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Home My WebLink About191-025CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: MPG-07 (PTD# 1910250) - Shut in for 4 year AOGCC MIT-IA Date:Monday, December 2, 2024 10:21:43 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Tuesday, November 26, 2024 1:10 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: NOT OPERABLE: MPG-07 (PTD# 1910250) - Shut in for 4 year AOGCC MIT-IA Mr. Wallace – PWI well MPG-07 (PTD# 1910250) is currently shut in and will not be brought online for its scheduled 4 year MIT-IA due this month. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. 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N Sands 4.5 5 5176 - 5188‘ 4045’ - 4053‘ 5220’ - 5238‘ 4076’ - 4089‘ 5257’ - 5262‘ 4103’ - 4107‘ 5286’ - 5326‘ 4124’ - 4153‘ 4.5 5 5398‘ - 5446’ 4204‘ - 4240’ OB Sands 4.5 5 5494‘ - 5534’ 4275‘ - 4305’ MPG-07i7UHH&DPHURQ³0 :HOOKHDG )0& ³ ; ´ ,QM KDQJHU Z 7&,, WKUHDG DQG ³ µ+¶ %39 SURILOH µ¶ ,' 12/27/91 HDS Original Completion 7“ Float Collar 7“ Shoe 5797‘ 5707‘ ³ .115‘ ³.%7&2697‘ RA Tag 4690’ 3.5“ WLEG 3.5“ HES XN-Nipple (2.813” pkg.) 2.750” No-Go ID 7“ x 3.5” Baker Premier Packer 3.5“ x 1.5” Camco MMG GLM 3.5“ x 1.5” Camco MMG-W GLM 3.5“ x 1.5” Camco MMG GLM 7“ x 3.5” Baker Premier Packer 7“ x 3.5” Baker Premier Packer 3.5“ HES X-Nipple (2.813” pkg.) 2,519‘3.5“ x 1.5” Camco MMG GLM 5,478‘ 5,470‘ 5,459‘ 5,419‘ 5,381‘ 5,344‘ 5,149‘ 5,112‘ 5,092‘ 3.5“ HES X-Nipple (2.813” pkg.) 09/28/07 SKB / LH RWO and casing repairs by 4ES 2,466‘ X 3.5“ x 1.5” Camco MMG-W GLM 5,219‘ 3.5“ HES X-Nipple (2.813” pkg.)5,448‘ KOP @ 500‘ Max hole angle (tbg) = 52 O @ 2800’ Hole angle thru perfs = 42 O 7“ HES Cementer & Baffle Plate 2,030‘ NOTE: SL had trouble getting through the SPM @ 5149‘ w/o KOT with catcher tray. 9 5/8“ Bowen Csg Patch 51‘ Flow Sleeve DV DV DV DV Valves in SPM / XN: Arrangement as of 10/16/12 PXN Extrapolated SBHP pressure 2/26/12 N-sands: 1941# @ 4026‘ TVD (8/19/11) OA sands: 2270# @ 4207’ TVD OB sands: 1953# @ 4258’ TVD . MEMORANDUM TO: Jim Regg�� P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector Well Name MILNE PT UNIT G-07 Insp Num: mitLOL201116094021 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, November 23, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC G-07 MILNE PT UNIT G-07 Src: Inspector Reviewed By P.I. Supry Comm API Well Number 50-029-22140-00-00 Inspector Name: Lou Laubenstein Permit Number: 191-025-0 Inspection Date: 11/15/2020 Packer Well G-07 ' jType Inj W ';TVD PTD 1910250 jType TestSPP Test psi BBL Pumped: 0.7 BBL Returned: Interval 4YRTST P/F Notes' Standard 4 year test Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 4000 11 TUbing� 1069 �� 1068 1076 1078 1500 IA 493 0.7 OA o _ 1732 1665 1655 o - 0 0 ' Monday, November 23, 2020 Page 1 of I • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,November 21,2016 TO: Jim Regg61( Z P.I.Supervisor J q SUBJECT: Mechanical Integrity Tests t HILCORP ALASKA LLC G-07 FROM: Bob Noble MILNE PT UNIT SB G-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB G-07 API Well Number 50-029-22140-00-00 Inspector Name: Bob Noble Permit Number: 191-025-0 Inspection Date: 11/13/2016 Insp Num: mitRCN161113164801 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well� G-07 ' Type Inj W' TVD 4000 - Tubing 1206 1205 - 1205 1204 , — - — 216 2007 - ' 1928 1914 PTD 1910250 - Type Test SPT Test psi 1500 IA Interval4YRTST P/F P ✓ OA 7 4 5 • 5 Notes: SEAMS JUN 0 8 2017 Monday,November 21,2016 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Saturday, November 10, 2012 7:42 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); AK, OPS MPU Well Ops Coord Cc: AK, D &C DHD Well Integrity Engineer, Wood, Alecia Subject: OPERABLE: Injector MPG -07 (PTD #1910250) AOGCC MIT -IA Passed Attachments: MIT MPG-07 11- 09- 12.xls All, Injector MPG -07 (PTD #1910250) passed an AOGCC witnessed MIT -IA on 11/09/2012. The passing test confirms two competent barriers to formation and the well is reclassified as Operable. The MIT -IA form is attached for reference: «MIT MPG -07 11- 09- 12.xls» Thank you, SCANNED jUL 2 2 2013 Mehreen Vazir BPXA Well Integrity Coordinator From: AK, D &C Well Integrity Coordinator Sent: Saturday, November 03, 2012 9 :00 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Chris Wallace (chris.wallace@ alaska.gov); Brooks, Phoebe L (DOA) (phoebe.brooksOalaska.gov); AK, OPS MPU Well Ops Coord Cc: Clingingsmith, Mike 3; AK, D &C DHD Well Integrity Engineer; Wood, Alecia Subject: UNDER EVALUATION: Injectors MPG -07 (PTD #1910250) POI for AOGCC MIT -IA All, Injector MPG - 07 (PTD # 1910250) is ready to be placed on injection so an AOGCC witnessed MIT -IA can be performed for UIC compliance. The well passed an MIT -IA on 02/26/2012 confirming two competent barriers to formation. At this time the well is reclassified as Under Evaluation. The MIT -IA form is attached for reference: « File: MIT MPG - 07 02 - 26 - 12.xls» Thank you, 1 Mehreen Vazir BP Alaska - Well Integrity Coordinator « OLE Object: Picture (Device Independent Bitmap) » WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com Direct Cell: 832.651.5253 Direct Email: Mehreen.VazirPBP.com 2 0 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reggaalaska.gov; doa .aogcc.prudhoe.bayValaska.gov; phoebe.brooksCdlalaska.gov; OPERATOR: BP Exploration (Alaska), Inc. FIELD 1 UNIT 1 PAD: Milne Point / MPU / G DATE: 02/26/12 OPERATOR REP: Mehreen Vazir AOGCC REP: Packer Depth Pretest Initial _ 15 Min. 30 Min. 45 Min. 60 Min. Well MPG-07 Type Inj. N TVD 4,000' Tubing 250 _ 250 250 250 Interval 0 P.T.D. 1910250 Type test P Test psi 2000 Casing 0 2005 1935 1922 P/F p Notes: Pre injection MIT -IA OA 0 0 0 0 Used 3.6 bbl to increase IA to test pressure Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test_ Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring 1 = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10-426 (Revised 06/2010) MIT MPG - 07 02 26 12.xls • i bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder -0 2 - Alaska Oil and Gas Conservation Commission D Y/ 333 West 7 Avenue l l / Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPG -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPG -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator . 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPG -Pad 10/10/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPG -01 1890290 50029219270000 Tanko conductor NA NA NA NA NA MPG -02 1890280 50029219260000 Tanko conductor NA NA NA NA NA MPG -03A 2042190 50029219420100 Tanko conductor NA NA NA NA NA MPG-04 1890450 50029219410000 Tanko conductor NA NA NA NA NA MPG -05 1910230 50029221380000 1.1 NA 1.1 NA 5.1 8/14/2011 ---> MPG -07 1910250 50029221400000 0.1 NA 0.1 NA 3.4 9/4/2011 MPG -08A 1930480 50029221410100 0.2 NA 0.2 NA 2.6 10/10/2011 MPG -09 1971170 50029227790000 1.3 NA 1.3 NA 15.3 10/30/2009 MPG -10 1971180 50029227800000 2.1 NA 2.1 NA 20.4 10/30/2009 MPG -11 1971190 50029227810000 0.8 NA 0.8 NA 5.1 8/14/2011 MPG -12 1971420 50029227920000 1.3 NA 1.3 NA 8.5 8/14/2011 MPG -13 1971200 50029227820000 1.2 NA 1.2 NA 10.2 10/30/2009 MPG -14 2011330 50029230310000 0.8 NA 0.8 NA 4.3 9/4/2011 MPG -15 1971220 50029227840000 2.9 NA 2.9 NA 34.0 10/30/2009 MPG -16 2032100 50029231890000 1.8 NA 1.8 NA 17.0 8/15/2011 MPG -17 2040130 50029231920000 1.6 NA 1.6 NA 14.5 8/15/2011 MPG -18 2040200 50029231940000 1.6 NA 1.6 NA 13.6 8/15/2011 MPG -19 2041920 50029232280000 1.6 NA 1.6 NA 13.6 8/15/2011 - ~~. _s - Vii. PROACTIVE DIAGNOSTIC SERVICES INC. SELL LOG TRANSM/TTAL To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Internationa{Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) lnjection Profile 03z1u1-10 MPU G10 BL; EDE 50-029-22780-00 ./ 2) .~, .~~:~~~~~ zU ~ ~' 2 Der Signed Print Name: Injection Profile 01,Ju1-10 MPU G07 BL/EDE 50-029-221 CJ ~ ; 3a ,3 7 ~--, ~ ~~ ! ~ ~ ,' Date : ~; l_ ~i ; ,'' ` i ,c' :. _ , PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : od~anc~TOraaeC~s'rser~orvlog.oo€~ WEBSITE : ~rrnru.merrsor?~loa.wom C:\Documents and Setfings\Diane Williams\Desk[op\Transmit_Conoco.docx • t/I~~~L LAG ~I ~~ 41 l l ~~I / l ~ '; 4 L 3s- ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 ~JN FEB ~. 9 2008 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing-lnspecticra(~liper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Andy Farmer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and V%c r~ ~ -oa~_ ~ ~ ~~3 i ProActive Diagnostic Servic~,lnc. Attn: ~ Robert A. Richey: 130 West Mternational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 1) Injection Profile 30-Nov-07 G071 1 EDE 50-029-221 d0~00 2) - _~, _. Signed . .Date ~ ` ' ..y ~ `" ~~'` Print Name: .~„ PROACTNE DIAGNOSTIC SERVICES, lNC., 130 W. {NTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 89518 PHONE: (907)245-8951 FAX: f8U7-245.88952 E-MAIL : pdsanctaoragela~mernorylog.com WEBSITE : wwvv.meaa~oryiog.corn D:\MTasOer_Copy_00_PDSANG20xx\Z_Word~DisenburionlTrmsmittal Sheets\Tcanamit Origmel New.dac • MEMORANDUM TO: Jim Regg (1 ~~`~ tt~ r=(~ P.1. Supervisor FROM: LOU Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, November 19, 2007 SUBJECT: Mechanical Integrity Tests / BP EXPLORATION (ALASKA) INC r(_/]~CJ"~ G-07 ~~, O MILNE PT [.KNIT SB G-07 Src: Inspector NON-CONFIDENTIAL Y Reviewed By: P.I. Suprv JSr Comm Well Name: MILNE PT iINIT SB G-07 Insp Num: mitLG071 1 1 6094909 Rel Insp Num: API Well Number: so-o29-z214o-00-0o Inspector Name• Lou Grimaldi Permit Number: 191-025-0 Inspection Date: 11/14/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~ ~ Well ~ G-o7 ;,Type Inj. '~ `~' ~~ TVD ~ aooo ~ IA I aIO ~ t7zo I66o I66o - 17910250 ~ SPT P.T. ~ iTypeTest j ~ Test psi j I soo , a pA o~ ~ off o I - Interval iNrTAL P/F P ~ Tubing I I2I5 Izls ~ izts ~ I21s~~ Notes' Observed well in pretest conditions for thirty minutes w/ no change..5 bbl's pumped. Good test. w`ud~~~~+NCV 3.,207 Monday, November 19, 2007 Page 1 of 1 11 /05/07 a~~l~m~~~~~~ Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .loh # ~'~~u IV~~ ~ ~~07 Inn 1')nsrrintinn n~tp NO. 4360 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Niakuk, Milne Pt., Pt. Mac, Prince C RI !`nlnr rr1 S-400A 11855508 USIT REVISED) C 09/18/07 1 C-30 11695080 LDL 10116/07 1 Z-228 11594525 SBHP SURVEY - 10/06/07 1 14-31 11890316 LDL 10118107 1 NK-22A 11855822 DRIFT TDILDL (- 10!25107 1 MPG-07 NIA CORRELATION/DDL ~ 09/08!07 1 • MPG-07 11628799 MEM INJ PROFILE C 10/20/07 1 MPF-10 11767140 MEM INJ PROFILE ~,' 09/15/07 1 MPS-OS 11745237 MEM PPROF SUPPLEMENT LOG - 3'~-. 10/09!07 1 P2-19A 11649963 _ MCNL '} ~ ,~ Z 04/22/07 1 1 OWDW-SW 11221548 RST ~ 03/05/06 1 1 W-17A 11588701 MCNL _ ~ 'tl. 12/26/06 1 1 14-30A 11485775 MCNL --6 (p0 11/22!06 1 1 L-51 40013624 OH MWD/LWD EDIT 06/26/06 2 1 YLtHJt AGI\NUVVLtUIit KtGt1Y i tiY SIIiNINCi ANU Kt 1 UKNINIi UNt GUYY tAG_ti 1 U: BP Exploration (Alaska) Inc. ~ w ~r) Petrotechnical Data Center LR2-1 - '^ 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~~.,11~ ~~ ~ ~~~ 1 Date Delivered: ~°4~?`plldRl`~ ,4t"-fit Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • ~Y STATE OF ALASKA /-~ f ALA OIL AND GAS CONSERVATION COM~SION ~~:~ REPORT OF SUNDRY WELL OPERATIONS `~ ra~,~,~ 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 191-025 - 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22140-00-00 , 7. KB Elevation (ft): 66 0' - 9• Well Name and Number: . MPG-07i " 8. Property Designation: 10. Field /Pool(s): ADL 047434' Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 5818 ' feet true vertical 4514 feet Plugs (measured) None Effective depth: measured 5707 ~ feet Junk (measured) 4690' true vertical 4432 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 115' 115' 2730 1130 Surface 2662' 9-5/8" 2697' 2372' 3520 2020 Intermediate Production 5762' 7" 5797' 4498' 7240 5410 Liner t`~w`.rv`r~e~l ~~~~ ' ~~~7 Perforation Depth MD (ft): 5176' - 5534' Perforation Depth TVD (ft): 4046' - 4305' 2-7/8", 6.5# L-80 5478' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 3-1/2" Baker Premier Packers '~ ' ~ -~- .,...a. ~ ~~ ~ 5112', 5344' & 5459' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ^ Development ®Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ^ Oil ^ Gas ^ WAG ^ GINJ ®WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Bryan McLellan, 564-5516 307-099 Printed Name Sondra Stewman Title Technical Assistant .-' Sig ature _ ^~~~, Phone 564-475 Dai~ ~ "~ Prepared By Name/NUmber: Sondra Stewman, 564-4750 ~~~~ :,~~ "r, Form 10-404 Revised 04/2006 C" l~~J~1'~ ~ f~( (~~ (~ ~ Submit Original Only IGINAL ~~~. ,~,o<<~ OR Tree:Cameron 3 1/8" 5N1~ Wellhead: FMC 11" X 3 1/2" Inj hanger w/ 3 1/2 TC-II thread and 3" `H' BPV profile. 2.98" ID 13 318" 54.54, K-55 115' KOP @ 500' Max hole angle (tbg) = 52o @ 2800' Hole angle thru perfs = 42o 9 5t8" 36#, K-55 BTC 2697` RA Tag 469 3.5", 9.2 ppf, L-80 TC-II Tbg. (cap. = 0.0087 bpf, drift = 2.867" 7" 26#, L-80, BTC Casing (drift ID = 6.151, cap.= .0383 bpf) Perforation Summary Size Spf Interval (TV N Sands 4.5 5 5176 - 5188' 4045' - 4C 5220' - 5238` 4076' - 40 5257' - 5262' 4103' - 41 5286' - 5326' 4124' - 41 O Sands 4.5 5 5398' - 5446' 4204' - 4< 5494` - 5534' 4275` - 4: 4.5" HSD, 51 B HJ-11, 72 deg. phasing 5 spf Orig. RKB - Hgr. Elev. = 35' (Nabors-27E) 3 5/8" Bowen Csg Patch 51' HES Cementer & Baffle Plate 2,030` ' 5" HES X-Nipple (2.813" pkg.) 2,466` 3.5" x 1.5" Camco MMG GLM 2,519` I HES X-Nipple (2.813" pkg.) 5,092` )TF I ~' ~~ ,ut' ~tilr~,1 through the SPM @ i ~ KC~T i!li ~;atchertray. 3.5" Saker Premier Packer 5,112` x 1.5" Camco MMG GLM 5,149' c 1.5" Camco MMG-W GLM 5,219' < 3.5" Baker Premier Packer 5,344` x 1.5" Camco MMG GLM 5,381 ` x 1.5" Camco MMG-W GLM 5,419' HES X-Nipple (2.813" pkg.) 5,448' K 3.5" Baker Premier Packer 5,459' 1ES XN-Nipple (2.813" pkg.) 5,470` 2.750" No-Go ID 3.5" WLEG 5,478' DATE REV. BY COMMENTS 12/27/91 HDS Original Completion 09/28/07 SKB / LH RWO and casing repairs by 4ES 7" Float Collar 5707` 7" Shoe 5797' MILNE POINT UNIT WELL No.: MPG-07i API : 50-029-22140 MPG-07i • • BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: MPG-07 Common W e1i Name: MPG-07 Spud Date: 5/17/1991 Event Nam e: WORKO VER Start : 8/27/2007 End: Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 9/9/2007 Rig Name: NABOB S 4ES Rig Number: Date ~ From - To Hours ' Task Code NPT Phase ~ Description of Operations 8/26/2007 14:00 - 15:00 1.00 MOB P PRE Move rig from MPU I Pad to MPU G Pad. 15:00 - 19:00 4.00 MOB P PRE Spot rig over MPG-07i and berm up rig. Spot pits and pipe shed and raise derrick. 19:00 - 20:30 1.50 W HSUR P DECOMP P/T circulating lines to 3500-psi. RU lubricator and P/T to 500-psi to pull BPV. Did not pull BPV as one was not set in wellhead. RD lubricator and lay down same. Accepted rig @ 1900-hrs. 20:30 - 00:00 3.50 KILL P DECOMP Load pits w/9.3-ppg NaCI brine. Spot, berm and rig up lines to Tiger Tank. Hook up bleed tank to OA. 8/27/2007 00:00 - 00:30 0.50 KILL P DECOMP Load pits w/9.3-ppg NaCI brine. Spot, berm and rig up lines to Tiger Tank. Hook up bleed tank to OA. 00:30 - 02:00 ~ 1.50 KILL P DECOMP Circulate out diesel freeze protection and packer fluid with ~ 190-Bbls. 9.3-ppg brine @ 3-4 BPM @ 500-800 psi. i Recovered -60-Bbls. diesel and trace crude along with packer fluid. No fluid recovered from OA. 02:00 - 03:00 1.00 WHSUR P ~ DECOMP FMC wellhead tech dry rod set TWG. Test same from above 1 03:00 - 04:00 1.00 WHSUR i P DECOMP and below to 1000-psi for 10-charted minutes. ND Tree. Inspect tubing hanger threads. Threads appear damaged and corroded. 04:00 - 07:00 3.00 BOPSUf~ P ~ DECOMP NU ROPE. 07:00 - 08:00 1.00' BOPSU P DECOMP Weekly safety meeting with all crew. 08:00 - 14:00 6.00 BOPSU~ P DECOMP P/T BOPE per AOGCC/BP requirements to 250-psi LO/3600-psi Hi. Tested 2-7/8" x 5-1/2" VBR's w/2-7/8" and 3-1/2" test joints. Tested annular preventer to 250-psi Lo/3500-psi Hi w/2-7(8" test joint. Test witness waived by B. i Noble, AOGCC, 16:00 hrs 8/26/2007. 14:00 - 17:30 3.50 PULL P DECOMP RU lubricator and tested to 500 psi. Pulled TWC. LD lubricator. 17:30 - 18:00 0.50 PULL P DECOMP MU landing joint and tubing spear. BOLDS. Held crew change. 18:00 - 19:30 1.50 PULL P DECOMP PJSM. PU tubing hanger with 25k Ib. Continued PU to 75k Ib (35k Ib over string weight) to release packer. Disengaged and ~ LD spear, RU to circulate. 19:30 - 20:30 1.00 PULL P DECOMP CBU at 4 bpm and 730 psi. Shut down and observed well. ~ Lost about 12 bbls fluid in 20 minutes. ~ 20:30 - 00:00 3.50 PULL P DECOMP POH, LD 2-718" tubing. Packer dragging 5k-10k Ib. Had initial minor swabbing. Slacked off and slowly rotated packer to free. Double displaced with 9.3 ppg brine. Fluid losses steady at 10-12 bph. ~ 8!2812007 00:00 - 02:30 2.50 PULL P DECOMP Continued POH, LD 2-7/8" tubing. Fluid losses steady at 10-12 bph. I 02:30 - 03:30 1.00 PULL P ' DECOMP LD packer and tailpipe ass'y. Middle packer element deformed and broken. Recovered packer, 160 jts 2-718" tubing, X nipple, ~~ PX plug. i 03:30 - 04:00 0.50 PULL P DECOMP Cleare and cleaned rig fioor. 04:00 - 06:00 2.00 CLEAN ~ P DECOMP PUMU BHA #2: 6-1/8" bit, 7" scraper, boot baskets, sub, bumper sub, oil jar, and DC's. 06:00 - 06:30 0.50 CLEAN P DECOMP PTSM, crew change and daily rig maintenance. 06:30 - 11:30 5.00 CLEAN P DECOMP RIH w/BHA #2 on 3-1/2" DP 1 x 1 from pipe shed. Maintaining constant hole fill. Fluid losses averaging 14-BPH. Tagged i solid fill @ 5498'. 11:30 - 13:45 2.25 CLEAN P ~ DECOMP Rig up circulating lines and attempt to break reverse i circulation. Unable to obtain returns @ 4.0-BPM @ 500-PSI. Printed: 10!312007 2:18:28 PM • • BP EXPLORATION Page 2 of 1O Operations Summary Report Legal Well Name: MPG-07 Common Weli Name: MPG-07 Spud Date: 5!17/1991 Event Name: WORKOVER Start: 8/27!2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/9/2007 Rig Name: NABOBS 4ES Rig Number: j Date From - To ;Hours ` Task '~ Code 8/28/2007 ~ 11:30 - 13:45 2.25 ~ CLEAN ~ P 13:45 - 16:30 I 2.75 I CLEAN I P 16:30 - 20:00 3.50 CLEAN P 20:00 - 22:00 2.00 CLEAN P 22:00 - 23:30 I 1.501 BOPSURN 23:30 - 00:00 8/29/2007 00:00 - 02:00 02:00 - 02:30 02:30 - 04:30 0.50 CLEAN P 2.00 CASE P 0.50 CASE P 2.00 CASE ~ P NPT ~ Phase Description of Operations - - _ DECOMP _ - - Swapped manifold to circulate long way. Circulating long way ~, @ 6.0-BPM @ 1280-PSI. Pump 2 x 20-Bbl. hi-vis sweeps @ ~, 6.0-BPM @ 1280-PSI to clean up hole of debris generated from scraper run. DECOMP Swap manifold to reverse circulate. Revrse circulating @ i ~ 3.0-4.0-BPM @ 400-500 PSI. C/O fill down to 5593' DPM. Bottom perfs. @ 5534'. Reverse circulate o e clean. ~ Recovered -1-yard of oily sand and scale across shaker. i j DECOMP POH w/BHA #2 standing DP in derrick. i DECOMP Stand back 4 3/4" DCs. Break out & UD BHA. Empty boot baskets. Recovered scale & oily sand. Clear & clean rig floor. !, DECOMP PfU kelly. Tighten up swivel packing. Attempt to pressure test ' kelly valves no success. i DECOMP M/U RBP & running tool. RIH on 4 3/4" DCs. j TIE61 RIH w/ RBP &DCs & 52 stands of DP. 5165'. TIEB1 ice out & set RBP w/ 15K @ 5140'. P/U Wt = 83K, S/O Wt 04:30 - 05:30 1.00 CASE P 05:30 - 08:15 2.75 CASE P i 08:15 - 09:30 1.25 CASE P 09:30 - 10:00 0.50 CASE P ii 10:00 - 11:30 1.50 CASE P 11:30 - 13:30 2.00 CASE P 13:30 - 18:00 4.50 CASE N i DFAL 18:00 - 22:00 4.00 CASE P 1 22:00 - 00:00 2.00 CASE P f 8/30/2007 00:00 - 01:30 1.50 CASE I P 01:30 - 02:30 1.00 CASE P 02:30 - 03:00 0.50 CASE P 03:00 - 04:30 1.50 CASE P 04:30 - 06:00 1.50 CASE P 1 06:00 - 09:00 3.00 CASE P 09:00 - 09:30 0.50 CASE P 09:30 - 10:45 1.25 CASE P 0 0 11 :45 - 13:00 ! 1. 26 F SH f P = oor~. TIEB1 Pressure up & attempt to test RBP. No good. Pumped 4.2 BPM @ 810 psi. S/D & pressure bled off to 380 psi in 7 min. OA was on vacuum. Unset RBP P/U 10' & reset RBP @ 5130'. Pressure up & test csg. Had to purge test Eine & replace sensor. Tested csg /RBP to 3600 psi for 30-charted minutes. Test good. TIEB1 Circulate bottoms up 5 BPM @ 740 psi. TIEB1 POOH w/ RBP setting tool. TIEB1 ND flow riser and NU shooting flange in preparation for running USIT log. TIEB1 PJSM -All crew: Rig up e-line to run USIT log. TIEB1 Rig up SWS E-line equipment and tools. TVE61 Run USIT logging tools to 5050' and log casing. TIEB1 POH wlUSIT logging tools. Logging tools failure. TIEB1 RIH & log w/ USIT. Logged in corrosion mode from 5100' to 30'. Logged in cement mode from 5100 to 30'. TIEB1 POOH & UD logging tools. Evaluate log w/ town &SWS engineers. TOC @ 2140'. located collars @ 2122', 2078', 2036' & 1992'. Plan to back off collar @ 2036' & make cut @ 2014'. TIEB1 M/U string shot. RIH & correlate shot over 7" casing collar @ 2036' (shot from 2030-2042'). Fire shot & POOH. UD tools. TIE.B1 f8/D logging equip. N/D shooting flange. N/U flow nipple. TIE.61 M/U 7" RBP. RIH on 4 314" DCs. TIE.B1 RIH w/ 7" RBP 25 stands + 1 single. TIE.B1 Space out RBP @ 2650'. Set w/ 15K . P/U Wt = 50K, S/O Wt = 42K. R/U & pressure test RBP to 1000 osi for 30 min. Charted test. Tested good. Pull two stands TIE:B1 Dump 1200# sand down DP to top of RBP. Allow sand to settle. Tai TO @ 2595'. TIE:61 Rig maintenance: Grease blocks, crown and drawworks. Derrick inspection. Check PVT alarms and make environmental walk-around. TIE:B1 POH UD RBP running tool. TIEB1 C&C rig floor. Prepare to PUMU 5-1/2" Multi-String cutter BHA. TIE61 PUMU BHA #3: 5-1/2" Multi-String casing cutter w/6-1/8" stabilizer. and REH w/same. Printed: 10/3/2007 2:18:28 PM • • BP EXPLORATION Page 3 of 10 Operations Summary Report Legal Well Name: MPG-07 Common Well Name: MPG-07 Spud Date: 5/17/1991 Event Name: WORKOVER Start: 8/27/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/9/2007 Rig Name: NABOBS 4ES Rig Number: Date ~ From - To Hours Task ', Code NPT ' Phase 8/30/2007 { 13:00 - 13:45 ~ 0.75, FISH ~ P ~ ITIE61 13:45 - 15:00 { 1.25 FISH {P ~ {TiE61 15:00 - 15:45 0.75 FISH P ' TIE61 15:45 - 16:30 0.75 FISH P i T1E61 16:30 - 18:30 2.00 FISH P I TIEBI 18:30 - 19:30 ~ 1.00 FISH P ~ TIE81 19:30-20:30 i 1.OO~FISH ~P { ~TIEB1 20:30 - 21:00 0.50 FISH P ~ TIEB1 21:00 - 22:00 1.00 FISH P TIEB1 22:00 - 22:30 I 0.501 FISH I P I I TIEB1 22:30 - 23:30 1.00 FISH P TIEB1 23:30 - 00:00 0.50 F1SH P TIEB1 8/31/2007 00:030 - 010:00 0.50 FISH P iTIE61 01:00 - 05:00 4.00 FISH P ~ TIEB1 05:00 - 06:00 1.00 FISH P `` TlEB1 06:00 - 09:00 3.00 FISH P I TIEB1 09:00 - 10:00 I 1.001 FISH 1 P I ITIEBI 10:00 - 11:30 1.501 FISH P TIE61 11:30 - 12:30 1.00 FISH P TIEB1 12:30 - 13:00 0.50 FISH I P ~ iTIEB1 13:00 - 13:45 0.751 FISH P I, ITIEBI Description of Operations Kelly up. Pressure up DP to 1200-psi to open cutter knives. reduce pressure to 150-psi and locate casing collar above cut @ 1997'. S!D pump and rack back kelly. Pick 1 jt. DP and 1 x 10' DP pup jt. PUMU Kelly. Pressure up DP and locate casing collar @ 2036'. S/D pump. Position cutter @ 2016'. Establish cutting parameters: 72-RP 750-pst pump pressure. Rotate @ 72-RPM @ 750-psi and make cut in casing. Line up circulating lines and pump 9.8-ppg brine down DP taking returns into Tiger Tank. Pumped 125-Bbls. brine and flushed OA until 9.8-ppg brine returns were obtained. Monitored OA for flow from leak in 9-5/8" casing. No returns were noted. PJSM -Pump hot diesel. MIRU LRS to pump diesel. LRS operator reported leak in water injection line behind rig adjacent to where LRS truck spotted. Reported leak to pad operator. Pad operator placed us on hold for 30-minutes. Pad operator released us to go back to work. Pumping 75-Bbls. diesel @ 1.5-BPM, 750-psi and 180E taking returns to Tiger tank. Spot diesel & allow to soak for 30 min, then circulate diesel out into tiger tank. Spot 50 bbl Surf-Safe -O in 7" x 9 518" annulus & allow to soak for 30 min. Pumped 3 BPM @ 600 psi. Circulate out Surf- Safe-O. Pumped 3.5 BPM @ 900 psi. Pumped total of 70 bbls until clean. Bled off 30 psi from DP x 7" annulus. open annular & flush out diesel w/ 10 bbls. Monitor well. RIH & verify cut @ 2016'. Set back kefly & blow down lines. UD 10' DP pup & 1 jt of DP. POOH & stand back 18 stands of 3 1 J2" DP. Stand back DCs. UD BHA. Inspect cutters. Good indication of cut. Recovered 2 pcs of metal on cutter. R/D spinners & R/U 7" power tongs. M!U BHA # 4, Spear assy as follows: Bull Nose, Spear Pack off, Spear, Extension, Stop Sub, XO. TL = 13.01'. Spear into hanger. Check all annulii. BOLDS. P/U & pull hanger to floor. Pulled w/ 57K. Remove Spear, Break out hanger & pup jt. UD same. POOH & UD 7" 26#, L-80 BTC casing. Recovered 46 full jts + 20' cut off jt. Cut appeared to have 6" window cut in it. See photos. Jts averaged 16K ft-lbs break out torq. Recovered 21 positive stand off centralizers. Clear & clean rig floor. R!D csg tools. PUMU BHA #5: 8-1/2" mill shoe, 8-1/8" wash pipe, 8-118" boot basket, 9-5/8" casing scraper, bit sub, XO, LBS, Jars, 9 x 4-3/4" DC's. RIH w/same on DP to 2012' staying 4' off top of stub with mill shoe. This would place 9-5/8" scraper @ 1970'. Kelly up, close annular preventer and reverse circulate surface to suface @ 5.0-BPM @ 720-PSI. Rack kelly back. POH w/BHA #5. BO/LD BHA #5. Crew change. Rig crew service rig and prepare to RIH w/9-5/8" Halco RTTS packer. RIH w/9 x 4-3/4" DC's and 9 stds. DP from derrick. PUMU Printed: 10/3/2007 2:18:28 PM • • BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: MPG-07 Common Well Name: MPG-07 Spud Date: 5/17/1991 Event Name: WORKOVER Start: 8/27/2007 End: Contractor Name: NABORS ALAS KA DRILLING I Rig Release: 919/2007 Rig Name: NABORS 4ES Rig Number: Date ~ From - To ~ Hours '', Task ,Cade ', NPT Phase Description of Operations 8/31!2007 FISH 0 ; P TIEB1 9-5/8" RTTS packer. ~ 13:46 - 14;45 FISH 1 .00 P TIEB1 Hook up circulating lines to DP. Set packer @ 46' below rotary table placing it in the middle of the 1st full joint of casing from surface. PIT 9-5/8" casing from below to 1000-psi for 10 charted minutes to ven y competent surface casing shoe. j I Tested good. 14:45 - 16:00 1 1.25 FISH P TIEB1 Release packer. RD circulating lines. POH UD 9-518" RTTS packer. 16:00 - 17:00 1.00 FISH P TIE61 PUMU Halco 9-5/8" RBP. RIH w/same to 1966'. Set RBP. 17:00 - 17:30 0.50 FISH P TIE61 POOH w! 2 stands. Prep to dump sand. 17;30 - 19:30 2.00 FISH P TIE61 Dump 44 sxs of 20/40 sand down drill pipe. Dumped total of 19:30 - 20:00 ~ 0.50 FISH P TIEB1 120:00 - 21:00 i.00 FISH P TIE61 21:00 - 22:00 1.00 FISH P TIEB1 22:00 - 22:30 0.50 FISH P TIE61 22:30 - 23:00 0.50 FISH P TIE61 23:00 - 00:00 1.OO FISH P TIEB1 911!2007 ',00:00-01;00 1,00 FISH P TIE61 01:00 - 01:30 0.50 FISH P TIEB1 01:30 - 02:30 1.00 FISH P I TIE61 02:30 - 03:00 0.50 FISH P TIEB1 ~I 03:00 - 05:00 I 2.00 FISH P TIEB1 '; 05:00 - 06:00 1.00 FISH P TIEB1 j 06:00 - 06:30 0.50 FISH P TIEB1 ~j 06:30 - 07:45 i 1.25 FISH P TIEB1 j 07:45 - 11:30 I 3.75 FISH P TiEB1 i j 11:30 - 13:00 1.50 FISH P TIEB1 113:00 - 14:00 1.00 FISH P TIEBi I 14:00 - 15:00 1.00 FISH P TIEB1 I 15:00 - 15:30 0.50 FISH P TIEB1 115:30 - 16:00 I I 0.50 FISH P TIEB1 I 16:00 - 17:00 1.00 FISH P TIEB1 i 17;00 - 18:30 1.50 FISH P TIEB1 18:30 - 20:00 1.50 FISH P i TIEB1 120:00 - 21:00 I 1.00 FISH I P i TIE61 121:00 - 22:00 ` 1.00 FISH ~ P I TIEB1 22:00 - 23:00 I 1.00 ~ FISH ~ P ~ TIEB1 123:00 - 00:00 ~ 1.00 i FISH ~ P TIEB1 R/U & pump 13.5 bbls down DP to displace sand. Pumped @ 1 BPM. POOH & stand back 3 1/2" DP. UD running tool. N/D BOP stack & set back. Remove DSA. N/D Tubing spool. R/U Wach's cutter. Cut off remaining wellhead below the landing flutes. X21") P/U & UD clamp head & cut off fluted hanger. N/U 21 1/4" flange to 13 3/8" conductor. N/U Tin Pot Riser to flange. Install flow riser & air boots. Fill riser & check for leaks, Ok. Load, Tally & MlU BHA #6 as follows: W/O Shoe, 2 ' WP Extensions, W/O Boot Basket, XO, XO. TL = 26.23'. RIH. Tag up & Wash over 9 518" casing @ 26'. Milling parameters: 60-RPM, 4.5-BPM @ 50-psi, WOB = 500#. Mill to 46'. CBU. Rotten cement, dead crude and diesel in returns across shaker screen. POH w/BHA #6 and lay down wash pipe extensions. PUMU BHA #7; Mil! shoe, washpipe, boot basket, XO, XO - 41.18'. Milling parameters: 60-RPM, 4.5-BPM @ 50-psi, WOB = 500#. Mill from 46' to 58'. CBU. POH BO/LD BHA #7. PJSM -PUMU BHA #8: 8-1J4" Multi-String Cutter, XO, 8-1/2" Stabilizer & XO. RIH w/BHA #8. Cut 9-5/8" casing @ 50'. RPM - 80, Pump psi - 780. POH UD BHA #8. PUMU BHA #9: Bull nose, ITCO 8-1/4" spear, spear extension, stop sub and XO = 11.34' RIH w/same. Spear 9-518" casing stub. POH UD 9-5/8" casing fish. recovered 1 casing collar and two cut pieces in one assembly which was 23.85' total length. UD BHA #9. PUMU BHA #10: 12-1/S" dress-off shoe, wash pipe extension, drive sub, XO & XO = 10.03'. RIH & dress off tubing casing stub. POH. Break out & UD BHA # 10. Blind off DP. RIH w/ 15 stands & displace fluid out of wellbore. POOH & stand back 3 112" DP w/o filling hole. P/U 3 4 3/4" DCs & bumper sub. Stand back in derrick. Printed: 10/3!2007 2:18:28 PM • • BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: MPG-07 Common Well Name: MPG-07 Spud Date: 5/17/1991 Event Name: WORKOVER Start: 8/27/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9!912007 Rig Name: NABOBS 4ES Rig Number: Date From - To 'Hours Task ', Code NPT Phase ~ Description of Operations 9/2/2007 ~ 00:00 - 01:30 ~, 1.50 ~ CASE ~ P ~ ~ TIEB1 ~ P/U external casing patch assy & 1 jt of 9 5/8" 40#, L-80, BTC 01:30 - 02:30 02:30 - 04:00 04:00 - 06:00 06:00 - 09:00 1.001 CASE { P i.50 CASE P 2.00 CASE P 3.00 CEMT ~ P 09:00 - 10:00 I 1.001 CASE P 10:00 - 10:30 I 0.50 CASE P I 10:30 - 20:00 9.50 CASE P 20:00 - 20:30 0.50 CASE ~ P 20:30 - 22:00 f 1.50 CASE ~ P TIE61 TIE61 TIE61 TIEB1 TIEB1 TIEB1 TIEBi TIEBi TIEB1 22:00 - 00:00 2.00 CASE P TIEBi 9!3!2007 00:00 - Oi:00 i 1.00 CASE P TIEB1 01:00 - 02:00 ~ 1.00 CASE P TIEBi 02:00 - 03:00 ~ 1.00 CASE P TiE61 03:00 - 03:30 0.50 CASE P TIE61 03:30 - 04:00 ! 0.50 CASE P TIE81 04:00 - 05:00 I 1.00) CASE I P I (TIE61 05:00 - 06:00 ! 1.001 CASE I P I I TIEB1 06:00 - 06:30 I 0.50 ~ CASE P TIE81 06:30 - 08:00. 1.50 ~ CASE ~ P i TIEB1 casing &RIH. M/U stand of 6-114" DCs & bumper sub on top of casing. Tag stub & rotate down over csg stub. Bump casing patch down over stub until it bottomed out. P/U & pull test string w/ 20K. Held Ok. Stand back DCs & bumper Sub. Fill 9 5/8" casing. R/U test equip. Pressure up & test 9 5/8" casing to 1000 psi for 10 min. monitorecTopen annulus. Tested Good. Charted test. R/D test equip. Suck out 9 5/8" casing. N(D Tin Pot riser. P/U & set slips w160K. R/U Wach's cutter & cut off casing. Cut jt. = 25.86`. Spot vac trucks and SLB cementers. Hook up hardline. Attempt to run 1" stinger in conductor through 1-314" port in 9-518" landing ring. Unable to run stinger due to taper from 20" to 13-3/8" in top of conductor. Connect cement line to 1" port on conductor. SLB batched up 5.5-Bbis. i5.8-ppg Class"G" cement w/accelerator and pumped same into 13-3/8" x 9-5(8" annulus @ .25-BPM. At 3.0-Bbis. away void filled up and returns were watery in consistency. At 3.5-Bbis. away returns changed to neat cement. Continued pumping cement until 5.5-Bbis. pumped away. Closed 1"ball valve on 1" port into conductor. Disconnected hardline and washed up cementers and lines into vac truck. Mix and apply gel plaster to top of landing ring/slips in top of 20" x 13-3l8" adapter spool to isolate 9.8-ppg brine from cement. Nipple up Tin Pot riser, air up airboots. RIH w!1 stand 6-114" DC's and 6-114" LBS. Hook up headpin to top of DC's to circulate 130-F 9.8-ppg brine. Circulate 130-F 9.8-ppg brine @ 3.0-BPM @ 35-psi. to aid in accelerating cement cure trme. ement -psi compressive strngth 1 0- rs. ave -hr. notice to AOGCC of impending weekly BOPE test @ 15:30-hrs. SWS had 550 psi compressive strength @ 2000 hrs. POOH & UD 4 3/4" DCs & bumper sub. Drain Tin Pot riser. N/D diverter flange & remove the Tin Pot riser from cellar. NJD oid Slip type wellhead. N/U new slip type starter head. N/U new slip type starter head. Tested to 950 psi for 30 min. N/U new tubing spoof. N/U DSA & BOPE. P/U running tool. Install test plug & UD running too{. Test breaks in BOPE & tubing spool by casing spool flange. LP 250 psi, HP 3500 psi. Charted same. Drain BOP stack. P/U running toot & pull test plug. install Wear Bushing. VD running tool. M/U RBP retieving tool, RIH w! 4 3/4" DGs & stands of 3 1!2" DP. Crew change and service rig. Derrick inspection, test PVT alarms and grease choke manifold. Stab TIW valvelheadpin and hook up circulating tines. Tag sand @ 1916'. Close annular preventer and reverse circulate sand off top of 9-5/8" RBP @ 1966' @ 5.0-BPM @ 600-PSI. Printed: 10/3/2007 2:18:28 PM ~ • BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: MPG-07 ~ Common Well Name: MPG-07 Spud Date: 5/17/1991 i Event Name: WORKOVER Start: 8/27/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 919!2007 ~~ Rig Name: NABOBS 4ES Rig Number: Date ,From - To ~ Hours ~ Task ~ Code , NPT ' Phase ~ Description of Operations 9/3/2007 06:30 - 08:00 1.50 i CASE ~ P j ~ TIEB1 I Latch u to 9-5/8" RBP and release. CBU. 08:00 - 10:15 2.25 ~ CASE ~ P ~ ~ TIEB1 POH UD 9-518" RBP. Jeff Jones waived AOGCC right to 10:15 - 10:30 I 0.25 F{SH ~ P ~ TIE61 10:30 - 11:00 ~ 0.50. FISH ~ P I , TIEB1 11:00 - 12:45 1.75 FISH P I TIE61 12:45 - 13:45 1.00. FISH P I TIEB1 13:45 - 15:00 1.25 FISH i N ~ DPRB TIEB1 15:00 - 15:30 0.50 FISH N ~ DPRB TIEB1 15:30 - 16:00 0.50 FISH N ',DPRB TIEB1 16:00 - 17:30 1 1.501 FISH I N I DPRB I TIE61 17:30 - 18:30 ' 1.00' FISH N ~ ! I DPRB TIEB1 18:30 - 19:30 1,00 FISH ~ N I DPRB TIEBi 19:30 - 20:30 1,00 FISH 1 N 1 DPRB TIEB1 20:30 - 21:30 1.00 FISH N f DPRB TIE61 21:30 - 22:30 1.00 ~ FISH N ~ DPRB ~ TIEB1 22:30 - 00:00 1.501 FISH P ~ TIEB1 9/4!2007 X00:00-01:30 ~ 1.50~FISH ~P ~ ~TIEB1 01:30 - 02:00 0.50 FISH P ~ TIEB1 02:00 - 02:30 0.50 FISH P ~ i TIEB1 02:30 - 03:00 0.50 FISH ~ P i ~ TIEB1 03:00 - 03:30 0.50 FISH I P i ~ TIEB1 03:30 - 04:30 1.00' FISH P TIE61 04:30 - 05:00 0.50 FISH P TIEB1 05:00 - 05:30 I 0.50 FISH {~{ P I TIEB1 05:30-10:30 ~ 5.00 BOPSURP ~ iTIEB1 10:30 - 11:00 I 0.501 CASE I P ; I TIEB1 witness BOPE test. PJSM -PUMU BHA. PUMU BHA #11: Muleshoe, 4-3/4" DC's x 9, blank XO, lower anchor, back-off tool, upper anchor & pumpout sub = 308.80'. RIH w/BHA #11. Filling DP every stand w(fresh water. Tag top of 7" casing stub @ 2016' wlbottom anchor of back-off tool. Applied torque along with 2000-4000 lbs. downweight on tools. Unable to work back-off tool into 7" casing. Disaplce DP w/9.8-ppg brine. POH VD BHA #11. PJSM -Make up BHA. PUMU BHA #12: 6" tapered bottom-hole mill, dbl. pin sub, boot basket x 2, bit sub, LBS, 4-3/4" drill collars x 9 = 312.03'. RIH w/same. Load pits w/150-Bbls. clean 9.8-ppg NaCt brine. Tag TOF @ 2016'. P/U kelly break circulation. Obtain milling parameters. P/U, S/O Wt = 45K. 5 BPM @ 300 psi. 70 RPMs, WOB 0-2K. Toirq =1500 Ft-Ibs. Work up & down thru top 5' of stub. Run in & out of stub w! o rotation. Con't in hole to 2370'. Circulate bottoms up 5 BPM @ 360 psi. Crew change. Inspect derrick & check PVT alarms. POOH & stand back 22 stands of 3 112" DP. Stand back 4 314" DCs. Break out & UD BHA # 12. P/U & M/U BHA #13 to back off 7" casing as follows: Mule Shoe, 9" 4 3/4" DCs, Blank X-Over, L. Anchor, Back Off Tool, U. Anchor, Pump Out Sub. TL = 308.8'. RIH w/ BHA #13. Fill each stand w! fresh water while RIH. Space out Back Off asst' from 2026-2046'. (connection @ 2036') M/U head pin. Pressure up & set bottom anchor wl 1000 psi & S!O ti{I take wt. Pressure up to 2K & set upper anchor. S/O w! 15K. Pressure up & Back off 7" casing„ Connection broke @ 12K. Cycled 12 times Back off pressure droipped to 400 psi, then began to increase to 800 psi. made total of 5 1/4 revolutions. Dropped dart. Sheared out 2500 psi. Pump 15 bbls to displace fresh water out DP. Break out & UD head pin. POOH & stand back 3 1!2" DP. Break out & UD BHA #13. M/U BHA #14 as follows: Bull Nose, Spear Pack Off, Spear, Extension, Stop Sub, XO, Bumper Sub, Jars, 9'DCs. TL = 309.47' RIH wJ BHA # 14 on 18 satands of DP. PiU kelly. Engage fish @ 2016' Swallow 8'. P/U 30K over, then S/O w/ 1 K over. Finish back off w/ 6 rounds.P/U pipe free. Set back kelly. Blow down lines. POOH & stand back 18 stands of 3 1/2" DP. Break out & UD fish &BHA #14. Recovered cit off jt 22.55 + .85 coupling. TL = 23.40'.' Have pin looking up @ 2040'. R!U test equip. Pull Wear bushing. Install test plug. Perform weekly BOPE test LP 250 nsi. HP 3600 psi, per AOGCCIBP requirements. Tested annular preventer to 250-psi Lo, 3500-psi Hi. M/U landing jt & pull test plug. UD same. Printed: 70/3/2007 2:18:28 PM • • $P EXPLORATION Page 7 of 10 operations Summary Report Legal Wel Common Event Na Contracto Rig Name Date 9/4/2007 I Name: MPG-07 Well Name: MPG-07 e: WORKOVER Start Name: NABOBS ALAS KA DRILLING 1 Rig NABOBS 4ES Rig ,From - To Hours ~ Task .Code NPT i'hase ~ -- -1 -_ - 11:00 - 12:00 1.00 CASE P i I TIE61 ~I 12:00 - 12:30 . 0.50 CASE P ' TIEB1 12:30 - 13:00 0.50 CPcSE ~ P ~ TIE61 I 13:00 - 14:00 1.00 CASE P ~ j TIEB1 ~ 14:00 - 14:30 0.50 CASE P ~ TIE61 i 14:30-15:00 0.50 CASE P I, ITIEBI 15:00 - 15:30 0.50 CASE P ~ ' TIEB1 15:30 - 20:30 5.00 CASE P ~~ m r ~ TIEB1 ~~ 20:30 - 21:30 ~ 1.00 ~ CASE ~ P I TIE61 i ~ I i 21:30 - 22:00 0.50 ~ CASE I P I ' TIE61 22:00 - 22:30 ~ 0.50 ~ CASE ~ P ' TIE61 22:30 - 23:00 0.50 CASE P I TIE61 . 23:00 - 23:30 0.50 CASE P ~TIEB1 23:30 - 00:00 0.50 CASE P ~ ~TIEB1 9!5/2007 1 00:00 - 00:30 0.50 CASE P I j TIEB1 1 00:30 - 01:30 1.00 CASE P I I TIEB1 01:30 - 02:00 ~ 0.50 ~ CASE ~ P 02:00 - 03:30 I 1.501 CEMT I P 03:30 - 04:00 I 0.501 CEMT I P 04:00 - 05:00 1.00 BOPSU P 05:00 - 06:00 1.00 WHSUR P 06:00 - 09:30 3.50 WHSUR P 09:30 - 10:00 0.50 WHSUR P 10:00 - 11:00 1.00 CASE P TIEB1 TIEB1 TIE61 TIE61 TIEB1 TIEB1 TIEBi TIEB1 11:00 - 12:00 1.00 CASE P ' TIE61 12:00 - 18:00 6.00 CASE P ~, TIEB1 I I 18:00 - 18:30 0.50 CASE I P I TIEB1 18:30 - 19:30 1.00 CASE P i TIEB1 19:30 - 22:00 2.50 CASE P j TIEB1 I Spud Date: 5/17/1991 8/27/2007 End: Release: 9!9/2007 Number: Description of Operations R/D DP tools. R/U floor to run 7" casing. Blow down lines. Drain BOP stack. P/U running tool & set test plug. N/D & remove test spool to allow for clearance to set slips. N/U BOP stack. Pressure test break on BOP. LP 250 psi, HP 3500 psi. Drain stack. P/U running tool & remove test plug. L/D same. P/U & run 7" 26#, L-80 TCII casing tie-back. Filled every 5 jts. Ran turbolator on each j texcept last jt below wellhead. Torque turned all connections to 10900 ft-Ibs. used Jet Lube Seal guard on all connections. Ran total of 50 jts. P/U 7" space out jt & landing jt. Establish weights. Slowly RIH while rotating string. Made up screw in connection to 10900 ft-Ibs by working torque down in string. P/U & pull twsted casing to 150K. P/U Wt = 52K, S/O wt = 46K. Rot wt = 48K. R/U equip & pressure test 7" tie-back to 2000 psi for 10 min, Held Ok. Charted test. Pressure up & shear open ES Cementer w/ 3300 psi. Pump thru ES cementer to insure good circulation. 4 BPM @ 250 psi. Split BOP stack & PfU. PIU & set slips w/ 100 K. as per FMC: Set stack back down on spool & N/U stack. Pressure test BOP break to 500 psi, Ok. R/U cementing head. Circulate well & heat up annular fluid. Pump 4 BPM @ 250 psi. Had 80 degree in & 80 degree out. Hold PJSM w/ all hands & review cementing procedure. Assign specific tasks to personnel. Pressure test lines to 3000 psi. Mix & pump 12 bbls of 15.8 ppg Class "G" cement. Blender "powdered out". S/D & clear blender. Con't pumping. Pumped 68.7 bbls of Class "G", mixed @ 15.8 ppg, Yld 1.16 ft3Jsx & 5.12 gal/sx mix water. Dropped plug & displaced w/ 78.9 bbls of 9.8 ppg brine. Bumped plug to 2400 psi, held 2 min, OK. Bled back .5 bbls, cementer held. Had i2 bbls of good thick cement returns to surface. PD @ 03:15 hrs. Flush all lines. Blow down all lines. R/D cementing head. R/D cementers. Drain BOP stack. N/D BOP. Cut off 7" casing w/ Wachs as per FMC. 7 1/2" of stub from cut. Dress csg stub. NU BOPE. Install 7" packoffs. Test 7" packoffs to 3600 psi. Test BOPE to 250 psi 13600 psi. Chart for 5 min. each. PUMU 6 118" Bit on 2 ea 4 3/4" Boot Baskets, Bit Sub, Bumper Sub, Oil Jars and 9 ea 4 3/4" DC's. OAL - 306.96' RIH on 3 1!2" DP to -1890'. WOC. @ 12:00 cmt with compressive strength of 26 psi Qust starting to come off bottom of UCA chart). Maintenance on draw-works. @ 14:00 compressive strength of 200 psi. @ 16:00 compressive strength of 350 psi. Crew change. Inspeck derrick. Check PVT alarms. Service rig. Cut & slip 84' of drilling line. Wait on cement @ 19:30 hrs had 785 psi..., 1000 psi @ 21:3C hrs. Printed: 10/3/2007 2:1828 PM • • BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: MPG-07 Common Well Name: MPG-07 Spud Date: 5/17/1991 Event Name: WORKO VER Start: 8/27/2007 End: Contractor Name: NABOBS ALAS KA D RILLING I Rig Release: 9!9/2007 .Rig Name: NABOB S 4ES Rig Number: Date ~ From - To ' Hours ~, 1 Task !Code NPT Phase Description of Operations - - - j-- - ~ 9/5/2007 ! 22:00 - 22:30 0.50 - - CEMT P 1 - - I TIE61 ; - - - j Finish RIH w/ 3 112" DP. 17 stands + doub{e. P/U Kelly. 22:30 - 23:30 1.00 CEMT P j TIE61 j Tag up on soft cement @ 1963'. Wash & rotate & drill thru cement to 2026' cement got harder towards bottom. Circulate II ~ I out cement. P/U Wt = 46K, S/O Wt = 40K Rot Wt = 44K. 60 I j ~ RPMs, WOB 1-6K, 5.8 BPM @ 630 psi. 23:30 - 00:00 0.50 CEMT P I TIE61 ~ Tag up on ES cementer @ 2026' 9/6/2007 00:00 - 00:30 0.50 CEMT P , ~ TIEB1 j Con't to drill out ES cementer. P/U Wt = 46K, S/O Wt = 40K, i . ~ ~ Rot Wt = 44K, 60 RPMs, WOB 5-10K. 5.8 BPM @ 630 psi. i i ~ Fell thru & washed from 2027 -2034' Tag up on Batfle Plate. I ~ 00:30 - 01:30 1.00 CEMT P ~ TIEB1 Mix & pump 40 bbls Hi-Vis sweep. Circulate until clean. Had I j. cement & rubber returns. 5.8 BPM @ 630 psi. I ~ 01:30 - 02:30 1.00 CEMT P TIEB1 Drill Baffle plate @ 2034'. P/U Wt = 46K, S/O Wt = 40K, Rot j ~ Wt = 44K, 60 RPMs, WOB 5-10K, 5.8 BPM @ 630 psi. 02:30 - 04:00 j 1.50 CEMT P ~ TIEB1 j Set back kelly &RIH to sand @ 2595'. Rot ate down into sand j ~ 6' , 1/2 BPM. P/U & UD 24' pup'. Pump 20 BBI Hi-Vis sweep & j ~ j circulate unfit clean. cement & pcs of rubber in returns. ~ 04:00 - 05:00 1.00 CEMT P i TIEB1 POOH & stand back DP. 05:00 - 06:00 1.00 CEMT P j TIEB1 i Break out & UD BHA #15. Empty boot baskets. j '; 06:00 - 07:00 1.00 CEMT P I TIEB1 I Crew change. Fill hole, close blind rams. Pressure test 7" csq j to 3600 psi and chart for 30 minutes. Good test. 07:00 - 07:30 0.50 DHB P ~ j TIEB1 PUMU RCJB BHA ~!, 07:30 - 09:30 2.00 DHB P ~ TIE61 ~ Tag sand @ 2590'. Establish parameters of 5 BPM, 80 RPM, 3K WOB, 52K PUW/SOW. Work RCJB to 2614' varying pump rate, rotation speed, WOB etc. j 09:30 - 11:30 2.00 DHB P i TIEB1 POOH keeping hole full w/ 9.8 #/gal brine. Break out boot baskets and RCJB. Recovered pieces of plastic, rubber, I rubber cone, and cement chunks. MU same BHA. 111:30 - 14:00 2.50 DHB P TIEB1 RIH and tag sand with same milling parameters as previously j j @ 2614'. Mil! and wash to 2636'. Pump 20 Bbl viscous sweep, ~ displace @ 5 BPM, 900 psi. 14:00 - 16:00 2.00 DHB P TIEB1 POOH keeping hole full wl 9.8 #/gal brine. Break out boot j baskets and RCJB. Recoverd marble size pieces of cement and brass. -1/2 cup volume. 16:00 - 17:30 1.50 DHB P TIEB1 MU HES retrieving head for 7" RBP (OAL-2.94'). RIH to retrive TBP f 17:30 - 18:00 0.50 CASE TIEB1 Reverse out sand over plug @ 2650'. reverse until clean. 4 BPM @ 480 psi. 18:00 - 19:30 1.50 CASE P TIE61 j Reverse & displace well from 9.8 ppg brine to clean 9.3 ppg brine.. 9.3 in & 9.3 out. 4 BPM @ 480 psi. ,19:30 - 20:00 0.50 DHB P TIEB1 Latch up on RBP & unset. allow rubbers relax. P/U RBP free. ~ ~ RIH below set depth, then P/U. P/U Wt = 50K, S/O Wt = 40K. j 20:00 - 21:30 1.50 DHB P ~ TIE61 UD single. POOH & stand back 3 1/2" DP. 21:30 - 22:00 22 00 2 0 0.50 0 0 DHB DHB P N ~TIEB1 DFAL ~ TIEB1 Stand back DCs. NO RBP!!. Inspect running tool, looked good. I i l &DC / : - 2:3 .5 H w runn ng too R s. i 22:30 - 00:00 1.50 DHB N DFAL TIEB1 RIH w/ 3 1/2" DP. Ran 52 stands. Found RBP directly above ~ RBP @ 5130'. 9/7/2007 j00:00 - 02:00 2.00 DHB N DFAL TIEB1 Lactch up on RBP. P!U w/ 8-9K drag. P/U Wt = 84K, S/O Wt = j ~ 55K. POOH con't to drag for -25 stands. POOH & stand back j ~ 52 stands. 02:00 - 02:30 0.50 DHB N DFAL TiEB1 j Stand back DCs & UD RBP. RBP intact appears to have no I ~ j damage. Rubbers looked new. Saw some scale on top of plug. j ~ Inspect rerieving tool, Ok. 02:30 - 03:00 0.50 DHB I P TIEB1 ~ RIH w/ retieving tool &DCs. Printed: 10/3/2007 2:78:28 PM • • BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date i From - To - ~--- 9/7!2007 103:00 - 05:00 I i i ~! 05:00 - 06:30 I I, i 06:30 - 09:00 I 109:00 - 09:15 MPG-07 MPG-07 Spud Date: 5/17/1991 WORKOVER Start: 8/27/2007 End: NABOBS ALASKA DRILLING I Rig Release: 9/9/2007 NABOBS 4ES Rig Number: Hours Task ~ Code NPT ~ Phase Description of Operations ~ ~ _ - - - 2.00 ~ DHB ~ P ` ~ TIEB1 RIH w/ 52 stands of 3 1!2" Dp. latch up on RBP. P/U w! 1!2 1.501 CASE I P 2.501 CASE I P 0.251 CASE I P 09:15 - 10:00 ~ 0.75 ~ CASE P 10:00 - 12:00 ~ 2.00 CASE P 12:00 - 13:00 , 1.00 CASE P 13:00 - 17:00 i 4.00 CASE P i j17:00-18:00 118:00 - 18:30 i 18:30 - 19:00 19:00 - 20:00 i ~ 20:00 - 22:00 122:00 - 22:30 i i i I 122:30 - 00:00 9/8/2007 100:00 - 00:30 00:30 - 06:00 I i 06:00 - 09:00 I I 09:00 - 11:30 I 111:30 - 15:00 I i 5:00 - 15:30 15:30 - 16:00 ~ 16:00 - 17:00 I I 17:00 - 19:30 I i 9:30 - 20:30 1.00 CASE P 0.50 CASE P 0.50 BUNCO 1.00 BUNCO P 2.00 BUNCO 0.50 BUNCO 1.50 BUNCO 0.50 BUNCO 5.50 BUNCO 3.00 BUNCO P 2.50 BUNCO 3.50 BUNCO P 0.50 BUNCO 0.50 BUNCO P 1.00 BUNCO P 2.501 RUNCOMP turn to right & work torque down. BP released. agllow to equalize. Fluid level slowly dropped. Move up & down past setting point to insure tree. TIE61 Circulate bottoms up. monitor losses. Pumped 4 BPM @ 580 psi. Losing 12 BPH. TIEB1 Flowcheck well. POOH w/ continuous hole fill. Losses @ ~4 BPH. TIE61 BOLD HES RBP. Elements in good shape, nothing abnormal noticed. TIE61 PUMU Baker Scraper BHA. TIEB1 R{H wf 7" Csg scraper. RIH to 5490'. POOH to 5151' TIE61 Circulate bottoms up @ 5 BPM, 1100 psi. TIE61 POOH laying down 3 1/2" DP. Keeping hole full wJ continuous hole fill. Losses @ -6 BPH. Notified AOGCC @ 14:00 regarding upcoming MIT-IA. State witnessing of test waived by Chuck Scheve. TIE61 Break out & UD BHA #18. TIEB1 Crew Change. Inspect derrick Check PVT alarms. RUNCMP P/U running tool & Pull Wear Bushing. VD same. RUNCMP Clear & clean rig floor. RUNCMP R/U handling tools for 3 112" completion. R/U torque turn equip. RUNCMP Hold PJSM w/ all hands. Review completion running order & assign specific tasks to crew members. RUNCMP M/U tail pipe & packer assys &RIH w/ same. RUNCMP Con't running Packer assys, nipple assys & GLMs. Torque turn all connections to 2300 ft-Ibs. & used Jet Lube seal guard on all connections. RUNCMP RIH wi 3 1/2" completion. Torque turn all connections to 2300 tt-Ibs & used jet Lube Seal Guard on all connections. Ran in hole w! 110 jts of 3 1/2" RUNCMP Crew change. Continue RIH w/ 159 jts of 3 112" TCII tubing. PUMU 3 1/2" landing joint w/ xo and TIW valve on top. Strap in hole and space out to position completion. Keep hole full by pumping across the top. RUNCMP SLB arrive on location. PJSM. RU SLB for GR/CCL log. Logging correlated to Compensated Neutron-Litho-Density log dated 21-May-i 991. Pressure test lubricator to 2500 psi. RUNCMP RIH w/ SLB logging tools. Log from RHC plug up through jewelry. RD SLB. RUNCMP Correlate jewelry log. PU 6' pup joint and tubing hanger. RIH and land hanger RUNCMP RILDS. Clean and clear rig floor. RUNCMP Reverse circulate 135 deg F Brine. 75 Bbls of 9.3 #Jgal followed by 140 Bbls of 9.3 #/gal w/ corrosion inhibitor. Pump @ 3 BPM, 210 psi. RUNCMP Drop ball and rod. Pressure tubing to 4200 psi and hold for 10 minutes to set packers. Bleed tubing pressure to 3600 psi and I, chart for 30 minutes. Bleed tubing to 1500 psi. Pressure IA 3600 si and chart for 30 minutes. (State witnessing of test i waived by Chuck Scheve wl AOGCC). Bleed off tubing r pressure & Shear out valve. sheared @ 800 psi. 1.00 RUNCOI~IP !RUNCMP ~ R/U & pump thru shear valve both ways. 3 BPM @ 470 psi. Printed: 10/3/2007 2:18:28 PM $P EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: MPG-07 Common Well Name: MPG-07 Spud Date: 5/17/1991 Event Name: WORKOVER Start: 8/27/2007 End: Contractor Name: NABOBS ALASKA BILLING { Rig Release: 9/9/2007 Rig Name: NABOBS 4ES Rig Number: Date 'From - To Hours ', Task 'Code NPT ~ Phase Description of Operations 9/8/2007 19:30 - 20:30 i ~ -- 1.00 _ RUNCOf~P _ - RUNCMP - - ------ - - Install TWC w1 T-bar. Test from above w/ 3500 psi for 10 min. I{ Test from below 1000 psi for 10 min. Charted test. 20:30 - 21:00 0.50 BUNCO P ~ RUNCMP R/D test equip. Blow down lines. Suck out BOP stack. 21:00 - 23:00 2.00 BOPSU P RUNCMP N/D BOPE. 23:00 - 00:00 1.00 WHSUR P RUNCMP N/U adapter flange. 9/912007 00:00 - 00:30 ~ 0.50 WHSUR P RUNCMP Pressure test hanger void to 5000 psi for 30 min, Held OK. 00:30 - 02:00 ~ 1.50 WHSUR P RUNCMP N/U tree. Orient tree as per Pad operator. Fiil tree w/ diesel & pressure test to 5000 psi. Held OK. 02:00 - 03:00 ~ 1.00 WHSUR P I RUNCMP M/U lubricator. Test to 500 psi. Pull & UD TWC & lubricator. 03:00 - 04:30 i 1.50 WHSUR P RUNCMP R/U lines to tree & pressure test to 2500 psi. Freeze protect w/ 80 bbls diesel pumping down annulus. 2 BPM @ 750 psi. 04:30 - 05:30 1.00 WHSUR P ~ RUNCMP R/U lines & allow well to U-tube diesel freeze protect fluid. 05:30 - 06:00 0.50 WHSUR P i RUNCMP P(U lubricator & set BPV. Pressure test BPV to 1000 psi. 06:00 - 08:00 I 2.OOj WHSUR P ~ RUNCMP Chart for 10 minutes. RID Hotoilers. Normal up tree and cellar. Release rig @ 08:00 Printed: 10/3/2007 2:18:28 PM 09/27/07 Alaska Data $ Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wnll In6 $ 1 nn nascrintinn N0.4437 Company: State of Alaska Alaska Oil 8~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay rlAt'R trZl.. Cnlnr C~ • 15-29A 11686783 SCMT a d 09/05/07 1 05-256 11630496 SCMT _ < 08/30/07 1 02-33A 11813082 SCMT 08/31/07 1 15-28A 11686782 SCMT 09/04/07 1 N-27 11824345 SCMT - L 09/12/07 1 05-22A 11813086 SCMT 09/18107 1 S-400A 11855508 USIT - 09/18/07 1 E-27A 11676963 USIT (CEMENT) ~ - 09/18/07 1 E-27A 11676963 USIT (CORROSION) 09118107 1 MPG-07 11594520 USIT S '~ 08/29107 1 MPS-37 NIA SCMT 09/08/07 1 PLEASE ACKNOWLEDGE RECEIPT 8Y SIGNING AND RETURNING ONE I::OPY EAGR 70: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 _ - 900 E. Benson Blvd. `- "~ ~ - ~ Anchorage, Alaska 99508 r ~ h il Date Delivered: ,.4bw - 4a~ ._ t • Alaska Data & Consulting Serv~ es 2525 Gambell Street, Suite 4 0 Anchorage, AK 99503-283 ATTN: Beth v _,_. ~-- Received b ~ ,~ ~.~iltt~l~~4~tt ib , , ~~ , CANCELLATION ADMINISTRATIVE APPROVAL NO. AIO I.OB-004 Ms. Andrea Hughes Well Integrity Coordinator BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~E;~~~b~~~ JAN ~ 20~ RE: Cancellation of Administrative Approval AIO l OB.004 Milne Point Unit G-07 (PTD 191-025) Schrader Bluff Oil Pool Dear Ms. Hughes: Pursuant to BP Exploration (Alaska), Inc. (`BPXA")'s request dated July 2, 2007 AOGCC hereby cancels Administrative Approval AIO lOB.004, which allows continued water injection in MPU G-07. This well exhibited surface casing communication, and BPXA did not at the time propose repairing the well to eliminate the problem. The Alaska Oil and Gas Conservation Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. Since then, BPXA has determined that the condition of MPU G-07 is inconsistent with their internal Well Integrity System policy. The well is shut in awaiting a rig work over. Consequently, Administrative Approval AIO lOB.004 no longer applies to operation of this well. Instead, injection in well MPU G-07 will be governed by provisions of the underlying Area Injection Order No. IOB. DONE at is orage, Alaska and dated July 9, 2007. The Alaska Oil and Gas Conservation Commission Orman niel T. Se ount, Jr. Cathy p/p / Commissioner Comr~4ssi~ Y~_; 'ii ~,~ 3 by . . SARAH PALIN, GOVERNOR AI',ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit, Schrader Bluff Oil Pool, MPG-07i Sundry Number: 307-099 \a.\-O~ Dear Mr. Reem: ~~~ MAR ~ 8 2007 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this '2J. day of March, 2007 Encl. ~ ' ~ RE f)T-f' . Z 3/~ATE OF ALASKA á.-..2Pðt. CEIVED ALASKA all AND GAS CONSERVATION COMM~ION '?n MAR 2 0 2007 APPLICATION FOR SUNDRY APPROVAL AlasKa Oil & Gas Cons. Commission 20 AAC 25.280 Anchnr2nø 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Time Extension o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. o Development o Exploratory 191-0251 3. Address: o Stratigraphic l8I Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22140-00-00 ( 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPG-07i I Spacing Exception Required? DYes l8I No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 047434 66.0' Milne Point Unit / Schrader Bluff { 12.' .. PRESENT WELL CONDITION SUMMARY .. ...... .... Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5818 4514 5705 4431 None None Casino Lenoth Size MD TVD Burst CollaDse Structural Conductor 80' 13-3/8" 115' 115' 2730 1130 Surface 2662' 9-5/8" 2697' 2372' 3520 2020 Intermediate Production 5762' 7" 5797' 4498' 7240 5410 Liner Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 5176' - 5534' 4046' - 4305' 2-7/8",6.5# L-80 5106' Packers and SSSV Type: 7" Otis PLS Retrievable I Packers and SSSV MD (ft): 5061' 13. Attachments: 14. Well Class after proposed work: l8I Description Summary of Proposal D BOP Sketch o Exploratory o Development l8I Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencinq Operations: May 1, 2007 DOil DGas D Plugged D Abandoned 17. Verbal Approval: Date: DWAG DGINJ l8I WINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bryan McLellan, 564-5516 Printed Na~id Reem Title Drilling Engineer Prepared By Name/Number: Signature ~ Phone Sh LJ·S71/3 Date ~ /1 r¡ jOçsondra Stewman, 564-4750 Commission Use Only I Sundry Number:_?{)7' n0CJ Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity ~BOP Test ~echanicallntegrity Test D Location Clearance Other: '3>500~'\ ~()V' ~* J R8DMS BFl. MAR 2 8 2DDi Subsequent Form Required: ~G~ I ~ ~COMMISSIONER 3·z3-~ APPROVED BY Approved By: T j THE COMMISSION Date Form 10-403 Revised 06/2006 G1N J \l "- Submit In Duplicate OR\ . . G MPG-07i Rig Workover Reason for RWO: There is a leak in the 9-5/8" surface casing. Scope of Work: Pull 2-7/8" L-80 completion, cut and pull 7" casing above the surface casing shoe, replace wellhead and first joint of 9-5/8" surface casing, run new 7" premium threaded casing and fully cement the 7" x 9-5/8" annulus to surface, run 3-%" L-80 Premium threaded completion. MASP: 1456 psi Well Type: Schrader Bluff Water Injector Estimated Start Date: May 1 , 2007 Pre-riQ prep work: Pre-Rig: S 1 Drift to PBTD' for 2-7/8" XX plug. Note obstruction at 3566' md seen on 4/5/06 would not allow 2.25" centralizer to pass. Set TIP in X-Nipple at 5096' md. 0 2 Install cellar liner to contain fluid returns from hole in surface casing. E 3 Punch holes in tubing at -5020' md (near the top of the first full joint of tubing above the packer). F 4 Circulate well with seawater and FP w/ diesel thru the cut. CMIT TxlA to 3600 psi to confirm mechanical barrier and casing integrity. Bleed WHP's to 0 psi. 0 5 PPPOT-T, -IC, check all LDS. 0 6 Set a BPV in the tubing hanger. Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed Procedure: 1. MIRU. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the tubing punch holes. 2. Pull and LD 2-7/8" tubing string with the retrievable packer. 3. Run a cement evaluation log to determine top of cement in 7" x 9-5/8" annulus. 4. Set a RBP in the 7" casing -1000' below desired 7" casing cut depth. (:£) 5. Cut and pull 7" casing above top of cement in the surface casing. 6. Set a RBP in the 9-5/8" casing above the 7" casing stub. Câ) 7. Remove the BOP's and cut off the wellhead. 8. Wash over the first joint of 9-5/8" casing. 9. Back off first joint of 9-5/8" 36# K-55 casing and run new 9-5/8" 40# L-80 casing. 10. Fill 9-5/8" x conductor annulus with cement to surface. 11. Install new wellhe¢{>n 9-5/8" casing. NU and test BOP's. 12. Pull 9-5/8" RBP. /W 13. Run new 7" premium threaded casing tieback from top of casing stub to surface. · · r'V-.>\\ ,\\\ ~'V:,'?~3t>fJ 14. Cement 7" tieback to surface.....-J ' 15. Run new 3-1/2" L-80 Premium-threaded tubing completion with packers at -5115', 5340' and 5460' md. 16. Displace the IA to packer fluid and freeze protection and set the packers. 17. Test tubing and IA to 3600 psi. 18. Set BPV. ND BOPE. NU and test tree. RDMO. . . WELL No. G-7 CASING SKETCH MILNE PO INT UNIT (I) API No.: 50-029-22140 PERMIT No.; 91-25 DRILLED: 5/23/91 ARCTIC PACKED: 10/11/91 OPERA TOR: CONOCO INC. SURFACE LOCATION: 3235' FNL. 3451' FEL. SEC. 27, T13N, Rl0E, U.M. BOTTOM HOLE LOCATION: 458' FNL, 1767' FEL, SEC 27, T13N, R10E, U.M. SPUD DATE: 5/17/91 ~ FMC CSG SPOOL RKB=36' .f· , ...:. ~ ". ...,:.., '. ~ .' ..... ......,; - ' /" 13 3/8", 54.5#. K-55, WELD SET 0 115' ~ CEMENT DATA; 582 SKS TYPE "C" .-. . .....,. PBm 5707' :...':.... ...."' ð < c.. U F U n:: < ... -" .. ..... ..... ARCTIC PACK DATA: 51 BBLS, 15.6 PPG, PERMAFROST ·C·, 60 BBLS DEAD CRUDE I ____ 9 5/8", 36#, K-55, BTRC, SET @ 2697' ,~ CEMENT DATA: 360 BBLS (1000 SKS) PERMAFROST T w/ 5# GILSONITE AND 44 BBLS (215 SKS) "G" w/ 0.27- CFR-3 & 27- COCl2 RA TAG 04690' 7", 26/1, L-BO, BTRC, SET @ 5797' CEMENT DATA: 67 BBLS (330 SKS) "G" W/ 0.2% CFR-3, 0.4% HALAD 344, 0.03% HR-5 TO 5815' \.--.- CONOCO INC. ANCHORAGE DIVISION APPROVED BY: HDS DRAFTED BY: SJN DATE: 5/14/92 CAD FILE: WCAG7 . . WELL No. G-7 COMPLETION SKETCH MILNE POINT UNIT (1) API No.: 50-029-22140 PERMIT No.: 91-25 COMPLETED: 12/27/91 LAST WORKOVER: N/A ~ 1. All MEASUREMENTS ARE FROM KDB OF NABORS RIG 27E KDS - GL = 35' 2. MAX. ANGlE = 51' 0 2600' 3. K.O.P. = 500' 4. SLANT HOLE; YES 5. TREE TYPE: FMC 2 9/16-, 50001, W / 2 7/S- Brd TREETOP CONNECTION 6. MIN 10 = 2.313-: OTIS 'X' NIPPLE AT 5059' AND 5096' 7. COMPLEllON FlUID: 8.6 PPG NoCI W/12% MeOH 8. STlMULA 1l0N: NONE N SAND PERFORATION DATA: MQ DEPTH: 5176'-5188' 5220'-5238' 5257' -5262' 5286'-5326' DENSITY: 5 SPF, 37 GM r& 4045'-4053' 4076'-4089' 4103'-4107' 4124'-4153' o SAND PERFORATION DATA: MQ DEPTH: 5398'-5446' 5494'-5534' DENSITY: 5 SPF, 37 GM r& 4204'-4240' 4275'-4305' CONOCO INC. ANCHORAGE DIVISION FMC TBG HGR W /3- SPV PROFilE 159 JTS 2 7/S-, 6.5#, L-SO, Brd EUE 5059' OTIS OVER SHOT TBG SEAL DIVIDER W/X PROFilE (2.313" 10) 5061' OTIS r PLS RETRIEVABLE PACKER (2.3S- ID) 5096' 2 7/S- OTIS -X" NIPPLE (2.313- 10) 5106' TBG TAIL (OTIS WLEG) 5707' PBID 5797' 7-, 2611. l-BO, BTRC APPROVED BY: HDS DRAFTED BY: SJN DATE: 7/29/92 CAD FILE: WCOG7 Tree: 3-1/8" - 5M Wellhead: 11" 5M FMC w/ 3-1/8" FMC Tubing Hanger, xxxx lift threads, MPU G-07i Propos. Orig. RT Elev. = ##.#' (N##E) Orig. GL Elev. = ##.#' RT to Csg Spool = ##.#' (N##E) 13-3/8" 54.5 ppf, K-55 ~ KOP @ ###' Max Hole Angle = XX deg, f/ XXXX' to XXXX' Hole angle through perfs. = xx deg. DLS = xx deg/1 00' @ xxxxx' 9-5/8" 36#/ft., K-55 BTRC. 12697' I Top joint is 9-5/8" 40#, L-80 BTRC 3.5", 9.2#/ft., L-80, TC-II tubing., (drift ID = 2.867", cap. = 0.0087 bpf) 7" 26#/ft., L-80, BTRC, csg., (drift ID = 6.151 ", cap. = 0.0383 bpf) Top -2500' is 7" 26# L-80 TC-2 csg Stimulation SummarY Perforation Summaiy Ref. Loa ##/##/## xxx/xxx Size SPF Interval 5 5176'-5188' 5 5220'-5238' 5 5257'-5262' 5 5286'-5326' 5 5398'-5446' 5 5494'-5534' TVD 4045'-4053' 4076'-4089' 4103'-4107' 4124'-4153' 4204'-4240' 4275'-4305' "XXXXX Jet Charges @ 60 deg. phasing" DATE REV. BY 3/8/07 BJM COMMENTS Proposed RWO 3.5" X-Nipple, 2.813" 10.12450' 3.5" x 1.5" GLM 12500' RA tag @ 4690' 3.5" "X" Nipple 15105' (2.813" Packing Bore ' 7" Baker Premier Pkr. 15115' 3.5" x 1.5" GLM's 5145'& 5175' 15340' 5370'& 5400' 15460' 15480' I 1 I 7" Baker Premier Pkr. 3.5" x 1.5" GLM's Baker 7" Premier Pkr 3.5" "XN" Nipple, 2.813" WLEG 7"landing collar (PBTD) 7" float collar I 7" float shoe 5797' MILNE POINT UN II WELL G-07i API NO. 50-029-22140 BP EXPLORATION. {AK). Alaska Department of Natural,ources Land Administration System . Page 1 of 4 State Cabins Natural Resources þvdP tf Alaska DNR Case Summary File Type: I~I?~.I File Number: L 47434 ~.. Printªþlª ÇaseFile$lIl11lT1ary -~~ .~~ .~~,~ V~N~~m~__~~~m See Township, Range, Section and Acreage? (i. Yes No http://www.dnr.state.ak.us/las/Case _Summary .cfm?FileType=ADL&FileNumber=4 7434&... 3/21/2007 -Alaska Depar1ment of Natura4J'0nrces Land Administration System . 08-25-1980 ***ASSIGNMENT LEGAL DES TION*** Page 2 of 4 SCHRADER BL UFF P A http://www.dnr.state.ak.us/las/Case _Summary .cfm?FileType=ADL&FileNumber=4 7434&... 3/21/2007 · Alaska Department ofNatnral.ourees Land Administration System . 'F.1.3N,R.1.0E., f!J.M. Page 3 of 4 CTION 3: S1/2; SECTION 9: ALL; SECTION 1. 0: ALL. ***************** 02-01. L DESClUPTION POINT UNIT VER P ARTIC http://www.dm.state.ak.us/1as/Case _Summary .cfm?Fi1eType=ADL&Fi1eNumber=4 7434&... 3/21/2007 Alaska Department of Naturallourees Land Administration System . ,\c h State Cabins Alaska DNR Su Page 1 of3 Natural Resources mary ~µt· File Type: I~[)~ ~PrintélÞIE!CélSe File$ummélry File Number: l~c_~~~~()c~J See Township, Range, Section and Acreage? C!'. Yes No http://www.dnr.state.ak.us/las/Case _Summary .cfm?FileType=ADL&FileNumber=25906&... 3/21/2007 ..Alaska Depar1ment ofNatural.ources Land Administration System . 11-02-1988***UNITIZED *** T.13N, R.I0E., UM SECTION 27: ALL 640 SEC 'N 28: ALL 640 ON 640 Page 2 of3 2560 ACRES, MORE OR LESS. http://www.dnr.state.akus/las/Case_ Summary .cfm?FileType=ADL&FileNumber=25906&... 3/21/2007 ..Alaska Department üfNalural,ources Land Administration System . Page 3 of3 End Case Summary Last updated on 03/21/2007. Not sure who to contact? Have a question about DNR? Visit the pwþlicJoforrnéJJíQn Report technical problems with this page to the Site optimized for Netscape 7, IE 6 or above. This site also requires that all must be accepted. state of Alaska Naturàl Resources LAS Home Gopyríght priv?cy ;:;ysternStatus http://www.dnr.state.ak.us/las/Case _Summary .cfm ?File Type= ADL&FileNumber=25906&... 3/21/2007 `J BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 March 9, 2007 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Subject: MPG-07 (PTD 1910250) Application for Cancellation of Administrative Approval Number 106.004 Dear Mr. Maunder: BPXA requests cancellation of Administrative Approval number 106.004 dated 10/27/05. The administrative approval was for continued water injection with surface casing communication. We do not plan to operate this well without surface casing integrity. If you require any additional information, please contact Anna Dube or Andrea Hughes at 659-5102. Sincere) , Wv , x.,. St~ ossberg ~`>~ ~ _ ,` ., n~,` Well Program Manager MPG-07 (PTD #1910250) Cancel Waiver . . Hello all. The waiver for well MPG-07 (PTD #1910250) has been canceled and the well classified as a Trouble well. The surface casing does not have integrity and we do not plan to operate the well. Tom/Jim/Winton: we will submit a letter canceling AA 10B.004. Lead Operator: would you please ensure all waiver-related information is removed from thewellhouse. Please call with any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Email: NSUADWWelllntegrityEngineer@bp.com SÇ^N~M~J) ( F I of I 10/23/20064:51 PM Emailing: MIT MPU G-07 10-19-05.xls Subj~Ct: Emailing: MIT MPU G-07 1O-19-0S.xls From: "NSU, ADW WI Tech" <NSUADWWITech@BP.com> Date: Sat,J?Dec 2005 15:07:pS -09QQ , 100: jim _regg@;' ~in;$tate.ak:~s, wiÌtì'tôn _ aubert@a<:ln} <:fleckensteirì ' . ',)n.state.ak:\.ts';tôm_maunder@ , .c E~gineer" <Nstr "''fNW ellInte ngiIleer@BP.com> a ',';us,Bob ,'" '",' " tat~.ak.us; t'NSU,4DW Wel, ntegrit:y+~~:.', . :~Wt0:: .<w~~:~:::::·.. «MIT MPU G-07 10-19-05.xls» Jim, Winton, Bob, and Tom, \<\ \-O~ Please see the attached MIT form for Milne Point well G-07 (PTD #1910250) . Thanks, Ely Luckett (alternate Ryan Holt) (907) 659-5524 ~ª~T!\~)_1i~!'I.~!,~,r;þ,:ª!þp_~g{?~ Your files are attached and ready to send with this message. Content-Description: l\'Ill MPL G-07 IO-19-05.xls MPU G-07 10-19-05.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 c'r ,e.. ~~!I\\!t;;v ~b1ro~w .:t:-= (\ (:; 1 of 1 ç>("''''~ 0 ~" ~c.c~ 1/9/20067:42 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Milne Point / MPU / G Pad 10/19/05 Lee Hulme Packer Depth Pretest Initial 15Min. 30 Min. WeIlIMPG-07 I Type Inj. I N TVD I 3,964' Tubing 800 800 800 800 Interval I V P.T.D.11910250 I Typetest I P Test psi! 1500 Casing 0 2,800 2,775 2,770 P/FI P Notes: MITIA to for SC leak Waiver Compliance. OA 0 0 0 0 AOGCC representative did not witness test. Weill I Type Inj. I I TVD I Tubing Interval I P.T.D.I I Type test I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval I P.T.D.I I Type test I I Test psil Casing P/FI Notes: OA I Weill I Type Inj.1 I TVD I Tubing Interval I P.T.D.I I Type test I I Test psi I Casing I P/F Notes: OAI I Weill I Type Inj.1 I TVD I Tubingl I ntervall P.T.D.I I Type test I I Test psi I I Casingl P/F Notes: I OAI TYPE INJ Codes D = Drilling Waist G = Gas I = Industrial Waistewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL. Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= other (describe in notes) MIT MPU G-07 10-19-05,xls - '~' ' ,~ - _ • ~7ANK H. MURKOWSKI, GOVERNOR ~+~1 ~RA ®~ ~ ~ 333 W. T" AVENUE, SUITE 100 C®1~TSERQATI®~ COI~'II$SI®~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO lOB.004 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 995 1 9-66 1 2 RE: Request for Administrative Approval Milne Point Unit G-07 (PTD 191-02~) Schrader Bluff Oil Pool Dear Mr. Rossberg: By letter application received October 26, 2005 BP Exploration (Alaska) Inc. ("BPXA") requested administrative approval to resume water injection into the subject well. Based on an evaluation of the submitted information and review of the well file, the Alaska Oil and Gas Conservation Commission grants BPXA's request for administrative approval to resume water injection in the subject well. AOGCC finds that BPXA has performed diagnostic well work on Milne Point Unit G-07 and based upon reported results of that work, the well exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to resume water injection in Milne Point Unit G-07 is conditioned upon the following: 1. Injection is limited to WATER ONLY; • 2. BPXA shall record wellhead pressures and injection rates daily; # ~ ~ .s ADMINISTRATIVE APt _.~VAL AIO fOB.004 October 27, 200 Page 2 of 2 3. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates; 4. BPXA shall perform aMIT - IA annually to 1.2 times the maximum anticipated injection pressure; ~. BPXA shall limit the well's IA operating pressure to 1000 psi; 6. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; and 7. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection. As provided in AS 31.0.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. D Aber 27, 2005. i Cathy P. Foers'fer Commissioner ~~ f "' ,~ ~ ~ ; ~~~ ~~ i - ~ ~ { ~ ~,; > ~ ~ "~ ~;~ tj:,~ 6 RE: MPG-07 (PTD 1910250) Surface Casing Leak ) ) Hi Tom and Jim. MPG-07 passed an MITIA to 2800 psi on 10/19/05. The passing MITIA demonstrates 2 well barrier systems: competent tubing and competent productíon casing. An Administration Action request was mailed today requesting continued injection operations with the surface casing leak. The well will remain shut-in until we receive authorization to return the well to injection. Please call jf you have any questions. Joe 1-907 -659-5102 ~ANNED) NOV () 2 2005 From: NSU, ADW Well Integrity Engineer Sent: Monday, October 17, 20058:29 PM To: AOGCC - Tom Maunder (tom_maunder@admin.state.ak.us); Jim_Regg (jim_regg@admin.state.ak.us) Cc: Rossberg, R Steven; Krom, Kristin L; MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Wells Ops Coord2; MPU, Operations Manager; Engel, Harry R; Dube, Anna T; Hughes, Andrea (VECO); Holt, Ryan P (VECO); Ohms, Danielle H Subject: MPG-07 (PTD 1910250) Surface Casing Leak Hi Tom & Jim. Injection well MPG-07 (PTD 1910250) is exhibiting signs of a surface casing leak. On 10/17/05, pressure was applied using N2 to the surface casing and fluid/bubbling was observed in the 13-3/8" by conductor annulus. An MITIA is scheduled 10/18, then freeze protect the tubing and evaluate repair versus AA request. The well will remain shut-in. Attached are wellbore schematics. Please call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. 1 of2 10/21/2005 2:44 PM ) ) .; >,,' (,... ;: :~'" ~>~'.~ - :~;. MECHANICAL INTEGRITY REPORT .\,\ \ _'o~ç ;' ,,' '. ....:..-.." "-:--r'^'\. ~' '~' '..: ,...1- £P.UQ Q¡grÇ'." ~!ill91...__ g{G...R~lé:-rJ::5 E: {21.~.119 f OPER & FIELD (;O/)rJCð / M (7U "TELL NUMBER WELL DATA TD: Slj 18 MD 579r I2s Shoe: - 5 ,. 2'1 MD Cas ing: 7" 26 L Liner: Shoe: MD Tubing: 2'/8 6__sPacker /:¡-06 I MD Hole Size 7" ,." ø ~~. and MECHANICAL INTEGRITY - PART HI Annulus Press Test: IP G -7 5707 Fe TVD; PBTD: S705 MD TVD TVD; DV: MD -TVD TVD; TOP: MD TVD TVD; Set at .¡;-/O~ Perfs S-I 7~ to .s-s 3{.¡ 15 min 30 min Comments: :>. ~.~cr·~"5';~'~\ \--\.. \. \"') i f'..:.~ \<e: ....- ~L\ \J\..v-~ Ob... \~c...~C9-~ c~· \O{O<":;; .~~t¿ f.\\(J\Oß.\JOL\ MECHANICAL INTEGRITY - PART #2 Cement Volumes: Amt. Liner ; Csg 700 s: JC ; DV Cmt vol to..cover perfs .._@ ,C~0 (-C~. C (,:,163 (.s7e;...,...~TO-;;;iJ-;(8?Ib-t ~RIB-579'7Y:$'i'~a+ (S791-Si7f; ~ tOR~ = 91 s~ Theoretical Toe . (;. .~~C~w, A ~I c::..\:) oS , ~ ~ 0 -. ,>olo't. ';Þ t .0"-,.,,· 0 $"/76 - r(~o 0 - q( ) -:-.. f()tI~_7 ':" 321.16 (þ ~ Cement Bond Log (Yes or No) !f e~ ; In AOGCC File 'I ~:S CBL Evaluation, zone above perfs ~r>n~ Dor;d¡lrl1Þ dhðlJ~ PQ'¡:~ J . Production Log: Type CONCLUSIONS: Par t D 1 : Par t # 2 : M I ,w!J //l(·JictJ te J., rev. OS/20/87 - iC I?L. __? c::~ ~-e5 (¡OCid Evaluation ..Af3~ 3( S/9 Z. -ç::. c:Dr-~~OI-;,(-OS C.02B ) ) BP Exploration (Alaska) Inc. Steve Rossberg, Wells Manager Post Office Box 196612 Anchorage, Alaska 99519-6612 R E: (~·E: u 'E·' =§'''J'''~ J .J!m'.= ß \lMðI,'l iltl, , OCT 2 6 Z005 October 19, 2005 ,AlasJ(¡ Oil & Crnnmissicn Anch(JJra1]e Mr. John Norman, Chairman Alaska Oil & Gas Conservation Commission 333 W. ih Ave. Anchorage, Alaska 99501 Subject: Milne Point well MPG-07 (PTD # 1910250) Request for Administrative Approval to Continue Water Injection Operations Dear Mr. Norman: BP Exploration (Alaska) Inc. requests administrative approval to continue water injection operations into Milne Point well MPG-07 while the well has a surface casing leak. Milne Point well MPG-07 has surface casing by conductor communication indicated by a bubbling well cellar during a failed MIT -OA with Nitrogen. Two competent barriers have been established and thus it is BP's contention that the well can be safely operated. The barriers have passed pressure tests to 1.2 times the maximum anticipated injection pressure and observed annulus operating pressures do not exceed 45% of the casing's rated burst pressure. The proposed operating and monitoring plan (attached) includes the following: 1. Daily recording of surface rate and injection pressure 2. Mechanical integrity testing on an increased frequency 3. Increased reporting to the AOGCC through the Monthly Injection Report If one of the competent barriers should become compromised, the well will be shut in, the Commission notified and physical corrective options will be evaluated. The proposed operating and monitoring plan is based on sound engineering and operating practices, and is consistent with Area Injection Order 10B, Rule 8. In addition, there is no source of underground drinking water; therefore, no USDW is endangered. It is BP's contention that approval of this request will provide safe operating conditions, is in the best interests of the GPB working owners and the State of Alaska. If you require any additional information, please contact me at 564-5637 or Joe Anders / Anna Dube at 659-5102. Attachments Technical Justification for Administrative Relief Request Well bore Schematic TIO Plot ) ) Milne Point well MPG-07 Technical Justification for Administrative Relief Request October 19, 2005 Well History and Status Milne Point well MPG-07 (PTO # 1910250) has surface casing by conductor communication. An MIT-IA passed to 2800 psi on 10/19/05. This test indicates competent tubing, and production casing. Surface casing by conductor communication identified 10/17/05 by a failed MIT-OA with Nitrogen resulting in bubbling at surface. Recent Well Events: - 10/17/05: MIT-OA to 500 psi Failed @ <10 psi bubbling in cellar. - 10/18/05: WIC Notified AOGCC via Email. - 10/19/05: MIT-IA to 2800 psi Passed. Barrier and Hazard Evaluation The well has 2 competent well barrier systems to prevent the atmospheric release of fluids and safely operate the well. The primary well barrier is the tubing. In the event of a leak, the secondary barrier system composed of the production casing will contain any pressure. Both of these systems have been pressure tested to 1.2 times the maximum anticipated injection pressure to ensure competency. Barrier competency is monitored using wellhead pressure plots (TIO plot), a Pressure/Rate plot and periodic pressure tests to 1.2 times the maximum anticipated injection pressure. Primary Well Barrier System: Tubing competency is demonstrated by the passing MIT -IA to 2800 psi on 10/19/05. Competency will be frequently monitored by daily annulus pressure observations, by frequent review of a TIO plot to monitor pressure trends and by conducting an annual MIT-IA. Secondary Well Barrier System: Production casing competency is demonstrated by the passing MIT-IA to 2800 psi on 10/19/05. Competency will be monitored by daily annulus pressure observations, by frequent review of a TIO plot to monitor pressure trends and by conducting an annual MIT-IA. Thermal pressure of the IA: Maximum allowable inner annulus pressure will be reduced to 1000 psi. In the event of a tubing leak, an IA pressure increase would be observed by the Operators conducting daily well inspections and the well would be shut- in. Any pressure in the IA would relieve into the formation through the production tubing, mitigating the potential of IA overpressure. Injection fluid temperatures are warmer than the wellbore temperatures to the depth of the production casing shoe. This results in the well cooling off when shut-in, preventing thermal overpressure. Mechanical Condition: The surface casing is not considered a component in the well barrier system. The tubing and the production casing are the 2 competent well barrier systems and have been confirmed. The well will be shut-in at any indication of barrier competency loss. ) ) Proposed Operating and Monitoring Plan 1. Continue water injection. 2. Record wellhead pressures and injection rate daily. 3. Submit a report monthly of well pressures and injection rates to the AOGCC. 4. Perform an MIT-IA every year to 1.2 x the maximum anticipated well pressure. 5. If there is any change in the well conditions that suggest one of the two barriers could be compromised, BPXA will shut in the well immediately and notify the AOGCC. NOTES~ 1. ALL MEASUREMENTS ARE FROM KDB OF NABORS RIG 27E KOB - GL = 35' 2. MAX. ANGLE = 51· 0 2600' 3. K.O.P. = 500' 4. SLANT HOLE: YES 5. TREE TYPE: FMC 2 9/16", 5000#, W / 2 7/8- Brd TREETOP CONNECTION 6, MIN ID = 2.313": OTIS ·x' NIPPLE AT 5059' AND 5096' 7. COMPLET10N FLUID: 8.6 PPG NoCI W /12X MeOH 8. STlMULA 110N: NONE N SAND PERFORATION VATA~ .MQ 00 DEPTH: 5176'-5188' 4045'-4053' 5220'-5238' 4076' -4089' 5257'-5262' 4103'-4107' 5286·-5326' 4124'-4153' DEN SITY: 5 SPF I 37 GM o SAND PERFORA nON DATA: MIl DEPTH: 5398'-5446' 5494'-5534' DENSITY: 5 SPF, 37 GM .IW 4204' -4240' 4275'-4305' CONOCO INC. ANCHORAGE DIVISION ) ) WELL No. G-7 COMPLETION SKETCH MI!..NE PO INT UNIT (I) API No.: 50-029-22140 PERMIT No.: 91-25 COMPLETED: 12/27/91 LAST WORK OVER: N / A t--- FMC TBG HGR W /3" BPV PROFILE 159 JTS 2 7/S", 6.511, L-80, 8rd EUE ~ - 5059' OTIS OVER SHOT TBG SEAL DIVIDER W/X ! I PROFILE (2.313" 10) ~ 5061' 0115 7" PLS RETRIEVABLE PACKER (2.36" ....,..-.,-- 10) a - 5096' 2 7/8" OTIS "x" NIPPLE (2.313" 10) ~ 5106' TBG TAIL (011S WLEG) - - - - - - -- - - - - - ...---- 5707' PSTD 5797' 7", 26#. L -80, STRC APPROVED BY: HDS DRAFTED BY: SJN DA TE: 7 /29/92 CAD FILE: WCOG7 ) ) WELL No. G-7 CASING SKETCH MILNE POINT UNIT (1) API No.: 50-029-22140 PERMIT No.: 91-25 DRillED: 5/23/91 ARCTIC PACKED: 10/11/91 OPERATOR: CONOCO INC. SURFACE lOCATION: 3235' FNl, 3451' FEl, SEC. 27, T13N, R10E, U.M. BOTTOM HOLE lOCATION: 458' FNL, 1767' FEl, SEC 27, T13N, R10E, U.M. SPUD DATE: 5/17/91 RKB=36' ': ::.~ '.::,..: . ,'. ~ ", ~ FMC CSG SPOOL .... ,., 10'". ...," ~:.:~'~..~/ ~ .. ,,", ~ ....f.·. . " .... ..... ~.. .. I," '0, :. ..'.''; '.:':::'.' / 13 3/8", 54.SM, K-55, WELD SET @ 115' D .:~,"','., CEMENT DATA:" 582 SKS TYPE ·C· êf. .'., '.' .. <.> :,......' ~ .::: ,;:'~ ..... ~ ARCTIC PACK DATA: 51 BBlS, 15.6 PPG, PERMAFROST ·C·, 60 BBlS DEAD CRUDE :;}~.~: ~ u f= u ~ psro 5707' .' ,...:.:.:..:~:: 9 5/8", 36#, K-55, BTRC, SET@2697' '. . :':' CEMENT DATA: 360 BBLS (1000 SKS) ~.. PERMAFROST "E" W/ 5# GILSONITE AND 44 BBlS (215 SKS) "G" WI 0.2% CFR-3 & 2% CaCI2 EST TOC @ 3850' RA TAG 0 4690' 7", 26#, L-80, BTRC. SET @ 5797' CEMENT DATA: 67 BBLS (330 SKS) "Goo WI 0.21. CFR-3, 0.4% HALAD 344, 0.03% HR-5 TO 5815' i.......~ CONOCD INC. ANCHORAGE DIVISION APPROVED BY: HDS DRAFTED BY: SJN DATE: 5/14/92 CAD FILE: WCAG7 '.. OOOA OOA -...-. OA ·...IA -.. Tbg ,.--=~.----,-,-.-._ IV ~ --..----------- . . , 1\ " i il-' ~ it II g i I I i I II i I. .1 : ÌI 8/19/2005 10/19/2005 !~. /~ ~ ~.'\ /\ ~. ~ 1\ / \ ~\. i ~\ ~. ./\ \ I '. \ / '. I' ~, I \ iii \.../ \... \, o . -...-*..-..j..-...-.-...!-....III-A-ìl~......~.~....I 10/19/2004 12/19/2004 2/19/2005 4/19/2005 6/19/2005 1,000' .°f'm~¡:.....: I . : I . . .........=' . ... I !' --- 2,000 . .!ð..Mðð§P.........___.... ···..____·····..·..·..···...····.···..···.·..nn. .....m·...m............................n..nm.........m..m.........nn..................................___ Q) ... ::::J th th ~ D.. ') 3,000 . 4,000 MPG-07 TIO Plot ) 'fG?1Q I z,{ ¡if f oS" Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us 6 \~VO'}- OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test BP Exploration (Alaska) Inc. Milne Point / MPU / G Pad 10/19/05 Lee Hulme Packer Depth Pretest Initial 15Min. 30 Min. WeIlIMPG-07 I Type Inj. I N TVD I 3,964' Tubingl 800 800 800 800 J Interval I V p.T.D.11910250 I Typetest I P Test psil 1500 Casing I 0 2,800 2,775 2,7701 P/FI P Notes: MITIA to for SC Leak Waiver Compliance. OAI 0 0 0 01 AOGCC representative did not witness test. Weill I Type Inj. I I TVD I Tubing I Interval I P.T.D.I I Type test I I Test psil Casing I P/FI Notes: OA I Weill I Type Inj.1 I TVD I Tubing I Interval P.T.D.I I Type test I I Test psi! Casing 1 P/F Notes: OA 1 Weill I Type Inj.1 I TVD I Tubing I Interval I P.T.D.I I Type test I I Test psi Casing I P/FI Notes: OA I Weill 1 Type Inj.J J TVD I Tubing 1 Interval p.T.D.1 J Type test I I Test psil Casing 1 P/FI Notes: OA 1 TYPE INJ Codes D = Drilling Waist G = Gas I = Industrial Waistewater N = Not Injecting W = Water MIT Report Form BFL 9/1105 TYPE TEST Codes M = Annulus Monitoring p = standard Pressure Test R = Internal Radioactive Tracer SUlvey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) Yo-'" ·h,:.<.~"'~~_~' . ~vnÐ\JM~{~l...^ c c 2005-1 019_MIT _MPU_ G-07.xls }91 - 0 as WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W, 7th Street Suite 700 3001 Porcupine St. Anchorage, Alaska 99501 RE: Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration(Alaska), Inc. Petro-Technical Data Center LR2-1 900 East Benson Blvd. Anchorage, Alaska 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FilM BLUELINE Open Hole 1 1 1 MP G-07i 7 -9-2003 Res. Eva!. CH 1~4 J5(' 1 1 ,"" Mech. CH 1 Caliper Survey RECEIV,ED igned: ~~\~~l{ì ~I~~¡~~ . " r'rn 1 --: l)t\n A Date:~ "'int Name: Alaska Oil & Gas Cons. CommisiOn Anmorage PRoAcTivE DiAGNOSTk SfRVicE~1 INÇ.( HQ Qpx 1}69 STAFFoRd TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 'E-mail: n~f~fflfJtlorylog.com Website: www.memorylog.com SCANNED FES 2 0 200,4 R~~y)\.~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 16 May 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ECC No. Run # 1 6427.00 Run # 1 6428.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign ~nd ~.eturn ~o; Petrotechnical Data Cen%e~ ~BP Exploration (Alaska) In~ ' RECEIVE,'D Alaska 011 & Gas Cons. Cor~!Is.$Jgll' Anchorage AOGCC Individual Geological Materials Well Inventory Page: Date: 1 01/28/94 PERMIT 91-025 DATA BGT T DATA_PLUS L 127-2701 RUN DATE_RECVD 05/29/91 91-025 CBT L 3890-5690 01/02/92 91-025 91-025 91-025 91-025 91-025 91-025 CNL/LDL-PORO CNL/LDL-RAW CST CYB DGR/CNO/DSFD DGR/CNO/DSFD L 2697-5715 L 2697-5715 L 5160-5540 L 2697-5666 L 2697-5752 MD L 2374-4466 TVD 05/29/91 05/29/91 05/29/91 05/29/91 06/18/91 06/18/91 91-025 91-025 91-025 91-025 91-025 91-025 91-025 DGR/CNO/DSFD DGR/CNO/DSFD DGR/EWR/FXE/ DGR/EWR/FXE/ DGR/EWR/FXE/ DGR/EWR/FXE/ DIL-SFL L 2697-5752 MD L 2374-4466 TVD L 2697-5752 MD L 2374-4466 TVD L 2697-5752 MD L 2374-4466 TVD L 2697-5743 06/18/91 06/18/91 06/18/91 06/18/91 06/18/91 06/18/91 05/29/91 91-025 GCT L 12-5650 01/02/92 91-025 91-025 91-025 91-025 NGT L 2697-5666 PERF L 5000-5667 RFT L 5150-5580 WFL L 5000-5497 05/29/91 01/02/92 05/29/91 11/02/93 91-025 WFL L 5000-5658 06/01/93 91-025 407 R COMP DATE:12/27/91 03/19/92 91-025 DAILY WELL OP R 05/17/91-12/27/91 03/19/92 91-025 SURVEY R SS DIRECTIONAL 02/05/92 91-025 4916 T 2500-5850,OH 06/18/91 91-025 4920 T 3501-5602, RFT 06/14/91 AOGCC Individual Well Geological Materials Inventory PERMIT DATA T DATA_PLUS RUN 91-025 4921 T 92.5-5803, OH/FINALS 91-025 5176 T GCT Page: Date: 2 01/28/94 DATE_RECVD · 06/14/91 02/05/92 Are dry ditch samples required? yes no And received? yes no Was the well cored? yes no Analysis & description received? Are well tests required? yes no Received? yes no Well is in compliance Initial yes no Comments PERMIT # O P E RATOR 91-025 CONOCO ~~GCC Individual Well ~ Geo,i jical Materials Inventory Page: 1 Date: 12/22/93 BGT DATA T DATA_PLUS mmmmmmm--m--mm L RI,2&5",127-2701 RUN SCALE DATE_RECVD 05/29/1991 91-025 CONOCO CBT L R1,5",3890-5690 01/02/1992 91-025 CONOCO CNL/LDL-PORO L RI,2&5",2697-5715 05/29/1991 91-025 CONOCO CNL/LDL-RAW L RI,2&5",2697-5715 05/29/1991 91-025 CONOCO CST L R1,5",5160-5540- 05/29/1991 91-025 CONOCO CYB L R1,5",2697-5666 05/29/1991 91-025 CONOCO DGR/CNO/DSFD L 2"MD,2697-5752 06/18/1991 91-025 CONOCO DGR/CNO/DSFD L 2"TVD,2374-4466 06/18/1991 91-025 CONOCO DGR/CNO/DSFD L 5"MD,2697-5752 06/18/1991 91-025 CONOCO DGR/CNO/DSFD L 5"TVD,2374-4466 06/18/1991 91-025 CONOCO DGR/EWR/FXE/ L 2"MD 2697-5752 06/18/1991 91-025 CONOCO DGR/EWR/FXE/ L 2"TVD,2374-4466 06/18/1991 91-025 CONOCO DGR/EWR/FXE/ L 5"MD,2697-5752 06/18/1991 91-025 CONOCO DGR/EWR/FXE/ L 5"TVD, 2374-4466 06/18/1991 91-025 CONOCO DIL-SFL L R1,2&5" 2697-5743 ! 05/29/1991 91-025 CONOCO GCT L R1,12-5650 01/02/1992 91-025 CONOCO NGT L R1,2&5" 2697-5666 05/29/1991 91-025 CONOCO PERF L R1,5" 5000-5667 01/02/1992 91-025 RFT L R1,5",5150-5580 05/29/1991 PERMIT # OPERATOR CONOCO ~-~GCC Individual Well Geological Materials Inventory Page: 2 Date: 12/22/93 DATA T DATA_PLUS RUN SCALE DATE_RECVD 91-025 CONOCO WFL L 5" 5000-5497 ! 91-025 WFL CONOCO L R1,5" 5000-5658 11/02/1993 06/01/1993 91-025 407 CONOCO R COMP DATE:12/27/91 03/19/1992 91-025 CONOCO DAILY WELL OP R 05/17/91-12/27/91 03/19/1992 91-025 SURVEY SCHLUMBERGER R SS DIRECTIONAL 02/05/1992 91-025 4916 CONOCO T 2500-5850,OH 06/18/1991 91-025 4920 CONOCO T 3501-5602, RFT 06/14/1991 91-025 4921 CONOCO T 92.5-5803, OH/FINALS 06/14/1991 91-025 5176 T GCT SCHLUMBERGER 02/05/1992 Well Data Summary Section Dry ditch samples required and received?...yes ...no cored intervals: - Description and analysis received...yes ...no ...not required Are well tests required and received?...yes ...no Well is in compliance. initial Comments :i ~ SCHLUMBERGER WELL SERVICL.~ A DIVISION OF SCHLUMBERGER TECHNOLOGY coRPORATION HOUSTON, TEXAS 7725 !-217S ~EASE REPLY TO SCHLUMBERGER WELLSERVICESPouch 340069 ?rudhoe Bay, AK 99734~006~ Attn: Bernie/Shelley Cortoco, I~tc. 3201 "C" Street, Suite 305 Anchorage, AK 99503 Attention: Dorothy Bourbeau Gentlemen: :~;~[[; Enclosed are 2 BL prints of the Water Flow,Log, Run Compony Conoco, Inc. ~n' Well Milne Point Unit G-7 , ,on: I Field Milne Point Additional prints are being sent to: 1 BLpr rints Conoco, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb, OF 2018 EPT ,.,County North Slope State Alaska 1BL prints, 1RF Sepia Chevron Production Company .... !301McKinney Houston, TX 77010 Attn: Gary Forsthoff 713/754-5618 1 BIp. rints Conoco, Inc. 1000 South Pine Ponca City, OK 74602-1267 Attn'. Janet Webb_. 1239 EB ERS . / /' Cnmmi / .~chora~e, ~ 99~0[ (Att~= ,,Lar~ Gra.t ~' prints The film is returned to Conoco._ Dorothy Bourbeau We appreciate the priVilege of serving you. SWS-- t 327-F CH (7 BL/3 I BL prints, 1RF Sepia ..OXY U.S.A.. Inc. 6 Desta Drive, Suite 6002 .Midland, TX 79705 Attn: John Carrol _ 915/685--SR03 ~.prints prints ' Date: ~ Very truly yours, _~ c~~ SCHLUMBERGER WELL SE_~ICES Raymond ti. Dickes DISTRICT MANAGER SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-21 75 PLEASE REPLY TO SCHI-UMSERGER WEI'L SERVICES MAY 2 9 1993 Pouch 340069 Prudhoe Bay, AK Conoco, [nc. 320]. "C" Street:, Suite 200 Anchoras;e, AK 99503 Attention: Llnda Start Gentlemen: Enclosed ere 3 BLprintsofthe Compony Conoco~ Inc. Well Milne Point Unit G-7 Field' Milne Point .: Additionalprintsare beingsentto: ]. BL prints Conoco~...Inc. 600 North Dairy Ashford Houston~ TX 77079 Attn: George Laab, OF 2018 PT WFL, Run 1, 5/~24/93 County' ..... ~ih Slope ' State. ,, Alaska I BL prints , I RF Sepia Chevron U.S.A. 11111 South Wilcrest Houston, TX 77099 Attn: Larry Sydora 713/561-3674 1BL prints Conoco, Inc. 1000 South Pine Ponca City, OK .74603 Attn: Glenn Welch, 7391RW 1BL prints , '1 RF Sepia OXY U.S.A.~ Inc. 6 De.tm Dr~v~: R-~t~ ~002 Midland. TX 79705 Attn: John Carrol ~ ~ . 915/685-5898 /z~~BLprints , 1 RF Sepia~'"'~ prints // Alaska Oil & Gas Conservati°~ / Commission . \ . -- -- t 300]. Porcupine Drive .~~j_ ~% b~% ..~-]-0.~_~:~ ~ .~chorage, ~ 99501 [~~~~~/ AeOn: Larry Grant ~-- t ~ ' ~~~ prints '7 99734-0069 The film is returned to Conoco, Llnda Start We oppreciate the privilege of serving you. 1993 Date: Very truly yours, SCHLUMBERGER WELL SERVICES SwS- 132 ? ¢ OH/CH (11 BL/3RF) _Ra_y~..0. _n~_N....l)ickes_ __ OI~)TR ICY MAN&OIl March 27, 1992 Mr. Blair Wondzell Naska Oil & Gas Conservation Commission ~001 Porcupine Dr. Anchorage, Alaska 99501 Dear Blair Wondzell, Please find attached the casing and cementing reports for.~~nd several other Schrader Bluff wells. Unfortunately, the foreman that completed the form did not Indicate that there were full returns during the c,-~ment job. However, I contacted the foreman, Joe Polya, that did th® cement job and he informed me that it was an oversight on his part. We have never had a problem with loss circulation on the 7" jobs on Schrader Bluff wells primarily due to the fact that we do not bring cement high enough in the wells to exc~md the fracture gradient. Additionally, I contacted the foreman opposite Mr. Polya and he confirmed that loss returns cfi thi~ cTdsing string in the ~chrader Bluff wells is not a problem. I have attached other casing/cementing reports from Schrader Bluff wells to provide you with additional support. Allow me to apologize for the delay in providing you with this iflf~on and tf there is anything I can do in the future do not hesitate to call (564-7~). Best Regards. Steve Bolt Division Drilling Superintendent RECEIVED ~AR 2 7 1992 ~klaska Oil & Gas Cons. Commission Anchorage 2_7 '92 15:27 CASING AND ~F~ENTING REPORT Full ~tu~ni~~ No) Camant Reruns co ~urt~o~ (Ye~,~._ . ~ ...... ~BL8 initial strlnB ~etShz{..~._=.~..._(Ibs) Final La~i~i ~eiihc i :}~ ..... (lbs). OR IG IN A L ' ~ ;'"'~ STATE OF ALASKA ! ~ ALASKa; ~JIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOCI 1. Status of Well Classification of Service Well OIL [~ GAS [~] SUSPENDED D ABANDONED 12 SERVICE 0[]~:::'[':!'-i~;~S--[' ~Jater ]~131ectton 2. Name of Operator ~ '7~;~;.17';;:~ 7/Permit Number co.o~o ~.c. ~,~~ ~ 3. Address ~ ~. k[,~,~[ 8. APl Number ~~, so- 02¢-2zz~o 320[ ~C~ St., Sutce 200, ~cho~a~e, ~as~ 99503 ~ ~r~ ~-r~0;~ . ,, 4. Location of well at surface ~~~b~/, 9. Unit o~ Lease Name 3235' ~, 3~1' ~, S~C. 27, T13~, ~t0~, ~, ~SS ~~~ Point At Top Producing Interval ~ ~~O 10. well Number soo' ~, 2ooo' ~s~, s~c ~7, ~z3., ~zo~, ~, .ss~~~~:~ , At Total Depth 11. Field and Pool 458' ~. 1767' FEL, S~,. 27. TI3N, alOE, ~, ~SB [upa~k ~ver/ 5. Elevation in f~t (indicate KB, DF. etc.) [ 6. Lease Designation and Serial No. Schrader Bluff B 35' AGE] ~L47434 ,2. DatsSpudded 13. DateT.D. Reached 14. DateComp.,Su,.orAband. ],5. WaterDepth, ifoffshor, 116. No. of Completions 5/17/91 5/23191 , 12/27/91I J~l~ ,., ~sL 0~ 17. TotalOepth(MD+TVO) 18. PlugBackOepthiM>WD) 19. DirectionalSurvey { 20. Depth where SSSV set [21.Thickn,sofPermafros, 22. Type El~tric or Other Logs Run SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1'~-3/8" 54.5 [-55 ,35' 115' 30" ~ 6~sx Pe~frost 'C' 9-5/8" 36.0 K-55 35' 2790' 12--1/~' ! 700ax P~mfroa~ I a 300ax _7~ 26.0 L-80 35' ,5~2~' 8-1,/2" ! 3~sx .......... 24. Perorations open to Production (MD+TVO of Top and Bottom and 25. TUBING R ECORO ~ ........ interval, size and number) SIZE DEPTH sET (MD) PACKER SET (MD} 2-7/8" ..6.5~ ~ 5106,15' OTI~ "PLS"-5060~87' TOP SROT- 5176* 4065~ B~ SLOT - 5534' 4308' ~ 26~ ACID, FRACTURE, CE~eNT'SOUEEZE, ETC.' DEPTH INTERVAL (MD) RMOUNT & KIND OF'MATERIAL USED ~~ OF S~ ~ERV~'S (37~-51B) ~/A ~/A ~ 5 ahots/ft. 821 total shots ,, 27. PRODUCTION TEST , = , Date First Production [ Meth'od of Operation (Flowing, gas lift. etc.) S/I for. Surface ~odifica(ioas.. Date of Test Hours Tested PRODUCTION FOR ~OIL,8BL GAS-MCF WATER~BBL CHOKE SIZE [ GAS-OIL RATIO TEST PERIOD ~ 1 'Flow Tubing Casing Pressure CALCULATED OIL*esL GAS-MCF WATER-eeL 01[ GRAVITY-APl' (tort) Press. 24-HOUR RATE ~ ~. CORE DATA , , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED ~0~ ~AR 1 9 1~9~ ~as~ 011 & Gas Cons. Anchorage .... '-orm 10-407 Submit ~duplicate ~., ~ v. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS' , ,, NAME .. _ Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. P,A~AG 4690 ~ TOP OF "N" SAND 5176' 4045 ' N/A TOP OF "0" SAND 5398' 4204' 31, LIST OF ATTACHMENTS NELL, ACTIVIT~ REPORT~, ~rELL SCItEMATIC 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ....... INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on ali types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 Milne Point G No. 7 - Drill & CASE API No.: 50-029-22140 Location: AFE Number: AFE Amount: Milne Point Field - SCHRADER BLUFF POOL 10-61-1380 Approved: 04/22/91 $1,098,000 gross Cost to Date: $ 443,045 gross 05/17/9~: Move rig f/ G-6 to G-7. Rig up. Mix mud. MU 12 1/4" bit and steerable BHA. Accepted rig at 0800 hrs 05-17-91. Spud well at 1430 hrs 05-17-91. Drill f/ 105' to 722'. 05/18/91: Drill f/ 722' to 1470'. Run check shot survey on WL. Short trip. Drill to 2730'. C & C. 05/Z9/9~: POOH. Run caliper on EL. RU and Run 63 jts, 2651', 9 5/8", 36 PPF, L-80, Butt csg. Used stab in FC at 2612'. FS at 2697'. Land csg. Circ. LD landing jt. RIH w/ stab-in adapter on DP. Stab into FC. Cement w/ 360 BBL Permafrost E cmt at 12.3 PPG and 44 BBL G cmt at 15.8 PPG. Had cmt returns to surface. Floats held. POOH w/ DP. ND Diverter. Install speed head. NU BOP's. Test same. 05/20/9~: Fin testing BOP's. MU 8 1/2" bit and steerable BHA. RIH. Test csg to 1500 psi. Drill out float equip and cement to 2730'. Drill 10' to 2740'. Run leakoff to 15.5 PPG EMW. Drill to 4539'. Short trip. Drill to 4711'. 05/2~/9~: Drill f/ 4711' to 5750'. C & C. POOH. RU EL. Run DIT-LDT-CNL- MSFL-NGT-AMS. 05/ZZ/9~: Finish Running DIT-LDT-CNL-MSFL-NGT-AMS. Run RFT and SWC's. RIH With Bit. Drill From 5750' to 5815'. C & C. POOH L/D DP. 05/23/9~: Finish POOH L/D DP & BHA. Change Rams to 7". Run 136 Jnts 7" 26 lb/ft, L-80 cSg. FS ~ FC at 5707'. Circ. Pump 50 bbls 11 PPG Preflush, 40 bbls Water, 330 sx (67.5 bbls) Class "G" cement and displace with 218 bbls of 8.9 PPG brine. Bump plug and test casing to 1500 psi for 30 min. N/D BOP's, Set and Test Packoff to 5000 psi, N/U Tree. Release rig fron G-7 at 2000 hrs on 5/23/91. Operations Suspended Until Arrival of Completion Rig. Rig down from I-2 & moved to G-7. Rigged up support equipment 0 but could not raise mast because of -50 weather. Started warming up to -35°. Rig up mast. Off load 50 BBLS of diesel & 450 BBLS of 8.6 NACL with 12% methanol brine. Set BPV. ND tree & NU BOP & start BOP test. ~2/Z4/9~: Complete BOP test. Pull two-way check. Pick up landing joint & stab into hanger & lay down had problems with power generators on rig. Looks like water in fuel. Install wear bushing. Tally pipe in pipe shed. Pick up 6" bit & 7" 26# casing scraper set nominal. RIH with bit & scraper, picking up 2-7/8" EUE 6.5#/ft. tubing (Ran into tee plug 3' below hanger worked with tongs till broke free). (Still hanging power failure - overheating) RU to press. VP on caping to 1500 PSI for 30 minutes. Mix 3.5# HEC/BBL Pills & 50 BBL Dirt. Mag. Pill (Mechanic found heat seminal's hook-up backward). Hook-up to pump 8.6 ppg NACL/12% meth. (reverse cir. 75 BBL diesel to slop tank). Pump 4.0 BBLS/min @ 875 pump pressure with 175 on tubing. Total cir. 240 BBLS before clean-up (problem with hydraulic pump overheating due to possible thermostat or head gasket leak). RU & pump 25 BBL, 3.5 HEC/BBL (source H20); 50 BBLS/1 drum dirt magnet; 25 BBL 3.5 HEC/BBL & displaced with 400 BBLS of 8.6 NACL 12% meth. clean & filter according: suction NTU. Low 77, high 200 & returns low 125, high 180 NTU's. Total BBLS circulated - 500 BBLS. 12/25/91: Complete brine circulation: prepare to POOH with 2-7/8" EUE, 6.5#/ft. tubing & 7,, scraper 'n bit. POOH with bit & scraper; lay down 20 JTS of tubing - 630'. Will leave 160 JTS in derrick (5047'). Schlumberger rig up to RIH with CBT with rigid stabelizers; CR/CCL sub. RIH tag PBTD 5694'. Log up to 3900' round top of cement at 4010' . Correlated with original dual induction log for accurate data. Tool assembly not functioning properly. RU to RIH with GCT continuous Gyro tool. RIH with GCT Gyro. Log both down & up from PBTD. Had problems with tool string. POOH to repair. RU 4.5" OD Gon assembly - 5 SPF, 37 GM (5lB) and CCL sub correlate with CCL from CBT. Perforated at the following intervals: 5304' - 5326' KB 5398' - 5418' KB 5418' - 5446' KB 5494' - 5513' KB 5514' - 5534' KB 5176' - 5188' KB 5220' - 5238' KB 5257' - 5262' KB 5286' - 5326' KB Total of seven intervals run. Ail shots fired. Completed penetrating at 0330. Set up to RIH with packer assembly & 2- 7/8" EUE 6.5#/ft. tubing. 12/26/91: Complete perforating intervals; all guns fired (821 total shots). RD Schlumberger E-line unit & equipment. Pick up Otis tubing seal divider, 7" 26# Otis PLS packer. 1 JNT 2-7/8" EUE 6.5#/ft tubing, otis "X" profile nipple, 2-7/8" EUE 6.5#/ft pup JNT, 8" wireline re-entry guide. RIH with above equipment & 159 JTS of 2-7/8" EUE 6.5#/ft tubing. Total of 4982.26' above packer. Assembly is 84.48'. Tubing tail is set at 5106.15' KBM. Mix 155 BBLS of 8.6 NACL & 6 gal of NALCO unitreat 3900. Pump down annulus. Spot 50 BBLS of methanol down annulus & 20 BBLS down tubing for freeze protection. Attempt to set packer & land hanger. Not able to align hanger with pin. Hanger not able to set down fully into tubing bowl. PU hanger and found both seals missing from hanger. Locate seals & redress hanger. Fish for O-rings. Fished one seal ring & lost the other down hole. Used stainless steel tubing 1/4". Set & released packer several times in order to set hanger in correct position. Finally had to release from packer & J-latch. Set packer & hanger & locked down pins on hanger. Press on annulus 1500 PSI for 30 minutes. Lost 80 PSI. Set BPV. 12/27/91: Pump off 250 BBLS of brine 8.6 NACL/12% methanol from volume { { pits. will use on G-5 Well. Empty slop tanks & vac lines. ND BOP's after installing BPV & NU Well Head. Pressure test to 5000 PSI. Hanger leaking through insulation sleave on tubing. ND wellhead. Found sleave to be egg shaped. Located another sleave. Cleaned up sealing surface & changed a-Rings on dummy penetrator. NU Wellhead. Press up to 200 PSI - dummy penetrator found to be leaking. ND wellhead. Change a-Rings on penetrator. NU wellhead. Tested to 5000 PSI test ok. Line-up wellhead valves in proper position. Transfer diesel from pill tank. Pressure test to 5000 PSI. Test ok. RD EWS Rig #4 & move to G-5 well. REEEIVED FEB 1 3 1992 Alas.lia :DiJ :& Gas Cons. Commission ~nchorage DEC 18 9:18 FROM CONOCO ANCH DIU 7 ~'"! :./'i' ,' "' ..... '. ~ "' ~. · ' ' :" .i'." ~ ·.'/ D£c 18 '91 9:17 FROM CONOCO RNCH DIU WELL No. G-7 CASING SK:ETCH APl No.: 50-029-22140 PERMIT No.: 91-25 DRILLED: 5/23/91 . . ARCTIC PACKED: 1 O/12/91 PAGE. 0 1 5 OPERATORt CONOCO INC. SURFACE LOCATION: 5235' I=NL, 3451' FEL, SEC. 27. '1'13N, R1OE:, U.M. BOTTOM HOLE: LOCATIONI N/A SPUD OATE: 5/!7/9~ RKg'"31' 7.5 eeLS DIESEl. 80 99LS FMC CSG SPOOL g 5/8", 36#, K-55, BTRC. SET I 2696' EST TOC · 3850' CEMENT DATA: 360 BELLS (lO00 PE:RMAFROST 'E' Gi[.$ONI'rE AND 4~ ,CFR.--5 & 2% RECEIVED RATAO · 46g0' FEB 1~ 1,992 .0ii & Gas Cons. Commission ~A~cborage Pe~ 5707' 7', 25~l, L-SO, BTRC, SET t 5797' CEMENT DATA: 6'7' BBLS (330 SKS) 'O' W/ 0.2% C;R-3. 0.4% HALAD ;344. 0.03~ HR-S 'T~ 5818' ~NOCO Inc. ANCHORAGE DIVI$10N , I IIII t APPRO~P.--D BY: HO$ O~ BY; 'I'~AT~: '" ~O/2"/"l 'I' II1'11-- CAD ~i.~ ¢P60_01~ I I III-- SUB - S URFA CE DIRECTIONAL SURVEY UIDANCE r~-! ONTINUOUS r'~ COL RECEIVED FEB 0 ~ 199~ AJaska Oil & Gas Cons. Commission Anchorage Company CONOCO INC. Well Name MPU G-7(3288'FNL,3393'FEL,SEC 27,T13N,R10EI Field/Location SCHRADER BLUFF, NORTH SLOPE, ALASKA Job Reference No. 92104 i !v " Loqqed BV: f Date 25-DEC-1991 Computed By.' R. KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR CONOCO, INC. MILNE POINT UNIT G-7 SCHRADER BLUFF NORTH SLOPE, ALASKA SURVEY DATE: 25-DEC-91 METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: TANGENTIAL- LINEAR HORIZ. DIST. ENGINEER: JEFF FORMICA Average~ aeviation and azimuth PROJECTED ONTO A TARGET AZIMUTH OF NORTH 30 DEG 53 MIN EAST CONOCO, INC. ~ILNE POINT UNIT G-7 SCHRADER BLUFF NORTH SLOPE, ALASKA COMPUTATION DATE: 3-FEB-92 TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH 0 O0 100 O0 199 99 299 99 399 99 499 97 599 88 699 60 799 04 898 21 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 PAGE 1 DATE OF SURVEY: 25-DEC-91 KELLY BUSHING ELEVATION: 66.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET DEG MIN 1000.00 996 98 1100.00 1094 1200.00 1191 1300.00 1286 1400.00 1380 1500.00 1471 1600.00 1561 1700.00 1651 1800.00 1738 1900.00 1818 DEPTH DEG MIN DEG MIN -66.00 0 0 N 0 0 E 34.00 0 20 N 79 40 E 133.99 0 18 N 67 23 E 233.99 0 28 N 64 1 E 333.99 0 39 N'59 30 E 433.97 1 35 N 47 41 E 533.88 3 9 N 39 38 E 633.60 5 15 N 37 5 E 733.04 6 49 N 37 8 E 832.21 8 5 N 35 39 E 930 98 10 20 59 1028 08 1125 65 1220 52 1314 70 1405 74 1495 15 1585 20 1672 39 1752 0.00 0.53 0.94 1.42 2.22 3.91 7.98 15.39 25.83 38.64 54 16 75 60 101 60 130 95 165 33 206 29 249 76 294 53 343 62 27 N 36 54 E 59 14 8 N 39 10 E 08 16 20 N 36 55 E 65 17 57 N 31 39 E 52 22 14 N 28 19 E 70 25 53 N 28 24 E 74 26 1 N 28 33 E 15 27 21 N 28 47 E 20 32 49 N 29 55 E 39 38 35 N 30 51 E 403 2000.00 1896 32 1830.32 39 14 2100.00 1972 2200.00 2046 2300.00 2117 2400.00 2183 2500.00 2247 2600.00 2310 2700.00 2372 2800,00 2434 2900.00 2497 N 30 57 E 465.94 N 31 8 E 530.71 N 31 21 E 598.15 N 30 23 E 668.82 N 28 14 E 743.81 N 28 27 E 820.37 N 28 37 E 897.88 N 28 31 E 976.14 N 28 10 E 1054.56 N 28 48 E 1132.03 50 1906.50 41 11 31 1980.31 43 48 05 2051.05 46 48 13 2117.13 49 37 37 2181.37 50 ,26 47 2244.47 51 17 65 2306.65 51 39 59 2368.59 51 42 73 2431.73 49 49 3000.00 2562.71 2496.71 48 59 N 29 4 E 1207.99 3100.00 2628.95 2562.95 47 50 N 29 30 E 1282.88 3200.00 2696.54 2630.54 47 16 N 29 48 E 1356.55 3300.00 2764.53 2698.53 46 25 N 30 38 E 1429.89 3400.00 2833.97 2767.97 45 53 N 31 42 E 1501.84 3500.00 2903.78 2837.78 45 33 N 32 2 E 1573.42 3600.00 2973.12 2907.12 46 51 N 32 10 E 1645.46 3700.00 3040.53 2974.53 48 31 N 31 36 E 1719.30 3800.00 3106.56 3040.56 48 29 N 31 39 E 1794.40 3900.00 3173.24 3107.24 48 7 N 32 18 E 1868.91 0.00 0.00 0.00 0 18 0 42 1 95 2 24 1 52 0 99 1 .28 4 25 181 3 28 4 24 3 17 0 87 0 84 1 82 9 82 0 47 2.28 1 .04 2.05 6.53 0.65 0.88 0.69 0.89 0.56 1.48 1.24 1 .41 0.95 2.46 0.74 0.81 1.15 1 .41 1 .20 0.73 79 104 134 170 208 247 290 342 FEET 0 O0 N 0 20 N 0 37 N 0 59 N 1 03 N 2 12 N 5 20 N 19 47' 42 42 N 59 42 N 92 N 17 N ~5 N 0 O0 E 071 E 1 22 E 1 77 E 2 61 E 4075 6845 ',] 43 E 17 77 E 25 41 E 0 O0 N 0 0 E 0 73 N 7431 E 1 28 N 73 9 E 1 87 N 71 37 E 2 81 N 68 34 E ,4 59 N 62 31 E 8 5~ N 52 44 E 15 93 N 45 5! E 26.36 N 42 2z: 5 39. 18 N 4O 25 E 34 60 E 54.74 N 39 12 E 47 94 E 76.35 N 38 54 E 64 33 E 102.59 N 38 50 E 80 94 E 131.92 N 37 51 E 97 81 E 166.02 N 36 6 E 26 N 117 48 N 138 81N 159 63 N 183 03 N 213 23 E 206.72 N 34 33 E 02 E 250.03 N 33 30 E 47 E 294.69 N 32 46 E 52 E 343.72 N 32 16 E 80 E 403.35 N 32 1 E 395.81 N 245 96 E 466.01 N 31 51 E 451.29 N 279 508.96 N 314 569.45 N 350 635.12 N 387 702.58 N 423 770.74 N 460 839.47 N 498 908.66 N 535 976.79 N 572 40 E 530.77 N 31 46 E 35 E 598.21 N 31 42 E 90 E 668.88 N 31 39 E 19 E 743.84 N 31 22 E 55 E 820.37 N 31 5 E 61 E 897.88 N 30 52 E 15 E 976.14 N 30 41 E 23 E 1054.58 N 30 30 E 26 E 1132.07 N 30 22 E 1043.33 N 608.98 E 1208.06 N 30 16 E 1108.65 N 645.67 E 1282.97 N 30 13 E 1172.73 N 682.07 E 1356.66 N 30 11 E 1236.04 N 719.09 E 1429.99 N 30 11 E 1297.67 N 756.21 E 1501.93 N 30 14 E 1358.45 N 794.05 E 1573.50 N 30 18 E 1419.47 N 832.37 E 1645.52 N 30 23 E 1482.09 N 871.53 E 1719.35 N 30 27 E 1546.08 N 910.85 E 1794.44 N 30 30 E 1609.24 N 950.40 E 1868.94 N 30 34 E CONOCO, INC. MILNE POINT UNIT G-7 SCHRADER BLUFF NORTH SLOPE, ALASKA COMPUTATION DATE: 3-FEB-92 PAGE 2 DATE OF SURVEY: 25-DEC-91 KELLY BUSHING ELEVATION: 66.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG M/N FEET 4000.00 3239 26 3173.26 49 17 4100.00 3304 74 3238.74 48 58 4200.00 3370 60 3304.60 48 41 4300.0C 3436 82 3370.82 48 22 4400.00 3503 36 3437.36 48 3 4500.00 3570 84 3504.84 46 49 4600.00 3639 87 3573.87 46 2 4700.00 3708 6C 3642.60 46 46 4800.00 3777.74 3711,7Z 45 55 4900.00 3848.06 3782.06 44 44 5000.00 3919.49 3853.49 44 49 5100.00 3990.76 3924.76 44 30 5200.00 4061.84 3995.84 44 36 5300.00 4133.87 4067.87 43 36 5400.00 4206.56 4140.56 43 13 5500.00 4279.62 4213.62 42 56 5600.00 4352.99 4286.99 42 48 5700.00 4426.33 4360.33 42 49 5800.00 4499.68 4433.68 42 49 5815.00 4510.68 ~444.68 42 49 VERTICAL DOGLEG RECTANGULAR COORDINATES HORiZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUT~ DEG/IO0 FEET FEET FEET DEG 83 77 41 21 56 20 43 N 30 22 E 1944 01 N 30 37 E 2019 58 N 30 48 E 2094 N 30 47 E 2169 N 30 39 E 2244 N 30 43 E 2318 N 30 39 E 2390 N 3O 38 E 2463 N 31 2 E 2535 N 31 34 E 2606.53 N 32 18 E 2676.50 N 31 43 E 2746.63 N 31 37 E 2816.97 N 32 17 E 2886.32 N 32 35 E 2954.97 N 32 23 E 3023.22 N 32 9 E 3091.14 N 32 4 E 3159.07 N 32 4 E 3227.02 N 32 4 E 3237.21 0 56 0 27 0 52 0 49 1 01 1 27 1 11 1.07 0.53 I .5~ 1673.43 N 989.39 E 1944.03 N 30 36 E 1'738.55 N 1027.74 E 2019.61 N 30 35 .E 1803.27 N 1066.15 E 2094.86 N 30 36 E 1867 63 N 1104.51 E 2169.79 N 30 36 E 1931 84 N 1142.59 E 2244.44 N 30 36 E 1995 30 N 1180.26 E 2318.24 N 30 36 E 2057 50 N 1217.21 E 2390.59 'N 30 36 E 2120 05 N 1254.15 E 2463.23 N 30 36 E 2182 OB N 1291.16 E 2535.46 N 30 37 5 224~ 8~ ~ ~328.1~ E 2606.56 ~ 30 3E E 0.02 1.05 236~ 1.34' 2421 0.62 2480 0.73 2538', 0.46 2595 0.40 2653 0.00 2710 0.00 2768 0.00 2777 2302 17 N 1365 19 E 2676 52 N 30 40 E 59 N 1402 52 N 1439 28 N 1476 28 N 151'2 84 N 1549 26 N 1585 84 N 1622 43 N 1658 07 N 1663 47 E 2746 32 E 2816 18 E 2886 94 E 29'54 67 E 3023 99 E 3091 06 E 3159 14 E 3227 56 E 3237 64 N 30 42 E 98 N 30 44 E 32 N 30 46 E 97 N 30 48 E 22 N 30 50 E 14 N 30 52 E 07 N 30 54 E ,02 N 30 55 E 22 N 30 55 E COMPUTATION DATE: 3-FEB-92 PAGE 3 CONOCO, INC. MILNE POINT UNIT G-7 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 25-DEC-91 KELLY BUSHING ELEVATION: 66.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG M[N 0.00 0.00 -66.00 0 0 N 0 0 E 0 O0 1000.00 996.96 930.98 10 20 N 36 54 E 54 16 2000,00 1896,32 1830,32 39 14 N 30 57 E 465 94 3000.00 2562,71 2496.71 48 59 N 29 4 E 1207 99 4000.00 3239,26 3173.26 49 17 N 30 22 E 1944 01 5000,00 3919.49 3853.49 44 49 N 32 18 E 2676 50 5815.00 4510.68 4444.68 42 49 N 32 ~ E 3237 21 0.00 0.00 N 0.00 E 0.00 N 0 0 E 4.25 42.42 N 34.60 E 54.74 N 39 12 E 2o28 395.81 N 245.96 E 466,01 N 31 51 E 1.24 1043.33 N 608.98 E 1208.06 N 30 16 E 0.56 1673.43 N 989.39 E 1944.03 N 30 36 E 0.02 2302.17 N 1365.19 E 2676.52 N 30 40 E 0.00 2777.07 N 1663.56 E 3237.22 N 30 55 E CONOCO, INC. MILNE POINT UNIT G-7 SCHRADER BLUFF NORTH SLOPE, ALASKA COMPUTATION DATE: 3-FEB-92 PAGE 4 DATE OF SURVEY: 25-DEC-91 KELLY BUSHING ELEVATION: 66.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICA: VERTICAL DEVIATION AZIMUT~ DEPTH DEPTH DEPTH DEG MIN DEG 0 0 N 0 0 E 0 21 N 72 57 E 0 19 N 68 59 E 0 20 N 70 36 E 0 35 N 63 41 E 1 10 N 53 6 E 2 39 N 39 53 E 4 39 N 37 38 E 6 19 N 37 13 E 7 38 N 36 2 E 0,00 66 O0 166 O0 266 01 366 01 466 O2 566 08 666 28 766 74 867 49 0 O0 -66 O0 66 166 266 366 466 566 666 766 866 O0 0 O0 O0 100 O0 O0 200 O0 O0 300 O0 O0 400 O0 O0 500 O0 OO 600 O0 OC! 700 O0 O~ 800 O0 ENGINEER: JEFF FORMICA VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN. 0 O0 0 39 0 80 1 22 1 91 315 6,30 12,50 22,0~ 34,21 968,57 966.00 900.00 9 15 N 36 13 E 48,86 1070,57 1066,00 1000.00 13 25 N 38 34 E 68,68 1173.90 1166,00 1100,00 15 43 N 38 22 E 94,44 1278,32 1266 O0 1200,00 17 26 N 33 13 E 124,37 1384,35 1366 O0 1300 O0 21 40 N 28 29 E 159.51 1493,67 1466 O0 1400 O0 25 49 N 28 22 E 203,55 1604.74 1566 O0 1500 O0 26 3 N 28 33 E 251,85 J1716,76 1666 O0 1600 O0 27 45 N 28 56 E 302,29 1833,65 1766 O0 1700 O0 36 9 N 30 23 E 362,56 1961,00 1866,00 1800 O0 38 45 N 30 52 E 441,41 N 31 8 E 525,02 N 31 24 E 617,17 N 28 19 E 723.80 N 28 30 E 843.00 N 28 37 E 967,74 N 28 33 E 1093,76 N 29 6 E 1211.76 N 29 35 E 1323,44 N 30 38 E 1431,43 N 31 56 E 1534,78 N 32 8 E 1637.85 N 31 32 E 1748.26 N 32 20 E 1860.85 N 30 27 E 1974.99 N 30 47 E 2089.61 N 30 39 E 2202.59 N 30 43 E 2313.01 N 30 31 E 2417.90 N 30 57 E 2523.30 N 31 44 E 2624,22 2091,36 1966,00 1900,00 41 5 2227,37 2066.00 2000,00 44 18 2373,65 2166.00 2100,00 49 22 2529.33 2266.00 2200.00 50 42 2689,28 2366.00 2300.00 51 40 2850,26 2466.00 2400,00 50 53 3005.01 2566.00 2500.00 48 56 3154.94 2666.00 2600.00 47 24 3302.14 2766.00 2700.00 46 22 3445.95 2866.00 2800.00 45 44 3589.58 2966.00 2900.00 46 44 3738.56 3066.00 3000.00 48 47 3889.16 3166.00 3100.00 48 6 4040.93 3266.00 3200.00 49 7 4193.04 3366.00 3300.00 48 41 4343.92 3466.00 3400.00 48 22 4492.90 3566.00 3500,00 46 57 4637.82 3666.00 3600.00 46 34 4783,11 3766.00 3700.00 45 59 4925,19 3866.00 3800.00 44 25 0,00 0,15 0,00 0 2O 0 33 1 01 1 67 2 16 1 55 0 O0 N 0 15 N 0 30 N 0 49 N 0 86 N 1 61 N 3 90'N 8 79 N 1642 N 26 23 N 0 O0 E 0 50 E 1 05 E 1 55 E 2 29 E 3 46 E 5 75 E 9 67 E 15.46 E 22.80 5 0,00 N 0 0 E 0,52 N 73 21 E 1 ,09 N 73 59 E 1 .63 N 72 24 E 2,45 N 69 32 E 3,81 N 65 6 E 6,95 N 55 52 E 13.06 N z['7 4z~ E 22,56 N 43 ~7 E 34,75, N 4: O E 2,62 38.14 N 3,04 53.97 N 2,34 74,20 N 59 2,54 98,62 N 77 3,72 129,03 N' 95 1,21 167.84 N 115 0,87 210,31 N 139 2,65 254,61 N 163 9,82 307.,01 N 193 0,48 374.76 N 233 43 55 E 69 93 E 95 41 E 125 O4 E 160 93 E 2O3 O2 E 252 22 E 302 03 E 362 36 E 441 31.42 E 49 4~ N 39 29 E 36 N 38 54 E 38 N 38 56 E 37 N 38 8 E 25 N 36 22 E 99 N 34 38 E 10 N 33 28 E 44 N 32 40 E 65 N 32 9 E 48 N 31 55 E 0,67 1 ,43 1 ,25 0.95 0,75 2,60 0,97 0,78 2 · 34 O, 34 446.42 N 276.46 E 525,09 N 31 46 E 525,20 N 324,25 E 617,23 N 31 41 E 617,48 N 377.70 E 723.84 N 31 27 E 722.49 N 434.35 E 843.00 N 31 1 E 832.08 N 494.13 E 967.74 N 30 42 E 943.19 N 553.87 E 1093.79 N 30 25 E 1046.63 N 610.82 E 1211.83 N 30 16 E 1143.95 N 665.67 E 1323.53 N 30 12 E 1237.37 N 719.88 E 1431.54 N 30 11 E 1325.66 N 773.58 E 1534.87 N 30 16 E 1.14 0.23 0.54 0.84 O. 49 0.27 1 .59 1.48 0.35 1 .50 1413.03 N 828.32 E 1637.92 N 30 23 E 1506.77 N 886.68 E 1748.30 N 30 29 E 1602.43 N 946.09 E 1860.88 N 30 33 E 1700.16 N 1005.07 E 1975.02 N 30 35 E 1798.78 N 1063.47 E 2089.63 N 30 36 E 1895.85 N 1121.28 E 2202.61 N 30 36 E 1990.83 N 1177.60 E 2313.04 N 30 36 E 2081.04 N 1231.11 E 2417.93 N 30 36 E 2171.68 N 1284.91 E 2523.32 N 30 37 E 2257,86 N 1337.42 E 2624.24 N 30 38 E CONOCO, INC. MILNE POINT UNIT G-7 SCHRADER BLUFF NORTH SLOPE, ALASKA COMPUTATION DATE: 3-FEB-92 PAGE 5 DATE OF SURVEY: 25-DEC-91 KELLY BUSHING ELEVATION: 66.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEC MIN DEC MIN FEET DEC/lO0 FEET FEET FEET DEC 5065.35 3966.00 3900.00 44 22 N 32 1 E 2722.39 5205.85 4066.00 4000.00 44 32 N 31 40 E 2821.07 5344.28 4166.00 4100.00 43 21 N 32 18 E 2916.77 5481.39 4266.00 4200.00 43 1 N 32 26 E 3010.54 5617.74 4366.00 4300.00 42 51 N 32 4 E 3103.19 5754.08 4466.00 4400.00 42 49 N 32 4 E 3195.82 5815.00 4510.68 4444.68 42 49 N 32 4 E 3237.2~ 1.21 2341.00 N 1389.68 E 2722 40 N 30 42 E 1.64 2425.01 N 1441.47 E 2821 08 N 30 44 E 0.46 2506.03 N 1492.45 E 2916 78 N 30 47 E 0.62 2585.14 N 1542.87 E 3010 54 N 30 50 E 0.62 2663.47 N 1592.40 E 3103 20 N 30 52 E 0.00 2741.99 N 1641.57 E 3195 82 N 30 54 E 0.00 2777.07 N 1663.56 E 3237.22 N 30 55 E CONOCO, INC. MILNE POINT UNIT G-7 SCHRADER BLUFF NORTH SLOPE, ALASKA MARKER 13 3/8" CASING ~9 5/8" CASING LAST READING GCT PBTD 7" CAS)NG TD COMPUTATION DATE: 3-FEB-92 PAGE 6 DATE OF SURVEY: 25-DEC-91 KELLY BUSHING ELEVATION: 66.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 3288' FNL & 3393' FEL, SEC27 T13N RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 115.00 2697.00 5649.99 5694.00 5797.00 5815.00 115.00 49.00 2370.79 2304.79 4389.65 4323.65 4421.93 4355.93 4497.48 4431.48 4510.68 4444.68 0 21N 837 40 N 2682 06 N 2707 39 N 2766 7i N 2777 07 N 0.79 E 497.02 E 1604.03 E 1619.89 E 1657.06 E 1663.56 E CONOCO, INC. MILNE POINT UNIT G-7 SCHRADER BLUFF NORTH SLOPE, ALASKA MARKER 13 3/8" CASING 9 5/8" CASING LAST READING GCT PBTD 7" CASING TD COMPUTATION DATE: 3-FEB-92 PAGE 7 DATE OF SURVEY: 25-DEC-91 KELLY BUSHING ELEVATION: 66.00 FT ENGINEER: JEFF FORMICA ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 3288' FNL & 3393' FEL, SEC27 T13N RIOE MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 115.00 115.00 49.00 0.21 N 0.79 E 2697.00 2370.79 2304.79 837.40 N 497.02 E 5649.99 4389.65 4323.65 2682.06 N 1604,03 E 5694.00 4421.93 4355.93 2707.39 N 1619.89 E 5797.00 4497.48 4431.48 2766.71 N 1657.06 E 5815.00 4510.68 4444.68 2777.07 N 1663,56 E FINAL WELL LOCATION AT TI.,: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 5815.00 4510.68 4444.68 HOR!ZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 3237.22 N 30 55 E DIRECTIONAL SURVEY COMPANY FIELD WELL COUNTRY RUN DATE LOGGED DEPTH UNIT CONOCO, INC. 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INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 6347 COMPANY · LOCATION ALASKA OIL & GAS CONSERVATION COMMISSION · 3001 PORCUPINE DRIVE ATTENTION · JOHN BOYLE WELL NAME · MPU SERVICES ,V~l GCT LIS TAPE ~1 ~cT DIRECTIONAL SURVEY NO. OF BOXES' ONE JOB NO. · 92104 WELL NAME · SERVICES · NO. OF BOXES' JOB NO. · ADD'L TAPES · *.gEE ABOVE ADD'L TAPES · COMPUTING CENTER PRINT CENTER WELL NAME SERVICES · FEB 0 5 199Z JOB NO. · ADD'L TAPES · WELL NAME · SERVICES · NO. OF BOXES· JOB NO. · ADD'L TAPES · WELL NAME · SERVICES · WELL NAME · SERVICES · NO. OF BOXES' JOB NO. · ADD'L TAPES · SCHLUMBERGER COURIER: DATE DELIVERED: NO. OF BOXES· JOB NO. · ADD'L TAPES · ~ STATE OF ALASKA AL.i.,KA OIL AND GAS CONSERVATION COIV,,,,,,~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend __ Alter casing ~ Repair well Change approved program Operation shutdown__ Re-enter suspended well _~ Plugging __ Time extention __ Stimulate Pull tubing Variance . Perforate X Other 2. Name of Operator Conoco Inc. 3. Address 3201 C Street, Suite 200 Anchorage, AK 99503 4. Location of well at surface 3288' FNL, 3393' FEL, Sec. 27, T13N, R10E, U.M. At top of productive interval 800' FNL, 2000' FEL, Sec. 27, T13N, R10E, U.M. At effective depth 5. Type of Well: Development Exploratory Stratigraphic Service N.S.B. AK NSB AK At total depth 384' FNL, 1767' FEL, Sec. 27, T13N, R10E, U.M. NSB AK Length 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Uner Perforation Depth: 5815' feet 4517' feet Plugs (measured) None 80' 2661' Junk (measured) None 5762' 5707 feet 4433 feet measured None true vertical None Tubing (size, grade, and measured depth) None Size 6. Datum elevation (DF or KB) KB 35' AGL feet 7. unit or Property name Milne Point Unit 8. Well number G-7 9. Permit number 91-25 lO. APl number 50-029-22140 11. Field/Pool Kuparuk RiVer/Schrader Bluff 13-3/8" 9-5/8" 1, Packers and SSSV (type and measured depth) None Description summary of proposal .X 13. Attachments 14. Estimated date for commencing operation December 23, 1991 Date approved 16. If proposal was verbally approved Name of approver Cemented Measured depth True vertical depth Surface 115' 115' Surface 2696' 2373' T0C @ 3900' 5797' 4504' RECEIVED DEC 1 6 1991 Alaska 0il & Gas Cons. C0mm~ss~0~ Anchorage Detailed operations program BOP sketch 15. Status of well classification as: Oil__ Gas . Suspended ~ ~g31~ Service 17. I hereby certify that the fore~loing is true and correct to the best of my knowledge. Signed/~r~,~./3--~,/ B~-'G. Augustine Title Sr. Production Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test Location clearance Mechanical Integrity Test ~.. Subsequent form required 10---~ ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner Approved by order of the Commission .~,pproved Copy Returned Date j,~. ic~, cjt Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MILNE POINT UNIT ~-7 COMPLETE AS INJECTOR SUMMARY PROCEDURE 1. MIRU EWS #4 rig. 2. ND production tree. NU and test BOPE. 3. RIH with bit and scraper to PBTD. Pressure test casing to 1500 psi. Reverse circulate hole and pump cleanup pills. POOH. 4. MIRU electric line unit. RIH with cement evaluation log and POOH. RIH with continuous gyro and POOH. 5. RIH with wireline perforating guns. Perforate the following intervals with 5 SPF: 5176'-5188', 5220'- 5238', 5257'-5262', 5286'-5326', 5398'-5446', and 5494'-5534'. POOH with guns. 6. RIH with packer on electric line. Set packer 50' above perforations. 7. RIH with seal assembly on 2-7/8" tubing. 8. Space out tubing. Circulate in packer fluid. Sting into packer and land tubing hanger. Pressure test casing-tubing annulus to 1500 psi. Pressure test hanger to 5000 psi. 9. ND BOPE and NU production tree. RDMO rig. 10. Prepare well for injection. BGA- 12/15/91 Atasl~ Oit & (~as Cons. ~nchomge Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 July 22, 1991 Mr. David Johnston Commissioner, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: RE: Applications for Sundry Approval Attached please find Applications for Sundry Approval for Wells G-6/7. These wells are located on the Milne Point Unit. If you have any questions or require additional information please contact me at 564-7617. Yours very truly, Bob Soptei Environmental Coordinator RJS(bgs) Attachments cc G-6 Well File G-7 Well File C:\DATA\WP51 \FUS\AOGCC 13.RJS RECEIVED J U L 2 4 t991 Alaska Oil & Gas Cons. Commission Anchorage AI.~SI~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of ReqUest: Abandon Suspend Operation shutdown Re-enter suspended well . Nter casing __ Repair well __ Plugging__ Time extention Stimulate Change approved program __ Pull tubing m Variance __ Perforate X Other 2. Name of Operator Conoco Inc. 3. Address 3201 C Street, Suite 200 Anchorage, AK 99503 5. Type of Well: Development Exploratory Stratigraphio Service 4. Location of well at surface 3288' FNL, 3393' FEL~ Sec. 27, T13N, R10E, Umiat Meridian, NSB, AK 6. Datum elevation (DF or KB) KB 35 AGL 7. Unit or Property name 'Milne Point Unit 8. Well number G-7 At top of productive interval 800' FNL, 2000' FEL, Sec. 27, T13N, R10E, Umiat Meridian, NSB, AK At effective depth At total depth 348' FNL, 1767' FEL, Sec. 27, T13N, R10E, Umiat Meridian, NSIB, AK 9. Permit number 91-25 10. APl number 50-029-22140 11. Field/Pool feet Kuparuk River/Schrader Bluff 12. Present well condition summary Total depth: measured 5815' feet true vertical 4517' feet Effective depth: measured feet true vertical feet Casing Length Size Structural Conductor 115' 13-3/8" Surface 2490' 9-5/8" Intermediate Production 5797' 7" Uner Perforation Depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Plugs (measured) Junk (measured) Cemented Surface Surface TOC @ +_. 3900' Measured depth 80' 2940' 5797' True vertical depth 80' 2400' 4504' RECEIVED J U L 2 4 t991 Alaska 0il & Gas Oons. um~misSio~ Anchorage 13. Attachments Description summary of proposal X Detailed operations program BOP sketoh ~ Complete well. Perforate intervals within 5175' - 5540' (gross). Fracture and gravel pack as necessary. 14. Estimated date for commencing operation August 15, 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil · Gas m Suspended X 17. I hereby certify that the forego, ing is true and correct to the best of my knowledge. Signed '/~*/~(-~. ~ B.G. Augustine Title Senior Production Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity. BOP Test ~ Location clearance Mechanical Integrity Test Subsequent form required 10- ~O¥ Approved Copy Original Signed By Returned, David W. John~tor~ Approved by order of the Commission -'"] / ~ I' Form 10-403 Rev 06/15/88 Date 7/22/91 Commissioner TO: Alaska Oil & Gas DATE: June 17, 1991 Conservation Commission Attn: Mr. John Boyle 3001 Porcupine Drive Anchorage, AK 99501 TRAINS #: AK-MM-910513 RE: CONOCO Milne Point G- 7 The following technical data is being submitted herewith. Please acknowledge receipt by signing and returning a copy of this letter to the address· printed below, attention E.A. Opstad. Well G - 7 ENCLOSED INFORMATION SUMMARY MD: 1 Set BId~lines 1 Set F~lded Sepias TVD: l~Set Bluelines i~?~ Set Folded Sepias LIS Tape: 1 Each RECEIVED JUN 1 8 1991 Oil & Gas Cons. Commission Anchorage Received By: /~~[.)~ · ~r[~~ Ai~sl~a Oil & Gas Conservatio~n"Commission - Date 5631 SilveradoWay, Suite G · Anchorage, Alaska99518 ° (907)563-3256 ° Fax(907)563-7252 A Baroid Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: Receipt of the following material which was transmitted via is hereby acknowledged: QUANTITY DESCRIPTION RECEIVED: DATED: Copy sent to sender YES NO , STATE OF ALASKA ~ ALA~ OIL AND GAS CONSERVATION COMMlu$1ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing ..... Repair well Change approved program Operation shutdown X Re-enter suspended well Plugging m Time extention Stimulate__ Pull tubing Variance Perforate Other m Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 5. Type of Well: Development X Exploratory Stratigraphic Service Location of well at surface 3,288' FNL, 3,393' FEL, Sec. 27, T13N, R10E, U.M., NSB, AK At top of productive interval 800' FNL, 2,000' FEL, Sec. 27, T13N, R10E At effective depth At total depth 384' FNL, 1,767. FEL, Sec. 27, T13N, R10E 6. Datum elevation (DF or KB) KB 35' AGL feet 7. Unit or Property name Milne Point Unit 8. Well number G-7 9. Permit number 91-25 10. APl number 50-029-22140 11. Field/Pool Schrader Bluff 12. Present well condition summary Total depth: measured 5815 feet true vertical 4517 feet Plugs (measured) Effective depth: measured feet true vertical feet Junk (measured) Casing Length Size Structural Conductor 115' 13-3/8" Surface 2,490' 9-5/8" Intermediate Production 5,797' 7" Uner Perforation Depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Cemented Surface Surface T.O.C. @__+ 3,900' Measured depth 80' 2,940' 5,797' True vertical depth 80' 2,400' 4,504' JUN :L Gas Cons. Commission /mchora~a 13. Attachments Description summaryof proposal X Shutdown Drilling Operations. Pending Completion. Detailed operations program BOP sketch 14. Estimated date for commencing operation July/August 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas__ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~. ~'. ~/~- R.S. RossbergFOR COMMISSIoNTitle Sr. DrillingusE ONLyEngineer Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Test Location clearance Meohanieal Integrity Test~ Subsequent form required 10- Approved by order of the Commission Date June 11, 1991 I Appr°val N°' ~/~;2/- ApproveCt GoP¥ ORIGINAL SIGNED BY ~ReturneCt L0.. E C. ? / ~mmi~ioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE SCHLUM~ERGER. i~. WELL SERVICES 900 W. ,NTI~I~NATIONAI. ^IFIP~FIT ANCHORAGE, ALASKA 99518 5383 COMPANY LOCATION ' ATTENTION · WELL NAME · NO. OF BOXES' JOB NO. · ADD'L TAPES WELL NAME · SERVICES · AL, AS~G~ OIL & GAS CONSERVATZON CCMHISSION 300.1 PORCUPINE DRIVE JOHN BOYLE MPU G-7 I OH LIS TAP/~' I RFT FIELP TAPE COPY ONE .~ 74591~ WELL NAME · SERVICES · NO. OF BOXES: JOB NO. ' · *SEE ABOVE ADD'L TAPES ' WELL NAME ' SERVICES · COMPUTING CENTER PRINT CENTER NO. OF BOXES: JOB NO. · ADD'L TAPES ' NO. OF BOXES' JOB NO. ADD'L}TAPES WELL NAME · SERVICES ' WELL NAME SERVICES NO. OF BOXES' JOB NO. · ADD'L TAPES · SCHLUMBERGER COURIER: DATE DELIVERED: JOB NO. ADD'L TAPES NO. OF BOXES: · '~, -- ) ~ ~EOEIVED ' . '~ -""~10~ ALASKA OIL AND GAS CONSERVATION COMMISSION April 8, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 R. S. Rossberg Senior- Drilling Engineer Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503 Re.' Milne Point Unit G-7 ReVised Conoco Inc. Permit No. 91-25 Rev Sur. Loc. 3235'FNL, 3451'FEL, Sec. 27, T13N, R10E Btmhole LOc. 393'FNL, 1757'FEL, Sec. 27, T13N, R10E Dear Mr. Rossberg: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated February 22, 1991 are in effect for this revision. Sincerely, ~rman Alaska ' n Gas Conservation Commission dlf Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-76OO April 4, 1991 David W. Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive AnChorage, Alaska 99501-1433 RE: Milne Point Unit Wells G-5, G-6, G-7, and G-8 Revised ApplicationS for Permit to Drill Dear Mr. Johnston: Attached are revised Applications for Permit to Drill (Forms 401 and attachments) requesting approval to drill Milne Point Unit wells G-5, G-6, G-7 and G-8, located in tract 14 of the Milne Point Unit. The Commission had previously issued permits to drill these wells on February 22, 1991. The proposed revisions are being submitted to reflect changes in surface location, in addition to the surface location, the target and bottom- hole location was changed for well G-6. Surface location changes were necessary to minimize modifications to the flowlines and to more readily accommodate future workover operations on the existing pads. The changed bottom-hole location in well G-6 is based on revised structural interpretation. If there are any questions pertaining to these wells please call me at 564-7637 or Mike Stockinger at 564-7609. Very truly Yours, R. S. RoSsberg Sr. Drilling Engineer RSR/jod cc: MPS file: 500.21.08 C:\data\wp51 \rsr\revgpa~ la. Type of work Drill Re-Entry STATE OF ALASKA ' : ALASK~,_iDIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Redrill %I lb. Type of well. Exploratory ~ Development Oil ]~ Deepen Stratigraphic Test~ m Service _-- Developement Gas '~_ Single Zone l~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Conoco Inc. KB 35' AGL feet Kuparuk River ~ 'Field 3. Address 99503 6. Property Designation Schrader Bluff Pool 3201 C Street, Suite 200, Anchorage, Alaska ADL 25906 7. Unit or property Name Milne Point Unit 4. Location of well at surface * ' 3235;.!-FNL, 3451'. FEL, SEC. 27 T13N, RIOE, At top of productive interval U.M , NSB, AK 800' FNL, 2000'FEL, SEC. 27, T13N, RIOE Attotaldepth 393' FNL, 1757" FEL, SEC. 27, Ti3N, RIOE 12. Distance to nearest property line 8560 feet 13. Distance to nearest well 60 feet 16. To be completed for deviated wells Kickoff depth 50. feet Maximum hole angle 46 * 8. Well number 6-7 9. Approximate spud date APril 24, 1991 14. Number of acres in property 2560 11. Type Bond (see 20 AAC 25.025) Blanket Number 8086-15-54 Amount $200,000 15. Proposed depth (MD and TVD) 5824'MD.~/.4.5097~ TVD feet 17. Anticipated pressure (see 20 AAC 25.035 (eX2)) Maximum surface 1850 psig At total del)th CrVD) 1950 18. Casing program size Hole .Casing 30" 13-3/8" 12-1/4" 9-5/8" 8-1/2" 7" " Specifications 54.5 F-55 IWeld ! so_.' 36 ~K-55 IBTTS [2755' MD 35' 35' 35' Setting Depth Top Bottom I TVD,, I, MD i TVD 12790'! 2 00' 35' 1 5824~'! i 4509' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Quantity of cement (include stage data) ± GO0 SX Permafrost "C" 700 SX Permafrost"E"~ 3,00,5 300 SX "6" · Downsqueeze ± 400 SX "C" Permafrost 1 60 bbl Diesel or Crude Effective depth: measured feet Junk (measured) true vertical feet Length Size cemented Measured depth True Vertical depth RECEIVED APR - ,5 t991 Alaslm Oil I Gas Cons, c mmiSSto Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Pit Sketch 20. Attachments Filing fee ~ Property plat X~] BOP Sketch ~ Diverter'Sketch '~. Drilling program]t2 Drilling fluid program rx Time vs depth plot ~ Refraction analysis [] Seabed report ~ 20 AAC 25.050 requirements 21. ! hereby certify that the, foregoing is true and correct to the best of my knowledge Signed ~ ?//. l,~ R. S. RossbergcommissionTitle useSr'onlyDrilling Engineer Date 4/3/9.~.. .... '~/-,,~ 50--~.Z<~- ~ ~--//---¢'o 02/22/91 for other requirements Conditions of approval Samples required ~ Yes ~No Mud Icg required ~ Yes ~ No Hydrogen sulfide measures ~ Yes ~ No Directional su~ey required ~ Yes ~ No Required working pressure for BOPE ~2M;' ~ 3M; ~ 5M; ~ 10M; '~ 15M ~ by order of Alppro~e ~-- Commissioner the commission Form 10-401 Rev. 1~- ~ ' (llCll Date ?,~,/¢! Submit in triplicate NOTES: si 8'5'42" .' ~II~IE POINT UNIT ~ G PAD 1. STATE PLANE COORDINATES ARE ZONE 4. ] [ MI~E~~ ~POINT ...... ~[ ~C~~BAy 2. ALL GEODE~C POSI~ONS ARE BASED ON ~ ./~ S PI N~ ~ PRUDHOE BASED ON PRO~AC~D VALUES OF ~E SEC~ON CORNER POSI~ONS. < MILNE PT. VICINITY MAP MILES G PAD ~t~ LocATIoN- IN SEC. 27, T. 15 N., R ~0 E., U.M. ~ ~, ~ ~" PROPOSED ~-6 I ~9~' FNL ~' FeL ~ ~'~ ~- - ~A~AN~iUN G-8 I 3~76' FNL 3a59' FEL ~ " - STATE PLANE COORDINATES-ZONE 4 )~ ~ ~~lV' i i [ ~ 0-6I' y 6,0:a,~20.66 x ss:,~eo.ss ~ ~ ~a~ / , G-8 j Y 6,014,539.45 I X 557,1~3.43 ~~~ ~a~ 0ii & Gas ~ns. ~1 ~ ~homge ;t l; GEODETIC POS'TIONS N4D 1927 ~ I]1 . ~, WE'lL I: NORTH ~'A~TUDE ] WEST LONGI~DE LEGEND 00.9 . G-6 70' 27' 00.126" 149' 52' 01.150" 0-7 70' 27' 00.710" 149' 32' 01.585" 0-8 70' 27' 01.295" 1~9' 32' 01.620" ~ EXISTING WELL ~ ~o~o~,~ w~,. PROPOSED WELL LOCATIONS F. ~ober~~' Z~I~,I~[, '~ i~/ SURVEYED FOR: ~.~s ~ ~o ~r~s JOB NO.: 90-059 ~s ~c~c ~L~. ~ ~o~ SCALE: i" = 300' , 3500 ( 3400 3300 3200 ( 3100 3000 2900 00 - - - - - -- - - - - - - 3000 (I) / 0 - 0 / N CX) \ / : 00 I ~ 1 1 00 J 1 30 1 900 3100 \ / I \ / '900 / (~ I ~~~/ J 1 1 00 00 1700 PAD G 3200 I /900 , I 8500 ;00 I 8 St)0"" VOU'" ð5°0... f30-0 - - ..... TS'UO- - - - -8¡TOO - _. - 1 3300 1300 I ~OO I I 3400 I I I >00 I I 3500 R'E@EIVED I I I APR - 5 1991 Alaska 011 & Gas Cons. Commission I >00 3600 I Anchorage I I 500 I I 1100 "00 I 3700 I 1300 I 300 - - - - 0- - - - - - - - - 3800 3500 3400 3300 3200 3100 3000 2900 CONOCO S}ructure ' Pad G Well ' 7 · Field ' Milne Point Unit Location ' North Slope, Alaska 200 4O0 6OO 8OO 1000 - 3600- 4000 Iru reated by : jones For' S ROSSBERG ate plotted .' 27--Mar-91 lot Reference is 7 Version oordinates are in feet reference slot t7. e Vertical Depths are reference wellhead I~J~EASTMAN IZ~CHRISTENSEN 4200¼ 4400~ KOP TVD=500 TMD=500 DEP=O 3.00 N 50 DEG 47 MINE 2835' (TO TARGET) East--> 200 400 600 800 1000 1200 1400 1600 1800 !I I! I ! II II II II II ! 5000 _ jT~LOC~T,O.: I 595' F'NL, 17,57' FEL J SEC. 27, TJ3N, RlO£J _ -2600 _ -2400 TARGET LOCATION: J - 800' FNLo 2000' FELJ SEC. 2'7. T15N, R~O£J -22~x~ 'P~/D- 4050 -2000 TMD-5165 ; 9 O0 DEP -2835 ~ ' NORq'H 2435 ' A EAST1451 -1800 21 ,~ - -14~ Z - 0 27.00 33.~ _ ~ 39.00 -~o~ ~ - ~=1873 TMD=2032 OEP=585 - 9 S/8'~SO PT ~ ~ I su~c[ t~:I ~ 13235' mL. 3451' ~LI I SEC 27 T15N AVERAGE ANGLE % - , , TARGET / N SNDS ~D=4050 TMD=5165 DEP=2S55 N~OII & Gas ~ns. Commission Scale i ' i00.00 OB SNDS TVD=4270 TMD=S¢81 DEP=3062 ~ B/ OB SNDS TVD=4300 TMD=5524 OEP=3093 ~ ~x TD / 7"CSG PT fVD=4509 TMD=5824 DEP=3509 '~ i 1 I i t I I i I i I i i I 'TI i ]-- I I I 1' i i I I I t I I --T I T--] 200 4C%9 600 800 1 OO0 1200 1400 1600 1800 2000 2200 2400 2C, GO 2800 3000 3200 3400 Vertical Section on _30.79 azimuth with reference 0.00 N, 0.00 E from slo~ #7 ALASKA OIL AND GAS CONSERVATION COMMISSION February 22, 1991 WALTER J. HICKEL, G~OVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 278-7542 R. $. Rossberg Sr. Drilling Engineer Conoco Inc. 3201C Street, Suite 200 Anchorage, AK 99503 Re: Milne Point Unit G-7 Conoco Inc. Permit No. 91-25 Sur. Loc. 3288'FNL, 3393'FEL, Sec. 27, T13N, R10E, UM Btmhole Loc. 384'FNL, 1767'FEL, Sec. 27, T13N, R10E, UM Dear Mr. Rossberg: 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. The Commission will advise you of those BOPE tests that it wished to witness. Sin.cerely, -Lonnie C.~ith, Commissioner Alaska Oil and Gas Conservation Commission dlf/enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ,,-% ALASKP~tL AND GAS CONSERVATION (--.__ MMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill Y Redrill lb. Type of well. Exploratory ~_ Stratigraphic Test .~. Development'Oil Re. Entry -- Deepen Service -- Developement Gas ~_ Single Zoner 2. N'ame of Op;~rator 5. Datum Elevation (DF or KB) 10. Field and Pool Conoco Inc. KB 35' AGL feet Iuparuk River Field 3. Address 99503 6. Property DesignatiOn Schrader Bluff Pool 3201 C Street, Suite 200, Anchorage, Alaska ADL 25906 ,, 4. Location of well at surface" 7. Unit or property Name 11. TyPe Bo~ld(see 20 AA(~ 25.025) 3288' FNL, 3393' FEL, SEC. 27 T13N, RIOE, Milne Point Unit Blanket At top of productive interval U.M., NSB, AK 8. Well number Number 800' FNL, 2000~FEL, SEC. 27, T13~, RIOE G-7 8086-15-54 , At total depth 9. Approximate sptJ'd date Amount 384' FNL, 1767' FEL, SEC. 27, T13N, RIOE April 24, 1991 $200,000 ":1'2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property lg~ Proposed depth (MD and TVO) property line 8560 feet 60 feet 2560 5838'MD/4.508'TVD feet '16. To be 'completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 Kickoff depth 50 it~eet Maximum hole angle 46 o Maximum surface 1850 psigAttotaldel:)thO'VD) 1950 psig 18. Casing program l .' Set'ting Depth ......... size Specifications Top Bottom Quantity of cement H'ole Casing Weight Grade Coupling Length MD TV'D MD TVD (include stage dat~)' ~'0,, 13_3/8" ~54.5 K-55 Weld 80' 35' 35' 115' 1~5' + 600 SX permafrost ,,C,, " 12-1/4" "'9-5/8" 36 K-55 BTTS 2758' 35' 35' 2793' 2400' ~ 700 SX Permafr0.s..t."E",. 300S 8-172'' 7" 26 L-80 BTTS 5803~' 35' 35' 5838' 4508' ., -~ ;t;; 300 5~ "C" .. 19. TO be C'~mpleted for Redrill, Re-entry, and Deepen Operations. " Downsqueeze Present well condition summary + 400 SX "C" Permafrost Total depth: measured feet Plugs (measured) 1 60 bb] Diesel or Crude true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size cemented Measured depth True Vertical depth Structural Co'nductor RECEIVED Surface Intermediate FEB 1 4 1991 Production Liner .~[ask~ ~ 0il & Gas Cons. Perforation depth: measured ~._~d~. ~ '~ true vertical Pit Sketch 2'0. Attachments Filing fee [I PrOperty plat ]~ BOP Sketch ~ Diverter Sketch ~ Drilling prograr~ ][~ ' ' Drilling fluid program rx Time vs depth plot ~1 Refraction analysis [] Seabed report r-i 20 AAC 25.050 requirements 21. I hereby certify that the, foregoing is true and correct to the best of"my knowledge ...... i< S (~~.,.-~tr R. S. R. ossberg Title Sr. Drilling Engineer ,., Date2/13/91 Signed Commission Use Only Permit Number I APl number IAppr°val date See c°ver letter ~1-- ~.~ 50--02.9 -~?--/~ o 02/22/91 for other require, m~nts .. Conditions of approval Samples required ~ Yes I~'lqo Mud log required ~ [] YeS Hydrogen sulfide.measures ,~ Yes I~I~1~o Directional survey required I~Yes [] No Required workingpressureforBOP, E ~!!~'2M; ~ 3M;' l--1 5M; [] 10M; [] 15M Other: ~.~.- ~/.~,.' ~ by order of Appro~,~ed by ( Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT G-7 Conoco Inc. 3201 C Street, Suite 200 Anchorage, Ak 99503-3992 I. Casing and Cementing Program CASING PROGRAM Hole 'Size Casing Size Depth Weight Grade (Inches) (Inches) (ft) (DDf) Conn 30" 13-3/8" 115 ' 54.5 ppf K-55 WELD 12-1/4" 9-5/8" 2,'793 ' 36 ppf K-55 BTTS 8-1/2" 7" 5,838 ' 26 pp f L- 80 BTTS ao The 13-3/8" conductor will be set at 80' below ground level then cemented to the surface with ±600 sacks Permafrost type IfCt! · Bo The 9-5/8" surface casing will be set approximately 500' below the base of the permafrost at 2,793' MD/2,400' TVD and cemented to surface. The cement slurry will consist of a lead slurry of approximately 700 sacks Permafrost Type "E" followed by a class "G" tail of approximately 300 sacks. A top job utilizing Permfrost Type "C" cement will be performed if cement is not circulated to surface. Co The 7" production casing will be set at 5,838' MD/4,508' TVD or approximately 300' below the base of the Schrader Bluff "0" series sands. Class "G" cement (approximately 300 sacks) will be circulated from the 7" shoe to 500' above the top of the Schrader Bluff "K" series sand. After the 7" casing is set, the drilling rig will move off and the well will be completed using a work over rig. II. Drilling Fluid Program A. 0 - 500' 9.0 ppg freshwater spud mud. B. 500'- 2,793' 9.0 ppg - 9.2 ppg freshwater spud mud. C. 2,793' - T D 9.2 ppg - 9.4 ppg dispersed. Conoco Inc. Supplemental Data Sheet Well G-7 February 1991 Page 2 III. Drilling Program Conoco Inc. proposes to drill MPU well G-7 to continue development of the Schrader Bluff Pool at Milne Point. The mud system will consist of a fresh water spud mud (9.0 - 9.2 ppg) from the surface to the 9-5/8" casing point at approximately 2,793'. A low solids, non-dispersed system (9.2 - 9.4 ppg) -will be used frOm 2,793' to the 7" casing point at 5,838' T D. Single shot surveys will be taken at the 9-5/8" and 7" casing points. MWD surveys will be taken every 30' in the build interval and every 100' in the vertical and slant sections. A gyro survey will be run from T D to surface at the completion of the well. All surveys will be referenced to the Section Grid System and corrected for magnetic declination. A complete set of open hole logs will be run from T D through the top of the Schrader Bluff interval. A 20", 2,000 psig diverter will be installed on the 13-3/8" conductor for drilling surface hole. A 13-3/8", 5,000 psi RSRRA BOPE stack will be nippled up to the surface casing for drilling the production hole. Pressure tests and function tests will be performed on the pressure control equipment as per State Regulations. Maximum downhole pressure is estimated at approximately 1,950 psig and based on initial reservoir pressure. Maximum surface pressure is estimated at 1,850 psig, based on an unexpanded gas bubble with temperature effects not taken into account. The closest wellbore is MPU well G-6 with 60' of closure at the surface. Approximately 400 sacks of Permafrost Type C cement displaced with dead crude and/or diesel will be pumed down the 7" x 9-5/8" annulus for final arctic pack and freeze protection after disposing of excess drilling fluids. RECEIVED FEB 1 4 t9 J1 Nas a ,Oil .& Gas Cons. Conoco Inc. Supplemental Data Sheet Well G-7 February 1991 Page 3 WELL PROGNOSISAND DRILLING PROGRAM ..TVD MD FORM 500 500 GRAVEL 994 1000 SAND/SHALE 2400 2793 CASING PT · 3560 4533 K TOP 3805 4845 M TOP 4050 5176 NA TOP 4205 5400 OA TOP 4270 5494 OB TOP 4300 5537 OB BASE 4508 5838 T.D. BIT TYPE WT YP PV VISC FL 5-1-5 SPUD 9.0 100 20 100 15 5-1-5 SPUD 9.0 100 20 100 15 5-1-5 SPUD 9.0 25 15 60 15 4-3-7 LSND 9.2 25 15 60 15 4-3-7 LSND 9.2 15 12 45 8 4-3-7 LSND 9.4 12 8 35 6 4-3-7 LSND 9.4 12 8 35 6 4-3-7 LSND 9.4 12 8 35 6 4-3-7 LSND 9.4 12 8 35 6 4-3-7 LSND 9.4 12 8 35 6 True vertical depths are based on a sub-surface datum. The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300' TVD a Sundry Notice will be submitted. R '¢EIVED FEB 1 4 t 91 J~ & .Gas Cons. Commission 23 24 ~M:>L-2S514 2S80 AC -- .... 30 ADL-2S5 18 2544 AC _ C~'YRON ~) 30 2~ 2235 AC ADL-47437 2560 AG (~) CHEVflOH CHt¥. A~CO BP IOaIO lo 2E ADL-47438 2544 , , · 29 30 31 32 21 ~DL-4743~ 1200 AC 22 AOL-315840 /1280, _ AC[ · EXHIBIT A MILNE POINT UNIT AREA 0 I 2 MIIoI _l __ III ; '" f . iii i i ii NOTES: u~.N~ PO~ uNrr I. STATE PLANE COORDINATES ARE ZONE 4 O8°O5'42' 2. ALL GEODETIC POSITIONS ARE BASED ON ... N.A,D. 1927~~j/~ 3. OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES O1: THE SECTION CORNER POSTIONS r'~- MILNE PT. VICINITY MAP z 30'~ ~ " LOCATION IN ~=_,____ : _ '~,-- SEC. 27, T13N, R1OE, UMIAT MERIDIAN .j ~' ] ~' WELL FROM NORTH LINE FROM EAST LINE · ,,-~0 o__.._~0_ ~ 6-,~ 3,~66' 33?0' (j, G-8 ~ ,,,x ,,,z O~ o .... ~ ~ G-5 3487' 3377' z ~-7 ~) G-6 3347' 3385' ~- L._ G-7 3288' 3383' .-_ _ ' -I --1 e-* I b Ii::) 3o'~ ~'"~"'- I ·--~--~--'°'~ ,,.10 STATE PLANE COORDINATES-ZONE 4 G-4 ~"~:)'~ WELL NORTH (Y) EAST (X) z ~-3 6, 01~, 190, 03' 557, £~3.78' J G"5 6,014,308.51' 557,226.72' I ~, r~b ~-6 6,014,368.30' 557,218.28' I j~ , G-8 6,014,487.10' 557,201.39' .I ~~~ ~~ GEODETIC POSITIONS NAD 1927 W~L NOETH LATI~DE WEST LON~E 10' G-5 70" 26' 59. 022' 149'31'59.222' [ G-6 70~ 26'59.607' 149'31'59 453' M~. ' ~I~J1~_ 290' _~ ~ G-7 70~ 27' 00 .192' 149'31'59.685' ~ LEGEND I TYPICAL o PROPOSED N~ WELL 8ECTION NO SCALE * EXISTING WELL CONDUCTO~ (LOCATION AS-BUILT) PROPOSED PAD EXTENSION~ ~~_ ~ ~ ~ ~ ~OB NO. ~ ~ ~ ~ 8gALE 1':2OO' FRB.8~OZ )~LLOC Nas .aas :Cons. CONOCO ]NC,--NABOR S RIG 27E 13-5/8" 5800 BOP SYSTEM Flll Line AFl 13-~8' ~1 Ali 13-,~8~ ~ APl 13-~B' ~ All 13-5/B' ~ API 13-5/8' 5M x 11" ~ APl 11" 5H Thre~led Connectlon m ~ Flow Line Annular Prevmtar R~m Rsm Rom C'hoke Ltne: 3" 5000~ Manual Gate VaLve -' & 3" HCR VALVE Ktt[ Ltne~ Two 3" 5000ff Hanua[ Oate VaLves" Tubing Spool w/ 2"-5000~t Side Outlets Casing Spool w/ 3"-5800~ Side Outlets 9-5/8" Surface Casing 13-3/8" Conductop Casing I, BOP STACK SIZE RAT]NO MEETS AP] RP53 & SPEC 6A FOR CLASS 5M 2, BOPE TO BE OPERATED EACH TRIP AND TESTED WEEKLY, 3, BOP HYDRAULIC CONTROL SYSTEH TO INCLUDE (5) STAT]ON CONTROL HAN]FOLD LOCATED REHOTE WITH t60 GALLON ACCUMULATOR, RESERVOIR UNIT, & AUXILIARY ENERG'( SOURCE FOR SYSTEM ACTIVAT]ON, q-, HINIHUH ONE SET BLIND RAHS & TWO SETS APPROPRIATE PIPE RAHS, 5, CHOKE & KILL MAN]FOLDS SHOWN SEPARATELY TO HEET APIRP 53 CLASS 5H REOU]REHENTS, · . KILL MA~'?IF'OLD FROM REI~IOTE HIGH PRESSURE PU~P '""' NOTE: L NY'Jm~UL)c CC.~TIi"~L StStl:¥ fO~ I~ ~&c~ & CMC~ RE~IOTE PRESSURE G'.tSE SENSCR HYCR,tULIC CONTROLLED REMOTE OPERATED DRILLINg SPOOl. HYDRAULIC CONTROLLED R E:),IOTE OPERATED REMOTE PRESSURE GAGE SENSOR ADJUSTABL~ CHOKE ADJUSTABLE CHOKE CHOKE ~,IAraIFOLD VARI,tBLE CHOKE CONTROL --.. TO SHgLE t BLEED LINE 10 PiT 1 TO AT~.OS?HERIC ~UD/GAS S£1::AAATOR RE'¢EIVED FEB 1 4 1991 Alaska 0il & Gas Oons. CommiSs'lo' ~nchorafle _ CHCKE 8 KILL NIAI';IFOLDS FOR q'S/8'~ 8 7" OD C~XSI~'~G BOP ST~.CK BOP t,(Ar,IIFOLD LAYOUT-CONOCO, INC. : CONOCO, INC. MILN[ POINT UNIT ?.,, DIVERTER STACK FOR 13 3/8° CONDUC]'OR ~,~¥[tT[ll QuICk, ¢C)~qNI:CT ASS[uhl -. t3 )/I' CLSIhG RECEI'V -D Alaska Oil ~ Gas Cons. 1. The hydraulic eontpol sys%e~ will be in accorda~e with AP1 specifications and ~ pequire~ents. 2. The HCR valve will open ~hen the ppuventer' 10" pelief line Hill pun off of ~he dpilling spool HCR valve and Hill have a ta~-geted downstream te~ fop downwind diversion. Valves on both sides of the tee ~tll be full opening ar~l linAed together' ~:o enable one to al~ays be and the othe~ to be closed. : I ._! d r i p- W W b_ O. W MPU WELL G ? DEPTH vs TIME O, .i ; | -1000 -r ............. i ii ............. '."", ..... '?-"X . ..... 1 . ............. ~ . .............. ' ............. ', , : I I I l I o I I I I l I I e I I · I I ! I I I ~.,I I I I I I I I I I Ill i i i i lo ! I i I qi I I ! I ! Il IIIIIll ~ Ill Of ! I ! ! I i ! I ii,.~! O I I. I IIII ! ! I I ! i I ! I !! ! I ! I I I I I I ! I I I I I I I I e I I I I II I ! I I I II II I O I I I ! ! I II I I t I I I t Il I II I I t I ! I II II !1 e I . . . . _. . . . i I i i I I ii i I. I I Il ! i ! ! i lO iii i i i I I i ! it Idll I i i i~ ! i i I t i i I ! ! I i I ,ll~1,111 i I I ! ! i I i i I Ill i ! Il I ! I ! I I ! i I i Ililllll I ! I I I ! II , I I O I O II I I I I I ! t t I I ! I I ! I I I II I I I I I II I II I ! I I I ! I II l I I I I I (I t I I I I I I ! I I I I I I I I I II I I I II I II I !1 I I I I ! I I II IIII1(11 III ! I III Il III !1 ~lllllllll I I ! il I Ill I I1 I I I !1 i ! "11 ! i ! I i I ! Ill I i I .~11 I I!! Ildll I I I I ! i Illlll I I 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 I I I I I I I I I I II I I I I I e I I I I I I I I ! 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 II I I i i i I i i i i i i i i i O 1 2 3 4 5 6 7 8 9 10 TIME (DAYS) CONOCO, Inc. Structure ' Pod G Well ·-7 Field · Milne Poinl Unit Location · North Slope, Alaska o o · ' 200 .- 400 RKB Elevation.' 59.27' 600 KOP Tvd=500 Tmd=500 Dep=O 3.00 N 29 DEG 15 MINE 2851' (TO TARGET) ,..,:,oo.oo East--> 0 200 400 600 CO0 1000 1200 1400 1600 1800 I I II II II I I I I II II II I TD Location;] -500O 384' FNL. 1767' FELl . Sec, 27. T13N. RIOE/ -28OO -25OO TARGET Location: -2400 800' FNL, 2000'FEL Sec. 27. T13N. RIOE -220O ,aaa: TARGET / N Snds 4400: Tvd=4050 Tmd=5177 Dep=2851 ~ OA Snds Tvd=4205 Tmd=5401 Dep=3013 ~ OB Snds Tvd=4270 Trod=5494 Dep=3081 ~ B/ OB Snds Tvd-4300 Tmd-5538 Dep-3112 ~. "rD / 7" Liner Tvd=,4508 Tmd=5838 Dep=3328 ~ i t i i t i t 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 4~0o 4~00 420o 4~0o 3~0 3~0 3~00 32oo 3oo0 2~00 2~o 2400 2200 zooo ~soo ~0o ~oo 12oo ~ooo Vertical Section on 29.2~, azimuth with reference 3288.00 N, 3393.00 E from slot -Scale 1 ' 100.00 TARGET / N Snds ' 800 9 O0 Tvd=4050 ~ · Trod-5177 -20GO \ Oep=285, A \ North 2488 I 1 GOO \ 15.00 E~3st 1393 - 1800 - ~ Build 30eg/lO0 Ft ('") ,400- ~ 27.00 -,400 Z 1800- 2000- 2200- - 9 5/8" cst Pt - o 280e- AVERAGE ANGLE M S.~o¢. Location 3GOO- 46 DEG 11 MIN ~ .3288' FNL 3392' 340O- K Snd, Tvd=3560,~,=.~, Oe.=2.., ~ ~ FEB 1 4 t991 M Snds Td 5v- 805-- Tmd--4823 Dep=2596 ~ ..... .. ~!asKa .Oil & 6as .Cons. 3500 340~~ ~ooo ~ ! ~ --- I ~ ' \ ! I \ ,,' 1 SO0 3300 3200 31 ~0. 30013 I I I 2900 I II 1300 '/ I 190,~ 3~ oo I ~x~ ~ ~ I ' I '{\i 1 o0 '~ 1300 P AD 9 I 3200 _ I t~,9oo -l'/ oolX°° · so~ ~ I ~ ~ 900 -- 33oo _I ~soo / ~400 [ F 9oo~ · ~,oo ~,~oo .... .~ m ~soo . I ~,oo RECEIVED I I ~o~ F~B ~ 4 I Naska 0ii & Gas Cons. Com~ts~to~ 'Anohomge 3SO0 _I 0 o0 - I ' ~ ~ o I ...... ~ ~ ~ sOO ......... . -. I I i I I I ''~ 3;700 _ 3800 3500 3400 33;00 3200 31 O0 3000 2900 30( .31C 32C 33( 34C 35( 36C 37( 38( ** CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee ~ ['2 ~hru ~ ' '' (3) Adm!n [9~~t ru [10 & 133 (4) Casg ~-~:~,~-~ //-S-~ ! 1'14 thru 22] (5) BOPE ~/.~,~/ //,~'-~/ i, i [23 thru 28] (6) Other [29 thr'u 31] (6) Addl Company 1. Is pemit fee attached ............................................... 2. Is well to be located in a defined pool .............................. j~ 3. Is well located proper distance from property line ................... ~ 4. Is well located proper distance from other wells ..................... ~ 5. Is sufficient undedicated acreage available in this pool ............. ~ 6. Is well to be deviated & is well bore plat included ................... 7. Is operator the only affected party.~ ................................ 8 Can pemit be approved before 15-day wai~ Lease & Well YES NO ,, · , e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. ~23. ~/24. 26. ~27. 28. 29. 30. 31. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~rnber appropriate ......................... ................. ~__ Does well have a unique name & ngmber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... ~,~ .. Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ..... · ........................ , ,, Is a d iverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... ..~ .. · Does BOPE have sufficient pressure rating -- test to ~oo~ psig ..... ~ .... Does choke manifold comply w/API RP-53 (May 84) ...................... , Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS' Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... _ax /- ,/ O 'rZ ~O u~-~ 32. Additional requirements ............................................. geology' eng i neet ing,: gw~ MTM/~./...LCS ~c~)x, RPC~)~. BEW//,,, · dH,.~ rev 03/29/91 jo/6.011 iNITIAL ..... GEO 1 UNIT O'N/OFF POOL CLASS STATUS AREA ~ SHORE ,,, i III I I Additional remarks' CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) Loc (2 thru (8) (3) Admin ~ ali 9 (~ thru 12) ' ' 10. (10 and. 13) 12. 13. (1~ thm 22) (23 thru 28) (6) OTHER ~~ ~t ~- (29 thr~ 3~) Geol° gy :' EngiD~erSn~ :~ 14. 15. 17. 18. 19, 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31. 32. Company Is the permit fee attached .......................................... Lease & Well No. YES NO -- 2. Is well t~ be located in a defined pool ............................. ~ 3. Is well located proper distance from property line .................. _~ 4. Is well located proper distance from other wells .................... CD ' .... 5. Is sufficient undedicated acreage available in this pool ............ ~ pl ~ ' 6. Is well to be deviated and is wellbore at included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. ~ conservation order needed ~ I~ ~dministrative approval need;~ .................................... Is the lease number ................................... appropriate ..................................... ~ Does the well have a unique name and number ...... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground, source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ....................... . .... Is a diverter system required ........................................ Is the drilling fluid program schematic and list of equipment adequate ~ i'",",' _ Are necessary diagrams'and descriptions of diverter and BOPE attached. ~ Does BOPE have sufficient pressure rating - Test to ,~OOd) psig .. ~ Does the choke manifold comply w/API RP-53 (May 84).................. ~ .... Is the presence of H2S gas probable ~ 'eeeeeeeeeeeeeeeeeeee..eeeeeeee.e exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ...... If an offshore loc., are survey results of seabed conditions Additional requirements ............................................. , ,, INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE s o f -ot 0 2 0 Ix) Additional Remarks'': Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improVe the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. (NOTE: **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 91/06/14 ORIGIN OF DATA: MPT REEL NAME: CONOCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: MPT DATE:' 91/06/14 ORIGIN OF DATA: G-7 TAPE NAME: MILNE PT CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: G7.DAT SERVICE NAME: MPT VERSION #: V 3.26 DATE: 91/06/14 MAX. RECORD LENGTH: FILE TYPE: EO PREVIOUS FILE NAME: 1024 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 EWR MPT OHMM 0 0 0 0 1 4 0 1 68 ROP MPT FT/H 0 0 0 0 1 4 0 1 68 CAL MPT INCH 0 0 0 0 1 4 0 1 68 FXE MPT HOUR 0 0 0 0 1 4 0 1 68 DDE MPT PPF 0 0 0 0 1 4 0 1 68 FXD MPT HOUR 0 0 0 0 1 4 0 1 68 DDD MPT PPF 0 0 0 0 1 4 0 1 68 FXN MPT HOUR 0 0 0 0 1 4 0 1 68 DDN MPT PPF 0 0 0 0 1 4 0 1 68 NFO MPT CTS 0 0 0 0 1 4 0 1 68 NFl MPT CTS 0 0 0 0 1 4 0 1 68 NN0 MPT CTS 0 0 0 0 1 4 0 1 68 NN1 MPT CTS 0 0 0 0 1 4 0 1 68 GRC MPT API 0 0 0 0 1 4 0 1 68 TVD CALC FT 0 0 0 0 1 4 0 1 68 NDIS CALC FT 0 0 0 0 1 4 0 1 68 AGC MPT OHMM 0 0 0 0 1 4 0 1 68 DSFD MPT G/C3 0 0 0 0 1 4 0 1 68 EDIS CALC FT 0 0 0 0 1 4 0 1 68 DEVI CALC DEG 0 0 0 0 1 4 0 1 68 NPSC MPT P.U. 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 EWR MPT OHMM 0 0 0 0 1 4 0 1 68 ROP MPT FT/H 0 0 0 0 1 4 0 1 68 CAL MPT INCH 0 0 0 0 1 4 0 1 68 FXE MPT HOUR 0 0 0 0 1 4 0 1 68 DDE MPT PPF 0 0 0 0 1 4 0 1 68 FXD DDD FXN DDN NFO NFl NN0 NN1 GRC TVD NDIS AGC DSFD EDIS DEVI NPSC MPT MPT MPT MPT MPT MPT MPT MPT MPT CALC CALC MPT MPT CALC CALC MPT HOUR PPF HOUR PPF CTS CTS CTS CTS API FT FT OHMM G/C3 FT DEG P.U. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 ** DATA VERIFICATION (every 100 FT) ** DEPT EWR ROP CAL FXE DDE FXD DDD FXN DDN NFO NFl NN0 NN1 GRC TVD NDIS AGC DSFD EDIS DEVI NPSC 2500 -999 -999 -999 .000 .250 .250 .250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2248.967 -1999.970 -999.250 2600 -999 -999 -999 .000 .250 .250 .250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2312.469 -1931.979 -999.250 2700 1 43 51 -999.250 -999.250 -999.250 2800 69 48 -999.250 -999.250 -999.250 2900 1 70 48 -999.250 -999.250 -1175.409 .943 -999.250 -1138.742 -999.250 -999.250 50.160 ~999.250 -999.250 50.998 .000 20.499 152.912 15.893 .517 .704 -999.250 .563 -999.250 1.053 473.000 527.000 2456.000 2440.000 .497 2374.912 -1863.684 342.340 3.018 -1100.840 51.532 .204 .000 11.969 226.261 9.069 .372 .736 -999.250 .885 -999.250 .578 513.667 485.000 2584.000 2573.333 .957 2437.086 -1794.614 13.830 2.289 -1063.915 51.413 .794 .000 8.183 199.609 8.896 .376 .912 -999.250 .587 -999.250 1.118 527.000 494.000 2512.000 2568.000 .684 2500.322 -1726.198 9.408 2.261 -1027.583 50.142 .756 3000.000 9.481 228.900 9.722 .438 .226 -999.250 1.587 -999.250 1.731 500.429 464.429 2419.428 2501.714 65.988 2565.229 -1659.269 10.161 2.249 -991.425 48.959 50.407 3100 1 24 60 .000 13.435 326.633 12.506 .312 .874 -999.250 .035 -999.250 .783 413.000 477.000 2256.000 2248.000 .093 2631.620 -1593.498 15.586 2.508 -955.844 47'.846 .985 3200 1 47 47 .000 9.809 339.178 10.197 .441 .562 -999.250 .010 -999.250 .683 521.667 489.000 2557.333 2600.000 .919 2699.081 -1528.737 10.380 2.330 -920.421 47.554 .272 3300 35 7O .000 13.570 244.160 14.122 .278 .593 -999.250 .862 -999.250 .501 415.000 407.000 -999.250 2136.000 .745 2766.538 -1464.649 13.892 2.112 -883.785 47.513 .877 3400 1 37 46 .000 13.150 233.679 11.708 .389 1.065 -999.250 .724 -999.250 1.010 485.000 469.000 2648.000 2568.000 .739 2834.661 -1401.586 12.532 2.737 -846.608 46.611 .700 3500.000 9.942 305.786 9.273 .696 -999.250 1.136 -999.250 1.923 559.000 591.000 2568.000 58.305 2903.928 -1339.791 11.558 2.192 -809.418 45.316 -999.250 2808.000 45.707 3600.000 9.865 347.206 9.701 .590 1.220 -999.250 1.235 -999.250 2.587 539.000 541.000 2804.000 2832.000 54.452 2973.215 -1278.164 9.551 2.241 -771.989 46.860 3700.000 2.857 54.454 43.685 3800.000 .769 86.205 47.289 3900.000 1.042 72.500 49.374 4000.000 1.471 45.423 42.092 4100.000 1.786 73.886 44.029 4200.000 2.174 62.562 59.038 4300.000 1.429 70.583 44.578 4400.000 2.564 55.851 41.210 4500.000 2.174 65.497 42.123 4600.000 1.370 35.983 43.842 4700.000 2.222 57.914 39.765 4800.000 1.887 50.030 41.178 4900.000 2.460 45.830 44.343 6.896 -999.250 3040.629 5.452 -999.250 3106.830 5.858 -999.250 3173.560 7.315 -999.250 3239.854 5.347 -999.250 3305.653 8.267 -999.250 3371.745 6.212 -999.250 3438.186 5.286 -999.250 3504.977 10.148 -999.250 3572.871 26.631 -999.250 3641.623 4.743 -999.250 3710.272 8.506 -999.250 3779.352 9.814 -999.250 3849.608 152.600 .826 -1214.875 174.735 .496 -1150.683 152.856 .725 -1087.328 212.614 1.429 -1023.058 109.091 1.308 -957.789 120.000 1.570 -892.920 194.192 1.016 -828.395 203.906 1.301 -763.971 105.268 1.010 -700.419 104.816 .962 -637.602 181.306 1.190 -574.728 144.281 .787 -512.387 200.391 .706 -451.408 9.208 503.000 7.167 9.242 499.500 6.568 9.104 441.000 6.764 9.764 567.000 7.096 8.956 535.000 5.358 10.738 465.000 8.162 9.072 523.000 6.008 9.214 559.000 5.304 9.361 535.000 11.280 10.773 511.000 17.628 8.978 543.000 4.805 9.544 535.000 7.988 9.373 524.333 8.463 .459 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2856.000 3920.454 -391.249 4.434 2.372 -247.498 44.731 5100.000 1.786 104.615 9.179 .631 1.961 -999.250 1.786 -999.250 1.667 639.000 567.000 2824.000 2840.000 60.599 3991.613 -331.585 1.724 2.232 -210.397 44.584 37.066 52OO 2 73 40 .000 3.826 177.623 8.911 .500 1.852 -999.250 .128 -999.250 1.654 567.000 535.000 2824.000 2776.000 .082 4062.889 -272.072 3.903 2.243 -173.275 44.496 .524 5300.000 6.266 133.280 8.876 .697 3.125 -999.250 1.754 -999.250 10.000 583.000 527.000 2776.000 2776.000 60.976 4134.551 -213.019 6.157 2.217 -136.166 43.853 41.074 5400 2 85 38 .000 3.936 124.336 8.951 .857 6.667 -999.250 .083 -999.250 2.703 631.000 639.000 2712.000 2664.000 .775 4207.127 -155.047 3.950 2.384 -99.128 43.087 .441 55O0 1 62 42 .000 4.835 123.625 8.904 .456 1.515 -999.250 .493 -999.250 1.020. 551.000 535.000 2632.000 2776.000 .764 4280.354 -97.790 4.554 2.210 -62.259 42.794 .516 5600 1 87 41 .000 3.684 39.502 9.054 1.798 .901 -999.250 .389 -999.250 .971 567.000 543.000 2840.000 2728.000 .131 4353.861 -40.706 3.669 2.299 -25.678 42.653 .270 5700.000 -999.250 110.955 8.956 -999.250 -999.250 -999.250 1.667 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 83.079 4427.372 16.673 -999.250 2.308 10.430 42.700 -999.250 58O0 -999 -999 -999 .000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .250 4500.864 74.165 -999.250 -999.250 46.398 42.699 .250 ** 610 DATA RECORDS ** FROM 2500.00 TO 5850.00 FT FILE TRAILER** FILE NAME: G7.DAT SERVICE NAME: MPT VERSION #: V 3.26 DATE: 91/06/14 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 2) ********** ** TAPE TRAILER** SERVICE NAME: MPT DATE: 91/06/14 ORIGIN OF DATA: G'7 TAPE NAME: MILNE PT CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 91/06/14 ORIGIN OF DATA: MPT REEL NAME: CONOCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** TAPE TERMINATED BY REEL TRAILER ********** * ALASKA COMPUTING CENTER * , ****************************** ****************************** FIELD NAME STATE API NiJ~BER ¢ONDC[3, INC. ~ILNE POINT UNIT SCHRADER 8LUFF ..~ NORT~ SLOPE 50-029-22140 92~04 FEB 0 5 1992 Alaska 0ii & Gas Cons. Conunission Anchorage I$ Ta~e verificatio~ Listing ~lU~<~be~ge~ Al, aEKa ComputlnO Center 3-FEB-1992 !9:2{ **** REEL HEAOER **** DATE : 92102/ 3 ORIGIN : F[;IC REEL NA~E : 92104 CONTINU~ATIOM PREVIOUS REE[~ C~,~ COM3CO !5!C , MP{] G'7, ......... CO~ENT : ..~,,z', .... . SCHrADeR BLUFF, APi #50'029'22140 **** TAPE HEADER **** SERVICE N~E : GCT DaTE : 9~/0~/ 3 ORIGIN ~ FLIC TAP~ M~ ~ 02104 CONTINUATION PREVIOUS T~PE CO~ENT PAGE{ **** FILE HEADER **** F!L~ NA~E : GCT ,001 SERVICE ! FLit VERSIOM ~ 001A~06 DATE ~ 92/02/ 3 M~X EEC S!ZE : 1024 FILM TYPE : LO L~ST FILE ******************************************************************************* ******************************************************************************* ** ** ** SCHbU~RERGER WELL SERVICES ** ** ** ******************************************************************************* ******************************************************************************* FIE[,D: SCHRADER BOROUGH: NO~TH SLOPE AP1 N{3SBER: ~()-0~9-22140 LOCATIOn: 3298' FNL & 3393' EEL SECTIOn: 27 TOw~S~,~Ip: !.3N RANGE: 10E PER~t, IENT DATI],~,,: ~tSL EbEVAT!O~'I: 0' LOG blEb. SURED rRO~ RK,~ 66' ABOVE PER~At'~E,~T D.ATU~ :hlumberqer AlasKa Computi~O Center 3-FEB-IR92 !9:24 PAGE: DF': 65' GL: 35' DSTE LOGGED: 25'DEC'91 RUN MU~BE~: ONE TD DRILLER: 58~5' TD LOGGER: 5606' CASING 1: CaSIN~ ~: C~SIWG 3: i3 3/8" 54.5 I,B ~ 'DRIbLER DEPTH OF 0" TO 115' g 5/~" 3.6 bB 0 DRILLER DEPT}.{ OF 0' TO 2697' 7" 26 LB O DRILLER DEPTH OF 0' TO 5797' TYPE FI, DID I~] HOLE: BRINE DE:NSITY: 8,6 LB/GA[.., ~XI~U~ TE~P RECORDED[ t12 DEGF LOGGING DISTRICT: LOGGING ENGiNEEr: WITNESS: PRUDHOE BAY JEFF FORMICA ANDREWS/ HARRiNGTON TOOL NUMBERS: CAL-YA 028 SGC-SA 59 CBS-DA B2 TCC-$ GCEC-~ 70~ STM-CB TCC'B 42o CBC-EB 83 GCAD-A 745 GCPC-A 705 PGGT-A 52 TC~ 27~ DATE jOB STARTED: 3-FEB-g2 JOB REFERENCE NO: 92{04 LDP/A~iA: ~. KRUWELb T~BLE TYPE : CONS WN ~ILN~ POINT UNIT G-7 Well Name N~TT USA Nation ST~T ALASKA State or Province COUN NORTH SLOPE County SFCT 27 Section TOwW 13N Township Rang 10~ ~anoe FL 3288' FNL & 3393' FEb Fieid Location So~ 425369 Service. Order Number API~ 50-029-22~,40 ~PI Serial Number TaPe Verificatio~ List!no ~-.hiumberger ^]as~a Computing CeDter 3-FEB-lg92 1g:24 T~SLE TYPE DEFI DEPT Depth Channel Name GDEP GYRO Depth YDEP True Yert~cal QeDth as chaDnel <TYTCPI> DEV! Dev~atloD NSD~ North South Drift EWDR East west Drift Component CWEL CURVATURE OF THE WELL I 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0,5 9 65 FT i! 66 32 12 6~ 13 66 0 I4 65 FT iS 66 68 16 66 1 n 66 0 ** SET TYPE - CHAN ** -~-;---~ ....... -'-~-~;~-'~; ............ -~-~--------~ .... .-..-..-.-------.-.,,.------. I[) OR~C~ # LOG TYPE CbASS ~OO ~U~B SA~P ELE~ CODE (HEX) ................... ..... ..-.; ..... ................................. D~PT PT 4 9 00 00 00 1 1 I 4 68 0 0 000000 GDEU GCT PT 425369 00 0O0 00 0 ! 1 1 4 68 0000000000 VOEP GCT FT 425369 O0 000 O0 0 1 ! 1 4 68 0000000000 DFV! GCT DE(; 425369 O0 000 O0 0 ~. 1 1 4 68 0000000000 ~{LAZ GCT DEG 4~5369 O0 000 O0 0 1 ! 1 4 68 0000000000 NSD~ GCT FT 425369 O0 OOO O0 0 ! 1 I 4 68 0000000000 IS Ta~e veriflcat, ion Listin~ :blUmberoer AlasKa Comput!.nq Center 3-FEB-199P i9:24 PAGE: ID ORDER ~ LOG TYPE CLASS MOD NUmB SAMP ELEM CODE (HEX) EWDm GCT FT 425369 O0 000 00 0 1 I ! 4 68 0000000000 CWEL GCT D/HF 425369 00 000 00 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 65535.500 GDEP.GCT 12,000 VDEP.GCT HLAZ.GCT 0.000 NSDR.GCT 0.000 EMDR.GCT D~PT. 65500,000 GDEP,GCT 1148,500 VDEP,GCT · . . ~D" GCT HLAZ GCT 39.085 NSDR (.;CT 68,919 [.)~pT 65412.(O00) GDEP.GCT 5815,000 VDEP.GCT }IL~Z~GCT ~2' 71 MSDR,GCT 2777,07] EMDR.GCT ** END OF DATA ** §:ooo 000 CWEL'GCT t141 51.4 DEVI.GCT 55~694 CWEb,GCT 4510 685 DEVI,GCT 1663~558 CWEL.GCT 0'000 0'000 000 **** FILE TRAILER **** FILM NA~E : GCT .001 S~RVICE : FLIC VERSION ~ 001A06 D~TM : 92/02/ 3 MAX REC SIZE' : ~02~ FILF TYPE : bO L~ST FILE : **** TAPE TRAILER **** SERVICE NAME : ~CT DATE : 92/02/ 3 ORIGIN : FblC T~PM NAME : 92104 CONTINUATION ~ % 1 PREVIOUS TAPE : CO~MENT ~ GCT, CONOCO INC., MPU G-7, SCHRADER BL, UFF, API #50-029-22140 **** REEL TRAILER **** SFRVICE NAMR : GCT D~TE : 92102/ 3 O~I~IM : Fb!C REEL N~E : 92104 CONTINUATION PREVIOUS R~L COMMENT : GCT, CONOCO INC., MPU 0-7, SCHRADER BLUFF, API #50-029-22140 ALASKA COMPUTING CENTE~ · COMPANY NA~E: CONOCO INC. WELL NAME : MILNE POINT UNIT G-7 FIELD NAME : SCHRADER BLUFF BOROUGH ~ NORTH SLOPE STATE ~ ALASKA AP! NUMBER : 50-029-22140 REFERENCE NO : 74591 RECEIVED ,JUN 1 4 19~)! Oil & ~ Con~ Tape Verification Listinq bio,berber Alaska ComPutiDO Center 12-JUN.1991 15:20 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 91/06/12 ORIGIN : FLIC REEL NA~E : 74591 CONTINUATION # P. EV!OUS REEL COMMENT : CONOCO,SCHRADER BbUFF,MiLNE POINT [)NIT G-7,50-029-22t40 **** TAPE HEADER **** SERVICE NAME ~ EDIT DATE : 91/06/12 ORIGIN : FLIC TAP~ NA~E : 74591 ONTINUATION # : 1 ~EVIOUS TAPE ~ COMMENT : CONOCO,SCHRADE~ BLUFF,MILME POINT UNIT G-7,50'029-22140 **** FILM HEADER **** F!L~ NAME : EDIT ,001 SERVICE : FLIC VERSION : O0!A06 DATE : 91/06/12 ~X REC sIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: ******************************************************************************* ******************************************************************************* ** SCHLUMBERGER WELL SERVICES ******************************************************************************* COMPANY N~M~: CONOC° INC, WELL: MILNE POINT UNIT FIELD: SCHRADER BLUFF BOROUGH! NORTH SLOPE STATE: ALASKA AP1 NUMBER: 50-029-22140 LOCATION: 3235' FNL & 3451' FEb SECTION~ ~7 TOWNSHIP: P£R~ANENT DATUM: MSb ELEVATION: RANGE: IOE Tape Verificat~on Listing hlumb, erger Alaska Computing Center l~-jUN-Ig9~ 15:~0 LOG MEASURED FROM RKB 65 ELEVATIONS KB: 65 DATE LOGGED: 21-MA¥-Iggl RUN NUMBER: ONE TD DRILLER: 5750 TD LOGGER~ 5751 CASING : BIT SIZE : 8,5 ABOVE PERMANENT DATUM · DF: 64 GL: 31 9 5/8'" _~ DRILl, ER DEPTH OF 2697 AND LOGGER DEPTN OF 2697 VISCOSITY~ 42 FLUID I,OS$: 6,5 TYPE FLUID IN HOLE: [~SND DENSITY~ 9,5 P~: 9 MUD RE$ISTIVITY~ FILTRATE RESISTIVITY: ~UD CAKE RESISTIVITY: 2,68 ~ 70 2,51 ~ 70 2,61 ~ 70 TIME CIRCULATION ENDED(BGT): 20~00 TI~E LOGGER ON BOTTO~(BGT): 03:00 TI~E CIRCULATION ENDEDiDITE/LDT/CNL/NG,~/MSFL): !6:00 5-~1 TIME LOGGER ON BOTTOM(D!TE/LDT/CNL/NGT/~$FL): 21:58 ~AXXMUM TEMP RECORDED(BGT): 78 M~X!MUM TEMP RECORDED(DITE/LDT/CNL/MGT/~SFL)~ 97 5°GGING DISTRICT: ~TNE$S: PRUDHOE BAY DECKERT / D, MOUNTjOY TOoL NUMBERS: A,M AA 774 TCC B ~39 NGD 756 NSC 1935 SRE D 797 SRT ~ ~852 CNC HA 332 ~$C g DRS 4969 PGGD 868 DIC 271 DIS 276 BGC-B 938 BGS-~ 956 FIELD REMARKS: TOOL STRING (BOT-TOP): DITE-LDT-CNT-MSFL-NGT-TCC-AMS SEVEN 1.4" TEFLON STANDOFFS AND A 2' HOLE FINDER WERE USED, NEUTRON MATRIX~ SAND, ~OLE CORRECTION: CALIPER DENSITY MATRIXm 2.65 G/CC, FLUID DENSITY: 1.0 G/CC. 6ENSITY HOLE CORRECTION: NONE. NGT FILIER: LEAST SOUARES, BOWSPRING USED ON THE CNL. ROLLOVER SLEEVES NOT AVAILABLE, LOGGED THE REPEAT PAS$¢FIL~ 8) AT 900 FPH IN TME NIGH RESOLUTION MODE FOR ~" CNL AND l" LOT SAMPLING, PLAYBACKS MADE ON TAPE OF THE PHASOR IN THE ENHANCED ~ODE, AND TOE NGT WITH KAL~AN FILTERING, ANGLE THROUGH THE LOGGING ZONE: 51-42 DES, , COMPUTING CENTER RE~ARKS: THIS LIBRARY TAPE ALSO INCLUDES THE FOLLOWING COMPUTING PAGE: ~hlumberger asea Comput t2-JUN-lg9! 15:20 CENTER PROCESSING WHICH IS LOCATED IN FILE #3 ON THIS TAPE: 1) PHASOR PROCESSED LITE 2) ALPHA PROCESSED LDT/CNL 3) KALMAN F.IbTERED NGT 4) ALPHA FILTERED NGT PAGE{ DATE JOB STARTED: 1-JUN-91 JOB REFERENCE NO: 7459] LDP/AN~{ KONRING FILE - EDIT.O0! cONoco INC. SCHRADER BLUFF MIL:NE POINT UNIT 50-029-22140 MAIN PASS LOG DATA DATA SAMPLED EVERY -.5000 FEET DATA iNCLUDED - Tool EXTENSION TOOL TYPE USED NAME * BGT ,BGT * DIT'E ,DTE * LDT .LDT * CNT'A/D/H ,CNL { NGT .NGT BOREHOLE GEOMETRY TOOL PHA$OR DUAL INDUCTION SFL 5ITHO DENSITY COMPENSATED NEUTRON NATURAL GAMMA SPECTROScoPY (LEAST SQUARES FILTERED) TABLE TYPE : CONS TU~I VALU DEFI CN CONOCO INC. Company Name FN SCHRADER BLUFF Field Name WN MILNE POINT UNIT G-7 Well Name APIN 50-029-22!40 API Serial Number FL 3235' FNL & 3451' FEE Field Location SECT 27 Section. TOWN 13N Township 'hlumberqer Alaska ¢omPutln~ Center 12-JUN~1991 15:20 PAGE~ 4 ,TUNI STAT PDAT EPD FT ~F ~PD FT EKB FT EDF FT E~5 FT TDD FT TD5 FT Bb! FT bI FT DFD G/C3 DFPM DFV CP DEGF ~FST DEGF R. MCS OH~ MCST DEGF TCS BHT ' DEGF VALU IOE NORTH AbASKA USA 5~8~9V 0, RKB 5~51. 5666. 2697~ 2,68 70~ '" 2.~! 70 ~6:00 97, DEFI Range county state or Prov~nce ~ation Witness' Name Serv ce Order Number Permanent datum Elevat on of Perm, Datum bog ~eas'red From A~OV~ ~E~MA~EN? D~TU~ Elevat~on of Der Floor Elevation of.Groun~ Leve! Total Depth Drlller Total Depth -bogger BOttom LOg Interval Top Lo~ InterVal Drlllln~ Fluid Type Dr,llin~ FlUid Density Drlllln~ FlUid Ph . Dr~lllnq FlUid ~lScosity Dril!$n~..Fluld Loss ResiStivity_of 2ud.$amp!e ~ud..Sample Temperature ~esistigitv of mud filtrate s Mud~.~F$ltrate Sample TemPeratu Resistivity of ~d Ca~e Sampl ~ud Ca~e Sample TemPerature Time CircUlation Stopped Bottom Hole Temperature mmm~mmmm~m~mm~mmmmmmm~m~mm~m~mmmmmm#mmm~m~mmmmm~mmmmm~m~m~m#m~mmmmN~m~mmmmm~m#~m~!. '. , TABLE TYPM ~ CURV DEFI DEPT Depth C~annel Name .. CIDP INDUCTION DEEP PHASUR CONDUCTIVITY IDP~ INDUCTION DEEP PHASOR RE$ISTI¥ITY CIMP INDUCTION MEDIUM PHASOR CONDUCTIVITY I"P~ INDUCTION ~EDIUM PHA$OR RESISTIVITY CILD Deep Induction Standard Processed Conductivity It, D Deep Induction Standard Processed Resistivity CISN Medium Induction Standard Processed COnductivity ILM ~edium Induction Standard Processed Resistivity IFR~ !nduct~on Calibrated Frequency IDQF Induction Deep Oualit¥ Factor I~OF Induction ~edium ~uality Factor IIRD Deep Induction Real Intermediate Conductivity IIXD Deep I.duction Ouad Intermediate Conductivlt9 I!R. ~ediu~ Induction Real Intermediate ConductlVi IIX~ ~edium Induction Quad Intermediate Conductivity Tape Verification [.,ist~ng ~hlumbergerAlaska CompUting Center PAGEI DEFI BFLU .SFb Resistivity (unaveraqed) SP Spontaneous Potential MTE~ HTEN DPH! PEF LS LITH SS2 SSHv LSRH LURH TENS MTE" ~RES HTEN NPHT RTN~ TNP~ TNRA NP~ RCNT RCFT CNT¢ CFTC SGR' CGR CALl CAbS TENS NTE~ HTE~ SGR CGR THOR POTR Spectroscopy Gamma-RaY Computed GR from Thorium, Uranium, Potassium Tension ~ud TemPerature MUD Res~stivlty Head~Tension Density Porosity 8ul~ Density Delta RHO Photoelectric Factor Quality control of lot~g spacing for bDT ~uallty control on short Spacl~ for ~DT [,.ong $~acing COmPuted Count Rate Long UPper 172 Window Count Rate LO~o:bower,,:Wlndow Count Rate bi' log WindOw Count Rate Short SpacinQ ~ Window Count Rate Short SPacing 2 WindOw Count Rate Long spacing'H1Qh Voltage OUtput Short Spacing High VOltage LoOP Output Short SPacing ~ Density Long SPacing"~R~OB (Lnc~rrected)U Long UPper RHOB Caliper' Spectroscopy Gamma-RaY COmPuted GR from Thorium, Uranium, Potassium Tension ~ud Temperature MUD Resistivity Head Tension Neutron Porosity Raw Thermal Neutron ~atlo Thermal Neutron Porosity Calibrated Thermal Neutron Rat~o Neutron Porosity Output From an Application Program R~W NEAR C~T COUNTS RAW FAR CNT COUNTS Corrected Near Thermal Counts Corrected Far Thermal Counts Spectroscopy Gamma-Ray Computed G~ from Thorium, Uramium, Potassium Caliper Sonic Caliper Tension ~UD Resistivity ~ud Temperature Mead Tension Spectroscopy Gamma-Ray Computed GR from Thorium, uranium, Potassium Thorium Potassium hlumheroer 1, asRa Comput !2-JUN-lg91 15:20 [)RAN Uranium wi.G window 1 ,,150 w ,C window '-I ndow 4 (I'6 WLNG WindOW 5 (2 -] MEV) T~N8 Tension MTE) Mud Temperature MAES ~UD Resistivity C8 Cable Speed. ~?EN ~ead Tension GR Gamma C! Caliper '1 - 3 C~ CaliPer 2 - 4 ,T~NS ?ens~on PAGE; DATA FORM.AT SP.F,.CIFICATION R'ECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 336 4 66 1 5 66 6 73 7 65 g 65 11 66 3 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NA~K SERV UNIT SERVICE API AP1 APl AP1 FILE NUMB NUMB SIZE REPR PROCESS ID- ORDER #LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) .... ,...........,........-..-,....................,...........,,. OEP.. F1 5481 7 O0 O0 O0 0 1 1 4 6 00000000 CIDP DTE MMHO 548197 O0 000 O0 0 1 1 1 4 68 0000000000 IDPM DTE OHMS 548197 O0 000 O0 0 ! 1 I 4 68 0000000000 CXMP DTE M~HD 548197 O0 000 O0 0 I I 1 4 68 0000000000 IS Tape Verification Listing :hlumberqer AlasKa ComPuting Center 12'JUN~1991 15:20 PAGEl ID ORDER # LOG TYPE CLASS MOD N{}~B SAMP ELEM ..CODE (HEX) I~PH DTE OHMM 548197 O0 ClLD DTE MMHO 548197 O0 I~D_ DTE OHMM 548197 O0 CILM DTE ~HO 548197 O0 IL~ DTE OH~M 548197 O0 IFR~ DTE BZ 548197 00 XDQ~ DTE 5.48197 O0 I~F DTE 548197 00 IXRD DTE ~MHO 548197 00 IIXD DTE MMHO 548197 O0 i!RM DTE MMHO 548197 00 II×~ DTE MMMO 548197 00 SFLU DTE OHMM 548197 O0 SP DTE MV 548197 O0 SGR DTE GAPI 548197 O0 CGR DTE GAPI 548197 O0 TENS DTE LB 548197 O0 ~TEM DTE DEGF 548197 O0 MRES DTE OHMM 548197 O0 HTEN DTE L~ 548197 O0 DPMI LOT PU 548197 O0 R~OB LOT G/C3 548)97 O0 D~MO LDT G/C3 548197 00 PEF LOT 548197 O0 OLS LDT 548197 O0 ~SS LDT 548197 O0 LS LDT CPS 548197 O0 LU LDT CPS 548197 O0 LL LOT CPS 548197 O0 LIT~ LDT CPS 548197 O0 $SI LDT CPS 548197 O0 $S~ LOT C~S 548~97 O0 LSHV LDT V 548197 O0 SSHV LDT V 548197 O0 $~RH LOT G/C3 548197 O0 LSRH bDT G/C] 548197 O0 LURH LOT G/C3 548197 O0 CALl LDT IN 548197 O0 SGR LDT GAPX 548197 O0 CGR EDT GAPI 548197 O0 TENS LDT LB 548197 00 MTEM LOT DEGF 548197 O0 MRE$ LDT OHMM 548197 O0 HTEN LOT LB 5481.97 O0 NPH! CNL PU 548197 O0 RTNR CNL 548197 O0 TNPH CNL pU 548197 O0 TNR~ CNL 548197 O0 NP0~ CNL PU 548197 O0 RCNT CNL CPS 548197 O0 RCFT CNL CPS 548197 O0 000 O0 0 I I 1 4 68 0000000000 000 O0 0 1 1 1 4 6~ 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 I 4 68 000000'0000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 I I 1 4 68 0000000000 000 O0 0 I I I 4 68 0000000000 000 O0 0 I 1 I 4 68 0000000000 000 O0 0 I ! I 4 68 0000000000 000 O0 0 1 I 1 4 68 0000000000 000 O0 0 I I 1 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 000 O0 0 1 ~ 1 4 68 0000000000 000 O0 0 1 ! I 4 68 0000000000 000 O0 0 I I 1 4 68 0000000000 000 O0 0 1 1 I 4 68 0000000000 000 O0 0 1 ! I 4 6~ 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 I 1 I 4 68 0000000000 O00 O0 0 1 I I 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 I I 4 68 0000000000 000 O0 0 1 1, I 4 68 0000000000 000 O0 0 I I 1 4 68 0000000000 000 O0 0 I 1 I 4 68 0000000000 000 O0 0 I I I 4 68 0000000000 000 O0 0 I 1 I 4 68 0000000000 000 O0 0 1 ~ 1 4 68 0000000000 000 O0 0 1 1 I 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 000 O0 0 1 I 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 I 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 t i 1 4 68 0000000000 000 O0 0 1 I 1 4 68 0000000000 000 O0 0 1 I 1 4 68 0000000000 000 O0 0 1 I 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 I 4 68 0000000000 000 O0 0 1 I 1 4 68 0000000000 000 O0 0 I 1 I 4 68 0000000000 :$ Ta~e Veri~,lc~tion Listi ~ :hlumberoer Alaska ComPut ~. Center 12-JUN-199! !5:20 NAME SERV UNIT SERVICE APl API API AP1 F bE NUmB NUmB SIZE REPR PROCESS R # LOG TYPE ChASS NOD NUMB SA~P ELE CODE (HEX) ID ORDE CNT~ CN.L CPS 548197 O0 000 O0 0 1 1 I 4 68 CFTC CNL CPS 548197 O0 000 O0 0 1 1 1 4 68 SGR CNL GAPI 548197 O0 000 O0 0 1 1 I 4 68 CGR CN'L GAPI 548197 O0 000 O0 0 I I I 4 68 CAb! CNL IN 548197 O0 000 O0 0 1 I I 4 68 CAL. S CNL IN 548197 O0 000 O0 0 1 1 1 4 68 TENS CNL LB 548197 O0 000 00 0 1 I 1 4 68 PRES CNL OHMM 548197 O0 000 O0 0 1 1 I 4 68 MTEM CNL DEGF 548197 O0 000 O0 0 ~ 1 1 4 68 HTEN CNL 5B 548197 O0 000 O0 0 1 I 1 4 68 SGR NGT GAPI 548197 O0 000 O0 0 1 1 I 4 68 CGR NGT GAPI 548197 O0 000 O0 0 1 I I 4 68 T~O~ NGT PPM 548i97 O0 000 O0 0 I 1 I 4 68 POTA NGT PU 5481,97 00 000 00 0 ~ I 1 4 68 URAN NGT PPM 548197 O0 000 O0 0 1 I 1 4 68 WING NGT CPS 548197 O0 000 O0 0 ! I I 4 68 W~NG NGT CPS 548197 O0 000 O0 0 1 ! I 4 68 W3NG NGT CPS 548197 O0 000 00 0 I 1 ! 4 68 W4NG NGT CPS 548197 O0 000 O0 0 I I I 4 68 WbN~ NGT CPS 548197 O0 000 O0 0 ! ! I 4 68 TENS NGT LB 548~97 O0 000 00 0 ~ 1 ~ 4 68 PTEM NGT DEGF 548197 O0 000 O0 0 ~ 1 1 4 68 N~E$ NGT OH~ 548197 O0 000 O0 0 I I ! 4 68 CS NGT F/HR 548197 O0 000 00 0 I ~ I 4 68 HTEN NGT LB 548197 O0 000 O0 0 1 ~ I 4 68 GR BGT GAP! 548197 O0 000 O0 0 I ~ 1 4 68 C! BGT IN 5481q7 O0 000 O0 0 ! 1 ! 4 68 C2 BGT IN 548197 O0 000 O0 0 ! i 1 4 68 TENS BGT LB 548197 00 000 O0 0 ! I ~ 4 68 000000000o 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 .PAGE~ DATA ** I~P":DTE 2,781 CI5b,DTE 350,~00 ILD'DTE b~'DTE 2,771 IFRE"DTE 20. O0 XDQF,DTE IIRO,DTE 291,000 IIXD.DTE 42.]13 IIRM,OTE SFbU.DTE 2,992 SP'DTE -34,469 SGR'DTE TENS.DTE 1320,000 MTEM,DTE 92,938 MRES,DTE DPHI.LDT 25,139 RHOB.bDT 2,235 DRHO,bDT OhS.bDT -0,018 DSS.bDT -0,003 LS,LDT bL,LDT 206,6~5 LITH,bDT 127,688 S$1,bDT LSHV,LDT 1707,000 $SHV,LDT 1357,000 S1RH,bDT LURH,LDT 2,242 CALI.LDT 2,883 SGR,bDT TENS.bDT 1320,000 MTEM,LDT 92.938 PRES,bDT NPHI,CNL 49,743 RTNR.CNL 3.705 TNPH.CNL NPOR,CNL 42.064 RCNT.CNb 2111.037 aCFT,CNL C C.CN 06.63b SSn.C b 109.566 CG .CN Ca S 2 a30 TENS.C 320.000 532.5OO 09.5b 2 887 2 854 3 000 335 250 109 .566 1 893 -0.007 388,500 217,625 2.268 ~09,566 1.893 42.064 562.656 96.403 1.893 96.403 CXMP,DTE ClLM,DTE IMOF,DTE IIXM,DTE CGR,DTE HTEN,DTE PEF,bDT _LU,LDT S$2,LDT bSRH.LDT CGR,bDT HTEN,GDT TNRA,CNL CNTCeCNb CRLI,CNL MTEM.CNL THOR,NGT 50O 2 000 18 703 96 403 532 500 2 922 363 750 II°o 96,403 532,500 3.504 2096.886 2.883 92,938 15.689 iS Ta~e ver. ification b. lsting ~h!um'erqer Alaska Computing Center pOTA,NGT 2.161 URAt~*MGT W3NG.NGT 58'486 W4NG,NGT MTEM.NGT 92,938 GR. BGT -999. 250 C1 .B~T DEPT. X~PH.DTE IIRD'DTE SFLU'DTE TENS,DTE DPMI.LDT OLS'LDT 5S~V'LDT LUR~.LDT TENSLDT NPO~oCNL CFTC CNL CALS:CNL HTEN.CNL POTA.NgT W~HG.NGT MTE~.NGT G~.BGT DEPT. X~P~.DTE XL~.DTE IXRD.DTE SFLU.DTE TENS.DTE 5800,000 2'781 2.7'71 291'000 2,99:2 ~030.000 25'139 0,018 1707'700 2'242 2030,=000 49'743 42.064 606,636 2'330 541.500 1,902 58,486 92'938 -999'250 sTo :ooo ,:158 3 094 ~79 000 3 152 3665 000 18 553 -0,018 171.250 1707.000 3665,000 42,022 38.652 621'175 2,330 1598.000 1.896 92 38 -999.250 5600.000 2.703 2.730 294.000 2.367 3875.000 CIDP.DTE CILD*DTE T~ IFRE,D.E XIXD DTE SP DTE MTE~ DTE RHOB'LDT O$$.LDT bXTH.LDT SSHV bDT CALILDT ~TE~ LDT RTNRCNL RCNT C~L SGR CNL TENS CNL SGR..NGT URAN NGT W4NG NGT MRE$.NGT Ct,BGT CIDP.DTE CILD..DTE IFRE.DTE IIXDDTE SP:DTE MTEM.DTE RHOB,LDT QS$,LDT LITH.LDT SSHV.LDT CALI LDT MTE~ bDT RTNR CNL RCNT CNL SGR CNL TENS.CNL SGR.NGT URAN,NGT W4NG.NGT ~RES.NGT C1.BGT CIDP.DTE CILD.DTE IFRE.DTE IIXD.DTE SP.DTE HTEM.DTE 12."JUN- 1991 15;20 PAGE{ O, ggg, 346 42 -34 92 2 -0 1 !0 !6 . 99'9, 327, 330, .20, -35° 0 100i 1358 9. 92. 3. 2076. 109, 3665. 109. 6. 16. 1 -999: 353. 359. 20. .46, ll.. 93. 39 WING.,NGT 348.624 ~0 CReBGT -999.=250 3 CS'NGT 1134.000 000 IDPH,DTE 000 XLD'DTE 000 IDOF~DTE 3!3 IIRM.:DTE 469 SGR,DTE )38 MRE$,DTE .~35 DRMO,bDT 003 LS.bDT 688 'S$1,5DT 000 $1RH'5DT 883 S~R.LDT 938 ~ RCFT;CNb 566 CGR,CNL 000 MRE$'CNb 566 CGR.NGT W5~G'NGT CS,NGT 500 IDPH,OTE 0 ILD'DTE ~0 IDOF'DTE !!~ IIRM'OTE SGR,DTE 8 MRES,DTE 344 DRHO*LDT 1 LS"LDT ~0 SSl,bDT 000 S1RH,LDT 938 SGR,LDT 938 ~RES.bDT 667 TNPH.CNL 100 RCFT,CNL 566 CGR,CN5 000 MRES,CNL 566 CGR,MGT 779 WlNG,NGT 055 W5NG,NGT 893 C$.NGT 250 C2.8GT 500 IDPH.DT£ 250 !Li!DTE 000 IDO DTE 344 XIR DTE 750 SGR.DTE 375 MRMS,DTE 2 887 2 854 3 000 335 ~50 388 500 2!7 625 2 2168 109 566 1893 064 4~ 56 656 58 994 1,893 358-994 48.624 9,~:174 174~'0:00 -99 .250 3 53 0 000 304:250 10 566 I 893 0 i~ 2 325 ~0 216875 2~334 109 ~566 ! 893 38740 555 .1182 58 096 i.893 58.096 34~.624 .~74 876.000 ~999..250 2.826 2.781 0.000 4o: oo 13 87 1.9o2 W2NG,NGT TEN$.NGT HTEN,NGT TENS,BGT CI~P..DTE CXL~'DTE INQF,DTE IIXM. DTE CGR DTE HTEN 862 LDT LSRH LDT C~ LDT HT~ LDT T~RA CNL CNTC CALX CNL MTE~ CNL W2NiG.NGT TENS*NGT HTEN,N~T TEN$'B~T CIMPDTE CXbM~DT£ IIXM,DTE CGR DTE MTEN DTE PEF bDT LULDT $$2LDT LSRH~LDT CGR.LDT HTEN. LDT TNRAiCNL NTC CNL ALI CNL ~TE~,CN5 T~OR,NGT W2NG.NGT TEN$,NGT HTEN.NGT TEN$.BGT CIMP.DTE CIL~.DTE IMOF.DTE IIXM.DTE CGR.DTE HTEN.DTE 154,816 1320,000 532,500 -.999,250 359,250 3602,500 · .000 18':703 58' 994 541 500 2 742 750 2 240 58 994 541 .~00 ~ 04 2096 886 2 8 7:2 27 1'54 8! 6 2030 000 54 500 -99~ :250 316 500 323 000 0 000 !9 625 58 096 1598 000 2 863 I0000 190 000 2 342 58. 096 1598 000 3 553 2058 148 9 938 92 938 7 024 8 6 154 0~}0 3665 1598 000 -999 250 369,500 366,000 0,000 39,438 82'459 1675,000 ;hlumberger Alaska ComPuting Center 12-JUN't991 15:20 PAGE: 10 ObS bDT Lb bDT LSHVLDT LURHLDT TENS bDT NPH! CNL NPOR'CNL CFTC,CNL CAbS,CNL HTEN.CNL POTA.NGT W3NG.NGT NTEM',NGT GR.BGT · ~!IRD'DTE SFLU~DTF .TENS..~TE DPHI~I. DT ObS'LDT Lb.bDT SHV'LDT URH,LDT TENS"bDT NPHI.CNL NPOR,CNL CFTC.CNL CALSoCNL ~HTEN,CNL POTa.NGT W3NG.NGT MTE~.NGT GR.BGT DEPT. IMPH.DTE Ib~.DTE IIRD.DTE SFbU.DTE TENS DTE DPHI:LDT OLS.LDT Lb'bDT LSH¥.LDT LURH.LDT TENS.bDT NPHI.CNL NPO~.CNL CFTC,CNL C~5S.CNL HTEN.CN5 2!.771 0,003 t90.625 1707,000 ,299 387~,000 44,~67 42,6~4 553,409 ,707 63.745 9 '375 99~.250 5500,000 5'727 5'547 ~67,500 6'523 3865,000 ~8;291 0.022 223~625 1707,000 ,197 386~,000 · 40 25:! 41 392 652 995 9063 1695 000 1 359 35 8 7 93 -999 250 5400.000 8.648 7.883 110.500 11.445 3775.000 26.689 '0,019 222,875 1707.000 2.201 3775.000 39.4~0 39.017 699,300 8,883 ~682,000 RHOB'LDT QSS.LDT L!TH.LDT SSNV bDT CALI bDT STEM bDT RTNR CNL RCNT CNL SGR CNb TENS CNL SGRiNGT URAN, NG:T W4NGiNGT ClDP,DTE CILDiDTE IFRE,DTE IiXD~DTE SP,DTE MTEM,DTE RHOB*bDT QSS, LDT 5ITH~LDT SSHV,LDT CALI'LDT MTEM'bDT RTNRiCNL RCNTCNL SGR. CNL TENS CNL SGR NOT URAN NOT W4NG NOT MRES NGT Cl BGT CID~:DTE CI5 DTE IiX DTE SP,DTE MTE~,DTE RHOB,bDT QSS,LDT LITH,LDT SSHV.LDT CALI.LDT ~TE~.LDT RTNR.CNL RCNT.CNL SGR CNL TENS~CNL SGR.NGT 2,291 01 LS'~DT O. 3! 109' 3 $SI:,~DT O0 RH, 1357, 0 Si bDT 47 9~ 7 SGR.'LDT .37 MRES,~DT 93' 5 87 3~ 9 TNPH,CNb 46 RCFT CN 2008, 1 ' 68 C~b !13, 7 CGR 3875,000 ~RES CNb. 113,687 CGR,NGT 3'937 W.ING;N~T 16.932 WSN'G,NGT , 1'902 CS'NOT 99:9,250 C2,BGT 8 '500 DTE '!25 ILD'DTE ,000 IDOF,DTE 5'047 IIRM.DTE -32:'969 SGR~DTE 93,375 MRES,DTE 2.183 DRHO'bD'T -0'007 LS,LDT 140,000 SSi'bDT 1357,000 S1RH,bDT 9,289 SGR,LDT 93,3~5 MRES'bDT _ 3,57 2!33'68~ TNPH,CNb RCFT,CNL 64,505 CGR.CNL 3865,000 NRES.CNL 64 505 CGR,~GT 1:589 WiNG.NGT 7 968 W5NG,N~T 99~i926 CS,NGT - 250 C2,BGT 117.375 IDPH,DTE 121,000 ILD,DTE 20'000 ID~F,OTE 13.438 IIRM,DTE -32,313 SGR,DTE 93.438 NRES.DTE 2.210 DRMO,bDT 0,017 LS,LDT 145,250 SSI,bDT 1357.000 S1RH,LDT ~:969 SGR.bDT 9 438 MRES,LDT 3.296 TNPH,CNL 2397,646 RCFT.CNL 73.949 CGR,CN5 3775.000 ~RES.CNL 73,949 CGR.NGT 0 001 35~750 21 375 2,287 43'.ij~48 504~60 8.2,459 7.~729 !0,956 1826..000 '999~250 5.418 5'313 0,000 169,625 64'~05 ~1'926 -'0,015 420':000 60' 64.505 1.926 39.,863 625~245 54,~ 1 5 'ii!s: 207 171 7 968 ~785 000 999 250 8.516 ,258 .000 .949 .950 0.006 417,500 8.000 222.176 73.949 1.950 39.~885 657.51! 66.802 1.950 66.802 PEF.'LDT L~'LDT SS ,bDT LSRH.LDT CGR~LDT HTEN.'LDT T~C~U CNTC'CNL CALI.CNL T:O~,.NGT W2NG,N~T ~TEN'NOT TENSiBOT M~FDTE :XL~ DTE IXMDTE CGR DTE HTENDTE PEF LDT LU~bDT SS2~LDT LSRH CGR bDT HTEN, LDT TNRA' CNTC,~NbNb CRh.X.CNb MTEM.CNL THOR.NGT W2N¢'NOT TENS,NOT HTEN"NGT TENS.BGT CIMP.DTE CIL~'DTE I~QF.DTE IIX~.DTE E 'DIE PEF.LDT bU.LDT SS2.LDT LSRH.LDT CGR.LDT HTEN bDT TNRA:CNL CNTC.CNb CAbI.CNb STEM.CMS THOR.NGT 3,027 330,500 316,.750 2~:289 82'459 1675'000 3,632 1973 499 9 477 93375 .9.907 19223~ 3875 000 3675 000 -999 250 174,500 1.80,250 0,000 6 · 2 717 392 500 324 750 2 197 ~oo 2!9~ 403279 9 ,189 93 75 3865' O0 ~695'000 999'250 115 563 126 750 0 000 46 719 66 802 1682 000 3 049 389,250 331,750 2'203 66,802 1682'000 3,332 2336,608 8,969 93,438 9,622 iS ~epe verification bisting ;hlUmberg'er Alaska ComPutin~ Center POTA.NGT W~N~.NGT MTEM.NGT GRiBGT DEPT*., !:~PH,DTE I~'DT~ i!RD~DTE SFLU'DTE TENS.'DTE DPHI'LDT OLS'LDT LL,LDT LSHV.LDT LURM,bDT TENS~LDT NPH~'CNL CFTC'CNL CALM'CNL HTEN,CN5 POT~'N~T GR'BGT DEPT Ib~ DTE iIRD DTE SFLU DTE TEN$,DTE DPH! LDT OhS LDT Lb bDT LSHV bDT LURH bDT TE~$,bDT NPO~,CNL CFTCoCNL CAb$,CNL H?EN,CNL POTA,NGT ~TE~,NGT G~.BGT DEPT. I~PH.DTE IL~.DTE I!RD.DTE SFbU.DTE TENS.DTM 30.784 93.438 -999.250 5300.000 6,664 6,363 140,875 3750,000 28.033 '0 020 225 87:5 !707 000 ,000 39.::!86 38 289 679349 8.992 1705000 O0 g3,125 -999,250 5200:000 3 611 3 570 230 375 3 428 3675 000 20 361 -0,,010 184,500 t707 000 2 307 3675 000 39 280 38 629 705 997 9 398 1709 000 1.384 28 770 92275o '999.250 5100,000 1'612 1,613 491,750 2'049 3685,000 URAN.NGT W4NG.NGT ~..RES.NGT C1,BGT C D 'DT C~LD,,DTE IfRE~DTE IIXD.DTE SP,DTE MTEM..DT~ RHOB:~LD~ OSS bDT bITH bDT SSHV bDT CALI bDT MTEM bDT RTMR CNb RCNT CNL SGR CNb TENS CNL SGR NGT URAN,NGT W4NG'NGT MRES. NGT C~.B~T CIDP'DTE CILD,DTE. IFRE'DTE IIXD'DTE SP.OTE MTEM.DTE RHOB.LDT Q$S.LDT LITH'LDT SSHV.LDT CALI bDT MTEM!LDT RTNR CNL RCNT.CNL SGR.CNL T~N$.CNL MGR,NGT URAN.NGT W4NG.NGT MRE$.N~T C1.BGT CIDP.DTE CILD.DTE IFRE.DTE !IXD.DTE SP'DTE MTEM.DTE 12-JUN-.1991 15:20 0.940 W!NG,NGT 9.325 W5NGj~GT: 1,950 CS~,NGT 999. 250 C2 ~BGT 157,8'75 160.500 20'000 -34.. 4 o 140 5 1357 000 9 008 9~ 125 654 2137 092 64 558 3750 000 64 ,558 1 363 4 98O ,50 66:.250 .000 20.~34 -25, 91 92.750 2,314 0 O2O 114i625 1357 0~0 ]! o 9 ~50 ! 68.156 75.000 3668,156 2.282 9,921 1.965 '999.250 625.500 32.500 620,000 !07.938 -61.531 92,313 IDPH.DTE iLD,DTE IDOF,DTE IIRM,DTg '$GR..DTE ~RE$,DTE DRHO,bDT LS,LDT $$1,LDT SlRH,LDT SGR,LDT MRES,LDT TNPH.,CNL RcFT,CNL CGR,CNb MRE$,CNb CGR,NGT WING,.NGT WbNG,NG? CS,NGT C2.BGT IDPH,DTE ILD,DTE IDOF,DTE SGR,DTE MRES.DTE DRMO,LDT L.S.LDT S$1'LDT :SlRH.LDT SGR,bDT MRE$.LDT TNPH,CMh RCFT,CNL CGR.CNb MRES,CNL CGR.NGT W1NG.NGT WbNG.NGT CS.NGT C2.BGT IDPH,DTE ILD.DTE IDOF.DTE IIRM,DTE $GR,DTE MRES.DTE 230'410 5~597 .250 6.328 6.227 0'000 148.125 64-558 .1,:954 ,.0'007 423,000 2202S00 64'558 !'954 39.555 649,442 54,295 1,954 54.295 216,135 6'972 ~789,000 999.:250 3 754 3 676 0 000 261 750 68 156 o 347 ,750 222. 875 2 27! 68 456 1 65 37 85.1 649 442 51.661 1,965 52.661 215.278 6.944 1.807.000 999,250 i.598 1.580 0.000 566.500 68.542 2.010 W2NG,NGT TENS.NGT HTEN'NGT TENS.BGT CIMP.DTE CILM.DTE IMQF'DTE IIXM.DTE CGR.DTE HTEN'DTE PEF,LDT LU,LDT SS2'~DT LSRH'[.DT 'CGR.bDT TENi~DT NRA CNb CNTC CNL CAP! CNb MTEM,CN5 TMOR,NGT W2NG,NGT TEN$~NGT HTEN'NGT TENS'BGT ClMP:.DTE CIbM'DTE IMQF.DTE I'IXM,DTE CGR,DTE HTEN*~DTE PEF,5DT LU.LDT ~S2.LDT LSRH.LDT CGR.LDT HTEN.LDT TNRA.CNb CNTC.CNL CALI.CNL MTEM.C~L THOR.NGT W2NG,NGT TEN$,NGT HTEN'NGT TEN$,BGT CIMP.DTE ClLM.DTE IMOF.DTE IIXM,DTE CGR.DTE HTEN.DTE PAGEI 3775' 999' · ~50 5~ 225791 9~ 8, 9~ 3750 0 3 5 1704 2 51 1709 2280 92 9¢ 3675 1709 -999 62O 619 0 46 7O t659 679 000 000 250 000 000 000 758 295 ;000 783 500 250 193 295 0 0 4O 633 000 000 250 75O 750 000 305 66i 000 814 500 75O 305 66 320 75O 2O6 000 000 25O 000 500 000 533 000 ::~ Ta~e Verification Listing :hlumberoerAlaska Computing Center DPHILDT 058 LDT bb. LOT LURH LOT TENS. bDT NPM! CML NPOR CNb CFTC CML CI. LS CNL HTEN CML POTANGT W3NG NGT STEM NGT GR,BGT I MpH, DTE b~DTE! IIRD'DTE SFLU'DTE TENS'DTE DPH!,LDT ObS.'LDT Lb'bDT bSHV'LDT LURW'bDT TENS,bDT NPHT'CNL N:POR~CNL CFTC,CML CAbS.,CN[., HTEN,CNL POT~.NGT W3NG,NGT STEM.MST GR.BGT DEPT, IMPM.DTE ILM.DTE I!RD,DTE SFLU DTE TENS:DTE DPHI.LDT OLS.LDT Lb.bDT LSHV,LDT LURW.LDT TENS,LOT NPH! CML CFTC.CML CAbS,CML HTEM,CNL 33.031 '0,013 265'500 1707,000 3605'000 38:597 38 453 705 954 8 664 !659 000 · 2 ,128 30,632 92,353 -999,250 5OOO 000 4 176 4 !76 205 750 4,:156 3630,000 19,246 -0,007 176'!25 1707'000 2;334 36.30.000 43'031 40,432 648'55.4 9'070 1713,000 2,167 53 ~71 91:50 -999,250 4900 000 6:398 6.148 134o000 6,727 3395,000 22,128 -O.008 193,375 1706.000 2.283 3395.000 39.247 38.860 73~,309 10.070 1619,000 RHOB,bDT OS$,LDT LITE bDT 'SSHV bDT CAb! LOT ~TEMbDT RTMR CNb RCNT CNL SGR CML TENSCNL SGR NGT URAN NGT W4NGNGT MRE$.NGT C1BGT CIDP,DTE CI!~D,DTE IFRE,DTE IIXD,DTE SP.DTE ~TEM,DTE RHOB'LDT Q$S'LDT blTHLDT SSMVLDT CALI bDT RTNR CNb RCNT CML SGR CNb TENS CML SGR NGT URRN NGT W4NG NGT MRE$.NGT C! BGT CXDP,DTE CILD,DTE IFRE,DTE iIXD.DTE SP,DTE MTEM.DTE RHOB,LDT ~SS. LDT bITH.bDT SSMV,LDT CAbI,LDT MTE~,LDT RTNR.CNL ~CNT.CNL SGR,CNb TENS, CML SGR,NGT .12-JUN-1991 15120 2 · 105 0,00! '000 8 648 92 3 32 :232~ 486 68 542 3605 000 4:10941 2. l0 -999. ~50 240,250 239~750 26;000 .27;391 .19'813 250 0'010 101'063 1357.000 9'328 91.250 3 519 I 302 3630 000 !03 302 3 076 2 35 -999 50 150. 5 20,000 13'375 -40o0~3 90.6 8 2.285 0 007 121 063 1357 000 10 086 90 688 3 862 2440 6~2 68 898 3395 000 68 898 IDPH!DTE 'iLD,,DTE IDQF.DTE IIRM.DTE SGR~,DTE MRESDTE DRHO bDT LS bDT SS!bDT SIRH bDT SGR bDT NRES'LDT TNPH,CNL RCFT,CNb CGR,CML ~RES,CNL CGR,NGT W1NG,NGT W5NG NGT CSiNGT C2 BGT IDPH,DTE XLD,DTE IDOF,DTE IIRM,DTE SGR,DTE NRES,DTE DRHO,hDT LS.bDT S$1,bDT S1RH,LDT SGR,LDT MRES,bDT TNPH,CNb RCFT,CNL CGR CNL MRES:CNL CGR,NGT 0 194 1808 -999 '0,009 PEF,BDT 492.000 bU,LDT 223'.375 SS2,bDT 2' 150 LSRH ~hDT 68,5.42 CGR,LDT 2 .010 HTEN,'LDT 38:720 TMRA,CNL 609 ,I.19 CNTC,CNL 70 533 CAbI'CNL · 2 010 ~TEM-CNb 533 THOR,NGT 664 W2NG'NGT 0929 TENS,MST 00 HTEN'NGT 250 TENS~BGT 4,160 CiMP,D~ 4i168 CXLM.DTE 0,000 iMOF'DT~ 224,500 iIXM*DTE !03,302 CGR.OTE 2'035 MTEN. DTE 0.003 PEF. bDT 332,250 bU bDT 218 !25 882 LOT 2 3t8 bSRH bDT 103:302 CGR bDT 2 035 HTEM 40 499 :T'NRR CML 590 632 CNTC CNL 860 CAbI,CNL 729 035 ~TEM.CNL 79 860 THOR NGT 9 .921 TENS NGT 1767 O00 HTEN NGT -999.250 TENS BGT 6,645 CIMP,DTE 6 602 C/L~,DTE 0 .000 XMOF.DTE 153 250 IIXM.DTE 68 898 CGR.DTE 2 029 HTEN.DTE 0 003 PEF,bDT 363 000 LU.LDT 221 250 GS2,LDT 2 268 LSRH.bDT 68 898 CGR,bDT 2 029 HTEN.LDT 38.771 TNRA.~NL 703.605 CNTC, NL 50.871 CAb!.CNL 2.029 STEM.CML 50.871 THOR,MST 2'316 452,500 338,500 .2,!!3 70'533 1659'000 3,:260 2297-153 8,648 92,3:I3,~ 98.*.8:14 ::3605,000 :16:59,~000 :999,.250 375 0 000 !7!3 000 3,025 312.:500 . 1713,000 3558 2202 250 9 328 91 250 1~ 453 141 865 363O 000 ~1713 000 -999 250 156,125 162,500 0,000 1,242 50,871 1619,000 2.816 339,000 281 50.87.1 1619,000 3,414 2429,028 10.086 90 688 '..S ?a~e verification 5istinq :blUm..berqer Ale. s~a Computing Center W3~.iG.NGT 690 NTEM.NGT . 90~688 GR,BGT 999,250 DEP?. I'NpH,DTE 'ILM,DTE IIRD'DTE S~LU'DTE T~IN$'DTE DPHI"LDT ~LS,LDT LL.LDT LSHV'LDT LUR~DT TENS'LDT NPH!.CNL NPOR.CNL C. FTC'CNL HTEN"CNL POTA.NGT W3NG.NGT MTE~,NGT GR.BGT DEPT. . -DIE IIRO'DT~ FLU'DTE TENS'DTE DPHI.LDT OLS'LDT LL.LDT LSHV.LDT LURH.LDT TENS LDT NPHI:CNL NPOR.CNL CFTC.CNL CAL$.CNL HTEN.CNL POTA.NGT W3N~.NGT ~TE~.NGT GR.BGT DEPT I~P~iDTE I5~ DTE I!RD.DTE SFLU.DTE T~NS.DT£ 4800.000 5,352 5,164 158,875 5,168 3370,000 25,'87.3 -0021 214500 1706.000 00 35,895 37 622 763 547 9 .3~3 !571'000 1,985 48,507 90,250 -999,250 4700,000 4,445 .4 340 186~625 5 992 3315:000 31.750 0.008 255 125 1706 000 2 150 3315 000 37 391 37 809 751,092 8 969 1612100o 0,920 23,810 89,375 -999.250 4600,000 19,391 18,469 51,250 20.578 3210,000 RAN.NGT 4MG'NGT MRES, NGT CI.BGT C!DP,DTE CILD.DTE XFRE'DTE IIXD,DTE SP,DTE HTE~*DTE ~HOB'LDT QSS,LDT LITH,LDT SSHV,bDT CALI,LDT MTE~LDT RTNR,CN5 RCNT'CN5 SG~CNL URAN,NGT 4NG,NGT MRE$,,NGT CI."BGT CILD:;DTE IFRE,DTE IIXD~DTE SP'DTE MTE~'DT'E RHOB,LDT O$$,LDT LITM,LDT SSHV,LDT CALI,LDT ~TEM,LDT RTNR,CNL RCNT. CNL SGR:C~L TEN$,CNb SGR,NGT URAN,NGT W4NG.NGT ~RE NGT CIDP.DTE CILD.DTE IFRE,DTE IIXD.DTE SP.DTE ~TE~.DTE 12-JUN-1991 !5:20 2.454 WING,MGT 10,913 WSNG,.N~T 2,029 CS,NGT · 999,250 C2.BGT 80,87 2:0, 0 14.719 -51'406 .. 223 40,006 15,1.25' 1357,000 9,477 90,250 3,395 2428'879 77,30:2 70;000 3377~302 ~'327 ,045 50 220 00.0 17 2 6 -0 012 171 000 1357 000 8 961 89 375 242~ 196 54 430 ]3!5 000 54 430 1.380 3.968 2.070 -999,250 53.531 57.500 20.000 2.908 -70.438 88.625 IDPH DTE 1LD DTE IDQF .DTE IIRM DTE SGR DTE ~RE$ DTE DRHO bDT L$ LDT SS bDT SlR~ bDT sG~ bDT MRE$ 5DT RCFT CNL CGR CNL MRE$ CNL CGR,NGT W1NG,NGT W5NG,NGT CS.NGT C2.BGT IDPM,DTE XLD,DTE IDQF,'DTE IIRM,DTE SGR,DTE ~RE$,DTE DRHO bDT LS:LDT $$1,LDT SlRH,LDT $GR,LDT ~RES,LDT TNPH.CNL RCFT,CNL CGR.CNL ~RES,CNL CGR,NGT WiNG,NGT W5NG,NGT C$,NGT c2,BGT IDPH,DTE ILD,DTE IDQF,DTE IIRMDTE SGR:DTE MRE$,DTE 230 7 5 5 0 182 77 2 -0 403 2.21 77 62 23.3 4 4 4 2 -0 467 218 2 54 2 37 703 47 2 47 183 5 1778 -999 18 17 0 51 42 2 ~937 000 ' 250 · 3 .000 125 302 045 00.1 250 125 229 302 045 161 206 2.18 045 218 209 664 000 250 70 47 25 43O O7O 016 5OO 000 2O5 430 070 744 6O5 ?O7 070 7O'/ 532 952 000 .250 .672 .375 .000 ,375 .118 .082 W2NG,NGT TENM.NGT HTEN,NGT TENS.BGT CI~IP,,DTE CXLM,DTE IMOF'DTE X!'XM.DTE CGR,DTE HTEN DTE PEF 5DT LU LDT 882 bDT LSRH LDT CGR LDT HTENiLDT TNRA:,CNL CNTC CNL CALl cnn ~TEN C~L THOR NGT W2Ni NGT TEN NGT HTE'N NGT TENS BGT CIMP DTE CIL~:DTE IMQF-DTE IlX~,DTE CGR,DTE HTEN,DTE PEF bDT 2 bDT LSRH LDT CGR.LDT HTEN.LDT TNRA.CN~ CNTC.CNL CALI.CNL MTEM,CNL HOR, T NGT W2NG,NGT TENS,NGT HTEN.NGT TENS,BGT CXMP.DTE yILM.DTE HQF.DTE IIX~.DTE CGR.DTE HTEN.DTE PAGE{ 13 104, i 67 3395,000 99,250 186 625 193 625 0 000 0 452 62 218 1571 000 2 566 377 250 32'7 250 2 223 62 218 1571 000 243~ ..180 1.06 9 477 90 250 13'2 3370 000 157! 000 -999 250 224., 7 50 2300~ 375 ~ 00'0 92 o½, 47 O~0 1612 305 0 334 2 141 47 707 1612 000 3 220 2408 417 365 3315,000 1612,000 -999.250 51,53i 54.09 0.000 696 1607,000 TaPe Verification List~no ~h!umbergerAlaska Computing Center DPHT.bDT OhS.bDT LL,LDT LSHV,LDT DURH bDT TENS bDT NPH! CNL NPOR CNL CFTC CNL CAbS CNL HTE...' CNL POTR NGT W3NG NGT MTEN NGT G~.BGT INP~,DTE IL~.DTE IIRD,DTE SFLU.'DTE TENS'DTE DPHIiLDT ~LS'LDT LL.LDT LSHV'LDT T~NS"LDT 'N NPHI,C~L NPO~.CNL CFTC.CNL CAbS'CNL H~EN.CNL PGTA.NGT W3NG.NGT ~TE~'NGT GR'BGT DEPT. IMPH:DTE Ib~.DTE I!RD.DTE GFb~.DTE TENS.DTE DPHI.LDT OhS.bDT LL.LDT LSHV.LDT bURH.LDT TENS,bDT NPHI.CNL NPOR.CNL CFTC.CNL CAb$.CNb HTEN,CNL 31,187 -0,004 254,875 1706,000 2,1.43 3210,000 6,,861 8~643 763'51.4 9'383 1607;000 · 1,245 ..8'625 '999,250 4500.000 17,219 17' 46,~31 44 18,344 3400;000 34'314' O25 1706'000 2 084 3400 000 44 316 44 801 667 992 10 125 1721,000 0,896 20,833 88.188 -999,250 4400.000 8.109 7.891 118,563 8.773 3370 O00 2i745 ~0 017 262.250 t706,000 2.117 3370.000 41,484 40.909 723.942 9.281 1714.000 RHOB,LDT OSS,PDT bITH,LDT SSHV LDT CALl bDT MTEMLDT RTNR CNL RCNTCNL SGR. CN5 TENS~.CNL SGR NGT {IRAN NGT W4NG.NGT MRES'NGT C1,BGT CI. DP'DTE CILD,DTE IFRE,DTE IIXD,DTE SP,DTE MTE~,D. TE RHOB~LDT OS$,LDT LXTH.bDT ~SBHVLDT CALILDT STEM bDT RTNR CNb RCNT CNb SGR CNb TENS CNL SGR NGT URAN NGT W4NG. NGT MRE$.NGT CI BGT C!DP,DTE CILD.DTE IFRE,DTE IIXD,DTE SP.DTE MTE~.DTE RHOB.bDT OM$.LDT LITH.bDT SSHV.LDT CALI.LDT MTE~.LDT RTNR.CNL RCNT.CNL SGR.CNL TENS.CNL $GR.NGT 12,'JUN'-1991 15120 PAGEI 14 2 135 Oo05 375 1.74 1356 00:0 8~ 586 625 33:467 250492 421i8 32i0 000 8 4 960 :2,082 '999,250 50,906 51',875 2O;000 O,020 -66'688 O, ~ 200'~ 2 !357.00~ 10:203 88 t88 954 22.5 413 3400 ~000 45 413 0,699 9~0 -999 250 ,000 120.000 9 313 -50~063 87,625 2.110 1 ,~50 1356, 00 5 3,724 2416.227 52.510 3370 o00 DRHO.LDT 25 LDT SSi bDT $1RH bDT SGR bDT MAES LDT :TNPH CNL RCFT.CNL CGR.CN5 MRES.CN~ CGR~NGT W1NG,NGT NG,NGT WSCS.NGT C2,BGT IDPH,.OTE ILD'DTE ID~F,OTE SGR'DTE MRE$~;DTE DRMO.,hDT bS.LDT SSi,BDT SIRH,bDT SGR,bDT MAES'bDT TNPH'CNL RCFT.CNL C~R,CNb MRES,CNL CGR.NGT W1NG.'NGT W5NG.NGT CS.,NGT C2.BOT iDPH.DTE ILD.DTE IDOF.DTE IIRM.DTE SGR,DTE MRES,DTE DRHO'bDT I,S.~DT SSI.LDT SlRH,bDT SGR.bDT MRES,bDT TNPH.CNL RCFT.CNL CGR.CNL MAES.CML CGR.NGT -0~004 470;250 22:5 ,500 2 2 .42 18 2 082 38 647 695 084 46 696 2 O82 46 696 129 960 5 ooo 17~ 952 -9 250 !~ 625 266 !o ooo 55 719 45:413 ~ 098 . 007 515 000 ':413 42'243 ~557,273 41.111 2.098 4 1,11 12~ 024 5 1764 000 =999 250 7 781 7 629 0 000 119 750 52 510 2 109 -0 012 487 250 221 375 2 168 52 510 2,109 40.113 692.574 41.255 2.109 41.255 PEF.LDT LU.LDT BS2,LDT LSRH,LDT CGR:~LDT MTENeLDT TNRA.CN5 CNTC,CNL CALI,CNL M:TEM,CNL THOR.NGT W2NG~NGT TENS,NOT HTEN'NGT TENS'BGT ClMP,DTE C!L~,DTE CGR'iTE HYEN,DIE PEF.bDT LU,LDT SS2'bD~ LSRH.LDT CGR'bD? HTEN,LDT TNRA'CNL CNTC,CNL CALI.CNL MTEM,C~L THOR.NGT N2NG.NGT TENS.NGT HTEN NGT TEN$:BGT CIMP.DTE CILM.DTE IMOF,DTE IIXM,DTE CGR,DTE HTEN.DTE PEF.LDT LU.LDT S$2.5DT LSRH.LDT CGR.LDT M?EN.LDT TNRA.CNL CNTC.CNL CALI.CNL ~TEM.CNL TBOR.NGT 2.213 430.750 337'750 46,696 X607,000 3,243 2513'313 8~i58'6~75 77;38S 3210,000 1607,000 "999,250 '58,031 58'688 .0'000 '6,180 4&'1il 22:54 478.000 "33~ ,000 ~090 4~ 1'721 3 700 2365 464 10 203 88 188 6 796 69 444 3400 000 1721 000 -999 250 250 0,000 1,275 41,255 1714~000 2'311 449,750 337,500 2'121 41,255 1714.000 3 475 2441:567 9.352 87.625 4.991 :S TaPe~ Verification Li lhlumberger Alaska Comp W3NG.NGT MTEM,NGT (;R, BGT DEPT' .DTE IIR. D~DTE SFbU,DTE TENS DTE DPH! bDT 058 bDT LL bDT LSHV bDT LURH bDT TENS bDT NPH] CNL NPOR CNL CFTC CN L W 9N~' NGT NTEM.NGT ~R.BGT DEPT' IMPH. DTE ISM DT~ I I R D ' .DTE ~FLU-, DTE TENS., DTE DPHI,LDT OhS,bDT Lb'bDT bSHV,LDT LURH bDT TENS~LDT NPHI CNL NPOR.CNL CFTC,CNL CAbS CNL WIN NGT GR.BGT DEPT, IMpH.DTE ILM,DTE IIRD.DTE SFLU.DTE T~NS.DTE 1,346 26,000 . $7,6~5 .999,250 4300.000 7,035 6.8!3 127'750 7,8.79 3635.000 33,231 -0,016 27.1'250 1706'000 2,102 3635'000 42:120 41~510 636240 9.563 1851 000 2 029 41 509 87 125 '999 250 000 6,250 132,0.00 5,762 3525,000 39,020 -0,007 319"750 1706.000 2'012 3525 000 50 970 49 753 422 875 10 133 1786 000 2,262 45,363 86.250 '999,250 4100,000 5,547 5,512 152,500 4.879 3210,000 ~t~nQ Cente~ URAN.NGT ~4NG,NGT C1-BGT CIDP,DTE CI~D'.D?~ IFRE~'DTE IIXD-DTE SP'!DTE MTEM~DTE RHOB~LDT OS$,LDT 5.ITH.LDT SSHV,LDT CALI,LDT' MTEM bDT RTNR CNL RCNT CNL SGR CNb TENS'CNL SGR.NGT URRN'NGT W4NGiNGT MRES'NGT CliBGT CIbD'DTE IFRE'DTE IIXD.DTE SP,DTE MTEM,DTE RHOB,bDT QSS.bDT bITH.LDT SSHV.bDT CAbI,LDT MTEM'bDT RTNR,CNb RCNT"CNb SGR.CNb TEN$.CNL SGR,NGT URAN,NGT W4NG,NGT MRES.NG~ C1,BGT CIDP,DTE CIbD,DTE IFRE,DTE IIXD.DTE SP.DTE MTEM,DTE 12-JUN-1991 i5:20 1,451 4,000 92,109 99,250 1'42,250 145'000 20'000 . 7,4~ 43,4 ~ 87,I~5 2.i 2 0.012 !69;250 1356'000 9'29'7 87,125 ~;571 2192.075 65'387 635.000 bs;3s7 0,117 5,660 2.135 999'250 1~0.0~0 5 8 539 -44 438 86 250 OO6 1356 000 10 398 1620,672 90.236 3525,000 90.236 0,669 9,073 2.127 '999,250 172.875 174.625 20.000 9,758 -42.500 85.625 W!NG.NGT W5~G'NGT C$'NGT' C2'BGT IDPH.,DTE ILD'DTE IDQF,DTE IIRM,DTE SGR'~DTE MRES'DTE DRHO~bDT .US,bDT SSi,bDT S1RH'LDT SGR,LDT MREShDT TNPS CNL RCFT CNL CGR CNb MRES CNb CGR NGT WiNG :NGT WSNG NGT CS. NGT C2 BGT IDPH.DTE IbD.DTE ID~F.DTE IIRM'DTE SGR,DT£ MR~S,DT~ DRHO,LDT S$1,LD? $1RH.LDT S~R,LDT MRE$,LDT TNPH,CNL RCFT,CNL CGR.CNL MRES,CNL CGR,NGT WING NGT WSNG:NGT C2,BGT ID~H,DTE ILD,DTE IDQ~.DTE IIRM,DT£ SGR.DTE MRES,DTE 1,000 1'73.000 000 9 250 7 027 6 891 0 000 138 500 0.002 502 500 2312 500: 65.38 ~ .135 41.252 592 025 65 O86 2 ,135 65 086 215 094 lO 377 743 000 ~999 ,250 0 O0 0.236 2,127 -0 003 591 500 233 125 2 018 90 236 370 793 127 85.841 07~ 750.000 ~999.250 5.777 5.723 0.000 170.750 93.624 2,184 W~NG.NGT TENS,NGT HTEN. NGT TENS.BGT CIMP,DTE CILM,DTE IMQF'DTE .IIXM~.iDTE CGR.DTE HTEN=~.DTE PEF..LDT bU bDT S$2 bDT LSRH~LDT CGR bDT HTEN LDT TNRR CNL CNTCCNL CAb! CNL MTEM C:N'L THOR NGT W2NG NGT TENS NGT HTEN'.NOT TENS,BGT CILM'DTE IMOF'DTE XIXMDTE CGR:DTE HTEN,DTE PEF.LDT _LU.LDT ~S2.LDT LSRH.LDT CGR.LDT HTEN,LDT TNRACN CNTC:CN~ CAhX,CNL MTEM,CNb THOR,NGT W2NG.NGT TENS,MbT HTEN,NGT TENS.BGT CIMP.DTE CIL~.DTE IMQF,DTE IIXM,DTE CGR,DTE HTEN,DTE PAGE: 15 63,000 3370,000 1714o000 '999,250 142,000 000 -2,516 .462'500 34~.,250 ,098 65-086 3'506 2!89,329 9~297 87~125 566 3635'000 ~851'000 999,250 158.750 159,875 0'000 -3 229 85 841 1786 000 29 2 ~00 544 357 750 2 008 1786 4 079 1655 183 10.398 86'250 12,588 144,i53 525,000 786.000 999'250 180.125 181,250 0,000 -0.59.4 82,848 1691,000 blumberger A ask. CoMputing Center DPHI,LDT OLS,LDT LL.LDT DSHV ·LDT LURH, bDT TENS bDT NPHI CNG NPO~ CNG CfTC CNG CAbS CNG HTEN CNG POT NG W3N~ T NUT NTEM NGT GR, BUT DEPT. !LM.DTE iIRD'DTE SFLU,DTE TENSSD'TE DPHI*LDT OhS'bDT bSMV,LDT LU~H'LDT TENS.bDT NPHI'CNL NPOR.CNL CFTC.CML CAbS.CNG HTEN,CNL PPT~'NUT W3NG.NGT MTE~.NGT GA.BUT DFPT IMPH:DTE ILN,DTE IlRD.DTE SFbU.DTE TEN$.DTE DPHI.LDT OLS,LDT LL.LDT LSHV.LDT LURH.LDT T~N$,LDT MPHI.CNb NPOR,CNL CFTC.CNG CAbS.CNG HTEN.CNL 29,i184 ~0.0!3 24 !,70~ o00 2 160 3210 000 46 024 40 626 :530 874 10 047 1691,000 113 . ~5.625 999,~50 4000000 6 988 6 891 !19 750 6 :!64 3235 000 33,512 -0.027 262'000 ~706,000 3235,000 41'755 39'005 667'008 9.~27 !721.000 1,590 43,173 84,313 -999.250 390~.000 7 ,285 ,121 125,938 7.477 3215.000 35,!79 0.004 209,500 1705.000 2.078 3215,000 44,580 45,364 664.656 8.977 1760.000 RHOB bDT QSSLDT LITH LDT ,SSHVLDT CALI~LDT MTEM~LDT RTNR,~CNL RCNT. CML TEN$~ NL SGR NGT URAN NGT W4NG ~T ~RES ~T Cf.BUT CIDP,DTE C!LD~;DTE !FRE.DTE IIXD'DTE ~TEM..DTE RHDB'bDT OS$,LDT LITH'LDT SSHV bDT CALIbDT ~TEM bDT RTNR, CN5 RCNT~CNL SGR:.CNG TENS. CNG SGRNGT URANNGT W4NG NUT MRE$ NUT C1.B~T CIDP.DTE CILD,DTE IFRE.DTE IIXD.DTE SP.DTE MTEM,DTE RHO'B.LDT OSS.LDT LITH.bDT SS~V.LDT CALI.LDT STEM.bDT RTNRCNL RCNT:CNL SGR.CNL TENS.CNG SGR.MGT 12-JUN-1991 15:20 2 168 0 011 147· 750 1356 000 9 906 85 625 18~984760 3 624 3210 000 · 4 7 519 2 184 -999 250 135 20 000 7 094 -46 406 84 313 2 097 -0.0!7 185 625 1356 000 9 266 313 8~469 2410 397 68 828 3 000 326~ 828 2 548 032 ~ 162 -999:.250 l t. °o .375 20,000 10,828 '56,281 83.625 2,070 0.0~2 199,3 5 1355,000 625 4.108 2361.522 61 208 3215:000 6~.208 b$,LDT S$1'LDT SiRH'LDT 8GR'~OT MRES.LDT TNPH;CNb RCFT.CNb CURCNb ~RES CNG CUR,NUT WING,~GT WbNG'NGT C2,BGT IDPH,DTE ILD'DTE IDOF.DTE IIRM'DTE SGRiDTE ~RE$,DTE DRMO,LDT LS'LDT SS.i'LDT ·$1R,LDT SG~,LDT MAES,bDT TNPH'CNb RCFT,CNb CUR,CNG ~R. ES,C~L CUR,NUT W1NG,NGT NUT W5NG. CS,NUT Cl,0GT IDPH,DTE XLD,DTE IDOF,DTE IIRM.DTE SGR,DTE ~RES.DTE DRHO LDT LS~LDT SSI,bDT S1RH,LDT SGR,bDT MRE$.bDT TMPH CNG RCFT:CNL CUR.CNG ~RES.CNL CUR.NUT · :000 GU,bDT 23~ 000. SS2,~DT ~09 LSRH,L~DT 3 62.4 CGR,LDT 92 '!84 HTE~.LDT 40 667 TNRA~i~CNL 482 222: CNTC,CNL 848 CALl.CNG 8~ t84 STEM,CNG 3~ :848 THOR,NGT 51!. ~2'NG.NGT 14.098 TENS.NOT 1796 .000 HTEN'NGT -999 250 TENS,BUT 7 7 o !36 68 2 "0 489 2.16 2 68 2, 49 49 7 1781. -999 i~83 CIMP.DTE 97 CILM-:DTE ii~00 I~OF,DTE 75 IIXM.DTE :8~8 CUR'.DiE 2 HTEN"DTE :~20 PEF.*LDT 750 ~U'LDT 625 SS2.LD? 197 828 CUR.bDT 162 HTEN,bDT 095 TNRA.CN~ 788 CNTC .162 STEM :CN~ 193 THORNUT 980 W2NG NUT O28 TENSMGT 000 HTENNOT 250 TENS 7.215 CIMP.DTE 7.:066 CILM.DTE 0.000 iMOF.DTE 132.500 IIXM.DTE 61.208 CGR.DTE 2.188 HTEN.DTM -0,004 PEF,LDT 530.500 GU,bDT 228.875 SS2,LDT 2,088 bSRH.LDT 61,208 CUR,BDT 2.188 HTEN,LDT 44.227 TNRA.CNL 643.043 CNTC.CNL 54.676 CALl.CML 2.188 STEM.CNG 54.676 THOR.NUT PAGE: !6 2 799 4~7 750 346 500 2. 156 82' 848 1691. 000 :3 769 1821 856 9 906 85,625 12, :650 142'857 32i0' 000 1691,000 '999~ 250 4 'ooo 145;000 0' :000 8'242 49,, 193 172 !!.2:000 2 242 455~ 500 3~6 500 49 93. ! 72~ 000 92! 228~ 483 266 84 313 6 :0 '~3 3235 000 !72i 000 -999 250 137 125 140 250 0 000 - ! 496 54 ,676 176~. 000 ~ 441 482 000 348 750 2 072 54'676 ~760,000 3,61~ 2399.73 8,961 83,625 5,440 ;hlu~berger Alaska CompUting Center 12-JUN-i991 15:20 P4GE: 1.7 pOTA'NGT 2 071 UR~N.NGT 1.023 W3[~G.NGT 31 124 W4NG,NGT 3.012 MT~i~.NGT 83 62:5 ~RE$.NGT 2.188 GR'BGT -999 250 CI.BGT ,.999.250 DEPT. T 3800.000 Ii~PH.D..:.E 7'832 IU~'DTE 7'477 IIRD,DTE 115~!88 SFL!.,!,DTE 8'250 TENS,DTE 3240,000 DPH!,LDT 35,914 QLS.LDT -0,007 bDT 291.,500 bSMV bDT 1705,000 LURM':LDT 2~066 TENS.bDT 3240'000 NPHI~CNL 36,224 NDOR'CNL 37'598 CFTC.CNL 703~439 C~.DS,CNL 10,539 HTEN.CNL !768.:000 POTA'NGT 1'813 W3N~.NGT 37.7.36 NTE~'NGT 83.063 GR'BGT -999.250 DEPT.. I5~ DTE ilRD DTE TENS DTE DPH! bDT OLS.LDT LL,LDT ~URH,LDT TE~8,LDT NPHI.CNL NPOW.CNL CFTC.CNL CALS.CNL MTEN.CNL POTA.NGT W]NG.NGT ~TEM,NGT G~.BGT DEPT. I~PN.DTE ILM.DTE IIRD.DTE SFLU.DTE TENS.DTE 3700 000 6 926 6 922 121 t88 5 859 3140 000 32!676 "0 029 259 250 1705.000 2.115 40.000 3145.235 41 342 566i985 8 836 1777.000 1,561 35,282 82,3~3 '999,250 3600. 10!, 7. 3230, 000 055 922 000 707 00o C!DP.DTE CILD.DTE iFRE,OTE IIXD, T" SP,DTE ~TE~,DT~ RHOB,LDT OSS,LDT bITH'LDT SSHV bDT CALI bDT ~TE~LDT RTNRCNL RCNT CNL SGRCNL TENS CNL SGR NGT URAN, NGT 'W4NG. NGT ~RES~NGT CI'BGT CIDP,DTE CIbD.'DTE IFRE.,DTE IIXD,DTE SP,DTE ~TE~.DTE RHOB.LDT OSS,bDT LITH,LDT SSHV,LDT CALI,LDT MTE~,LDT RTNR.CNL ~NT CNL GR.:CNL TENS.CNL SGR.NGT URAN.NGT W4MG.NGT MR~$,NGT C1.OGT CIDP.DTE ClLD.DTE IFRE.DTE IIXD.DTE SP.DTE MTEM.DTE 129,000 20,000 9,156 ,53,938 83.063 2 O57 0 000 ooo 000 9 71! 8~ 063 277 23~650 3240000 61:650 0.6~6 . 182 999,250 13'6,750 138.500 20,000 8,602 -49.094 ,313 8~.111 0 001 16 !35~ 125 000 8 797 82 313 3 829 2097 544 71 427 3140 000 71427 2 ~32 9 73 2.193 -999.250 109.375 12.750 120.000 6,660 -58.000 81.875 WlNG,NGT W5NG.NGT C$'NGT C2'BGT IDPN,DTE IbD,OTE IDOF.DTE IIR~'DTE SGR,DTE MRES,DTE DRH0"LDT b$"bPT SSi,bDT SlRH'bDT SGR,bDT TNP~.CNb RCFT.CN5 CGR,CNb ~RES'CN~ CGR..~GT W1NG,N~T W5NG"N~T CS,NGT C2.BGT IDPH'DTE ILD,DTE IDOF.DTE IiR~'DTE. SGR,DTE MRE$.DTE DRHO.LDT L$.LDT SSI,LDT Si~H,LDT SGR.LDT ~RES.LDT TNPH,CNL RCFT.CNL C~R,CNL MRES.CNb CGR.NGT WlN NGT CS.NGT C2'BGT IDPH.DTE ILD.DTE IDOF.DTE IIRM.DTE SGR.DTE ~RES.DTE 204.819 3, .012 1759.000 "'999'250 7 .46 0 000 126250 6~ 650 182 -0007 538 000 227 250 2;092 .650 653 126 55 787 2 !82 55:787 194 40 9 i ¢~ O0 50 7 7 5 0 0~0 2 193 -0 009 485 250 223 375 ~ 154 427 7~ 193 43 159 526845 55 086 2 55 086 ~27 823 5'040 1799.000 -999,25O 9.141 859 §:ooo !05.938 64.783 2.221 W2NG..NGT TE~S.NGT HTEN'NGT TENS.BGT CI~P.DTE CIL~,DTE I~QF,DTE IIX. M~DTE CGR.DTE HTEN.DTE PEF'bDT LU'LDT SS2,LDT LSRH.LDT CGR;LDT HTEN,LDT TNRA'CNL CNTC"CNL CALI.CNL MTE'M.'CNL THOR.NG'T W2NG'NG:T T£NS,NG'T HTEN:'NGT TENS~BGT CIMP'DTE CILM.DT£ IMOF,DTE IIXM.DTE CGRiDTE ~TEN,DTE PEF.LDT LSRH.LDT CGR.LDT HTEN,LDT TNR~.CNL CNTCCNL MTE~.CNL THOR.NGT W2NG.NGT TENS,NGT HTEN'NGT TEN$,BGT CIMP,DTE CIL~,DTE XMQF.DTE IXXM DTE CGR:DTE HTEN.DTE 96 386 5 000 ooo "999 250 127.625 133,625 O' 000 55' 1768~000 493 0 347 500 2 064 55 7.87 I768 000 3 2!8 2313 229 · 9 711 83 063 6 776 85 849 3240 000 176 ~000 -995. 250 144,250 144,375 0.000 6, :242 55:086 1777 000 2 510 451 750 337 750 5~ 119 1777 0 0 '3 635 2005 817 8 797 82 313 7 628 31 000 1777 000 -999 250 110,375 112,000 0,000 ,,,4.566 48,758 1796.000 Tape Veril!cation bisting hlumb~rger las~a comPut ng Center EPT, ~MpH .DTE ! XRD'DTE S ~b[.!, DTE TENS~DTE DPH]' bDT Qb~,LDT LSHV,LDT LURH, LDT TENS LDT .PHI CNL NPOR CNL CFTC CNL ~TEN CNL W3NG NGT MTE~ NGT GR.BGT DEPT. IMPH.DTE IS~.DTE SFLU.DTE TENS.DTE DPHI,LDT OLS.LDT bL"LDT LSHV.LDT LURH.LDT TENS.bDT NPHI.CNL NPOR'CNL CFTC.CNL CAbS.CNb HTEN.CNL !2,',JUN-1991 15:20 0 000 OS$.LDT 0'007 280 750 bITH,LDT 1~{'~500 ;168 RCNT.C,L 2260' 2 608':289 SGR.CNL 64.783 9,805 TEN$.CNL 3230'000 1796,000 SGR'NGT 64,783 · 1.787 URAN.NGT 2.0~2 39'6~3 W4NG*NGT 9 434 81 75 ~ Eg, NGT: 2:22! -999:50 C1.BGT -999,250 3500,000 672: 8 500 9'500 3195,000 35,574 -0,015 280,000 1706.000 2 082 3195 000 43 475 4~ 44~ 613 472 8 969 1887 000 1.736 34,137 81.!25 '999,250 CQP,DTE CILD,DTE IlXD,DTE SP;DTE ~TEM,DTE OSS.,[DT bITH,LDT SSHV.LDT CAbI'bDT MTEM~LDT RTNR,CNL RCNT',CN~ SGR'CNb TENS CNb SGR NGT URAN N~T W4NG NGT ~RE$ NGT C1,BGT CIDPDTE ClLD:DTE IFRE.DTE SP.DTE ~TE~.DTE RHOB.SDT QS$,LDT bITS.bDT $SHV.LDT CALI.LDT STEM.bDT RTNR.CNL RCNT,CNL SGR,C~b TE~S,CNL 3400.000 13.156 12.828 68.188 31.352 3170.000 31,224 -0.002 246.375 1705.000 2.162 3170,000 35,852 35.673 804.667 !1.6~5 1852,000 97.625 99.875 20,000 4..1~t -57 ~6 2 063 -0 12 !82 ~25 !355 000 9 008 8i 125 959 2201. 551 71 203 3195 000 71 ~03 137 032 2 240 -999]250 73,563 75.938 20,000 2.020 -67.56i 80.31 2,135 '0 005 168 000 1355 000 12 133 80 313 ] 2527 673 46 196 3!70 000 46 196 DRHO,bDT LS'bDT SSt'bDT SlRH,bDT SGR,LDT ~RES'LDT TNPH RCFT CNb CGR CNb MRES CNL CGR NGT WiNG NGT W5NG'NGT CS,NGT C2,BGT !DPH,DTE ILD,DTE IDOF.DTE IIRM,DTE MRES,DTE DRHO,SDT ~S,bD'T 8SI,~DT $1RH'bDT SGR bDT MRE$ bDT TNPH CML RCFT CNL CGR CNL ~RE$ CNL CGR MGT W1NG,iNGT WSNG,NGT C$,NGT C2,BGT IDPH.DT£ ILD'DTE IDQF.DTE IIRM,DTE SGR,DTE MRES.DTE DRHO,bDT L$,~DT SSi,bDT S1RH.LDT SGR.LDT ~RES.bDT TNPH.CNL RCFT,CNL CGR,CNL ~PES.CNb CGR.NGT i 0.:009 PEF, 6'000 U. .121 5SRH~ 4.78~ CGR HTEN 2''~]1 TNRA 4~ 2 48 5 -999 bDT bDT bDT bDT bDT bDT CNL 758 CALI*CN5 22i .MTEM.CNb THOR' 58 GT 92 ~2NG.NGT 660 TENS' .B~GT 000 HTEN.NGT 250 TENS,BGT 10.234 CI~P,DTE 10'=008 CIL~ DTE 0',000 IMOF DTE 97.750 IIXM DTE 71,203 CGR.DTE .240 HTEN ~DTE -0,019 PEF.bDT 520.000 LU.LDT 219,250 S$2 bDT 2,156 ~SRH bDT 42,354 ~NRA CNb 589"665 CNTC:CNb CAbI,CNL 46"4t4 2,240 ~TEM,CNL 46.414 THOR.NGT 227.91~ W2NG.NGT 020 ,NGT 179~:. TENS 000 HTEN.MGT 999.250 TENS,BGT 13 0 73 46 2 -0 455 213 2 46 2 35 742 13 578 ClMP,DTE 156 CXLM.DTE 000 IMQF,DTE 813 IIXM,DTE 1.96 CGR,DTE 273 HTEN.DTE 023 PEF.bDT 000 LU.LDT 250 S$2.LDT 246 LSRH.LDT 196 CGR.LDT 273 HTEN,LDT 021 TNRA.CNL 091 CNTC.CNL 45.546 CASI.CNL 2.273 ~TE~.CNL 45.546 THOR.NGT I8 470 ,750 ,000 · 086 48 758 ,1796 000 10 586 8! 875 3230 O0 !Te ; oo 999 250 00.,438 000 "4 977 46 414 :1887 000 398 4820 000 340 500 2 080 46 414 1887 .000 9 ~ 8 81..'~5 4 708 94 378 3195 000 1887 000 -999 250 75 938 77 875 0 000 =8 109 4 546 185] 000 2 262 O0 5O0 i o 156 45 546 1852 000 3,316 2549.894 12,133 80,313 6,071 Tape Verif{~catlon bi :hlumberger Alaska Comp stino utlng Center 12-JUN-! 991 1.5:20 PAGE: 19 POTA'NGT W3NG,NGT MTE~.NGT DEPT'. iMPH,'DTE tL~.'DTE IIRD,DTE SFLU.DTE TENS,.DTE DPHI.LDT LURH LOT TENS bDT NPHI CML NPOR CML CFTC CML CAtS CN5 HTEN CNb POTA NGT W3NG NGT MTEM.NGT GR,BGT DEPT, Ib~,DTE IIR~'DTE SFb ~DT'E TENS.DTE DPHI.LDT OLS.LDT LL.bDT LSHV LOT LURH:LDT TENS.LOT NPHT.CNL NPO~ CML CFTC:CML CAbS.CML HTEN.CNb POTA.NGT W3NG,NGT MTE~,NGT GR,BGT DEPT, !~PM.DTE IL~.DTE IIRD.DTE SFLU,DTE TENS.DTE 1 349 25 568 80 313 -999 250 3300,000 !1.594 11,375 75,563 9,930 2910.000 33*550 -000! 270 250 1705 000 2 113 29!i'000 '378 '656 537,.200 ~3914 !749000 '141 79*500 -999,250 3200,000 ~.766 9":563 2959, 36 043 '0,008 '283.000 ~703.000 2 0~4 ~955 000 4O 519 39 505 633 9~5 9 7i9 1782 000 1..373 40°043 79 000 -999:250 3100,000 13,344 12,96! 64~563 11,531 2860.000 URAN,NGT W4NG.NGT MRES.NGT CI,BGT CIDP,DTE CILD,DT~ IFRE.DTE iIXD'DTE SP,DTE MTEM,DTE RHOB,LDT Q$$'LDT LITH,LDT SSHV bDT CALl bDT STEM bDT RTNR CNb RCNT CNb SGR CNL TEN$CNL SGRNGT URANNGT W4NG NGT MRES~NGT CIDP,DT~ CILD~DTE IFRB,DTE IIXD,DTE SP'DTE ~TEM*DTE ~HOB.hDT GS$,LDT bITH'LDT $SHV,bDT CALI.LDT STEM.bDT RTNR.CNL RCNT.CNL SGR.CNL TEN$.CNL SGR.NGT URAN NGT W4NG:NGT MRE$,MGT Cl.BGT ClDP.DTE CILD.DTE IFRE.DTE IIXD.DTE SP.DTE MTEM.DTE O, 77 . 2.2 ] 999,250 82,188 .438 20,000 2.477 '69'500 096 0 009 185 875 1354 000 13.4'77 79 500 4. 172 !9!0 397 60712 2910 000 60 712 "~*!75 +028 ~99~ '285 ,250 .98 313 100 625 2~ 000 957 -68 563 79 000 2 088 0 17 194 ~75 1354 000 627 2319,560 58,932 2955,00o 58.932 0 915 6~494 2 352 -999:250 70.313 71,875 20.000 1,413 -72.188 78.375 W1MG*N~T W5NG'NGT C$,MGT C2.BGT IDPH'DT~ XLD,DTE XDQF'DTE iIRM'DTE $~R'DTE DRMO'LDT LS,hDT S$1,bDT SXRH,bDT $¢R'bDT MRES,bDT TNPH,CNb, RCFT,CNb CGR~CNb MRES'CNb CGR,N~T W1NG;NGT WSNG,NGT CS.NGT C2,SGT IDPH.DTE 'IbD.DTE IDQF.DTE IX~,DTE SGR.DTg MRES,DTE DRHO"5DT SSi.bDT SIRH,~DT SGR'LDT MRE$.LDT TNPH,CNL RCFT.CNL CGR,CNL ~RES.CNL CGR.NGT W!NG.NGT WLNG.NGT CS,NGT C2.BGT IDPH.OTE ILD,DTE ID~F,DTE IIR~,DTE SGR.DTE ~RES.OTE I4~,886 '576 ,gg.ooo ,g ,250 12 ~56 11 36 :0 000 83,,250 6017 2 49t ~0 4 021 6~ 285 62 02{ 169 679 5 ~020 !843 000 999 .250 10,164 ~ 930 ~000 8 ~38 ~8 32 2 352 0.O06 521,500 234 750 2.057 .932 4s 598 ~44 5! 494 2 352 51 494 · 202 381 9 740 1782 000 -999 250 14 219 , 3.898 10.000 73.125 34.233 2.354 W2NG, NGT TENS NGT HTEN.: MGT TENS, BGT CI~P.DTE CILM.DTE IMOF'DTE !IXN*.DTE CGR,DTE HTEN,DTE PEF*bDT LU,LDT $$2,LDT ~SRH.LD? 'CGR,LDT HTE~ bDT TNRA, CNL CNTC CNb CALI CML NTEM CNL THOR NGT W2NG TENS NG. HTEN NGT TENS BGT CI~P DTE CXLM DTE DTE CGR DTE HTEN,DTE PEFeLDT bU.bDT SS2,LDT bSRM,LDT CGR,bDT HTEN,LDT TNRA,CNb CNTC.CNb CAbI.CNb STEM.CML THOR.NGT W2NG,NGT TENS.NGT HTEN,NGT TEN$,BGT CIMP.DTE CILM.DTE IMQF.DTE IIXM.DTE CGR,DTE HTEN,DTE 57,765 17 0,000 ,00 o 9 86,188 8~,875 ,000 62;021 1749,000 2,650 453,000 332'250 2'~07 62~2! 1749'000 3,,762 1943,87! 13,477 79'500 8,t83 100,402 2910,000 1749,000 "999'250 102 375 104 500 0 000 4 17~1'~000 ,400 47.,750 349'750 ' 2~082 51,494 1782,000 3.428 2200~249 9 422 79 000 7 484 89 827 2955 000 1782 000 -999 250 74.875 77,063 0,000 ;8,484 3,435 3770.000 S Tape Yerl~lcatton Listing hlumberger AlasKa Computi. nq Center OLS,LDT Lb,bDT LSHV.LDT ~UR~ bDT TENS bDT NPHI CNL NPOR CNL CFTC CNL CAbS CNL HTEN CNL .. NG NGT STEM NGT Gm BGT 39.495 0,002 329,250 1704.000 28~ 002 000 36 ~95 36 go 673 834 ii 820 1770,000 0,622 18.072 . 78,375 999,250 RHOB.,LDT OSS.LDT LITH.LDT SSHV.LDT CALI LDT STEM bDT RTNR CNb RCNT CNb SGR.CNL TENS, CNb SGR,NGT URAN~NGT W4NG,NGT MRE$,MGT CI,BGT DEPT, I~PH.DTE .LM,DTE I!RD,DTE SFLU,DTE TEN$,DTE DPH! bDT QLS~LDT Lb,bDT bSH¥,LDT LURH.LDT TKNS,LDT NPHI,CNL NPO~.CNL CFTC.CNL CRL$.CNL HTEN.CNL POTA,NGT W3NG,NGT MTEM,NGT G~.BGT 3000 000 g ~13 9 og go 875 279~'828 · ,000 29.879 O 006 244 875 1705 000 279~ 170 000 39 741 42 396 571 077 9 891 1754,000 2.057 38,306 77,750 '999.250 C.IDP,DTE CILD.DTE IFRE.DTE IIXD.DTE SP*DTE ~TEM DTE RHOB:LDT OS$.LDT LITE.bDT SSHV LDT CAbI bDT MTE~ bDT RTNR CNL RCNT.CNL SGR CNL TENS!CNL SGR NGT URAN.NGT W4NG.NGT MRES.NGT C1,BGT DEPT. XMPH.DTE ILP.DTE IIRD.DTE SFLU DTE TENS:DTE DPHI,LDT OLS,LDT Lb.bDT LSHV,LDT LURE.bDT TENS.bDT NPHI,CML NPOP.CNL CFTC.CNL CAbS CML HTEN:CNL 2900,000 6.832 6'734 120,063 8,094 2715,000 35,382 -0,005 296.500 1705,000 2.059 2715.000 40,473 42,745 516.216 !0,641 1735.000 CIOP.DTE CIbD,DTE IFPE.DTE IIXD.DTE SP.DTE ~TEM.DTE RHOB.LOT QMS.bDT LITH,LDT SSHV,LDT CALI.bDT STEM.bDT RTNR.CNL RCNT.CNL SGR.CNL TENS.CML SGR,NGT 12-JU~-199! 15:20 1.998 O 015 257 250 1354 000 1 7~ 695 7~ 296 :383 2434 .233 28~ 000 23] I 61.4 4 016 2 354 -999 250 600 3 541 -59 00 77 ~50 2 -0 05 t56 ~25 1354 00 81 3 643 1985 129 77 803 2795 000 77 8O3 -0 102 9 073 2i352 -999 250 12 '000 -64.688 76.8~3 2.066 0,007 192,125 1354,000 10.297 76.813 3.567 1910,115 70.755 2715.000 70,755 DRHO bDT LS bDT S$1LDT SIRH bDT SGR bDT MRES bDT RCFT CGR.CNL MRES.CNb CGR.NGT W~NG,NGT W5NG,NGT CS,NGT C2.BGT IDPH,OTE ILD,DTE ID~F,DTE IX M.DTE SGR,DT~ MRES'DTE DRHO.LDT LS,bDT SSI,LDT S1RH,LDT SGR,LD~ MRES,LD.r TNPH,CNL RCFT,CNL CGR,CNL MRES'CNb CGR,NGT W1NG,NGT W5NG,NGT CS.NGT C2,BGT IDPH DTE ILD:DTE IDOF,OT~ IIR~,OTE SGR,DTE MRES,DTE DRHO,bDT LS,LDT SS1,LDT SIRH,LDT SGR,LDT MPES,LDT TNPH CNL RCFT CNb CGR CNL MRES CNL CGR NGT 233 2 39 581. 1751 -999 003 PEF,LDT 000 LU.LDT O00 SS2 LOT :014 LSRH bDT 233 CGR bDT 354 HTEN LDT 649 TNR. A CNL 542 CNTC CNL 435 CAbI 354 STEM CNb 435 THOR NGT 446 W2N'G NGT .008 TENS NGT O00 HTEN.NGT 250 TENS,BGT 9.953 9.758 i 10~ .8 7. 0 -0 450 224 41 530 81 1 1800 -999 CXMP DTE CIL~iDTE IMQF DTE iIXM,DTE CGR,DTE 2 HTEN,DTE ;~4 PEF'5DT 250 LU,LDT 000 SS2.LDT 176 LSRH bDT 803 CGR bDT 352 HTEN LDT 798 TNRA CNL 995 CNTC CNL 236 CALI CNL 352 NTE~ CNL 236 THOR:NGT 815 W2NG.NGT 097 TENS,NGT 000 HTEN,N~T 250 TENS.BGT 7.28! CIMP.DTE 7.176 ClLM,DTE 0.000 XMOF,DTE IIXM.DTE 140,O00 0.755 CG~.DTE 7~::~ MTEN.DTE PEF,LDT 546.000 bU.bDT 239.250 SS2,LDT 2,012 LSRH,LDT 70.755 CGR.LDT 2,389 HTEN.LDT 43.477 TNRA.CNL 474.252 CNTC.CML 6~.650 CALI.CNL 2.389 MTEM.CNL 61.650 TMOR.NGT . .i43 553,500 353:~500 2,000 :23,435 1770'000 3,334 23~8,307 .1t,695 78~.375 53,21 2860;~000 ~7'70;000 999'250 I07,313 109'750 0 000 '3 688 8i 236 175 000 000 2 160 81 36 1754 ~00 3:4~6 1996 675 77 .12 254 I 8 000 27}5 024 175~ 000 -999250 I .375 0,000 -13,500 61,650 1735,000 61 650 1735 000 3 498 1868 922 10 297 76 813 8,349 .'hlUmberger Alas{<a Computing Center POTA.NGT W3NG'NGT MTEP.NGT GR.BGT ILM.DTE I~RD,DTE SFLU.DTE TMNS,DTE DPH~.bDT OhS.bDT Lb,bDT ..SHV.LDT URM.bDT NPHI,CNL CFTC~CNL HTEN,CNb POT~,NGT W3NG,NGT MTE~'NGT G~,BGT DEPT' IMPM,DTE Ib~,DTE IIRD"DTE MFLU.DTE TMNM,DTE D~HI'bDT QbS.LDT Lb,bDT LSHV,LDT bURS.bDT TENS.BDT NPHI'CNL NPO~.CNL CFTC.CNL CAbS.CML POT~ GT W3NC,NGT MTEM.NGT GR.BGT DEPT. IMPH.DTE IbN.DTE IIRD.DTE SFLU.DTE TENS.DTE i'.794 URAN'NGT 35,141 W4NG.NGT 76,813 ~RE$'MGT '999,250 C!.BGT 2800,000 12,547 12 273 70 625 11 367 2980,000 29,343 '0.018 234'!25 1705'000 2'176 ~9~0'~000 47,~93 44,342 540,34! 9484 1824 000 ! 582 28 .112 76 125 -999 250 2700,000 I'441 '763 36i'250 12,016 ~785;ooo 29'850 11 1708.000 2,170 2785.000 49,810 48;470 437,703 12.375 1839.000 i 582 35~560 75,563 4O.O00 2600.000 1950 000 ~95o:ooo 90,813 9696,000 2580.000 CIDP,DTE CILD'DTE IFRE,DTE IIXDiDTE SP;DT~ NTEN:;~DTE RHOB*bDT QMS.bDT LITH.LDT SSHV;LDT CALI bDT MTEM bDT RTNR CNL RCNT CNL SGR CNL TEMSCNb URAN. NGT W4NGNGT ~RESNGT C! BGT CIDP.DTE CIbD,DTE IFRE.DTE IiXD,DTE SP.DTE MTEM,DTE RHOB,LDT QSS.LDT LITH,LDT SSHV.LDT CALl.bDT ~TEM.LDT RTNR,CNb RCNT.CNL SGR,CNL TEN$,CNb SGR,NGT URAN.NGT W4NG.NGT MRES. NGT C1.BGT CIDP.DTE CIbD.DTE IFRE,DTE IIXD.DTE SP DTE ~TEM:DTE !2-JUN-1991 15:20 t 625 W1NG,NGT 223,896 W2NG'.NGT 8 032 WbNG.NGT 9.'036 TENS.NGT 2 389 CS,NGT !844'000 HTE~,"'M NGT '999 2150 C2.BGT 999~250 TEN .BGT 76.688 79.000 20'000· 2'166 1 !.~5~ 000 9, 39 · 76 ii2562 203~ 02 75 ,~87 2980 000 754~7 1 646 6 024 2 422 864 '533 2 0 137 ~5 4 1703 65 2785 65 =0 7 2 12 99 100 20 -409 =257 74 5OO 5OO 000 000 875 563 157 OO7 75O 000 i469 '305 :040 .000 ,040 .066 .543 .449 .617 .875 ,375 .000 .000 ,750 .313 IDPH DTE IDO~ OTE IIR.. DTE: MGR OTE MRE$ DTE DRMO bDT kS,bDT SiRH.,bDT SGR'bDT MREM~5DT TNPH.~,CNb RCFTi. CNb CGR.CNL ~RES.CMb CGRi~MGT WlNG.NGT W5~GNGT CMNGT C2 BGT IDPH DTE ILO DTE IDOF DTE IIRM DTE SGR'DTE MRES,DTE DRHO.bDT LS.bDT SSi,bDT RH,LDT $~GR,LDT MRES,~DT TNPH.CNb RCFT,CNb CGR,CNb MRE$.CNL CGR.NGT WlNG.NGT W5NG,NGT C$.NGT C2.BGT IDPH DTE ILD:DTE IDQF,DTE IXRM.DTE SGR,DTE MRE$.DTE 13023 1~648 :000 77 .!88 75 .487 .~.422 OO9 437500 22~ :375 :209 75 487 2 422 45:07! :502 412 63 674 2 422 63674 247:992 10 .040 ~830 000 999 250 :156 066 0 000 52O 5OO 65 040 2 449 -0 .007 444 250 222 000 2 191 65 040 2449 395 74 ,325 2'449 74 ~25 7.g43 1954.000 12,180 10.008 9,953 0,000 -630000 50:139 2.459 CIMP,DTE CILM,DTE IMOF.DTE IIXM.,DTE CGR,DTE HT:EN:~pTE PEF*LDT bU,LDT SS2'LDT bSRM.LDT CGR'LDT HTEN,bDT TNRA'CNL CNTC'CNL CALi,CNb MTEM,CNL THOR.N~T W2NG.NGT TEN$'N~T MTEN'NGT T£NS.BGT CIMP.DTE CILM DTE IMOF DTE IIXM DTE CGR DTE HTEN DTE PEF bDT LU LOT S82 bDT LSRH bDT CGRLDT HTENLDT TNRA.CNb CNTC,CNb CALI.CNb MTEN.CNL THOR.NGT W2NG.NGT TEN$,NGT HTEN.NGT TEN$,BGT CI~P.DTE ClLMDTE IMOF:DTE IIXM.DTE CGR.DTE HTEN.DTE PAGEI 21 2710 .414 ! 000 1735 000 '999 250 7 9~ 642 5 :182.4000 2 830 406 500 3310'00 6~ ,174 674 .182~ 000 · 8o8 !99~0~4 2980,.000 ~824,000 999,250 693.000 -963500 1839 0 41.~1945500 330 250 2'164 74;325 1839;000 4,087 1724,.679 12,469 75,563 12.439 81,897 2785,000 1839,000 990,000 -646,000 -631.500 0.000 1788.000 38,898 1660.000 TaPe Yerif~lCation Listin :hlumberger A asKa ComputXn,~ Center DPHI. LDT QLS bDT L5 LDT LURH.LDT TEN$:'LDT PH.!, CN L PO~. CN5 CFTC' CN b CA~8..CNb HTEN'CNL POT~'NGT W3NG,NGT MTE~,NGT GR'BGT D~PT. IMPH.DTE XIRD.DTE 8~bU DT~ TENS:DTE DPHI.LDT OLd'bDT t · L D ? LSHV LDT LURH LDT TENMLDT NPH! CNL NPODCNL CFTCCNL CALM CNL HTEN CNL POTA NGT w3NG.NGT MTEM.NGT G~.BGT DEPT IMPH:DTE ILM.DTE IIRD.DTE SFLU.DTE T£NS.DT£ D~H!.LDT ~L$.LDT Lb.bDT LSMV.LDT bURS.bDT T~N$.LDT NPHT.CNL NPOR.CNL CFTC.CNL CALS.CNL HTEW.CML 44.699 RHOB.' bDT 0'039 QMS, bDT i7{ ~83.'000 LITH,bDT '000 SSHV.bDT 2.6]9 CALI'LDT 2580.000 MTEM~LDT 55 RTNR,CNL 'CNb '816 52,1 t I RCNT 318,129 SGR,CNb 6680'805 TENS~jCNL I .000 SGR,NGT 1,2~7 URAM.NGT 9'48 W4NG'NGT 1'969 CI.BGT 2500,000 t950'000 1950'000 107 750 9696 000 2580 000 41 9!3 0.096 !06,500 1708,O00 2,664 2580,000 59.:!03 50,180 340,128 2,252 1611.00.0 0.908 ·,188 31.750 ~400,000 999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999250 -9 -999.250 -999.250 -999.250 -999.250 -999.250 -999.,250 -999.250 CIDP,DTE CI.L~'DTE IFRE,DTE IIXD,DTE SP'DTE MT'EM~DTE RHOB~bDT QMS bDT LITHbDT SSHV bDT CALl bDT MTEMLDT RTNR CNL RCNT CNh SGR CNL~ TENS CNL 8GR NGT URAN NGT W4NG NGT ~RES NGT C1BGT CIDPDTE CILDiDTE IFRE DTE II×D.DTE SP.DTE MTEM.DTE RHOB.bDT QMS. bDT blTH bDT MSHV~LDT CALI.LDT MTEM.LDT RTNR.CNL RCNT.CNL SGR.CNL TEN$.CNb SGR.NGT 12-JUN-1991 15{20 1 912 -0 120 23 547 1359 000 8 797 74 313 4,43~ 1370,811 50.t39 80'000 '411 13,!33 119,438 121,813 20,000 "407;750 '276~000 74,188 .1'958 0,045 23,!25 1359,000 3,0~5 74,18 4 256 29 1 2580 29 721 -0 ~96 1 008 2 453 12 898 -999 250 -999 250 -999 250 -99g 250 -999 250 -999 250 -999 250 -999:250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999!250 -999 250 -999.250 DRH0.LDT L$, bDT S1RH +.bDT SGR, LDT ~RES~SDT TNPH,CNL RCFT ' CNL CGR,; CN b MRES.CNb CGR,NGT W5NG. NGT CS, NGT C2.BGT I~D, DTE IDOF' ~T~ SGR,DTE DRHO~, bdt bM.bDT SS I, bDT SGR' bDT MR ES, bDT TNPH~ CNb RCFT'CNL CGR'CNb MRES, CN5 CGR,NGT W lm N G ' N GT W5NG,NGT CS'NGT C 2" BGT IDPH,DTE X LD, DTE IDOF,DTE IIRM,DTE SGR DTE MRES:DTE DRHO.LDT LS. 5DT SSI .bDT S1RH.bDT SGR.bDT ~RES.LDT TNPH.CNh RCFT.CNL CGR.CNL MRES.CNL CGR.NGT .O 689 PEF'LDT . 59 HTEN,.LDT 53~.746 TNRA~CNL 302....601 CNTC'CN5 38~898 CAbI..CNL 2'459 MTEM~CNb 38.'898 THOR'NGT 140'.693 W2NG~NGT 4.329 TENS'NGT 1.886"000 HTEN.NGT 12'844 TENSoBGT 8.367 CXMP'DTE 8'203 CILM~DTE 0.000 IMOF.DTE -585.;500 XI'XM'DTE 29.72! CGR DTE 2'453 HTEN DTE 2~0'64! PEr 5DT 3,250 LU bDT 85,563 SS2,LDT 3'926 LSRH.LDT 29.721 CGR bDT 2'453 MTEN:LDT 50.180 TNRA CNL 3~5.469 CNTC CNL 32.72~ CAb! CNb 2..453 MTEM.CNL 32.72! THOR,NGT 85,6'85 W~N~N~T 3.024 TEN$'NGT 1886.000 HTEN.NGT 13.023 TEN$.BGT -999 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 250 CIMP.DTE CILM.DTE XMQF.DTE IIXM.DTE CGR.DTE HTEN.DTE PEF.LDT LU.LDT -999 250 SM2.LDT -999 250 LSRH.LDT -999 250 CGR.LDT -999 250 HTEN.LDT -999 250 TNRA.CNL -999.250 CNTC.CNL -999.250 CALI.CNL -999.250 MTEMoCNL -999.250 THOR.NGT PAGEI 22 18 109 199 625 13~ 750 6OO 38 898 1660 000 4 213 I:332 852 8,797 74 313 4~876 86 580 ~2580 000 1660 000 .!!80 000 -585500 -589 000 0 ,000 1516 000 32 721 16:31,000 i 375 ! ~500 ,598 32,721 t63~.,000 ,223 134~''025 · '055 4,~09 2580,0 16~!'000 1165,000 '999. 0 '999.250 '999.250 '999 250 '999:250 '999.250 '999.250 '999,250 '999.250 '999.250 '999.250 '999'250 '999:250 '999.250 '999.250 '999.250 Tape Verification Listing ,.lumberger Alas~a Computing Center !5:20 POTA.NGT -999.250 URAN,NGT -999.250 W3NG'NGT ~999'250 W4NG'NGT -999'250 ~TE~'".NGT 999,250 ~RES.,NGT -999,250 G~,BGT 66,750 C!'BGT 12'9!4 DEPT., INPH,DTE IL~,DTE IIRD,DT~ SFL[!'DTE TEN~DTE DPHI,LDT OS~,LDT 5L'LDT LSHV,LDT LURH 5DT TENS LDT NPHI CN5 NPO~ CFTC CNL C~SS CN5 HTEN CNL POTA,NGT W3NG.NGT ~TE,NGT GR'BGT DEPT, I~PH DTE IIRD,DTE SFLU.DTE TENS,DTE DP~I,LDT OL$:LDT' LL:LDT LSHV,LDT LUR~.LDT TENS.LDT NPHI.CNL NPOR,CNL CFTC.CNL CALS,CNL HTEN,CNL POTA,NGT W3NG,NGT ~TEM NGT GR:BGT D~PT. I~PH.DTE IL~.DTE IIRD.DTE SF50.DTE TEN$.DTE 2300.000 -999'250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -.999 250 -999 250 ~999,250 -999,250 -~99,250 - 9'9.250 -999'250 -999;250 -999'~250 -999,250 -999,250 52'344 2200 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999:250 -999250 -.999 250 -999250 -999.250 -999.250 -999'250 -999,250 -999.250 -999,250 -999,250 -999.~50 -999.250 -999.250 64.375 2100 000 -999 250 -999 250 -999 250 -999 250 -999,250 CIDP,DTE CXLD'DTE IFRE,DTE IIXD,DTE .$P*DTE ~TEN DTE RiHOB LDT QS$ LDT 5ITH LDT $8HV LDT CALI 5DT ~TEM LDT RTNR CNL RCNT CNb $~R CN5 TEnS CNL ORAN NGT W4NG NGT MRE$ NG:T Cl BGT CIDP~DTE ClLDiDTE IFRE.~DTE IIXDDTE SPDTE ~TE~ DTE RHOB LDT LITHLDT $8HV LDT CALI,LDT ~TEM.LDT RCNT,CNL SGR.CNL TEN$,CN5 SGR.NGT URAN,NGT W4NG,NGT MRE$..NGT C~"BGT CIDP.DTE CILD.DTE !FRE.DTE XIXD.DTE SP,DTE ~TEM.DTE -999~250 -999250 -999~250 -999;250 -999250 -999 250 -999 250 -999 250 -999 250 -999 250 '999 250 -999 250 -999 250 -999 ~50 -999 ~50 -999 250 -999 250 -999 250 -999 250 .172 -999250 -999250 -999 250 -999..250 -999~250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -.999250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 12.531 -999,250 '999,250 '999,250 =999.250 '999.250 '999.250 W1NG-,NgT WSNG,NGT C$,NGT C2,8GT IDPH,DTE ILD'DTE ID~F,DTE SGR,DTE MRE$,DTE DRHO;LDT L$,LDT SS!'~DT Sl. RH, hDT ~GR,5DT MRESLDT TNPH,CNh RCFT CNh CGR CNh CGR:NGT WING~NGT WSNG NGT C$,NGT C2,BGT IDPH,OTE iLD,DTE IDQF,DTE SGR,DTE MRE$,DTE DRHO,5DT 55~5D? $$I,LDT $~RH,5DT SGR,LDT ~RES,LDT TNPH,CNL RCFT,CNL CGR,CNL MRE$,CNL CGR,NGT W~NG,NGT W5NG,NGT C$,NGT C2,0GT IDPN,OTE ILO,DTE IDOF,DTE SGR,DTE ~RES,DTE -999"250 W2NG,NGT -999,250 TENS.NG? -999.250 HTEN,NGT t3,125 TENS,BGT -999.250 CX~P.D'TE -999.:250 CXSM.DTE -999'250 IMQF DTE -9.99~250 IIXM D~E -999.250 CGR DTE -999,250 HTEN DTE -999,~50 PEF 5DT -999 250 LU.LDT -999:250 882.LDT -999 -999 -999 -99'9 -999 -999 -999 -999 -99:9 -999 -999 13 CGR:LDT ,250 HTEN.bDT ~ TNR~!,CN~ CNTC,CNL 250 CALI,CNL 250 MTE~,CN5 250 THO~,NGT 250 ~2NG'NGT 250 TENS,NGT 250 HTEN,NGT 320 TEN$'BGT ~999 250 ¢INP,DTE 999:250 ClLM.DTE -999 250 I~QF,DTE 9~ 250 I'!X~,DTE :~9 CG~,DTE ,250 -999 2'50 HTEN.DTE -999 ~50 PEF.SDT -999 50 hU,LDT -999 250 882.LDT -999 250 LSRH.LDT -999 250 CGR.LDT -999 250 HTEN.LDT -999.250 TNRA,CNL -999.250 CNTC.CNL -999.250 CALI.CN5 -999.250 ~TE~.CNL -999'250 THOR.NGT -999.250 W2NG.NGT -999.250 TEN$,NGT -999.250 HTEN.NGT 12.844 TEN$,BGT ~999.250 CI~P.DTE 999.250 CXLP.DTE -999.250 X~QF.DTE 999.250 IIXM.DTE 999.250 CGR.DTE 999.250 HTEN.DTE PAGE: 23 -999.250 2999'250 999~250 1195~000 -999'250 -999..250 2999'.250 ,999,250 999,250 '999'~50 "999;250 :999'250 .999,250 9991250 -999~250 -999'250 -999~.250 -999,250 ::999,.:250 :999.,250 .999;250 999,250 1!30'.000 -9991250 '999 250 '999 250 '999250 -999 250 '999 250 -999 250 '999 250 -999 250 -999250 -999 250 -999 250 '999 250 999.250 -999,250 -999.250 -999,250 -999.250 -999.250 1055,000 -999.250 -999,250 999.250 999.250 999.250 -999.250 :.~lUmberger Alask~a Computing Center DPH!,5DT "999,250 OLS,LDT -999,~250 Lb"bDT -999 '250 LSHV'LDT -999,250 bURS"bDT -'999,250 TENS~LDT -999'250 NPHI,CNL -999.250 CFTCiCNL -999,250 CALS'CNL -999'250 HTEN'CNL -999.250 POTR;NGT -999'250 W3NG.NGT -999,250 ..TE~ NGT 999'250 G~,BGT 36,750 DEPT,. 2000.000 'IMP~DTE '999'250 IbM.DTE -999'250 IIRD.DTE -999,250 SFLU~DTE -999,250 TENS,DT~ -999.~250 OLS,LDT' 99~250 LL.LDT -999.250 LS~V,LDT -999'250 bURN.bDT -999'250 TENS.bDT -999'250 NP~I'CNL -999,250 NPO~'CNL -999'250 CFTC.CNL -999'250 C~L~,CNL -999'250 HTEN'C~L -999,250 POTR.NGT -999'250 W'~N~.NGT -999.250 ~TE~,NGT -999,250 GR,BGT 85.063 DEPT. 1900.000 I~PM.DT~ -999'250 'Ib~ DTE -999,250 .IIRD:DT£ -999.250 SFLU DTE -999.250 TENS:OT~ 999,250 DPHI.LDT :999.250 OLS.LDT -999,250 LL.LDT -999.250 LSHV.LDT -999.250 LUR~.LDT -999.250 TENS.bDT -999.250 NPHI.CNL -999.250 NPOR.CNL -999.250 CFTC C~L -999.250 CALS:CNL -999.250 HTE~.CNL -999.250 OSS. SDT LITH'LDT SSHV"LDT CAb! bDT ~TE~ bDT RCNT SGR CNL TENS CNL URAN NGT W4NG NGT ~R~$ NGT C~ BGT CIDP.DTE CILD,DTE IFRE'DTE IIXD'DTE SP.DTE ~TE~"DTE RHOB;LDT OSS.LDT LtTH:,LDT CAL!.LDT MTEM~LDT RTNRCNL RCNTCNL SGR CNL TE~$ CNL SGRNGT URAN NGT W4NG, NGT MRESNGT C1,BGT CIDP.DTE CILD,DTE IFRE.DTE IIXD.DTE SP.DTE MTEM.DTE ~HOB.LDT QSS,LDT LITH,LDT SSHV.LDT CALI.LDT STEM,bDT RTNR,CNL RCNT,CNL SGR.CML TEN$.CNL SGR.NGT !.2-JUN-1991 15:20 -999 250 -999 ~50 "999 50 "999 250 "999 250 "999 250 '999 '250 "999 250 '999250 '999 250 '999 250 "999 ~50 '99 250 !3 039 -999.250 -999'250 -999,250 -999,2~0 -999,:~50 999"250 -999,250 :999"250 :999.~50 ,999'250 999"250 -999'250 -999'250 -999;~50 -999.250 -999 250 -999 250 -999 ~50 -999 250 13 102 -999.250 -999,250 -999,250 -999.250 -999,250 -999,250 -999.250 -999.250 -999.2~0 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 DRMO'LDT L$:~bDT SSI.~DT $~RH:~LDT SGR,LDT ~RES.LDT TNPH~CNL RCFT. CNb ~RES CNL CGR NGT WiNG NGT :W5NG,NGT CS,NGT C2,BGT IDPH DTE ILD DTE IDOF DTE IIRM DTE SGR DTE ~RES DTE DRHO bDT L$:'LDT SSi,bDT SIRH'5DT SGR.LDT MRES'LDT TNPH.CNL RCFT'CNL CGR'CNb MRES,CN:L CGR.NGT W1NG.NGT W5NG.NGT CS.NGT C2,BGT IDPH.DTE ILD.DTE IDOF.DTE IIRM,DTE SGR,OTE MRES,DTE DRHO.LDT LS,bDT SSI,bDT SIRH.LDT SGR,LDT MRE$.bDT TNPH,CNL RCFT,CNL CGR.CNL MRES,CNL CGR,N~T -999,250 ~999'.~50 .999~'250 999.;250 '999~:~250 ~999.,'.250 .999'250 999.i250 ~999.250 999'250 12 9t4 -999,250 999250 999 ,250 999~50 -999 250 -999:250 -999 ~50 -999 ~50 -999 .250 -999 250 -999'250 -999.25o :999. 5o ~999.250 1999. 5o .999.250 .999'250 .999.250 .999.250 .999.250 13.719 ~999.250 999.250 -999.250 1999.250 .999.250 999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 999.250 -999 ~0 -999.25O PEF..,LDT bU,LDT S$2,LDT LSRH,LDT CGR'LDT HTEN'LDT TNRA':CNL CNTC,CNL MTEM,CNL THOR,NGT W2NG'NGT TENS'NGT HTEN,NGT TEN$,BGT CIMP.DTE ClLM.DTE I~OF,DTE IIXM.DTE CGR,DTE HTEN,DTE PEF'LDT LU,LDT SS2'LDT LSRH,LDT CGR'LDT HTEN'LDT TNRA'CNL CNTC'CNb CALI.CNb MTEM,CNL THOR,NGT W2NG.NGT TENS.NGT HTEM.~GT TENS.BGT CIMP.DTE CILM.DTE IMOF.DTE IIXM.DTE CGR..DTE HTEN.DTE PEF.bDT LU,LDT $S2'LDT LSRH,LDT CGR.LDT MTEN.LDT TMRA.CNL CNTC.CNL CALI.CNL MTEM.CNL THOR.NGT PAGEI 24 -999 250 -999 250 -999.~50 -999 -999250 -999250 -999 250 -999:2.50 -999 250 -999250 :999,.250 :999,~,2:50 .999;:250 999.250 I100'000 -999 0 '999,250 -999250 -999 2~0 -999250 '999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ,-999 250 -999 250 -999 250 -999 250 1040 000 -999,250 -999250 -999 250 -999250 -999.250 -999 250 -999250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 iS TaPe~ Verifaicatlo, Listing :hlumherger ~ laska Computing Center !2-JUN-{991 15120 PAGE~ 25 POT~.NGT ~TEM'MGT D'EPT'. SFLU~DTE TEN$'DTE DPHI~LDT LSHV,LDT LURH :LDT ENS bDT PHI CNL NPO~ CN5 CFTC CNh TEN CNL POTA'N~T M',..EM'NGT GR.~GT IIRD,DTg ~N$.D?E D~HI.LD? QbS.bDT LL.LDT LSHV.LDT LURM,LDT TENS.bDT NPHI.CNL NPO~.CNL CFTC.CNL CALS,CNL HTEN.CNL POTA.NGT W3NG.NGT MTEM NGT GP:BGT DEPT. IMPM.DTE YL~.DTE IIRD.DTE SFLU.DTE TEN$.DTE 48,563 C12BGT : :672 1800,000 '999'250 -999,250 -999'250 .999.'250 ~999;250 .999'250 999~250 -999,250 -999,250 -999250 -999250 -999250 -999250 -999 250 -999250 -999 250 -999 250 -999 250 64 438 1700,000 :999'.250 999,:250 '999,250 '999'250 '999,250 '999,250 '999,250 '999,250 '999,250 '999,250 999'250 :999.250 '999,250 "999,250 '999,250 '999,250 '999,250 '999,250 '999,250 27,828 1600,000 -999,250 -999,250 -999,250 -999,250 -999,250 CIDP.DTE T' CILD.,D...E IFRE,DTE IIXD,DTE SP'DTE MTEM,DTE RHOB'LDT QS$,LDT LITH.LDT $$HV.'LD:T CALI'LDT ~TEM,LDT RTNR~CNb RCNT~CNb SGR,CNb T:EN$,CNL SGR'NGT URRN~NGT W4NG'.NGT MR~$..NGT Cl'BG=T CIDP.DTE CILD"DTE IFRE,DTE IIXD,DTE SP,DTE MTEM'DTE RHOB.LDT Q$$.LDT bITH.LDT SSH'V,LDT CALI'LDT MTEM,bDT R~NR,CNb RCNT,CNb SGR,CNL TEN$,CNL SGR,NGT URAN,NGT W4NG.NGT MRE$,NGT C1.BGT CIDP,DTE CILD,DTE IFRE,DTE IIXD,DTE SP,DTE MTEM,DTE -999,250 '99 ,~!50 -99~ !50 -99~ 0 -999 150 -999,250 -999,250 -999'250 -999~250 -999,250 -999'250 -99 250 -99~ 25O -999~250 -999:~50 -999 -999 8 -999 ]50 '999 50 '999 0 '999 ~50 '999 250 '999 250 '999 50 -999 -999 250 -999 250 -999 250 -999 250 99 25O -999 250 -999 250 -999 250 -999 250 -999 250 -999,250 -999,2~0 -999,2 0 '999,250 '999,250 '999,250 !.NG,NGT 5NG,NGT C$,NGT C2.BGT IDPH,DTE ILD,DTE IDOF,DTE 'IIRM,DTE MRES,DTE DRHO.'bDT LS,bDT SSi'bDT RM'LDT SIGR'LDT MRES,.bDT TNPH'CNb ~ES'~N~ CGR,.NGT W~NG'NGT W5NG'NGT C$,NGT C2,BGT IDPH~DTE !bD, DTE ID~FiDTE IIRM, D?E SGR DTE MRES,DTE DRMO,LDT bM.bDT SSl,LDT S1RH,LDT SGR,bDT MREM,bDT TNPH,CNb RCFT,CNL CGR,CNb MRE$,CNE CGR,NGT W~NG,NGT W5MG,NGT C$,NGT C2,BGT IDPH.DTE ILD.DTE IDOF.DTE XIRM.DTE SGR.DTE ~RE$,DTE :ggg.250 .999,~'50 999'250 14'258 '999,250 ;999'25.. 999.250 999.250 -999 250 -999250 '999 250 -999 250 -999 250 -999 250 '999 ~50 '999 ~50 '999 250 '999 250 '999 250 "999.250 '999 ~50 13 063 -999'50 -999~50 ~999,250 999~250 -999'250 -999,250 -999 250 -999 250 -999.250 -999 250 -999 250 -999 ~50 -999 250 -999 ~50 -999 250 -999 250 -999 250 -999 250 -999 250 22 328 -999.250 -999,250 -999,250 -999.250 -999,250 -999.250 W2NG.NGT TENS.NGT MTEN.NGT TEM$.BGT CZ~'D~ CILM.DTE IMQF'DTE CGR,DTE PEF,LDT ~U'~D? SS2'.bOT bSRH,:bDT CGR,bDT HTEN'LDT TNRA,CN5 CNTC.CN5 MTEM4CN5 THOR'NGT N2NG'NGT TENS,NGT HTEN,NGT TENS'BGT CIMP,DTE CIb~'DTE !MQF,DTE C~R,DTE HTEN'DTE PEF,LDT bU,LDT SS2,bDT hSRH,LDT CGR,LDT HTEN DT CNTC,CNL MTEM,CNL TMOR.NGT W2NG.NGT TEN$,NGT HTEN.NGT TEN$.BGT CIMP.DTE CXLM.DTE IMQF,DTE IIXM,DT£ CGR.DTE HTEN.DTE '999.250 65;000 '999'250 ,999,~'50 '~999'250 1999"2M0 .999.~50 999'250 999'250 .999,250 999.~250 '999~250 '999,250 .999'250 999~250 '999~50 -999~250 '999~'250 ''999~50 '999 250 '999 2~0 :-999, 0 -999: ~50 '999 '999:250 · '999 250 '999 250 -999 ~50 '999 250 '999~ 250 -999~50 -999 250 -999 250 995 000 -999.250 -999"250 -999.250 -999,250 -999~250 -999.250 Tape Yerification blsting :btumDerger Alaska Computing Center DPH I, DDT OLS, bDT bL' kDT LSHV ' bUR~, bDT TENS,LDT NPOR CN~ CFTC CNL CAbS CNL MTEN CNL POTA~ NGT W3N~: NGT MTE~ NGT GR BGT -999,250 -999 250 -999250 -999250 -999.250 -999 250 -999250 -999250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 46 219 OSSLDT bITH. LDT ~TEH.LDT RTNR,CNL RCNT,CNL SGR CNb TENS CNL SGR,NGT URAN,NGT W4NG,NGT MRE$,NGT CI'SGT I~P~, i.E IL~*DT:E iIRD'DTE SFLU,DTE TENS.'DTE DPH! bDT LL,LDT LSHV'LDT ~$ bDT NPO~ CNL CFTC CAbS CNL POTa NGT GR BGT 1500,000 -999'250 '999'250 -999'250 "999,250 '999'250 -999 250 -999250 '999,250 '999,250 -999 ~ '999.250 '999 ~50 -999 250 -999 250 '999"250 '999~250 -999,250 -999,250 ~9'063 CIDP,DTE CIbD,DTE IFRE,DTE IIXD,DT~ SP'DTE ~TEM'DTE RHOB'bDT QMS,bDT b!TH~bDT 8SHV'.LDT CAbI'LDT STEM,bDT RTNR CNb RCNT~CNb SGRCNL TEN$.CNb SGR NGT URAN~NGT W4NGNGT MRES~NGT Ci BGT DEPT iMPH:DTE IL~,DTE IIRD,DTE SFLU,DTE TENS.DTE DPHI.LDT OLS.LDT Lb.bDT LSHV.bDT LURH.LDT TENS.bDT NPH!,CNL NPOR,CNb CrTC.CNL CRb$,CNL HTE~,CNL 1400.000 '999,250 '999.250 '999.250 '999,250 -999,250 -999,250 -999,250 -999,250 -999 250 -999:250 -999.250 -999,250 -999,250 -999.250 -999,250 -999,250 CIDP.DTE CILD,DTE IFRE,DTE IIXD,DTE SP,DTE ~TEM,DTE RHOB.LDT QSS,LDT GITH.LDT SSHV.GDT CAbI,LDT STEM,bDT RTNR,CNL RCNT,CNL SGR CNh TENS:CNL SGR.NGT 12-JUN-1991 15120 -999,250 -999~250 -999'~50 -999'250 -.999'250 '999 -999~ 0 0 -999250 -999 '999 ~ 0 0 '999}50 '999 250 '999 250 '999 250 .22 344 -999 250 -999 250 '999 250 '999 250 "999 250 '999 250 '999 250 '999'250 '99~.250 '99 25O '999 ~50 25O '9~9 '9 ~250 -9~ ~50 9 -9 250 -999 ~50 -99 250 -99~ :250 -99 i~50 -99~ 50 12 930 -999.250 :999.250 999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999,250 -999.250 -999.250 -999,250 -999.~50 -999.250 -999,250 -999,250 -999.250 DRHO,LDT bS, bDT SS 1. bDT S ! RH',LDT MRES~ ,bDT TNPH: .CNL f.RC I ~CNL CGR tnb ~RES CGR~ NGT W~NG~ NGT WbNG NGT CS NGT C2 IDPH,DTE .IhDi'DTE~ IDOF~DTE IIR~,DTE SGR,DTE ~RES,DTE DRHO,bDT US bDT $iR~ bDT bDT SGR ,bDT ~RE$ bDT TNP CNb RCF~ CNL CGR CNb MRES CNL CGR NGT WING NGT W5NG NGT CS NGT C2,BGT IDPH,DTE ILD,DTE IDOF,DTE IIRM.DTE SGR,DTE MRE$,DTE DRHO.bDT LS,bDT SSl.bDT S1RH,LDT SGR,LDT ~RE$,5DT TNPH,CNb RCFT,CN5 CGR,CN5 MRES,CNb CGR,NG~ 250 PEF.LDT 250 LU,LDT 250 S$2.LDT 250 bSRH*LDT 250 CGR'LDT 250 '99 '99 -999 -.999 HTEN,LD? -9 50 CNTC,CNL -999 250 CALI,CNb MTEM.CNL -999.~50 -999,250 TMOR'NGT -999,250 W2NG,NGT 1999.250 TENS,N~T 999,~50 HTEN,NGT 2!,95~ TENS,BGT 999.25~ CIMP,DTE ~999,~5 CILM~DTE ~999'250 IMQF,DTE 999'250 IIXM,DTE -999,250 CGR,DTE -999'2.50 HTEN,DTE -999,25~ -999*250 bU.'bDT -999.~250 -999j.250 bSRH'.bDT -999,250 CGR'GDT -999,250 HT£N'LDT :'999.250 T'NRA ~TE~NL -999~.250 -999'250 THOR -99~..250 ~2NG,NGT 13,031 TENS, BGT -999 250 CIMP.DTE .999 250 CIL~.OTE -999250 -999 250 ~I~.~TE -999 250 CGR,DTE '999 250 HTEN.DTE -999 250 PEF,LDT -999 250 LU.LDT -999 250 SS2.LDT -999 250 LSRH.LDT -999.250 CGR.LDT -999.250 HTEN.bDT -999.250 TNRA.CNL 999.250 CNTC.CNL ~999.250 CALIoCNL -999.250 HTEM.CNb -9991250 THOR.NGT PAGEI 26 '999.:,'250 '999 250 :'9992:50 :'999 250 -9'99 250 -999:250 .-999 250 -999 250 '-999 250 -999 250 -999 250 -999 250 -999 .250 '999250 925 000 :'999,~50 ::999.250 '.999'250 ~999,'250 ~999~250 999.'250 "999,250 '-999'250 "999,250 :"999~250 '999:,250 '999;,250 :-999 20 '999 -999 50 -999 ~0 -999~:250 -999 250 -999 .250 -ggg250 820 000 '999.250 '999.250 '999250 '999 250 '999250 -999.250 -999 250 -999 250 -999 250 -999 250 -999250 -999 250 -999 250 -999250 -999 250 -999 250 -999 250 Tape: verification I,.,ist~ng :hlumberger AlasKa Computln.q_ Center · .PAGE~ 27 DEPT. IMPH DTE .... .DT'E I!RD.DTE SFLU,DTE TEN'8.DTE DPHI,LDT bL.LDT bSHV.LDT bURS'bDT TENS,bDT NPOR.CNL CFTC~CNL CALS,CNL P~TA'N~T W.)N~,NGT MTE~.NGT GR.BGT D:EPT IMP~2DTE IIRD,DTE SFbU.DTE TENS'DTE DPHI.LDT OhS.bDT bL.bDT bSHV bDT 5URH:bDT TENS.bDT NPMI.CNL NPO~,CNb CFTC.CNL CAbS.CNL HTEN.CNL POTA.NGT W]NG.NGT MTEM.NGT GR.BGT DMPT. I~PH.DTE SFhU.DTE TENS.DTE 1300,000 -999'250 299'9'2S0 .999,2so 999,250 -999.250 -999,250 -999 250 -999 250 -999250 -999 250 -999 25O -999250 -999 250 -999 250 -999 250 -999 250 -999 250 '999 250 '999 250 74625 1200..000 -999.250 -999,250 '999'250 -999.250 -999,250 -999.250 -999,250 -999.250 999,250 999.250 '999'250 -999.250 '999,250 '999.250 -999 250 -999:250 -999.250 -999.250 -999,250 74.125 1100.000 -999,250 -999.250 -999.250 -999.250 '999,250 CIDP DTE CIbD DTE IFREDTE IIXD DTE MP~.DTE MTEM;..DTE RHOBLDT QS$,bDT LITH:LDT ~SHV bDT CALI bDT STEM bDT RTNRCN5 RCNTiCNL SGR CNb TENS CNb SGR NGT URAN. NGT W4NG NGT MRE$ NGT Ci BGT CIDP DTE CILD DTE iFRE DTE IIXD DTE SP DTE MTEM.'DTE RHOO'LDT Q$$,LDT LITH,LDT SSHV,LDT .STEM DT RTNR.C~b RCNT.CNL SGR.CNL TEN&.CNL SGR.NGT UR4N.NGT W4NG.NGT MRE$,NGT Ci.BGT CIDP.DTE CILD.DTE IFRE.DTE IIXD.DTE SP.DTE MTEM.DTE -999,250 -999.250 -999'250 !3'984 -999 -999 -999 -999 -999 -999 -999 -999 -999~ '999 -999 -999 -999 "999 "999~ ~50 '999 ~50 '999 250 "999 250 "999 250 "999 250 !4:008 -999 250 -99~ 250 -99 250 -999 250 -999 250 -999 250 -99~ 250 -99 250 -999250 -99 50 -999 250 -999 250 -999 250 -999.250 -999250 -999 250 -999 250 -999250 -999 250 18 031 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 W'I~G,NGT WSNG.~GT C$'NGT C2,BGT 250 250 ILD,DTE ~250 tDOF'DTE 250 IIRM,DTE 250 MRES,DTE 1250 0 LS'bDT 50 $1'R~'bDT ,bDT 50 SGR,bDT MRES,LiDT ]50 5O RCFT'CNL. MRE$,CNb CGR,NGT WING'N~T WbNG, NGT 'C$,NGT C2'BGT IDPHDTE ILD DTE IDQF DTE IIRM DTE SGR MRES,DTE DRMO.bDT LS,LDT SlRH,bDT SGR,bDT MRE$'bDT TNPH,CNL RCFT.CNL CGR,CNL MRES,CNL CGR,NGT WING,NGT WbNG,NGT CSNGT C~:BGT IDPH.DTE ILD,DTE IDQF.OTE IIRM.DTE SGR,OTE MRES.DTE ~999,250 W2NG,NGT 999,250 TENS,NGT -999.25~0 HTEN,,NGT 14,:102 TENS,BGT -999,250 CIMP,DTE -999,250 -999.250 IMQF.DTE -999-250 IIXM.'DT~ · -999,250 C~R,DTE -999,250 HT'EN'DTE -999,250 PEF'LDT -999'250 LU bDT ' T -999,250 .999,:25 GR,LDT .999°250 HTEN.LD~ .999'250 TNRA,CNb ,999j250 CNTC~jCNb :~999,250 CAbI.CN.b '.999':250 MTBM'CNb ~999~::250 THOR,NGT ~999,250 W2NG,NGT 999.250 TENSjNGT -999'.250 HTBN,NGT 14.789 TENS'.BGT -999,250 CIMP,DTE -999'250 ClLM'DTE -999,250 I~OF.DT£ -999;250 IIXM,DTE -999.250 CGR,DTE -999,250 HTEN'DTE -999,250 PEF.LDT -999.250 LU.LDT -999,250 $$2.LDT -999.250 bSRH.LDT -999:250 CGR.LDT -999 -999 -999 -999 -999 -999 -999 -999 -999~ 15 5 0 HTEN,LDT 50 TNRA,CNb ,,250 CNTC,CNb 250 CALI.CNb 250 MTEM.CNL 250 THOR,NGT 250 W2NG,NGT 250 TENS.NGT 250 HTEN NGT 672 TENS:BGT :99~.250 99.,250 :999.250 999,250 -999.~50 -999.250 CIMP.DTE CILM.DTE IMOF.DTE IIXM.DTE CGR.DTE HTEN.DTE :999'250 :999'250 999'250 8!0,000 -999'250 :999,250 ::999'~250 ~.99'9r'250 '~999,250 :999'250 :-999,250 :-999'2~0 :'999'250 :"999;250 ~999'250 ."999':250 999~250 "999'2~0 835,0~0 '999'250 -999,250 '999,250 :999,250 .999,250 :999:~:50 .999 1:50 9 9 :50 -9~9 LbO -999 -999:250 -999;250 -999250 -999:250 -999,250 -999,250 -999.250 ~999,250 '999,,250 740,000 -999 250 -999 250 -999 250 -999 250 -999250 -999 250 in Tape verification Listing ~hl. umbergerA!a$.Ka ComPuting Center 12-JUN-199! 15520 PAGEt ¸:28 DPHI.LDT OLS,LDT LURH' bDT TENS-bDT NPHI*CNL NPOR*CNL CA. bS'CNL HTEN.CNL W3NG'NGT MTE~,NGT GR'BGT DEPT I~:P~' .DTE IbM'DTE IIRD,DTE SFLU..DTE TENM.DTE DPHi,LDT OL~,LDT Lt:..,LDT bSHV.bDT LURH.LDT TENS,bDT NPM! CNL NP~R!CNL CFTC CNL HTEN.CNL POT~.NGT W3N~ NG.T GR. BGT DEPT. IMPH.DTg Ib~.DTE IIRD.DTE SFLU.DTE TENS.DTE DPHI.LDT QLS.LDT LL.LDT bSHV,bDT bURN.bDT TENS.bDT NPHI.CNL NPOR CML CFTC!CNL CAbS CNL HTEN.CNL -999,250 -999,250 -999,250 -999,250 -999250 -999 R50 -999 250 -999~50 -999 250 -999 250 -999 250 -999 RbO -999 250 '999~50 71 625 ~000,000 :999,~50 ~999,~50 ,999,250 999.250 '999,250 -999,250 -999'250 -999 250 -999 ~50 -999 250 '999.250 -999,250 -999~250 -999,250 -999.250 -999'250 -999,250 -999,250 -999.250 74,250 900,000 -999,250 -999.250 -999.250 -999.250 '999.250 '999.250 -999.250 -999.250 -999,250 -9~9,250 -999.250 -999 250 -999.250 -999.250 -999.250 OSS,LDT LITH.LDT SSHV,LDT CALI,LDT STeM,bDT RTNR,CNL RCNT.'CNb 8GR,CNb TENS,CNL SGR,NGT URAN,NGT ~RES, NGT CIDP,DTE CIbD,DTE I. FRB,DTg IIXD,DTE SP.DTE MTEM'DTE RHOB~:'LDT Q$~LDT h!TH,LDT SSHV,LDT CAbI,LDT STEM,bDT RTNR,CNb RCNT,CNb SGR'CNL TENS CNL SGR NGT [)RAN NGT N4NG NGT MRES NGT CI.BGT CIDP.DTE CILD.DTE IFRE.DTE IIXD.OTE SP.DTE MTEM,DTE RHOM.bDT O$S.LDT LITH.LDT MSHV.LDT CAbI.LDT ~TEM.LDT RTNR.CNL RCNT.CNb SGR.CNb TENS.CNL SGR.NGT -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 '999 250 '999 250 '999::250 '999 250 '999.~.50 '999,250 '999'250 t4,906 '999.250 '999j250 :999,250 999.~:50 '999 ~50 '999~R50 '999 50 '999 ~ 0 '999250 '999 250 '999 250 g g 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 15 211 -999 250 -999 250 -999 250 -999 250 -999 250 '9gg 250 -999 250 -999 250 -999 250 -999 ~50 -999.250 -999.250 -999.250 -999.~50 -999,~50 -999,~50 -999.250 DRHO.bDT b$.bDT SS 1 · bDT ! RH, bDT MRES,bDT TMPH, CNb CFT, CNL CGR, CNb MRES,CNb C G:R N GT 1 NG NGT W5NG'NGT CS'NGT C~, BGT DPH' DTE I L.D, D T g ID~F,DTE SGR, D ..:,g R ES ' DT E DRHO~ bDT bM, bDT SS 1, ~D~ I R H, b DT SGR'~DT MRES, bDT TNPH.'CNL RCFT.CNL CGR, C~5 ~RES. CNL CGR.NGT 1NG, NGT 5 N G N G T Cs: T C2.MGT DPH, DTE I L D, DT E IDDF, DTE IRS, DTE SGR,DTE MRES,DTE DRHO,LDT LS,LDT SSI.bDT S1RH.LDT SGR,LDT MRES.LDT TNPH'CNL RCFT,CNL CGR.CNL MRES,CNL CGR.NGT -999.~250 -999~250 -999~50 -999:250 -999 ~50 -999.250 -999~50 -999 250 -999~50 -999 250 -999 250 -999250 -999250 -999~50 13 633 -999.,250 '999'250 -999'250 -ggg'25:0 -999':250 '999.~250 -999.,250 999,~,250 '999,,~:250 '999:250 '999~250 '999250 -999250 '999250 -999~:250 -999 250 -9991250 -999 25O '999250 13 398 -ggg 250 -999 250 -ggg 250 -999 250 -999 250 999250 :999 250 -999 250 -999 250 -999 250 -999 250 -999.250 .999.250 999.250 -999.250 PEF.LDT LU'LDT LSRH.'LDT CGR,LDT HTEN'LDT T:NRA.CN5 CMTC.CNb CALI,CN5 MTEM'CNL THOR.~NGT W2NG~NGT T~N6,NGT HTEN.NGT TEN$,BGT CI~P..DTg CIbM,DTE IMOF.,DTE IIXM,DTE CGR.DTE HTEN,DTE PEF,L:DT LU:.LDT 8$2,LDT bSRH.LDT CGR'LDT HTEN,LDT TNRR'CNb CNTC-CNb CRb~.CNb MTEM,CNL THOR,NGT W2NG,NGT TEN$,NGT HTEN,NGT TEN$.BGT CIMP.DTE IMGF.DTE CGR DTE HTEN:DTE PEF.LDT LU.LDT $$2.LDT bSRH'LDT CGR.bDT HTEN.LDT TNRA'CNL CNTC,CNb CRbI.CNb STEM CNL THOR:NGT '999',250 '999;:250 ,250 -999,1250 -999'250 -999°250 :999'250 ;999'250 ~999250 '999 2~0 '999 2~0 685 000 :999 250 · 9gg 250 '999 250 '999 250 '999 250 '999250 '999 250 -999 250 -999~50 -999.250 :'999 250 '-999 250 -:999,250 :,999~250 ~999~ 50 ,999) 50 :'999 250 '999 250 '999 250 '999 250 690 000 '999 "50 "999 -ggg 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999'250 -999,250 -999,250 -999"250 -999"250 1999.250 999.250 Tape verification b:[stttnq ;hlumberoer AlasXa ComPut n~ Center 12-JUN-lgg1 PAGE~ .:29 POTA.NGT MTEM,NGT GR.BGT D~PT, iMP~,DT~ ~ILM,DTE !IRD~.DTE SFLU.DTE TENS DTE DPH! bDT QLSLDT LL bDT LSHV LDT LURH bDT TENS bDT NPH! CNL NPO~CNL CFTCCN5 CAbS CNL HTEN:CNL POT.A~.NGT W3NG NGT M...~EM,NGT GR,BGT D~PT I~PN "!b~ DTE I!RD DTE SFLU DTE TENS DTE DPHI,LDT OLS.LDT LL.LDT LSHV.L~T LURH,LDT TENS,bDT N~HI"CNL NPOR,CNL CFTC.CNL ALS,CNL ~TEN.CNL POT~ NGT W]NG:NGT ~TE~,NGT G~,BGT DEPT. I~PH,DTE ILM,DTE IIRD,DTE SFLU,DTE TEN$.DTE -999.~250 -999,250 -999,2:50 63't88 800,:000 '999~:50 '999'250 '999~250 '999',250 '99~,250 '99 ,250 ~999,250 ~999;~50 999,~50 '999;250 '999,250 '999'250 '999'.250 '999'250 '999,250 '999 250 '999 250 '999 250 '999,250 28,8~3 700,000 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 ~999,250 999,250 -999,250 -999,250 99,250 '999,250 '999,250 '999,250 '999,250 '999,250 65,688 -99 250 -99 250 -999,250 -999,250 -999,250 URAN.NGT '999,250 w4NG.NGT -999,250 ~R~ NGT -999,250 ~:BGT i7.45] CIDP,DTE IFRE,DTE IIXD,DTE SP~DTE ~TEM DTE RHOB LDT QS$,,LDT LITH LDT SSHV LDT CALI bDT MTEM LDT RTNR CNb RCNTCNL SGRCNb TENS CML SGR~NGT URANN~T: W4NG NGT MRES NGT Ci BGT ClDP,DTE CILD,DTE IFRE,DTE iIXD,DTE SP,DTE NTEM,DTE RHOB,bDT QMS,bDT LITH.LDT SSHV,LDT ALI,bDT ~TEM.LDT RTNR,CNL RCNT.CNL SGR,CNL TENS,CNL SGR,NGT URAN'NGT W4NG,NGT MRES,NGT C1.BGT CIDP.DTE CILD,DTE IFRE'DTE IIXD.DTE SP.DTE ~TE~,DTE -999.250 ~999~250 999.~50 -999.~50 999250 -999.~50 -999250 -99~250 -99 250 -999 250 -999 250 .999 250 999 250 C999~250 j999~250 ;999~250 999,250 20'063 -999 250 -999 250 -'999 250 -999 250 -999 250 -999 250 -999 250 :999 25o 999 250 -999 ~50 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 16 438 '999.250 '999.250 '999.250 '999.250 '999.250 '999,250 W5NG'NGT CS,NGT C2,BGT IDPH,DTE ILD,DTE IDPF~DTE SGR,DTE NRES,DTE DRHO,15DT SS,bDT SS!,bDT SG~'bDT 'LDT 9RE$~LDT TNPH,CN~ RCFT,CNL CGR,CNL MRE$,CNb CGR,NGT W~NG.NGT WbNG,NGT CS,N T C2,BgT !DPH. DTE ILD DTE !DQF DTE IIRM DTE SGR DTE MRE$,DTE DRHO,LDT LS'LDT SSi,bDT SlRH.bDT SGR.LDT ~RE$,LDT TNPH,CNL RCFT,CNL CG~,CNL MRES,CNL CGR,NGT WING.NGT W5NG,N~T CS.~GT C2,BGT IDPH,DTE I5D,DTE IDQF,DTE IIRM,DTE SGR,DTE MRES,DTE ~999'2 0 W2NG.,NGT ~999.~0 TENS,NGT 999,~ 0 HTEN,NGT 12,8~4 TEN$iBGT .999~.250 CILM~DTE -999 250 t~QF,DTE -999 250 IIX~,DTE -999~250 CGR. DTE -999 250 HTEN. PTE -999 250 PEF bDT -999 250 5U bDT -999 =250 SS2 bDT '999 250 5SRH bDT -999 250 CGR bDT -999 =250 HTEN"LDT -999 250 TNRA,CN~ -999 =250 CNTC'CNL -999~250 CALI,CNL -999.250 -999i250 THOR,NGT -999.250 W2NG'NGT -999"250 TENS,NGT -999'250 HTEN'NGT 17'.188 TEN$.BGT -999~.250 CI~P. DTE -999=.250 CI~ DTE -999= 250 ]~QF DTE -999 25~ IIX~ DTE -999 25 CGR DTE -999 250 ~TEN DTE -999 250 PEF bDT -999 .~50 LU bDT -999 50 SS2 LDT -999 250 -999 250 CGRibDT -999 250 HTEN - 250 TNRA,CNb -999 250 CALI.CNL -999"250 MTEN,CNL -999 250 THOR,NGT -999-250 W2NG,NGT -999 250 TE~S,NGT -999 250 HTEN,NGT 13 i72 TEN$,BGT -999,250 C]NP,DTE -999.250 CIL~,DTE -999.250 IMQF,DTE -999'250 IIXM.DTE -999.250 CGR.DTE -999,250 HTEN.DTE '999'250 -99 ;250 -99~,250 610,000 :'999'250 -999;250 -999-2.50 999~:250 999;250 ~999.~.~50 999'250 -999.250 -999,250 -999~250 -999,250 ~999,25 999'25~ '-999~250 -999,250 -999;~50 .250 -999'250 "999,250 635,000 ::'999,150 :999;: 50 999' 50 -999.~50 999- 0 '999250 -999:250 -999 250 -999 250 -999250 -9 250 -999 250 -999 250 -999 250 -99 250 -99~250 565 -999.250 '999,250 '999,250 '999.250 '999,250 -999~250 :hlum..erger Alaska ComPutin~ Center. 15:20 ¸3O LSHV.LDT NPHI:CNL ~PO~ CFTC,CNL CALS,C~L HTEN CNL POTA NGT MTEM,NGT G~,BGT D~PT' [~'PH~DTE I.LM.DTE II~D"DTE SFLU~D'TE DPHI~I. DT ~LS~DT LL.LDT LUR~LDT T~S~P~ NPH! CN5 NPOR CNL CFTC CNL CALS CNL HTEN,CNL POTA,NGT W3"G,NGT MTEM,NGT GR,BGT DEPT. IMPH.DTE ILM,DTE II~D,DT£ SFLU,DTE TENS,DTE DPH{,LDT OLS,LDT LL.LDT LSHV,LDT LURH,LDT TEN$,LDT NP~I.CNL NPO~,CNL CFTC CNL HTEN,CNL -999 250 .-999 250 -999250 -999250 -999 250 -999 250' -999~50 -999 250 -999~250 '99'9.250 "999,250 '"999,250 "999.250 '999'250 ~0'500 .5'00,000 '999,250 "999,250 '9'99'250 -999'250 '999,250 '"999'250 -999~250 -999.250 i999'250 ,999,250 .999,250 .999'250 2999'250 .999'250 999,250 -999.250 -999,250 -999.250 -999'250 55.500 400.000 '999,250 -999,250 -999.250 -999'250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 '999.250 '999.250 '999.250 -999.250 -999.250 -999.250 RHOB.LDT OS$.LDT LITH~.LDT SSHV. bDT CALI.LDT ~TE~.LDT RTNR.CN5 RCNT CN5 SGRCNL TENSCNL SGR NGT RAN,NGT 4NG'NGT ~RE$,NGT C1,BGT CIDP'DTE CILD.DTE 'IFRE,DTE IIXD~DTE S~.DT~ ~TE~,DTE RHOB.LDT ~SS,LDT LITN bDT SS~V CAb! ~TE~ bDT RTNR CNL RCNT CNL SGR CN5 TE~S CNL SGR NGT URAN NGT W4NGNGT MRE$.NGT C1,BGT CIDP.DTE CILD.DTE IFRE.DTE IIXD,DTE SP,DTE MTEM.DTE RHOB.LDT OS$.LDT LITH.LDT $SHV.LDT CALI.LDT MTEM.LDT RTNR CNL ~C~TiC.U SGR.CNL TEN$.CNL SGR.NGT "999,250 "999'250 ~999~250 ,999'250 ~999,250 ~999.250 ~'999'250 -999'250 '999 . '250 999.250 "999'250 "999,250 5'727 -999 5 -999~ 0 0 -999 50 -999:250 -999 .250 -999 ]50 -999 50 999 250 '9 "99 '99~ 150 '999 250 '999 250 '999 i5:0 '999 50 '999 50 '999250 18 953 -999 50 -999 ~50 -999 250 -999 250 -999250 -999~250 -999 0 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 DRHO bDT 5$ 5DT SSl bDT SIRH bDT SGR,LDT ~RES'bDT TNPH'CN5 RCFT.CNL CGR,CNL :~RES,CNL CGR,NGT WING;NGT W5NG'NGT CS,NGT C2;BGT IDPH:,DTE I5D~=DTE IDQF, DTE IIRM, DTE SGR~DTE NRE$ DTE DEHO=5DT LSLDT SSi ~DT S1RH bDT SGRbDT MRES ~DT TNPH CNb RCFT CNL CGR CNL ~RES CN~ CGR,NGT W1NG,NGT W5NG'NGT C$,NGT C2,BGT IDPM'DTE I5D'DTE ID~F'DTE IIRM.DTE SGR.DTE ~RE$,DTE DRMO.LDT $$~,LDT SGR,LDT MRE$.LDT TNPH.CNL RCFT,CNL CGR,CNL ~RE$.CN5 CGR,NGT "999125:0 '999 250 -999 250 -999 250 -999250 -999250 -99~ 250 -99 ~250 "999:250 -999,.:250 -999'25:0 -999,250 '999.,250 -999'250 13'578 "999'250 50 ~999'2 1999,:250 999i:250 -999~250 .99.~50 ~999· 50 .999,250 999"250 -999~250 -999,250 -999'250 -999.250 99~250 -999250 -999.250 -999.250 15.328 PEF*LDT LU,LDT $$2.~LDT LSRH'LDT CGR'LDT }{TEN bDT TNRA,CN5 CNTC'¢NL CALI'CNL MTEM,CNL T~OR~NGT TEN$,NGT HTEN.NGT TEN$,BGT CI~P'DTE CIb~,DTE IMQF'DTE IIXM'DTE CGR.DTE HTEN'DTE PEF-5DT LU'LDT SS2'LDT LSRH,LDT CGR.,LD? HTEN'~DT TNRA'CNL CNTC,CNL CALI.CNL ~TEM,CNL THOR,NGT W2NG,NGT TENS.NGT HTEN'NGT TEN$.BGT 'DTE 250 CI. LM DTE -99 250 I DTE .99 -99~ 250 CGR,DTE .250 HTEN,DTE -999 250 PEF.LDT LU*LDT -999250 -999 250 -999 250 -999 250 -999 25O -999 250 -999 250 -999 250 -999 250 -999.250 SS2.LDT LSRH.LDT CGR.LDT HTEN.LDT TNRA.CNL CNTC.CNL CALI.CN5 MTEM CNL THOR:NGT -999'250 1999,250 250 -999'250 :999;250 .999~250 -999,250 ~999,250 :999'250 i999:250 '"99 250 555, :So -999 !50 :999 5O '"999 '999 ~ ~0 :'999:~i . ~ :"999'" 00 "999 "'999 290 "999 250 '999:250 250 565 000 -999 250 .'999 250 -999 ~50 -999 250 -999 ~250 -999 50 -999 250 -999 250 -999. 250 -9~9:250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 Tape Verification Listing ;~:lUmberger laska CompUting Center pOTA, NGT -999,250 URAN.NGT W3NGiNGT -999,250 W4NG,NGT MTEM,NGT -999'250 MRE$,NGT G~, BG~ 59. 375 C~ ~BGT DEPT, ~ISM'DTE I I RD' DTE SFLU.DTE T~NSiDTE DPHI LDT OLS LDT I~L BDT [.S~V LDT LURH LDT TENS LDT NPH! CN5 NPO~ CNL CFTC CNL HTEN CN ~ POTA,NGT MTE~, NGT G~,BGT DEPT I5~ DTE IIRD DTE SFLU DTE TENS DTE DPH ! LDT ODS LDT LSHV,LDT LURH,LDT TENS,LDT NPHI.CNL NPOR,CNL CFTC,CNL CaLS'CNL HTEN.CNL POT~.~GT w~NG.NGT ~TE~ NGT GR:BGT DEPT. IMPH.DTE IL~.DTE IIRD.DTE SFLU.DTE TFNS.DTE 300.000 CIDP,DTE -999,250 CILD,DTE -999.250 IFRE'DTE n ~ :999,2:50 II×D, TR .999'250 SP*DTE 999'250 MTEM,DTE -999~250 RHOB,LDT -999,250 QS$,LDT -999,~50 LITH;LDT -999,250 SSHV,LDT -999.250 CASI,LDT -999 250 ~TEM,LDT -999 250 RTNR.CNL -999 ~50 RCNT,CN5 -999 ~50 SGR,CN5 -999,250 TENS,CNL -999 250 SGR'NGT -9'99 250 URAN..,NGT -999 250 W4NG,NGT -999 ~50 NRES,N~T 35 219 C1,B~T 200,000 CIDP,DTE -999' 250 CILD,D ,.E -999'250 IFRE"DTE -999'250 IIXD,DTE .-999,250 SP, DTE -999'~50 ~TEM,DTE -999.250 RHOB,LDT -999,250 QS$"LDT '999. 250 LITH.LDT '999.250 SSHV,LDT '999 2:50 CALI '999!250 MTE~,LDT '999 250 RTNR,CNL '999 250 RCNT,CNL '999.250 SGR'CNL '999.250 TEN$,CN5 '999,250 SGR,NGT '999,250 URAN, NGT :999,250 W4NG.NGT 999,250 ~R~. NGT 47.500 ".BGT 100.000 CIDP.DTE -999.250 CILD.DTE -999.250 IFRE,DTE -999.250 IIXD.DTE -999.250 SP.DTE -999.250 ~TE~.DTE .. l~-jUN-!gg! 15.2' 0 -99 -99~' 250 ..250 '999,250 17,500 -999,250 -999.250 -999'250 -999.250 -999 0 ~999 ~0 -999 50 -999 50 -999 i~50 -999 50 -999 250 '999 250 '999 ~50 '999 250 '999 ~50 '999 R50 '999 ~50 '999 250 969 -999 250 -999 250 -999 250 -999 250 '999 250 -999 250 -999.250 -99~: 50 -99 ~50 -99~ 250 -99 ~50 -99~ 250 -99 ~50 -999 250 '999 250 '999,250 -999.250 '999,250 -999,~50 -999. 50 17,313 ~999,250 999.250 -999.250 -999.250 -999.250 '999,250 WING,NGT CS'NGT C2,BGT IDPH,DTE ILD.DT~ IDQF,DTE SGR,DTE MRE$,DTE DRNO~DT S$1,SDT S~RH.SDT SGR LDT gRES 5DT TNPHCNS~ RCFTCN5~ CG~CN5 MRE$,CNL CGR'NGT W!NG,NGT W5NG, NGT 'CS'NGT C2'BG? ISD DTE IDO DTE "IIR~ DTE SGR DTE MRES,DTE DRHO'LDT 55,5DT ~IRH'LDT ~GR,~DT TNPH CNb RCFTCNL CGR CNL ,RES CNL CGR NGT W~NG,NGT WSNG.NGT CSNGT C2:BGT !DPH,DT£ ISD,DTE XDGF,DTE IIRM.DTE SGR,DTE MRE$,DTE ~999 250 -999.~50 !4,484 -999:250 -999 250 -999 250 -999 250 -999 ~50 .999: so -999~50 -999 250 -999 250 -999 -999,~50 -999 250 -999, i~50 -999 50 99~250 -999.~50 -999~50 -999 250 -999 23 859 -999 250 -999 250 -999250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -99 50 .999 50 -999,250 -999 250 -999 250 -999 250 -999250 -999.250 17.844 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 'W2NG NGT TENS:NGT HTEN,NGT TENS. BGT CI~P,DTE CIL~'DTE IIXM,DTE CGR~DTE 8TEN',DTE .PEF~LDT LU'SD~ SS2.SDT CGR"LDT HTEN,LDT TNRA'CNL CNTC,CN5 CALI,CNL ~TEM.CN5 THOR, NGT W2NG NGT TENS NGT HTEN. NGT TENS~BGT CIMP.DTE CIL~,DTE IIX~,DTE CGR,DTE HTEN'DTE PEF,SDT LU,LDT SS2,LDT 5SRH,LDT CGR,LDT HTEN,LDT TNRA,CNL CNTC,CNL CALI,CNL ~TE~,CNL THOR~NGT WRNG.NGT TENS,NGT HTEN,NGT TENS.BGT CI~P,DTE CILM.DTE I~OF,DTE IIX~.DTE CGR.DTE HTEN.DTE PAGE~ 33. '999,250 "999.;250 505'000 "999~250 .999,250 .999,250 999'250 '999~50 ~999:,50 :999; 5o ;999,250 999;2,50 -999 :,50 "999 150 250 "999 250 · -999 250 '999~50 -999: 0 400 000 :999'~50 .999 999 -999 50 99 ~50 25O -999 250 99250 -999250 -9 -999 250 -999 250 -999~250 -999250 -999250 465 000 -999250 -999 250 -999 250 -999 250 -999 250 -999 250 90~i00 ~ *0 000, Gg.666 ~666- 05~666- OS ~666- '6 OSS'; 66= 0~':666= OG~."666 0t~,666- 0~':'666- 0S'66 0~i~666' : . 0 0~g:666- o, 0S~666- 666~ 0S1'666~ ~£ ~3DVd ~gN'aON~ qN~iW~&N OSg qN~ IqV~ OS~ Oq'~DD &Oq"nq OS~ &aq*~3d OS~ o"a93 ~&O'WXII 3&O'WqI~ EI 666- 666- 666- 666- 666- 666' 666- 666' 666- 666- 666- 666- 666- 666- OSI 666- 166- 66- 666- a~ OS~ IqYD OS~ qN~ D~.N3 0 ~ VaNS OS ~Oq N~$H OSi 666- 666- 666- 666' 666' 666' 666- 666- 666- 666' 666- 666- 666' OS~ 666' SDN DNI~ &DN qND $oq 350 ~Oq'I OS~ 66- OS~ 666- 09~ 666- OS~ 666- 0~ ~66' OSg 66~ OS~ 666- 0~ 666- OS~ 166- OSg 66' OSg 666- OSg 666- OS~ ~66~ OSg 66~ oSI 666- OS~ 666- 666~ Oil 666' 0§~ 666' OS 666- OS 666- 0~ 666- Oil 666- Ol~' 666- Ot~ 666- 666- OS~ 666- Ogg 666- 0~ 666 0~ 6662 0~ 666- 310'0Xli IDN'DNg~ qND'~Dg $Oq OS~ 666- OS~ 666- OSE 666- OS~ 666- OS~ 666- 0~ 666- oSE 666- OS~ 666- OSg 666- 0f~ 666- 0S~ 666- 0~ 666- 0~ 666~ Oil 666' Otg 666' OS~ 666~ OS 0SE.666' OSE 666' OOt'E6 0SZ'666' OS~ 666- 0S~'666~ 0~g'666~ 0S:g'666- 0~'666- 0S~o666 0~666- 0~' 666- £DNi~S£W SDNgN£~ 9ND qND'aOd~ £Oq':Huflq ZOq'qq aaq:gqo £OqiHdO qND I~dN ~oq qq aOq ~elueD bul%ndmOD easetV J~bzeqmn'lq; buI3s~q uo!le~l~t~,aA a~'e$ ~ iS Tape: Yerl~,ication Listing ;hlumberger Alaska Computing center FILE NAME : EDIT ,002 SERVICE ~ FLIC V~R$ION : O01A06 DAT~ : 91/06/I~ MAX REC SIZE : 1024 FILE TYPE : LO 12"JUN-~ 991. 15;20 PAGE FILE - EDIT,O02 C0~OCO I~C. SCHRADER BLUFF MILNE POINT UNIT 50-029-22140 MAIN PASS MSf'5 LOG DATA DATA SAMPLED EVERY -,1667 FEET DAT.~ INCLUDED " TOOL EXTENSION ToOL TYPE USED NAME MSFL ,DLL MICRO-SFL ****************************************************************************** TABLE TYPE : CONS CN CONOCO INC, Company Name FN SCHRADER BLUFF Field Name WN MILNE POINT UNIT G-7 Well Name APIN 50-029-22140 API Serial Number Fl, 3235' FNL & 3451' FEb Field Location SECT 27 Section TOWN 13N Township RANG IOE Range COUN NORTH SLOPE County STAT ALASKA State or Province NaTI USA Nation WITN $, DECKERT / D, MOUNTJOY Witness' Name 'S TaDe Verification Listinq ~hlumherger AlasKa Computing Center DAT EPD FT APD FT E~B FT EDF FT E~L FT TDD FT TDL BLI FT TLI FT DFT DFD G/C3 DFPH DFV CP DF5 F3 RPS OHMM ~ST DEGF RMFS OHM~ MFS? DEGF R~C$ OHMM MCST ~EGF TC$ B~ DEGF VALU , DEF! 548t97 Service Order Number MSb Permanent datum 0 Elevation o~ Perm, Datum R~B LOg ~easured' From 65, ABOVE PERMANENT~DATUM 65, Elevation of Kelly 64, ~Elevation of Derric~ Floor Elevation of Ground ~evel 57 , 57§!, Total DePth - Logger' 5666, BottOm bog Interval 2697. ~ - Top ~og Interval LSND Urilltn~ Fluid Type.. 9'5 Drilling Fluid Density ~ ~9~~ Drilling Fluid Ph Ortllin~ Fluid VlScosit~ , DrlilinQ. FtUld boss 2.6B ResistiVitY of Mud~$ample 70 ~ud,.Samp!e. Temperature. 2,~1 Resistivity of mud filtrate 70 ' Mud...Filtrate.$emple.Tem~eratu: 2~! Resist~vit¥ oE MUd Ca~e.Sampl 70t Mud Ca~e Sample Temperature 16,oo 5,~i T~me C~rculat~on 97, Bottom Hole Temperature TABLE TYPE : CURV DEFI D~PT Depth Chann 1 Name MSFL ~$FL ResistYvltY $~IN Synthetic Micr Inverse Resistivity S~NO Synthetic Micr~ R s Y · Normal · tStiv!t ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE mmmmmmmmmmmmmmmmmmmmmmmm~mmmm 1 66 0 2 66 0 3 73 16 4 66 ! 5 66 6 0:~°6 SSS°9 989"~ ~"~ ~qO'ONNg 8[E'8 q~O'NI~ ~OL'B ~qO*~Xgw O00'O08f '~d2~ ~O'ON~ ~9'9 q~'NI~ ~£'6 ~'~2~ 000'006~ '~d2~ ~'ON~ ~9;'9 ~'NI~ ~9~°9 ~O°q~m 000'000~ ~Q*ON~ ~99'8 ~qO'NI~ ~6~*L qq~'~ 000'00~ ~qQ'ON~9 ~9~"~ qqo'Nl~ 8~6°~ qqQ'q~h 000'00~ qqO'ON~g T6£'t~ ~O'NIa9 £90'0~ q'lQ'~J~ O00'O0~S "~d~O QQQ*ON~ ~09°0~ QQQ'NI~ 68L'0~ Qq~'Q~gN O00*OOS~ '~d~Q QqO'ONN~ 6S8'~ qqO'Nl~ £~0'~ QqQ"Q~W O00'OOLS '~d3O 9gG'ONN~ 698'~ ggO'N~ 9~0°~ gqd'q~N 000'008~ ''''''''''''''''''''''''''''''''''''''''''''''''''0000000000 89 ~ T ~ 0 O0 000 .......... O0 ~618~§ ''''''~''''''''WEHO gQ ON~g 0000000000 89 ~ I ~ [ 0 O0 000 O0 L6t8~S ~hHO qqQ NI~ 0000000000 89 ~ I I ~ 0 O0 000 O0 L6~8~ ~NHO qqQ ']~ 0000000000 89 ~ t I ~ 0 O0 000 O0 L618~ ~ ~d3Q (X3H) ~QOD ~q3 d~ a~N QO~ ggVqD 3d~& 90q # ~O~O QI I 99 o I 99 9I 89 99 ST 0 99 £I 89 gI ~9 99 ~ ~tlq~A ~O03 ad~8' Md~& ~tO°O 990'9 990'L ~OI*L SiS*t q~O°ON~g ~qO'ONNg qqa'ON~9 qqo~oN~g Q~Q'ON~ qqo'o~N~ q~Q'ONW9 qqo'ON~g qqO'ON~9 [t9'O S[t'O 9DS'O 99L'L 8SL'8 OLL'9 6SE'6 L~O'LI 6~0'ol 88T°6 16£'6 S8l'9 gO6'D g£~'8 6gD'g~ : L6~'O~ 9qO'NI~ SLS'O qqO'q&s~ O00*g6D~ 9qO'NI~ ~6g'O qqa'9~ga O00'oosa 9qO'NI~ ~gL'O ~qo'q~9~ 000'009~ 9qO'NI~9 S08'6 qqo'q&g~ O00'OOB~ qgO'NIW~ E~S'~ 9qO'q~W 000'006~ 9qO'NI~g BE6'6 9qO'q~g~ 000'000~ qrlO'Nl~g £9S'E~ ~0'~ O00'OOEE ~qO'NIWS 9~9'9~ qqq'Q~g~ O00'OOD£ 9qO'Ni~9 LL6'E~ ~O'q~W O00'OOgE 9qO'NIWg 6~E'6 qrlO'~Jgw O00'oogE qqO'Ni~9 ELL'g ~qO'gjgW O00'OOLE qqO*Ni~ ~D~'~I qqO'q~ 000'008£ qqO'NiWS £S6'6 ~qo'qj~w O00'O06E 5qO'NI~$ Bi6'L 9qQ'qJgW 000'000~ qqO'NI~9 ~E6'S 9qO'qjgW O00'OOl~ qqO'NIWg 6S£'0! qqO'qjgW O00'ooE) qqo°NIHg 9gl'~t qqO'qjgW O00'OOt) qqO'Ni~g ~g8'91 qQO'Qig. O00'OOlD '~d2O '~d2a ~S Tape~ yeri~icat~on L~stlng :hlumberger' las~a Computing Center !2-JUN-!991 {.5:20 **** FILE TRAILER **** FILE NAME : EDIT ,002 SERVICE : F~IC VERSION .: 0 iA06 DATE : 91/06/!2 ~AX AEC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE NAME ~ EDIT ,003 VERSION ~ 00!A06 DATE : 9~/06/12 MAX AEC SIZE : ! 24 FILE TYPE : LO LAST FILE : PAGE~ 3'7 FILE - EDIT,O0] cONoco INC, SCHRADER BLUFF MILNE POINT UNIT G-7 50-029-22! 40 ALPHAPROCESSED DENSITY/NEUTRON & RECOMPUTED NGT. WITH KAbMAN & ALPHA FILTERS, ALSO INCLUDED IN PHASOR PROCESSED DITE DATA SAMPLED EVERY -,5000 FEET DATA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME * DIT-E PHS PHASOR DUAL INDUCTION SFL * LDT/CNL ,C~C SAN ALPHA PROCESSED LITHO DENSITY AND CNL * NGT ,K~ NATURAL GAMMA SPECTROSCOPY (KALMAN FILTERED) * NGT ,ALP NATURAL GAMMA SPECTROSCOPY (ALPHA FILTERED] i~IAI~9193~ ~09¥Hd NOI£~O~3B G~DN~HN3 NOI£3IIONI d330 ~3~I A£iAI~2RQNOD ~O~VHd NOI~AqO~ Q2DN~HN2 NOI£JRONi d22Q ~2QD A£IAI~D~QNOO BO~VHd W~IQ2N NOI~D~QNI ~WID %~IAI£DfiONOD MOP,Md dMMO NOI&Ofi~NI dOIO mmmmmmammmamammmmmamNmmmmmmmmammmmmmmm~mmmmmemmmmmmmmmmmmam paddO~ u~I~etn~tO aml& azn~ezadma~:a1~meg pnw OL A~gOO~A p~n~j ~U~tT~ZO ~ 9 6 H.d~O ~su~ p ntj 9~ 2. aTTllfl - qldaO IelO& °0~ l:a~aq punoJD ~o uol~eAaT3 buTqsng ~TTa~. ~o uo~eAeT3 '~9 ~VO ~N3NYW~d 3AO~'V *~9 ~J OdY mn3eo *m,:e~ ~o uo~leaet3 '0 JeqmnN ~aP~O a3~AJeg L6~g~g NOg. amen ,ssau3~ UOTleN VgA 1Z'~'N a~uTao~d ~.o ele3g AIUnOD MdO~9 H&MON N~03 abueB ~qsu~o~ NEt .N~O~ -uo¥).oeg L~ ~eq~N [e)Jeg I~V 0)~[~ eme~ PTeT~ ~m~N ~u~dmo~ I,J~O A"IVA ~e3ue3 , mm~mm~#mamm~m~mm#mmmmmmmmmmmm t 99 0 I 99 89 99 0 99 89 8 99 £~ 99 0 99 0 99 , . , mm~m~mmm~ammmmmmmmmmammmmmmmmm 6£ mnl~oq& ~OH& mnSsse~Od ~mn~ue~ ~mn~oq& ~o~ D pe~nd~oD · nlsse~Od ~Od mnI~oq~ ~OH~ mn;sse~od ~mn;uez~ 'mn~oq~m~o~ ~D pa~ndmo3 %~sO~Od uo~neN ~HdN ~suea uo~lnlosea Ie~llJe~ ~e~u~qu$ OH~N oo~ Dq~ eqg ~o~ ~;$O~Od ~IAI~DDON03 BO~Hd NOI~O~3B 03DN~HN3'X~3A NOI~DDONI W[~IO2~ aAWO A&IAI~ID3~ BODVHd NOI~9093~ ~3DNVHN3'A~3A NOIA.D~NI d33~ X~IAi~I~MM MOgYHd NOI'&Oqo~3M GMDN'VHN3 .NOI~D~NI WDIG3~ MMHI ~£IAI.£D~GNOD ~OS~Hd NOi&aqos3~ GMDN~HN3 NOI&Dfi~NI ~i'iI~3~ .hl.t~mberger AlasKa Computln0 Center i2-jUN-199~, 15~20 ** SET T~...E CHAN ** NAME SERV NIT SERVICE API I AP1 AP1 ID ORDER ~ LOG TYPE CLASS MOD DEPT FT 548197 CXDP PHS N~HO 548197 XDPH PHS OHMM 5481,97 XHP PHS MMHO 548197 MpH PHS OHMM 548197 CDE'R PHS ~MHO 548197 IDER PHS OHM~ 548197 CMER PHS MMHO 5481g7 IMER PHS OH.MM 548197 CDVR P~S MMHO 548197 IDYR PHS OM~M 5.48!97 C~VR PHS M~MO 548197 IMV~ PHS OHMM 548197 P~ND SAN PU 548197 PFDC SAN PU 548197 NRHO PRE G/C3 548197 RHOB CRC G/C3 548197 DRHO CRC G/C3 54819? PEF CRC 548197 NPOR SAN PU 548197 TNPH SAN PU 548197 NPH! SAN PU 548197 SGR KAL GAPI 548197 CUR KAL GAPI 548197 THOR KAL PPM 548197 POT~ KAL PU 548~97 U~AN KAL PP~ 548~97 SCR ALP GAPI 548197 CUR ALP GAPI 548197 THO~ ALP PPM 548197 POTA ALP PU 548197 URAN AI~P PP~ 548197 FILE NUMB NUMB SIZE R:PR PROCESS NUMB SANP ELE~ CODE [HEX) O0 000 OO O 3 O0 000 O0 0 3 O0 000 O0 O 3 OO 000 O0 O 3 ! O0 000 O0 0 3 OO 000 OO O 3 1 OO 000 OO O 3 1 O0 000 OO O 3 1 OO 000 O0 O 3 OO 000 oo O 3 O0 000 O0 0 3 1 O0 000 O0 0 3 O0 000 O0 0 3 00 000 00 0 3 00 000 00 0 3 I 00 000 00 0 3 I OO 000 OO 0 3 1 00 000 00 0 3 1 00 000 00 0 3 1 O0 000 00 0 3 I 00 000 00 0 3 ! 00 00o 00 0 3 1 O0 000 00 0 3 1 00 000 00 0 3 1 00 000 O0 0 3 1 00 000 00 0 3 1 00 0o0 00 0 3 00 000 00 0 3 1 O0 000 O0 O 3 1 00 000 00 0 3 OO 000 00 0 3 1 00 000 00 0 3 I I 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 t 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 ! 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 PAGE{ 4O DATA DEPT, 5803,000 IMPH,PHS 2,785 IMER.PHS 2,785 IMVR,PH$ 2,785 RHO~,CRC 2,215 TNP~.SAN 42,051 THOR.KA6 0,000 CUR.ALP -999,250 DEPT. 5BO0.000 ZMPH.PHS 2.785 I~E~.PHS 2.785 IMVR.PH$ 2,785 CIDP,PHS CDER,PHS CDVR,PHS PHND.SAN DRHO.CRC NPHI,SAN POTA KAL THOR:ALP CIDP.PHS CDER,PHS CDVR.PHS PHND,SAN 346 039 346 900 347 594 26 362 -0 007 42 051 0 000 -999:250 346.039 345,945 346.640 26.362 iDER IDVR PFDC PEr SGR URAN POTA IDPH IDER IDVR PFDC ,PHS ,PHS ,,PHS ,SAN ,CRC ,KAb ,KAL ,ALP ,PHS ,PHS ,PHS ,SAN 2890 2 883 2 877 26 362 '999 250 0 000 0,000 -999.250 2.890 2.891 2.885 26,362 CIMP,PHS CMER.PHS CM'VR,PHS NRHO,PRE NPOReSAN CUR,KAL SUR.ALP URAN.ALP CIMP,PH$ CFgR. PHS CMVoR:PHS NRH PRE 359 100 359 058 359 076 2 215 42 051 0 000 -999'250 -999,250 359,100 359,058 359,076 2.215 L~,LL~ ~6~9L~ ~LL 9L~ 06L'O 9L£°;9 £96°6~ 88L°0 L~[~L o~~ o~ 856,~9 68~,~[ 6~,O.L~ 989,~8 OS~ 960 8S LO£ 8E Oii ~ 6£6, ~E L~gTE 0S~666- 0~666.- 000 0 :~DVd NVD'aOdN 3~d'OHaN gHd*aAWD gHd'dNID gHd'dWI3 dqVjUOg NV~OdN 3Bd'OHBN gHd'~kWD 9Hd"dWID NVe~OdN 3~d~:OH~N ~Hd l~[D NVg'~OdN 2Bd'OHBN NVgSOdN LSL £ ~6S'l ~8"0 g~'~g 018'~ LtO'~ tO6° E£E'g Z69~ OOSoO 6LO.E 969' f96 o6a,t 096.S9 tE/.S $99.S 6 ~L02~ 05E'666-. 6L~'9 995~60~ SSOE 0S0,66 000,0 oos,o i6 ~ gHd'~2Ol gHdeRdOI dqV'VgOd gHd*8AOI ~Hd*HdOI dqV2V~Od qV~,NV~n q~ D~D'~3d gHd Hd~l N'VgDO~d Hd'~3Ol Hd'HdOI dqV*V$Od qV~SDg DHd*~QI qv~ :N'Vg DOJd LO0°O i~T6'99~ '99ig 099'L 90 °0 f09'~ O~6'~T LO6't~T ~68°LST t*6 9~8'T LO0'O 9L~i9Z tOT TIT SS~ I T98~6£ glO~O- ~'£6.L~ LL~'~LT E 'OT O0 ' 0 8~,, ~ T~ gE L£!* i N~g*QNHd gHd'a2QD qv~*{gOd NVDeIHdN gHd'BAQD DHd'~3QD ~Hd*dO)D dqV]aOH~ NVg,lHdN 3aD,OHaQ NVD'QNHd gRd'dOiD dqV"8OH~ DHDOHaO Nvg*.ONHd gRd:8 OD gHd~dOID dq¥'aOH~ N~gONHd SHddOlD )09°i TI9'E ET9'E T6T,LS TL~'8 T6T'[ 'L TSO,9 899 . 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LtL;OS 0£~'~ EL9 t L~t 9 ILO[ ~06' 8't 880'9 '0' :,9 6o :1. 66St 8E61o 8£g '89 gHd*aAOI 9Hd'HdaI qV~*NVSfl ~V~°BDg N~g*DQ~d SH~Hd~i ~:¥&Od gHd'Hdal N¥~'DOdd gRd~dOI Da/d' DHd*H3QZ SHdIHd~I ', ' 'e dqV.V& :d qv~:HDg , ESS 8f tO00- SL60£ 0t095 6£~ SS 61S £S t69'9 'LOl'I LT 'Oi t£8'LtI t69'8t~ 61 00'0' oLg,~ t ~Z808t Ozg. 8 SLL 8~ GOO 0 6S066 !SI 8~9~0t 900~0 L£9'8~ 68L;81 800 O* ~9 ' S~9 99E 8: OOL I 8 L 9 L £ NYD'IHdN 9Hd'~AflD gHd'dOlD dq~'aOH$ NVg'IHdN D~D*OH~ N~D'ONHd gHd'~AGD gHd'~3QD DHd'dOID dqV'~OHt NVg'IXdN DUD::OXSQ fl~g'ONHd 9Hd*BAQD 9Xd'~3OD 9Hd'dGi~ qV~Od DUD!OH~Q N'VD~flNHd 9Hd'SAQD 9Hd'HQID N~'D~QNHd gHd'd~lD dqV~BOH& N:~9 IHdN gHd"dQiD 00~ 6t 000'009~ 9L6'9~ 699'9 O00'OOL9 ~*19 ~8 '6 sgi'L£ LS£-~ 000 089 ~Og,9 O0 O06t t68'9L 000 O00S DUD'aOHa 98d'~ANI '&d3O q~'~OH& NVg'HdN& D~D'9OH~ gHd'aANI gHd'~3H! *Hd~I ~H'd.&d3O q~OH$ 9Hd'UA~i 9Hd"HdAI D~D~OHB gHd aa gHd:~a~i 6~0'99 d V 8DD SL6':L 'IV~*aOHi 68L:"~f Ni~"HdN~ 801'' DHD*HOHH O00'OOIl £difl 88'T9 dq~'aDD buTlndmoD e~sel¥ ~ab~e.q~ntq; Alaska Com~ut~n~ Center 12-JUN-!991 15:20 PAGg ,' 4¸3 KAL 1 , 146 CGR,AbP 6,426 DEPT. I~:PH,P~s !HER PHS I~V~ PHS RHO~ C~C NPUSAN ~OR D~PT z.p PuS I~ER PHS IMV~ PHS RHOB CRC TNPH SAN ~HOR KAL CCR A6P DEPT. iMPH.PH$ .PHS RHOB,CRC TNpH,sAN THOR.KAL CGR.ALP DEPT IPPHiPHS PE~ PHS I~V~ PHS RHOB CRC TNPH.SAN THOR.KAL CGR.AbP DFPT. IPPH.PH$ INER PHS RHOB,CRC TNPg'$AN TMOR,KAL CG~.A5P DEPT. IHPH,PH8 IMER.PH$ IMVR.PHS RHOB.CRC TNPH.$AN THOR.KAL 6'28! POTA.KAL 44*943 THOR.ALP 4500,000 CIDP,PHS 17,238 CDER;PH$ 16,971 CDVR,PH$ 16'532 PHND,$AN 2'088 DRHO'CRC 42'626 NPHI.,$AN 6'375 POTA*KAL 41,557 THOR.ALP 4400.000 CIDP.PH$ 8,114 CDER,PH$ 8,103 CDVR'PHS 8.346 PHND,SAN 2'1!5 DRHO;CRC 40,053 NPH.I.SAN 6'28! POTA~KA~ 46'601 THORiALP 039 CDERiPH$ 430i::0 CIOP:*PH$ 223 CDVR,PHS 41., 62 NPHI,SAN 5~.:~05 POTA.KAL 40.5 T~OR',ASP 4200,000 CIDP*PHS 6.302 CDER'PH$ 6,234 CDVR.PH$ 012 DRHO.CRC 48'453 NPHI.$AN 10.608 POTA,KA5 79.607 THOR.ALP 4100.000 CIDP.PH$ 5.550 CDER,PH$ 5.537 CDVR.PH$ 5'524 P~ND.SAN 2,173 DRHO.CRC 40.935 NPH! SAN i1'150 POTA~KA5 72'058 THOR.ALP 4000.000 C~DP.P~$ 6.995 CDER.PH$ 7.005 CDVR.PH$ 6,998 PHND.SAN 2.100 DRHO*CRC 41 163 NPHI.SAN 7:119 POTA.KAb 50, 56,. 3 ~3,797 0~? 28 443 21 849 1i8 501 32 4.1.1 ,053 !.435 5,972 142.258 ,399 133.074 155, 2 824 '0,002 48,453 2.~49 10.859 886 I73 319 28 903 0 012 40 935 ! 955 10:562 135,408 1~,1.95 .589 132,778 -0.020 41.163 1.893 URAN,KAL POTA*ALP IDPH,PHS IDER.PH$ IDVR'PH5 PFDC,SAN PEF,CRC SGR,KAb URAN,KAL POTA.,AL.P IDPH*PHS IDER,PH$ IDVR.PH$ PFDC~$AN PEF CRC SGR KAL URAN KAL POTA ALP. 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