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191-023
From:Darci Horner - (C) To:Regg, James B (OGC) Subject:RE: [EXTERNAL] RE: MIT-IAs for Milne Point wells G-05, G-09 and H-15 Date:Friday, April 1, 2022 10:30:08 AM Attachments:MIT MPU G-05 3-10-2022 pre-injection.xlsx Yes! I found that one, too, on the same day and filled out the form according to the field notes. Here ya go, Jim. Regards, Darci From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Friday, April 1, 2022 9:15 AM To: Darci Horner - (C) <dhorner@hilcorp.com> Subject: RE: [EXTERNAL] RE: MIT-IAs for Milne Point wells G-05, G-09 and H-15 Thanks; how about G-05 (PTD 1910230)? Possible done the same day? Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Darci Horner - (C) <dhorner@hilcorp.com> Sent: Friday, April 1, 2022 7:38 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: RE: [EXTERNAL] RE: MIT-IAs for Milne Point wells G-05, G-09 and H-15 Yes, I found this one done on Mar 10, Jim. From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Thursday, March 31, 2022 6:38 PM To: Darci Horner - (C) <dhorner@hilcorp.com> Subject: [EXTERNAL] RE: MIT-IAs for Milne Point wells G-05, G-09 and H-15 Was there a pre-injection MIT done? Jim Regg Supervisor, Inspections MPU G-05 PTD 1910230 CAUTION: 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. AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Darci Horner <dhorner@hilcorp.com> Sent: Wednesday, March 16, 2022 3:31 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Cc: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com>; Jon Arend <Jon.Arend@hilcorp.com>; David Gorm <dgorm@hilcorp.com>; Alaska NS - Milne - Wellsite Supervisors <AlaskaNS-Milne- WellsiteSupervisors@hilcorp.com>; Alaska NS - Wells Foreman <PBWellsForeman@hilcorp.com> Subject: MIT-IAs for Milne Point wells G-05, G-09 and H-15 All, Milne Point wells G-05 (PTD # 1910230), G-09 (PTD # 1971170) and H-15 (PTD # 2051590) successfully passed routine MIT-IAs on March 8 and 13, 2022. G-05 and G-09 are both recently returned to injection after being shut in. Please call myself or Jerimiah Galloway (907-564-5005) with any questions. Regards, Darci Horner Technologist Office: (907) 777-8406 Cell: (907) 227-3036 Email: dhorner@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified 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 deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately 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 the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual 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 the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1910230 Type Inj N Tubing 189 222 222 222 Type Test P Packer TVD 3,731'BBL Pump 2.5 IA 0 1745 1653 1627 Interval 4 Test psi 1500 BBL Return 1.5 OA 113 125 125 126 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: Hilcorp Alaska, LLC Milne Point / MPU / G PAD Derek Weglin 03/10/22 Notes:Returning to injection. Notes: Notes: Notes: G-05 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Form 10-426 (Revised 01/2017)2022-0310_MIT_MPU_G-05 J. Regg; 4/1/2022 CAUTION: 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: OPERABLE: Injector MPU G-05 (PTD# 191-0230) Date:Monday, March 14, 2022 3:03:07 PM Attachments:image001.png image002.png From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Tuesday, March 8, 2022 2:24 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; David Haakinson <dhaakinson@hilcorp.com> Subject: OPERABLE: Injector MPU G-05 (PTD# 191-0230) Mr. Wallace, PW Injector MPU G-05 (PTD# 191-0230) is currently shut in with plans to return to injection. The well was shut in September 2017 and has remained shut in since. The last witnessed MIT passed to 1970 psi in September 2017. Since the well has been shut in, it missed the last scheduled MIT. The well is classified as OPERABLE. Plan Forward 1. AOGCC Pre-Injection MIT-IA 2. AOGCC Post Injection MIT-IA (Upon stabilization) Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error,you are hereby notified 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, thenpromptly 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 the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems ordata. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,September 13,2017 TO: Jim Regg C �/ P.I.Supervisor l e f �t t- i/7 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC G-05 FROM: Jeff Jones MILNE PT UNIT G-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry d-�_— NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT G-05 API Well Number 50-029-22138-00-00 Inspector Name: Jeff Jones Permit Number: 191-023-0 Inspection Date: 9/9/2017 ✓ Insp Num: mitJJ170911105052 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 0-05 Type Inj W 'TVD 3731 Tubing 853 ' 853 - 855 855 - PTD 1910230 Type Test SPT Test psi 1500 IA 884 2023 - 1980 - 1970 - BBL Pumped: 0.8 •BBL Returned: 1 OA 324 348 , 353 - 354 - Interval 4YRTST P/F P ✓� Notes: 1 well inspected,no exceptions noted. iCA :-EB I 3 2013. Wednesday,September 13,2017 Page 1 of 1 MPt . pn tq(az3D Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] r7nO J1/ Sent: Tuesday, October 01, 2013 9:45 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: AK, D&C Well Integrity Coordinator Subject: September 2013 AOGCC MIT Forms Attachments: September 2013 MIT Forms.zip All, Please find the attached MIT forms for September 2013. WELL PTD# NOTES MPE-12 2050670 MPE-26 2002060 MPE-29 2010370 MPG-05 1910230 NJ!- c,h.hte5seot �� A- cc- MPG-19 2041920 MPS-15 2012450 NK-18 1931770 NK-65A 2050630 09-22 1831730 14-21A 2051070 GNI-02A 2061190 EPA AND AOGCC FORM a�� D �� � GNI-03 1971890 EPA AND AOGCC FORM s •+�4 GNI-04 2071170 EPA AND AOGCC FORM OWDW-NW 1002400 EPA AND AOGCC FORM OWDW-SE 1002390 EPA AND AOGCC FORM N-23 1970120 NG I-01 1750480 P-03A 1972280 U-05A 2090700 X-29 1931390 Please contact us with any questions. Thank you, Jack Disbrow BP Alaska-Well Integrity Coordinator GWgirQgaanization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator @bp.com 1 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaq @alaska.gov; doa.aoocc.prudhoe.bavaalaska.aov: phoebe.brooks(caalaska.aov; tom.maunderaalaska.nov OPERATOR: BP Exploration(Alaska),Inc. y C ' to(lit 3 FIELD/UNIT/PAD: Prudhoe Bay/MPU/G-Pad DATE: 09/09/13 OPERATOR REP: Laurie Climer AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well MPG-05 Type Inj. W ' TVD 3,731' Tubing 834 831 '' 829 835 - Interval 4 P.T.D. 1910230 / Type test P Test psi 1500 Casing 10 ' 2000 ' 1925 1905- P/F P Notes: Standard 4 year MITIA OA 180 224- 226 223 Took 1.3 bbls to reach 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 I=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 ACT MPG-05 09-09-13.xls • 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 �J Alaska Oil and Gas Conservation Commission 1 333 West 7 Avenue , Alaska 99501 1' Anchorage, � � � Subject: Corrosion Inhibitor Treatments of MPG -Pad I' I 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 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 if 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 -.---Y 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 OPERABLE: MPG-OS (PTD #1~230) Passing AOGCC witnessed MIT~ Page 1 of 3 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] '~~ ~~ J a-I~ Sent: Thursday, September 17, 2009 9:07 AM ~ To: NSU, ADW Well Integrity Engineer; Regg, James B(DOA); Maunder, Thomas E(DOA); MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Production Optimization Engineer; MPU, Wells Ops Coord2; MPU, Area Manager; NSU, ADW Well Operations Supervisor; Engel, Harry R; Rossberg, R Steven Cc: Quy, Tiffany; Lopez, Keith ~ Subject: OPERABLE: MPG-05 (PTD #1910230) Passing AOGCC witnessed MITIA All, Well MPG-05 (PTD #1910230) passed an AOGCC witnessed MITIA for regulatory compliance. The well has been reclassified as Operable. Please let me know if you have any questions. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 ~~'~:'~.~~~c.,r ;`f:~'' ~ ~' ~U~J From: NSU, ADW Well Integrity Engineer Sent: Saturday, September 05, 2009 3:43 PM To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Production Optimization Engineer; MPU, Wells Ops CoordZ; MPU, Area Manager; NSU, ADW Well Operations Supervisor; Engel, Harry R; Rossberg, R Steven Cc: Williams, Carrie; Engel, Harry R; lopez, Keith; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: MPG-05 (PTD #1910230) Place on injection for UIC MITIA All, Milne Point well MPG-05 (PTD #1910230) has been reclassified as Under Evaluation so that the well may be placed on injection, allowed to thermally stabilize, and an AOGCC witnessed MITIA may be conducted. A this ~- time there are no indications of integrity concerns. Please let us know if there are any questions. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) lfilell 1n~egrity Coardinator GP~ Wells Group Ph~n~: (907) 659-5102 Pager: (907) 659-5100 x1154 11 /4/2009 OPERABLE: MPG-OS (PTD #1~230) Passing AOGCC witnessed MIT~ Page 2 of 3 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, February 18, 2009 2:15 PM To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Production Optimization Engineer; MPU, Welis Ops CoordZ; MPU, Area Manager; NSU, ADW Well Operations Supervisor; Engel, Harry R; Rossberg, R Steven Cc: Holt, Ryan P(ASRC); Engel, Harry R; NSU, ADW Well Integrity Engineer; Roschinger, Torin T.; Lopez, Keith Subject: NOT OPERABLE: MPG-05 (PTD #1910230) Wait to place on Injection for UIC MITIA AI I, It has been decided to wait on return well MPG-05 {PTD #1910230) to injection until one of the offtake producers are online. The Under Evaluation notice will be sent at a later date. For now the well has been reclassified as Not Operable. Thank you, Anna ~u6e, ~. E. Well Integrity Coardinator GPB Welis Group F'hane: {907) 859-5102 Pager. (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, February 15, 2009 8:28 PM To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Production Optimization Engineer; MPU, Wells Ops Coord2; MPU, Area Manager; NSU, ADW Well Operations Supervisor; Engel, Harry R; Rossberg, R Steven Cc: Holt, Ryan P(ASRC); Engel, Harry R; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: MPG-05 (PTD #1910230) to place on Injedion for UIC MITIA All, MPG-05 (PTD #1910230) has been reclassified as Under Evaluation so that the well may be placed on injection, allowed to thermally stabilize, and an AOGCC witnessed MITIR may be conducted. A this time there are no indications of integrity concerns. The annulus pressures have been less than 100 psi since the well was shut-in 11 /13/05. Please let me know if there are any questions. Thank you, Anna ~Du6e, ~P. E. Well Int+egrity Coordinator G~B Welis Graup Phane: (907) 659-5102 Pager: (907} 659-510U x1154 From: NSU, ADW WeU Integrity Engineer Sent: Thursday, October 23, 2008 12:41 PM To: MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Production Optimization Engineer; MPU, Wells Ops Coord2; MPU, Area Manager; NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P(ASRC); Engel, Harry R 11 /4/2009 OPERABLE: MPG-OS (PTD #1~230) Passing AOGCC witnessed MIT~ Page 3 of 3 Subject: NOT OPERABLE: MPF-74 (PTD #1961080), MPG-05 (PTD #1910230), MPF-82 (PTD #2001250), MPF-90 (PTD #2012110) Hi all, Milne Point wells MPF-74 (PTD #1961080), MPG-05 (PTD #1910230), MPF-82 (PTD #2001250), and MPF-90 (PTD #2012110) are being reclassified to Not Operable due to being overdue for UIC MITIA testing. These wells are currently shut-in for reservoir management. When Milne Point operations are ready to return these wells to injection, please notify the Well Integrity Coordinator. The WIC will then obtain an agreement with the AOGCC to have these wells online for compliance testing. Please let us know if you have any questions. Thank you, Anna ~Dude, ~P. E. Weil Integrity Coordir~ator GPB Wells Group Phon~: (907) 659-5102 Pager: {907) 659-5100 x1154 11 /4/2009 ~ ~ ` ~~ / STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; tom.maunder~afaska_gov;ka~.fleck~n~ia~.gav;d~.aogcc.prudhoe.bay~alaska.gov OPERATOR: FIELD / UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP E~c~oratian (Alaska}, Inc. Miine Paint / MPIf ! G-Pad 09/16109 M~ iv~s+on J~eff Jon~s P~ker Rret~est In6tia1 15 RAin. 30 Min. Well MPG-05 T In'. W TVC) 3,73t' T' 1, 1,OOQ 1, 1,OU0 k~tervai' 4 P.T.D. 1914230 T test P Test ' 15(f(? C" i, 1,720 1,7 1,720 P/F P Notes: AOGCC witnessed MtTdA for 4-yr ~Jf~ {)A t45 t9(? 2()0 200 Well T In'. TVD ' T" Interval P.T.D. T test T~ ' P!F Notes: OR Well T tn'. TYD Tu ` Interval P.T.D. T test T~ ~ P/F Notes: OA Well T In"_ 7'WD T" Irrterval P.T.D. T test Test ' PIF Notes: OA Weli T in". TVQ T' Intervai P.T.D. T test Tesk " " P/F Notes: t?A TYPE INJ Codes D = Driliing Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water rv~ ~s~ coa~ M = Mnulus INonitarirrg P = Sharidard Pvesseare Te~ R= lr~ter~a! R' ' Tracer Su~uey A = T S~nrey D = • . T~~ Te.st (yy~,}p~=~~ ~[ P~ ~~' 1:~~4.tt~~V~Luild l~'y ~! J.~ C:~ G.S1L`J ~t~f ~ INTERVAL Codes I = Ini~al Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT MPU G-05 09-16-09.x1s NOT OPERABLE: MPG-OS~TD #1910230) Wait to place on Inject for UIC MITIA Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWe111ntegrityEngineer@BP.com] Sent: Wednesday, February 18, 2009 2:15 PM ~~~~ ~J16 ~II To: Regg, James B (DOA}; Maunder, Thomas E (DOA); MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Production Optimization Engineer; MPU, Wells Ops Coord2; MPU, Area Manager; NSU, ADW Well Operations Supervisor; Engel, Harry R; Rossberg, R Steven Cc: Holt, Ryan P (ASRC); Engel, Harry R; NSU, ADW Well Integrity Engineer; Roschinger, Torin T.; Lopez, Keith Subject: NOT OPERABLE: MPG-05 (PTD #1910230) Wait to place on Injection for UIC MITIA All, .~ WJ_~ 7 It has been decided to wait on return well MPG-05 (PTD #1910230) to injection until one of the offtake producers are online. The Under Evaluation notice will be sent at a later date. For now the well has been reclassified as Not Operable. Thank you, Anna ~Du6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, February 15, 2009 8:28 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Production Optimization Engineer; MPU, Wells Ops Coord2; MPU, Area Manager; NSU, ADW Well Operations Supervisor; Engel, Harry R; Rossberg, R Steven Cc: Holt, Ryan P (ASRC); Engel, Harry R; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: MPG-05 (PTD #1910230) to place on Injection for UIC MITIA All, MPG-05 (PTD #1910230) has been reclassified as Under Evaluation so that the well may be placed on injection, allowed to thermally stabilize, and an AOGCC witnessed MITIA may be conducted. A this time there are no indications of integrity concerns. The annulus pressures have been less than 100 psi since the well was shut-in 11 /13/05. Please let me know if there are any questions. Thank you, Anna ~Du6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer 4/ 16/2009 NOT OPERABLE: MPG-OS~TD #1910230) Wait to place on Inject for UIC MITIA Page 2 of 2 Sent: Thursday, October 23, 2008 12:41 PM To: MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Production Optimization Engineer; MPU, Wells Ops Coord2; MPU, Area Manager; NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC); Engel, Harry R Subject: NOT OPERABLE: MPF-74 (PTD #1961080), MPG-05 (PTD #1910230), MPF-82 (PTD #2001250), MPF-90 (PTD #2012110) Hi all, Milne Point wells MPF-74 (PTD #1961080), MPG-05 (PTD #1910230), MPF-82 (PTD #2001250), and MPF-90 (PTD #2012110) are being reclassified to Not Operable due to being overdue for UIC MITIA testing. These wells are currently shut-in for reservoir management. When Milne Point operations are ready to return these wells to injection, please notify the Well Integrity Coordinator. The WIC will then obtain an agreement with the AOGCC to have these wells online for compliance testing. Please let us know if you have any questions. Thank you, Anna ~Du6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 4/16/2009 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well MPC-41 MPG-05 MPL-33 P-06A DS 02-25 u.~. 09-10 B-20 Y-25 PSI-10 P-26 02-14A F-12 04-35 ~ 5-09A 15-09A 5·09A J-13 D.S. 09-29 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job# 10889195 10715440 11058514 11132061 10987525 11058237 10980591 10928605 10715447 10928634 11075901 NA 10889172 10889183 NA 10919942 10877750 10980596 ~NE[) OC1 :1 12.ûD5 Log Descriptiol1 SBH SURVEY MPSP INJECTION PROFILE INJECTION PROFILE LDL INJECTION PROFILE INJECTION PROFILE \>OO-~ y \~ ~ ~ LDL MEM PPROF W/DEFT MPSP IPROF & WARMABACK MEM PPROF W/DEFT MEM PPROF & IPROF LDL SBHP SURVEY OIL PHASE BOTTOM HOLE SAMPLE OIL PHASE BOTTOM HOLE SAMPLE OIL PHASE BOTTOM HOLE SAMPLE LDL PPROF W/DEFT c o&--~~- Date 12/24/04 11/09/04 06/03/05 10/12/05 06/24/05 08/16/05 08/05/05 11/20/04 01/01/05 06/02/05 07/09/05 06/03/05 10/10/04 11/04/04 02/02/05 02/13/05 06/29/04 08/10/05 NO. 3503 10/18/05 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Color CD ~ - Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 Anchorage, AK 99503- 8 A TTN: Beth Received by: , ðJN\ ~gl.;^L);;1t ..~.{-~ ON OR BEFORE 0 No EMBER 2 200 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate .~X Pull tubing __ Alter casing m Repair well ~ Other 2. Name of Operator CONOCO INC. 3. Address 3201 'C' STREET, SUITE 200, ANCHORAGE, AK 99503 4. Location of well at surface 3354'FNL, 3435'FEL, SEC.27, T13N,. RIOE, UN, NSB At top of productive interval 3400'FNL, 4700'FEL, SEC.27, T13N, RIOE, UN, NSB At effective depth At total depth 3365'FNL~ 4920'FEL~ SEC.27~ T13N~ RIOE~ UN,, NSB 12. Present well condition summary Total depth: measu red 4950 feet true vertical 4560 feet 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KB 35' AGL 7. Unit or Property name UII_NE POINT UNIT 8. Well number G-5 9. Permit number/approval number 91-23 10. APl number 50--029-22138 11. Field/Pool Plugs (measured) feet Effec,tive depth: measured 4570 feet true vertical 4304 feet Junk (measured) Casing Length Size Structural 70' 13-3/8" Conductor 2405' 9-5/8" Surface Intermediate 4155 ' 7" Production 800' 4-½" Liner Perforation depth: Cemented SURFACE SURFACE TOOL~3200 Measured depth 105' 2440 ' 4190' 4821 ' measured 4288'-4305', 4314'-4322', 4338'-4366', 4429'-4455', 4504'-4528' truevertical 4044'-4060', 4068'-4075', 4090'-4116', 4175'-4198', 4244'-4266' Tubing (size. grade, and measured depth) 2-7/8", 6.5#, L-80, 8 rd EuE, 4001'ND Packers and SSSV (type and measured depth) OT IS PLS RETR I EVABLE PACKER AT 3952 ~ueverticaldepth 105' 2340' 3947' 4533' J ECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) NONE Treatment description including volumes used and final pressure AUG 2 ? 1992 Alaska Oil & Gas Cons. Commission Anchorage 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 146 I~°D (CURRENTLY S/I' 8-92} 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __ Gas __ Suspended Service WATER INJECT ION 17. I ) istrue and correct to the best of my knowledge. ned L~..~ Title ~"~"~t ~L~D?=(_(2~ 1, ""~" Form 10-404 Rev 06/15/88 i SUBMIT IN DUPLICATE ~5 '8~ 14:15 P~GE.00~ CONOCO INC. DALLY WELL ACTIVITY REPORT ALASKA ACTIVITY ~F MD SERVICE PERSONNEL . NO. FLUID T'YPE/D.E ,NSITY: RIG SAFETY PERFORMANCE I ALL DAILY COSTS ENVIRONMENTAL INCIDENTS ~ YEAR TO DATE ~ $ LAST BOPE TEST LOSSESTODAY/CUM. I~ I I PILLS BOPE TEST DUE i A,15Ska ._~.! ~ ~RR .Cons. ^o~cc viSIT? ,~1 $ ;Anchprage CUM. FLUIDCOST: $ jl~ ~CS~ i~ PLUG DF. SC. BPV IN I(~"~ COST SUMMARY DALLY CUMULATIVE PREVIOUS TOTAL $ ..... S PLANNED TROUBLE TOTAL · , ENGINEER EST. FINAL pO.S'~'_ .$ ..... { SUPERVIS. OR~ /,/.]. 14:16 PRGE.004 CONOCO INC. DALLY WELL ACTIVITY REPORT ALASKA WELL' ~' PROJECT: ACTIVITY AT REPORT TIME: AFE/FACIUTY: WEATHER: ACTIVITY DAYS CUM/PI.,~N: CURRENT DEPTH: MD Gas Cons. Commission SERVICE PERSONNEL- NO. FLUID TYPEI DENSITY: _~.Z/~, RIG SAFETY PERFORMANCE ] ALL DAILY COSTS PILLS CUM. FLUID COST: $ DAYS WITHOUT ,, YEAR TO DATE LAST BOPE TEST __ _ BOPE TEST DUE AOGCC VISIT?. ENGINEER PLUG DESC. PREVIOUS TOTAL BPV IN/~ COST SUMMARY DALLY CUMULATIVE $ PLANNED TROUBLE TOTAL AFl: COST [ suP~RV~SO.~ ** TOTRL PRGE.004 ** ~201 C SO'eat, Suite 200 (907) March 27, 1992 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear Blair Wondzell, Please find attached the casing and oementing reports for J~and several other Schrader Bluff wells. Unfortunately, the foreman that completed the form .did not indicate that there were full returns during the cumerlt job. However, I contacted the foreman, Joe Polya, that did the 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 exceed the fracture gradient. Additionally, I contacted the foreman opposite Mr. Polya and he confirmed that loss r~turn~ or] this casing string in tho Schrader 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 inf~on and if the~'e i~ anything I can do in the future do not hesitate to call (,504-7609), i~st Regards, Steve Bolt DMsion Drilling Superintendent RECEIVED 2 7 ]992 A~aska tJil & Gas Cons. Commission Anchorage £7 ~@~ t5:27 ~Of'l CONOCO TO Mil;U-'. ?OINT CASING AND ¢~ENTI.qG REPORT ~' - -,~""-:"."z ..... .'. ......... ' .~ · i ..... . .... ,{ ,, , . .... ......................... _ · ........ ........ .... .... - ~;: ~ " ' ' ...... . . w ~ =. _ , , ,t~t. ,_. ~ ......... . ,..- .. ,- ' ... ~ ...... . . . . ....... _ ......... .~ ..... · .... .. - ~ ..... · ' ,,~.t.. i ..... .'z~ '. -~ ~ ~ .~.... ::: ..,,,... ..__ ............ ~ ~ ..... .~ .... . . ~ "' ' ' ~' ~~,~.t~ ~ ,, ~ -~ -~.--.m, .... ~ ..... ~. . .lS.o_O .......... /. ¢oo ... ~ .... / ..y..._e_._o_ .... .~-.,- , ., ...... ...... Race (~) Pre-Flu&h Re~tp. Pipe PSI (max.) lto[to~ Plug: (~ No) Top Ylug: .... Total Pu~ped DIsp. / ~ .(bb!6) Int~t~ ~r!n~ Welgh~; ~ ~({.b~) Flual LandiI~{ Weight : Service Co,: ~//,'$~r~ Performance: ~ Fair, Poor) Date: ~/~/~ ............. Supervisor:, "' - ............ ~/d/'~/~;-~~. - ~No) Bumped Tol> Plug: FtoaCs Reld~ ~ No) Ceme~ Returns to Surfacer (Yes.~ ~1~ B~Lg SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 -)ILL ? ?992 Conoco, Inc 3201 "C" Street, Suite 200 Anchora$,e, AK 99503 Attention: Linda Starr ~SE RElY TO SCHLUMBERGER WELL SERVICES Pouch 340069 Prudhoe Bay, AK 99734-0069 ATTN: Bernie/Shelley Gentlemen: Enclosed ore 3 BLprints of the Company Conoco, Inc Well Milne Point Unit G-5 Field MJlne l~oint /Schrmd~r R]uff County North Slope Additiono[ prints ore being sent to: I BL prints Conoco, Inc 600 North Dairy Ashford - Houston, TX 77079 Attn: George Lamb, OF _2.018 PER . State A] a ska Perf Rec, Run 1, 7/24/92 1BL prints, 1RF Sepia Chevron U.S.A. lllll South Wi]crest Houston, TX 77099 ATTN: Michael QuJnn *(713/561-3§79) on: I BL prints Conoco, Inc 1000 South Pine Ponco Cit7,.OK 74603 Attn: Glenn Welch, 7360 RDW -, /Alaska Oil & Gas Conser~ration / Commi ssJon 3001 Por_cuoJne Drive ~Anchorag~,- AK 99501 ~tn: 3o{~n Boyle prmnts I BL prints, I RF Sepia OXY U.S.A. Inc 6 Desta Dr~ve= .qu~te 60fi2 ~. TK .... 2.9705_ Attn: John Carrn] *(gl 5/6_85-5898) prints prints The film is returned to Conoco, Linda Starr We appreciate the privilege of serving you. SWS-- 1327-F OH/CH (llBL/3RF) Received by: /~ ~__---~--,_ Date: KtttlVCU JUL 2 8 1992 Very truly yours, SCHLUMBERGEIilaWE01~ %@~v~;L~so°mmi~i°n An0 ora e Raymond N. DJckes DISTRICT MANAGER OR IGIN Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (9O7) 564-76O0 April 28, 1992 Mr. David Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Applications for Sundry Approval Dear Mr. Johnston, Attached are our Applications for Sundry Approval for Wells G-3 and G-5. Both these wells are located in Conoco's Milne Point Unit. Please direct any questions or concerns regarding these applications to the undersigned at 564-7660. SHEAR Specialist Att: cc: Chevron Occidental G-3 Well File G-5 Well File Field Operations Foreman (Wells) RECEIVED d U N - 1 3992 .Alaska Oil & Gas Cons. Cornrnisslo~ Anchorage STATE O'F ALASKA ALA,~ )IL AND GAS CONSERVATION COMM 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 . Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 Location of well at surface 3354' FNL, 3435' FEL, Sec. 27, T13N, RIOE, U.M. At top of productive interval 3400' FNL, 4700' FEL, Sec. 27, T13N, RIOE, U.M. At effective depth 5. Type of Well: Development ~ Exploratory __ Stratigraphic ~ Service. X N.S.B. AK At total depth 3365' FNL, 4920' FEL, Sec. 27, T13N, R10E, U.M. NSB AK 6. Datum elevation (DF or KB) KB 35' AGL NSB AK 7. Unit or Property name Milne Point Unit Well number G-5 9. Permit number 91-23 10. APl number 50-029-22138 11. Field/Pool Kuparuk River/Schrader Bluff feet 12. Present well condition summary Total depth: measured true vertical 4850' feet 4560' feet Plugs (measured) Bridge plug at 4610', cement retainer at 4570'. Effective depth: measured true vertical 4570' feet Junk (measured) 4304' feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length Size Cemented Measured depth 70' 13-3/8" Surface 105' 2405' 9-5/8" Surface 2440' 4155' 7" TOC @ + 3200' 4190' 800' 4-1/2" 4821' measured None true vertical True vertical depth 105' 2340' 3947' 4533' RECEIVED Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EuE, 4001' MD Packers and SSSV (type and measured depth) Otis PLS retrievable packer at 3952' ,.I U N - 1 ' 992 Alaska 0il & Gas Cons. Comrnissio~ Anchorage 13. Attachments Description summary of proposal Detailed operations program X BOP sketch 14. Estimated date for commencing operation June 8, 1992 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Service Water Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~J[~. ~o ~,"*~~. G. Augustine Title Sr. Production Engineer FOR COMMISSION USE ONLY Suspended Date 5/28/92 Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10--~'~- Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner Approval No. ~pproved Copy Returned Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Page 4 HILNE POINT UNIT G-5 PERFORAT!NG PROCEDURE NOTES: a) b) c) d) e) f) A safety/planning meeting shall be held at the beginning of this job to ensure good communical~ion between all parties on location. Depths referenced to Schlumberger Litho- Density/Gamma Ray log run on 5/7/91. Area Engineer should be on-site for perforating. Ensure that all permits required for work have been approved. This work should be charged to AFE No. 10-61-1377 "G-5: Completion/Surface Equip & Install." A wellbore schematic is attached. le 2, Commence injection into well and pressure up to 500 psi. Maintain this pressure throughout job. MIRU Schlumberger perforating unit with mast truck. RU lubricator and pressure test to 1500 psi. RIH with a 2.125" gauge ring to 4000' to ensure tubing and packer assembly are clear. POOH. NOTES: a) Ensure that all radios, telephones (rig and cellular) and any other radio wave sources within a 500' radius of the wellsite are turned off. Broadcast a warning over the field radio before starting the process of arming the guns. Place warning signs on the roads leading to and from the location. b) Strap and record the lengths and OD for all tools that are RIH. c) Record length from CCL measurement point to the top shot on all gun assemblies. d) The first gun should incorporate a GR/CCL sub to tie into the openhole GR. Gun runs after the first should be made with a CCL sub only. Page 5 M~LNE POINT UNIT G-5 e) Resistive blasting caps should be used for all wirel ine perforating (standard Schlumberger pol icy). me . . RIH with 2-1/8" Enerjet gun loaded with 6 SPF in 45° phasing':~-. Perforate the following intervals- Depth Feet Sand Shot Density 4288'-4305' 17 NB 6 4314'-4322' 8 NC 6 4338'-4366' 28 NE 6 4429'-4455' 26 OA 6 4504'-4528' 24 OB 6 NOTE: These perforation intervals have been revised from the original procedure. POOH with perforating gun and RD Schlumberger. Continue injection per the previously published Tract 14 Injection Startup Procedure. Notify AOGCC of the following: a) Completion of project (AOGCC Form 10-404). RECEIVED J UN - 1 1992 Alaska 0il & Gas Cons, CommissiOn Anchorag~ -:~' ,'~-", STATE OF ALASKA -'~ ~ " ALASKA ,LL AND GAS CONSERVATION C~, .,MISSION . WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well . OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [~ 'i ~ 2. Name of Operator '~. Permit Number Conoco Thc. *' .... " ~~ 91-23 3. Address ~/-.~-~i~,~,~ 8. APl Number 3201 'C' St., Suite 200, AnchoraAe, Alaska 99503 5o-029-22138 4. Location of well at surface -i'-; ~ ~,~ ~.,.~ _~ :~,.~,~,,~ 9. Unit or Lease Name 3354' FNL, 3435' FEL, SEC. 27 T13N, R10E, U-M, NSB ~ '~..':~.i:~t:~)~ ~ Milne Point Unit At Top Producing Interval ~ :.:.t:.~:.~. _ ,, 10. Well Number At Total Depth 11. Field and Pool 3365' FNL, 4920' FEL, SEC. 27~ T13N, RIOE, U-M, NSB 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. Kuparuk River/ KB 35' AGL! ADL-47434 Schrader Bluff 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115'Water Depth, if offshore 116' No' of Completions 5/1/91 5/9/91 1/19/92I N/A feetMSLI ONE 17. Total Depth (MD+TVD) 18,PlugBackDepth(MD+TVD) 19. Directional Survey 20. Depth whereSSSV set I 21. Thickness of Permafrost 4850' MD 4821' MD YES ~ NO [] N/A feet MDI 1800+- 22. Type Electric or Other Logs Run ...... DLL-MSFL-DDT-CNL-NGT (Gyro) RFT ('DA') RFT ('OB) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i13-318" 54.5 K-55 35' 115' 30" 600 sx Perm ¢'C'~ 9-5/8" 36.0 K-55 35' 2517' 12-1/4"650 sx Perm ('E')/30£ sx 'G' 7" 26.0 L-80 35' 4200' 8-1/2"200 sx 'G' 4-1/2" 12.6 L-Il0 4021' 4821' 6-1/8"122 sx 'G' 15.8 ppg 2z~. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8"6.5#EuF. 4000.96' 3951MD-OTIS "PLS" I~OI~I-E 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 4580' MD (PEP, F) 10 BBLS - 50 sx 'G' cement 4229' MD (PEP, F) 100 sx 'G' cement ,., 27. PRODUCTION TEST Date First Production / Method of Operation (Flowing, gas lift, etc.) S/I for Surface Modificat~ions Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ F'iowTubing Casing pressure CALCULATED .1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) 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 NONE M Alaska Oil & Anchorage Form 10-407 Sul ~n duplicate Rev. 7-1~80 CONTINUED ON REVERSE SIDE 29. 30. NAME Top of "N" Sands Top of "0" Sands GEOLOGIC MARKERS MEAS. DEPTH 4284' 4430' TRUE VERT. DEPTH 4040' 4176' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Well Schematic, Daily Well Activity Report 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~,v ~"2,"1~- .... Title SR. FOREMAN Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Milne Point G No. 5 - Drill & CASE API No.: 50-029-22138 Location: AFE Number: AFE Amount: Milne Point Field - SCHRADER BLUFF POOL 10-61-1376 Approved: 04/22/91 $1,113,000 gross Cost to Date~ $ 96,467 gross 04/28/91: PU Rig f/ L-8 at 0100 HRS 04-27-91. Install mud lines for new mud cleaners. Hauling gravel for G Pad expansion. 04/29/91: Finish gravel expansion of G pad. Install lines for new mud cleaners. 04/30/91: Finish installing mud cleaners. Release rig for mobilization at 0800 HRS 04-29-91. Moving rig and camp to G Pad. 05/01/91: Finish mobilizing rig f/ L Pad to G Pad. Mix spud mud. Spot pipe shed. Accept rig at 1800 hrs 04-30-91. 05/02/91: Fin rigging up & mixing mud. RU diverter. MU 12-1/4" bit & steerable BHA. Spud well at 0800 hrs 05/01/91. Drill f/ 105' to 1291' (13-3/8" conductor pre-set at 105'). KOP at 500'. 05/03/91: Drill f/ 1291'to 1503'. Short trip to BHA. Drill to 2461'. Circ. Short trip. C & C. POOH. LD BHA. RU E/L. Run BHGT caliper. RD E/L. 05/04/91: Rig up casing crew and run 57 joints of 9-5/8" casing. Make up hanger, landing joint and cementing head. Circulate 480 bbls. while reciprocating pipe. Pump 50 bbl water spacer followed by 360 bbls. Type "E" cement and 72 bbls. class "G" cement. Displaced with 5 bbls. water and 175 bbls. 9.4 ppg mud. Nipple up wellhead and BOPs and pressure test to 3,000 psig high 500 psig low. Installed wear bushing and cleared floor. Strap caliper and pick up BHA. 05/05/91: Pick up 8-1/2" BHA and RIH to float eequipment. Pressure test casing to 1,500 psig for 15 minutes. Drill float equipment and 10' of new formation. Perform LOT to 11.8 ppg EMW. Drill from 2471' to 3474' and short trip 10 stands. Drill from 3474' to 4200'. Circulate and condition hole to run 7" casing. 05/06/91: POOH lay down 5" drill pipe. Change top rams to 7". Rig up casing crew and hold pre-job safety meeting. Run 153 joints of 7" casing and land at 4190'. Cemented with 165 sacks class "G" cement and displaced with 150 bbls. 9.2 ppg mud. Installed 7" packoff and tested to 5,000 psig. Note sheared off 4 - 1" x 1/2" studs and left in the hole. Changed to 3-1/2" rams, installed wear bushing and picked up 3-1/2" BHA. 05/07/91: Pick up 3-1/2" drill pipe. Change rams from 7" to 3-1/2". Pick up 3-1/2" BHA with junk basket, DP, and 6" mill tooth bit. RIH and drill out float equipment. Displaced LSND mud with salt based system. POOH and layed down junk basket. Recovered one sheared off bolt. Layed down mill tooth bit and ran insert bit. RIH to 7" shoe, break circulation, changed shaker screens and drilled from 4210' to 4565'. 05/08/91: Drilling from 4,565' to 4,650'. Ran multi-shot gyro on rig wireline unit. Gyro was off 10 degrees from MWD and DWD surveys. Surveyors checked calculations and the survey was re- run. The error was traced to the orientation azimuth supplied to Sperry. Circulate and condition fluid for log run. POOH to log. Recovered 3 of 4 studs sheared off the 7" pack-off running tool. Ran DLL, MSFL, DDT, CNL, NGT. POOH and ran RFT. 05/09/91: Make conditioning trip. Attempt 2 additional RFT's. Recovered drilling fluid. RIH w/ bit. Drill f/ 4650' to 4810'. 05/10/91: Drill f/ 4810' to 4850'. C & C. POOH. LD BHA. RIH w/ 7" Bridge Plug. Set at 4050'. Test csg and plug to 1500 psi. Dump 5 sx sand on top. POOH to 2000' while LD DP. Disp 2000' of hole w/ 75 BBL diesel for freeze protection. POOH, LD DP. Clean out pits. ND BOP's. Install tbg hanger and tree. Test to 5000 psi. Released rig at 2230 hrs 05-09-91. Operations suspended while waiting on arrival of completion rig. Milne Point G No. 5 - COMPLETION API No.: 50-029-22138 Location: AFE Number: AFE Amount: Milne Point Field - SCHRADER BLUFF POOL 10-61-1377 Approved: 04/22/91 $885,000 gross Cost to Date: $ 125,779 gross 12/27/91: Set BPV in hanger. Graded pad around wellhead & started to move over location. Should be rigged up and ready to warm up rig by 0300. 12/28/91: Move rig over wellhead - Rig up equipment. Complete AOGCC recommendations on flowline flow analyzer. Raise derrick & build berm for frac tanks. Spot 500 frac tank for displacement fluid. ND wellhead. NU BOP's. Install 2-way check in hanger. Change ram rubbers to 4" for drill pipe. Work on auxilary mud pump. Unload 4" drill pipe in pipe shed. Unload 4-1/2" liner & misc. equip, for job from flatbeds. Unloaded 300 BBLS of 10.5 PPG salt saturated brine in volume pits. Loaded potable water & diesel where necessary. Initiate & set up for BOP test to 2500 PSI. Initial point was 2000 PSI and 80% of annular. Test ok. Install wear bushing (pull 2-way check). RU & pull tubing hanger set wear bushing in hanger and lock down. Send hanger out for redress & RP make-up. PU Halliburton 2' overshot in order to remove Model III bridge plug. RIH picking up 4", 14 lbs/ft, S-135 drill pipe. Rabbit & Talley all pipe (2.341 drift). 12/29/91: Continue to talley rabbit & PU 4" 14 LBS/FT drill pipe. RIH to circulate out sand & retrieve Halliburton III Bridge plug. Tagged sand at 4025' KB, 15' above bridge plug (131 JNT's of 4" drill pipe in hole). PU PD motor, bit, collars, x-over's & jars and set in pipe shed. Line-up solid control box to slop tank. Air filters on rig plugging up due to blowing snow. Clean filters. Circulate 10.5 pog saturated brine DN tubing & taking returns over solid control systems. Pump rate of 3.5 BBL/min with 200 PSI pump pressure. Pump a total of 181 BBLS while reciprocating through sand. Latched on to bridge plug & pump pressure increased to 250 PSI. Pump one full circulation down tubing on top of bridge plug taking returns at surface (original returns 10.2 PPG Brine). Total fluid volume of 351 BBLS circulated. Set on bridge plug & overshot w/15,000 lbs of weight. Pull up 2' & rotate to release. Bridge plug released. Rig down Kelly & RIH past previous tag. Holes clear. POOH bridge plug ( OD 5.75 - ID of 7" 6.276"). Fill hole every 18 stands. Lay DN overshot & Bridge plug. PU mud motor 4-3/4" w/ 5-7/8 stabilizer, 2 drill collars, bumper sub, 2 oil jars (4- 3/4") & associated x-overs RIH with 4" 14 LB/FT drill pipe. RU & pump 4.0 BBL/MIN rate with 350 PSI of pump pressure at surface. Motor working fine. Talley all pipe running in hole. Gather up equipment to hook-up power swivel. Building berm for aux mud pump. Empty slop tanks. Continue to run 4" drill pipe with mud motor & BHA. TIH with 134 Jnt's of 4" drill pipe & 101' BHA. Pickup 40' and circulate hole. Fluid pumped 10.2 PPG saturated salt. Circulated a total of 120 BBLS of 10.1 PPG saturated salt until clean returns at surface. No noticeable solids. Lift bowen power swivel to hook. RU power swivel & associated equipment. Problem with swivel makeup & skate. Hold pre-job safety meeting. RIH with mud motor BHA, 4" drill pipe with bowen power swivel at surface. RIH 1 JNT pick-up & rotate - circulate up hole while back reaming the open hole. PU weight 61,000 LBS. Slack-off 49,000 LBS at 7" casing shoe. RIH from 7" casing shoe 660' to 4850'. Total of 154 joint PWS 101.25' BHA. Circulate bottoms up at 100 strokes/min. Pump 25 BBLS HEC 3.5#/BBL pill for total volume of 270' BBLS on TD. Max pump pressure while reaming 1500 PSI at 3.2 BBLS/min (took solid returns and opened the solid control system). POOH - laying down 22 JNT's with power swivel, working pipe & rotating pipe each JNT. 12/3~/9~: Continue to POOH laying down JNT's with bowen power swivel. Lay down a total of 22 JNT's which is at 7" casing shoe (Circulate & rotate while back reaming). RIH PU JNT's with power swivel. Total of 22 JNT's. Total in hole 154 JNT's plus BHA (4850'). Circulate bottoms-up 110 BBLS. Mix pump dry pill in order to POOH with dry siding. Pump dry pill down drill pipe and spot in 7" casing. Had problems mixing with 10.1 ppg saturated salt; used 10 BBLS of 8.6 NACL as pill base. Pump 12 BBLS DN drill pipe & spot pill. POOH with mud motor, bumper sub, oil jars, drill collars & 4" drill pipe. Lay down tools. Rig up casing crew to run 4-1/2' liner. RIH with a brown type VW 12" float shoe on bottom of joint #1. a brown type 1" landing collar on the top joint #2. Run joint #3. RU 4-1/2" butt crossover to TRW valve. Break circulation. Volume pumped 10 BBLS. RIH with a total of 800.66' of 4-1/2" liner including liner hanger. Rig down casing crew. Rig up to run 4-1/2" drill pipe. O~/o~/gz: RIH with 800.66 FT of 4-1/2 liner on 108 JTS of 4-1/2 drill pipe to top of 7" shoe at 4190. Break circulation. Take all but two rig hands to BC for 1992 safety kick off meeting. Mud pump engine broke down. RU back up mud pump. Also, lost motor on shaker screen. Had to be replaced. Start into open hole with 4-1/2 liner. Pick up weight 61K down weight 41K. Make up cement head & kelley hose. Tag TD at 4846. Pull up 3' and start circulating 10.1 ppg sized salt brine at 2-3/4 BBLS/min at 350 PSI. Completed circulation of the 10.1 ppg sized salt brine. Total pumped 300 BBLS. Rig up Halliburton to cement liner. Pressure test lines to 4000 PSI. 01/02/92: Finally got off of liner by putting ± 20,000# on hanger and rotating to right. Circulate 200 BBLS of 10.1 PPG size salt brine to balance hole. Rig up & pump 175 BBLS of junk fluid down Arctic pack followed by 50 BBLS diesel for freeze protection. Put 850' of 2-7/8" EUE 8RD tubing in pipe shed. Change out pipe rams & repair tongs. Clean rig floor. Test BOP's to 2500k. Run wear bushing. All test ok. Make up BHA 6" bit 7"26# scraper set nominal, tally in hole with 4" drill pipe. Tag liner top at 4021.00. POOH. 01/03/92: POOH with 6" bit & 7" 26# scraper. Change elevators & slips to run 2-7/8" & tally same. Make up BHA 3-3/4 mill 4-1/2" scraper set 2' JT 2-7/8" EUE 8RD tubing. Start RIH. Stop 50' above liner & rig up power swivel. Run into liner 10' & brake circulation at 1-1/2 BBLS/min @ 200 PSI. Scraped cement stringers 120' into liner. Tagged top of cement @ 4665.74'. Pick up power swivel. Brake circulation & start to mill on cement @ 3 BBLS/min @ 750 PSI. Pick up 5' & shut down. Mud pump sprung leak. Start circulating. Lost hydraulic press to charge pumps. Start circulating. Lost hydraulic press again to charge pumps. We made 12' before pumps quit. Circulate bottoms up. Looked like we drilled through bridge. Pick up one joint & RIH and tag liner top with PBR polishing mill. Pick up 5' & circulate for 45 min. Set down on PBR. Torque on swivel 1400 pump press 650 @ 3 BBLS/min. Work mill back & forth through PBR for 20 minutes. Pull up 15' & circulate BU. Pull to top of liner to test lap. 01/04/92: Slip drill line. POOH with 11 stands. This put us 85' above liner top. Rig up to pressure test liner. Close pipe rams. Start pumping @ 1/2 BBL/min. Pump 1/2 BBL/min @ 500 PSI, pressure climbing still. Pumping 1/2 BBL/min pressure @ 700 PSI & still climbing & still pumping at 1/2 BBL/min. Hole started taking fluid @ 800 PSI. Shut down. POOH to PBR mill assembly. Checked brass lugs on no go. It showed that we milled to the top of the PBR. RIH with logging tools. POOH with logging tools. Short in tools, changed out CBT, start back in hole. Log from 4670 with CBT to top of liner (no cement). Break out tools & rig down Schlumberger. 01/05/92: Call out to Atlas wireline to set brige plug. Start in hole with 3.75" GR/JB - would not go into top of liner. POOH & change over to a 3.625" GR/JB. RIH to 4659.40' WLM. POOH. Make up firing head & wire line. Run bridge plug. RIH & set plug @ 4610'. POOH & lay down running tools. Make up 3-3/8" OD perforating gun loaded with 4 SPF, 22 GM charges in 90o phasing & GR/CCL sub RIH. (NOTE: Change in plans - POOH RD wireline unit). RIH with 694.81' 2-7/8" TB EUE & 3188.54 bottom of tubing & KB bottom of tubing 3884.05. Rig up Halliburton. Retest lap with rig pump. Pump @ 1/2 BBL/min. Walk press up to 800 PSI. Hold started taking fluid. Shut down. Rig up Halliburton to do lap squeeze. Start pumping @ 1-1/2 BBLS/min to establish formation breakdown @ 1400 PSI. Pumping 1-1/2 BBL/min. Pressure went from 1400 PSI to 1750 in 5 seconds & held for 10 minutes. Bleed pressure off. 01/06/9Z: Open pipe rams to see if we could get returns. Pump 2 BBLS/min @ 100 PSI. Started getting returns after 5 BBLS. Closed rams & started pumping 1 BBL/min. Pressure climbed to 1500 PSI in 20 seconds. Total BBLS pumped was 3/4 of a BBL. Held 1500 PSI for 2-1/2 hours. During the attempted squeezing of the lap, a total of 5 BBLS was pumped. Bleed off pressure & recovered 4- 1/2 BBLS. 01/06/92: RIH with 3-3/8" OD perforating gun loaded with 4 SPF, 22 GM charges in 90o phasing & GR/CCL sub. Stack out on something @ 4554 - 56" higher than the bridge plug @ 4610'. POOH to top of liner @ 4021'. RIH to 4507'. Stack out. POOH & lay down guns. RU & RIH with 3625 OD junk basket to 4577' work down to 4599'. POOH to 4150' & hung up. Work free & POOH. Break down junk basket & found sand. RIH with junk basket to 4600' free all the way. POOH RU & RIH with perf guns. Correlate logs & shoot. Bottom shot @ 4580' top shot @ 4229'. POOH & rig down. RU & RIH with 3625" OD junk basket to 4599'. POOH. Junk basket clean. RD junk basket. MU Halliburton cement retainer for 4-1/2" 12.6# casing. RIH, correlate logs & set retainer @ 4570'. POOH & rig down E-line unit. RU & RIH with stinger for cement retainer, 11 JTS 2-7/8" EUE 8RD. Start RIH with 4" drill pipe. Strand on drill line broke. Shut down & replace drilling line. End of tubing 110' above liner circulate 8.6 brine 12% methanol mix with 45 BBL. Gel pill ahead. Take 10.1 sized brine to junk pit. Very contaminated with solids & dropping out down hole. Also pumping fluid down arctic pack. Pump junk fluids down 9-5/8" x 7" annulus. Pull and replace drill line. High winds and blowing snow causing problems w/line installation. MIRU HB&R to heat brine and thaw out junk fluid tank. Pumped 632 BBLS junk brine, pills down annulus followed by 40 BBLS diesel. Clean pits. RIH with 4" DP, tagged several times. Circ 2 BPM/146 BBLS BTM's up & took some 10 ppg returns then cleaned up to 8.5 ppg. Continue to RIH, tagged @ 4435'MD. Cir 190 BBLS, found mud and trash in returns. RU tongs & rotate while setting down. Tag retainer. Space out. RU & circulate pill. Returned junk & sand. Circ BTM's up. Continue to circ. Sting into 4-1/2" Halliburton cement retainer @ 4570' with 13,000 lbs of weight. Pump 8.6 NACL & establish circ up to 3.5 BBLS/min @ 450 PSI. Sting out of retainer & circulate 120 BBLS BTM's - up. Hole is clean. Sting back into retainer. Pump 10 BBLS of Class G 15.8 ppg cement @ 3.0 BPM @ 300 PSI, displaced with 36 BBLS of 8.6 NACL. Had press increase from 300 to 700 PSI while spotting cement on back-side. Established good circ throughout squeeze. PU out of retainer. Pump 125 BBLS w/2.SBBLS/min @ 500 PSI until established clean 8.7 ppg returns. POOH w/4" DP & 2-7/8" EUE 6.5 lb/ft w/ Halliburton seal bore. PU 3-3/4" bit, 4-1/2" scraper, Baker polishing mill, 2-7/8" EUE tubing & 4" drill pipe. RIH after spacing out in order to clean 4-1/2" liner. Mill polish the hanger liner @ 4021'. Halliburton cement retainer set @ 4570'. Pump 250 BBLS of slop fluids (diesel 8.6 NACL, 10.1 brine) down 9-5/8" x 7". Displace with 50 BBLS diesel @ 500 PSI. 01/09/9Z: Finished pumping tank fluids down 9-5/8" x 7". Total to date on this AFE has been 837 BBLS (fluids) & 140 BBLS of diesel. Continue to RIH with bit scraper, XO, 8 STDS 2-7/8", 2-4' pups, 112' of 2-7/8", polishing mill (Baker) & 535 STDS of 4" drill pipe. Sat down several times RIH in the 4-1/2" liner. Collars may be hanging up. Finally set down @ 4438' , 4 STDS shy of hanger & packer. Set 10 to 15 M lbs several times with no luck. 132' of difference to Halliburton retainer. PU 7500 FT- LB power swivel. RU to RIH & wash cement. Tag fill or cement 4438' 122' above retainer. Pump 196 BBLS of NACL @ 3.2 BPM @ 300 P~I. Rotate @ 110 RPM @ 1500' lbs. Milled through 8' bridge. Returns look like fine formation sand with some cement. Continue to clean out 4-1/2" liner. Quite a bit of sand & shall amounts of cement. Sat down @ 4021'. Bit is 10' above retainer. Polished bore of hanger. Pull up 5' out of hanger & RU to circ. Pump 8.7 NACL @ 3.2 BBLS/min. Large quantity of sand in returns. Pump total of 260 BBLS & shut down pumps. PU bit & scraper to just above hanger @ 4021' to perform pressure test on 7" & 4-1/2". Press @ 100 PSI - 1.7 BBLS/min, 200 PSI - 2.0 BPM & 300 PSI - 2.8 BPM. 1/2 BPM would not build pressure (shut down pump - bled to zero PSI). RIH to top of retainer & circ 8.6 NACL. Circulate 140 BBLS of 8.6 NACL waiting on orders. POOH. Lay down mill & RIH after PU 1 stand of 2-7/8" EUE. RIH with 3-3/4" bit, 4-1/2" scraper & tag fill @ 4465'. Pump 33 BBLS of NACL 8.6 PPG with no returns. S/D due to leak in hydraulic hose; Repair main mud pump. Pumped 250 BBLS of 8.6 ppg down 9-5/8" x 7" annulus with 40 BBLS of diesel on top. RU to reverse circulation in liner 15' above last tag (4450'). Pump 10 BBLS @ 2.5 BBL/min with no returns 150 PSI. POOH up to 7" Baker liner hanger. PU 50' above liner & pump 20 BBLS down tubing (no returns). RU to reverse (pump 5 BBLS - no returns) Strapped volume pits, then confirm fluid was pumped down hole. Formation taking fluid. Offload 300 BBLS 8.6 NACL & 50 BBLS of diesel in pits. Clean pill tank to mix 50 BBLS 8.6 NACL & light salt pill in order to spot @ 4229' and establish a circulation for a fill clean-out below the perforations (10.1 filter cake apparently has worked out; causing formation to suddenly drink fluid). 01/10/92: RU to circulate; pump 33 BBLS NACL 8.6#/gal with no returns. Shut down due to hydraulic leak, process of repair on main mud pump. Pump 250 BBLS 8.6#/gal NACL down 9-5/8" x 7" annulus w/40 BBLS diesel on top. Load brine van with 200 BBLS 8.6# NACL. RIH w/3-3/4" bit & 4+ CSG SCRP, tag fill @ 4465'. RU to reverse circulate in 4+" liner 15' above last tag @ 4450'. Pump 10 BBLS @ 2+ BBLS/min w/no returns @ 150 PSI. POOH up to 7" Baker liner hanger, pu above liner & pump 20 BBLS down tubing w/no returns. RU to reverse circ 5 BBLS w/no returns. Strapped volume pits; they confirm fluid is pumped downhole, formation is taking fluid. Offload 300 BBLS 8.6# NACL & 50 BBLS diesel in pits. Clean pit tanks to mix 25 BBLS 8.6# NACL & light sal pill in order to spot @ 4229' & establish a circulation rate for a fill clean out below perforations (10.#/gal sat-salt cake apparently has washed out causing this well to suddenly drink fluid). Fluid level 200' below rig floor (indication on drillpipe). Mix 25 BBL lite-sal pill with 8.6 PPG NACL. Pump 52 BBLS to spot pill into perforations. Pressure built up to 500 PSI and bled to 350. Continue to pump pill into formation for 2.0 hrs. Still have 10 BBL pill in drill pipe to dispose of. Bleed pressure off annulus after opening annular preventer. Let set for another hour prior to establishing circulation. Clean pill tank with source H20 and send to slop tank. Slop tank has 3.5' of sand and associated solids on bottom. Have had sand returns in the area of 3 to 4 BBLS since last cement squeeze. Pumped 50 BBLS of junk fluid down arctic pak. Fill hole with .52 BBLS of 8.6 PPG brine, TIH 45 STDS. and tag fill @ 4480'. RU and reverse circulate trying to wash through sand bridge. Washed down 4 joints of pipe and 11' on #5. Wash down to 4570' and tag Halliburton cement retainer. RU to reverse circ 25 BBLS of HEC, 50 BBLS of dirt magnet and another 25 BBLS of 3.5#/BBL HEC and displace with 8.6 NACL. Pump a total of 470 BBLS while washing down on top of retainer. Lost a total of 12 BBLS of 8.6 NACL during total clean-out. Finished clean-out @ 0200. POOH with drill pipe laying down. Process of pumping all junk fluid down the 9-5/8" x 7" annulus. 01/ll/gz: Continue to POOH with 3-3/4" bit, 4-1/2" casing scraper, 2-7/8" EUE 6.5#/FT TBG., and 14#/FT/4" DP. Pumped a total of 385 BBLS of fluid down arctic pack last night with 40 BBLS of diesel on top. Total fluid pumped down 9-5/8" X 7" to date is 1472 BBLS of fluid and 220 BBLS of diesel. Switch ram rubbers to 2-7/8" from 4". AOGCC is here to complete the weekly BOP test. Pull wear bushing from hanger. Completed BOP test. Had to change #1 bottle of NTRGEN on accumulator. RU Schlumberger to RIH with 3-3/8" OD gun assemblys with 6 shts/ft. RIH to perforate in five different intervals with 130' of shts. Tagged fill @ 4410'. Unable to break through with 900 lb. tool string. POOH with 3-3/8" guns & CCL. RD E-line equipment. Switch ram rubbers from 2-7/8" to 4". Transfer 2-7/8" and 4" drill pipe back in the pipe shed. Process of cleaning slop tank of solids. Tested RMS, ok. Install wear bushing in hanger. Continue to transfer pipe and set up to RIH. TIH w/2-7/8" 6.5#/ft EUE tubing (700'), XO, to 4", 14#/ft. in order to attempt 20 BBL cement squeeze at liner hanger @ perfs. RIH w/remaining 4" DP to the bottom of the top perf's in 4-1/2" 12.6#/ft. liner. Perf's clear. TBG tail @ 4243'. POOH w/DP, spot tail @ 3982', RU w/Halliburton equipment. Complete 100 sack cement squeeze 39.4' from top of liner hanger. Pumped total of 69.5 BBLS on total squeeze, which includes fluid ahead, cement, spcer fld and 8.6 NACL. Total cement pumped 22 BBLS. Very little returns. 16 BBLS of fluid lost during the squeeze. Max pressure 400 PSI @ 4.5 BBL rate, displaced at 3 BBL/M rate @ 100 PSI. Class G 15.8 PPG cement used. Injection test indicated .320 BBL/min w/o PSI BU. RD hall. POOH w/4" DP and 696' of 2-7/8" TBG (3286' DP). Finish RD Halliburton and pump off cleaning fluids. Complete POOH w/4" DP & 2-7/8" TBG. RIH w/4" DP with 7" casing scraper & 6" bit. Stop 12 stands shy of cement squeeze (732'). Clean up rig, let cement set. Clean up rig and pad area around the rig. Pumped 370 BBLs of misc fluid down arctic pak and freeze protected w/50 BBLS of diesel. TIH w/4" DP, 7" scraper w/6" bit. Tag cement @ 3654'. PU swivel & RU to wash 'n rotate 7" clean. Wash down w/swivel 106' while circ @ 2.7 BBL/min rate. Taking cement returns surface. Total 8.6 NACL circulated 290 BBLS. Continue to mill out cement, plug is solid, 367' (14 BBLS) of cement in 7". 4- 1/2" liner capacity is 3.16 BBLS which leaves a 4.84 BBLS of cement behind top perfs. Total drilled out is 129' , down to 3783'. Continue to rotate & wash. 1/13/92: Continue to mill cement in 7" casing. Tagged at 4021'. A total of 130 Jnt'sof 4" DP. Cir a total of 1890 BBLS of 8.6 NACL @ 3.5 BBL/MIN rate. Cir BTMS up until clean fluid across solids control sys. POOH w/4" DP, 7" casing scraper, & 6" bit. Lay DN 22 Jnts of 4" DP, left 108 Jnts in derrick. TIH w/4" DP 14#/ft, w/22 Jnts of 2 7/8" EUE 6.5#/ft. Tag cement at 4021'. RU bowen swivel in order to mill out 4-1/2" liner DN to retainer at 4570'. Reverse cir. at 3.0 BBL/M at 150 PSI while rotate with swivel at 100 RPM'S. Cement is solid at 1st 100'. Pump 300 BBLS of fluid DN Arctic Pak and topped with 50 BBLS of diesel. Crew change, continue to drill out 4-1/2" liner, rev. cir. at 3 BBLS/M with good cement returns. We are at 4171', 59' from the top set of Perf's. ~/],4/92: Continue to mill through cement in 4-1/2" liner. Milled solid cement through Perf's, broke through cement and hit sand at 4252'. Washed and milled sand to 4410' and returns confirmed sand bridge. Circulated at 2.0 BBL/M rate W/250 PSI of pump pressure. Reverse circulate to mill and wash. Mill and wash to 4540' taking solid sand returns over the shaker at 2.5 BBL/M rate at 250 PSI. No fluid loss since we started the clean-out. Roughly 7 BBLS have gone through the desilter and into the slop tank. Wash to 4570' on top of Halliburton retainer. Reverse circulate BTMS up until returns are clean, 120 BBLS of 8.6 NACL. POOH W/4" DP into the 7" and pressure test to 300 PSI for 10 min. No leaks. Pump 330 BBLS of contaminated brine DN the 9-5/8" x 7" and pumped 50 BBLS of diesel on top. RIH and tag at 4570'. Mix 3.5#/BBL HEC and dirt magnet pills. 01/15/92: Mix up 50 BBLS of HEC 3.5#/BBL and 50 BBLS of dirt magnet. Reverse circ. @ 2.0 BBL/M and displace with clean 8.9 PPG @ 250 PSI pump pressure. Mixed pills w/source water. POOH laying down drill pipe & 2-7/8 tubing. Found tubing hanger line up pin stripped out. Will need to be replaced. PU & RIH with bridge plug and set @ 1260'ND BOP to repair stripped out line up pin and 7" spool if needed. Found threads in 7" spool pulled out well. Need to replace complete spool. 01/16/92: Rig up to bleed off pressure on Arctic pack to remove 7" damaged casing spool. Also, round up replacement equipment. Arctic pack would not bleed off. Start on plan B to drill out stripped line up pin to 1-1/4" NPT and install bull plug. Drill out stripped pin. Tap to 1-1/4" NPT and install bull plug NU and test BOP to 5000 PSI test ok. Try to pump down Arctic pack, but could not; froze up. Call out hot oil truck to pump methanol and hot diesel. Took them 4 hrs to get here due to weather conditions. Try to spot some methanol down Arctic pack, no luck. Rig up to circulate hot diesel down 7" and up tubing. Hold pre job safety meeting before starting job. Start pumping diesel at 0430 1 BBL Min 180 degrees. Pumped casing volume one time before end tower. Continue to circulate at 1260'. Shut down to move bridge plug. Set bridge plug at 2220'. Test bridge plug to 500 PSI. Break circulation pump at 1 BBL/min. at 180 degrees. Continue to circulate. Pick up rate to 1-1/2 BBL/min at 180 degrees. Returns are 30 to 40 degrees. Stop pumping. Last rate: 1-1/2 BBLS/min at 180 degrees. Move bridge plug from 2220' to 2600'. Test bridge plug to 500 PSI. Bottom of 9-5/8" shoe is 2440'. Temp on returns before shut down 60 to 80 degrees. At all times during the circulation of hot diesel down the 7", held from 900 to 1300 PSI on the Arctic pack. Started losing some pressure on the Arctic pack at 2100 hrs. at 1300 PSI. Would lose 100 PSI in 10 to 15 min. I don't know if this is temp loss or if we are moving some fluid down the Arctic pack. The pressure loss stayed the same for 2-1/2 hrs. prior to moving bridge plug. Bridge plug set at 2620'. Break circulation. Pump rate 1-1/2 BBLS at 180 degrees. Holding 1300 PSI on Arctic pack. Arctic pack is showing that it is losing very little pressure around 100 PSI in 15 min. Shut down for 45 min. to replace packing on vac truck. Start circulating at 1 BBL/min at 160 degrees. Continue circulating at 1/14 BBLS/min at 170 degrees. Continue to circulate diesel at 1-1/4 BPM at 175 PSI pressure on Arctic pack bled off 200 PSI in 45 min. Shut down and re- rig suction line to HBR hot oil truck to increase pump rate. Start circulating. Pump rate 2-1/2 BBLS min at 180 degrees. Return temp 120 degrees. Holding 1400 PSI on Arctic pack. Continue circulating pump rate 2-1/2 BBLS at 180 degrees. Return temp. 128 degrees. At 1130 hrs. we dropped 1500 PSI to 1425 on Arctic pack. Shut down and change over HBR to pump down Arctic pack. Rig up HBR to Arctic pack and pressure test to 3500 PSI. Start staging up pressure from 1500 PSI to 2800 PSI in increments of 200 PSI. From 2500 PSI to 2800 PSI pressure would bled off 100 PSI in 2-3 min. Rig down HBR. Rig up HBR to circulate down 2-7/8 tubing and take returns up 7" casing. Pump rate 2-1/2 BBLS/min at 180 degrees. It would take 2-1/2 BBLS of diesel to pressure up Arctic pack to 2800 PSI. This indicated to that the ice plug is below 1600'. By pumping down the tubing this gets 180 degree diesel at the ice plug with less heat loss. R/U EWS on 7" x 9-5/8" Annulus and pressure up to 2200 PSI. Continue to circulate W/HBR with no significant results. Shut down circ. R/D HBR from TBG and R/U on 7" CSG. Start circ at 2-1/2 BBLS min at 180 degrees. Return temp 127 degrees R/U EWS to hold 2500 PSI on Arctic pack. Stop circ with no significant results. R/D HBR. RIH to 1/19/92: 2620' and latch bridge plug. ring (OD = 5.90"). POOH using bridge plug as gauge Continue to POOH with bridge plug. Did not have any problems getting to surface with bridge plug. Re-pressure Arctic pack with HBR to 2800 PSI. Held. R/D HBR & release. Hold pre job safety meeting. P/U and RIH with the following: W/L re-entry Guide, Otis 'X' Profile Nipple, 1 JT 2-7/8' TBG, 7", 26# Otis 'PLS' packer and Otis Tubing seal divider on 123 JT of 2-7/8" EUE 8rd Tbg. Set Packer at 3951' OKB. Bottom of R.E.G. at 4008' OKB. Press test Packer to 1500 PSI for 15 min. Test ok. Space out Packer and start circ 8.6 brine with 5 gal of 3900 unitreat at 2-1/2 BBLS/min at 500 PSI followed by 75 BBLS of Methanol for freeze protection. Complete circ. Rig up & u-tub methanol from CSG to TBG. Pick up hanger and land TBG. Press up on 7" CSG. CSG would not hold press. POOH with TBG hanger and re-space out. RIH & land TBG. Hanger press test to 1500 PSI ok. Set BPV ND/BOP & NU Prod tree. Pull BPV and set two- way check. Press test tree to 5000 PSI. Rig down EWS and move to G-1. RECEIVED FEB 1 1992 Alaska Oil & 6as Cons. (;ommissio~ Anchorage CONOCO, II',IC. G-5 ALASKA COMPUTATION DA TE' 1/15 TRUE SUB-SEA NEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 0 .00 500 499.99 7OO 699.68 95O 947.46 1100 1094.10 1250 !23:8.34 1500 ~473.60 !60C! !566.48 i750 !70E.84 1900 184~.34 2050 1984.00 2200 2122.87 26O0 2489.88 3350 3176.!t 3450 3267.79 '" 35 ,,:;550 3 o 49 '-' 750 3543. o , 48 '2 ~° 50 S728.48 4200 396i .66 4300 4055.03 440C ~147.36 4500 4239.94 4600 4331.43 4700 4422.67 4800 45!3.90 4850 4559.52 SPERm-SUN DR~LLZNG SERVICES ANCHORAGE ALASKA THE /92 OR IG I Ill,-,l, l DATE OF SURVEY': 05/'07/'91 BOSS GYROSCOPIC SURVEY JOB NUHBER: AK-LB-lO048 KELLY BUSHING ELEV. = 56.00 OPERATOR- SPERRY-SUN FT. COURS COURSE DLS iNCLN DIRECTION DG HN DEGREES DG/IO0 TOTAL RECTANGULAR COORD~NA}ES VERT. NORTH/SOUTH EAST/WEST SECT. -56.00 443.99 643.68 891.46 1038.10 0 0 N .00 E .00 0 30 S 12.10 E .10 5 25 S 58.00 W 2.64 9 40 S 64.00 W 1.73 14 30 S 70.10 X 3.33 .OON .OOE .00 2.133 .46E -.44 8.003 7,38W 7.~3 23.463 36.27W 36.44 35.393 65.27W 65.53 1182.34 17 i9 S 74.20 id 2.03 1417.60 22 10 S 81.40 W 2.i6 1510.48 21 !~ S 81.90 \~ .86 1649.84 22 ~ S 82.90 W 56 1788.84 22 4 S 87.70 W 1.20 47. 863 10Z_, , 44W 104.78 6E . 073 i 66.96W 18'7 . 43 70.453 223.62W 224. 13 77.783 ,-°73.51W 27°~.. 17 -- P, 2 403 3,34 ,' 6\4 '-'35 ":'~: I~28.00 91 45 N 88."' . ~. ~ 90 W 8,7 2066.87 22 40 N 87.50 W .71 2433.88 2~ 10 N 85.50 ~ .42 3120. ~1, ,:~o~, ~o5 N 84.90 W 11 4,211.79 °3 40 N 86 40 W 65 82.993 390.71W 391.2i 81.20S 447.38W 447.96 71.413 606.03W 606.53 46.123 907.55W 907.87 43.093 947.'38~ 947.67 3303.49 23 19 N 84.60 W .79 3487.48 22 49 N 85.60 ~ .32 3672.43 21 49 N 85.30 W .50 3905.66 20 ~5 iq 86.10 W .58 3999.09 2~ !9 N 86.00 W .91 39.973 987.t3W 987.40 33.263 !065.'24W 1065.46 27.243 1140.99W 1141.16 20.463 i2'SO.~.SW 1:23,"J.94 18.0iS 1256.27W 1266.47 4091.86 22 SO N 86.60 W !.19 41 ,o.,. co ~ N 87.2C' W a~ 8~ q4 '~ o~ .~ z75.43 24 10 N 8,9 20 W 1 10 4366.67 24 !0 N 89.20 W .00 4457.90 2A 10 N 89.20 W .00 15.613 !302.~2W '30' . ": !S.503 1342.57\"! IS42.(-3 12 2'° 13P2 8av,~ I~,_2 '}4 11 .673 1423.83W 1423.37 11 .103 1464.77',"/ 1464.31 4503.52 24 10 N 89.20 W .00 10.813 ~48E..2~W 1435.23 CALCULATION PROCEDURES ARE BASED ON THE USE OF HINZHUH CURVATURE HETHOD. HC:RiZONTAL DiSPLACENENT - 1485.28 F'-ET AT, ,_,~,,.,,cr~! ~TM,,, 89 ~nEG . 24 .Mik', ,., . WEST ,/"T ',..'ERTi c',,~ L~ , ¢ SCTTi~!N~_.. ,.~, R~:i .... ATi'./E,, Tr',, ,_, WELL HEAD '~' ON . . VERTICS, L SE',.,,~: COHPUTED ALONG 269 53 DEG SPEP.~-SUN DRZLLZNG SERVZCES ANCHORAGE ALASKA PAGE CONOCO, INC. G-5 ALASKA COMPUTATZON DATE: 1/15/92 DATE OF SURVEY: 05/07/91 JOB NUHBER: AK-LB-lO048 KELLY BUSHZNG ELEV. : 56.00 OPERATOR: SPERRY-SUN ZNTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTZCAL VERTZCAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDZNATES MD-TVD VERTZCAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -56.00 .00 N .00 E .00 1000 996.63 940.63 27.24 S 44.53 W 3.37 3.37 2000 1937.56 1881.56 83.35 S 372.19 W 62.44 59.07 3000 2854.95 2798.95 58.48 S 768.99 W 145.05 82.61 4000 3774.89 3718.89 25.72 S 1159.52 W 225.11 80.05 4850 4559.52 4508.52 10.8t S 1485.24 W 290.48 05.38 THE CALCULATZON PROCEDURES ARE BASED ON THE USE OF MINIMUM CURVATURE METHOD. FT. SPER,,,_~.~Y-SUN DR]'LLING SERVICES ANCHORAGE ALASKA PAGE CONOCO, iNC. G-5 ALASKA COMPUTATION DATE' t/15/92 DATE OF SURVEY' 05/07/91 JOB NUHBER' AK-LB-lO048 KELLY BUSHING ELEV. - OPERATOR- SPERRY-SUN 56.00 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA HEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -56.0O 56 56.O0 .00 156 156.00 100.00 256 256.00 200.00 356 356.00 300.00 .O0 N .00 E .00 .00 N .uu b .00 .00 .00 N .00 E .00 .00 .07 S .01 E .00 .00 .90 S .i9 E .00 .00 456 456.00 400.00 556 556.00 500.00 656 656.00 600.00 756 756.00 700.00 857 856.00 SO0.O0 1.76 S .Sa E .01 .00 2.94 S .10 td .02 .01 6.01 S 4.27 \¢ .16 .14 10.98 S !2.3E' ~ .62 .46 17.O5 S 28.51 b., i.43 .81 958 956.00 900.00 1060 1056.00 1000.00 1164 t156.00 1100.00 1268 1256.00 1200.00 1374 1356.O0 t300.OO '24.11 S 37.61 W 2.66 1.24 32.10 S 56.47 W 4.76 2.09 40.79 S 8.1.6-8 id 8.12 3.36 49.34 S 109.82 W 12.52 4.40 57.17 S 142.71 ~ 18.09 5.57 !481 1456. O0 ! 400. O0 1588 i 556. O0 ! 500. O0 1696 1656. O0 i 600. O0 i 804 i 756.00 i 700. O0 1912 i 856. O0 ! 8,30. O0 63 98 69.88 S 2!9.:57 :,,i 32.75 7.73 75 2,9 S 2r-:~- S0.30 S 298.':: ,62.58 S 2019 1956.00 t900.OO 2127 2056.00 2000.00 2235 2156.00 2100.O0 2344 2256.00 '2200.00 2453 2356.00 2300.00 8° °1 S ~,¢¢'~ ~,~ W 68 8~ 7 ~1 82 ~q c 419 ~ ~' 'W 71 ¢;6 7 70 80.60 S 461.20 W 79.91 8.35 78 78 c 5o2 c': i,, 8~. 'P~ ~ 37 76 13 S 54~ i:'W q7 '~5 & q7 2562 2456.00 2~00.00 2672 2556.00 2500.00 £782 2656.00 2600.00 2891 2756.00 2700.00 2C)0! 2856.00 2800.00 72.61 S 590.~T \*¢ 106.86 9.61 69 09 c ~5 ~ W 11~ ' . ~ ~ ..... ~7 9.61 65.56 S e.¥0.~5 '.~ ~26.0~ 9.51 62.04 S 725.{'9 ~',' !3'.E9 9.6t 58.44 ~ 753.::~ :.,: 145,.i¢; 9.46 ,?.i ~'0 235, E,.00 2'300.00 3217 ,3F · 2;328 3156 .00 2,100.00 ..... '-' v = 6. O0 3200. 00 254Fa ~. 356 . O0 3300. (J;O 50.74 S 85L5.-3 '~4 16,:,,. i0 ,3.98 46.89 S 89.?.5.8 '~,,~ 172.08, 8.98 43.,;i ,_;c 9-'2.23 ';,,~ 1>:'i . 1'-' q~.05 40.1t S 935.55 5: 190.20 9.07 SPEEg~-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE CONOCO, iNC. G-5 ALASKA COMPUTATION DATE' 1/15/92 DATE OF SURVE'Y" 05/07/91 JOB NUMBER' AK-LB-lOC48 KELLY BUSHING ELEV. - 56.00 OPERATOR' SPERRY-SUN FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL HEASD VERTICAL VERTICAL RECTANGULAR COORDINATES HD-TV DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DZFFERENC D VERTICAL E CORRECTION 3655 3456.00 3400.00 36.11 S 1028.50 W 199.0 3763 3556.00 3500.00 32.86 S 1070.50 W 207.5 3871 3656.00 3600.00 29.6'2 S 1112.05 W 215.9 3979 3756.00 3700.00 26.34 S 1151.98 W 223.6 4087 3856.00 3800.00 23.14 S 1191.58 W 231.2 8.88 8,.51 8.34 7 7~'' 7.61 419'3 3956.00 3900.00 20.6t S 12'28.72 W 237.96 4300 4056.00 4000.00 !7.9:6 S 1266.73 W 244.97 4408 4!56.00 4100.00 15.41 S !306.98 W 252.5',1 4517 4256.00 4200.00 13.t6 S 1349.5'2 W 261.51 4626 4356.00 4300.00 12.09 S 1393.91W 270.93 6.74 7 . 01 7 .,~,4 S.70 . ,," 4736 4456.00 4400.00 4850 4559.5'2 4503.52 i.46 S i438.78 W 280.54 0.81 S 1485.24 W 290.48 9.61 9.95 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT HD FROM RADIUS OF CURVATURE) POINTS SPERRY-SUN DRZLLZNG SERVZCES ALASKA 05/07/91 dEASURED ANGLE DIRECTION DEPTH DEG DEG VERTZCAL DEPTH LATZTUDE FEET DEPARTURE VERTZCAL DOG FEET SECTZON LEG 0.00 0.00 0.00 0.00 100.O0 0.i0 167.90 t00.00 200.00 0.20 167.90 200.00 300.00 0.30 167.90 300.00 400.00 0.40 167.90 400.00 0.O0 0.09 S 0.34 S 0.77 S 1.37 S 0.00 O.00 0.00 0.02 E -0.02 0.10 0.07 E -0.07 0.10 0.16 E -0.16 0.10 0.29 E -0.28 0.10 500.00 0.50 167.90 499 600.00 2.81 233.19 599 700.00 5.42 238.00 699 800.00 7.11 241.26 799 900.00 8.81 243.26 898 .99 .95 .68 .08 .12 4 8 13 19 .13 .03 .00 .48 .90 0.46 E -0.4-4 0. 10 1 .41 'W 1 .44 2.64 7.38 ~,',~ 7.43 2.6,3 16.81 l.',/' 16.9i 1 .73 29.08 W 29.22 1 .73 1000.00 11.26 246.6I 1100.00 14.50 250.10 1200.00 !6.38 252.99 1300.00 18.27 255.93 1400.00 20.20 258.92 ~96 6~ 1094.10 1190.49 lO85 9~ !380.36 27 35 43 51 58 .24 .39 .77 .80 .93 44 52: W' 4'4- 72. 65.27 'vi 65.53 5.3:3 90.53 'v,,' 30.34- 2.03 119.20 ,',,' ' 1'::.53 2. 1Et .36 i,,.' 15i .78 2. 16 1500.00 '22.17 261.40 !600.00 21.33 261.90 1700.00 21.83 262.57 tS00.00 22.06 264.50 1900.0a 22.08 '267.70 1473.60 1566.48 1659.47 1752.13 1844.$6 65 7O 75 79 82 .O7 .45 .42 .84 .40 186.96 W' 187.43 2.i6 223.63 W 224.13 0.86 260.07, ~ ~'~60.61 0.56 297.28 W 297.86 0.76 334.76 W c,~u.3~ ~.20 20C0.00 2i.85 269.96 zlO0.O0 °0.06 °71.58 2200.00 22.6? 272.50 2300.00 23.C4 273.02 2400.00 23.42 273.53 1937.60 2030.42 2!22.89 2215.04 2306.94 83.i7 82.56 81 .20 79.33 372.15 W S79~.7¢,¢ 0.87 409.37 W 409.')t~ 0.64 447.39 ¢./ ..:~7.3": C.71 486.18 5o~ 5~ \~' 5°6 ' ! (.' 42 2500.00 23.79 274.02 2600.00 24.17 27~.50 2700.00 24.07 274.58 2800.00 23.97 274.66 2900.00 22.87 274.74 2398 2489 2581 267°~ 2763 .94 .21 .55 .96 74 71 68 64 61 .43 .41 .18 .90 .58 ~:65 52 ','.i ": ',:}'3 '}-:-:" "' "- 606.05 V', 606.5,5 0.42 646.723 'w 647.':6 O. ~0 687.36 \',/ 687.8'~ O. 11 727.77 ;,',/ 728.20 0. ! 1 3000.06, 23.77 274.82 3100.00 23.67 274.90 3200.00 23.57 274.98 3300.00 23.4.7 275.06 3400.00 22.54 274.35 2855 2946 3038 S222 .44 .99 .6t .3! . 58 54 51 47 44 .22 .82 07 .88 .4'S 768.01 W 768.'42 0.11 808.09 e¢ 808.47 848.01 W ~;48.36 0.11 ~87 7~ " o.?..? 927 44 027 . ..' . ...... 3500.00 23. 50 274-. 49 3313 "'~:.r,c, n,-, 23 2::2' 275: i 5 34C 3700.00 22.9 f- '27 a. 65 2497 · 3or, r: OC, 22 R:E 074 47 358q 3900 . O0 Z2 . 08 274 . 62 3682 .68 .50 .49 .68, .18 c, 8. 15 .Z,:' . 80 31.77 ©O 7~ 9%7.36 ',,i )67.t4- C.']T 1006.8.3 ,'.,' ! ',-,'07. 08 C:. 39 1084.~1 ,4 1084. 72 O. 1122.39 W 1i22. .., SP~E.~RY-SUN DRILLING SERVICES ~EASURED DEPTH 4000.00 4100.00 4200.00 4300.00 4400.00 4500.00 4600.00 4700.00 4800.00 4850.00 ANGLE DIRECTION VERTICAL LATITUDE DEG DEG DEPTH FEET 21.55 274.55 3775.01 25.75 S 20.98 274.23 3868.20 22.97 S 20.42 273.90 3961.75 20.46 S 21.33 274.00 4055.18 18.01 S 22.50 273.40 4147.95 15.60 S 23.42 272.80 4240.03 13.50 S 24.17 270.80 433t.53 12.24 S 24.17 270.80 4422.76 11.67 S 24.17 270.80 4514.00 11.10 S 24.17 270.80 4559.62 10.81 S DEPARTURE FEET 1159.44 1195.60 1230.86 1266.41 1303.65 12,42.60 W 1382.93 W 1464.81W 1485.28 W ALASKA 05/07/9! VERTICAL DOG SECTION LEG 1159.59 0.53 1195.74 0.58 1230.98 0.58 1266.51 0.91 1303.73 1.19 !342.67 0.95 1382.98 1.10 1423.91 0.00 1464.85 0.00 !485.32 C:.O0 THE DOGLEG SEVER.T_TY IS IN DEGREES PER 100.00 FEET THE VERTT~CAL SECTION WAS COMPUTED ALONG 269.58;~ (~,RUE' BASED UPON MINIMUM CURVATURE TYPE CALCULATIONS. THE BOTTOM HOLE DISPLACEMENT IS 148~:- °2 FEET iN THE DIRECTION r';F 2&9 E, 8,.." (TRUE~ RECEIVED FEB 1 ,~ 1992 Alaska Oil & 6as Cons. Commissi~m Anchorage COUNTY CASING I,.INE R ~--"-11' '~'' '" . · : : : ~- : . . .:-.~. . ~..~..~. ,.~..~ . ~ : . . ... ~ ....... ~ .... ~ . : .... : . .... .. . ~ ~ . . ,. ~ ... ~ . ~ . ~ .... :. ...... ;..~ ........ . ~ .: ............... ~ ..... ... , ....... L~.~. ... ~ ~.~ ..,. ;. . : . : , . :: . .... ,. .... . . . . . , : · : ' · : ' ' ~t---~.,: ........ ; ; ...... : : .. .... . _ } . . ,~...: . ..~ . ~.~. , ~ ~ ....... .... -I JSt o,,s INSTALLATION ~- i LLL~ SIZE DEPTH WEIGHT GRAOZ:. THREAD TYPE COMPLETION FLUID IN GRAOE o P~'~A TOR'$ NAME GRADE THREAD OTI~ DESCRIPTION / / WELL No. G-5 CASING SKETCH MR, NE pOINT ~ ,(I) A~I No.: 50--029--22138 P~RM[T No.: 91-23 0ruLeD: 5/9/~'~ ARCTIC PACKED: 3P[RATOR: CONOCO 1NC. SURFACF. LOCATION: 3354' FNL, 3~35' FT.L, SEC. 27, T13N, R10E, U.kL ~=OTTOI~ HOLE, LOCATION: ~uD DAT~ ___.~,,~,--- ,~C CSG SPOOL. ' i' ..:I · ,;:', "' 13 5/8', 54.5#. K-55. WELD SET · 105' .:'~'.' :.:v:" CEULq~T DATA: 425 SKS ARCTIC SET I .',:... 7s ~.~s ~.'! . '.': 80 BBL$ ~' ,..4.':.: ""; '~:J Jlo.5 PPG ', ";.i:;..;-., SALT EST TOC · 3200' 9 5/8', 36f, K-55, BTRC, SET ~' 2440' CEMENT DATA: 360 IBG. LS (1000 SKS 72 BELLS (350 SKS] 15.8 PPG w/ 0.2% CFR-3 & CaCl~ HALLIBURTON tit RBP ~ ~,050' W/ 5 SKS 2.0/40 SAND ON RBP CEMENT DATA: ~, BtBL$ (18-5 O~[N HO~ FEB 1 3 t99~ Alaska Oil & G~s ~ ~o' Anchorage I APPRO~D BY: HDS OA~: 10/29/91 CONOCO Inc. DEAE~D BY: SJN CAD ~ GPBO_OlO AN~OR~GE DI~SION cl~ec!~ oH or list data as it is received.'~list received date for 407'. if not reejuired list as NR .... ~07 ~ * 3.,//.~./~,.~ drillinQ histo~ I ~ ~.~.vl/I ~., tests ~1 ~or. descriptio~A ] ,c,0~ed int~ais core anal?sis !~ d~ ditch inte~ais digital data ............ ~ ~t o ~ ' ......... ~X ~ ~ o~ ........... I', ' I,,, " " ,, il i ~.O= , , r-- RUP~' INTER~TALS SCALE ... NO. . [to.the nearest footI [inchll00'1 I ~ ~ ~~ ,, / ,, //;- ~ , ¢~ ,, ~ ,, , ~ ~CI~ ~ ~> /, ¢/~o ~, F~/~ , , ~., , ~ , ~ ,,~ ,. I~l .......... ' ~" i"8! .............. TO: THRU: MEMORAhL UM State of Alaska .AL.~SKi OIL AN0 GAs CONS~RYAT~ON COm~SS~'ON Lonnie C, Smi~C~ Commiss ioner DATE: FILE NO: TELEPHONE NO: Blair Wondzell ~/~3 SUBJECT: Sr. Petroleum Engineer Jan 14, 1992 DA. 114.4 BOPE Test Conoco MPU G-5 Permit No. 91-23 Kuparuk Rv. Field FROM: Doug Amos Petroleum Inspector Saturda Ja_~n ~!!~_ !992__i: I traveled this date from AAI's KRU CPF # 1 to Conoco's MPU G-5 well to witness the BOP test on EWS Rig No, 4. The testing commenced at 8:00 am and was concluded at 9:45 am. As the attached AOGCC BOPE Inspection report indicates there was one non compliance item found. The nitrogen bottle was replace~while I was on the location. In summary, I witnessed the BOPE Test at Conoco's MPU G-5 well on EWS Rig No, 4. The single non compliance item found during the test was corrected before I departed the location. Attachment. 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 OPERATION: Dr lg,__ Wkvr l~ Operator , , ,,, .... Location, Sec E'7 T,/.~A! R /DE Orlg oontrotr ,, E~,~ Location (general) , ~ Housekeeping {general) ~ Reserve pit , , ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report Well sign Rig, MUD SYSTEMS: Visual Audio Trip bank v/ Pit gauge ...... Flow monitor V/ Gas detectors Rig# TEST: Initial__ Weekly /.~ Other Permit ~ ~t'~ ACCUMULATOR SYSTEM: ft Full charge pressure ~~2~r~ psfg Press after closure l~t~7~ pstg Pump tncr clos press 200 psfg ~_~ mtn /5 sec Full charge press attained / mtn ~ sec Controls:'Master Remote KELLY AND FLOOR SAFETY VALVES: Upper Kelly ~ Test pressure BOPE STACX: Test Pressure Lower Kelly ~ Test pressure An~ular preventer,,,.,,~/, [~,,~,~0 Ball type _ / Test pressure Pipe rams ~_ 'j ~(~ Inside BOP / Test pressure Blfnd.rams L-)/ / I! Choke manifold / ~est pressure Choke 1 ~k~ ~ valves ~ /' Number valves _ ~ HCR valve ~/' ,~,-~,' J I! Number flanges Kill line valves ~ ~_ ~/ Adjustable chokes Check valve ~ Hydraulically operated choke., l! TEST RESULTS: Failures / Test time i '~ hrs Repair or replacement of failed equipment to be made within days. Notify the Inspector~ and follow with written/FAXed verification to Commission office. Remarks: Distribution: orig'- AOGCC c - Operator c - Supervisor C.OOq (rev 05/10/90) WITNESS SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 JAN ~ 7 ~g~2 Conoco, Inc 3201 "C" Street, Suite 200 Anchorase, AK 99503 Attention: Linda Start ~SE RElY TO SCHLUMBERGER WELLSERVICE$ Pouch 340069 Prudhoe Bay, AK 99734-0069 ATTN: Bernie/Shelley Gentlemen: Enclosed ore ~BLp. rints of the Compony Conoco, Inc USIT/CBT, Run 1, 1/5/92 on: Well Milne Point Unit G-5 Field. l~_lne POint Additionol prints ore being sent to: I BL prints Conoco, Inc 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb, OF 2018 PER County North Slope Stote, Alaska 1BL prints, I RF Sepia Chevron U.$,A, 11111 South Wi]crest Houston, TX 77099 ATTN: Michael QuJnn *(713/561-3673) I BL prints Conoco, Inc 1000 South Pine Ponco City, OK 7460--3 Attn: Glenn Welch, 7360-RDW ~Jon / "_ Commission_ prints _l_~b__prints, I RF Sepia OXY U.S.A. Inc 6 DeRta Drive= R.Jt~ 6002 MJ dlanc[~_ 792_05 Attn: .]ohn Carrnl *(cji ~/6R_ 5-58q8) prints prints The film is returned to Conoco, Linda Starr We oppreciote the privilege of serving you. $W$-- 132 OH/CH (I1BL/3RF) Received by: _~L~ ~' Date: r~r-~Cl V EIJ JAN !0 1992 VeF¥ tFU)¥ ¥OUFq,, ......... I ommlsslon SCH LU M BE RG L~~_~L~§~L~: ' . ~ncnorage Raymond N. DJckes DISTRICT MANAGER STATE OF ALASKA AL, ._.,<A OIL AND GAS CONSERVATION COM .... .,SION APPLI'CATTO# FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing Repair well Change approved program Operation shutdown__ Re-enter suspended well X Plugging __ Time extention __ Stimulate ~ Pull tubing __ Variance Perforate X Other Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 Location of well at surface 3407' FNL, 3377' FEL, Sec. 27, T13N, R10E, U.M. At top of productive interval 3488' FNL, 4634' FEL, Sec. 27, T13N, R10E, U.M. At effective depth 3488' FNL, 4613' FEL, Sec. 27, T13N, R10E, U.M. At total depth 5. Type of Well: Development Exploratory Stratigraphic Service N.S.B. AK NSB AK NSB AK 6. Datum elevation (DF or KB) KB 36' AGL 7. Unit or Property name Milne Point Unit 8. Well number G-5 9. Permit number 91-23 10. APl number 50-029-22138 11. Field/Pool Kuparuk River/Schrader Bluff feet 12. Present well condition summary Total depth: measured true vertical 4850' feet 4557' (est.) feet Plugs (measured) Retrievable bridge plug set at 4050'. Effective depth: measured 4850' feet Junk (measured) true vertical 4557' (estimated) feet None Length 69' 2404' 4154' measured None Size 13-3/8" 9-5/8" 7" true vertical None Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Cemented Measured depth True vertical depth Surface 105' Surface 2440' TOC@_+3200' 4190' 105' 2340' 3947' RECEIVED DEC 1 9 1991, Alaska Oil & Gas Cons. Comrnissio~ Anchorage 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation December 30, 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Service / 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Suspended _ Signed/f~v3u¢.~.~ ~ G. Augustine Title FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity B(~, Test Location clearance ._~ Mechanical Integrity Test _ , Subsequent form required 10- ~ _ Approved by order of the Commission ORiGiNAL $!GNED BY LONNIE C. SMITH Commissioner Form 10-403 Rev 06/1,5/88 Sr. Production Enqineer Date I Approval No. .,.pr-m/e-'-.1 CoPY '/~/ -- '~'-'"- p, eturr~ed . / SUBMIT IN TRIPLICATE MILNE POINT UNIT G-5 COMPLETE AS INJECTOR SUMMARY PROCEDURE 1. MIRU EWS #4 rig. 2. ND production tree. NU and test BOPE. 3. RIH with retrieving tool and engage bridge plug at 4050'. POOH with BP and lay down. 4. RIH with bit, drill collars, motor, and MWD on drill pipe to 4850' (TD). Wash and ream openhole section as necessary. 5. RIH with 4-1/2" liner with float collar and shoe on drill pipe. Cement with 250 sacks of Class 'G' cement. Reverse cement out. Set liner packer at 4050'. POOH with drill pipe. 6. RIH with bit and scraper to PBTD. pressure test casing to 1500 psi. Reverse circulate hole and pump cleanup pills. POOH. 7. MIRU electric line unit. RIH with cement evaluation log and POOH. RIH with continuous gyro and POOH. 8. RIH with wireline perforating guns. Perforate the following intervals with 5 SPF: 4284'-4304', 4314'-4322', 4338'-4378', 4430'-4466', and 4504'-4530'. POOH with guns. 9. RIH with packer on tubing. 10. Space out tubing. Circulate in packer fluid. Set packer. Land tubing hanger. Pressure test hanger to 5000 psi. Pressure test casing-tubing annulus to 1500 psi. 11. ND BOPE and NU production tree. RDMO rig. 12. Prepare well for injection. BGA- 12/17/91 RECEIVED D £ O 1 9 Alaska Oil & Gas Anchorage i-' GEORGE'S COURIER SERVICE 344-3323 COMPANY LOCATION ATTENTION WELL NAME · .~, - -- NO. OF BOXES' ~.~ JOB NO. · ~' -- ADD'L TAPES WELL NAME · -- SERVICES . -- NO. OF BOXES: JOB NO. . ADD'L TAPES WELL NAME SERVICES FROM ADDRESS CITY STATE ZIP SHIPPER / '/ '-~ '/-'-' - TIME ADDRE88 CITY STATE ZIP ATTENTION PHONE INSTRUCTIONS Ataska 0ii & Gas Cons. ¢~mmi~sip~ Anohorage [~/24 HOUR CASE NO. COURT DOCUMENTS SAME DAY [] P/U BY 3PM ONE HOUR $ SAME DAY $ 24 HOUR $ OTHER $ TOTAL $ [] ONE HOUR X I RECEIVED BY I DATE / / I TIME SERVICES · lNG CENTER iNTER (ELI:: l-U JUN I 3 1991 ',ii & Gas Cons. Commission NO. OF BOXES' JOB NO. · ADD'L TAPES · NO. OF BOXES' JOB NO. · ADD'L TAPES · SCHLUMBERGER COURIER: DATE DELIVERED: RECEIVED BY: SCHLUMBERGER WELL SERVICES A aIVISION ~ ~4~;HLUMff~:RGEI~ 'r~CHNOLOGY C~~A~ ~ST~ ~S 77251-2175 MAY 1 5 1991 ~~,~~ ~oucb 3~00~9 ~udhoe ~a~ ~ 9973~-0069 Attn: Be~nie/Shelley CONOCO, Inc. _ 3201 'C" Streets Suite 200 Anchorage, AK 99503 Attention: Van Lineberger { / / / / Gentlemen: DLL/MSFL, NGT, Raw Data, Porosity, Cyberlook, Enclosed ore. 2 BLprints of the -RFT, run 1, 5,/7/gl Company CONOCO, Inc. ~1 I. ~3 Well Milne Point Unit G-5 I- Field Mllne Point/Schrader Bluff Additional prints are being sent to: I BL nrints cONocO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER County.North Slope State. Alaska I BL prints, I RE Sepia CONOC0,..Inc. 1000 $ouCh Pine Ponca City, 01 74603 ..A¢$n: Glenn Welch 7360RDW I BL orints, I lie Sepia OXY U'S.A., Inc. 6 Desta Drive Rtdland, TX 79710 Attn: John Carrol *(915/685-5898) I BL prints, 1 RE $epla Chevron U.S.A. 11111 South Wtlcrest Hosuton, TX 77099 Attn: Priscilla MacLeroy *(713/561-3652) Aia~k~ 0il & Gas Conservation~ .. / Commission ) ._. (3001Porcuoine Drive ~a. nchora~e,-AK 99501 Ak~tn: John BOyle...- The film is. returned to CONOCO, Ponca City. We appreciate the privilege of serving you. prints prints' prints Received by: · . Date: Very truly yours, SCHLUMBERGER WELL SERVICES Sws-- 1327-F Raymond N. Dickes TO: THRU: FROM: MEMORANDUM Sta e of Alaska ALASKA OIL AND GASCONSERVATION COMMISSION Commissione~' ~ FILE NO: M TELEPHONE NO: SUBJECT: BOPE Test Conoco's MPU G-5 Permit No. 91-23 Kuparuk Rv. Field Doug Amos ~ Petroleum Inspector FridaY..Mav 3~ 1991: I traveled this date from AAI's KRU to Conoco's MPU to witness the BOPE test on Nabors Rig No. 27E. As the attached AOGCC BOPE Inspection Report indicates, all six of the gas detectors failed this test. I required Joe Polya, Conoco rep., to repair the cellar and shell shaker detectors before drilling out the 9 5/8" csg shoe and one day grace to repair and recalibrate the remainding detectors. I also warned him that if I found the gas detectors in non-compliance on my next test, that I would have no other alternative but to shut the operation down until the items were repaired and I had personally verified their retest. I issued this warning because according to my past records, the gas detectors have been defective on the last two BOPE tests. I was contacted by Joe Polya at 3:00 a.m. on 5/4/91 and informed that all the gas detectors had been repaired and retested and that he and the Nabor's Rig rep had instituted a new policy so that the gas detectors are calibrated on a two-week basis rather than the previous 90-day calibration. In summary, I witnessed the BOPE test at Conoco's MPU G-5 well on Nabors Rig No. 27E. All six of the gas detectors failed this test. I issued a verbal warning to the Conoco rep, Joe Polya, and was assured that a new policy would be instituted to correct this recurring problem. Attachment. 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 OPERATION: Drlg Operator STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report DATE Wkvr TEST: Initial ~ Weekly . Other Location: Sec ~ Drlg contrctr ~~ Location (general) Housekeeping (general) Reserve pit ..~/~..., Rig# Well sign J Rig ~ Audio I i I MUD SYSTEMS: Visual Trip tank t~ Pi t gauge (~ F1 ow monitor I~ Gas detectors BOPE'STACK: Annular preventer Pipe rams Blind rams Choke line valves HCR valve Kill line valves Check valve Representative '-)' ~O/L~(.k . Permit # q~/~" Casing set ~ ~,4~-.~ ft ~-"7 ~ Rep ~, ~', ~ ACCUMULATOR SYSTEM: Full charge pressure ~l ~0 psig Press after closure /,~O0 psig Pump incr clos pre~s 200 psig min 'J~ sea 11 c r~e Er~s~a~t[i~ed J min sec Controls: Master . ~ Remote ~ Blind switch cover ~ TEST RESULTS: day/. Notify KELLY AND FLOOR SAFETY VALVES: Upper Kelly ) Test pressure Lower Kelly I Test pressure Test Pressure ( ~ ,'~(5)0 Ball type ~1 Test pressure / , ~ ~t~)O Inside BOP d~ ! Test pressure J )~- Choke manifold j Test pressure ~ (~. Number valves )8 // / t~ Number fl anges -'~ q ~"~ ~_ ~) Adjustable chokes ~- ~- ~ ..... Hydr.aulically operated choke Failures ~ Test time ~ I/?.. hfs Repair or replacement of failed equipment to be made within the Inspector, and follow with written/FAXed verification to Commission office. Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 05/10/90) Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 May 10, 1991 David W. Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-1433 RE: Milne Point Unit Well G-5 Application for Sundry Approval to Suspend Operations Dear Mr. Johnston: Attached is the Application for Sundry Approval (Form 403) requesting approval to shutdown operations on MPU Well G-5 with the drilling rig, pending completion with a workover rig. Well G-5 was drilled to a total depth of 4,200' and 7" casing was set. A 6" open-hole section was drilled from the 7" shoe to a total depth of 4,850'. A retrievable bridge plug was set in the 7" casing at 4,050' and the drilling rig was moved off location. Plans are to complete the well by installing a 5" liner in the open-hole or with an open-hole gravel pack. If there are any questions pertaining to this well please call me at 564-7637. Very truly Yours, cc: Mike Stockinger File #500.21.08 RECEIVED Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA .... ALASKA OIL AND GAS CONSERVATION COMMIbolON iO APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend __ Operation shutdown X Re-enter suspended well Alter casing Repair well __ Plugging_ Time extension ~ Stimulate Change approved program Pull tubing Variance Perforate __ Other __ Name of Operator Conoco Inc. Address 3201 C Street, Suite 200, Anchorage, AK 99503 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 3354' FNL, 3435' FEL, Sec. 27, T13N, R10E, U.M., N.S.B., AK At top of productive interval 3400' FNL, 4700' FEL, Sec. 27, T13N, R10E At effective depth At total depth 3408' FNL, 4920' 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-5 9. Permit number 91-23 10. APl number 50-029-22138 11. Field/Pool Schrader Bluff Pool 12. Present well condition summary Total depth: measured 4850 feet true vertical 4562 feet Plugs (measured) Effective depth: measured 4050 feet true vertical 3817 feet Casing Length Size Structural Conductor 115' 13-3/8" Surface 2439' 9-5/8" Intermediate Production 4190' 7" Uner Perforation Depth: measured Junk (measured) Retrievable Bridge Plug set in 7" Casing. Cemented Measured depth True vertical depth Sudace 115' 80' Sudace 2439' 2303' T.O.C. @+2800' 4190' 3921' true vertical RECEIVED Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) MAY 1 4 t991 Alaska OiJ & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal __ Detailed operations program__ Suspend operations pending completion with workover rig EWS 4. BOP sketch 14. Estimated date for commencing operation 9/1/91 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/'~' ~ 4,,,,.~!~. Rossberg Title Sr. Drilling Engineer Date '~ _~ FOR COMMISSION USE ONLY Conditions of approval: Notify'Commission so representative may witness lApproval No. Plug integrity__ BOP Test Location clearance .~, ,- Mechanical Integrity Test '~ubsequent form required 10-'~./'~/~'~ , .... ORIGINAL S~GNED BY ~..~'~~ Approved by order of the Commission 5/10/91 LONNIE C. SMITH Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE CONOCO, Inc. SCHLUMBERGER WELL SERVICE8 A DIVISION OF ~4~HLUMBE;RGF..R TKCHNOL.OGY CORPORATION HOUSTON, TEXAS 7725 I-2175 MAY 0 ~ lg§!i ~~ ~ ,~mm:, Pouch 3~0069 Prudhoe Bay, AK 9973~-0069 Attn: Bernie/Shelley 3201 'C' Street~ Suite 200 Anchorage, AK. 99503 . Attention: Van Llneberger Gentlemen: Enclosed ore 2 BLprints of the BGT. Run 1; 5/02/91 Compony CONOC0t Inc. Well Milne Poir~r ,Init G-5 Field ..YcLlne Potnt,/Schrader Bluff County North 31ope Additional prints ore being sent to: ! BL nrints CONOCO, Inc. 600 North Da../.r.y Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER Stote Alaska I BL prints, I RP Sepia CONOCO, Inc. 1000 South P/ne ?onca City. OK 74603 Arch: Glenn 1/elch 736ORDI/ I BL nrints, I ltg Sepia OXY U~S.A., Inc. 6 Desta Drive ~d!and~ TX 79710 ArCh: John Carrol *(915/685-5898) I BL prints, 1 1~ Sepia Chevron U.S.A. 11111 South Vtlcrest Hosuton, TX 77099 Attn: Priscilla HacLeroy *(713/561'-3652) ~lask~ 0tl & Gas Conservation / ~' Commission ~ · ' / 3001Porcuolne Drive / ~ Anch°raee.-AK 99S01 / The film is returned to COnocO, Ponca City. We oppreciote the privilege of serving you. 0 prin~ 1 Reel Chevron U.S.A. P 0 Box 5042 San ~. ~ a mo n__~_,._~L_._..9_.~.~~ ATTN: Norm Stone prints prints Recelved by; Date: Very truly yours, SCHLUMBERGER WELL SERVICES Raymond N. Dtckes DISTRICT MANAGER SwS-- 1327-F ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 9950'1-3192 PRONE: (907) 279-1433 TELECOPY: (907) 276-7542 April 8, 1991 R. S. Rossberg Senior Drilling Engineer Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503 Re: Milne Point Unit G-5 Revised Conoco Inc. Permit No. 91-23 Rev. Sur Loc 3354'FNL, 3435'FEL, Sec. 27, T13N, R10E Btmhole Loc3408'FNL, 4920'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, 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 Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 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, Sr. Drilling Engineer RSR/jcd cc: MPS file: 500.21.08 ECEIVED C:\data\wp51 \rsr\revgpad APR - 5 1991 Oil & Gas Cons. Commission Anchorage ALASKA OIL AND GAS coNSIE~,~,:i-iON C-.,0MMISSION , PERMIT TO DRILL '-------" 20 AAC 25.005 la. Type of work Drill ~' Redrill ~j lb. Type of well. Exploratory ~ Stratigraphic Test ~ Development Oil Re-Entw -- Deepen~l Service -- Developement Gas ;'- Single Zone .%. Multiple Zone 2. Name of Operator Conoco Inc. '3. Address 99503 3201 C Street, Suite 200, Anchorage, Alaska 4. Location of well at surface - 3354' FNL, 3435t FEL, SEC. 27, T13N, RIOE, At top of productive interval U.M., NSB, AE 3400' FNL, 4700' FEL, SEC. 27, T13N, RIOE At total depth 3408' FNL, 4920 ' FEL, SEC. 27, T13N, RIO~ 12. Distance to nearest property line 5860 feet 16. To be completed for deviated wells Kickoff depth 500feet Maximum hole angle 23 0 13. Distance to nearest well 59 feet 18. Casing program size Hole Casing i Specifications Coupling Length ]0" 12--1/4" 8-i/2" 6-1/8" 13-3/8" 9-5/8" ,, 7" O-H 12-1/4" !O-H Weight 1 Grade 1 ! , Weld BTTS BTTS 80' 2482' 4165" 5. Datum Elevation (DF or KB) 10. Field and Pool KB 35' AGL feet !6. Property Designation ADL 25906 7. Unit or property Name Milne Point Unit 8. Well number 6-5 9. Approximate spud date April 8, 1991 ;{uparuk River Field Schrader Bluff Pool 11. Type Bond (see 20 AAC 25.025) Blanket Number 8086-15-54 Amount $200,000 14. Number of acres in property 2560 4823 'MD/4543 !' TVD feet 17. Anticipated pressure (see 20 AAC 25.035 Maxim.m s.,ace 1,850 psig ^, ,o,a, ~e~. ~vo) 1950 Setting Depth ' "Top Bottom 15. Proposed depth (MO and TVO) Quantity of cement TVD (include stage data) 115' .. 2400' MD I TVD 35' 135'. 35' 135'. 35' [35'' 35' 35' 600 SX Permafrost "C" 650 SX Perm. "E"/300 SX "G" 200 SX "G" Open-Hol e ,, iOpen-Hoi e Opened to 12-1/4" Downsqueeze +400 SX Perma- Frost "C" +60 bbls diesel 2517 ' 4200' 48--~V 4823', 19. To be completed for Redrill, Re-entry, and Deepen O2erations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet 3942' 4540' 4540' Effective depth: measured feet Junk (measured) true vertical feet Length Size Cemented Measured depth RECEIVED APR - 5 t991 Ala l Oil & Gas Cons. mmI i0 ; nchorage True Vertical depth Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Pit Sketch 20. Attachments Filing fee ~ Property plat ]~ BOP Sketch ~ Diverter Sketch X Drilling programX? Drilling fluid program DE Time vs depth plot X~ 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 f F ~...~ R. S. RossbergcommissionTitle Use Sr. OnlyDrillins Engineer Permit Number I APl number Approval date .~/-~-~ t 50--oZ~-'~-~2~/,.y~ 02/22/91 Conditions of approval Samples required ~ Yes ~ No Mud log required ~ Yes ~No Hydrogen sulfide measures ~ Yes ~ No Directional survey required ~ Yes ,_~ No Required working pressure for BOPE ])i~2M; ~, 3M; ~ 5M; [] 10M; [] 15M Other: ~[- by order of Approv b~.~ _'~...~( ~ ~~-' Commissioner Form 10-401 Re~ .'-~-'-' ~, - ""--= Date 4/3/91 the commission See cover letter for other requirements ' 8'5'42" IdlLNE POINT UNIT G PAD ,NOTES: 1 1. STATE PLANE COORDINATES ARE ZONE 4. I ...... (~ 'k_(;WYD'fR BAY I MIl_NE POINT~ ACC£~ ACCES~ J\ .....-~ ~ PRUDHOF 2. ALLN.A.D.GEODETIC1927. POSITIONS ARE BASED ONf-'l ROAD............~,~..~ ~~ ~/~ ~~..¢X ;'~'~'u~'')''-. ~. OF~-SETS TO SEC'nON UNES AR~- COMPUTED ~- N "Q ?/~' BASED ON PROTRACTED VALUES OF' THE n' S£CI~ON CORNER POS~IION$. <4 MILNE PT. VICINITY MAP 0 3 6 MILES G PAD ' LOCATION IN SEC. 27, T. 15 N., R 10 E~ U.M. ' G-5 J 3354' FNL 3435' FEL · ~ ROPOSED c-6 i ~294' FNL 5445' FEL ~ % G-7j 3235' FNL 3~51' FEL ' ~ ·~ EXPANSION 0-8 i 3176' FNL 3459' PEL ~1~~~~~e ~ STATE PLANE COORDINATES-ZONE 4 WELL ~ NORTH (Y) EAST (X) [ G-5 ~ Y 6,014,361.26 X 557,168.77 i I I N~ 0il & Gas Cons. Commission GEODETIC POSITIONS ~AD 1927 I J ~O~e j W~LL I ~ ' ~ NOR~ LATITUDE WEST LONGITUDE i 0-5 70' 26' 59.541" 149' 52' 00.916" / 0-6 70' 27' 00.126" 149' 52' 01.150" 0-7 70' 27' 00.710" 149' 52' 01.585" 6-8 70' 27' 01.295" 1~9' 52' 01.620" ~ EXISTING WELL PROPOSED WELL PROPOSED WELL LOCATIONS F. Robert ~, 0-5 0-6 0-7 & o-8 , ~iil, , ~H~ 1~ - ,~,,~,,~, ~ ~~i~ SURVEYED FOR- ~s JOB NO.: 90-059 3335 ~C%C 5L~O. ~% 201 ~00 O0 _ '.00 ;00 ~00 ~00 ~00 _ '00 _ 300 _ · 3500 :3400 :3:300 :3200 :31 O0 :3000 2900 I /~ ! I I I , ,. .......... . -- ~ ........... :3000 :3100 ' o h oo . ' · · ~~o~ - - ~ T~0 ~ ~00 - ~ SOO 300 O0 - / 900 ~ ~~ . - %oo ~ ~oo I ~,,oo RECEIVED i _~soo APR - 5 ~99! I Ala~,~ Oil & Gas Cons Commission ~,$oo~ :3600 :3700 3800 3500 3400 3:300 3200 :31 00 3000 2900 CONOCO Structure ' Pad O Well' 5 Field · Milne Point Unit Locofion · North Slope, Alosko 8 oo 40O (/) IOO0 1600- - t800- _ 2000 - - 2200- _ 2400- _ 2600- - 2800- 3600- 400O fated by : rickb For: S ROSSBERG1 plotted ' 25-Mor--9~ Reference is 5 Version 12. rdinates ore in feet reference s!ot ~5. Vedicol Depths ore reference wellheod,l F~IEASTMAN I RKB ELEVATION: 59.27' 3.00 TD LOCATION: I 3408' FNL, '~920' FELI SEC. 27, T13N, RIOE I K0P TVD=500 TMD=500 DEP:0 <-- West 1400 1200 ~000 800 600 400 200 0 200 200 ! SURFACE LOCATION: I 3354' FNL, 3435' FEL SEC. 27, T15N, RIOE " S 87,DEG 55 MIN W 1266 (TO TARGET) RECEIVED ,~.,~ ~ ~ APR - S t991 ~" ~=~o ~:~, ,' ~=~,~ ~ Oil & Gas ~ns. Commission AVE~AOE ANOLE 22 DEO 2 K SNDS ~D=3525 TMD=5725 DEP=1074 M SNDS~D=3760 TMD=3978 DEP=1169 ~D=4000 ¢MD=4257 DEP= 1266 ~ OA SNDS ~=4155 ~MD=4404 DEP=1329 ~~ ~ / 7"LINER ~=4545 TMD=4823 DEP=1486 ALASKA OIL AND GAS CONSERVATION COMMISSION February 22, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7,542 R. S. Rossberg Sr. Drilling Engineer Conoco Inc. 3201C Street, Suite 200 Anchorage, AK 99503 Re: Milne Point Unit G-5 Conoco Inc. Permit No. 91-23 Sur. Loc. 3407'FNL, 3377'FEL, Sec. 27, T13N, R10E, UM Btmhole Loc. 3399'FNL, 4936'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. Sincerely, _/ .... ~ ~onnie C.×Smi~, 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 -~- ALASK;~"~'~IL AND GAS CONSERVATION MMISSION ,- · PERMIT TO DRILL 20 AAC 25.005 -la. Type of work Drill ~' Redri,l ~l lb. Type of well. Exploratory ~ Stratigraphic Test ~ Development 0il ~ Re-Entry - Deepent'-J Service - Developement Gas ~_ Single Zone. ~' Nh:t4.P~Je Zu,Je ~ 2. Name of OPerator 5. Datum Elevation (DF or KB) 10. Field and Poop Conoco Inc. KB 35' AGL feet ~uparuk River Field 3. Address ' ' 99503 6. Property Designation Schrader Bluff Pool 3201 C Street, Suite 200, 2Lachorage, A.lasEa .A_DL 25906 4. Loc'ation ~f well at sur'face 7. unit or Property Name ii~' Type Bon~l Isee 20 AAC 25.025) Milne Point Unit 3407' FNL, 3377' FEL, SEC. 27, T13N, RIOE, Blanket At top of productive interval U.M., NSB, AY,. 8. Well number Number 3400' FNL, 4700' FEL, SEC. 27, T13N, RIOE G--5 8086-15-54 At total depth E' ;9. APproximat~ Spud date Amount 3399' FNL, 4936' FEL, SEC. 27, T13N, RIO~ April 8, 1991 $200,000 . ., "12. Distance to nearest 13. Disiance to nearest well 14. Number of acres in p'r0pert~'I l'g. Proposed depth(MD a.d 3'VD) property line 5860 feet 59 feet 2560 4853'MD/4540'TVD feet '16. To be (~'ompleted for deviated wells 17. AnticiPated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 500feet Maximum hole angle 23 0 Maximum surface 1,850 psig At total dePth {TVD) 1950 psig 18. Casing. prOgram Setting Depth ..... ' ....... size Specifications Top Bottom Quantity of cement ' Hole Casing Weight i Grade Coupling] 'Lengtl~' ' MD TVD MD TVD ' (inClude stage data) .... 30"" 13-3/8" 54.5 k-55 Weld 80' 35' 35' 115' 115' 60o sx Permafrost "C" 12-1/4" 9-5/8" 36 K-55 BTTS 2482' 35' 35' 2517' 2400' 650 SX Perm. "E"/300 SX "G" 8-1/2" 7" 26 L-80' BTTS 4165' 35' 35' 4200' 3942' 20O SX "G,' ....... ,,, · 6-1/8" O-H 35' 35" 4853' 4540' 0pen-Hole 112T1/4" O-H 35' 35' 4853' 4,540" 9pen-_Ho_le .Opened t,o. J2-1/4" 19. TO be completed for Redrilli' Re-entry, an~l Deepen Operations. Downsqueeze +b, 00 SX Perma- Present well condition summary Frost "C" +60 bbls diesel Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural sCu°r~;~t°r R E IV E D Intermediate Production FEB 1 4 1991 Liner Perforation depth: measured AJaska, 0il & Gas Cons. C0m~t$s'.te-tl ; mch_0mge. true vertical Pit Sketch '20. Attachments Filing fee'~ 'Property plat 3~ BOP Sketch ~ Diverter Sketch Z Drilling program]J2 ...... Drilling fluid program [Z Time vs depth plot Z] Refraction analysis [] Seabed report ~ 20 AAC 25.050 requirements X~ 21. I hereby 'ce"rti'fy that the foregoing is true and correct to the best of my knowledge ..... Signed./(_ F ~~.~/ R. S. Rossberg Title Sr. Drillin~ En~,ine..er .......... Date2/.13/.91 Commission Use Only Permi'"Uumber "IAPlnumber ' ' JApprovaldate' ' I See cover letter .......... ~/- ~ 50--0 ~.c) -~-,ZI.~.,~. 02/22/91 for other requirements Conditions of approval Samples required 1~ Yes [~o MUd Icg required ~ ~ Yes l~'qqo Hydrogen sulfide.measures ~ Yes I~,'1~o Directional survey required IZ~,"fes ~ No Required working pressure for BOPE .~2M; ~ 3M:.~ [] 5M; [] 10M; [] 15M Other: ' .-~/<:'"i-"r ~/:" ~ by order of Approved by i''~/~ '''~(v~~;~'~:,-' '"~-,-' '%--T~ - Commissioner the commission Oate~~2~'-'', Form 10-401 Rev. 12-1-85 Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT G-5 Conoco Inc. 3201 C Street, Suite 200 Anchorage, Ak 99503-3992 I. Casing and Cementing Program CASING PROGRAM E EIVED FEB 1 4 t991 Alaska Oil & Gas Cons. Commission Anchorage Hole Size Casing Size Depth Weight (Inches) (Inches) (ft) .(ppf) Grade Conn 30" 13-3/8" 115' 12-1/4" 9-5/8" 2,517' 8-1/2" 7" 4,200' 6-1/8" to 12-1/4" Open-hole 4,853' 54.5 ppf K-55 WELD 36 ppf K-55 BTTS 26 ppf L-80 BTTS ae The 13-3/8" conductor will be set at 80' below ground level then cemented to the surface with ±600 sacks Permafrost type tlCll . Be The 9-5/8" surface casing will be set approximately 500' below the base of the permafrost at 2,517' MD/2,400' TVD and cemented to surface. The cement slurry will consist of a lead slurry of approximately 650 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. Ce The 7" production casing will be set at 4,200' MD/3,942' TVD or approximately 50' below the base of the Schrader Bluff "M" series sands. Class "G" cement (approximately 200 sacks) will be circulated from the 7" shoe to 500' above the top of the Schrader Bluff "K" series sand. A 6-1/8" hole will be drilled from 4,200' through the Schrader Bluff "N" and "O" series sands to approximately 4,853'MD/4,540' TVD and underreamed to 12-1/4". The well will be completed utilizing a wire wrapped screen and subsequently gravel packed. II. Drilling Fluid Program A. 0 - 500' 9.0 ppg freshwater spud mud. B. 500' - 2,517' 9.0 ppg - 9.2 ppg freshwater spud mud. C. 2,517' - 4,200' 9.0 ppg - 9.2 ppg dispersed. De 4,200' - T D 10.4 ppg - 11.5 ppg Salt Saturated Polymer Brine Conoco Inc. Supplemental Data Sheet Well G-5 February 1991 Page 2 III. Drilling Program Conoco Inc. proposes to drill MPU well G-5 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 2,517'. A low solids, non-dispersed system (9.2 - 9.4 ppg) will be used from 2,517' 'to the 7" casing point at 4,200'. A salt saturated polymer brine will be used to drill and underream the open-hole section from 4,200' - 4,853'. 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-4 with 59' of closure at the surface. Approximately 400 sacks of Permafrost Type "C" cement displaced with dead crude and/or diesel will be pumped down the 7" x 9-5/8" annulus for final arctic pack and freeze protection after disposing of excess drilling fluids. The well will be completed with the drilling rig. A wire wrapped liner with a liner hanger and packer will be run from approximately 4,150' to TD. A gravel pack will be hydraulically placed behind the wire wrapped screen. RE([£1VED FEB 1 4 Alaska 011 & Gas Cons. commtSS'tot~ ~nchorage Conoco Inc. Supplemental Data Sheet Well G-5 February 1991 Page 3 WELL PROGNOSIS AND DRILLING PROGRAM TVD MD FORM 500 500 GRAVEL 898 900 SAND/SHALE 2400 2517 CASING PT 3525 3738 K TOP 3760 4000 M TOP 4000 4263 NA TOP 4155 4433 OA TOP 4230 4515 OB TOP 4265 4553 OB BASE 4540 4853 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 BRN 10.2 12 8 35 6 4-3-7 BRN 10.2 12 8 35 6 4-3-7 BRN 10.2 12 8 35 6 4-3 -7 BRN 10.2 12 8 35 6 4-3-7 BRN 10.2 12 8 35 6 Open-hole pilot section to be drilled with a 6-1/8", 4-3-7, rock bit and underreamed to 12-1/4". 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. RECEIVEi) Alasl~ 011 & Gas Cons. 'Anchorage T 13 NRe E T 1:3N R 10 E T 13 N R 11 E MILNE POIN' ' -- -' ............. ~ ~ ' J ii i ' Jl _ _L ,, . , ~-255~ 2533AC AOL'47434. ,, .2SSO,,AC~,,,~ ADL'47433_ ~60 A~. ~0~743~08 AC X ............ CONOCO ET . + + ._ 23 24 19 ~0 ~1 ~2 23 24 21 ADL-25516 ADL-4743e AOL-3 ISe4e Aox-s,,,,, ~2~oAc _.~2aOACI ~-25514 25~0 AC AOL-25515 2~4 ~C l~eO 4C 12aO AC ADL-47437 25aO AC ADL-47438 2544 [ .......... , · , , , , , , i , , 30 2~ 2~ ~T ~1 - ~S 30 29 ~ EX~[181T A 223S AC 20 ~AOL-25~ 2540 AC AOL-2SS la 2S60 AC AOL-28231 2SSS AC __ ~ . i iii mi ii i ~ ii m i · ' ~ IOmO UNIT 35.744 Acre.~ UNIT AREA Me~ldlln,Aleel~ · I 2 Scale NOTES: 1. STA'i'E PLANE COORDINATES ARE 7ONE 4 2. ALL GEODETIC POSITIONS ARE BASED ON N.A.D. 1927 OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSTIONS 30' ~ 120' -:_-~ - e--O_~ -- ._ IJ~'! '- ~[. e-2 290' G PAD O8' O6'42" MILNE PT. VICINITY MAP o 6 ~2 MILTS LOCATION IN SEC. 27, T13N, RIOE, UMIAT MERIDIAN WELL FROM NORTH LINE FROM EAST LINE 6.-1 6-2 6.-3 6.-4 G-5 G-6 g-7 3645' 3585' 3526' 3466' 3407' 3347' 3288' 3228' 3346' 3353 3362' 3?70' 3377' 3385' 3393' 3401 ' STATE PLANE COORDINATES-ZONE 4 WELL NORTH (Y) EAST (X) 6'-1 6.-2 6.3 G-5 G-6 G-7 G-8 6,014,071.65' 6, 014, 130.44' 6, 014, 190.03' 6,014,249.92' 6,014,308.91' 6,014,368.30' 6,014,427.70' 6,014,487. 10' 557, 260.71' 557, 252.51' 557, 243.78' 557, 235. 15' 557,226.72' 557,218.28' 557. 209.84' 557. 201.39' GEODETIC POSITIONS NAD 1927 WELL NORTH LATITUDE WEST LONGIT].~E 6'-1 6.-2 6.-3 6.-4 ¢, lO' G-5 MIN. g -6 ,_9£,!~[ !~_ 290' iL._ 6-8 :::/:: !.T.'~.'. ?':.:".'-'.::~/:::;;: !:':. i'.'.!'. '..' !.::';:'.':' .::.'.:/;~:':?.:.:::;:::':..i!!:,!:'.7::: ~,~1 5 N ~FRB. 84OOZ I'*I~LLOC C~AD£X~ (~ TYPICAL SECTION NO SCALE 70' 26 '56. 686" 7O' 26 '57. 269" ?0' 26 '57. 851" ?0' 26 '58.441" 70°26'59.022° 70°26'59.607' 70°27'00.192- 70°27'00.777' 14 9' 31 '£8.280 ' 14 9' 31 '£8. 508' 149' 31 '58. 751 * 149' 31 '58. 991 * 149o31'59.222. 149'31'59.453' 149°31'59.685" 149"31'59.916' LEGEND o PROPOSED NEW WELL · EXISTING WELL CONDUCTOR (LOCATION AS-BUILT) PROPOSED PAD EXTENSION ,..~.~,. & NEW WELL LOCATIONS ~,...'49TH /~..;, '-:.-,'~ &$'-. ~. ~o~ ~ .~ I DATE DEC. 10. 1990 /~~~~~ %"~;..~<o. 3:s=-s .'l~-~I ~,~wN ~ (( ( Y ~( Y ( /I ~.. .-:'~'~ I JOB NO. SCALE 1':200' I CONOCO INC,--NABORS RIG 27E 13-5/8" 5808 BOP SYSTEM, Flll Line APl 13-~E~ ~H APl 13-~ 5t4 AFl 1EF~%'B' 5t4 AFI 13-~%~B' ~ AFI 13-5A5' ~ x 11' ~ A?I 11' 5H Threaded CorrecHon Flow Llne Annular Preventer Ram Ram Ram Tubing Spool w/ 2"-5000~ Side Outlets Casing Spool w/ 3"-5000~ Side Outlets 9-5/8" Surface Casing C'hoke Line: 3" 50004~ Manual Oa~e VaLve & 3" HCR VALVE Kit[ Line: Two 3" 5000~ Manuat Oate VaLves" 13-3/8" Conductor Casing l, BOP STACK SIZE RATING MEETS APl RP53 & SPEC 6A FOR CLASS 5H 2, DOPE TO BE OPERATED EACH TRIP AND TESTED W'EEKLY, 3, BOP HYDRAULIC CONTROL SYSTEH TO INCLUDE (5) STATION CONTROL HANIFOLD LOCATED REHOTE WITH 168 OALLON ACCUHULAT'OR, RESERVOIR UNIT, & AUX]LIAR¥ ENERGY SOURCE FOR SYSTEM ACTIVATION, ~r, H]N]HUH ONE SET BLIND RAHS & TWO SETS APPR. OPR];ATE PIPE RAHS, 5, CHOKE & KILL HAN]FOLDS SHOWN SEPARATELY TO FLEET AP] RP 53 CLASS 5H REOU]REHENTS, KILL ~NIFOLD FRCM REMOTE HIGH PRESSURE PUMP NOI'E: SM S~S. ) PL'~dp RF-~(OTE PR£$$UfiE G.:',~£ SENS~ HTCR:ULIC CONTROLLED REMOTE OPERATED DRILLING SPOOl. HYDRAULIC CONTROLLED R~OTE OPE,RATED REMOTE PRESSURE GAGE $£NSOR ADJUSTABLE C~OI~E C~KE ,~NUSTA~ UA,N/FOL D C~O~E VARI,~BLE C~KE ~l CC~TROL ~ TO SHALE t 8LEZD LINE TO PiT J ~UD/GAS S£P,:RATOR RECEIVED CHCK£ 8 ~:ILL MANIFOLDS FOR cls/8" 8 7" OD C~,S]NG BOP BOP I,IANIFOLD LAYOUT-CONOCO, /NC, : FEB 1 4 t99t Alaska Oil & Gas Cons. Commission '*'~,."~,N ~ ..,., CONOCO, INC, MILH[ POINT UNIT DIVERTER STACK FOR 13 3/8' CONDUCTOR ,E~ &'"' ,q, ;'"' ... J I ' ~ ~'LOw LI~I I'tLL uf L~.[ ~~ ? .. , I)IvEATI;II OglCl ¢C)NN[CT ASS[MILT ,. RE( EIVED !: -'~'=-( 13 3/i' CJSIhG · 1. The hydraulic contt'ol syste~ will b~ tn a~rda~ with ~I specifications a~ ~ r~uirements. 2. The HCR valve will open ~en the preventer closes. A singl~ IO~ relief lina will run off of the drilling s~ol HCR valve and will have a ta,-geted downstrea~ tee for downwind dive. ion. Valves on ~th sides of the te~ will be full opening a~ linked ~ogethep ~o enabI~ one to al~ays be o~n a~ the othe~ to ~ closed. FEB 1 4 1Bgl Alaska Oil & Gas Cons. CommiSsion ~chorage ::3 ::3' l.~l t' k,.L 1,Nil i · i Mid (.N6aCA : d · . p- W W b_ I EL W MILNE POINT UNIT WELL G~5 0 DEPTH vs. TllX,IE MI / RU / Set Conductor / NU I)iverter 0 1 2 5 4 5 6 7 8 g 10 TIWE (DAYS) o · ' 200 400 - ~00- ~ 800- _ . (1) - - - - - 3600 - c o · ,I1C. Structure Well ?'5. Field · Milne Point Unit Location · North Slope, Alaske mted by : jone~ For; S ROSSRERG · Plotted : 7-d~n-gl t Refere~e is ~m~n ti. rdi~tes ore in feet reference s~t " · Ve~at ~pths are refere~e welled ~EASTMAN ~BCHRISTENSEN RK8 Elevotion: 5g.27' KOP Tvd=500 Trod=500 Dep=O 2.50 TD Location: ]3399' FNL. 4956' FEL [ Sec. 27. T15N, EIOE TAR¢~r / N Snds T,,d-4000 Trnd-4263 Oep== 1323 North 7 West 1323 <-- West 1~0 1~O 12~ 10OO 800 6OO 400 2~ 0 II'CIIIIIIIIIIII © SudoceLocotion; 3407' FNL. 3377' FEL Sec, 27, T$SN, RIOE Target Location; 3400' FNL. 4700' FEL Sec. 27. T13N, RIOE 7.50 12.50 Su~d 2.5 oe~/~oo rt 17.50 N 89 DEC; 4-2 MIN W OB Tvd=1420 Trnd=1446 Dep--193 1.323' (TO TARGET) \, g 5/8" CSG Pt ~'~ Tvd=2400 Tmd=2517 DER=622 ~ AVERAGE ANGLE ' 2,3 DEG 39 MIN ~K Snd, Tv0=5525 Trod:5745 DeO=I, 15 RECEIVED ~ M Snds Tvd=3760 Trod=4001 Dep=1218 FEB 1 4 1991 ~ T^RCET/ N Snds AlaS~:a 0d & 6as Cons. L;ommlss[o ~ Tvd=4000 Tmd=4263 Dep=1323 Anchorage ~ OA Snds Tvd=4155 Trod=4453 De~=1391 -- ~ OB Snds Tvd:-4230 Trod=4515 DER--142"4 B/ OB Snds Tvd4-265 Trod,=,4553 Oep,= 14.39 ~, TD/ 7" Liner Tvd=4540 Tmd=4853 Oep=155g J i' i i i i i i i i i i i i i i i i i i 3200 3400 38C~)~JO0 ~ *200 4400 4600 4800 500(] Scale 1 ' I00.00 Ver~ Se~e~ Z~-W mm 3500 340~ 3300 3200 3, O0 300D 2900 11 ~ · ~ ~ 3000 I \ ! 1500 ,oo_ I ~ ' ~ 11 O0 ~ 1 300 I ~ PAD ~ 3200 - ~ % /1 O0 ' I ~oo_ I &co ,~oo ' I ; ~oo / %00 ~ ~oo ~oo _I ~,,oo RECEIVED I I ~EB ~ 4 ~99~ 3600 _ j I 3700 _ J ~ I I 3800...- ......... I I _ 30( .32( .33( 34( Alaska Oil & Gas Cons. Gom~'tssiOtl ' J 3 6 ( Anchorage 'l, soo~ I , ~sOo __ __ ........... 38C i i I I 3500 :3400 3:300 3200 3 ! O0 3000 2900 ITEM APPROVE DATE Loc /j0~. (~, .//~/~ [':~ thru 8]' ' -' ** CHECK LIST FOR NEW WELL PERMITS ** (3) Admin '[9'~hru 133 " [10 & 133 (4) Casg /~.~,~ 4/-5'-~/ [14 thru :22] [23 thru 28] (6) Other [ 29'~ thru 3'1] (6) Add1 · e 3. 4. 5. 6. 7. 8. . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Company ~__~~ c_ ~ Lease & Well YES Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-dab:wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nL~nber appropriate .......................................... Does well have a unique n~me & n~nber ................................ 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 diverter 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 ~m~m 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... Additional requirements ............................................. NO O -rZ ~O geology' eng i neer i ng,;~ DNdj~ MTM~, LCS/__~~' RPC ~.~ BE.WP)" RAD__~-') rev 03/29/91 jo/6.011 INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' (1) Fee CHECK LIST FOR NEW WELL PERMITS Company C ~D/kJ CO ~ ~ Lease & Well No. _~~ U -- ~~ 1. Is the permit fee attached .......................................... ....... (2) Loc thru 8) ........ (8) (9 thru 13) 10. (10 and 13) 12. 13. (14 thru 22) (23 thru 28) (29 thru 31) Aaa: Geology: Eng~ne~ering:_ ~ - rev: 01/30/89 6.011 REMARKS Is well to' be located in a defined pool ............................. ~ ® 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... ~_ 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31 32. 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~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OOo psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence _of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones .... P ~-/-~;;;~;--/" If an offshore loc., are survey results of seabed conditions Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE _~j-/z/C / - cb 1 L ~q~ /I~Z~ c:) ;,3 i ! 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 roadability 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. ********************************* O.PANYNA.E i' CbNbCO ZNC': RECEIVED JUN 1 ~ 1991 0il & Gas Cons. Commi~ion Anchorage ape ve i cat ona m~erger A1 s~a Computinq Center s~vIcz NA~Z : £Ui~ D TE~- { 9!/06/12 REEL.NAME : 7454? CONTINUATION # : PREVIOUS ZZb : COMMENT : conocO, SCHRADEm BLUFF, RILN£ POINT UNIT' O'5, 50-029'2:2238 **** TAPE HEADER **** DATE : 91/06/12 ORIGIN = FbI¢ TAPE NAME - : 74547 C~NTZNUATiON # { I .ILN£ PblNT UNIT G"5, 50"'029'221{8 FtLE.NA~E : EDIT ',001 S~RVICE : FblC VERSION = 001A06.. DATE · { 91/06/12 ~X REC SIZE : 1024 FILE TYPE { bO bAST FILE { FIELDI : SCHRADER..BLUFF BOROUGH{ NORTH SLOPE STATE= AbASKA APl NUMBER{ 50-029-221~8'00 LOCATION: 3354' r~ &.~3435; rrb SECTION= 27 TOWNSHIP= 13N PERMANENT DATUt4: MSb EbEVATION{ 0 RANGE: 10Z ~'S Ta~e~ Veri.~icatlon I,~ in~ ~!~lu~e~,ae.r ~l~slca ¢o~l~tn.q Center 09145 'PAgZi 2 ~OG ~EASURED FRO~ RKB 65 A~OvE PER~ANENT DATUN RUN NU~SBRI ON~ TD DR~LbER~ 4650 TD LOGGERI ~650 : $~NG I ~ DRILb'ER DEPTH OF 41 LOGGER DEPTH OF 4190 B~T SZZ~ ~ ~2 I/4" TYPE FLUID IN HOLEI SIZED SALT DENSIT¥~ 10,3 V~SCOSITY1 43 PHI 8 FLUID LOSS 89 LOGGiNG~ ENGZ'NEER I TOOL NU.B~RSI. SPA'A 509 ECH-KC 2 DR$-C 4908 PDH-L 376i BGS-A 956 PRUDHOE BAY BARBER POLYA/OAViES/oECKERT A~S-AA'924 NGDiB 739 NSR-F 2290 PGD-O~ 3961 DbS-B BOC'B 953 NGT WAS LOGGED.WITH LEAST SQUARES FILTERING BOREHOLE SALINXTY~ 200,000 PPM CHLORIDES :. COMPUTING CENTER REMARKSi THIS LIBRARY TAPE Aba0 YNCbUDE$ THE F0bLOWING cONPUTING .. CENTER PROCESSING WHXCH IS LOCATED IN rILE #3 ON THIS TAPEI 1) KALNAN FILTERED NGT 2) ALPHA FILTERED NGT 3) ALPHA PROCESSED LDT/CNb ~hl~be,~oe~ Alaska Co~p~t~nO cente~ F~E,-EDIT,O01 CDNOCO ZNC. SCHRADER M'ILNE POINT UNIT 50'029-22!38-00 DATA 8AMPbED EVERY -.5000 FEET *' DEL ,Obb DUAb.,bA~ER~bPG * LOT,_ ,bO? bi?HO DENSITY . * CNT AID/H ,CNL COMPENSATED NEUTRON * NGT ,NG~ NATURAL:GAMMA SPECTROSCOPY (LEAST:SOUARES fILTERED) * CNT-A/D/H ,CSG COMPENSATED NEUTRON IN CASING WI~'H GAMMA RAY' ~ , . TABb£ TYpE { CONS ". : · TUN! ....... VALU ....... DErI.. ..... _ CN CONOCO iNC-,. CompanyrName FN ~CHRADER.BLUrF rie~d:.Name, WN MIbNE POINT UNIT O-5 Well Na~e . . _ : , 22138-00 Ae2.Serlal aumoer r~ . )354 FNL & 3435; FEb Field boc~ ion Township COUN NORTH SLOPE STAT AbASKA NAT! USA WZTN PObYA/DAV!E$/DECK~RT SON 548205 PDA? MSL EPD FT APD rT 65. EOF FT 6 , Ranqe County St&te:.or Prov~nce Wltn~ss'~Name Servxce Order Number Permanent datum Elevation o~ perm, Datum Log #easured ~rom ABOVE PERMANENT DATUM Elevat!on o~ Ke11¥ BuSh~nq glevat!on o~ Derrtc~ Floor hlumberqer Alaska Computing Center '12-aUN'!99t 09545 . . - ?UNI VALU DE'FI EGL FT 30 Elev tion of Ground Level TDD FT 46~0, T'Ota~ Depth - Driller TDL FT 4650, Total Depth - Logger BL! FT 45~, Botto~ ~o~ InterVal. TL! FT Ii2, TOp LO~ Interval~ . DFT SIZED S~LT Dr111I~ Flu!d Type.s. DFD G/C3 10,3 Drillinq FlUid DenSity DFPH B DrIllin~ Fluid DFV CP 4~. Dr!llln~ FlUid ViScosity DF~ Fl 55 Drlltin~,,rlutd Loss ,. RMS OH~ 0 06 ReS'iStlV'ity_otMud Sample MST DEGF 6 Mud.~'Sample Temperature. R~'FS OHMM 0 ~52 ResistiVitY o~.~ud.t!l~ra~a'-s ~FST D£GF 6 ~ud:rlltrateSample Temperatu RMCS OXM~ 0 .{34 ReSistiVitY o~,MPd. Ca~e Sam~l ~CST DEGF 6! ~ud.Ca~e..SamPle Temperature iO0 7-~A.Y Time'Circulatlon Stopped .~T~Es DECF }~,u' , Sottom Hole Temperature TABLE TYPE I CURV .......... DEFX' LLD CAbS CALX C.Abl SP T~NS HTEN G~ Cl C~ T~NS DPHX RHOB DRHO blTH Depth Channel Name batero-boq Shallow (Res~st~v~ty) ~atero-Lo~ Deep (ReSistivity) Sonic Caliper Caliper ' IAIPER1 pontaneous Potential. spectroscooy Gamma~Rav Tension ~ud Temper t re MUD Resist~ u vit¥ Head.Tension Gamma Ray Caliper i - 3 Calf?er 2 - 4 Tension ..,. Density Porosity BUlk Density Delta RHO - Photoelectric Factor - . Oual~ty control o~ long spacing'for LDT OualttY control On short spacing ~or. LDT Lon~ Spa¢inq Computed Count Rate ~LL+LU/2) Lon~ Upper i~2 ~tndow Count Rate Long Lower~indow Count Rate Litholog ~indow Count Rate Short SPacing ! ~tndo~ Count Ra~e Short Spaclne 2 ~indo~ CoUnt Rate ?.. ?a~e. veri~icetio. ~istin~ :hlu~ber~er AIe$~ca Computin~ Center 12-.JUN-199! 09~=45 PAGE; DEF! LSHV ~URH T~N8 MTEM HTE~ NPH! RTNR ?NRA ReNT RCF? CNT¢ CFTC TENS MTE~ HTEN THO~ P~TA URAN W!N~ W~N~ W4N~ W~N~ T~N$ M~ES NPH! RTNR TNPH TNRA NPOR RCNT R~FT CNTC CFTC T~NS ong..S~a¢t~ H~gh Voltage Output herr upaclng Mlgh Voltage hood OutPut hort SDaCirng l~.Density bonq SPacing~'RHOB (Uncorrected) ~onq~Upper' Ca.liuer ., S~ectroscopy Camma. Rav Tension ~ud Temperatvre ~UD Resistivity ,ead Tension . 'Neutron Porosity Raw ?hermal Neutron Ratio ?hermal Neutron Porosity Calibrated Thermal Neutron Ratio Neutron PoroSity OutPut ~rom an lpui[cat[on Prooram RCNT RCFT CNTC CFTC Spectroscopv Oamma-Rav ?ension. 'MUD Resistivity Mud ?empe ature Head Tension Suectroscouy...:'Gamma-Ra¥ Uranium~ Potassium computed GR. ~rom Thorium, ThOrium ~otassium Uranium Window (1,1 - !.6 M£V) window C1.~ - ~ ~Ev) Window 5 (2 3 E ) Tension Mud ?empereture MUD Resistivity Cable $~eed Head Tension Neutron ~oros{t¥ Raw Thermal Neutron.Ratio Thermal Neutron Porosity ~alibrated Thermal Neutron Ratio Neutron Porosity output From an ApUl~cat~on Program RCNT RCFT CgTC ¢~TC SDectroscoPy.~Gamma-R&v Computed GR ~om Thorium, Uranium, Potassium Tension.-. MUD Resistivity chlumber~'er Alaska ¢omput{ng Center PAGE= M?EM ~ud. Temperature HTEN ~ead Tension . DATA FORMAT SPECIF~CA?ION RECORD **. SET TYPE -64EB.. TYPE .REPR CODE . .VALUE 1 66 0 2 66 0 3 73 :332 4 66 5 66 65 6'8 I1 66 0 66 68 16 66 1 o, ~ 66. 0 , *.* SET TYPE - CHAN~** .. NAME SERV. UNIT SERVICE APl APl APX APl FILE NUMB NUMB SIZE REPR PROCESS :- ID ORDER #. LOG TYPE,CLASS MOD NUMB..SAMP ELEM .... CODE ,.(HEX) mmmmmm~mmmmmmmmmm~m~mmmmm~mmmmmmmmmmmmmm~mmmm~m~m~mmmmmmmmm~m~mm~m~m~m~mmmm DEP? F? 548205 O0 000 O0 .0 1 I I 4 0000000000 LLS D~L OHMM 548205 O0 000 O0 0 ! 1 1 4 0000000000 LLD DL~ OHMM S48205 O0 000 O0 0 1 ! 1 4 0000000000 0000000000 CAL8 DLL IN 548205 O0 000 O0 0 CALI DLL IN 548205 O0 000 O0 0 CALl DLL IN 548205 O0 000 O0 0 SP DL~ HV $48205 O0 000 O0 0 SGR DLL GAP! 548205 00 000 00 0 T~N8 DLL LB 548205 00 000 O0 0 NTEM DLL DEGF 548205 O0 000 O0 0 MRE8 DLL 0HMM 548205 00 000 00 0 HTEN DLL LB 548205 00 000 O0 0 OR BGT GAPI 548205 00 000 00 0 C1 BGT XN 548205 00 000 00 0 C2 BGT IN 548205 00 000 00 0 TEN8 BGT LB 548205 00 000 00 0 DPH! bDT PU 549205 00 000 00 0 68 I ! ! 4 68 I I ! 4 68 I 1 I 4 68 I I I 4 68 1 1 1 4 68 1 ! ! 4 68 1 1 ! 4 68 I ! 1 4 68 I 1 1 4 68 1 1 I 4 68 t 1 1 4 68 1 1 1 4 68 I I 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 TaPe veriJ.~ication [,~st~no :hlum~erger Alaska Comput{nd~ Center 12-JU.',199! 09:45 PAGE: · . NAME SERV UNIT SERVICE AP1 APl AP! AP1 FILE NUMB NUMB aIZE REPR PROCE88 ]D ORDER # bOG TYPE CbAaa MOD NUMB aAMP EHEM ...... .CODE ..... (HEX) · · RHOB bDT G/C3 00 000 O0 0 1 ! ! 4 6{ 0000000000 ~ i~ 0000000000 G/C3 548205 00 000 O0 0 I ! ! 4 8 0000000000 0000000000~ 548205 DRHO bDT PEF bDT 548~ oaa bDT 5482 5 LS bDT CPS 54820 05 HU LD? CPS 548205 LL bDT CPS 548205 bITH bDT aat bDT Sa2 bDT baHV bDT SSHV bDT S]RH bDT bSRH bDT GURH bDT CAb! bDT &GR.- bDT TENS ~DT MTEM bDT MREa bDT HTEN ~DT CPa 548205 CPS 548205 cpa 548205 V 548205 548205 ~/C3 548205 G/C3 548205 G/C3 548205 IN 548205 GAPI 548205 DEGF OHMM 548 5 CGR NGT GAP, 548205 W4NG NGT C.$ 548205 oo o. 00 oo 0 ! oo 0oo oo o 1 oo o00 oo o 1 oo ooo oo o 1 oo o0o OO o 1 o0 bO0 oo 0 1 1 oo ooo oo o % oo o0o OO o i oo o0o O0 0 oo 00o OO o l oo 000 OO 0 i oo 0oo oo o i O0 000 O0 0 ! 1 0o 000 o0 0 ! oo 000 O0 0 1 oo 00o o0 o 1 O0 000 O0 0 1 1 O0 000 O0 0 1 O0 000' O0 0 i oo 0o0 oo 0 i' 0. o 00o oo 0 o0 000 oo 0 O0 o0o oo o 1 °° °°° °° ° i oo 000 OO 0 oo 00o oo 0 O0 000 OO 0 ~ oo 00o O0 0 1 oo 000 o0 0 ! O0 000 o0 0 ! O0 0o0 O0 0 1 o0 000 o0 0 ! O0 00o OO 0 O0 000 O0 0 i 1 o0 o00 OO .0 ! O0 000 o0 0 1 o0 000 O0 0 ! O0 000 o0 0 I ! O0 000 O0 0 i 1 O0 o00 o0 0 I OO o00 OO 0 t 1 00 o0o O0 0 ! O0 000 oo 0 ! o0 00o O0 0 1 1 O0 000 OO 0 I 1 oo 000 O0 0 1 o0 000 OO 0 1 oo o00 oo 0 I t O0 00o oo 0 I 1 1 ! 1 1 1 ! 1 i, 1 I i ! 1 1 l 1 1 ! ! ! ! ! ! ! ! 1 ! ! ! ! ! ! 4 4' 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 6g i~ 0000000000 000000000.0 0000000000 6 0000000000 0000000000 00000000'00 68 0000000000 68 0000000000 68 0000000o00 00000000o0 0000000000 6~ 0000000000 6 0000000000 0000000000 0000000000 0000000000 8 ~000000000 0000000000 ~l 0000o00000 00000000~ 00000000 000000000o 0000000000 000000000 0000000o0 00000000o0 0000o00000 0000000000 0000000000 0000000000 0000000000 000o0000o0 0000000000 0000000000 0000000000 0000000000 0000000000 0000000o00 0000000000 o000000000 o000000000 0000000000 0000000000 0000000000 0000000000 0000000000 68 68 68 68 68 68 68 68 68 69 68 68 68 68 68 68 68 68 68 68 68 ch.lumberqer AlasRa ¢o~putinq Center 12-dUN-199! 09=45 . NAN~ SERV UNIT SERVICE AP! AP1 AP! AP~ FIbE NUMB NUMB SZZE REPR PROCESS ID ORDER # bOG TYPE CLASS MO NUMB SAMP EbEM , CODE ...~:~ ~.,,~o~ ooooo ooo~ , ~ , ~ oooooooooo .,.._,o ~,~o~ ooooo ooo~ ' i , ,,oooooooooo ,.,. c,o ,.,,~o~ ooooo ooo, ~ , ~ oooooooooo ,..~ ~o ,,~o, ooooo ooo, ~ , , ~ oooooooooo ..o. ~ ~ ~.~o.~ ooooo ooo, , ~ , ~ oooooooooo .~., ~o ooooo ooo , , , oooooooooo ~¢"~ ~o~ooooo oooI ~ ReFT CSO PS ~Ps s4s oo ooo oo o t ! 4 oo,oooo0oo s'~-~ . ~ , ~eoo,ooooooo c~¢ ~ig o~s s4s~o~ ooooo oo o ~ ,~~ ~ ss~$ o,ooooooo ~ ~ ~ ~.,~O~o~ ooooo oo o ~ ~ ~ oo 0~ ~4848 ~ 0 ! ~00000~0 TENS CSG bB 205 0 000 O0 0 ! ! 4 es 90 ooo O0 I ! 4 00~000000o ooooo ooo , , , oo..ooooooo MTEM H?E~ . LB 548205 O0 -000. O0 O. ~ ! 1 4 -60~i0000000 DEPT CAb! Db' TENS DL[~ OR BGT DPH! bDT Ob8 bDT LL LSNV LDT bURN bDT MTEM~ bDT RTNR, CNL RCNT. N T WINO'N~T MTEN, NPH~,CSO NPOR ~ CSG CFTC. MRE8. CSG DEP~, CALI,DLL TENS.DLL GR.BGT DPH[.bD~ · ' bb, bDT bSHV,bDT bURH.~DT 4666 ~435 999 142§ -999 ~999 -999 -999 00 LL$, 32 CALI~ 00o 250 92 RHOB. ~24 OSS., i63 LXTH, 426 SSHV, i T~NS 01 SGR 46 URAN, 94~ ~4NG 4?6 ~RB$~ 2S0 R?NR~ 250 RCNT, 250 SGR, 25O DLL Dbb DL.L bDT bDT bDT bDT LDT bDT CNL CNL NOT NOT NOT NOT CSG CSG CSG CSG 4600,000 LL&,DLL 473 CAL1.DLb ~s~:ooo .~..o~ 999,2S0 CI.BGT ~0,275 RHOB,bDT 259 bXTH,bDT ~3~ $SH¥.LDT '~0 ~$0 1314 o 0 . O° ? 999. ~0 ~999. 0 '999.250 '999.250 .C2 BOT -SSi, bDT SIRH, bDT HTEN. bDT: TNRA~CNb- CNTC:CNb MRES, CNL CGR, NGT WiNG, NOT WSNO;NGT CS,NOT TNPH,CSG. RCFT.CSG CGR,CSG HTENoCSG -999 .0 1819 -999 -999 -999 -999 ,052 ~0 ~o $0 TENS Pgr~ TN': NPOR: CFTC: TNOR~ TENS~ HTEN, TNaA, NTC, 4, ~ bbO~Obb -8!'446 CABS. 6,~ SP,Dbb ,000 SOR 89. 76 MRES,OLL . -~.03799 HTEN~ 0999~50 C2.BOT ,250 TENS~ 111.,_ ~__ SSI,bDT .699 S82~ 5°473 SGR,LDT i20.203 TENS DLb DLL 4~..052' :'99 2'684 6,29~ 1455~000 35'429 33,:8~2 486,625 89,.4?6 1435,000 '-999;2$o '999.2$0 '999,250 Dbb DLL Dbb 946 BGT -999 bDT bDT 33~ bDT 30~ .bDT bDT 3755 156' 203 ~968 · 77 ~0~0 ,259 000 :hl. umberqer Alas!(a Computtnq Center MT~ ~ NP!)R DEPT, T NS; SHV; ~URH P~TA MTEM NPOR MRE8. CAbl T~N8 DPHI ~URH MTEM RTNR RCNT POTt W~NG MT~M NPHZ NPOR CFTC bDT CNb CNb CNL NGT NGT NGT CSG Dbb bDT bDT bDT bDT bDT · D? CNL NGT NGT CE,(]; Dbb Dbb BGT bDT bDT bDT bDT bDT bDT CNL CNL CNb NGT NGT NG?r 89 '476 3 038 i2 9 759 li0 203~ 946 96'8 6~ 855 644 89 4?6 -999 ::50 "999 250 '999 250 4500 000 37:205 5?5 ooo 2 0 '0 OS 1 188 146 107,729 976,977 .6.91 .9~'191 -999, ~0 4400 000 383~ 781 000 -999 2S0 24 560 0 Or4 202;538 1412,702 2,263 89,541 3.080 · ,349 O1 3~,274 89,541 -999 250 .,: MAES bDT TNPHCNb RCFT CNb TEN& CNb 8GR NGT URAN NGT W4NG NGT MRE$ NGT RTNR, CSG RCNT~CSG SGRCSG MTEM CSG LbS, DLL CALI,DLU MTEM,Dbb CX,BGT RHOB,LDT bXTH'bDT SSHV;bDT: CALX,bDT TNPH,.CNL RCFT,CNb TENS, CNL .SGR,NGT URAN,NGT ~4NG;NGT ~RES, NGT RTNR,CSG RCNT, CSG SGR,CSG MTEM,CSG CAb10bb MTEM Dbb C1BGT RHOB bDT 085 bDT LXTHLDT SSHV bDT CALX bDT MR~$.LDT TNPHtCNL RCFT~.CNL TEN$~,CNL SGRi,NGT URAN,,NGT W4NG..NGT MRES,NGT RTNR,CSG RCNT,CSG SGR CSG 0'03? 35,1!0 TNRA,CNb t20'03 194 CGR,NGT 15' W1NG'NGT .1.,934 O] CS:,NGT o; t? '999,250 TNPH.'CSG '999,250 RCFT.~:CSG ~999,250 CGR,CSG -999,250 NPH~, NL NPOR,~NL CFTC'CNb MTEM,:CNL TMOR, NGT W2NG~NGT TENS~NGT HTENiNGT TENS, 982 .SP:,DLb 079.375 S~R* Lb DRHO'LDT: 0'07? PEr,bDT 81RH:'bDT !*0 3' bSRH*bDT 1~14.;9970 .SSi'bDT 21~.890~i9' SS2.bDT ~,5~5 SGR*~DT ; TENS~LDT MRES~CNb '036 MTEN'CNL 10'. 729 CGR,.NGT 80~$60 HTEN*NGT -9~ 2'0 TNPH~CSG -999'.~$0 TNRA'CSG -9- 250 RCFT~CSG -999,250 CNTC,CSG -97 50 -999,250 -99 -999,250 HTEN,CSG: ,:303 89.476 6,385 3955,,000 .=946'968 :999~.250 . 999,250 ~8 3 953 )0 .9~6 ) 7 -999 ,541 MRES,Obb . 0'036 HTEN,DLL 983 -99~,250 C2,BGT -999;250 TENS,BGT -9.9i ,245 DRHO,bDT 3' *000 PEr*bDT t24,7~4 .-LS,.LDT 34" ,04 StRH.,bDT LSRH,LDT 44 0.056' HTEN,bDT 8~'021 36;611 TNRA,CNb 9~0 988 NPOR.CNL ..34,961 _427,29~ CNTC,CNL 126~.659 CFTC CNL 42{,E82 3835'000 MRES CML 1036 NTEM.CNU 89,541. 73,.349 CGR NGT 52 099 THOR.NGT 2,949 WtNG.NGT 242 912 W2NG~NGT 5.325 WSNG NGT 6 390 TKNS,NGT 3835,000 . 0.036 CS.NGT 193t:664 HTEN.NGT .983,02t 999,250 TNPH,.CSG -999;~50 TNRA:CSG 999.250 -999.250 RCFT,.CSG -999.250 C~TC,CSO ?99;250 -999,25o cDR cso -999.250 TENS, CSG 999,250 1:8 ?aPe verification L~tst~ng :~!umber;'er Alask:a Computing Center MRES' DEPT' TENS GR DPH! URH RCNT PPTA- MTEM, NPH!* NPOR' CFTc, MRES. ~TENS, ~UR~.. MTEM, POT4., W3NG. NPHY. NPOR, DEP?: TEN8 DPH!. LSHV ~URH Dr, t, ~D? t,D? LDT ~D? LD? CNL CNt` N~ CS(; CNt, ¢84 DLL DL, L BOT LDT LDT bDT bDT LDT '999,250 4300'0.00 3590,000 '999.250 '22~6!6 90'388 I 12,635 2~276 88'481 t050'640 9646! -999.2'50 II9 -999,{50 420~,000 ~0 34.9:2 -0 016 268 ~ 5 1413:{02 8~093 44~925 953.25? 1 349 19 149 88 44 -999 250 199244 003? 4100000 000 -999 250 53 ~32 0 02? 93.460 1415469 2716 CALt,DLt' MTEM,DLL C1,BOT RHOB,LDT Q&$,LDT LXTH,LDT 8SHV'LDT MRES, LDT TNPH~CNL RCFT:-CNt, TEN$;CNL &OR'NOT URRN;NGT ~4NG, NOT MRE$,NGT R~NR,CSG RCNT'CSG. SGR,CSG CALt,DLL' C1;BOT RHOB..LDT OS$:;LDT LXTH.t,DT &SHY;LOT CRLX,t,DT MRES~LDT TNPH~CN RC'FT, CN~. TENSiCNL 8GR:NGT ORAN, NOT W4NG~NGT NRE&NGT R?NR~C&G &GR, LLSDLL CAbi, Dbt, NTEMDLb CI, BGT RHOB LDT bXTHLDT $SHV:LDT CALX.LDT 12-dUN'1991 09'45 PAGE '999.250 HTEN,CSG 8e8481 .SP:,DLL '2 7 DRHO, )T' o,0oo ,947 'SiRH,LDT: ':36~~ &OR,t,DT · 036 HTEN,LDT 40,i09 TNRA~CNL _324'~99 ,ooo ,036 WSNG NOT ~999,.250 RCFT :999,250 · 999.250 HT£N -999825o '999 20~, 06 2 5~ 94~ IIi -9! CAL$;DLL .5'~925 PEF'LDT bDT 55 8$2'LDT 0.9 LSRH.LDT 3! 000 NPHX,CNL 44i547 NPOR~CNL CFTC,CNL ,640 'THOR;NOT W2NO.,NGT 87.~327 TENS"NGT ~580,0:00 TNRA:,C$O TENS,CSG '999,250 I',5~9 LLD,DLL 6,471 .:Se' -999,250 :-999:250 2. PEF:bDT 1,3,690 1315,341 SSi,bDT' 8~2 bDT 3t0~.802 ~2~I~0':0~67'139§ CN-.c,TN~A''LDTH?EN'&OR'bDT~---. 3580.000 MRES,CNL MTEM.~CNL 44.925 COR'NOT 49'~32 THOR~.NOT 6,349 ,,0~4 W$NG, NGT' 4,255 TENS.N~, 35,0,000 0.036 CS,NOT 1820.155 H?EN,.NOT 4.000 TNPH. CSG -999,250 TNRA*CSG 642.94t RCFT,CSG 205,~94 CN?C'CSG 4b.615 CGR,CSG 19.q73 'TENS-CSG 3490.000 87,535 HTEN,CSG. 99!,621 98 600 .642 ,844 -999.~50 O45 t3 619 6 t59 LLD' DLL .6085 '0 SP.Dbt, 10'0~3 CAt`S:&OR MRESoDLL '0.036 HTEN ¢2,SGT -999.250 TENS LB,bDT 293 bU SSi,bDT S1RH,LDT 441 852 t,&RH Obt, Db 99~ .bDT :bDT ~LDT t,DT 3570 442 965 035. 666 s ?aoe ver~oat~on L~st~n~ ~l~mbeFoeF les~e ¢o~t~no CenteF HTEM 5DT R~NT HTEN POTA NGT W~NG NGT MTEM NPOR,CSG CFTC, CSG DEPT CALl DLL TENS DLL · GR BT DPHIL~T OLS bDT bDT LURH bDT MTEM HTEN CNL POTA NOT W3NG NGT MTEM NGT NPH! CSG CFTC CSG CALl DLL TEN O L bDT OL$ bDT LL bDT bURg MTEM.bDT RTNR CNL RCNT CNL SGR CNL HTEN CNL DOTA NGT W3NG NGT NTEM NGT NPH! CSG NPOR;CSG CFTC.CSG 38 965 948 0 -999 21~ 037 4000 000 350~000 0 ! 3~ OB 85.8 ~ 0 4O 952 748 38 332 -999 ~50 0 0 3900 000 -999 250 '999 250 ~2SO -99g ~50 -gg9 '999.250 -999 250 -999,250 -999 250 -999 250 -999,250 -999 250 -999 250 -999 250 4 -99~ 218 228 MRES'bDT TNPH CNL RCFT CNL TENS CNL 8GR NGT URAN NGT W4NG NGT MR~& NGT RTNR CSG RCNT~CSG SGR, CSG MTEM CSG LbS DLL CALi DLL MTEM D~U C I BGT RHOB bDT Q, SS bDT GXTH GDT $SHV bDT CALX bDT MRE& DT TNPH RCFT' CNL TENS., CNL SGR,NGT URRN.NGT M R ES., RTNR,CSG RCNT,CSG SGR., CSG NTE~.CSG . bbs Dbb CAb1 ~TE~ C1 BLT RHOB bDT OSS bDT bZTH bDT SSHV bDT CALX ,bDT MRES .bDT TNPH~ rCNb RCPT~ ,CNL TENS~ ,CNL SGR; NGT URAN.NGT N4NG, NGT MRES.NGT R~NReC8G RCNT,CSG SGR.CSG 12-JUN-lg9! 091,45 0 36 49 ~62 3570 ~00 38 965 ~036 857 3,9 5O? i600 652 1316 90 '999.250 '999,2 0 '999,2~ 999,. 50 '999, 50 '999,250 '999,250 '999, 999,250 '999,250 '999,250 '999,250 '999'250 896 29.018 NTEN..LDT TNRA'CNL CNTC,CNL MRES'CNL CGR,NOT W1NG~GT WSNG,'NOT TNPH SG RCFT ~8G CeA CSG HTEN CSG LLD.DLb 'SP.DLL MRES,DLL C2,BGT DRHO,bDT bS.bOT $St.-.LDT SIRt DT HTr! ~DT TNR; ~N.L CNT( CO; ,N "T WiN( .NiT W~N( C~ ~NGT TNPH CS ReFT ~$~ HTEN CSG LLD.DLL SP.DLL MRES,.D~b C2,B T DRHO,bDT .LS.bDT SSI,bDT $iRH;LDT 8GR.bDT HTEN'bDT ?NRA.CNb CNTC~.CNL MRES,.CNb CGR~,NGT WING,,NGT WSNG~NGT ,CSG ~CFT~CS6 COR,,CSG 3 NP0RCNL 850 308 CFTC i::CNL- ..0 O36 MTEM CN 24 lot THO; 125 it86 W2N( .NOT 8 763 .60.520 30,625 , 0.036 TENsH'TEN:DLL 9~9'~50 0~05 183~442 i~!,bOT 72'393 ' ~LD:T 4~152 3'T65 NPORsCNL 843*:662' CFTC'C~L 0,0~6 MTENwCNL 40,5~16 THOR*NGT 12:$,8~I W2NG.NGT .... 2,,~]i0 TENS'NOT 1834,3{2 HTEN.,NOT -999,:2~0 TNRA,CSG 204W2~;:! CNTC',CSG 4,3:,4 TENS,CSG -999,250 SGR'DLL -999,250 HTEN.,OLL -999,'2$0 TENS.BLT -999 250 PEr,bDT -999 250 ~U,LDT -999 250 S$2~bOT -999 250 LSRH,LDT -999 250 TENS~LDT -999 250 -999 250 NPOR~CNL -999 250 CFTC.~CNL -999 -999 -999 -999 -999 O4 250 MTEM~CNL 250 THOR,NGT 250 W2NG. NGT 250 TENS.NGT 250 HTEN,NGT 250 TNRA,CSG 657 CNTC,CSG 5i9 TENS'CSG 54::808 458 044 2 493. 948 ~i ~, 34eo:ooo 16,452' 40.934 952'?48 '999'250 I6,6'42 i8o,eg? 11.9'$58 ooo '999;250 -999.250 :999 ]50 · 999 ]50 ~999 250 -999 ~50 "999 ~50 ""' !18 =999 -999 ~ 20 -999 2 0 -999 2 0 -999 250 3 662 000 IS ?aPe 'verification b~st~[ng chlumt~erger Alaska ComPuttnq center 12-JUN-199! 09t45, PAGE; !2 T~NS DbL .. L. DT · Lb bDT LSHV kD? LURH bDT NTEM bDT RTNR CNL ECNT CNL SGR CNL H~EN CNL W3NG,NGT M?EN.NGT NPHI;CSG NPOR.,CSG CrTC.CSG M~ES,CSG D~PT' CAL~I.D:bL DPHI,:LDT OLS.LDT Lb. LOT LSHV.LDT bURH.LDT MTE~;LDT RTN~.CNL R~NT,CNL 8OR, Nb HTEN.~NL POTR~NGT N]NG'NGT NT~N,NGT NPOR.CS~ CFTC'CS~ ~RES.CSG DEPT' CALI,DbL TENSeDLL GR.BGT DPH~,bDT OhS,bDT bb,bD? LSHV.bD? LURH.LD? o.o37 3500,000 *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 44 860 -999 250 229 248 0 037 ?oo,Ooo '999.~250 :999,250 999*250 ~-999,250 -999-250 -999 SO -999 ~50 -999~ SO -999 250 -999~50 -999,~50 ~999~250 -999 250 52 242 -999 250 40 3600 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 MTEN,CSG CAL1,DLL MTE~*DLb CI,,BGT RHOB,bDT GSS~LDT bZTH*bDT SSHV,bDT CALl bDT MRESbDT TNPH CNL RCFT CNL TENS CNb SOR, NOT URANNGT: W4NG. NOT ~RES, NG' R~NR~C8~ RCNT:CSG 8GRi LbS, Obb CRL1,DLb MTEM' bDT OSS.,LDT L~TH,,,DT CALi~LDT MRESbDT TNPH~CNL RCFT, CNL SGR, UR~N~NGT W4NG, NGT NRESNGT RTNRiCSG RCN?CSG SGR. CSG MTE~.CSG LLSDLL CALt:DLL MTEM, DLL Ct. BGT RHOB.~DT 0S$ bDT SSHV~bDT C~LI LOT 86,534 '999.2!,0 '999.2!~0 -999~2~0 '999 '999 -999 2~0 -999 2!~0 -999 2!~0 '999.250 3,~86 28,06 85 845 -999. -999, '999. -99~. '999, -999.. -999, -999. -999' -999. -999' -999. -999. HTEN'CSG 891.003 MRES'DLL: :C2,BGT 999,25 DRH'O;bDT LS'bDT -9 ,250 SSl~'b~T ..~ SiRH,LDT -' SGR*b.i,T HTEN,bDT '! T~R~; ~NL' -99! MRES* Nb CGR, CS~NOT CGR, SGR'DLL -999 0 HTEN;DLL '999 0 TENS,,BGT -999 0 PEr'bDT -9~ ;0 LU'LDT -~ '.'8$~'LDT '99 ~SO LSRH,bDT '999 0 TENS,bDT '999 NPHX'CNL -99! ;0 NPOR.,CNL -99, iO CrTC,CNL "-9, MTEM:oCNL '9' 50 THOR*NOT -9* ~0 W2NG"NGT -( 0 ?EN$;NGT '~ 0 HTEN'NGT '9~ 0 TNRA'CSG CNTC'.CSG TENS*,CSG !50 LLD'OLL .999.250 CAbS:,'Obb .999:,,250 !~0 SP, Obb -999,'25o .$GR~DbL :-999,250 MRES',ObL~ -999,250 HTEN~OLL -999,~250 i'! C2;8GT -999,250 T'ENSi,..BGT :'999,250 DRHO*LDT: '999;.250 'LS*LDT -999.250 LU~.LDT :999.,250 ii~ $$:t'. bDT -999.: 250 SS2~ i, bOT 9'99,: 250 'SiRH,bDT -999-250 bSRH~,LDT "-999,250 !~0 SGR,bDT -999,250 TENSi,bDT :.999~250 !'~0 HTEN.,LDT -999,250 NPHii,CNL --999,250 ! 0 CNTC'CNL: 999,250 CFTC'CNL -999,250 MRES*CNb -999.~50 NTEH,CNL -999,250 CGR,NGT -999.250 THOR.NGT -999,250 ~50 NING, NGT -999,250 N2NG, NG~ '-999,250 !50 NbNG, N~T -999,250 TENS,NGT -999,250 !50 CS~,NGT -999,250 HTEN,NGT -999,250 900 TNPH,CSG. -999.250 TNRA,CSG 4,268 87 48~ RCFT.,CSG 194'2t0 CNTC,CSG 812,063 CGR'CSG ~35.905 TENS;CSG 3310'.000 4t2 HTENeCSG 868,~83 '50 LLO,OLL '999, 50 SP.Obb -999: '50 MRES.DbL -999, bDT -999 -999 '50 SSt,bDT -999~ =50 StRH*bDT -999~ 50 SGR.bDT -999 25 SGR,DLL 250 HTEN.DLL TENS,BGT 2SO S~Q;bD? 25O 250 TENS.bDT -999:250 "999~250 ~999,250 '999,'250 '999,250 '999~250 '999~250 '999~50 "999 250 IS ?a~e Ver~oation L~st~nq :hlO. m er Aleslca CompUt~nq Center qer 12-dUN-J991 09t45 !3 RTNR,CNL RCN?.CNL HTEN,CN~ W3NG,NGT NPDR'CSG TENS DLL OLS LOT Lb bDT bSHV bDT' LURH bDT MTEM LOT RTNR CNL R~NT CNL SGR CNL PQTA.NOT W3NG NOT MTEN NOT NPH'! CSG NPOR CSG CFTC CSG DEPT T~NS,Db~ .,bDT OhS,LOT bL,LDT LSHV,bDT LURH.LDT MTEM LOT RTNR CNL RCN? CNb SGR CNL HTEN CNL POTA NOT W3NG NOT MTEN NOT NPH! CSG NPOR CBC CFTC CSG -99g,250 *999,250 -gg~250 '9g'g,250 -gg9;250 '999,250 '999:250 '999~250 'ggg~250 '999:250 '999~250 '999~2 0 ~999~ '999~)50 ~999.~250 -9~99~250 '999.~250 ~999~250 '999~250 '999,250 '999~250 -99g.2S0 46.g21 -ggg.250 175',634 0.039 3400.000 '999~250 '999 '999~ 50 '999.250 '999 250 '999 250 '999 250 '999 250 '999,250 '999,250 '999.250 :999,250 999~250 '999,250 '999~250 49.279 '999.250 191.496 MRE$,,LDT TNPH:CNL RCFTCNb TEN$:CNb SGRNGT URAN NOT W4NG NOT MRESNGT RTNRCSG RCNT:CSG SGR,CSG ~T~ CSO C.ALI~DLb MT~N.,DLL C~.~BGT RHOB. bDT 0SS~bDT LZTH,bDT 8HVabDT AbI,LOT MRES, bDT: TNPH,CNL RCFT~CNb TENS. CNb 8OR.NOT URAN~NGT W4NG. NGT MRES, NGT RTNR,CSG RCNT~CSG SGR,CSG MT£M,CSG CALl Dbb ~TEN C! BGT RHOB bDT ~S&LDT bXTHi,bDT SSHV:bOT CAb! bDT ~RESbDT TNPH CNL RCFT~CNb TENS.CNL SGR~NGT URAN~NGT W4NG..NGT MRESiN6T RTNR..CSG RCNT,.CSG SGR CSG ,~50 TNRA -g9~..250 CNTC -999,250 MRES '99g,250 CGR .999.250 WtNG :99 ;250 WSNO gg~,250 CS ,636 TNPH ~;903 RCFT ,567 CGR 84,630 HTEN N b GT NOT NT C O -999,250 NPOR CNL' -999~250 CFTC CNL M~E~ CNL -999;:~50 -99g,250 THOR -ggs,~50 TENS -999'250 HTEN ! ! 3 CNTC 069 NGT NOT NOT NGT -ggg~ ~ggg': 'ggg~ ~ggg, 'ggg~ -ggg~ 'ggg= -9gg, .83$' '3255. 50 $0 25O 250 000 :999:250 LLD.DbL: -999,.~50 gg9:250 SP,D'bL -gg9.~'$O SGR,DLL ..999.250 .2 0 MRES.D~L -999 ~50 C2,BGT DRHO,bDT -999',~:$0 PEF.*LDT '-999 .250 ~999:2 0 -999.250 :.U~LDT .999 2~0 LS,bDT SSI,bDT -999,250 $~2;LDT '999.2'50 -ggg:250 -999 250 'SIRH,'LDT -gg~250 LSRN*LDT .-ggg~$O TENS*LOT )~ :99g.'250 :;.~9 SGR,bDT -999.250 NDH1,CNL :.'999,:.250 HTEN*b. DT -ggg,~50 NPOR,CNL :~9~ ~ .RES,C~b -.999;.25~ .TE.'CNb ,~-999;2'50 WtNG.NGT -999,250 W2NG-NO~ . 4 TNPH;.CSG -999,=250 TNRA~CSG. 57 !!~! CGR'CSG 26,269 TENS.CSG 235,000 83 ~,86 HTEN,CSG .925..567 -999 250 ~D'D~ :999'250 CAbS°Ob~ · 999;25'0 -999 25O 999~250 ~R~,D~ -999~250 H~N.Dbb -999'250 ~999 2~0 8P,D~ ~GR,D~L -999'25O 999 2 0 C2,8GT -999.250 TENS.SOT -999,250 -999 ~ DRHO.bDT -999.250 PEF.LDT 0999*.250 -999 L$,LDT -999,250 LU.LDT "999,250 0999 2 0 SSl,bDT -999.250 6S2'LDT :-999,250 -999 250 SZRH'LDT -999,250 bSRH*bDT -999 250 SGR,bDT -999,250 TENS.bDT :-999'250 -999 250 HTEN,bDT -999'250 NPHZ,CN~ .~999~250 -99g 250 TNRA,CNL -999 250 NPOR,CNL 'ggg,~50 250 MRES.oCNL -999 250 NTEN.CNL -999~250 °999 250 CGR,NGT -999 250 THOR,NOT -999,-250 -999 250 NtNG.NOT -999 250 N2NG,NOT -999,250 -999 250 WSNO,NGT -999 250 TENS~NOT -999,250 -999 250 CSoNOT -g99 250 HTEN~.NGT 0999,250 73~ 583 TNPH,CSG -999 250 TNRA~.CSG 4'!06' 25 2)9 RCFT,CSG 153 745 CNTC;~CSG 734.0?4 CGR.CSG 30 248 TENS,,CSG 3230.000 :hlumDerqer Alaska ¢omput . DEPT CAb! DbL DPH! bDT OLS bDT bURH bDT MTEM bDT RTN~ CNL RCN? CNL SGR HTEN P~T:A W3NG NOT MTEM NOT NPH! CSG CFTC CSG ~RES TENS ~DT bSH¥.~DT NT£M bDT RTN~ CNL ReNT CNL 8GR. POTA.NG? WING.NO? NPH~,CSG NPOR.CSG CFTC~CSG NRES.CSG DPHZ,LDT OhS,bDT LSHV.LDT LURH,LDT 0,039 _ 000 bLS 250 CAb1 -250 MTEM 25O 250 RHOB ~$0 SO 088 LiTH 250 SSHV MRES 250 TENS 250 SGR 25O URAN · :·04 R?NR 25O RCN? 24? SGR O39 gg -ggg -g~g -g~g -ggg -g~g -ggg 999 :ggg ggg -ggg -999 -999 -999 -999 46 -999 222 0 3200 '999 'ggg o999 'ggg '999 '999 '999 '999 '999 '999 '999 '999 '999 ~999' '999. '999 56 '999 3100 '999 '999 '999 '999 '999 '999 '999 '999 000 .bbS~ 250 CAbl', RHOB SSHV CAb! ,50 50 MRES, 250 TNPH, 250 RCrT. 250 T~NS 250 SOR~ 250 URAN~ 250 W4NG~ 250 MRES 324 R?NR: : 50 SGR~ 87 RCNT~ 040 MTEM 000 bbs 250 CAb1 250 MT~M 250 C1 250 RHOB 250 OSS 250 LITH, 250 SSHV~ 250 CAb! DbL DLb DLL- bDT bDT bDT bDT :! D? Nb ~b C'SG CSG CSG DbP DLL Db bDT bDT bDT bDT CNb CNb CNb NOT NOT NOT NOT CSG 8G CSG Obb DbL DLL BGT bDT bDT bDT bDT LOT 82,586 HTEN.CSG 913,'699 -999 .999 -999 .999 -999 .999 -999 -999 '999 '99'9 '999 o999 '999 '999 'ggg '999 '999 8 0 0 0 0 0 0 '0 0 So L.LD, DLL SP.,DLL MRE$,DLb C2,BGT DEHO.~DT .bS~bOT ,SSi, bDT $1R~,bDT SGR, LDT HTEN.bDT TNRA CNb CNTC CNL MRES CNb CORING? WING, NOT W5NO~NGT CSG RcrT 8G CGR HTEN CSG -999 -999 -999 -999 999 -ggg -ggg -9,99 -99 -99 50 5O 50 50 .~50 50 ~50 25~ CAL.$.DLL .SGR*DL.~ HTEN.DLb TENS,.BGT PEr. bDT LU;LDT 8S2,bDT SRH.bDT ENSabDT NPHZeCNL NPOR,CNb CFTC.CNL MTEN,,CN THOR~N~ W2.NG.:,NGT TENS~NGT HTEN~ CNTC~CSG T'EN$~CSG -999: 0 '999~ 999, 5 -999~ -999~ 0 -999:50 =999~ 50 ' O0 45,~6 80,044 LLD,DLL -999 :oh '"' N -999 · 2, BGT 0999 DRHO.bDT 0999 *$'bDT -999 HTEN.,L~? 999 CNTC, C L* MRE8.~ -,99 CGR, ~ -999 WiNG, NOT -999 WSNG.NGT -999 CS;NOT TNPH,CSG -99! RCFT,CSG CGR,CSG , 50 $0 250 250 250 CAbSi,Dbb 'SGR,,DbL HTEN,DbL TEN$,,,BGT PEr, ~LDT $~U:.*bDT DT NDX~CNL NPOR~ NL CFTC~NL MTEM,CNL THOR,NOT W2NG~NOT TENSING? NTEN'NGT TNR~,CSG CNTC,C~G TEN$'CSG -999.250 LLD,DbL '999,250 CAbs*Obb -999'250 SPeObb -999,250 SGR.DbL '999,250 MRES,DLb -999,250 HTEN,DLb -9990250 C2,SOT -999,250 TENS'BGT '999~250 DRHO~bD? -999,250 PEr'bDT -999e250 LS~bD? -999~50 bU~bDT ~999,250 $81~bD? -999,250 689~LDT 999e250 81RH~bDT -999,250 bSRN.bDT '999,250 SGReLDT -999.250 TENS.bDT '99! "gg! ogg! -g9999 150 '999 ;0 o999 150 °999~50 :'999'250 :'3~25,000 o999,;:250 -999'250 o999~250 '999'250 -999,250 '999~250 -999~250 .999~250 4'492 .784'6i6 3185,000 -999. -999&250 -999,250 -999,250 o999,~50 :999,2S0 .9991250 999'250 =hlumber~!er Alastcs. eomput center R?'NR CNL ReNt CN~ iGR HTEN, CNL POT~i.NG~ W)NG, NGT M'TEM, NGT CFTC,esc DEP? e~! DbL GR BGT DPH! LDT OhS .DT Lb .~DT LUR bDT MTE~ bDT R'TN CNL ReNT CNL SGR HTEN CNL W)NG NGT MTEM NT NPOR esG CFTC CSG MRES CSG DEPT c~bx DLL TENS DLL LDT GLS bDT LL LDT LSHV LDT LURH LDT MTE~ LDT RTNR CNL RUNT UNL SGR CNL HTEN CNL P~TA NGT WING NGT MTEM NGT NPH! CSG NPOR CSG CFTC CSG '999.250 '999.250 '999,250 '999-250 '999 250 '999 250 '999 -999 ~50 -9~ 399 250 18A 650 04! 30O0 O0 -999 -999 ~0 0 w999 -999 ~00 -999 50 '999, 0 -999'~50 -999. 50 -999 -999~ 50 -999 59 -999 2~60 169 656 0 042 900.000 999, 50 .999~$0 999.! -999** 50 50 -999 250 -999 250 -999 250 -999 250 -999 -999 5O -999~50 -999 250 54 139 -999250 175 5)9 MRES bDT TNPH, CNL RCFT CNL TENS CNL 8GR NOT URAN., W4]NGi N T MRES, NGT RTNR~ CSG RCNT~ CSG 8GR~ C G bbS~ Lb CALl MTEM DLL LDT OSS bDT LITH bDT SSHV LDT CALX LDT MRES~LDT TNPH, CNL RCFT,CNL TENS,CNh SGR ~ NGT URAN'N~T ~4NG~ R~NR~CSG RCN~ 'SGR~CSG MTEM'CSG LLS: DLL CALl DLL MTE~ DLL C X BGT RHOB LDT G86 LDT LXTH~ LDT SHV LDT ALZ LDT MRES bDT TNPH CNb RCFT CNL TENS CNL SGR NGT URAN NGT W4NG NGT ~RES NGT RTNR CSG RCNT CSG 8GR CSG '999. 50 '999, 50 "99'9, 50 '999. 50 '999, '999; '999, !~ '999. 0 -,~99 50 '999 -999 50 '999 50 '999 50 -999 -999 -.99 9 50 50 -99 50 -99; 50 -99 -99'~ 50 -99 50 0 -999 250 '999 0999 ~ w999 0 '999 0 :999 250 999 25O -999,250 0 '999, '999,250 ~999~2 0 592 35,46! HTEN,i CNTC, Nb MRES,CNb COR,NCT WtNG, NGT W5NG~N~T RCFT CsG CGR SG HTEN b DLL DLL MR DLL DR bDT LDT 8~ bDT bDT bDT bDT NL CNTC ~NL MRES CNL CGR NGT N T 'WING N~T WSNG RCFT CSG CG~ SG HTEN LLD, DLL SP Obb MRES DLL C2 BGT DRHO .bDT bS bDT SSt bDT SIRH bDT SGR bDT HTEN bDT TNRR CNL CNTC CNL MRES CNL CGR NOT WiN( NOT WBN( NOT C~ NGT TNPH~.CSG RCFT~CSG CGR,CSG ... :~99.,250 . 99,250 NPORt ~999,250 CFTCi 999,:250 -999.250 THOR~ :999,:250 N2N~ 999-250 -999.250 TNRA~ 153,417 CNTCi 2~'832 TENS'~ 935'548 -. iO I : 9 092 '999;250 CAL8 -:999,25~ soa -999'~50 HTEN -'9 ~-~50 TENS .,, -999'25o .999. ,o .,,, ,,,, -999 250 NPH! -999 250 NPOR -999 250 CFTC -999 250 MTEM -999 250 THOR -999 )SO W2NG -999 50 TEN8 -999 250 HTEN -999 250 TNRA i?O 49! CNTC 39650 TENS CNb -999'250 NL N::b -999,250 '999,250 CNL :-999,:250 NGT ~999,250 NOT '999-250 NOT '999*250 NGT :-999:':250 ;eso .o4,277 ~8O ~t30,000 CALS-DbL SGR,.Db~ H~EN,DLL TEN.&*.BGT 'PEF*bDT LU':LD'T :'SS2'b. OT LSRH,.,LDT NPH{,CNb NFO .,CNL .CFTC!CNL MTEM~:CNL T80~: NG~ W2NG' TENS NGT HTEN N.~T TNRA CNTC TENS Dbb DLL DLL BGT bDT ,bDT bDT bDT LOT :CNL CNL CNL ,CNL ,NGT ,NGT ~NGT ,NOT .CSG ,.CSG 14 3 ooo ,.999:~ t, 50 '° iO '9 ' ..9~= '9 ""*9 -9 '999 4:3'/2 668 2985 ~000 hlumberqer Alaslca ¢omputl~.~ Center TENS,DbL GRoBGT DPH~'bDT ObS~LDT Lb.'bDT LSH¥.,LDT LURHObDT MTEM.bDT' RTNR;CNL RCNT.CNL POTA~NGT W3NG'.NGT M~EM~NGT N'N~,CSG NPO~'CSG CFTC,C$~ ~RE8,CS~ 0,041 MTEM;OSG 76.~72 "TEN'CSG 892,143 28000000 LLS'*DLL -999.~250 LLD.DLL: '999'~50 -999 -999,.250 CALt'DLL ~999.,250 SP,OLL. . .250 ~R.Obb -999,250 MTE~,DLL .999:,~50 MRES*OLL .999.,250 HTEN,DLL *999.;250 Ci*BGT 999.250 C2,8GT' ~999.2.50 TENS*BGT ':999,,250 RHOB.LDT *999-;250 DRHO;'bDT :999'250 PEF"LDT .999.,2S0 OSS, LDT :999,250 b8 bDT ' 999,"250 :LU,LDT .999;25'0 LITH'LDT .999'250 .881.~ bDT ~999,250 882.LDT .999,250 8SHV~bDT .999.250 81RH.~ bDT 999.250 LSRH'bDT ~999,250 CALX,bDT 999.250 ;999.250 ~RE&,,bDT -999.250 H~:bOT'bOT'b -999,250'999'E50 ~ENS'bO~ 999,250 TNPH,CNL -999..250 TNRA.~ CN. -999,259 NPOR*CNL. -999,.250 RCFT,CNL -999.250 'CNTC: CML '-999,250 *999,250 SGR,NGT -999.250 CGR~N TNGTG -999;,~50 THOR N T -999,250 URAN~NGT -999.:250 WiNG -999,:~$0 W2NG~,' GT '*999.250 W4NG,* NOT 0999,250 WS~ ~,,NGT -999,250 :TEN&*NGT -999.,250 MRES*NGT ~999.250 ' NOT -999,:~50 49.534 RTNR.* CSG 4.979 TN~CSG 0999*250 :o.o42 '?,.,,9 DEP?',: 2700"000 bbS;DbL C~LI..DbL "999,250 CALi'DLL T NS,'DLL -9990250 M'T£M~DLL :GR'BGT -999,:250 OLS'*LDT "999'250 OS&bDT Lb.bDT "999. -999 $SHV~,LDT LSHI.LDT -,50 bDT bUR ~LDT -999 250 CALX.~LDT MT:EM.bDT -999 250 MRE$,LDT' RTNR.CNL *999 250 TNPM, CNL R~NT.CNL -999:2S0 RCFT~CNL -~99. 250 TEN& ~GR~CNL CNL HTEN;CNL -999 250 SGRi,NGT POTA ~NGT -999:250 URAN~ W~NGNOT -999, 50 MTEM NOT -999.~50 NPHY CSG . 51;018 NPOR CSG 99902 0 CFTC,CSG 189,376 MgES.CSG 0.042 DEPT., ~600,0 0 TEN$'DLL -999;250 GR~BGT -999.250 DPHY.LDT '999;250 QLS.LDT '999o250 -LL.LDT :999.250 LSHV.bDT .9990250 LURH.LDT 999.250 NGT W4NGNGT RTNR CSG SG MTEM,CSG bbg~Obb CALi,DLL MTEM~DLL C!.BGT RHOB.LDT GSS. bDT bXTH.bDT $SHV.LDT CALX.bDT -999 -999 "999 ~999 -999 -999 *999 '999 "'999 *999 '999 4 86O 74 *999 -999 -999 -999 -999 -999 -999 -999 -999. .C:~,BGT -999 ~0 fS$:L,,:bDT S~RI{i.LDT SGI~.LDT · .. '50 I 0 TNR,~,.CNL CNTi:~CNb MRES~.CNL I CGR~,NGT' -9! 0 WiNG.,,NOT WSNG~NGT ~$0 CS,ROT 273 TNPHvCSG -9 98? RCrT,CSO 204 86~ CGR,CSO 44 823 H?~N.CSG 905 ,250 250 250 250 ~$0 ~50 ~$0 .. MRES.ObL C2,BOT DRNO.LDT L$.LDT SSi.bDT $1RH.bDT SGR.bDT ~50 HTEN~.DLL PEr,:LOT YEN$,LD? ~$O THOR,NOT ~I~ W2NG-NGT TENS, NOT ~50 HTEN,NGT ~50 TNRA'CSG 657 CNTC.CSG 43~ TENS.CSG °999 250 -999 250 SGR~OLL :999 250 HTEN.OLL 99 -99~ ~50 -999 ~$0 -999 tS0 -999 250 LSRH.LDT -999.250 TENS. bDT "99! '9 lO "9 '9 -9! iO .,~ i0 ,,' ~0 -i ~0 i'O '99t -999 .'*999 -999 ':-999 ' · 2955 .000 "999:250 '999 250 "999 250 "999 -999250 -999250 -999.250 -999 250 =hIumberqer A~es~e Comput ~qq Center 09=45 RTNR CNL RCNT CNL POTA NOT W3NG N ? MT£M NDHICSG NPOR:;CSG MR'ES.CSG OhS bD? bSHV bURH bOT' MTEM bDT RTNR CNL RCNT :CNL H'TEN,CNL 'POT~*NOT W~NG..NCT CFTC* DEPT ?EN8 Dbb DPH! bDT OhS;bDT bb. LD? bSHV~bDT LURH.bDT NTE~ bDT RTN~ CNL ReNT CNL SGR H~EN CNL P~TA NGT W3NC NOT MTE~ NOT NPOR CFTC CSG -999 250 -999 250 -999 250 -999 250 ~999 250 -999 250 -999 ~50 -999 39 467 -999 250 22'7 0 043 2500 000 ~50 '999 ~50 -999 -999 '9 -9 250 '999 2 0 '999 ~999 -999 ~&3 '9~50 18'I 0 044 2400,000 -999.,250 '999~250 . 67,~68 -999..2S0 99,2So '999,250 -99 .99~.250 ,250 '999.250 '99 .99~.250 ,250 -9990250 '999,250 -999 -999e250 -999~250 -999.250 MRES bDT TNPH CNL RCFT tnb TEN$CNL SGR NOT URAN NOT W4NG NOT MRES NGT RTNR CSG RC~T CSG MTEN bLS DLL CAb1DLL NTE~ Dbb C'! BGT RHOB bDT 98S LOT LITH bDT $SHV bDT CAb! bDT MRE$ hOT TNPH CNL RCrT CNL TENS CNb SGR NOT. URAN NOT W4NG NOT MRES ~GT RCNT SGR CSG ~TEM CSG bLS,DLb CAL1,DLL MTEM.DLL CI,BGT RHOB.bDT OSS bDT LXTH bDT SSHV bDT CALX bDT MRES bDT TNPH CNL RCFT CNL TENS CNL SGR NOT URRN NGT W4NG NOT MRES NOT RTNR CSG RCNT, CSG SGReCSG -999 -999 -999 .999 999 -999 '999 -99i -99! -9 -9 ~9 '99 '9'9 '99 ~50 ~50 ~50 ~50 ~50 ~50 ~7 ~09 960 HTEN bDT TNRA CNL MRES,, CORING? WING N~T WSNO, TN~.''NOT Cso RCFT 250 b~D,Obb "550 *. P, DL bDT ,2~ 0 'SiRH,LDT 2; ~0 SGR. 'Dr 2~0 CN~C.CNb · ,~l ~0 MRES,,CNL WbNG. 2~ ,0 NOT ~N~H~ H~EN.CSG -9~ 2~0 "9 250 -99 * 250 '99 " 0 '9 2 0 25O -99 25O 25O 25O 25O '999 250 -999 250 -999 250 Obb MR~$ Obb bDT LS bDT SS1 bDT S1RH bDT SGR bDT HTEN bDT TNRA tnb MRES CGR NGT ~NG NOT ~5NG NOT CS NOT ~NPH CSG RCFT CSG CGR CSG -999,.25.0 NPOR,.: -.999,2 -999;25~ THOR -! 9, W2NG, -999.25 HT'EN~ 9!~:~§4 TENS. 999 tnb -. ,250 i NL 999,250 :Nrb '999',250 'Nb '-999,:250 NOT :999,250 N~ 999,,2 5 0 8 2935,0 0 50 T~NS,BGT -9' ~ HTEN.DbL -~ PEF*bDT .~i :.50 !,o ~ '~50 bARH*bDT -9! TENS.LOT -9' ~0 NPHX,CNL 250 NPOR.CNL C'F'TC~CNL :MTEM~CNL -9' ~ THOR'NOT -999;: W2NG.NGT 15,48 944'26~ TEN6 -999 '999 '999 150 w999 0 '~ iO "99~ 0 '"9~ 0 ~-! 0 '-! 0 :'999~25:0 2920,000 -999 250 cAbs'Db -999 250 SGR Ob~ '999' -999 250 H?EN Dbb ~-99~ 08 ;2~0 PEr bDT "999,250 -999 '999,250 -999.250 S~ LOT .bDT '"999,.2~G0 ~0 ~DT "999,.2] ,250 -999,250 H.H' CNL '999,2J0 999.250 NPO~ '999;2150 -' CNb -'999 250 CrTC.CN~ "999~250 -999 250 HTE# CN~ '999~-250 -999 250 - ' 999,=!50 THOR HOT -999 ~ 50 N2NG NOT "999&250 -999 ]~ TENS NOT 5O -999 250 CNTC.CSG "99 ~50 -999 250 TENS CSG -999 chlumberqer las~e Computino Center T£NS.DbL H~;bOT ~$HV~bDT bURH{bDT MTEM,bDT RCNT.CN~ 8GR.,CNb POTA~NGT W]NG,NGT NPH~,CSG NPOR.CSG CFTC., · 'GR BGT DPH~ bDT ~b$ bDT LURH. bDT MTEM;bDT RTNR"~Nb RCN?.'Nb ~SGR;CNL HTEN,CNL D~TA,NGT W,NG,INGT MTEM;NGT NPOR.CSG CF?C.CSG MRES*CSG DEPT' C~b~.Dbb GR,BGT DPH~.~DT ObS,bD? bSHV.bDT bURHe~DT ~300000 999250 -999 '999 250 '999 2S0 -999 250 .999 250 -999 250 ,999 "999~250 -999,)~0 '999-".0 '999,250 -999.250 -999,250 -999,250 ~999'250 999~250 55,094 -999~50 ~999.~250 '999~:250 '999,250 -999,250 '999.250 -999.250 '999~250 -999.250 -999'250 -999. -999; -999~25~ -999,250 -999.250 -999,250 2!~0.000 -999 250 -999~250 250 -999~250 -999 250 -999 250 -999 25O bb$;.Dbb MTEM,DLb CI',BGT RHOB~bDT QSS~bDT bITH~bDT $$HV~bDT CALl,bDT ~RE$.bDT TNPH*C~b RCFT'CNb TEN$:'CNb URAN,NGT' W4NG.,N~T RTNR'CSG RCNT~CSG $GRICSG MTEM,CSG C~bl'Dbb MTE~,Db RHOB,bDT USS;bDT bZTH, bDT 8SHV~bDT NRE&'bDT TNPH~NL RCFT,.~Nb T~bR~NG? URAN~N~? W4NG,NGT MRE$.,NGT RTNR~CSG ~CNTICSG SGR,CSG MTEMeCSG. bb$lDbb CAbi'Dbb NTEM,Dbb CI,BGT RHOB.~DT OS$,bDT b~TH,bDT $$HV.bDT CAbI.bDT -999,250 HTEN,¢$G '999"~50 '999.250 bbO*Obb '9991 CAb$,Dbb '999,250 8P, D~L -999~ $GR,Dbb '99'9.2~0 MRE$,DLL -999. HTEN,~T . !2,891 C2:;BGT TENS, 999,250 bS.,bDT '999.250 SSI,LOT "999,250 HTEN:,'bDT NPH~,CNL -999,250 TNRA;~CNL -999'.250 NPOR,CNb -999.250 CNTC~CNb -999,.250 CFTC~CNL -999,250 CGR,NGT' 50 THOR~.NGT -999.,.2~0 WING,NGT .-999~250 W2NG*NGT -999:'250 WSNG,,NGT -999'250 .TEN$'NGT -999,2~0 CS~NGT "999'~$0 HTEN,:NGT -999,250 -999,250 RCFT~CSG -999,.250 C.NTC~CSG '999,250 CGR'CSG: -.999,~50 TEN$"CSG '999,250 HTEN,CSG. -999~.250 -99') -99~) -'999. ~999 999~ -999 .999; .999 -999 -999 -999. -999 -999. -999 -999 -999 -999 -999 -999 0 ~0 0 25O 250 250 05 250 25O 250 250 Obb MRES;DLL C2.,BGT DRHO,LDT US.bDT SSi'bDT S1RH,LDT SGR,bDT HTEN,LDT TNRAeCNL CNTC,CNb MRES,CNL CGR, NGT WING, NGT WSNG, NGT C$~NGT TNPH:CSG RCFT~CSG CGR, CSG HTEN~CSG LLD.,OLb SP:DLL MRES DLL C2:BGT DRHO:LDT bS~bDT SSi, bDT SIRH bDT SGR bDT ~ 0 SGR'DLL TENS,BGT -999, 25 LU'LDT - .! TENS'bDT NPOR, CFTC:' N~ :999 0 TENS. NOT .999 999 ~ HTEN~NGT TNRA,CSG '999 ~ CNTC,CSG '999 TENS,CSG -999 250 LU~ bDT -999.255 852 LOT :999:2S0 999 25o -999 250 -999 250 "99 250 129 ~0 -99 ='9! :"9'! i:0 ': ,0 ~0 }0 '99 ~0 '99 1.,~, '9' '9! "999 '999 "'99 '999~;250 -999'250 .999.250 '999,250 -999~250 -999 25 1X75,00~ -999~250 *-999,250 -999~ 0 0 :hlumDe e r Alaslca Computlnq Cente SGI · CNb HTE]., CNh POTA,NGT W3NG, NG~ MTEM., NG? NPH~, C;SO NPO~.*,CSG CFTC,CSG MRE8, CSG TENS,Dbb . GR, BGT DPHi, bD~ GbS, b.D~ b&HV.bDT bURN ,~DT H~EN PDT~, W3NG ~NGT MTEM NGT N~Oe C8 C: TC ,CSt M ES ~CSG DEPT., CAL~ TENS )Lb GR ~GT DPH~ .bD~ Qb8 bD~ LURH~ bDT MTE~.bDT RTNR, CNL RCNT. CNb 8GR,CNL H~EN~.CNb POTA · NGT W3NG.NGT NTEN~NGT NPHI'CSG NPOR~CSG CFTC,CSG '999~250 -999250 -999 ..50 '999:~ 0 '999. ~0 '999,250 'o999.,250 -999,250 2000;000 '999,250 o999,250 ~0'5~ 0999,250 :999'250 999;25O 0999,250 1999.;2.0 :o999,150 0999.250 '999250 "999 ~.50 '999 0999 '999 ~50 1900'000 "999.250 o999.250 -999 250 -999 250 '999 250 '999 250 '999'~50 '999 50 '999250 '999 250 '999 250 0999 250 '999 2 0 -999 2~0 "999 250 -999 250 -999250 TNPH., tnb RCFTi CN SGR~ NGT DRAN~,, NGT W4NG~ MRE$~ RTNR,i CSG RCN?~CSG SGR ,CSG MTEM ~CSG, CA b i, Db b MTEM, DLL C ~, :BGT RHOB,L. DT GS&i LOT bETH*LOT SSHV i bDT CAL, Z~LDT MRE&;LDT TNPH~ ,CNL RCFT~ CNL TENS~ CNL 8GR~ NGT UR~N~ NGT MRES R~NR~ RCNT .CSG &OR:: .CSG CAb I,DLL MTEN, DLL C!*BGT RHOB,LDT GSa, LOT LXTHiLDT 8.HV. bDT ALI~ bDT NR~& bDT TNPH~ CNL eCrT~ CNb TENS CNL 8GR NGT URAN NGT N4NG? NGT NRE& NGT RTNR CSG RCNT CSG SGR CSG 12-SUN.!99! 09:45 '999.250 '999.250 . 9.250 999,250 o999~250 99.250 o999,250 09990 iO -999,250 -9! ,0, ~0 50 '9= 0 .9'! 0999. 0 -999 HTEN'bD? TNRA.:.C~b CNTC.,C~L MRES.,CNL CGR;NGT WSNG~NGT CS,NGT TNPH~CSG.. RCFT,CSG. .CGR,¢aG. H?EN'.CSG LbO;DbL. SP.,Dbb DRN'O;LD? LS*bDT SSI',LDT $iRH:;LDT: SGR,bDT': HTEN'LDT TNRA~CNL CNTC, CNb MRES'CNL CGR:*NGT WING'NGT W5NG, NGT: CS:-NGT. TNPN~.CSG RCFT',CSG CGR~CSG HTEN'CSG :999:'.250 .999,250 999 '250 -999,~2S0 -999,250 -999,'250 -999,250 -999,:250 -'999,250 -999,250 -999,250 -99 250 -99 -99 , -9! 0999 ~99! o~ o.! ,99~ .91 NPH! CNL NPOR CNL CFTC CNL .CNL 'THOR NOT W2NG NOT ~?~N8 NGT TNRR CSG CNTC TENS C$ CAb$;DLb SGR*D~ .HTEN,Db TEN$'BGT PEF':bDT NP'O~ CrT( ~.CNb MTEM~;.CNL '2NG~NGT HTEN.iNG~ TNRAi,.CSG CNTCi, CSG TEN$,CSG :999,250 ~o999,'250 .999*250 :.999,250 -999,250 .'§99;,250 0999,250 -999,250 0999,250 o! Itt '.-! --9! iO ~999 ,. , -999 : 50 -999,25~ '999:1 ~ SP'DLL 15~ SGR'DLL MRE$'.DbL -999~ HTEN,DbL -999,.250 ~2',5 4 -C2,BGT '.~ -999..~ 0 .LSLLDT 250 LU,LDT 0999.2 0 S81,LDT -999,250 $$2,L,DT :*999,250 -999°2 0 $2RH, bOT -999~"50 -999,250 -999'2:0 SGR'bOT '-999~50 TENS;LOT *999.,250 0999,250 HTEN,LDT -999;~ NPHt,¢NL '999,250 0999.250 TNRA*CNb -999, NPOR.CNb -999,250 "999,250 CNTC.CNb -999,250 CrT¢-CNb '-999.250 -999.2~0 MRES.CNL 0999.250 MTEN,CNL -999'250 -999,250 CGR.NG? :999,250 THOR;NGT -999,250 -999,250 W1NG,NGT 999,25o W2NO. NGT 999, 0, ~250 -999.2~0 HSNG~NG? -999.250 TENS;Ng? -999;250 -999,250 CSoNGT -999;250 HTEN.*NGT -999,-250 :999.250 TNPHvCSG -999*250 TNR~CSG 0999~250 ,999.~50 RCrT,CSG -999;250 CN~CeCSG :999.250 999,250 CGR,CSG -999,250 TENSeCSG 999.250 ZS .?e~e. ver~icet~on b~$~n~ :12-~U~-:t991 09~45 PA(;~ 20 chl~mber~er A~e~Ica Comp~tln~ cent. er ' D~P? T~NS DbL DPH! bDT Ob8 bSHV bDT bURH bD? RCNT,CNL H~EN CNb W3NG NG? NPOR,CSG MRES,CSG T~NS~DbL DPGReBO? OhS,bDT bb.~bDT bSHV,bDT bURH~bDT MT~M~bD? R?NR,CNb RCN?,CNL SGR,CNL ~OTA;NGT W3NG~NG~ MTE#.NGT NPHI.CSG NPOR~CSG CFTC,CSG MRES,CSG CAbI,DbL TENS,DbL DpGR.BGT ObS.bD? -~L;LDT LSHV,bDT LURH,LDT -999.250 MT;M,CSG -999,250 1800'.000 hL$;:Db~. -999..250 '999' ' MTEM,DLL -999,250 44 688 CI~BGT . 13.828 -999 250 RHOB,bDT ~999,250 -999=~50 -999 ~50 QSS~bDT 999~250 bXTH,bDT -999;250 -999 250 SSHV,bDT -999;250 -999 2:!.0 MR~S'LDT '999.250 -99912~0 CAb{,bDT -999'250. -999.290 TNPH,CNb ~0999,250 -999.250 RCFT, CNb -9'99,250 '-999 250 ?~N$.*CNb -999,2~0 :'999 290 SGR. NOT '999~2~0 '999. 50 URAN:NGT '999,250 '-999 ~$0 W4NG.. NOT 0999'250 '999 ~'50 NOT '999.250 "999 }~0 RTNR~¢SG -999,250 -999:250 RCNT. CSG -999;2~0 '-999 250 $ Ri '999,250 -999 250 M¥~MCSG: CSG -999,250 l?o0,O00 b~S:":D~b ,999.':250 -999,:250 CALt..DLL -999.250 -999.250 MTEM:Dbb -999,.250 68,625 Cl BGT . ~2,430 -999,250 RHOB: bDT -999,250 ~!i&bDT -999,2,0 '999,950 ~iLDT '999,250 )9.-250 CX~:bo? -999.250 b~T "999,'250 -999:~ ,RE&bDT -999"250 -999 TNPH~CNL -999,250 -999 i~O RCF?: :999.250 -999~50 CNb ?EN$,CNb ~999,~50 -999 250 SGR, NGT -999~50 URAN, NGT -999,250 W4NG NOT -999,250 0999 250 MRES NOT -999'2~0 -999. ~50 RTNR, CSG -999,250 ~$0 -999. 0999e250 RCNTiCSG. 0999 250 SOR, CSG ~999.250 -999 250 MTEM CSG 999..250 ~600000 -999 250 -999 250 -999~250 -999 250 -999250 -999 250 CAL~.DLL MTEM,.DLb CI-BGT RHOB. bD? bITH. LDT $$HV:bDT CAL! bDT '999,~ '999. -9§9. -999 -999 '999 "999 iO ~0 0 9 SP Dbb MRES DRHO bDT .bS :bDT SSi: ~DT SIRH bDT SGR HTEN ~DT TNRACNL CNTC. CGR,{GT W~NG~ WSNG~ CS:, TNPH~. RCFT,.SG 'HT£N, _:C2,BGT DRHO,bDT $IR~,LDT SGR,'L~T HTEN*L'T TNRA~CNb CNTC,CNL MRES.CNL WSNG,,NG~ TNPH~ CSG RCFT:CS CGRCS~ HTEN~CSG. SP, DLL NRE$ C2BGT DRHO LDT .b$ bDT SSi bDT $1RH bDT SGR bDT , -9" 0 .9999~.250 -999~:E50 -999~,.250 999,.2'50 -.999 ,250 0999,~.250 -999~,250 -999'250 -999..E50 -999.2$0 -999,250 -999.250 -999,25 -999~250 50 -9991~50 -999.~50 -999:; 5O -999~50 P~r, bO LU:LDT bSRH~LDT TENS:bDT NPH~CNL NPOR, CNb CFTC, CNb MTEM~CNL THOR=NOT W2NGNGT TENSN. T TNRAtC O CALS'DLL SGR,.DLL HTEN,DLL TEN$'B~T PEF, bDT LU*LDT SS2.'bDT L~RH,LDT TEN$.~,bDT N CF'TC-CNL MTEM CNL THOR W2NG~ TENS NOT HTEN NOT TNRA, CSG CNTC,CSG TENS.CSG CAL$,DLL SGR,DbL HTEN;DbL TENS.BGT PEF bDT bU bDT 852 LOT $RH~LDT EN$ bDT -999,250 -999,250 -999.250 !025,000 ~'999"250-999,250 -999.250 ;0 -99 -99 '-99 -99 -99 '-99 -9! ~50 " I'50 -99 -99 '9! 1030~ '"999~ ~-999i " 0 -999~ -999~ '-999~'2~0 -999,~ -999~2,0 1999:250 -999~ -999, 0 '999, 0 '999 0 TaPe· YeriL~[cetion L~s 12-dUN 199! 09~45 PAGEt In~ Center .'hlumberger Alesica Compu~t~n° ' 21 RUNT HTEN W3N~ NTEM.: NPH~ NPO~ D£PT TENS DPH! ~$HV LURH NTEM RTNR RCNT POTA W~NG NPH! N~OR C.~TC NRES D~PT CALl TENS ~URH NTE~ RCNT HTEN POTA W3NG MTEN NPN! NPOR CFTC bDT CNL CNL CNL CNL NGT NGT NGT CSG CSG CSG DLL DLL BGT bDT bDT bDT bDT LDT LDT NL NL CNL N~T N~T BGT bDT bDT bDT bDT bDT bDT CNL CNL CNL CNL NGT CSG CSG -999 250 : 99 999 250 -999 250 -999 2~0 -999 250 -999 250 -999 999 250 -ggg 250 -999 2~0 1500,000 "999,250 67,'5~3 '999.2.50 i999'250 999..250 '999 '999 50 -999 2~0 '999 250 9~9 250 29 9 250 -999 ~50 -999 :999 :$0 99 -99~ 250 -999 250 ~400,000 .999.250 '999.250 84,688 '999.250 '-999;250 '999.250 -999 250 '999 250 '999 250 '999 250 '999250 -999.250 -999 °999 250 -999~250 -99 ,99~ '25° .250 -999.250 TNPH. RCFT TENS SGR URAN, W4NG,, RTNR RCNT SGR MTEM C~LI ~lTH SSHV CALl TNPH RCF~ TEN~ URAB W4NG' MRE$, RTNR, RCNT, MTEM. CAL~ HTEM RHOB LXTH SSHV. CALl TNPH RCFT TENS 8GR URAN W4NG MRES R?NR RCNT bDT -999.25 CNL -999,25 CNL -999 CNL -999'~ N~T .999 · NOT -999 CSG .999 CSG -999,258 CSG '999 DLL DLL DLL SGT bDT bDT bDT bDT bDT DT NGT NGT DLL DLL DLL BGT bDT bDT LDT bDT bDT bDT CNL CNL CNL NGT NGT NGT CSG CSG HTEN:bDT 'TNRA, CNL CNTCiCNL~ W~NG.N.T ~GT TNPH,CSG RCFT,CSG HTEN,CSG -999'250 NPOR.,CNL -999,'250 CFTC.,CNL -999;250 MTEM,CNL -999~S0 THOR,NGT :999: 250 W2NG;NGT 999,250 'TENS'NGT -999,250 HTEN,NGT -999'250 TNRA.,~$G -999,'250 CNTC'CSG -999*290 TENS~CSG -999,.250 '999 "999 '999 '999 ~999 '999 ~999 ~999 {{o 250 ~250 250 -999..2~0 LLDi UL.b '99~ ~ 2 ....... .... 50 CALS'DLL '999,'250 SP~DLL' -9! ,'.250 "SGR,DLL '9! -999;250 MRESi.DL.L -9~ ,..250 HTEN,DLL -999,.250 SSt,.L'DT -9! .:'~$O SS2'LDT '999,250 $XRH~LDT -9~ ,'250 bSRH',,DT '"999,250 'SGR~DT -9! ~,250 TENS',DT -v~ iO -999.250 HTEN,.LDT: -9' .,250 NPHI':CNL -999,250 TNRA. CNL: .9i r250 NPOR,CNL T2~ i0 -9990250 CNTC~CNL- -9i ,250 C'FTC'CNL -~ ,0 -999,~50 NRESt:.CNL -9! ,250 MTEM,CN~ -999.250 CGR.NGT '~i ' W2NG.,NGT '"9! }0 '999,250 WSNG,rNGT' -9! ,~50 TENS'NOT -999,250 $,.NGT -9! ,,~50 HTEN,'NGT -999,250 TN~H.,C~G -9d ~'250 TNRA,CSG '-9'! ~0 -999.250 RCFT',CSG -9! ,:2~0 CNTC'.CSG '"9! ~0 -999'250 CGR,CSG. -9! ,..250 TENS,CSG '-99' ~0 .999.250 HTEN,CSG -99* ,250 -999 250 .999 .2S0 CA S'OL :999'2S0 -999 2~0 SP:,DLL -999,~50 :SGR,DLL ~999.,250 -999 250 aa~$*."D~b -999..250 HTEN~Db~ 999,25.0 12 891 C2'BGT' . 14,859 TEN$,BGT '850~000 '999 250 DRHO,,LDT .999,250 PEr,LDT 0999,250 "999 250 LS,LDT' 999,250 LU,LDT 0999,,2'$0 -999 250 SSX,.LDT -999,250 'SS2'LDT '-999,250 -999 250 $XRH bDT -999,.250 LSRHoLDT -999~250 -999 250 SGR: bDT -999,250 TENS,bDT -999v250 -999 2~0 HTEN bDT ~999,250 NPHZ,CN~ -999v250 -999 250 TNRA CNL 999.~50 NPOR,CNL -999,250 -999 250 CNTC CNL -999.250 CFTC.CNL -999 250 MRES CNL -999.~50 MTEM,CNL -999~250 -999 2~0 CGR NGT -999.250 THOR.NGT -999,250 -999 250 WiNG NGT -999,*~$0 W2NG~NGT -999,250 ~999 250 WSNG N~T -999.~50 TENS~NGT -999,~$0 999 250 CS NGT -999,250 HTEN,NOT -999 250 -999 250 TNPH CSG -999,250 TNRA.CSG -999 250 -999 250 RCFT CSG -999.250 CNTC,CSG -999i~250 -999 950 CGR.CSG -999,250 TENS.CSG -999.250 :hlumDerqer. AlasKa ComPut S,csC DEPT..: TENS'DbL DPHI"bDT OhS,bDT bSHV.,bDT bURH,bDT RTNR,CNL RCNT"CNb HTEN. CNL P~TA.N T M?EN;NT MRES"CSG CAL~,Dbb .GR,BGT DPH~,bD? OhS,bDT ~bb;bDT LSHV'bDT bURH,bOT MTEM.bDT RTN~;¢NL RCN?,CNL &GR.eCNb HTEN,CNL POTA,NGT W3NG'NGT MTEM'NGT NPH~,CSG NPOR.CSG CFTC,CSG DEPT' CRLIoDbb GR;BGT DPH~.bDT ObS,bD? bb,bDT bSHVebDT bURH,bD? '999.250 ! oo,ooo 99-250 999'250 999,250 '999~2~0 '999.250 99,250 '999:250 -999250 -999 2~0 -999 ~$O -999 '999 '999 '999 '999 " ~$0 "999 ~0 66 -999 -999 ~'~0 '999 250 -999 g50 l~O0 000 '999 ~$0 46 2t9 '999 250 '999 250 '999 250 '999 250 '999250 Abl,Dbb MTEM~DbL C~BGT Q$$:GDT GITH~,bDT SSHV~bDT CRbI, bDT MRES:~DT RCFT. T£'NS;CNb '$GR,NGT URRN,NG? ~4NG.,NGT R. TNR*CSG RCNT,CSG. 'SOR,CSG ~TEM;C'SG bb$.~Dbb CAL''Dbb. bDT SSH¥~LDT CAbI~LDT ~RE&,bDT ?NPH~CNb RCFT, CNb TENS, CNb SGR, NGT URAN~NGT ~4NG:NGT NRESNGT RTNR:CSG RCNT~CSG 8GRiCSG ~TE~ CSG · CAL1DLL MTEMDbb C~BGT RHOB:LDT OSS bDT blTH bDT 8SHV bDT CRb! bDT 12-JUN-199! 09145 PAGEI 22 -999,250 HTEN,CSG '999 '999 0 -999 250 '999 25 -999 258 '999 250 ~999 25 '999 ~rPS~ -999 ~5~ -999 ~ 50 ~999 -999 ,50 999 0 '999 2, 0 '999 999 2~, 0 -999 ~", 0 · -999 2! 0 -999 2~,i0 -999 -999 2~0 -999 2~0 -999 2~0 -999 2~i0 =999 250 -999 25O -999 250 -,,, '999 -999 250 -999 250 '999 250 !3 055 '999 250 =999 250 '999 250 -999 250 -999 250 Dbb · BGT DR'HO bDT bS bDT SSi, bDT 8~RH bDT SGR bDT HTEN bDT NRA:~CNL NTC.,C,NG. M'RES:.CNb CGR~..N'GT W~G&~'T WSNG, N~T .S,N TN~H, OT CSG RCFT,CSG COR,CSG HTEN.CSG Obb bDT $St.*bDT HTEN,.. .Nb TNRR,~Nb CN?C. CGR~NGT NING, NGT WSNG.NGT CS NGT TNPH SO RCFT CGR HTEN CSG LLD~DLL SP,DLb MRES,DLb C2.BGT DRHO,bDT bS,LDT SS~.GDT $1RH.GDT SGR,LDT -999.250 -999,25'0 HTEN,Dbb . 15,.4.5~ T'ENS,BGT -999,25 PE'F' bO~ 999.25 bDT -999 50 . O? - 999 50 ~NL -999 50 -999 ~ NPOI CNG NOT '9~ ~ W2.~ -' NOT 0 '999~ -999; -999" -999,' 0999. -999. -999' -999. -99 ' -99~' Dbb' -999.250 :999,~50 999,250 -999,250 -9990250 -999.250 0999;250 bSRH -999,250 TENS TENS~ PE. ,'~ LOT bDT 5~) N'PH~.CNL ~0 CF?C,, -999.; 50 MTEM, CNb -999, 50 -999~ S0 W~NG~ = 50 NGT e999~50 HTKN -999. TNRR ~999. 50CNTC -999~ TENS C8 -999,250 CAbS Obb SGR DLL HTEN TENS BGT PEF LOT , bU LOT 882 bDT bDT bDT -999 250 -999 250 999 :$0 -999 ~50 -999 i ~999 "999:250 o ~0 ~999 .. -999,250 -999~250 -999,250 790000 0999: ~S0 '999 250 ]:S ?a~e VerSa,cat,on ~st'~nq :hlumberc~er A~as~a. Comput~nq Cente~ 09145 ¸23 RTNR.CNL RCNT,CN~ SGR,CNL P~TA.*NGT Wi~.NG.,NGT M. TEM,NGT N'POR.CSG CFTC'.,CSG DEPT~ CAb~: Obb TEN8 .GR BGT DPH! bDT bL, bDT bURH BDT RTNe;CNb RCNT.CNb HTEN'CN'L W)N~.,NGT MTEM,NGT NPH!,CSG NPO~,C~ ~RE8'.CS~ DEPT, TENS.Dbb DPH~.bDT .b~bDT LSHV.LDT LURH,LDT NTEM.LDT RTNR. CNL RCNT CNL SGR CNL HTEN CNb POTA NGT W~N~ NGT MTEM NGT NPH! CSG NPOR CSG CFTC CSG '999:250 -999~250 '999~ 0 -999,2S0 ~999,250 .999~250 .999..250 999.250 -999'250 . ~000.~00 -999 -999 '999~ "999, -999.; 50 -999250 -999;250 -999"~50 -9'99~250 '999'250 '999.250 ~999.250 .999:.250 .999.250 999,250 9001000 -999,250 -999 25O -999,~50 -999 50 -999 ~50 -999 250 -999250 -999 250 -999 250 '999250 -999~2S0 -999 2~0 -999 2S0 -999 250 -999 250 '999m~50 '999°250 TNPH, CNL RCFT, CNb TENS, CNL SGR, NGT URAN~NGT W4NGjN(;T MRES~NGT RTNR,;,CSG RCNT;CSG SGR,CSG MTEM,CSG f Lb& .D~L~ CAb 1. , O ..b MTEM ~DLL: .bDT: QSS~ ,bDT: LITH~ SHV bDT RLX bDT MRES bDT TNPH~ CNL RCFT~ TEN&~ .CNL SGR~ ,NGT N T URAN.: N~T W4NG RTNR~ CSG RCNT~ CSG SGR. CSG MTE~ CSG LbS. DLL CAbl',Dbb MTEM.DLL C~;BGT GS~DT LITH'LDT SSHV~ bDT CRb~ bDT ~RES bDT TNPH: CNL RCFT CNL TEN&. CNL SGR~ NGT URRN. NGT W4NG: NGT MRES: NGT RTNR RCNT. CSG 8GR CSG -999 -999 ,,99 -999 '999 - 9 '9 -999 -999 -999 ~2 -999 -999 -999 '999 '999 '999 -999 -999 -999 m999 -999 250 250 250 250 250 :250 2'0 2:~0 250 250 -999.250 -999,250 -999.~50 '999.25i -999'2~ -999,25 '999.250 '999'250 "999.250 "999.250 -999' '999. 0 '999,250 '999.250 "999.250 '999.250 '999,250 '999.250 T~RA,C~'L CNTC,CNb M~ES,CNL CGR,NGT W5 TNPH,CSG RCFT.~CSG.: HTEN.CSG: .g'~O SP;iDbb :~ MRES.iDLL~ 250 DR~ BGT 2 0 2~0 H?~N,~D? SO TNR~iCNL MRE~ ,CNb: CG) ,NGT i ~i!iI WSNG ~NGT 0 TNPH:i.CSG ...50 RCFT:,,CSG. :. 50 CGR~ b~D~Dbb SP,DLL MRES,DLL C2,:BGT DRHO.LDT L$,LDT SSI.bDT SIRH.~LDT SGR, LDT HT~N, bDT TNRA~CNb CNTC. CNb MRES. CNL CGR. NGT ~INGNGT NSNG, NGT CS NGT TNPH ¢$G RCrT CGR CSG -999*250 ~999,250 CFTC.CNL · 999,250 MTEM,CNL :999,:250 THOR,NOT .999,~0 ;999,~50 .999;~50 T.NRA~CSG .999,~50 .CNTC,CaG 999'~50 '999 CAL&~OLL -9' '$GR*DLL -9' HTEN.,D:bb PEF:~LDT .LUeLDT LSR. H.LDT -999 ;0 NPOR'CNL .~50 -999 !)$0 CFT¢*¢NL MTEM.CNL .~ HTEN,NOT · TNRA~:CSG -999 :~0 CNTC,CSG -999 )50 TENSoCSG -999 '999.250 CAL$~OLL -999,~$0 .SOR,Obb -999.~$0 HTEN;Dbb ..-20.~47 TENS.BGT -999.250 PEF'LDT -999.250 LU.LDT -999.~50 S$2'LDT -999.250 LSRH'.LDT -999'~50 TENS'bDT -999'~S0 NPHX,CNL :999;250 NPOR, CNb 999~250 CFTC~CNL -999~ -999~ -999~ -999~ -999 -999 -999 -999 250 MTE~ 250 TXOF 250 W2N( 25O HTEN~ 250 TNRA 250 CNTC 250 TENS CNL NGT NGT NGT NOT CS(] CS(] CS(; '999:'250 -99925~ · '999~ '999,2~0 0 '999.. : 0 -999: '999 250 ~99! 250 :"! ~0 :~9! ~0 -! ~0 ii iO ,o ~0 '99 ;0' -9 -9 -~ ~0 -999 '999,250 -999,.250 -999;.250 .765,.000 ,999..,250 .999.250 .999~,250 :9.99,,250 999,1250 -999~,.250 ~ 50 "999'~50 -999, -999~250 -999,250 -999'250 ~999; .999,250 999,250 -999'250 IS Te~e VerSa,cat!on ~st(ng ~hlumber~er Alaska Computing center ~2-aUN.1991 09=4S .soo'ooo so -999, 50 TENS..DbL -999,250 MTE~Dbb -99 ,.250 ..G~.'SG~ .27,047 Cl.,SOT . DPHI;bD? -999.0250 RHOB,~DT 999,2 ~b$;bDT -999.250 O$$.,bDT -999'2~0 bL,bDT -999.~250 bZTH&~DT -99902~0 b~,LDT ~999':~ $0 $SS¥,bDT '999,2~0 b~RH'~DT '999,1~~ CAbI'bDT '999,250 MTEM~bD? -9~9. MRES, bDT -:999,250 TNPH,CNb '999.250 RCNT,CNb -999.250 RCFT,CNb -999,250 SGR;CNL -999: ~ 50 SGR:&NGT ' 999,250 POTA*NGT -999~ :!50 URAN-NGT -999,250 'W3NO.;NGT -999. W4NG~NOT -999,2~0 50 M?EM:;NG~ -999, MRES,NO? -9~9.~50 .$0 :50 -999;250 NPHI,.,CSC -999 RTNR'CSG MRES,CSG '999 MTEM,.C$O 0999.250 DEPT' TENS,DbL '-GR.BGT DPH~,bDT LSHV'LDT bURN,bDT ~TE~.LDT RTNR.:CNL RCNT..CNb SOR.,CNb HTEN~:CNb NTEN.NGT NPHZ,CSG NPOR::,CSG CFTC.~C$O NRES.,CSG- D~PT, TENS:.DbL GR;.BGT OhS. bDT bDRH.~D? .700.000 .999, :-50 46-, -999'250 - 999' 250 "999.; 250 -999,250 -999~250 -999,, ~0 -999, -999' '999,250 -999~ -999;..0 -999,250 -999,250 '999,250 '999,250 600 000 -999 250 -999 250 73.938 -999 250 -999250 -999 250 -999 250 -999 250 OSSiLDT bXTH, LDT 88H¥ bDT ~ALX bDT MRE&,bDT TNPH, CNL nOrTh.tNb TENS,CNL SGR~,NGT ~RAN,,NGT W4NGvNGT MREg, NGT RTNR,CSG ~CNT*CSG SGR.CSG MTEM.CSG LLS'DLb CAL1,DLb MTEM.DLb C1,BOT RHOB. LDT QS$.LDT kITH,bDT SSHV.LDT CRLXoLDT LLD St:' MRE~ c: DRHO 81RH H?EN Ob.b Dbb obit, BGT bDT bDT bDT bDT bDT. bDT TNRA,CNL CN?C,CNL MRES~CNL CGR,NGT WlNG~NGT W5NG, NGT TNH,CSG. RCFT'CSO CGR,CSG. HTEN.CSG. '999'r50 'P~Dbb '999' 0 DRHO,bDT '999~:"50 '999' S1RH,LDT -999,2 0 SGR'LDT '999.250 HTEN,LDT "999~ 150 TNRA*CNL -999~, $0 CNTC,CNL -999 50 MREStCNL -999, $0 CGR,NOT '999~ 2 0 WtNG,NGT 2~0 '999: WSNG~NGT -999:250 CS,NGT -999,250 CGR,CSG 250 HTEN.CSG. '999 '999 '999 12 '999 '999 '999 -999 -999 25 25~ LLO,DLL SP'DLL 25 MRES'DbL 55~ C2,BGT 25 25~ DRHOvLDT bS,bOT 8GRebDT '999.250 '999,~50 '9~9,250 ,250 PEr,bDT -999-250 'LU,LDT -999;250 'SS2..LDT "999,250 '999,~50 TENS,bDT '250 CrTC..C~b -999 '50 -999 ~50 MTEH*CNL THOR~NOT -999250 -999 250 -999 250 HTEN,NGT -999 250 TNRA*CSG -999 CNTC*CSG .: 50 TENS,CSG 999" So '9 *~ CALS,DLL · 18,.0~8 HTEN:,Dbb TEN$.'BOT '999,250 PEF,bDT -999,250 ~L~,bDT -999.,250 SS2'LDT -999'~50 '999,~$0 TENS,bDT -999,250 NPO~*CNL -999,250 CFTC.CNL -999.~50 NTEM,CNL - 9,'50 W2NG,NG~ '999,~50 TEN$'NGT -999,250 HTEN,NGT -999,250 TNRA*CSG -999,~50 CNTC,CSG 0999~250 TENSoCSG -999~250 -999'25 $OR,Obb '999,250 HTEN,DLL -. 18.$88 TEN$,BGT -999.250 PEr*bDT -999,250 bU..bDT -999,250 $$2,bDT -999.250 bSRH,bDT -999.250 TEN$.LDT "'999 iO -999 !50 ~0 '9! iO "9! "9~ ~50 '9! ~0 '9! - ~0 "9! "9~ '9! -9 iO "99; -99: ~50 '999 ~999 999 '9 :~50 '999 '999 '999 -999 ~0 -999,250 :999'250 999,250 .640,000 "999,250 .999,250 :999,250 999.250 Alaska.. ComDutin<3 Center RC~T.CN~ POTA,NG? W)NG..-NGT M?EM;NGT NPOR,¢SG CFT¢'eSG CAE! D~ T~NS DE~ '.OR BGT DPH! bDT O~S bDT ~ LDT MTE~DT R?N~ CNL RCN?CNb ~G~CNb P:OTA;NGT W~NG.NGT MT£M;NGT NPH~.CSG NPOR,CSG MRES,CSG DEPT ~ BOT DPH!,hDT OhS,bDT bb~bDT bSHV,bDT bURH bDT #TEM bDT RTNR CNb RegTiegb SGR,CNL HTEN,CNL P~TA.NOT W3NG'NGT MTE~.NGT NPHI,CSG NPO~,CS~ CFTC,CS~ -999 *'999 *999 "9999' .250 *99 ,250 '999 ,250 '999 '999 *999:250 $00,000 -999,250 '999,250 -999,250 -999,~~ 50 '999~:150 '999,.250 '999~ '999:~O0 *999250 '999250 '999'~56 '999, "999250 '999~250 '999~250 '999 250 400,000 '999' 55~406 -999:250 -999:250 -999.250 -999~ -999::50 '999150 -9992.O -999 2~0 -999 250 -999 ~$0 -999-250 -999250 -999 250 -999 250 -999 250 MRE$~bDT TNPH'CNL RCFT:~CNL TEN$,CNL SGR,NOT URAN~NGT W4NG,NGT RTNR~¢SG RCNT'¢SG SGR~..CSG MT'E~,CSG .). LLS, DLL ekb~*Dbb MTEM,DLL Cl,,BOT RHOB.LDT LITH.bDT $SHV';LDT CALX,LDT MRES; bDT TNPH, CN.L REFT, CNb TENS:., CNL ~4NG~NGT MR ES., NOT RTNR,CSG R. CNT,C~G 8GR~CSG C~LI.*DLL NTEN, DLL C. ~,BGT QSS, bDT LZTH. ~DT SSHV. bDT CALX~ bDT NRES, bDT TN~H~ CNL TENS* SGR, NOT URAN~ W4NO NOT ~RES ~GT R~NR CSG RC~T CSO SGR -999 :: 50 -999 ~5o .,999...,2 ~0 -999 =2 )0 '999 2 '~0 *.*999 2 ~0 -999 2 ~0 :999 ~ so 999 2 ~0 -999 ~ ~0 -9~9 2 ~0 -999 250 -999 250 "'999 250 -:999 250 ,999 250 ,,,999 999 ~0 -~99 2~;0 '999 2~;0 ~999 -999 -999.250 -999,250 999,250 -999,250 -999!250 -999~250 -999~250 -999;250 :999,250 999.250 *999.250 -9990250 -999,250 -999. -999;250 -999.250 '999.250 TNRA~ Nb CNT'C, Nb NRES:,CNL CGR~NGT W~NG~NGT WSNG~i'NGT CS NGT TNPH CSG RC'FT: CI~ CG'R LLD Obb SP DLL DRHO bDT bS bDT, SSZ bDT $~RHbDT~ SGR.LDT HTE'N L.DT: TNRA~CNL CNTC:CNL' MRES~:CNb" NZNG, NGT WSNG~NGT TNPH~C80. RCFT'CSG.: CGR~CSG HTEN'CSG LLD:OLL SP,Dbb' C2~BGT DRHO,bDT 81RH,bDT SGR,bDT 'HTZNtbDT TNRA~CNb CNTC, CNL NRES'CNL CGR~NGT WING, NOT WSNGeNGT eS,NOT TNPH'CSG RCFT.CSO CGR,CSG '999'~50 NPHZ'CNL ,,,99 ;..250 -999,'999 i:i5050 NPOR,CNL -99~.,:250 -999, MTEM, eNb ,250 -999,:~0 W2N'G.'NGT ~250 -999'~ 5 HTEN,NOT .-250 THR'~,CSG -999;.2 ~ CNTC,CSG :-99 ,250 -999,25 TENS,CSG :-999~250 -999'25~ '999'250 CA~S:,D~ -~ 250 -999' 250 HTEN..DLb '-~ ' 0 18'563 .~ENS'BGT 6; ~00 -999,250 PEr ,bDT -9~ 0 -999"250 bU,bO~ '-999,,. 0 -999,250 ;$~2-LDT -999,250 DSRH,;LOT :-99' 0 -999,250 TENS' bDT '-9~ 0 *999'250 NPH!'CNL '"' 0 0999.,. 250 NPOR.' CNL ,99~ 0 -999,:2:50 CFTC* CNL '-9~ '0 -999,250 MTEM, CNL- :" iO ,o 99, '5. W2NG,NGT LO ?99;250 HTEN,,NOT :'~9',~50 999,250 TNRA'CSG -999' 250 -999,250 CNTC;:C~G -999,250 -999,250 TENS*CSG -999'250 -999.250 =999 HTEN,DLL -999 I~ · SGR.DLL -999. 50 LU*LDT -999 ~I~, SS2'LDT -999 LSRH,~ -999 250 TEN& LOT ' -999 2SO NPHI~ CNL 9 .,,, -999 ~o NOT THOR -999 50 ~2NG~ :0999~2$0 ;'999,250 ;lO,....o, -.,,,.,so HTEN NOT :0999,2S0 -999~ 250 TNRA'CSG -999,250 -999~ 250 CNTC, CSG .-999,2S0 -999:250 TENS.CSG -999,250 -999;250 -999~250 -999~250 $95,000 -999,250 -999,250 -999,~$0 ;-999,~$0 '0999,~$0 :-999,2S0. -999,250 '"999.250 ~s.:?aPe vert~a~.t~on 5ist~n 12-JUN-199! 09:45 PAGE: 26 :hlumberoer:Al ska Computln~ center TENS,DL~ G~,BGT DPHI~bDT OhS,bDT bb!.bD? bURH,bDT RCNT CNL SG~ CML HTEN p~TR NGT NGT MTEM NPH! CSG NPOR CSG CFTC cst MRES CSG CAb! Obu DPH! ~D~ OhS bDT bURH bDT RTNRCNL RCNT CN~ SG~,CNb POTA.'NGT N3NG.NGT MTEM NOT NPOR csG CFTC CSG DEP?. TENS.DUb GR.BGT DPH~.ZDT ~bS,bD? bSHV.bDT bURH,bDT '999,250 300 000 -999 250 -999 30:188 '999 '999 250 '999 250 ~999 ~'999 250 '999 250 '999 250 ~999 ~50 '999.'50 "999 56 '999 ~50 '999:~5~ -999,~50 -999 250 200'000 -999,~'!50 -999;250 -999,250 -999,250 -999,250 - 9 250 ~999 250 -999 250 -999 250 '999 250 -999 :SO -999 ~50 -999 ~$0 -999.~50 -999 250 -999 250 100 000 -999250 -999 250 t5703 -999,250 -999,250 -999:250 -999.250 -999:250 MTEM, CSG CALl DUb MTEM Dbb C! BGT ~HOB.: bDT O$$ bDT bI~H~ bDT 88HV: bDT CALl: bDT M'RES bDT TNPH CNU RCFT: CNL YEN& CNb URAN, NG~ W4NG~NGT MRE~' NG~' R?NR ~ C8 RCN?,C&G 'SGR, D. b CALl, ~ OSS.~ 88H9~ CALl,. 'DT MRES:' ~DT ~NPH CNb RCrT CNb TENS tnb SGR NOT URRN: NGT N4NG NGT ~RE& NG~ RTNR RCNT CSG &GR C~G MTEM CSG bb& CAbt, Obb MTEM Dbb C1 RHOB bDT aSS bDT LITH bDT SSHV .hOT CRLI bDT .999. 5o '99~, SP~DLU 011 C2,BGT '999.'~ DRHO,,bDT '999,!: '0 bS,b:DT -9! 0 '9! SiRH.,'b:DT~ '9' SOR,,'bDT~ -~ HTEN'bDT! -99' TNRA,CNL' -9 C'NTC,CNb -9' MRES;.CNU '9' CGR'NGT '9~ '9 TNPH~CSG, '9' i~ CGR,CSG: '~ H~EN,CSG -999 150 HTEN.Dbb ' '2 0 -99! I'$0 bU.,bDT -999:250 -9! .SS2,.bDT ~-9 ~ 50 .mi -999:: NPO 'C b -i ;0 '99' CFTC.:CN'b -9, M?EM-:CN~ - iO -9' THO:R~NG~ :"- iO -'9~ W2NG:,NG~ ;0 -9' TENS.'NGT -9' HTEN.NGT ~-91 lO '" TNRA'CSG~ "9' TENS:, -999,250 b O'bb '999;;25 CAbS'DbL. ~'999,2~i0 -999,25 ,9.2so o ' i'4"69 '999.250 -999'25 :bU'bOT. bDT -999,25 SS2,LDT :-99,)~50 -999.250 SiRH, bDT -999,25 ~SRH~,~DT -,,9..;,o .: -999'250 TNRA~CNb: 999~5 NPOR-CNb '-99.)t250 -999'250 CNTC~CNL -999,25 CFTC',CNL -99:1,250 -999,250 MRES. CNL~ -999,250 MTEM~CNb: -99~),250 - g' ,' SO -999.250 #ING, NGT -999-~50 W2NG.NOT - -999,250 W5NG, NGT -g99.,250 TEN$'NGT - -999.250 CS~NGT -999.'250 HTEN, NGT 0999.250 TNPH, CSO -999.250 TNRA~CSG -999.250 RCFT~CSG -999.~50 CNTC¢SG -99~,250 -999.250 CGR CSG :999;250 TENS CSG -99~.250 -999.250 HTEN CSG 999'250 -999.250 bbO,Dbb '999.250 CAbSiDbb -999~250 -999 250 SP.Obb -999'~ 50 " '~$0 SGR.Obb -999,250 MRES,Dbb -999 H?EN,Dbb -999.250 -999.2~0 , '999, DRHO, bDT 50 PZrebD? '999 250 bS,bDT : ' 50 bU.bDT -99:'250 -999.250 SSt,bDT -999:250 SS2'bDT 999~250 -999.250 SiRH,UD? -999,250 bSRH,LDT -999'250 -999,250 SGR,bD? -999.250 TE~S,~DT [$ ?aDc. verification L~ =.hlumberc~er Alask:a Comp NTEM RTN~ RCM, HT~N PO:TA W~NG N~N! CFTC ,LDT CNL .NGT NGT CSG CSG DEPT,D ~CALI GR~BGT DPHT;hDT ObS.'bDT M?~;~DT R~NR'CNh RCNT;CN~ SGR~CN~ POTA,NG? W~NG~NGT M?EMiNG? NP~I;CS~ NPOR,CSG CFTC,CSG -999~250 -999,250 '-999,250 ~999,250 999:.250 999;250 999*.25O .999.,250 .999,250 ~999'.250 999;250 . 67*000 999, -999' -999~ 50 -999'250 -999~.250 '-999.250 ~999,250 -999250 -999 -999~ 50 "999-50 '999250 '999 250 END OF DATA StiD~ 12-dUN"]'99! 09~45 P.AG~= 2-/ TNPH RCFT TENS UR~N W4NG R~N? blTH SSHV CALl ?NPH~ ?EN$ URAN W4N~ MR~i R?NR~ RCNT MTEM BDT "999,250 HTEN,~D~ CNL -999,250 TNRA,CN~ CNb -999.250 CNb '999,250 MRES, NOT -999,250 CGR'NGT NGT -999.250 W~NG'NG? NGT ~999'250 W~NG,.NG? NGT '999,2~0 C$~.NGT .CSG -999,250 TNPH~CSG CSG -999'250 RCFT:~CSG. CSG -999~0 CGR~CSG CSG -999,250 HTENoCSG Dbb BGT LDT .BDT :LDT ,bDT CNL ,NGT ~NGT ~NGT ~NGT ,CSG -.999~ 0 -999~ 0 -999, iO "99'),; "99,), -99,)i .99~ 00 "99~1.~ 0 .,199~ 0 0 -99!t~ 0 "99!), "99'~, iO LLD .DLL 'BP DbL. MRES Obb' ,LDT .LS, LDT SSI~LDT SIRH, LDT SGRi.LDT HTEN,LDT TNRA,CNL CNTC,.CNL MRES,CNL wC~R:.NGT tG:NGT WSNG~NGT C$,.NGT TNPR.CSG RCFT,CSG CGR,CSG. HTEN~CSG '999.250 NPHI,CNL -999,250 NPOR..CNb -999.,250 CFTC.,CNL -999,250 MTEM,CNL -999.250 THOR.,NGT -999.~50 ~2NG,NGT -250 -999 HTEN,NGT -999 TNRA,CSG -999't~0 CNTC,CSG *250 T'ENS'CSG ;%o 'HTEN ~250 .250 TENS ,250 'NPOR ;:;50 C~TC ,~50 ~TEN ,~50 ,250 ,250 TENS ,250 HTEN 50 ~50 TNRA CNT¢ -99 -99 bDT bDT .NL , $~ "999,250 "999~250 ~999~250 '~999~250 '~999~250 "999~2'50 '999~250 "999.250 '"999,250 .4.35,000 ;999,:250~ : 999. 250 '~999.~250 :"999,250 :I!o '999,250 -999,2~0 -ggg,2so -999,~250' ';1,,.;,o. **** FILE TRAILER **** FILE.NAME = EDIT ,001 SERVICE VERSION DATE ~ 91/06/12 NAX. REC.SIZ~ ~ !024 FZL~ TYPE ! LO LAST FILE ~hl~ber~er AIaSka ~o~ ~n~ center PAG C SERVICE : FLOC V~RAION : 001A06.. DAT~ i 91/06/t2 MAX R£C SIZE : 1024 rILE TYPE I LO LAST FILE MAIN PASS bOG DATA DATA SAMPLED EVERY -.:1667 FEET DATA ~NCbUDgD -. TYPE USED NAME DLb cobb DUAL bA?ERObOG TABLE TYPE I cONs ,. TUNI .... VAbU DErI .............. CN CONOCO INC. Company. Name SCHRADER 6bUrr Ple~dNeme~ Well.Name A~l'~Sertal Number Fleld'bocatlon FN APIN 50 029 S~CT 2'7 TOWN RANG ~OE COUN NORTH STAT ALASKA NAT! USA W~TN PObYA/DAV2E$/DECKERT Section~ Township Range, County Ste~e or Prov~nce Nat$o~ Witness; Name .'~lu~be~ger: Alaska Computing Center APD FT 65, DF FT 64, EGL FT TOD rT TDb FT Bb! FT 45~ FT D'T $IZ DFD G/C3 10, DFPH RM8 0 MST 6 RMFS o 6 Ol CP DEGF ~FST DEGF MCS OHMM MCS? DEGF B~T DEGF VALU DEFI : 548205 Service Order Nu.mber Permanent datum Elevation of Perm.. Datum SA ? 6 52 34 kog Measured:From 'BOVE' .E'RM NEff? DATUM Elevat!on of Kellv~Bush~nq Elevet$on o~ oerric~ Flogr Elevation of,GrouRd ~evel Total Depth - Driller Total Debth o boqger POttom boq Interval TOp..bog~Interva~, .. Drillinq'rlu~d Type Or~t~inq Fluid Density Dr:fi. hq r u~d Ph esisttiity et.Mud.Sample ~'ud..<'Sampie:Te~peratute. Res~stt~ity o~...mud'£~l.t=ate~,~s Mud ri)trate:Sample,:~emperatg ReSistivity o~ Mhd Mud Ca~e'SimPle"~empera~ure ~me.C~rculation ..Bettem Ho.le Temperature 6!, I~ I00 7-MAY ~00. IIIIiitliiii · , ., TABbE TYPE t CURV ....... DEr! DEPT Deoth Channel. Name MSFL MSrb Resi. Sti~lty · SM!~ Synthetic M!cro-Znverse aes~stiv~ty SMNO Synthetic ,: rD-Normal Iiiliiii11111111111111111111111111111111111111111iliii!Iiii' DATA fORMAT 8PE¢IF!CATXON RECORD SET TYPE TYPE · REPR CODE VAbUE ! 66 0 2 66 0 3 73 16 4 66 5 66 6 73 1 66 64 13 6 0 14 ~5 FI 15 66 68 16 66 0 66 ... -- ** SET TYPE-..- CHAN ** N~H~ SERV UN~? 6£RVZCg APl AP! AP! ~P! r~ NUmB NUmB SZZE REPR PROCESS ID ORDER # bOG TYPE CbAS6 MOD NUMB-$ARP EbE~ CODE (HE..5) ~sr~ ~[ O.M~ s412§s oo ooooo o ~ s~x. ~o.~ s~e os oo oooo.oo ~. 1 ~ e 4 8 000 000000 .s~.o o~ o.~. ~.~ os .oo ooo oo o 2 ~ '~.~ oooooooooo $~- DATA DEP?. 4666,500 ~SF~,D~b i,053 SNZN,Dbb 9;052 S~NO.Db~ DEP?, 4600,000 ~SF~iDLb 4,170 SMIN.Dbb 107'257 SNNO.Db~ D£P?. 4500,000 MSFS'DSb 2,790 SNIN,D~b 24~$75 S~NO.D55 DEPT, 4400,000 MSF~,DS~ 1,468 SMZN.DS~ 33'120 S~NO,DSL DEP?. 4300,000 ~8Fb-,D~b 1,319 SMIN,D~L 15'639 SMNO',DbL DEPT, 4200,000 MSF~.D~b 1,020 SNIN.Dbb 13~922 S~NO.DLL DEPT, 4100.000 MSFb. DLb 222,T72 S~ZNoD~b DEPT. 4000°000 MSFb'D~ 221.995 DEP?. 3988,833 ~SFb. Dbb 221,07! S~IN,DL~ ~*~*~*~* $~N0.DLL 12.004 53'909 24,?01 24,779 16,EGO 14'964 8614"787 8539,693 8460,422 END Or DATA VERSZON ~ 001A06 DATE ~ 91/06/12 FIL~ TYPE: ~ LO LAST FXLE: I F'ZLE N'AME I EDIT ,003 MAX REC':$ZZE t 11024 TYPE ~ LO , , ALPHA PROCESSED DENSXTY/N~UTRON & RECOMPUTgD NOT N'/KALMAN & ALPHA FILTERS DATA SAMPLED EVERY -,5000 FEET DATA T0bL EXTENSlbN ToOL bDT/cML ',CRC ~SAN ALPHA PROCESSED ~:XTH~ DENSXTY AND CML NOT ~L NATURAL GAMMA SPECTROSCOPY (KALMAN FILTERED) NOT :~L~ NATURAL GAMMA SPECTROSCOPY (ALPHA'FXLTERED) .-hlum~erq. er Alaska COmputing Center TABLE TYPE = CONS C' CONOCO INC.,~ .. Com~any,~ame FY SCHRID[R.BbUFF I, 50-029 22138"00 .... ApI Serial Number F~ 3354· FN~ & 34~5· FEb 'Field.~ocation S~CT 27 Section.. TO,, 1~, lOrDship RANG !OZ COUN NORTH STAT AbASKA' ~tate,'or Province ~A?'! ~6A . NatiOn ~ WITN · 548205 ~erviee.Order Number PAT ~b Permanent':da:tum .. bo~ Measured From APD FT 65, ABOVE:,:.PERMANENT, DATUM Elevation o~De'~,ric~.Flo~r: EDF FT 6~, E:levat.!On et Ke.ll.¥.Bushin~ -EGb FT 3 EleVatlon.oE:Ground.~evel TDD FT 46~0,: Total Depth'-' Driller TDb FT 4650 TOtal DePth,-.LOqq~r Db! FT 45~)~ Bottom. boq. Integra!. D~D GtC3 10,t vrilll, nq Fluid.Density DFPN 8 Dr Dr~ F3 5~ R~S OH~ 0 06 ,eslsttvity of Mud::Sample ~ud-~Sample.Te~perature': MST DEGF 6~;~ RMF$ OHMM O: 52 sesist/v/ty o~'.mud'i!ltFete.~,s MFST DEG~ 6: Mud.~,rlltrate¢..,SampleTemperatu MCST DEGF 6, Mud..Ca~e...,SamPle:~.Tempe~ature TCS ~ j00 7'~AY Time:CirculatiOn StopPed BHT DEGF ... ZOO, TABLE TYPE ...... DEFI ,. DEPT Depth.,,Channel Name PHND Porosity From Enhanced Density PFDC Porosity Fromthe FDC Too! N~O Enhanced Vertical ~esolution Density ERDa Bulk Denslt¥ PEF. Photoe[ectrlc Factor D~HO Delta RHO cl~lu~ber~er A~es~e ¢om~ut~q .¢e.~e~ 3¸3 DK~I NPO'R MeutFon Porosity 0 From Application Prograe ostty NPH! Neutron Porosity SGR SpectFosoopy...GammaoRa¥ CGR ComPuted GR ~rom ThOriUm, Uranium, Potassium Thorium THOR POTA pore§slum URAN UFenlum R Speetroscopy Gamma-Rev .,R COmputed GR ~ro~ Thorium, Uranium, Potassium ?~OR ThoFlu~ DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB *,* I 66 2 66 3 73 4 66 5 66 6 ? 65 9 65 11 66 I~ 68 1 14 65 15 66 16 66 0 66 0 0 80 0 FT 68 1 1 ~m~m~m-mmmmm~mmmmmm~mmmm~mmmmm~mmm~mm~~m~mmm~mm~mm~m~mm~mm~mm~m~mm NAME 8ERV UNIT SERVICE APl AP1 APl APl FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE · (HEX) PHND SAN eU 548205 O0 000 O0 0 3 1. ~ 4 69 0000000000 PFDC SAN PU 548205 O0 000 O0 0 3 1 4 68 0000000000 NRHO PRE G/C3 548205 O0 000 O0 0 3 1 I 4 68 0000000000 ~oB CRC G/C~ 548205 O0 000 O0 0 3 t ~ 4 68 0000000000 P~ C~C 548205 O0 000 O0 0 ~ ~ ~ 4 68 0000000000 Chl. umberqer Alaska Computtn.~ Center 12-JUN-1991 09:45 ORDER # bOG TYPE CbRSS MOD NUMB 8AMP EbEN CODE {HEX) DRHO CR.C O/C3 S4e20S 00 N~Oe'SaN PU S4!~O~ oo T.,P~ SA., PU S O0 CG~ KAL GAPI ~48205 O0 KAL GAP', 48205 00 000 00 0 000 00 0 000 00 0 000 00 0 000 00 0 000 00 0 000 00 0 000 O0 0 000 O0 0 000 O0 0 000 O0 0 000 O0 0 000 O0 0 000 O0 0 1 I 4 68 0000000000 68 0000000000 I I 4 0000000000 i I 4 0000000000 000 000000 "ii ooo oooo.oo I ! 4 0000000000 I I 4 68 0000000000 0000 000000 I I 4 68 I I 4 68, 0000000000 I I 4 68 0000000000 I I 4 68 0000000000 I I 4 68 0000 I I 4 68 0000000000 0 00000 DATA DEPT RHOB TMPH THOR DEPT RHOB T~OR CRC 8Al~! KAL ALP CRC DEPT T~PH SAN THOR KAb ~-GR RbP DEPT RHOB CRC TNPH SAN THOR KAL CGR ALP OEP? eHoe CRC TNPH SAN THOR KAL CGR ALP 4666 500 2 -999 ~50 4600,000 4500'000 ,325 3!,404 ,705 81,860 4400,000 3! '239 ,567 ,335 6oe29o 4300.000 2,274 4~,045 ,371 42,172 PHND SA~ PEr CRC NPH! SAN POTA KAb THOR ALP PHND~SAN PEF,CRC NPHI,$AN PO?A,KAb THOR*ALP NPHI SAN POTA KAb THOR AbP PHND~&AN PEr,CRC NPHI,SAN THOR.AbP ; PHND SAN PEF CRC NPHI SAN POTR KAb THOR AbP 28 2O 19 24 22 ;~ PrD¢.,SAN ' ~l DR, HO,CRC I ~ :$GR'KA~ URAN~KA~ 250 POTA,AbP 426 PFDC,$AN 5~ SGR,K~b POTA,ALP 690 PrDC'BAN 62? URHO,ili 705 SGR, UR~N~K~ POTl,AbP 576 ~4 ??0 O45 PrOC SAN DRHO CRC~ SGR KAL RAN KAL OTA ALP la?DC SAN DRHO CRC 80R KAb URAN KAL POTA ALP ~.786 NRHO PRE ,033 NPOR SAN -999,.. 50 ALP -999, 50 UR ALP 20,426 NRHO PRE 991 CGR KAb 8OR AbP · 0.074 NPOR~SAN 103,181 CGR,KAb 2'e69 SGR,AbP 2,&3! URAN,Abe 24,880 NRHO,PRE NPOR ,SAN 0'00~ 71,47 CGR,KAb URAN,AbP ??0 NRHO.PRE 2~!009 NPOR.$AN $6,455 CGR~KAb 260 URANoAbP : 2, l 7 5 ::33,ell ~999,.250 999.'.250 "999'250 68,475 302 2,~25 38,058 80,913 58,530 0 5 4i 48 5~ 561 ~$, ?aPe Veri~,ic~t,ion D~PT~ R. HOB CRC TNPH SAN T~OR KAL DEPT RHOB CRC TNPH SAN THOR KAL CGR ALP DEPT RHOB CRC TNPH SAN THOR. KAL CG.R ALP DEPT. RHOB.CRC TNPH,'SAN THOR.KAL CGR.AbP 4200.:000 '74 4100000 I 762 49873 2696 26751 4000 O0 1. 9038 4907 96 2 3 6O B 3 -999 -999 ~050 PHND SAN PEr CRC POTi SAN KAL THOR ALP PHND.SAN PEr. CRC NPHI,SAN POTA.KAb THOR*ALP PHND SAN PEr CRC NPH! SAN PO?A KAL THOR ALP PHND..SAN PEr. CRC NPHI SAN PO?A KAL THOR ALP END Or DATA ** 34 53 60 "999 '999 102 214 935 803 603 873 841 134 180 49 952 PFDC.'~AN DRHO, ~C SCA,KAL URAN,KAb PO?A,AbP PFDC SAN DRHO CRC 8.GR KAb URAN KAL POTA ALP PFD¢ SAN DRHO CRC SGR KAb URAN KAL POTA ALP PFD¢ .8AN DRHO CRC SOR KAL URAN KAL POTA ALP , , O0 NPOR,SAN i~ig0$ NRHO.PRE CGR,KAb 169 URA~.AbP 53,803 NRHO.PRE T~,892 N'POR'SAN 37~939 CGR~KAb 55. SGR~AbP ~:. 84 UR. AN.AbP 44 '8G.,AbP URANeAbP -999 250 CGR~K. Ab -999 ~50 -999 '~SO SGR~AhP URAN~AbP I~.080 '104 41,060 51,;24! 24,,~5~ 38,35 1,482 40,:20 1.'S08 2~0"3 ?"999,250 :-999.250 .¸ER FIb~.NA~E : .003: SERVICE : FbZC V~RSiON : 001A06 DATE : 91/06/12 ~RX.REC $~E ~ t024 bAST rILE : **** TAPE TRAILER **** SERVICE NANE : EDIT DATE : 91/06/12 ORIGIN : Fbii TAPE NA~E , : ?45 ? CONTINUATION # : I " PREVIOUS TAPE : CON~ENT : CONOCO, SCHRADER BLurt, MIbNE PblNT UNIT G-S, 50-029-22138 ERVICE:NRME = EDIT REEL.NA~E ~ 74547 C~NTINUATION # ~ PREVIOUS REEb ~ CO~ENT ~ cONoco, SCHRADER BLUFF, 50-029-221:t 35 ;hlumber~er paqe ~, 500 WEST' XNTERNATiOAgN5L'''AIRPDRT8 ROAD, ANCHORAGE*,. ALASKA 9 t TAPE VERIFICATION LISTING LIS, FORMAT LIS TAPE VERIFICATXON FOR RFT FIELD* TAPE dob~Num'ber Nez! N&me County ~viCe Order Date~AcquLred Run Number Number ?A$47.. . MI_NE POINT UNIT 'SCHRADER. BLUFF NORTH SLOPE ALASKA 548205 O?'MAY'9! ONE ~02?'?NRU .0"$4 ,~h,!umbe~qer Paqe 2 500 NEST INTERNATIONAL AIRPORT ROAD ANCHORAGE. ,. AbRSKA 99518 907/562'2654 TAPE: VE:a:]:Ir:I:CATZON bis FORMAT ~ompa:fly amc well 'Name FLeld: Name County State~. Service Order Number: Date Acquired ~un Number' Oate Ptoeessed Files CONO¢OIN¢., $CHRADER. BbUrr NORTH:$bbeE AbA&KA' $4820S 07-MAYog! ONE RECEIVED dUN 1 ~ 1991 AJtmlm Oil & Gl. CoGs. ~ i: LIST Commend btstlnq KEY t ============================= Summary output~.~s created b¥~LIS~/~UMMARY .. · $ummartes'wrlt~en 'for bo~lcal LI$,~ructures~ F~LE (Abbrev~.r) b~$ IOqlCa~. f11e:tnfo TAPE (Abb'rev'~ T) LIS loqtcal'tape. 1nfo and for...the,.enttre.~8/A tnDut.'.l, oalCal u~it! LU .(Abbrev.l,b) Ll$/A'loqtce[ un[t.~nfo' The.f~el~'labels..appear on some or:*ell of these summaries, as,tnd~eate~ bY the a~brev, on r~qh~, Summary TAPES rILES PI UNITS Field babels~ Number of p~ys:~¢aZ. Feco~s Number of-log/cal..reqords iL~, Number g~ data.~ecqras Number encryp2e~'re¢ord ,,Number o~ data ~rames Primary Zndex channel name Prl.,ary ~ndex untt~mnemgnic Maximum prtmaF'¥ ~n!ex va~ue Minimum pr~mar¥.xnoex va~ue NOTE D~PTH OF PRESSURE TEST ~$:R~ORDED AS CHANNEL rDEP, FDEP IS ALSO. LISTED IN CONS,, TABLE ON TESTS NHERE THE CSU TABLES ~ERE DUMPED TO TAP~. FOR FORMATION TEST FXL~S. "D~PT* INCLUDED IN THESE LISTINGS DOES NOT REFER TO DEPTH OF MEASUREMENT BUT IS AN INTER~AL COUNTER USED WHEN MEASURING IN TIME, IN AN ATTEMPT TO KEEP. THIS L_ISTIN_G_ TO A REASONABLE LENGTH, ONLY SPECIFIC CHANNELS. AND CONSTANTS ARE LISTED,' THIS LISTING DOES NOT INCLUDE MANY OF THE CHANNELS AND CONSTANTS INCLUDED ON THE FIELD TAPE,! ~el header DEFAUb? 91/05/07 .ONTINUATION. #: I ?zvzous Tape header DEFAULT $~ TAPE H£ADER R VICE NAME : CRFTB ATE" ' : 9t/05/07 O~IGIN : DLIS TAPE'NA~E ~ : DE~AUL? C~NTINUATiON #1 1 ~ EVIOUS TAPE CDMMENT : PROCESSED BY SCHLUMBERGER DLI$ T~ ~I$ CONVERTER UTI~I?Y File header RFTB .027 ** :FILE HEADER F'IbE NAMEt RFTB ,'027 SERVICE NAME' JOB VERSION # : 4B0-162 DATE : 91/05/07 MAX,-R. EC~: LEN.I 8192 FILE TYPE : PREVIOUS FILE : Table type CON~ b~sting o~ set'-7 type. CONS DBdNAM STAT TUNI PUNI DESC VALU, FDEP ALLO F F FormatiOnlDePth.4295.' End of set Table type CON~ b~stinq.o~ set 8 type CONS- OBdNA# STAT TU#I PUNI'-:DESC VAbU ~nd of ;et II-dUN-91 15:26:38 Page.. 4 ~hlumberger ~ST ?able type: CONs · OB~NAN'STAT T~N! PU~I~DESC'..VA~U., End o~ set Data ~or*a.t.sp' ect~icati°n' ' record· h~Stin~ O~:'Set.l ty~e.64EB. ObjeCt ENTRY .V~LUE ~ ,REPCODE · ' 92 79 54 ~55 6666 , 0 73 4 8 66: £nd Of set AME SERV UNIT SERVICE APl APl APl APl Flb£ NUMB NUMB SIZE REP PROCESS · ID ORDER, # LOG TYP CLS MOD NUMB ELEN SAMP COD (HEX) ~P RFTB PSI 8! 400 0 :ii i !1 44 68 68 0000000000 0000000000 ~o.~ .~ .ltoo o ~T£~ RrTB 4 680000000000 ,.u~ ,.~ ~i,ooo I! i ' ' ,,oooooooooo 400 0 '. - I 4 . ~68~.0000000000 ~TNo.Rr?B 81..400 O. ! . I 4 68 0000000000 £nd of set Date record type ,O.TINE 4589596 ,5Ns ~?TM ~, '8GP 2232.189 PONE: i, P~E. 3. PHUN20 PTHO 2. ........ Data record type 0 TIMi 468'5596 o5HS ETIM 48, SGP 2230.458 PONE O, PTEN 3. PHU~ 2. PTHO 2. . Data record type 0 TIME.4?81596 .SMS ETIM 96, SGP 2230°324 PONE O. PTEN 3. PHUN 2, PT~O 2. Data,record type 0 , ETI~ 144~ SGP t763.832 PO~E 3, PTEN , - Data record type 0 TIME 4973596 ,SMS ETIM ~92. SGP 1763,648 PONE 3. PTEN 6. PHUN . PTHO Data record type .0 TIME 5069596 .'SMS ETIN 240. SGP:, 2229.?07 PONE 9. PTEN 2. PHU~-2~ PT~O 2. File trailer RFTB .027 **- FILE TRAILER FILE NA~E ~ RFTB ,027 SERVICE NAME = JOB. VERSION # ! 4BO-t62. DATE ; 91/05/07 MAXo~REC"LEN..~ 8192 ~ILE TYPE NEXT FZhE =hI. Umberqer LIS? ~TAOl []L:I:SA'DAT1 , .,! '3~ 40 0 ~l 954 TI~ ,:5~S , 45~9596. .5~6~39,.6 ,~ ,F'ZL~$:.TAPK8, , #hR #PR ...... eel header )ATE ~EEL NANE' ,. :ONTINUATION PREVIOUS REEL'I Tape header OEFAUbT RFTB 9t/o5/o? DEFAUbT pROC.EASED BY SCHbUMBERGER DL,1A TO bls CONVERTER UTILITY ** TAPE H~ADER ** TAPE NANE . I DEFAULT CONTINUATION #I PREVIOU& TAPE COMMENT I PROCESSED BY SCHLUMBERGER Dbl$ TO bis CONVERTER UTibITY header RFTB ,029 LIST MTAO~I:]bISA'.DA?~, II,.,JU~,,9! :[5~26~3~ Paqe 8 FIbE NAME I RFTB .029 SERV]CE N{NE ~ JOB ER~ZON ~ ~ 4B0-~62 ATE 191/05/07 ~AX. 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ED ' ORDER { BOG TYP ¢b8 MOD NUMB EbEM SiMP COD CHEX} ~,z. ,r,, ~ ~ ~g.t o 2~t ~ ~ ~aoooooooooo ,~._ ,r~ Ps~ ,t~ o o 2,t ~ ~ ~,oooooooooo ,o,~ ,r~, ,~~o o Ig~ , 4 s,oooooooooo ,~'. ,r~, s~~oo o ~ ~ 4 ~,oooooooooo 'HU~ RFTB 8! 400 0 ~9 ! ~ 4 68 0000000000 }THO RFTB 8! 400 0 9 I 1 4 68 0000000000 End ot set Data record type 0 TIME 5617334-,5M8 PHUN , PTHO Data record type 0 TIME 57133.34 ETIM 48. SOP 2206',91.? PONE 6, PTEN O. PHUN 2, PTHO 2. Data record type 0 TIME 5809334 PHUN 2. PTHO2' Data record tyue.. O.-TIME 5905334 ,SMa ............. ET:EM 144. SOP 1809,423 PONE 9, P~EN 0.' p,u,.,.......... ,,,o ~. .... Data record type 0 .TINE 6001334 ETIM ~92. SGP 1777,941 PONE PHUN , PTHO l, :hlumberger LIB? MTAO=[]'bISA.DA?I Il-JUN-91 15:26~38 Page O~ta. record tyoe 0 TIME 60973~4 ,SMS ETIM 240. BGP I173.6:91 PONE ), PTEN 7, PHUN '7, P?HO 1,. , , oata record type 0 71ME'6193334 .5M$ E?~M )36. 8GP 1772.063 'PONE 2. PTEN 7.' PHUN7. PTHO I. Data record type 0 ?IME 6385334 .5H$ ETXM 784. 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FI~E NAME I RrT8 ,030 SERVICE NAME I JOB VERSION # ! 4. BO MAX. RECi: GEN,t 8192 . .... #LA #PR #ENC #DR. #tM PI PX.UN~TS..MAXP! .... MXNP! ..... 47 54, ~ 2.5 2198. TINE · *SNS .... 6808126 ...... 8125326 TAPE SUMMARY mmmmmmmmmmmmmmmmmmmmmmmmmmm FXbES. #hR #PR I - 46 55 mmmmm~mmmmmmmmmmmmmmmmmmm~m :,hlumberqer L, IST M',/'AO:[]blSA,OATI ll-du~,,91 15~26~3B Paqe 16 R~b SUMMARY ..... '-1 1.. 49 ~el headeF D,E~AUbT ~ .R'Eb.~EAD~R )ATE, I 91/05/0? ~iOUS RZEb: :OMMENT : PROCESSED BY SCHLUMBERGER DLIS TO bis CONVERTER UTILITY Tape'header DEFAULT *~ TAPE HEADER S~RVICE NAME : CRFT8 · DblS O~iGIN : yEFAUbT CO'NT~NUATZON #) PREVIOUS:TAPE t .. CO~gT I PROCESSED BY SCHlUmBERGeR D~ZS rile~header RFTB .,03! FILE;NAME ! RFTB ,031 'SERVICE NAHE : jOB VERSION # I 4B0-~62 MAX,,~REC*,bEN.: 8192 FILE TYPE PREVIOUS FILE : ~able type CON8 biSt~nq o~ set ? tYPe,cONS .OBJNAH STAT TUN! PUNI DESC VAbU FDEP AbLO F r Formation DePth 43190008 £nd Ot met ;hlumberqer BI. 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O O, · Data record type o TIME 8726309 ETCH ½92, SGP 1765o969 PONE 5o PTEN 6. PHUN . PTHO I. Data record type 0 TIME 8822309 £TTM 240, SGP 1786.856 PONE 6, PTEN PHUN 7, PTHO Data record type. 0-TIME 69~6309 ~T~M 2880 SGP 1787e068 PONE PHUN 7 ' ' mPTHO 1, · · mmmmmmmmmlelmlmmmllmlmmmlmlmmlmemmpmmmmmmmmmelmlemBmmlmmmmlemlemmmmm :hlumber~er bEST MTAOt£]LISAoDA?; li-dU~-91 15{26{38 Paoe 19 Data record type 0 TI'ME 9014309 PHUN P?HO 2, TAle trailer RFTB .03t rILE NAME SERVICE MANE VERS'IOM # , NEXT FILE SUMMARY -#LA aPR #ENC .#DR #FM P! P.I.UNITS-,MAXP! MINP! 37 44 0 15 t253 TiME ,SM& 8342309 908i509 TAPE:.'$UM~ARY ~FILES .... #LA #PR .... 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Data record type O..T'IME 10265271 PHUN PTHO 0,. · · File traile ** FIbE TR rIbE..NAME VERSION # r RFTB I RFTB ,032 £ I dOB DATE I 91/05 7 ~AX.~REC,:bEN,.I 8192 FXbE. TYPE NEXT FILE rlLE.,SUMMAR¥ ............. '-..-.............-........-...........-....-....'........'....,,,.'.',,.,.,. #hR #PR #~NC ,~DR m~m~m~m~m~mmmm~mm . ~ 44 .... $! .- 0 19i4 :..TIME ,5MS . 930527~ ....... 10453071, TAPE,SUMNAR¥ ~ ribES. · -. ! ... 45 .52 REEL SUMMARY FILES TAPES- #hR #PR I I 46 $1 ~el header DEFAUbT R~TB : T~ , 91/05/0? ,~EE.L NtME I DEFAULT 2ONTINUATION {{ I PREVIOUS REE5 2DMMENT ' { PROCESSED BY SCHLUMBERGER D~IS TD LiS CONVERTER UTIL2TY Tape header DEFAULT S~RVICE NAME : CRFTB O~l~lN { D~IS' T'AP~ NAME .. { DEFAULT NTINUAT~ON. ~1 1 COMMENT I pROCESSED BY sCHLUMBERGER DbI8 E°F) F[le header RF~B **.. FILE HEADER Fi~E.NAMEI RFTB .035 SERVICE NAME dOB VERSION { { 4B0-162 Table type CONS b[stinq o~.met 1 t~pe..CONS OBdNAM 6T~T TUNt PUNI DE~C V~bU ,FDEP ALLOr F. Formation. DePth 4341,658 En~ o~ set ~hlumberger LIST Table type CON8 b~St~nq oi set 8 type OBJNAM STAT TUNI PUNI D~SC VALU End ot set Table tYpe'CON8 b~stino of set 9 type CON~ OBJNAM STAT TUN! PUN! DES~ VAbU ~nd of set Data format s~ec~t~cat~on record b~st~nq of set I! type 64EB objeCt 0 · ENTRY -VALUE' - REPCOD£ SIZE 0 66 5 0 66 6 0 73 4 7 IN 9 5MS 65 4 13 I 66 0 ! ~. 66. End o~ set · .bistinq o~set.o tY~eCXAN J~ME 8ERV UNIT SERVICE AP1 AP1 AP1 ~pI FILE NUmB NUmB &IZE RZP PROCESS ID. ORDER t. LOG~TYP CL$ MOD NUmB ELEM 8AMP ...... COD.(HEX) mmmmmmmemmemmmmmemmmemmmmememmmmmmmememmmmemmmmmmmmmmmmmmmmmmemmmmmmmemeeemmmM )?HOAr?B, 81 ,400 0 ! ! 4 $$- 0000000000 End o£ set ET~M 0., S~;P~ 2~52.ose PON£ ,2.:. P?EN 5. PHUN:2:, P?HO 2. Data .recOrd tYPe.' .O.TIME 12090276 .$M~S .......... E?XN 45, 8GP:, 2251,,999 PONE :~. PTEN S,?~ PHUN. 2., · PT'HO 2, ...... : Data record type .0. TXME. 12.:te6276 ,$~S ..... ETII~..96,. SGP ~560,804 .PONE: 0, PTE~ PHU~ 5, , p~HO ~, ..................... ii'IiiI~ilII Data record tvPe .0..?ll~E' ~2378276 ,SMS .... . . . . iiiiIilIIIIIilllilII~ii[111,iIiIIiiIilIIIIII1t11111'i! £?XN %92. 'SOP,: ~798..~6 PONE PHUN~,' PTHO' t® . ...... Data record type. ,O.TXNE 12474276 .,SNS. ~ . ETIM 2400~' 8GP. %794.758 PONE 4,' P~EN 9.:. IiiiiiiiiiIIiIiiiiliIIIIiiiIilIIIII~IIIiIiIilIIII i IIiili Data. record t¥ee: 0 ?XME. X2570276.,SM$ E?XM 288.' 8~P. {794,009 PONE 4. PTEN 9. mmmmmmmmmmmmmmmmlmmmmmmllmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmm~mmm)m chlumberqer bEST MTAO=[]b:[SA,DAT~ Il-dUN-9! 15125~38 Peqe 27 ETZM 336. SGP 1793.611 PONE 3. PTEN 9, PHUN7 . PTHO Da'~a record type 0 TIME ~2762276 ETIM~84, SGP. ~252,' PONE 2. PTEN $.~ PHU~ 2' PTXO., Data record type 0 TIME 128582?6 ,5MS- ETIM 432, SGP 2251,95t PONE t., PTEN PHUN 2, PTHO 2, FILE.NAME ~ RFTB SERVICE NAME I JOB VERSION # ~ 4~0'~6270 DATE I 9~/05/ MAX,:: RECi-~EN,.{' 8192 FiLE TYPE NEXT FILE FILE.SUMMARy .... #LR~ !PR .#ENC #DR . .#EM ..... PI .....PI.UNITS MAXPZ .... MINP! ,, 40.. 47 ..... 0 .t8 , 1556 .TIME ,5M$ .11994296.~ 12927276 TAPE.SUMMARY, · FILES #UR .#PR ~ 1 41 48 :hlumbetqet' LiST MTAO!E]bISA,DA?'t II.dUN,.91 15126138 Page 28 . FIb~$',TAPE$ #LA #PR eel header 5~R. ViCE NAME I RFTB · DR?r: I 9%/05/07 3RIGIN I DbZ8 REEb',,NAME... CONTINUATION ~I PREVIOUS REEL"! COMMENT' : PROCESSED BY SCHLUMBERGER DbES Tb bis CONVERTER TaPe header DEfaULT DATE 1.91/05/07 O~ZGIN, : OLES TAP~ NAME . I DEFAULT C~NTENUAT!ON #l PREVIOUS ?APE COMMENT I pROCESSED BY SCHLUMBERGER Obis:Th'LIS CONVERTER: UTXLETY' ri~e header RrTB .036 *~ FILE HEADER rlLE~NAM£ I RFTB ,036 SERVICE NAME t JOB VERSION #. l DATE I ~AX.:REC'~LEN,I TILE ~¥PE. 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I 4 68 0000000000 SGP RFTB PSI 81 400 0 36 i ! 4 68 0000000000 PONE RFTB PTEN RFTB 818 400 0 ~6 I ! 4 69 0000000000 ! 400 0 ~6 t I 4 68 0000000000 PHUN RFTB Bi 400 0 }6 ! ! 4 68 0000000000 PTHO.~FTB : 81 400 0 - · 36 I .! 4 68 0000000000 End Of set .-hi'Jmbez'qer: L,~,ST ~TAOi []i.,ISA.DA'I'I Il-dUN-91 {,5~26~38 Paqe 30 Data record type 0 TIME 13490451 ETIM ~, SGP 2299,778 PONE PHUN, , PTHO Data record type 0 TIME 13586451 ,5MS ~TIM 48, SOP 2299,891 PONE 9, PTEN 9,- PHUM 2, PTHO 2, Data record type 0 TIME 13682451 ETZM 96, SGP 17'05,759 PONE 5. PTEN 0.~ PHUN 7, PTHO Data record tvpe 0 TIME 1377'8451 ,SMS ETIM!'44, SGP 1820,37 PONE 0, PTEN 2,'~ PHU~ 8, PTHO Data record type 0 TIME 1{974451 ,SMS ETIM ~92, SGP 2299,929 PONE 9, PTEN 9.~ PHUN2, PTHO 2, Data record type 0 TIME 13970451 .SMS E?TM 240. SGP 2299,e37 PONE 9. ~TEN 9.- PHUN 2, PTHO2'~ r~le tra~ler t~rTS .036 FILE NAME I RFTB .036 SERVICE NAME VERSION # /05/07 DATE ' ~192 ~AX. REC~ FI~ETYPE NEXT FILE i0 .... ~6! 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Data record type O.TINE 15639531 .5MS E?IN ~40, 5GP-. 2345.209 PONE 5, PTEN 4. PHUN , PTHO.-2, ETZN 289',: SOP 2345,162 PONE: 5, PT~N 4.; PHUN 3, PTHO 2, F~le trailer RFTB .038 ,'hlumbe~qer LIST M?AO~.[]LIsA.DAT; Il-dUN-9! 15126:38 Paqe 38 ** FILE TRAILER ** :rILE, NAME t RFTB ,038 'SERVICE NAME I JOB VER&ION# I 4B0'162 DATE I 91/05/07 MAX., REC.:bENes,: 8192 FILE TYPE FILE SUHMARY #LA #PR #ENC #DR #FM PI PI.UNITS MAXP.I MiNPI 34 41 0 12 995. 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' .... . °~ OH&d °~ N~Hd '~ N3&d '9 3NOd L~8'9~ ~'dD9 ')OSK 9W~' 09~08~9 3NI& 0 ~A~ p~oaa~ "' ;~ OH,T,d '~; NI'1Hd mt~m~mimemmmmemm~m~mmmmmmmmam, mm,mmmmmmmmmmmmm~m~mmmmmmmmmmmmmmmmmmmmmmmmmmmm ~W~" 09~60L~9 3W%& 0 e~% p,zoaa,z e%eO '~ N3~d '8 3NOd [~g'SEgg dgg '80 WI&3 mmmmemmmemmmmmmmmmmemmmmmmmmm.m~em~mmmjemmemmmmmmemmmmmmmmmmjmmmemmmm. / 'g N3~d 'B 3HOd 666'Gggg "dD~ 'gl WZ&3 *~ OH&d '~ N~Hd '~ N3~d 'E 3NOd 6T6*E~ dDg "~9~£ WI&3 · . llimijiilii/imi.ilili/Jiiii,limlmiill/iiimkilimilJiiilliijlilllililii/ '~ OH&d ' ' 'g N~Hd 'T N3&d '8 3NOd 6~'STZ dD~ '9'T~[ WZ$3 ~Wg' ogg6EgT9 3WI& 0 .ad~l PlOOaI e~eO , E~T' aeed 6~:9~tgT TG,,,NA~'TT mmmmmmmm#mmmmmm~mmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmm ' ? *~ OH&d "*~ NflHd °L N3&d '*0 3NOd ~6~*OL~ 'dDg ~0~8~ Wl&~ mmmeemmemNmemmmmmmmNmmmemmm~mmmmNNmmmmmmmmmmmmmmmmmmemmmmemmmmmmmmmm " g#g' O9~LL~g ~wI& 0 adAl:P~o~a~ e%eO ., mmmiiiimmiililim/iiilmmilmiim,mliliilili#ImmmimltiM.iiliimlmmmmiilimii .... ~'g OH~d "g NflHd mmmmiiIM!ImmM!l!:MimMiillml,miimMiiiilm.lii,iiimmi, imllilii, iliimilimmiiml ............................ · .$' 09~S,$~C9 3~Z&"'O ..e~3 ,miimilliiiil!Mmiillmiiimiimil/lilmm.ii,llmlill, lmilmiimmiliii#mliiiiili ,:,.. m, mmliliimliilmml,iilIllmil, lmlimlliliiilllmlmlilliMmliliillilliliillii' ..... *~ OH~d '~ NA.Hd '*S N3~d iL 3NOd ~96iL$~ dDg '8~9~ Nl~3 NHH~ g N3~d '~ 3NOd 96u*~=~ ' '"dgg '00 WI&3 mmmmm.m~Imm~mm~m~mmmm..mm,~mmmi~i,m~mi$.~mm~li~'i.mmmm.~mmmmlmm~mm -gwg' OggL66T9 3HZ&-O ,a~ p~O~i e~O mmmmmammmmmmmamammmmmm~emmmnmmmmamaimmemmlmmmd, eimalammmimmmmmemmmimm '; OH&d '[ NOHd :~'6 #3&d '"G 3NOd LT&"66;. 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