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183-142
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, March 1, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 14-35 PRUDHOE BAY UNIT 14-35 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/01/2024 14-35 50-029-21018-00-00 183-142-0 W SPT 8229 1831420 2000 1264 1265 1265 1266 89 271 274 272 REQVAR P Adam Earl 1/15/2024 MIT-IA tested as per AIO 4E.021 to max ant. Inj. Psi of 2,000 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 14-35 Inspection Date: Tubing OA Packer Depth 209 2506 2479 2464IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240117082709 BBL Pumped:6.4 BBL Returned:4.8 Friday, March 1, 2024 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor 1 �/ FROM: Austin McLeod Petroleum Inspector I Well Name PRUDHOE BAY UNIT 14-35 Insp Num: mitSAM220108164742 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, January 11, 2022 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 14-35 PRUDHOE BAY UNIT 14-35 Src: Inspector Reviewed By: P.I. Supry Jam_ Comm API Well Number 50-029-21018-00-00 Inspector Name: Austin McLeod Permit Number: 183-142-0 Inspection Date: 1/8/2022 Tuesday, January 11, 2022 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 14-35-- Type Inj W - TVD 8229 Tubing 1556 ,i - 1554 -1 1551 - 1551 PTD 1831420 SPT Test,, Type'Test psi 2136 JA 494 X396 , 2424 2383 - BBL Pumped: p 4 BBL Returned: 4 - OA 441 t , 617. 611 , t 610 - Interval REQVAR iP/F P - Notes: 2 year to 1.2x MAIP. MAIP 1780psi. AIO 4E.021. Tuesday, January 11, 2022 Page 1 of 1 MEMORANDUM State of Alaska Insp Num: miu7200116155600 Alaska Oil and Gas Conservation Commission TO: Jim egg � R�/2 DATE: Thursday, January 23, 2020 P.I. Supervisor` 4/a� SUBJECT: Mechanical Integrity Tests Well BP Exploration (Alaska) Inc. Type Inj 14-35 FROM: Jeff Jones PRUDHOE BAY UNIT 14-35 Petroleum Inspector 1031 - See: Inspector Reviewed By: P.I. Suprvlm--- NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 14-35 API Well Number 50-029-21018-00-00 Inspector Name: Jeff Jones Permit Number: 183-142-0 Inspection Date: 1/16/2020 ✓ Insp Num: miu7200116155600 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 14-35 Type Inj w, TVD 8229 - Tubing 1031 - 1033 -� 1033 - 1033 - 1032 - PTD 1831420 Type Test sPT Test psi 2057 - IA 39 2499 _ 2494 - 2489 2486 - BBL Pumped: "BBL Returned: 42 OA 47 156 - 154 157 161 Interval REQVAR P/F P Notes: I well inspected, no exceptions noted. AID 4E.021 , IA x OA communication. Thursday, January 23, 2020 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,January 17,2018 TO: Jim Regg P.I.PSupervisor 'Fell. l(1 11l S SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 14-35 FROM: Jeff Jones PRUDHOE BAY UNIT 14-35 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 14-35 API Well Number 50-029-21018-00-00 Inspector Name: Jeff Jones Permit Number: 183-142-0 Inspection Date: 1/16/2018 Insp Num: mitJJl80116201451 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min We❑ 14-35 Type Inj W 'TVD j 8229 ' Tubing 1293 - 1294 - 1294 - 1294 PTD 1831420 'IType Test SPT Test psil 2057 ' IA 96 2500 ' 2484 - 2472 rt BBL Pumped: 5.5 - BBL Returned: 5.3 ' OA 238 419 - 414- 411 Interval REQVAR P/F P s% Notes: AA 4E.021:IA x OA communication.MIT-IA to 1.2 X max.injection pressure. 1 well inspected,no exceptions noted. - • `i SC kit*6( Wednesday,January 17,2018 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Monday,June 20, 2016 5:21 PM To: AK, OPS FS3 OSM;AK, OPS FS3 Facility OTL;AK, OPS FS3 Field OTL;AK, OPS FS3 DS Ops Lead;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC EOC IL;AK, OPS PCC Ops Lead;G GPB FS3 Drillsites;Vohra, Prachi;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep;AK, D&C Well Integrity Coordinator; McVey,Adrienne; Hibbert, Michael;Janowski,Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J; Regg, James B (DOA) Subject: OPERABLE:Injector 14-35 (PTD#1831420) Passed MIT-IA All, Injector 14-35 (PTD#1831420)was put on injection on 06/11/16, and passed an AOGCC-witnessed MIT-IA on 06/19/16. The well is reclassified as Operable. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376trAttaJAN 0 41i.01. Email: AKDCWellIntegritvCoordinator@BP.com From: A , :C Well Integrity Coordinator Sent: Thursday, ne 09, 2016 2:59 PM To: AK, OPS FS3 OS • 'K, OPS FS3 Facility OTL; AK, OPS FS3 Field OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Supe '• endent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr, , RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; 'chris.wallace@alaska. •v'; Vohra, Prachi Cc: AK, D&C DHD Well Integrity Enginee , 4K, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; 'Regg, James B (DOA) (jim.regg@ialaska.gov)'; Vey, Adrienne; AK, D&C Well Integrity Coordinator; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Core'; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, Aras J Subject: UNDER EVALUATION: Injector 14-35 (PTD #18314 c Surface Work Complete All, Injector 14-35 (PTD#1831420) is ready to be placed on injection.The well is recla ied as Under Evaluation. Plan forward: 1. Valve Shop: Replace tree/pull back pressure valve—DONE 12/13/14 2. Wellhead: Perform PPPOT-T—PASSED 12/21/14 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Monday,June 20,2016 P.I.Supervisor �Q?i (fll z (I�` SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 14-35 FROM: Matt Herrera PRUDHOE BAY UNIT 14-35 Petroleum Inspector Src: Inspector Reviewed By: P.I.SuprvJg! L__ NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 14-35 API Well Number 50-029-21018-00-00 Inspector Name: Matt Herrera Permit Number: 183-142-0 Inspection Date: 6/19/2016 Insp Num: mitMFH160619193726 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well i 14-35 - Type Inj w- TVD 8229 Tubing 958 959 . 959 _ 959 _ 960 - 966- PTD 1831420 - Type Test SPT Test psi 2057 • IA 246 2601 . 2583 . 2571 , 2561 _ 2552 . Interval REQVAR P/F P OA 230 357 362 364 , 365 - 365. Notes: AIO#4E.021 Field Inspector could not conclusively determine IA pressure loss was not constant due to increase in flowing tubing pressure. An increase in rate resulting in higher tubing pressure would result in higher injection temp thus in my opinion compensate IA pressure drop.Not a true reflection of IA pressure drop to show true stabilization.Noted less than 10%overall loss.Test pressure 2600 PSI.Per J. Regg-test result is a Pass. c/ SOAKED DEC 2 9 2U16 Monday,June 20,2016 Page 1 of I • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday,June 09, 2016 2:59 PM To: AK, OPS FS3 OSM;AK, OPS FS3 Facility OTL;AK, OPS FS3 Field OIL;AK, OPS FS3 DS Ops Lead;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC EOC IL;AK, OPS PCC Ops Lead;G GPB FS3 Drillsites;Wallace, Chris D (DOA);Vohra, Prachi Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Regg,James B (DOA); McVey, Adrienne;AK, D&C Well Integrity Coordinator; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel,Troy; Worthington,Aras J Subject: UNDER EVALUATION:Injector 14-35 (PTD#1831420) Surface Work Complete All, Injector 14-35 (PTD#1831420) is ready to be placed on injection.The well is reclassified as Under Evaluation. Plan forward: 1. Valve Shop: Replace tree/pull back pressure valve—DONE 12/13/14 2. Wellhead: Perform PPPOT-T—PASSED 12/21/14 3. Slickline: Pull dummy subsurface safety valve plug/reset dummy subsurface safety valve—DONE 06/04/16 4. DHD: Perform MIT-IA—PASSED 06/08/16 5. WIS: Reclassify as Under Evaluation—DONE 06/09/16 6. Operations: Place well on injection 7. DHD: Assist Operations with POI 8. DHD: Perform AOGCC-witnessed MIT-IA once well is thermally stable Please reply if in conflict with proposed plan. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) SCANNED JAN ) 6 2017 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWelllntegrityCoordinator@BP.com From: AK, D&C rity Coordinator Sent: Friday, November 21, 21 _ • 5 AM To: AK, OPS FS3 OSM; AK, OPS FS3 DS •• -.d; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, • - _K, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Chou, Irwin; • .*PS FS3 Facility OTL; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integri 'neer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; 'Regg, James B(DOA) (jim.regg(aalaska.gov)' Subject: NOT OPERABLE: Injector 14-35 (PTD #1831420) Possible Tubing x Inner Annu ' ommunication 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, January 15, 2013 TO: Jim Regg (—), P.I. Supervisor Ice4 I 1 7- 4 ( t 3 SUBJECT: Mechanical Integrity Tests ft BP EXPLORATION (ALASKA) INC 14-35 FROM: Bob Noble PRUDHOE BAY UNIT 14-35 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprvjr>,e— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 14-35 API Well Number 50-029-21018-00-00 Inspector Name: Bob Noble Permit Number: 183-142-0 Inspection Date: 1/8/2013 Insp Num: mitRCN130108174536 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 14-35 - IT 1 • 8229 - T A [ F .,,,, ', 521 7 2424 1 2426 I- 2422 , I 2420» ype nj 1 w1TVD PTD 1831420 ' Type Test SPT Test psi 2057 I OA 1 438 i 617. I 607 I 606 r, 608 [ , , I I I -I --1 I Interval REQVAR IP/F P ' I Tubing [ 674 - I 624 _I 616 I 616 611 - , Notes: 4.07 bbls pumped AA 4E.021 .., , . SCANNED APR 1 1 2013 Tuesday, January 15, 2013 Page 1 of 1 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, February 09, 2011 TO: Jim Regg P.I. Supervisor 'e1q 2 1 it SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 14 -35 FROM: Chuck Scheve PRUDHOE BAY UNIT 14 -35 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J FS', 2 --- NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 14 -35 API Well Number: 50- 029 - 21018 -00 -00 Inspector Name: Chuck Scheve Insp Num: mitCSl10207130411 Permit Number: 183 -142 -0 Inspection Date: 2/5/2011 - Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 14 - ` Type Inj. W TVD 8229 / 1 IA 560 2500 - 2500 2500 = P.T.D 1831420 TypeTest i SPT Test ps i i 2057 O 740 840 840 840 Interval RE " P/F P Tubing 950 950 950 950 Notes: Li .�, c A. r APR 1 3 t Wednesday, February 09, 2011 Page 1 of 1 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 t~~.6'~:~~~ ~ J~i`.i ~. Chi; Dec 07, 2009 ~~ ~ , ~.€_ C~~C % ~ ~Q~i9 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 14 Dear Mr. Maunder, 1 ~,,E - 3 u Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 14 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-14 Date: 12/05/09 ~•r Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 14-01A 1931850 500292031701 Sealed Conductor NA NA 14-02C 2071150 500292031803 Sealed Conductor NA NA t4-03A 1961290 500292031901 Sealed Conductor NA NA 14-04A 1961640 500292032001 Sealed Conductor NA NA 14-05A 1920010 500292032701 Sealed Conductor NA NA 14-O6A 2040360 500292032801 Sealed Conductor NA NA 14-07 1780660 500292032900 Sealed Conductor NA NA 14-OSA 2022100 500292033001 Sealed Conductor NA NA 14-09B 1820340 500292053402 Sealed Conductor NA NA to-t0 1801300 500292052800 Sealed Conductor NA NA is-11A 2051260 500292052901 Sealed Conductor NA NA 14-12 1811090 500292063100 Sealed Conductor NA NA 14-13 1811010 500292062400 Sealed Conductor NA NA 14-14 1811020 500292062500 Sealed Conductor NA NA 14-15 1810840 500292061100 Sealed Conductor NA NA t4-16A 1971670 500292060801 Sealed Conductor NA NA 14-17A 2030010 500292056201 Sealed Conductor NA NA 14-186 2071290 500292055102 Sealed Conductor NA NA 14-19 1810450 500292057800 Sealed Conductor NA NA 14-20 1810700 500292059800 Sealed Conductor NA NA 14-21A 2051070 500292075601 Sealed Conductor NA NA 14-22A 1921230 500292074701 Sealed Conductor NA NA 14-23A 2090200 500292075701 NA 4 NA 25.50 10/20/2009 14-24 1830910 500292097000 NA 0.6 NA 3.40 10/20/2009 14-25 1831020 500292098100 NA 2.1 NA 15.30 11/16/2009 t4-26 1811100 500292063200 Sealed Conductor NA NA 14-27 1831700 500292104600 NA 3 NA 17.00 10/25/2009 is-213 1820120 500292070800 Sealed Conductor NA NA 14-29 1811680 500292068000 Sealed Conductor NA NA 14-30 2050940 500292067901 Sealed Conductor NA NA 14-31 1831110 500292098900 Sealed Conductor NA NA 14-32 1831220 500292099900 NA 0.6 NA 3.40 10/19/2009 14-33 1831250 500292100200 Sealed Conductor NA NA 14-34 1831330 500292101000 NA 7.3 NA 47.60 10/20/2009 14-35 1831420 500292101800 Sealed Conductor NA NA 14-36 1831630 500292103900 NA 0.7 NA 3.40 10/20/2009 14-37 1880490 500292181000 NA 1.3 NA 5.10 10/20/2009 14-38 1881030 500292186200 NA 0.8 NA 3.40 10/24/2009 14-40A 2011350 500292187501 Sealed Conductor NA NA 14-41 1920960 500292229000 NA 0.8 NA 6.80 10/18/2009 14-43 1921080 500292229600 NA 1.4 NA 10.20 10/23/2009 14-44A 2021930 500292257301 NA 10 NA 88.40 11/24/2009 . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~::~~~~~ .yi ~°i, ~~i ~ iJ ~ U 1. Operations Abandon ^ Repair Well- ^ Plug Pertorations ^ Stimulate^ ~ .~'IQi1~f111SSIG , Performed: Alter Casing Pull Tubing ^ ^ Perforate New Pool Waiver Time Extension r ,, SET ^ ^ ^ ~1-~i~~~~~~~ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well^ ' 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^ Exploratory ^ ~" 183-1420 3. Address: P.O. Box 196612 Stratigraphic^ Service Q 6. API Number: Anchorage, AK 99519-6612 ~ 50-029-21018-00-00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO-028312 ~ PBU 14-35 10. Field/Pool(s): prudhoe bay FIELD /prudhoe bay POOL 11. Present Well Condition Summary: Total Depth measured ~ 9500 feet Plugs (measured) 9086' sp 12/11/09 feet true vertical ~ 9243.5 feet Junk (measured) None feet Effective Depth measured 9500 feet Packer (measured) 8404 true vertical 9244 feet (true vertical) 8229 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 48 - 128 48 - 128 Surface 2628 13-3/8" 72# I-80 47 - 2676 47 - 2676 4930 2670 Intermediate 8772 9-5/8" 47# 1-80 46 - 8620 46 - 8616 6870 4760 Production Liner 987 7" 29# I-80 8513 - 9500 8331 - 9244 8160 7020 Liner Pertoration depth: Measured depth: see attached - _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 SURFACE - 8540 SURFACE - 8356 Packers and SSSV (type, measured and true vertical depth) 9-5/8"X4-1/2" BKR S-3 PKR 8404 8229 12. Stimulation or cement squeeze summary: Intervals treated (measured): <~_ .{ a, ~~ ~~ `~ ~ ~ l ~~ . r ~1~;j Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 19280 1428 Subsequent to operation: 17184 1738 14. Attachments: 'h(. Well Class after work: oZ/ E Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^~ A,Q y • Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL GSTOR ^ -1Ah4~-~- GINJ ^ ~,//~ WINJ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exe mpt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 1/8/2010 Form 10-404 Revised 7/2009 Submit Original Only RBDMS JAN 1120 i•/I r~ ~ ,~;,,,,~ 14-35 183-142 PFRF ATTA(_HMFNT Sw Name Operation Date Perf Operation Code - -- -- - -- Meas Depth Top - - -- - ------ - - Meas Depth Base Tvd Depth Top Tvd Depth Base 14-35 3/31/85 PER 9,072. 9,092. 8,848.01 8,866.46 14-35 3/31/85 PER 9,095. 9,105. 8,869.22 8,878.44 14-35 3/31/85 PER 9,114. 9,124. 8,886.74 8,895.97 14-35 3/31/85 PER 9,132. 9,142. 8,903.35 8,912.58 14-35 3/31/85 PER .9,145. 9,155. 8,915.35 8,924.58 14-35 11/29/89 SQZ 9,072. 9,155. 8,848.01 8,924.58 14-35 12/6/89 RPF % 9,145. 9,155. 8,915.35 8,924.58 14-35 12/6/89 RPF 9,132. 9,142. 8,903.35 8,912.58 14-35 12/6/89 RPF 9,114. 9,124. 8,886.74 8,895.97 14-35 12/6/89 APF 9,155. 9,158. 8,924.58 8,927.35 14-35 12/6/89 APF 9,131. 9,132. 8,902.43 8,903.35 14-35 12/6/89 APF 9,124. 9,128. 8,895.97 8,899.66 14-35 12/6/89 APF 9,110. 9,114. 8,883.05 8,886.74 14-35 12/6/89 APF 9,142. 9,145. 8,912.58 8,915.35 14-35 2/16/99 APF 9,173. 9,178. 8,941.2 8,945.82 14-35 7/27/02 FIL 9,161. 9,178. 8,930.12 8,945.82 14-35 7/29/02 APF 9,056. 9,066. 8,833.25 8,842.48 14-35 7/29/02 APF 9,025. 9,045. 8,804.65 8,823.11 14-35 7/29/02 APF 9,070. 9,085. 8,846.17 8,860. 14-35 7/29/02 APF 8,960. 8,980. 8,744.69 8,763.13 14-35 7/29/02 APF 8,990. 9,010. 8,772.35 8,790.81 14-35 12/11/09 SPS ,086. ~ 9,178. 8,860.92 8,945.82 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT S SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 14-35 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 12/9/2009 CTU #5 w/ 1.75" CT: Sandback. MIRU CT Unit. «Interact Publishing» Well l injecting on arrival. SI well and RIH with BOT Nipple locator. Tag TD at 9287' CTMD. PUH to TT slight overpull continue PUH to XN Nipple good sign repeat . =POOH to change BHA for sand drop. RIH w/ 2.25" BDN '"**Job Continued on X12/10/09 WSR *** 12/10/2009 12/11 /2009 CTU #5 w/ 1.75" CT: Sandback. MIRU CT Unit. «Interact Publishing» Continued from 12/9/09 RIH w/2.25" BDN for sandplug park at flag at 9277' lay in 3500 # sand. PUH to 8500' wait for sand to settle. RIH to tag looks like sand still falling. PUH wait for sand. Make multiple tags while sand settling out. Repeatable tag after first dump found at 9240'. Lay in 3350# of river sand. PUf to 8500' and wait for sand to settle. Repeatable tag after second sand dump at 9061'. Perform infectivity test. Well injecting at 1570 psi WHP at 1 bpm. POOH. MU and RIH with BOT nipple locator for depth control.Tagged sand top at 9086' tagged twice POOH. ***Job Continued on 12/11/09 *** ~~ ~~.e.~~ ~a _~~,._..~._.~ ~..~m CTU # 5 Set sandplug (interact publishing) **" Continued from 12/10/09 *** ,r- 'POOH Tag at surface RDMO notify DSO to put well back on injection. ****Job (Complete "**" FLUIDS PUMPED BBLS 35 FRESH WATER 169 60/40 METH 17 gel 29 SLURRY 250 Total TREE = 7-1116" X 5-1 /8" FMC WELLHEAD ~ GRAY GEN 3 ACTUATOR = AXELSON KB. ELEV = 69' BF. ELEV = KOP = 6000' Max Angle = 27 @ 6800' Datum MD = 9095' Datum TV D = 8800' SS PERFORATION SUMMARY REF LOG: BHCS ON 11/12183 ANGLE AT TOP PF.RF: 23 @ 8960' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 4 8960 - 8980 O 07/29/02 3-318" 4 8990 - 9010 O 07129102 3-318" 4 9025 - 9045 O 07!29/02 3-318" 4 9056 - 9066 O 07/29/02 3-318" 4 9070 - 9085 O 07/29/02 3-118" 4 9071 - 9091 S 11 /29/89 3-118" 4 9094 - 9104 S 11/29189 3-3/8" 4 9110 - 9128 O 12106(89 3-118" 4 9113 - 9121 S 11/29/89 3-118" 4 9131 - 9151 S 11/29/89 3-318" 4 9131 - 9158 O 12/06!89 3-118" 4 9144 - 9154 S 11/29189 2-7/8" 4 9173 - 9178 O 02/16/99 GAS LIFT MANDRELS $554' ELMD TT LOGGED 02/16/99 DATE REV BY COMMENTS DATE REV BY COMMENTS 11123!83 ORIGINALCOMPLETION 12/12/09 JKC/PJC SAND PLUG 01/05/99 LAST WORKOVER 02/26/01 SIS-MD FINAL 09/04/01 RN/TP CORRECTIONS 07/29/02 TMN/KK ADPERFS 02!23107 ???/TLH WELLHEAD CORRECTIONS PRUDHOE BAY UNff WELL: 14-35 PERMIT No: 1831420 API No: 50-029-21018-00 SEC 9, T10N, R14E, 5.31 FEL 66 FNL BP Exploration (Alaska) 1 ~ ~~ ~ I ALLOWED ***~- ~,6} i y ~'. az ~ INJECTION -L •07 • ~~ MU~EWgY~/1-II~~f, Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~~~~~~ a9 ~Id `~ ~~S ~S, , 165S94:St ~flC~1~i Log Description N0.5271 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD osiosios H-35 14-35 06-08A AYTO-00018 ANHY-00087 AV1H-00012 CROSS FLOW CHECK L INJECTION PROFILE -" IBP/FBS/CFS/GRADIO/PRESS/T P _ 05/09/09 05/15/09 05/11/09 1 1 1 1 1 A-44 AWL8-00017 SCMT 05/25/09 1 1 12-07A BOCV-00016 SBHP SURVEY 05/19/09 1 1 09-24 ANHY-00088 CROSS FLOW CHECK/IBP ~ 05/17/09 1 1 H-29A AYOO-00027 PPROF/RST - 05/19/09 1 1 09-09 AYTU-00032 CROSS FLOW CHECK - , 05/06/09 1 1 15-458 ANHY-00010 PRODUCTION PROFILE ~- 05/09/09 1 1 13-13A AYTU-00033 USIT - ~ ' ~ 05/08/09 1 1 M-19B AY3J-00024 PRODUCTION PROFILE 05/14/09 1 1 Z-12 ANHY-00084 INJECTION PROFILE 05/07/09 1 1 E-36A BiJJ-00018 MEM CNUSTP / 05/18/09 1 1 X-30A B2WY-00005 MEM PROD PROFILE C 05/10/09 1 1 12-23 AYKP-00021 USIT L - 05/08/09 1 1 W-34A AWJI-00031 MEM PROD PROFILE 05/19/09 1 1 Z-14B AZCM-00022 PROD PROFILE/JEWELRY LOG • (O- 05/20/09 1 1 L1-21 B2NJ-00006 PRODUCTION PROFILE 05/24/09 1 1 A-31A AZCM-00023 USIT ~C - Q {~ L 05/22/09 1 1 H-19B' B2WY-00004 MEM PROD PROFILE t- 05/07/09 1 1 G-16 AYKP-00022 SCMT / / - 05/09/09 1 1 M-198 AY3J-00024 SCMT 05/15/09 1 1 12-37 AWL9-00032 PRODUCTION PROFILE _ Uu ` 04/21/09 1 1 11-04A AYOO-00028 USIT / L(~ 05/21/09 1 1 18-30 B1JJ-00015 MEM PROD PROFILE jGJ 05/13/09 1 1 4-14A/S-37 AYKP-00024 PRODUCTION PROFILE ~ - ~ i 05/11/09 1 1 3-37/L-35 AWL9-00035 PRODflNJECTION PROFILE 05/22/09 1 1 3-37/L-35 AWL9-00035 TEMPERATURE SURVEY 05/20/09 1 1 V-217 AYOO-00024 INJ PROFILE/RST WFL `} /~}/,'S 04/26/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EAGti TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 g ~~ 900 E. Benson Blvd. ~ `5 `4 ~ ,~ ~+i~ ~ 20~~s tc~ Os: ~"1l~Lr Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 MEMORANDUM To: Jim Regg `,v~/ II~~~~~ P.I. Supervisor ""7`( FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 21, 2009 SUBJECT: Mechanical Integrity Tests BPFXPLORATION(ALASKA)INC 14-3s PRUDIIOE BAY LIN1'I' 14-3s Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~~ Comm Well Name: PRUDHOE BAY UNIT 14-3s API Well Number: 50-029-2 1 0 1 8-00-00 Inspector Name: John Crisp Insp Num: mitJGr090120135350 Permit Number: tx3-Iaz-o Inspection Date• ti13i2oo9 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. __ _ __ 'Well to-3s TYPe Inj. N' TVD _ 82'9 IA zso zaoo ~' ?390 2390 P.T. Is3lazo 'TYPeTest sPr I Test psi zos~.zs '~ OA 300 3~0 3~0 3~0 ...Interval REQvAR P/F _ P _ . ~ Tubing ~ ezo ~za czo bzo __ _ __ Notes' 2 bbl's pumped for test. AA compliance. A r-~ 4E . C~z-i Wednesday,.lanuary 21, 2009 Page I of I • SdRa2t9 RALIAi, G0~IERNOR ~~lj ~ ~ 333 W. 7th AVENUE, SUITE 100 ~~TT Pt~~ ~+ a ~y ®A~~~~~~~3®S~ ~®~ i® ANCHORAGE, ALASKA 99501-3539 67 id PHONE (907) 279-1433 FAX (907) 276-?542 ADMINISTRATIVE APPROVAL AIO 4E.021 NIr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~,~~~ JINN ~ 2008 RE: PBU 14-35 (PTD 1831420) Request for Administrative Approval Dear Mr. Rossberg: In accordance with Rule 9 of Area Injection Order ("AIO"} 04E.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission"} hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue water injection in the subject well. PBU 14-35 exhibits slow inner annulus by outer annulus communication. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU 14-35. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures, PBU 14-35 exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection in PBU 14-35 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates; 3. BPXA shall perform anMIT-IA every 2 years to 1.2 times the maximum anticipated welt pressure; 4. BPXA shall limit the well's OA pressure to 1,000 psi; 5. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; AIO 4E.02 i April 6, 2007 Page 2 of 2 • • b. After well shut in due to a change in the well's mechanical condition, AC~C~ approval shall be required to restart injection, and 7. The MIT anniversary date is January 1$, 2007 As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day fails on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. D®NE at A~okage, Alaska and dated April 6, 2007. K rrnan Daniel T. Seamount, Jr. Chairman Commissioner ~~ Cathy P. oerster Commis ~ioner Re: FW: 14-35 (#1831420) Internal Waiver Cancellation - Normal Well e e Subject: Rc: F\V: 14-35 (#1831420) Intcrnal Waiver Cancellation - Normal Well From: James Rcgg <jim_regg(fi;admin.state.ak.us> Date: Fri, 24 Mar 200609:35:46 -0900 To: "NSU, ADW Well Integrity Engincer" <NSUADWWclllntcgrityEngineer@BP.com> cc: "AOGCC - Winton Aubert (E-mail)" <winton,..,é:lubert(q;admin.state.ak.us> Well 14-35 is listed in our database injection only since December 2002. of the IAxOA communication, but I do to operate the well. Please prepare also be added to the monthly report. as a WAG injector restricted to water The Commission was notified in December 2002 not find any record of approval for continuing an admin approval for this well¡ it should Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: Winton and Jim, I apologize, I meant to attach a TIO plot. The high lAP around 3/8/06 was induced to monitor the rate of IAxOA communication. PBrush Please let me know if you have any questions. Thanks, Anna I', I, * NSU, ADW Well Integrity Engineer *Sent: * Thursday, March 23, 2006 *From: 3:21 PM *To: * 'AOGCC - Winton Aubert (E-mail) '¡ (q:i!:!l_I3:~9.9:~9_ªf.I:1~p::~:t.:.a t I§..:.?:~~_'L?) ¡ NSU, ADW We 11 Steven¡ GPB, FS3 Area Mgr¡ Kurz, John¡ GPB, Jim Regg Operations Supervisor¡ Rossberg, R FS3 DS Ops Lead *Cc: * NSU, ADW Well Integrity Engineer¡ NSU, ADW WI Tech¡ Gerik, Bob G *Subject: * 14-35 (#1831420) Internal Waiver Cancellation - Normal Well All, An internal waiver was issued for slow IAxOA communication on well 14-35 (#1831420) on 08/25/03. The rate of communication has been reviewed and is manageable by bleeds. The well may remain on production under normal operating pressure limits of 2000 psi on the IA and 1000 psi on the OA. The well is reclassified as a Normal well. Please remove all waivered well signs and the laminated copy of the waiver from the wellhouse. Thank you, */Anna Dube/* *Well Integrity Coordinator* *GPB Wells Group* * Phone : (907) 659-5102* *Pager: (907) 659-5100 xl154* Content-Type: text/plain PBU 14-35 IAxOA 2002-1223.txt Content-Encoding: 7bit 1 of 1 3/24/2006 9:36 AM e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay 1 PBU 1 DS 14 02/20106 Anna Dube Packer Depth Pretest Initial 15Min. 30 Min. Well 114-35 I Type Inj. I W TVD I 8229' Tubing 1,175 1,175 1.175 1,175 Interval! 0 P.T.D.11831420 I Type test I P Test psi I 2057' Casing 200 2,400 2,380 2,370 P/FI P Notes: MIT-IA to update waiver, apply for AA. OA 350 550 550 550 Witnessing declined by AOGCC representative. Weill I Type Inj. I I TVD I Tubing Interval! P.T.D.I I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval I P.T.D.I I Typetestl Test psil Casing P/FI Notes: OA Weill Type Inj, I TVD I Tubing I I Interval P.T.D.I I Type test Test psil Casing I P/F Notes: OA I Weill I Type Inj.1 TVD I Tubing I I Interval P,T,D.I I Type test I I Test psi I Casing I I P/FI Notes: OA I I AOGCC Rep. Chuck Scheve declined to witness on 02119/06 TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test f' MIT Report Form BFL 9/1/05 MIT PBU 14-35 02-20-06.xls 'f1 'l Z/7A I eKe \I(¡Y \ ~'V 1.-./ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ,-, \''-It{i( Emall to:Wlnton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admlnstateak.us;Jlm_Regg@admln.stateak.us 7( z -; I C4 OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc Prudhoe Bay / PBU / OS 14 07/21/04 Joe Anders Well 14-35 Type Inj. S P.T.D. 1831420 Type test P Notes: Annual MITIA for waiver compliance. Packer Depth TVD 8,404' Tubing Test pSI 2,101 Casing Pretest Initial 15 Min. 30 Mln 400 400 400 400 Interval 20 2,400 2,400 2,400 P/F 0 P Well Type Inj. TVD Tubing Interval P.T D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. MIT Report Form Revised: 06/19/02 MIT PBU 14-35 07-21-04-1.xls [Fwd: Withdrawl of sundries for 09-15, 09-17, and 14~,~'" Subject: [Fwd: Withdrawl of sundries for 09-15, 09-17, and 14-35] Date: Thu, 18 Sep 2003 15:43:06 -0800 From: Winton Aubert <Winton_Aubert~admin.state.ak.us> Organization: AOGCC To: Jody J Colombie <jody_colombie~adrnin.state.ak.us> These are nos. 303-251, 303-254, and 303-255. Subject: Withdrawl of sundries for 09-15, 09-17, and 14-35 Date: Thu, 18 Sep 2003 16:24:36-0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> To: "AOGCC Winton Aubert (E-mail)" <Winton_Aubert~adrnin.state.ak.us> CC: "NSU, ADW Well Integrity Engineer" <NSUADWWel. llntegrityEngineer~BP.com>, "Engel, Harry R" <EngelHR~BP.com>, "Anders, Joe L" <anders22~BP.com> Hi Winton, Based on the conversations that were held between you, Harry Engel, and Joe Anders this morning concerning the Sundry matrix, we would like to withdraw our sundry applications for the following injection wells with slow IA xOA communication: 09-15 (PTD #1770360) 09-17 (PTD #1770380) 14-35 (PTD #1831420) If you have any questions, or would like to discuss in further detail, please let me know. Thanks, John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5100, x. 1154 RIB~$ BFL 8(;'ANNEE;:, SE? ~ 8 2003 1 of 1 9/18/2003 4:15 PM Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 08/18~03 NO. 2948 Company: State of Alaska Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description Date Blueline Color Prints CD D.S. 14-35 i ~:~c~-I LI ~)'v INJECTION PROFILE 08115/03 W-34A (~ ~), _"~ -_~_~_' - PROD PROFILE/DEFT 07~26~03 D.S. 4-31)~~~ PSP LEAK DETECTION LOG 08~07~03 D-06A ~ q ~ ~{ ~ PRODUCTION PROFILE 07/31/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. RE CE VED Anchorage, Alaska 99508 , Date Delivered: 2.000 AUG 2 '3 ' ~' j,,tiaoka J,, & Ga~ ~.;;or~s. Commis~n An~omge Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-20 Anchorage, Alaska 99519-6612 bp August 25, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: 14-35 (PTD 1831420) Application for Sundry Approval Dear Mr. Aubert: Attached is Application for Sundry Approval form 10-403 for well 14-35. This request is for approval to continue water injection in a well exhibiting slow IA x OA communication. A description summary of proposal and wellbore schematic is included for the well. If you require any additional information or clarification, please contact either John Cubbon or Joe Anders at (907) 659-5102. Well Integrity Engineer Attachments 1) Application for Sundry Approval form 10-403 2) Description Summary of Proposal 3) Wellbore Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPR L 20 AAC 25.280 1. Type of Request __ Abandon L~ Suspend r-~ Operation Shutdown D Perforate~...~/ Variance, Annuar Disposall I Alter Casin~3 [] Repair Well [] Plu. Perforations [] StimulateLTJ' Time Extensior• Otherl'-I _ Chanae Approved Pro,ram [] Pull Tubin~ [] Perforate New Pool ~ ~f:enter Suspended Wel[] H20 IN,) VARIANI~E 2. Operator 4. Current Well Class: / i5. Permit to Drill Number: · BP Exploration (Alaska), Inc. Name: Development[-1 ,,~xplorator3[-1 1~--I 3. Address: P.O. Box 196612 ,~/ i 6. APl Number Anchorage, Ak 99519-6612 StratigraphicL.~ Service. 50-029-21018-00-00 7. KB Elevation (ft): 9. Well Na,~e and Number: RKB 69.00 / 14-35 8. Property Designation: 10. Fief/Pool(s): APL 028312 ./ Prudhoe Bay Field / Prudhoe Bay Oil Pool ...... ~p,u,v, ug'[): ITotalDepthTVD(ff): IEffectiveDepthrv~(ff): IEffectiveDepthTVD(ff): I Plugs (measured): IJunk(measured): 9500 I 9244 I 9175 (08/~f5/03) I 8943 I None I None Casing Length Size ! /MD TVD Burst Collapse ~ top ./' bottom top bottom Conductor 80 20" /48' - 128' 48' - 128' 40K 520 Surface 2628 13-3/8" ! 48' -2676' 48'- 2676' 80K 2670 Intermediate 8772 9-5/8" /, 48' ~ 48'- 8616' , 80K 4760 Liner 987/""-~7" (.~~~~ I~! 8~'~"~- 9501~' 8331'-- 9244' 80K 7020 8960' - 9178' I 1~5' -~ ?'~. ~,'"~.'~. 4-1/2"12.6# I L-80 8540' Packers and SSSV Type: ~ ~. ..~ ~ ~. Packers and SSSV MD (ft): 9-5/8" x 4-1/2" PKR; 4-1/2"~.ah~co, Bl~ SSSV Nip PKR @ 8404', SSSV Nipple @ 2146' 12. Attachments: Description. S~-nma~ of ~;)osa, 13. Well Class after proposed work Detailed Operations Progran ~~P~etch [~ ' Exploratoq[~] Developmenr-] Service, 14. Estimated Date for ~ / ! 15. Well Status after proposed work: Commencing Operation 7~/'~'-/O_..~ oilr-1 GasF-] Plugged~l Abandoned~ 16. Verbal Approval: Date/ ' WAG• G'NJD WINJB WDSPLD Commission Representative: / Prepared by DeWayne R. Schnorr 564-5174. 17. I hereby certify that the foregoing is.~rue and correct to the best of my knowledge. Contact John Cubbon Printed Name Jo n Title GPB Well Integrity Coordinator Signature . ° Phone 907/659-5102 Date 08/25/2003 [ / / Commission Use Only v / Conditions of apploval: No~/COmr~mission so that a representative mucky witness Plug Integrity D B7 TestD Mechancial Integrity TesD Location Clearanc~E~ / Other: ~ ?, :' ' Subsequent F?equired: . ~ BY ORDER OF Approved .r: COMMISIONER THE COMMISSION Date: Form 10-403 Revised 2/2003 OEIG!NAi. SUBMIT IN DUPLICATE 14-35 Description Summary of Proposal 08/25/03 Problem: Injector with Slow IA x OA communication Well History and Status: Well 14-35 (PTD 1831420) is a PWI injector that exhibits slow IA x OA communication. Wellhead pressure plots indicate sustained tracking of IA and OA pressures. This sundry request is to allow for continued injection of water. The following diagnostic testing has recently been completed supporting this request: Recent Events: > 08/23/03: MIT-IA Passed to 2400 psi. > 08/23/03: MIT-OA Passed to 2400 psi. > 06/01/03: PPPOT-IC Passed to 3500 psi. > 01/27/03: NFT-OA Passed. This sundry request is to allow for continued water injection. The following supports this request: · A MIT-IA passed to 2400 psi on 08/23/03, demonstrating competent tubing and production casing. · A MIT-OA passed to 2400 psi on 08/23/03, demonstrating competent surface casing. · A MIT-IA and MIT-OA will be conducted annually to confirm tubing and surface casing integrity. Proposed Action Plan: 1. Allow well to continue water-only injection. 2. Record wellhead pressures and injection rates daily. 3. Submit a monthly report of daily pressures and injection rates. 4. Perform an MIT-IA and MIT-OA to 1.2 times max injection pressure annually. 5. Stop injection and notify the AOGCC if there is any indication of loss of tubing or surface casing integrity. TREE = GRAY GEN 3 WR LHEAD -~ MCEV OY A C'['. UATOR = AXELSON KB. ELEV = 69' BF. ELEV = KOP = 6000' Max An~le = 27 (~ 6800' Datum MD = 9095' DatumTVD = 8800' SS 3-3/8" CSG, 72#, L-80, ID = 12.347" I--I 2676' IMinimum ID = 3.813 @ 8518' 4-1/2" HES X NIPPLE 4-1/2" 'rBG, 2.6#, L-80, 0.0152 bpf, ID =3.958" I'-{ 8540' I 9-5/8"CSG, 47#,L-80,1D=8.681" I--~ 8820' PERFORATION SUMMARY REF LOG: BHCS ON 11/12/83 ANGLE AT TOPPERF: 23 @ 8960' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8960 - 8980 O 07/29/02 3-3/8" 4 8990 - 9010 O 07/29/02 3-3/8" 4 9025 - 9045 O 07/29/02 3-3/8" 4 9056 - 9066 O 07/29/02 3-3/8" 4 9070 - 9085 O 07/29/02 3-1/8" 4 9071 - 9091 S 11/29/89 3-1/8" 4 9094 - 9104 S 11/29/89 3-3/8" 4 9110 -9128 O 12/06/89 3-1/8" 4 9113 - 9121 S 11/29/89 3-1/8" 4 9131 - 9151 S 11/29/89 3-3/8" 4 9131 - 9158 O 12/06/89 3-1/8" 4 9144 - 9154 S 11/29/89 2-7/8" 4 9173 - 9178 O 02/16/99 I 7" LNR, 29#, L-80, 0.0371 bpf, ID: 6.184" I--~ 9500' 14-35 LI 2146' 8404' 8518' 8540' 8554' SAFETY NOTES: H 4-1/2 " CAM BAL-O SSSV NP, ID = 3.813" GAS LIFT MANDRELS 9-5/8"X4-1/2"BAKERS-3PKR, ID=3.875 I 4-1/2"HESX NIP, NOGO, ID= 3.813" 4-1/2" TUBING TAIL ELMD']-F LOGGED02/16/99 DATE REV BY COMMENTS DATE REV BY COMMENTS 11/23/83 OPJGINAL COMPLETION 07/29/02 'rMN/KK ADPERFS 01/05/99 LAST WORKOV ER 01/09/01 SIS-QAA CONVERTEDTOCANVAS 02/26/01 SIS-MD FINAL 09/04/01 RN/'rP CORRECTIONS PRUDHOE BAY UNIT WELL: 14-35 PERMIT No: 1831420 APl No: 50-029-21018-00 SEC9, T10N, R14E, 5.31 FEL66 FNL BP Exploration (Alas ka) II/ • Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWelllntegrityEngineer ©BP.com] Sent: Monday, December 23, 2002 3:10 PM To: Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); Regg, James B (DOA) Cc: 'NSU, ADW Well Integrity Engineer Subject: RE: 14 -35 MI status Attachments: MIT PBU 14 -35 12- 06- 02.xls; 14- 35.pdf a MIT PBU 14 -35 14- 35.pdf 12- 06- 02.xls Hi Tom, As per your request, I have attached a wellbore diagram and the MIT form for the 14 -35 well. If you have any additional questions or need anything else, please let me know. Thanks, John Cubbon GPB Well Integrity Coordinator 1- 907 - 659 -5102 pgr. 659 -5102, x. 1154 ) P‘' Original Message From: Tom Maunder [mailto:tom maunder @admin.state.ak.us] Sent: Monday, December 23, 2002 10:18 AM To: NSU, ADW Well Integrity Engineer Subject: Re: 14 -35 MI status Hi Brandon, I went back to check the emails we have exchanged. This is similar to P -03A, although from what you relate 14 -35 passed the MITIA. Since there was an integrity question reported, it is appropriate for you to submit the recently conducted MIT. Based on the information presently available, MI should not be introduced into this well without authorization from the AOGCC. Please make sure an appropriate notation is made in your files. Thanks for your attention to this matter. Tom Maunder, PE AOGCC "NSU, ADW Well Integrity Engineer" wrote: > Tom, > Well 14 -35 (PTD 1831420) is an injector that was recently > swapped from MI to water because it began showing signs of rapid IA x > OA communication. Since the swap, a MIT -IA passed to 3000 psi and a > MIT -OA passed to 2400 psi. (12/6/02) > The next step forward with this well is to test the PPPOT's for > integrity, and to bleed the annuli and monitoring build up rates. If > further testing should identify and /or allow us to fix the > communication problem, we will contact you prior to swapping back to > MI. Until that time, the well will remain on water injection. > If you have any further questions or concerns, or would like any additional > monitoring to be added, please contact the WIE at 659 -5102. Thanks. 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder @admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg @admin.state.ak.us OPERATOR: BP Exploration (Alaska) Inc. FIELD 1 UNIT / PAD: Prudhoe Bay / PBU / DS 14 DATE: 12/06/02 OPERATOR REP: Dave Reem AOGCC REP: Packer Depths (ft.) Pretest Initial 15 Min. 30 Min. P.T.D. 1 31420 Type Inj. S _ P M Test psi' 3000' 8,229' Casing, 10401 3000 2980 �) Interval 0 P Notes: Test was conducted in order to prove integrity after showing signs of T x IA communication on MI. Well Type Inj. MD/TVD Tubs Interval , P.T.D. Type test Test psi ' I Casing 1 P/F Notes: P.T.D. ` _ Type test ^ Test Psi' I Tubingrval InteP /F Notes: Type Ink P.T.D._ , Type test I M i I C�n 1 Inte /F Notes: Well Type Type t M Test ps i Tubing' ng Interval P/F • Notes: Test Details: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes F = Fresh Water Inj M = Annulus Monitoring I = Initial Test G = Gas Inj P = Standard Pressure Test 4 = Four Year Cycle S = Salt Water Inj R = Interval Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU 14-35 12- 06- 02.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Pedorate _X ADD PERES Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 313' FNL, 1218' EEL, Sec. 09, T10N, R14E, UM At top of productive interval 51' FNL, 217' EEL, Sec. 09, T10N, R14E, UM At effective depth 58' FNL, 135' EEL, Sec. 09, T10N, R14E, UM At total depth 67' FNL, 10' EEL, Sec. 09, T10N, R14E, UM 5. Type of Well: Development __ Explorato~__ Stratigraphic__ Sen/ice__X (asp's 675230, 5940028) (asp's 676223, 5940315) (asp's 676307, 5940308) (asp's 676432, 5940302) 6. Datum elevation (DF or KB feet) RKB 69 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-35 9. Permit number / approval number 183-142 10. APl number 50-029-21018-00 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2647' Intermediate 8791' Liner 987' 9500 feet Plugs (measured) 9344 feet 9166 feet Junk (measured) 8935 feet Size Cemented Measured Depth True Vertical Depth 20" 2050# Poleset 109' 109' 13-3/8" 1800 sx Fondu, 400 sx 2676' 2676' PFC 9-5/8" 500 sx Class 'G', 300 sx 8820' 8615' PFC 7" 334 sx Class 'G' 8513' - 9500' 8331' - 9243' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) Open Perfs 8960'-8980', 8990'-9010', 9025'-9045', 9056'-9066', 9070'-9085', 9110'-9128', Open Perfs 9131-9158. Perfs covered w/Fill 9173-9178. Sqzd Perfs 9085-9091, 9094-9104 Open Perfs 8745'-8763', 8772'-8791', 8805'-8823', 8833'-8842', 8846'-8860', 8883'-8900', Open Perfs 8902-8927. Perfs covered w/Fill 8941-8946. Sqzd Perfs 8860-8866, 8868-8878 4-1/2", 12.6#, L-80, TBG @ 8404' MD; 4-1/2", 12.6#, L-80, Tubing Tail @ 8540' MD. 9-5/8" x 4-1/2" Baker 'S-3' Packer @ 8404'. 4-1/2" Camco BAL-O SSSV Nipple @ 2146' MD. RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) OCT 0 4 2002 Treatment description including volumes used and final pressure Alaal,,'a I"111 ~ ~a~ t'~n~ I'!.nmmJcJ~Jnl'l 14. Representative Daily Average Production or Iniecti~)~'~'~{~ .... /l~'Jl~?~l~ ............. OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 07/27/2002 5000 672 Subsequent to operation Shut-In 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil__ Gas__ Suspended_ Service WAG INJECTOR 17. I hereby certify that the foregoing is true.and correct to the best of my knowledge. ~~'~/~~~v~C,,~'j~ Title: Technical Assistant DeWayne R. Schnorr Date September 16, 2002 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE O7/26/2OO2 O7/27/2OO2 O7/27/2OO2 O7/27/2OO2 O7/28/20O2 O7/29/2OO2 14-35 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PERFORATING: DRIFT/TAG; SSSV C/O OR STROKE PERFORATING: PERFORATING AND HOT OIL TREATMENT PERFORATING: SCMOO-B-GONE PERFORATING: SSSV C/O OR STROKE PERFORATING: SCMOO-B-GONE PERFORATING: PERFORATING EVENT SUMMARY 07/26/02 DRIFT TO 2132' SLM W/3.84 GUAGE RING. 07/27/02 ATTEMPT TO PERF - UNABLE TO DESCEND BELOW 2223 FT - FREED BY PUMPING 40 BBLS OF DIESEL HEATED TO 180' DOWN THE TUBING - PULLED BACK TO SURFACE WITH SCHMOO IN TOOLS - INFORMED PAD OPERATOR OF WELL STATUS - LEAVE SHUT IN FOR SBG TREATMENT. 07/27/02 PUMP 150 BBLS SCHMOO-B-GONE TREATMENT DOWN TUBING. O7/27/O2 PULLED WRDP-2 SSSV FROM 2132' SLM (SN HZS-1010), DRIFT W/3 3/8" DUMMY GUN TO 8511' SLM+29'=8540' ELM (CORRECTED), TD 9132' SLM+29'=9161' CORRECTED(17' OF FILL) (30' OPEN PERFS). TURN WELL OVER TO DSO- WELL LEFT SHUT IN. 07/28/02 FLUSHED SCHMOO-B-GONE WITH SW, FREEZE PROTECTED TBG WITH DIESEL, SECURE WELL. 07/29/02 PERFORATED 9070-9085 FT / 9056-9066 FT / 9025-9045 FT / 8990-9010 FT / 8960- 8980 FT. ALL GUNS = 3 3/8" HSD @ 4 SPF WITH 3406 POWER JET CHARGES PHASED 180 DEGS, RANDOM ORIENTATION. TAGGED AT TD 9166 FT MD. ALL SHOTS FIRED. PAD OPERATOR INFORMED WELL SHUT IN -OK TO POI. FLUIDS PUMPED BBLS 3 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 3 TESTS) 80 DIESEL 15O SEAWATER 150 SBG MIX (25 BBLS CONCENTRATE/125 BBLS WATER 383 TOTAL ADD PERFS O7/29/2OO2 THE FOLLOWING INTERVALS WERE PERFORATED USING THE 3-3/8" PJ-3406 4 SPF, 180 DEGREE PHASING, RANDOM ORIENTATION. 8960' - 8980' 8990' - 9010' 9025'- 9045' 9056'- 9066' 9070'- 9085' Page 1 MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson DAT£: February 22, 2000 Chairman P. I. Supervisor ~;.r FROM' John Crisp, SUBJECT: Petroleum Inspector Mechanical Integrity Test AAI PBU DS 14-35 PTD 183-142 February 22, 2000- I traveled to Arco Alaska Inc. Prudhoe Bay Unit DS 14 to witness the initial Mechanical Integrity Test on well #35. This well was recently converted from a producer to an injector. This was the first MIT since the conversion. Well 35 has been injecting 120 degree saltwater for 8 days. A standard annulus pressure test was performed on this well. The AOGCC test report is attached for reference. SUMMARY: I witnessed the successful MIT on AAI's PBU DS 14-35. Tested one well. MIT. No failures. Attachments: MIT PBU DS 14-35 2-22-00jc cc; NON-CONFIDENTIAL MIT PBU DS 14-35 2-22-00jc.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: Arco Alaska Inc. FIELD I UNIT / PAD: Prudhoe Bay / PBU/ DS 14 DATE: 2/22/00 Well #: 14-35 Salh~/ater 8,403 COMMENTS: Recently converted from producer to injector. PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: g 5/8"/47#/L-80 I I I 2057 1, O00 ~100 ~080 ~080 g40 I I I II TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Distribution: orig - Well File c - Operator c - Database c - Trip Rpt File c - Inspector TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL PAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 0.00 0.00 9.5 0.49 0.00 60/40 O. 38 WELL TEST: Initial X 4 - Year Workover Other OPERATOR REP SIGNATURE: Joe Anders , AOGCC REP SIGNATURE: John Crisp MIT PBU DS 14-35 2-22-00jc.xls (Rev 9/23/99) MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson~0 DATE: February 22, 2000 Chairman Blair Wondzeil, ~ P. I. Supervisor ~('~(q5 FROM: John Crisp~=~/~-'f/~ ~-~ SUBJECT: Petroleum ~nspector Mechanical Integrity Test February 22, 2000' I traveled to Arco Alaska Inc. Prudhoe Bay Unit DS 14 to witness the initial Mechanical Integrity Test on well #35. This well was recently converted from a producer to an injector. This was the first MIT since the conversion. Well 35 has been injecting 120 degree saltwater for 8 days. A standard annulus pressure test was performed on this well. The AOGCC test report is attached for reference. SUMMARY: I witnessed the successful MIT on AAI's PBU DS 14-35. Tested one well. MIT. No failures. Attachments: MIT PBU DS 14-35 2-22-00jc cc; NON-CONFIDENTIAL MIT PBU DS 14-35 2-22-00jc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: Arco Alaska Inc. FIELD I UNIT I PAD: Prudhoe Bey / PBU/ DS 14 DATE: 2/22/00 ,+0:' i~,=~= "1 ....... I .......... I Well #: 14-35 I S I P I Salb/vater 8,228 8,4O3 I g 5/8"/47#/L-80 ] 4 1/2" I COMMENTS: Recently converted from producer to injector. PTD: Nell #: COMMENTS: PTD: Well #: COMMENTS: =TD: Well #: COMMENTS: =TD: I I I I Well #: COMMENTS: I I I 2057 680 70O 700 7OO I l,O00 ~00 2,080 2,080 II II II II TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 0.00 0.00 9.5 0.49 0.00 60/40 0.38 WELL TEST: Initial X 4 - Year Workover Other Distribution: odg - Well File c - Operator c - Database c - Trip Rpt File c - Inspector OPERATOR REP SIGNATURE: Joe Anders MIT PBU DS 14-35 2-22-00jcl , AOGCC REP SIGNATURE: John Cdsp (Rev 9~23~99) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown _ Stimulate _ Plugging _ Pedorate _ Prod ->WAG Pull tubing _ Alter casing _ Repair well _ Other _X Conversion 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__ RKB 69 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service x Prudhoe Bay Unit 4. Location of well at surface 8. Well number 311' FNL, 1216' FEL, Sec. 9, T1 ON, R14E, UM (asp's 675231, 5940028) 14-35i At top of productive interval 9. Permit number / approval number 51' FNL, 217' FEL, SEC. 09, T1 ON, R14E, UM (asp's 676223, 5940315) 183-142/399-236 At effective depth 10. APl number 50-029-21018 At total depth 11. Field / Pool 66' FNL, 5' FEL, Sec. 9, T10N, R14E, UM (asp's 676434, 5940302) Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 9500 feet Plugs (measured) PBTD tagged @ 9302' MD (11/18/99) true vertical 9244 feet Effective depth: measured 9302 feet Junk (measured) true vertical 9060 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 20' 20' 2050# Poleset 80' 80' Surface 13-3/8" 13-3/8" 180o sx Fondu & 400 Sx PFC 2676' 2676' Production 9-5/8" 9-5/8' 500 Sx Class G & 300 Sx PFC 8820' 8615' Uner 7" 7' 334 Sx C~ass G 9500' 9243' Perforation depth: measured 9110' - 9128'; 9131' - 9158'; 9173' - 9178'. true vertical 8883'-8899'; 8902'-8927'; 8941'-8946'. ij i~'~ i ~ i j"'~ A L Tubing (size' grade' & measured depth) 4'1/2" 12'6#' L'80 Tbg @ 8540' MD' Packers and SSSV (type & measured depth) 9-5/8' X 4-1/2' BAKER S-3 PACKER @ 8404' MD. 4-1/2' CAMCO BAL-O SSSV @ 2152' MD. 13. Stimulation or cement squeeze summary '~ ~ -'~ ~ 7.~/~ Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Dally Avera.qe Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1243 18948 2412 - 391 Subsequent to operation - 10500 - 281 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations ._X Oil m Gas u Suspended __ Service WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~ (~,~ ~ ~_-/rlC)~,[ Title Arco Engineering Supervisor Date Erin Oba Prepared b? Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE DESCRIPTION OF WORK COMPLETED CONVERSION FROM PRODUCER TO WAG INJECTOR Date Event Summary 11102/1999 - Performed various surface drillsite facility modifications to convert well from a producer to a 12/20/1999: Water alternating Gas (WAG)injector. 11/18/1999: 2/06/2000: 2/07/2000: 2/15/2000: RIH & tagged PBTD @ 9302' MD. Set S.S.Catcher Sub., Pull Station # 1 CA RDO-20 RK, LDFN SET CA RD RK IN STA.#1 @ 3977' SLM. PUMPED INHIBITED S/W & 60/40. MITIA TO 2500 PSI (LOST 50 PSI IN 15 MIN) - PASSED. PULLED C-SUB. [GLV] Placed well initially on produced water injection. RECEtVEE) F~O~: ~RCO ~L~SK~ F~X NO.: 9072~51535 11-1~-99 12:57P P.O1 ARCO ALASKA, INC. Tubing Casing Casing SSSVNIP Gee LIf~ MandralNnlve 1 PKR Liner HIP 'ITL F'er~ Per? Pod SQZ Parf Perf Perf Perf Prudhoe Bay 14-35 14-3S APl; 500292101800 Well Type: PROD SSSVType: t Orig Cornpltn: 11/23/83 Annular Fluid: Diosel/SW Last W/O: 1/~/99 Reference Log: BHC$ Ret Lo~ Dale: 11112/83 Last Teg: 9430 TD: ge00 ftKD Last Tag Date; 1/8/99 M~x Hole 27 de~ @ 8800 Angle: General Notes Date Note TrL ELM: 8~,S~' [~1e/99 J~lry Log) Other (plugs, equip,, etc.) - JEWELRY Depth TYD Type Description 2151 ~,1{~1 $aSVNIP 4-1/2" Camm3 BAL-O SSSV Nipple ~403 8228 PKR 9-5/8" x 4-1~' Baker ,5-3 Per, er 8519 8337 NIP 4-t/2" HE$ 7~ Nipple. NOGO 8540 8358 'rTL 4-1/2" Tubing ?ail Casing Strings - All Size Weight Grade Top Btm 9.625 47.00 L-B0 0 8820 7.000 29.00 L,80 8513 9500 13.375 72.00 L-80 0 25?6 Tubing Strings - All Size Weight Grade Top Btm 4.500 12.60 L.8O 0 85~0 Gas Lift Mandrels/Valves Stn MD TVD Man Man VMfr Mfr Type I 3985 :~905 CA MMC~ CA Feet De$¢rlption 88~0 Casing 987 Liner 267B Casing Feet Description 8540 Tubing Angle (~ TS: 23 deg {~ 8955 Angle @ TO: 22 deg (~ 9'300 Rev Roe--on: POST RWO Las! Update: 1~0/99 ID 3,813 o, o0o 3.813 3.958 V Type VOD Latch Port TRO Date Run RDo-20 1.5 RK 0.313 0 1/8199 VIv Commenl Perfol~ttons Interval TVD Zone Status 9072 - 9092 8~48 - 8866 ZONE 4 O 9095 · 9105 8B~9 - 8878 ZONE 4 O 91'14 - 9124 8887 - 8898 ZONE 4 0 9132 - 9142 8903 - 8913 ZONE 4 0 9145 - 9155 8915 - 8925 ZONE 4 O 9t.10- 91 t4'~ 8883- 8887 ZONE4 0 9114 9124 ~, 8887- 8896 ZONE 4 O 9124 9t28J 889B- $900 ZONE 4 O 9131 - 9132'/ 8902- 8903 ZONE 4 O 9132 - 9f42[ 8903 - ~913 ZONF_4 O 9142 - 9145~ 8913 - 891S ~ONE4 O 9145 -91SS~ 6915 -89~5 ZONE a o 91S$ - 9158' 8925 - 8927 ZONE 4 O 9173- 9178 8941 -8946 ZONE 3 O Stimulations & Treatments Interval Date Type 9072- 9155 1t/29/89 SQZ FeetSPF Date Type Comment 20 0 3/31185 IPERF 10 0 3/31/85 IPERF 10 0 3131/85 IPERF %~ ,.c~,,~ 10 0 3131/B5 IPE, R; · -~ t0 0 3/31/85 IPERF ~t~-~ 4 4 l~e/B9 APERF _ 4 12/6/89 RPERF 4 4 12/6/89 APERF 4 1~6/89 APERF , 10 4 1~/89 RPERF 3 4 1~6/89 APERF 1o a ~/89 RP~RF 3 4 1~6/89 APERF Comment - Post-it~ Fax Note hone ~ 7671 Fax tf RECEIVED NOV 1 6 1 99 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA dh::> ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ (Prod -> WAG Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Conversion) Change approved program _ Pull tubing _ Variance _ Per/orate _ Other_X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface ,/4' v~ ~ 311' FNL, 1216' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 51' FNL, 217' FEL, SEC. 09, T10N, R14E, UM At effective depth At total depth 66' FNL, 5' FEL, Sec. 9, T10N, R14E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service _ 6. Datum elevation (DF or KB feet) RKB 69 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-35 9. Permit number / approval number 83-142~/' 10. APl number 50-029-21018 "'~ 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2607' Production 8751' Uner 987' Perforation depth: measured true vertical Tubing (size, grade, and measured depth ~ackers & SSSV (type & measured depth) Size 20" 13-3/8" 9-5/8" 7" 95OO 9244 9430 9179 feet ~ Plugs (measured) feet feet Junk (measured) feet Cemented 2o50# Poleset 1800 Sx Fondu & 400 Sx PFC 500 Sx Class G & 300 Sx PFC 334 Sx Class G 9110'- 9128'; 9131'- 9158'; 9173'- 9178'. 8883' - 8899'; 8902' - 8927'; 8941'- 8946'. 4-1/2", 12.6#, L-80 Tbg @ 8540' MD. 9-5/8" X 4-1/2" BAKER S-3 PACKER @ 8404' MD. 4-1/2' CAMCO BAL-O SSSV @ 2152' MD. PBTD tagged @ 9430' MD (1/08/1999) Measured Depth 80' 2676' 8820' 9500' True vertical Depth 80' 2676' 8615' 9243' 13. Attachments Description summary of proposal ._X Detailed operations program __ BOP sketch .__X 15. Status of well classification as: 14. Estimated date for commencing operation November 23, 1999 16. If proposal was verbally approved Name of approver Date approved Oil ._X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is t~e,,~rect to the best of my knowledge. Gordon Pospisil FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Questions? Call Brandon France @ 265.6937 Plug integrity_ Mechanical Integrity Test Approved by order of the Commission BOP Test __ Location clearance__ Subsequent form required 10- 1.1~{~ ~-I Original Signet ~:~ David W. Joh?.sto.-. Commissioner Approved Copy Returned Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DS 14-35 Conversion of a Producer to Water & MI Injection Well 14-35 is currently a producer in the Gravity Drainage Waterflood Interaction (GDWFI) area. The proposed conversion of well 14-35 in injection and the subsequent creation of a new WF pattern will allow for more efficient recovery of reserves from the DS-14 GDWFI area. Gas encroachment is causing high GOR's in many of the wells located in the western part of the GDWFI; however, injection from Well 14-13 has kept the GOC at a much higher level on the eastern portion of this area. Injection into Well 14-35 should help reduce GOR's in at least 5 other wells. Conversion of Well 14-35 to an injector may allow perf targets closer to the GOC to be produced in some offset producers. At this time there is one offset producer ,SI due to gas production and one well is on cycle. This well currently exhibits mechanical integrity as a producer. Plans are to dummy all gas lift mandrels prior to commencing injection. An MIT will be scheduled shortly after conversion to injection. Facility modifications will take place in Nov. 1999 and the well is expected to be ready for injection by the beginning of year 2000. RECEIVED : OV l 5 1999 & Gas Cons. Coaalssbn Anchorage AR3B-6003-93 242-2603 6 5 4 2 , CO~LED TUB].Ni~ UNIT BOP EOUI PHENT 2 2. 5000 PSI 4 1/1~," PIPE RAMS 3. 5000 PSI 4 1/6" HYD~LK~ SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS ~). :~)C)O PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUIrF'ING BOX RECEIVED BOP E i i 1. 5000 PSI 7" WELLHEAD CONNEC10R FLANGE ! 1. 5000 PSI 7" WELLHEAD CONN£C10R FLANGE j 2. 5DDD PSI W~RELIN[ RAMS (VARIABLE SIZE) ~ 3. 5DDO PSI 4 1/6" L UBRICA'~OR I I 4. 5000 PSI 4 1/6" IrLC)W TUBE PACK-Orr STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operators performed: Operation shutdown _ Stimulate _ Plugging _ Per/orate _X Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 311' FNL, 1216' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 51' FNL, 217' FEL, Sec. 09, T10N, R14E, UM At effective depth At total depth 66' FNL, 5' FEL, Sec. 9, T10N, R14E, UM 5. Type of Well: Development__X Explorato~___ Stratigraphic__ Service__ 6. Datum elevation (DF or KB feet) RKB 69 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-35 9. Permit number / approval number 83-142 10. APl number 50-029-21018 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 80' 20" Surface 2607' 13-3/8" Production 8751' 9-5/8' Liner 987' 7" 9500 feet Plugs (measured) 9244 feet 9330 feet Junk (measured) 9086 feet Cemented 2050# Poleset 18oo Sx Fondu & 400 Sx PFC 500 Sx Class G & 300 Sx PFC 334 Sx Class G PBTD tagged @ 9330 (2/16/1999) ORIGINAL Measured Depth 80' 2676' 8820' 9500' TrueverticalDepth 80' 2676' 8615' 9243' Perforation depth: measured 9110' - 9128'; 9131' - 9158'; 9173'- 9178'. true vertical 8883' - 8899'; 8902' - 8927'; 8941' - 8946'. Tubing (size, grade, and measured depth) 4-1/2', 12.6#, L-80, Tbg @ 8540' MD. Packers & SSSV (type & measured depth) 9-5/8' X 4-1/2' BAKER S-3 PACKER @ 8404' MD. 4-1/2" CAMCO BAL-O SSSV @ 2146' MD. RECEIVED AJaska 0ii & Gas Cons. Conirnis~io? Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 1041 Representative Daily Average Production or Injection Data Gas-Md Water-Bbl 10425 3150 1290 16148 3694 Casing Pressure Tubing Pressure 365 451 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Arco Well Group Supervisor Date 7- 24,- ?? Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 14-35 DESCRIPTION OF WORK COMPLETED PERFORATION Date Event Summary 2/16/1999: RIH & shot 5' of Add Perforations located @: 9173' - 9178' MD (Zone 3) Reference Log: BHCS 11/12/1983. Used 2-7/8" carriers & shot all perfs @ 4 SPF, 60° phasing, balanced press, & random orientation. POOH w/perf guns. ASF. RD. Returned well to production & obtained welltest data. STATE OF ALASKA ..... ALASKA ~,,L AND GAS CONSERVATION COrv,,~lSSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 I--IAIterCasing [~ Repair Well I--]Other 5. Type of well: [] Development I--I Exploratory [--I Stratigraphic E~Service 4. Location of well at surface 313' SNL, 1218' WEL, SEC. 09, T10N, R14E, UM At top of productive interval 51' SNL, 217' WEL, SEC. 09, T1 ON, R14E, UM At effective depth 64' SNL, 46' WEL, SEC. 09, T10N, R14E, UM At total depth 65' SNL, 8' WEL, SEC. 09, T10N, R14E, UM 6. Datum Elevation (DF or KB) 69' RKB 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 14-35 9. Permit Number / Approval No. 83-142 398-329 10. APl Number 50-029-21018 1. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 9500 feet true vertical 9243 feet Effective depth: measured 9434 feet true vertical 9182 feet Casing Length Structural Conductor 80' Surface 2607' Intermediate Production 8751' Liner 987 Plugs (measured) Junk (measured) PBTD Tagged at 9434' MD (06/94) Size Cemented MD 20" 2050# Poleset 80' 13-3/8" 1800 sx Fondu, 400 sx PF 'C' 2676' 9-5/8" 500 sx Class 'G', 300 sx PF 'C' 8820' 7" 334 sx Class 'G' 9500' TVD 80' 2676' 8615' 9243' Perforation depth: measured true vertical 9110'-9128', 9131'-9158' 8883' - 8899', 8902' - 8927' RECEIVED Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 8540' Alaska Oil & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) Baker S-3 packer at 8404'; 4-1/2" Camco BaI-O'SSSV Nipple at 2146' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments i--I Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [~] Oil l--I Gas I--] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~::~¢.--- ~-,'3.. ~ gan Stone Title Engineering Supervisor Prepared By Name/Number: Terrie Hubble;~4~i~8Duplicatel~ Form 10-404 Rev. 06/15/88 Progress Report Facility PB DS 14 Well 14-35 Rig Doyon 16 Page 1 Date 15 January 99 Date/Time 26 Dec 98 18:30-21:15 21:15-00:30 27 Dec 98 00:30-03:30 03:30-06:00 06:00-08:00 08:00-09:30 09:30-09:45 09:45-10:15 10:15-13:30 13:30-14:00 14:00-15:15 15:15-15:30 15:30-18:00 18:00-18:15 18:15-21:00 21:00-23:00 23:00-00:30 28 Dec 98 00:30-02:00 02:00-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-07:15 07:15-10:30 10:30-10:45 10:45-16:30 16:30-17:00 17:00-17:45 17:45-18:00 18:00-18:15 18:15-19:45 19:45-03:30 29 Dec 98 03:30-04:45 04:45-06:00 06:00-06:30 06:30-08:00 08:00-08:15 08:15-09:45 09:45-12:45 12:45-13:15 13:15-15:00 15:00-15:30 15:30-17:00 17:00-18:00 18:00-18:15 18:15-22:15 22:15-23:15 23:15-00:00 30 Dec 98 00:00-06:00 06:00-10:00 10:00-10:45 10:45-14:00 14:00-17:30 Duration 2-3/4 hr 3-1/4 hr 3hr 2-1/2 hr 2hr 1-1/2 hr 1/4 hr 1/2 hr 3-1/4 hr 1/2 hr 1-1/4 hr 1/4 hr 2-1/2 hr 1/4 hr 2-3/4 hr 2hr 1-1/2 hr 1-1/2 hr lhr lhr lhr lhr 1/2 hr 3/4 hr 3-1/4 hr 1/4 hr 5-3/4 hr 1/2 hr 3/4 hr 1/4 hr 1/4 hr 1-1/2 hr 7-3/4 hr 1-1/4 hr 1-1/4 hr 1/2 hr 1-1/2 hr 1/4 hr 1-1/2 hr 3hr 1/2 hr 1-3/4 hr 1/2 hr 1-1/2 hr lhr 1/4 hr 4hr lhr 3/4 hr 6hr 4hr 3/4 hr 3-1/4 hr 3-1/2 hr Activity Rigged down Drillfloor / Derrick Rig moved 100.00 % Rigged up Drillfloor / Derrick Fill pits with Seawater Fill pits with Seawater (cont...) Removed Hanger plug Rigged up High pressure lines Held safety meeting Circulated at 7568.0 ft Installed Hanger plug Removed Xmas tree Installed BOP test plug assembly Rigged up BOP stack Held safety meeting Rigged up BOP stack Tested BOP stack Serviced Top ram Tested BOP stack Retrieved BOP test plug assembly Rigged up Completion string handling equipment Pulled Tubing on retrieval string to 0.0 ft Circulated at 7568.0 ft Circulated at 7568.0 ft (cont...) Removed Tubing hanger Laid down 2151.0 ft of Tubing Retrieved SCSSSV nipple assembly Laid down 5392.0 ft of Tubing Rigged down Tubing handling equipment Tested Bottom ram Installed Wear bushing Held safety meeting Made up BHA no. 1 Singled in drill pipe to 5700.0 ft Tested Kelly Singled in drill pipe to 6668.0 ft Held safety meeting Singled in drill pipe to 7550.0 ft Fished at 7590.0 ft Circulated at 7590.0 ft Pulled out of hole to 400.0 ft Pulled BHA Laid down fish Pulled BHA Made up BHA no. 2 R.I.H. to 1430.0 ft Held safety meeting R.I.H. to 8300.0 ft Serviced Block line R.I.H. to 8442.0 ft Milled Permanent packer at 8445.5 ft Milled Permanent packer at 8446.0 ft (cont...) R.I.H. to 8483.0 ft Circulated at 8450.0 ft Pulled out of hole to 441.0 ft Facility PB DS 14 Progress Report Well 14-35 Page 2 Rig Doyon 16 Date 15 January 99 Date/Time 31 Dec 98 01 Jan 99 02 Jan 99 03 Jan 99 17:30-18:00 18:00-18:15 18:15-19:00 19:00-19:30 19:30-22:00 22:00-22:15 22:15-02:30 02:30-03:15 03:15-03:30 03:30-04:30 04:30-06:00 06:00-08:30 08:30-09:30 09:30-13:30 13:30-14:00 14:00-15:30 15:30-16:30 16:30-18:00 18:00-18:15 18:15-20:15 20:15-20:45 20:45-21:00 21:00-21:15 21:15-21:30 21:30-22:45 22:45-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-08:30 08:30-09:30 09:30-13:45 13:45-18:00 18:00-18:30 18:30-19:30 19:30-20:15 20:15-21:15 21:15-01:30 01:30-02:30 02:30-06:00 06:00-07:00 07:00-09:00 09:00-10:00 10:00-13:00 13:00-16:30 16:30-18:00 18:00-18:30 18:30-20:30 20:30-22:30 22:30-23:00 23:00-03:15 03:15-03:30 03:30-04:15 Duration 1/2 hr 1/4 hr 3/4 hr 1/2 hr 2-1/2 hr 1/4 hr 4-1/4 hr 3/4 hr 1/4 hr lhr 1-1/2 hr 2-1/2 hr lhr 4hr 1/2 hr 1-1/2 hr lhr 1-1/2 hr 1/4 hr 2hr 1/2 hr 1/4 hr 1/4 hr 1/4 hr 1-1/4 hr 4-1/4 hr lhr lhr lhr 1/2 hr 2hr lhr 4-1/4 hr 4-1/4 hr 1/2 hr lhr 3/4 hr lhr 4-1/4 hr lhr 3-1/2 hr lhr 2hr lhr 3hr 3-1/2 hr 1-1/2 hr 1/2 hr 2hr 2hr 1/2 hr 4-1/4 hr 1/4 hr 3/4 hr Activity Pulled BHA Held safety meeting Pulled BI-IA Made up BHA no. 3 R.I.H. to 8481.0 ft Fished at 8481.0 ft Pulled out of hole to 441.0 ft Pulled BHA Laid down fish Made up BHA no. 4 R.I.H. to 2640.0 ft R.I.H. to 8495.0 ft (cont...) Fished at 8495.0 ft Pulled out of hole to 170.0 ft Pulled BHA Laid down fish Made up BHA no. 5 R.I.H. to 6300.0 ft Held safety meeting R.I.H. to 9018.0 ft Washed to 9019.0 ft Pulled out of hole to 8490.0 ft Washed to 8530.0 ft R.I.H. to 8985.0 ft Washed to 9020.0 ft Pulled out of hole to 553.0 ft Pulled BHA Made up BHA no. 6 R.I.H. to 2140.0 ft Held safety meeting R.I.H. to 9020.0 ft Fished at 9022.0 ft Circulated at 9022.0 ft Pulled out of hole to 567.0 ft Held safety meeting Pulled BHA Serviced Block line Rigged up sub-surface equipment - Fishing tools Conduct braided cable operations - 3/16 size cable Made up BHA no. 7 R.I.H. to 7640.0 ft R.I.H. to 8992.0 ft Washed to 9144.0 ft Circulated at 9114.0 ft Washed to 9400.0 ft Circulated at 9400.0 ft Pulled out of hole to 5700.0 ft Held safety meeting Pulled out of hole to 1156.0 ft Pulled BHA Rigged up sub-surface equipment - Retrievable packer Ran Drillpipe in stands to 8415.0 ft Held safety meeting Tested Casing Facility PB DS 14 Progress Report Well 14-35 Page 3 Rig Doyon 16 Date 15 January 99 Date/Time 04 Jan 99 05 Jan 99 04:15-05:30 05:30-06:00 06:00-06:30 06:30-12:30 12:30-13:00 13:00-15:15 15:15-15:30 15:30-16:00 16:00-17:30 17:30-18:00 18:00-18:30 18:30-00:30 00:30-01:30 01:30-04:15 04:15-05:30 05:30-06:00 06:00-07:00 07:00-11:30 11:30-12:30 12:30-13:30 13:30-14:30 14:30-15:00 15:00-18:00 18:00-18:15 18:15-22:00 22:00-22:30 22:30-00:15 00:15-02:00 Duration 1-1/4 hr 1/2 hr 1/2 hr 6hr 1/2 hr 2-1/4 hr 1/4 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 6hr lhr 2-3/4 hr 1-1/4 hr 1/2 hr lhr 4-1/2 hr lhr lhr lhr 1/2 hr 3hr 1/4 hr 3-3/4 hr 1/2 hr 1-3/4 hr 1-3/4 hr Activity Circulated at 8415.0 ft Laid down 184.0 ft of 5in OD drill pipe Held safety meeting Laid down 7000.0 ft of 5in OD drill pipe Rigged down Kelly Laid down 1425.0 ft of 5in OD drill pipe Rigged down sub-surface equipment - Retrievable packer Retrieved Wear bushing Rigged up Tubing handling equipment Ran Tubing to 200.0 ft (4-1/2in OD) Held safety meeting Ran Tubing to 6390.0 ft (4-1/2in OD) Installed SCSSSV nipple assembly Ran Tubing to 8515.0 ft (4-1/2in OD) Installed Tubing hanger Ran Tubing on landing string to 8540.0 ft Installed Tubing hanger Reverse circulated at 8540.0 ft Set packer at 8404.0 ft with 4000.0 psi Tested Tubing Tested Permanent packer - Via annulus Installed Hanger plug Removed BOP stack Held safety meeting Installed Xmas tree Tested Xmas tree Freeze protect well - 150.000 bbl of Diesel Rigged up High pressure lines STATE OF ALASKA ALASKA ~JIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: []Abandon [] Suspend [] Plugging []Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Change to Injector 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 i4. Location of well at surface 313' SNL, 1218' WEL, SEC. 09, T10N, R14E, UM At top of productive interval 51' SNL, 217' WEL, SEC. 09, T10N, R14E, UM At effective depth 64' SNL, 46' WEL, SEC. 09, T10N, R14E, UM At total depth 65' SNL, 8' WEL, SEC. 09, T10N, R14E, UM 5. Type of well: [] Development I~1 Exploratory [] Stratigraphic []Service 6. Datum Elevation (DF or KB) 69' RKB 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 14-35 9. Permit Number 83-142 10. APl Number 50-029-21018 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 9500 feet true vertical 9243 feet Effective depth: measured 9434 feet true vertical 9182 feet Casing Length Size Structural Conductor 80' 20" Surface 2607' 13-3/8" Intermediate Production 8751' 9-5/8" Liner 987 7" Plugs (measured) Junk (measured) PBTD Tagged at 9434' MD (06/94) Cemented MD 2050# Poleset 1800 sx Fondu, 400 sx PF 'C' 80' 2676' 500 sx Class 'G', 300 sx PF 'C' 8820' 334 sx Class 'G' RECEiV Perforation depth: measured 9110'-9128', 9131'-9158' ~,T~C I 0 1998 true vertical 8883' - 8899', 8902' - 8927' Alaska 0il & Gas Co~ ~,uimmss~m, Anchora§e Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT at 8457'; 4-1/2", 12.6#, L-80 PCT tail at 8554' Packers and SSSV (type and measured depth) 5-1/2" Camco Bal-O SSSV at 2193'; Baker SAB packer at 8445' TVD 80' 2676' 8615' 9243' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 4. Estimated date for commencing operation December 17, 1998 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: John Powell, 564-5480 Date approved I15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~------~__~ ~,,~. Dan Stone Title Engineering Supervisor Commission Use Only Conditions of Approval: Notify Commission so representative may witness Date J Approval N o (..~..- Plug integrity BOP Test __ Location clearance Mechanical Integrity Test c..-.-' Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev. 06/15/88 Or~g~n~, Signea By David W. Johnston Commissioner Submit In Triplicate Workover Scope (DS 14-35) To RECOMPLETE WELL for PRODUCTION/INJECTION Pre-Riq Procedure 1. RU slickline and pull SSSV. Drift 5-1/2" tubing through tailpipe. Ri.q 1. Document location of any tight spots or restrictions and notify Operations Drilling Engineer. Note: 9-5/8" casing successfully pressure tested (CMIT) to 3,000 psi on 10/25/98. 2. RU electric line and make a chemical cut in the 5-1/2" tubing just above the production packer (packer is at -8,445' MD). Circulate well to clean seawater. Freeze protect to _+2,200' MD. Note: If tubing cut is unsuccessful, notify ODE immediately. 3. Test 9-5/8" packoff. Report test results to ODE. Carefully cycle LDS. 4. Set BPV in preparation for rig operations. Note: Records show hanger type as Gray Gen. II1. Workover Procedure MIRU rig. ND tree, NU and test BOPE. Circulate well to clean seawater. Note: Perforations will remain sanded off during this workover. 2. Pull 5-1/2" tubing from chemical cut. 3. Mill up and retrieve the production packer and tubing tailpipe assembly.. 4. RIH with an R-IFS and pressure test the 9-5/8" casing to confirm integrity. Note: Any unexpected 9-5/8" casing integrity concerns would be resolved at this time (i.e. 7" scab liner). As no problems are anticipated, no AFE funds have been included for this contingency. 5. RIH with new 4-1/2", L-80 completion. One GLM is proposed. An X-nipple is requested in the tubing tailpipe. Note: The packer should be set such that the tubing tailpipe is at least 100' MD above the top of the Sag River for future CT access. All tubulars must have premium connections. 6. Drop ball, set packer and pressure test new completion. 7. Freeze protect through upper GLM. 8. Set BPV, ND BOPE, NU and test tree. RDMO. Note: Post rig CT cleanout (of sand plug) will be required. DS 14 is not an H2S Pad. Well Control Considerations Pore pressure is estimated at 3,360 psi (7.34 ppg EMW). The perforations are currently sanded back and will remain as such for the duration of this workover. Although not expected, lost circulation may be a problem with seawater (-1.0 ppg overbalance). Standard non-damaging LCM pill formulations should be available to help maintain a full column of fluid. Contact DS Engineer before pumping any potential formation damaging LCM. Directional Information Maximum inclination in the wellbore is 26.73 degrees at 6,800' MD. Maximum dogleg severity (DLS) is 8.3 degrees/100' at a depth of 5,800' MD. No DLS above 3.8 degrees/100' exists below 5,900' MD. See directional profile for additional detailed information. Mechanical Information Wellhead: Outer Annulus: Inner Annulus: Tubing: No known problems 13-5/8" x 9-5/8"; no known problems 9-5/8" x 4-1/2"; passed CMIT to 3,000 psi on 10/25/98 5-1/2", L-80, IPC Multiple leaks from 7,525' - 7,633' MD Many joints 40-85% reduction in wall thickness (per 12/97 Kinley) Other Information Existing perforations were sanded back (with a CaCl2 cap) on 6/6/98. Well will be pre-produced for -6 months then converted to injection. Ensure tubing tailpipe is set -100' MD above Sag River to facilitate future CT access. Tubular Requirements Size Metallurgy Tubing 4-1/2" L-80 Tailpipe 4-1/2" L-80 Although 4-1/2", L-80 tubing is preferred, 5-1/2", L-80 tubing would be acceptable especially if using same would help with inventory reductions. Used, inspected tubulars are also acceptable. All tubulars must have premium connections due to future planned MI injection. DS RWO (Proposed Completion) i _~-, I 4-1/2' Profile -Ot~ ~ (SSSV not required) : @ -2,200' 13 3/8', 72#/ft, L-80, BTC @ 2,676' --~ i I AFE - 4J9099 4-1/2', 12,6#/ff, L-80, Work Order - 98327549 Tubing Completion (Premium Connections) ~ 1 - 4-1/2" x 1-1/2' GLM i , I 4-1/2' x 9-5/8' ~ ~ Production Packer @~8,700' MD · Top of 7" liner @ 8,513' MD ~ I I ~ - 4-1/2" X Nipple 9 5/8', 47#/ft, L-80 @ 8,820' MD ~ '~ ~ 100' spacing between tailpipe and Sag River Top Sag River (8,842' MD) Zone 4 Peals (Top perf @ 9,095' MD; Bottom perf @ 9,158' MD) 7', 29#/ft, L-80 Date Revised by Comments PRUDHOI;; RAY UNIT 11-18-98 TAB RWO - Pre-produced Injector WELL: 14-35 APl NO-. ARCO-BP SSD Tubing-PC - · Casing Casing WSSSV Gas Lift MandrelNalve I PBR PKR XO Tubing-PC NOGO Liner FISH SOSUB - - TTL 8995' - 9331' Sand Pumped to Secure Well (06/06~98) ..... Per[ Pelf Pelf SQZ Per[ Pelf Pelf 14-35 14-35 APl: 500292101800 H2S: SSSV Type: 1 Annular Fluid: Diesel/SW Reference Log: BHCS Last Tag: Rev Reason: Secure Well Elevations KB Grd KB-Grd Other (plugs, equip., etc.) - All Depth ID Type 2193 4.56 WSSSV 8430 0.0o PBR 8445 0.00 PKR 8457 0.00 XO 8542 0.00 NOGO Well Type: PROD Spud: 11/1/83 Odg Compltn: 11/23/83 Last W/O: 11/6/87 Ref Log Date: 11/12/83 Last Tag Date: Last Update: 9/11/98 RKB: 69 ft KOP: 0.00 ftKB PBTD: 9500.00 ftKB TD: 9500.00 ftKB Max Hole Angle: 27 deg @ 6800 Angle @ TS: 23 deg @ 8955 Angle @ TD: 22 deg @ 9500 69 ft Cas Flng 0 ft 0 ff Tub Head 0 ft 69 ft 8553 0.00 SOSUB 8554 0.00 'l-rL General Notes Date Note LDL 08/15/97 Indicates Multiple Leaks below POGLM 7525' - 7633' POGLM Pulled 12/13/97 8542 Min ID = 0.001' (4-1/2' Camco DB-5 No-Go Nipple ID=3.813" w/TTP) 'i-FL ELM @ 8558: ELM Tubing Tail (Logged 04/03/91) Daterun: 1983-11-23 Description 5-1/2' Camco BAL-O SSSV Nipple 5-1/2" Baker PBR Assembly 9-5/8" x 5-1/2' Baker SAB Packer Crossover 5-1/2" X 4-1/2' 4-1/2' Camco DB-5 No-Go Nipple ID=3.813' w/T'rP (Set 12/18/92) Leak noted 01/26/98 4-1/2' Baker Shearout Sub 4-1/2' Tubing Tail VIv Vlv Vlv Latch VIv Mfr OD Type Port (in) HES 1.00 OV BK 0.38 Status Feet SPF Date C 20 0 11/29/89 10 0 11/29/89 O 18 4 12/6/89 0 27 4 12/6/89 Type Comment SQZ Weight Grade 47.00 L-80 29.00 L-80 72.00 L-80 Weight Grade 17.00 L-80 12.60 L-80 Vlv VIv Run Vlv TRO Comment 8/11/94 Type Comment Sqz APERF APERF 1 3984 AVA DWP Perforations Summary Interval Zone 9072 - 9092 ZONE 4 9095 - 9105 ZONE 4 9110 - 9128 ZONE 4 9131 - 9158 ZONE 4 Stimulations & Treatments Interval Date 9072 - 9155 11/29/89 Top Btm 0 8820 8513 9500 0 2676 Top Btm 0 8457 8457 8554 Fish - Untitled Depth Description 8547 FISH Casing Strings - All Size Description 9.63 Casing 7.00 Liner 13.38 Casing Tubing Strings - All Size Description 5.50 Tubing-PC 4.50 Tubing-PC Gas Lift Mandrels/Valves Stn MD Man Man Type Mfr Comment Rubber Element GeOQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9174 Company: Alaska Oil & Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 1/5/95 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar Floppy Disk !n.c~, 3-13 ~7 ~-~7! INJEC PROFILE (12-4-94) 1 1 .~. 3-14 '7 ~---~?.~.- BACK-OFF RECORD (12-3-94) I 1 D.S. 9-5A _C/ ',,,~ ,, 6'2-~o STATIC REP SURVEY (12-9-94) - I 1 D.S. 11-24A c/"l~-"~2-(~(-~ PROD PROFILE (12-6-94) I 01 D.S. 14-99 ~.. ?-~ O~ PROD PROFILE (12-8-94) I 1 D.S. 14-24 '~_'~- C>C~ PERF RECORD (12-6-94) I 1 D.S. 16-20 PROD PROFILE (12-6-94) I 1 D.S. 17-2 ~)-' (~ (~ STATIC SE PRESS SURVEY (12-10-94) I 1 Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9139 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 12/30/94 Field: Prudhoe Bay Floppy Well Log Description BL RR Sepia RF Sepia Mylar Disk '.S. 14-15 ~'1'-O~ CNTD (5-17-94) (~ -~ (~ I ~ ~ D.S. 14-35 ~ - I~ CNTD (3-17-94) _ ~ ~ 1 D.S. 15-4 ~ ~ ? DUAL BURST TDT-P (7-27-93) ~ ~ 1 D.S. 18-8 ~& ~ 7~ DUAL BURST TDT-P (3-20-94) ~o '~~ 1 1 1 1 1 1 1 1 ' 1 1 SIGNED: DATE: Please sign and retrun one copy RECEIVED JAN 0 Alaska Oil & Gas Cons. "~.10 Anchorage .. · Page 4 STATE OF ALASKA ALASKA- .... ' AND GAS CONSERVATION CC ..... 111SSlON REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing AItercasing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 313' FNL, 1218' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 51' FNL, 217' FEL, Sec. 9, T10N, R14E, UM At effective depth 64' FNL, 46' FEL, Sec. 9, T1 ON, R14E, UM At total depth 65' FNL, 8' FEL, Sec. 9, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 69 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-35 9. Permit number/approval number 83-142 10. APl number 50 - 029-21018 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9500 feet true vertical 9243 feet Effective depth: measured 9434 feet true vedical 9182 feet Casing Length Size Conductor 80' 20" Surface 2607' 13-3/8" Production 8751' 9-5/8" Liner 987' 7" Plugs(measured) PBTD Tagged @ 9434' MD (6/16/94) ORIOiNAL Junk(measured) Measured depth True vertical depth 80' 80' 2676' 2676' 8820' 8615' 9500' 9243' Cemented 2050# Poleset 1800 sx Fondu & 400 sx PFC 500 sx CIG & 300 sx PFC 334 sx CIG Perforation depth: measured 9110-9128'; 9131-9158' true vedical 8883-8899'; 8902-8927' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8457' MD; 4-1/2", 12.6~, L-80, PCT tail @ 8554' MD Packers and SSSV (type and measured depth) 5-1/2", Camco BaI-O SSSV @ 2193' MD; Baker SAB packer @ 8445' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Produdion orlniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 1125 4588 1325 -- t' 1147 4044 2551 -- Tubing Pressure 850 257 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor Form 10-404'Rev 06/15/88 1229/14 KRF cc: KZ, JWP Date SUBMIT IN DUPLICATE,~ 14-35 DESCRIPTION OF WORK COMPLETED . ACID STIMULATION & POGLM INSTALLATION 6/16/94: RIH & tagged PBTD at 9434' MD. 6/18/94: An Acid Stimulation Treatment was performed as follows: MIRU CTU & PT equipment. Loaded the wellbore w/1% KCl Water, then RIH w/CT mounted inflatable packer & set at 9107' MD, to isolate the uphole squeezed perforation intervals from stimulation fluids. Treated the open perforation intervals located below the packer at: 9110 - 9128' MD (Z4) 9131 - 9158' MD (Z4) Ref. Log: BHCS 11/12/83. Pumped: a) 94 bbls 75% Diesel/25% Xylene @ 2.6 bpm, followed by b) 100 bbls 12% HCl w/5% Xylene @ 2.6 bpm, followed by c) 50 bbls 1% KCI Water, followed by d) 11 bbls Diverter Slug saturated w/Benzoic Acid Flakes, followed by e) 100 bbls 12% HCl w/5% Xylene @ 2.8 bpm, followed by f) 80 bbls 1% KCl Water Flush @ 2.8 bpm, followed by g) Shutdown. Deflated & POOH w/packer. N2 lifted & flowed well. Rigged down. 6/24/94: Pumped 80 bbls ESL scale inhibition treatment. 8/6/94: MIRU & PT equipment. Loaded wellbore w/Crude, then RIH w/tubing perforator & shot five circulation holes in the 5-1/2" tubing at 3992' - 3993' MD, for a Pack Off Gas Lift Mandrel Installation. RIH w/AVA POGLM & set across the circulation holes from 3984 - 3999' MD (seal to seal). PT POGLM OK. Rigged down. Returned well to production w/gas lift & obtained a valid production welltest. RECEIVED OCT - 4 1994 Ai~.ska Oi~ & Gas Cons. Commission Anchor~e GeoQuest 500 W. International Airpo~ Road Anchorage, AK 99518-1199 ATTN: Shenle NO. 8889 Company: I Aiaaka Oil & Gas Cons Comm Attn: Lam/Grant 3001 Porcupine Drive Anchorage, AK 99501 8/26/94 Field: Prudhoe Bay Well Log De~cription BL RR Sepia RF Sepia 19h/lar ~'~/'~'~ D.S. 1-09A DUAL BURST TDT (8-7-94) 1 1 ~-~_.T.L~ D.S. 4-05A PERF RECORD (8-9-94) 1 1 ~:Z-~,? D.S. 7-17 DUAL BURST TDT (8-5-94) 1 1 q ~_~._~ D.S. 9-5A DUAL BURST TDT (8-7-94) 1 1 ~!-?__._____~ D.S. 13-11 PROD PROFILE (8-5-94) 1 1 ~r3--~c D.S. 13-28 .LEAK DETECTION (8-5-94) 1 1 ~ ~'-~G D.S. 14-7 IBRIDGE PLUG RECORD (8-8-94) 1 1 __ ~ t tc~ D.S. 14-26 PROD PROFIE (8-6-94) 1 1 i'~w-'_ D.S. 14-35 TUBING PUNCHER & POGLM RECORD (8-6-94) 1 1 ~1-/'! D.S. 16-3 PERF REOORD(8-9-94) 1 1 , ~_ z--~"D~S. 16-31 LEAK DETECTION (8-9-94) 1 1 , , SIGNED: ~ PI nd retum o~e copy of this transmittal to Shertle at the above addr~aa. Thank you. ARCO Alaska, Inc. Date' Apr 14, 1994 P.O. Box 100360, ~ ,mrage, AK Transmittal #: 94034 99510,~ ~b' Subject: ARCO Cased Hole Finals From/Location- Telephone: To/Location: John- E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Well Number 01-09A i Tool Type Perf Record i Log Date ~ (M-D-Y) 04-02-94 77---5~ 01-11~ i 03-25-94 i TDT-P ~::~-i7~.. 01-33 ! 03-28-94 !/. TDT-P 75--f51 03-01 03-02 S:~-c[Z.! 03-19 ~'~--/9 ~ 03-29 03-27-94 i,~ Perf Record 03-22-94 i- Leak Detection /04-43 04-43 i ~,04-43 03-22-94 ~, Bridge Plug 03-18-94 ~ Leak Detection 03-27-94 03-31 03-27-94 03-29-94 c~. t0i 04-44 pl~(- 5u~ J 04-45 l-F -z i 05-08 ~.-~lt~ ! 06-19 '~1~ ~ 07-08 ~-(o~ 07-23 75'-7(~! 09-01 ,'Tt~--'tt~ 09-02 7(~-55i 09-03 "]'"/- ~i 09-19 ~%- 2_~.. 09-27 15ih- (¢0i 11-04 ~lo-C~Cl [ 11-17 '~)--Z0~- 11-24A ~ Z.- 5~.: 12-06A } z-¢ti 13-20 14-03 ~ 14-23 ~ 4-28 14-28 ~14-28 14-35 '2-t 5~ 16-04A 16-18 16-28 18-08 03-29-94 03-10-94 03-13-94 i,/ Bridge Plug i,/' Brid~ie Plu~ : ,/ TDT-P '/ CNTG / USIT .. i,/ USIT 03-29-94 ,/ USiTCement 03-14-94 v' Prod Profile 03-18-94 i,/ Perf Record 04-03-94 !.- Perf Record 03-21-94 i./ Bridge Plu(.:j 03-30-94 i,,' Prod Profile 03-17-94 i./ Prod Profile 03-29-94 i/ Prod Log Run, Scale ! 5II Contractor 1, 5" Sch ; Sch ! 5II 1 5" 2" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" ,5" 5" 5" 1,5" l"&5" 04-01-94 [¢- Perf Record [ 1, 5" 03-16-94 i/' Prod Lo(:j 03-22-94 i / Perf Record 03-16-94 ! ," Patch setting 03-29-94 i/ Perf Record [ 1, 1"&5" [ 1, 1"&5" | ! 5II ~ 1 03-18-94 I.- Prod Profile 03-15-94 i-" Leak Detection 03-28-94 i" CNL 03-19-94 i-" Prod Profile 03-15-94 !,/Leak Detection 03-28-94 iv- Patch Settincj i 1, 5" , 03-21-94 i.-- Brid~e Plu~ i 1, 5" 03-17-94 iv" CNL ! 1, 5" Sch Sch Sch :' Sch Sch : Sch Sch .: Sch Sch Sch : Sch Sch Sch : Sch : Sch : Sch Sch Sch Sch Sch Sch : Sch : Sch : Sch : Sch _, Sch : Sch Sch Sch Sch Sch Sch Sch 03-15-94 i,,'- Perf Record i 1, 5" 03-14-94 !,,"Leak Detection i 1, 2"&5" Sch 03-14-94 iv- Perf Record ~ 1, 5" Sch Sch 03-20-94 i"' TDT-P j 1, 5" Number of Records: 38 ARCO Alaska, Inc, Is a Subsidiary of AttanlJcRIchfleldCompany ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-31-92 REFERENCE: ~ [.-I ,~ ~~_24 qt ARCO CASED HOLE FINALS 1-11-92 Prod Profile ~ 1, 5" Camco 1-11-92 Prod Profile Run 1, 5" Camco 1-10-92 Prod Profile Run 1, 5" Camco 1-10-92 Prod Profile ~ 1, 5" Camco 1-15-92 CNL RLm 1, 5" Sch 1-18-92 Collar Log Run 1, 5" Atlas 12-27-91 Prod Profile ~ 1, 5" Camco 1-12-92 Jewelry Run 1, 5" Camco 1-20-92 Tubing Cutter Run 1, 5" Atlas 1-13-92 Leak Detect Rnn 1, 1" Camco 1-12-92 Prod Profile Run 1, 5" Camco. 1-17-92 CNL-GR ~ 1, 2"&5" Atlas 1-9-92 Prod Profile Run 1, 5" Camco 1-19-92 CCL/Perf Run 1, 5" Atlas Pleue sign and return the at,ached copy as receipt of ' Have A Nice Dayl Sonya Wallace APPROVED .~ - AT0-1529 Trans# 92o2 -t # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ~KA TEXACO * The correct APl# for 13-2A is 50-029-20324-01. RECEIVED FEB 03 1992 Alaska Oil & ~as Cons. Co,minion Anchorag~ ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-24-92 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS 7. ~'[> ~ 6-21 / 11-4-91 CNTD Run i Job#75329 ~~ l~ 14-35 w 7-28-91 DSN Run I Job#L66751-3 ~/8 1 15-15 '~ 7-22-91 DSN Run I Job#L66619-3 Please sign and return the attached copy as receipt of data~ RECEIVED BY ~~_~ Have A Nice Day~. Sonya Wallace ATO- 1529 $ch HLS HLS # CENTRAL FILES (CH) CHEVRON D&M DEDE SCHWARTZ (OH/GCC) # EXXON MARATHON MOBIL #PHILLIPS PB WELL ~ R&D # BPX # STATE OF ALASKA TEXACO RECEIVED FEB O~ 1992 Alaska 011 & (hs Cons. Commission Anchorage ARCO ALASKA, INC. F'.O, BOX ANCHORAGE, ALASKA 995i0 DATE' t-t5-92 REFEI_~ENCE ,~ARCO ~~ HOLE FINAL~? - ~'"~2-J6 t,.:-6-9~ ~CL FOR ~TRE~C FRAC ' ~,~]-Z J2-~8-9~ v.CCL FOR BRZD~E PLU6 -__ )~-~8 ~-24-gJ~'ERF RECORD ~.~/i~-i. 5. 7-22-9i ~~N , - ~g .,,/t e-ze tz-z~-'~t w CCL FOR P~RF F'LEA.?E ~I6N ~ND RETURN THE ~TT~CHED COPY RUN 3, 5' HL$ RUN i , 5' HL$ RUN i , 5' HL$ RUN i , 5' HL$ RUN i, 5' FILS RUN i, 5' HL$ RUN i , 5' HL~ RUN i , 5' HL$ RUN i, 5' HL3' RUN ~ , 5' HL$ ;<L'LL.b.. i Vt--D BY $ONYA WAL. L AL;~ ATO-i 529 A F'F'I:~.~u ¥ I" D ~ TRAN$:~ 92r(";'36 RECEIVED JAN 2 1 1992 ~uasKa Oil & Gas b"Ot~s. Commission Anchorage D!.?TRIBUTION -"- CENi'RAL FILES . AL~rCHEVRON D & M "- E X T E N.'_'_.71 C~ N EXF'LORATI FIN EXXON '11' MARATHON '"- HOBIL 1' F'H II_L I F'.S' F'B WELL F'I[_E>-', R & D BF'X STATE OF AI_ASKA TFXACO ALASKA ..... .AND GAS CONSERVATION CC "~ISSION lID REPORT SUNDRY WELL OPERATIONS" 1. Operations performed: Operation shutdown Stimulate X Plugging ~ Perforate Pull tubing Alter casing ~ Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic 4. Location of well at surface 313' FNL, 1218' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 51' FNL, 217' FEL, Sec. 9, T10N, R14E, UM At effective depth 64' FNL, 46' FEL, Sec. 9, T10N, R14E, UM At total depth 65' FNL, 8' FEL, Sec. 9, T10N, R14E, UM 12. Present well condition summary Total depth: measured true vertical Other 6. Datum of elevation(DF or KB) 69 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-35 9. Permit number/approval number 83-142 10. APl number 50 - 029-21018 11. Field/Pool J:)jt.~(j'~ ~'~{~y Oil Pool 9500 feet Plugs(measured) 9243 feet Effective depth: measured 9434 feet ........ - true vertical 9182 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 2050# Poleset ' 80' 80' Surface 2607' 13-3/8" 1800 sx Fondu & 400 sx PFC 2676' 2676' Production 8751' 9-5/8" 500 sx CIG & 300 sx PFC 8820' 8615' Liner 987' 7" 334 sx CIG 9500' 9243' Perforation depth: measured 9110-9114'; 9114-9124'; 9124-9128'; 9131-9155'; 9155-9158' true vertical 8883-8886'; 8886-8896'; 8896-8899'; 8902-8924'; 8924-8927' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8457' MD; 4-1/2", 12.64¢, L-80, PCT tail @ 8554' MD Packers and SSSV (type and measured depth) 5-1/2", Camco Bal-0 SSSV @ 2193' MD; Baker SAB packer @ 8445' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attachment Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 643 599 21 1357 844 1196 Tubing Pressure 219 243 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true a,..~ correct to the best of my knowledge. Signed Title Operations Engineering Manager Date ~/~/~} Form 10-404 Rev 06/15/88 '71~ ItAlC~ r,r,' 1'3 Wnrnnr ~,TC3.1~7Cl .(:;W .IWP SUBMIT IN DUPLICATE DS 14-35 DESCRIPTION OF WORK COMPLETED SELECTIVE HCL ACID STIMULATION TREATMENT 4/7/9 1: A Selective HCL Acid Stimulation using an inflatable packer, was performed as follows: MIRU CT & PT equipment. Loaded wellbore w/seawater. RIH w/CT mounted inflatable packer & set packer at 9107' MD (center of packer), to isolate the upper squeezed perforation intervals at: -- 9072 - 9092' MD (Z4) Ref. Log: BHCS 11/12/83. 9095 - 9105' MD (Z4) Treated open perforation intervals at: 9110 - 9114' MD (Z4) 9114 - 9124' MD (Z4) 9124- 9128' MD (Z4) 9131 - 9155' MD (Z4) 9155 - 9158' MD (Z4) Ref. Log: BHCS 11/1 2/83. Pumped: a) 154 bbls 12% HCI w/10% Xylene, followed by b) 25 bbls 2% NH4CI Water, followed by c) Shutdown. Flushed w/95 bbls of Meth/Water. POOH w/packer. RD. N2 lifted & flowed well. Obtained a valid production welltest. ARCO ALASKA, ANCHORA[.;.['~., ALA$1<A ?'95i () l,f..,1 E.' _;-6-, t -"r i -" .}.?, 0 '"~ -" 4'"' 9 i T E h F' F!: R A '1" U R f.'.";. F;: U i'.l t , _. · 2 .... i 6 4 -.- 'J :3-'--9 'i t.. E A K 1) E 'T' F:' C 'F I 0 i'.! - F;,' I.J N i., .., ~' '-. t 7 -.4 -'- t,::.'" .... "';-' ...., ~, 4 .... i ,.-::, 4..-. ri:..-. 9 i :r. I ~ -" 5:'"' '''> ":" .a -.. 2 © - ':::' i C'. B i" l:i: U Nt "~'" 6 .... i..,-'::.' z,., ... ,;.~,_, ..- ,:a, i P R 0 .... 1'.-.. I Ir",.. '¥ I O. 14. I.;:l...li'{ t , 5" 6--.:;-.::.¢;, 4-6-9i F'F;.:ODLICTION RUN i , .5" 9 -.a., ,',.., .- i 7,._ .-.-9. i 1... E A KD E T [.:' C T I '.".;'..-. '.':-;' 4 ---':':'- c;,, L. Iii[ Pi i.-'.'.' D Iii; 'f' I-'i[ C"I" [ f') N I:;,' U N t , 2 "&':5" _> ; 'l . .. 0 -- 10'1"- /:'- ,:, "~ ':.'i.-' 2, 1 ..... ¢ --i, (].'OL.I...AI;.:/F'["I-;~F" I:;:I...IN 0'~ ~"'O/~c-,,, ........ 48 4 4-9i (;AHHA/r;CL/JE:WEI..F..:Y I:;:UN i, .,-"::" i i- .-i, 4 .... 2 -.- 91 I_. ,r..~ A K. i i .... .3; -;-;" --. 2 - 9 .i, L. iii: A K I.., E T E C l I 0 i'--~, R t..I N t , ..; · t t ..-4 4 .... :3-9i !"'ITS/IN,JECTIOi'~, F;,'LIN t,:.'.'"' "- ,-..":' ;'!'f -.;-"~ -" 6 "" 9 t ]: f"~ J E f'-'. .... 1' ]: fl j"-~ Fi/U Ik.I t , c;..... ,, i 2 .... "~'":' " ,:.....:. .q. .... i 4-9"i IN,..IECTION Ir<UN t , ., ..... 5 ' .:,(- i4 2E.i T:~ ;'!;--91 PRODUCTliON RLIN t 4-.25: 4--3---9 t COLLAR F;:UN i '7 .... t --,a -.. ¥ .-. 9 i F:' F;.: 0 D I_.IC. 'f' I 0 N R L.I N t , ..;.'='" qO -. '-'"":"--'";:-" , / F' l,,J Z:' I.,,I 1 -" © A ........ '" i 'i" F:'I._E. AJ:.'['i: ,:'"..:IGN AND I:;,'IE'T'UF'::N THE ATi"ACHED COF:'Y AS F<ECEIF:"f' 01::' DATA, C A J',l C: i.':.'1 C A I,t CCi C A Fi C 0 C A H C 0 .S'CH C A i'1C [) CAMCO C A H C 0 C; A i"i C 0 A T I... A S C A J"i C 0 CAHCO C i::1 fl C C) C A M C 0 C A I"i C 0 C A M C 0 C A I'1C 0 CAMCO C A i"i C 0 C A H C 0 HAVE A NIC['_" DAY! .'.'-;' I-'1A F:.: 0 i'-.-! W I I.. S 0 i"'] ATO-i..., ,.... ":' ":" '::',- D I :'-]' T F;.: I B L.I T I [) N · ,-'"' CI.r.':N'i"RA~,... FILES · "- F: H F:' V ,r.;: r) N '11 ' _ ..... D & H · '1 ~% · ,.'"' [i: X 'r E: ?-4 ,S: I O i'--~ EXF:'I...ORF.,TIrli'.I.. :,"-' ["'XXON H A R A i" H 0 N -,¢: HOBII_ · ,,'"' PHILLIPS PB WELL F'ILE:£' R & D 4' B P X -,.'*',S"I"A'I'E BiF_ ALASKA i"EXACO · x- T I"11 ,S' I S A .f) L.IF:' L. I C A T E O F" T kt E L. O I] Y O L.I A i_. R F_": A I) Y R E C E I V E I), E. X C E F' T T H [:' A F:' I I$ COF;:RECTED, F'LEA,?E THI;,'OW '¥HE F'REVlOUS COPY WIIH 'f'HE WP,'ON(; AF'i~ AWAY, STATE OF ALASKA ALASF~"')IL AND GAS CONSERVATION ( .... 'vlMISSION ~ -:~ ~'"-'~ ~ REPOR OF SUNDRY WELL OPI RATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing Plugging Perforate X Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 313' FNL, 1218' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 51' FNL, 217' FEL, Sec. 9, T10N, R14E, UM At effective depth 64' FNL, 46' FEL, Sec. 9, T10N, R14E, UM At total depth 65' FNL, 8' FEL, Sec. 9, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 69 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-35 9. Permit number/approval number 83-142/9-773 10. APl number 50 - 029-21018 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9500 feet Plugs(measured) 9243 feet Effective depth: measured 9464 feet true vertical 9210 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 2050# Poleset 80' 80' Sudace 2607' 13-3/8" 1800 sx Fondu & 400 sx PFC 2676' 2676' Production 8751' 9-5/8" 500 sx Cl G & 300 sx PFC 8820' 8615' Liner 987' 7" 334 sx Cl G 9500' 9243' Perforation depth: measured 9110-9114'; 9114-9124'; 9124-9128'; 9131-9155'; 9155-9158' true vertical 8883-8886'; 8886-8896'; 8896-8899'; 8902-8924'; 8924-8927' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8457' MD; 4-1/2", 12.6~, L-80, PCT tail @ 8554' MD Packers and SSSV (type and measured depth) 5-1/2", Camco Bal-0 SSSV @ 2193' MD; Baker SAB packer @ 8445' MD 13. Stimulation or cement squeeze summary ~ ~ ~. V~/,'~ Intervals treated(measured) See attachment Treatment description including volumes used and final pressure i.v!.AY 0'8 1990 Oil & Gas Cons° Commission 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Production or Iniection Data ' ',ii, ~rlch01'a~ OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 1826 9724 566 -- 1175 2250 1350 793 -- 234 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE DS 14-35 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUT-OFF 10/20/89: MIRU CTU & Stimulation Equipment. PT equipment to 4500 psi. RIH w/CT and washed perforations at: 9072- 9092' MD Ref. Log: BHCS 11/12/83. 9095 - 9105' MD 9114 - 9124' MD 9132 - 9142' MD 9145 - 9155' MD Pumped 30 bbls 30 bbls 30 bbls the following treatment: 12% HCl w/10% Xylene, followed by, 12-3% HCI-HF, followed by 12% HCI. Displaced CT w/25 bbls of Diesel. POOH. Rigged down. I I/29/89: A cement squeeze and same day cleanout were performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/525 bbls of seawater. Pumped 50 bbls of cement, squeezing perforations: 9072 - 9092' MD Ref. Log: BHCS 11/12/83. 9095 - 9105' MD 9114 - 9124' MD 9132 - 9142' MD 9145 - 9155' MD Placed 7 bbls of cement behind pipe, at 3000 psi maximum squeeze pressure. Pumped 300 bbls of 1-1/2# Biozan w/20% Methanol and 165 bbls of 1/2# Biozan w/20% Methanol, to contaminant and circulate cement out of the wellbore. POOH while displacing CT w/208 bbls of 60/40 Meth - Water. Rigged down.. 12/1/89: MIRU, and RIH to tag bottom at 9456' MD. POOH. Rigged down. 12/6/89: Reperforated: 9114 - 9124' MD 9132 - 9142' MD 9145 - 9155' MD Ref. Log: BHCS 11/12/83. Added perforations: 9110 - 9114' MD 9124 - 9128' MD 9131 - 9132' MD 9142 - 9145' MD 9155 - 9158' MD Ref. Log: BHCS 11112/83. Returned well to production and obtained valid production test. ARCO ALASKA, INC F' ~ O. BOX i ANCHORAGE, ALASKA 995 t O DATE' REFERENCE' ARCO CASED HOLE FINALS '-~-t 6 i 8-'~4-89 GAMMA DSN 5-26 i 2-9-89 CBT 5-26 t 2-9-89 CET t4-35 t2-6-89 PERF F(ECORD t~- ~ i i 2-~'-8o.,, .CF'ET i 5-i i 2-i ~-89 COLLAR/PERF .PI_EA~E SIGN AND RETURN THE ATTACHED COPY RECEIVED BY ~ FIAVE A NICE DAY! SALLY HOFFECKER ATO-i 529 DEC 819B9 Aiasl '.Oil.& Gas Cons, DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION. EXXON MARATHON MOBIL RECEIF'T RUN t, .5' HLS RUN i , '5" SCI..i RUN i, 5." ,S'CH I;,' I.J Iq RUN i , i /'>,. '...-:* t" $CH RUN OF: DATA. AF'F'ROV 9~ ED __ TRANS$ 8 9 PHIl_LIPS F'B WELL F'ILES R & D BF'X STATE OF ALASKA TEXACO ARCO Alaska, Ir Prudhoe L. Engineering Post Office ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager August 29, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 14-35, Permit No. 83-142 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/DCR/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 14-35)W1-3 RECEIVED AUG 3 0 1989 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALAS}"'-'""DIL AND GAS CONSERVATION~ "VIMISSION APPLICATION FOR SUNDRY Ar, PROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate Change approved program Pulltubing Vadance Perforate X Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 313' FNL, 1218' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 51' FNL, 217' FEL, Sec. 9, T10N, R14E, UM At effective depth 64' FNL, 46' FEL, Sec. 9, T10N, R14E, UM At total depth 65' FNL, 8' FEL, Sec. 9, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 69 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-35 9. Permit number 83-142 10. APl number 50 - 029-21018 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9500 feet Plugs(measured) 9243 feet Effective depth: measured 9464 feet true vertical 9210 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 2050# Poleset 80' 80' Surface 2648' 13-3/8" 1800 sx Fondu & 400 sx PFC 2676' 2676' Production 8793' 9-5/8" 500 sx CIG & 300 sx PFC 8820' 8615' Liner 987' 7" 334 sx Class G 9500 9243' Perforation depth: measured 9072-9092'; 9095-9105'; 9114-9124'; 9132-9142'; 9145-9155' AUG ~ 0 ],989 Alaska Oil & Gas Cons. Corem true vertical 8848-8866'; 8869-8878'; 8886-8896'; 8903-8912'; 8915-8924' Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8457' MD; 4-1/2", 12.6#, L-80, PCT tail @ 8554' MD Packers and SSSV (type and measured depth) 5-1/2" Camco Bal-0 SSSV @ 2193' MD; Baker SAB packer @ 8445' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation September 1989 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~~//,,~~/_~,'~___,~ Title Operations Engineering Manager FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- 15. Status of well classification as: Oil x Gas Suspended Date Approved by order of the Commissioner ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE D.S. #14-35 CTU GSO Cement Squeeze PRELIMINARY PROCEDURE Objective: The purpose of this workover is to shut off excess gas production. 1. RU slickline. Surge well and tag bottom. 2. RU CTU and acid equipment. Acid wash the perforations. 3. Flowback acid load and production test the well. 4. RU CTU and cementing company. Squeeze off perforations with a maximum squeeze pressure of 3000 psi. The perforations to be squeezed are as follows (Ref BHCS dated 11/12/83): Perforation Interval Zone 9,072' -9,902' 4 9,095'-9,105' 4 9,114'-9,124' 4 9,132'-9,142' 4 9,145'-9,155' 4 5. Maintain 3000 psi squeeze pressure for one hour. 6. Dilute cement remaining in wellbore with mud. 7. Jet out diluted cement. Cleanout wellbore to PBTD. 8. Shut well in for one week. 9. Perforate the well as follows (Ref BHCS dated 11/12/83): Pre-squeeze perfs Comments 9,072'-9,092' Gas Source 9,095'-9,105' 9,114'-9,124' 9,132'-9,142' 9,145'-9,155' Post-squeeze perfs Zone SPF (~omm~n~ 10. Return well to production. 9,110'-9,128' 4 FSD Add/Reperf 9,131 '-9,158' 4 FSD Add/Reperf Current Status: Producing on cycle with an 8% shut-in factor. Estimated Reservoir Temperature: 220OF Estimated Reservoir Pressure: RECE YED 'AUG o 1_§89 3700 psi Alaska Oil & Gas Cons. commissio~ Anchorage 6 .5 4 3 2 COILED TUBIN~ UNIT BOP EOU l PllENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PiPE RAMS 3. 5000 PSI 4 1/6" ffYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 3 N:IRELINE BOP EQUIPMENT _ i I. 5000 PSI ?" W£LLHE. A~ CONN£CIOR FLANGE 2. 500C) PSI WIR£LINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUEIRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF AF.'.CO ~':~ AZKA, :[NC~ ANCHORAGE, ALA3'KA DATE' ~7-i 9-89 REFERENCE' ARCO CASED HOLE FINAt_~ 6-27-89 7- 'i 5.-89 7.-2-89 ~-..- i.~-o :? 6-5£:,-89 7-i -89 7-2-89 6 -'28 - 89 7-i -89 6-29-89 6-28-89 6-28-89 7-S-89 7-S-89 MI INJECTIF~N F'F.:OFILE S'URVEY RUN i ~" COLLAR/F'FRF I-;,'l.J N F'I:;..'ODUCTZOi'-~ PROF]:LE ,~UI:,.:VE"f' i:;:LiN 1 , 2 "-71.:..5 "' PRODUCTION F'IROF :[ !..E SURVEY I.;,'UN i, 5:" F'IT,S' RUN i, 5" F' 'f 'T.? RUN i-':'i::.;ODUCTIriN F'ROFILE F('UN ~ , 5" F'RODUCT..ION F'ROI:rILE ,S'UF,'¥FY RUN F'RODLIC-F I ON PROFILE RUN LEAK £:,ETECTION i:;:UN 4, t "' LEAK DETECTION RUN. LEAK DE'¥ECTION RIJN t, 5" · hR/t,..., L RUN GR/CCL ~.'.UN t, 5' F'LE RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER ATO--t~ ASE SIGN ~,NI, RE~]'URN THE ATTACHED COPY AS' RECEIPT OF' I)A ;t..,.oL ~'...:-~ *' ' 'TRAN2':~ 893¢4 C A ;"l C 0 A ]'I_A;"£ C A H :..: 0 tS A ri C_: 0 C A i-n C 0 C A ,',i C t] [:; ~'::'~ H C :3 C A ~'"'i C: t} C A H C U C: A ¢.i C 0 C A M C 0 C A i'd C 0 CAMCO CAMCO DISTRIBUTION CENTRAL FILEL~* ~ F'H ILL I F'5' CHEVRON F'B WELL FILES' D & M R & D EXTENSION EXPLORATION ~ BPX . EXXON ~ ;]"i-ATE OF ALASKA MARATHON ::-' TEXACO MOBIl_ ANCHORAGE~ AI_A~KA DATE: RFFERENCE' ARCO CA~ED HOLE FINAl_. PWDW2-t 4-29 9-'2 9-5 9-5 9-t5 t S-~...8 ~ 4-26 ~8-~ t8-9 CgI...I...AR/PFRFORATTnN gDILAR/PERFgRATIDN gDI..I..~R/PERFgRATION ~A~IN~ glITTFR fiOI...LAR COLLAR COL_LAR/P~RFRRATION CDI...I...AR/PERFDRATION CRt. t..~R/PERFORAT~ON CDt..I.AR COl._I._AR/PERFORATTDN COt. I..AR RIIN 'i: 5 · RIIN 't ,, ~" RIIN 'i...5" RIIN ~i , ~ · RI.IN 'i . .5" F,,'IIN 'i . ~ · RI.IN "i., .5 · RIIN 'i. 5· RI.IN 'l., ~ · RIIN 'i ,. ~ · R'I.JN "i ) 5" RLIN 't , ..'5 · RIIN 't, 5" RUN 'i, 5 · RECEIPT OF DATA., ATI .AX' ATi ~X' ATI .AX' ATI ATI..A,~ ATI. A,~' 'ATI.AS ATI ATI...AX' ATI.. A.S' ATI_A..~ ATI. A.~ ATI_.A,~ ATI_.A,~ ATI_.A,~ RECEIVED BY_ HAVE A NICE DAY~ CENTRAl_.. FILES · PHII...I..IF'$ CHEVRDN F'R WELl.. FII.F~ D & M R & D EXTEN2ION EXPLORATION · 2A~C MARATHON ~ ~ TEXACO MOBIl... ARCO Alaska, Inc P,O. Box Anchorage, Ala.~ka 995~ DATE: 9-30-87 REFERENCE: ARCO Magnefic 9-5 ~ ii-t9-84 CH CN/HS, 7-5 ~ ~-2~&J~-85 CH CN/MS, ~ 5-~ ~ 5-~ 6-87 CH ~-~/ 5-~5-85 CH CN/MS, ~ 4-.3.5 ,'"'5-~ ~ -85 CH CN/MS, Tapes EC .:~ 08,7 ECC2t t t ECC2 t 78 ECC2I 79 ECC2 t 66 · c E.~Y ! A~aska Oil & Gas Cons. Commission Records' T~ANS ~8T~89 Approved Run ,.'2 Run 6 K~ ~- of dafa. Afl. ms At I. ms (°)Cel~trat... Fi Le.$ ~ Phi ttip.~ Chevron F'B Wel. l Fi l. es D & H R &. D )F' , Mc F'h eef er ~.. ~ SAF'C Exxon ~ Sta~e of ALaska Ma )- a f h o)~ r~., .. -, ,.. o Mob i t ~' STATE Of ALASKA ~'~ ~ ALASKA ~IL AND GAS CONSERVATION L,,JMMISSION ~ ~ WELL COMPL :TIO# OR RECOMla'LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-142 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21018 4. Location of well at surface 9. Unit or Lease Name 313' FNL, 1218' FEL, Sec. 9, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 51' FNL, 217' FEL, Sec. 9, T10N, R14E, UM 14-35 At Total Depth 11. Field and Pool 65' FNL, 8' FEL, Sec. 9, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 69' ADL 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 11/01/83 11/1 2/83 11/23/8:3* N/A feet MSLt 1 17. TotalDepth(MD+TVD) 18.PiugBackDepth(MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 9500'MD, 924:3'TVD 9464'MD, 9210'TVD YES [~ NO [] 219:3' feet MD 1900' (approx) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, LDT/CNL/GR/Cal, RFT, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD , SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE iTOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ZO" 91.5# H-40 Surf 80' 30" 2050# Poleset 13-:3/8" 72.0# L-80 Surf 2676' 17-1/2" 1800 sx Fondu & 400 sx PFC 9-5/8" 47.0# L-80 Surf 8820' 12-1/4" 500 sx Class G & :300 sx PFC 7" 29.0# L-80 8513' 9500' 8-1/2" :334 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/4 spf, 120° phasing 5-1/2"/4-1/2" 8554' 8445' 9072 ' -9092 'MD 8848 ' -8866 'TVD 9095'-9105'MD 8869'-8878'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9114'-9124'MD 8886'-8896'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 91:32'-9142'MD 8903'-8912'TVD N/A 9145'-9155'MD 8915'-8924'TVD 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ .. Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MC~: WATER-BBL OIL GRAViTY-APl (corr)" Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. *Note: Perforated well 3/31/85. WorkoYer performed 11/9/87. Form 10-407 WC4/21 :DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ 29. ?,. 30. GEOLOGIC MARKER~;- - IFORMATION TESTS · . . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR,and time of each phase. Top Sadl erochi t 8954' 8739' N/A 0/W Contact 9334' 9090' Base Sadlerochit Not reacheJ .., 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ 5Z~/~/_//J-¢.)[ ! Title Associate Engineer Date /~'~/'1~7 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 STATE OF ALASKA ALA, , OIL AND GAS CONSERVATION COM .... 5ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging [] WORKOVER Alter Casing [] Other I~ Perforate [] Pull tubing 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska~ Inc. RKB 69' Feet 3. Address 6. Unit or Property name P.O. Box 100360 Anchorage, AK 99510-0360 Prudhoe Bay Unit 4. Location of well at surface 313' FNL, 1218' FEL, Sec. 9, TION, R14E, UM At top of productive interval 51' FNL, 217' FEL, Sec. 9, TION, R14E, UM At effective depth 64' FNL, 46' FEL, Sec. 9, TION, R14E, UM At total depth 65' FNL, 8' FEL, Sec. 9~ TION~ R14E~ UM 11. Present well condition summary Total depth: measured 9500'MD true vertical 9243'TVD Effective depth: measured 9464 'MD true vertical 9210 ' TVD feet Plugs (measured) feet 7. Well number 14-35 8. Approval number 7-854 9. APl number 50I 029-21018 10. Pool Prudhoe Ba~/ Oil Pool None feet Junk (measured) None feet Casing Length Size Conductor 80 ' 20" Surface 2648 ' 13-3/8" Producti on 8793 ' 9-5/8" Li ncr 987 ' 7" Cemented Measured depth True Vertical depth 2050# Pol eset 80 'MD 80 'TVD 1800 sx Fondu & 2676'MD 2676'TVD 400 sx PFC 500 sx Class G & 8820'MD 8615'TVD 300 sx PFC 334 sx Class G 8513'-9500'MD 8331'-9243 'TVD Perforation depth: measured 9072'-9092', 9095'-9105', 9114'-9124', 9132'-9142', 9145'-9155' true vertical 8848'-8866', 8869'-8878', 8886'-8896', 8903'-8912', 8915'-8924' Tubing (size, grade and measured depth) 5-1/2"/4-1/2", L-80, tbg w/tail ~ 8554' Packers and SSSV (type and measured depth) Camco Bal-O SSSV @ 2193', Baker' SAB hydrostatic pkr @ 8445' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED Alas~ 011 & Gas Cons. Commission Anchorage 13. N/A ' Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Wel 1 Hi story) Daily Report of Well Operations ~, Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Associate Engineer (Dani) 5W03/14 Date /2-~-~7 Submit in Duplicate .' :;~6~d',~i,~mpany. ~-' Well Histo~-Initial Repo,- Dally I~~ Prepare and ~bmit-the "Initial R~' on. the fl~ Wednesd~ a~e; a well is .~udded or workover o~ratlons are sta~ed. Daily work: prior to spudding should be summarized on the form giving inclusive dates only. - District A1 as~ . Field Prudhoe Bay ,_' . ADL 28312 Auth. or W.O. no~:- '- - -' ~' . .. - . -. '-, AStTO3L '- O.emtor.-~ - -..; ' - --:::: '-~:~_:: '~ ,-; - - -¥ - . -=..,:, --:-;-~. .. :-. ~}:: <~' '.-"-:-.~': ...... · ~0/28/87 . a: ~ -.~- -~ ' -. :~-. - ' , ' Date-a~d~ :'.:-~:.-:;¥... -;: -_ l~ete~rd for ea~ day re~ ::-~-4'-'~..';" . _ =--'-": .,-. ,-_: . ~,- _:':~?:77"-'"'i/" :-:_::'"".':-[~'::("'----95'00~' PB~, ~ BOPS :~- ~'- ' ~" '. [-' "',. 8:5 PPS sea : I' :' Accept ri$$ 1445 hfs, 10/28/87. . :-~f~ ' tree. ~ BOPS. - _.. : . 10/31/87 thru 11/02/87 11/03/87 11/04/87 11/o5/87 ,,:?:~,._~l~unw'parish°rb°r°ugh North Slope Borough Leas~ or Unit ITitle Recompletion API 50-029-21018 IHour · . 1445 Hrs. IState Alaska ARCO W.I. Prior status if e W.O. Well no. 14-35 W/O Kill well w/sea w~r. ND 21.66% 7" f/8513'-9500' 9500' PBTD, RIH w/retrv'g ti 8.5 ppg sea w-tr NU & tst BOPE. Shear PBR, POH w/5½" tbg. 3½" DP. RIH w/retrv'g tl on 7" f/8513'-9500' 9500' PBTD, Prep 20" csg 8.5 ppg sea wtr Rel pkr, POOH w/pkr & tail assy-. RU DA, make GR/JB rn to 8513'' WLM. RIH, set BP @ 8483', tst csg to 2200 psi. Displ 180' w/diesel. RIH w/cutter, cut 9-5/8" csg @ 45'. RIH w/BO tl, BO 9-5/8" csg stub, spear into same, back out & LD same. TIH w/BP; unable to get into 13-3/8" csg. TIH w/tapered string mill, mill wellhead bushing, POH. Chg mills, RIH, mill on bushing. ND BOPE. Set 13-3/8" BP. Displ diesel w/sea wtr. PU 13-3/8" spear. Make cuts on 20". Chip out cmt. 7" f/8513'-9500' 9500' PBTD, Tst BOPE 8.5 ppg sea wtr Fin preparing 20". BO 13-3/8". into 13-3/8" csg, dress off same. Instl 20" ext & he~.~aB--~'~~']~ NU BOPE & tst to 5000 psi. 7" f/8513'-9500' 9500' PBTD, POH w/3½" DP ' sk~0il~ ~as C0n~.¢0mmissi0~ 8.5 ppg sea wtr Retrv BP. RIH w/9-5/8" csg, screw into csg, BO-~-5/8"'c~ above slips. Displ well w/sea wtr @ 180'. Cut off 9-5/8" csg. NU tbg spool & BOP. Tst csg to 2500 psi, 9-5/8" pack-off to 3800 psi, 13-3/8" packoff to 1000 psi. RI~ w/shoe & PRT, cut over BP @ 8483', POH w/DP. 7" f/8513'-9500' 9464' PBTD, Make CO trip 8.5 ppg sea wtr POOH; no fsh. TIH w/spear, PO~H; no fsh. rec'd BP. TIH f/CO trip to PBTD. TIH w/OS, POOH; The above i~ correot For for}n Pre~lratlon and"dlStrtbutl°n, ~PmCedu~ ManUal;;Se~Uon: 10, DHI}ii'~ -P-~-~'- ~-id~ ~7.-".~: Date I Title 12/04/87 Drilling Supervisor a Company Daily Well History-Final Report Inlffucllona=:Prepero and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned. or Sold. "Final Rel~ert, should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. ~ I Accountlng cost center code I District ICounty orParish IState A~aska North Slope Borough Alaska Field ILease or Unit I Well no. Prudhoe Bay ADL 28312 14-35 W/O Auth. or W.O. no. ITitle AS 1703 I Recomplet ion WWS #1 API 50-029-21018 Operator ~.CO Alaska,Inc. IA'R'c°' w'l'21. 66% ,abandonmentlC°stlT°tal number °f wells (active °r inactive' °n thllcenter priOrof thist° pluggingwell and Workove= 10/28/87 ! 1445 Hrs. · [.. .: .-': Date and depth as of 8:00 aim. 11/06/87 11/07/87 thru 11/09/87 11/10/87 Complete record for each day reported 7" f/8513'-9500' 9464' PBTD, RIH w/5½" compl ~.5 ppg sea wtr TIH, tag fill @ 9444', rm to PBTD, rev CBU. Displ well w/filtered sea wtr treated w/C-143 inhibitor, POOH, LD DP. Make GR/JB rn to 8500'. RU & rn 5½" compl. 7" f/8513'-9500' 9464' PBTD, Wait on weather to move Diesel P,n 204 jts, 5½", 17#, L-80 LTC AB-Mod tbg w/Bal-O-Nipple @ 2193', SAB Pkr @ 8445', TT @ 8554'. ND BOPE. NU & tst tree to 5000 psi. Displ well w/diesel. Tst tbg to 3500 psi f/30 min; OK. Tst ann to 2500 psi f/30 min; OK. Wait on weather. Wait on weather. Rig on standby w/crews. RR @ 2400 hfs, 11/9/87. Old TD New TO Released rig 2400 Hrs. Date 11109187 IPB Depth Kind of rig 9464' Rotary Classifications (oil. gas. etc.) Oil Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing S ad ler ochit Potential test data Well no. Date Reservoir Producing Interval iOil or gasTest time Produclion Oil on test IGas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate ITitle 12/04/87 Drilling Supervisor STATE OF ALASKA AL,._~, OIL AND GAS CONSERVATION CO .... ,'IlSSlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon © Suspend .'~ Operation Shutdown .m. Re-enter suspended well [] Alter casing Time extension ~ Change approved program C Plugging m. Stimulate ..% Pull tubing'~ Amend order ~ Perforate _~ Other X 2. Name of Operator ARCO Alaska~ Inc 3. Address P. 0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 313' FNL, 1218' FEL, Sec. 9, T10N, R14E, UN At top of productive interval 51' FNL, 217' FEL, Sec. 9, T10N, R14. E, UN At effective depth 64' FNL, 46' FEL, Sec. 9, TION, R14E, UM At total depth 65' FNL, 8' FEL, Sec. 9, TION, R14E, UM 5. Datum elevation (DF or KB) RKB 69 ' 6. Unit or Property name Prudhoe Bay Unit 7. Well number 14-35 feet 8. Permit number 8B-147 9. APl number 50-- 029-21018 10. Pool Prudhoe Ba), Oil Pool 11. Present well condition summary Total depth: measured true vertical 9500 ' MD feet 9243 ' TVD feet Plugs (measured) None Effective depth: measured true vertical Casing Length Conductor 80' Surface 2648' Production 8793' Liner 987' Perforation depth: measured 9464 'MD feet feet 9210'TVD Size Junk (measured) None Cemented Measured depth 20" 13-3/8" 9-5/8" 7" 2050# Poleset 1800 sx Fondu & 400 sx PFC 500 sx Class G & 300 sx PFC 334 sx Class G 9072'-9092' 80'MD 2676'MD 8820'MD 8513'-9500'MD , 9095'-9105' , 9114'-9124', 91S2'-9142' ~ue Verticaldepth 80'TVD 2676'TVD 861 5 'TVD 8331'-9243'TVD , 9145'-9155' true vertical 8848 ' -8866 ' , 8869 ' -8878 ' , 8886 ' -8896 ' , 8903 ' -8912 ' , 891 5 ' -8924 ' Tubing (size, grade and measured depth) 5-1/2", 17#/ft, L-80, tubing w/tail @ 8544' /~: Packers and SSSV (type and measured depth) Camco Bal-O SSSV ~ 2183', Baker FHL-51A hydrostatic pkr ~ 8466' 12.Attachments Description summary of proposal ~/~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation October 27, 1987 14. If proposal was verbally approved A mechanical integrity test will be r'equired when the well Name of approver Mike Mi~'dSerC?:nf~Cc~d to injection. Date apprdved 10/27/87 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed <fl/~./~/[/ ~~.AJ Title Associ ate Eqaineer (~ Commission Use Only (JG) SA3/8 Conditions of approval Approved by Date [] Plug integrity [] BOP Test [] Location clearance! '~" ~'~: ~'~' ~'~ .....Commissioner -~ - ~, the commission Date / Form 10-403 Rev 12-1-85 Submit in triplicate~ PBU DS 14-35 WORKOVER PROCEDURE SUMMARY WORKOVER OBJECTIVE: To replace the cracked 13-3/8" mandrel hanger. Additionally, the retrievable packer will be replaced with a permanent packer and seal assembly suitable for miscible gas service. 1) MIRU WW1. ND tree, NU BOPE. Shoot circulation perforations above the PBR and displace the tubing and annulus to weighted seawater. 2) Pull the existing 5-1/2" tubing and PBR stinger. TIH and latch onto the PBR barrel. Remove the Baker retrievable FHL packer and PBR. 3) RIH with a retrievable 7" bridge plug and set it at 9000'. Test the bridge plug, liner lap, 7" casing and 9-5/8" casing to 2200 psi. 4) Pick up a Tri-State internal mechanical casing cutter. Cut the 9-5/8" casing just below the 9-5/8" mandrel hanger and pup. Remove the hanger and pup. Blow the 9-5/8" casing dry with air for 50'. 5) Back out the 9-5/8" stub at the next collar and lay down. 6) Set a 13-3/8" retrievable bridge plug just above the 9-5/8" casing stub. Remove the 13-3/8" starting head from the 13-3/8" nipple. 7) Circulate out the Arctic pack above the 13-3/8" bridge plug, replacing it with water or brine. Spear the 13-3/8" in the first joint below the hanger pup and pick up until weight is off the landing ring. 8) Cut the 20" casing below the 13-3/8" hanger pup connection. Locate the hanger flutes and make four vertical cuts along the flutes. Remove each piece. Dress the 20" stub. 9) Chip out the cement in the 13-3/8" x 20" annulus above the 13-3/8" hanger pup connection. Spear the 13-3/8" hanger pup and backout the hanger and the pup. Screw in a short section (+6') of 13-3/8" casing into the stub. NOTE: If the hanger and pup cannot be backed off, or the 13-3/8" stub threads are damaged, the following procedure will be used. a) Cut off the 13-3/8" casing just below the 13-3/8" fluted hanger. Remove the hanger. b) Dress the 13-3/8" stub. Place the 13-3/8" socket weld by socket weld bushing over the 13-3/8" stub and weld in place. 10) Trim cut the 13-3/8" to accept the casing head and base plate. Weld the 20" base plate onto the 20", adjusting the height with a 20" socket weld bushing. PBU DS 14-35 WORKOVER PROCEDURE SUMMARY (cont'd) 11) Install the starting head. Flush the water out of the 13-3/8" with diesel. Pull the 13-3/8" bridge plug. 12) Rerun a joint of 9-5/8" casing with a screw-in bushing on the end. Screw into the stub and make up. Hang off on emergency slips. 13) NU the tubing head and BOPE. Test the 9-5/8" casing and packoffs. TIH and pull the retrievable bridge plug. 14) RIH with a 8.500" gauge ring/junk basket to the top of the liner hanger. 15) Run a new completion consisting of: o A 4-1/2" or 5" tailpipe wi th XN or DB nipple. o A 5-1/2" x 9-5/8" permanent packer and seal assembly with extra seal units (if necessary) for WAG service. o A 5-1/2", 17#, L-80, LTC-Mod, IPC tubing string with a 5-1/2" SSSV. 16) Set a BPV. ND the BOPE. NU tree and test. Displace the annulus and tubing. Set the packer and test the tubing and annulus. 17) Release rig. PW06/9 10/27/87 I I ANNULAR PREVENTER PIPE RAMS BLIND RAMS 4 TUBING HEAD 1. 13-3/8" CASING HEAD 2. 9-5/8" CASING HEAD 3. 5000 PSi TiJBIN..'~ HEAD 4. 13-5/8" - 5000 PSI BLIND RAMS l?-~,/~" - 5000 sql .... 6. 13-5/8" - 5000 PSI ANNULAR . . . 6 7 8. . 10, !i. 12. !3. !4. ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR ~ESERVOIR TO PROPER LEVEL :WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PP. ESSURE IS 3000 PSi WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGiHG PUMP OFF. 4. RECORD ON THE IADC P. EPORT. THE ACCEPTABLE LOWER LIMIT IS 4,.5 SECONDS CLOSING TIME AND 1200 PSI P, EMAiNiI'.IG PRESSURE. BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. CHECK THAT ALL HOLD-DOWN SCREW5 ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT iN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE rlANIFOLD. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. ~NCREASE ~n=CC~lD~ TO ~n"" .... v'u At'iD HOLD FOP. !0 MINUTES ~- r~l._-~,..~ ~.r-.~ ,-' ~;.~ - · CLOSE VALVESDIREC,L uPSTREAM OFrHOKE'5 BLEED D©WNSTRE~r; PRESSURE TO. ZERO PSi To)_ TEST ",/,~.L" ' ",'~"'~,:,. TEST REMAINING U:.iTE':,TFD_ _ MANIFOLD VALVES. iF ANY. WITM 5OOU PS1 UPSTREAM OF VALVE AND WiTH ZERO PSI DOWNSTPEAM. ~LEEDSYSTEM TO ZERO PSI. OPEN PiPE ~A!'15. -*_--,ACi<.OFF F~U..NNiNC:, JT AND PULL OUT OF HOLE. CLOSE E:-L!ND F..AMS Al'iD TES? ?:5 50')0 P'.--;! FOR !.:) M',NUTES BLEED TO ZERO pSi. OPEN ~L,~' 'F~"'"" ..... RAMS AND REC':_-'.'VEP "r'E':'"r, ..... ~"I !IG MAKE SURE MANIFOLD A. LC- LINES ARE FULL OF ARCT;C DiE'EEL AND ALL VAL",/E~ A.~.E SET ~rq DPlLLING POSITION. TEST STANDP!PE VALVES TO.:, 5000 PSI. ?c~--~ 'LY' COC?:_U !NSi 5000 PSi 'w'iTH KOOMEv ',~o, KEL '- AND DE BOP TO ....... -,~-r ORn .'-;':,T iNF ORMA Ti ON ,-,r,: .... ~c ............. ~:LOWOUT PREVENTER ~-r-ST ""'"' SEI'.iD TO DRiLLiNG RI .,~.. t '* L,/ -- -, PERFORM F'F)~Di ETI= 6OPE '"'~'--" ....... ~ ~,:.,~ ,.., .~E A WEEK AND FLII"ICT!C'NALLY OPERATE BO!:'E DAILY. JO NOVEMBER 21. 1986 STATE OF ALASKA OIL ~ CAS CONS'ERVATION iBiO.P.E~ Inspectic)n Report Mud Systems Trip Tank Gas Detectors R~serve ~t ....... ~. _. , Visual Audio BOPE Stack Annular P~eventer ~i, pe Ram~ ~Iin~ Rams Choke Linm Valves Kill Line Valve~ Chack Valve Te~t Pressure ........ o .5-c9.. D o ........ ,x~--~ o .__ ..... Test Results: l~ailures '- ACCUHULATOR SYSTEH ;Pull Charge Prerat~,~l~eLa.~'~dp__.(~ p~t~.._ Pump incr. clos. pres, 200 psig ........ Remot~ ~ B!ind~ switch __K_e~J~)i and Fi~or Safety~ Valves Upp e,r Keiiy~ ' ~ a,e,. t Pr~sm~re ~00 ........ i,o~ k~l,lZ ~ ' ~ ~ ......... Ball Adjustable Cl~okes~/' ~v d ra2a ic ~ l~p,~p e r a t e d choke~ Test Time ~'.hrs, Repair or Replacement of failed equipmen~ to be med~ within Commis~on office notified, orig. - c¢ - Oparator cc - Suparvisor In,~ p ect~' ........ ARCO Alaska, Inc. P.O. Box i.00J60 Anchorage, Alaska DATE: May ~3, t987 REFERENCE: ARCO Cased Hole Final J -28 · 4-22-87 2-8 4-J 3-87 3-9 4-i 0-87 .3-22 4-J 5-87 3-22 4-29-87 · 3-25 4-t 5-87 3:3-25 4-~ 6-87 4-~ 7 4-~ i-87 6-22 4-t9-.87 6-23 4-2O-87 9-4 4-22-87 9-6 4-3-87 9--,...cl 4-~ 6-87 t t '-t 4-2.0-87 ~ ~-~ 0 4-~'?-8'? t t-~ 5 4-~ 8-87 t3-2t 4-20-87 ~ 3-25 4-25-87 t 3-:32 4-t 9-87 ~ 4-2'0 4-.5-.87 t 4-35 4-6-87 t6-24 4-6-87 t8--2 - 4--t 2-87 t 8-8 4-22-87 F lowmeter/CCL Run Leak Def,/Temp/Flowmeter Run Leak De~, Run Fluid I,D,/GR/Temp j~rl F Lop, F',L, (CCL/GR/Temp) Run F lowmefer/GR Run Pump in Temp, S~rvey Run In j, F'rofi le Run F lop,P,L, (CCL/GR/Temp) Run F lop ~F',L, (CCL/GR/Temp) Run Collar Log (~e~ bridge plug) Run Collar & F'erf, Log Run ColLar Log(~e~ AVA &DW pack) Run Prod, Profile/Flow/Fluid I,D Run F lop,F', L., (CCL/GR/Temp) Run F lop, P. L, (CCL/GR/Temp) Run In j, F'rofi le/Flowme~er Run In j, F'rofi Le/FLowmefer Run In j, Profi Le/FLowmeker Run CH CNL Run CH CNL Run F Lop,F',L, (CCL/GR/Tem~) Run FLowme~er/Temp/FLuid Density Run FLowmefer/FLuid Den~ify Run F'Lease sign and/x~u~J~l~e./~Lkached copy as rece I,E ' Rosanne -Feek '¥RANZ ~87237 ...~ Approved DISTRIBUTION ipt of data. Ca mc o Ca.)c o Ca~o $ch e~~ -~-::~.~ ~ch Gear Gemr Gear C~ II1~ 0 ~ch ~c h 08 .lc 0 C 8 .)~ o Ca .)~ o Sch Sch Sch C 8 (.c o ~,, Central Fi Les Chevron D & M Ex tens i on Exp [ora f i on Exxon M~r~ thon Mob( k ~.- F'hi LLips F'B WeLl Fi les R & D A F-.'. C 0 A !. ~'..'~ s' t-,' a, I n c ~ P,.O~ Box I¢(~60 A'nchorage: A[a~.rka I ~., - -.., ''~ q'--. 4 '-- 6 -- 8 '7 M. a g .l-. a p e 4.~: '7~,.'-' 2 6 4 C ~.-~, , C N L. .?C h R. ece i red By .............................................................................. HAVE A NiCE DAY! F.'.o s' a r,.r~ e F:'e e I-:: ATO- 1 529F '"' :"" ""'" ;* I c', ..~. r"~ -': --) 4 (7., ~ ' ! i-'.. i"i C'-'. C:. 'ii' C) f .-'- i .-' A, ............ &:. -.! t"t !; I""' ! i_) V -.;.' L~ ...................... .:~.~ ........................................ ...... ,.... , F'.. .,. 'F.', t l"i- 'r 0 N .L) .L ':"' 'T ', T. .....u . Ala'~ka 0il & Gas Cons. Commis~on Anchorage ARCO A,..k=. ,.c. X Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 ~ Date: September 5, 1985 ~ 1 Reference: ARCO CH .Finals · ~6-3--~~ Spinner 8-22/23-85 Run 1 5" Spinner 8-21-85 1 5" 9-20 Spinner 8-22-85 1 5" 14-35 Epilog 5-11-85 1 5" 15-10 Temp log 8-28-85 1 5" Camco Camco Camco DA Camco RECEIVED Please s~~.c..~~. ign as c p o t . .>~_~ Received Pam Lambert ATO 1429C Trane 305 Chevren D&M Expl. Services Ext. Exploration Exxon Marathon Mob i 1 Phillips PB Well Files R&D Sohio State..~f Alaska Texaco ARCO Alaska. Inc. Post Office Box 100360 Anchorage. Alaska 99510 Teiepl~one 907 276 1215 Date' June 21', 1985 - ~ · Reference: ARCO Pressure Data 6-7/Static Gradient 4-28-85 Camco 9-6 "PBU 5-24/25-85 DA 12-25 9FO 5-22-85 Camco 14-35 I~BU 5- 31-85 Camco 14-35"Flowing Gradient 5-30/31-85 Camco 15-7.~ PBU 9-11-84 SS 15-7/PBU .9-11-84 SS 15-8 'iPBU: 2-29-84 - SS 15-8 -'?PBU 10-20-84 SS 15-8/PBU 10-20-84 SS 17-5 'PBU 5-29-85 Camco /'S - ign as receipt~ data,~ _../~CE I~E~D~ .~, ReCeived by Alaska Oil & Ga~ C~n~ CemmJssion Anchom~je pam Lambert ATO 1429C .Trans 176 · . . . · Chevron D&M Expl.. Services Ext.'Exploration Exxon Marathon Mobil Phillips PB Well Files [ & D Sohio State of Alaska Iexaco ARCO Alas~.s~. Inc. Post Othce Box 100360 : Anchorage. Alaska 99510 Telephone 907 276 1215 Date- June 18, 1985 REference: ARCO CH Finals 1-25 Spinner 6-7-85 Run 2 5" Camco .~14-35 Spinner 5-30/31-85 I 5" Camco 15-17 CCL/Spinner 6-6/7-85 i 5" Camco 18-3 Static Temp. 6-5-85 1 5" Camco 18-3 Dynamic Temp. 6- 3-85 i 5" Camco Please sign as receipt of data. Received by Pam Lambert ATO 1429C Trans 166 Chevron D & M Expl. Services . Ext. Exploration- Exxon Marathon Mobil Phillips PB Well Files R &-D Sohio State of Alaska Texaco ARCO Alaska. Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: June 11, 1985 Reference: ARCO CH Finals' ~'-/ ~ 1-18~ Collar Log ~- ~'2-13 . Neutron GR --3-9 ~// Neutron GR -- ~ 4-9__~/_ Gamma Ray ---..~ .... --6~--/-- CET ~6=1'0 / Neutron GR ~6-24 /. Neutron GR ~ 7-26 /'/Neutron GR ~12-21 ~Spinne r ~12-22~ Co,ar L~ ~12-22 / Spinner ~12-25 /Temp. Log · ~2-25 ~ Spinner -. 5-18-85 ~12-28 /Spinner -/ 5-17/18-85 ~ 12-29 / Spinner 5-16/17-85 ~14-15 / Neutron. GR ~ 5-11-85 ~14-35~Neutron GR ,/ 5-11-85 ~15-9 / CBL ~ 11-8-84 5-20-85 Run 1 5" Camco 5-12-85 i 5" DA 5-15-85 2 5" DA 5-17-85 i 5" DA 3-7-85 i 5" Sch 5-10-85 1 5" DA 5-18-85 I 5" DA 5-16-85 1 5" DA 5-15/16-85 I 5" Camco 5-20-85 i 5" Camco 5-21-85 1 5" Camco 5-22-85 1 5" Camco I 5" Camco 1 5" Camco I 5" Caxnco i 5" DA 1 5" DA i 5" Sch Please sign as reciept of data. Received by ./// / ~~~.~--'/~"'"~ Pam Lambert ATO 1429C Trans 148 Chevron .. D&M Expl.. Services Ext. Exploration Exxon- Marathon Y~bil ~hi-ll£ps PB ~ell Files R& D Sohio Scare e f &laska' ARCO Alaska, Inc. Prudhoe Bay ,_.,gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer May 2, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 14-35 Permit No. 83-142 Attached is the Subsequent Sundry Notice for work completed on the above-mentioned well. Very truly yours, D. F. S cheve DFS/JEB/dh Attachments cc: Sohio Petroleum File PI(DS 14-35)W1-3 RECEIVED MAY 0 7 1985 AlaSka Oil & ~3as Cons. Commission Anchorage ARCO Alaska, Inc. Is a Submldlary of AtlanllcRIchfleldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED W E L L::"~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well (surface) 313' FNL, 1218' FEL, Sec 9 T10N, R14E, UM (Producing Interval) 51' FNL, 217' FEL, Sec 9, T10N, R14E, UM (Total Depth) 65' FNL, 8' FEL, Sec 9, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 69' RKB 12. 6. Lease Designation and Serial No. ADL 28312 7. Permit No. 83-142 8. APl Number 50-- 029-21018 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 14-35 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or )ther Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate} Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) ~1~ Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 3-31-85. RU perforating unit and pressure tested equipment. RIH w/gun 9!, shot select-fire interval 9145-9155' MD (8SPF); pulled up and shot select-fire interval 9132-9142' MD (8SPF). Shut-in well, POOH, all shots fired. RIH w/gun-#2, shot select-fire interval 9114-9124' MD (4SPF); pulled up and shot select-fire interval 9095-9105' MD (4SPF). Shut-in well, POOH, all shots fired. RIH w/gun #3, shot interval 9072-9092' MD (4SPF). Shut-in well, POOH, all shots fired. Secured well, RD. Ref: BHCS 11-19-83 MAY 0 '? 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~¢r~ ~/~ Title Regional Engineer The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1430 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: May 2, 1985 Reference: ARCO Pressure Data ~~~-Static Gradient 4-3-85 16-4 Static Gradient 4-18-85 16-12 Static Gradient 3-11-85 17-7 Flowing Gradient 4--8-85 Camco Camco Camco Camco Please Received by sign as receipt Of data. .~xlasv. a Oi! & (3~s Cor~s. oommissioB .~.nchora9e Pam Lambert ATO 1429C Trans 087 Chevron D & M Expl. Services Ext. Exploration Exxon Marathon Mobil Mobil E & P Phillips PB Well Files R & D Sohio Sta~e of Alaska Texaco ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: Apr il 23, 1985 Reference: ARCO CH Finals 3-8w/ Perf Log 1-9-85 Run 1 6-5 w,~ Collar Log 1-12-85 1 6-11~ Collar/Perf 12-25-84 ll-12/TDT 3-20-85 12-23b/Spinner/Temp 4-8-85 12-25 JCol 12-26/Col 12-29j Col 17-10~ S/pi nner ~s ign as lar/Perf 12-7-84 lar/Perf 12-2-84 lar/Perf 12-10-84 lar/Per f 3-33~85 4-4-85 receipt of data. 5" Sch 5" Sc h 1 5" Sch 1 5" Sch 1 5" Camco 1 5" Sch 1 5" Sch 1 5" Sch 1 5" GO 1 5" GO Received by Pam Lambert ATO 1429C Trans 081 Chevron Mobil E & P D & M Phillips Expl. Services PB Well Files Ext. Exploration R & D Exxon Sohio Marathon ~-at e?-.~f Alaska M0bi 1 Texaco ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer April' 19, 1985 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS i-IA DS 7-17 DS 12-26 DS 13-11 DS 13-27 DS 13-28 DS 13-29 DS 13-33 DS 14-35 DS 18-6 Permit No. 83-130 Permit No. 82-200 Permit No. 84-14 Permit No. 81-76 Permit No. 83-67 Permit No. 83-60 Permit No. 83-43 Permit No. 82-106 Permit No. 83-142 Permit No. 82-122 Attached are revised completion reports which have been updated to include the date of initial production for the above-mentioned wells. Very truly yours, D. F. Scheve RECEIV['[D DFS/JEB/la Enclosures cc: SOHIO Alaska Petroleum Co. P1 (DS 1-iA) W4-3 P1 (DS 7-17)W4-3 PI(DS 12-26)W4-3 PI(DS 13-11)W4-3 P1 (DS 13-27)W4-3 Pi(DS 13-28)W4-3 Pi(DS 13-29)W4-3 Pi(DS 13-33)W4-3 PI(DS 14-35)W4-3 P1 (DS 18-6) W4-3 APR 2 1 85 Alaska 0il & t~s (;0,,o. ~,v,nmissi(i~t Anchorage ARCO Alaska, Inc. la a Subaldlary of AtlanllcRIchlleldCompany STATE OF ALASKA ALASK/: . ~. AND GAS CONSERVATION C~. ,/IISSlON _ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] --. ~. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-142 3. Address 8. APl Number . .P.O. Box 100360, Anchorage, AK 99510 50- 029-21018 4. Location of well at surface 9. Unit or Lease Name 313' FNL, 1218' FEL, Sec. 9, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 51' FNL, 217' FEL, Sec. 9, TiON, R14E, UM 1~-35 At Total Depth 1 1. Field and Pool 65' FNL, 8' FEL~ Sec. 9~ TION~ _ R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.} I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 69' RKB [ ADL 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 11/01/83 11/12/83 11/23/83 N/A feet MSL 1 17. TotaIDepth(MD+TVD) 18. Plug Back Depth (MD+-I-VD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 9500' MD, 9243' TVD . 9464' MD, 9210' .Ty-D YES ~ NO [] nipple @ 217~eetMD 1900' (Approx) 22. Ty. pe E, lectric or Other Logs Run DIL/SP/BHCS/GR~ LDT/CNL/GR/Cal, RFT, CBL, Gyroscopic Survey '~23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20:~ 9i. 5~ H-4U Surf 80' 30" Instld w/2050# Poleset ±3-3/8" 72.0# L-80 Surf 2675' 17-1/2" Cmtd w/1800 sxs Fondu & zOO sxs Permafrost C 9-~/8" 47.0# L-80 Surf 8820' 12-1/4" Cmtd w/500 sxs Class G & 300 sx Permafrost C 7" 29.0~ L-80 8513' 9500' 8-1/2" Cmtd w/334 sxs Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9072-9092' MD Perf'd on 3/31/85 5-1/2" 8543' 8441 9095-9105' MD w/4 spf 9114-9124' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9132-9142' MD TVD of perfs: DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL UJED 9145-9155' MD 8848-8924' N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO Perf'd 3/31185 TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 124-HOUR RATE I~ 28. CORE DATA ., Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ""' ~: 2" ~' Alasl~.a 0il & Cas O0;~s. C0n-~?,:¢o~o,~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29.' :' : '" ' :";:dEoI~OGi-~M~,RK~F~S ~:!-':-:-: .-:'.;'-.'t":". ::':':-.:':::-' ':'~' :'":":': ':~:oRMATibN'+;Ej~ ,. .... .. _ ... · NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 8954' 8739' N/A O/W Contact 9334' 9090' Base Sadlerochit 'Not Reached 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~~_~ ~~~ Regional Engineer ~//~/~f~ Signed Title Date · · INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Prudhoe Bay E,,gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer July 18, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 14-35 Permit No. 83-142 Attached is "Notice of Intention" Sundry Notice for work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments cc: Sohio Petroleum File PI(DS 14-35)W1-3 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany t ECEIVED JUL 4 j, i Alaska Oil & Gas Cons. Commission Anchorage .I STATE OF ALASKA- :-.. ALASKA L _ AND GAS CONSERVATION CC VllSSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLYI~ OTHER 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well (Surface) 313' FNL, 1218' FEL, Sec 9 T10N, R14E, UM (Producing Interval) 51' FNL, 217' FEL, Sec 9, T10N, R14E, UM (Total Depth) 65' FNL, 8' FEL, Sec 9, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 69' RKB 6. Lease Designation and Serial No. ADL 28312 7. Permit Nb. 83-142 8. APl Number 50- 029-21018 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 14-35 11. FieldandPool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate I~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each coml~letion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand of the Prudhoe Bay Unit. Upon perforating, the well will be flowed for cleanup. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 9072 - 9092' MD (20') 9095 - 9105' MD (10') 9114 - 9124' MD (10') 9132 - 9142' MD (10') 9145 - 9155' MD (10') Ref: BHCS 11/12/83 .qubseque2t W~k Reported RECEIVED JUL2 419 Alasl<a Oil & Gas Cons, Commissior Anchorage 14. I hereby/~rtify that th_,A foregoing is true and correct to the best of my knowledge. Signed Title The space below for Commission user' Conditions of Approval, if any: Approved by COMMISSIONER Ai~proved - R~turn r By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc>_.. Post Offic~ ~ 360 - Anchorage, ~,aska 99510 Telephone 907 277 5637 Febr.uary 24, 1984 Reference: Arco Cased Hole Finals D.S D.S .D.S D.S D.S 1-9 f 1-8-84 CPL/TDT-M w/listing D.S 5-12 11-9-83 CH CNL 6-3 11-14-83 CH CNL 7-2f- 1-3-84 CPL/TDT-M w/listing 9-4 11-13-83 CH CNL 12-12 9-9-83 ~9-14-83 9-9-83 9-9-83 9-28-83 ~9-16-83 D.S. 14-4 f 2-4-84 D.S. 14-35 Production Caliper Production Caliper HP Gradient Stops CET Caliper Presentation EPL CCL & perf Record CPL/TDT-M w/listing 11-19-83 CBL/VD 5" Sch Run 10 5" Sch Run 8 5" Sch 5" Sch Run 8 5" Sch Run 1 5" Sch Run 2 5" Sch Run 1 Sch Run 1 5" Sch Run 1 5" Sch 5" Sch 5" Sch Run 1 ' 5" Sch . sign and return the attached copy as receipt of data. HAVE A NICE DAY! Kelly McFarland ATO-1429F Trans. #' 073 Chevron D & M Dallas Dril!i~g Exxon Getty Marathon Mobil DISTRIBUTION North GeQlogy ~ Prudhoe ~ay ' ' ' ~ R & D :,.,, Caroline Smith Sohio State of Alaska ARCO Alaska, inc. Post Office,"-"~. 360 Anchorage.. _,ska 99510 Telephone 907 277 5637 February 14, 1984 Reference: Arco Open Hole Finals D.S. 14-35 11-13-83 11-12-83 11-12-83 11-13-83 11-13-83 11-13-83 11-13-83 11-13-83 CPL / Cyber look BHCS DIL/SFL LDT / CNL / Ge ( Raw ) LDT/CNL/GR (Poro) GR through 9 5/8" casing RFT RFT Quicklook Run 1 5" Sch Run 1 2" & 5" Run 1 2" & 5" Run 1 5" Run 1 5" Run 1 5" Run 1 Run 1 sign and return the attached ~opy as receipt of data. HAPPY VALENTINES DAY! Kelly McFarland ATO-1429F Trans. # 052 DISTRIBUTION Chev~ 01'1 D &M Dallas Drilling Exxon Ge try Marathon Mobil 5 3 ~_ti C.ar, ' .... STATE OF ALASKA ALASK~ _ ,LANDGAS CONSERVATION C. ..MISSION WELL COMPLETION OR RECOMPLETION RE ORT AND LOO 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-142 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21018 4. Location of well at surface ~. ..................... r 9. Unit or Lease Name i L,7~< 4 :-,"~.!..:'.-'.; Prudhoe Bay Unit 313' FNL, 1218' FEL, Sec.9, T10N, R14E, UM · At Top Producing Interval J e ~ 10. Well Number 51' FNL, 217' FEL, Sec 9, T10N, R14E, UM ~ .... 6 ~- ; 14-35 At Total Depth '~¢ '-~ ,' ......... 11. Field and Pool 65' FNL, 8' FEL, Sec. 9, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 69' RKBI ADL 28312 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore 116. No. of Completions 11/01/83 11/12/83 11/23/83J N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9500'MD,9243'TVD 9464'MD, 9210'TVD YES [X~ NO []'lNipple ~ 2175 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, LDT/CNL/GR/Cal, RFT, CBL, Gyroscopic Survey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Z0" ~J1.5# H-40 Surf 80' 30" Instld w/2050# Poleset 13-3/8" 72.0# L-80 Surf 2676' 17-1/2" Cmtd w/1800 sxs Fondu + 400 sxs PF "C" 9-5/8" 47.0# L-80 Surf 8820' 12-1/4" Cmtd w/500 sxs "G" crnt + 300 sxs PF "C" 7" 29.0# L-80 8513' 9500' 8-I/2" Cmtd w/334 sxs "G" cmt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NONE 5-1/2" 8543 ' 8441 ' ,- - 26. ACID, FRACTURE,CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Opera~ion (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED OIL~BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (co[r) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water· Submit core chips. None Form 10-407 Submit in duplicate Rev. 7-1-80 DRN/WC04 CONTINUED ON REVERSE SIDE 29. 30. · GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 8954' 8739' 0/W Contact 9334' 9090' Base Sadlerochit NOT RI ACHED NONE : i 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) --32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on 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". DS 14-35 DRILLING HISTORY NU 20" hydril & diverter system. Spudded well @ 2030 hrs, 11/01/83. Drld 17-1/2" hole to 2690'. Ran 66 jts 13-3/8" 72#/ft, w/FS @ 2676' Cmtd 13-3/8" csg w/1800 sxs Fondu + 400 sxs PF "C". ND 20" hydril & d'iverter system. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Held 11.3 ppg. Drld 12-1/4" hole to 8859'. Ran 218 jts 9-5/8" 47#, w/FS @ 8820'. Cmtd 9-5/8" csg w/500 sxs "G" cmt. Tstd csg to 3000 psi - ok. Drld FC & cmt. 'T'.s. td csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW'- ok. Held 11.8 ppg. Drld 8-1/2" hole to 9500' (11/12/83). Ran DIL/SP/BHCS/GR f/9504' - 8820. LDT/CNL/GR/Cal f/9504' - 8820'. Run RFT f/9450' - 8860' Arctic packed 9-5/8" x 13-3/8" annulus 300 sxs PF "C" + 135 bbl AP. Ra~ 25 jts 7" 29#/ft, ~513' - 9500'. Cmtd 7" lnr w/334 sxs "G" cmt. Drld cmt to 9464' (PBTD). Tstd lnr lap to 3000 psi.- ok. Displaced well to NaC1. Run CBL f/9455' - 8420'. Ran 5-1/2" completion assy w/tail @8543' & pkr @8441' & SSSV @ 2175'. Tested hanger and packoffs to 5000 psi - ok. NU tree & tstd to 5000 psi - ok. Displaced well to diesel. Dropped ball & set pkr. Secured well & released rig @ 0200 hrs, 11/20/83. DRN/DH46 -tw Eastman/ Whipstock A PETROLANE COMPANY REPORT of SUB-SURFACE DIREC TI ON,4 L SURVEY AR(~,O ALASKA, IN~, COMPANY D. S. I4, Well Number: 35 WELL NAME Prudhoe Bay, North Slope, Alaska LOCATION JOB NUMBER CDC A-1183-02 SURVEY BY A CHAPMAN TYPE OF SURVEY Directional Single Shot/GO M%TD ,~ il)(' L: i V ~ ~) ..... ' '"~ ALASKA DATE 02-NOV -83 F(EI:::OF<Ei OF Si..IRVEY RADII.I:_--: i':~F CI..IRV~TLIRE. METHOD · C;QI';1F'UT ~T Z ON F'A6E I-:DC ) T I PiE DA'rE .. ,[.) .*: 55: St{) 18-NOV-83 TRUE 'gEASLII~E::[~ DRIFT DRIFT COURSE VERTICAL VERTIC:AL c. LB.-.EA DEP"rH ANGI_E DIRECTION LENGTH DEPTH. :.-:.:ECTION ~TV.D.. C. 0 q .R.P I. N A T._.E !_~.: P;.'.S-TANE:E /~IREC:TION :SEVER FE. IE'f' D I'1 D FEEl' FEET FEET FEET FEET FEET D M DG/10' 0. 0 I') C) 0. 0, O0 O, ()0 .-69 ,. 0[.! C.), O0 0. O0 0. O0 i'i 0 0, 0;. · ":" ":'F. A 0 0 ,:-.,LT/. 2676, CiO Cl. Ac) 2607 OQ 0 O0 O, e'IO ('l O0 0 ¢i i'i. r~.' .g.,,.,... -- · . .&..,_,? _*# . . . m - . . m . ._. :3':-i'.6'?. ii 30 N 4A E 59:3. 3268.99 1.7:2 :3:1.'?:~'.."P9 1,98 N 1./'6 E 2.59 N 4A () E . ...., , ........ q,~ N ::3:=',~'.:.~ 0 45 N 48 14 5TC. '="='18,96 1.5! :374".-,'..9!_.-, 7 '-'* .... ?',.:'.:~' -' .~("~ N '-"~ .=;:2: E ,:1.:2:'7'.:.-.'. 1:30 N 7'2 N 5/,0. 4:37¢. 85 . -8.0/, 4309.85 12.24 N 8.4:3 4958. 55q 4.. 56/':3. 578'7, .5880. :=: 15 N 71 H 6 :..:.:('~ N 50 N 5 0 N 21 W 6 45 N ~! E 8 o 'N 60 E 604.1,, 1.1 "1.5 N 75 E . .:'::,19.'.'-.. 15 15 N 76 E 6:3 !=!ii) ,, 1 :"'-.': 45 N '76 E 65().q. :2::1 4.5 N 76 E: 6...'S5'7, 25 30 N 80 E ':).% . · ._,7 :. 4 :.._7. -3!, ............. · .:,.~ 02 4 888 33 18, 4[.4.. I"J.. ._,,:,6. ._,.:,4.1.1 ::~: -7:3. '-'t = '" · :,:, ._,~7~..!3 42 8:3 N 11'.-"). 5659 .... 124, ':,'"' ='-'--'= -6.9 R(] 5F_.:06.. ~, Q 72:, ~ '" .'...:, ...,,:,/~_,. ~ Q ~.~ N ~, ~ .~ ~:.,:.~.?~L~ ~' =- ~ 6:[ N ~-:" e '2.", ~ ~'": N' ;' -:: ~ ~. 59 W ~03.40. N ,'! 32 10 E :... t ~ {.-'ao' N 8.3,8 ~ E I' :2 ,~ ;'£ 4 ~ 14.;, ,, 76 E 31. = ~ I~1 3/-. 5:=: N .=;'P 4.:3 W ........ 7 z~. 6'.=,' .W ,:,/_-., (')g N 60 1 i') W :1.._,4 ~ 'P6.'Yt4 I'..i MT 16 W .............. , ...... .~.!:h~':. ~:~ N ._,1 ~:.:..: W 80. ~7 72.04 N 102.51 N 44 39 W 95.59 N 29 11 W 93.24 N 7 8 W 108.27 N 1'7 ]5 E lZ!.;3.,.:~:5,,. N 35 4.7 E 1'..~3. 18 N 48 5 E .:,::.:,.. 6.,71..:,..! 314,04 ..~.~02,3:3'. )5'---/ 7:':: .IxJ 2('~':,,.'"'"'-- '-' "" .... .:,..,, ~ .:,4,:,, 16, N 6.2 41 ..... , ........................ r .... '--' *" ~ . , "~. tt ' .................. ' '.~ . ~70 36, E 508 '-"--' ;~2,~...N ~ . . .,~,~ N /'7 4.~:';.... E z JT. 04 N ,_ 4 E .... ,.,. l 0 hi .-., ..:,~, E 74. .... /.-, N 7;1. :.?7 E ................ ~.a.~ .:/J.'Z, .N. ..... '705 '..-' - '=' """:' q,..,.,?~ 77,:,~,. lg'~'', 712 ="P '~';""~' "g '-":' :~:'-, N E N 74 E 6,.,::: -1 '"'"'=" "': ,.-,.-,-:: ...:,.'7 · ,=,.,,;:,,/.. "':,zl ¢,,, ,- o 926 13 '.:'."59 2.:5 54. .. ,:,..., o..,. 6,.2 .~..:, ..... .,.. ,-c.',.-.,., ,=, ,, 6:2 ~..., ..- . . - 0.3 O, 6. 2.7 4. :37' 4.1".' C). 1'" 0.4:! . . 0.7'" ARCO ALA.':3KA~ INC, DS 14, WELL NO: 3:5 SIGMA-GYRO ,JOB NO: A1183RO403-OZ PRUDHOE BAY, NORTH SLOPE, ALASKA ._.c'II]MA-.GYR~-~, .... 0-'.-}464 MD, SURVEYOR: .JAHN/CORAM, DATE R~IN: 2:3-NOV-83 ',':-.';IGMA :300 NO: 74.5, F'ROBE NO: 064 FORE'SIGHT: N 13 1S~ W 'SLIRVEY TAKEN FROM WELLHIEAD VERTICAL SECTION CALE:ULATED IN PLANE OF PROPOSAL DIRECTION: N ~ ~' . . ~.~:. BEG 16 MIN E RECORD OF S';URVEY RADIU:--; OF CURVATURE METHOD ARCO AI..ASKA, INC. DS 14, WELL NO: :35 :5;iGMA_.GYRO F:'RLIDI-JCIE BAY., NORTH '.E;LOF'E, ALASKA ,_lOB NO: A 118 :=:R 04C.):3-0 Z COMF'!JTAT I ON T I M E D A'I" I= 1:2:: 2:2:: 3/.,, O'P -,J A N.- 8 :,7.:: PAGE NO'. 1, TRUE MEA:SURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C: T A N O U L A R C L.. 0 S LI R E,'. DEF'TI-~ ANGLE DIRECTION L. ENGTH DEPTH '.E;ECTION TVD C 0 0 R D I N A T E '.3 DISTANCE DIRECTIOI',I ::;EVERI'I-'. FEET D M D M FEET F'EET FEE'[' FEET FEET FEET D M DG/100F:" lC)0 0 14 S 15 =/' 0 c')6 E 0 2c') S 15 ~/-, E c'~ '-"-' ..... ,.:, E 1 c:)0 100 ¢)0 0. c').-'=i :2:1 00 CD 2c:) '=' 200 c') 17 S 1:3 .~i'-' .... J E 1 C)0. 200.00 0 .1 .., '= 1:31.00 0./-",4 :":~ 0, 1. 7 E 0 :}.':00 0 17 '.:, 1 ":' ._,7 E 1 ¢)c') 300.00 0. '""~ ..... '1, ¢)0 1 11 '.:, 0 . .,' ._.,~ ,_, ..... ~,:, 1.--, 45 E 0 400 0 1/. '.3 18:34 E lr~0. 400 0c) 0 42 .::.::1 0c] I .-,:, :3 c) 4.7 E i 65 S .1../:, :::9 E 0, 00 500. 0 15 ,.E; 18 2 E 100.. 500,00 0.55 4:2:1.00 2.00 S 0.61 E 2,0'.:.~ S 17 0 E 0.0:2: 600. 0 ? S 55 41 E 100. 57'.T~. ?:T~ 0.76 5:1E:0,~'.'.'~ 2, 2? ~S C).83 E 2.4:3 S 17 52 E 0, 1/=:, 700, 0 12 S 56 46 E 100, 67'.'-Y..'FY'.r.'~ 1.01 630.?$.'~ 2.46 S 1.08 E 2.6.'F.~ ::; 2.3 46 E 0.04 800. c) '~ S 46 55 E 100. 7'?'P.'P'P 1.25 73c),?? 2.66 S 1. :3:3 E 2.77 S 26:3:3 E 0.c)5 ~00. 0 10 S 43 ? E 100. 8'.:.~'.:.~.?? 1.46 830.?? 2.6:7 S 1.55 E 3.26 '.:: 28 17 E 0,02 1000. 0 10:3 2 57 W l c)O. '.~'.T~?. 'F~9 1.. 55 9o0,'-" ~'~ '-.J. 14 ~ . ' . , . - _ -- ~, ,_ 110C). C) 15 S 26 ._4 W 100. 10?fY ?YY'Y 1 44 1'0~:0 ?ySY ~: 51 S 1 M~; E .::.,:,4 S 2:3 48 E C). 1'-~ ~' .. . 25 1200 0 16 ~' 7 ._.3 W 100 1199.99 1 '-'" - .... . ..... ~,8 11:30.99 . 1 :-~'~'~ 0 z~""-' S 12 7 W 100: 12 ? ?. ~ ? I. 16 1230.9'~; 4.54 S . 1.30 E 4.72 ~'~, 16 I E 0 .0'? 1400. 0 2:3 :B 4 27 W 100 . 1 .=, ~'~; o.,.. 9. 9. 1.05 1 ~ 30.9'~ 5. 1 'F~ S 1. c,~ 1 E 5.33 S 1:3 ~ ..... E 0. ~'~F-, 150C) () ":"=' '=' , .... 15:34 E 100. 14 ? ? 9.'=: I 09 14 :=:c') 9::: .s ':'5 ¢' ..........- _.. ,: ...... 1.27 E 5._.99. . c:.._, 12 16, E 0.14 1/_-.cz)o. 0 14:3 45 2c) E 100. 157'.-.-~. '.-.-~8 1. '35' 15:.:.:0. '.-.-~:_:: 6. :31 S 1.54 E 6.50 '.3 1:2:44 E 0. '- ' 1700. . ('). 18 '.E; 71 20 E 100. 16?? .9:--:. _ 1 .75 1630 . .~:E: 6.56 ,.E: I .9.~. _ E 6. ,=: ~' S._ 'S 16 32 E 0. ~ 1:E:00. 0 1'~ :3 7C1) :35 E 1()0. 1777.78 2.2'.T~ 17:30.'F~8 6.75 S 2, 4? E '7.2c1) S 2(') 17 Er 0.02 1 ?c)(')... 0 17 ::: 53 4 E 100 . 18'Fy? . '.T~8 2 .7/_-. 1830 .9:-:. _ 7 ,01 S 2 . ?:i: E 7 .62 ...c- 2:3 i E F).. 1C)_ 200c). 0 20 S 71 48 E 100. 1777.78 3.24 1'.T~30.?:3 7.26 S 3.46 E 8.04 S 25 28 E 0. 12 2100. 0 24 S 54 54 E 100. 20??.?8 3.82 2030.?8 7.56 S 4.05 E 8.'57 S 28 11 E 0. 1:2: 22c)c). 0 24 S 37 12 E 100. 21'.=.~S~.77 4.31 213c)..97 8,05 S 4.56 E 9.25 S 2? :32 E 0. 12 2300. 0 28 S 35 33 E 100. 2277.?~7 4.7/_-. 2230.97 8.67 S 5.02 E 10.02 :E; :30 ::: E 0.07 2400. 0:32 S 53 5? E 100. 237'.-.'). ?7 5.35 23:30.':77 ?. 30:3 5.64 E lc). 87 S :31 14 E 0. 1:.:.'.': 2500. 0 38 S 52 28 E 100. 24'.:~?,76 6.17 2430.?6 9. ?2 S 6.47 E 11.85 S :::3 7 E 0.10 2600. 0 33 S 48 0 E 100. 25??. ?6 6.~5 2530. ?6 10.5'..:~ S 7.27 E 12.85 S 34 2'.~ E 0. 10 2700. 0 21 N 77 5:4 E 100. 26.'FY?.75 7.6? 2/_',30.'~5 10.79 S 8.02 E 13.44 '.3 :::6 :E::E: .E 0.45 2800. 0 26 N 66 43 E 100. 27~'~.'.-.-~5 8.37 273c). ?5 lc).57 S 8.7c) E 13.6'~ S 3? 2:3 E 0. 11 2?00. 0 32 N 56 36 E 100. 287'.--.~.75 ?. 15 2830.?5 10.16 S .'F~.46 E 13.6:8 S 42 58 E 0. 13 ARCO ALASKA, INC. DS 14.,, WELL NO:._,.=,~._ ._,c.i GMA-GYRO F'RLIDHOE BAY~ NORTH SLOPE, ALASKA ,_lOB NO: A 118:=:RC)403-OZ COMPUTPIT I T I ME DATE .1.._'-4: .,:.":' ..~,'=': :'::/-, .... (') '-.".,' - .J A I',.I -,=, ..--', / F'AGE NO. ' 2 TRUE: Ir i~o ~ ........... MEASURED DF:IFT DRIFT C:CIIJR'._;E VERTICAl,_ VERTI _.AL 'SLIB',E;EA R E ~z: T A N F~ LI L A R E: L 0 '._=; II R E Dr'u~l E:F.; FiEF'TH ANGLE DIRECTION LENGTH DEF'TH F.;ECTION TVD F: 0 0 R D I N A T E S FiISTAIqC':E DIRECTION SEVERIT' FEET D M D M FEET FEET F:'EET FEET F'EET FEET D M JIG/10C)F"' 2:C) 0C). 0:39 N 4:3 46 E 1C) 0. 2999.94 1C).C)C) 2:9:=:C).94 9.5:2 '.-5 1C).2:9 E 14.02 'S 47 14 E C). 14 · :: 1 C) 0 C) ':"=' N 2 6 1 I E 1 C) C) '::¢)¢,,9 ~ ~' '- · .., ........... :7.:: 1 C)./=,/=, :::(') :::("). 9 :::. ':',_,./=, 9 .S 1 C) . -9, :::.. E 1 ._3.9 ~, S 51 :31 E C).. ';::. 6 :32C)C). 0 27 N 48 4 E 1 CJC). :3199 9:3 11~-.-'-'-'"' .'=: 1 :::c) '.=,,::: 7 99 '.S i i 46 E 1 '~ 9'7 :=; ._.~'.:, .... :::: E C) '":' ' , . n ' - # '-! · ~k N - # [~ , , i, · d:, 3:3C~0 ....., Cj -:.,o.., ~. N 42 .~,/~,_ - E 100 , q'~'¢~':~._ ,=....., ':/~:.. 11 , :E:/=, .:,'-'~.=,']t ,9.'::. _ 7 , 37 S ! ~'-' ..... (")'F~ E 14 , 1/.:, S ._Pie",_, :=:9 E 0 ~ . :34C)C). C) 24 Iq 29:3(.") E I(")C). :=::'::9'.-.-~.':';'2 12.:38 3:3:']:0. 92 /=,.70 :=: 12.5'.-.? E 14.2/=, S /=,1 59 E C).17 ~,: ...... , .-, ..~ 17 /=,C) .:,4.:,( /=, 0:3 c. 12.7'.'.-'~ E 14.14. :-7; 644.5 E ("). 17 · :,._,(.)(.) 0 Z.:, N 5 1 :':: E 10(') o4 ::,' ?.,'. ¢/2 .... ) ¢/2 i , .. d.. n # . # :3 /=, (') (') C) '-"- N 1851 W 1 C) C) :3599 ': o ~= ~'..' /... 12...., :~:::(') 92 .~ :37 F.; 1° '71 E 1'-' 8C) S /=,7 F C) 16 . .n · · # ~ .... · . # " ,, '.-". . n :=: 7 C)(') C) ';..'C) c.78 '-'"' ~:/,=, c; /=,,..-.~ · _, oo E 10C) ':'/-¢~¢~ 92 1290 :363(:) 92 4 ~' 1.=". C)/=, E 1" 9::: ........... _-, ._ '.E: 7 E C)./=,2 · .... i I m '- i .. ~ :3:s:c)c). C) 1/=, N 3(.") 4 W 10C). :3799.92 131/=, :'-',7:=:(') 92 46:3 S 1:_:: .::1 E 14 C)9 S 7(I) 49 E ('~ .:.,.::, .'"'l ,'--, .~', ' .'=; '=.~ C) (') . ...... (') 4(") S 81 7 W lC)0 . :3899 .91 12 .47 ..-,,:,.:,(.) .91 4 . :'::0_ '.Et 12: ./=.1 E 1~... 2:2 ..,¢' 71 11 E.:. C)./=,3 4(')C)C)_ . C) 44 N 7441 W 10C). 3999. 907 . 11 .26 3930.90 4.23 S 11 . ~:'-.-~.. E 1"".,. 15 S /.:,'~ ...... .':,o E C). :3C) 4-10C). 1 2 N ~"-' " 5 c,.z, 44 W 100. 4C)99 89 9 '74 '4C)..~0 89 3 94 . . :, 9 87 E 10./-'7' c. 68 I E C) :3:3 ~ : ~' 6 A6 [ 6.93 S 62 ~ E 0 14 -- - n ,- u n u .-, n . . 44(:)(:). 1 27 N 80_ 39 ....... W lC)C). 4.3::~2. ~::: :3.71 43:30.83 _?. 9C)S ,_,. :~ ,~ :::9_. E c).. :3C). 450C). 144 N 8252 W 100. 4499.79 0,96 4430.79 2.50 S 1.04 E 2.71 L:; 2232 E 0.30 46(:)0. 2 33 N 80 25 W 100. 45'F/9.72 -2.73 45:30.72 1.96 ,.E; 2.68 W :3.32 S 5:':: 49 W 0.'"' 4700. 2 47 N 76 5 W 100. 4699./=,1 -7.27 4630.61 1.C) 1 S 7.24 W 7.31 S :32 4 W 0.. 4800. 2 43 N 79 19 W 100. 4'7'79.49 -11.94 4730.49 0.02 N 11.94 W 11.94 Iq 89 56 W 0. 17 4'.=/C)C). 3 6 N 77 C) W 100. 4:39':-7. 36 - 16.8'? 4830.36 1.0/=, N 16.9:3 W 16.96 N :E:/=, 25 W 0.40 5C)C)C). 3 38 N 72:32 W lC)C). 4:5':29.19 -22.51 49:30. 19 2./=,C) N 22.6C) W 22.75 N :=::=: 26 W 0.59 51c)c)__. 4 lC)_ N 7(:) 15 W 100. .~¢)':~:R_..._.96 -2'::.9¢)% . _ ~OC, C~._ _...96 4.78 N _.?c~.06 W 29..45 N F:O_ 40 W c)..57 5'200. 4:34 N 69 29 W 1C)0. 519:3.67 -35.99 5129.67 7.41 N :36.23. W :36.98 N 7:3 27 W C). 4(]) 5:::c)c).___ 4 59 N 78 30 W 100. 5298.32 -4c..92~ ~..5o.:,c~.32 9:7c) ...... N 44 24 W 45 ?9 N 77 .-,o:,,:, W C).:::6_ - ~ 67 5'-'--"-' 90 9/- ..... 77 ~4o~'~. :, 27 N 72 q7 N loo ~397 9A -._2 11 N 5:3.(')A H ~4 :::9 70 ............. ~,: ...... N 1:3 N 0.,_ ~,.~,(')o. /=, 17 N .~.~._._ 2:-=: W 1C)0. 5497..q'='._,_, -61.71 5428.38 16.42 N /=,2.23 W /=,4.3/=, N 751:2: W 1. ,?.~1. _ .5/=,C)C). .=,_ 5:3 N 47 19. W lC)C) . 5596 . :3(-). -/-,9_.. :q:=:_ _ 5527 .8('). '-":'..._,. (-):~. _ N 70 . .5/:_ W 74 .24 N 71 5:::_ Wc).. 9:.?. _ .'=;7c)(') 5 43 N 45 12 W 'lC)C) .~, /-, '=.M, 28 -76 ';'::: 5627 --,o .... ................ ... ,.., .~c). 12 N 77.9:3 W 8:=:. 54 N /-.8 .'=.2 W C). :32 '~'-" ' - q"" C):':-: N 6:=: - .... :,(.)(.) ........ A :::5 N :=::~ 48 E lC)C) 57'75 7(:) -77 '.-'..'-4_ .._5 -"-' /'/ .' =, .... 7(.") :::9 9C) hi 7:=:. 47 W ,_,: ......... :E: W :=:. ':'/- 59(')C) :E: 5,:_--: N /=,4 51 E 1(')C). 5894 85 -66 '=-":' 5825 85 47 '-'"" N 6:E: -'2_':.1. W 8:2:.42 N P;'q' .:;,:E: W :2:.:_:0 · . . k d.. . · ,, *_,._, · · ,_--~,.-.i · -- ARCO AI_ASI<A., I NC. ]...:, 14 -, WELL. NO:....,'":'.':;,._ '"'.:, I C. iMA-GYIRCI PIRUDHOE BAY, NORTH SLL]F'E, ALASKA ,_lOB NO: PI1183RO40:=:-CIZ CCIMF'U"I'PI'F I ON T I ME [ipi]"E 1:3: 2 ::ii:: :':: 6 0'.:.>-.._1 Pi N .- :ii.:: :'::: I='AGE NO', :3,. TRUE MEASURErf DRIFT DRIFT COURSE VERTICAl_ VERTICAL .SLtBSEPI R E C T A hi G U L. pi R C L fei ":':; U R E f'fOGL--EG DEF'TH ANGLE DIRECTION LEI'lOTH DEPTH SEC"I'I(]N TVD C 0 0 R If I N A T E S DISTANCE DIREC"I"IOI"I SEVERI'I"' FEET D M D I'1 FEET FEET FEET FEET FEET FEET B M BG/ 100F" ' . '--"-- 5' 592:4 :=:'? . C) 5 '--;''--' 5'--' ":; '-- . /:'0(')C). 1 I ::: N 72 26 E 10(:D. 5 'P 'P :3 , ':' :'~--'--0.87 . 54 N ...... '" W 7'--·:37 N 44 11 W .::, /:. 100 1 :=: 4 N 7 :=: '-' '=' E 100 /:,091 1/:, --.5:0 /:,:3 .:,.=, /. o .:,,:, .:,,=_, · :,.., ........ /-,022.1/:, /:,c')18 N .... 47 W ......... ,_, N 21 W 1 , 'F.,'4 6'2c) 0 1::; :34 N 74 I E 100. 61:3:=: 04 -6 /" , . .. -. ...... :,,=: 6119 04 /-..,7 cD7 N ::: 71 14 67./!,4 N 7 24 14 2.5" /:.,:300 17 44 N 7:=: '=,1 E 100 /:,26.::3. 84 21 09 /i-,214 84 75 (')1 N 1:=: o.:, F 77 3:=:' hi 14 6 E 2 1. ' ' '-. . · . . . . N 1_1 ,.., a mi. .-, 64. o 0 19 44 N 73 37 E i c~ ('D. 6.=, 7,_-, ~:l '~' 5 :.2 2 c~ A 2 C)'-=, ~'- _ .... , ............ .... _.., -;.t 6.: 4. c)(') N 49 .6 ::: E 9'?. 5'.:::' hi 3 (')2,/:, IF' .,::.. CD I 650(:) 2:1 ._ 7 N 74 E 100 6471 9,':::: ¢ '-, ~ '-' "",'-, · :,.- 71 /:,4 .D ... ~/,:, 75 N 9 ..... o.:, 1 E 1..._ ::2:1 N-'1.1 ~';¢)E 2. ""'-' /:./..0C). 24 18 N 77 4 E 100. 656:3,'?:3 125.C)/.-, 64'F, 4.9:3 1CD3.::-:/:, N 121,'F/9 E 159.:37~ N 49 44 E '2..56 /:,70¢D, 2/:, 41 N 78 3 E 100 /:,/-,54 18 1/-..,7.36 ,4 .=;~'"'; - .............:: .... : ..... 18 112.63 N 1/:,4.03 E 198. ':'-/':' N ':; ='"-, .:,.4 .... E 2: .41 6::2:00 ..... 2/:, 44 N 78:34 E 100. 6743, 51 211.64 6674.51 12:1.73 N 2 C) 8 06 E 241 ,, 05 N ''=''-..-' 40 E 0. '2 ::ii: · , - .-:,.~.~ .-,~ .-:, ..,=,.=, ,4.,9C)C) ...... . ~'.'".~.- .~5._ ._ N 7::: 9. E 100 . /',::::."::3 .... . 1::: .,:. ..... :_::4 /:,7/:,4 ,1:3 1:30 ·/:,6.: N ~: .... 1 , .51. E .~. ~,._,. 4:':: N /:.2": :':::3 E (').. 6.:3 70c)0. 25 37 N 77 51 E 100. 6923.18 298.13 6854, 18 139.72 N 294.c)4 E 325.55 N 64:35 E 0.:=:4 7100. 24 51 N 77 23 E 100. 701:3.64 340.04 '6944.64 148.86 N 335./:.'.=.~ E 367.22 N /:,/=. 5 E: 0.78 720c). 24 8 N 76 4'.T~ E 100. 7104.6:3 380,73 7035.63 158.11 N ~76.12 E 408.0cD N /:,7 12 E 0.77 7300. 2:3 28 N 76 44 E 100. 71,96.!2 420.28 7127.12 167.34 N 415.41 E 447.8.=; N 68 4 El 0./:.7 7400. 22 43 N 75 40 E 100. 7288.11 458.65 7219.11 176.69 N 453.51 E 4:36.72 N 6:3 43 E 0.6.:5 7~0C) ........................ ':'1 ':'.=; N 75 .'=;c) E 10C). 7:3:=:C) 72 4=95 47 7311 72 I:E:~ '--./,'=: N 49(] CD7 E ~'-'.'4. 17 N /:.'F.; 1:2: E 1 , 14 7/:,c') 0. 21 14 N 7/:. 4 E 100. 747:2:. :=.: 1 5:31.15 7404. :_-31 194. :=: 4 N 5'25.49 E 560.4. 5 N /:. 9 39 E 0. :':' ' 7700. 20 .=_;,cE) N 7/:. 40 E 1()0. 7567. 14 566.26.: 74.98.14 20:2:.:30 N 5/:,0.'.':::3 E 5'.-.--'6.12 N 70 4 [E (') ' ' 7:_::00. :2C) 44 N 77 2:3 E 10C). 7/_".6C~. 6.4 /_-,01.0'.~ 75'? 1.64 21 1.24, N 594. '.-.-'7 E 631. :2:6, N 70 27 E 0.2'7 '7':.~c~¢'~ ......... 2¢D ::2: N 77 48 E 10(]. 7754. :2:4 6.:35.41 7/-..,6666:5.34 ':'18.76, N .4.,'-.,':.>. (D.:.]'-' E 6./-.6...¢)3 N 70 5c'). E c)../-,1 800C). 19 56 N 78 4 E 100. 7848.28 669.13 7'779.28 225.92 N 662.60 E 700.05 N 71 1C) E 0. :2:2 6.:100. 1'.'} 3$/ N 78 38 E 100. 7942.37 702.49 7873.37 232.7/_-. N /:.'?~5.77 E 7:3:.::.67 N 71 30 E 0.:34 8200. 1'? 27 N 79 21 E 100. 8036.60 735.5:3 7967.60 2:39.15 N 728.62 E 766.8'7 N 71 5c) E 0.:32 :.=.:300. 1'.-} 36 N 80 28 E 100. 6.:130.85 766.:.60 6666:061.6666:5 245.01 N 761.5:3 E 7'F/'F.~.96.: N 72 10 E 0.41 :_:400. 20 6 N 80 20 E 100. 8224.'?0 802.25 8155. 'FrO 250.67 N 7'75.03 E 8:3:3./-...1 N 72:3c) E 0.51. :E:500. 20 2:7 N 6.:2 41 E 1C)O. 8316.:./:,5 6.:3/-..81 8249.65 255.81 N 829.45 E 868.00 N 72 52 E 0.96 8600. 21 4:3 N 84 25 E 100. 8411.90 872.80 8342.90 259.86 N 865.:33 E '.'.-~0:3.51 N 73 17 E 1.27 :E:700. 2:2 20 N 87 I E 100. 8504./:,0 'F/10.27 84:35./:.0 262.65 N '.-7~02.73 E :7¢4C). 17 N 7:3 4.7 E 1. 15 88c)0. 22 44 8 89 42 E 100. :3596.96 948.59 6666:527. ?'6 263.55 N '..~41.05 E 977.2/:. N 74 21 E 1. :3.1. 6.:'F.¢00. 23 1C) 6.; 6666:7 29 E 100. 866.:?·04 787.53 8620.04 262·60 N 980.04 E 1014.61 N 75 0 E 0.97 ARCO ALASKA· INC. D'.S 14~ WELL NEE: 35 :--:IGMA-GYRO PRUDHOE BAY~ NORTH SLOPE, ALASKA d 0 B N 0: A 118:2:R 0403- 0 Z COMPU'T'A'T' 101',1 · · 'T'I MF' DATE] 1 :=:: 2:3: ::'=': 6 0'.--.~ - ,J A N -8 F::'AC.~E NO .' 4 TRUE MEA'.E:I..IRED [)RIFT DRIFT COURSE VERTICAl_ VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R El DOGLE(]; DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI'/''~ FEET D M D M FEET FEEET FEE]; FEET FEET FEET ' D M DG/100F:" '?0C)0. 22 38 S 87 35 E ~.~100. ;.22 46 S 86 57 E 9200. 22 25 :-': 86 32 E '?..:' 300. 22 19 ::.; o ..... ,,:, E 9400. 2;-2 27 S 85 8 E 100. 8781.15 1026.35 8'712.1.5 .260.93 N 1018.92 E 1051.80 N 75:38 E 100. 8873.41 1064.83 :=:804.41 259.10 N 1057.47 E 1£):7.:8.75 N 76 14 E 100. 8765.73 1103.11 88'F~6.73 256.92 N 1075.:=:4 E 1125.55 N 76 48 E 100. 9058.20 1141.00 :_q?~8~.~.20 254.44 N 113:3.82 E 1162.02 N 77 21 E 100. 9150.66 1178.88 '.~081.66 25 .1.. 48 N 1171.81 E 1198.4'~ N 77 5:} E F'RO,JECTEI) TO F'BTD ?.)4./:,4 '='":' 27 S '-'= ~"E 64 92C)'."./ ~ 90':-: -' ::,,:, o._, ,:, r_~l I 15 c.~140 '"1 249 41 N 1196 1/=, E 1221 '"'-' N 78 13 E 0 ¢')':.:' PRO,JECTED TED TD 9500. 22 27 S 85 8 E 36. 9243.08 1216.81 9174.08 248.24. N 1209.86 E 1235.06 N 78 24 E C). ()() FINAL CLOSURE - DIRECTION: DISTANCE: N 78 DEGS 24 M!NS 17 $EC$ E 1235.06 FEET ARco ALA:E;KA, INC. I' ' ':-'~ ~' I):3 14.~ WELL N.i. IGMA-GYRFI ._lOB NO A11~::::R¢)4c):--:-FiZ F'RLII:)HOE BAY, NORTH '.3LOPE{, AL.A~;KA '~'1 I TM - '' ' '-"-' f' """-' -'::'IQiMA-GYRF~.,..., .. _ £)-94/.:.4. M£1, .:._RVEYUR. ._IAHN/F:ORAM, DATE RUN: ..' .:. - N _i V - .:. .:, '._--;II"~MA :'::00 NF~: 745, F'RO}BE NO: 064 FOF(E'.E;IGNT: N 13 1.':/ W SURVEY TAI<EN FROM WELLHEAD REC:ORD OF INTERPOLATED SURVEY ARCO ALA'.-_-.;KA, I NC. D'.--: 14~ WELL NO: 35 SI6MA-GYRO PRUDHOE BAY~ NORTH SLOPE~ ALASKA dOB NO: AllSBR()40'3-OZ COMPUTAT I ON T I ME DATE 13: 25: 32 O?-JAN-83 PAGE NO'. l, MARKER CODE NAME TRUE SUBSEA MEASURED VERTI. CAL MD-TVD VERTICAL R E C T A N O U L A R C L 0 S U R E VERTICAL I DEPTN DEPTH DIFF [EPTH C 0 0 R D I N A T E S DISTANCE DIRECTION THICI<NESS FEET FEET FEET FEET FEET FEET D M TOP SAG RIVER TOP SHUBLIK TOP SADLEROCHIT 'FOP ZONE 3 TOP ZONE 2 8842.00 8635.63 206.4 8566.63 8872.00 8663.26 208.7 8594.26 8954.00 8738.78 215.2 866'~.78 9190.00 8956.50 233.5 8887.50 9266.00 ~026,76 239.2 8957.76 263.15 N ~57.42 E 262.86 N 969.12 E 261.70 N 1001.04 E 257.14 N 1092.00 E 255.28 N 1120.91E '.*.*",'.'F-.-'2,:~:3 N 74 38 E 1004.,14 N 74 49' E I034.68 N 75 21 E: 1121.87 N 76 45 E" 114'.:i'.'. 61 N 77 10 E"' O/W CONTACT 9334.00 ~089.63 244.4 9020,63 253.43 N 1146.74 E: 1174.41 N 77 32 E ) Suggested form to be inserted in each "Active" well folder to d~eck for timely compliance with our regulations. · ' Ope-rater, weli-Nan~' and Number . Reports and Materials to be received by: /~ '~ Date Required Date Received Remarks - · Ccmpletion Report Yes ,Well ...... HistorY .Yes _3 , ,. ' ,4/d- Pi ,. Core. Chips' ~.,- ..- -.._~ · Core Description ' /~ ~__, ~-' · 0 K Registered Survey Plat 'y.~..,~, ~_ ~ ~'_~ ~ ~(~. m, · , , :Inclination Survey ,-.- Directional Survey '' Drill St6m Test Reports /~/~ , . Prod~CtiOn Test Reports Logs Run · . Yes DigitizedData. /2.-' 2~FJ ii , , , , , ARCO Alaska, Inc. Post Office , 360 .~:;choraoe. ~, _.;.'. ~ 9~510 Te,eDnone 907 277 5E.37 December 19, 1983 Re fe rence· Arco Directional Data D.S. 3-25'~/ 12-6-83 D.S. 4-20'~ 8-17-83 D.S. 14-27 '/ 12-12-83 m.s. m.s. 14-34 ~' 10-26-83 14-35*'~ 11-2-83 Single Shot Magnetic Survey Single Shot/GO MWD Single Shot Single Shot/GO MWD EW Teleco EW EW EW Pl~~ease sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 674 Chevron D & M Dallas Drilling Exxcn Getty Marathon :,~cbil DISTRIBUTION North Geology Phillips ~ ~_- j~ ,,..... Prudhoe Bay ,~&~O~ : ~ ~--~ -¢" 'k~ ,- ~'''/ ~~-- . . / Sohio " State o~ AlasAa STATE OF ALASKA - ALASKA ~ _AND GAS CONSERVATION CC' -VIISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION5/ · Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-142 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21018 9. Unit or Lease Name Prudhoe Bay Unit 4. Location of Well atsurface 313' FNL,1218' FEL, Sec.9, T10N, R14E, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 69 ' 6. Lease Designation and Serial No. ADL 2831 2 For the Month of November , 1983 10. Well No. 14-35 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Field 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well (~ 2030 hrs, 11/01/83. Drld 17-1/2" hole to 2690'. Ran, cmted & tested 13-3/8" csg w/F5 ~ 2676'. Drld 12-1/4" hole to 8859'. Ran, cmted & tested 9-5/8" csg w/FS @ 8820'. Drld 8-1/2" hole to 9500'. OH logs. Arctic Packed 9-5/8" x 13-3/8" annulus. Ran, cmtd & tsted 7" lnr. Ran CBL. Ran 5-1/2" compl, assy. Secured well & RR @ 0200 hfs, 11/20/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40 weld conductor set ~ 80'. Instd w/2050# Poleset. 13-3/8", 72#/ft, L-80 BTC csg w/FS ~ 2676'. Cmtd w/1800 sxs Fondu + 400 sxs PF "C". 9-5/8", 47#/ft, L-80 BTC csg w/FS ~8820'. Cmtd w/500 sxs "G" cmt + 300 sxs PF "C". 7", 29#/ft, L-80 BTC csg f/8513' - 9500'. Cmtd w/334 sxs "G" cmt. SEE DRILLING HISTORY 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/SP/BHCS/GR f/9504' - 8820'. LDT/CNL/GR/Cal f/9504' - 8820', GR to 2600'. RFT f/9450' - 8860'. CBL f/9455' - 8420'. 16. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~,- --,- TITLE DATE NOTE form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil ~'d Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DRN/MR52 Submit in duplicate DS 14-35 DRILLING HISTORY NU 20" hydril & diverter system. Spudded well @ 2030 hrs, 11/01/83. Drld 17-1/2" hole to 2690'. Ran 66 jts 13-3/8" 72#/ft, w/FS @ 2676' Cmtd 13-3/8" csg w/1800 sxs Fondu + 400 sxs PF "C". ND 20" hydril & ~iverter system. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Held 11.3 ppg. Drld 12-1/4" hole to 8859!. Ran 218 jts 9-5/8" 47#, w/FS @ 8820'.. Cmtd 9-5/8" csg w/500 sxs "G" cmt. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Held 11.8 ppg. Drld 8-1/2" hole to 9500' (11/12/83). Ran DIL/SP/BHCS/GR f/9504' - 8820. LDT/CNL/GR/Cal f/9504' - 8820'. Run RFT f/9450' - 8860'. Arctic packed 9-5/8" x 13-3/8" annulus 300 sxs PF "C" + 135 bbl AP. Ran 25 jts 7" 29#/ft, ~513' - 9500'. Cmtd 7" lnr w/334 sxs "G" cmt. Drld cmt to 9464' (PBTD). Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Run CBL f/9455' - 8420'. Ran 5-1/2" completion assy w/tail @8543' & pkr @8441' & SSSV @ 2175'. Tested hanger and packoffs to 5000 psi - ok. NU tree & tstd to 5000 psi - ok. Displaced well to diesel. Dropped ball & set pkr. Secured well & released rig @ 0200 hrs, 11/20/83. DRN/DH46-tw ARCO Alaska, Inc. Post Office ,~-:, 360 Anchoraoe.. .~k.= 995'10 Telephone 907 277 5637 December 8, 1983 Reference: Arco Magnetic Tapes w/listings D.S. 3-26 11-6-83 OH # 68730 Run 1 Sch RFT # 68730 Run 1 Sch D.S. 14-35 11-12-83 OH # 68770 Run 1 Sch RFT # 68770 Run 1 Sch D.S. 14-34 10-27-83 OH # 68714 Run 1 Sch 7f 1. 4- Please sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 659 Chevron Dallas Drilling Exxon Getty DISTRIBUTION North Geology Phillips Prudhoe Bay R & D Caroiine Sr,,i~h--~: Sohio Marathon State of Alaska Y. obi l' MEMORANOUM State of Alaska AND GAS CONSERVATIOt~ CO~'~-~ISSION ALASKA OIL TO: C Cl~a~n ~/ /' FILE NO: THRU: Lonn~e C. Sm~h ~[~[p.o~[~o: November 8, 1983 108A:H FROM: Harold R. Hawkins SUBJECT: Petroleum Inspector/~'~."~ Witness BOPE Test ARCO Alaska, Inc., Well No. 14-35, Sec 9, T10N,R14E,U.M., Permit No. 83-142. Wednesday, November 2, 1983: I left my house at 1.-00 pm for a i~30' Pm check i'~ a~ Alaska' Airlines for a departure to Deadhorse at 2:45 pm. I arrived at ARCO's drill site 14 at 5:15 pm. Thursday_, NoVember 3, 1983: I witnessed the BOPE test on ARCO's Well No. '14~35." "There was one ~failure, the companion flange leaked on the choke line next to outside choke from"' tree. i filled out an A.O.G.C.C. report V~ich is attached. In su~v~aary, I witnessed the BOPE test on ARCO's Well No. 14-35 that Parker 176 performed. The one failure was repaired and tested. The BOPE test was satisfactorily performed. Attachment 02-00IA(Rev. 10/79) '~O&G # 4 4/s0 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report I ns pe c to'r Date ..//~-- 3 Well Operator /~ 1~--0 Well /~ ~ 3 Location: Sec Drilling Contractor Rig #/ R e p r e s e n t a t iv e ./~~~_ _p~'.~>~.~ ~/~/ Permit # ~ -- /~ ~~Casing Set @ ~ 7ff ft. Representat iv~ .~ .7~ ~/~/~' ~ _// Location, General Well Sign General Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pres sure ACCUMULATOR SYSTEM Full Charge Pressure ~.~?)~ psig Pressure After Closure ~t~ psig 200 psig Above Precharge Attained: ---~ min~"Q sec. Full Charge Pressure Attained: ~ miL :,'~ sec Controls: Master Remote ~./~ Blinds 'switch cover E~/~ Kelly and Floor Safety Valves , Upper Kell~ Test Pressure Lower Kelly Bal 1 Type Ins id~ BOP Choke Manifold No. Valvas / / No. flanges ~ ~, Adjustable Chokes ~~ Hydrauically operated choke Test Pressure Test Pressure Test Pressure Test Pressure Test Results Failures ~/~- Test Time / hrs. ~ ~'3 z~/,'~ Repair or Replacement of failed equipment to be made within ~ -~-~days and Inspector/Commission. office notified. . Distribution orig. - A0&GCC cc - Operator cc - Supervisor September 22, 1983 Mr. }~rk A. Major Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re: Prudhoe Bay Unit DS 14-35 ARCO Alaska, Inc. Permit Mo. 83-142 Sur, Loc. 313'FNL, 12!8'FEL, Sec. 9, T10N, R14E, UM. Btmhole Loc. 276'FNL, 23'FWL, Sec. 10, T10N, R14E, UM. Dear Mr. Mai or .. Enclosed 18 the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a md log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of aDmdromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Ad~nistrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations pro~nulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to com~ncing operations You may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of thc blowout Mr. Mark A. Major Prudhoe Bay Unit DS 14-35 -2- September 22, 1983 prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to cormmencing ~quipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very. truly yours, Alaska Oil and Gas ConserVation Commission be~6~H/A Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office B,,.~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 16, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 14-35, Permit to Drill Dear Mr. Chatterton' Enclosed is our application for Permit to Drill DS 14-35 and the required $100 filing fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore; a proximity plat showing the subject wellbore's position to the nearest well drilled; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Since we expect to spud this well on October 6, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4965. M. A. Major// Area Drilling Engineer MAM/JG- tw GRU4/L52 Enclosures Aiaskr.! Oil & Gas ~' Aachorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA (J~L AND GAS CONSERVATION CO,,,MlSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. 2. Name of operator ARCO Alaska, Inc. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE I~ MULTIPLE ZONE ~. ¢/~,.. 9. Unit or lease Prudhoe Bay 10. Well number 11. Field and pool Prudhoe Bay Fi 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 313' FNL, 1218' FEL, Sec. 9, TION, R14E, UM At top of proposed producing interval 281' FNL, 162' FEL, Sec. 9, T10N, R14E, UN At total depth 276' FNL, 23' FWL, $ec.10, TION, R14E, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. 69' RKB ADL 28312 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 5 mi. NE of Deadhorse miles 4062' ~ surface fr/ADL 283!~et 16. Proposed depth (MD & TVD) 17. Number of acres in lease 9467' MD, 9253 ' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 5500 feet. MAXIMUM HOLE ANGLE 20 Ol(see20AAC25.035 (c) (2) Proposed Casing, 21 Coupling Length Welded 80' BTC 2670' BTC 8804' BTC 934' SIZE Hole Casing Weight BO" 20" 91.5# 8::./D2i;crib~'~ roposed 2p~o~g ram: CASING AND LINER Grade H-40 L-80 L-80 L-80 iner and Cementing Program SETTING DEPTH MD TOP TVD 30' I 30' 30' I 30' I 29' ~ 29' I 8533' 18377' f MD BOTTOM TVD 110'I 110' 2700'12700' 8833'18658' Prudhoe Bay Oil Pool Amount $500,000 15. Distance to nearest drilling or completed l~,~A~roxim~ spu~d (~it~ef&O6 10/06/83 feet 3394 psig@____ Surface 4148 psig@ 925~ ft. TD (TVD) QUANTITY OF CEMENT (includestagedata) 2050# Poleset 2300 sx Fondu+400sx PF 9467'19253' 500 sx G 1st stage 300 sx PF 1, 2nd stage 400 sx Class "G" cement ARCO Alaska, Inc., proposes to directionally drill this well to 9467'MD (9253'TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8", 5000 psi, RSRRA BOP stack will be installed. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17#, L-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set above the Sadlerochit. A separate Sundry Notice will be submitted when the well is to be perforated. A surface diverter will be used on this well. DS 14-34 will be 117' away from DS 14-35 at the surface. There are no closer wellbores within 200' anywhere down hole. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge S~GN ED ~ ~~ TITLEArea Dri 11 i ng Engineer The space beloJ for ~°o CONDITIONS OF APPROVAL Samples required ~]YES ~ Permit number APPROVED BY Form 10-401 Mud log required [~YES [~43 Approval date . .) //// Directional Survey required APl number ¢~ES ~NO 5o- 0-~1- SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE by order of the Commission Sept_c~ber 22, 1983 GRU4/PD14 Submit in triplicate ANNULAR PREVENTER BLIND RAMS PIPE RAMS SPOOL PIPE RAMS 13-5/8" BOP STACK 0IAGRAM Accumulator Caoacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator ~ressure is 3000 ~si with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultane- ously and record the time and pressure remaining after all units are closed with charging pump off. 4. Record on IAOC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 13-5/8' BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running Joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock dmm screws, 3, Close annular preventer and chokes and bypass valves on manifold, 4. In each of the following tests, first hold a 250 psi low pressure test for a minimum of 3, minutes, then test at the high pressure. 5, Increase presure tO.~'O00 P~ and hold for minim~ma of 3 minutes."~BT~e-U~pressure to zero. 6. Open annular preventer and close top pipe rams. Increase pressure t~ and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of c~ open chokes. Increase pressure to~ & hold for at least 3 minutes. Bleed pressure to zero, 8, Ope~ top set of pipe rams then close bottom set of pipe rams, Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. 9. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open bottom set of pipe rams. 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of Oegasser. 16. Record test information on blowout preventer test form. Sign and send to Orilling Super- visor. 17. Perform complete Bore test once a week and functionally operate Bore daily. 25 Rev. 5/~3/81 SURFACE HOLE D 1-VERTER ARCO ALASKA SYSTEM INC'. SCHEMATIC ... r IO" HYD. OPR. BALL VALVE ~WELL BORE (SEE DE TA IL ) I0" HYD. OPR. BALL VALVE ALL 90* TURNS ARE "TEE" CUSHION I ,.:.}. '~-' ~ BORE ~ RESERVE PIT AREA NOTE · FLOWL INE DRILLING RISER F ~I0" D'IVERTER 20" 2000 PSI ~ ANNULAR PREVENTOR I 0" HYDRAULIC OPERATED Valves on diverter lines open automati- cally when the annular preventer is closed. 20" CONDUCTOR PIPE "DETAIL" BALL VALVES 20260 ! 0207 ARCO AlaS'ka, Inc. P'ost Ol!ice l]ox JG0 · Anchorngo. Alas:!~,~ (J9510 Telephone 907 276 1215 July 5, 1983 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 995'01 SUBJECT' Surface Casing Setting Depth Proposal , LFILF: _..-~ Dear Mr. Chatterton' ' ..... Per your request in our June 29 meeting, l i~ted below are the proposed 13-3/8" casing setting depths for the wells we dis- cussed. DS 3-21 DS 14-31 DS 14-32 DS 14~35 DS 14-A DS 14-B 13-3/8" shoe @ 2900 13-3/8" shoe @ 3500 13-3/8" shoe @ 2900 13-3/8" shoe @ 3500 13-3/8" shoe @ 3200 13-3/8" shoe @ 3200 These depths are the planned casing points for the wells indicat- ed. However, as additional formation information is acquired, it may be necessary to revise some of tl~e depths. Any changes in the original plan will be indicated on the Permit to Drill. If you-require any additional information, please contact either myself at 263-4965 or Karla Lenz at 263-4966. Area Drilling Engineer MAM/KKL49 · sm cc: K. K. Lenz, ATO 1456 R. A.. Ruedrich, ATO 1926 P. A. VanDusen, ATO 1476 Appropr!ate ~ell Files K.~'.~m~, ATT_) 14e4 · I I ~, 3?. izgz' 10 5 8 V~G~I~fY -r'lo ~, RI4~ d.x4, 1~--4000' AS- v,/~t.b.. 31 "( -' 5', ~N-0, ~.95 t_A'r' : "/o°~"r' $6'. 16 Z ;'_.. 10. IG ~.A.r.-x 534o, (o'/5, ZO?. "/0° I'l-' "31. /48° 3 5 ' 05. "/5' 7" ~o) .o5 5,~)4o, oZ B.405 7o"/4' 30. 5 30~'° 14.$° 35' o5~ " P. 5. ~4 AS- DU~:u-r'-' L0CA'I'IO~_5: 3Z,~ AtlanttcRichfleldCompa O AT : DRAWING Ho: , CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. / ~ ~ ITEM APPROVE DATE /2 thru 8) / (3) Admin ( (4) Casg~~~, ~-~2~ -~ (12 thru 20) (21 thru 24) 1. Is the permit fee attached ........................................ 2. Is well to be located in a defined pool ........................... 3. Is well located proper distance from property line ................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is well bore plat included .............. 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... o 10. 11. 122 13. 14. 15. 16. 17. 18. 19. 20. YES NO 21. 22. 23. 24. 25. Does operator have a bond in force .......... Is a conservation order needed . .... pp · Is administrative a royal needed ............. Is conductor string provided ......................................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horiZons ..................... Will surface casing protect fresh water zones ....................... Will all 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 11 bore separation proposed we' e.eeeeeeeeeeeeeeeeeeeeeeeee Is a diverter system required ........................................ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test tO''~d)O .psig .. ~ ply /AP1 (F ) ' Does the choke manifold com w RP-53 cb.78 .... .............. Additional requirements ..................... , ....................... REMARKS Additional Remarks: Geology: Engiq~ering: WVA~ J K~~_~HJH ~ rev: 12/06/82 · INITIAL GEO. UNIT ON/OFF POOL. CLASS STATUS AREA~0.0. SHORE' Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No 'special'effort has been made to chronologically organize this category of information. ,o LIS TAPE VERZFICATION bISTING m,,.'~ m~ i m i i~ml kI:j ~! [:j ~ LVP 010.H02 V~RIFICRTION LISTING PAGE 2 DATE 1~3/11/13 ORIGIN :CSU. CONTINUATION # 50{ PREVIOUS REEL l COMM~.TS :~CHLUMBERGER WELt. SERVICES pROpRieTaRY FI~[.D TAPE DATE 183/11/13 CONTI~UA, TION # PREVT~US T~PE COMmEnTS ISCHt, UMBERGER ~LL SERVICFS PROPRIETARY F~LD TAPE ~'~[.[ NA~ IEFT 001 SERVIC~ NA~E ,PLaYeR rILE TYP~ FILE ~!~E l~rT .001 SERV~C~ ~A~£ IPLAYBA V~RSIO, ~ : 24.2 DAT~ :83/03/29 ~AXI~[l~ LENGTH :1024 r~b~ TYP~ IPE NEXT FTL~ NAME : V~RSION # : 24,2 DATE 193/03/29 MR,~I~I!~ LENGT~ :10~4 FILE TYP~ PREVIOUS ~S?RY ~LOC~S TYP~ ~IZE ~EPP CODE ENTRY 1 1 ~6 0 2 ! 66 0 3 2 79 56 4 1 66 255 5 1 66 0 6 4 73 311 ? 4 65 I~CH 8 ~ '73 6 9 4 65 11 t 66 16 1 66 1 0 0 66 SERVICE SERVICE UNIT lPI ~PI RPI AP! 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R~¢ORD ,, ~MTRY BLOCKS TYPE 3 5 6 7 9 O D~TUM SPEC~FYC~TION BLOCKS ~NE~ S~RV~CE SERVICE ID ORDER # MTiM RFT MSPE ~FT RPS gGP ~FT PSIG PRES ~FT PS~G ~PR£ RFT PDt0 ~FT PO20 RFT ~ONE ~FT PT~N RFT ~HUN ~FT ~ RFT gAPI ! 4 4 4 1 0 REPR CODE 66 66 79 66 66 ? 66 API APl LOG TYPE CLASS MOD O0 000 O0 0 98 636 ~1 0 98 635 21 0 98 970 01 0 98 814 O0 0 98 814 O0 0 98 814 O0 0 9~ 814 O0 0 08 814 O0 0 9~ 814 O0 0 98 ~14 O0 0 9~ 814 O0 0 q~ 814 O0 0 98 3i0 O0 0 FILE NO. 0 l0 107 107 107 107 107 ~07 ~07 10? 1o7 ~07 O~PT 65510.0000 ~TIM SGP 469~.0000 PRES PD~O 0,0630 PONE P?HO 4.0000 GR OEPT 65619.3906 ET~P SGP 468~,0000 PRES PD~O 0.06~0 PONE PTHO 4,0000 GP 16 0150 469~0000 0 0000 5~3711 328.6140 4684.0000 5.0000 TENS RPRE PTEN RPRE PTEN ** F{LE TRAILER ** ~ILE Na~W :RF~ .107 4 1 4 I 4 ENTRY 0 0 56 255 0 311 INCH 6 INCH ~8 1 SIZE SPb 4 1 4 4 1 4 4 1 4 4 1 4 4 1 4 1 4 1 4 4 1 4 I 2980.0000 4692.0000 0.0000 2984.0000 46~4,0000 9,0000 68 04200000000000 04200000000000 68 04000000000000 REPR PROCESS COD~ (OCTAL) 6~ 00000000000000 68 04000000000000 68 04000000000000 68 04000000000000 6~ 04100000000000 68 04000000000000 68 04000000000000 68 04000000000000 68 04000000000000 68 04200000000000 68 04200000000000 68 04200000000000 68 04200000000000 68 04000000000000 MSPE 16064 PDIO 0:0659 PHUN ?,0000 MSPE 48,656~ PP{.O 0,065 PHUN 6,0000 m il ii:-] L_.. 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PTHO PROCESS O~OER ~ LOG TYPE CLASS ~OD NO, CODE (OCTAL) FT O0 000 OO 0 0 4 I 6a 00000000000000 S q~ 6)6 ~1, 0 108 4 1 68 04000000000000 LB 98 635 21 0 108 4 1 68 04000000000000 ~PS 9~ 970 O! 0 108 4 1 68 04000000000000 P$I~ q~ 814 O0 0 108 4 I 69 04100000000000 PSIG 08 ~!4 O0 0 108 4 ! 68 04000000000000 ~SI~ On ~14 O0 0 108 4 I 68 04000000000000 9~ 814 O0 0 108 4 I 68 040'00000000000 q~ ~14 O0 0 108 4 1 68 04000000000000 9~ 814 O0 0 108 4 1 68 04200000000000 9~ 914 O0 C 10~ 4 1 68 04200000000000 9~ R14 O0 0 108 4 ! 68 04200000000000 98 ~!4 O0 0 108 4 1 68 04200000000000 GAPl 9~ 310 O0 0 10~ 4 t 68 04000000000000 5VP OlO.M02 VERIFICATION LISTING PAGE 17 {~TRY BLOCKS TYPE SIZE REPR CODE EMTRY I I 66 0 ~ ~ 66 0 3 2 79 56 4 ! 66 255 5 ! 66 0 6 4 73 311 7 4 65 ~CH 8 4 7 36 11, 1 66 o o 56 )ATUM 8PF,,CIF~Ca. TION nLO, C~S SERVICE SMRVI~E UN! API APl, API APl FILE SIZE SPb CODE C' T RE,PR PROCESS ID ORDER # LOG TYPE CLA~S MOD NO. 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DF? 98 814 00 0 D?HO RF? 9~ 814 O0 0 i09 GR PFT GAPI q~ 310 O0 0 109 4 4 4 4 4 4 4 4 4 4 4 4 4 CODE (OCTAL) 6~ 00000000000000 68 04000000000000 68 04000000000000 68 04000000000000 68 04100000000000 6~ 04000000000000 68 04000000000000 68 04000000000000 68 04000000000000 68 04200000000000 6~ 04200000000000 68 04200000000000 69 04200000000000 68 04000000000000 ~NTRY BI,OC~S TYPE SIZE ~EP~ COD~ I I 66 2 1 66 ENTRY 0 0 i,,,VP 010,N02 VErIFICaTION LISTIMG P~GE 19 ~EPT FT oo 00O OO 0 0 4 i 6S 00000O0O000000 l~ AFT S 98 6]6 21 0 i09 4 { 68 04000000000000 r~.s ~rT ~ ~ ~:{s ~l o lo. 4 ~, ~8 0~00~00o000o0 ~SPE ~FT .,PS 08 970 Oi 0 109 4 i 68 0400uu00000000 ~ ~rT ~s~c; ~ oo 0 lo9 4 i ~PRE PFT PD{O imF? :'070 AFT :'ONR~ {~FT PTEN ~FT }HUN R:FT }THO ~FT 14 PSIG 98 814 98 98 814 08 814 98 8~4 ~AP] 9~ 310 O0 0 109 4 O0 0 109 4 O0 0 109 4 O0 0 109 4 O0 0 1.09 4 O0 0 109 4 O0 0 109 4 O0 0 109 4 O0 01 09 4 04 00000000000 68 O~A 000000'00000 1 6'~ o~0 00000000000 1 68 04000000000000 1 6~ 04000000000000 I 68 04200000000000 I 68 04200000000000 68 04,200000000000 i 60 o, oggoooooooo s, o,oo oooooooo DATA )EPT 65510 0000 ETI~ ~GP 4723i0000 PRES ~D20 0 0630 PONE ~THO 4.0000 G~ )EPT 65621°3906 ETIM ~GP 4718.0000 PRES }D20 0,0620 {)ONE ~TNO 4.0000 ~R 15.0020 TENS 4720,0000 RPRE 0,0000 PTEN 5,8906 328.7518 TENS 4716.0000 ~PR~ 5,0000 PT~N 157.2500 3040, 0000 ~,SPE 0 PD10 3034 0000 ~$PE 4716!0000 PD10 2 0000 P~UN 1,'/783 O, 0659 7,0000 47.04375 0, 659 7,0000 · "ILE NAME :RF? ,109 ;ERSIO~ ~ : 24,~ )ATE :83/03/~9 ~AXI~{{~ [.,ENGT~ :1024 rYLE TYP~ VEXT ~II,~ N~F] : ~VP 010,M02 VERIFICA?ION LY$?ING PAGE 20 'YLE NA~E {AFT 1{0 ;ERVYCE M.AME :PL~YRA )ATE ~$3/03/2g ~AXIPUP LE~GT~ ~024 riLE TYPM { I 1 66 0 2 ! 66 0 3 2 79 56 4 ! 66 255 5 1 66 0 4 73 311 9 4 65 I~C~ 11 I 66 16 ! 66 0 o 66 )AT{}~{ SPECIFICATION ~LOCKS 4NE~ SERVICE SERVICE {,,INIT AP1 APl APl AP1 FILE 8YZE SPL REPR PROCESs ID ORDER # LOG TYPE CLASS ~{f3D ~0, CODE (OCTAL) )EPT FT 00 000 00 0 0 4 1 68 00000000000000 04000000000000 CTIM ~FT S 98 636 21 0 110 4 PENS ArT ~B 98 635 21 0 110 4 {SPE ~FT RPS 98 970 01 0 110 4 {GP AFT PSIG 98 814 O0 0 110 4 ~PES ~FT PSYG 98 814 00 0 110 4 {P~ ~FT PSIG 9~ 814 00 0 ii0 4 }~10 ~FT 0~ 814 00 0 110 4 ~O20 ~FT 98 814 00 0 110 4 }ONE ~FT 08 814 00 0 110 4 PT~ ~FT 9R 814 00 0 ll0 4 PHUN ~FT q~ 814 00 0 110 4 ~THO ~FT q8 8{.4 00 0 110 4 3~ ~FT GAP! 9~ ]10 O0 0 110 4 ! 68 I 68 04000000000000 1 68 04000000000000 1 68 04 0000000000'0 1 68 04~00000000000 1 68 04000000000000 1 68 04000000000000 I 68 04000000000000 ! 68 04200000000000 1 68 04200000000000 1 68 04200000000000 1 68 04200000000000 I 68 04000000000000 ~* D~TA FORMAT RECORD ** ~MTRY BLOCKS TYPE SIZE REPR CODE ENTRY 1 1 66 0 2 i 66 0 3 2 79 56 4 ~ 66 255 5 1 66 0 ~ 4 73 311 7 4 65 ~C~ L"I"I~ rm i ! k mil~i;..] dj! [;-]mJ ~ 4 73 6 9 4 65 INCH 11 ! 66 18 0 0 66 SPEC!FICATIO~! B}.,,,OC ~, S SERVICE UNIT ~P¢I. API AP] AP1 FILB] SIZE SPP REPR PROCE88 [~PDER # [~0, TYPE CLASS MOD NO, CODE (OCTAL) FT O0 000 00 0 0 4 1 68 00000000000000 8 9~ 636 21 0 lt0 4 ~ 6a 04000000000000 CENS RFT LB 9~ 635 21 0 I10 4 ~S'P~ ~F"'T RP$ 9~ 970 01 0 1,10 4 {GP ~FT PSIG 98 814 O0 0 11:0 4 ~RES ~F~ PSI~ 9~ ~1,4 00 0 1.10 4 {PRE RFT PSIU 98 8{.4 O0 0 110 4 )Oi, 0 RFT q~ 81~4 0O 0 1,!0 4 ~D20 RFT 98 814 00 0 il0 4 }ONE RFT 98 814 00 0 110 4 :TEN ~FT 9~ 814 00 0 110 4 ~{,I~I ~FT 9~ ~14 O0 0 110 4 ~T~ ~? 9~ 81~ 00 0 II, 0 4 ]R ~FT GAPI 9~ 3i0 O0 0 110 4 68 ~4000000000000 68 4000000000000 68 041000000,00000 68 04000000000000 6~ 04000000000000 6~ 04000000000000 6'8 04000000:000000 68 04200000000000 ~0420000000000004200000000000 6868042:0000000000004000000000000 T DEPT 65510.0000 ETIN 15,0160 TENS ~GP 4632,0000 PRES 463~,0000 RPRE :D20 0.0630 PONE 9.,0000 PTEN :THO 4,0000 G~ 5,0117 2970,0000 4632 0000 PD10 3:0000 PHUN .')EPT 6562i,5000 MTI~ 333 9147 TENS 2960.0000 MSPE 5GP 4632.0000 P~ES 4632:0000 RPRE 463~,0000 PD1, O ?020 0 0630 PONE 9:0000 PTEN 3,0000 PHU~,' ~T~O 4:0000 q~ 157 7500 1.4971 0,0659 6.0000 47,5313 0,0659 6,0000 FILE NAMM SERVYCM NA~M :PLAYRA W~SIOW ~ : 24,2 D~TE FILE TYPE ~EXT wILE ********** EOF ********** ~II.,E NAiF ~FT VERSION ~ { 24,2 LVP 010,H02 V~R~FICAT~O~ LY,.qT]fNG PAG~ 22 FI[,E TYP{~ ~ PREVIOUS FILE : ** DATA FORMAT REC(]RD ** 3 11 16 0 D~Ti.IM SPECIFICITIOM BLOCKS CODE 66 66 79 66 66 65 65 66 66 66 APl API API LOC, TYPE CLASS MOD OEPT FT O0 000 TENS RFT LB 9, 6,5 MSPE RFT RP$ 98 970 SGP RFT P$IG 98 814 PR,$ RF? P$IG 98 814 1. o RFT 9~ 14 PD~O ~FT 98 814 PON£ RFT 9~ ~14 PHUN ~FT 98 PT~O RFT 98 814 ~R ~FT GAPI 98 Ii0 EfNTR 5 0 31. 1 INCH 6 18 I FILE SIZE SPL O0 0 0 4 1 ~1 0 111 4 1 21 0 iii 4 1 01 0 111 4 1 00 0 111 4 O0 0 11! 4 O0 0 iii 4 00 0 111 4 00 0 111 4 1 00 0 111 4 1 O0 0 111 4 O0 0i 11 4 1 O0 0 111 4 1 00 0 Iii 4 1 E PR ODE 68 00000000000000 68 04000000000000 6 ~400000000 400000000~°0'0000 8 04100000000000 ~8 04000000000000 68 04000000000000 68 04000000000000 $~ 04000000000000 68 04200000000000 68 04200000000000 68 04200000000000 68 04200000000000 68 04000000000000 EMT~Y ~,LOC~S RECO~D * TYP E SIZE 1 1 2 1 4 5 1 6 9 1 6 1 0 0 REPR CODE 66 66 79 66 73 65 65 66 66 66 ENTRY 0 0 56 255 0 311 I~CH 6 INCH 1 :,,VP 01,0,H02 VERIrI'CATION LISTING PA~ 23 UNIT APl ,APl' API API FILE SIZE ~PL REPR CODE LOG TYPE CLASS MOD NO. 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RPS 98 970 O1 SGP RFT PS~G 98 8~4 O0 PR~:$ ~T PSiG 98 8~4 00 RPRE ~FT PSXG 98 8t4 O0 PD10 RFT 98 814 00 PD20 ~FT 99 81:4 00 PON~ PFT 98 81.4 00 PTEN RFT 98 814 00 p~I,!N ~FT g~ 814 00 PTNO ~FT g~ 814 00 G~ PFT UAP! g8 310 00 0 ll~ 4 0 Ii2 4 0 112 4 0 112 4 0 11~ 4 0 112 4 0 11.2 4 0 Ii2 4 0 112 4 0 1,12 4 0 112 4 0 112 4 0 112 4 ! 68 0¢000000:000000 I 68 04000000000000 I 68 04100000000000 1 68 04000000000000 i 68 04000000000000 1 68 04000000000000 ! 68 04000000000000 1 68 04200000000000 ! 68 04200000000000 1 68 04200000000000 1 68 04200000000000 1, 68 04000000000000 ** D~TA FOR~IT RECO~O ** ~TRY RLOCKS TYPE SIZE ~EPR CODE ENTRY I 1. 66 0 2 1 66 0 ~ 2 79 56 4 ! 66 255 5 t 66 0 6 4 73 311 7 4 65 INCH 8 4 73 6 g 4 65 INCH 11 I 66 16 i. 66 0 o 66 DATU~ SPECIFICATXOM Bt, OCKS ~NE~ SERVICE SEPVlC~ I.{N?T AP! 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LCCKS TYPE SIZE REPR CODE ~ 1 66 4 I 65 8 4 73 9 4 65 16 1 66, 0 1 66 )ATUM SPECIEICATION 6L~CKS 4NEM SER'VICE SERVICE UNIT ID OR.,ER # )E PT ;CL PS1 ;CL PS.Z 'CL PS3 ~T ~PI API A¢'i API PILE LOG TYPE CLASS MOO NO, O0 000 O0 0 0 O0 150 01 0 0 O0 150 O1 0 0 O0 150 O! 0 0 .:EPT '9a77,9160 CCL -0.0190 CCL -0,0513 CCL 0,0146 CCL 0,0278 CCL 0,0381 CCL -0,0337 CCL 0.0776 CCL -0.1230 CCc -999,Z500 CCL )EPT 9400,2500 CCL )EPT 9300.2500 CCL )EFT 9200.2500 CCL 'OPT 9100.2500 CCL )EPT 9000.2500 CCL :EPT '.3900.2500 CCL J6FT 8800.2500 CCL 8774.5000 CCL :!LE NA',tE :EDIT ,002 ENTRY 0 1 10. .lin 1 0 SIZE SPL ~ 1 4 1 ~ i -999.Z500 CCL 0,016i CCL 0,0923 CCL 0,5742 CCL 0,0996 CCL -0.0234 CCL 0.0278 CCL -0.1040 CCL 0.0674 CCL REPR PROCESS CODE (OCTAL) 68 O00000000OO000 68 00000000000000 68 000000,00000000 68 00000000000000 -99~.2300 -0.1392 0.0146 0.1846 0.0103 0.07~1 -0.0146 -0.0996 -999.2500 VP OlO.M02 VE~IFIC~TZO~ LISTinG PAGK ~RViCE N~M~ : ERSiON ~ : ATE : .~XIMUN L~NGTH : iLE TYPE : EXT FILE NAM~ ': :~:~ T.&i~E TRAILER ERV!CE NAME :EDIT A'T~ : 87/0.~/I~ 'RIG!N :7225 'APE NAME : ONTZNUA'T!~N ~ :01 ~EXT TAPE NAME OMNSNTS :LIS TAP,~ ARCE' PRU~HGE 5~.Y DS. i~-~,5~ APl ~0-0Zg'-Z1018 :~:~ REEL TRAILER ~:~ :ERVICE N~M~ :~LSIT ~ATE : 87/0~,/14 RiGIN : FEL NAM~ :7Z264 CNTiNUg, TION .~ i~X'T RE~L NAME : .DMM:=NTS :LIS TAOE, ARC~ PRUrjHO~Z ~JAY DS. 14-35, API 50-029-21018 $ ~ame Verification I~i, st,~no hlumberc~er Alaska ComputiDo Center 30-OCT-1994 D~TE : 94/10/~0 R~Er., NA~E : ~418~ CON?INU~T~O~ ~ : COM~EN'I' : ARCO ALASKA !NC., DRUDHOE ~AY. DS 14-35, 500292101800 S~RVICE NaME : EDiT DAT~ : ~4/I0130 OPI~IN : FLIC TAPF NA.}~E~ : 941,8~ Co~ENT r ,~,RCO A!.,A~KA INC., ~Ri.~[>~O~ BAY, DS 14-35, 500~9~I0~800 C~,S?D HOLE WI~ELIN~J 6OG,S API NUN~,B~P: OPEPATOR; LOGOING CO!~DA.~Y~ T~P~ CRF. ATION dOB NUN~BER: LOGCING E~G%N~ER: OPEPATO~ WITNFSS: 8~R~ACE !,,,DC a T l Or~ FNI.: FSL: FWL: FWL: ELEVATIO~fFT wROi~ ~SI.. 0) DEP~TC~ w!.,,OO~: ?ND ST,~ING ~RD [~S 14-35 50029210~800 SCHLUMBERGER ~EL, I, ~,~VICES 25-AUG-94 (;,SCHWARTZ J, .H~USS~ ION 313 121! 69.00 6~.00 ~9.00 []DE,~ ~OLE CASING DPILLFR$ CASING BIT SYZK (IN) SIZ~ (1~) DFPTH (VT) WEIGFT (LB/VT) 7.noO g500,O 29,00 ~.500 ~457.0 ~7.00 ~,50n 8554.o 12.60 :S ~'a~e 'ver.~.ff..cetfon :hlU~berger Al. as~a Co~,PUtin~ Center ~ASE..Li NE DEPTH 9286,0 9'2.,66,5 9241..0 9~36,0 919~;,0 91.84,5 91,79,5 9179,0 9!5~,0 9157.5 9143,5 9142.0 911a.5 9107.5 91.06,o 9093.5 9067.0 9052.5 9049,.5 9042.0 8985.~ 8~81..5 8955,0 894o. C)' 8933.5 8~24.0 8890.5 8.~8~.o 8~76.0 8~75.5 8n74.c 8~70.n ~44.5 8~40,0 !0~.0 G R C H C N T D 88889'5 ~8~89,0 9287,5 9.9,.~7.0 9242.0 9237,0 9196,0 91.~,0 9!80,0 9180.0 9159,0 9!.59,0 914~., 0 9144,0 9115,0 91.06.0 9095,0 9068,0 9054.,0 904a.., 0 80~7,0 8983,5 8~57,0 ~951,0 8935.0 8~25.0 8925.0 8901.0 8890.0 887~.0 8877,5 8~75,~ 8~71 .< 8n46,0 8~40,5 101,5 100,5 PEr'APES: 30-OCT-lgg4 14:33 UNSHIFT~D DEPTH---- .... -- T~E INFnR~ATION P~qRTAININ.C, ~'0 THE O.~EN MOLE LOG SI1CM L~GCI~;G D~T~, LnGCi~G Cfl~DA~Y PAS~ NIJ~.iBE~ ,~ND PON i,~E~ wAS MOT PR~VTDFO %~T?'w ~NE TAPE SUPPhIED BY THE CI. iKr~~ I:~E D~Tb Cq~ECFIOM SaO~N 19OVF. ~EFI.,FCT CASED BOLE TO OPeN hf:,Lw GR AND C~PiD HOLE ~,}PMI Tfl OPEN HOi.,F GR, 'S T~r~e Vorlffcation bist~,,nc :blumberoer A!a. sKo Co~p~,:tinc Center 30-(~CT-]gq4 14:33 CURVES wEP,~5 Cg,RR'iED '~ITH THE ~PMI SHIFTS EDITED CU~V'~$ DePth sh~..ited ~rld cliPPed curves for each Pass ~.n separate files. I 0.500O 8T,~RT DEPTH o .... 9'29'I. 0 ) STt!P [ MPTH 87~.0 878~.0 CURVE S~iFT DAY,~ - PASS TO PASSfS~.EASLi'RF.D DEPTH) mASEI, I~:E CI!RVE FOR SNIFTS .......... Ff~IIIVAI~NT IJNS~IFTFD DEPTH---- ...... PE'.~'APK$: l'W, I5, FI[.E cr~,~TATN$ PASS ~1 ..oF' T$IE C~]TD. NO PASS TO PASS SNIWTS t,~EP~: APPLIED TO TNTS [JA~'A, TASTE TYB? : CO~X5 TUf~I VALU DEFT CN ~RCO AbASKA, II~C. Company t~ame ~'~ PRUDHOE B~Y Field Hame ~ ~S ~4-35 Well Name A~i~ 5n-02~-2101~-00 ~PI Serial Number FI,. 3~3' F!~[, g 1218' FEL Field Location S~.CT 9 Section :hlUmberqer' ~l, aska Co~,putlno Center 30-OCT-~,9O4 14:33 T ~,! t~ ! v A L L.I D E F I . 8TA~ AbASKA N~TT USA PDAT tqSL EPD FT 0. L~F RKB APD FT 69. E~B FT 69, EDF FT E~L VT 39 TDD VT 9560. TDL FT 9,430. BI.,I FI 9~00. TI,i FT aS00. DFT [:~KAD CRUDE Township Ranqe County State or Province Nation Witness ~ame ServJ. ce Order Number Peri, anent datum Elevation of Permanent Datu~ bog ~easu:ted From Above ~ermanent Datum Elevat .oD of Kelly BuShing Elevate. on of Derrlc~ Floor Elevation of Ground Level Total Depth- Driller Total Depth - Logger Bottom 5oQ IDterval Top LogInterval Drilling Fluid Type Time 5o~er at Bottom T~B[..,E TYP~ : CU~V P~F! .... ................. . .......... . ............ ..... N~HT Co~Densate~ ~,ieutron Porosltv, SS ~tatrix, call & dead time corr. N~AT ~eutron Patlon Non-Dead time corrected C~Aw Neutron Patio, Dead Time Correcte~ (RN/RF) NC~T Paw ;'.}ear Detector Count Rate, Dea~ Tin'~e Corrected FCNT ~aw Far netector Cou~t rate, Dead Time Corrected CFTC Corrected Far Detector Count Rate C~.~T~ Corrected Near Detector Count ~ate G~CH ~a~a Pay .~ Casin~ TF~S Surface Tension COL CCt, ~litude G~ ~PT-morrected Cama~a Pay ** DATA P~nR~AT SPECTFTC~ITOr,; PECO~I) ** Tame Ver~.f~,cation T,,ist]~Dq 'blUrr~beraer ,Ala~-kl,o,, Comptlt.lna ..... Center,. 30-0CT-~994 1~:33 AGE; 4, 66 5 66 ~ 73 7 65 8 6~ 9 65 1~. 66 1,~ 66 1,~ 65 1,5 66 1.6 66 0,5 0 6~ NPH? CNmD PU-S NmAT CNTD CPAT CNmD NCNT CNTD CPS FCN~ CN~D CPS CWTr CNTD CPS C~TC CNTD CPS G~C{~ C~TD GAP~ CCL C~WD V G~ OH GAPT A I APl E NU~JB NU SI.,,L E pR El 'TYPE CLASS I~UB 51lJ~.~O SAMP ,F.,LEM CODE (HEX.') n 000 O0 0 1 ! 1 4 68 0000000000 480670 O0 o00 O0 0 1 ! 1 4 68 0000000000 4,8~670 O0 000 O0 0 I 1 1 4 68 0000000000 480670 O0 000 O0 0 1 1, 1 ,4 68 0000000000 480670 O0 000 OO 0 1 1 1 4 68 0000000000 ~80670 on 000 O0 0 1 I 1 4 68 0000000000 480670 O0 000 O0 0 1 1 1,, 4 68 0000000000 480670 O0 OOO O0 0 I ~ 1 4 68 0000000000 480670 O0 000 O0 0 1 1 1. 4 68 0000000000 480670 O0 gO0 OD 0 I ! 1 4 68 0000000000 480670 O0 000 O0 0 I 1 1 4 68 0000000000 4.80670 O0 nO0 On 0 1 1 1 4 68 0000000000 D~Pw. g7PS.00O NCN*.CtdTD P151.844 GPC~.Ct;T[, a2.7!9 tdPDI.C~TD 5?.744 r4RAT.CNTD 7.294 C~AT.ChTD wC~'T.CNTD ~9.q.011 CFTC.CNTD ¢8~.22] C.~TC. CNTD TEkS.C~TD O,iO.O00 CCL.CNTD o. O00 GR.OH -999.250 -999.250 37.375 7.638 2155,738 -999.250 S Tape Verificat,t, on List..Inq hlUmbero'er A3,asKa Computino Center 30-0CT-1994 14:33 **** FILM 'rR~ILEP **** FIL~ NA~E : EDIT 8FR¥IC~ : FblC VFR$I. Ot~ : OOJC01 D~Tw : 94/10/30 M~× REC SIZE : 10~4 F!LF TYPE : LO **** F' I.UE HE~DrR **** FTL~ NA~ : F, DIT .002 SERVICE : FLIC VFRSI'O{~ D~,TE : ~4110t30 FILF TYPE : LO L~ST FILE FFT bF.. HEADER Depth shifted and cl~,Dned curves DFPTH INCRE~E~,~'!': 0.5000 FILF I,DWG TOOl., CODE] ~T~R'~ DEPTF ST~P DEPmH ................. [-;; ..... C~CH 9~ 0 7 C;:~TD 9~93.0 878~, o CIIRVE SHIFT DaT~ - PASS TO PASS(~EASHR[{.:n DEPTH) PASE!,I~E C~JRVE FOR SHIFTS LDw~ CUR~ COD~: CRCH .......... F~UIVA[,E',NT Ur~SHIFTED DEPTH .......... .............. 9269.n 926a.5 9261,5 9239,o 9236.5 9187.0 9~65.g 9~51 .~ Q14 C N "rD 925q.0 920~, . 5 g!63,q 91.49.5 914~.5 iS 7aoe Yerif,~cation [,,l.,stino ~l. umberqer Alaska Computlno Center 14:33 9139.5 9129.0 9118,0 9115.5 9110.0 9~07,5 9105.5 9~03,0 9096,0 9093.5 9080.5 9078,0 907~.o 9070.0 906g,5 9055,0 905~.5 9044,0 904~o0 902a,5 9026,0 8995,0 8993.5 8989.5 8987,0 8953.0 8951.,0 8939.5 8036.0 ~90~.0 8007.0 ~90~.f) 8~99.5 ~97.0 8~95.0 884~.5 8~44.5 8~44.5 8~21.0 8813.0 8al~.O 8807.5 8805.n 100,0 97.5 97.5 THIS FI!,E CONTAINS PASS ~ OF TME CNTD, THE DEPTH CORrECTiONS $~{tJWN ABOVE REFLECT P~SS ~2 GRCH TO PASS GPCa AND PASS ~ ~PMI TO PASS ~1, Np~II, ALL O',rHE~ CNTD CURVES wE~.; C,IR~IED WITH THE NP~I SHIFTS. PAGE~ 7 ..................................' ' - .............................................. " ....... F~ P~UDIiOE BAY WN bS. 14-35 API~ 50-029=~1018-00 SFC? 9 ,row~' S~ ~LASK~ NIT? USA ~!T~' O HEUSSE~ SOf~ 4~670 L~F Field Name Well Name APl Serial Number Field I,ocatlon Secti. on Range County State or Province Nation Witness Name Service Order Number Permanent datum Elevatiom of PermaDent Datum Loo ~easured From :S ~a~e Ver.~,f~.cation Listino :hlt~mberoer Alaska Com. put~.t~q CeDter 30-0C~-~,994 14:33 P AG E: ~ T U ~t T v A L U D E F I , APD FT 69. EDF FT 6~. E~L FT 39, TDD FT 9500. TD5 F'T 9430. BLI F'T 9300. TLI ~T 8800. D~T D~A.D CRUD~ ABove Permanent, Datum ~.levati. on of: Kelly Bushing Elevation of Derrick Floor Elevation of' Ground bevel Total PePth - Driller Total DeDth Logger Bottom ,boo I~terval Lo, o Interval DrT°~ll, i~q F'lulO Type Time LogOer at Bottom T:~,B~.E; TYPE : CUR¥ D~F? NPHI Compensated ~eut, ron Porosity, S$ ~atrlx, call & dead time corr. NRAT Neutrom ~ation Non-Dead time Corrected CRA~ Neutron ~atio, Dead Time Corrected NCNT ~sw wear Detector Count Pate, Dead Time Corrected FCNI ~aw war Detector Count rate, Dead Time Corrected CFT~ Corrected Far Detector Count Rate C~TC corrected Near Detector Count Rate G~CM ~amma ~av ],n Casino T~NS Surface 'Pension CCL CCL am~lJ, tude ,* P.'ATA FORMAT SPF. CTF!CATI[..}N P.~,CO~D ** 2 66 n 3 73 44 5 66 6 73 7 65 8 68 0.5 11 66 23 17 68 13 66 14 65 1.5 66 68 'S Tape Ver~f~..cat,I, on rhlUmherger Al, asEa Co~p~,,,]t!r~o Center 994 I4 D~PT FT ~80~70 00 000 O0 0 2 I 1 4 68 NPHI CS:lTD PU-$ d80670 00 000 00 0 2 1 { 4 68 N~AT CNTD 4,80670 O0 000 O0 0 ~ ~ ~ 4 68 C~AT CNTD 4~0670 00 0O0 O0 O ~ ! i 4 68 NCNT CNTD CPS a, 80670 O0 000 00 0 ~ ~ 1 ,4 68 FCNT C~TD CPS 480670 00 0~0 00 0 ~ 1. 1 4 68 CFTC CNT!) CPS 480670 00 000 00 0 2 1 ! 4 68 C~ITC CNTD CPS 480670 00 000 O0 0 ~ 1 1 4 68 G~C~ CN~D GAPI 4~0~?0 00 000 00 0 2 1. 1 4 68 TFN$ C~TD L~ ~Ho670 00 000 00 0 2 1 I 4 68 CCL CNTD ¥' 4S0670 00 000 00 0 ~ ! ~ 4 68 0000000000 0000000000 O00000OO0O 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 D~PT. 9293.000 MPDI'CNTD 26.528 NRAT,CNTD NC~W.CI"~D 35~9.65'7 FCNT.CNTD 9,8,3.33] CFTC.CNTD G~CN.C~,)~[,) -909.250 wEMS.CNTD [015.000 CCL.CNTD **** FILE TRaI[,EP **** FILF ,W,A~,IE ; FPT'r .002 SwRvICF. : FLTC VFR~ID:'~. : 001 C01 D~T~ : O4.110/30 ~X R~C STZ~ : !.0~ FTLF TYPE : l,[.,, LaS~ ~II~E : 4.377 CPAT.CNTD 812.889 CNTC.CNTD 0.000 4.6t4 3652.18~ $ Tane Vmri~f.~cat.f. on 10isti,~no 'hlUm.heroer A]aska Computl,,no Center 30-OCT-1994 · PA :,g: I0 **** FT.,LE F~L~ NA~'.~E : EDT".[ ,003 8FRVlCE : Fb~IC V~RSlO~ : o01CO1 l:) AT~ : 94/10/30 M g. X R E C S I FILF T~P~: : LO LAST FILE EDITED C U R 'V I~.'.: $ .Depth s h.f ft. ed PAS8 ~!t.]~BER: D~PTH INC~E~ENT: LDWG TOOl., CODE CURVE SMIFT mASE!.,,I ~g P~SS 9284,0 9275,~ 926~.0 9753.0 974~,n 9242.5 9 .'222..~ 9211.0 990q.5 91 ~6. ") 9.~ 80,5 9~7~,5 9].64,K 91.53,B 91 51 .r, 9.~ 43,~ and cll. poed 3 0, riO00 curves for 9~.8 0 9293,0 DATA - PAS8 TO PASS(MEASURED CURVE: FI.iF SgI:FT8 CURVF CODE: GRCH ~LI~BER: 1 each pass j..n separate f~..les, 878~,0 B788.0 .......... POUIVALENT ~8~ 5 8U88.. 9266,5 995~,0 924l.o 9220.0 970q,O 9~07,5 91.88.0 91.84,~ 9179.o 9169,0 9~62,5 9!59,5 9.~ 51.,0 9147.0 9t. 4~.5 I.l} N~qFI I PT~D D.P.,PT_H---------- iS Ta~.e v er'~f~cat~on List,!~n~ :hlu~ber~:~er A ',as~ Computir~., Center 30-OCT-1994 14!:33 9!16.0 91.14o5 910~' 5 910~. 0 9087.0 9085.0 9075.5 9073.5 9069.0 9067.5 9044.0 904~.5 9041,5 9040,0 89~g.0 8987.0 8985.5 8984', 0 8958,0 [~956,5 895~.0 8~51.0 894~.5 8947.5 8945.5 8944,0 8935 0 8933.5 8~27~0 ~ s ~2~.o ~:~:~ 890~.0 8899.5 8fl77:0 8875.5 8845.5 8a44.0 884S,0 ~92~.5 8~29 lon.o ~.o TwI$ ~ir.,~: CoN'rAI,~s pass ~3 OF THE C~!TO. THE DEPTH COR~ECTIO~S S~OWN A~O~E }~EFLECT PASS ~3 G~CH TO PASS GRCH ~NO PA~S ~3 NPHI TO PAS8 ~1 WPHI ALL OT~ER CNTD Ct~RVE~ W~Pk: C~RPIFD WITH 'rile ~PHI SHI~TS $ DATA PAnEl 11 Fw PmUDHCE B~Y Field ~ame WM £~S 14-35 Well Name ADI~: 5o-029-~101, a-00 IPI Serial Number Fl, 313' FN[., g 1218' FEI, Fleld bocatlon SFC· 9 SecttoD TnW~, ln~ Townshi~ R~N~ la, g Ranoe 'S Ta~e Verification [.,istinq :hlUmberc]er AlasKa Computing Center 1,4:33 CO'ON F,~ r,'l R T Ii STAT I%L, ASK a NATT USA ~O]N 4,~0670 PDAT NSE E P D F T 0 APl,) FT 69, EKB MT 69, EDF FT 68, EGb VT' 39, T P D ~' T 9500, TD,h FT 9430. BI,,I FT 9300. DFT DEAD CRUDE TI, AD 11:~6 County 8tare or Province Nation wit:ness Name Service Order Number Permanent datum Elevation of Per~anent Datum Log Neasured From Above Permanent Datum Elevation of Kelly BuShing Elevation of Derric~ Floor Elevation of Ground bevel Total Depth - Driller Total Depth.- Logger Bottom LDo Interval Top boo Interval Drilling Fluid Type Time bogger at Bottom TABLE TYPM : CiUPV DEFT [)KPT Pe~th NPHT Compensated Neutron Porosity, SS ~,'latrix. cai.! & dead time tort, N~AT Neutron Ration Non-Dead time Corrected (N/F) C~AT Neutron Patio, Dead Time Correcteo (PN/RF) NCNT eaw wear Detector Count, Pate, Dead Time Corrected FCNT Paw Far Detector Count rate, Dead Time Corrected CFTC Corrected Far Detector Count Rate CNTC Corrected Near Detector Count Rate GPCW Camma Pay ~n Cas~n~ TFN~ Surface Tension CCL CCL ** DATA FORuAm ~PFCTFTCATION ~ECO~D ** TYUg ~EPR CODE 1 66 2 66 0 3 73 4 66 5 66 6 73 ~hlumberger AlasKa Cowp~lt, inq Center 30-0CT-~,994 14:33 7 65 9 65 1~ 66 17 6~ I,) 66 0 1,4 65 15 66 !.6 66 0 66 ** SET ~.~¥"P~ - CHAN ** ......................... .........,.....-......,.,.....--.---..--..-,---,...---.-- '"""'"""""",""~,~ ~ ~ ~o .... oo '",,'"'""'""'""o oo o ~ ~ .... '"'~ .... 4' .... '""'~ oooooooooo'"""" NPHT CHTD P,!.)-S 480670 O0 000 O0 0 3 1 1 4 6~ 0000000000 N~AT CNTD 480670 O0 000 O0 C~A? CNTD ,480670 O0 000 00 NCNT CN~D CPS 480670 O0 00O 00 FCNT C~TD CPS 480670 O0 000 O0 CFTC CNTD CPS 48(3670 O0 000 O0 CMTC CNTD CPS 480670 O0 000 00 GRC~ CNTD GAPT 480670 00 000 O0 0 3 1 i 4 0 3 I 1 4 0 3 1 1 4 0 3 1 I 4 0 3 1 1 4 0 3 1 I 4 0 3 1 1 4 68 0000000000 68 0000000000 0000000000 68 0000000000 6B 0000000000 68 0000000000 68 0000000000 ~3 ** DATA ** DEPW. 02q3.000 a!PHI.CNTD NCPJT.C~)'TD 34P6.1o5 PCNT.C~TD GPC~.C~!TD -909.~50 26.595 NRAT.CMTD ~00.000 CFTC.CNTD 1030.000 CC5.CNTD 4.54~ CRAT.CNTD 770.106 CNTC.CNTD 0.000 4.6~2 3537.345 ** EWO OW nATA ** 6 Ta~e Ver,f, ffcatlon ~hlumberqer A]ask. a Comput~.n.~ Center 30-0CT-1994 I4:33 PAGE~ 14 AvE1PAGS,:P CU~VFiS Compensated ~eutron: Arit. hmetl, c average o~~, edited passes for al..1 curves, ~ulseU ~eut. ron: ~.~maveraaed edited Pass 1 Gamma RaY and Dackroumd counts; arithmetic average of edited static basel,.ne ~asses for all other curves. D~PTH I~CRE~ENT 0,5000 P,aSSES INCLUDED IN AVERAGE ~,DWG TOO[, CODE PASS NUM~E~ ~A.[~KS: THIS FII~E CONTAINS T~E ~RITHgETIC AVErAgE OF THE THREE C~TD PASSES, ALI.., DEPTH CORRECTIONS WErE ~ADE BEFORE THE AVE[~A~E WAS COMPUTED, T.aBI,E '.['¥PF : CONS .~t,,i I VALU DEI?I CN ARCO A~SKA, INC. Company ~ame API~ FT, 8~CT R~ COUP7 STAT W TT"' PDAT ~:~D ~T W T WT PRUPHOE BAY DS 14-35 50-029-21018-00 313' FNT, & !21.8' WEb ].0~ NORTH SLOPE ALASKA []SA. O. HEU$$ER 480670 69, Field Name Well Name ~PI Serial. Number Field Location Section Township Range County State or Province Nation Witness Name Service Order ~umoer Permanent datum Elevation of Permanent Datum Lo~ Measured From Above Permanent Datum ~levatio~ of Kelly Bushing 'S ~ane Ver~tf~cat~.or~ List).n~ ~hlUf~beroer AlasKa Comput!.nc~ Center 30-~CT-~gg4 14:33 PA ,,E; 1 5 TIlN ~ VALU DEFI Elevation o~ Derric~ Floor EDF FT E~L ~T 39 TDL VT 9430. BLI ~T 9300. TLI WT 8800. DFT DEAD CRUDE Elevation of Ground Level Total. Depth - Driller Total Depth'- Logger Bottom LOq Interval TOD Loq I,terval Drill. lDq Fluid Type 1J.:16 17-~AP-94 Time {,oqcer at Bottom , TI, BLt TYPE ~ CU'~V .... ..... "" .... '"'"""'"'"'""--' ..... ~PHI Compensated Neutron Porosity, S~ ~atrix, cali& dead time corr. N~AT ~eutron ~ation Non-Dead time Corrected (N/F) C~AT ~leutron ~ati,,o, Dead Time Correctea (~N/RF) NCN~ Raw Near Detector Count ~ate, Dead ~ime Corrected FCN~ ~aw Far Detector Count rate, Dead Time Corrected CFTC Corrected Far Detector Count Rate CNTC Corrected blear Detector Count Rate G~CM Camma Pay in Casin~ 'YENS Surface Tensi. on 1 66 0 2 66 0 3 73 a.O 4 66 5 66 v 73 7 65 8 68 0.5 9 65 ll 66 25 12 68 14 65 15 66 6~ 0 ~6 mmmmmmmmmemmm memmmmmm~mmmemmme S Ta~.e Verification Listino hlumberger AlasKa Comput!no Center 30-OCT-!,994 1,4:33 PAGE~ SET TYPE - CHAN *$ MIT SER'V E APl .~ I APl FI E NUM NUN5 SI ~] OCE$$ ORDE~ # hOG TYP~ CL~6S ~OD NUMB SAMP ELEM CODE (H~X) DEPT Fm 4180670 00 000 O0 0 4 I I 4 68 NPRI CN.aV PU-S 480670 00 ()00 00 0 4 1 1 4 68 NPAT CNAV ,~80670 O0 000 O0 0 4 1 I 4 68 CPA, CN.~V 480670 00 000 00 0 4 1 I 4 68 ~CN~ CN~V CPS 480670 FCNT CNAV CPS 4,80670 00 000 00 0 ,4 1 1 4 68 C I ,, CNAV CP& ,480670 00 000 00 0 4 1 1 4 68 CNTC CN~V CPS 480670 O0 O00 O0 0 4 G~C~ CNnV GAP~ 480670 00 00O 00 0 4 1 I 4 68 TEN~ CaAV LB 4[.{0670 00 000 00 0 4 1 i 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 16 DFP~'. q293 000 N"Pi-II.C~,.A! 26.I43 NCNT.CNAV 3497.1,56 FCNT.CNAV 867.08~ G~CH.CN,~V ~11.338 T~iN~.CNAV 106~.,7,,27 NRAT.CNAV CFTC.CNAV 4 368 CRAT.CNAV 81,,~,"338 CNTC.CN'AV 4,564 3615,920 F?L~ NA~E ! ~D!T .004 6~RVICP.: : FLIC V~R~ION : 001C01 N~X ~FC SIZ~ : 1024 FILm TYP~ : LO I, SST FII.~ 5WRVICE : wLTC VERSION : n01C01 DATF ! q4/lO/30 M~X REC STZ~ : !0~4 FILm TYPK : LO L~ST FIr,~, Curves and loc~ header data for each mass in semarate files; raw baeKoround pass in last 'S TaDe Verif,lcet~ion !.,,ist. fn.ct ~hlumberqer AlasK',3 Comptltinc~ center 30-0CT-1994 14133 PAGE: PASS ~U~"~i~ER: DFPTH i r,!CPE~,,~E't,fT: 0. 5000 FIL~ VEN~mR T~i'JL CODE LOG HEADED ~ATA ST~P DEPTM DATE LOG~ED: SOFTWARE VERSION: TIME bOGGER ON TD D~II,,LFR (FT): TD I,,OGGER(FT): TOP LOG INTER'VaL ~OTTC,a bOG I.,iERVAL I,,O~GING SPEED (F'mH~): DEPTH CONTROL UfED (YES/NO): TO0~, ST~ING (TOP TO VENDO~ TOOL CODE TOOI~ TYPE t,,7-~AR-94 32.6 1116 9500.0 9430.0 8800.0 9300.0 1800.0 NO 17-~A~-94 CNT~ CNTD C~!TD $ ~OREMOLE A~!D CA$I~O DATA. OPEN DRTbI..EPS C~STNG DEPTH 8820.0 ~ OPEUO[..,E C .ONDITiO!~,K FLUID 'TYPE: FI,UTD DENSITY (t,~3/G): $~{RFACE TFHPEPATUgE C~)EGF): ~OTTO, ~4O[,,E TFN~EPATUPE (DE~F): F'IjiJTO S/bTcIT~'Y (PP~';): DLHZD LEVEL (F~): FI.,UTD R.~T~ hi ,~ELI.,HFAD W,~T~R CUTS CPCT): GIS/OTb CuOKE (DEC): DE~D CPUDE THERMAL 2.65 i.~I,U~i_.,TNF., CO;!MT ,gAT~; bOR,~AI, iMATInN I~! nil %ONE TOP NOPNALTZTN~ iS Tame Ver,lf~cation List',no :hlUmbercler Alaska Comput!no CeD, ter 30-0CT-~994 14:33 COUNT R~T~ SCALE6 SET BY WIELD COU{~T ~ATE HIGh,{ SCA'LE ~'~ET~R COONT RATE [,.,{~,.)~ SCALE (CPS): ~'Ea.R COUNT RR'I'~E HIGH SCALE PU~PED 400 ~BI,,S OF DEAD CRUDE ~EFORE LOGGING PASS NO.1 . LOGGED PASS NO.1 WHILE PUt, PING AT l,.O SP~ (DEAD C~UDE). LOGGED PASS NO.~ AND MO.3 wHILE PUMPING A,T .5 BPM, APPARENT dOC AT 9096'. TAGGED PbTD AT 9430' LO(,;~ED ~LL PASSES AT 30 FPS. PAGE~ X8 TABLE TYPE TUNT VALU D~FI C~ ARCO ADASKA, iNC. F~ PRUDHOE BAY ~ OS 14-35 ADI~ F'L 3~3' FNL g ~18' VEL SEC~' 9 T 0 ~ ~J 10 N C~IJ~ NnRTH SLUPE STAT ALASKA N~TI' USA WTT~ d ~;EUSSE~ PDA· E~D WT O. L~F RRB ADD VT 69. E~B FT 69. EOF FT 6~. E~L mT 39. TDD ~'r 9500. TDL ~T 9430. B[I FT 9300. T~,I WT 880~. DFT bEAD CkUDF T~.Am 11:16 17-WAP-94 Company Name Field Name Well Name APl Serial Number Field Location Sectio~ Township Range County State or Province Nation Witness same Service Order ~iumDer Permanent datum Elevation of Permanent Datu~ boo Measured From Above Permanent Datu~ Elevation of Kelly Bushing Elevation of Derric~ Floor Elevation of Ground Level Total DePth - Driller Iota] Depth - Log~er Bottom boq Interval ToD Loc Interval Drl. llinq Fluid ~ype Time Loqaer at Bottom '$ Ta~.e Verification [,ist,lno ~hlumber. qer A3ask.'a Comput.in~ Center 3~-0CT-1994 1~:33 DE',PT ~epth N~H'T' Compensate,~ Neutron PorositY, $8 .Natrix, call. & dead ti.~e corr, RT;~P ~aw ~erma] Neutron.~atio T~.~R~ Thermal Neutron ~at. io Calibrated RCNT RAW ~.!EAR CNT CO{.3~JTS RCFT RAW FAR CNT COUaTS CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Cogent Rate GR APl-Corrected Gamma ~aV T~N8 Surface Tension CC[,~ .:CI, ~mm J, tude PAGE: ** nATA FOR}~A,T SPECIFIC' '~TION RECOpD ** ~* SET TYP~ TYPE R~PR C[12E VALUE 1 66 0 2 66 0 3 73 44 4 66 6 73 7 65 8 68 0.5 9 65 FT il 66 13 66 0 15 66 ** SET 'r~PE - C~h~ ** "' ....................... 2;~ ..... '" ; .......... ~ .... ' .... ;;3~ ..... ' ID ORDEP ~ bOG TYP~ Ct, aSS yon ~U~e Sh~V ELE~:~ CODE (}lEX) ............... ; ...... ' .... 5;5" '-' ................. ~; .... 0 0~0 ~ 1 ~ ~ O0000O NPHT PSi PU .480070 O0 OO0 flO 0 5 i I 4 68 OOO00OOOO0 RwN~ PS~ 4.80670 nO 000 O0 0 5 I 1 4 68 0~00000000 TNR~ PSi. 480670 RCNT PSi CD& 4~0670 00 000 ~0 O 5 1. I 4 68 O0000O0000 RCF'W ~81 CPS 480070 00 000 00 0 5 1 1 4 6~ 0000000000 [S Tane verifl, catl. o~ L,isti, nq :blUmberqer AlasKa Comput,in~ Center 30-0¢7'-1994. 14:~3 2O ......... ---,,,-------,,---------,-- ..... .............,............,.......... C,,,8 480 O0 0 O0 5 I I 68 0 00000000 CFTC PS~ ~P5 480670 O0 000 O0 0 5 i i 4 6~ 0000000000 GP PS~, ~API 4B0670 O0 000 OO 0 5 I I 4 68 0000000000 'l'~,~S PSl LB 4B0670 00 000 O0 0 5 1 1 4 68 0000000000 CCL. PSt V 480670 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** RCi~T. PSI 3500.000 ~CFT.PSi GP. PS ~1. 1 5.164 'Y E~.I,$. PS 1 DEPT. 8774.500 NPHi.PS1 RCNT.PSI 2151.8,44 RCPT.PS1 G~.PS1 34.2~1 TENS.PS1 END 29 . ~ 54 R T N R .: P S 1 729 oo 52.744 RTNR,P$1 295,011 CNTC'PS1 940.0~0 CCL,P$1 4.800 3506, 334 CFTC.PS1 0,. 000 7.294 T~AoPS1, 2155.738 CFTC.PSi 0.000 5.027 697,559 **** FIL? ~RAII, EP **** SERVICE : WLIC VERSION : O01CO1 D~'r~ : 94/i0/~0 M~X REC S!Z~ : 10~4 F!L~ ~YPE : h~S~ PILE : FTLP ~'h~g ~ EIJTT .006 SFR¥IC~; : FIJIC !)~~r : 04110/30 ~X aFC 5TZ~ LaS· WILE FTL~ 14E ~OWR R~ CURVES turves a,~d lo~] aeader aata ~or each mass in separate D~P~H I~,~CPEUE'.~'.~T~ 0.5000 files: raw backoround pass in last fi 'S Ta~e VerJf. tcation :hlt)mberqer Al. asEa ComputJ. Da Center 14:33 ¸21 VEiNDf]R ToUL cODE START C~TD 9304',,,, 5 bOG H~D~ OA~A DA~E LOGGED: ~D D~ILLFR (FT): TOP LOG INTE~VAb (~T): ~GT'I'O~ bOG ,INTE~VA5 (FT) t,OGGTNG SPEED (FPH~)~ D[~:PTH COMTROT,, ttSEO (YES/NO): TO0[~ ST~I:NG (wOP TO BOTTO~,I) VF~D(]~ TODD COD~ TOOL 'rYPE C~ITD C,~TO C~TD C ~TD P, OPE~O[,E AMD C~SING DA~A OPEN ~O[,,E Bll SIZF; DRILLERS CASING DJ{mTn4 (FT)~ T.,[IGGFRS CASING DEPTH (FT): nOREtlO[,g CONDTTIONS FLUID TYPE: FLUID D~NSlTY (I~B/G): SIJRFACE TFMPEPATURE (DEGF) BnTTO~ HOLE T~7~iPE~ATURE (DECF): F[,~ID LEvkI (FT): FI,,UID RATE a'!' WELT,HEAD (Do~,~): G~S/CTL RATIU: C~OKE (DEG): ~E[I'I'R O ~3 TOOL TOOT..., TYPE (~PTII-IER~A[~ OR ~{ aT,iX DE~SYIY: MOL~ C[]gRFCTION (l~.~): STOP DEPTH 17-MAR-94 32,6 !1~,6 9500.0 9430.0 BgO0.O 9300'0 1800.0 NO 17-MA~-94 TOOb NUMBER CObLAR L CATOR CAI,-UB AUXILI, IARY MEAS!IRF~{~NTS ATC CB 433 COMPENSATED NEUTRON CNC DA 101 COMPENSATED NEUTRON NSR LA 3137 AI.JXI'LLi~,RY MODULE AT~ 1.60 8~20.0 DEAD CPUDE THERMAL SANOSTONM $ ?a~e Ver'i.f],cat.].on ListinO ~hlumberQer Alaska Comput.inq Center 30-OCT-1994 14:33 FA~ COUNT ~.ATE LOW SCALE (CPS): ~A~ COU~T ~ATE HTG~ SCALE (CPS): }~.;EAR COUNT R~TE LOW SCALE TOOL STA~tDOFF (IN)~ R. Fi'45RKS: TED !NT© bgCS DATE[) 12-~0V'-1983 ' ..... E.AD CRUDE BEFORE LO~GING PASS Pll~:~PE',r:~ 400 BBLS OF APPAREI'~T GOC AT 9096'. TAGGED P~TD AT bOG~ED ALL, PASSES AT 30 bT6 FORh~T DATA T~B[.,E TYP.F. : CONS A~. O DEFI' 'r[tN T V ., ,, , C~,~ ARCO AL,hSKA, I~iC. F~; PRUDHOE BAY ~ DS 14-35 API~ 50-029-~101~-00 F~.. 313' FNL & 121~8' FEL S~CT 9 TO~' 10N COU ~.~ ~,~OR T~ SLOPE N~T~ USA WIT~ d HE. USSER SO~) 4~06'/0 PDA~ EPD ~'l' 0, L~F RKB A~D VT 6q. EWB WT EC:b VT 39 T~I.7 r~ 95~0. TDL ~T 9430. BLI WL' 9~00. TL~ wi 6800. DWT DEAD C~UDE T[,A~ 11:16 17-b~AR-O4 Company Name Field Name Well Name API Serial Number Field Location Sect]on Townsnl~ Ranqe County State or Province Nation wltnes~ Name Service Order Number Permanent datum Elevation of Permanent Datum LDO ~easured From AbOve Permanent Datum ~levatioD of KellY ~ushinq Elevation o~ Oerric~ Floor £1evat~on of Ground ~evel Total DePth - Driller Total De~th - Logger aottom boq Interval ToD Log Interval Drillino Fl.,ul.d Type Time Loqqer at ~ottom S TaPe VerificatJ. on Listin~ hlumberger .Alaska Computi. n~ Center 30-0CT-~994 ~4:33 DEFI D~PT De~th NPHI Compensate~ Me~}tron Porosity, $8 Nat. rix, cal!& dead time corr, RTN~ ~aw Thermal Neutron Ratio TNR5 Thermal ~eutron Ratio Calibrated RCNT ~AW gE,AR CMT COUNTS RCFT RAW FA~ CNT COUNTS C~}TC Corrected ~ear Detector Count ~ate CFTC Corrected Far Detector Count Rate GP aPl-Corrected Gamma Pay TFNM surface Tension ** PATA. FORMAT SPECIF!C~T!UN RECORD ** I 66 0 2 66 0 3 73 44 I 66 5 66 6 73 7 65 8 68 0.5 9 ~ 5 1! 66 17 68 13 66 n 14 65 15 66 68 16 66 1 n ~6 mmmmmm~mmmmmmmmmmmmmmmmmmmmmmm NAgF S~RV UN VICE P PI AP1 A FIt, E . REPR ROCE$$ TO tINDER ~ bOG TYPF CLASS MOD NLJ~'B SAMP FLEM CODE '5;;; .................................................................................. ~.m ash670 oO OOO OO o 6 1 1 4 68 000~000000 M~i~I PS~ PU ,180670 O0 000 00 0 6 1 1 4 68 0000000000 RTNP PS2 a80670 00 U00 n0 O 6 1 i 4 68 0000000000 TNRA DS~ 4~0~70 O0 0OO 0O 0 6 1 1 4 68 000n000000 RCMT PS9 CPS A6o670 O0 000 00 0 6 1 1 4 6~ RCFT PS~ CPS ~0~70 00 000 0O o 6 1 I 4 6R 000000000o ~hlumberoer ^lasKa Comp~,~t. in~ Center 30-OCT-1994 14:33 a ~;i{V .......... 'VICE API P API A FILE B NUN8 SIZE REPR ~U ORDER ~ bOG TYPE CLASS ~OD NU~B SA~P Eb~,~ CODE CHEX) C~TC PS~ CPS 480670 O0 000 O0 0 6 ~ 1 4 68 0000000000 CFTC PS,~ CPS ~!80670 O0 000 O0 0 6 1 I 4 68 0000000000 G~ PS9 GAPI 480070 00 000 O0 0 6 I 1 4 68 0000000000 TF~!S P$~ ~,B 480,670 O0 000 00 0 f I 1 % 68 0000000000 CCD PS~ V ,48o6'70 00 000 00 0 6 I 1 4 68 0000000000 D~pT 9304.500 ~PHI'PS2 29.750 RT~R'PS2 ~ RCNT~PS2 ~287.3~6 ~CFT.PS2 686 606 CNTC.PS2 3~9~788336 CFTC.PS~TNR'~*PS~ GP.PS~ ],0,813 TENS.PS2 940~000 CCD.PS2 .000 059 TMR,A.P$~ 208 198 CFTC.PS2 0.000 5,01.4 656,843 7, 392 282:223 F!LF NA~E : EDTT ,006 SFRVICE : FDIC VERSION : 00!C01 DITF : q4/10/30 ~aX R~C S!Z~ : 10~4 FTLF '!'Y~E : !,O bAST FiLE : F?L? NA'~E : EOT'~ .0o7 8FRVICE : FLTC VFR$Ir~N : nO1. CO1 DATF : ~4/10/30 N~X RFC STZF : 10~4 FTbF TY~E : LD L~$T FIb~ : RaW CUkV~S Curves amd lo~ header ~ata ~or each mass in seDsrate DFPT?! I~JCRFi',~E~I:~: 0.5000 flles~ raw bacKmround oass in last fi i$ TaK~e V,rif{,catIon l.,lstin~ :hlumberger AlasKa ComPu. t, ino Center 30-OCT-~, 994 14:.33 2S # FIL~, SI, j NI,~ ARY VENDOR TOOL CODE $7,.'~!RT DE~TH C~TD ' 93 bOG HEADE~ DATA DATE LOGGED: SOFTWAR£ VERsIn':~: TI,~E LOG~ER ON TD D~ILLER {FT}: TD LOGGER {FT}: TOP [,,,0~ INTE~V~b (FI}: BOTTOm,,1 LOG .INTFRVAL fFT): LOGGING SPEED (FP~{~): DEPT~ CO~TROL !~$FD {YES/NO): TOOL ST~ING (TOP T0 BOTTO~} VEhDOR TOO[, CODE TOOL TYPE 32.6 11.16 9SO0.O 9430.0 8800.0 9300.0 ~, 800 0 NO 17-~AR-94 CNTD CNTD C ~TD C ,") T P $ AUXTI..,LIARY ~E~$1,1RFMENTS ATC CB 433 COMPENSATED NEUTRON CNC DA 10! COMPENSATED NEUTRON N6R I,A 3137 AIIXILI,,IARY ~C}DOLE AT~ 160 ~OREHOLE AN[) CASING DATA OPEN HObg BIT STZE (IN): DRILLERS C~SING DEPTN LOGGERS CASIWG D~PTH 8820.0 ln, 0 P E: ~.')01', E CONDITIO~iS FLI. JTD TYPE:: FLUID DENSITY (LB/G): S'.,IRWACE TF~PERATURE (DEGF): BOTTO'',~, HOI,E TF....~IPERATIJRE FLUID S~LI,~ITY (PPM): FS!iID LEVEL (FT) F!,UTD RATE ,~AT~R Ct]'rS (PCT) G~S/LJT[~ C~UKE CDEG) DF. AU CRUDE ~"EUTPO'! TOOL TOO!, TYPE (F,P_TTNEPMaL (.JP THERMAL): HOLF COPR~C~InN (IN): THF. R~AI, SAT'~DSTOD F. ? .65 BI.,UFLTNF. {'[]I!NT PATE I'!OR',:AI.,I%ATIOI',~ IN Oil, ZONE TOP NUR~'.',/~LTZI.NG Wlh~[)Ow (FT): tS Tape Yeti. fl, cation l..,istl, nq ~hlU~berger AlasKa ComDutt, no Center 30-OCT-1994 14;33 26 BL!~ELI~,!E COLI~,~'T ~ATE SC, ALES SFT BY FIELD ENGINE~ ~P COgeNT PATE LOW 8CAI,E (CPS)~ WA~ COUNT PATE HIGO SCALE ~E,~,R COU~,~T Ra, TE LOW SCAb~ (CPS): ~,~E,~,R COUNT .RAT~ ~IG~ SCALE (CPS)~ T[JOL STANIJ[]FF (IN): RF~ARKS: TIED INTO BNCS DATED 12-NOV-'I983 LOGGED PASS NO.], WHILE PUMPING AT 1,0 BPM (DEAD CRUDE), LOGGED PASS NO'2 AND ,NO,3 WRIbE PUMPING AT ,5 APPARF~T GOC AT 9096'. TAGGED PBTD AT 9430' LOGGED aLL PASSES AT"30 FPM. LIS FORMAT DATA TYPE : CC!MS TUNI VALU DEFI CN ARCO ~L.~$~A, INC. Company ~lame F~ PPUDHOE BAY wN DS 14-35 API~ 50-029-2101.8-o0 FL 3~3' FNL g 1218' FEL S~C? 9 C~U~ Nfl~TH SLOPE ~TAT N~'rI bSA W!T~' d. MEUSSE~ S~N 480670 PD.A? EPD FT O, L~F APD FT 69, EgG FT EDF FT EGL FT 39. TBD ~T T~L ~T 9~30. ~LI ~T 9300. T[~I ~7 8800. DFT D~AD CRUDE Field Name Well Name API Serial Number Field Location Section Township ~anGe County State or Province Nation Witness Name Serve. ce Order Number Permanent datum ~levatlon of Permanent Datum Log ~easured From ~ove Permanent Datum Elevation of Kelly ~UShin~ Elevation of Derrick Floor Elevation oi Ground Level Total De~tb - Dr~ller Total DePth - I.,ooger Botton: LDO I~terval ToD Log Interval Drllllno Fluid Type Tl~e Lo~er at Bottom '~ Ta.e Ver].f,i,,,cation Listin~,~ :hlumberger AlasKa Computing Center 30-OCT-!~994 14:33 T~BLE .TYP~,] : CU~V D F, F I '5~'"";;;[~'""'~ .......... '''''''''''''''''''''''''''''' N~HT Com;,ensated Neutron Porosl. t.y, SS ~atrix, call & ~ead time tort, RT~ ~aw Thermal Neutrom ~atlo TNRa Thermal ~eutron ~atio Calibrated RCNT D~W 51EAR CNT RCFT ~w FA[~ C~'T COUNTS C~TC Corrected. Near Detector Count Rate CFTC Corrected Far Detector Count Rate G~ aPI~Corrected Gamma TENS Surface Tension CCL CCL ,SmDlltude PA(~E: ¸27 ** DATb :FO)~A~ SPECIFTCATION ~ECOR[) ** SET TYPE T '¥ P E 1 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 ~I ll 66 23 12 68 ~3 66 0 14. ~5 WI 15 66 6b 1~ 66 1 0 66 !. ** SET TYPE - CHAN ** N~W $~'~V ll~: . E I PI AP1 APl FILE .tl~B NLI~B SIZE ~EPR R ESS TD ORDE~ ~ bOG TYPE CLASS ~UD NU~B SAMP EbFa CODE (HEX) mmmmmm~m~m~m~mm~~~m~m~~mmm~m~~m~mmm~mmm~m~m~mmm~mmmm~m~m~ DFPT FT 4~067(J O0 000 nO O 7 1 1 4 68 000fi000000 NPHT PS3 p~t 480676 nO 00O 00 O 7 1 1 4 68 0fi000~0O00 RTNP DS3 480670 m0 000 00 0 7 1 1 4 68 O000000O00 TNRa P53 48067(; a0 000 00 0 7 1 1 4 68 0000OD0000 ReNT PS3 CPS 480670 DO 00O a0 0 ~ I 1 4 6~ 0000000000 RCF· PS~ CPS 480670 00 UO0 O0 0 7 1 1 4 68 0000000000 :hlumberger Alaska Comput.~.na Cent;er 30-OCT-~994 14:33 PA~E: 28 NA.M~ SFRV UN $~PVICF PI AP A API FILE NUMB M ~B SIZE R, ,PROC TP O~DER ~ hOG TYP~ CbA$$ MOD NUMB SAMP ~LEM CODE (HEX) CNTC P$3 CPS 480670 O0 000 O0 0 7 ! 1 4 68 O0000OO000 CFTC P83 CPS 480670 00 000 O0 0 7 I 1 4 68 0000000000 G~ P$3 GIPI 4806?0 O0 000 00 0 ? 1 I 4 6~ 0000000000 TENg P$.3 hB 4006?0 O0 000 O0 0 ? 1 1 4 68 0000000000 CC~ PS3 V 480670 O0 000 00 O 7 1 1 4 68 0000000000 DEPT. 9305.000 MPMI.PS3 RCNT.PS3 :3200.000 ~CFT.PS3 G~.P$3 ~8'078 TEM$.PS3 28.714, RTMR.PS3 685.714 CNTC.PS3 1020.000 CCh. PS3 4.667 TN,RI.PS3 3205 792 CFTC.PS3 0~000 4.887 655.990 ** END (IF ~ATA ** **** FILE TR~ILEP **** SERVICE : ~b!C VFR$iON : O01Cnl. D~'rF : Oq/lO/30 M~X REC $IZ~ : 1024 F?bF TYPE ! LO LaST FILE : S~RVICE N~M~ : EDIT DtTF : 94/10/30 O~ICI~ : FLIC T~PF NAU~ : qql, 88 PPEVIOU$ TAPE C~MuE~II' : ~RCLI ALASKA INC., PRI.!D~OE RAY, DS ~4-35, 500~9~101800 SFRVICE ~,~M~ : EDIT D~T~ : o4/10/30 OPlGI~~ : FblC CO~TIt,]LJaTTOM ~ PREVInoS PE~L : CO~E~'!.' : APCU A~,ASKa INC., PRf]D~OE ~g¥, DS ~4-35, 500~9210ig00 LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO AlaSka, !nc. Well D.S. 14-35 Field ?rudhoe Bay ~. County, S~a~e North Slope, Al~s~~ Cu.~ve Name (Abbrev.) ECC $ 2166 Date 5/!1/85 Standard' Curve Name-'~'% Lozs Used Scale } .... File~ 1-3 · - . · CCL ! Casimg Collar Loca:or ' ' CN - M~i:iSP'ace· · --~-- i CN : I Compensated Neutron " 60 - 0 SSN i Short Soace " ' , - 5O - 550 LSN i~ Long Space. " 0 - 200 i ,, GR ~ Gamma Ray- 0 - 100, 100 - 200 , File 4 -, CNAV . Average CN " 60 - 0 .: I . . t I-' ' I I * REEL HEADER ** EEL NAME : ATE : ~RIGIN : FSY$ _ERVICE NAME: B!TLIS EEL CONTINUAT!OE NUMSER: O1 ~REVIOUS REEL NAME : -OMMENTS: DRESSER ATLAS LIS CUSTOMER TAP: --- CRESTEC BY SDS PROGRAM R 2.0 _ENGTH: 132 5YTES -* TAPE HEADER ** -APE NAME : :'ATE : SRZGIN : FSYS SERVICE NAME: PASS 1 TAPE CONTINUATION NUMBER: O1 ;REVIOUS TAPE NAME : AOMMENTS: LENGTH: 132 BYTES ** ~ILE HE~DER ~ I ~* :ILE N~ME: P~SS 1,001 SERVIC= NAME: VERSION # : 1 ~T~: ~5/11/20 ~AX RECORD LENGTh: 1024 BYTES FZLE TYPE: LC PREVIOUS FiLE NAME: . ** ZNFCRMATIC'N RECOPDS ** MNEM~ONTENTS APZN : 500~;21C18 CN : ARCO ~L~SKA, ~NC. WN : D.S. !~-35 ~N : PPUDHOE B~Y rOUN~ : N~RT~u ~cLOp~ STAT : AL~$K~ LCC : 150,00 ** FORM~.T ** UNITS ENTRY BLOCKS TYPE ENTRY ~ESCRZPTION ' 4 9 0 IIlIIIIi i i I !I I II ! ! i I BEPTHS DECREASE 6C,0 FRA~ SPACING .lin F~A~ SP~CING UNITS 51 MAXIMUM FRAMeS/RECORD TER~ZNATOR O.Em0 L~VEL SPACING -- ~ ,- A,.ON BLOCKS DATUM Sm'CIFIC ~ ~ME CODE SIZE SAMPI~- LNITS SN ~ 68 4 I CPS SN 68 4 I CPS 'R 68 4 I APi 'CL 68 4 1 DIM ~_N 68 4 1 LBF ~D 68 4 I F/MN N 68 4 1 % FORMAT ** ENTRY BLOCKS '¥P~ ENTRY DESCRIPTION ___ 4 I CEPTHS ~ECRE~SE 8 60,0 FRAHE SFACING 9 ,lIN FRAME SPACING UNITS 11 31 MAXIMUM FRAMES/RECORD 0 TERFINATOR -0,500 LEVEL SPACING ].~TUM SPECIFICATION BLOCKS -URVE REPR '~AHE CODE SIZE SAMPLE UNITS llll llli _SN 68 4 I CPS SSN 68 4 I CPS -R 68 4 1 ~pT~ COL 68 4 I DiM TEN 68 4 1 LSF $PD 68 4 I F/MN CN 68 4 1 % ** DAT& ** 3EPTH 9470.000 ST 2556.4620 M LSN 74,9~2 SSN TEN 85,391 ~EPTH o400. · ._uun~ FT -- ImmIm-- mImmmm m i LSN ~0,1~5 TEN 28,177 ~EPT~ 9300.C00 FT I -- -- ii m I ii -- m i-- -- i LSN 52.135 TEN -25.1 80 226,977 25,9~7 m$65 126~ ~ ~ - SSN 170.391 SPD 28.201 2834,6460 M SSN 180.122 SPD 28,529 OEPTH 9200.C00 FT 2804.166C M LSN 98,415 SSN 242,~7 TEN -28.343 SPD 27,934 DEPTH 9100,CC0 FT 2773.6850 M III/--IIi--lm--IIIIIIIIIiIIiIm~---- LSN 108.112 SSN 283.430 TEN -26,407 SPD 28,697 DEPTH 9000.C00 FT 2743.2060 M __ GR CN CN GR CN GR CN GR CN 699 28.~17 15.2~2 34,714 13,154 22.270 21,773 24.073 CCL CCL CCL CCL CCL I~.COC 13.000 13.000 15.000 83.000 ~S.~- 75.295 SSN "~-'" 242.056 'EM '-35.159 - SPO 25.699 GR CN -EPTH 8900.C00 FT 2712.7260 H SN 54.C83 SSN 214.C67 ~EN -22.293~ SPO 27.581 GR CN "EPTH 8878.5C0 FT 2706.172C M _SM 49.435 SSN TEN -13.511 SPD 214.245 GR 27.971 CN ~TARTING DEPTH = 9470.000 FT ~NDiNG DEPTH = 8878.500 FT Z886.4620 2706.1720 '* FZLE TRAILER ** :iLE NAME: PASS 1.001 }ERViCE NAME: VERSION # : 1 ~ATE: 85/11/ 2AXIMUM LENGTH: 1024 =ILE TYPE: LO '~EXT FILE NAME: ~ FILE HEADER # 2 :!LE NAME: PASS 3.002 S;RVICE NAME: 'VERSION # : 1 bATE: 85/11/20 ~AX RECORD LENGTH: 1~24 :iLE TYPm: LO ~REVIOUS FILE N~ ' ~, IN=OR~ATICN, . RECORDS, ~ ** ~YTES MNEM CONTENTS --~m APIN : 5002g~1£18 CN : A~CC ~L~SKA, WN : D.S. 14-35 FN : PRUgPOE 5~Y COUN : NORTH SLOPE STAT : ALASKA LCC : 150.00 '* ~ORMAT ** INC. UNITS ENTRY BLOCKS TYPE ENTRY 4 1 8 6C.0- 9 .lIN 11 31 O -0.500 DESCRIPTION D:PTHS DECREASE FRAME SPACING FRAME SPACING UNITS MAXIMUM FRAMES/RECORD TERmiNATOR LEVEL SPACING 23.12~-~- 31 .37 22C.1C? 42.295 12C.034 48.553 CCL CCL CCL 13.000 13.000 17.000 2ATUM SPECIFICATION BLOCKS NAME CODE $1Z~ SAMP"~'" LSN 68 4 1 SSN 68 4 1 GR 68 4 1 CCL 68 4 1 TEN 68 4 1 SPD 68 4 1 CN 68 4 1 ** FORMAT ** UNITS CPS CPS API DIM LBF FINN % ENTRY BLOCKS TYPE ENTRY DESCRIPTION 4 I DEPTH 8 6C.0 FRAME 9 .lIN FRAME 11 31 MAXIM 0 TERNI -0.5C0 LEVEL S DECREASE SPACZNG SPACING UNITS UM FRAMES/RECORD NATOR SPACING ~'~TUM SPECTFICATION.. mLO"~KS CURV$ REPR NAM= CODE SiZ~ SAMPLE UNITS LSN 68 4 1 CPS SSN 68 4 I CPS GR- 6~ 4 I ~Pl CCL 68 4 1 DIM TEN 68 4 1 LBF SPD 68 4 1 F/MN CN 68 4 I % DATA ** ~EPTH 9473.F00 FT ~887 ~76C M LSN 66.993 SSN 227.977 TEN -?~ 1~3 SDD O.~uO DEPTH 94C0.C00 FT 2865.126C M ~ - LSN 41.7~3 SSN 166.4C4 TEN 35.1 53 SDD 21 ~rEmTH. 9~C0., - · CC'"',-' r-T _P,~34~ . 6&6P., M, LSN 52.625 SSN TEN -21 .~.56 SPD 17.$.7S3 19.747 DEPTH 9200.CC0 FT LSN 106.940 SSN TEN -9.C84 SPD 2804,166C M 256.22/+. 18.589 Dr-PTH 9100.CC0 FT 2773.686C- M LSN 87.121 SSN TEN -26.976 SPD 267,093 18.971 CN ~R C N GR GR CN GR CN 2c .704 33.Q46 ~C.052 21 .7~0 Z_,-. 878 25.7CC 21.394 25.596 29.324 CCL CCL CCL CCL CCL 11 . 0 "" '"' 16.000 13.000 DEPTH 9CCO.CCO FT 2743.206C M _SN ?Z. 0'~6 SSN ~, 241.807 · -EN -46.103 SPD 15.6.42 =PTH 8G00.CC0 FT 2712.726:C M GR 52.137 SDN 213.315 -37.439 DPD 16.576 CN ~5~T~-,, ~,.,.,~1.5C0 FT 2707.0P7C,, M _SN 53.582 SSN TEN -40.111 SPD 21'9.14:3 GR 20.552 CN STARTING DEPTH, = 9473.v~'00 ET :NDING DEPTH = 8581.500 FT 2887.3760 2707.0870 -* FiLE TRAiLEm ** =iLE NAME: P~SS ~.002 SERVICE NAM$: VERSION # : 1 DATE: ~5/11/ ~'~AXI~UM LENGTH: 1024 =ILE TYPE: LO NEXT FILE N~NE: ~* TSPE TRAILER ** T&PE NAME: S=RVICE N~ME: PASS C~TE: ORIGIN OF D~T~: =SYS TAPE CONTINUATION NEXT TAPE N~FE: CO¢~ENTS: "1 *~ R:EL TR REEL N~ME: ~=RVI~ ~T: : ~tCiN OF RE;L CONTI %EXT ~EL COMHENTS: TAPE ~EA~E iNFOR~TZO FORMAT ~.AT~ - TAELE Dump - =ZLE TR~ZLE~ - TAP= TR~ZL=R - REEL TRAILER - :~E: BiTLZS D~:~ FSYS NU~T'ON ' N~E: DRESSEE R - R - N - : 01 ATLAS ! 1 2 2 ! 7~ 2 2 1 1 LiS CUSTCM:R T~P: t - 26.34-~---. 33.3~ 117.62C 44.348 91.2E:2 44.321 CCL CCL CCL SPE,'T=3. - -¥ ,;c3S 14.000 31 .000 2.0 TOT2L R=CORDS: 94 JUN £4 .............................. ,~a~a ,~t~ & Gas (Jon~. ~}mml~.~tO~ * ~S~ COMP~ING C~ER * * ............................ * * ....... S~L~ERGER ....... * * ............................ * COMPANY NAF1E : ARCO ALASKA, INC. WELL NAM~ : D . S . 14-35 FIELD NAM~ : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : AK API NUM~F2~ : 500292101800 REFERENCE NO : 98268 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: **** REEL~ER **** SERVICE NA~IE : EDIT DATE : 98/06/24 ORIGIN : FLIC REEL NAME : 98268 CONTINUATION # : PREVIOUSREEL : COF~T : ARCO ALASKA, DS 14-35 , PRUDHOE BAY, API #50-029-21018-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/06/24 ORIGIN : FLIC TAPE NAME : 98268 CONTINUATION # : 1 PREVIOUS TAPE : COf4FIENT : ARCO ALASKA, DS 14-35 , PRUDHOE BAY, API #50-029-21018-00 TAPE HEADER Prudhoe Bay CASED HOLE WIRELINE LOGS WELL NA~E: D.S. 14 -35 API NUFI~ER: 500292101800 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 24-JUN-98 JOB !973-M~ER: 98268 LOGGING ENGINEER: C Yon OPERATOR WITNESS: S Schudel SURFACE LOCATION SECTION: 9 TOWNSHIP: 1 ON RANGE: 14E FNL: 313 FSL: FEL: 1218 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 69. O0 DERRICK FLOOR: 68. O0 GROUND LEVEL: 39. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 9500.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUM~ER: DATE LOGGED: 12-NOV-83 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH RST 88888.0 88887.0 88889.0 9286.5 9287.5 9286.0 9285.0 9284.0 9285.0 9283.0 9280.5 9279.0 9277.5 9274.0 9273.5 9271.0 9270.0 9267.5 9267.0 9266.0 9267.5 9264.5 9263.5 9263.0 9263.5 9253.5 9253.0 9252.0 9253.0 9246.5 9246.0 9244.0 9243.5 9242.5 9242.0 9241.0 9242.0 9237.5 9237.0 9235.0 9237.0 9230.0 9229.5 9226.5 9224.5 9220.5 9219.5 9214.0 9213.5 9211.0 9211.5 9209.5 9209.5 9209.5 9206.5 9206.5 9198.0 9198.5 9196.5 9196.5 9194.0 9194.0 9193.0 9194.0 9186.0 9186.0 9185.5 9186.0 9184.5 9184.0 9182.5 9183.5 9182.0 9181.5 9179.5 9179.5 9180.0 9177.0 9177.0 9175.0 9176.5 9172.0 9170.5 9169.0 9167.5 9167.5 9164.5 9166.0 9163.0 9163.5 9161.0 9159.0 9159.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9158.5 9158.0 9157.0 9156.0 9152.5 9151.0 9147.0 9145.5 9144.0 9140.0 9138.0 9136.0 9131.5 9129.5 9129.0 9128.0 9125.5 9124.5 9121.0 9119.5 9116.0 9115.0 9112.5 9109 5 9108 0 9107 0 9104 5 9102 0 9097 5 9094 0 9093 5 9090 0 9085 0 9084 0 9082 0 9081 0 9078 0 9072 5 9071 5 9069 0 9065 5 9061 0 9059.0 9054.0 9053.0 9050.0 9047.0 9044.0 9043.0 9038.0 9036.0 9034.0 9032.0 9027.0 9025.5 9021.5 9157.0 9155.5 9153.0 9150.5 9147.5 9144.0 9141.5 9130.0 9127.5 9125.5 9123.0 9120.0 9115.0 9112.0 9109.0 9107.5 9102.5 9097.0 9093.5 9089.5 9083.5 9081.5 9077.0 9071.5 9065.0 9059.5 9054.0 9049.5 9047.5 9044.0 9039.0 9036.5 9035.0 9033.5 9026.5 9021.5 9159.0 9157.5 9146.0 9138.5 9136.0 9133.0 9129.5 9125.5 9120.0 9115.0 9109.0 9104.0 9097.0 9094.5 9084.0 9082.0 9073.0 9070.0 9062.0 9054.0 9044.0 9026.5 24-JUN-1998 12:07 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 9018.0 9018.0 9016.5 9016.5 9014.5 9013.5 9013.0 9013.0 9007.5 9007.5 9004.0 9003.5 9003.0 9003.5 9001.5 9000.5 8998.5 8998.0 8998.0 8998.0 8992.0 8992.0 8990.5 8990.0 8989.5 8990.0 8987.0 8987.0 100.0 100.0 100.5 CONTAINED~IN IS THE LDWG FORMATTED CASED HOLE RST DATA AQUIRED ON ARCO'S DS 14-35 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE BCS GAMMA RAY, ALSO BASE PASS #1 SIGMA AND THE BCS GAM~ARAY, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ $ PAGE: **** FILE~ER **** FILE NAFIE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILEHEADER FILE1VUFiBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFIBER : 1 DEPTH INCREFIENT: 0.5000 FILE SURFiARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9287.0 8985.0 RST 9300.0 8985.5 $ CURVE SHIFT DATA - PASS TO PASS (FiEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUFIBER: LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST RE~a2?3~: THIS FILE CONTAINS CASED HOLE RST BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 NBAC RST CPS 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC RST CPS 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 SBNA FIL CU 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 SFNA FIL CU 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 SBFA FIL CU 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 SFFA FIL CU 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 TI?AT FIL 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 IRAT FIL 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 CIRNFIL 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 CIRF FIL 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: NAFIE SERV UNIT SERVICE API API API API FILE N731~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) BSALRST PPK 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 SIBF RST CU 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI RST PU-S 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 SFFC RST CU 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 SFNC RST CU 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM RST CU 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 DSIG RST CU 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 GRCHRST GAPI 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 TENS RST LB 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 CCL RST V 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 CRRARST 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 FBEF RST UA 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1160739 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9320.000 NBAC. RST -999.250 FBAC. RST -999.250 SBNA.FIL SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST SIBF. RST -999.250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC.RST SIGM. RST -999.250 DSIG.RST -999.250 GRCH.RST -999.250 TENS.RST CCL.RST -999.250 CRRA.RST -999.250 FBEF. RST -999.250 GR.BCS DEPT. 8970.000 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.FIL SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST SIBF.RST -999.250 TPHI.RST -999.250 SFFC. RST -999.250 SFNC.RST SIGM. RST -999.250 DSIG.RST -999.250 GRCH. RST -999.250 TENS.RST CCL.RST -999.250 CRRA.RST -999.250 FBEF.RST -999.250 GR.BCS -999.250 -999.250 -999.250 -999.250 -999.250 60.000 -999.250 -999.250 -999.250 -999.250 -999.25O 39.031 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AU3FiBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER: 2 DEPTH INCREMeNT: 0.5000 FILE SUF~L~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9289.5 9000.0 RST 9299.5 8999.5 $ CURVE SHIFT DATA - PASS TO PASS (MEAS~ DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASSNUFiBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH RST 88888.0 88889.5 88888.5 9294.5 9295.0 9291.0 9292.0 9284.0 9285.0 9283.5 9285.0 9280.0 9281.5 9278.0 9279.0 9275.5 9275.0 9274.0 9275.0 9272.0 9270.5 9271.0 9272.0 9268.0 9269.5 9264.0 9263.5 9263.0 9263.5 9254.0 9253.5 9243.5 9244.0 9242.5 9242.0 9237.5 9237.0 9235.0 9237.0 9231.5 9233.5 9228.5 9230.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 9228.0 9225.0 9225.0 9226.5 9221.5 9221.5 9216.5 9217.0 9215.0 9213.5 9214.5 9215.5 9211.0 9211.5 9208.5 9209.0 9204.0 9204.5 9200.0 9199.0 9198.0 9198.5 9196.0 9196.0 9194.5 9194.0 9194.0 9194.0 9192.5 9192.5 9188.0 9188.5 9186.0 9186.0 9182.5 9183.5 9180.0 9179.5 9179.5 9180.5 9176.0 9177.0 9175.0 9176.5 9174 . 0 9175.0 9172.0 9173.5 9172.5 9165.5 9167.0 9163 . 0 9163 . 5 9160.5 9161.0 9160.0 9160.5 9157.5 9157.0 9157.0 9157.5 9152.5 9153.0 9150.5 9150.5 9148.5 9149.0 9147.5 9147.5 9146.0 9146.5 9144.0 9144.0 9142.5 9143.0 9140.5 9142.0 9138.0 9138.5 9137.0 9138.0 9134.0 9134.5 9132.5 9133.0 9132.0 9133.0 9130.0 9130.0 9129.0 9129.5 9125.5 9125.5 9124.5 9125.5 9120.5 9120.0 9119.5 9120.0 9116.5 9115.0 9116.5 9112.0 9112.5 9112.5 9109.5 9109.0 9108.0 9109.0 9103.5 9103.5 9101.5 9103.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 9098.5 9099.0 9098.0 9097.5 9097.5 9097.0 9094.0 9094.5 9093.5 9093.5 9092.5 9092.5 9089.0 9089.0 9088.5 9088.5 9086.5 9086.0 9085.0 9084.0 9084.0 9083.5 9081.0 9082.0 9077.5 9077.0 9077.0 9078.0 9073.5 9073.5 9072.5 9073.0 9069.0 9070.0 9068.5 9068.0 9065.0 9065.0 9059.5 9060.5 9057.0 9057.0 9056.0 9056.5 9055.5 9055.5 9054.5 9055.5 9051.5 9051.5 9050.0 9049.5 9051.0 9046.5 9047.0 9045.0 9046.0 9043.5 9044.0 9040.0 9041.0 9039.5 9039.0 9037.5 9038.0 9033.5 9033.5 9031.5 9031.0 9029.0 9028.5 9026.5 9026.0 9024.0 9023.5 9020.5 9020.0 9015.5 9016.0 9014.0 9013.5 9012.5 9013.0 9009.0 9008.5 9004.0 9003.5 9003.5 9003.5 100.0 100.0 99.5 REM3LRKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 10 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELI~4 CODE (HEX) DEPT FT 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 CIRNFIL 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 BSALRST PPK 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 SFFC RST CU 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM RST CU 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST CU 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 CRRARST 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 1160739 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 11 ** DATA ** DEPT. 9299.500 NBAC. RST 2312.121 FBAC. RST 3040.960 SBNA.FIL SFNA.FIL 19.636 SBFA.FIL 45.571 SFFA.FIL 17.469 TRAT.FIL IRAT. FIL 0.487 CIRN. FIL 1.092 CIRF. FIL 2.436 BSAL.RST SIBF.RST 40.614 TPHI.RST 24.751 SFFC. RST 14.853 SFNC.RST SIGM. RST 14.836 DSIG.RST 0.632 GRCH.RST -999.250 TENS.RST CCL.RST 0.001 CRRA.RST 2.071 FBEF. RST 64.489 DEPT. 8999.500 NBAC. RST 2372.014 FBAC.RST 2997.292 SBNA.FIL SFNA.FIL 17.472 SBFA.FIL 36.963 SFFA.FIL 15.442 TRAT. FIL IRAT. FIL 0.517 CIRN. FIL 1.323 CIRF. FIL 2.990 BSAL.RST SIBF. RST 27.886 TPHI.RST 17.037 SFFC. RST 12.594 SFNC.RST SIGM. RST 12.568 DSIG.RST -0.205 GRCH. RST -999.250 TENS.RST CCL.RST -0.003 CRRA.RST 1.909 FBEF. RST 61.847 56.070 0.919 52.321 15.076 1442.000 50. 013 0.848 16. 610 11. 924 1385. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~4E : EDIT .003 SERVICE . FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFIBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER: 3 DEPTH INCREMENT: 0.5000 FILE SUB, VARY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 12 GRCH 9288.0 9030.0 RST 9300.5 9030 . 0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH RST 88888.0 88888.0 88889.5 9293.5 9295.0 9286.5 9288.0 9283.5 9285.0 9283.0 9283.0 9280.0 9281.5 9277.5 9279.0 9262.5 9263.5 9253.0 9253.5 9244.5 9246.0 9243.0 9244.0 9241.0 9242.5 9235.5 9237.0 9235.0 9237.0 9231.0 9233.0 9228.5 9230.0 9224.5 9226.0 9218.5 9219.5 9210.5 9211.5 9208.5 9209.0 9208.0 9209.5 9206.0 9207.0 9203.0 9204.0 9198.0 9198.5 9197.0 9197.0 9194.0 9194.5 9187.0 9187.5 9186.5 9186.0 9182.5 9183.5 9179.5 9179.5 9179.0 9180.0 9174.5 9176.5 9168.5 9169.5 9164.0 9165.0 9159.5 9159.0 9153.0 9153.0 9148.5 9148.5 9148.0 9150.5 9142.5 9144.0 9142.5 9141.0 9142.0 9129.5 9130.0 9128.5 9129.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 13 9126.0 9126.0 9114.0 9115.0 9112.5 9112.5 9109.0 9109.0 9108.0 9109.5 9104.0 9104.0 9102.0 9101.5 9095.5 9096.5 9095.0 9094.5 9094.0 9094.5 9092.0 9092.5 9088.5 9088.0 9088.0 9089.0 9086.5 9086.0 9084.5 9084.0 9081.5 9082.5 9077.5 9077.0 9072.0 9073.0 9070.0 9070.0 9069.5 9070.0 9067.5 9068.5 9065.0 9066.5 9061.5 9062.0 9055.5 9055.5 9055.0 9055.5 9053.0 9054.0 9049.5 9051.5 9047.0 9047.0 9044.0 9044.0 9043.0 9044.0 9040.0 9041.0 9031.0 9031.0 100.0 100.0 100.0 $ RE~zAPJfS: THIS FILE CONTAINS CASED HOLE RST BORAX PASS #1. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCHBORAXPASS #1 AND GRCHBASE PASS #1, ALSO SIGMA BORAX PASS #1 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 14 TYPE REPR CODE VALUE 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUmB SAMP ELE~ CODE (HEX) O0 000 O0 0 3 1 1 4 68 0000000000 DEPT FT 1160739 NBAC RST CPS 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA FIL CU 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA FIL CU 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 SBFA FIL CU 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA FIL CU 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT FIL 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT FIL 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 CIRNFIL 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 CIRF FIL 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 BSALRST PPK 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RST CU 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RST PU-S 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RST CU 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 SFNC RST CU 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM RST CU 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RST CU 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH RST GAPI 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 TENS RST LB 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 CCL RST V 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 CRRARST 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 FBEF RST UA 1160739 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 15 DEPT. 9300.500 NBAC.RST SFNA.FIL 20.072 SBFA.FIL IRAT. FIL 0.485 CIRN. FIL SIBF.RST 43.190 TPHI.RST SIGM. RST 14.755 DSIG.RST CCL.RST 0.006 CRRA.RST DEPT. 9030.000 NBAC.RST SFNA.FIL 14.171 SBFA.FIL IRAT. FIL 0.513 CIRN. FIL SIBF. RST 89.755 TPHI.RST SIGM. RST 12.100 DSIG.RST CCL.RST -0.375 CRRA.RST 2986.913 FBAC.RST 49.559 SFFA.FIL 1.091 CIRF. FIL 25.676 SFFC. RST 0.747 GRCH. RST 2.060 FBEF. RST 2930.916 FBAC.RST 66.798 SFFA.FIL 0.766 CIRF. FIL 12.178 SFFC.RST -0.721 GRCH. RST 1.906 FBEF. RST 3255.580 17.297 2.446 14.772 -999.250 67.301 3125.992 13.536 2.297 12.032 204.487 63.152 SBNA. FIL TRAT. FIL BSAL. RST SFNC. RST TENS. RST SBNA. FIL TRAT. FIL BSAL. RST SFNC. RST TENS. RST 54. 980 O. 924 59. 365 15. 718 1698. 000 87.842 0.652 177.398 11.590 1678.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUF1BER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFIBER: 4 DEPTH INCREmENT: 0.5000 FILE SUF~NL~Y LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 9286.5 9022.0 RST 9300.0 9022.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 16 CURVE SHIFT DATA - PASS TO PASS (FiEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS ~ER : 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH RST ............................ 88888.0 88886.5 88889.0 9286.5 9287.5 9283.5 9285.0 9282.5 9281.0 9280.0 9281.0 9277.5 9279.5 9267.5 9269.0 9265.0 9263.5 9262.5 9263 . 5 9254.0 9253.0 9253.5 9253.5 9243.5 9244.0 9235.0 9237.5 9233.0 9233.5 9217.5 9216.5 9214.5 9215.5 9210.5 9211.5 9206.0 9205.5 9205.0 9205.0 9194.0 9194.0 9187.0 9187.5 9186.5 9186.0 9185.0 9184.0 9180.0 9179.5 9179.0 9180.0 9174.5 9176.5 9168.5 9170 . 0 9164.5 9165.5 9157.0 9157.0 9155.5 9154.5 9152.5 9153.0 9149.0 9148.5 9144.0 9144.0 9143.5 9144.0 9142.5 9142.5 9132.0 9133.0 9129.0 9129.5 9123.0 9122.0 9114.0 9115.0 9112.0 9112.0 9109.0 9109.0 9108.0 9109.5 9102.0 9101.5 9100.0 9099.5 9098.5 9099.0 9095.5 9095.0 9088.5 9088.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 17 9084.5 9084.0 9080.5 9079.5 9079.0 9080.0 9072.0 9073.0 9070.0 9070.0 9069.0 9070.0 9068.0 9068.0 9061.5 9061.5 9053.0 9054.0 9047.0 9047.0 9044.5 9044.0 9043.0 9044.0 9040.5 9041.0 9031.0 9031.0 9026.5 9026.5 100.0 100.0 100.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE RST BORAX PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCHBORAX PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 18 ** SET TYPE - CHAN ** ....................................................................................... NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) ....................................................................................... DEPT FT 1160739 O0 000 NBAC RST CPS 1160739 O0 000 FBAC RST CPS 1160739 O0 000 SBNA FIL CU 1160739 O0 000 SFNAFIL CU 1160739 O0 000 SBFA FIL CU 1160739 O0 000 SFFA FIL CU 1160739 O0 000 TRAT FIL 1160739 O0 000 IRAT FIL 1160739 O0 000 CIRNFIL 1160739 O0 000 CIRF FIL 1160739 O0 000 BSAL RST PPK 1160739 O0 000 SIBF RST CU 1160739 O0 000 TPHI RST PU-S 1160739 O0 000 SFFC RST CU 1160739 O0 000 SFNC RST CU 1160739 O0 000 SIGMRST CU 1160739 O0 000 DSIG RST CU 1160739 O0 000 GRCHRST GAPI 1160739 O0 000 TENS RST LB 1160739 O0 000 CCL RST V 1160739 O0 000 CRRARST 1160739 O0 000 FBEF RST UA 1160739 O0 000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9300.000 NBAC.RST 2888.948 FBAC. RST SFNA.FIL 19.421 SBFA.FIL 50.045 SFFA.FIL IRAT. FIL 0.490 CIRN. FIL 1.098 CIRF. FIL SIBF.RST 40.235 TPHI.RST 24.422 SFFC. RST SIGM. RST 14.632 DSIG.RST 0.484 GRCH.RST CCL.RST 0.014 CRRA.RST 2.072 FBEF. RST DEPT. 9022.000 NBAC.RST 2858.656 FBAC.RST SFNA.FIL 13.252 SBFA.FIL 61.352 SFFA.FIL IRAT. FIL 0.534 CIRN. FIL 0.866 CIRF. FIL SIBF. RST 92.428 TPHI.RST 14.452 SFFC. RST SIGM. RST 11.614 DSIG.RST -0.731 GRCH. RST CCL.RST 0.004 CRRA.RST 1.927 FBEF. RST 3270 945 17 260 2 439 14 643 -999 250 67 527 3325.952 12.913 2.349 11.561 91.409 63.371 SBNA. FIL TRAT. FIL BSAL. RST SFNC. RST TENS. RST SBNA.FIL TRAT. FIL BSAL.RST SFNC.RST TENS.RST 55.368 0.915 51.278 14.839 1673.000 82.841 0.688 183.645 11.057 1578.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 19 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE . FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION : 001C01 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUBIBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER: 5 DEPTH INCREFIENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9287.5 9019.5 RST 9300.0 9020.0 $ CURVE SHIFT DATA - PASS TO PASS (FIEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUf4~ER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH RST 88888.0 88887.5 88889.0 9286.5 9287.5 9284.0 9285.5 9281.0 9280.5 9278.0 9277.5 9279.0 9267.0 9268.5 9263.0 9263.5 9262.0 9263.5 9256.5 9257.0 9255.5 9255.5 9253.5 9253.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 2O 924 6.5 924 7.5 9245 . 0 9246.5 9244.0 9244.0 9241.0 9242.5 9242.0 923 6.0 9237.5 9235.5 923 7.0 9229.5 923 O. 0 9224.5 9226.0 9223.5 9224.5 9217.5 9219.0 9215 . 0 9215.5 9210.5 9211.5 9208.5 9209.0 9207.5 9206.0 9204.5 9204.0 9199.5 9199.5 9197.5 9197.0 9194.0 9194.5 9186.5 9186.0 9182.5 9183.5 9180.0 9179.5 9175.0 9176.5 9172.0 9172.0 9168.5 9169.5 9165.5 9166.5 9164.5 9166.0 9163.0 9163.0 9159.5 9160.0 9159.0 9159.0 9157 . 5 9157.5 9153.0 9153.0 9149.0 9148.5 9144.5 9144.5 9144.0 9144.0 9142.5 9142.5 9140.5 9142.0 913 6.0 913 6.5 9132.0 9132.5 9129.5 9130.0 9129 . 0 9129 . 5 9125.0 9125.5 9123.0 9122.0 9116.0 9117.0 9113.5 9115.0 9112.0 9112.5 9109.0 9109.0 9108.5 9109.5 9104.5 9104.0 9102.5 9102.0 9102.0 9101.5 9099.5 9100.0 9095.5 9095.0 9094.0 9094.5 9088.5 9088.0 9087.0 9086.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 21 9084.5 9084.5 9078.5 9080.0 9077.5 9076.5 9074.5 9075.5 9069.0 9070.0 9068.5 9068.5 9061.5 9062.0 9059.5 9060.5 9053.0 9054.0 9051.5 9053.0 9052.0 9048.0 9047.0 9045.0 9045.5 9044.5 9044.0 9043.0 9043.5 9040.5 9041.0 9036.5 9037.5 9033.5 9033.0 9031.0 9031.0 100.0 99.5 100.0 IAEMARJfS: THIS FILE CONTAINS CASED HOLE RST BORAX PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 22 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUFIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELb~4 CODE (HEX) DEPT FT 1160739 O0 000 O0 0 5 1 1 4 68 NBAC RST CPS 1160739 O0 000 O0 0 5 1 1 4 68 FBAC RST CPS 1160739 O0 000 O0 0 5 1 1 4 68 SBNA FIL CU 1160739 O0 000 O0 0 5 1 1 4 68 SFNA FIL CU 1160739 O0 000 O0 0 5 1 1 4 68 SBFA FIL CU 1160739 O0 000 O0 0 5 1 1 4 68 SFFA FIL CU 1160739 O0 000 O0 0 5 1 1 4 68 TRAT FIL 1160739 O0 000 O0 0 5 1 1 4 68 IRAT FIL 1160739 O0 000 O0 0 5 1 1 4 68 CIRNFIL 1160739 O0 000 O0 0 5 1 1 4 68 CIRF FIL 1160739 O0 000 O0 0 5 1 1 4 68 BSAL RST PPK 1160739 O0 000 O0 0 5 1 1 4 68 SIBF RST CU 1160739 O0 000 O0 0 5 1 1 4 68 TPHI RST PU-S 1160739 O0 000 O0 0 5 1 1 4 68 SFFC RST CU 1160739 O0 000 O0 0 5 1 1 4 68 SFNC RST CU 1160739 O0 000 O0 0 5 1 1 4 68 SIGM RST CU 1160739 O0 000 O0 0 5 1 1 4 68 DSIG RST CU 1160739 O0 000 O0 0 5 1 1 4 68 GRCH RST GAPI 1160739 O0 000 O0 0 5 1 1 4 68 TENS RST LB 1160739 O0 000 O0 0 5 1 1 4 68 CCL RST V 1160739 00 000 O0 0 5 1 1 4 68 CRRARST 1160739 O0 000 O0 0 5 1 1 4 68 FBEF RST UA 1160739 O0 000 O0 0 5 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 9300.000 NBAC.RST 3001.713 FBAC.RST 3316.578 SBNA.FIL SFNA.FIL 20.373 SBFA.FIL 43.791 SFFA.FIL 17.156 TRAT. FIL IRAT. FIL 0.487 CIRN. FIL 1.101 CIRF. FIL 2.471 BSAL.RST SIBF.RST 39.892 TPHI.RST 24.829 SFFC. RST 14.534 SFNC.RST SIGM. RST 14.508 DSIG.RST 0.692 GRCH. RST -999.250 TENS.RST CCL.RST -0.022 CRRA.RST 2.010 FBEF. RST 64.935 DEPT. 9019.500 NBAC. RST -999.250 FBAC. RST -999.250 SBNA.FIL SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST SIBF.RST -999.250 TPHI.RST -999.250 SFFC. RST -999.250 SFNC.RST SIGM. RST -999.250 DSIG.RST -999.250 GRCH. RST 105.640 TENS.RST CCL.RST -999.250 CRRA.RST -999.250 FBEF. RST -999.250 53.785 0.921 50.335 15.727 1605.000 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 23 **** FILE TRAILER **** FILE NAlVlE : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 6 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFIBER: 6 DEPTH INCREMF2~r: 0.5000 FILE SUM~IARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 9287.0 9023.5 RST 9300.0 9024.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUFI~ER: 1 .......... EQUIVALEiTT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH RST ............................ 88888.0 88887.0 88889.0 9286.5 9287.5 9284.5 9285.0 9282.0 9281.0 9280.5 9281.5 9278.5 9279.5 9277.5 9277.0 9263.0 9263.5 9253.0 9253.0 9253.0 9246.5 9247.0 9245.0 9246.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 24 9243.5 9244.0 9241.0 9242.5 9236.5 9237.0 9235.5 9237.0 9231.5 9233.5 9229.0 9230.0 9224.0 9224.5 9221.0 9222.0 9217.5 9218.0 9214.0 9215.5 9208.5 9209.0 9207.0 9206.5 9203.5 9204.5 9198.0 9198.5 9194.0 9194.0 9186.5 9186.0 9185.0 9186.0 9182.5 9183.5 9179.5 9179.5 9180.0 9177.0 9176.5 9175.0 9176.5 9170.0 9170.0 9168 . 5 9169.5 9164.5 9164.5 9160.5 9160.0 9159.5 9160.5 9157.5 9157.5 9152.5 9153.0 9150.0 9149.0 9149.5 9148.5 9143.5 9144.0 9142.5 9142.5 9140.5 9140.0 9130.5 9130.0 9128.5 9129.5 9127.0 9126.5 9119.5 9120.5 9116.0 9117.0 9112.0 9112.0 9109.5 9109.0 9108.5 9109.5 9107.0 9107.0 9104.0 9104.0 9102 . 0 9102.0 9098.0 9097.5 9093.5 9094.5 9092.5 9092.5 9089.5 9089.5 9088.5 9088.5 9084.5 9084.5 9084.0 9080.5 9080.0 9080.0 9080.0 9070.0 9070.0 9068.0 9068.0 9067.5 9068.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 25 9065.5 9066.0 9065.0 9064.5 9061.5 9062.0 9059.5 9060.5 9054.5 9055.5 9047.5 9047.0 9044.5 9044.0 9045.5 9043.0 9044.0 9040.0 9041.0 9031.0 9031.0 100.0 99.5 100.0 REMARKS: THIS FILE CONTAINS CASED HOLE RST FLUSH PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH FLUSH PASS #1 AND GRCH BASE PASS #1, ALSO SIGMA FLUSH PASS #1 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 26 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1160739 O0 000 NBAC RST CPS 1160739 O0 000 FBAC RST CPS 1160739 O0 000 SBNA FIL CU 1160739 O0 000 SFNA FIL CU 1160739 O0 000 SBFA FIL CU 1160739 O0 000 SFFA FIL CU 1160739 O0 000 TRAT FIL 1160739 O0 000 IRAT FIL 1160739 O0 000 CIRNFIL 1160739 O0 000 CIRFFIL 1160739 O0 000 BSAL RST PPK 1160739 O0 000 SIBF RST CU 1160739 O0 000 TPHI RST PU-S 1160739 O0 000 SFFC RST CU 1160739 O0 000 SFNC RST CU 1160739 O0 000 SIGM RST CU 1160739 O0 000 DSIG RST CU 1160739 O0 000 GRCHRST GAPI 1160739 O0 000 TENS RST LB 1160739 O0 000 CCL RST V 1160739 O0 000 CRRARST 1160739 O0 000 FBEF RST UA 1160739 O0 000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9300.000 NBAC.RST 2920.856 FBAC.RST 3272.933 SBNA.FIL SFNA.FIL 19.729 SBFA.FIL 43.729 SFFA.FIL 17.269 TRAT. FIL IRAT. FIL 0.492 CIRN. FIL 1.106 CIRF. FIL 2.435 BSAL.RST SIBF. RST 40.250 TPHI.RST 25.140 SFFC.RST 14.645 SFNC.RST SIGM. RST 14.628 DSIG.RST 0.516 GRCH. RST -999.250 TENS.RST CCL.RST -0.020 CRRA.RST 2.023 FBEF.RST 65.015 DEPT. 9023.500 NBAC.RST -999~250 FBAC.RST -999.250 SBNA.FIL SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT.FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST SIBF.RST -999.250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC.RST SIGM. RST -999.250 DSIG.RST -999.250 GRCH. RST 131.748 TENS.RST CCL.RST -999.250 CRRA.RST -999.250 FBEF. RST -999.250 54.376 0.925 51.319 15.184 1654.000 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 27 **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFIE : EDIT .007 SERVICE : FLIC VERSION : 001C01 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFI~ER: 7 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREFIENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUFIBERS 1, 2, RST $ REMARKS: THIS FILE CONTAINS THE ARITH~IETIC AVERAGE OF BASE PASSES 1 & 2. THE DATA WAS CLIPPED ANDDEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 28 TYPE REPR CODE VALUE .............................. 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... DEPT FT 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 NBAC RST CPS 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC RST CPS 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA RSAV CU 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA RSAV CU 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA RSAV CU 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA RSAV CU 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT RSAV 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT RSAV 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 CIRN RSAV 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF RSAV 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 BSALRSAV PPK 116'0739 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF RSAV CU 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI RSAV PU-S 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 SFFC RSAV CU 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 SFNC RSAV CU 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 SIGMRSAV CU 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 DSIG RSAV CU 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 CRRARSAV 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 FBEF RSAV UA 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH RST GAPI 1160739 O0 000 O0 0 7 1 1 4 68 0000000000 ....................................................................................... ** DATA ** DEPT. 9300.000 NBAC.RST 2062.032 FBAC.RST 2841.818 SBNA.RSAV -999.250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT. RSAV -999.250 IRAT. RSAV -999.250 CIRN. RSAV -999.250 CIRF. RSAV -999.250 BSAL.RSAV -999.250 SIBF.RSAV -999.250 TPHI.RSAV -999.250 SFFC.RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999.250 DSIG.RSAV -999.250 CRRA.RSAV -999.250 FBEF. RSAV -999.250 GRCH. RST -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 29 DEPT. 8985 . 000 NBAC. RST -999. 250 FBAC. RST -999. 250 SBNA. RSAV - 999. 250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT. RSAV -999.250 IRAT. RSAV -999.250 CIRN. RSAV -999.250 CIRF. RSAV -999.250 BSAL.RSAV -999.250 SIBF. RSAV -999.250 TPHI.RSAV -999.250 SFFC. RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999.250 DSIG.RSAV -999.250 CRRA.RSAV -999.250 FBEF. RSAV -999.250 GRCH. RST 39 . 052 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE · FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INC~: 0.5000 FILE SUF~4ARY VENDOR TOOL CODE START DEPTH ........................... RST 9325.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : STOP DEPTH .......... 8952.0 18-MAY-98 8C0-609 1730 17-MAY-98 9331.0 8985.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 3O BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 9299.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~fA RAY RST RESERVOIR SATURATION $ TOOL NUMBER ........... CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 9500.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE Tb~4PERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Borax/KCl NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): Thank you for using Schlumberger. This log was depth refernced to SWS BHC log dated 12-Nov-1983. Ail depth correllating material provided by co. rep. Logging procedure: After the first run of Sigma & C/O mode, 123 BBLS of Borax followed with KCl. Borax passes made between 9320-9040' @ 1800 FPH - KCl @2BPM. Borax #1 pass made w~ 114 BBLS KCl away @ 500 psi WHP Borax #2 pass made w~ 145 BBLS KCl away @ 375 psi WHP LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 31 Borax #3 pass made w~ 177 BBLS KC1 away @ 375 psi WHP Flush pass made w/ 217 BBLS KC1 away @ 50 psi WHP Pumped 20 BBLS crude to finish KC1 A total of 1150 BBLS KC1, 123 BBLS Borax, and 63 BBLS crude used for both Sigma & C/O log and Borax log. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 CS PS1 F/HR 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS1 LB 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 NPHVPS1 V 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 NPDE PS1 V 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 NSCE PS1 V 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 CRRAPS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 NSCR PS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 AQTMPS1 S 1160739 O0 000 O0 0 $ 1 1 4 68 0000000000 CHV PS1 V 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 CP5V PS1 V 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 CP2V PS1 V 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 CM2V PS1 V 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 32 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELE~ CODE (HEX) ....................................................................................... RCFR PS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 RCLC PS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 RCRC PS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 RCAKPS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 RTDF PS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 FPHVPS1 V 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 FPDE PS1 V 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 FSCE PS1 V 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 FSCR PS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 AQTF PS1 S 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 SF6P PS1 PSIG 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 HVPV PS1 V 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 BMCU PS1 UA 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 GDCUPS1 MA 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 EXCU PS1 UA 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 NBEF PS1 UA 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 FBEF PS1 UA 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 NPGF PS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 FPGF PS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 BSTR PS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 BSPR PS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 MARC PS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 ~ PS1 V 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 XPSV PS1 V 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 XP2V PS1 V 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 3~42V PS1 V 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 RXFR PS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 RXLC PS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 RXRC PS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 RXAKPS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 SHCU PS1 MA 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL PS1 PPK 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL SIG PPK 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 CIRNPS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 CIRF PS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 CIRNFIL 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 CIRFFIL 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 DSIG PS1 CU 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS1 CPS 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 IRAT PS1 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 IRAT FIL 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 NBAC PS1 CPS 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA PS1 CU 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA PS1 CU 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA PS1 CU 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA PS1 CU 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA SIG CU 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA SIG CU 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA SIG CU 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA SIG CU 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA FIL CU 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 33 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) SFFA FIL CU 1160739 O0 000 O0 0 8 1 1 4 68 SBNA FIL CU 1160739 O0 000 O0 0 8 1 1 4 68 SBFA FIL CU 1160739 O0 000 O0 0 8 1 1 4 68 SIBF PS1 CU 1160739 O0 000 O0 0 8 1 1 4 68 SFNC PS1 CU 1160739 O0 000 O0 0 8 1 1 4 68 SFFC PS1 CU 1160739 O0 000 O0 0 8 1 1 4 68 SIGM PS1 CU 1160739 O0 000 O0 0 8 1 1 4 68 SIBF SIG CU 1160739 O0 000 O0 0 8 1 1 4 68 SIGM SIG CU 1160739 O0 000 O0 0 8 1 1 4 68 TI{AT PS1 1160739 O0 000 O0 0 8 1 1 4 68 TI{AT SIG 1160739 O0 000 O0 0 8 1 1 4 68 TRAT FIL 1160739 O0 000 O0 0 8 1 1 4 68 GR PS1 GAPI 1160739 O0 000 O0 0 8 1 1 4 68 Ri)IX PSl 1160739 O0 000 O0 0 8 1 1 4 68 CRNI PS1 KHZ 1160739 O0 000 O0 0 8 1 1 4 68 CRFI PS1 KHZ 1160739 O0 000 O0 0 8 1 1 4 68 RSCS PS1 1160739 O0 000 O0 0 8 1 1 4 68 CTM PS1 DEGC 1160739 O0 000 O0 0 8 1 1 4 68 XTM PS1 DEGC 1160739 O0 000 O0 0 8 1 1 4 68 TAV PS1 KV 1160739 O0 000 O0 0 8 1 i 4 68 FICU PS1 AMP 1160739 O0 000 O0 0 8 1 1 4 68 CACUPS1 AMP 1160739 O0 000 O0 0 8 1 1 4 68 BUST PS1 1160739 O0 000 O0 0 8 1 1 4 68 BUSP PS1 1160739 O0 000 O0 0 8 1 1 4 68 RSXS PS1 1160739 O0 000 O0 0 8 1 1 4 68 TPHI PS1 PU 1160739 O0 000 O0 0 8 1 1 4 68 TPHI SIG PU 1160739 O0 000 O0 0 8 1 1 4 68 CCLC PS1 V 1160739 O0 000 O0 0 8 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 9320.000 CS.PS1 1774.515 TENS. PSi 1423.000 NPHV. PS1 NPDE. PS1 1557.199 NSCE.PS1 2.602 CRRA.PS1 1.987 NSCR.PS1 AQTM. PS1 0.441 CHV. PS1 201.096 CP5V. PS1 5.089 CP2V. PS1 CM2V. PS1 -12.211 RCFR.PS1 0.000 RCLC. PS1 0.000 RCRC. PS1 RCAK. PS1 0.000 RTDF. PS1 0.000 FPHV. PS1 1499.024 FPDE. PS1 FSCE. PS1 2.390 FSCR.PS1 -0.181 AQTF. PS1 0.441 SF6P.PS1 HVPV. PS1 160.645 BMCU. PS1 32.812 GDCU. PS1 59.684 EXCU. PS1 NBEF. PS1 29.497 FBEF. PS1 58.624 NPGF. PS1 0.999 FPGF.PS1 BSTR.PSl 12.110 BSPR.PS1 1.110 MARC. PSi 0.000 XHV. PS1 XPSV. PS1 5.050 XP2V. PS1 12.070 ]q42V. PS1 -12.211 RXFR.PS1 RXLC. PS1 0.000 RXRC.PS1 0.000 RXAK. PS1 0.000 SHCU. PS1 BSAL.PS1 -999.250 BSAL.SIG -999.250 CIRN. PS1 -999.250 CIRF. PS1 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.PS1 -999.250 FBAC. PS1 IRAT. PS1 -999.250 IRAT. FIL -999.250 NBAC. PS1 -999.250 SFNA.PS1 SFFA.PS1 -999.250 SBNA.PS1 -999.250 SBFA. PS1 -999.250 SFNA.SIG SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL -999.250 SIBF. PS1 SFNC. PS1 -999.250 SFFC.PS1 -999.250 SIGM. PS1 -999.250 SIBF.SIG 1569.825 0.056 12.173 0.000 1490.060 108.112 3.551 0.998 200.854 0.000 41.300 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 34 SIGM. SIG -999.250 TRAT. PS1 -999.250 TRAT. SIG GR.PS1 13.561 RDIX. PS1 153977.000 CRNI.PS1 RSCS.PS1 8459.000 CTM. PS1 75.684 XTM. PS1 FICU. PS1 2.617 CACU. PS1 2.603 BUST. PSi RSXS.PS1 8878.000 TPHI.PS1 -999.250 TPHI.SIG DEPT. 8970.000 CS.PS1 1901.938 TENS.PSi NPDE.PS1 1565.477 NSCE. PS1 2.619 CRRA.PS1 AQTM. PS1 1.322 CHV. PS1 201.339 CP5V. PS1 CM2V. PS1 -12.221 RCFR.PS1 0.000 RCLC. PS1 RCAK. PS1 1.000 RTDF. PS1 0.000 FPHV. PS1 FSCE. PS1 2.094 FSCR.PS1 -0.005 AQTF. PS1 HVPV. PS1 160.976 BMCU. PS1 34.758 GDCU. PS1 NBEF. PS1 30.070 FBEF. PS1 60.785 NPGF. PS1 BSTR.PS1 12.470 BSPR.PS1 1.075 MARC. PSi XP5V. PS1 5.047 XP2V. PS1 12.057 X~2V. PS1 RXLC. PS1 0.000 RXRC.PS1 0.000 RXAK. PS1 BSAL.PS1 19.726 BSAL.SIG 2.810 CIRN. PS1 CIRN. FIL 1.236 CIRF. FIL 2.866 DSIG. PS1 IRAT. PS1 0.515 IRAT. FIL 0.517 NBAC. PS1 SFFA.PS1 15.630 SBNA.PS1 52.333 SBFA.PS1 SFFA.SIG 0.330 SBNA.SIG 2.846 SBFA.SIG SFFA.FIL 15.714 SBNA.FIL 52.162 SBFA.FIL SFNC. PS1 13.408 SFFC. PS1 12.874 SIGM. PS1 SIGM. SIG 0.184 TRAT. PS1 0.847 TRAT. SIG GR.PS1 25.713 RDIX. PS1 163930.000 CRNI.PS1 RSCS.PS1 8463.000 CTM. PS1 71.533 XTM. PS1 FICU. PS1 2.551 CACU. PS1 2.610 BUST. PSi RSXS.PS1 8878.000 TPHI.PS1 17.228 TPHI.SIG -999.250 447.842 78.613 0.000 -999.250 1387.000 2.021 5.065 0.000 1501.466 0.441 60.105 1.000 0.000 -12.225 0.000 1.262 -0.108 2211.230 43. 020 5. 872 40. 720 12. 869 O. 011 465. 377 73.661 0.000 0.493 TRA T. FIL CRFI. PS1 TA V. PS1 BUSP. PS1 CCLC. PS1 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC.PS1 FPDE. PS1 SF6P. PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 TAV. PS1 BUSP. PS1 CCLC. PS1 -999.250 225.334 94.888 0.000 0.005 1566.163 0.016 12.224 0.000 1492.845 104.896 3.241 1.001 200.889 0.000 42.276 2.872 2960.428 18.601 0.274 18. 975 28. 975 0.984 0.847 230.217 94.970 0.000 0.030 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 35 FILE HEADER FILE NUM~ER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFIBER: 2 DEPTH INCREFIENT: 0.5000 FILE SUM~3~RY VENDOR TOOL CODE START DEPTH RST 9328.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH .......... 8970.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE Tt'~4PERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE 18-MAY-98 8C0-609 1730 17-MAY-98 9331.0 8985.0 9299.0 1800.0 TOOL NUMBER CGRS-A RST-A 8.500 9500.0 Borax~KC1 THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 36 TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 ~ COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger. This log was depth refernced to SWS BHC log dated 12-Nov-1983. Ail depth correllating material provided by co. rep. Logging procedure: After the first run of Sigma & C/O mode, 123 BBLS of Borax followed with KCl. Borax passes made between 9320-9040' @ 1800 FPH - KCl @2BPM. Borax #1 pass made w~ 114 BBLS KCl away @ 500 psi WHP Borax #2 pass made w~ 145 BBLS KCl away @ 375 psi WHP Borax #3 pass made w~ 177 BBLS KCl away @ 375 psi WHP Flush pass made w~ 217 BBLS KCl away @ 50 psi WHP Pumped 20 BBLS crude to finish KCl A total of 1150 BBLS KCl, 123 BBLS Borax, and 63 BBLS crude used for both Sigma & C/O log and Borax log. THIS FILE CONTAINS THERAW DATA FOR BASE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 37 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) DEPT FT 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 CS PS2 F/HR 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS2 LB 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 NPHVPS2 V 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 NPDE PS2 V 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 NSCE PS2 V 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 CRRAPS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 NSCR PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 AQTMPS2 S 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 CHV PS2 V 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 CPSV PS2 V 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 CP2V PS2 V 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 CM2V PS2 V 1160739 00 000 O0 0 9 1 1 4 68 0000000000 RCFR PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 RCLC PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 RCRC PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 RCAKPS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 RTDF PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 FPHVPS2 V 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 FPDE PS2 V 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 FSCE PS2 V 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 FSCR PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 AQTF PS2 S 1160739 O0 000 00 0 9 1 1 4 68 0000000000 SF6P PS2 PSIG 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 HVPV PS2 V 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 BMCU PS2 UA 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 GDCU PS2 MA 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 EXCUPS2 UA 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 NBEF PS2 UA 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 FBEF PS2 UA 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 NPGF PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 FPGF PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 BSTR PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 BSPR PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 MARC PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 XHV PS2 V 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 XPSV PS2 V 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 XP2V PS2 V 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 X~2V PS2 V 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 RXFR PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 RXLC PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 RXRC PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 RXAKPS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 SHCUPS2 MA 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 BSALPS2 PPK 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 BSAL SIG PPK 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 CIRNPS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 38 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELM CODE (HEX) CIRNFIL 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 CIRFFIL 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 DSIG PS2 CU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS2 CPS 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 II{ATPS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT FIL 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 NBAC PS2 CPS 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA PS2 CU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA PS2 CU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA PS2 CU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA PS2 CU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA SIG CU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA SIG CU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA SIG CU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA SIG CU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA FIL CU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA FIL CU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA FIL CU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA FIL CU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 SIBF PS2 CU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 SFNC PS2 CU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 SFFC PS2 CU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 SIGMPS2 CU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 SIBF SIG CU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 SIGMSIG CU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 TI{AT PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT SIG 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT FIL 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS2 GAPI 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 RDIX PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 CRNI PS2 KHZ 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 CRFI PS2 KHZ 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 RSCS PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 CTM PS2 DEGC 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 XTM PS2 DEGC 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 TAV PS2 KV 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 FICU PS2 AMP 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 CACU PS2 AMP 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 BUST PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 BUSP PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 RSXS PS2 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PS2 PU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI SIG PU 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 CCLC PS2 V 1160739 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 39 DEPT. 9320.000 CS.PS2 NPDE. PS2 1563.798 NSCE.PS2 AQTM. PS2 0.661 CHV. PS2 CM2V. PS2 -12.231 RCFR.PS2 RCAK. PS2 1.000 RTDF. PS2 FSCE. PS2 2.098 FSCR.PS2 HVPV. PS2 160.889 BMCU. PS2 NBEF. PS2 31.453 FBEF. PS2 BSTR.PS2 12.651 BSPR.PS2 XP5V. PS2 5.050 XP2V. PS2 RXLC.PS2 0.000 RXRC. PS2 BSAL.PS2 -999.250 BSAL.SIG CIRN. FIL -999.250 CIRF. FIL IRAT. PS2 -999.250 IRAT. FIL SFFA.PS2 -999.250 SBNA.PS2 SFFA.SIG -999.250 SBNA.SIG SFFA.FIL -999.250 SBNA.FIL SFNC.PS2 -999.250 SFFC.PS2 SIGM. SIG -999.250 TRAT. PS2 GR.PS2 193.694 RDIX. PS2 RSCS.PS2 8463.000 CTM. PS2 FICU. PS2 2.646 CACU. PS2 RSXS.PS2 8878.000 TPHI.PS2 DEPT. 8970.500 CS.PS2 NPDE.PS2 1566.201 NSCE. PS2 AQTM. PS2 1.322 CHV. PS2 CM2V. PS2 -12.240 RCFR.PS2 RCAK. PS2 0.000 RTDF. PS2 FSCE.PS2 2.056 FSCR.PS2 HVPV. PS2 160.791 BMCU. PS2 NBEF. PS2 32.085 FBEF. PS2 BSTR.PS2 12.799 BSPR.PS2 XP5V. PS2 5.048 XP2V. PS2 RXLC. PS2 0.000 RXRC.PS2 BSAL.PS2 18.451 BSAL.SIG CIRN. FIL 1.388 CIRF. FIL IRAT. PS2 0.526 IRAT. FIL SFFA.PS2 14.193 SBNA.PS2 SFFA.SIG 0.236 SBNA.SIG SFFA.FIL 13.939 SBNA.FIL SFNC. PS2 10.907 SFFC. PS2 SIGM. SIG 0.151 TRAT. PS2 GR.PS2 30.172 RDIX. PS2 RSCS.PS2 8463.000 CTM. PS2 FICU. PS2 2.580 CACU. PS2 RSXS.PS2 8878.000 TPHI.PS2 1735.801 TENS.PS2 2.642 CRRA.PS2 201.096 CP5V. PS2 0.000 RCLC. PS2 0.000 FPHV. PS2 0.077 AQTF. PS2 34.277 GDCU. PS2 62.603 NPGF. PS2 1.126 MARC. PS2 12.056 XM2V. PS2 0.000 RXAK. PS2 -999.250 CIRN. PS2 -999.250 DSIG.PS2 -999.250 NBAC. PS2 -999.250 SBFA.PS2 -999.250 SBFA.SIG -999.250 SBFA.FIL -999.250 SIGM. PS2 -999.250 TRAT. SIG 165955.000 CRNI.PS2 70.313 XTM. PS2 2.607 BUST. PS2 -999.250 TPHI.SIG 1784.048 TENS.PS2 2.660 CRRA.PS2 201.339 CP5V. PS2 0.000 RCLC. PS2 0.000 FPHV. PS2 0.044 AQTF. PS2 35.586 GDCU. PS2 62.571 NPGF. PS2 1.103 MARC. PS2 12.053 X~2V. PS2 0.000 RXAK. PS2 2.691 CIRN. PS2 3.169 DSIG.PS2 0.527 NBAC. PS2 53.782 SBFA.PS2 3.115 SBFA.SIG 48.564 SBFA.FIL 11.025 SIGM. PS2 0.831 TRAT. SIG 176069.000 CRNI.PS2 72.754 XTM. PS2 2.609 BUST. PS2 17.020 TPHI.SIG 1429.000 1.990 5.089 0.000 1499.024 0.661 59.356 1.002 0.000 -12.250 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 446.548 71.289 0.000 -999.250 1380.000 1.950 5.065 0.000 1503.907 1.322 59.859 0.998 0.000 -12.223 0.000 1.408 -0.127 2322.104 35.874 4.648 38.688 11.074 0.011 452.830 73.731 0.000 0.449 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC. PS2 FPDE. PS2 SF6P. PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC.PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 TAV. PS2 BUSP.PS2 CCLC. PS2 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC. PS2 FPDE. PS2 SF6P.PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 TAV. PS2 BUSP.PS2 CCLC. PS2 1564.943 0.095 12.202 0.000 1490.976 106.833 3.551 1.005 200. 854 O. 000 40. 650 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 224.354 95.175 0.000 0.003 1569.825 0.013 12.202 0.000 1493.226 105.810 2.841 1.006 200.903 0.000 41.517 3.166 2980.927 16.599 0.263 16.473 28.529 0.940 0.839 232.204 95.079 0.000 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 4O **** FILE TRAILER **** FILE NAM~ : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFIE : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUf4~ER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFI~ER: 3 DEPTH INCREMENT: 0.5000 FILE SO74~zARY VENDOR TOOL CODE START DEPTH RST 9328.0 $ LOG HEADER DATA STOP DEPTH .......... 8998.5 DATE L~ED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAI~VlA RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 18-MAY-98 8C0-609 1730 17-MAY-98 9331.0 8985.0 9299.0 1800.O TOOL NUMBER CGRS-A RST-A 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 41 DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 9500.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE T~PERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Borax/KCl NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger. This log was depth refernced to SWS BHC log dated 12-Nov-1983. Ail depth correllating material provided byco. rep. Logging procedure: After the first run of Sigma & C/O mode, 123 BBLS of Borax followed with KCl. Borax passes made between 9320-9040' @ 1800 FPH - KCl @2BPM. Borax #1 pass made w~ 114 BBLS KCl away @ 500 psi WHP Borax #2 pass made w~ 145 BBLS KCl away @ 375 psi WHP Borax #3 pass made w~ 177 BBLS KCl away @ 375 psi WHP Flush pass made w~ 217 BBLS KCl away @ 50 psi WHP Pumped 20 BBLS crude to finish KCl A total of 1150 BBLS KCl, 123 BBLS Borax, and 63 BBLS crude used for both Sigma & C/O log and Borax log. THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 42 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELM CODE (HEX) ....................................................................................... DEPT FT 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 CS BX1 F/HR 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 TENS BX1 LB 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 NPHVBX1 V 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 NPDE BX1 V 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 NSCE BX1 V 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 CRRABX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 NSCR BX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 AQTMBX1 S 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 CHV BX1 V 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 CP5V BX1 V 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 CP2V BX1 V 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 CM2V BX1 V 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 RCFR BX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 RCLC BX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 RCRC BX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 RCAKBX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 RTDF BX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 FPHVBX1 V 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 FPDE BX1 V 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 FSCE BX1 V 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 FSCR BX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 AQTF BX1 S 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SF6P BX1 PSIG 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 HVPV BX1 V 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 BMCUBX1 UA 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 43 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELEM CODE (HEX) GDCUBX1 MA 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 EXCUBX1 UA 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 NBEF BX1 UA 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 FBEF BXl UA 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 NPGF BXl 1160739 00 000 O0 0 10 1 1 4 68 0000000000 FPGF BX1 1160739 O0 000 O0 0 I0 1 1 4 68 0000000000 BSTR BX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 BSPR BX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 MARC BX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 X~V BX1 V 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 XPSV BXl V 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 XP2V BXl V 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 X~2V BXl V 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 RXFRBX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 RXLC BX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 RXRC BXl 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 R3fAKBX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SHCU BXl MA 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 BSALBX1 PPK 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 BSAL SIG PPK 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 CIRlVBXl 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 CIRFBX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 CIRNFIL 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 CIRFFIL 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 DSIG BX1 CU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC BX1 CPS 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 IRAT BX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 IRAT FIL 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 NBAC BXl CPS 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SFNA BXl CU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SFFA BX1 CU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SBNA BX1 CU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SBFA BX1 CU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SFNA SIG CU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SFFA SIG CU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SBNA SIG CU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SBFA SIG CU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SFlVAFIL CU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SFFA FIL CU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SBNA FIL CU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SBFA FIL CU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SIBF BX1 CU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SFNC BX1 CU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SFFC BX1 CU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM BX1 CU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SIBF SIG CU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM SIG CU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT BX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT SIG 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT FIL 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 GR BX1 GAPI 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 44 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) RDIX BX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 CRNI BX1 KHZ 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 CRFI BX1 KHZ 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 RSCS BX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 CTM BX1 DEGC 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 XTM BX1 DEGC 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 TAV BX1 KV 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 FICU BX1 AMP 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 CACU BX1 AMP 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 BUST BX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 BUSP BX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 RSXS BX1 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI BX1 PU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI SIG PU 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 CCLC BX1 V 1160739 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE. BX1 AQTM. BX1 CM2 V. BX1 RCAK. BX1 FSCE.BX1 HVPV. BX1 NBEF.BX1 BSTR.BX1 XPSV. BX1 RXLC. BX1 BSAL.BX1 CIRN. FIL IRAT. BX1 SFFA.BX1 SFFA.SIG SFFA.FIL SFNC.BX1 SIGM. SIG GR.BX1 RSCS.BX1 FICU. BX1 RSXS.BX1 DEPT. NPDE. BX1 AQTM. BX1 CM2 V. BX1 RCAK. BX1 FSCE. BX1 HVPV. BX1 9320.000 1561.586 0.661 -12.250 0.000 2.410 160.645 32 914 i1 444 5 O40 0 000 -999 250 -999250 -999 250 -999~250 -999.250 -999.250 -999.250 -999.250 122.045 8459.000 2.686 8878.000 8998.500 1562.959 1.322 -12.221 0.000 2.193 161.296 CS.BX1 1745.155 TENS.BX1 NSCE.BX1 2.952 CRRA.BX1 CHV. BX1 200.854 CP5V. BX1 RCFR.BX1 0.000 RCLC.BX1 RTDF. BX1 0.000 FPHV. BX1 FSCR.BX1 -0.011 AQTF. BX1 BMCU. BX1 36.914 GDCU. BX1 FBEF. BX1 67.045 NPGF. BX1 BSPR.BX1 1.089 MARC.BX1 XP2V. BX1 12.041 XM2V. BX1 RXRC. BX1 0.000 RXAK. BX1 BSAL.SIG -999.250 CIRN. BX1 CIRF. FIL -999.250 DSIG.BX1 IRAT. FIL -999.250 NBAC.BX1 SBNA.BX1 -999.250 SBFA.BXl SBNA.SIG -999.250 SBFA.SIG SBNA.FIL -999.250 SBFA.FIL SFFC. BX1 -999.250 SIGM. BX1 TRAT. BX1 -999.250 TRAT. SIG RDIX. BX1 417890.000 CRNI.BX1 CTM. BXl 52.246 XTM. BX1 CACU. BX1 2.632 BUST.BX1 TPHI.BX1 -999.250 TPHI.SIG CS.BX1 1806.351 TENS.BX1 NSCE. BX1 2.742 CRRA.BX1 CHV. BX1 201.096 CPSV. BX1 RCFR.BX1 0.000 RCLC.BX1 RTDF. BX1 0.000 FPHV. BX1 FSCR.BX1 0.001 AQTF. BX1 BMCU. BXl 36.523 GDCU. BX1 1704.000 2.037 5 079 0 000 1489 259 0 661 60 012 0 997 0.000 -12.270 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 449.294 53.223 0.000 -999.250 1621.000 1.934 5.069 0.000 1497.804 1.322 60.034 NPHV. BX1 NSCR.BX1 CP2V. BX1 RCRC.BX1 FPDE.BX1 SF6P.BX1 EXCU. BX1 FPGF.BX1 XHV. BX1 RXFR.BX1 SHCU. BX1 CIRF. BX1 FBAC.BX1 SFNA.BX1 SFNA.SIG SFNA.FIL SIBF. BX1 SIBF. SIG TRAT. FIL CRFI. BX1 TA V. BX1 BUSP. BX1 CCLC. BX1 NPHV. BX1 NSCR.BX1 CP2V. BX1 RCRC.BX1 FPDE. BX1 SF6P. BX1 EXCU. BX1 1555.177 0.089 12.202 0.000 1485.940 95.064 2.367 0.998 200.127 0.000 44.552 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 220.571 95.031 0.000 -0.002 1568.605 -0.073 12.224 0.000 1491.319 96.121 2.709 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 45 NBEF. BX1 32.874 FBEF.BX1 63.590 NPGF. BX1 BSTR.BX1 11.667 BSPR.BX1 1.023 MARC.BX1 XP5V. BX1 5.048 XP2V. BXl 12.056 X~2V. BX1 RXLC.BX1 0.000 RXRC. BX1 0.000 RXAK.BX1 BSAL.BX1 179.244 BSAL.SIG 3.201 CIRN. BX1 CIRN. FIL 0.851 CIRF. FIL 2.466 DSIG.BX1 IRAT. BX1 0.530 IRAT. FIL 0.526 NBAC.BX1 SFFA.BX1 12.232 SBNA.BX1 87.091 SBFA.BX1 SFFA.SIG 0.245 SBNA.SIG 3.899 SBFA.SIG SFFA.FIL 12.273 SBNA.FIL 88.584 SBFA.FIL SFNC. BX1 10.638 SFFC.BX1 10.774 SIGM. BX1 SIGM. SIG 0.165 TRAT.BX1 0.651 TRAT. SIG GR.BX1 20.313 RDIX. BX1 427259.000 CRNI.BX1 RSCS.BX1 8463.000 CTM. BX1 65.186 XTM. BX1 FICU. BX1 2.645 CACU. BX1 2.620 BUST. BX1 RSXS.BX1 8878.000 TPHI.BX1 12.986 TPHI.SIG 0.999 FPGF. BX1 0.000 XHV. BX1 -12.249 RXFR.BX1 0.000 SHCU. BX1 0.881 CIRF. BX1 -0.313 FBAC. BX1 2924.031 SFNA.BX1 65.150 SFNA.SIG 5.385 SFNA.FIL 61.591 SIBF. BX1 10.877 SIBF. SIG 0.010 TRAT. FIL 453.609 CRFI.BX1 67. 969 TAV. BX1 O . 000 BUSP. BX1 0.360 CCLC. BX1 1.001 200.757 0.000 46.156 2.451 3169.588 12.471 0.296 13.063 90.542 1.367 0.666 234.498 94.964 0.000 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~iE : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFIE : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUM~ER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUBIBER: 4 DEPTH INCREFIENT: 0.5000 FILE SUMF~L~Y VENDOR TOOL CODE START DEPTH STOP DEPTH RST 9328.0 8990.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 46 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~4E LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 18-MAY-98 8C0-609 1730 17-MAY-98 9331.0 8985.0 9299.0 1800.0 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RESERVOIR SATURATION $ TOOL NUMBER ........... CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) '. 8.500 9500.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Borax/KCl NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger. LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 47 This log was depth refernced to SWS BHC log dated 12-Nov-1983. Ail depth correllating material provided byco. rep. Logging procedure: After the first run of Sigma &C/O mode, 123 BBLS of Borax followed with KC1. Borax passes made between 9320-9040' ® 1800 FPH - KC1 ®2BPM. Borax #1 pass made w/ 114 BBLS KC1 away ® 500 psi WHP Borax #2 pass made w/ 145 BBLS KC1 away ® 375 psi WHP Borax #3 pass made w/ 177 BBLS KC1 away ® 375 psi WHP Flush pass made w/ 217 BBLS KC1 away ® 50 psi WHP Pumped 20 BBLS crude to finish KC1 A total of 1150 BBLS KC1, 123 BBLS Borax, and 63 BBLS crude used for both Sigma &C/O log and Borax log. THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 CS BX2 F/HR 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 TENS BX2 LB 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 NPHVBX2 V 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 48 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELE~ CODE (HEX) NPDE BX2 V 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 NSCE BX2 V 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 CRRABX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 NSCR BX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 AQTMBX2 S 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 CHV BX2 V 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 CP5V BX2 V 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 CP2V BX2 V 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 CM2V BX2 V 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 RCFR BX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 RCLC BX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 RCRC BX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 RCAKBX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 RTDF BX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 FPHVBX2 V 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 FPDE BX2 V 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 FSCE BX2 V 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 FSCR BX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 AQTF BX2 S 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 SF6P BX2 PSIG 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 HVPV BX2 V 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 BMCU BX2 UA 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 GDCU BX2 MA 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 EXCU BX2 UA 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 AUBEFBX2 UA 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 FBEF BX2 UA 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 NPGF BX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 FPGF BX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 BSTR BX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 BSPR BX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 MARC BX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 XHV BX2 V 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 XP5V BX2 V 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 XP2V BX2 V 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 X~2V BX2 V 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 RXFRBX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 RXLC BX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 RXRC BX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 RXAKBX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 SHCU BX2 MA 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 BSALBX2 PPK 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 BSALSIG PPK 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 CIRNBX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 CIRF BX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 CIRNFIL 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 CIRFFIL 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 DSIG BX2 CU 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 FBAC BX2 CPS 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 IRAT BX2 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 IRAT FIL 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 NBAC BX2 CPS 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 49 NAIVE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... SFNA BX2 CU 1160739 O0 000 O0 0 11 1 1 4 SFFA BX2 CU 1160739 O0 000 O0 0 11 1 1 4 SBNA BX2 CU 1160739 O0 000 O0 0 11 1 1 4 SBFA BX2 CU 1160739 O0 000 O0 0 11 1 1 4 SFNA SIG CU 1160739 O0 000 O0 0 11 1 1 4 SFFA SIG CU 1160739 O0 000 O0 0 11 1 1 4 SBNA SIG CU 1160739 O0 000 O0 0 11 1 1 4 SBFA SIG CU 1160739 O0 000 O0 0 11 1 1 4 SFNA FIL CU 1160739 O0 000 O0 0 11 1 1 4 SFFA FIL CU 1160739 O0 000 O0 0 11 1 1 4 SBNA FIL CU 1160739 O0 000 O0 0 11 1 1 4 SBFA FIL CU 1160739 O0 000 O0 0 11 1 1 4 SIBF BX2 CU 1160739 O0 000 O0 0 11 1 1 4 SFNC BX2 CU 1160739 O0 000 O0 0 11 1 1 4 SFFC BX2 CU 1160739 O0 000 O0 0 11 1 1 4 SIGM BX2 CU 1160739 O0 000 O0 0 11 1 1 4 SIBF SIG CU 1160739 O0 000 O0 0 11 1 1 4 SIGM SIG CU 1160739 O0 000 O0 0 11 1 1 4 TRAT BX2 1160739 O0 000 O0 0 11 1 1 4 TRAT SIG 1160739 O0 000 O0 0 11 1 1 4 TRAT FIL 1160739 O0 000 O0 0 11 1 1 4 GR BX2 GAPI 1160739 O0 000 O0 0 11 1 1 4 RDIX BX2 1160739 O0 000 O0 0 11 1 1 4 CRNI BX2 K}tZ 1160739 O0 000 O0 0 11 1 1 4 CRFI BX2 K~Z 1160739 O0 000 O0 0 11 1 1 4 RSCS BX2 1160739 O0 000 O0 0 11 1 1 4 CTM BX2 DEGC 1160739 O0 000 O0 0 11 1 1 4 XTM BX2 DEGC 1160739 O0 000 O0 0 11 1 1 4 TAV BX2 KV 1160739 O0 000 O0 0 11 1 1 4 FICU BX2 AMP 1160739 O0 000 O0 0 11 1 1 4 CACU BX2 AMP 1160739 O0 000 O0 0 11 1 1 4 BUST BX2 1160739 O0 000 O0 0 11 1 1 4 BUSP BX2 1160739 O0 000 O0 0 11 1 1 4 RSXS BX2 1160739 O0 000 O0 0 11 1 1 4 TPHI BX2 PU 1160739 O0 000 O0 0 11 1 1 4 TPHI SIG PU 1160739 O0 000 O0 0 11 1 1 4 CCLC BX2 V 1160739 O0 000 O0 0 11 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 9320.000 CS.BX2 1810.523 TENS.BX2 NPDE.BX2 1562.425 NSCE.BX2 2.739 CRRA.BX2 2 AQTM. BX2 0.661 CHV. BX2 201.339 CP5V. BX2 5 CM2V. BX2 -12.211 RCFR.BX2 0.000 RCLC. BX2 0 RCAK. BX2 1.000 RTDF. BX2 0.000 FPHV. BX2 1494 FSCE.BX2 2.190 FSCR.BX2 0.060 AQTF. BX2 0 HVPV. BX2 161.377 BMCU. BX2 36.621 GDCU. BX2 60 NBEF. BX2 32.878 FBEF. BX2 66.170 NPGF. BX2 0 BSTR.BX2 11.013 BSPR.BX2 1.015 MARC.BX2 0 1733 000 NPHV. BX2 013 NSCR.BX2 069 CP2V. BX2 000 RCRC.BX2 142 FPDE.BX2 661 SF6P.BX2 668 EXCU. BX2 991 FPGF. BX2 000 XHV. BX2 1564.943 0.003 12.129 0.000 1488.458 98.901 2.762 1.002 200.854 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 5O XP5 V. BX2 RXLC. BX2 BSAL . BX2 CIRN. FIL IRA T. BX2 SFFA. BX2 SFFA. SIG SFFA. FIL S FN C . B X2 SIGM. SIG GR . BX2 RSCS. BX2 FICU. BX2 RSXS. BX2 DEPT. NPDE. BX2 AQTM. BX2 C~2 V. BX2 R CAK . BX2 FS CE . BX2 HVPV. BX2 NBEF. BX2 BSTR . BX2 XP5 V. BX2 RXLC. BX2 BSAL. BX2 CIRN. FIL IRA T. BX2 SFFA. BX2 SFFA. SIG SFFA. FIL SFNC. BX2 SIGM. SIG GR . BX2 RSCS . BX2 FI CU. BX2 RSXS. BX2 5.050 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999 250 -999 250 -999 250 311 894 8463 000 2 607 8878.OOO 8990.500 1562.768 0.661 -12.289 2.000 2.067 161.361 33.070 12.556 5.046 0.000 184.127 0 854 0 514 13 120 0 268 12 983 10 913 0.168 17.367 8459.000 2.649 8878.000 XP2V. BX2 12.085 X~2V. BX2 RXRC.BX2 0.000 RXAK. BX2 BSAL.SIG -999.250 CIRN. BX2 CIRF. FIL -999.250 DSIG.BX2 IRAT. FIL -999.250 NBAC. BX2 SBNA.BX2 -999.250 SBFA.BX2 SBNA.SIG -999.250 SBFA. SIG SBNA.FIL -999.250 SBFA.FIL SFFC. BX2 -999.250 SIGM. BX2 TRAT. BX2 -999.250 TRAT. SIG RDIX. BX2 429450.000 CRNI.BX2 CTM. BX2 62.988 XTM. BX2 CACU. BX2 2.612 BUST. BX2 TPHI.BX2 -999.250 TPHI.SIG CS.BX2 1818.235 TENS.BX2 NSCE.BX2 2.666 CRRA.BX2 CHV. BX2 201.339 CP5V. BX2 RCFR.BX2 0.000 RCLC. BX2 RTDF. BX2 0.000 FPMV. BX2 FSCR.BX2 0.006 AQTF. BX2 BMCU. BX2 36.093 GDCU. BX2 FBEF.BX2 62.744 NPGF. BX2 BSPR.BX2 1.080 MARC. BX2 XP2V. BX2 12.065 XM2V. BX2 RXRC. BX2 0.000 RXAK. BX2 BSAL.SIG 3.235 CIRN. BX2 CIRF. FIL 2.369 DSIG.BX2 IRAT. FIL 0.518 NBAC. BX2 SBNA.BX2 86.810 SBFA.BX2 SBNA.SIG 4.005 SBFA.SIG SBNA.FIL 87.421 SBFA.FIL SFFC.BX2 11.664 SIGM. BX2 TRAT.BX2 0.703 TRAT. SIG RDIX. BX2 439256.000 CRNI.BX2 CTM. BX2 66.895 XTM. BX2 CACU. BX2 2.616 BUST. BX2 TPHI.BX2 14.935 TPHI.SIG -12.270 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 448.733 65.430 0.000 -999.250 1621.000 1.897 5.050 0.000 1496.583 0.661 60.099 1.011 0.000 -12.244 2.000 0.856 -0.737 2884.324 57.042 5.177 60.425 11.668 0.011 445.665 68.848 0.000 0.389 RXFR.BX2 SHCU. BX2 CIRF.BX2 FBAC.BX2 SFNA.BX2 SFNA.SIG SFNA.FIL SIBF. BX2 SIBF. SIG TRAT. FIL CRFI.BX2 TAV. BX2 BUSP.BX2 CCLC.BX2 NPHV. BX2 NSCR.BX2 CP2V. BX2 RCRC.BX2 FPDE.BX2 SF6P.BX2 EXCU. BX2 FPGF.BX2 XHV. BX2 RXFR.BX2 SHCU. BX2 CIRF.BX2 FBAC.BX2 SFNA.BX2 SFNA.SIG SFNA.FIL SIBF. BX2 SIBF. SIG TRAT. FIL CRFI.BX2 TAV. BX2 BUSP.BX2 CCLC.BX2 0.000 45.202 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 222.963 95.031 0.000 -0.003 1564.943 -0.035 12.129 0.000 1491.777 97.622 2.788 1.001 200.886 0.000 46.113 2.374 3353.623 13.126 0.311 13.043 92.635 1.392 0.696 234.893 95.031 0.000 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 51 **** FILE HEADER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFIBER : 5 DEPTH INCRE~F2FP: 0.5000 FILE SU~xARY VFIVDOR TOOL CODE START DEPTH ........................... RST $ LOG HEADER DATA DATE LOGGED: 9328.0 SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 8988.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAM~ RAY RST RESERVOIR SATURATION $ BORE~OLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 18-MAY-98 8C0-609 1730 17-MAY-98 9331.0 8985.0 9299.0 1800.0 TOOL NUMBER ........... CGRS-A RST-A 8.500 9500.0 Borax/KCl LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 52 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): RE~La2~KS: Thank you for using Schlumberger. This log was depth refernced to SWS BHC log dated 12-Nov-1983. Ail depth correllating material provided byco. rep. Logging procedure: After the first run of Sigma & C/O mode, 123 BBLS of Borax followed with KC1. Borax passes made between 9320-9040' @ 1800 FPH - KC1 @2BPM. Borax #1 pass made w/ 114 BBLS KC1 away @ 500 psi WHP Borax #2 pass made w/ 145 BBLS KC1 away ® 375 psi WHP Borax #3 pass made w~ 177 BBLS KC1 away ® 375 psi WHP Flush pass made w/217 BBLS KC1 away @ 50 psi WHP Pumped 20 BBLS crude to finish KC1 A total of 1150 BBLS KC1, 123 BBLS Borax, and 63 BBLS crude used for both Sigma &C/O log and Borax log. THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 368 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 53 TYPE REPR CODE VALUE .............................. 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 PT 15 66 68 16 66 1 0 66 1 .............................. ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 CS BX3 F/HR 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 TENS BX3 LB 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 NPHVBX3 V 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 NPDE BX3 V 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 NSCE BX3 V 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 CRRABX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 NSCR BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 AQTMBX3 S 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 CHV BX3 V 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 CP5V BX3 V 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 CP2V BX3 V 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 CM2V BX3 V 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 RCFR BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 RCLC BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 RCRC BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 RCAKBX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 RTDF BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 FPHVBX3 V 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 FPDE BX3 V 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 FSCE BX3 V 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 FSCR BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 AQTF BX3 S 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SF6P BX3 PSIG 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 HVPV BX3 V 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 BMCU BX3 UA 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 GDCU BX3 MA 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 EXCUBX3 UA 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 NBEF BX3 UA 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 FBEF BX3 UA 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 NPGF BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 FPGF BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 BSTR BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 54 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELEM CODE (HEX) ....................................................................................... BSPR BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 MARC BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 X~V BX3 V 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 XP5V BX3 V 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 XP2V BX3 V 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 X~2V BX3 V 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 RXFR BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 RXLC BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 RXRC BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 RXAKBX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SHCU BX3 MA 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 BSALBX3 PPK 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 BSALSIG PPK 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 CIRNBX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 CIRF BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 CIRNFIL 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 CIRF FIL 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 DSIG BX3 CU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 FBAC BX3 CPS 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 IRAT BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 IRAT FIL 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 NBAC BX3 CPS 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SFNABX3 CU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SFFA BX3 CU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SBNA BX3 CU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SBFA BX3 CU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SFNA SIG CU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SFFA SIG CU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SBNA SIG CU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SBFA SIG CU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SFNA FIL CU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SFFA FIL CU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SBNA FIL CU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SBFA FIL CU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SIBF BX3 CU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SFNC BX3 CU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SFFC BX3 CU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SIGM BX3 CU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SIBF SIG CU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 SIGMSIG CU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT SIG 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT FIL 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 GR BX3 GAPI 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 RDIX BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 CRNI BX3 KHZ 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 CRFI BX3 KHZ 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 RSCS BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 CTM BX3 DEGC 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 XTM BX3 DEGC 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 TAV BX3 KV 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 55 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG 2~PE CZdt~S MOD 3t-Ul~ S.2~IP ELI~J CODE (HEX) FICU BX3 AMP 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 CACU BX3 AMP 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 BUST BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 BUSP BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 RSXS BX3 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI BX3 PU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI SIG PU 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 CCLC BX3 V 1160739 O0 000 O0 0 12 1 1 4 68 0000000000 ** DATA ** DEPT. 9320.000 CS.BX3 1857 NPDE. BX3 1562.234 NSCE. BX3 2 AQTM. BX3 0.661 CHV. BX3 201 CM2V. BX3 -12.231 RCFR.BX3 0 RCAK. BX3 1.000 RTDF. BX3 0 FSCE. BX3 2.078 FSCR.BX3 0 HVPV. BX3 160.889 BMCU. BX3 35 ArBEF. BX3 32.024 FBEF. BX3 65 BSTR.BX3 10.613 BSPR.BX3 1 XP5V. BX3 5.050 XP2V. BX3 12 RXLC. BX3 0.000 RXRC. BX3 0 BSAL.BX3 -999.250 BSAL.SIG -999 CIRN. FIL -999.250 CIRF. FIL -999 IRAT. BX3 -999.250 IRAT. FIL -999 SFFA.BX3 -999.250 SBNA.BX3 -999 SFFA.SIG -999.250 SBNA.SIG -999 SFFA.FIL -999.250 SBNA.FIL -999 SFNC. BX3 -999.250 SFFC. BX3 -999 SIGM. SIG -999.250 TRAT. BX3 -999 GR.BX3 210.189 RDIX. BX3 441540 RSCS.BX3 8459.000 CTM. BX3 63 FICU. BX3 2.598 CACU. BX3 2 RSXS.BX3 8878.000 TPHI.BX3 -999. 046 TENS.BX3 1642.000 NPHV. BX3 683 CRRA.BX3 2.038 NSCR.BX3 096 CP5V. BX3 5.069 CP2V. BX3 000 RCLC. BX3 0.000 RCRC.BX3 000 FPHV. BX3 1494.142 FPDE.BX3 088 AQTF. BX3 0.661 SF6P.BX3 449 GDCU. BX3 59.684 EXCU. BX3 270 NPGF. BX3 0.999 FPGF. BX3 108 MARC. BX3 0.000 XHV. BX3 056 XM2V. BX3 -12.231 RXFR.BX3 000 RXAK. BX3 0.000 SHCU. BX3 250 CIRN. BX3 -999.250 CIRF. BX3 250 DSIG.BX3 -999.250 FBAC. BX3 250 NBAC. BX3 -999.250 SFNA.BX3 250 SBFA.BX3 -999.250 SFNA.SIG 250 SBFA.SIG -999.250 SFNA.FIL 250 SBFA.FIL -999.250 SIBF. BX3 250 SIGM. BX3 -999.250 SIBF. SIG 250 TRAT. SIG -999.250 TRAT. FIL 000 CRNI.BX3 453.733 CRFI.BX3 477 XTM. BX3 66.895 TAV. BX3 612 BUST. BX3 0.000 BUSP.BX3 250 TPHI.SIG -999.250 CCLC.BX3 DEPT. 8988.000 CS.BX3 1847.792 NPDE. BX3 1562.730 NSCE. BX3 2.637 AQTM. BX3 1.322 CHV. BX3 201.460 CM2V. BX3 -12. 221 RCFR. BX3 O. 000 RCAK. BX3 O. 000 RTDF. BX3 O . 000 FSCE. BX3 2. 062 FSCR.BX3 O . 160 HVPV. BX3 161. 475 BMCU. BX3 35. 820 NBEF. BX3 32.550 FBEF. BX3 61.933 BSTR.BX3 11.954 BSPR.BX3 1.067 XP5V. BX3 5.050 XP2V. BX3 12.056 RXLC.BX3 0.000 R32RC.BX3 0.000 BSAL.BX3 174.459 BSAL.SIG 3.209 CIRN. FIL 0.802 CIRF. FIL 2.225 IRAT. BX3 0.525 IRAT. FIL 0.523 TENS.BX3 1545.000 NPHV. BX3 CRRA.BX3 1.903 NSCR.BX3 CP5V. BX3 5.055 CP2V. BX3 RCLC. BX3 0.000 RCRC.BX3 FPHV. BX3 1496.583 FPDE.BX3 AQTF. BX3 1.322 SF6P.BX3 GDCU. BX3 59.815 EXCU. BX3 NPGF. BX3 1.000 FPGF. BX3 MARC.BX3 0.000 XHV. BX3 X~2V. BX3 -12.232 RXFR.BX3 RXAK. BX3 0.000 SHCU. BX3 CIRN. BX3 0.779 CIRF. BX3 DSIG.BX3 -0.439 FBAC.BX3 NBAC.BX3 2887.228 SFNA.BX3 1564 943 0 111 12 173 0 000 1489 984 100 437 2 762 0 993 200 854 0 000 45 853 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 222.619 95.031 0.000 -1.811 1566.163 0.072 12.209 0.000 1492.883 98.339 2.762 1.003 200.886 0.000 46.265 2.201 3320.754 14.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 56 SFFA.BX3 13.317 SBNA.BX3 91.291 SBFA.BX3 SFFA.SIG 0.287 SBNA.SIG 3.936 SBFA.SIG SFFA.FIL 13.437 SBNA.FIL 89.085 SBFA.FIL SFNC. BX3 11.950 SFFC.BX3 12.004 SIGM. BX3 SIGM. SIG 0.174 TRAT. BX3 0.684 TRAT.SIG GR.BX3 36.768 RDIX. BX3 451381.000 CRNI.BX3 RSCS.BX3 8463.000 CTM. BX3 67.627 XTM. BX3 FICU. BX3 2.649 CACU. BX3 2.616 BUST.BX3 RSXS.BX3 8878.000 TPHI.BX3 13.934 TPHI.SIG 68.490 SFNA.SIG 5.721 SFNA.FIL 64.236 SIBF.BX3 12.006 SIBF. SIG 0.012 TRAT. FIL 450.707 CRFI.BX3 69.336 TAV. BX3 0.000 BUSP.BX3 0.406 CCLC.BX3 0.343 14.436 88.505 1.361 O.684 236.877 95.041 0.000 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 13 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFiBER: 6 DEPTH INCREMENT: 0.5000 FILE SUF~4ARY VENDOR TOOL CODE START DEPTH ........................... RST 9327.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TDDRILLER (FT): STOP DEPTH .......... 8992.5 18-MAY-98 8C0-609 1730 17-MAY-98 9331.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 57 TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 8985.0 9299.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAF~A RAY RST RESERVOIR SATURATION $ TOOL NUMBER ........... CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 9500.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Borax~KC1 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): Thank you for using Schlumberger. This log was depth refernced to SWS BHC log dated 12-Nov-1983. Ail depth correllating material provided by co. rep. Logging procedure: After the first run of Sigma &C/O mode, 123 BBLS of Borax followed with KC1. Borax passes made between 9320-9040' @ 1800 FPH - KC1 @2BPM. LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 Borax #1 pass made w~ 114 BBLS KCl away @ 500 psi WHP Borax #2 pass made w~ 145 BBLS KC1 away @ 375 psi WHP Borax #3 pass made w/ 177 BBLS KCl away @ 375 psi WHP Flush pass made w~ 217 BBLS KCl away @ 50 psi WHP Pumped 20 BBLS crude to finish KC1 A total of 1150 BBLS KCl, 123 BBLS Borax, and 63 BBLS crude used for both Sigma & C/O log and Borax log. THIS FILE CONTAINS THE RAW DATA FOR FLUSH PASS #1. $ LIS FORMAT DATA PAGE: 58 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD AU]FIB SAMP ELE~ CODE (HEX) DEPT FT 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 CS FP1 F/HR 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 TENS FP1 LB 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 NPHVFP1 V 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 NPDE FP1 V 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 NSCE FP1 V 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 CRRAFP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 NSCR FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 AQTMFP1 S 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 CHV FP1 V 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 CP5V FP1 V 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 59 NA~IE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) CP2V FP1 V 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 Cl~2V FP1 V 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 RCFR FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 RCLC FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 RCRC FPI 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 RCAK FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 RTDF FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 FPHVFP1 V 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 FPDE FP1 V 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 FSCE FP1 V 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 FSCR FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 AQTF FP1 S 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 SF6P FP1 PSIG 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 HVPV FP1 V 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 BMCUFP1 UA 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 GDCU FP1 MA 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 EXCUFP1 UA 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 NBEF FP1 UA 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 FBEF FP1 UA 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 NPGF FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 FPGF FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 BSTR FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 BSPR FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 MARC FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 XHV FP1 V 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 XPSV FP1 V 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 XP2V FP1 V 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 X1v~VFP1 V 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 RXFR FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 RXLC FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 R3fRCFP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 RXAKFP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 SHCU FP1 MA 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 BSALFP1 PPK 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 BSAL SIG PPK 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 CIRNFP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 CIRFFP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 CIRNFIL 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 CIRF FIL 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 DSIG FP1 CU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 FBAC FP1 CPS 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 IRAT FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 IRAT FIL 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 NBAC FP1 CPS 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 SFNA FP1 CU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 SFFA FP1 CU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 SBNA FP1 CU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 SBFA FP1 CU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 SFNA SIG CU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 SFFA SIG CU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 SBNA SIG CU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 60 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... SBFA SIG CU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 SFNA FIL CU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 SFFA FIL CU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 SBNA FIL CU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 SBFA FIL CU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 SIBF FP1 CU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 SFNC FP1 CU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 SFFC FP1 CU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 SIGMFP1 CU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 SIBF SIG CU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 SIGM SIG CU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT SIG 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT FIL 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 GR FP1 GAPI 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 RDIX FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 CRNI FP1 KHZ 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 CRFI FP1 KHZ 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 RSCS FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 CTM FP1 DEGC 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 XTM FP1 DEGC 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 TAV FP1 KV 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 FICU FP1 AMP 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 CACU FP1 AMP 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 BUST FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 BUSP FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 RSXS FP1 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 TPHI FP1 PU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 TPHI SIG PU 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 CCLC FP1 V 1160739 O0 000 O0 0 13 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE.FP1 1563.112 NSCE.FP1 AQTM. FP1 CM2 V. F P1 RCAK. FP1 FSCE. FP1 HVPV. FP1 NBEF. FPi BSTR. FP1 XP5V. FP1 RXLC. FP1 9320. 000 CS. FP1 1791 . 928 TENS. FP1 1677. 000 NPHV. FP1 1562. 501 2. 697 CRRA. FP1 1. 997 NSCR. FP1 -O. 105 0 . 661 CHV. FP1 201 . 581 CP5V. FP1 5. 050 CP2V. FP1 12. 261 -12. 270 RCFR. FP1 O. 000 RCLC. FP1 O. 000 RCRC. FP1 O. 000 1. 000 RTDF. FP1 0. 000 FPHV. FP1 1501. 466 FPDE. FP1 1495. 134 2.126 FSCR.FP1 -0. 041 AQTF. FP1 O. 661 SF6P.FP1 106. 066 161. 621 BMCU. FP1 36. 328 GDCU. FP1 59. 356 EXCU. FP1 2. 762 32. 521 FBEF. FP1 64. 960 NPGF. FP1 O. 997 FPGF. FP1 O. 995 11. 559 BSPR. FP1 1.140 MARC. FP1 O. 000 XHV. FP1 201. 096 5. 040 XP2V. FP1 12. 041 3C42V. FP1 -12. 231 RXFR. FP1 O. 000 0.000 RXRC. FP1 0.000 RXAK. FP1 0.000 SHCU. FP1 43.902 BSAL.FP1 -999.250 BSAL.SIG -999.250 CIRN. FP1 -999.250 CIRF. FP1 -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.FP1 -999.250 FBAC. FP1 -999.250 IRAT. FP1 -999.250 IRAT. FIL -999.250 NBAC. FP1 -999.250 SFNA.FP1 -999.250 SFFA.FP1 -999.250 SBNA.FP1 -999.250 SBFA.FP1 -999.250 SFNA.SIG -999.250 SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 61 SFFA.FIL -999.250 SBNA.FIL SFNC. FP1 -999.250 SFFC. FP1 SIGM. SIG -999.250 TRAT. FP1 GR.FP1 47.462 RDIX. FP1 RSCS.FP1 8463.000 CTM. FP1 FICU. FP1 2.603 CACU. FP1 RSXS.FP1 8878.000 TPHI.FP1 DEPT. 8992.500 CS.FP1 NPDE.FP1 1567.155 NSCE. FP1 AQTM. FP1 1.322 CHV. FP1 CM2V. FP1 -12.231 RCFR.FP1 RCAK. FP1 O . 000 RTDF. FP1 FSCE. FP1 2. 029 FSCR.FP1 HVPV. FP1 161.589 BMCU. FP1 NBEF. FP1 32.757 FBEF. FP1 BSTR.FP1 11.410 BSPR.FP1 XP5V. FP1 5.050 XP2V. FP1 RXLC. FP1 0.000 RXRC. FP1 BSAL.FP1 11.606 BSAL.SIG CIRN. FIL 1.392 CIRF. FIL IRAT. FP1 0.534 IRAT. FIL SFFA.FP1 13.756 SBNA.FP1 SFFA.SIG 0.229 SBNA.SIG SFFA.FIL 13.891 SBNA.FIL SFNC. FP1 10.871 SFFC.FP1 SIGM. SIG 0.148 TRAT. FP1 GR.FP1 253.295 RDIX. FP1 RSCS.FP1 8463.000 CTM. FP1 FICU. FP1 2.623 CACU. FP1 RSXS.FP1 8878.000 TPHI.FP1 -999.250 SBFA.FIL -999.250 SIGM. FP1 -999.250 TRAT. SIG 460749.000 CRNI.FP1 80.566 XTM. FP1 2.612 BUST. FP1 -999.250 TPHI.SIG 1836.016 TENS.FP1 2.645 CRRA.FP1 201.944 CP5V. FP1 0.000 RCLC. FP1 0.000 FPHV. FP1 -0.003 AQTF. FP1 36.035 GDCU. FP1 64.190 NPGF. FP1 0.968 MARC. FP1 12.049 X~2V. FP1 0.000 RXAK. FP1 2.719 CIRN. FP1 3.135 DSIG.FP1 0.533 NBAC. FP1 48.755 SBFA.FP1 3.135 SBFA.SIG 48.552 SBFA.FIL 10.873 SIGM. FP1 0.829 TRAT. SIG 470072.000 CRNI.FP1 72.510 XTM. FP1 2.615 BUST. FP1 15.551 TPHI.SIG -999.250 -999.250 -999.250 446.144 85.449 0.000 -999.250 1595.000 1.960 5.050 0.000 1506.349 1.322 59.902 0.999 0 000 -12 228 1 000 1 384 -0 298 2992 728 32 349 4 602 36 572 10.903 0.011 448.042 73.731 0.000 0.456 SIBF. FP1 SIBF. SIG TRAT. FIL CRFI. FP1 TA V. FP1 BUSP.FP1 CCLC.FP1 NPHV. FP1 NSCR.FP1 CP2V. FP1 RCRC. FP1 FPDE. FP1 SF6P. FP1 EXCU. FP1 FPGF. FP1 XHV. FP1 RXFR. FP1 SHCU. FP1 CIRF. FP1 FBAC. FP1 SFNA. FP1 SFNA. SIG SFNA. FIL SIBF. FP1 SIBF. SIG TRA T. FIL CRFI. FP1 TA V. FP1 BUSP. FP1 CCLC. FP1 -999.250 -999.250 -999.250 223.352 95.031 0.000 -2.064 1568.605 -0.008 12.202 0.000 1495.057 100.232 2. 762 1. 010 200. 919 0.000 46.937 3.098 3190.349 16.928 0.275 16.749 26.147 0.942 0.826 228.640 95.031 0.000 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUN-1998 12:07 PAGE: 62 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/06/24 ORIGIN : FLIC TAPE NAM~ : 98268 CONTINUATION # : 1 PREVIOUS TAPE : CO~ENT : ARCO ALASKA, DS 14-35 , PRUDHOE BAY, API #50-029-21018-00 **** REEL TRAILER **** SERVICE NAFIE : EDIT DATE : 98/06/24 ORIGIN : FLIC REEL NAME : 98268 CONTINUATION # PREVIOUS REEL : COF~4FJTT : ARCO ALASKA, DS 14-35 , PRUDHOE BAY, API #50-029-21018-00 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAF1E : ARCO ALASKA INC. WELL NAME : D.S. 14-35 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUM~ER : 500292101800 REFERENCE NO : 98061 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE . 98/02/ 9 ORIGIN : FLIC REEL NA~E : 98061 CONTINUATION # : PREVIOUS REEL : COF~NT : ARCO ALASKA INC, D.S. 14-35, PRUDHOE BAY, 50-029-21018-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/02/ 9 ORIGIN : FLIC TAPE NAME : 98061 CONTINUATION # : 1 PREVIOUS TAPE : CO~IElVT : ARCO ALASKA INC, D.S. 14-35, PRUDHOE BAY, 50-029-21018-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 14-35 API NUMBER'. 500292101800 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 9-FEB-98 JOB ~ER: 98061 LOGGING ENGINEER: G. ELMORE OPERATOR WITNESS: K. NEUPERT SURFACE LOCATION SECTION: 9 TOWNSHIP: 1 ON RANGE: 14E FArL: 31 FSL: FEL: 1218 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 69. O0 DERRICK FLOOR: 68. O0 GROUND LEVEL: 39. O0 WELL CASING RECORD 1ST STRING 2NDSTRING 3RDSTRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) .............................................. 9.675 8820.0 47.00 7.000 9500.0 29.00 5.500 8457.0 17.00 4.500 8554.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUM~ER: PASS NUFiBER: DATE LOGGED: 12-NOV-83 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 9303.5 9291.0 9287.5 9287.0 9285.5 9281.0 9276.0 9273.5 9264.0 9263.5 9253.0 9248.0 9247.5 9242.5 9242.0 9237.5 9237.0 9232.5 9224.0 9219.5 9212.5 9212.0 9209.5 9205.0 9197.0 9193.5 9186.5 9186.0 9183.5 9183.0 9180.5 9180.0 9173.0 9172.5 9168.5 9164.0 9163.5 9161.0 9160.5 9159.5 9159.0 9154.5 9150.5 9149.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP 88887.0 88887.5 9303.0 9290.0 9290.0 9287.5 9287.5 9285.0 9285.0 9280.5 9280.5 9275.0 9275.0 9273.5 9273.5 9263.5 9263.5 9253.0 9253.0 9248.5 9248.5 9242.0 9242.0 9237.0 9237.0 9231.0 9231.0 9223.0 9223.0 9217.5 9217.5 9213.5 9213.5 9209.0 9209.0 9206.0 9206.0 9196.5 9196.5 9194.0 9194.0 9186.0 9186.0 9184.0 9184.0 9180.0 9180.0 9174.0 9174.0 9167.5 9167.5 9164.5 9164.5 9161.0 9161.0 9159.0 9159.0 9154.0 9154.0 9150.5 9150.5 9147.5 9147.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9143.5 9143.0 9138.0 9137.0 9132.0 9130.0 9129.5 9125.5 9121.5 9119.0 9115.5 9112.5 9111.5 9109.0 9106.0 9104.0 9103.5 9095.0 9092.5 9092.0 9089 5 9088 5 9084 5 9082 0 9073 5 9071 0 9068 0 9065 0 9061 5 9059 0 9055 5 9051 5 9048 5 9048 0 9044 0 9033 5 9027 5 9026.5 9021.0 9016.0 9012.5 9008.0 9007.5 8999.0 8998.5 8990.0 8986.5 8983.5 8983.0 8979.0 8978.5 8969.5 8963.0 8957.5 8956.5 8956.0 9144.0 9138.0 9136.5 9132.5 9129.5 9125.5 9120.5 9116.5 9115.0 9112.0 9109.0 9106.0 9104.0 9094.5 9092.0 9090.0 9083.5 9081.5 9073.0 9071.5 9068.0 9064.5 9062.0 9059.0 9055.5 9051.5 9047.5 9044.0 9033.5 9026.0 9021.5 9016.5 9013.0 9007.5 8998.0 8990.0 8987.0 8983.5 8980.0 8969.5 8964.0 8958.0 8956.5 9144.0 9138.0 9136.5 9132.5 9129.5 9125.5 9120.5 9116.5 9115.0 9112.0 9109.0 9106.0 9104.0 9095.0 9092.0 9090.0 9083.5 9081.5 9073.0 9071.5 9068.0 9064.5 9062.0 9059.0 9055.5 9051.5 9047.5 9044.0 9033.5 9026.5 9021.5 9016.5 9013.0 9007.5 8998.0 8990.0 8987.0 8983.5 8980.0 8969.5 8964.0 8958.0 9-FEB-1998 11:01 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 8955 5 8954 0 8952 5 8951 0 8950 5 8947 0 8939 5 8939 0 8937 5 8937 0 8935.0 8933.0 8927.5 8924.5 8916.5 8914.5 8908.0 8906.0 8905.5 8900.5 8896.5 8881.0 8880.5 8875.0 8874.0 8871.0 8866.0 8859.5 8852.0 8851.0 100.0 $ 8956.5 8954.0 8954.0 8951.0 8950.5 8947.5 8947.5 8939.5 8939.5 8937.0 8937.0 8935.0 8935.0 8933.5 8933.5 8928.0 8928.0 8924.5 8924.5 8917.0 8917.0 8915.0 8915.0 8907.0 8906.0 8905.5 8901.0 8901.0 8896.5 8896.5 8880.5 8880.5 8875.0 8875.0 8871.5 8871.5 8866.0 8866.0 8858.5 8858.5 8853.5 8852.5 101.5 101.5 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE TDTP DATA AQUIRED ON ARCO ALASKA'S DS 14-35 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE BCS GAM~A RAY, ALSO SIGMA PASS #1 AND THE BCS GAMMA RAY, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAM~ : EDIT .001 SERVICE ' FLIC VERSION · O01CO1 DATE : 98/02/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PAGE: EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NU~BER: 1 DEPTH INCREME1Fr: 0.5000 FILE SO?4FiARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9296.0 8851.5 TDTP 9307.5 8851.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUFIBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. RE~zAR~S: THIS FILE CONTAINS CASED HOLE TDTP PASS #1. NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA THERE ARE ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP EL~4 CODE (HEX) DEPT FT 1119528 SIGMTDTP CU 1119528 TPHI TDTP PU-S 1119528 SBHF TDTP CU 1119528 SBHN TDTP CU 1119528 SIGC TDTP CU 1119528 SIBH TDTP CU 1119528 TRAT TDTP 1119528 SDSI TDTP CU 1119528 BACK TDTP CPS 1119528 FBAC TDTP CPS 1119528 TCAN TDTP CPS 1119528 O0 TCAF TDTP CPS 1119528 O0 TCND TDTP CPS 1119528 O0 TCFD TDTP CPS 1119528 O0 TSCN TDTP CPS 1119528 O0 TSCF TDTP CPS 1119528 O0 INND TDTP CPS 1119528 O0 INFD TDTP CPS 1119528 O0 GRCH TDTP GAPI 1119528 O0 TENS TDTP LB 1119528 O0 CCL TDTP V 1119528 O0 GR BCS GAPI 1119528 O0 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 * * DA TA * * DEPT. 9320.000 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP -999.250 SBPiN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP -999.250 TENS.TDTP -999.250 CCL.TDTP -999.250 GR.BCS 60.000 DEPT. 8840.000 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP -999.250 TENS.TDTP -999.250 CCL.TDTP -999.250 GR.BCS 145.125 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE · 98/02/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUPl~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUM~fARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9296.5 8851.0 TDTP 9307.0 8551.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS--ER: 1 BASELINE DEPTH 88888.0 9307.0 9297.5 9291.0 9288.0 9287.5 9285.5 9275.0 9270.0 9264.5 9263.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP .............. 88887.5 88887.0 9290.5 9288.0 9275.5 9270.5 92 63.5 9306.0 9296.5 9287.5 9285.0 9264.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PAGE: 9256.0 9254.5 9254.0 9246.0 9245.0 9242.0 9236.5 9235.0 9232.5 9228.5 9226.0 9221.5 9220.5 9218.0 9214.0 9211.0 9207.0 9206.5 9203.5 9201.5 9199.0 9196.5 9195.5 9192.5 9188.5 9188.0 9186.0 9183.5 9182.5 9180.5 9180.0 9176.5 9175.5 9169.0 9162.5 9158.5 9157.0 9155.5 9152.0 9150.5 9149 0 9146 0 9144 5 9143 5 9138 0 9134 5 9132 5 9131 5 9130 0 9129 0 9126 0 9125 0 9121 0 9117 5 9112 0 9255.5 9253.0 9247.5 9237.0 9231.0 9222.5 9217.5 9212.0 9206.5 9202.5 9199.0 9196.5 9194.0 9188.0 9186.0 9184.0 9180.0 9177.5 9167.5 9162.5 9159.0 9158.0 9153.0 9150.5 9147.0 9146.0 9144.0 9138.0 9135.5 9132.0 9129.5 9125.5 9120.5 9115.0 9255.0 9245.0 9242.0 9237.0 9231 0 9225 5 9220 0 9214 5 9207 5 9204 5 9195.5 9188.5 9186.5 9183.5 9180.0 9176.0 9168.5 9154.5 9143.5 9135.0 9133.5 9129.5 9125.0 9112.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PAGE: 9111.5 9109.0 9108.5 9104.5 9098.0 9094.5 9093.0 9089.0 9086.0 9084 5 9081 5 9078 5 9073 0 9071 0 9069 5 9068.0 9065.0 9060.0 9058.0 9056.5 9055.0 9054.0 9051.5 9043.5 9041.0 9037.0 9031.5 9027.0 9021.5 9021.0 9015.5 9012.5 9008.0 9004.5 9000.0 8998.5 8997.5 8995.5 8992.0 8991.5 8990.0 8989.5 8986.5 8986.0 8982.5 8980.0 8978.0 8973.0 8972.0 8969.5 8969.0 8962.5 8959.5 8955.0 8953.5 9112.5 9109.0 9094.5 9093.0 9090.5 9086.5 9081.5 9071.5 9070.0 9068.0 9065.5 9059.5 9056.5 9055.5 9052.0 9044.0 9038.5 9022.0 9016.0 9013.0 8999.5 8998.0 8993.0 8990.0 8987.0 8980.0 8973.0 8969.5 8963.5 8954.0 9109.0 9104.5 9099.0 9095.0 9090.0 9083.5 9080.0 9073.0 9070.0 9060.5 9054.5 9044.0 9041.0 9032.0 9026.5 9022.0 9007.5 9004.5 8998.0 8995.0 8992.0 8990.5 8987.0 8983.5 8980.0 8972.5 8969.0 8961.5 8956.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PAGE: 10 8952.0 8953.5 8950.0 8950.5 8946.5 8947.5 8947.5 8942.5 8944.0 8939.5 8939.5 8939.0 8939.5 8937.5 8937.0 8934.5 8935.0 8930.5 8931.5 8930.0 8931.0 8924.5 8925.0 8925.0 8921.0 8921.5 8919.5 8920.0 8918.5 8919.5 8916.5 8917.5 8915.5 8916.0 8914.5 8915.0 8913.5 8914.5 8912.5 8914.0 8910.5 8911.0 8908.0 8907.0 8906.5 8907.0 8905.5 8905.5 8903.0 8903.5 8900.5 8901.0 8899.5 8900.0 8898.5 8898.5 8896.0 8896.5 8894.0 8894.0 8891.0 8892.0 8889.5 8889.5 8885.5 8886.0 8885.0 8885.0 8881.5 8881.0 8880.5 8880.5 8876.5 8877.5 8875.0 8875.0 8873.5 8875.0 8871.0 8871.5 8871.5 8866.0 8866.0 8865.0 8867.0 8860.0 8858.5 8853.5 8854.5 8852.0 8853.0 100.0 101.0 101.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO SIGMA PASS #2 AND SIGMA PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 SIGMTDTP CU 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 SBHI~TDTP CU 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 FBACTDTP CPS 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 TSCNTDTP CPS 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 1119528 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PAGE: 12 ** DATA ** DEPT. 9307.000 SIGM. TDTP 14.714 TPHI.TDTP SBHN. TDTP 51.308 SIGC. TDTP 1.018 SIBH. TDTP SDSI.TDTP 0.307 BACK. TDTP 137.258 FBAC. TDTP TCAF. TDTP 16055.965 TCND. TDTP 24553.242 TCFD. TDTP TSCF. TDTP 3094.164 INND. TDTP 2878.685 INFD. TDTP TENS. TDTP 1285.000 CCL. TDTP 0.000 DEPT. 8851.000 SIGM. TDTP 19.119 TPHI.TDTP SBHN. TDTP 52.146 SIGC. TDTP 2.426 SIBH. TDTP SDSI.TDTP 0.578 BACK. TDTP 180.874 FBAC. TDTP TCAF. TDTP 11891.387 TCND. TDTP 22037.863 TCFD. TDTP TSCF. TDTP 2308.139 INND. TDTP 2719.229 INFD. TDTP TENS. TDTP 1205.000 CCL.TDTP 0.000 30. 382 SBHF. TDTP 61. 666 TRAT. TDTP 29.840 TCAN. TDTP 7858. 486 TSCN. TDTP 415. 823 GRCH. TDTP 28. 038 SBHF. TDTP 62. 549 TRAT. TDTP 39. 594 TCAN. TDTP 7267. 756 TSCN. TDTP 444. 471 GRCH. TDTP 45.057 1.831 39346.070 7582.427 -999.250 36.349 1. 621 28076.188 5449. 638 65. 500 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION - O01CO1 DATE : 98/02/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE ' 98/02/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INC~: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH GRCH 9297.0 TDTP 9311.0 STOP DEPTH 8551.0 8550.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PA GE: 13 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUM~ER: 1 BASELINE DEPTH 88888.0 9300.0 9294.5 9292.5 9287.5 9287.0 9281.5 9275.0 9274.5 9271.5 9271.0 9263.5 9255.0 9254.0 9252.5 9249.5 9244.5 9235.5 9231.5 9230.0 9225.5 9223.0 9221.5 9219.5 9216.0 9213.0 9211.5 9209.5 9209.0 9206.0 9205.0 9201.5 9196.5 9194.5 9186.0 9183.5 9182.0 9180.0 9176.0 9175.0 9174.5 9172.0 9171.5 9169.0 9167.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88888.0 88891.0 9287.5 9275.0 9270.5 92 63.5 9255.5 9253.0 9248.0 9231.0 9222.5 9220.0 9217.5 9212.5 9209.5 9207.0 9202.0 9196.5 9194.5 9186.0 9184.0 9180.0 9177.0 9174.5 9173.0 9167.5 9303.0 9294.5 9290.5 9288.0 9281.0 9274.5 9270.0 92 63.5 9255.5 9245.0 9236.5 9229.0 9225.0 9220.5 9216.0 9213.0 9209.5 9207.0 9195.5 9183.0 9180.5 9176.0 9172.0 9168.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PA GE: 14 9163.0 9160.0 9157.5 9151.5 9143.0 9141.0 9137.5 9135.0 9132.5 9129.5 9128.5 9124.5 9119.5 9117.5 9112.0 9111.0 9108.5 9104.0 9102.5 9099.5 9097.5 9094.5 9093.0 9088.5 9084.5 9081.0 9076 0 9074 5 9072 5 9069 5 9069 0 9067 5 9064 0 9054 5 9054 0 9051.0 9050.0 9043.5 9040.5 9038.5 9031.5 9025.0 9021.5 9021.0 9015.5 9009.5 9006.5 9004.5 8999.5 8998.5 8991.5 8989.5 8986.5 8985.5 8982.5 9161.0 9157.5 9152.0 9144.0 9135.0 9129.5 9125.5 9115.0 9112.5 9109.0 9104.0 9099.5 9094.5 9093.0 9090.0 9081.5 9077.0 9O73.0 9070.0 9068.0 9065.0 9055.5 9049.5 9044.0 9038.5 9022.0 9016.5 9007.5 8998.0 8990.5 8987.0 9164.0 9157.5 9142.5 9137.5 9134.0 9129.5 9119.0 9112.0 9109.0 9104.0 9099.0 9095.0 9090.0 9084.0 9075.5 9070.5 9054.5 9052.0 9041.0 9032.0 9024.5 9022.5 9010.0 9004.0 8998.0 8992.0 8990.5 8987.0 8983.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PAGE: 15 8979.0 8980.0 8978.5 8980.5 8972.0 8972.5 8972.5 8969.0 8969.5 8968.5 8968.5 8962.5 8964.0 8959.5 8962.0 8957.5 8958.5 8955.0 8956.5 8953.5 8954.0 8951.5 8953.0 8949.5 8950.5 8946.5 8947.5 8946.0 8947.0 8942.5 8943.0 8939.0 8939.5 8938.5 8939.5 8934.5 8935.0 8930.0 8931.0 8927.5 8928.5 8924.5 8925.0 8924.0 8924.5 8918.5 8919.5 8916.5 8917.0 8915.0 8916.0 8914.5 8915.0 8915.5 8910.5 8912.0 8907.5 8907.0 8906.5 8907.0 8905.0 8905.5 8899.0 8900.0 8898.5 8898.5 8896.0 8896.5 8894.0 8894.0 8892.0 8892.5 8889.0 8890.0 8885.5 8885.5 8884.5 8886.0 8881.5 8881.0 8880.5 8880.5 8876.5 8877.5 8874.5 8875.0 8874.0 8875.5 8870.5 8871.5 8870.0 8871.0 8866.5 8866.0 8867.5 8859.0 8858.5 8853.0 8853.0 8852.0 8853.0 100.0 101.0 100.0 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCH PASS #1, ALSO SIGMA PASS #3 AND SIGMA LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PAGE: 16 PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 TSCNTDTP CPS 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-19~8 11:01 PAGE: 17 NA~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) INND TDTP CPS 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 1119528 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9311 SBHN. TDTP 51 SDSI.TDTP 0 TCAF. TDTP 16036 TSCF. TDTP 3081 TENS. TDTP 1290 DEPT. 8850 SBHN. TDTP 50 SDSI.TDTP 0 TCAF. TDTP 12329 TSCF. TDTP 2373 TENS. TDTP 1210 000 SIGM. TDTP 14.617 TPHI.TDTP 27.876 SBHF. TDTP 39.346 338 SIGC. TDTP 1.244 SIBH. TDTP 61.188 TRAT. TDTP 1.765 364 BACK. TDTP 182.421 FBAC. TDTP 35.940 TCAN. TDTP 37799.258 465 TCND. TDTP 24142.004 TCFD. TDTP 7843.539 TSCN. TDTP 7263.261 463 INND. TDTP 2851.072 INFD. TDTP 428.290 GRCH. TDTP -999.250 000 CCL. TDTP 0.000 000 SIGM. TDTP 17.231 TPHI. TDTP 23.179 SBHF. TDTP 38.426 367 SIGC. TDTP 3.295 SIBH. TDTP 57.916 TRAT. TDTP 1.560 552 BACK. TDTP 220.675 FBAC. TDTP 42.813 TCAN. TDTP 27798.613 729 TCND. TDTP 21853.910 TCFD. TDTP 7394.022 TSCN. TDTP 5350.370 090 INND. TDTP 2872.024 INFD. TDTP 421.510 GRCH. TDTP -999.250 000 CCL.TDTP 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE ' FLIC VERSION ' O01CO1 DATE : 98/02/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 98/02/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-19~8 11:01 PAGE: 18 FILE HEADER FILE NUFIBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, TDTP THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES 1,2, &3.THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA2~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PNAV CU 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PNAV PU-S 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF PNAV CU 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-199~ 11: O1 PAGE: 19 NAPiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) SBHNPNAV CU 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC PNAV CU 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH PNAV CU 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PNAV 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI PNAV CU 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 TCANPNAV CPS 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 TCAFPNAV CPS 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 TCNDPNAV CPS 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 TCFDPNAV CPS 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 TSCNPNAV CPS 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF PNAV CPS 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 INNDPNAV CPS 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 INFD PNAV CPS 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1119528 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9307.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV SDSI.PNAV -999.250 BACK. TDTP 44.529 FBAC. TDTP 12.241 TCAN. PNAV TCAF.PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV TSCF. PNAV -999.250 INND. PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP -999.250 -999.250 -999.250 -999.250 -999.250 DEPT. 8851.500 SIGM. PNAV 17.307 TPHI.PNAV 24.920 SBHF. PNAV 39.803 SBH~.PNAV 49.982 SIGC. PNAV 3.070 SIBH. PNAV 57.505 TRAT. PNAV 1.608 SDSI.PNAV 0.533 BACK. TDTP 127.698 FBAC. TDTP 31.453 TCAN. PNAV 29474.215 TCAF. PNAV 12814.396 TCND.PNAV 22429.219 TCFD. PNAV 7473.519 TSCN. PNAV 5700.710 TSCF. PNAV 2478.312 INND.PNAV 2744.426 INFD. PNAV 441.441 GRCH. TDTP 63.750 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE · 98/02/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-19~ 11:01 PAGE: 2O **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION · 001C01 DATE : 98/02/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 1 DEPTH INCREMF2FP: 0.5000 FILE SUFMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9334.0 8846.0 TDTP LOG HEADER DATA DATE LOGGED: 28-SEP-97 SOFTWARE VERSION: CP 44.2 TII4~ LOGGER ON BOTTOM: 1403 28-SEP-97 TD DRILLER (FT): 9345.0 TD LOGGER (FT) : 9327.0 TOP LOG INTERVAL (FT): 8850.0 BOTTOM LOG INTERVAL (FT) : 9345.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : TOOL NUMBER ........... CGRS-A-862 TDT SET 21 9500.0 PUMPED IN CRUDE 30.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PAGE: 21 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS BHCS DATED 12 NOV 83 ALL LOGGING PASSES MADE AT 1800 FPH PUMPED 250 BBLS CRUDE AT 5 BPM, THEN 1 BPM DURING LOGGING. FIELD PICK GOC 9095 TOTAL FLUIDS PUMPED: 333 BBLS CRUDE, 10 BBLD DIESEL FLUSH. THIS FILE CONTAINS THE RAW DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PAGE: 22 TYPE REPR CODE VALUE 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS1 CU 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF PS1 CU 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 SBHNPS1 CU 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC PS1 CU 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH PS1 CU 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI PS1 CU 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 BACK PS1 CPS 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS1 CPS 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 TCANPS1 CPS 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 TCAFPS1 CPS 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 TCNDPS1 CPS 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 TCFDPS1 CPS 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN PS1 CPS 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF PS1 CPS 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 INND PS1 CPS 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 INFD PS1 CPS 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1119528 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9320.000 SIGM. PS1 17.593 TPHI. PS1 31.910 SBHF. PS1 SBHN. PS1 56.502 SIGC.PS1 1.112 SIBH. PS1 74.365 TRAT. PSl SDSI.PSl 0.410 BACK. PSi 45.413 FBAC. PS1 11.152 TCAN. PS1 TCAF. PS1 11888.512 TCND.PS1 22598.387 TCFD. PS1 6951.927 TSCN. PS1 TSCF. PS1 2316.104 INND.PS1 3168.604 INFD.PS1 433.897 TENS. PSi GR.PS1 7.234 CCL.PS1 0.000 DEPT. 8846.000 SIGM. PS1 21.735 TPHI.PS1 31.266 SBHF. PS1 SBHI~.PS1 43.519 SIGC. PS1 3.312 SIBH. PS1 44.856 TRAT. PS1 SDSI.PS1 0.681 BACK. PSI 120.635 FBAC. PS1 29.022 TCAN. PS1 TCAF. PS1 9537.385 TCND.PS1 21338.176 TCFD. PS1 6443.040 TSCN. PS1 TSCF. PS1 1817.893 INND.PS1 2893.375 INFD. PS1 431.426 TENS.PSi GR.PS1 52.719 CCL.PS1 0.000 45.324 1.734 29041.836 5657.892 1275.000 39.182 1.740 25439.598 4835.509 1235.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PAGE: 23 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION : O01CO1 DATE ' 98/02/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE ' FLIC VERSION · O01CO1 DATE : 98/02/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUf4~IARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9334.0 8846.0 TDTP LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 28-SEP-97 CP 44.2 1403 28-SEP-97 9345.0 9327.0 8850.0 9345.0 1800.0 TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11: 01 PAGE: 24 GR GAMM~A RAY TDTP THERMAL DECAY $ CGRS-A - 862 TDT SET 21 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9500.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PUMPED IN CRUDE 30.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): RE~AR~S: CORRELATED TO SWS BHCS DATED 12 NOV 83 ALL LOGGING PASSES MADE AT 1800 FPH PUMPED 250 BBLS CRUDE AT 5 BPM, THEN 1 BPM DURING LOGGING. FIELD PICK GOC 9095 TOTAL FLUIDS PUMPED: 333 BBLS CRUDE, 10 BBLD DIESEL FLUSH. THIS FILE CONTAINS THE RAW DATA FOR PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PAGE: 25 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PS2 CU 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 SBHNPS2 CU 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PS2 CU 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PS2 CU 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PS2 CU 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 BACK PS2 CPS 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 CPS 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 TCANPS2 CPS 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 TCAFPS2 CPS 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 TCND PS2 CPS 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 TCFDPS2 CPS 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN PS2 CPS 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PS2 CPS 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 INNDPS2 CPS 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 INFD PS2 CPS 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1119528 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11: O1 PAGE: 26 ** DATA ** DEPT. 9320.000 SIGM. PS2 SBHN. PS2 57.466 SIGC. PS2 SDSI.PS2 0.503 BACK. PS2 TCAF. PS2 10601.381 TCND.PS2 TSCF. PS2 2031.239 INND.PS2 GR.PS2 169.125 CCL.PS2 17.686 TPHI.PS2 1.473 SIBH. PS2 137.335 FBAC. PS2 21139.195 TCFD. PS2 2743.002 INFD.PS2 0.000 31.809 76.552 31.925 6412.555 415.428 SBHF. PS2 TRAT. PS2 TCAN. PS2 TSCN. PS2 TENS.PS2 50.937 1.723 26310.633 5041.151 1285.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUM~ER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 9334.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TII4E LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : STOP DEPTH 8846.0 28-SEP-97 CP 44.2 1403 28-SEP-97 9345.0 9327.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PAGE: 27 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY TDTP THERMAL DECAY $ 8850.0 9345.0 1800.0 TOOL NUMBER CGRS-A-862 TDT SET 21 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9500.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PUMPED IN CRUDE 30.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS BHCS DATED 12 NOV 83 ALL LOGGING PASSES MADE AT 1800 FPH PUMPED 250 BBLS CRUDE AT 5 BPM, THEN 1 BPM DURING LOGGING. FIELD PICK GOC 9095 TOTAL FLUIDS PUMPED: 333 BBLS CRUDE, 10 BBLD DIESEL FLUSH. THIS FILE CONTAINS THE RAW DATA FOR PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PAGE: 28 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~I~ SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID O.RDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PS3 CU 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 SBHNPS3 CU 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PS3 CU 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PS3 CU 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PS3 CU 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 BACK PS3 CPS 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 CPS 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPS3 CPS 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 TCAFPS3 CPS 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 TCNDPS3 CPS 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 TCFDPS3 CPS 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PS3 CPS 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS3 CPS 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 INNDPS3 CPS 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PS3 CPS 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1119528 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-FEB-1998 11:01 PAGE '. 29 ** DATA ** DEPT. 9320.000 SIGM. PS3 18.936 TPHI.PS3 SBHN. PS3 54.745 SIGC.PS3 1.817 SIBH. PS3 SDSI.PS3 0.581 BACK. PS3 205.819 FBAC. PS3 TCAF. PS3 9911.582 TCND.PS3 20121.480 TCFD.PS3 TSCF. PS3 1899.558 INND.PS3 2819.833 INFD. PS3 GR.PS3 85.250 CCL.PS3 0.000 28.938 SBHF. PS3 69.545 TRAT. PS3 46.502 TCAN. PS3 6209.347 TSCN. PS3 419.379 TENS.PS3 47.822 1.625 23207.961 4447.813 1270.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/02/ 9 ORIGIN : FLIC TAPE NAME : 98061 CONTINUATION # : 1 PREVIOUS TAPE : CO~NT : ARCO ALASKA INC, D.S. 14-35, PRUDHOE BAY, 50-029-21018-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE . 98/02/ 9 ORIGIN : FLIC REEL NA~E : 98061 CONTINUATION # : PREVIOUS REEL COf4~_2TT : ARCO ALASKA INC, D.S. 14-35, PRUDHOE BAY, 50-029-21018-00 * HI4HH HHHH * * HHHH HHHH H H A LL LL II BBBB U U RRRR TTTTT O N N * * HHHH HHHH H H AA LL LL II B B U U R R T O O NN N * * HttttI'tI'II'IHI~ ~ A A LL LL II BBBB U U I:[RRR T O O N N N * * HP]HI~%~I~%~HHH H H AAAA LL LL II B B U U R R T O O N NN * * ~ ~ H H A ALL LL II BBBB U R R T O N N * *HHHH HHHH L O G G I N G S E R V I C E S , I N C . * * LIS TAPE VERIFICATION LISTING * ARCO ALASKA INC. * DS 14-35 * PRUDHOE BAY * NORTH SLOPE * ALASKA . * (DUAL SPACED NEUTRON LOG) . . . ******************************************************************************** RECEIVED FEB 0 1 92 Alaska 011 & Gas Cons. Commission Anchorage Page 1 REEL HEADER RECORD TYPE 132 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER PREVIOUS REEL NAME COMMENTS: --- COMCEN --- 92/01/06 --- ANCH --- 667513 TAPE HEADER RECORD TYPE 130 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER PREVIOUS TAPE NAME COMMENTS: --- COMCEN --- 92/01/06 --- ANCH ~m 0 COMMENT RECORD TYPE 232 TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0 ) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 14-35 500292101800 ARCO ALASKA INC. HALLIBURTON LOGGING SERVICES 06-JAN-92 L66751-3 HUCKFELDT DETHLEFS 09 i0N 14E 313 1218 69.00 66.00 39.00 Page 2 WELL CASING RECORD OPEN HOLE CASING DRILLER'S CASING BIT SIZE(IN) SIZE(IN) DEPTH(FT) WEIGHT (LB/FT) lST STRING 13.375 2676.0 72.00 2ND STRING 9.625 8820.0 47.00 3RD STRING 8.500 7.000 9500.0 29.00 PRODUCTION STRING 8.500 5.500 8457.0 17.00 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: GR PBU CURVE CODE: BCS RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: N/A BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH .......... CNSG 8820.0 8821.0 8842.5 8841.5 8849.0 8848.0 8872.5 8870.5 8913.0 8911.0 8954.5 8953.0 9044.5 9043.5 9110.0 9109.5 9181.0 9180.5 9245.0 9245.0 9290.0 9290.0 $ REMARKS: TIED INTO SCHLUMBERGER BCS LOG DATED 12-NOV-83 AND CNL DATED 06-APR-87. $ ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.001 --- 92/01/06 --- 1024 --- LO ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: EDITED CURVES 01 Page 3 Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 01 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL coDE START DEPTH STOP DEPTH CNSG 9290.0 8820.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH CNSG NO NPHI CURVE PRESENTED DUE TO INABILITY TO RECOMPUTE AT THIS TIME. CPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE: 8.5" CASING SIZE: 7.0" CASING WT.: 29.0~ PASS #1 LOGGED WITH WELL STATIC. PRESSURE: 2600 PSI AT SURFACE FLUID LEVEL: +/- 8700'. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 24 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 42 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F API CODE FILE~ 00000000 0 SIZE #SAMP REPR. 4 1 68 Page 4 GRCH CNSG 667513 GAPI 00000000 0 4 1 68 FUCT CNSG 667513 CPS 00000000 0 4 1 68 NUCT CNSG 667513 CPS 00000000 0 4 1 68 CPHI CNSG 667513 PU-S 00000000 0 4 1 68 NRAT CNSG 667513 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9290.000 GRCH = 30.300 FUCT = 356.800 NUCT = 404.500 CPHI = 25.840 NRAT = 1.160 DEPT = 9190.000 GRCH = 28.300 FUCT = 355.200 NUCT = 414.300 CPHI = 27.200 NRAT = 1.187 DEPT = 9090.000 GRCH = 32.300 FUCT = 423.400 NUCT = 493.800 CPHI = 26.730 NRAT = 1.187 DEPT = 8990.000 GRCH = 50.400 FUCT = 554.000 NUCT = 575.600 CPHI = 19.980 NRAT = 1.050 DEPT = 8890.000 GRCH = 89.900 FUCT = 391.300 NUCT = 441.000 CPHI = 25.080 NRAT = 1.156 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.001 ~tt 0 --- 92/01/06 --- 1024 --- LO --- COMCEN.002 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.002 mt~ 0 --- 92/01/06 --- 1024 --- LO --- COMCEN.001 COMMENT RECORD TYPE 232 Page 5 FILE HEADER FILE NUMBER: 02 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 02 DEPTH INCREMENT: 0. 5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH CNSG 9289.0 8835.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 01 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH CNSG 8834.5 8835.0 8870.5 8871.0 8911.0 8911.5 8953.0 8953.5 9043.5 9044.0 9109.5 9110.0 9180.5 9181.0 9245.0 9245.0 9289.0 9290.0 $ REMARKS: NO NPHI CURVE PRESENTED DUE TO INABILITY TO RECOMPUTE AT THIS TIME. CPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE: 8.5" CASING SIZE: 7.0" CASING WT.: 29.02 PASS 22 LOGGED AFTER PUMPING 250 BBLS SEAWATER. FLUID LEVEL: FULL $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 24 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN Page 6 11 2 79 12 4 68 14 4 65 15 1 66 16 1 66 0 1 66 42 -999.000 F 68 1 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS DEPT F GRCH CNSG 667513 GAPI FUCT CNSG 667513 CPS NUCT CNSG 667513 CPS CPHI CNSG 667513 PU-S NRAT CNSG 667513 AP1 CODE FILE~ SIZE #SAMP REPR. 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9289.000 GRCH = 26.400 FUCT = 358.400 NUCT = 412.200 CPHI = 26.040 NRAT = 1.172 DEPT = 9189.000 GRCH = 28.900 FUCT = 355.700 NUCT = 413.600 CPHI = 26.800 NRAT = 1.193 DEPT = 9089.000 GRCH = 27.600 FUCT = 388.800 NUCT = 455.700 CPHI = 26.880 NRAT = 1.196 DEPT = 8989.000 GRCH = 50.600 FUCT = 425.500 NUCT = 445.100 CPHI = 21.240 NRAT = 1.060 DEPT = 8889.000 GRCH = 76.900 FUCT = 396.300 NUCT = 432.900 CPHI = 23.110 NRAT = 1.129 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.002 --- 92/01/06 --- 1024 --- LO --- COMCEN.003 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME --- COMCEN.003 Page 7 VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME ------ 5 --- 92/01/06 --- 1024 --- LO --- COMCEN. 002 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 03 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 03 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH CNSG 9290.0 8835.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 01 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH CNSG NO NPHI CURVE PRESENTED DUE TO INABILITY TO RECOMPUTE AT THIS TIME. CPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE: 8.5" CASING SIZE: 7.0" CASING WT.: ~29.0~ PASS 23 LOGGED WHILE PUMPING AT 1 BBL/MIN. FLUID LEVEL: FULL $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 24 4 1 66 1 5 1 66 1 Page 8 8 4 73 9 4 65 11 2 79 12 4 68 14 4 65 15 1 66 16 1 66 0 1 66 60 .liN 42 -999.000 F 68 1 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F GRCH CNSG 667513 GAPI FUCT CNSG 667513 CPS NUCT CNSG 667513 CPS CPHI CNSG 667513 PU-S NRAT CNSG 667513 AP1 CODE FILE~ SIZE ~SAMP REPR. 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9290.000 GRCH = 30.900 FUCT = 358.500 NUCT = 411.900 CPHI = 26.280 NRAT = 1.174 DEPT = 9190.000 GRCH = 25.100 FUCT = 353.700 NUcT = 410.900 CPHI = 26.760 NRAT = 1.183 DEPT = 9090.000 GRCH = 28.600 FUCT = 382.900 NUCT = 440.500 CPHI = 26.430 NRAT = 1.173 DEPT = 8990.000 GRCH = 52.700 FUCT = 476.600 NUCT = 489.200 CPHI = 20.460 NRAT = 1.050 DEPT = 8890.000 GRCH = 81.700 FUCT = 332.700 NUCT = 399.600 CPHI = 28.560 NRAT = 1.234 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.003 ----m 0 --- 92/01/06 --- 1024 --- LO --- COMCEN.004 FILE HEADER RECORD TYPE 128 Page 9 FILE NAM~ SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.004 ~wm 0 --- 92/01/06 --- 1024 --- COMCEN.003 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 04 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 04 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH CNSG 9290.0 8835.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 01 EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH CNSG NO NPHI CURVE PRESENTED DUE TO INABILITY TO RECOMPUTE AT THIS TIME. CPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE: 8.5" CASING SIZE: 7.0" CASING WT.: 29.0~ PASS #4 LO~GED AFTER PUMPING ABOUT 325 BBLS. FLUID LEVEL: FULL $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 24 Page 10 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 42 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM DEPT GRCH FUCT NUCT CPHI NRAT SERVID SERVICE# UNITS API CODE FILES SIZE #SAMP REPR. F 00000000 0 4 1 68 CNSG 667513 GAPI 00000000 0 4 1 68 CNSG 667513 CPS 00000000 0 4 1 68 CNSG 667513 CPS 00000000 0 4 1 68 CNSG 667513 PU-S 00000000 0 4 1 68 CNSG 667513 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9290.000 GRCH = 31.800 FUCT = 348.000 NUCT = 408.600 CPHI = 27.420 NRAT = 1.199 DEPT = 9190.000 GRCH = 27.600 FUCT = 361.700 NUCT = 410.900 CPHI = 25.970 NRAT = 1.160 DEPT = 9090.000 GRCH = 26.400 FUCT = 391.700 NUCT = 449.800 CPHI = 26.680 NRAT = 1.177 DEPT = 8990.000 GRCH = 54.100 FUCT = 503.400 NUCT = 505.200 CPHI = 20.760 NRAT = 1.027 DEPT = 8890.000 GRCH = 91.100 FUCT = 335.500 NUCT = 390.700 CPHI = 26.600 NRAT = 1.187 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.004 --- 92/01/06 --- 1024 --- LO --- COMCEN.005 Page 11 FILE HEADER RECORD FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.005 ----g 0 --- 92/01/06 --- 1024 --- LO --- COMCEN.004 TYPE 128 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 05 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS CNSG $ REMARKS: 02,03,04 NO NPHI CURVE PRESENTED DUE TO INABILITY TO RECOMPUTE AT THIS TIME. CPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE: 8.5" CASING SIZE: 7.0" CASING WT.: 29.02 PASS 2, 3 & 4 ONLY USED FOR AVERAGE. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 24 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 42 12 4 68 -999.000 Page 12 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS DEPT F GRCH CNAV 667513 GAPI FUCT CNAV 667513 CPS NUCT CNAV 667513 CPS CPHI CNAV 667513 PU-S NRAT CNAV 667513 API CODE FILE~ SIZE #SAMP REPR. 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9289.000 GRCH = 29.733 FUCT = 358.500 NUCT = 418.133 CPHI = 26.707 NRAT = 1.188 DEPT = 9189.000 GRCH = 30.000 FUCT = 353.033 NUCT = 410.500 CPHI = 26.823 NRAT = 1.190 DEPT = 9089.000 GRCH = 28.700 FUCT = 382.700 NUCT = 447.333 CPHI = 26.513 NRAT = 1.191 DEPT = 8989.000 GRCH = 54.167 FUCT = 430.233 NUCT = 458.300 CPHI = 22.213 NRAT = 1.084 DEPT = 8889.000 GRCH = 74.000 FUCT = 385.300 NUCT = 440.233 CPHI = 23.717 NRAT = 1.163 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.005 --- 92/01/06 --- 1024 --- LO --- COMCEN.006 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION --- COMCEN. 006 ~ 0 --- 92/01/06 Page 13 MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- 1024 --- LO --- COMCEN. 005 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 06 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 01 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNT $ LOG HEADER DATA 9299.5 8821.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 28-JUL-91 DDL1 0092-49 1000 28-JUL-91 9500.0 9302.0 8819.0 9300.0 1800.0 NO TOOL NUMBER GR GAMMA RAY CNT COMP. NEUTRON (G) $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): 33006 27002 8.500 9500.0 PRODUCED/SEAWATER 57.0 182.0 15000 1.000 Page 14 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 8.500 NORMALIZATION WINDOW START DEPTH (FT): STOP DEPTH (FT): AMOUNT: 9156.0 9068.0 GAS SCALING FACTOR FOR NEAR AND FAR COUNTS: MULTIPLIER: 60.000 TOOL STANDOFF (IN): 0.0 REMARKS: NPNI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE: 8.5" CASING SIZE: 7.0" CASING WT.: 29.0# PASS #1 LOGGED WITH WELL STATIC. PRESSURE: 2600 PSI AT SURFACE FLUID LEVEL: +/- 8700'. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 28 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 36 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS DEPT F GR CNT 667513 GAPI MCCL CNT 667513 MV RCCL CNT 667513 MV FCNL CNT 667513 CPS NCNL CNT 667513 CPS API CODE FILE~ SIZE #SAMP REPR. 00000000 0 4 1 68 00310010 0 4 1 68 00150010 0 2 1 79 00150010 0 2 1 79 00334300 0 4 1 68 00334300 0 4 1 68 Page 15 NPHI CNT 667513 %-SS 00000000 0 4 1 68 NRAT CNT 667513 C/C 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9299.500 GR = .000 MCCL = 0 RCCL = 0 FCNL = .000 NCNL = .000 NPHI = 20.760 NRAT = -999.000 DEPT = 9199.500 GR = 27.100 MCCL = 300 RCCL = 28 FCNL = 580.500 NCNL = 546.900 NPHI = 16.368 NRAT = .963 DEPT = 9099.500 GR = 31.300 MCCL = 271 RCCL = 48 FCNL = 378.700 NCNL = 464.200 NPHI = 30.160 NRAT = 1.242 DEPT = 8999.500 GR = 34.900 MCCL = 278 RCCL = -8 FCNL = 589.100 NCNL = 588.100 NPHI = 17.696 NRAT = 1.017 DEPT = 8899.500 GR = 126.900 MCCL = 290 RCCL = 0 FCNL = 328.500 NCNL = 421.800 NPHI = 31.290 NRAT = 1.297 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.006 --- 92/01/06 --- 1024 --- LO --- COMCEN.007 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.007 --- 92/01/06 --- 1024 --- LO --- COMCEN.006 COMMENT RECORD TYPE 232 Page 16 FILE HEADER FILE NUMBER: 07 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 02 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNT 9299.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 8835.0 28-JUL-91 DDL1 0092-49 1000 28-JUL-91 9500.0 9302.0 8819.0 9300.0 1800.0 NO TOOL NUMBER GR GAMMA RAY CNT COMP. NEUTRON (G) $ 33006 27002 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 9500.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG)= PRODUCED/SEAWATER 57.0 182.0 15000 1.000 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 8.500 Page 17 NORMALIZATION WINDOW START DEPTH ( FT ): STOP DEPTH (FT): AMOUNT: 9156.0 9068.0 GAS SCALING FACTOR FOR NEAR AND FAR COUNTS: MULTIPLIER: 60.000 TOOL STANDOFF (IN): 0.0 REMARKS: NPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE: 8.5" CASING SIZE: 7.0" CASING WT.: 29.0# PASS #2 LOGGED AFTER PUMPING 250 BBLS SEAWATER. FLUID LEVEL: FULL $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 28 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 36 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS API CODE FILE~ SIZE ~SAMP REPR. DEPT F 00000000 0 4 1 68 GR CNT 667513 GAPI 00310010 0 4 1 68 MCCL CNT 667513 MV 00150010 0 2 1 79 RCCL CNT 667513 MV 00150010 0 2 1 79 FCNL CNT 667513 CPS 00334300 0 4 1 68 NCNL CNT 667513 CPS 00334300 0 4 1 68 NPHI CNT 667513 %-SS 00000000 0 4 i 68 NRAT CNT 667513 C/C 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9299.500 GR = .000 MCCL = 0 Page 18 RCCL = 0 FCNL = .000 NCNL = .000 NPHI = 24.120 NRAT = -999.000 DEPT = 9199.500 GR = 31.000 MCCL = 556 RCCL = 9 FCNL = 563.100 NCNL = 559.900 NPHI = 17.791 NRAT = 1.009 DEPT = 9099.500 GR = 27.800 MCCL = 570 RCCL = 9 FCNL = 337.600 NCNL = 414.600 NPHI = 29.260 NRAT = 1.245 DEPT = 8999.500 GR = 28.400 MCCL = 527 RCCL = -19 FCNL = 537.600 NCNL = 528.600 NPHI = 17.906 NRAT = 1.008 DEPT = 8899.500 GR = 124.600 MCCL = 538 RCCL = -28 FCNL = 265.800 NCNL = 365.400 NPHI = 40.160 NRAT = 1.383 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.007 ~ 0 --- 92/01/06 --- 1024 --- LO --- COMCEN.008 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.008 ~B 0 --- 92/01/06 --- 1024 --- LO --- COMCEN.007 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 08 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 03 Page 19 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNT 9299.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 8835.0 GR GAMMA RAY CNT COMP. NEUTRON (G) $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): NORMALIZATION WINDOW START DEPTH (FT): STOP DEPTH (FT): AMOUNT: GAS SCALING FACTOR FOR NEAR AND FAR COUNTS: MULTIPLIER: 28-JUL-91 DDL1 0092-49 1000 28-JUL-91 9500.0 9302.0 8819.0 9300.0 1800.0 NO TOOL NUMBER 33006 27002 8.500 9500.0 PRODUCED/SEAWATER 57.0 182.0 15000 1.000 THERMAL SANDSTONE 2.65 8.500 9156.0 9068.0 60.000 Page 20 TOOL STANDOFF (IN): 0.0 REMARKS: NPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE: 8.5" CASING SIZE: 7.0" CASING WT.: 29.0~ PASS ~2 LOGGED WHILE PUMPING AT 1 BBL/MIN. FLUID LEVEL: FULL $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 28 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 36 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F GR CNT 667513 GAPI MCCL CNT 667513 MV RCCL CNT 667513 MV FCNL CNT 667513 CPS NCNL CNT 667513 CPS NPHI CNT 667513 %-SS NRAT CNT 667513 C/C API CODE FILE# SIZE #SAMP REPR. 00000000 0 4 1 68 00310010 0 4 1 68 00150010 0 2 1 79 00150010 0 2 1 79 00334300 0 4 1 68 00334300 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9299.500 GR = RCCL = 0 FCNL = NPHI = 61.170 NP, AT .000 MCCL = 0 .000 NCNL = .000 -999.000 DEPT = 9199.500 GR = RCCL = 86 FCNL = NPHI = 16.368 NRAT = 26.900 MCCL = 643 574.200 NCNL = 549.300 .979 Page 21 DEPT = 9099.500 GR = 26.400 MCCL = 615 RCCL = 125 FCNL = 355.900 NCNL = 423.900 NPHI = 28.800 NRAT = 1.210 DEPT = 8999.500 GR = 32.100 MCCL = 545 RCCL = 18 FCNL = 518.100 NCNL = 525.100 NPHI = 18.106 NRAT = 1.030 DEPT = 8899.500 GR = 134.000 MCCL = 573 RCCL = 18 FCNL = 264.700 NCNL = 360.300 NPHI = 40.540 NRAT = 1.386 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.008 --- 92/01/06 --- 1024 --- LO --- COMCEN.009 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.009 --- 92/01/06 --- 1024 --- LO --- COMCEN.008 FILE HEADER FILE NUMBER:- 09 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 04 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNT 9299.5 8835.0 $ Page 22 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 28-JUL-91 DDL1 0092-49 1000 28-JUL-91 9500.0 9302.0 8819.0 9300.0 1800.0 NO TOOL NUMBER GR GAMMA RAY CNT COMP. NEUTRON (G) $ 33006 27002 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 9500.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED/SEAWATER 57.0 182.0 15000 1.000 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 8.500 NORMALIZATION WINDOW START DEPTH (FT): STOP DEPTH (FT): AMOUNT: 9156.0 9068.0 GAS SCALING FACTOR FOR NEAR AND FAR COUNTS: MULTIPLIER: 60.000 TOOL STANDOFF (IN): 0.0 NPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE: 8.5" CASING SIZE: 7.0" CASING WT.: 29.0~ PASS #2 LOGGED AFTER PUMPING ABOUT 325 BBLS. FLUID LEVEL: FULL Page 23 $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 28 4 1 66 1 5 i 66 1 8 4 73 60 9 4 65 .liN 11 2 79 36 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 GR CNT 667513 GAPI 00310010 0 -4 1 68 MCCL CNT 667513 MV 00150010 0 2 i 79 RCCL CNT 667513 MV 00150010 0 2 1 79 FCNL CNT 667513 CPS 00334300 0 4 1 68 NCNL CNT 667513 CPS 00334300 0 4 1 68 NPHI CNT 667513 %-SS 00000000 0 4 1 68 NRAT CNT 667513 C/C 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT =~ 9299.500 GR = .000 RCCL = 0 FCNL = .000 NPHI = 56.260 NRAT = -999.000 MCCL = 0 NCNL = .000 DEPT = 9199.500 GR = 26.100 RCCL = 8 FCNL = 562.500 NPHI = 16.612 NRAT = .992 MCCL = 587 NCNL = 547.900 DEPT = 9099.500 GR = 23.800 RCCL = 38 FCNL = 362.800 NPHI = 27.620 NRAT = 1.181 MCCL = 609 NCNL = 423.400 DEPT = 8999.500 GR = 31.100 RCCL = 28 FCNL = 523.200 MCCL = 545 NCNL = 521.800 page 24 NPHI = 17.948 N~AT = 1.018 DEPT = 8899.500 GR = 134.400 MCCL = 543 RCCL = 8 FCNL = 274.700 NCNL = 361.600 NPHI = 36.090 NRAT = 1.330 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.009 --- 92/01/06 --- 1024 --- LO ****************************************************************************** TAPE TRAILER RECORD TYPE 131 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER NEXT TAPE NAME COMMENTS: --- COMCEN --- 92/01/06 --- ANCH t~t 0 ****************************************************************************** REEL TRAILER RECORD TYPE 13'3 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER NEXT REEL NAME COMMENTS: --- COMCEN --- 92/01/06 --- 667513 ****************************************************************************** END OF TAPE ENCOUNTERED Page 25
