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y Samantha Carlisle at 8:26 am, Mar 02, 2022 'LJLWDOO\VLJQHGE\$OOHQ(VFKHWH '1&1 $OOHQ(VFKHWH ( $OOHQ(VFKHWH#&RQRFR3KLOOLSVFRP 5HDVRQ,DPWKHDXWKRURIWKLVGRFXPHQW /RFDWLRQ\RXUVLJQLQJORFDWLRQKHUH 'DWH )R[LW3')(GLWRU9HUVLRQ $OOHQ (VFKHWH DSR3/2/22 RBDMS SJC 030222 ! 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Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1C-27 50-029-22943-00 n/a Kuparuk River Packer Setting Record Field- Final 4-Jul-21 0 12 1D-135 50-029-22816-00 907261026 Kuparuk River Packer Setting Record Field- Final 11-Jul-21 0 13 1D-135 50-029-22816-00 907276312 Kuparuk River Packer Setting Record Field- Final 19-Jul-21 0 14 1E-34 50-029-22805-00 907273379 Kuparuk River Patch Setting Record Field- Final 17-Jul-21 0 15 1E-34 50-029-22805-00 907240278 Kuparuk River Multi Finger Caliper Field & Processed 29-Jun-21 0 16 1R-101 50-029-21404-03 907268285 Kuparuk River Leak Detect Log Field- Final 16-Jul-21 0 17 1R-101 50-029-21404-03 907269600 Kuparuk River Multi Finger Caliper Field & Processed 16-Jul-21 0 18 2K-04 50-103-20099-00 907266787 Kuparuk River Plug Setting Record Field- Final 14-Jul-21 0 19 2N-333 50-103-20525-00 906845070 Kuparuk River Cement Retainer Record Field- Final 2-Jul-21 0 110 2V-03 50-029-21040-00 907240668 Kuparuk River Plug Setting Record Field- Final 30-Jun-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:08/03/2021Wd͗ϭϵϳϭϲϲϬͲ^Ğƚ͗ϯϱϰϳϵBy Abby Bell at 2:10 pm, Aug 03, 2021 Originated: Delivered to:3-Aug-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1C-27 50-029-22943-00 n/a Kuparuk River Packer Setting Record Field- Final 4-Jul-21 0 12 1D-135 50-029-22816-00 907261026 Kuparuk River Packer Setting Record Field- Final 11-Jul-21 0 13 1D-135 50-029-22816-00 907276312 Kuparuk River Packer Setting Record Field- Final 19-Jul-21 0 14 1E-34 50-029-22805-00 907273379 Kuparuk River Patch Setting Record Field- Final 17-Jul-21 0 15 1E-34 50-029-22805-00 907240278 Kuparuk River Multi Finger Caliper Field & Processed 29-Jun-21 0 16 1R-101 50-029-21404-03 907268285 Kuparuk River Leak Detect Log Field- Final 16-Jul-21 0 17 1R-101 50-029-21404-03 907269600 Kuparuk River Multi Finger Caliper Field & Processed 16-Jul-21 0 18 2K-04 50-103-20099-00 907266787 Kuparuk River Plug Setting Record Field- Final 14-Jul-21 0 19 2N-333 50-103-20525-00 906845070 Kuparuk River Cement Retainer Record Field- Final 2-Jul-21 0 110 2V-03 50-029-21040-00 907240668 Kuparuk River Plug Setting Record Field- Final 30-Jun-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:08/03/2021Wd͗ϭϵϳϭϲϲϬͲ^Ğƚ͗ϯϱϰϴϬBy Abby Bell at 2:10 pm, Aug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y Meredith Guhl at 9:45 am, Jul 28, 2021 宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷宏宲宦室宷宬宲宱孽季宄宱宦宫宲宵室宪宨孯季宄宯室家宮室宇室宷宨孽季孵孳孵孴孱孳孺孱孵孻季孳孼孽孵孺孽孴孷孰孳孻孪孳孳孪安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孴孱孶Jan Byrne SFD 7/28/2021 , ADL 0025651 DSR-7/29/21VTL 8/9/21 SFD 7/28/2021 RBDMS HEW 7/28/2021 !" #$$%&''""(") * +%") $ + ") *+ " ) )#)&$& ,& ""# # $) '") -'") +%") && %%"%&'(. $$$ / $%&'.%&' . " "/ !" $"+%"# %" ) %&(0+ '") $%&'(. "&$& %&(00$ (( "/ !" $" $%&(./%&(00 $ + '") /%&'. # 1$ "&$& 00$ + '") 0&& $&$ % %&(.00$ + '") / %&(.00$ + '") / ") &$ , %&(.00$ ") / ") &$ %&(.00$ ") $ )$)&$ ! $ '",") %&'%.$$ $# /%& . ''") # &$ ' 2$&' .%& . +( ") / (") / )+") #)+ " ) &$ ( %&',. +(%") / +%") ))# $/+%") / )/ )+") & $ ( 3' $)$& $ 04&%&' 0 $& / $& / $ %&% / $ & )%&, %,567!89:;< 5==9>?@ABC>9:7@!D $'") ,& ' 22 &' .$ /( ") &% //' & / & $& '% /( "&2 & & '' !" $ ' " $%&(./ %&(.E%'" /%&'.,&( .F , +'") +(&'") & $ )&' '( $E %&'.+ '") /%&'. %(.& %'&,"F, , +%") +%%") / $ , %&'.+%%") $ E & & Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: CTMD 10,642.0 7/24/2016 1E-34 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Patch 7/18/2021 1E-34 spilch Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 42.0 Set Depth (ftKB) 121.0 Set Depth (TVD) … 121.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 41.0 Set Depth (ftKB) 5,576.8 Set Depth (TVD) … 3,949.7 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 38.8 Set Depth (ftKB) 9,821.2 Set Depth (TVD) … 5,970.3 Wt/Len (l… 26.00 Grade L-80 Top Thread ABM-BTC Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 9,640.5 Set Depth (ftKB) 11,712.0 Set Depth (TVD) … 6,087.3 Wt/Len (l… 12.60 Grade L-80 Top Thread NSCT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,640.5 5,898.5 65.14 SBE BAKER 80-47 SEAL BORE EXTENSION w/BAKER 5.5" C2 LINER SETTING SLEEVE 4.997 9,650.9 5,902.9 65.31 HANGER BAKER CMC MECHANICAL HANGER 4.276 9,694.1 5,920.7 66.00 NIPPLE CAMCO DB LANDING NIPPLE w/ 3.75" NO GO PROFILE 3.750 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 36.4 Set Depth (ft… 9,641.7 Set Depth (TVD) (… 5,899.0 Wt (lb/ft) 12.60 Grade L-80 Top Connection NSCT Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 36.4 36.4 0.00 HANGER FMC PRUDHOE GEN V HANGER 4.500 1,510.7 1,508.1 10.02 NIPPLE CAMCO BAL-O NIPPLE 3.812 9,572.2 5,869.3 64.41 NIPPLE OTIS X SELECTIVE PROFILE NIPPLE NO GO 3.813 9,611.8 5,886.3 64.67 PBR BAKER PBR 3.875 9,625.0 5,892.0 64.89 SEAL ASSY BAKER KBH-22 ANCHOR SEAL ASSEMBLY 3.875 9,625.8 5,892.3 64.90 PACKER BAKER FAB-1 HYDRAULIC SET PACKER 3.958 9,629.0 5,893.7 64.95 BLAST JT BLAST JOINT 3.958 9,638.7 5,897.8 65.11 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY w/2' SPACE OUT 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,636.0 4,471.3 62.42 PACKER - PATCH - UPR 4-1/2" P2P (ME 6636' RKB) (UPPER PATCH ASSEMBLY OAL 37.14') 7/18/2021 2.000 CPP45021 6,637.0 4,471.7 62.43 ANCHOR LATCH & SPACER PIPE 2-3/8" SPACER PIPE & ANCHOR LATCH 7/18/2021 2.000 CPAL45001 6,650.0 4,477.8 62.48 LEAK - TUBING LDL found Tubing Leak @6650' 6/27/2021 3.960 6,662.0 4,483.3 62.52 LEAK - TUBING LDL found Tubing Leak @6662' 6/27/2021 3.960 6,672.0 4,487.9 62.56 PACKER - PATCH - LWR 4-1/2" P2P (ME 6672' RKB) (OAL 4.89') 7/17/2021 2.000 CPP45005 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 10,025.0 10,075.0 6,042.6 6,058.4 C-4, 1E-34 3/13/2004 6.0 APERF 2.5" HSD Guns, 60 Deg Phase, Random Orient 10,095.0 10,115.0 6,064.0 6,068.9 C-4, C-3, 1E-34 3/12/2004 6.0 APERF 2.5" HSD Guns, 60 Deg Phase, Random Orient 10,194.0 10,444.0 6,082.4 6,082.1 C-3, 1E-34 11/5/1997 4.0 IPERF 2 7/8" TCP HSD 10,694.0 11,196.0 6,076.9 6,072.8 C-4, 1E-34 11/5/1997 4.0 IPERF 2 7/8" TCP HSD 11,244.0 11,644.0 6,071.9 6,084.1 C-4, 1E-34 11/5/1997 4.0 IPERF 2 7/8" TCP HSD Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,854.0 2,605.3 52.43 CAMCO KBG-2- LS 1 GAS LIFT GLV INT 0.188 1,250.0 11/27/2017 2 5,006.3 3,677.9 61.57 CAMCO KBG-2- LS 1 GAS LIFT OV INT 0.250 0.0 6/9/2021 3 6,639.4 4,472.9 62.44 CAMCO KBG-2- LS 1 GAS LIFT OV INT 0.250 0.0 7/17/2006 Heav y Scale on Latch 4 7,940.5 5,073.6 60.61 CAMCO KBG-2- LS 1 GAS LIFT DMY INT 0.000 0.0 10/10/1997 5 8,812.9 5,522.3 60.61 CAMCO KBG-2- LS 1 GAS LIFT DMY INT 0.000 0.0 10/10/1997 6 9,530.0 5,851.0 64.24 CAMCO KBG-2- LS 1 GAS LIFT DMY INT 0.000 0.0 10/10/1997 1E-34, 7/27/2021 12:47:39 PM Vertical schematic (actual) LINER; 9,640.6-11,712.0 IPERF; 11,244.0-11,644.0 IPERF; 10,694.0-11,196.0 IPERF; 10,194.0-10,444.0 APERF; 10,095.0-10,115.0 APERF; 10,025.0-10,075.0 PRODUCTION; 38.8-9,821.2 PACKER; 9,625.8 GAS LIFT; 9,530.0 GAS LIFT; 8,812.9 GAS LIFT; 7,940.5 PACKER - PATCH - LWR; 6,672.0 LEAK - TUBING; 6,662.0 ANCHOR LATCH & SPACER PIPE; 6,637.0 LEAK - TUBING; 6,650.0 GAS LIFT; 6,639.4 PACKER - PATCH - UPR; 6,636.0 SURFACE; 41.0-5,576.8 GAS LIFT; 5,006.3 GAS LIFT; 2,854.0 NIPPLE; 1,510.7 CONDUCTOR; 42.0-121.0 KUP PROD KB-Grd (ft) 48.01 Rig Release Date 10/11/1997 1E-34 ... TD Act Btm (ftKB) 11,712.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292280500 Wellbore Status PROD Max Angle & MD Incl (°) 92.37 MD (ftKB) 10,674.15 WELLNAME WELLBORE1E-34 Annotation Last WO: End DateH2S (ppm) 160 Date 7/31/2015 Comment SSSV: NIPPLE Originated: Delivered to:1-Jul-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL #1 1A-24 50-029-22984-00 907203651 Kuparuk River Packer Setting Record Field- Final 11-Jun-21 0 12 1E-34 50-029-22805-00 n/a Kuparuk River Leak Detect Log Field- Final 27-Jun-21 0 13 1E-34 50-029-22805-00 n/a Kuparuk River Plug Setting Record Field- Final 27-Jun-21 0 14 1J-168 50-029-23260-00 907188201 Kuparuk River Packer Setting Record Field- Final 3-Jun-21 0 15 2M-33 50-103-20240-00 907209681 Kuparuk River Packer Setting Record Field- Final 17-Jun-21 0 16 2N-347 50-103-20337-00 906961909 Kuparuk River Plug Setting Record Field- Final 14-Jun-21 0 17 2T-207 50-103-20287-00 907201320 Kuparuk River Leak Detect Log Field- Final 9-Jun-21 0 18 2T-207 50-103-20287-00 907199652 Kuparuk River Multi Finger Caliper Field & Processed 9-Jun-21 0 19 2V-03 50-029-21040-00 907177252 Kuparuk River Plug Setting Record Field- Final 27-May-21 0 110 3F-08 50-029-21464-00 907196137 Kuparuk River Plug Setting Record Field- Final 10-Jun-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:07/01/2021Wd͗ϭϵϳϭϲϲϬͲ^Ğƚ͗ϯϱϯϭϵBy Abby Bell at 3:53 pm, Jul 01, 2021 Originated: Delivered to:1-Jul-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL #1 1A-24 50-029-22984-00 907203651 Kuparuk River Packer Setting Record Field- Final 11-Jun-21 0 12 1E-34 50-029-22805-00 n/a Kuparuk River Leak Detect Log Field- Final 27-Jun-21 0 13 1E-34 50-029-22805-00 n/a Kuparuk River Plug Setting Record Field- Final 27-Jun-21 0 14 1J-168 50-029-23260-00 907188201 Kuparuk River Packer Setting Record Field- Final 3-Jun-21 0 15 2M-33 50-103-20240-00 907209681 Kuparuk River Packer Setting Record Field- Final 17-Jun-21 0 16 2N-347 50-103-20337-00 906961909 Kuparuk River Plug Setting Record Field- Final 14-Jun-21 0 17 2T-207 50-103-20287-00 907201320 Kuparuk River Leak Detect Log Field- Final 9-Jun-21 0 18 2T-207 50-103-20287-00 907199652 Kuparuk River Multi Finger Caliper Field & Processed 9-Jun-21 0 19 2V-03 50-029-21040-00 907177252 Kuparuk River Plug Setting Record Field- Final 27-May-21 0 110 3F-08 50-029-21464-00 907196137 Kuparuk River Plug Setting Record Field- Final 10-Jun-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:07/01/2021Wd͗ϭϵϳϭϲϲϬͲ^Ğƚ͗ϯϱϯϭϴBy Abby Bell at 3:53 pm, Jul 01, 2021 .� - • • CU CO 1 � � � w o CO .. 7.- a, r (" a Nu co O° WX Q Y M J CO a) Cu O 1 H Y O L _c C o 2 0. 5N- '- rte . t0 � 4- H T MI U a` a oN `1"> E c o` J O C p f° C cD rn a Q W " m p l2 cO co co 0 co co n3 Ou a) E s Q 2 Q 3 7 7 7 - L C C 'ra -J F E N W U) O) 0 n -0 O_ a) za r N N M M N ,.,= C v T v Z Q 0 O10 E O >, Q et u a) Q1U Y !— O a) '.' 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They are available in the original file and viewable by direct inspection. / ~'¢-/~ File Number of Well History File PAGES TO DELETE RESCAN n Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Odginal- Pages: [] Other - Pages: DIGITAL DATA [] Diskettes, No. Other, No/Type 'OVERSIZED r-i .Logs of vadous kinds [] Other Complete COMMENTS: E] Scanned by~~dred-D'aretha Naltmn Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: /si • Conoco/Phillips P.O. BOX 100360 ANCHORAGE, ALASKA, 99510-0360 April 16, 2008, Mr. Tom Maunder Alaska Oil 8c Gas Commission ~~~~ 333 West 7~' Avenue, Suite 100 ~~ APR ~ `~ Anchorage, AK 99501 Dear Mr. Maunder:. • RECEIVED APR 2 2 2008 Alaska oil & Gas cons. commission anchorage 1~"3~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosioninhibitor/sealant was pumped on 3/29/2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sinc ~~ fem. Perr ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surf~ic~' Casing'by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off „ Report of Sundry Operations (10-404) Kuparuk Field Date 3/2 9!2008 Well Name PTD # Initial top of Vol. of cement Final top of Cement top off Corrosion Corrosion inhibitor) cement um ed cement date inhibitor sealant date 1 E-34 197-166 ft 9" bbls NA ft 9" NA al 1 E-102 ~ 204-231 14" NA 14" NA 7 8 3/29/2008 1 E-114 204-171 24" " 3/29/2008 NA 24 NA 16 1 E-126 204-122 25" 3/29/2008 NA 25" NA 14 1 E-166 204-153 20" " 3/29/2008 NA 20 NA 12 3/29/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 0 390* 390 0 100 0 13062 21 100 0 18582 31 0 0 0 0 0 0 0 0 200 390 32034 52 Pressure vs. Time D Step Rate Test D *Initial Freeze protect volumes and LOT I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ \. \,~ Printed Name: Randy Thomas 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation D or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): o 2004 1 2nd 12962 2004 1 3rd 18482 2004 14th o 20051 1st o Total Ending Volume (bbls): 31444 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Form 10-423 Rev. 2/2004 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAG D GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: 304-186 (h)(3) Other Commission approved substances (include descriptions in block 12) 5/20/2004 Volume (bbls): Number of days disposal occurred , - . J . (',,~:::.. ¡: ~~ 2 2 ¿DDS ~~A,\h >,~....,L .J LJ L .1- ~ Date: Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 197-166 1 E-34 50-029-22805-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: .-- 5/20/2004 6/9/2004 1 E-123 8/1/2004 8/31/2004 1 E-126 -' Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. 71t 1..(o~ Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D 10. (h){1) drilling mud, drilling (h){2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAG D GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: 6. Permit to Drill Number: 7. Well Name: 8. API Number: 197-166 1 E-34 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: 50-029-22805-00 9. Field: 304-186 (h){3) Other Commission approved substances (include descriptions in block 12) 5/20/2004 Volume (bbls): Number of days disposal occurred Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: .~ Previous 0 totals (bbls): 2004/2nd 12962 2004 1 3rd 18482 2004 14th 0 20051 1st 0 Total Ending Volume 31444 (bbls): 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description{s): 0 390* 390 0 100 0 13062 21 5/20/2004 6/9/2004 1 E-123 100 0 18582 31 8/1/2004 8/31/2004 1 E-126 0 0 0 0 0 0 0 0 --- 200 390 32034 52 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, Pressure vs. Time D Step Rate Test D Qctober 20 for the third quarter, and January 20 for the SCANNED APR ..; 8 200iurth quarter. 1 *Initial Freeze protect volumes and LOT I hereby certify that the foregoing is true and correct to the best of my knowledge. . Signature: \ ~~. Date: Lf(L l-fos Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate 1 . Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAGD GINJ 0 WINJ 0 WDSPL 0 Sa. Sundry number: Sb. Sundry approval date: 6. Permit to Drill Number: 7. Well Name: 197 -166 1 E-34 8. API Number: 50-029-22805-00 9. Field: 304-186 (h)(3) Other Commission approved substances (include descriptions in block 12) 5/20/2004 Volume (bbls): Number of days disposal occurred ~ Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: Previous 0 0 390* 390 0 totals (bbls): 2004 / 2nd 12962 100 0 13062 21 5/20/2004 6/9/2004 1 E-123 2004 / 3rd 18482 100 0 18582 31 8/1/2004 8/31/2004 1 E-126 2004 / 4th 0 0 0 0 0 2005 / 1 st ~ Total Ending Report is due on the 20th Volume 31444 200 390 32034 52 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Step Rate Test 0 October 20 for the third quarter, and January 20 for the Other (Explain) 0 fourth quarter. 12. Remarks and Approved Substances Description(s): *Initial Freeze protect volumes and LOT I hereby certify that the foregoing is true and correct to the best of my knowledge. \~\~ Randy Thomas Signature: Printed Name: Form 10-423 Rev. 2/2004 SCANNED JAN 1 4 2005 l(7(oY Date: Title: Kuparuk Drilling Team Leader (907) 265-6830 Phone Number: INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added ~" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAGD GINJ D WINJ D WDSPL 0 5a. Sundry number: 5b. Sundry approval date: 6. Permit to Drill Number: 7. Well Name: 197-166 1 E-34 8. API Number: 50-029-22805-00 9. Field: 304-186 (h)(3) Other Commission approved substances (include descriptions in block 12) 5/20/2004 Volume (bbls): Number of days disposal occurred Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: Previous 0 0 390* 390 0 totals (bbls): 2004 / 2nd 12962 100 0 13062 21 5/20/2004 6/9/2004 1E-123 2004 / 3rd 18482 100 0 18582 31 8/1/2004 8/31/2004 1 E-126 2004 / 4th 2005/1st ~ Total Ending Report is due on the 20th Volume 31444 200 390 32034 52 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time D Step Rate Test D October 20 for the third quarter, and January 20 for the Other (Explain) 0 fourth quarter. 12. Remarks and Approved Substances Description(s): *Initial Freeze protect volumes and LOT I hereby certify that the foregoina is true and correct to the best of my knowledge. r\~l~ Signature: Printed Name: Randy Thomas Form 10-423 Rev. 2/2004 SCANNED NOV 0 r4 2004 l c> /(ør (0 f,( Date: Title: Kuparuk Drilling Team Leader (907) 265-6830 Phone Number: INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAGD GINJ 0 WINJ D WDSPL D Sa. Sundry number: 5b. Sundry approval date: 304-186 (h)(3) Other Commission approved substances (include descriptions in block 12) 5/20/2004 Volume (bbls): Number of days disposal occurred 6. Permit to Drill Number: 7. Well Name: 197 -166 1 E-34 8. API Number: 50-029-22805-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~:-~ Previous 0 0 390* 390 0 totals (bbls): 2004 / 2nd 12962 100 0 13062 21 5/20/2004 6/9/2004 1 E-123 2004 / 3rd 2004 / 4th 2005/1st Total Ending Report is due on the 20th Volume 12962 100 390 13452 21 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Step Rate Test 0 October 20 for the third quarter, and January 20 for the Other (Explain) D fourth quarter. 12. Remarks and Approved Substances Description(s): *Initial Freeze protect volumes and LOT I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~~ ~ Printed Name: Randy Thomas Date: Title: Kuparuk Drilling Team Leader ... .----. ."""'~II""'\"'I""" ""'~I nL\/r::OCE:: Clni= 7(8 íoc-( Phone Number: (907) 265-6830 Submit in Duplicate L' ..~. '~~~J~ \'/' -,vvJ U"""U1.y JV"'-H)V J"UlllUl(U J..J1:>pU:>i:l1j ~ ~ Subject: [Fwd: 1E-34 (197-166) Sundry 304-186 Annular Disposal] From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 19 May 200417:04:56 -0800 To: Randy Thomas <Randy.L. Thomas@conocophillips.com> -------- Original Message -------- Subject: 1E-34 (197-166) Sundry 304-186 Annular Disposal Date: Wed, 19 May 2004 17:02:55 -0800 From: Thomas Maunder <tom maander@admin.state.ak.us> Organization: State of-Ãi"aska--------- ---------------- To: Sharon Allsup-Drake ~§~l~~PE~~~~~~, Steve Shultz <Steven.M.Shultz@conocophillips.com> Sharon and Steve, Be advised that you have approval to begin The signed sundry will be ready tomorrow. Tom Maunder, PE AOGCC annular disposal into the subject well. 1 of 1 5/19/20045:06 PM r-- ~ NOTE TO FILE 1 E-34...197 -166...304-186 Request for Annular Disposal Approval Summary This well was drilled in late 1997 and a disposal authorization was not requested at that time. ConocoPhillips (CPAI) is planning to drill up to 12 new West Sak wells from 1 E pad and desires to use the annulus of this well. They have submitted the required information. This document analyzes the information and recommends approving their request. Offset Well Information Two wells and 1 abandoned wellbore section have been identified within % mile of 1 E-34. Referenced to the 9-5/8" casing shoe of 1 E-34, 1 E-02 is approximately 460' distant and 1 E-01 and 1 E-01A are approximately 1230' distant. These wells were drilled in 1980. As presented in the proximity analysis, 1 E-02 and 1 E-34 are parallel as one goes deeper while 1 E-01 and 1 E- 01A diverge. The abandoned section of 1 E-01 was satisfactorily cemented through the West Sak sand intervals. That wellbore section was abandoned due to sticking the 7" casing shallow. The surface casings of the older wells, per the practice at the time, were not set through the West Sak sands. The outer annulus on each well was down-squeezed with cement and arctic pak following drilling. A review of the files did not indicate that any waste fluids were pumped into either annulus. In each case sufficient total volume was pumped to place the cement below the surface casing shoe. It is probable that some of the West Sak sections were covered with cement, although it is not likely that the total intervals in either well were covered. Neither well has been reported as having external casing pressure problems as required by the sustained casing pressure orders. . It is likely that the wellbore sections of 1 E-02 and 1 E-01 A proximate to 1 E-34 are not cemented. 1 E-01A is sufficiently distant that any communication is unlikely. Although not cemented, given the age of the wells it is likely that the mud left in the production hole has dehydrated with time and sealed around the casing. It is unlikely that communication will be developed with the 1 E- 02 wellbore due to the limited volume of disposal allowed per the regulations. The intermittent nature of the disposal operations also results in the placement of disposal volumes in multiple "wings" surrounding the wellbore. The Campanian Sands are identified as being present in 1 E- 34 about 400' md below the surface casing shoe and they may be a potential disposal zone. Access to those sands will be dependant on how any fluids in that open hole section have dehydrated. Well 1 E-34 Information The surface casing was run and successfully cemented to surface in 2 stages. On the 2nd stage, lead cement was circulated before the tail slurry was pumped. Some difficulty was experienced when the landing joint was retrieved resulting in pulling 2 joints of surface casing. The casing was tied back and a top job performed. The record does not note that the casing was successfully pressure tested prior to drillout, although it is difficult to imagine that it was not. It is reported that the formation below the shoe was tested to 14.0 EMW. No pressure graph is available. CPAI has recently performed an injectivity test down the OA. In this most recent test, steady pump in occurs at about 12.8 EMW. After shut down, the pressure stabilized at around 11.2 EMW. If half water, half diesel is used as the fluid column; the EMWs are about 1 ppg higher. Pressure signatures such as these indicate that the shoe is still well cemented. The well was drilled to the top of the Kuparuk reservoir and 7" casing string was set and cemented without problems. On drillout, the formation was tested to 16.1 EMW without leakoff. It is indicated that the 7" casing is well cemented and that the Kuparuk sands are isolated. This well has not been reported as required by the sustained casing pressure order. G:\common\tommaunder\Well Inforrnation\By Subject\Annular Disposal\040519 _197-1 66--KRU_IE-34_AD.doc ",.--..,.. ~ Recommendation Based on the presented information, I recommend that ConocoPhillips' disposal in 1E-34 (197-166) be approved. ~d:J~ 5/ l <; --0 t-¡ Sr. Petroleum Engineer request for annular G:\common\tommaunder\ Well Inforrnation\By Subject\Annular Disposal\040519 _1 97-1 66--KRU _lE-34- AD.doc ~ ~ t STATE OF ALASKA RECEIVE~ ALASKA Oil AND GAS CONSERVATION COMMISSION (\ ANNULAR DISPOSAL APPLICATION MAY 1 8 2004 20 AAC 25.080 1. Operator Name: ConocoPhillips Alaska 2. Address: P.O. Box 100360, Anchorage, Alas~ 7. Publicly recorded wells a) All wells within one-quarter mile: 1E-O1/1A and 1E-02 (see attached summary) b) water wells within one mile: AllI!lka nil & f',"1 Cons r.nmmis!linn 3. Permit to Drill Anchorage Number: 97-166 4. API Number: 50-029-22805 S.Well '1 E-34 6. Field: Kuparuk River Unit 8. Stratigraphic description: a) Interval exposed to open annulus: interbedded claystone, siltstone and shale b) Waste receiving zone: Colville Clay Stone yes, but all have casing shoes above the West Sak 9. Depth to base of permafrost: 1565' MD/1555' TVD 11. Previous volume disposed in annulus and date: None 14. Estimated volume to be disposed with this request: 35,000 bbls. 16. Estimated start date: May 19,2004 17. Attachments: Well Schematic (Include MD and TVD) 0 Surf. Casing Cementing Data 0 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Other 0 c) Confinement: Shales beow the West Sak, Shales above the Kuparuk 12. Estimated slurry density: 10.0 ppg 10. Hydrocarbon zones above waste receiving zone: West Sak 13. Maximum anticipated pressure at shoe: 1225 psi 15. Fluids to be disposed: Types of waste can be drilling mud, drill cuttings, cement-contaminated drill mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, domestic waste water, and any water needed to facilitate pumping of drilling mud or drilling cuttings. Cement Bond Log (if required) Signature: _.~~~~ Printed Name: Randy Thomas Conditions of approval: ~ Form 10-403AD Rev. 9/2003 Phone Number: Commission Use Only 0 R , G \ ~1\LNER INSTRUCTIONS ON REVERSE D FIT Records w/LOT Graph 0 Title: ~ l~ "\ ~--- k-"A 265-6830 Date: 5/18/2004 LOT review and approval: fp?J/Y'¡ ql ~ \ Approval number: .3'0 ¥ -/56 ....-' BY ORDER OF THE COMMISSION Date: bkJH MIX. at ~I RBOMS BfL Submit in Duplicate r"\ ~ Co no cÓPh i iii ps Post Office Box 100360 Anchorage, Alaska 99510-0360 Steve Shultz Phone (907) 263-4620 Fax: (907) 265-1535 Email: steven.m.Shultz@conocophillips.com May 10 ,2004 Alaska Oil and Gas Conservation Commission 222 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on Well1E-34 Dear Sir: ConocoPhillips Alaska, Inc. hereby requests that 1E-34 be permitted for annular pumping of fluids occurring as a result of drilling operation, per regulation 20 ACC 25.080. It is intended to begin annular disposal operation on 1E-123 as soon as possible. Please see the attached form 10-403 and other pertinent information as follows: 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. Annular Disposal Transmittal Form Pressure Calculations for Annular Disposal Surface Casing Description Surface Casing Cementing Report and Daily Drilling Reports during cement ops Casing and Formation Integrity Report (LOT at surface casing shoe) Production Casing Description Production Casing Cementing Report and Daily Drilling Report during cement ops Plan View of Existing Adjacent Wells Plan View of Existing and Planned Adjacent Wells Pressure Integrity Test If you have any questions or require further information, please contact Steve Shultz at 263- 4620 in the Conoco/Phillips office. Sinr1y, {)I. I ; .~t~ dJz~ sieve Shultz ~ Drilling Consultant ~ ~ Annular Disposal Transmittal Form- WelllE-34 A. B. Designation of well to receive drilling wastes: The depth to the base of freshwater aquifers and permafrost, if present. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. A list of all publicly recorded wells within one- quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. c. D. E. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry. F. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operations and calculations showing how this value was determined. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation: Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: Any addition data required by the Commission to confirm containment of drilling wastes: G. H. I. 1E-34 No Aquifers/Base of Permafrost=:!:1565' MDI1555'TVD From the 9 5/8" shoe to the Cement top all that is open is interbedded claystone, siltstone and shale with occasional minor non- hydrocarbon bearing sands. See attached horizontal plane clearance report and plot indicating that there are three wells within a quarter of a mile in the same horizontal plane as the 9 5/8" surface casing shoe on 1E-34. 1E-01, 1E-01A and 1E-02 have been drilled within the quarter mile reference. All three of these wells were cement arctic packed (lE-0l/01A, 5130/80,41 bbls cement/114 bbls arctic pack and 1E-02, 6/17/80, 41 bbls cement/116 bbls arctic pack) Types of waste can be drilling mud, drilling cuttings, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, domestic waste water, and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 35,000 bbls. Maximum anticipated differential pressure at casing shoe during disposal operation is 1955 psi. See attached calculation page. See Attached: cementing reports, LOT/FIT reports and casing reports. See attached casing summary sheet and calculation pages. 5577' MD 3954' TVD Well: lE-34 Date 5/18/2004 ~ 9 5/8" Surface Csg ~ Estimated TOC 9200' ---------------------- 9821' MD 5989' TVD u ~ 7" Production Csg ,....., ~ Assumutions Maximum surface pressure of 1,200 psi, 12.0 ppg fluid being injected Column of gas to bottom GLM wi no gas lift pressure Going to 96% of 7" Collapse Values Gas down to lower GLM and no header pressure Maximum Differential Pressure at Surface Shoe Maximum Disposal MW 12 ppg Maximum Differential Pressure @ 9 5/8" Shoe 1955 psi (Max Diff Press=Max Disposal Press +(Max DISposal MW) (.O52)(TYD)-(Auid WI on Bacl<S1de)(.O52)(TVD) LOT on 9 5/8" Shoe 1225 psi 12.8 ppg MWE Production Casine Size Weight Grade Collapse @ 100% Collapse @ 85% Gas Depth (TVD of bottom GLM) Gas Gradient Max Disposal Pressure with 12.0 ppg Maximum pressure in 7" X 9 5/8" Annulus and below . No Header Pressure . Column of gas to last GLM . No cement outside 7" down to GLM . 12.0 ppg mud in 9 5/8" annulus . Water from 9 5/8" shoe to GLM . 1,200 psi injection pressure CPC=7" Colla~ Press -(Max Mud wUl.O52)(TVD of9 5/S")-S.33l.O52)ITVD ofGLM-TVD of9 5/S")+I... ¥radiennITVD of bottom GLM) TVD(.O52) 7 inch 26 ppf L-80 5410 psi 4599 psi 5940' TVD O.llppg 1,200 psi 5195 psi Surface Casine Size Weight Grade Burst @IOO% Burst @ 85% Fluid Weight on Backside Maximum Disposal Pressure Maximum Differential Pressure @ 9 5/8" Shoe . 13.0 ppg Mud Weight . Maximum surface pressure of 1500 psi . MDP=-(Ruid wt. backside)(.O52)(TVD)+MW(.O52)(TVD shoe)+Max Surface Pressure 9518 inch 40# L-80 5577 psi 3954 psi 8.33 ppg 1,200 psi 1955 psi Maximum Mud Weight . To burst 9 5/8"casing with 1 ,200 psi 22.2 ppg MMW=Pb @ 85% +(Fluid Weight on Backside)(.052)(TVD)-Max Disposal Press (.052)(TVD) / ~ ~ CASING I TUBING I LINER DETAIL 9-5/8" Surface Casing ARca Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN 39 Jts RKB to 9-5/8" cut-off stub / top of cellar Cut-Off Joint of 9-5/8" Casing - set on slips 9-5/8", 40#, L-80, BTC, Range 3, Class A Casing (Jts #89 - #127) Gemóco 754 PDC Cementing Stage Tool 9-5/8", 40#, L-80, BTC, Range 3, Class A Casing - Baker Locked 9-5/8", 40#, L-80, BTC, Range 3, Class A Casing (Jts #1 - #88) Gemoco Insert Shut-Off Baffle 9-5/8", 40#, L-80, BTC, Range 3, Class A Casing - Float Collar Jt Gemoco Float Collar 9-5/8", 40#, L-80, BTC, Range 3, Class A Casing - Baker Locked 9-5/8", 40#, L-80, BTC, Range 3, Class A Casing - Shoe Joint Gemoco Float Shoe Joint '0' 88 Jts Joint 'C' Joint 'B' Joint 'A' BakerLock thru Insert Shut-Off Baffle, plus Stage Collar WELL: 1 E-34 KRU DATE: 9/21/97 1 OF 1 PAGES LENGTH DEPTH TOPS 41.00 14.66 1697.69 2.85 46.41 3654.62 30 Bow Spring Centralizers: Install a Centralizer In the middle of Joints 'A' & 'B', Install a Centralizer on each of the next 26 Joints (Jt 'C' & Jts #1 thru #25), Install a Centralizer in the middle of Joint '0' & Joint #89. I (Put Centralizers on Stop Rings In middle of Jts 'A', 'B', '0', & #89). I 34.32 1.47 40.25 41.80 1.73 Bottom of Shoe ==» I TD = 5595' MD (17' Rathole) Put BakerLocked Jt '0' on Top of Jt #88 - Stage Collar on Top of Jt '0' - Then Jt #89, BackerLocked to Stage Collar. 41.00 55.66 1753.35 1756.20 1802.61 5457.23 5457.23 5491 .55 5493.02 5533.27 5575.07 5576.80 Remarks: String Weights with Blocks: 280K# Up, 150K# On, 75K# Blocks. Set 125K# actual on slips. Drifted casing with 8.679" plastic rabbit. Used National Arctic Grade API Modified No Lead thread compound on all connections (National = BOL 2000). Torqued to the base of the triangle stamp. Ran 132 joints (131 joints + Cut-off joint set on slips). Ran casing & did 2 stage cement job with cement returns to surface on 9/20. Set pipe on slips & cut-off on 9/21, after 147' top job. Parker Rig #245 Drílling Supervisor: Don E. Breeden ..d,/ ~",L .../ r'\ ~ Cementing Details Field: Kuparuk River Unit Date: 9/21/97 KOP & Angle I Shoe Depth Float Depth I % washout 1100' - 610 5577' 5457' State type used, intervals covered and spacing 30 Gemoco Bow Spring Centralizers: One on each of first 28 joints, 1 st two on stop rings in middle of float joints; One on stop ring in middle of joint on each side of Gemoco Stage Cementing Collar. Weight PV(prior cond) PV(after cond) yp(priOr cond) YP(after cond) 9.8ppg 26 19 25 12 Gels before Gels after Total Volume Circulated 8/10 4/5 Stg 1: 973 Bbls / Stg 2: 310 Bbls Type Volume I Weight Water 50 Bbls / 20 Bbls 8.34 ppg Type I Mix wtr temp No. of sacks I Weight Yield AS III LW :t75° F 230 sx / 480 s~ 10.5 ppg 4.42 cfs Additives: Class G + 3.5% 044 + 0.60% 046 + 30% 053 + 1.5% 079 + 50% 0124 + 1.5% S1 Type MiX water tempi No. of sacks I Weight I Yield Class G & AS I :t75° F 660 sx / 60 sx 15.8 / 15.7 1.15 / 0.93 Additives: Stage 1: Class G + 0.266% 029 + 0.2% 046 + 0.3% 065 + 1% S1 Stage 2: Arctic Set 1 Displacement Rate(before tail at shoe) Rate(tail around shoe) 7.6 BPM /8.5 to 5.1 BPM 7.1 BPM /5.0 BPM Reciprocation length Reciprocation speed :t12' :t45 FPM Theoretical Displacement Actual Displacement 414 Bbls / 133 Bbls 415 Bbls / 135 Bbls Calculated top of cement lOP Bumped plug I Floats held Cemented to Surface 1600, 9/20 Yes Yes Remarks: Include whether full returns were obtained, reciprocation, etc. 1st Stage: Prime up, test lines 3800 psi, 50 Bbls water, Mix & Pump 181 Bbls Lead, drop bypass plug, Mix & Pump 125 Bbls Class G Tail, drop top shut-off plug, pump 10 Bbls Tail on top of plug, pump 25 Bbls wash-up water, rig pump 379 Bbls mud & bumped plug to 1500 psi, floats held. Full returns. Reciprocated until all Lead cement had rounded the shoe. CIP @ 13:35. 2nd Stage: Opened Stage Cementing Tool @ 1753' with 3100 psi, circulate annulus clean, circulated out :t55 Bbls contaminated mud & cement, circulated 310 Bbls. Pump 20 Bbls water, Mix & Pump 378 Bbls 10.5 ppg Lead cement, got 10.3+ ppg cement returns from 220 Bbls to 325 Bbls with full returns, then slowly lost returns by 378 Bbls Lead (Got 105 Bbls + partial returns for next 50 Bbls of 10.3+ ppg Lead cement to surface). Switch to Tail & pump 10 Bbls AS 1, drop top closing plug, pump 30 Bbls wash-up water, displace with mud & bump plug, stage collar closed at 1500 psi, pressure up & hold 2000 psi, floats held. CIP#2 @ 1600, 9/20. On 9/21, after casing repair, did 13.4 Bbl 15.8 ppg AS 1 Top Job to 147' thru 1", CIP @ 07:15. Set casing on "emergency" slips. Cement Company I Rig Contractor Dowell Parker Rig #245 ARca Alaska, Inc. WeIll: 1 E-34 Casing Size Hole Diameter 9-5/8" 12-1/4" Centralizers Mud Spacer Lead Cement Tall Cement Str. Wt. Up 280K# Str. Wt. Down 150K# Str. Wt. in mud 190K# I Signature Don E. Breeden d/~ ~alllm~p~- Dowell Well Field County Beechey Point Rig Name Parker 245 Water Depth Drilling Fluid Type Bentonite Service Une Cementing Max. Allowed Tubing Pressure 0 psi Service Instructions ~ 1'""""'\ 1E 34 Cementing Service Report I Customer I Location (legal) Formation NamelType KUPARUK ARCO ALASKA INC I Job~;;ô061 _: . I Dowell Location Service Date Prudhoe Bay, AK 9/16/97 Deviation I Bit Size I Well MD Well TVD O' 0 in 5,595 ft 3,954 ft BHP I BHST I BHCT I Pore Press. ~radient 0 psi 60 of 70 of 0 psilft . :Casïngll1rKir.".~, ,,~' ~-'<"""~f;-~:~~,'-:ò"-';;~~ Size, in Weight, Ibift Grade Thread StateJProvince AK Dñlled For I Service Via Oil land Well Class I Well Type 201 Re-entry I Max. Density I Plastic Viscosity 9.7Ib/gal 52 cp . .... ... Depth, ft 0 0 TubinglQIiU ripe Size, in Weight, Ibift 0 0 0 0 Grade Thread Depth. 0 0 0 0 0 0 .p~~rat~~'~.;~;{~Ji:X,';,~r;j,;._.~ Bottom, ft spt No. ot Shots Total Interval Job Type Cern Surface Casing Max. Allowed Ann. Pressure I WellHead Connection 0 psi Top, ft 0 0 0 0 0 0 0 ft 0 0 0 0 0 0 ARCO FIELD EST: $ 50, 210.12 0212-7549 CasinglTubing Secured UtI Pressure: Pipe Rotated 0 No. Centralizers: 30 Cement Head Type: Job Scheduled For: 9120/97 7:30 .. j"~<ê'Fìû~:~_ipe:' . - ._~ ~.- .- ~~ ~~~ ~. ., . .' . ;::}~'j~!=';";";' :.:;.:..:..:,. :' 11:06 H2O 11 :13 11 :16 H2O 11 :19 11 :25 H2O 11 :36 CMT 12:01 12:09 Gmt 12:11 Cmt 12:30 12:35 Gmt 12:37 H2O 12:41 Mud 12:50 Mud 12:51 Mud 13:18 Mud 13:34 13:43 Mud Diameter 0 in Packer Depth Treat Down Packer Type Displacement Casing Tubing Vol. 0 bbl 0 ft OpenHoie Vol Casing Vol. Annular Vol. 0 bbl 0 bbl 0 bbl 0 bbl Casing Tools Squeeze Job Shoe Type: Float Squeeze Type Pipe Reciprocated ~ Shoe Depth: 5579.45 ft Tool Type: I Top Plugs: 1 I Bottom Plugs: Stage Tool Type: hyd open Tool Depth: Single Slage Tool Depth: 1759.3 ft TaU Pipe Size: I Arrived on Location: Leave Location: Collar Type: Float Tail Pipe Depth: 9120/97 7:30 9120/97 16:30 Collar Depth: 5492.5 ft Sqz Total Vol: ~;~~: ..:~~ ~':6~"t,~ ~ 0 0 0 10 0 0 0 Flush lines with 10 bblwater 0 0 0 0 0 0 0 Pressure test lines 3800 PSI 8.32 0 8 50 0 400 0 Start water down hole 0 0 0 0 0 0 0 Shutdown- rig problem 8.32 0 8 0 19 400 0 Resume pumping 10.5 0 8 181 50 400 0 Start lead emt - 37% flow 0 0 0 0 0 0 0 Shutdown - drop plug 15.8 0 3 125 231 40 0 Start tail cmt 15.8 0 6.7 0 0 240 0 increase rO-te - 34% flow 0 0 0 0 356 0 0 Shutdown - drop plug 15.8 0 2.5 10 356 0 0 Start Displaeement-1 0 bbl ant on top @ plug 8.32 0 6 7 25 10 40 0 Wash up down hole - 30% flow 9.7 0 7.5 379 35 200 0 Rig to disp - 30% flow 9.7 0 7.5 0 67 1200 0 H20@shoe-30%flow 9.7 0 7.5 0 107 200 0 lead@shoe-33%flow 9.7 0 7.5 0 423 500 0 Tail emt @ shoe - 42% flow 0 0 0 0 0 1500 0 Bump plug -3760 stks - cks float- holding 9.7 0 0 0 0 3050 0 Open stage tool-830 sks pump Gmt back ~ 1 Hole Volume Circulated prior to Cementing l!:J psi Oft Ojn Oft Obbl Page 1 of 2 ,....... ~ Well I Field Service Date I Customer I Job Number - 1E#34 KUPARUK 9/16/97 ARCO ALASKA INC. ..' 'í!~~Q61 .u. Time, c,FluidT}tpe " Fluid, Rates VoJumes Pres5lirèS MèsS.'. ' . ,Density ~'" .'fluid lner., , Cum. C:asing 'Tubing" c241!r, 'lbIgal 'bþm bPriì bbl 'bbl 'psi psi. clock. 14:35 H2O 8.32 0 5.8 20 0 150 0 Stort stoge 2 - 35% flow 14:39 Gmt 10.5 0 6.7 378 0 200 0 Switch to lead cement - 35% flow 14:54 Gmt 10.5 0 8.5 113 0 200 0 H2O @ cmt tool- 38% flow 14:56 Gmt 10.5 0 8.5 133 0 200 0 Lead @ cmt tool- 38% flow 15:22 Gmt 10.5 0 8.5 220 0 200 0 Gmt@ surface - 38% flow - ~ 15:31 Gmt 15.7 Q 5 10 378 200 0 Switch to tail cmt - no flow 15:35 0 0 0 0 388 0 0 Shutdown - drop plug 15.36 H2O 8.32 0 6.3 30 388 650 0 Wash up pump on top @ plug - 0 flow 15:43 Mud 9.7 0 7.5 104 30 600 0 Rig to disp. -? Flow 16:04 0 0 0 0 134 1500 0 Bump and close tool 16:07 0 0 0 0 0 0 0 check floats - holding - emt in bottom of stack . :PostJob Sum~:' ' " ,', .. Average Pump Rates, bpm Volume of Fluid Injected, bbl Slurry N2 Mud Maximum Rate Total Slurry Mud Spacer N2 0 0 I 0 0 0 -L 0 ~ 0 ~ 0 Treating Pressure Summary, psi Breakdown Fluid Maximum Final Bump Plug to Breakdown Type Volume Average Density 0 I 0 I 0 I Avg. m Pv<:ent \ Designed Slurry Volume 0 % Obbl Customer or Authorized Representative Don Breeden 0 0 L ~ Cement Circulated to Surface? Volume D Washed Thru Perfs To I ~ CirculationLost 0 bblL 0 Ib/gaJ bbl Displacement 0 bbl 0 ft Dowell Supervisor J Gray ~ Job Completed Page 2 of2 ,.. / I / Date: 1/2/98 ~ \ J ,....... ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 ================================================================================ WELL:IE-34 WELL_ID: AK9077 AFC: AK9077 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:09/16/97 START COMP: RIG:PARKER 245 0% SECURITY: 0 WI: TYPE: AFC EST/UL:$ 2290M/ 2950M API NUMBER: 50-029-22805-00 BLOCK: FINAL: ================================================================================ 09/15/97 (Dl) TD: 121' ( 121) SUPV:DCL DAILY: $ 09/16/97 (D2) TD: 451' ( 330) SUPV:DEB DAILY: $ 09/17/97 (D3) TD: 3543' (3092) SUPV:DEB DAILY: $ 09/18/97 (D4) TD: 4590' (1047) SUPV:DEB DAILY: $ 09/19/97 (D5) . TD: 5595' (1005) SUPV:DEB DAILY: $ 09/20/97 (D6) TD: 5595' ( 0) SUPV:DEB DAILY: $ 09/21/97 (D7) MW: 8.4 VISC: 44 PV/YP: 10/12 APIWL: 16.6 PU HWDP Move rig from 1E-33 to 1E-34. Accept rig @ 1900 hrs. 9/15/97. NU diverter system. 35,357 CUM:$ 35,357 ETD:$ 0 EFC:$ 2,325,357 MW: 8.8 VISC: 80 PV/YP: 24/26 APIWL: 11. 2 DRILLING Function test diverter, OK. Fill hole and check for leaks, air boot in riser in flow nipple. Change out air boot in telescoping sleeve in flow nipple. Spud at 121' and drill to 451'. Disc-Flo plugged with gravel. 85,839 CUM:$ 121,196 ETD:$ 110,721 EFC:$ 2,300,475 MW: 9.7 VISC: 60 PV/YP: 18/26 APIWL: 8.2 DRILLING @ 3950' Drill from 451' to 3543'. 71,315 CUM:$ 192,511 ETD:$ 370,468 EFC:$ 2,112,043 MW: 9.7 VISC: 65 PV/YP: 24/29 DRILLING AT 5,000' Drill from 3543' to 4535'. Hole trying to pack-off & not much cuttings returns. Circulate Lo & Hi visc sweeps around. Drill to 4590'. Bit torquing up & slow ROP. POH, RIH, hit bridge at 2302', wash & ream to 2400'. 80,837 CUM:$ 273,348 ETD:$ 458,422 EFC:$ 2,104,926 APIWL: 7.6 MW: 9.7 VISC: 52 PV/YP: 19/17 RUNNING SURFACE CASING Precautionary ream from 4354' 5595'. POH. Tight at 1490' to 2674'. POH for 9-5/8" surface 75,036 CUM:$ 348,384 ETD:$ 6.4 APIWL: to 4590'. Drill from 4590' to 1310'. Bridges at 2500' to pipe. 543,142 EFC:$ 2,095,242 APIWL: 6.4 MW: 9.8 VISC: 49 PV/YP: 19/12 PREP TO DO TOP JOB ON 9-5/8" Held pre-job safety meeting. Run 9-5/8" surface casing. Cement first and second stage. Back out LJ the wrong way, backed out of casing 2 jts below hanger. 227,404 CUM:$ 575,788 ETD:$ 543,142 EFC:$ 2,322,646 MW: 0.0 VISC: APIWL: 0.0 0 PV/YP: 0/ 0 f / I Date: 1/2/98 TD: 5595' ( SUPV:DEB DAILY: $ 09/22/97 (D8) TD: 5595' ( 0) SUPV:DEB DAILY: $ 09/23/97 (D9) TD: 6515' ( 920) SUPV:DEB DAILY: $ 09/24/97 (D10) TD: 8630' (2115) SUPV:DEB DAILY: $ 09/25/97 (D11) TD: 9607' ( 977) SUPV:DEB DAILY: $ 09/26/97 (D12) TD: 9832' ( 225) SUPV:DEB PREP TO TST WELD ON WH ADAPTER Drift & strap 9-5/8" & pick out joints for screw-in. Top Job with cement. Cut 18" section out of 16" conductor, lower landing ring, & reweld to accomodate welding on 9 5/8" & height difference with "emergency" wellhead equipment. Make final cut on 9 5/8" & dress off. Change out air IBOP & manual valve on top drive while weld cooling down. 75,082 CUM:$ MW: 8.5 VISC: 35 PV/YP: 4/ 7 RIH WITH BHA #3 Continue monitoring slow cool down of weld on FMC transition nipple. Test BOPE to 300/3000 psi. OK. Clean out 25' of cement on top of plug. Drilling out stage collar at 1753' . 169,329 CUM:$ MW: 8.7 VISC: 47 PV/YP: 10/13 DRILLING AT 7250' Drill out Gemoco stage collar at 1753', wash cement stringers/scale to 1840'. Drill cement from 5254' to 5452', just above shut-off baffle. Drill cement, shut-off plug, float collar, cement, float shoe. Drill 20' of new hole to 5615'. Perform formation leak off test, 14.0 ppg EMW. Drill from 5615' to 6515'. 81,157 CUM:$ 901,356 ETD:$ /,"", , ARCO ALASKA INC. WELL SUMMARY REPORT 0) 650,870 ETD:$ 820,199 ETD:$ MW: 8.9 DRILLING @ 8840' Drill from 6515' to 6395' to 6207'. 76,546 CUM:$ ".-..,., 543,142 EFC:$ 543,142 EFC:$ VISC: 48 PV/YP: 13115 632,737 EFC:$ Page: 2 2,397,728 APIWL: 20.0 2,567,057 APIWL: 9.5 2,558,619 APIWL : 6.4 8630'. POH for short trip. Tight from MW: 10.0 VISC: 54 PV/YP: 22/26 CBU & EVALUATE LOGS @ 9752' Drill from 8630' to 9607'. Connection gas to surface, boiling over bell nipple. Shut-in well. Had slow, ratty drilling break from 9545'-9550'. Circulate mud around on choke. Had oil and gas cut at start of circulation. Oil streaking stayed constant. Add LCM. Flow died out. Work pipe, pipe free, no sticking. Well started breathing or flowing slowly. 78,756 CUM:$ 1,056,658 ETD:$ 977,902 ETD: $ 838,709 EFC:$ 933,855 EFC:$ 2,429,193 APIWL: 4.2 2,412,803 MW: 11.3 VISC: 52 PV/YP: 23/20 11.6 PPG AROUND, PREP TO SHORT Reciprocate pipe and circulate down flowline, mud gas cut and boiling over bell nipple near bottoms up. Drill from 9607' to 9832'. Mud gas cut to 9.0 ppg and boiling for 65 bbls at bottoms up. Weight up to 11.3 ppg. Reciprocate pipe. Static. CBU. Very little gas cut at bottoms up, no APIWL: 4.4 iF / /' Date: 1/2/98 ~ .j ,-...., ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 boiling and no foamy mud. Pump out 5 stands. Try to pull next stand, tight and swabbing. DAILY: $ 98,016 CUM:$ 1,154,674 ETD:$ 955,767 EFC:$ 09/27/97 (Dl3) TD: 9832' ( 0) SUPV:DEB DAILY: $ 09/28/97 (Dl4) TD: 9832' ( 0) SUPV:DEB DAILY: $ 09/29/97 (D15) TD: 9832' ( 0) SUPV:DEB DAILY: $ 09/30/97 (Dl6) TD:10490' ( 658) SUPV:DCL DAILY: $ 10/01/97 (D17) TD:10775' ( 285) SUPV:DCL DAILY: $ 10/02/97 (D18) TD:l0954' ( 179) SUPV:DCL DAILY: $ 10/03/97 (D19) TD:11628' ( 674) SUPV:DCL DAILY: $ 10/04/97 (D20) TD:11712'( 84) SUPV:DCL 2,488,907 MW: 11.6 VISC: 51 PV/YP: 24/20 RUNNING 7" CASING Mud gas cut to 9.3 ppg for but not boiling. Weight up no gas at bottoms up. Held casing. 74,333 CUM:$ 1,229,007 ETD:$ APIWL: 4.8 45 bbls at bottoms up, foamy, to 11.6 ppg and circulate. CBU, pre-job safety meeting. Run 7" 955,767 EFC:$ 2,563,240 MW: 11. 6 VISC: 50 PV/YP: 14/16 APIWL: 9.2 LD 5" DP Run 7" intermediate casing. Pump cement. Test BOPE. 230,204 CUM:$ 1,459,211 ETD:$ 955,767 EFC:$ 2,793,444 MW: 12.0 VISC: 45 PV/YP: 13/14 APIWL: 8.0 CHANGE OVER TO 12.0 PPG MUD Freeze protect 9-5/8" x 7" annulus. Tag cement @ 9709' MD. 123,395 CUM:$ 1,582,606 ETD:$ 955,767 EFC:$ 2,916,839 MW: 12.0 VISC: 48 PV/YP: 20/25 APIWL: 4.4 DRILLING Drill out cement. Float equipment and 11' new hole to 9843'. Perform FIT, 16.1 ppg EMW. Drilling from 9843' to 10490' . 96,081 CUM:$ 1,678,687 ETD:$ 1,306,382 EFC:$ 2,662,305 MW: 12.2 VISC: 57 PV/YP: 24137 APIWL: 3.8 MU BHA Drilling from 10490' to 10775'. Pump out of hole to shoe. Hole taking improper fill. Circ out gas cut mud. Increase mud weight to 12.2 ppg. Pump out to shoe. Pump pill. POH to 7910'. Had slight flow. CBU. No gas cut mud. 92,311 CUM:$ 1,770,998 ETD:$ 1,471,616 EFC:$ 2,589,382 MW: 12.1 VISC: 64 PV/YP: 32/46 DRILLING @ 11200' Held safety meeting. Circ and balance mud. No bottoms up. Drilling from 10775' to 10954'. 109,645 CUM:$ 1,880,643 ETD:$ 1,575,394 EFC:$ APIWL: 3.2 gas at 2,595,249 MW: 12.1 VISC: 65 PV/YP: 32/48 APIWL: 2.8 DRILLING Drilling from 10954' to 11628'. 97,511 CUM:$ 1,978,154 ETD:$ 1,966,158 EFC:$ 2,301,996 MW: 12.4 VISC: 68 PV/YP: 27/52 APIWL: 3.0 MIX LCM Drilling from 11628' to 11712'. Raise mud weight to 12.2 ppg. POH. Hole taking improper fill. CBU. Had gas to surface at 1/2 bottoms up. Increase weight to 12.4 ppg. W if f! Date: 1/2/98 DAILY: $ ",.--..,. ..--..., ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 2,065,760 ETD:$ 2,014,859 EFC:$ 2,340,901 87,606 CUM:$ APIWL: 10/05/97 (D21) TD: 11712' ( 0) SUPV:DCL DAILY: $ 10/06/97 (D22) TD:11712 , ( 0) SUPV:DCL DAILY: $ 10/07/97 (D23) TD:11712' ( 0) SUPV:DCL DAILY: $ 10/08/97 (D24) TD: 11 712' ( 0) SUPV:DCL DAILY: $ 10/09/97 (D25) TD: 11712' ( 0) SUPV:DCL DAILY: $ 10110/97 (D26) TD:11712'( 0) SUPV:DCL DAILY: $ 10/11/97 (D27) TD:11712' ( 0) SUPV:DCL DAILY: $ MW: 12.4 VISC: 70 PV/YP: 32/48 2.8 LD BHA Pump pill. CBU. Small amount returns. Mix LCM and add gel mud. No gas at bottoms up. 82,607 CUM:$ 2,148,367 ETD:$ of gas at bottoms up. Lost 30% to system. Circ and condition 2,014,859 EFC:$ 2,423,508 MW: 12.4 VISC: 74 PV/YP: 29/51 APIWL: 3.0 MIX LCM FOR LINER Held pre-job safety meeting. RIH with 4.5" liner. 109,747 CUM:$ 2,258,114 ETD:$ 2,014,859 EFC:$ 2,533,255 MW: 12.3 VISC: 62 PV/YP: 29/40 SHAKEOUT LCM Continue to RIH with 4.5" liner on 3.5" DP to 11712'. Circ and condition mud. Lost 50% returns. Formation breathing. Pump baroseal and barofiber fine LCM. 106,171 CUM:$ 2,364,285 ETD:$ 2,014,859 EFC:$ 2,639,426 APIWL: 3.2 0 PV/YP: 0/ 0 APIWL: 0.0 MW: 0.0 VISC: PREP TO RUN COMPLETION RIH w/Baker GBH-22 locator seal assembly and packer. Set packer. Test casing to 3500. 138,761 CUM:$ 2,503,046 ETD:$ 2,014,859 EFC:$ 2,778,187 MW: 0.0 VISC: 0 PV/YP: APIWL: 0.0 0/0 ND BOPE Pump nut plug pill. Held pre-job safety meeting. RIH w/4.5" completion equipment. Latch into pkr. Shear PBR. Freeze protect. 321,130 CUM:$ 2,824,176 ETD:$ 2,014,859 EFC:$ 3,099,317 MW: 0.0 VISC: 0 PV/YP: 0/0 APIWL: 0.0 FINISH LD DP Finish run completion. ND BOPE. NO master valve. 102,035 CUM:$ 2,926,211 ETD:$ 2,014,859 EFC:$ 3,201,352 MW: 0.0 VISC: 0 PV/YP: 0/ 0 RIG RELEASED Release rig at 03:00 hrs. 10/11/97. 12,237 CUM:$ 2,938,448 ETD:$ 2,014,859 EFC:$ APIWL: 0.0 3,213,589 End of WellSummary for Well:AK9077 f / I ~ate' 1/2/98 ~ ~, fI ., ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS ------------------------------------------------------------------------------- ------------------------------------------------------------------------------- WELL:1E-34 WELL ID: 999079 AFC: 999079 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD: START COMP:10/27/97 RIG:NORDIC 0% WI: SECURITY: 0 TYPE: AFC EST/UL:$ 375M/ 519M API NUMBER: 50-029-22805-00 BLOCK: FINAL: ------------------------------------------------------------------------------- ------------------------------------------------------------------------------- 10/27/97 (C1) TD: 0' PB: 01 SUPV:MC DAILY: $ 10/28/97 (C2) TD:116461 PB:116461 SUPV:DLW DAILY: $ 10/29/97 (C3) TD:11712' PB:11646' SUPV:DLW DAILY: $ 10/30/97 (C4) TD:117121 PB:11646' SUPV:DLW DAILY: $ RIH TO DRILL CEMENT MW: 8.5 SW Move rig from 1E-31 to 1E-34. Accept rig @ 0100 hrs. 10/27/97. ND tree. NU BOPE. Test BOPE. Safety meeting. RIH w/2-7/8" DP. 0 CUM: $ 0 ETD:$ 0 EFC:$ 0 POOH FOR PERF GUNS MW: 8.5 SW Continue to RIH w/ BRA #1 on 2-7/8" DP. Work tight spot @ 97801. Clean out 4.5" liner from 9780' to 99221. Clean out cement stringers from 9780' to 116361. Monitor well. Well flowing. 0 CUM: $ 0 ETD:$ 0 EFC:$ 0 POOH W/PERF GUNS MW: 0.0 Pump brine to kill well. Pump Flo-Pro pill and spot from 11648' to 104001. Monitor well, dead. Safety meeting. RIH with tubing conveyed perforating guns. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 RIG MOVED TO 1E-33 MW: 0.0 Continue RIH w/2-7/8" tubing conveyed perforating guns on DP to 11646'. Fire guns. POOH w/ perf. guns. ND BOPE. NU tree. Test tree to 250/5000 psi. 0 CUM:$ 0 ETD:$ End of WellSummary for Well:999079 0 EFC:$ 0 ~ ~ CASING AND LEAK-OFF FRACTURE TESTS Well Name: 1 E-34 KRU Date: 9/23/97 Supervisor: Don E. Breeden 4/ ~ Casing Size and Description: 9-5/8",40#, L-80, BTC Casing Setting Depth: 5577' TMD 3950' TVD Mud Weight: 8.4 ppg EMW = Leak-off Pressure (PLO) 0.052 x TVD +MW EMW = 1155 psi I (0.052 x 3950 ft) + 8.4 ppg Drilled 8-1/2" hole to 5615' MD. EMW = 14.0 ppg Pumped 2.6 Bbls. 100 "\ broke Down @ 1- 55 psi .-.-.-.-.-.-.-.-.-. 2000 1900 1800 1700 1600 1500 1400 1300 1200 M:! 1100 m 1000 Œ 900 800 . 0 rv inute St ut-II" 700 600 500 400 300 -.- LEAK-OFF TEST -0- CASING TEST 200 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 smOKES 38.77 .96 1.42 9691.33 1.30 85.91 1.48 Bottom of Shoe ==» I TD = 9832' MD (:1:10' Rathole) "--.,, ~ CASING I TUBING I LINER DETAIL 7" Intermediate Casing ARCO Alaska, Inc. Subsidiary of Attantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN 7" Long String 234 Jts (Landing Joint = 42.45', 3.68' above RKB) RKB to Casing Head/Hanger Lockdowns - Parker Rig #245 FMC Gen 5, 7" Fluted Mandrel Casing Hanger & Packott (to LDS) FMC Pup Joint - 7", 29#, NT-80S Casing, NSCC pin x BTC pin 7", 26#, L -80, ABM-BTC Casing Jt #3 - #236 Gemoco Float Collar 7", 26#, L -80, ABM-BTC Casing Gemoco Float Shoe 2Jts Jt#l &#2 Baker Lock thru Float Collar 13 Bow Spring Centralizers: Run one on each of first 13 joints. Use stop rings in the middle of the first two joints. 13 Centering Guides: Slip on Joints # 188, 191, 194, 197, 200, 203, 206, 209, 212, #217, 222, 227, & 232. Install Hanger on top of Joint #236 (Leave 9 Joints in the Shed => Jts #237 thru #245.) WELL: 1 E-34 KRU DATE: 9/28/97 1 OF 1 PAGES LENGTH DEPTH TOPS 38.77 39.73 41.15 9732.48 9733.78 9819.69 9821.17 Remarks: String Weights with Blocks: 260K# Up, 145K# Dn, 75K# Blocks. Ran 236 joints of casing Drifted casing & hanger with 6.151" plastic rabbit. Used National Arctic Grade API Modified No Le< thread compound on all connections (National = BOL 2000). Torqued connections to the base of triangle stamp (6500 ft-Ib Average). Parker Rig #245 Drilling Supervisor: Don E. Breeden ~ ~ ARCO Alaska, Inc. Cementing Details Well#: 1 E-34 Field: Kuparuk River Unit Date: 9/28/97 Casing Size ;ole DiametEwerage Angl Shoe Depth Float Depth I % washout 7" 8-1/2" 61 ° 9821' 9732' Centralizers State type used, intervals covered and spacing 13 Bow Spring Centralizers: One on each of first 13 joints, used sto~ middle of first two joints. 13 Centering Guides: every 5th joint to K< 3rd joint to 2053' MD, I Weight PV(prior con PV(after conlyp(priOr conI YP(after cone 11.6 ppg 25 23 20 20 Gels before Gels after Total Volume Circulated 8/13 6/10 517 Bbls Spacer Type Volume ARC a Spacer 50 Bbls Lead Type MiX wtr tem: No. of sacks Weight Cement n/a Additives Mud Weight 12.0 ppg Yield Tail Type IMiX water te1 No. of sacks Weight I Yield Cement Class G -Û5° F 165 sx 15.8 ppg 1.15 cfs Additives: Class G + 0.20% D46 + 0.15% D65 + 0.26% D800 Displacemer Rate(before tail at shoe) Rate(tail around shoe) Str. Wt. Up 5.25 BPM 5.25 BPM 260K# Reciprocation length Reciprocation speed Str. Wt. Down :t 12' :t25 fpm 145K# I Theoretical Displacement Actual Displacement Str. Wt. in mu< 372.5 Bbls 372.5 Bbls 21OK# Calculated top of cemen CIP 3umped plug Floats held 8776' MD (for 8.835" Hole~ 1100,9/28 Yes I Yes Remarks: Include whether full returns were obtained, reciprocation throughout operation and any other pertinent information. Dowell prime up & flush line with 5 Bbls water. Test lines to 3800 psi. Pump 50 bt Spacer weighted to 12.0 ppg. Drop bottom plug. Mix & pump 33.6 Bbls (165 sx: cement. 4 BPM. Drop top plug. Kick out with 20 Bbls wash-up water. Switch to displace with mud, 5.25 BPM, 600 psi to 750 psi. Bumped plug at calculated disl Bumped up to 3500 psi & held for 5 minutes, lost 25 psi, OK. Bled off pressure & < floats, floats held. Reciprocated pipe throughout. 275K# to 260K# up weight. 11 145K# down weight. 75K# block weight. Full returns. CIP @ 1100 hrs, 9/28/97. Cement Company Dowell I Rig Contractor Parker Rig #245 I Signature Don E. Breeden - .~.. , ~ ~, ~ !Æ'~f 1 ':-34 Producer Comple'uon 1 U I /. ~ ~ /. ;.' ~ ~ /. ;.' ~ ~ /. /. ~ ~ ;.' I. ~ ~ /. ;.' ~ ~ /. /. ~ ~ /. /. ~ ~ ;.' /. ~ ~ ;.' I. ~ ~ /. /. ~ ~ I. /. ~ ~ I. I. ~ ~ /. /. ~ ~ /. /. ~ ~ /. /. ~ ~ I. /. ~ ~ ;.' /. ~ ;; ;.' ;' ~ ;; ~ ;; I. /. ~ ;; ;; ~ ~ ~ ~ ~ ~ ~ /. /. ~ ~ ~ ~ ~ ~ ;' /. :::, ~ ;.- /. ~ ~ ~ ~ ;; ~ ;; ~ - .,?'"' ~ ;C:;;j, g ~ i--"""""1 ~ ~ 4}ÑìwI$)!~l- ¿ ~, I L.~hf. ~ ;' /. ~ ~ /. /. ~ Top of Liner ~ ~ """ ~ ~ 200' above 7" shoe ~ ""',,"':ž ~ /. I. ~ ""I"I'. ;.' Intermediate csg: ~ ?'" 7" 26# loBO ~~ BTC-Mod ~ set above Kup; Plan: 987S' MD ~ ?¿ Z Z Z % Z Z Z Z Z ~ ~ Surface csg: ~ 9-S/8" 40# ~ l-80 BTC .. Liner: 4-1/2" 12.6# ~ L-80 NSCT ~ I. 4-1/2" SM FMC "Prudhoe BayN Gen V tubing hanger with 4-1/2" L-80 NSCT pin down. H. 4-1/2" 12.6# L-80 NSCT tubing to surface. G. 4-1/2" CAMCO BAL'() hydraulic landing nipple with 3.812"10 No-Go profile set at :t:1500' MD. Control line & bands. Run with 4-1/2N DB lock w/spacer. Nipple has BTC pin x pin: 6' L-80 flow coupling with handling pup on TOP of ~ need XO to NSCT; 6' L-SO handling pup below nipple also. ~ ž ž ž Ž % Ž Ž % ~ ~ ~ ~ ~ F. 4-1/2" 12.6# L-80 NSCTtubing to BAL-O landing nipple wI 4-1/2" x 1" CAMCO KBG-2-LS mandrels wI OVs & latches, BTC pin x pin connections. handling pups require XO to NSCT. Spaced out as follows: ~ MO-RKB TVO-RKB 6 2824' 2600' 5 4998' 3675' 4 6650' 4475' 3 7890' 5075' 2 8818' 5525' E. 4-1/2" x 1" CAMCO KBG-2-LS mandrels wI DVs & latches, BTC pin x pin connections. 6' handling pups require XO to NSCT. D. 1 ~ 4-1/2" L-80 NSCTtubing. C. 4-1/2" Otis 'X' landing nipple with 3.812" ID selective profile, NSCT. B. 1 ~ 4-1/2" L-80 NSCT tubing. A. Baker 12' PBR w/'KBH-22' latch-in anchor seal assembly (3.875" ID) and shear-pinned Baker GBH-22 locator seal assembly with 10' seals. 4-1/2" x 6' L-80 handling pup installed on top, XO EUE 8rd to NSCT. ~ Permanent Packer Assembly (run on drillpipe): . Baker 7" x 4-1/2" 'FAB-1' Packer . 4-1/2" x 10' L-80 NSCT blast joint (5.25" CD, 3.958"ID). . Baker "GBH-22" 4-1/2" locator seal assembly w/10' of seals and special locator to locate In liner SBE. 4-1/2" NSCT box on top of seal assembly. (4.7S" OD seals, 3.875" ID seal assembly). ..,¡( Liner Assembly (run on drillpipe): . Baker 5-1/2" setting sleeve (4.997" ID). . Baker 10' Seal Bore Extension (4.75" seal bore, 5.875" CD), XO to hanger. . Baker 5" x 7" 18# L-80 'CMC' mechanical liner hanger (4.276" ID), XO to 4-1/2" NSCT pin on bottom. I 4-1/2~ Camco 'DB' landing nipple with 3.75" ID No-Go profile set 1 joint below I the liner assembly. - Liner & packer run on 3-1/2" 15.5# G1 05 drill pipe wi 3-1/2" IF connections. Future Tublng-Conveyed Perforations (CTU) 4-1/2" NSCT landing collar/FS/FC Plan TO: 12200' MO (:1:2000' horz sect) DKP 09/19/97 ,-..... /""""\ lI!:i8 .... IÑTiij- Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E ConocoPhillips Alaska, Inc. Slot: Well: Wellbore: slot #34 34 34 ...-- ConocoPhillips SœI. IInoh" 1&" C~""Y PI"""" ca."""" $-",,-2004 P"'"""""", R.f""..h,,"WD<O-1171<' eo"".........,"....,...""""""o" T<~VO""""""Ih"""'.""",R~""- "_""d""'Ih'...""""~R~""- R~DoWm """"""- R~""",,"~_I."tl1300. PI"""""".......,.TRU'N","- East (feet) -> '" 3" soo """ 1SO0 '",,0 2100 2200 2>00 '400 . , , . . . . . , . , . . , , ~__'000 '3PtjI - 91 : -1100 - -1200 - -1400 - -1500 - -1700 . -2000 . -,.00 I' z 0 - -2700 5: i' D - -2SO0,: c:; - -2900 - -3000 - -3100 - -"00 \ \ \ \ \ \ \ \ \ \ ~ - -3300 - -'400 - -3500 - ->000 - -3100 - -"" - -4000 ~ - -4200 ~ - -4000 i . -4400 Š ~ ~ ConocÓÁtillips ConocoPhillips Alaska, Inc. MWD <0 -11712'>,34 slot #34, Pad 1 E CLEARANCE LISTING Page 1 Date Printed: 6-May-2004 Kuparuk River Unit, North Slope, Alaska ,&¡. BAKER HUGHES INTEQ Ellipse separations are reported ONLY if BOTH wells have uncertainty data Only Depth and Maç¡netic Reference Field error terms are correlated across tie points Proximities beyond ft with expansion rate of ft/1 OOOft are not reported Cutoff is calculated on CENTRE to CENTRE distance Summary data uses Horizontal Plane clearance calculation for all minima Hole size/Casinos are NOT included Hole size/Casinos are NOT subtracted from Centre-Centre distance Ellipses scaled to 2.58standard deviations. Closino Factor Confidence limit of 99.80% Errors on Ref start at Slot Permanent Datum (0.00) Report uses Revised: (D-C)/E Factor Calculation Well bore Name 34 I Created 19-5ep-2003 I Last Revised 5-May-2004 Well Name 34 I Government 10 I Last Revised 24-Feb-2004 Installation Name Pad 1E EaStinç¡ 550528.1946 I Northlno 5959591.1090 I Coord System Name North Aliç¡nment AK-4 on NORTH AMERICAN DATUM 1927 datum True Field Name Kuparuk River Unit I Eastina 487754.6208 Northina 5948985.8206 I Coord Svstem Name I North Alianment AK-4 on NORTH AMERICAN DATUM 1927 datum True Clearance Summary Offset Offset Offset Offset Minimum MD[ft] Diverging Ellipse Ellipse Clearance Clearance WellName Wellbore Slot Structure Distance From[ft] Separation MD[ft] Factor MD[ft] Iftl Iftl 2 2 slot #2 Pad 1E 463.72 5577.00 5577.00 1A 1A slot #1 Pad 1E 1229.23 5577.00 5577.00 1 1 slot #1 Pad 1E 1313.24 5577.00 5577.00 WS-2 WS-2 slot #WSR#2 Pad 1E 135116 5577.00 557700 23 23 slot #23 Pad 1E 1417 04 5577.00 5577.00 32 32 slot #32 Pad 1E 1460.24 5577.00 5577.00 Reference Well bore Survey Tool Program Survev Name MDrftl MWD<0-11712'> 11712.00 I Survev Tool ISCWSA MWD I Error Model Basic MWD - ISCWSA -28 JAN 03 OJH All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Actual Datum 113.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated Conocó'Phillips r--., /\ ConocoPhillips Alaska, Inc. MWD <0 -11712'>,34 slot #34, Pad 1 E CLEARANCE LISTING Page 2 Date Printed: 6-May-2004 Kuparuk River Unit, North Slope, Alaska All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Actual Datum 113 Oft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated _i. BAKER HUGHES INTEQ ~ ~ conocóPhillips ConocoPhillips Alaska, Inc. MWD <0 -11712'>, 34 slot #34, Pad 1 E CLEARANCE LISTING Page 3 Date Printed: 6-May-2004 Kuparuk River Unit, North Slope, Alaska ,&.. BAKER HUGHES INTEQ Clearance Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Horizontal Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Plane Separation Highside Distance [ft] [de¡¡l [ftl 5577.00 3949.85 2932.63S 1096.13E WS-2 3943 44 3949.85 2066.498 2133.16E 50.1 1351.16 Offset Well bore Survey Tool Proqrams Well fw, , ell bore I Survev Name WS-2 WS-2 TOTCO Survey ¡MDfft] JsurvevTool 66970 No Tool I Error Model All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Actual Datum 113.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated ~ ~ Conoc6Phillips ConocoPhillips Alaska, Inc. MWD <0 - 11712'>, 34 slot #34, Pad 1 E CLEARANCE LISTING Page 4 Date Printed: 6-May-2004 Kuparuk River Unit, North Slope, Alaska '&1. BAKER HUGHES INTEQ Clearance Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Horizontal Ellipse MD[ft] TVO[ft] North[ft] East[ft] MO[ft] TVO[ft] North[ft] East[ft] From Plane Separation Highside Distance [ft] fdeo] fft] 5008.42 3949.85 219892S 2308.43E 58.8 1417.04 5577.00 3949.85 2932.63S 109613E 23 Offset Wellbore Survey Tool Pro~rams Well Iwellbore I Survev Name 23 .. 23 GMS <0-8350'> I MOrftl J Survev Tool 8350.0 Level Rotor Gyro IError Model Standard All data is in Feet unless otherwise stated Coordinates are from Slot and TVO's are from Rig ( Actual Datum 113.0ft above mean sea level) Reference MO's are from Rig, Offset MO's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (10) Prepared by Baker Hughes Incorporated Conoc6Phillips ~ ConocoPhillips Alaska, Inc. MWD <0 -11712'>,34 slot #34, Pad 1 E ~ CLEARANCE LISTING Page 5 Date Printed: 6-May-2004 Kuparuk River Unit, North Slope, Alaska r&l. BAKER MUGMES INTEQ Clearance Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Horizontal Ellipse MO[ft] TVO[ft] North[ft] East[ft] MO[ft] TVO[ft] North[ft] East[ft] From Plane Separation Highside Distance [ft] fdeq] fft] 5976.83 3949.85 4280.30S 533.90E -157.3 1460.24 5577.00 3949.85 2932.63S 109613E 32 Offset Wellbore Survey Tool ProQrams Well Wellbore I Survev Name 32 32 MWO <0-10445'> MOfftl J Survev Tool 10445,011SCWSA MWD I Error Model Basic MWD - ISCWSA - 28 JAN 03 OJH All data is in Feet unless otherwise stated Coordinates are from Slot and TVO's are from Rig (Actual Datum 113.0ft above mean sea level) Reference MO's are from Rig. Offset MO's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated .---- ~ Conoc~illips ConocoPhillips Alaska, Inc. MWD <0 -11712'>,34 slot #34, Pad 1 E CLEARANCE LISTING Page 6 Date Printed: 6-May-2004 Kuparuk River Unit, North Slope, Alaska _i. BAKER HUGHES INTEQ Clearance Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Horizontal Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Plane Separation Highside Distance [ft] [deq] [ft] 515661 3949.85 2626.10S 1444.09E 48.6 463.72 5577.00 3949.85 2932 63S 1096.13E 2 Offset Wellbore Survey Tool Pro~rams Well Iwellbore I Survev Name 2 2 GMS <0-8440'> IMDfftl I Survev Tool 8440.od Level Rotor Gyro I Error Model Standard All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Actual Datum 113.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated ~, ~ oPh¥ . Canoe Imps ConocoPhillips Alaska, Inc. MWD <0 -11712'>,34 slot #34, Pad 1 E CLEARANCE LISTING Page 7 Date Printed: 6-May-2004 Kuparuk River Unit, North Slope, Alaska .¡. BAKER HUGHES INTEQ Clearance Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Horizontal Ellipse MO[ft] TVO[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Plane Separation Hlghside Distance [ft] Ideql Iftl 4406.83 3949.85 2054.07S 120.05E -480 131324 5577.00 3949.85 2932.63S 109613E Offset Wellbore Survey Tool Programs Well Wellbore Survev Name 1 1 MMS<0-2819'> 1 1. MSS <3010 - 7345'> MDfftl Survev Tool 2800.0(, Photomechanical Maqnetic 7345.0( Photomechanical Maanetic Error Model Standard Standard All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Actual Datum 113.0ft above mean sea level) Reference MO's are from Rig, Offset MO's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated /---- ~ Conoc~illips ConocoPhillips Alaska, Inc. MWD <0 -11712'>,34 slot #34, Pad 1 E CLEARANCE LISTING Page 8 Date Printed: 6-May-2004 Kuparuk River Unit, North Slope, Alaska r&l. BAKER HUGHES INTEQ Clearance Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Horizontal Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Plane Separation Highside Distance [ft] Ideq] 1ft] 4385.32 3949.85 1995.62S 300.51 E -40.3 1229.23 5577.00 3949.85 2932.63S 1096.13E 1A Offset Well bore Survey Tool Proarams Well wellbore Survev Name 1A 1A GMS <0-7310'> IMDrftl I Survev Tool 7310.0dLevel RotorGvro Error Model Standard All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Actual Datum 113.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: I 1E-34 I Rig: .. Date: I 5/8/2004 I Volume Input Pump Rate: Drilling supervisor:. I ~iCk Scales I pump. used: 1 Other - See comments;'" 1 Barrels i... ¡ Bbls/Strk I ... I Bbl/min I ... Type of Test Annulus Leak Off Test for Disposal Adequacy 1..-1 Pumping down I annulus. 1..-1 Casin~ Test Pressure Integrity Test Hole Size: lather - See commen~ .1 Casing Shoe Depth. .11 Hole Depth . Pumping Shut-in Pumping Shut-in RKB-CHF: 1Ft 5,615 IFt-MDI 3,950Ft-TVD IFt-MO I I Ft-TVO Bbls psi Min psi Bbls psi Min psi CasinQ Size and Description: 19-5/8" 4O#/Ft L-80 BTC 1.1 0 0.25 250 1 1100 ChanQes for Annular Adequacy Test Pressure InteQrityTest 1 0.5 300 2 1075 )uter casing shoe test results 6.8 in comments Mud Weight: 6.8 ppg 2 0.75 350 3 1050 Description references outer 8.8 casing string. Inner casing 00: 7.0 In. 3 1 400 4 1025 ;ize is that drilled below outer 5,615 casing. 4 1.25 550 5 990 ;timated TOC for Hole Depth. 5 1.5 700 6 960 Enter inner casing OD at right 7 DesiredPITEMW: 16.0ppg 6 1.75 850 7 950 Estimates for Test: 1890 psi #REF! 7 2 1000 8 935 Steel Volume During Casing Test = 0 bbl I. L Inner String Displacement = 0 bbl I. 8 2.25 1250 9 900 EMW = Leak-off Pressure + Mud Weight = 1225 68 PIT 15 Second 9 2.5 1275 10 900 0.052 x TVD 0.052 x 3950 + . Shut-in Pressure, psi 10 2.75 1225 0 EMW at 5615 Ft-MD (3950 Ft-TVD) = 12.8 1075 15 3 1215 0 20 3.25 1200 0 25 3.5 1200 0 30 3.75 1200 0 4 1200 0 4.25 1200 0 4.5 1200 0 4.75 1200 0 5 1200 0 0 0 ') 1500 ~ ... ... 1000 500 ) w cr:: :::) C/) C/) w cr:: c... -/ 0 0 2 3 Barrels 4 5 6 0 5 10 15 20 25 30 Shut-In time, Minutes 0 PIT Point Volume Pumped 0.0 tSbls Volume Bled Back I Bbls Volume Pumped 5.0 Bbls Vo ume Bled Back ItSbls Comments: ~CASING TEST 9-5/8" x 7" annulus. -LEAK-OFF TEST Hot Oil Pump Unit for La I RIG #: I DISPOSING INTO ANNULUS OF WELL: I ORIGIN OF FLUIOS START TIME END TIME INIGHT DISPOSAL SUPERVISOR: VERSION 1.3 PUMP RATE (BPM) STATIC PRESSURE (PSI) CPAI- DAILY ANNULAR DISPOSAL RECORD DA TE: I 5/8/2004 0000 HRS TO 0000 HRS DISPOSAL PRESSURE (PSI) 1 E-34 Operation that genarated Waste Mud TOTAL VOLUMES FOR DAY: I ADDITIVES USED: BARRELS DISPOSED (List under proper fluid type) Mud WATER for Flushing Annulus 300 MUD WATER GEL NIGHTS DAYS IDA Y DISPOSAL SUPERVISOR: DIESEL for Freeze Protecting 70 20 DIESEL a-GEL Rig Wash Water WASH WATER X-TND PAl DAILY ANNULAR INJECTION RECORD OTHER (specify in comments) OTHER BICARB TOTAL CUMULATIVE VOLUME 370 20 Totsl for Today PH6 FOR MUD ONLY: WEIGHT (PPG) FUNNEL VISCOSITY Cummu/ative Totsl from Previous Day ICPAI SUPERVISOR: NlcIc Scales Page - of- COMMENTS Completed 09/29/97 Rig 2- ) Diesel used for LOT 05/08/04 I New Totsl for this Annulus 390 SCOTT D. REYNOLDS 12-20-01 ~. ~ Mike Mooney Wells Group Team Leader Drilling & Wells ConocÓPhilli ps P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 May 10, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1 E-34 (APD # 197-166) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation activity on the Kuparuk well 1 E-34. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M. JI(~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED MAY 122004 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 1. Operations Performed: P. O. Box 100360 7. KB Elevation (ft): RKB113' 8. Property Designation: ADL 25660, ALK 470 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURF CASING PROD CASING LINER Perforation depth: RepairWell D Pull Tubing D Operat. ShutdownD Plug Perforations D Perforate New Pool D Perforate 0 4. Current Well Status: Development - 0 Stratigraphic D measured 11712' feet true vertical 6087' feet measured 11080' feet true vertical 6076' feet Length Size MD 121' 16" 121' 5464' 9-5/8" 5577' 9708' 7" 9821' 2071' 4-1/2" 11712' Stimulate D Other D Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 197-166/ 6. API Number: 50-029-22805-00 Exploratory D Service D 9. Well Name and Number: 1 E-34 10. Field/Pool(s): Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Burst Collapse 121' 3950' 5970' 6087' Measured depth: 10194'-10444', 10694'-11196', 11244'-11644', 10115'-10095', 10025'-10075' true vertical depth: 6082'-6082',6077'-6073',6072'-6084', 6069'-6064', 6043'-6059' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 9642' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FAB-1' pkr-- 9626' SSSV= Cameo Bal-O SSSV SSSV= 1511' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 13. Treatment descriptions including volumes used and final pressure: N/A Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Representative Daily Average Production or Injection Data Gas-Mel Water-Bbl 3247 4954 3911 5347 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: oil0 GasD WAGD Oil-Bbl 1263 1088 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Signature Mike Mooney @ 263-4574 Mike Mooney ~J H{~ Title Phone Form 10-404 Revised 04/2004 nJ)'~1t\1^\ RECEIVED MAY 1 2 2004 Alaska Oil & Gas Cons. Commission Anchorage Casino Pressure Tubino Pressure 201 281 Service D GINJD WINJD WDSPLD I Sundry Number or N/A il C.O. Exempt: Wells Group Team Leader (/ J / Date ..::r II¡ t/i PreDared by Sharon AI/suo-Drake 263-4612 _BFL SMA1 OJ.9i~1 ~Uð\ I " ,'-""" ~ 1 E-34 WELL EVENTS SUMMARY Date Summary 02/21/04 PRODUCTION PROFILE, DEFT+GHOST+TRACTOR. WELL IN TEST SEPARATOR, PRODUCING 5600 BWPD, 1700 BOPD, 3.624 MSCFID FORMATION GAS (NO GAS LIFT). LOG ACROSS PERFS IN HORIZONTAL SECTION USING WELL TEC TRACTOR. 02/22/04 MAINENT ANCE - ELINE - SWAP REEL POST TRACTOR JOBS 02/23/04 TAGGED DB NIPPLE @ 9694' RKB W/3.78" SWAGE, -9' CORR. DRIFTED TBG WITH 20' X 2.5" DUMMY GUN TO EST. 10131' RKB (PLANNED PERF INTERVAL 10025- 10115).0 [Tag] 02/25/04 DEMOB FROM TRACTOR 1 PPROFO [Prod-Inj Profile] 03/12/04 PERFORATE THE INTERVAL 10115-10095 USING 2.5" HSD GUNS LOADED 6 SPF, 60 DEG PHASED, RANDOM ORIENTATION (API CHARGE DATA: 2506 POWERJET HMX, 25.2" PENETRATION, 0.32" ENTRANCE HOLE.) NO CHANGE IN WHP AFTER FIRING EITHER GUN. PUMPED FLUIDS TO AID TOOLS FALLING IN HAW. MAX DEPTH WAS 10179.5'. PUMPED 97 BBL DIESEL AND 65 BBL 60/40 METH TOTAL. FP FLOWLINE WITH 60/40 METH. 03/13/04 CONTINUE PERFORATION PROGRAM: PERFORATE THE INTERVAL 10025-10075 IN THREE RUNS USING 2.5" HSD GUNS LOADED 6 SPF, 60 DEG PHASING, RANDOM ORIENTATION. CHARGES ARE 2506 POWERJET HMX, 25.2" PENETRATION, 0.32" ENTRANCE HOLE (API SPECS). ALL SHOTS FIRED. REACHED MAX DEPTH OF 10206 DUE TO HAW. sssv (1511-1512. 00:4.500) Gas Lift MandrelNalve 1 (2854-2855. NIP (9572-9573. 00:4.500) PBR (9612-9613, 00:4.500) SEAL (9625-9626. 00.4.500) SEAL (9639-9640. 00:4 750) TUBING (0-9642, 00:4.500. 10:3.958) NIP (9694-9695. 00.4.500) Perf :10194-10444) Perf :10694-11196) Perf :11244-11644) ,r-.., , ConocoPhillips AlaskaJ Inc" }[E-34:;O .. mm,",'.',':"','.',1F,' ~~;3M API: 500292280500 SSSV Type: WRDP ,~ Well Type: PROD Orig 10/11/1997 Completion: Last W/O: Ref Log Date: TD: 11712ftKB Max Hole Angle: 92 deg @ 10674 Annular Fluid: Reference Log: Last Tag: 11080 E-Line Lastl'a~ Date: 2/21/2004 ,C~l'ÌgjStritìg,;;'At;t;STRINGS Description CONDUCTOR SURF CASING PROD CASING LINER "TubiriO:Sttlng,.::ruBi NG ° Size I Top 4.500 0 l?ëlfcÏÏitlons;Sultimaryi" ° Interval TVD 10194 - 10444 6082 - 6082 10694 -11196 6077 - 6073 11244 -11644 6072 - 6084 ; Si's; llift:tJ aid (ølSNaN 8$ St MD TVD Man Man Type V Mfr Mfr 1 2854 2605 Cameo KBG-2-LS 2 5006 3677 Cameo KBG-2-LS 3 6639 4472 Camco KBG-2-LS 4 7941 5073 Cameo KBG-2-LS 5 8813 5522 Cameo KBG-2-LS 6 9530 5851 Cameo KBG-2-LS 1. ALL 6 MANDRELS ARE BTM LATCH ONL Y Other,;(pluQs;8(¡wp;; etêJ ~;¡}:eWELRY, Depth TVD Type 1511 1508 SSSV 9572 5869 NIP 9612 5886 PBR 9625 5892 SEAL 9626 5892 PKR 9639 5898 SEAL 9641 5898 SBE 9694 5921 NIP Size 16.000 9.625 7.000 4.500 Bottom 9642 Zone C-3,C-3 C-4 C-4 KRU Angle @ TS: 70 deg @ 9978 Angle@TD: 87deg@ 11712 Rev Reason: E-Line Tractor tag Last Update: 2/27/2004 Bottom TVD Wt Grade 121 121 62.58 H-40 5577 3950 40.00 L-80 9821 5970 26.00 L-80 11712 11712 12.60 L-80 TVD I Wt I Grade I Thread 5899 12.60 L-80 NSCT .,",,- Top 0 0 0 9641 Status Ft SPF Date Type Comment 250 4 11/5/1997 IPERF 27/8" TCP HSD 502 4 11/5/1997 IPERF 2 7/8" TCP HSD 400 4 11/5/1997 IPERF 27/8"TCPHSD V Type VOD Latch OV 1.0 INT DMY 1.0 INT DMY 1.0 INT DMY 1.0 INT DMY 1.0 INT DMY 1.0 INT Description Cameo 'BAL-O' WRDP Otis 'X' Selective Profile Nipple NO GO Baker Baker 'KBH-22' SEAL ASSY. Baker'FAB-1' Baker 'GBH-22' SEAL ASSY. Baker '80-47' Cameo 'DB' NO GO Nipple 1 E-34 Thread 00"- m' 0" Port TRO Date Vlv Run Cmnt 0.250 0 5/25/2002 (1) 0.000 0 10/10/1997 0.000 0 10/10/1997 0.000 0 10/10/1997 0.000 0 10/10/1997 0.000 0 10/10/1997 ID 3.812 3.813 3.875 3.875 3.958 3.875 3.922 3.750 Scbfumbepgep NO. 3125 Schlumberger -Des 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Well Job# Log Description 1C-1905t'3-rQ~ 10109106 INJECTION PROFILE 1E-34/9't 110 10109110 PRODUCTION PROFILE 1 C-15L 1!~G3 '(:',.3.') 10109113 PRODUCTION PROFILE 2Z-10 19;..t::i'- 3"1 10696843 PRODUCTION PROFILEIDEFT 2P-441gC'-=)-I&7ll 10696841 PERF/SBHP Field: Date BL Color 02116/04 1 02/21/04 1 02/25/04 1 02/26/04 1 03/01/04 1 ~ ' -----""'-" SIGNED: "f'))L"-"-- '<'- \ -),(\ ~,~ ~)~ DATE: 03/05/04 Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 1th Ave, Suite 100 Anchorage, AK 99501 Kuparuk CD R-C"-¡vcn ~ ' Ei L-tJ .' ,:, " 6 /,,¡I'\U!'l4~ I'" ., .: If' , . -,. L L-I.! "í,}...i...",n:lg("'..<)~CI'\nS Commi<HMn, ,~,!,:~ "" -~ ...~... Vii , ¡WI"'. Please sign and return one copy of this transmittal to Beth at the above address or fax to (901) 561-8311. Thank you. ,~w;horage ~~~n\~ THE MATER/AL UNDER T~S COVER ~s ~e~N. ON OR :BEFORE PL M ATE E W T H IS M ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Pedorate _ Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 634' FSL, 633' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 292' FNL, 2305' FWL, Sec. 27, T11N, R10E, UM At effective depth At total depth 828' FNL, 1335' FEL, Sec. 27, T11 N, R10E, UM 5. Type of Well: Development __X Exploratow__ Stratigraphic__ Service__ (asp's 549888, 5960223) (asp's 552882, 5954038) (asp's 554525, 5953514) 6, Datum elevation (DF or KB feet) RKB 113 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 E-34 9. Permit number / approval number 197-166 10. APl number 50-029-22805 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing CONDUCTOR SURF CASING 11712 feet Plugs (measured) 6087 feet PROD CASING LINER 11647 feet Junk (measured) 6084 feet Length Size Cemented 121' 16" 8 cu yds High Early 5464' 9-5/8" 711 Sx AS III LW, 660 Sx Gl G, & 60 Sx AS I 9708' 7" 165 Sx Class G 2071' 4-1/2" 360 Sx Class G Downhole Choke @ 9694' MD (set 4/4/00). Measured Depth True vertical Depth 121' 121' 5577' 3950' 9821' 5970' 11712' 6087' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 10194 - 10444'; 10694 - 11196'; 11244 - 11644' 6082-6082';6077-6073';6072-6084' 4-1/2", 12.6#, L-80, Tubing @ 9642' MD. Baker 'FAB-I' Packer @ 9626' MD. WRDP-2 on DB-6 Lock; set 10/29/97 @ 1511' MD. RECEIVED FEB 1 G ZOO1 Alaska Oi~ & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 2295 Subsequent to operation 1741 Representative Daily Average Productionorlniection Data Gas-Mcr Water-Bbl 19088 4975 2706 2407 Casing Pressure - Tubing Pressure 615 236 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: Form 10-404 Rev 06/15/88 · Date Z//~/~1 / Preparerd by John Peirce 265-6471 SUBMIT IN DUPLICATE '-'~[~ 1E-34 DESCRIPTION OF WORK COMPLETED BRIDGE PLUG REMOVAL& DOWN HOLE CHOKE INSTALLATION 3/22/00: RIH & pulled Bridge Plug (set 12-14-97) from 10515' MD. 4/4/00: RIH & set a 7/16" HF Down Hole Choke on a 4" DB-6 Lock at 9694' MD. Returned the well to production & obtained a valid well test. MEMORANDUM TO' Julie Heusser, Chairman State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 4, 2001 THRU: Tom MaUnder, P. I. Supervisor FROM: SUBJECT: Chuck Scheve; Petroleum Inspector Safety Valve Tests Kuparuk River Unit 1E Pad Thursday, January 4, 2001' I traveled to the Kuparuk River Field and witnessed safety valve system testing on 1E Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 9 wells 18 compOnents on 1E pad with 2 failures. The Pilot on well 1E-07 was frozen and the Surface Safety Valve on well 1E-24A had a slow leak when pressure tested. A pOrtable heater was brought to location and the above mentioned pilot was thawed out. I requested the portable heater remain on this well until repairs are made on the catalytic heater in the wellhouse. The failed safety valve will be serviced and retested when the grease crew becomes available Earnie Barndt conducted the testing today; he demonstrated good test procedures and was a pleasure to work With. I also inspected the well houses on this pad while Witnessing SVS testing. All the wellhouses were clean and the equipment appeared to be in good condition. Summary: I witnessed the SVS testing at 1E Pad in the Kuparuk River Field. KRU 1E Pad, 9 Wells, 18 components, 2 failure, 11.1% failure rate 16 wellhouSe inspections Attachment: SVS KRU 1E Pad 1-4-01 CS X Unclassified Confidential (Unclassified if doc. removed ) confidential SVS KRU 1E Pad 1-4-01 CS.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Operator Rep: Earnie Bamdt AOGCC Rep: Chuck Scheve . Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kuparuk / KRU / 1E Pad Separator psi: LPS 85 HPS 1/4/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed {;AS or CYCLE 1E-02 1800500 85 70 60 P' P ' OIL 1E-03 1800560 85 70 45 P P OIL 8oos' o 1E-06 1800780 1E-07 1800800 85 70 0 2 P OIL 1E-10 1820360 1 E- 11 1820510 1E-12 1820600 1E-14 1820790 . 1E-18 1830160! 85 70 50 P P OIL · 1E-19 1830170 1E-20 1830050 85 70 50 P P OIL 1E-21 1830020 1 E-23 1821840 1E-24A 1971870 85 70 70 P 4 ' OIL 1E-26 1821660! 1E-58 '" i821~80' 1E-29 1821540~ 1E-31 1971380~ 85 70 65 P P OILI 1E-33 . 1971510 1E-34 1971660 85 70 50 P P OIL 1E-36 1982130 85 70 60 P P OIL · Wells: 9 Components: 18 Failures: 2 Failure Rate: 11.1%~] 9o var Remarks: Pilot on 1E-07 frozen. Portable heater placed on pilot until catalytic repaired Surface Safety on 1E-24A had slow leak, valve to be serviced and retested. 1/9/01 Page 1 of l SVS KRU 1E Pad 1-4-01 CS.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, Commissioner DATE: July 22, 2000 THRU: Blair Wondzell, ~ SUBJECT: P. I. Supervisor e['z(,~o john H Spauldin¢/~ Petroleum Inspector FROM: SVS Tests Pads 1E & 2X Kuparuk River Unit Kuparuk River Field July 22, 2000: I traveled to Philips Alaska Inc.'s Kuparuk Field to witness the SVS Tests on 1E and 2X pads. The AOGCC form is attached for reference. As noted on the test reports a minimal amount of failures were observed (1 on each pad). Ernie Barndt the PAl representative and his helper did an excellent job of testing. SUMMARY: I witnessed the SVS tests on' PAl, KRU, 1E & 1X 1 E - 8 wells, 16 components, 1 failure, 9 % failure rate, 12 well house insp. 2X-- 10.wells, 20 compnents, I failure, 5 % failure rate, 12 well house insp. Attachment: Alaska Oil and Gas Conservation Commissioa Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: E. Bamdt AOGCC Rep: John H. Spaulding Submitted By: John H. Spauld Date: Field/Unit/Pad: Kuparuk/Kuparuk R. U./1 Separator psi: LPS 91 HPS 7/22/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code GAS or CYCLE 1E-02 1800500 91 70 65 P P OIL 1E-03 1800560 SI 1E-05 1800580 1E-06 1800780 SI 1E-07 1800800 91 60 55 P P OIL 1E-10 1820360 1E-11 1820510 1E-12 1820600 SI 1E-14 1820790 1E-18 1830160 91 60 46 P P OIL 1E-19 1830170 1E-20 1830050 91 60 48 P P OIL 1E-21 1830020 1 E-23 1821840 1E-24A 1971870 91 70 70 P P OIL 1E-26 1821660 SI 1E-28 1821580 SI 1 E-29 1821540 SI 1E-31 1971380 91 70 70 P P OIL 1E-33 I 1971510 ~2[-i~-~':~. ~ 1971660 91 70 70 P P OIL 1E-36 1982130 91 70 70 P P OIL Wells: 8 Components: 16 1 Failure Rate: 9.0% [] 90 Day Remarks: 8/7/00 Page 1 of 1 svs kuparuk kru 1 e 7-22-00js.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator ReP: E. Barndt AOGCC Rep: John H. Spaulding Submitted By: John Spaulding Date: Field/Unit/Pad: Kuparuk/Kuparuk R./2X Separator psi: LPS 96 HPS 22-Jul Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2~-01 1830840 2x-o2 .. 2X-03 1831090 2X-04 1831180 3000 2000 2000 P P WAG 2X-05 1831070 3000 2000 2000 P 4 WAG 2X-06 1831100 3000 2000 2000 P P WAG 2X-07 1831130 3500 2000 2000 P P WAG 2X-08 1831140 2X-09 1841620 96 70 60 P P OIL ,. 2X-10 1841630 96 70 65 P P OIL 2X- 11 1841640 96 60 60 P P OIL 2X-12A 1951760 2X-13 1841740 ~X-14 1841750 5X-15 1841760 96 70 70 e P OIL 2X- 16 1841720 I 2X-17 1951710 96 60 50! P P OIL 2X-18 1951600 96 60 50 P P OIL 2X-19 1951750 Wells: 10 20 Failures: 1 Failure Rate: 5.0% ~] 9o var Remarks: 8/15/00 Page 1 of 1 svs kuparuk kru 2x 7-22-00js.xls AOGCC Geological Materials Inventory PERMIT 97-166 ARCO Log Data Sent fi~ecieved 4--i-~ ~ ~ ~.~ ~-~P '~'~ ~ 1~0~99~ ~9~,998 97-166 ~ t0~,f]~ ,~ 10092-11630 ~}~ ~c~-)~ 'q/"~,p, ~,c,~ 1/20/1998 /29/1998 T 97-~66 ~ ~~ ~0092-~630 rkrP ~,y~ ~-.~':~',:-;.~ 1/20/~99~ /29a99~ · 9~-~66 ~ s~=VM~,/~mw~4 ~ ~)~ ~'c~ 2/~/~998 ~998 97-~6~ ~ 3959-6087 ¢g~ ~{~4 2/~a998 /~/~99~ 97-166 ~/~ 5595-11712 p4. b ?~ ~,~.,,, r~[ '~! 2/11/1998 /11/1998 97-166 t,t~'~- SPERRY 0-11712. 12/19/1997 /24/1997 97-166 SCHLUM ADN ' /cY (~ ( 11/10/1997 /13/1997 97-166 ~ BL(C) 10850-11600 ffL g ~ 11/10/1997 /13/1997 97-166 ~ BL(C) 10540-11710 ~ ~) ) .... ~ )'c*'- 11/10/1997 /13/1997 97-166 ~ 9821-11713.1. 9°~/~tm~ 11/10/1997 /13/1997 T -~0-407 Completion Date { O~ff ~7 Z Daily well ops ~3~/~) ~-' /¢~ 4 ~ 7 Are dry ditch samples required? Was the well cored? Are tests required? Well is in compliance Comments yes yes ~no Initial yes ~ And received? ~-no Analysis description recieved? Received'>_ yes ~.~no Box Thursday, October 07, 1999 Page I of 1 AOGCC Geological Materials Inventory TD PERMIT 97-166 ARCO Log Data Sent 7861 T SCHLUM ADN 11/10/1997 8238 D SPERRY MPT/GR/EWR4 2/11/1998 8303 T SCHLUM TDTP 1/20/1998 ADN IMAGES A BL(C) 10540-11710 11/10/1997 DGR/EWR4-MD L 5595-11712 2/11/1998 DGR/EWR4-TVD L 3959-6087 2/11/1998 DN4-MD A 9821-11713.1 11/10/1997 ELAN A BL(C) 10850-11600 11/10/1997 MWD SRVY R SPERRY 0-11712. 12/19/1997 TDTP L 10092-11630 1/20/1998 TDTP/B-SPIN L 10092-11630 1/20/1998 ~ 10-407 Completion Date __ Are dry ditch samples required? Was the well cored? yes Are tests required? yes Well is in compliance Comments Initial Daily well ops no And received? yes yes no Analysis description received? no Received? yes no Received 11/13/1997 2/11/1998 1/29/1998 11/13/1997 2/11/1998 2/11/1998 11/13/1997 T 11/13/1997 12/24/1997 1/29/1998 T 1/29/1998 T Box no -- yes - -- no Friday, October 08, 1999 Page 1 of l 1/20/98 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11730 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 -Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia LIS Tape 1'E-34 '/, -1I-- -~o.~ O7 97571 TDTP 971129 1 1 E-34 " 97571 TDTP-DEPTH CORRECTED 9711 29 I 1 1 E-34 '" 97571 TDTP BORAX/SPINNER 9711 29 I 1 1Q-0aA / '~ ~_~Oq, 98006 GR/CCL(PDC) 970728 1 3 C-05 INJECTION PROFILE 971 21 3 I 1 3 C-12 INJECTION PROFILE 9801 06 I 1 3 F-01 PRODUCTION PROFILE 9801 05, I 1 3F-12 INJECTION PROFILE 971 202 I 1 3F-15 INJECTION PROFILE 971 21 2 I 1 3 H -06 INJECTION PROFILE 971 205 I 1 3 H - 15 INJECTION PROFILE 971 209 I 1 30-11 . GAS LIFT SURVEY 971 027 I 1 WS 1 D-130 ./' ' CBT 9711 07 I I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL E~] GAS [~] SUSPENDED I~1 ABANDONED'---] SERVICE r~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 97-166 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22805 ........... "-~'~'~' 9 Unit or Lease Name 634' FSL, 633' FEL, Sec. 16, T11N, R10E, UM J ....... : :': ? At Top Producing Inte~al~ ~~~~~'~~~~ ;~J' ~: 10 WellKuparUkNumberRiver Unit At Total Depth _ .? ..... '~ .:': :;~ .... . ~- 11 Field and Pool 828' FNL, 1335' FEL, Sec. 27, T11N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indi~te KB, DF, etc.) J 6 Lease Designation and Sedal No. Kuparuk River Oil Pool Rig RKB 41', Pad 72'I ~L 25660 ~K 470 12 Date16_Sep_97Spudded 13 04-Oct-97Date T.D. Reached 14 09-Oct-97Date Comp., Susp. or ~and. 15 WaterNADepth, if offshorefeet MSL 16 No. l°f Completions 17 Total Depth (MD+WD) 18 Plug Back Depth (MD+WD) 19 Directional Su~ey 20 Depth where SSSV set 21 Thickness of permafrost 11712' MD & 6087' WD 11647' MD & 6084' WD YES ~ NO ~ NA feet MD 1465' APPROX 22 Type Electric or Other Logs Run G~Res + ADN4 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ G~E TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5¢ H-40 SURF. 121' 24" 8 cu. Yds. High Early 9.625" 40.0¢ L-80 SURF. 5577' 12.25" 711 sx ASIII LW, 660 sx Class G, 60 sx ASI 7" 26.0¢ L-80 SURF. 9821' 8.5" 165 sx Class G 4.5" 12.6¢ L-80 9640' 11712' 6.125" 360 sx Class G 24 Pedorations open to Production (MD+~D of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 9642' 9626' 10194'-10~' MD 6082'-6082' ~D 10694'-11196' MD 6077'-6073' ~D 26 ACID, F~CTURE, CEMENT SQUEEZE, ETC 112~'-116~' MD 6072'-6084' ~D DEPTH INTERV~ (MD) AMOUNT & KIND OF MATERIAL USED 4 spf P, CEiVE 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 11/10/97 gas lift Date of Test Hours Tested PRODUCTION FOI ,OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 1~25/97 12.00 TEST PERIOD 199 4751 0 212 26033 Flow Tubing Casing Pressure C~CU~TED OIL-BBL GAS-MCF WATER-BBL OIL G~VI~-API (~) Press. 210 1391 24-HOUR ~TE: 366 9528 0 24~ 28 CORE DATA Bdef description of lithology, porosiW, fractures, apparent dips and presen~ of oil, gas or water. Submit ~re chips. N/A nissi0r~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Total pump volumes for this event: Category 1. 0 Category 2. 0 Top Kuparuk C 9978' 6027' Category 3. 0 Bolfom Kuparuk C 11712' 6087' Total: 0 Top Kuparuk A 11712' 6087' Bottom Kuparuk A 11712' 6087' Total to Date: 0 Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drillin~ Reports, Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by Name/Number Sharon AIIsup-Drake/263-4612 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. ORIGINAL 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- in9 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 Date: 1/2/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:lE-34 RIG:PARKER 245 WELL_ID: AK9077 TYPE: AFC: AK9077 AFC EST/UL:$ 2290M/ 2950M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:09/16/97 START COMP: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22805-00 09/15/97 (D1) TD: 121' (121) SUPV:DCL DAILY:$ 09/16/97 (D2) TD: 451'(330) SUPV:DEB DAILY:$ 09/17/97 (D3) TD: 3543' (3092) SUPV:DEB DAILY:$ 09/18/97 (D4) TD: 4590' (1047) SUPV:DEB DAILY:$ 09/19/97 (D5) TD: 5595' (1005) SUPV:DEB DAILY:$ 09/20/97 (D6) TD: 5595' ( 0) SUPV:DEB DAILY:$ 09/21/97 (D7) MW: 8.4 VISC: 44 PV/YP: 10/12 APIWL: 16.6 Move rig from 1E-33 to 1E-34. Accept rig @ 1900 hrs. A!'~g0 9/15/97. NU diverter system. 35,357 CUM:$ 35,357 ETD:$ 0 EFC:$ 2,325,357 MW: 8.8 VISC: 80 PV/YP: 24/26 APIWL: 11.2 DRILLING Function test diverter, OK. Fill hole and check for leaks, air boot in riser in flow nipple. Change out air boot in telescoping sleeve in flow nipple. Spud at 121' and drill to 451' Disc-Flo plugged with gravel. 85,839 CUM:$ 121,196 ETD:$ 110,721 EFC:$ 2,300,475 MW: 9.7 VISC: 60 PV/YP: 18/26 APIWL: 8.2 DRILLING @ 3950' Drill from 451' to 3543' 71,315 CUM:$ 192,511 ETD:$ 370,468 EFC:$ 2,112,043 MW: 9.7 VISC: 65 PV/YP: 24/29 APIWL: 7.6 DRILLING AT 5,000' Drill from 3543' to 4535' Hole trying to pack-off & not much cuttings returns. Circulate Lo & Hi visc sweeps around. Drill to 4590' Bit torquing up & slow ROP. POH, RIH, hit bridge at 2302', wash & ream to 2400' 80,837 CUM:$ 273,348 ETD:$ 458,422 EFC:$ 2,104,926 MW: 9.7 VISC: 52 PV/YP: 19/17 APIWL: 6.4 RUNNING SURFACE CASING Precautionary ream from 4354' to 4590' Drill from 4590' to 5595' POH. Tight at 1490' to 1310' Bridges at 2500' to 2674' POH for 9-5/8" surface pipe. 75,036 CUM:$ 348,384 ETD:$ 543,142 EFC:$ 2,095,242 MW: 9.8 VISC: 49 PV/YP: 19212 APIWL: 6.4 PREP TO DO TOP JOB ON 9-5/8" Held pre-job safety meeting. Run 9-5/8" surface casing. Cement first and second stage. Back out LJ the wrong way, backed out of casing 2 its below hanger. 227,404 CUM:$ 575,788 ETD:$ 543,142 EFC:$ 2,322,646 MW: 0.0 VISC: 0 PV/YP' 0/ 0 APIWL: 0.0 Date: 1/2/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 TD: 5595'( SUPV:DEB 0) DAILY:$ 0) 09/22/97 (D8) TD: 5595'( SUPV:DEB DAILY:$ 09/23/97 (D9) TD: 6515' (920) SUPV:DEB DAILY:$ 09/24/97 (D10) TD: 8630' (2115) SUPV:DEB DAILY:$ 09/25/97 (Dll) TD: 9607' (977) SUPV:DEB DAILY:$ 09/26/97 (D12) TD: 9832'(225) SUPV:DEB PREP TO TST WELD ON WH ADAPTER Drift & strap 9-5/8" & pick out joints for screw-in. Top Job with cement. Cut 18" section out of 16" conductor, lower landing ring, & reweld to accomodate welding on 9 5/8" & height difference with "emergency" wellhead equipment. Make final cut on 9 5/8" & dress off. Change out air IBOP & manual valve on top drive while weld cooling down. 75,082 C UM:$ 650,870 ETD:$ 543,142 EFC:$ 2,397,728 MW: 8.5 VISC: 35 PV/YP: 4/ 7 APIWL: 20.0 RIH WITH BHA %3 Continue monitoring slow cool down of weld on FMC transition nipple. Test BOPE to 300/3000 psi. OK. Clean out 25' of cement on top of plug. Drilling out stage collar at 1753' 169,329 CUM:$ 820,199 ETD:$ 543,142 EFC:$ 2,567,057 MW: 8.7 VISC: 47 PV/YP: 10/13 APIWL: 9.5 DRILLING AT 7250' Drill out Gemoco stage collar at 1753', wash cement stringers/scale to 1840' Drill cement from 5254' to 5452', just above shut-off baffle. Drill cement, shut-off plug, float collar, cement, float shoe. Drill 20' of new hole to 5615' Perform formation leak off test, 14.0 ppg EMW. Drill from 5615' to 6515' 81,157 CUM:$ 901,356 ETD:$ 632,737 EFC:$ 2,558,619 MW: 8.9 VISC: 48 PV/YP: 13/15 APIWL: 6.4 DRILLING ~ 8840' Drill from 6515' to 8630'. POH for short trip. Tight from 6395' to 6207' 76,546 CUM:$ 977,902 ETD:$ 838,709 EFC:$ 2,429,193 MW: 10.0 VISC: 54 PV/YP: 22/26 APIWL: 4.2 CBU & EVALUATE LOGS @ 9752' Drill from 8630' to 9607' Connection gas to surface, boiling over bell nipple. Shut-in well. Had slow, ratty drilling break from 9545'-9550' Circulate mud around on choke. Had oil and gas cut at start of circulation. Oil streaking stayed constant. Add LCM. Flow died out. Work pipe, pipe free, no sticking. Well started breathing or flowing slowly. 78,756 CUM:$ 1,056,658 ETD:$ 933,855 EFC:$ 2,412,803 MW: 11.3 VISC: 52 PV/YP: 23/20 APIWL: 4.4 11.6 PPG AROUND, PREP TO SHORT Reciprocate pipe and circulate down flowline, mud gas cut and boiling over bell nipple near bottoms up. Drill from 9607' to 9832'. Mud gas cut to 9.0 ppg and boiling for 65 bbls at bottoms up. Weight up to 11.3 ppg. Reciprocate pipe. Static. CBU. Very little gas cut at bottoms up, no Date: 1/2/98 ARCO ALASKA INC. Page: 3 WELL SUMYLARY REPORT boiling and no foamy mud. Pump out 5 stands. Try to pull next stand, tight and swabbing. DAILY:$ 98,016 CUM:$ 1,154,674 ETD:$ 955,767 EFC:$ 2,488,907 09/27/97 (D13) TD: 9832' ( 0) SUPV:DEB DAILY:$ MW: 11.6 VISC: 51 PV/YP: 24/20 APIWL: 4.8 RUNNING 7" CASING Mud gas cut to 9.3 ppg for 45 bbls at bottoms up, foamy, but not boiling. Weight up to 11.6 ppg and circulate. CBU, no gas at bottoms up. Held pre-job safety meeting. Run 7" casing. 74,333 CUM:$ 1,229,007 ETD:$ 955,767 EFC:$ 2,563,240 09/28/97 (D14) TD: 9832' ( 0) SUPV:DEB DAILY:$ MW: 11.6 VISC: 50 PV/YP: 14/16 APIWL: 9.2 LD 5" DP Run 7" intermediate casing. Pump cement. Test BOPE. 230,204 CUM:$ 1,459,211 ETD:$ 955,767 EFC:$ 2,793,444 09/29/97 (D15) TD: 9832' ( 0) SUPV:DEB DAILY:$ MW: 12.0 VISC: 45 PV/YP: 13/14 APIWL: 8.0 CHANGE OVER TO 12.0 PPG MUD Freeze protect 9-5/8" x 7" annulus. Tag cement @ 9709' MD. 123,395 CUM:$ 1,582,606 ETD:$ 955,767 EFC:$ 2,916,839 09/30/97 (D16) TD:10490' (658) SUPV:DCL DAILY:$ MW: 12.0 VISC: 48 PV/YP: 20/25 APIWL: 4.4 DRILLING Drill out cement. Float equipment and 11' new hole to 9843'. Perform FIT, 16.1 ppg EMW. Drilling from 9843' to 10490' 96,081 CUM:$ 1,678,687 ETD:$ 1,306,382 EFC:$ 2,662,305 10/01/97 (D17) TD:10775'(285) SUPV:DCL DAILY:$ MW: 12.2 VISC: 57 PV/YP: 24/37 APIWL: 3.8 MU BHA Drilling from 10490' to 10775' Pump out of hole to shoe. Hole taking improper fill. Circ out gas cut mud. Increase mud weight to 12.2 ppg. Pump out to shoe. Pump pill. POH to 7910' Had slight flow. CBU. No gas cut mud. 92,311 CUM:$ 1,770,998 ETD:$ 1,471,616 EFC:$ 2,589,382 10/02/97 (D18) TD:10954' (179) SUPV:DCL DAILY:$ MW: 12.1 VISC: 64 PV/YP: 32/46 APIWL: 3.2 DRILLING @ 11200' Held safety meeting. Circ and balance mud. No gas at bottoms up. Drilling from 10775' to 10954' 109,645 CUM:$ 1,880,643 ETD:$ 1,575,394 EFC:$ 2,595,249 10/03/97 (D19) TD:11628'(674) SUPV:DCL DAILY:$ MW: 12.1 VISC: 65 PV/YP: 32/48 APIWL: 2.8 DRILLING Drilling from 10954' to 11628' 97,511 CUM:$ 1,978,154 ETD:$ 1,966,158 EFC:$ 2,301,996 10/04/97 (D20) TD:l1712'( 84) SUPV:DCL MW: 12.4 VISC: 68 PV/YP: 27/52 APIWL: 3.0 MIX LCM Drilling from 11628' to 11712'. Raise mud weight to 12.2 ppg. POH. Hole taking improper fill. CBU. Had gas to surface at 1/2 bottoms up. Increase weight to 12.4 ppg. Date: 1/2/98 ARCO ALASKA INC. WELL SIIMMARY REPORT Page: 4 DAILY:$ 87,606 CUM:$ 2,065,760 ETD:$ 2,014,859 EFC:$ 2,340,901 10/05/97 (D21) TD:l1712' ( 0) SUPV:DCL DAILY:$ MW: 12.4 VISC: 70 PV/YP: 32/48 APIWL: 2.8 LD BHA Pump pill. CBU. Small amount of gas at bottoms up. Lost 30% returns. Mix LCM and add gel to system. Circ and condition mud. No gas at bottoms up. 82,607 CUM:$ 2,148,367 ETD:$ 2,014,859 EFC:$ 2,423,508 10/06/97 (D22) TD:l1712' ( 0) SUPV:DCL DAILY:$ MW: 12.4 VISC: 74 PV/YP: 29/51 APIWL: 3.0 MIX LCM FOR LINER Held pre-job safety meeting. RIH with 4.5" liner. 109,747 CUM:$ 2,258,114 ETD:$ 2,014,859 EFC:$ 2,533,255 10/07/97 (D23) TD:l1712' ( 0) SUPV:DCL DAILY:$ MW: 12.3 VISC: 62 PV/YP: 29/40 APIWL: 3.2 SHAKEOUT LCM Continue to RIH with 4.5" liner on 3.5" DP to 11712'. Circ and condition mud. Lost 50% returns. Formation breathing. Pump baroseal and barofiber fine LCM. 106,171 CUM:$ 2,364,285 ETD:$ 2,014,859 EFC:$ 2,639,426 10/08/97 (D24) TD:l1712' ( 0) SUPV:DCL DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 PREP TO RUN COMPLETION RIH w/Baker GBH-22 locator seal assembly and packer. Set packer. Test casing to 3500. 138,761 CUM:$ 2,503,046 ETD:$ 2,014,859 EFC:$ 2,778,187 10/09/97 (D25) TD:l1712'( 0) SUPV:DCL DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 ND BOPE Pump nut plug pill. Held pre-job safety meeting. RIH w/4.5" completion equipment. Latch into pkr. Shear PBR. Freeze protect. 321,130 CUM:$ 2,824,176 ETD:$ 2,014,859 EFC:$ 3,099,317 10/10/97 (D26) TD:l1712' ( 0) SUPV:DCL DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 FINISH LD DP Finish run completion. ND BOPE. NU master valve. 102,035 CUM:$ 2,926,211 ETD:$ 2,014,859 EFC:$ 3,201,352 10/11/97 (D27) TD:l1712' ( 0) SUPV:DCL DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Release rig at 03:00 hrs. 10/11/97. 12,237 CUM:$ 2,938,448 ETD:$ 2,014,859 EFC:$ 3,213,589 End of WellSummary for Well:AK9077 Date: 1/2/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:lE-34 RIG:NORDIC WELL ID: 999079 TYPE: AFC: 999079 AFC EST/UL:$ 375M/ 519M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD: START COMP:10/27/97 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22805-00 10/27/97 (C1) TD: 0' PB: 0' SUPV: MC DAILY: $ 10/28/97 (C2) TD: 11646 ' PB: 11646 ' SUPV: DLW DAILY:$ 10/29/97 (C3) TD: 11712 ' PB: 11646 ' SUPV: DLW DAILY: $ 10/30/97 (C4) TD: 11712 ' PB: 11646 ' SUPV: DLW DAILY: $ RIH TO DRILL CEMENT MW: 8.5 SW Move rig from 1E-31 to 1E-34. Accept rig @ 0100 hrs. 10/27/97. ND tree. NU BOPE. Test BOPE. Safety meeting. RIH w/2-7/8" DP. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 POOH FOR PERF GUNS MW: 8.5 SW Continue to RIH w/ BHA #1 on 2-7/8" DP. Work tight spot @ 9780' Clean out 4.5" liner from 9780' to 9922' Clean out cement stringers from 9780' to 11636' Monitor well. Well flowing. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 POOH W/PERF GUNS MW: 0.0 Pump brine to kill well. Pump Flo-Pro pill and spot from 11648' to 10400' Monitor well, dead. Safety meeting. RIH with tubing conveyed perforating guns. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 RIG MOVED TO 1E-33 MW: 0.0 Continue RIH w/2-7/8" tubing conveyed perforating guns on DP to 11646' Fire guns. POOH w/ perf. guns. ND BOPE. NU tree. Test tree to 250/5000 psi. 0 CUM:$ 0 ETD:$ 0 EFC:$ 0 End of WellSummary for We11:999079 [:]Fill_liNG SEFI~JI I-- E S 19-Dec-97 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1E-34 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD n/a' MD 11,712.00' MD (if applicable) Please call me at 563-3256 if you have anY questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA, INC. KRU / 1E-34 500292280500 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 100597 MWD SURVEY JOB NUMBER: AKMM70271 KELLY BUSHING ELEV. = 113.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -113.00 0 0 N .00 E .00 121.00 121.00 8.00 0 0 N .00 E .00 462.44 462.44 349.44 0 17 S 47.54 W .08 914.59 914.56 801.56 0 47 S 29.84 W .12 1095.78 1095.70 982.70 1 49 S 10.52 W .62 .00N .00E .00 .00N .00E .00 .58S .64W -.43 4.06S 3.03W -1.64 7.99S 4.18W -1.54 1190.21 1190.02 1077.02 3 29 S 1.79 E 1.85 1284.07 1283.60 1170.60 5 5 S 7.71 E 1.78 1376.51 1375.47 1262.47 7 28 S 10.88 E 2.59 1468.61 1466.61 1353.61 9 0 S 10.50 E 1.67 1563.78 1560.27 1447.27 11 17 S 11.32 E 2.40 12.34S 4.37W -.38 19.33S 3.72W 2.38 29.30S 2.03W 7.03 42.27S .41E 13.33 58.74S 3.60E 21.40 1658.47 1652.43 1539.43 15 10 S 14.03 E 4.15 1751.28 1741.06 1628.06 19 17 S 16.40 E 4.50 1845.62 1828.96 1715.96 23 14 S 18.12 E 4.24 1939.17 1913.75 1800.75 26 43 S 19.73 E 3.79 2032.80 1996.21 1883.21 29 47 S 20.48 E 3.30 79.85S 8.42E 32.46 106.35S 15.70E 47.49 139.00S 25.89E 67.19 176.35S 38.73E 90.85 217.97S 53.98E 118.10 2125.21 2075.38 1962.38 32 16 S 20.95 E 2.70 2217.65 2152.15 2039.15 35 24 S 19.31 E 3.53 2310.28 2226.32 2113.32 38 12 S 18.22 E 3.10 2403.43 2298.08 2185.08 41 1 S 18.13 E 3.03 2496.17 2366.71 2253.71 43 29 S 19.42 E 2.82 262.51S 70.83E 147.77 310.84S 88.52E 179.39 363.37S 106.35E 212.45 419.79S 124.87E 247.35 478.82S 144.95E 284.53 2590.06 2433.41 2320.41 45 57 S 20.35 E 2.71 2682.65 2496.21 2383.21 48 37 S 20..44 E 2.90 2775.49 2556.40 2443.40 50 31 S 22.10 E 2.46 2867.47 2613.46 2500.46 52 45 S 20.58 E 2.75 2961.87 2668.97 2555.97 55 12 S 21.53 E 2.72 540.93S t67.43E 324.94 604.69S 191.14E 367.02 670.54S 216.78E 411.59 737.71'S 243.01E 457.11 808.96S 270.45E 505.04 3056.10 2720.76 2607.76 58 5 S 20.49 E 3.20 882.44S 298.66E 554.38 3150.51 2769.31 2656.31 60 0 S 19.41 E 2.24 958.53S 326.27E 603.96 3334.86 2861.15 2748.15 60 14 S 19.04 E .22 1109.46S 378.90E 700.25 3523.26 2952.14 2839.14 61 59 S 20.50 E 1.15 1264.66S 434.71E 800.87 3803.45 3084.87 2971.87 61 27 S 21.01 E .25 1495.41S 522.15E 954.73 3989.22 3176.44 3063.44 59 27 S 21.01 E 1.08 1646.26S 580.09E 1056.06 4176.69 3270.08 3157.08 60 36 S 18.64 E 1.26 1799.01S 635.13E 1155.21 4363.63 3361.56 3248.56 60 47 S 20.84 E 1.03 1952.43S 690.19E 1254.57 4546.54 3451.27 3338.27 60 28 S 19.79 E .53 2101.90S 745.53E 1353.00 4737.25 3546.29 3433.29 59 45 S 21.18 E .73 2256.79S 803.38E 1455.48 OR!81NAL SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA, iNC. KRU / tE-34 500292280500 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 100597 MWD SURVEY JOB NUMBER: AKMM70271 KELLY BUSHING ELEV. = 113.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 4922.84 3637.80 3524.80 5110.47 3726.97 3613.97 5295.71 3813.32 3700.32 5511.46 3917.06 3804.06 5772.26 4047.06 3934.06 61 9 62 5 62 20 60 10 60 1 S 23.85 E 1.46 2405.91S 865.23E S 23.78 E .50 2556.94S 931.88E S 23.41 E .22 2707.12S 997.48E S 23.75 E 1.02 2880.46S 1073.13E S 24.22 E .17 3087.02S 1165.03E 1559.99 1669.67 1778.08 1903.15 2053.85 6054122 4187.57 4074.57 6336.33 4327.60 4214.60 6616.67 4462.12 4349.12 6894.86 4588.91 4475.91 7175.03 4712.18 4599.18 60 11 60 17 62 20 63 25 64 22 S 24.74 E .17 3309.50S 1266.33E S 23.08 E .51 3533.36S 1365.58E S 21.37 E .91 3760.99S 1458.55E S 20.51 E .47 3992.23S 1547.03E S 21.17 E .40 4227.35S 1636.53E 2218.37 2381.37 2539.53 2694.54 2851.70 7457.43 4837.98 4724.98 7736.76 4972.17 4859.17 8017.09 5110.76 4997.76 8293.65 5251.24 5138.24 8574.09 5399.79 5286.79 62 43 59 50 60 53 58 2 57 58 S 21.18 E .58 4463.08S 1727.85E S 21..71 E 1.04 4691.08S 1817.39E S 21.30 E .39 4917.78S 1906.71E S 20.32 E 1.07 5140.42S 1991.36E S 22.03 E .52 5362.20S 2077.27E 3010.78 3165.80 3320.21 3468.93 3618.59 8669.44 5449.80 5336.80 8763.49 5497.61 5384.61 8857.88 5543.96 5430.96 8950.56 5588.21 5475.21 9043.85 5631.75 5518.75 58 45 60 9 61 1 61 56 62 26 S 24.77 E 2.58 5436.68S 2109.51E S 27.70 E 3.07 5509.31S 2145.32E S 30.50 E 2.75 5581.14S 2185.31E S 33.32 E 2.85 5650.26S 2228.36E S 37.59 E 4.08 5717.45S 2276.21E 3672.07 3728.39 3788.45 3850.58 3916.70 9136.46 5674.32 5561.32 9228.88 5716.87 5603.87 9321.45 5759.18 5646.18 9415.43 5800.83 5687.83 9509.44 5841.82 5728.82 62 49 62 21 63 15 64 8 64 9 S 40.38 E 2.71 5781.36S 2327.94E S 43.85 E 3.37 5842.21S 2382.95E S 47.18 E 3.34 5899.89S 2441.69E S 50.46 E 3.27 5955.34S 2505.09E S 53.18 E 2.60 6007.63S 2571.58E 3985.51 4056.50 4130.07 4207.40 4286.70 9603.44 5882.52 5769.52 64 32 9695.70 5921.10 5808.10 66 1 9773.61 5952.00 5839.00 67 15 9854.57 5982.31 5869.31 68 47 9886.45 5993.81 5880.81 68 54 S 56.09 E 2.82 6056.66S 2640.67E S 59.94 E 4.12 6101.03S 2711.75E S 64.63 E 5.75 6134.27S 2775.05E S 69.42 E 5.80 6163.54S 2844.15E S 69.59 E .62 6173.95S 2872.00E 4367.48 4448.72 4519.16 4593.91 4623.61 9918.22 6005.19 5892.19 9948.22 6015.84 5902.84 9980.76 6027.28 5914.28 10011.24 6037.76 5924.76 10041.90 6047.94 5934.94 69 6 69 18 69 31 70 14 70 57 S 69.30 E 1.06 6184.37S 2899.77E S 69.61 E 1.17 6194.21S 2926.03E S 71.36 E 5.08 6204.39S 2954.75E S 71.77 E 2.65 6213.44S 2981.90E S 71.63 E 2.39 6222.52S 3009.35E 4653.24 4681.25 4711.70 4740.32 4769.23 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASYA, INC. KRU / 1E-34 500292280500 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 100597 MWD SURVEY JOB NUMBER: AKMM70271 KELLY BUSHING ELEV. = 113.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 10074.48 6058.04 5945.04 72 55 S 71.41 E 6.08 6232.33S 3038.73E 4800.20 10106.83 6066.72 5953.72 75 56 S 71.35 E 9.31 6242.28S 3068.26E 4831.36 10138.26 6073.67 5960.67 78 30 S 71.34 E 8.18 6252.09S 3097.29E 4862.01 10169.72 6079.09 5966.09 81 39 S 72.45 E 10.57 6261.71S 3126.75E 4892.99 10200.45 6082.83 5969.83 84 20 S 71.51 E 9.30 6271.15S 3155.75E 4923.49 10230.58 6085.14 5972.14 86 50 S 71.81 E 8.36 6280.60S 3184.26E 4953.52 10263.06 6086.03 5973.03 90 1 S 72.12 E 9.84 6290.65S 3215.12E 4985.98 10293.11 6085.67 5972.67 91 19 S 71.57 E 4.67 6300.01S 3243.68E 5016.03 10325.06 6084.81 5971.81 91 47 S 71.10 E 2.08 6310.23S 3273.93E 5047.96 10357.13 6083.65 5970.65 92 20 S 71.38 E 1.92 6320.54S 3304.28E 5080.01 10388.42 6082.73 5969.73 91 3 S 72.11 E 4.74 6330.34S 3333.98E 5111.28 10421.15 6082.19 5969.19 90 49 S 71.66 E 1.53 6340.51S 3365.08E 5144.01 10452.48 6081.77 5968.77 90 42 S 72.16 E 1.64 6350.24S 3394.86E 5175.33 10483.72 6081.41 5968.41 90 35 S 72.80 E 2.08 6359.64S 3424.65E 5206.57 10516.21 6081.20 5968.20 90 10 S 71.37 E 4.58 6369.64S 3455.56E 5239.06 10547.86 6081.03 5968.03 90 25 S 71.39 E .79 6379.74S 3485.55E 5270.70 10579.32 6080.66 5967.66 90 55 S 71.99 E 2.46 6389.62S 3515.42E 5302.16 10611.66 6079.83 5966.83 92 0 S 72.57 E 3.82 6399.46S 3546.21E 5334.49 10642.91 6078.70 5965.70 92 7 S 73.95 E 4.43 6408.46S 3576.12E 5365.71 10674.16 6077.47 5964.47 92 22 S 73.78 E .94 6417.14S 3606.11E 5396.92 10705.76 6076.18 5963.18 92 20 S 73.31 E 1.49 6426.08S 3636.39E 5428.48 10739.05 6074.82 5961.82 92 20 S 72.17 E 3.42 6435.95S 3668.15E 5461.74 10771.06 6073.95 5960.95 90 46 S 72.17 E 4.90 6445.74S 3698.61E 5493.74 10803.34 6073.61 5960.61 90 25 S 72.-06 E 1.11 6455.66S 3729.33E 5526.02 10834.39 6073.34 5960.34 90 33 S 72.39 E 1.13 6465.14S 3758.90E 5557.06 10865.24 6072.93 5959.93 90 59 S 72.85 E 2.06 6474.35S 3788.34E 5587.91 10897.51 6072.47 5959.47 90 39 S 72.37 E 1.82 6483.99S 3819.13E 5620.18 10928.69 6072.42 5959.42 89 30 S 72.69 E 3.80 6493.35S 3848.87E 5651.36 10960.41 6072.80 5959.80 89 8 S 72.32 E 1.65 6502.89S 3879.12E 5683.07 10992.06 6073.28 5960.28 89 5 S 72.40 E .29 6512.48S 3909.28E 5714.72 11024.21 6073.97 5960.97 88 27 S 72.50 E 2.01 6522.17S 3939.92E 5746.86 11055.69 6074.73 5961.73 88 46 S 72.05 E 1.73 6531.75S 3969.90E 5778.33 11087.62 6075.32 5962.32 89 6 S 72.17 E 1.13 6541.56S 4000.28E 5810.25 11119.45 6075.07 5962.07 91 47 S 70.85 E 9.39 6551.65S 4030.46E 5842.08 11151.13 6073.96 5960.96 92 13 S 70.65 E 1.50 6562.09S 4060.35E 5873.73 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA, INC. KRU / 1E-34 500292280500 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 100597 MWD SURVEY JOB NUMBER: AKMM70271 KELLY BUSHING ELEV. = 113.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 11180.52 6072.93 5959.93 91 47 S 71.32 E 2.71 6571.66S 4088.12E 5903.09 11212.07 6072.17 5959.17 90 59 S 71.38 E 2.54 6581.75S 4118.00E 5934.63 11242.64 6071.67 5958.67 90 53 S 71.26 E .51 6591.54S 4146.96E 5965.19 11275.18 6071.29 5958.29 90 26 S 70.82 E 1.93 6602.11S 4177.73E 5997.72 11306.99 6071.29 5958.29 89 32 S 70.84 E 2.83 6612.55S 4207.78E 6029.52 11338.62 6071.81 5958.81 88 34 S 71.15 E 3.19 6622.85S 4237.68E 6061.14 11370.75 6072.70 5959.70 88 16 S 71.03 E 1.03 6633.26S 4268.06E 6093.25 11402.59 6073.52 5960.52 88 45 S 71.13 E 1.57 6643.58S 4298.17E 6125.08 11434.02 6074.33 5961.33 88 18 S 70.65 E 2.11 6653.87S 4327.86E 6156.49 11466.02 6075.25 5962.25 88 24 S 70.88 E .78 6664.40S 4358.06E 6188.46 11497.79 6076.03 5963.03 88 46 S 71.30 E 1.76 6674.70S 4388.11E 6220.22 11528.71 6076.84 5963.84 88 14 S 72.00 E 2.84 6684.43S 4417.44E 6251.13 11560.98 6078.24 5965.24 86 47 S 72.57 E 4.83 6694.24S 4448.15E 6283.36 11591.99 6080.31 5967.31 85 33 S 72.67 E 3.98 6703.48S 4477.68E 6314.30 11623.73 6082.61 5969.61 86 6 S 72.66 E 1.73 6712.91S 4507.90E 6345.96 11655.33 6084.42 5971.42 87 20 S 72.70 E 3.89 6722.30S 4538.01E 6377.50 11712.00 6087.05 5974.05 87 20 S 72.70 E .00 6739.14S 4592.06E 6434.11 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 8154.94 FEET AT SOUTH 34 DEG. 16 MIN. EAST AT MD = 11712 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 107.82 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 11,712.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 ARCO ALASKA, INC. KRU / 1E-34 500292280500 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 100597 JOB NUMBER: AKMM70271 KELLY BUSHING ELEV. = 113.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -113.00 1000.00 999.97 886.97 2000.00 1967.59 1854.59 3000.00 2690.40 2577.40 4000.00 3181.92 3068.92 .00 N .00 E .00 5.08 S 3.62 W .03 .03 202.94 S 48.41 E 32.41 32.37 838.33 S 281.91 E 309.60 277.19 1654.93 S 583.41 E 818.08 508.48 5000.00 3675.02 3562.02 6000.00 4160.62 4047.62 7000.00 4635.95 4522.95 8000.00 5102.45 4989.45 9000.00 5611.38 5498.38 2467.73 S 892.56 E 3266.77 S 1246.64 E 4080.30 S 1579.97 E 4903.87 S 1901.29 E 5686.27 S 2253.07 E 1324.98 506.90 1839.38 514.40 2364.05 524.67 2897.55 533.51 3388.62 491.07 10000.00 6033.96 5920.96 11000.00 6073.41 5960.41 11712.00 6087.05 5974.05 6210.13 S 2971.85 E 6514.88 S 3916.84 E 6739.14 S 4592.06 E 3966.04 577.42 4926.59 960.55 5624 . 95 698 . 36 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KRU / 1E-34 500292280500 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 100597 JOB NUMBER: AKMM70271 KELLY BUSHING ELEV. = 113.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -113.00 113.00 113.00 .00 213.00 213.00 100.00 313.00 313.00 200.00 413.00 413.00 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .00 N .00 E .00 .00 .07 S .08 W .00 .00 .41 S .45 W .00 .00 513.00 513.00 400.00 613.00 613.00 500.00 713.01 713.00 600.00 813.02 813.00 700.00 913.03 913.00 800.00 .76 S .83 W .00 .00 1.10 S 1.20 W .00 .00 1.65 S 1.65 W .01 .00 2.84 S 2.34 W .02 .01 4.04 S 3.02 W .03 .01 1013.04 1013.00 900.00 1113.09 1113.00 1000.00 1213.24 1213.00 1100.00 1313.58 1313.00 1200.00 1414.36 1413.00 1300.00 5.42 S 3.70 W .04 .01 8.53 S 4.28 W .09 .05 13.74 S 4.32 W .24 .15 21.93 S 3.37 W .58 .35 34.14 S 1.10 W 1.36 .78 1515.60 1513.00 1400.00 1617.77 1613.00 1500.00 1721.67 1713.00 1600.00 1828.31 1813.00 1700.00 1938.34 1913.00 1800.00 49.62 S 1.78 70.07 S 6.06 97.28 S 13.08 132.63 S 23.83 176.01 S 38.61 E 2.60 1.24 E 4.77 2.17 E 8.67 3.90 E 15.31 6.64 E 25.34 10.03 2052.15 2013.00 1900.00 2170.10 2113.00 2000.00 2293.41 2213.00 2100.00 2423.30 2313.00 2200.00 2560.70 2413.00 2300.00 226.97 S 57.34 285.45 S 79.41 353.54 S 103.09 432.25 S 128.99 521.15 S 160.09 E 39.15 13.81 E 57.10 17.96 E 80.41 23.30 E 110.30 29.90 E 147.70 37.40 2708.05 2513.00 2400.00 2866.72 2613.00 2500.00 3041.52 2713.00 2600.00 3237.90 2813.00 2700.00 3439.91 2913.00 2800.00 622.56 S 197.79 737.15 S 242.81 870.88 S 294.32 1029.91 S 351.42 1195.74 S 408.94 E 195.05 47.35 E 253.72 58.67 E 328.52 74.80 E 424.90 96.38 E 526.91 102.01 3652.85 3013.00 2900.00 3862.33 3113.00 3000.00 4061.16 3213.00 3100.00 4264.17 3313.00 3200.00 1371.83 S 474.77 1543.69 S 540.69 1704.10 S 602.30 1871.21 S 659.56 E 639.85 112.93 E 749.33 109.48 E 848.16 98.83 E 951.17 103.01 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KRU / 1E-34 500292280500 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 100597 JOB NUMBER: AKMM70271 KELLY BUSHING ELEV. = 113.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES'FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4468.90 3413.00 3300.00 2038.34 S 722.66 E 1055.90 104.73 4671.15 3513.00 3400.00 2203.54 S 782.75 E 1158.15 102.25 4871.75 3613.00 3500.00 2364.94 S 847.44 E 1258.75 100.60 5080.63 3713.00 3600.00 2532.81 S 921.25 E 1367.63 108.88 5295.02 3813.00 3700.00 2706.56 S 99'7.24 E 1482.02 114.40 5503.31 3913.00 3800.00 2873.98 S 1070.28 E 1590.31 108.28 5704.07 4013.00 3900.00 3033.15 S 1140.80 E 1691.07 100.77 5904.26 4113.00 4000.00 3191.30 S 1211.96 E 1791.26 100.19 6105.37 4213.00 4100.00 3349.80 S t284.90 E 1892.37 101.11 6306.86 4313.00 4200.00 3509.82 S 1355.54 E 1993.86 101.50 6510.82 4413.00 4300.00 3673.67 S 1424.38 E 2097.82 103.96 6726.31 4513.00 4400.00 3851.42 S 1493.93 E 2213.31 115.48 6948.70 4613.00 4500.00 4037.33 S 1563.90 E 2335.70 122.40 7176.92 4713.00 4600.00 4228.94 S 1637.15 E 2463.92 128.21 7402.93 4813.00 4700.00 4417.92 S 1710.35 E 2589.93 126.02 7616.71 4913.00 4800.00 4593.96 S 1778.95 E 2703.71 113.78 7818.05 5013.00 4900.00 4756.39 S 1843.39 E 2805.05 101.34 8021.69 5113.00 5000.00 4921.52 S 1908.17 E 2908.69 103.64 8220.62 5213.00 5100.00 5082.13 S 1969.62 E 3007.62 98.94 8410.36 5313.00 5200.00 5233.29 S 2025.75 E 3097.36 89.74 8599.01 5413.00 5300.00 5381.79 S 2085.20 E 3186.01 88.65 8794.56 5513.00 5400.00 5533.10 S 2158.07 E 3281.56 95.55 9003.48 5613.00 5500.00 5688.76 S 2254.88 E 3390.48 108.92 9220.53 5713.00 5600.00 5836.86 S 2377.84 E 3507.53 117.05 9443.34 5813.00 5700.00 5971.33 S 2524.46 E 3630.34 122.81 9675.91 5913.00 5800.00 6091.85 S 2696.19 E 3762.91 132.57 9940.18 6013.00 5900.00 6191.59 S 2918.99 E 3927.18 164.27 11712.00 6087.05 5974.05 6739.13 S 4592.06 E 5624.95 1697.77 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS TONY KNOWLE$, GOVEF~NOFI ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 10, 1997 Michael Zanghi, Drilling Superintendent ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1E-34 ARCO Alaska, Inc. Permit No: 97-166 Sur. Loc.: 634'FSL, 633'FEL, Sec. 16. T11N, R10E, UM Btmhole Loc: 955'FNL, 863'FEL, Sec. 27. TI 1N, R10E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. This approval includes annular disposal of drilling wastes and is contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT) - cementing records, FIT data. and any CQLs are to be submitted to the Commission prior to the start of disposal operations. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 65, David Chairman BY ORDER OF THE COMMISSION dlffenclosures cc: Department of Fish & Game. Habitat Section w/o encl. Department of Envinornment Conservation w/o encl. STATE OF ALASKA A,._ ...,KA OIL AND GAS CONSERVATION OOMM,,..o,ON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill r-I ~ i b Type of Well Exploratory r'l Stratigraphic Test BI Development Oil X Re'Enh7 D Deepen r'lI Service I~ Development Gas ri Single Zone X Multiple Zone r-! 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 72' feet Kuparuk River Field ~. ' Address 6. Properly Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25660, ALK 470 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 634' FSL, 633' FEL, Sec. 16, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 308' FNL, 2404' FWL, Sec. 27, T11N, R10E, UM 1 E-34 #U-63061 0 At total depth 9. Approximate spud date Amount 955' FNL, 863' FEL, Sec. 27, T11N, R10E, UM 9/1 0/97 $200,000 12. Distance to nearest 13, Distance to nearest well 14. Number of acres in property 15, Pmpesed depth (MD and TVD) property line 1 E-05 12200' MD 308' @ TD feet 19' @ 300' feet 2560 6109' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035(e)(2)) Kickoff depth 11 00' feet Maximum hole angle 61/91 Maximurnsurface 3560 pslg At total depth (3'VD) 3900 psig 18. Casing program Setting Depth size Specifications Top Bottom Quanlit¥ of cement Hole Casing Weight Grade Coupling Length MD TVD MD 'I-VD (include stage data) 24' 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625' 40.0# L-80 BTC-ERV~ 5532' 41' 41' 5573' 3954' 1680 Sx Arcticset III & 530 Sx Clasm G 8.5' 7' 26.0# L-80 BTCMO£ 9855' 41' 41' 9896' 601 3' 70SxClassG Top 500' above shoe 6.125' 4.5' 12.6# L-80 NSCT 2500' 9700' 5930' 12200' 6109' 300SxClass G 1 9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: t rume;SvUreertdical ff::l Plugs (measured) 0 RIG IN A L Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Length Size Cemented MeasuracLdel~,hj~,~ L ~.~ r~ ~ ~,., i~ ~ T i ~ ~ depths, I Conductor Surface Intermediate Production $ i:'O-; 2 Liner Perforation depth: measured ~_a-s.~ .0il .& Gas C0rls, true vertical'Anchqraga 20. Attachments Filing fee X Property plat [-] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot r=] Refraction analysis ~-] Seabed report r-] 20 AAC 25.050 requirements X 21. I hereby certify that.the fo.~going is true and correct to the best of my knowledge Signedj/~.,.~ Title Drilling Superintendent Date~f~' ~ For questions, please call Denise Petrash '1' Commission Use Only PermiLNumber APl number I Approval date ~r! !ui~r~d~ .~] I See cover letter for ?2-/~ / 5 0- ~ 2..- ~ -" ~ 2_ '~::;~(:::~ 5 other requirements Conditions of approval Samples required [-! Yes J~ No Mud g q Yes J~ No Hydrogen sulfide measures ~I~ Yes [~ No Directional survey required J~ Yes ~--] No Required working pressure for aOPE D 2M r-] aM ~i~ 5M D 1OM ~] 15M Other:Original Signeo David W. J0hr],~t0r~ by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 ~b~nit n t-d~licate I GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 1 E-34 1. Move in and rig up Parker #245. 2. Install diverter system. 3. Drill 12.25" hole to 9-5/8" surface casing point (5,573')according to directional plan. 4. Run and cement 9-5/8" casing, using stage collar placed at least 200' below the base of the permafrost, and light weight lead cement. 5. Install and test BOPE to 5000~si. Test casing to 2000 psi. 6. Drill out cement and 10' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. 7. Drill 8.5" hole to intermediate TD (9,896') according to directional plan. 8. Run and cement 7" intermediate casing string. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. 9. Test breaks in BOPE to 5000 psi. Test casing to 3500 psi. 10. Drill out cement and 10' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. 1 1. Drill horizontal section to total depth (12,200') according to directional plan, running LWD logging equipment as needed. 12. Run and cement 4-1/2" NSCT liner with Baker liner-top hanger and integral PBR. Set +_200' inside intermediate casing shoe to provide appropriate liner lap. 13. Run Baker 'FAB-I' packer with seal assembly. Sting into liner PBR and set packer. Pressure test liner to 3500 psi. 14. Run completion assembly. Latch PBR and seal assembly into FAB-1 packer. Pressure test tubing and annulus. 1 5. ND BOPE and install production tree. 1 6. Shut in and secure well. 1 7. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. Note: Perforating strategy is still being decided. This well may be tubing-conveyed perforated with Parker 245 or Nordic 2. Note: As a dedicated producer, cased hole cement bond logs (SLT-J or CBT) will not be run unless the cement job requires evaluation. DRILLING FLUID PROGRAM Well KRU 1E-34 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +10% Drill out to 7" interm, casing 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes- Drill out to TD 12.5 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 2,341 psi could be reached. Maximum anticipated surface pressure is calculated using a intermediate casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3,560 psi could be reached. Therefore, ARCO Alaska, Inc. will do a one-time test of the BOP equipment to 5000 psi, retesting only broken flanges or after 7 day limit. The nearest existing well to 1E-34 is 1E-05. As designed, the minimum distance between the two wells would be 19.0' @ 300' MD. Drillin~l Area Risks: Risks in the 1E-34 drilling area include lost circulation and high pressures in the Kuparuk formation. Both are addressed by setting intermediate casing above the Kuparuk. Careful analysis of pressure data from offset wells shows that a mud weight of 12.5 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" and 7" casing shoes will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS WELL KRU 1E-34 Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. (Note that cement rinseate will not be injected down the dedicated dis.oosal well but will be recycled or held for an open annulus.) The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1E-34 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 1E-34 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoes will be set +_200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 3967 psi The pressure is very conservative as frictional losses while pumping are not accounted for. The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 9.625 40 L-80 3 BTC 3090 2627 5750 4 8 8 8 7.000 26 L-80 3 BTC-M 5410 4599 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 (g) (1). ,~ ~._~ ~ ARCO Alaska, Inc. Pad 1E 34 slot #34 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE by Baker Hughes INTEQ REPORT Your ref = 34 Version #9 Our ref = prop2153 License = Date printed = 29-Aug-97 Date created = 31-Mar-97 Last revised = 29-Aug-9? Field is centred on n?0 16 18.576,w150 5 56.536 Structure is centred on n?0 18 1.316,w149 35 26.769 Slot location is nT0 18 ?.551,w149 35 45,225 Slot Grid coordinates are N 5960220.???, E 549891.008 Slot local coordinates are 634.00 N 633.00 W Projection type= alaska - Zone 4, Spheroid= Clarke - 1866 Reference North is True North Report is 1/mired to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PMSS <121 - 10445'>,,B(32),Pad 1E D(35) Version #1, ,D(35) ,Pad 1E GMS <0-7420'>,,24 GMS <0-7512'>,,12 ~MS <0-7750'>,,13 GMS <0-7190'>,,14 ~MS <0-8%35'>,,15 GMS <0-7885'>,,17 GMS <0-8150 >,,18 ~MS <0-?898 >,,19 GMS <0-8650 >,,20 ~MS <0-7%20 >,,21 ~ <0-9%80 >,,22 ,Pad 1E ,Pad 1E ,Pad 1E .Pad 1E ,Pad 1E .Pad 1E .Pad 1E .Pad 1E .Pad 1E .Pad 1E .Pad 1E G~MS <0-8350 >,,23,Pad 1E GMS <0-7%67 >,,25,Pad 1E GMS <0-6800 >,,27,Pad 1E G~S <0-7665 >,,28,Pad 1E TOTCO Survey,,WS-2,Pad 1E GMS <O-?310'>,,1A,Pad 1E MSS <2819-7345'>,,1,Pad 1E GMS <0-8440'>,,2,Pad 1E G~S <O-8905'>,,3,Pad 1E GMS <0-9150'>,,%,Pad 1E ~MS <0-?195'>,,5,Pad 1E GMS <O-9837~>,,6,Pad 1E Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 5-Aug-97 %79.9 220.0 220.0 6-May-9? 596.0 %20.0 8558.2 %-Aug-92 190.7 2625.0 2625.0 %-Aug-92 244.3 6%0.0 1100.0 %-Aug-92 183.9 900.0 900.0 4-Aug-92 180.0 1400.0 1400.0 4-Aug-92 228.0 1825.0 1825.0 4-Aug-92 468.6 20.0 12140.0 4-Aug-92 400.5 1675.0 1675.0 4-Aug-92 430.2 1550.0 10052.9 4-Aug-92 465.8 20.0 520.0 4-Aug-92 292.? 2396.2 2396.2 4-Aug-92 533.0 20.0 11200.0 %-Aug-92 572.4 160.0 700.0 4-Aug-92 214.9 2700.0 2700.0 4-Aug-92 341.5 3025.0 3025.0 4-Aug-92 819.5 820.0 2125.0 4-Aug-92 1256.1 5100.0 5100.0 4-Aug-92 309.7 3340.0 3340.0 %-Aug-92 317.3 3220.0 3220.0 4-Au~-92 234.5 3520.0 3520.0 4-Aug-92 217.4 660.0 10860.0 %-Aug-92 99.6 500.0 500.0 4-Aug-92 19.0 300.0 300.0 4-Aug-92 139.0 20.0 1125.0 GMS ¢0-9310 >,,7,, GMS ¢0-7590 >,,8,Pad ~E GMS ~0-7000 >,,9,Pad 1E GMS ~0-7811 >,,10,Pad 1E GMS <0-8754 >,,11,Pad 1E G~MS ~0-6835 >,,29,Pad 1E MSS ¢2370-3605f>,,26,Pad 1E GMS <0-8017~>,,26A, Pad 1E GMS (O-7715~>,,16,Pad 1E GMS <0-7310f>,,30,Pad 1E PMSS ¢8798-10023'>,,31,Pad 1E PMSS ~121 - 9130~>,,31,Pad 1E 33 Version #6,,33,Pad 1E PMSS <121-??????>,,33,Pad 1E 4 -Aug- 92 4-Aug-92 4 -Aug- 92 4 -Aug- 92 4 -Aug- 92 25-Jun-97 4-Aug- 92 25-Jun- 97 9 -Jul- 97 9 -Jul- 9? 19-Aug- 97 11 -Aug- 97 14 -Aug- 9 ? 29 -Aug- 97 258 371 55? 438 339 534 638 621 353 519 197 197 650 650 36 940.0 20.0 1040.0 140.0 2850.0 3480.0 3500.0 1375.0 2200.0 660.0 660.0 20.0 120.0 520.0 940.0 1125.0 1040.0 140.0 2850.0 3480.0 3500.0 1375.0 2200.0 8800.0 8380.0 11800.0 11940.0 C,~o~d ~ ~.~h For: D PETRASH Plot Reference is 34- Version ~§. ***NOTE*** SEE PAGE 2 FOR HORIZONTAL SECTION 5O0 5OO lOOO 150O 2000 2500 5000 55oo ARCO Alaska, Inc. I~ 40aa I 4500 RKB ELEVATION: 1 13' Structure : Pad 1E Well : 54 Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) -> 800 0 800 1600 2400 5200 4000 4800 5600 I [ I [ II II II I I II II 800 SURFACE LOCATION: KOP 634' FSL, 65Y FEL <~ SEC. 16, T11N, RIOE 153.98 AZIMUTH 6924' (TO TARGET) ***Plane of Proposal*** KOP TVD=llO0 TMD=IIO0 DEP=O legin Turn to Targets '~EOC C4- TARGET LOCATION: ~ .308' FNL, 2404' FWL ~ I SEC. 27, T1 1N, RIOE '~ TARG ET ~ TVD=6083 %Top West Sak Sands TDMEDp=~09(~749 ~ SOUTH 5588 ~ EAST 2405 t;uo ~ 9 5/8 Casing C80~?mponion SS C40\ x Begin Angle Build~, ^$~v - - C3b-~. .,eo~ ~,o c3oX. aa~ o~ 800 1600 2400 0 3200 --I- 4000 1 V 48O0 5600 6400 3-OOBEGIN TURN TO TARGETS TVD=1235 TMD=1253 DEP=4 DLS: 3.00 deg per 100 ft ' ka8.84 ~,. :~: 2 lqq7 44.84 " ...... ~u~; ° I ID LOCATION: 50 84 '" j~" ~ ' FEL ¢ 'i' ~ ...... ' l ~ FNL 863 141 DEP 981 ~¢l& SEC 27 TllN RIOE '[ EOC WD=2777 TMD=5 W SAK SNDS WD=5431 TMD=4493 DEP=2160 TANGENT ANGLE ~ ~ ~r ~ C9~® 6 1.05 DEG cgs ~ST. 9 5/8" CSG PT ~D=3954 7MD=5573 DEP=3102 C80~9 TMD=6017 DEP=3489 BEGIN ANGLE BUILD ~D=5389 TMD=8537 DEP=568~O 60.97 5500 61'0~1.95 63.56 65 84 68.49 DEG - -. ~ A~,~ ~u,d 6~00 I I I I I I I I I I I I 500 0 500 1000 1500 2000 2500 3000 5500 4000 4500 5000 5500 6000 6500 7000 7500 Verficel Section (feet) -> Azimuth 153.98 wHh reference 0.00 N, 0.00 E from slot ~34 Creoted by finch For: D PETRASH Dote plotted : 2g-Aug-§7 Plot Reference is 54 Version ~9. Coordinates are in feet reference slot ~34. True Vertical Depths~ce RKB (Porker ~NT~ 153.98 AZIMUTH ***Plane of Proposal*** ARCO Alaska, Inc Structure : Pad 1E Well : 54 Field : Kuparuk River Unit Location : North Slope, Alaska 2400 2600 2800 5000 ~Bese HRZ 7 Casing~ Marker "¥ "'----~RGET - C4 C4 TARGET LOCATION: I ~cjle Build 308' FNL, 2404 FWL I ~ [ SEC. 27, TllN, RIOE I TARGET - TD 1E-34 Toe Rvsd 29-Au9-97 B/ HRZ TVD=5939 TMD=9715 DEP=6670 K1 MARKER TVD=6010 TMD=9888 DEP=6796 7" CSG PT TVB=6013 TMD=9896 DEP=6801 TARGET-C4 TVD=6083 TMD=10079 DEP=6924 END ANGLE BUILD TVD=6133 TMD=10358 OEP=Y115 C3 TVD=6127 TMO=10805 DEP=7423 TD TVD=6109 TMD=lfifi00 DEP=8389 East '(feet) -> 5200 3400 5600 3800 4000 4200 4400 4600 4-800 5000 5200 TD LOCATION: 955' FNL, 863' FEL SEC. 27, T11N, RIOE 5800 6000 6200 6400 6600 6800 7000 5700 5800 5900- _ 6000- 61 O0 6200 C4 TARGET ANGLE 68.49 DEG HORIZONTAL SEC. ANGLE 90.74 DEG i i i i i i i i i i i J i i i i i i i i i i i ~ ~ i~ i J i i i i ~ i i i i i 6600 6700 6800 6900 7000 71 O0 7200 7300 7400 7500 7600 7700 7800 7900 8000 81 O0 8200 8300 8400 8500 Verticol Section (feet) -> Azimuth 153.98 with reference 0.00 N, 0.00 E from slot #54 Cr~ot~d ~ n~h For: D PETRASH Dote p~otted : 2§-Aug-g7 PI~t Reference is 3'~ Version ~g. Coordinates ore in feet reference slot True Vertical Depths are reference R~B (Parker 120 160 200 240 280 320 360 400 440 480 I 520 560 6OO 640 ARCO Alaska, Inc. Structure : Pad 1E Well : 34 Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) -> 80 40 0 40 80 120 160 200 240 280 320 560 400 440 480 520 80 000 0 ~1200 /1800 ~ 1 300 ~ ~ 400 4O ~ ~00 ~ 1600 t 1600 80 ~, /1570 /1700 5000 \\,\ ~)~100/1600 ~\ 1800 /1500 11 O0 \\~ / 1400 ~ 1900 ~_1100 , 1300..~ y ' ~soo ~oo ~F-~ 200 1700 .... 1100 1300 1400 1500 ~1600 1100 ', 4800 · · ~'~ 110~ ~, 4700 210~' ~ 2200 01 O0 ~ 4600 ~ 2300 500 ~ 4500 oo ~1100 ~1700 X,,, 4400 ~ k "~ 2500 1~oo ~ ~7oo k 150~ ~"-..,.~ ~000 ",, i i I I I i~ ~10 i I I I i i i i I I i i I i 80 40 0 80 120 160 200 240 280 320 ~60 400 440 480 520 E~sf (feel) -> 4300 i 80 40 40 80 120 160 2OO 240 28O 320 360 4OO 440 480 52O 5~0 600 640 0 7 , 6 5 13 5/8" 5000 P,.,, BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE 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 CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. I I1 1. 16"- 2000 PSI STARTING HEAD 2. 11"- 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"-5000 PSI VARIABLE PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. TEST ANNULAR PREVENTOR TO 3000 PSI ONLY. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TESTTO 250 PSI AND 5000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSi LOWAND 5000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST Bo~-rOM RAMS TO 250 PSI AND 5000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEKAND FUNCTIONALLY OPERATE BOPE DAILY. NOTE: PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE ALL FLANGES AND SEALS BROKEN BETWEEN THIS TEST AND THE PRIOR ONE WILL BE TESTED TO 250 PSI LOW AND 5000 PSI HIGH KUPARUK RIVER Ult. £ 20" DIVERTER SCHEMATIC 6 4 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR. 2. SLIP. ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 11/1 O/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11540 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) Well Job # Log Description Date BL RF Sepia LIS Colored Tape Print 1E-34 ~"7,-'/GL .~7~/ 97470 ADN4 971006 I I 1 · 1 E-34 ~ 97470 ADN IMAGES 971006 1 1 E-34~ 97470 ELAN ELEMENTAL ANALYSIS 971 006 1 SIGNED' ~~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. t, OV '1 5 199/' Gas Lk~is. 0 F:t I I--I-- I I~1G WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs February 11, 1997 1E-34, AK-MM-70271 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin. Sperry-Sun Drilling Services, 5631 Silverado Way,//G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22805-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company n I::t I i_l_l N G S ~ I:l~J I C ~:: S VCELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1E-34, AK-MM-70271 February 11, 1997 The technical dam listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1E-34: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22805-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22805-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~'//¢~,,)/~_---) ~ INIT CLASS ~ ADMINISTRATION WELL NAME .,~_~,, .,/ GEOL AREA ~;~,"~ PROGRAM: exp [] dev~redrll [] serv [] wellbore seg ri ann. disposal para UNIT# ////,~,,,~ ON/OFF SHORE ~ 1. Permit fee attached. 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... N N N N N N N N N N N N ENGINEERING APPR 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. Ifa re-drill, has a 10-403 for abandonment been approved.. 22. Adequate wellbore separation proposed ............. (~ N 23. If diverter required, does it meet regulations .......... N 24. Drilling fluid program schematic & equip list adequate ..... N(~' 25. BOPEs, do they meet regulation ................ ~ N 26. BOPE press rating appropriate; test to ~-¢rO'Z2 psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... N ' 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. j Y N 34. Contact name/phone for weeklypro.qress reports ..... ~ Y N [exploratory only] REMARKS GEOLOGY: RPC~ ENGINEERING: COMMISSION: . JDH ~ RNC~ Comments/Instructions: HOW/lit - A:\FORMS\cheklist rev 07/97 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 unde~ APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Thu Feb 05 16:08:11 1998 Reel Header Service name ............. LISTPE Date ..................... 98/02/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Technical Services ' Tape Header Service name ............. LISTPE Date ..................... 98/02/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Scientific Library. Scientific Physical EOF Con~nent Record TAPE HEADER KUPAJ~UK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 AK-MM-70271 B. HENNINGSE D. BREEDEN 1E-34 500292280500 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 05-FEB-98 MWD RUN 4 MWD RUN 5 AK-MM-70271 AK-MM-70271 P. SMITH K. FERGUSON D. BREEDEN D. LUTRICK JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: MWD RUN 5 AK-MM-70271 K. FERGUSON D. LUTRICK 16 lin 10E 634 633 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD .00 112.90 71.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 12 . 250 9 . 625 5575.0 3RD STRING 8.500 7.000 9821.0 PRODUCTION STRING 6.125 11712.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 4 AND 5 ARE DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) IN THE HORIZONTAL HOLE. 5. MWD DATA FROM 10606'MD, 6080'TVD TO 10868'MD, 6073'TVD WAS ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS PERFORMED WHILE TRIPPING OUT OF THE HOLE FOLLOWING MWD RUN 5. 6. RESISTIVITY VALUES FROM MWD RUN 4 HAVE BEEN REPROCESSED OWING TO ORIGINALLY INCORRECT CALIBRATION VALUES. GAMMA RAY VALUES FROM RUNS 3 THROUGH 5 HAVE BEEN CORRECTED TO API STANDARDS. 7. DEPTH SHIFT/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DENISE PETRASH OF ARCO ALASKA, INC. ON 10/20/97. 8. MWD RUNS 1-5 REPRESENT WELL 1E-34 WITH API#: 50-029-22805-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF l1712'MD, 6087'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. CURVES WITH A "-M" SUFFIX INDICATE MAD PASS DATA. GAMMA RAY CORRECTIONS: 6-3/4" TOOL (MWD RUN 3) = 1.14 4-3/4" TOOL (MWD RUN 4) = 1.05 MWD RUN 5: NO CORRECTION NEEDED. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 5527.0 11669.5 ROP 5595.0 11712.5 FET 9812.5 11676.5 RPD 9812.5 11676.5 RPM 9812.5 11676.5 RPS 9812.5 11676.5 RPX 9812.5 11676.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 3 5595.0 9832.0 4 9832.0 10775.0 5 10775,0 11712.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 RPX MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPM RPD FET GR MWD MWD MWD MWD OHMM 4 1 68 OHMM 4 1 68 HOUR 4 1 68 AP1 4 1 68 16 20 24 28 Name DEPT ROP RPX RPS RPM RPD FET GR Min 5527 4 7712 2 3706 1 4043 0 1738 2 1979 0 3514 29 9095 Max Mean Nsam 11712.5 8619.75 12372 947.461 162.661 12236 2000 50.3847 3729 2000 51.3876 3729 2000 57.5796 3729 2000 74.3562 3729 95.2101 3.47545 3729 480.776 113.746 12286 First Reading 5527 5595 9812.5 9812.5 9812.5 9812.5 9812.5 5527 Last Reading 11712.5 11712.5 11676.5 11676.5 11676.5 11676.5 11676.5 11669.5 First Reading For Entire File .......... 5527 Last Reading For Entire File ........... 11712.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH FET 10606.0 RPD 10606.0 RPM 10606.0 RPS 10606.0 RPX 10606.0 all MAD runs merged using earliest STOP DEPTH 10834.5 10834.5 10834.5 10834.5 10834.5 GR RAT $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: 10612.5 10834.0 10641.5 10868.0 MAD RUN NO. MAD PASS NO. 5 MERGED MAD PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE TOP 10606.0 Name Service Order Units Size Nsam Rep Code Offset Channel DE?T FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 RPX MAD OHMM 4 1 68 8 3 R?S MAD OHMM 4 1 68 12 4 RPM MAD OHMM 4 1 68 16 5 RPD MAD OHMM 4 1 68 20 6 FET MAD HOUR 4 1 68 24 7 GR MAD API 4 1 68 28 8 MERGE BASE 10868.0 Name Min Max Mean DEPT 10606 10868 10737 RAT 253.784 598.416 367.147 RPX 35.7621 85.8623 54.5233 RPS 45.7456 80.0106 58.7156 RPM 51.0666 86.4099 69.72 RPD 73.2161 129.646 97.2928 FET 41.4477 83.5735 70.7837 GR 32.1948 128.037 58.6459 Nsam 525 454 458 458 458 458 458 444 First Reading 10606 10641.5 10606 10606 10606 10606 10606 10612.5 Last Reading 10868 10868 10834.5 10834.5 10834.5 10834.5 10834.5 10834 First Reading For Entire File .......... 10606 Last Reading For Entire File ........... 10868 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 5527.0 ROP 5595.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: II 2.17F DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9790.0 9832.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL G~ RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 26-SEP-97 ISC 5.06 CIM 5.46/SP4 5.03/DEP MEMORY 9832.0 5595.0 9832.0 58.1 67.3 TOOL NUMBER P0845CG6 8.500 8.5 LSND 167.30 47.0 9.0 600 9.5 I~UD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 · 000 ,000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 API 4 1 68 8 3 52.2 First Name Min Max Mean Nsam Reading DEPT 5527 9832 7679.5 8611 5527 ROP 13.0225 606.954 182.264 8475 5595 GR 43.1631 480.776 t33.438 8527 5527 Last Reading 9832 9832 9790 First Reading For Entire File .......... 5527 Last Reading For Entire File ........... 9832 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9790.5 FET 9812.5 RPD 9812.5 RPM 9812.5 RPS 9812.5 RPX 9812.5 ROP 9834.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: II 2.17F DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) STOP DEPTH 10722.0 10729.0 10729.0 10729.0 10729.0 10729.0 10775.0 01-0CT-97 ISC 5.06 ClM 5.46/SP4 5.03/DEP MEMORY 10775.0 9832.0 10775.0 68.8 92.4 TOOL NUMBER P0694SP4 P0694SP4 6.130 6.1 LSND 230.80 46.0 8.5 400 5.8 MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.500 2.150 3.000 3.800 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 4 FT/H 4 1 68 4 2 FET MWD 4 HOUR 4 1 68 8 3 RPX MWD 4 OHMM 4 1 68 12 4 RPS MWD 4 OHM~ 4 1 68 16 5 RPM MWD 4 OHMM 4 1 68 20 6 RPD MWD 4 OHMM 4 1 68 24 7 GR MWD 4 API 4 1 68 28 8 60.6 Name DEPT ROP FET RPX RPS RPM RPD GR Min 9790.5 4 7712 0 3514 2 3706 1 4043 0 1738 2 1979 29 9095 First Max Mean Nsam Reading 10775 10282.8 1970 9790.5 658.594 133.39 1883 9834 95.2101 3.32553 1834 9812.5 2000 40.1023 1834 9812.5 2000 40.2435 1834 9812.5 2000 47.7158 1834 9812.5 2000 59.709 1834 9812.5 151.266 71.5333 1864 9790.5 Last Reading 10775 10775 10729 10729 10729 10729 10729 10722 First Reading For Entire File .......... 9790.5 Last Reading For Entire File ........... 10775 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Conunent Record FI LE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10733.0 FET 10739.5 RPD 10739.5 RPM 10739.5 RPS 10739.5 RPX 10739.5 ROP 10776.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: II 2.17F DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): STOP DEPTH 11669.5 11676.5 11676.5 11676.5 11676.5 11676.5 11712.5 04-OCT-97 ISC 5.06 ClM 5.46/SP4 5.03/DEP MEMORY 11712.0 10775.0 11712.0 85.6 92.3 TOOL NUMBER P0847SP4 P0847SP4 6.130 DRILLER'S CASING DEPTH (FT): 6.1 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): I~UD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHN~4) AT TEMPERATURE (DEGF) I~UD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 232.70 65.0 8.8 5OO 2.8 3.500 2. 023 2.800 3.700 .6 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RPX MWD 5 OHMM 4 1 68 RPS MWD 5 OHMM 4 1 68 RPM MWD 5 OHN~ 4 1 68 RPD MWD 5 OHMM 4 1 68 ROP MWD 5 FT/H 4 1 68 FET MWD 5 HOUR 4 1 68 GR MWD 5 API 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 56.1 Name Min Max Mean DEPT 10733 11712.5 11222.8 RPX 30.5042 102.52 60.3899 RPS 34.6809 90.1079 62.2119 RPM 37.3063 95.7494 67.0848 RPD 53.478 130.496 88.3844 ROP 6.601 947.461 103.638 FET 0.4308 34.3634 2.81458 GR 33.5566 101.515 66.7637 Nsam 1960 1875 1875 1875 1875 1873 1875 1874 First Reading 10733 10739.5 10739.5 10739.5 10739.5 10776.5 10739.5 10733 Last Reading 11712 5 11676 5 11676 5 11676 5 11676 5 11712 5 11676 5 11669 5 First Reading For Entire File .......... 10733 Last Reading For Entire File ........... 11712.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Corament Record FILE HEADER FILE NUMBER: 6 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: FILE SUMMARY .5000 5 VENDOR TOOL CODE START DEPTH STOP DEPTH FET 10606.0 10834.5 RPD 10606.0 10834.5 RPM 10606.0 10834.5 RPS 10606.0 10834.5 RPX 10606.0 10834.5 GR 10612.5 10834.0 RAT 10641.5 10868.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: II 2.17F DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : 04-OCT-97 ISC 5.06 CIM 5.46/SP4 5.03/DEP MEMORY 11712.0 10775.0 11712.0 HOLE INCLINATION (DEG MINIMUM ANGLE: NLAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHM}4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 85.6 92.3 TOOL NUMBER P0847SP4 P0847SP4 6.130 6.1 LSND 232.70 65.0 8.8 500 2.8 3.500 2. 023 2.800 3.700 56.1 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPX MAD 5 OHMM 4 1 68 4 2 RPS ~AD 5 OHM>4 4 1 68 8 3 RPM MAD 5 OHMM 4 1 68 12 4 RPD MAD 5 OHMM 4 1 68 16 5 RAT MAD 5 FT/H 4 1 68 20 6 FET MAD 5 HOUR 4 1 68 24 7 GR MAD 5 API 4 1 68 28 8 Name Min Max Mean DEPT 10606 10868 10737 RPX 35.7621 85.8623 54.5233 RPS 45.7456 80.0106 58.7156 RPM 51.0666 86.4099 69.72 RPD 73.2161 129.646 97.2928 RAT 253.784 598.416 367.147 FET 41.4477 83.5735 70.7837 GR 32.1948 128.037 58.6459 Nsam 525 458 458 458 458 454 458 444 First Reading 10606 10606 10606 10606 10606 10641.5 10606 10612.5 Last Reading 10868 10834.5 10834.5 10834.5 10834.5 10868 10834.5 10834 First Reading For Entire File .......... 10606 Last Reading For Entire File ........... 10868 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/02/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/02/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER . * ............................ . ....... SCHLUFiBERGER ....... , COMPANY NAFIE : ARCO ALASKA, INC. WELL NAF~E : 1E-34 FIELD NAME : KUPARUKRIVER UNIT BOROUGH : NORTH SLOPE STATE : ALASKA API~ER : 500292280500 REFERENCE NO : 97571 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: **** REEL HEADER **** SERVICE NAMiE : EDIT DATE : 98/01/ 8 ORIGIN : FLIC REEL NAME : 97571 CONTINUATION # : PREVIOUS REEL : COF~ENT : ARCO ALASKA INC, 1E-34, KUPARUK RIVER UNIT, 50-029-22805-00 **** TAPE HEADER **** SERVICE NAM~ : EDIT DATE : 98/01/ 8 ORIGIN · FLIC TAPE NAM~ : 97571 CONTINUATION # : 1 PREVIOUS TAPE : COMF~aNT : ARCO ALASKA INC, 1E-34, KUPARUK RIVER UNIT, 50-029-22805-00 TAPE HEADER KUPARUK RIVER UNIT CASED HOLE WIRELINE LOGS WELL NAME: 1E-34 API NUM~ER: 500292280500 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 7-JAN-98 JOB NUMBER: 97571 LOGGING ENGINEER: BAILEY OPERATOR WITNESS: N. SCHUROSKY SURFACE LOCATION SECTION: 16 TOWNSHIP: 1 iN RANGE: 10E FNL: FSL: 634 FEL: 633 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 112.90 GROUND LEVEL: 71.40 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) IST STRING 9. 625 5577.0 40. O0 2ND STRING 7. 000 9821 . 0 26. O0 3RD STRING 4. 500 11712.0 12.60 PRODUCTION STRING 4. 500 9625.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (FiEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: SPERRY SUN BASELINE DEPTH 88888.0 11606.5 11592.5 11562.0 11547.0 11532.5 11525.0 11507.0 11492.5 11490.0 11475.5 11459.5 11438.5 11428.0 11413.5 11407.0 11392.0 11385.5 11362.0 11354.0 11353.5 11346.0 11340.5 11328.0 11321.5 11317.5 11315.5 11314.0 11313.0 11305 5 11302 0 11288 5 11277 0 11271 5 11267 0 11255.5 11247.5 11236.5 11224.5 11224.0 11220.5 11218.0 11209.0 11197.0 11196.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88886.0 88887.0 11605.5 11590.5 11590.5 11560.0 11560.0 11546.5 11530.5 11530.5 11524.5 11524.5 11507.5 11507.5 11493.0 11489.0 11477.0 11477.0 11458.5 11458.5 11438.5 11438.5 11427.5 11427.5 11413.5 11413.5 11406.5 11406.5 11392.5 11392.5 11386.5 11386.5 11363.0 11363.0 11353.0 11352.5 11339.5 11329.5 11322.5 11317.5 11313.0 11310.0 11305.5 11301.0 11290.0 11276.0 11270.0 11265.5 11256.5 11248.5 11223.0 11218.5 11207.0 11196.0 11347.0 11329.5 11322.5 11317.5 11312.0 11301.0 11289.5 11276.0 11270.0 11265.5 11256.5 11248.5 11234.5 11223.0 11218.0 11196.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 11186.0 11186.0 11186.0 11174.0 11173.0 11173.0 11171.0 11167.5 11167.0 11166.5 11164.0 11160.0 11162.5 11159.5 11156.5 11149.5 11148.5 11149.0 11148.0 11134.0 11131.5 11133.0 11131.0 11128.5 11127.0 11120.0 11117.5 11119.0 11117.5 11112.0 11111.0 11101.5 11100.0 11096.0 11094.5 11094.5 11092.0 11091.5 11091.5 11082.0 11081.5 11081.5 11075.5 11074.0 11074.0 11067.0 11064.5 11065.5 11064.5 11056.0 11055.0 11055.0 11036.5 11034.0 11034.0 11019.0 11017.0 11018.0 11017.0 11014.0 11012.5 11012.5 11007.0 11007.0 11006.5 11007.0 10996.5 10995.0 10995.0 10994.0 10988.0 10988.5 10988.5 10974.5 10974.5 10970.0 10971.0 10961.0 10960.5 10960.5 10962.0 10955.5 10956.5 10948.5 10949.0 10944.5 10944.5 10944.0 10940.0 10939.5 10938.5 10939.0 10926.0 10925.0 10925.0 10923.5 10922.0 10922.5 10922.0 10917.0 10917.5 10917.5 10911.5 10912.0 10912.0 10904.5 10904.0 10891.0 10890.0 10889.0 10888.5 10883.0 10883.5 10875.5 10875.5 10875.0 10875.5 10870.5 10870.5 10856.0 10857.5 10857.0 10843.0 10843.0 10842.5 10842.5 10826.5 10826.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10825.5 10826.0 10820.5 10819.5 10820.0 10819.5 10808.0 10806.5 10797.5 10796.0 10797.0 10796.0 10794.0 10792.0 10791 . 5 10791 . 5 10789.0 10786.0 10782.5 10782.0 10779.5 10778.5 10778.5 10775.0 10772.5 10773.5 10772.0 10768.5 10767.0 10767.0 10759.5 10759.5 10759.5 10754.0 10755.0 10751 . 0 10750.5 10750.5 10750.5 10743.0 10741.5 10742.5 10735.0 10735.0 10734.0 10735.0 10729.5 10730.5 10718.5 10718.5 10718.5 10707.5 10705.5 10707.0 10705.5 10700.0 10699.5 10699.5 10699.5 10694.0 10694.0 10690.5 10689.5 10689.5 10687.5 10686.5 10687.0 10686.5 10679.5 10678.0 10678.5 10677.5 10673.5 10673.0 10673.0 10669.0 10668.0 10668.0 10660.0 10658.5 10653 . 0 10654.0 10645.0 10643.0 10641 . 5 10642.5 10636.5 10636.0 10631.0 10630.5 10628.5 10628.0 10612.5 10609.0 10609.0 10606.5 10604.0 10601.5 10601.5 10590.5 10590.5 10589.5 10590.0 10580.5 10581 . 5 10575.0 10575.0 10571 . 5 10570.5 10564.5 10563.0 10564.0 10563 . 5 10560.5 10559.0 10560.0 10559.0 10548.0 10547.0 10535.5 10534.5 10534.5 8-JAN-1998 10:12 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 10530.0 10530.5 10529.5 10530.5 10518.5 10518.5 10518.0 10518.5 10507.5 10506.5 10506.0 10506.0 10498.5 10498.5 10497.0 10486.5 10486.0 10484.0 10484.0 10477.0 10476.0 10475.5 10476.0 10464.0 10464 . 0 10464.0 10452.0 10452.0 10451.5 10452.0 10445.0 10444.0 10444.0 10427.5 10426.0 10427.0 10426.0 10421.5 10420.0 10420.5 10420.5 10410.5 10409.0 10410.0 10408.5 10403.0 10402.5 10402.5 10399.5 10398.5 10398.5 10387.5 10388.5 10388.5 10378.0 10379.0 10368.5 10367.5 10367.0 10367.5 10362.5 10362.5 10361.0 10362.0 10346.0 10347.0 10347.0 10337.5 10337.0 10335.5 10334.5 10324.0 10322.0 10309,5 10310.0 10310.0 10301.0 10299.0 10300.0 10299.0 10274.5 10271.5 10271.5 10270.5 10267.5 10265.0 10262.5 10263.0 10259.5 10262.0 10259 . 5 10244.5 10245.0 10233.5 10231.5 10232.5 10231 . 5 10209.5 10208.5 10208.0 10208.5 10195.0 10192.0 10192.0 10184.5 10182.5 10184.0 10182.5 10171.5 10170.0 10170.0 10161.5 10161.0 10156.5 10154.0 10142.5 10144.0 10141.5 10142.0 10136.0 10135.5 10135.5 10131.5 10130.5 8-JAN-1998 10:12 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 10131.0 10130.5 10123.0 10121 . 0 10121 . 0 10117.0 10115.5 10115.5 10108.5 10106.5 10106.5 10104.5 10101.5 10102.0 10101.5 10099.5 10099.5 100.0 100.0 99.5 $ CONTAINED HEREIN IS THE CASED HOLE LDWG FORMATTED TDTP DATA AQUIRED ON ARCO ALASKA'S 1E-34 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN PASS #1 GRCH AND THE BCS GAM~A RAY, ALSO PASS #1 SIGMA TO THE BCS GAM~A RAY, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE IVUM~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SD?4~L~RY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11593.0 10095.5 TDTP 11621.0 10095.0 $ CURVE SHIFT DATA - PASS TO PASS (FIEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUFiBER : BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #1. LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 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 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 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NU~IB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM TDTP CU 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 SBHNTDTP CU 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 TCAN TDTP CPS 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 TSCNTDTP CPS 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 TSCFTDTP CPS 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEI~ CODE (HEX) INFD TDTP CPS 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1066347 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11712.000 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 -999.000 DEPT. 9750.000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP TENS. TDTP -999.250 CCL. TDTP -999.250 GR.BCS 108.130 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFiE : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11585.5 10096.5 TDTP 11627.5 10096.5 $ CURVE SHIFT DATA - PASS TO PASS (MEAStrRED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUPiBER : 1 BASELINE DEPTH 88888.0 88888.5 88887.5 11616.0 11615.5 11609.0 11610.5 11605.5 11605.5 11591.5 11591.5 11585.5 11583.5 11583.0 11580.5 11575.0 11575.5 11574.0 11572.0 11572.5 11571.5 11565.0 11566.5 11562.0 11563.0 11560.5 11560.5 11560.0 11555.5 11551.5 11552.5 11549.5 11546.5 11539.0 11536.0 11538.5 11538.0 11536.0 11532.5 11531.0 11530.5 11524.5 11526.5 11517.5 11518.0 11512.0 11510.5 11510.5 11511.5 11501.0 11498.0 11498.5 11499.5 11493.5 11493.0 11485.5 11488.0 11478.0 11477.5 11481.5 11470.0 11468.5 11467.5 11465.0 11460.5 11458.5 11453.0 11453.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 10 11451.5 11452.5 11447.5 11447.5 11440.5 11438.5 11438.5 11443.5 11435.0 11437.0 11425.0 11426.0 11421.5 11422.0 11419.5 11419.0 11411.5 11411.5 11405.0 11405.5 11401.5 11403.0 11396.5 11398.0 11395.0 11397.0 11386.5 11388.0 11378.0 11379.0 11376.0 11378.0 11372.0 11373.5 11365.5 11365.5 11362.0 11363 . 0 11359.5 11360.5 11353.5 11353.0 11353.0 11353.0 11347.5 11347.0 11346.0 11345.0 11331.5 11329.5 11330.5 11332.0 11326.0 11322.5 11322.0 11321.0 11319.0 11317.0 11318.0 11317.0 11305.0 11305.5 11305.0 11296.0 11294.5 11293.0 11291.5 11280.5 11278.5 11280.0 11281.0 11276.5 11277.5 11267.0 11266.0 11264.0 11267.5 11256.0 11256.0 11255.0 11256.5 11252.0 11253.0 11246.5 11248.5 11244.5 11236.0 11234.5 11234.0 11232.5 11224.5 11223.5 11223.0 11223.5 11218.0 11216.5 11217.5 11218.5 11211.0 11209.0 11203.5 11204.5 11199.5 11197.5 11196.5 11197.0 11173.0 11170.5 11171.5 11171.0 11163.5 11162.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 11 11158.5 11155.0 11153.5 11153.5 11148.5 11148.5 11140.5 11140.5 11135.0 11133.5 11133.0 11131.0 11122.0 11120.0 11118.5 11116.5 11111.5 11111.0 11106.0 11104.5 11100.5 11100.5 11096.0 11096.0 11091.5 11091.0 11091.0 11091.0 11083.5 11082.5 11080.5 11081.0 11075.5 11074.0 11072.5 11071.5 11069.0 11069.0 11064.0 11064.0 11057.0 11055.0 11055.5 11057.0 11049.0 11048.0 11044.0 11042.0 11041.5 11040.0 11039.0 11039.0 11035.5 11034.5 11034.0 11029.0 11028.0 11021 . 5 11022.5 11019.0 11017.5 11013.0 11011.5 11011.5 11012.5 10999.0 11000.5 10991.5 10993.0 10992,0 10988.5 10988.5 10983.0 10982.5 10975.0 10978.0 10968.5 10970.5 10965.5 10966.0 10954.0 10957.0 10953.0 10954.0 10949.0 10949.5 10944.5 10946.5 10934.0 10934.5 10924.5 10924.5 10918.5 10920.0 10914.0 10912.0 10913.5 10915.5 10909.5 10912.0 10890.0 10890.0 10887.5 10888.5 10881.0 10883.0 10873.0 10872.0 10863.0 10864.5 10855.5 10857.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 12 10855.0 10852.5 10848.5 10845.5 10836.5 10834.0 10829.5 10827.5 10825.0 10818 0 10817 5 10812 5 10807 0 10806 5 10801 5 10790 0 10788 5 10783 0 10780 0 10776.5 10769.5 10767.0 10761.0 10756.0 10752 5 10746 5 10741 5 10738 5 10733 0 10728 5 10719 0 10718 0 10708 5 10704 0 10695 5 10693 5 10680 5 10673.5 10673.0 10667.5 10663.0 10659.0 10657.0 10652.5 10644.0 10638.0 10636.5 10636.0 10628.5 10614.5 10613.0 10607.5 10604.0 10601.5 10593.0 10857.0 10851.0 10837.5 10826.5 10820.0 10814.5 10807.5 10803.5 10788.5 10779.5 10778.0 10762.0 10757.5 10747.0 10741.5 10729.0 10719.0 10709.5 10693.0 10673.0 10662.5 10658.0 10637.0 10635.5 10612.0 10602.0 10854.5 10845.5 10834.0 10831.0 10826.0 10818.5 10806.0 10791.5 10782.0 10769.0 10766.0 10750.5 10737.0 10733.0 10727.5 10718.0 10703.5 10696.0 10680.5 10674.0 10667.0 10660.5 10657.5 10654.5 10642.5 1O636.0 10628.5 10614.0 10606.5 10600.0 10591.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 13 10590.0 10588.0 10585.0 10585.5 10582.5 10583.0 10577.5 10576.5 10577.0 10575.0 10574.5 10573 . 0 10569.5 10567.5 10566.0 10566.0 10565.5 10563.5 10563.5 10563.0 10560.0 10559.0 10559.5 10559.0 10548.0 10547.0 10540.5 10540.5 10535.0 10534.5 10529.5 10530.5 10523.5 10524.5 10514.5 10516.0 10504.0 10506.0 10500.0 10501.5 10499.5 10498.0 10491.0 10494.0 10486.0 10486.0 10480.5 10479.0 10475.0 10476.0 10462.5 10463.5 10453.0 10452.5 10449.5 10453 . 0 10443.5 10444.0 10443.0 10447.5 10436.5 10435.5 10435.5 10439.5 10430.0 10429.5 10429.0 10426.5 10427.0 10426.5 10420.5 10420.5 10410.5 10409.0 10398.0 10399.0 10390.0 10390.5 10386.0 10385.0 10385.5 10385.0 10383.0 10384.0 10379.5 10381 . 0 10377.5 10377.5 10379.0 10374.0 10374.5 10371 . 0 10372.5 10368.0 10367.5 10361.5 10362.5 10352.0 10350.5 10341.5 10340.0 10339.0 10337.0 10336.5 10334.5 10326.5 10325.0 10326.0 10323.5 10320.0 10318.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 14 10318.0 10317.5 10311 . 0 10311 . 0 10306.0 10307.5 10304.0 10305.0 10303.0 10299.5 10297.0 10296.5 10284.0 10281.0 10280.0 10279.0 10281.5 10269.0 10268.5 10260.5 10259.5 10258.5 10259.5 10254.5 10252.5 10253.5 10252 . 5 10249.0 10247.0 10247.0 10246.5 10242.5 10241.5 10236.5 10236.0 10234.5 10234.0 10230.5 10231 . 5 10228.5 10229.0 10226.0 10223.5 10225.5 10224.5 10217.0 10215.5 10210.0 10207.0 10207.5 10204 . 5 10206.5 10208.0 10199.0 10198.5 10195.0 10194.0 10194.0 10192.5 10185.0 10185.0 10185.0 10180.5 10180.5 10177.5 10177.5 10167.5 10169.5 10160.5 10161.0 10159.0 10161.5 10154.5 10158.0 10152.0 10154.0 10145.0 10146.0 10140.0 10142.0 10139.0 10140.0 10133.0 10133.5 10131.5 10130.0 10131.0 10130.5 10125.0 10123.5 10121.5 10121 . 0 10114.5 10114.0 10110.0 10111.0 10109.0 10108.5 10106.5 10107.5 10104.0 10103.5 10102.0 10103.0 10101.0 10101.5 10100.5 10100.5 10098.5 10099.0 100.0 100.5 100.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 15 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCHBASE PASS #2 AND GRCHBASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE 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 ** NA~E SERV UNIT SERVICE API API API API FILE NUM~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 SBHIV TDTP CU 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 16 NA~E SERV UNIT SERVICE API API API API FILE NU~IB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CI. dtSS MOD ~ S,~,IP ELI~I CODE (HEX) TCAF TDTP CPS 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 TSCNTDTP CPS 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 1066347 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11627.500 SIGM. TDTP 33.350 TPHI.TDTP 58.213 SBHF. TDTP SBHN. TDTP 55.104 SIGC. TDTP 1.453 SIBH. TDTP 94.294 TRAT. TDTP SDSI.TDTP 1.089 BACK. TDTP 413.702 FBAC. TDTP 264.782 TCAN. TDTP TCAF. TDTP 4622.283 TCND. TDTP 15061.672 TCFD. TDTP 3338.838 TSCN. TDTP TSCF. TDTP 517.075 INND. TDTP 2301.749 INFD.TDTP 296.238 GRCH. TDTP TENS. TDTP 25.000 CCL. TDTP 0.000 DEPT. 10096.500 SIGM. TDTP SBHN. TDTP 53.640 SIGC. TDTP SDSI.TDTP 0.823 BACK. TDTP TCAF. TDTP 5207.804 TCND. TDTP TSCF. TDTP 568.706 INND. TDTP TENS. TDTP 25.000 CCL. TDTP 34 807 1 046 224 503 16603 551 2347 508 0 000 41.819 1.953 17565.098 1858.321 -999.250 TPHI.TDTP 60.518 SBHF. TDTP 45.854 SIBH. TDTP 89.613 TRAT. TDTP 1.959 FBAC. TDTP 38.866 TCAN. TDTP 19940.621 TCFD.TDTP 3751.097 TSCN. TDTP 2028.330 INFD.TDTP 296.093 GRCH. TDTP 55.281 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE ' FLIC VERSION · O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 17 **** FILE HEADER **** FILE NAFiE : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUPiBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INC~: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11595.0 10104.5 TDTP 11629.5 1 O105.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASUR3F~ DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 11616.0 11610.5 11594 0 11588 5 11583 5 11581 5 11571 0 11564 0 11561 5 11559 5 11555 0 11549 0 11544 0 11540 5 11537 5 11531 5 11529 0 11527.0 11524.5 11523.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88888.0 88887.5 11583.5 11571.0 11563.0 11560.0 11552.0 11547.5 11539.5 11530.0 11524.5 11615.5 11607.5 11592.0 11587.0 11580.5 11572.0 11565.0 11555.5 11538.5 11529.5 11526.5 11522.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 18 11518.0 11517.5 11512.5 11512.0 11507.0 11507.5 11500.0 11498.0 11498.0 11499.5 11495.5 11493.0 11488.5 11489.5 11487.5 11485.0 11474.5 11477.5 11472.0 11464.0 11462.5 11457.5 11458.5 11453.5 11452.5 11453.0 11454.5 11446.5 11447.5 11441.5 11443.5 11438.0 11437.5 11435.5 11437.5 11432.0 11432.5 11427.0 11429.0 11425.0 11425.5 11416.5 11415.0 11413.5 11411.0 11412.0 11414.0 11407.5 11407.0 11403.0 11403.0 11396.5 11397.0 11392.0 11391.0 11387.0 11388.5 11382 . 5 11382.5 11375.0 11377.5 11373.5 11378.0 11370.5 11368.0 11368.0 11365.5 11363.0 11365.5 11353.0 11353.0 11350.0 11353.0 11349.5 11351.0 11346.5 11345.0 11346.0 11346.5 11342.0 11339.5 11331.5 11332.0 11331.0 11329.5 11323.5 11322.5 11321.0 11322.5 11319.0 11318.0 11308.5 11309.5 11301.5 11300.0 11300.5 11301.5 11296.5 11299.5 11294.0 11294.5 11291.0 11291.5 11286.0 11284.5 11281.0 11278.5 11279.5 11277.5 11271.0 11272.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 19 11270.0 11268.5 11266.0 11260.0 11253 5 11241 0 11239 5 11235 0 11223 0 11222 5 11216.5 11216.0 11209.5 11200.0 11193.5 11185.0 11182.0 11175.5 11171.0 11162.0 11160.0 11152.5 11150.0 11148.0 11141.5 11133.5 11131.5 11127.0 11120.5 11119.5 11113.5 11110.5 11105.0 11098.0 11097.0 11096.0 11089.5 11088.0 11080.5 11079.5 11074.0 11069.0 11068.5 11063.0 11062.5 11055.0 11054.0 11050.0 11041.0 11034.0 11033.5 11025.0 11024.5 11022.0 11017.0 11270.0 11267.5 11259.0 11241.0 11224.0 11217.5 11186.5 11173.0 11151.5 11140.5 11131.0 11127.0 11120.0 11110.5 11097.0 11096.0 11088.0 11081.5 11074.0 11068.5 11062.0 11055.0 11051.0 11041.5 11034.5 11026.5 11022.5 11017.0 11267.5 11256.5 11244.5 11234.5 11223.5 11218.0 11210.0 11201.5 11194.5 11182.5 11175.0 11162.0 11159.0 11153.5 11148.5 11133.5 11120.5 11114.5 11104.5 11098.0 11091.0 11081.0 11069.0 11061.0 11055.0 11034.0 11026.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 2O 11012.5 11012.5 11006.0 11007.0 11000.5 11002.5 10999.0 10998.5 10992.0 10992.0 10990.0 10988.5 10989.0 10990.0 10983.5 10986.0 10983.0 10982.5 10977.5 10978.5 10973.5 10974.0 10972.0 10965.5 10966.0 10961.0 10962.0 10955.0 10954.0 10954.0 10956.5 10948.0 10949.5 10945.5 10944.0 10941.5 10939.0 10938.5 10939.5 10931.5 10930.5 10926.5 10928.0 10924.0 10925.0 10916.0 10915.5 10911.0 10912.0 10907.5 10909.0 10903.0 10903.5 10902.0 10903.0 10889.0 10890.0 10888.5 10888.5 10888.0 10887.5 10882.0 10880.0 10875.0 10875.5 10870.0 10870.5 10864.0 10864.5 10859.0 10859.5 10854.0 10856.5 10853.0 10852.5 10848.5 10849.0 10843.0 10843.0 10844.5 10839.0 10837.5 10833.5 10834.0 10827.5 10826.5 10824.0 10826.0 10822.5 10820.0 10818.0 10814.5 10817.0 10818.5 10814.5 10814.0 10807.0 10807.0 10805.5 10806.0 10803.0 10803.5 10798.5 10797.0 10796.5 10794.5 10792.5 10791.5 10789.0 10788.0 10782.5 10782.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 21 10782.0 10778.0 10776.0 10772.5 10775.0 10777.0 10762.5 10762.5 10752.5 10755.0 10749.0 10750.0 10748.0 10750.5 10743.5 10745.5 10738 . 5 10739.5 10724.0 10724.0 10722 . 5 10721 . 5 10708.5 10710.5 10708.0 10709.5 10706.5 10708.0 10705.0 10705.5 10694.0 10696.0 10689.0 10693.0 10681 . 5 10680.0 10665.5 10670.0 10659.5 10660.0 10653.5 10656.0 10650.5 10654.0 10643.5 10643.0 10639 . 5 10642.5 10634.5 10636.0 10633.0 10637.0 10627.5 10628.5 10627.0 10630.0 10618.0 10618.5 10614 . 5 10614.5 10612.0 10612.0 10608.5 10609.5 10607.0 10606.5 10601.5 10602.0 10600.0 10600.0 10594 . 5 10595.5 10590.0 10588.0 10587.5 10590.0 10583 . 5 10585.5 10579.0 10580.0 10575.5 10575.5 10574.0 10573.5 10564.0 10563.0 10561.0 10559.0 10558 . 5 10559.5 10548.0 10549.0 10547.0 10547.0 10534.5 10534.0 10529.5 10530.5 10525.5 10525.0 10518.0 10518.5 10508.0 10510.5 10503.0 10506.0 10502.0 10502.0 10495.5 10494.0 10495.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 22 10491.0 10486.0 10479.0 10477.0 10471.0 10462.5 10460.0 10455.0 10454.0 10447.5 10442.5 10436.5 10431.0 10427.0 10424.0 10422.0 10411.5 10410.5 10405.0 10390.0 10383.5 10379.5 10376.5 10375.5 10370.0 10367.5 10359.0 10358.0 10351.0 10343.0 10338.0 10325.5 10324.0 10313.0 10312.5 10305.5 10303.5 10302.0 10297.0 10295.0 10286.0 10283.5 10282.5 10272.5 10266.0 10259.5 10253.5 10252.0 10247.5 10247.0 10234.5 10226.0 10223.0 10222.5 10210.0 10476.0 10464.0 10452.5 10435.5 10427.0 10420.5 10412.0 10404.0 10388.5 10383.5 10377.5 10373.0 10359.5 10345.0 10339.5 10327.0 10314.5 10304.0 10299.0 10294.5 10286.5 10281.0 10271 5 10259 5 10252 0 10247 0 10226 5 10221 5 10488.5 10484.0 10475.5 10464.5 10455.0 10451.5 10445.5 10439.5 10433.5 10429.5 10424.0 10411.0 10379.0 10376.0 10367.0 10356.5 10349.0 10339.0 10325.5 10312.5 10304.5 10296.0 10282.0 10264 5 10252 5 10247 0 10235 0 10223 5 10211 5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 23 10206.0 10204.5 10205.5 10208.5 10201.5 10199.5 10194.0 10193.5 10192.5 10192.0 10185.0 10184.5 10176.5 10176.5 10174 . 0 10172.0 10165.5 10166.5 10161.5 10161.5 10157.5 10156.0 10145.0 10142.0 10144.5 10144.0 10142.5 10140.0 10142.0 10140.5 10137.0 10133.5 10132.5 10131.0 10132.0 10128.5 10121.0 10121.0 10119.0 10118.5 10113.5 10115.5 10107.5 10108.5 10106.5 10107.0 100.0 100.5 101.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #3 AND SIGMA BASE 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 24 TYPE REPR CODE VALUE 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** N32.1E SERV UNIT SERVICE ~::~I API gPI API FILE NUlvlB NUblB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1066347 O0 000 O0 0 3 1 1 4 68 SIGMTDTP CU 1066347 O0 000 O0 0 3 1 1 4 68 TPHI TDTP PU-S 1066347 O0 000 O0 0 3 1 1 4 68 SBHF TDTP CU 1066347 O0 000 O0 0 3 1 1 4 68 SBHN TDTP CU 1066347 O0 000 O0 0 3 1 1 4 68 SIGC TDTP CU 1066347 O0 000 O0 0 3 1 1 4 68 SIBH TDTP CU 1066347 O0 000 O0 0 3 1 1 4 68 TRAT TDTP 1066347 O0 000 O0 0 3 1 1 4 68 SDSI TDTP CU 1066347 O0 000 O0 0 3 1 1 4 68 BACK TDTP CPS 1066347 O0 000 O0 0 3 1 1 4 68 FBAC TDTP CPS 1066347 O0 000 O0 0 3 1 1 4 68 TCAN TDTP CPS 1066347 O0 000 O0 0 3 1 1 4 68 TCAF TDTP CPS 1066347 O0 000 O0 0 3 1 1 4 68 TCND TDTP CPS 1066347 O0 000 O0 0 3 1 1 4 68 TCFD TDTP CPS 1066347 O0 000 O0 0 3 1 1 4 68 TSCN TDTP CPS 1066347 O0 000 O0 0 3 1 1 4 68 TSCF TDTP CPS 1066347 O0 000 O0 0 3 1 1 4 68 INND TDTP CPS 1066347 O0 000 O0 0 3 1 1 4 68 INFD TDTP CPS 1066347 O0 000 O0 0 3 1 1 4 68 GRCH TDTP GAPI 1066347 O0 000 O0 0 3 1 1 4 68 TENS TDTP LB 1066347 O0 000 O0 0 3 1 1 4 68 CCL TDTP V 1066347 O0 000 O0 0 3 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 ** DATA ** DEPT. 11629.500 SIGM. TDTP 32.039 TPHI.TDTP 61.914 SBHF. TDTP 29.877 SBHN. TDTP 66.745 SIGC. TDTP 1.200 SIBH. TDTP 131.524 TRAT. TDTP 2.041 SDSI. TDTP 0.992 BACK. TDTP 451.255 FBAC. TDTP 446.523 TCAN. TDTP 30284.672 TCAF. TDTP 7473.996 TCND. TDTP 14366.869 TCFD. TDTP 3035.276 TSCN. TDTP 1670.121 TSCF. TDTP 447.283 INND. TDTP 2442.148 INFD.TDTP 279.356 GRCH. TDTP -999.250 TENS.TDTP 15.000 CCL.TDTP 0.000 DEPT. 10104.500 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 64.438 TENS. TDTP -999.250 CCL. TDTP -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 25 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS--ER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 1i 600.0 1 O109.5 TDTP 11626.0 10109.5 $ CURVE SHIFT DATA - PASS TO PASS (FiEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NU~IBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP ............................ 88888.0 88889.0 88889.0 11620.0 11621.0 11614.5 11615.0 11604.0 11605.5 11596.0 11596.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 26 11589.5 11590.5 11587.0 11588.5 11586.5 11586.0 11581.5 11583.5 11579.0 11580.5 11575.0 11575.5 11568.5 11571.0 11561.5 11564.5 11558.5 11558.5 11554.0 11555.5 11549.0 11549.0 11545.0 11544.5 11540.0 11539.5 11527.5 11530.0 11526.5 11529.0 11525.5 11527.0 11522.5 11526.0 11511.0 11511.5 11508.0 11508.0 11504.0 11505.5 11503.0 11502.5 11500.5 11499.5 11496.0 11498.0 11488.5 11489.5 11481.5 11487.5 11477.5 11475.5 11464.5 11465.0 11462.0 11469.0 11457.0 11457.0 11456.0 11461.5 11448.5 11451.5 11443.5 11448.0 11440.5 11443.0 11438.0 11439.5 11437.0 11437.5 11435.5 11439.0 11423.5 11427.5 11418.5 11419.0 11417.0 11422.0 11413.0 11415.5 11412.5 11415.0 11410.5 11411.0 11408.0 11406.5 11406.5 11405.0 11404.0 11406.5 11388.5 11390.5 11386.0 11386.5 11377.0 11378.0 11373.0 11378.0 11370.5 11370.5 11370.0 11373.5 11364.5 11365.5 11364.0 11364.5 11358.0 11357.5 11353.5 11353.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 27 11349.0 11349.5 11348.5 11347.0 11343.0 11345.0 11338.0 11337.5 11328.5 11329.5 11325.5 11328.0 11322.5 11322.5 11316.0 11317.0 11314.0 11317.0 11309.5 11312.0 11303.0 11305.0 11300.0 11301.0 11299.5 11300.0 11292.5 11294.5 11292.0 11291.5 11287.0 11290.0 11277.0 11277.5 11276.5 11278.5 11269.0 11267.5 11265.0 11266.0 11255.5 11256.0 11249.5 11248.5 11249.5 11238.0 11241.0 11231.5 11234.5 11220.0 11224.0 11213.0 11218.0 11210.0 11209.0 11206.0 11205.5 11202.5 11202.0 11193.5 11195.5 11191.5 11197.0 11187.5 11186.5 11179.5 11179.0 11165.5 11171.0 11161.5 11163.5 11157.0 11155.5 11153.5 11153.5 11148.0 11148.0 11143.5 11149.0 11142.0 11143.5 11128.5 11134.0 11127.0 11131.0 11115.5 11121.5 11111.5 11116.0 11106.5 11110.5 11100.0 11104.5 11089.0 11090.5 11086.5 11091.5 11081.5 11082.5 11076.5 11081.5 11065.0 11067.0 11064.5 11069.0 11060.5 11064.5 11055.5 11057.0 11051.5 11054.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 28 11049 0 11042 0 11041 0 11040 0 11039 0 11030 5 11030 0 11022 0 11020 0 11015 5 11015 0 11007 0 11005 0 11001 0 10999 5 10995 0 10985 5 10983.0 10978.0 10975.5 10973.0 10962.0 10959.0 10956.0 10949 5 10944 5 10938 5 10938 0 10929 0 10925 0 10922 5 10915 5 10911 0 10906.5 10902.0 10897.5 10896.0 10895 5 10885 5 10879 0 10869 5 10868 0 10861 0 10850 0 10843 0 10836 5 10835 5 10827 0 10826 5 10813.5 10809.0 10806.0 10796.0 10790.5 10784.0 11055.0 11045.5 11034.5 11029.5 11022.5 11012.5 11007.5 11000.0 10989.0 10982.5 10978.0 10974.5 10964.5 10962.5 10951.0 10944.0 10939.5 10933.0 10928.0 10920.0 10912.5 10903.0 10898.5 10881.0 10869.5 10853.0 10846.5 10838.0 10826.5 10814.0 10807.0 10797.5 10792.0 11044.0 11041.5 11039.5 11032.0 11023.0 11017.0 11008.5 11001.0 10986.0 10957.5 10939.0 10925.0 10912.0 10904.0 10895.0 10892.5 10882.5 10866.0 10857.0 10834.5 10825.5 10809.0 10791.5 10782.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 29 10783.5 10779.0 10772.0 10771.0 10767.5 10764 5 10763 0 10759 0 10756 5 10750 5 10748 0 10746 5 10739 5 10732 5 10731 0 10722 0 10720 0 10717 5 10712 5 10708 5 10703 5 10701 5 10694 0 10691 0 10688 0 10682 0 10677 5 10676.5 10664 5 10656 5 10654 0 10651 5 10651 0 10645 5 10643 0 10639 5 10635 5 10623 5 10609 5 10608 0 10599 5 10596 0 10590.0 10586.5 10582.5 10575.5 10574.0 10571.5 10559.5 10554.5 10553.5 10546.5 10540.5 10537.5 10531.5 10786.0 10773.5 10767.0 10762.0 10758.5 10750.0 10747.0 10741.5 10730.5 10719.5 10715.0 10710.0 10706.0 10693.0 10689.5 10675.5 10667.5 10660.0 10656.0 10650.0 10643.0 10637.0 10622.5 10609.5 10602.0 10590.0 10582.5 10575.5 10573.0 10557.0 10547.0 10541.0 10530.5 10777.0 10772.0 10769.0 10764.5 10755.0 10750.5 10740.0 10735.0 10726.5 10724.0 10705.5 10694.0 10686.5 10680.5 10660.0 10657.0 10647.5 10642.5 10614.5 10600.5 10588.0 10575.0 10559.0 10554.5 10541.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-i998 10:12 PAGE: 3O 10523.5 10524.5 10518.0 10518.5 10512.5 10514.5 10512.0 10512.5 10504.0 10501.5 10498.5 10497.5 10496.0 10494.0 10482.0 10481.0 10478.0 10476.0 10476.0 10476.0 10465.0 10464.0 10463.0 10463.0 10454.5 10456.0 10451.5 10449.5 10445.5 10440.0 10442.0 10437.0 10433.5 10435.0 10435.5 10433.0 10426.5 10431.5 10432.0 10429.0 10428.0 10427.5 10421.5 10424.5 10423.5 10422.0 10420.0 10415.5 10411.0 10414.5 10412.5 10399.0 10398.5 10396.5 10395.5 10390.5 10387.5 10387.5 10388.5 10385.5 10383.5 10369.5 10368.0 10367.5 10367.5 10362.5 10362.0 10357.0 10356.0 10352.5 10352.0 10347.5 10347.0 10344.0 10345.0 10339.5 10340 . 0 10334.5 10337.0 10334.0 10334.5 10328.0 10327.5 10322.5 10321.5 10317.0 10314.5 10309.0 10307.0 10309.5 10307.0 10303.5 10300.0 10301.5 10296.0 10293.0 10290.0 10286.5 10286.0 10280.5 10281.0 10278.0 10278.0 10281.5 10269.5 10270.0 10260.0 10259.5 10258.0 10262.0 10245.0 10246.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 31 10240.0 10241.5 10238.5 10242.0 10230.5 10235.0 10227.5 10230.0 10218.0 10221.5 10213.0 10217.0 10211.5 10215.0 10208.5 10212.5 10207.5 10208.5 10195.0 10199.0 10198.0 10180.0 10184.5 10179.0 10185.0 10177.5 10182.5 10164.5 10170.0 10161.0 10166.5 10152.0 10154.0 10147.0 10148.0 10145.0 10148.5 10141.0 10142.0 10134.5 10135.5 10140.0 10130.0 10130.0 10128.0 10128.5 10123.5 10122.5 10121.5 10123.5 10115.0 10115.5 10109.5 10110.0 I00.0 100.5 100.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BORAX PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #1 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #1 AND SIGMA BASE 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 O. 5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 32 TYPE REPR CODE VALUE .............................. 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 ** ....................................................................................... NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI. dtSS MOD ~ S~IP EL~.I CODE (HEX) DEPT FT 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM TDTP CU 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI TDTP PU-S 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF TDTP CU 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 SBHNTDTP CU 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH TDTP CU 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT TDTP 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 TCAN TDTP CPS 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF TDTP CPS 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 TCND TDTP CPS 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 TSCNTDTP CPS 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF TDTP CPS 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 INND TDTP CPS 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 INFD TDTP CPS 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 CCL TDTP V 1066347 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11626.000 SIGM. TDTP 33.649 TPHI. TDTP 92.798 SBHF. TDTP 52.953 SB~N. TDTP 58.552 SIGC. TDTP 0.000 SIBH. TDTP 105.322 TRAT. TDTP 2.526 SDSI.TDTP 0.862 BACK. TDTP 411.522 FBAC. TDTP 147.884 TCAN. TDTP 23619.453 TCAF. TDTP 5111.322 TCND. TDTP 15232.385 TCFD. TDTP 3062.760 TSCN. TDTP 2256.441 TSCF. TDTP 483.374 INND. TDTP 2231.441 INFD. TDTP 287.215 GRCH. TDTP -999.250 TENS. TDTP 25.000 CCL.TDTP 0.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 DEPT. 10109.500 SIGM. TDTP 33.989 TPHI.TDTP 42.679 SBHF. TDTP SBHN. TDTP 76.325 SIGC. TDTP 0.471 SIBH. TDTP 162.160 TRAT. TDTP SDSI.TDTP 0.884 BACK. TDTP 220.811 FBAC. TDTP 36.110 TCAN. TDTP TCAF. TDTP 3625.926 TCND. TDTP 9521.328 TCFD. TDTP 2508.534 TSCN. TDTP TSCF. TDTP 407.785 INND. TDTP 2049.498 INFD.TDTP 272.361 GRCH. TDTP TENS. TDTP 15.000 CCL.TDTP 0.000 PAGE: 33 59.213 1.579 11214.787 1144.118 66.750 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS ND?4BER : 5 DEPTH INCREFIENT: 0.5000 FILE SUMM3~Y LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11602.0 10123.0 TDTP 11630.0 10124.0 $ CURVE SHIFT DATA - PASS TO PASS (f~EAStrRED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 34 88888.0 11585.0 11583.5 11557.5 11536.5 11519.5 11512.0 11471.0 11453 0 11444 5 11442 0 11433 0 11421 0 11411 5 11411 0 11403 5 11384 5 11369 0 11365 0 11342 5 11324 5 11305 5 11283.0 11278.5 11258.5 11255.0 11248.5 11247.5 11241.5 11238.5 11230.5 11225.0 11219.0 11203.5 11190.5 11177.5 11162.0 11161.0 11136.0 11124.0 11109.0 11102.5 11088.0 11086.0 11082.5 11075.0 11069.5 11061.0 11047.5 11029.5 11028.0 11019.0 11007.5 10993.5 88892.0 88892 0 11589.0 11589 0 11583.5 11583 5 11559.5 11559 5 11539.5 11539 5 11524.0 11524 0 11512.5 11512 5 11473.0 11473 0 11461 5 11452 5 11445.5 11422.0 11410.5 11443.0 11415.5 11407.0 11391.0 11376.5 11091.0 11079.0 11069.0 11055.0 11055.0 11033.5 11034.5 11024.5 11024.5 11012.5 11012.5 11002.0 11001.0 11077.5 11089.5 11366.0 11344.0 11329.5 11329 5 11312.5 11312 5 11289.5 11289 5 11283 0 11265.5 11265 5 11258 0 11252 0 11256.5 11245.0 11248.5 11236.5 11236.5 11233.5 11233.5 11223.5 11223.5 11215.0 11215.0 11201.5 11186.0 11186.0 11168.0 11171.0 11141.0 11141.5 11131.5 11134.0 11116.5 11116.5 11111.0 11111.0 11095.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 35 10985.5 10990.0 10984.0 10991.0 10976.0 10978.0 10975.0 10982.0 10960.0 10966.0 10946.0 10951.0 10944.5 10954.5 10918.5 10928.0 10928.0 10906.0 10912.5 10912.5 10895.5 10902.5 10902.5 10883.0 10888.0 10888.0 10846.0 10858.0 10858.0 10817.5 10826.0 10826.0 10808.5 10814.0 10799.0 10807.0 10792.5 10797.0 10797.0 10767.0 10772.0 10765.5 10767.0 10764.0 10769.0 10751.0 10755.0 10747.5 10750.5 10741.5 10746.5 10740.0 10750.5 10737.0 10740.5 10732.0 10731.0 10729.5 10731.5 10726.5 10725.0 10714.0 10720.0 10712.0 10715.0 10710.5 10717.5 10702.5 10706.0 10701.0 10713.0 10691.5 10703.0 10687.0 10695.5 10685.5 10693.0 10681.5 10692.0 10672.0 10680.0 10656.5 10667.5 10649.5 10658.0 10643.0 10642.5 10633.5 10635.0 10635.0 10627.5 10630.5 10630.5 10616.0 10618.5 10618.5 10604.5 10609.0 10609.0 10598.0 10602.0 10602.0 10581.5 10585.5 10585.5 10570.5 10576.0 10576.0 10546.5 10550.5 10550.5 10540.0 10541.0 10541.0 10528.5 10530.0 10530.0 10513.0 10515.5 10515.5 10504.0 10508.5 10508.5 10478.0 10481.0 10481.0 10471.0 10475.5 10475.5 10466.5 10468.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 36 10448.5 10440.0 10444.0 10417.0 10421 . 0 10399.5 10407.5 10393.5 10390.0 10395.5 10387.5 10385.5 10370.0 10356.0 10362.0 10340.5 10350.0 10328.5 10340.5 10309.0 10308.0 10319.5 10289.0 10299.5 10279.5 10264.5 10272.0 10259.5 10267.5 10240.0 10246.5 10221.0 10228.5 10204.0 10186.5 10192.5 10167.5 10175.5 10162.5 10172.5 10144.0 10154.0 10135.5 10147.0 10125.5 10120.0 10133.0 100.0 113.0 $ 10449.0 10421.0 10392.5 10387.5 10385 5 10372 0 10362 0 10348 0 10339 5 10319 0 10299.5 10286.5 10272.0 10267 5 10246 5 10228 5 10212 0 10192 5 10175 5 10172 5 10139.5 114.0 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BORAX PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #2 AND SIGMA BASE 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 37 TYPE REPR CODE VALUE .............................. 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 ** NAFiE 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 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 SIGMTDTP CU 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI TDTP PU-S 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF TDTP CU 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 SBHNTDTP CU 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC TDTP CU 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH TDTP CU 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT TDTP 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI TDTP CU 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 BACK TDTP CPS 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 TCAN TDTP CPS 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 TCAF TDTP CPS 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 TCND TDTP CPS 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD TDTP CPS 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 TSCNTDTP CPS 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF TDTP CPS 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 INND TDTP CPS 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 INFD TDTP CPS 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH TDTP GAPI 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 TENS TDTP LB 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 CCL TDTP V 1066347 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11630.000 SIGM. TDTP 34.012 TPHI.TDTP 62.346 SBHF. TDTP SBHlV. TDTP 61.705 SIGC. TDTP 0.000 SIBH. TDTP 115.406 TRAT. TDTP SDSI.TDTP 0.800 BACK. TDTP 345.380 FBAC. TDTP 311.250 TCAN. TDTP TCAF. TDTP 7628.950 TCND. TDTP 15311.160 TCFD. TDTP 3362.238 TSCN. TDTP TSCF. TDTP 567.672 INND. TDTP 2304.172 INFD. TDTP 288.224 GRCH. TDTP TENS. TDTP 20.000 CCL.TDTP 0.000 52.686 1.977 27611.879 2118.193 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 38 DEPT. 10123.000 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 75.313 TENS. TDTP -999.250 CCL. TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 98/01/ 8 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--ER: 6 DEPTH INCREMENT: 0.5000 FILE SU~ff4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11598.5 10114.0 TDTP 11616.0 10114.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 39 BASELINE DEPTH GRCH TDTP 88888 0 11589 5 11574 0 11557 5 11557 0 11525 5 11524 0 11501 0 11462 5 11449 0 11442 5 11438 0 11410 0 11393 0 11372 0 11362 5 11354 5 11335 5 11314 5 11302 5 11284 0 11267 5 11247 5 11242 5 11221 5 11212 0 11198 5 11186 5 11181 5 11176.5 11166 0 11158 5 11143 5 11131 5 11121 0 11119 0 11106 5 11105 0 11100.0 11095.0 11091.0 11081.5 11079.0 11069.0 11067.0 11063.5 11053.0 11021.5 11010.5 10976.5 10957.0 10944.0 10940.5 88890.5 88882.0 11560.0 11524.0 11583.5 11573.5 11555.5 11527.5 11499.5 11499.5 11459.0 11459.0 11446.0 11446.0 11439.0 11439.0 11432.5 11432.5 11405.0 11405.0 11392.5 11392.5 11378.0 11378.0 11370.5 11370.5 11363.0 11363.0 11344.5 11344.5 11322.5 11322.5 11312.5 11312.5 11291.5 11276.0 11276.0 11259.0 11259.0 11249.0 11232.5 11232.5 11223.0 11223.0 11209.0 11209.0 11201.5 11199.5 11193.0 11193.0 11186.5 11186.5 11173.0 11170.5 11150.5 11150.5 11140.0 11140.0 11131.5 11131.5 11117.5 11117.5 11107.0 11096.0 11096.0 11091.0 11081.5 11081.0 11074.0 11074.0 11069.0 11064.5 11055.0 11055.0 11022.5 11022.5 11012.5 11012.5 10981.0 10981.0 10962.0 10962.0 10951.0 10951.0 10944.0 10944.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 4O 10932 5 10930 0 10922 0 10912 5 10907 5 10903 0 10899 0 10896.0 10869.5 10854.0 10823.0 10815.0 10806.5 10804 5 10780 5 10759 0 10739 0 10737 5 10733 0 10725.5 10725.0 10716.5 10698.0 10692.0 10688.5 10680.5 10669.0 10665.0 10654.5 10646.5 10636.5 10629.5 10624.0 10613.5 10605.0 10601.0 10578.5 10556.5 10523.0 10513.5 10511.5 10497.0 10480.5 10463.0 10445.0 10421.5 10407.0 10392.0 10383.5 10362.0 10346.5 10338.0 10334.5 10332.0 10319.5 10937.0 10934.0 10926.5 10912.5 10903.5 10875.5 10858.5 10826.0 10819.5 10808.0 10767.0 10751.0 10730.0 10719.5 10693.0 10672.0 10662.0 10643.0 10635.0 10630.5 10619.5 10611.5 10585.5 10557.5 10519.0 10510.0 10506.5 10494.0 10479.0 10443.5 10424.5 10409.0 10398.5 10388.5 10376.5 10362.0 10349.5 10327.5 10937.0 10934.0 10925.0 10912.5 10901.5 10875.5 10858.5 10826.0 10818.5 10806.5 10791.5 10767.0 10746.5 10739.5 10728.0 10713.5 10703.0 10695.5 10680.5 10654.5 10635.0 10630.5 10614.0 10585.5 10557.5 10519.0 10510.0 10506.5 10494.0 10479.0 10468.5 10449.5 10424.5 10409.0 10398.5 10388.5 10376.5 10362.0 10346.0 10341.5 10327.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 41 10311.5 10318.5 10289.0 10299.0 10299.0 10269.0 10278.5 10278.5 10259.5 10267.5 10267.5 10240.0 10246.5 10246.5 10222.5 10229.5 10229.5 10219.5 10226.5 10226.5 10211 . 0 10215.0 10215.0 10202.5 10208.5 10198.5 10201.0 10195.0 10197.5 10197.5 10191.0 10193.5 10177.5 10180.5 10180.5 10165.5 10166.5 10151.0 10148.5 10143.5 10142.5 10142.5 10139.0 10140.0 10140.0 10123 . 5 10123.5 10118.5 10118.5 10118.5 100.0 100.0 100.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BORAX PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #3 AND SIGMA BASE 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 42 TYPE REPR CODE VALUE 0 66 1 ** SET TYPE - CHAN ** NAFiE 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 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM TDTP CU 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI TDTP PU-S 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF TDTP CU 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 SBHN TDTP CU 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC TDTP CU 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH TDTP CU 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT TDTP 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI TDTP CU 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 BACK TDTP CPS 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC TDTP CPS 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 TCANTDTP CPS 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF TDTP CPS 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 TCND TDTP CPS 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD TDTP CPS 1066347 O0 000 O0 0 6 i 1 4 68 0000000000 TSCNTDTP CPS 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF TDTP CPS 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 INND TDTP CPS 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 INFD TDTP CPS 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH TDTP GAPI 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 TENS TDTP LB 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 CCL TDTP V 1066347 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 11616.000 SIGM. TDTP 34 SBHN. TDTP 58.661 SIGC. TDTP 0 SDSI. TDTP 1.357 BACK. TDTP 283 TCAF. TDTP 4596.231 TCND. TDTP 12222 TSCF. TDTP 419.521 INND. TDTP 1787 TENS. TDTP 25.000 CCL.TDTP 0 DEPT. 10114.000 SIGM. TDTP 35. SBHN. TDTP 76.114 SIGC. TDTP O. SDSI. TDTP 1.059 BACK. TDTP 221. TCAF. TDTP 3427.809 TCND. TDTP 9882. TSCF. TDTP 368.295 INND. TDTP 1984. TENS. TDTP 25.000 CCL. TDTP O. 739 TPHI. TDTP 70. 950 SBHF. TDTP 52. 746 151 SIBH. TDTP 105. 671 TRAT. TDTP 2. 114 423 FBAC. TDTP 130. 380 TCAN. TDTP 18192. 676 250 TCFD. TDTP 2664. 854 TSCN. TDTP 1652.3 65 650 INFD. TDTP 257. 809 GRCH. TDTP -999. 250 000 125 TPHI. TDTP 45. 535 SBHF. TDTP 59. 689 458 SIBH. TDTP 161. 483 TRAT. TDTP 1. 604 172 FBAC. TDTP 38. 471 TCAN. TDTP 11069. 695 709 TCFD. TDTP 2550. 680 TSCN. TDTP 1087. 933 671 INFD. TDTP 274. 861 GRCH. TDTP 67. 563 000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 43 **** FILE TRAILER **** FILE NA~E : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 7 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER: 7 DEPTH INCREMENT: 0.5000 FILE SU~FIARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11606.5 10097.0 TDTP 11628.0 10102.0 $ CURVE SHIFT DATA - PASS TO PASS (FIEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS ND?4~ER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88898.5 88894.0 11587.5 11593.5 11585.0 11587.0 11577.0 11580.0 11574.5 11585.0 11571.5 11573.0 11567.5 11578.0 11550.0 11558.5 11548.5 11555.5 11545.5 11548.5 11545.0 11555.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 44 11536.0 11542.5 11529.5 11536.5 11528.5 11532.5 11525.0 11527.0 11510.5 11524.5 11493.5 11502.5 11476.0 11485.0 11461.5 11473.0 11445.5 11457.5 11442.0 11452.5 11438.5 11452.5 11419.0 11430.0 11405.5 11411.5 11397.5 11402.5 11394.5 11402.5 11386.5 11398.0 11381.0 11388.0 11375.0 11388.5 11366.5 11376.0 11378.5 11359.0 11366.0 11358.5 11370.0 11342.5 11353.0 11336.5 11346.5 11333.0 11342.0 11322.5 11330.5 11320.0 11332.0 11308.5 11317.0 11305.0 11313.0 11298.0 11305.5 11293.0 11300.0 11285.0 11295.0 11283.0 11291.0 11282.0 11291.5 11275.5 11281.5 11272.0 11272.0 11269.0 11267 . 5 11268.5 11273.5 11257 . 0 11265.5 11256.5 11255.5 11249.0 11249.0 11238.5 11248.5 11238.0 11241.0 11226.0 11234.0 11225.0 11234.0 11221.5 11229.5 11216.5 11227.0 11214.0 11223.5 11206.0 11219.0 11199.0 11211.5 11198.5 11210.0 11193.0 11203.5 11191.5 11204.5 11184.0 11197.0 11182.5 11192.5 11180.5 11188.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 45 11172.5 11170.0 11167.0 11158.5 11156.5 11150.0 11147.0 11137.5 11135.5 11125.5 11124.5 11111 5 11103 5 11092 5 11087 0 11079 0 11072 5 11072 0 11067.0 11055.0 11049.0 11028.0 11021.5 11009.0 11000.5 10996.0 10989.5 10977.5 10965.0 10955.0 10943.0 10942.0 10934.0 10914.5 10911.5 10892.0 10878.0 10872.0 10859.0 10850.0 10842.0 10832.0 10815.5 10814.5 10812.0 10808.0 10796.0 10789.5 10782.5 10772.5 10769.5 10757.0 10755.5 10747.5 10744.5 11178.5 11175.5 11173.0 11165.5 11156.0 11145.0 11137.5 11114.5 11102.5 11096.0 11080.0 11059.0 11037.0 11018.0 11007.5 10987.0 10964.5 10950.0 10938.0 10913.0 10900.0 10882.0 10867.5 10851.5 10844.5 10823.0 10817.0 10792.0 10782.5 10766.5 10755.5 11171.0 11165.0 11147.5 11133.5 11119.5 11091.0 11082.5 11077.5 11064.5 11032.5 11009.0 10995.5 10970.5 10954.0 10924.5 10882.0 10848.5 10826.0 10819.0 10806.0 10797.5 10779.5 10767.0 10759.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 46 10739.0 10734.5 10730.5 10720.5 10718.0 10709.5 10707.5 10700.0 10692.0 10690.0 10676.0 10674.5 10667.0 10666.5 10659.0 10644.0 10642.0 10627.5 10617 5 10610 5 10609 0 10605 0 10604 0 10600 5 10594 0 10585 5 10581 0 10577 0 10571 5 10568.0 10566.5 10561.0 10560.0 10553.0 10549.5 10549.0 10545.0 10542.0 10539.5 10528.0 10523.0 10515.5 10504.5 10502.5 10492.0 10468.0 10466.5 10457.0 10454.0 10448.5 10441.5 10428.5 10416.0 10412.0 10405.0 10743.5 10731.0 10717.5 10702.0 10700.0 10686.0 10675.0 10668.0 10655.5 10635.5 10610.5 10607.0 10590.0 10571.5 10565.5 10555.5 10546.0 10543.0 10526.5 10506.0 10469.0 10457.5 10445.5 10435.0 10423.5 10413.5 10750.5 10741.5 10731.0 10718.5 10706.0 10685.0 10681.0 10654.0 10628 5 10620 0 10615 0 10606.0 10600 5 10593 0 10588.0 10581 0 10575.5 10566.5 10562.5 10559.0 10555.0 10540.5 10525.5 10514.5 10506.0 10478.5 10465.0 10453.5 10433.0 10421.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 47 10398.0 10410.5 10392.0 10402.5 10375.5 10387.5 10372.0 10383.5 10365.5 10374.5 10353.0 10367.5 10348.5 10352.0 10340.5 10349.5 10336.0 10339.5 10319.5 10324.0 10318.5 10324.0 10289.0 10299.5 10287.0 10292.5 10277.5 10281.5 10265.5 10270.0 10259.0 10264.5 10253.5 10258.5 10250.5 10249.5 10247.5 10252.0 10237.0 10235.5 10231.5 10233.5 10226.5 10229.0 10218.5 10222.0 10206.0 10209.0 10204.0 10207.5 10184.0 10184.5 10167.0 10167.5 10165.0 10169.0 10156.5 10160.5 10136.5 10140.5 10132.5 10139.5 10127.5 10132.5 10115.0 10120.0 10107.0 10116.5 10097.5 10107.5 100.0 105.0 110.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP FLOWING PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH FLOWING PASS #1 AND GRCH BASE PASS #1, ALSO SIGMA FLOWING PASS #1 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 48 ** 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 ** NAIVE SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 SIGMTDTP CU 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI TDTP PU-S 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF TDTP CU 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 SBH~TDTP CU 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC TDTP CU 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH TDTP CU 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT TDTP 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI TDTP CU 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 BACK TDTP CPS 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC TDTP CPS 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 TCAN TDTP CPS 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 TCAF TDTP CPS 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 TCND TDTP CPS 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD TDTP CPS 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 TSCNTDTP CPS 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF TDTP CPS 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 INND TDTP CPS 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 INFD TDTP CPS 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH TDTP GAPI 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 TENS TDTP LB 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 CCL TDTP V 1066347 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 49 ** DATA ** DEPT. 11628. 000 SIGM. TDTP SBHN. TDTP 52. 643 SIGC. TDTP SDSI . TDTP 1 . 170 BACK. TDTP TCAF. TDTP 6717. 826 TCND. TDTP TSCF. TDTP 765. 719 INND. TDTP TENS. TDTP 20. 000 CCL. TDTP DEPT. 10097.000 SIGM. TDTP SBH~.TDTP -999.250 SIGC. TDTP SDSI.TDTP -999.250 BACK. TDTP TCAF. TDTP -999.250 TCND. TDTP TSCF. TDTP -999.250 INND. TDTP TENS. TDTP -999.250 CCL.TDTP 34.151 TPHI.TDTP 51.983 SBHF. TDTP 41.967 0.000 SIBH. TDTP 86.427 TRAT. TDTP 1.828 159.689 FBAC. TDTP 90.225 TCAN. TDTP 22096.340 15744.125 TCFD.TDTP 4096.075 TSCN. TDTP 2415.242 2473.027 INFD. TDTP 339.054 GRCH. TDTP -999.250 0.000 -999. 250 TPHI. TDTP -999. 250 SBHF. TDTP -999. 250 -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 -999.250 TCFD. TDTP -999. 250 TSCN. TDTP -999.250 -999. 250 INFD. TDTP -999. 250 GRCH. TDTP 47. 063 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~BER: 8 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 INCRE~F2FT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUFiBERS TDTP 1, 2, 3, $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 5O REMARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES 1,2, &3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** 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 ** NAIVE SERV UNIT SERVICE API API API API FILE NUmB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM PNAV CU 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PNAV PU-S 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 SBHF PNAV CU 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 SBt{NPNAV CU 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 SIGC PNAV CU 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 SIBH PNAV CU 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PNAV 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 SDSI PNAV CU 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 BACK TDTP CPS 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC TDTP CPS 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 TCANPNAV CPS 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 TCAF PNAV CPS 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 TCND PNAV CPS 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 TCFD PNAV CPS 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 TSCN PNAV CPS 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 51 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) TSCF PNAV CPS 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 INND PNAV CPS 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 INFD PNAV CPS 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 GRCH TDTP GAPI 1066347 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 11621.000 SIGM. PNAV 34.446 TPHI.PNAV 58.682 SBHF. PNAV SBP~N. PNAV 58.808 SIGC. PNAV 0.403 SIBH. PNAV 106.148 TRAT. PNAV SDSI. PNAV 1.089 BACK. TDTP 147.426 FBAC. TDTP 65.132 TCAN. PNAV TCAF. PNAV 4675.786 TCND.PNAV 14569.063 TCFD. PNAV 3358.198 TSCN. PNAV TSCF. PNAV 523.215 INND.PNAV 2305. 784 INFD.PNAV 286.331 GRCH. TDTP 49. 099 1. 902 16919.242 1837. 073 -999.250 DEPT. 10095.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SB~ZN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI. PNAV -999.250 BACK. TDTP 190.853 FBAC. TDTP 31.207 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD. PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~BER RAW CURVES LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 52 Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREP~NT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 11640.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : STOP DEPTH 10095.5 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 TDTP GAM~A RAY SOURCE TDTP PROD. LOGGING HOUSING TDTP TDTP DETECTOR CART TDTP TDTP TOOLS TDTP FULL BORE SPINNER $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE 29-NOV-97 CP 44.2 1538 29-NOV-97 11644.0 11635.0 10100.0 11635.0 1800.0 NO TOOL NUMBER CGRS-A-862 CPLH-A-999 TDIC-A-843 TDT SET 21 FBS-B-1879 5577.0 VARIOUS 40.0 THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 53 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): 11000 NEJL~ COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1 TIED IN TO DRILLERS CASING TALLEY AND ANADRILL ADN4 16-SEP 60 FPM AND 90 FPM FLOWING DOWN PASSES WERE MADE WITH THE SPINNER AND A 30 FPM UP PASS WITH BOTH SPINNER AND TDTP WERE MADE. THE 60 FPM DOWN PASS WAS MADE BEFORE THE WELL HAD STABILIZED AFTER RE-OPENING WELL TO FLOW. SINCE THE CHARACTER OF THE CURVE WAS THE SAME, ANOTHER 60 FPM DOWN PASS WAS NOT MADE. THE APPROXIMATE PRODUCTION RATE WHILE LOGGING WAS 7000 TO 10000 MCF/D. 250 BBLS OF SEAWATER WAS PUMPED PRIOR TO LOGGING THE FIRST BASELINE TDTP PASS. THE INJECTION RATE DURING THE BASELINE PASSES WAS 1 BPM. 250 BBLS OF BORAX/WATER WAS PUMPED AT 3 BPM PRIOR TO LOGGING THE BORAX TDTP PASSES. AN INHERENT CHARACTERISTIC OF SPINNERS RUN BELOW TDTP IS THAT WHEN THE SPINNER STOPS TURNING, THE COUNTS JUMP TO OVER 300 RPS. AS THE FULLBORE CAGE CLOSES DOWN OR THE TOOL STOPS MOVING, A FALSE RPS INCREASE OCCURS. APPROXIMATE PRODUCTION SPLITS: 10194-10444'=0~, 10694-11196'=81%, 11244-11644'=19% SPINNER SHOWS MOST OF PRODUCTION FROM UPPPER 150' AND LOWER 120' OF MIDDLE PERFORATION INTERVAL. THE BORAX LOG AGREES CLOSELY WITH THE SPINNER DATA. THE BORAX LOG TENDS TO INDICATE THAT THE UPPER SET OF PERFS IS MORE PERMEABLE THAN THE LOWER. $ 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 54 TYPE REPR CODE VALUE 9 65 FT 1i 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUFIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT 1066347 O0 000 O0 0 9 1 1 4 SIGM PS1 CU 1066347 O0 000 O0 0 9 1 1 4 TPHI PS1 PU 1066347 O0 000 O0 0 9 1 1 4 SBHF PS1 CU 1066347 O0 000 O0 0 9 1 1 4 SBPiNPS1 CU 1066347 O0 000 O0 0 9 1 1 4 SIGC PS1 CU 1066347 O0 000 O0 0 9 1 1 4 SIBH PS1 CU 1066347 O0 000 O0 0 9 1 1 4 TRAT PS1 1066347 O0 000 O0 0 9 1 1 4 SDSI PS1 CU 1066347 O0 000 O0 0 9 1 1 4 BACK PS1 CPS 1066347 O0 000 O0 0 9 1 1 4 FBAC PS1 CPS 1066347 O0 000 O0 0 9 1 1 4 TCANPS1 CPS 1066347 O0 000 O0 0 9 1 1 4 TCAFPS1 CPS 1066347 O0 000 O0 0 9 1 1 4 TCND PS1 CPS 1066347 O0 000 O0 0 9 1 1 4 TCFD PS1 CPS 1066347 O0 000 O0 0 9 1 1 4 TSCN PSl CPS 1066347 O0 000 O0 0 9 1 1 4 TSCF PS1 CPS 1066347 O0 000 O0 0 9 1 1 4 INND PS1 CPS 1066347 O0 000 O0 0 9 1 1 4 INFD PS1 CPS 1066347 O0 000 O0 0 9 1 1 4 TENS PS1 LB 1066347 O0 000 O0 0 9 1 1 4 GR PS1 GAPI 1066347 O0 000 O0 0 9 1 1 4 CCL PS1 V 1066347 O0 000 O0 0 9 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 ** DATA ** DEPT. 11640.000 SIGM. PS1 22.721 TPHI.PS1 SBPiN. PS1 123.357 SIGC. PS1 0.000 SIBH. PS1 SDSI.PS1 2.142 BACK. PSi 53.228 FBAC. PS1 TCAF. PS1 0.000 TCND.PS1 -627.415 TCFD.PS1 TSCF. PS1 0.000 INND.PS1 -1.809 INFD.PS1 GR.PS1 41.938 CCL.PS1 0.043 0.000 SBHF. PS1 169.913 TRAT. PS1 22.278 TCAN. PS1 -261.071 TSCN. PS1 -0.757 TENS.PSi 83.169 0.000 0.000 0.000 15.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 55 DEPT. 10095.500 SIGM. PS1 SBHN. PS1 54.025 SIGC. PS1 SDSI.PS1 0.778 BACK. PSi TCAF. PS1 5637.716 TCND.PS1 TSCF. PS1 619.086 INND.PS1 GR.PS1 46.781 CCL.PS1 34.350 TPHI.PS1 1.059 SIBH. PS1 190.853 FBAC. PS1 16397.055 TCFD.PS1 2311.098 INFD.PS1 0.000 54.227 SBHF. PS1 90.844 TRAT. PS1 31.207 TCAN. PS1 3848.799 TSCN. PS1 282.624 TENS. PSi 46.508 1. 851 20163. 730 2061. 533 25. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE · FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUM~ER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INC~: O. 5000 FILE SUI~/iARY VENDOR TOOL CODE START DEPTH ........................... TDTP 11638.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~IE LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : STOP DEPTH 10096.0 29-NOV-97 CP 44.2 1538 29-NOV-97 11644.0 11635.0 10100.0 11635.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 56 LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP TDTP TDTP TDTP TDTP $ GAM~A RAY SOURCE PROD. LOGGING HOUSING TDTP DETECTOR CART TDTP TOOLS FULL BORE SPINNER TOOL NUMBER ........... CGRS-A-862 CPLH-A-999 TDIC-A-843 TDT SET 21 FBS-B-18?9 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 5577.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TE~IPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : VARIOUS 40.0 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 (F~: BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 11000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2 TIED IN TO DRILLERS CASING TALLEY AND ANADRILL ADN4 16-SEP 60 FPM AND 90 FPM FLOWING DOWN PASSES WERE MADE WITH THE SPINNER AND A 30 FPM UP PASS WITH BOTH SPINNER AND TDTP WERE MADE. THE 60 FPM DOWN PASS WAS MADE BEFORE THE WELL HAD STABILIZED AFTER RE-OPENING WELL TO FLOW. SINCE THE CHARACTER OF THE CURVE WAS THE SAME, ANOTER 60 FPM DOW PASS WAS NOT MADE. THE APPROXIMATE PRODUCTION RATE WHILE LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 57 LOGGING WAS 7000 TO 10000 MCF/D. 250 BBLS OF SEAWATER WAS PUMPED PRIOR TO LOGGING THE FIRST BASELINE TDTP PASS. THE INJECTION RATE DURING THE BASELINE PASSES WAS 1 BPM. 250 BBLS OF BORAX/WATER WAS PUMPED AT 3 BPM PRIOR TO LOGGING THE BORAX TDTP PASSES. AN INHERENT CHARACTERISTIC OF SPINNERS RUN BELOW TDTP IS THAT WHEN THE SPINNER STOPS TURNING, THE COUNTS JUMP TO OVER 300 RPS. AS THE FULLBORE CAGE CLOSES DOWN OR THE TOOL STOPS MOVING, A FALSE RPS INCREASE OCCURS. APPROXIMATE PRODUCTION SPLITS: 10194-10444'=0%, 10694-11196'=81%, 11244-11644'=19% SPINNER SHOWS MOST OF PRODUCTION FROM UPPPER 150' AND LOWER 120' OF MIDDLE PERFORATION INTERVAL. THE BORAX LOG AGREES CLOSELY WITH THE SPINNER DATA. THE BORAX LOG TENDS TO INDICATE THAT THE UPPER SET OF PERFS IS MORE PERI~_~ABLE THAN THE LOWER. $ 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 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFiE SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM PS2 CU 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI PS2 PU 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PA GE: 58 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) SBHF PS2 CU 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 SBHNPS2 CU 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 SIGC PS2 CU 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 SIBH PS2 CU 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT PS2 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 SDSI PS2 CU 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 BACK PS2 CPS 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC PS2 CPS 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 TCANPS2 CPS 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 TCAFPS2 CPS 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 TCND PS2 CPS 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 TCFD PS2 CPS 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 TSCN PS2 CPS 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 TSCF PS2 CPS 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 INND PS2 CPS 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 INFD PS2 CPS 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 TENS PS2 LB 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 GR PS2 GAPI 1066347 O0 000 O0 0 10 i 1 4 68 0000000000 CCL PS2 V 1066347 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 11638.500 SIGM. PS2 34.350 TPHI.PS2 54.227 SBHF. PS2 SBHN. PS2 54.025 SIGC. PS2 1.059 SIBH. PS2 90.844 TRAT. PS2 SDSI.PS2 0.778 BACK. PS2 190.853 FBAC. PS2 31.207 TCAN. PS2 TCAF. PS2 5637.716 TCND. PS2 16397.055 TCFD. PS2 3848.799 TSCN. PS2 TSCF. PS2 619.086 INND. PS2 2311.098 INFD. PS2 282.624 TENS.PS2 GR.PS2 274.500 CCL.PS2 0.021 DEPT. 10096.000 SIGM. PS2 34.807 TPHI.PS2 60.518 SBHF. PS2 SBh~V. PS2 53.640 SIGC. PS2 1.046 SIBH. PS2 89.613 TRAT. PS2 SDSI.PS2 0.823 BACK. PS2 224.503 FBAC. PS2 38.866 TCAN. PS2 TCAF. PS2 5207.804 TCND.PS2 16603.551 TCFD. PS2 3751.097 TSCN. PS2 TSCF. PS2 568.706 INND.PS2 2347.508 INFD.PS2 296.093 TENS.PS2 GR.PS2 55.281 CCL. PS2 0.000 46.508 1. 851 20163. 730 2061. 533 25. 000 45.854 1.959 19940.621 2028.330 25.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 59 **** FILE TRAILER **** FILE NAFiE : EDIT . O10 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : TDTP LOG HEADER DATA FILE HEADER FILE NUMBER 11 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 STOP DEPTH 11639.0 10104.0 DATE LOGGED: 29 -NOV- 97 SOFTWARE VERSION: CP 44.2 TI~E LOGGER ON BOTTOM: 1538 29-NOV-97 TD DRILLER (FT) : 11644.0 TD LOGGER (FT) : 11635.0 TOP LOG INTERVAL (FT): 10100.0 BOTTOM LOG INTERVAL (FT) : 11635.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER TDTP GAlV~fA RAY SOURCE CGRS-A-862 TDTP PROD. LOGGING HOUSING CPLH-A-999 TDTP TDTP DETECTOR CART TDIC-A- 843 TDTP TDTP TOOLS TDT SET 21 TDTP FULL BORE SPINNER FBS-B-1879 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 6O BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 5577.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TE~IPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : VARIOUS 40.0 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): 11000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #3 TIED IN TO DRILLERS CASING TALLEY AND ANADRILL ADN4 16-SEP 60 FPM AND 90 FPM FLOWING DOWN PASSES WERE MADE WITH THE SPINNER AND A 30 FPM UP PASS WITH BOTH SPINNER AND TDTP WERE MADE. THE 60 FPM DOWN PASS WAS MADE BEFORE THE WELL HAD STABILIZED AFTER RE-OPENING WELL TO FLOW. SINCE THE CHARACTER OF THE CURVE WAS THE SAME, ANOTER 60 FPM DOW PASS WAS NOT MADE. THE APPROXIMATE PRODUCTION RATE WHILE LOGGING WAS 7000 TO 10000 MCF/D. 250 BBLS OF SEAWATER WAS PUMPED PRIOR TO LOGGING THE FIRST BASELINE TDTP PASS. THE INJECTION RATE DURING THE BASELINE PASSES WAS 1 BPM. 250 BBLS OF BORAX/WATER WAS PUMPED AT 3 BPM PRIOR TO LOGGING THE BORAX TDTP PASSES. AN INHERENT CHARACTERISTIC OF SPINNERS RUN BELOW TDTP IS THAT WHEN THE SPINNER STOPS TURNING, THE COUNTS JUMP TO OVER 300 RPS. AS TME FULLBORE CAGE CLOSES DOWN OR THE TOOL STOPS MOVING, A FALSE RPS INCREASE OCCURS. APPROXIMATE PRODUCTION SPLITS: 10194-10444'=0%, 10694-11196' =81%, 11244-11644'=19% SPINNER SHOWS MOST OF PRODUCTION FROM UPPPER 150' AND LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 61 LOWER 120' OF MIDDLE PERFORATION INTERVAL. THE BORAX LOG AGREES CLOSELY WITH THE SPINNER DATA. THE BORAX LOG TENDS TO INDICATE THAT THE UPPER SET OF PERFS IS MORE P~LE THAN THE LOWER. $ 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 $ 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 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~ 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 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM PS3 CU 1066347 O0 000 O0 0 1i 1 1 4 68 0000000000 TPHI PS3 PU 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 SBHF PS3 CU 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 SBPiNPS3 CU 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 SIGC PS3 CU 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 SIBH PS3 CU 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT PS3 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 SDSI PS3 CU 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 BACK PS3 CPS 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 FBAC PS3 CPS 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 TCANPS3 CPS 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 TCAFPS3 CPS 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 TCND PS3 CPS 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 TCFDPS3 CPS 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 62 NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TSCN PS3 CPS 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 TSCF PS3 CPS 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 INNDPS3 CPS 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 INFD PS3 CPS 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 TENS PS3 LB 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 GR PS3 GAPI 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 CCL PS3 V 1066347 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. 11639.000 SIGM. PS3 34.807 TPHI.PS3 60.518 SBHF. PS3 45.854 SBHN. PS3 53.640 SIGC. PS3 1.046 SIBH. PS3 89.613 TRAT. PS3 1.959 SDSI.PS3 0.823 BACK. PS3 224.503 FBAC. PS3 38.866 TCAN. PS3 19940.621 TCAF. PS3 5207.804 TCND. PS3 16603.551 TCFD.PS3 3751.097 TSCN. PS3 2028.330 TSCF. PS3 568.706 INND.PS3 2347.508 INFD.PS3 296.093 TENS.PS3 15.000 GR.PS3 224.250 CCL.PS3 0.035 DEPT. 10104 000 SIGM. PS3 30.565 TPHI.PS3 49.669 SBHF. PS3 45.755 SBHN. PS3 53 121 SIGC. PS3 1.223 SIBH. PS3 87.955 TRAT. PS3 1.896 SDSI.PS3 0 689 BACK. PS3 234.469 FBAC. PS3 37.215 TCAN. PS3 23908.211 TCAF. PS3 6844 927 TCND. PS3 17348.191 TCFD.PS3 4217.702 TSCN. PS3 2551.838 TSCF. PS3 794 561 INND.PS3 2157.200 INFD.PS3 293.744 TENS.PS3 20.000 GR.PS3 64 438 CCL.PS3 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAlVlE : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAi~E : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 63 FILE HEADER FILE NUMBER 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMzARY VENDOR TOOL CODE START DEPTH TDTP 11639.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~E LOGGER ON BOTTOM: TD DRILLER (FT) : STOP DEPTH 10105.0 TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 29-NOV-97 CP 44.2 1538 29-NOV-97 11644.0 11635.0 10100.0 11635.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER TDTP GAMMA RAY SOURCE CGRS-A-862 TDTP PROD. LOGGING HOUSING CPLH-A-999 TDTP TDTP DETECTOR CART TDIC-A-843 TDTP TDTP TOOLS TDT SET 21 TDTP FULL BORE SPINNER FBS-B-1879 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL)'. MATRIX: MATRIX DENSITY: 5577.0 VARIOUS 40.0 THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 64 HOLE CORRECTION (IN): 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): 11000 ~ COUNT RATE LOW SCALE (CPS): 0 ~ COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #1 TIED IN TO DRILLERS CASING TALLEY AND ANADRILL ADN4 16-SEP 60 FPM AND 90 FPM FLOWING DOWN PASSES WERE MADE WITH THE SPINNER AND A 30 FPM UP PASS WITH BOTH SPINNER AND TDTP WERE MADE. THE 60 FPM DOWN PASS WAS MADE BEFORE THE WELL HAD STABILIZED AFTER RE-OPENING WELL TO FLOW. SINCE THE CHARACTER OF THE CURVE WAS THE SAME, ANOTER 60 FPM DOW PASS WAS NOT MADE. THE APPROXIMATE PRODUCTION RATE WHILE LOGGING WAS 7000 TO 10000 MCF/D. 250 BBLS OF SEAWATER WAS PUMPED PRIOR TO LOGGING THE FIRST BASELINE TDTP PASS. THE INJECTION RATE DURING THE BASELINE PASSES WAS 1 BPM. 250 BBLS OF BORAX/WATER WAS PUMPED AT 3 BPM PRIOR TO LOGGING THE BORAX TDTP PASSES. AN INHERENT CHARACTERISTIC OF SPINNERS RUN BELOW TDTP IS THAT WHEN THE SPINNER STOPS TURNING, THE COUNTS JUMP TO OVER 300 RPS. AS THE FULLBORE CAGE CLOSES DOWN OR THE TOOL STOPS MOVING, A FALSE RPS INCREASE OCCURS. APPROXIMATE PRODUCTION SPLITS: 10194-10444'=0%, 10694-11196'=81%, 11244-11644'=19% SPINNER SHOWS MOST OF PRODUCTION FROM UPPPER 150' AND LOWER 120' OF MIDDLE PERFORATION INTERVAL. THE BORAX LOG AGREES CLOSELY WITH THE SPINNER DATA. THE BORAX LOG TENDS TO INDICATE THAT THE UPPER SET OF PERFS IS MORE PEPJVZEABLE THAN THE LOWER. $ 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 65 TYPE REPR CODE VALUE 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 ** NAiVlE 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 ?T 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 SIGM BX1 CU 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI BX1 PU 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 SBHF BX1 CU 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 SBHNBX1 CU 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 SIGC BX1 CU 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 SIBH BX1 CU 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT BX1 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 SDSI BX1 CU 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 BACK BX1 CPS 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 FBAC BX1 CPS 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 TCANBX1 CPS 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 TCAFBX1 CPS 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 TCNDBX1 CPS 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 TCFDBX1 CPS 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 TSCN BX1 CPS 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 TSCF BX1 CPS 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 INNDBX1 CPS 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 INFD BX1 CPS 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 TENS BX1 LB 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 GR BX1 GAPI 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 CCL BX1 V 1066347 O0 000 O0 0 12 1 1 4 68 0000000000 ** DATA ** DEPT. 11639.000 SIGM. BX1 42.680 TPHI.BX1 86.712 SBHF. BX1 57.710 SB~N. BX1 60.661 SIGC. BX1 0.000 SIBH.BX1 112.065 TRAT. BX1 2.082 SDSI.BX1 1.034 BACK. BX1 356.427 FBAC.BX1 342.808 TCAN. BX1 14932.486 TCAF. BX1 3315.159 TCND.BX1 12688.365 TCFD.BX1 2374.418 TSCN. BX1 1155.879 TSCF. BX1 227.580 INND.BX1 1979.548 INFD.BX1 258.278 TENS.BX1 15.000 GR.BX1 133.500 CCL.BX1 0.048 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 66 DEPT. 10105.000 SIGM. BX1 30.805 TPHI.BX1 SBHN. BX1 76.311 SIGC.BX1 0.272 SIBH.BX1 SDSI.BX1 0.706 BACK. BX1 224.983 FBAC.BX1 TCAF. BX1 4445.644 TCND.BX1 10373.947 TCFD.BX1 TSCF. BX1 521.079 INND.BX1 2017.618 INFD.BX1 GR.BX1 59.375 CCL.BX1 0.000 42.208 SBHF. BX1 162.114 TRAT. BX1 39.166 TCAN. BX1 2811.969 TSCN. BX1 272.701 TENS.BX1 58.142 1.671 13474.096 1488.502 25.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFIE : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUM~ER 13 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUF~zARY VENDOR TOOL CODE START DEPTH TDTP 11639.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): STOP DEPTH 10103.0 29-NOV-97 CP 44.2 1538 29-NOV-97 11644.0 11635.0 10100.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PA GE: 67 BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 11635.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP TDTP TDTP TDTP TDTP $ GAM~A RAY SOURCE PROD. LOGGING HOUSING TDTP DETECTOR CART TDTP TOOLS FULL BORE SPINNER TOOL NUMBER ........... CGRS-A - 862 CPLH-A- 999 TDIC-A- 843 TDT SET 21 FBS-B-1879 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 5577.0 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) : VARIOUS 40.0 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): 11000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #2 TIED IN TO DRILLERS CASING TALLEY AND ANADRILL ADN4 16-SEP 60 FPM AND 90 FPM FLOWING DOWN PASSES WERE MADE WITH THE SPINNER AND A 30 FPM UP PASS WITH BOTH SPINNER AND TDTP WERE MADE. THE 60 FPM DOWN PASS WAS MADE BEFORE THE WELL HAD STABILIZED AFTER RE-OPENING WELL TO FLOW. SINCE THE CHARACTER OF THE CURVE WAS THE SAME, ANOTER 60 FPM DOW LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 68 PASS WAS NOT MADE. THE APPROXIMATE PRODUCTION RATE WHILE LOGGING WAS 7000 TO 10000 MCF/D. 250 BBLS OF SEAWATER WAS PUMPED PRIOR TO LOGGING THE FIRST BASELINE TDTP PASS. THE INJECTION RATE DURING THE BASELINE PASSES WAS 1 BPM. 250 BBLS OF BORAX/WATER WAS PUMPED AT 3 BPM PRIOR TO LOGGING THE BORAX TDTP PASSES. AN INHERENT CHARACTERISTIC OF SPINNERS RUN BELOW TDTP IS THAT WHEN THE SPINNER STOPS TURNING, THE COUNTS JUMP TO OVER 300 RPS. AS THE FULLBORE CAGE CLOSES DOWN OR THE TOOL STOPS MOVING, A FALSE RPS INCREASE OCCURS. APPROXIMATE PRODUCTION SPLITS: 10194-10444'=0%, 10694-11196'=81%, 11244-11644'=19% SPINNER SHOWS MOST OF PRODUCTION FROM UPPPER 150' AND LOWER 120' OF MIDDLE PERFORATION INTERVAL. THE BORAX LOG AGREES CLOSELY WITH THE SPINNER DATA. THE BORAX LOG TENDS TO INDICATE THAT THE UPPER SET OF PERFS IS MORE PERMEABLE THAN THE LOWER. $ 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 ** NA~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 1066347 O0 000 00 0 13 1 1 4 68 0000000000 SIGM BX2 CU 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 69 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) TPHI BX2 PU 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 SBHF BX2 CU 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 SBPINBX2 CU 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 SIGC BX2 CU 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 SIBH BX2 CU 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT BX2 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 SDSI BX2 CU 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 BACK BX2 CPS 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 FBAC BX2 CPS 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 TCANBX2 CPS 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 TCAFBX2 CPS 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 TCNDBX2 CPS 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 TCFDBX2 CPS 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 TSCNBX2 CPS 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 TSCF BX2 CPS 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 INNDBX2 CPS 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 INFDBX2 CPS 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 TENS BX2 LB 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 GR BX2 GAPI 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 CCL BX2 V 1066347 O0 000 O0 0 13 1 1 4 68 0000000000 ** DATA ** DEPT. 11639.000 SIGM. BX2 30.805 TPHI.BX2 42.208 SBHF. BX2 58.142 SBHN~BX2 76.311 SIGC. BX2 0.272 SIBH. BX2 162.114 TRAT. BX2 1.671 SDSI.BX2 0.706 BACK. BX2 224.983 FBAC.BX2 39.166 TCAN. BX2 13474.096 TCAF. BX2 4445.644 TCND.BX2 10373.947 TCFD.BX2 2811.969 TSCN. BX2 1488.502 TSCF. BX2 521.079 INND.BX2 2017.618 INFD.BX2 272.701 TENS.BX2 20.000 GR.BX2 335.500 CCL.BX2 0.000 DEPT. 10103.000 SIGM. BX2 31.539 TPHI.BX2 44.329 SBHF.BX2 65.385 SBPiN. BX2 77.696 SIGC.BX2 0.330 SIBH. BX2 166.544 TRAT. BX2 1.694 SDSI.BX2 0.794 BACK.BX2 222.509 FBAC.BX2 34.558 TCAN. BX2 12360.631 TCAF. BX2 3890.982 TCND.BX2 10081.303 TCFD.BX2 2696.749 TSCN. BX2 1351.397 TSCF. BX2 456.650 INND.BX2 2212.195 INFD.BX2 268.239 TENS.BX2 15.000 GR.BX2 56.219 CCL.BX2 0.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 7O **** FILE TRAILER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION ' O01CO1 DATE · 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT . O14 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArUFiBER 14 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUPIBER: 6 DEPTH INCREFiENT: 0.5000 FILE SUF~W_ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11639.0 10103.0 TDTP LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIFIE 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 TDTP TDTP TDTP TDTP TDTP $ GAMMA RAY SOURCE PROD. LOGGING HOUSING TDTP DETECTOR CART TDTP TOOLS FULL BORE SPINNER 29 -NOV- 97 CP 44.2 1538 29-NOV-97 11644.0 11635.0 10100.0 11635.0 1800.0 NO TOOL NURSER ........... CGRS-A-862 CPLH-A-999 TDIC-A-843 TDT SET 21 FBS-B-1879 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 71 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): L~ERS CASING DEPTH (FT) : 5577.0 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) : VARIOUS 40.0 NDUTRON 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): 11000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #3 TIED IN TO DRILLERS CASING TALLEYAND ANADRILL ADN4 16-SEP 60 FPMAND 90 FPM FLOWING DOWN PASSES WERE MADE WITH THE SPINNER AND A 30 FPM UP PASS WITH BOTHSPINNER AND TDTP WERE MADE. THE 60 FPM DOWN PASS WAS MADE BEFORE THE WELL HAD STABILIZED AFTER RE-OPENING WELL TO FLOW. SINCE THE CHARACTER OF THE CURVE WAS THE SAME, ANOTER 60 FPM DOW PASS WAS NOT MADE. THE APPROXIMATE PRODUCTION RATE WHILE LOGGING WAS 7000 TO 10000 MCF/D. 250 BBLS OF SEAWATER WAS PUMPED PRIOR TO LOGGING THE FIRST BASELINE TDTP PASS. THE INJECTION RATE DURING THE BASELINE PASSES WAS 1 BPM. 250 BBLS OF BORAX/WATER WAS PUMPED AT 3 BPM PRIOR TO LOGGING THE BORAX TDTP PASSES. AN INHERENTCHARACTERISTIC OF SPINNERS RUN BELOW TDTP IS THAT WHEN THE SPINNER STOPS TURNING, THE COUNTS JUMP TO OVER 300 RPS. AS THE FULLBORECAGE CLOSES DOWN OR THE TOOL STOPS MOVING, A FALSE RPS INCREASE OCCURS. APPROXIMATE PRODUCTION SPLITS: 10194-10444'=0%, 10694-11196'=81~, 11244-11644'=19~ SPINNER SHOWS MOST OF PRODUCTION FROM UPPPER 150' AND LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 72 LOWER 120' OF MIDDLE PERFORATION INTERVAL. THE BORAX LOG AGREES CLOSELY WITH THE SPINNER DATA. THE BORAX LOG TENDS TO INDICATE THAT THE UPPER SET OF PERFS IS MORE PERFIEABLE THAN THE LOWER. $ 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 ** NA~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 1066347 O0 000 O0 0 14 1 1 4 68 0000000000 SIGM BX3 CU 1066347 O0 000 O0 0 14 1 1 4 68 0000000000 TPHI BX3 PU 1066347 O0 000 O0 0 14 1 1 4 68 0000000000 SBHF BX3 CU 1066347 O0 000 O0 0 14 1 1 4 68 0000000000 SBHNBX3 CU 1066347 O0 000 O0 0 14 1 1 4 68 0000000000 SIGC BX3 CU 1066347 O0 000 O0 0 14 1 1 4 68 0000000000 SIBH BX3 CU 1066347 O0 000 O0 0 14 1 1 4 68 0000000000 TRAT BX3 1066347 O0 000 O0 0 14 1 1 4 68 0000000000 SDSI BX3 CU 1066347 O0 000 O0 0 14 1 1 4 68 0000000000 BACK BX3 CPS 1066347 O0 000 O0 0 14 1 1 4 68 0000000000 FBAC BX3 CPS 1066347 O0 000 O0 0 14 1 1 4 68 0000000000 TCANBX3 CPS 1066347 O0 000 O0 0 14 1 1 4 68 0000000000 TCAFBX3 CPS 1066347 O0 000 O0 0 14 1 1 4 68 0000000000 TCNDBX3 CPS 1066347 O0 000 O0 0 14 1 1 4 68 0000000000 TCFDBX3 CPS 1066347 O0 000 O0 0 14 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 7 3 NAFiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEi~ CODE (HEX) TSCN BX3 CPS 1066347 O0 000 O0 0 14 1 1 4 TSCF BX3 CPS 1066347 O0 000 O0 0 14 1 1 4 INNDBX3 CPS 1066347 O0 000 O0 0 14 1 1 4 INFD BX3 CPS 1066347 O0 000 O0 0 14 1 1 4 TENS BX3 LB 1066347 O0 000 O0 0 14 1 1 4 GR BX3 GAPI 1066347 O0 000 O0 0 14 1 1 4 CCL BX3 V 1066347 O0 000 O0 0 14 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. SBHN. BX3 SDSI.BX3 TCAF. BX3 TSCF. BX3 GR.BX3 11639.000 SIGM. BX3 31.539 TPHI.BX3 77.696 SIGC. BX3 0.330 SIBH.BX3 0.794 BACK. BX3 222.509 FBAC.BX3 3890.982 TCND.BX3 10081.303 TCFD.BX3 456.650 INND.BX3 2212.195 INFD.BX3 320.750 CCL.BX3 0.004 44.329 SBHF. BX3 65.385 166.544 TRAT. BX3 1.694 34.558 TCAN. BX3 12360.631 2696.749 TSCN. BX3 1351.397 268.239 TENS.BX3 10.000 ** ~ OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .014 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NABiE : EDIT .015 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 15 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFiBER: 7 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 74 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 11639.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIM~ 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 .......... 10064.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP TDTP TDTP TDTP TDTP $ GAMMA RAY SOURCE PROD. LOGGING HOUSING TDTP DETECTOR CART TDTP TOOLS FULL BORE SPINNER 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 TE~IPERATURE (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): 29-NOV-97 CP 44.2 1538 29-NOV-97 11644.0 11635.0 10100.0 11635.0 1800.0 NO TOOL NUMBER CGRS-A- 862 CPLH-A-999 TDIC-A-843 TDT SET 21 FBS-B-1879 5577.0 VARIOUS 40.0 THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 75 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 11000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: THIS FILE CONTAINS THE RAW DATA FOR FLOWING PASS #1 TIED IN TO DRILLERS CASING TALLEY AND ANADRILL ADN4 16-SEP 60 FPM AND 90 FPM FLOWING DOWN PASSES WERE MADE WITH THE SPINNER AND A 30 FPM UP PASS WITH BOTH SPINNER AND TDTP WERE MADE. THE 60 FPM DOWN PASS WAS MADE BEFORE THE WELL HAD STABILIZED AFTER RE-OPENING WELL TO FLOW. SINCE THE CHARACTER OF THE CURVE WAS THE SA~E, ANOTER 60 FPM DOW PASS WAS NOT MADE. THE APPROXIMATE PRODUCTION RATE WHILE LOGGING WAS 7000 TO 10000 MCF/D. 250 BBLS OF SEAWATER WAS PUMPED PRIOR TO LOGGING THE FIRST BASELINE TDTP PASS. THE INJECTION RATE DURING THE BASELINE PASSES WAS 1 BPM. 250 BBLS OF BORAX/WATER WAS PUMPED AT 3 BPM PRIOR TO LOGGING THE BORAX TDTP PASSES. AN INHERENT CHARACTERISTIC OF SPINNERS RUN BELOW TDTP IS THAT WHEN THE SPINNER STOPS TURNING, THE COUNTS JUMP TO OVER 300 RPS. AS THE FULLBORE CAGE CLOSES DOWN OR THE TOOL STOPS MOVING, A FALSE RPS INCREASE OCCURS. APPROXIMATE PRODUCTION SPLITS: 10194-10444'=0%, 10694-11196'=81%, 11244-11644'=19~ SPINNER SHOWS MOST OF PRODUCTION FROM UPPPER 150' AND LOWER 120' OF MIDDLE PERFORATION INTERVAL. THE BORAX LOG AGREES CLOSELY WITH THE SPINNER DATA. THE BORAX LOG TENDS TO INDICATE THAT THE UPPER SET OF PERFS IS MORE PERMEABLE THAN THE LOWER. $ 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 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 76 TYPE REPR CODE VALUE 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NANIE 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 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 SIGM FL1 CU 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 TPHI FL1 PU 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 SBHF FL1 CU 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 SBP~NFL1 CU 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 SIGC FL1 CU 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 SIBH FL1 CU 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 TRAT FL1 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 SDSI FL1 CU 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 BACK FL1 CPS 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 FBAC FL1 CPS 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 TCANFL1 CPS 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 TCAFFL1 CPS 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 TCNDFL1 CPS 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 TCFDFL1 CPS 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 TSCNFL1 CPS 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 TSCF FL1 CPS 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 INNDFL1 CPS 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 INFDFL1 CPS 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 TENS ELI LB 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 GR FL1 GAPI 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 CCL FL1 V 1066347 O0 000 O0 0 15 1 1 4 68 0000000000 ** DATA ** DEPT. 11639.000 SIGM. FL1 27.231 TPHI.FL1 0.000 SBHF.FL1 108.703 SBHN. FL1 161.405 SIGC. FL1 0.000 SIBH. FL1 228.537 TRAT.FL1 0.000 SDSI.FLi 1.440 BACK. FL1 29.802 FBAC. FL1 21.862 TCAN. FL1 0.000 TCAF. FL1 0.000 TCND.FL1 -357.353 TCFD.FL1 -256.692 TSCN. FL1 0.000 TSCF.FL1 0.000 INND.FL1 -1.013 INFD.FL1 -0.743 TENS.FL1 20.000 GR.FL1 38.938 CCL.FL1 0.017 DEPT. 10064.000 SIGM. FL1 33.909 TPHI.FL1 42.963 SBHF. FL1 33.635 SBHN. FL1 39.219 SIGC. FL1 1.075 SIBH. FL1 43.498 TRAT. FL1 1.759 SDSI.FL1 0.613 BACK. FL1 240.318 FBAC.FL1 56.188 TCAN. FL1 33208.172 TCAF.FL1 10365.070 TCND.FL1 22744.691 TCFD.FL1 6373.073 TSCN. FL1 3607.268 TSCF.FL1 1182.483 INND.FL1 3159.265 INFD.FL1 535.528 TENS.FL1 20.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JAN-1998 10:12 PAGE: 77 GR.FL1 42.688 CCL.FL1 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .015 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/01/ 8 ORIGIN : FLIC TAPE NAlVZE : 97571 CONTINUATION # : 1 PREVIOUS TAPE : COlVlMENT : ARCO ALASKA INC, 1E-34, KUPARUK RIVER UNIT, 50-029-22805-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/01/ 8 ORIGIN : FLIC REEL NAIViE : 97571 CONTINUATION # : PREVIOUS REEL : COMIVZEAUf : ARCO ALASKA INC, 1E-34, KUPARUK RIVER UNIT, 50-029-22805-00 * ALASKA COMPUTING CENTER * * . ****************************** * ............................ * * ....... SCHLUMBERGER ....... * ............................ * ****************************** NOV "1 ,~ '~997 COMPANY NAME : B.P. EXPLORATION WELL NAME : 1E-34 FIELD NAi~iE : KUPARUK BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22805-00 REFERENCE NO : 97470 Dat~ ALASKA cOMPUTING cENTER . COMPANY NAME : B.P- ExPLORATION : 1E-34 WELL NAM~ : KuPARUK FIELD NAME · NORTH SLOPE BOROUGH . ALASKA STATE ' 50_029-22805'00 REFERF2~CE NO : 97470 . LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-1997 09:29 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/11/ 6 ORIGIN : FLIC REEL NA~IE : 97470 CONTINUATION # : PREVIOUS REEL : CO~R~ENT : ARCO ALASKA, INC., KUPARUK 1E-34, API #50-029-22805-00 **** TAPE HEADER **** SERVICE NA~E : EDIT DATE : 97/11/ 6 ORIGIN : FLIC TAPE NAME : 97470 CONTINUATION # : 1 PREVIOUS TAPE : CON~IENT : ARCO ALASKA, INC., KUPARUK 1E-34, API #50-029-22805-00 TAPE HEADER KUPAR UK ~D/~ LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION BIT RUN 1 ......... 97470 JWPB /EK BREEDEN SECTION: TOWNSHIP: RANGE '. FNL: FSL : FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 1E-34 500292280500 B.P. EXPLORATION SCHLUMBERGER WELL SERVICES 5-NOV-97 BIT RUN 2 ......... 97470 JWPB/EK LUTRICK BIT RUN 3 ......... 16 liN iOE 112.90 71.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 5579.0 6.125 7.000 9821.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-1997 09:29 3RD STRING PRODUCTION STRING Well drilled 29-SEP through 06-0CT-97 with ADN only. All data was collected in two bit runs. $ $ PAGE: **** FILE HEADER **** FILE NAM~ : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 97/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO ~T FILE : FILE HEADER FILE NUM~ER: 1 EDITED MERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREME2F~: 0.5000 FILE SUMMARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (~I~ASUREDDEPTH) START DEPTH STOP DEPTH 9722.0 11713.0 BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD BIT RUN NO. MERGE TOP MERGE BASE 1 9722.0 10775.0 2 10534.0 11713.0 No depth adjustments were made to this data. The ADN quadrant outputs are as follows: ROBB/ROBU/ROBL/ROBR are bottom, upper, left, and right quadrant density; and are also listed as RHO1, RH02, RH03, RH04 in the LDWG listing. The RHOB in the edited file is a best pick spliced file from the best data quadrant. The other outputs (Delta Rho, PEF, ) are listed with their quadrants as DRHB/DRHU/DRHL/DRHR, PEB/PEU/ PEL/PER. LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-1997 09:29 PAGE: LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR O0 000 O0 0 1 1 1 4 68 0000000000 RHOBMWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RHO1 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RH02 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RH03 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RH04 NWl) G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E O0 000 O0 0 1 1 1 4 68 0000000000 DCALMWD IN O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-1997 09:29 PAGE: DEPT. 11712.000 FET.MWD RHO1.MWD -999.250 RHO2.MWD DRHO.MWD -999.250 PEF.MWD DEPT. 11700.000 FET.~IWD RHO1.MWD -999.250 RHO2.MWD DRHO.MWD -999.250 PEF.MWD DEPT. 11400.000 FET.MWD RHO1.MWD 2.267 RHO2.MWD DRHO.MWD -0.008 PEF. MWD DEPT. 11100.000 FET.MWD RHO1.MWD 2.070 RHO2.MWD DRHO.MWD -0.044 PEF. MWD DEPT. 10800.000 FET.MWD RHO1.MWD 2.152 RHO2.MWD DRHO.MWD -0.032 PEF.MWD DEPT. 10500.000 FET.MWD RHO1.MWD 2.154 RHO2.MWD DRHO.MWD -0.039 PEF.MWD DEPT. 10200.000 FET.MWD RHO1.MWD 2.344 RHO2.MWD DRHO.MWD 0.026 PEF.MWD DEPT. 9900. 000 FET.MWD RHO1 . MWD 2 . 143 RH02 . MWD DRHO . MWD -0. 026 PEF. MWD DEPT. 9800.000 FET.MWD RHO1.MWD -999.250 RHO2.MWD DRHO.MWD -999.250 PEF.MWD -999.250 ROP.MWD -999.250 RHO3.MWD -999.250 DCAL.MWD -999.250 ROP.MWD -999.250 RHO3.MWD -999.250 DCAL.MWD 1.333 ROP.MWD 2. 330 RH03 .MWD 20. 612 DCAL.MWD 1. 961 ROP.MWD 2. 070 RH03 .MWD 52.189 DCAL. MWD 2. 613 ROP.MWD 2. 153 RH03 .MWD 23. 685 DCAL.MWD 1.223 ROP.14WD 2.154 RHO3.MWD 55.625 DCAL.MWD 1.778 ROP.MWD 2.170 RHO3.MWD 11.397 DCAL.MWD 2. 183 ROP.MWD 2.143 RH03. MWD 51. 254 DCAL. MWD -999.250 ROP.MWD -999.250 RHO3.MWD -999.250 DCAL.MWD 123.367 -999.250 -999.250 104.067 -999.250 -999.250 86.550 2.274 0.351 92.306 2.070 0.000 64.287 2.110 0.088 37.976 2.154 0.000 264. 858 2.246 O. 049 107.782 2.143 0.000 -999.250 -999.250 -999.250 RHOB.MWD RHO4.MWD NPHI.MWD RHOB.MWD RHO4,MWD NPHI.MWD RHOB. MWD RH04. MWD NPH I . MWD RHOB.MWD RHO4.MWD NPHI.MWD RHOB.MWD RHO4.MWD NPHI.MWD RHOB . MWD RH04 . MWD NPHI.MWD RHOB.MWD RHO4.MWD NPHI,MWD RHOB.MWD RHO4.MWD NPHI.MWD RHOB.MWD RHO4.MWD NPHI.MWD -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.434 2.434 37.187 2.070 2.070 24.385 2. 152 2. 273 28. 961 2.154 2.154 40.301 2. 344 2.251 40. 030 2.143 2.143 50.578 -999.250 -999.250 57.667 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-1997 09:29 PAGE: **** FILE HEADER **** FILE NA~iE : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~ER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCRE~fENT: 0.5000 FILE SUF~$ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9722.0 10775.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ADN DENS./NEUT. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) '. BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : 06-0CT-97 5 R36 _ 5. OB MEMORY 11713.0 9722.0 11713.0 68.0 85.0 TOOL NUMBER ADN-4 023 8.500 5579.0 LSND 12.10 1200 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-1997 09:29 PAGE: FLUID LOSS (C3): RESISTIVITY (0H~94) AT TEMPERATURE (DEGF): MUD AT M~ASURED TEMPERATURE (MT): 3.070 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 4. 420 MUD CAKE AT (MT): 2. 940 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.5 REMARKS: RUN 1 9821' - 10775' ADN4 RUN IN COM~INATION WITH SPERRY RES. RUN 2 10775' - 11713' ADN4 RUN IN COMBINATION WITH SPERRY RES. RUN 1 BIT TO DEN:89.6', TO NEU: 92.7' RUN 2 BIT TO DEN: 79.6', TO NEU: 82.7' NO MAD PASS DATA DATA FROM DOWNHOLE MEMORY, VS. OB SOFTWARE $ LIS FORMAT DATA 80.0 80.0 80.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 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 6-NOV-1997 09:29 PAGE: ** 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 O0 000 O0 0 2 1 1 4 68 0000000000 ROP5 LW1 F/HR O0 000 O0 0 2 1 1 4 68 0000000000 TABD LW1 O0 000 O0 0 2 1 1 4 68 0000000000 ROSB LW1 G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 ROBB LW1 G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 ROBU LWl G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 ROBL LW1 G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 ROBR LW1 G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 DRHB LW1 G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 DRHU LW1 G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 DRHL LWl G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 DRHR LW1 G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 PEB LW1 O0 000 O0 0 2 1 1 4 68 0000000000 PEU LW1 O0 000 O0 0 2 1 1 4 68 0000000000 PEL LW1 O0 000 O0 0 2 1 1 4 68 0000000000 PER LW1 O0 000 O0 0 2 1 1 4 68 0000000000 TNPH LW1 PU O0 000 O0 0 2 1 1 4 68 0000000000 DCAL LW1 IN O0 000 O0 0 2 1 1 4 68 0000000000 TNRA LW1 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11713 . 000 ROPS.LW1 -999.250 TABD.LW1 -999.250 ROSB.LW1 ROBB. LW1 -999. 250 ROBU. LW1 -999. 250 ROBL. LW1 -999. 250 ROBR. LW1 DRHB.LW1 -999.250 DRHU. LW1 -999.250 DRHL.LW1 -999.250 DRHR.LW1 PEB. LW1 -999. 250 PEU. LW1 -999. 250 PEL. LW1 - 999. 250 PER. LW1 TNPH. LW1 -999. 250 DCAL. LW1 -999. 250 TNRA. LW1 -999. 250 DEPT. 11700.000 ROPS.LW1 -999.250 TABD.LW1 -999.250 ROSB.LW1 ROBB . LW1 -999. 250 ROBU. LW1 -999. 250 ROBL. LW1 -999. 250 ROBR. LW1 DRHB.LW1 -999.250 DRHU. LW1 -999.250 DRHL.LW1 -999.250 DRHR.LW1 PEB.LW1 -999.250 PEU. LW1 -999.250 PEL.LWl -999.250 PER.LW1 TNPH. LW1 -999. 250 DCAL. LW1 -999. 250 TNRA. LWl -999. 250 DEPT. 11400.000 ROPS.LW1 -999.250 TABD.LW1 -999.250 ROSB.LW1 ROBB.LW1 -999.250 ROBU. LW1 -999.250 ROBL.LW1 -999.250 ROBR.LW1 DRHB.LW1 -999.250 DRHU. LW1 -999.250 DRHL.LW1 -999.250 DRHR.LW1 PEB.LW1 -999.250 PEU. LW1 -999.250 PEL.LW1 -999.250 PER.LW1 TNPH. LW1 -999. 250 DCAL. LW1 -999. 250 TNRA. LW1 -999. 250 DEPT. 11100.000 ROPS.LW1 -999.250 TABD.LW1 -999.250 ROSB.LW1 ROBB.LW1 -999.250 ROBU. LWl -999.250 ROBL.LW1 -999.250 ROBR.LW1 DRHB.LW1 -999.250 DRHU. LW1 -999.250 DRHL.LW1 -999.250 DRHR.LW1 PEB.LW1 -999.250 PEU. LW1 -999.250 PEL.LW1 -999.250 PER.LW1 TNPH. LW1 -999. 250 DCAL. LW1 -999. 250 TNRA. LW1 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-1997 09:29 PAGE: DEPT. 10800. 000 ROPS.LW1 ROBB. LW1 -999. 250 ROBU. LW1 DRHB. LW1 - 999. 250 DRHU. LW1 PEB . LW1 - 999. 250 PEU. LW1 TNPH. LW1 -999. 250 DCAL. LW1 DEPT. 10500. 000 ROP5.LW1 ROBB. LW1 2.154 ROBU. LW1 DRHB . LW1 - 0.039 DRHU. LW1 PEB. LW1 55. 625 PEU. LW1 TNPH. LW1 40. 3 O1 DCAL . LW1 DEPT. 10200. 000 ROP5. LW1 ROBB. LW1 2. 344 ROBU. LW1 DRHB.LW1 O. 026 DRHU. LW1 PEB . LW1 11.397 PEU. LW1 TNPH. LW1 40. 030 DCAL.LW1 DEPT. 9900. 000 ROPS. LW1 ROBB. LW1 2.143 ROBU. LW1 DRHB.LW1 -0. 026 DRHU. LW1 PEB . LW1 51. 254 PEU. LW1 TNPH. LWl 50. 578 DCAL . LW1 DEPT. 9722. 000 ROPS. LW1 ROBB. LW1 2.439 ROBU. LW1 DRHB.LW1 -0.260 DRHU. LW1 PEB . LW1 33 . 219 PEU. LW1 TNPH . LW1 55. 9 O1 DCAL . LW1 -999. 250 TABD. LW1 -999. 250 ROBL. LW1 -999 . 250 DRHL. LW1 -999. 250 PEL. LW1 -999. 250 TNRA. LW1 37. 976 TABD. LW1 2.154 ROBL. LW1 -0. 039 DRHL.LW1 55. 625 PEL. LW1 O . 000 TNRA. LW1 264. 858 TABD. LW1 2.170 ROBL . LW1 -O. 026 DRHL. LW1 73. 290 PEL. LW1 O . 049 TNRA . LW1 107. 782 TABD.LW1 2.143 ROBL. LW1 -0. 026 DRHL.LW1 51. 254 PEL. LW1 O. 000 TNRA. LW1 439.317 TABD . LW1 2. 566 ROBL. LW1 - O. 179 DRHL. LW1 31. 026 PEL. LW1 O . 283 TNRA . LW1 -999.250 ROSB.LW1 -999.250 ROBR.LW1 -999.250 DRHR.LW1 -999.250 PER.LW1 -999.250 1. 223 ROSB. LW1 2.154 ROBR . LW1 - 0.039 DRHR. LW1 55. 625 PER. LW1 20. 621 1. 778 ROSB. LW1 2.246 ROBR . LW1 -0. 005 DRHR. LW1 20. 702 PER. LW1 20. 501 2.183 ROSB. LW1 2.143 ROBR . LWi -0. 026 DRHR.LW1 51. 254 PER. LW1 25. 235 2. 433 ROSB. LW1 2. 480 ROBR. LW1 - O. 214 DRHR. LW1 35.352 PER.LW1 28. 929 -999.250 -999.250 -999.250 -999.250 2.294 2.154 -0.039 55.625 2.261 2.251 -0.007 29.953 2.241 2.143 -0.026 51.254 3.326 2.388 -0.271 40.223 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~IE : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE · 97/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-1997 09:29 PAGE: FILE HEADER FILE ~ER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREME1VT: 0.5000 FILE SUMFiARY VENDOR TOOL CODE START DEPTH MWD 10534.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11713.0 06-0CT-97 5 R36 5. OB MEMORY 11713.0 9722.0 11713.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ADN DENS./NEUT. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT 14FJLgURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 80.0 92.3 TOOL NUI~BER ADN-4 023 8.500 5579.0 LSND 12.10 1200 3.070 80.0 4. 420 80.0 2. 940 80.0 SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-1997 09:29 PAGE: 10 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.5 REMARKS: RUN 1 9821' - 10775' ADN4 RUN IN COM~INATION WITH SPERRY RES. RUN 2 10775' - 11713' ADN4 RUN IN COMBINATION WITH SPERRY RES. RUN 1 BIT TO DEN: 89.6', TO NEU: 92.7' RUN 2 BIT TO DEN: 79.6', TO NEU: 82.7' NO MAD PASS DATA DATA FROM DOWNHOLE ~ORY, VS. OB SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 ROP5 LW2 F/HR O0 000 O0 0 3 1 1 4 68 0000000000 TABD LW2 O0 000 O0 0 3 1 1 4 68 0000000000 ROSB LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 ROBB LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 ROBU LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 ROBL LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 ROBR LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-1997 09:29 PAGE: 11 NA~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) DRHB LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DRHULW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DRHL LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DR3~R LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 PEB LW2 O0 000 O0 0 3 1 1 4 68 0000000000 PEU LW2 O0 000 O0 0 3 1 1 4 68 0000000000 PEL LW2 O0 000 O0 0 3 1 1 4 68 0000000000 PER LW2 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH LW2 PU O0 000 O0 0 3 1 1 4 68 0000000000 DCALLW2 IN O0 000 O0 0 3 1 1 4 68 0000000000 TNRALW2 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11713. 000 ROP5. LW2 120. 881 TABD. LW2 9. 395 ROSB. LW2 ROBB. LW2 2. 225 ROBU. LW2 2. 251 ROBL. LW2 2. 228 ROBR. LW2 DRHB.LW2 -0. 010 DRHU. LW2 -0. 005 DRHL.LW2 -0. 015 DRHR.LW2 PEB.LW2 19. 998 PEU. LW2 118. 013 PEL.LW2 46. 004 PER.LW2 TNPH. LW2 33 . 051 DCAL. LW2 O. 059 TNRA. LW2 17.369 DEPT. 11700. 000 ROPS.LW2 104. 067 TABD.LW2 9. 395 ROSB. LW2 ROBB.LW2 2.225 ROBU. LW2 2.251 ROBL.LW2 2.228 ROBR.LW2 DRHB.LW2 -0. 010 DRHU. LW2 -0. 005 DRHL.LW2 -0. 015 DRHR.LW2 PEB.LW2 19. 998 PEU. LW2 118. 013 PEL.LW2 46. 004 PER.LW2 TNPH. LW2 33. 051 DCAL. LW2 O. 059 TNRA. LW2 17.369 DEPT. 11400.000 ROPS.LW2 86.550 TABD.LW2 1.333 ROSB.LW2 ROBB. LW2 2 . 267 ROBU. LW2 2.330 ROBL. LW2 2. 274 ROBR. LW2 DRHB.LW2 -0. 008 DRHU. LW2 -0. 008 DRHL.LW2 -0. O17 DRHR.LW2 PEB.LW2 20.612 PEU. LW2 51.385 PEL.LW2 44.249 PER.LW2 TNPH. LW2 37.187 DCAL. LW2 O. 351 TNRA. LW2 19.235 DEPT. 11100. 000 ROPS.LW2 92. 306 TABD.LW2 1. 961 ROSB.LW2 ROBB.LW2 2. 070 ROBU. LW2 2. 070 ROBL.LW2 2. 070 ROBR.LW2 DRHB.LW2 -0. 044 DRHU. LW2 -0. 044 DRHL.LW2 -0. 044 DRHR.LW2 PEB.LW2 52.189 PEU. LW2 52.189 PEL.LW2 52.189 PER.LW2 TNPH. LW2 24. 385 DCAL. LW2 O. 000 TNRA. LW2 13. 357 DEPT. 10800. 000 ROPS.LW2 64.287 TABD.LW2 2. 613 ROSB.LW2 ROBB.LW2 2.152 ROBU. LW2 2.153 ROBL.LW2 2.110 ROBR.LW2 DRHB.LW2 -0. 032 DRHU. LW2 -0. 041 DRHL.LW2 -0. 054 DRHR.LW2 PEB.LW2 23. 685 PEU. LW2 35. 652 PEL.LW2 55. 123 PER.LW2 TNPH. LW2 28. 961 DCAL. LW2 O. 088 TNRA. LW2 15. 493 DEPT. 10500.000 ROP5.LW2 -999.250 TABD.LW2 -999.250 ROSB.LW2 ROBB. LW2 -999. 250 ROBU. LW2 -999. 250 ROBL. LW2 -999. 250 ROBR. LW2 DRHB.LW2 -999.250 DRHU. LW2 -999.250 DRHL.LW2 -999.250 DRHR.LW2 PEB.LW2 -999.250 PEU. LW2 -999.250 PEL.LW2 -999.250 PER.LW2 TNPH. LW2 -999. 250 DCAL. LW2 -999. 250 TNRA. LW2 -999. 250 2.269 2.235 -0.005 26.532 2.269 2.235 -0.005 26.532 2.304 2. 434 -0. 011 18. 821 2.227 2.070 -0.044 52.189 2.268 2.273 -0.006 14.395 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-1997 09:29 PAGE: 12 DEPT. 10200. 000 ROP5.LW2 ROBB.LW2 -999.250 ROBU. LW2 DRHB. LW2 - 999.250 DRHU. LW2 PEB . LW2 -999. 250 PEU. LW2 TNPH. LW2 -999. 250 DCAL. LW2 DEPT. 9900. 000 ROPS. LW2 ROBB. LW2 -999. 250 ROBU. LW2 DRHB . LW2 - 999. 250 DRHU. LW2 PEB . LW2 -999. 250 PEU. LW2 TNPH. LW2 -999. 250 DCAL. LW2 DEPT. 9722. 000 ROPS. LW2 ROBB. LW2 -999. 250 ROBU. LW2 DRHB.LW2 -999.250 DRHU. LW2 PEB . LW2 -999. 250 PEU. LW2 TNPH. LW2 -999. 250 DCAL. LW2 -999. 250 TABD. LW2 -999. 250 ROBL. LW2 -999. 250 DRHL. LW2 -999. 250 PEL. LW2 -999. 250 TNRA. LW2 -999. 250 TABD. LW2 - 999.250 ROBL. LW2 -999. 250 DRHL. LW2 -999. 250 PEL. LW2 -999. 250 TNRA. LW2 - 999.250 TABD. LW2 -999. 250 ROBL. LW2 -999. 250 DRHL. LW2 -999. 250 PEL. LW2 -999. 250 TNRA. LW2 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ROSB. LW2 ROBR . LW2 DRHR. LW2 PER. LW2 ROSB. LW2 ROBR. LW2 DRHR. LW2 PER. LW2 ROSB. LW2 ROBR. LW2 DRHR . LW2 PER. LW2 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE ' 97/11/ 6 MA=YREC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/11/ 6 ORIGIN : FLIC TAPE NA~E : 97470 CONTINUATION # : 1 PREVIOUS TAPE COMMENT : ARCO ALASKA, INC., KUPARUK 1E-34, API #50-029-22805-00 **** REEL TRAILER **** SERVICE NAM~ : EDIT DATE : 97/11/ 6 ORIGIN : FLIC REEL NAMiE : 97470 CONTINUATION # : PREVIOUS REEL : COM~iEi~f : ARCO ALASKA, INC., KUPARUK 1E-34, API #50-029-22805-00