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)/2$76+2( )/2$7&2//$5 ,3(5) ,3(5) ,3(5) ,3(5) ,3(5) ,3(5) ,3(5) ,3(5) ,3(5) 6%(;2 6($/ 1,33/( ,1-(&7,21 3$&.(53$7&+/:5 6SDFHU3LSH6QDS/DWFK 7EJ/HDN 3$&.(53$7&+835 27+(5 /($.78%,1* 7$0&2//$5 1,33/( &21'8&725 ;25HGXFLQJ +$1*(5 +$1*(5 .83,1- .%*UGIW 55'DWH 2WKHU(OHY« ' 7' $FW%WPIW.% :HOO$WWULEXWHV )LHOG1DPH :(676$. :HOOERUH$3,8:, :HOOERUH6WDWXV ,1- 0D[$QJOH 0' ,QFO 0'IW.% :(//1$0( :(//%25(' $QQRWDWLRQ /DVW:2 (QG'DWH +6SSP 'DWH&RPPHQW 66691,33/( C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-08-09_21093_KRU_1D-122_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21093 KRU 1D-122 50-029-22905-00 LeakPoint Survey 09-Aug-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:198-149 T36871 Kayla Junke Digitally signed by Kayla Junke Date: 2022.08.12 09:15:36 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-08-09_21093_KRU_1D-122_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21093 KRU 1D-122 50-029-22905-00 Caliper Survey w/ Log Data 09-Aug-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:198-149 T36863 Kayla Junke Digitally signed by Kayla Junke Date: 2022.08.11 08:39:39 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1D-122 (PTD 198-149) Report of suspect annular communication Date:Tuesday, May 17, 2022 11:28:13 AM Attachments:1D-122 90 day TIO trend 5.17.22.pdf 1D-122.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, May 17, 2022 6:45 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1D-122 (PTD 198-149) Report of suspect annular communication Chris, KRU 1D-122 (PTD 198-149) was flagged by a problem well report this morning for exhibiting suspect IA pressurization. The plan is to bled the IA pressure down and if the IA repressurizes the well will be shut in and freeze protected. DHD will be begin initial diagnostics within the next few days. The proper paperwork for continued injection or corrective action will be submitted once a path forward has been determined. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 INSIDE PIPE DIAMETER SAND PRODUCTION CHOKE 45. INJ RAZE TNJ PRES 2021. ORIF DP TNJ TEMP 74. INJ VOL TGV/OGV 1N plot duration: "3 aonths 5 days LH/D SAVE---INOTIFY CORR OF PIPE ID CHANGE OPERATOR NOTES SET CHORE 863. HDR PRES 2147. installed -7SO' orifice on 10AUG2012 Jack NattL 171_ Supports 1D-116. 1D-115. 1D-121. 1D-123 230. WELL STATUS 100.00 1000 ON 2800.0 --------------------------------------------------------------------` OPEN/SI EVENT AT 115.00 3000-11 900 PICA TINE 2500.0 799 GENERAL PURPOSE 1000.0 0.1111 EVENT AT 45. 45. 699 PICA TIME 0.00 INJ PRES CREATE WELL NOTE AT AUTOSCALE Flow 590 PICA TIME INJ TEMP 198 ORIFICE r WH PRES Iff 397 FREEZE GET p� INJ RATE PROTECTION MINOR TIME 299 WELL HEAD SAVE 171. 171. MAJOR TIME WEER INSTANT FW HOURLY VA: No surface casing 396 IA PRES 0.00 ZOOM noiraj e, MINUTE FW DTIi-Y IN VIEW SDI. � � OA PRES 777777? 208.80 96 Iff CREATE EDL 59.00 . ■ PREV/NEXT WELL ■Email cs� acxacn�enc WT SUMMARY 9.00 -S Pw VIEW EPDDL 0.00 iI 0.00 --------------------------------------------------------------------` in CREATE EPDDL ER SCALE DESC PICK VALDE LATEST PI -OT DURATION 2168.0 ims 17'iMAY-27 V6.49 0.1111 CHOKE 45. 45. RES INJ PRES 2021. 2021. •,,•�� ANNCOM PROBLEMS INJ TEMP 74. 74. Flags: IAS WH PRES 796. 796. FICK i= `- 14 -NAY -22 18:35:06 Tac: INJ RATE 862. 863. MINOR TIME 1A, ORIF -DP 171. 171. MAJOR TIME WEER INSTANT FW HOURLY VA: No surface casing - single annulus - aoni IA PRES 963. 965. ZOOM noiraj e, MINUTE FW DTIi-Y OOA/Tree: � � OA PRES 777777? �M PRIMARY WELL DATA WELL EVENTS WELL SYMBOLS it PARAFFIN . ■ PREV/NEXT WELL ■Email cs� acxacn�enc WT SUMMARY WELL NOTES TEST FAC Iff KRDH NOTES MAXIMIZE TREND 7� sEcurs In i • AT PE n.cai o�.rocraonc F.0 L IP21 TREND I SUM MENU FLE) WIDE ALM MENU OPTIMIZEFt r � Trent 141-01 _ _ . V . RECEIVED STATE OF ALASKA •SKA OIL AND GAS CONSERVATION C SION APR 1120 $ REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ GOen ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:Patch❑i 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 198-149 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service ❑✓ 6.API Number: 99510 50-029-22905-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1D-122 ADL0025650 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): . 10.Field/Pool(s): Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 5,445 feet Plugs measured None feet true vertical 4,194 feet Junk measured None feet Effective Depth measured 4,680 feet Packer measured 3583,3610,4723 feet true vertical 3,480 feet true vertical 2669,2686,3519 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 15 " 121' MD PRODUCTION 5,394 feet 11 " 5,435' MD Tubing(size,grade,measured and true vertical depth) 4.5 " L-80 4,723' MD 3,519'TVD Packers and SSSV(type,measured and true vertical depth) UPPER PACKER-UPPER 2.285"PIIP(SN:CPP 3,583' MD 2,669'TVD LOWER PACKER-LOWER 2.285"PIIP(SN:CPI 3,610' MD 2,686'TVD SEAL-BAKER SBE GBH22 4,723' MD 3,519'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 318-064 Contact Name: Jan Byrne/Kelly Lyons Authorized Name:Jan Byrne Contact Email: N1617@conocophillips.com Authorized Title:Well Integrity Supervisor Contact Phone: 907-659-7224 I Authorized Signature: �,,.- / _*- Date:4-6-18 Y'T— 4/ Mg A 4002 BDMS��' APR 1 11018 Form 10-404 Revised 4/2017 Submit Original Only • • y/ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 6th, 2018 Commissioner Hollis S. French Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner French: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well KRU 1D-122 (PTD 198-149) for tubing patch repair. If you need additional information,please contact us at your convenience. Sincerely, Jan B me/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM • 1D-122 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 1 D-122 was reported to the AOGCC for an unexplained IA pressure anomaly on 1-20-18. The well was shut in and secured after which diagnostics culminated in an LDL locating a tubing leak at 3597'. A 25' OAL 2.285" OD retrievable tubing patch was set over the leak. Passing MITs were then acquired. The well was BOI and once stablilized a AOGCC witnessed MITIA was completed. Pertinent work is copied below. 02/03/18 LEAK DETECT LOG: PERFORM BASELINE TEMP PASS FROM 100'TO PLUG IN NIPPLE @ 4680' RKB, LRS ONLINE PUMPING DOWN TUBING, RETURNS FROM IA, RATE 0.1BPM/3000PSI, PERFORM STATION STOP @ 4620' RKB, LOG UP DOWN PASSES OVER GLM FROM 4500' -4680' RKB, LOG UP/DN PASSES @ 40 & 80 FPM OVER INTERVAL 3500' -3700', STATION STOPS @ 3610', 3605', 3601', 3600', 3599', 3598' RKB, LEAK FOUND IN TUBING @ 3597' RKB 03/22/18 BRUSH N FLUSH PATCH SET AREA FROM 3500' -3700' RKB. ATTEMPT TO DRIFT FOR PATCH WITH 20'x 2.30" BUT DRIFT UNABLE TO PASS NIPPLE @ 476' RKB. SET LOWER 2.825" PIIP PACKER MID ELEMENT @ 3610' RKB. SET 2.875"TTS TEST TOOL IN LOWER PACKER &CMIT TBG x IA TO 2500 PSI ( PASS ) SET UPPER 2.285" PIIP PACKER PATCH ASSEMBLY( OAL 25' ) MID ELEMENT @ 3585.9' RKB. ATTEMPTED MITx IA 2500 PSI INCONCLUSIVE ) IN PROGRESS. START=2500/2515/377 15 MIN =2490/2510/382 30 MIN =2485/2510/438 03/23/18 SET TEST TOOL IN UPPER PACKER @ 3586' RKB &OBTAIN PASSING MITT. ATTEMPT MITIA( FAILED ) PULLED UPPER 2.285" PIIP PATCH ASSEMBLY @ 3586' RKB. CMIT TBG x IA 2500 PSI AGAINST TEST TOOL IN LOWER PACKER @ 3610' RKB ( PASS ) IN PROGRESS. BEGIN CMIT. INITIAL T/I/IL=490/375/673 LRS PT TBG x IA W/ 1.1 BBLS START= 2700/2550/673 15 MIN =2640/2550/573 30 MINS =2630/2550/673 03/24/18 SET NEW 2.285" P2P UPPER PATCH ASSEMBLY IN LOWER PACKER @ 3610' RKB. MIT T x IA 2500 PSI ( PASS ) JOB COMPLETE. BEGIN MITIA 2500 PSI. INITIAL T/I/IL =400/550/607 LRS PT TBG WITH .7 BBLS DSL. START=400/2560/607 15 MIN =400/2490/607 30 MIN =400/2460/607 • 1D-122 • DESCRIPTION OF WORK COMPLETED SUMMARY • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regqaalaska.0ov AOGCC.Insoectors(a�alaska.gov phoebe.brooksaalaska.gov chris.wallace[rialaska.00v OPERATOR: ConocoPhillips Alaska Inc, FIELD/UNIT/PAD: Kuparuk/KRU/1D Pad DATE: 04/05/18 OPERATOR REP: Miller/Beck AOGCC REP: Brian Bixby Well 1D-101 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2001830 Type Inj W Tubing 846 846 844 843 Type Test P Packer TVD 3626 BBL Pump 0.8 IA 340 2000 1950 1950 Interval 0 Test psi 1500 BBL Return 0.6 OA Result P Notes: Post Patch MITIA per Sundry#318-065 ***Single casing well*** Well 1D-122 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1981490 Type Inj W Tubing 950 950 951 951 Type Test P Packer TVD 3519 BBL Pump 0.7 IA 360 2000 1910 1900 Interval 0 Test psi 1500 BBL Return 0.6 OA Result P Notes: Post Patch MITIA per Sundry#318-064 ***Single casing well*** Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT KRU 10-101 and 122 04-05-18.xlsx KUP INJII 1D-122 ConocoPhillips Well Attributes Max Angle&MD TD Wellbore API/UWI Field Name Wellbore Status II ncl(1) MD(ftKB) Act Btm(11KB) AI25k8,Lu:. 500292290500 WEST SAK INJ 54.58 1,775.00 5,445.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ... SSSV:NIPPLE Last WO: 6/14/2008 47.99 8/17/1998 1D-122,3/25/2018 6:29:46 PM Last Tag Vertical scnemalic(actual) Annotation Depth(ftKB) End Date Last Mod By Last Tag:RKB 5,301.0 1/23/2018 condijw HANGER;38.8 111 W_ Last Rev Reason Annotation End Date Last Mod By Rev Reason:PATCH 3/25/2018 condijw Casing Strings Casing Description OD 00) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H-40 Welded XO Reducing;41 6 i Casing Description OD(in) ID(in) Top MB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len0...Grade Top Thread PRODUCTION 5,5"93.5" 51/2 4.950 40.7 5,434.5 4,183.8 15.50 L-80 BTCM aaa' 738'� Tu@4bing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)I...Wt(Ib/ft) Grade Top Connection TUBING 27/8 2.441 38.8 4,734.6 3,530.4 6.50 L-80 CONDUCTOR;41.0-121.0--e. "-Completion Details Top(ND) Top Inel Nominal 1 Top(ftKB) (ftKB) (°) Item Des Com ID(in) NIPPLE;476.3 4 38.8 38.8 0.00 HANGER TUBING HANGER 3.500 41.6 41.6 0.00 XO Reducing CROSSOVER 3.5"x27/8" 2.875 476.3 476.2 3.86 NIPPLE Camco"DS"Nipple w/2.30"Drift 2.300 4,679.7 3,479.7 23.56 NIPPLE Camco"D"Nipple w/2.24"Drift 2.250 4,722.6 3,519.4 22.26 SEALBAKER SBE GBH22 3.000 Upper Packer;3,583.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) C) Des Com Run Date ID(in) 3,583.0 2,668.8 51.29 Upper Packer UPPER 2.285"PIIP(SN:CPP287016)+Hang off XO, 3/24/2018 1.380 Tbg Leak;3,597.0 OAL=3.6' Spacer Pipe+Snap Latch, 3,587.0 3,587.0 2,671.3 51.30 Spacer Pipe+ SPACER PIPE,22'x 2 1/16"&LATCH SEAL 3/24/2018 1.380 Snap Latch ASSEMBLY(SN:287003),OAL 23.3' Lower Packer;3,610.0 3,597.0 2,677.6 51.32 Tbg Leak TBG LEAK at 3597' 2/3/2018 2.440 3,610.0 2,685.7 51.35 Lower Packer LOWER 2.285"POP(SN:CPP287014),OAL=3.6' 3/22/2018 1.380 Perforations&Slots Shot INJECTION;4,632.7 Dens Top(ND) Btm(TVD) (shots/ft Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ) Type Com 4,788.0 4,818.0 3,579.9 3,607.8 NSD,1D-122 3/22/1999 4.0 (PERF 2.5"HC,BH 4,850.0 4,886.0 3,637.5 3,670.9 WS C,WS B, 3/22/1999 4.0 IPERF 2.5"HC,BH NIPPLE;4,679.7 1D-122 4,898.0 4,918.0 3,682.1 3,700.6 WS A4,1D-122 3/22/1999 4.0 (PERF 2.5"HC,BH 4,944.0 4,954.0 3,724.8 3,734.1 WS A3,10.122 3/22/1999 4.0 IPERF 2.5"HC,BH 4,964.0 4,992.0 3,743.4 3,769.5 WS A3,1D-122 3/22/1999 4.0 (PERF 2.5"HC,BH 5,013.0 5,026.0 3,789.1 3,801.2 WS A2,10-122 3/22/1999 4.0 IPERF 2.5"HC,BH 5,034.0 5,050.0 3,808.6 3,823.6 WS A2,1D-122 3/22/1999 4.0 IPERF 2.5"HC,BH 5,060.0 5,080.0 3,832.9 3,851.6 WS A2,1D-122 3/22/1999 4.0 IPERF 2.5"HC,BH __..h 5,090.0 5,108.0 3,860.9 3,877.7 WS A2,10.122 3/22/1999 4.0 IPERF 2.5"HC,BH SEAL;4,722.6 Mandrel Inserts St at( N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 4,632.7 3,436.9 CAMCO KBMG- 1 GAS LIFT DMY BK 0.000 0.0.6/21/2018 M-22 I IPERF;4,7880-4,818.0 Notes:General&Safety End Date Annotation 6/17/2008 NOTE: MONOBORE INJECTOR IPERF;4,850.0-4,886.0 6/17/2008 NOTE:VIEW w/9.0 SCHEMATIC IPERF;4,898.0-4,918.0 IPERF;4.944.0-4,954.0 IPERF;4,964.04,992.0 IPERF;5.013.0-5,026.0 IPERF;5,034.0.5,050.0 IPERF;5.060.0-5,080.0 IPERF;5,090.0-5,108.0 PRODUCTION 5.5"03.5" 4738';40.7-5,434.5-- @ • MEMORANDUM 'State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday,April 05,2018 TO: Jim r,en 4�c�(I P.I.Supervisor SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1D-122 FROM: Brian Bixby KUPARUK RIV U WSAK 1D-122 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry �l L -- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1D-122 API Well Number 50-029-22905-00-00 Inspector Name: Brian Bixby Permit Number: 198-149-0 Inspection Date: 4/5/2018 Insp Num: mitBDB180405122840 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ID-122 Type Inj W TVD 3530 - Tubing 950 " 950 • 951 - 951 PTD 1981490 - Type Test SPT Test psi 1500 IA 360 2000 - 1910 - 1900 BBL Pumped: - BBL Returned: 0.6 OA � 0.7 Interval 1 OTHER P/F P Notes: This is a monobore well so there is no OA.Test was conducted per Sundry#318-064 post tubing patch. SC Makig Thursday,April 05,2018 Page 1 of 1 09 O � d D > E Z3 m o L �- w ed w a, 2 c0 C7 5 N t m 0 +J Z tin +- > M __`� 0 Q m o Y m o 0 E cu �� r C on N °° " a x o a ac O ' v c +o /1 w••• E as O :15 > ca < Q v o m 6 0 Q co Co ao ao 0o ao ao 0o ao v u t cn r _ 8 s .6 .a .o _6 _6 .6 .6 E " -° 0) 0) 0) 0) 4) 0) d 0) L- -6 n} W LL LL LL LL LL LL LL LL C u C Q1 til ZU Z g v > -0 0)) O C to 110 (u 0 000 00000C `n O w J J J J J J J J J on O ;� 0 O y W W W W W W W W W U ^^ I- LL LL LL LL LL LL LL LL LL +-+ G 01 O 6 0_ > -C 0) C, Q J J J J J J J J +, w •, Q z z z z z z z z z u, c o Z z z z z z z z z a- • r"} 0 LL LL LL LL LL LL LL LL LL CC •L Q .1-, > kI' (O +U+ > Y 4J E 0) [0 C 0) L O Q u v O C u, a 0) u > .� U d, O _O ro CO @ 0 - U L I- c H c G O ce o c cuo a o o L'3 is .� c C LL a a 0 a U ` u 't co" ix 0 U U m 0 a H g F < a- = a C> w U us I- 1 al w v C ,, iisl +-4 o 03 m Q. O rr u MI 61 034 1.4 d w ro 4152'333333333 , m oz w � 4 to *V111 .--9F, IP u.i pil: cec4wrecerecere £ E w W w W W W w w 3 u > > > > > > > > t vi Y Y Y Y Y Y Y Y> > > > > > > > Ot Q2 Ce Cr re W W Ce Ce v �' a: LU Q Q Q Q Q Q Q Q Q )� a a a a a a a a a13 a o > > > > > > > > > c u 0 Y Y Y Y Y Y Y Y Y Co C on )a U >LU 00 cc U LLI 0 a- a- CO O N N N N N X v) •C a N { , 0 0 0 0 0 0 0 0 0 0 £ co co v& �/ cc O O o 0 0 0 0 0 0 0LU ,a CCS v u ti u . ti n ti u r- u.. v _ LL LL LL LL LL LL LL LL LL > 0 0 0 0 0 0 0 0 0 C O, m IL) co LU �F vu) o �CC 0 0 0 0 0 0 0 0 0 C ~ 00 C N N N in •- O ,r- co BVI O O h- co O O O) N O) 0 N N O 00 N N C') )!) e- t() L U tN N O 0 N N M M 0 M O N N N N N N N N N N L _� r. W M Q) O) O) T O M C G) 7n N O N N N N N O N ', (�� 01 O r 0 O O O O 0 LI O O O O O O O O O C 00 00 C N N V7 N U N N O N 8. CM C Zc. Lrla) 'u ; 0 Ls.) Y 0 WI X C C CO v .- Q p ) L .c 'D e z d ekoQ) '-1 Q in in co O r r ab N ate+ aO+ In L C = a Q Fr vi O N W M M r G 2 = N = UCro) z v0i Y pp r �"'� L n C +' f0 v) p CO a v� c 2 3 @ � 0) as v 4 F- a a Q THE STATE ALASKA GOVERNOR BILL WALKER Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1D-122 Permit to Drill Number: 198-149 Sundry Number: 318-064 Dear Mr. Byrne: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 W W W.aogcc. olaska.gov Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this 2-(' day of February, 2018. REDMS LL� FEEL' 7 2118 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 iv1 RECEIVED FEB 2 0 20% AOGCC) 1. Type of Request: Abandon IT Plug Perforations LJ Fracture Stimulate Ll Repair Well MexOperations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ - Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Patch Other: ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service Ex 198-149 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 500292290500- 00292290500-7. 7.If perforating: 1%b 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Al A- Will planned perforations require a spacing exception? Yes ❑ No ❑ KRU 1 D-122 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025650 Kuparuk River Field /West Salk Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 5,445' - 4,194' - 4680' ' 3480' 4680' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 121' Surface Intermediate Production 5,394' 12" 5,435' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4788'-5108' 3579'-3878' 2.875" L-80 4,723' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary O Wellbore schematic O 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service Q 14. Estimated Date for 2/27/2018 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ Q WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jan Byrne Contact Name: Kelly Lyons/ Jan Byrne Authorized Title: Well Integrity Supervisor Contact Email: N1617@conocophillips.com Contact Phone: 907-659-7224 Authorized Signature: ` (3 Date: 2 - /? - g COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integnty ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: �/ Post Initial Injection MIT Req'd? Yes )I/ No ❑ 1L REWS t L- F -T- Z ? ?C18 Spacing Exception Required? Yes No Subsequent Form Required: �(7 �O ❑ APPROVED BYI _ G Date: .L — t Approved by. THE ' COMMISSIONER COMMISSISI ON 4I,,�b ""h 42-0 /'g X I G I N A L n Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. V Submit Form and Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 17, 2018 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue, Suite 100 Anchorage, AK 99501 Commissioner French: Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 1D-122 (PTD# 198-149). The request is for approval to set a retrievable tubing patch over a tubing leak at 3597' MD to regain tubing integrity. / If you need additional information, please contact myself or Kelly Lyons at 659-7224. Regards, Jan Well Integrity Supervisor ConocoPhillips Alaska, Inc. 1D-122 DESCRIPTION SUMMARY OF PROPOSAL 1 D-122 On January 20th, 2018, injector 1 D-122 was reported to the AOGCC for unexplained IA pressure anomaly. The well was shut in and secured. Diagnostics were then performed, with a leak detect log locating a tubing leak at 3597' MD. This request is to install a 2.875" retrievable patch over the tubing leak to regain tubing integrity and return the well to injection. a 1. Prep wellbore for patch. 2. Set 2.875" —24' patch over tubing leak at 3597'. 3. Perform MIT -IA. 4. Bring well on injection. 5. Perform SW MIT -IA. 6. Submit 10-404 1D-122 ConocoPhillips Well Attributes IMaxAngle&MD ITD Na$ka, Inc. wNlbore APxuwl FlNa name well bore slMu: 500292290500 WESTSAK INJ Incl p) MO(.P) Ad can WE, Sd 5O 1,]]5.00 5,445.O Comment H2a(Ppm) Dae SSSV: NIPPLE Arnausion Entl Cate KB4randfllq Rap®se Deb LasI WO: 8/142008 4799 811]11998 ID422.4n840n ttW:43 yM veNbalwMmaec edwl Annotrtbn Dry1n 1XK81 Entl W. AnnM,l,,c Lx[Metl By Entl Dide Lang RKB 5,316.D 4/1]201] Rev ReasO¢TAG Ppmven 41182017 HANGER:3s9Casing birlings Casing Desnlpnon O011n ID9n) Top InK6) SM OepIM1 IXKBI SN pepInINO... WVLen 11... Grak iop TM1lmtl CONDUCTOR 16 15062 61.0 121.0 1210 62.58 H-40 WelOad Casln9 Cecc0pllon OOIin) 1O9n) Top IXKB) Set Dash lttKe) SH pepM jlY➢1... WtlLen 11...GMe Top TM1ratl PRODUCTION 5.5x35" 5112 4.950 40.7 5,636.5 4,103.0 15.50 L-80 I DTCM 38' Tubing Strings rubmg Dewnpnon snmg ma... ID ln) TopinKeI sal Depen (X_ Sel Depen IrvO11... wtllnlnl Grad, Topcon.act- XOReemlry:418 TUOING 2]18 2441 38.8 4,]34.6 3,530.4 650 L6O Completion Details mipzl lD O,8 rop !n0. 3080.00 HANGER TUBING HANGER 3.500 ;11TnpIrvG1 6180.00 XO Reducing OROSSOVER3.5'x2]R" 28]5 C0NDUCT0R:410921O 4]6.2386 NIPPLE Camca'DS' Nipple wl2.3O"Dnfl 2300 36]9]2356 NIPPLE Camcb'D"Nipplaw/224"Dnfl 2250 NIPPLE4]0.3 3$le 2226 SEAL BAKER SBE GBH22 3000 Perforations & Slots Enol Dan Top (ND) BhnINO) (shc"' Top MIKE) Bum IXKB) ITB) IXKB) bne Dab U Type Com 4,788,0 4,8160 3,5799 3,6078 Wa D. 10.122 322/1999 44 (PERF 2.5" HC. BH 4,8500 4,866.0 3,63]5 3,670.9 WE C, WS B, 3/22/1999 4.0 IPERF 2.5" HC. BH D1 2 Iwscnox; d.ma] 4.898.0 4,9160 3.682.1 3.7OO.6 WS AL, 1P 31=1999 O.O IPERF 2.5" HC. BH 122 4,9440 4.954.0 3.724.8 3.734.1 WSA3. 10- WM1999 4.0 IPERF 2.5"HC. BH 122 4,964.0 4,9820 3,7434 3.789.5 WSA3, 1D- 312211999 4O IPERF 2.5"HO, BH NIPPLE. a e197 122 5,0130 5,026.0 3,789.1 3,801.2 VVSA2, 1D- 312211999 4.0 IPERF 2.5 -HC, BH 122 5,034.0 5.050.0 3.808.6 3.823.6 WSA2, 1D- 3IM1999 4.0 IPERF 2,5' HC, BH 122 5,060.0 5.080.0 3.832.9 3.8518 WSA2. 1D- 3IM1999 4O IPERF 2.5' HC, BH 122 5,090.0 5,1080 3,860.9 3,877.7 WS A2, 1D- 312211999 4O IPERF 2,5' HC. BH 122 Mandrel Inserts sFu:4.>�25 St on °t1^ ToP(dKBI Top (TV IXKB) Make Model OOIIn) Sery vales Type Lain type PortsI- Iln) TRO Run (psi) Run gas Com 1 4632] 3138.9 CAMCO KSMG- 1 GASLIFT OM1 BEK 0000 0.0 6242008 I M-22 I 1 Notes: General & Safety Entl Dam Annolmion .pERP:4,J,,d,A1B0 6117/20DB NOTE: MONOBORE INJECTOR 6/1112006 NOTE: VIEW n9.O5CHEMATIC IPERF;465064.006O IPERF:4,e96P4910O IPERF: 4A44Ad.h40 IPERFAM40.4,9920- IPERF: 5 01305.026 0 IPERF:5034.0.5A50.0 IPERF:5Cad.0-e.08O0 IPERP:SAl0.0.5,ldad PRODUCTK1N 5513.5 ®473a; 401dA34.5 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Saturday,January 20, 2018 2:01 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of sustained casing pressure of IA on West Sak injector 1D-122 (PTD 198-149) 1-20-18 Attachments: 1D-122 schematic.pdf; 1D-122 90 day TIO plot 1-20-18.JPG Chris, West Sak water injector 1D-122 (PTD 198-149) is experiencing an unexplained IA pressure anomaly. Attempts to bleed the IA earlier today to establish a better dP between the tubing and IA were unsuccessful. There is a^'200psi difference in pressure now between the two,with the IA higher than WHP and both below the IA DNE of 2000psi. The difference in pressures could be the hydrostatic balance point with different fluids on either side creating different hydrostatic heads. The well will be shut in and freeze protected as soon as possible. Slickline will initially be mobilized to set a tubing plug prior to any pressure testing because this is a single casing well and we want to avoid a well control issue were an additional leak to develop at surface in the course of the testing. Once the plug is set, packoff testing/MITs and any other intervention wellwork will be pursued as necessary to identify the suspected leak point. Prior to returning the well to injection and/or performing any needed repairs, proper paperwork will be provided. Please let us know if you disagree with the path forward. Attached are the schematic and 90 day TIO plot. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 MEMORANDUM TO: Jim Regg ~Q~ ~ ~~l, 1i~1 P.I. Supervisor ' FROM: Lou Grimaldi Petroleum Inspector i State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 10, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 D-122 KUPARUK RIV U WSAK ID-122 Src: Inspector NON-CONFIDENTIAL Reviewed By: n P.I. Suprv Comm Well Name: KUPARUK RIV U WSAK 1D-122 API Well Number: 50-029-22905-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG100717100013 Permit Number: 198-149-0 Inspection Date: 7/17/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 11D-122 Type Inj. 4 N ~TVD 3530 Ip 90 1700 1s7o lsso - lsao ' 1981 I T ypeTest P.T.D~ SPT I Test psi 1500 OA ~ _ __ Interval ~T~R p/F' P Tubing ~ 530 530 530 530 530 Notes: Monobore injector. Retest of inconclusive test from yesterday..9 bbl's pumped Well stabilized after 130 psi drop in first 15 min's. ' _ ~` _ `1(I~~S Tuesday, August 10, 2010 Page 1 of 1 • MEMORANDUM To: Jim Regg P.L Supervisor ( ~~~ T 2{~• ltG FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Thursday, July 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-122 KUPARUK RIV U WSAK 1D-122 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ ~'~-- Comm Well Name: KUPARUK RIV U WSAK ID-122 Insp Num: mitRCN100718142157 Rel Insp Num: API Well Number: 50-029-22905-00-00 permit Number: 198-149-0 Inspector Name: Bob Noble Inspection Date: 7/16/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ IDa22' Type Inj. N TVD 3530 ~ IA ]0 1717 - 1556 1536 ~ P.T.D~ 1981490 TypeTest SPT Test psi 117 OA Interval aYRTST p/F' F Tubing 600 600 600 600 Notes: ~~~~~I~ f~~~, J ~t-eSSu~ ~t~S ~~ 1O r frf i ids, t.~iY;,~~ s~I ~1 ~, f1l ~L'. w . ~ ., w . - Thursday, July 22, 2010 Page 1 of 1 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 1D-122 Run Date: 2/5/2010 February 18, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1 D-122 Digital Data in LAS format, Digital Log Image file, Interpretation Report 50-029-22905-00 Injection Profile Log _~, ,~ ~~; _ ~, ~, ~ ~~; 50-029-22905-00 "` ~'~~" ~"~' ~ `~ ~` ~ ``" 1 CD Rom 1 Color Log PLEASE ACKNOWLEDGE RECEII'T BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto ~ ~ ~- 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto~ltalliburton.com Datc: - ~ , ~ `~ ~l ~ ~ r~ ~'~ ~ , ? ~. Signcd: ~ ~~~ ~~L ~~ :a ~_- - ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7tt1 Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this ~ansmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907) 245,8952 1) Caliper Report / MfT 25-Fetr09 1x119 2) MTT 25-Feb-09 1 D~122 ...' ' ~ 9 ~- ~, r ~ '~, ~ i i a l h~\ ~' t Signed : ~ 1 %f % Print Name: 1 Report / EDE 50.029-22836-00 1 Report ~ 1"~"! Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONA! AIRPORT RO SURE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ~C~~IICifl;3~3~3"1^~3i3~8''di'Ga'7,.CJs:3 WEBSRE V'."i~f,yi ~~:~:~3=I~t~~,=.3a'i3 F-? C:\Documents and SettingsWwneclDesktop\Trensmit_Conoco.docx __`) • Memory Magnetic Thickness Toal Log Results Summary Company: ConocoPhillips Alaska, Inc. Well; 1D-122 Log Date: February 25, 2tm9 Field: Kuparuk Log No. ; 10543 State: Alaska Run No.: 4 (2"d MTT) API No.: 50-029-22905-00 Pipet Desc.: 2.875" 6.51b L-80 Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvl.: 213 Ft. {MD) Pipet Desc.: 5.5" 15.5 Ib L-80 BTCM Top Log Infirl.: Surface Pipet Use: Production Casing Bo#. Log Intvl.: 213 Ft. (MD} Pipe3 Desc.: 16" 62.581b. H-40 Welded lop Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Inivl.: 121_ Ft._(MD) Inspection Type : Corrosive 8 Mechanical Damage Inspection COMMENTS This MTT data is tied into ifie Mandrel Hanger ~ 0' Depth. This is the second time this well has been logged with a PDS 12 Arm Magnetic Thickness Tool (MTT}. The Magnetic Thickness Tool responds to the total thickness of metal of the 2.875" tubing and 5.5" production casing, with some influence from the 16" conductor pipe. Passes at 8Hz, 10Hz and 12Hz were made at 20 fpm, with the 10Hz pass selected for analysis in this report. Due to the concentric pipe strings in the log interval, the MTT response is qualitative -indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. COMPARfSON TO PREVIOUS MTT LOG RESULTS The 3.5" tubing was replaced with 2.875" tubing since last MTT was run in this well on December 14, 2006. ' The current log indicates two pup joints in the new tubing completion (34' - 54') that appear to have a thicker wall or different metal grade than the surrounding tubing joints. The previous MTT log indicates an 8°~ circumferential metal loss at 36' that appears to now be masked by these pup joints in the new completion. In addition to the new tubing completion, the logging speed has been reduced from 40 FPM in the 2006 log to 20 FPM in the current. The slower logging speed appears to provide a beater signal to noise ratio. Although a direct comparison between the current log and previous log is not possible due to the change in tubing completion and the change in lagging speed, generally the recordings appear to indicate no signficant change in metal loss between logs. A log plot overlay of the average metal thicknesses recxx-ded by the MTT for the current and previous log (December 14, 2006) is included in this report. In the 2006 logs, calibration samples were only taken within the concentric pipe that included the conductor. 1 As a result, calculated metal thiclo~ess below the conductor appears to show metal loss due to the absence of the extra metal from the conductor pipe. The current log includes an additional calibration sample below the conductor that has been applied to that portion of the data, so the calculated metal thickness no longer reflects a Toss due to the absence of the conductor. ,,pp 5~n //p0tt (A, ,! l'j~'p~3 tir~"N ,, _2.J~r~R:ti !~`f'2~ rir' ~[ L,. 4i~F INTERPRETATION OF MTT LOG RESULTS ~ ProActi~~e Diagnostic Services, Inc. /' P.O. Box 1369, Stafford, TX 77497 Phone: (Z81} or (888} 565-9085 Fax:: (281} 505-1369 E-mail: PDS~a~memorylog.com Prudhoe Bay Field Office Phone: (907} 659-2307 Fax:: (907) 659-2314 t` • The 1OHz MTT log results cover the interval from surface to 213'. Changes in metal volume are relative to the calibration points at 74' and 139', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points. A maximum overall metal volume loss of 4% is indicated in joints 1 (32') and 2 (70') in the 1OHz pass. A log plot of the MTT recordings at 1OHz is included in this report. The Delta Metal Thickness (%) curve in this plot refers to total metal surrounding the MTT tool. Intervals of overall metal loss are indicated in the 1OHz pass as follows: A 3% circumferential metal loss is recorded in the interval between 4' - 6'. A 4% circumferential metal loss is recorded in the interval between 28' - 34'. A 4% circumferential metal loss is recorded in the interval between 59' - 74'. The percent arcumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which indudes influences from the 2.875", 5,5" and 16" pipe. If all of the metal loss is specific to the 5.5" production casing, the percent metal Toss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 2.875" tubing or 16" conductor. Field F~gineer. G. Etherton Analyst: HY. Yang Witr~ess: C. Fitzpatrick ProACtive Diagnostic Services, Inc. / P,O. Box 1369, Stafford, Tx 7749- Phone: {281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS,a~memorylog.cam Prudhoe Bay Field Office Phone: (907) 659-?307 Fax: (907) 659-2314 • Comparison to Previous ~T Logs Overlay S Februar 26, 2009 and December 14, 2006 PIOA(.'i~YE D{A{jNd61tC SENICE4y ~1YC. Database File: d:lwarriorldatalld-1221comp.db Dataset Pathname: 1/1 /1 /comp Presentation Format: 24COMP-1 Dataset Creation: Mon Mar 02 17:43:40 2009 Charted by: Depth in Feet scaled 1:150 Delta Metal Thickness 2006 (10 Hz} (%) Delta Metal Thickness 2009 {10 Hz} (%) 0 Metal 20 TTr-r I I I I T~~~I- Delta Metal Thickness 40 60 80 of 1 40 100 1 D-~ Recorded Magnetic Thicks Log Data - 10Hz Pass -=~--+- (Surface to 213') February 25, 2009 PwoA,c~ive Di~gnanic SE~vlcg, INC. Database File: 1d-122.db Dataset Pathname: 10Hz.1 Presentation Format: 2scale Dataset Creation: Thu Feb 26 23:03:38 2009 by Calc Warrior 7.0 STD Cas Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Loss (%) 50 2 MTTP01 (rad) 12 0 Line Speed (ft/min) 200 -6.8 MTTP12 (rad) 3.2 Tree Hanger IMeti I Li ssJ slta Metal Thickness Jt. 1 20 Metal 2.875'~Collar Pup Jt. 40 875" Collar lar Pup Jt. 60 Metal Loss Jt. 2 lid- Bottom of 16" Conductor 80 875" Collar .5" Collar ConocoPhillips ,.,.,..., in: MANGER, NIPPLE. 58E.~1i3 IPERF, 4,1883,818 IPERF, 4,8883,918 IPERF, 4,9643,954 IPERF 5,0905. 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L-~ 2.441 _ 2,789:88 4,944.9 1,976,8 20.4 78 T' 87 32.03 Tubing _ .668 6.50 L-80 2.441 2,821.71 4,9129 1,944.9 20.6 78 ^. 88 31.E Tubing .668 6.50 L-80 2.441 2,853.70 4,880.9 1.312.@ 20.8 79 ; ( 89 _ 32.D~S Tu6i~ . ~ .. _...-- ~ _. ~--- - .686 __6.50 L-8D 2.441 2,885.75 1.848.8 1,880.9 21.1 19 90 31.98 Tubing .868 8.50 L-~ 2.441 2,977.74 1.816.8 7.84$.8 21.3 79 91 3204 Tubing .6681 8.50 L-~ 2.447 - -- 2,&19.7$ 1,7134.8 4,876.8 21.5 49 ~ 92 3209 Tubing .668 6.60 L-80 2.441 ~ 2,981.81 1,F52.8 1,784.8 24.8 49 _ 93 32116 Tubes .868 6.50 L-80 2.441 3,093,87 1,720.7 1,7@2.8 22.0 20 -- 94 32.02 Tubing .668 8.50 L-80 2.444 8,045.89 1>Bti8.7 4,720.7 22.2 20 ~ ---- ~ 32.04 Tubing .888 6.50 L-811 2.444 9,077.90 1,858.7 1.688.7 22.5 20 --- 96 31.95 Tubi'ig .868 8.50 L-~ 2.449 _ 3,105.85 18'L4.7 1,656.7 22.7 20 ` 97 32.03 Tubing ~~ .888 $.50 L-80 2.444 3,144.8$ 1,592.7 4,824.7 22.9 20 98 33.02 7uti~g .888 6.50 L-80 2.444 3,973.90 1,5[10.7 4,592.7 23.2 27 ~ 99 31.08 Tubing .6B8 6.50 L-~ 2.449 3,204.98 4,5'1.9.8 1,580.7 23.4 21 : 700 3'1.94 Tubaig .66$1 6.50 L-~ 2.447 3,236.92 1,497.8 4,529.6 23.6 21 901 32.07 Tuba~g _fD68 6.6D L-BO 2444 ~ 3,268.95 1,465-6 1,497.6 23.9 21 102 31.98 Tubing .6681 6.50 L-$0 2.441 3,300.97 1,4:f3,8 4,465.6 24.1 21 403 32.04 Thing .668 8.50 L-80 2.447 3,933.04 1,404.6 1,433.6 24.3 22 Wetllrew -Tubing Run Ta!!y {1 t``y~, Tubing Uesca4ptliorx: 2 71$ crflmptetion ~ M- Sat i~epth (ftKB): 4,734.57 f2un Date: 511212008 07:45 Cu Ref Len OL3 Wt iD Top 4 Cum Len Top Btm m Cu Run Ivo. (~} item i7escrip#ion (m3 (~ Gra (~} Thread cen x (~} Mice} {tnc43} voi m t} ~ ~~` t D4sp wt ~, J (bbi} {t ~ Oa 4 ~~ ';- 104 32.00 Tubing .88$ 8.50 L-~ 2.441 3,38'',x.01 1.36.9.6 1.401.$ 24.6 22 _ ' 105 32.06 Tubing .868 8.b0 1-80 2.441 _ 3,397~')fi 1,337.b 1,38A.6 24.$ 22 __ _ t 106 32.04 Tubirfg .8~ 8.50 L-~80 2.441 _ 3 429.10 1,305.6 1,337.5 25.0 22 's.! 1©7 32~ _ _ Tubing ' .888 8.50 L-8t1 2.441 ~ 3,461.15 1,'1.73.4 1,3(k'i.5 25.3 23 ~ -} ~ 108 31 ~ Thing ,868 8.50 L-80 2441 _ 3.493.13 1,:!41 A 1,273.4 2S.~i 23 ~_. '~1C~ 3094 Tubing .868 8.50 E-80 2-441 3,524.07 1,'L10.5 3,241.4 25.7 23 ~' 110 31.97 Tubing .888 8.50 L-80 2.449 3,558.04 1,178.5 1,210.5 25.9 23 = 111 32.02 Tuhbtg .868 6.bQ G80 2441 3.588.08 1,tA6.5 1.178.5 28.2 23 _ 112 29.15 Tutsing _.__. ~ - ~~ .888 8.50 L-Sfl 2.441 3,817.21 1,417.4 1,148.5 26.4 24 113 32.00 Tubing .868 6.50 t_-80 2.441 3,849.21 1 fl85.a 1,117.4 28.8 24 114 32.10 Tul~ng .668 850 L-80 2.441 3,881.31 1,053.3 1,085.4 28.9 24 116 31.98 Tubing .668 6.50 L-80 2.441 3,713,29 1,041.3 1,053.3 27.1 24 116 31.99 Tubing .688 8.50 L-80 2.441 3.745.28 989.3 1,021.3 27.3 24 177 31.90 Tubing 6.50 L-80 2.441 3,777.98 95"7,4 9~.3 27.8 25 118 32.00 Tubes .888 8.50 L-~ 2.441 3,809.18 925.4 967.4 27.$ 25 119 32A4 Tubing .888 6.50 1-80 2.441 3,841.19 89:1.4 925.4 28.0 25 _ t20 32.Q8 Tubi .686 8.50 L-~3 2.441 _ 3,873.27 88fi.3 893.4 28.3 25 121 32.09 Tubing .668 6.50 L-8<! 2.941 3,808.96 2 881.3 28.5 25 122 32.03. Tub»~ .6'68 6-50 L-.88 2,441 _ 3.937.38 797'.2 829.2 28.7 28 123 3197 Tttlxing .888 8.50 L-80 2.441 _ ~ 3,969.35 78.''1.2 - 7972 329.0 ~ 124 31.72 Tubing .~ 6.50 L-SO 2.441 4,001,07 73:1.5 785.2 29.2 28 925 32.E Tu6irig .868 8.50 L-~ 2.441 4.033.07 701.5 733.5 29.4 26 _ 128 31.97 Tubing .668 6.50 L-80 2.441 a,t185.04 X3,5 7fl1.5 29.7 28 127 3206 Tutting .888 8.30 L-80 2.441 _ 4,t?97.10 63Y.5 86'9.5 29.9 27 ~ 928 32 Tubirxg .888 6.SD L-80 2.441 4,129.14 605.4 637.5 30.1 27 129 32.00 Tubing .668 8.5D L-80 2441 _ 4,167.14 57:1,4 605,4 30.4 ?7 130 31.97 Tubing .88$ 6.50 1.-80 7.449 4,193.19 549.5 573.4 30.8 27 131 37.98 Tubing .688 8.50 L-&3 2.441 4,225.08 504!.5 541.5 30.8, 27 132 32.06 Tutring .~8 6.50 L-80 2449 4,257.15 47"!.4 309.5 31,9 28 1.12 Catnc+o "DS" Mppie w! 2.30' DrHt .868 8.50 L-8fl 2.312 4,258.27 47t:.3 477-4 31.1 28 _ 133 31.98 Tub~g ..888 8.50 L-~ 2441 4290.26 44A.3 478.3 37.3 28 _ F 134 32.04 Tutring .868 8.50 L.BO 2941 _ 4,322.30 411.3 444,3 31.5 28 _ 133 30.98 Tutdnq .888 8.50 1,80 2.441 4,363.28 381.3 4123 31,8 28 : 138 32.02 Tubing .888 8.50 L~80 2.941 _ 4,385.30 34$.3 3$1.3 32.0 29 _~ 137 3208 Tubing .688 8.50 L,80 2.441 4,417.38 31%2 349.3 32.2 29 138 32.03 Tubi~tg .668 6.50 L,80 2.441 4,449.41 285.2 317.2 32.5 29 139 3L96 Tubing .868 8.50 GSO 2441 4,481.38 253.2 285.2 32.7 29 140 32.02 Tubilg _ .888 fi.~ L-80 2.441 4,513.38 221.2 253.2 32.9 29 1 . 141 _32.D6 Tubng .8Yi8 6.60 L-80 2.441 4,545.44 188.1 221.2 33.2 30 142 31,98 _ 7utring __ .. .888 8.60 L-~ 2.441 4,577.42 1572 189.1 33.4 30 _ . 143 32.fl3 Tubtng .88$ 8.80 L-80 2.441 4,609.45 125.1 157.2 33.8 ~ 144 32,00 Tubing .668 8.50 L-841 2.941 ~ _ ~, 4.641.45 93.7 125.4 33.8 ~ _~ 9.89 Tubing Pup Joint 2 7f6 6.50 L-80 2.441 4,657.34 $3.2 93.1 ~ 33.9 3a ~ 8.02 Tubing Pup Joint 2 7/8 8.50 L-80 2.441 ~ 4,659.E 76.?. 832 33.9 30 , 145 3206 Tubing .868 6.50 L-~ 2.441 4,894.41 43?. 75.2 34.1 31 _ 1.58 Ct4550ver .868 8.5f3 L-~ 2.750 4,892.99 41_!1 43.2 34.1 31 1.~ Tutxir~ Pup Joint 3 412j 9.30 L-60 2.992 4,894.&5 39.43 41.6 34.1 37 i.i2 Tubing Hanger .868 6.50 L-~! 2.441 4.895.77 3S.t3 39.9 34.1 31 _ 38.80 Original RKB Parker 245 .6681 8.50 L-80 2.441 4.734.57 0.0 39.8 34.4 31 MEMORANDUM . Toy Jim Regg ~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commis DATE: Monday, August 18, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-122 KUPARUK RIV U WSAK 1D-122 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv (~- Comm Well Name: KUPARUK RIV U WSAK 1D-122 API Well Number: so-o29-22905-00-0o Inspector Name: Chuck Scheve Insp Num: mitCS080811130656 Permit Number: 198-149-0 Inspection Date: 8/8/loos Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well tD-t22 Type Inj. w' TVD ssz~ ~ IA Zao zsao zazo zato p.T. 1981490 TypeTest SPT Test psi t soo OA Interval IIVITAL per, P Tubing sso sso aso sso Notes: ~~~~~I~E~ SEr :~ 208 Monday, August 18, 2008 Page 1 of 1 • ~~ ~ STATE OF ALASKA "'"'~- ~ ,~~' ~`i,is ALASKA OIL AND GAS CONSERVATION COMMISSION ! ; +4,., ,~ ,~ REPORT OF SUNDRY WELL OPERATION - - 1. Operations Performed: Abandon ^ Repair Well Q Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing Q ~ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 198-149 / ' 3. Address: Stratigraphic ^ Service ^~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22905-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 71' 1 D-122 8. Property Designation: 10. Field/Pool(s): ADL 25650 • Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 5445' feet true vertical 4201' feet Plugs (measured) Effective Depth measured 5201' feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' PRODUCTION 4697' 5-1/2" 4738' 3541' PRODUCTION 697' 3-1/2" 5435~',~ 1 ~.A~i~f~ AU~G ~~ 200$ Perforation depth: Measured depth: 4788'-4818', 4850'-4886', 4898'-4918', 4944'-4954', 4964'-4992', 5013'-5026', 5034'-5050', 5060'-5080', 5090'-5108' true vertical depth: 3566'-3615', 3645'-3678', 3689'-3708', 3732'-3741', 3750'-3777', 3796'-3808', 3816'-3831', 3840'-3859, 3868'-3885' Tubing (size, grade, and measured depth) 2-7/g", L-80, 4735' MD. Packers &SSSV (type 8~ measured depth) Baker GBH-22 SBE @ 4723' no SSSV ~' C , . L.K.. (~ V\~~~tG-('~ 12. Stimulation or cement squeeze summary: ~~ Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 38 -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 ' Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ Q WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.o. Exempt: 308-192 Contact Cody Gauer @ 263-4802 Printed Name Title Wells Group Engineer Signature Phone: 263-4802 Date ~~-- ~~--~~j Pre aced b Sharon All -Drake 263-4612 Form 10-404 Revised 04/2006 ^ ~ ~ jX~' ` ~~ ~ ~ Submi Original Only ~ , ~ ~/~~' C©nocoP"~illips Time Log & Summary N!¢'jv7EW Web RepoFting Report Well Name: 1 D-122 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 6/12/2008 3:00:00 AM Rig Release: 6/14/200812:30:00 PM Time Lo s Date From To Dur S. De th E De th Phase Code 5ubcode T Comment 6!11!2008 24 hr summary Move Nordic Rig 3 from 1 C-11 to 1 D-122 21:00 00:00 3.00 MIRU MOVE MOB P Moving Nordic Rig 3 from 1C-11 to 1 D-122 6/12/2008 Continue to Move Nordic Rig 3 from 1 C-11 to 1 D-122 MIRU and Pull BPV. Circ and kill well w/ 9.2 w/ 6% KCL. ND Tree NU BOPE -Test 250/2,500 si Load i e shed w/ 2 7/8 Tb . 00:00 03:00 3.00 MIRU MOVE MOB P Continue to move Nordic Rig 3 from 1 C-11 to 1 D-122 03:00 05:00 2.00 COMPZ RPCOM RURD P Hang tree, spot rig equipment, bring lubricator to floor 05:00 06:00 1.00 COMPZ RPCOM RURD P Lubricate out BPV. 06:00 08:00 2.00 COMPZ RPCOM RURD P RU hoses in cellar, load 9.2 KCL into its. 08:00 10:30 2.50 COMPZ RPCOM RURD P RU kill tank and hardline. PT to 2500 si. 10:30 12:30 2.00 COMPZ RPCOM CIRC P ' ' T/IA = 250/250 psi,,. Circulate 9.2 KCL down tubing, up the IA @ 3 bpm. Pumped a total of 131 bbl. Final SIP T/IA = 0/0 si. 12:30 19:00 6.50 COMPZ RPCOM NUND P Set BPV. ND tree, NU BOPS. 19:00 22:30 3.50 COMPZ WELCTL BOPE P Test BOPE 250/2,500 osi, Draw down test: Start 2950 End 1950 200 in 35 sec. FR 1 min 36 sec. 4 Bottles 2200 si. 22:30 00:00 1.50 COMPZ RPCOM OTHR P Load pipe shed w/ 2 7/8 8rd AB Mod. R&T, drift 2.347" 6/13/2008 Continue to Load pipe shed w/ 2 7/8 Tbg. BOLDS and Pull hanger to rig floor. Lay down hanger and reverse circ 2 BU. Pooh and lay down 3 1/2 tbg completion. Change rams to 2 7/8 and test. MU and Rih w/ 2 7/8 Completion. Spot corrosion inhibited 9.2 brine . Land hanger w/ Bottom of seal assy @ 4,734', RILDS. 39 bbls lost toda . 00:00 01:30 1.50 COMPZ RPCOM OTHR P Continue to load pipe shed w/ 2 7/8 Prod. string. Rack, tally and drift w/ 2.347" 01:30 03:00 1.50 4,727 4,689 COMPZ RPCOM OTHR P Pull BPV. BOLDS and tbg elongated x 1'. Pull seals from SBE @ 4,725' @ 120k -pull free. Pull han er to ri floor 72k u wt. 03:00 03:30 0.50 COMPZ RPCOM CIRC P Reverse circulate 100 bbls 9.2 ppg brine w/ 6% KCL @ 5 bpm @ 1,180 si. 03:30 10:00 6.50 4,689 0 COMPZ RPCOM PULD P Pooh la ing down 3 1/2 tbg and strapping the same f/ 4,689' U0. LD seal assembl . 10:00 13:30 3.50 COMPZ RPCOM SFEQ P change out LPR from 3-1/2" to 2-7/8". PT 250/2500 si. Page 1 of 2 • Time Logs Date From To Dur S De th E. De th Phase Code Subcode T Comment 13:30 14:30 1.00 0 COMPZ RPCOM PULD P MU seal assembly 14:30 20:00 5.50 4,736 COMPZ RPCOM RCST P RIH with 2-7/8"completion string to 4,736'. Tag no-go @ 4,726'. Verify seals are in by Pressuring up to 250 si on IA w/ no comunication t 20:00 21:30 1.50 4,736 4,700 COMPZ RPCOM HOSO P Space out and install hanger and landin 't. 21:30 23:30 2.00 4,700 COMPZ RPCOM CIRC P Wait on corrosion inhibitor and Reverse circulate 5 bbls corrosion inhibited 9.2 ppg brine followed by 32 bbls clear brine, then 33 bbls corrosion inhibited 9.2 ppg brine followed by 5 bbls clear brine fo total of 75 bbls of calculated space out @ 4 b m 500 si. 23:30 00:00 0.50 4,735 COMPZ RPCOM OTHR P Rinse stack, land tbg w/mule shoe @ 4,735' and no go @ 4,723'. 58k up wt, 50k do wt and 35k block wt. RILDS 6/14/2008 PT tbg and IA @ 2,500 psi and chart for 30 minutes. Shear out SOV @ 750 psi. RD PT equip. and BO landing jt. Set TWC . ND ROPE. NU tree PT 250/5000 psi. Pull TWC, freeze protect tubing and IA down to 2000' with diesel. Set BPV. RDMO. Nordic Ri 3 released from 1 D-122 12:30 m on 6-14-08 00:00 02:30 2.50 4,735 COMPZ RPCOM DHEO P RU to PT. Drop ball and rod. PT and chart Tb 2,500 psi for 30 min. Bleed down to 1,750 psi. Pressure u to 2 500 on IA and chart for 30 minutes. Tbg increased to 2,100 psi. Dump tbg pressure after test was final and shear out SOV @ 750 si. RD PTE ui ment. 02:30 03:00 0.50 COMPZ RPCOM OTHR P Set TWC. 03:00 05:00 2.00 COMPZ RPCOM NUND P ND BOPE and replace 2 7/8 rams w/ 3 1/2 rams. 05:00 05:30 0.50 COMPZ RPCOM SFTY P Performed pad evacuation drill with Nordic 2 CTD rig. Tested Nordic 3 rig ESD s stem. 05:30 10:30 5.00 COMPZ RPCOM NUND P Con't ND BOPE. NU tree. Test 250/5000 si. 10:30 12:00 1.50 COMPZ RPCOM FRZP P RU up to freeze protect. Pump 52 bbl of diesel down the IA taking returns up the tubing. Pumped 2 bpm @ 1250. Allowed to u-tube for 30 min. RD hoses. 12:00 12:30 0.50 COMPZ RPCOM OTHR P Set BPV. Nordic Rig 3 released 12:30 m on 6-14-08 from 1 D-122. Page: F taf 2 ;` `~~ Cr~nocoPhilli~ I I ..~_i~_n-3 -lei-I I: , ~M nl:rg Nar~r, 3a c,oe4 aer, 4z KU P 1 D-122 ~.. ~ ,xt Im InGlnaROn (°) Total Uepth (RKB) 53.72 5.445.0 wnd Distance (R) Rig Release Date 35V: NONE Last WO: 6/14/2008 47.99 8117/1998 notation Depth (111(8) End Date Annotation End Date 1st Tag: 5,207.0 ~ 5/18/2008 Rev Reason: WORKOVER 6/17x2008 r wing Description OD (in) ID (in) Top (RKB) Set Depth (Tti(B) Set Depth (TVD) (Po(B) VJt (Ibsllt) Grade ~ Top l:onneGit ONDUCTOR 16 15.062 0.0 121.0 121.0 62.58 H-40 Welded Isirg Description OD (in) ID (In) TOp (RKB) Set Depth (RKB) Set Depth (TVD) (RKB) VJt (Ibs/R) Grade Top Connectk ~ODUCTION 1 5 1/2 5.000 10.0 4,748.0 3,549.9 15.50 L-80 BTCM Isirg Desuiptlon OD (in) ID (in) Top (RKB) Set Depth (RKB) Set Depth (TVD) (RKB) Wt (Itu/ft) Grade Top ConneGic iODUCTION 2 3 1x2 2.992 4,748.0 5,445.0 4,200.7 9.30 L-80 EUE 8rd ....,~~ s IbingDesdiptbn OD (n) _y IID (n) ~ T p (hK... 5 t 0 rm trr B) S t Depth (ND) (fIKB)~Wf (Ibs/R) Grade Top Connect or,~ 7/8 completion 3.668 2.441 0.0 a ''a 3,5376 650 L-80 ';;I b ;, 3. i~,,,3., s r_ „ ~ op I1tit81 Item Description I Comment I ID 1 CONDUCTOR, 0.121 NIPPLE, 478 Btm Shot Celcal. Dens Shot sho... Total INJECTOR, 4,633 NIPPLE, 4,680 B, 1 D-122 IPERF WS A4, 10-122 IPERF WS A3, 10.122 IPERF WS A3, 1o-1z2 IPERF WS A2, 1D-1zz IPERF WS A2, 10.122 IPERF WS A2, 1o-1zz IPERF WS A2, 10.122 Annotation BBE, 4,723 PRODUC710N 1, 10.4,748 Stn Yaive latch Pert TFN kun Make Model OD Iln) ~ TYPe ~ TYPe Size pn)~ (Pail TD, 5,445 PRODUCTION 2, 4,7485,40.5 • • _.~ ~ ~ ~ ~ SARAH PAL/N, GOVERNOR AI,ASSA OII~ Al`D CsA5 333 W. 7th AVENUE, SUITE 100 C01~T5ERQA7`IO1~T COM11II551O1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX`- (907) 276-7542 Howard Gober Wells Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360. ~~E~ a~N ~ 2D08 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1D-122 Q ~ ~(~ Sundry Number: 308-192 `~ u Dear Mr. Gober: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~2~ Daniel T. Seamount, Jr. Chair -~4 DATED this 3° day of May, 2008 Encl. O p nocoPh i l i e ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 30, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: WO~4.r. MAY 3 0 2008 Alaska Oif & Gas Cons. Commission Ancfloraga ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the West Sak Well 1 D-122 (PTD# 198-149). Injecting well 1 D-122 was drilled and completed in 1998. The well operated on water injection until August 2007 when it failed an MITIA. Tubing by Inner Annulus communication was suspected and a caliper survey was run to identify leaks. A caliper PDS log was run showing wall penetrations in excess of 20% in 132 of 164 joints logged. Based on this, the tubing will be replaced with smaller diameter tubing for more effective corrosion control The purpose of the proposed workover will be to pull the existing 3-1/2" tubing string and replace it with a new 2-7/8" tubing. Attached is a proposed schematic along with a general workover procedure. Due to a last minute rig schedule change this well has moved up in the order to after 1C-11. Nordic 2 and Nordic 3 are both moving to 1 D pad. Due to proximity issues of the 2 rigs, we had c-~ to do the workover on 1 D-122 instead of the 1 D-113 well we had planned to move to. The workover should begin on 6/2/08 or 6/3/08 If you have any questions or require any further information, please contact me at 263-4220. Regards, Howard Gober Wells Engineer CPAI Drilling and Wells • ~3~~ (~ Cj STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION R~~~IVE'~ MAY 3 0 2008 APPLICATION FOR SUNDRY APPROVI~~fCe 0'f & Gas COnS. Commi~~{or~ Anchorage 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ Other ^ Alter casing ^ Repair well ^/ - Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing Q - Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 198-149 ' 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22905-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y2S ^ NO ^~ 1D-122 •. 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25650 RKB 41', Pad 71' Kuparuk River Field /West Sak Oil Pool , 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5445' , 4201' • 5312' Casing Length Size MD ND Burst Collapse CONDUCTOR g0' 16" 121' 121' PRODUCTION 4697' 5-1/2" 4738' 3541' PRODUCTION 697' 3-1/2" 5435' 4191' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): see below' see below" 3-1/2" L-80 4727' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat June 2, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ 0 WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Howard Gober @ 263-4220 Printed Name Howard Gober Title: Wells Group Engineer Signature ~~ Phone 263-4220 Date 5/ wC7 r;?~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test' Mechanical Integrity Test ~ Location Clearance ^ Other: a S V ~.J ~~ ~ \J Q ` '~ ~'~'- Subsequent Form Required: ~D Approved by: -__ COMMISSIONER APPROVED BY THE COMMISSION Date: O ~'~788r-4818r 4850'-4886', 4898'-4918', 4944'=4954', 4964'-4992', ~~}} pip 5 6p,'~p80', 5090'-5108' MD Form 10-403 Revised d6/ 6 'll~R-'~: ~UEy ~ tUU~ Submi in Duplicate ~RIGI~iAL ~ ~ s~~ West Sak 1 D-122 General Workover Procedure 5/30/08 .Pre-Riq Work 1. Obtain an updated SBHP reading .(Done 5/18/2008- 1747 psi at 4948' RKB, 3736' TVD. 9.0 ppg kill fluid with no overbalance) 2. Tag fill. (Done 5%18/08 -Tag at 5233' RKB) 3. _Pull DV at 4622'MD (Done 5/18/08) 4. Set 3" CIW H BPV - 5. Prepare location for arrival of Workover Rig General Workover Procedure 1. MIRU Nordic 3 2. Pull BPV. Load well with 9.2 ppg brine. 3. Set BPV. ND tree. MU blanking plug. 4. NU 11" 5M BOP with 3.5" and 2.875" pipe rams. Pressure test to 250/2,500 psi.- (The last SBHP measurement at the mid pert (4948' RKB, 3736' TVD) was 1,747 psi on 5/18/08. The calculated maximum possible surface pressure assuming a gradient of 0.1 psi/ft is 1,373 psi.) 5. Pull 3.5" tubing and. run new 2.875" tubing completion 6~ Prior to setting new completion, load IA with corrosion inhibited brine 7. Drop ball and rod. Pressure test tubing and IA to 2500 psi. Shear SOV. 8. Set 2 way check 9. ND BOPE, NU tree., and pressure test 10. Pul) 2 way check. Freeze protect well. Set BPV. 11. RDMO workover rig Post-Riq. Work 1. Pull BPV 2. Pull ball and rod. 3. Pull SOV and set DV in GLM 4. Pull RHC plug in nipple 5. Return`to injection Well: 1 D-122 API: 50-029-229-0500 ~OC"10CQ~'tl~~S Field: WestSak PTD: 198-149 2008 RWO REVISED PROPOSED COMPLETION A NEW COMPLETION WELLHEAD Lift threads: 3.725" MCA TUBING BPV: 3" CIW H 2-7/8", 6.5 ppf, L-80, 8rd-MOD Model: Vetco West Sak Inj _ A: Nipple: CONDUCTOR 2 7/8" with 2.313" DS @ 500' MD 16", 62.58 ppf, H-40, welded B: Gas Lift Mandrel- _ SURFACE CASING B No. MD TVD TYPE No Surface Casing in this Well c 1 -4,622 .3,435' 1" KBMG C: Nipple: 2-7/8" with 2.25" D profile D PRODUCTION-CASING - 5.5", 15 ppf, L-80, BTC-MOD D: Seal Assembly @ -4,726' MD TUBING and LINER 3.5", 9.3 ppf, L-80, 8rd-MOD . PERFS. WS D: 4,788'-4,818' MD Last Tag: 05/18/08 WS B: 4,850'-4,886' MD ' ' Tag Depth: 5233' RKB WS A4: 4,898 -4,918 MD Fill: NO FILL 125' of Rathole WS A3: 4,944'-4,954' MD ' ' TD: 5,445' RKB 4,964 -4,992 MD WS A2: 5,013'-5,026' MD 5,034'-5,050' MD 5,090'-5,108' MD .Last Updated: 22-.May-08 Updated by: CLG I I I I I I I I I I I I I I I I I I ~ I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. September 10, 2007 9510 2 3.5" 9.3 lb. L-80 Tubing Well: 1D-122 Field: Kuparuk state: Alaska API No.: 50-029-22905-00 Top Log Intvl1.: Suñace Bot. Log Intvl1.: 4,904 Ft. (MD) Inspection Type : COMMENTS: Corrosive & Mechanical Damage Inspection This caliper data is tied into the DS Nipple @ 4,681 ' (Drillers Depth). This log was run to assess the condition of the 3.5" tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the 3.5" tubing interval logged is in good to poor condition. A maximum wall penetration of 80% is recorded in joint149 @ 4,767'. Overall, wall penetrations in excess of 20% are recorded in 132 out of the 164 joints logged, excluding the know perforations. The damage appears in the form of isolated deeper pits, general corrosion and line corrosion. No areas of significant cross sectional wall loss are recorded. A minimum 1.0. restriction of 2.33" is recorded in joint 153 @ 4,874'. This is the second time a PDS caliper is run on this well. A comparison between the current log and the previous (July 30, 2005) indicates no significant change in corrosive damage. Some of the maximum penetrations recorded in this recent log do not measure as deep as those from the previous log. This appears to be due to some of the deeper penetrations falling between the caliper fingers and some influence by the accumulation of light deposits. A comparison chart is presented in this report. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Line Corrosion ( 80%) Jt. Line Corrosion (70%) Jt. line Corrosion ( 70%) Jt. Isolated Pitting ( 68%) Jt. Isolated Pitting ( 67%) Jt. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: 149 @ 147 @ 69 @ 129 @ 56 @ 4,767 Ft. (MD) 4,655 Ft. (MD) 2,206 Ft. (MD) 4,065 Ft. (MD) 1,781 Ft. (MD) No areas of significant cross sectional wall loss (>12%) are recorded in the tubing interval logged, excluding areas with known perforations. MINIMUM RECORDED ID RESTRICTIONS: Deposits Deposits Deposits Min. 1.0. = 2.33" Min. 1.0. = 2.36" Min. 1.0. = 2.42" 153 @ 152 @ 154 @ 4,874 Ft. (MD) 4,862 Ft. (MD) 4,904 Ft. (MD) Jt. Jt. Jt. I Field Engineer: Carpenter/MilJer Analyst: B. Qi Witness: C. Kennedy ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 5GANNED SEP 1 9 2007 () Ie. 10, 1)- 14C W>- I bLf 1'3 I I Pipe 1 I I I I I I I I I I I I I I Correlation of 3.5 in (41.6'- .... Q) .Q 80 E :;¡ z ..... .S; .g 100 GLM 1 I Bottom of 50 rvey "" 154 I I Damage to Profile WeD: field: 10-122 ConocoPhiRips Alaska, inc. USA September 10, 2007 Tool DeviatiOll Borehole Profile 20 40 60 120 140 154 o 50 Profile wall) I Tool Deviation 42 645 1273 1901 2524 ti ¡;:; 3152 3771 4394 4900 100 I I I I Wel/: Fie1d: Company: Country: Survey Date Prevo Date: Too!: Tubing: 1D-122 Kuparuk ConocoPhmips Alaska, Inc. USA I I September 10, 2007 JUly 30,2005 UW MFC 24 No. 212330 3.5" 9.3 Ib l-BO Max. Rec. Pen. (mils) Diff. ìn Max re". (mì!s) -100 -50 0 50 100 0 100 200 10 20 30 40 50 60 j¡ 70 f E ::> 80 z Z ! E 2. 90 100 110 120 130 140 147 -47 ·24 0 24 Appro>< û",osjo" Rate (mpy) I I I I I I I I I I ¡I I I I I Weil: Field: 1 !J..122 Kuparuk I USA I Weight 9.3 f Grade & Thread 1..,.80 Nom.GD 3.5 ins I Penetration and Metallos¡¡ penetration 150 metal loss body I 100 I 50 o 0 to 1% 1 to 10"1" I sed 20 5 o 6 4 149 I I Configuration ( body) 80 I 60 40 20 o isolated genera] line ring hole I pass pitting corrosion cOITosian caITasian ible höle I I I I !ne. over 85% 3 o NomAD 2.992 ins GlM 1 10, 2007 UW MfC 24 No. 212330 1.69 24 B. Nom. Upset 3.5 ins len. 6.0 ins Profile penetration body o 1 metal loss 50 100 Bottom of Survey = 1 S4 Analysis Overview page 2 I I I I Joint No. I I I I I I I I I I I I I 3.5 in 9.3 0.254 in 0.254 in 2.992 in o o o 0, Jt Depth PerL Pen. Ppn,! Me!al ~: ~~~(~ t :~ in --1...- 42 ---.1:L 73 2 84 3 115 4 146 5 178 6 ~ 10.02 7 7 ~ I 0.05 21 1~O ~~~ II 11 36 ~' g 0.4 ~7 003! 15 488 (! 0.02 16 519 17 "'10 18 '1R1 19 613 20 64 21 67 22 7D 23 739 24 770 25 801 26 833 27 f3Et863 0 28 29 30 957 31 9 8 32 H W 33 H 53 34 1084 35 1115 36 1'146 37 1178 38 1210 39 1242 40 1773 41 1303 42 1335 43 1366 44 1397 45 1429 0, ,17 46 1460 47 48 1527 49 1 554 o o o 012 tlt "1? 0.11 0.10 0.12 0.11 0.11 0.12 0.11 0.12 2.93 I 796 I ~,§4 2.92 2.94 Shallow oit1in2. 7.% i 2q 2.9 J 2.9 14 ,I, 2.!}) :i .~ 2.!}2 2.95 ShallQW piUinl:!:. 2.94 Shallow pit1ing. 2.93 Shallow oitliml. '--I' sola ted Di,iU¡·og. Isolaœd oittiml. Isolated oittinll. Isolatet! Dittinll. oiUinll. 2.9 lsolatec oittinll. '--- ~ lsolaæd pitting. Isolated oithl1g. . 3 Isolated pitting. 2.94 Isolated oittinll. so!aœd oiUinll. isolaæd oittinll. lsolaæd oittinll. I=!ated pitting. Isolated oitting. Isolated Ditting. lso!aœd oittinll. Isolated oit1ìoll. isolated oiWnll. I=!ated pitting. Isolated pitting. L-80 19 0.06 o JOINT ¡ ¡ 2.95 .94 .94 .94 .95 2.94 4 ¡ ¡ 2.94 tB~ Well: Field: Min. 1.0. (Ins.) Shallow oiUml:. UtATION SH 10-122 Kuparuk Cono(".()Philips USA 10, 2007 Comments loe. .~ Profile wall) o 50 100 I I REPORT JOINT TABULATION I I Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0,254 in 2.992 in Wen: Field: 1 0-122 Inc. USA 10, 2007 I Joint J1. Depth Pen Pert Pen. l\Aplal Min. ~ Profile No. W. Comments (0/" -,vall) (Ins.) (Ins.) (Ins.) 0 50 100 50 11 ;~ Isolated oittin£ 51 1617 .10 Line corrosion 52 1648 .13 line corrosion. 53 1679 2.93 line corrosion. 54 1711 0 2.'H 1 iUins;¡; 55 1743 0 44 294 orrosion. 56 1774 0 292 Isolated oiWnlt 57 1005 0 I 2,91') Isolated oiUin£ 58 1837 0 Isolated oinin£ I t Deno.<;its. 59 1ru;q 0 Z Corrosion. 60 Isolated oittin£ 61 1932 4 62 1963 ¡ 6 2.93 Corrosion. U. Oel1o<;its. 63 1~ II Corrosion 64 2025 line corrosion 65 2056 0.12 line corrosion 66 2~1R 67 1119 4 2.94 Isolated DiUinQ. 68 71')1 5 2.93 ! in", (,f>rrosion 69 71ft2 0 0.18 7.94 Line corrosion. It. f)prw:;it<;. 70 2 H "0.15 iti Isolated DiUinQ. 71 2 44 0.12 Isolated oittinlt It f)poosits. 72 2 7f> O. )4 0 13 Corro<;ion. U. DelJOSÏts. 73 2308 0 )6 0.14 Isolated oittinlt ]4 ~ 0.15 293 Corrosion. 75 17 0.14 2.94 76 2401 0.12 2.94 Corrosion. U. f)enm:¡ts. 77 2432 0 0.12 2.95 Corrosion. 78 2463 0 0.14 ~ Corrosion. It Deoosit<;. 79 2495 0 Isolated Pittin~ 80 2524 0 it 2.92 Corro<;ion. It DerJOSits. 81 2558 0 J? 0.1 2.92 Corrosion. U. Deoosits. 82 2588 0.1 ' 2.93 ittins;¡; 83 2620 0.13 84 2650 0.14 it I in. """"ion. 85 2682 0.13 Corrosion. U. Denosits. 86 2713 n n 014 !.;olaled pittinlt 87 2745 0.12 2.95 Corrosion. 88 2776 0.14 296 Isolated oiUinlt L1. Deoosits. 89 2807 =tm 2.93 Line corrosion. U. DelJOSÏts. 90 2839 2.92 Isolated oiWn2:.. 91 2871 2.93 tl . 92 2901 2.Q<; orrosion. 93 2932 0.11 d=f 2 91 Corrosion. It DerJOSíts. 94 2964 0.15 293 Isolated piWnlt 95 2995 I 0.13 2.93 Corrosion. 96 3027 D. 16 0.12 I 2.91 Isolated DittínQ. 97 3058 0.12 ~ Corrosion. 98 3088 [ 0.11 Isolated oittin£ 99 3119 0 010 -7.95 Corrosion. I I I I I I I I I I I I 2 I I I I PDS REPORT JOINT TABULATION SHEET I Pipe: Body Wall: UpsetWaU: Nominal I.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in We!!: Reid: Company: 10-122 Alaska, Inc. USA 10,2007 I Joint Jt. Depth Pen,! Pen. Pen, I Metal Min. -o~ No. W. Comments wal!) (Ins,) (Ins.) (Ins.) 0 50 100 100 1184 ~ =Mt ~ Idp¡terl nitlipo 101 i soiat"'''¡ niWoo 102 3214 1 'J 'Jh Corrosion. 103 3245 fï': 1 4 Ii ' .95 Corrosion. 104 3277 0.11 q ¡ .93 n. U. Deno<:it<:. 105 3308 010 Corrosion. 106 3340 0.12 C-orrosion. Lt Denosit<:. 107 3368 0.11 if Isolated niUiI1º 108 3399 0.12 109 3430 II ttinoi t f)erv'sits. 110 ;; ì 0.11 "- line corr""ion. i t. f)e""""¡ts. 111 3493 Line COfrosion. 117 3524 line corrosion. 113 3554 Une corrosion. Lt. Denosit<:. 114 3S85 n or:¡ 14~ 2.94 l<;nalel'l nitti"cr 115 3617 n O.1~ 4( I 2.95 Cor"""'ion. ~tt =tH x~ ! ine corrosion. 117 3679 1.')3 Isolate njtti"o 118 3710 2.92 lsolat"" nittind 119 3741 0 "1 2.97 j solate PO 1771 <] 0.12 Iii Line corrosion. 121 1M, U 0.13 4 Une corrosion. 122 3834 Isolp¡tpd n¡Uino 123 3866 2.94 Isolated "¡Wno 124 3897 2.95 Cor """,io n. 125 3929 Line corrosion. 126 3959 line corf""ion. 127 3992 line corrosion. 128 4023 0.16 2.95 Isolated n¡ttin<> Lt.. Denosits. 129 4054 2.94 Isolated nittinŒ 130 4082 Il11 2.94 line rnrrosion. 131 4115 0.12 2.95 Line corrosion. 132 4147 ~~.~~ Une corrosion. Lt. Dpnn<åts. 133 4177 line corrosion. 134 4208 .1O:¡ 7.95 Isolated níttina 135 4239 nm 0.13) =N: line corro;;ion. 136 4271 n 0-1 <; Line ....orrosion. 137 4300 -Õ-e) 2.93 line corrosion. 11ft I 4331 0.13' ~=Ht Corrosion. 139 4363 0.12 line corrosion. 140 4394 0.11 ) 2.97 line corrosion. 141 4425 n H 0.11 I) =m line corrosion. 142 4457 0.14 Une corrosion. 143 4488 Corrosion. 144 4'>20 c¡- 2.93 Corrosion. 145 4552 0.1 Corrosion. 14fi 0.12 in". rnrrosion. 146.1 4607 n i¡:·, 0.14 ¡:¡:;¡: UP Une corrosion. Lt. Denn,,¡ts. 146.2 onl ¡ ¡:, n NA LM 1 { atrh @ 1:00\ 146.3 4628 . ! 0.14 I S7 r; I 2.94 PUP line cnrrosion. Lt. Denosits. I I I I I I I I I I I Body Metal Loss 3 I I PDS REPORT JOINT LATION SH I Pipe: Body Wall: Upset Wall: Nominal I.D.: 3.5 in 9.3 0.254 in 0.254 in 2.992 in L-80 Well: Fièld: Company: Country: Survey Dat€: 10-122 Kuparuk ConocoPhiUips Alaska, Inc. USA September 10, 2007 I I I joint No. Comments I I I I I I I I I I 4 I o Profile wail) 50 100 - - .. -- ----- - - -- - s rt s s Well: 10·122 field: f(uparuk Alaska, Ine. Country: USA Tubin : 3.5 ins 9.3 f L·80 10, 2007 UW MFC 24 No. 212330 1.69 24 B. i Tool Size: No. of Ana! st for 7ft Too! '" 43 10'" 2.992 Nominal OD '" 3.5 Too! deviation'" 26 " Line Corrosion ,20 ins'" 80% Wall Penetration HIGH SIDE '" UP Cross Sections page 1 .. .. .. .. Well: 10-122 Field: Alaska, Inc. USA Tubin : 3.5 ins 9.3 f L-80 .. .. .. .. .. .. .. .. rt s 10,2007 UW MFC 24 No. 212330 1.69 24 B. ¡ Tool '" 43 Nominal 10'" 2.992 Nominal 00 '" 3.5 Too! deviation'" 26· it Line Corrosion .18 ins'" 70% WaH Penetration HIGH SIDE'" UP Cross Sections page 2 .. .. - ............ .............. ...... .. .. PDS C Sections WeU: 10-122 lOi 2007 Field: UW MFC 24 No. 212330 Ajaska, loe Tool Size: 1.69 USA No. of 24 Tubin : 3.5 ins 93 f l·80 Anal !it: B. ¡ ft Tool '" 43 NominallO 2.992 Nominal 00 '" 3.5 Tool deviation'" 25· Deposits Mio 1.0. '" 2.33" HIGH SIDE'" UP Cross Sections page 3 ------ ------- ------ PDS rt ross ons Wen: 10- 122 ffeld: Kuparuk Inc. USA Tubin: 3,5ìns 9.3 f L·BO Survey Date: Tool Tool Size: No. of Anal st: 10,2007 UW MfC 24 No, 212330 1.69 24 B. i ft Tool = 43 Nominal fO = 2.992 Nomina! 00 = 3.5 Tool œviatlon = 250 Min 1.0, '" 2.36" HIGH SIDE = UP Cross Sections page '5 I KRU 1 D-122 I I I I NIP I (4681-4682, OD:3.5OO) I I SSE I I Perf (4781>-4818) I Perf ( 4850-4800) Perf (4898-4918) I Perf (5013-5025) I I I I I I I 1D-122 (PTD 1981490) failed MITI. Regg, James B (DOA) . Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Wednesday, August 22,200710:23 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity proj; NSK Problem Well Supv Subject: 1D-122 (PTD 1981490) failed MITIA Attachments: MIT KRU 1 D-122 08-21-07.xls; 1 D-122 schematic.pdf; 1 D-122 90 day TI plot.jpg .,/ --/" .../" q{S:(07 ~¢111 I Tom & Jim, West Sak injector 1D-122 (PTD 1981490) failed a MITIA on 08/21/07. It was originally reported with suspect T x IA earlier in the day on 08/21/07. The immediate action was to shut in the well and add it to the monthly failed MITIA report. The TI prior to the MIT were 550/875. Preparations are being made to secure the well and perform an Eline LDL to identify the location of the leak. Attached is a schematic, 90 day TI plot, and the MIT form, Please let me know if you have any questions. «MIT KRU 1D-122 08-21-07.xls» «1D-122 schematic'P'?!:.::;S..<j,Q;.1¡2.90 day TI plot.jpg» Brent Rogers . Problem Wells Supervisor 659-7224 S'CANNED SEP 1 1 2007 9/5/2007 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk 1 KRU 110-122 08/21/07 Greenwood/Coleellves - AES '"-1fbr¿ ctfÇ;(ù7 Packer Depth Pretest Initial 15 Min. 30 Min. Welll1D-122 1,;- Type Ini. I N TVD I 3,530' Tubino 550 550 Interval I 0 p.T.D.h981490 /1 Type test I P Test psil 1500 Casing 875 1800 P/F F Notes: Established a LLR of 5.6 gpm @ 1800 psi. /' OA Weill I Type Ini.1 TVD I Tubino I ntervall p.T.D.1 I Type test! Test psil Casing P/FI Notes: OA Weill I Type In¡.1 TVD I Tubino I ntervall P.T.D,I I Type test! Test psil Casino P/F Notes: OA D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1105 /' M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT KRU 10-122 08-21-07.xls (47884818) Perl (48504886) Perl (48984918) (49444954 ) Perl (49844992) Perl (5013-5026) Production . . ConocóPhillips Alaska RECEIVED JUL 1 0 Z007 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Alaska Oil & Gas Cons. Commission Anchorage July 6, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 t~~~' JUL 11 ZOD1 PI " \ '-fq \C\~ Dear Mr. Maunder: " "~. .... _ ... _~ .." -..ø"-'fL Enclosed please find a spreadsheet with a list of wells from the kûparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter 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. Please M.J. Loveland at 907-659-7043, if you have any questions. ~- ConocoPhillips Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement DumDed cement date inhibitor sealant date ft bbls ft oaf 1 0-09 198-065 23" na 5 6/912007 10-101 200-183 2" na 3.2 6/912007 10-1 02 200-075 2" na 3.2 6/9/2007 10-103 202-096 5" na 8 6/9/2007 10-105a 201-202 25" na 38 6/912007 10-106 197-240 2" na 3.2 6/9/2007 10-107 200-177 2" na 3.2 6/912007 10-108 198-187 8" na 12.8 6/9/2007 10-113 198-178 2" na 1 6/9/2007 10-114 198-159 2" na 1 6/912007 10-115 197-232 2" na 1 619/2007 10-116 198-172 2" na 1 6/912007 10-117 197-237 2" na 1 6/912007 10-118 197-229 2" na 1 6/912007 10-119 197-222 2" na 1 6/912007 10-122 198-149 2" na 1 6/912007 10-123 198-170 2" na 1 6/9/2007 1O-125a 200-044 2" na 1 6/912007 10-126 198-108 2" na 1 6/9/2007 10-127 198-109 8" na 2.5 61912007 10-128 198-133 2" na 1 6/9/2007 10-129 197-213 2" na 1 6/9/2007 10-130 197-183 23" na 5 6/9/2007 Kuparuk Field June 9,2007 . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. . To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/ Open Hole/ Mechanical Logs and / or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 {';; ,...-: !s' ._£ \ '2" n r¡p f;¡ '0UQ 1 0 - 106 1) 2) 3) 4) 5) 6) 7) 1 Report MTT Log MTT Log MTT Log 1 Report 1 0 - 122 1 Report 10 - 125A i Signed: I /1 V v! ,'- \ /'~'~ ¡~ " (\1\ ( ¡II r ìÂ¿;t, i¡ n Ii V I j~\J j1 ! , 1;1 (;. /\ \____4 '-:......~ . t:r;i :' 1,,'__~ ~"'__,_'\ ,1_',\\ ~a - ._ Print Name: 13-0ec-06 U.:r:C- I "7"~ --:;fIe ,,040ec-06 v:ri: ."fo '!;D '- 14-0ec-06 U¡é. .;bo -01:1'1 Oaté: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 WEBSITE: ¡o:" E-MAil: _"," -_.-~':)~-">".,') _~" ~_ -""~_':1 .-- ,'.- ..- '~.' ,- .. '·C"·:'~"'''4·,,-_,-._..._·,·._>o_.,;,,,,·"-_,\ D' ,00 _ PDSANC-2006lZ.W ord\Distributioll\Transmittat. Sheets\Transmit.. Original,doc I I I I I I I I I I I I I I I I I I I Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: Pipe2 Desc.: Pipe2 Use: Pipe3 Desc.: Pipe3 Use: . . Memory Magnetic Thickness Tool Log Results Summary ConocoPhillips Alaska, Inc. December 14, 2006 7633 1 3.5" 9.3 Ib L-80 EUE 8RD Tubing 5.5" 15.5 Ib L-80 BTCM Production Casing 16" 62.58 lb. H-40 Welded Conductor Pipe Well: Field: State: API No.: Top Log Intvl.: Bot. Log Intvl.: Top Log Intvl.: Bot. Log Intvl.: Top Log Intvl.: Bot. Log Intvl.: 1D-122 Kuparuk Alaska 50-029-22905-00 Surface 190 Ft. (MD) Surface 190 Ft. (MD) Surface 121 Ft. (MD) Inspection Type: Assess External Co"osive Damage (Metal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing and 5.5" production casing, with some influence from the 16" conductor pipe. Due to the concentric pipe strings in the Jog interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (60'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3.5" tubing, 5.5" casing, and 16" conductor pipe. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval from surface to 190'. A log plot of the entire pass, plus a detailed section of any interval showing damage is included in this report. The Delta Metal Thickness (%) curve in these plots refers to total metal surrounding the MTT tool. A maximum 8% circumferential metal loss is recorded in the interval between 31' - 38'. A 5% circumferential metal loss is recorded in the interval between 3' - 6'. A 3% circumferential metal loss is recorded in the interval between 46' - 58'. A 3% circumferential metal loss is recorded in the interval between 64' - 71'. A 2% circumferential metal loss is recorded in the interval between 12.5' -13.5'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5", 5.5" and 16" pipe. If all of the metal loss is specific to the 5.5" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some ofthe metal loss indicated could be from either the 3.5" tubing or 16" conductor. I Field Engineer: J. Halvorsen Analyst: M. Tahtouh & J. Burton WitneR~, DEC 1 9 ZOLj Pro,i1.ctive Diagnostic Services, P,O, 80\ 1369, Stafford" TX 7ï497 ¡..;none: or (888) 565-9085 Fax: 565-1369 E-rnaH: Prudhoe Bay Field Office Pllone: (907) 659-2307 Fax: (907) 659-2314 U.:r- c.-. /c¡-õ - lL.{D¡ A,ib$ka Oil & Gas Cons. Conllì1¡ssion Anchorage I cia _ J.s.. Magnetic Thickness (10HZ Pass) I PnoAcrivE ÐiA.q.,os"¡c SER"¡CE5, INC. Database File: d\warrior\data\1d-122\60' cals 1d-122,db Dataset Pathname: 10Hz. 1 I Presentation Format: 2,8 scale Dataset Creation: Sun Dee 1708:15:362006 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1150 I -- -- --- -50 Delta Metal Thickness (%) 50 2.8 MTTP01 (rad) 12.8 0 Line Speed (ftlmin) -200 -5.6 MTTP12 (rad) 4 I \ -20 I I I , ^~-- --- --¡---- I .--ì.- - Tree Line~ I Hanger Pup Jt '-- 5% Metal Loss ~ ^^^- ~oo I '-- I -- ¡¡:;:: 2% Metal Loss - - -"'. I 3,5" - '- .- Ji. 1 ;-... --- -.oo- I 20 I ._-~- '- L..._, I-- ! I - - - - - 3 5" COllar- - -oo ì ... --.- - --J----L_L -- oo I Pup Ji. 40 -"- I __ I ff+= 5.5" Collar - 3.5" Collar -- _W_^_ I .- r- I ~ 3% Metal Loss 3.5" -- I - ... - -- Ji. 2 _. I I 60 = '- - -- -OO ____ --"-' '-' -,--,... "-- - ¡. I '-. --. - ,-+--. ^^--" - - I I-- Botto~~fl10Ilar -1- - <' I 16" Condrn It""';;:;;' -- r ~ ..- f---- I ~, l 80 I ~ ~ I \ T I ~ I I, I I I II I I I I I I I I I I I I I I I I I I I I ~ I I . r---- - Ii i I ~I ¡ ! mt- I II ! I I JI f { } '} ~5.5" Collar ~. %_. "-. l. ' I, .¡ 3.5" 5: :?' <.~ :E /~ :; ~ -;r- ::-::;?- I Jt. 3 -", -- - f--- [-,-- --- -. ~._- 100 - -- -- -3 5" Collar~ ~..- --,,-,-- ~ -t- f---..- - II - !'II" "- ~ 1 .- -. -,,- f-·- ¡,- -. ~... i 3,5" , Jt. 4 --- -..- -- - ,-. 120 : ~- , .~. ~-- ,-, -",,, ..--.... _. I -- < m;COllar- - - ff 3 5" tOllar .~ ~ I ~ ~ I ? -- - ..~ Ë - - _.~ ~- 140 - ,-- ( I - --- -.-- --- ~, -.'''- ---- --",,, ,~ -,,-- ""-- ~ 1---- = 3,5" 0 Jt. 5 , .- I - ) ----.. -- -'- ".- '- .- -. ~, --- .- - ~. -- . --- ,..- --1- 160 -_om -- I·.~ -- -. ~.,'- -1 :~1 3.5" Collar .11 1- -'- ~ b ~ v ~ I lÇ 1 5.5" 'vOi .----' ~ r·- - lar 3,5" --- - ---- ---,,, .- Jt. 6 '-' -, -. - ) I 180 -- - -- '~. '- ~- -- -- - "- .~ --- -- - - ~iRE -- - \ ¡. .. <: , -~ - - -..... -. ~' -- ""- --!-/' I- End of lQ9.J__ -¡.. owl .iI" :; -------- -50 Delta Metal Thickness (%) 50 2,8 MTTP01 (rad) 12.8 0 Line Speed (ft/min) -200 1-5,6 MTTP12 (rad) 4 I I I I I I I I I I I I I I I I I I I ~ Magnetic Thickness Tool (10HZ Pass) PROÁcTIvE OIAql'ol<:>Srlc SENCE5, INC. Database File: d\warrior\data\1d-122 0-10'\60' cals 1d-122.db Dataset Pathname: 10Hz, 1 Presentation Format: 2,8 scale Dataset Creation: Sun Dee 1708:15:362006 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 150 -50 Delta Metal Thickness (%) 50 12.8 MTTP01 (rad) 12,8 0 Line Speed (ft/min) -200 -5,6 MTTP12 (rad) 4 -IV I I '- ~- '---.., - ,,- Line Speed Tree ~'^- ¡....- I I Hanger 0 Pup Jt I I -.- ¡----- '-- ---..- / Þ é/< s-' ~:__S / ~,'5(:: c /' : t-- 5% Metal Loss ¿ ,~~ ,> '-. "- +T- ¡--- -- :> ;'" :> I ? I I -- 1--- ,.. -- - ^--- -- '- - ì 10 'ì> ? I ;, I I > ) l' ¡ > .....- 2% Metal Loss { ¡ I·i ¡ I I - '- ---- 3.5" ? - L I Jt 1 < I I I I I I I I I ~ I I ~ , .~~ =--- ? -50 Delta Metal Thickness (%) 50 2,8 MTTP01 (rad) 12.8 0 Line Speed (ftlmin) -200 -5,6 MTTP12 (rad) 4 I I I I I I I I I I I I I I I I I I I ~ JS. Magnetic Thickness T (10HZ Pass) - PnoA.ctfve DIAqNoen-lc SERvicES, INC. Database File: d \warrior\data \1 d-122 20'-40'\60' cals 1 d-122. db Dataset Pathname: 10Hz, 1 Presentation Format: 2,8 scale Dataset Creation: Sun Dee 17 08:15:36 2006 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1 25 Ï-5õ ---- ... Delta Metal Thickness (%) 50 2,8 MTTP01 (rad) 12.8 0 Une Speed (ft/min) ~200 -5.6 MTTP12 (rad) 4 I, ,ll slii31JOII1, ~,I I~ I {I D 'j ~ ( I/~ 3.5" > ~ I> Jt. 1 r;~ r' I I i ,r r~""'" ~'" ~ ",:!" I < t 1-- ,1,/'" ~ ";> ,[ :;::> l)1 ¿ 3 ) t. Þ ( ';? < ) ~: !l -, ( ~ <, \ ~. þ [) (I ) I I ~þ .~~ ( ~ ( 1 ~L¡-. 8% Metal Loss » I,.", :> ('7 ;1 ~ I 1 ~ ~ <: I 3,5" ( ~ , ¡ ì .lL ) "; Pup Ji. ) < ~J ~ ./ 'I:::: "; I( ..-.... I ) '.,,? ~.~ .¡ S 'o, , '::::::;'" ~ :.::::: c () 3~· ~ ~ ~ , ~ <I:":¡ ~~ <:: lî It ( .~ ( I ( ) c ) 40 ¡ 7 .~ ~ ~. J: rJ .1 ( j 1 ( :> ..\ p '1 ) ~ :::> ~~: ~ t;:> '"-., ? ( {. ...,.,.. ~ '0: - =::::; ~ "7 ..¡ r:~ r\ "I, --- -. \.~- ¿ :> <... -~ " 3.5" ::;ollar ( I;;¡:y ~ j ~ ) 1 ~ .> <:::~ > -J [) I 3,5" - (I < D J 1\ .. ~. ( ( ( I Jt. 2 ~ ( ! [> 5.5" Collar 3 f,( þ D / ) ) I I I l/} ( í I I( f ( (/ f/ rl 5' -50 Delta Metal Thickness (%) 50 2,8 MTTP01 (rad) 12.8 0 Line Speed (ft/min) -200 -56 MTTP12 (rad) 4 I I I I I I I I I I I I I I I I I I I cI2s. Magnetic Thickness T (10HZ Pass) PAOÀcTIVE DlAqi'OOSJic Sell\llcB, INC. Database File: d \warrior\data \ 1 d-122 _3 60-80'\60' cals 1d-122.db Dataset Pathname: 10Hz, 1 Presentation Format: 2. 8 scale Dataset Creation: Sun Dee 1708:15:362006 by Cale Sondex Warrior V7.0 Charted by: Depth in Feet scaled 160 ~hickness ('Yo) ., 50 ,. oo 2,8 MTTP01 (rad) 12,8 0 Line Speed (ftlmin) -200 -5.6 MTTP12 (rad) 4 i!1 '"tV I I -.::: Þ. F", 3.5" Collar- - 5,5" Collar - I I...~ ~)~I..; <~ ) c.. ¡ ~> .:: t) / .-,51" /"' (.> ,/ ,,> r .¿¡ ~ ~~ I 50 I I - , I 3% Metal Loss 3,5" I I Ji. 2 i I , I ! I I I I I 60 . I I ,- I ¿ ;> I I ~ ! ! I I I..-. '<'Yo Metal Loss 70 I I I i J I "':: )I;.. ? s_ ;> J" ~:1f~lIar ~ . Bottom of .~ ! I 16" Conductor " J ' -~-- -50 Delta Metal Thickness ('Yo) 50 2.8 MTTP01 (rad) 12.8 0 Line Speed (ftlmín) -200 -5,6 MTTP12 (rad) 4 I I I I I I I I I I I I I I I I I I I PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY KR 1 D-122 '10,.122 API: 500292290500 Well Tvae: INJ Anale!âJ TS: deg@ SSSV Tvoe: NONE Oria Comaletian: 8/17198 Anale!âJ TD: 20 dea !âJ 5445 Gas Lift Annular Fluid: 3%KCI Last W/O: Rev Reason: Taa bv ImO arxtellOummy Reference Log: Ref LOQ Date: Last Uodate: 5/9100 Valve 1 Last T aa: 5275 TD 5445 ftKB ( 4622·4623, ~ Max Hole ¡!âJ 1744 007725) Tubing Size Top Bottom TVD Wt Grade Thread (0·4739, 16,000 0 121 121 6258 H-40 Welded 003,500, 5.500 0 4725 3529 15,50 L-80 BTCM 10:2.992) I 3,500 4725 5435 4191 9,30 L-80 EUE 8rd lADIng ~ Top I Bottom I TVD Wt I Grade I Thread 0 I 4739 3542 I 9,30 I L-80 I EUE 8rd Interval TVD Zone Status Feet SPF Date Type Comment NIP 4788·4818 3587 ·3615 WSD 30 4 3/22199 IPERF 2,5" HC BH (4681-4682, 4850 - 4886 3645 - 3678 WS 36 4 3/22/99 IPERF 2.5" HC, BH 00:3500) C,WSB 4898·4918 3689 - 3708 WSA4 20 4 3/22199 IPERF 2,5" HC, BH Production 4944 . 4954 3732 - 3741 WSA3 10 4 3122199 2.5" HC, BH (0-4725, 4964 - 4992 3750 - 3777 WSA3 28 43/2 2,5" HC, BH 00:5,500, 5013 - 5026 3796 - 3808 WSA2 13 4 3/22199 2,5" HC, BH Wt:1550) 5034 - 5050 3816-3831 WSA2 16 43/22/99 IPERF 2.5" HC BH 5060 - 5080 3840 - 3859 WSA2 4 3/22199 2,5" HC BH 5090 - 5108 3868 - 3885 WSA2 4 3/22199 2,5" HC BH ",.. F Stn MD TVD Man Man I V Mfr , V Type 'V OD ILatchlPort, TRO 1 Date I. Vlv SSE Mfr Type Run Commen1 (4726-4727, 00:4,000) 1 4622 3435 CAMCO KBG29 I CAMCO I DMY I 1,0 INT 00001 o I 9/25198 I ,l!í:ItlÏp.,et! ,}.JeWelrv Depth TVD Type Description ID 4681 3488 NIP S wlNOGO 2,812 4726 3530 SBE Baker GBH·22 3000 Production 5319 4082 PLUG Set 3.5" Baker bridae clue far PBTD of 5319' RKB, 0000 (4725-5435, 5434 4190 SHOE 3,000 003500, Wt:9,30) ~-_._~ ~ Perf ( 4788-4818) --- Perf ( 4850-4886) Perf ( 4898-4918) ---- Perf -- ( 4944-4954) Perf ( 4964-4992) '- Perf ( 5013-5026) ---- PLUG (5319-5320, 003,500) MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.l. Supervisor "':' f;! '7 IJ ~¿fÍC) !./,~".)! ! ~ DATE: Monday, July 31, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-122 KUPARUK RIV U WSAK lD-122 {/¡,ff{ \ ~ \r"\ FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv"::T15F- Comm NON-CONFIDENTIAL Permit Number: 198-149-0 Inspector Name: John Crisp Inspection Date: 7/29/2006 Well Name: KUPARUK RIV U WSAK 1D-122 Insp Num: mitJCr060731101254 Rei Insp Num API Well Number 50-029-22905-00-00 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1D-122 Type Inj. . N · TVD 3530 IA 0 r 1630 1600 1590 P.T. ! 1981490 IT T t I SPT i . 1500 OA ! ype es, . Test pSI -L Tubing 200 I 250 250 Interval 4YRTST P/F P ¿'" 250 Notes 1 bbl pumped for test Monobore, no OA Monday, July 31, 2006 Page I of 1 Schlumbergep NO. 3492 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Anchorage, AK 99503-2838 - NOV [\ f1; 2f\üÇ, A TTN: Beth $CANNED .'J',=! Ü ~ J',j Field: Well Job# Log Description Date BL 3M-07 11015737 INJECTION PROFILE 09/26/05 1 1E-18 11015745 GLS SURVEY 10102/05 1 1 Q-22 11015744 PRODUCTION PROFILE 10/01/05 1 1G-08A 11072911 PRODUCTION PROFILE 10/01/05 1 1G-10A 11072910 PRODUCTION PROFILE 09/30/05 1 2C-04 11072907 INJECTION PROFILE 09/27/05 1 2D-05 11072909 INJECTION PROFILE 09/29/05 1 2P-429 11056695 INJECTION PROFILE 09/18/05 1 2N-306 11056696 INJECTION PROFILE 09/19/05 1 1D-122 11015730 INJECTION PROFILE 09/06/05 1 1 C-111 11015732 INJECTION PROFILE 09/22/05 1 1 D-114 11015728 INJECTION PROFILE 09/04/05 1 2V -08A 11072913 INJECTION PROFILE 10/03105 1 3M-01 (REDO) 11015736 INJECTION PROFILE 09/25/05 1 31-04 10092325 PRODUCTION PROFILE 1.0/02/05 1 1 E-105 11015726 TEMPERATURE SURVEY 09/02/05 1 SIGNED: Z.I rJ/jJ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 10107/05 Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk .~ Color CD .~ /7 G~JvN-r- t't& -f''-f~ Al{ ;' ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. West Sak 1 KRUI 10-122 07/26/05 Rodgers - AES ~(q 7(Z1{O!5' \ ~~ .... ~ If(} Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us Well 10-122 Type Inj. N TVO 3,530' Tubing P.T.D. 1981490 Type test P Test psi 1500 Casing Notes: Mono-Annulus Integrity Verification MITIA with plug in tbg. Pretest Initial 15 Min. 30 Min. 0 2000 1950 1940 Interval 0 0 0 0 0 P/F P 1940 2075 2075 2050 Interval 0 0 2500 2450 2400 P/F F Packer Depth Well 10-122 Type Inj. N TVO 3,530' Tubing P.T.D.1981490 Type test P Test psi 1500 Casing Notes: Mono-Annulus Integrity Verification MITT with plug in tbg. Well 10-122 Type Inj. N TVO 3,530' Tubing 2050 2050 2050 P.T.D. 1981490 Type test P Test psi 1500 Casing 2400 2500 2500 Notes: Mono-Annulus Integrity Verification MITIA with plug in tbg. Bumped up for 2nd test. 2050 Interval 0 2500 P/F P Interval P/F Interval P/F Well Type Inj. TVO Tubing P.T.D. Type test Test psi Casing Notes: Well Type Inj. TVO Tubing P.T.D. Type test Test psi Casing Notes: Test Details: SCÄ,NNED l~UG 092005 TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form Revised: 06/19/02 2005-0726_MIT _KRU_1 D-122_MITIA2.xls MEMORANDUM TO: THRU: FROM: State of Alaska Alaska Oil and Gas Conservation Commission Randy Rued~n h'-} 1 r~/D3 DATE: June 20, 2003 Chair .-~, ~/1 iOt[ ~ f~ ,,UBJECT: Mechanical Integrity Tests Jim Regg '~.~¢J(t ConocoPhillips Alaska Inc. P.I. Supervisor~,~ I-D 114, 122, 128, 132 John H. Spaulding Kuparuk River Unit Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth .Pretest Initial 15 Min. 30 Min. WeilI 1D-~4 ITypeinJ. I S I T.V.D. I~ I Tubingl 100I,ooI,ooI,oo llnte~va,I 4I P.T.D.I 1981590 ITypetestI p ITestpsil 883 I Casingl 360 I 2620 I 26°°1 2600 I P/F I [~ I Notes: I Welll ~O-,~ I Type,nj.Is I I ITubingI I I I I,nterva, I4 P.T.D.I 1981490 Type testI P I Testpsil 883 I Casingl POS. I 2500 I 24901 2490 I P/F I ~P Notes: We"I '1D-12SI P.T.D. I 1081330 Notes: P.T.D. I 1981210 Notes: WellI P.T.D.I Notes: Type,nj.IS I T.V.D. I ~,~ I Tubingl SO0 I~00 I,,00 I~,00 I,nterva,[ 41/' Type testI I Testpsil 863 I Casingl 80 I 25001 24901 2490l P/F I 'P,I// Type,ni.Is I T.V.D. [ 34s~)[Tubi,g 1~3SO 1~3SO 1~3~0 1~350 I,nterva, I 4 TypetestII Testpsil 872 I Casingl POS. I 25001 2490[ 2490I P/F I ~ Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER IN J, N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details As noted in the above report all wells passed. Well houses were found to be clean and orderly. M.I.T.'s performed: 4 Number of Failures: 0 Attachments: Total Time during tests: 3 hours CC: MIT report form 5/12/00 L.G. ,~sOANNED JU'L 3 ~. ;~003 2003-0620_M IT_KR U_ 1 D- 132_js.xls 7/9/2003 Well Compliance Report File on Left side of folder 198-149-0 MD 05445 ~ Microfilm Roll KUPARUK RIV U WSAK 1D-122 50- 029-22905-00 PHILLIPS ALASKA INC TVD 04201 f Completion Date: ~8 Completed Status: 1WINJ Current: / - Roll 2 / -- Name D 8761 L CBL/SCMT L DGR/EWR4-MD L DGR/EWR4-TVD L INJP L SCMT R SRVY RPT Interval Sent Received T/C/I) PERRY MPT/GR/EWR4 OH 10/21/98 10/28/98 ~ '~../'3¢- ~/c~ ~ CH 5 4600-5320 OH ~AL 121-4201 ~ OH 4660-5180 1/6/00 CH 5 BL(C) 4600-5320 2/26/99 CH 5 /~"E'-'R R Y 0-5445. Daily Well Ops qi/~/.~/ _~/.).,/c/v/ Was the well cored? yes ~ 3/12/99 3/18/99 10/21/98 10/22/98 10/21/98 10/22/98 1/27/00 2/4/00 6/8/99 6/16/99 OH 5 9/2/98 9/3/98 Are Dry Ditch Samples Required? yes ~And Received? Analysis Descriptio ' . ~ Samp~ Comments: Tuesday, August 01, 2000 Page 1 of 1 6/8/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'rN: Sherrie NO. 12633 Company Alaska Oil & Gas Cons Camm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk/Tarn Pool/West Sak Well Job # Log Description Date Color Print 2T-210 99240 ,CBLW/PSP/SCMT 990523 1 2N-320 99241 SCMT 990303 1 2L-323 b~ c_. 99239 CBT w/pSp/SCMT 990221 1 1C- 18 99243 CBT W/PSP/SCMT 990402 1 1 D- 132 t.x ~ ~.- 99248 SCMT 990216 1 1D-125 99249 CBT W/PSP/SCMT 990220 1 1 D- 114 I.,~ ~ ~-., 99246 CBT W/PSP/SCMT 990421 1 1 D- 128 99247 SCMT 990215 1 1D- 122 4. ~¢ .... 99244 CBT W/PSP/SCMT 990226 1 1D-111 b~ ~ ' ' 99245 CBT W/PSP/SCMT 990415 1 C'- 14 /,~ ¢. 99242 SCMT 990122 1 SIGNE ._.. ~L_ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ARCO Alaska, Inc. " Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 14, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-122 (Permit No. 98-149) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1D-122. If there are any questions, please call 265-6120. Sincerely, T. W. Mc Kay Drilling Team Leader AAI Drilling TWM/skad 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 [~ GAS E~ SUSPENDED E~ ABANDONED~ SERVICE [~ Injector 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-149 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22905 4 Location of well at surface i ~.;~;,'r;i'i:'!'i'~i i 9 Unit or Lease Name 196' FNL, 598' FEL, Sec. 23, T11N, R10E, UM ~//'~'~, i ~~~ Kuparuk R~er Unit 120' FSL, 1867' FWL, Sec. 14, T11 N, R10E, UM '~ 1D-122 ...... 11 Field and Pool At Total Depth ~.... , ..... _ .~ 148' FSL, 1633' ~L, Sec. 14, T11N, R10E, UM ~ KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. West Sak Oil Pool RKB 41' Pad 71' ADL 25650 ALK 468 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions 12-Au~-98 14-Au~-98 17-Aug-98 NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey 20 Depth where SSSV set 21 Thickness of permafrost 5445' MD & 4201' TVD 5319' MD & 4082' TVD YES ~ NO ~ NA feet MD 1874 APPROX 22 Type Electric or Other Logs Run G~Res, PSP/G~CCUSCMT 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT BECO~D 16" 62.5~ H-40 SURF. 121' 24" 9 cu yds High Early 5.5" x 15.5¢ L-80 SURF. 4725' 8.5" 507 bbls ASIII & 94 bbls Class G 3.5" 9.3g L-80 SURF. 5434' 8.5" (included above) 24 Pedorations open to Production (MD+TVD of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH S~ (MD) PACKER SET (MD) 4788'-4818' MD 3587'-3615' TVD 5090'-5108' MD 3868'-3885' ~D 3.5" 4739' N/A 4850'-4886' MD 3645'-3678' TVD 4898'-4918' MD 3689'-3708' TVD 26 ACID, F~CTURE, CEMENT SQUE~E, ETC 4944'-4954' MD 3732'-3741' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4964'-4992' MD 3750'-3777' ~D All 4 spf N/A N/A 5013'-5026' MD 3796'-3808' TVD 5034'-5050' MD 3816'-3831' TVD 5060'-5080' MD 3840'-3859' TVD 27 PRODUCTION TEST nDI~IKtAi Date First Production ~Method of Operation (FIowing,lnjectorgaS lift, etc.) Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO I TEST PERIOI' Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL G~VI~-API (corr) Press. 24-HOUR RATE: 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-!-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 GaR, and time of each phase. Top West Sak Sand 4785' 3584' West Sak Base 5250' 4018' Annulus left open - freeze protected with diesel. 31. LIST OF A1-rACHMENTS Summary of Daily Drilling Reports, Directional Survey and correct to the best of my knowledge. ,~ 32. I herebYsigned '~certifY that the foregoing~is true ~~' Title ~~/~-''~ 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. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 1/26/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:ID-122 WELL ID: AK9601 TYPE: -- AFC: AK9601 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:08/12/98 START COMP: RIG:RIG % 245 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22905-00 08/12/98 (D1) TD: 528'(528) SUPV:FRED HERBERT 08/13/98 (02) TD: 3788'(3260) SUPV: 08/14/98 03) TD: 5445' 1657) SUPV:FRED HERBERT 08/15/98 04) TD: 5445' 0) SUPV:FRED HERBERT 08/16/98 (05) TD: 5445' ( 0) SUPV:FRED HERBERT 08/17/98 (06) TD: 5445'( 0) SUPV:FRED HERBERT MW: 9.6 VISC: 257 PV/YP: 57/69 DRILLING AHEAD, DEPTH 1600' APIWL: 4.5 Move rig from 10-125 to 10-122. Rig accepted @ 1700 hrs. 8/12/98 on 10-122. NU Diverter system and function test. Drilling 8.5" hole from 121' to 523' MW: 9.7 VISC: 234 PV/YP: 40/53 CIRC BOTTOMS UP AFTER TRIP APIWL: 5.4 Drilling 8.5" hole from 523' to 3788' POOH, tight and swabbing @ 2450', pump out from 2450' to 1615' MW: 9.6 VISC: 240 PV/YP: 43/51 RIH W/ HOLE OPENER, WASH & REAM @ 3500' APIWL: 5.8 Wash and ream from 2843' to 2939' Drilling 8.5" hole from 3788' to 5445' POOH for hole opener, tight and swabbing from 4545' to 3315' MW: 9.8 VISC: 224 PV/YP: 49/43 CIRC & COND MUD FOR CEMENT JOB APIWL: 3.8 RIH w/hole opener, wash and ream from 2881' to 4587', 5157' to 5445' Run 3.5" x 5.5" tapered casing. MW: 9.5 VISC: 76 PV/YP: 31/23 APIWL: 4.6 Run 5.5" x 3.5" casing to 4400' Pump cement. NU BOPE and test to 300/3000'. Run 3.5" tubing. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 Test casing, began leaking, bled off to 1000 psi. Check surface equipment. Bleed off pressure and sting into SBE. P/U tubing leaking. Freeze protect well. ND BOPE. NU tree and test to 3000psi. Rig released from 10-122 @ 1200 hrs. 8/17/98. ARCO Alaska, Inc. KUPARUK RIVER UNIT ~ WELL SERVICE REPORT '~' K1(1D-122(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-122 PERFORATIONS-E-LI N E 0225991929.11 DATE DAILY WORK UNIT NUMBER 03/22/99 PERFORATE DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 2 NO YES SWS-ELMORE JOH NS FIELD AFC# CC# Signed ESTIMATE AK9601 25WS1 D6DL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 200 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY PERFORATED A-2, A-3 AND A-4 SANDS.[Perf] I TIME LOG ENTRY 07:00 MIRU SCHLUMBERGER E-LINE. HELD SAFETY MEETING. 07:30 PRESSURE TESTED LUBRICATOR TO 3000 PSI. 09:20 RIH W/18' 2.5" HALLOW CARRIER PERF GUN, 4 SPF, 90 DEGREE FROM LOW SIDE. TIE-IN AND SHOOT PERFS IN A-2 5090' TO 5108' POOH 10:30 RIH WITH 20' PERF GUN, TIE-IN AND SHOOT A-2 5060' TO 5080'. POOH. 11:20 RIH WITH 16' PERF GUN, TIE IN AND SHOOT A-2 5034' TO 5050'. POOH. 12:40 RIH WITH 13' PERF GUN, TIE-IN AND SHOOT PERFS IN A-2 5013 TO 5026'. POOH. 13:40 RIH WITH 20' PERF GUN, TIE-IN AND SHOOT A-3 AT 4972 TO 4992'. POOH. 14:30 RIH WITH 8' PERF GUN, TIE-IN AND SHOOT A-3 AT 4964' TO 4972'. POOH. 15:30 RIH WITH 10' PERF GUN, TIE-IN AND SHOOT, A-3 PERFS AT 4944' TO 4954'. POOH. 16:30 RIH WITH 20' PERF GUN, TIE-IN AND SHOOT PERFS A-4 4898' TO 4918'. POOH. 17:45 RDFN ARCO Alaska, Inc. KUPARUK RIVER UNIT ~, WELL SERVICE REPORT '~' K1(1D-122(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-122 PERFORATION S-E-LI NE 0225991929.11 DATE DAILY WORK UNIT NUMBER 03/23/99 PERFORATE DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 3 NO NO SWS-ELMORE CHANEY FIELD AFC# CC# Signed ESTIMATE AK9601 25WSl D6DL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 200 PSI 200 PSI 0 PSI 0 PSI 0 PSII 0 PSI DAILY SUMMARY IPERFORATED "B" SANDS 4850'-4886' RKB & "D" SANDS 4788'-4818' RKB. USED 2.5" HC - DP CHGS - 4 SPF - 180 DEGREE PHASING - ORIENTED 90 DEGREES FROM THE LOW SIDE OF THE HOLE.[Perf] TIME LOG ENTRY 07:00 MIRU SWS, HELD SAFETY MEETING (4 PEOPLE ON LOCATION). 08:00 RIH W!2.5" HC - DP CHGS- 4 SPF- 180 DEGREE PHASING - ORIENTED 90 DEGREES FROM THE LOW SIDE OF THE HOLE. LENGTH 20' 08:30 TIED IN AND SHOT HOLES IN THE "B" SAND 4866' - 4886'. STARTED OOH 08:50 ON SURFACE & ASF. 09:00 RIH W/2.5" HC- DP CHGS - 4 SPF- 180 DEGREE PHASING- ORIENTED 90 DEGREES FROM THE LOW SIDE OF THE HOLE. LENGTH 16' 09:30 TIED IN & SHOT HOLES IN THE "B" SAND 4850' - 4866'. STARTED OOH. 09:50 ON SURFACE & ASF 10:00 RIH W/2.5" HC - DP CHGS - 4 SPF - 180 DEGREE PHASING - ORIENTED 90 DEGREES FROM THE LOW SIDE OF THE HOLE. LENGTH 20' 10:30 TI IN & SHOT HOLES IN THE "D" SAND 4798' - 4818'. STARTED OOH. 10:50 ON SURFACE & ASF. 11:00 RIH W/2.5" HC - DP CHGS -4 SPF - 180 DEGREE PHASING - ORIENTED 90 DEGREES FROM THE LOW SIDE OF THE HOLE. LENGTH 10' 11:30 TIED IN & SHOT HOLES IN THE "D" SAND 4788' - 4798'. STARTED OOH. 11:50 ON SURFACE & ASF. 13:00 RDMO SWS ( PERF JOB COMPLETE) Date 03/21/99 Upcoming F-- Well Na 1D-122 Job Num 0225991929.11 Service Type ELECTRIC LINE Unit Desc of Work SET BRIDGE PLUG Supervisor JOHNS Contractor Key Perso SWS-ELMORE Complet I~ Successful I~ Accident I~ Initial Tbg Press 0 Injury I~ Initial Int Csg Press 0 Spill I~ Initial Out Csg Press 0 Summary SET 3.5" BAKER CAST IRON BRIDGE PLUG, FOR A PBTD OF 5319'. [Perf] . .J AFC AK9601 0 Final Tbg Press 0 Final Int Csg Press 0 Final Out Csg Press 0 Prop 25WS1D6[ Uploaded to SeP Date printed: 04/14/99 at: 09:39:06 D I:t I L_I_ I I~ I~ S E I:!~.~ I r' E S 24-Nov-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well~ 8-27B Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 13,020.06' MD 'MD 13,493.00' 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) 273-3500 · Fax (907) 273-3535 A Halliburton Company DI:t I LLI I~ G S IE F:! ~./I I-- I:: S 02-Sep-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-122 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 5,445.00' 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 " ~ ii i " " SURVEY CALCULATION AND FIELD WORKSHEET i ~ Job No. 0450-99762 Sidetrack No. Page 1 of 2 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER- 245 Field KUPARUK RIVER UNIT Well Name & No. PAD 1D/1D#122/F2 Survey Section Name SPERRY SUN BHI Rep. I~lrr'~i~ WELL DATA Target TVD (Fl') Target Coord. N/S Slot Coord. N/S -196.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL0 SS[-] Target Description Target Coord. EA/V Slot Coord. E/W -598.00 Magn. Declination 27.420 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30m[-] 10m0 Vert. Sec. Azim. 276.40 Magn. to Map Corr. 27.420 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'I-VD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (ET) (DD) (DD) (FT) (FT) (FT) (FT) (Per 400 ET) Drop (-) Left (-) MWD 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 12-AUG-98 MWD 121.00 0.00 0.00 121.00 121.00 0.00 0.00 0.00 0.00 0.00 6 3/4"MACH 1C-AKO-1.4 DEG. 12-AUG-98 MWD 201.10 0.48 258.93 80.10 201.10 0.32 -0.06 -0.33 0.60 0.60 12-AUG-98 MWD 289.35 0.54 252.19 88.25 289.35 1.05 -0.26 -1.09 0.10 0.07 12-AUG-98 MWD 377.56 2.02 261.44 88.21 377.53 2.93 -0.62 -3.02 1.69 1.68 12-AUG-98 MWD 469.28 4.33 270.92 91.72 469.10 7.94 -0.81 -8.08 2.57 2.52 13-AUG-98 MWD 560.29 9.25 274.08 91.01 559.45 18.68 -0.23 -18.82 5.42 5.41 3.47 13-AUG-98 MWD 649.08 14.63 273.59 88.79 646.29 37.02 0.98 -37.14 6.06 6.06 -0.55 13-AUG-98 MWD 741.37 17.38 274.66 92.29 734.99 62.44 2.83 -62.52 3.00 2.98 1.16 13-AUG-98 MWD 831.63 20.69 274.40 90.26 820.30 91.86 5.15 -91.86 3.67 3.67 -0.29 13-AUG-98 MWD 922.08 24.67 273.66 90.45 903.74 126.70 7.58 -126.64 4.41 4.40 -0.82 13-AUG-98 MWD 1012.69 29.41 276.10 90.61 984.43 167.86 11.15 -167.66 5.37 5.23 2.69 13-AU G-98 MWD 1103.54 30.45 275.78 90.85 1063.16 213.19 15.84 -212.75 1.16 1.14 -0.35 13-AUG-98 MWD 1194.75 32.04 276.93 91.21 1141.14 260.49 21.09 -259.76 1,86 1.74 1.26 -- 13-AU G-98 MWD 1286.19 34.70 278.07 91.44 1217.50 310.77 27.67 -309.62 2,99 2.91 1.25 13-AUG-98 MWD 1376.30 38.37 277.70 90.11 1289.89 364.39 35.02 -362.75 4.08 4.07 -0.41 13-AUG-98 MWD 1467.07 40.38 277.54 90.77 1360.05 421.96 42.66 -419.82 2.22 2.21 -0.18 13-AUG-98 MWD 1557.59 43.47 278.23 90.52 1427.39 482.41 50.96 -479.72 3.45 3.41 0.76 13-AUG-98 MWD 1647.64 48.39 278.54 90.05 1490.01 547.05 60.40 -543.71 5.47 5.46 0.34 13-AUG-98 MWD 1743.59 53.72 279.45 95.95 1550.30 621.57 72.09 -617.38 5.60 5.55 0.95 13-AUG-98 MWD 2027.39 53.28 278.39 283.80 1719.11 849.48 107.47 -842.75 0.34 -0.16 -0.37 13-AUG-98 MWD 2313.32 51.13 278.02 285.93 1894.33 1075.30 139.72 -1066.37 0.76 -0.75 -0.13 13-AU G-98 MWD 2594.74 52.63 277.95 281.42 2068.05 1296.60 170.47 -1285.61 0.53 0.53 -0.02 13-AUG-98 MWD 2879.03 51.07 278.08 284.29 2243.65 1520.07 201.64 -1506.99 0.55 -0.55 0.05 i SURVEY CALCULATION AND FIELD WORKSHEETJob No. 0450-99762 Sidetrack No. ~ Page 2 of 2 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER- 245 Field KUPARUK RIVER UNIT Well Name & No. PAD 1D/1D#122/F2 Survey Section Name SPERRY SUN BHI Rep. J~Jllllrr~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -196.00 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. EAN Slot Coord. EAN -598.00 Magn. Declination 27,420 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30m~] 10m~ Vert, Sec. Azim. 276.40 Magn. to Map Corr. 27.420 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Total Coordinate Build Rate I Walk Rate Date Tool Depth Angle Direction Length 'FVD VertiCaIsection N(+) / S(-) E(+)/W(-) DL Build (+)I Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 FI') Drop (-) Left (-) 13-AUG-98 MWD 3164.64 52.67 277.52 285.61 2420.00 1744,66 232.12 -1729.57 0.58 0.56 -0.20 6 3/4"MACH 1C-AKO-1.4 DEG. 13-AU G-98 MWD 3448.74 52.06 275.02 284.10 2593.49 1969.61 256.71 -1953.17 0.73 -0.21 -0.88 ,," ,. 13-AUG-98 MWD 3729.51 50.79 273.40 280.77 2768.57 2188.94 272.85 -2172.06 0.64 -0.45 -0.58 14-AUG-98 MWD 3923.13 49.55 268.99 193.62 2892.62 2336.95 276.00 -2320.65 1.86 -0,64 -2.28 14-AUG-98 MWD 4017.94 48.12 270.07 94.81 2955.02 2407.81 275.40 -2392.02 1.73 -1.51 1.14 14-AUG-98 MWD 4112.58 44.60 274.59 94,64 3020.35 2476.08 278.11 -2460,41 5.08 -3.72 4.78 14-AUG-98 MWD 4206.81 40.62 275.29 94.23 3089,68 2539.84 283.59 -2523,95 4,25 -4.22 0.74 14-AU G-98 MWD 4302.34 37.92 275.27 95.53 3163.63 2600.29 289.15 -2584.16 2.83 -2.83 -0.02 14-AUG-98 MWD 4396.21 34.69 276.33 93.87 3239.27 2655.85 294.75 -2639.45 3.51 -3.44 1.13 14-AUG-98 MWD 4490.29 30.68 277.31 94.08 3318.44 2706.64 300.75 -2689.88 4.30 -4,26 1.04 14-AUG-98 MWD 4585.23 27.06 278.11 94.94 3401.57 2752,46 306.88 -2735.30 3,83 -3.81 0.84 14-AUG-98 MWD 4681.52 23,41 278,75 96.29 3488.65 2793.48 312.89 -2775.91 3,80 -3.79 0.66 14-AUG-98 MWD 4777.27 21.98 278,22 95.75 3576,99 2830.40 318.34 -2812.44 1,51 -1.49 -0.55 14-AUG-98 MWD 4967.03 21.49 278,22 189.76 3753,25 2900,63 328.39 -2881.99 0.26 -0,26 0.00 ; -- 14-AUG-98 MWD 5156.16 20.60 276.70 189,13 3929,77 2968.53 337,22 -2949.32 0,55 -0.47 :0.80 14-AUG-98 MWD 5385.43 20,09 274.53 229.27 4144.74 3048,22 345.04 -3028.64 0.40 -0,22 -0.95 14-AUG-98 MWD 5445.00 20.09 274.53 59.57 4200,68 3068.67 ' 346.66 -3049.03 0.00 0,00 0,00 CLO, DIST=3068.68 AZ1=276.49 , i Kuparuk Unit Kuparuk 1D 1D-122 ORIGINAL SURVEY REPORT 27 August, 1998 Your Reft API-500292290500 Last Survey Date 14-August-g8 Job# AKMW1/V80335 KBE- 112.10' DRILLING SERVICES Survey Ref: svy60 Sperry-Sun Drilling Services Survey Report for 1D-.122 Your Ref: API-500292290500 Kuparuk Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -112.10 0.00 0.00 N 0.00 E 121.00 0.000 0.000 8.90 121.00 0.00 N 0.00 E 201.10 0.480 258.930 89.00 201.10 0.06 S 0.33 W 289.35 0.540 252.190 177.25 289.35 0.26 S 1.09 W 377.56 2.020 261.340 265.43 377.53 0.62 S 3.02 W 469.28 4.330 270.920 357.00 469.10 0.81 S 8.08 W 560.29 9.250 274.080 447,35 559.45 0.24 S 18.82 W 649.08 14.630 273.590 534.19 646.29 0.98 N 37.14 W 741.37 17.380 274.660 622.89 734.99 2,83 N 62.52 W 831.63 20.690 274.400 708.20 820.30 5.14 N 91.86 W 922.08 24.670 273.660 791.64 903.74 7.58 N 126.64 W 1012.69 29.410 276.100 872.33 984.43 11.15 N 167.66 W 1103.54 30.450 275.780 951.06 1063.16 15.84 N 212.75 W 1 194.75 32.040 276.930 1029.04 1141.14 21.09 N 259.76 W 1286.19 34.700 278.070 1105.40 1217.50 27.67 N 309.62 W 1376.30 38.370 277.700 1177.79 1289.89 35,02 N 362.75 W 1467.07 40.380 277.540 1247.95 1360.05 42.65 N 419.82 W 1557.59 43.470 278.230 1315.29 1427.39 50.96 N 479.72 W 1647.64 48.390 278.540 1377.91 1490.01 60.40 N 543.71 W 1743.59 53.720 279.450 1438.20 1550.30 72.08 N 617.38 W 2027.39 53.280 278.390 1607.01 1719.11 107.46 N 842.75 W 2313.32 51.130 278.020 1782.23 1894.33 139.71 N 1066.37 W 2594.74 52.630 277.950 1955.95 2068.05 170,47 N 1285.61 W 2879.03 51.070 278.080 2131.55 2243.65 201.64 N 1506.99 W 3164.64 52.670 277.520 2307.90 2420.00 232,11 N 1729.57 W 3448.74 52,060 275.020 2481.39 2593.49 256.70 N 1953.17 W 3729.51 50.790 273.400 2656.47 2768.57 272,84 N 2172.06 VV 3923.13 49.550 268.990 2780,52 2892.62 275.99 N 2320.65 W 4017.94 48.120 270.070 2842.92 2955.02 275.40 N 2392.02 W 4112.58 44.600 274.590 2908.25 3020.35 278.10 N 2460,41 VV Global Coordinates Dogleg Vertical Northings Eastings Rate Section (fi) (fi) (°/100~) (fi) 5959469.06 N 560490.71E 0.00 5959469.06N 560490.71E 0.000 0.00 5959468.99 N 560490.38 E 0.599 0.32 5959468.79 N 560489.62 E 0.096 1.05 5959468.41N 560487.69 E 1.688 2.93 5959468.18 N 560482.64 E 2.575 7.94 5959468.67 N 560471.89 E 5.420 18.68 5959469.74 N 560453.56 E 6.060 37.02 5959471.38 N 560428.17 E 2.997 62.44 5959473.46 N 560398.81 E 3.668 91.86 5959475.62 N 560364.01E 4.411 126.70 5959478.86 N 560322.97 E 5.372 167.86 5959483.19 N 560277.84 E 1.158 213.19 5959488.05 N 560230.79 E 1.862 260.49 5959494.23 N 560180.88 E 2.989 310.77 5959501.16 N 560127.69 E 4.080 364.39 5959508.33 N 560070.56 E 2.217 421.96 5959516.15 N 560010.60 E 3.451 482.41 5959525.08 N 559946.54 E 5.469 647.05 5959536.17 N 559872.77 E 5.604 621.57 5959569.73 N 559647.12 E 0.338 849.48 5959600.19 N 559423.25 E 0.759 1075.30 5959629.17 N 559203.77 E 0.533 1296.60 5959658.56 N 558982.15 E 0.550 1520.07 5959687.24 N 558759.33 E 0.581 1744.66 5959710.03 N 558535.54 E 0.729 1969.61 5959724.41N 558316.52 E 0.639 2188.94 5959726.36 N 558167.92 E 1.862 2336.95 5959725.20 N 558096.55 E 1.735 2407.81 5959727.35 N 558028.14 E 5.076 2476.07 Comment Kuparuk 1D Continued... 27 August, 1998 - 16:07 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-122 Your Ref: AP1-500292290500 Kuparuk Unit Measured Sub-Sea Vertical Depth Incl. Azim, Depth Depth (~) fit) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 4206.81 40.620 275.290 2977.58 3089.68 283.58 N 2523.95W 5959732.31N 557964.56 E 4302.34 37.920 275.270 3051.53 3163.63 289.15 N 2584.16W 5959737,39 N 557904.31E 4396.21 34.690 276.330 3127.17 3239.27 294.74 N 2639.45W 5959742.54 N 557848,98 E 4490.29 30.680 277.310 3206.34 3318.44 300.75 N 2689.88W 5959748.15 N 557798.49 E 4585.23 27.060 278.110 3289.47 3401.57 306.88 N 2735.30W 5959753.91N 557753.03 E 4681.52 23.410 278.750 3376.55 3488.65 312.88 N 2775.90W 5959759.59 N 557712.38 E 4777.27 21.980 278.220 3464.89 3576.99 318.34N 2812.44W 5959764.75 N 557675.80 E 4967.03 21.490 278.220 3641.15 3753.25 328.38 N 2881.99W 5959774.23 N 557606.17 E 5156.16 20.600 276.700 3817.67 3929,77 337.22 N 2949.32W 5959782.53 N 557538.77 E 5385.43 20.090 274.530 4032.64 4144.74 345.04 N 3028.64W 5959789.70 N 557459.39 E 5445.00 20.090 274.530 4088.58 4200.68 346.65 N 3049.03W 5959791.16 N 557438.98 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 276.400° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5445.00ft., The Bottom Hole Displacement is 3068.68ft., in the Direction of 276.486° (True). -- Dogleg Rate (°/t00~) 4.253 2.826 3.505 4.299 3.835 3.801 1.509 0.258 0.552 0.397 0.000 Vertical Section 2539.83 26o0.28 2655.85 2706.64 2752.46 2793.48 2830.40 2900.63 2968.53 3O48.22 3O68.67 Comment Projected Survey Kuparuk 1D Continued... 27 August, 1998 - 16:07 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for '1D-122 Your Ref: API-500292290500 Kuparuk Unit Kuparuk 1D Comments Measured Depth (ft) 0.00 5445.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 0.00 N 0.00 E 4200.68 346.65 N 3049.03 W Comment Tie-on Survey Projected Survey 27 August, 1998 - 16:07 - 4. DrillQuest 3/12/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12431 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date Blueline Sepia 1 E-36 MEMORY GPJCCL 990304 1 1 1G-07 PRODUCTION PROFILE W/PSP 990218 1 1 1D-122 CBIJSCMT 990226 1 1 1 D-125 CBLW PSP/SCMT 990220 1 1 2L-323 CBLW PSP/SCMT 990221 1 1 2L-323 PRESS/TEMP SURVEY 990223 1 1 2N-320 cai/SCUT 990303 1 1 2N-345 PRODUCTION PROFILE IPSP) 990227 1 1 , , Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: 1999 0il & Gas Gons,, A ohora o I:! I I._1_ I I~ 13 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs October 21, 1998 1D-122, AK-MM-80335 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of 2 Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, ~3, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22905-00 OCT 2 i'2 7r.J Alaska 0it & Gas G~ns. ~mmission Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 0 F! I L-I-I IM CS SEFI~/ICE S WELL LOG TRANSMITY~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs October 21, 1998 1D-122, AK-MM-80335 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention oE Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 11)-122: 2"x 5" MD Resistivity & Gamma Ray Logs: 50-029-22905-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22905-00 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 TONY KNOWLE$, GOVERNO,n, ALASKA OIL AND GAS CONSERVATION COMMISSION August 11. 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Paul Mazzolini Drill Site Develop Sup,,' ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 ae~ Kuparuk Rivcr Unit 1 D- 122 ARCO Alaska Inc. Permit No. 98-149 Sur. Loc. 196'FNL. 598'FEL. Sec. 23. TI 1N. R10E. UM Btmhole Loc. 144'FSL. 1655'FWL. Sec. 14. T1 IN. R10E. UM Dcar Mr. Mazzolini' Enclosed is thc approvcd application for permit to drill thc above rcfcrcnccd well. Please note that any disposal of fluids generated from this drilling operation which arc pumped down the surface production casing annulus of a permitted existing well on Drill Site I-D must comply xvith the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35.000 barrels through the annular space ora single well or for a period longer than onc ,,'car. Thc pcrmit to drill docs not exempt you from obtaining additional permits required by law from other governmental agcncics, and docs not authorize conducting drilling opcrations until all other rcquircd permitting dctcrminations arc made. Thc blew'out prcvcntion cquipmcnt (BOPE) must be tcstcd in accordance ,~vith 20 AAC 25.035: and thc mechanical intcgrity (MI) of thc injection wells must bc dcmonstratcd under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximatcly 24 hours) of the MI test before operation, and of thc BOPE test pcrformed before drilling below thc surfacc casing shoe. must be given_so that ~ativc o(,,!.hc Commission may witncss thc tests. Notice mav be given bv ,,.conm'ehng,taZ'~9mm~ssto~peti~cum field inspccto~ on thc North Slope pager at ~59-3607. David W. Johnston Chairman ._ / BY ORDER OF THE COMMISSION dlf/Enclosurc cc~ Department of Fish & Game. Habitat Section w/o cncl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA ALA,U,,A OIL AND GAS CONSERVATION COMrV,~SION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill F' lb Type of Well Exploratory [" Stratigraphic Test C Development Oil Re-Entry r- Deepen [~ Service X Development Gas E SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 71' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 196' FNL, 598' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 125' FSL, 1826' FWL, Sec. 14, T11N, R10E, UM 1D-122 #U-630610 At total depth 9. Approximate spud date Amount 144' FSL, 1655' FWL, Sec. 14, T11N, R10E, UM 8/12/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 D-121 5442' MD 1655' @ TD feet 15' @ 100' feet 2560 4183' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 400' feet Maximum hole angle 52.31 o Maximum surface 1381 psig At total depth (TVD) 1815 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 69' 41' 41' 110' 110' +_200 CF 8.5" 5.5" x 15.5# L-80 BTC 4641' 41' 41' 4682' 3470' 513 Sx Arcticset IIIL & 8.5" 3.5" 9.3# L-80 8rd MOD 760' 4682' 3470' 5442' 4183' 445 Sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface ILi!°ee!umc~id;ante 0RIG!NAL Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat [~ BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot ]-"' Refraction analysis [~ Seabed report F~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~'~,4J~ ~'~.~'~'_ Title Drill Site Develop. Supv. Date ~ L 0 ~7 Commission Use Only PermiLN~lmber IAPInumber .- ,~ ~ ~"O,..~' I Approvaldate ~)_~/,/ ~,~ See cover letter for ?,~--,,/'~/~. 50- O ~,, ¢ other requirements Conditions of approval Samples required ~- Yes ~ No Mud logrequired E~ Yes J~ No Hydrogen sulfidemeasures J~' Yes ~' No Directional survey required J~' Yes r- No Required working pressure for MOPE E~ 2M F' 3M ~ 5M [~ 1OM E~ 15M Other: Original SJgr!e0 by order of ~ ...~ /// Approved by David W. J0hnstur, Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate RECEIVED JUL 3 1.. ]998 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor July 28, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1 D-122 West Sak Phase lB Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1D pad. The well is designated as a monobore injection well using a 5 Y2" x 3 Y2" tapered casing string, with 3- 1/2" tubing used as a tieback string. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak Pool Rules. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU and West Sak wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-122, such as shallow gas. There have been ten (10) Kuparuk wells and (18) West Sak wells drilled from KRU 1 D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. RECEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany jUL 3 ! 1998 Aiaska 0ii & Gas Cons. Commission 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Aisc note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type Icg generation and sample catching are planned. Please note that the anticipated spud date for this well is August 12, 1998. If you have any questions or require further information, please contact Scott Goldberg at (907) 263-4622 or Tom McKay at (907) 265-6890. Sincerely;, Scott Goldberg Operations Drilling Engineer CC: West Sak 1 D-122 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Cliff Crabtree NSK6 RECE!VED JUL ,5 't 1998 Alaska 0il & Gas Cons. Commissior~ Anchorage Drill, Case and Completion Plan for West Sak 1D-122 (F2) Monobore Injector General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. . Spud and directionally drill 8-1/2" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 3-1/2" 9.3# L80 8RD x 5-1/2" 15.5# L80 BTC tapered casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with non freezing completion brine, bump the plug and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results of pressure test NOTE: TAM Port Collar will be placed in the 5 Y2" casing +1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is close to the surface, a top job may be performed in lieu of utilizing the port collar. 6. Nipple down diverter, nipple up tubing head and BOP's. Test BOP's. Notify AOGCC 24 hours before test , Rig up and run 3-1/2" tubing tieback to surface for monobore injector. Before stinging into seal bore, freeze protect well with enough diesel to cover Permafrost. Sting into seal bore and pressure test tubing and annulus to 3,000 psi. Set tubing hanger. Install back pressure valve. 8. Nipple down BOP's. Install production tree and pressure test same. 9. Secure well, release rig. 10. If necessary, rig up Coiled Tubing Unit (CTU) and clean out 3-1/2" monobore tubing to PBTD. Circulate well to clean brine. Secure well and release CTU. 11. Rig up E-line unit and RIH with CBL/CET, and run cement bond Icg across West Sak interval. Report results to office for remedial action if necessary. -~ i- EC EIVED 12. Big up E-line unit and RIH with through-tubing perforating guns. jUL, b ! ,998 1 D-122 (F2) Page I Ala$~ 0il & Gas Cons. Commission ___~_c. horage SG, o7/28/98, v.1 13. Perforate well overbalanced. POOH with perf guns. Repeat runs as required to perforate all desired West Sak intervals. Rig down E-line unit. 14. Install back pressure valve, shut in and secure well. 1 D-122 (F2) Page 2 Anchorage SG, 07/28/98, v.1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1D-122 (F2) Drilling Fluid Type Extended Bentonite Slurry Drilling Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.O ppg 4O 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.7-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12 % Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A tapered 5-1/2" x 3-1/2" surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface. A TAM Port Collar will be placed at approximately 1000' TVD. This will be used as a contingency if cement is not brought to surface as planned. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-122 (F2) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. - , CEiVFD 1 D-122 (F2) Page I jUL b i t998 0il & 6as Oo~s, 60.m~¢ssior~ SG,07/28/98,v. 1 Anchorage Based on actual well test data from the nearby WS1-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.7 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,524' MD/TVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. . Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base to surface, the following MASP can be computed: MASP = (3945 ft)(0.46- 0.11 psi/ft) = 1381 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the $-1/2" x 3-1/2" combination surface / production casing in this well, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi. The 5-1/2" 15.5# LB0 ElTO casing to be used has a burst rating of 7,000 psi; 70 % of this burst rating is 4,900 psi. After testing, a 3-1/2" tubing tieback string will be installed in the well to be used as the injection string. Drilling Area Risks: Drilling risks in the West Sak 1D-122 (F2) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. Well Proximity Risks: The nearest existing well to West Sak 1D-122 (F2) is WS 1D-121. As designed, the minimum distance between the two wells would be 15.0' at 100' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existing well on DS-ID. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-122 (F2) surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 3-1/2" tubing tieback string and prior to the drilling rig moving off of the well. 1 D-122 (F2) Page 2 u~ Cons. C0i~!~issio~ SG,07/28/98,v.1 WeS' Sak 1 D-122 (F2) Injector com ietion 5-1/2" x 3-1/2" Tapered String 16" Conductor @ 80' TAM International 5-1/2" Ported Collar Stnd. Grade BTC Threads set +/- 1000' TVD Production csg. 5-1/2" 15.5# L-80 BTCM run XO/SBE to surface XO set +/-100' above top perf (+/- 4682' MD / 3470' TVD) Production csg. 3-1/2" 9.3# L-80 EUE 8RD-Mod run TD to XO/SBE (+/- 4682' MD / 3470' TVD) to (+/- 5442' MD / 4183' TVD) G. 3-1/2" Vetco-Gray tubing hanger 3-1/2" EUE 8RD-Mod pin down F. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to surface E. 3-1/2" x 1" Camco 'KBG-2-9' mandrel w/DV & latch, 3-1/2" x 15' pups installed above & below, BTCM pin x EUE 8RD-Mod box Special Clearance Coupling D. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing C. 3-1/2" Camco 'DS' landing nipple w/2.812" No-Go profile. 3-1/2" x 6' L-80 pups installed above and below. EUE 8RD-Mod B. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing A. Baker 3-1/2" 'GBH-22' Locator Seal Assembly w/12' of seals & Iocator 3-1/2" x 6' handling pup installed on top. EUE 8RD-Mod box up I!aker 5-1/2" XO, BTC x LTC aker XO Coupling w/Iocator shoulder, LTC x SBE aker 5" OD x 4" ID Seal Bore Extension aker XO, SBE x 3-1/2" EUE 8RD D Sands B Sands A Sands TAB, 6/11/98, v. 1 1D-122 Cement Volumes Surface Hole Casing Depth Casing OD Casing Weight Hole Size Upper Casing Volume/Foot Upper Annulus Volume/Foot Lower Casing Volume/Foot Lower Annulus Volume/Foot Shoe Joint Length 500' TVD Above WS HiStrgth Depth Base Permafrost Top of 3 1/2" Permafrost Excess Below Permafrost Excess feet inches Ibs/ft inches bbl/ft bbl/ft feet Class Excess Requirement Additive 1 Additive 2 Additive 3 Additive 4 Additive 5 Additive 6 Density Yield Water Requirement Thickening Time PPg ft3/sx gal/sx hours Class Excess Requirement Additive 1 Additive 2 Additive 3 Additive 4 Density Yield Water Requirement Thickening Time PPg ft3/sx gal/sx hours % % · I1' J'~ . '11'! Stage 1 Lead 404.32596 513.6403315 bbls sacks 94.34512 445.1662595 bbls sacks 25O 25O 500 750 1(300 1250 1500 EL 1750 Q~ 2000 2250 25O0 I V 2750 5000 3250 5560 3750 4OOO 4250 c,~o,,~ ~ ¢;,¢~ For: BROCKWAY O~te Catted: IO-,~un-98 ~: Refeten¢~ ;~ ~ 10-122/F2 Ve~. ~4. Caota;nate~ are ;n lect reference ~lol ~122. r~e Vet6co~ Oepms ere re~ence ~B (Po~er ~2~ f_ -RCO Alaska, ........... Structure : Pod 10 Well: 122 Field : Kuparuk River Unit Location :-North Slope, Alas <- West (feet) .3250 .3000 2750 2500 2250 2000 1750 1500 1250 1000 750 500 250 0 250 L 750 ^ 500 250 ~ o 4.00 2 I TO LOCATION' .uu I 144' FSL, 1655"r"-WL I I TARGET LOCATION' ' 2.00 [ SEC. 14, T11N, RIOE 6.00 [ SEC. 14.,'T11N, RIO~[ 20.00 TARGET ESTIMATEB .... TVD=3710 SURFACE LOCATION: L-~.uu DLS' 4 O0 de~ '--r 1nn f+ TMD=4939 196' FNL 598' FEL 800 ' ' v ~" .... DEP=2874 SEC. 23, :~11N, R~OE 'X- ' NORTH 321 '~6000 WEST 2856 "X,,40.O0 ",%44-.00 x. 4.8.00 -%',~.00 LOC 1'V0=1554 TMD=1708 DEP=557 "'%~RMAFROST TVD= 1635 TMD= 1874 DEP=688 MAXIMUM ANGLE ~-~'~J'- I~G---- ~ 276.4 AZIMUTH 2874' (TO TARGET) BEGIN ANGLE DROP TVD=299~IMD=3975BEP=2350"~.52.00 UGNU SNDS T'VD~5 DEP=24~4'"'%48'00'006.0040.00 DLS: 4.00 deg per 100 ft 2.00 8.00 4.00 TARGET - A3 TVD=3?iO TMD=4939 DEP-20?4 TARGET - A3'TVD=371u .MD=4939 9EP=2874 _ TARGET ANGLE ,/w SAN SNOS TV0:3995 TM0=5242 0EP=297~,dt_iL o 1. !99. 250 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 5000 .3250 Vertical Section (feet) -> Azimuth 276.40 with reference 0.00 N, 0.00 E from slot #122 ITCreoted by finch For: BROCI<WAYI Dote plotted: lO-Jun-98 Plot Reference is WS 1D-122/F2 Vers. ~4. Coordinates arc in feet rcfcrcnc¢ slot ~122. rue Yerticol Depths arc r~:farencc RKB (Porker ~245).~ fARco Alaska, Structure : Pad 1D LField : Kuporuk River Unit Well : 122 Location : North Slope, Alaska <- West (feet) 280 ...... ~- 240 2riO 2O0 90 _o.o_.o. ....... .to. 160 120 120 . ~ .................................. 1400 1500 ~ 500 1 ................ 1500 ~ ............... 1200 500~ 40 40 · ~ ...... ~, - ..................... 1100 1~00 ~ ~ 0 ¢ ~[' -J:~ ..................... u 900 800 ~ ~uu ~ ~ ~ ,, -~ 1800 /~ o ~ ~ ' ~ ~ 700 _-<~'-~ ~ ol ~.,,~ ~¢.,¢~ aDO ............. ~/~ 900 -~ o ~-- ~ 900 ......... 2000 / ~0 ~ 40 500 ~ ~ ~'~"~ 1100 ....................... 1200~ O~ ... 80 ~, ~2oo ............... ,~oo~ ~/.~-"~o~ ~/ -' X,'qooo ~'N. 9O~o~''' 200 1 O0 240 ~ , ~ 360 320 280 240 200 160 120 80 40 0 40 80 ;00 760 720 680 640 600 560 520 480 440 400 <- Wesf (feel) /x I Z Created J:,~ ¢inc~ For: BROCKWAY[ Date platted: lO-Jun-CJ8J Plot Re, ...... is WS 1D-'22/F2 V .... t4. J Coordlnotca arc in feet ~e~crcncc slot ~122. J ARCO Alaska, Inc. Structure : Pad 1D Well : 122 Field : Kuparuk River Unit Location : North Slope, Alaska 8O0 700 600 50O 400 A I ~oo 200 <- West (feet) 3100 .3000 2900 2800 2700 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1;500 1200 1100 1000 900 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ~-~. 5600 ...... 5500 .............. 2100 ~300 '- ............. 700 ~ ........ _..2.0.00 ~ 4900 ........... ~ 4800 ...... ~..1900 600 ~ 4700 ....... ~ 4600 -'~4500 ..... -.. 1800 ~'"---.~4400 ......... . .... . ......1700 500 , 4000 9oo .............. 1 400 3300 ~ 4200 300 .................................... .~.: ."."_ 2800 2700 ...................... 2600 2500 .............................. fL?_ ..... 2200 .......................... ~2.1 O0 2000 ......................... .]1900 r 100 -4-- 0 Z 0 100 200 300 400 500 2200 2100 2000 19OO 1800 1700 1600 2700 1500 26OO 140( 2500 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I HO0 3000 2900 2800 2700 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 <- West (feet) Z 0 200 -~ 1 O0 "~ 0 300 400 500 200 100 · _ , iARCO Alaska, Inc. Structure : Pad 1D Well : 122 Field : Kuparuk River Unlt Location : Norfh Slope, Alaska WELL PROFILE DATA 111 aa o.oo o.oo KOP ~.~ 0.~ ~ of ~ 3974.5952.31 ~d of ~ 4782.3520.~ T~9~ ~ 10-F2 ~ 2 ~ et ~d 5242.~ T.O. ~ End al Hold 276.40 0.00 276.'~0 400.00 276.4O 1533.~0 275.4O 276.~ 276.~ 3710.00 275.~ 3g05.~ 275.~ ~.0 700 330 "..,, _ 15, TRUE NORTH 0 520 10 20 510 300 60 290 70 280 80 270 + 90 260 O0 100 250 110 240 250 220 ,,, ; ·,, 21~'" (~" 2O0 190 Normal Plane Travelling Cylinder- Feet .- SO0 ~ 100 ___~oo ~ 4_p___~ ................... 500 ' ~oo 150 ....... ::::-'~--_~ ~ 160 180 170 All depths shown ore Measured depths on Reference Well ARCO Alaska, Inc. Pad 1D 122 slot #122 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : WS 1D-122/F2 Vets. #4 Our ref : prop2204 License : Date printed : 10-Jun-98 Date created : 16-Apr-97 Last revised : 9-Jun-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 17 59.388,w149 30 36.341 Slot Grid coordinates are N 5959468.694, E 560490.5~4 Slot local coordinates are 196.00 S 598.00 W Projection type: alaska - Zone 4, Spheroid~ Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEAR~tNCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath WS 1D-114/D2 Vets. #5,,114,Pad 1D PMSS <O-5142'>,,115,Pad 1D WS 1D-113/C1 Vets. #4,,113,Pad 1D WS 1D-125/H2 Vets. #5,,125,Pad 1D WS 1D-123/G1 Vets. #4,,123,Pad 1D WS 1D-134/L5 Vets. #3,,134,Pad 1D WS 1D-132/K4 Vets. #3,,132,Pad 1D WS 1D-131/L3 Vets. #3,,131,Pad 1D WS 1D-128/K2 Vets. #3,,128,Pad 1D PMSS ¢0 - ?340~>,,10,Pad 1D PMSS <0-5462 >,,129,Pad 1D PMSS <0-4414 >,,121,Pad 1D PMSS <0-4530 ),,120,Pad 1D P~LSS <0-4515 >,,119,Pad 1D PMSS <0-4590 ),,liS,Pad 1D PHSS <0-5205 ),,liT,Pad 1D PMSS <0-4850f>,,109,Pad 1D PMSS ¢0-5126~>,,106,Pad 1D PMSS <381-6092~),,105,Pad 1D PMSS <1957-5265f>,,133,Pad 1D PMSS <0-5015'~,,135,Pad 1D PMSS <0-4778'),,130,Pad 1D PMSS <0-5047~>,,124,Pad 1D WS 1D-116/E1 Vets. #4,,116,Pad 1D WS 1D-112/A1 Vets. #4,,112,Pad 1D Minimum Distance method Closest approach with 3-D Last revised Distance M.D. Diverging from M.D. 8-Jun-98 149.2 600.7 600.7 2-Jun-98 135.0 180.0 '~ 180.0 2-Ju~-98 165.0 300.0 300.0 5-Jun-98 90.0 400.0 400.0 9-Jun-98 15.0 280.0 280.0 2T-May-98 315.0 300.0 5320.0 27-May-98 240.0 240.0 240.0 2?-May-98 225.0 240.0 240.0 1-Jun-98 135.0 400.0 400.0 28-Apr-98 360.0 120.0 120.0 2-Jttn-98 194.3 300.0 300.0 2-Jun-98 15.0 100.0 100.0 2-Ju~-98 30.0 100.0 100.0 2-Jun-98 45.0 100.0 100.0 2oJun-98 89.0 550.0 550.0 2-Jun-98 105.0 100.0 100.0 2-Jun-98 255.0 100.0 100.0 2-Jun-g8 300.0 100.0 ?00.0 2-Jun-98 329.5 300.0 300.0 2-Jun-98 252.1 340.0 340.0 2-Jun-98 330.0 120.0 120.0 2-Jun-98 209.9 400.0 400.0 2-Jun-98 70.9 525.0 525.0 2-Jun-98 120.0 380.0 5442.1 2-Jun-98 180.0 300.0 300.0 WS 1D-157 WS 1D-156 WS 1D-155 WS 1D-154 WS 1D- 153 WS 1D-150 WS 1D-152 WS 1D-149 WS 1D-148 WS 1D-147 WS 1D-146 WS 1D- 145 WS 1D-144 WS 1D- 143 WS 1D-139 WS 1D-140 WS 1D-142 WS 1D-141 WS 1D- 158 WS 1D- 136 WS 1D-Iii/B2 Vets #5,,11 .d 1D WS 1D-110/C3 Vets #4,,lld'/~ad 1D WS 1D-108/A3 Vets #4,,108,Pad 1D WS 1D-101/C5 Vets #3,,101,Pad 1D WS 1D-104/A7 Vets #3,,104,Pad 1D wS 1D-103/B6 Vets #3,,103,Pad 1D WS 1D-102/A5 Vets. #3,,102,Pad 1D WS 1D-107/B4 Vets. #1,,107,Pad 1D WS 1D-151/G11 Vets. #1,,151,Pad 1D WS 1D-138/K6 Vets. #1,,138,Pad 1D WS 1D-161/57 Vets. #1,,161,Pad 1D WS 1D-160/K8 Vers. #1,,160,Pad 1D WS 1D-159/L9 Vets. #1,,159,Pad 1D IK10 Vets. #1,,157,Pad 1D IJ9 Vets. #1,,156,Pad 1D ~H8 Vets. #1,,155,Pad 1D ~Jll Vets. #1,,154,Pa~ 1D ~H10 Vets. #1,,153,Pad 1D ~F10 Vets. #1,,150,Pad 1D 'G9 Vets. #1,,152,Pad 1D 'F8 Vets. #1,,149,Pad 1D 'Ell Vets. #1,,148,Pad 1D 'E9 Vets. 91,,147,Pa~ 1D 'D10 Vets. #1,,146,Pad 1D 'Cll Vets. #1,,145,Pad 1D 'D8 Vets. #1,,144,Pad 1D 'C9 Vets. #1,,143,Pad 1D /B8 Vets. #1,,139,Pad 1D /A9 Vets. #1,,140,Pad 1D /B10 Vets. #1,,142,Pad 1D /All Vets. #1,,141,Pad 1D /511 Vets. #1,,158,Pad 1D /J7 Vets. #1,,136,Pa~ 1D TOTCO Survey,,WS-8,Pad 1D 1D-B Version #3,,1D-B,Pad 1D 1D-F Version #2,,1D-F,Pa~ 1D 1D-D Version #2,,1D-D,Pad 1D PGMS <0-8365'>,,1,Pad 1D PGMS <O-9783'>,,2,Pad 1D PGMS <0-8070'>,,3,Pad 1D PGMS <0-7502'>,,4,Pad 1D PGMS <0-8930'>,,5,Pad 1D PGMS <0-8610'>,,6,Pad 1D MSS <3311-8200'>,,7,Pad 1D PMSS <556-7024'>,,9,Pad 1D WS 1D-126/J1 Vets. #5,,126,Pad 1D WS 1D-127/L1 Vets. #3,,127,Pad 1D 8-Jun-98 2-Jun-98 2-Jun-98 27-May-98 27-May-98 27-May-98 27-May-98 27-May-98 15-Apr-97 27-May-98 27-May-98 27-May-98 27-May-98 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr- 97 15-Apr- 97 15-Apr- 97 15-Apr-97 15-Apr-97 15-Apr- 97 15-Apr-97 15oApr-97 15-Apr-97 15-Apr- 97 15-Apr-97 15-Apr-97 27-May-98 27-May-98 27-May-98 27-May-98 27-May-98 21-May-98 24-Nov-97 24-Nov-97 24-Nov-97 10-De¢-97 4-Aug-92 4-Aug-92 4-Aug-92 13-Nov-97 13-Nov-97 6-Nov-97 29-Apr-98 27-May-98 27-May-98 222.7 240.0 270.0 388.0 343.0 358.0 373.0 283.0 320.3 377.0 453.0 439.2 425.6 398.5 385.1 371.8 358.7 345.7 307.9 332.9 295.8 283.9 272.4 261.1 250.3 239.9 230.1 197.2 204.3 220.8 212.2 412.0 347.0 407.0 182.0 272.0 152.0 430.1 312.8 191.9 71.5 47.1 167.0 287.0 60.0 105.0 120.0 675.~ 300.0~; 300.0 300.0 280.0 280.0 300.0 300.0 300.0 340.0 300.0 300.0 260.0 300.0 300 0 400 0 300 0 3O0 0 300 0 400 0 400 0 300 0 400.0 400.0 300.0 400.0 400.0 260.0 360.0 300.0 260.0 260.0 400.0 40.0 400.0 400.0 400.0 775.0 425.0 650.0 575.0 20.0 20.0 400.0 120.0 300.0 240.0 675.0 300.0 300.0 300.0 280.0 280.0 300.0 300.0 300.0 340.0 300.0 300.0 260.0 300.0 300.0 400.0 300.0 4940.0 300.0 400 0 400 0 300 0 400 0 400 0 300 0 400 0 400 0 260.0 4083.2 300.0 260.0 260.0 400.0 40.0 400.0 400.0 400.0 775.0 425.0 5442.1 575.0 450.0 20.0 400.0 120.0 300.0 240.0 ARCO Alaska, Inc. Pad 1D 122 slot #122 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref = WS 1D-122/F2 Vets. #4 Our ref : prop2204 License : Date printed : 10-Jun-98 Date created = 16-Apr-97 Last revised : 9-Jun-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 17 59.388,w149 30 36.341 Slot Grid coordinates are N 5959468.694, E 560490.554 Slot local coordinates are 196.00 S 598.00 W Pro~ection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 1D,122 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref = WS 1D-122/F2 Vets. #4 Last revised : 9-Ju~-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C O 0 R D I N A T E S Deg/100ft Sect 0.00 0.00 276.40 0.00 0.00 N 0.00 E 0.00 0.00 400.00 0.00 276.40 400.00 0.00 N 0.00 E 0.00 0.00 KOP 500.00 4.00 276.40 499.92 0.39 N 3.47 W 4.00 3.49 600.00 8.00 276.40 599.35 1.55 N 13.85 W 4.00 13.94 700.00 12.00 276.40 697.81 3.49 N 31.11 W 4.00 31.30 800.00 16.00 276.40 794.82 6.19 N 55.14 W 4.00 55.49 900.00 20.00 276.40 889.91 9.63 N 85.85 W 4.00 86.38 1000.00 24.00 276.40 982.61 13.81 N 123.06 W 4.00 123.84 1100.00 28.00 276.40 1072.47 18.70 N 166.62 W 4.00 167.67 1200.00 32.00 276.40 1159.05 24.28 N 216.30 W 4.00 217.66 1300.00 36.00 276.40 1241.94 30.51 N 271.86 W 4.00 273.56 1400.00 40.00 276.40 1320.73 37,38 N 333.03 W 4.00 335.12 1500.00 44.00 276.40 1395.02 44.84 N 399.51 W 4.00 402.02 1600.00 48.00 276.40 1464.48 52.86 N 470.98 W 4.00 473.94 1700.00 52.00 276.40 1528.74 61.40 N 547.09 W 4.00 550.52 1707.76 52.31 276.40 1533.50 62.08 N 553.18 W 4.00 556.65 1873.77 52.31 276.40 1635.00 76.74 N 683.73 W 0.00 688.02 2000.00 52.31 276.40 1712.17 87.88 N 783.00 W 0.00 787.91 2500.00 52.31 276.40 2017.86 132.00 N 1176.20 W 0.00 1183.58 3000.00 52.31 276.40 2323.56 176.13 N 1569.39 W 0.00 1579.25 3500.00 52.31 276.40 2629.25 220.26 N 1962.59 W 0.00 1974.91 3974.59 52.31 276.40 2919.40 262.15 N 2335.81 W 0.00 2350.47 3982.35 52.00 276.40 2924.17 262.83 N 2341.90 W 4.00 2356.60 4082.35 48.00 276.40 2988.43 271.37 N 2418.01 W 4.00 2433.19 4083.20 47.97 276.40 2989.00 271.44 N 2418.64 W 4.00 2433.82 4182.35 44.00 276.40 3057.88 279.40 N 2489.48 W 4.00 2505.11 4282.35 40.00 276.40 3132.18 286.86 N 2555.97 W 4.00 2572.01 4382.35 36.00 276.40 3210.97 293.72 N 2617.13 W 4.00 2633.57 4482.35 32.00 276.40 3293.85 299.96 N 2672.69 W 4.00 2689.47 4582.35 28.00 276.40 3380.44 305.53 N 2722.37 W 4.00 2739.46 4682.35 24.00 276.40 3470.30 310.42 N 2765.93 W 4.00 2783.29 4782,35 20.00 276.40 3563.00 314.60 N 2803.15 W 4.00 2820.74 4938.78 20.00 276.40 3709.99 320.56 N 2856.31 W 0.00 2874.24 4938.79 20.00 276.40 3710.00 320,57 N 2856.32 W 0.00 2874.25 5000.00 20.00 276.40 3767.52 322.90 N 2877.12 W 0.00 2895.18 5242.08 20.00 276.40 3995.00 332.13 N 2959.40 W 5442.08 20.00 276.40 4182.94 339.76 N 3027.38 W EOC Base Permafrost Begin Angle Drop Top U~nu Sands Top West Sak Sands / gOD TARGET - West Sak 43 WS 1DoF2 Rvsd 26-Jan-98 0.00 2977.98 Base West Sa]; Sands 0.00 3046.38 TD - Casing Pt Anchora~o 411 data is in feet unless otherwise stated. Coordinates from slot #122 and TVD from P-KB (Parker #245) (112.00 Ft a~ove mean sea level). Bottom hole distance is 3046.38 on azimuth 276.40 degrees from wellhead. Total Do~leg for we11path is 84.62 degrees. Vertical section is from wellhead on azimuth 276.40 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,122 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-122/F2 Vets. #4 Last revised : 9-Jun-98 Comments in we11path MD TVD Rectangular Coords. C~mment ............................................................ . ......... ~ .................................... 400.00 400.00 0.00 N 1707.76 1533.50 62.08 N 1873.77 1635.00 76.7% N 3974.59 2919.40 262.15 N 4083.20 2989.00 271.44 N 4782.35 3563.00 314.60 N 4938.78 3709.99 320.56 N 4938.79 3710.00 320.57 N 5242.08 3995.00 332.13 N 5442.08 4182.94 339.76 N 0.00 E KOP 553.18 W 683.73 W Base Permafrost 2335.81 W Begin Angle Drop 2418.64 W Top U~nu Sends 2803.15 W Top West Sak Sands / EOD 2856.31 W TAROET - West Sak A3 2856.32 W WS 1D-F2 Rvsd 26-Jan-98 2959.40 W Base West Sak Sands 3027.38 W TI) - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 5442.08 4182.94 339.76N 3027.38W 5 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coord/nates Revised WS 1D-F2 Rvsd 26-Jan 557632.000,5959766.000,0.0000 3710.00 320.57N 2856.32W 9-Oct-96 ARCO Alaska, Inc. Pad 1D,122 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : WS 1D-122/F2 Vets. #4 Last revised : 9-Ju/1-98 Measured Inclin. Azimuth True Vert R E C T A N ~ U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect 0.00 0.00 276,40 0.00 196.00 S 598.00 W 0.00 0.00 400.00 0.00 276.40 400.00 196.00 S 598.00 W 0.00 0.00 500.00 4.00 276.40 499.92 195.61 S 601.47 W 4.00 3.49 600.00 8.00 276,40 599.35 194.45 S 611.85 W 4.00 13.94 700.00 12.00 276.40 697.81 192.51 S 629.11 W 4.00 31.30 800.00 16.00 276.40 794.82 189.81 S 653.14 W 4.00 55.49 900.00 20.00 276.40 889.91 186.37 S 683.85 W 4.00 86.38 1000.00 24.00 276.40 982.61 182.19 S 721.06 W 4.00 123.84 1100.00 28.00 276.40 1072.47 177.30 S 764.62 W 4.00 167.67 1200.00 32.00 276.40 1159.05 171.72 S 814.30 W 4.00 217.66 1300.00 36.00 276.40 1241.94 165.49 S 869.86 W 4.00 273.56 1400.00 40.00 276.40 1320.73 158.62 S 931.03 W 4.00 335.12 1500.00 44.00 276.40 1395.02 151.16 S 997.51 W 4.00 402.02 1600.00 48.00 276.40 1464.48 143.14 S 1068.98 W 4.00 473.94 1700.00 52.00 276.40 1528.74 134.60 S 1145.09 W 4.00 550.52 1707.76 52.31 276.40 1533.50 133.92 S 1151.18 W 4.00 556.65 1873.77 52.31 276.40 1635.00 119.26 S 1281.73 W 0.00 688.02 2000.00 52.31 276.40 1712.17 108.12 S 1381.00 W 0.00 787.91 2500.00 52.31 276.40 2017.86 64.00 S 1774.20 W 0.00 1183.58 3000.00 52.31 276.40 2323.56 19.87 S 2167.39 W 0.00 1579.25 3500.00 52.31 276.40 2629.25 24.26 N 2560.59 W 0.00 1974.91 3974.59 52.31 276.40 2919.40 66.15 N 2933.81 W 0.00 2350.47 3982.35 52.00 276.40 2924.17 66.83 N 2939.90 W 4.00 2356.60 4082.35 48.00 276.40 2988.43 75.37 N 3016.01 W 4.00 2433.19 4083.20 47.97 276.40 2989.00 75.44 N 3016.64 W 4.00 2433.82 4182.35 44.00 276.40 3057.88 83.40 N 3089.48 W 4.00 2505.11 4282.35 40.00 276.40 3132.18 90.86 N 3153.97 W 4.00 2572.01 4382.35 36.00 276.40 3210.97 97.72 N 3215.13 W 4.00 2633.57 4482.35 32.00 276.40 3293.85 103.96 N 3270.69 W 4.00 2689.47 4582.35 28.00 276.40 3380.44 109.53 N 3320.37 W 4.00 2739.46 4682.35 24.00 276.40 3470.30 114.42 N 3363.93 W 4.00 2783.29 4782.35 20.00 276.40 3563.00 118.60 N 3401.15 W 4.00 2820.74 4938.78 20.00 276.40 3709.99 124.56 N 3454.31 W 0.00 2874.24 4938.79 20.00 276.40 3710.00 124.57 N 3454.32 W 0.00 2874.25 5000.00 20.00 276.40 3767.52 126.90 N 3475.12 W 0.00 2895.18 KOP E0C Base Permafrost Begin Angle Drop Top U~nu Sands Top West Sak Sands / EOD TARGET - West Sak A3 WS 1D-F2 Rvsd 26-Jan-98 5242.08 20.00 276.40 3995.00 136.13 N 3557.40 W 0.00 2977.98 Base West Sak Sands 5442.08 20.00 276.40 4182.94 143.76 N 3625.38 W 0.00 3046.38 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 14, TllN, R10E and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 3046.38 on azimuth 276.40 degrees from wellhead, Total Dogleg for wellpath is 84.62 degrees. Vertical section is from wellhead on azimuth 276.40 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,122 Kuparuk River Unlt,North Slope, Alaska PROPOSA~ LISTING Page 2 Your ref : WS 1D-122/F2 Vets. #4 Last revised : 9-Jun-98 Comments in we11path MD TVD Rectangular Coorde. Comment 400.00 400.00 196.00 S 1707.76 1533.50 133.92 S 1873.77 1635.00 119.26 S 3974.59 2919.40 66.15 N 4083.20 2989.00 75.44 N 4782.35 3563.00 118.60 N 4938.78 3709.99 124.56 N 4938.79 3710.00 124.57 N 5242.08 3995.00 136.13 N 5442.08 4182.94 143.76 N 598.00 W KOP 1151.18 W EOC 1281.73 W Base Permafrost 2933.81 W Begin Angle Drop 3016.64 W Top U~nu Sands 3401.15 W Top West Sak Sands / EOD 3454.31 W TARGET - West Sak A~ 3454.32 W WS LD-F2 Rvsd 26-Jan-98 3557.40 W Base West Sak Sands 3625.38 W TD - Casing Pt Casing positions in string Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coorde. Casing 0.00 0.00 196.00S 598.00W 5442.08 4182.94 143.76N 3625.38W 5 1/2" Casing Targets associated with this we11path Target name Geographic Location T.V.D. Rectangular Coordinates Revised ...................................................... T .............. ...................................... WS 1D-F2 Rvsd 26-Jan 557632.000,5959766.000,0.0000 3710.00 124.57N 3454.32W 9-0ct-96 ARCO Alaska, Inc. Pad 1D,122 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTIN(~ Page 1 YOur ref : WS 1D-122/F2 Vets. #4 Last revised ~ 9-Jun-98 Vert Ellipse Sem/ Axes Minor Sect Major M~nor Vert. Azi. 0.00 0.00 276.40 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 400.00 0.00 276.40 400.00 0.00 N 0.00 E 0.00 1.04 1.04 0.60 N/A 500.00 4.00 276.40 499.92 0.39 N 3.47 W 3.49 1.33 1.31 0.?5 276.40 600.00 8.00 276.40 599.35 1.55 N 13.85 W 13.94 1.74 1.58 0.90 276.40 700.00 12.00 276.40 697.81 3.49 N 31.11 W 31.30 2.41 1.88 1.06 276.40 800.00 16.00 276.40 794.82 6.19 N 55.14 W 55.49 3.43 2.20 1.22 276.40 900.00 20.00 276.40 889.91 9.63 N 85.85 W 86.38 4.86 2.57 1.40 276.40 1000.00 24.00 276.40 982.61 13.81 N 123.06 W 123.84 6.76 2.97 1.61 276.40 1100.00 28.00 276.40 1072.47 18.70 N 166.62 W 167.67 9.17 3.41 1.85 276.40 1200.00 32.00 276.40 1159.05 24.28 N 216.30 W 217.66 12.12 3.88 2.14 276.40 1300.00 36.00 276.40 1241.94 30.51 N 271.86 W 273.56 15.65 4.39 2.49 276.40 1400.00 40.00 276.40 1320.73 37.38 N 333.03 W 335.12 19.78 4.91 2.91 276.40 1500.00 44.00 276.40 1395.02 44.84 N 399.51 W 402.02 24.52 5.45 3.39 276.40 1600.00 48.00 276.40 1464.48 52.86 N 470.98 W 473.94 29.87 5.98 3.96 276.40 1700.00 52.00 276.40 1528.74 61.40 N 547.09 W 550.52 35.82 6.52 4.60 276.40 1707.76 52.31 276.40 1533.50 62.08 N 553.18 W 556.65 36.29 6.56 4.65 276.40 1873.77 52.31 276.40 1635.00 76.74 N 683.73 W 688.02 46.32 7.44 5.76 276.40 2000.00 52.31 276.40 1712.17 87.88 N 783.00 W 787.91 53.94 8.11 6.60 276.40 2500.00 52.31 276.40 2017.86 132.00 N 1176.20 W 1183.58 84.31 10.80 10.01 276.40 3000.00 52.31 276.40 2323.56 176.13 N 1569.39 W 1579.25 114.75 13.50 13.45 276.40 3500.00 52.31 276.40 2629.25 220.26 N 1962.59 W 1974.91 145.21 16.21 16.90 276.40 3974.59 52.31 276.40 2919.40 262.15 N 2335.81 W 2350.47 174.13 18.78 20.19 2?6.40 3982.35 52.00 276.40 2924.17 262.83 N 2341.90 W 2356.60 174.60 18.82 20.24 276.40 4082.35 48.00 276.40 2988.43 271.37 N 2418.01 W 2433.19 180.05 19.38 20.86 276.40 4083.20 47.97 276.40 2989.00 271.44 N 2418.64 W 2433.82 180.09 19.38 20.86 276.40 4182.35 44.00 276.40 3057.88 279.40 N 2489.48 W 2505.11 184.89 19.94 21.41 276.40 4282.35 40.00 276.40 3132.18 286.86 N 2555.97 W 2572.01 189.12 20.49 21.89 276.40 4382.35 36.00 276.40 3210.97 293.72 N 2617.13 W 2633.57 192.74 21.04 22.30 276.40 4482.35 32.00 276.40 3293.85 299.96 N 2672.69 W 2689.47 195.78 21.56 22.65 276.40 4582.35 28.00 276.40 3380.44 305.53 N 2722.37 W 2739.46 198.26 22.06 22.94 276.40 4682.35 24.00 276.40 3470.30 310.42 N 2765.93 W 2783.29 200.21 22.S1 23.17 276.40 4782.35 20.00 276.40 3563.00 314.60 N 2803.15 W 2820.74 201.70 22.93 23.36 276.40 4938.78 20.00 276.40 3709.99 320.56 N 2856.31 W 2874.24 204.02 23.59 23.65 276.40 4938.79 20.00 276.40 3710.00 320.57 N 2856.32 W 2874.25 204.02 23.59 23.65 276.40 5000.00 20.00 276.40 3767.52 322.90 N 2877.12 W 2895.18 204.93 23.84 23.76 276.40 5242.08 20.00 276.40 3995.00 332.13 N 2959.40 W 2977.98 208.53 24.86 24.21 276.40 5442.08 20.00 276.40 4182.94 339.76 N 3027.38 W 3046.38 211.52 25.69 24.59 276.40 Anchorage All data is in feet unless otherwise stated. Coordinates from slot #122 and TVD from ~ (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 3046.38 on azimuth 276.40 degrees from wellhead. Vertical section is from wellhead on azimuth 276.40 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,122 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : W$ 1D-122/F2 Vers. #4 Last revised : 9-Jun-98 POSITIONUNCERTAINTY SUMMARY Depth Position Uncertainty From To Su=vey Tool Error Model Major Minor Vert. 0 5442 ARCO (H.A. Mag) User specified 211.52 25.69 24.59 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied to~ether the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. Comments in we11path MD TVD Rectangular Coords. Comment ........................................................................................................... 400.00 400.00 0.00 N 0.00 E KOP 1707.76 1533.50 62.08 N 553.18 W EOC 1873.77 1635.00 76.74 N 683.73 W Base Permafrost 3974.59 2919.40 262.15 N 2335.81 W Begin Angle Drop 4083.20 2989.00 271.44 N 2418.64 W Top U~nu Sands 4782.35 3563.00 314.60 N 2803.15 W Top West Sak Sands / EOD 4938.78 3709.99 320.56 N 2856.31 W TARGET - West Sak A3 4938.79 3710.00 320.57 N 2856.32 W WS 1D-F2 Rvsd 26-Jan-98 5242.08 3995.00 332.13 N 2959.40 W Base West Sak Sands 5442.08 4182.94 339.76 N 3027..38 W TD - Casing Pt Casing positions in string 'A' ==_- _- ==_- _- _-_-_- ==_-_-_- ==_-_-= = Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 5442.08 4182.94 339.76N 3027.38W 5 1/2" Casing Targets associated with this we11path =_--_=_-====_-_-=_-= ===_- = = ~_-==--m ~_---=---- ~ ------= Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-F2 Rvsd 26-Jan 557632.000,5959766.000,0.0000 3710.00 320.57N 2856.32W 9-0ct-96 ARCO Alaska, Inc. Pad 1D,122 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref ~ WS 1Do122/F2 Vets. #4 Last revised = 9-Jun-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Dsg/100ft Sect Easting Northing 0.00 0.00 276.40 0.00 0.00N 0.00E 0.00 0.00 560490.55 5959468.69 400.00 0.00 276.40 400.00 0.00N 0.00E 0.00 0.00 560490.55 5959468.69 500.00 4.00 276.40 499.92 0.39N 3.47W 4.00 3.49 560487.08 5959469.06 600.00 8.00 276.40 599.35 1.55N 13.85W 4.00 13.94 560476.69 5959470.14 700.00 12.00 276.40 697.81 3.49N 31.11W 4.00 31.30 560459.42 5959471.93 800.00 16.00 276.40 794.82 6.19N 55.14W 4.00 55.49 560435.37 5959474.43 900.00 20.00 276.40 889.91 9.63N 85.85W 4.00 86.38 560404.64 5959477.63 1000.00 24.00 276.40 982.61 13.81N 123.06W 4.00 123.84 560367.39 5959481.50 1100.00 28.00 276.40 1072.47 18.70N 166.62W 4.00 167.67 560323.80 5959486.04 1200.00 32.00 276.40 1159.05 24.28N 216.30W 4.00 217.66 560274.09 5959491.21 1300.00 36.00 276.40 1241.94 30.5LN 271.86W 4.00 273.56 560218.48 5959496.99 1400.00 40.00 276.40 1320.73 37.38N 333.03W 4.00 335.12 560157.27 5959503.36 1500.00 44.00 276.40 1395.02 44.84N 399.51W 4.00 402.02 560090.73 5959510.28 1600.00 48.00 276.40 1464.48 52.86N 470.98W 4.00 473.94 560019.21 5959517.72 1700.00 52.00 276.40 1528.74 61.40N 547.09W 4.00 550.52 559943.04 5959525.64 1707.76 52.31 276.40 1533.50 62.08N 553.18W 4.00 556.65 559936.94 5959526.27 1873.77 52.31 276.40 1635.00 76.74N 683.73W 0.00 688.02 559806.29 5959539.86 2000.00 52.31 276.40 1712.17 87.88N 783.00W 0.00 787.91 559706.94 5959550.19 2500.00 52.31 276.40 2017.86 132.00N 1176.20W 0.00 1183.58 559313.44 5959591.12 3000.00 52.31 276.40 2323.56 176.13N 1569.39W 0.00 1579.25 558919.93 5959632.05 3500.00 52.31 276.40 2629.25 220.26N 1962.59W 0.00 1974.91 558526.42 5959672.98 3974.59 52.31 276.40 2919.40 262.15N 2335.81W 0.00 2350.47 558152.91 5959711.82 3982.35 52.00 276.40 2924.17 262.83N 2341.90W 4.00 2356.60 558146.82 5959712.46 4082.35 48.00 276.40 2988.43 271.37N 2418.01W 4.00 2433.19 558070.65 5959720.38 4083.20 47.97 276.40 2989.00 271.44N 2418.64W 4.00 2433.82 558070.02 5959720.44 4182.35 44.00 276.40 3057.88 279.40N 2489.48W 4.00 2505.11 557999.12 5959727.82 4282.35 40.00 276.40 3132.18 286.86N 2555.97W 4.00 2572.01 557932.59 5959734.74 4382.35 36.00 276.40 3210.97 293.72N 2617.13W 4.00 2633.57 557871.37 5959741.10 4482.35 32.00 276.40 3293.85 299.96N 2672.69W 4.00 2689.47 557815.77 5959746.89 4582.35 28.00 276.40 3380.44 305.53N 2722.37W 4.00 2739.46 557766.05 5959752.06 4682.35 24.00 276.40 3470.30 310.42N 2765.93W 4.00 2783.29 557722.46 5959756.59 4782.35 20.00 276.40 3563.00 314.60N 2803.15W 4.00 2820.74 557685.21 5959760.47 4938.78 20.00 276.40 3709.99 320.56N 2856.31W 0.00 2874.24 557632.00 5959766.00 4938.79 20.00 276.40 3710.00 320.57N 2856.32W 0.00 2874.25 557632.00 5959766.00 5000.00 20.00 276.40 3767.52 322.90N 2877.12W 0.00 2895.18 557611.18 5959768.17 5242.08 20.00 276.40 3995.00 332.13N 2959.40W 0.00 2977.98 557528.83 5959776.73 5442.08 20.00 276.40 4182.94 339.76N 3027.38W 0.00 3046.38 557460.80 5959783.81 All data in feet unless otherwise stated. Calculation uses minimum cu~-vature method. Coordinates from slot #122 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 3046.38 on azimuth 276.40 degrees from wellhead. Total Dogleg for we11~ath is 84.62 degrees. Vertical section is from wellhead on azimuth 276.40 ~egrees. Grid is alaska - Zone 4. Grid coordinates in FEET and co=~uted using the Clarke - 1866 spheroid Presente~ by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,122 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref = WS 1D-122/F2 Vets. #4 Last revised = 9-Jun-98 Comments in we11path MD TVD Rectangular Coords. Comment ........................................................................................................... 400.00 400.00 0.00N 1707.76 1533.50 62.08N 1873.77 1635.00 76.74N 3974.59 2919.40 262.15N 4083.20 2989.00 271.44N 4782.35 3563.00 314.60N 4938.78 3709.99 320.56N 4938.79 3710.00 320.57N 5242.08 3995.00 332.13N 5442.08 4182.94 339.76N 0.00E KOP 553.18W EOC 683.73W Base Permafrost 2335.81W Begin Angle Drop 2418.64W Top U~nu Sands 2803.15W Top West Sak Sands / EOD 2856.31W TARGET - West Sak A3 2856.32W WS 1D-F2 Rvsd 26-Jan-98 2959.40W Base West Sak Sands 3027.38W TD - Casing Pt Casing positions in string ~A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 5442.08 4182.94 339.76N 3027.38W 5 1/2" Casing Targets associated with this we11path Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-F2 Rvsd 26-Jan $57632.000,5959766.000,0.0000 3710.00 320.57N 2856.32W 9-0ct-96 Z0" DIVERTER SCHEiW tTIC Kuparuk River Unit West Sak Operations 6 5 4 3 DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES Maintenance & Operation 1. 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 2. 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 ~¥ 3-5/8" 5000 psi BOP Kuparuk River Unit West Sak Operations - Injector Wells 5 4 3 2 ! I 1. 16" Starting Head 2. 7-1/16" 5000 psi Tubing Head 3. 7-1/16' x 13-5/8" 5000 psi Double Studded Adapter/Spacer Spool 4. 13-5/8' 5000 psi x 13-5/8' 5000 psi Spacer Spool 5. 13-5/8' 5000 psi Pipe Rams 6. 13-5/8' 5000 psi Drilling Spool with Choke and Kill Lines 7. 13-5/8' 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 8. 13-5/8' 5000 psi Annular Preventer 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 the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 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, 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 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on k~l and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 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 bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 3000 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 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with Koomey pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. ** VBRS will accornodate 3-1/2" to 6" or 4-1/2" to 7" pipe OD's as appropriate ** FRO~: KUPURAK TOOL HOUSE 07-27-98 t$:15 P ,02 ._. C ._ O.$. 1-D 108~j 110~ ~o~ "1,11 112~ '113 114 i~ 122 125 ~ 127~ 132 134~ 21 WEST .SAK-1 THIS SUR1/EY VI CINt TY MA ?_ ____ MILE LEGEND · 0 £XISFING CONOUCTOR$ $ 'AS-gUlL T" CONDUCTOR LOCA FION ARCO Alaska, Inc. FILE NO. DRA~NG w610416 07/22/98 SEE SHEET t 2 FOR NOTES AND LOCATION tNFORldATION CEA-D1OX-6104D16 FLO~UNSB URY & A~SOCIATES, INC. AREA' lO ~L[ XX DRILL ~ST SAK PHASE lB - ~ CONDUCTORS AS-gUILT LOCAtiONS ~EET: ~EV: UNIT' FEOH: KUPURAK TOOL, HOUSE KAX NO.: 659 768! 0?-2?-98 R~VI gATE ] 8Y j CK .["AFPI . OE~i[:RIPTIO~ ,,, . _ 14 ~ 2~. TO~EHi~ ~I NORTH. RANGE 10 EAST. U.M. ~~ ' ,. O, TES ~,UR~' 7~/98, ~ELD BK. ~98-52. P~. ,3-44; 7/~/~& FIELD ~K. L~-50. PUS. 45-47; 5. ORILL SIE 1-0 ~RID NOR~ IS ~FAFED 00' 01" 05' 6. SEE D~A~NG N~-J. 5-1 F~ AS-BUILT L~AKI~S OF c~oucr~ ~-~. ~-mox-~o~o~o ~ c~oucr~ CEA-OtDX-6IO4Dt5 F~ C~OUCTO~ t25- t28 _ WClN! SCALE: l ' ~ I ~LE Sec. 14, ~11 N.. R. IO ... ~, ·, No. Y ~ LoL Lon~. F.~L.[F.E.L, Pod O.G, ,oe ~.~=~.~e.e~ ~o.~.~ ~o:' re' o2o, o~ ~,~" ~' as.~x" ~' ~' ~.~'s~.,' Sec. 23, ~11 N., R. IO E. F.N.L.'F.E.C:~aU 0.~. ~3 ~ 5.959.633.93 5~0,4~G56~ 70' ,,O 5.,59.5,,9~ ~O,,,o. OJ J 70',,'00.570' ,22 5,959.,,9.0~ [ 5,0.490.~, 70' ,,' 5g.~g2' } ,49' 30' ~.~37' ,2J s. g59.,53.8, 5,~490.69 70',7'5g. 2,2' . :~ '""' AL~S~ ANO ~H~T ~Hl~ PL~F ~EP~ESENT5 ~ S~V~Y i ii ~ LOUNSBUgY i ii i i i ii i ' " A~ aa~ a~ ~-D ARCO Alaska,Inc. ~ ~s~ s~ ,.~ ~ - ~ co.~uc~o,s AS-BUILT LOtiONS '1 i LK$1O~6 07/22/~8 CEA-D1DX-~10~16 · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ADMINISTRATION ENGINEERING DATE GEOLOGY APPR DATE, INIT CLASS WELL NAME f,~_,~ //~-/~,-' 2_ PROGRAM: exp [] dev [] redrll [] serv'v'v~wellbore seg ll ann. disposal para reql, 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 ........... 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. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. 34. GEOL AREA ~.~ ~ UNIT# ////~",,~ ON/OFF SHORE N N N N N N N ANNULAR DISPOSAL 35. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. / ~ N If diverter required, does it meet regulations .......... ~'f' N Drilling fluid program schematic & equip list adequate ..... ~'1t N BOPEs, do they meet regulation .... ~ .......... )'~ N BOPE press rating appropriate; test to .~000 psig. ,¢'1 N Choke manifold complies w/APl RP-53 (~lay 84) ........ ~'t N Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. ~.,~' Permit can be issued w/o hydrogen sulfide measures ..... y N/ Data presented on potential overpressure zones ....... Y Seismic analysis of shallow gas zones ............. Seabed condition survey (if off-shore) ............. /' Y N ' - Contact name/phone for weekly progress reports ....... ./' Y N [exploratory only] With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; (B) will not contaminate freshwater; or cause d~waste . .. to surface; (C) will not impair mechanical integrity, gffthe well used for disposal; (D) will not damage producing ~j'm'~ion or impair recovery from a pool; and (E) will not circumv, e~-"Y0'AAC 25.252 or 20 AAC 25.412. APPR DATE Y N Y N Y N G_EQL~.Y: EH~INEERING: UIC/Annular COMMISSION: JDH:,/' RNC ~~ ~-'""- CC) Comments/Instructions: M:cheklist rev 05/29/98 Ill C:\ ~soff c,r;\word an\diann\checl,,list Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. ... No special effort has been made to chronologically organize this category of information. ckdsl /1ð-I'-Ir Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: CONOCOPHILLlPS ALASKA, INC. July 30, 2005 6513 1 3.5" 9.3 lb. L-80 EUE-8rd Tubing Inspection Type : Well: Field: State: API No.: Top Log IntvI1.: Bot. Log IntvI1.: 1 D-122 Kuparuk Alaska 50-029-2290500 Surface 4,782 Ft. (MD) Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the DS Nipple @ 4,681' (Drillers Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the interval of 3.5" tubing logged is in good to poor condition, with a maximum recorded penetration of 77% Wall thickness @ 4,657'. Wall penetrations ranging from 20% to 77% wall thickness are recorded in 134 of the 158 joints logged. The damage recorded appears mostly in the form of Line Corrosion. There are no areas of significant Cross Sectional Wall loss recorded throughout the interval logged. Deposits restrictthe ID to 2.75" @ 4,764'. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WAll PENETRATIONS: Line Corrosion Line Corrosion Line Corrosion Line Corrosion Line Corrosion ( 77%) ( 76%) ( 71 %) ( 69%) ( 65%) Jt. Jt. Jt. Jt. Jt. 147 149 73 69 74 @ @ @ @ @ MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No areas of significant cross-sectional wall loss (>10%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: Deposits Deposits Deposits Min ID = 2.75" Min ID = 2.77" Min ID = 2.79" No other significant I.D. restrictions are recorded. 1"'.1"'. {, Aäl.:'\L::I', .... '¡:)vi»'}~ ~,~"+!~~[.) I Field Engineer: N. Kesseru Analyst: J. Thompson Jt. Jt. Jt. 149 @ 148 @ 148.1 @ 4,657 Ft. (MD) 4,760 Ft. (MD) 2,323 Ft. (MD) 2,193 Ft. (MD) 2,344 Ft. (MD) 4,764 Ft. (MD) 4,706 Ft. (MD) 4,721 Ft. (MD) Witness: C. Fitzpatrick PrüActive Diagnostic Services, Ine. I P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudlloe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 r" q ,; r) [ì IY' :." (:,j ': ,,' L ,;'} l(1 .' .", ,_.v.... J ck3s. Well: Field: Company: Country: 1 0-122 KUPARUK CONOCOPHILLlPS ALASKA INC USA I Tubing: Weight 9.3 ppf Grade & Thread L-80 EUE-8rd Nom.OD 3.5 ins Penetration and Metal Loss (% wall) _ penetration body 200 B!i metal loss body 150 ~----I 100 50 0 o to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 158) pene. 0 2 22 23 111 loss 1 157 0 0 0 o o Damage Configuration ( body) 150 100 50 o isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 150) 13 12' 125 0 0 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.ID 2.992 ins July 30, 2005 MFC 24 No 99628 1.69 24 J. Thompson Nom. Upset Upper len. 3.5 ins 1.2 ins Lower len. 1.2 ins Damage Profile (% wall) _ penetration body o O=- ~ s:ææ::... ::=r lI:::- -==- - --:-!:' ii1II\l metal loss body 50 100 49 ~.~ ~G, , " ,..; I, i'\. , 99 .. \' . , " " GlM 1 147r: Bottom of Survey = 150 Analysis Overview page 2 I~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE-8rd Well: 10-122 Body Wall: 0.254 in Field: KUPARUK Upset Wall: 0.254 in Company: CONOCOPHILLlPS ALASKA INC NominaII.D.: 2.992 in Country: USA Survey Date: July 30,2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall) (Ins.) (Ins.) 01 (Ins.) 0 50 100 10 .1 35 0 0.03 12 0 2.87 PUP Shallow pitting. 1 37 0 0.03 13 2 2.91 Shallow pitting. 1.1 69 0 0.02 7 2 2.88 PUP 2 79 0 0.03 12 2 2.90 3 110 0 0.04 17 :~ 2.90 Shallow corrosion. 4 142 0 0.04 15 2 2.91 Shallow pitting. 5 173 0 0.04 14 :>, 2.90 Shallow corrosion. 6 203 0 0.03 11 2 2.91 7 235 0 0.04 15 2 2.91 Shallow corrosion. 8 265 0 0.04 14 2 2.92 Shallow corrosion. 9 297 0 0.03 12 2 2.91 10 327 0 0.04 17 2 2.90 Shallow corrosion. 11 357 0 0.03 13 2 2.92 Shallow corrosion. 12 389 0 0.03 12 2 2.92 13 420 0 0.03 10 3 2.91 14 452 0 0.03 13 2 2.91 Shallow corrosion. 15 483 0 0.05 21 8 2.91 Corrosion. Lt. Deposits. 16 515 0 0.04 15 2 2.91 Shallow pitting. 17 546 0 0.03 11 2 2.93 18 578 0 0.04 15 3 2.90 Shallow pitting. 19 609 0 0.04 15 3 2.90 Shallow corrosion. 20 641 0 0.03 13 2 2.92 Shallow pitting. 21 672 0 0.04 17 '} 2.90 Shallow pitting. .) 22 704 0 0.03 12 2 2.91 23 735 0 0.04 15 2 2.92 Shallow corrosion. 24 766 0 0.06 22 2 2.90 Corrosion. Lt. Deposits. 25 797 0 0.07 26 2 2.91 Corrosion. Lt. Deposits. 26 828 0 0.07 26 2 2.92 Isolated pitting. 27 859 0 0.06 22 2 2.91 Isolated pitting. 28 889 0 0.09 35 3 2.90 Isolated pitting. Lt. Deposits. 29 921 0 0.09 35 2 2.92 Isolated pitting. 30 952 0 0.07 28 5 2.91 Isolated pitting. Lt. Deposits. 31 984 0 0.08 33 3 2.91 Isolated pitting. 32 1015 0 0.09 35 3 2.90 Line of Pits. Lt. Deposits. 33 1047 0 0.09 34 2 2.90 Line of Pits 34 1079 0 0.12 46 5 2.90 Line Corrosion. Lt. Deposits. 35 1110 0 0.09 34 2 2.91 Line Corrosion. 36 1142 0 0.09 34 3 2.91 Line Corrosion. 37 1173 0 0.09 35 3 2.91 Isolated pitting. 38 1205 0 0.10 40 2 2.91 Isolated pitting. 39 1236 0 0.09 33 5 2.91 Line Corrosion. Lt. Deposits. 40 1267 0 0.10 38 4 2.90 Isolated pitting. Lt. Deposits. 41 1298 0 0.10 41 6 2.92 Line Corrosion. 42 1329 0 0.10 39 4 2.93 Line Corrosion. 43 1361 0 0.08 33 4 2.91 Line Corrosion. 44 1392 0 0.11 44 6 2.91 Line Corrosion. 45 1423 0 0.11 43 5 2.91 Line Corrosion. Lt. Deposits. 46 1454 0 0.10 41 5 2.90 Line Corrosion. 47 1485 0 0.12 47 5 2.91 Line Corrosion. 48 1516 0 0.12 46 4 2.90 Line Corrosion. I Penetration Body Metal Loss Body Page 1 ~ PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 EUE-8rd 0.254 in 0.254 in 2.992 in Joint Jt. Depth Pen. Pen. Pen. ¡'vle-lal Min. No. (Ft.) Upset Body 0/0 Loss 1.0. (Ins.) (Ins.) (Yc) (Ins.) 49 1548 0 0.10 41 6 2.91 50 1579 0 0.13 50 6 2.92 51 1611 0 0.12 46 4 2.90 52 1642 0 0.11 43 5 2.91 53 1674 0 0.10 41 5 2.89 54 1705 0 0.11 43 6 2.89 55 1737 0 0.12 46 6 2.91 56 1768 0.07 0.15 57 7 2.89 57 1799 0 0.12 45 6 2.91 58 1831 0 0.13 53 6 2.87 59 1862 0 0.13 51 5 2.89 60 1894 0 0.12 46 6 2.88 61 1925 0 0.15 61 7 2.87 62 1957 0 0.14 57 7 2.86 63 1988 0 0.16 63 1:3 2.86 64 2020 0 0.11 45 C) 2.87 65 2050 0 0.16 65 6 2.90 66 2082 0 0.16 63 7 2.89 67 2113 0 0.13 53 6 2.89 68 2145 0 0.16 63 a 2.85 69 2176 0 0.18 69 6 2.85 70 2207 0 0.16 65 6 2.88 71 2239 0 0.15 60 6 2.89 72 2270 0 0.16 62 B 2.87 73 2302 0 0.18 71 7 2.88 74 2332 0 0.17 65 7 2.91 75 2364 0.10 0.15 59 6 2.91 76 2394 0 0.13 50 6 2.90 77 2426 0 0.13 51 <) 2.87 78 2457 0 0.13 51 9 2.85 79 2488 () 0.15 60 7 2.90 80 2519 0 0,14 57 8 2.91 81 2550 O.OC) 0.13 52 6 2.89 82 2581 0 0.15 59 6 2.88 83 2612 0 0.15 61 6 2.88 84 2644 0 0.16 64 7 2.89 85 2675 0 0.13 53 6 2.89 86 2707 0 0.16 63 6 2.86 87 2738 0 0.13 53 6 2.86 88 2770 0 0.14 56 10 2.89 89 2801 0 0.13 51' 9 2.91 90 2833 0 0.16 65 8 2.87 91 2864 0 0.12 47 5 2.89 92 2895 0 0.12 46 7 2.89 93 2926 0 0.12 48 6 2.87 94 2957 0 0.13 53 6 2.87 95 2988 0 0.12 46 6 2.84 96 3020 () 0.12 49 7 2.87 97 3051 0 0.13 50 5 2.91 98 3082 0 0.12 48 6 2.88 Well: Field: Company: Country: Survey Date: 1 0-122 KUPARUK CONOCOPHILLlPS ALASKA INC USA July 30, 2005 Comments Damage Profile (% wall) o 50 100 Line Corrosion. Lt. Deposits. Line Corrosion. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Line Corrosion. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. .. .. I .. .. I I Penetration Body Metal Loss Body Page 2 ~ { PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 EUE-8rd 0.254 in 0.254 in 2.992 in Joint Jt. Depth Pen. Pen. Pen. Melal Min. No. (Ft.) Upset Body % Loss 1.0. (Ins.) (Ins.) (~/o (Ins.) 99 3113 0 0.12 47 5 2.88 100 3145 0 0.15 58 () 2.91 101 3176 0 0.12 46 6 2.90 102 3207 0 0.14 55 G 2.86 103 3238 0 0.13 53 6 2.86 104 3269 0 0.12 46 6 2.88 105 3300 0 0.12 48 7 2.87 106 3331 0 0.12 46 5 2.88 107 3360 0 0.12 48 5 2.87 108 3392 0.09 0.15 61 6 2.83 109 3423 0 0.13 50 5 2.84 110 3455 0 0.12 48 5 2.87 111 3486 0 0.12 48 6 2.91 112 3516 0 0.14 56 6 2.89 113 3547 0 0.11 45 6 2.89 114 3578 () 0.12 46 6 2.88 115 3610 0 0.13 52 5 2.89 116 3641 0 0.13 52 6 2.86 117 3672 0 0.13 51 G 2.89 118 3703 0 0.12 49 7 2.88 119 3733 0 0.14 57 5 2.90 120 3764 0 0.12 48 5 2.93 121 3795 0 0.13 51 4 2.89 122 3827 0 0.12 48 6 2.90 123 3858 0 0.12 49 5 2.90 124 3890 0 0.11 43 5 2.90 125 3921 0 0.10 40 5 2.87 126 3952 0 0.13 SO 6 2.87 127 3983 () 0.11 44 5 2.88 128 4015 0 0.12 48 4 2.86 129 4046 0 0.13 51 4 2.91 130 4075 0 0.12 47 4 2.88 131 4107 0.07 0.12 47 5 2.90 132 4138 () 0.15 59 5 2.92 133 4168 0 0.12 47 4 2.90 134 4200 0 0.12 46 4 2.93 135 4231 0.07 0.13 50 5 2.91 136 4263 0 0.14 56 6 2.91 137 4292 0 0.11 43 6 2.90 138 4324 0 0.13 51 6 2.92 139 4355 0.07 0.13 50 6 2.91 140 4387 0 0.13 50 5 2.90 141 4418 o.nG 0.11 44 G 2.93 142 4450 0 0.12 47 4 2.91 143 4481 0 0.13 50 5 2.92 144 4513 0 0.16 64 7 2.92 145 4545 0 0.14 53 5 2.91 146 4576 0 0.10 39 4 2.90 146.1 4608 0 0.13 51 4 2.91 146.2 4622 0 0 0 0 N/A Well: Field: Company: Country: Survey Date: 1 0-122 KUPARUK CONOCOPHILLlPS ALASKA INC USA July 30, 2005 Comments Damage Profile (% wall) o 50 100 Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Line Corrosion. Line Corrosion. Lt. Deposits. Line Corrosion. Line Corrosion. Line Corrosion. Line Corrosion. Line corrosion. Line Corrosion. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Line Corrosion. Line corrosion. Lt. Deposits. . Line corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line, Corrosion. Lt. Deposits. Line Corrosion. Line corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. PUP Line G:orrosion. Lt. Deposits. GLM 1 (No Deviation) I --- ... ... ... I Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 EUE-8rd 0.2 54 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 0-1 22 KUPARUK CONOCOPHILLlPS ALASKA INC USA July 30, 2005 Joint Jt. Depth Pen. Pen. Pen. Melal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) Ok) (Ins.) 0 50 100 146.3 4628 0.11 0.11 43 4 2.89 PUP Line corrosion. Lt. Deposits. 147 4643 0 0.20 77 () 2.93 Line corrosion. Lt. Deposits. 147.1 4675 0 0.08 33 '1 2.94 PUP Line Corrosion. .) 147.2 4681 0 0 0 () 2.81 OS NIPPLE 147.3 4683 0 0.12 46 ') 2.91 PUP Line corrosion. . ) 148 4688 0.10 0.13 49 () 2.77 Line corrosion. Deposits. 148.1 4720 0 0.12 49 5 2.79 PUP Line Corrosion. Deposits. 148.2 4727 0 0 0 0 3.00 SBE 148.3 4739 0 0.10 39 2 2.90 PUP Line Corrosion. Lt. Deposits. 149 4746 0 0.19 76 7 2.75 Line Corrosion. Deposits. 150 4777 0 0.17 65 4 2.87 Line Corrosion. Lt. Deposits. . Penetration Body 1;( Metal Loss Body Page 4 cId··.·~.···--.'·'·_···· .6. .. PDS Report Cross Sections Well: Field: Company: Coun try: Tubing: 10-122 KUPARUK CONOCOPHILLlPS ALASKA INC USA 3.5 ins 9.3 ppf L-80 EUE-8rd Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 30, 2005 MFC 24 No 99628 1.69 24 J. Thompson Cross Section for Joint 147 at depth 4657.01 ft Tool speed = 50 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 96 % Tool deviation = 27 0 Finger 20 Penetration = 0.195 ins Line Corrosion 0.20 ins = 77% Wall Penetration HIGH SIDE = UP Cross Sections page 1 ····-->LS ~ .' PDS Report Cross Sections Well: Field: Company: Coun try: Tubing: 10-122 KUPARUK CONOCOPHILLlPS ALASKA INC USA 3.5 ins 9.3 ppf L-80 EUE-8rd Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst July 30, 2005 MFC 24 No 99628 1.69 24 J. Thompson Cross Section for Joint 149 at depth 4759.88 ft Tool speed = 49 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 95 % Tool deviation = 25 0 Finger 18 Penetration = 0.193 ins Line Corrosion 0.19 ins = 76% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ··~.,lS.'.' ,', ~ .. PDS Report Cross Sections Well: Field: Company: Country: Tubing: 10-122 KUPARUK CONOCOPHILLlPS ALASKA INC USA 3.5 ins 9.3 ppf L-80 EUE-8rd Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 30, 2005 MFC 24 No 99628 1.69 24 J. Thompson Cross Section for Joint 149 at depth 4764.32 ft Tool speed = 48 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 98 % Tool deviation = 23 0 Finger 3 Projection = -0.228 ins Deposits Min 10 = 2.75 ins HIGH SIDE = UP Cross Sections page 3 1----1s ~ ø· PDS Report Cross Sections Well: Field: Company: Country: Tubing: 10-122 KUPARUK CONOCOPHILLlPS ALASKA INC USA 3.5 ins 9.3 ppf L-BO EUE-8rd Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 30, 2005 MFC 24 No 99628 1.69 24 J. Thompson Cross Section for Joint 148 at depth 4705.49 ft Tool speed = 53 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 98 % Tool deviation = 23 0 ~ Finger 18 Projection = -0.226 ins Deposits Min 10 = 2.77 ins HIGH SIDE = UP Cross Sections page 4 WPHILLlPS Ala~rta, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY 1 D·122 GasUft anctå/Dummy Valve 1 (4622-4623, 00:7.725) Tubing (0-4739, 00:3,500, 10:2.992) API: 500292290500 SSSV Type: NONE Annular Fluid: 3% KCI Reference Log: LastTag: 5275 Last Tag Date: 5/4100 Casing String - ALL Size Top 16.000 0 5.500 0 3.500 4725 Tubing String· Tubing Size I Top 3.500 0 Perforations Summary Interval TVD 4788 - 4818 3587 - 3615 4850 - 4886 3645 - 3678 I[]I NIP (4681-4682, 00:3.500) Production (()"4725, 00:5.500, Wt:15.50) ,I SSE (4726-4727, 00:4.000) - - - Production (4725-5435, 00:3.500, Wt:9.30) Perf (4788-4818) Perf (4850-4886) Perf (4898-4918) Perf (4944-4954) Perf (4964-4992) Perf (5013-5026) PLUG (5319-5320, 00:3.500) x KRÙ Well Type: INJ Orig Completion: 8/17/98 Last W/O: Ref Log Date: TO: 5445 ftKB Max Hole Angle: 54 deg @ 1744 1 D-122 Angle @ TS: deg @ Angle ~ TO: 20 deg ~ 5445 Rev Reason: Tag by ImO Last Update: 5/9/00 Bottom TVD Wt Grade Thread 121 121 62.58 H-40 Welded 4725 3529 15.50 L-BO STCM 5435 4191 9.30 L-BO EUE 8rd Bottom TVD Wt Grade Th read 4739 3542 9.30 L-80 EUE 8rd Zone WSD WS C,WSB WSM WSA3 WSA3 WSA2 WSA2 WSA2 WSA2 Status Feet SPF Date Type 30 4 3/22199 IPERF 2 5" HC BH 36 4 3/22199 IPERF 2:5" HC: BH 2 5" HC BH 2:5" HC: BH 2 5" HC BH 2: 5" HC: BH 2 5" HC BH 2: 5" HC: BH 2.5" HC, BH 20 10 28 13 16 20 18 43/22199 IPERF 4 3/22199 IPERF 4 3/22199 IPERF 4 3/22199 IPERF 4 3/22199 IPERF 4 3/22199 IPERF 4 3/22199 IPERF 4898 - 4918 3689 - 3708 4944 - 4954 3732 - 3741 4964 - 4992 3750 - 3777 5013 - 5026 3796 - 3808 5034 - 5050 3816 - 3831 5060 - 5080 3840 - 3859 5090 - 5108 3868 - 3885 Gas Lift MandrelsNalves Stn MD TVD Man Man Mfr Type 1 4622 3435 CAMCO KBG29 CAMCO DMY Other ~)Iugs, equip., etc.) . Jewelry Depth TVD Type 4681 3488 NIP Cameo OS wlNOGO 4726 3530 SBE Baker GBH-22 5319 4082 PLUG Set 3.5" Baker bridge plug for PBTD of 5319' RKB. 5434 4190 SHOE VMfr V Type Comment 1.0 V OD Latch Port TRO Date Run o 9/25/98 Vlv Commenl Description INT 0.000 ID 2.812 3.000 0.000 3,000 Sperry-Sun Drilling Services LIS Sc Utility Wed Oct 14 09:07:36 1998 Reel Header Service name ............. LISTPE Date ..................... 98/10/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 98/10/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT (WEST SAK) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING MWD RUN 1 AK-MM-80335 S. BURKHARDT F. HERBERT OPEN HOLE BIT SIZE 1D-122 500292290500 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 14-OCT-98 MWD RUN 2 AK-MM-80335 So BURKHARDT F. HERBERT 23 liN 10E 196 598 .00 112.10 70.60 CASING DRILLERS (IN) SIZE (IN) DEPTH (FT) 2ND STRING 3RD, STRING PRODUCTION STRING REMARKS: 8.50~ 5445.0 .... 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM MIKE WERNER OF ARCO ALASKA, INC. ON 08/26/98. MWD IS PDC. 3. MWD RUNS 1 & 2 ARE DIRECTIONAL, DUAL GAMMA P_AY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . 4. WELL 1D-122 REACHED A TOTAL DEPTH OF 5445'MD, 4201'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. SLIDE = MUD MOTOR DRILLING (NO ROTATION). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/14 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 RPD 63 0 5407 5 RPM 63 0 5407 5 RPS 63 0 5407 5 RPX 63 0 5407 5 GR 71 0 5415 0 FET 100 0 5407 5 ROP 102 0 5445 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ EQUIVALENT UNSHIFTED DEPTH MERGED. DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: BIT RUm NO MERGE TOP MERGE BASE 1 121.0 3788.0 2 3788.0 5445.0 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 DEPT FT 4 1 GR MWD API 4 1 RPX MWD OHMM 4 1 RPS MWD OHMM 4 1 RPM MWD OHMM 4 1 RPD MWD OHMM 4 1 ROP MWD FT/H 4 1 FET MWD HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name DEPT GR RPX RPS RPM RPD ROP FET Min 63 11 1937 0 7625 1 0424 0 3577 0 2336 8 1558 0 0794 Max 5445 149.828 2000 2000 2000 2000 642.413 11.7203 Mean Nsam 2754 10765 71.1104 10689 62.0141 10690 63.2044 10690 75.2947 10690 77.3294 10690 285.164 10687 0.337364 10616 First Reading 63 71 63 63 63 63 102 100 Last Reading 5445 5415 5407.5 5407.5 5407.5 5407.5 5445 5407.5 First Reading For Entire File .......... 63 Last Reading For Entire File ........... 5445 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF Wile Header Service name ........... '..STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD RPM RPS RPX GR FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 63 0 63 0 63 0 63 0 71 0 100 0 102 0 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 3749 5 3749 5 3749 5 3749 5 3757 5 3749 5 3787 5 13-AUG-98 ISC 5.06 CIM 5.46/EWP4 1.38 MEMORY 3788.0 121.0 3788.0 .0 52.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P1067CRG6 P1067CRG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 8.500 8.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPEP_ATURE (MT): LSND 9.60 257.0 8.4 400 4.5 6.000 MUD AT MAX CIRCULATING TERMPEP~ATURE: MUD FILTRATE AT M MUD CAKE AT MT: NEUTRON TOOL NLATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STAi~DOFF (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 A~sent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 4.595 3.500 3.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 ~0.6 First Name Min Max Mean Nsam Reading DEPT 63 3787.5 1925.25 7450 63 GR 11.1937 149.828 67.9653 7374 71 RPX 0.7625 2000 85.711 7374 63 RPS 1.0424 2000 87.3666 7374 63 RPM 0.3577 2000 105.081 7374 63 RPD 0.2336 2000 108.011 7374 63 ROP 53.26 624.305 309.999 7372 102 FET 0.0794 2.7657 0.227538 7300 100 Last Reading 3787 5 3757 5 3749 5 3749 5 3749 5 3749 5 3787 5 3749 5 First Reading For Entire File .......... 63 Last Reading For Entire File ........... 3787.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/14 Maximum Physical Record..65535 File Type ................ LO Next File Name .......... ~TSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/14 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 3750 0 5407 5 RPD 3750 0 5407 5 RPM 3750 0 5407 5 RPS 3750 0 5407 5 RPX 3750 0 5407 5 GR 3758 0 5415 0 ROP 3788 0 5445 0 $ LOG HEADER DATA DATE LOGGED: 14-AUG-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46/EWP4 1.38 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 5445.0 TOP LOG INTERVAL (FT) : 3788.0 BOTTOM LOG INTERVAL (FT) : 5445.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 20.1 MAXIMUM ANGLE: 49.6 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) : TOOL NUMBER P1067CRG6 P1067CRG6 8.500 8.5 LSND 9.60 293.0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT NLAX CIRCULATING TERMPERATLrRE: 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 8.4 300 .6 3.400 2.300 4.500 2.400 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 2 API 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 40.4 Name Min Max Mean DEPT 3750 5445 4597.5 GR 20.4365 139.434 78.1064 RPX 1.7012 107.867 9.31793 RPS 1.8958 89.1189 9.4734 RPM 1.5252 78.9759 9.05709 RPD 1.4001 69.7129 9.10095 ROP 8.1558 642.413 229.935 FET 0.0831 11.72 0.579142 Nsam 3391 3315 3316 3316 3316 3316 3315 3316 First Reading 3750 3758 3750 3750 3750 3750 3788 3750 Last Reading 5445 5415 5407.5 5407.5 5407.5 5407.5 5445 5407.5 First Reading For Entire File .......... 3750 Last Reading For Entire File ........... 5445 File Trailer Service name ............. STSLIB.003 Service Sub Level Name..~ Version Number .......... 0.0 Date of Generation ...... ~8/10/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/10/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ............ UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/10/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File