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Home My WebLink About198-262C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\OLDB5O34\2023-01-08_15899_KRU_2L-321_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 15899 KRU 2L-321 50-103-20286-00 LeakPoint Survey 08-Jan-23 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 By Meredith Guhl at 3:20 pm, Jan 11, 2023 198-262 T37434 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.11 15:22:36 -09'00' ! " # " $% & $% ' ()! * '& +, !- ."!! /, +, 01021*-1 3+ - " ' & 04156 ! 2./16 ! $ & 04156 5046750.67 52/675(.6 2./16 20.(6720..67 2512672516 8 (.1#*016 9 24./#2206 + :77 -0#53.; ,#.1 5.(68& 250169& < 9+ '7 - 50468& 50.68& 52/68& 5(.68& !3 20.(69& 20..69& 251269& 25169& !3 0 =: ' ) + - !3 5 = 2" < & ' " $% ' & , ' (" < > "&, $ & > >)!? @ ,@> '!!3 $% ! $ : 1.6 00.*6 2.*.6 2526 05.16 4464#30; ?< !3 *.6 50*46 (; *#23.; 2#30;%5#30; , , 05256 4(6 $,A ,A),!&>!$ 9)!88))! !"#$%&% '($!()$%(%#&$(($(( * 2 & !0 ! ! 4" B"< ()#((') + ,-.* <7) B%115(1 7A//21 5 +%$)%! < & ' )C & /BB, /11 0218 **B&002 4 += 01021*17021*7D020.5- 5.B& > #8 / 1.6 55106 011 0 !3 $ > $ :! & & ")!?"> 0428 " #B #B *)' ' '< 02BB, 005 & ' 'E +/1*-(2/#*004 ") ' <0< <0< <0< <B<&< 9! 1#414 13010 " 51' By Samantha Carlisle at 2:28 pm, Oct 14, 2021 Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2021.10.14 11:21:35-08'00' Foxit PDF Editor Version: 11.0.0 Dusty Freeborn ADL0380052, ADL0380051, DSR-10/15/21SFD 10/19/2021 RBDMS HEW 10/15/2021 SFD 10/19/2021 VTL 01/24/2022 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 12,068.0 12/7/2018 2L-321 condijw Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set patch extension, open SSD, Set POGLM 9/30/2021 2L-321 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 30.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 28.5 Set Depth (ftKB) 3,302.1 Set Depth (TVD) … 2,287.4 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-MOD Casing Description PRODUCTION 5.5"x3.5" @ 11454' OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 27.0 Set Depth (ftKB) 12,379.6 Set Depth (TVD) … 5,877.8 Wt/Len (l… 15.50 Grade L-80 Top Thread LTC-MOD Casing Description PRODUCTION SCAB LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 25.0 Set Depth (ftKB) 11,440.7 Set Depth (TVD) … 5,351.5 Wt/Len (l… 11.60 Grade T-95 Top Thread HYD 513 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 11,395.5 5,325.5 55.46 XO - Reducing 4 1/2" ST-L Box x 3 1/2 IBT Pin XO 3.500 11,396.4 5,326.0 55.44 SBR Baker 40-26 2.688" Seal Bore 3 1/2" IBT pin x 3 1/2" IBT-Mod box 2.680 11,418.5 5,338.7 54.93 LOCATOR LOCATOR SUB 2.980 11,421.3 5,340.3 54.88 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY 2.980 Tubing Strings Tubing Description TUBING WO String Ma… 2 3/8 ID (in) 1.96 Top (ftKB) 25.0 Set Depth (ft… 11,386.0 Set Depth (TVD) (… 5,320.2 Wt (lb/ft) 4.60 Grade L-80 Top Connection IBT Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 25.0 25.0 0.08 HANGER FMC TC-1A-EMS TUBING HANGER 1.990 11,315.8 5,281.4 57.30 Sliding Sleeve - Open 09-30-21 HES SSD-XD SLIDING SLEEVE (opened 09/30/2021) 1.875 11,365.1 5,308.4 56.16 LOCATOR LOCATOR w/ 2' SPACE OUT 2.680 11,367.9 5,310.0 56.10 PACKER BAKER D PRODUCTION PACKER w/ GBH-22 BONDED SEAL ASSEMBLY 2.680 11,370.4 5,311.4 56.04 SBE SEAL BORE EXTENSTION 23-26 2.680 11,383.7 5,318.9 55.73 NIPPLE CAMCO D PROFILE NIPPLE w/ 1.812" PROFILE 1.812 11,385.3 5,319.8 55.69 WLEG WLEG GUIDE w/ 2 3/8" BOX 1.970 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 11,315. 0 5,281.0 57.32 POGLM 1.875" X-Lock w/ POGLM (1/4"OV) 47.5" OAL 9/30/2021 0.000 11,324. 0 5,285.8 57.11 PACKER - PATCH - UPR Set 3 3/8" TTS P2P packer, xo, & anchor latch stung into exististing pack (OAL 4.01') 9/30/2021 1.000 CPP23802 11,328. 0 5,288.0 57.01 PATCH PACKER 1.81" P2P CPP23803 w/ 27' OF SPACER PIPE AND ANCHOR LATCH CPAL23801. OAL 31' MAX OD 1.81" 2/15/2019 0.950 CPP23803 11,332. 0 5,290.2 56.92 SPACER PIPE 27' OF 1" SPACER PIPE. 2/15/2019 1.070 CPAI 11,340. 0 5,294.6 56.74 TUBING LEAK TUBING LEAK AT 11340', CONFIRMED BY LDL ON 11/5/17 AND AGAIN ON 12/8/18 11/5/2017 2.992 11,350. 0 5,300.1 56.51 TUBING LEAK SUSPECTED TUBING LEAK AT 11350', BASED ON LDL ON 12/8/18, AND ON ERROSION SEEN ON LWR P2P PACKER PULLED ON 12/7/18 12/8/2018 2.992 11,359. 0 5,305.1 56.30 PATCH PACKER 1.81" P2P CPP23801. OAL 4' MAX OD 1.81" 2/14/2019 1.000 CPP23801 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 11,680.0 11,720.0 5,489.3 5,511.9 S-5, 2L-321 1/26/1999 6.0 IPERF 2.5" HC Big hole chrgs, 60 deg ph 11,680.0 11,720.0 5,489.3 5,511.9 S-5, 2L-321 12/9/2018 6.0 RPERF 1-9/16" Perfecta Gun, Loaded 6-SPF, 60-deg Phasing Notes: General & Safety End Date Annotation 12/6/2008 NOTE: View Schematic w/ Alaska Schematic9.0 5/23/2007 NOTE: 5 1/2" PRODUCTION CASING LEAKS TO FORMATION @ 7694' TO 8411' RKB 2L-321, 10/7/2021 10:42:06 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 11454'; 27.0-12,379.6 IPERF; 11,680.0-11,720.0 RPERF; 11,680.0-11,720.0 PRODUCTION SCAB LINER; 25.0-11,440.7 WLEG; 11,385.3 NIPPLE; 11,383.7 SBE; 11,370.4 PACKER; 11,367.8 LOCATOR; 11,365.1 PATCH PACKER; 11,359.0 TUBING LEAK; 11,350.0 SPACER PIPE; 11,332.0 TUBING LEAK; 11,340.0 PATCH PACKER; 11,328.0 PACKER - PATCH - UPR; 11,324.0 Sliding Sleeve - Open 09-30-21; 11,315.7 POGLM; 11,315.0 SURFACE; 28.5-3,302.0 CONDUCTOR; 30.0-108.0 HANGER; 25.0 KUP PROD KB-Grd (ft) 37.50 Rig Release Date 1/12/1999 2L-321 ... TD Act Btm (ftKB) 12,403.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032028600 Wellbore Status PROD Max Angle & MD Incl (°) 70.21 MD (ftKB) 6,344.88 WELLNAME WELLBORE2L-321 Annotation Last WO: End Date 11/21/2008 H2S (ppm) 30 Date 12/6/2016 Comment SSSV: NONE P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 14, 2021 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the tubing patch repair of KRU 2L-321 (PTD 198-262). Please contact me at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2021.10.14 11:20:55-08'00' Foxit PDF Editor Version: 11.0.0 Dusty Freeborn ! "" # "$!!" %& '"(! #)*"%( " ""&+ '(' $ "+ ""#"" (' #"*", ""!" '"$ *, "!'--- " --- "', "!$ +." $ "+*"#"!,*.$ +"+ /012345678592:1;2 /<<4=>;?@9=451;2: WELL LOG TRANSMITTAL #905482341 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log and Packer Set Record: 2L-321 Run Date: 2/13/2019 and 2/14/2019 108"62 30 72 6 April 12, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 2L-321 Digital Data in LAS format, Digital Log file 50-103-20286-00 RECEIVE,) MAY 0 8 2019 AOGCC 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ ANC@halliburton.com Date: o Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 'RECEIVED LIAR 2 8 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Op n , Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Tubing/Casing Patch 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development EI Exploratory ❑ Stratigraphic❑ Service ❑ 198-262 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20286-00 7. Property Designation (Lease Number): s. Well Name and Number: ADL 380053 K RU 2L-321 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Tarn Oil Pool 11. Present Well Condition Summary: Total Depth measured 12,403 feet Plugs measured None feet true vertical 5890 feet Junk measured None feet Effective Depth measured 11,716 feet Packer measured 328, 11359, 11 c feet true vertical 5,512 feet true vertical 1288, 5305, 5311 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 16 108' MD SURFACE 3,274 feet 7 5/8 " 3,302' MD PRODUCTION 12,353 feet 4 1/2 " 12,380' MD PRODUCTION 11,416 feet 5 1/2 " 11,441' MD Perforation depth: Measured depth: 11680-11720 feet True Vertical depth: 5489-5512 feet Tubing (size, grade, measured and true vertical depth) 2,4 " 0 11,384' MD 5,319' TVD Packers and SSSV (type, measured and true vertical depth) PATCH PACKER - 1.81" P2P CPP2380 11,328' MD 5,288' TVD PATCH PACKER - 1.81" P2P CPP2380 11,359' MD 5,305' TVD PACKER - BAKER D PRODUCTION P/ 11,368' MD 5,310' TVD NONE - Type Not Found (Manual Entry 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf I Water -Bbl Casing Pressure Tubing Pmssure Prior to well operation: 120 218 143 2615 269 Subsequent to operation:1 117 17 1 171 432 278 14. Attachments (requires per 20 AAc 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations ID Exploratory ❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil p Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NIA Contact Name: Steve Drake Authorized Name: Steve Drake contactEmail�e .G.Drake@cop.com Authorized Title: Sr. Wells Engineer Authorized Signature: Date: 3 z Contact Phone: (907) 263-4062 Form 10-404 Revised 4/2017 V 7'L g fll9 'a ul�q �(' Submit Original Only RBDMS+�,/ MAR 2 9 2019 General Well Work Request Form Well: 2L321 Date of Request: Request SPOC: Well Type: Producer Req. Written by: Job Scope:j Tubing/Casing Patch Shut -In Reason Code: Budget Category: I Kuperuk Base Expense Well Shut in Date (if SI) Prioritization Category Network: Job I SAP Comment: Well Work is not justigell via imneased Production Current Well Data Current Oil Rate (BOPD) 0 Post -Job Oil Rate (BOPD) Risked NOB (BOPD) 1/24/2019 I CPF2 PE David/Stephanie x7519, pgr 252 Steve Drake, 263-4062 270 Tubing / Casing / Packer Leaks 12/1712018 Opportunity/Rate Adding 10401291 Preventive Maintenance Program Request After Well Work Data 180 Enter Rates Last SBHP 2516 psi Last Tag 12,127'md H2S (PPM): 30 ppm on 12/6/16 SBHP Date 6119/2017 Tag Date 10/24/2018 Any Fluid Restriction on Well? No SBHP Datum (TVD/SS?) 5500 TVD Max Inclin. 70° Max Dogleg 7" 1 100'and Min. LD (at/above work) 1.875" Max Incl. Depth 6,344'md Max Dogleg Depth 1,754'md Well Work Justification & Objectives (and date required if appropriate): 2L-321 is a single bore producer that was drilled and completed in December of 1998. The well began experiencing problems in 2006 and was worked over in 2008. CONDENSED TROUBLESHOOTING HISTORY: 2L-321 has gone through a number of patches and different sized jet pumps to get it to produce. The most recent jet pump and patch was set on 12/12/18. Shortly after the well began cycling power fluid. The jet pump was pulled, sliding sleeve closed, patch tested and pulled and a passing CMIT with a plug set in the nipple profile @ 11384' RKB. This procedure will outline the steps to 1. Perform a LDL to ensure there are no other leaks besides the ones at 11340 and 11350. 2. Circulate clean corrosion inhibited seawater in the IA through the leaks. 3. Patch over the leaks. 4. Install a ported gas lift sleeve over the CMD to convert the well to gas lift. Risk/Job Concerns: Min ID of a Halliburton SSD -XD sliding sleeve of 1.875" @ 11315' RKB Steps: RELAY - LDL (can use CISW in LRS step for LOU 1. MIRU Relay and associated support equipment. 2. RU LRS to pump down tubing and take returns off the IA for LDL. Returns can be taken to 2L-322, currently online as of 1/15/19. 3. RIH with shifting tool and shift sliding sleeve @ 11,316' CLOSED. Sleeve shifts UP to close. 4. MU and RIH with LDL tools, pumping down tubing, taking returns off A. Reconfirm leaks at 11340 and 11350. Investigate tubing for other potential leaks. 5. If other leaks are found, confer with town over potential to patch all leaks. 6. If no other leaks are found, will run patch configuration similar to the last TTS patch in hole. 7. POOH. Leave LRS on location to pump circ out. LRS - Circ out 1. Pump 124 barrels of corrosion inhibited SW followed by 35 barrels of diesel down the tubing taking returns off IA. 2. U-tube diesel from tubing to IA at surface. 3. RDMO RELAY - LDL (set patch and POGLM) 1. MIRU Relay and associated equipment 2. Pull 1.81" CA2 plug in nipple @ 11384' RKB. 3. RIH with 2 3/8" TTS packer (1.810" running OD) and set center element at 11,359' RKB. 4. RIH with 2 3/8" TTS test tool and set in top of packer. CMIT TxIA to 3000 psi. Pull test tool. 5. RIH with stinger/spacer pipe/upper TTS packer assembly (33.05' CAL) and stab into top of lower packer at 11359' RKB. This should put the top PIIP packer at approximately 11,328' RKB. 6. RIH and set test tool in top of patch @ 11,329' RKB and MIT -T to 3000 psi. Pull test tool from uppper packer. 7. Open XD sliding sleeve (shifts down to open)@ 11,316'. 8. CMIT to 3000 psi to ensure snap latch assembly in patch is holding. 9. Set ported gas lift sleeve across open sliding sleeve at 11,316' RKB with 1.875" x -lack. 30. RDMO 11. Turn well over to OPS to BOL. 2L-321 LDL_Pamh_GL Sleeve 01-24-18 SGD.xkm Printed 3/27/2019 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday, April 3, 2019 9:44 AM To: Drake, Steve G Subject: KRU 2L-321 (PTD 198-262) Recent Tubing/Casing Patch 10-404 Submission Steve, Please provide the well service reports for this work. They should be included in the 10-404 submission. You may email them to me. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepppalaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeongalaska aov Well History 2L-321 API / UM Legal WeIlName Field Name 5010320286 2L-321 TARN PARTICIPATING AREA Well TypeOrigina[K&RT Elevation (ft) Well Status Development 146.10 PROD Left START DATE is from Daily Ops and Right Start Date represents the Job Start Lags] Stan Date WeIlName Last 24hr Sum AFEIRFE R,g Supervisor Job Type Sial Data 2/15/2019 2L-321 CMIT TO 3000 (PASS) WITH TEST TOOL SET IN P2P @ 10401291 FAMA, ESP / JET PUMP 4/2412018 11,359' RKB. SET 1.81" P2P (#CPP23803), SPACER PIPE, JAKE,Wells ANCHOR LATCH (#CPAL23801) MID-ELEM @ 11,328' RKB. Supervisor LRS PERFORM PASSING MITIATO 3000. IN PROGRESS. 2/14/2019 2L-321 PULLED 1.81" CA-2 PLUG @ 11,384' RKB. SET 1.81" P2P 10401291 FAMA, ESP I JET PUMP 4/24/2018 (#CPP23801) MID ELEM @ 11,359' RKB. CORRELATE TO JAKE,Wells TBG TALLY 11119/2008. IN PROGRESS. Supervisor 2/13/2019 2L-321 CONFIRM XD CLOSED @ 11,316' RKB. LOG BASELINE 10401291 FAMA, ESP / JET PUMP 4124/2018 TEMP TO PLUG @ 11,384' RKB. CONFIRMED KNOWN JAKE,Wells LEAKS @ 11,340' & 11,350' RKB. NO OTHER LEAKS Supervisor OBSERVED. LRS ON LOCATION TO CIRC OUT TBG x IA. LRS PUMPED 105 BBLS OF CORROSION INHIBITED SW FOLLOWED BY 55 BBLS OF DSL. U-TUBE TO FREEZE PROTECT IAAND TUBING. JOB IN PROGRESS. 1/712019 2L-321 MIT Tx IA COMBO KRUCPF2LRS KENNEDY, PUMPINGTRACKING 11/9/2018 CHRIS,Wells ONLY Supervisor 1/712019 21--321 PULLED 1.81" CA2 @ 11,331' RKB. DRIFTED TBG w/ 1.85" 10401291 FERGUSON, ESP I JET PUMP 4/24/2018 SWEDGE. CLEAR TIGHT SPOT/ OBSTRUCTION. SET 1.81" SID,Wells CA2 w/ 1.84" NOGO @ 11,383' RKB. CMIT TO 3000 PSI "" Supervisor PASS ""`. CURRENT PROCEDURE COMPLETE, NEED PLAN FORWARD. 1/6/2019 2L-321 ATTEMPT TO TEST LOWER PACKER w/o SUCCESS. PULL 10401291 FERGUSON, ESP / JET PUMP 4/24/2018 LOWER PACKER. ATTEMPT TO SET 1.81" CA2 PLUG. SO SID,Welis HIGH @ 11,331 RKB. LEFT PLUG IN HOLE. IN PROGRESS. Supervisor 1/5/2019 2L-321 PULLED 1.81" UPPER PACKER & SPACER PIPE.'"' 114 OF 10401291 FERGUSON. ESP / JEf PUMP 4/24/2018 ONE ELEMENT & 1 OF 3 SLIPS LEFT IN HOLE •"" TIGHT SID,Wells SPOT / OBSTRUCTION @ 11,331' RKB. LIB INCONCLUSIVE Supervisor & MAGINET RECOVERED SMALL SPRING, IN PROGRESS. 1/4/2019 21--321 SET TEST TOOL IN TOP OF PATCH @ 11,329' RKB. MIT TO 10401291 FERGUSON, ESP/ JET PUMP 4/24/2018 3000 PSI "`• PASS —ATTEMPT TO PULL PATCH w/o SID,Wells SUCCESS. IN PROGRESS. Supervisor 1/3/2019 2L-321 PULLED 2" JET PUMP @ 11,315' RKB. CLOSED XD SLEEVE 10401291 FERGUSON, ESP / JET PUMP 4/24/2018 @ 11,315' RKB. ATTEMPT TO MIT x IA. ""' FAIL •"" ABLE TO SID,Welis PUMP @ 1.1 BBLS/ MIN ONLY REACHING 2425 PSI Supervisor PRESSURE BEGINS TO FALL AS SOON AND PUMP SHUTS DOWN. IN PROGRESS 1/2/2019 21--321 DRIFT TO TOP OF JET PUMP @ 11,315' RKB w/ 1.89" 10401291 FERGUSON, ESP / JET PUMP 4/24/2018 GUAGE RING. IN PROGRESS. SID,Wells Supervisor 12/12/2018 21--321 SET 1.875" XLOCK & 2" RC JET PUMP, SHOCK, SPARTEK 10410033 HAZEN. ESP/ JET PUMP 8/22/2018 GAUGE (#CP-1170, 10A RATIO, 31" C–C ON PKG) IN XD MIKE,Welis SSD 11,316 RKB. PUMP DOWN TATO CONFIRM Engineer COMMUNICATION. JOB COMPLETE. 12/11/2018 2L-321 SET 1.81" P2P (#CPP23803), SPACER, ANCHOR LATCH 10410033 HAZEN, ESP / JET PUMP 8/22/2018 (#CPAL23801) MID ELEM @ 11,329' RKB. MIT IA TO 3000 MIKE,Wells (PASS). OPEN XD SSD @ 11,316 RKB. IN PROGRESS. Engineer 12/10/2018 2L-321 BRUSH n' FLUSH TBG TO 11383' RKB, SET 1.81" LOWER 10410033 CONDIO. ESP / JET PUMP 8/22/2018 P2P PACKER @ 11360' RKB (CPP23801 / 1" ID / DAL 3.73'), JOHN,Wells CMIT TBG x IA TO 3000 PSI PASS. IN PROGRESS. Supervisor 12/9/2018 21--321 RAN TWO 20'x 1 9/16" HSC 6 SPF 60 DEG PERFECTA 10410033 CONDIO, ESP/ JET PUMP 8/22/2018 PERFORATING GUN'S SHOT FROM 11720' TO 11680' RKB JOHN,Wells TIE INTO GAMMA RAY LOG JANUARY 1999. IN Supervisor PROGRESS. 12/8/2018 2L-321 LOG GAMMA RAY CCL FROM 12068' RKB TO 11298' RKB, 10410033 CONDIO, ESP I JET PUMP 8/22/2018 LOG 24 ARM CALIPER FROM 11496' RKB TO SURFACE JOHN,Wells (GOOD DATA), PREFORMED LDL FROM 11450' TO 11250' Supervisor RKB SEE POSSIBLE NEW LEAK @ 11350' RKB CONFIRM LEAK @ 11340' RKB. IN PROGRESS. Page 1131 Report Printed: 4/412019 KUP PROD WELLNAME 21_-321 WELLBORE 2L-321 h..l ' Well Attributes Max Angle S MD TO '"'�� Fkla Name ve"a"ePPW'M Wellbore Slalus ncl rl MOIttxBI Net 9lm (HeinNBbke. Ina TARN PARTICIPgTING AREA 501032028600 PROD 0.21 634488 124030 azlWo: 2.1. 3rb 11935156AM Last Tag Vxtl®rrc,aiuticl�N Annotamn expeopKel End Dtle WeIIMre LastMW By Last Tag: RKB 12,068.0 1 12/]12018 2L-321 mndijw __..__._.................._........_............. ....... Last Rev Reason HANGER;2BC Annciallon End Dab ..Wra tffitMctl By Rev Reason. Close siding sleeve, pull plug, set patch 215/2019 2L-321 f, Casing Strings n.m. Deecryfien oo (nl m(m) Top lnxRl Goepm Ilona) Set o.pM (NEN When n._GrM. Top]Mead CONDUCTOR 16 1586 30.0 IS 1080 108.0 62.58 H-40 WELDED Camne Damnation OD had ID (in) Top W" SHOeINk(aKIN C... Set oepmND) WIILen R... Gen. Topommid SURFACE 753 887 28.5 3,302.1 2,2874 29.70 LA0 BTC -MOD CasLry Emaciation OD(n) ID lin) Tdp has 8et0epM „tl(B) BN oepm tiVD)... WSLen p... Grade Top Thoned PRODUCTION 5112 4.95 21.0 12,3)9.6 5,87].8 15.50 LA0 LTC -MOD 5.5'X3.5" @ 11454' Casing DeacrlM PRODUCTION SCAB Goin) 4112 oil.) 396 rop MKa) 250 sM oepm me) 11,4407 SeI DegS madL. 5,351.5 liantan 11... 1160 Goode Tap nlreM T-95 HYD 513 LINER Liner Details coxoumoa:3Do-lmo xoMnal io Top11,3 TaplNDl taKB1 Top Ind Pl ttRe Des Com ll3. 11,395.5 5,3255 5546 XO -Recanting 4112"STA eoxx 11210] Pin XO 3.500 11,396.4 5,3260 55.44 SBR Beker4 eat ore /'I pini 1l" 2.68 IBT-Mod box 11,418.5 53387 54.93 LOCATOR LOCATOR SUB 2.9 11,421.3 5,340.3 5488 SEAL ASSY IBAKER 80-0O GBH -22 SEAL ASSEMBLY 2.9 SURFACE ; M"3020 -Tubing Strings ),bine Descnpuonstanp an...rDf nl TaHUNKB) Eel DepmW SNDepmn'VEH( WIHann) Gnae rnpeonneceon TUBING WO 2318 1.96 25.0 113863 5,3202 460 LA0 IBT Completion Details Top ITRa Top Nominal Top UVKER UKal (°1 Nem Des Com I(Hoa sM'rvsx.le..' 25.0 25.0 0.06 HANGER FMC TC -IA -EMS TUBING HANGER IRIAU 11,315.8 5,2814 5].30tieing reeve- HESSSD-XD SLIDING SLEEVE (CLOSED 113119) 1.815 Closed! 11,3651 5.3084 56.16 LOCATOR LO ATOR .12 SPACE OUT 2680 PATCH PAcnER;tt3:aoUp 11,3679 5,310.0 56.10 PACKER BAKER D PRODUCTI NPACKER WI GBH -22 BONDED SEAL 2680 ASSEMBLY meixc LEAK u,31oD LEAK 11,3704 5.3114 56.04 SBE SEAL BORE EXTENSTION 23-262680 PACER 1Limed 11,3837 5,318.9 55.]3 NIPPLE CAMCO D PROFILE N IPPLE WI 1812' PROFILE 1.812 11385.3 5,3198 5569 WLEG WLEGGUIDEw/23/8"BOX 1970 TUB NG LEAC 11,Y4.o Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top QVDI Topl al Tan (MB) UKEU I•) Des Com Run mb mam) 11,328.0 5,280.0 57,01 PATH 1.81"P P CPP23803 .127' OF SPACER 2/158019 0.950 PATCH PACKER, 11.359.0 PACKER ANCHOR CATCH CPALKU*1. OAL31' MM OD 1.81" 11,332.0 5,290.2 PA ER PIPE 27 OF 1"SPACER PIPE. L15I2019 1.070 11,340.0 5,294.6 56.77 TUBING LEAK TUBING LEAK AT 11340', CONFIRMED BY LDL ON 11/5IM17 2992 LocAroR; ,3531 113117 AND AGAIN ON 1218118 PACI(ER;fL3a]a 11,350.0 5,300.1 5851 TUBING LEAK SUSPECTED TUBING LEAK AT 1135(1',BA LDL ON 1218/18, AND ON ERROSION SEEN ON CAB 12/88018 2.992 BEE;1L3ma P2P PACKER PULLED ON 120118 11,3590 5305.1 56.30 MUM 181' P2P CPP23801. DAL 4'MAX DD 181" 2/148019 1.000 PACKER NIPPLE, 11.383.] Perforations 8r slots She WLEG, II38E3 TOP MIR BMMDI Dens Ishabm Topime) Busy" I (I EB (MB) Linked2one Dale I Tyye Com 11,6800 11,720.0 5,489.3 5,511. S -5, n-321 18611999 6.0 IPERF Big hole culls, 60 deg ph 11,680.0 11,720.0 5,489.3 5,511. 5,2L-321 12/912018 60 RPERF 1-47T9 ecm un, 1 Loaaea 6 -SPF, 6"eg Phasing Notes: General 8 Safety Ena Dale Annomdon 5838007 NOTE S 111' PRODUCTION CASING LEAKS TO FORMATION @ 7694TO 8411' RIGS 12168008 ING,: 1mvW hem.U,.Aleska5cUURafc98 PRCDVCTIGNaCABDNER; E 611,ap] RPERF; 11.b0611.TA0 IPERF; 118W- 611,Tip.O� PRODUCLON UVIAMl 'V23e hii—CF STATE OF ALASKA ' �°� ALIIIL OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS MAY 0 3 2018 1.Operations ' Abandon El Plug Perforations❑ Fracture Stimulate El Pull Tubing El e.- , "•.:' Performed: Suspend El Perforate ❑ p ❑ Other Stimulate ❑ Alter Casing❑ Change Approve. -rograrr� ❑ Plug for Redrill ❑ 'erforate New Pool El Repair Well ❑ Re-enter Susp Well❑ Other: Tubing Patch 'i 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. p Exploratory Development 2❑ Ex loratory ❑ 198-262 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service ❑ 6.API Number: 99510 50-103-20286-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 2L-321 ADL 380053 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 12,403 feet Plugs measured None feet true vertical 5,890 feet Junk measured None feet Effective Depth measured 11,716 feet Packer measured 11,368 feet true vertical 5,512 feet true vertical 5,310 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 16 " 108'MD 108'ND SURFACE 3,274 feet 7 5/8" 3,302' MD 2288'ND PRODUCTION 11,416 feet 4 1/2 " 11,441' MD 5350'ND PRODUCTION 12,353 feet 4 1/2 " 12,380'MD 5878'TVD Perforation depth: Measured depth: 11680-11720 feet �i 2 True Vertical depth: 5489-5512 feet �/Y �, Tubing(size,grade,measured and true vertical depth) 2.375 L-80 11,386' MD 5,320'TVD Packers and SSSV(type,measured and true vertical depth) PACKER- BAKER D PACKER 11,368' MD 5,310'ND_ SSSV = NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: 1 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 117 150 11 2300 250 Subsequent to operation: 180 170 18 2400 274 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development l] Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas El WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ 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: N/A Contact Name: Steve Drake Authorized Name: Steve G.Drake Contact Email: Steve.G.Drake@cop.com Authorized Title: Sr.Wells Engineer / Authorized Signature: ,� Date: 5/ 3 /X Contact Phone: (907)263-4062 Form 10-404 Revised 4/2017 vi-L- B/L. `v R�+��S� MAY O 201 Submit Original Only • 2L-321 TUBING PATCH DTTMSTI JOBTYP SUMMARYOPS 4/24/18 ESP/ PULLED PLUG &GAUGES @ 11384' RKB (2570 PSI MAX PRESSURE) JET FLAG WIRE OFF OF D NIPPLE. SET 2 3/8"SLIP STOP @ 11352' RKB. PUMP SET 2 3/8" LOWER K-3 PACKER @ 11350' RKB. SET 17' PATCH ASSEMBLY W/STINGER &2 3/8 K3-PACKER, TOP OF PACKER @ 11333' RKB. GOOD DRAW DOWN ON IA. IN PROGRESS. 4/25/18 ESP/ SET 2 3/8" SLIP STOP ON UPPER K-PACKER @ 11333' RKB. MIT IA TO JET 3000 PSI, PASS. OPEN XD SLEEVE @ 11315' RKB. SET 1.875 X-LOCK& PUMP 2" RC JET PUMP (SN: CP-1160 7B RATIO), PUMPED DOWN IA CONFIRMING GOOD COMMUNICATION. JOB COMPLETE. 1 •ral Well Work Request Form ,• o Well: 2L-321 Date of Request: 3/19/2018 Request SPOC: CPF2 PE David/Stephanie x7519,pgr 252 ° Well Type: Producer Req.Written by: Steve Drake,263-4062 Job Scope: Tubing/Casing Patch Shut-In Reason Code: 270 Tubing/Casing/Packer Leaks Well Shut in Date(if SI): 11/5/2017 Prioritization Category: Opportunity/Rate Adding Budget Category: Kuparuk Base Expense Network: 10401291 Job/SAP Comment: Well Work is not justified via increased production El Preventive Maintenance Program Request -urrefit Vveli Data Current Oil Rate(BOPD) 0 Post-Job Oil Rate(BOPD) 180 Risked NOB(BOPD) Enter Rates Last SBHP 2516 psi Last Tag 12,022'md H2S(PPM): 30 ppm on 12/6/16 SBHP Date 6/19/2017 Tag Date 6/19/2017 Any Fluid Restriction on Well? No SBHP Datum(TVD/SS?) 5500 TVD Max Inclin. 70° Max Dogleg 7°/100'and Min. I.D(at/above work) 1.875" Max Incl. Depth 6,344'md Max Dogleg Depth 1,754'md Well Work Justification & Objectives(and date required if appropriate): 2L-321 is a single bore procducer that was drilled and completed in December of 1998. The well began experiencing problems in 2006 and was worked over in 2008. Most recently,while troubleshooting jet pump problems a leak was located at a depth of 11,340',below the sliding sleeve. This procedure will outline the steps to set a patch using Baker K-series packers as well as resetting a jet pump over the slideing sleeve. The patch will ensure that all power fluid exits the IA into the tubing through the sleeve. Risk/Job Concerns: Min ID of a Halliburton SSD-XD sliding sleeve of 1.875" @ 11315' RKB RELAY-Pull plug with gaugues/Set patch 1. MIRU Relay and associated support equipment. 2. RIH with 2" RS and pull prong on CA plug @ 1,384' RKB. 3. RIH with 2"RS and pull plug body with gauges. Pulling of plug body should be sufficient drift for patch run. 4. RIH with slip stop and set top at 11,351' RKB. 5. RIH with 2 3/8"K-series packer(1.812"running OD)and set on slip stop at 11,351' RKB. This should place mid element at 11,350'RKB. (Maintain surface pressure on tbg while pooh to aviod swabbing K packer up hole) 6. RIH with modified k-series test tool and set in top of k-series packer. CMIT TxIA to 3000 psi. (Maintain surface pressure on tbg while pooh to aviod swabbing K packer up hole) 7. RIH with stinger/15'spacer pipe/upper k-series packer assembly and stab into top of lower packer at 11349' RKB. This should put the top k- series packer at approximately 11,332' RKB.(Maintain surface pressure on tbg while pooh to aviod swabbing K packer up hole) 8. RIH with 1.5"test tool and set in top of k-series packer. CMIT TxjA to 3000 psi.(Maintain surface pressure on tbg while pooh to aviod swabbing K packer up hole) 9. RIH with upper slip stop and set on top of k-series packer at RKB. RELAY-Set jetpump 10. sliding sleeve(shifts down to open)@ 11,31, . 11. Set 7B jet pump across open sliding sleeve at 11,316' RKB with 1.875"x-lock. 12. RDMO 13. Turn well over to OPS to BOL per standard surface powered jet pump procedure. 2L-321 Patch 03-14-18 SGD.xlsm Printed 4/30/2018 1p, KUP PROD 2L-321 Conoco dlipS9410\ Well Attributes Max Angle&MD TD a \ Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Alaska,Inc, !" 501032028600 TARN PARTICIPATING AREA PROD 70.21 6,344.88 12,403.0 ,:mo'''""!ps r . Comment H2S(ppm) Date Annotation End Date KB-Grd(tt) Rig Release Date +... SSSV:NONE 30 12/6/2016 Last WO: 11/21/2008 37.50 1/12/1999 2L-321.4/26/2018 9:19:43 AM Last Tag il Vertical schematic(actual) Annotation Depth(ftKB) End Date Last Mod By Last Tag:RKB 12,022.0 6/19/2017 pproven HANGER;25.0 1111( Last Rev Reason 11 L�l- Annotation End Date Last Mod By j it Rev Reason:Pulled plug&gauges,set TBG patch,set jet pump. 4/25/2018 fergusp 0, ut � Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)... Wt/Len(L..Grade Top Thread Ni le CONDUCTOR 16 15.062 30.0 108.0 108.0 62.58 H-40 WELDED ` I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread •� , SURFACE 7 5/8 6.875 28.5 3,302.1 2,287.4 29.70 L-80 BTC-MOD "'Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 51/2 4.950 27.0 12,379.6 5,877.8 15.50 L-80 LTC-MOD 5.5"x3.5"@ 11454' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len 8...Grade Top Thread PRODUCTION SCAB 4 1/2 3.958 25.0 11,440.7 5,351.5 11.60 T-95 HYD 513 LINER Liner Details Nominal ID .A.A./CONDUCTOR;30.0108.0 _ Top(ftKB) Top(TVD)(ftKB) Top Incl TI Item Des Com (in) 11,395.5 5,325.5 55.46 XO-Reducing 41/2"ST-L Boxx 31/2 IBT Pin XO 3.500 11,396.4 5,326.0 55.44 SBR Baker 40-26 2.688"Seal Bore 31/2"IBT pin x31/2" 2.680 IBT-Mod box 11,418.5 5,338.7 54.93 LOCATOR LOCATOR SUB 2.980 11,421.3 5,340.3 54.88 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY 2.980 Tubing Strings Tubing Description String Ma...ID(in) Top MKS) Set Depth(ft..f Set Depth(TVD)(...Wt(Ib/rt) Grade Top Connection TUBING WO 2 3/8 1.960 25.0 11,386.0 5,320.2 4.60 L-80 IBT SURFACE;28.5-3,302.0-+ Completion Details Top(ND) Top Incl Nominal Top(ftKB) (ftKB) (°) Item Des Corn ID(in) 25.0 25.0 0.08 HANGER FMC TC-1A-EMS TUBING HANGER 1.990 1 I 11,315.8 5,281.4 57.30 SLEEVE-C HES SSD-XD SLIDING SLEEVE(CLOSED 10/12/17) 1.875 *+ 11,365.1 5,308.4 56.16 LOCATOR LOCATOR w/2'SPACE OUT 2.680 Pump;11,315.0 7, 'lul 11,367.9 5,310.0 56.10 PACKER BAKER D PRODUCTION PACKER w/GBH-22 BONDED SEAL 2.680 SLEEVE-C;11,315.7 a ASSEMBLY 11,370.4 5,311.4 56.04 SBE SEAL BORE EXTENSTION 23-26 2.680 11,383.7 5,318.9 55.73 NIPPLE CAMCO D PROFILE NIPPLE w/1.812"PROFILE 1.812 11,385.3 5,319.8 55.69 VVLEG WLEG GUIDE w/2 3/8"BOX 1.970 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Patch;11.3330 Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 11,315.0 5,281.0 57.32 Pump 2"Jet Pump(7B)on 1.875"X lock.(47"GAL) 4/25/2018 0.000 11,333.0 5,290.7 56.90 Patch 2 3/8"slip stop,2 3/8"K-3 packer,15'spacer pipe,2 3/8" 4/24/2018 0.620 K-3 packer,2 3/8"slip stop.(Slip stops have 1.375" extemal F/N,K-3 packers have 1.375"G F/N) LOCATOR;11,365.1 Perforations&Slots PACKER;11,367.8 ShotDens Top(TVD) Btm(TVD) (shots/ft SBE;11,3704 Top(ftKB) Btm(ftKB) (RKB) (ftKB) Zone Date ) Type Com 11,680.0 11,720.0 5,489.3 5,511.9 S-5,2L-321 1/26/1999 6.0 IPERF 2.5"HC Big hole chrgs,60 deg ph Notes:General&Safety End Date Annotation NIPPLE;11,383.7 5/23/2007 NOTE: 5 1/2"PRODUCTION CASING LEAKS TO FORMATION @ 7694'TO 8411'RKB WLEG;11,385.3 12/6/2008 NOTE:View Schematic w/Alaska Schemalic9.0 • • PRODUCTION SCAB LINER; 11 25,011,440.7 IPERF;11,680.0-11,720.0 PRODUCTION 5.5"x3.5.6_ 11454';27.012,379.6 gac(' 2.4 2. • • z_ 3g WELL LOG ,I. TRANSMITTAL DATA LOGGED PROACTIVE DIAC{NOSTIC SERVICES, INC. /741201% seNDEp Prf .._ To: AOGCC JAN 1 2 2018 Makana Bender 333 West 7th Avenue Suite 100 AOGCC Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MU) 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: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907)245-8952 SCANOEU 1) LeakPointTM Survey 07-Dec-17 2L-321 Color Log/CD 50-103-20286-00 2) Signed : � Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)2454951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplatehles\Templates\Distribution\TraasmittalSheetKonocoPhil lips_Traasmit.docx C5' • a `A N 4 �!j IXJ O v� N (/' ( r- % u� (11 d row v U ^ W L _ V r a) W kLl p U 060 Y 41H CV N FL Y: O c in CLO • H >4 QiO . Oto 0 a u 0 > E y O o c W _oO O c ro Q2t 0 (0 C -a > 0 m ° J w `° o N E _E J Q +., +, In +� Vl Q N' 00w ) N d v, L 0 0 coo N.f! 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CA T O M co Of 0 O) T 0A T aJ O N N N O N N N N N N N caj °1 O O O r O O O O O O O 0 O O O O O O O O O O OM am 0a U) U) U) U) in U) U) N N U) U) Q U +,+ en 1-C. Z rn E a) > J �• W Y O _IY CL. C MI F- Q 110 J r J h a' U) T f0 cu C 7 CL Z 01 Of N N �' T U) W C U) 4, (n OJ +..� CO fYl r r r M r r r r r y F— m a '� 1"- c U r 2 J 7 -i 4 N 4 LL E ro Z ar ao Q O r W N W r r r r VI I/1 Y 'L r-1 U—I c ^ r C C fl) in 0 CA a Q SI I- a a Q • • Kat ZL_.-3 z Regg, James B (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Friday, August 11, 2017 4:00 PM (7 ( Z To: Bixby, Brian D (DOA) , d (7 Cc: Regg, James B (DOA) Subject: 170701 KRU 2L-Pad Deficiency Report Attachments: 2L AOGCC Deficiency Report - Completed File - 08-11-2017.pdf Brian, Please see the completed deficiency report for 2L. The paperwork, photo and lab reports have all been combined into a single file for simplicity. If you prefer separate files or need anything additional from us please let me know. Cheers, Matt Matthew Raiche/Darrell Humphrey Production Engineering Specialist ConocoPhillips Alaska Ph:907.659.7535 Pg:924 Mail: NSK 69g t f i g -'�;I Original Message From: NSK Prod Engr Specialist Sent: Sunday,July 02, 2017 9:22 AM To: Bixby, Brian D (DOA) <brian.bixby@alaska.gov> Subject: RE: [EXTERNAL] Emailing: 170701 KRU 2L-Pad Deficiency Report.pdf Brian-enclosed is a signed copy of the AOGCC Deficiency Report for your records. We will follow up on this and send you documentation of the corrective actions taken when completed. Thanks, Darrell Humphrey 907-659-7535 Original Message From: Bixby, Brian D (DOA) [mailto:brian.bixby@alaska.gov] Sent: Sunday,July 02, 2017 7:20 AM To: NSK Prod Engr Specialist<n1139@conocophillips.com> Subject: [EXTERNAL] Emailing: 170701 KRU 2L-Pad Deficiency Report.pdf Darrell, Please print this, sign it and send it back to me. Thanks, • • • Brian Brian Bixby Petroleum Inspector Cell 509-998-3683 brian.bixby@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Brian Bixby at(907) 279-1433 or brian.bixby@alaska.gov. 2 • • -36g._ 012117 State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: KgU ZL 14 Date: uty t''zoi PTD: 2,141 "67.3 Operator: ecDoNtocc)(?0.4 Lt. }s �LACSZType Inspection:SVS s,- (•.1 Operator Rept—pAyAeLL /IV+N IREy InspectorZgJixg/ Position: 0 . C u,..i 2 t -►sr Op.Phone: q 03.. G59 IG3�,'` Correct by(date): Sert p Z017. Op.Email: n 1 ince. xwiaCe Nit.Lt . Follow Up Req'd: Detailed Description of Deficiencies Date Corrected V1u ZL -3) /ha, 4 , ELL'k i AU6t $ /// // � <gu23Z% , 3i6, 3zve ..r1Eeve-. AL," voEc.>LS . -1146z6 is s ul uiarn up pu + “,ae. 4W> ---qtrfi So .77.4 Rt.; THE Ft_uz-+Es 0,1 I JCu. , 1111/651164T6 �"0 r,,l/a Ocrlr 77/6 g AS PoSeTf.t.1 Attachments: flora de In*al.tea. ''1 Sr9n[2L-31+1); Lms repor+5 -945 t nti1y-SIS Operator Rep 7, 2.17 Signatures: Rl fay/ AOGCC Inspector *After signing,a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up • inspectionwasperformed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 q ck -2L_ -3 z |�� 2��D '�' ` '� ConocoPhillips Alaska AOGCC EXCEPTION REPORT Location: 2L Date: 07K01d7 AOGCC Inspector: Brian Bixby Correct by: September 1st 2017 Instructions: All exceptions listed ba|om,must be corrected by date noted on the AOGCC Deficiency Report. Documentation of the work performed is to be entered into the'Action Taken'section below. Note - Failure to comply with these instructions may constitute a violation of SOA regulations and may be subject to enforcement action under 20 AAC 25.535 EXCEPTIONS NOTED: 2L-314 a well sign needs to be installed -Confirm sign is in place with a photo. 2LWells-All wells need to he inspected for gas bubbling up through the cellars and Flutes. A gas sample is requested to determine the source. See AOGCC deficiency report. Action Taken to Correct Problem: Gas samples from the bubbling conductors/cellars as well as the IA's were taken from wells 2L-327 and 2L-326 on 7/6/17 (the OA FL's for both wells were at surface; therefore no OA gas sample could be obtained). Lab analysis of the composition of the gas samples from conductor/cellars showed they were methane and N2 primarily(as would be expected from natural ground sources with Date: 07/17/17 Initials: KAL air contamination). They did not match the annulus gases which contain significant quantities of ethane/propane/butane/pentane. On 2 separate occasions we attempted to obtain cellar/conductor samples from 2L-321 (bubbling had been observed from that well on the day of the inspector visit). However no bubbling was present on either day, which supports our understanding that the natural ground source gas liberation tends to be intermittent. A new sign with pertinent well information was installed on the Date: 08/11/17 Initials: MCR outside of the well house. Please see attached photo. Date: Initials: Date: Initials: Date: Initials: Date: Initials: Return completed form to Prod. Engr. Specialist: • n11 39conocophillips.com • • Distribution: CPF DSLT CPF OPS Supv Prod. Engr. Specialist C.C. CPF1&2 Ops Supt CPF3 Ops & DOT Pipelines Supt NSK Fieldwide Operations Supt • • KUPARUK LAB ANALYTICAL REPORT +tn011ll1 ps 907-659-7214 n1020@cop.com Sample Number:S-170713-00227 Sample Name:OA Casing Valve Location: Area:KUPARUK Unit:DS2L Sample Point:2L-321 ✓ (f7.j1 I ge9Z6 ) Sampled Date: 7/6/2017 9:20:00AM Matrix Id: GAS-MISC Reviewed By: Carville, Daniele Date:07/16/2017 Analysis Results: Parameter Result UO'4 D-1945*N2(NITROGEN) N2(NITROGEN) 1.687 Mole% D-1945*CARBON DIOXIDE CARBON DIOXIDE 0.004 Mole% 0-1945*METHANE METHANE 96.048 Mole% D-1945*ETHANE ETHANE 1.717 Mole% 0-1945*PROPANE PROPANE 0.324 Mole% 0-1945*I-BUTANE I-BUTANE 0.054 Mole% D-1945*N-BUTANE N-BUTANE 0.095 Mole% D-1945*I-PENTANE I-PENTANE 0.011 Mole% D-1945*6I-PENTANE N-PENTANE 0.011 Mole% D-1945*TOTAL C65 TOTAL C6S 0.003 Mole% 0-1945*TOTAL C7S TOTAL C75 0.004 Mole% D-1945*C6 HEAVIER C6 HEAVIER 0.049 Mole 9 D-1945*C8 HEAVIER C8 HEAVIER 0.042 Mole% D-1945*NET HEAT OF COMBUSTION NET HEAT OF COMB 914.2 Btu/SCF D-1945*AVERAGE MOL WT AVERAGE MOLECULAR WT 16.70 g/mol D-1945*SP GRAV IDEAL SPECIFIC GRAN IDEAL 0.5766 D-1945*SP GRAV REAL SPECIFIC GRAV REAL 0.5775 D-1945*COMP FACTOR COMPRESSIBILITY 0.9980 D-1945*BTU/IDEAL CF(DRY) BTU/IDEAL CF(DRY) 1017.3 Btu/SCF D-1945*BTU/REALCF(DRY) BTU/REALCF(DRY) 1016.2 Btu/SCF D-1945*BTU/REALCF(SAT) • • KUPARUK LAB ANALYTICAL REPORT >+1C1C�1�hINNI 907-659-7214 n1020@cop.com Sample Number:S-1.70713-00227 Sample Name:OA Casing Valve Location: Area:KUPARUK Unit:DS2L Sample Point:2L-321 Sampled Date: 7/6/2017 9:20:00AM Matrix Id: GAS-MISC Reviewed By: CarviIle,Daniele Date:07/16/2017 Analysis Results: Test parameter Result UOM BTU/REAL CF(SAT) 998.4 Btu/SCF D-1945*BTU/IDEAL CF(SAT) BTU/IDEAL CF(SAT) 1001.9 Btu/SCF Sample Notes/Comments • • KUPARUK LAB ANALYTICAL REPORT I14CoPfliCll ps 907-659-7214 n1020@cop.com Sample Number:S-170713-00226 Sample Name:OOA Casing Valve Location: Area: KUPARUK Unit:DS2L Sample Point:2L-321 Sampled Date: 7/6/2017 9:30:00AM Matrix Id: GAS-MISC Reviewed By: Carville,Daniele Date:07/16/2017 Analysis Results: Test Parameter Re UOM, • D-1945*N2(NITROGEN) N2(NITROGEN) 0.855 Mole% D-1945*CARBON DIOXIDE CARBON DIOXIDE 0.002 Mole% D-1945*METHANE METHANE 98.851 Mole% D-1945*ETHANE ETHANE 0.233 Mole% D-1945*PROPANE PROPANE 0.013 Mole% D-1945*I-BUTANE I-BUTANE 0.003 Mole% D-1945*N-BUTANE N-BUTANE 0.001 Mole% D-1945*I-PENTANE I-PENTANE 0.001 Mole% 0-1945*N-PENTANE N-PENTANE 0.000 Mole% D-1945*TOTAL C6S TOTAL C6S 0.000 Mole% D-1945*TOTAL C7S TOTAL C7S 0.006 Mole% D-1945*C6 HEAVIER C6 HEAVIER 0.041 Mole% 0-1945*C8 HEAVIER CS HEAVIER 0.035 Mole% D-1945*NET HEAT OF COMBUSTION NET HEAT OF COMB 903.2 Btu/SCF 0-1945*AVERAGE MOL WT AVERAGE MOLECULAR WT 16.22 g/mol D-1945*SP GRAV IDEAL SPECIFIC GRAV IDEAL .- 0.5602 D-1945*SP GRAV REAL SPECIFIC GRAV REAL 0.5610 D-1945*COMP FACTOR COMPRESSIBILITY 0.9980 D-1945*BTU/IDEAL CF(DRY) BTU/IDEAL CF(DRY) 1005.5 Btu/SCF D-1945*BTU/REALCF(DRY) BTU/REAL CF(DRY) 1004.3 Btu/SCF D-1945*BTU/REAL CF(SAT) • • KUPARUK LAB ANALYTICAL REPORT G1C1oCQNull1 907-659-7214 n1020@cop.com Sample Number:S-170713-00226 Sample Name:OOA Casing Valve Location: Area:KUPARUK Unit:DS2L Sample Point 2L-321 Sampled Date: 7/6/2017 9:30:00AM Matrix Id: GAS-M1SC Reviewed By: Carville,Daniele Date:07/16/2017 Analysis Results: Iss� Parameter Result UOM BTU/REAL CF(SAT) 986.7 Btu/SCF D-1945'BTU/IDEAL CF(SAT) BTU/IDEAL CF(SAT) 990.3 Btu/SCF Sample Notes/Comments ‘c1.*4.2 z h .ECEW ED 2514\ 2— WELL 4\ 2WELL LOG TRANSMITTAL FEB 13 2015 DATA LOGGED C1/201AOGCC M K.BENDER To: Alaska Oil and Gas Conservation Comm. February 11, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper(MFC) : 2L-321 Run Date: 2/8/2015 The technical data listed below is being submitted herewith. P leas_a address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2L-321 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20286-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com 1) ,/aizadeek.4) 6..e4teeve Date: Signed: XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~' -~.~~ ,':ile Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Mildred Daretha N~ Lowell Date: c~/(~ /si ~ [] TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: ~si ~ ~ ... Conoco~~ll~ps February 2, 2010 ~„~t FEa ~" ~~~`` Dan Seamount AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7~' Ave. Ste. 100 Anchorage, AK 99501 L J Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907)659-7535 Fax: 659-7314 FED U 4 201Q ~~ko Dil ~ Gu Conn. Corrntission ~nwshar~do Dear Mr. Seamount, ConocoPhillips Alaska, Inc. has changed the production method for 2L-321 a Tarn production well. Enclosed you will find 10-404 Report of Sundry Well Operation for ConocoPhillips Alaska, Inc. for Tarn we112L-321 (PTD 198-262). This report records the removal of the surface powered jet pump. If you have any questions regarding this matter, please contact myself or Robert D. Christensen at 659-7535. Sincerely, Darrell R. Humphrey Attachments • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED FEB 0 4 2010 REPORT OF SUNDRY WELL OPERATIONSAIaskaOil~t6asCons.Commissiol~ ~. operations Performed: Abandon (-' Repair well ~ Plug Pbrforations ~ Stimulate ~ Othe ~ fIdQ9 Alter Casing ~ FUII Tubing ~'; Pbrforate New Pool r; Waiver r Time 6ctension Pull SPJP Change Approved Frogram ~ Operat. Shutdow n r Perforate r Re-enter Suspended Well 2.Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhilli s Alaska, Inc. p Develo ment Ex lorato p Ivy p rY r 198-262 3. Address: Stratigraphic [" Service r .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20286-00 7 Property Designation: 8. Well Name and tuber: ADL 380053, ALK 4601 2L-321 9. Field/Pool(s): \ Kuparuk River Field / Tarn Oil Pool 10. Present Well Condition Summary: Total Depth measured ~ 12403 feet Plugs (measured) None true vertical ~ 5890 feet Junk (measured) None Effective Depth measured 5512 feet Packer (measured) 11368 true vertical 11716 feet (true vertucal) 5310 Casing Length Size MD TVD Burst Collapse CONDUCTOR 108 16" 108 108 0 0 SURFACE 3302 7-5/8" 3302 2288 0 0 PRODUCTION 11439 4-1/2" 11439 5350 0 0 PRODUCTION 12380 5-1/2" 12380 5878 0 0 Perforation depth: Measured depth: 11680 - 11720' True Vertical Depth: 5489 - 5512' Tubing (size, grade, MD, and TVD) 3.5, L-80, 11386 MD, 5359.1 TVD Packers &SSSV (type, MD, and TVD) BAKER MODEL' D' PACKER @ 11367.85 MD and 5309.96 TVD SSSV =None 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 120 20 187 1463 226 Subsequent to operation 423 351 11 2452 223 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development ~ Service r 5. Well Status after work: Oil ~ Gas r WDSPL [- Daily Report of Well Operations X GSTOR [' WAG r GASINJ r WINJ r SPLUG 16. 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: N/A Contact Bob Christensen/Darrell Hump hrey Printed Name Darrell R. Humphrey Title Production Engineering Specialist Signature Phone: 659-7535 Date 1 __ _ ,,~ ;L -~, .. Form 10-404 Revised 7/2009 ~BDMS FEO 0 5 20~ ~~ 2`'~ z y io ~8~ Submit Original Only • 2L-321 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/14/10 01/15/10 PULLED 1.875" JET PUMP (SN# CP-1150 w/ 7-B RATIO, #7 NOZZLE & #8 THROAT) 11316' RKB. SET 1.812" CA-2 PLUG @ 11383' RKB. DISPLACED TBG/ IA WITH 190 BBLS DIESEL. CLOSED SSD @ 11316' RKB. IN PROGRESS. MITIA TO 2500#. *'"'PASS'`*'`. PULLED 1.81" CA-2 PLUG @ 11383' RKB. JOB COMPLETE. ~,, ConocoPhillips ALTSka,hr.: HANGER, 25 CONDUCTOR, D-108 SURFACE, 03.302 SEAL ASSY, 11,368 38E, 11 370 TIPPLE, 11,33/ WLED, 11,335 PRODUCTION 0 5", 25-11 491 CSR, 11,433 11,680-11,72[1--- PRODUCTION 5 5'x3 5', 0-1 z33D ~~ TD, 12,003 SLM KUP 30 1/13Y2009 Last WO: i(BI Entl Data Annotation 6.0 1Y2/2009 Rev Reason: Pull Pump, Close Ing 0... String ID .. . Top (NNB/ Set Depth (f... Set [ 16 15.062 0.0 108.0 Ing 0... String ID .. . Top (/tlt8( Set Depth (f... Sat [ 7 SIS 6.750 0.0 3,302.0 Ing 0... String ID ... Top (fB(B) Set Depth (f... Set f 51/2 4.950 0.0 12,380.0 Top Incl 1° Data 2L-321 11/21/2008 37.50 1/12/1999 Sleeve Laat Mod ... Imosbor Entl Dale 1/29/2010 epth (TV01 ... 108.0 String Wt... S 62.58 tring... H-00 String TOp Thrtl WELDED apm (rvDt ... 2,287.2 snmg we... s 45.50 tring ... L-80 string rap rnrd BTC-MOD apth (TVD( ... 5,878.0 String Wt... S 15.50 tring ... L-80 String Top Thrtl LTC-MOD apN (rvD( ... 5,351.5 String Wt_. 11.60 Siring ... T-95 String Top ThM HYD 513 epth (TVO) ... 5320.1 Siring Wt... 4.60 String ... L-80 String Top Thrd IBT Comment Nomi. ID (in STATE OF ALASKA ALASKA LAND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS ~~ E ~ ~ r ^~, i; ~. operations Pertormed: Abandon [ Repair w eu [ Plug Ft'rforations ^ Stimulate [~ e i ,I ~~5 ( ~ ~~~~~~ g ~ g Alter Casin Pull Tubin ~ Fbrforate New Fbol ^ Waiver ime tensbn [I Change Approved Program C Operat. Shutdown ^ Perforate ^ e ~ Re-enter Suspended We~f'~°"?° 2.Operator Name: 4. Current Well Status: Permit to Drill Number: Inc. ConocoPhillips Alaska Development ~y Exploratory [ 198-262 - , 3. Address: Stratigraphic Ci Serve ~ API Number. 50-103-20286-00 P. O. Box 100360, Anchorage, Alaska 99510 Property Designation: .Well Name and Number: ADL 380053, ALK 4601 2L-321 9. Field/Pool(s): Kuparuk River Field / Tarn Oil Pool 10. Present Well Condition Summary: Total Depth measured ~ 12403 feet Plugs (measured) None true vertical ~ 5890 feet Junk (measured) None Effective Depth measured 5512 feet Packer (measured) 11368 true vertical 11716 feet (true verucal) 5310 Casing Length Size MD TVD Burst Collapse CONDUCTOR 108 16" 108 108 0 0 SURFACE 3302 7-5/8" 3302 2288 0 0 PRODUCTION 11439 4-1/2" 11439 5350 0 0 PRODUCTION 12380 5-1/2" 12380 5878 0 0 Perforation depth: Measured depth: 11680 - 11720' th 5512' V rti l D 5489 .~ ~. _~ 21-, ~ ~ ~ `~~ ~ ~ ~ ~~~ '~ `~ ~ : e ca ep - True ; ~ Tubing (size, grade, MD, and TVD) 3.5, L-80, 11386 MD, 5359.1 TVD Packers &SSSV (type, MD, and TVD) BAKER MODEL'D' PACKER @ 11367.85 MD and 5309.96 TVD SSSV =None 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12, Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 526 558 18 1128 217 Subsequent to operation 120 20 187 1463 226 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory C Development ~ Service r . Well Status after work: Oil ~ Gas Q WDSPL Daily Report of Well Operations X GSTOR ~ WAG ^ GASINJ ^ WINJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.6cempt: NIA contact Bob Christensen/Darrell Humphrey Chris nsen Printed Name Ro rt D Title Production Engineering Specialist . Signature -- Phone: 659-7535 ~~~ Date ~ ~ ~ ~/! RBDMS faw -s ~ ~ Form 10-404 Revised 7/2009 ~ ~' ~' ~~ Submit Original Only ~~7~0 • • 2L-321 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/07/09 12/08/09 12/10/09 CUT HEAVY PARAFFIN FROM 0' TO 3600'. GAUGED TBG TO 1.88" TO SSD @ 11316' RKB. MIT IA 2500 PSI: PASS. OPENED SSD @ 11316' RKB. PUMPED 5 BBL DSL DOWN IA, CONFIRMED SSD OPEN. IN PROGRESS. SET 7B RATIO JET PUMP ON 1.875" X-LOCK @ 11316' RKB. PUMP 5 BBL POWER FLUID TO CONFIRM IA OPEN. COMPLETE. PULLED JET PUMP @ 13316' RKB: NO PROBLEMS OBSERVED WITH PUMP. HOT FLUSHED TBG. SET NEW 76 RATIO JET PUMP ON 1.875" X-LOCK @ 13316' RKB. COMPLETE. ~,, KUP 2L-321 COf1000Pfl1~~IP5 ell Attributes Max An le & MD TD Alds}t r Wellbore APINWI 501032028600 Fieltl Name Well StaNs Incl (°) MD (ftKB) TARN PARTICIPATING AREA PROD 7021 6,344.88 Act Btm ((tN0) 12,403.0 "' ll C 2L321 1n 201070 49 15 AM W ti Comment H2S (ppm) SSSV: NONE 30 Dale Annotation End Data 1/13/2009 Last WO: 11/21/2008 KB13rd (R) 37.50 Rlg Raleasa Dab 1/12/1999 on : e - : Schematk-ACtusl Annotation Depth (ftKB) End Date Annotation Lasl Mo d ... End Data Last Tag: SLM 12,066.0 1/2/2009 Rev Reason: OPEN SLEEVE, SET JET PUMP Imosbor 1!1/2010 Casin Strin s Casing Deacrlpdon CONDUCTOR String 0... 16 String ID ... 15.062 Top (ftKB) 0.0 Set Depth (f... 108.0 Set Depth (TVD) ... 108.0 String Wb,. 62.58 String ... H-40 String Top Thrd WELDED ~ ~ Casing Description SURFACE Siring 0... 75/8 String ID ... 6.750 Top (fIK B) 0.0 Sat Depth (f... 3,302.0 Set Depth (TVD) ... 2,287.2 String Wt... 45.50 String ... L-80 String Top Thrd BTC-MOD HANGER, 25 ` Casing Oascrlpdon PRODUCTION String 0... 51/2 StrlnB ID ... 4.950 Top (f1KB) 0.0 Set Depth (f... 12 380.0 Set Depth (TVD) ... 5 878.0 String Wt... 15.50 Siring ... L-80 String Top Thrtl LTC-MOD 5 5" 3 5" , , . x . Casing Description PRODUCTION 4.5" String 0... 4 1/2 String ID ... 3.958 Top (ftKB) 0.0 3el Depth (f... 11,438.7 Sat Depth (TVD) ... 5,350.3 String Wt... 11.60 String ... T-95 String Top ThrO HYD 513 Tubin Strln s 1 ~, Tubing Description String 0... S[ring ID ... Top ((tKB) Sat Depth (f... Sat Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 2 3l8 1.960 25.0 11,386.0 5,320.1 4.60 L-80 IBT Com letion Details coNDUCroR, 0.1 Too IftKB) Top Depth (TVD) lRKB) Top Incl 1°) Item Description Comment Nomi ID (Ir Top Incl Btm PACKER, 11,369 SBE, 11,370 iPPLE, 11 WLEG, 17 PRODUCTION 4.5", 011,439 CSR, 11 433 Comment Run Oate IPERF, 11,680.11,720 -~ PRODUCTION 5 5'x3 5', 0-12,380 TD, 12,403 STATE OF ALASKA ~ ~~~~~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 2 3 2t~08 REPORT OF SUNDRY WELL OPERATIOI<1~~ ~ „__ „_~,~;~M,,., 1. Operations Pertormed: Abandon ^ Repair Well ^~ Plug Pertorations ^ Stimulate ~Onh@rOrag~ ^ I ~ GC Alter Casing ^~ Pull Tubing Q Pertorate New Pool ^ Waiver ^ Time E nsion ^ xt e Change Approved Program ~ Operat. Shutdown^ Perforate ^ Re-enter Suspended Weil Q . 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ^' Exploratory ^ 198-262 / ` 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20286-00' 7. KB Elevation (ft): 9. Well Name and Number: RKB 28', Pad 115' ° 2L-321 ° 8. Property Designation: 10. Field/Pool(s): ADL 380053. Kuparuk River Field / Tarn Oil Pool 11. Present Well Condition Summary: Total Depth measured 12403' feet true vertical 5890' feet Plugs (measured) Effective Depth measured 12140' feet Junk (measured) true vertical 5747' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 108' 108' SURFACE 3274' 7-5/8" 3302' 2288' PRODUCTION 11426' 5-1/2" 11454' 5359' PRODUCTION 11411' 4-1/2" 11439' 5350' LINER 926' 3-1/2" 12380' 5878' Perforation depth: Measured depth: 11680'-11720' true vertical depth: 5489'-5512' '~D'~~.j ~~~ ~ r ~~U~ ~~+1:. ~ D'q ~~ ck U Tubing (size, grade, and measured depth) 2-3/8", L-80, 11386' MD. Packers &SSSV (type & measured depth) Baker'D' pkr @ 11368' no SSSV 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 SI -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-390 / ~ ~ Contact Howard Gober @ 263-4220 Printed Name Howard Gober Title Ph 263 220 Wells Group Engineer D ~ ~ / Signature -4 one: ate Z3 / P red b Sharon Allsu rak 263-4612 Form 10-404 Revised 04/2006 ~~~ 3~,~,!~ti ~~_ ~)~'~ ~ ~~Q~ Submit Original Only 2L-321 Pre and Post Rig Summary DATE SUMMARY 8/16/08 T - POT- PASSED; T - PPPO~ASSED; IC -POT -PASSED; IC - PPPO~AILED; LDS - FUNCTIONAL (PRE- RWO) 11/22/08 ATTEMPT TO DRIFT TBG W/ 1.805", ABORT RUN FOR TODAY PER CO REP. 11/23/08 TAGGED CA-2 PLUG @ 11384', OPENED SSD-XD @ 11316' RKB, CIRC'D OUT 9.3 BRINE FROM TBG & IA W/ 175.0 BBLS DIESEL. CLOSED SSD-XD, ATTEMPTED MIT-T. IN PROGRESS. 11/24/08 MIT TBG TO 2500 PSI=PASS. MIT IA TO 3500 PSI=PASS, JOB COMPLETE. 12/8/08 PULLED PRONG AND 1.81" CA2 BLANKING PLUG @ 11383' RKB. TAGGED @ 12073' RKB. COMPLETE. ConocoPhiilips ... 1u,., ,. trx'. HANGER. 25 CONDUCTOR, 0-108 SURFACE. 0-3,302 SLEEVE-C, 11,316 KUP , ~ 2L-321 Wep Attributes Max Mgle & MD Wellbore APUUWI ~. Field Name ,Well Stat Pod/Inj Type Inc! (°) MD (kKBj j TD 'Act Bbn (kKB) 70.21 I 6,34988 501032028600 ~_TARN PARTICIPATING AREA.PROD 72,402.0 Comment - ~H25 (ppm) 'Date An tat on IEnd Date KB-Grtl (kj 'Rig Release Da' SSSV~ NONE 7/1!2008 (Last WO: '. 1 112 1 2008 ~ 3J.50 i 60 1/12/1999 A I Annotation Depth (kKB) End Date Annotation End Date Last Tag: SLM 12,076.0 '~ 12/8/2008 IRev Reason: PULL PLUG, TAG ~ 12/9/2008 Casing Strings Casing Description _ String O.. String ID ... Top (kKB) Set Depth (i... Set Depth (ND) ... String WI... String ... String Top Thrtl 'CONDUCTOR j 16 15.062 0.0 108.0 108.0 62.58 H-00 WELDED Casing Description String 0... String ID ._ Top (kKB) Sat Depth (i... Set Depth (ND) ... String WI... String ... Sirilg Top Thrtl SURFACE 75/8 6.750 0.0 3,302.0 2,287.2 45.50 L-80 BTC-MOD Casing Description String 0... String ID ... Top (kKB) Sat Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrtl '',PRODUCTION 51/2 4.950 0.0 12,380.0 5,878.0 I 15.50 L-80 LTC-MOD 15.5"x3.5" ' I 'Casio Descri lion 9 P Sfrin 0... Strin ID ... Top (kKB Sat De th i... Set Depth ND ',String VJ1... String ._ 9 9 I P ( ( j ~~~ ~ String Top Thrtl PRODUC TION 4.5" ' 11.60 I T-95 41/2 3.958 0.0 11438.7 5,350.3 HVD 513 .Tubing Strings . Tubing Des ription I,String O... String lD ... Top (kKB) Set Depth (f... Sel Depth(ND).. .String Wt...'Str ng ._ String Top ThM TUBING 23/8 1.960 I 0.0 I 113860 I 5,320.1, 4.60 ~.. L-80- ~ IBT (Completion Det - Top Depth ails. _...._ -_ _. ' (ND) ToP Inc! Top (kKB) (kK6) (°) Item Desaiptbn Comment ID (i ~ 25.0 25.0 0.72 HANGER FMC TC-IA-EMS TUBING HANGER 2.3 11,315.81 5,281 4 57.30 SLEEVE-C HES SSD-XD SLIDING SLEEVE (DOWN TO OPEN) CLOSED 1.8' 1 1 11/232008 I 11,365.11 5,308.2 '', 55.'~' SEAL ASSV BAKER 40-26 SEAL ASSY 2.6 11,367.91 5,309.7 PACKER _ BAKER MODEL'D PACKER 2.6 11,370.41 5,311.2 ~I 55.13 SBE Seal Bore Extension 23-26 - 2.6~ 11,380.2 5,316.81 55.08 X0-Retlucing Bolcom Sub 23-26 2.4 11,383.7 5,318.8 ~ 55 07 NIPPLE Camco "D"Prof le Nipple w/1.812" Profile 1.8 ID Shot Btm (ND) Dens (kKB) Zone Data (sh... PACKER. - _ -- 11,388 SBE. 11,370 NIPPLE, 11,386 --- WLEG. 11,385 - -- IPERF, 11,880-t 1,720 PRODUCTION e_ 5.5'x3.5', 0-12.380 TD, 12.402 NOTE VIEW SCHEMATIC wlAlaska Schematic9-0 ~ono~c~~ilips Time Log & Summary 3YelWiew Web Reporting Report Well Name: 2L-321 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 11/2/2008 2:00:00 PM Rig Release: 11/21/2008 9:00:00 AM Time Logs D to From To Dur S. De tp h E. Depth Phase Code 5ubco~,g T Comment 11 /02/2008 34 hr Summary Move Nordic Rig 3 to 2L-321. MIRU and Pull BPV, Open up well. SITP 0, SICP 0, and SIOAP 150 psi. Install BPV and ND Tree NU BOPE. install test plug and Test BOP 4.5", 3.5" & 2.875 and Choke manifold to 250 / 3,500 psi. Annular 250 / 2,500 psi. 24 hr notice was given to AOGCC @940 hrs on 11-2-08 and Witness of test was waived b Chuck Scheve 945 hrs on 11-2-08. 02:30 05:30 3.00 COMPZ MOVE MOB P Road Nordic Rig 3 from 2A-05 to 2M Pad 05:30 07:00 1.50 COMPZ MOVE WOEO P Stop @ 2M Pad to allow Sim ops HES Slickline and LRS Hot oil unit to pass by for work to be done on 2N Pad. This was the only passable. area before 2L Pad. 07:00 13:00 6.00 COMPZ MOVE MOB P Continue to move rig from 2M Pad to Meltwater bridge and tie on with cats to assist up grade to level road. Then continue on to 2L Pad. 13:00 14:00 1.00 COMPZ MOVE OTHR P Held PJSM and Hang off Replacement tree for 2L-321 in Cellar. 14:00 15:00 1.00 COMPZ MOVE RURD P MIRU on 2L-321 and spot and level rig. Nordic Rig 3 was accepted @ 1400 hrs on 11-2-08 15:00 17:00 2.00 COMPZ WELCTL OWFF P Pull BPV, RU hardline and monitor 0 TBG psi, 0 IA psi & 150 si on the OA. Set BPV. 17:00 18:30 1.50 COMPZ WELCTL NUND P PJSM, ND Tree and send outside cellar to go to Inspection and restock. 18:30 21:30 3.00 COMPZ WELCTL NUND P NU 13 5/8" BOPE and install Riser. 21:30 00:00 2.50 COMPZ WELCTL BOPE P PT BOPE and Choke manifold to 250 low and 3,500 psi. Test Annular to 250 low and 2,500 si. 11 /03/2008 Continue to Test BOP 4.5", 3.5" & 2.875 and Choke manifold to 250 / 3,500 psi. Annular 250 / 2,500 psi. Pull Test plug and BPV. MU LJ and unland hanger. Circ out freeze protect. POOH and lay down 3.5 Kill strin . PU and MU BHA #1 4.75" Bit RIH to 1,470'. 00:00 05:00 5.00 0 0 COMPZ WELCTL BOPE P PT BOPE w/ 4.5, 3.5, & 2.875" and Choke manifold to 250 low and 3,500 psi. Test Annular to 250 low and 2,500 psi. 24 hr notice was given to AOGCC @ 09:40 hrs on 11-2-08 and Witness of test was waived by Chuck Scheve @ 09:45 hrs on 11-2-08. i~~ge 1 ref ~ ~i r Time Logs I Date From To Dur S De th E. Degth Phase Code Subcode T Corliment 05:00 07:30 2.50 0 0 COMPZ RIGMNT SVRG P Clear floor, BD test equipment and store. PJSM. Sli and cut drill line. 07:30 10:30 3.00 0 0 COMPZ RPCOM OTHR P Pull blanking plug, pull BPV. MU landing joint, test hardline to kill tank and blow down. 10:30 12:00 1.50 1,627 1,627 COMPZ RPCOM CIRC P BOLDS. Pull up hanger 4' with 45K#. Circulation around the kill string 2 volumes. Pumped 70 bbl at 4 bpm and 280 psi. Blow down hard line to return tank. 12:00 15:30 3.50 1,627 0 COMPZ RPCOM PULD P PJSM. POOH with 3-1/2" kill string, la in down and i 15:30 20:00 4.50 0 0 COMPZ RPCOM OTHR P Continue to Load and Tally 3 112 PH-6 TBG in i e shed. 20:00 20:30 0.50 0 0 COMPZ RPCOM OTHR P Set wear ring 20:30 22:00 1.50 0 198 COMPZ DRILL PULD P PU DRLG BHA #1 4.75" Bit Assy. RIH to 198'. 22:00 00:00 2.00 198 1,470 COMPZ DRILL TRIP P RIH w/ BHA #1, PU and drifting 3 1/2 PH-6 TBG to 1,470' 50k up wt, 50k do wt. 11 /04/2008 RIH to 7,491' and tagged retainer, circulated out corrosion inhibitor, drilled out retainer and cement to 7,845'. 00:00 08:00 8.00 1,470 7,491 COMPZ DRILL TRIP P Continue to RIH w/ 3.5" PH-6. Ta ed at 7491'. 08:00 09:00 1.00 7,491 7,491 COMPZ DRILL CIRC P K/U. Circulate BU to circ out previously spotted corrsion inhibitor. Pum in 5 b m 2000 si. 09:00 13:00 4.00 7,491 7,492 COMPZ DRILL DRLG P Start drill on cement retainer. ROT @ 40 rpm, 4K WOB, 2 bpm @ 3500 psi, torque 2600 ft#, up wt = 95K, down wt = 63K. Slowed pump rate to 1 bpm @ 70 psi, ROT @ 60 rpm, WOB 5K, torque 2660 ft#. Drilled down to 7492'. U wt = 95K, down wt = 63K. 13:00 14:00 1.00 7,492 7,492 COMPZ RIGMNT SVRG P Service rig. 14:00 15:00 1.00 7,492 7,492 COMPZ RIGMNT RGRP T CO electrical relay on top drive. 15:00 00:00 9.00 7,492 7,845 COMPZ CEMEN" DRLG P Cont drilling cement from 7,492' to 7 845'. 1 bpm at 80 psi, 60 rpm, WOB 5 - 10K, on bottom torque 2,400 - 3,500ft/Ibs, up wt 112K, down wt 55K, rot wt 70K. 11 /05/2008 POOH, added scraper to drilling assembly, RIH with 4 3/4" bit, reverse circulated hole clean to 7,850' and cont drill out cement to 8,256'. 00:00 01:00 1.00 7,845 7,876 COMPZ CEMEN" DRLG P Cont drilling cement from 7,845' to 7,876'. 5 bpm at 2,000 psi, 60 rpm, WOB 5 - 10K, on bottom torque 9,OOOft/Ibs, up wt 108K, down wt 45K, rot wt 70K, top drive stalling out and not makin an hole. ~~rs~ ? of 1fi Time Logs _ _ _ Date From To Dur S De th E._De~th Phase Code Subcode T Comment _ ,__ 01:00 02:00 1.00 7,876 7,876 COMPZ DRILL CIRC P Circ a hi-vis sweep at 5bpm - 2,000 psi with little cuttings or metal returns. 02:00 06:00 4.00 7,876 0 COMPZ DRILL TRIP P POOH to inspect bit and make a lan forward. 06:00 06:30 0.50 0 0 COMPZ DRILL PULD P PU and MU BHA #2 with scra er. 06:30 10:00 3.50 0 7,850 COMPZ DRILL TRIP P RIH w/ 3.5" PH-6. Tagged at 7,879", PU to 7,850'. 10:00 11:00 1.00 7,850 7,850 COMPZ DRILL CIRC P Reverse circulate @ 4 bpm - 1,380 si. 11:00 00:00 13.00 7,850 8,256 COMPZ CEMEN" DRLG P Cont drilling out cement from 7,879' to 8,256', 5bpm @ 1,950 psi, 20 - 40rpm, off bottom torque at 3,600 ft/Ibs with safe tube in seawater, added 1% EP lube and torque dropped to 1,600 ft/Ibs, maintaining 1% EP tube, on bottom torque at 2,800 - 3,300 ft/Ibs, 5K on bit, up wt 105K, down wt 65K, rot wt 70K. 11 /06/2008 Cont drill out cement to 8,500', CBU, RU and tested 5 1/2" csg to 1,000 psi for 30 min. 5 1/2" csg test failed. 200 si bleed off in 10 min. cunt drillin cement to 8,759'. 00:00 13:00 13.00 8,256 8,500 COMPZ CEMEN" DRLG P Cont drillin out cement from 8,256' to 8,500', 5bpm @ 1,950 psi, 20 - 40rpm, maintaining 1% EP tube, on bottom torque at 2,800 - 3,300 ft/Ibs, 5K on bit, up wt 105K, down wt 65K, rot wt 70K. 13:00 14:00 1.00 8,500 8,440 COMPZ DRILL CIRC P Pulled up hole to 8,440' and pumped 25 bbl viscous sweep @ 5bpm, 2,100 si. 14:00 15:00 1.00 8,440 8,440 COMPZ CASING DHEQ P RU and test casin to 1000 psi. Casin losin 200 psi every 10 min. RD test equipment and perform fluid swap with clean seawater. Tom Maunder w/AOGCC approved continuing with the program, not requiring any remedial action to re air the leak in the 5.5" casin . 15:00 00:00 9.00 8,500 8,759 COMPZ CEMEN" DRLG P Cont drilling out cement from 8,500' to 8,759', 5bpm @ 1,950 psi, 20 - 40rpm, maintaining 1 % EP tube, on bottom torque at 3,500 - 4,500 ft/Ibs, 5K on bit, up wt 110K, down wt 65K, rot wt 70K. 11!07/2008 POOH to LD scraper and PU mud motor, RIH with 72 jnts 2 7/8" followed by 3 1/2" workstring, cont drilling cement with 5 blade junk mill and clean out to 8,770' MD, motor stalling, POOH from 8,770' to 1,771' for BHA chan e. 00:00 01:00 1.00 8,759 8,759 COMPZ CEMEN" DRLG P Attempt to cont drilling out cement from 8,759', 5bpm @ 1,950 psi, 20 - 40rpm, maintaining 1% EP tube, on bottom torque at 3,500 - 4,500 ft/Ibs, 5K on bit, up wt 11 OK, down wt 65K, rot wt 70K. Cannot make an hole. 01:00 02:00 1.00 8,759 8,759 COMPZ DRILL CIRC P CBU while rotate and recip. 1~~~ 3 €~f 1S Time Logs ___ _ __ Date From To Dur S De th E. De th Phase Code Subc_ode T Comment ___ _ 02:00 06:00 4.00 8,759 0 COMPZ DRILL TRIP P POOH with cement drilling assembl , LD scra er. 06:00 11:30 5.50 0 2,491 COMPZ DRILL TRIP P MU mud motor and 5 blade junk mill, single in hole with 72 jnts 2 7/8" HT PAC i e. 11:30 14:30 3.00 2,491 8,759 COMPZ DRILL TRIP P Continue to RIH with stands of 3-1/2" PH6 and fillin i e eve 20 stands. 14:30 18:00 3.50 8,759 8,770 COMPZ CEMEN" DRLG P Mill on top of cement from 8759' to 8 770'. Pumping 3 bpm @ 900 psi through Baker 3-1/8" motor rotating bit ~ 490 rpm. Motor stalling, cannot make an hole. 18:00 00:00 6.00 8,770 1,771 COMPZ DRILL TRIP P Drop ball and open POS, blow down top drive, POOH from 8,770' to 1,771'. 11 /08/2008 RIH with 4 3/4" bit on tapered work string and cont drilling out cement from 8,770' to 9,000', washed down to 9,216' then singled in hole to 11,432', cont wash down to 11,400', pumped hi-vis sweep and cont wash down to 11,435', POOH to 5,845'. 00:00 02:00 2.00 1,771 0 COMPZ DRILL TRIP P Cont POOH from 1,771, LD mud motor and mill. 02:00 07:30 5.50 0 8,750 COMPZ DRILL TRIP P MU BHA #4 and RIH on tapered_ strip to 8 75 '. Up wt 100K, down wt 65K. 50 rpm @ 3,000 ft Ib, 3 bpm 700 si. 07:30 12:00 4.50 8,750 9,216 COMPZ CEMEN" DRLG P Wash down and tag at 8,770', drilling cement, 85 rpm @ 2,700 ft/Ib, 5 bpm @ 1,300 psi, drill out to 9,000' MD and found open casing, washed down to 9,216'. 12:00 15:30 3.50 9,216 11,342 COMPZ DRILL TRIP P Blow down top drive and cont to sin le in hole to 11,342' and to to of CaCO3 lu . 15:30 17:00 1.50 11,342 11,400 COMPZ DRILL OTHR P MU top drive on jnt #285, break circ at 1 bpm - 750 psi, rotating 40 rpm and wash down to 11 400' up wt 145K, down wt 65K. 17:00 18:00 1.00 11,400 11,400 COMPZ DRILL CIRC P Pump a hi-vis sweep at 2 bpm, 1,080 si, surface to surface. 18:00 18:30 0.50 11,400 11,435 COMPZ DRILL OTHR P Cont to wash down and to to of CSR at 11,435' on final RKB. 18:30 20:30 2.00 11,435 11,417 COMPZ DRILL CIRC P Pull up 20' and pump another hi-vis sweep at 3 bpm, 1,050 psi surface to surface, while rotate and reciprocate strip . 20:30 00:00 3.50 11,417 5,845 COMPZ DRILL TRIP P BD top drive and start POOH from 11,417' to 5,845'. 11 /09/2008 POOH with drilling assembly, RIH with scraper and string mill, RIH to CSR and reverse circ cleanout down throw h CSR to 11,453', swa fluid to fresh SW, POOH LD to ered work strip from 11,451' to 4,448'. 00:00 04:30 4.50 5,845 0 COMPZ DRILL TRIP P Cont POOH with drilling assembly, LD bit. 04:30 06:00 1.50 0 0 COMPZ RIGMNT SVRG P Cut and slip drill line, service blocks, crown and draw-works. 06:00 14:00 8.00 0 11,316 COMPZ RPCOM TRIP P MU scra er strip mill and MS, RIH with to ered strip to 11,316'. ~_e®__ - F~a 4 ~f 1~i T+me Lomas _ _ _ Date From To _ Dur S. De th E. D~th_Phase Code Subcode T Comment 14:00 15:00 1.00 11,316 11,453 COMPZ RPCOM FCO P Up wt = 125K, down wt = 70K. RIH to 11.405', close annulate establish rev circ rate 1 bpm = 570 pai, 2 bpm = 760 psi, 3 bpm = 1060 psi. RIH to 11,,426', close annular, strip in while rev circ at 1 b m 550 si. 15:00 16:00 1.00 11,453 11,451 COMPZ RPCOM FCO P Strip down to 11453', no-go at 11435' top of CSR. Annular pump pressure started to climb when BHA no-go. PU 2' and start rev circ hole clean with clean seawater w/ 0.6% Safelube. Pumping 3 bpm @ 1,100 si. 16:00 00:00 8.00 11,451 4,448 COMPZ RPCOM TRIP P Blow down top drive, POOH LD 3 1/2" PH-6 DP from 11,451' to 4,448'. 11/10/2008 Cont POOH LD 3 1/2" PH-6 and 2 7/8" PAC pipe, bleed off OA and pull pack-off through BOP stack, replace pack-off and test, PU and rotate BOP stack for lift ram alignment, perform weekly BOP test, PU and RIH with 4 1/2" cs to 1,389'. 00:00 05:00 5.00 4,448 0 COMPZ RPCOM TRIP P Cont POOH LD 3 1/2" PH-6, 2 7/8" PAC i e and BHA #5. 05:00 07:30 2.50 0 0 COMPZ RPCOM OTHR P Off load pipeshed, clean floor and Baker tools, drain BOP stack, RU and pull wear ring. C/O elevators, wash stack. 07:30 11:00 3.50 0 0 COMPZ RPCOM OTHR P Latched into old packoff and attempted to BOLDS. Casing wanted to raise, screwed into TD and set down 20K lbs. BOLD's pulled out old packoff, attempted to set new ackoff. Could not set new packoff as casing was still 1" high. Closed bag and pressured up to 500 psi to seat packoff, RILDS. Pressure tested packoff to 5000 psi for 15 min. Good test. 11:00 16:00 5.00 0 0 COMPZ RPCOM NUND P ND BOPE, RU slings, lifted, turned and re-set stack NU BOPE. 16:00 20:00 4.00 0 0 COMPZ WELCTL ROPE P Weekly BOPE pressure test 250/3500 psi for 4-1/2". AOGCC was notified of weekly test at 8:30 hrs on 11/9/08, AOGCC Rep Bob Noble requested an up-date on 11/10/08. Notified AOGCC on 11/10/08 at 6:40 hrs and AOGCC Rep Bob Noble waived witness of test. 20:00 21:00 1.00 0 0 COMPZ RPCOM OTHR P Co saver sub, Rack & Tallly 2 3/8" IBT Mod tbg while waiting for XO and new crew to arrive on location. 21:00 00:00 3.00 0 1,389 COMPZ CASING RNCS P PJSM, MU seal assembly, XO's, and seal bore, start PU and single rn hole with 4 1/2" L-80 Hyd 513 cs~ to _ _ __. 1,389', up weight 47K, down weight 45K. I~~~e ~ €s~ 1~ Time Logs _~ __ _ Date From To Dur S. Depth E. Depth Phase Code Subcor~e T Comment _ 11/11/2008 24 hrSummarv Cont PU RIH with 4 1/2" csg to 11,433', displace well to 11.5 brine (with corrosion inhibitor) and spot 25 bbls diesel in upper portion of well, strip csg inhole and stab seals, attempted test on 4 1/2 x 5 1/2"and then 4 1/2", had communication in 4 1/2" x 5 1/2". 00:00 15:00 15.00 1,389 11,406 COMPZ CASING RNCS P Cont PU single in hole with 4 1/2'5 d 513 cs from 1,389' to no- o 11 433' obtaining up and down weights every 5 joints. Final up and down weight 125/65. Space out 2', POOH 27' to 11,406' and mark for cut. 15:00 18:00 3.00 11,406 11,406 COMPZ CASING CIRC P Dispalce well to 11.5 brine down the 4 1/2" 2 b m - 900 si. 18:00 20:00 2.00 11,406 11,406 COMPZ CASING RURD P LD landing jnt and CO to longer bales, RU circ lines, sensors and LRS. 20:00 21:00 1.00 11,406 11,406 COMPZ CASING CIRC P Close annular and reverse circ 35 bbls of 11.5 brine w/corrosion inhibitor at 1 b m -1,300 si, switch to LRS and pump 25 bbls of diesel at 1 b m 1 300 si. 21:00 00:00 3.00 11,433 11,433 COMPZ CASING DHEQ P Strio in hole and pained 17' from revious no- ode th. Determined previous no o was on fill, not top of CSR. Attempted to pressure test 4 1/2" x 5 1/2"with LRS. Pressured up to 1,000 psi and shut in, pressure dropped to 600 psi and held solid for 10 minutes on chart. No communication through 4 1/2". RD LRS, lined up and attempted to pressure test 4 1/2" csg but getting returns to 5 1/2" annulus. POOH 20' and circulated approximately 20 bbls to remove diesel, stung back into CSR to no-go, and saw no increase in pump pressure. POOH 20', sting into CSR with no increase in pump ressure. 11 /12/2008 Freeze protect 4 1/2" x 5 1/2", RU and test 4 1/2" csg at 1,500 psi for 30 minutes on chart, ND BOP stack and lift, install emergency slips, cut csg and LD stub, install pack-off and new tbg head, MU stack, CO rams to 2 3/8", test breaks. page ~i oaf ~ ~ r ~! Time Logs __-- -- ___--- _ -- Date From To Dur Depth S. E De th Phase Code Subcode T Comment _ 00:00 03:00 3.00 _ 11,433 11,433 COMPZ ___ CASING CIRC P _ Called engineer to discuss options, decision made to circ out diesel and corrosion inhibitor from annulus and wt u remainin seawater to 11.5 ppg for reverse circulating out fill. Lined up and attempted to circulate to kill tank, had pressure increase to 900 psi in 26 strokes with no returns to kill tank. Bled off and POOH 20', broke circ at 1 bpm - 60 psi, increased rate to 2 bpm - 70 psi. Lowered strin and stun seals assembly into CSR with no increase in pressure to no-go, POOH 2' and pressure increased to 900 psi, shut down pump and bled off 4 1/2" csg, started pump at 1 bpm and obtained 900 psi with 24 strokes, shut in and monitored pressure for 15 minutes with no loss. balled LRS to freeze rotect 4 1 /2" x 5 1 /2". 03:00 04:30 1.50 11,433 11,431 COMPZ CASING DHEQ P RU and blew down hard line to kill tank, blew down top drive, RU circ hose and chart sensor, set string 2' above no-go and pressured up to 900 psi with no loss, bumped pressure up to 1,500 osi and monitor while waiting on LRS, rack and tally 2 3/8" tb . 04:30 05:00 0.50 11,431 11,411 COMPZ CASING RURD P RU LRS for freeze protect, bleed off cs and POOH 20'. 05:00 05:30 0.50 11,411 11,411 COMPZ CASING CIRC P Close annular and pump 25 bbls diesel down the IA (4 1/2 x 5 1/2) at 1 b m - 1,500 si. 05:30 06:30 1.00 11,411 11,441 COMPZ CASING RNCS P Shut down LRS, strip 4 1/2 cs down to no-go, POOH approx 4' (2' above string weight) for space out, pressure up 4 1/2" csg to 1,500 psi and test for 1 hr on chart. 06:30 07:00 0.50 11,441 11,441 COMPZ CASING RNCS P Bleed pressure to 340 psi. Pull up hole 16', still holding press. This confirms seals still in CSR. Bleed off pressure. Lower back down to locator (no go) @ 11,423.33', PU to neutral wt. 110K PU 2' for space out. This puts the locator @ 11,421.33' and the end of the seals 11,440.72'. 07:00 09:00 2.00 COMPZ CASING NUND P PJSM. Drain stack. ND BOPE @ to of on final tubin head. 09:00 11:30 2.50 COMPZ CASING OTHR P RU lifting equipment, PU stack, set emergency slips, cut 4 1/2" casing off and LD 31' piece of casing. Set 4 1/2" packoff and test to 5K. Install and test new tubin head. ~~~~ 7 rsf 1 ~ r a Time Lomas ~ __ Date From To Dur S DeQth E. De th Phase Code Subcod_e T Comment 11:30 00:00 12.50 COMPZ CASING NUND P RU BOP stack to slings and re-set with blocks due to height, NU BOP's, MU kill and choke lines,~install riser, fill stack, attempt shell test, door seal leakin . 11 /13/2008 Test BOP breaks at 250/3,000 psi, PU and single in hole with 2 1/16" motor on 2 3/8" tubing, recording up and down weights every 5 jnts, to drill out fasUdrill plug at 11,500', Performed full circ with 11.5 ppg brine at 11,479', washed down through fill to 11,544' and started milling on plug, had increase in flow and pit gain, shut in well and monitored ressures. 00:00 01:30 1.50 COMPZ WELCTt BOPE NP Drain stack, open Upper Pipe Ram doors, clean up bolt holes and seals, re-seal doors. 01:30 03:00 1.50 COMPZ WELCTL BOPE P Shell test, tested Upper Pipe Ram's at 250/3,000 si, tested annular at 250/,2,500 psi. Notified AOGCC at 18:00 hrs on 11/10/08 of ram and shell test. AOGCC Rep John Crisp waived witness of test. RD test equipment, ulled test lu ,installed wear rin . 03:00 20:00 17.00 0 11,479 COMPZ RPCOM TRIP P PJSM, PU 2 1/16" motor and single in hole with 18 jnts 2 1/16" CS Hydril tubing, cross over and cunt to PU and single in hole with 2 3/8" IBT tubing. Fill pipe at 1,000' and start recording up/down weights every 10 joints to 11,479'. Tagged fill at 11 479. 20:00 22:00 2.00 11,479 11,479 COMPZ RPCOM CIRC P MU top drive and break circ at 1.5 bpm - 1,050 psi and CBU to ensure ood 11.5 throu hout well. 22:00 23:00 1.00 11,479 11,544 COMPZ RPCOM FCO P Wash down through fill from 11,479' to 11,544' and tag plu . 1.5 bpm - 1,050 si. 23:00 23:30 0.50 11,544 11,544 COMPZ PLUG MILL P Mill on plug, less than 1K on bit, 150 psi differential on motor, no rotation, 1.5 b m - 1,200 si. 23:30 00:00 0.50 11,544 11,544 COMPZ RPCOM OWFF P Flow paddle showed sudden increase in return rate, pit's showed 5 bbl increase in volume, shut down pump and checked for flow well flowing, shut in 2 3/8" rams and monitor pressure. SIDP reading 10 psi (2 check valves in BHA), SICP stabilized at 570 psi. Pits showing total of 15 bbl ain. 11 /14/2008 Drop ball and open pump out sub, displace well to 13 ppg hi-vis brine and kill well, attempt to push plug to bottom, POOH to close POS or run 2 3/8" completion. Called AOGCC Rep Jeff Jones at 1:05 AM to report closure of BOP for well control purposes, also sent a-mail of details of kick and control measures. Gave AOGCC Rep Jeff Jones 24 hr notice for upcoming BOP component test at 21:45 on 11/14/08. Sent a-mail to AOGCC Re Jeff Jones to u -date on well kill for 2L-321. Page Z3 €~f 16 11 Time Lo~s__ `__ ___ _ _ Date From To Dur S Depth E. De th Phase Code Subcode T Comment _ 00:00 _ 01:00 _ 1.00 11,544 11,544 COMPZ RPCOM OWFF T ____ SIDP 10 psi -SICP - 570 psi, called Kuparuk base and notified of venting gas on pad, attempted to circ at 1 bpm through choke and degasser to pits, return fluid at 11.4 ppg ,shut down pump, shut in choke. SIDP at 10 psi -SICP increased and stabilized at 1840 si after 30 minutes. 01:00 02:30 1.50 11,544 11,544 COMPZ RPCOM OWFF T Notified AOGCC Rep Jeff Jones, Well Engineer and Wells Superintendant of 2 3/8" ram closure and kick. With casing shut in, pressured up on DP to open check valves and obtain DP pressure, pumped total of 1 bbl (17 stks) obtained max pressure of 980 psi and shut down pump, DP stabilized at 400 psi with. no in_ r~ _ ._ in casin ressure. 02:30 04:00 1.50 11,544 11,544 COMPZ RPCOM OTHR T Confrence call with Well Engineer, Mud Engineer and Co Reps, made decision to order 300 bbls hi-vis brine. Notified Kuparuk Base and Pad Operator we were no longer venting gas, Baker Rep advized we drop ball and open pump out sub due to amount of weight material per bbl in kill weight brine, bled off top drive and shut in to monitor for any increase in DP ressure. 04:00 06:00 2.00 11,544 11,544 COMPZ RPCOM OWFF T Cont monitor DP for pressure, break off top drive and drop 5/8" ball to open POS, MU top drive and allow ball to drop. Pressured u on DP and sheared ump out sub at 3,150 psi, check hardline and connections to kill tank for well kill, informed CPF 2 production of situation and they will shut in wells 2L-317 and 2L-323 In~ectors to reduce the chance of communication. 06:00 1.5:00 9.00 11,544 11,544 COMPZ RPCOM WOEQ T Wait on kill weight mud to be delivered from mud lant. 15:00 17:00 2.00 11,544 11,544 COMPZ RPCOM OTHR T Load pits with 12.7 ppg kill wei ht brine, wei ht u new brine to 13 ® ~a~~ 9 €~f 1 fi Time l.ocLs _ _ __ _ Date _ From To Dur __ S. Deptht E. Qe th Phase Code Subcode T Comment ___ _ 17:00 20:00 3.00 11,544 11,544 COMPZ RPCOM CIRC T PJSM, break circ with 20 bbl hi-vis spacer down the drill pipe out the pumpout sub, followed by 13 ppg killweight hi-vis brine, at 2 bpm - 1,790 psi, maintainin 1,880 si on cs , throu h choke to kill tank, pumped drill pipe volume (45 bbls). an_d maintained drill pipe pressure at 2,150. psi for remainder of circulation with choke. At 3,766 total strokes (221 bbls) closed choke and bullheaded 5 bbls down to bottom perf depth of 11,720' at 1 bpm -1,200 psi, opene c o e an resume circ to kill tank at 2 bpm - 2,150 psi on drill pipe, pumped a total of 250 bbls and shut down pump, check, ed well for flow, no flow. 20:00 22:00 2.00 11,544 11,544 COMPZ RPCOM OTHR T Cont monitoring well and weight up remainin brine to 13 ppQ. Had no flow. 22:00 22:30 0.50 11,544 11,534 COMPZ RPCOM TRIP T Attempt to RIH and push FasDrill plu to bottom (no longer able to run motor with pump out sub open), max set down weight on bit 3K with no movement of plug, up weight 65K, down weight 45K, POOH 10' to 41,534'. 22:30 00:00 1.50 11,534 11,543 COMPZ RPCOM CIRC T CBU at 3 bpm - 2,910 psi. Change shaker screens. 13.0 ppg going in 13.0 comin out. 11 /15/2008 POOH to test BOP components used for well kill operation. Pulled wear ring and well began to flow. Attempted to bullhead at 2,000 and 3,000 psi, shut in well, confrence call with Well Engineer, Wells Supervisor, Haliburton, Co Rep's and MI Reps. Call out slickline to run WRP. ND BOP riser, NU shooting flan e, RU slickline unit. 00:00 00:30 0.50 11,543 11,543 COMPZ RPCOM OWFF T Shut down pump after bottoms up. Monitor well, static. Blow down top drive. ~~tJ~ 1p ~sf 96 l ~ Time Logs Date From To Dur S. De th E. D~th Phase Code Subcode T Comment _ 00:30 10:00 9.50 11,543 0 COMPZ RPCOM TRIP T POOH from 11,543', standing back 2 3/8" tbg, recording hole fill every 5 stands, pulled 10 stands, calculated hole fill 1.5 bbls, actual hole fill .4 bbls, monitored well at 10,643' for 30 minutes, well static, cont POOH 5 stands and monitored well at 10,193' for 5 minutes, calculated hole fill .78 bbls, actual hole fill .5 bbls, well static, cont POOH 15 stands and monitored well at 8,843' for 20 minutes, calculated hole fill 2.34 bbls, actual hole fill 1.4 bbls, well static, cunt POOH 15 stands to 7,493' and monitored well for 30 minutes, calculated hole fill 2.34 bbls, actual hole fill 1.2 bbls, well static, cunt POOH 5 stands to 7,043' and monitored well for 30 minutes during crew change, calculated hole fill .78 bbls, actual hole fill .3 bbls, well static, cont POOH, changed out 4 joints of 2 3/8" tubing due to pin damage (over torqued) at 1,680' while monitoring well, well static, cont POOH to BHA,LD mud motor and mill, replaced pump out sub, monitorin well, static. 10:00 11:00 1.00 0 0 COMPZ WELCTL BOPE T Clean rig floor and flush choke manifold in preparation for BOPE test. Monitor well, static. 11:00 11:30 0.50 0 0 COMPZ WELCTL BOPE T Monitored trip tank while pulling wear ring. Trip tank gained 2 bbls in 30 min. 11:30 13:00 1.50 0 0 COMPZ WELCTL OTHR T Well flowin shut blinds. SIP 60 si. Attempt to bullhead ,press up to 2000 psi. Bled press to 0. Attempt to bullhead again, press up to 3000 psi. Bled press off again. Monitor well, press slowly building up approx. 125 si er hour. 13:00 19:00 6.00 0 0 COMPZ WELCTL WOOR T Monitor well while lining up options. Decision made to RIH with WRP on slickline and attempt to set at 1,000'. Annulus ressure at 700 si. ~a€~e 11 a€ Mfr Time Logs __ __ _ _ Date From To Dur S De th E_De~th Phase Code Subcode T Comment _ 19:00 00:00 5.00 0 0 COMPZ WELCTL NUND T Drain BOP riser with trash pump down to upper pipe rams, ND riser, sting 13 5/8" x 7" shooting flange into cellar, MU flange on riser, spot Haliburton unit, MU 7" x 4 1/2" XO on shooting flange, load slickline equipment on rig floor, load lubricator section in pipeshed and warm up, assemble lubricator and stuffing box, install 8' riser section on XO, install pump in sub, install Haliburton BOP, bring Weatherford plug to floor, assemble plug setting tools. Annulus ressure at 900 si. 11/16/2008 Set 3.77" WRP plug at 135', POOH RD slickline, bled off annulus, flushed all circ lines with water and blew down, ND 13 5/8"annular, choke and kill lines, ND hardline to kill tank, raised rig and backed off well to allow AES to build scaffold and RU coil unit, RU to 13 5!8" BOP stack and functioned blind rams to allow Coil Unit to RIH after ressure testin well bore and BOP's. 00:00 00:30 0.50 0 0 COMPZ WELCTL OTHR T MU weight bars, SWS a-fire tool and 3.77" WRP, MU lubricator on riser, pressure test lubricator at 250 and 900 psi, no leaks, equalized and opened 13 5/8" blinds with 900 psi on well bore. 00:30 01:30 1.00 0 0 COMPZ WELCTI TRIP T RIH on slickline to 128' WLM and tagged an obstruction, possible ice plu ,POOH with slickline, closed 13 5/8" blinds, bled off lubricator (gas), called Well Engineer and Wells Supervisor, decision was made to un bailer, ND lubricator, LD WRP, 790 si on well bore. 01:30 02:30 1.00 0 0 COMPZ WELCTI TRIP T MU 2 1/2"drive down bailer, equalize lubricator, open blinds, RIH to 70' and tagged an obstruction, worked throu h, RIH to 128' and to ed obstruction, worked through and RIH to 400' WLM with no roblem, decision made to POOH and run 3.80" guage rin ,POOH, closed blinds and bled off lubricator (brine), emptied bailer and saw no indication of ice. Recovered a large chunk of black rubber when lowering wei ht bar from lubricator, 810 psi on well bore. ~~a~~ 12 of 1 & f , Time Logs _ _ Data From To Dur Comment S De th E. Depth Phase Cod e Subcode T __ 02:30 04:00 _ 1.50 0 0 COMPZ _ __ WELCTL TRIP _ T _ . LD ua a rin , MU SWS a-fire tool and 3.77" WRP, equalized lubricator, opened blinds, RIH and tagged an obstruction at 135'. Deasio a to set WRP at 135' WLM so as not to _ .u__.__ _._ lodge tools in well bore with anymore debri. Allow tool to set, POOH with slickline, close blinds, bled off lubricator, lined up well bore to choke manifold and bled off to kill tank to ensure WRP is holdin , RD lubricator and bled off a-fire tool. 04:00 10:00 6.00 0 0 COMPZ WELCTL OTHR T RD Slick Line and flush, BD circulating lines. RD shooting flange. ND annular preventer, secure pipe in derrick, re ri for move. 10:00 12:00 2.00 0 0 COMPZ WELCTL OTHR T PJSM, move rig off well and set down. Arranged rig mats to ramp up for Coil Ri . 12:00 18:30 6.50 0 0 COMPZ WELCTL OTHR T AES RU scaffolding on 2L-321, MU ada for flan a and SLB Coil Tubing BOP on to of 13 5/8" Nordic BOP. 18:30 20:30 2.00 0 0 COMPZ WELCTL OTHR T Spot an oil Unit on well. 20:30 22:30 2.00 0 0 COMPZ WELCTL OTHR T Coil Unit RU tools, pull tested connector, pressure tested MHA head to well. 22:30 23:00 0.50 0 0 COMPZ WELCTL OTHR T Coil unit pressure tested below 13 5/8" blinds to 1,500 psi, then pressure tested on top of 13 5/8" blinds, bled off and opened 13 5/8" blind rams, Coil Unit performed high ressure test to 3 500 si ood test ble ..off. 23:00 00:00 1.00 0 0 COMPZ WELCTL OTHR T Coil Unit RIH and latched onto WRP at 135', POOH to 87' and hung up, pumped diesel at 2,000 psi and ulled free, POOH with WRP. 11/17/2008 Stand by with rig while Coil Unit RIH and milled out FasDrill plug at 11,544', Clean out down to 12,140' coiled tubing MD. POOH. Coil Unit RIH and set "D" packer assembly with tail pipe plug at 11,376' in 4-1/2" casing, Coil Unit tested packer to 3,500 psi (good test), spotted corrosion inhibited brine then POOH from 11,356' to 7,500' dis lacin well to 9.6 brine. 00:00 02:00 2.00 0 0 COMPZ WELCTL OTHR T Coil Unit LD WRP, MU motor and mill. 02:00 04:00 2.00 0 11,450 COMPZ WELCTL OTHR T Coil Unit RIH to 11,450' and tagged on ossible fill, bled well bore to zero bled ri ht o 04:00 05:00 1.00 11,450 11,450 COMPZ WELCTL OTHR T Coil Unit displacing well to seawater. 05:00 06:30 1.50 11,450 12,140 COMPZ WELCTL OTHR T Coil Unit start milling on plug and, ushed to bottom at 12 140' CTMD. 06:30 09:00 2.50 12,140 0 COMPZ WELCTL OTHR T Coil Unit POOH from 12,140'. 09:00 09:30 0.50 0 0 COMPZ WELCTL OTHR T Coil Unit MU correlation BHA. 09:30 12:00 2.50 0 11,396 COMPZ WELCTL OTHR T Coil RIH to 11,396' and verify depth of 2 3/8" SBR. 12:00 13:30 1.50 11,396 0 COMPZ WELCTL OTHR T of nit H from 11,396'. ® ~ _ . _ ~'~,e 13 ~f 't6 ~~ Time Logs _ _ _ Date From To Dur S. De~_t_h. E. De th Phase Code Subcode T Comment _ _ _ 13:30 16:30 3.00 0 0 COMPZ WELCTI OTHR T Coil Unit wait on 4 1/2" "D" packer assembl with 2 3/8" IBT tail i e. 16:30 18:00 1.50 0 0 COMPZ WELCTI OTHR T Coil Unit MU packer assembly. 18:00 20:30 2.50 0 11,396 COMPZ WELCTI OTHR T wjth 3.75" "D" packer assembly with CA-2 plug in D nipple below packer to 11,396' and tag top of 2 3/8" SBR with mule shoe. 20:30 22:00 1.50 11,396 11,358 COMPZ WELCTL OTHR T Coil rnt P H 2 ' to 11,376' end of mule shoe) and drop 1/2" ball, circ down ball and seat, pressure up on packer to 1,800 psi, over pull on packer 10K, then pressured up on packer to 3,200 psi to shear out of assembly, ~D" packer top set at 11,357.85', end of mule shoe set at 11 376'. (overall length of packer, seal bore extension and Camco "D" rofile ni le = 18.15' . 22:00 23:30 1.50 11,358 11,353 COMPZ WELCTL OTHR T Coil Unit POOH 15' and displace well to sea-water. Pressure test packer to 3,500 si test ood . 23:30 00:00 0.50 11,353 7,500 COMPZ WELCTI OTHR T Coil Unit spotted 20 bbls 9.6 brine with corrosion inhibitor then POOH from 11,353' to 7,500' displacing well to 9.6 brine. 11 /18/2008 Coil Unit POOH laying in 9.6 ppg brine, Bleed off well to 0 psi, Close Nordic blind rams, drain Nordic BOP stack, RD Coil Unit, ND flange and valve off BOP stack, move Coil Unit off well site, RD scaffold, move Nordic Ri 3 back over well, NU annular on BOP stack, erform full BOPE test, 00:00 01:30 1.50 7,500 0 COMPZ WELCTI OTHR T Coil Unit cunt POOH laying 9.6 brine from 7,500'. 01:30 03:30 2.00 0 0 COMPZ WELCTL OTHR T Coil Unit bled off well and drained BOP stack down to mud cross, Nordic Rig 3 closed blinds on BOP, Coil unit RD lubricator and Coil Unit. 03:30 06:00 2.50 0 COMPZ WELCTI OTHR T Coil Unit pulled off well, RD valve and flange, RD scaffolding from around well head. 06:00 08:00 2.00 COMPZ WELCTL OTHR T Respot rig mats, back rig up, double mat for under rig. Move rig over well, s of & level ri . 08:00 08:30 0.50 COMPZ WELCTL NUND P Berm up cellar. PJSM for NU annular and riser. 08:30 12:00 3.50 COMPZ WELCTI NUND P NU annular preventer and riser. 12:00 12:30 0.50 COMPZ WELCTI BOPE P Set test plug. 12:30 13:30 1.00 COMPZ WELCTL EQRP P Change out lower pipe rams to 2 3/8". 13:30 20:30 7.00 COMPZ WELCTI BOPE P Rig up test equipment. Test ROPE to 250/3500 psi. Witnessing of test waived b AOGCC (Jeff Jones) @ 11:15 am 11/18/2008. 20:30 23:30 3.00 COMPZ WELCTL BOPE T Lock down test plug. Remove and repair 2 3/8 LPR's. Test 250/3,500 si. 23:30 00:00 0.50 COMPZ WELCTI OTHR P Pull test plug. RU to lay down 2 1/16" Pi a from derrick I"'ar~~ 14 a~f 1 ~ a • Time Lomas --- - --- - ----- Date From To Dur S Depth E. Depth Phase Code S ubcode T Comment _ 11/19!2008 __ ___ _ 24 hrSummarv LD 2 1/16" tubing BHA from derrick, Run 2-3/8" IBTM tubing completion to 7,023'. 00:00 02:00 2.00 COMPZ RPCOM PULD P La down 2 1/16" CS h dril tubin from derrick. 02:00 03:00 1.00 0 0 COMPZ RPCOM PULD P Swap TBG equip to 2-3/8 and MU seal assy. RIH to 29' and hit Ice lu .POOH and and lay down seals. 03:00 04:00 1.00 0 0 COMPZ RPCOM OTHR T MU circulating hose and wash thru Ice lu to 35'. RD Lines. 04:00 00:00 20.00 0 7,023 COMPZ RPCOM PULD P MU and RIH w/ seal assy on 2 3/8" tubing from derrick, drifting each stand with 1.901 drift. All jts frozen on top. Steaming ice out before dropping drift. RIH t/ 7,023' w/ 2 3!8 IBTM completion. 50k up wt, 45k do wt. 11 /20/2008 Continue to RIH w/ 2 3/8 IBTM completion f/ 7,023' & engage seal assy in D PKR. Space out. Spot corrosion inhibited brine and land han er. RILDS. PT tubin to 3000 si and IA to 3500 si. ND ROPE. 00:00 08:00 8.00 7,023 11,342 COMPZ RPCOM TRIP P Continue to RIH w/seal assy on 2 3/8" tubing from derrick, drifting each stand with 1.901 drift. All jts frozen on top. Steaming ice out before dro in drift from 7,023' to 11,342'. 08:00 10:30 2.50 11,342 11,371 COMPZ RPCOM HOSO P TD up. Attempt to locate seals while pumping. Stacked out @ 11,371' w/ muleshoe on bottom of seal ass . No press. increase. Worked up and down, rotating 2 rounds and pumping 1 BPM @ 275 psi W/no press. increase. Attempted this 3 times with no success. Stacking out at same lace, 11,371'. 10:30 12:00 1.50 11,371 11,371 COMPZ RPCOM CIRC P Circulated @ 1bpm w/ 275 psi to keep top drive from freezing while waitin on more fluid. 12:00 12:30 0.50 11,371 11,383 COMPZ RPCOM HOSO P Attempted to stab in seals again by rotating 2 RPM w/400 ft/Ibs torque while pumping 1 BPM w/275 psi. Worked seals in SBR ress increased to 500 psi, shut down pump and lowered seals down another 12', stacked out with locator 11,383'. 12:30 14:30 2.00 11,351 COMPZ RPCOM CIRC P Pulled 1 jt. Fluid keeps U-tubing. MU top drive and circulate @ 1 BPM w/275 si until new fluid arrived. 14:30 15:30 1.00 COMPZ RPCOM CIRC P Circulate clean 9.2 ppg brine @ 4 BPM w/2860 si. 15:30 16:30 1.00 COMPZ RPCOM HOSO P Pulled 2 jts. MU 2 - 2 3/8" space out pups, returned top jt. MU hanger and Landin 't. 16:30 17:00 0.50 COMPZ RPCOM CIRC P Spot 20 bbls .1 % by volume corrosion inhibited 9.2 ppg brine around seals on back side. Pac~a~ 1 ~f 1 ~ a Time Logs Date From _ To Dur _ __ S. De th E. De th Phase Code Subcode T Comment 17:00 19:00 2.00 COMPZ RPCOM DHEO P _ _ Land hanger, RILDS. RU to test tubing. Pressure test tubing to 3000 psi chart for 30 min. pressure test IA 3,500 si for 30 minutes. 19:00 20:30 1.50 COMPZ RPCOM OTHR P RD Test equipment and lay down landin 't. Set BPV. 20:30 22:00 1.50 COMPZ RPCOM OTHR P Remove 2 3/8 pipe rams from BOP. Clean u BOP and Pre for stora e. 22:00 00:00 2.00 COMPZ RPCOM NUND P ND 13 5/8 BOP 11 /21 /2008 Continue to ND BOP ,NU Tree, test to 250/5,000 psi. RDMO of 2L-321. Wrap tree and install heater to keep tree warm. Move to 1 R-09 Released Nordic 3 ri 09:00 hrs 11/21/2008 00:00 01:30 1.50 COMPZ RPCOM NUND P Continue to ND 13 5/8 BOP 01:30 05:30 4.00 COMPZ RPCOM NUND P Clean Wellhead and NU Adapter and new 2-9/16'Tree, Orientation alignment was OK'd by DSO (Randy George). Pressure test tree to 250/5000 si.OK. 05:30 06:30 1.00 COMPZ RPCOM DHEQ P .Set BPV. Clean cellar. Break bolts on 13 5/8" stack before removing from cellar. 06:30 09:00 2.50 COMPZ MOVE DMOB P Pull rig forward off of well. Remove rig mats. Wrap tree with plastic and install heater to keep tree and wellhead from freezing. Removed 13 5/8" BOP stack from cellar and placed on cradle. Released Nordic 3 ri 09:00 h rs 11 /21 /2008. Pa~r~~e 1fi of 1f~ RE: 2L-321 (PTD#198-262; S~#308-390) • Page 1 of ~~ Maunder, Thomas E (DOA) From: Gober, Howard [Howard.Gober@conocophillips.com] Sent: Monday, November 17, 2008 6:02 PM To: Maunder, Thomas E (DOA) Cc: Cawvey, Von; CPA Wells Supt; smithjae@bp.com; Burd, James A; Braun, Michael; Jones, Jeffery B (DOA); Nordic 3 Company Man Subject: RE: 2L-321 (PTD#198-262;. Sundry#308-390) Tom, Here is a synopsis of the conversation we just had on the phone. Subsequent to the note below, we have made good progress. We changed the plan slightly, but the end result is similar. Here is what we have accomplished so far: o The rig was moved off the well and a coil unit rigged up. o The connection between the rig BOP stack and the coil BOP stack was pressure tested. o We ran in hole and milled up the FasDrill bridge plug and cleaned out fill to 12,140' coiled tubing measured depth using slick seawater. o After pulling out of the hole, we ran a nozzle to tag the seal bore at the bottom of the 4-1 /2" casing. o We pulled out of the hole and are waiting on the equipment for our next run. We found a 4-1/2" permanent packer that we can set in the 4-1 /2" casing. The tail pipe of the packer will have a plug installed. Once the packer is set we will be isolated from the perforations. This will be in place of the IBP that I mentioned below. Advantage of this system is that we will not have the risk of pulling a IBP back through the 2-3/8" tubing. We will only need to pull a plug out of the 1.812" D nipple in the packer tail pipe. Here is the plan forward: o Run the 4-1/2" packer assembly on coil and set just above the bottom of the 4-1/2" casing. o Pressure test the packer to 3500 psi o Spot corrosion inhibited brine on bottom above packer. Load remainder of hole with uninhibited 9.6# brine. Bleed off pressure and ensure well remains dead. o POOH with coiled tubing. Ensure wel! is dead. Close rig blind rams and lock out the rig BOP. RD CTU. o MIRU Nordic 3. o Test BOP o Run 2-3/8" tubing completion. ~~~~~ ~~~ ~ ~ ~~~~ o Pressure test tubing and IA. o Set BPV. ND BOP. NU and test Tree. o RDMO o Pull BPV. Pull plug in 1.812" nipple. Freeze protect tubing with diesel. o Open sliding sleeve. Freeze protect IA with diesel. o Close sliding sleeve. o Open up well to production. The well will eventually be a surface powered jet pump completion, but they plan to flow the well prior to running the jet pump. I just wanted to give you an update of the status of the workover. We should be moving Nordic 3 back over the well sometime tomorrow. Please let me know if you have any questions. ~~~ ~r~~~ 3/24/2009 2L-321 (PTD#198-262; Sundry#308-390) Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Sunday, November 16, 2008 10:15 AM To: 'Gober, Howard' Cc: O'Dell, Brian J; Nordic 3 Company Man; Jones, Jeffery B (DOA); Cawvey, Von; smithjae@bp.com; Braun, Michael Subject: RE: 2L-321 (PTD#198-262; Sundry#308-390} Howard, I confirm our conversation and the discussion of your plans forward. When operations have been completed, a report regarding the operations on this well should be submitted. It is interesting that 13.0 ppg was necessary to kill the well and initial milling operations were being conducted with 11.5 ppg. Call or message with any questions. Tom Maunder, PE AOGCC From: Gober, Howard [mailto:Howard.Gober@conocophillips.com] Sent: Saturday, November 15, 2008 3:36 PM To: Maunder, Thomas E (DOA) Cc: O`Dell, Brian ]; Nordic 3 Company Man; Jones, ]effery B (DOA); Cawvey, Von; smithjae@bp.com; Braun, Michael Subject: 21-321 (PTD#198-262; Sundry#308-390) :~, ~~ ~, _,~~ , i ~~, , Tom, I wanted to document our conversation today concerning our plan forward on 2L-321 (PTD#198-262) with Nordic 3. The rig is operating on the well under Sundry #308-390. Yesterday we successfully killed the well with 13.0 ppg brine. We pulled out of the hole and stood back our 2-3/8" tubing. As we prepared to run our test plug for a BOP test, we noticed a flow from the well. The blinds were closed and we had 60 psi on the well. We attempted to bullhead fluid in the well, but we could not pump into the formation. The well currently has about 570 psi on it as the gas bubble migrates to surface. We have decided that the best plan of action is to utilize coiled tubing to get the well under control and ready for the completion. Here is our plan forward that you and I discussed: o Move the rig off the well to the side allowing enough room for CTU to rig up. The BOP stack will remain on the well as our source of control. o Rig up CTU with coil BOP's on top of the rig BOP stack. o Run in hole with CTU and displace out the 13.0 ppg fluid to 9.6 ppg brine. o Mill up the remainder of the FasDrill bridge plug at 11,540' RKB. Cleanout fill below perfs to +/- 11,900' RKB. o Run 1-11/16" inflatable bridge plug and set in liner at 11,600' RKB o Bleed off wellhead pressure to ensure IBP is holding good o Rig down CTU o MIRU Nordic 3 o Test BOP o Run 2-3/8" tubing completion o Pressure test tubing and IA. 11/16/2008 2L-321 (PTD#198-262; Sundry#308-390) Page 2 of 2 • • o Set BPV. ND BOP. NU Tree. o RDMO o Pull BPV. Pull IBP. o Open sliding sleeve. Run jet pump. As we discussed, we will not need to file a suspension since we are moving forward towards completion of the work scope as outlined in the Approved Sundry. Please let me know if you have any questions. I will update you on Monday morning with our status. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell 11/16/2008 FW: Kick on Nordic Rig 3 • • Maunder, Thomas E (DOA) From: Jones, Jeffery B (DOA) Sent: Saturday, November 15, 2008 7:34 AM Page 1 of 2 To: Crisp, John H (DOA); Jones, Jeffery B (DOA}; Noble, Robert C (DOA); Regg, James B (DOA); Scheve, Charles M (DOA); Maunder, Thomas E (DOA) ~) Subject: FW: Kick on Nordic Rig 3 n ~ J' ~ 0'" FYI \ JJ \ From: Nordic 3 Company Man [mailto:n1433@conocophillips.com] Sent: Friday, November 14, 2008 9:33 PM To: Jones, Jeffery B (DOA} Cc: Gober, Howard; O'Dell, Brian ] Subject: FW: Kick on Nordic Rig 3 Jeff, Nordic Rig 3 KWM arrived at the rig at 15:00 hrs - 11/14/08. We loaded pits and adjusted weight to 13ppg. We pumped 13 ppg KWM at 17:30 pm,11/14/08, to kill the well. Components used for well kill were the 2 3/8" pipe rams and choke manifold. These two components will be tested at approximately 10:00 am on 11!15/08 as soon as we are out of the hole with the 2 3/8" tubing string. Thanks, Rick Overstreet/Peter Nezaticky (Days) Randy Dolcater / Rance Pederson (Nights) Nordic 3 Co Man Office 907-659-7446 Fax: 907-659-7566 From: Nordic 3 Company Man Sent: Friday, November 14, 2008 8:32 AM To: yeff.jones@alaska.gov' Cc: Gober, Howard; O'Deil, Brian J Subject: Kick on Nordic Rig 3 We112L-321, 11/14/2008 Nordic Rig 3 Jeff, Milling on FasDrill plug at 11,544' MD with 11.5 ppg brine at 1.5 bpm, Driller noticed an increase in flow and a 5 bbl gain. 11/16/2008 FW: Kick on Nordic Rig 3 Page 2 of 2 Driller shut down pump and observed well flowing. Driller chose to close 2 3/8" pipe rams for a faster shut in at 23:30, 11/13/08. Total pit gain 15 bbls. With 2 check valves in the BHA the initial SIDP read 10 psi -SICP read 570 psi. Attempted to circulate through choke and gas-buster at 1 bpm, but surface volume weight was cutting back to 11.4ppg. Pumped a total of 5 bbls. Shut down pump and closed choke, and obtained SIDP of 10 psi -SICP of 1840 psi. Pressured up on drill pipe with backside closed in, to open both check valves, and obtained a SIDP of 400 psi. Calculated KWM at 13.0 ppg. At 08:30 we are currently waiting on kill weight fluid. Rick Overstreet/Peter Nezaticky (Days) Randy Dolcater / Rance Pederson (Nights) Nordic 3 Co Man Office 907-659-7446 Fax: 907-659-7566 11/16/200$ Kick on Nordic Rig 3 Page 1 of 1 ~ i Regg, James B (DOA) From: Jones, Jeffery B (DOA) Sent: Friday, November 14, 2008 8:59 AM To: Crisp, John H (DOA); Jones, Jeffery B (DOA); Noble, Robert C (DOA); Regg, James B (DOA); Scheve, Charles M (DOA) Cc: Maunder, Thomas E (DOA) ~ n („ Subject: FW: Kick on Nordic Rig 3 ~~ ~ d-"' Hello, Here's another kick, as of 9:00 am today they are still waiting for KWF (13 ppg brine) to be delivered to -the rig. I was notified at approx. 0115 am 11/14/0$. Jeff From: Nordic 3 Company Man [mailto:n1433@conocophillips.com] Sent: Friday, November 14, 2008 8:32 AM To: Jones, Jeffery B (DOA) Cc: Gober, Howard; O'Dell, Brian J Subject: Kick on Nordic Rig 3 ~~~; ~~ ~ ~~ Well 2L-321, 11 /14/2008 Nordic Rig 3 Jeff, Milling on FasDrill plug at 11,544' MD with 11.5 ppg brine at 1.5 bpm, Driller noticed an increase in flow and a 5 bbl gain. Driller shut down pump and observed well flowing. Driller chose to close 2 3/8" pipe rams for a faster shut in at 23:30, 11/13/08. Total pit gain 15 bbls. With 2 check valves in the BHA the initial SIDP read 10 psi -SICP read 570 psi. Attempted to circulate through choke and gas-buster at 1 bpm, but surface volume weight was cutting back to 11.4ppg. Pumped a total of 5 bbls. Shut down pump and closed choke, and obtained SIDP of 10 psi -SICP of 1840 psi. Pressured up on drill pipe with backside closed in, to open both check valves, and obtained a SIDP of 400 psi. Calculated KWM at 13.0 ppg. At 08:30 we are currently waiting on kill weight fluid. Rick Overstreet/Peter Nezaticky (Days) Randy Dolcater / Rance Pederson (Nights) Nordic 3 Co Man Office 907-659-7446 Fax: 907-659-7566 11 /14/2008 2L-321 (PTD#198-262) • Maunder, Thomas E (DOA) Page 1 of 1 From: Maunder, Thomas E (DOA) Sent: Thursday, November 06, 2008 4:17 PM To: 'Gober, Howard' Cc: NSK Well Integrity Proj; Nordic 3 Company Man Subject: RE: 2L-321 (PTD#198-262) Howard, You have accurately captured our discussion. Tom Maunder, PE AOGCC From: Gober, Howard [mailto:Howard.Gober@eonocophillips.com] Sent: Thursday, November 06, 2008 4:01 PM To: Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; Nordic 3 Company Man Subject: 2L-321 (PTD# 198-262) ~~~~ ,~ ~ „ ~ `~ ~.~~~~ ,~~.- Tom, I just wanted to document our conversation a few minutes ago. Nordic 3 is currently working on 2L-321 (PTD#198-262) under Sundry #308-390. The 5-1/2" production casing has known leaks between 4694' and 8415' RKB. These leaks were squeezed during a workover in May of 2007. The rig has drilled out the cement retainer and cement down to 8500' RKB. The 5-1/2" casing was pressured up to 1000 psi with seawater in the hale. We are experiencing a bleed off of Z00 psi every 10 min. At the conclusion of this workover, the 5-1/2" casing leaks will be isolated by a 4-1/2" inner casing string that will be run to surface. The 4-1/2"x5-1/2" annulus will be able to be monitored at surface. With this slow leak rate we should be able to see a pressure change on this annulus if the 4-1 /2" inner casing becomes compromised. Therefore we will not make another attempt at remedial cementing. We will continue on with the work scope as outlined in the Sundry application with a couple of exceptions. We will not be able to get a 1000 psi pressure test on the 5-1/2" casing at this time. We will not be able to pressure test the 4-1/2"x5-1/2" annulus to 1000 psi after the 4-1/2" casing is landed. Please let me know if this accurately describes our conversation. Thank you for your help with this matter - I appreciate it. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howard.Gober@conocophillips.com 11 /6/2008 • • ~~ ~ ~ a SARAH PAL/N, GOVERNOR 1~T ~+ ~-m~~1~~ ~W taisil ~ 333 W. 7th AVENUE, SUITE 100 CO„-7ERQ~~Ois CUll~l'II$SjO1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (9b7) 276-7542 Howard Gober Wells Group Engineer ConocoPhillips Alaska Inc. &,~ ; _ ~ ~ ~t L u PO Box 100360 ~'~'~'~'`~ `' Anchorage, AK 99510 ~~ Re: Kuparuk River Field, Tarn Oil Pool, 2Ir321 ~~~ f Sundry Number: 308-390 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, ~~ Daniel T. Seamount, Jr. ~,~ Chair DATED this3 ~ day of October, 2008 Encl. • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ,a ~~ October 27, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the. Tarn Well 2L-321 (PTD 198-262). This is a change to the Sundry (308-376) which was approved on 10/21 /08. Upon further review of the completion design, several changes were made. The 4-1/2" AVA nipple has been removed due to fears that the sleeve may become dislodged while landing the 2- 3/8" tubing string. We have also decided to mill up the FasDrill bridge plug while the rig is on the well. Another nipple was added to the 2-3/8" tubing string to give us a no-go nipple at the bottom of the tubing string. The BOP pressure test high value has been changed to 3500 psi as stated in the approved Sundry (308-376) If you have any questions or require any further information, please contact me at 263-4220. Sincerely, Howard B. Gober Wells Engineer CPAI Drilling and Wells y ~ ~~ ~ ~_~~ ~~~°` m ~ ~ r~1~ ~ O ~~4 STATE OF ALASKA ~- , r~ ` '~~ '~~ ALASKA OIL AND GAS CONSERVATION COMMISSION !f"' 1,D! ~ a APPLICATION FOR SUNDRY APPRO,VAI~ 20 AAC 25.280 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^/ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillipsAlaska, Inc. Development ^/ Exploratory ^ 198-262' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20286-00 ' 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? YeS ^ NO ^~ 2L-321 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): , ADL 380053 , RKB 28', Pad 115 Kuparuk River Field / Tarn Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12403' ~ 5890' ~ 11716' ~ 5512' - 7286', 11540' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 108' 108' SURFACE 3274' 7-5/8" 3302' 2288' PRODUCTION 11426' 5-1/2" 11454' 5359' LINER 926' 3-1 /2" 12380' 5878' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11680'-11720' 5489'-5512' 3.5" L-80 1627' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV 13. Attachments: Description Summary of Proposal Q 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 November 3, 2008 Oil 0 ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ 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 l 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: '~50p~5~ ~~~'~ST t -'s~~S c,.~~t-pVC,.1 S~P~.r~~ 3`~~s-3ry(o Subsequent Form Required: ~OL{ ~,;, ~~ APPROVED BY /~ ~~ J/ ApNnve~ Yy: C~MMISSI~NER THE C~MMISSI~N Date: Form 10-403 Revised 06/2Q0~ Submit in Dyplicate • • Kuparuk 2L-321 General Workover Procedure Pre-riq Work 1. Apply for Sundry General Workover Procedure Major steps: 1. MIRU Nordic #3 rig. 2. Pull BPV. Ensure well is dead. Reset BPV. 3. ND tree, NU and test 13-5/8" 5M BOP to 250/3500 psi. Test annular to 250/2500 psi. MASP=2602 psi. 4. Pull 3-1/2" kill string 5. Drill out cement retainer and cement in 5-1/2" casing to expose casing holes 7694'-8415' RKB. Pressure test casing to 1000 psi. Resqueeze if necessary. Continue to clean out down to 11425' RKB (just above casing seal receptacle). POOH. 6. Run scraper and string mill on 3-1/2" PH-6 workstring. Run stinger on bottom of scraper and cleanout CSR while on bottom. POOH. 7. Run 4-1/2" flush joint inner casing string. Change over fluid in hole to 11.5 ppg brine. Load 5-1/2" x 4-1/2" annulus with corrosion inhibited fluid. Freeze protect with diesel. Stab into seal bore. Break BOP flange at top of tubing head. Lift stack. Install emergency slips and packoff. Cut casing and install 2"d tubing head. NU and Test BOP. PT 5-1/2"x4-1/2" annulus to 1000 psi. 8. PU 2-3/8" tubing and BHA with 2.6" mill. Drill up FasDrill bridge plug and clean out to 11,900' RKB. POOH standing back tubing. 9. Run new 2-3/8" IBT-Mod completion for gas lift. Sting into seal bore at the bottom of the 4- 1/2". Space out. 10. Spot inhibited brine. Land tubing. PT IA to 3500 psi for 30 min and record on chart recorder 11. Set BPV. ND BOP. NU 2-9/16" tree. 12. Pull BPV. RU slickline. Run standing valve and set in tubing tail nipple. PT tubing to 3000 psi. Pull standing valve. Open sliding sleeve. Freeze Protect with diesel. Set BPV. 13. RDMO Nordic 3. Post-Rig Work: 1. Pull BPV. 2. RU slickline and run jet pump assembly. 4. Modify S-riser for higher tree. 5. Return to production. Well: 2L-321 API: 501032028600 ~C?IlOC4F~~'tl~~l~35 Field: Tarn PTD: 198-262 2008 RWO PROPOSED COMPLETION EXISTING COMPLETION NEW COMPLETION WELLHEAD WELLHEAD Lift threads: 3%" 8rd EUE Lift threads: 2-7/8" 8rd EUE BPV: 3" CIW H BPV BPV: 2.5" CIW H BPV Model: FMC Tarn Gen V Model: FMC Tarn Gen V Slimhole Slimhole CONDUCTOR 16", 62.58 ppf, H-40 ,welded INNER CASING 4-1/2", 11.6 ppf, T-95 & L-80, SURFACE CASING Hyd 513 75/8', 45.5 ppf, L-80, BTC-MOD TUBING CASING LEAKS 2-3/8", 4.6 ppf, L-80, IBT-Mod 7694'-8415' RKB A: Sliding Sleeve: 2-3/8" with 1.875" X profile PRODUCTION CASING a 5%2', 15.5 ppf, J-55, BTC-MOD B: Nipple: 1.812" D e C: Seal Assembly: 2-3/8" LINER ~ 3'/z', 9.3 ppf, L-80, EUE-8rd Mod D: Seal Assembly: 3-1/2" on bottom of 4-1/2" inner casing PLUG 3-1/2" HES Fas Drill Bridge Plug Set at 11,540' RKB To be removed during workover PERFS 11,680'-11,720' MD ~ Last Tag: 7/26/06 5,489'-5,512' TVD Tag Depth: 11,716' RKB 6 spf, 1/26/99 Fill: 4' fill above btm pert TD: 12,403' RKB Last Updated: 27-Oct-08 Updated by: HBG • E ~ R 1 ~ ~ SARAH PALIN, GOVERNO ~-7~~ OII• ~ ~~~ 333 W. 79t AVENUE, SUITE 100 CON51$RVA~'I011T COl-IIrIIS5I011i ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Howard Gober Wells Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, 2L-321 Sundry Number: 308-3'76 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) 659-360'7 (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, ~~~' Daniel T. Seamount, Jr. Chair DATED this~~ day of October, 2008 Encl. • ConocoPhillip-s Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 17, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner. CJ ,~ ~~~~ ~Q~~ ~6~~~~ C~~k ~'~;; Canso ~~~rr~i~~i~ t~~''; :; 3i"~L~~ ConocoPhillips Alaska, lnc. hereby applies for an Application for Sundry Approval to workover the Tarn Well 2L-321 (PTD 198-262}. 2L-321 was completed in January of 1999. The well produced with gas lift for artificial lift until November of 2001. During this time the well had chronic problems with paraffin deposition. The well was converted to utilize a surface powered jet pump for downhole artificial lift in 2001. Not only did this provide lift, but it also provided heat to prevent paraffin deposition in the tubing. In July of 2006, the well began to show some irregular performance. Leak detect logs eventually revealed a leak in the 5-1/2" production casing at +/- 8400' RKB. The well has been shut in since July 17, 2006. In May of 2007, Nordic 3 moved onto the well to repair the casing leak. Instead of one casing leak at 8400' RKB, pressure testing determined that casing leaks existed between 7694' and 8415' RKB. The workover was suspended so that the next steps could be planned out and so that materials could be procured. The first objective of this workover will be to ensure the leaks in the 5-1/2" casing have been adequately cemented off. Then a 4-1/2" inner casing string will be run along with a 2-3/8" tubing string. Once the workover has been completed, the well will be capable of artificial lift via either jet pump or gas lift. If you have any questions or require any further information, please contact me at 263-4220. Sincerely, Howard B. Gober Wells Engineer CPAI Drilling and Wells J}? • • ~~~~~,~, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION C) C T .~ ~ 1~~~~~ APPLICATION FOR SUNDRY APPROVAI~~$ ~~~~ {J~f p~; i~;ut~~lf~iw,w,idai-; 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver Other ^ Altar casing ^~ Repair well ^~ PlugPartorations ^ Stimulate ^ Time Extension ^ Change approved program ^ Puil Tubing ~ Perforate New Pool ^ Re-enter Suspended Well Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development [~] Exploratory ^ 198-262 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20286-00 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? YeS ^ NO Q 2L-321 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool{s): ADL 380053 RKB 28', Pad 115' Kuparuk River Field !Tam Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD {ft): Effective Depth MD (rt): Effective Depth TVD (ft): Plugs (measured}: Junk (measured): 12403' 5890' 11716' 5512' 7286', 11540' Casing Length Size MD TVD Burst Catlapse CONDUCTOR 80' 16" 108' 108' SURFACE 3274' 7-518" 3302' 2288' PRODUCTION 11426' 5-1/2" 11454' 5359' LINER 926' 3-1/2" 12380' 5878' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11680'-11720' 5489'-5512' 3.5" L-80 1627' Packers and SSSV Type: Packers and SSSV MD {ft} no packer no SSSV 13. Attachments: Description Summary of Proposal '0 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 Operai October 27, 2008 Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ 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 Commission Use Onl Sundry Number: ~, . Conditions of approval: Notify Commission so that a representative may witness ~ .3ofr-~7 i7 Plug Integrity ^ BOP Test (~ Mechanical Integrity Test ^ Location Clearance ^ Other: '~ `~ j``f ~ ~ ~ ~ ~~~ '~ `~ ~ ~' ,. Subsequent Form Required: ~o ,,,,, r,„~1PPROVED BY ~ r ~ ~ l / / t A proved b : -.. I~AM~SSI~JNER THE COMMISSION Date: ~ Form 10-A03 Revised"06/2006 {- ~ ' ' ' `-~ Submit in Duplicate Kuparuk 2L-321 General Workover Procedure Pre-riq Work 1. Apply for Sundry General Workover Procedure Major steps: 1. MIRU Nordic #3 rig. • 2. Pull BPV. Ensure well is dead. Reset BPV. ~~ ~~ \ ~ , ~~~ ~'~~ ~~~jr? 3. ND tree, NU and test 13-5/8" 5M BOP to 250/30 C? psi. Test annular to 250/2500 psi. MASP=2602 psi. 4. Pull 3-1/2" kill string 5. Drill out cement retainer and cement in 5-1/2" casing to expose casing holes 7694'-8415' RKB. Pressure test casing to 1000 psi. Resqueeze if necessary. Continue to clean out down to 11425' RKB (just above casing seal receptacle). POOH. 6. Run scraper and string mill on 3-1/2" PH-6 workstring. Run stinger on bottom of scraper and cleanout CSR while on bottom. POOH. 7. Run 41/2" inner casing string. Load annulus with corrosion inhibited brine. Land in CSR. ND BOP. Install slips for 4-112" casing. Cut off 4-1/2" casing and NU new tubing head. Pressure test packoffs, NU and test BOP. Freeze protect 4-1 /2" x 5-1/2" annulus. 8. RU slickline. RIH and set isolation sleeve in 4-1 /2" AVA nipple. PT sleeve to 3500 psi. RD slickline. ` 9. Run 2-3/8" completion with sliding sleeve in open position. Load tubing and IA with corrosion inhibited brine. Space out and land 2-3/8" tubing. CMIT tubing and IA to 3500 psi. . 10. ND BOP, NU and test new 2-9/16" tree. Freeze protect tubing and IA. 11. RU slickline. Close sliding sleeve. Pressure test IA to 3500 psi. Pressure test tubing to 3000 psi. RD slickline. Set BPV. c-'°'`s""'ti 12. RDMO Nordic 3. Post-Rig Work: 1. Pull BPV. 2. RU CTU with 1.5" tubing. RIH and mill up FasDrill bridge plug and clean out to PBTD. 3. RU slickline. Pressure test to to 3500 psi. Open sliding sleeve. Run Weatherford jet pump assembly ar concentric gas lift mandrel. 4. Modify S-riser for higher tree. 5. Return to production. • • Well: 2L-321 API: 50103202$600 ~~}~~ ~~j~~j~$ Field: Tarn PTD: 198-262 2008 RWO PROPOSED COMPLETION EXISTING COMPLETION WELLHEAD Lift threads: 3%' 8rd EUE BPV: 3" CIW H BPV Model: FMC Tarn Gen V Slimhole CONDUCTOR 16", 62.58 ppf, H-40 ,welded J SURFACE CASING 7%8', 45.5 ppf, L-80, BTC-MOD PRODUCTION CASING 5%', 15.5 ppf, J-55, BTC-MOD c D i~P-1L~ 7 3'/i', 9.3 ppf, L-$0, EUE-8rd Mod PLUG 3-1/2" HES Fas Drill Bridge Plug Set at 11,540' RKB PERFS 11,680'-11,720' MD 5,489'-5,512' TVD ~ ` ,,~., 6 spf, 1/26/99 NEW COMPLETION WELLHEAD Lift threads: 2-7/8" 8rd EUE BPV: 2.5" CIW H BPV Model: FMC Tam Gen V Slimhole INNER CASING 4-1 /2", 11.6 ppf, T-95 & L-80, Hyd 513 TUBING 2-318", 4.6 ppf, L-80, !BT-Mod A: Sliding Sleeve: 2-3/8" with 1.$75" X profile B: AVA Nipple: 4-1 /2" C: Seal Assembly: 2-3/$" D: Seal Assembly: 3-1/2" on bottom of 4-1/2" inner casing Last Tag: 7126/06 Tag Depth: 11,716' RKB Fill: 4' fill above btm pert TD: 12,403' RKB Last Updated: 17-Oct-08 Updated by. HBG RE: 2L-321 (198-262) Forward Plans . /9¿7~~~ Subject: RE: 2L-321 (198-262) Forward Plans From: "Gober, Howard" <Howard.Gober@conocophillips.com> Date: Mon, 18 Iun 200715:24:24 -0800 To: Thomas Maunder <tom _ maunder@admin.state.ak.us> Tom, Thanks for the note. Hopefully we will have a game plan soon so that we can order materials. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howard.Gober@conocophillips.com -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, June 18, 2007 3:22 PM To: Gober, Howard Subject: 2L-321 (198-262) Forward Plans Howard, This confirms our conversation, when the forward plans for this well are determined you will need to submit them with another sundry. Tom Maunder, PE 'J".--;........ ..:",."- 6~ JUN ~ 6 Z001 --' 1 of 1 6/19/20078:54 AM . RECEIVED . STATE OF ALASKA JUN 1 3 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIONSAlaska Oil & Gas Cons. COO1mission 1. Operations Performed: Abandon D Repair Well 0 Plug Perforations D Stimulate D Other LJ Alter Casing 0 Pull Tubing 0 Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0' Exploratory D 198-262 1 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20286-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 28', Pad 115' . 2L-321 . 8. Property Designation: 10. Field/Pool(s): ADL 380053: ALK 4601 Kuparuk River Field 1 Tarn Oil Pool" 11. Present Well Condition Summary: Total Depth measured 12403' . feet true vertical 5890' . feet Plugs (measured) 7286' Effective Depth measured 11716' / feet Junk (measured) true vertical 5512' / feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 108' 108' SURF CASING 3274' 7-5/8" 3302' 2288' PROD CASING 11426' 5-112" 11454' 5359' LINER 926' 3-1/2" 12380' 5878' Perforation depth: Measured depth: 11680'-11720' true vertical depth: 5489'-5512' SCANNE.DJUN ~ 6 2007 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 1627' MD. Packers & SSSV (type & measured depth) Baker K-1 cement retainer @ 7494' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) 7694' - 8411' MD squeeze cement 95 bbls Class G cement below retainer, / Treatment descriptions including volumes used and final pressure: place 5 bbls cement on top of retainer. Est. TOC = 7286' MD. Final squeeze pressure = 2100 psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation SI -- Subsequent to operation SI -- 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service... ~. ( /'1~ ¡if Daily Report of Well Operations _X 16. Well~after proposed work: s~~<L~ed eT2.-' ,... l ~ Ii ~ . _' I GasD WAGD GINJ WINJ D WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge~ \\(,<6 Sundry Number or N/A if C.O. Exempt: 307-156 Contact Howard Gober @ 263-4220 Printed Name Howard Gober Title Wells Group Engineer (p /tZ../o:¡- Signature ~ Phone Date Prenared bv Sharon AII~un-Drak'" 263-4612 I RBDMS BFl JUN 1 9 2007 ~ ~¡1'Rt67 Submit Original Only 7 ~þ ,-. ~S/ . " Form 10-404 Revised 04/2004 0 R , G t N A L Conoc;Phillips Wellvlew Web Reporting Time Log Summary 05/18/2007 15:00 16:00 1.00 MIRU MOVE DMOB P Move rig offweIl2M-31. 16:00 22:00 6.00 MIRU MOVE MOB P Move rig from 2M to 2L Pad. 7.2 mile move with derrick up. Used 2 PEAK Cats for emergency braking ahead of rig while moving up hill from bridge near 2L. Rig on location & spotted @ 21 :30.( Set up & accept @ 22:00 5-18-07.) 22:00 00:00 2.00 MIRU MOVE OTHR P Spot Mud engineers office-hook up lines to kill tank Rig up Handi Berm. Hookin u lines to dis lace well. 05/19/200700:00 01:30 1.50 MIRU MOVE RURD P PJSM-Rigging up to kill well. 01:30 03:30 2.00 MIRU RPCOfl. RURD P Rig up lines in cellar-finish rig up of kill tank-Test all lines to 3000 psi-blow down lines-load seawater. 03:30 04:30 1.00 MIRU RPCOfl. OTHR P Open SSV-check well for pressure-pull BPV wI lubricator. 700 psi on tbg. '0' on inner annulus. 04:30 08:00 3.50 MIRU RPCOfl. OTHR P Bleed tbg. to 270 psi-pump down inner annulus wI seawater to displace diesel out of tb .. 08:00 11 :30 3.50 MIRU RPCOfl. OTHR P Pump down tbg. & displace hole wI 233 bbls. seawater. Shut down & monitor well. Small flow. 11:30 18:00 6.50 MIRU RPCO OWFF P Monitor well for pressure build up. With sliding sleeve open-well pressure built to 580 psi on tbg. 590 psi on inner annulus. 18:00 21:00 3.00 MIRU RPCOfl. OWFF P While monitoring well=spot slick line unit & unload tools. PJSM on slick line work. Rig up slick line-pump in sub-2 extensions-BOP-sheaves & tools. Pressure test to 1500#. 21:00 22:30 1.50 MIRU RPCOfl. SLKL P RIH wI slickline Dual 42 bo shifting tool assembly-close sleeve @ 11332 SLM. 22:30 23:00 0.50 MIRU RPCO SLKL P Pressure test tbg. to 1800 psi. (HELD) 23:00 00:00 1.00 MIRU RPCOfI. OTHR P Bleed tbg. & annulus to '0' & monitor well for ressure build u . 05/20/2007 00:00 01:30 1.50 MIRU RPCOfl. OWFF P Continue monitoring well- Tbg. '0' IA 430 si. 01:30 02:30 1.00 MIRU RPCO SLKL P Open sliding sleeve & POH wI slickline. 02:30 04:00 1.50 MIRU RPCOfl. RURD P PJSM-Rig down slickline & equalize well. 05/20/2007 04:00 04:30 0.50 MIRU RPCOII. OTHR P Blend brine to 11.6# & line up to kill well. 04:30 06:00 1.50 MIRU RPCOII. CIRC P Pump 11.6# brine down tbg. & displace fluid to kill tank. 06:00 08:00 2.00 MIRU RPCOII. OTHR P Blow down lines to kill tank-monitor well. (Well Dead) 08:00 09:30 1.50 MIRU RPCOII. NUND P Set BPV-Nipple down tree-inspect tbg. hanger threads-function LDS. 09:30 13:30 4.00 MIRU RPCOII. NUND P Nipple up BOPE. 13:30 17:30 4.00 MIRU RPCm DHEQ P Testing bope.( Annular preventer element leaked.) All other equipment tested fine. Witnessed by AOGCC Jeff Jones. 17:30 00:00 6.50 MIRU RPCOII. OTHR NP Drain stack-nipple down riser & change out element in annular preventer. 05/21/2007 00:00 02:00 2.00 MIRU RPCOII. NUND P PJSM= Rig down lift cap & rig up riser. 02:00 03:00 1.00 MIRU RPCOII. SFEQ P Test annular preventer 250-2500 psi. Riq down test lines. 03:00 05:00 2.00 MIRU RPCm OTHR P Pull BPV-make up landing jt.-BOLDS-pull hanger to floor. (Pulled loose @ 145k-string wt. wI blocks-115k. 05:00 07:00 2.00 MIRU RPCOII. CIRC P Circ. hole volume 233 bbls. Total losses @ 20 bbls. 07:00 08:00 1.00 MIRU RPCOII. PULD P Monitor well-Lay down tbg. from 11432' to 10964'. Monitor well. 08:00 00:00 16.00 MIRU RPCOII. PULD P Fill tbg.-continue laying down 3.5" tbg. (Bad corrosion on outside tbg. Hole swabbing-filling hole thru tbg. & circ. every 45 jts. Layed down tbg. to 2852'. 05/22/2007 00:00 05:30 5.50 MIRU RPCm PULD P Cont to POOH fl 2852' to surface. LD seal assy. 05:30 06:00 0.50 MIRU RPCOII. OTHR P Number and tally tubing, kick out of pipe shed and clean floor fl next operations. 06:00 06:30 0.50 MIRU RPCOII. RURD P Set wear bushing. 06:30 07:00 0.50 MIRU RIGMN SVRG P Change out saver sub & service rig. 07:00 07:30 0.50 MIRU RPCOII. PULD P Load tools fl clean-out run. 07:30 11:30 4.00 MIRU RPCOII. PULD P PJSM, MU clean-out BHA: 27/8" Mule shoe jt, 5 1/2" csg scraper, (1) collar, 4.8" string mill, 3 1/8" bumper sub, 3 1/8" oil jars, (6) 3 1/8" DC's on 3 1/2" PH-6 work string. RIH wI PH-6 work string flO - 2047'. PU 55 klbs, SO 55 klbs. 11:30 12:30 1.00 MIRU RPCOII. SFTY P Secure well, CPAI sponsored safety award dinner wI safety meeting and intro wI Rig-Safety-Zone personell. 12:30 14:30 2.00 MIRU RIGMN 'SVRG P PJSM, Slip & Cut drill line. 05/22/2007 14:30 15:00 0.50 MIRU RPCOI\. CIRC P CBU long way @ 4 bpm wI 650 psi. Full returns wI sludge appearing material. 15:00 16:00 1.00 MIRU RPCOI\. PULD P Cant RIH wI PH6 work string and clean-out BHA f/2047' - 3046'. 16:00 16:30 0.50 MIRU RPCOI\. CIRC P CBU @ 4 bpm & 850 psi. Full returns wI sludQe appearing material. 16:30 17:30 1.00 MIRU RPCm PULD P Cant RIH wI PH6 work string and clean-out BHA f/3046' - 4046'. 17:30 18:00 0.50 MIRU RPCOI\. CIRC P CBU @ 4 bpm & 1000 psi. Full returns wI sludqe appearinq material. 18:00 19:00 1.00 MIRU RPCOI\. PULD P Cant RIH wI PH6 work string and clean-out BHA f/4046' - 4920'. 19:00 19:30 0.50 MIRU RPCOI\. CIRC P CBU @ 4 bpm & 1250 psi. Full returns wI cleaner returns. 19:30 20:30 1.00 MIRU RPCOI\. PULD P Cont RIH wI PH6 work string and clean-out BHA f/4920' - 5950'. 20:30 21:00 0.50 MIRU RPCOI\. CIRC P CBU @4 bpm & 1400 psi. Full returns wI some viscous material. 21:00 22:00 1.00 MIRU RPCOI\. PULD P Cant RIH wI PH6 work string and clean-out BHA f/5950' - 6980'. 22:00 22:30 0.50 MIRU RPCOI\. CIRC P CBU @ 4 bpm & 1600 psi. Full returns wI viscous appearinQ material. 22:30 23:30 1.00 MIRU RPCOI\ PULD P Cant RIH wI PH6 work string and clean-out BHA fl 6980 - 8011'. 23:30 00:00 0.50 MIRU RPCOI\. PULD P CBU @ 4 bpm & 1750 psi wI full retu rns. 05/23/2007 00:00 02:00 2.00 COMPZ RPCOI\. TRIP P Continue RIH wI clean-out BHA #1, PU PH-6 work string fl 8011' to 8990' MD. 118K# PU, 68K# SO. 02:00 03:00 1.00 COMPZ~ RPCOI\ CIRC P CBU, 4 BPM, 1860 psi, full returns, some qrittv/sandv fines over shakers. 03:00 04:00 1.00 COMPZ~ RPCOI\. TRIP P Continue RIH wI clean-out BHA #1, PU PH-6 work string from 8990' to 10,002' MD. 125K# PU, 68K# SO. 04:00 06:00 2.00 COMPZ~ RPCOI\. CIRC P CBU,4 BPM, 1970 psi, full returns, some qrittv/sandv fines over shakers. 06:00 07:00 1.00 COMPZ~ RPCOI\. TRIP P Continue RIH wI clean-out BHA #1, PU PH-6 work string from 10,002' to 11,008' MD. 132K# PU, 67K# SO. 07:00 08:30 1.50 COMPZ~ RPCOI\. CIRC P CBU, 4 BPM, 2130 psi, full returns, some Qrittv/sandy fines over shakers. 08:30 09:00 0.50 COMPZ~ RPCm TRIP P Continue RIH wI clean-out BHA #1, PU PH-6 work string. Tag up with bottom of 2-7/8" Muleshoe stinger at 11,454' MD - 4-1/2" OD XO tagging top of seal bore at 11,438' MD (Nordic 3 RT). Clean tags. 140K# PU, 68K# SO. 09:00 11:30 2.50 COMPZr RPCOI\. CIRC P MU top drive. Pump hi-visc sweep & circulate around, 4 BPM, 2270 psi, full returns, small increase in gritty/sandy fines over shakers with sweep, circulate clean. 13:30 14:30 14:30 15:30 15:30 00:00 05/24/2007 00:00 02:00 02:00 03:00 03:00 04:00 04:00 05:30 05:30 06:00 06:00 12:00 12:00 17:00 17:00 21:00 21 :00 00:00 05/25/2007 00:00 04:00 04:00 04:30 1.00 COMPZ RPCOII. CIRC 1.00 8.50 2.00 COMPZ 1.00 1.00 1.50 0.50 6.00 5.00 4.00 COMPZ CASIN OTHR 3.00 4.00 0.50 Swap manifold around to reverse circulate. Reverse circulate, stage rate up to 3 BPM, 1600 psi, full returns. At 4 BPM, 2100 psi, well started taking some fluid, reduced rate to 3 BPM with no loss. Reversed a full circulation, no significant amount of grittylsandy material over shakers, saw rust flakes from PH-6 i e. P Swap lines. Circulate, pump hi-visc pill and spot on bottom, 3 BPM, 1800 si. Blow down to drive. P Start POOH. Elevators hanging up on PH-6. LD 1 joint. Pull 1 stand, hole taking fill-up from work string. RU line to maintain hole fill by filling work strin . P POOH with clean-out BHA #1. Fill work string every other stand to maintain ro er hole fill. P Finish POOH wI PH-6 workstring fl 1035' - BHA to . P LD Drill Collars, jars, bumper sub, casin scra er, POS and XO's. P PJSM, PU Baker Retrieveamatic test acker for leak location rocedure. T Down for rig repair. Repair broken chain in draw-works. P Service and lube rig. P Cont RIH with Baker Retrieve-a-matic test packer to 8505' MD. PU 112 klbs, SO 65 klbs. P RU fl test operations. Through numerous set and pressure cycles below packer determine deepest leak interval to be above 8411' - 8414' drlrs depth wI packer set. Casing held 2500 si below this de tho P Change test mode for locating upper boundary of casing leak(s). Start pulling out of hole wI intermittent stops to test casing integrity by setting packer, closing rams and testing casing above packer for leaks. Through sequential testing determine upper leak(s) in casing to be bel~ packer set depth of 7694' drlrs depth. Casing held 2500 psi test above this de tho P POOH fl 7694' - 4696' wI packer on PH6 workstrin to run US IT 10 s. P Continue POOH wI test packer fl 4696' - surface. P UD Baker Retrievamatic test packer. Clear floor in preparation for eline 10 in work. 05/25/2007 04:30 06:00 1.50 COMPZ~ EVALv\¡ RURD P PJSM, RU Schlumberger equipment for cased hole logging. Fct test tools and RIH. Will run USIT log for further casinç¡ corrosion investiç¡ation. 06:00 07:30 1.50 COMPZr EVAL,^ ELOG P RIH wI USIT 07:30 10:00 2.50 COMPZr EVALV\¡ ELOG P Unable to RIH beyond 3735', logging tools stacking out due to high hole angle. Decide to Log out and PU tractor. Loç¡ fl 3735' to surface. 10:00 11:00 1.00 COMPZI EVA LV\¡ RURD P PU I MU tractor, function test tools. 11 :00 19:00 8.00 COMPZI EVALv\¡ ELOG P Continue RIH wI USIT on tractor. Start logging, tool failure, POOH. 19:00 21:30 2.50 COMPZI EVALV\¡ ELOG T POOH wI US IT, LD tools and rig down shieve for rig operations. 21:30 00:00 2.50 COMPZI RPCOII. TRIP P PU and RIH w/3 1/2" PH6 workstring to displace Calcium Carbonate pill over top of Casing Seal Receptacle (CSR) for upcoming cement work wI waiting on SLB to repair logging equipment. 05/26/2007 00:00 06:00 6.00 COMPZI RPCOII. TRIP P RIH w/3 1/2" PH6 workstring f/2907' - 11403' to displace calcium carbonate I pill over top of CSR. 06:00 07:30 1.50 COMPZI RPCOII. CIRC P Mix and attempt displacement of Calcium Carbonate pill. Pumped 20 bbls of 35 bbls pill prior to mechanical problems wI mix system. Decision to abort and displace mixed amount into I place and repeat. 07:30 09:00 1.50 COMPZI RPCOII. TRIP T POOH f/11403' - 9435' and allow Calcium Carbonate to settle out of pill I prior to repeat of procedure. 09:00 10:00 1.00 COMPZr RPCm OTHR T Wait for Pill #1 to settle out in wellbore above CSR. 10:00 11:00 1.00 COMPZI RPCOII. TRIP T RIH f/9435' -11305'. 11:00 12:30 1.50 COMPZ' RPCOII. CIRC P Mix, pump and displace 2nd 35 bbl calcium carbonate pill over top of Casinç¡ Seal Receptacle. 12:30 19:00 6.50 COMPZ~ RPCm TRIP P POOH wI workstring. 19:00 00:00 5.00 COMPZI EVALv\¡ ELOG P PJSM, RU Schlumberger and RIH wI USIT logging tool & tractor for casing evaluation. 05/27/2007 00:00 06:00 6.00 COMPZr EVA LV\¡ ELOG P Running USIT logging tool for casing corrosion analysis. 06:00 08:00 2.00 COMPZr EVAL,^ ELOG P Finish log f/11 ,000' to surface wI USIT. RD same. 08:00 10:30 2.50 COMPZI RPCOII. TRIP P RIH wI 40 stands PH6 tubing t 13782' fllay down and removal from workstring. 10:30 15:00 4.50 COMPZr RPCOII. PULD P POOH laying down excess PH6 workstrinç¡. PJSM, PU and RIH w/5 1/2" Baker K-1 cement retainer on remaining PH6 workstring to 7494'. PU 97 klbs, SO 60 klbs. Pressure IA to 500 psi and est inj rates: .5 bpm @ 1180 psi, 1 bpm @ 1400 psi, 1.5 bpm @ 1560 psi, 2 bpm @ 1900 psi, 2.5 bpm @ 2300 psi wI ramp up in pressure at final rate. Sus end in'ectivit test. 20:00 21:00 1.00 COMPZ RPCOII. OTHR P Unsting from retainer, test casing to 2500 psi. Unable to test due to bleed-off. Work on surface isolation issues, retest, OK. 21:00 22:00 1.00 COMPZ CEMEJ\ RURD P RU cementers fl squeeze operations. S ot vac trucks for fluid xfers. 22:00 00:00 2.00 COMPZ CEMEJ\ SQEZ P PJSM, pump 5 bbls fw lead, batch 15.8 ppg cmt in hopper and begin pumping cement. Pump 50 bbls 15.8 ppg "G" cement @ 3 bpm wI holding 1000 psi on IA wI rig choke. Sting into retainer and continue wI squeeze. Pump cmt 45 bbls cmt @ 2.2 bpm wI ICP 1800 si, final 2200 si. 05/28/2007 00:00 01:30 1.50 COMPZ CEMEJ\ SQEZ P Hesitate squeeze remaining cement into place in 10 bbl increments. Final squeeze pressure 2100 psi. Total cement squeezed below retainer 95 bbls 15.8 ppg "G" cement. Total cement above retainer after unsting 5 bbls for total of 100 bbls cement. Est TOC 7286'. 01:30 02:30 1.00 P Equalize fluids in workstring. Blow down and release cementers. POOH wI 3 stands workstring prior to Reverse out. 02:30 03:30 1.00 P Reverse out string to remove contamination and clean strin 03:30 05:00 1.50 P PJSM. Displace out 11.6 ppg mud wI 9.6 inhibited brine. 05:00 06:00 1.00 P Finish clean-up, blow down top drive and prepare to POOH laying down workstrin . 06:00 07:00 1.00 P POOH laying down 3 1/2" PH6 workstrin . 07:00 08:30 1.50 P POOH laying down work string. 08:30 09:30 1.00 P PJSM, slip and cut drill line. 09:30 12:00 2.50 P Cont POOH f/5725' - 4971' laying down PH6 wOrkstring, filling hole wI 9.6 inhibited brin . 12:00 17:30 5.50 P Finish POOH fl 4971' - surface and lay out remainin workstrin . 17:30 18:30 1.00 P Pull wear ring, unload tools and prep to RIH wI kill strin . 18:30 20:00 1.50 P RIH wI 9.3# 3 1/2" L-80 IBT Mod tubin 51 IS. Make up hanger and landing jt. Land hanger, PU 47klbs, SO 47 klbs wI 1628' tubin . RILDS. Set BPV. 21:30 00:00 2.50 P PJSM, nipple down stack. 05/29/2007 00:00 04:00 4.00 P Nipple down BOP stack, stand back on stub in cellar. Cleanin its. 04:00 06:00 2.00 P Install and nipple up tree. Prep rig for move. 06:00 09:00 3.00 P Finish Nipple up and test tree. Install BPV. RIG RELEASED THIS DATE @ 0900 Hrs. PROD CASING (0-11454, 00:5.500, Wt:15.50) SURF CASING (0-3302, 00:7.625, Wt:45.50) CEMENT PLUG (7286-7494, 00:3.500) LINER '11454-12380, 00:3.500, Wt:9.30) Perf '11680-11720) . . Conocoptdllips A.laska, ¡Inc. KRU 2L-321 API: 501032028600 SSSV Type: NONE Rev Reason: WORKOVER Last U date: 6/11/2007 Wt 62.58 45.50 15.50 9.30 Grade Thread H-40 WELDED L-80 BTC-MOD L-80 LTC-MOD L-BO EUE-8RD Thread IBT MOD Descri lion CEMENT RETAINER @ 7494', 96 BBLS CMT SQUEEZED BELOW 5 BBLSABOVE RETAINER 5/2212007 ID 0.000 ill' Date Note 7/24/2006 PRODUCTION CASING LEAK TO FORMATION 8400' 06/08/07 Schlumbergep '.'_ ·~,>..o .:~,.',... -.' ~..~."..,"._..,.p.,..,.., " NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 1 ]. 20m , ~;f"âtd"U::¡;~ JUN 1 4 2007 G(ì\ìS. CammiS~!O~1I1'=~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~y Field: Kuparuk } cr?ç -Qro8- Well Color CD Job# Log Description Date BL 2L-321 11629010 MULTI-FINGER CASING INSPECTION 05/12/07 1 2C-16 11629008 PPROF/LDL 05/10/07 1 2G-11 11638863 PRODUCTION PROFILE 05/05/07 1 1C-125 N/A MEM INJECTION PROFILE 05/05/07 1 2D-13 11638861 PRODUCTION PROFILE 05/03/07 1 2D-08 11638862 PRODUCTION PROFILE 05/04/07 1 2G-09 11638864 PRODUCTION PROFILE 05/06/07 1 2N-349A 11629004 RST/ WFL 05/04/07 1 3H-19 11638867 PRODUCTION PROFILE 05/09/07 1 1Q-10 11628771 MEM PRODUCTION PROFILE 05/03/07 1 1 E-11 11629012 INJECTION PROFILE 05/14/07 1 2L-321 11665439 USIT OS/25/07 1 2V-08A 11629013 PMIT 05/15/07 1 1 J-160 11632704 PRODUCTION PROFILE 03/19/07 1 1H-07 11665436 SBHP SURVEY OS/20/07 1 2F-11 11665434 PRODUCTION PROFILE 05/19/07 1 2X-07 11665433 INJECTION PROFILE 05/18/07 1 1B-01 11665432 PRODUCTION PROFILE 05/17/07 1 2X-01 11637338 INJECTION PROFILE 05/15/07 1 2Z-29 11665438 PRODUCTION PROFILE OS/22/07 1 1 H-22 11637339 INJECTION PROFILE 05/16/07 1 1Y -11 11632708 INJECTION PROFILE OS/23/07 1 1G-03 11637336 INJECTION PROFILE 05/14/07 1 1A-23 11665443 MEM PRODUCTION PROFILE OS/29/07 1 1 F-08 11665435 SBHP SURVEY OS/20/07 1 1J-170 11632709 INJECTION PROFILE OS/24/07 1 1 D-1 09 N/A INJECTION PROFILE 05/13/07 1 2M-24 11665440 SBHP SURVEY OS/28/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . ~V~VŒ (ID~ !Æ~!Æ~fß!Æ . AIfA~JiA. OIL AlU) GAS CONSERVATION COMMISSION / SARAH PAUN. GOVERNOR 333 W. 7th AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Howard Gober Wells Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 \ o....~.I cþ 'Y . ,,-.... Re: Kuparuk River Field, Tarn Oil Pool, 2L-321 Sundry Number: 307-156 Dear Mr. Gober: SQ~NED MAY 0' 9 2007 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may me 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, Dan T. Seamount Commissioner DATED this? day of May, 2007 Encl. · Crl16'1"i RECEIVED STATE OF ALASKA MAY 0 4 2007 ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROV ALAlaska Oil & Gas Cons. commission 20 MC 25.280 . Anchorage 1, Type of Request: Abandon D Suspend D Operational Shutdown D Perforate D Waiver D Other D Alter casing 0- Repair well 0 Plug Perforations D Stimulate D Time Extension D Change approved program D Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well D 2, Operator Name: 4. Current Well Class: 5, Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0/ Exploratory D 198-262 -' 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20286-00 r 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? Yes D No 0 2L-321 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380051. ALK 4601 RKB 28', Pad 115' Kuparuk River Field 1 Tarn Oil Pool r' 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12403' , 5890' , 11716' 5512' 11425' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16" 108' 108' SURF CASING 3274' 7-5/8" 3302' 2288' PROD CASING 11426' 5-1/2" 11454' 5359' LINER 926' 3-1/2" 12380' 5878' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11680'-11720' 5489'-5512' 3-1/2" L-80 11454' Packers and SSSV Type: Packers and SSSV MD (ft) Baker casing seal receptacle @ 11433' Cameo DS nipple @ 512' 13. Attachments: Description Summary of Proposal D 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch D Exploratory D Development 0 Service D 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat May 15, 2007 Oil 0/ Gas D Plugged D Abandoned D 17, Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL D 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 f1S.A ~ "'" Phone 265-6958 Date Commission Use Onlv Sundry N~ber.:.. i~ Conditions of approval: Notify Commission so that a representative may witness ,- -1n ~ /"' , // Plug Integrity 0 BOP Test ~ Mechanical Integrity Test D Location Clearance D Other: ~OO Ç>"'>\ ~ a ~ \-t:~ \- S,bse"e", Fo~ Re";,,," ~ RBDMS BFl MAYO 8 2007 App"",,' by' ~ APPROVED BY S/7/7 COMMISSIONER THE COMMISSION Date: Form 10-403 Re!J¡sed 06/2006 / Submit in Du licate nRIGINAI ~:Þ6? .{¡\!:>--; t"<-7 . ~ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED MAY 04 2007 Alaska Oil & Gas Cons. Commission Anchorage May 3, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Tarn We1l2L-321 (PTD 198-262), 2L-321was completed in January of 1999. The well produced with gas lift for artificial lift until November of 2001. During this time the well had chronic problems with paraffin deposition. The well was converted to utilize a surface powered jet pump for downhole artificial lift in 2001. Not only did this provide lift, but it also provided heat to prevent paraffin deposition in the tubing. In July of 2006, the well began to show some irregular performance. Leak detect logs eventually revealed a leak in the 5-1/2" production casing at +/- 8400' RKB. The well has been shut in since July 17, 2006.~ The first objective of the workover is to identifÝ the leaking interval. If the leak is a single point, we will repair the well with an expandable casing patch. This material is available and ready for the workover. If the leak is over a larger area or if the casing shows extensive damage on the USIT log, we will run a 4-1/2" inner string with 2-3/8" tubing. The pipe for the repair will need to be procured, so the well will be secured and the rig would return at later date to finish the repair. If you have any questions or require any further information, please contact me at 263-4220, Sincerely, ~ Howard B. Gober Wells Engineer CPAI Drilling and Wells . . Kuparuk 2L-321 General Workover Procedure Pre-ria Work Slickline: 1. Pull plug at 11,425' RKB. Tag fill. 2. Set composite bridge plug in 3-1/2" liner at +/- 11,550' RKB. 3. Open sliding sleeve at 11,323' RKB. Valve Shop: 4. Set 3" CIW 'H' BPV within 24 hrs of MIRU. General Workover Procedure Major steps: 1. Apply for Sundry 2. MIRU Nordic #3 rig. 3. Kill well. NO tree, NU and test 11" 5M BOP to 250/3000 psi. Test annular to 250/2500 psi. MASP=2602 psi. 4. Pull 3-1/2" completion 5. Run scraper and string mill on 3-1/2" PH-6 workstring. Run stinger on bottom of scraper and cleanout CSR while on bottom, 6. Run test packer. Identify casing leak interval. 7. RU E-Line. Run USIT log and caliper survey in 5-1/2" casing. Have tractor on location in case it is needed. 8. If leak can be isolated with 40' patch, continue with next step. If not, lay down PH-6, run kill string and,suspend operations. .If') 4I~A ~Ç:~~ ~I'f)~-\- ~.r-, 9. Run 40' Baker ExPatch and seal off casing hole. Lay down PH-6. 10. Run new completion including turned down CMU and 3-1/2" IBT-Mod tubing with special clearance couplings. 11. Sting into CSR. PT casing patch. 12. Spot corrosion inhibited seawater. Space out and land completion. 13. Pressure test tubing and IA. 14. NO BOP, NU and test tree. 15. Freeze protect well. 16. ROMO Nordic 3. . . Post-Ria Work: Slickline: 1. Pull SOY from #2 GLM and replace with DV. CTU: 2. Drill up composite bridge plug at +/- 11,550' RKB. Ensure liner is clean past bottom perf at 11,720' RKB. Slickline: 3. Tag fill. 4. Open sliding sleeve. 5. Set jet pump. 6. Return to production. SURF CASING (0-3302, OD:7.625, Wt:45.50) PROD CASING (0-11454, OD:5 .500, Wt:15.50) Gas Lift :mdrellDummy Valve 1 (6646-6647. OD:4.725) SLEEVE-C (11323-11324, OD:4.500) Gas Lift 3lldrel/Dummy Valve 2 (11373-11374, OD:4.725) NIP (11425-11426, OD:4:470) PLUG (11425-11426, OD:2.750) SEAL (11454-11455, OD:4.000) LINER (11454-12380, OD:3.500, Wt:9.30) Perf (11680-11720) ----~" KRU 2l-321 Rev Reason: SET DMY, PLLJG Last U date: 4/11/2007 ~ade H-40 L-80 L-80 L-80 CAMCO OS NIPPLE ¡:¡AKER CMU_§LlDING SLi::EVE CLOSE,[) 7/22/20oL....... §ET 2. 7~ CA-2 PL1.Lº-º-t\i4/6/2007 ,____ CAMCO 0 NIPPLE BAKER 80-40 SEAL ASSY ID 2.875 __ __lJH 3 0.000 2.750 2.985 ~~~~~_..~~~~~~ "~~---~---~._--~.~~-- ~.~--_..- . Conoc.;¡;í,illips Well: 2L-321 Field: Tarn . API: 501032028600 PTD: 198-262 2007 RWO PROPOSED COMPLETION WELLHEAD Lift threads: 3%" 8rd EUE BPV: 3" CIW H BPV Model: FMC Tarn Gen V CONDUCTOR 16",62.58 ppf, H-40 , welded SURFACE CASING 7%", 45.5 ppf, L-80, BTC-MOD PRODUCTION CASING 5%", 15.5 ppf, J-55, BTC-MOD TUBING 3%", 9.3 ppf, L-80, EUE-8rd Mod LINER 3%", 9.3 ppf, L-80, EUE-8rd Mod NIPPLE 3%" Camco 'D' Nipple with 2.75" ID PERFS 11,680'-11,720' MD 5,489'-5,512' TVD 6 spf, 1/26/99 A B B I c D E NEW COMPLETION A: Landing Nipple: 2.875" DS profile 500' TVD= 500' MD B: Gas Lift Mandrels No. MD TVD TYPE 1 3,611 2,400 1" KBG2-9 2 8,280 4,121 1" KBG2-9 -100' above casing patch C: Expandable Casing Patch: Baker ExPatch. Post expansion ID=4.381". OAL=66'. Top of patch at -8380' RKB. D: Sliding Sleeve: Baker 3W' CMU with 2.813" DS profile. Body turned down to 4.180" OD. 1 joint above the XN nipple E: Nipple: 3%" with 2.813" XN profile (2.75" No Go). Place at least 1 full joint above seal assembly F: Seal Assembly @ 11,454' MD Last Tag: 7/26/06 Tag Depth: 11,716' RKB Fill: 4' fill above btm perf TD: 12,403' RKB Last Updated: 1-May-07 Updated by: HBG . . -------- Original Message -------- Subject:RE: FW: Kuparuk (Tam) producing we1l2L-321 (PTD 198-262) Communication Date:Tue, 25 Ju12006 13:07:45 -0800 From:NSK Problem Well Supv <n1617@conocophillips.com> To:Thomas Maunder <tom _ maunder@admin.state.ak.us> CC:NSK Problem Well Supv <n1617@conocophillips.com> Tom: 2K-22 packer was found leaking. We will probably make one attempt to hydraulically reset the packer, but the probability of that working is low. That means a workover will be next. Fortunately it was not the casing string. This failure on 2L-321 is going to be researched quite a bit to see if there is a correlation with any Drilling problems, etc. We just hope there is not a zone with a prevalence for corrosion or some other bad mechanism. The power fluid is produced water that by itself is not bad, but if the fluid rate is very low it could drop out solids and cause an internal corrosion problem. I doubt that is the case with 2L-321, but it could apply to West Sak wells where the rates are very low. The produced water does not have any additional inhibitors beyond whatever is added for the water injection system--in fact it comes off the same header. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, July 25, 2006 12:42 PM To: NSK Problem Well Supv Cc: Jim Regg Subject: Re: FW: Kuparuk (Tarn) producing well 2L-321 (PTD 198-262) Communication Thanks Jerry. This makes 2 casing failures that I am aware of. What was the failure of2K-22 determined to be? Is there anything special about the power water? Is it inhibited any different from the injection water? Hope this isn't the first couple of a whole bunch. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 7/25/2006 12:35 PM: Tom: Yesterday (7/25/06) a Leak Detection Log was ran on 2L-321 to identify the leak path from the IA. A leak in the casing has been identifiëd at 8400' md which is above the seal assembly. The well will be secured and remain off line until the casing is repaired. A schematic diagram is attached for your reference. «2L-321.pdf» Let us know if you have any questions. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 of2 5/7/20072:05 PM . . -----Original Message----- From: NSK Problem Well Supv Sent: Sunday, July 23,200611:01 AM To: tom maunder@admin.state.ak.us Cc: NSK Problem Well Supv; CPF2 Prod Engrs Subject: Kuparuk (Tarn) producing well 2L-321 (prD 198-262) Communication Tom: Yesterday (7/22/06) an MITIA failed on Tarn jet pumped producer we1l2L-321 (PTO 198-262). Slickline was troubleshooting the jet pump system, which was taking more water for lift than what had been normal. After pulling the jet pump the CMU was closed and an MITIA attempted. A sustained rate of 1.5 bpm was established into the IA @ 2600 psi. An MITT passed against a tubing plug @ 2500 psi. The results indicate either a potential hole in the casing or a failed packer. A leak detect log wíll be performed within a few days to locate the leak mechanism. The well will remain shut-in until further notice. Attached is a trend plot showing the increasing power fluid rate for the last few weeks. This well had last passed an MITIA 5/18/05 to 3000 psi. Please call if you have any questions. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907 -659-7043 2of2 5/7/20072:05 PM PM . . WELL LOG TRANSMITTAL ,- _.- ._-~--"--'~'---"~ 1 j ~ 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 / MTr) 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 International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 1 BL / EDE Disk 2L - 321 Caliper Report 15 - Oct-06 1) 2) 3) 4) 5) 6) 7) t , , Print Name: Œ-.L ~~{,¡~hIAP ~lA it ~u¡ Signed: Datè15:G~1 ()it /1, (~;-d~t~~~xv-~r~'~~ll~~.i~:~i(;r- I CJ ¥ - QG, 8 ;t: Ji.( éJòS- PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E ..MAil: ?D-~.).¡.j:;;;-:..)¡~L~/3;(;D;\.1S:V!i.) R\¡l.. ,,:>3 ..:;::' }.i~ WEBSITE : ;jÌ}':N''-lJ~;HEll;ID,~"'/L;'JGo-::)Gì DIOO _ PDSANC-2006\Z_ W ordlDistributíonl Transmittal_ Sheetsl Transmit_ OriginaJ.doc I I I I I I I I I I I I I I I I I I I . . Memory Magnetic Thickness Tool and Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2L-321 Log Date: October 15, 2006 Field: Kuparuk Log No. : 8061 state: Alaska Run No.: 1 API No.: 50-103-20286-00 Pipe1 Desc.: 3.5" 9.3 Ib L-80 Top Log Intvl.: 3,290 Ft. (MD) Pipe1 Use: Tubing & Liner Bot. Log Intvl.: 11,561 Ft. (MD) Pipe2Desc.: 5.5" 15.5 Ib L-80 Top Log I ntvl.: 3,290 Ft. (MD) Pipe2 Use: Production Casing Bot. Log Intvl.: 11.454 Ft. (MD) Pipe3 Desc.: 7.625" 45.5 Ib L-80 Top Log Intvl.: 3,290 Ft. (MD) Pipe3 Use: Surface Casing Bot. Log Intvl.: 3,302 Ft. (MD) Inspection Type: Assess COffosive Damage (Metal Loss) to Production Casing. COMMENTS: This Caliper/MTT data is tied into the Seal Assembly @ 11,454' (Driller's Depth). This is the first log of this well with the 24-Arm Multi-finger Caliper (MFC) and 12 Arm Magnetic Thickness Tool (MTT), The caliper records the features of the internéd surface of the 3.5" tubing in this well and the Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing & liner, 5.5" production casing and 7 5/8" surface casing within the logged interval. The entire tubing string was logged with both tools, but the MTT recorded useable data only up to the bottom of the 7 5/8" surface casing (3,302')- therefore MTT results are only provided for this interval (3,302' - 11,561' MD). 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. In this log, the MTT was calibrated down hole (8,000'), 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 and 5.5" production casing. INTERPRETATION OF CALIPER LOG RESULTS FOR 3.5" TUBING & LINER: The 3.5" tubing and liner logged appears to be in good condition with respect to corrosive and mechanical damages. No significant wall penetrations, areas of cross-sectional wall loss, or 1.0. restrictions are recorded in the 3.5" tubing and liner logged. 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 also included. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 18%) are recorded. MAXIMUM RECORDED CROSS-SeCTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 5%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded. RECEIVED NOV 0 3 2006 1£115' - :;)Co d #- ILré)D5- commisSiOi · ,'\Iaska on & Gas eons· Ancttora9Ð I I I I I I I I I I I I I I I I I . INTERPRETATION OF MTT LOG RESULTS: . The MTT log results cover the interval between 3,290' to 11,561'. The recordings indicate apparent isolated metal loss on the low side of the pipe in the interval between 7,500' and 11,420', as illustrated in the MTT Maximum Recorded Metal Loss Graph. A graph illustrating the Maximum Recorded Metal Loss is included in this report. Log plots of the detailed sections at 8,105',9,481',7,693', and 8,999' showing isolated metal loss are included in this report. MAXIMUM RECORDED METAL LOSS FROM MTT: Isolated Metal Loss on Low Side Isolated Metal Loss on Low Side Isolated Metal Loss on Low Side Isolated Metal Loss on Low Side Isolated Metal Loss on Low Side Isolated Metal Loss on Low Side Isolated Metal Loss on Low Side Isolated Metal Loss on Low Side Isolated Metal Loss on Low Side Isolated Metal Loss on Low Side Isolated Metal Loss on Low Side 45% Metal Loss 42% Metal Loss 34% Metal Loss 31% Metal Loss 27% Metal Loss 22% Metal Loss 22% Metal Loss 22% Metal Loss 22% Metal Loss 22% Metal Loss 22% Metal Loss @ @ @ @ @ @ @ @ @ @ @ 8,105 Ft. (MD) 9,481 Ft. (MD) 7,693 Ft. (MD) 8,999 Ft. (MD) 8,918 Ft. (MD) 8,113 Ft. (MD) 11,089 Ft. (MD) 10,468 Ft. (MD) 11,202 Ft. (MD) 10,814 Ft. (MD) 9,570 Ft. (MD) The percent isolated 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" and 5.5" 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. I Field Engineer: R. Richey Witness: C. Fitzpatrick I Analyst: M. Tahtouh & J. Burton I I I Well: Field: Company: Country: 2 L- 321 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Norn.OD 3.5 ins Weight 9.3 f Grade & Thread L-80 EUE 8rd I I Penetration ami Metal loss ("I" wall) penetration body metal loss body I 300 250 200 150 100 50 o 10 to 20 to 40 to over 20% 40% 85% 85%, I o to 1% 1 to 10% I o o I I Damage Configuration ( body ) 80 I 60 40 I 20 o I isolated pitting general line ring hole I poss corrosíon corrosion corrosìon ible hole I o I I DS Repo Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Anal st: Nom.ID 2.992 ins October 15, 2006 MFC24UWNo.211387 1.69 24 M. Tahtouh Nom. Upset 3.5 ins Upper len. 1.2 ins Lower len. 1.2 ins Damage Profile wall) penetration body o o metal loss body 50 100 GLM 1 Bottom of Survey = 365 GLM 2 Analysis Overview page 2 I I I I Pipe 1 I I I I I I I I I I I I I I Correlation Recorded Damage to Borehole 3.5 in (20.6' - 11530.1 ') Well: Field: Company: Country: Survey Date: Approx. Tool Deviation 50 100 21.-321 Kuparuk ConocoPhillíps Alaska, Inc. USA October 15, 2006 Approx, Borehole Profile 38 1573 3134 150 4692 Õ (¡; ::E ..Q .¡..J E LL :;; c: z 200 6255 ..s= GLM 1 ã. QJ 0 0 ~ 250 7861 300 350 GLM2 365 o Damage Profile (% I Bottom of Survey 365 I I 50 I Tool Devi a tion (degrees) 9421 10985 11530 100 I I MTT Maximum Recorded Metal Loss Relative to Calibration Point 125 3912 150 4692 175 5472 200 GlM 1 Q:j 225 ...Q E :::¡ z E 250 0 275 300 325 350 GI.M2 372 -100% 0 Change in Metal Thickness (%) Pipe 1 3.5 in (3290.6' - 11530.1') Well: Field: Company: I I Survey Date: I I Decrease I I I I I I I I I I I I I Bottom of Survey = 365 21.-321 Kuparuk ConocoPhillips Alaska, Inc. USA October 15, 2006 Increase 6255 0 7081 ~ .....: LL c .s::: 7861 õ.. (j) 0 8641 9421 10202 10985 11530 100% I I MIT Circumferential Recorded Metal Loss Relative to Calibration Point Pipe 1 3.5 in (3290.6' - 11530.1') Well: Field: Company: Country: Survey Date: 2L-321 Kuparuk ConocoPhillips Alaska, Inc. USA October 15, 2006 I I I Decrease Increase I 125 I 150 I I I I I I 175 200 GLM 1 ~ 225 (!) ..Q E ::J Z ..... 250 c 'õ 275 300 325 350 GLM2 372 -50% 0 Change in Metal Thickness (%) I I I I I I Bottom of Survey = 365 3912 4692 5472 6255 Õ 7081 :¿ +-' u.. c ..c 7861 ã. (!) 0 8641 9421 10202 10985 11530 50% I I I I I I I I I I I I I I I I I I I £s. Magnetic Thickness I Log (10Hz) PnoAcmre DiAqN05Tic SElWlca, ¡,""" Database File: d \warrior\data \21-321 \21-321. db Dataset Pathname: cut Presentation Format: 22SCAL -1 Dataset Creation: Tue Oct 17 12:20:302006 Charted by: Depth in Feet scaled 160 0 LSPD (ft/min) -100 12.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 1-6.1 MTTP12 (rad) 3.4 i I/~i r.J í I) (I) !I >t ( 1/ ; ,/ 1/ l~j -'- ___M 1 l \, > \, 1\) \' L,\ l) ) [) f rl !.'> r :> ( ,)t ~ t D I, ~ [) l ' I) L I) l\¡:, 8100 ,¿"i J" (¡ I (, I~ t ~ ~ ( L) 1 ) '\ \ '\ "~'I 'I J'r ~ 1 ( (' ( / ( G 1/ ( ) I 3.5" Joint 1\ ( 5% Metal Loss \ ~ f~ ',-' -t ~¡C"ij L i"""': D~~.. \ -, -~-- 1 11 -( - -. ( li,\ ( (\ (' \ I ( 1\ I, í\" ~ ¡..;¡- ~ c/ !(, l ~ 'cC: ,K' ~ ...) 'i: < i'~'" ~ "'\, +f "''''' '''i.~ '-L, "": II '-¡ ! i-i 1\ ,J c 35" Collar8110 c: .-:-:i: if :::"- ..; -;:. ê':'C' ) f> ( r ( ') , 1'( i i m 25% ~ffi=rfft ( ) ;~ ~ ."",f ,---1 ','J! I '-, ¡-;:= Fþ ~ þ;L.. r /t / ~ .~. ¡' .. ",. /' I: 7'l~~ i'llj /II?? Ii>: ,<-.. h '} þ/ 3.5" Joint ,.- i 1 ! l t l > l ~) 1 l J /1) I ) '} I >1 I:: r Il) 8120 \11 t S l~ I) l > ) ]¡> !) i"I:\. h I I( ( I~ [ ( \ I ( It' , \ 1 i,\ 1\, V ( ( ( ( [ ( ii' \ i l 'i. i, ) r' ( ,1,\' (> ) ( Il ( ( c ( ~.. -^--- p ( J 1(1 V ( ( ( ( ] 2.1..2lL "- h. 1\ 0 LSPD (ft/min) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -66 MTTP12 (rad) 34 I I I I I I I I I I I I I I I I I I I ~. Magnetic Thickness I Log (10Hz) PR<>ÁCTIvE DiAq"""",1c SERvicES, I..." Database File: d\warrior\data\21-321\21-321. db Dataset Pathname: cut Presentation Format: 22SCAL -1 Ji1!iòSf'!! Creation: Tue Oct 17 12:20:302006 Charted by: in Feet scaled 175 10 LSPD (ftlmin) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) 3.4 r¡ .ì ¡ \ 1'"1 '. \, I'¡ " 1 ') ¡ \,) "- 1 '0" ( " i\ I( ( /1;\ ...~ !( , ~. '- r -~,- r) ? { } 1/) i ( ( ) Ie? ( I ! 9460 I 1/ ? J If' ~ :: 113 /l ~/"= ...-./ .-. __~_n_ ( --E ¡--.-¡ ( ( 3' ~ I\'~:) }- ". [2. []> ,.. 1"1, .... '~\ I,~.)/ ¿ ::) ::'~J > Line S~eed l, \1 ..~ ~ 1,;1) I :~ l (, 1£ 11) ")" 2 f"'¡ ~ r L._ i\ ",.P' r ( ./ ( ( ( ( 1(1_( ".. 3.5" Joint ". ~.- :'.\ 1\ rf ? II ) / ( > ~ ';;; I I i '¡ 9470 j , ) , D .... I) [) "- ) "- l? ) 1\ .J c"" ,/ ) ) ::::;:., ì .1;) l l. I) '1 l, I) ~~.. \) ...." j' ¿L ~")'\\ . ¡--- (¡..of ./' ~~ (~ ./ I(~ (.) <J c:' [ (II "ì ( \ 1 ( 1'1 "-.. t ¡~ , C) .J .cl ) fl .l ($ ) ! ( ( ::::'. 1 \ } 1 .r? I.r) () ./ (J I) ( J) ) I!~ I~ ~t> "~ ! 9480 Rm~ J < ~~ "'1, > I '·.~I !"'-, '.. " ..<: ? :::;1 :;;¡ ~.. Œ c-- t.. l \.." I". "- II,.,. , ·3 5" Collar - ¡---, ·"·...0. ~;:: 11 Ir' f .I ( ( ( Ie. . ':~ ( - [':'" '-' '"' -~ í;r-- -- ~ !./J ( Lí { ( J ( ( _"~m { J) J ) 2_ ) ¿ / I _¿ ( J i ./ 9490 I I 2 211' ~. ) ,) ~.~ l1 j' J j ì I t,~ I J to I) t .~ p, l" ~] l ¿ Lí~ ~ .¿ 35" Joint I~ ( .~ { I ( ç C, ~~^^ ] . ..'l ~\ .- \ p'l I $' ( j eei / (J { /' { ,> l~ I I \ I S ,I t I) ) ) c: ), I~"~: !o...j 1 n<::nn 7 f (' r ~) 0 LSPD (ftlmin) -100 2.2 MTTP01 (rad) 12.2 ·50 Delta Metal Thickness (%) 50 ·6.6 MTTP12 (rad) 3.4 I I I I I I I I I I I I I I I I I I I cI2s. Magnetic Thickness I Log (10Hz) PftOAcrlvE DiAqN05TIc SERvicE<, INC, . Database File: d\warrior\data\21-321 \21-321. db Dataset Pathname: cut Presentation Format: 22SCAL -1 Dataset Creation: Tue Oct 17 12:20:302006 Charted by: Depth in Feet scaled 160 0 LSPD (ftlmin) -100 12.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) 3.4 tf-i1 1'," il- l---- l. l t l Ie l -. C ~ I} ¿ } ¿ / t ~ U [~ ~ ( ( Line Speed 1-)- ( I~- ( -/- -- -1- _.- I) ¿ ) ;' It) Ii / ,,' I I 7680 ( ( ( ',. C /1 ! (I } ¿ ) ( (: ( / ) ( ) \".. ( / of) 1 <- /1 ( I¿ ) ( Ie: (I (! ) C: ( [ .~"- 1 1\ , I) I I .c. ij Æ':. ~'" ( ) ,j < V ,( J L I ~./~ ( t ( ( 11- '\ ~... \,'\ " -,-~-- '-:::: è } f(: I) e::~ ~ \i'¡. :) ( ~( C I ( ) :', \ ~ '<. 7 ¡.- 3.5" Joint ~= ( .::::> ( (' ) (; l) .../¡ ?= , 1 It r ::;::;¡ r ( c I 7690 1 ;; ~~I cb ~~ ) . ì, J (' (5 ¡J ~) ¿ "j 1 34% Metal Loss ¡ I( ( 1 r3 _ CJ~~ ~ l) ) "- ) .... ) D .f~;) þ If ( / I '-. -.- .-- r ) ) 1) ) Þ '''' ) ) ) [:) '0 > lJ t I I _. f., ¡.., f) \ \ \. ') i) 1 ) I) ) ) ) ¡ I ! / I I) 1 \ ? t. ) ) \ I> "- ) ) IS) I I I lì / I 1 r"l 7700 I~ \, 1,- t " I( l. "j >, 1 r> ~~, ~ \ é. ) ( \: I ~ J ..~ ,\ ¿ ,--_1(\ ,[1 (~ ! ~~. I~. it ~.... ?;. J~:=. rl rt~ ~ " >.. r..··· ,_'_~ ~~" .~. .~ I- 3.5" Collar \. l::... ~ -~,,¡ "'- J J i I"''':~ 'C < "~1: = IJ '"'c::] :tJ -¡~ J .-< ~..) :;;t~ ì 7 --. l.. I.. ) I> \, 1,,\ ~~ ) ':> I) [) ( r /- =~.. I( I) - 1..... l. j , II) , I.,,> __..2:Z.1..0.... II r) t I) j D > 0 LSPD (ftlmin) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -66 MTTP12 (rad) 34 I I I I I I I I I I I I I I I I I I I <Ias. Magnetic Thickness I Log (10Hz) ~ DlAqroosrlc SERVIces, INC. Database File: d\warrior\data\21-321\21-321.db Dataset Pathname: cut Presentation Format: 22SCAL -1 Dataset Creation: Tue Oct 17 12:20:302006 Charted by: Depth in Feet scaled 160 0 LSPD (ft/min) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) 3.4 Line ( ( ( r ( I ( ( ! ¡ ¡ ) '> " \..,'" ~ "") " '" 1 " \.\, ) / ( ì ) ( '- r-- -. ~ > \ \\ ) ~/ ? > I '" ) [> \¡ l )':1 (;' 8990 t, L l", l , ,l:; 1 ) I> '\¡ I ) I) fì [) [ ,/ ~ 1 ( ) ( (' '(/ ( I J I "\ \, ( ( [) ,i \ /) ,rJ ( '> (I I~ > . \ ( -. þ ? ( ,) ~-) LI') ( /"J J , ('/'" r.) ~/ Ir;¡ f'J ( \, ( , .rf' \ Ii % Metal Loss ~. ~ ) ) 'rJ I,) 1\.., \¡'c- 0:::::: /J ~; (1 l' 9000 I r'J "? í' ~) ~ I (~ ) I"~, ) " ) \ I) 1 "\ / (" C' :::::2, l1 I lo I) l \ ~ ~) !) /1) ) } ) i) } j /. ----^ ) ,') 1. ~!, (D c¡ ) l "? I ] ß lL - j [:::;;;0 C) ( c:, I ( (\ J ( 1'1 r) ( ( , ( I() ( (/\/ (~ ( ~ !r: ( I,) ì ') 1:\" ) 9010 "I (I ( )1 ) ) J (' ( I ¡ 1# 1 ( (~, :"1< < ,,-J ~ 'I C, "J l~ ~:," J: ,=::~? 7 I I" ~~ 3,5" Collar ~ ~"'l [ì'í '--- t'!"" r~ "'. ¡,O¡c 1 , '"' ! k) ~~~; ) _1:';= ¿ t,e] ) ~ ( ,J r~ ,-J }:: þ( ::;>.1' I!r~ , 1"/ lr- ) ~~.~ .L "._~~ r' -.-- . m~_ I C. l. ) \ [i ) ) ;J .J I ^~-- ~''¡ /" .._"-_J_ --.-,.- -.'^ f ¡ f í ( ¡ r 0 LSPD (ftlmin) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) 3.4 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf L-80 WE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2 L-321 Kuparuk ConocoPhillips Alaska, Inc. USA October 15, 2006 Joint Je Depth Pe Pen. P,·n. Metal Min. Damage Profile No. (Ft.) Body I.D. Comments (%wall) ( (Ins.) (Ins.) ° 50 100 .1 21 0 0.03 13 1 2.94 PUP Shallow oiUing. .2 24 0 0.04 Ii 2 2.92 PUP Shallow corrosion. .3 30 0 0.03 1 3 2.93 PUP Shallow oitting, ¡ .4 33 0 o .en 3 2.94 PUP Shallow corrosion. 1 38 0 0.03 It 2.93 2 73 0 0.03 I 2.92 Shallow niUinQ. 3 105 U 0.03 12 2,94 4 136 0 0.03 12 2.94 5 167 0 0,03 13 2,93 Shallow oitting. 6 198 CI 0.ü3 11 I 2.94 7 230 CI 0.02 1) I 2.94 8 261 CI 0.03 II 1 2.91 9 292 CI 0.04 17 2 2.93 Shallow nittinQ, iii 10 324 CI 0.03 n 4 2.93 Shallow niUinQ. 11 356 CI 0.02 n I 2.93 m 12 387 U 0.03 n 2 2.93 Shallow oiUing, 13 419 0 0.02 7 2 2.93 14 449 0 0.03 1 I 2.91 15 479 0 0,02 n 2 2.93 15.1 510 0 0 0 2.88 DS NIPPLE 16 512 0 0.03 3 I 2.93 Shallow corrosion. 17 544 I 0.04 16 2 2.92 Shallow corrosion. 18 575 ( 0.03 10 ( 2.93 19 605 ( 0.ü3 11 I 2.93 20 636 ( 0.03 11 2 2.94 21 667 ( 0.ü3 10 2 2.92 22 698 t 0.03 13 2 2.92 Shallow nittinQ. 23 729 0 0.03 ¡ 1 I 2.93 ¡III 24 761 I 0.03 11 2.93 Shallow corrosion. 25 792 ( 0.03 ¡ 1 2.94 26 823 ( 0.04 2.94 Shallow oittiml?:. 27 854 ( 0.03 2.93 Shallow oitting. 28 885 ¡ 0.03 1 ¡ 2.93 Shallow oitting. 29 916 0 0.02 2 2.91 ¡III 30 948 0 0.ü3 1 2.93 ¡III 31 979 ( 0.02 1) 2.93 fill 32 1010 0 0.02 7 ¡ 2.92 33 1041 0 0.04 I') 2.92 Shallow oittlng. 34 1071 0 0,03 12 I 2.93 35 1103 0 0.ü3 II I 2.92 36 1134 0 0.02 q 2 2.92 37 1166 0 0.02 C! 2 2.94 38 1197 0 0.03 1 1 2.91 39 1228 CI 0.Q2 q I 2.93 11II 40 1260 CI 0,03 II 2 2.93 41 1291 CI 0.02 9 I 2.93 42 1322 0 0,03 1 ~I 2,93 43 1354 0 0.03 10 I 2.93 44 1385 0 0.ü3 1 2 2.93 45 1417 0 0.03 I 2 2.90 Shallow nittinQ. iii Body Metal Loss Body Page 1 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: NominaILD.: 3.5 in 9.3 ppf 1.-80 EUE 8rd 0.254 in 0,254 in 2.992 in Well: Field: Company: Country: Survey Date: 21.-321 Kuparuk ConocoPhillips Alaska, Inc. USA October 15, 2006 Joint Jt. Depth PC'! Pen. Pe¡;- ! MeLd Min. Damag e Profile No. (Ft.) Body I !.D. Comments (% wall) Ins) (Ins.) (Ins.) 0 50 100 46 1448 0 0.02 q I 2.93 47 1479 n 0.03 10 I 2.92 48 1511 I¡' 0.03 In ) 2.92 49 1542 Ii 0.03 I ) 2.93 50 1573 0.04 ¡ I 2.93 Shallow Dittin2. 51 1604 ( 0.03 I I 2.93 Shallow oittin2. 52 1635 0.03 I I 2.93 53 1667 0.02 7 I 2,93 54 1698 I 0.03 1 1 2,92 55 1730 I 0.02 c ) 2.93 56 1761 0 0.03 II I 2.93 57 1792 0.03 1"1 Ie 2.91 Shallow nittiml. 58 1823 0.02 q I 2.93 59 1854 0.03 1'1 ) 2.91 ' I 60 1886 0.03 II j 2.92 61 1916 I 0.03 1 2 2.93 62 1947 0.03 i 1 2.91 Shallow corrosion. 63 1978 I 0.03 I) ) 2.93 64 2010 0,02 q ) 2.93 65 2040 0 0.03 I 1 2.93 66 2071 0 0.02 q I 2.93 67 2102 0.03 11 ) 2.93 68 2134 0.03 11 I 2.93 69 2165 I 0,03 0 2 2.92 70 2196 i 0,02 q I 2.93 71 2228 0 0.03 12 2.92 ¡¡II 72 2259 II 0.03 1 2.93 !II 73 2290 0 0.04 I 2.93 Shallow corrosion. 74 2321 0 0.03 1 e 2.94 Shallow oittin2. 75 2353 0.03 I 2 2.93 76 2383 0 0.04 1 :2 2.92 Shallow corrosion. 77 2414 0 0.02 q I 2.90 78 2445 IT 0,02 I 2.93 79 2476 iI' 0.04 I):¡- I 2.91 Shallow nittin2. 80 2508 il 0.03 iO 1 2.92 81 2540 0 om q ) 2.93 82 2571 0 0.03 H ) 2.93 83 2602 0 0.03 I :2 2.93 84 2633 0 0.03 I ¡ 2.92 Shallow oittin2. 85 2664 0 0.03 I 2,93 86 2696 () 0.03 I ) 2,93 87 2727 II 0.03 II 2.93 Shallow nittiml, 88 2758 il 0.04 1'5 2.93 Shallow niUing:. 89 2789 0 0.02 II :2 2,92 90 2821 0 0.03 1 2 2.91 Shallow corrosion, 91 2852 U 0.03 I .2 2.93 92 2883 () 0.02 I I 2.93 93 2915 0 0.03 I '\ 2.92 94 2946 0 0.03 10 ) 2.93 95 2978 0 0.02 9 2 2.93 Penetration Body Metal Loss Body 2 I I I I I I I I I I I I I I I I I I PDS REPORT NT TABULATION SH Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf L-80 fUE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Date: 2L-321 Kuparuk ConocoPhillips Alaska, Ine. USA October 15, 2006 Joint Jt. Depth PCTI Pen. Pen ¡\Aeral Min. Dan lage Profile No. (Et.) Body J.D. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 96 3009 0 0.03 10 1 2.92 97 3040 0 0,02 9 2.93 98 3071 0 0.02 7 2.94 99 3103 0 0.ü2 9 2.93 100 3134 0 0.04 14 2.93 Shallow corrosion. 101 3165 0.03 13 'j 2.93 Shallow oittím;¡. 102 3197 ( 0.03 ] 2 2.93 103 3228 0.03 1\ 2 2.93 104 3259 U 0.04 I 2 2.91 Shallow pitting. 105 3291 ( 0.03 I 2 2.92 106 3322 0 0.03 1 2.92 Shallow pitting, 107 3352 0 0.03 1 2.93 108 3383 0 0.03 13 2.92 Shallow oittim!. 109 3415 0 0.03 11 2.92 110 3446 () 0.03 I 2,93 111 3477 0 0.03 2 2.93 112 3508 0 0.03 2 2.93 113 3540 0 0.04 2.92 Shallow corrosion. 114 3571 0 0.03 11 2.92 115 3602 0.03 11 2.93 116 3634 0.03 10 2.92 117 3665 1 0.03 11 2 2.92 118 3696 ( 0.03 12 2.91 I 119 3728 0 0.04 16 2,92 Shallow corrosion. 120 3759 0.04 1'1 2.93 Shallow pittim!. I 121 3790 ( 0.03 12 2.93 122 3822 0 0.03 11 2.91 123 3850 0.02 9 2.93 124 3881 0.04 11 2.93 Shallow oitting. 125 3912 0.02 9 I 2.93 I 126 3943 0.04 1 2.93 Shallow corrosion. Lt. Deposits. 127 3975 0.03 1\ 2.93 128 4006 0 0.03 I 2.92 129 4038 0 0.03 13 2.92 Shallow pitting. 130 4068 0.02 9 2.93 131 4099 0 0.03 I 2.94 Shallow oittim;¡. 132 4131 0 0.02 e 2.92 133 4162 0 0.03 I ¡ 2.94 Shallow corrosion. 134 4193 0 0.04 1·1 2 2.92 Shallow oitting. 135 4225 U 0.03 I 2.91 Shallow pitting. 136 4256 U 0.03 12 2.93 Shallow pitting. 137 4287 ( 0.03 11 2.94 138 4319 ( 0.04 14 2.91 Shallow oittim!. 139 4350 ( 0.03 11 2 2.93 140 4381 ( 0.02 e 2 2.93 141 4412 ( 0.03 11 2.92 142 4444 ( 0.03 13 2.92 Shallow pitting. 143 4475 0 0.03 11 2.91 144 4504 (1 0.03 12 2,92 145 4535 0 0.01 13 2 2.91 Shallow pitting. ~F Body Metal Loss Body Page 3 I I PDS REPORT JOINT TABU ON SHEET I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 WE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2L-321 Kuparuk ConocoPhil!ips Alaska, Inc. USA October 15, 2006 I Joint Jt. Depth Pen Pen. Pen "A,'tal Min. Damag e Profile No. (Ft.) Body I.D. Comments (% wall) (Ins) (Ins.) (Ins.) 0 50 100 146 4567 ( 0.03 1 () I 2.92 147 4598 ( 0.03 11 2 2.92 It Deoosits. 148 4629 ( 0.02 7 t 2.93 149 4661 0.03 1 \ 2.92 Shallow oittimI. 150 4692 0 0.03 2 2.93 U. Denosi ts. 151 4722 0 0.03 2.93 152 4754 0 om 2.93 153 4785 0.02 ') 2.92 154 4816 0.03 1 2,91 155 4848 0.03 It 2,89 156 4879 i 0.03 11 2 2.89 Shallow corrosion. 157 4911 0 0.03 I' 2 2.91 158 4942 0 0.03 1 2.91 159 4973 0 0.02 2.93 160 5004 0 0.02 2.92 161 5036 0 0.02 2.93 162 5067 0 0.03 t2 2.91 Shallow oittiml, 163 5097 0 0.03 1.\ I 2.94 Shallow corrosion. 164 5128 t1 0.02 9 2 2.92 165 5159 0 0.02 II 2 2.94 166 5190 0 0.04 17 2 2.92 Shallow corrosion. II 167 5222 0 0.03 11 2.91 168 5253 t 0.02 9 2.91 169 5284 t 0.03 II 2.92 170 5316 ( 0.03 12 2.92 171 5347 i 0.03 13 2 2.93 Shallow oittim;¡. 172 5379 0 om 1) 3 2.92 173 5410 0 0.02 2 2.90 174 5441 0 om 11 2 2.92 175 5472 0 0.03 10 2 2.92 176 5504 ( 0.03 '1 'j I 2.93 177 5534 ( om 10 .2 2.93 178 5566 I 0.03 11 2 2,94 179 5597 ) 0.02 ') j 2.93 180 5628 0.D2 ') .2 2.94 181 5660 0 0.03 t 2.92 Shallow oíttinll:. 182 5691 0 0.03 1 2.93 Shallow oittinll:. 183 5722 0 om I 2.93 Shallow corrosion. 184 5753 0 om ~¡ '1 2.93 185 5785 0 0.03 10 2.91 186 5816 0 0,03 12 2 2.93 187 5847 0 0.02 ') 2 2.92 188 5878 0 0.04 I ¿( 2 2.93 Shallow nitting. 189 5909 0 0.03 n 2 2,92 Shallow corrosion. W 190 5941 n 0.04 IS 1 2.93 Shallow nittinQ. 191 5973 ( 0.03 11 2 2.93 192 6003 ( om II 2 2.93 193 6034 ( 0.03 12 3 2.94 194 6066 ( om 11 '1 2.92 195 6098 0 0.03 P ') 2.92 Shallow corrosion. I I I I I I I I I I I I I Penetration Body Metal Loss Body Page 4 I I I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH 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 Well: Field: Company: Country: Survey Date: 21.-321 Kuparuk ConocoPhillips Alaska, Inc. USA October 1 5, 2006 Joint Jt. Depth 1\'1 Pen. Pen ·\le1,,1 Min. Damage Profile No. Body I.D. Comments (%wall) (Ins (Ins.) (Ins.) 0 50 100 196 6129 0.D3 1 2.92 197 6161 1 0.D3 I) 2.93 Shallow corrosion. 111 198 6193 ( 0.04 2 2,92 Shallow corrosion. 199 6224 0.04 ! i 2 2.92 Shallow Ditting. U. Denosits. I 200 6255 n 0.04 T ) 2.92 Shallow corrosion, 201 6287 !) 0.03 If ) 2.93 202 6319 n 0.03 ( 1 ') 2.92 203 6350 n 0.02 9 ) 2.92 204 6382 11 0,04 1 :1 2.93 Shallow [¡itting. 205 6414 U 0.05 1 'i 2.93 Shallow corrosion. 206 6445 n 0.02 ( 4 2.92 207 6477 n 0.04 1 2.90 Shallow corrosion, It. Denosits. 208 6508 (¡ 0.02 (J 2.91 209 6540 (¡ 0.03 11 2.92 Shallow corrosion. Lt. Denosi ts. 111 210 6572 U 0.04 "7 2.91 Shallow corrosion. I.t. Denosits. 211 6604 0 0.02 , 2.92 211.1 6635 0.03 2 2.93 PUP 211.2 6650 U 0 U NJA GlM 1 (latch @ 10:30\ 211.3 6658 iT 0.04 Hi ~¡ 2.89 PUP Shallow corrosion. Lt, Denosits. 212 6671 U 0.03 Ii ) 2.92 Shallow nitting. Lt. Denosíts, ~ 213 6702 U 0.04 I) ) 2.94 Shallow corrosion. 214 6734 n 0.04 16 ') 2.93 Shallow corrosion. I 215 6765 () 0.03 ) 2.92 U, Denosi ts. 216 6797 U 0.03 '! 2.92 Shallow oittim2. 217 6829 () 0.03 I 2.92 fII 218 6860 0.03 1 2 2.92 1.1. Deoosits. fII 219 6892 0.03 i 2.91 fII 220 6924 0.02 q 2.92 221 6955 ( 0,03 Ii ( 2.91 Shallow corrosion. Lt. Denosits. 222 6987 () 0.D3 1 2,94 223 7018 () 0.04 1 ( 2,93 Shallow oittím¿. 224 7049 n 0.03 1 2 2.93 225 7081 0 0.02 c 2 2.93 226 7112 !) 0.04 14 2.92 Shallow corrosion. 227 7143 n 0.04 14 2.92 Shallow nitting. 228 7175 () 0.04 16 2.91 Shallow níttí¡1QI. 229 7206 () 0.02 I) 2.93 230 7238 0.03 13 2.91 Shallow oittim!. 231 7269 0.D3 I 2.93 232 7300 U 0.03 1 ^ 2 2.92 233 7332 U 0.03 12 I 2.93 234 7363 U 0.02 B 2 2.92 235 7394 () 0.03 11 1 2.92 ~ 236 7425 n 0.04 17 I 2,93 Shallow corrosion. 237 7457 n 0.04 14 1 2.92 Shallow corrosíon. 238 7488 U 0.02 ) 2.92 239 7518 U 0.03 1 ) 2.93 240 7549 U 0.03 2 2.92 241 7581 n 0.02 ) 2,93 242 7611 !I 0.02 if I 2.91 Body Metal Loss Body Page 5 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf L·80 EUE 8rd 0.254 in 0.254 in 2.992 in Well: Field: Company: Co un try: Survey Date: 2L·321 Kuparuk ConocoPhíllips Alaska, Inc. USA October 15, 2006 Joint Jt. Depth Pc Pen. p'c'n. ,Vletal Min. Damag e Profile No. (Ft.) 'I Body 1 1.0. Comments (% wall) I (Ins.) (Ins.) 0 50 100 243 7643 0 0.03 12 2 2.95 Shallow oittim2:. 11II 244 7673 0 0.02 9 I 2.93 11II 245 7705 0 0.03 1 ¡ 2,92 Shallow pitting. 11II 246 7736 0 0,03 ID I 2.94 247 7767 0 0.03 13 I 2.93 Shallow pittim:!. Ii!J 248 7799 0 0.ü2 7 I 2.93 %!1 249 7830 0 0.D3 11 4 2.93 250 7861 0 0.03 II ;; 2.91 I t. Deposi!s. 251 7892 0 0.03 3 I 2.93 Shallow pitting. 252 7925 0 0.03 11 4 2.93 253 7955 0 0.03 0 2.92 254 7986 0 0.03 I 2.94 255 8017 0 0.03 ¡ 2,91 256 8049 0 0.02 9 2.92 257 8079 0 0.03 10 I 2.93 258 8110 0 0.04 \4 ;; 2.93 Shallow oittim:!. 259 8142 0 0.D3 10 ¡ 2.93 260 8173 I) 0.03 1 ;; 2.93 261 8203 0 0.D3 1 ) ;; 2.93 262 8235 0 0.02 c ;; 2.93 263 8266 0 0.04 I 2.93 Shallow corrosion. ill 264 8297 0 0.D3 3 2.93 Shallow corrosion. 265 8326 0 0.03 11 2.93 266 8357 0 0.03 12 2.93 267 8388 PI 0.02 9 2.95 268 8420 0 0.03 ¡ ;; 2.92 Shallow corrosion. 269 8452 ( 0.03 1 2 2.93 Shallow pittinQ. 270 8481 0.03 1 I 2.93 271 8512 0.03 I 2.93 272 8546 0.02 9 2.93 273 8578 0 0.02 9 2.93 274 8610 0 0.02 a 2.91 275 8641 0 0.03 1 2.93 276 8672 I 0.02 9 2 2.94 277 8703 0,02 9 7 2.94 278 8734 0.D3 1 2.94 Shallow pittin\!.. 279 8766 0.D3 1) 2.94 280 8798 U 0.01 6 2.93 281 8828 U 0.02 2.92 282 8860 U 0.03 11 ;; 2.93 283 8891 U 0.02 9 ;; 2.92 284 8923 U 0.02 9 ;; 2.93 285 8953 0 0.03 1'3 ;; 2.93 Shallow pittinQ. 286 8985 0.02 9 I 2.93 287 9016 ( 0.03 13 7 2.93 Shallow corrosion. 288 9047 ( 0.03 11 ;; 2.93 I 289 9078 ( 0.04 "j¿ 3 2.93 Shallow corrosion. 290 9110 0 0.03 I ;; 2.94 Shallow pitting. 291 9142 U 0.02 9 ;; 2.92 292 9173 0 0.04 1 I 2.93 Shallow pittimz. Penetration Body Metal Loss Body Page 6 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: Nominal I.D.: 3,5 in 9.3 ppf L-80 WE 8rd 0.254 in 0,254 in 2.992 in Well: Field: Company: Country: Survey Date: 2L-321 Kuparuk ConocoPhillips Alaska, Inc. USA October 15, 2006 Joint Jt. Depth Pen. Perr \·1elal Min. Damage Profile No. (Ft.) Body ID. Comments (%wall) ( (Ins.) (Ins.) 0 50 100 293 9204 ( 0.02 3 2.94 294 9235 0.02 .2 2.92 295 9266 0.03 ) 2,92 296 9297 ¡ 0.03 OJ 2.93 Shallow nittinp. 297 9329 II 0.03 II 2,93 298 9360 )j 0.03 I) 2,93 299 9392 () 0.03 ¡f)" 2.92 300 9421 () 0.02 B 2.93 301 9452 () 0.03 II I 2.93 302 9484 0 0.03 II 'i 2.92 303 9516 () 0.03 II 2.91 304 9547 0 0.02 B 2.94 305 95711 )j 0.03 i 2.92 Shallow nittinQ. 306 9609 ( 0.03 11 2.93 307 9639 () 0.03 12 2.94 308 9670 () 0.03 11 2.93 309 9702 0 0.03 I ;; 2.93 310 9733 () 0.02 9 ;; 2.94 311 9764 (¡ 0.03 I ;; 2.94 Shallow Dittim~. 312 9796 0 0.02 7 , 2.96 . 313 9828 () 0.02 7 ) ~ 314 9858 () 0.03 Ii ) 315 9891 I 0.02 p j 2.95 316 9921 0.02 l' 2 2.93 317 9953 0.02 q I 2.93 318 9984 0.03 I) .2 2.94 319 10016 ( 0.03 I j 2,92 320 10047 () 0.02 i) ¡ 2.93 321 10078 0 0.04 14 ) 2.93 Shallow nittinQ. 322 10110 () 0.03 1.2 2 2.91 323 10140 0 0.03 I .2 2.94 324 10172 0 0.03 I 2 2.95 325 10202 0 0.04 ¡ 2 2.93 Shallow Dittim~. 326 10235 0 0,02 ( 2 2.94 327 10266 0 0.03 1, 1 2.96 328 10297 Ö 0.03 f 2.95 329 10329 I 0.02 R 2.95 330 10360 () 0.04 16 2.93 Shallow nittinQ. ¡II! 331 10392 0.02 11 2.96 332 10423 0.03 1 2 2.93 333 10454 0.02 q 2 2.94 334 10484 0.03 1 2 2.91 Shallow oitûm;¡, 335 10517 0.02 q I 2.94 336 10546 0 0.04 17 .2 2.92 Shallow nittinQ. III 337 10579 0 0.02 ij .2 2.95 338 10610 0 0.03 13 2 2.96 Shallow oittinQ. !II' 339 10641 ( 0.03 I 2.93 !II 340 10673 ( 0.03 I 2.92 ¡II! 341 10705 0 0.02 ( 2.93 !II 342 10736 0 0.03 1) 2.93 Penetration Body Metal Loss Body Page 7 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION S Pipe: Body Wall: Upset Wall: NomínaII.D.: 3.5 ín 9.3 ppf l-80 WE 8rd 0.254 in 0.254 in 2.992 in Well: Fíeld: Company: Country: Survey Date: 2l-321 Kuparuk ConocoPhíllíps Alaska, Inc. USA October 15, 2006 Joínt Jt. Depth 1\'11. Pen. Pen. ! !;¡/;Ie!I Mín. Dan ¡age Profile No. (Ft.) Body IJJ. Comments (%wall) (1IiS) (Ins.) (Ins.) 0 50 100 343 10766 0.04 15 2 2.92 Shallow nittin<>, if 344 10799 0.02 ( 2,91 345 10829 0.03 1 2.93 346 10861 0.02 ( 2.93 347 10892 0 0,03 10 2.93 348 10923 I) 0.02 q 2.91 349 10955 0 0.02 2.92 350 10985 0 0,02 I 2.93 351 11017 0 0.04 17 2 2.91 Shallow corrosion. 352 11048 0 0.02 1 2.91 353 11079 0 0.03 ] 2,92 354 11111 0 0.04 2 2.92 Shallow corrosion. 355 11141 0 0.03 11 2.93 356 111 72 0 0,04 1 2,94 Shallow níttínQ. 357 11203 0 0.02 2.94 358 11234 () 0.02 2.92 359 11264 0 0.02 2 2,94 360 11296 0 0.03 0 2 2.92 360.1 11325 n 0 I () 2.81 SLIDING SLEEVE 361 11332 ( 0.03 1) 2.91 Shallow nittínQ. 11II 361.1 11363 () 0.02 .j 2.91 PUP 11II 361.2 11377 n 0 () I N/A GlM 2 (latch @ 10:0m 361.3 11384 ( 0.03 3 2.92 PUP Shallow oittinQ. ~ 362 11396 0.03 I 2.93 iii 362.1 11 42 7 0 () N/A CA-2 PLUG 362.2 11435 ( 0 () 2.75 D NIPPI E 362.3 11440 ( 0.01 3,00 PUP 362.4 11451 n 0 0 N/A Seal Assemblv 362.5 11459 0.04 1 2.89 PUP Shallow níttínQ. It. Denosíts. 363 11467 0.03 1 2.94 364 11498 0.05 ¡ 2.93 Shallow oittin\!. 365 11530 ( 0.03 If 2 2.94 End of lo\!. Body Metal loss Body Page 8 I I TUBING (0·11454, OD:3.500, I ID:2.992) SURF CASING (0-3302, OD:7.625, I Wt:45.50) I PROD CASING (0-11454, OD:5.500, Wt:15.50) I I Gas Lift I ndrêllDummy Valve 1 (6646-6647, ODA.725) I I SLEEVE·C 11323-11324, 00:4.600) I Gas Lift I ¡ ndreliDummy Valve 2 1137:>-11374, 00:4.725) I PLUG I 11425-11426, 00:2.750) NIP 11425-11426, 00:4A70) I I I SEAL 11454-11455. 00:4 oooj LINER I 11454-12380, 00:3.600, Wt:9.30) Perf == = 11680-11720) -- I _. ~_..- - t-- --- I-- I KRU 2l-321 2L-321 API: 501032028600 SSSV Type: NIPPLE Well Tvpe: PROD Orig 1/12/1999 ComDletion: Last W/O: RefLoo Date: TO: 12403 flKB Max Hole Anole: 70 deo (â) 6345 Anole (â) TS: deo (â) Angle@ TO: 57 deg @ 12403 Annular Fluid: Reference Loo: Last Tao: 11716' RKB ~1\~~6/2006 Descriooon CONDUCTOR SURF CASING PROD CASING UNER Tj¡.,......"'...,...... Size I Ton Bottom ~O I 11454 , 11:80 - 11720 5489 - ~5" i ZO.8 is'''', fi ¡S::F ¡ W~m99 I ,¡~:' i~;;; ~hC ':¡:,::::::,,,, 60 Gas St MD TVD Rev Reason: SET PLUG Last Update: 7/27/2006 Size 16.000 7.625 5.500 3.500 TOD Bottom TVD Wt Grade Thread 0 108 108 62.58 H-40 WELDED 0 3302 2288 45.50 L-80 BTC-MOD 0 11454 5359 15.50 L-80 LTC-MOO 11454 12380 5878 9.30 L-80 EUE-8RD I TVO I Wt I Grade Thread 5359 9.30 , L-80 EUE-8RD Man Man Type V Mfr V Type V OD Latch Port Mfr 1 6646 3500 CAMCO KBG29 CAMCO DMY 2 11373 5313 KBG29 CAMCO DMY .....i '" /"~J" DeDtn TVD T1IDe- 512 512 NIP CAMCO OS NIPPLE 11323 5285 SLEEVE-C BAKER CMU SLIDING SLEEVE - CLOSED 7/22/2006 11425 5342 PLUG SET 2.75" CA-2 PLUG ON 7-26-2006 11425 5342 NIP CAMCO D NIPPLE 11454 5359 SEAL BAKER 80-40 SEAL ASSY INCltÐS Date Note 118/2000 Pumped 150 BBLS hot diesel down IA. 7/24/2006 PRODUCTION CASING LEAK TO FORMATION (â) 8400' TRO 1.0 1.0 o o Date Run 1/12/1999 ~ 1112/2001 Vlv Cmnt !NT INT 0.000 0.000 DescriDtion ID 2.875 2.813 0.000 2.750 2.985 08/09/06 SCblumbepgep RECEIVED ...;:r',", ¡o.¡,,¡'-''''' nIUG'; ?1'1ï!i~ ~.,3V)~P(;,t:~.j Iii ..L I..:: J--JULJ NO. 3910 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth AUG 1 0 2005 .\¡'~~ OH & I'::;~ Cons. Commissìcn Anchorage Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 10~ -d~8 Field: Kuparuk Well Job # BL Color CD Log Description Date 1J-127 11216302 US IT 06/05/06 1 10-119 11249924 INJECTION PROFILE 07/05/06 1 2L-321 11235382 LDL 07/24/06 1 2V-13 11235385 SBHP SURVEY 07/26/06 1 1Q-13 11249936 INJECTION PROFILE 08/02/06 1 1 Q-26 11249937 PROD PROFILE W/DEFT 08/03/06 1 1R-14 11235386 PROD PROFILE W/DEFT 08/03/06 1 1 G-09 11249938 INJECTION PROFILE 08/04/06 1 3N-16 11235389 sBHP SURVEY 08/05/06 1 1 E-112 11285935 MEM INJECTION PROFILE 08/05/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Re: Jet Pumped Wells Subject: Re: Jet Punlped ¥lells From: "NSK Problem Well Sup"" <n 1617@)conoeophil1ips.com> Date: Sat, 7 Dee 2002 14:07:01 -0900 To: TOOl Iv-taunder <tom_maunder@'adolin.state.ak.us> CC: "n 1617" <n 1617(@conocophillips.com> Tom: 1 requested a list of surface powered jet pump wells from our PEls. The followlng should be the current total for the Kuparuk area: West Sak wells: 1C-123 ~PTD 2010840) was recently 51 for high watercut 1C-135 (PTD 2012200) is a huff and puff well and was recently put on water injection cycle CPF 2 are as follows: 2L-307 (PTD 1982560) 2L-313 (PTD 1982190) 2L-315 (PTD 1982180) ~ 2L- 321 (PTD 1982620) , 2 L - 3 2 5 (PTD 198 2 0 9 0 ) 2N-303 (PTD 2001690) 2N-304 (PTD 2011300) 2N-305 (PTD 2001350) 2N-318 (PTD 2001000) 2N-319 (PTD 1981970) 2N-332 (PTD 2000790) 2N-337 (PTD 1981220) 2N-339 (PTD 1981000) 2P-415 (PTD 2012260) There are no surface powered jet pump wells at CPF3. I hope this answers your question. Let me know if you need more information. Jerry Dethlefs ConocoPhillips Problem Well Supervisor Tom Maunder <t.:..:orn maundE:pii'ddmin. state. êl~:. us> 12/06/2002 09:00 AM To: NSK Problem Well Supv/PPCQ@Phillips cc: Subject: Jet Pumped Wells Pete and e,r Jei.-l-Y r I have some emails from a while back regarding the wells out there on jet pumps. Would you please Provide an updated l.L"st~ng - t 1 ... 0 t t le we 11 s present y on jet pumps in greater KRU?? Thanks in advance. To Casing Detail 7.625" Surface Casing (qt~ èL9~ ARca Alaska, Inc. # ITEMS Subsidiary of Atlantic Richfield Company jtS. 55-77 jts. 3-54 jts 1-2 COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 141 RKB to LR = 28.501 Above RKB 7 5/811 Landing Joint FMC GEN V- Prudhoe 7 5/811 Csg Hgr 75/811,29.7#, L-80 BTC-mod(23 jts) TAM 7 5/811 Port Collar 75/811,29.7#, L-80 BTC-mod (36 jts) Gemeco Float Collar 75/811,29.7#, L-80 BTC-mod(2 jts) Gemeco Float Shoe Casing shoe @ T.D. @ 33101 leaving 81 of rathole 5 Gemeco Bow SprinQ CENTRALIZERS Run centralizers in center of Jts. 1, 2, 54, 55, over stop collars and over collars of jt 74, UNABLE TO RUN FULL COMPLEMENT OF CENTRALIZERS DUE TO EXTREMELY BAD HOLE CONDo Joints 78-85 (8 joints) will remain in the pipe shed. WELL: TARN 2L-321 DATE: 12/31/98 1 OF 1 PAGES LENGTH DEPTH TOPS 28.50 2.69 974.41 2.41 2211.99 1.32 79.23 1.50 Remarks: String Weights with Blocks: 85K Up, 60K On, 12k Blocks. Ran 77 joints of casing. Drifted casing with 6.75011 plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Drilling Supervisor: R. W. SPRINGER ~CA\NNE[j) ~~A~ 1 5 2004 28.50 31.19 1005.60 1008.01 3220.00 3221":3.2 3300.5~ \3302.0$ \ '-../ ~~ ~" ARCa Alaska, Inc. Well Name: 2L-321 Rig Name: DOYON 141 Cementing Details Report Date: 01/01/98 AFC No.: AK9773 Report Number: 6 Field: TARN Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: I LC Depth: % washout: 7.518 9-7/8 3302' 3220 Centralizers State type used, intervals covered and spacing Comments: BOW SPRING ON JTS 1,2, 54, 55 76 OVER STOP COLLARS SEE REMARKS Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 10.0 46 30 56 26 REDUCED VIS F/200+ TO 100 Gels before: Gels after: Total Volume Circulated: 22/40 14/38 1200 BBL Wash 0 Type: Volume: Weight: Comments: ARCO 847 17 BBL 8.5 Spacer 0 Type: Volume: Weight: Comments: ARCO 845 40 BBL 10.5 i Lead Cement 0 Type: Mix wtr temp: N10f sa1ks: I Weight: Yield: Comments: ASIIILW 75 595 j 10.7 4.44 Additives: \.. ..j G W/30% D53, .6% D46, 1.5% D79, 1.5% 5001, 50% D124 Tall Cement 0 Type: Mix wtr temp: \' of sac~r I Weight: Yield: Comments: G 75 235 15.8 1.16 Additives: '\"'" / Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. WI. Up: Comments: 6BPM 6BPM 85 Reciprocation length: Reciprocation speed: Str. WI, Down: 6' 6'/MIN 60 Theoretical Displacement: Actual Displacement: Str. WI. in mud: 148 148 Calculated top of cement: CP: Bumped plug: I Floats held: CMT TO SURFACE Date:12/31/98 YES YES Time: 1740 Remar1<s:11 HOURS TO RUN CSG, REDUCED NUMBER OF CENTRALIZERS DUE TO EXTREMELY BAD HOLE CONDITIONS. WOULD HAVE BEEN UNABLE TO GET CSG DOWN WINORMAL CENTRALIZER PROGRAM. FULL RETURNS THROUGHOUT JOB. .--~ Cement Company: Rig Contractor: IAPproved By: DS DOYON R. W. SPRINGER ~~ ~" ARCO Alaska, Inc. AFC No. AK9773 Date 12/31/98 Well: 2L-321 RptNo 6 Depth (MDITVD) Daily Cost $ 153616 Last Csg: 7-5/8" 3302' Rig Accept - hrs 12/26/9812:00:00 PM Days Since AccepUEst: 5.5 I Contractor: DOYON Rig Name: DOYON 141 Operation At 0600: TESTING BOPE. Upcoming Operations: FINISH TEST BOPE. CUT DRLG LINE, MIU BHA. TEST CSG, LOT, DRILL AHEAD 3310/2290 Prev Depth MD: 3310 Cum Cost $ 717438 Next Csg: 5-1/2 X 3-1/2" 11307' MUD DATA MUD TYPE LSND DRILLING DATA DEPTH WEIGHT 10.0ppg VISCOSITY 97sqc ROTWT PUWT PVIYP 30 I 26 GELS 14/381 APIWL 6.6 HTHP WL mV30 min SOLIDS 11.0% HOLE VOLUME 153bbl MBT 22.5 ph 8.5 LGS 86.27% SOWT AVG DRAG MAX DRAG TRO BTM TRO OFF PUMP PRES III PUMP NO 1121 I LINER SZ 61611 SPM 1 III PIT VOL 0 GPM2 III DAILY MUD $2096 SPS 1 III TOTAL MUD SPP 1 $88121 III COMPANY MUDWT BAROID 10.2111 TIME END HOURS 12:00 AM 12:30 AM 0.50 12:30 AM 01:30 AM 1.00 01 :30 AM 11 :30 AM 10.00 11:30 AM 03:00 PM 3.50 03:00 PM 06:00 PM 3.00 BIT NO. 4R1 SIZE 6.75 MAKE HYC TYPE STR554 SERIAL NO 1901317 DEPTH OUT DEPTH IN 3310 FOOTAGE 0 ADTlAST I WOB2 RPM 1 TFA JETS 13 1131131131 I BIT COST 0.00 DULL III GRADE III CASG CASG CEMENT 06:00 PM 06:30 PM 0.50 CEMENT 06:30 PM 08:30 PM 2.00 NU_ND 08:30 PM 09:30 PM 1.00 NU_ND 09:30 PM 12:00 AM 2.50 NU_ND 24.00 Daily Drilling Report: 2L-321 12/31/98 BIT DATA SIT NO. SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOTAGE ADT/AST I WOB2 RPM 1 TFA JETS 11111 BIT COST DULL III GRADE III HOLE SECT SURF SURF SURF SURF SURF SURF SURF SURF SURF EH&S INCIDENT N EMPLOYER SPILL N TYPE VOLUME LAST SAFETY MTG 12/31/98 INJECTION INJECTION WELL 2L.325 SOURCE WELL 2L-321 RATE (bpm) 2.5 PRESSURE (psi) 650 INJECTION FLUIDS Water Base Muds 971 Fresh Water 65 Diesel 30 Cement 60 0 TOTAL VOL (bbl) 1126 TOT FOR WELL (bbl) 11833 PHASE OPS Other Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Other Other Other Other Daily Drilling Report Rig Relase - hrs: Progress: 0 Est Cost To Date $ Shoe Test: DRILLS/BOP DATA LAST BOPIDIVERT LAST BOPIDRILL TST 12/26/98 LAST H2S DRILL 12/02/98 LAST CONFINED SPACE LAST FIRE DRILL 12/22/98 LAST SPILL DRILL 12/31/98 FUEL & WATER FUEL USED 2800 DRILL WATER USED- BBLS POTABLE WATER USED - BBLS 1750 167 WEATHER & PERSONNEL DATA TEMP OF -21 WIND SPEED WIND DIRECTION 45° CHILL FACTOR of -26.66 ARCO PERSONNEL CONTRACTOR PERSONNEL 27 MISC PERSONNEL 5 SERVICE PERSONNEL 15 TOTAL OPERATIONS FROM 0000 - 0000 FINISH POH. CLEAR FLOOR & RIU TO RUN CSG & PJSM. 48 RUN 7-5/8" CASZNG, SLO fWNNINGJ?.~E TO WASHING DOWN. "" CIRC & COND;¡;: N MUD WHILE RECIPROèf(IlNG PIPE, DROPP V 1200-100 SEC. "\ §. MP'5 SX LEAD CMT, SPACER TO SURFAC 0 WED BY 235 SX TAIL CMT, CMT TO SURF ,!d' PED PLUGS W/CALC DISPLACEMENT, FL \.ILL RETURNS THROUGHOUT. LID.PEMENTING HEAD, LD"G.J:r..-g' LEAR FLOOR. NID ÖIV.es,!~~y.s:reM:"'- NIU CSG HEAD, TBG SPOOL & ADAPTER SPOOL, TEST HEAD TO 1000# F/10 MIN-OK. NIU BOPE. Supervisor: R.W. SPRINGER Page 26 CASING TEST and FORMATION INTEGRITY TEST Well Name: 2L-321 Date: 1/1/1999 Supervisor: R.W. SPRINGER Casing Size and Description: 75/8", 29.7 ppf, L-80, BTC Casing Setting Depth: 3302 TMD 2,290' TVD Mud Weight: 9.1 ppg EMW = Leak-off Press. + MW 0.052 x TVD Hole Depth: 2,298' TVD 825 psi + 9.1 ppg LOT = (0.052 x 2,298') EMW = 16.0 ppg Fluid Pumped = 0.7 bbl Pump output = 0.1010 bps ~TIME LINE ,I I I ! I - lONE MINUTE TICKS I I' I I I '' " I 'I' 'I' I' I I tf-!....,. .... ' . 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 J ' I I I I, I I I I I 1 I ! ¡ I I I I I ,. I I I I I """'LEAK-OFF TEST I : I , I I ! I I I f --L . I -'-CASING TEST ! I I' I I I I ! I , I I --<\0--- LOT SHUT IN TIME + ! I ill I ¡ -Á- CASING TEST SHUT IN TIME I" , ¡ I -+-TIME LINE I + 1'\ I I i I I[ j, I i I i!l ; I I I TIT I I I I i '~ I ~"I I . I 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1 ,900 psi 1,800 psi 1 ,700 psi 1,600 psi 1,500 psi W 1,400 psi a: 1,300 psi ~ 1,200 psi æ 1,100psi a: 1,000 psi a. 900psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 46 50 52 54 56 56 60 62 64 66 68 70 72 74 76 78 80 82 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR FIT STROKES PRESSURE CSG TEST STROKES PRESSURE E=~f~~~=i~~ r:=~;i~~~~~E~ii~ ! ! 2 stks ! 93 psi I ! I 2 stks I 90 psi I I-----------~-------+-------------I ~-------------~--------------~---------------~ L--------L-!..stk!_--L-~~~J?~~--JOcj)------------------L----~-~~-~~----~--_!?qJ?_~~---j ! ! 4 stks ! 505 psi I or-' ! 4 stks I 310 psi! r-----------'--5 stks--T-655iišT1$" 0-----------------'----5 stks----r---¡sõ--p-sT"-1 t-;-----~-----1-6-štks---T--699-p-sT"ï.1 ç t------------------1-----S-šti(s----t--Ëf9«Yp-sii ttz.-:t~ ~_i_- 7 stk!_--__t=~~fp_~~=j i._-===~~~=~-=t~~~I~~~~~==t__Æ~_q_p~~-j ! ! ! ! ! ! 8 stks ! 1 ,060 psi! I--------,----------+------------ ~---------------t---------------i-------------:--I ! ! ! ! ! ! 9 stks ! 1 ,170 PSI! r----."-----,----------..,..--------------" r----------------T---------------.,-----------------r ! ! ! ! ! I 10 stks ! 1 ,320 psi! .---------..----------~-------------.. -..-------------------.-----------------¡---------------..... ! ! ! ! ! ! 11 stks I 1 ,450 psi! [=====~=l=~=~=~~=~~~~~t~~=~~===~=J [=~~=~~====r--~~~~~=~~t~1~~Q~R~lJ ! ! ! ! ! ! 13 stks ! 1 ,960 psi! ~-=~=~-=~1=-==-~=-~~L~~~~~~=~~~=~~~~ r~~~~~~~~~~~~=~~~~l=j~~~~~~~~~¡=~~~~Q~R~_C~ I I I I I I I I ~----------i----------+------------ ~------------------i----------------~----------------~ ~-t==:==~~=:=:==~ ~===:==:=t::::====:=:t-======~ }----------------i------------+----------------~ ¡ ¡ , , ! i ! I ! SHUT IN TIME! SHUT IN PRESSURE [-===~=--=-T=--==~~=~=I=~-=~-==-~~=J [=~Q~!!![~~~~[~=~~~=~~~~~~~=[~~~Q~Q~Ë~.cJ ! ! ! ! ! 1.0 min ! ! 2,030 psi! r--------;-----------T--------------t t----------:-----f---------------i-------------:--; I I I I I 2.0 mln I I 2,020 pSI I 1-----------------1------------------1---------------1 ! 3.0 min i I 2,010 psi! E:~gEE====:~JI~l~í-j ! 6.0 min ! ! 1,990 psi! r-~=?~~!ñ~~~=~I~=~~~=~~===~+~~~~~~Q1!~~~ ~-----~;Q-~!!1.._--¡--------------__-i--_1!~!!~.e~~---i ! 9.0 min ¡ ! 1,980 psi! .----------------T-----------------r-------------'" ! 10.0 min ! I 1,980 psi! [=i§J?~!!!~~~~~I~~~=~~~=~~=~~~~~~¡~j~~~Q~R~[J ! 20.0 min : I 1,970 psi! }------------------I----------------1------------------I ! 25.0 min ! I 1,960 psi! [~~~Q~~!!11~~~~[~~~=~=~~~=~~~~~[~~~r~E~[] L~!'.l!.!..!~ TIM.5J-________2.I!Y_!..!~_~.!t~~~~~E L__<!.:g_mi~_.J___--______L_~25 J?21.._J ! 1.0 min ! ! 420 psi! 1--- 1- ----+------------1 L---~~~!~--J----------l..---~Q-~P_~--J L--~;..o mil'!.._j__-------_.l---~~~_p_~L_J ! 4.0 min ! ! 391 psi! t--~---i---------+----------;,--- ~-_É.:_Q..~!!1.._-!------------!---~~_p_~_I____~ L--§;S> mi~--J___---------.l-_!~~_psi --j ! 7.0 min ! ! 383 psi! ¡--ä:oñÏin-I----------t----3"iff"p-Š-f---1 I--------------~-----------+----------------I ! 9.0 min ! ! 380 psi! [~I~õ- ml~~J~-=~=--===I~~~!p~C] NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ~~ ~~ ARCO Alaska, Inc. Daily Drilling Report AFC No, I Date RptNo I Rig Accept - hrs Days Since AccepVEst: 6.5 I Rig Relase - hrs: AK9773 01/01/99 7 12/26/9812:00:00 PM Well: 2L.321 Depth (MDfTVD) 34081 Prev Depth MD: 3310 Progress: 98 Contractor: DOYON Daily Cost $ 96328 Cum Cost $ 813766 Est Cost To Date $ Rig Name: DOYON 141 Last Csg: 7-5/8" @ 3302' Next Csg: 5.1/2 X 3.1/2" @ 11307' Shoe Test: Operation At 0600: DRILLING 6-3/4" HOLE @ 4000' Upcoming Operations: CONTINUED DRILLING TO T.D.. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOPIDIVERT LAST BOP/DRILL LSND 3408 4R1 N TST 01/01/98 01/01/98 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.1ppg 50 6.75 12/02/98 12/22/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 48sqc 75 HYC N SPACE 12/31/98 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 14/16 45 STR554 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 2800 4/51 5 1901317 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1750 6.6 5 01/01/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 133 ml/30 min 1500 3310 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 3.0% 1500 98 2L-325 I PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADTIAST SOURCE WELL TEMP of -17 131bbl 2000 III 1 1 2L.321 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 5 7.5 11211 2.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 225° 9.0 61611 700 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of -22.45 2.09% 70 III Water Base Muds 616 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 1 420 297111 13 11111 45 1131131131 I Diesel 40 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 27 $9568 III 0.00 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $97689 III III III 701 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 14 10.2111 III III 12584 PERSONNEL TOTAL 47 T.IME' I, END .... 'HqURS 1, OPS CODE I . ... ,HQLEi;Se:CT " j8HASEOPS...,. 'I..,.. '.'> 'QP~RArloNsFROMOOOO~OQOO . "r' 12:00 AM 12:30 AM 0.50 NU_ND PROD Other FINISH NIU BOPE. 12:30 AM 01:30 AM 1.00 BHA PROD Other LAY DOWN 9 D.CLR F/DERRICK. 01 :30 AM 12:00 PM 10.50 BOPE PROD Other RIU & TEST BOPE, HYDRIL FAILED, CHANGE OUT RUBBER, ALL OTHER TESTS OK, WITNESSING WAIVED BY SPAULDING.AOGCC. 12:00 PM 12:30 PM 0.50 BOPE PROD Other NIPPLE UP RISER, LAY DOWN POTATOE MASHER & HWDP, RIG UP TEST EQUIPMENT. 12:30 PM 01 :00 PM 0.50 BOPE PROD Other TEST HYDRILL, BOTTOM PIPE & PIPE RAMS. 01 :00 PM 01 :30 PM 0.50 BOPE PROD Other RIG DOWN TEST EQUIPMENT, INSTALL WEAR BUSHING. 01 :30 PM 04:00 PM 2.50 RIGS PROD Other SLIP ON NEW DRLG LINE 04:00 PM 06:30 PM 2.50 BHA PROD Other MIU BHA, ORIENT, INITIALIZE MWD, LOAD SOURCES. 06:30 PM 08:00 PM 1.50 BHA PROD Other CONTINUE PIU BHA RIH TO 3174'. SOFT CEMENT. 08:00 PM 08:30 PM 0.50 CIRC PROD Other CIRC OUT CONTAMINATED MUD. 08:30 PM 09:30 PM 1.00 TEST_CSG PROD Evaluation TEST CSG TO 2000# F/30 MINUTES. 09:30 PM 10:30 PM 1.00 DRIL PROD Making Hole DRLG HARD CEMENT & FLOAT EQUIPMENT & 20' NEW HOLE TO 3330' 10:30 PM 11:00 PM 0.50 CIRC PROD Other SWAP OVER TO NEW 9.1 PPG MUD. 11:00 PM 11:30PM 0.50 TEST PROD Evaluation PERFORM F.I.T. TO 16.0 PPG EMWOO:OO 11:30 PM 12:00 AM 0.50 DRIL PROD Making Hole DRLD F/3330-3408' 24.00 Supervisor: R.W. SPRINGER Daily Drilling Report: 2L-321 01/01/99 Page 30 Casing Detail 5-1/2" X 3-1/2" Production Casing WELL: TARN 2L-321 DATE:1/10/99 1 OF 1 PAGES ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RT to LOS = 27.001 TOPS 51/211, LANDING JT. 32.151 OVERALL LENGTH 27.00 5-1/211 GEN V CASING HANGER 2.93 27.00 Jts. 1-268 5-1/211,15.5# L-80, LTC MOD (joints) 11392.88 29.93 PUP 5-1/211, 15.5# L-80, LTC MOD 10.59 11422.81 Baker Csg Seal Receptacle (CSR), SIZE 80-40, 5-1/211 x 411 20.26 11433.40 XO 3-1/211 9.3# L-80 8rd EUE X 5 1/211 EUE 8rd (XO) .75 11453.66 pup 3-1/211 9.3# L-80 8rd EUE 10.15 11454.41 Jts.326-329 3-1/211 9.3# L-80 8rd EUE (4 joints) 125.12 11464.56 pup 3-1/211 9.3# L-80 8rd EUE (marker) 6.11 11589.68 Jts.304-325 3-1/211 9.3# L-80 8rd EUE (22 joints) 686.13 11595.79 Weatherford Gemoco Float Collar 1.18 12281.92 Jts. 301-303 3-1/211 9.3# L-80 8rd EUE (3 joints) 94.62 12283.10 Weatherford Gemoco Float Shoe 1.84 12377.72 Bottom of Shoe @ 12379.56 ACTUAL TD= (124031) 23.51 RA THOLE. Bypass plug latch in receptical @ 122491. (top of jt. #304) (29) 3-1/211 x 6-1/211 straight blade centralizers(Jts.301-329 ) (12) 5 1/211 x 6 3/411 bow spring centralizers (Jts.1-12) (18) 5-1/211 x 6-1/211 centering guidess on jts 208, 211, 214, 217, 220,223,226,229,232,235,238,241,244,247,250,253,258,263. Remarks: String Weights with Blocks: 138K Up, 45K On, 12K Blocks. Ran 29 Joints 3-1/211 and 268 Joints of 5-1/211 casing. Drifted 5.511 (4.7511)& 3.511 (2.86711) casing with plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Drilling Supervisor: DA VE BURLEY ~~ ~" ARCO Alaska, Inc. Cementing Details Well Name: 2L-321 Report Date: 01/11/99 Report Number: 17 Rig Name: DOYON 141 AFC No.: AK9773 Field: Tam Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: I LC Depth: % washout: 3.1/2" x 5-1/2" 6.3/4" 12380 12249 Centralizers State type used, intervals covered and spacing Comments: Placement on casing detail. Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 9.9 22 18 21 19 Gels before: Gels after: Total Volume Circulated: 9/11 6/8 525 Wash 0 Type: Volume: Weight: Comments: ARCO 20 bbls 8.5 Spacer 0 Type: Volume: Weight: Comments: ARCO 845 40 12.0 Lead Cement 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: Additives: Tall Cement 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: G 70 290 15.8 1.2 Additives: 2 gps D600, 0.1gps D135, 0.1gps D47, 3% D53, 0.8% D65, 0.12% D800. Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. WI. Up: Comments: 4.0 3.5 137 Reciprocation length: Reciprocation speed: Str. WI, Down: 25 10 fpm 45 Theoretical Displacement: Actual Displacement: Str. WI. in mud: 279.3 bbls 282.7 bbls Calculated top of cement: CP: Bumped plug: I Floats held: 10954' Date:1/11/99 yes yes Time:0015 hrs. Remarks:Pumped 20 bbls preflush, 40 bbls of spacer and 56.2 bbls of cement, displaced with 20 bbls of fresh water and 262.7 bbls of seawater. Landed casing after pumping spacer due to pipe sticking. Bumped plugs to 2000 psi, full returns throughout. Cement Company: Rig Contractor: Itpproved By: DS DOYON D.BURLEY ~It.. ~" ARCO Alaska, Inc. Daily Drilling Report AFC No. I~ate RptNo I Rig Accept - hrs Days Since AccepUEst: 15.5/13 Rig Relase - hrs: AK9773 01/10/99 16 12/26/9812:00:00 PM Well: 2L-321 Depth (MDITVD) 12403/5890 Prev Depth MD: 12403 Progress: 0 Contractor: DOYON Daily Cost $ 236859 Cum Cost $ 2033235 Est Cost To Date $ 1600000 Rig Name: DOYON 141 Last Csg: 7-5/8" @ 3302' Next Csg: 5-1/2 X 3-1/2" @ 12307' Shoe Test: 16.0 PPG F.I.T. Operation At 0600: Running 3-1/2" completion. Upcoming Operations: Run completion, ND BOPE, NU wellhead. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO, INCIDENT LAST BOPIDIVERT LAST BOP/DRILL LSND 5 N TST 01/07/99 01/01/99 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.9ppg 6.75 12/02/98 12/22/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 49sqc HTC N SPACE 12/31/98 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 18/21 STR554 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1620 7/81 0322873 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 425 5.4 12403 01/10/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 1D7 ml/30 min 6848 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 9.5% 5555 2L-325 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of -7 252bbl III 44.2/6.7 I 2L-321 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 5 12.5 11211 10 - 15 2.3 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 15° 9.0 61611 90 - 285 - 750 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of -11.95 7.1% III .518 Water Base Muds 238 PIT VOL GPM2 JETS JETS ARCO PERSONNEL 1 700 III 131131131131 I 11111 0 0 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 27 $3287 III 8571 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $232243 III 111No1A III 238 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 14 BAROID III X II I NO I TD III 18245 PERSONNEL TOTAL 47 ,TIME L ,I;NO . .':.HOURS :1' OPSCODE, . [; HQLE$EiCT. IPHASEQP$ ....... >1.;.> ....;..'..... QPE,RATIONSf8QMOOOO" 0000, '.. ..... ...; '. 12:00 AM 03:00 AM 3.00 BHA PROD Making Hole PJSM. Down load LWD, laid down tools. 03:00 AM 09:30 AM 6.50 RUN_CSG PROD Casing and Pulled wear bushing and RU GBR casers. Held safety Cementing meeting and run 3.1/2" x 5-1/2" casing to 4506'. 09:30 AM 10:30 AM 1.00 CIRC PROD Casing and CBU at 4 bpm, 470 psi, full returns. Cementing 10:30 AM 01 :00 PM 2.50 RUN_CSG PROD Casing and Run 5-1/2" casing to 7200'. Cementing 01 :00 PM 02:00 PM 1.00 CIRC PROD Casing and Staged pumps up to 3 bpm and CBU, 65% returns. Cementing 02:00 PM 03:30 PM 1.50 RUN_CSG PROD Casing and Run 5-1/2" casing to 9800'. Cementing 03:30 PM 04:30 PM 1.00 CIRC PROD Casing and Staged pumps up to 3 bpm and CBU, 65% returns. Cementing 04:30 PM 07:00 PM 2.50 RUN_CSG PROD Casing and Run 5-1/2" casing, PU hanger and landing joint, MU cement Cementing head. 07:00 PM 10:00 PM 3.00 CIRC PROD Casing and Circ and cond mud intial rate 2 bpm Cementing 50% returns. Final rate 3.5 bpm 90% returns. 10:00 PM 12:00 AM 2.00 CMT_CSG PROD Casing and Cement casing as per plan Cementing displacing cement with seawater at midnight. 24.00 Supervisor: D.P.BURLEY Daily Drilling Report: 2L-321 01/10/99 Page 68 CASING TEST and FORMATION INTEGRITY TEST Well Name: Date: 1/11/1999 2L-321 Supervisor: D.P.BURLEY Casing Size and Description: 7 5/811, 29.7 ppf, L-80, BTC Casing Setting Depth: 3302 TMD 2,2901 TVD Mud Weight: 9.9 ppg EMW = Leak-off Press. + MW 0.052 x TVD Hole Depth: 5,896' TVD 390 psi + 9.9 ppg EMW LOT= (0.052 x 2,290') = 13.2 ppg Fluid Pumped = 5.0 bbl Pump output = 0.1010 bps ....¡TIMELINE 2,300 psi I I - ONE MINUTE 2,200 psi . 2,100 psi ': ! I ~ 1 1 I 2 000 psi I i J""~~..>.k, A' . : '. I I ! T ,-tk*, '" I 1,900 psi I i I 1800psi ,I I I I I 1'700 psi " " , ¡ I I I I 1'SOOPSi' I II I I i I I . . I I 1 I ! ! ! 1,500 ps~ I I I ~ I I I i I W 1,4OOPS~, III I I ' I a: 1,300 psi I 'I I i I ~ 1,200 psi en 11ooPSi! J~ I I ! ~ 1'000 . I, I I I I ..... . psi 'I I I I ~LEAK-OFFTEST r-I:--- ~ 900 psi ! I I I I "'-CASING TEST ~-- 800 psi I j I I'.<>-'LOT SHUT IN TIME -- 700 psi I!! I I! " I I ' -,k-CASING TEST SHUT IN TIME -- Soopsi :. I I I I I' -+-TIME LINE -- SOOpsi I I . 400 ps~ ~'I"71 I I &, I 300 psi ø' 1 I I I 200 psi I I 100' j I ps~ 'PI' I ! I 0 psi I I 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 68 70 72 74 76 78 80 82 84 86 88 90 .............................................. STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR FIT STROKES PRESSURE CSG TEST STROKES PRESSURE C--=-~~=--r==-=1---=--=~ . [=~~===]~~~-=~~===~~I~~~~~~===] I-----==--=t=~ :::-:1:~~::=b$==:=i=:I:~~ti=~f};-~ L---------J-~~tks l--~! pSL_t1:t.t-__-----------!-_!.~-~~----t-----~.Q..J?~!._~ I I 3 stks I 375 psi 4';" I I 3 stks ' 170 Dsi I ~-------------~--------+-----------~~~---------------r------------t------_J_----I L____--1_'! stks -~.Q.p-~~ ~ L_--______L__!~~~_----_~_1 0 .J?.~-j ~----_--!--~tks -i-i~O p~W ~-------------!----~~~~--+-_~~_J?Si --i L---------l--Ê stks -L...!20 ps-U ~-----------J-~stk~_-.!--_~-~J?_~)--1 L_--1--? stks _~25- psi --l L_____---______L___L~!.~!.___l.._-~_~Q..J?.~L.J ~-___~__8 stk~i--- 450 .p~L_-i ~------------!---_!.~!~~---i--!!Q~~~~!_~ ~----~--- 9 stks L- 45.Q..p~-I ~---------------¡---~ S!_~~--+_!Z)_!QJ~~-U L-------1-J.Q.~!~Li50 ps~..J L_-----------~----_!~-~!_~~---+-_!!~~"p'Si_J L_-------__-J--_15 ~tks -_.l_.i~.Q.p-~!._~ L______--------i----!.!.~!~~--t-_!!45<!'p-Si_J ~--------~-~O ~~ks_--1- 470 psi --~ ~-------_--_+__12 st~~_!!~~Q.p~!-i i-------L~5 stks ---L 47~.E.~!._.J L------------~---_!.~~-~---.!--!!~~~"p'~!_j L_---__J___30 stks _l.~l!.p~i_j L_________l__.!!~!~~--~-~z!>80 R~j ! ! 35 stks ¡ 480 psi! ! ! , ! t=~=~1=~0 stks -=1~~ 48~£!c=1 C==~~~~~==-t~==~====-~1=~~~~~~~~=--~~~~] ! ! 45 stks ¡ 480 psi! ! ! ! ! r==--==]=SÕ s~~~=l-~!~p-:;L_~~ ¡------------¡--------------'------------1 i ! ¡ ! ! SHUT IN TIME I SHUT IN PRESSURE C==L---===I=~~=--==] [=-~Q_!!1iñ-=~t~=~~=~~==I~~~~~~E?lJ L -~-- ! --.-1 L__1.0 .!!l!~---~-----------+--~P~~~!!_~ I i I I ~____3~Q.~~__--t-----------t~~~~PS!_-~ L!l!l!.!_!~ TIf.!~L-----___2_'tl!!.!~PR~~~~~E L~;Q-~!~----L-------------+-_~Q!Q'p-si.J L~~~in _L_--____.L.380 _p.~LJ L_~;Q_~~__L_______L_~!QQ~-~~!J I 1 O' I I 325 . I I 5 O' I I 2 000 . I ~--=~~~-------¡.-------p~~-~ ~_..._-~-~!~---+------------i---!---_U'~.!-~ L-~Q- min ---J-----.!-__~.Q.~i-! ~---§;..q-~!~---!---------------J-!z.9~Q.p-~J_j L-_l9 mi~_J___---___.l_~90 .p~L_j L_.z;..~rn!~____L-----------.l-!!~J.Q-p'~j ~--~;Q-~!~--!--------i--_~!psi -~ ~----~;Q-~!~---t-------------t-_!!~~.Q.P~J_-~ L-- 5.0 min ~-___--1-~80 .p_!L-1 ~--- 9.0 !!1J~---~----_..._---..-_!z~~-p.~J--! i---Ê;O mJ!!...J----L-~~.ps~-.J L__!Q;!L~!~___L____-_--------t_!!~80..e!!_J LZ;Q. min ---~_--____L- 28~.p~L_J L_1É;..q-~!~--!--------------_+__!z.97<!_P.!!_J U.:2.!11in --!------J-- 28~.P.!~__j ~--~2;Q-~!~---~-------------t-_!!~70 ~si-J ~!!1.!!1---L----.L- 280 'p~-~-j L-~~q-~~--{------------+_!!~.?.!» p!!-.J L_.!P,O min L__________L 280 .p_!LJ L_~Q;Q_!!1J~___L____________l_1.z~~Q~!_J NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY '198,262_0 KUPARUKRIVuTARN 2L~321 50- 103-20286-00 PHILLI?sALASKAINC Roll #1: Start: Stop Roll #2: Start Stop MD 12403 TVD 05890 Completion Date: 1/11/99 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D ~//'D 9222 2,3 SPERRY MPT/GR/EWR4/CNP/SLD OH 6/22/99 6/29/99 L DGR/CNP/SLD-MD FINAL 3312-12403 ~..~3.~. OH 6/24/99 6/29/99 L DGR/CNP/SLD-TVD FINAL 2290-5890 ~-~0~- ' OH 6/24/99 6/29/99 L DGR/EWR4-MD FINAL 3312-12403 ~,(~'~ OH 6/24/99 6/29/99 L DGR/EWR4-TVD FINAL 2290-5890 ~- OH 6/24/99 6/29/99 b/' R SRVY CALC BH 192.31-12403. OH 4/19/99 4/20/99 tA SRVY RPT SPERRY 0-12403. OH 1/27/99 1/28/99 T Thursday, January 25, 2001 Page 1 of l 0 !:! I I--I--I IM G ~I,I, LOG TRA~$]VHTTAL TO: State of Alaska June 24, 1999 Alaska Oil and Gas Conservation Comm Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 St I RE: MWD Formation Evaluation Logs 2~ AK-MM-90041 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Jun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 2I.,-323: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20282-00 1 Btuetine 1 Folded Sepia 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-103-202824)0 1 Blueline 1 Folded Sepia 2" x 5" MD Neutron & Density Logs: 50-103-20282430 2"x 5" TVD Neutron & Density Logs: 50-103-202824)0 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1999 Alaska 0it & Gas Cons. Cernmi 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company CI !:! I I--I-- I IM G S ~: I~! ~.1 1 C Ec: WELL LOG TRANSMITFAL To: State of Alaska Alaska Oil and Gas Conservation Cornm_ Atto: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs June 22, 1999 2L-321, AK-MM-90051 1 LDWG formatted Disc with vexification listing. APl#: 50-103-20286-00 PI,EASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ~ ATYACHED COPY OF THE TRANSMI'VFAL LE'VFER TO THE ATYENTION OF: Sperry-Stm Drilling Service Attn: Ynn Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED · ., v9 lqq9 Date: Alaska Oil & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company · . ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 16, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2L-321 (Permit No. 98-262) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 2L-321. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Drilling Team Leader AAI Drilling PM/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 [~] SUSPENDED [~] ABANDONED~ SERVICE [~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-262 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 .......... L~.~ 50-103-20286 4 Location of well at surface · !~'~; i..:'!'~'i(J~.i i ~ 9 Unit or Lease Name 205' FNL, 806' FEL, Sec. 22, T10N, R7E, UM } ~ Kuparuk River Unit At Top Producing Interval ............ i 10 Well Number 859' FNL, 1265' FWL, Sec. 25, T10N, R7E, UM .'~,,~,,-,,_'.'. -..:i 2L-321 At Total Depth .... ' '-'~-... ~ ',' ~ 11 Field and Pool 1270' FNL, 1780' FWL, Sec. 25, T10N, R7E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. Tarn River Oil Pool RKB 28', Pad 115' ADL 380053 ALK 4601 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 26-Dec-98 08-Jan-99 11-Jan-99I NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 12403' MD & 5890' TVD 12249' MD & 5807' TVD YES M NO U NA feet MD 1204 APPROX 22 Type Electric or Other Logs Run GPJRes/Neu/Dens, GR/CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECOI~D 16" 62.5# H-40 SURF. 108' 24" 9 cu yds High Early 7.625" 29.7# L-80 SURF. 3302' 9.875" 595 sx AS Iii LW & 235 sx Class G 5.5" x 15.5# L-80 SURF. 11454' 6.75" 290 sx Class G 3.5" 9.3# L-80 11454' 12380' 6.75" (included above) · -£ · ,,~ 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 11450' 11433' (CSR) 11680'-11720' MD 5489'-5512' TVD 6 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11680'-11720' see attachment 27 PRODUCTION TEST 0RIG"'AL Date First Production Method of Operation (Flowing, gas lift, etc.) I1~1 3/4/99 Flowing Date of Test Hours Tested PRODUCTION FOiOIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 3/4/99 9 TEST PERIOI: 302 449 ~83 0I 1491 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBl. OIL GRAVITY-APl (corr) Press. 0 0 24-HOU R RATE: 0 ! 0 1357 488 0 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. 7-1-80 CON'rlNUED ON R'EVERSE SIDE 9. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T-3 11612' 5450' T-2 11754' 5531' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by Name/Number Sharon Allsup-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: 2/2/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2L-321 WELL ID: AK9773 TYPE: -- STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:12/26/98 START COMP: RIG:RIG % 141 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20286-00 12/26/98 (D1) TD: 480'(480) SUPV:R.W. SPRINGER 12/27/98 (D2) TD: 2773' (2293) SUPV:R.W. SPRINGER 12/28/98 D3) TD: 3310' 537) SUPV:R.W. SPRINGER 12/29/98 D4) TD: 3310' 0) SUPV:R.W. SPRINGER 12/30/98 (D5) TD: 3310' ( 0) SUPV:R.W. SPRINGER 12/31/98 (D6) TD: 3310' ( 0) SUPV:R.W. SPRINGER MW: 9.9 rISC: 46 PV/YP: 37/62 APIWL: 6.0 DRILLING 9-7/8" HOLE @ 980' (FIELD POWER 8 HR) Move to 2L-321. Accepted rig @ 1200 hrs. 12/26/98. NU diverter and function test. Drill 20' ice and 4' new hole. Drill from 108' to 480' MW: 10.2 VISC: 98 PV/YP: 24/ 0 DRILLING @ 3245' APIWL: 4.8 Drill 9-7/8" surface hole from 480' to 2773' MW: 10.2 VISC: 120 PV/YP: 29/32 ATTEMPTING TO BACK OFF STUCK PIPE APIWL: 3.4 Drilled from 2773' to 3310' POH, hole tight all the way out. Wash and ream tight hole from 650'-917', major coal and fine sand across shakers from 650' area. Packing off, pulled up to 892', packed off. No circulation unable to go up or down, working stuck pipe. R/U to run free point. MW: 10.2 VISC: 175 PV/YP: 26/59 WIPER /CLEANOUT TRIP F/CSG APIWL: 3.6 R/U free point stuck pipe @ 867'. RIH w/fishing BHA %3 w/screw in sub & jars & caliper. Jar on fish, move up hole. Unable to circulate. POH w/ fish. MW: 10.1 VISC: 210 PV/YP: 46/64 RUNNING CASING. APIWL: 4.8 POOH w/fish. RIH w/hole opener. Wash & ream from 492'-963' Bridge @ 963' unable to go through w/bull nosed opener. POH. RIH. Wash & ream from 780'-1141'. Wash & ream from 1315'-1430'. CBU. Work pipe, ream & pump out of hole from 1850'-1473' MW: 10.0 VISC: 97 PV/YP: 30/26 TESTING BOPE. APIWL: 6.6 Run 7-5/8" casing. Pump cement. ND diverter. NU BOPE. Date: 2/2/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 01/01/99 (D7) TD: 3408' ( 98) SUPV:R.W. SPRINGER 01/02/99 DS) TD: 5321' 1913) SUPV:R.W. SPRINGER 01/03/99 D9) TD: 5823' 502) SUPV:R.W. SPRINGER 01/04/99 (D10) TD: 6848' (1025) SUPV:R.W. SPRINGER 01/05/99 (Dll) TD: 8549' (1701) SUPV:D.P.BURLEY 01/06/99 (D12) TD:10113' (1564) SUPV:D.P.BURLEY MW: 9.1 rISC: 48 PV/YP: 14/16 DRILLING 6-3/4" HOLE @ 4000' APIWL: 6.6 Test BOPE, hydril failed, change out rubber. Test hydril. RIH to 3174', soft cement. Circ out contaminated mud. Drilling hard cement and float equipment and 20' new hole to 3330'. Perform LOT to 16.0 ppg EMW. Drilled from 3330' to 3408' MW: 9.2 VISC: 46 PV/YP: 14/15 STRIPPING INTO WELL F/CSG SHOE APIWL: 5.8 Drilled from 4442' to 5321'. Short trip to casing shoe @ 3300', observe well, well bubbling, then started flowing, Shut well in. Attempt to circ gas out using drillers method. Monitor SICP. MW: 10.2 VISC: 59 PV/YP: 24/27 DRILLING @ 6322' APIWL: 6.6 Pump mud, strip into well from 3300' to 5300' using annular preventer. Raise mud weight to 10.5 ppg. Shut well in, no pressure. Well static. Drilled from 5321' to 5823' MW: 10.2 VISC: 54 PV/YP: 22/27 DRLG @ 7131 APIWL: 6.8 Drilled from 5823'-6848' Drilling rate slow, nozzle plugged. MW: 10.1 VISC: 47 PV/YP: 21/18 DRILLING PRODUCTION HOLE FROM 8670' APIWL: 6.6 Precautionary ream from 6682' to 6848' Drill from 6848' to 8549' Began losing mud @ 8300'. Lower mud weight to 10.1 ppg, adding fine LCM, losses increased to 80-90 bph. Pumped sweeps and circ clean, reduced pump rate, adding fine LCM MW: 10.0 VISC: 50 PV/YP: 19/19 DRILLING PRODUCTION HOLE FROM 10280' APIWL: 5.4 Continue to monitor well, initial flowback rate reduced. Wiped hole to 6650'. Flowback rate reduced. No other problems. Drill from 8549' to 9178' Pumped 7 ppb LCM around, losses reduced. Drill from 9178' to 10113' Date: 2/2/99 ARCO ALASKA INC. WELL SUM~LARY REPORT Page: 3 01/07/99 (D13) TD:11332'(1219) SUPV:D.P.BURLEY 01/08/99 (D14) TD:12403' (1071) SUPV:D.P.BURLEY 01/09/99 (D15) TD:12403' ( 0) SUPV:D.P.BURLEY 01/10/99 (D16) TD:12403' ( 0) SUPV:D.P.BURLEY 01/11/99 (D17) TD:12403' ( 0) SUPV:D.P.BURLEY 01/12/99 (D18) TD:12403'( 0) SUPV:D.P.BURLEY MW: 9.9 VISC: 51 PV/YP: 19/20 DRILLING PRODUCTION HOLE FROM 11500' APIWL: 5.6 Circ clean, initial flowback 60 bph, slowed to 24 bph. Wiped hole to 8200', flowback from well 10 bph. No other problems. Drill from 10113' to 10769' Control ROP < 200 fph for wellbore stability. Losing 10 bph while circulating, well flowing back while pumps off. Drill from 10769' to 11332'. MW: 9.9 VISC: 53 PV/YP: 20/25 APIWL: 5.2 COMPLETED 250/2000 TEST ON ANNULAR PREVENTOR, RIH, 4600' ~ 0 Drill from 11332' to 11396'. Pump sweep and circ clean, monitor well, initial flowback 60 bph slowed to 35 bph. Wiped hole to 9850', no problems. Flowback from well 6 bph. Drill from 11396' to 12403' MW: 9.9 VISC: 54 PV/YP: 22/25 RUNNING 3-1/2" X 5-1/2" PRODUCTION CASING. APIWL: 4.4 Set storm packer at 68' Tested annular to 250/2000 psi. Pump hi-vis sweep and circ hole clean. Encountered 15 bph losses, max background gas 40 units. Circ clean, initial flowback 80 bph slowed to 30 bph. MW: 9.9 VISC: 49 PV/YP: 18/21 RUNNING 3-1/2" COMPLETION. APIWL: 5.4 Run 3.5" x 5.5" casing. Cement casing. MW: 8.5 VISC: 28 PV/YP: 0/ 0 RIG RELEASED 1-12-99 ~ 0200 HRS. APIWL: 0.0 Install packoff and test to 5000 psi. Run 3.5" completion. Freeze protect tubing and 5.5" annulus. ND BOPE and install master valve and test. MW: 0.0 VISC: RIG RELEASED ~ 0200 HRS. 0 PV/YP: 0/ 0 APIWL: 0.0 Released rig ~ 0200 hrs. 1/12/99. ARCO Alaska. Inc. KUPARUK RIVER UNIT ~ WELL SERVICE REPORT ,, Kl(2L-321 (W4-6)) WELL JOB SCOPE JOB NUMBER 2L-321 F RACTU RING. 0120990821.4 DATE DAILY WORK UNIT NUMBER 01/29/99 SCOUR AND BRACKET FRAC TARN SAND DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 NO YES DS-GALLEGOS SCHU ROSKY FIELD AFC# CC# Signed ESTIMATE AK9773 180KNU2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 680 PSI 810 PSI 500 PSI 2000 PSI 0 PSII 0 PSI DAILY SUMMARY PUMPED SCOUR STAGES USING 8719 LBS. 20/40 C-LITE, PUMP BRACKET FRAC WITH 4000 LBS. 20/40 RIVER SAND AND 1015 LBS. D-124 LOW DENSITY PROP. OVER DISPLACE TO PERFS. FROZE TREATING LINE. THAW TREATING LINE AND TREE TO PULL TREESAVER. DISPLACE TBG. WITH 30 BBLS DIESEL. RIG DOWN TO THAW VALVING AND HARDLINE. TIME LOG ENTRY 06:30 MIRU DOWELL FRAC EQUIP. HOLD PER JOB SAFETY MEETING. COVER JOB AND WEATHER. 08:00 CONT RIG UP. MANLIFT ON LOCATION. HOLD SECOND TGSM. LOW TEMPS AND WIND CHILL. 10:30 LOW PRESS. TEST ON TREATING LINES. PT ANNUL. LINES. 10:50 PT TREATING LINES TO 8100 PSI. 12:00 SET TREESAVER. HOT OIL TOP OFF DIESEL TANKER. 12:45 PUMP BREAKDOWN STAGE AT 8000 PSI, 23 BPM. FOR 100 BBLS. ISIP= 950 PSI 13:05 PUMP CONDITIONING AND GEL BREAKDOWN STAGES. 25 BPM AT 5400 PSI. ISIP= 900 PSI 14:20 PUMP DATA FRAC. 5 BPM AT 1900 PSI. FOR 100 BBLS - DISPLACE WITH WATER AT 15 BPM 3000 PSI FOR 110 BBLS. ISIP= 970 PSI CLOSING PRESSURE 800 PSI. 15:40 PUMP BRACKET FRAC PER SCHEDULE. 16:00 SHUT DOWN PUMPS, RECALC PAD AND MAIN FRAC. PICK CLOSURE. WATCH PRESSURE FOR 30 MIN PER DS ENG. MIX GEL. 17:00 TRY TO PUMP BUT WAITED TOO LONG AND FROZE TREATING LINE. 17:30 WRAP WELLHEAD WITH TARP AND ADD LOTS OF HEATERS.UNABLE TO PULL TREE SAVER. 22:00 AFTER ADJUSTING TARPS AND HEATERS ABLE TO GET TREE SAVER UP. DISPLACE TBG. WITH 13 BBLS DIESEL. SEND LITTLE RED FOR 20 BBLS MORE DIESEL TO PUMP. 00:15 REPLACE TREE CAP FLANGE, COMPLETE RIG DOWN. 01:30 ROAD DOWELL TRUCKS TO KIC SHOP FOR THAWING. CONT JOB AT LATER TIME. Date 01/26/99 upcoming E~ Well Name 2L-321 Job Num 0114991847.3 Service Type ELECTRIC LINE · Unit 2128 Desc of Work INITIAL PERFORATIONS Supervisor FITZPATRICK Contractor KeyPerson SWS-DECKERT Complete [~ Successful [~ Accident [~] Initial Tbg Press 0 Injury E~ Initial Int Csg Press 0 Spill E~ Initial out csg Press 0 Summary AFC AK9773 0 Final Tbg Press 100 Final Int Csg Press 0 Final Out Csg Press 0 PERFORATED FROM 11680' TO 11720' RKB USING 2-1/2" HC BIG HOLE CHARGES @ 6 SPF, 60 DEG PHASING. [Perf] Prop 180KNU2 Uploaded to S Date printed: 01127/99 at: t5:12:43 ARCO Alaska, Inc. KUPARUK RIVER UNIT ~ WELL SERVICE REPORT ,~' K1(2L-321 (W4-6)) WELL JOB SCOPE JOB NUMBER 2 L-321 PERFORATIONS-E-LINE 0114991847.3 DATE DAILY WORK UNIT NUMBER 01/26/99 INITIAL PERFORATIONS 2128 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 YES YES SWS-DECKERT FITZPATRICK FIELD AFC# CC# Signed ESTI MATE AK9773 180 KN U2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 100 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY PERFORATED FROM 11680' TO 11720' RKB USING 2-1/2" HC BIG HOLE CHARGES @ 6 SPF, 60 DEG PHASING.[PerfJ TIME LOG ENTRY 07:00 MIRU SWS. AIR SYSTEM FROZEN. TROUBLESHOOT & THAW SAME. LAY OUT PERF GUNS & TOOLS. 11:00 CALL FOR RADIO SILENCE. DEPLOY SAFETY SIGNS. NOTIFY ON-SITE PERSONNEL. ARM GUNS (SAFE SYSTEM). P/U, STAB ON, TEST BOPE 3000 PSI, OK. 11:45 RIH WITH GR / CCL / 20' X 2-1/2" HOLLOW CARRIER PERF GUN (BIG HOLE SHOTS) WITH 6 SPF @ 60 DEG. 13:45 TIE-IN. PUMP UP TBG TO 600 PSI. PERFORATE FROM 11700' TO 11720'. 15:05 POH 16:30 OOH, ALL SHOTS FIRED. 17:20 CHANGEOUT GUNS. REMOVE GUN GR. 19:15 RIH WITH CCL/20' GUN. TIE-IN CCL. PERFORATE FROM 11680' TO 11700'. POH. 20:30 OOH, ALL SHOTS FIRED. 21:30 RD, MO. ARCO Alaska. Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT ,, K1(2L-321(W4-6)) WELL JOB SCOPE JOB NUMBER 2 L-321 FRACTU RI NG. 0120990821.4 DATE DAILY WORK UNIT NUMBER 02/03/99 PUMP FRAC JOB DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 2 YES YES DS-YOAKUM JOHNS FIELD AFC# CC# Signed ESTIMATE AK9773 180KNU2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 170 PSI 0 PSI 2000 PSI 500 PSI 0 PSII 0 PSI DAILY SUMMARY I PUMPED "A" SANDS FRAC ,PLACED 86000# PROPPANT TO7 PPA IN PERFS.. SCREENED OUT FRAC ,LEAVING 18884-# IN I I TUBING.[Frac-Refrac] I TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP., LITTLE RED PUMP AND APC VACUUM TRUCK. 09:10 HELD JOB SITE SAFETY MEETING, MUSTER AREA 16 PEOPLE. 09:40 PRESSURE TEST SURFACE LINE TO 8500 PSI. 09:52 PUMPED TWO PULSES WITH DIESEL, 5 BPM. 11:03 PUMPED 100 BBLS OF 50# GELAT 5 BPM AND 1895 PSI. 11:20 PUMPED 200 BBLS OF 50# GEL AT 15 BPM AND 3543 PSI. 11:32 PUMPED 150 BBLS WITH 2PPA 20/40 PROPPANT, 15 BPM AND 3616 PSI. 11:44 PUMPED 500 BBLS 2 PPA TO 4.5 PPA PROPPANT 12/18,15 BPM AND 4720 PSI. 12:16 PUMPED 66 BBLS TO 7 PPA 12/18 PROPPANT, 15 BPM 12:22 SCREENED OUT FRAC TO 6475 PSI., SHUTDOWN. PLACED 86000# PROPPANT IN PERFS, LEFT 18884# PROPPANT IN TUBING. i~ S[J[~VEY C]flkl(~tJlifli'rION iflkN[~ [:l~l'[:) WORKSHEET J°b N°' °451-°3°89 Sidetrack N°'-- Page 1 °f 6 Company ARCO ALASKA, INC. Rig Contractor & No. DOYON - 141 Field TARN DEVELOPMENT FIELD Well Name & No.TARN DRILLSITE 2L/321 Survey Section Name 2L-321 BHI Rep. I~"~~ WELL DATA Target TVD,_ (FT) Target Coord. N/S Slot Coord. N/S -205.00 Grid Correction 0.000 Depths Measured From:RK~ MSL~ SS[- Target Description Target Coord. E/W Slot Coord. E/W -806.00 MaSh. Declination 26.770 Calculation MethodMINIMUM CURVATU1 Target Direction (DD) Build\Walk\DL pelfl0ft[~ 30mi-'] 10m~ Vert. Sec. Azim. 128.91 Mash. to Map Corr. 26.770 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction L~gl~ ~h TVD Section N(-~T/~S(-) E(+0F/TY (-' DL Build(+) Right(+) Comment Type (ET) (D-D) (DB).__. (ET).__. x---t (Per 100 F~l~rop (-) Left (-) MWD 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 26-DEC- 98 MWD 192.31 0.60 129.25 192.31 192.31 1.01 -0.64 0.78 0.31 0.31 ,,' 26-DEC- 98 MWD 276.24 0.54 128.66 83.93 276.23 1.84 -1.16 1.43 0.07 -0.07 26-DEC-9~ MWD 367.04 0.63 137.40 90.80 367.03 2.76 -1.80 2.10 0.14 0.10 27-DEC- 91 MWD 463.06 0.54 152.95 96.02 463.04 3.70 -2.59 2.66 0.19 -0.09 27-DEC-9~ MWD 559.52 1.03 148.80 96.46 559.49 4.93 -3.73 3.32 0.51 0.51 27-DEC-9~ MWD 650.38 2.71 128.07 90.86 650.30 7.85 -5.76 5.43 1.96 1.85 30'140M 27-DEC- 91~ MWD 741.20 4.14 131.54 90.82 740.96 13.27 -9.26 9.58 1.59 1.57 20'140M 27-DEC-.9~ MWD 833.14 5.68 141.64 91.94 832.56 21.02 -15.03 14.89 1.91 1.68 10.99 40'140M . 27-DEC-98 MWD '923.71 8.06 143.94 90.57 922.47 31.53 -23.67 21.41 2.64 2.63 2.54 40'140M 27-DEC-9~ MWD 1012.34 10.77 142.77 88.63 1009.90 45.57 -35.29 30.08 3.07 3.06 -1.32 45'HS I 27-DEC-9~ MWD 1103.61 13.44 141.90 91.27 1099.13 64.19 -50.43 I 41.78 2.93 2.93 -0.95 60'HS 27-DEC-9~ MWD 1193.68 17.09 141.38 90.07 1186.01 87.32 -69.02 56.51 4.'06 4.05 -0.58 60'HS -- 27-DEC-9~ MWD 1286.57 21.41 139.45 92.89 1273.69 117.33 -92.57 76.06 4.70 4.65 -2.08 75'5L ,~ -- 27-DEC-9~ MWD 1381.70 27.41 139.74 95.13 1360.27 155.94 122.50 101.52 6.31 6.31 0.30 75'5R 27-DEC-9~ MWD 1474.52 33.34 139.18 92.82 1440.32 202.06 -158.14 132.03 6.40 6.39 -0.60 62'5R 27-DEC-9~ MWD 1568.12 37.22 138.73 93.60 1516.71 255.29 -198.90 167.53 4.15 4.15 -0.48 62'HS I 27-DEC-9~ MWD 1659.21 41.33 139.85 91.09 1587.21 311.99 -242.62 205.11 4.58 4.51 1.23 75'HS 27-DEC-91~ MWD 1754.14 47.73 137.91 94.93 1654.85 377.53 -292.69 248.91 6.89 6.74 -2.04 75'20L 27-DEC-9~ MWD 1846.56 53.66 135.76 92.42 1713.38 448.33 -344.79 297.85 6.66 6.42 -2.33 47'20L(SHORT TRIP@1900') 27-DEC-9[ MWD 1942.23 58.30 134.33 95.67 1766.89 527.14 -400.86 353.88 5.01 4.85 -1.49 62'30L 27-DEC-91~ MWD 2036.33 62.48 '130.91 94.10 1813.38 608.75 -456.20 414.08 5.45 4.44 -3.63 62'20L 27-DEC-91~ MWD 2129.12 67.12 128.04 92.79 1852.89 692.67 -509.52 478.89 5.73 5.00 -3.09 20'20L 27-DEC-9[ MWD 2223.61 67.20 127.60 94.49 1889.57 779.74 -562.92 547.68 0.44 0.08 -0.47 .I SURVEY CALCULATION AND FIELD WORKSHEET No. 045]-03089 Sidetrack No._____ Page 2 of 6 Company ARCO ALASKA, INC. Rig Contractor & No. DOYON - 141 Field TARN DEVELOPMENT FIELD Well Name & No.TARN DRILLSITE 2L/321 Survey Section Name 2L-321 BHI Rep. WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -205.00 Grid Correction 0.000 Depths Measured From: RKB~ MSL[--] SS~ Target Description Target Coord. E/W Slot Coord. E/W -806.00 Magn. Declination 26.770 Calculation MethodMINIMUM CURVATUt Target Direction (DD) Build\Walk\DL pel.fl0ft[~ 30m[-] 10m~ Vert. Sec. Azim. 128.91 Magn. to Map Corr. 26.770 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool ~gl~~ ~T/)S +0F/T ~0g._ F~B)rOpBuild (+)(_) Right (-)(+) Comment Depth Angle Direction L TVD Section N( (-) E( (-', (peDrL100 Type (FT) (D-D) (DD) (FT) Left 27-DEC-9~ MWD 2315.79 67.19 127.27 92.18 1925.29 864.68 -614.57 615.15 0.33 -0.01 -0.36 27-DEC-9[ MWD 2409.19 67.12 129.12 93.40 1961.56 950.75 -667.79 682.80 1.83 -0.07 1.98 15'HS 27-DEC-9~ MWD 2502.15 68.42 130.73 92.96 1996.73 1036.78 -723.02 748.78 2.13 1.40 1.73 27-DEC-9~ MWD 2596.88 69.02 126.76 94.73 2031.12 1125.02 -778.24 817.61 3.96 0.63 -4.19 27-DEC-9~ MWD 2691.52 68.65 125.72 94.64 2065.29 1213.18 ~830.42 888.79 1.10 -0.39 -1.10 28-DEC-9~ MWD 2790.15 68.28 127.54 98.63 2101.50 1304.85 -885.15 962.41 1.76 -0.38 1.85 28-DEC-9~ MWD 2885.16 68.02 128.46 95.01 2136.86 1393.02 -939.44 1031.90 0.94 -0.27 0.97 28-DEC-91 MWD 2977.04 69.19 128.53 91.88 2170.38 1478.57 -992.69 1098.86 1.28 1.27 0.08 28-DEC-9~ MWD 3071.12 68.95 129.12 94.08 2203.98 1566.44 -1047.78 1167.32 0.64 -0.26 0.63 28-DEC-9~ MWD 3167.20 69.00 127.95 96.08 2238.46 1656.12 -1103.65 1237.47 1.14 0.05 -1.22 28-DEC-9~ MWD 3232.93 68.86 128.17 65.73 2262.09 1717.45 -1141.46 1285.76 0.38 -0.21 0.33 , 01-JAN-9[ MWD 3336.23 67.89 128.84 103.30 2300.16 1813.47 -1201.25 1360.91 1.12 -0.94 0.65 DRILL OUT 7 5/8" CASING 02-JAN-9[ MWD 3431.95 68.24 129.84 95.72 2335.91 1902.26 -1257.53 1429.58 1.04 0.37 1.04 02- JAN-9g MWD 3524.80 69.15 129.94 92.85 2369.65 1988.75 -1313.01 1495.95 0.99 0.98 0.11 -- 02- JAN-9[ MWD 3621.74 69.41 130.44 96.94 2403.95 2079.40 -1371.52 1565.21 0.55 0.27 0.52 02-JAN-9[ MWD 3716.88 67.87 130.07 95.14 2438.60 2167.97 -1428.78 1632.83 1.66 -1.62 -0.39 12'@180 02-JAN-9[ MWD 3812.35 68.06 130.81 95.47 2474.42 2256.44 -1486.18 1700.18 0.75 0.20 0.78 02-JAN-9[ MWD 3901.98 68.21 130.39 89.63 2507.80 2339.58 -1540.3i 1763.34 0.47 0.17 -0.47 '02-JAN-9[ MWD 3997.62 68.18 129.78 95.64 2543.32 2428.36 -1597.49 1831.28 0.59 -0.03 -0.64 02-JAN-9[ MWD 4088.96 68.46 130.43 91.34 2577.06 2513.22 -1652.17 1896.20 0.73 0.31 0.71 02-JAN-9[ MWD 4184.09 68.56 129.41 95.13 2611.91 2601.72 -1708.97 1964.09 1.00 0;11 -1.07 02-JAN-9[ MWD 4276.32 68.50 . 129.69 92..23 2645.67 2687.55 -1763.62 2030.27 0129 -0.07 0.30 02-JAN-9[ MWD 4369.11 68.52 130.39 92.79 2679.67 2773287 -1819.17 2096.37 0.70 0.02 0.75 02-JAN-9~ MWD 4463.88 68.48 131.66 94.77 2714.40 2861.98 ~ 1877.04 2162.89 1.25 -0.04 1.34 1-' Ll[r]'-l ::(-I Company ARCO ALASKA, INC. Rig Contractor & No.DOYON - 141 Field TARN DEVELOPMENT FIELD I Well Name & No.TARN DRILLSITE 2L/321 Survey Section Name 2L-321 BHI Rep. ~r~'rl~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -205.00 Grid Correction 0.000 Depths Measured From:RKl~ MSL[--] SS[- Target Description Target Coord. E/W Slot Coord. E/W -806.00 Magn. Declination 26.770 Calculation Method MINIMUM CURVATUI Target Direction (DD) Build\Walk\DL p6t00ft[~ 30m[~ 10m[-] Vert. Sec. Azim. 128.91 Magn. to Map Corr. 26.770 Map North to:OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction L~_gl~l TVD Section N(-~:T/~S(-) E(+0F/T~W(-' DL Build (+) Right (+) Comment Type (ET) (DD) (DD)_ _ (ET), -- ,---- (Per 100 F~Ejrop (-) Left (-) 02-JAN-9~. MWD 4559.10 68.70 129.91 95.22 2749.16 2950.58 -1934.95 2230.01 1.73 0.23 -1.84 ,-, 02-JAN-9~. MWD' 4646.54 68.58 129.96 87.44 2781.01 3032.00 -1987.22 2292.45 0.15 -0.14 0.06 02-JAN-9~. MWD 4747.72 68.40 131.46 101.18 2818.11 3126.08 -2048.61 2363.80 1.39 -0.18 1.48 02-JAN-9~ MWD 4841.75 68.38 132.05 94.03 2852,74 3213.40 -2106.83 2429.02 0.58 -0.02 0.63 25'90L 02-JAN-9~. MWD. 4935.58 69.10 130.96 93.83 2886.76 3300.75 -2164.78 2494.50 1.33 0.77 -1.16 02-JAN-95 MWD 5029.32 69.28 130.47 93.74 2920.07 3388.33 -2221.93 2560.92 0.52 0.19 -0.52 30'l10L 02-JAN-9~, MWD 5122.47 68.60 128.90 93.15 2953.54 3475.25 -2277.44 2627.81 1.73 -0.73 -1.69 02-JAN-9~. MWD 5217.38 68.53 128.04 94.91 2988.23 3563.59 -2332.40 2696.98 0.85 ' -0.07 -0.91 03-JAN-9~. MWD 5314.80 68.66 127.95 97.42 3023.78 3654.28 -2388.24 2768.46 0.16 0.13 -0.09 03-JAN-9! MWDI 540.7.30 68.96 127.71 92.50 3057.22 3740.51 -2441.13 2836.58 0.40 0.32 -0.26 03-JAN-9~. MWDI 5502.59 68.33 128.15 95.29 3091.92 3829.24 -2495.68 2906.58 0.79 -0.66 0.46 03-JAN-9~. MWD' 5594.24 68.46 127.91 91.65 3125.66 3914.44 -2548.18 2973.70 0.28 0.14 -0.26 03-JAN-9! MWD 5689.63 69.06 128.41 95.39 3160.22 4003.34 -2603.11 3043.60 0.80 0.63 0.52 03-JAN-9! MWD 5778.60 69.21 128.06 88.97 '3191.91 4086.47 -2654.57 3108.91 0.40 0.17 -0.39 03- JAN-9! MWD 5875.77 69.26 126.57 97.17 3226.36 4177.29 -2709.64 3181.16 1.43 0.05 -1.53 03-JAN-9! MWDI 5968.01 68.43 127.96 92.24 3259.65 4263.28 -2761.72 3249.62 1.67 -0.90 1.51 10'180 03- JAN-9! MWD 6063.84 69.07 126.66 .95.83 3294.38 4352.55 -2815.86 3320.66 1.43 0.67 -1.36 03-JAN-9! MWD 6158.44 69.56 126.91 94.60 3327.80 4440.99 -2868.85 3391.54 0.57 0.52 0.26 03-JAN-95 MWD: 6251.09 69.87 127.31 92.65 3359.92 4527.85 -2921.29 3460.84 0.53 0.33 0.43 15'180 04-JAN-9~ 'MWD 6344.88 70.21 127.27 93.79 3391.94 4615.98 -2974.69 3530.98 0.36 0.36 -0.04 20'180 04-JAN-9~. MWDI 6442.47 68.88 126.74 97159 3426.04 4707.36 -3029.73 3604.00 1.45 -1.36 -0.54 04- JAN-9~ MWD 6533.63 68.63 126.4i 91.16 3459.07 4792.25 -3080.36 3672.23 0.43 -0.27 -0.36 04- JAN-% MWD 6628.45 68.94 127.53 94.82 3493.39 4880.60 -3133.52 3742.85 1.15 0.33 1.18 04-JAN-9~ MWD 6721.51 68.15 126.92 93.06 3527.43 4967.17 -3185.91 3811.81 1.05 -0.85 -0.66 i i~ S[JRVI::'~r C'ifliL("~Ut'ifliTION AND FII:::LD WOi~KSHEET J°b N°' 0451'03089 Sidetrack N°'~' Page 4 °f 6 Company ARCO ALASKA, INC. Rig Contractor & No.DOYON - 141 Field TARN DEVELOPMENT FIELD Well Name & No.TARN DRILLSITE 2L/321 Survey Section Name 2L-321 BHI Rep. WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -205.00 Grid Correction 0.000 Depths Measured From: RKI~ MSL[~ SS~ Target Description Target Coord. E/W Slot Coord. E/W -806.00 Magn. Declination 26.770 Calculation MethodMINIMUM CURVATUt Target Direction (DD) Build\Walk\DL pd~10ft[~ 30m[-] 10m[--] Vert. Sec. Azim. 128.91 Magn. to Map Corr. 26.770 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Total Coordinate Build Rate Walk Rate Course Vertical Build (+) Right (+) Comment Date Tool Depth Angle Direction L~gl[ [1,, TVD Section N(- ~ -~T/~S(-) E( +0F~,? (-' DL Type (FT) (D-D) (DD) (FT) (Per 100 F'll~rop (-) Left (-) 05-JAN-9! MWD 6819.37 68.89 127.08 97.86 3563.26 5058.18 -3240.72 3884.54 0.77 0.76 0.16 -- 05-JAN-9! MWD 6912.03 70.11 127.67 92.66 3595.71 5144.94 -3293.40 3953.51 1.45 1.32 0.64 20'180 05- JAN-9! MWD 7004.71 68.69 126.41 92.68 3628.32 5231.64 -3345.66 4022.75 1.99 -1.53 -1.36 05- JAN-9! MWD 7100.01 69.45 126.77 95.30 3662.36 5320.58 -3398.72 4094.22 0.87 0.80 0.38 05-JAN-9! MWD 7192.15 69.70 126.56 92.14 3694.52 5406.86 -3450.28 4163.48 0.35 0.27 -0.23 20'160R 05-JAN-9! MWD 7286.35 67.11 128.64 94.20 3729.19 5494.41 -3503.70 4232.87 3.43 -2.75 2.21 05- JAN-9¢ MWD 7382.49 67.33 128.72 96.14 3766.41 5583.05 -3559.10 4302.07 0.24 0.23 0.08 05- JAN-9! MWD 7475.67 67.37 128.36 93118 3802.30 5669.04 -3612.68 4369.33 0.36 0.04' -0.39 05- JAN-9! MWD 7571.66 67.44 128.26 95.99 3839.18 5757.66 -3667.62 4438.87 0.12 0.07 -0.10 05- jAN-9¢ MWD 7664.91 67.83 128.44 93.25 3874.66 5843.89 -3721.12 4506.50 0.45 0.42 0.19 05-JAN-9¢ MWD 7758.86 68.12 128.23 93.95 3909.89 5930.98 -3775.14 4574.82 0.37 0.31 -0.22 15'180 05-JAN-9[ MWD 7855.38 65.92 129.57 96.52 3947.57 6019.83 -3830.93 4643.97 2.61 -2.28 1.39 05-JAN-9~ MWD 7947.71 65.94 128.82 92.33 3985.23 6104.13 -3884.21 4709.30 0.74 0.02 -0.81 05- JAN-9¢ MWD 8041.08 65.78 129.05 93.37 4023.41 6189.34 -3937.75 4775.58 0.28 -0.17 0.25 ~!' -- 05-JAN-9[ MWD 8134.38 65.93 128.75 93.30 4061.58 6274.47 -3991.22 4841.84 0.33 0.16 -0.32 05-JAN-9~ MWD 8228,97 65.97 128.71 94.59 4100.13 6360.85 -4045.26 4909.22 0.06 0.04 -0.04 05-JAN-9~ MWD 8322.83 65.65 128.81 93.86 4138.59 6446.47 -4098.86 4975.99 0.35 -0.34 0.11 .. 05- JAN-9[ MWD 8415.29 66.09 128.96 92.46 4176.39. 6530.85 -4151.83 5041.67 0.50 0.48 0.16 . 06-JAN-9~ MWD 8509.45 65.88 129.96 94.16 4214.71 6616.85 -4206.49 5108.07 1.00 -0.22 1.06 20'45R 06- JAN-9[ MWD 8603.11 67.77 126.90. 93.66 4251.57 6702.94 -4259.99 5175.52 3.62 2.02 -3.27 ,, 06--JAN}9[ MWD 8698.67 68.11 127.86 . 95.56 4287.46 6791.47 -4313.75 5245.89 1.00 0.36 1.00 06- JAN-9[ MWD 8792.53 68.85 126.71 93286 4321.89 6878.75 -4366.64 5315.36 1.39 0.79 -1.23 06-JAN-9[ MWD 8887.75 69.56 126.98 95.22 4355.70 6967.71 -4420.02 5386.60 0.79 0.75 0.28 15'180 06- JAN-9[ MWD 8983.03 68.21 127.94 95.28 4390.02 '7056.56 -4474.08 5457.15 1.70 -1.42 1.01 i SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-03089 Sidetrack No.__ Page 5 of 6 Company ARCO ALASKA, INC. Rig Contractor & No. DOYON - 141 Field TARN DEVELOPMENT FIELD Well Name & No.TARN DRILLSITE 2L/321 Survey Section Name 2L-321 BHI Rep. I~"~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -205.00 Grid Correction 0.000 Depths Measured From:RKl~ MSL[~ SS~ Target Description Target Coord. E/W Slot Coord. E/W -806.00 Magn. Declination 26.770 Calculation Method MINIMUM CURVATUt Target Direction (DD) Build\Walk\DL pd~0ft[~ 30m[--] 10m[--] Vert. Sec. Azim. 128.91 Magn. to Map Corr. 26.770 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate '~T/)S +OF/T? 'rl T-~Build (+) RightLeft(_) (+) Comment Date Tool Depth Angle Direction Len~th(FT) TVD Section N( (-) E( ((peDL00!F__rop(_) Type (FT) (DD) (DD) (FT) 06-JAN-9[ MWD 9076.78 68.99 127.84 93.75 4424.23 7143.83 -4527.68 5526.04 0.84 0.83 -0.11 06- JAN-gr~ MWD 9171.43 69.99 127.50 94.65 4457.39 7232.46 -4581.86 5596.21 1.11 1.06 -0.36 ' 06-JAN-9[ MWD 9264.75 68.06 126.33 93.32 4490.80 7319.53 -4634.20 5665.87 2.38 -2.07 -1.25 20' 180 06-JAN-9[ MWD 9356.78 68.76 127.17 92.03 4524.66 7405.04 -4685.40 5734.43 1.14 0.76 0.91 06-JAN-9~ MWD 9450.85 69.98 127.37 94.07 4557.80 7493.04 -4738.71 5804.49 1.31 1.30 0.21 06-JAN-9~ MWD 9546.31 67.77 126.51 95.46 4592.21 7582.03 -4792.22 5875.65 2.46 -2.32 -0.90 25' 180 06-JAN-9[ MWD 9638.95 67.85 127.77 92.64 4627.20 7667.77 -4844.01 5944.03 1.26 0.09 1.36 06-JAN-9[ MWD 9733.45 68.83 126.77 94.50 4662.08 7755.55 -4897.19 6013.92 1.43 1.04 -1.06 06- JAN-9[ MWD 9826.21 69.79 126.20 92.76 4694.85 7842.25 -4948.79 6083.69 1.18 1.03 -0.61 06-JAN-9S MWD 9918.95 69.16 125.34 92.74 4727.37 7928.97 -4999.56" 6154.16 1.10 -0.68 -0.93 15' 180 06-JAN.9[ 'MWD 10011.27 68.74 126.17 92.32 4760.53 8015.00 -5049.90 6224.08 0.95 -0.45 0.90 07-JAN-9['~ MWD 10105.88 68.92 126.33 94.61 4794.69 8103.13 -5102.07 6295.23 0.25 0.19 0.17 07-JAN-9[ MWD 10200.28 69.24 124.47 94.40 4828.40 8191.14 -5153.15 6367.10 1.87 0.34 -1.97 .__ 07-JAN-9~ MWD 10293.86 69.90 125.55 93.'58 4861.07 8278.63 -5203.46 6438.92 1.29 0.71 1.15 / -- 07-JAN-9[ MWD 10387.09 68.08 125.86 93.23 4894.49 8365.52 -5254.25 6509.59 1.98 -1.95 0.33 20' 07-JAN-9~ MWD 10478.52 68.05 125.52 91.43 4928.65 8450.20 -5303.73 6578.47 0.35 -0.03 -0.37 07-JAN-9~ MWD 10573.30 68.86 125.51 94.78 4963.45 8538.20 -5354.94 6650.23 0.85 0.85 -0.01 07-JAN-9[ MWD 10668.57 69.06 125.10 95.27 4997.66 8626.94 -5406.33 6722.80 0.45 0.21 -0.43 07-JAN-9[ MWD 10760.68 68.54 127.77 92.11 5030.97 8712.73 -5457.32 6791.88 2.76 -0.56 2.90 31' 07-JAN-9[ MWD 10854.98 67.04 129.81 94.30 5066.62 8800.02 -5512.00 6859.93 2.56 -1.59 2.16 15' 07-JAN-9~ MWD 10948.70 65.03 128.38 93272 5104.69 8885.65 -5566.01 6926.38 2.56 -2.14 -1.53 15' 07-JAN-9[ MWD 11041.14 62.97 129.67 92.44 5145.21 8968.73 -5618.31 6990.93 2.56 -2.23 1.40 20' 07-JAN-9~. MWD 11135.77 61.14 130.08 94.63 5189.55 9052.31 -5671.90 7055.08 1.97 -1.93 0.43 20' 07-JAN-9[~ MWD 11232274 59.27 130.52 96.97 5237.73 9136.43 -5726.33 7119.26 1.97 -1.93 0.45 31' ~~ !.~'~ SURVI::Y CII. LCUL/lllTION AND [~ll:LD ~I/ORKSHI~I:T Job No. 0451-03089 Sidetrack No.__ Page 6 of 6 [~ ::~-'~1[[114-' I Company ARCO ALASKA, INC. Rig Contractor & No. DOYON - 141 Field TARN DEVELOPMENT FIELD I Well Name & No.TARN DRILLSITE 2L/321 Survey Section Name 2L-321 BHI Rep. I~'r~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -205.00 Grid Correction 0.000 Depths Measured From:RKl~ MSL[~ SS[- Target Description Target Coord. E/W Slot Coord. E/W -806.00 Magn. Declination 26.770 Calculation Method MINIMUM CURVATUI Target Direction (DD) Build\Walk\DL p~lfl0ft[~ 30m~ 10m[-] Vert. Sec. Azim. 128.91 Magn. to Map Corr. 26.770 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Depth Angle Direction L~g~ TVD Section N(-~T/?(-) E(+()F/T~0V(- (peDrL100 F'lE}rop (-) Left (-) Type (FT) (DD) (DD) (FT) 08-JAN-9c. MWD 11323.86 57.11 130.86 91.12 5285.76 9213.83 -5776.81 7177.97 2.39 -2.37 0.37 31' 08-JAN-9t. MWD 11420.13 54.89 128.42 96.27 5339.60 9293.62 -5827.73 7239.41 3.12 -2.31 -2.53 31' ~: 08-JAN-9t. MWD 11514.62 54.43 130.18 94.49 5394.25 9370.69 -5876.54 7299.05 1.60 -0.49 1.86 .. 08-JAN-9t. MWD 11608.95 55.03 130.03 94.33 5448.72 9447.68 -5926.16 7357.96 0.65 0.64 -0.16 08-JAN-9~ MWD 11702.86 55.55 129.88 93.91 5502.20 9524.87 -5975.73 7417.13 0.57 0.55 -0.16 08-JAN-9t. MWD 11797.08 55.83 130.22 94.22 5555.31 9602.68 -6025.81 7476.71 0.42 0.30 0.36 08-JAN-9~. MWD 11891.40 55.86 128.68 94.32 5608.26 9680.72 -6075.40 7536.97 1.35 0.03 -1.63. 08-JAN-9~. MWD 11986.14 56.11 128.91 94.74 5661.26 9759.25 -6124.60 7598.18 0.33 0.26 0.24 08-JAN-9! MWD 12081.42 56.30 129.57 95.28 5714.26 9838.43 -6174.69 7659.50 0.61 0.20 0.69 08-JAN-9! MWD 12174.75 56.26 128.25 93.33 5766.07 9916.06 -6223.45 7719.91 1.18 -0.04 -1.41 08-JAN-9g MWD 12269.72 57.09 127.45 94.97 5818.25 9995.40 -6272.13 7782.57 1.12 0.87 -0.84 08-JAN-9g MWD 12332.31 57.25 127.02 62.59 5852.18 10047.97 -6303.96 7824.44 0.63 0.26 -0.69 08-JAN-9g MWD 12403.00 57.25 127.02 70.69 5890.42 10107.39 -6339.75 7871.91 0.00 0.00 0.00 NO SURVEY EXTRAPOLATE TO TD -- . Arco Alaska Inc. North Slope Alaska ASP Zone 4 Kuparuk 2L, Slot 2L-321 2L-321 Job No. AKMM90051, Surveyed: 26 December, 1998 SURVEY REPORT 25 January, 1999 ORI61NAL Your Ref: API-501032028600 KBE-146.10 MWD SURVEY INSTRUMENT Surface Coordinates: 5927641.12 N, 460727.42 E (70° 12' 47.7231" N, 150° 19' 00.2158" W) ORILLINB c= IE RVI r" ES Survey Ref: svy1944 Sperry-Sun Drilling Services Survey Report for 2L-321 Your Ref: API-501032028600 Job No. AKMM90051, Surveyed: 26 December, 1998 Arco Alaska Inc. North Slope Alaska · -~ Measured .... Depth Incl. (ft) Azim. Sub-Sea Depth (ft) 0.00 0.000 0.000 -146.10 192.31 0.600 129,240 46.21 276.24 0.540 128.660 130.13 367.05 0~630 137.400 220.94 463.05 0.540 152.950 316.93 559.53 1.030 148.810 413.40 650.38 2.710 128.070 504.20 741.20 4.140 131.540 594.86 833.14 5.680 141.640 686.46 923.71 8.060 143.940 776.37 1012.34 10.770 142.770 863.80 1103.61 13.440 141.900 953.03 1193.68 17.090 141.380 1039.91 1286.57 21.410 139.450 1127.59 1381.70 27.410 139.740 1214.17 1474.52 33.340 139.180 1294.22 1568.12 37.220 138.730 1370.61 1659.24 41.330 139.850 1441.14 1754.14 47.730 137.910 1508.76 1846.56 53.660 135.760 1567.28 1942.33 58.300 134.330 1620.85 2036.33 62.480 130.910 1667.29 2129.12 67.120 128.040 1706.80 2223.61 67.200 127.600 1743.47 2315.71 67.190 127.270 1779.17 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.00 N 0.00 E 5927641.12 N 460727.42 E 192.31 0.64 S 0.78 E 5927640.48 N 460728.20 E 276.23 1.16 S 1.43 E 5927639.95 N 460728.84 E 367.04 1.80 S 2.10 E 5927639.31N 460729.51 E 463.03 2.59 S 2.66 E 5927638.52 N 460730.07 E 559.50 3.73 S 3.32 E 5927637.37 N 460730.72 E 650.30 5.76 S 5.43 E 5927635.33 N 460732.82 E 740.96 9.26 S 9.58 E 5927631.81 N 460736.95 E 832.56 15.02 $ 14.89 E5927626.02 N 460742.23 E 922.47 23.67 S 21.41 E 5927617.34 N 460748.70 E 1009.90 35.29 S 30.08 E 5927605.67 N 460757.31E 1099.13 50.43 S 41.78 E 5927590.47 N 460768.94 E 1186.01 69.02 S 56.51 E 5927571.81 N 460783.57 E 1273.69 92.57 S 76.06 E 5927548.15 N 460802.99 E 1360.27 122.50 S 101.52 E 5927518.09 N 460828.30 E 1440.32 158.14 $ 132.03 E 5927482.29 N 460858.62 E 1516.71 198.90 S 167.53 E 5927441.35 N 460893.91E 1587.24 242.63 S 205.12 E 5927397.43 N 460931.28 E 1654.86 292.69 S 248.91 E 5927347.14 N 460974.80 E 1713.38 344.79 S 297.85 E 5927294.79 N 461023.47 E 1766.95 400.92 S 353.93 E 5927238.36 N 461079.26 E 1813.39 456.20 S 414.08 E 5927182.77 N 461139.12 E 1852.90 509.52 S 478.88 E 5927129.11 N 461203.65 E 1889.57 562.92 S 547.67 E 5927075.36 N 461272.16 E 1925.27 614.53 S 615.09 E 5927023.40 N 461339.30 E Dogleg Rate (°/100ft) 0.312 0.072 0.139 0.189 0.511 1.964 1.590 1.915 2.645 3.065 2.932 4.055 4.700 6.308 6.396 4.155 4.577 6.894 6.663 5.000 5.456 5.730 0.437 0.330 Vertical Section (ft) 0.00 1.01 1.84 2.76 3.70 4.93 7.84 13.27 21.02 31.53 45.57 64.19 87.32 117.33 155.94 202.06 255.29 312.01 377.52 448.32 527.23 608.75 692.67 779.73 864.60 ASP Zone 4 Kuparuk 2L Comment Continued... 25 January, 1999 - 14:36 - 2 - DrillQuest Arco Alaska Inc. North Slope Alaska .,. Measured Depth Incl. (ft) Azim. Sub-Sea Depth (ft) 2409.19 67.120 129.120 1815.47 2502.15 68.420 130.730 1850.64 2596,88 69.020 126.760 1885,03 2691.52 68.650 125.720 1919.20 2790.15 68.280 127.540 1955,41 2885.16 68.020 128.460 1990.77 2977.04 69.190 128.530 2024.28 3071.12 68.950 129,120 2057.89 3167.20 69.000 127.950 2092.36 3232.93 68.860 128.170 2115.99 3336.23 67.890 128.840 2154,06 3431.95 68.240 129,840 2189.82 3524,80 69,150 129.940 2223.56 3621.74 69.410 130.440 2257,85 3716.88 67.870 130.070 2292.51 3812.35 68.060 130.810 2328.32 3901,98 68,210 130.390 2361.70 3997,42 68,180 129,780 2397.16 4088.96 68.460 130.430 2430.97 4184.09 68.560 129.410 2465.82 4276.32 68.500 129.690 2499.58 4369.11 68.520 130.390 2533.57 4463.88 68.480 131.660 2568.31 4559.10 68.700 129.910 2603.07 4646.54 68.580 129.960 2634,92 Sperry-Sun Drilling Services Survey Report for 2L-321 Your Ref: API-501032028600 Job No. AKMM90051, Surveyed: 26 December, 1998 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 1961,57 667.79 S 682.79 E 5926969.79 N 461406,73 E 1996.74 723.02 S 748,77 E 5926914,22 N 461472,42 E 2031.13 778.24 S 817.60 E 5926858.63 N 461540,96 E 2065.30 830.42 S 888.78 E 5926806,09 N 461611.87 E 2101.51 885.15 S 962.41 E 5926750.97 N 461685.21 E 2136.87 939.44 S 1031.90 E 5926696.32 N 461754.42 E 2170.38 992,69 S 1098.85 E 5926642.73 N 461821.09 E 2203.99 1047.78 S 1167.31 E 5926587.28 N 461889.26 E 2238.46 1103.65 S 1237.46 E 5926531.05 N 461959.12 E 2262.09 1141.46 S 1285.75 E 5926492.98 N 462007.22 E 2300.16 1201.25 S 1360.90 E 5926432.81N 462082.06 E 2335.92 1257.53 S 1429.57 E 5926376.17 N 462150.43 E 2369.66 1313.01S 1495.94 E 5926320.35 N 462216.51E 2403.95 1371.52 S 1565.21E 5926261.48 N 462285.47 E 2438.61 1428.78 S 1632.82 E 5926203.87 N 462352.79 E 2474.42 1486.18 S 1700.18 E 5926146.12 N 462419.84 E 2507.80 1540.31S 1763.33 E 5926091.66 N 462482.72 E 2543,26 1597.37 S 1831.13 E 5926034,25 N 462550.22 E 2577.07 1652.17 S 1896.19 E 5925979.11N 462614.99 E 2611.92 1708.97 S 1964.08 E 5925921.96 N 462682.58 E 2645.68 1763.62 S 2030.26 E 5925866.96 N 462748.48 E 2679.67 1819.17 S 2096.36 E 5925811.07 N 462814.29 E 2714.41 1877.04 S 2162.88 E 5925752.85 N 462880.51 E 2749.17 1934.95 S 2230.00 E 5925694.60 N 462947.32 E 2781.02 1987.22 S 2292.44 E 5925642.00 N 463009.49 E Dogleg Rate (°/100ft) 1.825 2.127 3.956 1.097 1,757 0.939 1.275 0.639 1.138 0.378 1.116 1 ,O36 0,985 0.552 1.659 0.746 0.466 0.594 0.727 1.003 0.290 0.702 1.248 1.727 0,147 Vertical Section (ft) 950.74 1036.77 1125.02 1213.18 1304.84 1393.02 1478.56 1566.43 1656.11 1717.44 1813.47 1902.25 1988.74 2079.39 2167.97 2256.43 2339.58 2428.17 2513.22 2601.72 2687.54 2773.86 2861.98 295O.57 3031.99 ASP Zone 4 Kuparuk 2L Comment Continued... 25 January, 1999 - 14:36 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 2L-321 Your Ref: API-501032028600 Job No. AKMM90051, Surveyed: 26 December, 1998 Arco Alaska Inc. North Slope Alaska , . Measured Depth Incl. (ft) Azim. Sub-Sea Depth (ft) 4747.72 68.400 131.460 2672.02 4841.75 68.380 132.050 2706.65 4935.58 69.100 130.960 2740.67 5029.32 69.280 130.470 2773.98 5122.47 68.600 128.900 2807.45 5217.38 68.530 128.040 2842.14 5314.80 68.660 127.950 2877.69 5407.30 68.960 127.710 2911.12 5502.59 68.330 128.150 2945.82 5594.24 68.460 127.910 2979.57 5689.63 69.060 128.410 3014.13 5778.60 69.210 128.060 3045.82 5875.77 69.260 126.570 3080.27 5968.01 68.430 127.960 3113.56 6063.84 69.070 126.660 3148.29 6158.44 69.560 126.910 3181.71 6251.09 69.870 127.310 3213.83 6344.88 70.210 127.270 3245.84 6442.47 68.880 126.740 3279.95 6533.63 68.630 126.410 3312.98 6628.45 68.940 127.530 3347.29 6721.51 68.150 126.920 3381.33 6819.37 68.890 127.080 3417.17 6912.03 70.110 127.670 3449.62 7004.71 68.690 126.410 3482.23 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 2818.12 2048.61S 2363.79 E 5925580.24 N 463080.52 E 2852.75 2106.83 $ 2429.01 E 5925521.68 N 463145.44 E 2886.77 2164.78 S 2494.49 E 5925463.40 N 463210.62 E 2920.08 2221.93 S 2560.91 E 5925405.90 N 463276.74 E 2953.55 2277.44 $ . 2627.80 E 5925350.04 N 463343.34 E 2988.24 2332.40 $ 2696.97 E 5925294.72 N 463412.22 E 3023.79 2388.24 S 2768.45 E 5925238.52 N 463483.41 E 3057.22 2441.13 S 2836.57 E 5925185.27 N 463551.25 E 3091.92 2495.68 S 2906.57 E 5925130.35 N 463620.97 E 3125.67 2548.18 S 2973.69 E 5925077.51 N 463687.81 E 3160.23 2603.11 S 3043.60 E 5925022.21 N 463757.44 E 3191.92 2654.57 S 3108.90 E 5924970.42 N 463822.47 E 3226.37 2709.64 S 3181.16 E 5924914.97 N 463894.44 E 3259.66 2761.72 S 3249.62 E 5924862.53 N 463962.63 E 3294.39 2815.86 S 3320.65 E 5924808.03 N 464033.38 E 3327.81 2868.85 S 3391.53 E 5924754.66 N 464103.98 E 3359.93 2921.29 S 3460.84 E 5924701.87 N 464173.01E 3391.94 2974.70 S 3530.97 E 5924648.10 N 464242.87 E 3426.05 3029.73 S 3603.99 E 5924592.68 N 464315.60 E 3459.08 3080.36 S 3672.22 E 5924541.70 N 464383.57 E 3493.39 3133.52 S 3742.84 E 5924488.18 N 464453.91 E 3527.43 3185.91S 3811.81E 5924435.42 N 464522.60 E 3563.27 3240.72 S 3884.53 E 5924380.24 N 464595.04 E 3595.72 3293.40 S 3953.50 E 5924327.20 N 464663.74 E 3628.33 3345.66 S 4022.74 E 5924274.58 N 464732.71 E Dogleg Rate (°/100fi) 1.391 0.584 1.327 0.525 1.734 0.847 0.159 0.405 0.789 0.282 0.796 0.404 1.435 1.669 1.430 0.574 0.525 0.365 1.455 0.435 1.149 1.045 0.771 1.445 1.992 Vertical Section (ft) 3126.08 3213.39 3300.74 3388.32 3475.24 3563.58 3654.27 3740.50 3829.23 3914.44 4003.34 4086.47 4177.29 4263.27 4352.55 4440.99 4527.85 4615.97 4707.35 4792.25 4880.59 4967.16 5058.17 5144.93 5231.64 ASP Zone 4 Kuparuk 2L Comment Continued... 25 January, 1999 - 14:36 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 2L-321 Your Ref: API-501032028600 Job No. AKMM90051, Surveyed: 26 December, 1998 Arco Alaska Inc. North Slope Alaska ., Measured Depth Incl. (ft) Azim. Sub-Sea Depth (ft) 7100.01 69.450 126.770 3516.27 7192.15 69.700 126.560 3548.42 7286.35 67.110 128.640 3583.09 7382.49 67.330 128.720 3620.32 7475.67 67.370 128.360 3656.20 7571.66 67.440 128.260 3693.08 7664.91 67.830 128.440 3728.57 7758.86 68.120 128.230 3763.80 7855.38 65.920 129.570 3801.48 7947.71 65.940 128.820 3839.14 8041.08 65.780 129.050 3877.32 8134.38 65.930 128.750 3915.49 8228.97 65.970 128.710 3954.03 8322.83 65.650 128.810 3992.50 8415.29 66.090 128.960 4030.29 8509.45 65.880 129.960 4068.62 8603.11 67.770 126.900 4105.48 8698.68 68.110 127.860 4141.37 8792.53 68.850 126.710 4175.80 8887.75 69.560 126.980 4209.61 8983.03 68.210 127.940 4243.93 9076.78 68.990 127.840 4278.14 9171.43 69.990 127.500 4311.30 9264.75 68.060 126.330 4344.70 9356.78 68.760 127.170 4378.57 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 3662.37 3398.72 S 4094.21E 5924221.15 N 464803.90 E 3694.52 3450.28 S 4163.47 E 5924169.23 N 464872.89 E 3729.19 3503.70 S 4232.87 E 5924115.45 N 464942.00 E 3766.42 3559.10 S 4302.06 E 5924059.69 N 465010.91E 3802.30 3612.68 S 4369.33 E 5924005.76 N 465077.89 E 3839.18 3667.62 S 4438.86 E 5923950.46 N 465147.15 E 3874.67 3721.12 S 4506.49 E 5923896.61N 465214.50 E 3909.90 3775.14 S 4574.81E 5923842.23 N 465282.53 E 3947.58 3830.93 S 4643.96 E 5923786.08 N 465351.39 E 3985.24 3884.21 $ 4709.30 E 5923732.47 N 465416.45 E 4023.42 3937.75 S 4775.57 E 5923678.58 N 465482.45 E 4061.59 3991.22 S 4841.83 E 5923624.77 N 465548.42 E 4100.13 4045.26 $ 4909.22 E 5923570.38 N 465615.53 E 4138.60 4098.86 S 4975.98 E 5923516.43 N 465682.01 E 4176.39 4151.83 S 5041.66 E 5923463.12 N 465747.42 E 4214.72 4206.49 S 5108.06 E 5923408.11N 465813.54 E 4251.58 4259.99 S 5175.51 E 5923354.27 N 465880.70 E 4287.47 4313.76 S 5245.89 E 5923300.13 N 465950.80 E 4321.90 4366.65 S 5315.36 E 5923246.88 N 466019.99 E 4355.71 4420.03 S 5386.59 E 5923193.14 N 466090.95 E 4390.03 4474.08 S 5457.15 E 5923138.72 N 466161.22 E 4424.24 4527.69 S 5526.03 E 5923084.75 N 466229.82 E 4457.40 4581.86 S 5596.20 E 5923030.21 N 466299.71 E 4490.80 4634.20 S 5665.86 E 5922977.51 N 466369.10 E 4524.67 4685.40 S 5734.42 E 5922925.96 N 466437.40 E Dogleg Rate (°/100ft) 0.872 0.345 3.431 0.241 0.359 0.121 0.455 0.372 2.613 0.742 0.283 0.335 0.057 0.355 0,498 0.995 3.618 0.997 1.386 0.791 1.700 0.838 1.109 2.376 1.140 Vertical Section (ft) 5320.57 5406.86 5494.41 5583.05 5669.04 5757.66 5843.89 5930.98 6019.83 6104.13 6189,33 6274.47 6360.85 6446.47 6530.85 6616.85 6702.93 6791,47 6878.74 6967.70 7056.55 7143.82 7232.45 7319.53 7405.04 ASP Zone 4 Kuparuk 2L Comment Continued... 25 January, 1999 - 14:36 - 5 - DrillQuest Sperry-Sun Drilling Services Survey Report for 2L-321 Your Ref: API-501032028600 Job No. AKMM90051, Surveyed: 26 December, 1998 Arco Alaska Inc. North Slope Alaska Measured Depth Incl. (ft) Azim. Sub-Sea Depth (ft) 9450.85 69.980 127.370 4411.71 9546.31 67.770 126.510 4446.11 9638.95 67.850 127.770 4481.10 9733.45 68.830 126.770 4515.98 9826.21 69.790 126.200 4548.76 9918.95 69.160 125.340 4581.27 10011.27 68.740 126.170 4614,43 10105.88 68.920 126.330 4648.60 10200.28 69.240 124.470 4682.31 10293.86 69.900 125,550 4714.98 10387.09 68.080 125.860 4748.40 10478.52 68.050 125.520 4782,55 10573.30 68.860 125.510 4817.36 10668.57 69.060 125.100 4851.56 10760.68 68.540 127.770 4884.88 10854.98 67.040 129.810 4920,53 10948.70 65.030 128.380 4958.59 11041.14 62.970 129.670 4999,12 11135.77 61.140 130.080 5043.46 11232,74 59,270 130.520 5091.64 11323.86 57.110 130.860 5139.67 11420.13 54.890 128,420 5193.50 11514.62 54.430 130.180 5248.16 11608.95 55.030 130.030 5302.63 11702.86 55,550 129.880 5356.11 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 4557.81 4738.71 S 5804.48 E 5922872.28 N 466507.17 E 4592.21 4792,22 S 5875.64 E 5922818,40 N 466578.06 E 4627,20 4844,01 S 5944,02 E 5922766,25 N 466646.16 E 4662.08 4897.20 S 6013,91 E 5922712,71 N 466715.78 E 4694.86 4948.79 S 6083.68 E 5922660.75 N 466785.28 E 4727.37 4999.56 S 6154.15 E 5922609.61 N 466855.48 E 4760.53 5049.91 S 6224.07 E 5922558.91 N 466925.14 E 4794.70 5102.07 S 6295.22 E 5922506.37 N 466996.02 E 4828.41 5153.15 S 6367.09 E 5922454.92 N 467067.62 E 4861.08 5203.46 S 6438.91 E 5922404.24 N 467139.18 E 4894.50 5254.25 S 6509.59 E 5922353.08 N 467209.59 E 4928.65 5303.73 S 6578.47 E 5922303.24 N 467278.21 E 4963.46 5354.94 S 6650.22 E 5922251.66 N 467349.70 E 4997.66 5406.33 S 6722.79 E 5922199.90 N 467422,00 E 5030.98 5457.32 S 6791.87 E 5922148.54 N 467490.81 E 5066,63 5512.00 S 6859.92 E 5922093.51 N 467558.58 E 5104,69 5566.01 S 6926.38 E 5922039.16 N 467624.75 E 5145.22 5618.32 S 6990.92 E 5921986.52 N 467689.02 E 5189.56 5671.91 S 7055.08 E 5921932.59 N 467752.90 E 5237.74 5726.33 S 7119.25 E 5921877.84 N 467816.79 E 5285.77 5776.81 S 7177.97 E 5921827.05 N 467875.24 E 5339.60 5827.73 S 7239.40 E 5921775.81 N 467936.41 E 5394.26 5876.55 S 7299.05 E 5921726.69 N 467995.80 E 5448.73 5926.16 S 7357.95 E 5921676.77 N 468054.45 E 5502.21 5975.73 S 7417.13 E 5921626.89 N 468113.36 E Dogleg Rate (°/100ft) 1,312 2.463 1.262 1.429 1.184 1.103 0.954 o.247 1.871 1.291 1.977 0.347 0.855 0.453 2.761 2.558 2.558 2.557 1.971 1.968 2.392 3.120 1.595 0.649 0.569 Vertical Section (ft) 7493.04 7582.03 7667.76 7755.55 7842.25 7928.97 8015.00 8103.13 8191.13 8278.62 8365.52 8450.19 8538.19 8626.94 8712.72 8800.02 8885.65 8968.73 9052.31 9136.43 9213.82 9293.61 9370.68 9447.68 9524.87 ASP Zone 4 Kuparuk 2L Comment Continued... 25 January, 1999 - 14:36 - 6- DrillQuest Sperry-Sun Drilling Services Survey Report for 2L-321 Your Ref: A PI-501032028600 Job No. AKMM90051, Surveyed: 26 December, 1998 Arco Alaska Inc. North Slope Alaska Measured Depth Incl. (ft) Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 11797.08 55.830 130.220 5409.22 5555.32 6025.81 S 7476.70 E 5921576.50 N 468172.68 E 11891.40 55.860 128.680 5462.17 5608.27 6075.40 S 7536.97 E 5921526.60 N 468232.68 E 11986.14 56.110 128.910 5515.17 5661.27 6124.60 S 7598.17 E 5921477.08 N 468293.63 E 12081.42 56.300 129.570 5568.17 5714.27 6174.69 S 7659.50 E 5921426.67 N 468354.70 E 12174.75 56.260 128.250 5619.98 5766.08 6223.45 S 7719.90 E 5921377.60 N 468414.84 E 12269.72 57.090 127.450 5672.16 5818.26 6272.14 S 7782.56 E 5921328.59 N 468477.25 E 12332.31 57.250 127.020 5706.09 5852.19 6303.96 S 7824.43 E 5921296.55 N 468518.96 E 12403.00 57.250 127.020 5744.33 5890.43 6339.76 S 7871.90 E 5921260.50 N 468566.24 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. Magnetic Declination at Surface is 26.765° (26-Dec-98) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 128.910° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12403.00ft., The Bottom Hole Displacement is 10107.39ft., in the Direction of 128.847° (True). Dogleg Rate (°/lOOft) 0.421 1.351 0.332 0.609 1.177 1.122 0.631 0.000 Vertical Section (ft) 9602.68 9680.72 9759.25 9838.43 9916.05 9995.39 10047.96 10107.38 ASP Zone 4 Kuparuk 2L Comment Projected Survey Continued... 25 January, 1999 - 14:36 - 7- DrillQuest Sperry-Sun Drilling Services Survey Report for 2L-321 Your Ref: API-501032028600 Job No. AKMM90051, Surveyed: 26 December, 1998 Arco Alaska Inc. North Slope Alaska . .~. Comments Measured Depth (ft) 12403.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 5890.43 6339.76 S 7871.90 E Comment Projected Survey ASP Zone 4 Kuparuk 2L 25 January, 1999 - 14:36 - 8 - DrillQuest 27-Jan-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2L-321 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 12,403.00' 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 [F ;w~4J 2L-321 ';;Yell Control Incident] Subject: [Fwd: 2L-321 Well Control Incident] Date: Mon, 11 Jan 1999 09:10:52 -0900 From: Blair Wondzell <Blair_Wondzell~admin.state.ak.us> Organization: SOA-AOGCC To: aogcc_prudhoe_bay~admin.state.ak.us Subject: Re: 2L-321 Well Control Incident Date: Mon, 11 Jan 1999 08:48:34 -0900 From: Blair Wondzell <Blair_Wondzell@admin. state.ak.us> Organization: SOA-AOGCC To: Paul Mazzolini <PMAZZOL~mail.aai.arco.com> CC: Mike Zanghi <MZANGHI~mail.aai.arco.com>, Tom J Brassfield <TBRASS~mail.aai.arco.com>, Morrison&Winfree <N1335@mail.aai.arco.com> Paul, Thanks for the info. Our objective was to aid you at looking at all relative aspects of the occurrence. We are now going to file the E-mail. Thank you, Blair 1/11/99. Paul Mazzolini wrote: Blair, Here are the answers to the the questions you have asked. - The element on the annular was changed out on 1/1 the day before the well kick occurred and successfully pressure tested. The problem with the element was found during the weekly BOP test. - The exact size of the kick is presently unknown. When the trip was started a relief pit watcher was working and didn't utilize the trip sheet. Valves were incorrectly lined up so mud was lost over the shakers (not sure for how long before spotted) and there were other valves in the mud pit that were incorrectly positioned. The best estimated that can be made at this time is 25-35 bbls. - The Driller's Method is not SOP once the drill string has been pulled up into the shoe. Parameters such as FIT~LOT results, size & type of influx, SICP & SIDPP are taken into account prior to utilizing the Driller's Method to circulate while weighting up the mud. - The annular will be tested next trip out of the hole and prior to running production casing. - The hole was being filled every 5 stands and after 15 stands were ~4~ pulled 16 barrels had been added to the hole. A total of 22 stands were pulled but, the pitwatcher had to add more mud to the trip tank, due to a leaking valve, so the total mud added to the hole is unknown. - The sand in question which seems to be causing our problems is equivalent to the Tabasco interval in the Kuparuk Field. This is a very serious incident and ARCO is continuing, with Doyon's assistance to resolve the reasons and practices, such as not filling out a trip sheet which lead to the well control incident. Please contact me with any further questions at 263-4603. Paul Mazzol ini Drilling Team Leader Blair Wondzell <Blair Wondzell@admin.state.ak.us> on 01/05/99 08:42:59 AM -- To: Paul Mazzolini/AAI/ARCO cc: aogcc_prudhoe_bay@admin, state, ak. us Subject: Re: 2L-321 Well Control Incident Paul, Thanks for the e-mail. We do have a couple of questions. *When did the kick occur relative to changing the annular preventer bag? *What was the size of the kick when first noticed? *Is it SOP to use the Drillers Method when half way out of the hole? 1 of 2 1/12/99 8:56 AM TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION December 23, 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Paul Mazzolini Drilling Team Leader ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 ac: Kupamk Rivcr Unit 2L-321 ARCO Alaska Inc. Pcrmit No: 98-262 Sur Loc: 205'FNL, 806'FEL, Sec. 22, T10N, R7E, UM Btmholc Loc. 1208'FNL, 1708'FWL. Sec. 25, T 10N, R7E, UM Dear Mr. Mazzolini' Enclosed is the approved application for permit to drill thc above rcfcrcnced ,,','ell. Annular disposal of drilling wastes vdll not bc approved for this well until sufficient data is submittcd to ensure that thc requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data. and any CQLs must be submitted to thc Commission on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 2L must comply with thc requirements and limitations of 20 AAC 25.080. Approval of this permit to drill docs not authorize disposal of drilling waste in a volume greater than 35,000 barrels through thc annular space of a single well or to usc that well for disposal purposes for a period longer than onc year. Thc permit to drill docs not exempt you from obtaining additional permits rcquircd by law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting dctcrminations are made. Blowout prevention equipment (BOPE) must bc tested in accordance v,'ith 20 AAC 25 035.' Sufficient notice (approximatcly 24 hours) must be given to allow a rcprcscntative of the Commission to witness a test of BOPE installed prior to drilling nexv hole. Notice may be given by. contacting thc Commission pctrolcum field inspcctor on thc North Slopc pager at 659-3607. Sinc 7 Chairman BY ORDER OF THE COMMISSION dlf/Enclosures I)epartmcnt of Fish & Game, Habitat Section w/o encl. Department et' Enviromnental Conservation w/o tmcl. r-- ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 12~ $ December 22, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2L-321 Dear Mr. Commissioner: We are asking AOGC _, to expedite processing of the Permit to Drill for 2L-321 due to rig scheduling changes. The change in rig' schedule will allow the Slope operatior~s to stimulate 2L- 305. there are any questions, [)lease call 265-6377, Sincerely, T. Brassfield / D'-illing Engineer AAI Engineer TJB/skad .. AlaskaOil &, Gas Cons. Commis~ STATE OF ALASKA ALA~I~A OIL AND GAS CONSERVATION COMrV~SlON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill J lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 115' feet Kuparuk River Field 3. Address 6. Property Designac.tJon Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380053,-ALK 4601 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 205' FNL, 806' FEL, Sec.22, T10N, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 887' FNL, 1299' FWL, Sec. 25, T10N, RTE, UM 2L-321 #U-630610 At total depth 9. App_roximate spud date Amount 1208' FNL, 1708' FWL, Sec. 25, T10N, R7E, UM 12J.25¢/98 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) propedylineI 2L-323 12285' MD 887' @ Target feet 25.7' @ 655.6' feet 2560 5839' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 600' feet Maximum hole angle 68.43° Maximum surface 1357 psig At total depth (TVD) 1610 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 90' 28' 28' 118' 118' +_.200 CF 9.875" 7.625" 29.7# L-80 BTC MOB 3305' 28' 28' 3335' 2300' 360 Sx Arcticset III & 235 Sx Class G 6.75" 5.5" 15.5# L-80 LTC-M 11279' 28' 28' 11307' 5278' 240 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 978' 11307' 5278' 12285' 5839' (included above) 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 Sudace Intermediate Production Perforatio~i;;rpth: measured ORIGINAL true vertical 20. Attachments Filing fee X Property plat r~ BOP Sketch X Diveder Sketch X Drilling program X Drilling fluid program X Timevs depth plot F.~ Refraction analysis F~ Seabed report ~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'"~O.~ '~'~~ Title Tarn Drilling Team Leader Date I~'/~-~l/~ Commission Use Only ~mt~ APl number I Approval date /~ ~. O~,,~ ~~ I See cover letter for Permit N r.... ~ & ~. 50- J I~ "~ ~)~ ~ ~ ~6 · '"' other requirements Conditions of approval Samples required Fl Yes [~ No Mud log required [~, Yes ~.' No Hydrogen sulfide measures F_l Yes ~ No Directional survey required [~ Yes Bi No Required working pressure for BOPE 2M [~(~[~ 5M E] 1OM E~ 15M Other: ORIGINAL SIGNED.By by order of Approved by Rob6rt N. Ohristenson Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. GENERAL D~ILLING AND COMPLETION PRO~;'C. DURE KUPARUK RIVER FIELD - PRODUCER KRU 2L 321 1. Move in and rig up Doyon 141. , . Install diverter system. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. Run and cement 7-5/8" 29.7#, L-80 BTC-Mod 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. NOTE: TAM Port Collar will be placed in the 7-5/8" 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 above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the . cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. See attached TAM Port Collar Utilization Decision Tree. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. , Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 7. Drill 6.75" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). . Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. ND BOPE and install production tree. 12. Secure well. Rig down and move out. 13. Hydrocarbon intervals will be tested after the rig move. ARCO Alaska, Inc. DRILLING ~ ~UlD PROGRAM, PRESSURE CAL~'ULATIONS, AND DRILLING AREA RISKS Well KRU 2L-321 Drilling Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-10.2 ppg 15-35 25-50 70-120' 10-25 15-40 5-7 9.5-10 +10% Drill out to TD 8.5- 10.0 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Arete & Tarn 9.0-10 <11% Drilling Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,357 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2L pad are expected to be -2,350 psi (0.50 psi/fi).. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a -I-VD of 5,100'. Well Proximity Risks' The nearest well to 2L-321 is 2L-323. The wells are 25.7' from each other at a depth of 655.6'. ARCO Alaska, Inc. Drilling Area Risks: The primary risk in the 2L-321 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8- 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300'-I-VD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2L-321 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2L-321 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDVV's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 100' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,100') + 1,500 psi Max Pressure - 2,810 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5½" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi ARCO Alaska, Inc. 18rd EUE Modl~O,~O psiI ~,,~,--r psi I~0,~0 psiI 8,636 psiI Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). ARCO Alaska, Inc. Diverter SChematic Doyon '14'1 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS El 3" 5,000 psi WP OCT MANUAL GATE VALVE ~ r'-j KILL LINE 3" 5,000 psi wP Shaffer GATE VALVE L w/hydraulic actuator I 1 DSA 13-5/8" 5,000 psi WP ....--"'~[_ x 11" 3,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple w/pipe rams on top and blind rams on bottom 3" 5,000 psi wP Shaffer GATE VALVE w/hydraulic actuator ;_~~ CHOKELINE 13-5/8" 5,000 psi WP DRILLING SPOOL L__~~ w/two 3" 5M psi WP outlets SINGLE 13-5/8" 5,000 psi WP, ' HYDRIL MPL BOP w/pipe rams c,.~t,z ~ ,;,~. FOR: BRASSYIELD O~tm plotted: 17~D~¢-~ Plot Referencl I$ 321 VlrlJon Coordlnote~ ore in feet referlnce True VerUcel Oepthe om re;~ce RKB (D~n ~141).~ 500 1000 1500 2000 2500 0 ~ooo > 3500 I--- 4000 4500 5000 5500 6000 IARCO Alaska, Inc. Structure : Tarn Drill Slfe 2L Well : 321 Field : Tarn Development Field Location : North Slope, Alaska. East (feet) -> 0 800 1600 2400 5200 4000 4800 5600 6400 7200 8000 SURFACE LOCATION' I I I I ~ ~ a I ~ I I ~ I a ~ ~ a I I I I I , 205' FNL, 806' FEi , ~ in ~ ~ ~1 .... il~ J SEC 22 TION R7E .~., (~ue..9 o uecj/ uu, ~ o m ' ' m '0 ~uase of PermoTrost Top of West Sok ~ ~egin Turn to Torge~ o= oo .oo O0 ~ B/PERMAFROST ~D= 1195 TMD= 1204 DEP=95 ~ 25.oo T/WIST ~K ~0=~237 ~UO=~5~ D[P=~ ~ ~TM ~500 DLS: 5.00 deg per 100 ft ~ 45.~ ~ BEGIN TURN TO TARG~ WD= 1676 TMD= 1800 DEP=427 ~ .... B/WEST SAK WD=1900 TMD=2247 DEP=809 ~~7 5/8" CASING_. PT WD=2500 TMD=5535 DEP=1B21 ~ ~ ~ [~ ~ ~ ~~ r Iceber Interval . . ~ I TARGg LOCATION: J Bsgln Angle ~op~ce g ANGLE I ...................... ~ I SEC 25~ RTE J ~ ~q~ B~rmud~ +G~'~O TD - Casing DEP=9492 SOUTH 5962 EA~ 7586 TD LOCATION: 1208' FNL 1708' FWL , . C40 WD=4187 TMD=8467 DEP=6593 m SEC 25,~10N, R7E .21 8.21 . C35 ~D=5667 TMD= 11985 DEP=9766 TD - CASING PT ~D=5839 TMD=12285 DEP=10012~ I I ! [ I ! I ! I I I i I i I I I I I I I II I Ii I [ I I I i I i I I I I I i I I I 0 500 1000 1500 2000 2500 ;5000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 Vertical Section (feet) -> AZimuth 128.91 with rOferen'ce 0.00 N, 0.00 ir from slot #$21 800 1600 ' 0 2400 ¢- --I- 3200 "~ 4000 I 48O0 5600 64OO ARCo Alaska, Inc. Sfructure : Tarn Drill Site 2L Well: 321 Field : Tarn Developmenf Field Location : Norfh Slope, Alaska WELL PROFILE DATA TM .a.-lO (0 321 R 1 l~4e, e7 Tn. · F..Jtd ~! H~Jd 1.22~4..71 320 540 \ 5O TRUE NORTH 0 10 210 700 2O ~0 1700 40 310 5O 300 6O 290 28 270 2 3 100 ._5po 80 26O 100 250 110 240 250 220 210 200 190 180 120 130 140 150 160 170 Normol Plone Trovelling Cylinder - Feet All depths shown ore Meosured depths on Reference Well ARCO Alaska, Inc. Structure : Tom Drill Site 2L Well : 321 Field : Tarn Development Field Location: Nodh Slope, Alaska East (feet) -> 80 40 0 40 80 120 160 200 240 280 320 560 400 440 480 520 560 4080t ' I Z [ ' ' i I I ' ' I '~l I~{~Iz' ' ' I I I ' ' ' I ' ' ' ' 1~11 16007005~0~ --0~-°-- ~900~ ~0~ e ~__ -- 00__ __ __ ~go0__ --~1000__ __ ~1100__ 1200 4080 ~ ~ t .700 --.1100 ----~---__ 1300 )~ o 120 160 200 240 V -'~ 280 0 320 I v 360 400 440 800 '" ---~_.1200 800 "-o 800 . '" --- ...1500 ~ o N, go0 ~ ..900 ~'". go0 -" '" --- 1400 ~.go0 1(~C \% 1000 '~%1000 $~0- .~.. 1000 o..~....___ ~-1500 lOOO ~ x .... '- .... 1.oo 14o~ .~ ~ ~ 1100 ~0~%'\''~u '~ '~-'~.'~ "'"-,. 1500 '""~' '-, 1100 "' --- ~..16_..00_/~.>, 1300__ ~. 1200_ % 1200 ~ 1500 ~.~. 'k 1300'~%.' .. "-,~1600 ~... ~1200 1310401~ ' ~. 80 ~ ._ ' '~' ",,~1300 % 1300 ~ ~. 1300 -~"'~1500 " '~ 1800 17~'-- ' '~ 150'0X~uu -.. -. '~'~ I;O0".~ -~. 120 ~ ~' ~ ~ ~ 19oo '-.~_~ 13oo % 1 400 ',~ -.."'.~ ~ ~--- 1400 ~ ~ 1~oo %". ;~W '~ ~ 18o0'-~ .. ~ ' ~ ,t~ ~ ~ ~2ooo ~ ~ ~so ~ % ~ ~ 1700 ~ ~ ~ 1500 '. ~ ~ ~ ~ X~ ,~ ', 1500 ~100 ~ ~5ooN ~ ~ ~ ~ ~~oo ~. ~ ~ ~soo ~ ~ N x ~ %1600 ~1700 1600'x x %~900 xx ~ ~. 'q 9~ x ~ 280 ~ 1~oo x, ~ ~ ~ 32o ~ o X ~ % 2000 ~ x $1(~ 2100 400 ~ 1900 ~ ~ x ~ 1800 N x 22c~ ~0 East (feet) -> 480 520 560 600 200 0 240 ,--I- I v AI CO Alaska, Inc. Structure: Tarn Drill Site 2L Well : 521 Field: Tarn Development Field Location: North Slope, Alaska East (feet) -> 400 500 600 700 800 900 1000 1100 1200 1500 1400 1500 1600 1700 1800 1900 300J _~k %-2 ~2o..o ~__ 500 ~ ~- 1600 -" "'- --- ~2400 1 g 2200 x ~ '~ '"<-'--. --ccc. 600 xx,.x,.~xxx ~'.xxx ~o 700 700 2200 ! 800 0 ! ouu ~' % '%-= 2000 - 900 ~ ~. % % ~'~,.~. 900 ~' ~. ~' ~. 2600 ~ ~ ~ 1000 ~ ~ '%.. ~' 1000 '~ ' '. -. ",.,'~zoo o ,,_e 2400 ',,~22 ha.. ~ -., ~-c ~ 1100 x 1100 0 1200 x -- L 1200 '~ %2200 I x ' I -x. k 1500 v 1~oo "~;,, ~ v ~k 1400 1500 '~~. ~.3000 1500 2800 1800 ~.-.~ . J 600 1700 18O0 1900 2000 3000 i I i i i i I 400 500 600 700 800 900 1000 1100 1200 1500 1400 1500 1600 1700 1800 1900 East (feet) -> 1700 1800 1900 2000 C~ot,,.~ by ,,ix. Plot I~fenmc* ~e $21 Ye~on ~7. ARCO Alaska, Inc. Structure : Tarn Drill Site 2L Well : 521 Field: Tarn Development Field Location : Nor-th Slope, Alaska East (feet) -> 1200 1500 1800 21 O0 2400 2700 3000 35iX) 5600 5900 4200 4500 4800 51 O0 5400 5700 6 ~ %2700 900 ~ ~ ~2100 ~ ~ x ~ 900 [00 ~ 1200 ~ ~oo ~ ~ ~ ~ 2~o x~ 500 35oo ~oo 1 N 18oo 2100 2100 300 700 0 0 I 3 V ~ xx. x 4200 x 5600 3soo X°''~ '.~.. ~600 '--. 3600 3900 ~ ~ ~ ~ 3900 x ~nnn ~ % 4200 4200 4200 4500 NX' 4500 4800 5400 . ~ ~00 5100 ~ 5100 5400 5400 5700 5700 1200 1500 1800 21 O0 2400 27~ 5~0 5~0 3600 5900 4200 4500 ~800 51 O0 5400 5700 East (feel)-> C~oted by r'mH ~3~ I~Ot~ed: IS-Dec-gS PIoA Reference ia 321 Ve~lcm ~7 . Coordlr~e c:re In feet rlfer~.~ce ek:t ~321. Tr~ Vlrlicx]l Olp~ll Om r~lnc~ RKB (O~Tj~:~ ~1141). ARco Alaska, Inc. Structure : Tarn Drill Site 2L Well : .321 Field : Tarn Development Field Location: North Slope, Alaska East (feet) 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 7600 7800 8000 5400 t~ 5600~ 3800 4000 4200 4400 4600 480O 5000 5200 I V 54oo 5600 5800 6000 62OO 640O 6600 6800 600 '" -.. '-.3600 ).~ ~ 4200 5000~ ~ -,~ ~ %4400 5200 5400 3800 -,. 4600 5600 '- ~ %4800 '" ..4000 5000 I I I I [ I I I I I 440~ '~ ~ 4600 '~4400 ~ "~.4200 ~ .. 5200 -. 540O \%,5600 ~ %5800 i i r i i i i i i i i i i t i i i i i i i i i i i i i i i i i 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 East (feet) -> 7200 7400 7600 7800 8000 3400 3600 3800 4000 4200 4400 4600 4800 0 _ _5ooo 5200 ..~ I 54oo V 5600 5800 6000 6200 6400 6600 6800 ARCO Alaska, Inc. Tarn Drill Site 2L 321 slot #321 Tarn Development Field North Slope, Alaska MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 321 Version Our ref : prop2888 License : Date printed : 20-Dec-98 Date created : 17-Mar-98 Last revised : 17-Dec-98 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on nT0 12 49.742,w150 18 33.414 Slot location is n?0 12 47.729,w150 18 56.825 Slot Grid coordinates are N 5927641.118, E 460844.214 Slot local coordinates are 204.63 S 806.43 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PMSS <0-9200'>,,325,Tarn Drill Site 2L 317 Version #4,,317,Tarn Drill Site 2L 319 Version #4,,319,Tarn Drill Site 2L 311 Version #6,,311,Tarn Drill Site 2L PMSS <0-6864'>,,Arete,Tarn Drill Site 2L 329A PMSS <2506 - 6190'),,329A,Tarn Drill Site 303 Version #5,,303,Tarn Drill Site 2L 309 Version #5,,309,Tarn Drill Site 2L 315 PMSS <0-???'>,,315,Tarn Drill Site 2L PMSS <0-11140>,,313,Taru Drill Site 2L 307 Version #6,,30?,Tarn Drill Site 2L PMSS <0-9210'>,,305,Tarn Drill Site 2L 323 Version #5,,323,Tarn Drill Site 2L PMSS <0-???>,,323,Tarn Drill Site 2L PMSS <0-?650'>,,Tarn#2,TARN #2 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 19-NOv-98 )59.5( 100.0 23-Aug-98 )48.3( 933.3 5800.0 25-Nov-98 )27.3( 500.0 2240.0 25-Nov-98 )148.4( 300.0 300.0 16-Nov-98 )116.0( 400 0 400.0 16-Nov-98 )116.0( 400.0 9540.0 25-Nov-98 )268.3( 300.0 300.0 3-Dec-98 )177.2( 500.0 500.0 15-Dec-98 )82.8( 500.0 500.0 15-Dec-98 )117.7( 600.0 11320.0 15-Dec-98 )208.5( 300.0 8500.0 15-Dec-98 )239.1( 200.0 7520.0 4-Dec-98 )26.8{ 622.2 622.2 18-Dec-98 )25.7( 655.6 655.6 7-Dec-98 )0.0( 7620.0 10955.6 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 9951'0:0360 December 21, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re' Application for Permit to Drill KRU 2L-321 Surface Location: 205' FNL 806' FEL Sec 22 T10N R7E, UM Target Location: 887' FNL, 1299' FWL Sec. 25, T10N, R7E, UM Bottom Hole Location: 1208' FNL, 1708' FWL Sec. 25, T10N, R7E, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a '~ development well in the Tarn area, KRU 2L-321, located approximately six miles southwest of the Kuparuk River Unit's 2M Drillsite. :-¥ ~;~.' The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2L (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H~S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H~S. The following are ARCO's designated contacts for reporting responsibilities to the Commission' ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany David W. Johr' ~n Application for-,-ermit to Drill Page 2 KRU 2L-321 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2L-321 Well File ARCO Alaska, Inc. GENERAE~DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2L 321 1. Move in and rig up Doyon 141. 2. Install divertersystem. 3. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. , Run and cement 7-5/8" 29.7#, L-80 BTC-Mod 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. NOTE: TAM Port Collar will be placed in the 7-5/8" casing +! 000' 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 above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGOC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. See attached TAM Port Collar Utilization Decision Tree. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. o Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 7. Drill 6.75" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, su--~ient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). . Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. ND BOPE and install production tree. Secure well. Rig down and move out. !3. Hydrocarbon intervals will be tested after the rig move. ARCO Alaska, Inc. DRILLIN'~FLUID PROGRAM, PRESSURE C~LCULATIONS, AND DRILLING AREA RISKS Well KRU 2L-321 Drilling Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-10.2 ppg 15-35 25-50 70-120' 10-25 15-40 5-7 9.5-10 +10% Drill out to TD 8.5- 10.0 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Arete & Tarn 9.0-10 <11% Drilling Fluid System' ! Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,357 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2L pad are expected to be -.-2,350 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a -I-VD of 5,100'. Well Proximity Risks: The nearest well to 2L-321 is 2L-323. The wells are 25.7' from each other at a depth of 655.6'. ARCO Alaska, Inc, Drilling Area Risks: The primary risk in the 2L-321 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8- 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class I! disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid dunng any extended shut down (> 4 hr) in pumping operations. The 2L-321 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2L-321 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 100' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe -I-VD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,100') + 1,500 psi Max Pressure = 2,810 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5½" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi ARCO Alaska, Inc. 8rd EUE Mod110,530 psi1 8,~'~ psi 110,160 psiI 8,636 psiI Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). ARCO Alaska, Inc. Diverter Schematic Doyon 141 21¼" 2,000 psi wP DRILLING SPOOL w/16" Outlet Flowline ~ 21%" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE (/ 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS ] I 3" 5,000 psi WP OCT MANUAL GATE VALVE ~ KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE L_ w/hydraulic actuator Fl · J BSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple D~I~ .c~/§t~.~. ~.(~s~V./~,VE w/pipe rams on top and blind rams on bottom 3" 5,000 psi WP Shaffer GATE VALVE 1;/hydraulic actuator CHOKE LINE 13-5/8" 5,000 psi WP DRILLING SPOOL % w/two 3" 5M psi WP outlets ~SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams C,.~t.d by ,~.e FOR: BRASSFIELD Dote plotted: 17-Dec-DB Plot Reference [$ 321 Version ~7 . I C oordlnate~ are in feet reference slot 1~321. I ITrua VarUcol Oap[h= ara rafaranc= RKB (Doyon ~141).{ ARCO Alaska, Inc. Structure : Tarn Drill Site 2L Well : 321 Field : Tarn Development Field Location : North Slope, Alaska East (feet) -> 0 800 1600 2400 3200 4000 4800 5600 6400 7200 8000 500 1000 1500 2000 2500 C) 3000 --I..- ~ 3500 I-- 4000 I 4500 5000 5500 6000 SURFACE LOCATION' [ I I I I I t I t I I I ~ I I ~ ~ I ~ I I ~ ~ 205' FNL 806' FEi[ . , · ~' '>7 ~r~n~l o'7~ C, bBegln 5 Dec/lO0 Build [ ................ I ~'~'O"~,Base of Permofros~ 0 Top of West Sok ~ ~egln Turn to Target ~EOC RKB ELEVEATION 143' ~se of Wes~ Sok 800 ~7 5/8 Casing Pt KOP ~D=600 ~D=800 DEP=0 ~ 5.00 ~~ 9'O~EGIN 5 DEC/lO0' BUILD WD=1094 TMD=1100 DEP=64 z~ ~ B/PERMAFROST ~D= 1195 TMD= 1204 DEP=95 ~ ~ ~25.00T/WEST SAK ~D=1257 TMD=1251 DEP=111 ~ ~5.00 DLS: 5.00 dec per 100 fl ~ ~45.~ ~, BEG~N TURN TO TARG~ TVD=1676 TMD=lBO0 DEP=427 ~ ~.~ ~200 ~-'~ 063. EOC WD=1890 TMD=2220 DEP=784~uDu B/WEST SAK TVD:1900 TMD:2247 DEP=809 ............... ~v 5/B " CASING PT TVD=2300 TMD=3335 DEP=1B21 ~ m~ [m~ m · ~m~ ~ · ~ c~0 ~VD=2~ ¢~D=~O~ D~.=~ P4~ ~TU ]A~GET) ~ ~ ,*,Plane of Proposal*,, ~ 4800 . ~ ~ I Begin Angle Drop~ceberg Interval ...................... ~ I SEC 2s~, R7E 1%~_?~~~ ~V~=~ _ · TMD= 11 650 TD Casing P~ 6400 DEP=9492 SOUTH 5962 EA~ 7386 112~NL. 1708' FWL C40 TVD=4187 TMD=8467 DER=6595 ~ ~6~,-R)~- .21 8.21 C55 TVD=5667 TMD=11985 DEP=9766 ~ TD - CASING PT TVD=5B~9 TMD=12285 DEP=10012 ~ 1600 2400 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 i 0 §00 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6600 7000 7600 8000 8600 9000 9500 10000 10500 Vertical Section (feet) -> Azimuth 128.91 with reference 0.00 N, 0.00 E from slot #321 ARCO Alaska, Inc. Structure : Tarn Drill Si're 2L Well: 321 Field : Tarn Developmenf Field Location : North Slope, Alaska ..... Point ..... UD rum t~ 'ron~: 18D0.~ o~ ~1~ ~lg.~ a~ ~um 11~7.~ WELL PROFILE DATA 350 320 x TRUE NORTH 0 10 21 0 17oo 2O 310 ~,e FOR: BRASSF[ELD Dote I~otted: 15-Bec-gE [ ~mnce ;s 321 Ve~;~ ~7 . [ 1700 40 5O 500 6O 29O 270 o soo + 100 ~_spo 80 260 100 250 110 240 120 230 22O 210 2O0 190 180 130 140 150 160 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well Cr~t~l th' r~x~e FOR: BRA~SFIELD Dote ~oRe4: 16-D~-68 PI~ R~er~¢o ~ ~21 Ve~l~ ~7 . C~rd~no~ ore In T~ V~I Oep~s om mFe~ RKO (~n ~141),I ARCO Alaska, Inc. Sfrucfure: Tarn Drill STfe 2L Well : 521 Field : Torn Developmenf FTeld Looofion : North Slope, Aloeko 8O 40 4O 80 120 16O 200 240 280 520 56O 400 440 48,0 520 56O 60O 640 8O 40 0 40 I , , , , ' ~11~ ,700 ' ' ' ' ' I ~'~'~) I~ O~ ~ , ~)' 5~0~o~~ ~700 900 1 ;, 1600 ~ O0 lq~, 1000 1100 Eosf (feet) -> 80 120 160 200 240 280 520 360 400 440 480 520 560 I I I I I I I I I 8(3 800 %0 800 800 ~ 900 '~ ~.900 lO0 % 1000 % %1000 N%1100 '~ 1400 .~ 1100 "- 1500 130 ,~ 1200 % 1200 1200 1 140( 1300 ~ 1500 13,00 1500 1 '-~ 1400 140x X \ 1700 \ 0 1500%, \ \ \ \ 1700 1600x 16O0 1800 1900 1000 ~o-... 1100 ~ -- ~ _ ~ 1200 ~1100 ~o_...~ 1500 ~ ~1200 -- ~ ~ ~ 1000 150( ,~100 1600 1 1700 1800 ~%.1400 1800 X X X \ X \ 1700"~X 1500 1900 \ \ \ \ '- --~14oo ""-- ..1500 1200 1900 2000 \ \ \ 1500 2000 40 80 120 -%?°° 1800~~ 2000 ~ 160 2100 200 600 2100 800 \ 40 I I I I I I I I I t o lo do ,~o 1~o 260 2;0 2~o East (feet) -> % 3~o ' ~o ' Go ' i 2200 0 240 ('- 280 320 j 400 440 480 520 560 600 640 i i i i 480 520 560 c~t~ ~ ~ FOR: BRA~SFIELD Date I~affed: 18-0~c-98 pl~ ~r~ce ~ ~21 C~rdlna~ are In ~e~ referee ARCO Alaska, Inc. Sfru~fure : Tarn Drill Sire 2L Well : 321 Field : Tarn Developmenf Field Loaafion: Norfh Slope, Alaska East (feet) -> 400 500 600 700 800 g00 1000 1100 1200 1500 1400 1500 1600 1700 1800 1900 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 k"~L x.~ ~- '-o 1600 '"' ---0...2400 "~N "~ N '"Q" -- -- -- -. -_ 500 N. '~-2-00 "' ~,,.18(~ ~ -.. -...,,.. 600 ". 'x ~'-.X '"'"'~" N 'x 'N "~' 0 700 800 2200 ''x, "'-., "N ~2000 N 'x x.~ 2000 900 x', ... / x., ~.2600 1000 x.. 1100 1200 'x %2800 x x %2200 1300 1400 N N '" N 360 1500 N N N%,3000 2800 1 fi00 ...~.~ 1700 1800 3O00 1900 2O0O I I I I I I I I I I I I I I t I I I I [ t I I I I I t 400 500 600 700 800 g00 1000 1100 1200 1300 14.00 1500 1600 1700 1800 1 g00 East (feet) -> 3OO 400 5OO 6OO 1700 800 9O0 lOO0 0 1100 1200 ._+. I 1300 V 1400 1500 1600 700 1800 1900 20OO ARCO Alaska, Inc. Structure : Tarn Drill S|fe 2L Well : 521 Field : Tarn Development F~eld Location : North Slope, Alaska East (feet) -> 1200 1500 1800 21 O0 2400 2700 3000 5300 5600 3900 4200 4500 4800 51 O0 5400 5700 300 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 --- --~ 2700 "" -.~ 3900 600~ ~ 800 "'- -- ~ 5100 ~ ~ \ ~ --~.~ '--- ~ooo i .. \ ~ "'-,.~._27 O0 "" 5000 ~ --- ~..3300 900 '% ~"-,,~2100 % ~ / --- ~_.36oo ,. 1200 ~ 2200 1500 '~%3( ~'~' ,__ ~ . /~ 5292 ~600 % 4800 0 2100 0 0 ~oo .... .~ 3600 2700 3900%~ 51 oo~ ~ 3ooo 3900 5000 ~200 5300 4200 5600 5900 4200 45O0 48OO 5100 54O0 5700 45OO 4800 5100 ~ %3300 x % %~5600 4800% x N % % 4200 5100 % % 5400 N 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 1200 1500 1800 21 O0 2400 2700 3000 3300 3600 3900 4200 ¢500 4800 51 O0 5400 5700 East (feet) -> 500 6O0 900 1200 1500 1800 2100 24O0 0 2700 ('"' 5000 ,,-,i- 5300 1 V 3600 3900 4200 45OO 4800 5100 5400 5700 ARCO Alaska, Inc. Structure : Tarn Drill Site 2L Well : 521 Field : Tarn Development Field Location : North Slope, Alaska 5400 5600 3800 4000 4200 4400 4600 ~ 4800 --I-- ~'~ 5000 0 5200 I V 540o 5600 5800 6000 6200 6400 6600 6800 East (feet) -> 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 7600 7800 8000 I I I I I I I I I I I I I I I I I I I I 600 " %36O0 % 4200 x ~ 3800 5000~ ~ ~ ~ ~ %4400 5200 ~ ~ 5400 % ~ ~ % 4600 5600 ~ ~ "" .,,4000 ,,,4800 5000 I 4600 "- ~,,4200 ~ ~5200 5400 4400 X%.5600 '~ %5800 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 5000 5200 5400 5600 5BO0 6000 6200 64-00 6600 6800 7000 7200 7400 7600 7800 8000 East (feet) -> 3400 5600 5800 4000 4200 4400 4600 48oo 0 5000 5200 .-~ 54oo 56O0 5800 6000 6200 64OO 6600 6800 ARCO Alaska, Inc. Tarn Drill Site 2L 321 slot $321 Tarn Development Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION D-~CERTAINTIES by Baker Hughes INTEQ Your ref : 321 Version #7 Our ref : prop2888 License : Date printed : 20-Dec-98 Date created : 17-Mar-98 Last revised : 17-Dec-98 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on nT0 12 49.742,w150 18 33.414 Slot location is nT0 12 47.729,w150 18 56.825 Slot Grid coordinates are N 5927641.118, E 460844.214 Slot local coordinates are 204.63 S 806.43 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PMSS <0-9200'>,,325,Tarn Drill Site 2L 317 Version #4,,317,Tarn Drill Site 2L 319 Version #4,,319,Tarn Drill Site 2L 311 Version #6,,311,Tarn Drill Site 2L PMSS <0-6864'>,,Arete,Tarn Drill Site 2L 3294 PMSS <2506 - 6190'),,329A,Tarn Drill Site 303 Version #5,,303,Tarn Drill Site 2L 309 Version #5,,309,Tarn Drill Site 2L 315 PMSS <0-???'>,,315,Tarn Drill Site 2L PMSS <0-11140>,,313,Tarn Drill Site 2L 307 Version #6,,307,Tarn Drill Site 2L PMSS <0-9210'>,,305,Tarn Drill Site 2L 323 Version #5,,323,Tarn Drill Site 2L PMSS <0-???>,,323,Tarn Drill Site 2L PMSS <0-7650'>,,Tarn#2,TARN #2 Closest approach with 3-D Minimum Distance method Last revised Distance )59 5( )48 3( )27 3( )148 4( )116 0( )116 0( )268 3( )177 2( )82.8( ) 117.7 ( )208.5( )239.1( )26.8( )25.7( )0.0( 19-Nov-98 23-Aug-98 25-Nov-98 25-Nov-98 16-Nov-98 16-Nov-98 25-Nov-98 3-Dec-98 15-Dec-98 15-Dec-98 15-Dec-98 15-Dec-98 4-Dec-98 18-Dec-98 7-Dec-98 M.D. 100.0 933.3 500.0 300.0 400.0 400.0 300.0 500 0 500 0 600 0 300 0 200 0 622 2 655 6 7620 0 Diverging from M.D. 7140.0 5800.0 2240.0 300.0 400.0 9540.0 300.0 500.0 500.0 11320.0 8500.0 7520.0 622.2 655.6 10955.6 PAYABLES Da,e: ~2/2~ Page orooloQ~r 0 0 6 9 8 ~.O. BOX 102776 Pay antity: ~" w,~o~ ~: ~nchorage, AK 99510 o2o~ ~ooo~2o2o22~ 12/16; 98 VR121698SJH03 C345S 129 SJH 100.00 100.00 FILING FEE FOR PERMIT TO ~RILL WELL %RU 2L-322 .............................. :::~ ~:~:::~:.:.~-:-~:~-~:::~:RE; ~:E:E'~:~::-::~:~::~::: ................ ~::~:~:~:~:~:~:~'E:E:~$~$~:~:~:~:~:~:~:~:~:~:~:~-~:::~:~:~:-$:-~-:-:-:-~ ::::::::::::::::::::::::::: ..................................... :~:~:~.::~:~:~:~-~.:::~:;~:~:~:~:;a:;:;~:~:~:~S~:~:~:?:~:~:::? ............... .................... ............ ,. . -_ ~..- .............................. :::::::::::::::::::::::::::::::::::::::::::::::::::::::: .......... ~ ZOO. 00 ZOO. 00 ~uestions regarding this remittance can be made by calling or wrztmg: ;RT 907/265-6904 P.O. BOX 103560, Anchorage, AK 99510-3560 vlATLSg07/265-6904 P.O. BOX 103560, Anchorage, AK 99510-3560 ;VCS 907/265-6080 P.O. BOX 103240, Anchorage, AK 99510-3240 :)IAL 907/263-~22 Detach check before depositing ~' ':";:':' ....... :': ...... "T~.' :: '" :: ":" :':'":": '':'~ 'L...:.:.::,' -.::..:: .-:.,-:-.:;-.:-.... :...i .:: - -;;-;:....ii-..:::- -::::.!::.:!:..:~i-- ,.-...;0,--' ~...'! 02 6.:.-' ':.:..::-:'.:.:::: .~:::...-.:':~.::::::;'.,' ':.:.:..:: '---..:::..~: .-::.....~::;'...':..-::- . .-:.:. ~,fi~h0r~;'AK:.:9~10:.':.::.' :i:.;":i;; .~:::"':?..:..':::':-';'.:: ."':.:"i:.': ::::::::::::::::::::::::::::::: !i!;':-:i' :i!::':::?.::-:-';';:::::.?::;'":;!:'.::::'?::':--:.. ~!;~"';i:-; ;;' ;?::::-':::'::"::::::::;::':::;"?~.'::;"':'::-;;;:-:~:: :;:.::' :::,; :';"?:'::?;:;-;::'"::'?,;'::,;;:'-:'?i?'":-::"i.: '!!:."!~:. i:,:"..::::: /' - '- " ;'- :-:;:. ~:;;' ':-!'":i:."::::""'"':';:>.. ~'~ :':'.' ::':' .': ..... '" ..-'ot,,'s a,T. am:)~D. 'D6~'~.Rs'- i~',q:) NO CS~TrS''':'" ..... ': ' :::' '..-":'"-.'"::' -. -"';:-"..' :""'"' '"'-'-' : "~ .::'".. ".: ".' ':"' '"": /' - .- ':" :"":' ' .~,' ' ' ' ' · .:'..' .... -: · -.-:.-: ':" .: :--:. -. --.. · -.-0 t 0'0 6 9;8- (*'Amount Not To Exceed ~,000.O0") ' 12-21-98 **************100.00' TO the order of: ALASKA DEPT OF REVENUE Da~e A_mount ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE Void after 90 days ANCHORAGE AK 99501 ' " " ' 0 ~1~_0 signatures requited - · -. i' ': ' · .. - .' .." - for amounts-..over-~000.O0 ..' .... : ' . ,"OOOO;OO&qfi"" ::O~iSqOL, B&~,: Oq qOOOO,' .__ .... ._W_E L__~L__P_._E _R_ M ! T CHECKLIST ADMINISTRATION / ~.. ~_ ...........INrt CLASS ........... DC.. u_._/'_--...__d-;~- ......... GEOLAREA ..... I I~e~l~lit fee attached ............. 2. lease i~unlber appropriate ............ 3 Ulfique well name and numbel. ...... 4 Well located in a defined pool ............ 5 6 7 8 9 l0 11. Al~l:q,~ DAlE ~ 12. ..... '"~,,~c~l~ 13. Well located proper distance flora d~illing unit bot.)damy. . . Well located proper distance from other wells ....... Sufficienl acreage available in drilling ~mil. If deviated, is wellbore plat included .... (.)pe~atol only affected party ........... Operator has appropriate bond in force ............. Permit can be issued without conservation order ....... Permit can be issued without administrative approval ..... Ca~ permit be approved before 15-day wait ........... ~ L_~._3 ~-/PROGRAM: exp El dev..__~.!.e_..d.r_l! I2 s_.e_!'_v. !:~].wellbore seg II ann, disposal para ?'6_ .............. .............................. S,ORe · . ENGINEERING 14. Co~d~clor string provided ................ 15 Surface casing protects all known USDWs ......... 16. CMl' vol adequate to circulate on conductor 8, surf csg .... ! 7 CMi vol ade(:luale to tie-in long string to surf csg .... 18 CMI will cover all known productive horizons ...... /9. Casting designs adequate for C, '1, B & permaf~osl ....... 20 Ade(l~ale lankage or reserve pti ............... 21 I! a re.d[ill, has a 10-403 for abandonment been approved.. 22 Adequate wellbore separation proposed ............ 23. If diveder required, does it meet regulations ......... 24. Drilling fluid program schematic & equip list adequale .... 25. BOPEs, do they meet regulation ................ AI)I)I~ UAl E 26. BOPE press rating appropriate; test to _~_~O.~_ ............. psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28 Work will occur without operation shuldow~ .......... ~ .._f_~¢~~ 29. Is p,esence of H2S gas probable ................. ~~ ........ ~ i;~i ca~ be issued WIG hydrogen sulfide measures 3'1. l)ala presenled Orlp0te~~s ...... 32 S~is,nic ana~~ g~Fonts ..... ' ...... 33 Sc~~-shore)._.._;_.:.. ..... 34 Contact name/phonp ~or weekly progress ~eports /'exploratory only] (A) will contain waste in a suitable receiving zone; ....... ([]) will ~ot contaminale fl'eshwater; or cause drilling waste Io si,face; ~ ¢ I$~) ~ ((;) will ,,ol impair mechanical inlegrity of the well used for disposal' ~ N (I)) will nol damage p~'odt~cing formation or i~nl)air ~ecove~y from a ~ N . po(4; a~d .~_ ....... ............. ...... ~ . ...... ~::). will nol chcumver]t 20 AAC 25.252 or 20 AAC 25.412. _ GE(~3Y' ENG~_E_[~.~G: UIC/Annular COMMISSION: J DI t..,..,______~.. CO ....................... M ~:)F,klI~;l ~,'v ,tH (1 Nm',~dl. ,,hw)[d*;,~bh,,h~b I.- ih I Y N Y N 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. Sperry-Sun Drilling Services LIS Scan Utility Thu Jun 17 11:00:05 1999 Reel Header Service name ............. LISTPE Date ..................... 99/06/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/06/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT, TARN POOL 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: MWD RUN 2 AK-MM-90051 G. GRFIIN R. SPRINGER 2L-321 501032028600 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 17-EFLTN-99 MWD RUN 3 AK-MM-90051 G. GRFIIN R. SPRINGER 22 10N 07E 205 806 146.10 144.60 117.10 RECEIVED JUN 29 1999 & Gas Cons. Commission WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 108.0 9.875 7.625 3302.0 6.750 12403.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUNS 2 AND 3 ARE DIRECTIONAL WITH DUAL GAMM3~ P~AY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PH3~SE-4 (EWR-4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD) . 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DEDE SCHWARTZ OF ARCO ALASKA, INC ON 16 JUNE, 1999. SPERRY-SUN MWD DATA IS PRIMARY DEPTH CONTROL (PDC) FOR WELL 2L-321. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12403'MD, 5890'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. TNPS = SMOOTHED COMPENSATED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). CTNA = SMOOTHED AVER3~GE OF NEAR DETECTORS' COUNT RATES. CTFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED. SC02 = SMOOTHED STANDOFF CORRECTION. SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: FIXED HOLE SIZE: MUD WEIGHT: MUD SALINITY: FORMATION WATER SALINITY: FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: $ File Header Service name ............. STSLIB.001 6.75" 9.1 - 10.2 PPG. 400 - 700 CL- PPM. 19149 CL- PPM. 1.00 G/CC 2.65 G/CC SANDSTONE Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HED~DER 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 GR 3257 0 PEF 3302 0 DRHO 3302 0 RHOB 3302 0 FCNT 3302 0 NCNT 3302 0 NPHI 3302 FET 3302 RPD 3302 RPM 3302 RPS 3302 RPX 3302 ROP 3312 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REM3LRKS: BIT RUN NO MERGE TOP MERGE BASE 2 3312.0 6850.0 3 6850.0 12403.0 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 STOP DEPTH 12349 0 12327 5 12327 5 12327 5 12312 0 12312 0 12312 0 12356 0 12356 0 12356 0 12356 0 12356 0 12402 5 EQUIVALENT UNSHIFTED DEPTH MERGED ~LAIN PASS. $ Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD P.U. 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean Nsam DEPT 3257 12500 7878.5 18487 ROP 0.02 2418.54 185.26 18182 GR 40.83 237.18 121.59 18185 RPX 0.1 52.86 4.6558 18109 RPS 0.08 67.83 4.8306 18109 RPM 1.1 2000 6.16741 18109 RPD 1.11 2000 6.14772 18109 FET 0.19 113.01 0.965848 18304 NPHI 11.74 61.16 35.1288 18021 FCNT 108.34 933.32 272.135 18021 NCNT 13199.9 32662.9 20350.8 18021 RHOB 1.56 3.33 2.32932 18052 DRHO -0.41 1.01 0.0830307 18052 PEF 1.45 12.77 3.35334 18052 First Reading 3257 3312 3257 3302 3302 3302 3302 3302 3302 3302 3302 3302 3302 3302 Last Reading 12500 12402.5 12349 12356 12356 12356 12356 12500 12312 12312 12312 12327.5 12327.5 12327.5 First Reading For Entire File .......... 3257 Last Reading For Entire File ........... 12500 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR PEF DRHO RHOB FCNT NCNT 3257 0 3302 0 3302 0 3302 0 3302 0 3302 0 NPHI 3302 0 FET 3302 0 RPD 3302 0 RPM 3302 0 RPS 3302 0 RPX 3302 0 ROP 3312 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~AY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : STOP DEPTH 6794 5 6773 0 6773 0 6773 0 6757 5 6757 5 6757 5 6801 5 6801 5 6801 5 6801 5 6801 5 6850 0 04-JAN-99 INSITE 3.2.12.3 CIM 5.46,SP4 5.16,SLD 10.87 MEMORY 6850.0 3312.0 6850.0 67.9 70.2 TOOL NUMBER P1043GR4 P1043GR4 P1043GR4 P1043GR4 6.750 6.8 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 TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 10.20 59.0 9.5 450 6.6 4.500 3.473 7.O00 2.700 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 NPHI MWD 2 P.U. 4 1 68 32 9 FCNT MWD 2 CNTS 4 1 68 36 10 NCNT MWD 2 CNTS 4 1 68 40 11 RHOB MWD 2 G/CC 4 1 68 44 12 DRHO MWD 2 G/CC 4 1 68 48 13 PEF MWD 2 B2LRN 4 1 68 52 34.5 First Name Min Max Mean Nsam Reading DEPT 3257 6850 5053.5 7187 3257 Last Reading 6850 ROP 0.02 2418.54 234.486 GR 40.83 155.62 109.356 RPX 0.1 52.86 4.99828 RPS 0.08 67.83 5.19653 RPM 2.65 2000 8.57547 RPD 2.95 2000 8.21702 FET 0.19 113.01 1.17652 NPHI 11.74 61.16 39.0873 FCNT 108.34 862.44 217.879 NCNT 13199.9 31570.6 18179.2 RHOB 1.93 2.74 2.23333 DRHO -0.41 0.63 0.0688766 PEF 1.5 12.77 3.57124 7077 7076 7000 7000 7000 7000 7000 6912 6912 6912 6943 6943 6943 3312 3257 3302 3302 3302 3302 3302 3302 3302 3302 3302 3302 3302 6850 6794 5 6801 5 6801 5 6801 5 6801 5 6801 5 6757 5 6757 5 6757 5 6773 6773 6773 First Reading For Entire File .......... 3257 Last Reading For Entire File ........... 6850 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 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: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI PEF DRHO RHOB 3 .5000 START DEPTH 6758 0 6758 0 6758 0 6773 5 6773 5 6773 5 STOP DEPTH 12312 0 12312 0 12312 0 12327 5 12327 5 12327 5 GR 6795 0 FET 6802 0 RPD 6802 0 RPM 6802 0 RPS 6802 0 RPX 6802 0 ROP 6848 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXI~ ANGLE: 12349.0 12356.0 12356.0 12356.0 12356.0 12356.0 12402.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MTJD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPER3ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: 08-JAN-99 INSITE 3.2.12.3 CIM 5.46,SP4 5.16,SLD 10.87 MEMORY 12403.0 6850.0 12403.0 54.4 70.1 TOOL NUMBER P1043GR4 P1043GR4 P1043GR4 P1043GR4 6.750 6.8 LSND 9.90 49.0 9.0 550 5.4 2.100 1.185 3.900 3.300 51.1 .6 $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD 3 FT/H 4 1 68 GR MWD 3 API 4 1 68 RPX MWD 3 OHMM 4 1 68 RPS MWD 3 OHMM 4 1 68 RPM MWD 3 OHMM 4 1 68 RPD MWD 3 OHMM 4 1 68 FET MWD 3 HOUR 4 1 68 NPHI MWD 3 P.U. 4 1 68 FCNT MWD 3 CNTS 4 1 68 NCNT MWD 3 CNTS 4 1 68 RHOB MWD 3 G/CC 4 1 68 DRHO MWD 3 G/CC 4 1 68 PEF MWD 3 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min DEPT 6758 ROP 1.04 GR 43.89 RPX 1.13 RPS 1.13 RPM 1.1 RPD 1.11 FET 0.2 NPHI 12.25 FCNT 151.41 NCNT 15907.7 RHOB 1.56 DRHO -0.2 PEF 1.45 Max 12402.5 789 96 237 18 16 09 15 09 13 15 12 78 13 27 49 89 933 32 32662.9 3.33 1.01 12.55 Mean Nsam 9580.25 11290 153.837 11110 129.383 11109 4.44 11109 4.60001 11109 4.65004 11109 4.84381 11109 0.837312 11109 32.6659 11109 305.892 11109 21702.1 11109 2.3893 11109 0.0918768 11109 3.21715 11109 First Reading 6758 6848 6795 6802 6802 6802 6802 6802 6758 6758 6758 6773.5 6773.5 6773.5 Last Reading 12402.5 12402.5 12349 12356 12356 12356 12356 12356 12312 12312 12312 12327.5 12327.5 12327.5 First Reading For Entire File .......... 6758 Last Reading For Entire File ........... 12402.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/06/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/06/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File