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195-121
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:NSK Wells Integrity Eng CPF1 & CPF3 Subject:10-426 forms for 1D-101 Witnessed & 1Q-pad non-witnessed MIT-IA"s 7/15/25 Date:Wednesday, July 16, 2025 8:07:58 AM Attachments:image001.png MIT KRU 1D-101 7-15-25.xlsx MIT KRU 1Q-PAD SI TESTS 07-15-25.xlsx Morning, Please see the attached 10-426 forms from the AOGCC witnessed MIT-IA on 1D-101 and the non-witnessed MIT-IA’s on 1Q-pad that were performed on 7-15-25. If you have any questions, please let me know. Thanks, Matt Miller/ Bruce Richwine DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .584 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2051420 Type Inj N Tubing 1190 1200 1220 1250 Type Test P Packer TVD 5100 BBL Pump 1.1 IA 265 2000 1890 1880 Interval 4 Test psi1500BBL Return1.1OA0000 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1951210 Type Inj N Tubing 1680 1680 1680 1680 Type Test P Packer TVD 5894 BBL Pump 1.0 IA 1030 3300 3200 3180 Interval V Test psi 3000 BBL Return 1.0 OA 20 210 210 210 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 1Q Pad Non-witnessed Beck/Cook 07/15/25 Notes: Notes: 1Q-02B 1Q-24 Notes:MITIA every 2 years at maximum anticipated injection pressure per AIO 2C.017 Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2025-0715_MIT_KRU_1Q-24 9 9 9 9 999 999 99 9 9 -5HJJ 1Q-24 AIO 2C.017 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 10, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1Q-24 KUPARUK RIV UNIT 1Q-24 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/10/2023 1Q-24 50-029-22584-00-00 195-121-0 W SPT 5894 1951210 3000 2215 2215 2215 2215 160 525 525 525 REQVAR P Austin McLeod 7/5/2023 Two year to MAIP. AIO 2C.017. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1Q-24 Inspection Date: Tubing OA Packer Depth 700 3310 3170 3150IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230705181429 BBL Pumped:1.4 BBL Returned:1.4 Thursday, August 10, 2023 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Brian Bixby Petroleum Inspector Well Name KUPARUK RIV UNIT IQ -24 Insp Num: mitBDB210713101057 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 15, 2021 SUBJECT: Mechanical Integrity Tests ConecoPhillips Alaska, Inc. 1 Q-24 KUPARUK RIV UNIT IQ -24 Sre: Inspector Reviewed By: P.I. Supry I3iz Comm API Well Number 50-029-22584-00-00 Inspector Name: Brian Bixby Permit Number: 195-121-0 Inspection Date: 7/12/2021 - Packer Well IQ -24 Type Inj w TVD— PTD I 1951210 ;Type Test" SPT jest psi BBL Pumped:1.1 ;BB' L Returned: Interval REQVAR P/F Notes: MITIA as per AIO 2C.017 ✓ Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 5894 TUbin 2480. 2480 2480 _ 2480 - g — 3000 A 1210 3310 - 3170 -3160 �— 1.1 OA540 ._ 45- 820 _ _ 820 P Thursday, July 15, 2021 Page 1 of 1 MEMORANDUM TO: Jim RPgg P.I. Supervisor FROM: Austin McLeod Petroleum Inspector Well Name KUPARUK RIV UNIT IQ -24 Insp Num: mitSAM190703202358 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 15, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. I Q-24 KUPARUK RIV UNIT IQ -24 Src: Inspector Reviewed By: P.I. SuprvJB/-- NON-CONFIDENTIAL Comm API Well Number 50-029-22584-00-00 Inspector Name: Austin McLeod Permit Number: 195-121-0 Inspection Date: 7/3/2019 Packer Depth Pretest Initial I� Vlin 30M in 45 Min 60 Min Well Qza iTypeInj W TVD 5894 - b g1 z3s 75- PTD 1951210 - IType Test SPT Test psi 3000 IA 540 3300 - 11;0 3135 - BBL Pumped�1-7 -BBL Returned: 1.5 OA 65 460 - 460 450 - Interval REQVAR P/F P Notes: 2 year MIT -IA to MAIP. A10 2C.017. v Monday, July 15, 2019 Page I of 1 S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,July 18,2017 P.I.Supervisor eV 11-a (t7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1Q-24 FROM: Jeff Jones KUPARUK RIV UNIT 1Q-24 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry COP-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Q-24 API Well Number 50-029-22584-00-00 Inspector Name: Jeff Jones Permit Number: 195-121-0 Inspection Date: 7/8/2017 ' Insp Num: mitJJ170718120857 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IQ-24 Type Inj W' TVD 5894 - Tubing 2410 - 2410 2410 - 2410 PTD 1951210 Type Test SPT iTest psi 3000 IA 1230 3300 - 3170 - 3170 - BBL Pumped: 1.2 - BBL Returned: 1.1 - OA 170 460 440 440 Interval REQVAR P/F P ' Notes: AIO 02C.017 T x IA communication.2 Year MIT-IA.The surface pipe landing flutes are above the conductor. SCANNED SEP 2 5 2017 Tuesday,July 18,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,February 27,2017 TO: Jin,Regg P.I.SupervisorSUBJECT: Mechanical Integrity Tests '1� i�► CONOCOPHILLIPS ALASKA INC 1Q-24 FROM: Chuck Scheve KUPARUK RIV UNIT 1Q-24 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry M NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Q-24 API Well Number 50-029-22584-00-00 Inspector Name: Chuck Scheve Permit Number: 195-121-0 Inspection Date: 2/20/2017 Insp Num: mitCS170220161624 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well T 1Q-24 (Type Inj W TVD 5894 ✓Tubing 2250 2250 2250 2250 PTD 1— 1951210 Type Testi SPT Test psi 3000 IA 980 3320 3200 3180 BBL Pumped: 1.3 BBL Returned: 1.1 OA 40 200 200 200 Interval ; REQVAR P/F P e/ Notes: Tested per AIO 2C.017 SCANNED APR 2 8 2J17. Monday,February 27,2017 Page 1 of 1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, March 10, 2015 2:17 PM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; Senden, R.Tyler Subject: KRU 1Q-24 (PTD 195-121) Report of IA pressure anomaly Attachments: Picture (Device Independent Bitmap) 1jpg; 1Q-24 90 day TIO plot.JPG; 1Q-24 schematic.pdf Chris, Kuparuk injector 1Q-24(PTD 195-121)was reported with a pressure spike in IA pressure. The well had some temperature changes when WAG'd from water to gas injection and the pressure anomaly may be a delayed response to the thermal changes in the wellbore. Initial diagnostics will be performed with DHD to include an MITIA, IA DD test if the MIT passes,tubing and inner casing packoffs. Assuming the above tests all pass, it is ConocoPhillips intention to leave the well on gas injection for 30 days to confirm the pressure spike is thermally related. If the MITIA fails,the well will be put on water injection for 7 days and then shut in for further diagnostics. If it appears that there is communication while on gas injection,the well will be put on water injection for a 30 day test period in preparation for an AA. An update will be submitted based upon the results of the testing. Attached is a 90 day TIO plot and wellbore schematic. Please let me know if you disagree. ED 1JIAR 1 U 2D'i Well Name 1Q-24 Notes: Start Date 12110/2014 Days 90 End Date 3/10/2015 4000 WHPP Annular Communication SurveillanceiA 3E00 — OAP ti'JN T 3000 2E00 2000 .tR 1E00Y'r 1000 E00it\ '`i 0 Nov-14 Dec-14 Dec-14 Dec-14 Jan-15 Jan-15 Jan-1E Feb-15 Feb-1E Feb-1S Mar-15 1 0 zz:— oc Er w� LL a;: vtn ELM an , Nov-14 Dec-14 Dec-14 Dec-14 Jan-15 Jan-1E Jan-15 Feb-15 Feb-1E Feb-1E Mar-1E 1 Date Brent Rogers I Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr. 909 4414WELLS TEAM Conocps • 2 , KUP 1Q-24 Conoco Philli t AWell Attributes Max Angle&MD TD Alaska.Inc. '1 Wellbore API/UWI Field Name Well Status Inel(°) MD MKS) Act Btm(SKS) „MKr,rm,(I,P. 500292258400 KUPARUK RIVER UNIT INJ 35.90 3,149.80 7,313.0 Comment H23(ppm) Dab Annotation End Dote KB-Ord(R) Rig Release Date "' SSSV:NIPPLE Last WO: 9/4/1995 Well Conlin-10-24,5/23/2013 8:11:16 AM Schematic-Actual Annotation Depth(NKS) End Date Annotation Last Mod.,.End Date Last Tag:SLM 6,994.0 11/6/2011 Rev Reason:WELL REVIEW osborl 5/23/2013 Casing Strings HANGER,37 - .. Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 H-40 WELDED Casing Description String 0... (String ID...Top(11KB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd SURFACE 75/8 6.875 40.9 4,206.5 3,800.0 29.70 L-80 LTC . stitc Casing Description String 0... Shing ID...Top(RKB) Set Depth(f...Set Depth(TVD).--String Wt..String...String Top Thrd PRODUCTION51/2 4.950 38.6 7,300.4 6,426.7 15.50 L-80 LTC-MOD 1 5.5"x3.5"@6701' Tubing Strings Tubing Description String 0... String ID...Top(MB) Set Depth If...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING 31/2 2.992 36.6 6,678.9 5,896.0 9.30 L-80 ABM-EUE Completion Details Top Depth (TVD) Top Incl Norni... CONDUCTOR, Ibm Description Comment ID(In) 42-121 36.6 36.6 2.21 HANGER FMC GEN IV TUBING HANGER 3.500 509.8 509.7 1.30 NIPPLE CAMCO DS LANDING NIPPLE w/2.856"NO GO PROFILE 2.812 NIPPLE,510 6,670.0 5,888.3 30.21 NIPPLE CAMCO'D'NIPPLE w/2.795"NO GO PROFILE 2.750 I 6,677.1 5,894.5 30.25 SEAL ASSY LOCATOR BONDED SEAL ASSEMBLY-STABS INTO PROD CSG 3.000 5.5"x3.5"CROSSOVER Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth GAS LIFT, � (TVD) Top Incl 2,587 Top(RKB) (RKB) (°) Description _ Comment Run Date ID(in) CSG PATCH Seal weld bottom of flute of starter head w/3'2 7/8"length- 11242010 15.0... Mil 8".500 API 5L-65 X 8".500 X 65.Sleeve fitting over double - collars 4'4"length-10".500 API 5L X 65,OAL=75"SURF CSG PATCH Perforations&Slots Shot Top(TVD) Btm(TOD) Dens Top(NKB)Bon(NKB) MKS) MKS) Zone Date (sh.-. Type Comment 6,785.0 6,830.0 5,987.8 6,026.4 C4,C3,10-24 11272011 6.0 IPERF 60 DEG,DP MILLENIUM SURFACE. 7,016.0 7,034.0 6,184.7 6,200.1 A-4,A-3,1Q-24 12/31/1995 4.0 IPERF 180 deg.phasing;Oriented 22 deg. _ _ CCW F/High Side,2 1/2"Hollow Carrier 7,056.0 7,070.0 6,218.8 6,230.7 A-3,10-24 12/31/1995 4.0 IPERF 180 deg.phasing;Oriented 22 deg. GAS LIFT. CCW F/High Side,2 1/2"Hollow 4.560 - -- - Carrier Notes:General 8 Safety End Date Annotation 5/23/2009 NOTE:View Schematic w/Alaska Schematic9.0 12/4/2010 NOTE:TAG OBSTRUCTION @ 6994' GAS LIFT, 5.643 - - 1 U U II GAS LIFT, _.._ 6.622 I a NIPPLE,6,670 , 1' SEAL ASSY, 6,677 '�I I 1 I i (PERF. 6.785.6,830 • Mandrel Details Top Depth Top Port (PERF,__ 5... (TVD) Incl OD Valve Latch Sias TRO Run 7.01x7,034 N...Top(ftKB) (ftKB) (°I Mole Model On) Sery Type Type On) (PAO Run Date Com... 1• 2,586.7 2,471.6 35.06'BST 'AXT 1 GAS LIFT DMY T-1 0.000 0.0 4/10/1996 2 4,560.5 4,089.2 35.43.BST AXT 1 GAS LIFT DMY T-1 0.000 0.0 4/10/1996 7,056-7,07 (PERF0•--- - 3 5,843.5 5,188.5 34.17 BST AXT 1 GAS LIFT DMY T-1 0.000 0.0 12/27/1995 _ 4 6,622.3. 5,845.5 27.81-BST AXT 1 GAS LIFT DMV T-1 0.000 0.0 4/12/1996 PRODUCTION 1.5'5,3.5"06701', 30-7,300 , ' TD,7,313 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. File Number of Well History File PAGES TO DELETE RESCAN Complete [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: Ir/, i ~") Other ~ Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS' Scanned by:~Dianna Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is/ STATE OF ALASKA ' ALASKOL AND GAS CONSERVATION COMMI•N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell >^ Rug Perforations r Stimulate r Other r Alter Casing (— Pull Tubing r Perforate New Pbp.l Waiver r Time Extension -°" Change Approved Program j'°- Operat. Shutdow n r forate 7" Re -enter Suspended Well r 2. Operator Name: 4. Well Class &Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r . 195 -121 3. Address: 6. API Number: Stratigraphic I Service j;r P. O. Box 100360, Anchorage, Alaska 99510 f 50 029 - 22584 - 00 `' 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25641 • r 1 Q - 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7313 feet Plugs (measured) None true vertical 6437 feet Junk (measured) None Effective Depth measured 7236 feet Packer (measured) no packer true vertical 6372 feet (true vertucal) Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 SURFACE 4166 7.625 4206 3800 PRODUCTION 7262 5.5 x 3.5 7300 6427 RECHVED DEL 2 9 731 Perforation depth: Measured depth: 6785'- 6830', 7016'- 7034', 7056-7070' hg # '.1:1 ii �� ° ®mllf�slA True Vertical Depth: 5988'- 6026', 6185'- 6200', 6219' -6231' �nr;nafpc Tubing (size, grade, MD, and TVD) 3.5, L - 80, 6679 MD, 5896 TVD St.ANNEL JA NI 4 ZLJI Packers & SSSV (type, MD, and TVD) no packer SSSV - CAMCO 'DS' NIPPLE @ 510 MD AND 510 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable 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 2221 Subsequent to operation 4354 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development ]-" Service ` J Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL Daily Report of Well Operations XXX GSTOR r WINJ WAG'S" GINJ r SUSP r SPLUG r 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: none Contact John Peirce a( 265 -6471 Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date , z/zs /ii d l BDMs DEC 2 9 2011 F /2____ Form 10-404 Revised 10/2010 Submit Original Only 1Q -24 Well Work Summary DATE SUMMARY 11/6/11 GAUGED TBG TO 2.78" TO 667 KB. RAN 2.63" x 22' 9" DUMMY GUN, AI@ 6994' SLM / 7026' RKB. READY FOR E /L. 11/26/11 RIH WITH 14' PERFORATING GUN (60 DEG / 6 SPF / DP MILLENIUM ) AND PERFORATE THE FOLLOWING INTERVAL - 6816 -6830' / RIG DOWN FOR NIGHT AND COME BACK IN MORNING TO SHOOT REMAINING INTERVAL 11/27/11 RIH WITH 2.5" 60 DEG / 6 SPF / DP MILLENIUM PERF GUNS AND SHOOT THE FOLLOWING UN ONE 6799 -681 RUN TWO 6785 -6799' T • KUP 1Q -24 ...., ConocoPhillips ogi Well Attributes Max Angle & MD TD Alaska. h Welibore API /UWI Field Name Well Status Inc! ( °) MD (kKB) Act Btm (ft0B) Conco;ItiMps 500292258400 KUPARUK RIVER UNIT INJ 35.90 3149.80 7,313.0 """ Comment N2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date "' SSSV: NIPPLE Last WO: 9/4/1995 Well Con% -1D- 2411/30/201110' AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 6,994.0 11/6/2011 Rev Reason: ADD PERFS ninam 11/30/2011 Casing Strings _ a ' Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (71/0) ... String Wt... String ... String Top Thrd HANGER, CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd ___ SURFACE 75/8 6.875 40.9 4,206.5 3,800.0 29.70 L - 80 LTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVO) ... String Wt... String ... String Top Thrd PRODUCTION 51/2 4.950 38.6 7,300.4 6,426.7 15.50 L -80 LTC -MOD 1 1 5.5 "x3.5" Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 36.6 6,678.9 5,896.0 9.30 L -80 ABM -EUE Completion Details Top Depth (TVD) Top Inc! Nomi... ' i ' CONDUCTOR, Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 42 - 121 36.6 36.6 2.21 HANGER FMC GEN IV TUBING HANGER 3.500 509.8 509.7 1.30 NIPPLE CAMCO DS LANDING NIPPLE w/2.856" NO GO PROFILE 2.812 NIPPLE, 510 6,670.0 5,888.3 30.21 NIPPLE CAMCO'D' NIPPLE w/2.795" NO GO PROFILE 2.750 6,677.1 5,894.5 30.25 SEAL ASSY LOCATOR BONDED SEAL ASSEMBLY - STABS INTO PROD CSG 3.000 5.5 "x3.5" CROSSOVER Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth GAS LIFT, (TVD) Top Inc! 2587 Top (ftKB) (ftKB) In Description Comment Run Date ID (in) CSG PATCH Seal weld bottom of flute of starter head w/3' 2 7/8" length- 11/24/2010 15.0... 8" .500 API 5L- 65 X 8" .500 X 65. Sleeve fitting over double collars 4' 4" length - 10" .500 API 5L X 65, OAL= 75" SURF CSG PATCH • Perforations & Slots Shot • Top (TVD) Btm (TVD) Dens i Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (eh.- Type Comment se 6,785 6,830 5,987.8 6,026.4 C4, C3, 1Q -24 11/27/2011 6.0 IPERF 60 DEG, DP MILLENIUM , 4 2 6 7 ,016 7,034 6,184.7 6,200.1 A -4, A -3, 1Q-24 12/31/1995 4.0 IPERF 180 d asi a.so e9 i g ndl Oriented 22 de 9 CCW F/ High Side, 2 1/2' Hollow Carrier • 7,056 7,070 6,218.8 6,230.7 A -3, 10-24 12/31/1995 4.0 IPERF 180 deg. phasing; Oriented 22 deg. GAS LIFT CCW F/ High Side, 2 1/2' Hollow 4 560 Carrier Notes: General & Safet , End Date Annotation 5/23/2009 NOTE: View Schematic w/ Alaska Schematic9.0 '12/4/2010 NOTE: TAG OBSTRUCTION @ 6994' • GAS LIF1 5 843 GAS LIFT 6 622 NIPPLE 6,670 SEAL ASSY, ( t 6.6, 1 1 J IPERF, 6,785-6,830 Mandrel Details Top Depth Top Port IPERF, (TVD) Inc' OD Valve Latch Size TRO Run 7.016- 034 Stn Top (ftKB) (ftKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,586.7 2,471.6 35.06 BST AXT 1 GAS LIFT DMY T -1 0.000 0.0 4/10/1996 2 4,560.5 4,089.2 35.43 BST AXT 1 GAS LIFT DMY T -1 0.000 0.0 4/10/1996 IPERF, 3 5,843.5' 5,188.5 34.17 BST AXT 1 GAS LIFT DMY T -1 0.000 0.0 12/27/1995 7,056 - 7,070 4 6,622.3 5,845.5 27.81 BST AXT 1 GAS LIFT DMY T -1 0.000 0.0 4/12/1996 P800uc TION 59'5 397 TD. 7 .313 1 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 27, 2011 CF a g- 3'14. I Commissioner Dan Seamount Alaska Oil and Gas Commission. JUL 2 L� 1, 333 West 7 Avenue, Suite 100 l' Anchorage, AK 99501 P.ncticreig6 Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 3/21, 5/9, 5/23 and 5/24, 2011. The corrosion inhibitor /sealant was pumped 6/18, 6/19, 6/20 and 6/21, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, MJ L veland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 06/27/2011 1A,1B,1E,1L,1Q,1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date gal ft bbls ft 1A -03 50029206150000 1810880 I 16" N/A 3" I N/A I 1.7 6/20/2011 1A -04A 5002920621 0100 2001940 18" N/A 23" N/A 2.5 6/20/2011 1A -16RD 50029207130100 1820310 SF N/A 22" N/A 5 6/18/2011 1B -03 50029205880000 1810560 SF N/A 23" N/A 5 6/21/2011 1B -04 50029205950000 1810650 18" N/A 18" N/A 2.5 6/21 /2011 1B-05 50029202370000 1770010 31" 6.40 2'9" 5/24/2011 6 6/21/2011 1B -07 50029206160000 1810890 72" 1.00 22" 5/9/2011 2.5 6/21/2011 1B -08A 50029206350100 1971120 18'8" N/A 29" N/A 4.5 6/21/2011 1B -09 50029206550000 1811340 SF _ N/A 23" N/A 5 6/20/2011 1B -10 50029206560000 1 1811350 SF N/A 23" N/A 6 6/21/2011 1B-12 50029223650000 1930610 13'4" 2.00 24" 5/9/2011 6 6/21/2011 1B -101 50029231730000 2031330 3" _ N/A 22" N/A 1.7 6/21/2011 1B -102 50029231670000 2031220 11'2" 0.60 36" 5/9/2011 I 1.7 6/21/2011 1E -05 50029204790000 1800580 19" _ N/A 19" N/A 1.7 6/19/2011 1E-22 50029208840000 1822140 14" 1.75 17" 3/21 /2011 1.7 6/19/2011 1E-23 50029208580000 1821840 _ 58' _ 10.75 2'5" 5/23/2011 3.4 6/19/2011 1E -30 50029208140000 1821390 15'5" 1.75 16" 3/21/2011 2.5 6/19/2011 1E -105 50029232430000 2050060 20" N/A 20" N/A 6 6/19/2011 1L-16 50029212020000 1841810 14'9" 2.00 35" 5/23/2011 6 6/20/2011 1L -18 50029221450000 1910350 SF N/A 18" N/A 2.5 6/19/2011 10-24 50029225840000 1951210 _ T8" _ 1.00 12" 5/9/2011 5 6/18/2011 1Y-02 50029209410000 1830590 40'10" 5.00 41" 5/9/2011 8.5 6/18/2011 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, January 20, 2011 TO: Jim Regg P.I. Supervisor 'N l ` ' of If SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1Q-24 FROM: John Crisp KUPARUK RIV UNIT 1Q -24 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry -J � NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1Q API Well Number: 50 029 - 22584 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr110112133307 Permit Number: 195 - 121 - Inspection Date: 1/1 1/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1Q-24 'Type Inj. W ' TVD 5893 - IA 1300 2800 2720 2720 ' P.T.D 1951210 1TypeTest SPT Test psi 1500 OA 700 820 910 I 900 Interval 4YRTST - P/F P - Tubing 2150 2150 2150 2150 Notes: .77 bbls pumped for test. - z.` Nastie F Ea 0 3 2011 Thursday, January 20, 2011 Page 1 of 1 ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 DEC Q 6 2010 Alaska Oil & Gas Cons. Cornn*sion November 29, 2010 Anchorage Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 `Ulu Commissioner Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., well 1Q -24, PTD 12j-121, Sundry 310 -268 surface casing repair. Please call MJ Loveland or Perry Klein at 659 -7043 if you have any questions. Sincerely, Perry Klem ConocoPhillips Well Integrity Projects Supervisor STATE OF ALASKA ALASKA 0 GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon [7 Repair well rv7j Plug Perforations [j Stimulate Other R Welded SC patch After Casing 17 Pull Tubing 17 Rarf orate New Pool ❑ Waiver J Time Extension C Change Approved Program ® Operat. Shutdown [.� Perforate Re -enter Suspended Well 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development [i Exploratory 17 a 195 - 121 3. Address: 6. API Number: Stratigraphic Service rijo P. O. Box 100360, Anchorage, Alaska 99510 % 50-029-22584- 7. Property Designation: 8. Well Name and Number: ADL 25641 ALK 2572 4 1 Q -24 9. Field /Pool(s): Kuparuk River Field / Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 7313 feet Plugs (measured) None true vertical 6437 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 37, 6670, 6677 true vertical 0 feet (true vertucal) 37, 5888, 5894 Casing Length Size MD TVD Burst Collapse CONDUCTOR 121 16 121 121 0 0 SURFACE 4166 7.625 4206 3800 0 0 PRODUCTION 7262 5.5 7300 5896 0 0 Sleeve 7'5" 10" 7'5" 7'5" 0 0 Perforation depth: Measured depth: 7016 -7034, 7056 -7070' RE CEIV E D True Vertical Depth: 6185 -6200, 6219 -6231 DEC 0 6 2010 Tubing (size, grade, MD, and TVD) 3.5, L -80, 6678 MD, 5894 TVD 't18S'r'.8 +I Gas Cis. 001 illyliSSIOn Anchorage Packers & SSSV (type, MD, and TVD) SEAL ASSY - LOCATOR BONDED SEAL ASSEMBLY - STABS INTO PROD CSG 5.5 "X3.5" CROSSOVER @ 6677 MD and 5894 TVD 11. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbi Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation n/a n/a n/a n/a n/a Subsequent to operation n/a n/a n/a n/a n/a 13. Attachments 14. Well Class after proposed work: f Copies of Logs and Surveys run n/a Exploratory ❑ Development [ Service E 15. Well Status after work: Oil [ Gas r WDSPL Daily Report of Well Operations x GSTOR r WAG GASINJ [ i WINJ Ei SPLUG 16. 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: 310 -268 Contact Perry Klein /MJ Loveland Printed Name MJ Loveland Title Well Integrity Project Supervisor Signature Phone: 659 -7043 Date 11/28/10 MIMS BEG 06 20101 Form 10 -404 Revised 7/2009 �Z �� Submit Original Only IQ-24 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/08/10 Cut and removed landing ring and conductor, overall length is 94 ". Removed cement and cleaned surface casing for inspection by Kakivik. SC hole is 39 1/2" from the top of the flutes at the 2:00 position. 11/09/101 Notified AOGCC State man to witness SC damage (Jeff Jones) 11/10/10 1 UT /MT inspection. "A" band (10" band) and "B" (10" band) have very little metal loss - bottom of flutes to bottom of B band is 93 ". 11/23/10 Notified state man (John Crisp) of the opportunity of witness the weld of the surface casing patch. 11/24/10 Welded bottom band double collars 4" length - 8" .500 API 5L- X 65 & 2 3/4" x 8" API 5L - .500 X 65. Seal weld starter head. Seal welded to the bottom of the flute of the starter head with double collars 3'2 7/8" lenght - 8".500 API 5L - 65 X 8".500 X 65. The sleeve fitting over the double collars 4'4" lenght 10".500 API 5L X 65 for an overall lenght of 7' 5" of welding. 11/26/10 Preformed MIT OA. Initial T /I /O = si(0) /0 /0. Pressured OA up to 1800 with .5 bbls of diesel. _ = min T /I /O = si 0 Start MITT /I /O si(0) /0/1800. 15 min T /I /O si(0)/0/1755. 30 /0/1740.45 min ( ) T /I /O = si(0)/011740.60 min T /I /O = si(0)/0/1740. (PASSED). 11/27/10 Welded 94" of 16" X .395" conductor pipe back on well. Ready to top of conductor with cement and sealant. }� 3 a y .. . k Ilk ti ; k� QCoraoco a; file' This taea b E . { Con ocoP;hl 1 : xIn t and Cann 4 publish e, s" w h. t u k k �r k � k e f y� t� X§ f � � � k �Q •� u � F S t gyp, j r 7, t , } t 1 OL a � L i E+ ry+ c 2 t` • • ~~Q~~ 0~ Q~Q~~Q /,~,_..N.~~~. MJ Loveland Well Integrity Project Supervisor F! :_~~ `:.S ConocoPhillips Alaska, Inc. .,~,~~.r~-;~ '~ ~'-'~~ ~ '~ 5~ P.O. Box 100360 "~"' I~ Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 1 Q-24 Sundry Number: 310-268 Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this d da of Au st, 2010. ,~ Y ~ Encl. ~J ConocoPhillips ~~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 !~ r~ August 25, 2010 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: ~I~ska ~a 6a~ ~~~, C~r~rnr~ ;~<~c~a~r;.-~~~ Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 1Q-24, PTD 195-121 surface casing repair. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, ~~ ~~~~~ MJ oveland ConocoPhillips Well Integrity Projects Supervisor Enclosures STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMIS APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 "'~-~ ~~ 0 ~.30 1. Type of Request: Abandon r Plug for Redrill r Perforate New Puol r Repair w ell ~ Change Approved Program r Suspend r Plug Pbrforations r Perforate ~ FUII Tubing r Time Extension r Operational Shutdow n r Re-enter Susp. Well r Stimulate ARer casin r 9 ~ Other: Welded SC patch r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 195-121 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-22584-00 ` 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 Required? Yes r No r 10-24 9. Property Designation: _ 10. Field/Pool(s): ADL 25641 ALK 2572 Kuparuk River Field /Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ff): Effective Depth ND (ft): Plugs (measured): Junk (measured): 7313 ^ 6437 Casing Length Size MD ND Burst Collapse CONDUCTOR 121 16 121' 121 SURFACE 4166 7.625 4206' 3800 Prod Casing 6583 5-1/2" 6701.14' 5896 Liner 621 3-1 /2" 7300 6426 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7016-7034, 7056-7070' slss-s2oo, 6219-6231 3.5 L-80 6678 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) NIPPLE - CAMCO 'D' NIPPLE W/NO GO PROFILE MD= 6670 ND= 5888 SEAL ASSY -LOCATOR BONDED SEAL ASSEMBLY -STABS INT MD= 6677 ND= 5894 NIPPLE - CAMCO DS LANDING NIPPLE w/NO GO PROFILE MD= 510 ND= 510 - no SSSV 12. Attachments: Description Surrrnary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch (-' E~loratory r Development r Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: Septmember 15, 2010 Oil r Gas ~ WDSPL r Suspended (! 16. Verbal Approval: Date: WINJ r GINJ r" WAG ~ ' Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct the best of my knowledge. Contact: Perry Klein/MJ Loveland Printed Name MJ Loveland ~_ Title: Well Integrity Project Supervisor Signature Phone: 659-7043 Date a $"~(,~(~ / ~ Commission a Onl Sundry Number: 3i~ ~a ~T'~(J Conditions of approval: Notify Commission so that a representative may witness vN ical Integrity Test r Location Clearance Plug Integrity r BOP Test r Mechan / Other: -~s'LGU'~''r-~ ~U~d d~cti~e~~ia~ ~ ~~ ~ ('eba..c.rr- ~-~,:~~,..~'t~ ~.Q® ~V OTi ~~ 1. n SLOG ~-' t. S ~ lk, h ~ e.Q . '~ i~ ~ ~ ~ ~ ~i ! ?. Subsequent Form Required: ~ O _ , /may ~~"~'~is~ kr~i, tai ~8~i ~~ir~~„ v~~1i111S5i APPROVED BY ~ ~ r Approved by: - COMMISSIONER THE COMMISSION Date: ORIGINAL .3~.i~ Form 10-403 Revised 1/2010 `E~~6~~mit in Duplicate a • ConocoPhillips Alaska, Inc. Kuparuk Well 1Q-24 (PTD 195-121) SUNDRY NOTICE 10-403 APPROVAL REQUEST 08-25-10 This application for Sundry approval for Kuparuk well 1 Q-24 is for the repair of a surface casing ~ leak. The well is an injection wells and was drilled in 1995. On 06/23/08 a surface casing leak was confirmed and reported to the AOGCC. The leak was temporarily repaired with Brinker Platelets 10/24/09. ConocoPhillips would now like to permanently repair the well with a welded patch. With approval, repair of the surface casing will require the following general steps: 1. Shut-in and secure well. Set positive pressure plug and fluid pack the IA. Freeze protect the T and IA. Perform mechanical integrity test on tubing plug to verify barrier. 2. Excavate wellhead location. , 3. Install nitrogen purge equipment. 4. Cut away the conductor casing and remove cement around surface casing leak for inspection. 5. Notify AOGCC Field Inspector of repair operation so they may witness the event. 6. Repair damaged surface casing integrity. Repair options include sleeve patch, seal weld, lap patch, deposition weld and will be determined after inspection of the casing damage. 7. QA/QC the repair welds and MIT-OA to verify integrity 8. Install anti-corrosion coating on exposed surface casing. ' 9. Patch the conductor and top off the conductor void with cement and corrosion inhibiting . sealant. 10. Backfill gravel around the wellhead as needed. 11. Remove plugs and return the well to service. 12. Submit 10-404 report of repair operations to AOGCC. , • • Page 1 of 2 i Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, November 24, 2009 2:29 PM To: 'NSK Well Integrity Prof Cc: Regg, James B (DOA); Schwartz, Guy L (DOA); NSK Problem Well Supv Subject: RE: KRU Injector 10-24 (PTD 195 -121) Hi MJ, Got the 404 for 1 Q -24 as well as others. Looks like you were 5 out 6, not bad. The need for any MITIA at this time will likely be determined by the performance as you bring the well back on -line. If there are no issues identified, then it is appropriate to perform the MITIA next summer. Tom Maunder, PE AOGCC From: NSK Well Integrity Proj [ mailto :N1878 @conocophillips.com] Sent: Monday, November 23, 2009 2:01 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); Schwartz, Guy L (DOA); NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: KRU Injector 1Q -24 (PTD 195 -121) Tom, Attached the MITOA. Currently we were not planning on MITIA before the due date, however we can if required. Please advise if anything additional is required. Regards MJ Loveland 2009 Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 Cell (907) 943 -1687 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, November 23, 2009 10:45 AM To: NSK Well Integrity Proj Cc: Regg, James B (DOA); Schwartz, Guy L (DOA); NSK Problem Well Supv Subject: RE: KRU Injector 1Q -24 (PTD 195 -121) MJ, I have looked at the file. The 404 is likely in process to report the repair. Can you provide a copy of the MITOA? According to the information in the file, the well last passed a successful MITIA 7/17/06, was SI 3/2007, returned to service in May 2008 when the communication issue was identified and SI at CPAI's decision in June 2008. No AA was applied for since the well was not in operation. There is no information that would indicate that the tubing, packer or production casing are not competent. It would appear that this well meets the specification of AIO 2B and other regulations. Maintaining low positive pressure on the annulus is not an issue. Is there any plan to conduct an MITIA in advance of July 2010? 1 look forward to your reply. Call or message with any questions. 11/24/2009 Page 2 of 2 Tom Maunder, PE AOGCC From: NSK Well Integrity Proj [ mailto :N1878 @conocophillips.com] Sent: Friday, November 20, 2009 7:15 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); Schwartz, Guy L (DOA); NSK Problem Well Supv; NSK Well Integrity Proj Subject: KRU Injector 1Q -24 (PTD 195 -121) Tom, KRU injection well 1Q -24 (PTD 195 -121) has had the reported surface casing leak repaired with Brinker Platelets and has passed a 1800 psi pressure test. State Inspector, John Crisp, waived the follow up MITOA that was conducted on 10/28/09. The follow up 10-404 Report of Sundry Operations has been filed with the Commission. Based on the successful repair, it is ConocoPhillips intention to return this well to normal status and inject water and /or gas with the operating restraint of maintaining a small amount of positive pressure in the OA. Please notify us if it is not ok to resume injection in the well. Regards MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 Cell (907) 943 -1687 11/24/2009 RECEIVED ConocoPhillips NOV 11 2009 P.O. BOX 100360 Alaska 41aska Oil & Gas Cons. Commission ANCHORAGE, ALASKA 99510 -0360 AncHrag6 November 14, 2009 Mr. Guy Schwartz Alaska Oil and Gas Conservation Commission 333 West 7' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Schwartz: Enclosed please find the 10 -404 Report of Sundry well operations for ConocoPhillips Alaska, Inc. well 1Q -24, PTD 195 -121 surface casing repair with Brinker Platelets. Please call Perry Klein or me at 659 -7043 if you have any questions. Sincerely, f M/Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures • ECS VED STATE OF ALASKA • NOV 1 7 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION991aska Oil & Gas COILS. C°mmission 1. Operations Performed: Abandon ❑ Repair Well ✓❑ Plug Perforations ❑ Stimulate ❑ Other ✓ R pair SC w PlateU Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Well Class Before Work: Permit to Drill Number: ConocoPhillips Alaska Inc. Development ❑ Exploratory ❑ 195 3. Address: Stratigraphic ❑ Service ✓❑ API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 22584 - 00 N. KB Elevation (ft): If `S�Well Name and Number: I 1 Q - 24 Property Designation: 10. Field /Pool(s): ADL 25641, ALK 2572 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7313' feet true vertical \ 6437' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURFACE 4165.58' 7 -5/8" 4206.46' 3800' Prod Casing 6583' 5 -1/2" 6701.14' 5896' Liner 621' 3 -1/2" 7300 6426' Perforation depth: Measured depth: 7016 -7034, 7056 -7070' true vertical depth: 6185 -6200, 6219 -6231 Tubing (size, grade, and measured depth) 3 -1/2 ", L -80, 6678.93' MD. Packers & SSSV (type & measured depth) Seal Assembly 6677 no SSSV 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 Casing Pressure Tubing Pressure Prior to well operation NC -- Subsequent to operation NC 14. Attachments . Well Class after work: Copies of Logs and Surveys run _ Exploratory ❑ Development ❑ Service ❑✓ Daily Report of Well Operations _X Well Status after work: N o iii Gas❑ WAG GINJ❑ WINJ ❑ WDSPL❑ 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: 309 -304 Contact MJ Loveland/ Perry lein 65 -7043 Printed Name MJ Loveland Title Well Integrity Project Supervisor Signature Phone: 659 -7043 Date � 11n lfts22fa Pre b S e 263 -4612 Form 10-404 Revised 04/2006 NOV 1 8 20M ��� Z - ®/ Submit Original Only IQ-24 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/24/2009 Brinker Platelets SCLD /Repair; Initial T /1 /0= 150si/90/0; OA FL @ 23ft. Rigged up Triplex to injection manifold and established several LLR (Diesel)- 2gal. per min. @ 540psi. 3.4gal. @ 560psi. 3 al. per min. @ 500psi. 2.8gal per min. @ 500psi. 2.6gal. per min. LLR- (diesel gel) 13.8gal. per min. @ 40psi. 11.6ga . per min. 11.6gal. per min. Started to inject platelets 20- 1 Omm round platelets on first attempt; 20 -10mm solid core round platelets; 100- 5mm cube platelets and some vairous smaller sized cubes and held @ 300psi. for 15min. pressured up to 1000psi. 15min. reading 990psi. 30min. reading 990psi. pressured up to 1810psi. 15min. reading 1790psi. 30min. reading 1765psi. 45min. reading 1755psi. 60min. reading 1745psi. Pumped approximately 4bbls.of diesel gel. & 5bbls. of returns through conductor casing down spout. Bled down OA 500psi. 2hr. post OA bleed 545psi. Final T /1 /0= 150si/90/545 I 10/27/2009 Called and invited State inspector to witness MITOA tomorrow - no call back. 10/28/2009 MITOA - Passed. Initial T /1 /0= SI(150)/100/530. OA FL AS. Pressured up OA to 1000 psi with 1/4 bbl of diesel gel. Start MITOA, T /1 /0= SI(150)/100/530, 15 min T /1 /0= SI(150)/100/1000, 30 min T /1 /0= SI(150)/100/1000. Bleed OA down to 320. Final T /1 /0= SI(150)/100/320. Summary SuccessfuII7 repaired SC leak with Brinker Platelets i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg @alaska.gov; phoebe.brooks @alaska.gov; tom.maunder @alaska.gov; doa.aogcc.prudhoe.bay @alaska.gov OPERATOR: ConocoPhillips Alaska Inc. FIELD / UNIT / PAD: Kuparuk / KRU / 1Q -24 DATE: 10/27/09 OPERATOR REP: Phillips / Westlake AOGCC REP: State rep was notified with no response Shoe Depth Pretest Initial 15 Min. 30 Min. Well 1Q -24 Type Inj. N TVD 1 3,800' Tubing 150 150 150 150 Interval O P.T.D. 1951210 Type test P Test psi 1000 Casing 100 100 100 100 P/F P Notes: OA 530 1000 1000 320 MITOA Test per Sund ry # 309 -304 - Entered Shoe TVD in Packer slot. Weill I Type Inj. I TVD I I Tubingl I I Interval P.T.D.1 Type test Test psi I I Casing P/F Notes: I OA Weill Type Inj. N TVD Tubin Interval P.T.D. Type test P Test psi Casin P/F Notes: OA EE] Weill Type Inj. TVD Tubing Interval P.T.D.1 I Type testl I Test psi I Casing P/F Notes: I 0A Weill Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test O = Other (describe in notes) I MIT Report Form BFL 11/27/07 MIT KRU 10-24 10- 27- 09.)ds • • ~~~ ~a.~,, F~ ~ ~ y~ w `s ~~~ ~-~ ~. ~ ~ "~ a~~,~ ~ ~~~`~ ~ ~,s .~ ~~~ ~~ ~~ ~ ~ p~, ~~P~ ~~~ ~ ~ ~~ " ~w~ ~ ~ ~ ~~ A ~ ~ \;'`~pp ~ ~G, }~ ~~ SEAN PARNELL, GOVERNOR ~ E3 ,6 ~ . 4 ~ 6='^" ~% ~ q 0 '~ ~ . y 1 ~ J 6 ~. ~~7 ¢~ ~" "' ~,~~~~, ~ G' '~~.u~~ ~:o,«=i ~~ ~-J~ ~:,~ ~ ..~: E.; ~ ~.h ~~ ~~3' @~. ~ o,~ ~ ~V~la~ ~~ A~D ~ ~ COI~TSERQATI011T COMl-IIS51O1~T ~R 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 r FAX (907) 276-7542 Mr. M.J. Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. ~ ,~~ P.O. Box 100360 ~~ ~~"` ` ~ ~ ~~ Anchorage, AK 99510 ~l °I~ ~ i 1 Re: Kuparuk River Field, Kuparuk Oil Pool, 1 Q-24 ~ Sundry Number: 309-304 Dear Mr. Loveland: 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 ~r ~,~. DATED this ~ day of September, 2009 Encl. r ~ ~ • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 28, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~ s }' .~' a.._...,. ~ ' ~.- ~~`. ;, ~~` ~:i C~"~ ~~ 1 1(~ i: ) ..a .~.....x~a.~. . $~ . ~ - ~_ _ a Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1Q-24 (PTD 195-121) surface casing repair. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, ? i~~'~-'~ ~~ . ~~ MJ oveland ConocoPhillips Well Integrity Projects Supervisor Enclosures ~ ~.. ' 4 t'CJT /~ "+o ~ ~~ ~ ~~ ~ • ~a ~"'` " .,~ .~ u w _ $,.s • c~ ~ ~ ~ yM A~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION "~ ~~ ~~ ~~~ '~~~/,~ APPLICATION FOR SUNDRY APPROVAl~-. , a~~",~.r„~ 20 ,4ac 25.ZSO ~'~ 1. Type of RequeSt: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ Other ~/ Alter casing ~ Repair well ^~ Plug Perforations ^ Stimulate ^ Time E~ension ~ SC Platelet Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 195-121 ' 3. Address: Stratigraphic ~ Service Q. 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22584-00~ 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? Y@S ^ NO ~ 1Q-24 " 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25641; ALK 2572 RKB 97' Kuparuk River Field ! Kuparuk Oil Pool . 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 7313' • 6437' • Casing Length Size MD ND Burst Collapse CONDUCTOR 121' 16" 121' 121 SURFACE 4165.58' 7-5/8" 4206.46' 3800 Prod Casing 6583 5-1/2" 6701.14' 5896 Liner 621 3-1 /2" 7300 6426 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7016-7034, 7056-7070' 6185-6200, 6219-6231 3-1/2~~ L-8~ 6678.93~ Packers and SSSV Type: Packers and SSSV MD (ft) Seal Assembly 6677 no SSSV no SSSV 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ Service ~' 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat October 15, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q . GINJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my kngwledge. Contact: MJ Loveland/ Perry Klein 659-7043 Printed Name MJ Loveland Title: Well Integrity Pro~ect Supe isor Signature / Phone 659-7043 Date ~,~~ ~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness h i l I t i T ~ r n ti Cl L ^ wt~'~ sr an ca n egr Plug Integrity ~ BOP Test ~ Mec ty est ce on ea a oca 'L°~s `-~ Other: ~, Z.0°I Subsequent Form Required: l° ' Y°Y - ~~ ~„ ~ ` ~~ ~~~~~~ APPROVED BY ~~ ~~ ~ ~ MMISSIONER Ap roved b: ~ N Y THE COMMISSION Date: Form 10-403 Revised 06/2006 V f~ 1 V I( V/°l L ~~-~~ _~~, ~,~~' _~ ~~ ~~JU~ ~S,;,b}~~~ou~ te .~ y~Z~v9 ~ 1._J ConocoPhillips Alaska, Inc. Kuparuk We111Q-24 (PTD 195-121) ~...~ SUNDRY NOTICE 10-403 APPROVAL REQUEST August 28, 2009 This application for Sundry approval for Kuparuk well 1Q-24 is for the repair of a surface casing ~ leak. Kuparuk River Unit well 1Q-24 (PTD 195-121) was drilled and completed in 1995 as injector. In May 2008 surface casing leak was reported to the AOGCC. Subsequent testing indicated the leak depth is very close to surface. For technology development and due to the back log of surface casing excavation repairs ConocoPhillips is planning a temparary repair with Brinker Platelets (long term plans still include a conventional welded patch). Platelets are free floating (neutral density) discrete particles which are injected into the system (in this case the OA) and transported with the fluid flow and entrained in the leak with fluid force thus providing a seal. The Platelet material is entirely inert, designed to function in oil and gas applications, and within the operating conditions of the well. Each particle is individually sized to fit the predicted leak geometry. With approval, repair of the surface casing will require the following general steps: l. Rig up Platelet manifold to OA 2. Establish liquid leak rate; 3. Deploy a finite number of Platelets; 4. Maintain specified pressure on OA for a specific amount of time (to be determined by Platelet Tech, however probably less than 1000 psi). 5. MITOA to 1800 psi; 6. Return well to normal operations, however maintaining some positive pressure on OA. 7. File 10-404 1Q-24, WAG Injector, PTD # 19~21, notice af suspect surface casing leak. Page 1 of ~~ • Maunder, Thomas E (DOA) From: NSK Well lntegrity Proj [N1878@conocophillips.com] Sent: Thursday, June 26, 2008 4:58 AM To: Maunder, Thomas ~ (DOA) Cc: NSK Problem Welt Supv Subject: RE: 1Q-24, WAG Injector, P7D # 195-121, notice of suspect surface casing teak. Tom, The well was SI since Mar 2007 and just brought on line (BOL} May 20th 2008. The changes mid chart are thermal from the BOL event. It is possible that the surface casing still has good integrity and the recent oil staining around #he tanko head is from the thermal effects from BOL on old well bore fluids trapped in the conductor from a historicaily recorded (not currently active) braiden head leak. We will perform SC diagnostics after we prove up 2 barriers with an MITIA. Let me know if you have any additional questions. MJ Loveland Weli Integrity Project Supervisor ConocoPhiliips Alaska, Inc. ~~~~~r~ ~~; 4~ ,+r ~ ~r, ~~~~ Office (907) 659-7043 Cell (907} 943-1687 From: Maunder, Thomas ~ (~~A) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, June 24, 2008 7:54 AM To: NSK Well Integrity Proj Subject: RE: iQ-24, WAG Injector, PTD # 195-121, notice of suspect surface casing leak. Thanks Perry. What is the recent history of the well? It appears that the pressures are changing quite a bit in the middle af the chart. Tom Maunder, PE AOGCC ~ NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Mo ]une 23, 2008 4:18 PM To: Maunder, Tho (DOA}; Regg, James B(DOA) Cc: CPFi Prod Supt; CPF ead Techs; CPF1 Prod Engr; Cavwey, Von Subject: 1Q-24, WAG Injector, 95-121, notice of suspect surface casing leak. Tom, 1Q-24, WAG Injector, PTD # 195-121, has a suspected surfiace casing leak. C~'~~~ ~C ~ P ~ ct~`' 1 U23/2009 FW: 1Q-24, WAG Injector, PTD # 195-121, notice of suspect surface casing leak. Page 1 of 1 • • Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.comj Sent: Monday, June 23, 2008 4:21 PM C'~ To: Maunder, Thomas E (DOA); Regg, James B (DOA) Subject: FW: 10-24, WAG Injector, PTD # 195-121, notice of suspect surface casing leak. Attachments: 1 Q-24 90 day TIO.jpg; 1 Q-24.pdf Tom and Jim I've added the TIO pressures. From: NSK Well Integrity Proj Sent: Monday, June 23, 2008 4:18 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)' Cc: CPFl Prod Supt; CPFl DS Lead Techs; CPFl Prod Engr; Cawvey, Von Subject: 1Q-24, WAG Injector, PTD # 195-121, notice of suspect surface casing leak. Tom, / 1 Q-24, WAG Injector, PTD # 195-121, has a suspected surface casing leak. T/I/O = 2250/200/0 Immediate action will be to freeze protect the tubing, set a plug in the profile at 6670', and perform an MITT / / MITIA to prove up our two barriers. Once the well is secure DHD will begin surface casing leak diagnostics. The well will remain shut in and has been added to the monthly report. ~ I've enclosed a schematic and 90 day TIO. Let me know if you have any questions. Sincerely, Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 d j «1Q-24 90 day TIO.jpg» «10-24.pdf» 7/31/2008 KRU 1 Q-24 PTD 195-121 rRri_~rEra ~ta[r. 4000. d't)tl. 3000. snan, 3000. 4000. 0. 0. 0. 0. 0. D. o. o. SC ~ooo 3600 3200 2000 zoo 2000 1600 1200 800 goo 0 ------------------------------------------------------------------------------------------------- PLOT START "I'1MF: MINOR TIME 25-MAR-OB 16:24 MAJOR TIME WEER PICK TIME 22-J UN-08 07:06:40 ~C TAG HANE DESCRIPTION P--VALDE LATEST WL1Q-24-CHORE FLOW TUBING CHORE 16. SCRATCH 44 FLOW TUBING PRESSURE 2121. SCRATCH_44 FLOW TCJHl'NG 'CEMP ????'~?? ~ ??7??77 ~ 7777777 ~ SCRATCH_44 INNER ANNULUS PRES 1250. SCRATCH_94 OUTER ANNULUS PRES 10. ANNULUS PRESSURE TRENDS WELL NAME WLRRUIQ-24 PLOT DURATrON PLO"I' F:Fdfl TtME +02160:00:00 HRS23-JUN-08 16:24 DRILLSITE WELL PREV WELL 1Q 24 NEXP WELL E1TI'RY TYPT: OPERATOR ~ OPERATOR VERIFIED .;`t:~TEM A[JTO ENTRY ~ HOTH • • '~-~ ~ ~ KRU 1Q-24 ,.~ J Cono~t~Phillips Ai~ska~ Ertc. 1Q-24 -- API: 500292258400 Well T e: INJ An le TS: 30 de 6780 SSSV Type: NIPPLE Orig 9/4/1995 Angle @ TD: 32 deg @ 7313 Com letion: Annular Fluid: Last W/O: Rev Reason: POST FCO TAG NiP (61o-s11, oD:3.5o0) for IPROF TueING Reference Lo Ref Lo Date: Last U date: 5/17/2006 (o-ss7s, Last Ta : 7208 TD: 7313 ftKB oD:3.5o0, 992) '~ ID:2 Last Ta Date: 5/15/2006 Max Hole An le: 36 de 3150 , . Casin Stria -CONDUCTOR ~ ~ Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 12T 62.58 H-40 Casin Stria =SURFACE Descri lion Size To Bottom TVD Wt Grade Thread Gas Lin ' ~ SUR. CASING 7.625 0 4206 3800 29.70 L-80 andrel/Dummy Valve 1 ~ - Casin Shin - PRODUCTION (2587-2588, :- Descri lion Size To Bottom TVD Wt Grade Thread PROD. CASING 5.500 0 6680 5896 15.50 L-80 Casin Stria -LINER Descri lion Size To Bottom TVD Wt Grade Thread LINER 3.500 6679 7300 6426 9.30 L-80 Tubin Stria -TUBING Size To Bottom TVD Wt Grade Thread Gas Lin ~, , 3.500 0 6679 5895 9.30 L-80 ABM EUE andrel/Dummy -_- ~"' PerForations Summa valve z (4560-4561 ~_ - Interval TVD Zone Status Ft SPF Date T e Comment , oD:a.75o) == 7016 - 7034 6185 - 6200 A-4,A-3 18 4 12/31/1995 IPERF 180 deg. phasing; Oriented 22 deg. CCW F/ High Side, 2 1/2" Hollow Carrier 7056 - 7070 6219 - 6231 A-3 14 4 12/31/1995 IPERF 180 deg. phasing; Oriented 22 deg. CCW F/ High Side, 2 1/2" Hollow Carrier GasLift MandrelsNalves Gas Lift andrel/Dummy _ =.' St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Valve3 4r ~ Mfr Run Cmnt (58435844, 4 750 OD _ 1 2587 2472 BST ATX DMY 1.0 T-1 0.000 0 4/10/1996 . ) : 2 4560 4089 BST ATX DMY 1.0 T-1 0.000 0 4/10/1996 3 5843 5188 BST ATX DMY 1.0 T-1 0.000 0 12/27/199 4 6622 5845 BST ATX DMY 1.0 T-1 0.000 0 4/12/1996 Oth er lu s e ui .etc. -JEWELRY Packerless Com letion. De th ND T Descri lion ID 510 510 NIP Camco'DS' Landin Ni le; 2.856" NO GO 2.812" 2.812 Gas Lift } 6670 5887 NIP Camco'D' Ni le NO GO 2.750 andrevoummy Valve a -- - ~ 6679 5895 SEAL Baker'GBH-22' Stabbed into Seal Bore 3.000 (ss22-ss23, ~ 6679 5895 TTL 2.992 oD:a.75o) `_ General Notes Date Note ~ 4/25/1996 Note on Schematic: Packerless Com letion NIP I I,) (66705671, OD:3.500) PROD. CASING (0-6680, ', OD:5.500, W t:15.50) ' TTL ~ (6679-6680, OD:3.500) SEAL (6679-6680, ------- OD:3.500) Perf i (7016-7034) ------- ------ j i LINER ' (6679-7300, ~~___"~- --____- OD:3.500. ______ ................. Wt:9.30) Perf .................. _.....__..- 'i (7056-7070) MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg '--;-:)1\ ( -L. P.I. Supervisor ~1 7 Z-? p:..Co DATE: Wednesday, July 19,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHJLLIPS ALASKA INC lQ-24 KUPARUK RIV UNIT IQ-24 \lA..bJ \'ð--\ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .J13t2-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IQ-24 API Well Number 50-029-22584-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060718103403 Permit Number: 195-121-0 Inspection Date: 7/17/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ¡Type Inj. i W I TVD I , Well I IQ-24 5895 IA 930 2760 ¡ 2690 , 2690 I , i i ¡ i i I I I P.T. I 1951210 ITypeTest I SPT i Test psi 1500 I OA 490 770 i 740 720 I i I I I ! i I I i Interval 4YRTST P/F P Tubing i 2160 i 2160 2160 i 2160 I I Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. . .' C) <' ;~,.;;.....:. ~J J.. Wednesday, July 19,2006 Page I of 1 Scblumbergel' Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # 1Y-12 i.<¡(~-,~,:¡C 11235362 1L-06 i'ff.l./- I?:=' 11213748 1Q-24 c;ç - ),] i 11213849 1H-04 l-k,'.:J-I ~1, 11213752 1 H-08 }-$(:) - -,,c,;: 11213751 2Z-02 i'"lí? - ~','Í¿; 11235362 1 H-16 r=¡¡. -l~¡ 11235365 2A-04 I ~< - G"S< 11213755 31-10 1'iC¡-{':-z..1 11213759 1H-19 ¡,c :;;- j.:J?j 11320975 2A-13 i~- - iLf'.I 11320976 2Z-04 Î *" 3 -c:~ 11213757 2Z-12A I ,(,'S. - ¡.:¡~ 1123568? 3F-02 ¡ 4<'~ -;.,~( 11213758 RECEìVED \., /\ ,-. ....-n6 i\; j x 'il! , 1 'J V LGU "J<:$'.a C H ,~3<ìS Gens. Ccmfi'~ '~r:,<:1"('?qe Log Description INJECTION PROFILE PRODUCTION PROFILE WIDEFT INJECTION PROFILE INJECTION PROFILE RSTIWFL INJECTION PROFILE PRODUCTION PROFILE W/DEFT CROSSFLOW DETERMINATION PRODUCTION PROFILE W/DEFT INJECTION PROFILE LDL INJECTION PROFILE GLS PRODUCTION PROFILE W/DEFT NO. 3831 Company: " " (,' Field: Date BL OS/20/06 1 05/19/06 1 OS/20/06 1 OS/23/06 1 OS/22/06 1 OS/28/06 1 OS/24/06 1 OS/26/06 1 05/30/06 1 OS/29/06 1 05/30/06 1 OS/28/06 1 OS/27/06 1 OS/29/06 1 06/02/06 Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 ", \ do- \ Anchorage, AK 99501 \ ~6"'" Kuparuk \ e Color CD e c-11 ---._' Please sIgn and return one copy of this transmIttal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, June ~3. ~OO4 SlIBJECT: f\lechamcallmegrity Test:; CONOCOPHILLlPS ALASKA INC Jim Regg P.I. Supervisor l:'o/1 b/Z1/0'i FROI\I: IQ-14 KUPARUK RIV UNIT lQ-~..\ Chuck Scheve Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Supn' ~ Comm Well Name: KUPARUK RIV UNIT IQ-24 Insp Num: mnCSO-t0619202237 Rellnsp Num: API \Vell Number: 50-029-22584-00-00 Permit Number: 195-121-0 Inspector Name: Chuck Scheve Inspection Date: 6/19/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well )Q-~4 IType Inj. P TVD 6-138 IA 950 2100 2100 2100 P.T. )95)~10 !TypeTest SPT Test psi 1-173 75 OA 550 740 740 7..\0 Inten'al -IYRTST P/F P Tubing 2250 :!250 2~50 2~50 Notes: Pretest pressures obsen.ed for 30+ minutes and found smble. Well demonstrated good mechanical integrity. Wednesday, June 23. 2004 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. i. Supervisor DATE: May 17, 2001 FROM: John Crisp, ' SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit lQ Pad May !7 ,..2. 00!: i traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Bamdt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, the SSV on 1Q-05 would not pass the DP test. The valve was serviced & would not pass the re-test. Well 1Q-05 is shut in until repaired & re-tested. The AOGCC test report is attached for reference. I inspected 20 well houses on lQ Pad w/no problems witnessed. SUMMARY: t witnessed SVS testing in Kuparuk River Field. 15 wells, 30 components tested. 1 failure witnessed. 3.33% failure rate. 20 well houses inspected. Attachments: SVS KRU lQ 5-17-01jc cc_; N.,..ON-CONFIDENTIAL SVS KRU lQ 5-17-Oljc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: P~i!!ips Alaska Operator Rep: Ernie Barndt AOGCC Rep: John Crisp Submitted By: Jolm C 'risp Date: Field/Unit/Pad: Kupamk River'unit lQ Pad Separator psi: LPS 85 HPS 5/17/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip. .Code Code Code Passed GAS orCYCLE 1Q-02A 1951'93,0i ..... lQ-03 1842530 '~5 70 ~ "65~ 'P P ...... 0IL lQ-.04 ,' 1842540 ....... 85 60 55,".'P P" . ...... "'. .'OIL lQ-05 18~2170 85 "70 54 e "4-' OIL Q-06 1842080 85 60 55 p ' '~3 ............. OIL ,1Q-o9 1841920 3750 2000 19i)0 P P WAG 1.Q,-10 '1 1841980 85 ')0 " 62 e e ............... oIL 1..Q2 i 1, ..... i 1841990 .................. lQ-12 1841930 il.Q.-15 18504~0 ............... 'IQ-16 1850470 85 ' 70 '~4~ P ...... P " ' .~ . " OiL Q-26A 19~ 1560 ' 85 70 ~50 e P ......... OIL ,lQ-21 1951330 1Q-22 1951400 '" 85 70 '55 P ' ' P ...... OiL Q-23 ' 1951'410 ' 85 "70 ' 50 P e .... ~ ........... OIL 1Q-26 1951320 "'85 ' ;70 '52 P' "P ........ lq-08~ 1970930 ' '37:~0" '2000 18'50 '"' P "~ '~ ..... WAG lq-13 1850440 37501 ~000 " 1850 P P ............. WAG lq-14 1850450 3750 2000 1850 P P WAG 1Q-24 1951210' 3750' 2000 2100 "P P Wells: 15 Components: 30 Failures: 1 Failure Rate: 3.33% ["190 Day Remarks: 1Q-05 was serviced & re-tested, re-test failed & well was shut in for re. pairs. RJF 1/16/01 Page 1 ofl SVS KRU lQ 5-17-01je STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_X Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 97 feet 3. Address Explorato~ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__x Kuparuk Unit 4. Location of well at surface 8. Well number 1450' FNL, 1825' FEL, Sec.26, T12N, R9E, UM (asp's 527798, 5984417) 1Q-24i At top of productive interval 9. Permit number / approval number 212' FNL, 4635' FEL, Sec. 25, T12N, R9E, UM (asp's 530263, 5985670) 195-121 At effective depth 10. APl number 50-029-22584 At total depth 11. Field / Pool 94' FNL, 4356' FEL, Sec. 25, T12N, R9E, UM (asp's 530540, 5985784) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 7313 feet Plugs (measured) Tagged PBTD (11/25/99) @ 7175' MD. true vertical 6437 feet Effective depth: measured 7175 feet Junk (measured) true vertical 6320 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 250 Sx AS I 121' 121' SURF CASING 4109' 7-5/8" 690 Sx AS III, 330 CIG 4206' 3800' PROD CASING 6583' 5-1/2" 210 Sx Class G 6680' 5896' LINER 621' 3-1/2 ...... 7300' 6426' , . . , : Perforation depth: measured 7016 - 7034'; 7056 - 7070' ~ true vertical 6185 - 6200'; 6219 - 6231' ".. 7 3 2001 Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80, Tubing @ 6679' MD. 41aska Oil & Gas Cons. CO~rn'ssio~.i Packers & SSSV (type & measured depth) No Packer. Anchorage CAMCO 'DS' LANDING NIPPLE; 2.856" NO GO 2.812" @ 510' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - 800 - 2450 Subsequent to operation - 2200 - 2400 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ._X Oil __ Gas __ Suspended __ Service __(WAG)__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~;~lf~ Title: Date 7_¢///~,,/ · Prepared by John Peirce 265-6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 1Q-24i DESCRIPTION OF WORK COMPLETED HIGH PRESSURE BREAKDOWN TREATMENT 11/25/99: RIH & tagged PBTD at 7175' MD. 12/5/99: MIRU & PT equipment to 9400 psi. Pumped a Fullbore Non-Reactive High Pressure Breakdown to treat the open perforation intervals located at: 7016 - 7O34' MD 7056 - 7070' MD Pumped the treatment in 3 slurry Scour stages, which contained 20/40 mesh proppant in 1 to 2 ppa concentrations. Pumped all stages @ 40 bpm, and used rocksalt diverter in the 2nd & 3rd stages. Pumped slurries contained a total of 3600 lbs of rock salt diverter, and 12100 lbs of proppant. RD. Returned the well to water injection & obtained a valid injection rate. W c:t.ov, lxt, ta~t .DOC ARCO Alaska, Inc. Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 April 9. 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, First Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the first quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the first quarter of 1999. Annular Injection during the first quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-315 25326 100 0 25426 See Note ~ betow 25426 2L-325 8397 100 0 [ 8497 11883 20380 2N-321A 27507 100 0 I 27607 0 27607 3K-23 15 0 0 15 0 15 3K-25 4202 100 0 4302 0 4302 1 C- 15 16695 100 0 16795 0 16795 2L-313 8554 100 0 8654 0 8654 Note #1: Well # 2N-315. The previously r~ ~orted volume of 220 barrels was purnped into this annuhts during the drilling of the well. This was the w~[ume required to j'htsh and freeze protect the annulus during initial drilling operations, not a w~lume qf disposal }hdds injected prior to the receipt o~' authorization for annular injection. Total Volumes into Annuli for which Injection Authorization Expired during the quarter Total I Total h(1) I Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus 1C-12 34995 100 0 35095 Open, Freeze Protected 1C-13 26800 100 0 26900 Open, Freeze Protected Additionally, to prevent any possible confusion regarding previous reports of volumes injected, and to insure that the State's records are in agreement with ARCO's, we would like to repeat and supplement information we provided with our letter of February 26,1999. The information below is only for those wells for which injection volumes may not have been properly reported at the time of injection. Again, these volumes are the same as those reported with our February 26th letter, and are only reported here again for the sake of clarity. ARCO Alaska, inc. is a Subsidiary of Atlantic Richfield Company AR3B-6003-C Ms. Wendy Mahan AOGCC First Quarter 1999 Annular Injection Report Page Two Total Total h(1) Total h(2) Total h(3) Volume Current Status of Well Name Volume Volume Volume Injected Annulus 2A-22 16749 100 0 [ 16849 Open, Freeze Protected 2F-19 20725 100 0 I 20825 Open, Freeze Protected 3K-27 37173 100 0 I 37273 Open, Freeze Protected 3K-26 33970 100 0 [ 34070 Open, Freeze Protected 1E-31 33645 100 0 ' I 33745 Open, Freeze Protected 1E-32 45205 100 0 I 45305 Open, Freeze Protected 3Q-22 6245. 100 0 i 6345 Open, Freeze Protected 1Q-24 23158 ] 100 0 I 23258 Open, Freeze Protected 1Q-26 25931 I 100 0 t 26031 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader cC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental' Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Steve McKeever Well Files C 0 k'J B'I E N T S ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 25, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1Q-24 (Permit No. 95-121) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent operations on KRU 24. If there are any questions, please call 263-4622. Sincerely, W. Isaacson Drilling Engineer Kuparuk Drill Site Development ORIGINAL WSI/skad lQ- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL [~] GAS ~ SUSPENDED [----] ABANDONED E~ SERVICE r'~ Classification chan~led to injector March 1996 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-121 .. 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22584 4 Location of well at surface La?~,~..,,.~.,._. 9 Unit or Lease Name ~-".~:ili:.'i ~'-?-~ "i' ~: ilI,.~-'~-,~ Kuparuk River Unit 1455' FNL, 1825' FEL, Sec. 26, T12N, R09E, UM ¢ :"'.' '. lO Well Number At Top Producing Interval ........ , 1 Q-24 At Total Depth:~ .... ~"-.~i _ ~::~ 11 Field and Pool 93' FNL, 921' FWL, Sec. 25, T12N, R09E, UM ;:' .... , ............... J KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. RKB 41', Pad 56'I ADL 25641 ALK 2572 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions August 28, 1995 September 2, 1995 31 -Dec-95 (perrd) NA feet MSLJ 1 7313' MD & 6438' ~D 7236' MD & 6372' TVD YES ~ NO ~~ NA feet MDJ = 1380' ss APPROX 22 Ty~ Electric or Other Logs Run ARCE/GR, GR/CC~SLT-J 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE ~ GRADE TOP B~ HOLE SIZE CEME~ ~RD 16" 62.5~ H-40 SURF. 121' 24" 250 sx AS I 7.625" 29.7~ L-80 SURF. 4206' 9.875" 690 sx AS III Lead, 330 sx Class G Tail 5.5" x 3.5" 15.5~/9.3~ L-80 SURF. 7300' 6.75" 210 sx Class G ,,, 24 Pedorations o~n to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD inte~al, size and numar) ~SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 6679' 7056'-7070' MD 4spf 6219'-6231'~D 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 7016'-7034' MD 4spf 6185'-6200' ~D DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7016-7034', 7056-7070' 5400~ of 20/40, 10738~ of 1~18, 29000~ of 16/20 proppant 27 PRODUCTION TEST Date First Production Method of O~ration (Flowing, gas li~, etc.) Mar-96 nitially planned as a producer, due to high water cut on production tests, well converted to IWAG injector Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 3/19/96 12 TEST PERIOD ~ 1 00 1217 283 100 12082 Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 2~ 1371 24-HOUR RATE ~ 201 2433 566 =24° 28 CORE DATA Brief description of lithology, ~rosity, Eactures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, v~EAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 6780' 5983' Bottom Kuparuk C 6855' 6048' Top Kuparuk A 6999' 61 70' Bottom Kuparuk A 7130' 6282' AI:..¢'?. Oii_. ,:.: '" ¢_-.,.:s Co::..-'.--'.;-;.. -',,>': ...... At';r.;hr:::'~ s 31. LIST OF A'I'TACHMENTS Directional Survey, Daily Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible', Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 tte: 2/23/96 WELL' 1Q-24 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 RIG:NO RIG WELL ID: AK8309 AFC: AK8309 -- STATE'ALASKA AREA/CNTY' NORTH SLOPE EAST · FIELD: KUPARUK RIVER UNIT SPUD' START COMP: TYPE: BLOCK: FINAL' WI: 55% SECURITY:0 AFC ES?/UL:$ 1300M/ API NUMBER' 50-029-22584-00 OM 8/18/95 ( 1) TD' 121' ( 121) ~UPV:RLM DAILY: 08/19/95 (2) TD' 121'( 0) SUPV'RLM DAILY' 08/20/95 ( 3) TD: 121'( 0) SUPV'RLM DAILY' 08/21/95 ( 4) TD: 121'{ 0) SUPV:RLM DAILY' 08/22/95 ( 5) TD' 121'( 0) SUPV'RLM DAILY' 08/23/95 ( 6) TD: 121' ( 0) SUPV: JT DAILY' 08/24/95 ( 7) TD' 121' ( 0) SUPV' JT DAILY' 08/25/95 ( 8) TD' 121'( 0) SUPV:JT DAILY: 08/26/95 ( 9) TD: 121' ( 0) SUPV' JT DALLY' MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG Move ball mill 14.3 miles from 2T pad to iQ pad. $24,895 CUM: $24,895 ETD: $0 EFC: $1,324,895 MW: 0.0 PREP MODULES FOR MOVE Preparing rig for move. $118,109 CUM' $143,004 ETD' PV/YP: 0/ 0 APIWL. 0.0 $0 EFC' $1,443,004 MW: 0.0 PICK UP PLYWOOD Moving rig. $92,987 CUM: $235,991 ETD: PV/YP: 0/ 0 APIWL' 0.0 $0 EFC' $1, 535, 991 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MOVE MAT BOARDS AROUND RIG Lay matting boards through section of repaired road. Move utility module from 2A pad to F pit staging area. $92,223 CUM: $328,214 ETD: $0 EFC: $1,628,214 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 LAYING PLYWOOD Move drilling and utility modules one mile from F pit to 2A pad. Lay plywood and matting boards between 2A and four corners. $52,444 CUM: $380,658 ETD: $0 EFC: $1,680,658 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 LAYING PLYWOOD Lay plywood and matting boards between 2A pad and the four corners. Move both modules from 2A to four corners. $65,565 CUM: $446,223 ETD: $0 EFC: $1,746,223 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 LAYING PLYWOOD & MOVING RIG Lay plywood and matting boards between the four corners and 2B, and then to CPF-2.Moving utility and drilling modules. $58,312 CUM: $504,535 ETD: $0 EFC: $1,804,535 MW: 0.0 MOVING RIG Move rig and utility modules. $58,816 CUM' $563,351 ETD: PV/YP' 0/ 0 APIWL' 0.0 $0 EFC: $1,863,351 MW' 0.0 PV/YP' 0/ 0 APIWL' 0.0 PREPARE TO RAISE DERRICK Move rig module. Position utility module. Set derrick on drill module. Position drill module over well. $63,751 CUM' $627,102 ETD' $0 EFC' $1,927,102 Oate: 2/23/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 08/27/95 (10) TD: 121'( 0) SUPV:JT DAILY: 08/28/95 ( 11} TD: 250' ( 129} SUPV: JT DAILY: 08/29/95 (12) TD: 4220' (3970) SUPV: JT DAILY: 08/30/95 (13) TD: 4220' ( 0) SUPV:RLH DAILY: 08/31/95 (14) TD: 4220' ( 0) SUPV:RLM DAILY: 09/01/95 (15) TD: 5272' (1052) SUPV:RLM DAILY: 09/02/95 ( 16) TD: 6643' (1371) S UP V: RLM DAILY: 09/03/95 (17) TD: 7313' (670) S UP V: RLH DAILY: 09/04/95 (18) TD: 7313' ( 0) SUPV:RLM DAILY: 09/05/95 ( 19} TD: 7313' ( 0) SUPV:RLM DAILY: MW: 9.0 PV/YP: RU TOP DRIVE Raise derrick. Set utility module. $75,146 CUM: $702,248 ETD: 26/36 APIWL: 5.6 $0 EFC: $2,002,248 MW: 9.0 PV/YP: DRILLING Accept rig 8/27/95 @ 1500 hrs. Drill to 250' $78,526 CUM: $780,774 ETD: 24/33 APIWL: 5.4 9-7/8" hole from 121' $0 EFC: $2,080,774 MW: 10.0 LD BHA Drilled from 250' to 4220' $75,693 CUM: $856,467 ETD: PV/YP: 20/13 APIWL: 7.8 POOH to run 7-5/8" casing. $0 EFC: $2,156,467 MW: 10.0 CIRCULATE CASING Run 7.625" casing. Lost mud. $75,173 CUM: $931,640 ETD: PV/YP: 16/10 APIWL: 8.8 $0 EFC: $2,231,640 MW: 8.6 PV/YP: 3/ 3 APIWL: 18.4 WORK ON ANADRILL PROBE Pump casing in hole. Cement 7-5/8" casing. CIP at 1053 hfs 8/30/95. High pressure drop across Anadrill tool. Reconfigure tools until pressure drop acceptable. $184,579 CUM: $1,116,219 ETD: $0 EFC: $2,416,219 MW: 8.7 PV/YP: 9/ 6 APIWL: 10.3 DRILLING Pressure test casing. Directional drill 6.75" hole from 4230' to 5272' $72,641 CUM: $i,188,860 ETD: $0 EFC: $2,488,860 MW: 9.0 PV/YP: 15/ 9 APIWL: 7.0 DRILLING Directional drill 6.75" hole from 5272' to 6643' $73,669 CUM: $1,262,529 ETD: $0 EFC' $~,562,529 MW: 11.1 PV/YP: 31/16 APIWL: 24.0 POOH TO RUN CASING Directional drill 6.75" hole from 6643' to 7313' $94,182 CUM: $1,356,711 ETD: $0 EFC' $2,656,711 MW: 11.1 PV/YP: 31/16 APIWL: 4.5 LAY DOWN 4" DRILL PIPE Run 3.5" and 5.5" casing. Cement 3.5" x 5.5" production string CIP at 1951 hfs 9/3/95. Freeze protect annulus. $154,101 CUM: $1,510,812 ETD: $0 EFC: $2,810,812 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Lay down drill pipe for around the corner move. Release rig @ 0900 hrs. 9/4/95. $10,874 CUM: $1,521,686 ETD' $0 EFC' ~.2,821,686 Date' 2/23/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 3 REMEDIAL AND COMPLETION OPERATIONS WELL'lQ-24 RIG:NO RIG WELL ID' AK8309 AFC' AK8309 TYPE: STATE'ALASKA AREA/CNTY' NORTH SLOPE EAST FIELD' KUPARUK RIVER UNIT SPUD' START COMP: BLOCK: FINAL: WI: 55% SECURITY'0 AFC EST/UL:$ 1300M/ OM API NUMBER: 50-029-22584-00 12/26/95 (20) TD: 7313' PB: 7236' SUPV:BP DAILY: N/U BOPS MW' 0.0 SW Hove rig to 1Q-24. Accept rig @ 0430 hrs, 12/26/95. N/D tree. N/U BOPs. $14,581 CUM' $1,536,267 ETD: $0 EFC: $2,836,267 12/27/95 (21) TD' 7313' PB' 7236' SUPV' DEB DAILY' RIG RELEASED MW: 0.0 NU and function test BOPE. Test 5-1/2" x 3-1/2" casing to 3500 psi for 30 minutes, lost 100 psi, OK. Run 3-1/2" single completion assembly. Freeze protect annulus. Test tubing to 3500 psi, lost 50 psi in 30 minutes, OK. Bleed off tubing. Test annulus to 3500 psi, lost 50 psi in 15 minutes, OK. Test packoff to 5000 psi. Test tree to 250 psi and 5000 psi. Secure well. Release rig @ 0600, 12/27/95. $34,160 CUM: $1,570,427 ETD: $0 EFC: $2,870,427 End of WellSummary for Well:AK8309 ABCO Alaska, Inc. KUPARUK RIVER UNIT ,~ WELL SERVICE REPORT i '~ K1(1Q-24(W4-6)) WE. rLL JOB SCOPE JOB NUMBER 1 QI-24 PERFORATE, PERF SUPPORT 1 228951 61 5.1 UNIT NUMBER DATE 1 2/31/9 5 DAILY WORK PERFORATE 'A' SAND OPERATION COMPLETE I SUCCESSFUL I KEY PERSON YES I YES I BAILEY InitialTbgPress IFinalTbgPress llnitiallnnerAnn IFinallnnerAnn 0 PSI 800 PSI 0 PSI 500 PSI SUPERVISOR PAIGE Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI DAILY SUMMARY COMPLETED PERFORATING 'A' SAND INTERVAL 7056'-7070' & 7016'-7034' USING 2-1/2" HOLLOW CARRIER W/4 JSPF, 180 DEG PH, ORIENTED W/2 SPF 22 DEG CCW F/HIGH SIDE AND 2 SPF 158 DEG CW F/HIGH SIDE TIME LOG ENTRY 07:00 MIRU SWS. HELD SAFETY MTG. 09:00 PT LUB TO 3000#; TEST OK. RIH W/GUN#1 - 18' 2-1/2" HOLLOW CARRIER W/4 JSPF, 180 E)EG PH, AND ORIENTED W/2 SPF 22 DEG CCW F/HIGH SIDE & 2 SPF 158 DEG CW F/HIGH SIDE TO SHOOT 7056'-7070' PER CBL DATED 9/8/95 09:15 MIRU LIL' RED. PT7" CSG TO 3000# FOR 15 MINS; TEST OK. 10:00 FIRED GUN W/1400# OF PRESSURE ON TBG TO SHOOT 200# OVERBALANCED. POH W/GUN#1. RDMO LIL' RED. 10:30 AT SURF W/GUN#1; ALL SHOTS FIRED. 11:15 PT LUB TO 3000#; TEST OK. RIH W/GUN#2 - 18' 2-1/2" HOLLOW CARRIER W/4 JSPF, 180 DEG PH, Ai"~ID ORIENTED W/2 SPF 22 DEG CCW F/HIGH SIDE & 2 SPF 158 DEG CW F/HIGH SIDE TO SHOOT 7016'-7034' PER CBL DATED 9/8/95 12:00 FIRED GUN; POH. 12:30 AT SURF W/GUN#2; ALL SHOTS FIRED. 13:00 RDMO TO 1Y-28. 5.. l ~ 2,0 0 t ;"+ 9 ~ 5 ? 5~ :?,~ i ? :5 ~., 3 ? 3 t:. ~ 5.. :3 .'5, ?'-'2 ~ _;. 4; z 2 ! 7'31; :._';,3 t '-" ] ".. ,i 2 :, 3,5: !. · ;) ~ ....... Z':77./: ............. : .... ': ...... ARCO Alaska, Inc. Date- December 26, 1995 Transmittal #' 9310 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 'fj'~)~ 2T-27 CDR 04/17/95 REF #50-103-20217 r 2T-32 CDN 04/30/95 REF #50-103-2021 8-00 ,f,.E~,-¢ ~f '"2T-32 CDR 04/30/95 REF #50-103-20218-00 ,/,¢-~-? 2T-30 CDR 05/12/95 REF #50-103-20219-00 ~ ~--(,'7.,.c[ 2V-06 TDTP 06/11/95 REF #95219 cC'-u'[ 2T-31 CDR 0713/95 REF #50-103-20226-00 f2T-36 CDR 07/25/95 REF #50-103-20228-00 ~-2T-36 ~/~ CDN 07/25/95 REF #50-103-20228-00 ~:2T-38 CDR 08/03/95 REF #50-103-20229-00 B. fl ~ )._2T-38 CDN 08/03/95 REF #50-103-20229-00 %p. ~o~ 2T-37 CDR 08/10/95 REF #50-103-20227-00 ~.~ 1Q-24 ARC5 Array Resistivity Comp. 08/30/95 4206-7270 ,~ ~3~,- 1Q-26 ARC5 Array Resistivity Comp. 09/22/95 3820-7010 ~-..~,.,~ 1Q-23 ARC5 Array Resistivity Comp. 09/30/95 5156-9982 Acknowledged' Date' DISTRIBUTION' Mr. Vernon E. Pringle Jr. DeGIoyler and MacNaughton One Energy Square Dallas, TX 75206 Erickson/Zuspan NSK Central Files NSK 69 Sharon AIIsup-Drake DS Development ATO - 1205 Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 ,,,..~,,.. nil & Gas Cons. Cc,w-mi~'en Anchorage Clifton Posey Geology ATO - 1251 11/9/95 NO. 987O GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'n'N: Sherrie Well /Job # Log Description Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Kuparuk (Open Hole) Field: LIS RF Sepia DIR MWD Tape Date BL 1Q-24 f 95324 ARC5 950830 I I 1 2T-32 95172 CD~CDN 950430 1 2T-32 CDR 950430 I 1 2T-32 CDN 950430 I 1 ,, , , ,, , SIGNED: DAT~laska Oil & Gas C(~ns. Commission Ancl~orage Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. PERMIT DATA 95-121 6928 AOGCC Individual Well Geological Materials Inv! .... tory T DATA_PLUS -- L 4206-7313 ARRAY RESISITIVITY 1 Page: 1 Date: 01/24/96 RUN DATE_RECVI 11/17/95 Are dry ditch samples required? yes no And received? Was the well cored? yes no Analysis & description received? Are well tests required? yes no Received? yes no Well is in compliance Initial COMMENTS yes no yes no PERMIT 95-121 95-121 TRAN~o~ DATA AOGCC Well Inve ry With Scale RUN DATA_PLUS Page' 01/24/1996 2 SCALE 6928 1 ARRAY RESISITVTY 1 4206-7313 ARRAY RESISITIV 4206-7270 0 2&5 ARCO Alaska, Inc. Date: October 20, 1995 Transmittal #: 9305 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Taleak Kuparuk Operations File Clerk ATO-1270A P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. receipt and return one signed copy of this transmittal. 2T- Cement Bond Log 9/8/95 CDN 5/28/95 CDR 5/28/95 .b-01 Cement Bond Log 9/25/95 Ultrasonic Imager 9/25/95 CDN 8/16/95 CDR 8/16/95 CDR 6/24/95 CDR 4/6/95 Please acknowledge APl #50-029-22584 APl #50-103-20221 APl #50-103-20221 APl #50- ! 03-20230 APl #50-103-20230 APl #50-103-20230 APl #50-103-20230 APl #50-103-20224 APl #50-103-20216 Acknowledged: 2 , Date: DISTRIBUTION: Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 TONY KNOWLES, GOVERNOR ALASKA OIL ~ GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 16, 1995 Mike Zanghi, Drlg Engr Supv ARCO Alaska Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Kuparuk River Unit 1Q-24 ARCO Alaska, Inc. Permit No 95-121 Surf Loc 1455'FNL, 1825'FEL, Sec. 26, T12N, R09E, UM Btmhole Loc 152'FNL, 953'FWL, Sec. 25, T12N, R09E, UM Dear Mr. Zanghi' Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector 659-3607. Yours very truly, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation o w/o encl STATE OF ALA,SKA ALASKA OIL AND GAS ~SERVATION COMIv,,..~SION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work Drill X Redrill r-I i b Type of Well Exploratory E] Stratigraphic Test I'-1 Development Oil X Re-Entry E! Deepen [--I Service El Development Gas El Single Zone X Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool · ARCO Alaska, Inc. RKB 41', Pad 56' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360~ Anchorage~ AK 99510-0360 ADL 25641~ ALK 2572 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.O25) 1455' FNL, 1825' FEL, Sec. 26, T12N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 292' FNL, 655' FWL, Sec. 25, T12N, RgE, UM 1Q-24 #U-630610 At total depth 9. Approximate spud date Amount 152' FNL, 953' FWL, Sec. 25, T12N, RgE, UM 8/20/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1Q-09 7353' MD 152 ~ TD feet 10.5' ~ 1225' MD feet 2560 6473' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 1200' feet Maximum hole angle 33.11° Maximum surface 2242 p$ig At totaJ depth ('I'VD) 3317 psig 18. Casing program Setting! Depth size Specifications Top Bottom Quantit~ of cement Hole Casin~l Welt, iht Grade Couplin~l Len~lth MD TVD MD 'i'VD (include 8rage dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +P00 CF 9.875" 7.625" 29.7# L-80 LTC 4106' 41' 41' 4147' 3787' 640 Sx Arcticset III & HF-ERW 330 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMOD 6659' 41' 41' 6700' 5926' HF-ERW 6.75" 3.5" 9.3# L-80 8rdMOD 653' 6700' 5926' 7353' 6473' 230SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (r~eas-ured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor r~ ......... : Surface ~'. ii. I ~' Intermediate Production LinerAUG 0 8 1995 Perforation depth: measured true vertical j~l~l, Cli[ .& Gas Cons. Comrni~sion Anchorane 20. Attachments Filing fee X Property plat r"l BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot El Refraction analysis El Seabed report El 20 AAC 25.050 requirements X 21. I hereby certify that thee foregoingjs true and correct to the best of my knowledge Signed '~.,/(.. ,~ Title i Drill Site Develop. Supv. Date Commission Use On ~f . Permit Number I APl rlu~be¢ ..... I Approval date.,~, _, ,~.-~----- I See cover letter for ' ~. ~'-/2. / I 5 0- ~ :~. ~ - --~- ~_% ~2x I ' / ~ ' 7~'~ I other requirements Conditions of approval Samples required [--i Yes [~ No Mud log required [-1 Yes J~ No Hydrogen sulfide measures [~ Yes r=l No Directional survey required .[~ Yes I--1 No Required working pressure for BOPE 2M ~ 3M r=l 5M r=l 1OM El 15M Other: Approved by i~US'~ELL A. DOUGLAS~ Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD 1Q-24 · . . . · . . · 10. 11 12 13 14 15 16 17 Move in and rig up Parker #245. Install diver, er system. Drill 9-7/8" hole to 7-5/8" surface casing point (4,147')according to directional plan. Run and cement 7-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 6-3/4" hole to total depth (7,353') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement tapered 5-1/2" x 3-1/2" casing string. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & either full opening valve (if logging planned) or master valve and upper tree assembly (if no logging planned). Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test tapered 5-1/2" x 3-1/2" casing to 3500 psi. Run completion assembly. Pressure test SBE/XO. ND BOPE and install production tree. Shut in and secure well· D Clean location and release rig in preparation for perforating. ,, ,... ~. i ~. ,.,. AUG 0 8 1995 Alaska 0il & Gas Cons. Commission Anchorage DRILLING FLUID PROGRAM Well 1Q-24 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.1 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Dril ling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators AUG 0 8 1995 Pit.& Gas Cons. Commission ',~orage Notes- Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 A^C 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 2,242 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 1Q-24 is 1Q-09. As designed, the minimum distance between the two wells would be 10.5' @ 1225' MD. Annular Pumping Activities: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1Q-24 surface/production casing annulus will be filled with diesel after setting the 5-1/2" x 3-1/2" tapered casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 1Q-24 be permitted for annular pumping occurring as a result of the drilling project on DS lQ, per proposed regulations 20 AAC 25.005 (k). Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Surface casing will be set in the Creatceous 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. Generally, the surface casing shoe is set 200' vertical below the base of the West Sak into the heart of the shales. Drillin~l Area Risks- Risks in the 1Q-24 ddlling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation matedal (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #1 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of ~ta from offset wells s w that a mud we_~g_h_t of 1.1.1 pp~ will provide sufficient overpressure ~ safely ddll, trip pipe, and c~m-~ The 7-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. AUG 0 8 1995 0it & Gas Cons. Commission Anchorage ARCO ALASKA, Inc. Structure : Pad lQ Well : 24 Field : Kuporuk River Unit Location : North Slope, Alaska l ]Created by : jones For: D PETRASH IDote plotted : 27-Ju1-95 iP[ot Reference is 24 Vere[on #4. iCoordincrtes ere in feet reference slot ~24. iTrue Ver[icel Depths ere reference RKB (Porker ~245). 0 _ 0 o o,,I _ ,, 400 _ o.oo East > 0 500 600 900 1200 1500 1800 2100 2400 2700 3000 TD LOCATION: 152' FNL, 953' FWL SEC. 25, T12N, R9E RKB ELEVATION: 97' SURFACE LOCATION: 1455' FNL, 1825' FEL /"'/'~%,* >~-""'- SEC. 26, T12N, R9E ~ ~,,., % .//~¢o~%/- ~ %¥~ '~ TARGET LOCATION: ~ Ye ~ %+ o% 292' FNL, 655' FWL KOP 'TVD=1200 TMD=1200 DEP=O r~-d~o_ % 3.oo % % SEC. 25, T12N, RgE 6.00 ~ ';>0 TARGET 12.00 El/ PERMAFROST TVD=1597 TMD=1600 DEP=42 "%_ 'rvD=5968 TMD=6750 ~5.oo DEP=2739 18.00 21.00 BUILD 3 DE(; / 100' NORTH 116.5 24.00 EAST 2480 27.00 33.00 EOC TVD=2245 TMD=2504 DEP=310 T/ UGNU SNDS TVD=2397 TMD=2487 DEP=410 I I V 800 _ -- 1200_ _ 1600_ _ 2000_ _ 24OO_ _ 2800_ _ 3200_ _ 5600_ _ 4000_ _ 4400_ _ 4800_ _ 5200_ _ 5600_ _ 6000_ _ 6400_ _ 6800 4O0 T/ W SAK SNDS TVD=3012 TMD=3221 DEP=811 N 64.88 DEG E 2739' (TO TARGET) B/ W SAK SNDS TVD=5587 TMD=5908 DEP=1186 7 5/8" CSG PT ~/D=3787 TMD=4147 DEP=1317 AVERAGE ANGLE 33.11 DEG K-10 WD=4827 TMD=5388 DEP=1995 TARGET - T/ ZONE D TVD=5968 TMD=6750 DEP=g739__ B/ KUP SNDS TVD=6305 TMD=7153 DEP=2959 TD /'~ 1/2" CSG PT TYD=6473 TMD=7353 DEP=3068 K-5 "~D=5587 TMD=6296 DEP=2491 1500 1200 900 . ' 600 300 _ 0 AUG 0 8 1995 Al~ka Oil & Gas Cons. Commission Anchorage HRZ Midpoint TVD=5801TMD=6551 DEP=2650 T/ ZONE C TVD=6009 TMD=6799 DEP=2766 ZONE B ~7D=6078 TMD=6882 DEP=2811 ZONE A TVD=6191 TMD=7017 DEP=2885 T/ A5 SNDS TVD=6217 TMD=7048 DEP=2902 I I I I I I I I I I I I I I I 400 800 1200 1600 2000 2400 2800 .3200 Scale 1 : 200.00 Vertical Section on 64,88 azimuth with reference 0.00 N, 0.00 E from slot #24 ALPC0 ALASKA, Inc. iCreeted by : jones FOr: D PETRASH iOa[e plotted : 27-Jul-95 IPIot Reference is 24 Version ~4. Coordinates ore in feet reference slot t~24. iTrue Verticol Depths ore reference RKB (Parker ~245). 600 . . 56O 520 48O 440_ 400 360 320 280 _ - 240 _ 200 _ 160 120 80 40 40 0 0 -- 120 0 Structure : Pad lQ Well : 24 Field : Kuparuk River Unit Location : North Slope, Alaska East ScaPe 1 : 20.00 80 40 0 40 80 120 160 200 240 280 520 560 400 440 480 520 560 _ oo _ ~00 _ _ 3400 5200 3000 _ /1200 2800 26OO _ /lOOO / Z400 00 800 ~ / 2000 ~ ~ 80o % % % % % % r~°( 2000 24OO I I I I I I I I I I I I I I I I I I II I I I I I I I I I I 80 40 0 40 80 120 160 200 240 280 320 3150 400 440 480 520 560 o.oo Fasf > . 600 _ _ 560 _ _ 520 _ _ 480 _ _ 440 _ _ 400 360 32O 280 I I 240 200 0 ~60 I 120 80 40 0 4O C) C) 8O .. 120 0 ~) © ,.UPARUK RIVER UNI,. 20" DIVERTER SCHEMATIC 6 3 I DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. , MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THATAN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) AUG 0 8 1995 1. 16"CONDUCTOR. Ala$~ Oil & Gas Cons. Commission 2. SLIP-ON WELD STARTING HEAD. ~u'c"orage 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"- 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 2Ct' - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 7 5 4 13 5/8" 5000 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. I 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"- 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3.CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILLAND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7.TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOWAND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'I-I'OM PIPE RAMS. TEST BO'I-I'OM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILMNG POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. PIPE RAMS ARE 4"; WHEN 5-1/2" CASING IS TO BE RUN THE RAMS WILL BE CHANGED OUT TO ACCOMODATE 5-1/2" CASING AND ALL BREAKS TESTED. "Fo ~eoo Psi AUG 0 8 1995 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Box 100350 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 3, 1995 Mr. David Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: 1Q-24 Slimhole Request for Permit to Drill Dear Mr. Johnston: Attached is the Permit to Drill application for 1Q-24. This well will be the first in Kuparuk's renewed "slimhole" drilling program. The wells at DS lQ will be similar to the initial pilot slimhole program conducted in spring of 1994, when we drilled KRU 3H-26, 1B-18 and 1B-19 as slim wells. The major differences between the 1995 slimhole program and conventional Kuparuk wells are: 1. The smaller casing program (from 9-5/8" to 7-5/8" and from 7" to tapered 5-1/2" x 3-1/2"). . Replacing the production packer with a polished seal bore integral to the casing string; Nordic Rig #1 will later run a seal assembly at the end of the completion string and sting into the seal bore. , If topsetting the Kuparuk with 5-1/2" casing is required due to high reservoir pressure, either Nordic or the coiled tubing unit will continue the well through the Kuparuk due to the small size of drillpipe/coil required in 5-1/2" casing. If there are any questions please contact the Parker 245 Drilling Engineer, Denise Petrash at 263-4183; or myself at 265-6206. ~~!.Since z~rely, , Supervisor Kuparuk Drill Site Development AUG 0 8 1995 Oil & Gas Cong. Commission ~mchorage AR3B-6003-93 2d2-2603 WELL PERMIT CHECKLIST PROGRAM: exp [] dev~ redrll [] serv [] ON/OFF SHORE <~ ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ..... ~ 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... il. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ....... ENGINEERING APPR DATE 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndrunnt been approved. -~ 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate .................... 26. BOPE press rating adequate; test to __~(~ psig.~ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ GEOLOGY DATEi 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ ...~ Y N 34. Contact name/phone for weekly progress reports . . ./~ . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: DWJ Cc~ments/Instructions: ~W/~o - A:~FORMS~cheklist rev 03/94 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. M C OF LM :g * , , ALASKA COMPUTING CENTER · * * * ....... SCHLUMBERGER · * * COMPANY NAME WELL NAME FIELD NAME BOROUGH STATE AP1 NUMBER REFERENCE NO : ARCO ALASKA, INC. : lq - 24 : KUPARUK RIVER UNIT : NORTH SLOPE : ALASKA : 50-029-225584-00 : 95324 LIS Tape Verification Listing Schlumberger Alaska C~mputiCg Center 6-NOV-1995 14:47 **** REEL HEADER SERVICE NAME : EDIT DATE : 95/ll/ 6 ORIGIN : FLIC REEL NAME : 95324 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK 1~-24, aPI ~50-029-22584-00 **** TAPE HEADER SERVICE NAME : EDIT DATE : 95/lZ/ 6 ORIGIN : FLIC TAPE NAME : 95324 CONTINUATION # : PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK ~Q-24, API ~30-029-22584-~0 TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 3002922338400 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 6-NOV-93 BlT RUN ~ BlT RUN 2 BIT RUN 3 JOB NUMBER: 95324 95324 LOGGING ENGINEER: KADRMAS KADRMAS OPERATOR WITNESS: MORRISON MORRISON SURFACE LOCATION SECTION: 26 TOWNSHIP: 12N RANGE: 9E FNL: 1455 FSL: FEL: [825 FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: 97.00 DERRICK FLOOR: 97.00 GROUND LEVEL: 55.70 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 95324 KADRMAS MORRISON 1ST STRING 7.625 4206.0 2ND STRING PAGE: LIS Tape Verification Listing Schlumberger Alaska Cbmputidg Center 6-NOV-1995 14:47 3RD STRING PRODUCTION STRING REMARKS: Well drilled 31-AUG through 03-SEP-95 with ARC5 only. All data was collected in three bit runs. MAD data was collected on bit run #3 from 5343' to 5576'. The well was depth shifted to the CBT run 8-SEP-95. The LDWG presentation does not have ROP or acquisition ticks presented due to acquisition format compatibility. $ $ **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/ 6 MAX REC SIZE : 1~24 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH MWD 4173.0 7313.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MWD 88888.0 88891.~ 6767.0 677~.0 6732.5 6735.~ 6675.0 6677.~ 6508.5 6510.0 6497.0 6499,0 6451.0 6452.5 6387.0 6388.5 6075.0 6077.0' 5854.0 5855.5 100.~ 101.5 $ MERGED DATA SOURCE LDWG TOOL CODE BIT RUN NO. MERGE TOP MERGE BASE LIS Tape Verification Listing Schlumberger Alaska C~mputing Center 6-NOV-1995 14:47 PAGE: MWD 1 4173.0 4422.~ MWD 2 4422.0 5576.0 MWD 3 5576.0 7313.0 $ REMARKS: The depth adjustments shown above reflect the MWD GR to the CBT GR logged by SWS. All other MWD curves were carried with the GR. The ARC5 curves, GR, and TAB were converted from the field data, ROP and the GR TAB were not able to be converted from the field data due to format compatibility with the field files. $ LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 14 65 FT 15 66 68 16 66 ~ 66 0 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 00 000 eO 0 1 1 1 4 68 00000~0000 ROP MWD F/HR 00 000 00 e 1 1 1 4 68 00000000~0 FET MWD HR 00 000 0~ 0 1 1 1 4 68 00000~0~0 GR MWD GAPI 00 000 00 0 1 1 1 4 68 00~00000~ RPXX MWD OHMM 00 000 00 0 1 1 1 4 68 00~0000000 RPX MWD OHMM 00 ~00 00 0 1 1 1 4 68 0000000000 RPS MWD OHMM 00 000 ~0 0 1 1 1 4 68 00~0000000 LIS Tape Verification Lis~ing Schlumberger Alaska C~mpu~iAg Cen~er 6-NOV-1995 14:47 PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RPM MWD OHMM 9~ 090 00 0 1 1 1 4 68 0000000000 RPD MWD OHMM 00 990 00 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 4176.0e~ ROP.MWD 180.900 FET.MWD 10.486 GR.MWD RPXX.MWD 100~.0~ RPX.MWD 1~00.999 RPS.MWD 1~.~0 RPM.MWD RPD.MWD 1000.000 DEPT. 7315.00~ ROP.MWD 90.99e FET.MWD 0.656 GR.MWD RPXX.MWD 2.708 RPX.MWD 2.805 RPS.MWD 2.852 RPM.MWD RPD.MWD 2.884 48.689 1000.000 75.178 2.863 END OF DATA **** FILE TRAILER FILE NAME : EDIT SERVICE : FLIC VERSION : 001C91 DATE : 95/11/ MAX REC SIZE : le24 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earlJes~ passes. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verifica%ion Lis%lng Schlumberger Alaska Cbmpu%ihg Cen%er 6-NOV-1995 14:47 MAD $ MERGED DATA SOURCE LDWG TOOL CODE 5343.0 5576.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE $ REMARKS: The MAD da%a was ob%ained on Bi% Run #3 from 5343' %o 5576'. The da~a was dep%h shifted %o %he CBT GR run on 8-SEP-95 by SWS. LIS FORMAT DATA PAGE: DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 36 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 00 000 00 0 2 1 1 4 68 0000900000 ROP MAD F/HR 99 990 99 9 2 1 1 4 68 0999999999 FET MAD HR 99 990 99 9 2 1 1 4 68 0999999999 GR MAD GAPI 00 900 09 9 2 1 1 4 68 9909999090 RPXX MAD OHMM 99 999 99 9 2 1 1 4 68 0999999090 RPX MAD OHMM 00 909 09 0 2 1 1 4 68 0999999099 RPS MAD OHMM 00 909 09 0 2 1 1 4 68 0999999099 RPM MAD OHMM 99 909 99 9 2 1 1 4 68 0990999999 LIS Tape Verification List|ng Schlumberger Alaska CbmputiHg Center 6-NOV-~995 ~4:47 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RPD MAD OHMM 00 000 0¢ 0 2 1 1 4 68 0000000000 ** DATA DEPT. 5345.500 ROP.MAD 180.000 FET.MAD 0.000 GR.MAD RPXX.MAD 81,772 RPX.MAD 100.769 RPS,MAD 19,534 RPM,MAD RPD.MAD ~.4~6 DEPT. 5576.000 ROP.MAD 180.000 FET.MAD ~.506 GR.MAD RPXX.MAD 2.433 RPX,MAD 2,4Z9 RPS,MAD 2.427 RPM,MAD RPD.MAD 2.457 6.990 10.477 80.067 2.446 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .0~2 SERVICE : FLIC VERSION : 001C0~ DATE : 95/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 · DATE : 95/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED MAD PASSES Depth shifted and clipped curves; for each pass of each run in separate files. MAD RUN NUMBER: 3 MAD Pass NUMBER: ~ DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Cbmputing Center 6-NOV-~995 14:47 PAGE: MAD 5343.e 5576.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) E~UIVALENT UNSHIFTED DEPTH BASELINE DEPTH MAD 88888.0 6767.0 6732.5 6655.5 6508.5 6~77.0 100.0 $ 88891.0 6770 0 6735 0 6657 5 6510 0 6079 e le2 0 REMARKS: The MAD pass data was obtained on Bit Run #3 from 5345~ to 5576~. The data was depth shifted to SWS CBT run 08-SEP-95. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 2 66 0 3 73 36 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 14 65 FT 15 66 68 16 66 0 66 1 LIS Tape Verifica%ion Lis%ing Schlumberger Alaska Compu~i.g Cen~er ** SET TYPE - CHAN ** 6-NOV-1995 14:47 PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 00 000 00 0 3 1 1 4 68 0~00000000 ROP MAD F/HR 00 000 00 0 3 1 1 4 68 oeoe000000 FET MAD HR 00 000 00 0 3 1 1 4 68 0000000000 GR MAD GAPI 00 000 00 0 3 1 I 4 68 000000~000 RPXX MAD OHMM 00 000 00 0 3 1 ~ 4 68 0000000000 RPX MAD OHMM eO 000 00 0 3 1 [ 4 68 0000e00000 RPS MAD OHMM ~e 000 00 0 3 1 1 4 68 0000000000 RPM MAD OHMM Oe e00 00 0 3 1 ~ 4 68 0000000000 RPD MAD OHMM 00 000 Oe 0 3 1 ~ 4 68 0000000000 ** DATA ** DEPT. 5345.5~0 ROP.MAD ~80.0e0 FET.MAD 0.000 GR.MAD RPXX.MAD 81.772 RPX.MAD 100.769 RPS.MAD 19.534 RPM.MAD RPD.MAD 11.416 6.990 10.477 ** END OF DATA **** FILE TRAILER FILE NAME : EDIT .003 SERVICE : FLIC VERSION : DATE : 95/~1/ 6 MAX REC SIZE : ~024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : ~O1C~ DATE : 95/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW MWD Curves and log header da%a for each bi% run in separa%e files. BIT RUN NUMBER: 1 LIS Tape Verification Listing Schlumberger Alaska Computihg Center 6-NOV-1995 14:47 PAGE: DEPTH INCREMENT: 0.5090 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ARC5 $ LOG HEADER DATA 4173.9 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 4465.9 31-AUG-95 5.5C 5.5C MEMORY 4465.9 4173.9 4465.9 75 34.7 35.8 TOOL NUMBER ARC5 RESISTIVITY ARC5 ENP995 ARC5 RESISTIVITY NMDC 4359 ARC5 RESISTIVITY UBHO 931-A5 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (~T): MUD AT MAX CIRCULATIONG TEMPERATURE MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 6.759 4296.9 GEL POLYMER 8.6 35.9 29999 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-1995 14:47 REMARKS: BIT RUN #1 4173' TO 4465'. GR TO BIT: 46.66'; RES. TO BIT: 41,72' BIT RUN #2 4385' TO 56~9' GR TO BIT: 36.66'; RES. TO BIT: 31,72' BIT RUN #3 5343' TO 7313'; MAD PASS 5343' TO 5609' GR TO BIT: 46,66'; RES. TO BIT: 41.72' IDEAL 40BO3/SPM 40BOS/TS40B16/DH40B09 $ LIS FORMAT DATA PAGE: DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 2 66 0 3 73 36 4 66 255 5 66 6 73 7 65 $ 68 0.5 9 65 FT 13 66 0 14 65 FT 15 66 68 16 66 1 ~ 66 1 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 00 000 00 0 4 1 1 4 68 00000000~0 ROP LW1 F/HR 00 000 0~ 0 4 1 1 4 68 0000000~90 FET LW~ HR 90 090 09 9 4 1 1 4 68 09990090~9 GR LW1 GAPI 00 009 00 9 4 1 1 4 68 0090909900 RPXX LWl OHMM 00 000 09 0 4 1 I 4 68 9000099999 RPX LW1 OHMM 00 090 00 9 4 1 1 4 68 9090900990 RPS LW1 OHMM 90 0~9 ~0 9 4 1 1 4 68 999909990e RPM LWI OHMM 90 000 90 0 4 1 I 4 68 9009099099 RPD LW1 OHMM 00 000 99 9 4 I I 4 68 0000900009 LIS Tape Verifica%ion Lis%lng Schlumberger Alaska Computing Cen~er DATA ** DEPT. 4176.090 ROP.LWl RPXX.LW1 1999.999 RPX.LW1 RPD.LW1 1999.999 DEPT. 4465.999 ROP.LW1 RPXX.LW1 3.496 RPX.LW1 RPD.LW1 3.569 END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .994 SERVICE : FLIC VERSION : 991C91 DATE : 95/11/ 6 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .095 SERVICE : FLIC VERSION : 991C01 DATE : 95/11/ 6 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : 6-NOV-1995 i4:47 189.999 FET.LW1 19.492 1999.999 RPS.LW1 1999.999 99.999 FET.LW1 3.471 RPS.LW1 9.739 3.546 GR.LW1 RPM.LW1 GR.LWl RPM.LWi PAGE: 11 51.167 1999.999 198.493 3.612 FILE HEADER FILE NUMBER 5 RAW MWD Curves and log header da%a for each bi% run in separa%e files, BIT RUN NUMBER: 2 DEPTH INCREMENT: 0.509~ FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ARC5 4385.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 5699.0 1-SEP-95 5.5C 5.5C LIS Tape Verification Listing Schlumberger Alaska COmputing Center 6-NOV-~995 ~4:47 PAGE: 12 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: MEMORY 5609.0 4385.~ 5609.0 80 30.3 35.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ARC5 RESISTIVITY ARC5 ENP005 ARC5 RESISTIVITY NMDC 4350 ARC5 RESISTIVITY UBHO 031-A5 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 6.7S0 4206.0 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 CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): GEL POLYMER 8.7 36.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) EWR FREQUENCY (HZ) 2~0~0 REMARKS.: BIT RUN #1 4173~ TO 4465~ GR TO BIT: 46.66~; RES. TO BIT: 41.72~ BIT RUN #2 4355~ TO 5609~ GR TO BIT: 36.66~; RES. TO BIT: 31.72~ BIT RUN #3 5343~ TO 73~3~; MAD PASS 5343~ TO 5609~ GR TO BIT: 46.66~; RES. TO BIT: 41.72~ IDEAL 40BO3/SPM 40BOS/TS40B16/DH40B09 $ LIS FORMAT DATA LIS Tape Veri{ica%ion Lis%ing Schlumberger Alaska Computing Cen~er 6-NOV-1995 14:47 PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT ROP LW2 F/HR FET LW2 HR GR LW2 GAPI RPXX LW2 OHMM RPX LW2 OHMM · RPS LW2 OHMM RPM LW2 OHMM RPD LW2 OHMM 00 000 00 0 5 I 1 4 Oe 000 00 0 5 1 1 4 00 e00 eO 0 5 1 1 4 00 000 00 0 5 I I 4 00 000 00 0 5 1 1 4 00 ~ 0~ ~ 5 1 1 4 00 000 00 0 5 1 1 4 0~ 000 ~0 0 5 1 1 4 00 000 00 0 5 1 1 4 DATA DEPT. RPXX.LW2 RPD.LW2 DEPT. RPXX.LW2 RPD.LW2 4385.500 1000.000 1.000 5609.000 2.818 3.182 ROP.LW2 RPX.LW2 ROP.LW2 RPX.LW2 180.000 FET.LW2 0.415 RPS.LW2 90.00~ FET.LW2 2.946 RPS.LW2 0.000 GR.LW2 0.300 RPM.LW2 0.408 GR.LW2 3.034 RPM.LW2 5.126 0.500 77.353 3.101 LIS Tape Verif|cat|on Listing Schlumberger Alaska Ccmputi~g Center 6-NOV-1995 14:47 PAGE: 14 END OF DATA **** FILE TRAILER FILE NAME : EDIT .005 SERVICE : FLIC VERSION : ~O1CO1 DATE : gs/ll/ 6 MAX REC SIZE : ~24 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .~06 SERVICE : FLIC VERSION : DATE : 95/~/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RaW MWD Curves and log header data for each b|t run in separate Giles. BIT RUN NUMBER: 3 DEPTH INCREMENT: 0.5~0~ FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ARC5 $ LOG HEADER DATA 5576.0 7313.0 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: 3-SEP-95 5.56 5.56 MEMORY 73~3.0 5576.0 73~3.0 90 30.3 3:1.. 7 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-J995 [4:47 PAGE: '15 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ARC5 RESISTIVITY GR ENP005 ARC5 RESISTIVITY NMDC 4350 ARC5 RESISTIVITY UBHO 05'1-A5 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 6.750 4206.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C$): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): GEL POLYMER 1'1.00 51 .El 9.5 2.17El 74.El 2.Ei2Ei 72.El O.EIEIEI EL.El NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: BIT RUN #! 4173' TO 4465'. GR TO BIT: 46.66'; RES. TO BIT: 41.72' BIT RUN #2 4385' TO 56El9' GR TO BIT: 36.66'; RES. TO BIT: 31.72' BIT RUN #3 5343' TO 7313'; MAD PASS 5343' TO GR TO BIT: 46,66'; RES. TO BIT: 41.72' IDEAL 4ElBEl3/SPM 4ElBElS/TS4ElB16/DH4ElBE19 $ LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 El 2 66 El LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-NOV-1995 14:47 PAGE: 16 TYPE REPR CODE VALUE 3 73 36 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 SET TYPE - CHAN'** NAME SERV UNIT SERVICE API aPI API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT ROP LW3 F/HR FET LW3 HR GE LW3 GAPI RPXX LW3 OHMM RPX LW3 OHMM RPS LW3 OHMM RPM LW3 OHMM RPD LW$ OHMM 00 000 ~0 0 6 I 1 4 00 000 00 0 6 I 1 4 00 000 0~ 0 6 1 1 4 0~ 000 ~0 0 6 1 1 4 00 000 00 0 6 1 1 4 00 000 ~0 0 6 1 1 4 00 000 00 0 6 1 1 4 00 ~0~ ~0 0 6 1 1 4 00 000 ~ 0 6 1 1 4 ** DATA ** · DEPT. 5343.500 RPXX.LW$ 81.772 RPD.LW3 11.416 ROP.LW3 RPX.LW3 180.0~0 FET.LW3 100.769 RPS.LW3 0.000 GR.LW3 19.534 RPM.LW3 6.990 10.477 ** END OF DATA LIS Tape Verification Listing Schlumberger Alaska Comput|r:g Center **,* FILE TRAILER ,-,- FILE NAME : EDIT .006 SERVICE : FLIC VERSION : ~1C01 DATE : 9S/il/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 6-NOV-1995 14:47 PAGE: 17 · ~ FILE HEADER ~ FILE NAME : EDIT .0~7 SERVICE : FLIC VERSION : ~01C01 DATE : 95/11/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER T RAW MAD Curves and log header data ~or each pass MAD RUN NUMBER: 3 MAD PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MAD $ LOG HEADER DATA 5343.0 5576.0 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 1-SEP-95 5.5C 5.5C MEMORY 7313.~ 5343.0 5576.0 80 30.3 31.7 TOOL NUMBER ARC5 RESISTIVITY ARC5 ENPOe5 ARC5 RESISTIVITY NMDC 4350 LIS Tape Verification Listing Schlumber9er Alaska Computi~g Center 6-NOV-1995 14:47 PAGE: ARCS RESISTIVITY $ UBHO ~31-A5 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 6.75 4206.0 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 CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): GEL POLYMER 11.0~ S1.0 9.5 2. 170 2. 020 74.0 72 .ID NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: BIT RUN #1 4173' TO 4465'. GR TO BIT: 46.66'; RES. TO BIT: 41.72' BIT RUN #2 4385~ TO 5609~ GR TO BIT: 36.66'; RES. TO BIT: 31.72' BIT RUN #3 5343~ TO 7313~; MAD PASS 5343' TO 5609~ GR TO BIT: 46.66'; RES. TO BIT: 41.72' IDEAL 40BO3/SPM 40BeS/TS40B16/DH40B09 $ # LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 2 66 3 73 4 66 5 66 6 73 7 65 0 0 36 255 LIS Tape Verification Listing Schlumberger Alaska Computimg Center 6-NOV-1995 14:47 PAGE: TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 0 66 1 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 09 999 99 9 7 1 1 4 68 9999999999 ROP MAD F/HR 99 999 99 9 7 1 1 4 68 9999999999 FET MAD HR 99 999 99 9 7 1 1 4 68 9999999990 GE MAD GAPI 99 999 99 9 7 1 1 4 6e 9999999990 RPXX MAD OHMM 99 999 99 9 7 1 I 4 68 9999e99999 RPX MAD OHMM 99 999 99 9 7 1 1 4 68 9999999999 RPS MAD OHMM 99 999 99 9 7 1 1 4 68 9999999999 RPM MAD OHMM 99 999 99 9 7 1 1 4 68 9999999990 RPD MAD OHMM 99 999 99 9 7 1 1 4 68 999999~999 DATA DEPT. 5345.599 ROP.MAD 180.e09 FET.MAD 9.990 GR.MAD RPXX,MAD 81,772 RPX,MAD le0,769 RPS.MAD 19.534 RPM.MAD RPD,MAD 11.416 DEPT. 5576.999 ROP.MAD 180.~00 FET.MAD 9.596 GR.MAD RPXX.MAD 2.433 RPX.MAD 2.419 RPS.MAD 2.427 RPM.MAD RPD.MAD 2.457 6.990 10.477 80.967 2.446 END OF DATA **** FILE TRAILER FILE NAME : EDIT .907 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/ 6 MAX EEC SIZE : 1924 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computiffg Center 6-NOV-1995 14:47 PAGE: 20 **** TAPE TRAILER SERVICE NAME : EDIT DATE : 95/1~/ 6 ORIGIN : FLIC TAPE NAME : 95324 CONTINUATION # : ! PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK 1~-24, AP1 #50-029-22584-00 **~ REEL TRAILER SERVICE NAME : EDIT DATE : 9S/~1/ 6 ORIGIN : FLIC REEL NAME : 95324 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK ~-24, AP1 #50-029-22584-00
