Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
181-071
1 Regg, James B (OGC) From:NSK DHD Field Supervisor <n2238@conocophillips.com> Sent:Friday, July 14, 2023 12:08 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:Well Integrity Specialist CPF1 & CPF3 Subject:CPAI 10-426 form for Non-witnessed shut in tests on 1A-02 and 05 on 7/13/23 Attachments:MIT KRU 1A-02 & 05 SI TESTS 07-13-23.xlsx Please see the attached 10‐426 form for Non‐witnessed shut in MIT‐IA’s that were performed at 1A pad on 7/13/23. Please let me know if you have any questions or concerns. Thank you, Shelby Sumrall / Bruce Richwine DHD Field Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659‐7022 Cell phone: (907) 943‐0167 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. KRU 1A-02PTD 1810710 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1810710 Type Inj N Tubing 2817 2820 2820 2820 Type Test P Packer TVD 5835 BBL Pump 1.2 IA 1180 1810 1770 1760 Interval 4 Test psi 1500 BBL Return 1.2 OA 506 510 510 510 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1811040 Type Inj N Tubing 2840 2855 2850 2850 Type Test P Packer TVD 5920 BBL Pump 5.4 IA 415 3500 3440 3430 Interval V Test psi 3000 BBL Return 5.4 OA 36 40 40 40 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 / 1A Pad Hembree / Hills 07/13/23 Notes: Notes: 1A-02 1A-05 Notes:MITIA to maximum anticipated injection pressure per AIO 2C.083 Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2023-0713_MIT_KRU_1A-02 J. Regg; 10/12/2023 MEMORANDUM State of Alaska Alaska Oil and Cas Conservation Commission To: Jim Regg DATE: Wednesday, September 11, 2019 P.I. Supervisor q ilt'q SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. IA -02 FROM: Austin McLeod KUPARUK RIV UNIT IA -02 Petroleum Inspector Ste: Inspector Reviewed P.I. Supry �LhIZ NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IA -02 Insp Num: mitSAM190908140708 Rel Insp Num: Well IA -02 ITYpe PTD 1810710 Type BBL Pumped: 1.1 Interval avRrsr Notes: MIT -IA API Well Number 50-029-20599-00-00 Inspector Name: Austin Mcleod Permit Number: 181-071-0 Inspection Date: 9/8/2019 - Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Inj c .� 5836 ':Tubing 3115 - 3126 3127 Test sPT T tse lsls soo IA 880 zoos - 920— BBL Returned: I OA sn m 577 P/F P .i Wednesday, September 11, 2019 Page 1 of I vttl-o-t\ WELL LOG TRANSMITTAL#902902560 ryp7p LOGGED .. d E/20NDER1 G, To: Alaska Oil and Gas Conservation Comm. January 15, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 JAN 2 0 2015 AOGCC RE: Injection Profile : 1A-02 Run Date: 11/10/2015 The technical data listed below is being submitted herewith. Please address any problems or • concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1A-02 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20599-00 Injection Profile Log 1 Color Log 50-029-20599-00 SCANNED � 1h, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ,,aiza fto ,, • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,October 28,2015 TO: Jim Regg P.I.SupervisorC} 11(3(1 S SUBJECT: Mechanical Integrity Tests 4 CONOCOPHILLIPS ALASKA INC 1A-02 FROM: Jeff Jones KUPARUK RIV UNIT 1A-02 Petroleum Inspector �� �% 0 t1 4J 1tY Src: Inspector Reviewed By: P.I.Supry-.Yn NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-02 API Well Number 50-029-20599-00-00 Inspector Name: Jeff Jones Permit Number: 181-071-0 Inspection Date: 10/16/2015 Insp Num: mitJJ151017071535 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well; IA 02 Type Inj W fTVD 5836 ' Tubing 1604 1606 - 1597 - 1598 - 1R1o710 Type Test SPT(Test psis 1500 IA 550 2300 2240 2230 -, PTD � i - — Interval INITAL P/F P '' OA 1 793 788 789 - 791 Notes: 1 well inspected,no exceptions noted. i—2itiv -I 31,-4z`1 Wednesday,October 28,2015 Page 1 of 1 • • Brooks, Phoebe L (DOA) d7T174ticj f 0-1 t 0 From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, October 28, 2015 11:15 AM To: Brooks, Phoebe L (DOA) Subject: RE: Recent MIT's performed at KRU Attachments: 1A-02 schematic.pdf Attached is the current schematic. Let me know if you need anything else. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 206 WELLS TEAM SCpNHV I��AY 1 4ft From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks©alaska.gov] Sent: Wednesday, October 28, 2015 11:03 AM To: NSK Problem Well Supv Subject: [EXTERNAL]RE: Recent MIT's performed at KRU Brent/Kelly, Will you send me the well schematic for KRU 1A-02? We have a packer tvd of 5908' in our database so I wanted to verify. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, October 19, 2015 4:46 PM To: Wallace, Chris D (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: Recent MIT's performed at KRU Attached are the test forms for the recent MIT's that were performed at KRU. Please let me know if you have any questions. 1 , a ilk KUP INJ • IA-02 ConocoPhillips ° Well Attributes Max Angle&MD TD AlaSka,Inc. ,Wellbore AP0lhNI Field Name Wellbore Status Incl(°) MD(RKB) Act Blot(RKB) ,-a geMp / 500292059900 KUPARUK RIVER UNIT INJ - 49.00 7,200.00 8,355.0 .. ... .0 Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date IA-02,9/1720151:13:45 PM SSSV:NONE Last WO: 8/5/2015 39.01 7/2/1981 Ver&al schema&(actual) Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag:ELMD 7,840.0 10/9/2008 Rev Reason_WORKOVER smsmith 9/16/2015 HANGER,28.3 i�_I _ � �- Casing Strings �`yiCasing Description OD(in) ID(in) Top(ORB) Set Depth NOW) Set Depth(TVD)...Wt/Len(I...Grade Top Thread �ll`I CONDUCTOR 16 15.063 39.0 112.0 112.0 65.00 H-40 WELDED '� Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)...WULen(I...Grade Top Thread di SURFACE 103/4 9.797 28.7 2,902.0 2,662.5 45.50 K-55 BUTT I i Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)...WULen(1...Grade Top Thread PRODUCTION 7 6.276 27.9 8,337.0 6534.8 26.00 K-55 Casing Description OD(in) ID(in) Top(RKB) Set Depth(PIKS) Set Depth(TVD)...WtA,en(I...Grade Top Thread CONDUCTOR 39.0.1120 • ,MCL 7"Casing Patch 6.178 5-583 2,990.1 3,046-0 2,760.7 FODC-OR Tubing Strings SURFACE;28.7-2,902.0 ', Tubing Description Sting Me,..10(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)I...Wt(Ib/R9).30 Gnde Top Connection TUBING-WO2015- 31/21 2.992 28.31 7,358.11 5,829.0! 9.30 LA0 !EUE Brd UPPER- J Completion Details I INominal ID Top(RKB) Top(TVD)(RKB) Top Ind(°) Item Des Com (in) MCL 71 Casing Patch;2,990.1- 28.3 28.3 0.00 HANGER FMC GEN IV TUBING HANGER 2.991 3,046.0 7,335.4 5,813.7 47.65 LOCATOR BAKER 80-40 LOCATOR 3.000 7,336.3 5,814.3 47.64 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.980 - Tubing Description String Mn...ID(in) Top(RKB) I Set Depth(fl..Set Depth(TVD)I...Wt(1619) Grade Top Connection GAS LIFT;7,281_1 TUBING-WO 2015- 41/2 2.992 7,344.0 7,759.5I 6,109.1 LA0 TCI! SELECTIVE Completion Details Top(ftKB) TopNominal ID (TVD)(RKe) Top Incl(") Item Des Com 00) LOCATOR;7,3351 7,344.0 5,819.5 47.56 PBR BAKER 8040 PBR 4.000 t 7,367.5 5,835.4 47.32 PACKER BAKER FHL 4762 RETRIEVABLE PACKER 2.940 SEAL ASSY;7,336.3 -,� PBR;7,344.0 7,420.1 5,871.2 46.80 NIPPLE CAMCO DS NIPPLE 2.813 PACKER;73675 7,547.9 5,959.7 45.64 BLAST JTS 3-1/2"EUE X TC II L-80 Blast Joint XO 2.992 7,568.8 ,• 4. 45.48 BLAST JTS 3-1/2'TC II L-80 Blast Joint 2.992 7,695.4 6,063.6 45.01 BLAST JTS 3-1R"TCII X EUE L-80 Blast Joint XO 2.992 7,724.7 6,084.3 44.75 SLEEVE BAKER CMU SLIDING SLEEVE W/BX PROFILE 2.810 ' 7,749.9 6,102.2 44.50 XO Reducing Crossover 3-1 "EUE B x 2-7/8'EUE P 2.970 CUT TUBING;7,424,0 7,751.0 6,103.0 44.49 LOCATOR BAKER 80-32 GBH-22 LOCATOR 2.410 7,752.0 6,103.8 44.48 SEAL ASSY BAKER 80-32 GBH-22 SEAL ASSY 2.410 Tubing Description !String Ma...1113(In) 'Top(RKB) Set Depth(R..I Set Depth(ND)(,•.IWt(m8t) 'Grade lop Connection TUBING-ORIGINAL 2 7/8 2.441 7,753.0 7,782.1 6,125.3 6.50 J-55 EUEBrdABMOD GAS LIFT:7,4725 Completion Details Nominal ID Top(RKB) Top(TVD)(RKB) Top Ind 1°) Item Des Com (in) 7,753.0 6,104.5 44.47 PACKER BAKER PERMANENT PACKER(7734'WLM 3.250 12/21/1986) GAS LIFT;7,530.6, 7,756.6 6,107.1 44.43 SBE XO Baker Seal Bore Extension w/XO 3.5"to 2 7/8" 2.875 4.0 CUT TUBING;7,534.0 7,769.8 8,116.5 44.30 NIPPLE CAMCO 13'NO GO NIPPLE 2.250 ■ 7,779.7 6,123.6 44.20 XO CROSSOVER 2 7/8"TO 3.5' 2.441 7,781.4 6,124.8 44.19 SOS OTIS SHEAROUT SUB/ELMD TTL G7764 during .992 RPERF;7,552.0.7,577.0- I (PROF On 2/11/2008 (PERF;7,552.0-7,591.0 4 III Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Ind Top(RKB) (ftKe) ("I Des Com Run Date ID(in) RPERF;7,601.0-7,828.01 7,424,0 5,873.9 46.76 CUT TUBING CHEM-CUT TBG 7/11/2015 (PERF;7,601-4-],648.0-.- 7,534.0 5,950.0 45.75 CUT TUBING CHEM-CUT TBG 7/10/2015 RPERF;7,652.0.1,6000 7,725.0 6,084.5 44.75 RHC BODY RHC Body with Ball and Rod in place 8/22/2015 IPERF;7,654.0-7,6880-• 7,902.0 6,212.1 42.98 FISH Vann Gun,340.14"long 7/1/1981 0.000 a 7,902.0 6,212.1 42.98 FISH Lock Key from AVA IBP left in hole @ 7902' 10/31/1999 0.000 -' Perforations&Slots IPERF;7,700.0-7,712.0- 0 0 Shot Dens ill Top(NO) Blen(ND) (shasir TOP( B) etrn(ftK6) (RKB) (ftK8) Zone Date t) Type Corn lir 7,552.0 7,577.0 5,962.6 5,980.1 C-4,1A-02 12/23/1986 12.0 RPERF 120 deg.Ph;5"HyperJet RHC 0005;7,725.0 ll SLEEVE;7,724.7 7,552.0 7,591.0 5,962-6 5,989.9 C-4,1A-02 7/1/1981 4.0 IPERF Squeezed&Reperfed; Vann Gun 7,601.0 7,626.0 5,997.0 6,014.6 C-3,1A-02 12/23/1986 12.0 RPERF 120 deg.Ph;5'HyperJet LOCATOR;7,751.0 ' II Alt7,601.0 7,646.0 5,997.0 6,030.1 C4,C-3,IA- 7/1/1981 4.0 IPERF Squeezed&Reperfed; PACKER;7,753-41 .,. 02 Vann Gun SEA.ASSY;7,752.0 SSE 20;7,756.6 la 7,652.0 7,652.0 7,688.0 6,032.9 6,058.3 C-2,1A-02 12/23/1986 12.0 RPERF 120 deg.Ph;5"HyperJet II ti- 7,654.0 7,688.0 6,034.3 6,058.3 C-2,1A-02 7/1/1981 4.0 IPERF Squeezed&Reperfed; NIPPLE;7,769-4 ENVann Gun 7,700.0 7,712-0 6,066.8 6,075.3 C-1,UNIT B, 7/1/1981 4.0 IPERF Squeezed&Reperfed; 00;7,779.7 f+l 1A-02 Vann Gun 508;7,751.4 elk 7,796.0 7,850.0 6,135.3 6,174.3 A-5,A-4,1A- 7/1/1981 4.0 IPERF 120 deg.Ph;Vann Gun 02 IPERF;7.798.0.7,050.0--..- Cement Squeezes Top(NO) then(TVD) Top OMB) Otto(RICER (RKB) (ft18) Des Start Date Com FISH;7,902.0 7,552.0 7,591.0 5,962.6 5,989.9 Cement SQZ 7/1/1981 Reperfed 7601-7626 on 23/23/86(WO) FISH;7,902-4 7,601.0 7,648.0 5,997.0 6,030.1 Cement SQZ 7/1/1981 Reperfed 7601-7626 on 23/23/86(WO) 7,654.0 7,654.0 6,034.3 6,034.3 Cement SQZ 7/1/1981 Reperfed 7601-7626 on 23/23/86(WO) I 7,700.01 7,712.0 6,066.8 6,075.3 Cement SQZ 7/1/1981 Reperfed 7601-7626 on 23/23/86(VVO) PRODUCTION;27.9-5,337,0-- p ilk KUP INJ • 1A-02 ✓ ConocoPhillips Alaska,Inc. ca nooPttlufs 1A-02,911 71201 5 1:1347 PM Vertical schematic(actual) HANGER;283 g II( F Mandrel Inserts St ati on Top(TOO) Valve LAWS Port Size TRO Run N Top(ftKEN (ftKB) Make Model 00(in) Sem Type Type (in) (psi) Run Date Com r,. 1 7,281.1 5,777.3 CAMCO KBG-2- 1 GAS LIFT SOV INT 1.000 2,000.0 8/24/2015 'DCK3 9 2 7,472.5 5,907.2 CAMCO KBMG 1 GAS LIFT DMY BKS 0.000 0.0 8/22/2015 '7`~^CONDUCT0R:39.an2.0 ¢ 3 7,5307 5,947.7-CAMCO KBMG 1 GAS LIFT OMY BK-5 0.000 0.0 8/22/2015 l. Notes:General&Safety SURFACE;28.7-2,902.0E 5. End Date Annotation 8/31/2005 NOTE:TUBING LEAK FOUND w/PONYTAIL @ 7739' 8/14/2006 NOTE:IA leak @ 3025'plugged with Sealtite Flo-Seal Sealant 8/29/2006 NOTE:WAIVERED WELL-IA x FORMATION MCL r Casing Peen;2,999.1- 8/18/2008 NOTE:VIEW SCHEMATIC w/ALaska Schematic9.0 3,046.0 2/1/2009 NOTE:LEAK FOUND @ 3030'ON TECWELL LDL 12/30/2013 NOTE:CASING LEAK AT 3030'RKB GAS LIFT:7,281.1 LOCATOR;7,335.4 il SEAL ASSY;7,338.3 PBR;7,344.0 PACKER;7,367.5 l CUT TUBING;7,424.0 GAS LIFT;7,472.5 GAS LIFT;7,530.61 CUT TUBING:7,534.0 RPERF;7,552.0-7,577.0-_ (PERT;7,552.0-7,591.0 Y. II RPERF;7,601.0-7,628.0.` I (PERF;7,807.0-7,848.0—�—.RPERF;7,652.0-7,688 0 I (PERF;7,854.0-7,688.0 I (PERF;1,700.0-1712.0 KI RNC BODY;7,725.0 •IL SLEEVE;7,724.7 ITf LOCATOR;7,751.0 a PACKER;7,753.0., SEAL ASSY;7,752.0 SSE SO;7,756.6 Zs'.e. NIPPLE;7,7699.9 II II 1111 XO;7,779.7 1-; SOS;7,761.4 i /PERF;7,796.0-7,a50A----- I FISH;7,902.0 FISH;7,902.0 PRODUCTION;27.9-8,337.0 • • 2G3-61 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 15, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED wikv2o15 Anchorage, Alaska 99501 M.K.BENDER RECEIVED RE: Multi Finger Caliper(MFC) : 1A-02 o Run Date: 8/21/2015 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1A-02 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20599-00 z1 L'A SCOW PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: vCtg__.J7,�c,,, .___ta"a STATE OF ALASKA ALL OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing 17 Operations Shutdown fl Performed: Suspend f Perforate f Other Stimulate r/ vc Alter Casing F Change Approved Program Rug for Redrill r Perforate New Pool r Repair Well Re-enter Susp Well f' Other: Casing Patch (✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory E 181-071 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-20599-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25647 KRU 1A-02 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: RECEIVED Total Depth measured 8355 feet Plugs(measured) none true vertical 6548 feet Junk(measured) none SEP 2 2 2015 Effective Depth measured 8242 feet Packer(measured) 7368, 7753 d'10�L.�� true vertical 6464 feet (true vertical) 5836, 6104 Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 112 112 SURFACE 2873 10.75 2902 2663 PRODUCTION 8309 7" 8337 6535 SCANNED NOV 1 6 2015 Perforation depth: Measured depth: 7416-7426, 7526-7536, 7552-7591, 7601-7648, 7652-7688,7700-7712, 7796-7850 True Vertical Depth: 5868-5875, 5944-5951, 5963-5990, 5997-6030,6033-6058,6067-6075, 6135-6174 Tubing(size,grade,MD,and TVD) 3.5",J-55, 7750' MD/6102'TVD and 2.875",J-55, 7750-7783 MD/6102'-6126'TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER FHL PACKER @ 7368 MD and 5836 TVD PACKER-BAKER DB PERMANENT PACKER @ 7753 MD and 6104 TVD NO SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation 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 shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 17 Exploratory fl Development r Service P Stratigraphic Copies of Logs and Surveys Run r 16.Well Status after work: Oil Gas r WDSPL fl Printed and Bectronic Fracture Stimulation Data r GSTOR f WINJ r WAG F GINJ r SUSP I— SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-429 Contact Danny Kane a 265-6048 Email Danny.Kaneconocophillips.com Printed Name Danny Kane Title Sr. Wells Engineer Signature — Phone:265-6048 Date t �� 21– EP–ZetSfS k `, yr-L. 4/Z 1/yam RBDMS Qk SEP 2 5 2015 ,/ '00..� Form 10-404 Revised 5/2015 Submit Original Only KUP INJ • 1A-02 ConocoPilillips .; well Attributes Max Angle&MD TO Alaska.(fio 0. itakkkOl Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) T.,romuu,pstiq' 500292059900 KUPARUK RIVER UNIT INJ 49.00 7,200.00 8,355.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1A-02,9/17/20151:1345 PM SSSV:NONE Last WO: 8/5/2015 39.01 7/2/1981 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date - ----- ---- - - Last Tag.ELMD 7,840.0 10/9/2008 Rev Reason:WORKOVER smsmith 9/16/2015 II j HANGER;28.3 Fr Casing Strings i= Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.063 39.0 112.0 112.0 65.00 H-40 WELDED I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.797 28.7 2,902.0 2,662.5 45.50 K-55 BUTT CONDUCTOR 39.0 IICaning Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I.Gratle Top Thread PRODUCTION 7 6.276 27.9 8,337.0 6,534.8 26.00 K 55 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD).. Wt/Len(I...Grade Top Thread -AAA.-w w wIlia w w w•w 17,7. MCL 7"Casing Patch 6.178 5.583 2,990.1 3,046.0 2,760.7 FODC-OR -112.0 Tubing Strings Tubing Description !String Ma...IID(in) !Top(ftKB) !Set Depth(ft..I Set Depth(ND)(...Wt(Ib/ft) !Grade !Top Connection SURFACE;28.7-2,902.0 TUBING-WO 2015- 31/2 2.992 28.3 7,358.15,829.0 9.30 L-80 EUE 8rd UPPER-3 1/2" Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°)_ Item Des Com (in) MCL]'Casing Patch',2,990.1- 26.3 28.3 0.00 HANGER FMC GEN IV TUBING HANGER 2.991 3,046.0 7,335.4 5,813.7 47.65 LOCATOR BAKER 80-40 LOCATOR 3.000 7,336.3 5,814.3 47.64 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.980 Tubing Description (String Ma...ID(in) Top(ftKB) !Set Depth(ft..l Set Depth(TVD)(...IWt(!blot) !Grade !Top Connection GAS LIFT;7,281.1 11 TUBING-WO 2015- 41/2 2.992 7,344.0 7,759.5 6,109.1 L-80 TCI! SELECTIVE It Completion Details 111 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) LOCATOR;7,3354 7,344.0 5,819.5 47.56 PBR BAKER 80-40 PBR 4.000 7,367.5 5,835.4 47.32 PACKER BAKER FHL 4782 RETRIEVABLE PACKER 2.940 SEAL ASSY;7,336.3 PBR;7,3440 -i 7,420.1 5,871.2 46.80 NIPPLE CAMCO DS NIPPLE 2.813 PACKER;7,367.5 7,547.9 5,959.7 45.64 BLAST JTS 3-1/2"EUE X TC II L-80 Blast Joint XO 2.992 7,568.8 5,974.3 45.48 BLAST JTS 3-1/2"TC II L-80 Blast Joint 2.992 11/ 7,695.4 6,063.6 45.01 BLAST JTS 3-1/2"TCII X EUE L-80 Blast Joint XO 2.992 ill 7,724.7 6,084.3 44.75 SLEEVE BAKER CMU SLIDING SLEEVE W/BX PROFILE 2.810 7,749.9 6,102.2 44.50 XO Reducing Crossover3-1/2"EUE B x 2-7/8"EUE P 2.970 CUT TUBING,7,424.0 7,751.0 6,103.0 44.49 LOCATOR BAKER 80-32 GBH-22 LOCATOR 2.410 7,752.0 6,103.8 44.48 SEAL ASSY BAKER 80-32 GBH-22 SEAL ASSY 2.410 • Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(TVD)(...Wt(10/ft) Grade Top Connection TUBING-ORIGINAL 2 7/8 2A41 7,753.0 7,782 1 6,125.3 6.50 J-55 EUE8rdABMOD GAS LIFT,7,472.5 Completion Details aS Nominal ID III Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) ill 7,753.0 6,104.5 44.47 PACKER BAKER PERMANENT PACKER(7734'WLM 3.250 12/21/1986) GAS NG;7,534 0 LIFT,7,530.61 CUT TUBING, 7,756.6 6,107.1 44.43 SBE XO Baker Seal Bore Extension w/XO 3.5"to 2 7/8" 2.875 RPERF,75520-7,5770mg 7,769.8 6,116.5 44.30 NIPPLE CAMCOPRQFOn'D2/1'NO1/2006 GO NIPPLE 2.250 rl 7,779.7 6,123.6 44.20 XO CROSSOVER27/8"TO3.5" 2.441 7,781.4 6,124.8 44.19 SOS OTIS SHEAROUT SUB/ELMD TTL @ 7764 during 2.992 ��� �. !PERF;7,552.0-7,591.0 Othen Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) Des Com Run Date ID(in) RPERF;7,601.0-76480* 7,424.0 5,873.9 4g.)76 CUT TUBING CHEM-CUT TBG 7/1112015 !PERF;],601.0-7,646.0 7,534.0 5,950.0 45.75 CUT TUBING CHEM-CUT TBG 7/10/2015 7,725.0 6,084.5 44.75 RHC BODY RHC Body with Ball and Rod in place 8/22/2015 RPERF;],652.0-7,688.0 !PERF;7,654 0-7688 oL 7,902.0 6,212.1 42.98 FISH Vann Gun,340.14"long 7/1/1981 0.000 rs 7,902.0 6,2121 42.98 FISH Lock Key from AVA IBP left in hole @ 7902' 10/31/1999 0.000 • Perforations&Slots IPERF;7,700.0-7,712.0_] E Shot Dens ® Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,552.0 7,577.0 5,962.6 5,980.1 C-4,1A-02 12/23/1986 12.0 RPERF 120 deg.Ph;5"HyperJet RHC BODY;7,725.0r� II SLEEVE;7,724.7 7,552.0 7,591.0 5,962.6 5,989.9 C-4,1A-02 7/1/1981 4.0 IPERF Squeezed 8 Reperfed; Vann Gun 7,601.0 7,626.0 5,997.0 6,014.6 C-3,1A-02 12/23/1986 12.0 RPERF 120 deg.Ph;5"HyperJet LOCATOR',7,751.0 M II 7,601.0 7,648.0 5,997.0 6,030.1 C4,C-3,1A- 7/1/1981 4.0 IPERF Squeezed 8 Reperfed; PACKER;7,753 0' 02 Vann Gun SEAL ASSY,7,752.0 SBE SO;7756.6 • 7,652.0 7,688.0 6,032.9 6,058.3 C-2,1A-02 12/23/1986 12.0 RPERF 120 deg.Ph;5"HyperJet iizi II 7,654.0 7,688.0 6,034.3 6,058.3 C-2,1A-02 7/1/1981 4.0 IPERF Squeezed 8 Reperfed; NIPPLE;7,769.8 Vann Gun 7,700.0 7,712.0 6,066.8 6,075.3 C-1,UNIT B, 7/1/1981 4.0 IPERF Squeezed 8 Reperfed, xo;7,7797 + 1A-02 Vann Gun SOS, 7814la 7,796.0 7,850.0 6,135.3 6,174.3 A-5,A-4,1A- 7/1/1981 4.0 IPERF 120 deg.Ph;Vann Gun 02 IPERF;7,796.0-78500-_ Cement,Squeezes Top(ND) Btm(ND) Top(ftKB) Stem(ftKB) (ftKB) (ftKB) Des Start Date Com FISH;7,902.0 7,552.0 7,591.0 5,962.6 5,989.9 Cement SQZ 7/1/1981 Reperfed 7601-7626 on 23/23/86(WO) FISH;7,902.0 7,601.0 7,648.0 5,997.0 6,030.1 Cement SQZ 7/1/1981 Reperfed 7601-7626 on 23/23/86(WO) 7,654.0 7,654.0 6,034.3 6,034.3 Cement SQZ 7/1/1981 Reperfed 7601-7626 on 23/23/86(WO) 7,700.0 7,712.0 6,066.8 6,075.3 Cement SQZ 7/1/1981 Reperfed 7601-7626 on 23/23/86(WO) PRODUCTION;27.9-6,337.0-, KUP INJ • 1A-02 ConocoPhillips Alaska.Inc. 1A-02,9/17/2015 1:1147 PM Verkcal schematic(actual) HANGER;28.3 i tT° 1 Mandrel Inserts "k Sl ati # on Top(TVD) Valve Latch Port Size TRO Run ■ R Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 7,281.1 5,777.3 CAMCO KBG-2- 1 GAS LIFT SOV INT 1.000 2,000.0 8/24/2015 DCK3 9 2 7,472.5 5,907.2 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 8/22/2015 -A-A-A w N U w w w M t `� 3 7,530.7 5,947.7 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 8/22/2015 wwww CONDUCTOR;a9.0.1120� , Notes:General&Safety SURFACE',28.7-2,902.0- S End Date Annotation 8/31/2005 NOTE:TUBING LEAK FOUND w/PONYTAIL @ 7739' 8/14/2006 NOTE:IA leak @ 3025'plugged with Sealtite Flo-Seal Sealant 8/29/2006 NOTE:WAIVERED WELL-IA x FORMATION MCL 7 Cas/ng Patch;2,990.1- 8/18/2008 NOTE:VIEW SCHEMATIC w/ALaska Schematic9.0 3046.0 2/1/2009 NOTE:LEAK FOUND @ 3030'ON TECWELL LDL 12/30/2013 NOTE:CASING LEAK AT 3030'RKB GAS LIFT;7,281.1 4. LOCATOR;7,335.4 'A SEAL ASSY;7,336.3 PER;7,344 0 PACKER;7,367.5 X CUT TUBING',7,424.0 N a GAS LIFT;7,472.5 a a a GAS LIFT,7,530.61 CUT TUBING,7534.0 a RPERF;7,552.0-7577.0 IPERF;7,5520-7591.0-] RPERF;7 601 0-7,626.0 L_. IPERF;7601.0-7,648.0--.] RPERF;],652.0-7,668.0 IPERF;7,654.0-7688.0A___:-... IIPERF,7,700.0-7,712.0_____jgLt RHC BODY;7,725 0 SLEEVE 7,724.7 V LOCATOR;7,751.0IP PACKER;7,753.01 SEAL ASSY;7,752 0 SBE 80;7756.6 • I NIPPLE;7,769.8 I 80;7,779.7 SOS;7,781A -.. . IPERF;7,796.0-7,850.0 FISH;7,902.0 FISH;7,902.0 PRODUCTION;27.9-8,337.0, 1-02 WELL WORK SUMMARY • • DATE SUMMARY PRE-RIG WELL WORK 2/20/2015 (PRE-RWO): FUNCTION TESTED ALL LDS'S AND GN'S (ALL FUNCTIONED), T-POT(PASSED), T-PPPOT (PASSED), IC-POT (PASSED), IC-PPPOT (PASSED), OC-POT (PASSED), OC-PPPOT (FAILED), SCLD WITH N2 TO 1000 PSI (PASSED). 2/21/2015 (PRE-RWO) OC POT- PASSED; OC PPPOT- PASSED; RE-TORQUED OC LDS 7/8/2015 RAN FLAPPER CHECKER TO SSSV @ 1813' RKB TO CONFIRM FULLY OPEN. EQUALIZED WRP @ 7503' RKB. AFTER PULLING WRP FROM SET DEPTH @ 7503' RKB, WRP BECAME STUCK IN SBR @ 7447' RKB. PULLING TOOL SHEARED AFTER 45 MIN OF HEAVY JARRING. WILL RESUME TOMORROW. *JOB IN PROGRESS 7/9/2015 PULLED WRP FROM SBR @ —7447' RKB. PULLED CV FROM ST#11 @ 7509' RKB AND DMY VLV FROM ST#10 @ 7400' RKB, PERFORMED SBHPS @ 7614' RKB (6006'TVD) FOR 30 MIN 2445.5 psia, 138.3*F), PERFORMED GRADIENT STOP @7471' RKB (5906'TVD) FOR 15 MIN 2385.8 psia, 141.3*F) *JOB IN PROGRESS 7/10/2015 PULLED CATCHER @ 7682' SLM (*RECOVERED MISSING PIECE FROM WRP ELEMENT). FIRED 10' STRING SHOT © INTERVAL 7526'-7536' RKB AND 10' STRING SHOT @ INTERVAL 7416'-7426' RKB. CUT TUBING W/2 5/8" CHEM CUTTER © 7534' RKB. *JOB IN PROGRESS 7/11/2015 CUT TBG W/2 5/8" CHEM CUTTER © 7424' RKB. PERFORMED REQUIRED RUNS TO PERMANENTLY LOCK-OUT SSSV @ 1813' RKB. *JOB COMPLETE *SEVERING HEAD PARTIALLY WASHED OUT ON ONE SIDE AFTER FIRING (SEE TIMELOG FOR DETAILED DESCRIPTION) POST-RIG WELL WORK 9/3/2015 ATTEMPTED SET BAITED PULLING TOOL IN 2.70" BELL GUIDE ON BALL & ROD; UNABLE TO PASS GLM# 1 @ 7281' RKB. IN PROGRESS. 9/5/2015 BAILED PUTTY TYPE MATERAL & SAND FROM 7685'TO 7688' SLM. SET 2.75'AVA CATCHER @ 7688' SLM. PULLED SOV FROM 7281' RKB, SET DV @ SAME. MITT 2500 PSI, PASSED. MITIA 3000 PSI, PASSED. PULLED CATCHER. PULLED B&R FROM 7688' SLM. PULLED RHC PLUG BODY FROM 7725' RKB. COMPLETE. �► i Cono►cohillips Time Log & Summary NJellview Web Reporting Report Well Name: 1A-02 Rig Name: NABORS 9ES Job Type: RECOMPLETION Rig Accept: 8/14/2015 5:00:00 PM Rig Release: 8/26/2015 5:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 38/05/2015 24 hr Summary Continue to standby for operational supplies to be delivered to various operations that would be effected by the rig move. An operational decision was made to discontinue the move of to 1C-08 and move to 1A-02. Jacked up the sub, moved the sub-1 mile down the Oliktok road and the rear tires sunk into the road. Set the sub down, placed dunnage under the rear tires, laid plywood in front of the rear tires, laid mats in front of the sub in order to pull the sub onto mats, and rig up two dozers. Pull the sub out and on top of the mats. Lay mats for about 100 yards to the first stretch of rig mats already on the road. 12:00 20:00 8.00 0 0 MIRU MOVE MOB P Continuing to standby for operational supplies to be delivered to various operations that would be effected by the rig move. **Operational decision was made to discontinue the move to 1C-08 and move to 1A-02 as Doyon 25 would not be able to pass by during their rig move to back side of 1C pad, along with poor road conditions possibly causing large in felid delays."" 20:00 20:30 0.50 0 0 MIRU MOVE MOB P Jacked up the sub, moved the sub —1 mile down the Oliktok road and the rear tires sunk into the road. 20:30 23:30 3.00 0 0 MIRU MOVE MOB T Set the sub down, placed dunnage under the rear tires, lay plywood in front of the rear tires, lay mats in front of the sub in order to pull the sub onto mats, and rig up two dozers. Pull the sub out and on top of the mats. 23:30 00:00 0.50 0 0 MIRU MOVE MOB T Lay mats for about 100 yards to the first stretch of rig mats already on the road. 08/06/2015 Moved the sub on mats to 10 shuffling mats and were able to move off mats for the last 0.2 miles to 10 pad access. Moved the sub(not on mats)from 10 Pad access about 1 mile and driller side right front tires sank into the road and set the sub down. Place dunnage under the tires, hook up the dozers, pulled the sub out steering to the high side of the road, and the back off driller side tires sank into the road. Set the sub down. Lay mats in front of the rig and place dunnage under the rear tires. 00:00 01:30 1.50 0 0 MIRU MOVE MOB T Continue to lay mats for about 100 yards to the first stretch of rig mats already on the road. 01:30 12:00 10.50 0 0 MIRU MOVE MOB T Move the sub on mats to 10 shuffling mats and were able to move off mats for the last 0.2 miles to 10 pad access. 12:00 17:00 5.00 0 0 MIRU MOVE WAIT T Pick up mats and haul to Oliktok and Spine, lay mats over known soft road areas. Page 1 of 20 111 Time Logs Date From To Dur S. Depth E. Deoth Phase Code Subcode T Comment 17:00 19:00 2.00 0 0 MIRU MOVE MOB T Move rig from 1Q Pad access about 1 mile and driller side right front tires sank into the road and set the sub down. 19:00 22:00 3.00 0 0 MIRU MOVE MOB T Dig out the road to straighten the tires enough to jack up. Place dunnage under the tires, hook up the dozers, pulled the sub out steering to the high side of the road, and the back off driller side tires sank into the road. Set the sub down. 22:00 00:00 2.00 0 0 MIRU MOVE MOB T Lay mats in front of the rig and place dunnage under the rear tires. 08/07/2015 Continue to lay mats in front of the rig and place dunnage under the rear tires. Attempt to pull onto the mats with dozers,the sub moved about 10 feet and both side rear tires sank into the road. Repeat the process until sub is up on mats. Move the sub on mats towards the drilling tool house shuffling mats. 00:00 16:30 16.50 0 0 MIRU MOVE MOB T Continue to lay mats in front of the rig and place dunnage under the rear tires. Attempt to pull onto the mats with dozers, the sub moved about 10 feet and both side rear tires sank into the road. Repeat the process until sub is up on mats. 16:30 00:00 7.50 0 0 MIRU MOVE MOB T Move the sub on mats towards the drilling tool house shuffling mats. 08/08/2015 Continue to move the sub on mats to the drilling tool house shuffling mats. On standby for north side of the field to re supply and stage equipment. SimOps: Move 2 shops and satellite office to 1A pad. 00:00 21:30 21.50 0 0 MIRU MOVE MOB T Continue to move the sub on mats to the drilling tool house shuffling mats. 21:30 00:00 2.50 0 0 MIRU MOVE WAIT T On standby for north side of the field to re supply and stage equipment. SimOps: Move 2 shops and satellite office to 1A pad. 08/09/2015 On standby for north side of the field to re supply and stage equipment. Move 2 shops and satellite office to 1A pad. Move the sub 0.3 miles from the tool house access road to the KCS warehouse access road on portable mat system. On standby to allow traffic to bypass,to lay out portable mat system and for north side of the field crew change. Move the sub 0.5 miles from the KCS warehouse access road to the Oliktok/Spine road intersection on portable mat system. On standby to lay out mats and to allow traffic to bypass. 00:00 10:30 10.50 0 0 MIRU MOVE WAIT T On standby for north side of the field to re supply and stage equipment. SimOps: Move 2 shops and satellite office to 1A pad. 10:30 16:00 5.50 0 0 MIRU MOVE MOB T Move the sub 0.3 miles from the tool house access road to the KCS warehouse access road on portable mat system. 16:00 20:00 4.00 0 0 MIRU MOVE WAIT T On standby to allow traffic to bypass, to lay out portable mat system and for north side of the field crew change. Page 2 of 20 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 20:30 0.50 0 0 MIRU MOVE MOB T Move the sub 0.5 miles from the KCS warehouse access road to the Oliktok/Spine road intersection on portable mat system. 20:30 00:00 3.50 0 0 MIRU MOVE WAIT T On standby to lay out mats and to allow traffic to bypass. 08/10/2015 On standby to lay out mats and to allow traffic to bypass. Move the sub 0.3 miles from the Oliktok/Spine road intersection to D pit turn out on mats. On standby to lay out mats, lay out portable mat system, lay out plywood, and to allow traffic to bypass. 00:00 03:00 3.00 0 0 MIRU MOVE WAIT T On standby to lay out mats and to allow traffic to bypass. 03:00 03:30 0.50 0 0 MIRU MOVE WAIT T Move the sub 0.3 miles from the Oliktok/Spine road intersection to D pit turn out on mats. 03:30 04:00 0.50 0 0 MIRU MOVE WAIT T On standby to lay out mats and to allow traffic to bypass. 04:00 08:00 4.00 0 0 MIRU MOVE WAIT T On standby for field wide change out. 08:00 16:00 8.00 0 0 MIRU MOVE WAIT T On standby to lay out mats and to allow traffic to bypass. 16:00 19:00 3.00 0 0 MIRU MOVE WAIT T On standby for field wide change out. 19:00 00:00 5.00 0 0 MIRU MOVE WAIT T On standby to lay out portable mat system, lay out plywood, and to allow traffic to bypass. 38/11/2015 On standby to lay out plywood and to allow traffic to bypass. Back the sub out of D pit access road, move mats from D pit access road, and lay out in front of the rig. Move the sub 0.2 miles down the spine road and the rear driller side tires sunk into the road while on portable mats system. Use Caterpillar dozers, dunnage, and sand bags to get the rig up on mats. On standby to repair the road in front and back of the rig. Lay out mats behind the sub and start laying the mats that came from Deadhorse in front of the rig. Move the sub back to D pit access road on mats shuffling as needed. 00:00 02:00 2.00 0 0 MIRU MOVE WAIT T On standby to lay out plywood and to allow traffic to bypass. 02:00 03:30 1.50 0 0 MIRU MOVE MOB T Back the sub out of D pit access road, move mats from D pit access road, and lay out in front of the rig. Move the sub 0.2 miles down the spine road and the rear driller side tires sunk into the road while on portable mats system. 03:30 17:30 14.00 0 0 MIRU MOVE MOB T Use Caterpillar dozers,dunnage, and sand bags to get the rig up on mats. 17:30 19:30 2.00 0 0 MIRU MOVE WAIT T On standby for field crew change. SimOps: Pick up all the dunnage and sand bags. 19:30 22:00 2.50 0 0 MIRU MOVE WAIT T On standby to repair the road in front and back of the rig. Lay out mats behind the sub and start laying the mats that came from Deadhorse in front of the rig. 22:00 00:00 2.00 0 0 MIRU MOVE MOB T Move the sub back to D pit access road on mats shuffling as needed. 38/12/2015 Continue to move the sub back to D pit access road on mats shuffling as needed. Pick up the mats on the road, repair the damaged section of road,and level out the remaining road from D pit access to 1R/1G access road. On standby to lie the mats back out onto the road. Page 3 of 20 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:00 4.00 0 0 MIRU MOVE MOB T Continue to move the sub back to D pit access road on mats shuffling as needed. 04:00 08:00 4.00 0 0 MIRU MOVE WAIT T On standby for field crew change. 08:00 17:00 9.00 0 0 MIRU MOVE WAIT T Pick up the mats on the road, repair the damaged section of road, and level out the remaining road to 1R/1G access road. 17:00 20:00 3.00 0 0 MIRU MOVE WAIT T On standby for field crew change. 20:00 00:00 4.00 0 0 MIRU MOVE WAIT T On standby to lay the mats back out onto the road. 38/13/2015 On standby to lay the mats back out onto the road. Back the sub out of D pit access road onto the Spine road on mats, shuffle the mats from D pit access road to the front of the mats on the Spine road, and move the sub 0.7 miles down the Spine towards 1G/1R access road, set down, and shuffling mats. Move the sub back over the stacked mats, shuffle the mats forward, move the sub 0.5 miles to the 1G/1R access road, and set the sub down. Transport the mats around the rig and lay the mats out towards the 1A access road. Move the sub 0.3 miles from 1G/1R access road, off the Spine road, and onto 1A access road. Pick up mats on the Spine road. Lay mats across, soft areas, culverts, and pipeline crossing from 1C pad to 1A pad to be able to move the pits from 1C pad. 00:00 01:30 1.50 0 0 MIRU MOVE WAIT T On standby to lay the mats back out onto the road. 01:30 05:00 3.50 0 0 MIRU MOVE MOB T Back the sub out of D pit access road onto the Spine road on mats, shuffle the mats from D pit access road to the front of the mats on the Spine road, and move the sub 0.7 miles down the Spine towards 1G/1R access road, set down, and shuffling mats. 05:00 09:30 4.50 0 0 MIRU MOVE WAIT T On standby for field crew change. 09:30 14:00 4.50 0 0 MIRU MOVE MOB T Move the sub back over the stacked mats, shuffle the mats forward, move the sub 0.5 miles to the 1G/1R access road, and set the sub down. 14:00 17:00 3.00 0 0 MIRU MOVE WAIT T On standby to transport the mats around the rig and lay the mats out towards the 1A access road. 17:00 19:00 2.00 0 0 MIRU MOVE WAIT T On standby for field crew change. 19:00 21:00 2.00 0 0 MIRU MOVE WAIT T On standby to transport the mat around the rig and lay the mats out towards the 1A access road. 21:00 22:00 1.00 0 0 MIRU MOVE MOB T Move the sub 0.3 miles from 1G/1R access road, off the Spine road, and onto 1A access road. 22:00 00:00 2.00 0 0 MIRU MOVE WAIT T On standby to pick up mats on the Spine road. Lay mats across culverts and pipeline crossing from 1C pad to 1A pad to be able to move the pits from 1C pad. Page 4of20 Time Logs • Date From To Dur S. Depth E. Death Phase 'Code Subcode T Comment 08/14/2015 24 hr Summary Move the pits from 1C pad to in front of KCC. On standby for field crew change. Move the sub from 1A access road onto 1A pad. Move the pits from KCC to 1A pad, move the sub over well 1A-02, spot the pits to the sub, and MU interconnect. Raise the derrick and pin. Rig accepted at 17:00 hours; load the pits with 8.4+ppg seawater. Pull the BPV with the lubricator. Open up tubing and bleed of gas to the kill tank. Kill the well by pumping 358 bbls of 8.4+ppg seawater down the tubing taking returns out the IA staging the pumps up to 3.5 BPM=540 psi; lost 78 bbls during the circulation. 00:00 02:00 2.00 0 0 MIRU MOVE WAIT T On standby to pick up mats on the Spine road. Lay mats across culverts and pipeline crossing from 1C pad to 1A pad to be able to move the pits from 1C pad. 02:00 04:00 2.00 0 0 MIRU MOVE WAIT T On standby to pick up mats on the Spine road. Lay mats on the 1A access road for the pits to move past the sub. SimOps: Start up the generators on the pits and hook up the Jeep to the pits. 04:00 04:30 0.50 0 0 MIRU MOVE MOB T Move the pits from 1C pad to in front of KCC. SimOps: Continue to lay mats on the 1A access road for the pits. 04:30 06:30 2.00 0 0 MIRU MOVE WAIT T On standby for field crew change. SimOps: Continue to lay mats on the 1A access road for the pits. 06:30 07:30 1.00 0 0 MIRU MOVE MOB T Move the sub from 1A access road onto 1A pad. 07:30 09:00 1.50 0 0 MIRU MOVE WAIT T On standby for field crew change. 09:00 12:00 3.00 0 0 MIRU MOVE MOB P Move the pits from KCC to 1A pad, move the sub over well 1A-02, spot the pits to the sub, and MU interconnect. Raise the derrick and pin. 12:00 17:00 5.00 0 0 MIRU MOVE RURD P RU rig floor, spool tugger, spool winches, pin cattle chute, bridle down, and pin the block to the top drive. 17:00 18:00 1.00 0 0 MIRU WELCTI RURD P Rig accepted at 17:00 hours. Load the pits with 8.4+ppg seawater. AES RU hardline to the choke house and kill tank. 18:00 19:30 1.50 0 0 MIRU WELCTL RURD P Change out flange on wing valve, install 3-1/16"working valve on the IA, RU circulation lines from secondary kill to wing valve, RU IA to kill tank, and blow down lines. 19:30 20:00 0.50 0 0 MIRU WELCTI SFTY P PJSM for RU lubricator and pulling BPV. 20:00 21:00 1.00 0 0 MIRU WELCTL MPSP P RU lubricator to the tree,test to 1000 psi(good test), RD test hose, pull 'IS-A' BPV(400 psi below BPV), close master valve, bleed off gas, and RD lubricator. ( Page 5 of 20 Time Logs III Date From To Dur S. Depth E. Depth Phase 'Code Subcode T Comment 21:00 21:30 0.50 0 0 MIRU WELCTL SFTY P PJSM for well kill operation. 21:30 22:00 0.50 0 0 MIRU WELCTL SEQP P Fill lines with seawater and PT lines to 1000 psi(good test). 22:00 00:00 2.00 0 0 MIRU WELCTL KLWL P Open up tubing and bleed of gas to the kill tank. Kill the well by pumping 358 bbls of 8.4+ppg seawater down the tubing taking returns out the IA staging the pumps up to 3.5 BPM=540 psi. Lost 78 bbls during the circulation. 08/15/2015 Observe the well for flow for 30 minutes;tubing and IA are on a vac. Install 3"'IS-A'BPV per FMC. ND the tree and install the blanking plug. NU the DSA and NU BOP stack. Fill stack with fresh water and observed a leak between the adaptor flange and BOP stack. ND the BOP stack to change out the API ring and discovered that the wrong API ring was installed; installed the correct API ring and NU the BOP. Conduct initial BOPE test to 250/3000 psi: test 2-7/8"x 5"VBR's(upper and lower pipe rams)with 3-1/2"test joint; test annular to 250/3000 with 3-1/2"test joints; conducted CPAI Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Jeff Jones via email on 8/14/15 at 19:40 hours. Pulled the BPV, BOLDS, pull tubing free at 110K, pull hanger to the rig floor, and lay down tubing hanger. Circulated surface to surface at 5 BPM and saw a small amount of gas at bottoms up. POOH laying down 3-1/2"tubing spooling control line and removing stainless steel bands from tubing cut at 7421'to 6354'at midnight. 00:00 00:30 0.50 0 0 MIRU WELCTL OWFF P Observe the well for flow for 30 minutes;tubing and IA are on a vac. 00:30 01:00 0.50 0 0 MIRU WELCTL RURD P Blow down all lines used during circulation and RD all circulation hoses from the tree. Clean and clear the cellar. 01:00 01:30 0.50 0 0 MIRU WHDBO MPSP P Install 3"'IS-A' BPV per FMC. 01:30 03:30 2.00 0 0 MIRU WHDBO NUND P ND tree, install blanking plug, and install DSA. 03:30 07:00 3.50 0 0 MIRU WHDBO NUND P NU DSA and BOPE. Set riser in place,secure stack, and air up boots. Install mouse hole. 07:00 09:00 2.00 0 0 MIRU WHDBO RURD T RU to test BOPE. Test flow line and verify no leaks. Fill stack with fresh water and observed a leak between the adaptor flange and BOP stack. Tightened and observe same leak. 09:00 12:00 3.00 0 0 MIRU WHDBO RGRP T ND the BOP stack to change out the API ring and discovered that the wrong API ring was installed. Installed the correct API ring and NU the BOP. 12:00 13:00 1.00 0 0 MIRU WHDBO RURD P PU 3-1/2"test joint and MU 3-1/2" EUE TIW. Fill BOP stack, choke manifold, and test joint with fresh water. MU the top drive. Shell test the BOP stack(good test). Page 6 of 20 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 16:45 3.75 0 0 MIRU WHDBO BOPE P Conduct initial BOPE test to 250/3000 psi: test 2-7/8"x 5"VBR's (upper and lower pipe rams)with 3-1/2"test joint;test annular to 250/3000 with 3-1/2"test joints; conducted CPAI Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Jeff Jones via email on 8/14/15 at 19:40 hours. Tests: #1)Annular with 3-1/2"test joint, TD Upper IBOP, Kill Demco, Chokes 1, 2, 3, & 16(Passed) #2) Upper Pipe rams with 3-1/2"test joint, HCR Kill, TD Lower IBOP, Chokes 4, 5, &6(Passed) #3) Lower Pipe rams with 3-1/2"test joint, 3-1/2" EUE TIW(Passed) #4)Manual Kill, Blind rams, Chokes 7, 8, &9(Passed) #5)Manual Choke, Hydraulic Choke, HCR Kill (Passed) #6)Chokes 10& 11 (Passed) #7)Chokes 12, 13, & 14(Passed) #8)Choke 15(Passed) #9)HCR Choke(Passed) #10)Manual Choke(Passed) #11)Blinds, HCR Kill, Outer Test Spool(Passed) #12)Blinds, Inner Test Spool (Passed) Conduct CPAI Koomey Draw Down Test: Starting Accumulator Pressure= 2900 psi Accumulator Pressure After Closer= 1650 psi Pressure Gain of 200 psi=34 seconds Full System = 155 Seconds Average N2(6 Bottles)=2050 psi 16:45 17:15 0.50 0 0 MIRU WHDBO RURD P RD BOPE testing equipment, suck out the stack, blow down the choke/kill lines, pull blanking plug with test joint, and lay down test joint. 17:15 18:00 0.75 0 0 MIRU WHDBO MPSP P PU T-bar, sting into BPV, open poppet valve(gas below BPV), vent off gas through poppet valve, and monitor for 15 minutes. PU BPV retrieving tool, pull BPV, and lay down T-bar. SimOps: RU Weatherford tubing tongs and SLB control line spooler. Page 7 of 20 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 18:30 I 0.50 0 0 COMPZ RPCOM SFTY P PJSM on laying down tubing and spooling control line. 18:30 19:15 0.75 7,425 7,421 COMPZ RPCOM PULL P PU landing joint, MU crossover, MU the top drive to the landing joint, BOLDS, pull tubing free at 110K, pull hanger to the rig floor, break out crossover, unscrew landing joint, lay down landing joint, and lay down tubing hanger. 19:15 19:30 0.25 7,421 7,421 COMPZ RPCOM RURD P RU to circulate. 19:30 20:30 1.00 7,421 7,421 COMPZ RPCOM CIRC P Fill the hole with 30 bbls and circulate surface to surface staging the pumps up to 5 BPM =470 psi. At bottoms up observed a small amount of gas in the returns but no gain in fluid in the pits. Lost 47 bbls during the circulation. 20:30 20:45 0.25 7,421 7,421 COMPZ RPCOM OWFF P Monitored the well for flow;well is on a vac. SimOps: Blow down the top drive. 20:45 00:00 3.25 7,421 6,354 COMPZ RPCOM PULL P POOH laying down 3-1/2"tubing spooling control line and removing stainless steel bands from tubing cut at 7421'to 6354'at midnight(PU = 85K, SO-74K). Total losses during trip=27.1 bbls. 38/16/2015 Continue POOH laying down 3-1/2"tubing spooling control line and removing stainless steel bands from 6354' to 5595'. Lay down SCSSSV; recovered 33 stainless steel control line bands. Continue POOH laying down 3-1/2"tubing removing 10 GLM's from 5595'to surface. Cut joint length = 14.06'. Conduct BOPE test to 250/3000 psi: test 2-7/8"x 5"VBR's(upper and lower pipe rams)with 4"test joint;test annular to 250/3000 with 4"test joints(all tested passed). PU, MU, and RIH with overshot assembly for 3-1/2"tubing to 2215' RKB. Slip and cut 104'of drilling line. Continue to RIH with overshot assembly from 2215'to 4785' RKB at midnight. Fluid loss rate about 10 bbls/hour. 00:00 01:15 1.25 6,354 5,595 COMPZ RPCOM PULL P Continue POOH laying down 3-1/2" tubing spooling control line and removing stainless steel bands from 6354'to 5595'(PU =80K, SO-70K). Lay down SCSSSV; recovered 33 stainless steel control line bands (records show 32 stainless steel control line bands were installed in 1986). 01:15 02:00 0.75 5,595 5,595 COMPZ RPCOM RURD P RD and lay down SLB control line spooler and tool baskets. Change out Weatherford tubing tongs. 02:00 09:15 7.25 5,595 0 COMPZ RPCOM PULL P Continue POOH laying down 3-1/2" tubing removing 10 GLM's from 5595' to surface. Strap,tally, and remove tubing from the pipe shed as needed. Cut joint length= 14.06'. 09:15 10:30 1.25 0 0 COMPZ RPCOM RURD P RD Weatherford tubing tongs. Clean and clear the rig floor. Change elevators from 3-1/2"tubing to 4"DP. Finish unloading the pipe shed of 3-1/2"tubing. Page 8 of 20 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 10:30 11:15 0.75 0 0 COMPZ RPCOM RURD P Load fishing tool into the pipe shed. 11:15 12:00 0.75 0 0 COMPZ RPCOM BOPE P RU BOPE test equipment and set test plug. 12:00 12:30 0.50 0 0 COMPZ RPCOM BOPE P PU 4"test joint. MU TIW and Dart Valve. Fill BOP stack with fresh water and shell test. 12:30 13:30 1.00 0 COMPZ RPCOM BOPE P Conduct BOPE test to 250/3000 psi: test 2-7/8"x 5"VBR's(upper and lower pipe rams)with 4"test joint; test annular to 250/3000 with 4"test joints(all tested passed). Tests: #1)Annular with 4"test joint, Dart Valve(Passed) #2)Upper Pipe rams with 4"test joint,4" HT-40 TIW(Passed) #3)Lower Pipe rams with 4"test joint,4" HT-40 TIW(Passed) 13:30 14:00 0.50 0 0 COMPZ RPCOM BOPE P Lay down testing tools, suck out the BOP stack, and RD BOP testing equipment. 14:00 14:30 0.50 0 0 COMPZ RPCOM SVRG P Service the top drive and draw works. DROPS inspection. 14:30 15:00 0.50 0 0 COMPZ RPCOM RURD P PU 4"DP joint, MU wear ring running tool, install wear ring,and lay down wear ring running tool. 15:00 15:30 0.50 0 0 COMPZ RPCOM SFTY P PJSM for PU fishing BHA. 15:30 17:30 2.00 0 316 COMPZ RPCOM BHAH P PU and MU BHA#1 -Overshot assembly for 3-1/2"tubing with dress off shoe. 17:30 20:00 2.50 316 2,215 COMPZ RPCOM PULD P Single in the hole with BHA#1 on 4" DP from the pipe shed from 316'to 2215' RKB. 20:00 20:15 0.25 2,215 2,215 COMPZ RPCOM SFTY P PJSM for slipping and cutting drilling line. 20:15 21:45 1.50 2,215 2,215 COMPZ RPCOM SLPC P Inspect brake bands and brake linkage. Slip and cut 104'(16 wraps) of drilling line. 21:45 00:00 2.25 2,215 4,785 COMPZ RPCOM PULD P Continue to single in the hole with BHA#1 on 4"DP from the pipe shed from 2215'to 4785' RKB at midnight (PU= 121K, SO=82K). Fluid loss rate about 10 bbls/hour. 08/17/2015 Continue to RIH with overshot assembly,dress off tubing stub down to 7412'RKB,engage tubing stub at 7417' RKB,jar fish free at 235K(70K over pull). Circulate bottoms up and TOOH. Recovered 4.53'section of 3-1/2"tubing. TIH with overshot assembly, dress off tubing stub down to 7422' RKB, engage tubing stub at 7423' RKB,jar fish free at 245K(75K over pull). Circulate bottoms up and TOOH to 5072' RKB at midnight. 00:00 02:30 2.50 4,785 7,400 COMPZ RPCOM PULD P Continue to single in the hole with BHA#1 on 4" DP from the pipe shed from 4785'to 7400' RKB(PU= 165K, SO= 100K). Page 9 of 20 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 02:45 0.25 7,400 7,400 COMPZ RPCOM CIRC P Obtain slow pump rates with 8.4+ ppg seawater. Mud Pump#1: 2 BPM= 100 psi; 3 BPM=210 psi. Mud Pump#2: 2 BPM=90 psi; 3 BPM=200 psi. 02:45 04:15 1.50 7,400 7,412 COMPZ RPCOM MILL P Tag top of fish at 7409' RKB and dress tubing down to 7412'at 60 RPM,7-9K torque, rotating weight= 125K, 2 BPM= 100 psi. Stop rotation. 04:15 04:45 0.50 7,412 7,417 COMPZ RPCOM JAR P Stop rotation, SO,engage fish down to 7416.6' RKB, PU to 175K, begin jarring staging up to 235K(70K overpull), and string weight went to 168K free travel. 04:45 05:00 0.25 7,417 7,360 COMPZ RPCOM PULD P Lay down two joint of DP to get on even stand for TOOH. 05:00 06:00 1.00 7,360 7,360 COMPZ RPCOM CIRC P Circulate bottoms up at 5 BPM= 506 psi. Observed no gas at bottoms up. Monitored the well for 5 minutes;well is still on a vac. Blow down the top drive. 06:00 11:00 5.00 7,360 322 COMPZ RPCOM TRIP P TOOH standing back DP from 7360' to 322' RKB 11:00 12:00 1.00 322 29 COMPZ RPCOM BHAH P Stand back three stands of DC's and lay down BHA#1 -Overshot assembly for 3-1/2"tubing with dress off shoe. 12:00 12:15 0.25 29 29 COMPZ RPCOM SFTY P Crew change. PJSM for laying down BHA. 12:15 13:30 1.25 29 0 COMPZ RPCOM BHAH P Continue to lay down BHA. No fish sticking out the bottom of the overshot. Break down extension and found fish. Fish was a 4.53'piece of 3-1/2" tubing(pictures in well folder). 13:30 13:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM for picking up BHA. 13:45 15:00 1.25 0 316 COMPZ RPCOM BHAH T PU and MU BHA#2-Overshot assembly for 3-1/2"tubing with dress off shoe. 15:00 16:45 1.75 316 5,072 COMPZ RPCOM TRIP T TIH with BHA#2 from 316'to 5072' RKB. 16:45 18:00 1.25 5,072 5,927 COMPZ RPCOM PULD T Single in the hole with the remaining DP in the pipe shed from 5072'to 5927'RKB. 18:00 19:00 1.00 5,927 7,359 COMPZ RPCOM TRIP T Continue to TIH from 5927'to 7359'. 19:00 20:00 1.00 7,359 7,422 COMPZ RPCOM MILL T Dress tubing down to 7422'at 40-60 RPM,6-9K torque, rotating weight= 125K, 2 BPM= 100 psi. Stop rotation. 20:00 20:45 0.75 7,422 7,423 COMPZ RPCOM JAR T Stop rotation, SO,engage fish down to 7423' RKB, PU to 180K, begin jarring staging up to 245K(75K overpull), string weight dropped, PU, and had 5-10K drag. Page 10 of 20 Time Logs • • Date From To Dur S. Depth E.Depth Phase Code Subcode „ T Comment 20:45 22:00 1.25 7,423 I 7,359 COMPZ RPCOM CIRC T Stand back one stand. Circulate bottoms up at 4 BPM=325 psi. Observed no gas at bottoms up. Monitored the well for 5 minutes;well is still on a vac. Blow down the top drive. 22:00 00:00 2.00 7,359 5,072 COMPZ RPCOM TRIP T TOOH standing back DP from 7359' to 5072' RKB at midnight. 08/18/2015 Continue to POOH with BHA#2. Recovered 3.20'of 3-1/2"tubing. Make up BHA#3; fishing overshot with grapple. RIH and engage fish at 7,425'. Jar fish free at 235K. Circulate annular volume. Observe 20'of drag. POOH. Recovered partial tubing joint, pup joint and SBR. Make up BHA#4 Overshot for slickstick. RIH to 7,356'. Establish parameters and engage fish and swallow down to 7,444'. Jar free at 47K over. Circulate hole, observe gas near annular volume pumped. Daily fluid lost to formation 220 bbls;total lost 850 bbls. 00:00 02:45 2.75 5,072 322 COMPZ RPCOM TRIP T Continue TOOH standing back DP from 5072'to 322' RKB. 02:45 03:00 0.25 322 322 COMPZ RPCOM OWFF T Observe the well for flow;well is on a vac. SimOps: PJSM for laying down BHA. 03:00 04:00 1.00 322 0 COMPZ RPCOM BHAH T Lay down BHA#2-Overshot assembly for 3-1/2"tubing with dress off shoe. Recovered 3.20'of 3-1/2" tubing. 04:00 05:30 1.50 0 313 COMPZ RPCOM BHAH T PU and MU BHA#3-Overshot assembly with cut lip guide 05:30 06:15 0.75 313 973 COMPZ RPCOM TRIP T TIH with BHA#3 to 973'. 06:15 06:45 0.50 973 973 COMPZ RPCOM SVRG P Daily inspection and service top drive,adjust bail clamps. 06:45 09:00 2.25 973 7,355 COMPZ RPCOM TRIP T Continue to trip in hole with BHA#3 to 7,355'; lost 49.6 bbls of fluid 09:00 10:15 1.25 7,355 7,383 COMPZ RPCOM FISH T Obtain SPR's. Wash down at 3 bpm 200 psi.Tag fish at 7,420'. rotate 10 rpms 6Kft-lbs torque. Swallow fish down to 7,425'. Pick up to 235Klbs and fire jars. Fish free. Observe drag for—20'. Pick up to 7,383' (PUW 175K) 10:15 11:00 0.75 7,383 7,383 COMPZ RPCOM CIRC T Circulate bottoms up at 5 bpm 490 psi. Monitor well for 10 minutes- fluid falling. 11:00 16:30 5.50 7,383 316 COMPZ RPCOM TRIP T POOH with BHA#3 to 316'. 16:30 17:30 1.00 316 0 COMPZ RPCOM BHAH T Lay down BHA, rack back drill collars. Lay down fish; 8.15'of 3-1/2"partial joint, 7.42'pup joint and 24.70'SBR recovered. 17:30 18:00 0.50 0 0 COMPZ RPCOM RURD P Clean and clear rig floor. Rig up to make up BHA#4. 18:00 19:30 1.50 0 313 COMPZ RPCOM BHAH P Make up BHA#4 as per Baker to 313'; overshot, bumper sub, oil jars, drill collars and intensifier. 19:30 22:00 2.50 313 7,356 COMPZ RPCOM TRIP P Trip in hole to 7,356'. Page 11 of 20 Time Logs • Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 22:00 23:00 1.00 7,356 7,424 COMPZ RPCOM FISH P Establish parameters: PUW 168K, SOW 102K; 120 psi at 2 bpm. Wash down at 2 bpm, observe pressure increase at 7,438'. Swallow fish down to 7,444'. Slack off 10K, pick up to 30K overpull. Slack off 10K, pick up to 200K and bleed jars. Reset jars and pick up to 225K(47K over),fire jars. Pick up to 7,424 with 0-5K drag. Slack off and tag up at same depth, pick up to 7,424'with slight drag. 23:00 00:00 1.00 7,424 7,424 COMPZ RPCOM CIRC P Circulate hole volume at 3 bpm 245 psi. Observe gas 23 bbls prior to annular volume pumped. Slow pump rate down to 2.5 bpm to circulate out gas. 38/19/2015 Continue to circulate hole volume. POOH with BHA#4. Fish recovered: slick stick, packer, GLM and tubing down to cut. Pick up BHA#5 overshot and RatPack. RIH to 339'and test RatPack-good. Contine to trip in hole to 7,478'. Slip and cut drilling line. Continue to trip in hole and engage fish at 7,521', swallow to 7526'. Pick up 70K over-fish free. Pick up weight 177K with 7K drag. Circulate hole clean. POOH with fish to 1,300'. Daily fluid lost to formation 146 bbls,total lost 996 bbls. 00:00 00:45 0.75 7,424 7,424 COMPZ RPCOM CIRC P Continue to circulate hole volume i until returns are clean. Monitor well for 15 minutes, hole continues to take fluid. Blow down top drive. 00:45 06:15 5.50 7,424 313 COMPZ RPCOM TRIP P POOH with BHA#4. PUW 170 K with 5-10K drag. Standing back drill pipe in Derrick. 06:15 07:30 1.25 313 83 COMPZ RPCOM BHAH P Lay down BHA; Rack back drill collars. Lay down bumper sub and jars. 07:30 08:00 0.50 83 83 COMPZ RPCOM RURD P Rig up Weatherford tongs to break out, and lay down fish. 08:00 09:30 1.50 83 0 COMPZ RPCOM PULL P Lay down overshot and fish. Fish recovered :slick stick(23.75'), FHL packer(7.13'),joint of 3-1/2"tubing (29.99'), GLM (8.5')and cut joint (7.13'). Total length of fish 83.41'. 09:30 10:00 0.50 0 0 COMPZ RPCOM RURD P Lay down GBR tools,clean and clear rig floor 10:00 12:00 2.00 0 339 COMPZ RPCOM BHAH P Pick up Baker Fishing tools. Make up BHA#5 overshot dressed for 3-1/2"tubing and Baker RatPack to 339' 12:00 12:30 0.50 339 339 COMPZ RPCOM DHEQ P Test Ratpack at 2 bpm, 1105 psi- good. Blow down top drive. 12:30 15:00 2.50 339 7,478 COMPZ RPCOM TRIP P Trip in the hole with BHA#5 to 7,478'. PUW 170K, SOW 103K. 15:00 16:15 1.25 7,478 7,478 COMPZ RPCOM SLPC P Slip and cut 52'of drilling line. Service draw works and brakes. Page 12 of 20 Time Logs Date From To Dur S. Depth E. DepthPhase Code Subcode T Comment 16:15 17:15 1.00 7,478 7,478 COMPZ RPCOM FISH P Establish parameters PUW 170K, SOW 103K. Slack off and tag fish at 7521', swallow 5.5'and set 10K down. Pick up to 245K-fish free. Observe drag as seals pull free. PUW 177K,with 7K drag. Pick up to 7478' 17:15 19:00 1.75 7,478 7,478 COMPZ RPCOM CIRC P Drop ball to shear out pump out sub. Circulate hole volume at 3 bpm 170 psi. Monitor well,static. 19:00 00:00 5.00 7,478 1,300 COMPZ RPCOM TRIP P POOH with fish from 7478' PUW 192K, SOW 102K to 1300'. 08/20/2015 Continue to POOH with BHA#5. Lay down BHA. Rig PESI tools to lay down blast joints. Remove collar sleaves from blast joints,control break blast rings to break out joints. Lay down blast rings. 'GS'spear and casing patch also recovered. Lay down seal assembly. Rig up and RIH with BHA#6 6.2135"drift run. RIH to 2968'. Wash and ream to 3,022',tag up. Mill from 3,022'to 3,024'; unable to mill any further. Circulate annular volume and POOH. L/D BHA. Daily fluid los to formation 154 bbls,total lost 1150 bbls 00:00 01:00 1.00 1,300 520 COMPZ RPCOM TRIP P Continue to POOH with BHA#5 to 340'. 01:00 03:00 2.00 520 180 COMPZ RPCOM BHAH P Rack back drill collars. Lay down BHA. 03:00 14:00 11.00 180 0 COMPZ RPCOM PULL P PJSM with PESI Lay down blast joints, seal assembly and pup joint.. Remove sleeves covering casing collars; only 1 sleeve will remove properly. Cut sleeves around casing collars. Wrap blast rings with duct tap and absorb. Break enough blast rings to allow tongs to bite on joint. Continue laying down all blast ring joints. Observe trapped pressure in 4th joint, bleed off. 'GS'Spear and tubing patch recovered. 14:00 15:00 1.00 0 0 COMPZ RPCOM RURD P Clean and clear rig floor. Lay down casing tongs,. 15:00 16:15 1.25 0 307 COMPZ WELLPF BHAH P Pick up BHA#6 as per Baker- 6-1/8"bit, string mills, bumper subs, oil jars, and drill collars to 307' 16:15 18:00 1.75 307 2,968 COMPZ WELLPF TRIP P Trip in hole with drill pipe from derrick to 2968'. PUW 95K, SOW 72K 18:00 20:45 2.75 2,968 3,024 COMPZ WELLPF MILL P Establisth rotary 50 rpms free torque 3,000 ft-lbs. Break circulation and stage up to 6 bpm 435 psi. Wash and ream to 3021',tag up. Mill from 3022'to 3024':WOB 1-4K, Torque 4-8K. At 3,024' unable to mill further; no torque building with WOB. 20:45 21:30 0.75 3,024 3,024 COMPZ WELLPF CIRC P Circulate annular volume at 8 bpm 750 psi. Monitor well for 10 minutes. 21:30 22:45 1.25 3,024 307 COMPZ WELLPF TRIP P POOH with BHA#6 to 307'standing back drill pipe. 22:45 00:00 1.25 307 COMPZ WELLPF BHAH P Lay down BHA#6, rack back drill collars. Break bit. Page 13 of 20 110• Time Logs • Date From To Dur S. Depth E.Depth Phase ''Code Subcode T Comment 08/21/2015 24 hr Summary Make up BHA#7, casing scraper/cleanout assembly. and RIH to 7,748'. Wash down to 7,750'; circulate high viscosity sweep around. POOH with BHA#7. Lay down BHA#7. Install dutch riser. Rig up E-Line. Run in hole with Caliper log on E-line to 7,750'. Caliper from 7,750'to surface. Rig down E-Line, rig down dutch riser. Rig up to RIH with 3-1/2"selective completion. Daily fluid lost to formation 156 bbls,total lost 1306 bbls 00:00 00:30 0.50 0 12 COMPZ WELLPF BHAH P Make up BHA#7 mule shoe and crossovers. 00:30 01:45 1.25 12 230 COMPZ WELLPF PULD P Pick up 7 joints of drill pipe from shed. 01:45 03:00 1.25 230 541 COMPZ WELLPF BHAH P Continue making up BHA#7 casing scraper, boot baskets, bumper sub, oil jars. 03:00 07:00 4.00 541 7,680 COMPZ WELLPF TRIP P RIH with BHA#7 with HT40 drill pipe from derrick to 7,680'. PUW 170K, SOW 100K 07:00 09:00 2.00 7,680 7,750 COMPZ WELLPF CIRC P Establish circulation,stage up to 7 bpm 1000 psi. Wash down from 7,680'to 7,750'. Circulate high viscosity sweep around. Monitor well for 10 minutes, static. Blow down top drive. 09:00 13:30 4.50 7,750 541 COMPZ WELLPF TRIP P POOH with BHA#7 from 7,750'to 541' 13:30 15:00 1.50 541 0 COMPZ WELLPF BHAH P PJSM, lay down BHA#7 with 8 joints of drill pipe. 15:00 15:30 0.50 0 0 COMPZ WELLPF RURD P Clean and clear rig floor. 15:30 18:00 2.50 0 0 COMPZ WELLPF ELOG P Rig up dutch riser. Spot in and rig up E-Line 18:00 21:30 3.50 0 0 COMPZ WELLPF ELOG P RIH with Caliper log on E-line. Log 7"casing from 7,400'to surface. 21:30 23:00 1.50 0 0 COMPZ WELLPF FLOG P Rig down E-Line. Lay down E-line tools. Rig down dutch riser. 23:00 00:00 1.00 0 0 COMPZ RPCOM RURD P Rig up to RIH with 3-1/2"selective completion. 08/22/2015 Continue to RIH with 3-1/2"selective completion to 7,751'. Spot corrosion inhibited brine. Observe seals engage'DB'packer. Space out 1'off no-go. Drop ball and rod and pressure up to 2600 psi to set FHL packer. Shear out PBR. Stand back one stand and set test packer. Test lower completion to 3000 psi- good. POOH to 4760'standing back drill pipe. Continue to POOH to 3,050'laying down drill pipe. Set test packer and test from 3,050'below to 3000 psi-good. Pull out to 2,989 and set packer. Test from 2,989 to surface to 3000 psi-good. POOH. Rig up and begin testing BOPE's 250/3000 psi with 3-1/2"and 4"test joint. State's right to witness waived by Chuck Sheve. Accumulator test: Starting pressure 2950 psi,final pressuge 1700 psi. First 200 psi recharge 30 seconds,full recharge 141 seconds. 6 N2 bottles at 2075 psi average. Daily fluid lost to formation 125 bbls;total lost to formation 1431 bbls. 00:00 03:30 3.50 0 432 COMPZ RPCOM PUTB P PJSM. Pick up 3-1/2"selective completion with blast joints, FHL packer and test packer to 432' 03:30 09:00 5.50 432 7,751 COMPZ RPCOM RCST P RIH with selective completion on drill pipe from the derrick to 7,751'. PUW 170K, SOW 100K. Page 14 of 20 110 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 09:00 10:00 1.00 7,751 7,751 COMPZ RPCOM CRIH P Spot corrosion inhibited seawater. Pump 19 bbls at 3 bpm 204 psi off the vac truck followed by 76 bbls clean seawater from the pits at 5 bpm 518 psi. 10:00 11:00 1.00 7,751 7,344 COMPZ RPCOM PACK P Slack off and observe seals engage with pump pressure incease. No-go seal assembly and space out 1'off bottom. Drop ball and rod. Pressure up to 2600 psi to set FHL packer. Bleed to 1200 psi and shear out PBR at 185K up. 11:00 11:30 0.50 7,344 7,238 COMPZ RPCOM PRTS P Stand back 1 stand. Set test packer ag 7,688'and test lower completion to 3000 psi for five minutes-good. 11:30 12:00 0.50 7,238 7,238 COMPZ RPCOM SVRG P Inspect and service top drive and drawworks. 12:00 14:00 2.00 7,238 4,760 COMPZ RPCOM TRIP P POOH with test packer and seal assembly standing back in derick to 4,760'. 14:00 15:30 1.50 4,760 3,050 COMPZ RPCOM PULD P Continue to POOH laying down drill pipe to 3050'. 15:30 16:30 1.00 3,050 2,989 COMPZ RPCOM PRTS P Set test packer and test from 3,050' and below to 3000 psi for 5 minutes- good. Lay down two singles and set test packer at 2989'. Test from 2,989'to surface to 3000 psi for five minutes-good. 16:30 19:30 3.00 2,989 46 COMPZ RPCOM PULD P Continue to POOH laying down drill pipe 19:30 20:00 0.50 46 0 COMPZ RPCOM BHAH P Lay down test packer and seal assembly 20:00 20:30 0.50 0 0 COMPZ RPCOM RURD P Clean and clear rig floor. Pull wear bushing. 20:30 21:00 0.50 0 0 COMPZ WHDBO RURD P Set test plug. Rig up to test BOPE. 21:00 00:00 3.00 0 0 COMPZ WHDBO BOPE P Weekly BOPE test to 250/3000 psi with 3-1/2"and 4"test joints. State's right to witness test waived by AOGCC rep Chuck Sheve. 1.Annular with 3-1/2"TJ; Kill demco; dart; Chokes 1,2, 3, 16 -pass 2. UPR with 3-1/2"TJ; HCR Kill; TIW; Chokes 4, 5,6-pass 3. LPR with 3-1/2"TJ;TIW-pass 4. Blinds; manual kill;chokes 7, 8, 9 -pass 5. Chokes 10, 11 -pass 6. Chokes 12, 13, 14-pass Accumulator test: Starting pressure 2950 psi, final pressuge 1700 psi. First 200 psi recharge 30 seconds, full recharge 141 seconds. 6 N2 bottles at 2075 psi average. Page 15 of 20 1110 TimeLogs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/23/2015 24 hr Summary Continue to test BOPE to 250/3000 psi with 3-1/2"and 4"test joint. State's right to witness waived by Chuck Scheve. Rig down test equipment. Make up BHA#8 6.2135"string mill. Run in hole and open DV collar to 6.2135" POOH and lay down BHA. Rig up and run in hole with 5.5 MCL expandable casing patch to 121'. 00:00 02:45 2.75 0 0 COMPZ WHDBO BOPE P Continue to test BOPE 250/3000 with 3-1/2"and 4"test joint. State's right to witness waived by Chuck Scheve. 7. IBOP; 3-1/2" EUE TIW; choke 15- pass 8. UPR with 4"TJ; HCR choke; manual IBOP-pass 9. Manual choke; LPR with 4"TJ- pass 10. UPR with 4"TJ; HCR Kill; Outer test spool; IBOP-pass 11. UPR with 4"TJ; Inner test spool- pass 02:45 03:45 1.00 0 0 COMPZ WHDBO RURD P Rig down testing equipment. Drain stack, pull test plug. Install wear bushing 03:45 05:15 1.50 0 308 COMPZ WELLPF BHAH P Make up BHA#8, 6.2135"sting mill assembly.to 308 05:15 06:45 1.50 308 3,000 COMPZ WELLPF TRIP P Trip in the hole with string mill assembly with stands from the derrick to 3000'. 06:45 08:45 2.00 3,000 3,070 COMPZ WELLPF MILL P Establish parameters: PUW 93K, SOW 75K, ROTW 84K. Free torque 2,500 ft-lbs at 60 rpms. Establish circulation at 5 bpm 269 psi. Wash down to 3,029'and tag up on DV collar(Mill depth 3,018'). Milli DV collar and open up to 6.2135"with WOB 0-5lbs; 60-90 rpms and 4,000. Mill to 3,031' pumping high viscosity sweep while milling. Continue to wash down to 3,070'with no issues. 08:45 09:45 1.00 3,070 3,070 COMPZ WELLPF CIRC P Circulate hole clean at 5 bpm 240 psi pumping high viscosity sweep. Circulate hole volume. Monitor the well for 15 minutes. Blow down top drive. 09:45 11:15 1.50 3,070 308 COMPZ WELLPF TRIP P POOH with BHA#8 from 3,070'to 308' 11:15 12:30 1.25 308 0 COMPZ WELLPF BHAH P Lay down BHA as per Baker rep. 12:30 13:00 0.50 0 0 COMPZ WELLPF RURD P Clean and clear rig floor. 13:00 18:00 5.00 0 0 COMPZ WELLPF WAIT T Wait on 23#cone for Weatherford's MCL expandable casing patch.. After analyzing caliper log and ID of 7"casing Weatherford stated a 23# cone was needed to set casing patch; not the 26#cone. 23#cone is coming from Houston and was on a flight leaving Houston at 07:00 Houston time. Page 16 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 23:30 5.50 0 121 COMPZ WELLPF BHAH P Make up MCL inner string while waiting on cone and lay down. Cone arrived on location at 19:30. Make up cone to bottom of Anchor joint. Make up standard joint and isolation joint;torqued to 2400 ft-lbs with TORO turn tongs. Make up inner sting and hydraulic setting tool 23:30 00:00 0.50 121 121 COMPZ WELLPF RURD P Rig down casing tongs. Change out elevators for 4"drill pipe. 08/24/2015 RIH with MCL expandable patch to 3,046'. Set anchor patch as per WTF at 3,046'with 5,000 psi. Attempt to continue to set patch with straight overpull. Pull 110K over no movement. Pressure up to 3000 psi to stroke hydraulic too. Continue process to set MCL casing patch from 2990.09'to 3046'. Test casing to 3000 psi for 5 minutes-good. POOH laying down drill pipe and WTF hydraulic setting tool. Rig up and RIH with 3-1/2" completion as per detail Calculate spaceout. 00:00 03:00 3.00 121 3,046 COMPZ WELLPF TRIP P RIH with Weatherfords MCL patch on drill pipe from derrick to 3,046'. PUW 88K, SOW 70K. 03:00 03:30 0.50 3,046 3,046 COMPZ WELLPF RURD P Rig up to pressure up on expandable casing patch to 5,000 psi. 03:30 03:45 0.25 3,046 3,036 COMPZ WELLPF OTHR P Set MCL patch: Pressure up on hydraulic setting tool with mud pumps to 4000 psi. Observe break over at 2700 psi as setting tool strokes and begins setting patch. Pressure maintains 2500 to 2800 psi while stroking,then pressures up to 4000 psi. Shut in and line up test pump to build pressure to 5000 psi, hold for 30 seconds. Bleed off and repeat process with no break over. Anchor set. Page 17 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode :T Comment 03:45 04:30 0.75 3,036 2,980 COMPZ WELLPF OTHR P Continue to set MCL patch from 2990.09'to 3046' Pick up on setting tool and observe —10'of free travel(setting tool resetting). Continue pulling up to 110K over with no movement. Pressure up and observe break over at 2600 psi with overpull dropping off to 80K over. Pressure builds to 3600 psi, bleed off losing over pull. Pick up on setting tool and observe —10'of free travel. Continue pulling up to 110K over with no movement. Repeat process of building pressure to use setting tool with identical results. Pick up on setting tool and observe 10'of free travel. Continue pulling and observe—5'of travel with 100- 110K over. Stop at 120K over. Repeat process of building pressure to use setting tool with identical results. Pick up and observe—10'of free travel. Continue pulling and observe 2'of travel with 110K over. Stop at 120 K over. Build pressure up to 3000 psi prior to seeing breakover. Observe inner string exit top of MCL liner. 04:30 05:00 0.50 2,980 2,980 COMPZ WELLPF PRTS P Lay down two joints and test casing to 3000 psi for 5 minutes. 05:00 05:30 0.50 2,980 2,980 COMPZ WELLPF RURD P Drop dart to open drain sub. Rig down testing equipment. 05:30 08:30 3.00 2,980 121 COMPZ WELLPF PULD P POOH laying down drill pipe from 2980'to 121' 08:30 10:15 1.75 121 0 COMPZ WELLPF BHAH P Lay down Weatherford's setting tool. 10:15 11:30 1.25 0 0 COMPZ RPCOM RURD P Clean and clear rig floow. Pull wear bushing. 11:30 12:00 0.50 0 0 COMPZ RPCOM SVRG P Inspect and service drawworks, and top drive. 12:00 13:30 1.50 0 0 COMPZ RPCOM RURD P Rig up to RIH with 3-1/2"completion. Rig up power tongs, bring hanger to floor, check running order. Page 18 of 20 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 23:30 10.00 0 7,358 COMPZ RPCOM PUTB P PJSM. Run in hole with 3-1/2" completion as per detail. Observe 1-2K drag while going through casing patch. Observe multiple collars tagging top of patch with 5K-10k before falling off. Continue to RIH to 7,330'. Establish circulation at 1 bpm. Observe pressure increase as seals engage. Shut down and bleed pumps. Continue to slack off an no-go with 15K down. 23:30 00:00 0.50 7,358 7,348 COMPZ RPCOM HOSO P Space out. Lay down partial joint. Attempt to lay down second joint. Hanging up. 08/25/2015 Finish running completion. Circulate 258 bbl inhibitted brine. Space out and land tubing. Set BPV. Perform BWM. N/D BOPE. N/U tree and test tubing head adapter to 250/5000 psi. Pull BPV and set TWC. Test tree to 250/5000 psi. Pull TWC and prep to freeze protect. 00:00 01:00 1.00 7,348 7,344 COMPZ RPCOM HOSO T Continue to attempt and lay down second joint for space out. Joint hanging up on casing patch. Work pipe up to 50K over multiple times, with no sucess. Pick up to tight spot. Pressure up(seals still engaged)to 1000 psi and attempt to pull through tight spot, unsuccessful. Slack off and pressure up to 2000 psi over, pick up 40K over-weight drop off. 01:00 03:00 2.00 7,344 7,340 COMPZ RPCOM HOSO P Continue to lay down two joints for spaceout. No indication of tight spot on second joint. Make up spaceout pup,full joint, hanger, and landing joint. 03:00 04:30 1.50 7,340 7,340 COMPZ RPCOM CRIH P PJSM displacing well to corrosion inhibited seawater at 3 bpm 212 psi. 04:30 04:45 0.25 7,340 7,340 COMPZ RPCOM THGR P Slack off and observe seals engage with pressure increase. Suck out Stack. Land tubing. RILDS 04:45 06:15 1.50 7,340 7,340 COMPZ RPCOM PRTS P Test tubing to 3500 psifor 30 minutes. Bleed tubing pressure to 2500 psi. Test IA to 3000 psi ofr 30 minutes. Bleed tubing pressue to 0 psi to shear SOV. 06:15 06:45 0.50 7,340 7,340 COMPZ RPCOM OWFF P Observe well for flow 06:45 07:30 0.75 7,340 7,340 COMPZ RPCOM RURD P L/D landing joint. R/D lines and test equipment 07:30 08:00 0.50 7,340 7,340 COMPZ WHDBO MPSP P Set IS-A BPV and test to 1000 psi in direction of flow. R/D lines 08:00 08:30 0.50 7,340 7,340 COMPZ WHDBO SFTY P Safety meeting on nippling down BWM and nippling down BOPE 08:30 09:30 1.00 7,340 7,340 COMPZ WHDBO OTHR P Flush stack. Pull riser and mousehole Page 19 of 20 Time Logs Date From To Dur " S. Depth E. Depth Phase Code Subcode T Comment 09:30 11:15 1.75 7,340 7,340 COMPZ WHDBO SVRG P Perform Between Well Maintenance on BOPE. Set 4"test joint and function annular. Element in good condition w/no defects observed. No key seating observed 11:15 12:00 0.75 7,340 7,340 COMPZ WHDBO SVRG P Continue BWM. Open doors on upper pipe rams 12:00 12:30 0.50 7,340 7,340 COMPZ WHDBO SFTY P Safety meeting 12:30 16:00 3.50 7,340 7,340 COMPZ WHDBO SVRG P Continue breaking bolts on top pipe rams. Inspect rams. Close doors and installl studs. Break studs on blinds. Remove studs and open doors. Inspect Blind rams. Close doors and install studs. Break studs on bottom pipe rams. Open doors and inspect VBR's. 16:00 17:00 1.00 7,340 7,340 COMPZ WHDBO NUND P Remove VBR's from lower pipe rams and replace with 7"casing rams. 17:00 18:30 1.50 7,340 7,340 COMPZ WHDBO NUND P Remove turnbuckles. Break bolts on 11"DSA. Stand back BOPE on stump and secure. Remove DSA 18:30 19:30 1.00 7,340 7,340 COMPZ WHDBO NUND P Pull tree and tubing head adapter into cellar. Pre cellar to N/U tree 19:30 20:00 0.50 7,340 7,340 COMPZ WHDBO SFTY P Safety meeting on nippling tree and setting BPV 20:00 22:00 2.00 7,340 7,340 COMPZ WHDBO NUND P N/U tubing head adapter and tree. Test tubing hanger pack off to 250/5000 psi for 5 min-good test. Open SSV. 22:00 22:30 0.50 7,340 7,340 COMPZ WHDBO MPSP P Pull IS-A BPV and set TWC. 22:30 23:15 0.75 7,340 7,340 COMPZ WHDBO PRTS P Fill tree with diesel and test to 250/5000 psi-good test. R/D test equipment 23:15 23:30 0.25 7,340 7,340 COMPZ WHDBO MPSP P Pull TWC with lubricator 23:30 00:00 0.50 7,340 7,340 COMPZ WHDBO FRZP P Rig up to freeze protect well. 08/26/2015 Freeze protect well with 73 bbl diesel. Set BPV and release rig. 00:00 02:00 2.00 7,340 7,340 COMPZ WHDBO FRZP P Pressure test lines to 3000 psi. Pump 73 bbl LEPD in IA. Put IA and tubing in communication and rig up to U-tube. ICP=750 psi FCP= 1100 psi. 02:00 02:15 0.25 7,340 7,340 COMPZ WHDBO FRZP P Rig down LRS. Break down hardline. 02:15 03:00 0.75 7,340 7,340 COMPZ WHDBO OWFF P Observe well for flow. Shut in 03:00 03:45 0.75 7,340 7,340 COMPZ WHDBO MPSP P Set BPV and rig down lubricator 03:45 04:15 0.50 7,340 7,340 DEMOB MOVE SFTY P Pre-job meeting with truckers and crew to move pits 04:15 05:00 0.75 7,340 7,340 DEMOB MOVE RURD P Remove secondary valves from wellhead. Secure cellar. Install spreader bar in A-leg. Secrue rig floor. Work on rig move checklist. Rig released at 0500 hrs 8/26/2015 to move to 1A-28. Page 20 of 20 • OF TA c,;w\�� cs,7 THEALASI�:A STATE Alaska Oil and Gas f Conservation Commission _ : .� _;_ 333 West Seventh Avenue ' k GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *.�'' Main: 907.279.1433 OF ALAS. Fax: 907.276 7542 www aogcc.alaska gov tiED ,,i ,ati Danny Kane Sr. Wells Engineer O( •� 071 ConocoPhillips Alaska, Inc. , 1 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1A-02 Sundry Number: 315-429 Dear Mr. Kane: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster ,,yam Chair DATED this 2`t'day of July, 2015 Encl. STATE OF ALASKA � ",',6.; 'ED • A. .,KA OIL AND GAS CONSERVATION COM. SION IUl 1 5 2015 APPLICATION FOR SUNDRY APPROVALS ors z/ 24-( IS 20 AAC 25.280 AqGCC 1.Type of Request. Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r i erations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r- Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well Fi, - Re-enter Susp Well pa/d l 7 Other: G/Q�/•�1q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill NiM ber: vrt-- ConocoPhillips Alaska, Inc.• Exploratory r Development r 181-071 3.Address: 6.API Number: Stratigraphic r Service r , P.O. Box 100360,Anchorage,Alaska 99510 50-029-20599-00 i. 7.If perforating, 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r i KRU 1A-02, 9.Property Designation(Lease Number): 10.Field/Pool(s). ADL 25647 ' Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft). Plugs(measured): Junk(measured): 8355 • 6548 - 7504' 7650,7902 Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 112' 112' - SURFACE 2873 10.75 2902' 2663' PRODUCTION 8309 10 8337' 6535' Perforation Depth MD(ft). Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft). 7552-7591,7601-7648,7652-7688,7700-7712,7796-7850 a 5963-5990,5997-6030,6033-6058,6067-6075,6135-6174 3.5 J-55 7781 Packers and SSSV Type Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER HYD PACKER MD=7474 TVD=5908 . PACKER-BAKER PERMANENT PACKER MD=7753 TVD=6104 TRDP-CAMCO'TRDP-1A-ENC' MD=1814 TVD=1785 1 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work. Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development Service �' 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work: 8/1/2015 OIL r VVINJ r WDSPL r Suspended r 16 Verbal Approval Date: GAS r WAG GSTOR r SPLUG r Commission Representative GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Danny Kane @ 265-6048 Email. Danny.Kane(c,conocophillips com Printed Name Danny Kane Title: Sr. Wells Engineer Signature C-11-.5 _ .— Phone.265-6048 Date (I4 a,..zS Commission Use Only Sundry Number Conditions of approval: Notify Commission so that a representative may witness 3(fj- LII-1 Plug Integrity r BOP Test f' Mechanical Integrity Test rk` Location Clearance r Other: 56 P fZ i/- #0 3c c G p 5 ; (7V1 P 5 P �S 17// /25,-) / rzryv/Gik- p r ✓ CC✓ti t/ tr$ t fo 25 00 psi -ta.te vv-IVr)cS4rd /1/1- IS-IA rzv�`r6"� a,f't<r SfetbJ./i�3_cd ,-,, j-r� fedi-, . Spacing Exception Required? Yes No ® Subsequent Form Required: /G 4c zf D APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: 7- Z(/. /5-- k,7--i_ 5-- Approved application is valid for 12 months from the date of approval. k TL / /' Submit Form and Form 10-403 Revised 5/2015 ORIGINAL 'D/ �//r// Attar ents in Duplicate Zll��y RBDIVM PIG - 2 2015 ECEW D ✓ lUi_ 15 2015 ConocoPhillips Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 July 10,2015 Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to workover Kuparuk Injector KRU 1A-02(PTD# 181-071). Well 1A-02 was spudded in June 1981 and completed as a comingled Kuparuk A- & C-sand injector; however the well was initially pre-produced during the early field life. A rig work-over was performed in 1986 to provide Kuparuk A-&C-sand selectivity and the well was finally converted to a MWAG injector in 1991. In 1996,a leak was noticed in the IA while injecting Drill Site lA reserve pit water and subsequent diagnostic work suggested the leak was within the vicinity of the Halliburton DV collar at 3022' MD. A variance was requested of the AOGCC to continue water injection and was granted. Water injection continued until 2006 when questionable MIT-OA results and a failed MIT-IA showed there could be a IA x OA x formation leak path. The well was shut-in and a Seal-Tite repair was performed shortly thereafter at the DV collar. The well was returned to water injection until it had to again be shut in for a breakdown in the Seal-Tite repair in 2008. In 2009 another Seal-Tite repair was performed at the DV collar and the well was returned to water injection. In 2013 the well failed an MIT-IA meaning the second Seal-Tite application had broken down. The well was shut in&placed on the rig work-over list. The proposed work-over will consist of pulling the existing upper & selective completion to the lower permanent packer, installing a Weatherford MetalSkin expandable casing patch across the leaking DV collar, and to reinstall a 3-1/2"selective injection completion. This Sundry is intended to document the proposed work on KRU 1A-02 because of the intent pull tubing and repair the well (production casing leak)as well as to request approval to workover this well. If you have any questions or require any further information,please call me at 265-6048 or email me at danny.kanefikonocophillips.com. Sincerely, Danny Kane Wells Engineer CPAI Drilling and Wells KRU 1A-02 Rig Workover Pull & Replace Selective /Production Casing Patch (PTD #:181-071 /RWO Sundry: 186-538) Current Status: KRU 1A-02,a Kuparuk A-&C-sand injector,is currently shut-in for a failed MIT-IA as a result of a historical leak in the 7"production casing at identified to be between 3002'—3030'MD. Based upon past remediation work& historical records,the leak is believed to be across the Halliburton DV stage cementing collar(3022'—3025' MD). Please see below for a history of the remedial work performed on this leak: - 1996—Noticed leak in IA while injecting Drill Site lA reserve pit water. o Diagnostics showed a leak within the vicinity of the Halliburton DV stage collar(3022'MD), part of the 7"production casing string. The leak was suspected to be in the DV collar based upon historical precedent(DV collars known to leak)and review of well cementing records. - 1997—Sundry#397-037—Variance requested for continued water injection with IA leak. - 2006—MIT-IA failed. Questionable MIT-OA results,potential leak path from IA to OA to formation. o With new leak detection technology confirming a leak in Halliburton DV collar and with the close proximity to the questionable OA shoe,the well was shut-in per internal policies. - 2006—Sundry#306-217—Seal-Tite treatment performed,passing MIT-IA. Returned to injection. - 2008—Failed MIT-IA,Seal-Tite treatment broke down,&well was shut-in. - 2009—Sundry#309-102—Seal-Tite treatment performed,passing MIT-IA. Returned to injection. - 2013—Failed MIT-IA, Seal-Tite treatment broke down,&well was shut-in. Additionally,there is a known leak in the 3-1/2"tubing within the Kuparuk C-sand selective that was unsuccessfully repaired in 2009. Please see below for a history of the remedial work performed on this leak: - 2005—Leak detected in tubing at 7722' MD(above AVA nipple in C-sand selective). - 2006—Set straddle patch across leak,passing MIT-T. - 2008—Leak detected across tubing patch set in 2006. - 2009—Sundry#309-075—Attempted to pull tubing patch,unsuccessful,patch fish left in hole. Scope of Work: Repair the production casing leak & replace the selective completion to regain Kuparuk A- & C-sand injection selectivity. Pull the upper completion,perform a casing scraper run to the production packer,and evaluate the casing for the proposed casing patch and new packer-setting depth. Pull the selective completion to the permanent packer and run new selective completion,engaging the seals into the Brown DB/SBE permanent packer. Space out,drop ball &rod,and set the Baker FHL production packer. Use test packer to pressure test FHL packer&confirm leak in the production casing at 3030' MD. Run tandem mills required to dress casing prior to setting patch& set patch across production casing leak. Pressure test casing&lay-down patch setting tools. Run upper completion to surface. General Well Info: Well Type: Injector MPSP: 1,711 psi using MASP=(PP-(0.1*TVD)),assuming dry gas gradient to surface. Reservoir Pressure/TVD: Kuparuk A/C—2,445 psi/6,006' TVD(7.9 ppg EMW) Wellhead Type/Pressure Rating: FMC Gen I(5M Tubing Head/3M Casing Head) BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT Results: MIT-T Passed 30-Dec-2013 MIT-IA Failed 26-Nov-2013 Passed 02-Mar-2013 (Leak in DV Collar at 3030'MD) MIT-OA Failed 26-Oct-2008 Passed 23-Mar-2006(Leaking OA Shoe) Earliest Estimated Start Date: 13-Jul-2015 Production Engineer: Kay Sind Workover Engineer: Danny Kane (907)265-6048 danny.kane@conocophillips.com KRU 1A-02 Rig Workover Pull & Replace Selective /Production Casing Patch (PTD #:181-071 /RWO Sundry: 186-538) Summary of Proposed RWO Procedure: Proposed Pre-Rig Work: 1. Pull 2.78"WRP at 7504'MD(set in 2013). 2. Pull 1"CV-BK from GLM#11. 3. Pull 1-1/2"DMY-RM from GLM#10. 4. Cut 3-1/2"tubing at 7534'MD. 5. Cut 3-1/2"tubing at 7424'MD. 6. Set BPV. Proposed Rig Workover Procedure: 1. MIRU RWO Rig. 2. Pull BPV. Circulate KWF around. Obtain SITP&SICP;if pressure is observed at surface,calculate new KWF and repeat circulation if necessary. Verify well is static prior to proceeding. 3. Set BPV(PT to 1000psi),ND tree,NU BOPE,&test BOPE to 250/3000psi low/high. 4. Pull BPV,screw in landing joint,BOLDS,&unseat tubing hanger. 5. P/U on tubing&pull hanger to the rig floor. Verify well is static&TOH laying down 3-1/2"upper completion to pre-rig tubing cut at 7424'MD. 6. M/U& TIH with tubing body overshot, latch onto&engage seal assembly fish,& pull free from Baker SBR. TOH with&lay-down same. 7. M/U & TIH with 7" casing scraper to just above Baker SBR(7447' MD). TOH& lay-down same. Reverse circulate until returns are clean. 8. R/U wireline&perform casing caliper logging run down to 7400' MD. R/D wireline. a. CONTINGENCY:If the caliper data shows significant subsidence-induced damage,prepare to perform subsidence repair of production casing. 9. M/U & TIH w/Baker FHL Packer retrieving assembly, release packer, & pull free. TOH with & lay-down packer and selective completion to pre-rig tubing cut at 7534'MD. 10. M/U&TIH w/overshot fishing assembly(include agitation device), latch onto&engage tubing stub fish,and pull free from Baker DB packer/sealbore extension at 7753'MD. TOH with&lay-down remainder of selective completion. 11. M/U & TIH w/7" casing scraper assembly to the Baker DB packer/sealbore extension(7753' MD). Reverse circulate until returns are clean. TOH&lay-down same. 12. M/U&TIH w/tandem mill assembly made up for casing patch drift as per Weatherford representative. Dress patch interval,TOH,&lay-down same. 13. M/U&TIH w/the selective completion to just above the existing Baker DB packer/SBE. a. Production Packer/Injection Mandrel/Blast Joints/Sliding Sleeve w/RHC body/Seal Assembly 14. Displace the well to corrosion-inhibited kill-weight brine. 15. Sting into the SBE until fully-located,pick-up to neutral weight+2',and drop the ball&rod. Set the production packer,shear the PBR,&TOH laying down drill pipe(less what's required to run test packer&casing patch). 16. M/U&TIH w/test packer to 3050'MD. Pressure test casing&FHL packer to 3000psi. 17. TOH to 3000'MD with test packer&pressure test casing above to 3000psi. TOH w/test packer. 18. M/U&TIH with Weatherford MetalSkin casing patch. Space-out across production casing leak as indicated by caliper&mill run results,and set as per Weatherford representative. TOH w/setting assembly laying down drill pipe&BHA. 19. Pressure test 7"casing to 3000psi. ✓ KRU 1A-02 Rig Workover Pull & Replace Selective /Production Casing Patch (PTD #:181-071 / RWO Sundry: 186-538) 20. M/U&TIH with new 3-1/2"upper completion as per design to just above the new production packer. 21. Space-out tubing tail in sealbore receptacle,mark pipe at surface,and lay down two joints. 22. Space-out with tubing pups,M/U tubing hanger,land hanger,&RILDS. 23. Pressure test tubing to 3500psi&IA to 3000psi. Bleed the IA&then the tubing. Ramp up IA pressure quickly to shear the SOV. 24. Back-out landing joint,install BPV,&pressure test to I000psi from below. 25. ND BOPE,NU tree,install tree test plug,&pressure test tree. 26. Freeze protect well through SOV. 27. Set BPV. 28. RDMO RWO Rig. Proposed Post-Rig Work 1. Pull BPV. 2. RU slickline to perform the following: a. Pull ball&rod. b. Remove SOV& install gas lift mandrel design. c. Pull RHC plug. 3. Reset well house(s)&re-attach flow line(s). 4. Turn well over to operations. , KUP INJ 1A-02 ConocoPh- Mips , r," Well Attributes Max Angle&MD TD -',.- Wellbore APW WI Field Name Wellbore Status ncl r) MD(ftKB) Act Btm(ftKB) Alaska.Inc. ^' (,rrr dh11p+ 1 500292059900 KUPARUK RIVER UNIT INJ 49.00 7,200.00 8,355.0 -.- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 16-02.102420141;16'.31 PM SSSV:TRDP Last WO 12/25/1986 39.01 7/2/1981 Vertical schematic(actual} Annotation Depth(ftKB) End Date Annotation Last Mod By End Date --- ----- - - ---- ----- Last Tag:ELMD 7,840.0 10/9/2008 Rev Reason.WAIVERED WELL NOTE hipshkf 10/24/2014 �a� Casing Strings TA I HANGER;27.7 )II Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.063 39.0 112.0 112.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.797 28.7 2,9020 2,662.5 45.50 K-55 BUTT Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Ml. CONDUCTGR139o-1120-� PRODUCTION 7 6276 27.9 8,337.0 6,534.8 26.00 K-55 1=, Tubing Strings SAVETY VLV:16135 Tubing Description String Ma...11)(in) Top(ftKB) Set Depth(ft..Set Depth)TVD)(...WI(Ib/ft) Grade Top Connection TUBING 31/2 2.992 27.7 7,782.1 6,125.3 9.20 J-55 EUE8rdABMOD SURFACE;28.7-2,902.0 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl("I Item Des Com (in) 27.7 27.7 0.00 HANGER Tubing Hanger 3.500 GAS LIFT;3,063.2 1,813.5 1,784.8 25.27 SAVETY VLV CAMCO TRDP 1A-ENC 2.812 7,447.3 5,889.9 46.53 SBR BAKER SBR 3.000 7,473.5 5,908.0 4626 PACKER BAKER HYD PACKE 3.000 f 7,549.6 5,960.9 45.63 BLAST RINGS BLAST RINGS(7)-WLM 7547'-7717' 2.867 GAS LIFT;4.453.5 II 7,7412 6,096.1 44.59 NIPPLE AVA BOTTOM NO GO PORTED NIPPLE 2.750 GAS LIFT;4,876.9 7,752 1 6,103.8 44.48 LOCATOR Locator Space Out 2.875 GAS LIFT,5,2456 7,753.0 6,104.5 44.47 PACKER BAKER PERMANENT PACKER(7734'WLM 3.250 12/21/1986) GAS LIFT,5.614.5 7,756.6 6,107.1 44.43 SBE XO Baker Seal Bore Extension w/XO 3.5"to 2 7/8" 2875 7,769.8 6,116.5 44.30 NIPPLE CAMCO'D'NO GO NIPPLE 2.250 GAS LIFT,5.982.9 7,779.7 6,123.6 44.20 XO CROSSOVER 2 7/8"TO 3.5" 2.441 7,781.4 6,124.8 44.19 SOS OTIS SHEAROUT SUB/ELMD TTL @ 7764 during t 2.992 GAS LIFT;6,294.6 IPROF on2/11/2008 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;6,659.1 Top(ND) Top Incl Top(ftKB) (ftKB) )") Des Com Run Date ID(in) GAS LIFT;7,029.5 7,503.8 5,929.0 45.97 PLUG WEATHERFORDWRP 12/30/2013 0.000 7,650.0 6,031.5 45.13 FISH 3'x 1"COLLET LOST ON G-SPEAR BELOW 5/24/2009 0.000 GAS LIFT;7.400.6 al. PATCH 7,727.0 6,086.0 44.73 G-SPEAR BAITED BOWEN G-SPEAR ON PATCH(OAL 24") 5/17/2009 0.000 7,728.0 6,086.7' 44.72 PATCH 3.5"LOWER PATCH ASSY FISH(14.5"OAL 3/7/2006 1.600 SBR;7,447.3 -IS. PATCH REMAINING) PACKER;7,4735 7,9020 6,212.1 42.98 FISH Vann Gun,340.14"long 7/1/1981 0.000 PLUG;7,503.0 7,902.0 6,212.1 42.98 FISH Lock Key from AVA IBP left in hole @ 7902' 10/31/1999 0.000 Perforations&Slots INJECTION,7,509.3 g- Shot Den Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com RPERF 7,552.0-7,577.OLi 7,552.0 7,577.0 5,9626 5,980.1 C-4,1A-02 12/23/1986 12.0 RPERF 120 deg.Ph;5"HyperJet IPERF',7,552.0.7.591.0 II 7,552.0 7,591.0 5,9626 5,989.9 C-4,1A-02 7/1/1981 4.0 IPERF Squeezed&Repelled; RPERF;7,60L0.7.8260L_� r- Vann Gun (PERF;7.601.0.7,6400- 7,601.0 7,626.0 5,997.0 6,014.6 C-3,1A-02 12/23/1986 12.0 RPERF 120 deg.Ph;5"HyperJet II 7,601.0 7,648.0 5,997.0 6,030.1 C4,C-3,1A- 7/1/1981 4.0 IPERF Squeezed&Repelled, 02 Vann Gun FISH;2650.0 _ _ 7,652.0 7,688.0 6,032.9 6,058.3 C-2,1A-02 12/23/1986 12.0 RPERF 120 deg.Ph;5"HyperJet II RPERF 7,652.0-7,6880 7,654.0 7,688 - .0 6,034.3 6,058.3 C-2,1A-02 7/1/1981 4.0 IPERF Squeezed&Repelled; IPERF;7,654.0-7,688.01- Vann Gun -yyy 7,700.0 7,712.0 6,066.8 6,075.3 C-1,UNIT B, 7/1/1981 4.0 IPERF Squeezed&Reperfed; IPERF;7.700.0-7,712.o_ ■ . 1A-02 Vann Gun ii J 7,796.0 7,850.0 6,135.3 6,174.3 A-5,A-4,1A- 7/1/1981 4.0 IPERF 120 deg.Ph;Vann Gun 02 0-SPEAR;7,727.0 Cement Squeezes PATCH,7,728.0 Top(TVD) Btm(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 1 7,5520 7,591.0 5,962.6 5,989.9 Cement SQZ 7/1/1981 Repelled 7601-7626 on 23/23/86(WO) 7,601.0 7,648.0 5,997.0 6,030.1 Cement SQZ 7/1/1981 Repelled 7601-7626 on 23/23/86(WO) NIPPLE,7,741.2 , , 7,654a 7,654a 6,034.3- 6,034.3 Cement SQZ 7/1/1981 Repelled 7601-7626 on 23/23/86(W0) 7,700.0 7,712.0 6,066.8 6,075.3 Cement SQZ 7/1/1981 Repelled 7601-7626 on 23/23/86(WO) Mandrel Inserts LOCATOR,7.752.1 St PACKER,7.753 0 ati SBE 00;7,756.6 on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1' 3,063.2 2,772.4 Camco KBUG 1 Gas Lift DMY BK-2 0.000 0.0 11/19/1991 NIPPLE;7,769.8 2 4,453.5 3,714.3 Camco KBUG 1 Gas Lift DMY BK-2 0.000 0.0 4/22/2009 00 7,779.7 3 4,876.9 4,009.3 Camco 'KBUG 1 Gas Lift DMY BK-2 0.000 0.0 11/19/1991 SOS.7.781 4 4 5,245.6 4,273.0 Camco KBUG 1 Gas Lift DMY BK-2 0.000 0.0 11/19/1991 1-- IPERF, `IPERF,7,796 0-7.850 0 5 5,614.5 4,546.3 Camco KBUG 1 Gas Lift DMY BK-2 0.000 0.0 11/19/1991 6 5,9829 4,824.1 Camco KBUG 1 Gas Lift DMY BK-2 0.000 0.0 11/19/1991 FISH.7,902.0 FISH;7,9020 7 6,294.6 5,061.5 Camco KBUG 1 Gas Lift DMY BK-2 0.000 0.0 11/19/1991 8 6,659.1 5,340.1 Camco KBUG 1 Gas Lift DMY BK-2 0.000 0.0 11/19/1991 PRODUCTION;27.9-8.337.0-. KUP INJ 1A-02 ConocoPhillips Alaska.Inc. CanocrWelkpa 1A-02 1024201d 1.16.32 PM Vertical schematic(actual) re- HANGER,27.7 � ll Mandrel Inserts st ati Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 7,029.5 5,608.9 Camco KBUG 1 Gas Lift DMY BK-2 0.000 0.0 12/25/1986 CONDUCTOR;39.0.112.0—e 1 7,400.6 5,857.9 OTIS LBX 1 1/2 Gas Lift DMY RM 0.000 0.0 8/15/2006 SAVETYVLV;1,813.5 /! _ 0 1 7,509.3 5,932.8 Camco KBUG 1 INJ CV BK 0.000 0.0 421/2013 1 I SURFACE;28.7-1902.0 Notes:General&Safety End Date Annotation II 8/31/2005 NOTE:TUBING LEAK FOUND w/PONYTAIL @ 7739' GAS LIFT,3,063.2 8/14/2006 NOTE:IA leak @ 3025'plugged with Sealtite Flo-Seal Sealant 8/29/2006 NOTE:WAIVERED WELL-IA x FORMATION 8/18/2008 NOTE:VIEW SCHEMATIC w/ALaska Schematic9.0 2/1/2009 NOTE:LEAK FOUND @ 3030'ON TECWELL LDL GAS LIFT;4,453.5 12/30/2013 NOTE:CASING LEAK AT 3030'RKB GAS LIFT.4,876.9 GAS LIFT;5,245.6 GAS UFT;5,614.5 1.1 1.1 GAS UFT;5,982.9 • GAS LIFT;6294.6 GAS LIFT;6,659.1 1.1 GAS LIFT;7,029.5 GAS UFT;7,400.6 SBR;7,447.3 - PACKER;7.4735 PLUG;7503.8 INJECTION;7,509.3 RPERF;7,552.0.7,577.0 (PERF;7,552.0.7,591.0--NA i RPERF;7,601.0.7,626.OL� IPERF;7.601.0-7.848.0—] FISH;7,650.0 RPERF;7,652.67.688.0, IPERF;7,654.67.668.0 IPERF;7,700.0.7.712.0-1 awe G-SPEAR;7,727.0 PATCH;7,728.0 NIPPLE.7,741.2 LOCATOR;7,752.1 PACKER;7,753.0 SBE 50;7.756.6 NIPPLE; 5 o:7.7797 SOS,7,781.4 IPERF;7,798.0.7,850.0— FISH;7,902.0 FISH;79020 PRODUCTION;27.9.8337.0 FMC Gen I(Retro to Gen IV) K R U 1A-02 ConocoPhillips Kuparuk A&C Selective Injector Proposed RWO Scope 16"65#H-40 WLD,112'MD O. prognosed Scone of Work 1-Pull Existing Upper Completion 2-Scrape&Caliper Production Casing 3-Pull Existing Selective to DB Packer 4-Run New Selective Completion,Set FHL 5-Pressure Test Casing&FHL Packer Surface Casing Primary Cementing i::: Using Test Packer 1650sx 12.0 ppg'Fondu'Lead 6-Prepare Production Casing for Patch 250sx 15.2 ppg Arctic Set II Tail ; 7-Install MetalSkin Expandable Patch iAcross DV Collar Leak :; 8-Run New Upper Completion OA Shoe Squeeze 250sx 15.2ppg Arctic Set II ::•: Displaced to 2300'MD(Arctic Pac) : - 10-3/4"45.5#K-55 BTC,2902'MD - WFT MetalSkin Expandable Casing Patch 3030'MD-Casing Leak(DV Collar)— ►g ® ... °;:ice Length TBD by Packer/Caliper Diagnostics f— %, 3-1/2"9.3#L-80 EUE-8RD AB-Mod Drilling Mud/Cement Spacer :::t2ipppi C9irrent:-:: :-44.4-15.8ppg Cern@nt; Imag.oject Well History File Cover ee XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 1 B 1 - } 11 Well History File Identifier Organizing (done) RESCAN K Two-Sided 1111111111111111111 DIGITAL DATA o Rescan Needed 111I111111111111111 OVERSIZED (Scannable) 0 Color items: 0 Grayscale items: 0 Poor Quality Originals: 0 Other: o Diskettes, No. Other, NofType o Maps: Other items scannable by large scanner o o OVERSIZED (Non-Scannable) NOTES: o Logs of various kinds BY: BEVERLY ROBIN VINCENT ~ MARIA WINDY o Other DATEð '-30 I Od-/SI . òtL BY: E¿OBIN VINCENT SHERYL MARIA WINDY III 1111111I11111111 DATE: V¡.~.())-/SI ~ Project Proofing "' l x 30 = þ 90 + Icr = TOTAL PAGES j()9 Scanning Preparation BY: ~~ROBIN VINCENT SHERYL MARIA WINDY DATE: /./5-03 IS/~ Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: In, PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: * YES _ NO BY: BEVER~INCENT SHERYL MARIA WINDY DATE: 1~/Úr03JSI ~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: _ YES _ NO BV: BEVERLV RO"N VINCE~1A WlNDV DATE;).~!,' ~ (~~~~I~~~~~;;~~L~~~ ~~~~~::SS)ECIAL ATTENTION IS REQUIRED ON AN INDMDUAL PAGE BASS· 11111111111111.11111 ReScanned (individual page [special attention] scalln/ng completed) 1III111111111111111 RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: ISI General Notes or Comments about this file: Quality Checked (done) 111111111I111I11111 '" 12/10102Rev3NOTScanned.wpd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission / DATE: Wednesday, July 27, 2011 TO: Jim Regg n it P.I. Supervisor l� SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A-02 FROM: Chuck Scheve KUPARUK RIV UNIT 1A -02 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry ;JCR - NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1A - 02 API Well Number: 50 029 - 20599 - 00 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS110727064540 Permit Number: 181 -071 -0 Inspection Date: 7/26/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1A -02 • Type Inj. W TTVD 5908 . IA 720 2980 - 2900 2890 P.T.D1 1810710 " ITypeTest SPT Test psi 1500 LOA 500 500 500 500 . + I Interval 4YRTST p/F P ' Tubing 1700 1700 1700 1700 Notes: Wednesday, July 27, 2011 Page 1 of 1 • Conocol~illips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: s"' t p~ EV~~~L.~ .~ APR 2 '~. 2010 .iaska nit & Gas Cans. Gommissiar Ancheuaq~ . ~~~~~- i Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRi.J).. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering.the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 21, 2010. The corrosion inhibitor/sealant was pumped April 1 thru Apri117, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Since ~.1 Perry 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 4/23/10 1A. 1 F. 1Q ~ 1Y PAD's Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-01 50029205900000 1810590 SF n/a 4" n/a 2.55 4/5/2010 A-02 50029205990000 1810710 SF Na 9" Na 4.25 4/6@010 1A-05 50029206270000 1811040 SF n/a 6" Na 4.25 4/7/2010 1A-08 50029203130000 1780400 SF n/a 10" n/a 13.7 4/17/2010 1A-09 50029206690000 1811520 SF n/a 4" n/a 2.55 4/2/2010 1A-15 50029207110000 1820170 SF n/a 4" n/a 2.55 4/4/2010 1F-15 50029210250000 1831490 21" n/a 21" n/a 4.25 4/1/2010 1 Q-02 50029212480200 2051420 22" n/a 22" Na 7.2 4/6/2010 1Q-03 50029212490200 1842330 27" n/a 27" n/a 3.4 4/8/2010 1Q-05 50029212330000 1842170 32" n/a 32" n/a 3.4 4/1/2010 1 Q-06 50029212240000 1842080 32" n/a 32" n/a 2.12 4/1/2010 1Q-10 50029212150000 1841980 32" n/a 32" n/a 3.82 4/1/2010 1Q-15 50029213080000 1850460 22" n/a 22" n/a 2.97 4/1/2010 1Q-16 50029213090000 1850470 25" n/a 25" n/a 3.82 4/1/2010 1Y-21 50029223870000 1931020 23" n/a 23" n/a 3.82 4/1/2010 1 Y-24A 50029223717100 2041250 26" n/a 26" n/a 3.82 4/1 /2010 1Y 28 50029223800000 1930890 28" n/a 28" n/a 5.52 4/1/2010 1Y-31 50029223810000 1930900 6'8" 0.65 24" 3/21/2010 5.52 4/1/2010 • MEMORANDUM To: Jim Regg ~ P.I. Supervisor FROM: John Crisp Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 12, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 A-02 KUPARUK RIV UNIT 1A-02 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv . Comm Well Name: KUPARUK RIV UNIT 1A-02 Insp Num: mitJCr090507150532 Rel Insp Num: API Well Number: 50-029-20599-00-00 Permit Number: 181-071-0 Inspector Name: John Crisp Inspection Date: 5/3/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wel] 1A-o2 Type Inj. W TVD 5908 IA 680 1700 1660 1655 ' P.T.D ]slo7lo TypeTest SPT Test psi 17ao OA alo aoo 390 390 Interval oT~R P/F P / Tubing 900 900 900 900 NOtes• 1 bbl pumpd for test. MITIA post IA seal tite repair. ,/ _ r i~ ~~ ~W Tuesday, May 12, 2009 Page 1 of 1 • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 4, 2009 • ~A`~ 2.00 ais~lca Oil & Oas Onrsa. ~ommissinst Anci~nrapa Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 2 ~- } ,~ ~~ ~ -~~~- ~, Dear Mr. Maunder: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 1A-02 PTD 181-071 (Sundry # 309-102) for repair of a production casing leak repair with Seal-Tite. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, s~/ i~~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures cc ~~~GD MAY ~ ~ ?Q49 STATE OF ALASKA - ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIO~~ka ~'~ ~` ~~~ Cans. C~rnrnissia~ lfnrhnra>tng 1. Operations Performed: Abandon ^ Repair Well 0 f Plug Perforations ^ Stimulate ^ Other Q Seal-rite treat Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ 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 ^ Exploratory ^ 181-071 3. Address: Stratigraphic ^ Service^ , 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20599-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 100' 1 A-02 8. Property Designation: 10. Field/Pool(s): ADL 25647 ~ Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8355' feet true vertical 6548' feet Plugs (measured) Effective Depth measured 7852 feet Junk (measured) true vertical 6143 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 112' 16" 112' 112' SURFACE 2802' 10-3/4" 2902' 2663' PRODUCTION 8237' 7" 8337' 6535' Perforation depth: Measured depth: 7552-7591, 7601-7648, 7652-7688, 7770-7712, 7796-7$50 true vertical depth: 5962-5990, 5998-6030, 6030-6058, 6066-6075, 6135-6174 Tubing (size, grade, and measured depth) 3-1/2" , J-55, 7782.15' MD. C sand patch 7728-7741 Packers &SSSV (type & measured depth) Packer =Baker FHL, Baker DB 7474 & 7753' C~ _ _ `~S\ ~ry-~ ` ~J~ 1 .Er c ) ` SSSV= Camco TRDP 1A=enc 1814' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin 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 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 r Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ 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: 309-102 contact MJ Loveland/ferry Klein Printed Name MJ Loveland Title WI Project Supervisor Signature one 659-7043 Date y.. ~ / ~71 1, ~ S ' ~ . cry Form 10-404 Revised 04/20~~ ~ ~ ~ ~ ~ ~ ~~~ ~ ~'i 7~Q~ Submit Origi ~`~~ 4 .~ I t... r ~ ~ L 1 A-02 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/08/09 04/21/0! 04/22/09 _SET 2.81" PX PLUG (4 x 1/4" ports 20" oal, 1 7/8" prong 1 3/8 fn, 89" oal) IN SBR t7 7447' RKB. pTESTED PLUG TO CONFIRM SET. PULLED DGLV FROM 4454' RKB, POCKET OPEN I LOADED IA WITH 9.6 PPG INHIBITED BRINE. DISPLACED LEADING EDGE OF 3 BBL FLOW-SEAL (SEALTITE) PILL DOWN IA TO 2821' MD WITH 71.5 BBLS DIESEL TAKING RNS FROM THE TUBING. 9.6 PPG BRINE LEFT IN TUBING, SET DV @ 4454' RKB. MITT 2000 PSI, PASSED. ATT LEFT BAILER BBL IN WELL. FISHED SAME. BAILED ATTEMPTED PULL PRONG. IN PROGRESS. 7419' S ..MITT -Passed, Pre T/I/O/OOA = 250/675/460/0. Pressured up to 2000 psi with 1 bbl diesel. ',Initial T/I/O/OOA = 2025/725/470/0, 15 min reading T/I/O/OOA = 2000/750/470/0 30 min (reading = 2000/750/470/0. 04/23/09 04/24/09 BAILED SCALE FROM 7421' TO 7424' SLM. PULLED 2.81" PX PLUG @ 7447' R_ KE FOR DHD. Rig up triplex to IA valve. Initial T/I/O/00 = SI/400/480/0. Pumped 1.8 bbl of diesel thru IA int T/I/O/00 = SI/2475/480/0, 15 min T/I/O/00 = SI/2350/480/0, 30 min T/I/O/00 = SI/2300/480/0, 45 min T/I/O/00 = SI/2300/480/0. Represuured to 2475 with 11.6 gallons of diesel, T/I/O/O = SI/2475/480/0, 15 min T/I/O/00 = SI/2400/480/0, 30 min T/I/0/00 = SI/2350/480/0, 45min T/I/O/00 = SI/2340/480/0, 60min T/I/O/00 = SI/2300/480/0, 75min T/I/O/00 = SI/2300/480/0, 90 min T/I/O/00 = SI/2250/480/0, 105 min T/I/O/00 = SI/2220/480/0, 120 min T/I/O/00 = SI/2150/480/0 .Repressured to 2500 psi with 7.8 gal of diesel follow up in A.M. Total bbls pumped 2.3 bbls. Pumped 38.75 gallons of diesel thru IA valve. Pre T/I/O/00 = 0/1450/480/0, start T/I/O/00 = 0/2600/480/0, 15 min T/I/O/00 = 0/2475/480/0, 30 min T/I/O/00 = 0/2425/480/0, 45 min T/I/O/00 = 0/2375/480/0, 60 min T/I/O/00 = 0/2325/480/0, 75 min T/I/O/00 = 0/227/480/0, 90 min T/I/O/00 = 0/2240/480/0, 105 min T/I/O/00 = 0/2200/500/0, 135 min T/I/O/00 = 0/2125/500/0, 165 min T/I/O/00 = 0/2050/500/0, 195 min T/I/O/00 = 0/1975/500/0. Repressured to 2500 psi with 15.5 gal of diesel. Int T/I/O/00 == 0/2500/500/0,30 min T/I/O/00 = 0/2400/500/0, 60 min T/I/O/00 = 0/2300/480/0, 90 min T/I/O/00 = 0/2240/490/0, 120 min T/I/O/00 = 0/2150/490/0, 150 min T/I/O/00 = 0/2100/480/0, 180 min T/I/O/00 = 0/2050/480/0, 180 min T/I/O/00 = 0/2000/480/0. Repressured to 2500 psi with 11.6 gal of diesel. Int T/I/O/00 = 0/2500/480/0, 30 min T/I/O/00 = 0/2425/480/0, 60 min T/I/O/00 = 0/2350/480/0, 90 min T/I/O/00 = 0/2300/480/0, 120 min T/I/O/00 = 0/2240/480/0, 150 min T/I/O/00 = 0/2175/480/0, 180 min T/I/O/00 = 0/2125/480/0. Repressured to 2500 psi with 19.3 gal of diesel.total diesel used today 2.02 bbl • 1 A-02 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/25/09 04/26/09 05/02/09 05/03/09 Intial T/I/O/00 = 0/1300/480/0. Pumped 46.5 gal of diesel thru IA to push seal-tite pill, T/I/O/00 = 0/2500/480/0, 30 min T/I/O/00 = 0/2400/480/0, 60 min T/I/O/00 = 0/2300/480/0, 90 min T/I/O/00 = 0/2200/480/0. Repressured to 2500 psi with 15.5 gal of diesel,T/I/OlOO = 0/2500/480/0. 120 min T/I/O/00 = 0/1950/480/0. Represuure to 2500 psi with 7.7 gal of diesel, T/I/O/00 = 0/2500/480/0, 30 min T/I/O/00 = 0/2300/480/0, 60 min T/I/O/00 = 0/2200/480/0, 90 min T/I/O/00 = 0/2125/480/0, 120 min T/I/O/00 = 0/2025/480/0, 150 min T/I/O/00 = 0/1950/480/0, 180 min T/I/O/00 = 0/1900/480/0, 210 min T/I/O/00 = 0/1800/480/0, 240 min T/I/O/00 = 0/1750/480/0, 270 min T/I/O/00 = 0/1700/480/0. Repressure to 2500 psi with 31 gal of diesel, total diesel pumped today 2.0 bbl. T/I/O/00 = 0/2500/480/0, 30 min T/I/O/00 = 0/2400/480/0. Follow up in A.M. Intial T/I/O/00 = 0/1550/480/0. Rig up to IA with triplex. Pumped 34.9 gallons of diesel, T/I/O/00 = 0/2500/480/0, 30 min T/I/O/00 = 0/2450/480/0, 60 min T/I/O/00 = 0/2450/480/0, 90 min T/I/O/00 = 0/2450/480/0. Re pressured to 2500 with 3.8 gal of diesel. Total diesel toda .9 bbls. T/I/O/00 = 0/2500/480/0. IA pressure held ~ 2500 psi for 8 hours, bled down tol', 1500 psi. Final T/I/O/00 = 0/1500/480/0. Pre State Wittnessed MITIA -passed. Initial T/I/O/OOA= 900/2350/420/0. Pressured up the IAA to 2500 psi. with 5 gal. of diesel, T/I/O/OOA= 900/2500/420/0. 15 min. T/I/O/OOA= 900/2500/420/0. 30 min. T/I/O/OOA= 900/2500/420/0. Bled down the IA. Final T/I/O/OOA= ' 900/1000/420/0 MITIA - (passed), State Witnessed (John Crisp), Initial T/I/O/OOA= 900/680/410/0. Pressured up IA to 1700 psi using 1 bbl of diesel. Start MITIA, T/I/O/OOA= 900/1700/400/0, 15 min T/I/O/OOA= 900/1660/390/0, 30 min T/I/O/OOA= 900/1655/390/0. Bled IA down. Final T/I/O/OOA= 900/720/400/0. Summary Pumped 3 bbls Seal-Tite to Casing Leak at 3030. Brought well online. MITIA passed. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Conoco Phillips Alaska KRU 1A-02 05/03/09 Coffee/Ives John Crisp Packer Depth Pretest Initial 15 Min. 30 Min. Well 1A-02 T pe Inj. W TVD 5,908' Tubing 900 900 900 900 Interval O P.T.D. 1810710 Type test P Test psi 1500 Casing 680 1700 1660 1655 P/F P Notes: MITIA post IC Seal-Tite repair OA 410 400 390 390 Well Type tnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT KRU 1A-02 05-03-09.x1s To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road ,~~~~~; ~ ~ ~ ~, ~ ~ Suite C Anchorage, AK 99518 Fa~c (907j 245-8952 1) 2) Signed Print Name: :Leak Detection - WLD 01-Fetr09 1 A-02 E~ 50.0290599-00 Corrected API # on Las files only a, ,/ Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907}245-8951 FAx: (907}245-88952 C_\Documents and Settings\Owner\Desktop\1Yansmit_Conoao.docx ~,~~w~~i ~ ~r n ~~~ ~ ~~~ ALASSA OIL A1~TD GA,S C01~5~R~ATIOAT COMr-IISSIOrT MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska Inc. PO Box 100360 ~~-~~1.~ MAC ~~~ ~~ ~~~ Anchorage AK 99510-0360 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, Kuparuk River Oil Pool, lA-0 Sundry Number: 309-102 Dear Ms. Loveland: ~~~~ ~~ ~~ 2 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, ~. - .., --y ~- .,.,< -- Daniel T. Seamount, Jr. ~ Chaix DATED this ~3day of March, 2009 Encl. • • ConocoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 16, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~1.J ~IAH ~ F3 2009 ~iasaca Oil ~ gas ~on~. iaoaurnission ~nci~ora~e Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1A-02 PTD 181-071 production casing leak repair with Seal-Tite. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, i~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures a~ ~iv~ ~ •3 ~ STATE OF ALASKA ~ ~! ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 1 ~~~~ 2~~'f APPLICATION FOR SUNDRY APPROV 7 a Oil ~e Oas ions. ol~r~ission 20 AAC 25.280 Anchtlr~tte 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ ~ Other Q Alter casing ^ Repair well ^/ Plug Perforations ^ Stimulate ^ Time Extension ^ Chan e a roved ro ram g pp p g ^ Pull Tubing ^ Perforate New Pool ^ Seal-Tile in PC Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 181-071 ' 3. Address: Stratigraphic ^ Service Q , 6. API Number: P. O. Box 100360, Anchora e; Alaska 99510 50-029-20599-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Required? YeS NO ^~ 1A-02 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25647 RKB 100' Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MU (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8355' ~ 6548' 7852' 6143' Casing Length Size MD TVD Burst Collapse CONDUCTOR 112' 16" 112' 112' SURFACE 2802' 10-3/4" 2902' 2663' PRODUCTION 8237' 7" 8337' 6535' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7552-7591, 7601-7648, 7652-7688, 7770-7712, 7796-7850 5962-5990, 5998030, 6030-6058, 6066-6075, 6135-6174 3-1 /2" J-55 7782.15' Packers and SSSV Type: Packers and SSSV MD (ft) Packer =Baker FHL, Baker DB 7474 & 7753' SSSV= Camco TRDP 1A=enc 1814' 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 Operations: April 1, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Perry Klein/MJ Loveland Printed Name MJ Loveland Title: Well Integrity Project Supervisor Signature Phone 659-7043 Date ` j ~ G Commission Use Onl Sundry Number. Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test `~ r-~ ~ Location Clearance ~ „ ~ i ^ ~~- ~' -' ~- l awl' Other: Subsequent Form Required: ~~ ~'=~ ~ ~~~ ~" ~~ L~D9 APPROVED BY ~ I ~ ~ / Approved by: OMMISSIONER THE COMMISSION Date: / Form 10-403 Revised 06/2006 °,~ ~-~ ~ ~~~i~~uplicat~= ~, /~•.~~ • 1A-02 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska, Inc. Kuparuk Well 1A-02 PTD 181-071) Sundry Notice 10-403 Request 16-Mar-09 Purpose: The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to repair the 7" production casing leak at 3002' with Seal-Tite Sealant. History (if needed): Known 7" production casing leak at 3002' was originally repaired with Seal-Tite in August 2006. The sealant broke down in October of 2008 and the treatment needs to be repeated Proposed Plan: 1. Circulate IA with 9.6 ppg brine 2. Siphon 3 bbls Flo-Seal into IA 3. Pressure up IA as needed to 2500 psi and hold for 8 hours to cure 4. MITIA 5. Return well to injection 6. State Witnessed MITIA 7. Submit 10-404 • • ti~~ ~ d o ~ D SA RAH rALIN, GOVERNOR CO1vSE8Q~A,iI01~ ~ ~SS~ 333 W 7th AVENUE, SUITE 100 •~ A~i l~o~~`•••~~~11~~•iii ----777 0l` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John Peirce Wells Engineer ConocoPhillips Alaska Inc. PO Box 100360 a,yd4~'x`~~~- ('~~`~~ ~'' `~ ~~ Anchorage AK 99510 ~~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 1A-02 Sundry Number: 309-075 Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager) . As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair DATED this ~ day of March, 2009 Encl. ~~o°` ~~~o°~ ~v ~-'~~ ~i~~® ~v~ ~~~ ~ ,~(j(}9 ST~E OF ALASKA • A~ SKA OIL AND GAS CONSERVATION COMMISSION ~~ ~~~~~~ ~~L~:~'I~OR SUNDRY APPROVAL Anchorage 20 AAC 25.2so ~~~ ~a?-O9 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repair well ^ Plug Perforations Stimulate ^ repair leaky patch Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Poo! ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ .181-071 - 3. Address: Stratigraphic ^ Service 0 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-20599-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Requires? YeS ^ NO ^~ 1A-02 - 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ~„~.ir~r ADL 25647 - RKB 100' - 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 TVD (ft): Plugs (measured): Junk (measured): 8355' - 6548' - 8242' 6464' 7902' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 112' 112' SURFACE 2902' 10-3/4" 2902' 2663' PRODUCTION 8337 7" 833T 6535' Perforation Depth MD ( 7552'-7591' Perforation Depth TVD (ft): 5963'-5990' Tubing Size: Tubing Grade: Tubing MD (ft): 7601'-7648', 7652'-7688', 7700'-7712', 7796'-7850' 5998'-6030', 6033'-6058', 6067'-6076', 6135'-6174' 3-1/2" J-55 7782.15' Packers and SSSV Type: Packers and SSSV MD (ft) Baker Hyd pkr, Baker Retriev. Pkr @ 7474', 7753' Camco TRDP 1A-ENC @ 1814' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat March 15, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~~ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Printed Name John Peirce Title: Wells Engineer Signature ~~ "- Phone 265-6471 Date Z Z.~ "© Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness - Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^~ - ^ ~4-~`~~.1. ~,Ia` ~~j Other: ~~ Subsequent Form Required: ~'\~ iV ~`~>~;~A,~`y ~~ H~<r ~, 12 m ~~ LQ,:., ~i APPROVED BY ~ Z Approved by COMMISSIONER THE COMMISSION Date: -_ Form 1 3 R ec~Q6/200 Submit in Duplicate ~ a ~ ~~~ t ~, >~ U U 1A-02 Proposed Leaky Tubing Patch Replacement Procedure In 2008, PWI data suggested that a tubing patch in 1A-02 was failing. A 10/9/08 IPROF was run that showed 100% of PWI now enters the C sand through a leaky retrievable tubing patch which was set 3/7/06 at 7728 - 7742' RKB to isolate PWI from the C sand. The leaky patch at 7728' will be pulled and a new retrievable straddle patch will be installed to isolate PWI from the C sand, and to convert 1A-02 to `A sand only' injection. Procedure: Slickline Latch and pull the leaky tubing patch at 7728' RKB from the well. 2. Brush & flush the 3.5" tubing at 7690 - 7770' RKB in the area where a new tubing patch is to be set. E-line Install a new retrievable straddle patch assembly: 3. RIH with a 2.72" run OD straddle packer. Set the packer with element at 7747' RKB (+/-1'). This location puts the packer at the mid-point of the 3-1/2" pup joint (6.10' OAL) immediately below the 2.75" ID AVA BPL. Slickline: 4. RIH with a 2.72" OD straddle packer, ~20' spacer pipe, and Anchor Seal assembly. Sting and latch into lower packer at 7747' RKB. Set the top packer at 7727' RKB to complete the straddle patch at 7727 - 7747' RKB (seal to seal). Set a test plug in the upper packer at 7727' RKB and PT the tubing to 2500 psi to verify packer integrity. Pull the test plug. RD. Return 1A-02 to PWI as an `A sand only' injector for injection testing. JWP 2/24/2009 Conocot'hiltips s..,. ~n,.z, eP%,; Tuhing GAS LIFT. 4.454 GAS LIFT. 4.677 GAS LIFT, 5,2d6 GAS LIFT. 5.6' S GAS LIFT, _ s,sa3 GAS LIFT, __ 6.295 GAS LIFT, -_ Tdm S6R, 7,447 - PACKER, 7,474 -- cMrsoz, 7.552 7,7oo-7,nz cldr soz, z7oo PATCH. 7.]28 - COLLAR, 7,737 NIPPLE, 7.741 - LOCATOR, 7.752 PACKER, ],]53' SRE x0, ],757 NIPPLE, 7,770 xo, 7.7so - SOS, ],]61 IPERF,- 7,796-7,850 FISH, ],902- FISH, ],902- PRODUCTION. 0-8,33] TD. 8,355 KU P ~ 1 A-02 Vell Attribut 'ellbore APUUWI es Field Name jMax Well Status Prodllnj Type lncl (°) Angle 8 MD TD MD (ftK8) Act Bhn (kK6) 5002920599170 KUPARUK RIVER UNIT INJ PWI 49.00 I 7,200.00 8.355.0 ment H2S (ppm) Annotation End Data Date ~KB-Grd (ft) Rig Release Dat SSV: TRDP 0 ( 7/1!2008 Last WO: 12/25/1986 _._ 39.01 7/2/1981 nnotation Dep[h (ftK6) Entl Data Annotation (End Date ast 7aq ELMD , ( 7,840.0 '. 10/9/2008 Rev Reason LEAK FOUND @ 3030' '. 2/22009 :asing Strin gs asing Description String 0... 'String ID ... Top (ftK8) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd ONDUCTOR 16 15.063 0 0 112.0 112.0 65.00 H-00 asing Description ;String 0... 'String ID ... Top (kK8) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd URFACE 10 314 ~ 9.797 0.0 2,902.0 2,662.5 45.50 K-55 asing Description String 0... ~iString ID ... Top (ftK8) Set Depth (f... Set Depth (ND) ... ( String Wt... String ... String Top Thrd Top Depth (ND) ~ Top Inc! Top{ftK6) (ftK6) (°) Item Description Comment ID in) 7,813.5 1,784.8 25.27 SAVETY VLV Camco TRDP 1A-ENC 2.813 7,447.4 5,890.1 46.53 SBR Baker SBR 2.813 7,473.6 5,908.1 ~ 46.26 PACKER Baker Hyd Set Packer Pinned 70,000N 2.891 7,549.6 5,960.9 45.38 1 Blasi Joint ,Tubing w/Blast Rings WLM 7547-7717 2.992 7,737.0 6,093.3 44.63 COLLAR ~XO Collar 2.992 7,741.3 6,096.3 44.59 NIPPLE ~iAVA Bottom NOGG Ported Landing Nipple w/Sleeve 2.750 7,752.1 6,104.0 44.48 LOCATOR iLOCator Space Out - 2.875 7,753.0 6,104.6 44 47 PACKER Baker 2 7/8" X 7" DB Wireline Set Permanent Packer @ 7734 WLM on 3.250 i 72/21/7986 7,756.7 6,107.2 44.43 SBE XO ~ Baker Seal Bore Extension w/XO 3.5" to 2 7/8" 2.875 7,769.8 6,116.6 - - 44.30 NIPPLE ',Camco D No-Go Nipple 2.250 7,779.8 6,123.6 44.20 X0 CROSSOVER 2 7/8" TO 35" 2-441 _ 7,781.5 6.124.8 44.19 SOS (Otis Shear Out Sub ' _ 2.992 O_ ther I n Hole ( Top Depth/ wrelin e retrievable plugs, valves, pumps, fish, etc.) _ _ (TVD) Top Inc! Top (ftK6) (ftK6) () i Description Comment RunDt ID (inj_ 7,728.0 6,087.0 ~ 44.72• PATCH 9.5"K3 PACKER/EXTENSIOWAVA SEAL STINGER ASSY 3/7/2006 ', 1.600 ((173.5" OAL, 1.6" ID), SET DEPTH 7742' RKB. SET i SLIPSTOP ABOVE EXTENSION 3/7/2006 7,902.0 6,271.6 42.00 FISH Vann Gun, 340.14" long - 7/1/1981 0.000 7,902.0 6,211.6 42.00 FISH Lock Key from AVA IBP left in hole @ 7902' 70/31/1999 0.000 ' Perfora .. tions _.. _ _. _ _;~snM _ - --___--.. __._...- Top RVDI Btm (ND) Dens I ' T_op (ft KB) Btrn (ftK6) (flKe) (ftK8) Zone ~ Dale (h.. Type Comment __ 7,552.0 7,591 0 5 962.5 5,989.9 C-4, 1A-027/1/1981 4.0 IPERF Squeezed & Repeded; Vann Gun 7,552.0 7,577.0 5,962.5 5,980.1 C4, 1A-02 ; 72!23/1986 12.0 RPERF 120 deg. Ph; 5" HyperJef II 7,601.0 7,648.0 5,998.0 6,030 4 C4, C-3, 1A-02 7/1!1987 4.0 IPERF Squeezed 8 Reperfed; Vann Gun 7,601.0 7,626.0 5,998.0 6,015.2 C-3, 1A-02 12/23/7986 12.0 RPERF 120 deg. Ph; 5" HyperJet II 7,652.0 7,688 0 6.033.2 6,058.3 C-2, 1A-02 12/23/1986 12.0 RPERF '.120 deg. Ph; 5" HyperJet II 7,654.0 7,688.0 6,034.6 6,058.3 C-2, 1A-02 17/7!1981 4.O, IPERF Squeezed & Repented; Vann Gun 7,700.0 '' 7,712.Oi 6066.8 6075.S~C-1, UNIT B, 7/1!1981 4.O~ ~ IPERF 'SqueezedBReperied: Vann Gun i,1 A-02 '', 7,796.0 %,850.0 6,735.3 G,1744~A-S,A-4, to-02 7/1/1981 I 40~ IPERF 720 deg-Ph; Vann Gun Cement S ueezes '~, Top Depth Btm Depth (ND) (NO) Top (RKB) ~., Btrn (RKB) (ftK8) (RKB) Description I Start Date Comment _ __ ' _7,552.O i 7,591.0' 5,962.5 5,989.9Cement SQZ 17/1/7981 RPERFS In 1986 ~ 7,601.0 1 7,648.0 5998.0 6,030.4ICement 502 '~7l1l1981 RPERFS in 1986 - _- - 7,6540 7,654.0' 60346 6,034.6 CementSQZ 7!1/19A1 iRPERFS In 1986 7,700.01 7,712.0, 6,066.8 6,075.8 CementSOZ 7/1/1981 RPERFS in 1986 Notes: General & Safey - - Ena Date r__ Annotaton _ _ _ - _ 11/tA/2001 (NOTE: WAIVERED WELL-TxIA Communication 8/31/2005 -TNOTE TUBING LEAK FOUND w/PONYTAIL @ 7739' 8/14/2006 ~~NOTE: IA leak @ 3025' plugged with Sealtite Flo-Seal Sealant 8/182008 (NOTE: VIEW SCHEMATIC w/ALaska Schematic9.0 2/1/2009 - (NOTE: LEAK FOUND @ 3030' ON TECWELL LDL (Mandre l Details Top Depth Top I Port (TVD) Inc! ', i OD Valve Latch S¢e TRO Run Stn p( To ft ) (RKB) (°) Make ~ Model (in) Sere TYPe Type (in) (psi) Run Data Comm... K6 1 3,063.2 2,772.5 47.00 Camco,KBUG 1 Gas Lift DMY BK-2 0 0 0 17/19/1991 2 4,453.5 3,714.5 46 60 Camco KBUG 1 Gas Lift DMY BK-2 0 0.0 17/19/1991 3 4,877.0 4,009.345.31;Camco KBUG 1 Gas Lift DMY BK-2 0 0011/1917991 4 5,245.6 4,273.1 43.14~Camco KBUG 1 Gas Lift i,DMY BK-2 0 0.011/19!1991 5 5,614.61 4,546.4 41.43~CamcoKBUG l (Gas Lift DMY BK-2 0 0.0 11/19/1991 6 5,982 9' 4,824.1 41.00 Camco •KBUG 1 Gas Lift DMY BK-2 0 0 0 11/19/1991 7 6,294.7 5,061.6 39.05 Camco jKBUG 1 Gas Lift DMY BK-2 0 00 11/19!1991 ~' 8 6,659.2 5,340.1 42.30 Camco •KBUG 1 Gas lift DMY BK-2 0 - 0.0 11/79/1991 9 7,029.5 5,608.8 45.81 Camco KBUG 1 Gas Lift DMY BK-2 0 0.0 12/2511986 10 7,400.6 5,857.9 46.99 Otis LBX 1 112 Gas Lift DMY RM 0 0.0 8/1512006 11 7,509.4 5,932.7 4548iCamco KBUG 1'INJ IIDMY BEK 0 0.0 10!4!1999 1 A-02 (PTD 181-071) Report Of ~ed Seal-Tite Treatment • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, October 20, 2008 1:25 PM Page 1 of 2 To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF1 DS Lead Techs; CPF1 Prod Engr; Kovar, Mark Subject: 1A-02 (PTD 181-071) Report Of Failed Seal-Tite Treatment Attachments: 1A-02 Wellbore Schematic.pdf; 1A-02 TIO Plot.ppt .~ Tom/Jim, Kuparuk water injector 1A-02 (PTD 181-071) was reported to have a potentially compromised IAxFormation Seal- Tite treatment on 9/26/08. Subsequent diagnostics have confirmed the failure of the treatment and the well has been shut in. The well has a current T/IA/OA of 887/378/610 and will be added to the Monthly Failed MIT report. ConocoPhillips intends to conduct additional diagnostics and submit a 10-403 to repair or seek administrative approval to continue injection. Attached is an updated 90 day TIO plot and a Wellbore schematic. «1A-02 Wellbore Schematic.pdf» «1A-02 TIO Plot.ppt» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 .,E ~' 1~~, ~'°i ' .~~tl~~ ~~' L~js'w ~'~k~.~;~.a From: NSK Problem Well Supv Sent: Friday, September 26, 2008 3:25 PM To: 'tom.maunder@alaska.gov'; 'jim.regg@alaska.gov' Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 1A-02 (PTD 1810710) Report of suspected failed Seal-Tate treatment Tom, Jim The Seal-Tite treatment on Kuparuk water injector 1A-02 (PTD 1810710) is suspected to have broken down. The treatment was used to repair the IAxFormation leak that was identified in 08/2006. The current TIO is 900/600/620. The current plan will be an attempt to reactivate the Seal-Tite treatment with the well on injection. The Seal-Tite treatment is pressure activated and by leaving the well on injection, it will help alleviate the cooling thermal effects while trying to re-energize the sealant. If the treatment can not be reactivated the well will be shut in while evaluating for future repair. ConocoPhillips will update the AOGCC with the results. 12/ 10/2009 1 A-02 (PTD 181-071) Report Of ~ed Seal-Tite Treatment • Page 2 of 2 Attached is a 90 day TIO plot and wellbore schematic. File: 1A-02 schematic.pdf» « File: 1A-02 90 day TIO plot.jpg » Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 12/ 10/2009 ~olZ~~c~, IAP 1400 1200 1000 a $00 600 400 200 D OAP TII/O P I of -1 A-02 200 150 a E a~ 100 Y O L v 50 01-Aug-08 01-Sep-08 Date 01-Oct-O$ 0 I~~ _ ~_ ~~ ~P ~ 1A 02 CC)t'~C3Ci7F~F1tI~E~S ( I~ `, 'well Attributes _ __.. ( . 1„°_ i~ ~ ~ Wellbore APl/UWI Fieltl Name Well Status Prod/inJ Well Type Incl (°) MD (RKB) TD (max) (ft... / 500292059900 KUPARUK RIVER UNIT INJ PWI 49.00 7,200.00 8,355.0 Comment H2S (ppm) Data Annotation End Date KBGrd (R) Rig Rel se Data "' - TRDP 0 7/1/2008 Last W0: 12/25/1986 39.01 7/2/1981 well Contra. -1A-02 10110/2W6753 d2 AM Sehema[ic-~a~ai ~_-- - Annotation Depth (RKB) End Date Annotation End Date Last Tag: 7.840.0 10/9/2008 Rev Reason: ELMD TAG 10/102008 Casin Strin s -- - ' Casing Description String 0... String ID . Top (kKB) Set Depth (f... Set Depth (ND)... String WL.. Strhlg Gr... - Str iy icy i1~1J wrong 1 - . ~-~ ~ CONDUCTOR 16 15063 0.0 1120 112.0 65.00 H-40 _ Tub rig Hangee_ _-"_ -'. ;Casing Description String 0... String lD ... Top (RKB) Set Depth (f... Set Depth(ND)... String Wt... String Gr... String Top Thrd ~•=••., (SURFACE 103/4 9.797 0.0 2,902.0 2,662.5 45.50 K-55 ~. ~ ~~ ( Casing Description String 0... String ID ... lop (TtKB) Set Depth (f... Set Depth (ND) ... String Wt... String Gr... String lop Thrd ~ ~ ' PRODUCTION 7 6.156 0.0 8.337.0 6.534.8 26.00 K-55 ,; ,r° ~a; Stnn~c s Tubmg w - _ _ T b g Desc pt n 61 g O String ID _. Top (ffKD) Sef Depth (f Set D pth (ND) -. 51 g Wt.. SS g ..String T p Thrd 0112 ~ SSSV 1 914 - ~>• TUBING 3 12 ', 2 992 3 5x7.875"x,i 5' ~ __ l_-..__ -0 6 _.. 7 782 1 6 125.3 9 20 ~ ._._ _ -.___- _ J 55 EUE8rdABMOD ' ~- -- . . - Completion D_ etails --- ~~ -~- ~ - - ---~~ SURFACE. ~ iop DePih 0.2.902 (TVD) Top - - W Top (RKB) (kK8) Incl (°) ttem Description Comment ID (in) GAS LIFT, 3,~ ~.w 1,813.5 1,784.8 2527 SSSV Camco TRDP 1A-ENC 2.81; ' j 7,447.4 5,890.1 46.53 SBR Baker SBR 2.81; GAS LIFT, 4,asa ~~ ~~ 7,473.6 5,908.1 46.26 PACKER Baker Hyd Set Packer Pinned 70,000# 2.89' _ -- ~„ 7,549.6 5,960.9 45.38 81asi Joint Tubing wBlast Rings WLM 7547-7717 2.99: GAS LIFT, ~-~'~ t ~ ~ 7,737.0 6,093.3 44.63 COLLAR XO Collar 2.99% 4.877 ._ _ _ 7,741.3 6,096.3 44.59 NIPPLE AVA Bottom NOGG Poned Landing Nipple w/Sleeve 2.751 GAS LIFT, f ` v~r 7,752.1 6,104.0 44.48 LOCATOR Locator Space Out 2.87: 5,246 -~~ 7,753.0 6,104.6 44.47 PACKER Baker 2 7/8" X 7" DB Wireline Set Permanent Packer @ 7734 WLM on 3.251 12/21/1986 GAS LIFT, _ T' -~ 5,616 i_`~ 7,756.7 6,107.2 44.43 SBE XO Baker Seal Bore Extension w/X0 3.5" to 2 7/8" 2.87! 7,769.8 6,116.6 44.30 NIPPLE Camco D No-Go Nipple 2.251 GAS LIFT, 5,993 ~~'~ 7,779.8 6,123.6 44.20 XO CROSSOVER 2 7/8" TO 3.5" 2.44' 7,781.5 6,124.8 44.19 SOS Otis Shear Out Sub 2.99. GAS LIFT, 6.~ -~ ' _.T,. -__... .._ Other In Hole (Wireli - ne retrievab _ le plugs, valvesr pumps, fish,_etc•) ___ _ _,__ __ GAS LIFT, 7.c3o GAS LIFT. 7,401 SBR, 7,447 'ACKER, 7,474 INJECTION. 7,509 RPERF, 7,ssz-7,sn ~ . IPERF, _- 7,552-7,591 CMT SOZ, 7,552 RPERF, 7,601 7,626 IPERF, 7.601-7.648 ' CMT SOZ. 7,601 CMT SOZ, 7,654 RPERF, 7,652-7.668 IPERF, - 7,654-7,666 IPERF. 7,700.7.712 ~_ , CMT SOZ, 7,700 ~ ~ - Top Depth -~- - - (ND) Tap ~ ~~ Top (RKB) (RKB) Incl (°) Descrl - .~ 7,728.0 6,087.0 44.72 PATCH ~ ~ L~- _ 7,902.0 6,211.6 42.00 FISH 7,902.0 6,211.6 42.00 FISH Perforations Tap (ND) Btm Top (RKB) Btm (RKB) (RKB) (R . .~~•. ~-.~r 7,552.0 7,591.0 5,962.5 5, _ u` ~ 7,552.0 7,577.0 5,962.5 5, Cement Squeezes (RKB( PATCH, 7,728 COLLAR, 7.737 NIPPLE, 7,741 ~- I LOCATOR, ' 7,752 _. - PACKER,7,753 :~% -~ SBE XO, 7.757 ' r !`~ NIPPLE. 7,770 f _' 1 x0, 7.760 "11 sos, 7,791 - IPERF. , 7,7ss.7,eso FISH, 7,902 FISH, 7.902 - PRODUCTION, 0.8,337 TD. 9,355 Date Camco Comment 3.5" K3 PACKER/EXTENSION/AVA SEAL STINGER f ;173.5" DAL, 1.6" ID), SET DEPTH 7742' RKB. SET SLIPSTOP ABOVE EXTENSION 3/7/2006 Zona I Data TxIA Comment OD Serv I TYPe TYPO (in) TRP Run DMV lA-OZ (PTD 1810710) Report of ~ected failed Seal-Tite treatment ~ Page 1 of 1 Regg, James B (DOA) mm~_~m _ ~, From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, September 26, 2008 3:25 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 1A-02 (PTD 1810710) Report of suspected failed Seal-Tite treatment Attachments: 1A-02 schematic.pdf; 1A-02 90 day TIO plot.jpg ,~-~ Tom, Jim The Seal-Tite treatment on Kuparuk water injector 1A-02 (PTD 1810710) is suspected to have broken down. The treatment was used to repair the IAxFormation leak that was identified in 08/20 6. The current TIO is 900/600/620. The current plan will be an attempt to reactivate the S I-Tite treatment with the well on injection. The Seal-Tite treatment is pressure activated and by eaving the well on injection, it will help alleviate the cooling thermal effects while trying to re-energize the sealant. If the treatment can not be reactivated the well will be shut in while evaluating for future repair. ConocoPhillips will update the AOGCC with the results. Attached is a 90 day TIO plot and wellbore schematic. «1A-02 schematic.pdf» «1A-02 90 day TIO plot.jpg» Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 12/10/2009 KRU 1A-02 PTD 181-071 9/26/2008 TIO Pressures i • ;~~ ~P ConocoPhillip~ ~' ~ . , ~w A '~t,n;l. :1"' ~ J API/UWI 1 A-02 ' / 5002920599 KUPARUK RIVER UNIT INJ 49.00 8.355.0 Comment H2S (ppm) Date Annotati... End Date KB-Ground Distance (ft) Rig Release Date '~~ 'SSSV: TRDP 0 7/1/2008 LastWO: 12/25/1986 39.01 7/2/1981 Well Conlin. - 1A-02 BI19I2C06 11'.Sa'.42 AM schematic. ~ Ac~ual --Ann station Depth (ftKB) End Date Annotation End Date __ Last Tan: 7.655.0 1/ 13/2007 Rev Reason 8.1 FORMAT UPDATE 8/18/2008 Casing btnngs t ion I ~ O O Tut gH g _ ~ p ion I 0 1 ' B) ToPO et L.. , Set De )(n-- W .~~ ToP Connect Ion 28 ,.; ~._. ~ _,,,_ ~ ~SU RFACE 03/4 9( 797 O 2 9020 2`662.5 45. 0 K55 .a ,. ~ ~ y Des n OD n) ( ID (In ) To ftKB P l 1 Set De th ft... p ( Set D pth TVD ft... ( 11 Wt Ibsl 1 Gro Ion op On ' ~ ~ F' DUCTION _ 7 6.156 00 8,337.0 6534.8 26.00 K 55 Tubing Strings _ ~~rv~ -- ~y I'- ~ - ~ c ~ ten ' ~"- T I y D p OD (i I I ID (n) Top I(f 5 t D pth IftK.. Set Deptl (TV D) (ftKB) Wt (Ibslft) G d T p C ,.~ o-nz ~IUksING I 3912 __ ., j 2.992 L -D.6 I 7,7821 _ 6,125.3 9.20 J-55_EULo,u.a6Po~uL _ _ sssv,1,614 SURFACE, 0-2,902 GAS LIFT, ~~ ' 3,Ofi3 ~~ GAS LIFT, ~~ 4,454 GAS LIFT, ~ ~~ 4,877 -~~..- _ GAS LIFT, 5,615 GAS UFT, 5,883 GAS LIFT, 6,295 GAS LIFT, 6.659 GAS LIFT, 7.030 GAS LIFT, ],401 SBR, 7,447 PACKER, 7,474 RPERF, ],552-7,577 IPERF, 7,552-],591 RPERF, 7 601-7,fi26 IPERF, 7.601-7.648 RPERF, 7,652-7,688 IPERF, 7.654-7.688 IPERF, 7.700-7.712 COLLAR, 7,737 NIPPLE, 7,741 TUBING Space Out Assembly, 7,750 LOCATOR, 7,752 'ACKER, 7,753 SSE, 7,757 NIPPLE, 7,770 XO, 7,780 SOS, 7,781 IPERF, 7,796-7,850 FISH, 7,902 FISH, 7,902 PRODUCTION, _a ~_ . 1 f .~ -_-_, L-_~ 1 _~~ ~oarx.m I ~~ ~.`~ _. ~y ' I L i _. ;."1 1A-02 7,796.0 7,650.0 6,135.3 6,174.4 IPERF A-5, A-0, 1A-02 4.0 7/1/1981 120 deg. Ph; Vann 'Cement Squeezes __ Notes: General 8 Safet E d Uata Annotation 1 1/18/201 O~OTE: WAIVERED WELL - T x IA Communication )etails ~ Sel Depth - -- - -Port (ND)__~._..... ~ ~ Valve Latch Size ~RO Run (ftKB) Make M d I OD (in) Type Type (1n) (psQ Run Date Comment 1 1 1 D 1111 7.509.41 6.125.31Camco IK9UG I 11DMY IBEK I 01 0.0110/4/1999 IDPHF I Perforations _ ._.. _ __. -.r _-..__ Top Btm Shot Top Btm (ND) (TVO) Dens (ftKB) (ftKB) (ftKB) I (ftKB) TYPe Zone (sho... Date Comment ~~~~m~~~~r~ ~: `~ :''; Schlumberger -DCS 2525 Gambeli Street, .Suite 400 Anchorage, AK 99503-2838 ATTN: Beth t `<° p s a`r,°~'s,s n ~ ~ ,C E r,, i ~~~fr Well Job # Log Description N0.4914 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/14/08 1 L-23 - 12097405 SBHP SURVEY / 07/17/08 1 1 2A-17 11975793 PRODUCTION PROFILE 9 - /C © p L 09/10/08 1 1 3G-25X 12080437 LDL ~ - rj L((o 09/21/08 1 1 2C-04 12100444 INJECTION PROFILE C C ( 09/14/08 1 1 3M-13 12096541 LDL - (~C( j (~C( 09/10/08 1 1 2Z-13A 12100446 LDL aQ(o- i~0 '3U 3 09/15/08 1 1 1 F-06 12096510 PRODUCTION PROFILE 07/17/08 1 1 3C-14A 12080436 SCMT - S"a 09/22/08 1 1 1C-111 12100451 INJECTION PROFILE ~ p .. 09/20/08 1 1 30-15 12100452 LDL - -~ 5Q 09/21/08 1 1 1C-117 12100453 INJECTION PROFILE o r 09/23/08 1 1 1 R-11 11966277 SBHP SURVEY ~- ~ V 09/25/08 1 1 1 R-35 11966279 SBHP SURVEY ~ 09/25/08 1 1 1 R-14 11966286 LDL ( 09/29/08 1 1 2X-18 12080443 PRODUCTION PROFILE 09/30/08 1 1 iR-34 12080444 GLS ~jL .- 10/01/08 1 1 2A-13 12096547 PRODUCTION PRO ILE -~ L ~~~/ 10/02/08 1 1 1 D-01 12097422 GLS 10/03/08 1 1 1 R-07 12097425 PRODUCTION PROFILE ~'''~ -~ ( 10/06/08 1 1 1H-19 12096548 INJECTION PROFILE L/ 10/03/08 1 1 18-16 12097426 GLS ~ - =' 10/07/08 1 1 3B-09 12100442 PRODUCTION PROFILE 09/12/08 1 1 3K-103 12096550 USIT 10/06/08 1 1 2X-05 12096551 INJECTION PROFILE ~~ 10/07/08 1 1 iB-04 12096552 INJECTION PROFILE ~ 10/08/08 1 1 1A-02 12096553 INJECTION PROFILE ~ 10/09/08 1 1 1 B-16 12096554 PRODUCTION PROFILE G, (~ ~ G 10/10/08 1 1 2D-15 12096555 PRODUCTION PROFILE ('~C , 10/11/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • 1A-02 (PTD 1810710) Report of suspected failed Seal-Tile treatment Page 1 of 1 • • Maunder, Thomaa E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, September 26, 2008 3:25 PM To: Maunder, Thomas E {DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 1A-02 (PTD 1810710) Report of suspected failed Seal-Tile treatment Attachments: 1A-02 schematic.pdf; 1A-02 90 day TIO plot.jpg Tom, Jim The Seal-Tile treatment on Kuparuk water injector 1A-02 (PTD 1810710) is suspected to have broken down. The treatment was used to repair the IAxFormation leak that was identified in 08/2006. The current TIO is 900/600/620. The current plan will be an attempt to reactivate the Seal-Tile trea#ment with the well on injection. The Seat-Tile treatment is pressure activated and by leaving the well on injection, it will help alleviate the cooling thermal effects while trying to re-energize the sealant. If the treatment can not be reactivated the well will be shut in while evaluating for future repair. ConocoPhillips will update the AOGCC with the results. Attached is a 90 day TIO plot and wellbore schematic. «1A-02 schematic.pdf» «1A-02 90 day TIO plot.jpg» Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 9/3012008 -~ rte' i~ ~' ~ 4~ ~IC~IIII~~~~1' Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth '~`1/~R U 4 IUCl~3 ~? ~a'."1~3$Il " ~~ . ~~~~~~ ~~~ ~ ~ ~Q~~ Well Job # Log Description C N0.4617 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 02/28/0$ 1A-02 (REVISED) 11994615 INJECTION PROFILE / ~ 02/11/08 1 1C-27 11970632 WFL ~} 02/21/08 1 3R-21 11970633 LDL j . (~ 02/22108 1 2P-451 11996604 SBHP SURVEY ' O ~~25 02/22/08 1 1C-11 11968846 LDL j ~ ~ 02/20!08 1 2P-438 11964581 SBHP SURVEY aU j - 02/26/08 1 2P-448A 11964582 SBHP SURVEY 02127108 1 L J • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~~~ F~~ ~ e~ Z~o~ Well Job # Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2L-319 11970619 SCMT - I 12/31/07 1 1A-02 11994615 INJECTION PROFILE (- 02/11/08 1 1F-10 11994616 INJECTION PROFILE - / 02/12/08 1 2X-08 11996603 INJECTION PROFILE U=C ~, - ((~ 02113!08 1 3N-11 11968841 INJECTION PROFILE - ~~ 02/16/08 1 1J-152 11994623 PRODUCTION PROFILE (p - / 02!18108 1 2W-17 N!A SBHP SURVEY ~ _ ~ ` 02120108 1 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: Jim Regg~ é'tfLf 7( 31 ( 07 P.I. Supervisor t FROM: Bob Noble Petroleum Inspector Well Name: KUPARUK RlV UNIT IA-02 Insp Num: mitRCN070719124318 Rei Insp Num: -~- Well ¡ 1A-02 ¡Type Inj. ì N P.T.DI 1810710 ITypeTest: SPT Interval 4YRTST P/F Notes: Friday, July 20, 2007 ~"..--_'- Packer TVD Test psi P DATE: Friday, July 20,2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA INC 1A-02 KUPARUK RlV UNIT lA-02 Src: Inspector NON-CONFIDENTIAL API Well Number: 50-029-20599-00-00 Permit Number: 181-071-0 1// Depth .-- 5908 /[ IA 1680 vr"OA I Tubing / 01\ \%\' Reviewed By: P.I. Suprv ,.JP;2-- Comm Inspector Name: Bob Noble Inspection Date: 7/15/2007 1000 1680 Initial 15 Min. 30 Min. 45 Min. 60 Min. I T- -- Pretest - T i I 510 520 850 850 T 850 SCANNED AUG 0 6 2007 1630 1630 520 520 I_~ , I I 850 Page 1 of 1 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commiss TO: Jim ReggKe4~(" 0/?D¡lit? P.I. Supervisor [ ~I DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IA-02 KUPARUK RIV UNIT IA-02 \£?¡\~ 01\ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .:JBi:?- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IA-02 API Well Number 50-029-20599-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ060824 1425 I I Permit Number: 181-071-0 Inspection Date: 8/2212006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IA-02 Type Inj. w TVD 5908 IA 1140 2550 ! 2540 2540 P.T. 1810710 TypeTest SPT Test psi 1500 OA 680 700 T 700 700 Interval OTIIER PIF P / Tubing 1900 1900 I 1900 1900 Notes Post seal-tite repair MIT ofT x IA communication. 1.4 BBLS diesel pumped, I well house inspected, no exceptions noted. -' v SCANNeD SEP 082005 Wednesday, August 30,2006 Page I of I ¡..... 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other U Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 181-071/306-217 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20599-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 100' 1A-02 8. Property Designation: 10. Field/Pool(s): ADL 25647 . Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8355' feet true vertical 6548' . feet Plugs (measured) 7447' Effective Depth measured 7852' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 112' 16" 112' 112' SUR. CASING 2802' 10-3/4" 2902' 2663' PROD. CASING 8237' 7" 8337' 6535' Perforation depth: Measured depth: 7552'-7577',7601'-7626',7652'-7688', 7796'-785°:SCJ\NNE(} AUG 3 1 2005 true vertical depth: 5963'-5980',5997'-6015',6033'-6058',6135'-6174' Tubing (size, grade, and measured depth) 3-1/2" 12.875", J-55, 7782' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'DB'; BAKER 'FHL' HYD SET pkr= 7753'; 7474' Cameo'TRDP-1A-ENC' SSSV= 1814' 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-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation Subsequent to operation 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oilD GasD WAG 0 GINJD WINJ0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Guy Schwartz @ 265-6958 Printed Name Guy S - /J Title Wells Group Engineer Signature ~ ~- /" þ£ Phone Date (- .2 8 - ð b -:x Prenared bv Sharon AI/suo-Drake 263-4612 C7 ~ RBDMS 8Ft AUG 3 1 2006 ~ ~.~o. H~ce/VED . STATE OF ALASKA . ~JJIi 8i /JI1J.lJ/jJj ALASKA OIL AND GAS CONSERVATION COMMISSION At6~~l.lJi' &43 REPORT OF SUNDRY WELL OPERA TION~~I\Q \;j A 81:C'OI.SC~Rn Form 10-404 Revised 04/2004 OR\G\NAL A-¥ ~ Submit Original Only ~ . ConocoPhilUps Alaska, Inc. . KRU 1Ä-02 1A-02 API: 500292059900 Well Tvoe: INJ Anale (â) TS: 46 dea (â) 7554 SSSV Type: TRDP Orig 7/2/1981 Angle @ TD: 42 deg @ 8355 sssv Comoletion: (1814-1815, OD3.500) Annular Fluid: Last W/O: 12/25/1986 Rev Reason: PULL DV Reference Loa: Ref Loa Date: Last Uodate: 7/1/2006 . Last Taa: 7852' TD: 8355 ftKB Last Taa Date: 8/31/2005 Max Hale Anale: 49 dea (â) 7200 Casino Strina - ALL STRINGS - Description Size Too Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 112 112 65.00 H-40 SUR. CASING 10.750 0 2902 2663 45.50 K-55 PROD. CASING 7.000 0 8337 6535 26.00 K-55 Tubino Strino - TUBING Size Top Bottom TVD Wt Grade Thread 3.500 0 7757 6107 9.30 J-55 EUE 8RD AB-MOD TUBING 2.875 7757 7780 6124 6.50 J-55 EUE 8RD AB-MOD (0-7757, 3.500 7780 7782 6125 9.30 J-55 OD:3.500, Perforations Summarv ID:2.992) Interval TVD Zone Status Ft SPF Date Tvoe Comment 7552 - 7577 5963 - 5980 C-4 25 12 12/23/1986 RPERF 120 dea. Ph; 5" HYDerJet II 7577 - 7591 5980 - 5990 C-4 C 14 0 7/1/1981 Saz 7601 - 7626 5997 - 6015 C-4,C-3 25 12 12/23/1986 RPERF 120 dea. Ph; 5" HYDerJet II 7626 - 7648 6015 - 6030 C-3 22 0 7/1/1981 7652 - 7654 6033 - 6034 C-2 2 12 12/23/1986 RPERF 120 dea. Ph; 5" HvperJet II 7654 - 7688 6034 - 6058 C-2 34 16 12/23/1986 RPERF 120 dee. Ph; 5" HVDer Jet II 7700 - 7712 6067 - 6075 C-1,UNIT 12 0 7/1/1981 B . 7796 - 7850 6135 - 6174 A-5,A-4 54 4 7/1/1981 IPERF 120 dee. Ph; Vann Gun Stimulations & Treatments Interval Date Tvpe Comment 7552 - 7591 7/1/1981 Cement Saueeze Reoerfed 7552-7577 on 12/23/86 (WO)) 7601 - 7648 7/111981 Cement Saueeze Renerfed 7601-7626 on 23/23/86 (WO) 7654 - 7654 7/1/1981 Cement Saueeze Reoerfed 7652-7688 on 12/23/86 (WO) 7700 - 7712 7/111981 Cement Saueeze Gas Lift MandrelsNalves - St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 3063 2772 Cameo KBUG DMY 1.0 BK 0.000 0 11/19/1991 2 4454 3715 Cameo KBUG DMY 1.0 BK 0.000 0 11/19/1991 3 4877 4009 Cameo KBUG DMY 1.0 BK 0.000 0 11/19/1991 4 5246 4273 Cameo KBUG DMY 1.0 BK 0.000 0 11/18/1991 PLUG 5 5615 4547 Camco KBUG DMY 1.0 BK 0.000 0 11/19/1991 (7447-7448, OD:2.810) 6 5983 4824 Cameo KBUG DMY 1.0 BK 0.000 0 11/18/1991 7 6295 5062 Cameo KBUG DMY 1.0 BK 0.000 0 11/19/1991 8 6659 5340 Cameo KBUG DMY 1.0 BK 0.000 0 11/19/1991 9 7030 5609 Camco KBUG DMY 1.0 BK 0.000 0 12/25/198E 10 7401 5858 Otis LBX OPEN 0.0 0.000 0 6/27/2006 Iniection MandrelsNalves St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt - I--- 11 I 7509 59331 Cameo I KBUG I DPHF DMY 1.0 BEK 0.000 0 10/4/19991 Perf - I--- Other II luos eouiD. etc.\ - JEWELRY (7552-7577) - I--- Deoth TVD Tvoe Descriotion ID - I--- Perf - I--- 1814 1785 SSSV Cameo 'TRDP-1A-ENC' 2.813 (7601-7626) - I-- 7447 5890 SBR Baker 2.813 Perf - I--- 7447 5890 PLUG SET 2.81" PX PLUG ON 6/26/2006 0.000 (7652-7688) - I--- 7474 5908 PKR Baker 'FHL' hvd set 2.891 Perf 7728 6087 PKR EXT 3-1/2" K3 PACKER 1 EXTENSON 1 AVA SEAL STINGER ASSY (173.5" 1.500 (7700-7712) ASSY OAL, 1.6" ID) @ 7742' RKB. SET SUP STOP ABOVE EXTENSON set PKR EXT 31712006 ASSY 7742 6097 NIP A V A BPL NIPPLE, MODEL '21 B' 2.750 (7728-7742, 7753 6105 PKR Baker 'DB' 3.250 OD:3.500) 7770 6117 NIP Cameo 'D' Nioole NO GO 2.250 7781 6125 SOS Otis 2.992 7782 6125 TTL 2.992 Fish - FISH TUBING Depth I Description I Comment (7757-7780, 0 I Lock Kev I Lock Kev from AVA BIP left in hole. Deoth unknown. OD:2.875, 7902 I Vann Gun 1340.14' lona ID:2.441) General Notes TUBING Date Note (7780-7782, 11/18/2001 WAIVERED WELL - T x IA Communication OD:3.500, ID:2.992) 8/31/2005 TUBING LEAK FOUND w/PONYTAIL (â) 7739' Perf 4/27/2006 Slow IA to Formation Leak (â) 3025' '" (7796-7850) - - Bì . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk / KRU /1A 08/22/06 Sauvageau/Noble - AES Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. Well!1 A-02 I Type Ini. I W TVD I 5,908' Tubing 1900 1900 1900 1900 I nterva I 0 p.T.D.11810710 I Type test I P Test psil 1500 Casing 1140 2550 2540 2540 P/F1 P Notes: MITIA as required by sundry approval 306-217 for OA 680 700 700 700 repair of IA leak at 3028'. Sealtite sealant was squeezed into leak on 8/14/06. ,/ Weld 1 A-09 I Type Ini. I W TVD I 6,043' Tubino 2000 2000 2000 2000 Interv~ 0 P.T.D.!1811520 I Type test I P Test psi11510.75 Casino 1865 2660 2660 2640 P/FI P Notes: MITIA as required by sundry approval 306-218 for OA 660 670 670 670 repair of IA leak at 2574'. Sealtite sealant was squeezed into leak on 8/15/06. Weill I Type Ini. I TVD I Tubinq Interv~ P.T.D.I I Tvpe test I Test psil Casino P/FI Notes: OA Weill I Type Ini. I TVD I Tubino Interv~ P.T.D.I I Tvpe test I Test psil Casino P/FI Notes: OA Weill I Type Ini. I TVD I Tubino Interval P.T.D.I I Type test I Test psil Casino P/F1 Notes: OA Weill I Type Inj. I TVD I Tubino Interval P.T.D.I I Type test I Test psil Casino P/F1 Notes: OA Weill I Typelni. I I TVD I Tubing Intervaf P.T.D.I I Type tesd I Test psil Casing P/FI Notes: OA D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT KRU 1A Pad 08-22-06.xls DATE 08/14/06 08/15/06 08/22/06 . 1A-02 Well Events Summary . Summaryops SEAL TITE PC LEAK @ 3,002' WITH 3 BBLS FLO-SEAL ¡/ SET DV @ 7401' RKB. TESTED TBG 3000 PSI, GOOD. PULLED PLUG @ 7447' RKB. MITrA-PASSED, POST SEAL-TITE IA LEAK (WITNESSED) Re: lA-02 (181-071) and lA-09 (181-152) F¡ up ~ . MJ, It appears that your repairs have been successful as evidenced by the witnessed MITs on August 22. Your plan is acceptable. Tom Maunder, PE AOGCC NSK Well Integrity Proj wrote, On 8/28/2006 4:27 PM: SCANNED AUG ~: £ 2005 Tom, Jim, Subsequent to the recent Sealtite repair treatments (10-403/404 Sundry #'s 306-217 and 306-218) and following passing State Witnessed MIT's on wells 1A-02 (181-071) and 1A-09 (181-152), ConocoPhillips intends to return these injection wells to a normal 4 year MIT cycle and remove them from the failed MIT report. ConocoPhillips would like confirmation from the Commission that the plan is acceptable. Please let me know if you have any questions regarding the treatments or the MIT results. MJ Loveland ConocoPhillips Alaska Well Integrity Project Supervisor Office (907) 659-7043; Cel (907) 448-3114 1 of 1 8/29/2006 9:32 AM KRU MIT data 8/22/06 . . Tom, Jim, & Bob, Attached are passing KRU MITs as witnessed by Jeff Jones on 8/22/06. 3S was the last KRU drill site due for MITIAs in August. C02 is still due this month and is tentatively planned for this weekend. 1A-02 & 1A-09 MITs were completed due to recent repair work. CPAI will be in contact to discuss regulatory requirements to leave these wells on injection post repair. At this time, both wells remain on the failed MITIA report. 10-10 MIT was an initial MITIA post RWO. The RWO replaced rotten tbg. This well has been removed from the failed MITIA report. I am leaving the slope this afternoon, please let Perry Klein know if there are any questions. Marie McConnell Problem Well Supervisor 659-7224 «MIT KRU 1A Pad 08-22-06.xls» «MIT KRU 10-10 08-22-06.xls» «MIT KRU 3S PAO 08-22-06.xls» Content-Description: MIT KRU lA Pad 08-22-06.xls KRU lA Pad Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 Content-Description: MIT KRU ID-IO 08-22-06.xls KRU ID-IO Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 : Content-Description: MIT KRU 38 PAD 08-22-06.xls MIT KRU 38 PAD 08-22-06.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 1 of 1 8/29/2006 9:27 AM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk / KRU / 1A 08/22/06 Sauvageau/Noble - AES Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. Well!1A-02 I Type Inj. I W TVD I 5,908' Tubina 1990 1900 1900 1900 Interval[ 0 P.T.D.!1810710 I Type test I P Test psil 1500 Casino 1140 2550 2540 2540 p/FI P Notes: MITIA as required by sundry approval 306-217 for OA 680 700 700 700 repair of IA leak at 3028'. Sealtite sealant was squeezed into leak on 8/14106. 10-404 re~ ort to be submitted. Well 11 A-09 I Type Ini. I W TVD 6,043' Tubing 2000 2000 2000 2000 IntervaiT 0 P.T.D.11811520 I Type test I P Test psi 1510.75 Casina 1865 2660 2660 2640 p/FI P Notes: 45 min T/I/O: 2000/2640/670. Sundry 306-218 for OA 660 670 670 670 repair of IA leak at 2574'. Sealtite sealant was squeezed into leak on 8/15/06. 1 0-404 re~ ort to be submitted. Weill I Type Ini. I TVD Tubing I ntervall P.T.D.I I Type test I Test psi Casino p/FT Notes: OA weill I Type Ini. I TVD Tubing Interval[ P.T.D.I I Type test I Test psi Casino p/FI Notes: OA Weill I Type Ini. I TVD Tubina Interval[ P.T.D.I I Type test I Test psi Casino p/FI Notes: OA Weill I Type Ini. I TVD Tubina I ntervall P.T.D.I I Type test I Test psi Casing p/FI Notes: OA Weill I Type Inj. I TVD I Tubina I ntervall P.T.D.I I Type test I Test psil Casing p/FI Notes: OA D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential T em perature Test I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT KRU 1A Pad 08-22-06.xls /4'1-°71 rmlill·,' n:, ".' 6,· , ffi¡;, ~ ,,1m, :^,,\,@,', ~"n,. /7, " ~, ' I, ) ¡ J!.J. \ ,0 \ ~~ ,\ i ü \ u IJ UlJ ! LtlJ Q.v 'û LnJ ø í J FRANK H. MURKOWSKI, GOVERNOR / / I ¡ 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 AlASKA OIL AND GAS CONSERVATION COMMISSION Guy Schwartz Wells Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 1A-02 Sundry Number: 306-217 !~·Ç"\MN :.:;f ¡ ,:"10 Æ,',' ,*"',,< ·'iìii!',t·''i··'' -, "" ~¿ 20Gb Dear Mr. Schwartz: 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, DATED thisJi day of June, 2006 Encl. r1rl- () 7-"1 . Conoc6Phillips . Guy Schwartz Wells Group Engineer Drilling & Wells P. 0, Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6958 June 16, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: RECE\VED JUN 1 6 2006 C c()l'llrission .Maska Oil & Gas ons. 1 t AnchOrage, \' 0 ' \~. Subject: Application for Sundry Approval for 1A-02 ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the upcoming well work on the Kuparuk weIl1A-02. If you have any questions regarding this matter, please contact me at 265-6958. Sincerely, ê?d.5: G. Scliwartz Wells Group Engineer CPAI Drilling and Wells GS/skad trfs 'J) f k C(tJ- qM!ðf... k. RECEIVED STATE OF ALASKA . (p il" ALASKA OILAND GAS CONSERVATION COMMISSION JUN 1 6 Z006 APPLICATION FOR SUNDRY APPROVAL . . 20 MC 25.280 Alaska Oil & Gas Cons. Commtsslon . 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 Waivt#nCn~yt: Other 0 Alter casing 0 Repair well 0, Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 181-071 . 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20599-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 100' 1A-02 8. Property Designation: 10. Field/Pool(s): ADL 25647 . Kuparuk River Field / Kuparuk Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8355' . 6548' . 7852' 6143' 7902' Casing Length Size MD TVD Burst Collapse CONDUCTOR 112' 16" 112' 112' SUR. CASING 2902' 10-3/4" 2902' 2663' PROD. CASING 8337' 7" 8337' 6535' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7552'-7577',7601'-7626',7652'-7688', 7796'-7850' 5963'-5980',5997'-6015',6033'-6058',6135'-6174' 3-1/2" J-55 7782' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER 'FHL' HYD SET; BAKER 'DB' pkr= 7474'; 7753' Camco TRDP-1A-ENC SSSV @ 1814' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15, Well Status after proposed work: Commencing Operations: June 26, 2006 Oil 0 Gas 0 Plugged 0 Abandoned 0 16, Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Guy Schwartz @ 265-6958 - Printed Name Guv Title: Wells Group Engineer Signature R::' ~*&-.<'\ Phone 265-6958 Date (;-1(,. -o~ ref- - Commission Use Only sund~~r: \ '7 Conditions of approval: Notify Commission so that a representative may witness ( OJd-- Plug Integrity 0 BOP Test 0 Mechanical Integrity Test '~ Location Clearance 0 Other: k \ \' ú..\J,(.\ \.NtC\.\- ~ "- -\- Subsequent Form Required: I~O~ RBDMS 8Ft .iUN 2 0 2006 ~Y¡ APPROVED BY Date: b-/?-ðb Approved by: ~SSIONER THE COMMISSION l/ ~~ .~ ¿'/T'ð'- Form 10-403 Revised 7/2005 OR\G\f\1/\1 ~ø;;¡ . . lA-02 IA Repair Procedure 6-l2-06 Well Background: lA-02 fails an MITIA with a leak rate of about 2-3 gal/min. at 2500 psi. The IA leak also apparently communicates with the OA open shoe. Subsequent testing indicated the tubing and packer were competent and that the leak was somewhere in the 7" casing. With such a small leak conventional leak detection methods were not adequate so CPAI enlisted TECWEL (Ultrasonic Leak tools) to help find the leak path. The tool successfully pinpointed the leak at 3028' md behind pipe in the 7" casing (the surface casing is set at 2902' md). Plan forward to repair the well is to use Sealtite by spotting product across the known leak point and squeezing the sealant into the leak. If successful this will allow the IA to test and allow the well to return to injection. Procedure Outline: 1. RIH and set WRP plug in tubing just below GLM @ 3063'. 2. Pull DV in GLM #1 (3063' md) and circulate 9.8 ppg brine around tubing/ IA until stable. 3. Pump 2 bbls SealTite sealant (sealant is 9.4 ppg) from surface into IA (returns taken up tubing side). 4. Displace sealant to leak area with diesel to the leak pt. (Sealant will float on top ofthe9.8 ppg brine). 5. Shut in at surface and bullhead sealant into the formation. Hold 1000 psi differential and allow to cure 4 hours. Increase to 2000 psi and hold for 8 hrs. Lock in pressure for 7 days and allow to cure. 6. Pull WRP plug/ replace DV and MITIA after 7 day cure time is complete. 7. Return well to injection. Final Job Report Manufacturer: Tec\/lJel AS Document no, ' IN-WLD-2006-05-117 4 Appendices 4.1 Log-Leak Point . ~ , ~ ~ ~ . , , , ~ , ~ ~ ~ ~ ~ -, ~ , , ,~ ~ , ~ ~ - , ~ - , -, ___L ~ : ,~ , --, , , - -" . , -,' - , ~ . ''f¥:Cff ". ., - -.1U~--~~- - Revision 1 ¿-j"U ~ , , - " "'- , ~ , - - - -- ~, if.- / ~~L-- ~~. .. tIft" . ~- , C__! ,",,____ ___ - - - ,-- - , IL:J -\,-- ;~~+tr Il-':-~- -- , _,_ + ~- :t· ._:'d~:;, ) _ i , ~- ~í)LM Page 3 of 8 5-15-06 - ~ ~ - '~-- ~ ---.------ ---,~--~- - , ~ -- -, ---- -~ - - , -., -- :,----_.~-)--~ ~- '''~- --- - - , ConocoPhillips AI.a, Inc. . KRU 1A-02 tAc02 API: 500292059900 Well Type: INJ Anqle (âJ TS: 46 deQ (âJ 7554 SSSV Type: TRDP Oriq Completion: 7/2/1981 Anqle (âJ TD: 42 dea (âJ 8355 SSSV Annular Fluid: Last W/O: 12/25/1986 Rey Reason: Intearity COM (1814-1815, Reference Loa: Ref Loa Date: Last Update: 4/30/2006 OD3.500) Last Taa: 7852 TD: 8355 ftKB Last TaQ Date: 8/31/2005 Max Hole AnQle: 49.7200 I iCâsinQ Sb;ind- ." Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16,000 0 112 112 65.00 H-40 SUR. CASING 10.750 0 2902 2663 45.50 K-55 PROD, CASING 7,000 0 8337 6535 26.00 K-55 ìûbiÐâSfriôdi- !TIt IBING, :: Size ìop Bottom TVD Wt Grade Thread 3.500 0 7757 6107 9.30 J-55 EUE 8RD AB-MOD 2,875 7757 7780 6124 6.50 J-55 EUE 8RD AB-MOD 3,500 7780 7782 6125 9.30 J-55 : TUBING Interval TVD Zone Status Ft SPF Date Tvee Comment (0-7757, 7552 - 7577 5963 - 5980 C-4 25 12 12/23/1986 RPERF 120 deQ. Ph; 5" Hyper Jet II OD:3,500, ID:2,992) 7577 - 7591 5980 - 5990 C-4 C 14 0 7/1/1981 Saz 7601 - 7626 5997 - 6015 C-4,C-3 25 12 12/23/1986 RPERF 120 dea. Ph; 5" Hyper Jet II 7626 - 7648 6015 - 6030 C-3 22 0 7/1/1981 7652 - 7654 6033 - 6034 C-2 2 12 12/23/1986 RPERF 120 deQ. Ph; 5" Hyper Jet II 7654 - 7688 6034 - 6058 C-2 34 16 12/23/1986 RPERF 120 dea, Ph; 5" HyperJet II 7700 - 7712 6067 - 6075 C-1,UNIT B 12 0 7/1/1981 7796 - 7850 6135 - 6174 A-5,A-4 54 4 7/1/1981 IPERF 120 deQ. Ph; Vann Gun :11) Interval Date Type Comment 7552 - 7591 7/1/1981 Cement Squeeze Reperfed 7552-7577 on 12/23/86 (WOn 7601 - 7648 7/1/1981 Cement Saueeze Reperfed 7601-7626 on 23/23/86 (WO\ 7654 - 7654 7/1/1981 Cement Saueeze Reperfed 7652-7688 on 12/23/86 (Wo\ 7700 - 7ï '12 7/1/1981 Cement Squeeze Gas .·..Bift St MD TVD Man Mfr Man Type V Mfr V Type VOD Batch Port TRO Date Vlv Run Cmnt 1 3063 2772 Cameo KBUG DMY 1,0 BK 0.000 0 11/19/1991 2 4454 3715 Cameo KBUG DMY 1,0 BK 0,000 0 11/19/1991 3 4877 4009 Cameo KBUG DMY 1,0 BK 0,000 0 11/19/1991 4 5246 4273 Cameo KBUG DMY 1,0 BK 0.000 0 11/18/1991 5 5615 4547 Cameo KBUG DMY 1.0 BK 0,000 0 11/19/1991 6 5983 4824 Cameo KBUG DMY 1,0 BK 0,000 0 11/18/1991 7 6295 5062 Cameo KBUG DMY 1.0 BK 0,000 0 11/19/1991 8 6659 5340 Cameo KBUG DMY 1.0 BK 0,000 0 11/19/1991 9 7030 5609 Cameo KBUG DMY 1.0 BK 0.000 0 12/25/1986 10 7401 5858 Otis LBX DMY 1.5 RO-5 0.000 0 12/25/1986 SBR InjectioriMaôørâlsC\lâWes (7447-7448, St MD TVD Man Mfr Man Type V Mfr V Type VOD Batch Port TRO Date Vlv OD:3,500) Run Cmnt 11 1 7509 5933 Cameo I KBUG I DPHF DMY 1.0 1 BEK 1 0.000 0 I 10/4/1999 1 (i)ther (I luds¡âc:îûi Ì) ,âtêI\ :,c'Ai'::'}RY Depth TVD Type Descrietion ID 1814 1785 SSSV Cameo'TRDP-1A-ENC' 2.813 7447 5890 SBR Baker 2,813 7474 5908 PKR Baker 'FHL' hyd set 2,891 7728 6087 PKR EXT 3-1/2" K3 PACKER / EXTENSION / AVA SEAL STINGER ASS'Y (173.5" OAL, 1.6" 1,500 ~ ~ ASSY 10\ (âJ 7742' RKB. SET SLIP STOP ABOVE EXTENSION set 3/7/2006 Perf ~ ~ 7742 6097 NIP AVA BPL NIPPLE, MODEL '21B' 2.750 (7552-7577) ~ f-- 7753 6105 PKR Baker 'DB' 3.250 ~ ~ 7770 6117 NIP Cameo 'D' Nipple NO GO 2.250 Perf ~ 7781 6125 SOS Otis 2.992 (7601-7626) ~ ~ 7782 6125 TTL 2.992 Perf ~ ~ Fishi- FISH (7652-7688) ~ ~ Deeth Description I Comment Perf 0 Lock Key 1 Lock Key from AVA BIP left in hole. Depth unknown, (7700-7712) 7902 Vann Gun 1340,14' lona PKR EXT ASSY Date Note (7728-7742, 11/18/2001 WAIVERED WELL - T x IA Communication OD3.500) 8/31/2005 TUBING LEAK FOUND w/PONYTAIL (âJ 7739' 4/27/2006 Slow IA to Formation Leak (âJ 3025' TUBING (7757-7780, OD:2.875, ID2441) TUBING (7780-7782, OD:3,500, ID:2.992) Perf (7796-7850) - - - ..Tecwel report for 1A-02" . . Tom, Here is the report and data we got for 1A-02. Can't find my electronic copy of 1A-09 but it is very similar. ~'\~-O~\ The sundries are headed your way!! Thanks, Guy «FJR-1A-02.pdf» ~\%\-\~J Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy.l.schwartz@conocophillips.com Content-Description: FJR-IA-02.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 6/19/2006 10:02 AM . . TecWel'" Q~ Final Job Report ConocoPhillips Kuparuk lA-02 L ") l ~ l -1) '\ \ Well Leak Detector (WLD) AUTHORIZATION Prepared By Joel Johns 5-15-06 Approved By . . Final Job Report Manufacturer: TecWel AS Document no. : IN-WLD-2006-05-117 Il'ämm clas, Revision 1 1 General Information IA fails MIT with a leak rate established at 3.1 gpm at 3000 psi. 12/09/00 Well on waivers requiring quarterly monitoring of IA fluid level. 2 Objectives The objectives ofthe operation were: · To locate source of pressure loss during MITIA. 3 Results · The leak rate was established by pumping diesel down the IA and maintaining a pressure between 2500 and 2000 psi. · Leak rate at above pressures was maintained between 0.83 and 0.73 gpm. · Typical leak signature located at @ 3030' in the 7" casing near a landing collar. · Leak confinned by stationary logs. Page 2 of 8 5-15-06 17 Revision 1 4 Page 30f8 Manufacturer: Document no. . TecWel AS IN-WLD-200S-05-117 Revision 1 over L8PD (ftImin: CCl 1000 1000 100 6875 ALDA AlD8 ALDG Page 4 of 8 17 Revision 1 o 500 100 475 ALDA AWS ALDC Page 5 of 8 17 Revision 1 6of8 Manufacturer: Documenl no, . TecWe! AS 17 Revision 1 al 7" slage collar 3026' leaks ¡¡was 1545 Page 70f8 . Final Job Report Manufacturer: TecWel AS Document no. : IN-WLD-2006-05-117 4.6 Tool Schematic f-HEN eCL eel ALOA ALOB ALDC AlOD TSTAMP ITEMPX HVOLTX 677 5,18 5,18 0,00 0,(X}! 000 000 -0.40 -OAO -0,40 "Schematic o 'ì \ ~\ ';í 'L Revision 1 ~r¡Ft¡on GHD-AES (000001\ -~:abœ He-ad PSJ-010 (OO(J(J()Z) , '5columborger _I jolt« ASG-QOO (3217-4) 'Adaptor 5<01"mber9er= ,\\AGS-0ü1 (O21247} , "dapllOr GofS"'dex "" PKJ-013 (050323) " Proœæoo _ Jokit LPKJ-013 (050326) Pcoœæoo _ Jam . PRe-D34 (51192) - ProŒi<tioo Reier certralíser - HADES lJppef ~XTU'-OO1 (031523) Ç:rQS:iOver lJlú<iWÌl'E', Toolbus to Uhijn:k " HnJ-Oaa (031525) . -Head Tension Urit GGL-015 (030589) -(:asing Collar locator PRC-034 (0511 91} ~ŒlCl'Íon RoIe.r CertrBliSP.l" ~ HADES Upper .. WLD-002 (041272) -Tec.tÑ'ei Acoustic- Listening Device. BUL.oû6 (030639:) ~·-·B.ulln-oS6 Dataset T alai Length Total Weight 0.0 run1f013upr 1676 a270 1.69 Page 8 of8 . Il1!ZD Jai Len (ft) ºº(In) Wt(lb) 104 144 200 1.33 I 1.69 10,00 037 1.69 110 021 169 1.00 0.54 1.69 3.50 0.54 169 3.50 2.77 169 1300 1.58 1.69 6.50 1.79 1000 169 1.54 900 169 2.77 1300 1.69 1.97 169 8.60 030 169 1.50 5-15-06 RECEIVED 05/18/06 Scblulllbel'gel' MAY 2 4 2006 3~~ ('J.I <) ~ ..11 ç¡ Gas C;ns. COITnni$$k;n r\~~ NO. 3808 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 í\ \ Cb '''' t> \ (" e'e,. %Ie ,,,,¡;..¡¡:,;,- <:JV/"t; ,¡,¡' ~'-' .; l l' <.) Field: Kuparuk Well Log Description Date Color CD Job # BL 1 G-01 (REDO) 11213744 INJECTION PROFILE ì'Qd -;36 05/03/06 1 1 Q-26 11258706 PRODUCTION LOG WIDEFT i C1 "\ - I ~ ';) 05/06/06 1 1 A-03 11258708 PRODUCTION LOG W/DEFT I ~í - o~1I" 05/07/06 1 1Y-15A 11216294 PRODUCTION LOG WIDEFT ,e, 7( _ ,-kG., 05/08/06 1 1 A-02 11258709 SBHP SURVEY t.' :r e. I ~ t - (")-::r ¡ 05/09/06 1 1R-13 11258711 INJECTION PROFILE (\ ":1 (' \ <¡.¡..,- - I.:..-r, 05/10/06 1 2M-34 11216296 INJECTION PROFILE lfi:~ \ C¡ Co'., - (ì~ 05/11/06 1 2F-03 11216298 SBHP SURVEY j \'~ I' \..y~ - i~-"- 05/14/06 1 2F-14 11216299 SBHP SURVEY 0;-(. IfI-~-- ~ 05/14/06 1 1A-06 11258712 INJECTION PROFILE ~) or Q.. '''X: i-I} c:. 05/14/06 1 3Q-11 11216301 LDL i <S-ti· -,~;' 05/16/06 1 1J-184 11216297 USIT r) "1 (' ;.::\ ··,t.. (. )L}¿t 05/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. L!..l0- ~/6>s-(o{, 9 e e • • ' Conoc Phillips Fax Cover l c6 t- -U'1 \ R q , !0 G t of 4 •�'��''��YY�� . '�* 9 \ c' � . . fr+ f s From Name Phone Number r f'1I w ` (NN t.- 64 ?1- 72,v,f Sending location (euilding /RoornlCity) Fax NL nbar IC u'AI9. v 1 EtL- 66 I — 73 t f To Name Phone I umber _ or Rem!' ,;r "fir, inber ; ` TOM MAUNDER, P.E. : • sub* , -, , , . SENIOR PETf�OLEta'M ENGINEER 1 STATE OF ALASKA cc_ & GAS CONSERVATION COMMISSION 333 7t1+ Ave., Sts, 100 Notes/ Anchorage. AK 99501 Phone: (907) 793-12 F (c�D7) 276.742 Email: Tom- Maunderf;Dadmlrt.atats.a�us . cIl:+• s+ _ . \ __re `t' €c_ C.0 L -i..'M - AT N' t- i I - CAS toes 1 A-CC.,,, !) Confidentiality Statement This facsimile transmission contains information from ConocoPhillips ani is cgnfidential or privileged. The information is intended to be for the use of the individual or entity named above, if you are not the intended recipient, be aware that any disdosurf , copying, - distribution or use of the contents of this information is prohibited, If yoi. hove received this transmission in error, please notify us immediately by telephone et the ni rnber above. Thank you. 4 -1181 PA, 9 -02 Form 16103 -S 9 -42 . ` .) APP 1 5 ZOlt • Z0 39dd dnoao S113M >1SN PTEL659L06 Z0 :0Z 900Z/E0/90 ' 4AtlanticRichfieldCompany * Drilling -- Completion— Workover Loi '.. fill or l a , mer ". ._ _ _" Well member Irmo •• Mid ' � ... pii 0 . .074/ Dlatrlci . fir- a. . .S I ILO'rd& ,i ounty or par Provide, or ■ its Tim, dhndlwaan • home Y. I • a - .1 4 Mn !1SieA o bey Eva 1? . • _ amanita' 1 Rig up and a . v a 4 . ; Ftic. ,a r ' 1...I 44 tun clown ! Drilling normal III ,, .. • H Directional . IP. MAL, I / ft •ni -2 - .) 1r 4a F. s; drilling ,. . ..a11 f rs . Reaming i .1 .1. 1 , b r- I dS F r Tripe to Chums bit Orlllinp with • I _EMSTM :, • r cancel returns combating loaf `1 rlar.+ytL Bra TOIL rfsaj Stbia .... _ circulation MIN I ' Z ITS 7 "t4* - s 4 N.1.. _� 77 Candle - ngm r r W Ai-S5 [S6 - ��. �G� antl cira Del-c•. & Ir T , rl crib . r- : l fiiii V IL r . • �� T!^= _ 7 6 Z �rt x -s S $. tf p.L. MO Cs rT / 543,04 r S � z4 .1(1 OwlabCn arrw L Pq.- &S $.itf. K Mario. 24,71 f (•�L _ . " F 1 ,ZO. I I uhrlaaN AO � r LT z Cut ott • - 7" . Pr- limn Acme I favicPy 7-r• ?E?( -Cli q . .. r ' _ .r. . , .6dL EtW Tact casing it elr! i 6 3 el or e,o.P. 1: -. . 61/ _. _ 4 ---- ,....� .2 e� side NW - • . , 1 1 - r r s 7"2br IC- ss $...r -L, civil C s a 9 - g- ,' - r rh' .211 ' 7"24,4t-5s R[!_7' :L. st... f.s'S • �sr.. 1 .z, , 01 G ,. :off;' z 1 . -15 • _ .� ,s • - ^ , ' T i 'I '! �Y 0. DM clam test r } �7 r ° - : 1 C - -4' . �s awl hole NW + a. • `4 sal i F ''7 7.7 Wlrs I na ,r ! � i Y< - -....... � ily'TA ' L 1�3J 1 .7 IoQOin back �•, r v X P14;gdng back r .. • . . _ - _ . . �. — _ -.__. ... / . and Mingn r ivt7 . sit Con i • 1_ / ysy e"-‘ id ...a moment �� � / egging -. �a7! ;�.... - ^"tr - �. . _ a ' I ' Sf �► es CUM:1Mals y �i - 7 J - _ . .. _' ' .�i�? 3 C7 L'J P°rfWaiing • ._ ' r �4 , .• f�' t.� !J , WlrelYne lean • l ... r _ r Vi! M at mad Mk ; _ I "/ .+ t# • ♦ a . _ - - . .. . I . ` __ . 1 / , i: c hot.�t MINI / I Tooting IIIII – • Or'. ewrbb MN ,. o f Aoldirmg III / FrsGmring "' ..., si nark _ O b17 J ,� ru • ng trips �. = 5 �.t50 •t - TOM Other MIN A rCr► -Ir f er �� / � 1' . 1 Y Teat■ ;Salsa I Fest ' W.lgbl area. Tpw.d ' Glen » Q.D. orb i AS A Tame susmary Shoe r IfyS f 4 I i Pay work •. I. , sae dim Nauru woo }•e - -- . —. 1 Caller . 1.111a011111111 Joints pipe � ll� °' Total li . 1ill. Rita to illWAIIIII MU -� " Dept11 arel� /7�+, ,� /������. I1A7� -426 glean fi 1 / - ∎ ■ f . •ter„" h , * �.r -.. .. - -�,.. . -.__ . �.,,�.. _ „- r,�,�,,.. -. Z0 SSVd dfl(DdS ST11M >ISN IZEL6S9L06 Z0 :0Z 9002/E0/S0 0 05/04/2006 11:19 9076597314 PAGE 01 NSK WELLS GROUP Conocol'hillips ...._.. _.. Calculations Chz -------gmet number Subject of File 1 By Date - ......_, . 1 • • . . „ • . .. . . .... • • . 1- :?E•f - „. - 'tz - " , :i. , • ' . . . . . . . .. . F R j7 , .e.,..<9,..."c_.:7cze--L-cl- - .. .. ' . mAY '0 ::i7 . 2 ot:if. , .. . .. • . = Oil & GI); Ctiii ' • . . . ' ' . . . . • . , , . . .... „. . ' e .. .e..7‘• • 1,7C • . ..., )ZI--1 e / Pe- • '''/ .. ;=i2,.,4Z,___ • . . .. . . .. „ ....... .. ... .... . . .. ..... . . . . . . ... , . . . . . .. . . . : .. . . • • . . .. .. . ..• . . ..... . „.... . .. • " . _ .. .. , . . „..... . . . . . . . .„ • ... . . ,... . ... . . . . „ .. .. ... . . ............ . . ......... , . .. . . .. .. ....... . ... . . . ...... : .... . . . . .. . ..... ...... . . . . ........ ... . • .. .... ...... . . , ............,• ...,......... •• ••••.... •,............. .. , .. .. ... . .... „ . .„. . ........... • . :..' . •• • ... . . .. • ..... ..... . ........ .... . . „ .. • . . . .. .. .. . • ,. „ . ...... . . .. ,.. . . .... . . . . .. ..... . • ...... .. . ........ ' 7 2 ra -ccgl-q1 fr..e..e.k.:-/ . / 4.27. A..//./ ..r- • . .. ... , Cc . . ....... ..........• . ...... .. . .. . . .. „.... . ...... . .. .. . . . .... . .......„ ... . . ... .. .... .. . .. ... . . ...... . . .., . .. ....... . .. . .. • "."-" " . • . ..... . • .• • .. .. . . . .. .. ...... ... . . . . . . ... . .... .. . ..... .. . . , .. 6 eit ,, t ,, s .. . . .. ... .. . . ... • .. . . F . . .. . . ... . . . . . . • . . . . . . • . , . , . . ._..• . . . . . .. ,• ._____ ",.....: . . .. . • . . , .... . . . . ..... , . .... . . . . . ... ... . ... ... . . „ . . . . .. .... . Q.L. PAINTING (507) 563-4743 05/04/2006 11:19 9076597314 NSK WELLS GROUP 40 PAGE 02 ARC CO Alaska ka, I . SubSidiery of AtlantleRIehileldCompeny Drilling Report -°w Dai Walt Size & Depth Last CSG Days Actual Days Predicted Date / n'ap �ttlx- A -2 7 533 l5 /7 C�_1 _ "nn D rT Depth Y esterday Progress ' Formation -- I�o& Rt _ 3' ; s V z g zv -- Discretion at 0600 ' Dally ' Accum. Cos Accum. Mud Cost 1... o .. 3 z d $ / 6 q 1 107 7.E Mud Weight Vie. P V.1 . Gels. Ph, W.L. Cake Chi, Sand Sol, Oil Temp Data 10.1 of /J S p K s� 60; n£ Pit W IF,L. r Sl Pump No. & Type Liner {{ rPM rGPM 'P.S,r, Noz. Vet, 'A.V_ - 1],P. A.V. - D.C. Slow Pump Rate 6 pz, -9 s x 9 I Bit No. Size f Make Type 5N W Jets Depth In Depth Out Feet 'Hrs. RPM T_ ' Condition — alt 4 8 141 1 _ 6 X54 210mb) Do D'V A pl.r mo o_ P8 r2 5-6 — Torgu Rqt. Wt. P.U. Wt, S.O. Wt, $I A Wt. -Air BHA Wt. Mud DRLG T1m a -- ' Accum. Rot. Hrs. ,,� , now BOTTOM HOLE ASSEMBLY: (INCLUDING DRILL PIPE SIZE & GRADE} � A a • it C. R 1 A. .4iA • * : • c ri e, Tv _ . r p aoo bbl Lo tr- �'r. _ ,�o�.f pe (�1 ' let7 j , q P ZSd sue_. sik.— • r r, ' .. f�! 0 • , 1 , .0Q A. ) 26./ TOTAL COiRDINATES VE,RT, SEC, ANGLE /D1RECT1ON M.D. ANGLE DIRECTIC; V _ T.V.D, NORTH/SOUTH l EAST/WEST J - FROM LAST SURVEY POINT • — TO TARGET Angle Direction a tErg1.1. , TIME DPMRATIONS FRONT 6800 TO 0600 — ----- 00o - 07 00 _ Ca re. HO'-6, F • -I) °— o1oo - og30 T . oi't 0f 3 ! 1 U 17 .ess 1 1.____ ----Camp idE Ard ► i I 100 /4,00 .CA SED HOL L>a; , 4 - C BL It Ct . . : .. . AAA A G J9 2C7 Rj Gvtr 0.500 - 053.0 .. '/ <- y , o. "tea 2 j_ �3_Z t{I f 0 CHECK THIS B' ,OCK 1F SUMMARY CONTINUED ON SACK Ser, er . on Loc! Accidents Date Last Date LdSt BOP Kick Drill TeSt �, / Qe.ro� 1 S L15( y a 1 � r x,�_f � 'rlt Y L � �iara:�_ S �l ✓. �3 -$r+ ' V e . A 3 ire; Call-' Wirt o � Diesel On! c, R D esei Used I e Dies Recd, g U sed ( F) W ater Recd From ■ /f 3 00 pj �y e/S l Temp Visibilit / ti I ntl Vel. SlgnB T S / / b - f .. /...r 1. P ea NORTH ALASKA Born ce, 1 n 05/04/2006 11:19 9076597314 • . NSK WELLS GROUP PAGE 03 ARCO Alaska, Inc. i Subsidiary of AtieAticRlchfloldO mpany Drilling Report — Dai Well Size & Depth Last CSG rays Actual Days Predicted / t. WAY; J _.. Contra r QeptTT Oapth Yesterday Formation y�6 ,v, ;2.402. 83S _ O p tan at 0600 Oaily Coat Actum. Cost Accum_ MUd Cost C 2. ... E ry A r c • 11. " R i .► Z'-9 - g Mud Weight O e \ C o OelS. 0916111111Millill Se t. Olt F, _: pump N0. & Type Line SI = SPIV, IPM P.S.1, Noz. Vel, A.V_ - D.P. A.V. - O.C. Slew - nip Rate Data r Bit No, Size , Ty a SN Depth In Depth Out Hrs. iliCondition ME IiiiiMMIMMENIMEIMIMI Torque Rot. Wt_ P_U, Wt. S.O. Wt, BHA Wt, Mud DRLQ Time Aceurrt- Rot. HI% i SvR 7 8z -r aQTTOM HOLE ASSEMBLY! (INCLUDINP DRILL PIPE SIZE & GRAPE) 11 I, T 1li( 7 3C/Ry 1 Z ✓Boer Ag$rr T J 3 - Di , • _ _} _ � ! TOTAL COORDINATES VERT. SEC. ANdLI: /171RECT10n M.D. ANGLE Di RECTA: N T.V.D. NORTH /SOUTH _ EAST /WEST - t J am — �[ T - FROM LAST J SURVEY POINT (7___ TO TARGIET Angle . -,...- ` Direction -' — i tin .. _ TIME OPERATIONS PROM 0600 TO 0600 0609 /'1,1tre If i _ , ct , -a 3 - r viii r, - 1 , 4.D - rat . 1300 ,°CJ etr #{4; . f C ., • . ,.a, - t. 9 r L-- .S. ..5 ,► ,, - 1(11.5 l, b.o._ir!4 3 Z�_ + (dS [ J S .. _- - 5 e / •• a,1 / ,1 , a DO PV it . 4 A tit 1,1 414 2t'2 r0+6 . , � F/ f eed Z'GP b I (,i ce 7 "tem - f 1$0 7-#-4'19 r 1 c j8.(S --ort 1 p S14 „,/ e: tL RR , r . re� 0_�? , r - 2 s 4 s., • ?.+ad -0230 D I „ F f el r : . - o ,,.Ar o.,. , 14 . ' - , a t l .0 30 — o$3 Q 6c 0 >wT ., . b33't # � 0' O J'� 0y00-0500 l ; ✓i 1 9; i / , w i r” _ i : 0 . , to. I hr I - . � ^ r , _. 1. rr ' 4 J U cHECIS T1-115 ti .QC15 IF SUMMARY CONTINUED ON SACK $er. Per r on Lac: Accidents Date Last Date Last BOP - ' . • ` -; ) + � Y , e �' Kick Drill Test �.... 41 7rf - OAT -4 DOW on La . Diesel uleo Diesel Re . sed F) Water Ree'd From Z: .'''A-• _ 17 „ 'd . eel' *,! RIG y p0 Temp C.F. I Intl Vel, Signed 3 30 -5 . ,. CA p oc NORTH ALASKA 05/04/2006 11:19 9076597314 NSK WELLS GROUP • PAGE 04 • TIME OPERATIONS LAST 24 CONT'D= -- • • 'UMBER M a SIGNED / /! GATE S Ci IESC RIPTION OF KICK DRILL: ❑ WHILE PULLING PIPE C. WHILE RUNNING PIPE 0 WHILE DRILLING © MORNING LOUR - WELL CLOSED IN r SECONDS, ON STATION _ SECOI4DS El EVENING TOUR - WELL CLOSEt IN - , SECONDS, ON STATION SECONDS ESC RIPTI OF ACCIDENT; AME OF INJURED �- EMPLOYER ATT PORT FILED 05/04/2006 11:19 9076597314 NSK WELLS GROUP • PAGE 05 ARCul Alaska, mill:• Subsidiary of AllenticPiehfieideompany Drilling Report — Dai Well r Size & Depth Last CSG Days Actual Days Dnedieted FiaffAr/ / d +l f�A,X .'� _ , / - r ' o3 7 f 3 1i .. Contractor Depth Today Depth Yesterday Progress Formation o M J h?f e j (3 3 ass Operation at 0600 Daily Cost Aceum. Cost Accum, Mud Cost T 7 imcn Z!f 38v / if 3 a 10 . Mud Weight Vie. F.V. Y, W ' Geis ah. w L. Cake Chl. sa ) Q Sol. on L Temp Data 10 1 �' 4 140 2:2- � -5 - 5/ 1 3 I ro ‘,LO a. '700 ' - i . .. t P te $ IF.L.� Pump No. & Type "Liner Size SPM GPM P,5,1. - Noz VOl, A-V, - D.P. A,V. - D,C. Slow Pump Rate Data 9 — Bit No. Size Make Type 5l: Jets Depth in Depth Out Feet — Hrs. RPM WT..M Condition L5 S . err „ r ! / Y_ letro ei9s ?sass ISD /' _ 9s 6 ° 3 TOrque Rot- Wt. P,V, Wt, S.O. Wt, BHA Wt . Air BHA Wt. Mu DRLG Time I Acccu } m n , loot, Hrs, BOTTOM HOLE ASSEMBLY! ( INC LUDINI; DRILL PIPE SIZE & GRADE) `-' "'�^ , _e:r d 41 Al a 2 r Fes. ` r. C »-ode r - S x_5337 , TOTAL COORDINATES M.D. ANGLE DIRECTI•I N T.V.D. VERT. 5EC. ANGLE /DIRECTICt NORTH/SOUTH EA5T/WEST 1 ��� - FROM LAST - SURVEY POINT TO TARGET Angle Direction TIME OPERATIONS FRcF: 0600 TO 0600 • - ALI "Ib +- L.1.. ca! • p. •700 4 • -0. .. ' - - - O:. -- _ I wE - R. Al i : w . _ FoR - •• -- 03. ^. g.. r . . 0o • Zd 00 . r. 1 8 5 , 7 z 6 # /1C - _ , r, $ 3 3 3 . a- Z300 R { ihr. d , A1 W4 R E E 9 y , r - r + 3 ; r - s • O .° ./ 3 - ad 4. .S 'A /t 7 - .I 000.. / f i _' Iv ■ ' P c Ea (j ' S G - r A �� y . J1'",. g - < • - ' LA-5c !s 2L 3 lD,I± ' ' y6 CB&i'�+l 4✓DCS' p.$ r,z -iG s/ : -. - : . a . _ .z Atac, 1 , e a Ry oX .,._, 6 .411 .. ^ . 3 A ' ' . Q7), • " ,. • -- r. +g -sea el MI C1 -HECK THIS if LOCK IF SUMMARY CONTINUED ON BACK "�� Ser, PeC on Loc! Accidents Data Last Date Last 6DI 1 4- -i�itle Cl I , LALcy , LJ r �,t4 Kick Drill Test OIBSQI o L. ■lesel Used Diesel Recd. ` s - Water 3� • v { '' 'iI," � � R/ : /9O4 Temp I find Vel. 011' Signed / /JP a 0 . ,�►'f , „ eAmp soar,, NORTH ALASKA — 05/04/2006 11:19 9076597314 NSK WELLS GROUP • PAGE 06 • TIME OPERATIONS LAST 24 h RS. CONT S 8 . _ /T L. /'? .rN4 Z ^" r+� , .4s uecn Cj 7 " th a/ . O jr 30 P• fl4- Eat! f,bt &. nag P et v1 P ,,.# , b& Ps 44 I. To 2,00e) P (. v *• aCEO a rc, Fcorl ± J S La sF"6. C. _P e0/ s , 0) a♦ " . Zed D .eie .011 , A; r w r� LPG a G,� OF'E.► / a c✓r `I aD P s[ ,zcb r 00 f'� lef _ �i 42 L2 6 a� !� u Q (2l 1. . . , --�- 0312)- 03 r A . ,N 4 03 A G 1 6. P /1 . , .n - Z r. , if ( - �.� +r3 1. — t SOO 1 0. L • , . 13 i ke7 TNsJ2 o t , •. .. ►b0 ' bZ F . 5 r 7 P_A�KO — Affi /ELL ^, A — E.J !UMBER SIGNED Z , / 1 GATE •.. Cr / 'ESC RIPTION OF KICK DRILL! 0 WHILE PULLING PIPE C WHILE RUNNING PIPE 0 WHILE GRILLING ❑ MORNING TOUR — WELL CLOSED IN SECONDS, ON STATION SECONDS © EVENING TOUR —WELL CLOSED IN „ SECONDS, ON STATION _ . SECONDS ESC RIPTION OF ACCIDENT! AME OF INJUREO _ EMPLOYE GT REPORT FILED 05/04/2006 11:19 9076597314 NSK WELLS GROUP ill PAGE 07 - . AtlanticRlcl ifieldCompany 4 Drilling —Completion — Workover Loc . _. _ —.- Wok or Bran �. +WII numtrer I wo ,_A r pAa: i 6 / _ Yield Dratrint G ^ unry a / ♦n � _. _ IPrerl no ar nnrto.'n tlm• diplt ion • ho /2 Z i ! �, . D�l� L. 7q !ic>o, Morn. Day T EVA cr.,nVneter Rlp hp and R -., / Q,W.J'�A ,,. dsa!6t 1a c�8y[J2: { . roar down - Dr'rUlnq normal 4 G,.mac ✓ ?_L_. rIwi.(_1 412aa_OgS f_o'r.e..e40.?.� • _ drinlna • ` Ramming" retu It ._ olga3 ! hfg.;74 . Il R• .� /' 7 TriPM it bit {� � f Drll rl r wfth ___�_ 3- �.Q.fV4iA.T^i�!�R.(� � _1 /+_/ g L_Tf� ,C OVUM I �r� rnA I � g V / ' �/ Comhtatlnq loot „" a" .r l_2 r. „ , zt -s e _jt s 7 _.S P /_ D �; ,_6. `e alrculatbn Condllbnlnamud I! f . fy---67• 7 1 D :=P! 4 c '7._.6.41 nv.. r! N Curd Clrtulatlnau p S A r ` ' FlMlnq ■ . r LLe��M1Rr�i li- 1►3r r�r_J- �l�•� . e , ' F DO v latlon auruwy -'•' I Lubricous rip — I z'�� {..►k.�!_Z• d_�_.�O con orr �` .� } �' o doper Ilna ...._ /� /Y• -. • i c_ e ,. (� �RePRb rig e� '491 rdtllnp "• ...L 1 ♦ ,e. is f . ✓�(J F ,p_. t -`Y.�. or 6.0,1 Bide wool . • - ,,, ' �� y 'j ' O r ConvvnllOnal Diamond ,. .le_. -r.•( -- Shoo: or- ° ._mss ./ _ a � 1411:2,_. _�. 1 *Ira lino f • - w .e Doll alert) toot �- _ � - ter` Oboe holR /L�•I► _ rh l n .. 1 r 9f: / ._ ' . � � _ . /f logging epan hole ••••• ' l PIUgg hp bona r . � _ �unninR cooing yam l an6 cemen ling 1t.t7A.c.. . :. Sr7Jit _ q„ay� ' l c n h coaad hple , � "per x Wlrn r ion — 4P—f"- •� ^ell - _.6, A.f ._.2 _ Mat vasod nala IR stem loaf d. _ �/ i wrra .... _ � meebi• — ._.y , w� y,! � o't�.y J ay Tooting _ 3!N -. ..rte, _ __ ".r•N,.�+pJ /.0 , I Rw+tbb a: __ w: lloltllslnp II t 1 r ,..•" - . ... � � • / . ,, . �- Z4 Oa _ Qt ltor _ ... ._ .. _______I--_____:._ Tamil I - M ' tnrwl Or•A Throod CIaO• . ...:- a O.D. coiling ' ma rnumm•my JoJoints 1 et t rM e a Tl _ L -v I Shoo Qoy work ._ ..__ 301 joint our w(dd ...._i_.__ _ Collar Houre . wobip ,, _ I . ._ �.. I Joint!. plea Wows amndby ..... , ' 4 'Rkb to Depth oat Or TO1R1 d ork .I An23.221-11 I . !�•� ..._ r ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor "j') I ~11.1-¡'(D5" DATE: Monday, September 12,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA. INC 1A-02 KUPARUK RIV UNIT 1A-02 /\ \~r ö FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ßV Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT lA-02 Insp Num: mitLG050907074634 Rei Insp Num API Well Number 50-029-20599-00-00 Permit Number: 181-071-0 Inspector Name: Lou Grimaldi Inspection Date: 9/5/2005 Interval REQVAR P/F ~___..____._ Notes Yearly tubing test for variance compliance. Inflatable Bridge Plug set @7495' in between straddle packers and above A V A sleeve. Initially 190 psi decline (1 st min.) then stabilized. Watched additional 15 minutes. Tubing appears to have integrity. Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I I J IA 230 230 230 230 220 -\------ OA 600 600 600 600 600 Tubing 160 3500 3310 3280----r----'3260----i Packer Depth -Well I lA-02 Type Inj. w I TVD ·-----1 5908 P. T.·--r- 1810710 ¡ I TypeTest s~~ I Test psi I 1477 '"' L 1-; £\ (,: 't.n n~ ,ç' ,.", #\ \(\\N'\'tJ' :) iC.f' (.., <~\~"'" ..I Monday, September 12,2005 Page I of 1 Re: KRU IA-02 Failed MIT Subject: Re: KRU lA-02 Failed MIT Date: Thu, 25 Sep 2003 09:57:53 -0800 From: NSK Problem Well Supv <nl 617~conocophillips.com> To: Jim Regg <jim_regg~admin.state.ak.us> CC: nl 617 <nl 617~conocophillips.com> Excuse me if I already answered this--I think I deleted it before I sent it! Anyway, thanks for your diligence in researching this Sundry. You are right about the terms of Sundry 397-037; this was done prior to my tenure here and I did not get the details right. I have made the necessary changes in our tracking system to reflect the casing leak and not T x IA communication. From this point forward we will: 1. Add surface casing pressures on the Monthly Report; 2. Perform quarterly IA fluid levels and add them to the monthly report; 3. Perform 2-year MIT-tubing and NOT perform MITIA/leak rate. The most recent IA fluid levels show them to be at the surface. I researched back through the events that transpired on this well over the past year. The well was shut in on 11/10/02 for flowline repairs. The well was brought back on water injection on 7/25/03. The well had been shut-in at the wellhead with the surface safety valve closed. It would not be routine for the Operator to open the SSV with the well under construction, so depending on where the pressure was read it may have been header pressure. The injection rate over this time period shows zero rate which is accurate, and the IA pressure also looks accurate. Now that the well is back on injection the wellhead pressures and rates appear to be in line. Please let me know if you need further information about this well. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 Jim Regg <jim_regg@admin.state.ak.us> 09/23/2003 08:59 AM To: NSK Problem Well Supv/PPCO@Phillips, Tom Maunder <tom maunder@admin.state.ak.us> cc: Subject: KRU lA-02 Failed MIT AOGCC Inspector Jeff Jones witnessed an MIT at KRU lA-02 on 9/13; his inspection report is attached. He noted that an MITT passed, but a subsequent MITIA failed; he further noted no change in OA pressures during the test. Well currently has an AOGCC approved waiver to continue PWI. Your monthly injection well waiver report indicates the basis for waiver is TxIA because of a failed MITIA (does not appear to be supported by data presented with Sundry 397-037; approved 3/6/97). My review of the well file indicates the basis for the approved waiver was a production casing..lea.k. (suspected leaking 7" stage collar located at 3022 ft MD) according to info provided in support of the sundry, not TxIA communication. As conditions of approval, you were required to: 9/25/2003 10:16 AM Re: KRU lA-02 Failed MIT 1) monitor tubing, inner annulus, outer annulus pressures daily; report these pressures and injection rate monthly 2) check IA fluid level quarterly (monitor PC leak; verify integrity of production packer) 3) MIT well every 2 years (validate tubing as a barrier) A couple concerns - - your monthly injection well wiaver report only provides tubing and IA pressures; there is no information about the OA; also, tubing and IA pressures through late June and early August are questionable - there is no information about the fluid level in the IA; when was the last fluid level determined and what did it indicate?; the most recent info about the fluid level in the IA should be included in the monthly report - unclear what value there is by continuing to perform MITIA (known loss of casing integrity); with a production casing leak, it is necessary to demonstrate tubing and packer integrity; an MITT coupled with monitoring and fluid level checks should be sufficient (and is what was required by the approved sundry) Please review your actions regarding lA-02 and make appropriate changes to be consistent with the AOGCC approved sundry. Jim Regg (See attached file: 2003-0913_MIT_KRU_IA-02_jj.xls) (See attached file: jim_regg.vcf) l~2003-0913 MIT KRU lA-02 jj.xlsI Type: EXCEL Fi~e (ap~-licati~-n/msexcel) :jlEnc°ding: base64 Jim Regg <jim_regg~admin. state.ak.us> Petroleum Engineer AOGCC Administration 2 of 2 9/25/2003 10:16 AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Reudrich Commissioner .. P. I. Supervisor [ DATE: September 13, 2003 FROM' Jeff Jones Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests Conoco-Phillips lA Pad 1A-02 KRU Kuparuk River Field Packer Depth Pretest Initial 15 Min. 30 Min. , Welll 1A-02 ITypelnj. I S I T.V.D. I 5908 Tubing 1840 3080 2980 2940 Interval V P.T.D.I 1810710I IType testI P Test psiI 1477 Casing 160 170 170 170 P/F P Tubing 2080 2300 2300 2250 Interval V Casing 120 2600 1880 1440 P/F F Notes: TTP set below packer ~ 7770' MD for 2 year MIT: Sundry #397-037 'ype INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle ~ V= Required by Variance W= Test during Workover O= Other (describe in notes) September 13, 2003: I traveled to Conoco-Phillips lA Pad in the Kuparuk River Fidd to witness a 2 year MIT on water injection well lA-02, required by AOGCC Sundry #397-037. .~ There is known tubing x IA communication in this well and a tubing tail plug was set below the packer at 7770' RKB MD to facilitate the test. The pre-test pressures were monitored and found to be stable and the MIT was performed in two steps. The tubing was first pressured up and monitored for 30 minutes, passing the MIT. The tubing pressure was reduced to 2080 psi and the standard annulus pressure test was performed with the casing failing the MIT. No increase in the outer annulus pressure ocurred during this test. Summary: I witnessed MIT's on Conoco-Phillips water injection well lA-02 in the Kupamk River Field. M.I.T.'s performed: 2 Number of Failures: 1_ Attachments: Wellbore Schematic (1) n, Total Time during tests: 4 hrs. CC: MIT report form 5/12/00 L.G. OCT 1 I.. 2003 2003-0913_M IT_KRU_ 1A-02_ij.xls 9/22/2003 .KRU IA-02 Failed MIT Subject: KRU lA-02 Failed MIT Date: Tue, 23 Sep 2003 08:59:45-0800 From: Jim Regg <jim_regg~admin.state.ak.us> Organization: AOGCC To: NSK Problem Well Supv <nl 617@conocophillips.com>, Tom Maunder <tom_maunder~admin.state.ak.us> AOGCC Inspector Jeff Jones witnessed an MIT at KRU lA-02 on 9/13; his inspection report is attached. He noted that an MITT passed, but a subsequent MITIA failed; he further noted no change in OA pressures during the test. Well currently has an AOGCC approved waiver to continue PWI. Your monthly injection well waiver report indicates the basis for waiver is TxIA because of a failed MITIA (does not appear to be supported by data presented with Sundry 397-037; approved 3/6/97). My review of the well file indicates the basis for the approved waiver was a production casing leak (suspected leaking 7" stage collar located at 3022 ft MD) according to info provided in support of the sundry, not TxIA communication. As conditions of approval, you were required to: 1) monitor tubing, inner annulus, outer annulus pressures daily; report these pressures and injection rate monthly 2) check IA fluid level quarterly (monitor PC leak; verify integrity of production packer) 3) MIT well every 2 years (validate tubing as a barrier) A couple concerns - - your monthly injection well wiaver report only provides tubing and IA pressures; there is no information about the OA; also, tubing and IA pressures through late June and early August are questionable - there is no information about the fluid level in the IA; when was the last fluid level determined and what did it indicate?; the most recent info about the fluid level in the IA should be included in the monthly report - unclear what value there is by continuing to perform MITIA (known loss of casing integrity); with a production casing leak, it is necessary to demonstrate tubing and packer integrity; an MITT coupled with monitoring and fluid level checks should be sufficient (and is what was required by the approved sundry) Please review your actions regarding lA-02 and make appropriate changes to be consistent with the AOGCC approved sundry. Jim Regg ~2003-0913 MIT KRU 1A-02_jj.xls{ Type: EXCEL Fi~e (ap~licati~n/msexcel) t Jim Regg <jim_regg~admin.state.ak.us> Petroleum Engineer AOGCC Administration 9/23/2003 8:59 AM PHILLIPS Alaska, Inc. A Subsidiary el= PHILLIPS PETROLEUM COMPANY SSSV ~ (1814-1815, 0D:3.500) TUBING (O-7757, 0D:3.500, ID:2.992) SBR (7447-7448, 0D:3.500) Perf (7552-7577) Perf (7601-7626) Perf (7700-7712) SLEEVE (7741-7742, 0D:2.750) TUBING (7757-7780, 0D:2.875, ID:2.441) TUBING (778O-7782, 0D:3.500, ID:2.992) KRU 1A-02 APl:J 500292059900 IJ WellLast Type: J INJj Jl AngleAngle @@ TD:jTSi14642 dew ~ 7554 SSSV Type: i TI~DP W/O: i 12/25/1986 I deg @ 8355 Annular Fluid: I Orig Completion:l 7/2/1981 Rev Reason: Waivered Well by ~mO... Reference Lo<j- .... Rc.f Log. Da[e_L- Last ..U..pdate: ' 114/2002 .... , Last Tag: ~ 786.2 ................... _T._B:.~8. 355 ftKB ..... __ Last .T.a_g..Date:, 10/31!1999 , Max h.'ol~..A._ngl~:..4.~_.d.eg_(¢., 7200 ;_Ca_sins S_t.r. Ln..9_-..._AL.L S.__.T. RJ.N..G_S. Description Size ~'-'~-o¥ ...... i-B-~-~ TVD ' --~i "-G~-d'e Thread CONDUCTOR J 16.000 0 112 112 J 65.00 H40 SUR. CASING J 10.750 0 2902 2663 45.50 K-55 PROD. CASING 7. OOO 0 8337 I ~535 I 26.00 I K-5-_S J Tubin:~!iStii~g',TUBING; :~:' ;;: ~'; ::::~;:. :'41.!. :':;:ii!;: i~,!u!:~;;;i ;':.i ;.ii:,, ;::~ i;;: i;: :=; ; :.!: ; ;i:i::;: :': ::~!;,::;:;":::::' Size Top I Bottom "rVD Wt J 2rade J Thread 3.500 0 J 7757 6107 9.30 "J J-55 J EUE 8RD AB-MOD 2.875 7757 ' 7780 6124 " 6.50 J J-55 I EUE 8RDAB-MOD 3.500 7780 7782 6125 J 9.30 ' J-55 Perforations Summary Interval TVD ' Zone ~ Status 7552-7577 5963- 5980 0-4 7577- 7591 5980- 5990 C-4 C 7601- 7626 5997- 6015 C--~,~-3 7626-7648 6015- 6030 7652- 7654 6033- 6034 7654 - 7688 6034 - 6058 7700 - 7712 6067- 6075 C-I,UNIT B 7796-7850 6135-6174 Ft s'PF Date J Type Comment 25 12 12/23/1EB6J RPERF 120 deg. Ph; 5" HyperJet II 14 0 7/1/19E1 J Sqz 25 12 12/23/1~ 86J RPERF 120 deg. Ph; 5" HyperJet Il 22 0 711/19E 2 12 12/23/1E861RPERF 120 deg. Ph; 5" HyperJet II 34 I 16 112/2311E [RPERF 120deg. Ph;5"HyperJetll 12 0' 7/1/19E 186 / 154 I 4 I ~/1/19E 1 I. IPER~ 120 deg. pl~.~,van?.Gun .... Type t Comment Cement Squeeze; I Reperfed 7552-7577 on 12/23/86 (we)) Cement Squeeze; Reperfed 7601-7626 on 23/23/86 (we) CementCement SqueeZesqueeze Reperfed 7652-7688 on 12/23/86 (we) VIv Cmnt Interval Date, 7552 - 7591 7/1/1981 7601 - 7648 711/1981 7654 - 7654 7/1/1981 7700 - 7712 7/1/1981 Gas Lift Mandrels/Valves St j MD J TVD J Man Man j V Mfr I VType I V OD I LatCh I'Port I TROI Date Mil' Type Run 1 3063 2772 Camco KBUG DMY 1.0 BK 0.000 0 11/19/1991 2 4454 3715 Cam.co KBUG ' DMY 1.0 BK 0.000 0 111/19/1991 3 48771 40091 Camco KBUG ~, DMY 1.0 I BK 0.000 0 11/19/1991 4 I 5246~ 4273 CamcO) KBUG DMY I 1 0 [ BK 0.000 I 0 H1/18/1991 5 56151 4547 Camco KBUG DMY 1.0 BK 0.000 0 11/19/1991 615983 4824 Camco KBUG I i DMY '1.0 BK 0.000 0 111/18/1991 7 62955062J Camco KBUG I DMY 1.0 BK J 0.000 0 '11/19/1991 8 6659 5340 Camco KBUG I DMY 1.0 BK 0.000 0 11/19/1991 9 703015609 Camco I KBUG DMY I 1.0 BK 0.000 0 12/25/1986 1017401j 58581 Otis J LBX _L I DMY i 1.5 J RO-510.000 0112/25/1986 In action Mandrels/Valves ' ' VIv Cmnt Description ID SSSV Camco q'RDP-1A-ENC' 2.813 ' SBR Baker 2.813 2.891 2,313 2.750 3.250 2.250 2.992 PKR SLEEVE Baker 'FHL' hyd set Set 2.75" AVA TPI SLEEVE new style 10/31/99. NIP AVA BPL NIPPLE PKR Baker 'DB' NIP Camco 'D' Nipple NO GO SOS Otis TTL 2.992 Description Lock Key from Comment AVA BIP left in hole. Depth unknown. Vann Gun 340.14 ong ;Ge:n.~'ral;fN~t~s ~...;,.i:,'?i ::' .:.:.......': :.: ..::~. :.:.:..'.~.., :..i :,.:.....:......::::...:.... '::...:....:~'.:.:?..:': :::,:.:!.' :::.:',~i. :'..i::ii :,:i;'::.::..';:..:,..':;' :i.':u..':. ':i:..... ::::..:').:.'i.~.":::.'ii: :'... '::i=?:.::. ~':, ;. ii: ;~% .i Date I Note 1~18/20011WAIVERED WELL - T x IA Communication 1TP '777o' (OdMS) ~eB 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 LO 0 LO 0 I~ 0 LO 0 0 LO ~ ~ cO CO C~I C~I ~ ~ LO 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 LO 0 LO 0 LO CO 04 0~1 ~-- ~-' (!sd) e~nsse~d % % % % % .'- - STATE OFALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend__ Operation Shutdown __ Re-enter suspended well__ Alter casing -- Repair well __ Plugging __ Time extension Stimulate Change approved program _ Pull tubing __ Variance X_ P'~erforate __ O'~"er' __ 2. Na~ne of Operator 5..Type of Well: 6. Datum elevation (DF or KB) "Development ~ ARCO Alaska, Inc.. Exploratory .-- .RKB 100 .. feet 3. Address Stratigraphic __ 7. Unit or Property name ip. O. Box 100360, Anchorage, AK 99510 Service,. y Kuparuk River Unit . . 4. Location of Well at surface 8. Well number 1259' FSL, 313' FWL, Sec. 5, T11N, R10E, UM 1A-02 At top of productive interval 9. Permit number 1172' FSL, 3750' FWL, Sec. 6, T11N, R10E, UM . 8.1-7 1 At effective depth ORIGINAl 10. APl number 1297' FSL, 4211"FEL, Sec. 6, T11N, R10E, UM 50-_0_29-20599 At total depth '11. Field/Pool 1312' FSL, 4344' FE.L, Sec. 6~ T11N, R10E, UM ..... Kuparuk' River Oil Field/Pool 12. Present well 'condition summary Total Depth: measured 8355 feet Plugs (measured) None ¢= true vertical 6548 feet 8242 feet Junk (measured) Vann Gun, 324' long.'@ 7375' Effective i~th: ,~measured 1'-., Eotrue vertical 6464 feet Casing ~" ~ ~.~gth Size Cemented Measured depth True vertical depth Structural----- I'--- Conduct(JrLJ .c~! 1 1 2' 1 6" 200 Sx PF 1 1 2' 112' Surface ~', ¢ ~: 2902' 1 0-3/4" 1650 Sx Fondu & 2902' 2662' Intermed~'ate. t,a..I ~ ' 250 Sx AS I! Productior~ u.,. ~ 8337' 7" 838 Sx Class G & 8337" 6535' Liner "~ 400 Sx AS II Perforation Depth 7552'-7591, 7601'-7648', 7654'-7688', 7700'-7712', 7796"'-~-850' true vertical 5962'-5990', 5999'-6030', 6034'-6059', 6067'-6075', '6135'-6174' Tubing (size, grade, and measured depth) " J I ' 3:5, 9;3#, ,55.::@ 75 0 packers"a'nd ~Ssv (type and measured depth)' Pkr: Baker FH @ 7455', Baker 'DB' ~.. 7734; SSSV: Camco TRDP-1A-SSA @ 1795' 13. Aitachments Description summary of propOSal X Detailed operation program .- B~)P sketch._. CONTINUE INJECTION AS IS 14. Estimated date for Commencing operation i5. Status of well classification as: ' ... Oil . Gas..._. Suspended 16. If proposal was verbally approved o ,. Name of f~over Date approved Service X and correct to' the best"'of my knowledge. 17."' I he~ebt, c/eftifY that JJ~l fgr.e.,8oing is ~rue U , Title Wells Superintendent ,,, Date Sig ed i FOR COMMISSION USE ONLY Conditior¢' of approval: Notify Commission so ~presentative may witness IAppro_vai"No. ' Plug integrity BOP Test _ _ Location clearance I Mechanical IntegrityTest I~, ~Ue.f~,l ~,~i~bs.e~en~,~f°rm re~ire 10-,, " 'Original Signecl Ely q !.Approved by order o,f, the Commission ~J~lvid W.._io.h..n.£?~~ Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT II [PLICATE Attachment 1 Request for Variance Kuparuk Well 1A-02 As per Area Injection Order No. 2, Rule 7, ARCO Alaska is hereby notifying the Commission of a small production casing leak in a KRU drillsite lA water alternating miscible gas (WAG) injection well 1A-02. As set forth in the Rule 7, ARCO Alaska is requesting Commission approval to continue water injection into this well. As found in Area Injection Order No. 2, the aquifers described by a 1/4 mile area beyond and lying directly below the Kuparuk River Unit are exempted for Class II injection activities by 40 CFR 147.102(b) (3) and 20 AAC 25.440(c). As. such, continued injection will not endanger any Underground Source of Drinking Water (USDW). History. 1A-02 passed a mechanical integrity test (MIT) on May 21, 1995. Starting July 23,1996, 1A-02 was temporarily utilized for injection of drillsite lA reserve pit water. Two..days into ,this effort it was determined that the production casing x tubing an.n,,ulus had imbibed approximately 50 bbls of diesel while holding ~,' 3500 psi "backside pressure to prevent significant tubing movement due to high tubing pressures applied during the pit water injection operations. Upon recognition of this, pit water injection into the well was suspended and the production casing x tubing annulus pressure was ,bled.back toits normal operating pressure range (approximately 500 psi); The production casing x surface casing packoff was tested July 28, 1996 and found to be leaking, the lock down screws were retorqued and the packoff was subsequently tested to 3000 psi and .passed. When we rigged back up to continue pit water injection, we found the production casing x tubing annulus was still taking fluid at 3500 psi backside pressure. Upon determining this, pit water injection operations were discontinued. On August 19; 1996, the production casing x surface.casing packoff was again checked and found to be pressure tight. Well work operations to determine the nature and extent of the suspected 7" casing leak were planned. As there was no indication of a tubing leak which would allow migration of injected fluids out of the Kuparuk injection interval, normal waterflood injection operations were continued. On September 18, 1996 the Kuparuk C sand was isolated by installation of an isolation sleeve at 7722' MD. On September 19, a standing valve was set in the D 'nipple at 7751' MD and the tubing was successfully pressure tested to 4000 psi with a loss of 100 psi in 30 minutes. With the tubing at 3000 psi, the .production casing x tubing annulus was pressure tested to 3000 psi (twice) which subsequently bled off to 2600 psi in 15 minutes. Following these tests, the standing valve was retrieved and the well was returned to service on waterflood injection. Page 1 of 2 Attachment 1 Request for Variance Kuparuk Well 1A-02 Analysis ~ ~view of relevant eom letion data stroh I sa ests the cause of the cusiP' fluid"~- '''~/''~ ~ p g,y gg causeoT[ne ~ ~ ~on ' casing leaks at Kuparul~ have been in wells com~.[~_ted ~ ~-with stage collars in the 7" casing string. ~'~reeen~tabi~~?~~~'~"~ ~ ~,ne~~~~:i~~.ow~ann utar~?pressures~in dicates .~i~~e ~ Recommendation Given the current condition of KRU 1A-02, AAI perceives no significant risk of fluid migration to non-exempt fresh water intervals or loss of hydrocarbon resources with continued operation of KRU 1A-02 as is. AAI therefore requests the Commission approve continued operation of this well as a water alternating miscible gas injector. AAI requests the Commission approve tubing pressure tests as a 'substitute for the four year annular MIT requirement. Tubing pressure tests combined with normal daily monitoring of production casing x tubing pressure under normal water alternating miscible gas service should suffice to ensure protection of underground sources of drinking water and mitigate any potential loss of hydrocarbon resources. Page 2 of 2 // KRU WAG Injector 1A-02 Proposed Operating Plan Under Waivered Production Casing Leak O~ily U..onitoring The drill site operator (DSO) will monitor the production casing x tubing annulus pressure daily (unless weather or urgent operational needs prevented it) and update the morning report daily. The annular gauge will be zeroed weekly. A placard will be installed on the 7" annulus instructing the DSO to notify the drill site supervisor an'd engineer at any abrupt change in the casing x tubing annulus pressure. Additionally, a pressure transmitter would be installed on the production casing x tubing annulus and Programmed to alarm to the board operator at high pressure or high rate of pressure change, Quarterly,, Monitoring Check'the fluid level in the production casing x tubing annulus. A reminder notification will set up in the PM system to be forwarded to the drill=site lA Petroleum Engineer (DSE) on a quarterly basis. The DSE will ensure the fluid level is obtained analyzed and placed in the CPF and central well file and the DSE's well notebook. Yearly Monitoring A casing MIT will not be possible, A 4000 psi tubing pressure test should be conducted yearly with the C sand isolated and a plug or standing valve set in the, tubing tail D nipple. The MIT's will be documented in the CPF and central well file wellfiles and recorded on the in house MIT schedule. ARCO Alaska, In=. Kupamk'Operation$ Post Office Box 196105 Anohorage, Alaska 99619-6105 1A4)2 Monitoring Report SI DATA Z S GAS WATER GAS C O T CMOF~ 7" 10" LIFT INJ INJ H M O N A OR AM~ CSG CSG VOL VOL VOL R I D DATE E T % FTP FTT T~P PSI PSI MSCF BBLS MMSCF 8 N ~ 04/01 B SW ~ 15 2319 141 -21 616 610 04/02 B Sw MM 15 2238 141 -13 616 603 0 5247 0,000 0000 0 0 5249 0,000 0000 O. 04/03 n SW 1~{ 15 2251 141 04/04 B SW MM 15 2253 133 04/05 a SW NI~ 0 1949 68 04/06 B SW ~ 10 276? 76 04/07 B MI MM 10 3168 136 -8 615 603 0 5248 0,000 0000 0 -11 603 596 0 BO30 O,O00 0000 0 -9 535 549 0 105 1,197 1442 51 -4 550 549 0 4268 0,000 0000 0 2 630 623 0 0 11,919 0000 0 04/08 B MI ~m~ 10 3169 135 1 624 627 04/09 B MI ~ 10 3168 133 -5 615 623 04/10 B MI MM 10 3157 136 -9 616 622 04/11 B M! MM 10 3133 130 -8 605 618 04/12 B MI MM 10 3119 130 -10 608 619 0 0 12,431 0000 0 0 0 12.816 0000 0 0 0 12,725 0000 0 0 0 12.661 0000 0 0 0 12,915 0000 0 04/13 B GI MM 10 3109 130 -16 608 681 04/14 B GI MM 10 3097 132 -13 612 628 04/15 B MI ~4 10 3088 135 -6 614 614 04/16 B MI MM 10 3087 137 2 619 620 04/17 B MI MM 10 3091 135 6 614 617 0 0 12,912 0000 0 0 0 12,814 0000 0 0 0 12,625 0000 0 0 0 12,620 0000 0 0 0 12.969 0000 0 04/18 B MI MM 10 3083 139 04/19 B MI MM 10 3066 136 04/20 B MI ~ 10 3053 136 04/21 B MI MM 10 3062 146 04/22 B MI MM 10 3070 143 11 623 624 8 618 624 8 617 621 3 635 630 -6 628 628 0 0 13,739 0000 0 0 0 12,603 0000 0 0 0 12.229 0000 0 0 0 13,043 0000 0 0 0 13,669 0000 0 04/23 B MI MM 10 3068 140 04/24 B NI ~ 10 3055 131 04/25 B MI MM 10 3055 134 04/26 B MI MM 10 3054 134 04/27 B MI MM 10 3053 133 -4 620 623 -7 609 613 -5 617 616 -6 619 616 -4 618 613 0 0 13,939 0000 0 0 0 14,165 0000 0 0 0 14.022 0000 0 0 0 13.910 0000 0 0 0 13,981 0000 0 04/28 B MI ~ 10 3053 136 04/29 ~ Mi ~,M 10 3053 136 04/30 $ MI MM 10 3038 142 0 623 614 3 62Z 614 19 633 622 SRTJT-IN CODE 36 = FLOW LINE MAI~ENANCE SHUT-IN CODE 51 = WA~I.W~L SWITCH OVER 0 0 i3,S94 0000 0 0 0 13.804 0000 0 0 0 13.535 0000 0 -.SENT BY :ARCO ALASI~ : 3- 8-99 ; 9:00A1~1 : RPS/~FI.I.S/CNST/PROJ-~ ARCO Alaska, Inc,, Kuparuk Operations Post Offk)e Box 19~105 Anchorage, Alaska 99519-6105 907 276 7542;# 1/ 7 1A.02 Monitoring Report 8I DATA ~, S ~A,q WAqP%'J[ GAS C O l' CItOK~, 'I" 10" LIFT ZNJ ~NJ H M 0 ~ A 0]'{ ~ ~ CS~ VOL VOl., ~5 R I D DATE ~ T % FTP FTT TE~ PBI P9~ MSCF B~S ~CF S N E 02/01 B ~w 20 2180 119 -38* 548 533 0 3289 0.000 0000 0 02102 B 8w 45 2225 130 -33 591 580 0 3971 0.000 0000 0 02/03 B SW 45 2242 129 -23 573 588 0 3288 0,000 0000 0 02/04 B SW 45 2259 130 -30 567 620 0 3287 0.000 0000 O 02/05 B SW 45 2269 130 -35 56~ .611 0 3290 0,000 0000 0 02/06 B SW 45 2278 130 -36 565 608 0 3286 U.00O 0000 0 02/07 B SW 45 2290 130 -31 565 604 0 3291 D.000 0000 0 02/08 O SW 45 2300 129 -38 566 609 0 3290 0.000 0000 0 02/09 m SW 45 2305 129 ,-4~ 566 609 0 3285 0,000 0000 0 02/10 B SW 45 2157 122 -43 SS? 578 0 3022 0,000 OD00 0 02/11 B ,qW 4~ 1482 89 -2t 509 538 0 1444 0.000 0000 0 02112 B SW 45 2319 132 -10 621 597 0 3~A9 (].000 0000 0 02/13 B SW 45 2~54 133 -15 604 603 0 3289 0,000 0000 0 02/14 B ~W 45 2365 130 -15 583 603 0 3287 0,000 0000 0 02/15 B SW 45 2365 130 -19 577 603 0 328~ 0.000 0000 0 02/16 B SW 45 3379 134 -15 5,86 606 0 3291 0.000 0000 0 02/17 B SW 45 2387 132 -17 5.80 607 0 328'7 0.000 0000 0 02/1~ B SW 45 23,83 133 -4 585 605 0 328'6 0.000 0000 0 02/19 B GW 45 2387 136 -3 593 613 0 3291 0.000 0000 0 02/20 B SW 45 2391 135 -7 588 612 0 32~7 0.000 0000 0 02/21 B SW 15 ~,381 127 -10 576 608 0 32';0 0.000 0000 0 02/22 B SW 45 2'~87 137 -5 620 615 0 32~7 0.000 0000 0 02/23 B SW 45 2392 132 -13 b98 6].0 0 329,0 0,000 0000 0 02/24 B SW 45 2396 132 -14 f895 610 0 3288 0,000 0000 O 02/25 B SW 45 2400 130 -6 '589 606 0 328~8 0,000 0000 0 02/26 B SW 45 2404 129 -10 587 603 0 3290 0,000 OD00 0 02/27 ~ SW 45 2410 140 -10 614 615 O 32H$ 0,000 0000 0 02/28 B SW d5 1935 135 -16 589 605 0 ~91~ 0.000 0000 0 SHUT-IN CODE 51 = WAMI W~LL SWITCH OVER ARCO Alike, Inc. Is a SubSidiary of AtMnlle Rlchllaid Corep~ny RECEIVED UAR 1999 Alaska Oil & Gas uo.$. (;.O, mmi~lm,.. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter casing ~ Repair well Change approved program 99510--'I 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK Suspend __ __ Plugging Pull tubing 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1259' FSL, 313' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1172' FSL, 3750' FWL, Sec. 6, T11N, R10E, UM At effective depth 1297' FSL, 4211' FEL, Sec. 6, T11N, R10E, UM At total depth 1312' FSL, 4344' FEL, Sec. 6, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical Effective i~th: ~measured ~ true vertical Casing ~" cr~., ~¢~1_~-~ g t h Structural--- I"-- r~ ~ 2' Conductc~r.t..I O,! ~ 1 1 Surface ~'- (33 ~- 2902' Intermed~'ate, t.z.I '~ Productior~- LL. ~ ~ 8337' Liner Perforation Depth 7552'-7591, true vertical 5962'-5990', Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7510' Operation Shutdown Re-enter suspended well Time extension Stimulate Variance X Perforate ~ Other __ 6. Datum elevation (DF or KB) RKB 100 Pkr: 3. 0RIGINA[ 7. Unit or Property name Kuparuk River Unit 8. Well number 1A-02 9. Permit number 81 -71 10. APl number 50-029-20599 =11. Field/Pool Kuparuk River Oil Field/Pool 8355 feet 6548 feet feet Plugs (measured) None 8242 feet 6464 feet Junk (measured) Vann Gun, 324' long '@ 7375' Size Cemented 1 6" 200 Sx PF 1 0 - 3 / 4" 1650 Sx Fondu & 250 Sx AS II 7" 838 Sx Class G & 400 Sx AS II Measured depth True vertical depth 112' 112' 2 9 0 2' 2662' 8337' 6535' 7601'-7648', 5999'-6030', 7654'-7688', 6034'-6059', 7700'-7712', 6067'-6075', Packers and SSSV (type and measured depth) Baker FH @ 7455', Baker 'DB' @ 7734; SSSV: Camco TRDP-1A-SSA @ 1795' Attachments Description summary of proposal X Detailed operation program __ CONTINUE INJECTION AS IS 7796'-~50' 6135'-6174' BOP sketch 4. Estimated date for commencing operation 15. Status of well classification as: Gas . 16. If proposal was verbally approved Name of~C"~over Date approved Service X 17. I herebtTify tha.~oing is ,rue and correct to the best of my knowledge. ISigned /,,~~'¢'~q~,,~ Title Wells Superintendent '- / - ORCOMM,SS,ONUS ON Y /Conditior~ of approval: Notify Commission so representative may witness Suspended Date ~""~'~--- ~"~ U IAppro_val No. _ Plug integrity BOP Test Location clearance I Mechanical Integrity Test ,1~ ~Ue.¢~,l ~ S~s..e-eqJJ~form require 10-, ¢ /drioinal Signed By Approved by order of the Commission ~vid ~ _inhnefn~ Commissioner Date Form 10-403 Rev 06/15/88 ................. SUBMIT I~ TRIPLICATE Attachment 1 Request for Variance Kuparuk Well 1A-02 As per Area Injection Order No. 2, Rule 7, ARCO Alaska is hereby notifying the Commission of a small production casing leak in a KRU drillsite lA water alternating miscible gas (WAG) injection well 1A-02. As set forth in the Rule 7, ARCO Alaska is requesting Commission approval to continue water injection into this well. As found in Area Injection Order No. 2, the aquifers described by a 1/4 mile area beyond and lying directly below the Kuparuk River Unit are exempted for Class II injection activities by 40 CFR 147.102(b) (3) and 20 AAC 25.440(c). As. such, continued injection will not endanger any Underground Source of Drinking Water (USDW). History 1A-02 passed a mechanical integrity test (MIT) on May 21, 1995. Starting July 23, 1996, 1A-02 was temporarily utilized for injection of drillsite lA .5.~t~ ~ reserve pit water. Two days into this effort it was determined that the production ~'~ casing x tubing an.n,,ulus had imbibed approximately 50 bbls of diesel while holding ~'.~,~¥ 3500 psi "backside pressure to prevent significant tubing movement due to high tubing pressures applied during the pit water injection operations. Upon recognitionr',~,~'"" of this, pit water injection into the well was suspended and the production casing x ~,,,j~' tubing annulus pressure was bled back to its normal operating pressure range (approximately 500 psi). The production casing x surface casing packoff was tested July 28, 1996 and found to be leaking, the lock down screws were retorqued and the packoff was subsequently tested to 3000 psi and passed. When we rigged back up to continue pit water injection, we found the production casing x tubing annulus was still taking fluid at 3500 psi backside pressure. Upon determining this, pit water injection operations were discontinued. On August 19, 1996, the production casing x surface casing packoff was again checked and found to be pressure tight. Well work operations to determine the nature and extent of the suspected 7" casing leak were planned. As there was no indication of a tubing leak which would allow migration of injected fluids out of the Kuparuk injection interval, normal waterflood injection operations were continued. On September 18, 1996 the Kuparuk C sand was isolated by installation of an isolation sleeve at 7722' MD. On September 19, a standing valve was set in the D 'nipple at 7751' MD and the tubing was successfully pressure tested to 4000 psi with a loss of 100 psi in 30 minutes. With the tubing at 3000 psi, the production casing x tubing annulus was pressure tested to 3000 psi (twice) which subsequently bled off to 2600 psi in 15 minutes. FolloWing these tests, the standing valve was retrieved and the well was returned to service on waterflood injection. R£c IV D Page 1 of 2 011 & B~An~t~0r ~3~ C~. G0mmiss~. Attachment 1 Request for Variance Kuparuk Well 1A-02 Analysis A review of relevant completion data strongly suggests the cause of the casing fluid loss noted during pit water disposal is the 7" stage collar at 3022' MD. To date, the only known instances of 7" casing leaks at Kuparuk have been in wells completed with stage collars in the 7" casing string. The recent tubing string pressure test combined with a steady history of Iow annular pressures indicates injected fluids are contained within the Kuparuk reservoir. Recommendation Given the current condition of KRU 1A-02, AAI perceives no significant risk of fluid migration to non-exempt fresh water intervals or loss of hydrocarbon resources with continued operation of KRU 1A-02 as is. AAI therefore requests the Commission approve continued operation of this well as a water alternating miscible gas injector. AAI requests the Commission approve tubing pressure tests as a substitute for the four year annular MIT requirement. Tubing pressure tests combined with normal daily monitoring of production casing x tubing pressure under normal water alternating miscible gas service should suffice to ensure protection of underground sources of drinking water and mitigate any potential loss of hydrocarbon resources. Page 2 of 2 KRU WAG Injector 1A-02 Proposed Operating Plan Under Waivered Production Casing Leak Daily Monitoring The drill site operator (DSO) will monitor the production casing x tubing annulus pressure daily (unless weather or urgent operational needs prevented it) and update the morning report daily. The annular gauge will be zeroed weekly. A placard will be installed on the 7" annulus instructing the DSO to notify the drill site supervisor and engineer at any abrupt change in the casing x tubing annulus pressure. Additionally, a pressure transmitter would be installed on the production casing x tubing annulus and programmed to alarm to the board operator at high pressure or high rate of pressure change. Quarterly Monitoring Check the fluid level in the production casing x tubing annulus. A reminder notification will set up in the PM system to be forwarded to the drill: site lA Petroleum Engineer (DSE) on a quarterly basis. The DSE will ensure the fluid level is obtained analyzed and placed in the CPF and central well file and the DSE's well notebook. Yearly Monitoring A casing MIT will not be possible. A 4000 psi tubing pressure test should be conducted yearly with the C sand isolated and a plug or standing valve set in the, tubing tail D nipple. The MIT's will be documented in the CPF and central well file wellfiles and recorded on the in house MIT schedule. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: ARCO Alaska~ Inc.. .. FIELD ! UNIT / PAD: KUPARUK / KRU / 1A-PAD DATE: 5/21/95 ii!ii i !! i!! COMMENTS: 5, a04 7,455, COMMENTS: 1A-05 COMMENTS: .2,725 1,700 LI .. 2,725 I, 620 u i' 2,725 1,580 1,71o l 1,7ool ~,~o l G DIESEL I ~,~2~ i' 7" / 2'~ / K-5S ~.~ ' ~,~'oo" ~,,~o I .~,~'o,,, I' e,e~,o "1 ...... '~,'~ "i ,'o;oo,~ ' ' ' I ~,7451 1,~8O l l, eeo l 1, eeO l 1, eeo I This well was bled down'~om 2500 PSIG to 1500 PSlG the day prior to te~t. Communication between tubing and oasing , is known t° exist and a,. wa~er is being sought. ,. Pres..sUm in casing held finn during, te~.,. ................... *TUBING INJECTION FLUID: P = PRODUCED WATER INJ. S = SALT WATER INJ M = MISCIBLE INJ. I = INJECTION N = NOT INJECTING ANNULAR FLUID: DIESEL GLYCOL - SALT WATER DRILLING MUD OTHER P.P.G. Grad. ,,, i i WELL TEST: Initial 4 - Year X Workover Other 1A'05 Distribution: orig - Well File c - Operator c- Database c - Trip Rpt File c - Inspector AOGCC REP.: OPERATOR REP.: IA_MIT. XL8 Jerry Herring' Eric Zuspan ... ,.,.~ ARCO Alaska, Inc. ' '~ Post Office B~,.. J00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 /Ffl I G June 8, 1992 Mr. Lonnie C. Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached in duplicate are multiple Report of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION WELL ACTION 1A-02 Cony. to Water Inj. 1A-04 1A-05 Conv. to Water Inj. 3N-02A 3Q-03 Fracture 3Q-04 3Q-07 Fracture Cony. to Water Inj. Fracture Fracture If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Operations Engineer cc: J.D. Bolling ATO-1196 KOE1.4-9 (w/o attachments) (w/o attachments) RECEIVED JUN 1 0 1992 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichtieldCompany AF:~;-' ;:~' ORIGINAL REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Pull tubing Alter casing Stimulate i Plugging Perforate Repair well Other X 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ~ Exploratory _ Stratigraphic Service ~ ~r~ , Location of well at surface 1259' FSL, 313' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1172' FSL, 3750' FEL, Sec. 6, T11N, At effective depth 1297' FSL, 4211' FEL, Sec. 6, T11N, At total depth ! 312' FSL~ 4344' FEL~ Sec. 6r T11N, R10E, UM R10E, UM R10E, UM 12. Present well condition summary Total Depth: measured 8 3 5 5' true vertical 6 548' feet feet Plugs (measured) Effective depth: measured 8242' true vertical 6 4 6 4' feet Junk (measured) feet Casing Conductor Surface Length Size 112' 16" 2902' 10 3/4" 8337' 7" Production Perforation depth: measured 7552'-7577', true vertical 5962'-5980', Tubing (size, grade, and measured depth) 6. Datum elevation (DF or KB) 100' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1A-02 9. Approval number 538 //'~-~,,~,'z%¢ ~/- 10. APl number 50-029-;~05~)~) 11. Field/Pool Kuparuk River Oil Pool Vann gun fish @ 7902' WLM Cemented Measured depth True vertical depth 200Sx PF 112' 112' 1650 Sx Fondu & 2 9 0 2' 2 6 6 2' 250 Sx AS II 838 Sx Class G & 8837' 6535' 250 Sx AS II 7601'-7626',7652'-7688', 5999'-6014', 6033'-6059', 3 1/2" 9.3#, J-55, tubing tail @ 7782' Packers and SSSV (type and measured depth) FHL pkr ~ 7474'~ DB pkr ~ 7753'~ TRDP-1A-ENC ~ 1814' 13. Stimulation or cement squeeze summary Convert well to water injection. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 7796'-7850' 6135'-6174' RECEIVED JUN 1 0 1992 Alaska 0il & Gas Cons. Commissi0II Anchorage 14. Reoresentative Daily Averaae Production or Iniection Data - OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 600 900 4500 1250 300 Subsec~uent to operation 0 - 0 - 45 0 0 5 5 0 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Water Injector X Daily Report of Well Operations X Oil Gas Suspended ;17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 235O Form 10-404 Rev 09/12/90 Date SUBMIT IN DUIbLICATE ~,~ WELL '.~.RCO Alaska, Inc..~ Subsidiary of Atlantic Richfield Compan. IPBDT "ONTRACTOR REMARKS · :~ /TD - l'~tc. (.: 7" c~¢- tq~:c ~,~z ID, cEa ~c,e FIELD - DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT IDA5S 1DATE I /i-/¢-(// lq4~' 1655 /7/,: /'Zo~,, i iq$c RECEIVED J UN 1 0 1992 Alaska Oil & Gas Cons. Commission · Px~Ess~E ?~.TTE/~ 7" ~uctz. as '~. ~c~-.c.~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weat~Re~fl [ Temp.*F ~ Chill Factor I Wind Vel. knots ~ Slgn~ .,Iv','"'''', .,,.. 'A_RCO Alaska, Inc-~ Subsidiary of Atlantic Richfield Compan~ . I Al - ~ E,~'+~' I /~£/d ~ON ~~~ ·/~ ~/~ I~OPERATION AT RE~RT TIME '"ONTRACTOR REMARKS WELL SERVICE REPOR1 Il,On o , , · II !1.1 uu,~ 1 0 'moo Alaska Oil & G~ ,.,u,,~,. ,.,u,,,,, ...... Anchorage I--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots W Z S E 0 T L N A L E T 1 B PR 3 B PR 8 B PR 10 B SI 17 A PR 18 B PR 19 B PR 20 B PR 22 B PR 23 B PR 25 B TS 26 A PR 27 B PR 28 B PR TOTALS: W Z S E 0 T L N A L E T 2 B SW 4 B SW 5 B SW 6 B SW 7 B SW 9 B SW 11B PW 12 B SW 13 B PW 14 B PW 15 B PW 16 B SW TOTALS: KDGS MORNING WELL REPORT FOR 05/06/92 DRILLSITE lA PA~E 1 PRODUCTION WELL STATUS ---- 7" 10" TP TT WC H2S CSg CSg PSI CH½ DEG % PPM PSI PSI GAS LIFT STATUS --- SI CN GAS INd AH TEMP METER VOL1S LI DEg READING MSCF EB S/I IMPACT C H M 0 R I D EPL S N E BBLS 268 176 134 80 150 900 750 315 176 121 55 50 1280 925 314 176 122 60 25 I220 950 0 0 0 79 40 1400 50 269 176 96 60 175 1400 20 264 176 102 64 80 1600 130 340 176 128 70 200 1400 100 274 176 80 2 257 176 103 10 282 176 145 80 267 176 115 40 250 176 68 7 268 176 138 60 261 176 74 20 0 920 60 0 980 700 0 1780 625 50 1150 275 0 850 500 15 2000 930 0 990 290 0 0 0 0 0 0 0 0 77 0 793 0 0 0 0 0 0 0 0 0 32 0 982 0 0 0 0 0 77 0 480 0 78 0 305 0 0 0 0 0 78 0 882 0 76 0 48O 0 0 0 0 0 79 0 492 0 0000 0 0 0000 0 0 0000 0 0 2400 35 372 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 4414 0 372 INdECTION WELL STATUS INdECTION VOLUME S/I ALLOW PSI ACT 7" 10" INd TT CSg CSg PSI DEg CHK PSI PSI 2500 ~ 84 25~~00 2500 2366 78 10 1400 200 2500 2361 84 ~°0 1050 450 2500 3609 78 (i~_p 350 250 2500 2363 78 10 50 40 2500 2259 80 47 1200 225 2500 2326 142 66 1050 50 2500 1504 81 6 1000 990 2500 2108 143 38 450 350 2500 2306 142 66 250 160 2500 2217 143 80 1290 850 2500 2343 81 20 100 50 INJ INJ METER VOLS VOLS READING BBLS MMSCF 60 000 0 000 0 3258 0 000 0 681 0 000 0 507 0 000 0 3472 0 000 0 2222 0 000 0 5735 0 000 0 4907 0.000 0 3538 0.000 0 7722 0.000 0 8544 0.000 C H M 0 R I D S N E 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 SWI: 27263 + PWI: 18389 = 45652 0.000 RECEIVED JUN 1 0 199~ Alaska Oil & Gas Oons, GommiSs'~oo Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501.3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 JUNE 9, 1992 WATTy STRICKLAND ARCO ALASKA IN. P O BOX 1900360 ANCHORAGE, ALASKA 99510 RE: 85-0163 81-0071 81-0096 81-0104 86'0141 KUPARUK RIVER UNIT KUPARUK RIVER UNIT KUPARUK RIVER UNIT KUPARUK RIVER UNIT KUPARUK RIVER UNIT 3J-2 lA-2 lA-4 lA-5 2T-2 DEAR MR. STRICKLAND, OUR FILES INDICATE THAT ARCO ALASKA INC. IS THE OPERATOR FOR THE REFERENCED WELLS. OUR FILES ARE MISSING PAPER WORK FOR THE CONVERSION OF THESE WELLS AS I MENTION APRIL 29, 1992 IN A CONVERSATION I HAD WITH YOU . THESE WELLS· HAD 403'S' SUBMITTED IN NOVEMBER' OF 1991 TO CONVERT OIL TO WATER-INJECTORS AND OUR MONTHLY PRODUCTION REPORTS SHOW THESE WELLS W~RE CONVERTED IN NOVEMBER AND AOGCC DIDN'T RECEIVE THE 404'S ONCE THE coNVERSION WAS COMPLETED. THIS MATTER NEEDS TO BE CORRECTED SO OUR FILE ARE CURRENT AND UP TO DATE. . . WOULD 'YOU PLEASE CHECK THIS PROBLEM AND FORWARD THE APPROPRIATE DOCUMENTS TO ME. SINCERELY, STEVE MCMAINS STATISTICAL TECHNICIAN C: ROBERT CRANDALL SR PETR GEOLOGIST .. ARCO AP~ska, Inc. ')~' Post Office Box'100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 13, 1990 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Start Date 1A-02 1A-04 1A-05 Cony to WAG Inj Conv to WAG Inj Cony to WAG Inj December, 1991 December, 1991 December, 1991 If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Operations Engineer J. D. Bolling M. C. Pearson KOE1.4-9 ATO- 1196 ATO-1176 (w/o attachments) (w/o attachments) RECEIVED [ ov 1 5 1991 Alaska 0ii & Gas Cons. Cornm~ss~or~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C APPLICATION FOR SUNDRY APPROVALS OlllGINAI 1. Type of Request: Abandon Suspend Alter casing _ Repair well _ Change approved program X 2. Name of Operator AR~O Alaska. IBc, 3. Address P. O. Box 100360, Anchorage, AK 99510 $. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1259' FSL, 313' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1172' FSL, 3750' FEL, Sec. 6, T11N, R10E, UM At effective depth 1297' FSL, 4211' FEL, Sec. 6, T11N, R10E, UM At total depth 1312' FSL~ 4344' FELt Sec. 6~ '!'11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 8 3 5 5' fe et true vertical 6548' feet Effective depth: measured 7 8 5 3' feet true vertical 61 4 3' feet Operation Shutdown Re-enter suspended well Plugging _ Time extension Stimulate Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 100' RKB 7. Unit or Property name feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 112' 2902' 1 6" 10 3/4" 8337' 7" Kuparuk River Unit 8. Well number 'lA-g 9. Permit number 81 -71 10. APl number 50-029-20599 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) None Junk (measured) Vann Gun @ 7902' Cemented Measured depth True vertical depth 200 Sx Permafrost 1 12' 1 12' 1650 Sx Fondu & 2902' 2662' 250 Sx ASII 838 Sx Class G & 8337' 6535' 25O SX ASII RE ¢EIVED measured 7552'-7577',7601'-7626',7652'-7688',7796'-7850' true vertical 5962'-5980',5999'-6014',6033'-6059',6135'-6174' NOV 'j 5 '~ Tubing (size, grade, and measured depth) 3 1/2", 9.3# J-55, tbg w/tail @ 7782' Alaska 0ii & Gas Cons. C0mmis~, Packers and SSSV (type and measured depth) Anch0ra~e Packer: FHL @ 7474' & DB ~ 7753'; SSSV: Camco TRDP-1A-ENC @ 1814' 13. Attachments Description summary of proposal _ Detailed operation program _ BOP sketch _ Convert well from oil producer to WAG injector. (Wellbore schematic attached). 14. Estimated date for commencing operation 15, Status of well classification as: December. 1991 Oil __ Gas _ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service WAG Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Date 11/13/ql Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test_ Location clearance ~ Mechanical Integrity Test ~ Subsequent form require Approved b)~ order of the Commission Form 10-403 Rev 09/12/90 ORIGINAL SIGNED BY gT.]l'dl~*l-~''''' ' '' 10- ~ ~r' Approvsc; Copy Returhsd IApproval /- Commissioner Date ~1 ' '~ ~ - cl I SUBMIT IN TRIPLICATE Well;IA-02 ARC(' ~LASKA INC.-KUPARUK FIE[ Spud Date 0 6- 1 5 -8 1 Completion Date: 1 2 - 2 5 - 8 6 Maximum Hole Angle: 49 Original Rig RKB: 28.3' All depth are RKB MD to top AP 1#50-029-20599-00 C Sand: OPEN A Sand: OFEN deg. @ 7200' MD of equipment. Well Type: OIL Tree Type: FMC GEN 1 5000# Tree Cap Type: OTIS Tree Cap Size: Tree Cap O-ring ASN: Last Workover Date: 1 2 - 2 5 - 8 6 Jewelry 1 SSSV: CAMCO TRDP-1A-ENC 2.812" ID @ 1795' 2 SBR: BAKER @ 7428' 3 PKR: BAKER FH @ 7455' 4 PKR: BAKER DB @ 7734' 5 CROSS OVER: 3.5" TO 2.875" @ 7756' 6 NOGO: CAMCO'D' NIPPLE 2.25" ID @ 7751' 7 CROSS OVER: 2,875" TO 3.5" @ 7779' 8 SHEAR OUT: OTIS @ 7782' 9 TUBING TAIL: 3.5" TUBING @ 7762' Minimum ID:2.25" NOGO Casing and Tubing Size Weight Grade Toz~ Bottom 1 6" 65# H-40 0' 112' 0,75" 45.5# K-55 0' 2902' 7" 26# K-55 0' 8337' 3.5" 9.3# J-55 0' 7763' Gae Lift Information De~th Stn# Valve Tvoe Sz. Latch 3044' 1 R.OPE G/L I" BK 4435' 2 R.CPE G/L I" BK 4858' 3 FLOPE D/V I" BK 5227' 4 FLOPE G/L I" BK 5596' 5 ~ G/L 1" BK 5964' 6 FLCPE G/L 1" BK 6276' 7 FLOF~ G/L 1" BK 6640' 8 R.OPE G/L 1" BK 7010' 9 D/V I" BK 7382' 1 0 D/V 1.5" RO-5 Descri~)tion CASING CASING CASING TUBING RECEIVED Port Sz. AID# Date Run 0.1562 02-24-87 0.25 02-24-87 09-22-87 0.25 02-24-87 0.3125 02-24-87 0.3125 02-24-87 0.3125 02-24-87 0.3125 02-24-87 6 7 8,g _Production Equipment De~th Stn# Model Tv=e Sz. 7490' 1 GLM D/V 1" 7722' 2 AVA 2.75" 3.5" Latch Vlv/SIv AID# Date Run BK BPL COMM 08-30-90 Perforation Data Interyal SPF Date Phase 7552-7577 12 12-23-86 120 7601-7626 12 12-23-86 120 7652-7688 1 2 12-23-86 120 7700-7712 7796-7850 4 07-02-81 120 FT Zone Comments 25 C 4 SQUF;T;O AND 25 C3 F~=EFFED @ WO 36 C 2 SAME AS ABOVE C 1 ._q~__~:;Tf:~ 54 A4 4" VANN GUNS Comments: VANN GUN 340.14' AT 790Z LASTTD: 7844' CN 08-31 -90 PBTD: 8242' PBTDSS: 6364' LAST REVISION DATE:07- 1 8-91 REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate j~ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1259' FSL, 313' FWL, Sec. 5, TIOE, RIOE, UM At top of productive interval 1172' FSL, 3750' FEL, Sec. 6, T11N, RIOE, UM At effective depth 1297' FSL, 4211' FEL, Sec. 6, T11N, RIOE, UM At total depth 1312' FSL, 4344' FEL, Sec. 65, T11N, RIOE, UM 5. Datum elevation (DF or KB) RKB 100' 6. Unit or Property name Kuparuk River Unit 7. Well number !~-2 Producer 8, Approval number 8-381 , 9. APl number 50-- 029-20599 10. Pool Feet Kuparuk River Oil Pool 11. Present well condition summary Total depth' measured true vertical 8355' MD feet 6548' TVD feet Plugs (measured) None Effective depth: measured 7853' MD feet true vertical 6143' TVD feet Junk (measured) Vann Gun @ 7902' Casing ' Length Size Structural Conductor 112' 16" Surface 2902' 10-3/4" · Intermediate Production 8337' 7" Liner Perforation depth: measured true vertical Cemented Measured depth True Vertical depth 200 SX Permafrost 1650 SX Fondu & 250 SX ASII 838 SX Class G & 250 SX ASII 112' MD 2902' MD 8337' MD 112' TVD 2662' TVD 6535' TVD 7552'-7577' 7601'-7626' 7652'-7688' 7796'-7850' MD 5962'-5980' 5999'-6014' 6033'-6059' 6135'-6174' TVC ,. Tubing (size, grade and measured depth) 3½" J-55 tbg w/tail @ 7782'MD Packers and SSSV (type and measured depth) FHL pkr @ 7474', DB pkr @ 7753', and TRDP-1A-ENC @ 1814' MD 12. Stimulation or cement squeeze summary Intervals treated (measured) 7796' - 7850' MD . , Treatment description includin.cl volumes used and final pressure 8200 gallons diesel, 440 gallons varsol solvent, final pressure = 800 .PS,$~.~ 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 242 358 17 1220 28! 359 0 1220 Tubing Pressure 1'75 130 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge t,,~.~Z~', FoS:gmn:~.404~~Rev. 12~5 / ~/~¢~~ Title /~~ ~~'Z__~~'~ ~'/'~ Date ~~z~.~¥ Submit in Duplicate WELL SERVICE REPORT ARCO Alaska, Inc -~ '~ Subsidiary of Atlantic Richfield Company · WELL ~ONTRACTOR REMARKS JPBDc~ Z~ ~ IFIELD - DISTRICT- STATE OPERATION AT REPORT TIME DAYS t DATE c.c. ~:~.o C~,Sto AL t'o I~fO° (~ 0 Io to l ~ r--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Report ) 2- °F --'Z. ~ °F] / 0 miles I REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL CAMCO -- , OTIS ................ SCHLUMBERGER DRESSER.ATLAS ..... DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES ...... Roustabouts t'~.~r ~r;~/<r / 00. oo_..... Diesel Methanol - Supervision '~ oo~-'~' Pre-Job safety Meeting AFE H~o+ 0;~ $.~-,~;c.¢_~ /o~~'~ .... TOTAL'YIELD ESTIMATE "~ I ~ 8 0 ~'~' 3/~ ~ O~''~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . ' Operation Shutdown ~ ] Re-enter suspended well .~. Alter casmng [I TIme extension Change approved program Plugging '7 StimulateX Pull tubing Amend order .r Perforate r~' Other .] 2 Name of Operator ARCO Alaska~ Inc. 3 Address Locauon lwell at -'" '~"'"o~''''~''~ 'surface .......... ="' .... 4. Sec. 5, T11N, RIOE, UM 172. FSL. 3750' e~ec~ive aepth 1~97' FSL, 4211' At total depth 1312' FSL, 4344' FEL, Sec. 6, T11N, RIOE, UM FEL, Sec. 6, T11N, RIOE, UM FEL, Sec. 6, T11N, RIOE, UM 5. Datum elevation (DF or KB) RKB 100 6. Unit or Property name v,,n=v,,,[, ~'~w,',v, U.n..i-I- '~'.'" ~i ~-r{ b rfi'~e'r .... lA-? Prnd~cer 8. Permit number Permit #81-71 9. APl number 50- 029-20599 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured 8355' MD true vertical 6548' TVD Effective depth: measured 7853' ND true vertical 6143' TVD feet Plugs (measured) None feet feet Junk (measured) feet Vann Gun @ 7902' Casing Length xx~y~(xxxxx Conductor 112' Surface 2902' Production 8337' xx~xxxxx Perforation depth: measured true vertical Size Cemented Measured depth True Vertical depth 16" 200 SX Permafrost 112' MD 112' TVD 10-3/4" 1650 SX Fondu & 2902' MD 2662' TVD 250 SX ASII 7" 838 SX Class G 8337' MD & 250 SX ASII 7552'-7577' 7601'-7626' 7652'-7688' 7996'-7850' MD 5962'-5980' 5999'-6014' 6033'-6059' 613~'~b~10'~' ?!i~. 6535' TVD Tubing (size, grade and measured depth) 3½" J-55 tbg w/tail @ 7782' MD Packers and SSSV (type and measured depth) FHL pkr @ 7474'~ DB pkr @ 7753', and TRDP-1A-ENC 12.Attachments Description summary of proposal X Detailed operations program ~ BOP sketch .r-z_, Refrac 'A' Sand 13. Estimated date for commencing operation September, 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true, e~and correct to the best of my knowledge Signed ,~~,~ ~ 2/O'"~t,~/l"C'b~ Title Sr. Operations En~lineer Commission Use Only Date 4/29/88 Conditions of approval Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Notify commission so representative may witness F_] Plug integrity [] BOP Test ~ Location clearance Approved Copy eturned ~ Commissioner IApprOval NO' ~~ ~_./ by order of the commission Date feet Form 10-403 Rev 124-85 Submit in triplicate 1A-02 SUNDRY NOTICE No BOP will be used for the proposed work. The estimated BHP in the "A sand is 2400. psi at 6200'. No workover fluids are roquired. -. K. Hutchins August 10, 1988 Page 3 WELL 1A-2 Pre Frac Work · · 3. 4. 5. 6. 7. Tag fill to verify 2/23/88 measurement or 7853' RKB. Contact Operations Engineering to evaluate CTU need based on rathole found by tag. If necessary, CTU fill. Verify minimum of 25' rathole after CTU. Pull gas lift valves in GLMs 1-8. Run dummy valves. Run standing valve in no-go (7751' RKB). Pressure test tubing. Pull standing valve. Pre Job Work · Check tanks for cleanliness. Insure diesel is uncontaminated. Obtain proppant for sieve analysis. Fracture Treatment I · · · · Rig up frac equipment and tree saver. Pressure test all lines. Pump 100 bbls of gelled diesel containing 40 lb/lO00 gals silica flour at 20 BPM. Pressure up annulus, as necessary, to prevent tubing buckling. Shut down for ISIP and to check perf friction. Leave well shut in for five minutes to allow pressure to stabilize. - Check tanks straps against flow meter. Correct for main frac as warranted. Pump fracture treatment per the attached schedule. - Mix stages on fly. - Use silica flour in pad only at 40 lb/lO00 gals. - Gelled diesel pad and stage volumes should contain an 8 hour breaker. The flush volume should contain a fast low temperature breaker. - Ramp up slowly between stages to avoid density spikes. Check tanks during job to insure meter accuracy. - Expected pressures are: Frac gradient 0.69 Tubing friction 120 psi/lO00 ft Average well head treating pressure 3800 psi - DO NOT OVERFLUSH PROPPANT Rig down fracturing equipment and bleed annulus as required. JME: kj r: 0081 FRACTURE SCHEDULE WELL 1A-02 Sta;le Proppant Pump Rate Clean Volume Proppant Slurry Volume Cumulative Stage hits (PP,G) (BPM) (BBLS) (Pounds) (BBLS) Slurry VolumePerfs @ (BBLS~ ,, Breakdown Silica Flour 2 0 1 0 0 0 1 0 0 1 0 0 7 0 ,, SD For ISIP 0 Pad Silica Flour 2 0 831 0 8 3 183 7 0 2 20/40 20 1 8 1544 20 203 153 6 20/40 20 24 5980 30 233 173 1 0 20/40 20 21 8747 30 263 203 Flush 6 9 6 9 332 Total 315 1 6270 332 , , Volume to p,erfs = 70 Bbls Flush stage ,intentionally underflushed by 1 Bbl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . * Operation Shutdown ~ ~ Re-enter suspended well .~. Alter casmng £I T,me extension Change approved program Plugging '~ StimulateX Pull tubing Amend order ,r Perforate r_i Other .] 2 Name of Operator ARCO Alaska, Inc. 3 Address 4. L~'a t'i'o~r~' o f* ~ ~i ~a'~ 'surface .......... ~"' ............. A~;f ~c~;nt~, Sec. 5, T11N, RIOE, UM ~le~f2ej vFeS~dpth3750' FEL, Sec 6, TllN, RIOE, UM A ti 1297' FSL, 4211' FEL, Sec. 6, TllN, RIOE, UM At total depth 1312' FSL, 4344' FEL, Sec. 6, TllN, RIOE, UM 5. Datum elevation (DF or KB) RKB 100 feet 6. Unit or Property name v,,~,=,,,,b ~,:er Unit lA-? Prndllc. er 8. Permit number Permit #81-71 9. APl number SO-- 029-20599 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured 8355' MD feet true vertical feet 6548' TVD · Effective depth: measured 7853' MD feet true vertical 6143' TVD feet Casing Length Size xx~(Yu~Xxxxxx Conductor 112' 16" Surface 2902' 10-3/4" Production 8337' xx~-~14~xxxxx Perforation depth: measured Plugs (measured) None Junk (measured) Vann Gun @ 7902' Cemented Measured depth True Vertical depth 200 SX Permafrost 112' MD 112' TVD 1650 S× Fondu & 250 SX ASII 2902' MD 2662' TVD 7" 838 SX Class G 8337' MD 6535' TVD & 250 SX ASII 7552'-7577' 7601 '-7626' 7652'-7688' 7996'-7850' MD true vertical 5962'-5980' 5999'-6014' 6033'-6059' 6135'-6174' TYD ~ ~ ~ ,,~ '~ - , Tubing (size, grade and measured depth) 3½" ,]-55 tbg w/tail @ 7782' MD Packers and SSSV (type and measured depth) FHL pkr @ 7474'~ DB pkr e 7753' TRDP-1A-~ 12.Attachments Description summary of proposal Detailed operations program Refrac 'A' Sand 13. Estimated date for commencing operation September, 1988 BOP sketch , , , 14. If proposal was verbally approved Name of approver Date approved Approved by 15. I hereby certify that the foregoing Is true_and correct to the best of my knowledge Signed ,,~r~/~ j~ ~<~/~ igb~l~l~ Title Sr. Operations Engineer Date4 Commission Use Only Conditions of approval N~otify commission so representative may witness I Approval No. r__J Plug integrity E) BOP Test r'l Location clearanceI c/-'- ~ Approved Copy Returned s, .E0 LONNIE C. SMITH by order of Commissioner the commission Date Form 10-403 Rev 124-85 Submit in triplicate 1A-02 SUNDRY NOTICE No BOP will be used for the proposed work. The estimated BHP in the "A" sand is 240Q~.psi at 6200'. No workover fluids are required. K. Hutchins August 10, 1988 Page 3 WELL lA-2 Pre Frac Work le 2, 3. 4. 5. 6. 7. Tag fill to verify 2/23/88 measurement or 7853' RKB. Contact Operations Engineering to evaluate CTU need based on rathole found by tag. If necessary, CTU fill. Verify minimum of 25' rathole after CTU. Pull gas lift valves in GLMs 1-8. Run dummy valves. Run standing valve in no-go {7751' RKB}. Pressure test tubing. Pull standing valve. Pre Job Work le Check tanks for cleanliness. Insure diesel is uncontaminated. Obtain proppant for sieve analysis. Fracture Treatment 1. Rig up frac equipment and tree saver. Pressure test all lines. 2. Pump 100 bbls of gelled diesel containing 40 lb/lO00 gals silica flour at 20 BPM. Pressure up annulus, as necessary, to prevent tubing buckling. 3. Shut down for ISIP and to check perf friction. Leave well shut in for five minutes to allow pressure to stabilize. - Check tanks straps against flow meter. Correct for main frac as warranted. 4. Pump fracture treatment per the attached schedule. - Mix stages on fly. - Use silica flour in pad only at 40 lb/lO00 gals. - Gelled diesel pad and stage volumes should contain an 8 hour breaker. The flush volume should contain a fast low temperature breaker. - Ramp up slowly between stages to avoid density spikes. Check tanks during job to insure meter accuracy. - Expected pressures are: Frac gradient 0.69 Tubing friction 120 psi/lO00 ft Average well head treating pressure 3800 psi - DO NOT OVERFLUSH PROPPANT 5. Rig down fracturing equipment and bleed annulus as required. JME: kj r: 0081 FRACTURE SCHEDULE WELL 1A-02 Stage Proppant "Pump Rate, Clean Vo'lume' Proppant islu, rry volume Cumulative Sta'~e hits " (PPG) (BPM) .(BBLS.). (Pounds) (BBLS) Slurry VolumePerfs @ (BBLS) BreakdOwn Silica Flour 2 0 1 0 0 0~ ........ 1 0,0 .... 1 0 0 7 0 SD For ISIP 0 Pad Silica Flour 20 83 0 83 183! 7 0 2 20/40 20 1 8 1544 20 203 153 6 20/40 20 24 5980 30 233 173 .. 1 0 2,0/40 20 21 8747 30 263 203 F'i'u~l " 69 6'9 332 , , . T~ta'l 315 1'6270 33'2 Volume tO p,erfs = 70 .Bb.l.~ staae'intenti°nally i/ j1 Bbl' Flush f,!°ur !~ pad onlY nderflushe.d by Silica ARCO Alaska, Inc. ~ Post Office Box~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 9, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Start Date 2D- [,2 ........ ~ ........................ ~.j~.~.~e May, 1988 .~ 1H-3 Stimulate May, 1988 1A-2 Stimulate May, 1988 If you have any questions, please call me at 265-6840. Sincerely, Senior Operations Engineer GBS'pg:0181 Attachments cc' File KOE1.4-9 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ' STATE Of ALASKA COMrv,,~ION ~ ALASK. )OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate J~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 100' 3. Address 6. Unit or Property name PO Box 100360, Anchorage, AK 99510 Kuparuk River Unit 4. Location of well at surface 7. Well number 1259' FSL, 313' FWL, Sec. 5 T11N RIOE UM 1A-2 Producer At top of productive interval ' ' ' 8. Permit number 1172' FSL, 3750' FEL, Sec. 6, T11N, RIOE, UM Permit #81-71 At effective depth 9. APl number 1297' FSL, 4211' FEL, Sec. 6, T11N, RIOE, UM 5o-- 029-20599 At total depth 10. Pool 1312' FSL, 4344' FEL. Sec. 6. T11N. RIOE. UM KuDaruk River Oil Pnnl , 11. Present well condition summary Total depth: measured 8355' ND feet Plugs (measured) None true vertical 6548' TVD feet Effective depth: measured 7853' MD feet Junk (measured) true vertical 6143' TVD feet Vann Gun @ 7902' Casing Length Size Cemented Measured depth XXX~lq~)~(IxXXXX Conductor 112' 16" 200 SX Permafrost 112' MD Surface 2902' 10-3/4" 1650 SX Fondu & 2902' MD XXXMl~O(l~O~H(~te 250 SX AS I I Production 8337' 7" 838 SX Class G 8337' MD xxx~J~xxxx & 250 SX ASII Perforation depth: measured 7552'-7577', 7601'-7626', 7652'-7688' feet True Vertical depth 112' TVD 2662' TVD TVD true vertical5962,_5980, 5999'-6014' 6033'-6059' Tubing (size, grade and measured depth) 3½" J-55 tbg w/tail @ 7782' MD FPl. rl_cke[-s an..d .SSSV.(tyRe and measured depth) HL pKr t.~ 7474', DB pkr @ 7753', and TRDP-1A-ENC @ 1814' MD 12Attachmer~ts D(~scripti9n..sumrnary o,.f proDosal [] 'Sbl~)en~/-~Fiesel wasn oT A ~anaperTora~;ions. 6535' , 7996'-7850' MD 13. ~)t~t~edl(~ for commencing operation , 6~35'-6174' T Detailed operations ~~"~ ~.~tch ~ 4/19/88 Date4/29/88 14. If proposal was verbally approved e~.t.,- ~ ~.~ L. Smi th ~ ~ ~~['/Date approved Name of approver o~ ]i'o~m ~ 15. I hereb,v..certifv...that the foregoing isA~Je and correct to the b_est of my knowledge [~ ~ ~ ~ Sr. Dperat~ons Engineer Signed Title Commission Use Only Notify commission so representative may witness I Approval No. ~ ~)// [] Plug integrity [] BOP Test [] Location clearance Conditions of approval Approved Copy Returned Commissioner the commission Dat triplica~l~ 1A-02 SUNDRY NOTICE No BOP will be used for the proposed work. The estimated BHP in the "A" sand is 2400 psi at 6200'. No workover fluids are required. K. Hutchins Apr. il 11, 1988 Page 3 Well 1A-2 Procedure: le 2. 3. 4. 5. Pump 60 BBLS hot diesel with 20 percent solvent (500 gallons/9 drums). Displace diesel/solvent with 67 BBLS diesel (tubing tail). Inject a maximum pump pressure and rate available with hot oil truck. Immediately flow back well with 350M gas lift rate. Test well after stable flow is established. Date: ARCO Alaska, Inc.~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 12, 1987 Transmittal ~: 6082 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3M-17 Kuparuk Well Pressure Report (Otis) 9-23-87 3M-21- Kuparuk Well Pressure Report (Otis) 9-24-87 2C-3 Kuparuk Well Pressure Report (Otis) 9-28-87 IA-10 Kuparuk Well Pressure Report (Camco) 10-1-87 lA-2 Kuparuk Well Pressure Report (Otis) 10-1-87 Static Static PBU 'A' Sand Receipt Acknowledged: DISTRIBUTION: D&M ..State of Alaska i~ BPAE · Unocal Chevron Mobil SAPC ARCO Alaska, Inc. is a Subsidiary of AtlanticRIchfieldCompany ARCO Alaska, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 90? 276 1215 Date: August 24, 1987 Transmittal ~ 6035 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 "Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 31-3 Kuparuk Well Pressure Report 7-15-87 lQ-3 .Kuparuk Well Pressure Report 4-28-87 '-IA-2 Kuparuk Well Pressure Report 8-11-87 Receipt Acknowledged: DISTRIBUTION: Naska 011 & Gas Cons. (~ommissiu. Anchorage D&M State of Alaska BPAE Chevron Mobil SAPC Unocal. ARCO Alaska, Inc. is a Subsidiary of AllanticRichlleldCompany WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well -- OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ...... ...... 2. Name Of' Operator ..... 7. Permit Number ARCO Alaska, Inc. 81-71 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20599 4. Location of well at surface 9. Unit or Lease Name 1259' FSL, 313' FWL, Sec. 5, T11N, RIOE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1172' FSL, 3750' FEL, Sec. 6, TllN, RIOE, UM 1A-2 At Total Depth 11. Field and Pool 1312' FSL, 4344' FEL, Sec. 6, T11N, R10E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) i 6. Lease Designation and Serial No. Kuparuk River 0il Pool RKB 100'I ADL 25647 12. Date Spudded i 3, Date T.D, Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16, No. of Completions 06/15/81 06/27/81 07/02/81' N/A feet MSL 1 17. Totai'Depth(MI~+TVD)' 18. PIU§BackDepth(MD~TVD) 19.'D'i~ecti(~n'al'Surve¥" I 20. Depthwl~eresSS~/set , 21.ThicknessofPermafr0st 8355'MD 6548'TVD 8242'MD 6464'TVD YES.[~ NO[]I 11814' feetMD 1650' (Approx) 22. Type Electric or Other Logs Run ........ D IL/SP/BHCS/GR, FDC/CNL/NGT/CAL, CBL/CCL/GR, Gyro, CET 23, ~ CAS!NG,.L.I.NER A. ND C:.EMENT!N_G RECOEJD SETTING DEPTH MD CASING SIZE WT. PER FT, GRADE TOP BOTTOM, HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65.0# H-40 Surf 112' 24" . 2.00..s~.. Pe rr.m~frost. 10-3/4' 45.5 K'55 Surf 2902'... ..... .1..3-3/4" 1650 EX. Fondu & 250 EX. tS..11 7'" '26.0# K-55 Surf , ,,".833,~I, ..8.T3/,4,1 .. 838 .Ex.Cia, ss. G & 250 sx AS II '2'4. Perforations open to Production (MD+TvD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEI~'TH SET (MD) PACKER SET iM'D) 7552'-7577'MD 5962'-5980'TVD .. }-1/2" 7782' 7474' & 7753' 7601 '-7626'MD 5999'-6014'TVD ............... ' ............ 7652 ' ~7688'MD 6033 ' -6059'TVD :26. "ACID,, FR.ACTURE, CEMENT SQUEEZE', 7796'-7850'MD *6135 '-6174 'TVD ..DEpyH !NTE-R. VAL.(MD.) .A, MQUN.T~ & K'IN~ 0~'... M~,TERIAL., ... . .. .USED Perforated w/12 spf, 120° phasing .... P.erforati0ps' f/.?0,3 'T7787' ..3.50 .sx..Cl..a.$s G ..... *Perforated w/4 spf .......................... .... 27." . PRODUCT,ON TEST Date First Production' ' { Method of operation '("~i'o~inlg',' g;; 'li~t, e't~,) ......................... .1,2,/26/8,1 ........ I, , ~ ~,~ Date Of Test H'O~rS :r~ted PRODUCTION FOR el L-~'BL GAS-MCF WATER.BBL CHOKE SIZE J GAS-OIL RATIO .... 7/3!/8,L ....14 ....... TESTPER. IODI~ 1733 .... 711 .- Afl/R/..114.10 ,, · Flow Tubing Casing Pressure CALCULATED OIL,BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press: 685 ............ -- , 24-HOUR RATE I1~ 297,1r , 12,18 -- 24,. 6 28. CORE DATA Brief description of lithoIogy, porosity, fractures, apparent dips and preserme of oil, gas or ware r. Submit core chips. N/A RECEIYEI) f: EBo 6 1987 Alaska OB a Gas Cons. Commission Anchorage ~.Not, e: Well.. worked ,over. 12/24/86 ................. Form 10-407 WC2: 011: DAN I submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ' . 29. ( · 7 30. "' GEOLOGIC MARKI~'S ' .' ' FORMATION TESTS , NAME Include interval tested, pressure data, a!! f!,;;:~' :, .' :: ,: MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase Top Kuparuk 7526' 5944' N/A Top Upper Sand 7554' 5964' Base Upper Sand 7575' 5979' Top Lower Sand 7785' 6127 ' Base Lower Sand 7850' 6174' Base Kuparuk 7935' 6236' ~ -. ... , 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~/~J~,~t~L~-(~Lj ~ Title Associate Engineer Date ~'~-~7 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate whiCh elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for 'separate production from more than one interval (multiple completion), so state in ,item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a ~parate form for each additional interval to be separately Produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and .the location of the cementing tool. ..~ Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" Form 10-407 STATE OF ALASKA ~',S ALASC'r. OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate~,,, Pull tubing Alter Casing [] Other WORKOVER 2. Na .m~e~gf. Qpqrator. ftl~t.u R i asKa · i nc. 3. Ad~r.~s. SBox 100360 Anchorage· AK 99510-0360 4. Location of well at surface 1259' FSL· 313' FWL· Sec. 5, T11N, RIOE· UN At top of productive interval 1172' FSL, 3750' FEL, Sec. 6, TllN, RIOE, UN At effective depth 1297' FSL, 4211' FEL, Sec. 6, T11N· RIOE, UN At total depth 1312' FSL, 4344', FEL, Sec. 6, TllN, RIOE, UN 5. Datum elevation (DF or KB) RKB 100' 6. U. nit or .Pr~operty name r~uparuK Klver Unit 7. Well number 1A-2 8. Approval number 538 9. APl number 50-- 029-20599 lO'P~aruk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor SurfaCe 8355"MD feet 6548 ' TVD feet 8242 ' MD feet 6464 ' TVD feet ProduCtion Plugs (measured) None Junk (measured) Vann Gun ~ 7902' Length Size Cemented Measured depth 112' 16" 200 sx Permafrost 112'MD 2902' 10-3/4" 1650 sx Fondu & 2902'MD 250 sx A5 II 8337' 7" 838 sx Class G & 8337 'MD 250 sx AS II True Ve~ical depth ll2'TVD 2662'TVD 6535'TVD Perforation depth: measured 7552'-7577'MD, 7601'-7626'MD, 7652'-7688'MD, 7796'-7850'MD true vertical 5962'-5980'TVD, 5999'-6014'TVD, 6033'-6059'TVD, 6135 ' -6174 ' TVD Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail ~ 7782' Packers and SSSV (type and measured depth) FHL pkr ~ 7474', DB pkr ~ 7753', & TRDP-1A-ENC ~ 1814' RECEIYEO JAN 2 3 19°-,7 12. Stimulation or cement squeeze summary Intervals treated (measured) ~aS~3 0il & Gas Cons. C0mmissi01~ Anchorage Perforations f/7037 ' -7787 ' ( i ncl udi ng squeeze perfs f/7756 ' -7758 ' ) Treatment description including volumes used and final pressure 350 sx Class G 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressu re 14. Attachments Daily RepoltW%~kv%qr ~l~(~ta~)l~t~°~) Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Associ ate Engineer Date Submit in Duplicate Form 10-404 Rev. 12-1-85 DAN i) $W0/155 Oiland Gas Company Daily Well History-Final Report IIt~JIl~tk.~: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Rel~rt" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovere when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Flnel Rel~rr' form may be used for reporting the entire operation if space is available. IAccounting cost center code District [County or Parish State I Alaska North Slope Borough I Alaska Field Lease or Unit Well no. Kuparuk River ADL 25647 lA-2 Auth. or W.O. no. JTitle AFR 505005 I Completion Nordic 1 AP1 50-029-20599 Operator ] A.R.Co. W.I. ARCO Alaska, Inc. - 56.24% Spudded or W.O. begun Date Complete 12/11/86 Date and depth Complete.record for each day reported as of 8:00 a.m. Old TD Released rig 12/26/86 2300 hrs. I otal number of wells (active or inactive) on this DSt center prior to plugging and ~ bandonment of this well I our ' I Prior status if a W.O. 0200 hrs.], Classifications (oil, gas, etc.) Oil 7" @ 8337' 8242' PBTD 6.8 Diesel TlR w/3-1/2" tbg & FHL pkr. SSSV @ 1814', FHL pkr @ 7474', DB pkr @ 7753', & TT @ 7782'. Install SSSV & control line. Test 5000 psi - i5 min. TIH land tbg in lower pkr. Space out. Land hgr, set pkr~ Test 2500 psi. Shear out SBR, reland. Shear out ball. Pull landing jr. Set BPV. ND BOPs. NU tree & test 250/5000 psi. Displ well w/diesel. RR @ 2300 hfs, 12/24/86. RECEIYEO JAN 2 3 1987 Naska 0il & Gas Cons. Commission Anchorage I.ow 8242 ' PBTD TD PB Depth Date K nd. of r g 12/24/86 Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day , Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Oil and Gas Company Daily Well History--Interim completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) Inltl~clionl: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final on Wednesday of the week in which oil string is set. Submit weekly for worl~overs and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. I County or Parish Alaska Lease or Unit North Slope Borough Kuparuk River I ADL 25647 Complete record for each day while drilling or workover in progress 12/18/86 12/19/86 12/20/86 thru 12/22/86 State 7" @ 8337' 7450', Drlg cement 9.0 NaCl Continue TIH w/3½ DP to 7712'. RU Dowell. Set 150 sx Class G balanced plug. POOH 15 stands, sqz cement into C-sand perf. Hold pressure on sqz. Reverse out water, LD 15 jt DP, POOH. PU BHA, cut drlg line, TIH. Tag cmt @ 7037'. Drlg cmt 7037'-7450'. Alaska IWell no. lA-2 7" @ 8337' 7450' POOH. 9.0 NaC1 Drld cmt 7450'-7488'. Bit plugged. Reverse circ. Clean pits, cut brine f/10# to 9.0#. Drlg cmt 7488' to 7738'. Tst C-sand. Perf test failed. Drlg cmt retainer 7738'-7740'. Drlg cmt 7740'-7783'. Circ bottoms up. POOH f/test packer. 7" @ 8337' 7900' POOH. TIH w/7" csg scraper 9.0 NaC1 PU R-3 pkr TIH. Set pkr @ 7740'. Test sqz perf to 2000 psi; test failed. POOH. RU WL unit. RIH set cmt retainer @ 7725" WLM. TIH w/sqz stinger. Squeeze. wl~~x_~lass G. Reverse water out of DP. POOH. PU BHA TIH. Drlg cmt & retainer 7717' to 7787'. Circ bottoms up. POOH. Cut drlg line PU R-3 pkr TIH. Set pkr @ 7740'. Tst sqz perf to 2000 psi. Test ok~~~ pkr @ 7500'. Test 7" csg to 3000 psi. POOH. RU Schlumbe~r~ un~CE~T_~pg, MU BHA. TIH. Drld BP & ream to 79--0~~-. Circ Ottoms up. POOH. PU 7" TIH. 12/23/86 7" @ 8337' 8242' RIH w/6.125" GR/JB 9.0 NaC1 Continue TIH w/7" csg scraper to 7890'. w/clean 9.0 brine. POOH. LD 3-1/2" DP. Pump high vis. pill, Displ Pull wear bushing - RU 12/24/86 Schlumberger. Test lubricator 1200 psi, perforate C-sand w/5" guns 12 spf, 120 phasing 7552'-7577', 7601'-7626', 7652'-7688'. RIH w/6.125 GR/JB. 7" @ 8337' 8242' PBTD, Make up new Baker 7" FHL pkr 9.0 NaC1 RIH w/GR/JB, set Baker DB permanent pkr @ 7734' WLM. RIH w/3-1/2" completion assembly. PU SSSV test control 5000 psi - OK. RIH, stab in, space out, land tbg. Pressure up to 2500 psi to set pkr & test tbg - pkr would not set. POOH w/3-1/2" tbg. The above is correct see Procedures Manual Section 10, Drilling, Pages 86 and 87 Drilling Supervisor Distflot · me~ KUPa~uk River ~ Auth. or W.O. no. ~ ~ 505005 Nordic I O~emtor ARCO Alaska, Tnt. Spudded or W.O. begun Co=pIete Date and degth as of 8:0~ ~m~ 12/11/86 12/13/86 thru 12/15/'86 12/16/86 12/17/86 weft: after a well is spudded or wort(over operations are sti~ted. form giving inclusive dates only. parish or I~orough North Slope Borough ]t~as~Title or Unit ADL 25647 Completion State AP1 50-029-20599 .[Date 12/11/86 IHOur Oomglete record for each Oay reported 0200 hrs. 7" @ 8337' 8242' PBTD, RU S/L 6.8 ppg diesel Accept res @ 0200 hfs, 12/11/86. Pull BPV. Alaska IARCO w.I. Prior status if a W.O. IWell no. lA-2 56.24% RECEIVED 7" @ 8337' 8242' PBTD, Attmpt shear SBR 9.0 NsC1 Pull ck valve @ 7377', dtsp well to diesel, tst tb8 l to 650~. Disp well to 9.0 NaC1, pull standing valve wi:h'W./~, pump lite-sal pill & sqz into perf's; no loss. Set BPV,. tree; NU BOPE & tst, attempt to pull SBR, tbg hgr hanginsup in hydril, lift riser to inspect. RU s/L.. JAN 2 1987 Naska 0il & Gas Cons. CommiSsion Anchorage r~ 7" @ 8337' 8242' PBTD, POOH 9.0 NaC1 Pull FMC hgr, chg out colts on 3~" tbg to AB-Mod; taking rtns thru tbg. SI well, circ out diesel & oil, POOB. RU & RIB w/retrv'g tl, pull FHL pkr. RU W/L, pelf 7756'-7758' @ 4 SPF. Make 6-1/8" GR/JB rn to 3023'. Make 5-7/8" GR/JB rn to 7850'. RIM, set Bkr BP @ 7778', retnr @ 7730', RD WL. RU a pmp & sqz 100 sx C1 "G" cmt into perfs. Sting out of ret & set plug. L~---~.__._. ,I I1 acro~-' C"~&~-~=-~-00~-"~P& stinger. ~ 7" @ 8337' 8242' PBTD, TIH w/retry BP 9.0 NaC1 POOH w/stinger. RIB w/BP, set @ 6800', tst to 2000 psi. ND BOPE, chg out tbg head, NU S tst BOPE. TIH w/retrv'g~ ti to 6800'. 7" @ 8337' 8242' PBTD, TIB to squeeze 9.0 NaC1 Finish TIH, Retrieve BP. POOB. TIH w/bit & jk bskt, tag cmt @ 7603'. Drill cmt from 7603'-7739'. Cmt retriever, circ. Pressure test surface equipment. Test perfs. Broke down w/500 psi. Pump in @ 1/2 BPM w/400 psi, 1BPM w/700 psi. POOH. TIH open ended for balance plug squeeze across parrs. Theabove is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ~'.~ STATE OF ALASKA ALASK IL AND GAS CONSERVATION COMM ,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ,-I Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Time extension ~ Change approved program ~ Plugging ~ Stimulate ~ Pull tubing ~ Amend order ~ Perforate ~ Other 2. Name of Operator ARCO Alaska, lnc. 3. Address P. 0. Box 100360 Anchorage, AK 9951 0-0360 4. Location of well at surface 1259' FSL, 313' FWL, Sec.5, TllN, R10E, UM At top of productive interval 1172' FSL, 3750' FEL, Sec.6, T11N, R10E, UM At effective depth 1297' FSL, 4211' FEL, Sec.6, TllN, R10E, UM At total depth 1312' FSL, 4344' FEL, Sec.6, T11N, RIOE, UM 11. Present well condition summary Total depth: measured true vertical 8355 'MD feet Plugs (measured) feet 6548'TVD 5. Datum elevation (DF or KB) 1 O0 ' RKB feet 6. Unit or Property name Kuparuk River Unit 7. Well number lA-2 8. Permit number 81 -71 9. APl number 50-- 029 -20599 10. Pool Kuparuk River Oil Pool None Junk(measured) Effective depth: measured 'H feet true vertical 8242 D feet 6464'TVD Casing Length Size Cemented Measured depth Rue Vertical depth Conductor 112' 16" 200 sx Permafrost 112'MD 112'TVD Surface 2902' 10-3/4" 1650 sx Fondu & 2902'MD 2662'TVD 250 sx AS II Production 8337' 7" 838 sx Class G 8337'MD 6535'TVD Vann Gun ~ 7902' Perforation depth: measured 7552 ' -7591 ', 7601 ' -7648 ', 7654 ' -7688 ' , 7700 ' -771 2 ' , 7796 ' -785( true vertical 5962'-5990' 5999'-6030', 6034_'-_6..059' , , , 6067'-6075' 6135'-6174 CEIVED Tubing (size, grade and measured depth) 3-1/2", J-55 ~ 7510' Packers and SSSV (type and measured depth) FHL pkr ~ 7439' & WRDP ~ 1926' Description summary of proposal [] 12.Attachments OCT B86' ~,~,a Oil &gas. Coati Gommission Detailed opetl~a~l~rogram [] BOP sketch 13. Estimated date for commencing oPeration November 21~ 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~/)~ ,Z~.II./,Lf~. Title Associate Engineer · Commission Use Only ( JWR ) Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test Location clearance APproved Copy Returned Commissioner SA/135 Date J Approval NO.,,_.~-~',~ .~_ ,10rder of /~~, the commission Dat Submi{ in triplicate KUPARUK WELL 1A-2 CONVERSION TO SELECTIVE SINGLE PRELIMINARY PROCEDURE 1. Move in and rig up workover rig. Kill well. 2. Nipple down tree. Nipple up and test BOPE. 3. Shear out of SBR. POOH and stand tubing in derrick. 4. Pick up 3-1/2" drill pipe and retrieve packer. POOH. 5. Run CET. Perform cement squeeze between "A" and "C" sands if required. 6. Run in hole and set retrievable bridge plug. Remove 3M tubing head and install 5M head. Test casing to 3500 psi. Retrieve RBP. 7. RIH with casing scrapers and 6-1/8" bit to PBTD. Circulate and condition brine. POOH. 8. Re-perforate "C" sand if well is squeezed. Run GR/JB to PBTD. RIH and, set permanent packer between "A" and "C" sands. 9. Run 3-1/2" single selective completion assembly. 10. ND BOPE. NU tree and test. 11. Displace well to diesel by reverse circulation. 12. Test annulus and tubing. 13. Secure well and release rig. 14. The well will be acidized and/or fracture stimulated after rig release. (Workover Fluid' NaC1/NaBr) BHP = 2800 psi @ 6017'TVD(7330'MD) SA/135a-dmr 10-30-86 RECEIVEI) OCT 1 1986 Alaska O~ & Gas Cons. Commission Anchorage ANNULAR PREVENTER § BLIND RAIIS 5 PIPE RAtlS 4 TUBI#O HEAD 2 1, 16" CONDUCTOR SWAGED TO 10-3/4" 2. 1 t"-3000 PSI STARTING HEAD 3. 11"-3000 PSI X 7-1/16"-5000 PSI TUBING HEAD 4. 7-1 / 16"- 5000 PSi PIPE RAI'IS 5. 7-1 / 16"- 5000 PSI BLIND RAHS 5. 7-1 / 16"- 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUI'IULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUtlLILATOR PRESSURE IS 3000 PSi WITH 1500 PSI DOWNS~Atl OF THE RE6ULATOR. :~. OBSERVE TIME. THEN CLOSE ALL UNITS SII'IULTANEOUSLY ANO RECORD THE TIldE AND PRESSURE REFIAININ(~ AFTER ALL UNITS ARE CLOSED WITH CHAR61N6 PUtlP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE L(TWER IS 45 SECONDS CLOSING TIldE AND 1200 PSI REi~IAININ6 PRESSURE. BOP STACK TEST 1, FILL BOP STACK AND FIANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN 'SCREWS ARE FULLY RETRACTED. PREDETERHINE DEPTH THAT TEST PLUG WILL SEAT ANO SEAT IN WELLHEAD, RUN IN LOCK-DOWN SCREWS IN HEAD. 3, CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE HANIFOLD, 4. TEST ALL COFIPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5, INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 I~IlNUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAHS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 HINUTES, 8. CLOSE VALVES DIRECTLY UPSTREAI'I OF CHOKES. BLEED DOWNSTREAi'I PRESSURE TO ZERO PSI TO TEST VALVES, TEST REHAINING UNTESTED I'IANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAH OF VALVE AND WITH ZERO PSI DOWNSTREAtl, BLEED SYSTEH TO ZERO PSI. 9. OPEN PIPE RAHS, BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAHS AND TEST TO 3000 PSI FOR 10 FltNUTES, BLEED TO ZERO PSI. 10. OPEN BLIND RAHS AND RECOVER TEST PLUG, HAKE SURE HANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO :3000 PSI WITH KOOHEY PUI'IP, 13. RECORD TEST INFORHATION ON BLOWOUT PREVENTER TEST FOI:~I. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PEP. FORH COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. RE£EIYEI) OCT 1 986 'Alas~ Oil & Sas ans. CommlssiO~ JUNE 16, 1986 ") Anch, nratle (NORDIC RIG 10-;5/4 ARCO Alaska, inc. Po~t Office ~ 1003~0 "~ Anchorage, A~aska 99510-0360 · Te~i:~ho~ ~07 276 1215 _- September 2, 1986 Mr. C. V. Chatterton~ . Alaska Oil and Gas Conservation Con~nission 3001 Porcupine Drive __ Anchorage, Alaska 99501 Subject: Kuparuk River Field _ Production Surveys Dear Mr. Chatterton' ~ tn compliance with Rule 9 of Conservation Order Number 173, Kuparuk River Field Rules, we are hereby submitting production survey informa- tion for the second quarter of 1986. Production survey information consists of production logs and production tests as identified in Attachment 1. Production logs {spinners} identified in this attachment will be sent under separate cover. Note that several initial spinners not previously submitted to the State are being submitted at this time. If you. h,,,o ~ n, ~ +- ' . . l! U S ~l One rnP. c~rIil nq -- -y ~ ...... . the infor~nation reported, please contact me at {907) 263-4935. Sincerely, '? . ~ · ~ Oil a Cas Cons. Comm~icn ARCO AI;$ka. :nc. is a ~ub~;~e,v. , ot Atiant.~¢RichlietUCom~.any IT..--") ARCO Alaska, In~~ Post Office Box 100360 Anchorage, Alaska 99510-0350 Te!ephone 907 276 1215 DATE: 05-2 9-85 TRANSMITTAL NO: 5203 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-11!5B P.O. BOX 100300 AI~HORACE, AK 99510 TIQ%NSMITTED I.!ERE%',7IT}[ ARE 'f~IE FOLLOWING ITE,qS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TF~.NSMITTAL. SEQUENCE OF EVENTS pREssu:I?~' DATA ~2A-3 PBU- '~' SAND -2A-5 SBIIP -2B-1 PBU 2B'2 PBU ' 2B-15 PBU- POST FRAC -2B-16 PBU 2F-7 PBU- STATE 'f['~C'~:':'[') PBU- 'a' SAND ~F~__9~B U- STATE -~PBU 2G-!2 PBU- 'A' SAND o,_15 .... oB}I~ '7 · ,;~-13 PBU- 'C' SAND 2X-13 PBU POST F F,~AC 03-16-85 11-21-84 04-01-85 04-02-85 04-09-85 04-10-85 04-14-85 04-20-85 ........... 04-13-85 04-11-85 03-23-85 04-10-85 04-21-85 03-30-85 BAKER/ LYNES PRESSURE REPORTS (ONE COPY OF EACH) SET DEPTH la-1 PDU 04-23-~5 7187' .1A~ PB U 04-2 3- 8 5 7476 ' 1~ ~..- PBU 04-23-85 7476 ' la-5 BUILD-UP 04-23-~5 6957 ' la-6 PBU 04-23-85 8300 ' la-6 BUiLD-UP 04-2 3-S 5 8300 ' ia-10 BUILD-UP 04-23-85 8415 ' ia-10 BUILD-UP 04-23-25 8415 ', RECEIPT ACKNOWLEDGED: B PAE * 3. CURRIER* D & H* DRILLING L. J'OtlNSTON MOBIL* NSK CLERK TOOL NO. 1722 1302 1512 !734 1719 2062 1508 1299 .... DISTRIBUTION: W. PASTIER EXXON PHILLIPS OIL* J. RATHMELL* D2-J~-~,,;;a u. & 6=~ Cons. Commisslorl Anchorage STATE OF ALASKA'~ SOH10* UNION* K.TULIN/VAULT ARCO AlaSka, Inc./ Post Office box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 I)ATE' 05-t 5-- °''''- TRANSMITTAL N0'5t84 RE'FURN 1'0' ARCO AI._(.',."91(A, I NC. A l' T N ' R E [: 0 R D 2 £.' L E R K Al'O-1 t t 5B P.O. BOX t ANCI'IORAL;E, Al< 9~5i 'f R A f,I S H I T '1" E I) I-.I [..'. R E W I T I.-I h R [:' 1' I-I E F 0 [. L. 0 W ]: i',! 6 I l E: i'.t .S'. I!. [ ,[ .:, . :[ .? .j .:. .. F::ECEIPT ,qNI) I;:ETLJF,:N ON[." ,S'IGi',ll--.D Ct]F'Y OF.' THI,S' 'f'RANSMI'F'IFAL, I...YNE2 F:'BU F;: E:' [:' O I:( 'I' S t A- 2 ,-':, 4-. ::?. - i¢1-2' 6,4--2S-85 i A-5 04-''~ '5 ..: .~ -' 8 t A--6 4)4-23--8D iA ¢ ¢)" ,--, - o 64 - .... 3 -" 85 i A-t 0 04--23-85 i A-I G 04-'~3-85 i C--6 04-2 "=' I C-'6 04-'23-85 t F-5 (')4 . -' t F"'3 . 04-'2S-85 t F:'-- 5 04 -" 2 i F'-S 04-23'-85 t F:-7 04-23-8% t F- ¢ 04-2S "~ 1G-4.. 04--23-°'::',::, .., I6-4 04-23 .... '~:' ( 0 H [" C 0 I::' Y 0 F: [" A C I"1. ) TOOl_. SET DEF"fH 7 t 87 7 :I 76 7,176 84t5' 9'?:88 6 t 55 6 t 5 5 70",'*5 '"~ · °"7 I~' /(')~ ..~ ?'St2 67(.)t 670t TOOL. t 7 ''~ ''~ t 30::~ t ':~ 1 2 ._ t 7.'34 t7t9 20.::':,2 1299 t 508 .., Jt 8 i S(~'? ~'. 0 iSi i t3t8 t '7 qZ '7, 13t7 15t~ F~:EC["' l F°T ACI(NOWL. EI)[;ED · BF'AE* B. [.' U F< I-:: I E R .x- CI.iE VI~ON-x- I) & M* D I:;: I I.. I.. I N G L.. J[]I..IN.".;'TON MOBIl_, NSi( CI_ Ei:::i( D I $ 'f' R I i.'~ LJ T ]: 0 N ' l,,J F'A2HIT_'F( ' SA1;6]~EOipF~ ,ALASI< n-x- l:'.-.XXOi',l SOHIO-x- ~as Cons. O0n,~,:ssi0r, P I-'11 !_ L I P 2 01 L * U i',l I 0 N'x. A J. IqA'f'HMF'iLL* I( ,, TUL Ii',I/VAULT RETURN TO: I'RANSM I 'I'T E D RECEIF'T AHD ARCO Alaska, inc.f" Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 05-t 5-85 TRANSMITTAL N0'5t85 ARCO ALASI<A, IN(], ATTN: RECORDS CLERK Al'O-1 t t 5B F'·O. BOX t00360 ANCHOI:;tA(;E, Al< 995t0 I"iE;REWITH ARE 1'HE F'OI_LOWING RETURN ONE SIGNED COF'Y I I'E. HS ,~A CI< NOWLED[;E OF 'TI--lIS 'FF<ANSM ITTAL , WSR/SF.Q, tJENCE OF EV[..'.t.,il'S (ONE COPY 01:' EACI'I) tA-t tA-i tA-2 tA'-2 tA-S tA-4 f A-5 tA-5 tA-6 IA-6 iA-6 tA-iO tA-t ~ iB-3 tB-3 t C-4 tC-4 tC-6 IC-6 iE-4 t 1::'-3 1 F'-3 IF-5 PBLJ F'BU RLJN LYNES RE:CORDEI?S I:".ND F'~.~tJ/F';UN WRDF' ,c'* ', ..~ gl-ir:' SIicHF:' F'BU PUi_L F'BU P B U I"IANG OFF LYNE.k' i""RIESSUF;;I:': BOHBS' FOF< F'BU i:" I N I ,S' H F' B U RLIN LYNI::':.5' RECOF;~DEF(S F'LILL LYNE$ RECOI:,:DERS P B U F' B U 5' B i"1F:' SBHF' RUN LYNE$ RECORDE:i:;:S RFTRIi:"VIE LYNES I",:FC, ORI)FF<S RUN Si::']: i',INFi:;:/TEMF:'[':.:RATUF;;E SLIRVEY--L. EAI< DEI'I:"CT ION RUN F:'BU SURVEY I N ,J E C l' I V I I'Y T [': :';"f' INJIFCTIVITY TEST INJECTION 'f'l"":.'-';T/' A 'SAND T EHF'ERATURE/$F' I N N E F;:-- LEAK DE:'TECTION RUN LYNES TANDEM F'RI:':'SS'UF;:i:..' BOMBS' F'OR F'BU RETRIEVE LYNE,S' RECORI)ERS RUN L. YNES RECORDEI:;:S ..... 'C' SAND ONL't RIi"'TI;: I I.'-.VE I_YNF.$ I'::ECOF;:DIi:'F;:S BF'AE~ B. CURRIER* C H E V R 0 N '~ D & M* 04 -2 t -8'5 CAMCO 04 -' '22 - 85 C A M C 0 · ) £:' (') 4 - 21 -' 6 .~ C A M C 0 · O4-2;5 "'"' -8.> CAMCO 0'1-t 9-85 CAMCO ' '04-t 9-85 CAMCO 04-21 -85 CAMCO (~4-.22-85 CAMCO ¢4-2i-85 OI'IS (.) 4 -. 2 t -. 85 O'f I S 04-22-135 [)TIS (')4 ,..1 -85 CAMC[) · 04-°'~/"~3-85-..,.. ... CAMCO O 4-.":Z 1 -85 CAHCO 04.-22-8'"~ CAMCO 04-.20-85 CAMCO 04-25-85 CAMCO 04-2t -.85 OT I,S" 04-.23-85 OTIS 04 -'.'"' 3 "'~' ':' ,.. -,::,..> C A M C 04 -. 26- 85 C A H C 04-t 9-85 (:~4-20-85 ARCO 04-22-85 ARCO 04 -27-85 OTIS 04-2t -85 O'T'I S 04-23-85 OTIS 04-2t -85 OTIS' 04 "~"> '"' --. ~-8~ O'FIS ACI<NOWLEEDGED: ............. ........... DR Ii..1_ I NC; I,.,I. I:'AS HEi:;: i .... J Oi"iN.'~TON r:-'XXON , H 0 I{'. I I... , F:' I--I I 1.. L I F:' 5' 01 L N,:?I( CI_EF;:I< .x.J, I:'<A'I'HHI:"'LL DATE: *STATE OF ALASKA *SOHIO ,UNION i<, 'rtJl.. ~. N/VAUL. T ~,i~cno~a~e, ~iasKa ~5'~0-~$i3iJ Telephone 907 276 1215 '¥F;;¢~N,~'H :['I'T¢~L NJ): ~ t 6['3 I:;:1E T t..ll;;iq T 0 · :1: T Iii: f"i '[ ~:'~-2 l:-'l...Ot,..J ]: N(.; [;l:;:l-'-'~I)]:lii:HT '~ f~ .... 5 F L- 0 W 3; N ~; G R i:~ I) I E N T 0 3 '-' 0 <? "" 0 5 ~ I... "" 4 :1: i',l T !!.". R N ]: 'T' T r.-!: iq '1' I... :[ F:' T ti) 4 - 0 6 .--I.:] 5 · i (;]---. 0 S"l" ~:, T ]: C G R ~-'~ I) ]: iii: N T 0 4 .-. 0 S -- E) 5 ARCO.Alaska, inc. t~ Post Office . 100360 .Anchorage, Alaska 99510-0360 Telephone 907 276 1215 r ;'..':: .... r:. 'r r:,T ?:.,[::? ? ,c'il., ...... L. li.'. r',~':i !:: ~',. .t. ~ , .-,,...,.,,... ~ ..... .... -", I:: '- '::' ~...- L' ~'~. 7i:' ',..~ ~,~'.-, .. , :'.. "["~ I 'I' ~'. I ~'" S: c--i !:::, l": :!: !i::r,'"' :;,' ;...' ,. ,,~' q',','H. ,:; 'I" 0 ~-~.. i::: '::.'.': ':',:' r~ t';! -:'.-' :, ',... ......... . ........ · . :" '~ ~'~ ¥" '[ I :,; I r', ..'? ;".-. C.' ~. !~:" .-".':,.~, ..: .:,.,.. . ,... ~... ;,.: -' , ....... .= ~ ~ :,: ~ t'; :.... ,::,. ...... F'H I' I ':' ~ " .... M,::" CL.r"R''' ,I ' ...... ' ...... ' ' · ',,. : .... .... ~ t". } : ;s !'* . ~-..' "'". ..... ~. ',' L-i"t I i I; i=..ol...~... '' ....... ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska. Inc. , ..-;.':c'.'-,c ~,7 277 5f37 Return To: · . . ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchora§e, AK 99510 Date: 10/08/84 Transmittal No: 4759 PAGE 1 of 2 ,/~Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ' ~~RVEYS/PRESSURE ANALYSIS 5/ll,12/84'Torque Turn (Pressure & Temp Surveys) 7/06/84 Camco - 7/10,12/84 Camco 5/10/84 Otis 12/17/83 Otis Static /04/84 Otis 2/2!/83 Camco 12/23/83 Camco 8/11/84 Otis 5/21/84 Camco 5/13,14/84 Torque:Turn (Pressure & Temp Surveys) 6/26/84 Camco Static 6 / 30/.84 Camco 5/26/83 Camco HP 8/11/84 Camco 6 / 28 / 84 Camco 5/18/83 Caraco HP .. ~.4j. it!~,..~ .~ ....w.. 't'!i,.,~!~' 12/27/83--.Otis ii~i~Static 12/14/83 Otis ? 12/15/83 Otis :,: 7/03/84 Otis 4/10/84 Camco Receip 7 ~ac~nowledged: B. Adams F.G. Baker P. B~xter BPAE Chevron Date: DISTRIBUTION D & M Drilling .Geology Mobil NSK Operations W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell R&D C. R. Smith Sohio Union Well Files ARCO Alaska, Inc. , .. ;.':er, c ~.~,: 2=7 5[37 Date: 10/08/84 Transmittal No: PAGE 2 of 2 4759 Return To: · . · ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 smitted herewith are the following items, Please acknowledge receipt and return one signed copy of this transmittal, 2C-2 2C-6 5 3C-6 3C-6. 5/28/84 11/09/83' 11/09/83 11/08/83 11/08/83 4/18/83 4/24/83 4/22/83 4/30/83 4/28/84 4/29/84 5/04/84 5/06/84 8/12/84 5/08/84 5719/84 5/17/84 .. / cat Receipt Acknowledged: Otis Lynes 'Lynes Lynes Lynes Camco Camco Camco Otis Camco Camco Dresser Otis Otis Camco DrESser Dresser PBU Flow Survey (Gradient). Static Gradient Mini Drawdown & BUildup Survey ~ate~ DISTRIBUTION B. Adams F.G. Baker P. Baxter BP;~ D & M Drilling Geology Mobil W.W. Pasher G, Phillips Phillips Oil J.J. Rathmell C. R. Smith Sohi° Union Chevron NSK Operations R&'D Well Miles KUPARUK EIA31NEERING William VanAlen ~: D.W. Bose/Shelby J. Matthews Transmitted herewith are the fol lowing: PLEASE NOTE: BL - BLUEL INE, S - SEPIA, F - F i LM, T - TAPE, / / '~LEASE RERJt~ RECEi PT TO: ~ ALASKA, INC. Aiaska ()i~' n A~: ~IE~Y J ~~B~ A~/111 5-B ~ uas Co~s. P. O. ~X 100360 Anchorage ~E, ~. 99510 KUPARUK ENGINEERING TRANSMITTAL TO' ~William Van Allen FROM' D.W. Bose/Shelby J. Matthews WELL NAME- Transmitted herewith are the following' PLEASE NOTE' BL - BLUELINE, S - SEPIA, ..L /pECIPT ACKNOWLEDGED: LEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN- SHELBY J. MATTHEWS - AFA/3!I P"O. BOX 360 ANCHORAGE, AK. 99510 DATE KUPARUK ENGINEERING TO: DATE: TRANSMITTAL # /~ / D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, ~ FILM, T TAPE RECEIPT ACKNOWLEDGED: ~~LEASE RETURN RECEIPT TO: DATE: · ARCO ALAS~, INC. ~,n~,,-:? ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX '360 ANCHO~GE, ~ 99510 ALASK L AND GAS CONSERVATION .:tM1SSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG ' ...... 1. Status of Well Classification of Service Well OIL ~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-71 3. Address 8. APl Number P.O.Box 360, Anchorage, AK 99510 50- 029-20599 4. Location of well at surface 1259'FSL, 313'FWL, Sec 5, T11N, R10E, UM 9. Unit or Lease Name Kuparuk 25647 At Top Producing ~nterva~ 117;"FSL, 3750'FEL, Sec.6, TllN, R10E, UM 10. WelINumber 13iE ~' lA-2 At Total Depth ~,~', j.~tS'FSL, ~FEL, Sec 6, T11N, R10E, UM 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 100' RKBI ADL 25647 Kuparuk River .0il Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of CompletiOns 6/15/81 6/27/81 7/2/81 -- feet MSLI 1 · 17. Total Depth (MD+TVD)8355! MD ~5~TVl) 18.Plug Back Depth (MD+TVD)8242I FID YES [j~] 19. Directional Survey NO I--} I 20. Depth where SSSV set1926 feet MD I21' Thickness Of PermafrOst1650 (approx) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/NGT/CAL, CBL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1~" ASt~ H-/*O .~,rf 112' 2M' 200 sx Permafrost, in ~/&,, /z~ ~t~ ~_~ .~,,r~'. 2902' 1~I ;il/* 1F;50 .~x Fondu & 25( sx AS II 7" 26# K-55 Surf 8'337' 8 ti/*" Rt8 .~x Class C 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD · interval, size and number) . SIZE DEPTH SET (MD) PACKER SET (MD) 3 !/2" 75'10' 7/*:19' 7552'-7591 ' 7601 '-7648' W/4 SPF ' 26.' ACID, FRACTURE, CEMENT SOUEEZE, ETC. ' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7654! -7688' 7700' -7712 ' N/.A. · 7796' -7850' .. 27. " PRODUCTION TEsT " Date First Production I Method of Operation (Flowing, gas lift, etc.) ' ' :I ' :' ' ' ' ': : ' ': ~ ' ' 12/26/81 flowing , , Date of Test Hours Tested PRODUCTION FOR gl L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 7/31/8! !~. _h_l,.$._ T~STpERIOD I~. 1733 711 -. 40/~;z~ I. /,10 Flow. Tu.~bing Casing pressure CALCULATED ' OIL-BBL GAS-MCF.. WATER-BBL OIL GRAVITY-APl (corr) 24_HoUR'RATE' 2971 .Press685 , ___ I~:. 1718 -- 24.6 28. CORE DATA -' Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A . ' ..' , , - A, ~orm 10-407 : r ' " submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' ' 30. GEOLOGIC MARKERS rC, r';,~,:,~-~ (": -'~?~::;-;:~ NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk River Form 7526' 5944' Base Kuparuk River Form. 7935' 6236' · .. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~ ~~ Area Ops. Engr. .AR ~0',~8~ Signed - , Title Date -- INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item. 16 and 24' If this well is completed for separate production from more than one interval (m!ultiple comPletion), so state i.n 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 anYmultiple 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 Supplementary Test Data A-1 RU WLU, tested lub. to 2500 psi. RIH with HP, temp tool, gradiomanometer, & fullbore flowmeter. Opened well for flow test and survey. HP tool set at 5933'ss Flowed at rate of 2880 BOPD. GOR=387 FTP=325 psi, FBHP=1860psi. Ra~ ..... p~oduction logs. SI well for PBU, final SI BHP=3094 psi. POH with PL string. Secured well 7-3-81. A-2 B-2 C-1 C-2 RU WLU, tested lub. RIH with fullbore spinner, temp. tool, HP, gradiomanometer & CCL. HP tool set at 5948'ss. Opened well for flow test and survey. Flowed at rate of 2971 BOPD. GOR=410, FTP=685, FBHP=2490 psi. Ran production logs. SI well for PBU, final SI BHP=3091 psi. POH with PL string. Secured well 8-2-81. RU WLU, tested lub. RIH with spinner temp t~ol, HP and gradio. HP tool set at.6145'ss. Opened well for flow test and survey. Flowed at rate of 2972~BOPD. GOR=350, FTP=380, FBHP=2131 psi. Ran production logs. SI well for PBU, final SI BHP=3173 ~ psi. POH with PL string. Secured well 6-26-81. Production test results: Flow rate = ~~ BOPD, GOR=435, FTP=400 psi, FBHP=1990 psi.. HP tool set at 6329'ss0 SI well for PBU, final SI BHP=3252 psi. POH with PL string. Secured well 5-9-81. RIH with HP, temp tool, gradio and fullbore flow- meter. HP t~ool set at 6307'ss. Opened well for flow test and survey. Flowed at rate of.~ BOPD. GOR=401 FTP=270 psi, FBHP=1866 psi. Ran production logs. SI well for PBU, final SI BHP=3160 psi. PDH with PL string. Secured well 5-7-81. OCT 1981 Alaska Oil & Gas Cons Co'omission .Ar~chora~ October 1, 1981 Supplementary Test Data Page Two C-7 RU WLU, tested lub. to 2500#. RIH with HP, gradio, temp tool and spinner. HP tool set at 6458'ss. Opened well for flow test and survey. Results un.reliable due to bad test data SI & secured well on 5-18-81 Retest performed 7-12-81. RIH with production tool, set HP at 6489'ss. Opened well for flow test and survey. Flowed at rate of 1528 BOPD. GOR=344, FTP=170 psi, FBHP=3244 psi. Ran'"~production logs. SI well for PBU, final SI BHP=3240 psi. POH with PL string. Secured well 7-13-81. C-8 RIH with HP, temp toOl, gradio, spinner and CCL. HP set at 6448'ss. Opened well for flow test and survey. Flowed at rate of 413 BOPD. GOR=366, FTP=120 psi, FBHP=2181 psi. ~'~ porduction logs. SI well for PBU, final SI BHP=3264 psi. POH with PL string. ~Secured well 5-23-81. RE *EIV'ED ()CT 13 ~laska Oi; & Gas Cons. ConTi~ission ^r~chorage ARCO Alaska, Inc. Post Office ,, 360 Anchorag~:'~,,;aska 99510 Telephone 907 2?7 5637 October 1, 1981 Mr. William VanAlen State of Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99504 Attached is well test information B-2, C-i, C-2, C-7, C-8. The test subsequent to the completion of Report (Form 1-407) or Sundry notice was submitted to you. Area Operations Engineer ! for Wells A-i', ~ results were obtained the Well Completion (Form 10-403) which EAS/bl Attachments RECEIVED Alaska Oil & Gas Cons. Commission 4nchorage ARCO Alaska. Ir, c ~ 5td).~;Mia,¥ o~, Atl~mtlcR;cP, fif.idComDa~v., October 9, 1981 Mr. P. A. VanDusen District Drilling Engineer ARCO Alaska, Inc. Po O. Box 360 Anchorage, Alaska 99510 Dear Mr. VanDusen ~ We have recently received completion reports on several wells where the reported bottom hole location cannot be verified by the directional surveys that have also been submitted' The list of the wells in question is enclosed. We would apprec£ate Four checking to determine the data used in arriving at the bottom hole locations for these wells. Since we have an internal program to cross-check the accuracy of the submitted data, it is necessary to detemine why the discre- pancies exist. if you could have a member of the department that determines this data call Mrs. Elaine Johnson at 279-1433 it should pin- point where and why there are differences. Thank you for your help in this ~tter. Yours very truly Harry W. Kugler Commissioner Enclosure. ARCO Alask Inc. Post Office ~L,~ Anchorage, A I ,? ,:. '-.: ~' Telephone 9f17 277 5637 September 28, 1981 Mr. Harry Kugl.er State of Alaska Alaska Oil and Gas Conservati on Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 12-11 DS 16-4 West Sak #18 DS 12-12 DS 16-5 A-2 DS 14-9A DS 16-14 A-3 DS 14-19 DS 17-7 B-4 · DS 14-20 DS 17-8 C-8 DS 16-1 DS 17-9 Dear Sir: Enclosed please find the Completion Reports for the following wells: A-2, A-3, B-4 and C-8. Although these Kuparuk wells have been per- forated, production test data has not been obtained; this information will be forwarded to your office When available. .Also enclosed are Completion Reports for the following wells: DS 12-12, DS 14-19, DS 14-20, DS 16-4, DS 16-5, DS 17-7, DS 17-8 and DS 17-9. Production test information is not applicable for these wells since they have not yet been perforated but will be submitted to your office when we obtain the information. Previously unreported information such as locations for bottom hole, producing interval and geological forma- tions have been added to the updated Completion Reports. DS 14-9A and West Sak #18 have been plugged and abandoned. An updated Completion Report with Drilling HiStories for these wells is enclosed. Information regarding West Sak #18 is of a confidential nature and we would appreciate securely storing the report where it will receive minimum exposure. The initial Gyroscopic Survey for DS 16-1 was unacceptable and a rerun is presently being authorized by our engineering staff. An updated Completion Report for this well will be sent to your office subsequent to our receiving an acceptable survey. The remainder of the requested informat'i°n - an overdue Completion Report on DS 16-14 and an incomplete Completion Report for DS 12-11 was sent to your office August 27, 1981 and was apparently enroute at the time of your September 2, 1981 letter to this department. Also included are completion Gyroscopic Surveys for DS 12-12, DS 17-7 and DS 17-9. Sincerely, ~j~Str~i~ct. Dri l 1 i ng. Engineer SEP 0 ]98! Oil & Gas Cons. Commission ~chorags ALASKA ,; AND GAS CONSERVATION C ,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,. 1. Status of Well Classification of Service Well OIL X]X GAS [] SUSPENDED [] ' ABANDONED [] SERVICE [] , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-71 3. Address 8· APl Number P.O. Box 360 Anchorage, AK 99510 50- 029-20599 4. Location of well at surface__ 9. Unit or Lease Name 1259' FSL, 313' FWL, Sec 5, T11N, RIOE, UN I~CxrP~T~(SNsl Kuparuk 25647 At Top Producing Interval '~ VERIFIED ~ 10. Well Number " 1172' FSL & 3750' FEL, Sec 6, T11N, RIOE, UN su~. ~ '. A-2 At Tc~lllgqepth c/~q, '2 ~ B.H.~ _. _-- 11. Field and Pool ~ FSL &-~3q"N' FEL, Sec 6, T11N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 100' RKBI ADL 25647 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of ComP'l'etions 6/15/81 6/27/81 7/2/81 I '- feetMSL I ,1 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set i 21. Thickness of Permafrost 8355'MD 8242'MD YES[~X NOr-1I 1926 feetMD 11650 (approx) 22. Type Electric or Other Logs Run IIIL/SP/BHCS/GR; FDC/CNL/NGT/CAL, CBL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD . . SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1~,, - ~g~ N-zln Surf , .]12, 24,, 200 SX. Permafrost · 10 3/4" z~_.~# I<-.~.~ Surf 2902' 13 3/4" 1650 sx Fondu & 250 ~s.x AS II · 7" 26# I<-~.~ gurf F~337'.. 8 3/4" 838 SX. Class G . , , [ ,, · 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) ........ " 3 1/?" 7510' 7429' 7552'-7591' ,. 7601'-7648' w/4 spf ::' ' 261 '' ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7654'-7688' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED - ', .. ~., , -. ,,~ ,.' , ( ' . .... , , 7700,...7712, :~ .N/A i I ' 7796'-7850' . , 27. ' ' ' .... ::PRoDucTION 'TEST ' Date .First Production , Method of Operation (Flowing, gas lift, etc.) . , Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow'Tu6'[ng" Cfising Pressure ": CALCULATED' I~ OIL'-BBL "'GAS-McF' wATER-BBL OIL GRAVITY-APl ('corr) Press;~ .... ; '"'.;' ' ..... ' 24-H~)UR RATE.'~ ~: ' ' "' 28. ;' ~ ' ' " " ' :"' ': ' CORE DATA ' , . Brief description of lithology, porosity, fractures, apparent dips and presence of oH, gas or water· Submit cdre chips. N/A ' , , . , · :, .. -. ,-. , -. ' · :,~ ~ - .. , . - m . .. Alaska 0il & Gas Cons. Cor~is$ior~ " AnCl~orag~ _ Form 10-407 ..... submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' ' 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure (~ata, alt fluids recovered ancl gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk 7526' 5944' N/A Top Upper Sand 7554' 5964' Base Upper Sand 7575' 5979' Top Lower Sand 7785' 6127' Base Lower Sand 7850' 6174! Base Kuparuk 7935' 6236' · , · · 31. LIST OF ATTACHMENTS Drilling History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~, ~~ Title Disto Drlgo Engo Date 9/17/81 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 2~: If this well is completed for separate production. from re:Ore than one interval (multiple completion), so state in item 16, and in i:~.em 24 show the.producing intervals for only the interval rePerted in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to suCh interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). '~, Item 23' Attached supplemental records for this well should:show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift,' Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, ShUt-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ALASKA OIL AND GAS CONSERVATION COMMISSION ~LL LOCATION DISCREPANCIES Kuparuk 25647 Kuparuk 25645 Kuparuk 25649 B-4 C-8 The following are all in the Prudhoe Bay Unit~ DS 12-12 DS 14-11 DS 14-19 DS 14-20 DS 16-4 DS 16-5 DS 17-7 ~ 17-8 DS 17-9 September .2, ~1981 Mr. P'. A. Van Dusen District Drilling Engineer Arco!' A la s ka, 'Inc. . P.O. Box 360 ' ! Anchorage, Alaska 99501 Overdue Data Submission Dear Mr. Van Dusen: Wells on the attached lists are those for which Completion ~eports (form 10-407) are either incomplete or apparently overdue, with completion,~ abandonment, or suspension dates prior~to ~August 1, I981. i ~ . The first list is of those wells for which an incomplete Completion Peport was filed, with the comment that the locations at the top of the producing interval and at the total depth were be submitted" or "N/A." The'iccmpletion dates go back to January 9. % The second list is of those wells for which available information indicates the wells have been completed, but the 30 day filing period has passed wi thou~ a Completion Report having been submitted. We need to be brought up-to-date on directional survey problems that may be responsible for these ]ate filings, or have the required directional surv~ey~ and reports submitted to us. We would appreciate a response at your earliest convenience. Sincerely yours, Harry Rug ler Commissioner h~WK / JAL/g lh P. A. Van Dusen~ September 2, I981 Incomplete Completion Reports Well Name and Number CgmP 1 e t ion / Aba ndonIne nt Suspension bate Prudhoe Bay Unit DS 16-1 Prudhoe Bay Unit DS 14-9A Prudhoe Bay Unit DS 16-4 West Sak 18 Prudhoe Bay Unit DS 16-5 Kuparuk C-8 Prudhoe Bay' Unit DS.14-19 Prudhoe Bay Unit DS 17-7 Prudhoe Bay Unit DS 14-20 nit DS 12-11 Prudhoe Bay Unit' DS 17-8 1-9-81 3-21-81 3-27-81 4-17-81 4-21-81 5-15-81 6-6-81 6-10-81 6-30-81 7-1-81 7-2-81 7-2-81 _ v) Completion Reports Overdue. (. ,. Prudhoe Bay Unit DS 16-14 Kuparuk B-4 Kuparuk A-3 Prudhoe Bay Unit DS 17-9 Prudhoe Bay Unit DS 12-12 7-9-81 7-14-81 7-24-81 7-25-81 7-26-81 J. J. Pawelek/Ann Simonsen DATE- ~-PP'-~/ WELL NA;.iE- Transmitted here;vi th are the following' PL~A,E HOTE BLUELIilE,. SEPIA F - FILH, T - TAPE /'~"~~LEASE RETURH RECEIPT TO' RECEIVED 'A!~ska. Oil & Gas Cons. Commlssior~ ARCO ALASka, If,lC. Anchorage ATTH: AHH SIFIONSEH - AFA/311 P.O. BO;< .360 ANCi4ORAGE, AK 99510 ,' NORTH SLOPE ENGINEERING TO' TRANSMITTAL FROM: J.J. Pawel ek/Ann Simonsen DATE' ¢7 - ?~-IS 1 WELL NAME' Transmitted herewith are the following- PLEASE NOTE:~)-BLUELINE, (~-SEPIA, F - FILM, T - TAPE ~PLEASE RETURN RECEIPT TO' ARCO ALASKA:~?, INC. ATTN' ANN ~IMONSEN - AFA/311 P.O. BOX 36~,':. ~' .,, ANCHORAG ~ >.~F% "" ";"' ,. RECEIVED D^T~- JIJL ~ "/lgSl Aia8ka 0il & f: ........ HORTH SLOPE ENGII,IEERIHG TRAHSMITTAL # ~9/' TO' ~ ///~,,.,'/~W~) FROM' J. J. Pawelek/Ann Simonsen DATE' '~-- 7.-!-- 5/ WELL NAME' Transmitted herewith are the following' PLEASE HOTE' BL - BLUELIHE, S - SEPIA, F - FILM, ~,T~- TAPE ~PLEASE RETURN RECEIPT TO' JUL 2 4 198I DA/E_: ~, Aiasl<a ,.,N & ,G~,s Cc-r.~. C~m."nissio, Anchorage RECEIVED ARCO ALASKA, INC. ATTN' ANN SIMONSEN - AFA/311 P.O. BOX 360. A N C H 0 R A G.E., '" 3.~e':951 0 , , NORTH ~LOPE EHGIHEERIHG i TO' TRAHSMITTAL # ~,/ FROM: J. J. Pawelek/Ann Simonsen DATE' ~)~-- ~/ WELL NAME- Transmitted herewith are the fol'lowing' PL. EASE I~OTE~- BLUELI~E, ~])- SEPIA, F- F,~LM, T TAPE RECEIPT .~CY,[',OWLEDG "..~.-~.. - ' ' '-,. ~S RLC~?T TO' ARCO ALA~rtA INC E RETURiI ~ ~' q" , · ATTN' A~l~i SIHO~]SEH - AFA/3ll P.O. BOX 360 A~I~CHORAGE, AK 99510 DATE' Naska Oil & Gas Cons. Anchorag9 July 21, 1981 Mr. Hoyl e Hamil ton State'of Alaska Alaska Oil and Gas Conservation Com~i ssion 3001 Porcupine Drive Anchorage, AK 99501 Subject- DS 12-10 DS 16-14 DS 12-11 DS 17-7 DS 14-18 DS 17-8 DS 14-19 A-1 DS 14-20 4m~m~L~E~ DS 16-13 B-3 B-4 Dear Sir' Enclosed 1) The 2) The 3) The DS 1 4) The A-1 please find: monthly reports for DS 16-14 & B-4. subsequent Sundry Notice for DS 14-18. Completion Reports for DS 12~0~ DS l~ DS 14-19, 4-20, DS 16-13, DS 17-7, DS -~, A-1 & B-3. Gyroscopic Surveys for DS 12-10, DS 14-20, DS 16-13, and B-3. Sincerely, P. A. VanDusen District Drilling Engineer PAV/KJG-sp Enclosures RECEIVED JUL 2 1 1981 Al...ska Oil & Gas Cons. Commission '/'Amchorage .... O(,~"~ ~,vIlSSIO N '~'i L.' STATE OF ALASKA ALASKA AND GAS CONSERVATION C ,, WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, ];nc. 81-71 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 50-029-20599 4. Location of well at surface 9. Unit or Lease Name 1259'FSL, 313'FWL, Sec 5, TllN, R10E, UM Kuparuk 25647 ... At Top Producing Interval 10. Well Number To be submitted A-2 At Total Depth 11. Field and Pool To be submitted Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 100' RKB ADL 25647 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 6/15/81 6/27/81 7/2/81 --- feet MSLI 1 17. Total Depth (MD+TVD) :18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8355'MD 8242'MD YESES/( NO[] 1926 feetMDI 1650 (approx) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR. FDC/CNL/NGT/CAL, CBL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-40 surf ll2' 24" 200sx Permafrost 10-3/4" 45.5# K-55 surf 2902' 13-3/4" 1650sx Fondu & 250s> AS II 7'" 26# K-55 surf 8337' 8-3/4" 838sx Class G i 24, Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD · interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3½" 7510' 7439' 7552-7591' 7601-7648' w/4 spf 26. ACI D, FRACTUR E, CEMENT SQUEEZE, ETC. ..7654-7688' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED · . , , ., ,. 7700-7712' n/~ 7796-7850' .. · . , 27. PRODUCTION TEST Date First Production ~' I Method of Operation (Flowing, gas lift, etc.) : . ',, n/a I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ . . OIL-BBL GAS~MCF WATER-BBL OIL GRAVITY-APl (corr) Flow T:ubing Casing Pressure CALCULATED Pre§s. 24-HOUR RATE ., 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED . "' JUL 2 ! 1981 " ' ' ~as.~ 0ii.& Gas Cons. ~chorag, a Form 10-407 Submit in duplicate. Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS .~ORM.~,T;f;"': ';- i:-'..-, S NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. To be submitted n/a · · , ,, ....... 31. LIST OF ATTACHMENTS Drill ing History ~ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ......... INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.. Item 1: Classification of serVice Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate whiCh elevation is used as reference (where not otherwise shown) fOr'depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If.~.this well is completed for separa~:~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". A-2 DRILLING HISTORY NU hydrill & diverter. Spudded well @ 0830 hrs, 6/15/81. Drld 13-3/4" hole to 2915' Ran multishot. Ran 70 its 10-3/4" 45.5#/ft K-55 csg w/shoe @ 2902~. Cmtd 10-3/4" csg w/1650 sx Fondu & 250 sx AS II. ND hydrill & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC '& cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg ErCW - ok. Drld 8-3/4" hole to 8195'. Ran DIL/SP/BHCS/GR, FDC/CNL/NGT/CAL. Drld 8-3/4" hole to 8337' TD. Ran 185 its 7" 26#/ft K-55 csg w/shoe @ 8337'. Cmtd 7" csg w/838 sx Class G. Instld 7" pack- off & tstd to 3000 psi - ok. Displaced well to NaC1. Tstd csg to 3000 psi - ok. Drld cement to 8242' PBTD. Ran CBL/CCL/GR. Arctic packed 7" x-10-3/4" annulus w/200 bbls H20, 250 sx AS II & 112 bbls arctic pack Ran Gyro. Ran 3½" perf completion assy w/tail @ 7510' & pkr @ 7439'. Tstd tbg hanger & packoff to 3000 psi - ok. Set pkr. Displaced well to diesel. Tstd tbg ~to 3000 psi f/1 hr - ok. Tstd ann to 1500 psi f/1 hr - ok. ND BOPE. NU tree & tst to 3000 psi - ok. Dropped perf bar & perf'd 7552-7591 ', 7601-7648', 7654-7688', 7700-7712', & 7796-7850' w/4 spf, Flowed well to tst tanks. SI well. Released perf guns. Bull headed 50 bbl diesel down tbg. Closed SSSV. Instld tree cap & tstd 3000 psi - ok. Secured well & released rig @ !200 hrs, 7/2/81. EC 'iVED JUL 2 1 ~1 Oil & 13as Cons. Co/nrnis~i% 400' 800' 1200. SURFACE LOCATION IS 1259' NSL, 1513' EWL , SEC. 5 T II N, R I0 E, UM VERTICAL SECTION ARCO ALASKA INC KUPARUK A-2 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE I" = I000' JULY 2:5, 1981 321 ALL DEPTHS SHOWN ARE TVD .. 5200 TVD : 6548' TMD : 8:555' HORIZONTAL VIEW ARCO ALASKA INC KUPARUK A-2 RADIUS OF CURVATURE GYROSCOP lC SURVEY SCALE I" = I000' :JULY 25~ 1981 T V D = 6548' TM D = 8555' CLOSURE N 89° 18' W - 4598' · .................... T '11 'N' R ~10 E-, U'M ......................... I ALL DEPTHS SHOWN ARE TVD COMPLETION REPORT ARCO ALASKA INC GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDC BY FM LINDSEY & ASSOC 23 JULY 81 KUPARUK A-2 KB ELEV 100. FT. · JOB NO 5556 RECORD OF SURVEY TRUE MEAS. DRIFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC . D M DEG. 0 0 0 100 0 0 3OO 0 0 4O0 0 0 5OO 0 0 60O 0 0 70O 0 0 800 0 0 9OO 0 0 1000 1 0 0,00 -100.00 N O.OOW 100.00 0.00 N82.SlW 300.00 200mO0 N79.83W 400,00 300,00 N79,45W 500,00 600.00 700,00 800,00 900.00 999,99 400,00 N79.O6W 500,00 N78,68W 600,00 N78.30W 700,00 N78,18W 800,00 N78,33W 899,99 N74,98W 1100 4 .0 1099.88 999,88 N82,61W 200 5 0 1199.57 Z099,57 N79,78W ~300 7 0 1299,02 1199,02 586,43W 1400 11 45 1397,66 1297,66 588,20W 1500 18 0 1494,26 1394.26 N83,O1W 1600 21 0 1588,51 1488,51 N88.53W 1700 23 0 '1681,22 1581,22 N89,00W 1800 25 0 1772.57 · 1672,57 N89.01W 1900 27 0 1862.45 1762,45 N88,58W 2000 30 0 1950.32 1850,32 N89,16W 2100 30 15 2036,81 1936,81 N88,41W -2200 32 15 2122.30 2022,30 N86,50W 2300 34 0 2206.05 2106.05 N86.56W 2400 36 24 2287.75 2187.75 N86.20W '2500 38 0 2367,39 2267.39 $8B.11W TOTAL COORDINATES ,00 ,5 0,00 W ~0.00 S 0,00 W ~iO.o0 S 0,00 w :0:. 00' ,5 ..... 0 · 00.. W_ o. oo o.oos;: w o'Oo:: S · ;0o ' 0,00 S 0.00 W 0,20 N 0.84 W 1,04 N 5,12 W 2,24 N 12.87 W 2.85 N 23.28 W 2~09 N 39.55 W 3.24 N 65,15 W 5,70 N 98.43 .W 6,51 N 135.88 W 7,21 N 176.54 W 8.13 N 220.37 W 9.07 N 268.07 W 10,13 N 318.25 W 1-2.43 N 370.07 W 15.73 N 424,61 W 19.37 N 482,15 W 20.38 N 542.58 W CLOSURES DJ,STANCE ANGLE D M 5 0.00 5 0 0 0 W 0,00 5 0 0 0 W 0,00 ,5 0 0 0 W 0.00 5 0 0 0 W 0.00 5 0 0 0 W 0.00 5 0 0 0 W 0,00 $ 0 0 0 W 0.00 S 0 0 0 W 0.00 $ 0 0 0 W 0,87 N 76 39 29 W 5.23 N 78 26 34, W 13.07 N 80 5 49 W 23.46 N 83 0 55 W 39,60 N 86 58 28 W 65,24 N 87 8 4`2 W 98,59 N 86 40 53 W 136,03 N 87 15 19 W 176,69 N 8-7 39 32 W 220,52 N 87 53 .8 W 268,22 N 88 3 42 W 318.41 N 88 10 36 W 370.28 N 88 4 34` W 4`24.90 N 87 52 39 W 4`82,54 N 87 41 57 W ~4`2,97 N 87 50 55 W DOG LEG SEVERITY DEG/ZOOFT 0,000 0,000 0,000 0.000 0,000 0.000 0.00.0 0,000 0,000 1.000 3,000 1.000 2.010 4.751 6.306 3.083 2.001 2.000 2,002 3.004 0.314 2.073 1.750 2.420 2.673 SECTION DISTANCE 0,00 0,00 0.00 0,00 0,00 0,00 0.00 0.00 0,00 0,85 5.13 12,90' 23.31 39,57 65.19 98e49 135.95 176e62 268,16 318,35 370.19 424,77 4`82e35 ~4,2~79 ARCO KUPARUK A-2 GYROSCOPIC SURVEY JOB NO 5556 23 JULY RECORD OF SURVEY TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG~ ~600 40 0 2445,10 2345,10 585.45W 2700 43 0 2519.99 2419,99 585.43W 2800 45 15 2591.75 2491.76 S83.46W 2900 47 0 2661.07 2561.07 584e41W 3000 47 0 2729.27 2629,27 584,21W 3100 47 0 2797.47 2697.47 $84.10W 3200 47 0 2865,67 2765,67 585,15W 3300 47 0 2933,87 2833,87 585e48W 3400 47 0 3002.07 2902,07 $85,45W 3500 47 0 3070e27 2970.27 S84.53W 3600 47 30 3138,15 3038,15 $85,65W 3700 48 0 3205.38 3105e38 $85e71W 3800 48 0 3272.30 3172,30 $85,50W 3900 47 45 3339.37 3239.37 $85e23W 4000 48 0 3406e45 3306e45 S84e68W 4100 47 15 3473.85 3373.85 S84e68W ".200 47 30 3541,56 3441e56 583,45W ~300 47 0 3509,44 3509e44 S83,48W 4400 47 0 3677,64 3577,64 S82,55W 4500 46 15 3746e32 3646e32 S82.55W 4600 46 0 3815.63 3715,63 S83,45W 4700 45 45 3885.25 3785.25 S84.06W 4800 45 30 3955,19 3855e19 S84,53W 4900 45 15 4025e43 3925*43 $84.30W 5000 45 0 4095,99 3995,99 S84,76W 5100 44 0 4167e31 4067,31 S86,35W 5200 43 15 4239.70 4139,70 S85,43W 5300 43 0 4312.69 4212,69 S87.06W 5400 42 0 4386,41 4286e41 587,68W TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M .S DOG LEG SEVERITY DEG/IOOFT 16,85 N 605,41 W 11,58 N 571.45 W 4,85 N 740,74 W 2,75 S 812,42 W 9e99 S 885e20 W 17044 S 957e95 W 2~.29 $ 1030.77 W 30,26 5 1103,65 W 605,64 N 88 24 19 W 671,55 N 89 0 41 W 740,76 N 89 37 28 W 812.43 S 89 48 20 W 685.25 S 69 21 lO W 958.11 S 88 57 25 W 1031,05 $ 88 39 0 W 1104,07 & 88 25 45 W 36,04.5 1!76,56 W; 1177,12 5 68 t4 43 W 42:'~2'$.~ i249'42 W 1250,14 S 88 3 18 W 1396,39~W. 1397,45 S 87 46 25 W D9'97~i ' i~70;49W;: 1471.71 S 87 39 5Z W 65,96 S 1544,41 W 72,48 S 1618,30 W 79,32 $ 1691,85 W 86e93 S 1765,04 W 9~.28 S 1837e99 W 104e17 S .1910e58 W 113,60 S 1982,66 W lZ2,38 $ 2054,20 W 130.19 S 2125,56 W 137e29 S 2196~69 W 1~4,21S 2267e52 W 150e96 S 2338,06 W 156e39 S 2407,9~ W 161e33 5 2476,75 W 165.80 $ 2544,96 W 168m90 S 2612.45 W 1545.82 S 87 33 15 W 1619.92 S @7 26 7 W 1693.71S 87 18 55.W 1767.18 $ 87 10 49 W 1840,46 S 87 1 56 W 1913.42 $ 86 52 44 W 1985.91 $ 86 43 14 W 2057,85 5 ~6 35 2~ W 2200~97 S 86 25 25 W 2272,10 5 86 21 38 W 2342,93 $ 66 18 20 W 2413,01 $ 86 17 1W 2482.00 5 86 16 22 W 2550.36 $ 86 1~ ~0 W 2617,91 $ 86 18 2 W 2.283 3,000 2,459 1,822 0,146 0,768 0,244 0.024 0,670 0,766 0,501 0,161 0,290 0,393 0,750 0,716 0,500 0.683 0,750 0,529 0,403 0.345 0,276 0,342 1.~58 0,865 0,800 1.037 SECTION DISTANCE 605,57 671,55 740,75 812,33 885,01 957,67 1030,40 1103e21 1176.04 1248,81 1321.89 1395,63 1469e66 1543.50 1617,30 1690.77 1763,86 1836.71 1909,18 1961.14 20~2,57 2123,83 2194,86 2265.61 2336.06 2405.87 2474.62 2542,77 2610,22 ARCO KUPARUK A-2 GYROSCOPIC SURVEY JOB NO 5556 23 JULY RECORD OF SURVEY TRUE NEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES ~5 42 0 65~8,~0 6448,10 N76*4~W 55.60 N ~597,80 W BOTTOM HOLE CLOSURE 4598.13 FEET AT N 89 18 25 W CLOSURES DISTANCE ANGLE D M 5 4~98,13 N 89 18 25 W DOG LEG SEVERITY DEG/3,0OFT 0.000 SECTION DIGTANCE ARCO KUPARUK A-2 GYROSCOPIC SURVEY · JOB NO 5556 23 JULY 81 RECORD OF SURVEY TRUE HEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D N SUB DRIFT SEA DIRE¢ DEG, TOTAL COORDINATES C L 0 $ U R E 5 D I STANCE ANGLE D N DOG LEG SEVERITY DEG/iOOFT ~500 42 0 4460.73 4360.73 $88JO3W 5600 41 30 4535.33 4435,33 S88,41W 5700 41 0 4610.52 4510.52 588.81W 5800 41 0 4685e99 4585e99 $88e41W 9900 41 0 4761,46 4661,46 S89.73W 6000 41 0 ~836,93 4736e93 N89,71W 6100 41 0 4912.40 4812.40 $89.41W 6200 40 0 4988.44 4888.44 S89.65W 6300 39 0 5065.60 4969.60 N89.55W 6400 38 45 5143,45 5043.45 N87,98W 6500 40 0 5220,75 5120.75 N87.~OW 6600 42 0 5296.22 9196.22 N87.16W 6700 42 30 5370.24 5270.24 N86.66W 6800 43 0 5443.67 5343,67 N85.80W 6900 43 30 5516.51 5416.51 N85.18W 7000 45 0 5588,14 5488,1/+ N84.53W '100 47 45 ~657.13 5557,13 N82,38W ~'""f200 49 0 5723.55 5623,55 NSI,llW 7300 48 0 5789.81 5689.81 N79.05W 7400 47 0 5857.37 5757.37 N77.28W 7500 46 0 5926.20 5826.20 N75.85W 7600 45 15 5996.14 5896.14 N74.06W 7700 45 0 6066.69 5966.69 N74.28W 7800 44 0 6138,02 6038.02 N75.65W 7900 43 0 6210,56 6110.56 N76.90W 8000 42 0 6284,28 6184,28 N76,55W -8100 42 0 6358.60 6258.60 N75,93W 8150 42 '0 6395,75 6295.75 N76,45W 171,40 5 2679.32 W 173.46 5 2745,87 W 175,05 S 2811.79 W 176.64 S 2877.38 W 177,70 S 2942.97 W 1~7.69 5 3008.58 W 1 ?.86 $ 3o74.18 w 178,39 5 3139.12 W 2684,79 $ 86 20 22 W 2751.35 5 86 23 6 W 2817,'23 5 86 26 14 W 2882,79 $ 86 29 13 W 2948,33 5 86 32 40 W 3013.82 5 86 37 11W 3079,32 5 86 41 19 W 3144.19 5 86 44 50 W 3202.,.73 ....... W 3207.69 S 86 48 46 W 3270.27 5 86 53 51 W 3328.87 W 3333.45 $ 86 59 44 W 339.4,41 ~W .... 3398.76 5 87 6 4 W 3465.6/+ .5 87 13 i W 163.80 S 3529.29 W 158.42 5 3597.59 W 192.16 5 3667.09 W ~43.92 $ 3738.99 W 1~3.19 $ 3812,97 W 120.30 $ 3886.74 W 105.18 5 3958.90 W 88.33 $ 4029,45 W 69.78 S 4098,47 W 50.45 $ 4166.65 W 32.27 $ 4234.34 W 15.94 $ 4301,21 W 0,43 $ 4366.96 W 15.48 N 4431,95 W 23,46 N 4464.44 W 3533.09 5 87 20 33 3601.08 5 87 28 42 3670,24 S 87 37 25 3741,76 5 87 47 44 3815,29 $ 87 59 57 3888,60 $ 88 13 37 3960,29 $ 88 28 41 4030./+1 $ 88 4~ 39 409'9.06 $ 89 1 '28 4166.96 $ 89 18 22 4234.46 S @9 33 47 4301e24 $ 89 47 19 4366,96 S 89 59 39 4431.98 N 89 47 59 4~64.50 N 89 41 55 0.234 0.528 0.529 0.262 0.86~ 0.361 0.569 1,00~ le049 0.663 1.250 2,027 0.550 0m642 0,579 1.535 2e992 1.443 1.517 1.376 1.171 0,272 1.198 1,157 leO12 0.413 0,691 THE FOLLOWING INFORMATION IS EXTRAPOLATED TO TD SECTION DISTANCE 2677,0~ 2743,97 2809.47 2875.03 2940,61 3006.21 3071e81 3136,74 3200e34 3263.10 3326.52 3392,09 3459.26 3927.05 3595.41 3664,98 3736,98 3811.08 3885.00 39~7,33 4097.33 4165.73 4233.64 4300.70 4366.~4 4431,82 4464.40 'ARCO KUPARUK A-2 GYROSCOPXC SURVEY JOB NO 5556 INTERPOLATED TRUE VERTICAL DEPTHS. COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE CODE MEASURED VERTICAL NAME DEPTH DEPTH TOTAL COORDINATES ' C L 0 S U R E DISTANCE ANGLE b M 23 JULY 81 ,SUB SEA K-13 3542 2098,86 W,SAK S-T 3720 3218,77 W,SAK S-B 3885 3329,29 ~,-12 4058 3445,42 K-10 4779 3940,48 K-5 6250 5026,88 K-3 6550 5258,77 K-2 6991 5581,77 BGRS 7263 5765,1% K'I 7441 5885,44 D 7526 5944,30 TOP KUP, 7~26 5944,30 C'4 7554 5963,85 TOP US 7554~ 5963,85 C-3 7575~ 5978,57 BASE US 7575 5978,57 C-2 7652 6032,79 C-1 7596 5993,32 7710~ 77 6073, <~4 7785 6127.24 TOP kS 7785--{ 6127.24 A-3 7793 i 6132.99 A-2 7815 61~8.82 A-1 7850 6174,14 BASE L5 7850'- 6174,14 KS 7935 6236.23 BASE ~U~, 7935 6236.23 PBTD 8242 6464.~2 ID 8355 65~8,i0 45,53 55,57 65,46 76,97 136,09 178,67 176,78 125,28 98,25 1280,03 W 1411,20 W 153~,31 W 1661,01W 2181,-74 W- 3171.09 W 3269,23 W 3361.30 W 3660,72 W 3859,62 W 3987,97 W 1280,84 ~ 87 57 46 W 2998,86 1412,29 S 87 44 40 W 3118,77 1534,71 S 87 33 18 W 3229,29 1662,80 S 87 20 48 W 3345,42 2185,99 S. 86 25 49 W 3840,48 3176,12 S 86 46 30 W 4926,88 3274,01 S 86 54 16 W 5048,13 3365,75 & 87 3 12 W 5158,77 3663,90 S 87 36 58 W 5481,77 3861,65 S 88 8 27 W 5665,14 3989,18 $ 88 35 19 W 578~,44 83.45 S <:::~4047e47..W ....... z+048.33 5 88 z~9 7 W 5844.30 78,13 $<!~. 78,13 $ 74,09 5 74,09 5 59,61 5 70,56 S 48,51 $ ~4,44 S 32.98 S 29,59 S 23,47 ,5. 2~ ,47 S 10,19 S ' 10,19 ,5 38,35 N 5~,60 N 4067,5z~ $ 88 53 57 W 586~,85 6,~9~..:~ ............... ~067,54 S 88 53 57 W 586~,85 4081,22 W 4133,93 W 4095,74 W 4173,44 W 4224,11W 4224,11 W 4229,49 W 4267,78 W 4267.78 W 4324,29 W 4524,17 W 4597,80 W 4081J89 S 88 57 35 W 5878,57 4134,36 5 89 10 25 W 5932,79 4096,35 S 89 0 46 W 5893,32 4173e72 S 89 20 2 W 5973,77 4224,26 S 89 31 58 W 6027.24 4224,26 S 89 ~1 58 W 6027,2~ 4229,62 S ~89 33 11W 60~2,99 4244,50 S 89 3~ 1 W 6048,82 4267,8~ S 89 41 5 W 6074.14 4267,84 S 89 41 5 W 6074.14 432~,30 $ 89 51 53 W 6136,23 4524,34 N 89 30 51~W 6364e12 4598e13 N 89 18 25 W ARCO KUPARUK A-2 GYROSCOPIC SURVEY JOB NO 5556 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 23 JULY 81 200 200. 100 0 300 300, 200 0 400 400, 300 0 500 500. 400 0 600 600* 500 0 700 700, 600 0 800 800. 700 0 900 900e 800 0 1000 1000. 900 0 1100 1100, 1000 0 1200 1200. 1100 0 1301 1300. 1200 0 1402 1400, 1300 2 1506 1500, 1400 6 1612 1600e 1500 12 1720 1700e 1600 20 1830 lB00, 1700 30 1942 1900, 1800 42 2057 2000, 1900 57 2174 2100, 2000 73 2293 2200, 2100 92 2415 2300, 2200 115 2541 2400, 2300 141 2673 2500, 2400 172 2812 2600, 2500 211 2957 2700, 2600 257 3103 2800* 2700 303 3250 2900, 2800 350 '3397 .3000e 2900 397 3543 3100, 3000 443 3692 3200e. 3100 491 3841 3300, 3200 541 3990 3400, 3300 590 4138 3500, 3400 638 4286 3600, 3500 686 0 0.00 S 0 0,00 S 0 0.00 S 0 0.00 S 0 0,00 S 0 0.00 S 0 0.00 S 0 0.00 S 0 0 · 20 N !'.:: 0 1,04 N ::: 0 2,24 N .., 0 2,84 N · 8 ' 6,65 N 10 7,47 N 12 8,74 N 15 9.71 N 16 11,94 N 19 15e95 N 2~ 19,92 N 26 19,21 N 31 12,66 N 39 3,84 N ~6 7,i1 S ~6 17~66 S 47 27,~7 S 48 54,64 S 50 62,62 S 49 72,30 S 48 82.33 S ~8 94.62 S 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W 0.8~ W 5.12 W 12.87 W 23,40 W 39e96 W 67,00 W 102.75 W 143,76 W 189,36 W 239e84 W 296,62 W 356,15 W 420e52 W 491.06 W 568.04 W 653,21 W 749,02 W 853,88 W 960e14 W 1067,19 W 1174,30 W 1280,76 W 1390,37 W 1500e82 W 1610,85 W 1719.61 W 1827e75 · ARCO KUPARUK A-2 GYROSCOPIC SURVEY JOB NO 5556 HEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. 23 JULY 81 TRUE MEASURED VERTZCAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 4432 3700, 3600 732 4577 3800. 3700 777 4721 3900. 3800 821 4864 4000. 3900 864 5005 4100, 4000 905 5145 4200, 4100 945 5282 4300, 4200 982 5418 4400. 4300 1018 5553 4500, 4400 1053 5686 4600. 4500 1086 5818 4700, 4600 1118 5951 480.0, 4700 1151 6083 4900. 4800 1183 6215 5000. 4900 1215 6344 5100, 5000 1244 6473 5200, 5100 1272 6605 5300. 5200 1305 6740 5400. 5300 1340 6877 5500. 5400 1377 7017 5600. 5500 1416 7164 5700e 5600 1464 7315 5800. 5700 1515 7462 5900, 5800 1562 7605 6000. 5900 1605 7747 6100. 6000 1647 7885 6200, 6100 1685 8021 6300. 6200 1721 8156 6400, 6300 1756 8290 6500. 6400 1790 46 107,43 45 120,96 44 131,76 43 142.04 41 151.33 40 158.69 37 165,42 36 169e51 I 35 172.63 32 177e03 177.64 33 171e70 35 166.28 37 39 150.87 48 137.02 51 118.14 43 68,80 42 41.48 38 17.53 36 2,99 35 24,38 1933.71 W 2037.70 W 2140.51W 2241.91 W 2341.58 W 2439.02 W 2532.68 W 2624.48 W 2714e49 W 2802e58 W 2889.18 W '2976.43 W 3063e03 W 3148.79 W 3230.38 W 3311.56 W 3397.76 W 3488.56 W 3581.79 W 3679.09 W 3786.17 W 3897.66 W 4002.84 W 4101.88 W 4198.43 W 4291e04 W 4380.59 W 4468.15 W 4555.34 W ARCo KUPARUK A-2 SURVEY JOB NO 5556 INTERPOLATED VALUES FOR EVEN [000 FEET OF MEASURED DEPTH, TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL COORDINATES 1000 999, 899, O.2Z N 2000 Z950. Z850* 9,38 N 3000 2?29, 2629. Z0.39 $ ~000 3~06. 3306. 73,07 5 5000 4095, 3995. 151,62 S 6000 4836. ~736, ~77,70 5 7000 5588, 5~88. 15~.73 5 8000 6284e 6Z84. 0e39 N 0,84 W 268,06 W 885.16 W 1618,24 W 2338.00 W 3008.57 W 3667.05 W 4366,76 W 23 JULY Check Form for timely ccm]pliance witJ~ our r-cx~ulations. 'Operator, We~I ~'.,~o and Number Reports and Materials to be received by: Date Completion Rcport Wel 1 History Samples Mud Core Chips Core Description Required Yes Yes Registered Survey Plat Date Received Remarks Inclination S urffey Drill Stem Test Reports Production Test Reports · Logs Run Digitized Log Data Yes NORTH SLOPE ENGINEERIHG DATE' J. J. Pav.,elek/Ann Simonsen Transmitted herewith are the following' PLEASE NOTE:~?-BLUELINE, Z~- SEPIA, F - FILM, T - TAPE ATTN' ANN SiMONSEN - AFA/311 P.O. BOX 36O ANCHORAGE, AK 99510 DATE' RECEIVED JUL 20 1981 Anchcm~e HOy le ~. Chairman ALASKA OIL AND GAS CONSERVATION COMMISSION Hamilton~ Thru: Lonnie C. Smith Commissioner June 23, 1981 Harold R. ~awkins Petroleum Inspector Witness B.O.P.E. Test on ARCO's Kuparuk Well #A-2 Sec. 6, T11N, R10E, UM Permit #81-71. ...J.un.e.19,. !98~1: I left Anchorage at 6:05 PM, to Prudhoe Bay by wien Airlines, arriving in Prudhoe at 8:40 PM and arriving at Arco's drill site, Kuparuk A-2 at 9:30 PM. The B.O.P.E. test started at 10:00 PM June 20, 1981~ I finished witneSSing the B.O.P.E. test at 1:30 A~:~,' ~T~ere~was one failure, the blind rams, they were changed out and tested to 3000 p.s.i.g. I filled out an A.O.G.C.C. report (attached). In ~mmary, I witnessed the B.O.P.E. test on Arco's Kuparuk well No. A-2. The B.O.P.E. test's were satisfactory. 4/81' ~' STATE OF ALAS}(A ALASKA OIL~l& CAS CON,qERVKrlON CCN~tlSSIO B.O.P.E. Inspection Report ~Inspector Date Wel 1 Operator ~ .~ /~C'O Well /~.. - 2., Location: Sec _~ T~//], a/~,M Dril linq Contractor ,./~J~,~J Representative Permit # ~ / /~ ,~-Casing Set Rig # ?,~ Representative location, -General ~ ~', Well Sign Ceneral Housekeeping .... Reserve pit ___ BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves. H.C.R. Valve -- Kill Line Valves Check Valve Test Pressure ACCUMULATOR SYSTEM Full Charge Pressure 2~~''~ Pressure After Closuring9 ~ Pump incr. clos. pres. 200 psig __ psi9 psi9 sec. Full Charge Pressure Attained: ;/ min.ff~sec. Controls: ~ster -~_/~ l~.~_e___~_~f B 1 i~ n.d s_ .sA4__i _t_ _d3.__g_o. _v_e ~~__ Kelly and Floor Safety Valves - Upper Ke 1 ly. Lo~r Kelly. Ball Type_ Ins ide BOP Choke Manifold No. Valves NO. flanges, ~dj ustable Chokes. Hydrauically operated choke Test Pressure Test Pres sure Test Pressure Test Pres sure .... Test Pressure _319 ~ 6) Test Results: Failures ..... ~_/--' X"-- Test Time~hrs[-~ Repair or Replacement of failed equipment to be made within,, days and Inspector/Ccmmission office notified. Distribution' orig. - A,O,&CCC cc - Operator cc - Supervisor Mmy 29, 1981 Mr. P. A. VanDusen District Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Kuparuk 25647 A-?- ARCO Alaska, Inc. Permit No. 81-71 Sur. Loc.~ 1259'FSL, 313'FWL, Sec 5, TllN, R10E, UM. Bottomhole Loc.: 1331'FSL, 508'FWL, Sec 6, TllN, R10E, UM. Dear Mr. VanDusen: Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A directional survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to con%mencing operations you may be contacted by the Habitat coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen Kuparuk 25647 A-2 -2- May 29, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a wi the s s pre sent, Ve~.ry truly yo3Ars, , , ,th Commistioner of ~Y ORDER OF THE CONIMISSION _ Alaska Oil & Gas Conservation Commission Enclosure ccz Department of Fish & Game, Habitat Section w/o eno1.. Department of Environmental Conservation w/o/eno1. ARCO Alaska, Inc.~r Post Office B~.. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 26, 1981 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Kuparuk A-2 Dear Sir: Enclosed please find the following: 1. The Application for Permit to Drill Kuparuk A-2 and a $100.00 check for the application fee. 2. A diagram showing the proposed horizontal and vertical projections of the wellbore. 3. An as-built drawing of "A" pad indicating the proposed surface location. 4. A proximity map indicating the relative locations of Kuparuk wells A-1 and A-2. 5. A diagram and description of the surface hole diverter sys tern. 6. A diagram and description of the BOP equipment. In addition, please note that this well is subject to letters of Non-Objection from BP Alaska Exploration Inc. and Sohio Alaska Petroleum Company. These letters should be on file with your office. Please contact me at 263-4270 if your records indicate otherwise. Si ncerel y yours, P. A. VanDusen District Drilling Engineer PAV/DSS:sp Enclosures RECEIVED Alaska 0ti & Gas Cons Co~ej~i~ ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany . .... STATE OF ALASKA ALASKA ( _ AND GAS CONSERVATION MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL I-~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL IXI SlNGLEZONE ~1 DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, AK 99510 I;l !:: ~' I:: ! ,VE D 4. Location of well at surface '' '- '~ '" 9. Unit or lease name ' ' 1259'FSL, 313'FWL, Sec 5, TllN, R10E, UM Kuparuk 25647 At top of proposed producing intervalMAY2 7 ]98] lO. Well number -. 1320'FSL, 1320'FWL, Sec 6, TllN, R10E, UM A-2 At total depth Alaska 0il & Gas Cons. C0mrr l~l~Oj~ield and pool ' ' ' 1331'FSL, 508'FWL, Sec 6, TllN, RIOE, UN Anchorage -Pr'_'dhoe ~y 14~7~r~l 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. Kuparuk ~iver 0i 1 Pool 61'GL, 66' Pad, 100' RKB ADL 25647 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/ornumber Fed [ns Co 8088-2627 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi NW of Deadhorse miles (at TD) 508 feet well (at surf) 120 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 8628'MD/6802' TVD feet 2560 6/4/81 , 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures ;"~3~,~ Psig@ OU"I' SurfaCe KICK OFF POINT 928feet. MAXIMUM HOLE ANGLE45 o (see 20 AAC 25.035 (c) (2) 3105 psig@ 5990 ft. TD (TVD) 21 " Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF cEMENT'. Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) ' 24" 16" 65# 'H-40 ~lelded 80' Pad I Pad 114 11114 + 200 ft3 ' ' 13-3/,~ 10-3/l 45 5# K-55 BT&C 2990' Pad ~ Pad 3024 2700 + 3300 ft3 8-3/4 7" 26# K-55 BT&C 8594' Pad , Pad 8628 6802 700 sx Class G I I ' I ~ I 22. Describe proposed program: ARCO Alaska, Thc. proposes ,co drill a Prudhoe Ba~v Kuparuk River 0il Pool development well 'co approxima'cel~v 8628'MD,.6802'TVD. Selec'ced in'carrels will be logged A 20" x'2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8" 5000 psi RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig' Expected maximum surface pressure will be 2583 psig.* The well will be completed with 3½" 9.3# J-55 buttress tubing. Non-freezing fluids will be left on uncemented annuli thru .the permafrost interval. Selected intervals will be perforated within the Kuparuk formation an. reported on subsequent reports. A'downhole safety valve will be installed and tested upon conclusion of job. *Based on cooling of gas bubble rising at constant volume. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge '. The space'below for Commission use CONDITIONS OF APPROVAL i Samples required Mud log required Directional Survey required APl number r-lYES [~NO []YES [~O I~YES i--INO 50- o~1--~' ~ 'Z.~ ~-c~ 9' Permit number .... Approval da~ ~') ""~/~-- ~31r~/2J~/9/1 I SEE cOVER LETTER FOR OTHER REQUIREMENTS · ... APPROVED BY _ ,COMMISSIONER DATE Nay 2.9, 1981 V ....... ~'~ ~ by order of the Commission ' ' Form 10~,01 Rev. 7-1-80 Submit in triplicate ~'' ~ ~----~' ~,-----~, '' ~''' ' ' : l'''' .... : :, ~-,,~---~ , ...... :' - ~ ....... t'~'? ....~ ......;-; .... ~ .... ,'~'~"~ ...... ,' ~'~ ..... RRC~ RLRSKR, INC. ': i .... .": · '"~ ' ~ " .: , ~ Ii X t..,- ! l.: ~,.,.I.,.~. · ~ .... PRD R, NELL NO: 2 PROPOSED .. ;' ..... , ~..~. :.. . : ~:. SCRLE 1 IN. ,= 1000 FEET .; KUPRRUK FIELD, NORTH SLOPE, R ........ ~ ................ ~ LRSKR,.. .~:.;.,:~. ...... ~ ~ ..... ~.l.,.,:,j..~;..;..i...;~ ~ ........... ,.~... ERSTMRN WHIPSTOCK, INC.' ~ ~'; ;);;~. }!: ~ ..... ~, ~ ;; ~;.l'~;~.~I:~;~;; . ~'' .... ] .... ~ -. ~ ~ . ,, .... ...: .. ..... ~, .. ,. ,.. : . ) .... : .I ;'!(~;;,~.., ~, '.. :. .~ ; ~ ~,, ~ ~ , ~ .. , ,.. , ) ...... , . . ; , · ' ~ '. ' ~,;;.~i': i . , ~ ' ,~ O SURFRCE ~ .... ~ ~ ...... ~ , ~ , N 89 DEB t t ~IN ' 4273 FT (TO ;TRRGE~) < ~ , , , ~ .... :..~ ;..: ... ' ' ' . , .... '~: ) ~'"' ~ :~ .... ~'~ ~000' i ~O00 ~ 1000 " ' 1000 KOP TVD=9~8 TMD=9~8 DEP=O . ~ . .~... I000 5000 ' ~OOD ' m ' ' "" 'i "' ,'". ~ ~-::J-" 18 BRSE PERHRFROST TVD=1~O T~1573 DEP=~08 ..... ~ · : 1 ' " ~ 3980 FT " ' .' T q " ~ ..... . . I3al FTc;:: DEP=4278 ~ '. ' ' "'' i ..: ' ~ ..... "":'" NORTH el ' TOP ~. SRK SRNDS TVD=3~40 T~=37~ DEP=152~ ~ . . G 5 ' ".:.:WEST 4273 ' '' '~'L; _~.~. ? K-t2' TVD=~40:T~=4213 D~=t822 ,. I ...... : .... ! - t , --: ~ ~ . . ~ . . , i ; . , i' .~ i [ ' ~ ......... ' ..... ] " ' 'i- ~ ....... ~ i' i .~: .. .i..:_..~: : i ........ ":i'~ ' t ~ } ' '~ i ~.,~ ~ , ",.. i ~" i { , RVERRGE RNGLE~.'' ; ...... }+: ~ ''- ..... , . , '"' ........ [ , ' '~ ..... ""[ ;.'. ) ~.;:.{ ?. 'L,...L/..;.;_' - , . ~ "~'' t I .... I 2000 9000 4000 _ 5000 _ 6000 _ 7000 .., I I I 1000 2000 3000 4000 : VERTICRL SECTION 0 'SURFACE 313 FT i,---i., K-5 TV0=5880 TH0="/523 OEP=4163. ~ , · . I ; TRRGET CTOP KUP SRNOS)~ TVD=5990 TH0=7679 DEP=4279 l~ LOWER ~NDS TVO=6180 T!10.7947 0~.4464 ~SE KUP SRNBS T~=6~O THD=SI03 DEPm4~4 ', ID TVD : ' '8 '.DEP =' 5086 I 5000 . I , l , , I I ' 1259 FT' , 1 l' ' , .I RRCO RLRSKR, INC. PAD R, HELL NO: I PROPOSEB KUPRRUK FIELB, NORTH SLOPE, RLRSKR ERSTHRN WHIPSTOCK. INC. 50O 40O 400 300 200 I 5CRLE 1 -IN. = 100 FT. NORTH 100 0 100 200 300 I I I I I _.- 2004 ......... .......... ~ ................. '... ~.~'_ii ...'.'.;' ~ .'"i ;i. i"iL.LU'~ ..... ~ ................................. : .......... ; ..... : ......... ? ............ ~ ....... . . ........................... : ........................ · .............. ~ ................... ~:!LL~Z._.;..L.::L".'.~ ' --. ................. "' . .. '...' ". ,, .-..-' . ...... ,.,,...~,-....~..,:...~_~..~,...,.~_~ ......... ~..;.,~ -,--.-~.~ ...... .-.~.,.~ .............. ? .......... . - ------"~;-- ...................................... i- ............ i ........... .-:. ....................... ~ ............. ~ ............................. , ............ ~ ........................... i ........... ~ .- ~.'.~ =_--':",._.......'".,.'._.',..~"',.'- _- ----.. --- ..... _'.:-"~ ...... ~ .'_:'0 ............... ~' ...... ~' ....... ~"---? ...... "' ............ ~ ......... ~-i .......... ~ ........... : ....... .' ' ....... i -, ~ - ~':! ~i.~_!__~.~ ....... 'i'';'I''''~ -i~.ii~i_.__ ~.~ 'l "! ..... .......... ' ~ ; ................... I-'T' r'"?-'"-'{-T-'-~'"~"T'"'-~'-;"~- ! ' ~ ' I ....... .......... ~ ............ ~ ' ' ..... f';'~!"~f'"? ............ x ~' ~ ...... ~"~ ...... ............... '~"'¥ ...... ~"~-' ' .......... ................ :..L'?'.:~' :.-.: .L";: ~' :'..'::.;.~-..'~:"'_;'.:'.TL:ZF_;Z:?.:'L'_~::~_:~;£;.-.;'_;[: ~ :!' ! '~;::'"L-'::~.;.;~';E;.:.-.:!.:'~.'!":':' ?;: ':~':"'~ ........... :" !"'-:'"':'"~.S': ......... :-i :' ........... . ....-. ~..., ..~..........--....: ~ ._~ ... -.: ...... : ...................... "'~"'~-- Y" .... ',.": ......... f' t' :' ........ :' ~'-'~'"'~'~'"'~"?"~"~ ~ ..... ..... ~ ...... ~'-' ~"f ........ ~ '" ~ ....~' '~ -! - .'." ........ ; ....... ; .... , : ' .... ~.-'. - ~, .......... : ,-~ ........ ' -,~ .............. :., ............ ~-: .......... ~- .............. ~ .......... ; ~. .... ; ...... ~....~,...~...~ ......... ; ....... ~. ....i.._ .~; _; , -'. ........ ~...: ..... ~-..--;.. ;'. ..... ;...! '- ..... ! ..... :.. ':. ......... : . ....? ..... i'-...'~;... i . ": :' ::': .......... .":.-..-".-':"::-:":"::~-.~,---~..~._~..S~,_,O0~" '~' '~ ........... : ' ' ....... ? '~"-'T-'. ...... i' -': .................... -" ......... : .... r ...................! ................... ; ............. ~--- -,' ......... .-~ ....... ;-- -~- ..... ........... '~ ....................................... i ........ ~ ...... ' ......... '~' ........... ? ................... !(ti ..... : "; .... ~ ......... i- ........... -~ .~ ..... ~ ....... ,- .......... ~.,~ ..... ~ . - ........ T--.---~ ........... ' .......... ' ~ - -' ....................................... 1~ ......................... i .......... ; ......... ~ ....... : ......... ., ........ · ...................................... · .... ~.. ~ + .......... . "':-s:?'~"'"','!'~.'::~':-:'?'!':!'~:,ii':'; -..' !...' · --'-~':'-~ ................... . ......... ~ ............ ~'i.-'-~':'. i ............................................................. ~, ....... ~- ~ .......................... ; ........... ~ ......... ~ .............. ~-- ' ..... :- ....." i '- ' ~,-,- - ...... .J ..... : ....... ~ .. ......... ~ ........................~, ................. ~ ......... ~, .......... ' ............. .'. ............ ~ ........ ~' i-.'_~: '. .................. '" .. ..... ? -' ........... ,. ~ .......... -' ........... ~ ......... ~ .i,. ' ~. ......... ;, ........... ~ .: .~... ;.--: .~ ......... - . ..... ~.-.~ ..... ~ .... ~-~_~ ............ ~. .... .:__~LLLLLZ_.S ............................ ~ .............. ~ ........................... ~ ............ .:...._L. .; .... .j, ........ .;. ~..~ ...... ~._.._, ......... f. ~--. i.i ..... : ...... : ~. ...... .-'. ..... ~ ......... ~ ....... ': .... :'" .'"' ..... .'..::::-~i:'.~' ........ '. ............................ ~ --,.:-~ .... : } ..... ; ........ '..:. ~ .;.:.: ; .; : ; ~ ......... J L..: :...i ~ ..... ........ · ' ' _..~ .... =--..300 ........... :' ............. ...... - .......... "': ........ ':' :.:: ..... ~ ...... '~'~'":"'""; ........ " ............ I4ELL NO~ ~ ~ PROPOSED 'ONLY ......................... L;~;.;'.~".... ::; ...... :.. ........... '~ .................................................... '" .............. ," ................. - - ......... ; ................................. ~ .................................. i,..' ..".[', .ii i'. ',: .i :. '.i_~.-. ................. "~-": i..~i'~',i'.-/ i ' ' '"='=~'"'~":'"-~' ="~'":'~'":-'"'?~ ~:'?~ '"""'=~'~'~'~~ ~ ~ .......................... i ......... ~-'~~-~ ...... ~-'~ ..... ~' ........ '~ ........... ' .......................... : ........................ ~" ~ ........ " ' _:.--... .. -: ;'-. i:: - :"i:-'; i" "': i'-"!':-'-:: ...... .... ' ' : ....... ~ "': ..... : ; ..... :' ..... ? ....... ~ .... . ~ '" i ' . ~ ................. ·.. . ' ....... ? ............ '~ .............. ? .... '--~'-,', .......... ,"' ....... :' :--' ........ ;---:'- ....... ," ....i ............... ~ ....... ~ ....... ~. , ~:-; ......... ~ '-' ' '?':?'" :? ..... "- '-:-'::"::? ............ ':"-" . ................ ~ ....... ;......~..~.; ............................. ! ....................... ~ .... ? ..... ~. ............. ! ................. .:...._:.. . 1 WELL A1 Y = 5,97l,a67.25 I ~ X = 540 ,'1 78.17 ' LAT = 7~°19'58.741'r > < , LONG =_ 149°40'26.679'' · WELL A2 ~Y = .5,971,34'6.82 , ~14' ' AI~ , X = 540,178.32 ~ . , ....... djr i I LAT = 70°19' 57. 557'l ' ~l LONG = 149°40'26. 693II > < I--I~' " J -- WELL A3 Y = 5 971 227 31 ~I%~ AZ.~ ,~ I X = '540,'178.'51 ~ , ~ ~ LAT = 70°19'56.381'' ' ~ LONG = 149°40' 26. 707'' , ~l~l AA~ ~ WELL A4' Y = 5,971,\106-83 > '~j x = 54o 178 52 --_ LAT · 7OO19'55.196" ~2.' A~r®~ LONG .? 149o40' 26.72 5" ~ ~ WELL A5 Y':~': 5,970,986.86 ~ ~ ~ X = ~'40,178.61 i ~ ,ii ~;11' A~® LAT = 70°19'54.016'' > · LONG = 1 49°40'26.741'' ~ ~ ~10' A~, ~ WELL A6 Y = 5,970,866,70 ~ ® . ,; X = 540,178.71 I LAT = 70°19'52 834" ~ ~ ~ I LONG =' 149°40'26.757'' I~_. S .............. ~ "' " WELL A7 Y = 5,970,746.73 I X = 540,178.55 "-'.-' !~, ~ _~ ^ LAT = 7OO19'51 .654' ~ ~O-/~ At~ "~ ,WE~T LONG = 149o40'26.781'' --r----- · ~ ~ ~' z~.,~¢'l~. WELL A8 Y = 5,970,626.78 ~ I X : 540,178.59 I i LAT = 70o19'50.47'5'' i~, ?t_~,~ I LO~IG = 149°40'26.798'' i I~ ~o0' I' I - ~. ,.'...~ .~-,,. I HEREBY CERTIFY THAT ! AM .,,.~'-?.-...- . ..'%f,.,,, PROPERLY REGISTERED AND LICENSED :'.? '.-c: TO PRACTICE LAND SURVEYING IN · :'~. · " THE STATE OF ALASKA AND THAT :' BUILT SURVEY MADE BY ME, AND ,'~'"'(/' "' ' '~i.,?,.['.'~.';,' ,.. ~-THAT ALL DIMENSIONS AND OTHER MAY2? 1981.. .L. 7-.~ ..-'.-[ . DETAILS ARE CORRECT, .AS OF' · .... ." .. )/.:. 'Al~skaOii & Gas Cons. Commissio, .--,:.,:,,, .,..: , ... Anchorage ~' --" i i i ii ! i .. l~lb~ ~lT~- A~ W~'~L~ I-~ DOOA'1'ION. A~-t~bllbT~ · · .. , ,. i ii I AtlanticRichfieldCompany ~ DATE: DRAWING .No: -. NORTH AMERICAN PRODUCING DIVISION IO-~Z.~o ' '-::'::-.-, ..c~:;'': ALASKA DISTRICT--- KUPARUK,. "- .... "~"'~'~>' ' "" 1. 16" 2. 16:' x 20" 2:0C0 ~si dsubl~ s~-u'~-~ a~a's.--~r 3. 20" 2000 psi drilling spcsl ',.:/'3" side 4. lO" ball valves, hyrauiicaliy actuated, w/lO" lines to reserve pit. Valves Zo o~en autsmati- -cally upcn closur~ of ~nnuiar ~ .......... 5. 20" 2000 psi =-~',iar prevente- 6. 20" bell nipple. _,,? - -_ · · Maintenance & Operation ~-'. 1. Upon initial installation close annular 1 . p~eventer and verify that ball valves ! ':. ' have opened properly. · . I 2. Close annular preventer and blow air ~_ through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not shut in well -- under an~ circumstances. 16" Conductor RECEIVED MAY 2 7 1981 Alaska 0ii & Gas Cons. Commission Anchorage . · r L ,, 1 ,, 8 KJ-- [ ) P: r--- P,=: ,S ..... ) 7- C ) C. : : ,) BL:N~ .'- ... P ! PF_ R?--::'IS 1. 16" 3rad:nhead " 2 16 2 ad~t~ spool . 6. 13-~/B" ~0~ ~ d~ii~ng s~;~ w/c,,~,~e and 7. 13-''~" ~/o SOOO PSt pipe rams 8. 13-~/8" 5000 PSi blind rams 9. 13-~/8" 5000 ~Si annular . . ACCU:tULATO R ~ * ~ * *' ~,. ?,~,T':' TEST CHECK A,'-ID FILL ACCU:.:ULATOR ,R.~.SEF, VO.[~"TO,. ?ROPER LEVEL ',,IIT4' HYD.RAULIC FLUID. '- ASSURE THAT ACCU:iULATOR PRESSURE IS 2000 PSI WITH, 150O PSI DO:.S;STREAH OF THE REGULATOZ. OBSE?,VE Tii-1E. THEH CLOSE ALL UNITS SIF. ULTA:;E- OUSLY AND RECORD THE TIHE A~ID PRESSURE IHG AFTER ALL UHITS ARE CLOSED ;,)ITH CHAX,S:i;G pU:i~P OFF. RECORD 0~1 IADC REPORT. THE ACCEPTABLE LC~ER L1HIT IS 45 SECO:iDS CLOSI,",G TI~1E AI;D 1200 PSI REMAIHIi;G PRESSURE. - .-. 13-5/8" BOP STACK TEST FILL BOP STACK AHD MANIFOLD WITH ARCTIC DIESEL. CHECK THAT ALL HOLD DO',.LI SCRE'JS ARE FULLY TRACTED. PREDETE?J'IIHE DEPTH THAT TEST PLUG WILL SEAT A¢;D SEAT IN WELLHEAD. RU~( I~l LOCi( DO;;~; SCRE~S IN HEAD. CLOSE A,qHULAR PREVENTER A~;D CHOKES AND SYPASS VALVES 0~( HA:IIFOLD. '[EST ALL CCHPO~IE;ITS TO 250 PSI AND HOLD FOR .UTcS. 10 HI" ' INC,REASE PRESSURE TO 1800 PSI AND HOLD FOR lO HIRUTES. BLEED TO ZERO PSI. OPEN A[INULAR PREVEHTER AND CLOSE TOP SET OF PIPE ~'lS. IHCREASE PRESSURE TO 3000 PSI AHD HOLD FOR l0 I'lI HUTES. CLOSE VALVES DIRECTLY UPST,qE~'I OF CHO'4ES. BLEED DO;:~ISTREA:'I PRESSU?.E TO ZERO PSI TO TEST VALVES. TEST RF,'.IAIHI~;G U~ITESTED HA~;IFOLD VALVES. IF AHY, ~4ITH 3000 PSI UPSTRE&"I OF VALVE A~iD ZERO PS~ DO;¢;SIRE£~I. BLEED SYSTEH" TO ZERO PSI. OPEH TOP SET OF PIPE RA,'-IS AHD CLOSE BOTTC:'I SET OF PIPE RA~qS. lO. IHCZEASE PRESSURE TO 3000 PSI AmID HOLD FOR lO tIISUTES. BLEED TO ZERO PSI. ll. OPEH BOTT3;I SET OF PIPE RA"IS. BACK OFF RU~I- l~I;;O JOI;iT A~;D PULL OUT OF HOLE. CLOSE 5LI,",D R~;IS A~lO TEST TO 3030 PSI FOR lO BLEED IO'ZE~O PSI. 12. OPE:: GLI:;3 RAJ.IS ;,.':D RECOVER TEST PLUG. SU;-'.£ ;.:A;ilFC. LD A:,D LIE;ES ;,RE FULL CF Ar, CT:C DiESE. L ;,:;3 .ALL ',',:,L','ES AP.E SET [;; C2-,ILL;:;S POS[TIC:;. 13. lEST ST,.:;,].:'~?E VALVES TO .'.OCS PSI. 14. lE:T >;ELL': COC:,:S A:;D ::,S~.3£ -SC.:' TO ]CCD PSI ,. [ ::t ...... .-v .",, .,.: o 15. ?E.C~.]D TECT I:,FC.-':.."AT:'3'~ r,...~ ~Lr.;;SUT TE'T FC.:.:t <:G:i.. A:,3 ~'"'"'..:.,,-, TO [/~[LL::,.S VlS:.q. 16. ~E.-]FC.--.'I C:-':PLETE ~:2S TEST OS;CE A ',-~E( FU:;CTIC:;ALL'f CPEF. ATE -COPE F.~!L'/. · o -o. -, SOHIO ALASKA PETROLEUM COMPANY 100 PINE STREET, SAN FRANCISCO, CA 9411 1 October 17, 1980 ARCo Oil and Gas Company North Slope District P. O. Box 360 Anchorage, Alaska 99510 Attention: Mr. S. R. Jaime ~'LAND OCT 27 1980 NORTH A/_~SKA ARCo Oil and Gas Company, by letter of September 23, 1980, has requested a letter of non-objection by Sohio Alaska Petroleum to the drilling of the following development wells: Well No. Bottom Hole Location .E-6 B-3 A-1 .A-2 A-3 A-6 A-7 500' NSL, 2640' EWL, Sec. 16, TllN, R10E, UM 1320' NSL, 1320' EWL, Sec. 9, TllN, R10E, UM 1320' SNL, 1320' WEL, Sec. 6, TllN, R10E, UM 1320' NSL, 1320' EWL, Sec. 6, TllN, R10E, UM 1320' SNL, 1320' WEL, Sec. 5, TllN, R10E, UM 1320' NSL, 1320' EWL, Sec. 8, TllN, R10E, UM 1320' NSL, 1320' EWL, Sec. 7, TllN, R10E, UM Please be advised that Sohio Alaska Petroleum Company does not object to the drilling of the proposed wells. For your information consent to E-6 was previously forwarded by Sohio to ~he Conservation Commission at the request of P. A. Van Dusen of your office. Sohio's concurrence to the drilling of the listed wells is with the understanding that ARCo, Sohio and other affected working interest owners will proceed in good faith toward an equitable unitization of the Kupart~ Reservoir and that such unitization is achieved prior to the commencement of production from the wells. GJA:c cc: P. Hardwick, BPAE P. Rumley, Anchorage Yours very truly, BPAlaska Exploration Inc. 255 Cali[ornia S;,eet, San F'rancisco0Calilornia 94111. Telephone(4 tS} 445-9211 I'ETER HAI~DWK~K October 8, 1980 ARO0 Oil & Gas Co, any North Slope District P.O. Box Anchorage, Al,~ka 99510 Attention: 5~. S.R. Jaime Re' Letter of' Non-Objection ' Ar400 Oil '~nd ~ 'Le.~,~e ADL 25651 · C~nt ] emen: V,'e .~fer to your letter of 23 September 1.980, in ~vhich you ac%~ised us of your intention to dr~]l the £o]]owing deve]ot~nt E-~ ^-3 A-6 Hole ' Ir~:a.tion ~,~O'h,.L,~.q 2640' ~.%, ,~c. 16, 'fl]N, R]OE, UM c,.~ ~;~, 1320' E~, Sec. 9, ~IN, R1OE, ~2~O' NSL, 1320' ~%%, Sec. 6, TI]N, R1OE, ]"~T~' ~, ]320' %~, ,_et. 5, ......'~' "~:'~',,_,, ]220' ~%%~ Sec. ,,L'." '~. ,, ,....,,.,. ........ ~ affect, ed Le. ssee of Record, hereby cO,:T ~h~J; i"; ~ ??:t-"' L¢.m.~ ~o the. applic~t-~on .for Permi~ to ,~.:'!~..' (:~.' ~,.'.~:.~',n ' ';b- .-. w~':~.]s. ~lis I~.tter of Non-Ob~ection is, ;,i,':,~,-.-~.'-, v:,.- ;: '~'; +.o'~ k -:-:'c~m'.wP. nnding that Limoly and bonafide r~%x~res to ~haic-ze the Kup~ ,-.- ;~r~rvo4r in a fair [md c~4uit-able nmmcer ara . adopted by the p,mrti,:'? ilvolvec], .~ch that said parties ma), a£,~ree upon the terms of such unitization and 'their rcsI~ctive rights and obli~,~ations therein, prior to the czm~e, nc~nt of any producution from the Kuparuk Res~rvoir. Yours very truly, c~:: }.ir. G. Abrnh,~m, Sohio, An~llura~* LIST FOR NEW WELL PE~LITS Lease & Well No. ITEM APPROVE DATE (2) Loc /2~2~~- 8)"f'-"~7'?f 1. Is the ~ermit fee attached .......................................... 2. Is ~11 to be located in a dafined pool ............................. ( 3. Is ~11 located proper distance from property line .................. 4. Is ~11 located proper distance from other ~lls .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is ~11 to be daviated and is ~11 bore plat included ............... 7. Is oparator the only affected party ................................. 8. (3) ~dmin 9. ( ) 10. 11. ~/('12 thru 20) 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO --~'21 thru 24) Is conductor string provided ....................................... Is enough cement used to circulate on conductor and surface ........ Will cement tie in surface and intermediate or production strings .. Will cement co~r all known productive horizons .................... Will surface casing protect fresh ~ater zones ...................... Will all casing give adequate safety in collapse, tension and burst. Can permit be approved before ten-day %ait .......................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... / ~, , Is administrative approval needed ................................... ,, Is this ~11 to be kicked off from an existing ~llbore ............. __ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate ~11 bore separation proposed ........................... Is a di~rter system required ....................................... ~ ... Are necessary diagrams of diverter and BOP Oquipment attached ....... Does BOPE have sufficient pressure rating - Test to _~oc-~ psig .. Does the choke manifold comply w/API RP-53 (Feb. 78) .................. RENARKS Additional requiremants ............................................. Additional R~marks: C~olo$y~: Engine, ring: HWK , ~ LCS ~:/'~'~B~'W ~ my: 03/10/81 INITIAL CLASS STATUS UNIT ON/OFF SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process · but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. .o I I I I I I I I I I I I I I I I I I I e e UIU (8/- 071 Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. February 12, 2006 7048 1 3.5" 9.3 lb. J-55 EUE 8RD AB-MOD Tubing Well: 1A-02 Field: Kuparuk State: Alaska API No.: 50-029-20599-00 Top Log Intvl1.: Surface Bot. Log IntvI1.: 7,764 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This log is tied into packer@ 7,474' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate the 3.5" tubing appears to range from good to poor condition. Wall penetrations from 20% to 53% are recorded throughout the tubing logged. The damage appears in the forms of general corrosion and scattered pitting, at times appearing in a line. No significant areas of cross- sectional wall loss or I.D. restrictions are recorded. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting Isolated Pitting Isolated Pitting Isolated Pitting Isolated Pitting ( 53%) ( 43%) ( 42%) ( 32%) ( 30%) Jt. Jt. Jt. Jt. Jt. 4 @ 101 @ 139 @ 110 @ 25 @ 152 Ft. (MD) 3,122 Ft. (MD) 4,251 Ft. (MD) 3,389 Ft. (MD) 791 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: MAXIMUM RECORDED ID RESTRICTIONS: No significant areas of cross-sectional wall loss (> 6%) are recorded. No significant I.D. restrictions are recorded. I Field Engineer: W McCrossan Analyst: M. Lawrence Witness: C. Fitzpatrick I PrucH10e PmD.ctive ~1hone: or Inc. P.O. 80'< Fa,,: 565-1369 Phone: 659-2307 TX Î7497 659-2314 FEB 2 4 2006 ~"i:.·'·; ":i'. I I I I We!!: Field: Company: Country: 1A-02 Kuparuk ConocoPhillips Alaska, Inc USA PDS Repo Overview Body Region Analysis Survey Date: rool rype: 1001 Sf7(": No. of Fingers: Febrllaryl2,2006 MFC 24 No. 040665 1.69 24 I Penetration ami Metal loss (% wail) I penetration metal loss body 250 I 200 150 100 I 50 o 10 to 20 to 40 to over 2{Yj'~ 40% 55°;;) 85% o to 1% 1 to 10% I I o = 255) 3 I Damage 100 I 80 60 40 I 20 n I lSo·!ate-d generJ.! !me nng hole / poss pitting COITOSJOn CO!TOS¡On corrOSion ¡ble Iwle I I I I I o o o pellPtration C li'v11 ClM 2 ClM 3 Cli'v\ 4 C 1.:',11 5 ClM 6 ClM 7 CLvl8 ClM 9 ClM!! Damage Profile (% wall) metal loss 50 100 Bottom of SlHvey = 250.1 Analysis Overview page 2 I Correlation of Recorded Damage to Borehole Profile I Pipe 1 3,5 in (24.0' - 7744.2') I I I I I I I CLivI 1 I I .... c CLM ') CLM '1 I CLM 4 C;Liv1 5 I CLM 6 CLM 7 I CLM 8 CLivI C) I CLMIO Inj, Mandrel I Well: Field: Company: Country: Survey Dale: ApPf()'\. 1001 Deviation 1A-02 Kuparuk ConocoPhillìps Alaska, Inc. USA February 12, 2006 Appro\.. Borehole Profile ~ ill ..0 E ::J Z 50 "'TII12ß I I I I I I I I 766 I I I I' Ir~7 -)-) ¡ I I I Bottom of Survev = 250.1 Damage Profile ('X) wall) I 1001 Deviation (degrees) I I 23!0 3069 o ::E .,.J 3827 ~ ..r: 1:1. ill o 4580 5343 6113 6885 7713 7744 100 I I I I I I I I I I I I I I I I I I I Pipe: Body Wall: Upset Wall: NominaIID.: loi ') ") .1) 34 i 35 I 36 i 37 44 45 46 PDS REPORT JOINT TABULATION SHEET 3.5 in 9.3 ppf EUE 8RD AB-MOD 0.254 in 0,254 in 2,992 in it Dp¡)th I I .1 1.1 1.2 1'1 2 ) 4 S 6 7 8 9 10 1 I 1 I 1 1 1 I I 2 2 22 23 24 !) 28 !) S7 0 6) 0 ]8 ¡) 81 . () 112 iI.llh mmi41 . ii 170 i!.!)h 201 !).!)~ ,:2.31 II()!, 26 !) i! 1 i! o i! i! I! !) II II II , II ( I! (,4. !) 674 II 705~ 0 !) !) 11') !J ) I! iI I! iI ;~ iI 1 i! 1 I! l' iI lH i! 11 i! 1169 I! 1~00 II !. 32 iI !. ~64 II 1293u_ iI 1325 I.! 1356 iI 1385 iI 1417 I.! II I :~;;~ , (Ins.) 0.01 0.04 (UB 0.06 0.01 0.07 0.04 0.1'{ 0.02 0.02 0.05 0.05 0.05 0.02 0.04 0,03 OJ)l 0.05 0.04 0.04 0.03 0.04 0.04 00'1 10.1)) I OJ)l 0.04 0.06 0.08 0,05 (WI IU)2 (1,01 )4 0, )7 0.05 0.06 0.04 O.lB 0.04 0.03 0.01 0.06 0.05 0.04 0.03 i I\'L \;)e)(11 Min. I 1.0. (Ins,) I I~ 10 '.1 .( '111 J) ') ! ) - Ii! 21! ...11 ¡) 14 JO I I') I') Iii II 11 iI· II Ii) h I" )"1 10 I() . ¡'. i, ( II I~ "I! 1:- 2n ) I _J I ! :- 11 I( I.: (¡ .21. In !,' II 2.97 2.(\' 2. 2. 2. 2 2 ! 1 , I I I , "I , I) · ; , ) .' , · · I · , , .' , , ) ) · ) , · ) ) , · · ; ) , , , · · I .' , I ) , ) ) 2 2 2.93 I }.9} 2,91 2 ( 2 ( 2 ( 2 ( 2.91 2.93 2.90 2.90 2()j" , 2.92 I 2.92 2.91 2,89 '2.'13 2.91 2.90 2.95 2.92 2.94 2.94 2,94 2.91 2.93 2,91 2.94 2.94 2.93 2.94 2,95 2.97 2,97 2.94 2.91 291 2.94 2.94 Well: Field: Company: Country: Survey Date: 'J PUP ~111c;\:';· ;>( P ::>1 p Isolatpd Ditting, ::>( ::> so ated nittinQ. Lt ,hi Ik)\' pitting, o ate! Ditting. itt !Ilg 11 upset ilt !ng 11 II set iJilllowD ng, solated D I1Q. solated D 1HZ. Shallow pitting. Shallow nitting. Shallow pitting Shl1110w nittinQ .. Shallow pitting. Shallow oittill&r. Shallow nittinQ .. . _.~.~ lAD2 Kuparuk ConocoPhillips Alaska, Inc. USA February 12, 2006 Comments Lt Damage Profile (%wall) o 50 100 I I I II _ .,. .m,~ I I ! I ,..=='= I I . ~---=I Shallow pittiOK,JJ. Deposits, , "~_'m ISOIIHPc! oittil1R.... Isolated n IHI. Shallow n tt 111l. Isolatpd n ()g:. Isolatpd n tt I1Q. Isolated nittil1Q. Shallow DittinQ. Sh,~lIow nittinll Isolated nilt !1Q. Shallow nilt I1Q. Shallow Ditt nil. Shallow Ditt nQ. Page 1 ~m^^ I I I . I ~ II I!I I" ; rr r'f Body Metal Loss Body I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: NominaII.D.: 3,5 in 9.3 ppf FUF 8RD AB-MOD 0,254 in 0.254 in 2,992 in 1A-02 Kuparuk ConocoPhillips Alaska, Inc. USA February 12, 2006 Well: Field: Company: Country: Survey Date: loint jt. Depth I Pen Pen. Pc: \/¡elal Mill. I Damage Profile No. (Ft.) II I Body ID Comments (%,wall) (IllS.) (IllS.) '0 50 100 47 I 1448 I I) 0.05 Iß ) I 2.93 Shallow nittinQ. stl I I r---48 ~.-+ 1478 I jJ 0,05 19 I J 291 Sh.\llow nittinQ. -II 1--49 : 1507 I () 0.04 I- I , 2,91 Shallow I)lt1.ng. III : I , () I) , 2()1 , 50 1537 CUB 5! 1567 () OJ)4 IS ) 2e)1 "12 1595 () 0.05 21 .' 2.95 sr) ! 1627 () , 0,04 ì" ) 291 ~t···· 1658 () 0.04 III ) 2,93 Shallow nittinQ. I 111I1 , I I I _J639 II fL04 17 I 2 2.95 Shallow nittilw. I , I 56 1720 ! () 0.02 7 ! 2.93 I I I I , () 6 ) -2.91 ' I I , 57 1750 0.02 I , "58 -1780 II 0.02 ß I 2.92 I I I 58.1 1812 n 0 0 Ii 2.81 SSSV I I 59 1824 {) 0.04 I ') ) 2.90 [t. I , 60 ](355 I 0 I 0.05 I ìß ) 2.92 I 61 1886 0 0.04 14 , 2. 'I ha ow nittillQ. I 62 1917 II 0.04 17 ) 2. '2 11a ow pittillg. I 63 1948 II 0.04 16 J 2. '2 11<1 ow nittillQ. I 64 1980 0 0.02 9 J 2. I) I 65 2011 0 0.02 6 I 2. '6 66 2043 0.02 7 ) 2.90 I 67 {) 0.02 c¡ 2 2.92 -~.~~ I 2073 I i 68 2103 {) 0.02 - I 2.94 I _"_",~,""__~...'m.._..__.,... I 69 2134 II 0.03 II 4 2.90 Shallow nittilw. I I 70 2164 {) 0.02 " ) 2.92 71 2192 () 0.\)1 3 ) 2en I t IÎpnn"!I,, I 72 2222 {) 0.02 7 ) 2.94 I ~--H 2251 (I 0.f)1 \ ) 2.9! 2282 () 0.01 ), I 2.90 I 75 2310 0 0.01 'j ) 2.94 76 2342 () 0.02 )) 2 2.91 77 2372 Ii CUB 13 ) 2.95 Shallow nillin\!. I 1 78 2402 II 0.01 "1 ) 2.91 79 2432 II 4 ) ~.... .. ..-. --- 0.01 80 2462 II O.O! \ ) 3! 2491 Ii 0,02 9 : ) [1. r'bnn,;'" 32 2521 lill- 0.03 Iii : ( It pittillg in upset 33 2553 Ii 0.01 4 ) I 84 2583 Ii 0.02 II 4 Lt. 1- 'm"";tc 35 2613 \I 0.01 "1 2 [1. r'pnnc,tc 36 2642 II I 0.03 P ) I 2.89 Shallow nittil1Q, 37 2672 Ii I 001 "1 I 2.92 88 2703 0 0.01 "1 ) 2.93 Lt DeDosits. , 89 2733 I) \ ) ~,_.. .~,~.._".,.. .- ---.------- 0.01 2,92 I 90 2766 () O. ()7- 26 ) 2,92 I Isolated nittimI. ,I 91 2795 II 0.04 1 " 2 2,88 Shallow nittinQ. Lt. Deposits. I 92 2825 0 O.OL I I ) 2.88 Lt. DeQQ?its~. _____n_ 93 2855 U 0.02 7 ) 2.93 .-. 94 2385 U 0.02 ß ) 2.9) 95 29!5 U 0,02 ') I 2.94 I i Penetration Body Metal Loss Body Page 2 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal ID.: 3.5 in 9.3 ppf EUE 8RD AB-MOD 0.254 in 0,254 in 2,992 in 1A-02 Kuparuk ConocoPhillips Alaska, Inc, USA February 12, 2006 Well: Field: Company: Country: Survey Date: Joint It h Pen. Pen. \\et::1 Min. Damage Profile No. (Ft.) ,t 1 !.D. Comments (%,wall) (Ins.) (Ins.) 0 50 100 % 2945 ii 0.02 (! : 2.93 fill! I 97 2975 {) 0.04 5 j 2.88 Shallow niuinQ. fill! 98 3003 i! 0.02 7 4 2,93 C)C) , 3034 ii O.OJ 4 I 2.91 .. 99.! 3063 i! I()' I i! N/A CIMI II 'ltch (i¡) 12:00\ I 100 i069 i! I 0.031 i! "j 2.92 101 \098 i! CU'] I 43 j I 2.90 I Isolated niltil1Q. It. !)pnn"òt" tir i129 0 OJ)] (, ) 2,93 I I ., i! 0.01 4 ) --..-- ---~.- ) il C,j 2,90 -, I I I 3192 i! 0.01 4 ) 2.9! .-.- I I J( 3221 ii 0.01 (, ) 2.92 I I ]( 3251 U 9 I I "-,."..,,,.~ -~----- 0.02 ) 2.91 _~__ __"~._"m . ... . . - J( 3281 Ii 0,02 7 ) 2.92 0 I ) ~m''''_._._,~_____ 108 Bm OJ)] 2.89 I 109 i! )4 17 ) 2.89 Shallov~ nitÙ¡;Q I I ° 0 )8 \2 ) 2.90 Isolated Dittimz, )1 {) )1 ) 2.91 Ii )6 '4 I 2.92 Isolated Ditting I {) 0.02 2.90 I I i! 0.02 !) ) 7.92 I I 11 S Ii )7 :') ) 2,93 Isolated Ditting I 116 3553 {) )1 4 I 2.91 II 117 '~;;R Ii )1 'i 1 2.92 IIR i(,1 I) )1 4 I 2.92 "~._",,. I I 119 i(,4 Ii }4 F ) 2.92 ~i PO i(,7, i! 0.03 II ) 2.94 PI UO¡ i! 0,01 U I 2.92 1:n i! ° 02 7 : 2.93 _.m__ JZ:H2.__ I in 3767 Ii CWI : 2.92 124 i796 Ii 0.01 4 2.90 I PS m27 Ii 0.01 ) 2.90 Pitting. 126 ~57 {) CI11 ) 2.92 U. 127 3ii.I2Q._ ii 0 , 2.88 I 121'1 )t)! _"___"_"'~M" ".". , -. -- II {) O.O)m 4 ) Isolated nittillfLJ.t Deposits, , 129 {) ) )3 """ , mm__ I 1--\0 ii ) 38 lil ,) i )] H2 4( Ii , 4 )2 In 4( i! 9 ) 2 12 H4 4( {) 9 ..,,"_._-~- I I . 2.Q9 ns 41)1 {) 11 4 ) 2,91 I 13b 41 'd 0 Ii 10 ) ._2_.90 I I I H7 411'1 0 OJ)] 6 I ').93 ¡iF\ 4,)P 0 8 ) "" - --- 0,02 2.89 I 1i9 4')4) 0 0.11 42 2.90 Isolated Dittimz, I ' I 140 4:J7 Ii 0.01 (, ) I 2.87 I II I 141 4>'01 Ii 0.03 ) 2.89 Pitting, IIII 14') 21 ) ·1~~J<~t~dl;itting. __'m"""'" 111 4331 Ii 0.07 2.93 ¡4i 4 '>, (;~m Ii 0.01 5 ) 2.91 U_LllJ 144 4393 () 0.04 ) 2.91 Shallow Ditting. Lt. Body Metal Loss Body Page 3 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: Nominal LD.: 3.5 in 9.3 ppf EUE 8RD AB-MOD 0.254 in 0,254 in 2.992 in 1A-02 Kuparuk ConocoPhillips Alaska, Inc. USA February! 2, 2006 Well: Field: Company: Country: Survey Date: joint I Jt Depth I FH' Pen. 1"'11. 'vletll Min. ;)mIIlI!" Profile No. I (Fl.) II I I I.D. Comments (Ins.) (Ins.) 0 .50 100 145 441'i II 0.04 . ~~..~.~.......... ";1 -- 2,91 Shallow Ditting ~"'I I III 14'i1 44'i II 0 ~N7A C; L I\lLLlLiIJ(I¡(a}2;IQl ----- I 146 441, II 0.04 j(¡ I 2.91 .. ~11;)II{)vYJ)itting. "'I I II 147 44() II nQDl 4 I 2.89 I , I ' - ~~,~--------- 148 4'i1 Ii 0.03 W I: 2,90 t49 4'i4 II . 00? ,) ) 2,89 L I. Deº{)'iiJ:i,~ __mmm__________ t'iO 4'iRO II 004 ~ ) 2.88 Shallow nittil '" 1'it 46! 1 II 003 H ) 2,88 I SI¡alloY"'...J2Ltting. It Deposits. l'i) 4(4) II 0.01 h ) 2.88 I I. J2f:J2{)si ts. I n_ I 153 4671 II I 10 ) 2.90 I 154 4700 II ¡I I 2.92 155 4731 {) 4 ) 2,88 Shallow pitting TSG 4760 {) ( n, 2,91 It D"Dosits ~ I 1'i7 4791 {) 1. I 2.88 Isolated pitting It Deposits, I I 15R 4822 n , 4 2.86 159 4850 {) , ) 2.86 ..1. f)p"n~;k II" I t'i91 4R7R {) {I ,vA 3 latch «(I) 2 :30) I 160 4RWi {) 0 )2 '; ^.t f)pnn~ik 1(,1 4916 n 0 )) ( I " 162 4946 )1 0 P ( 4 16~{ 4976 II OO{ In 4 I 164 5007 n 002 II ; ~t. f1pnnç;k 165 5(n6 n (un 1; I Shallow nitting. It I 166 'i066 II Ofn 10 ) 167 5094 () O.Qj ') I _t f)pnncik 16R 51 \)5 (¡ 0.04 14 4 2.91 Shallow pitting, 169 5156 () 0.02 9 I )8 It Denosits, I 170 'i 1i1S~ 0 O.O! 4 ) 11 171 5)1') )1 0.03 I I )R Shallow pitting. It. II" 171.1 5246 () 0 0 fA :;1 \¡\ 4 II ,.trh @ 8:(0) In 'i255 () 0.05 ¡ I: n Isol Ited pitting, III 17:; 521)) II 0.04 ) 39 Sh;1 Ilow Lt I 174 5'1]) () 0 ; 2.82 It )pnncik 17.5 5:;4'{ () 0 ) 2.90 j )pnncik 176 5'{74 () O. 2. I 177 'i406 0 0 i t t f)"",''';k 17R 54:;5 )1 0 I 179 5465 il 0 I IRO .5494 0 0 ! ( I ;1111 10wD tting, It I lRl 55)4 il 0 i ;¡);¡ low D tting. 182 5~,,15~ iI 0.04 If¡ ) 2.92 ;ha IOWD tting. i83 55B5 () 002 9 ) 2.91 j i _LtJL1 5615 () Qn~ () () N/A ;LM 5 I _atch @ 4:30) tIt .-. is I _lB4 5622 il _.11.06 LZL Corrosion, Lt. DpPQ::;it:i.,__ lB5 56.54 --¡¡-- 0.01 S i _ 2.91 186 56122 iI 0.07 if¡ .~ 2.89 Isolated Ditting~_ ..~~ 187 5716 ii om II ) .:2,B8 Sllallow DittillR_lt,_I2f'JlQsits. lB8 5747 il ocn II 4 2.85 Shallow corIQ'?ion, 18') 5775 II 0.02 9 I 2.90 It Deposit::;,___ 190 5806 U 0.01 6 4 2.87 It. DeDositscn~.__ I Body Metal loss Body Page 4 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABU ON SH Pipe: Body Wall: Upset Wall: NominalLD,: 3.5 in 9.3 ppf EUE 8RD AB-MOD 0,254 in 0,254 in 2.992 in lA-02 Kuparuk ConocoPhillips Alaska, Inc. USA February 12, 2006 Well: Field: Company: Country: Survey Date: Joint I Jt Depth 1\'1 Pen. Pen !vle!:!1 Min. Damage Profile' No. (Ft) I ,( I ID Com men ts (%wall) I (Ins.) (Ins.) 0 50 100 ~~ M ~~...~___~.. ---------- ._._-----------.~--------- ____n________m____ ¡91 5836 II I 0.01 ) 2.1)1) .... M"__M ~ ... _w___. -- ---- M_____n____ ---- _____n____________________ H 192 5865 Ii ( 4 2.91 -- ---- __ __________n________ -------- 19) 513')4 )) ( )4 2.89 Isolated pittir¡g. Lt. Deposits. 194 5923 )) ( ß .t I I 195 59')) )) ( ß t Deposits. 195.1 ')91)') ii 0 \j 'I' CI M (, (I ateh @ 4:30) 1% 5990 !i iin 1 0.07 I 4 Lt. 197 6021 I ii 0.02 ì I I ì I 19R 6052 0 OJ)] \ I t.)pn(Kik I I I 199 4 I , 6(81) I 1'1 0.01 I 1 200 6113 Ii 0.01 i Lt. )p,\('\",I" 1 201 6143 Ii 0.03 I t. )pnn"lI" 202 6174 Ii 0.01 2.88 203 6 ') 0) , !i 0.02 2. 90 . _..___..___...MO 204 6n5 ii 0.11 2,89 I 205 6266 0 O. 15 In 4 2.R3 Line shallow corrosion. I 2051 6297 0 ( I '4f¡ GLM 7 (Latch Ci!) 8:(0) I I ..;2Q(' 6303 (} O. 13 12 2 .7 _t. n=n".·'''' I I 2M 6333 0 0.01 6 ) ~.8: 208 6363 0 0.01 3 ) .RI 209 6393 !i OJJ2 9 I, 2.8') i 210 6424 0 I 001 '; » 2.90 I 0 0,02 ~--- 9 i 2.90 )11 6452 212 6481 ii OJJl 6 I 2.R9 t. I")pnn"i¡" I I 213 6512 0 0.03 Iii , 2.91 214 6543 ii 0.02 9 4 2,92 215 6574 )) o.i1i 9 4 2,85 216 660.3 ii 0,02 7 i 2.90 217 6632 0 0.03 13 i Shallow 1 t. fbnn"it" ...... 2,86 217.1 6662 0 0 () () N/A eLM 8 (Latch @ HL\O\ 218 6671 0 0.03 I 2,85 L t DeDosits. ._MO_. __ __~__ _______________m_ 2!9 6703 0 OJ)! I 220 6734 ii 0,03 1 t. I=.v,,·'''· 221 6762 0 0.02 !i .t. lon".-"'- 222 6794 Ii 0.02 ." t. lon",';''- 223 6824 {) 0.02 7 224 6854 {) 0,01 6 I 225 6B85 0 (Un 10 I t. lJeposíts. I 226 6916 U 0.03 10 2.89 I i I 227 6945 0 IUB II 2.87 228 6973 {) 0.03 13 'I 2.87 I t. r)pnn"it" 229 7004 !i 0.01 '; I 2.86 Lt. DeDosits. 229.1 7032 {) 0 (1 !i N/A CLM 9 II ;]teh (Íl! 7:00) 230 7042 0 C).03 13 4 2,86 Shallow niHinQ. I t. fjpnn"ik 231 7072 0 001 J 4 2.86 ~.~ 232 7102 0 0.02 C) ) 2'91 I 233 7131 0 O.C)) 10 I 2.ß8 L t I")(~n()"it" 234 7162 !i IJ.(ìl 4 ; 2.90 235 7192 0 u 0.01 ; 2.87 236 7223 0 0.03 12 ) 2.85 Body Metal Loss Body Page 5 I I I I I I I I I I I I I PDS EPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf EUE 8RD AB-MOD 0,254 in 0,254 in 2,992 in Well: Field: Company: Country: Survey Date: lA-02 Kuparuk ConocoPhillips Alaska, Inc. USA February 12, 2006 J. It. Depth Pi', Pel 1\'11. ' MeLd I Min. rhnuGP Profile No. (Ft.) \ I I I.D. Comments (%wall) I (Ins.) (Ins.) ° .50 100 23ì 7253 () OJ)I ') 2 2.89 I 238 ì 4 f):) ... 0 0,05 iB 5 2.82 Shallow It. Deoosits. rllll1 ~- T312 Ii OJ)1 4 I 2.8ì I ~.....................- 0.03 11 I 2.89 Sh,¡lIow nittil1\l, II 240 T343 I i 241 ì3i:\ ifj······· 0.03 1\ '') 2.84 it. IS I I I I I 241.1 ì404 0 0 0 0 N/A GLMIO ILilIch (d) 9:30\ I , 242 ì412 Ii 0.02' B \ 2.88 11 I ~-- , 242.1 ì442 ¡) 0.01 5 I 2 2.93 PUP I I 24. .2 ì45t=L'i 0 ¡) ¡) 2,81 SRR I 24. .3 74ì 0 0 ¡) Ii 2.89 PACKER ~L3 ì484 ii 0.02 I) ) 2.90 Lt. [JE~!J.()2it? II I I I - - _m_ ~ 2 1 ì515 0 0 ¡) ¡) N/A eLM 11 (Latch @12:00) ì525 () 0,02 () I 2.91 II I 7554 , ii 13 10 ) 2.94 '')8 ii 6 ) 2.92 I ,I ¡) () I 2.90 A () 9 ) 2.84 .1. ,8 Ii B I 2.92 0 I ii () ) 2.90 2 .1 '4L ¡) 0 (i Ii 2.31 A VA BPL Ninnle & IT'I SLEtvE Body Metal Loss Body I I I I I I Page 6 .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. os s rt ns Well: Field: Company: Country: 1A-02 Kuparuk ConocoPhillips Alaska, Inc. USA Survey Date: Tool Type: Tool Size: No. of Fingers: February 12, 2006 MFC 24 r'..Jo. 040665 1.69 24 Tool speed = 56 NominallD = 2.992 Nominal OD = 3.500 Remaining wall area = 96 % Tool deviation 1 0 Finger 21 Penetration = 0,134 ins Isolated Pitting 0.13 ins = 53% Wall Penetration filCH SIDE UP Cross Sections page 1 .. .. .. .. .. .. .. .. .. .. .. .. .. .. - .. .. .. .. s ross S ns Well: Field: Company: Country: lA-02 Kuparuk ConocoPhillips Alaska, Inc. USA Survey Date: Tool Type: Tool Size: No. of Fingers: February 12, 2006 MFC 24 No. 040665 1.69 24 Cross Tool speed 52 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area 97 % Tool deviation 62 0 Finger 8 Penetration = 0.109 ins Isolated Pitting 0.11 ins = 43% Wall Penetration HIGH SIDE = UP Cross Sections page 2 .. .. .. I 1A-02 I sssv - I I I TUBING I I I I I I SBR ~---~~ (7447-7448, 00:3.500) I !D 2,813 2.813 I Pelf I ~.:..8§JG (7552-7577) 2.313 .J 2,750 I Perf I 3.250 I (7601-7626) 2.250 I Perf 2.992 (7652-7688) 2.992 Perf (nOO-n12) I I TUBING I ID:2.441) TUBING (n80-n82, 00:3.500, 10:2.992) I Pelf (7796-7850) I ~m~mmmmmmm~m~mmmm~mm~ 5I$ YAPE VERIFICATION LISTING LVP 009,H03 VERIFICATION LISTING PAGE ** RELb HEADER SERVICE NAME :SERVIC DATE :81/07/ 9 REEL ~AME :REE~ ID CONTINUATION PREVIOUS ~EEL COM~E~OTS :REEL COMMENTS ** TAPE HEADER ** SERVICE NAME :SERVIC DATE :81/07/ 9 ORIGIN :1070 TAPE NAME :61746 CONTImUATION # PREVIOUS TAPE : COMMENTS :TAPE COMMENTS EOF ** FILE HEADER FILE ~AME :SERVIC.O01 SERVICE NAME : VERSION DATE : MAXIMUM LENGTH : ~024 FILE TYPE : PREVIOUS FILE : ** INFORMATION RECORDS MNEM CONTENTS CN : AbCO ALASKA INC. WN : KUPARUK "A"'2 FN : KUPARUK RANG: ~0 E TOWN: 11N SECT: 5 COON: N. SLOPE STAT: ALASKA CTRY: U.S.A. MNE~ CONTENTS PRES: NE[)IT4F ** RECORD TYPE 047 ** ** RECORD TYPE 047 ** UNIT TYPE CATE SIZE CODE 000 000 016 065 000 000 014 065 000 000 008 065 000 000 004 065 000 000 004 065 000 000 001 065 000 000 008 065 000 000 006 065 000 000 006 065 UNIT TYPE CATE SIZE CODE 000 000 O07 065 LVP 009.H03 VERIFICATION LISTING PAGE 2 RECORD TYPE 047 ~ ~ COMMENTS ~ DATE LOGGED ~ 24-JUN-SI , BIT SIZE : 8.75 FLUID TYPE : DEXTRID POLYMER DENS. : !0.4 VI$C. : 4~ PH : 9.0 FLUID LOSS : 6.0 C3 RM ~ MEAS. TEMP. RMF ~ MEA$. TEMP. RMC ~ MEAS. TEMP. RM ~ BMT MATRIX : SANDSTONE RUN NO. : ONE 3.98 8 58 F 5.70 ~ 58 F 2.70 @ 58 F 1.795 ~ 140 F ~ DATA FORMAT RECORD ~ ENTRY 8LOCKS TYPE SIZE REPR CODE ENTRY 4 1 66 1 8 ~ 73 60 9 4 65 .lin 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API AP1 AP1 AP1 FILE SIZE PROCESS SAMPLE REPR 1D ORDER # LOG TYPE CLASS MOD NO. DEPT FT 0 0 0 0 0 4 SFLU lSD OHMM 0 0 0 0 0 4 ILM ISD OHMN 0 0 0 0 0 4 ILO ISD OHMM 0 12 46 0 0 4 SP ISO HV 0 ! 0 0 0 4 GR I~D GAPI 0 31 32 0 0 4 DT iSD US/F 0 52 32 0 0 4 RHOB ISM-- G/C3 0 35 1 0 0 4 NPHI iSM PU 0 ~$ 2 0 0 4 SGR ISM GAP! 0 0 0 0 0 4 CALl ISM IN 0 28 3 0 0 4 DRHO ISM G/C3 0 44 0 0 0 4 NRAT ISM 0 42 1 0 0 4 LEVEL CODE 0 I 68 0 ! 68 0 1 68 0 1 68 0 I 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 I 68 0 1 68 0 I 68 LVP 0~)9. HO3 VERIFICATION NCNb FCNL THOR POTA ORAN CGR ISN PU PPM GAPI ** DAT~ DEPT SP NPHI NRAT POTA DEPT SP NPHI NRAT POTA DEPT SP NPHi NRAT POTA DEPT SP NPHI NRAT POTA DEPT NPHI NRAT POTA DEPT SP NPHI NRAT POTA DEPT NPHI NRAT POTA DEPT SP NPHI 8213 -20 -999 -999 -999 8200 -20 -999 -999 -999 8100 -34 -999 -999 -999 8000 -34 -999 -999 -999 7900 -42 33 3 0 780O -58 9_7 2 0 7700 -58 2 0 7600 -86 29 .50O .234 .250 .250 .250 .000 .516 .250 .250 .250 .000 .719 .250 .250 .250 .000 .469 .250 .250 .250 .000 .250 .740 .047 .020 .000 .000 .637 .633 .016 .000 .125 .348 .902 .017 .000 .375 .932 SFLU SGR NCNb ORAN SFLU SGR NCNb URAN SFLO SGR NCNb URAN SFLU GR SGR NCNb URAN SFLO GR NCNb URAN SFLO GR SGR NCNb URAN GR SGR NCNb URAN SFLU GR SGR LISTING 0 34 92 0 0 0 34 93 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 3 9O -999 -999 -999 3 90 -999 -999 -999 96 -999 -999 -999 2 99 -999 -999 -999 5 8O 94 2480 2 12 66 6 2869 1 15 71 80 2554 0 151 43 .688 .250 .250 .250 .250 .688 .250 .250 .250 .250 .082 .500 .250 .250 .250 .592 .688 .250 .250 .250 .777 .000 .938 .000 .896 .516 .500 250 :000 .613 .008 .938 .063 .000 ,117 .375 .031 .688 IbM DT CALI FCNb CGR IbM DT CAbI FCNb CGR IbM DT CALI FCMb CGR IbM DT CALl FCNb CGR IbM DT CALl FCNb CGR IbM DT CALl FCNb CGR IbM DT CALI FCNb CGR IbM DT CALl 5O -999.250 -999.250 -999.250 3.217 97.750 -999.250 -999.250 -999.250 375 -999.250 -999.250 -999.250 2.379 106.000 -999.250 -999.250 -999.250 5,672 94.188 9.594 764.500 72.563 50 9.094 1053.000 59.000 13.453 89.750 9.375 838.000 70.750 106.875 75.563 9,086 IDD RHOB DRHO THOR RHOB DRHO THOR IbD RHOB DRHO THOR RHOB DRHO THOR RH00 DRHO THOR IUD RHOB DRHO THOR ILD RHOB DRHO THOR I~D RHOB DRHO PAGE 1 68 I 68 I 68 I 68 1 68 i 68 3 436 '9991250 -999 250 -999 250 3 436 : 999.250 -'999.250 25O 999. 50 .999.~50 2.338 -999.250 999 250 5: 45 377 O70 8.922 2.318 555 10.875 2.469 0.016 12.578 102.688 013 LV'P O09.H03 VERIFICATfON LISTING PAGE 4 NRAT 2.783 NCNb 2882.000 POTA 0.009 URAN 1.770 DEPT 7bO0.O00 SFEU 2.363 Sp -45.500 GR 98.500 NPHI 44.873 SGR 108,813 NRAT 3.701 NCN5 i776.000 POTA 0.029 ORAN 2.512 DEPT 7400.000 SFGU 2,277 ~H~ -;~:~o SG~ -~.~o NRAT -999. 250 NCNL -999. 250 ~OTA "999. 250 ORAN '999. 250 DEPT 7300,000 SFLU 3.000 SP -29.953 GR 129.250 NPHI -999.250 SGR -999.250 NRAT -999.250 NCNb -999.250 POTA -999.250 URAN -999.250 DEPT 7200,000 SFDu 3,717 Sp -33.188 GR 161.875 NPHi -999,250 SGR -999,250 NRAT -999,250 NCN~ -999,250 POTA -999.250 URAN -999.250 DEPT 7100.000 SFLU 4.012 Sp -40.219 GR 150.625 NPHI -999.250 SGR -999.250 NRAT -999.250 NCNL -999.250 POTA -999.250 URAN -999.250 DEPT 7000,000 SFLU 2.403 SP -31.172 GR 148.375 NPHI -999.250 SGR -999.250 NRAT -999.250 NCNL -999,250 POTa -999.250 URAN -999.250 DEPT 6900.000 SFLU 7,438 SP -29.266 GR 101.125 NPHI -999.250 SGR -999.250 NRAT -999.250 NCN5 -999.250 POTA -999.250 ORAN -999.250 DEPT 6800.000 SFLU 2,945 SP -29.969 GR 121.063 NPHI -999.250 SGR -999.250 NRAT -999.250 NCNL -999.250 POTA -999.250 URAN -999.250 DEPT t700.O00 SFLU 3.570 Sp -20.484 GR 130.500 NPHI -999.250 SGR -999.250 NRAT -999.250 NCNL -999.250 CGR IbM DT CALl FCNL DT CALl FCNL CGR DT CAbI FCNL CGR IbM DT CALI FCN5 CGR DT CALI FCN5 CGR DT CAbI CGR D~ CALI FCN5 CGR DT CAbI CGR DT CALI FCN5 953.000 37,344 2.002 113.188 10.000 442.000 91.875 2.420 114.750 -999.250 -999.250 -999.250 2.672 107.750 -999.250 -999,250 -999,250 3.035 108.375 -999.250 -999.250 -999.250 3.471 114.188 -999.250 -999.250 -999.250 2.227 110.375 -999.250 -999.250 -999.250 5.090 101 88 -999.250 -999.250 2.680 i0~,000 -99 .250 -999,250 -999,250 2.252 105.750 -999.250 -999.250 THOR IUD RHOB DRHO THOR ILD RHOB DRHO THOR R~OB THOR RHOB DRHO THOR ILD R~OB DRHO THOR RHO'B DRHO THOR RHOB DRHO THOR IbP RHOB DRHO THOR ILD RHOB DRHO THOR 7.559 1.982 2.316 0 030 11~641 2,398 '999,~50 '999. 50 '999,2~0 2 602 . '999,250 '999,250 '999.250 2:965 :~ 2~o 999'250 -999.250 250 -999.250 2,170 250 999.250 5 109 -999:250 99'.250 2,666 -999.250 -999,250 -999,250 2.096 -999 250 -999:250 -999,250 ~¥P' 009,H03 VERIFICATION 5ISTING POTA -999,250 URAN -999 DEPT 6600.000 SFbU SP -25.453 GR NPHI -999.250 SGR NRAT -999.250 NCNb POTA -999.250 ORAN 3 133 -999 '999 -999 DEPT bLO0,O00 SFbO SP -42.469 GR NPHI -999.250 SGR NRAT -999.250 NCNb POTA -999.250 ORAN 3 119 -999 '999 '999 DEPT 6400.000 SFLU SP -39.219 GR NPHI -999.250 SGR NRAT -999.250 NCNb POTA -999.250 URAN 4 172 -999 '999 -999 D£PT ~_300 000 SFb~ SP - 242453 GR NPHI -999.250 SGR NRAT -999.250 NCNb POTA -999,250 ORAN 1 145 -999 -999 -999 DEPT 6200.000 SFLU SP -23.453 GR NPHI -999.250 SGR NRAT -999,250 NCNb POTA -999.250 ORAN 1 121 -999 -999 -999 DEPT 6100.000 SFLU SP -34.000 GR NPHI -999.250 SGR NRAT -999.250 NCNb POTA -999.250 ORAN 2 159 -999 '999 -999 DEPT 6~00,000 BP 25.438 GR NPHI -999.250 NRAT -999.250 NCNb POTA -999.250 ORAN 2 117 -999 -999 -999 DEPT 5900.000 BFLU BP -25.156 GR NPHI -999,250 SGR NRAT -999.250 NCNL POTA -999,250 ORAN 2 104 -999 -999 -999 DEPT 5800.000 SFLU SP -33,969 OR NPHI -999.250 SGR NRAT -999.250 NCNb POTA -999.250 ORAN 2 100 -999 -999 -999 .250 .512 .250 .250 .250 ,250 .338 .250 .250 .250 .i95 .625 ,250 ,250 .250 .401 .125 .250 .250 .250 .764 ,750 .250 .250 .920 .000 .250 .250 .250 .457 .563 .250 .250 .535 .000 .250 .250 .25¢ ,15b .750 .250 .250 .250 CGR IbM DT CALf FCNb CGR D~ FCNL CGR IbM DT CGR IbM DT CALI CGR DT CALI FCN5 CGR DT CA51 FCNb CGR IbM DT CALi CGR IbM DT CALl FCNL CGR IbM DT CAI, I CGR -999,250 2,906 109.563 -999.250 -999,250 -999.250 3,i50 107,375 -999,250 -999.250 -999,250 3,049 110.188 999250 -'999.'250 -999,250 1.421 108,563 -999.250 -999,250 -999,250 1.418 116,000 -,999,250 999,250 -999.250 B99 -999.250 -999,250 -999.250 570 ,-999,250 999,250 -999,250 2,525 103.188 '999,250 2,098 110,750 '999,250 '999,250 '999.250 ILD RHOB DRHO THOR ILD RHOB DRHO THOR RHOB DRHO THOR ILD RHOB DRHO THOR RHOB DRHO THOR RHOB DRHO T~OR RHOB DRHO THOR RHOB DRHO THOR ILD RHOB DRHO THOR PAGE 2867 -999!250 -999250 -999.250 3.148 -999.250 -999250 2 977 -999!250 -999250 -999,250 1,472 -999,250 -9 ,250 1410 -999:250 -999,250 -999,250 2.723 -'999i250999 -999 i5050 2 627 -99~ 250 -99 : 250 2.543 99,250 99'250 102 -999,250 LVP 009.H03 VERIFICATION LISTING PAGE 6 DEPT 5700.000 SFLU SP -42.719 GR NPHI -999.250 SGR NEAT -999.250 NCNb POTA -999.250 URAN DEPT 5t~O0.O00 SFLU SP -42.500 GR NPHI _-999 250 SGR NEAT -R99:250 NCNb POTA -999.250 URAN DEPT 5500.000 SFbU Sp -33.688 GR NPHI -999.250 SGR NRAT -999.250 NCNb POTA -999.250 URAN DEPT 5400.000 SFLU Sp -24.~53 GR NPHi -999.250 SGR NEAT -999.250 NCNb POTA -999.250 URAN DEPT 5300.000 SFLU SP -35.938 GR NPHI -999.250 SGR NEAT -999.250 NCNb POTA -999.250 ORAN DEPT 5200.000 SFLO Sp -45.500 GR NPHI -999.250 SGR NEAT -999.250 NCNb POTA -999.250 URAN DEPT 5100.000 SFLU Sp -36.406 GR NPHI -999.250 SGR NEAT -999.250 NCNb POTA -999.250 ORAN DEPT 5000.000 SFbU SP -37.969 GR NPHI -999,250. &GE NEAT -999.250 NCNb POTA -999.250 ORAN DEPT 4900.000 SP -44.156 GR NPHI -999.250 NRAT -999.250 NCNb POTA -999.250 URA~ 2 -999 -999 -999 2 79 -999 -999 -999 2 87 -999 -999 -999 3 75 '999 -999 -999 2 -999 -999 -999 2 72 -999 -999 -999 2 96 -999 -999 -999 2 101 -999 -999 -999 3 91 -999 -999 -999 .59~ .563 .250 .250 .250 .506 ,18B .250 250 ~250 .41~ .125 .250 .250 .250 .070 .563 .250 .250 .250 .799 .875 .250 .250 .250 .828 .68~ .250 .250 .250 .811 .125 .250 .250 .250 ,918 .625 .250 .250 .250 .566 .500 .250 .250 .250 CALl FCNL CGR IbM DT CALI FCNb CGR IbM DT CALl FCMb CGR ILM DT CAbI FCNb CGR DT CAhI FCNL CGR IbM DT CALI FCNb CGR IbM DT CAbI FCNb CGR IbM DT CALI FCNb CGR IbM DI CALI FCNb CGR 2.602 10i 000 -999.250 -999.250 2.457 105.000 -999.250 -999.250 -999.250 2.395 106.563 -999.250 -999.250 -999.250 2.672 107.188 -999.250 -999.250 -999.250 2.746 105.188 -999.250 -999.250 -999.250 2.789 104.000 -999.250 :999,250 999.250 2.934 i06.563 -999.250 -999.250 -999.250 2.652 110,375 -999,250 -999.250 -999.250 3.633 108.188 -999.250 -999.250 -999.250 ILD RHOB DRHO THOR DRHO THOR ILD RHOB DRHO THOR RHOB DRHO THOR RMOB DRHO THOR RHOB DRHO THOR ILD ORHO THOR RHOB DRHO THOR ILD RMOB DRMO THOR 2.625 -999'250 -999,250 -999.250 2.492 -999,250 -999.250 -999.250 2.432 -999.250 -999.250 -999.250 2.803 -999.250 2.805 -999.250 -999.250 -999.250 9 250 2 979 -999 50 -999 250 2 682 , -999'250 -999,250 -999.250 3 746 -999!250 -999 250 -999.250 O09, HO3 DEPT NPHI NRAT POTA DEPT NPHI NRAT POTA DEPT SP NPHI NRAT POTA DEPT NPHI NRAT POTA DEPT SP NPHI NRAY POTA DEPT SP NPHI NRAT POTA DEPT SP NPHI NRAT POTA DEPT SP NPHI NRAT POTA DEPT SP NPHI NRAT POTA DEPT VERIFICATION LISTING 4~00.000 SFbU -48.438 GR -999.250 -999.250 NCNb -999.250 URAN 5.520 65.500 -999,250 -999,250 -999,250 4700.000 SFLU -43.~69 GR -999.250 SGR -999.250 NCNb -999.250 ORAN 3,439 84,312 -999.250 -999,250 -999.250 4600.000 SFLU -45.531 GR -999,250 $GR -999,250 NCNb -999.250 URAN 3.131 108.438 -999.250 -999,250 -999.250 4500.000 SFLU -44.750 GR -999.250 SGR -999.250 NCNL -999,250 ORAN 97,375 -999,250 -999,250 -999.250 4400.000 SFLU -45,719 GR -999,250 SGR -999,250 NCNb -999.250 ORAN 3.9~8 94,188 -999.250 -999,250 -999,250 4100.000 SFLU -45,188 GR -999.250 SGR -999.250 NCNb -999.250 URAN 3.920 75,813 -999,250 -999,250 -999,250 4200.000 SFbU -46.969 GR -999.250 SGR -999.250 NCNb -999,250 ORAN 3.469 !03.000 -999.250 -999.250 -999.250 4100.000 $FbO -50.438 GR 41.113 SGR 3.563 NCNb 0.027 ORAN 4.262 91.875 2004.000 3.016 4000.000 SFLO -56.125 GR 40.u88 SGR 3.525 NCNb 0,021 ORAN 4.395 79.938 87.312 2021.000 3.436 3900.000 SFLU 5.074 IbM DT CALI FCNb CGR DT CALI FCNb CGR I5~ DT C~Li FCN5 CGR IbM DT CALI FCNb CG~ DT CALf FCNb CGR IbM DT CALl FCNb CGR IbM DT CALI FCNb CGR DT CALI FCNb CGR DT CALl CGR 4,457 99,375 '999,250 -999,250 '999,250 2.939 114.188 -999.250 -999.250 -999.250 3.291 117.188 -999.250 '999.250 -999.250 3.283 11b.563 -999.250 -999.250 -999.250 4.094 1t1,000 -999.250 -999.250 -999.250 3.797 1~4.375 -999.250 -999.250 -999.250 3.861 Ii6.i88 -999.250 -999,250 -999.250 4 941 114.'750 il,26'6 503.250 68,125 4.988 222.000 11.984 499.500 64.000 5.574 RHOB DRHO THOR RHOB DRHO THOR ILD RHOB THOR RHOB DHHO THOR ibD RHOB DRMO THOR ILD RHOB DRHO THOR ILD RHOB DRHO THOR RHOB DRHO THOR RHOB DRMO THOR ILD PAGE 4,516 -999,250 -999,250 -999.250 3.037 -999.250 -999.250 -999.250 3.457 -999.250 -999 250 3 443 -999 250 4 480 -999!250 -999 250 -999.250 3.869 -999,250 -999 250 -999:2~0 4.109 -999,250 -999.250 -999.250 5 422 0.059 6.754 5,523 2,266 0 95 6.074 LVP O09.HU3 SP NPHI NEAT POTA DEPT SP NPHI NEAT POTA DEPT SP NPHI NEAT POTA DEPT SP NPHI NRAT POTA DEPT SP NPHI NRAT POTA DEPT SP NPHI NEAT POTA DEPT SP NPHI NRAT POTA DEPT SP NPHI NEAT POTA DEPT SP NPHI NEAT POTA DEPT SP VERIFICATION LISTING -49.000 G~ 39.844 3.490 NCNb 0.016 URAN 75.250 79.563 2100.000 2.945 3800.000 SFLU -86.688 GR 41.650 SGR 3.484 NCNb 0.015 URAN 48.658 42.750 51.938 2250.000 0.739 3700.000 -56.938 GR 36.621 3.324 NCNb 0,019 URAN 9.578 82.125 85.063 2176.000 2.1~9 3600,000 SFLU -58.719 GR 40.186 SGR 3.525 NCNb 0.020 URAN B.lb4 70.063 75.813 2130.000 1.521 3500.000 SFLU -68.188 GR 40.039 3.473 NCNb 0.011 URAN 9.492 50.188 45.594 2176'000 1:590 3400,000 SFLU -61.bBb 42.969 3.545 NCNb 0.014 URAN 8.539 66,43~ 64,000 2150.000 3.590 3300,000 -68.438 GR 39.648 SGR 3.377 NCNb 0.019 URAN 12,547 76.375 77.56~ 2234.000 2.315 3200.000 -71.375 GR 42,334 SGR 3.641 NCNb 0.012 URAN 28.859 44,688 47,125 2414.000 1,246 3100.000 -54.656 45.410 3.b84 NCNb 0,0~4 URAN 1~.922 66.063 63.18~ 2168.000 2.396 3000.000 SFLU -63.219 G~ ll,oa~ 50.469 DT CALl FCNL CGR DT CALl FC~L CGR Ib~ DT CALI FCNb CGR DT CALI FCNb CGR DT CALI FCNL CGR DT CALl FCNL ILM DT CALI FCN5 CGR DT CALl FCNL CGR DI CALl FCN5 CGR DT 114.375 1~.227 55 .500 5~.938 38.844 114.000 9.578 623,000 48.312 8.781 109.750 11.750 642.500 65.438 8.102 124.750 11.789 586.500 61.656 9.289 144.750 10.508 562.500 36.094 8.664 127.375 9.398 548.000 35.750 11.i72 127.375 9.617 625,000 59.281 34,906 14~.375 11,625 578.500 37.312 11.516 133.750 9.445 522.000 42.250 10.391 137.750 RHOB DRHO THOR RHOB DRHO THOR RHOB DRHO THOR ILD RHOB DRHO THOR RMOB DRHO THOR DRHO THOR RHOB DRHO THOR IbD RSOB THOR ILO RHOB DRHO THOR IbD PAGE 2 311 8.312 34.000 2.164 0.022 6.152 9,555 2.389 0.022 8.289 8 523 2!260 0 017 8.078 10.I09 2.164 -0,003 5.602 9.023 2 168 -0:001 3.268 11.406 2.182 -0.003 7,746 30 375 2:057 0,005 4.027 12,156 2.i29 '0,006 5.586 11.086 2,057 LVP 009,H03 VERiFfCATION DISTING NPHI 45.557 SGR NRAT 3,707 NCNL POTA O,OlO DEPT 2900.000 SFLU SP -7.906 GR NPHI 58.496 SGR NRAT ~.~53 NCNL POTa 0.012 URAN DEPY 2~28.000 SFLU SP 9.875 GR NPHI -999.250 SGR NRAT -999.250 NCNL POTA -999,250 URA~ 53,469 2236,000 1,953 2000,000 41,844 40.969 1570,000 b,566 31.344 -999.250 -999,250 -999.250 CALf FCN5 CGR DT CALl CGR DT CALl FCNL CGR ** FILE TRAILER FILE NA~E ;SERVlC.OOi SERVICE NA~E : VER$IOC~ ~ DATE : MAXI~Q~ LENGTH : 1024 FILE TYPE NEX~ FIDE MAME : ~ TAPE TRAILER ~ SERV!C~: NA~E :SERVIC DATE :81/07/ 9 ORIGIN :1070 TAPE NA~E ;61746 CONTi~UATiO~ # :01 NEXT TAPE NA~E : COMMENTS :TAPE COMMENTS *~ REEL TRAILER ~ SERVICE NAME :SERVIC DATE :81/07/ 9 ORIGIN : REEL NAME :REEL ID CONTIN},~ATION # :01 NEXT REEL NA~E ~ COMMENTS :REEL COMMENTS EOF 9,641 542.500 38.188 2000.000 58.375 9,984 314.000 38,063 2000,000 -999.250 -999.250 -999'250 -999,250 DRHD THOR RHOB DRHO THOR RHOB DRHO THOR 0,004 4.234 4,309 1,905 -0.780 6.508 9 563 -999;250 :999,250 999 ' 250 ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 MMeemmoorryy MMaaggnneettiicc TThhiicckknneessss TTooooll LLoogg RReessuullttss SSuummmmaarryy Company: ConocoPhillips Alaska, Inc. Well: 1A-02 Log Date: October 24, 2014 Field: Kuparuk Log No.: 16007 State: Alaska Run No.: 2 (1st MTT) API No. 50-029-20599-00 Pipe Description: 3.5 inch 9.3 lb. J-55 Top Log Interval: 2,902 Ft. (MD) Pipe Use: Tubing Bottom Log Interval: 7,480 Ft. (MD) (MTT only) Pipe Description: 7 inch 26 lb. K-55 Top Log Interval: 2,902 Ft. (MD) Pipe Use: Production Casing Bottom Log Interval: 7,480 Ft. (MD) (MTT only) Inspection Type : Production Casing Damage Inspection COMMENTS : This MTT data is tied into the bottom of the surface casing at 2,902 feet (Driller’s Depth). This is the first time a 12 Arm Magnetic Thickness Tool (MTT) has been run in this well. The MTT responds to the metal surrounding the tool, including the 3.5 inch tubing and 7 inch production casing. A pass at 10Hz was made at 20 fpm from 2,902 feet (bottom of surface casing) to 7,480 feet. INTERPRETATION OF MTT LOG RESULTS : The MTT metal volume assessment covers the interval below the surface casing from 2,902 to 7,480 ft. Due to the concentric pipe strings in the log interval, the MTT response is qualitative – indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. High frequency signal oscillations in the individual sensor curves are generally associated with tubing damage, while low frequency deviations in the overall metal thickness measurement point to metal loss in the production casing. Changes in metal volume are relative to the calibration point at 5,935 feet, where the readings are assumed to represent undamaged pipe. All other readings are relative to this reference point, which include influences from the 3.5 inch tubing and 7 inch production casing. A plot of the 10Hz MTT recordings is included in this report. A continuous line of high frequency signal oscillations is recorded across the interval logged. This pattern of high frequency signal oscillations indicates possible damage to the tubing. No low frequency indications of significant production casing damage are recorded throughout the interval logged. All of the variances apparent in the overall delta metal thickness curve appear to be associated with manufacturing aspects of the tubing and casing joints. Detailed log plots of the damage recorded by the 10Hz MTT pass from 2,885 feet to 3,040 feet and from 5,790 feet to 5,940 feet are included in this report. The percent circumferential metal loss expressed in this summary is a percentage of the total metal the tool is responding to, which includes influences from the 3.5 inch tubing and 7 inch production casing. If all of the metal loss is specific to the 7 inch production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. D. Cain J. Bruning, J. Burton E. Zumba, M. Walters Field Engineer(s) Analyst(s) Witness(es) Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.063 Top (ftKB) 39.0 Set Depth (ftKB) 112.0 Set Depth (TVD) … 112.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.797 Top (ftKB) 28.7 Set Depth (ftKB) 2,902.0 Set Depth (TVD) … 2,662.5 Wt/Len (l… 45.50 Grade K-55 Top Thread BUTT Casing Description PRODUCTION OD (in) 7 ID (in) 6.276 Top (ftKB) 27.9 Set Depth (ftKB) 8,337.0 Set Depth (TVD) … 6,534.8 Wt/Len (l… 26.00 Grade K-55 Top Thread Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 27.7 Set Depth (ft… 7,782.1 Set Depth (TVD) (… 6,125.3 Wt (lb/ft) 9.20 Grade J-55 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 27.7 27.7 0.00 HANGER Tubing Hanger 3.500 1,813.5 1,784.8 25.27 SAVETY VLV CAMCO TRDP 1A-ENC 2.812 7,447.4 5,889.9 46.53 SBR BAKER SBR 3.000 7,473.6 5,908.0 46.26 PACKER BAKER HYD PACKE 3.000 7,549.6 5,960.9 45.63 BLAST RINGS BLAST RINGS (7) - WLM 7547'-7717' 2.867 7,741.3 6,096.1 44.59 NIPPLE AVA BOTTOM NO GO PORTED NIPPLE 2.750 7,752.1 6,103.8 44.48 LOCATOR Locator Space Out 2.875 7,753.0 6,104.5 44.47 PACKER BAKER PERMANENT PACKER (7734' WLM 12/21/1986) 3.250 7,756.7 6,107.1 44.43 SBE XO Baker Seal Bore Extension w/XO 3.5" to 2 7/8" 2.875 7,769.8 6,116.5 44.30 NIPPLE CAMCO 'D' NO GO NIPPLE 2.250 7,779.8 6,123.6 44.20 XO CROSSOVER 2 7/8" TO 3.5" 2.441 7,781.4 6,124.8 44.19 SOS OTIS SHEAROUT SUB / ELMD TTL @ 7764 during IPROF on 2/11/2008 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 7,503.8 5,929.0 45.97 PLUG WEATHERFORD WRP 12/30/2013 0.000 7,650.0 6,031.5 45.13 FISH 3' x 1" COLLET LOST ON G-SPEAR BELOW PATCH 5/24/2009 0.000 7,727.0 6,086.0 44.73 G-SPEAR BAITED BOWEN G-SPEAR ON PATCH (OAL 24") 5/17/2009 0.000 7,728.0 6,086.7 44.72 PATCH 3.5" LOWER PATCH ASSY FISH (14.5" OAL PATCH REMAINING) 3/7/2006 1.600 7,902.0 6,212.1 42.98 FISH Vann Gun, 340.14" long 7/1/1981 0.000 7,902.0 6,212.1 42.98 FISH Lock Key from AVA IBP left in hole @ 7902' 10/31/1999 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (shots/f t)Type Com 7,552.0 7,577.0 5,962.6 5,980.1 C-4, 1A-02 12/23/1986 12.0 RPERF 120 deg. Ph; 5" HyperJet II 7,552.0 7,591.0 5,962.6 5,989.9 C-4, 1A-02 7/1/1981 4.0 IPERF Squeezed & Reperfed; Vann Gun 7,601.0 7,626.0 5,997.0 6,014.6 C-3, 1A-02 12/23/1986 12.0 RPERF 120 deg. Ph; 5" HyperJet II 7,601.0 7,648.0 5,997.0 6,030.1 C4, C-3, 1A- 02 7/1/1981 4.0 IPERF Squeezed & Reperfed; Vann Gun 7,652.0 7,688.0 6,032.9 6,058.3 C-2, 1A-02 12/23/1986 12.0 RPERF 120 deg. Ph; 5" HyperJet II 7,654.0 7,688.0 6,034.3 6,058.3 C-2, 1A-02 7/1/1981 4.0 IPERF Squeezed & Reperfed; Vann Gun 7,700.0 7,712.0 6,066.8 6,075.3 C-1, UNIT B, 1A-02 7/1/1981 4.0 IPERF Squeezed & Reperfed; Vann Gun 7,796.0 7,850.0 6,135.3 6,174.3 A-5, A-4, 1A- 02 7/1/1981 4.0 IPERF 120 deg. Ph; Vann Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Start Date Com 7,552.0 7,591.0 5,962.6 5,989.9 Cement SQZ 7/1/1981 Reperfed 7601-7626 on 23/23/86 (WO) 7,601.0 7,648.0 5,997.0 6,030.1 Cement SQZ 7/1/1981 Reperfed 7601-7626 on 23/23/86 (WO) 7,654.0 7,654.0 6,034.3 6,034.3 Cement SQZ 7/1/1981 Reperfed 7601-7626 on 23/23/86 (WO) 7,700.0 7,712.0 6,066.8 6,075.3 Cement SQZ 7/1/1981 Reperfed 7601-7626 on 23/23/86 (WO) Mandrel Inserts St ati on No /S Top (ftKB) Top (TVD) (ftKB)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date C o m 1 3,063.2 2,772.5 Camco KBUG 1 Gas Lift DMY BK-2 0.000 0.0 11/19/1991 2 4,453.5 3,714.4 Camco KBUG 1 Gas Lift DMY BK-2 0.000 0.0 4/22/2009 3 4,877.0 4,009.3 Camco KBUG 1 Gas Lift DMY BK-2 0.000 0.0 11/19/1991 4 5,245.6 4,273.0 Camco KBUG 1 Gas Lift DMY BK-2 0.000 0.0 11/19/1991 5 5,614.6 4,546.4 Camco KBUG 1 Gas Lift DMY BK-2 0.000 0.0 11/19/1991 6 5,982.9 4,824.1 Camco KBUG 1 Gas Lift DMY BK-2 0.000 0.0 11/19/1991 7 6,294.7 5,061.6 Camco KBUG 1 Gas Lift DMY BK-2 0.000 0.0 11/19/1991 8 6,659.2 5,340.2 Camco KBUG 1 Gas Lift DMY BK-2 0.000 0.0 11/19/1991 9 7,029.5 5,609.0 Camco KBUG 1 Gas Lift DMY BK-2 0.000 0.0 12/25/1986 1 0 7,400.6 5,857.9 OTIS LBX 1 1/2 Gas Lift DMY RM 0.000 0.0 8/15/2006 1 1 7,509.4 5,932.8 Camco KBUG 1 INJ CV BK 0.000 0.0 4/21/2013 Comment SSSV: TRDP1A-02, 1/1/2014 1:18:38 PM Vertical schematic (actual) PRODUCTION; 27.9-8,337.0 FISH; 7,902.0 FISH; 7,902.0 IPERF; 7,796.0-7,850.0 SOS; 7,781.4 XO; 7,779.8 NIPPLE; 7,769.8 SBE XO; 7,756.7 PACKER; 7,753.0 LOCATOR; 7,752.1 NIPPLE; 7,741.3 PATCH; 7,728.0 G-SPEAR; 7,727.0 CMT SQZ; 7,700.0 IPERF; 7,700.0-7,712.0 IPERF; 7,654.0-7,688.0 RPERF; 7,652.0-7,688.0 CMT SQZ; 7,654.0 FISH; 7,650.0 CMT SQZ; 7,601.0 IPERF; 7,601.0-7,648.0 RPERF; 7,601.0-7,626.0 CMT SQZ; 7,552.0 IPERF; 7,552.0-7,591.0 RPERF; 7,552.0-7,577.0 INJECTION; 7,509.4 PLUG; 7,503.8 PACKER; 7,473.6 SBR; 7,447.4 GAS LIFT; 7,400.7 GAS LIFT; 7,029.5 GAS LIFT; 6,659.2 GAS LIFT; 6,294.7 GAS LIFT; 5,982.9 GAS LIFT; 5,614.6 GAS LIFT; 5,245.6 GAS LIFT; 4,877.0 GAS LIFT; 4,453.5 GAS LIFT; 3,063.2 SURFACE; 28.7-2,902.0 SAVETY VLV; 1,813.5 CONDUCTOR; 39.0-112.0 HANGER; 27.7 Annotation Last Tag: ELMD Depth (ftKB) 7,840.0 End Date 10/9/2008 Annotation Rev Reason: SET PLUG Last Mod By lehallf End Date 12/31/2013 KUP INJ KB-Grd (ft) 39.01 Rig Release Date 7/2/1981 Annotation Last WO: End Date 12/25/1986 1A-02 H2S (ppm) Date... TD Act Btm (ftKB) 8,355.0 Well Attributes Wellbore API/UWI 500292059900 Field Name KUPARUK RIVER UNIT Wellbore Status INJ Max Angle & MD Incl (°) 49.00 MD (ftKB) 7,200.00 Notes: General & Safety End Date Annotation 11/18/2001 NOTE: WAIVERED WELL - T x IA Communication 8/31/2005 NOTE: TUBING LEAK FOUND w/PONYTAIL @ 7739' 8/14/2006 NOTE: IA leak @ 3025' plugged with Sealtite Flo-Seal Sealant 8/18/2008 NOTE: VIEW SCHEMATIC w/ALaska Schematic9.0 2/1/2009 NOTE: LEAK FOUND @ 3030' ON TECWELL LDL 12/30/2013 NOTE: CASING LEAK AT 3030' RKB 1A-02, 1/1/2014 1:18:39 PM Vertical schematic (actual) PRODUCTION; 27.9-8,337.0 FISH; 7,902.0 FISH; 7,902.0 IPERF; 7,796.0-7,850.0 SOS; 7,781.4 XO; 7,779.8 NIPPLE; 7,769.8 SBE XO; 7,756.7 PACKER; 7,753.0 LOCATOR; 7,752.1 NIPPLE; 7,741.3 PATCH; 7,728.0 G-SPEAR; 7,727.0 CMT SQZ; 7,700.0 IPERF; 7,700.0-7,712.0 IPERF; 7,654.0-7,688.0 RPERF; 7,652.0-7,688.0 CMT SQZ; 7,654.0 FISH; 7,650.0 CMT SQZ; 7,601.0 IPERF; 7,601.0-7,648.0 RPERF; 7,601.0-7,626.0 CMT SQZ; 7,552.0 IPERF; 7,552.0-7,591.0 RPERF; 7,552.0-7,577.0 INJECTION; 7,509.4 PLUG; 7,503.8 PACKER; 7,473.6 SBR; 7,447.4 GAS LIFT; 7,400.7 GAS LIFT; 7,029.5 GAS LIFT; 6,659.2 GAS LIFT; 6,294.7 GAS LIFT; 5,982.9 GAS LIFT; 5,614.6 GAS LIFT; 5,245.6 GAS LIFT; 4,877.0 GAS LIFT; 4,453.5 GAS LIFT; 3,063.2 SURFACE; 28.7-2,902.0 SAVETY VLV; 1,813.5 CONDUCTOR; 39.0-112.0 HANGER; 27.7 KUP INJ 1A-02 ... MID REPORT 1A - 02 Single Completion Injector Conoco Phillips Alaska, Inc. Company: Conoco Phillips Alaska, Inc. Country: USA K Field: Kuparuk Logging Date: 23 – Oct – 2014 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 2 of 52 DATA RECORDED BY Dale Cain / Alexey Li ANALYST Alfiia Gabdrakhmanova REVIEWED BY Matthew Lawrence Interpretations made by TGT OILFIELD SERVICES at the request of ConocoPhillips are based on information provided to TGT OILFIELD SERVICES by ConocoPhillips. All conclusions and recommendations were produced using measurements and empirical relationships and assumptions. All representations and warranties, expressed or implied, in respect of this report are hereby excluded. TGT OILFIELD SERVICES cannot, except in the case of negligence on part of TGT OILFIELD SERVICES, be held liable or responsible for any losses, costs, damages or expenses which might be incurred by anyone in relation to the contents of this report. Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 3 of 52 CONTENTS 3 4 5 6 7 8 9 10 11 22 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 51 52 CONTENTS EXECUTIVE SUMMARY Fig. 1 Tubing Joint #131 – Tubing Corrosion with 41% of Metal Loss Fig. 2 Tubing Joint #140 – Tubing Corrosion with 45% of Metal Loss Fig. 3 Tubing Joint #156 – Tubing Corrosion with 41% of Metal Loss Fig. 4 Tubing Joint #211 – Tubing Corrosion with 37% of Metal Loss Fig. 5 Tubing Joint #16 – Tubing Corrosion with 33% of Metal Loss Fig. 6 Tubing Joint #85 – Tubing Corrosion with 33% of Metal Loss Fig. 7 Casing Joint #154 – Casing Corrosion with 34% of Metal Loss SURVEY RESULTS Fig. 8 Magnetic Imaging Defectoscope within Interval 30 – 300 ft Fig. 9 Magnetic Imaging Defectoscope within Interval 300 – 600 ft Fig. 10 Magnetic Imaging Defectoscope within Interval 600 – 900 ft Fig. 11 Magnetic Imaging Defectoscope within Interval 900 – 1,200 ft Fig. 12 Magnetic Imaging Defectoscope within Interval 1,200 – 1,500 ft Fig. 13 Magnetic Imaging Defectoscope within Interval 1,500 – 1,800 ft Fig. 14 Magnetic Imaging Defectoscope within Interval 1,800 – 2,100 ft Fig. 15 Magnetic Imaging Defectoscope within Interval 2,100 – 2,400 ft Fig. 16 Magnetic Imaging Defectoscope within Interval 2,400 – 2,700 ft Fig. 17 Magnetic Imaging Defectoscope within Interval 2,700 – 2,902 ft Fig. 18 Magnetic Imaging Defectoscope within Interval 2,902 – 3,200 ft Fig. 19 Magnetic Imaging Defectoscope within Interval 3,200 – 3,500 ft Fig. 20 Magnetic Imaging Defectoscope within Interval 3,500 – 3,800 ft Fig. 21 Magnetic Imaging Defectoscope within Interval 3,800 – 4,100 ft Fig. 22 Magnetic Imaging Defectoscope within Interval 4,100 – 4,400 ft Fig. 23 Magnetic Imaging Defectoscope within Interval 4,400 – 4,700 ft Fig. 24 Magnetic Imaging Defectoscope within Interval 4,700 – 5,000 ft Fig. 25 Magnetic Imaging Defectoscope within Interval 5,000 – 5,300 ft Fig. 26 Magnetic Imaging Defectoscope within Interval 5,300 – 5,600 ft Fig. 27 Magnetic Imaging Defectoscope within Interval 5,650 – 5,760 ft Fig. 28 Magnetic Imaging Defectoscope within Interval 6,100 – 6,400 ft Fig. 29 Magnetic Imaging Defectoscope within Interval 6,400 – 6,700 ft Fig. 30 Magnetic Imaging Defectoscope within Interval 6,700 – 7,000 ft ATTACHMENTS SEQUENCE OF EVENTS WELL SCHEMATICS (Provided by Client) ABBREVIATIONS QUALITY CONTROL TGT MID LOGGING TOOL STRING SCHEMATIC DESCRIPTION OF LOGS Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 4 of 52 EXECUTIVE SUMMARY OBJECTIVES To identify metal loss (corrosion) in the 3 1/2” tubing (first barrier) To identify metal loss (corrosion) in the 7” casing behind the 3 1/2” tubing – total metal content loss FINDINGS A Magnetic Imaging Defectoscope (MID) survey was run in 1A-02 to identify the metal loss* in the 3 1/2” tubing and in the 7” casing behind the 3 1/2” tubing. MID data indicates the 3 1/2” tubing and 7” casing appears to range from good to poor condition. Metal loss* from 9% to 45% is recorded in the tubing and from 9% to 34% in the casing. No 7” casing corrosion was detected at 3,030 ft, in the vicinity of a known casing leak. The absence of significant metal loss in this vicinity and the nearby casing collar at 3,025.5 ft. suggests the possibility of a collar leak. 3 1/2” TUBING MAXIMUM METAL LOSS EVENTS Joint Number Metal Loss (%) Max. Metal Loss Depth (ft) What page in this report? Tabulation Log Plot 140 45 4265 15 6 131 41 3998 15 5 156 41 4754 15 7 211 37 6446 17 8 16 33 495 12 9 85 33 2611.4 14 10 7” CASING MAXIMUM METAL LOSS EVENTS Joint Number Metal Loss (%) Max. Metal Loss Depth (ft) What page in this report? Tabulation Log Plot 154 34 6884.5 21 11 * - Metal loss is averaged circumferentially and along the tool’s sensor length, which is 5 in. for the tubing and 13 in. for the casing. Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 5 of 52 Fig. 1 Tubing Joint #131 – Tubing Corrosion with 41% of Metal Loss Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness Tubing corrosion line Casing corrosion line 3 1/2” tubing 7” casing Tubing collars Casing collars Tubing corrosion with 41% metal loss Tubing corrosion line Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 6 of 52 Fig. 2 Tubing Joint #140 – Tubing Corrosion with 45% of Metal Loss Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness Tubing corrosion line Casing corrosion line 3 1/2” tubing 7” casing Tubing corrosion with 45% metal loss Tubing corrosion line Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 7 of 52 Fig. 3 Tubing Joint #156 – Tubing Corrosion with 41% of Metal Loss Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness Tubing corrosion line Casing corrosion line 3 1/2” tubing 7” casing Tubing corrosion with 41% metal loss Tubing corrosion line Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 8 of 52 Fig. 4 Tubing Joint #211 – Tubing Corrosion with 37% of Metal Loss Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness Tubing corrosion line Casing corrosion line 3 1/2” tubing 7” casing Tubing corrosion with 37% metal loss Tubing corrosion line Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 9 of 52 Fig. 5 Tubing Joint #16 – Tubing Corrosion with 33% of Metal Loss Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness Tubing corrosion line Casing corrosion line 3 1/2” tubing 7” casing Tubing corrosion with 33% metal loss Tubing corrosion line Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 10 of 52 Fig. 6 Tubing Joint #85 – Tubing Corrosion with 33% of Metal Loss Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness Tubing corrosion line Casing corrosion line 3 1/2” tubing 7” casing Tubing corrosion with 33% metal loss Tubing corrosion line Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 11 of 52 Fig. 7 Casing Joint #154 – Casing Corrosion with 34% of Metal Loss Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness Tubing corrosion line Casing corrosion line 3 1/2” tubing 7” casing Casing corrosion with 34% metal loss Tubing corrosion line Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 12 of 52 First Barrier: 3.5” Tubing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 1 27.7 57.0 2.1 57.0 62.8 2.2 62.8 77.2 2.3 77.2 80.1 3 80.1 111.3 corroded 89.5 12 4 111.3 141.5 5 141.5 170.5 corroded 156.5 13 6 170.5 201.0 7 201.0 231.5 corroded 204 21 227.3 13 8 231.5 261.0 9 261.0 291.0 corroded 277.0 9 10 291.0 321.0 11 321.0 350.5 12 350.5 378.5 13 378.5 409.0 corroded 394 9 14 409.0 439.0 15 439.0 469.0 corroded 446 17 16 469.0 497.0 corroded 470.5 29 495 33 17 497.0 526.5 18 526.5 554.5 corroded 531.5 25 19 554.5 585.0 20 585.0 612.5 corroded 590 13 603 13 21 612.5 641.5 corroded 628 13 22 641.5 672.0 23 672.0 702.5 corroded 676 17 24 702.5 732.0 corroded 709.5 13 25 732.0 763.5 26 763.5 795.0 corroded 774 17 791 13 27 795.0 826.5 28 826.5 857.5 corroded 851.9 13 29 857.5 888.5 30 888.5 919.5 31 919.5 951.5 32 951.5 982.0 33 982.0 1011.0 corroded 997.9 9 34 1011.0 1042.5 corroded 1033.3 13 35 1042.5 1073.5 36 1073.5 1106.0 37 1106.0 1137.5 38 1137.5 1168.0 corroded 1151 13 1163.5 17 39 1168.0 1198.5 corroded 1169.5 17 1173.5 9 39 1187 9 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 13 of 52 First Barrier: 3.5” Tubing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 39 corroded 1197.5 17 40 1198.5 1231.0 41 1231.0 1263.0 42 1263.0 1292.5 corroded 1278.1 21 1289 21 43 1292.5 1324.5 corroded 1319.7 17 44 1324.5 1355.5 corroded 1331.5 13 45 1355.5 1385.0 corroded 1369.6 9 1382.4 21 46 1385.0 1415.0 47 1415.0 1446.0 corroded 1437.5 9 1442.5 9 48 1446.0 1476.5 corroded 1472 25 49 1476.5 1506.0 corroded 1478 13 1484.5 13 50 1506.0 1535.5 51 1535.5 1565.0 corroded 1546.5 17 52 1565.0 1594.5 corroded 1571 13 53 1594.5 1626.5 54 1626.5 1657.0 55 1657.0 1688.0 56 1688.0 1719.0 57 1719.0 1749.0 58 1749.0 1779.0 corroded 1762.5 21 59 1779.0 1809.1 60.1 1809.1 1821.4 60.2 1821.4 1854.5 61 1854.5 1885.5 62 1885.5 1916.0 63 1916.0 1947.5 corroded 1922.9 9 64 1947.5 1979.0 corroded 1967.5 17 65 1979.0 2010.0 corroded 1982.9 9 66 2010.0 2042.5 67 2042.5 2072.5 68 2072.5 2101.5 69 2101.5 2133.0 70 2133.0 2163.0 corroded 2142.5 13 2159.5 13 71 2163.0 2190.5 corroded 2172 13 72 2190.5 2221.5 corroded 2214 13 73 2221.5 2250.5 74 2250.5 2280.5 75 2280.5 2309.5 76 2309.5 2341.0 77 2341.0 2371.0 corroded 2364.6 17 78 2371.0 2400.5 79 2400.5 2430.0 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 14 of 52 First Barrier: 3.5” Tubing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 80 2430.0 2461.0 corroded 2456.5 21 81 2461.0 2490.0 82 2490.0 2519.5 83 2519.5 2552.0 84 2552.0 2582.0 85 2582.0 2612.0 corroded 2597.5 29 2611.4 33 86 2612.0 2641.5 87 2641.5 2671.0 corroded 2645.5 21 88 2671.0 2701.5 corroded 2696.5 9 89 2701.5 2732.5 90 2732.5 2765.0 91 2765.0 2794.0 92 2794.0 2824.5 93 2824.5 2854.0 corroded 2829.5 21 94 2854.0 2883.5 corroded 2860 9 95 2883.5 2913.5 96 2913.5 2943.5 corroded 2935.5 9 97 2943.5 2974.0 98 2974.0 3002.5 corroded 2987.5 13 99 3002.5 3032.5 100 3032.5 3061.2 101.1 3061.2 3066.6 101.2 3066.6 3097.0 102 3097.0 3128.0 corroded 3099.5 21 103 3128.0 3159.5 104 3159.5 3190.0 105 3190.0 3219.5 106 3219.5 3249.5 107 3249.5 3279.0 108 3279.0 3309.0 corroded 3289 21 3303.9 13 109 3309.0 3337.0 110 3337.0 3368.0 111 3368.0 3399.0 112 3399.0 3429.5 corroded 3409.9 13 3426 9 113 3429.5 3461.0 114 3461.0 3490.5 115 3490.5 3521.5 116 3521.5 3551.5 corroded 3532 25 3544.5 13 117 3551.5 3581.5 corroded 3578.5 21 118 3581.5 3612.0 119 3612.0 3642.5 120 3642.5 3672.5 121 3672.5 3703.5 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 15 of 52 First Barrier: 3.5” Tubing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 122 3703.5 3735.0 123 3735.0 3765.5 124 3765.5 3794.0 corroded 3776.5 25 3789.5 17 3791.5 13 125 3794.0 3825.0 126 3825.0 3855.5 127 3855.5 3884.0 128 3884.0 3912.5 corroded 3888.5 21 129 3912.5 3942.0 130 3942.0 3972.5 131 3972.5 4002.0 corroded 3985 21 3998 41 132 4002.0 4030.5 133 4030.5 4060.0 corroded 4040 25 4050 13 4053 9 134 4060.0 4091.0 135 4091.0 4121.0 136 4121.0 4151.0 137 4151.0 4181.0 138 4181.0 4210.0 corroded 4191 17 139 4210.0 4240.0 corroded 4213.5 17 140 4240.0 4269.5 corroded 4265 45 141 4269.5 4299.0 corroded 4274 21 142 4299.0 4329.5 corroded 4305.5 25 143 4329.5 4362.0 corroded 4344 9 4357 17 144 4362.0 4391.5 145 4391.5 4423.0 146 4423.0 4453.0 147.1 4453.0 4458.4 147.2 4458.4 4488.0 148 4488.0 4517.5 149 4517.5 4547.5 150 4547.5 4578.0 151 4578.0 4609.5 152 4609.5 4639.5 corroded 4619.5 13 153 4639.5 4669.5 154 4669.5 4698.5 155 4698.5 4729.0 156 4729.0 4758.5 corroded 4754 41 157 4758.5 4789.0 158 4789.0 4819.5 159 4819.5 4848.0 160 4848.0 4876.5 161.1 4876.5 4882.5 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 16 of 52 First Barrier: 3.5” Tubing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 161.2 4882.5 4913.5 162 4913.5 4944.0 163 4944.0 4974.5 164 4974.5 5005.0 165 5005.0 5034.0 166 5034.0 5063.5 corroded 5061 17 167 5063.5 5091.5 168 5091.5 5123.0 169 5123.0 5154.0 corroded 5151.5 9 170 5154.0 5183.0 171 5183.0 5213.5 172 5213.5 5243.6 173.1 5243.6 5249.5 173.2 5249.5 5281.0 174 5281.0 5310.5 175 5310.5 5341.0 corroded 5336 9 176 5341.0 5372.0 177 5372.0 5403.5 corroded 5388 17 178 5403.5 5432.5 179 5432.5 5463.0 180 5463.0 5492.5 181 5492.5 5522.0 corroded 5496.5 13 182 5522.0 5552.5 183 5552.5 5582.5 184 5582.5 5614.0 185.1 5614.0 5619.4 185.2 5619.4 5652.0 186 5652.0 5683.0 187 5683.0 5714.0 corroded 5708.6 9 188 5714.0 5745.5 189 5745.5 5773.5 190 5773.5 5804.0 191 5804.0 5834.0 192 5834.0 5863.5 193 5863.5 5892.5 194 5892.5 5921.5 195 5921.5 5952.5 196 5952.5 5982.4 197.1 5982.4 5988.6 197.2 5988.6 6019.5 198 6019.5 6049.5 199 6049.5 6080.0 200 6080.0 6110.5 201 6110.5 6141.5 202 6141.5 6172.0 203 6172.0 6201.0 corroded 6197 21 204 6201.0 6232.5 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 17 of 52 First Barrier: 3.5” Tubing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 205 6232.5 6263.5 206 6263.5 6294.1 207.1 6294.1 6301.0 207.2 6301.0 6331.5 208 6331.5 6361.0 209 6361.0 6391.0 210 6391.0 6421.5 211 6421.5 6450.0 corroded 6446 37 212 6450.0 6479.5 corroded 6466.5 25 213 6479.5 6509.5 214 6509.5 6541.0 215 6541.0 6572.5 corroded 6547.5 13 216 6572.5 6600.5 217 6600.5 6629.5 218 6629.5 6658.8 219.1 6658.8 6669.9 219.2 6669.9 6701.0 220 6701.0 6731.5 221 6731.5 6760.5 222 6760.5 6792.0 223 6792.0 6822.0 224 6822.0 6851.0 corroded 6836 17 225 6851.0 6883.0 226 6883.0 6913.0 227 6913.0 6943.5 228 6943.5 6971.0 229 6971.0 7001.5 230 7001.5 7029.7 231.1 7029.7 7039.9 231.2 7039.9 7070.5 232 7070.5 7099.5 233 7099.5 7129.0 234 7129.0 7159.5 235 7159.5 7190.0 236 7190.0 7220.5 237 7220.5 7250.5 238 7250.5 7280.5 239 7280.5 7310.0 240 7310.0 7340.5 241 7340.5 7371.5 242 7371.5 7400.9 243.1 7400.9 7409.6 243.2 7409.6 7440.5 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 18 of 52 Second Barrier: 7” Casing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 1 27.9 69.8 2 69.8 111.7 3 111.7 154.0 4 154.0 195.5 5 195.5 234.0 6 234.0 274.0 7 274.0 316.5 8 316.5 358.5 9 358.5 400.5 10 400.5 441.1 11 441.1 485.8 12 485.8 523.0 13 523.0 565.0 14 565.0 608.5 15 608.5 647.0 16 647.0 688.0 17 688.0 727.0 18 727.0 766.0 19 766.0 806.6 corroded 774 9 789.4 9 20 806.6 850.0 21 850.0 891.5 22 891.5 930.0 23 930.0 972.0 24 972.0 1014.5 corroded 998.5 9 25 1014.5 1057.0 26 1057.0 1099.0 corroded 1061.5 14 27 1099.0 1142.0 28 1142.0 1186.5 29 1186.5 1228.5 30 1228.5 1271.5 31 1271.5 1310.5 32 1310.5 1352.0 33 1352.0 1391.5 corroded 1383 9 34 1391.5 1431.5 35 1431.5 1471.5 36 1471.5 1516.5 corroded 1478.5 20 37 1516.5 1557.0 38 1557.0 1599.5 39 1599.5 1640.0 40 1640.0 1682.5 41 1682.5 1722.5 42 1722.5 1762.5 43 1762.5 1804.1 44 1804.1 1846.0 45 1846.0 1888.7 46 1888.7 1931.0 47 1931.0 1970.0 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 19 of 52 Second Barrier: 7” Casing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 48 1970.0 2012.5 49 2012.5 2052.5 50 2052.5 2097.5 51 2097.5 2146.0 52 2146.0 2193.0 53 2193.0 2240.5 54 2240.5 2286.5 55 2286.5 2333.0 56 2333.0 2380.0 57 2380.0 2426.0 58 2426.0 2474.0 59 2474.0 2522.0 60 2522.0 2568.5 61 2568.5 2614.5 62 2614.5 2660.0 63 2660.0 2705.0 64 2705.0 2750.4 65 2750.4 2798.0 66 2798.0 2844.5 67 2844.5 2892.0 68 2892.0 2928.5 69 2928.5 2976.5 70 2976.5 3025.5 71 3025.5 3074.0 72 3074.0 3109.0 73 3109.0 3156.0 corroded 3130.1 17 74 3156.0 3203.0 75 3203.0 3249.7 76 3249.7 3297.5 77 3297.5 3343.5 78 3343.5 3387.0 79 3387.0 3434.0 80 3434.0 3481.5 81 3481.5 3529.0 82 3529.0 3576.0 83 3576.0 3622.0 84 3622.0 3669.0 85 3669.0 3715.5 86 3715.5 3758.5 corroded 3733 9 87 3758.5 3804.5 88 3804.5 3850.5 89 3850.5 3898.0 90 3898.0 3945.0 91 3945.0 3991.5 92 3991.5 4033.0 93 4033.0 4079.5 94 4079.5 4127.5 95 4127.5 4174.5 96 4174.5 4221.0 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 20 of 52 Second Barrier: 7” Casing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 97 4221.0 4269.5 98 4269.5 4316.5 99 4316.5 4363.5 100 4363.5 4410.0 101 4410.0 4457.2 102 4457.2 4504.8 103 4504.8 4552.5 104 4552.5 4591.9 105 4591.9 4634.5 106 4634.5 4680.5 107 4680.5 4726.0 108 4726.0 4771.5 109 4771.5 4813.6 corroded 4797.4 12 110 4813.6 4859.5 corroded 4818 20 111 4859.5 4907.5 112 4907.5 4954.5 113 4954.5 5002.0 114 5002.0 5046.5 corroded 5031 12 115 5046.5 5094.0 116 5094.0 5140.5 117 5140.5 5187.5 118 5187.5 5234.6 119 5234.6 5278.5 120 5278.5 5326.1 121 5326.1 5372.1 corroded 5343.1 12 122 5372.1 5419.4 123 5419.4 5467.0 124 5467.0 5513.5 125 5513.5 5559.0 126 5559.0 5605.0 127 5605.0 5649.0 128 5649.0 5696.5 129 5696.5 5743.0 130 5743.0 5790.2 131 5790.2 5837.5 132 5837.5 5885.0 133 5885.0 5932.5 134 5932.5 5979.6 135 5979.6 6024.3 136 6024.3 6071.5 137 6071.5 6117.9 138 6117.9 6165.5 139 6165.5 6212.8 140 6212.8 6260.0 141 6260.0 6307.5 142 6307.5 6354.5 143 6354.5 6402.0 144 6402.0 6439.5 145 6439.5 6487.0 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 21 of 52 Second Barrier: 7” Casing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Max. Metal Loss Depth (ft) Metal loss* (%) 146 6487.0 6534.0 147 6534.0 6581.2 148 6581.2 6627.0 149 6627.0 6673.6 150 6673.6 6719.5 151 6719.5 6766.4 152 6766.4 6813.6 corroded 6794.8 12 153 6813.6 6859.0 154 6859.0 6905.0 corroded 6884.5 34 155 6905.0 6952.5 156 6952.5 6994.0 157 6994.0 7040.4 158 7040.4 7087.0 159 7087.0 7133.6 160 7133.6 7180.5 161 7180.5 7228.0 162 7228.0 7275.5 163 7275.5 7322.1 164 7322.1 7368.5 165 7368.5 7414.5 166 7414.5 7463.0 Note: According to MID survey 10 3/4" casing shoe was detected at 2904 ft. * - Metal loss is averaged circumferentially and along the tool’s sensor length, which is 5 in. for tubing and 13 in. for casing. Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 22 of 52 SURVEY RESULTS Fig. 8 Magnetic Imaging Defectoscope within Interval 30 – 300 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness Tubing corrosion line Tubing corrosion line Casing corrosion line 3 1/2” tubing 7” casing Tubing collars Casing collars Tubing corrosion Tubing corrosion Tubing corrosion Tubing corrosion Tubing corrosion Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 23 of 52 Fig. 9 Magnetic Imaging Defectoscope within Interval 300 – 600 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 24 of 52 Fig. 10 Magnetic Imaging Defectoscope within Interval 600 – 900 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 25 of 52 Fig. 11 Magnetic Imaging Defectoscope within Interval 900 – 1,200 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 26 of 52 Fig. 12 Magnetic Imaging Defectoscope within Interval 1,200 – 1,500 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 27 of 52 Fig. 13 Magnetic Imaging Defectoscope within Interval 1,500 – 1,800 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 28 of 52 Fig. 14 Magnetic Imaging Defectoscope within Interval 1,800 – 2,100 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 29 of 52 Fig. 15 Magnetic Imaging Defectoscope within Interval 2,100 – 2,400 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 30 of 52 Fig. 16 Magnetic Imaging Defectoscope within Interval 2,400 – 2,700 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 31 of 52 Fig. 17 Magnetic Imaging Defectoscope within Interval 2,700 – 2,902 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 32 of 52 Fig. 18 Magnetic Imaging Defectoscope within Interval 2,902 – 3,200 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 33 of 52 Fig. 19 Magnetic Imaging Defectoscope within Interval 3,200 – 3,500 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 34 of 52 Fig. 20 Magnetic Imaging Defectoscope within Interval 3,500 – 3,800 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 35 of 52 Fig. 21 Magnetic Imaging Defectoscope within Interval 3,800 – 4,100 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 36 of 52 Fig. 22 Magnetic Imaging Defectoscope within Interval 4,100 – 4,400 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 37 of 52 Fig. 23 Magnetic Imaging Defectoscope within Interval 4,400 – 4,700 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 38 of 52 Fig. 24 Magnetic Imaging Defectoscope within Interval 4,700 – 5,000 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 39 of 52 Fig. 25 Magnetic Imaging Defectoscope within Interval 5,000 – 5,300 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 40 of 52 Fig. 26 Magnetic Imaging Defectoscope within Interval 5,300 – 5,600 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 41 of 52 Fig. 27 Magnetic Imaging Defectoscope within Interval 5,650 – 5,760 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 42 of 52 Fig. 28 Magnetic Imaging Defectoscope within Interval 6,100 – 6,400 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 43 of 52 Fig. 29 Magnetic Imaging Defectoscope within Interval 6,400 – 6,700 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 44 of 52 Fig. 30 Magnetic Imaging Defectoscope within Interval 6,700 – 7,000 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness 7” casing 3 1/2” tubing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 45 of 52 ATTACHMENTS Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 46 of 52 ATTACHMENT 1 SEQUENCE OF EVENTS Well 1A-02 Completion Single Completion Injector Oil field Kuparuk Date 2014/10/23 State Well is shut-in Survey MID survey The MID (Magnetic Imaging Defectoscope) was recorded with TGT memory tools by PDS on an HLS-760 unit. Date Time Start of interval, ft End of Interval, ft Logging speed, ft/min Las Name Event 23 -Oc t -14 MID Survey 07:00 Travel 08:30 Arrive - On Location 08:40 Safety Meeting 09:02 Program tool 09:25 Stab on Lubricator - Run 1 09:30 0 7460 150 RIH 10:19 7460 7460 Stopped at 7460 Slickline depth (38 Ft RKB) 10:24 7460 0 16 S5U1 Log up @ 16 / fpm 18:34 Download depth file 18:39 Break Off Lubricator - Run 1 18:54 Download Tool 19:20 Travel 20:00 End Ticket Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 47 of 52 ATTACHMENT 2 WELL SCHEMATICS (Provided by Client) Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 48 of 52 ATTACHMENT 3 ABBREVIATIONS Nomenclature Description G/C Gauge cutter MID Magnetic imaging defectoscope HPT High precision temperature HUD Hold up depth POOH Pull out of hole R/D Rig down R/U Rig up RIH Run in hole RU Reservoir unit THP Tubing head pressure Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 49 of 52 ATTACHMENT 4 QUALITY CONTROL Logging speed while MID runs was 15±2 ft/min. Depth was correlated using well sketch provided by ConocoPhillips. 3 1/2" tubing thickness 7” casing thickness SSSV Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 50 of 52 SBR 3 1/2" tubing thickness 7” casing thickness GL Mandrel PACKER Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 51 of 52 ATTACHMENT 5 TGT MID LOGGING TOOL STRING SCHEMATIC Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 52 of 52 ATTACHMENT 6 DESCRIPTION OF LOGS Original logs A list of recorded logs is given below. Calculated profiles A list of all profiles derived from original logs is given below. LOG UNIT DESCRIPTION COMMENTS DEPTH ft Measured depth Calculated from RKB LSPD ft/min Cable speed SS RESPONSE mV Short sensor response 42 points of time response (0.1-75 ms) LS RESPONSE mV Long sensor response 51 points of time response (0.1-275 ms) LOG UNIT DESCRIPTION COMMENTS T1 inch 3 1/2” tubing thickness T2 inch 7” casing thickness NEAR DELTA V/V Near Zone Model Deviation 31 points of time response (0.75-56.2 ms) FAR DELTA V/V Far Zone Model Deviation 32 points of time response (2.37-206 ms) MID REPORT 1 A - 02 Sing le Completion Injector ConocoPhillips Alaska, Inc. Company: ConocoPhillips Alaska, Inc. Country: USA : Field: Kuparuk Logging Date: 23 – Oct – 2014 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 2 of 46 DATA RECORDED BY Dale Cain / Alexey Li ANALYST Alfiia Gabdrakhmanova REVIEWED BY Matthew Lawrence Interpretations made by TGT OILFIELD SERVICES at the request of ConocoPhillips are based on information provided to TGT OILFIELD SERVICES by ConocoPhillips. All conclusions and recommendations were produced using measurements and empirical relationships and assumptions. All representations and warranties, expressed or implied, in respect of this report are hereby excluded. TGT OILFIELD SERVICES cannot, except in the case of negligence on part of TGT OILFIELD SERVICES, be held liable or responsible for any losses, costs, damages or expenses which might be incurred by anyone in relation to the contents of this report. Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 3 of 46 CONTENTS 3 4 15 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 44 46 CONTENTS EXECUTIVE SUMMARY SURVEY RESULTS Fig. 1 Magnetic Imaging Defectoscope within Interval 30 – 300 ft Fig. 2 Magnetic Imaging Defectoscope within Interval 300 – 600 ft Fig. 3 Magnetic Imaging Defectoscope within Interval 600 – 900 ft Fig. 4 Magnetic Imaging Defectoscope within Interval 900 – 1,200 ft Fig. 5 Magnetic Imaging Defectoscope within Interval 1,200 – 1,500 ft Fig. 6 Magnetic Imaging Defectoscope within Interval 1,500 – 1,800 ft Fig. 7 Magnetic Imaging Defectoscope within Interval 1,800 – 2,100 ft Fig. 8 Magnetic Imaging Defectoscope within Interval 2,100 – 2,400 ft Fig. 9 Magnetic Imaging Defectoscope within Interval 2,400 – 2,700 ft Fig. 10 Magnetic Imaging Defectoscope within Interval 2,700 – 3,000 ft Fig. 11 Magnetic Imaging Defectoscope within Interval 3,000 – 3,300 ft Fig. 12 Magnetic Imaging Defectoscope within Interval 3,300 – 3,600 ft Fig. 13 Magnetic Imaging Defectoscope within Interval 3,600 – 3,900 ft Fig. 14 Magnetic Imaging Defectoscope within Interval 3,900 – 4,200 ft Fig. 15 Magnetic Imaging Defectoscope within Interval 4,200 – 4,500 ft Fig. 16 Magnetic Imaging Defectoscope within Interval 4,500 – 4,800 ft Fig. 17 Magnetic Imaging Defectoscope within Interval 4,800 – 5,100 ft Fig. 18 Magnetic Imaging Defectoscope within Interval 5,100 – 5,400 ft Fig. 19 Magnetic Imaging Defectoscope within Interval 5,450 – 5,600 ft Fig. 20 Magnetic Imaging Defectoscope within Interval 5,650 – 5,760 ft Fig. 21 Magnetic Imaging Defectoscope within Interval 6,100 – 6,400 ft Fig. 22 Magnetic Imaging Defectoscope within Interval 6,400 – 6,700 ft Fig. 23 Magnetic Imaging Defectoscope within Interval 6,700 – 7,000 ft ATTACHMENTS SEQUENCE OF EVENTS WELL SCHEMATICS (Provided by Client) ABBREVIATIONS QUALITY CONTROL TGT MID LOGGING TOOL STRING SCHEMATIC DESCRIPTION OF LOGS Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 4 of 46 EXECUTIVE SUMMARY OBJECTIVES To identify metal loss (corrosion) in the 3 1/2” tubing (first barrier) To identify metal loss (corrosion) in the 7” casing behind the 3 1/2” tubing – total metal content loss FINDINGS A Magnetic Imaging Defectoscope (MID) survey was run in 1A-02 to identify the metal loss* in the 3 1/2” tubing and in the 7” casing behind the 3 1/2” tubing. MID data indicates the 3 1/2” tubing and 7” casing appears to range from good to poor condition. Metal loss* from 5% to 45% is recorded in the tubing and from 5% to 35% in the casing. No 7” casing corrosion was detected at 3,030 ft, in the vicinity of a known casing leak. The absence of significant metal loss in this vicinity and the nearby casing collar at 3,025.5 ft. suggests the possibility of a collar leak. 3 1/2” TUBING MAXIMUM METAL LOSS EVENTS Joint Number Metal Loss (%) Depth Interval of Metal Loss (ft) What page in this report? Tabulation Log Plot 135 40-45 3,996.5 3,999.5 8 28 144 40-45 4,264.5 4,266 8 29 161 40-45 4,753.5 4,755 8 30 221 35-40 6,445 6,447.5 10 36 18 30-35 494 496 5 16 88 30-35 2,608 2,611.5 7 23 7” CASING MAXIMUM METAL LOSS EVENTS Joint Number Metal Loss (%) Depth Interval of Metal Loss (ft) What page in this report? Tabulation Log Plot 154 30-35 6,884.5 6,887 14 37 * - Metal loss is averaged circumferentially and along the tool’s sensor length, which is 5 in. for the tubing and 13 in. for the casing. Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 5 of 46 First Barrier: 3.5” Tubing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 1 27.7 57.0 good 2 57.0 62.8 good 3 62.8 77.2 good 4 77.2 80.1 good 5 80.1 111.3 corroded 89-91 10-15 6 111.3 141.5 good 7 141.5 170.5 corroded 154.5-157.5 10-15 8 170.5 201.0 good 9 201.0 231.5 corroded 202-204.5 225-228 20-25 10-15 10 231.5 261.0 good 11 261.0 291.0 corroded 276.5-278 5-10 12 291.0 321.0 good 13 321.0 350.5 good 14 350.5 378.5 good 15 378.5 409.0 corroded 393.5-395 5-10 16 409.0 439.0 good 17 439.0 469.0 corroded 445.5-447 15-20 18 469.0 497.0 corroded 470-472 494-496 25-30 30-35 19 497.0 526.5 good 20 526.5 554.5 corroded 529.5-532 20-25 21 554.5 585.0 good 22 585.0 612.5 corroded 587-591 602-603.5 10-15 10-15 23 612.5 641.5 corroded 627.5-629 10-15 24 641.5 672.0 good 25 672.0 702.5 corroded 675-677.5 15-20 26 702.5 732.0 corroded 708.5-711 10-15 27 732.0 763.5 good 28 763.5 795.0 corroded 773-774.5 790-791.5 15-20 10-15 29 795.0 826.5 good 30 826.5 857.5 corroded 851-852.5 10-15 31 857.5 888.5 good 32 888.5 919.5 good 33 919.5 951.5 good 34 951.5 982.0 good 35 982.0 1011.0 corroded 998-999 5-10 36 1011.0 1042.5 corroded 1033-1034.5 10-15 37 1042.5 1073.5 good 38 1073.5 1106.0 good 39 1106.0 1137.5 good 40 1137.5 1168.0 corroded 1150-1151 1163-1164 10-15 15-20 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 6 of 46 First Barrier: 3.5” Tubing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 41 1168.0 1198.5 corroded 1169-1171 1173-1175 1186.5-1188 1196.5-1198 15-20 5-10 5-10 15-20 42 1198.5 1231.0 good 43 1231.0 1263.0 good 44 1263.0 1292.5 corroded 1277.5-1279 1288-1290 20-25 20-25 45 1292.5 1324.5 corroded 1318.5-1321.5 15-20 46 1324.5 1355.5 corroded 1331-1334 10-15 47 1355.5 1385.0 corroded 1369-1370 1382-1383 5-10 20-25 48 1385.0 1415.0 good 49 1415.0 1446.0 corroded 1437-1438.5 1442-1443 5-10 5-10 50 1446.0 1476.5 corroded 1471.5-1473 20-25 51 1476.5 1506.0 corroded 1477.5-1479 1484-1485 10-15 10-15 52 1506.0 1535.5 good 53 1535.5 1565.0 corroded 1546-1547.5 15-20 54 1565.0 1594.5 corroded 1567.5-1572 10-15 55 1594.5 1626.5 good 56 1626.5 1657.0 good 57 1657.0 1688.0 good 58 1688.0 1719.0 good 59 1719.0 1749.0 good 60 1749.0 1779.0 corroded 1762-1764 20-25 61 1779.0 1809.1 good 62 1809.1 1821.4 good 63 1821.4 1854.5 good 64 1854.5 1885.5 good 65 1885.5 1916.0 good 66 1916.0 1947.5 corroded 1923-1923.5 5-10 67 1947.5 1979.0 corroded 1966-1968 15-20 68 1979.0 2010.0 corroded 1982-1984 5-10 69 2010.0 2042.5 good 70 2042.5 2072.5 good 71 2072.5 2101.5 good 72 2101.5 2133.0 good 73 2133.0 2163.0 corroded 2142-2144 2157-2160 10-15 10-15 74 2163.0 2190.5 corroded 2172-2173 10-15 75 2190.5 2221.5 corroded 2213-2216 10-15 76 2221.5 2250.5 good 77 2250.5 2280.5 good 78 2280.5 2309.5 good 79 2309.5 2341.0 good Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 7 of 46 First Barrier: 3.5” Tubing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 80 2341.0 2371.0 corroded 2364-2366 15-20 81 2371.0 2400.5 good 82 2400.5 2430.0 good 83 2430.0 2461.0 corroded 2456-2457.5 20-25 84 2461.0 2490.0 good 85 2490.0 2519.5 good 86 2519.5 2552.0 good 87 2552.0 2582.0 good 88 2582.0 2612.0 corroded 2596.5-2598.5 2608-2611.5 25-30 30-35 89 2612.0 2641.5 good 90 2641.5 2671.0 corroded 2644-2648 20-25 91 2671.0 2701.5 corroded 2695-2697.5 5-10 92 2701.5 2732.5 good 93 2732.5 2765.0 good 94 2765.0 2794.0 good 95 2794.0 2824.5 good 96 2824.5 2854.0 corroded 2829-2831 20-25 97 2854.0 2883.5 corroded 2860-2860.5 5-10 98 2883.5 2913.5 good 99 2913.5 2943.5 corroded 2935.5-2936.5 5-10 100 2943.5 2974.0 good 101 2974.0 3002.5 corroded 2987-2988.5 10-15 102 3002.5 3032.5 good 103 3032.5 3061.2 good 104 3061.2 3066.6 good 105 3066.6 3097.0 good 106 3097.0 3128.0 corroded 3099-3100 20-25 107 3128.0 3159.5 good 108 3159.5 3190.0 good 109 3190.0 3219.5 good 110 3219.5 3249.5 good 111 3249.5 3279.0 good 112 3279.0 3309.0 corroded 3288-3290 3301-3304.5 20-25 10-15 113 3309.0 3337.0 good 114 3337.0 3368.0 good 115 3368.0 3399.0 good 116 3399.0 3429.5 corroded 3409-3410 3422-3428 10-15 5-10 117 3429.5 3461.0 good 118 3461.0 3490.5 good 119 3490.5 3521.5 good 120 3521.5 3551.5 corroded 3531.5-3533 3544.5-3545.5 20-25 10-15 121 3551.5 3581.5 corroded 3577-3580 20-25 122 3581.5 3612.0 good Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 8 of 46 First Barrier: 3.5” Tubing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 123 3612.0 3642.5 good 124 3642.5 3672.5 good 125 3672.5 3703.5 good 126 3703.5 3735.0 good 127 3735.0 3765.5 good 128 3765.5 3794.0 corroded 3776-3777 3789-3790 3791.5-3792.5 20-25 15-20 10-15 129 3794.0 3825.0 good 130 3825.0 3855.5 good 131 3855.5 3884.0 good 132 3884.0 3912.5 corroded 3888-3890 20-25 133 3912.5 3942.0 good 134 3942.0 3972.5 good 135 3972.5 4002.0 corroded 3984.5-3985.5 3996.5-3999.5 20-25 40-45 136 4002.0 4030.5 good 137 4030.5 4060.0 corroded 4039.5-4040.5 4049.5-4050.5 4052-4053.5 20-25 10-15 5-10 138 4060.0 4091.0 good 139 4091.0 4121.0 good 140 4121.0 4151.0 good 141 4151.0 4181.0 good 142 4181.0 4210.0 corroded 4190.5-4191.5 15-20 143 4210.0 4240.0 corroded 4213-4214 15-20 144 4240.0 4269.5 corroded 4264.5-4266 40-45 145 4269.5 4299.0 corroded 4273.5-4275.5 20-25 146 4299.0 4329.5 corroded 4305-4306.5 20-25 147 4329.5 4362.0 corroded 4344-4345 4355.5-4358 5-10 15-20 148 4362.0 4391.5 good 149 4391.5 4423.0 good 150 4423.0 4453.0 good 151 4453.0 4458.4 good 152 4458.4 4488.0 good 153 4488.0 4517.5 good 154 4517.5 4547.5 good 155 4547.5 4578.0 good 156 4578.0 4609.5 good 157 4609.5 4639.5 corroded 4619-4620 10-15 158 4639.5 4669.5 good 159 4669.5 4698.5 good 160 4698.5 4729.0 good 161 4729.0 4758.5 corroded 4753.5-4755 40-45 162 4758.5 4789.0 good 163 4789.0 4819.5 good Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 9 of 46 First Barrier: 3.5” Tubing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 164 4819.5 4848.0 good 165 4848.0 4876.5 good 166 4876.5 4882.5 good 167 4882.5 4913.5 good 168 4913.5 4944.0 good 169 4944.0 4974.5 good 170 4974.5 5005.0 good 171 5005.0 5034.0 good 172 5034.0 5063.5 corroded 5059.5-5062 15-20 173 5063.5 5091.5 good 174 5091.5 5123.0 good 175 5123.0 5154.0 corroded 5150-5152.5 5-10 176 5154.0 5183.0 good 177 5183.0 5213.5 good 178 5213.5 5243.6 good 179 5243.6 5249.5 good 180 5249.5 5281.0 good 181 5281.0 5310.5 good 182 5310.5 5341.0 corroded 5334-5336 5-10 183 5341.0 5372.0 good 184 5372.0 5403.5 corroded 5387.5-5389 15-20 185 5403.5 5432.5 good 186 5432.5 5463.0 good 187 5463.0 5492.5 good 188 5492.5 5522.0 corroded 5496.5-5497 10-15 189 5522.0 5552.5 good 190 5552.5 5582.5 good 191 5582.5 5614.0 good 192 5614.0 5619.4 good 193 5619.4 5652.0 good 194 5652.0 5683.0 good 195 5683.0 5714.0 corroded 5708-5709 5-10 196 5714.0 5745.5 good 197 5745.5 5773.5 good 198 5773.5 5804.0 good 199 5804.0 5834.0 good 200 5834.0 5863.5 good 201 5863.5 5892.5 good 202 5892.5 5921.5 good 203 5921.5 5952.5 good 204 5952.5 5982.4 good 205 5982.4 5988.6 good 206 5988.6 6019.5 good 207 6019.5 6049.5 good 208 6049.5 6080.0 good 209 6080.0 6110.5 good 210 6110.5 6141.5 good 211 6141.5 6172.0 good Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 10 of 46 First Barrier: 3.5” Tubing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 212 6172.0 6201.0 corroded 6194.5-6198 20-25 213 6201.0 6232.5 good 214 6232.5 6263.5 good 215 6263.5 6294.1 good 216 6294.1 6301.0 good 217 6301.0 6331.5 good 218 6331.5 6361.0 good 219 6361.0 6391.0 good 220 6391.0 6421.5 good 221 6421.5 6450.0 corroded 6445-6447.5 35-40 222 6450.0 6479.5 corroded 6466-6467.5 20-25 223 6479.5 6509.5 good 224 6509.5 6541.0 good 225 6541.0 6572.5 corroded 6543.5-6548 10-15 226 6572.5 6600.5 good 227 6600.5 6629.5 good 228 6629.5 6658.8 good 229 6658.8 6669.9 good 230 6669.9 6701.0 good 231 6701.0 6731.5 good 232 6731.5 6760.5 good 233 6760.5 6792.0 good 234 6792.0 6822.0 good 235 6822.0 6851.0 corroded 6835.5-6837 15-20 236 6851.0 6883.0 good 237 6883.0 6913.0 good 238 6913.0 6943.5 good 239 6943.5 6971.0 good 240 6971.0 7001.5 good 241 7001.5 7029.7 good 242 7029.7 7039.9 good 243 7039.9 7070.5 good 244 7070.5 7099.5 good 245 7099.5 7129.0 good 246 7129.0 7159.5 good 247 7159.5 7190.0 good 248 7190.0 7220.5 good 249 7220.5 7250.5 good 250 7250.5 7280.5 good 251 7280.5 7310.0 good 252 7310.0 7340.5 good 253 7340.5 7371.5 good 254 7371.5 7400.9 good 255 7400.9 7409.6 good 256 7409.6 7440.5 good Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 11 of 46 Second Barrier: 7” Casing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 1 27.9 69.8 good 2 69.8 111.7 good 3 111.7 154.0 good 4 154.0 195.5 good 5 195.5 234.0 good 6 234.0 274.0 good 7 274.0 316.5 good 8 316.5 358.5 good 9 358.5 400.5 good 10 400.5 441.1 good 11 441.1 485.8 good 12 485.8 523.0 good 13 523.0 565.0 good 14 565.0 608.5 good 15 608.5 647.0 good 16 647.0 688.0 good 17 688.0 727.0 good 18 727.0 766.0 good 19 766.0 806.6 corroded 773.5-774.5 788.5-789.5 5-10 5-10 20 806.6 850.0 good 21 850.0 891.5 good 22 891.5 930.0 good 23 930.0 972.0 good 24 972.0 1014.5 corroded 998-999 5-10 25 1014.5 1057.0 good 26 1057.0 1099.0 corroded 1060-1062 10-15 27 1099.0 1142.0 good 28 1142.0 1186.5 good 29 1186.5 1228.5 good 30 1228.5 1271.5 corroded 31 1271.5 1310.5 good 32 1310.5 1352.0 good 33 1352.0 1391.5 corroded 1382-1383 5-10 34 1391.5 1431.5 good 35 1431.5 1471.5 good 36 1471.5 1516.5 corroded 1478.5-1479.5 15-20 37 1516.5 1557.0 good 38 1557.0 1599.5 good 39 1599.5 1640.0 good 40 1640.0 1682.5 good 41 1682.5 1722.5 good Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 12 of 46 Second Barrier: 7” Casing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 42 1722.5 1762.5 good 43 1762.5 1804.1 good 44 1804.1 1846.0 good 45 1846.0 1888.7 good 46 1888.7 1931.0 good 47 1931.0 1970.0 good 48 1970.0 2012.5 good 49 2012.5 2052.5 good 50 2052.5 2097.5 good 51 2097.5 2146.0 good 52 2146.0 2193.0 good 53 2193.0 2240.5 good 54 2240.5 2286.5 good 55 2286.5 2333.0 good 56 2333.0 2380.0 good 57 2380.0 2426.0 good 58 2426.0 2474.0 good 59 2474.0 2522.0 good 60 2522.0 2568.5 good 61 2568.5 2614.5 good 62 2614.5 2660.0 good 63 2660.0 2705.0 good 64 2705.0 2750.4 good 65 2750.4 2798.0 good 66 2798.0 2844.5 good 67 2844.5 2892.0 good 68 2892.0 2928.5 good 69 2928.5 2976.5 good 70 2976.5 3025.5 good 71 3025.5 3074.0 good 72 3074.0 3109.0 good 73 3109.0 3156.0 corroded 3129.5-3131 15-20 74 3156.0 3203.0 good 75 3203.0 3249.7 good 76 3249.7 3297.5 good 77 3297.5 3343.5 good 78 3343.5 3387.0 good 79 3387.0 3434.0 good 80 3434.0 3481.5 good 81 3481.5 3529.0 good 82 3529.0 3576.0 good 83 3576.0 3622.0 good 84 3622.0 3669.0 good Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 13 of 46 Second Barrier: 7” Casing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 85 3669.0 3715.5 good 86 3715.5 3758.5 corroded 3729.5-3734 5-10 87 3758.5 3804.5 good 88 3804.5 3850.5 good 89 3850.5 3898.0 good 90 3898.0 3945.0 good 91 3945.0 3991.5 good 92 3991.5 4033.0 good 93 4033.0 4079.5 good 94 4079.5 4127.5 good 95 4127.5 4174.5 good 96 4174.5 4221.0 good 97 4221.0 4269.5 good 98 4269.5 4316.5 good 99 4316.5 4363.5 good 100 4363.5 4410.0 good 101 4410.0 4457.2 good 102 4457.2 4504.8 good 103 4504.8 4552.5 good 104 4552.5 4591.9 good 105 4591.9 4634.5 good 106 4634.5 4680.5 good 107 4680.5 4726.0 good 108 4726.0 4771.5 good 109 4771.5 4813.6 corroded 4796.5-4798 10-15 110 4813.6 4859.5 corroded 4815-4818 15-20 111 4859.5 4907.5 good 112 4907.5 4954.5 good 113 4954.5 5002.0 good 114 5002.0 5046.5 corroded 5031-5032 10-15 115 5046.5 5094.0 good 116 5094.0 5140.5 good 117 5140.5 5187.5 good 118 5187.5 5234.6 good 119 5234.6 5278.5 good 120 5278.5 5326.1 good 121 5326.1 5372.1 corroded 5343-5344 10-15 122 5372.1 5419.4 good 123 5419.4 5467.0 good 124 5467.0 5513.5 good 125 5513.5 5559.0 good 126 5559.0 5605.0 good 127 5605.0 5649.0 good Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 14 of 46 Second Barrier: 7” Casing Joint Tabulation Report Joint Number Top (ft) Bottom (ft) Condition Interval of corrosion (ft) Metal loss* (%) 128 5649.0 5696.5 good 129 5696.5 5743.0 good 130 5743.0 5790.2 good 131 5790.2 5837.5 good 132 5837.5 5885.0 good 133 5885.0 5932.5 good 134 5932.5 5979.6 good 135 5979.6 6024.3 good 136 6024.3 6071.5 good 137 6071.5 6117.9 good 138 6117.9 6165.5 good 139 6165.5 6212.8 good 140 6212.8 6260.0 good 141 6260.0 6307.5 good 142 6307.5 6354.5 good 143 6354.5 6402.0 good 144 6402.0 6439.5 good 145 6439.5 6487.0 good 146 6487.0 6534.0 good 147 6534.0 6581.2 good 148 6581.2 6627.0 good 149 6627.0 6673.6 good 150 6673.6 6719.5 good 151 6719.5 6766.4 good 152 6766.4 6813.6 corroded 6793.5-6797 10-15 153 6813.6 6859.0 good 154 6859.0 6905.0 corroded 6884.5-6887 30-35 155 6905.0 6952.5 good 156 6952.5 6994.0 good 157 6994.0 7040.4 good 158 7040.4 7087.0 good 159 7087.0 7133.6 good 160 7133.6 7180.5 good 161 7180.5 7228.0 good 162 7228.0 7275.5 good 163 7275.5 7322.1 good 164 7322.1 7368.5 good 165 7368.5 7414.5 good 166 7414.5 7463.0 good Note: According to MID survey 10 3/4" casing shoe was detected at 2904 ft. * - Metal loss is averaged circumferentially and along the tool’s sensor length, which is 5 in. for tubing and 13 in. for casing. Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 15 of 46 SURVEY RESULTS Fig. 1 Magnetic Imaging Defectoscope within Interval 30 – 300 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing thickness 7” casing thickness Tubing corrosion line Tubing corrosion line Casing corrosion line 3 1/2” tubing 7” casing Tubing collars Casing collars Tubing corrosion Tubing corrosion Tubing corrosion Tubing corrosion Tubing corrosion Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 16 of 46 Fig. 2 Magnetic Imaging Defectoscope within Interval 300 – 600 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 17 of 46 Fig. 3 Magnetic Imaging Defectoscope within Interval 600 – 900 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 18 of 46 Fig. 4 Magnetic Imaging Defectoscope within Interval 900 – 1200 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 19 of 46 Fig. 5 Magnetic Imaging Defectoscope within Interval 1200 – 1500 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 20 of 46 Fig. 6 Magnetic Imaging Defectoscope within Interval 1500 – 1800 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 21 of 46 Fig. 7 Magnetic Imaging Defectoscope within Interval 1800 – 2100 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 22 of 46 Fig. 8 Magnetic Imaging Defectoscope within Interval 2100 – 2400 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 23 of 46 Fig. 9 Magnetic Imaging Defectoscope within Interval 2400 – 2700 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 24 of 46 Fig. 10 Magnetic Imaging Defectoscope within Interval 2700 – 3000 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 25 of 46 Fig. 11 Magnetic Imaging Defectoscope within Interval 3000 – 3300 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 26 of 46 Fig. 12 Magnetic Imaging Defectoscope within Interval 3300 – 3600 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 27 of 46 Fig. 13 Magnetic Imaging Defectoscope within Interval 3600 – 3900 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 28 of 46 Fig. 14 Magnetic Imaging Defectoscope within Interval 3900 – 4200 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 29 of 46 Fig. 15 Magnetic Imaging Defectoscope within Interval 4200 – 4500 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 30 of 46 Fig. 16 Magnetic Imaging Defectoscope within Interval 4500 – 4800 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 31 of 46 Fig. 17 Magnetic Imaging Defectoscope within Interval 4800 – 5100 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 32 of 46 Fig. 18 Magnetic Imaging Defectoscope within Interval 5100 – 5400 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 33 of 46 Fig. 19 Magnetic Imaging Defectoscope within Interval 5450 – 5600 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 34 of 46 Fig. 20 Magnetic Imaging Defectoscope within Interval 5650 – 5760 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 35 of 46 Fig. 21 Magnetic Imaging Defectoscope within Interval 6100 – 6400 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 36 of 46 Fig. 22 Magnetic Imaging Defectoscope within Interval 6400 – 6700 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” Tubing 7” Casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 37 of 46 Fig. 23 Magnetic Imaging Defectoscope within Interval 6700 – 7000 ft Field Well Completion : Kuparuk : 1A-02 : Single Completion Injector Date of survey Date of interpretation Survey Depths : 10/23/2014 : 10/28/2014 : MID logging : measured from RKB 3 1/2” tubing 7” casing Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 38 of 46 ATTACHMENTS Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 39 of 46 ATTACHMENT 1 SEQUENCE OF EVENTS Well 1A-02 Completion Single Completion Injector Oil field Kuparuk Date 2014/10/23 State Well is shut-in Survey MID survey The MID (Magnetic Imaging Defectoscope) was recorded with TGT memory tools by PDS on an HLS-760 unit. Date Time Start of interval, ft End of Interval, ft Logging speed, ft/min Las Name Event 23 -Oc t -14 MID Survey 07:00 Travel 08:30 Arrive - On Location 08:40 Safety Meeting 09:02 Program tool 09:25 Stab on Lubricator - Run 1 09:30 0 7460 150 RIH 10:19 7460 7460 Stopped at 7460 Slickline depth (38 Ft RKB) 10:24 7460 0 16 S5U1 Log up @ 16 / fpm 18:34 Download depth file 18:39 Break Off Lubricator - Run 1 18:54 Download Tool 19:20 Travel 20:00 End Ticket Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 40 of 46 ATTACHMENT 2 WELL SCHEMATICS (Provided by Client) Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 41 of 46 ATTACHMENT 3 ABBREVIATIONS Nomenclature Description G/C Gauge cutter MID Magnetic imaging defectoscope HPT High precision temperature HUD Hold up depth POOH Pull out of hole R/D Rig down R/U Rig up RIH Run in hole RU Reservoir unit THP Tubing head pressure Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 42 of 46 ATTACHMENT 4 QUALITY CONTROL Logging speed while MID runs was 15±2 ft/min. Depth was correlated using well sketch provided by ConocoPhillips. 3 1/2" tubing 7” casing SSSV Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 43 of 46 SBR 3 1/2" tubing 7” casing GL Mandrel PACKER Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 44 of 46 ATTACHMENT 5 TGT MID LOGGING TOOL STRING SCHEMATIC Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 45 of 46 Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 1A-02 1st Barrier: 3.5” 9.2# J-55 Tubing Log Date: 2014-Oct-25 2nd Barrier: 7” 26# K-55 Casing Page 46 of 46 ATTACHMENT 6 DESCRIPTION OF LOGS Original logs A list of recorded logs is given below. Calculated profiles A list of all profiles derived from original logs is given below. LOG UNIT DESCRIPTION COMMENTS DEPTH ft Measured depth Calculated from RKB LSPD ft/min Cable speed TEMP °F Temperature SS RESPONSE mV Short sensor response 42 points of time response (0.1-75 ms) LS RESPONSE mV Long sensor response 51 points of time response (0.1-275 ms) LOG UNIT DESCRIPTION COMMENTS T1 inch 3 1/2” tubing thickness T2 inch 7” casing thickness NEAR DELTA frac Near Zone Model Deviation 31 points of tie response (0.75-56.2 ms) FAR DELTA frac Far Zone Model Deviation 32 points of tie response (2.37-206 ms)
