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199-077
By Grace Christianson at 8:01 am, Jun 09, 2023 X 10-404 VTL 4/13/23 BOP test to 4000 psig Annular preventer test to 2500 psig X MDG 4/7/2023 DSR-4/6/23GCW 04/13/23JLC 4/13/2023 04/13/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.13 15:05:57 -08'00' RBDMS JSB 041423 Originated:Delivered to:8-Dec-21HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAMEJOB TYPEDATA TYPE LOGGING DATE PRINTS #DIGITAL #1 3F-13A 50-029-21499-01 907473188 Kuparuk River Leak Detect Log Revised 28-Oct-21 0 12 3F-13A 50-029-21499-01 907473188 Kuparuk River Plug Setting Record Revised 28-Oct-21 0 1345678910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:12/08/2021Wd͗ϭϵϵϬϳϳϬ Ͳ^Ğƚ͗ϯϲϬϳϭBy Abby Bell at 3:21 pm, Dec 08, 2021Data and Transmittal Re-Submittal from 11/23/2021 Originated:Delivered to:8-Dec-21HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAMEJOB TYPEDATA TYPE LOGGING DATE PRINTS #DIGITAL #1 3F-13A 50-029-21499-01 907473188 Kuparuk River Leak Detect Log Revised 28-Oct-21 0 12 3F-13A 50-029-21499-01 907473188 Kuparuk River Plug Setting Record Revised 28-Oct-21 0 1345678910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:12/08/2021Wd͗ϭϵϵϬϳϳϬ Ͳ^Ğƚ͗ϯϲϬϳϮBy Abby Bell at 3:21 pm, Dec 08, 2021Data and Transmittal Re-Submittal from 11/23/2021 C:\Users\aebell\Desktop\December 2021 Data Drop\CPAI Data Drop 12082021\2021-12-03_20188_3F-13A_CaliperSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 20188 KRU 3F-13A 50-029-21499-01 Caliper Survey 03-Dec-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM 37' (6HW ___________________________________________ Signatururuuruuuuruuuuuruuuuuuruuuuuuuuuue Abby Bell By Abby Bell at 9:47 am, Dec 08, 2021 C:\Users\aebell\Desktop\December 2021 Data Drop\CPAI Data Drop 12072021\2021-12-02_14494_3F-13A_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 14494 KRU 3F-13A 50-029-21499-01 LeakPoint Survey 02-Dec-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM 37' (6HW _______________________________________________ Signattttttttttttturuuuuuruuuuruuuuuuuuuuuuuuuuuuuue Abby Bell By Abby Bell at 10:27 am, Dec 07, 2021 From:Well Integrity Specialist CPF1 & CPF3 To:Loepp, Victoria T (OGC) Cc:Earhart, Will C Subject:KRU 3F-13A (PTD 199-077) Report of OA Sustained Casing Pressure Date:Monday, October 25, 2021 12:12:45 PM Attachments:3F-13A.pdf 3F-13A 90 day TIO trend 10.25.21.pdf Victoria, Yesterday Coil tubing was performing a FCO on 3F-13A (PTD 199-077) and after breaking through a solids bridge at 6575’ the tubing, IA, and OA pressure started rising. The OA pressure stabilized at 1225 psi. The 7”, 26 lb/ft, J-55 casing has a burst rating of 4980 psi (45% of the burst rating is 2241 psi). CPAI intends to leave the OA pressure as is while diagnostics are being progressed. The immediate plan is for Coil tubing to finish the FCO and then diagnostics will be performed with Slickline and Eline as needed to locate and repair the leak source. A wellbore schematic and 90 day TIO trend are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 Annular Communication Surveillance 27-Jul-2021Well Name:3F-13 Start Date:27-Jul-2021 25-Oct-2021Days:90 End Date:25-Oct-2021 50 60 70 80 90 100 110 120 130 140 150 0 200 400 600 800 1000 1200 1400 1600 27-Jul-2130-Jul-212-Aug-215-Aug-218-Aug-2111-Aug-2114-Aug-2117-Aug-2120-Aug-2123-Aug-2126-Aug-2129-Aug-211-Sep-214-Sep-217-Sep-2110-Sep-2113-Sep-2116-Sep-2119-Sep-2122-Sep-2125-Sep-2128-Sep-211-Oct-214-Oct-217-Oct-2110-Oct-2113-Oct-2116-Oct-2119-Oct-2122-Oct-2125-Oct-21Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1 27-Jul-21Injection Rate (BPD or MSCFD)Injection Rate Summary DGI MGI PWI SWI BLPD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Tagged Mud) 6,420.0 10/15/2021 3F-13A zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag Depth 10/15/2021 3F-13A zembaej Casing Strings Casing Description WINDOW A OD (in) 7 ID (in) 5.00 Top (ftKB) 6,626.0 Set Depth (ftKB) 6,636.0 Set Depth (TVD) … 5,263.9 Wt/Len (l… 26.00 Grade L-80 Top Thread Casing Description TIE-BACK LINER 2012 OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 24.5 Set Depth (ftKB) 5,551.0 Set Depth (TVD) … 4,436.1 Wt/Len (l… 15.50 Grade L-80 Top Thread H511 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 5,539.0 4,427.2 41.98 XO Reducing CROSSOVER 5-1/2 H511 BOX X 5 BTC PIN 5.000 5,540.5 4,428.3 41.98 LOCATOR LOCATOR 4.860 5,541.5 4,429.0 41.97 SEAL ASSY BAKER TIE-BACK STEM ( 4.25" ID X 5.25" OD) 5" BTCM BOX X MULESHOE 4.250 Casing Description STRADDLE ASSY 2012 OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 5,544.4 Set Depth (ftKB) 6,500.2 Set Depth (TVD) … 5,160.5 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Casing Description LINER 1999 OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 6,485.8 Set Depth (ftKB) 9,350.0 Set Depth (TVD) … 6,204.6 Wt/Len (l… 9.30 Grade L-80 Top Thread EUE8RDMO D Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,485.8 5,149.5 40.09 PACKER BAKER ZXP MECH ISOLATION PACKER w/TIEBACK RECEPTACLE 5.250 6,503.5 5,163.0 40.22 HANGER HMC HYDRAULIC HANGER 3.500 6,511.0 5,168.8 40.25 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 8,550.8 5,873.2 68.23 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,571.9 5,881.1 67.81 NIPPLE HALLIBURTON POLISH NIPPLE 2.750 Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 23.5 Set Depth (ft… 5,588.4 Set Depth (TVD) (… 4,463.9 Wt (lb/ft) 9.30 Grade L-80 Top Connection IBT-M Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.5 23.5 0.03 HANGER FMC GEN III TUBING HANGER 3.500 489.2 489.2 0.44 NIPPLE CAMCO DS NIPPLE, SN: T061242 2.875 5,492.2 4,392.4 42.14 NIPPLE CAMCO D NIPPLE, SN: T061007 2.812 5,531.8 4,421.8 42.01 LOCATOR BAKER LOCATOR 2.970 5,532.3 4,422.1 42.00 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY 3.010 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,865.0 5,428.1 54.71 CEMENT PUMPED 12 BARRELS OF 15.8 PPG NEAT CLASS G CEMENT 7/2/2012 2.992 8,904.0 6,013.8 65.66 FISH 13" OF JD SPRING DOWNHOLE, CEMENT RETAINER REMNATS 7/5/2012 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,553.0 8,570.0 5,874.0 5,880.4 C-4, 3F-13A 4/22/2000 4.0 APERF 2.5" HC-DP, 180 deg ph, +/- 90 deg orient 9,070.0 9,100.0 6,083.6 6,096.4 A-2, 3F-13 9/20/1999 4.0 IPERF 2.5" HC; 180 deg ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,823.0 2,504.5 47.85 CAMCO KBG-2- 9 1 GAS LIFT GLV INT 0.156 1,206.0 9/17/2021 2 4,082.8 3,364.6 46.65 CAMCO KBG-2- 9 1 GAS LIFT OV INT 0.156 0.0 9/17/2021 3 4,945.6 3,990.9 43.00 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 9/17/2021 4 5,439.5 4,353.4 42.34 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 9/16/2021 Notes: General & Safety End Date Annotation 11/5/2010 NOTE: View Schematic w/ Alaska Schematic9.0 10/12/2005 NOTE: LEAK FOUND @ UPPER PACKER @ 5678' 9/3/1999 NOTE: WELL SIDETRACKED 'A' 3F-13A, 10/16/2021 7:29:35 AM Vertical schematic (actual) LINER 1999; 6,485.8-9,350.0 IPERF; 9,070.0-9,100.0 FISH; 8,904.0 APERF; 8,553.0-8,570.0 PRODUCTION; 35.0-8,050.0 CEMENT; 6,865.0 ftKB CEMENT; 6,865.0 WINDOW A; 6,626.0-6,636.0 STRADDLE ASSY 2012; 5,544.3-6,500.2 SEAL ASSY; 5,532.3 TIE-BACK LINER 2012; 24.5- 5,551.0 LOCATOR; 5,531.8 NIPPLE; 5,492.2 GAS LIFT; 5,439.5 GAS LIFT; 4,945.6 GAS LIFT; 4,082.8 SURFACE; 37.0-3,651.6 GAS LIFT; 2,823.0 NIPPLE; 489.2 CONDUCTOR; 38.0-112.0 HANGER; 23.5 KUP PROD KB-Grd (ft) 41.88 Rig Release Date 12/20/1985 3F-13A ... TD Act Btm (ftKB) 9,350.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292149901 Wellbore Status PROD Max Angle & MD Incl (°) 78.82 MD (ftKB) 7,158.60 WELLNAME WELLBORE3F-13A Annotation Last WO: End Date 7/31/2012 H2S (ppm) DateComment SSSV: NIPPLE r . STATE OF ALASKA A OIL AND GAS CONSERVATION COM•SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon j Repair w ell 17 Plug Perforations r Perforate r Other r Alter Casing 17 Pull Tubing 17 Stimulate - Frac r Waiver r Time Extension Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r' Exploratory r " 199 - 077 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50- 029- 21499 -01 vOci 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25632 0 3F -13A 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: Total Depth measured 9350 feet Plugs (measured) 6550', 8551' true vertical 6205 feet Junk (measured) 8904 Effective Depth measured 9254 feet Packer (measured) 5544', 6486' true vertical 6161 feet (true vertucal) 4431', 5150' Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 112 112 SURFACE 3615 9.625 3652 3065 PRODUCTION 8015 7 6635 5264 TIE BACK LINER 5527 5.5 5552 4437 ISOLATION STRING 947 4.5 6500 5160 RECEIVED LINER 2865 3.5 9350 6204 AUG 2 2 2012 Perforation depth: Measured depth: 8553' 8570', 9070' - 9100' True Vertical Depth: 5874' 5880', 6084' - 6096' AOG Tubing (size, grade, MD, and TVD) 3.5, L - 80, 5588 MD, 4464 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER C -2 ZXP LINER TOP PACKER @ 5544 MD and 4431 TVD PACKER - BAKER ZXP MECH ISOLATION PACKER @ 6486 MD and 5150 TVD SSSV - CAMCO DS NIPPLE @ 489 MD and 489 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - . Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development f -, Service r Stratigraphic r 16. Well Status after work: r Oil r Gas r WDSPL r Daily Report of Well Operations _XXXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 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: 312 -167 Contact Brett Packer @ 265 -6845 Printed Name Brett Packer Title Sr. Wells Engineer Signature �vVV ` -- C-/ Phone: 265 -6845 Date 8+`z / /`2 g. 23. / Form 10-404 Revised 11/2011 RBDMS AUG 2 3 201 1. ` s ubmit Original Only 1 41 8 KUP • 3F -13A Conoc g Well Attributes Max Angle & MD TD HX: Welibore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) Alaska, 500292149901 KUPARUK RIVER UNIT PROD 78.82 7,158.60 9,350.0 • ' Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV: NIPPLE 70 12/22/2004 Last WO: 7/31/2012 41.88 12/20/1985 Well Config - 3F -13A, 8/21/20129'49'03 AM Schematic Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: RKB 8,918.0 6/12/2012 Rev Reason: REVISE FISH ninam 8/21/2012 �.� Casing Strings HANGER, 23 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd CONDUCTOR 16 15.062 38.0 112.0 112.0 62.58 H - 40 WELDED _ Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 37.0 3,651.6 3,065.0 36.00 J - 55 BUTT Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 35.0 8,050.0 5,735.7 26.00 J - 55 BTC Casing Description Stri. ' • ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd r WINDOW : 5_,,_.000 6,626.0 6,636.0 5,263.9 26.00 L - 80 asing Description String 0... String ID ... T.1• (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd TIE - BACK LINER 5 1/2 4.950 24.5 5,551.0 4,436.1 15.50 L - 80 H511 CONDUCTOR, j 38 -112 I Liner Details _ -- fop Depth (TVD) Top Ind Nomi... NIPPLE. 489 i ( Top (ftKB) (ftKB) (°) Item Description Comment ID (in) l 5,539.0 4,427.2 41.98 XO Reducing CROSSOVER 5-1/2 H511 BOX X 5 BTC PIN 5.000 l 5,540.5 4,428.3 41.98 LOCATOR LOCATOR 4.860 I GAS LIFT, . - , 5,541.5 4,429.1 41.97 SEAL ASSY BAKER TIE -BACK STEM ( 4.25" ID X 5.25" OD) 5" BTCM BOX X 4250 e e z 2,623 MULESHOE 5 1 Casing Description String 0... String ID ... Top (5103) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd STRADDLE ASSY 41/2 3.958 5,544.4 6,500.2 5,160.5 12.60 L - 80 IBTM Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 31/2 2.992 6,485.8 9,350.0 6,204.6 9.30 L -80 EUE8RDMOD SURF L Liner Details ACE, To Depth 37 - 3,852 (TVD) Top Inc! Nomi... - -� Top (ftKB) (ftKB) ID Item Description Comment ID (!n) GAS LIFr, I 1 6,485.8 5,149.5 40.16 PACKER BAKER ZXP MECH ISOLATION PACKER w/TIEBACK RECEPTACLE 5.250 4,063 6,503.5 5,163.0 40.22 HANGER HMC HYDRAULIC HANGER 3.500 6,511.0 5,168.8 40.25 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 8,550.8 5,872.9 67.35 NIPPLE CAMCO D NIPPLE NO GO 2.750 GAS L I 6 _ _ 8,571.9 5,881.0 67.22 NIPPLE HALLIBURTON POLISH NIPPLE 2.750 .. Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String .. String Top Thrd TUBING I 3 1/2 I 2.992 I 23.5 I 5,588.4 4,463.9 I 9.30 L IBT - M GAS LIFT. 5,440 P 's Completion Details Top Depth 1.11 1 (TVD) Top Inc] Nomi... ME Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 23.5 23.5 0.00 HANGER FMC GEN III TUBING HANGER 3.500 NIPPLE, 5,492 LW ` MB 489.2 4892 0.45 NIPPLE CAMCO DS NIPPLE, SN: T061242 2.875 IMF 5,4922 4,392.4 42.14 NIPPLE CAMCO D NIPPLE, SN: T061007 Z812 ir LOCATOR, 5,531.8 4,421.8 42.01 LOCATOR BAKER LOCATOR 2.970 5.532 5,532.3 4,422.2 42.00 SEAL ASSY BAKER 80-40 GBH -22 SEAL ASSEMBLY 3.010 Illi• Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth TIE -BAC (TVD) Top 18cl LINER, - w Top (fIKB) (ftKB) (°) Description Comment Run Date ID (In) SEAL ASS Y, 255,S 6,550 5,198.5 40.39 WRP 2.69 " WRP 7/10/2012 0.000 /, 5,532 6,865 5,428.1 54.69 CEMENT PUMPED 12 BARRELS OF 15.8 PPG NEAT CLASS G 7/2/2012 2.992 , t CEMENT SW 8,551 5,872.9 67.35 PLUG 2.75" CA -2 PLUG 7/9/2012 0.000 8,904 6,013.8 65.66 FISH 13" OF JD SPRING DOWNHOLE, CEMENT RETAINER 7/5/2012 0.000 / REMNATS Perforations & Slots 01 , - Shot Top (TVD) Btm (TVD) Dens NMI Top (ftKB) 8101 (ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment STRADDLE ' ® 8,553 8,570 5,873.8 5,880.2 C 3F - 13A 4/22/2000 4.0 APERF 2.5" HC - DP, 180 deg ph, +/ 90 deg :S. - ASSY, l"1 orient 5,544.6,500 9,070 9,100 6,083.6 6,096.4 A -2, 3F -13 9/20/1999 4.0 IPERF 2.5" HC; 180 deg ph Notes: General & Safety End Date Annotation 9/3/1999 NOTE: WELL SIDETRACKED 'A' WRP, 6,550 iMI 7/16/2005 NOTE: 2 SLIPS FROM ECLIPSE PACKER LOST DOWNHOLE WINDOW A, - 10/12/2005 NOTE: LEAK FOUND @ UPPER PACKER @ 5678' 6,626 11/5/2010 NOTE: View Schematic w/ Alaska Schematic9.0 CEMENT, 3Mt 7 6,865 PRODUCTION, + db. Mandrel Details 35 -8,050 Top Depth Top Port PLUG, 8,551 (TVD) Intl OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (°) Make Model (in) SerV Type Type 0n) (psi) Run Date Com... APERF, 1 2,823.0 2,504.6 48.07 CAMCO KBG - 2 - 9 1 GAS LIFT DMY DK - 1 0.000 0.0 7/30/2012 8,553 2 4,082.8 3,364.6 46.76 CAMCO KBG -2 -9 1 GAS LIFT DMY DK -1 0.000 0.0 7/30/2012 1 3 4,945.6 3,990.9 43,00 CAMCO KBG -2 -9 1 GAS LIFT DMY DK -1 0.000 0.0 7/30/2012 FISH, 8,904 4 5,439.5 4,353.4 42.31 CAMCO KBG -2 -9 1 GAS LIFT SOV ' DK -3 0.000 0.0 7/30/2012 IPERF, 9,070 -9,100 LINER, 6,486 -9,350 TD (3F -13A), • • 9,350 3F -13A Pre -Rig Well Work Summary DATE SUMMARY 6/7/12 SET CATCHER SUB ASSEMBL ONTOP OF CA -2 PLUG @ 8551' RKB. FLED GLV'S AND OV @ 3201', 4952', AND 5603' RKB. SET DV'S @ 3201 AND 4952' RKB. IN PROGRESS. 6/8/12 SET BTM LATCH DV @ STA# 3 5603' RKB, RAN D &D HOLE FINDER CONFIRM LEAK BELOW PACKER COMMUNICATION TO OA. TESTED ABOVE PACKER ALL DV HOLDING. PULLED CATCHER SUB AND CA -2 PLUG @ 8551' RKB. JOB IN PROGRESS 6/12/12 SET 2.69" HES FAS DRILL COMPOSITE BRIDGE PLUG AT 7059', APPROX MIDDLE OF FULL JOINT. LOG CORRELATED TO PDS LEAK DETECTION LOG DATED 13 OCT 2005. BLEED OA DOWN TO 1000 PSI. TURN WELL OVER TO DSO. 6/12/12 TAG BTM W/ 2.65 CENT SAMPLE BAILER @ 8919' RKB, LOWER PERFS COVERED EST 349' RAT HOLE BELOW UPPER PERF.) PERFORM SBHPS STOPS @ 8918' RKB & 8806' RKB.. 4436 PSI 158 TEMP; 6/15/12 ATTEMPT TO SET CATCHER @ 7054' SLM, IN PROGRESS. 6/16/12 SET CATCHER @ 7059' RKB, PULL DMY VLV @ 5603' RKB, PULL CATCHER, SHIFT CMD OPEN @ 6376' RKB; READY FOR CTU 6/26/12 (PRE RWO) : POT -T PASSED, PPPOT -T PASSED, POT -IC PASSED, PPPOT -IC PASSED, POT -OC PASSED, PPPOT -OC PASSED, FUNCTIONED TESTED LDS'S (ALL GOOD). 7/1/12 MOBILIZE CREW TO KUPARUK FROM ALPINE. ,r 11 7/2/12 SET RETAINER WITH 3000 PSI AT 6865' CTMD. PUMPED 12 BARRELS OF 15.8 PPG ' NEAT CLASS G CEMENT UNDER RETAINER TO LINER. STACKED OUT 3 TIMES AT D 15,j- 6538' CTMD SET DOWN 4000 POUNDS WHILE CLEANING UP. FREEZE PROTECTED TBG. RECOVERED BALL FROM SETTING TOOL NO SIGNS OF SETTING DOWN ON THE SETTING TOOL. CEMENT REPORT IN ATTACHMENTS. JOB IN PROGRESS. 7/3/12 RIH WITH MOTOR AND 2.8" JUNK MILL, TAGGED CMT RETAINER AT 6866' CTMD, MILLED THROUGH CMT RETAINER AND CEMENT DOWN TO 6973' CTMD. IT APPEARS THAT A PIECE OF THE RETAINER IS STIRRING AROUND DOWN HOLE, TRY JARRING DOWN TO BREAK IT UP WITH NO SUCSESS, POOH, F/P CT AND TBG. JOB IN PROGRESS 7/4/12 PERFORMED A PASSING CMIT T /IA/OA, RIH WITH VENTURI JUNK BASKET TO CLEAN OUT MILLING DEBRIS, 1/2 OF THE BASKET WAS FULL OF BROKEN SLIPS FROM THE CMT RETAINER, RIH WITH MOTOR & 2.8" MILL, STILL GETTING ALOT OF STALLS, POOH FOR ANOTHER VENTURI RUN, CLEANED DOWN TO 6991' CTMD, F/P CT AND TBG, JOB IN PROGRESS 7/5/12 MILLED CMT FROM 6990' TO 7046' CTMD, MILLED CBP FROM 7046' TO 7050' CTMD, ESTABLISHED COMMUNICATION TO PERFS, PUSH CBP TO NPL AT 8539' CTMD, POOH, RIH WITH SMALLER BIT AND PUSH CBP TO BTM AT 8904' CTMD, F/P TUBING, READY FOR S /L, JOB IN PROGRESS 7/7/12 DRIFT TBG W/ 2.77" CENT, BLB, 2.67" GAUGE RING TO SIT DOWN @ 6918' SLM, WORK DOWN TO 6942' SLM, TOOLS HANG UP, SCRAPE MARKS ON GAUGE RING AND METAL MARKS ON CENT, WORK 2.67" CENT, 2.5" BLR f/ 6980' TO 7053' SLM, THICK FLUID, PIECE OF RUBBER IN BLR. IN PROGRESS. 7/8/12 RAN BLB, 2.78" GAUGE RING, TOOLS SIT DOWN AND HANG UP BETWEEN 6920' TO 7062' SLM, RECOVER METAL DEBRIS ON 2.61" MAGNET, RECOVER METAL DEBRIS, THICK SCHMOO, FINE SILT IN 2.5" PUMP BAILER, DEEPEST DEPTH REACHED W/ BAILER 8319' SLM, RD FOR UNIT MAINTENANCE. IN PROGRESS. 7/9/12 RAN BAILER AND CLEARED TBG. DOWN TO 8070' SLM ( RECOVERED FILL AND METAL CHUNKS ). BRUSH AND FLUSH W/ 2.78 GAUGE RING DOWN TO 8535' RKB; SET 2.75 CA -2 PLUG @ 8550' RKB; DRIFT W/ 2.78 DUMMY WRP DOWN TO 7060' SLM. BLEED TBG AND IA TO 0 PSI. READY FOR E -LINE TO SET WRP. 7/10/12 SET WEATHERFORD 2.69" WRP MID ELEMENT AT 6550'. CORRELATED TO LINER DETAIL 7/14/12 ATTEMPTED CMIT 2500 PSI, LOST 400 PSI IN 15 MIN, FAILED. REPEAT, SAME RESULT. WITH HOLEFINDER ON WRP @ 6550' MD ATTEMPTED CMIT 2000 PSI, LOST 300 PSI IN 15 MIN, FAILED. RESET HOLEFINDER @ 6445' MD, SAME RESULT. PRESSURE BUILDING IN 5 -1/2" x 7" ANNULUS FROM 120 TO 840 PSI WHILE ATTEMPTING TBG x IA MIT. BLED PRESSURES DOWN. IN PROGRESS. 3F -13A Pre -Rig Well Work Summary 7/15/12 TBG & IA REMAINED @ 500 l 'NITE. BLED T /I /O TO 0/75/20 PSI. Alp MIN, T /I /O @ 100/125/30 PSI. AT 60 MIN, /1 /O @ 125/150/30 PSI. MONITORING T ONTINUE. 7/17/12 (RWO) CMIT- Tx IA x OA FAILED TO 2000 PSI. I • ConocoPhitlips Time Log & Summary We /fwew Web Reporting Report Well Name: 3F - 13 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 7/22/2012 1:00:00 PM Rig Release: 7/30/2012 7:00:00 PM Time Cogs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/21/2012 24 hr Summary Move rig t/ 3F -13 A, mob complexes, continue with pad lift, spot mats around well, move complexes to 3B pad to stage untill sub arrives, lay matting on road ways, move sub from 3N to 3F. 00:00 00:00 24.00 0 0 MIRU MOVE MOB P Move camp t/ 3F pad, Spilt complexes, move complexes to 3B pad until sub can move, Wait on matting road ways from 3N due to AES employees timed out and insufficient staffing, continue with pad lift on 3F pad around well raise 1.5' of lift, set rig mats and spill containment on well 3F -13, move sub t/ 3F -13A 07/22/2012 Move Sub to location, spot over well, Move complexes to location, spot comlexes, hook up service lines, spot tiger tank, Rig Accepted @ 1300 hrs, wait on harlines & choke skid, build scaffold around well. hook up hardlines & choke skid, test lines t/ 3000 psi, displace well with 9.6ppg brine down turing taking returns up IA, attempt to pump down OA no circ, R/D blow down. 00:00 03:00 3.00 0 0 MIRU MOVE MOB P Crab Sub down pad and spot over well. 03:00 05:00 2.00 0 0 MIRU MOVE MOB P Move pipe sheds F/ 3B pad T/ 3F and spot. Spot rockwasher 05:00 07:30 2.50 0 0 MIRU MOVE MOB P Move pit complex and pump room F/ 3B T/ 3F and spot same 07:30 09:30 2.00 0 0 MIRU MOVE MOB P Move Motor complex and Boiler complex F/ 3B pad T /3F and spot same 09:30 10:00 0.50 0 0 MIRU MOVE SFTY P PJSM on Rigging up with crews 10:00 12:00 2.00 0 0 MIRU MOVE RURD P Work onn Rig acceptance check list 12:00 13:00 1.00 0 0 MIRU MOVE RURD P Work on rig acceptance, set up scaffolding around tree. 13:00 14:00 1.00 0 0 MIRU WELLPF OTHR P Rig accepted (a7 13:00 hrs _ 7 -22 -2012, PJSM, R/U lines, vent IA to burp tank and take on 9.6 ppg brine 14:00 15:30 1.50 0 0 MIRU WELLPF SEQP P OA on Vac, Check POPIT on BPV and pull same as per -FMC, SIMOPS- Berm tiger tank 15:30 16:15 0.75 0 0 MIRU WELLPF SEQP P Install double annulus valve and R/U lines to tree for displacement 16:15 18:30 2.25 0 0 MIRU WELLPF OTHR P Wait on hardline for displacement to tiger tank. Cont. rigging up 18:30 19:15 0.75 0 0 MIRU WELLPF OTHR P R/U hard line & choke skid. 19:15 21:00 1.75 0 0 MIRU WELLPF OTHR P Load 4" dp in shed Page of 12 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 21:45 0.75 0 0 MIRU WELLPF PRTS P Flood lines w/ H2O, attempt to pressure test lines found leak in hardlines, blow down replace gasket, retest hard lines U 3000 psi (Good). 21:45 23:00 1.25 0 0 MIRU WELLPFCIRC P Break circ. down tubing taking returns to up IA to tiger tank a 126 gpm 500 psi 149 bbls 23:00 00:00 1.00 0 0 MIRU WELLPF CIRC P Line up to take returns up OA unable to circ. pressure up to 600 psi. attepmt to circ down OA taking returns up tubing, unable to circ. pressure up to 600 psi , R/D blow down 07/23/2012 Tried to circ down OA up through the tbg no go, set BPV and tested same, R/D scaffolding, PJSM nipple down tree, N/U adapter flange and BOPE, Test BOPE 250 low / 3000 high Needed 3500 high test retest to -z 3500 psi, (BOP test wavied by Bob Noble) 00:00 00:15 0.25 0 0 MIRU WELLPF SFTY P PJSM circulating down OA 00:15 00:30 0.25 0 0 MIRU WELLPFCIRC P R/U and attempt to pump down OA taking returns through Tubing, No good OA pressured up to 600 psi. 00:30 01:00 0.50 0 0 MIRU WELLPF OTHR P Blow down lines and R/D 01:00 01:15 0.25 0 0 MIRU WELLPF OTHR P Set BPV as per -FMC 01:15 01:30 0.25 0 0 MIRU WELLPF OTHR P R/U to test BPV in direction of flow 01:30 02:00 0.50 0 0 MIRU WELLPF OTHR P Test BPV for 10 min, IA pressure bleed down F/ 1000 psi T/ 650 psi in 10 min, no returns observed past BPV. OA pressure= 900 psi, bleed off. OA went up to 500 psi. Decision made to pump down IA taking retuns through OA 02:00 03:15 1.25 0 0 MIRU WELLPF OTHR P R/U and circulate through IA taking returns through the OA, pumped one bbl and pressured up to 1000 psi, decision made to move forward, blow down lines and R/D. 03:15 03:45 0.50 0 0 MIRU WELLPF OTHR P R/D scaffolding 03:45 04:00 0.25 0 0 MIRU WELLPF SFTY P PJSM on N/D tree 04:00 05:00 1.00 0 0 MIRU WELLPF NUND P Nipple down tree 05:00 07:30 2.50 0 0 MIRU WELLPF NUND P N/U adapter flange and BOP stack 07:30 08:00 0.50 0 0 MIRU WELLPF SFTY P PJSM on R/U and test BOPE 08:00 09:15 1.25 0 0 MIRU WELLPF BOPE P R/U to test BOPs Page 2 of 12 • • Time Logs Date From - To Dui ° S. Depth E. Depth Phase Code Subcode T Comment 09:15 12:00 2.75 0 0 MIRU WELLPF BOPE P Test BOPs T/ 250 psi low and 3000 psi high, Test # 1= top rams, CM valves 1, 12, 13, 14 and manual kill valve, Test # 2= Upper IBOP valve, j ' CM valves 9 & 11, Test # 3= Lower IBOP valve, HCR kill, CM valves 5,8 & 10, Test# 4= Dart valve, CM valves 4, 6 & 7, Test #5= Floor valve & CM valve # 2, Test # 6= HCR choke, 4" Kill line Demco valve, Test # 7= Manual Choke and HCR kill. (Test waived by AOGCC Bob Noble) 12:00 12:45 0.75 0 0 MIRU WELLPF BOPE P Continue testing BOP, Test Annular with 3.5" test joint 12:45 13:00 0.25 0 0 MIRU WELLPF BOPE P R/D 3.5" test Joint 13:00 13:30 0.50 0 0 MIRU WELLPF BOPE P Test Blinds and choke valve # 3, 13:30 14:15 0.75 0 0 MIRU WELLPF BOPE P P/U and M/U 5.5" test joint, Test upper 3.5" x 6" VBR and annulur 250 low / 3500 high, R/D 5.5" test, M/U 3.5" and retest BOPE to 3500 psi high. 14:15 18:30 4.25 0 0 MIRU WELLPF BOPE P Test # 1= upper 3.5" x 6" VBR, choke 1,12,13,14 and Manual kill valve. Test # 2= Upper IBOP, HCR kill, choke valves 9 &11. Test# 3= lower IBOP, Choke valves, 5, 8 and 10. Test # 4= Dart valve, Choke valves 4, 6 and 7. Test # 5= floor valves and choke valve # 2. Test # 6= HCR choke, 4" kill line Demco valve. Test # 7= Manual choke. Test # 8= Annular, Test # 9= Blid rams and choke valve 3. Accumulator test: sys pressure= 3000 psi, pressure after closing= 1800 psi, 200 psi attained= 37 sec, Full pressure attained= 183 sec. Nitrogen avg= 2150 psi. 18:30 19:00 0.50 0 0 MIRU WELLPF BOPE P Rig down test equipment and pull blganking plug, blow down lines and choke. 19:00 21:30 2.50 0 0 MIRU WELLPFOTHR P Check POPIT on BPV, Observed pressure on tbg, check IA @ 50 psi, OA 460 psi and 100 psi on OOA, Bleed off IA to 0 psi, (No fliud in returns) Line up to OA to choke and tiger tank and bleed to 0 psi for 20 min and 2 bbls back, IA on vac. Check POPIT on BPV again Obseved gas then diesel under slight pressure. 21:30 21:45 0.25 0 0 MIRU WELLPF SFTY P PJSM circulating down tbg and out IA to tiger tank. 21:45 23:30 1.75 0 0 MIRU WELLPFCIRC P Close Blinds rams and circulate down tbg through BPV out IA to tiger tank @ 1 bpm 175 psi FCP 23:30 00:00 0.50 0 0 MIRU WELLPF OWFF P Monitor well (static) Page 3of12 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/24/2012 24 hr Su mmary Pull hanger to rig floor, hanger pulled @ 75K. Reverse circulate 100 bbls. UD 5650' of 3 -1/2" tubing. M/U Baker G plug, Observed 450 PSI on OA. Attempt to circulate through holes in 5-1/2" liner, no go. P/U 4" DP while waiting on E -Line. RIH w/ tubing punch and shoot holes in 5 -1/2" liner. Circulate out freeze protect to tank. Set G plug 100' below table. N/D BOPE. 00:00 00:30 0.50 0 0 COMPZ WELCTL MPSP P PJSM, Drain stack t/ make sure we are in the correct spot. Check for pressure under BPV, no pressure. Pull BPV as per FMC. 00:30 01:00 0.50 0 5,650 COMPZ RPCOM THGR P P/U joint of tubing and screw into hanger. Pull hanger @ 75K, P/U wt.= 73K. 01:00 02:00 1.00 5,650 5,650 COMPZ RPCOM CIRC P Rig up and reverse circulate 100 bbls @ 4 BPM =650 PSI. 02:00 02:15 0.25 5,650 5,650 COMPZ RPCOM OWFF P Open annular and monitor well for flow, static. 02:15 02:30 0.25 5,650 5,650 COMPZ RPCOM RURD P Rig down circulating equipment. 02:30 07:30 5.00 5,650 0 COMPZ RPCOM PULL P UD 3.5" tubing. UD 176 joints of 3.5" tubing, 6 pup joints, 3 gas lift mandrels and seal assembly. Total footage= 5650.0. Actual displacement= 18.36 bbls, Calculated displacement= 18.05 bbls. 07:30 07:45 0.25 0 0 COMPZ WELLPFOTHR P Blow down kill line, choke line and top drive. 07:45 08:15 0.50 0 0 COMPZ WELLPF OTHR P Clean and clear rig floor. 08:15 08:30 0.25 0 0 COMPZ WELLPF PULD P P/U Baker tools f/ beaver slide. 08:30 08:45 0.25 0 0 COMPZ WELLPF SFTY P Hold PJSM on setting G plug. 08:45 09:15 0.50 0 0 COMPZ RIGMNT SVRG P Service rig. 09:15 10:00 0.75 0 0 COMPZ WELLPF PULD P M/U G plug as per Baker rep., 10:00 12:00 2.00 0 0 COMPZ WELCTL DISP P Observed 375 PSI in the OA, decision made to pump down 5 -1/2" scab liner taking returns to tiger tank. Unable to circulate, pressured up V 1200 PSI several times. Observed pressure dropping off. The hole in the 5 -1/2" scab liner was not large enough to pump through. 12:00 12:45 0.75 0 0 COMPZ WELLPF PULD P UD running tool, M/U stand of 3 -1/2" PH6 tubing and stand back in derrick. 12:45 13:00 0.25 0 0 COMPZ WELLPF SFTY P Hold PJSM on P/U 4" DP via mouse hole. 13:00 13:30 0.50 0 0 COMPZ RIGMN1SVRG P Service pipe skate and iron roughneck. 13:30 16:00 2.50 0 0 COMPZ WELLPF PULD P P/U 4" drill pipe via mouse hole. 16:00 16:30 0.50 0 0 COMPZ WELLPF RURD P UD mouse hole and clear floor. 16:30 17:30 1.00 0 0 COMPZ WELLPF RURD P PJSM, R/U HES E -Line Page 4of12 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 18:30 1.00 0 0 COMPZ WELLPF ELNE P RIH w/ HES 8 shot tubing punch on E -Line. Fire tubing punch f/ 5640' MD t/ 5644' MD. Observed OA ✓ '� pressure increase from 0 PSI t/ 450 SV � PSI when shot was fired & 1.2 bbl loss in liner. 18:30 19:00 0.50 0 0 COMPZ WELLPF ELNE P POOH w/ E -Line, Hold PJSM on displacing out freeze protect. 19:00 19:45 0.75 0 0 COMPZ WELLPF DISP P Close blind rams and circulate down scab liner out the OA to choke out to tiger tank. Pump @ 3 BPM= 300 PSI ICP and 750 PSI FCP. Pumped 75 bbls total. Open well and monitor OA and IA, static. 19:45 21:30 1.75 0 0 COMPZ WELLPF PACK P M/U Baker G plug and RIH w/ 3 -1/2" PH6 tubing. Set plug (A7, 100' MD as per Baker. POOH w/ running tool, SIMOPS cont t/ monitor OA & IA. 21:30 22:00 0.50 0 0 COMPZ WELLPF PRTS P Flood kill line, close blind rams and test plug t/ 3000 PSI f/ 5 min, good test. Bleed off pressure. 22:00 22:15 0.25 0 0 COMPZ WHDBO NUND P Blow down kill line and drain stack. 22:15 00:00 1.75 0 0 COMPZ WHDBO NUND P PJSM, nipple down stack. 07/25/2012 N/D BOPE, weld slips and N/U BOPE. Attempt t/ test break in BOPE, no leaks observed © 2000 PSI. Retreive G -Plug. Make up spear and pull 5 -1/2" scab liner to surface. Lay down 6467' of 5 -1/2" liner and 842' of 3 -1/2" tubing. Joints # 151 and # 152 of the 5 -1/2" liner were damaged. 00:00 01:30 1.50 0 0 COMPZ WHDBO NUND P PJSM, Nipple down stack and tubing spool. Pull pack -off. 01:30 02:00 0.50 0 0 COMPZ WHDBO OPNW P Weld slips to 5 -1/2" scab liner. 02:00 04:15 2.25 0 0 COMPZ WHDBO NUND P Nipple up spacer spool and BOPE stack. 04:15 04:45 0.50 0 0 COMPZ WHDBO BOPE P Test break @ spacer spool. Attempt to pressure up, observed fluid being g pumped away. Pumped 9.4 bbls ! ,� Y. away total, with 9.4 bbls lost in mud pits. While pressured up t/ 2000 PSI, a � visually inspected break for leaks, no leaks. Pressure dropped off t/ 850 PSI, held f/ 5 min. 04:45 05:45 1.00 0 0 COMPZ WELLPF OWFF P Monitor well, observed slight flow from injecting fluid. Monitored well until flow stopped. 05:45 06:00 0.25 0 0 COMPZ WELLPF SFTY P Hold PJSM, fill out HRC and HRW on M/U G -plug retrieval tool. 06:00 06:15 0.25 0 0 COMPZ WELLPF PULD P M/U retrieval tool as per Baker rep. 06:15 07:00 0.75 0 0 COMPZ WELLPF TRIP P RIH t/ 100' MD. Retreive Baker G -plug as per Baker. POOH w/ G -plug. 07:00 07:30 0.50 0 0 COMPZ WELLPF RURD P R/U tongs and break G -plug. L/D G -plug as per Baker rep. 07:30 07:45 0.25 0 0 COMPZ WELLPF SFTY P Hold PJSM, fill out HRC and HRW on M/U spear. Page 5 of 12 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 09:00 1.25 0 0 COMPZ WELLPF PULD P Suck out BOP stack w/ vac unit. M/U spear assembly as per Baker rep. 09:00 09:45 0.75 0 6,493 COMPZ WELLPF FISH P RIH and spear 5 -1/2" liner. Pull liner to rig floor, liner pulled free ga 195K, P/U wt.= 137K. Pulled slips to the floor w/ liner. 09:45 10:30 0.75 6,493 6,493 COMPZ WELLPF OWFF P Monitor well, static. R/U tongs and P/U casing tools from beaver slide. 10:30 11:00 0.50 6,493 6,480 COMPZ WELLPF PULD P UD running tool and cut joint of 5 -1/2" liner 11:00 12:00 1.00 6,480 6,164 COMPZ WELLPF PULL P UD 5 -1/2" 15.5 Ib Hydril 511 liner, R/U and install air slips. 12:00 16:00 4.00 6,164 1,900 COMPZ WELLPF PULL P Cont t/ UD 5 -1/2" 15.5 Ib Hydril 511 liner f/ 6164' MD t/ 1900' MD. Well out of balance due to U -tube of gas and crude from under packer. 16:00 17:00 1.00 1,900 1,900 COMPZ WELLPF CIRC P M/U top drive and circulate well to balance @ 4 BPM= 200 PSI. 17:00 18:45 1.75 1,900 840 COMPZ WELLPF PULL P Cont t/ UD 5 -1/2" 15.5 Ib Hydril 511 liner f/ 1900' MD t/ 840' MD. Pulling slow and stopping several times to allow gas to migrate. Actual displacement= 33.62 bbls, Calculated displacement= 31.77 bbls. 18:45 20:30 1.75 840 840 COMPZ WELLPF PULL P PJSM, break out joint #136 liner slow and allow pressure to bleed off. P/U and expose 3 -1/2" tubing. Rig up false table and break out tubing tail from packer. UD joint # 136 of 5 -1/2" liner with packer inside. 20:30 20:45 0.25 840 840 COMPZ WELLPF RURD P R/D 5 -1/2" handling equipment and R/U 3 -1/2" handling equipment. 20:45 22:15 1.50 840 840 COMPZ WELLPF PULL P POOH laying down 3 -1/2" tubing and lower seal assembly. Total 3 -1/2" laid down= 24 joints, 6 pups, 8rd X IBT, CMD w/ X profile, X nipple and seal assembly. Total tenth= 842.32'. Actual displacement= 2.6 bbls, Calculated displacement= 2.42 bbls. 22:15 22:30 0.25 840 840 COMPZ WELLPF RURD P R/D false table and 3 -1/2" handling tools. R/U 5 -1/2" handling tools. 22:30 00:00 1.50 840 0 COMPZ WELLPF PULL P Cont t/ UD 5 -1/2" 15.5 Ib Hydril 511 liner f/ 840' MD. Laid down 154 full joints, 1 cut joint and seal assembly. The box of # 152 was damaged along with the pin of # 151, The hole in # 151 was approximately 1/2" wide. Total length= 6467'. Actual displacement= 4.5 bbls, Calculated displacement= 4.45 bbls. 07/26/2012 Test lower rams w/ 4" and 3 -1/2" test joint. M/U Baker spear and RIH and fish seal assy @ 6523' MD. POOH and UD 25" of fish. M/U clean out BHA w/ 7" scraper and RIH. RIH t/ 6533'. Pump HiVis sweep and circ hole clean. POOH 00:00 02:00 2.00 0 0 COMPZ WELLPF PULD P PJSM, clean casing equipment and rig floor. Send out unwanted tools. Page 6 of 12 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 02:15 0.25 0 0 COMPZ WHDBO SFTY P Hold PJSM on R/U and testing BOPE. 02:15 03:15 1.00 0 0 COMPZ WHDBO RURD P Rig up to test BOPE. W {� D 03:15 05:00 1.75 0 0 COMPZ WHDBO BOPE P Test w/ 4" test joint. Test annular, V,(� top rams and bottom rams t/ 250 PSI/ 3000 PSI. Test bottom rams w/ 3 -1/2" test joint to 250 PSI/ 3000 PSI, charted. 05:00 06:00 1.00 0 0 COMPZ WHDBO RURD P Rig down test equipment and set wear bushing. 06:00 06:15 0.25 0 0 COMPZ WELLPF SFTY P Hold PJSM, fill out HRC & HRW on M/U spear. 06:15 07:00 0.75 0 58 COMPZ WELLPF PULD P M/U Spear as per Baker rep. 07:00 11:00 4.00 58 5,253 COMPZ WELLPF PULD P Single in the hole w/ 4" drill pipe f/ 58' MD t/ 5253' MD. 11:00 12:00 1.00 5,253 6,481 COMPZ WELLPF TRIP P RIH f/ 5253' MD t/ 6481' MD. P /U= 122K, S /O= 87K. Actual displacement= 39.9 bbls, Calculated displacement= 36.6 bbls. 12:00 12:30 0.50 6,481 6,481 COMPZ WELLPF FISH P M/U to topdrive @ 6481' MD. P /U= 122K, S /O= 87K. Break circulation @ 2 BPM =550 PSI. S/O and engage fish @ 6523' MD, set down 10K and observed pump pressure increase t/ 950 PSI. Shut down pump, S/O and maintain 10K on fish. Fire jars w/ 25K overpull two times. Fire jars with 50K overpull two time. Fire jars with 75K overpull, pump @ 2 BPM, observed pump pressure increase t/ 1150 PSI when fish came free. Keep rate © 2 BPM, P/U 5' to verify fish was free, observed pressure drop off t/ 550 PSI. Pull up to 6481' MD. 12:30 13:30 1.00 6,481 6,481 COMPZ WELLPFCIRC P CBU X 1 -1/2 @ 3 BPM =1500 PSI, observed gas break out at bottoms up. 13:30 13:45 0.25 6,481 6,481 COMPZ WELLPF OWFF P Stand one stand back in derrick. Monitor well, static. 13:45 17:30 3.75 6,481 0 COMPZ WELLPF TRIP P POOH f/ 6481' MD. UD fish and spear assembly. Length of fish= 25 ". Actual displacement= 40.1 bbls, Calculated displacement= 36.18 bbls. 17:30 18:15 0.75 0 0 COMPZ WELLPF OTHR P Clean and clear rig floor. 18:15 18:30 0.25 0 0 COMPZ WELLPF SFTY P Hold PJSM on M/U scraper assembly. 18:30 21:30 3.00 0 6,495 COMPZ WELLPF TRIP P M/U 7" scraper w/ 2 -7/8" PAC tail pipe and RIH t/ 6494' MD. Actual displacement= 36.1 bbls, Calculated displacement= 36.78 bbls. Page 7 of 12 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 22:30 1.00 6,495 6,533 COMPZ WELLPF CIRC P M/U to top drive, P /U= 122K, S /0= 87K. Establish circulation © 4 BPM =300 PSI. Wash down to 6533' MD, did not take any weight. ht. P/U 5' and increase pump rate to 7.5 BPM= 925 pSI. Pump 30 bbls HiVis sweep w/ 3 PPB flowzan. CBU X 2 -1/2. S/O t/ 6533' MD when sweep was to bit. 22:30 22:45 0.25 6,533 6,495 COMPZ WELLPF OWFF P Stand back one stand and monitor well, static. 22:45 00:00 1.25 6,495 4,606 COMPZ WELLPF TRIP P POOH w/ scraper f/ 6495' MD t/ 4606' MD. P /U= 95K, S /O= 75K. Actual displacement= 11.2 bbls, Calculated displacement= 10.8 bbls. 07/27/2012 Cont. POOH w/ clean out BHA. UD BHA. M/U test packer and RIH. Isolate leaks in 7" casing between 5580' MD- 5673' MD. CBU and POOH. Slips and cut drilling line, service rig. RIH w/ real time Gyro and HES 40-arm caliper log. 00:00 01:00 1.00 4,606 72 COMPZ WELLPF TRIP P PJSM, Cont. t/ POOH f/ 4606' MD t/ 72' MD. Actual displacement= 27.86 bbls, Calculated displacement= 26.56 bbls. 01:00 01:30 0.50 72 0 COMPZ WELLPF PULD P UD BHA # 3 as per Baker. 01:30 02:00 0.50 0 0 COMPZ WELLPF OTHR P Clean and clear rig floor. P/U Baker packer f/ beaver slide. 02:00 02:15 0.25 0 0 COMPZ WELLPF SFTY P Hold PJSM on M/U test packer and RIH. 02:15 02:45 0.50 0 23 COMPZ WELLPF PULD P M/U BHA, test packer and seals as per Raker rep _ 02:45 05:00 2.25 23 6,442 COMPZ WELLPF TRIP P RIH w/ test packer f/ 23' MD t/ 6442' MD. 05:00 05:15 0.25 6,442 6,442 COMPZ WELLPF PACK P et parker Q 6442' Mn. P /U= 120K, S /O= 90K. 05:15 05:45 0.50 6,442 6,442 COMPZ WELLPF PRTS P Pressure test below packer t/ 2500 PSI t/ 10 min, good test. Attempt to test annulus, pressure leaking off @ 1100 PSI at 1 BPM. Pressure k dropped to 825 PSI and held. 05:45 06:30 0.75 6,442 4,544 COMPZ WELLPF TRIP P POOH f/ 6442' MD t/ 4544' MD. Actual displacement= 11.39 bbls, Calculated displacement= 10.8 bbls. 06:30 07:00 0.50 4,544 4,544 COMPZ WELLPF PRTS P Set packer @ 4544' MD, pressure test annulus t/ 2500 PSI, good. 07:00 07:45 0.75 4,544 6,328 COMPZ WELLPF TRIP P RIH f/ 4544' MD U 6328' MD. Actual displacement= 10.54 bbls, Calculated displacement= 10.26 bbls. 07:45 10:45 3.00 6,328 5,596 COMPZ WELLPF PRTS P Attempt pressure test annulus t/ 2500 PSI, leaking. Begin to POOH and pressure test each stand. The leak in the casing was located f/ 5580' MD to 5673' MD. The casing tested good above 5580' MD and below 6573' MD. 10:45 11:30 0.75 5,596 5,596 COMPZ WELLPF CIRC P CBU @ 5596' MD @ 4 BPM =300 PSI w/ 20 % flow. 11:30 11:45 0.25 5,596 5,596 COMPZ WELLPF OPNW P Monitor well, static. Page 8 of 12 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:45 12:00 0.25 5,596 4,650 COMPZ WELLPF TRIP P POOH f/ 5596' MD t/ 4650' MD. Actual displacement= 4.93 bbls, Calculated displacement= 5.4 bbls. 12:00 13:30 1.50 4,650 23 COMPZ WELLPF TRIP P PJSM, Cont t/ POOH f/ 4650' MD t/ 23' MD. Actual displacement= 34 bbls, Calculated displacement= 32.25 bbls. 13:30 13:45 0.25 23 0 COMPZWELLPF PULD P UD BHA #4, test packer and seals as per Baker rep,. 13:45 14:15 0.50 0 0 COMPZ WELLPF OTHR P Clean and clear floor, blow down top drive. 14:15 14:30 0.25 0 0 COMPZ RIGMN1SFTY P Hold PJSM on slip and cut drilling line. 14:30 15:30 1.00 0 0 COMPZ RIGMNT SLPC P Slip and cut 65' pf drilling line. 15:30 16:00 0.50 0 0 COMPZ RIGMNTSVRG P Service rig. 16:00 17:00 1.00 0 0 COMPZ WELLPF RURD P PJSM, rig up HES E -Line. , 17:00 22:45 5.75 0 0 COMPZ WELLPF ELOG P RIH w/ E -Line, real time Gyro. 22:45 23:00 0.25 0 0 COMPZ WELLPF ELOG P R/D E -Line tools 23:00 23:30 0.50 0 0 COMPZ WELLPF ELOG P R/U E -Line memory HES 40 -arm caliper & GR /CCL 23:30 00:00 0.50 0 0 COMPZ WELLPF ELOG P RIH w/ E -Line t/ 64$0' MD. 07/28/2012 Cont. E -Line w/ HES 40 -arm caliper & GR/CCL. R/D E -Line and R/U t/ run 4 -1/2" straddle assy. RIH w/ 4 -1/2" straddle assy t/ 6500' MD. Top of TBS © 5544.3' MD Spot 40 bbls on inhibited brine and test seals. Set liner hanger assy and PT t/ 2500 PSI. POOH UD 4" drill pipe. R/U and RIH w/ 5 -1/2" tie back liner. 00:00 02:45 2.75 0 0 COMPZ WELLPF ELOG P PJSM, Cont RIH w/ E -Line HES 40 -arm caliper & GR/CCL. Log f/ 6500' MD to surface. 02:45 03:15 0.50 0 0 COMPZ "WELLPF RURD P R/D E -Line as per Halliburton rep. 03:15 03:30 0.25 0 0 COMPZ WELLPFSFTY P Hold PJSM on rigging up and running 4 -1/2" liner 03:30 04:30 1.00 0 0 COMPZ WELLPF RURD P Pick up casing equipment and rig up. 04:30 04:45 0.25 0 0 COMPZ WELLPF PUTB P Make up tie back stem and muleshoe as per Baker rep. 04:45 06:30 1.75 0 967 COMPZ WELLPF PUTB P RIH w/ 4 -1/2" L -80 IBTM liner t/ 967' MD. M/U SBE, liner hanger and liner top packer as per Baker rep. 06:30 06:45 0.25 967 967 COMPZ WELLPF RURD P R/D casing equipment and floor valve. 06:45 07:00 0.25 967 967 COMPZ WELLPF CIRC P P/U 1 stand and pump 15 bbls @ 3 BPM =100 PSI w/ 19% flow. 07:00 09:00 2.00 967 6,461 COMPZ WELLPF RUNL P RIH w/4 -1/2" liner on 4" drill pipe f/ 967' MD t/ 6490' MD. No -go on existing tag -back sleeve @ 6460.68. P /U= 117K, S /0= 90K. Actual displacement= 37.73 bbls, Calculated displacement= 37.29 bbls. 09:00 09:30 0.50 6,461 6,461 COMPZ WELLPFCRIH P M/U to top drive and establish circulation @ 5 BPM =550 PSI w/ 23% flow. Pump 40 bbls of inhibited brine and chase w/ 74.5 bbls of 9.6 ppg brine. Page 9 of 12 • • Time Logs Date From To Dur S. Depth E. Depth Phase C • • e Subcode T Comment 09:30 09:45 0.25 6,461 6,461 COMPZ WELLPF PACK P String seals back down into tie -back stem. Pressure up down drill pipe t/ 500 PSI t/ ensure seals are engaged f/ 5 min, good. 09:45 10:00 0.25 6,461 6,461 COMPZ WELLPF PACK P Drop ball and allow to free fall f/ 10min. 10:00 10:15 0.25 6,461 6,440 COMPZ WELLPF PACK P Pressure up t/ set Liner hanger assv., and release packer as per Baker rep. 10:15 10:45 0.50 6,440 6,440 COMPZ WELLPF PRTS P Pressure test annulus t/ 2500 PSI f/ 10 min, good test. 10:45 11:00 0.25 6,440 6,440 COMPZ WELLPF OTHR P Blow down top drive and kill line. 11:00 15:30 4.50 6,440 0 COMPZ WELLPF PULD P POOH laying down 4" drill pie. 15:30 16:00 0.50 0 0 COMPZ WELLPF PULD P UD running tool as per Baker rep. 16:00 17:30 1.50 0 0 COMPZ WELLPF PULD P PJSM, RIH w/ remaining 4" drill pipe, POOH laying down 4" drill pipe. 17:30 18:30 1.00 0 0 COMPZ WELLPF RURD P PJSM, rig up to run 5 -1/2" tie back ,. casing. 18:30 19:00 0.50 0 0 COMPZ WELLPF OTHR P Pull wear bushing. 19:00 00:00 5.00 0 3,315 COMPZ WELLPF PUTB P PJSM, RIH w/ 5 -1/2" liner. First two joints were tight, had to lightly push them with top drive. Decision made to POOH and inspect seals. Seals looked good, cont. t/ RIH t/ 3315' MD. P /U =90, S /O= 54K. 07/29/2012 Cont t/ run 5 -1/2" tie -back liner U 5544' MD. Pumped 50 bbls of gelled diesel in 5.5" X 7" annulus. Tested liner seals t/ 2500 PSI. N/D BOP and set emergency slips. N/U tubing head and N/U BOPE. Test BOPE t/ 250 PSI/ 3500 PSI for weekly BOP test. Rig up and run 3 -1/2" completion. 00:00 01:45 1.75 3,315 5,540 COMPZ WELLPF PUTB P PJSM, Cont to pick up 5 -1/2" liner f/ 3315' MD t/ 5540' MD. P /U= 125K, S /O =63K. 01:45 02:00 0.25 5,540 5,542 COMPZ WELLPF PUTB P P/U 4' pup and string into seal assy, No -go @ 5542' MD. Bottom of Baker tie -back seal stem @ 5551.96' MD. XO f/ locater on 3 -1/2" tubing @ 5544' MD 02:00 02:45 0.75 5,542 5,542 COMPZ WELLPF PRTS P Rig up and test down liner t/ 1000 PSI to ensure seals are holding, good. 02:45 03:00 0.25 5,542 5,542 COMPZ WELLPF SFTY P Hold PJSM on pumping gelled diesel w/ Little Red. 03:00 03:30 0.50 5,542 5,527 COMPZ WELLPF RURD P Pick up 15' to un- string seals. Rig up Little Red on annulus and to take returns out the 5 -1/2" liner. 03:30 04:15 0.75 5,527 5,527 COMPZ WELLPF FRZP P Pump 50 bbls of gelled diesel down 5 -1/2" X 7" annulus with Little Red. 04:15 05:00 0.75 5,527 5,542 COMPZ WELLPF PRTS P Sting back into tie -back sleave and pressure test annulus to 2500 PSI f/. 15min, good. 05:00 05:30 0.50 5,542 5,542 COMPZ WELLPF PRTS P Rig up and test down 5 -1/2" liner t/ 2500 PSI f/ 15 min, good. 05:30 06:00 0.50 5,542 5,542 COMPZ WHDBO OTHR P Suck out liner and drain stack. Blow down kill and choke lines, pump out stack. Page 10 of 12 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 06:30 0.50 5,542 5,542 COMPZ WHDBO SFTY P Hold PJSM on nippling down stack and setting emergency slips. SIMOPS, OWFF 06:30 07:30 1.00 5,542 5,542 COMPZ WHDBO NUND P Break two connections on stack and lift stack to set slips. 07:30 08:45 1.25 5,542 0 COMPZ WHDBO OTHR P Set emergency slips w/ 70K down weight. Total weight with top drive= 105K. Cut casing w/ WACHS cutter as per FMC. 08:45 09:30 0.75 0 0 COMPZ WHDBO NUND P Pick up 1 joint and install pack -off as per FMC. 09:30 11:30 2.00 0 0 COMPZ WHDBO NUND P Nipple up tubing head and test t/ 3000 PSI f/ 15 min as per FMC. 11:30 12:30 1.00 0 0 COMPZ WHDBO SFTY P Hold safety stand down w/ both crews. Go over the recent incidents and near misses field wide. 12:30 14:45 2.25 0 0 COMPZ WHDBO NUND P PJSM, Cont. t/ N/U BOPE. 14:45 15:00 0.25 0 0 COMPZ WHDBO SFTY P Hold PJSM on testing BOPE. 15:00 19:00 4.00 0 0 COMPZ WHDBO BOPE P Test BOPE t/ 250 PSI /3500 PSI. Test # 1: Top rams, manual kill, CV P 1,12,13 & 14. Test # 2: Upper IBOP, PT1 HCR kill, CV9 &11.Test #3: [ Lower IBOP, CV 5,8,& 10. Test #4: Dart, CV 4,6 & 7. Test #5: Floor valve & CV 2. Test #6: HCR choke & 4" kill line demco. Test # 7: Manual choke valve & HCR kill. Test #8: Annular preventer. Test #9: Lower pipe rams. Test #10: Blind rams & CV 3. Accumulator test: system pressure= 3000 PSI, Pressure after closed= 1800 PSI. 200 PSI attained after 35 sec, Full pressure attained after 188 sec. Nitrogen bottle= 2150 PSI average. John Crisp waved witness of test. 19:00 19:15 0.25 0 0 COMPZ WHDBO OTHR P Blow down choke and kill line. 19:15 20:15 1.00 0 0 COMPZ RPCOM RURD P Rig up to run 3 -1/2" completion. 20:15 20:30 0.25 0 0 COMPZ RPCOM SFTY P Hold PJSM on running 3 -1/2" tubing. 20:30 00:00 3.50 0 1,604 COMPZ RPCOM RCST P RIH w/ 3 -1/2" L -80 IBT -M tubing t/ 1604' MD. 07/30/2012 RIH w/ 3 -1/2" tubing. Land tubing 7.7' off located position. Test down tubing U 2500 PSI and test IA t/ 3500 PSI. Test OA t/ 1500 PSI. Nipple down BOPE and nipple up tree. Test tree t/ 5000 PSI. Freeze protect well w/ 50 bbls of diesel. Rig down and prep to move. Rig released @ 1900 hours. 00:00 03:30 3.50 1,604 5,539 COMPZ RPCOM RCST P PJSM, Cont t/ run 3 -1/2" tubing f/ 1604' MD. Tag locator © 5539' MD. Actual displacement= 13.55 bbls, Calculated displacement= 13.77 bbls. 03:30 04:00 0.50 5,539 5,480 COMPZ RPCOM HOSO P UD 3 joints and P/U 26.47' of space out pups, 3 pups 9.82', 5.85' and 10.80'. Page 11 of 12 f • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 04:30 0.50 5,480 5,400 COMPZ RPCOM CRIH P Spot 15 bbls of inhibited brine and displace out of pipe w/ 44 bbls @ 3 BPM =450 PSI. 04:30 05:00 0.50 5,400 5,400 COMPZ RPCOM THGR P Rig down circulating equipment and P/U 1 joint, make up tubing hanger. 05:00 05:30 0.50 5,400 5,533 COMPZ RPCOM THGR P Drain stack and land hanger. Land 7.7' off located position. Bottom of seal assy. @ 5588' MD 05:30 07:30 2.00 5,533 5,533 COMPZ RPCOM PRTS P Test down tubing t/ 2500 PSI f/ 30 min, good. With 2500 PSI on tubing \ / 1 pressure test IA t/ 3500 PSI f/ 30 M min, good. Bleed off pressure and test OA t/ 1500 PSI f/ 15 min, good. All tests charted. 07:30 07:45 0.25 5,533 5,533 COMPZ RPCOM OTHR P Rig up and pressure up IA t/ shear out the SOV, sheared @ 1500 PSI. 07:45 08:00 0.25 5,533 0 COMPZ WHDBO OTHR P Rig down test equipment and back out landing joint. Flush stack with fresh water. 08:00 08:15 0.25 0 0 COMPZ WHDBO SEQP P Install BPV as per FMC. 08:15 08:30 0.25 0 0 COMPZ WHDBO PRTS P Pressure up through the IA t/ 1000 PSI f/ 10 min. t/ ensure BPV is holding. 08:30 09:15 0.75 0 0 COMPZ WHDBO OTHR P R/D test equipment and flush out both mud pumps. Blow down choke, kill and cement lines. 09:15 09:30 0.25 0 0 COMPZ WHDBO SFTY P Hold PJSM, fill out HRC and HRW on N/D BOPE. 09:30 10:45 1.25 0 0 COMPZ WHDBO NUND P Nipple down BOPE. SIMOPS, wash and clean tubing tools. 10:45 12:00 1.25 0 0 COMPZ WHDBO NUND P Nipple up tubing head adapter and pull in new tree. 12:00 12:15 0.25 0 0 COMPZ WHDBO PRTS P PJSM, test hanger pack -off/ adapter t/ 5000 PSI f/ 15 min, good. 12:15 14:00 1.75 0 0 COMPZ WHDBO NUND P Nipple up tree, pull BVP and set tree test plug. Test tree t/ 250 PSI /5000 PSI on chart, good. Pull tree test plug. 14:00 16:00 2.00 0 0 COMPZ WHDBO FRZP P PJSM, rig up little red to freeze protect well. Pressure test lines t/ 1500 PSI. Pump 50 bbls of diesel @ 1 BPM =1350 PSI. 16:00 19:00 3.00 0 0 DEMOB MOVE DMOB P U -Tube well, set BPV and secure well. SIMOPS, rig down and clean pits. Rig released @ 1900 hrs. Page 12 of 12 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 30, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 NNE JUN 2 7 2 a S(;,p► RE: Multifinger Imaging Tool (MIT) : 3F -13A Run Date: 7/27/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3F -13A Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 21499 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: Signed: G �%�� %wL- /7,44/1/— • X99 -077 2 --\-7 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 26, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 3F -13A SCANNED JUN 2013 Run Date: 7/24/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3F -13A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21499 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: q2.1 J, Z_ Signed: 7)/tv 113-eeer(_, I • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, July 25, 2012 12:50 PM To: 'Packer, J.Brett' Subject: RE: 3F -13A (PTD#199 -077, Sundry #312 -167) Brett, Thanks for the update and background info. 1 don't see any issues with your plan forward. The 2000 psi test before leak -off verifies your BOP break is tested and holding. I agree with waiting till you can set a blanking plug and getting the full 3000 psi test on the break and also on not having to do the full BOP test until you need do your Weekly test. Regards, Guy Schwartz SCANNED MAY 0 7 2811 Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Packer, J.Brett [mailto:J. Brett.Packer @conocophillips.com] — _ • ... �....,. Sent: Wednesday, July 25, 2012 9:35 AM To: Schwartz, Guy L (DOA) Subject: 3F -13A (PTD #199 -077, Sundry #312 -167) Guy, As a follow -up to our conversation, I just want to summarize what has been done as well as the plan forward. Background • Reservoir pressure is 4,420 psi. • The well is isolated from the reservoir w/ a plug in the 3.5" liner D- nipple at 8,551' RKB and a ' WRP set above that in the 3.5" liner at 6,550' RKB. • There is a minor leak somewhere either in the 7" casing or at the ZXP liner top packer at 6,486' RKB. • The well passes an MIT -00A (7" x 9.625" annulus) • The well is static with 9.6 ppg brine in the hole. • Tubing has been pulled above the SAB -3 packer. • A LokSet bridge plug is currently set in the 5.5 casing w/ drillpipe hanging below. (We did this for added down weight while nippleing down the tubing head, just in case the casing wanted to grow due to subsidence. Summary of Events Last night, they nippled down the BOP stack, nippled down the tubing head, and nippled up the BOP stack to the 5.5" casing head. We attempted to test the break to 3,000 psi, and since we can't set a test plug in the casing head, we were testing against the 7 casing, ZXP liner top packer and WRP in the liner; meanwhile knowing that we have a minor leak downhole. We could not get it above 2,000 psi without it leaking off downhole. They verified that there were no leaks at the break or in the BOP stack at surface at 2,000 psi. Plan forward Pull the LokSet bridge plug, stand back drillpipe. Pull the 5.5" casing. Set a blanking plug and do a proper test on the break to 3,000 psi (Max. working pressure of the casing 7/25/2012 Page 2 of 2 head) In my original sundry application, I made an error in Step #8 where I said to do a "full BOP test" once the 5.5" casing was out of the hole. What I meant was to set a blanking plug and get an actual test on the break since I knew it was likely that I wouldn't be able to get a 3,000 psi test on the break beforehand. I just wanted to clarify things so there's no question as to why we weren't able to test the break to 3,000 psi after we nippled up to the casing head. Please reply with your comments /approval to continue operations as planned. Thanks! J. Brett Wacker �Dril�ng osZ Webs Workover Engineer Work# (907) 265 -6845 CeIT# (907) 230 -8377 7/25/2012 KUP 3F -13A ConocoPh1II1p5 ' t Well Attributes • Max Angle 8 MD TD Alaska. I6 K; Wellborn APSUWI . Field Name Well Status I eel (°) MD (RKB) 'Act Bite (ttK8) 500292149901 KUPARIJK RIVER UNIT !PROD 7882 7,158.60 9,350.0 Comme H25 (Ppm) OW Comment End Date ' KB -ON (R) Rig ReMae Date ••• VJBIIConrq: - 3F13# 2Jt1/10123:5232PM SSSV: NIPPLE 70 12/222004 [Last WO: 6/22/2005 41.88 12/20/1985 Sdenetic - Actal Annotation IDepth MK B) End Date Annotation Last Mod ... End Date Last Tag: 9.070.0 2/2/2006 Rev Reason: WELL REVIEW osbod 2/22/2012 Casing Strings 9 HANGER, 24 - !' Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 112.0 112.0 62.58 H WELDED Casing Description String 0... String ID ... Top (f1KB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.921 37.0 3,651.6 3,065.0 36.00 J - 55 BUTT Casing Description String 0... String ID ... Top (18(8) Set Depth (f... Set Depth (TVD)... String WE.. String ... String Top Thrd �;. PRODUCTION 7 6.276 35.0 8,050.0 5,735.7 26.00 J - 55 BTC Casing Description String 0... String ID ... Top (BKB) Set Depth (L.. Set Depth (ND)... String Wt... String _. String Top Thrd WINDOW A 7 5.000 6,626.0 6,636.0 5,263.9 26.00 L Casing Description String 0... String ID ... Top (MB) Set Depth (I - . Set Depth (TVD) ... String Wt... String ... String Top Thiel TIE -BACK LINER 5 1/2 4.950 26.0 6,493.8 5,155.6 15.50 L-80 HYDRIL 511 CONDUCTOR, Liner Details 38-112 _. Top Depth (TVD) Top Intl NIPPLE, 524 Top (5KB) ( 18,13 ) (°) Rein Description Comment ID (In) 1 i 6,482.8 5,1472 40.15 NIPPLE BAKER NO GO NIPPLE 4.437 6,484.2 5,148.3 40.15 SEAL BAKER TIE BACK SEAL STEM 4. Casing Description (String O... !String ID ... I _ Top (18(8 I ) Set Depth (f... /Set Depth (1/0) ._'String WE- !String ... /String Top Th GAS LIFT, _ LINER I 3 1/2 2.992 6,485.8 9,350.0 6,204.6 ■ 9.30 L EUE8RDMOD 3,201 iii Uner Details Top Depth . ('IVD) Top Intl - - 1Nomi._ Top (MB) 0 8,13 ) ( Item Description Comment ' ID (In) 6,485.8 5,149.5 40.16 PACKER BAKER ZXP MECH ISOLATION PACKER w/nEBACK RECEPTACLE 5.250 6,503.5 5,163.0 40.22IHANGER HMC HYDRAULIC HANGER 3.500 SURFACE, „A d► 6,511.0 5,168.8 40.25 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 37 - 3,652 ■ - - 8,550.8 5,872.9 67.35INIPPLE CAMCO D NIPPLE NO GO 2.750 8,571.9 5,881.0 67.22 HALLIBURTON 2.750 GAS LIFT, Tubing Strings Set 4,952 LLL - - -- ■ Tubing Description /String 0... String ID ... Top MKS) S Depth (f... Set Depth (TVD)... String Wt... /String ... String Top Thrd ■a TUBING WO i 3 1/2 2.992 23,8 6,519.6 5,175.4 9.20 i L-80 IBT Completion Details GAS LIFT, Top Depth 5,603 (TVD) Top Inc! N a nd "' 1. Top(IIKB) Ma/ I ° ) hem Description Comment ID (in) IR 23.8 23.8 0.00 HANGER FMC GEN III 5M TUBING HANGER 3.500 _ 524.2 524.2' 0.39, NIPPLE CAMCO D LANDING NIPPLE 2.875 LOCATOR. 5,656 F J J 5,656.3 4,514.6 41.42', LOCATOR BAKER LOCATOR SUB 3.000 SBE, 5.659 _.] 5,658.7 4,516.4 41.41'1 SBE BAKER SEAL BORE EXTENSION 3.000 ANCHOR, aa($ -v 5,672 I�_.- ' 5,672.4 4,526.7 41.37 ANCHOR BAKER ANCHOR 3.000 PACKER, 5,673 - __ 5,673.1 4,527.3 41.37 PACKER BAKER SAB-3 PACKER (MILLED OUT TO 2.81" ID 7!10!05) 2.810 6,376.5 5,065.3 39.21 SLEEVE BAKER CMD SLIDING SLEEVE w/ BX PROFILE 2.812 6,458.0 5,128.2 40.06 NIPPLE HES X PROFILE NIPPLE 2.813 SLEEVE, 6,376 -- 6,471.6 5,138.6 40.11 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.850 r . Other in Hole reline retrievable per valves, pumps, fish, etc.) Top Depth ND Top (MB) (tn(f3) Top Inc! Description Run Date ID (In) NIPPLE, 6,458 - -- 8,550.8 5,872.9 67.35 PLUG 2.75" CA -2 PLUG SET IN NIPPLE 7/29/1008 0.000 i nt 8,600.0 5,891.8 67.05 FISH 13" OF JD SPRING DOWNHOLE 7/29/2008 0.000 III Perforations & Slots Shot Top(TVD) Btm(TVD) Dens Top (MB) Btm (MB) DR(B) (MB) Zone Date (ah... Type Comment 8,553.0 8,570.0 5,873.8 5,880.2 C-4, 3F -13A 4/22/2000 4.0 APERF 2.5" HC-DP, 180 deg ph, +/- 90 deg orient TIE 9,070.0 9,100.0 6,083.6 6,096.4 A -2, 3F -13 9/20/1999 4.0 IPERF 2.5" I-1C; 180 deg ph LINER, Notes: ^___�. y 26-6,494 & SEAL ASSY, 6 N General Safety 6,472 1 End Date Annotation " 9/3/1999 NOTE: WELL SIDETRACKED 'A' 7/16/2005 NOTE: 2 SLIPS FROM ECLIPSE PACKER LOST DOWNHOLE 10/12/2005 NOTE: LEAK FOUND @ UPPER PACKER @ 5678' 11/5/2010 NOTE: View Schematic w/ Alaska Sdmmahc9.0 WINDOW A, 6,6266,636 1 PRODUCTION l � 35 -8,050 PLUG, 8,551 Mandrel Details Top Depth Top Port APERF, h,cl 00 Valve Latch Sine TRO Run 8,5538,570 - - Sin Top (RPM) Ifti(B) 11 Make Mode (In) sere Type Type PO Ipel Run Date Com... 1 3,201.5 2,757.7 48.54 CAMCO KBG2 -9 1 GAS LIFT GLV BTM 0.156 1,289.0 6/26/2005 ® 2 4,952.1 3,995.6 43.01 CAMCO KBG2 -9 1 GAS LIFT GLV BTM 0.188 1,324.0 6/26/2005 FISH, 8,600 -- 3 5,603.0 4,474.9 41.59 CAMCO KBG2 -9 1 GAS LIFT OV BIM 0.250 0.0 6/26/2005 ERF, 9, 0708 IP ,100 - LINER, 6,406-9,350 ' TD (3F -13A), 9,350 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 15, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 3F -13A Run Date: 6/12/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3F -13A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21499 -01 SCANNED JUN 2 7 2,013 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: Signed: / _ • • g , S SEAN PARNELL, GOVERNOR CYLeH Li ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Brett Packer Senior Wells Engineer o 7 ConocoPhillips Alaska, Inc. 10101' P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3F -13A Sundry Number: 312 -167 SLAWNETRAY 2012 Dear Mr. Packer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P9;le.-01/474--"---' Cat . Foerster Chair DATED this 10 of May, 2012. Encl. li • • ConocoPhilhps Alaska P.O. BOX 100360 RECEIVED ANCHORAGE, ALASKA 99510 -0360 April 27, 2012 APR 2 7 2012 Commissioner AOGCC State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7` Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover Kuparuk Well 3F -13A (PTD# 199 -077). Producing well 3F -13A was originally completed in 1999 as a sidetrack of 3F -13. The sidetrack placed a 3 'h" liner to bottom and also installed a 5 1/2' tie -back liner to surface because the well was known to have a casing starter head leak when on gas lift. - The well was completed with 3 ' /2" tubing and slimhole gas lift mandrels, making this essentially a "monobore" completion. 3F -13A failed a TIFL in May of 2003. Attempts were made to regain tubing integrity by changing out GLV's, but the well continued to fail a TIFL. In October 2003, an Eclipse patch was set across GLM #3. This temporarily fixed the tubing x IA communication. The well produced until January of 2005 when the well died. A leak detect log in February 2005 discovered - multiple tubing leaks thus requiring a rig workover. While preparing for the workover, it was found that the 5 ' /2" casing was communicating with the 7" casing. A RST /WFL was run and the top leak in the 5 '/z" casing appeared to be no shallower than 5,765' RKB. The rig workover in June 2005 straddled the 5 'h" csing leak with the new 3 1/2" completion, the seal assembly provided the bottom isolation and the packer in the 51/2" casing provided the top isolation. During the post -rig work following the RWO, they discovered that the packer bore was 2.80" and the RHC plug body below the packer was 2.813 ", thus we had to mill the packer bore to 2.813" in order to be able to pull the RHC plug body through. After attempting to flow the well, the tubing loaded up with fill immediately. Following a fill cleanout, a caliper was run and found damaged liner between 6,900' and 7,000' MD. Prior to the workover, plans are to cement squeeze this damaged area of the liner. It appears that the milling operation on the packer back in 2005 compromised the packer because we are seeing TxIAxOA communication once again, and the well has basically been SI since the last workover. The proposed workover will pull and replace both the 3 1/2" tubing and the 5 'h" casing strings. The well passes an MIT -OOA (7" x 9 %" annulus), so with a successful workover, we will adequately restore two barriers for gas lifting the well. This Sundry is intended to document the pulling and replacing of the casing as well as request approval to workover the well. The most recent SBHP was obtained on 7/28/08 and measured 3,992 psi at 9,040' MD (6,071' TVD), equivalent to an EMW of 12.6 ppg. The well has been SI since the last SBHP, so the reservoir pressure may have decreased since then due to any offtake in the area. A current SBHP will be obtained prior to the workover. There is currently a plug set downhole, but prior to the plug being set, the max historical SIWHP was 1,800 psi. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 265 -6845. Sincerely, �! Brett Packer Wells Engineer CPAI Drilling and Wells STATE OF ALASKA 407 s /f / , Z RECEI V ED 1 AIWA OIL AND GAS CONSERVATION COMM WON APPLICATION FOR SUNDRY APPROVALS APR 2 7 2012 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Fool r Repair well ` t , �i Change App g ogram f Suspend r Aug Perforations E Perforate r Pull Tubing l✓ Time Extension r Operational Shutdown r R -enter Susp. Well r Stimulate Alter casing � r g F,-; Other: ('""' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F,-,.' Exploratory r 199 -077 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 21499 -01 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No P" 3F -13A • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25632 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 ND (ft): Plugs (measured): Junk (measured): 9350 • 6205 • 9254' 6161' 8551' 8600' Casing Length Size MD ND Burst Collapse CONDUCTOR 74 16 112' 112' SURFACE 3615 9.625 3652' 3065' PRODUCTION 8015 7 6635' 5264' isolation string 6447 5.5 6485' 5150' LINER 2865' 3.5 9350' 6205' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8553'- 8570', 9070' -9100' 5874'- 5880', 6084' -6096' 3.5 L -80 6520 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - BAKER SAB -3 PACKER MD= 5673 TVD= 4527 PACKER - BAKER ZXP ISOLATION PACKER MD= 6486 TVD= 5150 NIPPLE - CAMCO D LANDING NIPPLE MD= 524 TVD= 524 12. Attachments: Description Summary of Proposal r,�" 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/25/2012 Oil r ` Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265 -6845 Printed Name '7j/e.--- Brrett acker Title: Sr. Wells Engineer Signature i ''� (A'■. Phone: 265-6845 Date 1 /47//2 Commission Use Only Sundry Number: 'il I Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test Mechanical Integrity Test r Location Clearance r 4 Other: Ot/ ir7 / e fey aS I fr7Cl/Ca le - ei . 3G vo # 50P /C5 Subsequent Form Required: � APPROVED BY Approved by: agiv / T COMMISSIONER THE COMMISSION Date: — -/ Form 10 -403 Reviled 1/2010 0,1 ^ MAY 0 9 2 012 Submit in Duplicate J2I ,, 51 P c LIII K UP • 3F -13A ConocoPhiltips � Well Attributes Max Angle & MD TD Alaska, Inc Wellbore APUUWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) 500292149901 KUPARUK RIVER UNIT PROD 78.82 7,158.60 9,350.0 Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date "' SSSV: NIPPLE 70 12/22/2004 Last WO: 6/22/2005 41.88 12/20/1985 Well Gentle - 3-8, 22/201 Scne -12ACwaI 2 3 52:32 PM Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 9,070.0 2/2/2006 Rev Reason: WELL REVIEW osborl 2/22/2012 Casing Strings HANGER 24 ...., 'P.' Casing Description String 0... String ID ... Top (666) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd CONDUCTOR 16 15.062 38.0 1120 1120 62.58 H - 40 WELDED 1 r Casing Description String 0... String ID ... Top (fIKB) Set Depth (f... Set Depth i 3,065.0 V tt J-55 BUTT SURFACE rising PRODUCTION • t : t t tt J-55 BTC WINDOW Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String VVt... String ... String Top Thrd ttt 6,626.0 6,636.0 5,263.9 26.00 a Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TIE LINER 5 1/2 t 26.0 t :t HYDRIL CONDUCTOR, 1 11 Liner t . 38 -112 NIPPLE, 524 UR Top Description laill 6,482.8 5,147.2 40.15 NIPPLE BAKER NO GO NIPPLE 4.437 MI 6,484.2 5,148.3 40.15 SEAL BAKER TIE BACK SEAL STEM 4.250 MI Casing Description String 0... String ID ... T op (ftKB) Set Depth (L.. Set Depth (ND) ... String Wt... String ... hrd cns LIFT, LINER 1 3 1/2 I 2.992 I 6,485.8 I 9,350.0 I 6,204.6 I 9.30 L - 80 I String lop 7 EUE8RDMOD 3,201 I - Liner Details Top Depth (ND) Top Ind Nomi... Top (ftKB) (MB) (1 Rem Description Comment ID (in) 6,485.8 5,149.5 40.16 PACKER BAKER ZXP MECH ISOLATION PACKER w/TIEBACK RECEPTACLE 5.250 6,503.5 5,163.0 40.22 HANGER HMC HYDRAULIC HANGER 3.500 SURFACE, 6,511.0 5,168.8 40.25 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 37 -3,652 8,550.8 5,872.9 67.35 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,571.9 5,881.0 67.22 NIPPLE HALL)BURTON POLISH NIPPLE 2.750 cns 4152 .--, Tubing Strings .. ,. i Tubing Description String .. String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING WO I 0. 3 1/2 I 2.992 I 23.8 6,519.6 I 5,175.4 9.20 L-80 IBT Completion Details GAS LIFT, Top Depth 5,603 ki 4 13 (TVD) Top Inc! NomL.. Top (ftKB) (ftKB) E) Item Description Comment ID (in) V I r 23.8 23.8 0.00 HANGER FMC GEN III 5M TUBING HANGER 3.500 524.2 039 NIPPLE CAMCO D LANDING NIPPLE 2.875 LOCATOR, 5,656 ± ' 4,514.6 LOCATOR BAKER LOCATOR SUB 3.000 SBE, 5,659 / 5,658.7 4,516.4 41.41 SBE BAKER SEAL BORE EXTENSION 3.000 ANCHOR, _.3.' ■ s,67z - -- _ 5,672.4 4,526.7 41.37 ANCHOR BAKER ANCHOR 3.000 PACKER, 5,673 _ Fat ito 5,673.1 4,527.3 41.37 PACKER BAKER SAB -3 PACKER (MILLED OUT TO 2.81" ID 7/10/05) 2.810 6,376.5 5,065.3 39.21 SLEEVE BAKER CMD SLIDING SLEEVE w/ BX PROFILE 2.812 illr 6,458.0 5,128.2 40.06 NIPPLE HES X PROFILE NIPPLE 2.813 SLEEVE, 6,376 6,471.6 5,138.6 40.11 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.850 1116, Other In Hole Wireline retrievable • lu• s, valves, . um .s fish etc. 11111 Top Depth gm Top (ftKB) Description Comment Run Date ID (in) NIPPLE,6,456 an 8,550.8 PLUG 2.75" CA-2 PLUG SET IN NIPPLE tt: toot - 8,600.0 5,891.8 67.05 FISH 13" OF JD SPRING DOWNHOLE 7/29/2008 0.000 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm(ftKB( MB) (ftKB) Zone Date (sh... Type Comment 8,553.0 8,570.0 5,873.8 5,880.2 C-4, 3F -13A 4/22/2000 4.0 APERF 2.5" HC-DP, 180 deg ph, +/- 90 deg orient TIE -BACK t 9,070.0 9,100.0 6,083.6 6,096.4 A -2, 3F -13 9/20/1999 4.0 NM 2.5" HC; 180 deg ph LINER, e 26 -6,494 SEAL ASSY, 0 Notes: General & Safety 6,472 :- - End Date Annotation 9/3/1999 NOTE: WELLSIDETRACKED'A' _ _ _ 7/16/2005 NOTE: 2 SLIPS FROM ECLIPSE PACKER LOST DOWNHOLE 10/12/2005 NOTE: LEAK FOUND © UPPER PACKER © 5678' 11/5/2010 NOTE: View Schematic w/ Alaska Schematic9.0 WINDOW A, 6,626 -6,636 : j4 '°I- PR000CTION. 1, 35 -8,050 PLUG,8,551 Mandrel Details Top Depth Top Pon APERF, (TVD) Inc! OD Valve Latch Saxe TRO Run 8,553-8,570 Stn Top(RK (ftKB) ( °) Make Model (in) Sery TYPe Type lin) (Psi) Run Date Com... 1 3,201.5 2,757.7 48.54 CAMCO KBG2 -9 1 GAS LIFT GLV BTM 0.156 1,289.0 6/26/2005 2 4,952.1 3,995.6 43.01 CAMCO KBG2 -9 1 GAS LIFT GLV BTM 0.188 1,324.0 6/26/2005 FISH, 8600 - 3 5,603.0 4,474.9 41.59 CAMCO KBG2 -9 1 GAS LIFT OV BTM 0.250 0.0 6/26/2005 IPERF, 9,070 -9.100 LINER. 6,486 -9,350 TD (3F -13A), , • • 9,350 0 • ConocoPhillips Well: 3F -13A 2012 RWO Proposed Completion )i to 16" 62# H-40 to 112' MD 9 -5/8" 40# L -80 to 3,652' MD ■ New 3 -1/2" Gas Lift Completion 3 - 1/2" 9 3# L -80 IBTM Tubing Camco 2.875 ' 'DS' Nipple @ -500' MD 5x Camco 1" KBG2 -9 Gas Lift Mandrels Camco 2.813" 'DS' Nipple @ `XXXX' MD Baker GBH -22 Seal Assy. (15' seals) u ks c 5 -1/2" 15.5# L -80 Tie -back Liner to 6,485' MD ,1 4 Existing 10' Tie -back Sleeve at 7,486' MD f Existing 5 -1/2" x 7" Liner Top Packer WI at 7,496' MD Existing 20' SBE @ 6,511' MD 7" 26# L -80 shoe at 8,050' MD ■ Ij '!, 4 Existing 2.75" D Nipple @ 8,551' MD 1 C-4 sand nerfs 8.553' - 8.570' MD 1 ' o" 1 A -2 sand perfs 9,070' - 9,100' MD "'aill 3 -1/2" 9.3# L -80 Liner from 6,485' to 9,350' MD • • 3F -13A Rig Workover Pull & Replace 3 ' /2" Tubing and 5 Y2" Casing (PTD #: 199 -077) Current Status: This well has been SI since January 2005 and cannot be brought online due to TxIAxOA ' communication and a damaged liner between 6,900' — 7,000' MD. Scope of Work: Cement squeeze the damaged casing pre -rig. Pull and replace the 3 'h" tubing and 5 ' /2" casing. General Well info: Well Type: Producer MPSP: 1,800 psi (based on max historical SIWHP) Reservoir pressure /TVD: 3,992 psi / 6,071' TVD (12.6 ppg) Wellhead type /pressure rating: FMC Gen III, 7- 1/16" 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: MIT -OOA passed on 9/24/09. CMIT T x IA x OA to be done pre -rig. Earliest Estimated Start Date: May 25, 2012 Production Engineer: Len Jansen / Jeremy Mardambek Workover Engineer: Brett Packer (265 -6845 / j.brett.packer @conocophillips.com) Pre -Rig Work 1. RU Slickline: a. Set catcher sub above CA -2 plug at 8,551' RKB. Pull GLV's from GLM's #1 & #2, replace w/ DV's. Pull OV from GLM #3 and leave pocket open. Open sliding sleeve at 6,376' RKB. Pull catcher sub and CA -2 plug at 8,551' RKB. b. RIH w/ dual Panex gauges and obtain mid -perf A/C combined SBHP. c. Set composite bridge plug at 7,050' RKB. 2. RU CTU: a. RIH w/ 3.5" cement retainer, set retainer at 6,865' RKB, determine injection rate. b. Cement squeeze damaged liner (between 6,900' — 7,000' RKB). WOC for —12 hrs. c. RIH w/ 2.80" mill, mill up cement retainer and cement in liner down to 7,020' RKB. CMIT TxIAxOA to 2,000 psi. Mill up composite bridge plug at 7,050' RKB. Circulate well clean. 3. RU Slickline: a. Install CA -2 plug at 8,551' RKB. b. Set WRP at 6,550' RKB w/ catcher sub on top. c. CMIT TxIAxOA to 2,000 psi. Perform drawdown test. 4. Pressure test TBG, IC, and OC packoffs, FT LDS's. 5. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU Doyon 141. 2. Pull BPV. RU to OA valve, reverse circulate 60 bbls KWF (est. 13 ppg mud) down OA taking returns out the tubing. RU to IA valve, reverse circulate 120 bbls KWF down the IA taking returns out the tubing. Obtain SITP & SICP, seeing any pressure at surface, calculate new KWF and repeat circulation as necessary. Verify well is dead. 3130 5c ct5f 3. Set BPV & blanking plug, ND tree, NU BOPE & test. Nfl &U ce , y2j e , c fcK 241 116 4. Pull blanking plug & BPV, screw in landing joint, BOLDS's, unlankl tubing hanger. (4 ✓ t L' L F t . • • 3F -13A Rig Workover Pull & Replace 3 Y2" Tubing and 5 1 /2" Casing (PTD #: 199 -077) 5. POOH laying down 3 'A" tubing. a. If tubing will not pull free, RU E -line and cut the tubing at 5,630' MD. 6. PU & RIH w/ 3 'A" drillpipe to 5,500' MD, install storm packer and set at —100' MD w/ drillpipe hanging below. NDBOP & tubing head. NU BOP stack to 5 'A" casing head & test break to 3,000 psi (max pressure). Release / storm packer and POOH laying down storm packer. POOH standing back drillpipe. 7. Spear 5 'A" casing and simultaneously pull both the 5 'A" casing out of the tie -back sleeve and the 3 'A" seal assembly out of the SBE. Circulate KWF around. P0014 laying down 5 'A" casing until reaching the SAB -3 packer at 5,673' RKB. a. RU false table and POOH laying down remaining 840' of 3 'A" tubing. b. POOH w/ remaining 5 'A" casing. 8. Set test plug in 5 'A" casing head and do full BOP test. Pull test plug. 9. RIH w/ 7" casing scraper and spear extension on drillpipe down to tie -back sleeve, circulate hole clean. Attempt to spear remainder of seal assembly left in the SBE from the 2005 RWO at 6,520' RKB. POOH laying down drillpipe. 10. RU Slickline: RIH w/ 40 arm caliper, log from 6,400' RKB back to surface. RD Slickline. 11. Offload old tubing & casing, rack & tally new tubing & casing. 12. RIH w/ new 5 'A" L -80 Hydril 511 casing and seal assembly. Locate tie -back sleeve. Mark pipe and pull up one joint, space out. Record up /down weights. 13. Close the annular and load the 5 'A" x 7" annulus with gelled diesel, strip the 5 'A" casing through the bag and land in the tie -back sleeve. PT the 5 'A" x 7" annulus to 2500 psi. Bleed pressure to zero. Open annular, and monitor for 30 min to verify no flow. 14. ND BOP stack. PU 5 'A" casing to string weight + 1 ft, set the casing in the slips, install casing packoff. RU Wachs cutter and cut excess 5 'A" casing. NU tubing head, PT packoffs. NU BOP stack to tubing head. Set test plug, PT break. 15. PU & RIH w/ seal assy. and new 3 'A" IBTM -SCC tubing. Locate SBE, mark the pipe and pull up one joint. 16. Space out w/ pups, MU hanger. Swap well over to 9.6 ppg corrosion inhibited brine. Land the hanger, RILDS. 17. PT the tubing to 3,000 psi, bleed tubing to 2,500 psi, PT the IA (3 'A" x 5 'A" annulus) to 3,500 psi for 30 min and record. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 18. Pull the landing joint, install two -way check. 19. ND BOPE. NU and test tree. Pull two -way check. 20. Freeze protect through the SOV, set BPV. 21. RDMO Doyon 141. Post -Rig Work 1. Reset well house(s) and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: Pull SOV and replace w/ DV. PT tubing & IA. Pull catcher sub, pull WRP at 6,550' MD. Pull CA -2 plug at 8,551' RKB. Tag fill. 4. FCO if necessary. 5. Turn well over to operations. . ~ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 2, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED S EP 0 8 2003 V~~'DìÎ Dear Mr. Maunder: " Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU) 3F Pad. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, 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 top-fill operation was completed on August 14,2006 and is reported as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 21-29,2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7043",,/({You have any questions. //' Sincerely, /'1' /? /// / (/~/~I /" . f{/).t/.j/;'Z~/#~~ /' j if /' / M.J.loveland ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 8/31/2006 Initial Top Cement Final Top Sealant Well Name PTD # of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date .' 3f:O,1:, " -- 18â:""3:2Q¡ , , NA' , , l..~ ' , gf~'fr~UØ~ . , 3F-02 185-226 24' 7.0 8/14/2006 7.5 8/21/2006 . . 3F'~Ø3 . "', HJ5~2:27' c·;, 5,. ' J3~4" .. '." 23 " .... '., ' 8tt4lZ~O~ r· " ·:$)~1/~Q:tIØ·¡ ,." < '., _' '- '_f., . "', 'i>' '''''.--:",.,.:'.--". .'" 3F-04 185-228 80' 22.7 1 0' 8" 8/14/2006 38.2 8/21/2006 ·3~E,Ø:q;;:;;., ~ ':' '. 5.1 " .. .', ;'" .:. .' ,'" --aì1{if/fiOr;f6 " 1:5." , ·'gf~11~òø:6: 3F-06 Did not modify 3P¡:9i7c' .' '.' :; '''~$f~5:: '.,- .- , &.6 ' ,8/14/2Q.06 r, 7;5 ., :8¡21ì~ØQ6' " 3F-08 185-246 1 1 '4" 2.6 8/1 4/2006 6.6 8/21/2006 3F::&\1 ",' . ja~4iIO Did not modify 3F-1 0 1 85-271 SF NA NA 6.6 8/21/2006 . ;áf,,.l1' .... . ,'<,- la5~~12 , '. NA , 'N,4.;:, .. "- .1,.7 SI~3/2Q{);~ . '.' . 3F-1 2 185-273 7'4" 1 .8 8/1 4/2006 6.2 8/23/2006 " ~ ...... 4.REta~!¡~~ ~ '¿':tffJ.gl(~tl~è~: '_ - --_,_ _~. "^'._ ~_-_" ,...·."'",d_. _, ~ ~Did not "M .. .. .2)1, .. ..... .' , . ,~8'11¡fl2ø:Q~;':/ ..". '''. ' ,.; :.:~øl:2:~t~Ð'Ø6 3F-16 196-151 6" NA NA 2.7 8/23/2006 ~ ~ ~. ..' ··1'1" . ,.... 3.1 . . , .'. ;·äf14Z20€!ß,. . ..' . 8 . ·.ø/~É2øn~ ' 4' NA NA 28 8/23/2006 ·3¡;~;'f9: -.~-;-" .. ':"~Ø':4~1tìf~;:; f;' ' .A!'.. .' ··,NA..·.·. 8", .~A'.', . . ';. 2 . ãf2~1QijØß;, , . " , .., 3F-20 199-079 36" NA NA 1 7.7 8/23/2006 3F~2í " . '2QÔ+2Ò~' .' ' .' 45'" NA NA 3-1 .. 8/,21'l2ÔÞ6 , RE: 1A-09 (PTD 1811520) cause of failed MW identified by ne... e Sub.iect: RE: 1 A-09 (PTD 1811520) cause of làiled MlTIA identified by new LDL tool From: NSK Problem Well Supv <n I G17@conocophillips.com> Date: Mon, 17 Oct 2005 09:21 :53 -0800 To: NSK Problem Well Supv <nl617@collocophillips.eom>, Thomas Maunder <tom _ _ maunder@admin.state.ak.us> CC: James Regg <jim_regg@admin.state.ak.us> Tom, The other wells are: 3G-24 - tbg leak found between bottom GLMs at 9346' 3F-13A - Tbg leak to OA found in the packer at 5678~ , ~<\ - a~, 30-19 - casing leak found in the liner at 5512' / ' All these will have sundries for repair that will report the leak depths once a repair plan is decided. Marie -----Original Message----- From: NSK Problem Well Supv Sent: Monday, October 17/ 20059:14 AM To: 'Thomas Maunder' Cc: 'James Regg' Subject: RE: 1A-09 (PTD 1811520) cause of failed MmA identified by new LDL tool ( Tom, The work load here is such that if a report isn't required there isn't time or resources to create it or it would take time away from monitor the wells for integrity and catching any compliance issues to avoid NOVs, our highest priority. The email was something I sent you as a courtesy as I thought you'd be interested from both a well and engineering prospective. This work will be reported on the summary list of completed wellwork submitted to AOGCC as required. If a repair is made on this well, the sundry will mention the leak depth. Yes, our internal guidelines have changed, internal waivers are no longer issued for failed MITIAs if the well also had a failed MITOA. Marie -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, October 17/ 2005 8:01 AM To: NSK Problem Well Supv Cc: James Regg Subject: Re: 1A-09 (PTD 1811520) cause of failed MITIA identified by new LDL tool Marie, Good news on the new diagnostic tool. Is it possible to submit a "report" of the work on lA-09? You could submit it with a 404. What are the other wells that you indicate were successfully logged? You state that lA-09 no longer meets CP AI internal requirements. Have the internal requirements changed? Look forward to your reply. 10f2 3/6/200610:18 AM RE: 1A-09 (PTD 1811520) cause off ailed MW identified by ne... e Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 10/16/20054:18 PM: Tom, This note is to inform you of recent diagnostic results on 1A-09 (PTD 1811520). This well has a failed MITIA (Sundry approval 303-307) that was assumed to be a packer or casing leak as an MITT wmp passes. The leak rate was too slow to identify the depth with known logging tools. A new ultrasonic leak detect logging tool (tecwel) was ran in the well on 10/8/05 and identified the leak depth at 2574'. I reviewed the 303-307 sundry for the failed MITIA and didn't see any issues. CPAI has determined this well no longer meets our internal requirements and the well has been SI. The leak is in close proximity to the OA cmt shoe and the OA shoe leaks. At this time, it is uncertain when or how the well will be repaired, but the appropriate sundry will be submitted at that time. Tecwel can measure leak rates down to something around a quart or cup per minute. Three other wells with small leaks were logged successfully. Marie McConnell Problem Well Supervisor 659-7224 20f2 3/6/200610:18 AM ) ) Howard Gober Wells Engineer Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4220 July 19, 2005 RECEIVED JUL 2 0 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission Anchorage Subject: Report of Sundry Well Operations for 3F-13A (APD # 199-077 1305-130) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operation on the Kuparuk well 3F-13A. If you have any questions regarding this matter, please contact me at 263-4220. Sincerely, ~ H. Gober Wells Engineer CPAI Drilling and Wells SCANNED JIlL 2 0 2005 HG/skad RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 2 0 2005 REPORT OF SUNDRY WELL OPERA TION$laska Oil & Gas Cons Co .. ~, mmltSfO'l Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other AndhØrsge 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 0 199-077/305-130 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21499-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 93' 3F-13A 1. Operations Performed: ) ) STATE OF ALASKA 8. Property Designation: AD L 25632, ALK 2565 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURF CASING PROD CASING CSG WINDOW TIE BACK LINER LINER Perforation depth: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 9350' feet true vertical 6205' feet measured 9116' feet true vertical feet Length Size MD 112' 16" 112' 3559' 9-5/8" 3652' 7957' 7" 8050' l' 5-1/2" 6636' 6392' 5-1/2" 6485' 2865' 3.5" 9350' Measured depth: 8553'-8570', 9070'-9100' Plugs (measured) Junk (measured) TVD Burst Collapse 112' 3065' 5736' 5264' 5149' 6205' R8DMS 8Fl JUL 2 0 2005 true vertical depth: 5874'-5881',6084'-6096' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6525' MD. ~OOl 0 Z lnr 1:18 SWCmJ Packers & SSSV (type & measured depth) pkr= BAKER SAB-3 pkr, Eclipse pkr@ 5673',6583' Cameo '0' Landing Nipple @ 524' 12. Stimulation or cement squeeze summary: Intervals treated (measured) n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinç¡ Pressure Tubinq Pressure Prior to well operation SI Subsequent to operation 93 196 304 181 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: oil0 GasD WAG 0 GINJD WINJ 0 WDSPLD 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 Printed Name Signature Howard Gober @ 263-4220 Howard Gober ~ Wells Engineer Title Phone .=1/, q 1~5 Date U RIG II~ A L Preoared bv Sharon AI/suo-Drake 263-4612 Form 10-404 Revised 04/2004 Submit Original Only ) ) '" .. '. ,. '.' . ... ......nT~?Ø~Q~~mi~~·~I~~ ..:. .... Oper~ti()n~.·$~.~m~·ry.··.·Ii~port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3F-13 A 3F-13 A WORKOVER/RECOMP n 3scm@conocoph¡lIips.com Nabors 3S Start: 6/17/2005 Rig Release: Rig Number: Spud Date: 12/12/1985 End: 6122/2005 Group: ·lfrorn':Tq HoÜrs ·€Óde: .. Sub . Þhåsé Code' ... '.. .. . .... . ".. . ···þ~SÂtiptìÔri ôfþpèrå~iBr\~·. 6/17/2005 00:00 - 01 :00 1.00 MOVE RURD MOVE Pulled off previous well @ 3H; prepped for move. 01 :00 - 03:00 2.00 MOVE MOVE MOVE Moved rig to 3F-13. Onsite, spotting, & rigging equipment. 03:00 - 12:00 9.00 WELCTL NUND RIGUP Moved rig to 3F-13. Onsite, spotting and riging up. Ordered 60 bbls potable water and 2600 gals diesel. Called AOGCC delayed BOP test. 12:00 - 15:30 3.50 WELCTL NUND DECOMP Rig accepted 6/17/05 at 12:00 15:30 - 15:45 0.25 WELCTL SFTY DEMOB Crew chane out; tour meeting-plan forward 15:45 - 20:45 5.00 WELCTL NUND DECOMP Begin NU BOP's 20:45 - 00:00 3.25 WELCTL NUND DECOMP Gave AOGCC 2-hr notice of upcoming BOP test; Waived by state rep John Crisp. Cont. nippling up. 6/18/2005 00:00 - 05:00 5.00 WELCTL BOPE DECOMP Begin test BOP stack. 05:00 - 11 :30 6.50 WELCTL BOPE DECOMP Having difficulties getting initial test; appears that blanking plug is leaking by. Discuss wI valve rep. Pulled blanking plug run test joint test rams. 11 :30 - 16:00 4.50 WELCTL TRIP DECOMP BOP test still leaking by. Called AOGCC permission granted by Lou Grimaldi to pull hanger and run test plug. LDS were backed out. Gland nuts torqued. hanger was pulled out of tubing head. Hanger and tubing string were recipricated several times in an attempt to pull out of PBR. Hanger was pulled to rig floor and it was noticed that the elastomer rubber seal was missing. (Nitrile packing FMC part #82-742-201, approx. 1/2" x 1/2" x 6-7/8" round 5-7/8" ID).Pulled out of seals at 145K. Well began to flow. Shut in well. Monitored tubing pressure. Tubing pressure is building. 16:00 - 18:00 2.00 WELCTL CIRC DECOMP Circulate 2X hole vol. Shut in well and monitor. 18:00 - 20:00 2.00 WELCTL OBSV DECOMP Pressure test tbgllAlOA to 1000 psi; hold for 15 mins-solid, plug appears to be holding. Bleed down and monitor. Tbg/lA pressure climbing to 290 psi. 20:00 - 22:00 2.00 WELCTL CIRC WRKOVR Begin circulating once again down tbg, up IA. Getting crude mixed wI brine back to pits. 1000 psi dp, holding 300 psi IA. 260 bbls away, shut down to monitor. 22:00 - 00:00 2.00 WELCTL OBSV WRKOVR TBG/IAlOA leveling off at 320 psi. Call WO Eng to discuss. Rig up to circulate 5-1/2x7 annulus. 6/19/2005 00:00 - 02:00 2.00 WELCTL CIRC DECOMP Begin circulating down tbg up 5-1/2x7" annulus. No gas, trace of crude to pits. Taking fluid wgts every 15 mins= 9.5# light. 02:00 - 03:00 1.00 WELCTL OBSV DECOMP 120 bbls around; shut down. Bleed off whtp. Immediately climbs back to 290 psi= TbgllAlOA all tracking. Call out kill wgt brine.Perform 30 min tbgxlAxOA MIT to 1000 psi; holds solid 03:00 - 04:00 I 1.00 WELCTL CIRC DECOMP Come back online to circ 3 hole vol down tbglup lA, hold 380 psi @ I choke- traces of crude in rtns. 04:00 - 06:00 2.00 WELCTYOBSV DECOMP Shut down to monitor well. Immediately came up to 290 psi, 330 psi I I after 20 mins. 06:00 - 12:30 , 6.50 WELCTL CIRC I DECOMP Pump 11.2 ppg kill for 7" x 5.5" and 5.5" x 3.5" tbg. 5.5 casing hole I I I I apeared to partially plug at end of kill pressuring up to 3400 psi. monitor : well for flow. : Updaded Lou Grimaldi (AOGCC) on testing situation. 12:30 - 18:00 5.50 WELCTL BOPE DECOMP Landed hanger with landing joint, test rams, annular, choke. 18:00 - 00:00 6.00 WELCTL BOPE DECOMP ,Ran blanking plug to test blinds. BOP Test complete-rams 250/3500, , annular 250/2500-passed. Pull pluglBPV. Prep to begin pulling tbg. 6/20/2005 00:00 - 17:00 17.00 FISH PULL DECOMP Begin pulling 3-1/2" completion laying down sideways. Some corrosion , on last 8 collars 17:00 - 21 :00 4.00 CMPL TN CIRC CMPL TN Completion out of hole. Circulate down 7" backup5-1/2" annulus with 11.2 brine. To insure we can cir. Having problems with pipe skate control-call out electrician. 21 :00 - 23:00 2.00 CMPL TN RUNT CMPL TN Pipe skate appears to be working now; conduct pre-job safety meeting. Printed: 7/15/2005 2:05:22 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . . . . ... . .. .... . . : . .: . "..:: "::.". ...:",.. ::" ".:" .:...... ". "' ..... ....... ..·9()nþqØRhilliÞ~AI~~~a··. . . .......",.... .... '. :" ... :n.:. ::".: .:' ::':..'::. ..... : ... . .... ".. .. .. . .." :.: :....: ";" . ()þ~råiti()~sl.~µmr11¡¡rY..·Rep()n:.··· 3F-13 A 3F-13 A WORKOVER/RECOMP n3scm@conocoph¡llips.com Nabors 3S Start: 6/17/2005 Rig Release: Rig Number: Spud Date: 12/12/1985 End: 6/22/2005 Group: . . . . . . . ... ... -..."' D~ss,,¡p~iÔr· of (j)pøratÎ()rI$ P· ·..·r··.o.··m··...·.·. .._..·....T.·.·.O· · H··. ·.0··· .·.u··· r··s····.·. C·od·e SUb p.. ·.·h.·.··.·.a·· ·s· e·· .......... L . ........ .... . Code.. 6/20/2005 21 :00 - 23:00 23:00 - 00:00 00:00 - 14:00 14:00 - 16:00 6/21/2005 16:00 -19:30 19:30 - 00:00 6/22/2005 00:00 - 01 :20 01 :20 - 04:10 04:10 - 06:00 06:00 - 10:00 10:00 - 11 :30 11 :30 - 17:00 17:00 - 23:30 2.00 CMPL TN RUNT CMPL TN Begin running new completion. 1.00 RIGMNT RGRP CMPL TN Shut down to repair pipe skate again. 14.00 CMPL TN RUNT CMPL TN Continuing to run new 3-1/2" completion. 2.00 CMPL TN RUNT CMPL TN RIH to locateSBE. Circulated down with charge pump until pressure increased indicating entering SBE. Bled pressure to 0 psi. Slacked off 5' putting 25K, lost wt gain l' then applied 25K with no movement. Kicked charge pump in, put 70psi, PU, at 62K up wt. started to move pipe, PU 6' lost pressure. Entering SBE only 6'. Performed this twice to confirm stackout. 3.50 CMPL TN RUNT CMPL TN Confirmed with Anchorage to complete well as-is and allow wells group to trouble shoot fill issues in the SBE. Loaded truck of brine on location. Truck showed up with 12.2 PPG brine w/2% Baker Petrolite CRW132. Asked MI to dilute for effect on completion fluid. Pick up spaceout pups and hanger. Clean rig and prepare for move. 4.50 CMPL TN RUNT CMPL TN 12.2 PPG brine was over diluted to 10.8 heavy. sent truck to off load brine at KIC and pick up new batch of Baker Petrolite CRW132. KIC out of CRW132. Rousted warehouseman from bed at KOC to issue new TOTE. 1.33 CMPL TN CMPL TN Truck arrived on location with CRW132 on board. Take on 70 BBLs from tank farm. prep to circulate. 2.83 CMPL TN CIRC CMPL TN Circulate 55 BBLS of 11.2 PPG brine w/2% Baker Petrolite CRW132 into the 5 1/2" X 7" Annulus with a freeze protect of 8 bbls Diesel. Pumped and displaced 3 1/2" X 5-1/2" annulus with 25 BBLS of 11.2 PPG Brine w/2% Baker Petrolite CRW132 corrosion ihibitor. 1.83 CMPL TN PCKR CMPL TN Up Wt. 42K Dn.Wt 34k. Dropped ball and rod, set Baker packer with 4,500# tubing pressure, 0# on the IA. 2000 psi assist on shearing the PBR. Spaced out with pups, positioning 1 full jt below hanger. 4.00 CMPL TN DEQT CMPL TN RU chart recorder to tbg & IA. With annulus open, PT tubing to 2500 psi for 30 min. Bled off tubing pressure to 1500 psi. Holdingthe tubing pressure at 1500 psi, PT IA to 2500 psi for 30 min. Bled off tubing pressure and sheared the SOV in bottom GLM. 1.50 CMPL TN NUND CMPL TN Bled all pressure off. LD landing jt. Set BPV. 5.50 CMPL TN NUND CMPL TN Blowdown all surface lines. Remove bell nipple, ND BOPE. 6.50 CMPL TN NUND CMPL TN NU tree. Pull BPV. Install test plug. Test tree and packoffs to 5000 psi. hold for 10 min. Tree passed. No visual leaks. Set BPV and prepare to rig dwn. Rig Released 23:30 hrs 6/22/2005. Printed: 7/15/2005 2:05:22 PM TUBING (0-6525, 00:3.500, 10:2.992) ANCHOR (5672-5673, 00:3.500) 3F';13Þ. ') KRU 3F-13A Well Type: PROD Angle ~ TS: 69 deg ~ 8523 Orig Completion: 9/6/1999 Angle ~ TD: 64 deg ~ 9350 Last W/O: 6/22/2005 Rev Reason: WORKOVER Ref Log Date: Last Update: 6/25/2005 TD: Max Hole Angle: Size Top Bottom TVD Wt Grade Th read 16.000 0 112 112 62.58 H-40 WELDED 9.625 0 3652 3065 36.00 L-80 BTC-MOD 7.000 0 8050 5736 26.00 L-80 BTC-MOD 5.500 0 6485 5149 15.50 L-80 HYD-511 3.500 6485 9350 9350 9.30 L-80 EUE 8rd 6.151 6635 6636 5264 0.00 ) ConocoPhilUps Alaska, Inc" . .. E~"""""','" ¡;,;,,-;.... UI l" . .. j ~ fl I NIP . (8551-8552, 00:4.500) LINER (6485-9350, 00:3.500, 1JIA:9.30) ..--- Perf - (8553-8570) ---- Perf n (9070-9100) API: 500292149901 SSSV Type: NIPPLE Annular Fluid: Reference Log: 35' RKB Last Tag: 9116 Last Tag Date: 3/15/2001 CaslngStdnA·,'·;'1i..LL Description CONDUCTOR SURF CASING PROD CASING TIE BACK LINER J LINER CSGWINDOW V TUbing String - Size 3.500 v' ,I'" ~¡!" Interval 8553 - 8570 TVD 5874 - 5881 Zone C-4 Status Ft SPF 17 4 Date Type Comment 4/22/2000 APERF 2.5" HC-DP, 180 deg ph, +1- 90 deg orient 9/20/1999 IPERF 2.5" HC; 180 deg ph 9070 - 9100 6084 - 6096 Gas Lift Mandrels'Valves St MD TVD Man Man Type V Mfr V Type V OD Latch Port Mfr 1 3201 2757 CAMCO KBG2-9 DMY 1.0 2 4952 3996 CAMCO KBG2-9 DMY 1.0 3 5603 4475 CAMCO KBG2-9 SOY 1.0 Other (pluQs, equip., etc.) - JEWELRY (WORKOVER 6/22/2005) Depth TVD Type Description 24 24 HANGER TUBING HANGER 524 524 NIP CAMCO '0' LANDING NIPPLE 5656 4514 LOCATOR BAKER BOT LOCATOR SUB 5659 4517 SBE BAKER SEAL BORE EXTENSION 5672 4526 ANCHOR BAKER ANCHOR 5673 4527 PACKER BAKER SAB-3 PACKER 6376 5065 SLEEVE BAKER CMD SLIDING SLEEVE I BX PROFILE 6457 5127 NIP HES 'X' PROFILE NIPPLE wIBALL & ROD 6471 5138 SEAL BAKER 80-40 SEAL ASSEMBLY other (plÚgs, equip., etc.)'; ·.EXISITING<3.5"LlNERJEWELRY Depth TVD Type Description 6503 5163 HANGER BAKER HMC HYDRAULIC LINER HANGER 6583 5224 PACKER ECLIPSE PACKER wlKOBE KNOCKOUT set 4/25/2005 8551 5874 NIP 3.5" LINER: CAMCO D NIPPLE 8572 5881 NIP 3.5" LINER: HES HPN POLISHED NIPPLE. 9350 9350 SHOE BAKER FLOAT SHOE A-2 30 4 TRO DK-1 DK-1 DK-1 o o o Date Run 6/22/2005 6/22/2005 6/22/2005 Vlv Cmnt 0.000 0.000 0.000 ID 2.910 2.875 3.000 3.000 3.000 2.800 2.813 2.812 2.990 ID 3.500 1.750 2.750 2.750 3.500 i~ c;:-U It"""1; i.t::";J ílÇ' :,~ Ui(L,. ",I r ; A,';I ¡ 'j i I , \ >'" :u~ i¡lJ~ : I¡ ~:, rl',>d i!1 :Y.M l~ :! ! LI \\~ :! /LJ IÛ tJ ~~ 'l'-,"l-'~', ,r:::;J , II ! ! '" , !' if II '\ i ' I I ' ~! U": ¡1:::1 ¡ ! J :1 \11 II .\.~~) ~ J n' , I ¡ I ~ ~ ~, ,,,,,--,! ) /99 -07 7 ) AIfA~KA OIL AND GAS CONSERVATION COM:MISSION FRANK H. MURKOW5KI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Howard Gober Wells Engineer CpnocoPhillip Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 SCANNED MAY 2 7 2005 Re: Kuparuk 3F-13A Sundry Number: 305-130 Dear Mr. Gober: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours 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 If, liday or weekend. A person may not appeal a Commission decision to Superior unless rehearing has been requested. DATED this 1-<::y of May, 2005 Encl. ) ConocóP'hillips Alaska ) RECEIVED MAY 2 4 Z005 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Alasko Oil &, Gas Cons. Commission Anchorage May 23, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 3F-13A. 3F-13A was completed in 1999 as a sidetrack of 3F-13. In 2003, a tubing leak was diagnosed. A Eclipse patch successfully isolated the leak, and the well produced until 2005. More leaks along with a leak in the 5-1/2" tie-back casing were diagnose, b;inning in February of 2005. The well I \ was left shut-in awaiting the 2005 workover program. c:...(1.~\,",~ \~~ ~ Ð\o~"()~Ç;,~ ~ ~"""'~~<t.\..,"~~ \o~. J'~ The purpose of the proposed workover will be to replace the failed Tubing. As part of the work, a I(p:.. -, - ( straddle will be installed to isolate the 5-1/2" casing leak. Corrosion inhibited brine will be circulated into the annuli. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 263-4220. Sincerely, ~ Howard B. Gober Wells Engineer CPAI Drilling and Wells O· [") ¡ ('-"~ i \. I A':¡ L f\\O\\\J ~~. V(>:y ç" z5'" ()ç ~ ) ~ ')~/"RECE,IVED STATE OF ALASKA / <:: /~ ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 2: 4~ Z005 "SId ~ APPLICATION F~~~2~~~RY APPROV A"'n$k~ Oil &63$ (;011$. Commission fmclmmgc o Suspend 0 Operation Shutdown 0 Perforate 0 Waiver . U Other 0 o Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 o Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 4. Current Well Class: 5. Permit to Drill Number: 199-077 ./ 6. API Number: -/ 50-029-21499-01 9. Well Name and Number: 3F-13A 1. Type of Request: Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 93' Exploratory 0 o Development 0 Stratigraphic 0 Service 8. Property Designation: ADL 25632, ALK 2565 11. Total depth MD (ft): 9350' 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6205' Length Casing CONDUCTOR SURF CASING PROD CASING CSG WINDOW TIE BACK LINER MD TVD Burst Collapse 112' 112' 3652' 3065' 8050' 5736' 6636' 5264' 6485' Plug Integrity 0 BOP Test'p< Mechanical Integrity Test 0 . Location Clearance 0 , \' Other ~SOÖ~';õZ'\~"'~ ~(J~~'.>\:, ~~\\'û..\ \~O~~~\ -\-a\a€..~\\~~~~(¿J T ~"11 c / ~ ~ RBDMS BFl MAY 2 5 2005 APproved!y.A' , COMMISSIONER ~~~~~V;~I~~ION Date 11 oS' ed 11/2004'-- 0 R \ G \ N A L Size 16" 112' 3559' 7957' 9-5/8" 7" l' 5-1/2" 5-1/2" 6392' Perforation Depth TVD (ft): 5874'-5881',6084'-6096' Packers and SSSV MD (ft) 6485' SSSV= 519' Tubing Size: 3-1/2" Perforation Depth MD (ft): 8553'-8570', 9070'-9100' Packers and SSSV Type: pkr= BAKER 5" X 7" ZXP MECHANICAL ISOLATION PACKER SSSV= NIP 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Howard Gober m~ May 24, 2005 Date: 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Contact: Title: Phone Signature Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Form 10-403 Tubing Grade: L-80 Tubing MD (ft): 6525' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Howard Gober @ 263-4220 Wells Engine~.I Date ~'dr!o!5 Sundry Number: ~ S - \ ~G Submit in Duplicate Current Completion ~ :!'~I~ tj ~ ~ . II ..; ~ ... ...... ~ ...... ) ) 3F-13A Proposed Workover 2.875" OS Nipple +/- 500' ...... 9-5/8" Casing 3.5" Tbg 4 KBG2-9 GLM's 2.813" Camco OS Nipple 5.5" 15.5# Tie-back Casing Baker liner top packer/hanger w/ 5- ')I.¡" tie-back receptacle on top and 4" seal bore on bottom 7" Csg with sidetrack window at 6635' 3-1/2" Liner Proposed 2005 Completion ..... . II .. III II ~~ ..... ...... ..... ...... 2.875" OS Nipple +/- 500' ...... 3.5" Tbg IBT w/ special clearance couplings 3 KBG2-9 GLM's 3-%" x 5-%" SABL-3 Packer/PBR at +/- 5700' 2.813" Camco OS Nipple ) ) Kuparuk 3F-13A General Workover Procedure Pre-rig Work 1. Set Eclipse plug to isolate perforations. RU Slickline Unit. Pull GL Vat 2955' and 4733'. Install DV's in both pockets. Pull DV at 6357' leaving an open pocket 2. Load well with 9.6 ppg brine 3. Set BPV. 4. Prepare location for Workover Rig. Ñ~ \o(:),~ ~ ~ General Workover Procedure 1. MIRU Workover Rig. 2. ND Tree, MU Test plug, NU BOPE. 3. Test the BOPE to 250/3500 psi. Test annular to 250/2500 psi 4. Pull Test plug. Pull BPV. 5. Pull tbg hanger. POOH w/ tubing and seal assembly. 6. MU redressed seal assembly, stack packer, and gas lift mandrels on new 3-1/2" tubing. 7. Load 5-1/2" x 7" annulus with corrosion inhibited brine and diesel. Circulate corrosion inhibited brine into the 3-1/2" x 5-1/2" annulus through the straddle area 8. Set packer. Packer will be set at +/- 5700' RKB. The packer and seal assembly will create a straddle to isolate the leaking 5-1/2" casing. 9. Pressure test IA to 2500 psi. 10. Shear PBR. Space out. Land tubing hanger. RILDS. Set BPV. 11. ND BOPE. NU Tree. Pull BPV. Set test plug. Test tree. Pull test plug. 12. Set BPV. RDMO workover rig. Post-Rig Work: 1. Pull BPV. 2. Recover brine for re-use. Freeze protect well. 3. RU Slickline. Pull ball and rod. Pull Eclipse plug. Run gas lift valves. 4. Return to production. Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2926 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 07/31/03 Field: Kuparuk Well Job # Log Description Date BL Color CD 1B-10 i ~ )~' I,~,% SBHP 07/21/03 lC-27 )c__/~-~'~/='~ TEMP/PRESS SURVEY 07/22/03 1D-140~___j~,,-- t'~ SBHP 07/22/03 4J-10 .~'~_..~'~"7'~ i SBHP 07/24/03 2B-01 ,~<~ ~1 '-~-\,~ PRODUCTION PROFILE .07/19/03 2B-02 1'~-~- t,.~q.~ PRODUCTION PROFILE 07/20/03 2B-14 ~' ~1 \ PRODUCTION PROFILE 07/23/03 2E-14 ~ ~'~']',~'~ PRODUCTION PROFILE 07/18/03 3F-13A /~ ~"~';'¥¥" LDL 07/17/03 3K-08 \~.~" ~ ~ LDL 07125/03 3M-03 i~~ I~-~ LDL 07/24/03 3S-19 ~.."~-~..~/? PERF/JEWELRY/& INITIAL SBHPS 07/11/03 DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ConocOphillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 1, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-404 Sundry Notices for ConocoPhillips Alaska, Inc., wells 3F-13A (PTD 199-077), and 3R-18 (PTD 192-017). The Sundry Notices regard tubing patches mn to fix above Packer tubing leaks. Please call Nina Woods, Jerry Dethlefs or me at 907-659-7224 if you have any questions. Sincerely, . ~-" o ' lip Problem Well Supervisor Attachments I ORIGINAL NOV Oil & ~3~$ Cons. STATE OF ALASKA ~r' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon [] Suspend E~] Operation Shutdown [] Perforate [] Vadance [] Annular Disp. r'~ Alter casing [] Repair Well [-~ Plug Pedorations ~ Stimulate r-~ Time Extension Change Approved Program ~ Pull Tubing ~ Perforate New Pool ~ Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: 5. Permit to Ddll Number: ConocoPhillips Alaska, Inc. Development _ )~ Exploratory [~] 199-077 / 3. Address: Stratigraphic ~ Service [--I 6. APl Number: P. O. Box 100360 50-029-21499-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 93' 3F-13A 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9350' feet true vertical 6205' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet 3-1/2" Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 112' 16" 112' 112' SURF CASING 3559' 9-5/8" 3652' 3065' 5210" 2370 PROD CASING 7957' 7" 8050' 5736' 6340 4320 CSG WIN DOW 1' 5-1/2" 6636' 5264' TIE BACK LINER 6392' 5-1/2" 6485' 7000 4990 Perforation depth: Measured depth: 8553-8570', 9070-9100' true vertical depth: 5874-5881', 6084-6096' Tubing (size, grade, and measured depth) 3-1/2" L-80, 6525' MD. . ~.,,i~ F ..... ~ '" .... Packers & SSSV (type & measured depth) pkr= BAKER 5"X 7" ZXP MECHANICAL ISOLATION PACKER W/'I'BR pkr= 6485' NOV {~ ~.:i,. I,'I'~ ~ ~'~ SSSV= NIP/None SSSV= 519' 12. Stimulation or cement squeeze summary: ~,~"~':,.¢;',,.;,'~'~ UI~ ,~. Intervals treated (measu red) N/A .i:~ ~ C I";,~ ~::..~:~i ~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin,q Pressure TUbin,q Pressure Prior to well operation 0 0 0 900 1250 Subsequent to operation 500 300 1500 1330 210 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run ~ Exploratory ~ Development ~] Service r'-] Daily Report of Well Operations _X 16. Well Status after proposed work: Oil['~ Gas[~ WAG r-] GINJ ["-~ WINJ F'-] WDSPLF-I 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.C. Exempt: I Contact MJ Loveland/Nina Woods 659-7224 Printed Name MJ Lovelar,,d / ,/,~Ue Problem Well Supervisor signature/...///~.,.~~~/~ .~,'/ Phone 659-7224 Date//~,,/.,~/'/J//'~---'~'"~ / Form 10-404 Revised 2/2003 · ORIGINAL 3F-13A i~' DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/26/2003 SET ECLIPSE TUBING PATCH IN TWO RUNS. FIRST RUN SET LOWER ASSEMBLY CENTER OF ELEMENT AT 5782'. SECOND Fi, UN, STING UPPER ASSEMBLY INTO LOWER AND SET UPPER,,PACKER AT 5762. TAGGED TOP OF PATCH AFTER SETTING. MIN ID OF PATCH IS 1.75 . OAL IN PLACE IS 24.5', 20' BETWEEN ELEMENTS. 10/28/2003 MITIA - passed, T/I/O = 850/1350/0 Pressure up IA with diesel to 2500 psi, start MITIA T/I/O= 850/2500/0, 15 minute reading T/I/O= 850/2450/0,30 minute reading T/I/O- 850/2450/0 Summary ISet Retrivable patch from 5782-5762' and Pressure tested good TUBING -- (0~o525, 0D:3.500, ID:2.992) PATCH (5762-5782, OD:3.500) APl: 500292149901 Well T PROD SSSV NIPPLE 9/6/1999 Annular Fluid: Last W/O: Size CONDUCTOR 16.000 Rev Reason: i GLV design, set !Patch SURF CASING 9.625 PROD CASING 7.000 TIE BACK LINER 5.500 LINER 3.500 CSG WINDOW 6.151 Reference 10/31/2003 Last 9116 TD: 9350 ftKB 3/15/2001 Max Hole An¢ ~iAEl~i:!.::i , i, ,' Top Bottom TVD 0 112 112 0 3652 3065 0 8050 5736 0 6485 5149 6485 9350 9350 6635 6636 5264 Size Bottom I TVD 3.500 0 6525 I 5179 PerforatiOns Summary . ': Interval TVD Zone 8553 -8570 5874 - 5881 C-4 9070 - 9100 6084 - 6096 A-2 Thread WELDED BTC-MOD BTC-MOD HYD-511 EUE 8rd Man Type 1. PA TCH SET ~ KBG29 KBG29 KBG29 KBG29 5762' ACROSS GL V #3 wt IGrade I 'Thread 9.30 I L-80 I EUE 8rd Comment 2.5" HC-DP, 18Odeg ph, +/- orient NIP PATCH NIP LOCATOR TTL PKR HANGER SBE NIP NIP SHOE LOCATOR SEAL STEM CAMCO DS NIPPLE Description 20' PATCH set ACROSS GLV #3 10/26/2003 CAMCO DS NIPPLE BAKER NO GO LOCATOR TUBING TAIL FOR 3.5" TUBING Description BAKER 5" x 7" ZXP MECHANICAL ISOLATION PACKER W/I'BR BAKER HMC HYDRAULIC LINER HANGER BAKER 80-40 SBE 17' STROKE 3.5" LINER: CAMCO D NIPPLE 3.5" LINER: HES HPN POLISHED NIPPLE. BAKER FLOAT SHOE 5" LINER JEWELRY Description BAKER NO GO 4.437" X 5.5" BAKER TIE-BACK SEAL STEM 199-077-0 KUPARUK RIV UNIT Roll #1: Start: Stop Roll #2: MD 09350 ,-~"TVD 06203-. Completion Date: 3F-13A 50- 029-21499-01 Start Stop .. C~f6~9 Completed Status: 1-OIL PIqlLLIPS ALASKA INC Current: T Name Interval D 9079 c~"~-' 2,3 SPERRY MPT/GR/EWR4 OH L DGR/EWR4-MD~.,-~' FINAL 6650-9330 L DGR/EWR4-TVD ~'/~' FINAL 5250-6203 R SRVY RPT SPERRY 6593.60-9350. OH 2/5 OH 2/5 OH Sent Received T/C/D 12/7/99 12/9/99 12/9/99 12/9/99 D 12/9/99 12/9/99 9/28/99 9/30/99 Wednesday, June 20, 2001 ' ' Page 1 of'l .... STATE OF ALASKA ..... --~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Per/orate _X Pull tubing _ Alter casing _ Repair well _ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 93 feet 3. Address Exploratow__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 5227' FNL, 157' FEL, Sec. 19, T12N, R9E, UM (asp's 508341, 5985875) 3F-13A At top of productive interval 9. Permit number / approval number 160' FNL, 1901' FEL, Sec. 19, T12N, R9E, UM (asp's 506573, 5990943) 199-077 At effective depth 10. APl number 50-029-21499-01 At total depth 11. Field / Pool 4701' FNL, 2002' FEL, Sec. 18, T12N, R9E, UM (asp's 506469, 5991678) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 9350 feet Plugs (measured) Tagged PBTD (7/24/00) @ 9268' MD. true vertical 6205 feet Effective depth: measured 9268 feet Junk (measured) true vertical 6169 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 110' 16" 331 S× AS II 110' 110' SURFACE 3559' 9-5/8" 1000 Sx PFE; 400 PFC 3652' 3065' PRODUCTION 6542' 7" 305 Sx G & 175 PFC 6635' 5263' ISO. TIEBACK 6392' 5-1/2" 6485' 5149' LINER 2865' 3-1/2" 544 Sx G 9350' 6205' Perforation depth: measured 8553 - 8570'; 9070 - 9100' true vertical 5874 - 5881'; 6084 - 6096' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 6485' MD. ~C~I~~ Packers & SSSV (type & measured depth) BAKER 5" X 7" PACKER @ 6485' MD. CAMCO DS @ 519' MD. 13. Stimulation or cement squeeze summary /~l~tSl~& 0i~ E knchOrE~e ' Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 223 52 263 165 Subsequent to operation 322 175 1102 226 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~, ,/~,,4~% Title: D at~repared~by~Jo h~ p~eir~ce 2,,~265.6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE'~ 3F-13A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 4/22/00: MIRU CTE & PT equipment. RIH w/perforating guns & shot 17' of perforations as follows: Added perforations: 8553 - 8570' MD Used 2-1/2" Hollow carriers & shot the perfs at 4 spf at 180 degree phasing. POOH w/guns. 7/24/00: RIH w/CT & jetted out fill down to a hard tag at 9268' MD. POOH w/CT. RD. RD. Returned the well to production w/gas lift & obtained a valid well test. WELL LOG TRANSMITTAL To.' State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs December 09, 1999 iqq · O"Tq 3F-I3A, AK-MM-90147 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 3F-13A: 2" x 5" MD Resistivity & Cramma Ray Logs: 50-029-21499-01 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-21499-01 1 Blueline 1 Folded Sepia .LBlueline 1 Folded Sepia _':' !? 9 999 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 A Halliburton Company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs December 07, 1999 3F-13A, AK-MM-90147 1 LDWG formatted Disc with verification listing. API#: 50-029-21499-01 PLEASE ACK!NOWLEDGE RECEIFr BY SIGNING AND RETURNING TItE ATTACHED COPY OF THE TRANSMITTAL LETrER TO THE ATTENTION OF: Sperry-SunDfilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 A Halliburton Company ARCO Alaska, Inc. : Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 2, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3F-13A (Permit No. 99-77) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on 3F-13A. If there are any questions, please call 265-6120. Sincerely, G. C. Alvord Drilling Engineering Supervisor AAI Drilling GCA/skad · ~., STATE OF ALASKA .... ~, ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND. 1. Status of well Classification of Servi68 We'll Oil r~ Gas BI Suspended [~ Abandoned [--1 Service D ?¢::;L-::,;'~:~- Of, ".-12~r~._...-~, f: 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 99-77 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-21499-01 4. Location of well at surface 9. Unit or Lease Name · :: : . 52' FSL. 158' FEL, Sec. 19, T12N, R9E, UM i :;~ i, ;i,Ti'k]f,,:. ;; '% ~ Kuparuk River Unit AtTop Producing Interval ~ j¢-; i-~ 2. ~ ~~t ~i 10. Well Number 160' F NL, 1901' FEL, Sec. 19, T12N, R9E, UM i- ~~--~-~ ][ !'~~'i 3F-leA At Total Depth i ~~ i' ~;L]~[ ll.F,eldandPool 579' FSI_, 2003' F~I_, Sec. 18, T12N, R9~, UM ........ .~..~~,~.~,~. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I~. Lease Designat-io~a~Sedal No. Kuparuk River Pod RKB 24' feetI ADL 25632 ALK 2565 ,12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions August 28, 1999 September 1, 1999 September 6, 1999I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Deplh (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 9350' MD/6203'TVD 9254' MD/6161'TVD YES ['~ No BII N/A feetMD 1500' approx. 22. Type Electric or Other Logs Run GR/Res, COL ['~ R I fi i ix~~ 23. CASING, LINER AND CEMENTING RECORD ..... ' ' ~ i~'"~w"~¢'~ SETTING DEPTH MD CASING SIZE WT. PER FF. GRADE TOP BO-I-I'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 110' 24" 331 sxAS II 9.625" 36# J-55 Surface 3652' 12-1/4" 10oo sx PF 'E', 4OO sx PF 'C' 7" 26# J-55 Surface 6635' 8-1/2" 305 sx Class 'G', 175 sx PF 'C' 5.5" 15.5# L-80 Surface 6485' 6.125" isoloation tieback string 3.5" 9.3# L-80 6485' 9350' 6.125" 544 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) 3.5" 6525' 6486' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9070'-9100' MD 6082'-6095' TVD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9070'-9100' MD 130M# in formation, 10ppa, 12/18 on perfs 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) October 6, 1999 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 10/16/1999 12.0 Test Period > 239 381 511 0I 1799 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press. 192 psi 1131 24-Hour Rate > 474 763 255 22.8° 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS 31. LIST OF ATTACHMENTS MEAS. DEPTH TRUE VERT. DEPTH 8530' 8716' 8955' 9273' 5864' 5936' 6034' 6169' FO RMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Mark Chambers 265-1319 Graham C. Alvord Title Drilling Engineering Supervisor INSTRUCTIONS Prepared by Sharon Afisup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg 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 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 cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 09/22/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:3F-13A WELL_ID: AK0041 TYPE: STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER I/NIT SPUD:08/28/99 START COMP: RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NLrMBER: 50-029-21499-01 08/20/99 (D1) MW: 0 0 VISC: 0 PV/YP: 0/ 0 APIWL: 0 0 TD/TVD: 8050/8050 (8050) MOVING RIG FROM 3G TO 3F SUPV:D. WESTER/S. GOLDBERG Turn key rig move from 3G to 3F. Rig stuck in road. Lay down rig mats. 08/21/99 (D2) MW: 0 0 VISC: 0 PV/YP: 0/ 0 APIWL: 0 0 TD/TVD: 8050/8050 ( 0) MOVING RIG FROM 3G TO 3F SUPV:D. WESTER/S. GOLDBERG Moving rig from 3G to 3F. Having to drive forward on rig mats. Double stack behind. 08/22/99 (D3) MW: 0 0 VISC: 0 PV/YP: 0/ 0 APIWL: 0 0 TD/TVD: 8050/8050 ( 0) MOVING RIG FROM 3G TO 3F SUPV:D. WESTER/S. GOLDBERG Continue turnkey rig move from 3G to 3F. Still using the double stack method to get rig mats from behind the rig. 08/23/99 (D4) MW: 0 0 VISC: 0 PV/YP: 0/ 0 , APIWL: 0 0 TD/TVD: 8050/8050 ( 0) LOADING BOPE INTO CELLAR SUPV:D. WESTER/S. GOLDBERG Continue moving rig from 3G to 3F. still double stacking to get mats from behind pipe. 08/24/99 (D5) MW: 11 0 VISC: 45 PV/YP: 12/29 APIWL: 4 0 TD/TVD: 8050/8050 ( 0) TESTING BOPE'S SUPV:D. GLADDEN/T. BRASSFIELD Move rig onto 3F pad. MIRU. Held safety meeting. Circulate well to 11.0 ppg LSND/GEM mud. ND tree. 08/25/99 (D6) MW: 11 0 VISC: 43 PV/YP: 12/23 APIWL: 4 0 TD/TVD: 8050/6361 ( 0) PU 90 JTS OF 3-1/2" DP & STAND BACK IN DERRICK SUPV:D. GLADDEN/T. BRASSFIELD Continue ND tree, install test plug. NU BOPE and test to 250/3500 psi. Top IBOP failed. Test BOPE's. POOH w/3.5" tubing. PJSM. Date: 09/22/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 08/26/99 (D7) MW: 11.0 VISC: 42 PV/YP: 12/25 APIWL: 3.8 TD/TVD: 7346/5803 ( 0) RD SWS & PU WINDOWMASTER SUPV:D. GLADDEN/T. BRASSFIELD Continue POOH with 3.5" tubing and jewelry. Test lower pipe rams to 250/3500 psi. Safety meeting. RIH w/bit/casing scraper BHA. Circulate and condition wellbore at 9.4 bpm/2600 psi while rotating and reciprocating pipe. 08/27/99 (D8) MW: 11.0 VISC: 38 PV/YP: 12/22 APIWL: 2.8 TD/TVD: 6658/5281 ( 0) CIRCULATING PRIOR TO FIT SUPV:D. GLADDEN/T. BRASSFIELD PJSM. Make 6.13" GR/JB run to 6852', hit tight spot at 4970' Set bridge plug at 6658'. RIH w/windowmaster whipstock, upper string mill tight from 36' to 50', unable to RIH, POOH. RIH with new 6.125" upper string mill, tight at 68' Mill from 48' to 73', tight at 68', RIH with mill to 180', POOH. RIH w/windowmaster milling assembly, work thru tight spot at 68'. POOH. 08/28/99 (D9) MW: 11.0 VISC: 38 PV/YP: 12/23 APIWL: 2.8 TD/TVD: 6665/5286 ( 7) DRILLING 6 1/8" HOLE ~ 6830' SUPV:D. GLADDEN/T. BRASSFIELD Tag WL set bridge plug at 6658'. Set windowmaster whipstock with top at 6635' Mill window from 6636' to 6644'. Drill 21' of hole to 6665'. Work and ream BHA thru window, circulate 20 bbl 12.4 ppg weighted barafiber sweep. Perform FIT at 6665', 13.6 ppg EMW. RIH, slide thru window, OK. Tag bottom at 6665' 08/29/99 (D10) MW: 11.1 VISC: 39 PV/YP: 11/23 APIWL: 2.4 TD/TVD: 7357/5556 (692) DRILLING AT 7800' SUPV:D. GLADDEN/T. BRASSFIELD Drilling from 6665' to 7313'. RIH, wash and ream to bottom, no fill/no tight spots. Drilling from 7313' to 7357'. 08/30/99 (Dll) MW: 11.2 VISC: 37 PV/YP: 13/30 APIWL: 2.8 TD/TVD: 8186/5755 (829) REPAIR RISER BOOT & TEST BOPE SUPV:D. GLADDEN/T. BRASSFIELD Drilling from 7357' to 8186' Circulate and work pipe on each connection. Pumped one 12.7 ppg weighted sweep to clean hole. Circulate low visc sweep and condition mud. Make wiper trip to window. A couple of tight spots on stands #64 & #63. POOH to repair lower riser boot and perform a weekly BOPE test. 08/31/99 (D12) MW: 11.2 VISC: 38 PV/YP: 12/24 APIWL: 3.0 TD/TVD: 8448/5837 ( 262) DRILLING AHEAD AT APPROX. 8700' (TOP KUP AT APPROX 85 SUPV:D. WESTER/S. GOLDBERG Run test plug and test BOPE, OK. Pull test plug. Wash and ream. Slight pack offs. Work pipe with rotation and high flowrate. Drilling from 8186' to 8380' Swivel packing failed on top drive. Drilling from 8380' to 8448' Date: 09/22/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 09/01/99 (D13) MW: 11.2 VISC: 39 PV/YP: 11/25 APIWL: 3.4 TD/TVD: 9350/6203 (902) PULLING OUT OF HOLE FOR LINER SUPV:D. WESTER/S. GOLDBERG Drilling from 8488' to 9122'. Packing on top drive failed. Pull off bottom and repair. Continue drilling to 9350' TD. 09/02/99 (D14) MW: 11.3 VISC: 40 PV/YP: 11/25 APIWL: 3.5 TD/TVD: 9350/6203 ( 0) BATCH MIXING CEMENT FOR LINER CEMENT JOB SUPV:D. WESTER/S. GOLDBERG Continue running back in hole after wiper trip. Circulate and condition mud for trip out of hole and cement job. Pump weighted sweep. POOH to window. Monitor well, no loss or gain. Pump dry job and continue out of hole. Rig safety audit. Run float equipment and run 3.5" liner. 09/03/99 (D15) MW: 11.2 VISC: 39 PV/YP: 11/22 APIWL: 3.8 TD/TVD: 9350/6203 ( 0) N/D WELLHEAD AND N/U NEW WELLHEAD SUPV:D. WESTER/S. GOLDBERG Continue running in hole with liner. Pump cement. N/D BOPE. 09/04/99 (D16) MW: 11.2 VISC: 42 PV/YP: 11/23 APIWL: 3.8 TD/TVD: 9350/6203 ( 0) RUNNING 5 1/2" TIEBACK STRING SUPV:D. WESTER/S. GOLDBERG Attempt to N/D tubing head. Bolts were not backing out easily. Safety meeting. Continue to work wellhead problem. N/U BOPE and function test. 09/05/99 (D17) MW: 8.5 VISC: 28 PV/YP: 0/ 0 TD/TVD: 9350/6203 ( 0) RUNNING 3 1/2" COMPLETION SUPV:D. WESTER/S. GOLDBERG PJSM. RIH w/ 5.5" casing. APIWL: 0.0 09/06/99 (D18) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 9350/6203 ( 0) CLEANING PITS FOR WEST SAK. CLEANING UP LOCATION SUPV:D. WESTER/S. GOLDBERG N/U BOPE and function test BOPE to 250/3500 psi. PJSM. RIH w/ 3.5" tubing. Test tubing to 3000 psi. N/D BOPE, N/U tree and test to 250/3000 psi. 09/07/99 (D19) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 9350/6203 ( 0) MOVE RIG TO 1D-129 SUPV:D. WESTER/S. GOLDBERG Move rig off well, clean cellar area, clean pits and flush surface lines. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,[ WELL SERVICE REPORT '' K1(3F-13A(W4-6)) WELL JOB SCOPE JOB NUMBER ' " 3F-13A PERFORATIONS-CT. 0919991803.2 DATE DAILY WORK UNIT NUMBER 09/20/99 PERFORATE UNIT #3 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 YES YES DS-NEWELL LIGENZA FIELD AFC# CC# Signed ESTIMATE AK0042 230DS36GG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 70 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY I RAN MEMORY TIE IN LOG FROM 8860' TO 9208'. PERFORATED FROM 9070' TO 9100'. 4 SPF, 180 DEGREE PHASING. INJECTIVITY 2680 PSI AT .5 BPM.[Perf] TIME LOG ENTRY 07:00 MIRU DS CTU. MU RADIUS HHA AND PDS LOGGING TOOLS. 09:00 TGSM; DISCUSS PERFING JOB PLAN, EVAC POINT. PRESSURE TEST TO 4,000 PSI. RIH 10:05 WT CHECK AT 7,000', 18,000#. 10:55 START LOGGINGUP FROM 9200' CTM. AT 40 FPM TO 9100'. FLAG PIPE. 11:05 CONTINUE LOGGING UP TO 8850' CTM. POH. 12:20 ON SURFACE. RIG DOWN PDS. STAND BY FOR SCHLUMBERGER. 16:00 SCHLUMBERGER ON LOCATION. TGSM DISCUSS RIG UP, JOB PLAN. MU FIRING HEAD, 30', 2.5" HC GUNS. 17:20 PRESSURE TEST TO 2200 PSlG. RIH. 19:40 LOCATE PIPE FLAG AT 9099.0' PER MEMORY LOG. MINUS 7.2' OF TOOLS FROM COIL CONNECTOR TO TOP SHOT. LOAD 5/8" BALL. RESET DEPTH COUNTER TO 9091.8'. LOCATE TOP SHOT AT 9070' PER PROCEDURE. 20:15 BALL ON SEAT AFTER PUMPING 29.8 BBLS. GUNS WENT OFF AT 3400 PSI. POH. 21:30 ON SURFACE. ALL SHOTS FIRED. BREAK DOWN GUNS AND TOOL STRING. STAB BACK ON TO DISPLACE. 22:30 RIH TO 2500' PUMPING DIESEL HOLDING 300 PSI BACK PRESSURE. AT 2500', BLOCKED IN CHOKE. PUMPING .5 BPM, PRESSURE LEVELED OUT AT 2680. PUMPED 4 BBLS. POH. . . ' 23:45 ON SURFACE. RDMO DS CTU. - Date 09/25/99 Upcoming Well Na 3F-13A Job Num 0923991745.4 Service Type PUMPING Unit Desc of Work A2 FRACTURE TREATMENT Supervisor ODELL Contractor Key Perso DS-GALLEGOS Complet r~ successful Accident I-- Initial Tbg Press 940 Injury I-' Initial Int Csg Press 0 Spill F- Initial Out Csg Press 0 Summary AFC AK0042 0 Final Tbg Press 1400 Final Int Csg Press 500 Final Out Csg Press 0 Prop 230DS36C- Uploaded to Ser, PUMP FRACTURE TREATMENT AS DESIGNED. 130M# IN FORMATION, 10 PPA, 12/18 ON PERFS. FLUSHED TO COMPLETION. [Frac-Refrac] Date printed: 09/28/99 at: 16:11:37 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 3F, Slot 3F-13 3F-13A Job No. AKMM90147, Surveyed: I September, 1999 SURVEY REPORT 28 September, 1999 Your Ref: API-500292149901 Surface Coordinates:.5985874.97 N, 508341.36 E (70° 22' 21.4664" N, 149° 55' 55.9365" W) Kelly Bushing: 86.60ft above Mean Sea Level Survey Ref: svy8863 Sperry-Sun Drilling Services Survey Report for 3F-13A Your Ref: AP1-$00292149901 Job No. AKMM90147, Surveyed: I September, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 6593.60 40.570 340.710 5143.52 6635.00 40.640 340.630 5174.95 6672.74 40.680 340.250 5203.58 6769.33 41.690 339.680 5276.27 6866.24 54.880 339.110 5340.62 6963.39 70.040 338.530 5385.40 7060.94 78.790 338.510 5411.59 7158.60 78.820 338.170 5430.55 7255.56 78.730 338.250 5449.42 7352.98 78.440 338.090 5468.70 7450.55 75.330 340.890 5490.84 7546.91 75.160 339.430 5515.39 7644.13 74.860 338.830 5540.53 7741.12 74.520 339.300 5566.14 7837.52 74.390 337.950 5591.98 7935.14 75.030 340.220 5617.72 8031.34 75.000 341.330 5642.60 8128.99 75.120 340;650 5667.77 8226.17 75.060 340.670 5692.78 8323.82 75.120 340.210 5717.90 8419.96 75.130 341.100 5742.58 8515.64 68.930 351.760 5772.17 8614.32 66.960 352.610 5809.22 8709.54 66.380 351.880 5846.93 8806.49 66.230 351.160 5885.89 Vertical Local Coordinates . Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 5230.12 3391.00 N 1148.89W 5989264.69 N 507188.69 E 5261.55 3416.43 N 1157.81W 5989290.11 N 507179.74 E 5290.18 3439.60 N 1166.04W 5989313.27 N 507171.49 E 5362.87 3499.35 N 1187.83W 5989373.00 N 507149.63 E 5427.22 3566.90 N 1213.27W 5989440.52 N 507124.12 E 5472.00 3646.98 N 1244.33W 5989520.56 N 507092.97 E 5498.19 3734.33 N 1278.70W 5989607.87 N 507058.49 E 5517.15 3823.37 N 1314.06W 5989696.87 N 507023.04 E 5536.02 3911.68 N 1349.37W 5989785.14 N 506987.63 E 5555.30 4000.32 N 1384.88W 5989873.75 N 506952.03 E 5577.44 4089.30 N 1418.18W 5989962.68 N 506918.63 E 5601.99 4176.95 N 1449.80W 5990050.30 N 506886.90 E 5627.13 4264.70 N 1483.26W 5990138.01N 506853.35 E 5652.74 4352.07 N 1516.68W 5990225.35 N 506819.83 E 5678.58 4438.55 N 1550.53W 5990311.79 N 506785.88 E 5704.32 4526.51 N 1584.14W 5990399.71 N 506752.18 E 5729.20 4614.25 N 1614.74W 5990487.42 N 506721.48 E 5754.37 4703.45 N 1645.47W 5990576.59 N 506690.65 E 5779.38 4792.06 N 1676.57W 5990665.16 N 506659.45 E 5804.50 4880.98 N 1708.16W 5990754.04 N 506627.76 E 5829.18 4968.65 N 1738.94W 5990841.68 N 506596.88 E 5858.77 5056.89 N 1760.40W 5990929.90 N 506575.33 E 5895.82 5147.49 N 1772.84W 5991020.49 N 506562.79 E 5933.53 5234.13 N 1784.63W 5991107.11N 506550.90 E 5972.49 5321.93 N 1797.72W 5991194.90 N 506537.71 E Alaska State Plane Zone 4 Kuparuk 3F Dogleg Rate (°ll00ff) Vertical Section (ft) Comment o.211 0.665 1.116 13.618 15.614 8.970 0.343 o.123 0.338 4.239 1.476 o.671 0.584 1.356 2.337 1.115 0.684 0.065 0.459 0.895 12.415 2.150 o.931 0.697 3579.90 3606.84 3631.42 3694.97 3767.o6 3852.80 3946.49 4042.07 4136.95 4232.21 4327.11 4420.23 4514.Ol 46o7.41 47o0.11 4794.13 4887.03 4981.35 5075.23 5169.55 5262.43 5353.01 5443.07 5529.16 5616.76 TIE ON WINDOW POINT Continued... 28 September, 1999 - 10:20 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 3F-13A Your Ref: API-500292149901 Job No. AKMM90147, Surveyed: 1 September, 1999 Prudhoe Bay Unit Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) Vertical Local Coordinates Global Coordinates Depth Northlngs Eastings Northlngs Eastings (ft) (ft) (ft) (ft) (ft) 8904.92 65.650 351.580 5926.02 6012.62 5410.79 N 1811.21W 5991283.74 N 506524.12 E 9001.12 64.970 351.440 5966.20 6052.80 5497.24 N 1824.11W 5991370.18 N 506511.12 E 9098.66 64.700 352.530 6007.68 6094.28 5584.66 N 1836.42W 5991457.58 N 506498.71 E 9195.92 '64.460 352.370 6049.43 6136.03 5671.74 N 1847.97W 5991544.65 N 506487.07 E 9293.24 64.100 351.780 6091.66 6178.26 5758.58 N 1860.05W 5991631.48 N 506474.89 E 9350.00 64.100 351.780 6116.46 6203.06 5809.12 N 1867.35W 5991682.00 N 506467.53 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Alaska State Plane Zone 4 Kuparuk 3F Dogleg Rate (°/100ft) Vertical Section (ft) Comment 0.706 0.719 1.049 0.288 0.660 0.000 5705.48 5791.73 5878.72 5965.16 6051.53 6101.87 PROJECTED POINT The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 342.180° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9350.00ft., The Bottom Hole Displacement is 6101.87ft., in the Direction of 342.180° (True). Continued... 28 September, 1999 - 10:20 - 3 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 3F-13A Your Ref: API-500292149901 Job No. AKMM90147, Surveyed: 1 September, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 3F Comments Measured Depth (fi) 6593.60 6635.00 9350.00 Station Coordinates TVD Nothings Eastings (~) (~) (~) 5230.12 3391.00 N 1148.89W 5261.55 3416.43 N 1157.81W 6203.06 5809.12 N 1867.35W Comment TIE ON WINDOW POINT PROJECTED POINT 28 September, 1999 - 10:20 - 4 - DrillQuest n I:! I I_1_1 ~ G S E !:!~./I C ~: S 28-Sep-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3F-13A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 6,593.60' MD 6,635.00' MD 9,350.00' MD (if applicable) Please call me at 273-3545 if you have any queStij~s or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIV_E ~6P 30 1999 ~s~a ~ & ~as Oons. Con. Won 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 9. 1999 Randy Thomas Drilling Team Leader ARCO Alaska. Inc. PO Box 100360 Anchorage, AK 99510-0360 ae~ Kuparuk River Unit 3F-13A ARCO Alaska. Inc. Permit No: 99-077 Sur Loc: 52'FSL. 158'FEL. SEC. 19. T12N, R09E. UM Btmhole Loc. 852'FSL. 1998'FEL. SEC. 18. T12N. R09E. UM Dear Mr. Thomas: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required bx' law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Bloxvout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice max' be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson. P. E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. · ' STATE OF ALASKA ..... ' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill [] Redrill [] I lb. Type of well. Exploratory [] StratigraphicTest[~] ...... Development Oil[] Re-entry [] Deepen []I Service [] Development Gas [] SingleZone [] Multiple Zone[] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 87 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-036( ADL 25632 ALK 2565 Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.o251) 52' FSL, 158' FEL, Sec. 19, T12N, R9E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 689' FSL, 1986' FEL, Sec. 18, T12N, R9E, UM 3F-13A #U-630610 At total depth 9. Approximate spud date Amount 852' FSL, 1998' FEL, Sec. 18, T12N, R9E, UM August 15, 1999 $200,000 12. Distance to nearest properly line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 689' @ Target feet No hazards feet 2560 9585 ' MD / 6212 ' TV• 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 6645 MD Maximum hole angle 74° Maximum surface 2846 psig At total depth (TVD) 3500 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6.125" 3.5" 9.3# L-80 EUE 8rd Mo( 3090' 6495' 5155' 9585' 6212' 124 bbls Class G sidetrack - top of window @ 6632' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 8108 feet Plugs (measured) true vertical 6410 feet Effective Depth: measured 7962 feet Junk (measured) true vertical 6289 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 110' 16" 331 sxAS II 110' 110' Surface 3615' 9.625" 1000 sx PF E, 400 sx PFC 3652' 3065' Production 8013' 7" 305 sx Class G & 175 sx PF 'C' 8050' 6363' Liner Of?/$//V4LRECEiVE D Perforation depth: measured 7479'-7579', 7592'-7599', 7721'-7748', 7763'-7814' ALIG O 2:1999 true vertical 5904'-5982', 5993'-5998', 6094'-6116', 6127'-6168' ~l~k~ 0il & Gas Cone. A...chora?_- 20. Attachments Filing fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 2O AAC 25.050 requirements [] 21. I hereby cedify that the foregoing is true and correct to the best of my knowledge Questions? Call Mark Chambers 265-131~. Signed ~~ Title: Ddlling Team Leader Date Randy Thomas pr~n~rc.d hv ,~h~rnn AIl.~un-I')r~kr Commission Use Only Permit Number I APInumber I Approval date % ~o_...~ _C~ ISee cover letter ~'¢ "' 7 ,~ 50-4~--.~2~-""' ~-, / ~' ¢~ '-~/ for other requirements Conditions of approval Samples required [] Yes ,~ No Mud Icg required [] Yes ~ No Hydrogen sulfide measures [] Yes [] No Directional survey required [] Yes [] No Required working pressure for BORE [] 2M; [] ~ [] 5M; [] 10U;• [] Other: ORIGINAL SIGNED-BY by order of ~-,~.0,,) q ._ Approved bY Rober[ N. Chfistensorl .. commissioner the commission Date Form 10-401 Rev. 12/1/85 · Submit in triplicate 1. Type of rec STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS uest Abandon _X Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 52' FSL, 158' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 1302' FNL, 1496' FEL, Sec. 19, T12N, R9E, UM At effective depth At total depth 945' FNL, 1618' FEL, Sec. 19, T12N, R9E, UM 5. Type of Well: Development __X Exploratory __ Sl~atJg raph ic __ Service __ 6. Datum elevation (DF or KB feet) RKB 31' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3F-13 9. Permit number/approval number 85-291 10. APl number 50-029-21499 11. Field / Pool Kuparuk River Field/Kuparuk Oil Poc 12. Present well condition summar Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 3615' Production 8013' Liner 8108 feet Plugs (measured) 6410 feet 7962 feet Junk (measured) 6289 feet Size Cemented 16" 331 sx AS 11 9.625" 1000 sx PF 'E', 400 sx PF 'C' 7" 305 sx Class 'G', 175 sx PF 'C' Measured Dep~ TrueverticalDepth 110' 110' 3652' 3065' 8050' 6363' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 7479'-7579',7592'-7599',7721'-7748',7763'-7814' 5904'-5982',5993'-5998',6094'-6116',6127'-6168' 3.5", 9.3#, J-55 @ 7663', 2.875'. 6.5#, J-55 @7666' Otis 'HB' pkr @ 7365', Otis WD pkr @ 7654', Camco TRDP-1A-ENC SSSV @ 1795' 13. Attachments Description summary of proposal qX Detailed operations program __ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operation August 11, 1999 16. If proposal was verbally approved Name of approver Date approved Oil __X Servioe __ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~~-~~ Title: Drilling Team Leader Randy Thomas FOR COMMISSION USE ONLY Questions? Call Mark Chambers 265-1319 Date :~//'~'//'~ ~ Prepared b~ Sharon AIIsu~-Drake Conditions of approval: Notify Commission so representative~.may witness Plug integrity-L'~/ BOP Test[;;;~/ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- ~:'u~ ~ Approved by .o..rder of the .Commi ,,ssio,n ....... ~ ,, Commissioner Approval no. 3/~,~... ,//~~ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE 3F-13 A Proposed' ompletion 3-1/2" 5M FMC Gen I11 Tubing Hanger with 3-1/2" L-80 EUE 8rd Mod pin down. 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to surface. 3-1/2" Camco 'DS' Landing Nipple with 2.875" No-Go Profile set at +/- 500' MD. 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to 'DS' Landing Nipple with 3-1/2" x 1" Camco 'KBG-2-9' Mandrels with DV's spaced out as follows: 9-5/8" 36# J-55 casing set @ 3652' MD. GLM's MD TVD Note: Each GLM should have 6' L-80 handling pups installed on top and bottom. 7" Baker 'Window Master Whipstock' Top of Whipstock @ 6632' MD Bottom of Whipstock @ 6645' MD 7" Bridge Plug @ 6653' MD Bridge Plug Depth tied in with CET 1/7/86 3-1/2" x 1" Camco 'KBG-2-9' Mandrel with DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. 1 joint 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing. 3-1/2" Camco 'DS' Landing Nipple w/2.812" ID and No-Go profile. 3-1/2" Baker '80-40' Seal Assembly (17' effective stroke) w/crossover and 6' handling pup installed. 5-1/2" 15.5# Hyd 511 Casing to surface (NOTE: Will need a selection of pup joints to space out 5-1/2" Hyd 511 @ surface). 5-1/2" Baker 'TBSM' Tie Back Seal Mandrel (10') w/crossover and 6' handling pup installed. 5"x 7" Baker 'ZXP' Liner Top Packer w/10' Tie Back Recepticle. 5" x 7" Baker 'HMC' Liner Hanger. 3-1/2" Baker '80-40' SBE Seal Bore Extension (20' length w/4" ID seal bore and 17' effective stroke) w/crossover and 6' handling pup installed. 3-1/2" L-80 EUE 8rd Mod tubing from 'D' Nipple to Liner Hanger. 3-1/2" Camco 'D' Nipple with 2.75" No-Go Profile with 3-1/2" EUE 8rd Box x Pin. 20' Pup Joint 3-1/2" 9.3# L-80 EUE 8rd Box x Pin. 3-1/2" Halliburton Polish Nipple w/2.75" Packing Bore and 3-1/2" EUE 8rd Box x Pin. 3-1/2" L-80 EUE 8rd Mod tubing from Landing Collar to Polish Nipple. Abandoned C-Sand Perfs 7479'-7579' 7592'-7599' 3-1/2" EUE 8rd Landing Collar. Crossover EUE 8rd Box x BTC Pin. 1 joint 3-1/2" L-80 BTC Mod tubing. 3-1/2" BTC Float Collar. 2 joints 3-1/2" L-80 BTC Mod tubing. 3-1/2" BTC Float Shoe. 7", 26#,J-55 casing @ 8050' MD Abandoned A-Sand Peds 7721'-7748' 7763'-7814' Last Tag @ 7828' MD on7/14~9 PBTD @ 7962' MD TD @ 8108' MD TD @ 9585' MD/6212'TVD MAC 7/29/99 !REDRILL PLAN SUMMARY Well 3F-13 A Type of well (producer/injector): Surface Location: Target 1: Top C4 Target 2: Top A3 Target 3: Top Miluveach TD: MD: 9585' TVD: 6212' Rig: Estimated Start Date: Operation Days to Complete: Producer 52' FSL, 158' FEL, Sec 19, T12N, R9E, UM 85' FNL, 1919' FEL, Sec 19, T12N, R9E, UM 315' FSL, 1958' FEL, Sec 18, T12N, R9E, UM 689' FSL, 1986' FEL, Sec 18, T12N, R9E, UM 852' FSL, 1998' FEL, Sec 18, T12N, R9E, UM Nordic Rig 3 8/15/99 15 Drill Fluids Pro.qram: Density =V YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Milling Mill to Weight Up Weight Up to TD 11.4 25-30 25-35 50-60 5-10 8-13 <5 8.5-9.5 17-19 11.4 25-31 14-18 45-55 3-8 7-12 <4 8.5-9.5 17-19 11.6 25-32 14-18 45-55 3-8 7-12 <4 8.5-9.0 17-19 Drilling Fluid System: Tandem Geolograph/Swaco Shale Shakers Mud Cleaner Degassers Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes; Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Casin`q/Tubin`q Pro_qram: Hole size Cs_c~rb`q Liner 6-1/8" 3-1/2", 9.3#, L-80, EUE 8rd Mod Tubing 3-1/2", 9.3#, L-80, EUE 8rd Mod Len`qth Top (MD/'rVD) Btm (MDrrVD) 3090' 6495'/5155' 9585'/6212' 6495' 30'/30' 6495'/5155' Cement Calculations: Casing to be cemented: 3-1/2" in 6-1/8" open hole Volume = 124 bbls, Class G Cement Based on: Open hole volume + 60%, 150' liner lap, and 150' of cement above liner top. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated surface pressure is estimated at 2846 psi and is calculated using a gas column to surface with a maximum expected formation pressure in the Kuparuk of 3500 psi and a gas gradient of 0.11 psi/ft. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3500 psi. See attached BOPE schematic. Drilling Hazards: Lost Circulation: The suspect lost circulation zones throughout the Kuparuk field are the K-10 and K-5 intervals. The sidetrack 3F-13 A, will kick off out of the 7" casing below both the K-10 and K-5 intervals and current cement bond Icg, on 3F-13, indicates adequate cement exists behind 7" casing at the planned window depth. However, It is believed that both intervals should be able to handle the expected mud weights to be used for this sidetrack. Recent infill drilling data shows that wells in the area of 3F-13A were drilled to TD through the K-5 and K-10 intervals with mud weights as high as 12.6 ppg with no losses. Overpressured Intervals: Other Hazards: The kick-off point in 3F-13 A is below any zones which would be of pressure concern prior to weighting up for the Kuparuk interval. None Directional: KOP: Max hole angle: Close approach: 6,645' MD / 5,267' TVD 74° (in sidetrack portion) No Hazards 48° (in original portion) Lo_el_ Cl i n_cl Pro_qram: Open Hole Logs: Cased Hole Logs: GR / Resistivity None Notes: All drill solids generated from the 3F-13 A sidetrack will be hauled to CC2A in Prudhoe Bay for grind and inject. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well. KRU 3F-13 A GENERAL SIDETRACK PROCEDURE P&A WORK (Pre-Rig): 1. RU slickline unit. RIH and pull 1/4" OV at 2479' MD RKB and run dummy valve. Pressure test 7" casing to 3000 psi for 30 min (chart test). RIH and pull BPI from AVA at 7640' MD RKB. 2. RU E-line unit or use SL downhole power unit. RIH and set bridge plug in 3-1/2" tubing at +/-7647' MD RKB (middle of 10' pup joint below AVA and above Otis 'WD' packer) to isolate A sand perforations. 3. RU pump truck. Perform C sand injectivity test for upcoming CTU squeeze, by bullheading +/- 15 bbls of diesel down tubing into perforations. Record pressure and pump rate. . RU CTU. RIH and establish injection rate into perforations. Record breakdown pressure and rate. Note final injection rate and pressure. Tag bridge plug set in step #2 to tie-in CTU depth with RKB depth and flag coil. RIH with cement retainer on CTU and set retainer at +/- 7390' MD RKB (in first full joint of 3-1/2" tubing below Baker 'HB' packer). 5. Squeeze 37 bbls of 15.8 ppg Class G cement below retainer (10 bbl for the 3-1/2" and 7" volume between the packers + 27 bbls into perfs). If needed, use a spotting valve placed immediately above the retainer to displace the cement down coil to desired distance above top of retainer. Close valve and pump cement squeeze below retainer into perfs. Unsting from retainer and circulate any excess cement from well bore. Leave well shut-in with initial tubing pressure on wellhead. RDMO CTU. 6. Bleed annulus pressure to 0 psi. Pressure test tubing above cement retainer to 2500 psi for 30 min (chart test). Slowly bleed tubing pressure to 0 psi and monitor pressure for build-up. 7. RU slickline unit. RIH and pull 1-1/2" DV from bottom GLM at 7300' MD RKB, leaving an open pocket. 8. RU E-line unit. RIH and cut tubing at +/-7330' MD RKB (middle of first full joint of 3-1/2" tubing above Baker 'HB' packer). 9. Remove well house and scaffolding. WORKOVER RIG WORK: 1. MIRU Nordic 3. Lay hard-line to tree. 2. Verify well is dead. Circulate well to 11.4 ppg drilling mud through tubing cut at 7,330' MD. 3. Set BPV. ND tree. NU and test BOPE. Screw in landing joint. Pull tubing hanger to rig floor. POOH laying down all tubing and jewelry. PU 7" Casing Scraper on DP and run through Bridge Plug setting depth. RU E-line Unit. RIH and set Bridge Plug at +/- 6,653' MD. PU Baker 7" Window Master Bottom Trip Whipstock, MWD, Etc and RIH. Orient and set whipstock w/MWD. Shear off whipstock bolt and test wellbore to 3000 psi, testing bridge plug and cement plug to ensure isolation from perforations. Mill window in 7" casing. POOH and LD milling assembly. RIH w/6-1/8" bit, MWD / LWD, and steerable drilling assembly. Slide out window, perform FIT test, kick-off and directionally drill to total depth as per directional plan. Short trip to window in casing. POOH. Note: Mud should be weighted up +/- 200' MD above estimated top of Kuparuk. , . , . o 9. Run 3-1/2" liner to TD w/15u of overlap to top of milled window. 10. Cement liner. Set liner hanger and liner top packer. 11. Pressure test casing and liner lap to 3000 psi for 30 min (Chart Test for State). 12. PU above liner top and set storm packer. 13. ND BOPE, install 5-1/2" casing spool, NU and test BOPE. 14. Release storm packer and continue POOH laying down drill pipe. 15. RIH w/5-1/2" casing and sting into Tie Back Receptacle at top of liner. Space out. Freeze protect 5-1/2" x 7" annulus and land casing. 16. RIH w/3-1/2" completion assembly and sting into Seal Bore Extension below liner top packer. Space out. Displace well to sea water and land tubing. Test tubing and annulus to 3000 psi. 17. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic. 18. Clean out well to PBTD w/coiled tubing. Perforate through tubing. Lower Limit: 14 days Expected Case: 15 days Upper Limit: 17 days No problems milling window, drilling new hole, or running completion. Difficulties encountered milling window, or drilling new hole. MAC 7/29/99 NOTES I. COORDINATES ARE A.S.R, ZONE 4. 2. SECTION LINE DISTANCES ARE TRUE. ;5. HORIZONTAL AND VERTICAL POSITIONS ARE BASED ON MONUMENTS 3F-MIDDLE 8. 3F-EAST PER L.H.DaASSOC. 4.0. G. ELEVATIONS INTERPOLATED FROM S/C DWG. NO. C ED - R lXX -:~ 0~50 _.~. OF. A~ ~ ~ -~ ..'~ I HEREBY'CERTIFY THAT I AM. PROPERLY FIEGISTERED AND LICENSED TO PRACTICE LAND SURYEYINI~"IN THE .STATE OF ALASKA, THAT THIS PLAT REPRESENTS A SURVEY MADE UND. ER MY DIRECT SUPER¥11tON AND THAT CONDUCTOR8 I THRU 8 ARE .CORRECT AS OF SEPTEMBER 19,1985 AND.CONDUCTORS'8 THRU 16 ARE CORRECT AS OF SEPTEMBER CONDUCTORS 9 THRU 16 LOCATED IN PROTRACTED SEC. 19, T. 12 N., R.9 E., U. MER. AS BUIL. ONDUCTORS I-8 IN SE[eTlON 29 1- Y=5,98~, 734.98 LAT=70°22 ' 20. O858,, X= 508,662 89 FNL, 162 2- Y=5,985,745.10 X= 508,638.99 78 FNL, 139 3- Y=5,985,7~4 X= 508,616 69 FNL, 116 FWL, 4- Y=5,985,764.77 X= 508,593.66 59 FNL, 93 FWL, 5- Y=5,985,774.87 X= 508,570.43 49 FNL, 70 FWL, 6- Y=5,985,784.84 X= 508,547.58 39 FNL, 48 FWL, 7v Y=5,985,794.93 X= 508,524.44 28 FNL, 24 FWL, 8- Y=5,985,804.81 X= 508,501.41 .35 LONG=149°55'46.549'' FWL, 52 O.G., 56.1 PAD. LAT=70°22'20.1856'' LONG=149°55'47.233'' FWL, 52 O.G., 56.3 PAD .79 LAT=7OO22 20.2812" .29 LONG=149°55'47.896'' 52 O.G. 56.3 PAD LAT=70°22 20.3796" LONG=149°55'48.558~, 52 O.G. 56.2 PAD LAT=70°22 20.4792" LONG=149°55'49.237 52 O.G. 56.2 PAD LAT=70°22 20.5776" LONG=149°55'49.906'' 52 O.G. 56.1 pAD LAT=70°22 20.6771" LONG.149°55'50.582'' 52 O.G.,55.9 PAD LAT=70°22 20.7744" LONG=149°55t51.256'' 18 FNL, 1 FWL, 52 O.G.,55.9 PAD AS BUILT CONDUCTORS 9-161N SECTION 19 9- Y=5,985,834.85 X= 508,432.81 12 FSL, 67 FEL, 10- Y=5,985,844.70 X= 508,410.73 21'FSL, 89 FEL, 11- Y=5,985,855.14 X= 508,387.41 32 FSL, 112 FEL, 12- Y=5,985,865.19 X= 508,364.05 42 FSL,136 FEL,5 13- Y=5,985,874.97 X= 508,341.36 52 FSL, 158 FEL, 14- Y=5,985,885.O8 X= 508,318.27 62 FSL, 181 FEL, LAT=70°22 21.0708" LONG=149°55'53.26~'' 51.20.G. 56.1 PAD LAT=70°22 21.1678" LONG=149°55'53.908', 51.20.G. 56.2 PAD LAT=70°22 21.2708" LONG=149°55'54.590'' 51.20.G 56.3 PAD , LAT=70°22 21.3699" LONG=149°55,55.273,, 1.1 O.G.56.2 PAD LAT=70°22 21.4663" LONG=149°55,55.937,, 51.10.G. 56.3 PAD LAT=70°22 21.5660" LONG=149°55,56.612TM 51.1 O.G.,56.3 PAD ' 15- Y=5,985,894.96 LAT=70°22 21.6635" X= 508,295.72 LONG=149°55 ' 57. 271'' 72 FSL, 204 FEL, 51 O.G. 56.1 PAD 16- Y=5,985,904.95 LAT=70°22' 21. 7619'' X= 508,272.74 LONG=149°55 ~ 57. 943,, 82 FSL, 227 FEL~ 51 O.G. 56 PAJp - ~- · ~f,~ J~ ARCO Alalka, Inc.' L.II DRILL SITE? F IIUii ~ CONDUCTOR AS B~LT UUII? LOCATIONS ~.,-- m--. Drafted by: Sydney2 ~1- NO. N~ 85-26 ] '"-2~ "._ k II I '"~_' · . _ -~. I I · E,~ISTIN~' CONDUCTORS o NEW CONDUCTOR LOCATIONS ~££ SH££T #2 FOR NOT£$ AND LO¢^TION INFORM^TION LoUNSBURY & ASSOCIAT~2J, I~C. J~ DRILL ~TE A R C 0 AI ask a, in c. ~r ~u. OONDUOTORS 17-19 Subaidiary of Atlantic Riohfleld Company LOCATION AS-BUILT LK6306D8 5/06/96 CJ~A-D3F~-63O6D8 11" 50 "3 psi BOP Stack-- Nor 'ic Rig 3 Kuparuk River Unit Choke Line 1. Accumulator (;;apacity Test Check and fill accumulator reservoir to proper level with hydraulic fluid. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. B..OP Stack Test Fill BOP stack and manifold with water. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as instep 4, Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. D.o not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 Iow and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug.- Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for-3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Pedorm BOPE test once per week and functionally operate BOPE daily. 1. 16" Starting Head 2. 11" 5000 psi Horizontal Tubing Head 3. 11" 5000 psi Double Flange Adapter/Spacer Spool 4. 11" 5000 psi Hydril Type V Single Pipe Rams, 3-1/8" 5000 psi Side Outlets w/ manual locks 5. 11" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate, 2 Kill valves - each are 3" 5000 psi gate 6. 11" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams on Bottom, 3-1/8" Side Outlets w/Manual Locks 7. 11" 5000 psi Hydril Annular Preventer TAB, 09/30/98, v.1 7-1/16" 5 00 psi BOP Stack-- N'=rdic Rig 3 Kuparuk River Unit Operations Kill Line 3 I Choke Line Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 psi Iow and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 16" Starting Head 2. 7-1/16" 5000 psi Tubing Head 3. 7-1/16" 5000 psi Hydril Single Pipe Rams, 3-1/8" 5000 psi Side Outlets w/ Manual Locks 4. 7-1/16" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate, 2 Kill valves - each are 3" 5000 psi gate 5. 7-1/16" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams on Bottom, 3-1/8" Side Outlets w/Manual Locks 6. 7-1/16" 5000 psi Hydril Annular Preventer, Hub Bottom Connection TAB, 10/01/98, v.2 3F-13 Proposed P&A Bridge Plug Depth tied in with CET 1/7/86 9-5/8" 36# J-55 casing set @ 3652' MD 7" Baker 'Window Master Whipstock' top @ 6632' MD. 7" Baker Bridge Plug set @ 6653' MD. Abandoned C-Sand Perfs 7479'-7579' 7592'-7599' Cement retainer set in first full joint below packer @ +/-7390' MD with cement squeezed below, down through AVA into C sand perfs Bridge plug set in 10' pup joint below AVA @ +/-7647' MD to isolate A sand perforations. Abandoned A-San~ Perfs 7721'-7748' 7763'-7814' 7",26#,J-55 casing @ 8050' Last Tag at 7828' MD on 7/14/99 PBTD = 7962' MD TD = 8108' MD BDN / MAC 7/28/99 KRU 3F-13 SUNDRY OBJECTIVE P & A WELL FOR SIDETRACK OPERATIONS (reference attached plugback schematic) CURRENT WELLBORE STATUS: 3F-13 was drilled and completed in December 1985 as a 3-1/2" selective single completion producing from the Kuparuk C and A sands. The C sand has watered out and hydraulically limits A sand production. An infill injector is planned for 2000 in this fault block and along with existing producer 3F-19 will recover the remaining A sand reserves. The sidetrack of 3F-13 is into an isolated fault block to the west, targeting A sand reserves with injection support provided by 3F-16A. The 3F-13 C sand is currently shut in and the gas lift mandrels contain dummy valves (except for an OV in the top station at 2479' MD RKB). The tubing tail with stuck Amerada gauges in the 'D' nipple was cut on 8/30/97 at 7666' MD RKB. There is also documented 7" by 9 5/8" communication when the well is on gaslift and dried pipe dope on the 7" BTC connection is suspected. The 7" casing pack off pressure tested successfully on 7/17/99. The P&A to prepare the well for sidetracking is a two step procedure. First setting a bridge plug in the 3-1/2" tubing above the bottom production packer to isolate the A sand perforations and then setting a cement retainer as noted on the plugback schematic and down-squeezing cement through the AVA and into the open C sand perfs. P&A WORK (Pre-Ric~): 1. RU slickline unit. RIH and pull 1/4" OV at 2479' MD RKB and run dummy valve. Pressure test 7" casing to 3500 psi for 30 min (chart test). RIH and pull BPI from AVA at 7640' MD RKB. 2. RU E-line unit or use SL downhole power unit. RIH and set bridge plug in 3-1/2" tubing at +/-7647' MD RKB (middle of 10' pup joint below AVA and above Otis 'WD' packer) to isolate A sand perforations. 3. RU pump truck. Perform C sand injectivity test for upcoming CTU squeeze, by bullheading +/- 15 bbls of diesel down tubing into perforations. Record pressure and pump rate. . RU CTU. RIH and establish injection rate into perforations. Record breakdown pressure and rate. Note final injection rate and pressure. Tag bridge plug set in step #2 to tie-in CTU depth with RKB depth and flag coil. RIH with cement retainer on CTU and set retainer at +/- 7390' MD RKB (in first full joint of 3-1/2" tubing below Baker 'HB' packer). 5. Squeeze 37 bbls of 15.8 ppg Class G cement below retainer (10 bbl for the 3-1/2" and 7" volume between the packers + 27 bbls into perfs). If needed, use a spotting valve placed immediately above the retainer to displace the cement down coil to desired distance above top of retainer. Close valve and pump cement squeeze below retainer into perfs. Unsting from retainer and circulate any excess cement from well bore. Leave well shut-in with initial tubing pressure on wellhead. RDMO CTU. 6. Bleed annulus pressure to 0 psi. Pressure test tubing above cement retainer to 2500 psi for 30 min (chart test). Slowly bleed tubing pressure to 0 psi and monitor pressure for build-up. 7. RU slickline unit. RIH and pull 1-1/2" DV from bottom GLM at 7300' MD RKB, leaving an open pocket. 8. RU E-line unit. RIH and cut tubing at +/-7330' MD RKB (middle of first full joint of 3-1/2" tubing above Baker 'HB' packer). 9. Remove well house and scaffolding. BDN 7/28/99 5200 3000 I ~ I Point T~e-ln Survey Top of ~¢nlpetock KOP / Base Wh;l~tock Mill Bury OepU~ / B~ EOC C50 C20 (HRZ Midpe;nt) Base HRZ K-1 Marker Begin Drop/Turn to T Top D EOC / 5F-13A Top C4 Top C~ Top C2 Top C1 lop B Shale Fop A6 Cop A5 JTop A4 Beg;n 8u;Id/SF-15A T Top A2 EOC Top A1 5F-15A Top M;luveach ,TO / CSC PT ARCO Alaska, Inc. Sfruafurs: Pod 3F Well : 15A Field: Kup~ruk River Unit Leoeflon : North Slope, Alaska West (feet) 2800 2600 2400 2200 2000 I I I II II I I TD LOCATION: 852' FSL, 1998' FEL SEC. 18, T12N, RgE TARGET / TOP MILUVF_ACH: 689' FSL, 1986' FEL SEC. 18, T12N, RgE TARGET / TOP AS: I 315' FSL, 1958' FEL SEC. 18, T12N, RgE TARGET / TOP C4: 85' FNL, 1919' FEL SEC. 19, T12N, R9E 340.92 AZIMUTH 5443' (TO C4 TARGET) ***Plane of Proposal*** PROFILE COMMENT DATA MD Inc O;r TVD NoH. h F'os[ 659a..00 40.55 540.72 5251.07 5590.40-1147.78 6532.00 40.63 .540.645259,93 3415,75-1155,96 664-5.00 4250 559.6a.5269.66 5421.84-1155.89 6661,00 44.80 558.4.55281.25 5432,15-1162.84 6895-21 75.81 559.70 5398,50 3616.80-1255.0~ 7115.81 75.81 559.70 5460,00 5815.49-1506,58 7874-.23 75.81 559.70 5672.00 4500.40-1559.94 8064.55 75.81 559.70 5725,00 4671.65-1623.27 6529.76 75.81 559.70 5799.00 4910.71-1711.71 8436.11 75.81 ,559,705828.6-55006.50-1747.14 8569.52 68.40 352.60 5872.00 5128.65-1777.49 8585.61 67.81 554.21 5878.00 5145.46-1779.21 871802 67.81 354.21 5928.00 5265.44-1791.57 8760.59 67.81 554.21 5g4a.,OO5504.47- 1795.,.~5 6765.04 67.81 554.21 5945.00 5306.91-1795.78 8792.17 67.81 .:35~.21 5956.00 5553.7,5 - 1798.49 6960,19 67.81 554.21 6027.00 5506.95- 1816.05 8988.14 67'81 554.21 6050.00 5514.27-1816.79 9006.68 67.81 554.21 6057.00 5551.55-1816.52 g019.92 67'81 554.21 6042.00 5543.55-1519.76 9107.54 72.04 555.42 6072.00 5625.50-1827.17 9126.48 7236 555. 676077.76 5643.50-1825.59 9311.61 72,96 ,.~55.67 6152.00 5820.00-1841.95 9414.00 72.96 5.55.575162.00 5917.62-1849.54 9564.65 72.96 555,67 6212,00 6080,31-1861,65 ~o V. Sect D~]/I O0 357':J.54 0.00 5604.06 5512.68 1.5.28 5625.72 15.2.8 5821.18 12.50 4~032.98 0.00 4~76~09 0,00 4945.62 0.00 5200.47 0,00 5427.92 10.00 544.2.50 1 5561.81 0,00 5599.99 0,00 560258 0,00 552.~-53 0.00 579~.06 0,00 5805.2.2 0,0~ 3821.92 0.00 5853.86 0,0(: 5913.54 5.0C 5951.20 B 102.58 O.OC B 197.04 0.0~ 6354.82 0,00 1800 1600 1400 1200 1000 800 I I I I I I I I I I I rD / csG PT 3F-13ATop Miluveoch 7/29/99 A1 EOC A2 Begin Build/SF-15A Top A3 7/15/99 A4 A5 A6 B Shole C1 ,Cc23 EOC / 3F-13A Top C4 7/29/99 : Top D in Drop/Turn Lo Target 4-1 Marker Bose HRZ C20 (HRZ Midpoint) C50 Mill Bu~ Depth / Begin Buil( KOP / Bose Whipstock Face KOP / BASE WHIPSTOCK: 1806' FNL, 1304' FEL SEC. 19, T12N, R9E TO~TiPe of Whipsi:ock -In Survey SURFACE LOCATION: (NOT DISPLAYED) 52' FSL, 158' FEL SEC. 19, T12N, R9E 600 6400 6200 6000 5800 5600 5400 5200 5000 4800 4800 I Z 0 440O 4200 --I- 4000 3800 3600 3400 3200 3000 2800 2600 2400 Created by: Andrews For: CHAMBERS1 Dote plotted : 29-Ju1-1999/ I Plot Ret ...... ;, 15A Ver,;on ~12. / I Coordinates ore ;n feet reference elo~ ~13A. / ARCO Alaska, Inc.[ Struotum: Pad 3F Well: 13A I Field: Kuparuk River Unlt Location : Norlh Slope, Alaska] 4650- 4800 4950 5100 ..-.. 5250 ~ 5400 5550 0 5700 0 > 5850 I-,- 6000 I 6150 6300 6450 6600 6750 TANGENT ANGLE: 73.81 DEG 340.92 AZIMUTH 5443' (TO C4 TARGET) ***Plane of Proposal*** TARGET ANGLE: 67.81 DEG TARGET ANGLE: 72.96 DEG i i i i i i i i i i i i i i i i i i i i i i i i i i i i ii i i i i i i i i i i i i I i i i 3150 3500 3450 5600 3750 3900 4050 4200 4550 4500 4650 4800 4950 51 O0 5250 5400 5550 5700 5850 6000 6150 6500 6450 Vertical Section (feet) -> Azimuth ,540.92 wlfh reference 0.00 N, 0.00 E from slo! #15A Creoted by: Andrews For: CHAMBEI~ Dote I~otted Plot Re terence Caordrnates are In fed reference slot ~13A. True V~ ~*.U~__~2~,~ 6600 6400 6200 6000 5800 5600 5400 5200 A 5000 I 4800 4600 4400 4200 4000 3800 5600 5400 3200 5000 2800 ARCO Alaska, Inc. Sfruafure: Pad 5F Waft : Reid : Kul~ruk River Unlt Le;~lon: North Slope, Alaska <- West (feet) 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 200 I I I I I I I I I I I I I I I I I I I I I I I I I I ! I I 1 J5BO 0 ~200 I~ ~000 I \ i, 5800 \ 6200 \ 6000 \ 5800 O~ 5600 560 O0 4200 \~6200 5400 \~6000 5200 ~ 4000 5800 5000 38OO 5600 4800 5600 5400~ 400 ~5 4600 '~ 5200 J~ 5400 ~ ~, 6200 0 ~ ~ 5800 3000 , , , ~ ~ , ~ , , ~ , ~ , , , , , , , \~=~ ~ , , , , , ]28oo 2800 2600 2400 2200 2000 18oo 1600 1400 12oo lOOO 8oo 600 400 200 o 200 ~- West (feet) 66OO 6400 62O0 6OO0 580O 5600 54OO 5200 50OO A I 4600 33O 320 310 34O ARCO Alaska, Inc. Sfruofure: Pad 3F Well: Fle~d: Kuparuk River UnFf Laoaflon: North Slope, Alaska TRUE NORTH .5500 10 20 30 40 50 3OO 60 29O 7O 280 2( 80 27O z750 26O 100 24O 110 120 230 220 210 2OO 190 180 170 160 150 140 130 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ARCO Alaska, Inc. Pad 3F 13A slot #13A Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 13A Version #12 Our ref : prop3483 License : Date printed : 29-2u1-1999 Date created : 23-2u1-1999 Last revised : 29-~u1-1999 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 22 20.956,w149 55 51.299 Slot location is n70 22 21.467,w149 55 55.922 Slot Grid coordinates are N 5985875.078, E 508341.871 Slot local coordinates are 52.00 N 158.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 3F, 13A Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 1 Your ref : 13A Version #12 Last revised : 29-Ju1-1999 Dogleg Vert Deg/lOOft Sect 6594.00 40.55 340.72 5231.07 3390.40 N 1147.78 W 0.00 6600.00 40.56 340.71 5235.63 3394.08 N 1149.07 W 0.25 6632.00 40.63 340.64 5259.93 3413,73 N 1155.96 W 0.25 6645.00 42.50 339.64 5269.66 3421.84 N 1158.89 W 15.28 6661.00 44.80 338.45 5281.23 3432.15 N 1162.84 W 15,28 3579.34 Tie-In Survey 3583.24 3604.06 Top of Whipstock 3612.68 KOP / Base Whipstock Face 3623.72 Mill Bury Depth / Begin Build 6700.00 49.68 338.73 5307.70 3458.80 N 1173.29 W 12.50 3652.32 6800.00 62.17 339.29 5363,63 3535.99 N 1202.88 W 12.50 3734.94 6893.21 73.81 339.70 5398.50 3616,80 N 1233,08 W 12.50 3821.18 EOC 7000.00 73.81 339.70 5428,27 3712.98 N 1268.66 W 0.00 3923.71 7113,81 73.81 339.70 5460,00 3815.49 N 1306.58 W 0.00 4032,98 C30 7500.00 73.81 339.70 5567,67 4163,34 N 1435,25 W 0.00 4403.78 7874.23 73.81 339,70 5672.00 4500.40 N 1559.94 W 0.00 4763,09 C20 (HRZ Midpoint) 8000.00 73.81 339,70 5707.06 4613.69 N 1601.84 W 0.00 4883.85 8064.33 73.81 339.70 5725.00 4671,63 N 1623.27 W 0.00 4945.62 Base HRZ 8329.76 73,81 339.70 5799,00 4910.71 N 1711.71W 0.00 5200.47 K-1 Marker 8436.11 73.81 339.70 5828.65 5006.50 N 1747.14 W 0.00 5302.58 Begin Drop/Turn to Target 8500.00 71.11 345.77 5847,92 5064.62 N 1765,23 W 10,00 5363.42 8569,52 68.40 352.60 5872.00 5128.63 N 1777.49 W 10.00 5427.92 Top D 8585.61 67.81 354.21 5878.00 5143.46 N 1779,21 W 10.00 5442.50 EOC / 3F-13A Top C4 7/29/99 8585.66 67.81 354.21 5878.02 5143.50 N 1779.21 W 10,00 5442,54 8718.02 67.81 354.21 5928.00 5265.44 N 1791,57 W 0.00 5561.81 Top C3 8760.39 67,81 354.21 5944.00 5304.47 N 1795,53 W 0.00 5599.99 Top C2 8763.04 67.81 354.21 5945.00 5306.91 N 1795.78 W 0.00 5602,38 Top C1 8792.17 67.81 354,21 5956.00 5333.75 N 1798.49 W 0.00 5628.63 Top B Shale 8980.19 67.81 354.21 6027.00 5506.95 N 1816.05 W 0.00 5798,06 Top A6 8988.14 67.81 354.21 6030.00 5514.27 N 1816.79 W 0.00 5805.22 Top A5 9000.00 67.81 354.21 6034.48 5525.20 N 1817.90 W 0.00 5815.91 9006.68 67.81 354.21 6037.00 5531.35 N 1818.52 W 0.00 5821.92 TopA4 9019.92 67.81 354.21 6042,00 5543.55 N 1819.76 W 0,00 5833.86 Begin Build/3F-13A Top A3 7/15/99 9100.00 71.68 355.32 6069.72 5618.35 N 1826.60 W 5.00 5906,79 9107.34 72.04 355.42 6072.00 5625.30 N 1827.17 W 5.00 5913.54 Top A2 9126.48 72.96 355.67 6077,76 5643.50 N 1828.59 W 5.00 5931.20 EOC 9311.61 72.96 355.67 6132.00 5820.00 N 1841.95 W 0,00 6102,38 Top A1 9414,00 72.96 355.67 6162.00 5917.62 N 1849.34 W 0.00 6197.04 3F-13A Top Miluveach 7/29/99 9500,00 72.96 355.67 6187.20 5999,61N 1855,54 W 0.00 6276.56 9584,65 72.96 355.67 6212,00 6080.31 N 1861.65 W 0.00 6354,82 TD / CSG PT All data is in feet unless otherwise stated. Coordinates from slot #13A and TVD from RKB (Nordic III) (87,00 Ft above mean sea level), Bottom hole distance is 6358.93 on azimuth 342,98 degrees from wellhead. Total Dogleg for wellpath is 53.83 degrees, Vertical section is from wellhead on azimuth 340,92 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 3F, 13A Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 13A Version #12 Last revised : 29-Ju1-1999 Comments i n wel 1 path MD TVD Rectangular Coords. Comment 6594.00 5231.07 3390.40 N 1147.78 W Tie-In Survey 6632.00 5259.93 3413.73 N 1155.96 W Top of Whipstock 6645.00 5269.66 3421.84 N 1158.89 W KOP / Base Whipstock Face 6661.00 5281.23 3432.15 N 1162.84 W Mill Bury Depth / Begin Build 6893.21 5398.50 3616.80 N 1233.08 W EOC 7113.81 5460.00 3815.49 N 1306.58 W C30 7874.23 5672.00 4500.40 N 1559.94 W C20 (HRZ Midpoint) 8064.33 5725.00 4671.63 N 1623.27 W Base HRZ 8329.76 5799.00 4910.71 N 1711.71W K-1 Marker 8436.11 5828.65 5006.50 N 1747.14 W Begin Drop/Turn to Target 8569.52 5872.00 5128.63 N 1777.49 W Top D 8585.61 5878.00 5143.46 N 1779.21W EOC / 3F-13A Top C4 7/29/99 8718.02 5928.00 5265.44 N 1791.57 W Top C3 8760.39 5944.00 5304.47 N 1795.53 W Top C2 8763.04 5945.00 5306.91 N 1795.78 W Top C1 8792.17 5956.00 5333.75 N 1798.49 W Top B Shale 8980.19 6027.00 5506.95 N 1816.05 W Top A6 8988.14 6030.00 5514.27 N 1816.79 W Top A5 9006.68 6037.00 5531.35 N 1818.52 W Top A4 9019.92 6042.00 5543.55 N 1819.76 W Begin Build/3F-13A Top A3 7/15/99 9107.34 6072.00 5625.30 N 1827.17 W Top A2 9126.48 6077.76 5643.50 N 1828.59 W EOC 9311.61 6132.00 5820.00 N 1841.95 W Top A1 9414.00 6162.00 5917.62 N 1849.34 W 3F-13A Top Miluveach 7/29/99 9584.65 6212.00 6080.31N 1861.65 W TD / CSG PT Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised ...................... EOC / SF-13A Top 04 ~ii~DD[~_D~_~i~D~iDiDD[iD"~[~[D~ ...... ~.~[~I~ ..... ~.~[~.l~"~.~[~[~i[~ ....... Begin Build/3F-13A T 506516.000,5991416.000,0.0000 6042.00 5543.55N 1819.76W 21-Jun-1999 3F-13A Top Miluveach 506486.000,5991790.000,0.0000 6162.00 5917.62N 1849.34W 29-Ju1-1999 ARCO Alaska, Inc. Pad 3F, 13A Kuparuk Ri ver Uni t, North S1 ope, A1 aska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 1 Your ref : 13A Version #12 Last revised : 29-Ju1-1999 Dogleg Vert Deg/lOOft Sect 6594.00 40.55 340.72 5231.07 3442.40 N 1305.78 W 0.00 6600.00 40.56 340.71 5235.63 3446.08 N 1307.07 W 0.25 6632.00 40.63 340.64 5259.93 3465.73 N 1313.96 W 0.25 6645.00 42.50 339.64 5269.66 3473.84 N 1316.89 W 15.28 6661.00 44.80 338.45 5281.23 3484.15 N 1320.84 W 15.28 3579.34 Tie-In Survey 3583.24 3604.06 Top of Whipstock 3612.68 KOP / Base Whipstock Face 3623.72 Mill Bury Depth / Begin Build 6700.00 49.68 338.73 5307.70 3510.80 N 1331.29 W 12.50 3652.32 6800.00 62.17 339.29 5363.63 3587.99 N 1360.88 W 12.50 3734.94 6893.21 73.81 339.70 5398.50 3668.80 N 1391.08 W 12.50 3821.18 EOC 7000.00 73.81 339.70 5428.27 3764.98 N 1426.66 W 0.00 3923.71 7113.81 73.81 339.70 5460.00 3867.49 N 1464.58 W 0.00 4032.98 C30 7500.00 73.81 339.70 5567.67 4215.34 N 1593.25 W 0.00 4403.78 7874.23 73.81 339.70 5672.00 4552.40 N 1717.94 W 0.00 4763.09 C20 (HRZ Midpoint) 8000.00 73.81 339.70 5707.06 4665.69 N 1759.84 W 0.00 4883.85 8064.33 73.81 339.70 5725.00 4723.63 N 1781.27 W 0.00 4945.62 Base HRZ 8329.76 73.81 339.70 5799.00 4962.71 N 1869.71 W 0.00 5200.47 K-1 Marker 8436.11 73.81 339.70 5828.65 5058.50 N 1905.14 W 0.00 5302.58 Begin Drop/Turn to Target 8500.00 71.11 345.77 5847.92 5116.62 N 1923.23 W 10.00 5363.42 8569.52 68.40 352.60 5872.00 5180.63 N 1935.49 W 10.00 5427.92 Top D 8585.61 67.81 354.21 5878.00 5195.46 N 1937.21 W 10.00 5442.50 EOC / 3F-13A Top C4 7/29/99 8585.66 67.81 354.21 5878.02 5195.50 N 1937.21 W 10.00 5442.54 8718.02 67.81 354.21 5928.00 5317.44 N 1949.57 W 0.00 5561.81 Top C3 8760.39 67.81 354.21 5944.00 5356.47 N 1953.53 W 0.00 5599.99 Top C2 8763.04 67.81 354.21 5945.00 5358.91N 1953.78 W 0.00 5602.38 Top C1 8792.17 67.81 354.21 5956.00 5385.75 N 1956.49 W 0.00 5628.63 Top B Shale 8980.19 67.81 354.21 6027.00 5558.95 N 1974.05 W 0.00 5798.06 Top A6 8988.14 67.81 354.21 6030.00 5566.27 N 1974.79 W 0.00 5805.22 Top A5 9000.00 67.81 354.21 6034.48 5577.20 N 1975.90 W 0.00 5815.91 9006.68 67.81 354.21 6037.00 5583.35 N 1976.52 W 0.00 5821.92 Top A4 9019.92 67.81 354.21 6042.00 5595.55 N 1977.76 W 0.00 5833.86 Begin Build/3F-13A Top A3 7/15/99 9100.00 71.68 355.32 6069.72 5670.35 N 1984.60 W 5.00 5906.79 9107.34 72.04 355.42 6072.00 5677.30 N 1985.17 W 5.00 5913.54 Top A2 9126.48 72.96 355.67 6077.76 5695.50 N 1986.59 W 5.00 5931.20 EOC 9311.61 72.96 355.67 6132.00 5872.00 N 1999.95 W 0.00 6102.38 Top A1 9414.00 72.96 355.67 6162.00 5969.62 N 2007.34 W 0.00 6197.04 3F-13A Top Miluveach 7/29/99 9500.00 72.96 355.67 6187.20 6051.61N 2013.54 W 0.00 6276.56 9584.65 72.96 355.67 6212.00 6132.31 N 2019.65 W 0.00 6354.82 TD / CSG PT All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 19. T12N. R9E and TVD from RKB (Nordic III) (87.00 Ft above mean sea level). Bottom hole distance is 6358.93 on azimuth 342.98 degrees from wellhead. Total Dogleg for wellpath is 53.83 degrees. Vertical section is from wellhead on azimuth 340.92 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska. Inc. Pad 3F,13A Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 13A Version#12 Last revised : 29-Ju1-1999 Comments in wellpath MD TVD Rectangular Coords. Comment '~594.00 5231.07 3442.40 N 1305.78 W Tie-In Survey 6632.00 5259.93 3465.73 N 1313.96 W Top of Whipstock 6645.00 5269.66 3473.84 N 1316.89 W KOP / Base Whipstock Face 6661.00 5281.23 3484.15 N 1320.84 W Mill Bury Depth / Begin Build 6893.21 5398.50 3668.80 N 1391.08 W EOC 7113.81 5460.00 3867.49 N 1464.58 W C30 7874.23 5672.00 4552.40 N 1717.94 W C20 (HRZ Midpoint) 8064.33 5725.00 4723.63 N 1781.27 W Base HRZ 8329.76 5799.00 4962.71N 1869.71 W K-1 Marker 8436.11 5828.65 5058.50 N 1905.14 W Begin Drop/Turn to Target 8569.52 5872.00 5180.63 N 1935.49 W Top D 8585.61 5878.00 5195.46 N 1937.21W EOC / 3F-13A Top C4 7/29/99 8718.02 5928.00 5317.44 N 1949.57 W Top C3 8760.39 5944.00 5356.47 N 1953.53 W Top C2 8763.04 5945.00 5358.91N 1953.78 W Top C1 8792.17 5956.00 5385.75 N 1956.49 W Top B Shale 8980.19 6027.00 5558.95 N 1974.05 W Top A6 8988.14 6030.00 5566.27 N 1974.79 W Top A5 9006.68 6037.00 5583.35 N 1976.52 W Top A4 9019.92 60z12.00 5595.55 N 1977.76 W Begin Build/3F-13A Top A3 7/15/99 9107.34 6072.00 5677.30 N 1985.17 W Top A2 9126.48 6077.76 5695.50 N 1986.59 W EOC 9311.61 6132.00 5872.00 N 1999.95 W Top A1 9414.00 6162.00 5969.62 N 2007.34 W 3F-13A Top Miluveach 7/29/99 9584.65 6212.00 6132.31N 2019.65 W TD / CSG PT Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised Begin Build/3F-13A T 506516.000,5991416.000,0.0000 6042.00 5595.55N 1977.76W 21-Jun-1999 3F-13A Top I.liluveach 506486.000,5991790.000,0.0000 6162.00 5969.62N 2007.34W 29-Ju1-1999 ARCO Alaska, Inc. Pad 3F, 13A Kuparuk Rive,- Unit,North Slope, A1 Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth 6594.00 40.55 340.72 5231.07 6600.00 40.56 340.71 5235.63 6632.00 40.63 340.64 5259.93 6645.00 42.50 339.64 5269.66 6661.00 44.80 338.45 5281.23 aska PROPOSAL LISTING Page 1 Your ref : 13A Version #12 Last revised : 29-Ju1-1999 R E C TAN G U L A R Dogleg Vert G R I D C 0 0 R D S C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 3390.40N 1147.78W 0.00 3579.34 507190.36 5989263.83 3394.08N 1149.07W 0.25 3583.24 507189,06 5989267.51 3413.73N 1155.96W 0.25 3604,06 507182.15 5989287,15 3421,84N 1158.89W 15.28 3612.68 507179,21 5989295.26 3432.15N 1162.84W 15.28 3623.72 507175,25 5989305.57 6700,00 49.68 338.73 5307.70 3458.80N 1173.29W 12.50 3652.32 507164,77 5989332,20 6800.00 62.17 339.29 5363,63 3535.99N 1202.88W 12.50 3734.94 507135.10 5989409.35 6893.21 73.81 339.70 5398.50 3616,80N 1233.08W 12.50 3821.18 507104,80 5989490.11 7000.00 73.81 339.70 5428.27 3712.98N 1268.66W 0.00 3923.71 507069,12 5989586.25 7113.81 73.81 %9.70 5460.00 3815.49N 1306.58W 0.00 4032.98 507031.09 5989688,70 7500.00 73.81 339.70 5567.67 4163.34N 1435.25W 0.00 4403.78 506902.04 5990036.36 7874.23 73.81 339.70 5672,00 4500.40N 1559.94W 0.00 4763.09 506776.98 5990373.26 8000.00 73.81 339.70 5707.06 4613.69N 1601.84W 0.00 4883.85 506734,95 5990486.48 8064.33 73.81 339.70 5725.00 4671.63N 1623,27W 0.00 4945,62 506713.46 5990544.40 8329.76 73,81 339.70 5799,00 4910.71N 1711.71W 0.00 5200.47 506624.76 5990783.35 8436.11 73.81 339.70 5828.65 5006.50N 1747.14W 0.00 5302.58 506589.22 5990879.09 8500.00 71.11 345.77 5847,92 5064.62N 1765.23W 10.00 5363,42 506571.07 5990937.19 8569.52 68.40 352,60 5872,00 5128.63N 1777.49W 10.00 5427.92 506558.73 5991001.18 8585.61 67.81 354.21 5878,00 5143.46N 1779.21W 10,00 5442,50 506557.00 5991016.00 8585.66 67.81 ~54.21 5878.02 5143.50N 1779.21W 10.00 5442.54 506557.00 5991016.04 8718.02 67.81 354.21 5928.00 5265.44N 1791.57W 0.00 5561.81 506544.50 5991137.95 8760.39 67.81 ~54.21 5944,00 5304.47N 1795.53W 0.00 5599.99 506540.50 5991176.98 8763.04 67.81 t~4.21 5945,00 5306.91N i795.78W 0.00 5602.38 506540.25 5991179.41 8792.17 67.81 ~34.21 5956.00 5333.75N 1798.49W 0.00 5628.63 506537.50 5991206.24 8980.19 67.81 ~{M.21 6027.00 5506.95N 1816.05W 0.00 5798.06 506519.75 5991379.41 8988.14 67.81 354.21 6030.00 5514.27N 1816,79W 0,00 5805.22 506519.00 5991386.73 9000.00 67.81 354.21 6034.48 5525.20N 1817.90W 0,00 5815.91 506517,88 5991397.66 9006.68 67.81 354.21 6037.00 5531.35N 1818.52W 0.00 5821.92 506517.25 5991403.81 9019.92 67.81 354.21 6042.00 5543.55N 1819.76W 0.00 5833.86 506516,00 5991416.00 9100.00 71.68 355.32 6069.72 5618,35N 1826.60W 5.00 5906.79 506509.07 5991490.79 9107.34 72.04 355.42 6072.00 5625.30N 1827.17W 5.00 5913.54 506508.50 5991497.74 9126,48 72.96 355.67 6077,76 5643.50N 1828.59W 5,00 5931.20 506507,06 5991515.93 9311.61 72.96 355.67 6132.00 5820.00N 1841,95W 0.00 6102.38 506493.50 5991692.40 9414.00 72.96 355.67 6162.00 5917.62N 1849.34W 0.00 6197.04 506486.00 5991790.00 9500.00 72.96 355.67 6187,20 5999.61N 1855.54W 0.00 6276.56 506479,70 5991871.98 9584.65 72.96 255.67 6212.00 6080.31N 1861.65W 0.00 6354.82 506473.50 5991952.66 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #13A and TVD from RKB (Nordic III) (87.00 Ft above mean sea level). Bottom hole distance is 6358.93 on azimuth 342.98 degrees from wellhead, Total Dogleg for wel 1 path is 53.83 degrees, Vertical section is from wellhead on azimuth 340,92 degrees, Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 3F, 13A Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 13A Version #12 Last revised : 29-Ju1-1999 Comments in wellpath MD TVD Rectangular Coords. Comment 6594.00 5231.07 3390.40N 1147.78W Tie-In Survey 6632.00 5259.93 3413.73N 1155.96W Top of Whipstock 6645.00 52,~9,66 3421.84N 1158,89W KOP / Base Whipstock Face 6661.00 5281,23 3432.15N 1162.84W Mill Bury Depth / Begin Build 6893.21 53%,50 3616.80N 1233.08W EOC 7113.81 5460,00 3815.49N 1306,58W C30 7874.23 5672,00 4500.40N 1559,94W C20 (HRZ Midpoint) 8064.33 5725,00 4671.63N 1623.27W Base HRZ 8329.76 57~9,00 4910.71N 1711.71W K-1 Marker 8436.11 5828.65 5006.50N 1747.14W Begin Drop/Turn to Target 8569.52 5872,00 5128.63N 1777.49W Top D 8585.61 5878.00 5143.46N 1779.21W EOC / 3F-13A Top C4 7/29/99 8718.02 5928,00 5265.44N 1791.57W Top C3 8760.39 5%4.00 5304.47N 1795.53W Top C2 8763.04 59t15.00 5306,91N 1795.78W Top C1 8792.17 5956.00 5333,75N 1798,49W Top B Shale 8980.19 60'!i',00 5506,95N 1816,05W Top A6 8988.14 60r~S.O0 5514.27N 1816.79W Top A5 9006.68 6037.00 5531.35N t818.52W Top A4 9019.92 6042.00 5543.55N 1819.76W Begin Build/3F-13A Top A3 7/15/99 9107.34 6072.00 5625.30N 1827.17W Top A2 9126.48 6077.76 5643.50N 1828.59W EOC 9311.61 6132.00 5820.00N 1841.95W Top A1 9414.00 6162.00 5917.62N 1849.34W 3F-13A Top Miluveach 7/29/99 9584.65 62i2.00 6080.31N 1861.65W TD / CSG PT Targets associated with this wellpath Target name Geographic Location T,V.D. Rectangular Coordinates Revised Begin Bull'~ }F-13A T 506516.000,5991416.000,0.0000 6042.00 5543.55N 1819.76W 21-~1un-1999 3F-13A To~. ~'~luveach 506486.000,5991790.000,0.0000 6162.00 5917.62N 1849.34W 29-~1u1-1999 ARCO Alaska, Inc. Pad 3F,13A Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 6594,00 40.55 340.72 5231.07 6600.00 40.56 340.71 5235,63 6632.00 40.63 340.64 5259.93 6645.00 42.50 339.64 5269,66 6661.00 44.80 338.45 5281.23 6700.00 49.68 338.73 5307.70 6800.00 62.17 339.29 5363.63 6893.21 73.81 339.70 5398.50 7000.00 73.81 339.70 5428,27 7113.81 73.81 339.70 5460.00 PROPOSAL LISTING Page 1 Your ref : 13A Version #12 Last revised : 29-Ju1-1999 R E C T A N G U L A R Vert Ellipse Semi Axes Minor C 0 0 R D I N A T E S Sect Major Minor Vert. Azi. 3390.40 N 1147.78 W 3579.34 75.76 26.72 22.70 341.35 3394.08 N 1149.07 W 3583.24 75.76 26.72 22.70 341.35 3413.73 N 1155.96 W 3604.06 75.76 26.72 22.71 341.35 3421.84 N 1158.89 W 3612.68 75,77 26.72 22.71 341.34 3432.15 N 1162.84 W 3623.72 75.78 26.72 22.71 341.34 7500.00 73.81 339.70 5567.67 7874.23 73.81 339.70 5672.00 8000.00 73,81 339.70 5707.06 8064.33 73.81 339.70 5725.00 8329.76 73.81 339.70 5799.00 3458.80 N 1173,29 W 3652.32 75.82 26.73 22.71 341.34 3535.99 N 1202.88 W 3734,94 76.08 26.74 22.75 341.33 3616.80 N 1233.08 W 3821.18 76.56 26.76 22.83 341.30 3712.98 N 1268,66 W 3923.71 77.37 26.78 22.96 341.26 3815.49 N 1306.58 W 4032,98 79,01 26.82 23.25 341.20 4163.34 N 1435.25 W 4403.78 84.55 26.95 24.22 340.97 4500,40 N 1559,94 W 4763.09 93,32 27.15 25.84 340,73 4613.69 N 1601.84 W 4883.85 96.27 27.21 26.38 340.65 4671.63 N 1623.27 W 4945.62 98,15 27.26 26.74 340.62 49!0.71 N 1711.71 W 5200.47 105,94 27.44 28.24 340.48 8436.11 73.81 339.70 5828.65 5006.50 N 1747.14 W 5302.58 109,06 27,51 28.84 340.42 8500.00 71.11 345.77 5847,92 5064.62 N 1765.23 W 5363.42 110.80 27.56 29.23 340,50 8569.52 68.40 352.60 5872,00 5128,63 N 1777,49 W 5427.92 112,30 27,62 29.64 340.69 8585.61 67.81 354.21 5878.00 5143.46 N 1779,21 W 5442.50 112,64 27,63 29.73 340.73 8585.66 67.81 354.21 5878,02 5143.50 N 1779.21 W 5442,54 112.64 27.63 29.73 340.73 8718.02 67.81 354.21 5928.00 5265.44 N 1791.57 W 5561.81 115.65 27.79 30.57 341,09 8760.39 67.81 354.21 5944.00 5304.47 N 1795.53 W 5599,99 116,61 27.84 30.84 341.21 8763.04 67,81 354.21 5945.00 5306.91 N 1795.78 W 5602,38 116.67 27.84 30,86 341.21 8792.17 67.81 354,21 5956.00 5333,75 N 1798.49 W 5628,63 117.34 27,87 31.04 341.29 8980.19 67.81 354.21 6027.00 5506.95 N 1816.05 W 5798.06 121.61 28.10 32,24 341.80 8988.14 67.81 354.21 6030.00 5514.27 N 1816.79 W 5805.22 121.79 28.11 32.29 341.82 9000.00 67,81 354.21 6034.48 5525.20 N 1817.90 W 5815.91 122.06 28,12 32.36 341.86 9006.68 67.81 354.21 6037.00 5531.35 N 1818.52 W 5821.92 122,22 28.13 32.41 341.87 9019.92 67.81 354.21 6042,00 5543.55 N 1819.76 W 5833.86 122.53 28.15 32.49 341.91 9100.00 71.68 355.32 6069,72 5618.35 N 1826,60 W 5906.79 124,45 28.27 33.06 342.14 9107.34 72.04 355.42 6072.00 5625.30 N 1827.17 W 5913.54 124,62 28.28 33.11 342.16 9126.48 72.96 355.67 6077.76 5643.50 N 1828.59 W 5931.20 125,08 28,31 33.25 342,22 9311.61 72.96 355.67 6132.00 5820.00 N 1841.95 W 6102.38 129.66 28.61 34.62 342.75 9414.00 72.96 355,67 6162.00 5917.62 N 1849.34 W 6197,04 132,19 28.77 35.38 343.05 9500.00 72.96 355.67 6187.20 5999,61 N 1855.54 W 6276.56 134.38 28.93 36.04 343.29 9584.65 72.96 355,67 6212.00 6080.31 N 1861.65 W 6354.82 136.56 29.08 36.69 343.52 All data is in feet unless otherwise stated. Coordinates from slot #13A and TVD from RKB (Nordic III) (87.00 Ft above mean sea level). Bottom hole distance is 6358.93 on azimuth 342.98 degrees from wellhead. Vertical section is from wellhead on azimuth 340.92 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 3F,13A Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 13A Version #12 Last revised : 29-Ju1-1999 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 6594 ARCO (H.A. Gyro) User specified 75.76 26.72 22.70 6594 9585 ARCO (H.A. Mag) User specified 136.56 29.08 36.69 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a random relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. Comments i n wel 1 path MD TVD Rectangular Coords. Comment 6594.00 5231.07 3390.40 N 6632.00 5259.93 3413.73 N 6645.00 5269.66 3421.84 N 6661.00 5281.23 3432.15 N 6893.21 5398.50 3616.80 N 7113.81 5460.00 3815.49 N 7874.23 5672.00 4500.40 N 8064.33 5725.00 4671.63 N 8329.76 5799.00 4910.71 N 8436.11 5828.65 5006.50 N 8569.52 5872.00 5128.63 N 8585.61 5878.00 5143.46 N 8718.02 5928.00 5265.44 N 8760.39 5944.00 5304.47 N 8763.04 5%5.00 5306.91 N 8792.17 5%6.00 5333.75 N 8980.19 6027.00 5506.95 N 8988.14 6030.00 5514.27 N 9006.68 6037.00 5531.35 N 9019.92 6042.00 5543.55 N 9107.34 6072.00 5625.30 N 9126.48 6077.76 5643.50 N 9311.61 6]32.00 5820.00 N 9414.00 6162.00 5917.62 N 9584.65 6212.00 6080.31 N 1147.78 1155 96 1158 89 1162 84 1233 08 1306 58 1559 94 1623 27 1711 71 1747 14 1777 49 1779 21 1791 57 1795 53 1795 78 1798 49 1816 05 1816 79 1818 52 1819 76 1827.17 1828.59 1841.95 1849.34 1861.65 W Tie-In Survey W Top of Whipstock W KOP / Base Whipstock Face W Mill Bury Depth / Begin Build W EOC W C30 W C20 (HRZ Midpoint) W Base HRZ W K-1 Marker W Begin Drop/Turn to Target W Top D W EOC / 3F-13A Top C4 7/29/99 W Top C3 W Top C2 W Top C1 W Top B Shale W Top A6 W Top A5 W Top A4 W Begin Build/3F-13A Top A3 7/15/99 W Top A2 W EOC W Top A1 W 3F-13A Top Miluveach 7/29/99 W TD / CSG PT Targets associated with this wellpath Target name Geographic Locati on T.V.D. Rectangul ar Coordi nates Revised Begin Build'3F-13A T 506516.000,599!416.000.0.0000 6042.00 5543.55N 1819.76W 21-Jun-1999 3F-13A Top Hiluveach 506486.000,5991790.000,0.0000 6162.00 5917.62N 1849.34W 29-Ju1-1999 ARCO Alaska, Inc. Pad 3F 13A slot #13A Kuparuk River Unit North Slope, Alaska SUHMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 13A Version #12 Our ref : prop3483 License : Date printed : 29-Ju1-1999 Date created : 23-2u1-1999 Last revised : 29-2u1-1999 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on nTO 22 20.956,w149 55 51.299 Slot location is n70 22 21.467,w149 55 55.922 Slot Grid coordinates are N 5985875.078, E 508341.871 Slot local coordinates are 52.00 N 158.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wel 1 path PGMS <0-8390'>,,3,Pad 3A PGMS <0-7630'>,,13,Pad 3A PGMS <O-8024'>,,12,Pad 3A PGMS <0-7350'>,,11,Pad 3A PGMS <0-7000'>,,lO,Pad 3A MMS <O-6400'>,,WS-23,Pad 3A PGMS <O-7120'>,,8,Pad 3A PMSS <0-7275'> PGMS <0-7680'> PGMS <0-8660'> PGMS <0-8690'> PGMS <0-9155'>, PGMS <0-8160'>, PGMS <0-7855'>, PMSS <0 - 8795'> PMSS <0 - 7785'> PGHS <0-8475'> PGMS <0-9600'> ,7,Pad 3A ,6,Pad 3A ,5,Pad 3A ,2,Pad 3A ,16,Pad 3A ,15,Pad 3A 14,Pad 3A ,18,Pad 3A ,17,Pad 3A ,4,Pad 3A ,1,Pad 3A PMSS <644 - 7165'>, ,17,Pad 3F PGMS <0-8730'>,,1,Pad 3F PGMS <0-7455'>, ,15,Pad 3F PGMS <0-6975'>, ,14,Pad 3F PGMS <0-7570'>, ,12,Pad 3F PGMS <0-8600'>,,11,Pad 3F PGMS <0-6650'>, ,10,Pad 3F PGMS <0-8070'>,,7,Pad 3F PGMS <0-7717'>, ,6,Pad 3F Closest approach with 3-D Minimum Distance method Last revised Distance 17-Mar-1998 777.5 2-Jan-1992 6547.2 2-Jan-1992 6657.5 2-Jan-1992 5684.7 2-Jan-1992 6144.2 2-Jan-1992 5309.7 2-Jan-1992 3011.8 2-2an-1992 4597 5 2-2an-1992 3331 8 2-Jan-1992 5981 9 2-2an-1992 1452 3 2-Jan-1992 7249 2 2-Jan-1992 7123 1 2-Jan-1992 7210 9 17-Sep-t996 6637 5 19-Mar-1997 5515 0 30-Apr-1996 3437 0 2-2an-t992 5117 8 5-Mar-1999 1447 0 21-Nov-1991 5547 8 21-Nov-1991 2821 4 21-Nov-1991 2174 3 21-Nov-1991 4213 9 21-Nov-1991 5233 3 21-Nov-1991 4370.4 21-Nov-1991 2287.9 21-Nov-1991 4506.5 M.D. Diverging from M.Di 9540.0 9540.0 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 958416 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 9584.6 6594.0 6594.0 6594.0 6594.0 6594.0 6594.0 6594.0 6594.0 6594.0 6594.0 6594.0 6594.0 6594.0 6594.0 6594.0 6594.0 6594.0 6594.0 PGI,1S <0- 6913 '> ,4, Pat,, PGI.1S <0- 7966 '> , 3, Pad ~31~ PGI.IS <0- 7864'> , 2, Pad 3F PGHS <0-7785'> ,9,Pad 3F PGMS <0-8600'>, 16,Pad 3F PGMS <0-7050'> ,8,Pad 3F PGMS <0-8875'> ,5,Pad 3F PMSS <7121-8580'> ,16A,Pad 3F PMSS <475 - 6868'>, ,18,Pad 3F PMSS <550 - 8132'>, ,19,Pad 3F PGMS <0-8108'>,,13,Pad 3F 21-Nov- 21-Nov- 21-Nov- 21-Nov- 21-Nov- 21-Nov- 5-Mar- 5-Mar- 5-Mar- 5-Mar- 8-Apr- 1991 1991 1991 1991 1991 1991 1999 1999 1999 1999 1999 4135.5 5163.6 5143.1 5016.4 1701.2 3407.3 4209,1 1537.3 5318.6 1142.1 0.0 6594 6594 6594 6594 6594 6594 6594 8220 6594 6594 6594 0 0 0 0 0 0 0 0 0 0 6594.0 6594.0 6594.0 6594.0 6594.0 6594.0 6594.0 8220.0 6594.0 6594.0 6594.0 ARCO Alaska, Inc. ALPINE DISBURSEMENT ACCOUNT P.O. Box 103240 Anchorage, AK 99510-3240 PAY TO THE ORDER OF: 249004453 73-426 839 JUNE 22, 1999 0990337 ALASKA DEPT OF:REVENUE :,:::::-::~:~,,?~ ALASKA OIL, ~ GAS CONSERVATION COMMI :;i: ::':i:, : 3001::PORCUPiNE:DRIVE': : , i! ,~~ voID: AFTER 90 DAYS '::'i::~: i: EXACTLY *******'***:~100 :!DOLLARS AND . oo CENTs "~ ~ ¥~*********** 100.00 The First Nat=¥o~n~l.'B:~,k 0~" Chi'cago-0710 '"'. ~.~ ":~.'? :':' :?~". ~:~.':':'. Chiea~i: ' I II inoi s Payable Through Republic Bank Shelbyville, Kentucky TRACE NUMBER: 249004453 Ira' 2 h ciOO [, h 5 :~lm' m-'DP, ~, CiD t, 2 ?, 2'-' O Ci CiD ~= ~, ?1~m WELL PERMIT CHECKLIST COMPANY ,~/'./. ~ dev ,/~ redrll ~ serv wellbore seg ann. disposal para req · -- WELL NAME, .~_~ ~J'T'"'//~,~'? PROGRAM: exp FIELD & POOL INIT CLASS .,~)¢~./ / ADMINISTRATION ENGINEERING AP,E~R- DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to 3 ®© C) psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOL AREA ,,~ ~'x"'~ UNIT# ,/'//~:~' ON/OFF SHORE Permit can be issued w/o hydrogen sulfide measures ..... Y~NYY N //'~¢' ~ Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones ............. Seabed condition survey (if off-shore) ............. Contact name/phone for weekly progress reports [exploratory onJ~] Y N / GEOLOGY 30. 31. 32. 33. 34. ANNULAR'DISPOSAL APPR DATE 35. With proper cementing records~jh~ plan (A) will contain waste in_..a-sditabl~receiving zone; ....... Y N (B) will not conta~mi an~e fresh~a/ter; or cause drilling waste ._:.~__._-- Y N to suffac ;e¢~ // ~-~ ..... (C) will/~ot'~mpair mecharfical integrity ~_the-weql~sed for disposal; Y N (D)'-~ill not damage produ__d~n~erm-~iti'~)n or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or20 AAC 25.412. Y N GE,.O__L.~: ENGINEERING: UIC/A.~Q___~ , COMMISSION: J Dt-L..--, ...- CO Comments/Instructions: c:\msoffice\wordian\diana\checklist 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. [QQ-07? Memory Multi-Finger Caliper Log Results Summary [I' Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. September 16, 2005 7020 1 3.5" 9.3Ib. L-80 Tubing & Liner Well: Field: State: API No.: Top Log IntvI1.: Bot. Log IntvI1.: 3F-13A Kuparuk Alaska 50-029-21499-01 Surface 9,046 Ft. (MD) Inspection Type: Co"osive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the IIHPNII Nipple @ 815721 (Drillers Depth). This log was run to assess the condition of the 3.5" tubing and liner with respect to corrosive and mechanical damages. The 3.5" tubing appears in good condition with no wall penetrations in excess of 12%. The 3.5" liner logged appears to be in good to poor condition with respect to corrosive damage, with probable holes recorded in joints 214 and 215 (6,932' and 6,962'). The damage recorded in the liner appears in the forms of scattered pitting, lines of corrosion and general corrosion. An area of 17% cross-sectional wall loss is recorded in joint 214 (6,932'). Perforation intervals are recorded between the "D" Nipple and "HPN" Nipple in pup joints 266.2 and 266.3 (8,553' and 8,570'). No areas of I.D. restrictions are recorded throughout the tubing and liner logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS: Probable Multiple Holes Probable Multiple Holes Line of Pits Corrosion Line of Corrosion ( 96%) ( 93%) ( 70%) ( 69%) ( 62%) Jt. Jt. Jt. Jt. Jt. 215 @ 214 @ 216 @ 267 @ 201.2 @ 6,962 Ft. (MD) 6,932 Ft. (MD) 6,971 Ft. (MD) 8,604 Ft. (MD) 6,441 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Probable Multiple Holes in Corrosion (17%) Jt. 214 @ 6,932 Ft. (MD) No other significant areas of cross-sectional wall loss (> 13%) are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing and liner logged. , .' ,. "", c'·- C') C'I ') (1 01: SCJ'\N~\!E.LI ;) E P /. c:'Ì f.. ,,;j I Field Engineer: W McCrossan Analyst: M. Tahtouh Witness: Nina Woods ProActive Diagnostic Services, Ine. I P.O. Box 1369, Stafford, TX 77497 Phone: (281) o~-<I(8ß8) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Pi"Udhoe Bay Field Office Ptlone: (907) 659-2307 Fax: (907) 659-2314 I . • • I PDS Report Overview �►. Body Region ion Analysis I Well: 3F -13A Kuparuk Survey Date: September 16, 2005 Field: Tool Type: MFC 24 No. 00387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Analyst: M. Tahtouh Tubing: Nom.OD Weight Grade &Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 ppf L-80 2.992 ins 3.5 ins 1.2 ins 1.2 ins 1 Penetration and Metal Loss (% wall) Damage Profile (% wall) 1 NE penetration body mji metal loss body m. penetration body im metal loss body 0 50 100 250 0 I 200 150 100 1 50 -' . l_ __ _ 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% 1 Number of joints analysed (total = 306) GLM 1 96 pene. 23 199 19 45 16 4 loss 92 210 4 0 0 0 1 Damage Configuration ( body) GLM 2 I :: GLM 3 186 20 — 0 isolated general line ring hole / poss U pitting corrosion corrosion corrosion ible hole 277 . Number of joints damaged (total = 83) _- I 56 9 14 0 4 Bottom of Survey = 282 i I Analysis Overview page 2 1 ' • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 3F -13A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: September 16, 2005 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 .1 -2 0 0.01 2 2 2.96 PUP i I 1 2 0 0.01 2 1 2.97 1.1 35 0 0.01 2 2 2.97 PUP 1.2 37 0 0.01 2 2 2.98 PUP 1.3 39 0 0.01 2 2 2.97 PUP I 1.4 49 0 0.01 2 1 2.87 PUP Lt. Deposits. 2 59 0 0.01 2 1 2.91 3 92 0 0.01 2 1 2.96 4 124 0 0.01 2 2 2.96 I 5 156 0 0.01 2 1 2.83 6 186 0 0.01 2 1 2.96 7 218 0 0.01 3 1 2.96 8 249 0 0.01 2 1 2.96 I 9 280 0 0.00 1 2 2.97 10 311 0 0.00 2 2 2.97 11 342 0 0.01 2 2 2.97 12 374 0 0.01 2 2 2.97 13 405 0 0.01 2 2 2.97 U 14 15 436 0 0.01 3 2 2.97 467 0 0.01 2 1 2.97 15.1 498 0 0.00 1 0 2.98 D Nipple 16 512 0 0.00 2 2 2.96 I 17 543 0 0.01 2 2 2.98 18 574 0 0.01 2 2 2.97 19 606 0 0.01 2 2 2.96 20 638 0 0.01 2 3 2.97 I 21 670 0 0.01 2 1 2.97 22 702 0 0.01 2 1 2.97 23 733 0 0.01 3 1 2.97 24 765 0 0.01 2 1 2.97 25 795 0 0.00 1 2 2.96 I 26 827 0 0.00 2 2 2.97 27 859 0 0.01 2 1 2.97 28 891 0 0.01 2 1 2.97 29 920 0 0.01 2 1 2.97 I 30 952 0 0.01 3 1 2.98 31 984 0 0.01 2 1 2.96 32 1016 0 0.00 1 1 2.98 33 1048 0 0.00 2 1 2.97 I 34 1078 0 0.01 2 1 2.96 35 1110 0 0.01 2 1 2.97 i 36 1141 0 0.01 2 1 2.97 37 1173 0 0.00 1 1 2.97 I 38 1204 0 0.00 2 1 2.97 39 1236 0 0.01 2 2 2.97 40 1266 0 0.01 2 2 2.96 41 1297 0 0.01 2 1 2.97 i I 42 1328 0 0.01 3 1 2.97 43 1359 0 0.01 2 1 2.98 44 1390 0 0.00 1 1 2.97 'Penetration Body I Metal Loss Body Page 1 1 I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 3F -13A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: September 16, 2005 I Joint Jt Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (` wall) (Ins.) (Ins.) % (Ins.) 0 50 100 45 1422 0 0.00 2 1 2.97 1 I 46 1453 47 1485 0 0.01 2 1 2.98 O 0.01 2 1 2.96 48 1516 0 0.00 2 1 2.98 49 1547 0 0.01 2 1 2.97 I 50 1575 51 0 0.01 2 1 2.96 1606 0 0.01 2 1 2.97 52 1637 0 0.00 1 2 2.97 53 1668 0 0.00 2 2 2.97 I 54 1700 0 0.01 2 1 2.97 55 1730 0 0.01 2 2 2.97 56 1762 0 0.01 2 1 2.96 57 1792 0 0.01 3 1 2.97 58 1824 0 0.01 2 1 2.97 111 59 1855 0 0.00 1 2 2.96 60 1887 0 0.00 2 2 2.97 61 1919 0 0.01 2 2 2.97 62 1950 0 0.01 2 2 2.98 I 63 1982 64 2013 0 0.01 2 2 2.96 O 0.01 2 1 2.98 65 2045 0 0.01 2 2 2.97 66 2076 0 0.01 3 2 2.96 67 2108 0 0.01 2 _ 2 2.97 68 2139 0 0.00 1 2 2.97 69 2170 0 0.00 2 2 2.97 70 2202 0 0.01 2 2 2.97 71 2233 0 0.01 2 2 2.97 72 2265 0 0.01 2 2 2.96 73 2296 0 0.01 2 2 2.97 74 2327 0 0.01 2 1 2.97 75 2359 0 0.01 2 2 2.96 I 76 2390 0 0.01 3 2 2.97 77 2422 0 0.01 2 2 2.98 78 2454 0 0.00 1 1 2.92 79 2485 0 0.00 2 1 2.98 I $0 2517 81 2548 0 0.01 2 2 2.97 O 0.01 2 2 2.96 82 2579 0 0.01 2 1 2.97 83 2611 0 0.01 2 2 2.96 I 84 2643 0 0.01 2 2 2.97 85 2674 0 0.01 2 2 2.96 86 2706 0 0.01 2 2 2.96 87 2737 0 0.01 2 2 2.96 I 88 2769 0 0.01 2 2 2.96 89 2800 0 0.01 2 2 2.97 90 2831 0 0.01 3 1 2.96 91 2862 0 0.01 2 2 2.96 I 92 2894 0 0.00 1 2 2.98 93 2925 0 0.00 2 2 2.97 94 2956 0 0.01 2 1 2.96 Penetration Body I Metal Loss Body Page 2 I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 3F -13A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: September 16, 2005 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 95 2988 0 0.00 2 1 2.97 I 96 3019 0 0.01 2 2 2.96 97 3050 0 0.01 2 2 2.97 98 3082 0 0.01 2 1 2.97 99 3113 0 0.01 3 2 2.97 I 100 3145 0 0.01 2 1 2.96 100.1 3176 0 0.00 1 3 2.96 PUP II 100.2 3186 0 0.00 2 0 N/A GLM 1 (Latch C 8:00) 100.3 3193 0 0.01 2 2 2.94 PUP I 101 3202 0 0.00 2 2 2.96 102 3234 0 0.01 2 2 2.96 103 3265 0 0.01 2 2 2.97 104 3297 0 0.01 2 2 2.97 I 105 3328 0 0.01 3 2 2.97 106 3360 0 0.01 2 2 2.96 107 3391 0 0.00 1 2 2.97 108 3423 0 0.00 2 2 2.96 109 3455 0 0.01 2 2 2.97 I 110 3486 0 0.00 2 2 2.96 111 3518 0 0.01 3 2 2.97 112 3549 0 0.01 2 3 2.96 I 113 3581 0 0.01 3 2 2.96 I 114 3612 115 3643 0 0.01 2 2 2.94 0 0.00 1 2 2.92 116 3674 0 0.00 2 2 2.98 117 3706 0 0.01 2 2 2.93 I 118 3737 0 0.00 2 2 2.95 119 3769 0 0.01 3 1 2.97 120 3800 0 0.01 2 1 2.97 121 3831 0 0.01 3 2 2.98 I 122 3862 0 0.01 2 1 2.96 123 3893 0 0.00 1 1 2.97 124 3925 0 0.00 2 2 2.97 125 3957 0 0.01 2 1 2.97 126 3988 0 0.00 2 1 2.97 U 127 4020 0 0.01 3 1 2.97 128 4051 0 0.01 2 2 2.97 129 4083 0 0.01 3 1 2.98 130 4115 0 0.01 2 2 2.96 I 131 4146 0 0.00 1 1 2.97 132 4178 0 0.00 2 1 2.98 133 4209 0 0.01 2 2 2.96 134 4241 0 0.00 2 2 2.96 I 135 4272 0 0.01 3 2 2.95 136 4304 0 0.01 2 1 2.98 137 4335 0 0.01 3 1 2.97 138 4367 0 0.01 2 1 3.00 I 139 4398 140 4429 0 0.00 1 2 2.97 0 0.00 2 2 2.97 141 4460 0 0.01 2 2 2.98 Penetration Body I Metal Loss Body Page 3 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 3F -13A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: September 16, 2005 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (°/0 wall) (Ins.) (Ins.) % (Ins.) 0 50 100 142 4492 0 0.00 2 1 2.99 I 143 4524 0 0.01 3 2 2.98 144 4555 0 0.00 2 1 2.95 145 4587 0 0.01 2 1 2.98 146 4618 0 0.00 2 2 2.97 I I 147 4649 0 0.01 3 2 2.97 148 4680 0 0.01 2 2 2.97 149 4711 0 0.01 3 1 2.98 150 4742 0 0.01 2 1 2.95 I 151 4774 0 0.00 1 2 2.96 152 4806 0 0.00 2 1 2.98 153 4837 0 0.01 2 1 2.96 154 4868 0 0.00 2 2 2.97 155 4899 0 0.01 3 2 2.98 I 155.1 4931 0 0.01 3 2 2.93 PUP 155.2 4941 0 0 0 0 N/A GLM 2 (Latch GP 8:00) 155.3 4949 0 0.01 2 2 2.98 PUP 156 4956 0 0.01 2 2 2.95 I 157 4988 0 0.00 1 1 2.96 158 5019 0 0.00 2 1 2.98 159 5050 0 0.01 2 2 2.97 160 5082 0 0.00 2 2 2.98 I 161 5113 162 5145 0 0.01 3 2 2.96 0 0.00 2 1 2.97 163 5177 0 0.01 2 2 2.96 164 5208 0 0.00 2 2 2.97 I 165 5238 0 0.01 3 1 2.94 166 5270 0 0.01 2 1 1.36 167 5301 0 0.01 3 2 2.96 168 5332 0 0.01 2 2 2.96 I 169 5364 0 0.00 1 2 2.96 170 5395 0 0.00 2 2 2.96 171 5427 0 0.01 2 1 2.98 172 5458 0 0.00 2 1 2.96 173 5490 0 0.01 3 2 2.98 1 174 5521 175 5552 0 0.01 2 2 2.98 0 0.01 3 2 2.96 175.1 5584 0 0.01 3 1 2.90 PUP 175.2 5594 0 0 0 0 N/A GLM 3 (Latch @ 10:00) I 175.3 5600 0 0.01 3 1 2.97 PUP 176 5609 0 0.01 3 1 2.93 176.1 5641 0 0.01 2 2 2.94 PUP 176.2 5647 0 0.01 3 2 2.97 PUP I 176.3 5659 0 0 0 0 N/A PACKER 176.4 5668 0 0.00 1 2 2.96 PUP 177 5669 0 0.00 2 1 2.97 178 5701 0 0.01 2 1 2.98 I 179 5732 0 0.00 2 1 2.97 180 5763 0 0.01 3 2 2.97 181 5794 0 0.01 2 2 2.97 I Petation I M r Loss Bo dy Page 4 1 1 I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 3F -13A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: September 16, 2005 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 182 5826 0 0.01 3 1 2.98 1 I 183 5858 0 0.01 3 2 2.96 184 5889 0 0.01 2 2 2.97 185 5921 0 0.00 2 2 2.98 186 5952 0 0.01 3 2 2.96 I I 187 5983 188 6015 0 0.01 2 1 2.90 O 0.01 3 2 2.97 189 6047 0 0.01 2 2 2.97 190 6078 0 0.00 1 1 2.98 I 191 6110 0 0.00 2 1 2.96 192 6141 0 0.01 2 2 2.97 193 6173 0 0.00 2 2 2.96 194 6205 0 0.01 3 2 2.98 I I 1 195 6236 0 0.00 1 2 2.98 196 6268 0 0.00 2 1 2.98 197 6299 0 0.01 2 1 2.97 i 198 6331 0 0.00 2 2 2.96 198.1 6362 0 0.01 3 2 2.95 PUP I I 198.2 6368 0 198.3 6372 0 0 0 2.81 Sliding Sleeve 0 0.03 12 3 2.93 PUP r 199 6378 0 0.00 2 1 2.98 200 6410 0 0.01 2 2 2.97 1 I 200.1 6441 200.2 6443 0 0.02 8 2 2.94 PUP • O 0.01 5 2 2.93 PUP • 200.3 6450 0 0 0 0 2.81 X Nipple 200.4 6451 0 0.01 5 2 2.93 PUP r I 200.5 6457 0 0.01 4 3 2.94 PUP f 201 6463 0 0.01 2 1 2.97 201.1 6511 0 0 0 0 3.50 Liner Hanger 201.2 6527 0 0.16 62 4 2.91 PUP Line corrosion. Lt. Deposits. MN= 202 6534 0.20 0.13 50 5 2.93 Line corrosion. 203 6565 0.06 0.10 39 4 2.93 Line corrosion. C 204 6597 0 0.12 46 3 2.94 Line corrosion. 205 6628 0 0.13 52 5 2.91 Line corrosion. 206 6660 0 0.12 46 3 2.94 Line corrosion. MIMI I 207 6690 0 0.09 34 3 2.94 Line corrosion. MIMI 208 6720 0 0.09 36 3 2.95 Line corrosion. NMI 209 6751 0 0.06 22 3 2.93 Line corrosion. NM 210 6782 0 0.06 24 2 2.93 Line corrosion. MI I 211 6814 0 0.06 24 2 2.92 Line corrosion. NMI 212 6845 0 0.05 19 2 2.94 Line of shallow pits. IN 213 6877 0 0.06 23 2 2.94 Line corrosion. Pr- 214 6907 0 0.24 93 17 2.94 Probable Multiple HOLES ! ''+1111111111111• I 215 6939 0 0.24 96 13 2.94 Probable Multiple HOLES ! �� 216 6970 0.13 0.18 70 7 2.94 Isolated pitting. 217 7002 0 0.09 37 3 2.92 Isolated pitting. 218 7033 0 0.08 30 3 2.91 Isolated pitting. Lt. Deposits. I 219 7065 220 7095 0 0.05 20 3 2.91 Line corrosion. O 0.06 24 2 2.92 Isolated pitting. 221 7127 0 0.09 37 4 2.92 Isolated pitting. 111111111 1 t0 n1 Metal Los Bo dy I Page 5 1 • PDSREPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 3F -13A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: September 16, 2005 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 222 7158 0 0.11 41 3 2.92 Isolated pitting. Lt. Deposits. ■w I 223 7190 0 0.15 57 4 2.92 Isolated pitting. ■ 224 7221 0 0.04 17 3 3.00 Shallow pitting. Deposits. ■: 225 7251 0 0.09 34 5 2.92 Isolated pitting. ■w 226 7281 0 0.09 34 4 2.92 Isolated pitting. ■w , I 227 7313 0 0.12 45 2 2.96 Isolated pitting. ■w 228 7344 0 0.10 40 3 2.92 Isolated pitting. ••• 229 7375 0 0.07 26 3 2.99 Isolated pitting. 230 7406 0 0.04 16 3 2.91 Shallow pitting. ■ ■� I 231 7437 0 0.05 19 3 2.91 Shallow pitting. 232 7468 0 0.03 11 2 2.92 ■ w� 233 7500 0 0.09 34 3 2.92 Isolated pitting. ■w 234 7531 0 0.07 26 2 2.93 Isolated pitting. ww I 235 7561 0 0.06 25 5 2.93 Isolated pitting. • 236 7593 0 0.04 15 2 2.93 Shallow pitting. ■3 237 7624 0 0.07 28 4 2.93 Isolated pitting. '' 238 7655 0 0.01 4 12 2.90 Isolated pitting. 239 7686 0.07 0.09 35 3 2.91 Isolated pitting. ■w II 240 7717 0 0.07 27 3 2.91 Isolated pitting. ■w 241 7747 0 0.10 37 4 2.92 Isolated pitting. Lt. Deposits. ■w 242 7776 0 0.08 31 3 2.97 Isolated pitting. ■ 243 7806 0 0.05 19 5 2.90 Shallow pitting. Lt. Deposits. ■: I 244 7838 0 0.06 24 4 2.92 Isolated pitting. ■w 245 7868 0 0.08 33 4 2.92 Isolated pitting. ■w 246 7899 0 0.10 39 3 2.92 Isolated pitting. ■w 247 7930 0 0.09 33 3 2.90 Isolated pitting.. ■w P 248 7961 0 0.09 35 3 2.90 Isolated pitting. ■w 249 7993 0 0.05 20 2 2.90 Isolated pitting. ■w 250 8022 0 0.09 36 3 2.91 Isolated pitting. ■ 251 8054 0 0.04 17 2 2.91 Shallow pitting. P 252 8084 0 0.07 28 4 2.89 Isolated pitting. ■ 253 8115 0 0.04 17 2 2.95 Shallow pitting. ■� 254 8147 0 0.06 25 2 2.96 Isolated pitting. ■w 255 8177 0 0.06 25 2 2.91 Isolated pitting. ■w 256 8209 0 0.07 26 3 2.91 Isolated pitting. • II 257 8240 0 0.03 13 3 2.93 Shallow pitting. ■ll 258 8272 0 0.06 24 6 2.93 Isolated pitting. 259 8302 0 0.04 15 2 2.94 Shallow pitting. ■ 260 8333 0 0.04 17 3 2.92 Shallow pitting. ■ I 261 8364 0 0.04 17 2 2.92 Shallow pitting. 262 8396 0 0.05 19 2 2.90 Shallow pitting. ■ 263 8427 0 0.07 28 3 2.89 Isolated pitting. ■w 264 8459 0.06 0.05 20 4 2.90 Shallow pitting. ■w I 265 8489 0 0.08 32 2 2.91 Isolated pitting. ■w 266 8520 0 0.13 53 4 2.91 Isolated pitting. III 8551 0 0 0 0 2.75 D Nipple 266.2 8552 0 0.27 100 5 2.88 PUP Perforation Interval. NB I 266.3 8562 0.08 0.57 100 13 2.89 PUP Perforation Interval, 266.4 8572 0 0 0 0 2.75 HPN Nipple 267 8574 0.05 0.18 69 4 2.91 Corrosion. Lt. Deposits. Penetration Bo I Metal Loss Body dy Page 6 1 I 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 3F -13A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: September 16, 2005 U Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (°/0 wall) (Ins.) (Ins.) % (Ins.) 0 50 100 268 8604 0 0.07 29 4 2.91 Corrosion. imil I 269 8635 0 0.06 22 4 2.90 Corrosion. �� 270 8666 0.06 0.09 34 4 2.89 Isolated pitting. mum 271 8697 0 0.08 33 4 2.91 Isolated pitting. soli 272 8726 0 0.07 27 4 2.87 Isolated pitting. Lt. Deposits. Noi ' I 273 8758 0 0.05 20 3 2.85 Shallow pitting. Lt. Deposits. uni 274 8789 0 0.12 46 4 2.88 Isolated pitting. Lt. Deposits. mu 275 8821 0 0.07 26 5 2.91 Isolated pitting. .. d 276 8852 0 0.08 30 4 2.91 Isolated pitting. Lt. Deposits. Now I 277 8881 0 0.09 33 4 2.90 Corrosion. 278 8913 0 0.06 24 4 2.89 Corrosion. �� sold 279 8943 0 0.12 49 6 2.88 Corrosion. Lt. Deposits. ■ m 280 8974 0 0.12 47 9 2.90 Corrosion. mus 281 9005 0 0.14 54 8 2.90 Corrosion. Lt. Deposits. two I 282 9036 0 0.13 53 9 2.83 Corrosion. Lt. Deposits. Penetration Body Metal Loss Body 1 1 1 1 1 1 1 1 Page 7 1 1 ow am am me EN No EN um um EN a N. E No No am PDS Report Cross Sections Well: 3F -13A Survey Date: September 16, 2005 Field: Kuparuk Tool Type: MFC 24 No. 00387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 Analyst: M. Tahtouh Cross Section for Joint 214 at depth 6932.117 ft Tool speed = 53 • Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 83 % Tool deviation = 82 ° 1 • Finger 13 Penetration = 0.236 ins Probable Hole in Corrosion 0.24 ins = 93% Wall Penetration 17% Cross - Sectional Wall Loss HIGH SIDE = UP Cross Sections page 1 ow um am sue No N No um me um mos am no EN um No 11. we ow 1: 4 4 -S - PDS Report Cross Sections Well: 3F -13A Survey Date: September 16, 2005 Field: Kuparuk Tool Type: MFC 24 No. 00387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 Analyst: M. Tahtouh Cross Section for Joint 215 at depth 6961.693 ft Tool speed = 53 • Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 89 % Tool deviation = 89 ° i • Finger 13 Penetration = 0.244 ins Probable Hole in Corrosion 0.24 ins = 96 %Wall Penetration HIGH SIDE = UP Cross Sections page 2 0 " KRU 3F -13A 111111 ConocoPhillips Alaska, Inc. • 3F -13A — API: 500292149901 Well Type: PROD Angle TS: 69 deg (ca 8523 TUBING SSSV Type: NIPPLE Orig Well 9/6/1999 Angle (a1) TD: 64 deg (0) 9350 (0 -6525, Annular Fluid: Last W /O: 6/22/2005 Rev Reason: TAG, GLV design, OD:3.500, puff Ball/ Rod & I ID:2.992) Eclipse PKR Reference Log: 35' RKB Ref Log Date: Last Update: 7/28/2005 Last Tag: 6705 SLM TD: 9350 ftKB Last Tag Date: 7/16/2005 Max Hole Angle: 79 deg (0) 7159 Casing String - ALL Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 112 112 62.58 H-40 WELDED SURF CASING 9.625 0 3652 3065 36.00 L -80 BTC -MOD PROD CASING 7.000 0 8050 5736 26.00 L -80 BTC -MOD TIE BACK LINER 5.500 0 6485 5149 15.50 L -80 HYD -511 LINER 3.500 6485 9350 9350 9.30 L -80 EUE 8rd CSG WINDOW 6.151 6635 6636 5264 0.00 Tubing String - TUBING Size Top Bottom TVD Wt Grade Thread 3.500 0 6525 5179 9.30 L -80 EUE 8rd I Perforations Summary Interval TVD Zone Status Ft SPF Date Type Comment 8553 -8570 5874 -5881 C-4 17 4 4/22/2000 APERF 2.5" HC -DP, 180 deg ph, +/- 90 deg orient 9 070 - 9100 6084 -6096 A -2 30 4 9/20/1999 IPERF 2.5" HC; 180 deg ph I ,� Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date VIv ANCHOR Run Cmnt (5672-5673, 1 3201 2757 CAMCO KBG2 -9 GLV 1.0 BTM 0.156 1289 6/26/2005 OD:3.500) all 2 4952 3996 CAMCO KBG2 -9 GLV 1.0 BTM 0.188 1324 6/262005 I 3 5603 4475 CAMCO KBG2 -9 OV 1.0 BTM 0.250 0 6/26/2005 Other (plugs, equip., etc.) - JEWELRY (WORKOVER 6/22/2005) Depth TVD Type Description ID 24 24 HANGER TUBING HANGER 2910 524 524 NIP CAMCO '1) LANDING NIPPLE 2.875 t 5656 4514 LOCATOR BAKER BOT LOCATOR SUB 3.000 5659 4517 SBE BAKER SEAL BORE EXTENSION 3.000 5672 4526 ANCHOR BAKER ANCHOR 3.000 5673 4527 PACKER BAKER SAB-3 PACKER (MILLED OUT TO 281" ID 7/10/05) 2810 6376 5065 SLEEVE BAKER CMD SUDING SLEEVE / BX PROFILE 2813 I 6457 5127 NIP HES 'X' PROFILE NIPPLE 2.812 6471 5138 SEAL BAKER 80-40 SEAL ASSEMBLY 2.990 Other (plugs, equip., etc.) - EXISITING 3.5" LINER JEWELRY Depth TVD Type Description ID 6503 5163 HANGER BAKER HMC HYDRAULIC LINER HANGER 3.500 I 8551 5874 NIP 3.5" LINER: CAMCO D NIPPLE 2.750 8572 5881 NIP 3.5" LINER: HES HPN POLISHED NIPPLE. 2750 9350 9350 SHOE BAKER FLOAT SHOE 3.500 General Notes Date Note I 7/16/2005 2 SLIPS FROM ECLIPSE PACKER LOST DOWNHOLE I NIP y (855182, 55 II OD: -8 LINER — -- I (6485-9350, 00.3. OD:3.500, Wt9.30) Pert (8553-8570) i NIP - II (8572 -8573, OD:4.500) i. Pert I (9070-9100) I_ Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Dec 03 14:09:58 1999 Reel Header Service name ............. LISTPE Date ..................... 99/12/03 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/12/03 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 2 AK-MM-90147 RANDY KRELL DEARL GLADDE 3F-13A 500292149901 Arco Alaska, Inc. Sperry Sun 03-DEC-99 MWD RUN 3 AK-MM-90147 RANDY KRELL DEARL GLADDE 12N 9E 52 158 86.60 86.60 30.30 , 0 9 1999 Oil & Gas Cons, Comm ion 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 9.630 6665.0 6.125 7.000 8186.0 6.125 9350.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD)UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT pRESENTED. 3. MWD RUNS 2-3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS,AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. DIGITAL DATA ONLY IS CORRECTED TO THE PDC GR LOG (FDN OF 12/20/85) WITH KBE = 93' AMSL. MWD DATA IS CONSIDERED PDC FOR 3F-13A. 5. MWD RUNS 1-3 REPRESENT WELL 3F-13A WITH API%: 50-029-21499-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9350'MD, 6203'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 6621.0 9304.0 RPD 6628.0 9311.0 RPM 6628.0 9311.0 RPS 6628.0 9311.0 RPX 6628.0 9311.0 FET 6660.0 9311.0 ROP 6663.5 9348~5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA {MEASURED DEPTH) BASELINE DEPTH 6621 0 6622 5 6624 0 6625 0 6626 5 6628 0 6629 5 6631 0 6633 5 9348 5 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: GR 6621 0 6622 5 6624 0 6625 5 6627 5 6628 5 6630 0 6633 0 6635 0 9350 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 200 6621.0 8185.0 300 8185.0 9350.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 6621 9348.5 7984.75 5456 ROP MWD FT/H 4.04 463.95 92.9192 5371 First Reading 6621 6663.5 Last Reading 9348.5 9348.5 GR MWD API 40.73 562.83 RPX MWD OHMM 0.74 771.41 RPS MWD OHMM 0.84 2000 RPM MWD OHMM 1.5 2000 RPD MWD OHMM 1.57 2000 FET MWD HOUR 0.2234 27.9837 141.61 5367 6.69024 5367 9.1474 5367 14.2246 5367 15.0045 5367 1.2541 5303 6621 6628 6628 6628 6628 6660 9304 9311 9311 9311 9311 9311 First Reading For Entire File .......... 6621 Last Reading For Entire File ........... 9348.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH SGRC SEXP SEDP SESP SEMP SFXE SROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 6621 0 6628 5 6628 5 6628 5 6628 5 6661 5 6665 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): STOP DEPTH 8142.0 8149 0 8149 0 8149 0 8149 0 8149 0 8185 0 30-AUG-99 Insite 0 Memory 8186.0 BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 40.7 78.8 TOOL NUMBER P1350GRV4 P1350GRV4 6.125 Water Based 11.10 39.0 9.4 900 2.4 1.65O .861 1.550 3.400 74.0 148.0 74.0 74.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD 2 FT/H GR MWD 2 API RPX MWD 2 OHMM R?S MWD 2 OHMM RPM MWD 2 OHMM RPD MWD 2 OHMM FET MWD 2 HOUR Min Max 6621 8185 4.04 463.95 63.95 562.83 0.79 771.41 1.34 2000 2.03 2000 1.57 2000 0.2234 9.5586 Mean Nsam 7403 3129 92.6746 3041 172.661 3043 5.42262 3042 8.75639 3042 18.0118 3042 20.5265 3042 0.936764 2976 First Reading 6621 6665 6621 6628.5 6628.5 6628.5 6628.5 6661.5 Last Reading 8185 8185 8142 8149 8149 8149 8149 8149 First Reading For Entire File .......... 6621 Last Reading For Entire File ........... 8185 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH SGRC SEDP SEMP SESP SEXP SFXE SROP $ 8142 5 8149 0 8149 0 8149 0 8149 0 8149 0 8188.0 LOG HEADER DATA STOP DEPTH 9305 5 9312 5 9312 5 9312 5 9312 5 9312 5 9350 0 DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 01-SEP-99 Insite 0 Memory 9350.0 64.1 75.1 TOOL NUMBER P1350GRV4 P1350GRV4 6.125 Water Based 11.20 38.0 8.9 750 3.0 1. 650 .762 1.350 3.400 67.0 153.0 67.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 GR MWD 3 RPX MWD 3 RPS MWD 3 RPM MWD 3 RPD MWD 3 FET MWD 3 FT/H API OHMM OHMM OHMM OHMM HOgR 1 68 1 68 1 68 1 68 1 68 1 68 1 68 4 8 12 16 20 24 28 Name Service Unit DEPT FT ROP MWD 3 FT/H GR MWD 3 API RPX MWD 3 OHMM RPS MWD 3 OHMM RPM MWD 3 OHMM RPD MWD 3 OHMM FET MWD 3 HOUR Min 8142.5 5.23 40.73 0.74 0.84 1.5 1.91 0.2628 Max 9350 205 29 186 41 61 85 767 93 1159 75 47 75 27. 9837 Mean Nsam 8746.25 2416 93.2639 2325 100.923 2327 8.64068 2328 9.50429 2328 10.3975 2328 9.89367 2328 1.67093 2328 First Reading 8142.5 8188 8142.5 8149 8149 8149 8149 8149 Last Reading 9350 9350 9305.5 9312.5 9312.5 9312.5 9312.5 9312.5 First Reading For Entire File .......... 8142.5 Last Reading For Entire File ........... 9350 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/12/03 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 99/12/03 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
