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197-237
Originated: Delivered to:18-Jun-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 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 NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1B-20 50-029-23164-00 910026681 Kuparuk River Packer Setting Record Field- Final 7-May-25 0 12 1D-117 50-029-22844-00 910027101 Kuparuk River Plug Setting Record Field- Final 8-May-25 0 13 1D-133 50-029-22827-00 910010225 Kuparuk River Multi Finger Caliper Field & Processed 25-May-25 0 14 1G-02 50-029-20813-00 910036496 Kuparuk River Multi Finger Caliper Field & Processed 21-May-25 0 15 1H-08 50-029-20763-00 910080713 Kuparuk River Multi Finger Caliper Field & Processed 22-May-25 0 16 1H-08 50-029-20763-00 910080713 Kuparuk River Plug Setting Record Field- Final 22-May-25 0 17 1Q-04 50-029-21250-00 910027200 Kuparuk River Tubing Cut Record Field- Final 14-May-25 0 18 1Q-04 50-029-21250-00 910027200 Kuparuk River Tubing Cut Record Field- Final 15-May-25 0 19 1Q-22 50-029-22595-00 910027102 Kuparuk River Plug Setting Record Field- Final 16-May-25 0 110 2B-02A 50-029-21154-01 910106459 Kuparuk River Leak Detect Log Field- Final 14-Jun-25 0 1PLEASE 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:203-115197-237197-206182-138182-093184-234195-140216-087T40582T40583T40584T40585T40586T40586T40587T40587T40588T405896/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.20 08:37:34 -08'00'1D-11750-029-22844-00 910027101Kuparuk RiverPlugSetting RecordField- Final8-May-2501197-237 197-237 T38923 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.13 08:25:27 -08'00' Originated: Delivered to:2ͲMayͲ24Halliburton Alaska Oil and Gas Conservation Comm.Wireline & PerforatingAttn.:Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska99501Anchorage, Alaska 99518Office: 907Ͳ275Ͳ2605FRS_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 NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#11DͲ117 50Ͳ029Ͳ22844Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 21ͲAprͲ24 0 121EͲ05A 50Ͳ029Ͳ20479Ͳ01 n/a Kuparuk River Plug Setting Record FieldͲFinal 2ͲAprͲ24 0 131HͲ102 50Ͳ029Ͳ23580Ͳ00 909266407 Kuparuk River Multi Finger Caliper Field & Processed 22ͲAprͲ24 0 142BͲ03B 50Ͳ029Ͳ21151Ͳ02 909270379 Kuparuk River Perforation Record FieldͲFinal 11ͲAprͲ24 0 152CͲ12 50Ͳ029Ͳ21222Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 29ͲAprͲ24 0 162DͲ13 50Ͳ029Ͳ21070Ͳ00 909258948 Kuparuk River Leak Detect Log FieldͲFinal 11ͲAprͲ24 0 172DͲ13 50Ͳ029Ͳ21070Ͳ00 909258948 Kuparuk River Multi Finger Caliper Field & Processed 9ͲAprͲ24 0 183GͲ24 50Ͳ103Ͳ20145Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 8ͲAprͲ24 0 193JͲ14 50Ͳ029Ͳ21496Ͳ00 909238639 Kuparuk River Leak Detect Log FieldͲFinal 7ͲAprͲ24 0 110 3JͲ14 50Ͳ029Ͳ21496Ͳ00 909238639 Kuparuk River Multi Finger Caliper Field & Processed 6ͲAprͲ24 0 1PLEASE 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:T38757T38758T38759T38760T38761T38762T38762T38763T38764T38764111DͲ11750Ͳ029Ͳ22844Ͳ00 n/aKuparukRiverPlugSettingRecordFieldͲFinal21ͲAprͲ240 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 1D-07 50-029-20430-00 179112_1D-07_SCMT_14Oct23 1D-11 50-029-22946-00 199072_1D-11_IPROF_04Apr2022 1D-117 50-029-22844-00 197237_1D-117_RBP_10Jun2022 1D-135 50-029-22816-00 197184_1D-135_LDL_05Jun2022 1D-30 50-029-22965-00 2000104_1D-30_Plug_11May2023 1D-34 50-029-22975-00 200143_1D-34_CHC_02Aug2022 1D-36 50-029-22973-00 200130_1D-36_RBP_19Jul2023 _1E-02 50-029-20472-00 180050_1E-02_CHC_29Mar2023 180050_1E-02_RBP_24Mar2023 _1E-102 50-029-23236-00 204231_1E-102_Pres-Temp_29Jul2023 _1E-12L1 50-029-20736-60 210004_1E-12_JetCutter_12Jun2022 210004_1E-12_MechCutter_06Jun2022 210004_1E-12_SBHPS-RBP-LDL_03Jun2022 2of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38317 T38318 T38321 T38322 T38323 T38324 T38325 T38326 T38327 T38328 2/29/2024 1D-117 50-029-22844-00 197237_1D-117_RBP_10Jun2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:18:42 -09'00' Originated: Delivered to:22-Oct-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 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 NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1A-25 50-029-22116-00 907415285 Kuparuk River Multi Finger Caliper Field & Processed 28-Sep-21 0 12 1D-117 50-029-22844-00 n/a Kuparuk River Packer Setting Record Field- Final 21-Oct-21 0 13 2F-14 50-029-21035-00 907412448 Kuparuk River Plug Setting Record Field- Final 25-Sep-21 0 14 2V-09 50-029-21300-00 907375358 Kuparuk RiverLeak Detect Log Field- Final 4-Oct-21 0 15 2V-09 50-029-21300-00 907429731 Kuparuk River Multi Finger Caliper Field & Processed 5-Oct-21 0 16 2V-13 50-029-21293-00 907399709 Kuparuk River Leak Detect Log Field- Final 21-Sep-21 0 178910PLEASE 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:10/25/2021Wd͗ϭϵϳϮϯϳϬ Ͳ^Ğƚ͗ϯϱϴϲϱBy Abby Bell at 11:08 am, Oct 22, 2021 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Tubing patch 2.Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 5205 None Casing Collapse Conductor Surface Production Liner Packers and SSSV Type:PKR:Packers and SSSV MD (ft) and TVD (ft):PKR: SSSV:SSSV: 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:9/23/2021 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Well Integrity Specialist Jan Byrne n1617@conocophillips.com 467 121 121 4880 81 16 7.6255150 Length TVD Burst 4414 MD 4393 4083 5190 4408 4866 PRESENT WELL CONDITION SUMMARY 4070 None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025650 197-237 P.O. Box 100630, Anchorage, Alaska 99508 50-029-22844-0000 ConocoPhillips Alaska, Inc. KRU 1D-117 Kuparuk River / West Sak Oil COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): 3712 - 4082 Perforation Depth TVD (ft):Tubing Size: 4508 - 4879 Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 659-7224 Baker Anchor Seal Assembly None 4413 / 3616 None Size 4 Authorized Signature: 10/15/2021 3.5 Perforation Depth MD (ft): L-80 m n P 66 t Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 11:40 am, Sep 23, 2021 321-502 Digitally signed by Jan Byrne DN: CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2021.09.23 11:08:25-08'00' Foxit PDF Editor Version: 11.0.0 Jan Byrne DLB 09/23/2021 X VTL 9/28/21 X DSR-9/23/21 X 10-404 sta 9/28/2021 JLC 9/28/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.28 13:38:57 -08'00' RBDMS HEW 9/28/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 23, 2021 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 1D-117 (PTD 197-237) to pull and reset a retrievable tubing patch. Please contact me at 659-7224 if you have any questions. Sincerely, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Digitally signed by Jan Byrne DN: CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2021.09.23 11:07:45-08'00' Foxit PDF Editor Version: 11.0.0 Jan Byrne Executive Summary 1D-117 has a known tubing leak at 4387’ and is believed to have a leak at the existing patch upper packer or just above that depth. The plan is to pull the existing patch and set a new tubing patch across those depths. The proposed Well Work Request is below. Well Work Justification & Objectives (and date required if appropriate): 1D-117 Was reported by Operations to be experiencing suspect IA pressurization. An MITIA passed, but the IA-DDT failed and the well was shut in and freeze protected. Diagnostic results have been inconclusive- An MITT above the patch extension failed, but after the patch extension was pulled the MITT passed. An MITIA passed, but when carried out longer failing numbers occurred. A 5+ hour pressure up on the IA showed extremely small linear pressure loss. There is very little that can be deduced from the minuscule pressure fall off. Reviewing the original patch installation shows it was unknown if the upper packer leaked or there was an additional leak above the upper packer prior to the patch extension being set. The most likely scenario is that the upper patch packer is leaking so this WWR is to pull and replace the existing patch extending the upper packer to where the previous HF test passed. Risk/Job Concerns: •Single casing well •Tubing patch at 4371' to 4398'. •SUB I-B END. Drift with dummy patch had no issues on 3/12/21. •Patch extension at 4359' with slip stop on top at 4357' pulled on 5/13/21. •HF test passed at 4364' on 5/4/17. •Need Sundry Approval Prior To Installing New Patch Steps: Relay 1. RIH to pull WFT WPLE patch at 4371' (NORM test equipment). 2. RIH to brush and flush patch set area 4350' to 4410'. 3.Displace tubing with 40 bbls diesel post brush and flush for clean fluid. 4. RIH with lower P2P to set mid element at 4399' (~1' lower than previous) . Correlate to SLB LDL 3.16.17. 5. RIH to sting into lower P2P with test tool and CMIT TxIA to 3000 psi. Record TIOs. Pull test tool. 6. RIH with upper patch assembly to sting into lower P2P. The patch should be 35' element to element setting the upper P2P at 4364'. 7. Perform MITIA to 3000 psi. Record TIOs. 8.RDMO, turn well over to Operations. 9. DHD to perform SW MITIA once well has stabilized.DHD to perform SW MITIA once well has stabilized. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 4,715.0 9/23/2013 1D-117 hipshkf Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled K3 patch extension from 4359' RKB 5/12/2021 1D-117 spilch Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 40.0 Set Depth (ftKB) 121.0 Set Depth (TVD) … 121.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 40.5 Set Depth (ftKB) 5,190.0 Set Depth (TVD) … 4,393.3 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description GRAVEL PACK LINER OD (in) 4 ID (in) 3.96 Top (ftKB) 4,413.0 Set Depth (ftKB) 4,880.0 Set Depth (TVD) … 4,083.4 Wt/Len (l…Grade Top Thread Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 4,413.0 3,616.5 0.68 PACKER BAKER GRAVEL PAK PACKER SC-1 4.000 4,421.6 3,625.2 0.53 SLEEVE 80-40 GRAVEL PACK SLIDING SLEEVE 4.700 4,424.2 3,627.7 0.54 SBE 80-40 SEAL BORE 4.000 4,441.7 3,645.3 0.63 SAFETY SOS SHEAROUT SAFETY JOINT 3.958 4,508.3 3,711.9 0.95 SCREEN Bakerweld Gravel Pack Screen Size 4.0" X .020" guage X 37' 3.958 4,879.4 4,082.9 1.52 PLUG BAKER BULL PLUG 4.000 Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 39.6 Set Depth (ft… 4,414.0 Set Depth (TVD) (… 3,617.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 39.6 39.6 0.00 HANGER VETCO GRAY TUBING HANGER 3.580 497.2 496.5 7.82 NIPPLE CAMCO DS LANDING NIPPLE 2.812 4,354.7 3,558.2 1.11 NIPPLE CAMCO D NIPPLE 2.750 4,393.1 3,596.6 1.00 PBR BAKER 80-40 POLISHED BORE RECEPTACLE 4.000 4,412.8 3,616.3 0.69 SEAL ASSY BAKER ANCHOR TUBING SEAL ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 4,371.0 3,574.5 0.98 PACKER - PATCH - UPR 2.72" WFT WPLE PKR 5/4/2017 1.720 CP350123 4,378.0 3,581.5 0.96 SPACER / ANCHOR LATCH 21' SPACER PIPE, ANCHOR SEAL ASSY, PATCH OAL= 28.95' / 2.72" MAX OD MID- ELEMENT 5/4/2017 1.720 CPS350058 4,387.0 3,590.5 0.98 LEAK LEAK FOUND AT PUP JOINT ABOVE PBR 3/16/2017 0.000 4,398.0 3,601.5 1.01 PACKER - PATCH - LWR 2.72" WPLE PACKER SN = CP 350147 @ 4398' RKB, SET UPPER 2.72" WPLE PACKER SN = CP 350131 5/1/2017 1.810 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 4,508.0 4,879.0 3,711.5 4,082.4 WS D, 1D-117 11/3/2000 32.0 SLOTS Bakerweld Gravel Pack Screen Size 4.0" X .020" guage X 37' 4,524.0 4,554.0 3,727.5 3,757.5 WS D, 1D-117 2/22/1998 4.0 IPERF 4,524.0 4,547.0 3,727.5 3,750.5 WS D, 1D-117 11/3/2000 12.0 RPERF 4.5" HSD Frac guns w/43cj UP II RDX 4,524.0 4,547.0 3,727.5 3,750.5 WS D, 1D-117 2/18/1998 4.0 IPERF Zero deg phasing 4,547.0 4,554.0 3,750.5 3,757.5 WS D, 1D-117 11/3/2000 12.0 APERF 4.5" HSD Frac guns w/43cj UP II RDX 4,588.0 4,608.0 3,791.5 3,811.5 WS B, 1D-117 11/3/2000 12.0 RPERF 4.5" HSD Frac guns w/43cj UP II RDX 4,588.0 4,608.0 3,791.5 3,811.5 WS B, 1D-117 2/14/1998 4.0 IPERF Zero deg phasing 4,635.0 4,650.0 3,838.5 3,853.5 WS A4, 1D-117 2/12/1998 4.0 IPERF Zero deg phasing 4,640.0 4,650.0 3,843.5 3,853.5 WS A4, 1D-117 11/3/2000 12.0 RPERF 4.5" HSD Frac guns w/43cj UP II RDX 4,692.0 4,722.0 3,895.5 3,925.5 WS A3, 1D-117 2/5/1998 4.0 IPERF 4,746.0 4,776.0 3,949.5 3,979.4 WS A2, 1D-117 2/1/1998 4.0 RPERF Zero deg phasing 4,746.0 4,776.0 3,949.5 3,979.4 WS A2, 1D-117 1/27/1998 4.0 IPERF Zero deg phasing 4,820.0 4,828.0 4,023.4 4,031.4 WS A2, 1D-117 11/3/2000 12.0 APERF 4.5" HSD Frac guns w/43cj UP II RDX 4,862.0 4,870.0 4,065.4 4,073.4 WS A1, 1D-117 11/3/2000 12.0 APERF 4.5" HSD Frac guns w/43cj UP II RDX Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 2/2/1998 4,746.0 4,828.0 0.0 0.00 0.00 2 FRAC 2/6/1998 4,692.0 4,722.0 0.0 0.00 0.00 3 FRAC 2/12/1998 4,635.0 4,650.0 0.0 0.00 0.00 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 4,311.2 3,514.8 1.29 CAMCO KBMM- 2 1 GAS LIFT DMY BK 0.000 0.0 3/21/2017 1D-117, 5/20/2021 6:06:23 AM Vertical schematic (actual) SURFACE; 40.5-5,190.0 GRAVEL PACK LINER; 4,413.0- 4,880.0 APERF; 4,862.0-4,870.0 APERF; 4,820.0-4,828.0 FRAC; 4,746.0 IPERF; 4,746.0-4,776.0 RPERF; 4,746.0-4,776.0 IPERF; 4,692.0-4,722.0 FRAC; 4,692.0 SLOTS; 4,508.0-4,879.0 RPERF; 4,640.0-4,650.0 FRAC; 4,635.0 IPERF; 4,635.0-4,650.0 IPERF; 4,588.0-4,608.0 RPERF; 4,588.0-4,608.0 APERF; 4,547.0-4,554.0 IPERF; 4,524.0-4,554.0 RPERF; 4,524.0-4,547.0 IPERF; 4,524.0-4,547.0 SEAL ASSY; 4,412.8 PACKER - PATCH - LWR; 4,398.0 PBR; 4,393.0 SPACER / ANCHOR LATCH; 4,378.0 LEAK; 4,387.0 PACKER - PATCH - UPR; 4,371.0 NIPPLE; 4,354.7 GAS LIFT; 4,311.2 NIPPLE; 497.2 CONDUCTOR; 40.0-121.0 HANGER; 39.6 KUP INJ KB-Grd (ft) 41.00 Rig Release Date 1/2/1998 1D-117 ... TD Act Btm (ftKB) 5,205.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292284400 Wellbore Status INJ Max Angle & MD Incl (°) 50.33 MD (ftKB) 2,675.00 WELLNAME WELLBORE1D-117 Annotation Last WO: End Date 5/19/2002 H2S (ppm) 0 Date 7/12/2001 Comment SSSV: NIPPLE Notes: General & Safety End Date Annotation 4/27/2017 NOTE: UNABLE TO DRIFT 2.74" THRU D-NIPPLE @4,355' RKB 2/24/2009 NOTE: View Schematic w/ Alaska Schematic9.0 10/31/2000 NOTE: Nordic 3 Workover to Gravel Pack completion (10/31 - 11/6/00) 11/6/1998 NOTE: Tag spline @ 4352' 1D-117, 5/20/2021 6:06:24 AM Vertical schematic (actual) SURFACE; 40.5-5,190.0 GRAVEL PACK LINER; 4,413.0- 4,880.0 APERF; 4,862.0-4,870.0 APERF; 4,820.0-4,828.0 FRAC; 4,746.0 IPERF; 4,746.0-4,776.0 RPERF; 4,746.0-4,776.0 IPERF; 4,692.0-4,722.0 FRAC; 4,692.0 SLOTS; 4,508.0-4,879.0 RPERF; 4,640.0-4,650.0 FRAC; 4,635.0 IPERF; 4,635.0-4,650.0 IPERF; 4,588.0-4,608.0 RPERF; 4,588.0-4,608.0 APERF; 4,547.0-4,554.0 IPERF; 4,524.0-4,554.0 RPERF; 4,524.0-4,547.0 IPERF; 4,524.0-4,547.0 SEAL ASSY; 4,412.8 PACKER - PATCH - LWR; 4,398.0 PBR; 4,393.0 SPACER / ANCHOR LATCH; 4,378.0 LEAK; 4,387.0 PACKER - PATCH - UPR; 4,371.0 NIPPLE; 4,354.7 GAS LIFT; 4,311.2 NIPPLE; 497.2 CONDUCTOR; 40.0-121.0 HANGER; 39.6 KUP INJ 1D-117 ... WELLNAME WELLBORE1D-117 Wallace, Chris D (CED) From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, April 19, 2021 8:55 AM To: Wallace, Chris D (CED) Cc: Earhart, Will C Subject: KRU 1 D-117 (PTD 197-237) Report of suspect IA pressurization Attachments: 1 D-117.pdf, 1 D-117 90 day TIO trend 4.19.21 jpg Chris, KRU 1D-117 (PTD 197-237) was reported by Operations this morning to be exhibiting suspect IA pressurization. DHD will mobilize to the well today to perform initial diagnostics. Dependent upon those diagnostics the well will begin a 30 day monitor period or be shut in and freeze protected until further diagnostics take place. The proper paperwork for continued injection or corrective action will be submitted once a path forward has been determined. A 90 day TIO trend and wellbore schematic are attached. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg p e DATE: Monday,June 12,2017 P.I.Supervisor ��C b( i�f 7 SUBJECT: Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA INC 1D-117 FROM: Adam Earl KUPARUK RIV U WSAK 1D-117 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 3i eC— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1D-117 API Well Number 50-029-22844-00-00 Inspector Name: Adam Earl Permit Number: 197-237-0 Inspection Date: 5/27/2017 Insp Num: mitAGE170528113331 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ID-117 _ Type Inj _W-TVD 3616 Tubing 620 621 619 619 PTD 1972370 Type Test SPT (Test psi 1500 " IA 1520 2300 2265 2260 , BBL Pumped: 0.6.. -_ BBL Returned: 0.5 - OA Interval STA P/F P Notes: Initial MITIA post patch per sundry#317-146/This well does not have an 0/A .. SCANNED AUG 1 5 2017, Monday,June 12,2017 Page 1 of 1 STATE OF ALASKA NIL OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Plug Perforations U Fracture Stimulate H Pull Tubing H Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑., Re-enter Susp Well ❑ Other: Tubing patch ❑✓ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 1972370 3.Address: Stratigraphic ❑ Service ❑� 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-22844-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025650 KRU 1 D-117 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 5205 feet Plugs measured None feet true vertical 4408 feet Junk measured None feet Effective Depth measured 4866 feet Packer measured 4413 feet true vertical 4070 feet true vertical 3616 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 16" 121' 121' Surface 5150' 7 5/8" 5190' 4393' Intermediate RECEIVED Production Liner 467' 4" 4880' 4083' MAY 31 2017 Perforation depth Measured depth 4508'-4879' feet True Vertical depth 3712'-4082' feet AOGCC Tubing(size,grade,measured and true vertical depth) 3 1/2",L-80,4414'MD,3618'TVD 39'Retrievable patch from 4359'-4398'MD Packers and SSSV(type,measured and true vertical depth) SSSV Nipple,Camco DS Landing Nipple,497'MD,496'TVD Seal Assembly,Baker Anchor Tubing Seal Assembly,4413'MD,3616'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: SCANNED , . . f 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure - Prior to well operation: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAc 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑., Exploratory ❑ Development❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Q WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-146 Authorized Name: Brent Rogers Contact Name: Brent Rogers/Kelly Lyons Authorized Title: Well Integrity upervisor Contact Email: N1617@conocophillips.com Authorized Signature: / 4,14 Date:May 28,2017 Contact Phone: 659-7224 t /�/7-/i7— 4 7 Form 10-404 Revised 4/2017 � .y RBDMS I \-/ MAY 3 1 201 Submit Original Only • • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 1 ANCHORAGE,ALASKA 99510-0360 MAY 3 2017 AOGCC May 29, 2017 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 1D-117 (PTD 1972370). The report is for a tubing patch that was set to repair a leak above the top Seal Assembly as per Sundry#317-146. Please call Kelly Lyons or myself at 659-7224 if you have any questions. Sincerely, "(1,j/4/14---0 Brent Rogers NSK Well Integrity Supervisor CPF1 & 2 Attachments • • Date Event Summary 05/01/12 RIH W/ RELAY TO OBTAIN PSI &TEMP, SET 2.72"WPLE PACKER @ 4398' RKB, SET UPPER 2.72"WPLE PACKER @ 4373' RKB, LRS ATTEMPTED FOUR MITIA WITH DIESEL, ALL FAIL. 05/02/17 ATTEMPTED MIT-IA(FAILED). SET TEST TOOL IN TOP OF PATCH @ 4376' RKB & ATTEMPT MITT (FAILED), PULLED AND RE-SET TEST TOOL; MITT CONTINUES TO FAIL. APPEARS WING AND CHECK ON SURFACE PIPING ARE LEAKING. IN PROGRESS. 05/03/17 MITT TO 2500 PSI AGAINST TEST TOOL SET IN PATCH @ 4376' RKB (PASS). ATTEMPT MITIA TO 2500 PSI (FAIL). PULLED TEST TOOL & UPPER PATCH ASSY (SNAP LATCH SEALS DAMAGED). SET TEST TOOL IN LOWER PACKER @ 4398' RKB &COMBO MIT T x IA TO 2500 (PASS). IN PROGRESS. 05/04/17 SET 28.95'x 2.72"WFT WPLE PKR (#CP350123), 21' SPACER PIPE, ANCHOR SEAL ASSY(#CPS350058), MID-ELEMENT @ 4371' RKB. ATTEMPTED MIT-IA(FAIL). SET TEST TOOL IN TOP OF PATCH &ATTEMPT MITT (IA TRACKING). SET HOLEFINDER MID-ELEMENT @ 4364' RKB (7'ABOVE UPPER WPLE PKR ELEMENT) & MITT TO 2000 PSI (PASS). JOB SUSPENDED FOR PLAN FORWARD. 05/13/17 CMIT TxIA TO 2500 PSI (PASS); SET K-3 PLUG ASSEMBLY ON TEST TOOL @ 4359' RKB (MID-ELEMENT); MITIA TO 2500 PSI (PASS); PULLED K-3 PLUG ASSEMBLY& PULL ER TEST TOOL @ 4371' RKB. JOB POSTPONED UNTIL PATCH EXTENSION IS READY. 05/16/17 SET K3 PATCH EXTENSION MID ELEMENT @ 4359' RKB. SET SLIP STOP ON K3 PACKER. MIT-IA TO 2500psi (PASS) JOB COMPLETE. MITIA: Pre TI: 550/350. Starting TI: 550/2550. 15 min TI: 550/2450. 30 min TI: 550/2425. 05/27/17 (ISW) : INITIAL STATE WITNESSED (ADAM EARL) MIT-IA(PASSED) TO 2300 PSI. Summary A 27' element to element Weatherford retreivable patch was set. An additional leak was discovered after the patch was set so a 12' patch extension was set on top. A total of 39' was patched with a 3 part retrievable patch. The AOGCC witnessed MITIA following passed. • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reggna,alaska.gov AOGCC.Inspectors(a�alaska.gov phoebe.brooksRalaska.aov chris.wallace(ialaska.gov OPERATOR: ConocoPhillips Alaska Inc, FIELD/UNIT/PAD: Kuparuk/KRU/1D Pad DATE: 05/27/17 OPERATOR REP: Sumrall AOGCC REP: Adam Earl Well 1D-117 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1972370 Type Inj W Tubing 620 621 619 619 Type Test P Packer TVD 3616 BBL Pump 0.6 IA 1520 2300 2265 2260 Interval I Test psi 1500 BBL Return 0.5 OA Result P Notes: Initial MITIA post patch per Sundry#317-146 Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT KRU ID-117 05-27-17.xlsx 1.-, . KUP INJ • 1D-117 • • C©nocoPhiHips �'.4'..-= Well Attributes Max Angle&MD TD AIBSke,Inc. K't 6'"""' ,„F Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) man«0,m-, . 500292284400 WEST SAK INJ 50.33 2,675.00 5,205.0 --- -. Comment 1125(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 10-117,5/19/20172:37:11 PM SSSV:NIPPLE 0 7/12/2001 Last WO: 5/19/2002 41.00 1/2/1998 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _.._ _Last Tag:SLM 4,715.0 9/23/2013 Rev Reason:SET PATCH&SEE NOTES pproven 5/19/2017 ie Casing Strings J,,,urn u,m a^uu,om,,,^���^^^.^^.uww Casing Description OD(in) ID(in) Top IRKS) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I..Grade Top Thread HANGER 396 i I- "�`CONDUCTOR 16 15.062 40.0 121.0 121.0 62.58 H-40 WELDED i= Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 12. SURFACE 75/8 6.875 40.5 5,190.0 4,393.3 29.70 L-80 BTCM Casing Description OD(in) ID(in) Top(ORB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread GRAVEL PACK LINER 4 3.958 4,413.0 4,880.0 4,083.4 Liner Details Nominal ID CONDUCTOR;40.0-121.0 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 4,413.0 3,616.5 0.68 PACKER BAKER GRAVEL PAK PACKER SC-1 4.000 NIPPLE;4972 11 4,421.6 3,625.2 0.53 SLEEVE 80-40 GRAVEL PACK SLIDING SLEEVE 4.700 4,424.2 3,627.7 0.54 SBE 80-40 SEAL BORE 4.000 4,441.7 3,645.3 0.63 SAFETY SOS SHEAROUT SAFETY JOINT 3.958 4,508.3 3,711.9 0.95 SCREEN Bakerweld Gravel Pack Screen Size 4.0"X.020" 3.958 guage X 37' 4,879.4 4,082.9 1.52'PLUG BAKER BULL PLUG 4.000 Tubing Strings Tubing Description !String Ma...I ID(in) 'Top(ftKB) 'Set Depth(ft..f Set Depth(TVD)(...�Wt(lb/ft) !Grade I Top Connection GASLIFT;4,311.2 TUBING 31/2 2.992 39.611 4414.011 , 3,6175 9.30 L-80 EUE8rd Completion Details Nominal ID Top(ftKB) _Top(TVD)(ftKB) Top Incl 7) Item Des Corn (in) NIPPLE;4,354.7illir 39.6 39.6 0.00-HANGER VETCO GRAY TUBING HANGER 3.580 a..., 497.2 496.5 7.82 NIPPLE CAMCO DS LANDING NIPPLE 2.612 SLIP STOP;4,357.4 4,354.7 3,558.2 1.11 NIPPLE CAMCO D NIPPLE 2.750 PATCH;4,359.0 ( 4,393.1 3,596.6 1.00 PBR -BAKER 80-40 POLISHED BORE RECEPTACLE 4.000 4,412.8 3,616.3' 0.69 SEAL ASSY BAKER ANCHOR TUBING SEAL ASSEMBLY 3.000 Other In Hole(Wireline'retrievable plugs,valves,pumps,fish,etc.) PATCH;4,371.0 1 Top(ND) Top not Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 4,357.4 3,560.9 1.09 SLIP STOP 3.5"SLIP STOP(18.75"OAL)TO SET ON K3 PKR 5/16/2017 PBR;4,393.0 4,359.0 3,562.5 1.08 PATCH K3 PACKER,SPACER PIPE,SEAL ASSY(121.5" 5/16/2017 1.430 PATCH;4,398.0 ! OAL/106.75 ME TO BTM/1.43"ID @ K3 PKR) 4,371.0 3,574.5 0.98 PATCH 2.72"WFT WPLE PKR(SN:CP350123),21' 5/4/2017 1.720 SPACER PIPE,ANCHOR SEAL ASSY(SN: CPS350058),PATCH OAL=28.95'/2.72"MAX OD/ 1.72"ID f� 4,398.0 3,601.5 1.01'PATCH 2.72"WPLE PACKER SN=CP 350147 @ 4398' 5/1/2017 1.810 SEAL ASSY;4,412.8 r`=r. RKB,SET UPPER 2.72"WPLE PACKER SN=CP ; v. 350131 Perforations&Slots Shot �I I- Dens Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 4,508.0 4,879.0 3,711.5 4,082.4 11/3/2000 32.0 SLOTS Bakerweld Gravel Pack Screen Size 4.0" X.020"guage X 37' 4,524.0 4,547.0 3,727.5 3,750.5 WS D,1D-117 2/18/1998 4.0 (PERF Zero deg phasing 4,524.0 4,547.0 3,727.5 3,750.5 WS D,1D-117 11/3/2000 12.0 RPERF 4.5"HSD Frac guns w/43cj UP II RDX 4,524.0 4,554.0 3,727.5 3,757.5 WS D,10-117 2/22/1998 4.0 IPERF RPERF;4,524.0-4,547.0 ,1 IPERF;4,524.0-4,547.0A - 4,547.0 4,554.0 3,750.5 3,757.5 WS D,1D-117 11/3/2000 12.0 APERF 4.5"HSD Frac guns (PERF;4,524.0-0,554.0- w/43Cj UP II RDX APERF;4,547.0-4,554.0 - 4,588.0 4,608.0 3,791.5 3,811.5 WS 8,1D-117 2/14/1998 4.0 (PERF Zero deg phasing 4,588.0 4,608.0 3,791.5 3,811.5 WS B,1D-117 11/3/2000 12.0 RPERF 4.5"HSD Frac guns (PERF;4,588.0-0,608.0 ; w/43cj UP II RDX RPERF;4,588.0-0,608.0 4,635.0 4,650.0 3,838.5 3,853.5 WS A4,1D- 2/12/1998 4.0 IPERF Zero deg phasing • 117 - IPERF;4,635.04,650.0 4,640.0 4,650.0 3,843.5 3,853.5 WS A4,1D- 11/3/2000 12.0 RPERF 4.5"HSD Frac guns FRAC;4,635.0 . r 117 w/43cj UP II RDX RPERF;4,640.0-4,650.0 . _ 4,692.0 4,722.0 3,895.5 3,925.5 WS A3,1D- 2/5/1998 4.0 IPERF SLOTS;4,508.0-4,879.0 117 FRAC;4,692.0 (PERF;4,692.0-0,722.0 C 1 4,746.0 4,776.0 3,949.5 3,979.4 WS A2,10- 1/27/1998 4.0 IPERF Zero deg phasing i 117 RPERF;4,746.04,776.0 111'., 4,746.0 4,776.0 3,949.5 3,979.4 WS A2,10- 2/1/1998 4.0 RPERF Zero deg phasing ■ IPERF;4,746.0-4,776.0 i. 117 FRAC;4,748.0 rt~- 4,820.0 4,828.0 4,023.4 4,031.4 WS A2,1D- 11/3/2000 12.0 APERF 4.5"HSD Frac guns APERF;4,620.0-4,828.0 117 W/43CJ UP 11 RDX 4,862.0 4,870.0 4,065.4 4,073.4 WS Al,11D- 11/3/2000 12.0 APERF 4.5"HSD Frac guns 117 w/43cj UP II RDX APERF;4,862.0-4,870.0 Stimulations&Treatments I/ Proppant Designed(Ib) Proppant In Formation(Ib) Date 2/2/1998 Stimulations&Treatments Mr GRAVEL PACK LINER;4,413.0- _ Vol Clean Pump 4,880.0 Stg# Top(ftKB) Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) 1 4,746.0 4,828.0 2/2/1998 I) Proppant Designed(Ib) Proppant In Formation(Ib) Date 2/6/1998 SURFACE;40.5-5,190.0- KUP INJ 0 1D-117 e ConoccPhillips Alaska.)nc, , CeresaPhiSfpc ID-117,5/19/2017 2:37:11 PM Vertoalschernano(actual) rib Stimulations&Treatments Vol Clean Pump HANGER;39.6 Wuut'.f —I ' ILLYYStg# Top(ftKB) Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) 1 4,692.0 4,722.0 2/6/1998 Proppant Designed(Ib) Proppant In Formation(Ib) Date 2/12/1998 Stimulations&Treatments — Vol Clean Pump ,./v Stg 9 Top(ftKB) Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) CONDUCTOR;40.0-121.0 A1 4,635.0 4,650.0 2/12/1998 NIPPLE;497.2 tin Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 4,311.2 3,514.8 CAMCO KBMM- ' 1 GAS LIFT DMY BK ' 0.000 0.0 3/21/2017 2 Notes:General&Safety End Date Annotation t.--,_.-1-. 11/6/1998 NOTE:Tag spline @ 4352' 10/31/2000 NOTE:Nordic 3 Workover to Gravel Pack completion(10/31-11/6/00) GAS LIFT;4,311.2 2/24/2009 NOTE:View Schematic w/Alaska Schematic9.0 4/27/2017 NOTE:UNABLE TO DRIFT 2.74"THRU D-NIPPLE @4,355'RKB NIPPLE;4,354.7 SLIP STOP;4,357.4 y^ PATCH;4,359. PATCH;4,371.0 PM;4,393.0' PATCH;4,398.0 _-rte 1 m. SEAL ASSY;4,412.8 '' :.. 11 ....- 1111 RPERF;4,524.0-4,547.0 IPERF;4,524.0.4 547.0., IPERF;4,524.04,554.0 APERF;4,547.0-4,554.0--..p IPERF;4,588.0-4,606.0, .a.= RPERF;4,588.0-4,608.0 maul Ya6- IPERF;4,635.0-4950.0 FRA4,650.0� mo. RPERF;4,640.0.0-0,650.0 SLOTS;4,508.0-4,879.0 FRAC;4,692.0 IPERF;4,692.04,722.0 .®_1 RPERF;4,746.04,776.0, �- IPERF4,746.04,776.O _ ---- FRAC;4,]46.0 -mss A-- APERF;4,820.04,828.0 C APERF;4,862.0-4,870.0 GRAVEL PACK LINER;4,413.0- , 4,660.0 SURFACE;40.5-5,190.0 • AtiOF ?j1 • • w Iyjy s, THE STATE Alaska Oil and Gas :_ =i ®f® ® c Conservation Commission ALAS s t t£ ",>"�_:_-_�=-�, 333 West Seventh Avenue , GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Brent Rogers NSK Well Integrity Supervisor CPF1 and CPF2 ConocoPhillips Alaska, Inc. P.O. Box 100360 SCANNED APR 1 920i? Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1D-117 Permit to Drill Number: 197-237 Sundry Number: 317-146 Dear Mr. Rogers: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this t day of April, 2017. RBDMS :L' "I'll 7 2017 RECEIVED • • STATE OF ALASKA APR 0 7 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION 197S41// / APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate r Repair Well Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Plug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: Tubing patch P'. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r" 1972370` 3.Address: Stratigraphic r Service • 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-22844-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No R-... KRU 1D-117 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025650 -, Kuparuk River Field/West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 5205 4408 -, 4866' - • 4070' Casing Length Size MD TVD Burst Collapse CONDUCTOR 81' 16 121' 121' SURFACE 5150' 7 5/8 5190' 4393' Gravel Pack Liner 467' 4 4880' 4083' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Intervals from 4524'-4870' ' Intervals from 3728'-4073' 3 1/2 L-80 4413 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) NIPPLE=CAMCO DS LANDING NIPPLE MD=497 TVD=496 PBR=BAKER 80-40 POLISHED BORE RECEPTACLE MD=4393 TVD=3597 SEAL ASSY=BAKER ANCHOR TUBING SEAL ASSEMBLY MD=4413 TVD=3616 ' 12.Attachments: Proposal Summary f WellBore Schematic Fr. 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service Ip- • 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: 04/10/17 OIL r WINJ pr. WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdow n r Abandoned r 17.I hereby certify that the foregoing is true Contact: Brent Rogers/Kelly Lyons Printed Name Brent Rogers Phone:659-7224 Email: n1617( conocophillips.com Title: NSK Well Integrity Supervisor CPF1 &2 Signature 7G�� `.....)0441 --,•-------- Date: April 06,2017 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ItSc ti (.. 1,1 Rug Integrity rBOP Test Mechanical Integrity TestIV/Location Clearance r Other: RBDMS w 7)9 1 2 2017 Post Initial Injection MIT Req'd? Yes IV No r Spacing Exception Required? Yes r No r-/ Subsequent Form Required: /D "-1 (j APPROVED BY Approved by: / 1 _ COMMISSIONER THE COMMISSION Date: 4—(/—/7 . Li/ �i- viz._ 4//61i? 0 R1f6dIaa1k Form 10-403 Revised 11/2015valid for 12 months from the date of approval. Attachmentss in Duplicate • • lopv ConocoPh i I I i ps Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 APR 0 7 20"17 AOGCC April 6, 2017 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1D-117 (PTD 1972370). The request is for approval to patch a tubing leak above the top Seal Assembly. / Please call Kelly Lyons or myself at 659-7224 if you have any questions. Sincerely, ‘-‘41'4, Brent Rogers NSK Well Integrity Supervisor CPF1 & 2 Attachments III • ConocoPhillips Alaska,Inc. Kuparuk Well 1D-117 (PTD 1972370) SUNDRY NOTICE 10-403 TUBING REPAIR 04/06/17 This Sundry is a request for approval to repair ConocoPhillips (CPA) Kuparuk Well 1D-117 (PTD 1972370) with a tubing patch. On February 24, 2017, the AOGCC was notified of a failed MITIA. Subsequent diagnostics have identified a tubing to IA leak at 4387' MD. The plan is to set a retrievable patch over the leak, conduct an MITIA, and return the well to normal WI injection. REPAIR PLAN 1. Set 3.5"retrievable tubing patch across the leak. 2. MITIA as per AOGCC requirements (0.25 x TVD to packer). 3. Return the well to injection 4. AOGCC witnessed MITIA once thermally stabilized. 5. Submit 10-404 post-repair. NSK Well Integrity Supervisor CPF1 &2 • KUP INJ • 1 D-117 ConocoPhillips ;Xxla' Well Attributes Max Angle&';AD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) cmecoatvxtpr 500292284400 WEST SAK INJ 50.33 2,675.00 5,205.0 •-• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1D-117,3/24201710:48.59 AM SSSV:NIPPLE 0 7/12/2001 Last WO: 5/19/2002 41.00 1/2/1998 Vesical schematic(actuaq Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 4,715.0 9/23/2013 Rev Reason:GLV C/O pproven 3/24/2017 r Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WVLen(I...Grade Top Thread nawuw �a uum CONDUCTOR 16 15.062 40.0 121.0 121.0 62.58 H-40 WELDED HANGER;39.fi •r.' rei 'I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread ',*7, SURFACE 75/8 6.875 40.5 5,190.0 4,393.3 29.70 L-80 BTCM ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread I GRAVEL PACK LINER 4 3.958 4,413.0 4,880.0 4,083.4 Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inel C) Item Des Com (in) CONDUCTOR;40.0-121 0 . 4,413.0 3,616.5 0.68 PACKER BAKER GRAVEL PAK PACKER SC-1 4.000 4,421.6 3,625.2 0.53 SLEEVE 80-40 GRAVEL PACK SLIDING SLEEVE 4.700 NIPPLE;497.2 - 4,424.2 3,627.7 0.54 SBE 80-40 SEAL BORE 4.000 ' 4,441.7 3,645.3 0.63 SAFETY SOS SHEAROUT SAFETY JOINT 3.958 4,508.3 3,711.9 0.95 SCREEN Bakerweld Gravel Pack Screen Size 4.0"X.020" 3.958 guage X 37' I 4,879.4 4,082.9 1.52 PLUG BAKER BULL PLUG 4.000 Tubing;Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...WI(15/11) Grade Top Connection TUBING 3 1/2 2.992 39.6 4,414.0 3 617.5 9.30 L-80 EUE8rd Completion Details GAS LIFT;4,311 2 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (in) 39.6 39.6' 0.00 HANGER VETCO GRAY TUBING HANGER 3.580 497.2 496.5 7.82 NIPPLE CAMCO DS LANDING NIPPLE 2.812 4,354.7 3,558.2 1.11 NIPPLE CAMCO D NIPPLE 2.750 NIPPLE;4,3547 4,393.1 3,596.6 1.00 PBR BAKER 80-40 POLISHED BORE RECEPTACLE 4.000 £ 4,412.8 3,616.3 0.69 SEAL ASSY BAKER ANCHOR TUBING SEAL ASSEMBLY 3.000 II Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PBR;4,393.0 11 1Top(ND) Top Incl I Top(RKB) (ftKB) Cl Des Com Run Date ID(in) SURFACE CASING PATCH:Welded 5'-9"of 10".500 7/4/2012 wall 65#sleeve over SC starting©bottom of starter head. SEAL ASSY;4,4128 Wi - Perforations&Slots ,., ,., Shot Dens Top(ND) Bier(ND) (shotslr Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 4,508.0 4,879.0 3,711.5 4,082.4 11/3/2000 32.0 SLOTS Bakerweld Gravel Pack I Screen Size 4.0„ X.020"guage X 37' 4,524.0 4,547.0 3,727.5 3,750.5 WS D,10-117 2/18/1998 4.0 IPERF Zero deg phasing 4,524.0 4,547.0 3,727.5 3,750.5 WS D,1D-117 11/3/2000 12.0 RPERF 4.5"HSD Frac guns 13 w/43cj UP II RDX 4,524.0 4,554.0 3,727.5 3,757.5 WS D,1D-117 2/22/1998 4.0 IPERF -++ m--- 4,547.0 4,554.0 3,750.5 3,757.5 WS D,1D-117 11/3/2000 12.0 APERF 4.5"HSD Frac guns _..„.1 w/43cj UP II RDX 4,588.0 4,608.0 3,791.5 3,811.5 WS B,1D-117 2/14/1998 4.0 IPERF Zero deg phasing IPERF;4,524 0-4.547.0 RPERF;4,5240-4,5470- I 4,588.0 4,608.0 3,791.5 3,811.5 WS B,1D-117 11/3/2000 12.0 RPERF 4.5"3cHj USDP FrIIRDXac guns IPERF;4,524 0-4,554 0-.- w/4 APERF;4,547.0-4,554.0_._ - 4,635.0 4,650.0 3,838.5 3,853.5 WS A4,1D- 2/12/1998 4.0 IPERF Zero deg phasing 117 4,640.0 4,650.0 3,843.5 3,853.5 WS A4,10- 11/3/2000 12.0 RPERF 4.5"HSD Frac guns 117 w/43cj UP II RDX RPERF;4,588.0-4.908.0 - - IPERF;4,5880-4,6080 ,. ;1 4,692.0 4,722.0 3,895.5 3,925.5 WSA3,10- 2/5/1998 4.0 IPERF 117 4,746.0' 4,776.0' 3,949.5 3,979.4 WS A2,10- 1/27/1998 4.0 IPERF Zero deg phasing IPERF,4,635.0-4,650.0 117 FRAC;4,635 4,746.0 4,776.0 3,949.5 3,979.4 WS A2,1D- 2/1/1998 4.0 RPERF Zero deg phasing RPERF;4,6400-4,650.00 - "--- 117 sl.ors;4s0e 0-4.979 0 4,820.0 4,828.0 4,023.4 4,031.4 WS A2,10- 11/3/2000 12.0 APERF 4.5"HSD Frac guns IPERF,4,692.0-4,722.0 4,692.0- �I 117 w/43cj UP I RDX FRAC;4,722.0, 4,862.0 4,870.0 4,065.4 4,073.4 WS A1,1D- 11/3/2000 12.0 APERF 4.5"HSD Frac guns 117 w/43cj UP II RDX IPERF;4,7460-4,7760 ' -- RPERF;4.7460-4,776.0 Stimulations&Treatments FRAC;4,746.0 Proppant Designed(Ib) Proppant In Formation(Ib) Date 2/2/1998 APERF,4,820.0-4,8280 Stimulations&Treatments : ' - Vol Clean Pump Stg# Top(ftKB) Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) APERF;4,862.0-4,870 0- 1 4,746.0 4,828.0 2/2/1998 Proppant Designed(Ib) Proppant In Formation(Ib) Date 2/6/1998 Stimulations&Treatments _.. Vol Clean Pump Stg# Top(ftKB) Btm(ftKB) Date StimRreat Fluid (bbl) Vol Slurry(bbl) GRAVEL PACK LINER;4,413.0. , '.. 1 4,692.0 4,722.0 2/6/1998 4'8800 Proppant Designed(lb) Proppant In Formation(lb) Date 2/12/1998 Stimulations&Treatments Vol Clean Pump Stg it Top(ftKB) Btm(ftKB) Date Stim/Treat Fluid (bbl( Vol Slurry__(bbl) 1 4,635.0 4,650.0 2/12/1998 SURFACE;40.5-5,190.0- a rtot KUP INJ • 1D-117 } C©n©coPhillips a Alaska,Inc, -' , Cmr000Plvw� 10-117,3/242017 10:49;00 AM Vertical schematic(actual) ill Mandrel Inserts t ww i HANGER 396 °k i°J N Top(ND) Valve Latch Port Size TRO Run Top(RKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 147 1' 4,311.2 3,514 8 CAMCO KBMM- 1 GAS LIFT DMY BK 0.000 0.0 3/21/2017 2 Notes:General&Safety End Date Annotation 11/6/1998 NOTE:Tag spline(0 4352' CONDUCTOR;400-121.0 10/31/2000 NOTE:Nordic3 Workover to Gravel Pack completion(10/31-11/6/00) NIPPLE,497.2 -. 2/24/2009 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;4,311 2 if I II NIPPLE;4,354.7 .- 1 PBR;4,353.0 II C SEAL ASSY;4,412.0 1fj 1 ill 22 B I IPERF;4,5240-4,5470 RPERF;4,5240-4,547.0., IPERF;4,524 0-4,554.0 APER F,4,547.0-4,554.0— RPERF;4,588.0-4,608.0 IPERF;4,588.0-4.6080 IPERF;4,635.0-4,650.0 FRAC;4635.0 RPERF,4,640.0-4,650.0 — IC — SLOTS;4,508.0-4,879 0 IPERF.46920-4,7220,,` f-- IPERF;4,746.0-4,776.0,RPERF,4,746.0-4,776.0 FRAC;4.746.0 & .(k APER F;4,820.0-4,828.0 APER F,4,062.0-4,870.0 4 GRAVEL PACK LINER;4,4130- 4,860 0 SURFACE,40.5-5,1900— • 0 N r Q. r r r r • , by a Q a) �° o � � `° as h asw -o a3 - ++ -C O o v ,(!).. . v a` Q, C ° 5 a ,o + � y C =o a 3 ❑W N'w 0 s Ou E a C Q 0 Q C7o❑ ' r r r 4-J N OCr m 0Nw 0 L `. , e.CI as ea as co r p n Qy,1 w 05 C t L v, Qi ~ N N N N 0 -C N L tri Z ❑ Q CI a) E \ u i.~ +0_, u � C O 0 0 0 0 C v v ' L a J J J J d4 C O >. 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CO 7 CO n CO CO ce o 0 0 0 0 C• Cal V O o00Q0 a) 0 0 0 0 0 -- co 'r > 0 0 0 0 0 > W N V w fnnfnto fn 0 0 0 0 0 Q C o ® n au va Y W Q N 0 ° - 0 0 0 0 0 Q CC et 4 CO CO N M CO N M M M M p, N N N N N 0 r t� a o) o) o) o, o, c o a p N N N N N CO Q1 O O O O o O 0 L pp 0 0 0 0 0 a+ +' C 0 c aa y DD c to to N IJ) MJ 0. d 0 0 en l E w c , U ROA .E CI) a W p W a' •0 E E 02 u N Ip\ a o 9 ~ u CJ H a F N 7 co O y C Y Y 4) Z O to s- co y 00 �v�, Z r r r r ywj ��.' v a Q C N D -7 y, O O Z d C '� c ^ L C 41 E E • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday, February 24, 2017 8:34 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of IA pressure anomaly 1D-117 (PTD 197-237) 2-24-17 Attachments: 1D-117 schematic.pdf; 1D-117 90 day TIO 2-24-17.PNG Chris, West Sak water injector 1D-117 (PTD 197-237) is experiencing an IA pressure anomaly. Yesterday,following an IA bleed to create the proper differential pressure across the T and IA,the IA saw a relatively fast recharge. Although there is a "200psi pressure differential between the two now,that may just be the difference in hydrostatic head of the different fluid columns. Today DHD will be obtaining the standard suite of initial diagnostics,to include MITIA, packoff and drawdown tests. If the MITIA fails,the well will be shut in and freeze protected as soon as possible with follow-up well intervention work with slickline etc as needed. If the MITIA passes,we will put the well on a 30 day monitor. A follow- up email will be provided at the conclusion of the diagnostics. Please let us know if you disagree with the path forward. Attached are the schematic and 90 day TIO plot. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Mobile Phone (907)943-0170 SCANNED APP 2 8 2017 1 • • ConocoPhillips RECEIVED Alaska P.O. BOX 100360 OCT 0 9 2012 ANCHORAGE, ALASKA 99510 -0360 AOGCC October 5, 2012 q . 7 Commissioner Dan Seamount 1 r 1 Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 1 7 Anchorage, AK 99501 to. ANr NO V 1 3 2 C' Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped in the summer /fall of 2012. The corrosion inhibitor /sealant was pumped in the month of September 2012.The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, /i7.01/./7,// Martin Walters ConocoPhillips Well Integrity Projects Supervisor 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 10/05/2012 1D,WSW,1F,2F 2L,2T,2Z,3G,31 & 3M PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft _ gal 1D-113 50029229170000 1981780 2" n/a 8" n/a 5.1 9/27/2012 1D-117 50029228440000 1972370 7' 0.80 25" 7/22/2012 8.7 9/27/2012 WSW -11 50029208820000 1822120 SF n/a 8" n/a 2.9 9/30/2012 1F-11 50029209930000 1831150 19'8" 3.40 12" 7/22/2012 3.4 9/27/2012 2F -19 50029227280000 1962010 7'5" 1.30 18" 9/19/2012 19 9/27/2012 2L -305 50103202790000 1982400 SF n/a 7" n/a 4.4 9/28/2012 2T -28 50103202250000 1950920 9" n/a 27" n/a 13.6 9/27/2012 2Z -10 50029213780000 1851370 5'9" 0.80 23" 9/19/2012 7.7 9/30/2012 3G -03 50103202450000 1961220 2" n/a 12" n/a 7.5 9/28/2012 31 -06 50029219350000 1890380 7' 0.80 11" 7/22/2012 6 9/28/2012 3M -13 50029217200000 1870400 7'7" 0.50 12" 7/22/2012 4.7 9/28/2012 • � t i �6—tt7 • P 117 23 70 Regg, James B (DOA) From: Patterson, Amanda [ Amanda .Patterson @conocophillips.com] Sent: Monday, August 20, 2012 8:21 AM 1`��i To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; Short, Suzanne C; Hutcherson, Mark R; CPF1 Prod Engr Subject: RE: LPP /SSV defeated on 1D-117: Aug 15, 2012 Jim, The low pressure pilot (LPP) on the well listed below was returned to service on 8/19/2012 after the wellhead injection pressure stabilized above the setting of the low pressure pilot. Current wellhead pressure and injection rate are also listed below. This pilot had been defeated on 8/15/2012 in accordance with "Administrative Approval No. CO 406B.001." The injection pressure has increased on the following well so as to remain above 500 psi and the LPP /SSV function has been returned to normal. • Well: 1D-117 • Permit to Drill #: 197 -237 • Wellhead Injection Pressure (PSI): 626 • Injection Rate (BWPD): 386 Please let me know if you have any questions. Thank you. Amanda Patterson West Sak Production Engineer MAY 7 r pdr [U13 ConocoPhillips Alaska, Inc. SCANNED MA Y a Office: (907) 265 -6782 Cell: (281) 796 -5044 From: Regg, James B (DOA) [mailto:jim.reggCc1alaska.gov] Sent: Thursday, August 16, 2012 3:38 PM To: Patterson, Amanda Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Pro Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; Short, Suzanne C; Hutcherson, Mark R; CPF1 Prod Ens Subject: [EXTERNAL]RE: LPP /SSV defeated on 1D -117: Aug 15, 2012 Administrative Approval 406B.001 (attached) requires LPP to be p ced back in service when injection surface pressure reaches 5OOpsi. Jim Regg AOGCC 333 W. 7th Av e, Suite 100 Anchorage, AK 99501 907- 793 -1236 From: Patterson, Amanda [mailto:Amanda.Patter •n • conoco•hilli•s.com] Sent: Wednesday, August 15, 2012 4:01 PM To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv SK Problem Well Supv; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 1 tR7 03 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, August 16, 2012 3:38 PM gq S j, 6(12-- To: 'Patterson, Amanda' Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; Short, Suzanne C; Hutcherson, Mark R; CPF1 Prod Engr Subject: RE: LPP /SSV defeated on 1D-117: Aug 15, 2012 Attachments: co406b -1. pdf Administrative Approval 4068.001 (attached) requires LPP to be placed back in service when injection surface pressure reaches 500psi. Jim Regg AOGCC SCANNED MAY 0 7 7013 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 -793 -1236 From: Patterson, Amanda [mailto: Amanda .Patterson@conocophillips.com] Sent: Wednesday, August 15, 2012 4:01 PM To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; Short, Suzanne C; Hutcherson, Mark R; CPF1 Prod Engr Subject: LPP /SSV defeated on 1D -117: Aug 15, 2012 Jim, I am Amanda Patterson, the new West Sak production engineer for ConocoPhillips AK (replacing Jenn Gauer). I will be emailing you occasionally to inform you of LPP status changes. The low pressure pilot (LPP) on injector 1D-117 (197 -237) was defeated on 08/15/12. Current wellhead pressure is 450 psi at an injection rate of 280 bwpd. The low pressure occurred after the well had been shut in for a period of time and put back on injection today. We anticipate the pressure will build up to 700 psi within the next week. The AOGCC will be notified when the injection pressure has increased to above 700 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Amanda Patterson West Sak Production Engineer ConocoPhillips Alaska, Inc. Office: (907) 265 -6782 Cell: (281) 796 -5044 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Perforations r Perforate r Other SC Repair Alter Casing r Rill Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdown 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 197 -237 3. Address: 6. API Number: Stratigraphic r Service (r �+�,, P. O. Box 100360, Anchorage, Alaska 99510 50 - 029 - 22844 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025650 "' 1D 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): e- Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 5205 feet Plugs (measured) None true vertical 4408 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 4413 true vertical 0 feet (true vertucal) 3616 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 121 121 1640 630 SURFACE 5150 12 5190 4393 6890 4790 Sleeve 5'9" 10" .500 wall 65# 0 0 0 0 0 0 0 0 0 f 0 0 0 Perforation depth: Measured depth: 4508 - 4870 Reel �, True Vertical Depth: 3712 - 4073 JU if� ° 20 /2 Tubing (size, grade, MD, and TVD) 3.5, L -80, 4413 MD, 3616 ND C Packers & SSSV (type, MD, and TVD) SEAL ASSY - BAKER ANCHOR TUBING SEAL ASSEMBLY @ 4413 MD and 3616 TV 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation na na na na na Subsequent to operation na na na na na 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations x 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 -221 Contact Martin Walters / MJ Loveland • Printed Name MJ Loveland Ti _.-- 1/Vell Integrity Supervisor Signature one: 659- Date 7/5/2012 ./ ' e R8DMS JUL 0 9 20122 7 ?- /Z_ Form 10-404 evised 11/2011 Submit Original Only I v' • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 July 05, 2012 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., well 1D -117, PTD 197 -237 , Sundry 312 -221 surface casing repair. Please call MJ Loveland or Martin Walters at 659 -7043 if you have any questions. Sincerely, V MJ Lov and ConocoPhillips Well Integrity Projects Supervisor .r to . ,, 4 & . '' ' ' 4111111■14* a.. .. . ,,,,,„ r - ,..,,, , ., ....... r.... . . . , ‘, Ilk\ . .... ... , , ..., , . . ,... C .. . • iiiiii„„A ' # 0 -0 0 0 0 Q' n = O N 0 n co 0 03• o a. O n 3 ... O a. N N ? 7 N n N 0 N 0 � " Do =m D.-a _ n> ° m m x m n _ c.) N O `< _ N -, n 3 n } al t t . s PA aska'A � G OConocOPo \$ GOO" 9htb \n ho a ° Con °c't3r" \cps A e a a S e d of d tarn ° tbe ut expre an th pub \she o °f nk P \aska ion u oPh�i \cps li; or - °" x { ) 4 f , I' 10-117 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/09/11 Cut 10 X 10" windows in front and backside of wellhead conductor and chip cement, TOC = 29 ". Inspected SC and found minor pitting. Burst seam on side of conductor was split and looked like circ port had been cut off in the past. 11/18/11 After furture examanation of SC thru windows it was decided we need to have Kakivik inspect. (11/21/11 report shows up to 42.1% wall Toss C grade pipe) 06/16/12 SET 2.75 CA -2 PLUG @ 4354' RKB, MIT TBG PASS, DRAWDOWN TEST ON TBG PASS, 06/20/12 Cut 7' 3" of conductor off wellhead including the Vetco top ring. Chipped the cement off and buffed SC for UT inspection. 06 /21 /12lNotifed stateman (Chuck Scheve) opportunity to inspect SC damage. 07/01/121 Welded 5' 9" long 10" .500 wall X65 sleeve onto surface casing. ✓ 1 07/02/12 Post SC repair MITIA. (Passed) Pressured up IA to 1800 psi with .5 bbls of diesel for one hour test.Starting T /I= siO/1810. 15 min T /I =si0 /1800. 30 min T /I= si0/1790. Re- pressured IA to 1800 psi to repeat one hour test. Starting T /I =si0 /1800. 15 min T /I =si0 /1800. 30 min T /I =si0 /1800. 45 min T /I =si0 /1800. 60 min T /I= si0/1800. Bled IA back to 0 psi and normal up IA jewelry. Final T /I= si0 /0. 07 /04 /121Welded 7' of 16" 62.58# .375 wall conductor pipe onto exsting conductor I 1 I I I 1 I I • • ",,, " , „ s SEAN PARNELL, GOVERNOR LL-J u L U ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Martin Walters Well Integrity Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 iql - Anchorage, AK 99510 ` Re: Kuparuk River Field, West Sak Oil Pool, 1D-117 Sundry Number: 312 -221 Dear Mr. Walters: St,PIANED JUN ,,, 9 2012 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, 1 P-4-e--144--' Cathy . Foerster Chair DATED this b t da y of June, 2012. Encl. • • STATE OF ALASKA RECEIVED AL. OIL AND GAS CONSERVATION COMMI•N APPLICATION FOR SUNDRY APPROVALS JUN 2 012 20 AAC 25.280 AoGC 1. Type of Request: Abandon r Flug for Redrill fl Perforate New Pool r Repair well fl Change pprove Program 17 Suspend fi Plug Perforations fi Perforate r Rill Tubing fi Time Extension fl Operational Shutdown C Re -enter Susp. Well [ Stimulate r Alter casing ri Other:SC Repair p • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development i Exploratory f 197 -237 ` 3. Address: 6. API Number: Stratigraphic r Service J • P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 22844 - 00' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes fi No r 1D , 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0025650 • Kuparuk River Field / West Sak Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5205 4408 ■ Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 121' 121' 1640 630 SURFACE 5150 12 5190' 4393' 6890 4790 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4508 -4870 3712 -4073 3.5 L -80 4413 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER = BAKER ANCHOR TUBING SEAL ASSEMBLY MD = 4413, TVD = 3616 SSSV = CAMCO DS LANDING NIPPLE MD = 497, TVD = 497 12. Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development fi Service r • 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/29/2012 Gil r Gas [ WDSPL r Suspended 17 16. Verbal Approval: Date: WINJ r7, GINJ r WAG [ j Abandoned fi Commission Representative: GSTOR fi SPLUG ri 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Martin Walters / MJ Loveland Printed Name �/ Martin Walters Title: Well Integrity Supervisor Signature /� %' / etil Phone: 659 -7043 Date: 06 /11/12 C• Commission Use Only Sundry Number: 3‘ 2,-2,2_,t 1 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test (' Mechanical Integrity Test [ Location Clearance f Other: Do ry 41-"tY' . Subsequent Form Required: / c .,.. 9 b 4 1 APPROVED BY / (� Approved by: P COMMISSIONER THE COMMISSION Date: - -- / -1------ ' f Z �/ ,L � p , Form 10 -403 Revised 1/2010 ` n � JUf4 1 I r Submit in Du licate ` � eirz 0R1G1N ' A , ;7 • • • Pr" • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 11, 2012 w Commissioner Dan Seamount C� ). Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: Enclosed lease find the 10 -403 Application for Sundry Approvals for ConocoPhillips p Pp rY pp s p Alaska, Inc. well 1D -117, PTD 197 -237 surface casing inspection and repair. Please call MJ Loveland or me at 659 -7043 if you have any questions. /4/4:77 �v Martin Walters ConocoPhillips Well Integrity Projects Supervisor Enclosures • • ConocoPhillips Alaska, Inc. Kuparuk Well 1D -117 (PTD 197 -237) SUNDRY NOTICE 10 -403 APPROVAL REQUEST 06/11/12 This application for Sundry approval for Kuparuk (West Sak) well 1D -117 is for the proactive inspection and repair of the surface casing near surface. This well is a single casing water injection well that was drilled and completed in 1998. During proactive casing inspection work the production casing was discovered to have approximately 42% wall loss. The well is currently shut in and is scheduled to be secured. While the well is secured ConocoPhillips intends to excavate around the well head approximately 10' deep, remove the conductor, and patch the suspected areas on the surface casing. With approval, inspection and possible repair of the production casing will require the following general steps: 1. Ensure the well is secure with a tubing plug. 2. Remove the floor grate, well house, flow lines, and other equipment from around the wellhead. 3. Remove gravel from around well head to an approximate depth of 10' and install shoring. Complete 4. Install nitrogen purge equipment for the conductor (and OA if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection (Complete). Remove the entire exposed conductor if needed. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine if patch or repair is needed to return the casing to operational integrity. 7. If a patch is required, QA /QC will verify t e repair for a,inal integrity check. 8. MIT casing patch. tic, � 14- '' 0-04- 9. Install anti - corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plugs and return the well to injection. 13. File 10 -404 with the AOGCC post repair. Well Integrity Project Supervisor 6/11/2012 ` . KU P 1 D -117 y ' O COnOCOPhiflips Well Attributes Max Angle -& MD TD N'I5ka Inc Wellbore API (UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) c/awcw+,Ileps 500292284400 WESTSAK INJ 50.33 2,675.00 5,205.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV: NIPPLE Last WO: 5/19/2002 41.00 1/2/1998 Well Con89'. -1 0-117, 3/25/2011 3:55'14 PM Schematic - Actual Annotation Depth (111513) End Date Annotation Last Mod ... End Date Last Tag: ELMD_ 4,802.0 4/17/2009 Rev Reason: FORMAT UPDATE Imosbor 3/25/2011 Casing Strings Casin Description String 0... String ID ... Top (11158) Set Depth (1... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15 40 121 121.0 62.58 H WELDED Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 40 SURFACE 75/8 6.750 40.5 5,190.0 4,393.3 29.70 L-80 BTCM -( Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd GRAVEL PACK LINER 4 3.958 4,413.0 4,880.0 4,083.4 Liner Details Top Depth (TVD) Top Intl Nom). -. CONDUCTOR, T op (ftKB) (RKB) (°) Item Description Comment ID (In) 40-121 4,413.0 3,616.5 0.49 PACKER BAKER GRAVEL PAK PACKER SC -1 4.000 NIPPLE, 497 4,421.6 3,625.2 0.53 SLEEVE 80-40 GRAVEL PACK SLIDING SLEEVE 4.700 arasr: 4,424.2 3,627.7 0.54 SBE 80-40 SEAL BORE 4.000 4,441.7 3,645.3 0.63 SAFETY SOS SHEAROUT SAFETY JOINT 3.958 4,508.4 3,711.9 0.95 SCREEN Bakerweld Gravel Pack Screen Size 4.0" X .020" guage X 37 3.958 4,879.5 4,082.9 1.52 PLUG BAKER BULL PLUG 4.000 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) 'Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 I 2.992 I 39.6 I 4,414.0 I 3,617.5 9.30 I L -80 I EUE8rd Completion Details GAS LIFT, Top Depth 4,311 k IIIM. (TVD) Top Ind Nomi. -. Top (ftKB) MB) Item Description Comment ID (In) -0 39.6 39.6 -0.19 HANGER VETCO GRAY TUBING HANGER 3.580 497.2 496.5 7.84 NIPPLE CAMCO DS LANDING NIPPLE 2.812 NIPPLE, 4,355 / r:'. 4,354.7 3,558.2 0.89 NIPPLE CAMCO D NIPPLE 2.750 l 4,393.1 3,596.6 1.20 PBR BAKER 80-40 POLISHED BORE RECEPTACLE 4.000 4,412.8 3,616.3 0.49 SEAL ASSY BAKER ANCHOR TUBING SEAL ASSEMBLY 3. 000 PBR, 4,393 Perforations & Slots _ _ _ Shot Top (TVD) Btm (TVD) Dens Top (R)(B) Btm (RKB) (ftKB) (ftKB) Zone Date (eh ° Type Comment _ 4,508.0 4,879.0 3,711.5 4,082.4 11/3/2000 32.0 Screen Bakerweld Gravel Pack Screen Size SEAL ASSY, _ 4.0" X .020" guage X 37 4,413 �' 4,524.0 4,547.0 3,727.6 3,750.6 WS D, 1D- 117 2/18/1998 4.0 IPERF Zero deg phasing 0 _4 4,524.0 4,554.0 3,727.6 3,757.6 WS D, 10-117 2/22/1998 4.0 IPERF 4,524.0 4,547.0 3,727.6 3,750.6 WS D, 1D -117 11/3/2000 12.0 RPERF 4.5" HSD Frac guns w /43cj UP II RDX IF 4,54 4,554.0 3,750.6 3,757.6 WS D, 10-117 11/3/2000 12.0 APERF 4.5" HSD Frac guns w /43cj UP II RDX 4,588.0 4,608.0 3,791.5 3,811.5 WS B, 1D- 117 2/14/1998 4.0 IPERF Zero deg phasing 4,588.0 4,608.0 3,791.5 3,811.5 WS B, 1D-117 11/3/2000 12.0 RPERF 4.5" HSD Frac guns w /43cj UP II RDX 4,635.0 4,650.0 3,838.5 3,853.5 WS A4, 1D- 117 2/12/1998 4.0 IPERF Zero deg phasing 4,640.0 4,650.0 3,843.5 3,853.5 WS A4, 1D -117 11/3/2000 12.0 RPERF 4.5" HSD Frac guns w /43cj UP II RDX _'�" 4,692.0 4,722.0 3,895.5 3,925.5 WS A3, 1D- 117 2/5/1998 4.0 IPERF 4,746.0 4,776.0 3,949.5 3,979.5 WS A2, 1D -117 1/27/1998 4.0 IPERF Zero deg phasing 4,746.0 4,776.0 3,949.5 3,979.5 WS A2, 1D -117 2/1/1998 4.0 RPERF Zero deg phasing 4,820.0 4,828.0 4,023.4 4,031.4 WS A2, 1D -117 11/3/2000 12.0 APERF 4.5" HSD Frac guns w /43cj UP II RDX RPERF, 4,862.0 4,870.0 4,065.4 4,073.4 WS A1, 1D - 117 11/3/2000 12.0 APERF 4.5" HSD Frac guns w /43cj UP II RDX 4,524-4,547 IPERF, \ 1 4,524-4,547 V Notes:. General Safety IPERF, E Date Annotation 4,524 -4,554 11 /6/199 8 NOTE: Tag inc 4352 APERF, 9 s W 4,54]4,554 10/31/2000 NO TE: Nordic 3 Workover to Gravel Pack completion (10/31 - 11/6/00) 2/24/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 RPERF, Y#'. 4,598 -4,606 IPERF, 4,588-0,608 IPERF, 4,835 -4,650 RPERF, . , 4,640-4,650 Soren, 4,508-4,679 IPERF, 4,892 -4,722 RPERF, 4,74,776 IP 4,746 -4,776 . ' 4620 -4e a ' h �, Mandrel Details Top Depth Top Port APERF, (TVD) Inc! OD Valve Latch Size TRO Run 4,8624,870 Stn Top (ftKB) (11KB) (1 Make Model (in) Sery Type Type (i") (psi) Run Date Corn... 1 4,311.2 3,514.8 1.41 CAMCO KBMM -2 1 GAS LIFT DMY BK 0.000 0.0 5/27/2002 GRAVEL PACK LINER, 4,413 -4,880 SURFACE, 40 -5,190 "\ TO, 5,205 MEMORANDUM To: Jim Regg P.I. Supervisor ~~ ~~~'~~" Fltolvt: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-117 KUPARUK RIV U WSAK 1D-117 Src: Inspector NnN-CnNFIDENTIAL Reviewed By: P.I. Suprv ~'~' Comm Well Name: KUPARUK RIV U WSAK 1D-117 API Well Number: 50-029-22844-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100718140542 Permit Number: 197-237-0 Inspection Date: 7/16/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1D-117 'Type Inj. N - TVD 3617 ~ IA 20 1740 ~ 1630 1620 P.T.D 1972370 ~TypeTest ~ SPT 'rest pSl 1740 ~ QA InterVal4YRTST pn-, P ~ Tubing 550 550 550 550 Notes: I,A~; /~~ fir/ cf -~"~f' = i ~'C~~S ~r,~~'~` i.- Thursday, July 22, 2010 Page 1 of 1 ~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description 3F-03 ANHY-00070 INJECTION PROFILE ' _ 2D-03 ANHY-00075 _ PRODUCTION PROFILE 1E-29 B04C-00030 PRODUCTION PROFILE 3G-13 ANHY-00079 INJECTION PROFILE _ 3F-18 'iD-117 1 D-128 B04C-00031 B14B-00027 AYS4-00057 PRODUCTION PROFILE / INJECTION PROFILE ~._ INJECTION PROFILE iH-21 6146-00028 PRODUCTION PROFILE iD-120 AYS4-00058 INJECTION PROFILE 2K-22 AYS4-00059 IBP/SBHP 1 E-15 1Y-04 AYS4-00061 AYS4-00071 INJECTION PROFILE ~ INJECTION PROFILE 3F-02 AYS4-00063 PRODUCTION PROFILE ~ - 1G-04 B14B-00036 SBHP SURVEY '~. 1 R-03A AYS4-00063 SBHP SURVEY i } -t f _(~~~ ( ` r ~ SC iG-O6 B14B-00035 _ c . SBHP SURVEY ~~ `~~ P ~ ~ 1R-10 2F-02 1R-15 B14B-00031 AYS4-00060 8148-00032 ~~ SBHP SURVEY ~'.~, INJECTION PROFILE v (.+ .- ~~ I SBHPSURVEY~ irr rx<-- tC `l l~q t Date 04/10/09 04/14/09 04/15/09 04/15/09 04/16/09 04/16/09 04/17/09 04/17/09 04/18/09 04/20/09 04/28/09 04/22/09 04/23/09 04/23/09 04/23/09 04/20/09 04/19/09 04/20/09 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Color CD 1 1 1 1 1 1 1 1 1 1 1 1 04/30/09 s • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Suite 100 Anchorage, Alaska 99501 ProActive Diagnostic Services, tnc, Attn: Robert A. Richey 130 West International Airport Road ,., .:,~ i ~ ~ E, ~` ~~~~ Suite C ~~~Y~~ ~V1~i~ ~': Anchorage, AK 99518 Fax: (907) 245-8952 1) 2] Capper Report / M1`f 24Feb-09 1 D~106 1 Report / EOE 50-029-22847-00 -~ ~ T ~!;I RE : Cased Hole/Open Hole/Mechanical Logs and/or - ubing Inspectaon(Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following Caliper Report / MTT 23-Eeb~09 1 D-117 1 Report / EDE i~~i ~' ~' ,, , Signed : ~v~ ' i1 Date : ~~ ~ ~; ~ ~~~`1 Print Name: ~r,;-~~? PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAQE, AK 99518 PHONE: (907)245-8951 Fax: (907245-88952 E-MAIL : ~~s~l~~:~aa~~~a~sret~c~~~~l~~.~~z~ WEBSITE: ~rv,xr,i,>~~:~~~a~'~~,~~s~t ,:~- ;~ t C:\DocomenCs and Settings\OwnalDesktop\Tiansmit Conoco.docx C~ • Memory Caliper & Magnetic Thickness Tool Log Results summary Company: ConocoPhillips Alaska, Ina Weil: 1D-117 Log Date: February 23, 2009 Field: Kuparuk Log No.: 10539 State: Alaska Run NO.: 4 (2"d MIT, 3rd MTT) API No.: 50-029-22844-00 Pipet Desc.: 3.5" 9.3 Ib L-80 EUE 8RD Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvl.: 4,414 Ft. (MD) Pipet Desc.: 7.625" 29.7 Ib L-80 BTCM Top Log Intvl.: Surface Pipet Use: Surface Casing Bot. Log Intvl.: 212 Ft. (MD) Pipe3 Desc.: 16" 62.58 Ib. H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS The caliper ksg is tied Into the tubing tai/ @ 4,414' (Driller's Depth), while the M7T data is tied into the Mandril Hanger @ 0' Depth. This is the second time this well has been logged with a PDS caliper and the third time with the 12 Arm Magnetic Thickness Tool (MTT}. The Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing, 7.625" surface casing and 16" conductor pipe. Passes at SHz, 8Hz, 10Hz and 12Hz were made at 20 fpm. While making passes at 5Hz and 10Hz, the wire line operator began logging down a little early, resulting in the loss of data for the top -35' of the well bore for these passes. As a result, the 8Hz pass has been selected for analysis and comparison to previous logs in this report. Due to the concentric pipe strings in the log interval, the MTT response is qualitative -indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. INTERPRETATION OF CALIPER LOG RESULTS This iog was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damage and to identify buckling throughout the interval logged. The caliper recordings indicate that the 3.5" tubing appears to be in good to poor condition, with a maximum penetration of 59% recorded in a line of pits in joint 77 (2,451'). Recorded damage appears in the form of isolated pitting, often in a tine, and shaAow corrosion. No significant areas of cross-sectional wall loss or I.D. restrictions are recerded. The caliper recordings indicate slight buckling from surface to -1,600', with moderate budding recorded from1,600' #o _4,300'. A 3-D log plot of the caliper recordings across an interval of slight buckling from surface to 1,000' is included in this report. This is the second time a PDS Caliper has been run in this well and the tubing logged. A comparison between the current and previous log (July 30, 2005) indicates an increase in corrosive damage during the time between logs. A graph illustrating the difference in maximum recorded penetrations on a joint-by joint basis between logs is included in this report. i, ~ 3.5" TUBING -MAXIMUM RECORDED WALL PENETRATIONS: Line of Pits (59%) Jt. 77 @ 2,451 Ft. (MD) Line of Pits (54%) Jt. 78 @ 2,471 Ft. (MD) Line of Pits (54%j Jt. 96 C~ 3,045 Ft. (MDj ProActive Diagnostic Services, Inc. / P.rJ. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281} 565-1369 E-mail; PDSCg~memarylog.com Prudhoe Bay Field Office Phone: 0507} 659-2307 Fax: (907) 659-2314 Line of Pits (52°~) Jt. 69 @ 2,178 Ft. (MDj ' Isolated pitting (50%) Jt. 44 @ 1,409 Ft. (MD) 3.5" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: ' No significant areas of cross-sectional wall loss (> 6%) are recorded. 3.5" TUBING -MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. res#rictions are recorded. ' GOMPARISORI TO PREVIOUS MTT LOG RESULTS A comparison between the current log and the previous log (October 6, 2007) indicates a slight decrease in overall metal volume over the interval from 6' to 58' as recorded by the MTT. The difference ranges from about 0°!° to 3% loss of total metal volume over this interval. A log plot overlay of the average metal thicknesses recorded by the MTT for the curren# and previous logs (December 9, 2006 and October 6, 2007) is included in this report. In the 2007 and 2006 logs, calibration samples were only taken within the concentric pipe that included the conductor. As a result, calculated metal thickness below the conductor appears to show metal loss due to the absence of the extra metal from the conductor pipe. The current log includes an additions! calibration ^ applied below the conductor, so the calculated metal thickness no longer reflects a loss due to the absence of the conductor. Critical analysis of the current log passes, including the 5Hz pass, indicate that the bottom of the conductor is at 81', rather than at 112', as indicated in the previous logs. The caliper indicates that the top three tubing joints have a slightly smaller ID than the remainder of the tubing, which supports the probability of slightly thicker wall in the top three tubing joints. The MTT's response to this change in tubing thickness (less thick below Jt. 3 G~ 112') appears similar to its response to the bottom of the conductor at recording frequencies of 8Hz, 10Hz and 12Hz. However, the 5Hz MTT pass recorded in the current logging operation clearly indicates the end of the conductor at 81' (at the top of tubing Jt. 3, rather than the bottom of tubing Jt. 3}. INTERPRETATION OF MTT LOG RESULTS The 8Hz MTT log results cover the interval from surface to 212'. Changes in metal volume are relative to the calibration points at 68' and 148', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points. A log plot of the 8Hz MTT pass is included in this report. An indication of 16% overall metal loss is indicated just below the mandrel hanger in this tog -the same as in ~ the previous two logs. A similar MTT response just below the mandrel hanger in the 1C-178 well was I ~ confirmed to be signal inversion due to the high metal content of the hanger This area will continue to be monitored, but this toot response just below the hanger is not suspected to be due to pipe damage. Other intervals of overall metal loss are indicated in the 8Hz pass as follows: ' 10' - 11' 2% to 4% arcumferenciat metal loss, no significant isolated pits indicated 1T significant isolated metal loss indicated in current and previous {ogs 1 31' significant isolated metal toss indicated in current and previous logs 33' - 57' 2°r6 to 4% arcumferencial metal loss indicated, though masked by tubing collars at 35', 45' and 50', and a casing collar at 48'. 39' - 45' Group of several significant isolated metal loss events indicated in both current and previous logs. ProActive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax; (281) 565-1369 E-mail; PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~ ~ The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5", 7.625" and 16" pipe. If ail of the metal Toss is specific to the 7.625" surface casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conduckor. Field Engineer. G. Etherton Analyst: C. Waldrop (MI'n, HY. Yang (MT'T) & J. Burton Witness: C. Kennedy ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDSramemorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907; 659-2314 ~ • PDS Multifinger Caliper 3D Log Plot ~ ~~ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1 D-117 Date : February 23, 2009 1 Description : Detail of Caliper Recordings Across Interval of Slight Buckling from Surface to 1000' Depth Max ID (1/1000 in.) (Off enter) Image Map (Centered) Image Map ft:750R 2500 3500 0° 90' 180° 270° 0° 0° 90° 180° 270° 0° Min ID (1/1000 in.) 2500 3500 Nominal ID (1/1000 in.) 2500 3500 ^ • Ni le DS pp - Joint 15 Slight Buckling 500 Joint 16 _ .~"t'~`° Slight Buckling - a 550 t Joint 17 Joint 18 - Slight Buckling 600 Joint 19 Sli ht Bucklin - _ „~,;;~. g g .., _ .~T.,v_ s. Joint 20 650 Joint 21 , 4 700 ~ ~,_ Joint 22 `"""~ Slight Buckling ~-= Joint 23 _ "~ __,_, -, 750 ~~~- Joint 24 ~ ! .. t 25 J i 800 - --- o n - ~ ~__ Joint 26 __ ' Slight Buckling _ -_ ~ ~ , _ ~~W~ 850 ~ _ - __ ; v~ Joint 27 - ~ ,._... ,. int 2s J y~ o Slight Buckling 900 _ t 29 J i n o Slight Buckling _. ~ _- ; 950 - Joint 30 _ ~ ~-; -~ - -~_}- g _ _ J i t 31 ': -- - n o ~- - - -~ Nominal ID (1/1000 in.) 2500 3500 Min ID (1/1000 in.) 2500 3500 Comments Depth Max ID (1/1000 in.) (OTf-Center) Image Map (Centered) Image Map T 1ft:750ft~2~ 3500 0° 90° 180° 270° 0° 0' 90° 180° 270° 0° i • i `~ Well: 1D-117 Field: Kuparuk Company. ConocoPhillips Alaska, Inc. Country: USA Maximum Recorded Penetration Comparison To Previous Survey Date: February 23, 2009 Prev. Date: July 30, 2005 Tool: UW MFC 24 No. 218183 Tubing: 3.5' 9.31b L80 Overlay M 0 5 ax. Rec. Pen. (mil 0 100 1 s) 50 2 U0 0.1 8 17 27 37 47 57 E 67 0 z 77 3 87 97 107 117 127 136.1 138.5 ^ February 23, 2009 ~ July 30, 2005 Difference -1 D 00 -5 ill. in Maz 0 . Pen. (mil 0 5 s) 0 1 00 a E a z e 'S -2 8 -1 4 0 1 4 2 8 Appr ox. Co~eos ion Rate ( mpy) 8 17 27 37 47 57 67 77 87 97 107 T17 -1-2? 136.1 ~ Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (23.8' -4413.9') Well: 1 D-117 Field: Kuparuk Company: ConocoPhillips Alaska, Inc Country: USA Survey Date: February 23, 2009 ^ Approx. Tool Deviation ^ Approx. Borehole Profile 28 325 640 948 1260 1574 1888 2201 ~ 2516 .c s Y 2829 v 3142 3455 3770 4083 GLM 1 138.5 4414 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 138.5 1 10 20 i0 40 50 60 70 rv .n ~ 80 Z Y , .O cjU r 100 110 , 120 130 u PDS Report Overview ~~, ~.. Body Region Analysis Well: 1 D-117 Survey Date: February 23, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country; USA No. of f=angers: 24 Anal st C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower (en. 3.5 ins 9.3 f L-80 2.992 ins 3.756 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body r~ metal loss body 150 100 50 0 0 to 1 to 10 to 1% 10% 20% 20 to 40 ro over 40% 85% 85% Number of ~oints anal e d total = 144 pene. 0 30 29 loss 34 110 0 65 20 0 0 0 0 Damage Configuration (body ) 80 - 6O 4U 20 0 isolated general line ring hole /pons pitting corrosion corrosion corroaon able hole Number of 'oints dama ed total = 86 75 11 0 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 n GLM 1 Bottom of Survey = 138.5 Analysis Overview page 2 ~ i PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 D-117 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 23, 2009 Joint No. Jt. Depth (Ft.) Nc~n. Uls~~t (In..) Pen. Body (Ins.) Pe°n. % M~~t.,l I ~,~. . Min. LU• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 24 tt 0.01 5 ~ ~ .90 PUP 1 28 tt 0.03 12 s 2.93 1.1 59 t1 0.0 9 U 2.90 P P 1.2 9 t' 0.03 1 t) U 2. 1 UP 2 73 U 9 ~ .94 Sli ht6 cklin . 3 1 5 U .03 12 2.91 4 36 t) 0.03 1I i~ 2.92 168 O 0.0 ti 2 9 6 199 tl .0 9 1 2 7 231 tt 0. 2 9 I 2.92 8 262 U 0.02 7 I .9 li ht B cklin . 9 294 t) 0.02 7 .9 10 325 t ~ 0.02 t3 1 2.9 11 3 7 it 0.0 ~~ Z .93 Sli ht Bucklin . 1 388 a 0.01 6 Z .9 Sli ht Buckli 13 420 tl 0.0 9 2.9 14 451 U 0.03 11 ~' 2.92 141 481 t1 0 U It 2.81 r c Landin Ni le 1 48 tt 0.01 1 I .93 li t c in . 16 1 U 0.02 ~) 2 .94 Sli t u' 17 546 c I 0.01 ~~ 2.94 18 577 a 0. 3 l U I 2.9 S i ht Bucklin 19 609 tt 0.01 5 I 2 93 SI' h Bucklin . 20 640 l) 0.03 1 t~ 1 2.91 670 l) t I 3 22 701 tl 0.02 tt a 2.93 Sli ht Bucklin . 3 733 t l 0 03 1 u .92 24 762 t ~ 0.03 1 U _' 2.93 5 79 t ~ 0.03 1:3 .9 26 825 i~ 0.02 7 U 2.93 Sli ht Bucklin . 856 i ~ 0.02 7 I 2.93 28 887 i ~ 0.04 14 I 2.94 Sli fit Bucklin . 9 919 a .03 1 1 _' 2.91 Sli ht Bucklin . 30 948 U 0.02 ~~ .92 31 979 U 0.02 ~~ I 2.93 32 1010 ll 0.04 1 7 2.92 Sli ht Bucklin . 1042 U 0.03 I ~' 2.91 Sli ht Bu kin 34 1072 t t 0.0 ti 2.94 3 1103 tt 0.04 17 I .93 36 1135 tl 0.04 17 I 2.93 37 1166 tl 002 ~) 2.94 li ht ckl'n . 38 1198 U 0.07 Z(~ I 2.93 Sli ht Bucklin .Isolate it6n . 39 1 29 a .03 1 ~ 2.9 40 1260 t1 0.06 Z3 I 2.93 Isolated ittin . 41 1 91 i I .12 46 i 2. 3 Is lat d ittin . 42 1323 ~? 0.04 1(~ 1 2.93 4 13 4 u 0. 7 27 _' 2.93 li ht Bucklin Is la ed ittin . 44 1386 ti 0.13 5O 3 2.93 Isolated ittin . 45 1417 l) 07 27 1 2. 3 Is fated ~ittin . 46 1449 tl 0.04 17 1 2.90 Sli ht Bucklin . Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf L-80 Well: 1 D-117 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 23, 2009 Joint No. Jt. Depth (Ft.) I'~~n. UI,«~i (Irn.1 Pen. Body (Ins.) Pen. %~ ~~1c~t.il Iutis ~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 47 1479 I~ 0.09 X34 .93 Sli ht ucklin Is lated itti 48 1 11 ~~ 0.0 ti I 2.93 9 154 t ~ 0.05 ~' ~) 2.93 50 1574 ~~ 0.06 ~'_' 2.93 ucklin .Isolated ittin . 1 1606 tl 0.10 s~1 _' 2.94 ucklin Isolated itti 52 1637 ) 0.0 1 £i 1 2.93 53 1669 t) 0.10 4l) .' 2.94 Line of its. 54 1700 l) .07 ~sO 2.93 Line of its. 732 U .09 30 ~' 2.94 Line of its. 56 1763 U 0.0 >"~ ? 2.95 Bu klin . Li e of its. 57 1795 O 0.10 -1O 4 2. 4 Bu klin ine of its. 1826 (~ 0.07 ~~ Z 2.92 ine of its 59 1 56 l1 0.08 31 _' 3 Line of its. 60 1888 ~~ 0.09 36 _' 2.93 'ne of its 61 1920 ~) 0.07 ' 7 ' .93 Bucklin 'n of i 62 19 0 i) 0.08 ~i2 2 2.93 Bucklin .Line of its. 63 19$1 ~) 0.08 ~ I 2 2.9 Line of its. 64 01 U 0.07 2E~ 3 2 3 ine f 'ts. 65 204 i) 0.07 2(~ ; .94 ucklin .Line f its. 6 2076 ~) 0. 7 ~'~i ~ .92 ine of its. 67 1 u 0.11 -14 -t .94 ine of i 68 2138 ~~ 0.10 -t1 4 2.92 Line of its. 6 2169 t) 0.1 5~' -1 2.9 Bucklin 'ne of i JO 2201 l) 0.10 3~) t 2.94 Bucklin .Line of its. 71 2 U 0 24 .' 2.9 i e f its. 72 2264 ~~ 0.07 2£3 ? 2.93 Line of its. 73 2 9 O 0.06 24 Z 2.91 in of i 74 2327 0 0.04 17 I 2.93 Bucklin . 75 2358 U 0.0 ?~) 2.93 76 2390 U 0.08 ~~ 2.94 Line of its. 77 2421 O 0.15 5~) -4 2.94 Line of its. 78 2453 ~).e~; 0.14 54 ~ 2.96 Bucklin .Line of ~ts. 79 2484 ~> 0.07 2F~ ~' 2.94 Bucklin Line of its. 80 2516 O 0.07 2£i ~ 2.95 Line of its. 81 2547 O 0.09 S7 ~' 2.92 Line of its. 8 2579 U 0.06 24 1 2.92 Line of its. 83 611 a 0. 5 10 ? 2.90 84 2642 t) 0.07 ~'~> 2.93 Bucklin .Line of its. 85 267 ~~ 0.05 11) 2.91 B cklin . 86 2704 U 0.10 ~i~) Z 2.44 Line of its. 87 2736 U 0.06 l5 ' 2.92 L'n f its. 88 2767 U 0.10 39 ? 2.93 Line of its. 89 798 t~ 0.10 3£3 ~' .9 Bu klin i e of its 90 2829 U 0.08 31 ? 2.92 Bucklin .Line of its. 91 286 l) 0.09 35 _' .93 Buckl~n ine f 92 2891 O 0.10 39 2.93 Line of its. 93 2923 ~~ 0.03 1 i I .93 94 2954 U 0.04 17 I 2.92 95 29 ~~ 0.09 35 _' 2.94 Bucklin .Line of its. 96 3016 ~~ 0.14 54 ~1 2.92 Bucklin =. Line of its. Penetration Body Metal Loss Body Page 2 ! • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 D-1 17 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 23, 2009 Joint No. Jt. Depth (Ft.) I'~~n. UI>~f~t (In~.i Pen. Body (Ins.) Pen. % a1~~i,il I<s ,~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 97 3048 lI 0.0 15 _' 2.94 98 3 79 l) 0.10 39 .9 'n f i 99 3111 t) 0.05 1 ~) I 2.93 100 3142 l1 0.0 I i .93 10 3174 t~.t)5 0.0 li I 2.94 B klin .Line of its. 1 2 2 U 0.11 45 2.94 ine of its. 103 3235 a 0.04 16 2.93 104 3 66 l1 0.05 Z I _' 2.92 'n of i 1 5 298 U 0.09 34 _' 2 3 u lin .Lie f its. 106 33 t~ 0.0 ~'_' ? 2.94 ucklin ine of 'ts. 1 7 3361 U 0.11 44 ~ 2.94 ine f i 108 339 U .11 41 4 2 93 Line f its. 109 342 U 0.03 1 S .93 Bu klin . 110 3455 t ~ 0 05 1 ~) I 2.92 Bucklin . 111 3487 a 0. 8 3(1 ~' 2.93 Line of its 11 3518 a 0.10 iti 2 96 Isolated ittin . 113 35 0 u 0.08 3.3 ~~ 2.92 Isolated ittin . 114 3581 U 0.11 4 i 3 2.96 Is lated itti 1 5 3 13 t) .08 31 ~ 2.92 B ckli Corrosio 11 3644 ).U(~ 0. 8 3O 3 2. 3 solated ittin . 1 7 3 76 U 0.10 41 t 2.93 Isolated ittin . 118 3707 t~ 0.09 34 -1 2.9 Isolat ittin . 119 3738 U 0.08 ~ 3 2.93 I I ted ittin . 120 3770 a 0.10 41 !~ 2.95 Bucklin .Corrosion. 121 801 (~ 0.10 3 9 -l .94 I I t i 122 3832 tI 0.11 4Z 2.94 Isolated ittin . 1 3 3864 a 0.08 .3 3 _' 2.9 Bu (in Corros~on. 124 3894 U 0.07 29 2.94 Bucklin .Corrosion. 125 925 l) 0.09 36 ~ .94 I of to i tin . 126 3956 t) 0.11 45 4 2.94 Isolated ittin . 127 398 t) 0 08 33 i 2.9 I late itti 12$ 4020 tl 0.08 ~3"3 4 2.92 Corrosion. 129 4051 (~ 0.09 36 2.94 Bucklin orrosio . 130 4083 (~ 0.10 3`) ~! 2.95 Corrosion. 131 4114 t~ 0.08 ~' _' 2.9 ucklin .Isolated itti 132 4145 ~~ 0.10 41 2.94 Bucklin I o ated "ttin . 133 177 a 0. 7 27 4 .94 Corr sion. 134 4208 U 0.09 3b 2.91 Isola ed itti 135 4240 l~ 0.11 4' -1 2.91 B cklin Is I ted ittin . 136 4270 (t.U~> 0.07 2~) ~ 2.94 Bucklin .Isolated ittin . 6.1 302 U 0.0 14 I 2.88 PUP Cor sion. 136.2 4308 i t 0 u t t N A GLM 1 Latch ~ 7:30 136.3 4 14 ~ ~ 0.06 24 2 90 PUP orros on. 137 4320 tI 0.12 4~) .' 2.94 Isolated ittin . 137.1 4 1 U 0 U lI .75 C me Ni le 138 4353 n 0.12 4~) 4 2.96 Corrosion. 138.1 4384 11 0.0 i4 a 2.91 PUP 1 olate ittin . 138.2 4390 U 0 0 i~ 4.00 PBR 138.3 4403 U 0 tI ~? N A P cker 138.4 4406 ~ I 0 ~) i ~ 3.00 Seal Assembl _ Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 D•117 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 23, 2009 Joint Jt. Depth I'~~n. Pen. Pc~n. ~Ic~~,~l Min. Damage Profile No. (Ft.) I lls~~t Body % I oss LD• Comments (%wall) 11n~.) (Ins.) `;~ (Ins.) 0 50 100 1 8.5 4414 u 0 0 (1 2. 9 L _ Penetration Body Metal Loss Body Page 4 ~r ~ ~ ~ r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~^r ~ r PDS Report Cross Sections ~~~~. ~~ „ Well: 1 D-117 Survey Date: February 23, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc Tool Size: 1.69 Country: USA No. of Fingers: 24 Tuhing; _ 3.5 ins 9.3_ppf_ l_-80__ ___ ___ ___ _ __ Analyst: _ C. Waldrop Cross Section for Joint 77 at depth 2451.07 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 96 °~ Tool deviation = 52 ° Finger 23 Penetration = 0.15 ins Line of pits 0.15 ins = 59% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 ~c~ PDS Report Cross Sections ~u Well: 1D-117 Survey Date: February 23, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA ~ti'o. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 Anal st: C. Waldro Cross Section for Joint 78 at depth 2471.15 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 96 Tool deviation = 47 ° Finger 2 Penetration = 0.138 ins Line of pits 0.14 ins = 54% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ~, Comparison to Previous ~ Logs Qverlay February 23, 2009, October 6, 2007 and December 9, 2006 PnnAc~tve Dlwgnosiic Sewvlcs„ Inc. Database File: d:lwarriorldatal1d-1171comp 8hz.db Dataset Pathname: merge1 Presentation Format: 24COMP--1 Dataset Creation: Sun Mar 01 10:12:3 2009 Charted by: Depth in Feet scaled 1:150 -40 Delta Metal Thickness 2007 (10 Hz) (%) 40 -40 Delta Metal Thickness 2006 (10 Hz) (%) 40 -40 Delta Metal Thickness 2009 (8Hz) (%) 40 0 20 40 60 Metal Metal Thickness 80 I I 1 1 I I I 3ottom of 16" Conductor • 100 120 140 Metal Thickness 160 180 Thickness ~~ Delta Metal Thickness -40 Delta Metal Thickness 2007 (10 Hz) (%) 40 ' 1 D-~7 Recorded Magnetic Thickr~s Log Data - 8Hz Pass (Surface to 212') February 23, 2009 ~G7rVE a1-Q/InSi~G $EIIVIC6~ ENG. Database File: 80'conductor 1d-117.db ' Dataset Pathname: 8HzPass.1 Presentation Format: 2 scale Dataset Creation: Wed Feb 2517:49:00 2009 by Calc Warrior 7.0 STD Cas Charted by: Depth in Feet scaled 1:150 ' -50 Delta Metal Thickness (%) 50 2 0 Line Speed (ft/min) -200 -6.8 ~-~-~ - ~ I Tree - '-'3 5" Collar ~ - _ - Line Speed Hanger "" ' ~}-1G%° Metal Loss ossib e nvErte~:_I ~._u ~ ~1_ ' 3.5" Collar - - -{- _11-_4% Metal Loss - ---__ i-- Jt. 1 20 elta Metal Thickness __i ___ . ' ~.~ __ - - _ . - 3.5" Col la _ _ _~. _ _ .~ ~ Isolated Metal ' ~_ _ 3.5" Collar Pup Jt. 7.625" Colla Pu - ~~ 3.5" Collar 4% Metal Lass ' Jt. 2 I, I ~ .- - I ~ -.-~ .. _ t _ ... - - ~i -- . ' -- Bottom of 16" Conductor 3.5" Collar .625" Collar ~ - c - -- - 1 ~ ~--- - -- - -- --- -- =~ ,, - MTTP01 (rad) 1 MTTP12 (rad) 3. solated Metal solated Metal Metal Metal Jt. 3 _3.5" Collar 120 7.625" Colla ~~ 4 140 3.5" Collar Jt. 5 160 .625" Collar Colla 180 ~_.~~ Jt.6 ~ Metal Thickness 200 3.5" Colla -50 Delta Metal Thickness (%} 50 2 MTTP01 (rad) 12 0 Line Speed (ft/min) -200 -6.8 MTTP12 (rad) 3.2 KRU 1 D-117 ~~ ConocoPhillips Alaska, Inc. s r- • ~~~ ~~~~~..~ ESP TUBING DETAIL TTCESPCP/Heat Trace wet.t :1U-~~~ DATE: 11105/00 PHILLIPS Alaska, Inc. 1 ot= 1 PAGES # ITEMS CCIMPLi=TE DESG12lPTIQId OF EQl11PMENT Rt.iN LENGTH dEPTH Centrilift TOPS 1 Flat Bands 36 Single channel cross coupling clamps 1 Dual channel end shoe clamps 73 Dual channel cross cou ling Gamps 2 3` Mid joint dual channel clamps 7 4' Mid joint dual channel clamps 359 5' Mid joint dual channel clamps RAYCHEM 1 Band RtG FLOOR TO LDS- Parker 245 33.12 HGR ABB Vetca Grey Tubing Han er W13'- 3-112" L-80 pup 3.92 33.12 Space out Pups as Required (10.07') 10,07 37.04 jt # 3-136 3-1t2", 9.3# L-80 Eue $ rd A&Mod Tbq 41$7.42 47.11 3"112", 9.3# L-80 Eue $ rd AB-Mod Tbg t3.19 4234.53 3-112" x 1" Camco KBMM GL~JI W- Llpen pot,kef 6.75 4242.72 3-112", 9.3# L-80 Eue 8 rd AB-Mod Tb 5.83 4249.47 Jt # i-2 3-112". 9.3# L-80 Eue 8 rd AB-Mod Tbg 62.82 4255.10 4317.92 3-112" Eue 8 rd At3-Mod Handing Pup 3.54" dD, 2.992" iD 10.00 4317.92 3-112" Eus 8 rd AB-Mad Handing Pup 3.50" QD, 2.992" iD 10.10 4327.92 3-1/2" Slotted Nipple 3.50" QD, 2.992" ID 3.00 433$.02 3-112" Tubing TTC Crossover 3.50" OD, 2.992" 1C1 1.40 4341.02 ESP Tandem Seal Section GST3 4t3 IL H6 PFS S.i3" OD 13.80 4342.42 ESP Gear box 9:1 525 Series 5,25" OD 1.30 4356.22 f`5P PGESP Motor 57 HP 1315126 KMH 5.562" OD 8.80 4357.62 Motor centralizer 6.25" OD .50 4364.32 4364.82 Note: Top of 5cn3sns {~ 4413' Noce: Raychem Neat Tcatx attached ~ Thread end of joint tt 54 5' up Note: BOT sensor t;augs attached io joent II9 4398' Mi? 3922' TVn Note: Circulating valve Installed to 3-1t2" Camco valve after rig morel tda#e: Joint #1 famished CentrHift, Remarks: String Weitlhts wi#h Blocks- 75K# Up, 50K# Dn, 23K# Blocic~. Ran 136 joints of tubin g. -- - __ ©rifted tubing & hanger with 2.867" plastic rabbit. Used Arctic ra s ~ o a ea rea camoound on all connections. 7ub~0 is nc~n-coated. _ Atl tubing Is nev~I __ Nordic Rig #3 ©riNing Superv/sar' Donald L. !`ester _ f/I!~LL L~~ ,~ .JJ. 1'I~~4NSl'1~/fTT~4L -- - }: ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following RE : Cased Hole/Open Hoie/Mechanical Logs and/or Tubing fnspection(Caliper/ MTn BP Exploration (Alaskaj, Inc. Petrotechnical Data Center Attn: Andy Farmer LR2-1 900 E. Benson Bhid. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Ro4aert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8951 1) 2) Signed NITT 07~ct-07 IV1TT 06-0ctd7 t~~ ~-~~ ~a 2007 (.~~ tam - a3~- v~.C goT- fa~f 10-111 1 Report 1D~117 l,. 50.029-2302900 1 Report 50-0292284400 Date . ~~~ 3`;,,3; ~ _ „ `' Prynt Name: PROACTIVE DIAGNOSTIC SERVICES, WC., 138 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8861 Fax: (807)245-88852 E-MAIL: ~~s~~cv~~r~~eCc~rl~ers3®rJ~mc~.a~•rh WEBSRE: ~rau~u.rr~;~:~r°;r~ca~.~~rs D:VHaAer Copy_00_PDSANC-20xx\Z_Wotd\Disrnbution\Ttaz~smitlal_Stieels\Tru~t Otiginal New.doc Memory Magnetic Thickness Tool Log Resins summary Company: __ CanacoPhillips Alaska, inc. _ _ Well: _ _ 1D-117 Log Date: October 6, 2007 Field: Kuparuk Log No.: 8639 State: Alaska Run No.: 2 API No,: 50-029-22844-00 Pipet Dese.: 3.5" 9.31b L-80 EUE 8RD Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvl.: 194 Ft. (MD) Pipet Desc.: 7.625" 29.71b L-80 BTCM Top Log tMv1.: Surface Pipet Use: Surface Casing Bot. Log Intvl.: 194 Ft. (MD} Pipe3 Desc.: 16" 62.58 Ib. H-40 Welded Top Log Intvl.: Surface Pipe3 Use:_ Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD) Inspection Type : Assess iFxternal Corrosive Damage (Metal Loss] to Surface Casing. COMMENTS This 16/TT data is tied into the Altandrel Hanger ~ 0' Depth. This is the second lag of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tao! responds to the total thickness of metal of the 3.5" tubing and 7.625" surface casing, with some influence from the 16" conductor pipe. Due to the concentric pipe strings in the log interval, the MTT response is qualitative -indicating an overall increase or decrease in meta! surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (70'), where the readings are assumed to represent undamaged tubing and casing. Afl other readings are relative to this reference point, which include influences from ate 3.5" tubing, 7.625" casing, and 16" conductor pipe. COMPARISON TO PREVIOUS MTT LOG RESULTS : A comparison between the current log and the previous (December 9, 2006) indicates no significant change in metal lass as recorded by the MTT. A log plot overlay of the average metal thicknesses recorded by the MTT for the current and previous log is included in this report. INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval from surface to 194'. A log plot of the entire pass, plus a detailed section ofi any interval showing damage is included in this report. The Delta Metal Thickness (%} curve in these plots refers to total metal surrounding the MT7' tool. A maximum of 16% circumferential metal Ices is recorded just below the mandrel hanger in the interval between 0' - 2'. A 3% circumferential metal loss is recorded in the interval between 10' -11.5'. Three noteworthy isolated metal loss events are recorded at 5', 17' and 31'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5", 7.625" and 16" pipe. If all of the meta{ loss is specific to the 7.625" surface casing, the percent metal toss from that pipe atone ~ probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. Field Engineer: K. MIIIer Analyst: M. Lawrence & J. Burton Witness: C. Kennedy ProActive Diagnostic Services, Inc. / P.O. box 1369, Stafford, TX 77491 Phone: (281) or (888) 565-9Q85 Fax: {281) 565-1369 E-mail: PDS@memoryloq.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 V ~,(~ ~~~ - ~~- Comparison to Previous MTT Log Overlay ~~ ~~~ Ste, ~ October 6, 2007 and December 9, 2006 Database File: d:lwarriorldatal1d-1171comp.db Dataset Pathname: merge2 Presentation Format: 24COMP--1 Dataset Creation: Wed Oct 1010:30:'' 2007 Charted by: Depth in Feet scaled 1:150 -50Delta Metal Thickness 2007 (%} 50 -50Delta Metal Thickness 2006 (%) 50 0 10 20 30 40 50 60 70 80 90 Magnetic Thickness Tool {10 Hz Pass} ~~ o~~ ~~~ ~~ October 6, 2007 Database File: d:\warriorldatal1d-11711d-117.db Dataset Pathname: 10hz.1 Presentation Format: 2.4 scale Dataset Creation: Tue Oct 09 09:44:01 2007 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (%) 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (ft/min) -200 -6.4 MTTP12 (rad) 3.6 5" Collar 6% Metal Loss ~~ ~ Pup Jt. r- , ~?- ~-~ 10 3.5'• Isolated Metal i Jt. 1 20 30 5" Collar ~7. t.5" ClIollarlI ~f~l 7.625" Ct 60 3.5" Jt. 2 70 90 3.5" Metal Magnetic Thickness Tool (10 Hz Pass} October 6, 2007 Database File: d:lwarriorldatal1d-11711d-117.db Dataset Pathname: 10hz.1 Presentation Format: 2.4 scale Dataset Creation: Tue Oct 09 09:44:01 2007 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1:50 -50 Delta Metal Thickness (%) 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (ft/min) -200 -6.4 MTTP12 (rad) 3.6 Tree I I 1 ~ ~ 3.5" Collar Hanger i i ~ ~ ~ :~ 16% Metal Loss Pup Jt. 3.5" Colla 3% 10 3.5" Jt. 1 20 Isolated Metal Loss ConocoPhillips Alaska, Inc. KRU 1 D-117 ~ o-~» - API: 500292284400 Well T INJ An le TS: d TUBING SSSV T ®: Ni a Ori Com lotion: 1/2/1998 An le TD: 1 d 5205 (0-a41a, Annular Fluid: Last W/O: 5/19/2002 Rev Reason: TAG FLL 003.500, Reference L Ref L Date: Last U ate: 5/19/2007 102.992) Last Ta : 8645' RKB TD: 5205 ftKB Last Ts Date: 5/92007 Max Hole An le: 50 2816 suRFace C i Stri -ALL TRINGS (Db190, i do Si a To Grode Three 00.7.625, VJt29 70 CONDUCTOR 16.000 0 121 121 62.58 H-40 WELDED . ) NIP 98 499 SURFACE 7.625 0 5190 4393 29.70 L-80 BTCM . (4 , OD_4 500) PROD LINER 4.000 4413 4880 4083 11.50 L-80 SLHT _ Turin Strin -TUBING Size T Bottom ND Wt Grade T r d 3.500 0 4414 3617 9.30 L-80 EUE 8RD Perforations Summa Interval T Zons Status Ft S F Dete T e Comment cas Lill -l 4524 - 4547 3727 - 3750 WS D 23 20 11/32000 RPERF 4.5" HSD Frac guns w/43cj UP II RDX ~ ndrellDummy Vatye 1 (4311-4312 _ ^ 4547 -4554 3750 - 3757 W S D 7 16 11!32000 RPERF 4.5" HSD Frac guns w/43cj LIP II RDX , 00:5.390) 4586 - 4608 3791 -3811 WS 8 20 16 11/3Y,2000 RPERF 4.5" HSD Froc guns w/43cj UP II RDX _~" 4635 -4640 3838 -3843 WS A4 5 4 2/12/1998 IP RF Zero d hasin 4640 -4650 3843 -3853 W S A4 10 16 11/32000 RPERF 4.5" HSD Frac guns wl43cj L~ II RDX 4692 - 4722 3895 -3925 W S A3 30 4 2/5/1998 IPERF 4746 - 4776 3949 -3979 WS A2 30 8 2/1/1996 RPERF Zero d esin NIP 4820 -4828 4023 -4031 W S A2 8 12 11/32000 RPERF 4.5" HSD Frac guns w/43cj UP II RDX (4356-4356, 00:4.520) 4862 - 4870 4065 - 4073 W S Al 8 12 11!32000 RPERF 4.5" HSD Frac guns w/43cj UP II RDX Gas Lift M a drelsNah-es St MD ND Men Mfr Men Type V Mfr V Type V Op Latch Port TRO Date Run Vlv Cmn 1 4311 3514 Camco KBMM-2 DMY 1.0 BK 0.000 0 5272002 1 ? ~9DOtt Shear Out Other lu ui .etc. -JEWELRY D th TVD T •ecrl tion I 498 497 NIP CAMCO DS LANDING NIPPLE 2.812 PBR 4355 3558 NIP CAMCO D NIPPLE 2.750 (~9~~• 4393 3596 PBR BAKER POLISHED BORE RECEPTABLE 80-40 4.000 00:5.900) 4412 3615 SEAL BAKER ANCHOR TUBING SEAL ASSEMBLY E22 80-40 3.000 4413 3616 PACKER BAKER SC-1 PACKER left in lace from revious WO 110' above ib rfs 0.000 4414 3617 TTL 2.992 Gener al No Date No 11!6/1 998 NOTE: Ta s line 4352' 10!31/2 000 NOTE: Nordic 3 Workover to Grovel Padc m lotion 10/31 - 11/6/00 SFJ1L (4412-4413, 00:5.OfX1) PACKER (44134414, 00:6.750) Pert (4588-4808) Pert (asas•asos) Pert (~~) Pert (~~) Pert (assz-4722> Pert (a7ae;.ans} Perf (47484776) Psrt 48204828 ( ) Pert (4862-4870} . . ~ ConocoPhillips Alaska RECEIVED JUL 1 0 Z007 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Alaska Oil & Gas Cons. Commission Anchorage July 6,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 ,Q1í';}.37 SCANNED JUL 1 1 2007 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of fonn 10-404, Report of Sundry Operations. Please M.J. Loveland at 907-659-7043, if you have any questions. .;;µ M.~ ConocoPhillips Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft ~al 1 0-09 198-065 23" na 5 6/912007 10-101 200-183 2" na 3.2 6/9/2007 10-102 200-075 2" na 3.2 6/9/2007 10-103 202-096 5" na 8 6/912007 1O-105a 201-202 25" na 38 6/9/2007 10-106 197-240 2" na 3.2 6/9/2007 10-107 200-177 2" na 3.2 6/9/2007 10-108 198-187 8" na 12.8 6/912007 10-113 198-178 2" na 1 6/9/2007 10-114 198-159 2" na 1 6/912007 10-115 197-232 2" na 1 6/912007 10-116 198-172 2" na 1 6/9/2007 10-117 197-237 2" na 1 6/912007 10-118 197-229 2" na 1 6/912007 10-119 197-222 2" na 1 6/9/2007 10-122 198-149 2" na 1 6/9/2007 10-123 198-170 2" na 1 6/9/2007 1O-125a 200-044 2" na 1 6/912007 10-126 198-108 2" na 1 6/9/2007 10-127 198-109 8" na 2.5 61912007 10-128 198-133 2" na 1 6/9/2007 10-129 197-213 2" na 1 6/9/2007 10-130 197-183 23" na 5 6/9/2007 Kuparuk Field June 9,2007 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 1 00 Anchorage. Alaska 99501 (907) 659-5102 ,.#,' f'A. it\~I.J¡¡;:f,'; ;~¿;\:4""~?'~ l~~F)I"" RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Rease acknowfedge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8952 "ì ;:>' 1 .0 CHI & Gon5. 1) 1 Report 2) 1 Report 3) 1 Report 4) 1 Report 5) 1 Report 6) 1 Report 7) Signed: Print Name: 1C - 111 MTT Log 1C - 117 MTT Log 1 C - 127 MTT Log 1 C - 133 MTT Log 10-114 MTT Log 10-117 MTT Log 10- Dec -06 U"I Q... êìol - Id?r 11- Dec -06 UTe. dOl-Ie I 11- Dec -06 V..lC--dO 1- /It./ 12- Dec 06 U r c... 861 - 6-=t~ 08- Dec -06 U:r~ tqir -l5'ì 09- Dec -06 U:.te.... \ q '7 -éB1-- ~.jj~ ~/h r~~ ~O~ /Jilt'), Vi. Vl {¡~f/1 Date: If) IIK!()~ PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATloNAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: :>::::3Ai';G:·I(','t\'.3'::(t),x=~"ç,."t"_>J.G;)c';i WEBSITE : 'fci"N'iJ.:HEf,JCi"Cf'..I:G,·(;O;',] D:\OO _ PDSAN C-2006\Z _ W ord\Distribution\TrarumIittaJ _ Sheets\TransnIit_ Original.doc I I I I I I I I I I I I I I I I I I I . . Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 10-117 Log Date: December 9, 2006 Field: Kuparuk Log No. : 8078 state: Alaska Run No.: 1 API No.: 50-029-22844-00 Pipe1 Desc.: 3.5" 9.3 Ib L-80 EUE 8RD Top Log Intvl.: Surface Pipe1 Use: Tubing Bot Log Intvl.: 192 Ft (MD) Pipe2 Desc.: 7.625" 29.7 Ib L-80 BTCM Top Log I ntvl.: Surface Pipe2 Use: Surface Casing Bot Log Intvl.: 192 Ft (MD) Pipe3 Desc.: 16" 62.58 lb. H-40 Welded Top Log Intv!.: Surface Pipe3 Use: Conductor Pipe Bot Log Intvl.: 121 Ft (MD) Inspection Type: Assess External Co"osive Damage (Metal Loss) to Surface Casing. COMMENTS: This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first log ofthis well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing and 7.625" surface casing, with some influence from the 16" conductor pipe. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (70'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3.5" tubing, 7.625" casing, and 16" conductor pipe. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval from surface to 192'. A log plot of the entire pass, plus a detailed section of any interval showing damage is included in this report. The Delta Metal Thickness (%) curve in these plots refers to total metal surrounding the MTT tool. A maximum of 16% circumferential metal loss is recorded just below the mandrel hanger in the interval between 0' - 2'. A 2% circumferentië¡1 metal loss is recorded in the interval between 10' -11.5'. A -60% isolated metal loss is recorded @ 31'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" surface casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. I Field Engineer: R. Richey Witness: C. Fitzpatrick I Analyst: M. Tahtouh & J. Burton ProÞ,ctive Diagnostic Ser\dces¡ Inc., Pr-wlle: (281) or (888) 565-9085 Fax: Prudhoe Bay Field Office Phone: Box 1369/ Stafford, TX 77497 565-1369 E-mail: PDS(çÜmemor¡log.com (907) 659-2307 Fax: (907) 659-2314 U::rc- JC7'1-Q3?- I I I I I I I I I I I I I I I I I I I ) J-S. Magnetic Thickness Tool (10Hz Pass) ... PROÁcIivE DW:¡NO!õIlc SeRvicES, INC. Database Filel d\warrior\data\1 d-117\1 d-117db Dataset Pathname: 10hz. 1 Presentation Format 24SCAL -1 Dataset Creation: Sun Dee 1009:42:232006 by Calc Sondex Warrior V70 Charted by: Depth in Feet scaled 1150 -- -50 Delta Metal Thickness (%) 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (ft/min) -200 -6.4 MTTP12 (rad) 3.6 -:¿u ~... - '-- I ""-",. I - -10 Tree =H+= Hanger Pup Jt I 1't I~. --- }" I ~, -- 3 5" Collar I I I 10 I -f T7 ( I- 2% Metal Loss ( (. ~ = 35" Jt I I ì i ------ -- f--- Jt 1 ---.,-. -- ~. ¡:::::-- } !;- I--- ~ ..... ¡-- -- i\-- 20 - I -......... !~ T i I ~ j II; 30 ~ ~,~ I- ~_.- f--. ...-.. ---- I - Line S --- -- Pup Jt. 3.5" Call 'I:. 40 ~ ~--- - 3.5" Collar >- Pup Jt :JU 5" Collar - I ~ I I -~ H .. .--- =ft=1325" Casing Cüllar ''', ~ 60 I ._f-- -~._--- 3.5" Jt .., } I Jt 2 ... ¡ 70 ~ r-I _ ~.--. I ..--... t---- --- 3.5" Collar ...... I+- Qn -<:::: I I I I I I I I I I I I I I I I I I I \1 I I I I ~ \:1 11 I \1 \ìt-t 1 1-= k ~7.625" cl.ollar ~ ~'I l; /,."" '&, 90 I 3.5" Jt - Jt 3 - 'I ut= 100 -...... -- ~," ~:.tr:' "onduelm ---. "~ -- ~ - 35" Collar - - - - 120 - r---.- ~- ..- i--- 3.5" Jt t I Jt 4 - ~ - 1-...-.. :s ..- """'}, .... -1':1" ~ =-¡-625" Casing Collar ?- Þ- "..'" ... :>- --.-- ¡. ~. ...... I I I 140 .... Þ$ - , ..-. ..- I---- ~ ,.. , 3.5" Colla -- '- 150 - f-- 1--..... --.. i--- 35" Jt - - I--- Jt. 5 - I--- - 160 1-..- -- . - I - 170 ,- - I ' 1--7i62~" Casing Collar -.. II I ~ -+f 3.5" Callar- i--- ~ ,-- ...-.. 180 - I ~ 3.5" Jt. ,- - - -......-.. " '\ ¡ ^~---- - ~._- ---- ,... Jt 6 :> 1 t if .....~ 190 = * End of Log I--- --: I _. ·50 Delta Metal Thickness (%) 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (ftlmin) -200 -64 MTTP12 (rad) 36 I I I I I I I I I I I I I I I I I I I cIas. . Magnetic Thickness Tool (10Hz Pass) p~ DIAqNOSric SER\IICB" INC. Database Filel d \warrior\data \ 1 d-117\top metal loss \ 1 d-117. db Dataset Pathname: 10hz. 1 Presentation Format 24SCAL -1 Dataset Creation: Sun Dee 1009:42:232006 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 175 -_.~ -50 Delta Metal Thickness (%) 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (ftJmin) -200 -6.4 MTTP12 (rad) 3.6 _:~ Tree Hanger 0 ~ f..... =tti. iOllar_ Pup Jt _. ." .- --; 1--.. ( ~, I ;=- 5: 'J I ) l J 11 l I ( I I I ~ 1 10 I .~ - 2% ¡Met¡al Loss I: ( 1/ (' ( ~ r\ ¿ I I I ...~ I 35" Jt I m I Jt 1 ¡ iIi_ - '" > ~~ I ... I 20 .. i , ? ¡... r s; i I Ii ¡ I ~ l , " ¿ ~ ] ,t' :> I -.- - j ~ =- ~ ". , 30 ;:=:- ~. >-. " ,_. :". .~ ;: f---- ~ ~'> ¡.. ~ <~ "':> "'-.. I ~~t;~ .I i-- Line Spee j I TI'- f-- ~ - 3.5" Collar j Pup Jt f---- l5 ,I ¡ ~. ]; -50 Delta Metal Thickness (%) 50 24 MTTP01 (rad) 12.4 0 Line Speed (ftJmin) -200 -6.4 MTTP12 (rad) 3.6 I I I I I I I I I I I I I I I I I I I ") . I Magnetic Thickness Tool (10Hz Pass) - PR<>Á.I::;rivE DIAq_ic SERVIcES, INC. Database File: d\warrior\data\1d-117\isolated\1 d-117.db Dataset Pathnamel 10hz. 1 Presentation Format: 24SCAL -1 Dataset Creation: Sun Dec 1009:42:232006 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 150 - -50 Delta Metal Thickness (%) 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (ftlmin) -200 -6.4 MTTP12 (rad) 3.6 I II: I I I !;;,- IP ::2 :~ ;> l;:,"~' I ) ~ :> I 20 " ~ ~L,,: ,~: ! ::> > :? +; I I ""? I P- I -t- '~ 3.5" ~ ( It ~ Jt 1 - ß 1 1,\ ~ ,,," I I ? , , I ;:J" I ~ $ -± I ) I ::> > tt I I 30 ¿' 'I I I j )~~ ;:;== := :~ :::~ ,;;:, ? < I I- 60% Isolated I, < ~ Metal Loss_ - ~ f:; ~ I ¿:? I I :~" ,t \ 1\ ¿" I~ ---i-~r~ '\"1 ') "'I, ') I> ~ b " I,~ -,. '._.....,..,. " I" ~ \, ."C l':::::: i-- Line Speed ~ ~~ :~r5" Colia. } I ) ] Ii - l / Pup Jt I .- 11 M ( ;:> ~ ¡rJe 40 ,"ii 1 "'::¡¡ ~ .¿ ¡ ~ <: I; )' -50 Delta Metal Thickness (%) 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (ft/min) -200 -6.4 MTTP12 (red) 3.6 I I .- -. .... .. . - KRU 1 D-111 .... <, '.11).'t1'1 TUBING API: 500292284400 Well Type: INJ Angle tI'iJ TS: dea tI'iJ (0-4414, SSSV Tvne: Nioole Orig Completion: 1/2/1998 Angle tI'iJ TD: 1 dea tI'iJ 5205 00:3.500, Annular Fluid: Last W/O: 5/19/2002 Rev Reason: TAG FILL 102.992) Reference Log: Ref Log Date: Last UDdate: 7/10/2006 ~ TD: 5205 ftKB SURFACE Max Hole Angle: 50 deg @2816 (0-5190, 007.625, II"....... Wt:2970) Description Size Top Bottom TVD wt Grade Thread NIP (498-499, CONDUCTOR 16,000 0 121 121 62.58 H·40 WELDED 004.500) SURFACE 7.625 0 5190 4393 29.70 L-80 BTCM 4.000 4413 4880 4083 11.50 L-80 SLHT IUQluuStnnå+ IUØU'\I\::I Size I Too 1 Bottom 1 TVD I wt 1 Grade I Thread 3.500 I 0 I 4414 I 3617 1 9.30 I L-80 I EUE 8RD GasUft DI andr€llOummy Interval TVD Zone Status Ft SPF Date Tvpe Comment Valve 1 4524 - 4547 3727 - 3750 WSD 23 20 11/3/2000 RPERF 4.5" HSD Frac guns w/43cj (4311-4312, UP II RDX 00:5.390) 4547 - 4554 3750 - 3757 WSD 7 16 11/3/2000 APERF 4.5" HSD Frac guns w/43cj UP II RDX 4588 - 4608 3791 - 3811 WSB 20 16 11/3/2000 RPERF 4.5" HSD Frac guns w/43cj UP II RDX 4635 - 4640 3838 - 3843 WSA4 5 4 2/12/1998 IPERF Zero dea phasina 4640 - 4650 3843 - 3853 WSA4 10 16 11/3/2000 RPERF 4.5" HSD Frac guns w/43cj NIP UP II RDX (4355-4356, 4692 - 4722 3895 - 3925 WSA3 30 4 2/5/1998 IPERF 00:4.520) 4746 - 4776 3949 - 3979 WSA2 30 8 2/1/1998 RPERF Zero dea phasina 4820 - 4828 4023 - 4031 WSA2 8 12 11/3/2000 APERF 4.5" HSD Frac guns w/43cj UP II RDX 4862 - 4870 4065 - 4073 WSA1 8 12 11/3/2000 APERF 4.5" HSD Frac guns w/43cj UP II RDX St MD -rMan Man Type I V Mfr I V Type I V 00 I Latch I Port I TRO I Date Run I C~~t Mfr PBR 1 4311 35141 Cameo 1 KBMM-2 I I DMY 1 1.0 1 BK 1 0.000 I o 15/27/20021 (1) (4393-4394, "ON "'h~~' A", 00:5.900) ~etc;.) IC\AIIHþV Demn Tvpe ~ Description I ID 498 497 NIP DING NIPPLE 1 2,812 4355 3558 NIP LE 2.750 4393 3596 PBR BAKER POLISHED BORE RECEPTABLE 80-40 4.000 4412 3615 SEAL BAKER ANCHOR TU BING SEAL ASSEMBLY E22 80-40 3.000 4413 3616 PACKER BAKER SC-1 PACKER (left in place from previous WO 110' above top perfs) 0.000 SEAL 4414 3617 TTL 2.992 (4412-4413, iNotes 005.000) Date 1 Note 11/6/19981 T aa spline @ 4352' PACKER 0/31/2000 Nordic 3 Workover to Gravel Pack comDletion (10/31 - 11/6/00) (4413-4414, 006.750) -- Perf ~ (4588-4608) :: = = = - - Perf - I (4635-4650) Perf -. ( 4692-4n2) - -- - Perf - (4746-4776) - -- f----- == f----- Perf f----- (4820-4828) 1--- - ~_.- - - 1--- - - f----- Perf - f- (4862-4870) - - f----- - - f----- --- - f---- I I I I I I I I I I I I I I I I I RECE\VED A.UG () ð Z006 08/01/06 Scblumbel'gel' ~ OJ! & Gas Cons. Comrr~ ,AI1~horage NO. 3899 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth l: T' Œ, ~ C)-::¡ - d3-:J· Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 2";l~.Þ.. ~.H"Jþ. ìi ........ ¡ J.. ~;; ""1-:.......<.- f' '," f "'¿nnc Field: \.1 .~ ',': ,,'J"") Kuparuk Well Job # BL Color CD Log Description Date 1 J-1 01 (REDO) 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 1D-125A (REDO) 11213778 INJECTION PROFILE 07/17/06 1 2K-24 (REDO) 11213781 INJECTION PROFILE 07/20/06 1 1 G-05 11249932 INJECTION PROFILE 07/28/06 1 3A-08 11249933 PROD PROFILE W/DEFT 07/29/06 1 1 D-117 11216305 INJECTION PROFILE 07/08/06 1 3F-18 11235384 SBHP SURVEY 07/25/06 1 3F-17 11235383 BHP SURVEY 07/25/06 1 1Y-32 11213707 SBHP LOG 07/25/06 1 3G-25X 11216313 PROD PROFILE W/DEFT 07/31/06 1 1Y-24A 11216315 GLS/FBHP SURVEY 08/01/06 1 1 R-36 11249931 LDL 07/27/06 1 2V-10 11216311 SBHP SURVEY 07/28/06 1 1 D-1 07 11216309 INJECTION PROFILE 07/12/06 1 1 D-130 11249928 INJECTION PROFILE 07/09/06 1 31-03 11213788 PROD PROFILE W/DEFT 07/26/06 1 1 Y -05 11216310 LDL 07/27/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . MEMORANDUM e e .. State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor /7 -;/zS /C0 f-,c?11 DATE: Wednesday, July 12,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA INC 10-117 KUPARUKR1VUWSAK 10-117 \ q1,~7 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :Jí3/Z- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK 10-117 API Well Number 50-029-22844-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ060711174544 Permit Number: 197-237-0 Inspection Date: 7/10/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! 10-117 ¡Type Inj. : W ! TVD 3616 I IA ! 350 I 2020 1950 ! 1930 I I 1972370 I . I i I --+- 1-- P.T. ITypeTest I SPT I Test psi 1500 lOA I I I i I Interval 4YRTST P/F P .../ Tubing! 1240 i 1240 1240 I 1240 I i Notes Monobore injector, 1.3 bbls diesel pumped. 1 well house inspected; no exceptions noted. Wednesday, July 12,2006 Page 1 of! e PHilliPS Alaska.. Inc. A Slt'sidiðJ\/ of PHILLIPS PETROLEUM 'Ç~PÞ.Ji" e KRU 1 D-117 TUBING / 10.117 (04414, API: 500292284400 Well Tvoe: INJ Annie IffJ TS dea IŒ 00:3500, SSSV Type Nipple Orig 1/2/1998 Angle @ TO 1 deg @ 5205 102.992) Comoletion: II Annular Fluid: Last W/O: 5/19/2002 Rev Reason: Format update by ";'::¡:¡:j;j:¡:¡:: ImO 11¡II:ilillill::::::::::::::t~ Reference Loa: Ref Loa Date: Last Uodate: 8/15/2002 LastTaa: TO: 5205 ftKB Last Tao Date: Max Hole Anole: 50 deo IŒ 2816 : Casil'lo- $trinQ-ALLSTRINGS : .. ... .... Descri"tion Size Toe Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.58 H-40 WELDED SURFACE : SURFACE 7625 0 5190 4393 29.70 L-80 BTCM (0-5100. PROD LINER 4.000 4413 4880 4083 11.50 L-80 SLHT 007625, Tubina Strina.-TUBING ... :.. ..... Wt29.70) Size I Top I Bottom I TVO I Wt 1 Grade I Thread : 3.500 I 0 I 4414 I 3617 I 930 I L-80 1 EUE 8RD Perforations Summary . .. ..... ...... ...:.. '.. ...... : : Interval TVD Zone Status Ft SPF Date Tvpe Comment 4524 - 4547 3727 - 3750 WSD 23 20 11/3/2000 RPERF 4.5" HSD Frac guns w/43c NIP UP /I RDX (43554356, II 4547 - 4554 3750 - 3757 WSD 7 16 11/3/2000 APERF 4.5" HSD Frac guns w/43cj UP /I RDX 004.520) 4588 - 4608 3791 - 3811 WSB 20 16 11/3/2000 RPERF 4.5" HSD Frac guns w/43cJ : UP II RDX 4635 - 4640 3838 - 3843 WSA4 5 4 2/12/1998 IPERF Zero dea phasinq ... 4640 - 4650 3843 - 3853 WSA4 10 16 11/3/2000 RPERF 4.5" HSD Frac guns w/43cj : UP /I RDX 4692 - 4722 3895 - 3925 WSA3 30 4 2/5/1998 IPERF PBR = .'C 4746 - 4776 3949 - 3979 WSA2 30 8 2/1/1998 RPERF Zero deq ohasinq (4393-4394, .... 4820 - 4828 4023 - 4031 WSA2 8 12 11/3/2000 APERF 4.5" HSD Frac guns w/43cj 005.900) : UP II RDX 4862 - 4870 4065 - 4073 WSA1 8 12 11/3/2000 APERF 4.5" HSD Frac guns w/43cj UP /I RDX GêI$Lift MêlI1drelsNalves ... ..... St I MD I TVD I Man Man I V Mfr I V Type I V OD Latch I Port I TRO Date I Vlv Mfr Tvee Run Cmnt SEAL 1 T 43111 35141 Camco 1 KBMM-2 I I DMY I 1.0 I BK TO.ooo T 0 5/27/20021 (1) (4412-4413, ........ 1. 2900# Shear Out 00:5.000) Other "mas, eauie..etc. - JEWELRY d. .. .... .... .... < Depth TVO Tvpe Description ID ...... 498 497 NIP CAMCO OS LANDING NIPPLE 2.812 .<.. ....... : 4355 3558 NIP CAMCO 0 NIPPLE 2.750 4393 3596 PBR BAKER POLISHED BORE RECEPTABLE 80-40 4.000 4412 3615 SEAl BAKER ANCHOR TUBING SEAL ASSEMBLY E22 80-40 3.000 1« 4413 3616 PACKER BAKER SC-1 PACKER (left in place from previous WO, 110' above top 0.000 PACKER . ...... oerfs) (4413-4414, 4414 3617 TTL 2.992 006.750) General N.otes .. ... Date 1 Note -' f---- 11/6/1998 Tag spline @ 4352' Pelf - ~ (45244554) ==- 0/31/2000Nordic 3 Workover to Gravel Pack comoletion 110/31 - 11/6/00) - I-- Pelf = I=: -'-- (4547-4554) - ~ '1-- :::::::: ~ .~ E - ~ - I-- :::::::: t= -. I=: - ~ - '-- Pelf = F = = (4588-4608) ;;;. ~ ;: ;;;;;; - ~ - - Pelf - I- - - (4635-4650) == Ë :: === - - - - Pelf _: - - : - (4&324722) - - -. - -. - - - Pelf - - -.- (47464776) - - - - - - -' - Pelf - - -: - (4620-4828) - - - -' - - - - - - - Pelf -. - - - (4862-4870) - - -. - - - -: - e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. West Sak / KRU/1D-117 07/24/05 Arend / Rodgers - AES 1ßl-- 1\ ~b F>:7' "ì' ., Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us o P o F o P Well P.T.D. Notes: Well P.TD. Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature TeI!It .Ä;_;,.-":'·~i"""''' INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) ''')(i' "'-' ., 5CANNED NOV 0 ~ 2.005 MIT Report Form Revised: 06/19/02 2005-0724_MIT _KRU_1 D-117 _MITIA2.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O. Taylor/~ Chair DATE: October 24, 2002 THRU: Tom Maunder ~__..~ ~~~..~, ©-~ Petroleum Engineer FROM: Lou Grimaldi Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests Conoco/Phillips 1 D pad 1D~103, 1D-117 Kuparuk River Unit Field Packer Depth Pretest Initial 15 Min. 30 Min. WellI 1D-103 I Typelnj. I S I T.V.D. I 6491 }Tubing I 1350 I 1350 I 1350 I 1340 I lntervall I P.T.D.I 2020960 ~ Type test ] P I Testpsil 1500 ICasing] 1250 I 1990 ] 1970 ] 1960I P/F ] P ~ Notes: WellI 1D.117 ITypelnj. I S I T.V.D. I 3616 J TubingI 1240 I 1240 I 1240 I 1240 Ilntervall I P.T.D.I 1972370 TypetestI .P ITestpsiI 1500 I Casingl 11oo I 188o I 18So I lS6OI P/F I P Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Vadance W= Test during Workover O= Other (describe in notes) Test's Details This was the initial: pressure test of theSe wells production casings. The tests went well with no appreciable loss of pressure during the thirty minute tests. I passed these wells for continued injection. M.I.T.'s performed: _2 Attachments: Number of Failures: None Total Time during tests: 3 hours cc: DethlefslNezetiky MIT report form 5/12/00 L.G. MIT KRU 1D 10-24-02 LG.xIs 10/27/2002 P "' "LIPS Alaska, Inc. A Subsidiary of PHILLIPs PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 May 31, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 3F-19 (197-237 / 302-089) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the West Sak well 1D-117. This workover converted the well from a producer to an injector. If there are any questions, please contact me or Skip Coyner at 265-6074. Sincerely, R. Thomas Kuparuk Drilling Team Leader Phillips Drilling RT/skad RECEIVED 1. Operations performed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation shutdown_ Pull tubing _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 91' FNL, 597' FEL, Sec. 23, T11N, R10E, UM At top of productive interval 1037' FSL, 1223' FWL, Sec. 13, T11N, R10E, UM At effective depth Stimulate _ Plugging _ Perforate _ Alter casing _ Repair well _ Other _Conversion to Injector (PWI) 5. Type of Well: 6. Datum elevation (DF or KB feet) Development __X RKB 40 feet Exploratory__ 7. Unit or Property name Stratig raphic __ Service (asP's 560491, 5959574) At total depth 4224' FNL, 4064' FEL, Sec. 13, T11N, R10E, UM (asp's 562291, 5960733) 12. Present well condition summary Total depth: measured 5205 feet Plugs (measured) true vertical 4408 feet Kuparuk River Unit 8. Well number 1D-117 9. Permit number / approval number 197-237 / 302-089 10. APl number 50-029-22844 11. Field / Pool Kuparuk River Field / West Sak Oil Pool Baker Bridge Plug @ 4880' Effective depth: measured 5060 feet Junk (measured) true vertical 4263 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 9 cu yds High Early 121' 121' SURF CASING 5149' 7-5/8" 446 bbls AS IIILW, 368 bbls Class 5190' 4393' 'SCREEN 467' 4" x 4.5" N/A 4413'- 4880' 3616' - 4083' Perforation depth: measured 4524' - 4554', 4588' - 4608', 4635' - 4650', 4692' - 4722', 4746' - 4776', 4820' - 4828', 4862' - 4870' RECEIVED true vertical 3727' - 3757', 3791' - 3811' 3838' - 3853', 3895' - 3925' 3949' - 3979', 4023' - 4031' 4065' - 4073' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 4414' MD Packers & SSSV (type & measured depth) Baker Gravel Pack SCl packer @ 4413' No SSSV 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 18 60 Oil-Bbl 202 N/A Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run_ Daily Report of Well Operations __X Oil__ Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ R. Thomas Suspended Title: Kuparuk Drilling Team Leader Form 10-404 Rev 06/15/88 · Casing Pressure Tubing Pressure - 232 JUN 2002SUBMIT IN DUPLICATE Service_ PWI Injector XX , Questions? Call Skip Coyner 265-6074 Date 5"'-( ~ f /fO ~ Prepared b~/ Sharon Alfsup-Drake 263-4612 WEST SAK 1D'1 Post. Conversion Schematic 121! MD 3 1/2" Vetco Gray Tubing Hanger w/3-1/2" L-80 EUE 8rd Mod Pup Joint, CAMCO "DS" nipple (2 812" bore): 493' ;tage Toot 2073' MD Directional KOP = 250' Max Angle = 49,76 Deg ~ 2816' Avg Angle Thru W.Sak = +/- 1.5 Deg Depths are based on original RKB Parker 245 3-1/2" 93¢~ L-a0 EUE 8rd Mod Tubing to Surface 3-1/2" x 1" Camco 'KBMM' GLM: 4311' CAMCO "DS" nipple (275" bore): 4354' BAKER "E-22r' Anchor Seal nipple and 12' (80-40) PBR: 4393' - 4412' Drillers TD @ 5205' MD Bakel Model SC-1 Packel @ +/- 4414' MD (110' above top pelforation) D-Sand Peals: 8 SPF 4524'- 4547' Frac'd wi Carbolite and Prop Lock(Existing Perforations 4 SPF 4547' - 4554' Frac'd w/Carbolite and Prop Lock (Existing Perforations Plan to Re-Pedorate from 4524' to 4554' (~ 12 SPF B-Sand Ports: 4 SPF 4588' - 4608' Frac'd w/Carbolite and Prop Lock (Existing Per~orations Plan to Re-Perforate from 4588' to 4608' @ 12 SPF A4-Sand Perfs: 4 SPF 4635' 4650' Frac'd w/Carbolite and Prop Lock (Existing Perforations Plan to Re-Per~orate from 4640' to 4650' @ 12 SPF A3-Sand Perfs: 4 SPF 4692' - 4722' Frac'd w/Carbolite and Prop Lock (Existing Perforations A2-Sand Perfs: 8 SPF 4746' - 4776' Fradd w/Carbolite and Prop Lock (Existing Perforations Plan to Add Pe*%rations From 4820' to 4828' (~ 12 SPF A%Sand Perfs: Plan to Add Perforations From 4862' to 4870' @ 12 SPF Bridge Plug @ +/~ 4880' MD (10' Below Bottom Perforation) PBTD @ +/- 5060' MD (Gemoc0 Insert Shut-Of¢~B~l~X!~t¢~,*,~/¢ "~>¢~ S * /'{~( 7-5/8" 297¢ L-80 BTC Mod @ +/- 5190' MD , ............. Legal Well Name: 1D-117 Common Well Name: 1D-117 Spud Date: Event Name: WORKOVER/RECOMP Start: 5/8/2002 End: 5/16/2002 Contractor Name: n1268@ppco.com Rig Release: 5/16/2002 Group: Rig Name: Nabors 245 Rig Number: 245 ~:~:~D~e~:~:~:~E~:~:~e~:- ~~~~e~::~`~:~:~:~:~:~:~ase~ ~?.~Descnptlon of Operati°ns : : 51812002 00:00-03:00 3.00 MOVE MOB MOVE Prepair Uility module for Pad to Pad move F / 10 to 1J 03:00-05:00 2.00 MOVE MOB MOVE Move Utility Module away from sub and drive to enterance of 1C pad. 05:00-17:00 12.00 MOVE MOVE MOVE Move Utility Module f/ 1C pad to 1D pad and spot by well 1D-117 17:00-21:00 4.00 MOVE MOVE MOVE Skid rig floor for move drilling module 21:00-00:00 3.00 MOVE MOVE MOVE Raise cellar box and stomper beam. Get dril ling module ready to move. 5~9~2002 00:00-12:00 12.00 MOVE MOVE MOVE Move drilling module ft 10 pad to spine road Broke drive chain manuvering rig around o n to spine road for turn around. Repair sam e 12:00-00:00 12.00 MOVE MOVE MOVE While maneuvering rig on turn around at bas e camp broke drive chain again. Repair sam e. Completed turn around and moving past t he Y on spin road @ 2400 hrs to 1D pad. 5/10/2002 00:00 - 06:00 6.00 MOVE MOVE MOVE C o n t i n u e ri g m o v e f r o rn P P C O b a s e ¢ a rn p t o 1D pad. Drilling module came on to pad at 0 600 hrs. 06:00-10:30 4.50 MOVE MOVE RIGUP Mat location for Nabors 245e. Maneuver drill lng module over 1D-1 17. Lower stomper, Lev el rig, Lower cellar box over well. Jack der rick back over cantilever. 10:30-15:00 4.50 MOVE MOVE RIGUP Move Utility module and maneuver along sid e drilling module. R/U Centrailift spooling u nit and build berm for containment. 15:00-21:00 6.00 MOVE MOVE RIGUP Hook up all utility lines. Clean up rig put th ings back in place. 21:00-00:00 3.00 CMPLTNOIRC RIGUP Hook up circulating lines to welt head. Take on 290 bbl's of 8.5 ppg @ 100 deg Sea war er in rig tanks. Accept rig for operation @ 2 100 hfs 5/10/2002 5/11/2002 00:00-03:00 3.00 WELOTLKILL WRKOVR Continue to hook up lines to well head and t est to 1000 psi. Pull BPV 150psi SICP "0" SlTP. 03:00-10:00 7.00 WELOTLKILL WRKOVR Start bleeding pressure off annulus. Gas & deisel from annulus returned to rig tanks in side. To much gas coming for inside house. Shut well in and ordered out Tankco flowbac k tank. Move ball mill in place and hook up to rig. 10:00-13:00 3.00 WELOTLKILL WRKOVR Test lines to 1000 psi O.K. Pump down tbg @ 3 bpm "0" psi w/ 240 bbl's 100 deg seawa ter. Taking returns to flowback tank. Displa ce diesel freeze protection 75 bbl's and 100 bbl's crude oil. Seawater around. Observe well O.K. TBG on vacuum install 2 way chec k. 13:00-15:00 2.00 WELOTLNUND WRKOVR PJSM. Remove tree. Take out of cellar. 15:00-00:00 9.00 WELCTLNUND WRKOVR N/U on 1 1" 5M Veco Gray tbg flange. 1 1" X 13 5/8" 5M DSA, 13 5/8" 5M tripple gate w/ 13 5/8" Hydril. Work on Koomey hoses to th Legal Well Name: 1D-117 Common Well Name: 1D-117 Spud Date: Event Name: WORKOVER/RECOMP Start: 5/8/2002 End: 5/16/2002 Contractor Name: n1268@ppco.com Rig Release: 5/16/2002 Group: Rig Name: Nabors 245 Rig Number: 245 5/11/2002 15:00-00:00 9.00 WELCTLNUND WRKOVR e choke and kill HCD valve. 5/12/2002 00:00 - 00:30 0.50 WELCTL NUND WRKOVR N i p p l e u p B O P E 00:30-12:00 11.50 WELCTLBOPE WRKOVR Test BOPE to 250 psi Iow & 3500 psi high, R etest 3 valves 12:00-15:30 3.50 WELCTLEQRP WRKOVR Test Blind rams- Door seal failed, Repair sa me 15:30-16:30 1.00 WELCTLBOPE WRKOVR Finish testing BOPE, Rig down test equip., Blow down choke & kill lines 16:30-18:30 2.00 WELLSRSEQP WRKOVR Pull 2- way check, Pick up landing joint, Rig to circ well, Back out lock down screws 18:30-00:00 5.50 WELLSFOTHR WRKOVR Unable to pull hanger, Max pull 225K, String weight 52K, Blocks 80K, Pulling 93K on ha nger & still unable to pull same 5/13/2002 00:00-03:00 3.00 WELLSF~JAR WRKOVR Pick up Spear, Jars & ACC, Jar Tbg. hanger loose, Fill hole w/ Seawater 03:00-05:00 2.00 WELLSRRURD WRKOVR Remove heat cable & electric line from tbg. hanger, Lay down tbg. hanger & landing jt. 05:00-21:30 16.50 WELLSRPULD WRKOVR POOH w/ Completion string, Lay down jewelr y & Tbg, equip. 21:30-00:00 2.50 WELLSRPLGM WRKOVR Rig Schlumberger wire line 5/14/2002 00:00-00:30 0.50 WELLSRPLGM WRKOVR Schlumberger. Continue running 6.6" gauge ring junk Basket to 4414'. Recovered test ru bber. R/D 00:30-04:30 4.00 WELLSRPLGM WRKOVR Run Baker IBP 2.13" Set @ 4450' POOH 04:30-05:30 1.00 CASE DEQT WRKOVR Test 7 5/8" csg and IBP to 4450' w/ 2500 ps i for 30 min O.K. 05:30-12:00 6.50 LOG OTHR WRKOVR Run USIT f/ 4414' to 400' POOH R/D 12:00-15:00 3.00 WELLSRPLGM WRKOVR P/U 10 4-3/4" DC's and Howco 7 5/8" strom packer set at 55' 15:00-21:30 6.50 DRILL CIRC PCPTST Load 200 bbl's Mud clay seal 9.0 ppg. P/U b t w/ 9/32 jets . 1 863 . Sheared mud 1 30 spm (555 gpm) @3000 psi for 2 hrs. Pull jet out. Flow test mud system including shaker, rio wline and troughs, first test w/ 50 mesh scr eens to 1000 gpm. O.K. but trough full belo w shakers. With some conserns settling in tr ough will cause overflow. C/O screens to 80 mesh and repete test to 1000 gpm. Screen f ull trough full. Note! Mud clean with no curt ing or sand. 21:30-22:00 0.50 DRILL CIRC PCPTST Circ mud out of stack. L/D bit. Blow down to p drive. 22:00-00:00 2.00 WELLSRNUND WRKOVR N/D BOPE, Remove riser and prepare to cha nge out Vetco Gray production tree to Inject or tree. 5/15/2002 00:00-02:00 2.00 WELCTLNUND WRKOVR Change out well heads 02:00-06:30 4.50 WELCTLNUND WRKOVR Nipple up BOPE 06:30-07:30 1.00 WELCTLBOPE WRKOVR Test BOPE Breaks to 250 psi Iow & 3500 psi high 07:30-09:30 2.00 WELLSFiTRIP WRKOVR Retrieve storm packer & lay down DC's 09:30-14:30 5.00 WELLSRPULD WRKOVR RIH w/ Completion string 14:30-17:00 2.50 WELLSRPULD WRKOVR Sting into SC-1 packer, Test latch & press. to 1000 psi, Shear out PBR w/ 32K, Space o ,, Printed: 5/28/2002 1:01:23 PM CANNEE) JUN 2, 4 2{]D2 ........................ Legal Well Name: 1D-117 Common Well Name: 1D-117 Spud Date: Event Name: WORKOVER/RECOMP Start: 5/8/2002 End: 5/16/2002 Contractor Name: n1268@ppco.com Rig Release: 5/16/2002 Group: Rig Name' Nabors 245 Rig Number: 245 5/15/2002 14:30-17:00 2.50 WELLSRPULD WRKOVR ut & land tbg., Lay down landing joint & set BPV 17:00-20:00 3.00 WELCTLNUND WRKOVR Nipple down BOPE 20:00-22:30 2.50 WELCTLNUND WRKOVR Nipple up Tree & test 250 psi Iow & 5000 ps i high 22:30-00:00 1.50 WELLSRDEQT WRKOVR Rig & test Tbg to 2500 psi f/ 30 min. 5/16/2002 00:00-01:00 1.00 WELLSRDEQT WRKOVR Pressure test tbg. to 2500 psi & csg to 3000 psi f/ 30 min. 01:00-02:00 1.00 WELLSRCIRC WRKOVR Shear out RP valve in GLM @ 4311', Pump 9 0 bbls corrosion inhibitor 8.5 ppg brine dow n annulus at rate of 2.5 bpm @ 1000 psi 02:00-04:00 2.00 WELLSRFRZP WRKOVR Pump 95 bbls Diesel down annulus at rate of 2.5 bpm @ 1000 psi for freeze protection & let U-tube w/ tbg. 04:00-05:00 1.00 WELLSFPLGM WRKOVR Set BPV & VR plug, Release rig @ 0500 hrs 5/16/02 Printed: 5/28/2002 1:01:23 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _X Change approved program _ Pull tubing _X Variance _ Perf _ Conversion from prod to inj 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 111 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 91' FNL, 597' FEL, Sec. 23, T11 N, R10E, UM (asp's 560491, 5959574) 1D-117 At top of productive interval 9. Permit number / approval number 1037' FSL, 1223' FWL, Sec. 13, T11 N, R10E, UM 197-237 At effective depth 10. APl number 50-029-22844 At total depth 11. Field / Pool 4224' FNL, 4064' FEL, Sec. 13, T11 N, R10E, UM (asp's 562291, 5960733) Kuparuk River Field / West Sak Oil Pool 12. Present well condition summary Total depth: measured 5205 feet Plugs (measured) Baker 7.625" Cast Iron Bridge Plug @ 4880' true vertical 4408 feet Effective depth: measured 4292 feet Junk (measured) true vertical 3495 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 9 cu yds High Eddy 121' 121' SURF CASING 5149' 7-5/8" 446 bbls AS IIILW, 368 bbls Class 5190' 4393' G, 60 sx AS 1 SCREEN 467' 4" X 4.5" N/A 4413' - 4880' 3616' - 4083' Perforation depth: measured 4524' - 4554', 4588' - 4608', 4635' - 4650', 4692' o 4722', 4746' - 4776', 4820' - 4828', 4862' - 4870' true vertical 3727' - 3757', 3791' - 3811', 3838' - 3853', 3895' - 3925', 3949' - 3979', 4023'- 4031', 4065'- 4073' Tubing (size, grade, and measured depth 3-1/2", 9.3#, L-80 Tbg @ 4365' MD ' '! !!'!I-',. ix .... , r' ,"'; Packers & SSSV (type & measured depth) Baker Gravel Pack SC1 packer @ 4413' No SSSV Alaska 0~1 & ~..~ Cons. ~J0mmissi0n 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sk~t~'3,'~!~ 14. Estimated date for commencing operation 15. Status of well classification as: May 1,2002 16. If proposal was verbally approved Oil __X Gas __ Suspended __ Name of approver Date approved Service 17.1 hereby ce~,~ify tl~t~e foregoing is/tJ~,p~d correct to the best of my knowledge. Questions? Call Skip Coyner 265-6074 Signed ~- ........ ,,~ Title: Drilling Engineering Supervisor Date C Malla~ / / ~..Prepared by Sharon AIIsup-Drake 263-4612 ........ (.,.// FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness 'Z~_~'~ ~,~Tt ~,~,.'~ ~,,\ w,.,,~,~.~"~ ~.~ Plug integrity ~vBOP Test'~_ Location clearance __ . Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission Commissioner Date ? ~.".'.~.. Jla,_ - L ;,,3imy 0echsh Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE , , , 10. 11. Notes: - Make up torque for 3-1/2", 9.3~, L-80, EUE: 2400 min, 3200 opt, 4000 max. - Check the torque in every cplg. - Change out Atlas-Bradford seal rings in all cplgs that have been broken out - Drift all the 3-1/2" tubing and GLM's to 2.867", except the "DS" nipples. the SC-1 packer. Sting into the packer bore '/7 Tag + half way (bur, one seal) and test the "E" anchor, packer and IA to 1000 psi. Bleed off the pressure, slack off and latch the 'E" anchor in the SC-1 packer. Pick up + 15,000# and test the latch. Pick up and shear the PBR, pull up + 3' and mark the pipe. Space out using the new mark and measurements from step #3 so that the PBR Iocator is 3' above the T/PBR. Install the tubing hanger. Pump a 25 bbl Hi-Vis sweep followed by 150 bbl of clean brine with corrosion inhibitor. Displace the tubing with 40 bbl of brine. Sting into the PBR and land the hanger. RILDS. Test the tubing against the IBP to 2500 psi for 30 minutes on chart. Bleed the tubing pressure off. Lay down the landing joint and install BPV. ND BOP stack and NU the new injection tree. Confirm that the wing valve alignment is the same as the original. Pull BPV. Install test plug. Test tree to 250 and 3500 psi. Pull the test plug. Pressure up the tubing to 1000 psi. Pressure test the IA to 3000 psi for 30 minutes on chart. Hold 3000 psi on the IA and bleed off the tubing to shear the RP shear valve in the top GLM. Circulate the tubing and IA with diesel to freeze protect. Set a BPV & VR plug. 12. RDMO Nabors 245. Post-rig Work: , 2. 3. 4. 5. Pull the BPV. RU Slickline. Replace the RP shear valve with a DGLV. Retrieve the IBP. Re-connect flow lines, etc. Re-set the well house. 4/08/02 2 Version 1 Status: Workover Procedure West Sak Oil Producer on artificial lift (ESP) Pre-Ri.q: 1. RU SLU. Retrieve the GLV from the mandrel at 4243' MD. 2. Optional: run a Kinley (or PDS) caliper in the tubing. RD SLU. 3. Freeze protect the well and flowtine. Set a BPV. 4. Remove the well house. Workover/Conversion: 1. MIRU Nabors 245E./Pull the BPV. Circulate the well with 50 bbl of hot diesel followed by heated, clean seawater through the GLM at 4243' MD taking returns down the flowline. Ensure that the well is dead. Keep the hole full. . Re-install BPV and ND tree. NU BOPE. Function test BOPE. Pull BPV. Install test plug. Test rams, annular and choke manifold to 250/3500 psi.~Minimum 24 hours notification to AOGCC is required prior to nipplin.q up and testing). 3. Screw into (or spear) the tubing. BOLDS, pull hanger to floor. 4. POOH standing back 3-1/2" tbg. Spool heat trace and ESP cable onto drums. ,/ 5. Run 3-1/2" injection completion. Stab the "E" anchor seals into SC-1 packer and test the seals to 1000 psi to confirm the seal bore of the packer is still good. Slack off and latch the "E" anchor in the SC-1 packer. Shear out of the PBR and space out the tubing string. Sting back into the PBR and land the hanger. RIDLS. Re-test the IA and packer seals to 2500 psi on chart for 30 minutes, l~r,.~,~- ~ 3"t(:Y~"~,Fk') v/ 6. Pull landing joint. Install BPV. ND BOP stack and NU tree. Pull BPV. Install test plug. Test tree to 250 and 5000 psi. Test packoff to 5000 psi. Pull test plug. ¢-- , Increase the IA pressure and shear the RP shear valve. Displace well with seawater and corrosion inhibitor. Freeze protect the well by pumping + 75 bbl of diesel down the IA. Shut in the IA. Bullhead + 20 bbl of diesel down the tubing. Shut in the well. Monitor and record SICP and SITP. 9. Set BPV and RDMO Nabors 245E. / 10. Turn the well over to Production via handover form. Post-Riq' 1. RU SLU. Pull the BPV. Replace the RP shear valve with a DGLV. RD SLU. 2. Hook up the flowlines and re-set the wellhouse. 3. Run an MIT on the IA. 2/27/02 I Version 1 WEST SAK '1D-117 Current Schematic PHILLIPS Alaska, Inc. A Subsidiary' of PHILLIPS PETROLEUM COMPANY 16" 62.5# H-40 @ 121' MD Stage Tool 2073' MD Depths are based on original RKB Parker 245 3-1/2" Vetco-Gray Tubing Hanger w/3-1/2" L-80 EUE 8rd Mod Pup Joint,ESP Power Cable Penetrator, Heat Trace Penetrator and TEC Wire Penetrator. 3-1/2" 9.3~ L-80 EUE 8rd Mod Spaceout Pups as Required for Heat Trace. Raychem Heat Trace @ +/- 2276' MD Directional KOP = 250' Max Angle = 49.76 Deg @ 28'16' Avg Angle Thru W. Sak = +1- 1.5 Deg 3~1/2" 9.3# L-80 EUE 8rd Mod Tubing to Surface. 3-1t2" x 1" Camco 'KBMM' GLM run open. Handling pups installed on top and bottom. After the rig moves off location, the wells group will install a Shear Circulating Valve (pinned for 3000 psi Tbg / Csg differential). I Joint 3-1/2" 9.3~ L-80 EUE 8rd Mod Tubing. 1 Joint 3-1/2" 9.34¢ L-80 EUE 8rd Mod Tubing. Baker Sentry BHP Gauge (attached to 2nd 10' Pup Joint above the Slotted Nipple). 10' Spaceout Pup 3-1/2" 9.3~ L-80 EUE 8rd Mod Tubing 10' Handling Pup 3-1/2" 9.3~ L-80 EUE 8rd Mod Tubing Centrilift ESPCP (components as listed below) w/bottom set @ 4,365' MD (total length = 26.8') Centrilift 3-1/2" Slotted Nipple. Centdliff TTC Changeover Centriliff Single Seal Section: GSB3 DB ILH6PSF Centriliff PC Pump and Flex Shaft Assembly: KUDU 80TP2000 Centriliff Gear Reduction Unit: 525 Series, 9:1 Centrilift Motor: 57 HP KMH 1315/26 Centrilift Motor Centralizer Baker Model SC-1 Packer @ 4413' MD D-Sand Perfs: 20 SPF 4524' - 4547' Frac'd w/Carbolite and Prop Lock 16 SPF 4547' - 4554' Frac'd w/Carbolite and Prop Lock B-Sand Perfs: 16 SPF 4588' - 4608' Frac'd w/Carbolite and Prop Lock A4-Sand Perfs: 4 SPF 4635' - 4640' Frac'd wi Carbolite and Prop Lock 12 SPF 4640 - 4650' Frac'd w/Carbolite and Prop Lock A3-Sand Perfs: A2.-Sand Perfs: 4 SPF 4692' - 4722' Frac'd wi Carbolite and Prop Lock 8 SPF 4746' - 4776' Frac'd w/Carbolite and Prop Lock 12 SPF 4820' - 4828' Al-Sand Perfs: 12 SPF 4862' - 4870' Bridge Plug @ 4880' MD (10' Below Bottom Perforation). PBTD @ +/- 5060' MD (Gemoco Insert Shut-Off Baffle). Drillers TD @ 5205' MD 7~5/8" 29.7# L-80 BTC Mod @ 5190' MD TJM 2/27/02 WEST SAK 1D-117 Proposed Schematic PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 16" 62.5# H-40 @ 121' MD Stage Tool @ 2073' MD Depths are based on original RKB Parker 245 3-1/2" Vetco-Gray Tubing Hanger w/3-1/2" L-80 EUE 8rd Mod Pup Joint,ESP Power Cable , Heat Trace and TEC Wire Penetrator blanked off. 3-1/2" 9.3# L-80 EUE 8rd Mod Spaceout Pups as Required Camco "DS" Nipple (2.813" ID) at +/- 500' MD Directional KOP = 250' Max Angle = 49,76 Deg @ 2816' Avg Angle Thru W.Sak = +/- 1.5 Deg 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to Surface. 3-1/2" x 1" Camco 'KBMM' GLM wi RP Shear Valve (pinned for 2900 psi). 1 Joint 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing. "E" anchor seal nipple & PBR to latch into the SC-1 PKR & provide "floating seals" Baker Model SC-1 Packer @ 4413' MD D-Sand Perfs: 20 SPF 4524' - 4547' Frac'd w/Carbolite and Prop Lock 16 SPF 4547' - 4554' Frac'd w/Carbolite and Prop Lock B-Sand Perfs: A4-Sand Perfs: A3-Sand Perfs: A2-Sand Perfs: A1-Sand Perfs: 16 SPF 4588' - 4608' Frac'd wi Carbolite and Prop Lock 4 SPF 4635' - 4640' Frac'd w/Carbolite and Prop Lock 12 SPF 4640 - 4650' Frac'd w/Carbolite and Prop Lock 4 SPF 4692' - 4722' Frac'd w/Carbolite and Prop Lock 8 SPF 4746' - 4776' Frac'd w/Carbolite and Prop Lock 12 SPF 4820' - 4828' 12 SPF 4862' - 4870' Bridge Plug @ 4880' MD (10' Below Bottom Perforation). PBTD @ +/- 5060' MD (Gemoco Insert Shut-Off Baffle). 7-5/8" 29.7# L-80 BTC Mod @ 5190' MD Drillers TD @ 5205' MD TJM 2/11/02 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. R. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 March 5, 2002 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 1D-117 Application for Sundry Approval (APD 197-237) Dear Commissioner: Phillips Alaska, Inc. hereby files this Application for Sundry Approval to workover the West Sak well 1D-117. This workover will be to convert the well from producer to injector. / If you have any questions regarding this matter, please contact Skip Coyner at 265-6074. Sincerely, Drilling Engineering Supervisor PA1 Drilling CRM/skad k~LL NUlfBER 117 :JELL Casing Shoe: %lqO MD ~$TVD; DV: .MD .TV'D - inet · Shoe -ubTM: ~ Y~ Packer Sole S~'-' O.'y~ '~ TVD; TOP: !-~ TVD : Sec ar -- iNTEGRITY - P.~RT t! Annulus Press Test: ; 15 m in ; 30 >~--C. R~2NiC;_L' iNTEGRITY - PART ; 2 Cemen~ Volumes :' J~nt. Liner ; Csg ; DV Cmt vol to dover perfs 2"~. $g Theoretical TOC Stgv~--- M~.~.c,~ ¢,~' Cement BOnd Log (Yes or No). f ; In AOGCC File .Production Log: T~e '; Evaluation CO ¢iLUszo s: ' .. P art PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 February 13, 2001 Mr. Daniel T. Seamount, Jr. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations - 1D-117 Dear Mr. Commissioner: Phillips Alaska, Inc. hereby files this Report of Sundry Well Operations to cover the recent workover operations on this well. If you have any questions regarding this matter, please contact me at 265-6434 or Pat Reilly at 265-6048. Sincerely, J. Trantham Drilling Engineering Supervisor PAl Drilling JT/skad STATE OF ALASKA '- ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well ._X Other __X ESP change-out 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): Phillips Alaska, Inc. Development X. RBK 41' 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service _~. Kuparuk River Unit 4. Location of well at surface: 8. Well number: 91' FNL, 597' FEL, Sec. 23, T11N, R10E, UN 1D-117 At top of productive interval: 9. Permit number/approval number: 1037' FSL, 1223' FWL, Sec. 13, T11 N, R10E, UN " 97-237 / 300-264 At effective depth: 10. APl number: 50-029-22844-00 At total depth: ! 1. Field/Pool: 1051' FSL, 1214' FWL, Sec. 13, T11 N, R10E, UN Kuparuk River Field / West Sak Oil Pool 12. Present well condition summary Total Depth: measured 5205' Plugs (measured) bridge plug @ 4880' true vertical 4408' Effective Deptl measured 4880' Junk (measured) true vertical 4083' Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 9 cu yds High Early 121' 121' Surface 5149' 7.625" 446 bbls AS IIILW & 5190' 4393' 368 bbls Class G & 60 sx AS I Screen 467' 4" x 4.5" 4413'-4880 3616'-4083 Production Liner Perforation Depth measured 4524'-4554', 4588'-4608', 4635'-4650', 4692'-4722', 4746'-4776' 4820'-4828', 4862'-4870' true vertical 3727'-3757', 3791'-3811' 3838'-3853', 3895'-3925', 3949'-3979' 4023'-4031' 4065'-407~ Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @4365' Packers and SSSV (type and measured depth) Baker Gravel Pack SCl packer @ 4413', No SSS~ 13. Stimulation or cement squeeze summary Intervals treated (measured~ N/A Intervals treated (measured) 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~ Oil __X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. -- Signed O,.~.,.~.~ [ f"l,~.~~ Title:'~'t~ E.~ ¢' ~"~.~¢ Date I,'~ F~ "~,.~..~'~J Form 10-~)4 Rev 06/15/88 i SUBMIT IN DUPLICATE Date: 12/01/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:iD-117WO RIG:NORDIC 3 STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: WEST SAK BLOCK: SPUD:10/31/00 START COMP:10/31/00 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22844-00 10/31/00 (C1) TD: 5205' PB: 5060' 11/01/00 (C2) TD: 5205' PB: 5060' 11/02/00 (C3) TD: 5205' PB: 5060' 11/03/00 (C4) TD: 5205' PB: 5060' 11/04/00 (C5) TD: 5205' PB: 5060' SUPV: PUMP 50 BBL'S DIESEL FOLL MW: 9.0 KCL Move rig from 1D-140ML to 1D-117 WO. Accept rig for operations @ 1330 hrs. 10/31/00. Spot rig over 1D-117. PJSM. Pump KC1 seawater down tubing. RIH TO 4676' TAG FRAC SAN MW: 9.0 KCL SUPV:DONALD L. WESTER Continue well kill. Pump warm diesel down tubing followed by seawater. Displace with brine. ND tree. NU BOPE. Test BOPE 250/3500 psi. Circulate well with clear brine. Monitor well dead. PJSM. POOH stand back 3.5" tubing. P/U RUN & SET BAKER 7-5/8 MW: 9.0 3KCLSW SUPV:DONALD L. WESTER Continue to P/U 3.5" PH6 work string RIH w/ BHA ~1 6" mill. Tagged up @ 4676' Clean out frac sand and pea gravel. POH for perforating. PJSM. Perforate using 4.5" HSD frac guns. Made 6 runs and all shots fired. New perfs rUn 91 4862'-4870', run 92 4820'-4828', re-perf run ~3 4640'-4650', run ~4 4588'-4608', run ~5 4544'-4554' & run ~6 4524'-4544' POOH L/D SCRAPERS, DC'S & MW: 9.0 3KCLSW SUPV:DONALD L. WESTER Continue to RIH w/7-5/8" Baker drillable cast iron bridge plug and set @ 4880' POOH. PJSM. RIH w/scrapers tag bridge plug @ 4880'. Short trip w/scrapers back to top scraper and RIH to 4880'. PJSM. Pump caustic soda wash pill. PJSM. Pump DP pickle job. POOH. CONTINUE GRAVEL PACK OPER MW: 9.0 3KCLSW SUPV:DONALD L. WESTER Continue to POOH L/D scrapers mule shoe @ 6 4.75" DC's. PJSM. Fire drill. Run 4" x 4.5" x 37' Baker screens. RIH to 4880'. Drop ball set Baker 7-5/8" top packer @ 4413'. PJSM. Start gravel packing screens. Date: 12/01/00 ARCO ALASKA INC. WELL SUFRVLARY REPORT Page: 2 11/05/00 (C6) TD: 5205' PB: 5060' 11/06/00 (C7) TD: 5205' PB: 5060' CONTINUE RUNNING ESP PUMP MW: 9.0 3KCLSW SUPV:DONALD L. WESTER Continue gravel pack operation prestressed gravel pack with sand. POOH. R/U to run 3.5" ESP completion. PJSM. Run ESP pump and heat trace on 3.5" tubing. RIG RELEASED @ 1330 HRS 1 MW:15.7 DOILW SUPV:DONALD L. WESTER Finish running completion. ND BOPE. N/U tree and test to 250/5000 psi. Test ESP cable before pumping diesel. Pump diesel for freeze protection. Release rig @ 1330 hrs. 11/6/00 . ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS-~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well Alter casing _ Repair well _X Plugging _ Time extension _ Stimulate _ Other_ Change approved program _ Pull tubing _ Variance _ Perforate _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 41 feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 91' FNL, 597' FEL, Sec. 23, TllN, R10E, UM 1D-117 At top of productive interval 9. Permit number / approval number 1037' FSL, 1223' FWL, Sec. 13, T11 N, R10E, UM 97-237 At effective depth 10. APl number 50-029-22844-00 At total depth 11. Field / Pool 1051' FSL, 1214' FWL, Sec. 13, T11 N, R10E, UM Kuparuk River Field/West Sak Oil Pool 12. Present well condition summary Total depth: measured 5205 feet Plugs (measured) true vertical 4408' feet Effective depth: measured 5060 feet Junk (measured) true vertical 4263' feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 16" 9 cu yds High Early 121' 121' Surface 5149' 7.625" 446 sxAS IIILW, 368 sx Class G 5190' 4393' & 60 sx AS I Production Perforation depth:: measured 4524'-4554', 4588'-4608', 4635'-4650', 4692'-4722', 4746'-4776' true vertical 3727'-3757', 3791'-3811', 3838'-3853', 3895'-3925', 3949'-3979' Tubing (size, grade, and measured depth 3.5", 9.3#, L-80 @ 4435' MD Packers & SSSV (type & measured depth) No packer, No SSSV 13. Attachments Description summary of proposal ~ Detailed operations program Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic __ 14. Estimated date for commencing operation 15. Status of well classification as: October 30, 2000 16. If proposal was verbally approved Oil __X Gas __ Suspended __ Name of approver Date approved Service __ 17. I hereby c~rlify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mark Chambers 265-1319 Signed ..,,% , ~ Title: Drilling Engineering Supervisor Date James Trantham Prepared by Sharon Allsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Append. Plug integdty ~ BOP lost ff Location clearance __ Mechanical Integr~y lost __ Subsequent form roquired ORIGINAL SIGNED BY' Approved by order of the Commission O Ts,¥1or SesITIOURt Commissioner Date //~/-,-~ ~,/~-~ Uv Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE West Sak 1D-117 General Workover Procedure Pre-Riq Procedure: 1. RU CTU. R[H and cleanout fill to top of pump. 2. RU Slickline Unit. RTH and pull shear valve from GLM @ 4,306' leaving an open pocket. 3. Set BPV in tubing. 4. Prepare location for Nordic 3. General Workover Procedure: 1. M1~RU Nordic Rig 3. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits with 9.0 ppg filtered 3% KCL kill weight brine. Displace tubing and annulus with kill weight brine. SI: well and monitor pressure to ensure well is dead. Set BPV. 3. ND/NU and test BOPE. 4. Screw in landing joint. POOH standing back 3-1/2" tubing and spooling up ESP Cable and Heat Trace. 5. Load, strap and dri~ 3-1/2" workstring. 6. R~H w/clean out assembly, PU 3-1/2" workstring off rack, and clean out fill to PBTD. 7. POOH standing back 3-1/2" workstring. 8. RTH w/tubing conveyed perforating guns. Perforate 7-5/8" casing as per design. 9. POOH standing back 3-1/2" workstring. ~-i:'?-~ :: ~:':-:-'.-~'..~. ~.: i:'~:!:"?~: , : i::?:'': 10. R~H w/bridge plug. Set top of Bridge Plug @ +/- 4,880' MD. , ~ ::':':'".- © '::i ..... 1:l. POOH standing back 3-1/2" workstring. ,,. !:~!,,!;-!:::.:i~ii :i !'!'~. !"i.~ "i1~ '.':7.' ;:i':::~.;'.':-~;!~i::! :: 12. RIH w/muleshoe and dual scraper assembly. Pump caustic wash and pickle. :13. POOH standing back 3-1/2" workstring. :14. RZH w/gravel pack assembly. Set gravel pack packer @ +/- 4414' MD and perform gravel pack as per design. :15. POOH laying down 3-:¥2" workstring. :16. RIH w/3-1/2" tubing and ESP Assembly. Space out heat trace and splice power cable and Z-wire to penetrators. 17. Land tubing hanger. R;[LDS, install two-way check and test tubing hanger. 18. ND/NU/Test 19. Freeze protect with diesel to +/- 2000' TVD. Lower Limit: 7.0 days No problems encountered. Expected Case: 8.0 days Upper Limit: 9.0 days Problems pulling ESP, cleaning out or gravel packing ~4AC 10118100 WEST SAK 1D-117 Workov¢-" Proposed Schematic Standard Frac For Sand Control FFSC to FFSCGP ARCO Alaska, Inc. H-40 3" 62.5# J @ 121' MD :3tage Tool 2073' MD Depths are based on original RKB Parker 245 !__ 3-1/2" Vetco-Gray Tubing Hanger w/3-1/2" L-80 EUE 8rd Mod Pup Joint, ESP Power Cable Penetrator, Heat Trace Penetrator and TEC Wire Penetrator. 3-1/2" 9.3# L-80 EUE 8rd Mod Spaceout Pups as Required for Heat Trace. Raychem Heat Trace @ +/- 2276' MD Directional KOP = 250' Max Angle = 49.76 Deg @ 2816' Avg Angle Thru W.Sak = +/- 1.5 Deg 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to Surface. 3-1/2" x 1" Camco 'KBMM' GLM run open Handling pups installed on top and bottom. After the rig moves off location, the wells group will install a Shear Circulating Valve (pinned for 3000 psi Tbg / Csg differential). 1 Joint 3-1/2" 9.3# L.-80 EUE 8rd Mod Tubing. 1 Joint 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing. Baker Sentry BHP Gauge (attached to 2nd 10' Pup Joint above the Slotted Nipple). 10' Spaceout Pup 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing 10' Handling Pup 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing Centrilift ESPCP (components as listed below) w/bottom set @+/- 7,154' MD (total length = 26.8') Centrilift 3-1/2" Slotted Nipple. Centrilift TTC Changeover Centrilift Single Seal Section: GSB3 DB ILH6PSF Centrilift PC Pump and Flex Shaft Assembly: KUDU 80TP2000 Centrilift Gear Reduction Unit: 525 Series, 9:1 Centrilift Motor: 57 HP KMH 1315/26 Centrilift Motor Centralizer Baker Model SC-1 Packer @ +/- D-Sand Perfs: B-Sand Perfs: A4-Sand Perfs: A3-Sand Perfs: A2-Sand Perfs: Al-Sand Peds: 4414' MD (110' above top perforation). 8SPF 4SPF Plan to 4524' - 4547' Frac'd w/Carbolite and Prop Lock (Existing Perforations) 4547' - 4554' Frac'd w/Carbolite and Prop Lock (Existing Perforations) Re-Perforate from 4524' to 4554' @ 12 SPF 4 SPF 4588' - 4608' Frac'd w/Carbolite and Prop Lock (Existing Perforations) Plan to Re-Perforate from 4588' to 4608' @ 12 SPF 4 SPF 4635' - 4650' Frac'd w/Carbolite and Prop Lock (Existing Perforations) Plan to Re-Perforate from 4640' to 4650' @ 12 SPF 4 SPF 4692' - 4722' Frac'd w/Carbolite and Prop Lock (Existing Perforations) 8 SPF 4746' - 4776' Frac'd w/Carbolite and Prop Lock (Existing Perforations) Plan to Add Perforations From 4820' to 4828' @ 12 SPF Plan to Add Perforations From 4862' to 4870' @ 12 SPF Bridge Plug @ +/- 4880' MD (10' Below Bottom Perforation). PBTD @ +/- 5060' MD (Gemoco Insert Shut-Off Baffle). 7-5/8" 29.7# L-80 BTC Mod @ +/- 5190' MD Drillers TD @ 5205' MD MAC 10/18/00 11" 5000 psi BOP Stack Kuparuk River Unit West Sak Operations- Producer Wells ~J 6 4 2 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 3000 psi for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with Koomey pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 13-3/8" Landing Ring 2. 11" 5000 psi Horizontal Tubing Head 3. 11" 5000 psi Pipe Rams 4. 11" 5000 psi Drilling Spool with Choke and Kill Lines 5. 11" 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 6. 11" 5000 psi Annular Preventer MAC 3/15/OO 197-237-0 K-LIPARUK RIV U WSAK 1D-117 50- 029-22844-00 ARCO MD 05205 TVD 04408 Completion Date: 2/22/98 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D D 8242 OH 1/28/98 1/28/98 2 L CMT MAP LOG CH 2/23/98 2/26/98 L DGR/EWR4-MD ~'~ 120-5205 OH 1/28/98 1/28/98 L DGR/EWR4-TVD ~AL~ 121-4408 OH 1/28/98 1/28/98 R MWD SRVZ ~-5205. OH 1/29/98 2/4/98 Daily Well Ops/~-J, Was the well coredg--y--ea_.ll.~L..._~ Are Dry Ditch Samples Required? yes ~_~,,And Received?.-,~$-a~~ Analysis D e s c r ipti~n-R'e~~'3~--~n o Sam, p~-~-~ ........ Comments: ?' Thursday, February 03, 2000 Page 1 of 1 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 9, 1999 Mr. Robert Christenson Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: P,equest to Commingle Test Production frd'~20~d W-200 Wells Dear Chairman Christenson: As you are aware, BP as PBU WOA Operator on behalf of the lease owners, has drilled two Schrader test wells in the PBU WOA and requested approval of a Pilot Production Plan. S-200 (aka SB-01) bottomed on T12N-R12E UM Sec. 27 within ARCO/Exxon lease ADL 28258. W- 200 (aka SB-02) bottomed on Sec. T11N-P, 12E Sec. 21 within Mobil/Phillips/Chevron lease ADL 28263. Both wells have been briefly tested from various Schrader Bluff formation intervals, but additional appraisal completion or testing work remains to be performed before the pilot period. Both wells will be completed in the Schrader Bluff formation, no approval is requested for downhole commingling with formations other than the Schrader Bluff. The wellwork is expected to be performed in September and October 1999. Production testing is not expected to exceed seven days per well. Consistent with existing practices, BP requests approval by the AOGCC on behalf of ARCO/Exxon and Mobil/Phillips/Chevron to commingle production with other pools for processing at PBU Gathering Center 2 during the testing period. Production allocation will be based on the existing well test methodology approved by the AOGCC, based on well tests conducted at S and W pads. Similar approval was granted by letter of 12/18/97. BPX will undertake to advise the Division of the status of well operations in a timely manner. If you have any questions, please contact Steve Deckert at (907) 564-4128. Sincerely, Jo'~ Hurliman, Team Leader Central North Slope- Western Developments CC: K. Boyd - Department of Natural Resources M. Evans - Exxon Company, U.S.A. W. Fennell- Chevron U.S.A., Inc. J. Hollier- Mobil Exploration & Production U.S., Inc. J. Johnson - Phillips Petroleum Company J. Pilkington - Department of Revenue G. Pospisil - ARCO Alaska, Inc. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 14, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1 D- 117 (Permit No. 97-237) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak 1D-117. If there are any questions, please call 265-6890. Sincerely, /', ----. T. W. Mc Kay Senior Drilling Engineer Kuparuk Development TWM/skad ~.PR. I t; 1998 Al~k~ Oil & Ga~ Con..,. Co,mmi~b~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~] GAS E~ SUSPENDED [--1 ABANDONED~ SERVICE 2 Name of Operator 7 Pe~it Number ARCO Alaska, Inc 97-237 3 Address 8 APl Number P.O. Box 100360, Anchora~e, AK 99510-0360 50-029-22844 4 Location of well at sudace ~ ?,~}~.~,~,?'~.~-;'~[.} '} . 9 Unit or Lease Name ' ~/~¢~ 91 FNL, 597' FEL, Sec. 23, T11N, R10E, UM ~/~' ~ J~ At Top Producing Inte~al 1037' FSL, 1223' ~L, Sec. 13, T11N, R10E, UM ~ ~l~:;J"~":~;:~ ~ I[~~ ~ West Sak 1D-117 At Total Depth .: -~ ...... ~ ~.~ ~ 11 Field and Pool 1051' FSL, 1214' ~L, Sec. 13, T11N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) ~ 6 Lease Designation and Sedal No. West Sak Oil Pool RKB 41', Pad 71'~ ADL 25650 ALK 468 12 Date28.Dec_97Spudded 13 29-Dec-97Date T.D. Reached 14 22-Feb-98Date Comp., Susp. or Aband. 15 WaterNADepth, if offshorefeet MSL 16 No.1 of Completions 17 Total Depth (MD+~D) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey ~20 Depth where SSSV set 21 Thickn~s of permafrost 5205' MD & 4408' ~D 5060' MD & 4263' ~D YES ~ NO ~ NA feet MD 1884' APPROX 22 Type Electric or Other Logs Run GR/Res, FDC/CNL, CCL 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECO~D 16' 62.58~ H-40 SURF. 121' 24' 9 cu yds High Eady 7.625" 29.7~ L-80 SURF. 5190' 9.875" 446 sx AS III LW, 368 sx Class G, 60 sx AS I 24 Pedorations open to Production (MD+~D of Top and BoEom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5' 4435' 4746'-4776' MD 3949'-3979' ~D 4635'-4650' MD 3838'-3850' ~D 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4588'-4608' MD 3791'-3811' ~D DEPTH INTERVAL (MD) M AMOUNT & KIND OF MATERIAL USED 4524'-4554' MD 3727'-3757' ~D 4746'-4776' MD, 4635'-4650' see a~achments 4 spf ~88'-~08' MD. 4524'-~' MD Date First Production4/4/98 Method of OperatiOnGas(FIowing,Lift gas lift, etc.) Date of Test Hours Tested PRODUCTION Fei OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE [ GAS-OIL RATIO 4/11/98 6.00 TEST PERIOI: 52 3 33 0~ 75 Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVIS-APl (corr) Press. 141 -]5 24-HOUR RATE: 200 15 131 0° 28 CQRE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure dafa, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak Sand 4519' 3722' Base West Sak Sand 4955' 4158' Annulus left open - freeze protected with diesel. 31. LIST OF ATrACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. _ , INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 4/13/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:ID-ii7 WELL_ID: AK8997 TYPE: AFC: AK8997 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:12/28/97 START COMP:03/29/98 RIG:NORDIC BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22844-00 03/29/98 (C8) TD: 5205' PB: 5059' SUPV:MC/B 03/30/98 (C9) TD: 5205' PB: 5059' SUPV:MC/B 03/31/98 (Ci0) TD: 5205' PB: 5059' SUPV:DLW 04/01/98 (Cll) TD: 5205' PB: 5059' SUPV:DLW 04/02/98 (C12) TD: 5205' PB: 5059' SUPV:DLW 04/03/98 (C13) TD: 5205' PB: 5059' SUPV:DLW ACCEPT RIG 3/29/98 MW: 8.8 BRINE Move rig to 1D-117. Accept rig 3/29/98 1000 hrs. Test BOPE 300/3000 psi. POOH W/CLEANOUT ASSEMBLY MW: 8.7 BRINE POOH with 3.5" frac string. RIH with 6.75" cleanout assembly. Clean out frac sand from 4494' to 5049' CONTINUE C/O MW: 8.8 KCL Continue circulating and clean wellbore. Unable to reverse circulate. RIH w/3.5" tubing. Circulate long way. Try to reverse circulation plug pipe. RUN R/A TRACER LOG MW: 8.6 KCL After reverse circulating complete hole volume from PBTD 5060' Try to POOH tight. Run back to bottom. Circulate out carbolite, rubber and gun debris. Displace viscosified completion fluid with caustic SL flush followed by filtered KC1 fluid. Continue circulating and filtering to lower NTU's. Continue circulating and filtering completion fluid to lower NTU's. Having trouble getting fluid to clean up. Displace hole volume. FREEZE PROTECT W/DIESEL MW: 8.7 2KCL Run Protechnics RA tracer log across perforated zones. Run 3.5" tubing w/ESP and heat trace cable. RELEASED RIG @ 1230 HRS 4 MW: 0.0 ND BOPE. N/U tree, test packoff to 5000 psi, test tree to 250/5000 psi. Release rig @ 1230 hrs. 4/3/98. End of WellSummary for Well:AK8997 Date: 4/14/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-ii7 WELL_ID: AK8997 TYPE: AFC: AK8997 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:12/28/97 START COMP:03/29/98 RIG:NORDIC BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22844-00 12/27/97 (D1) TD: 121'(121) SUPV:GRW MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 DRILLING @ 400' Move rig 30' form 1D-115 to 1D-117. N/U diverter system. 12/28/97 (D2) TD: 2782' (2661) SUPV:GRW 12/29/97 (D3) TD: 5205'(2423) SUPV:GRW 12/30/97 (D4) TD: 5205'( SUPV:GRW o) 12/31/97 (D5) TD: 5205'( SUPV:GRW o) 01/01/98 (D6) TD: 5205'( SUPV:GRW o) 01/02/98 (D7) TD: 5205'( SUPV:GRW o) MW: 9.2 VISC: 300 PV/YP: 26/42 APIWL: 8.2 DRILLING @ 3700' Function test diverter. Drill from 121' to 2782' MW: 9.0 VISC: 220 PV/YP: 26/34 RIH W/HOLE OPENER Drill from 2782' to 5205' APIWL: 6.8 MW: 9.4 VISC: 105 PV/YP: 27/33 APIWL: 7.4 N/U BOPE Run 7-5/8" casing to 5190'. Cement first stage cement. MW: 8.9 VISC: 49 PV/YP: 8/24 APIWL: 20.0 MAKING SCRAPER RUN Cement 2nd stage cement. N/D diverter. N/U BOPE. Test to 300/2000 psi. Drill stage collar ~ 2072' Drill cement from 4765' to 5059' MW: 8.3 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 PREPPING TO MOVE RIG Run 3.5" tubing. Displace hole w/Hogwash. Freeze protect well. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED N/U tree. Test packoff - leaking to tree. Pull tree and install new packing. Install tree. Test packoff to 5000 psi - OK. Test tree to 4700 psi. Release rig @ 1200 hrs. 1/2/97. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-117(W4-6)) WELL 1D-117 DATE 01/2 7/98 DAY 1 JOBSCOPE PERFORATE, PERFSUPPORT DALLY WORK RUN SCMT CEMENT BOND LOG AND PERFORATE 30'2 1/8" EJ BH OPERATION COMPLETE SUCCESSFUL I KEY PERSON YES YES I SWS-BAILEY JOB NUMBER 0122980220.1 UNIT NUMBER 8337 SUPERVISOR JORDAN Initial Tbg Press 0 PSI Final Tbg Press 0 PSI Initial Inner Ann 1 I 0 PSI Final Inner Ann I I 0 PS! Initial OuterAnn I 0 PSI I Final Outer Ann 0 PSI DALLY SUMMARY RUN SCMT CEMENT MAPPING TOOL. SHOWED MICROANULUS AS CEMENT IMPROVED WITH INCREASING WHP. SHOT 2 I 1/8" EJ BH FROM 4746' TO 4776', 4 SPF. I TIME LOG ENTRY 07:00 MIRU SWS # 8337 W/BAILEY - MASCARELLA - WOOTEN. HOLD BUMPER SAFETY MEETING. 08:00 15:00 17:00 18:20 19:00 20:30 PFF WHE TO 3000 PSI. RIH W/SCMT-GR-CCL. LOG NUMEROUS PASSES CHANGING CALIBRATIONS. SINCE THERE WAS NO 100% FREE PIPE, TOOL WAS RECALIBRATED USING VARYING REFERENCE UNTIL CEMENT MAP COMPARED FAVORABLY TO VDL. LOGGED WITH 0 PSI, 1000 PSI, AND 2500 PSI SURFACE PRESSURE. MICROANULUS WAS INDICATED BY CEMENT BOND LOG IMPROVEMENT WITH INCREASED SURFACE PRESSURE. AT SURFACE. RIG DOWN SCMT. OBTAIN RADIO SILENCE AND STOP WELDING ON PAD. ARM 2 1/8" EJ BH, 4 SPF, 30'. P/T WHE TO 3500 PSI. RIH W/SWIVEL, CCL-L, MPD-H, 30' 4 SPF EJ BH 0 DEG PHASED & 0 DEG. ORIENTED. TIE IN TO SWS PDC LOG DATED 26-JAN-98. LOG INTO POSITION AT 4741' TO SHOOT FROM 4746' TO 4776'. SHOT GUN WITH GOOD INDICATIONS AT SURFACE ON CURRENT AND TENSION. POOH. ATSURFACE. START FINISH R/D. LEAVE LOC.. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-117(W4-6)) WELL 1D-117 JOB SCOPE FRAC, FRAC SUPPORT JOB NUMBER 0131981536.3 DATE DALLY WORK UNIT NUMBER 02/01/98 "A2" SAND FRAC KEY PERSON DS-YOAKUM DAY OPERATION COMPLETE I SUCCESSFUL 1 YES I NO Initial Tbg Press I Final Tbg Press I Initial InnerAnn 200 PSI 200 PSI 200 PSI DAILY SUMMARY SUPERVISOR CHANEY Final Inner Ann I I 20O PSI Initial Outer Ann I 0 PSI I Final Outer Ann 0 PSI "A2" SAND FRAC SCREENED OUT EARLY. MAXIMUM PRESSURE 3100 PSI & F.G. (.66). INJECTED 25000 LBS OF PROP IN THE FORM W/3.8# PPA OF #16/20 @ THE PERF'S, ALL PROP COATED W/PROPLOCK AND HAS RA TRACER (IRIDIUM) ADDED. TBG AND CSG FREEZE PROTECTED W/DIESEL. TIME LOG ENTRY 12:00 02:00 02:20 03:25 04:15 05:10 MIRU DOWELL FRAC EQUIP, HES PROPLOCK EQUIP, LRS HOT OIL TRUCK, APC VAC TRUCKS, AND PROTECHNICS EQUIP. HELD SAFETY MEETING (20 ON LOCATION). PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 4200 PSI. PUMP IMPULSE TEST W/DIESEL @ 18.5 BPM. SLURRY VOLUME PUMPED 20 BBLS. MAXIMUM AND ENDING PRESSURE 3000 PSI. S/D AND OBTAINED ISIP OF 1117 PSI W/F.G. @ (.64). STOOD-BY AND MONITORED WHTP. PUMP BREAKDOWN W/50# HEC - 3% KCL @ 20 BPM. SLURRY VOLUME PUMPED 120 BBLS. MAXIMUM PRESSURE 3000 PSI AND ENDING PRESSURE 1200 PSI. STEPPED RATE DOWN AT THE END OF THE STAGE. S/D AND OBTAINED ISIP OF 865 PSI W/F.G @ (.66). MONITORED WHTP AND PULSED FOR CLOSURE. CLOSURE TIME 5 MINS @ 780 PSI. PUMP DATAFRAC W/50# HEC - 3% KCL @ 5 TO 20 BPM. SLURRY VOLUME PUMPED 90 BBLS. MAXIMUM AND ENDING PRESSURE 2300 PSI. S/D AND OBTAINED ISIP OF 865 PSI W/F.G. @ (.66). STOOD-BY AND MONITORED WHTP FOR CLOSURE. CLOSURE TIME 4.5 MINS @ 777 PSI. PAD VOLUME = 44 BBLS. PUMP FRAC W/50# HEC - 3% KCL @ 5 TO 20 BPM. SCREENED OUT EARLY. SLURRY VOLUME PUMPED 340 BBLS. MAXIMUM AND ENDING PRESSURE 3100 PSI. PUMPED 33702 LBS OF #16/20 PROP. INJECTED 25000 LBS OF PROP IN THE FORMATION W/3.8# PPA OF #16/20 @ THE PERF'S, ALL PROP COATED W/PROPLOCK AND ADDED RA TRACER (IRIDIUM). REVERSED OUT 5500 LBS OF PROP AND LEFT 3202 LBS OF PROP IN THE WELLBORE. ESTIMATE FILL @ 4950'. TBG AND CSG FREEZE PROTECTED W/DIESEL. 05:30 STARTED R/D. 07:00 08:00 REMOVED TREESAVER (ALL CUPS RETURNED) & CONTINUED R/D. R/D COMPLETED. WELL SECURED AND NOTIFIED DSO OF STATUS. ARCO Alaska, Inc. WELL 1D-117 DATE 02/01/98 DAY 2 DALLY SUMIV JOB SCOPE PERFORATE, PERF SUPPORT DALLY WORK PERFORATE, PERF SUPPORT OPERATION COMPLETE I SUCCESSFUL YES I YES KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-117(W4-6)) JOB NUMBER 0122980220.1 UNIT NUMBER SUPERVISOR BLACK KEY PERSON SWS-DALEBOUT Initial Tbg Press I Final Tbg Press1300 PSI 300 PSI ~ARY Initial Inner Ann Final Inner Ann I 0 PSI 0 PSI I Initial Outer Ann I 0 PSI I Final Outer Ann 0 PSI I RE PERFORATE "A2" FROM 4746 - 4776' ELM W/2-1/8" EJ BH @ 4 SPF, O DEG PHASED & ORIENTED TIME 22:15 LOG ENTRY MIRU SWS (DALEBOUT & CREW). TGSM & JOB OVERVIEW. MU GUN ASSEMBLY (30' 2-1/8" BH/CCL/WT) TL- 35'. PT BOPE TO 2500 PSI. 00:15 RIH TO 4825' ELM & TIE INTO 1/26/98 SWS PDC GR/CCL. PERFORATE FROM 4746 - 4776 W/2-1/8" EJ BH @ 4 SPF, O DEG PHASED & ORIENTED. GOOD SURFACE INDICATIONS. LOG OFF & POOH. 01:45 AT SURFACE. ALL SHOTS FIRED. BEGIN RD. 02:30 RD COMPLETE. OFF LOCATION & READY FOR "A2" REFRAC. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-117(W4-6)) WELL JOB SCOPE JOB NUMBER 1D-117 FRAC, FRAC SUPPORT 0131981536.3 DAILY WORK UNIT NUMBER "A2" SAND FRAC: 2ND ATTEMPT OPERATION COMPLETE I SUCCESSFUL YESI YES Initial Tbg Press I Final Tbg Press 350 PSII 500 PSI DAILY SUMMARY DATE O2/O2/98 DAY 1 SUPERVISOR CHANEY IKEY PERSON DS-YOAKUM 'nitiallnnerAnn IFinailnnerAnn IlnitialOuterAnn IFinaiOuterAnn 350 PSI 500 PSI 0 PSI 0 PSI I"A2 SAND FRAC: 2ND ATTEMPT SCREENED OUT EARLY. MAXIMUM PRESSURE 3000 PSI & F.G. (.66). INJECTED 40150 LBS PROP IN THE FORM W/4.7# PPA OF #16/20 @ THE PERF'S, ALL PROP COATED W/PROPLOCK AND ALSO HAS RA TRACER (SCANDIUM) ADDED. FREEZE PROTECTED TBG AND CSG W/DIESEL. TIME 04:00 06:30 07:30 08:40 10:00 LOG ENTRY MIRU DOWELL FRAC EQUIP, HES PROPLOCK EQUIP, LRS HOT OIL TRUCK, APC VAC TRUCKS, & PROTECHNICS. HELD SAFETY MEETING (20 ON LOCATION) PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 4500 PSI. PUMP BREAKDOWN W/50# HEC - 3% KCL @ 30 TO 25 BPM. SLURRY VOLUME PUMPED 270 BBLS. MAXIMUM PRESSURE 3000 PSI AND ENDING PRESSURE 1350 PSI. S/D AND OBTAINED ISIP OF 796 PSI W/F.G. @ (.65). MONITORED WHTP AND PULSED FOR CLOSURE. PUMP DATAFRAC W/50# HEC - 3% KCL @ 5 TO 25 BPM. SLURRY VOLUME PUMPED 160 BBLS. MAXIMUM PRESSURE 2700 PSI AND ENDING PRESSURE 2550 PSI. S/D AND OBTAINED ISIP OF 847 PSI W/F.G. @ (.66). MONITORED WHTP FOR CLOSURE. CLOSURE TIME 5.2 MINS @ 793 PSI. PAD VOLUME = 110 BBLS. PUMP FRAC W/50# HEC - 3% KCL @ 5 TO 25 BPM. SCREENED OUT EARLY. MAXIMUM AND ENDING PRESSURE 3000 PSI. PUMPED 48901 LBS OF #16/20 PROP. INJECTED 40150 LBS PROP IN THE FORMATION W/4.7# PPA OF #16/20 @ THE PERF'S, ALL PROP COATED W/PROPLOCK AND ALSO HAS RA TRACER (SCANDIUM) ADDED. REVERSED OUT 5500 LBS AND LEFT 3251 LBS IN THE WELLBORE, ESTIMATE TOP OF FILL TO BE @ 4800. FREEZE PROTECTED TBG AND CSG W/DIESEL, BACKSIDE FULL OF DIESEL. 11:00 STARTED R/D. CHECKED ALL LINES AND TANKS FOR RADIATION AND NO HEALTH OR ENVIROMENTAL HAZARDS FOUND. 11:45 12:30 REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. PJD COMPLETE AND ALL EQUIP MOVED FOR ACCESS TO WELL. WELL SECURED AND DSO NOTIFIED OF STATUS. ARCO Alaska, Inc. WELL 1D-117 DATE O2/O6/98 DAY 3 JOB SCOPE FRAC, FRAC SUPPORT DALLY WORK PUMP "A-3" FRAC OPERATION COMPLETE I SUCCESSFUL YESI YES Initial Tbg Press Final Tbg Press 354 PSI 1000 PSI DALLY SUMMARY Initial Inner Ann 1200 PSI KUPARUK RIVER UNIT WELL SERVICE REPORT K1 (1D-117(W4-6)) JOB NUMBER 0131981536.3 KEY PERSON DS-YOKUM UNIT NUMBER SUPERVISOR JOHNS Final Inner Ann I I 1200 PSI Initial Outer Ann I I 0 PSI Final Outer Ann 0 PSI PUMPED 99,256# 16/20 PROPPANT W/PROP-LOK TO PERFS. LEFT 2900# IN PIPE I TIME LOG ENTRY 06:30 MIRU DOWELL FRAC, APC SUPPORT, PROTECNICS, HALLIBURTON PROP LOCK. 07:00 HELD SAFETY MEETING. 08:30 PRIME PUMPS AND PRESSURE TEST TO 4000 # PSI. SET TREE SAVER. 09:08 PUMP 20 BBLS IMPLUSE TEST, 20 BPM AND 3125 PSI. SHUTDOWN FOR 1 HOUR 10:10 PUMP BREAKDOWN, FLUSH AND OVER DISPLACEMENT, 20 BPM AND 2700 PSI. 11:15 PUMP DISPLACEMENT AND DATA FRAC 5 TO 20 BPM AND 2481 PSI. 13:15 PUMP 11 BBLS PAD 13:19 PUMP 102,156 # 16/20 PROPPANT W/PROP-LOK 2#PPA TO 10# PPA TO A-3 SANDS. SCREENED OUT 8 BBLS SHY OF COMPLETE FLUSH. 13:57 REVERSE OUT SLURRY FROM TUBING, LEFT TUBING AND ANNULUS FULL OF DIESEL. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-117(W4-6)) WELL 1D-117 DATE 02/12/98 DAY 4 JOB SCOPE FRAC, FRAC SUPPORT DAILY WORK "A4" SANDS FRAC OPERATION COMPLETE YES Initial Tbg Press 30O PSI DALLY SUMMARY SUCCESSFUL I KEY PERSON YES I DS-GALLEGOS FinalTbg Press I Initial InnerAnn1500 PSI 300 PSI JOB NUMBER 0131981536.3 UNIT NUMBER SUPERVISOR CHANEY Final Inner Ann J I 5OO PSI Initial OuterAnn 1 I 0 PSI Final Outer Ann 0 PSI "A4" SAND FRAC SCREENED OUT EARLY. MAXIMUM PRESSURE 3400 PSI & F.G. (.68). INJECTED 65627 LBS OF PROP IN THE FORM W/7.3# PPA OF #16/20 @ THE PERF'S. LEFT TBG AND CSG FREEZE PROTECTED W/DIESEL. TIME LOG ENTRY 06:30 10:00 MIRU DOWELL FRAC EQUIP, HES PROPLOCK EQUIP, LRS HOT OIL UNIT, APC VAC TRUCKS, AND PROTECHNICS EQUIP. HELD SAFETY MEETING (24 ON LOCATION). PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. PT'D HIGH PRESSURE LINES TO 5200 PSI. A'FFEMPTED TO SET TREESAVER AND UN ABLE TO GET IT DOWN. 10:30 STOOD-BY FOR TREESAVER REPAIR. 13:00 R/U NEW TREESAVER AND PT'D HIGH PRESSURE LINES TO 5000 PSI. SET TREESAVER AND HOLDING. 13:10 PUMP IMPULSE TEST W/DIESEL @ 20 BPM. SLURRY VOLUME PUMPED 20 BBLS. MAXIMUM AND ENDING PRESSURE 3400. S/D AND OBTAINED ISIP OF 1172 PSI W/F.G. OF (.66). STOOD-BY FOR 1 HR AND MONITORED WHTP.CLOSURE PRESSURE 810 PSI. 14:15 15:15 16:25 17:05 PUMP BREAKDOWN W/50# HEC - 3% KOL & DIESEL @ 30 TO 20 BPM. SLURRY VOLUME PUMPED 235 BBLS. MAXIMUM PRESSURE 3100 PSI AND ENDING PRESSURE 1600 PSI. S/D AND OBTAINED ISIP OF 1231 PSI W/ F.G. @ (.68). STOOD-BY AND MONITORED WHTP. PULSED FOR CLOSURE DETERMINATION. CLOSURE TIME 7.3 MINS @ 1180 PSI. PUMP DATAFRAC W/50# HEC - 3% KCL & DIESEL @ 5 TO 20 BPM. SLURRY VOLUME PUMPED 115 BBLS. MAXIMUM PRESSURE 2700 PSI AND ENDING PRESSURE 2400 PSI. S/D AND OBTAINED ISlP OF 1295 PSI W/ F.G. @ (.69). STOOD-BY AND MONITORED WHTP FOR CLOSURE. CLOSURE TIME 4 MINS @ 1231 PSI. PAD VOLUME = 45 BBLS. PUMP FRAC W/50# HEC - 3% KCL @ 5 TO 20 BPM. SCREENED OUT EARLY. MAXIMUM AND ENDING PRESSURE 3400 PSI. PUMPED 79021 LBS OF #16/20 PROP. INJECTED 65627 LBS OF PROP IN THE FORMATION W/7.3# PPA F #16/20 @ THE PERF'S. REVERSED OUT 11300 LBS OF PROP W/120 BBLS OF DIESEL. LEFT 2050 LBS OF PROP IN THE WELLBORE AND EST FILL LEVEL @ 4610'. LEFT TBG AND CSG FULL OF DIESEL. STARTED R/D TIME 18:00 19:30 LOG ENTRY REMOVED TREESAVER (ALL CUPS REMOVED) CONTINUED R/D. R/D COMPLETED AND ALL EQUIP AND PERSONNEL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-117(W4-6)) WELL 1D-117 JOB SCOPE PERFORATE, PERF SUPPORT DATE DALLY WORK 02/12/98 PERFORATE, PERF SUPPORT DAY OPERATION COMPLETE I SUCCESSFUL 4 YES I YES InitialTbgPress IFinalTbgPress IlnitiallnnerAnn 400 PSI 400 PSI 0 PSI DALLY SUMMARY KEY PERSON SWS-ELMORE JOB NUMBER 0122980220.1 UNIT NUMBER SUPERVISOR BLACK Final Inner Ann J I 0 PSI Initial OuterAnn ] 0 PSI I Final Outer Ann 0 PSI PERFORATED "A4" FROM 4635 - 4650' ELM W/2-1/8" EJ BH @ 4 SPF, O DEG PHASED / ORIENTED TIME LOG ENTRY 03:00 MIRU SWS (ELMORE & CREW). TGSM & JOB OVERVIEW. MU GUN ASSEMBLY (15' 2-1/8" EJ/CCL/HD) TL-21'. PT BOPE TO 2000 PSI. 03:45 RIH W/GUN ASSEMBLY TO 4600' ELM. TIE IN W/2/5/98 SWS COMPLETION RECORD & VERIFY W/1/26/98 SWS GR/CCL. PERFORATE "A4" F/4635-4650' ELM W/2-1/8" EJ BH @ 4 SPF, O DEG PHASED, ORIENTED. GOOD SURFACE INDICATIONS. LOG UP & POOH. 05:45 AT SURFACE. ALL SHOTS FIRED. RELEASE RADIO SILENCE & BEGIN RD. 06:15 RD COMPLETE. LEAVE SI F/"A4" FRAC. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-117(W4-6)) WELL 1D-117 DATE 02/14/98 DAY 6 JOB SCOPE PERFORATE, PERF SUPPORT DALLY WORK PERFORATE, PERF SUPPORT OPERATION COMPLETE YES ISUCCESSFUL YES IKEY PERSON SWS-ELMORE Initial Tbg Press 4O0 PSI DALLY SUMMARY Final Tbg Press 400 PSI Initial Inner Ann I I 0 PSI JOB NUMBER 0122980220.1 UNIT NUMBER SUPERVISOR BLACK Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSII 0 PSII 0 PSI PERFORATED "B" SAND FROM 4588 - 4608' ELM W/2-1/8" EJ BH @ 4 SPF, O DEG PHASED / ORIENTED TIME LOG ENTRY 10:00 MIRU SWS (ELMORE & CREW). TGSM & JOB OVERVIEW. MU GUN ASSEMBLY (20' X 2-1/8" EJ/MPD/CCL/WT) TL-36'. PT BOPE TO 3000 PSI. 11:45 RIH & TIE IN WITH 2/12/98 SWS PERF RECORD. COULD NOT GET PAST 4586' ELM W/GUN ASSEMBLY. POOH TO RUN CCL/WT COMBINATION TO FIND BOTTOM. 13:00 AT SURFACE. MU CCL/WT ASSEMBLY. PT & RIH. TIE IN W/ABOVE LOGS & VERIFY W/1/26/98 SWS PDC CCL/GR. TAGGED @ 4586' ELM. PU & SPUDDED. WENT THROUGH BRIDGE @ 4586' ELM. CONTINUE TO RIH TO 4684' ELM. PU CLEAN & RE TAG @ 4684' TWICE. ONCE LAST TAG PU WT INCREASED (800 LB OVER TOOL WEIGHT). COULD NOT GET BACK TO 4684' ELM. ASSUME SAND FLUFFED. PU & WAIT F/20 MINUTES FOR SAND TO SETTLE. 14:45 RIH & TAGGED @ 4655' ELM. CLEAN PU. PULL UP & WAIT 30 MINUTES FOR SAND TO SETTLE. RIH & TAG @ 4617' ELM. PULL UP & WAIT20 MINUTES. RIH &TAG SAND @ 4613' ELM. PULL UP & WAIT20 MINUTES. RIH & TAG SAND AGAIN @ 4613' ELM. 16:45 RU LRS & PRESSURE UP TO 1500 PSI TO SEE IF SAND PLUG BLED OFF. HELD SOLID. RIH &TAG SAND AGAIN @ 4613' ELM. POOH F/GUN RUN. 17:15 AT SURFACE. MU SAME GUN ASSEMBLY AS BEFORE. EQUALIZE PRESSURE & TEST BOPE TO 1500 PSI. RIH & TIE IN. PERFORATE "B" SAND F/4588 - 4608' ELM W/2-1/8" EJ BH @ 4 SPF, O DEG PHASED / ORIENTED. GOOD SURFACE INDICATIONS. LOG UP & POOH. 19:30 AT SURFACE. ALL SHOTS FIRED. BEGIN RD. 20:30 RD COMPLETE. TURN WELL OVER FOR "B" SAND FRAC. ARCO Alaska, Inc. WELL 1D-117 JOB SCOPE PERFORATE, PERF SUPPORT DATE DALLY WORK 02/18/98 PERFORATE D SAND DAY OPERATION COMPLETE I SUCCESSFUL 7 YES I YES Initial Tbg Press I Final Tbg Press I Initial Inner Ann 200 PSII 200 PSII 200 PSI DALLY SUMMARY KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-117(W4-6)) JOB NUMBER 0122980220.1 KEY PERSON SWS-JOHNSON UNIT NUMBER 8392 SUPERVISOR SCHUROSKY Final Inner Ann I I 200 PSI Initial OuterAnn I I 0 PSI Final Outer Ann 0 PSI RAN CCL AND WT. BAR, TAGGED FILL @ 4548'. PERFORATE 23' ZONE 4524' TO 4547'. I TIME LOG ENTRY 17:30 19:00 20:00 22:10 23:00 23:50 MIRU SWS, TGSM, DISC. JOB AND CHANGES WE MAY NEED TO MAKE. PRESS. TEST LUB AND BOP TO 3000 PSI LEAVING 1000 PSI ON LUB WHILE OPENING SWAB.(AVOID SAND FLUFFING) RIH WITH 12' WT. BAR, CCL, AND BOTTOMNOSE. TIE INTO DEPTH CONTROL LOG DATED 1/26/98. TAGGED SAND FILL @ 4548'. POOH. DISCUSS WITH STIM ENG. WHEATHER TO PERF. @ HIGHER INTERVAL, WAS OK'ED THAT WE PERF. FROM 4524' TO 4547'. PRESS. TEST TO 3000 PSI. HOLD 1000 PSI ON LUB. WHILE OPENING SWAB VALVE. RIH WITH 23' X 2 1/8 ENERJET STRIP WITH 4 SPF BIGHOLE CHARGES. 0 PHASE 0 ORIENT. TIE IN FOR DEPTH CONTROL, SHOOT GUN 4524' TO 4547' GOT SURFACE INDICATION OF GUN WORKING. POOH. AT SURFACE, CHECK GUN FOR DISCHARGE. GUN DID FIRE. COMPLETE RIGDOWN AND MOVE SWS TO NORDIC FOR JOB. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-117(W4-6)) WELL 1D-117 JOB SCOPE PERFORATE, PERF SUPPORT DATE DAILY WORK 02/22/98 PERFORATE D SAND DAY OPERATION COMPLETE I SUCCESSFUL 9 YES I YES Initial Tbg Press I Final Tbg Press I Initial InnerAnn 200 PSII 200 PSII 200 PSI DAILY SUMMARY JOB NUMBER 0122980220.1 UNIT NUMBER KEY PERSON SWS-JOHNSON Final Inner Ann I Initial Outer Ann1200 PSI 0 PSI SUPERVISOR SCHUROSKY Final Outer Ann 0 PSI PERFORATE D SAND 4524' TO 4554' . TAG FILL AT 4562' E-LINE. TIME LOG ENTRY 16:30 MIRU SWS E-LINE, HOLD TGSM- SLICK PAD,SLIPS. MAKE UP 30' ENERJET STRIP GUN.2 1/8" 4SPF BIG HOLE CHARGES. 17:45 PT LUB AND BOP STACK TO 3000#. KEEP +- 800 ON LUB WHILE OPENING WELL TO AVOID SAND FLUFFING 18:15 RIH WITH GUN, CCL, WT.BAR. TIE IN TO DEPTH CONTROL JEWELRY LOG. SET DOWN AT 4562' ELINE. PUT GUN ON DEPTH AT 4524' TO 4554'. SHOOT GUN WITH GOOD SURFACE INDICATION.POOH. 20:00 AT SURFACE WITH GUN SHOWING ALL SHOTS FIRED. RDMO. MOVE TO 1D-115 TO PERF. ARCO Alaska, inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-117(W4-6)) WELL 1D-117 JOB SCOPE FRAC, FRAC SUPPORT DATE DALLY WORK 02/24/98 PUMP 'D' SAND FRAC DAY OPERATION COMPLETE I SUCCESSFUL 11 YES I YES InitialTbgPress IFinalTbgPress IlnitiallnnerAnn 370 PSI 1000 PSI 300 PSI DAILY SUMMARY KEY PERSON DS-GALLEGOS JOB NUMBER 0131981536.3 UNIT NUMBER SUPERVISOR BRADLEY Final Inner Ann I Initial Outer Ann I Final Outer Ann 1000 PSII 0 PSII 0 PSI PUMPED 'D' SAND FRAC. PUMP TOTAL OF 100,898# 16/20 CARBO-LITE AT 2-10 PPA STAGES. PROPLOCK ADDED TO SAND STAGES AFTER 2 PPA STAGE. TOTAL OF 100397# BEHIND PIPE WITH 10 PPA AT PERFS (501# LEFT IN WELLBORE). TIME 10:15 15:00 16:15 LOG ENTRY MIRU DOWELL FRAC CREW AND ASSOCIATED EQUIPMENT. HELD SAFETY MEETING (19 PEOPLE ON LOCATION). FINISH RIGGING UP BACKSIDE LINE FOR REVERSING. LOAD AND HEAT DIESEL FOR DOWELL TANKER. PT TO 5500#. START BREAKDOWN STAGE. PUMP 200 BBLS 50# HEC GEL W/3% KCL AT 15 - 20 BPM AND 2300 - 2900#. ISIP = 1220# (FG - 0.68 PSI/FT). FLUSH W/54 BBLS DIESEL. SD AND MONITOR PRESSURES. PUMP PULSE TESTS AS REQUIRED. CLOSURE PRESSURE-- 1185 PSI. PUMP DATA FRAC. DISPLACEMENT AT 5 BPM AND 1300#. PUMP DATA FRAC AT 15 BPM AND 2000 PSI. DISPLACE DATAFRAC WITH 49 BBLS DIESEL. SD AND MONITOR PRESSURES. CLOSURE PRESSURE = 1163 PSI, CLOSURE TIME = 16 MINUTES. FG = 0.69 PSI/FT. CUT 23 BBLS OF OF DESIGNED PAD VOLUME (DESIGN = 55, PUMP 32 BASED ON DATAFRAC CALCULATIONS). 17:30 STANDBY FOR RADIO SILENCE WHILE RUNNING CHEMICAL CUTTER ON NORDIC RIG. TIME 20:00 LOG ENTRY START FRAC. PUMP 32 BBLS PAD (50# HEC W/3% KCL) AT 5 BPM AND 1300#. PUMP TOTAL OF 100,898# 16/20 CARBO-LITE AT 2-10 PPA STAGES. PROPLOCK ADDED TO SAND STAGES AFTER 2 PPA STAGE. TOTAL OF 100397# BEHIND PIPE WITH 10 PPAAT PERFS (501# LEFT IN WELLBORE). BLUE DIE ADDED TO ALL PROPPANT STAGES. 21:05 REVERSE CIRCULATE 120 BBLS SLICK DIESEL AT 6 BPM WHILE HOLDING 600# ON CHOKE. 21:30 BEGIN RD DOWELL. 23:30 DOWELL RD. TURNED WELL OVER TO DSO TO BE LEFT SI PENDING NORDIC COMPLETION. NOTE> NEED TO HAVE BPV SET BEFORE NORDIC MIRU. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA, iNC. WEST SAK / iD-ii7 500292284400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 122897 MWD SURVEY JOB NUMBER: AKMM80069 KELLY BUSHING ELEV. = 111.40 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/t00 NORTH/SOUTH EAST/WEST SECT. .00 .00 -111.40 0 0 N .00 E .00 121.00 121.00 9.60 0 0 N .00 E .00 170.00 170.00 58.60 0 30 N 22.00 E 1.02 289.95 289.92 178.52 1 40 N 66.19 E 1.13 380.05 379.88 268.48 4 12 N 59.80 E 2.84 .00N .00E .00 .00N .00E .00 .20N .08E .17 1.39N 1.88E 2.32 3.58N 5.93E 6.93 472.42 471.77 360.37 7 21 N 55.01 E 3.45 562.39 560.59 449.19 10 53 N 55.10 E 3.92 653.28 649.21 537.81 14 38 N 58.08 E 4.20 743.13 735.61 624.21 17 10 N 59.81 E 2.86 834.63 822.13 710.73 20 46 N 60.38 E 3.93 8.68N 13.71E 16.23 16.85N 25.41E 30.47 27.85N 42.21E 50.54 40.53N 63.33E 75.17 55.35N 89.12E 104.91 923.76 904.40 793.00 24 26 N 60.29 E 4.12 1015.90 987.38 875.97 27 4 N 60.36 E 2.85 1106.73 1067.77 956.37 28 23 N 57.46 E 2.08 1202.39 1151.01 1039.61 30 37 N 58.10 E 2.35 1295.82 1230.20 1118.80 33 27 N 58.87 E 3.07 72.30N 118.89E 139.14 92.12N 153.67E 179.16 113.96N 189.84E 221.41 139.06N 229.69E 268.50 164.96N 271.95E 318.06 1393.44 1309.94 1198.54 36 57 N 59.24 E 3.59 1485.35 1381.60 1270.20 40 33 N 59.50 E 3.92 1579.66 1451.32 1339.92 44 5 N 60.05 E 3.76 1675.85 1517.99 1406.59 48 7 N 59.16 E 4.25 1869.48 1645.86 1534.46 49 12 N 59.08 E .56 193.89N 320.22E 374.34 223.20N 369.72E 431.86 255.15N 424.59E 495.34 290.23N 484.36E 564.63 364.85N 609.14E 710.02 1963.22 1707.53 1596.13 48 30 N 58.86 E .78 2248.31 1895.41 1784.01 49 2 N 59.15 E .21 2532.33 2082.46 1971.06 48 35 N 55.19 E 1.06 2816.45 2268.19 2156.79 49 45 N 54.60 E .44 2911.81 2330.48 2219.08 48 42 N 58.20 E 3.07 3007.54 2393.65 2282.25 48 42 N 60.51 E 1.81 3101.38 2455.84 2344.44 48 16 N 61.33 E .80 3196.27 2519.45 2408.05 47 31 N 60.28 E 1.14 3290.39 2585.73 2474.33 42 54 N 58.66 E 5.06 3383.72 2656.37 2544.97 38 40 N 58.16 E 4.56 401.24N 669.63E 780.61 511.66N 853.44E 995.02 627.49N 1033.01E 1208.65 751.!2N 1208.88E 1423.19 79t.09N 1269.00E 1495.34 827.75N 1330.87E 1567.24 861.90N 1392.28E 1637.45 896.24N 1453.75E 1707.81 930.14N 1511.30E 1774.58 962.06N 1563.23E 1835.54 3479.36 2732.97 2621.57 34 52 N 57.66 E 3.99 992.46N 1611.73E 1892.78 3573.09 2811.62 2700.22 31 0 N 57.86 E 4.12 1019.65N 1654.82E 1943.73 3668.79 2895.43 2784.03 26 40 N 57.11 E 4.55 1044.43N 1693.75E 1989.87 3762.98 2981.01 2869.61 22 38 N 58.94 E 4.34 1065.28N 1727.05E 2029.16 3857.85 3069.40 2958.00 19 57 N 61.77 E 3.04 1082.36N 1756.97E 2063.59 ORIGINAL SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA, INC. WEST SAK / 1D-1i7 500292284400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 122897 MWD SURVEY JOB NUMBER: AKMM80069 KELLY BUSHING ELEV. = 111.40 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 3952.52 3159.75 3048.35 14 40 N 60.23 E 5.59 1095.97N 1781.63E 2091.72 4047.30 3252.18 3140.78 10 47 N 54.40 E 4.32 l107.10N 1799.27E 2112.59 4141.49 3345.21 3233.81 7 4 N 51.37 E 3.98 1115.86N 1810.97E 2127.14 4235.48 3438.77 3327.37 3 47 N 43.86 E 3.56 1121.71N 1817.65E 2135.88 4330.36 3533.56 3422.16 1 8 N 18.13 W 3.59 1124.87N 1819.53E 2139.13 4519.79 3722.96 3611.56 1 0 N 20.31 W .08 1128.21N 1818.37E 2139.89 4709.19 3912.31 3800.91 1 40 N 31.27 W .38 1132.12N 1816.36E 2140.22 4898.35 4101.39 3989.99 1 30 N 31.97 W .09 1136.57N 1813.62E 2140.20 5085.51 4288.50 4177.10 1 17 N 32.51 W .11 1140.43N 1811.19E 2140.14 5138.72 4341.70 4230.30 1 10 N 23.37 W .43 1141.43N 1810.65E 2140.21 5205.00 4407.96 4296.56 1 10 N 23.37 W .00 1142.67N 1810.11E 2140.40 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2140.61 FEET AT NORTH 57 DEG. 44 MIN. EAST AT MD = 5205 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 58.55 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 5,205.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, INC. WEST SAK / 1D-1i7 500292284400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 122897 JOB NUMBER: AKMM80069 KELLY BUSHING ELEV. = 111.40 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -111.40 1000.00 973.19 861.79 2000.00 1731.91 1620.51 3000.00 2388.68 2277.28 4000.00 3205.87 3094.47 .00 N .00 E 88.57 N 147.43 E 415.49 N 693.21 E 824.96 N 1325.94 E 1101.75 N 1791.27 E .00 26.81 26.81 268.09 241.28 611.32 343.23 794.13 182.80 5000.00 4203.01 4091.61 5205.00 4407.96 4296.56 1138.80 N 1812.22 E 1142.67 N 1810.11 E 796.99 2.86 797.04 .05 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. WEST SAK / !D-i!7 500292284400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 122897 JOB NUMBER: AKMM80069 KELLY BUSHING ELEV. = 111.40 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -111.40 111.40 111.40 .00 211.40 211.40 100.00 311.44 311.40 200.00 411.68 411.40 300.00 .00 N .00 E .00 N .00 E .53 N .22 E 1.64 N 2.45 E 4.97 N 8.19 E .00 .00 .00 .00 .00 .04 .03 .28 .24 512.46 511.40 400.00 614.34 611.40 500.00 717.84 711.40 600.00 823.18 811.40 700.00 931.47 911.40 800.00 11.95 N 18.39 E 22.86 N 34.38 E 36.83 N 57.03 E 53.37 N 85.65 E 73.90 N 121.69 E 1.06 .78 2.94 1.88 6.44 3.50 11.78 5.34 20.07 8.29 1042.88 1011.40 900.00 1156.42 1111.40 1000.00 1273.39 1211.40 1100.00 1395.28 1311.40 1200.00 1525.04 1411.40 1300.00 98.19 N 164.34 E 126.73 N 209.90 E 158.61 N 261.49 E 194.46 N 321.19 E 236.45 N 392.34 E 31.48 11.41 45.02 13.54 61.99 16.97 83.88 21.89 113.64 29.76 1666.05 1511.40 1400.00 1816.73 1611.40 1500.00 1969.05 1711.40 1600.00 2120.13 1811.40 1700.00 2272.69 1911.40 1800.00 286.52 N 478.12 E 344.33 N 574.89 E 403.50 N 673.37 E 462.01 N 770.32 E 521.15 N 869.21 E 154.65 41.01 205.34 50.69 257.65 52.32 308.73 51.07 361.29 52.57 2424.73 2011.40 1900.00 2576.08 2111.40 2000.00 2728.53 2211.40 2100.00 2882.81 2311.40 2200.00 3034.43 2411.40 2300.00 582.25 N 966.07 E 646.22 N 1059.95 E 712.25 N 1154.17 E 779.39 N 1250.56 E 837.69 N 1348.46 E 413.33 52.04 464.68 51.35 517.13 52.45 971.41 54.28 623.03 51.62 3184.35 2511.40 2400.00 3324.98 2611.40 2500.00 3452.87 2711.40 2600.00 3572.81 2811.40 2700.00 3686.59 2911.40 2800.00 891.88 N 1446.11 E 942.22 N 1531.07 E 984.26 N 1598.73 E 1019.55 N 1654.68 E 1048.68 N 1700.36 E 672.95 49.91 713.58 40.63 741.47 27.90 761.41 19.94 775.19 13.77 3795.79 3011.40 2900.00 3902.20 3111.40 3000.00 4005.66 3211.40 3100.00 4107.36 3311.40 3200.00 1071.57 N 1737.70 E 1089.15 N 1769.45 E 1102.40 N 1792.28 E 1113.02 N 1807.32 E 784.39 9.20 790.80 6.41 794.26 3.46 795.96 1.70 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. WEST SAK / 1D-1i7 500292284400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/22/98 DATE OF SURVEY: 122897 JOB NUMBER: AKMM80069 KELLY BUSHING ELEV. = 111.40 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4208.03 3411.40 3300.00 1120.27 N 1816.16 E 796.63 .67 4308.19 3511.40 3400.00 1124.36 N 1819.50 E 796.79 .16 4408.21 3611.40 3500.00 1126.34 N 1819.04 E 796.81 .02 4508.23 3711.40 3600.00 1128.02 N 1818.44 E 796.83 .02 4608.24 3811.40 3700.00 1129.68 N 1817.81 E 796.84 .02 4708.28 3911.40 3800.00 1132.09 N 1816.37 E 796.88 .04 4808.33 4011.40 3900.00 1134.57 N 1814.87 E 796.93 .04 4908.36 4111.40 4000.00 1136.79 N 1813.48 E 796.96 .03 5008.39 4211.40 4100.00 1138.96 N 1812.12 E 796.99 .03 5108.42 4311.40 4200.00 1140.86 N 1810.92 E 797.02 .02 5205.00 4407.96 4296.56 1142.67 N 1810.11 E 797.04 .02 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 2/23/98 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11853 Company: AlaSka Oil & Gas Cons Comm Attn: Lori Taylor 300! Porcupine Drive AnChorage, AK 99501 Field: West Sak (Reservoir Analysis Logs) Well Job # Log Description Date BI' RF Sepia Floppy Disk 1 D- 11 7 C~q_ ;~ ;~ ~7 -- CEMENT MAP LOG 9 8 01 2 6 I 1 1 D- 1 21 ~ ~7 - / ~ / --~' CEMENT MAP LOG 9 8 01 21 I 1 1 D-13 0 ~7 - ? ~' ~ FOUR ARM CALIPER W/FMS 971 1 0 5 I 1 1 D-130 ~ CEMENT BOND LOG 9801 1 0 I I SIGNED- Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: 0 F! I I_1-- I N (:S S E FI~JI I::: E S 29-Jan-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-117 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD n/a' MD 5,205.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company OF:IICI--lNG S ~:: !:! ~J I [~ ~: S $.VELL LOG TRANSMITTAL To: State of Alaska January 28, 1998 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1D-117, AK-MM-80069 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin. Sperry-Sun Drilling Services, 5631 Silverado Way,//G, Anchorage, AK 99518 1D-117: 2" x 5" MD Resistivity & Gamma Ray Logs' 50-029-22844-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22844-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I::t I I--I-- I IM G WELL LOG TRANSMITTAL To: RE' State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1D-117, January 28, 1998 AK-MM-80069 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin. Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG fbrmatted Disc with verification listing. API#' 50-029-22844-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 19. 1997 Michael Zanghi Drilling Superintendent ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: West Sak I D-117 (E7) ARCO Alaska. Inc. Permit No 97-237 Sur. Loc.: 91 'FNL. 597'FEL, Sec. 23. T11N, R10E, UM Btmhole Loc: 1021'FSL, 1221'FWL. Sec. 13. TllN. R10E. UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance xvith 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. 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. TypeofWork Ddll X Reddll lb Type of Well Exploratory I--I Stratigraphic Test FI Development Oil X Re-Entry Deepen Service Fl Development Gas E] Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 71' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 91' FNL, 597' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1021' FSL, 1221' FWL, Sec. 13, T11N, R10E, UM West Sak 1D-117 (E7) #U-630610 At total depth 9. Approximate spud date Amount 1021' FSL, 1221' FWL, Sec. 13, T11N, R10E, UM 1/3/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1D-04 5162' MD 1221' @ TD feet 32.2' @ 300' feet 2560 4352' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 49° Maximum surface 1453 psig At total depth 1910 psig (TVD) 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' +200 CF 9.875" 7.625" 29.7# L-80 BTC MOB 5121' 41' 41' 5162' 4352' 520 Sx Arcticset III & 310 Sx Class G & 60 sx AS I 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Totaldepth: truemeasuredvertical feetfeet _..P-bJgs(measured) 0RIdlNAL Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface IntermediateRECEIVED Production Liner Perforation depth: measured ~C ? 0 true vertical D~vert~r-W.¢l~1~ ~08 {JOri ~l~il. itlfi,l~Ko, gram X 20. Attachments Filing fee X Property plat [] BOP Sketch [] ' --,~J3P,~0~' ¢,~$ .......... 25 050 re'~iul~-u~rem' ents Drilling fluid program X Time vs depth plot [] Refraction a~nalysis [] Seabed report [] ~u . q X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge S igned~~" '~/~' /~~~/~//~'~ -~--~//¢2]~/ Title Drilling Superintendent Date /'~ Commission Use Only Number IAPl number ~2 ¢~ IAppr°v~ date '-''~ ,''~ --''' Isee c°ver letter f°r Permi/~ ~_ 2_~ "~ 50- 0 ~ 9- ~-- ~- /C~. '" /~"" ~ .'7 other requirements Conditions of approval Samples required r- Yes I~ No Mud Io~ required' ['- Yes ~' No Hydrogen sulfidemeasures E~]Yes [~No Directional survey required [~Yes F~ No Required workingpressureforBOPE [~2M [~ 3M [--] 5M ~] IOM [~ 1SM Other: Original Signeo David W. Johnstonbyorder of Approved by Commissioner the commission Date /2-'/F'""FY Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor December 9, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1D-117 (E7) West Sak Phase lA Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1D pad. The well is designed including hydraulic fracturing stimulation treatments using resin coated type proppant material. The stimulation procedure is designed to control sand production expected in these unconsolidated formations. The well is planned as a producer well using a progressive cavity ESP ("PCESP") to artificially lift the well. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak Pool Rules. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany this area. There are also no shallow hazards expected at WS 1D-117 (E7), such as shallow gas, There have been eight (8) KuParuk wells and several West Sak wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Aisc note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type Icg generation and sample catching are planned. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is January_ 3, 1998. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. Sinceret~ ~ Thomas A. BrockwaY- Operations Drilling Engineer Attachments: cc: West Sak 1D-117 (E7) Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK6 Drill and Case Plan for West Sak 1D-117 (E7) Frac-for-Sand Control Producer General Procedure: , Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. , Spud and directionally drill 9-7/8" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. , Run and cement 7-5/8" 29.7# L80 BTC casing to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. , Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3,000 psi. . Pick up 6-3/4" mill tooth bit with 3-1/2" drill pipe and collars. Trip in and drill out stage collar. Clean out to PBTD. . Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. , Swap well over to non-freezing completion brine. Filter brine to desired level. Trip out. 10. Pick up 3-1/2" tubing deadstring and TIH. Circulate filtered brine to desired level. 11. Hang tubing in wellhead, install back pressure valve, and nipple down BOP stack. Nipple up and pressure test production tree. Secure well. 12. Release rig. TAB, 11/10/97, Rev.3 RECEiVeD nch0r~t.,.u Page 1 Completion Plan for West Sak 1 D-117 (E7) Frac-for-Sand Control Producer Four-Staqe, Frac-for-Sand Control Completion (Off Rig Fracs) General Procedure: Well Preparation , Rig up frac equipment on well, and pressure test lines and production tree. Pull back pressure valve, and pressure test tubing and annulus. . Rig up E-line unit, and make correlation run as required with GR/CCL to correlate logs for perforating. NOTE: The number of stages frac'd may decrease from four (4) to three (3) depending on log results and final completion design strategy. Stage 1 . Rig up thru-tubing perf guns for Stage 1 frac job which includes the West Sak A2 sands. RIH with perf guns, and position guns on depth. 4. Perforate Stage 1 overbalanced, and POOH with E-line. . Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 1 interval. o Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 1 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 1 from Stage 2 to follow. Pressure test sand plug as required. , RIH with slickline and confirm sand top above Stage 1 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 2 , Rig up thru-tubing perf guns for Stage 2 frac job which includes the West Sak A3 sands. RIH with perf guns, and position guns on depth. 9. Perforate Stage 2 overbalanced, and POOH with E-line. 10. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 2 interval. Page 2 11. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 2 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 2 from Stage 3 to follow. Pressure test sand plug as required. 12. RIH with slickline and confirm sand top above Stage 2 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 3 13. Rig up thru-tubing perf guns for Stage 3 frac job which includes the West Sak A4 and B sands. RIH with perf guns, and position guns on depth. 14. Perforate Stage 3 overbalanced, and POOH with E-line. 15. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 3 interval. 16. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 3 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 3 from Stage 4 to follow. Pressure test sand plug as required. 17. RIH with slickline and confirm sand top above Stage 3 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 4 18. Rig up thru-tubing perf guns for Stage 4 frac job which includes the West Sak D sands. RIH with perf guns, and position guns on depth. 19. Perforate Stage 4 overbalanced, and POOH with E-line. 20. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 4 interval. 21. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 4 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 4 from tubing tail. Pressure test sand plug as required. 22. RIH with slickline and confirm sand top below tubing tail. Use CTU as required to jet sand plug top to desired PBTD. 23. Set back pressure valve in tubing hanger, pressure test production tree and secure well. Release frac, E-line, CTU, and slickline equipment as required. Page 3 Pull Deadstring, Clean Out Well, Run ESP and Production Tubing 24. MIRU completion rig on well. Nipple down production tree and nipple up BOP stack on wellhead. Install 3-1/2" rams unless VBR's are available. Pressure test BOP stack to 3,000 psi. 25. Pull back pressure valve. 26. Pull tubing hanger and circulate well to clean brine as required. 27. T©H and lay down deadstring. 28. Pick up rock bit and casing scraper and TIH with workstring. 29. Clean out sand plugs, proppant, and perforating debris to PBTD below base of West Sak interval. 30. Circulate well to clean brine. TOH with workstring. Change rams to 2- 7/8" and pressure test same unless VBR's are available. 31. Pick up Centrilift PCP-ESP (progressive cavity ESP) on 2-7/8" production tubing. 32. Run in well with PCP-ESP pump with power cable and data gathering information wire attached to tubing. 33. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. 34. Position PCP-ESP at desired depth, set tubing hanger and run electrical penetrators through same. 35. Make surface electrical connections as required, and set back pressure valve in tubing hanger. 36. Nipple down BOP stack, and nipple up production tree. Pressure test production tree. Secure well. 37. Release rig and turn well over to production. TAB, 11/10/97, Rev.3 Page 4 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1D-117 (E7) Drillinq Fluid Tyl3e Extended Bentonite Slurry Drillinq Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 4O 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.6-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12% Drillinq Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A combination surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface using a stage (DV) collar. The stage collar will be placed approximately 200 feet TVD below the base of the permafrost interval. Page 1 MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-117 (E7) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. Based on actual well test data from the nearby WS1-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.6 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,708' MD/TVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WSl-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base to surface, the following MASP can be computed' MASP = (4152 ft)(0.46 - O. 11 psi/fi) = 1453 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 7-5/8" combination surface / production casing in this well, the BOP stack will be installed and tested to 3,000 psi. The stage collar will then be drilled out and the well cleaned out to PBTD. At that time, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi as well. The 7-5/8" 29.7# L80 BTC-MOD casing to be used has a burst rating of 6,890 psi; 70 % of this burst rating is 4,823 psi. A deadstring will then be run in the well in preparation for off-rig perforating and fracture stimulation treatments. A completion rig would then return to the well following fracture stimulation work to remove the deadstring, and to install the ESP pump, power cable, heat trace, and production tubing. Page 2 Drillinq Area Risks: Drilling risks in the West Sak 1D-117 (E7) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1D-117 (E7). Well Proximity Risks: The nearest existing well to West Sak 1D-117 (E7)is KRU 1D-04. As designed, the minimum distance between the two wells would be 32' at 300' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of an existing well on DS-1D. That annulus will be left with a non-freezing fluid during any extended shut down (>4 hr) in pumping operations. The West Sak 1D-117 (E7) surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 7-5~8" combination surface / production casing and prior to the drilling rig moving off of the well. TAB, 12/08/97 Page 3 oe0t~,~ ~y f~o~ For: T Mci(AY Dote I~OU. ed: 28-0ct-§7 Plot Reference is ~ ID-117/E7 Vets;on ~4. 250 50O 75O 1000 1250 1500 1750 20OO 2250 2500 2750 3000 3250 5500 5750 4000 4250 4500 Structure: Pad 1D Well: Field : Kuparuk River Unit Location : North Slope, Alaska RKB ELEVATION: 11 2' K0P TVD=300 TMD=300 DEP=0 4.00 8.00 12.00 1 6.00 20.00 24.0O 28,00 2O0 DLS: 4.00 dee per 100 ft 52.00 36.00 40.00 44.00 48.00 LOC TVD=1481 TMD=1625 OEP=492 B/ PERMAFROST TVD=1641 TMD=1869 DEP=677 East (feet) -> 200 400 600 800 1000 1200 1400 1600 1800 2000 I I I t I I I I I I I I I I I I I I ]1400 1021' FSL, 1221' FWL / TARGET - AS/ SEC. 13. T11N, RIOE J Top Ugnu Sa~'(~st ~ ~ !~ooo TVD=3864 TMD=¢674 . DEP=2131 /.---~egin Angle Drop NORTH 1112 ~ r 8oo EAST [600400 /./~/Bose Permafrost ../EOC I 200 SURFACE LOCATION: ] [ 91' FNL, 597! FEL SEC. 25, T11N, R~OE 200 Z 0 MAXIMUM ANGLE 48.99 DEG TARGET ANGLE VERTICAL 58.55 AZIMUTH 2131' (TO TARGET) ~oBEGINo,_E' ANGLE DROP TVD=2477 TMD=3145 DEP=1638 36.00%,, 32.00 X 28.00 ~ DLS: 4.00 deg per 100 f( 24.00 ~, 20.O0'~tT/ UGNU SNDS TVB=3054 TMD=5853 DEP=2039 ~ 6.00 ~ 12.00 ~ 8.00 4.00 ENB ANGLE DROP TVD=3558 TNB=4368 DEP=21,31 T/ W SAK SNDS TV0=5708 TNB=4518 DER=2151 TARGET - W SAK A3 TVD=3864 TMD=4674 DEP=2131 B/ W SAK SNDS TVD=4152 TMD=4962 DEP=2151 J LTD - csG PT TVD=4352 TMD=5162 DEP=2131 i i I i I i I i i I i i I i I iI i I 0 250 500 750 1000 1250 1500 1750 2000 2250 VerticalSection (feet)-> Azimuth 58.55 with reference 0.00 N, 0.00 E from slot #117 Ic~e~te~ ~*~c~ For: T McKAY Date p~atted : 28-Oct-g7 [ Piot Reference is ¥~ 1D-117/E7 Version ~t4. I Coordinates ore ~n fee[ reference slat ~117, J T~e Vertlcol gept~s~ RgB (P~rker J243). 520 48O 44O 4OO 36O 320 280 240 A I 200 ,4,--- 160 ('- ~20 0 ~o 4o 4O 8o 120 160 2OO 240 ARCO ALASKA, Inc. Structure : Pad 1D Welt: E7 Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) -> 80 40 0 40 80 120 160 200 240 280 320 360 400 440 480 520 I I I I I I I I I [ I I I I I I I I I I I I I I I I I I I I I 2700 , ,' /;/ /;/ \ i ,;' ,," /~ 600 i / oo ~ooo ~ ~ ~oo / / ~,. / ..,. P 44o 1899.99~ ~ ~1500 2500 ~zool ~ / /'~oo/ .~ ~oo ~ ~ook ~ ,,' .,' /~ 4oo .... % ~ 25oo /' ,,.. ~ ~4oo ~oo k i ,,, .... ~ L ~ ;6o ~4oo I ~ 1~oo/ /i'oof;OO ~;o- ~ ,,, ,,, - ~oo~ ~ /'/,,, % I .p~000 210 ~ o~ ;r~;'% ~'~ --'" ",, ~0~00 / .--" ~ o~ ..'?~ 2500 / ...... 2~0 o ,, e~; ~ ..--' ".. ~.'~ 2ooi ./{~oo 900 '~,, ~ ~ .....--' 2oo 800"~, 2200~ 1 goo .--// ~oo; 1~oo .--~'~'~o ' ~ ,- ~ ~"~ i 20 ,." .....---' ~: '~, ~?' i v tg'~ ~ ~.~oo ~ooo; 1~oo lOO .... ¢.,~¢o, ~ ~o .... -. 600 , 900 600 40 700~. 500 400 .-/' ~'60( 1400 0 ~oo~-f~ ~00 2~00 2~00 ~ ....... 80 / 2ooo/ ,,' 120 2100/ ,' ,, ~oo ~soo ~6oo ~7oo , 2200/ ~ ~~oo ~ ~ao / 1900 2~oo/'"' ~ ~~~ 2ooo 2OO i 240 I i i i i I i i [ I ~ i i i I i i i i i I I i t i i ! i t i 80 40 0 40 80 120 160 200 240 280 520 560 400 440 480 520 E~sf (feet) -> Z 0 ARCO ALASKA, Inc. Pad 1D E7 slot 8117 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE by Baker Hughes INTEQ REPORT Your ref : WS 1D-117/E7 Version 84 Our ref : prop2209 License : Date printed : 28-0ct-97 Date created : 17-Apr-97 Last revised : 28-0ct-97 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is n70 18 0.421,w149 30 36.312 Slot Grid coordinates are N 5959573.689, E 560490.700 Slot local coordinates are 91.00 S 597.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PGMS <0-8365'>,,1,Pad 1D TOTCO Suz-vey,,WS-8,Pad 1D PGMS <O-8930'>,,5,Pad 1D PGMS <0-7502'>,,4,Pad 1D PGMS <0-8070'>,,3,Pad 1D PGMS <0-9783'>,,2,Pad 1D PGMS <O-8610'>,,6,Pad 1D MSS <3311-8200'>,,7,Pad 1D WS 1D-118/E5 Version 84,,E5,Pad 1D WS 1D-119/F4 Vers.83,,F4,Pad 1D WS 1D-120/F6 Vets. 83,,F6,Pad 1D WS 1D-105/C7 Version 84,,CT,Pad 1D WS 1D-106/D6 Vers.83,,D6,Pad 1D WS 1D-109/D4 Vets. 82,,D4,Pad iD WS 1D-115/E3 Version 84,,E3,Pad 1D WS 1D-124/G3 Version 83,,G3,Pad 1D WS 1D-129/J3 Version 83,,J3,Pad 1D WS 1D-130/H4 Version 84,,H4,Pad 1D WS 1D-133/J5 Version 84,,J5,Pad 1D WS 1D-135/G7 Version 84,,G7,Pad 1D WS 1D-121/G5 Version #3,,GS,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance Diverging from M.D. 4-Aug-92 280.2 1100.0 16-0ct-96 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 25-Oct-97 25-Oct-97 28-Oct-97 6-Oct-97 6-Oct-97 22-0ct-97 8-0ct-97 8-Oct-97 22-0ct-97 22-Oct-97 22-Oct-97 27-0ct-97 22-Oct-97 22-0ct-97 23-0ct-97 511.4 152.1 32.2 77.0 197.2 272.0 392.0 15.0 60.0 75.0 224.1 165.3 149 8 3O 0 180 0 300 0 315 0 360 0 435 0 90 0 1100.0 400.0 20 0 20 0 750 0 925 0 20 0 400 0 400 0 400 0 400 0 575 0 950 0 525 0 280 0 400 0 300 0 400 0 280 0 400 0 400 0 5161 400 5161 750 925 20 400 400 400 5109 575 950 525 280 400 3O0 4O0 280 400 5080 we t Sak 1D-117 (E7) Pr° ucer Well Four (4) Stage Frac-for-Sand Control with 3-1/2" Deadstring 7-5/8" Casing Marker Joint 29.7# L-80 BTC-MOD (set 50' MD above top perforation) 7-5/8" Combination Surface/Production Casing, 29.7# L~80 BTC-MOD (Cemented to Surface) 16" Conductor Casing @ 80' Weatherford Gemoco 754HO 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) 3-1/2" Tubing Deadstring 9.3# L-80 EUE 8RD (to frac through off-rig) 3-1/2" Tubing Muleshoe (set +/- 75' above top of D Sand) D Sand Frac'd with Resin Coated Proppant B + A4 Sands Frac'd with Resin Coated Proppant A3 Sand Frac'd with Resin Coated Proppant A2 Sand Frac'd with Resin Coated Proppant ARCO Alaska, Inc. TAB,12/01/97, Rev.1 West SeE 1D-117 (E7) Comple on Diagram Four (4) Stage Frac-for-Sand Control Completion 2-7/8" Production Tubing 6.5# L-80 EUE 8RD Power Cable for ESP Centrilift 7-5/8" Casing Marker Joint 29.7# L-80 BTC-MOD (set 50' MD above top perforation) 7-5/8" Combination Surface/Production Casing, 29.7# L-80 BTC-MOD (Cemented to Surface) 16" Conductor Casing @ 80' Raychem Heat Trace (through permafrost) Weatherford Gemoco 754HO 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) Camco 2-7/8" Gas Lift Mandrel with 1" side pocket Arctic Lift 3000 psi Shear circulating valve pre-loaded in GLM (circulate well for freeze protection purposes) ESP Pump Section Centrilift ESP Gearbox Centrilift ESP Motor Section Centrilift D Sand Frac'd with Resin Coated Proppant RECEIVED B + A4 Sands Frac'd with Resin Caoted Proppant~JP, Sk~ A3 Sand Frac'd with Resin Coated Proppant A2 Sand Frac'd with Resin Caoted Proppant ARCO Alaska, Inc. TAB, 12/01/97, Rev. 1 KUPARUK-'RIVER UNIT - WEST S~AK OPERATIONS 20" DIVERTER SCHEMATIC HCR i o, 3 DO NOT SHUT IN DlVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. , MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE QPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THATAN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. TWM, 9/15/97 , -- 13 5/8I! 5000BOP STACK 8 '7 ' 6 5 4 West 3 Sak Operations - Producer Wells ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. 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 AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL 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 LOW AND 3000 PSI HIGH. TESTAS 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 BO'I-rOM RAMS TO 250 PSI AND 3(X)O PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BUND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10.OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LIN ES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. .. 11.TEST STANDPIPE VALVES TO 3000 PSi FOR 3 MINUTES. 12_TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13.RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14.PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 6' OR 4-1/2' TO 7" PIPE ODS AS APPROPRIATE. 1. 16" - STARTING HF__J~D 2. 11" - 5000 PSI HORIZONTAL TUBING HEAD 3. 11" 5000 PSI X 1~5/8' 50(X) PSI DOUBLE STUDDED ADAPTER/SPACER SPOOL 4. 13-5/8" - 5000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 5. 13-5/8" - 5000 PSI PIPE RAMS 6. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 7. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 8. 13-5/8" -5000 PSlANNULAR TWM, 9/22/97 REV I 'A1'E : '3Y i dx: ,i APP ,' ? . 2ESCRIPTION - REV I DATE i ~3.~.-_, SX i' APP i. 3ESCRIPI~ON i ~ I ~ 14'.1~ , . ~ , ,,~ ~ ~CINI TY MAP ' ~ ~ ~7 ~ SCALE: 1" = I MILE ~9 ~ . · 124 , N 6 ~5 ~ ~ 8 ,I I ~ o LEGEND s[~ SHE~ ~ 2 FOR NOTES ~O LO~TION INFOR~TION o gx~S,NG CONOUCrO~S ~ LOUNSBURY · NEW CONOUCTO~ LOC~ ~OJ~'"'C/J~ ~ ASSOCZATgS. [~C. ~EA' 1D ~ffiU~ XX UNIT' D1 ~ DRILL SI~ 1-D A R C 0 Ala sk a, Inc. ~ ~ST SAK PHASE ! - ~ CONDUCTORS AS-BUILT CADD Pl~ NO. LK610410 ~ 9/02/97 1~2~~ .~ , PC PER KSB~ K97082ACS NO TE$ . i ~' ~l~s~e! ~ \ ~ "' 1. CCORDINAEEZ ~HO~ ARE A.S.P. ZONE 4, N.A.O. 2Z ~ -- ~ Lo.s.~e ~ ,-~. ELEVA'ONS SHO~ ARE ~'ITISH PE~OLEUM MEAN /~ C.P.F. 1I- / ~) ~ ~ ZEA LEAL. ALL DISTANCES SHO~ ARE TRUE. ~ONU~ENTS PER LHD AND ASSOCIA~S. '~ ,t ~&R~ ' CONDUCTORS ?~ ~ 23, TO.SHIP ~ NOR~, RANGE ~0 EAS~ U.~. 4. OA~ OF ~UR~ 8/25, 2~ ~ 30/~7, nErD BK L~7-24,~ ~? ~ ~ i~ ~ ~ ~. ~z- 4~. ~a- 7~.~ 5. DRILL SITE i-O GRID NOR~ IS ROTA~D OD' 0~' ~s~ ~o~ ~.s.~. ZON~ ~ sma NO~. ~. SEE DRA~NC NSK-S. 5-~ FOR AS-BUILT tOCA~ONS Of CONDUCTORS ~ ~ROUSH ~8. ~ . ,' ..... ' ................ '~/~2'~~ ~I ~ClNI TY MAP ~ ~ ' : ~ SCALD I" = I MILE ~ m, ~. LS-8035 ~ ~ ~ .....'" No. ,y, A.S.P.s 'X' LA ~TUDE LONGI~DE ~ ~ ELE~ ~ELE~ S,~c. 14, T. 11 N., R. IO E. FS.L.F.E.L. 105 5,959,798.99 560,490.57 70' 18' 02.637' 149' ~0' ~6.263" : ~4' 595' 70.5' 62,0' ~ ~06 ; 5,959,768.93 560,490,67 : 70' 18' 02.~41' 149' 30' ~6,268" 104' 595' 70.4' 62.~' ~ ~09 ~ 5,959,72~.89 560,490.60 ~ 70' 18' 01.898' r 149. ~0, ~6,280, ~59, 596, 70.4, 62.7, "~ FEL I . N., . . . ~I5 5,959.60~.93 560,490.68 I 70' 18' .00.~18' ' 149' 30' ~6.3~' 6I' 597' 70.4' 6~,4' 117 5,959,57~.95 ~0,4~.65 ~ 70' 18' ~.42~' ~ 149' 30' ~5.3~4' 9~' 1597' 70.4' 1 ~18 5.959,55&95 560,490.68 70' 18' 00.276' ~ 149' 30' ~6,316' 1~' ' 597' 70,4' 6~4' ~19 5,959,513.86 560,490.72 70' 17' 59,8~2' 149' 30' ~6,326' 15I' 598' 70.~' ~ 66.0' 120 5,959.499.01 560,490.77 70' 17' 59,686' ~49' 30' 36,327' 166' 598' 70.6' ~ 66.0' 12~ 5,959,48~.89 5~0,490.67 70' 17' 59.538' 149' 30' ~6.3~5' 181' 598' 70.5' ~ 66.0 124 5,959,~93,96 560,490,70 70' 17' 5&653' ~49' ~0' ~6.355' 271' 599' 70.3'1 65.0' ~ 129 5,959,27~.92 560,490.79 70' 17' 5Z472' ~49' 30' 36.~0' 391' 600' ~0.3' ~ ~ I~0 5,959,259.09 560,490.81 70' 17' 5Z326' 149' ~0' ~6.~3' 4~' 600' 70.5' : I~3 5,959,21~.89 560,49G68 70' 17' 56.~2' 149' ~0' ~6.397' 451' 600'~ 70.4' 69.0' 1~5 5.959,1~9.02 560,490.80 70' 17' 56.146' 149' ~0' ~6,412' 526' 60~' ! 70.5' 69.4' SUR~YOR'S CER~RCA ~ ~o uc~sEo rD P~cn~ ~NO SU~,N~ ~ ~ SUPER~SiON AND ~Ar ALL DIMENSIONS AND O~ER ~/J~ & ASSOCIATES, INC. ~EA: 1D ~U~: ~ UNll ~ DRILL Si~ 1-D ARCO Alaska. Ino. - co,.uc o,s CADD FILE NO. ~ [ ORA~NG N~ ~610410 9/02/97 CEA-D1DX-610~10 2 ~ 2 ~'e# A.S,P.s LAnTUOE LONGITUDE s c.[sEct o No. 'Y' 'X' '"~"-' '"~'-' ELEV. i ELEV. S,..c. 14, T. 11 N., R. IO E. F.S.L.F.E.L. 105 5,959,798.99 560,490.57 70" 18' 02.6`77' 149" .70' .76.265" 1`74' 595' 70.5' 62,0' 106 5,959,768.9.7 560,490,67 70' 18' 02.341' 149' ,70' .76,268" 104' 595' 70.4' 109 5,959,72.7.89 560,490.60 70' 18' 01.898' 149' .70' .76,280" 59' 596' 70.4' 62.7' S ,.c. 23, T. 11 N., R. 10 E. F.N.L. F.£.L. 115 5,959.60`7.93 560,490.68 70' 18' .00.718' 149' .70' ,,~6.306' 6I' 597' 70.4' 63,4' 117 5,959,57.7.95 5~0,490.65 70' 18' 00.42`7' 149' .70' .76.314' 9I' 597' 70.4" 63.4° 118 5.959,558.95 560,490.68 70' 18' 00.276' 149' .70' .76,316' 106' 597' 70,4° 63.4' 119 5,959,513.86 560,490.72 70" 17' 59,8.72' 149' .70' .76,326' 15I' 598' 70.5° 66.0' 120 5,959.499.01 560,490.77 70' 17' 59,686' 149' .70' .76,327' 166' 598' 70.6° 66.0' 121 5,959,48`7.89 560,490.67 70' 17' 59.538' 149' .70' .76.3`75" 181' 598' 70.5" 66.0 124 5,959,.795,96 560,490,70 70' 17' 58,653' I49' ,,~0' .76.$55" 271° 599' 70.3° 65.0' 129 5,959,27`7.92 560,490.79 70' 17' 57.472' 149' .70' 36.,580" 391' 600' 70.$" 68,2' I`70 5,959,259.09 560,490.81 70' 17' 57.$26° 149' JO' ,76.38.7' 406' 600' 70.5° 6&2' I`73 5,959,21.7.89 560,490.68 70' 17' 56.882' 149' .70' .76..797' 451" 600° 70.4' 69.0' 1`75 5.959,1`79.02 560,490.80 70' 17' 56.146' 149' `70' .76,412' 526' 601° 70.5' 69.4' · WELL PERMIT CHECKLIST COMPANY FIELD & POOL.. ~Z ~'O//,_~"~:~ INIT CLASS WELL NAME /,~.?/.-f /~'///7 //"~/'/ GEOL AREA PROGRAM: exp [] dev.' redrll [] serv [] wellbore seg E: ann. disposal para req [-_i ~'~",,..'-) UNIT# -- /.,2/~'~,o ON/OFF SHORE ,~.,,%) ADMINISTRATION /~R D/~TE ? 1. Permit fee attached ....................... N 2. Lease number appropriate ................... N 3. Unique well name and number .................. N 4. Well located in a defined pool .................. N 5. Well located proper distance from drilling unit boundary .... N 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available in drilling unit ............ N 8. If deviated, is wellbore plat included .............. N 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ N 12. Permit can be issued without administrative approval ...... N 13. Can permit be approved before 15-day wait ........... N ENGINEERING 14. Conductor string provided ................... (_.Y/ N 15. Surface casing protects all known USDWs ........... ~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... ~ N 17. CMT vol adequate to tie-in long string to surf csg ........ N 18. CMT will cover all known productive horizons .......... N 19. Casing designs adequate for C, T, B & permafrost ....... N 20. Adequate tankage or reserve pit ................. (~Y~xl 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. (~ N 23. If diverter required, does it meet regulations .......... ~ N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ............... N 26. BOPE press rating appropriate; test to ~o0-1~ psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... ~,2 ~N"/ 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N/'.z, ,,,~ 31. Data presented on potential overpressure zones ....... Yy~ .~"/',,/~. _ . , 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. / /y .DATE ' 34. Contact name/phone for we_eklyprogress reports ....... N /~. '/~//¢? lexploratory on,y] REMARKS GEOLOGY: ENGINEERING: COMMISSION' ter 8 DWJ JDH t./d~ RNC '~ CO ~"1f/¢ Comments/Instructions: HOW/lit - A \FORMS\chekhst rev 09197 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. r - [ I [ [ I [ I l /9 7 - 2 3 "7 Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe 1 Desc.: Pipe 1 Use: ConocoPhillips Alaska, Inc. July 30, 2005 6512 1 3.5" 9.3 lb. L-80 EUE 8RD Tubing Well: 1D-117 Field: Kuparuk state: Alaska API No.: 50-029-22844-00 Top Log IntvI1.: Surface Bot. Log IntvI1.: 4,414 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This log is tied into the end of the tubing tail @ 4,414' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate the 3.5" tubing appears to range from good to poor condition. Wall penetrations from 20% to 58% are recorded throughout the tubing logged. The damage appears in the form of shallow general corrosion and scattered pitting with deeper isolated pitting, often in a line (1,300' - 3,500'). No significant areas of cross-sectional wall loss or 1.0. restrictions are recorded. During logging operations the tool became lodged in the GLM. As a result of the over-pull used to free the tool, no interpretable data is available for the pup joint immediately above the GLM. MAXIMUM RECORDED WALL PENETRATIONS: Line of Pits Isolated Pitting Line of Pits Isolated Pitting Line of Pits ( 58%) ( 57%) ( 56%) ( 55%) ( 53%) 77 @ 132 @ 69 @ 137 @ 81 @ 2,449 Ft. (MD) 4,161 Ft. (MD) 2,177 Ft. (MD) 4,339 Ft. (MD) 2,562 Ft. (MD) Jt. Jt. Jt. Jt. Jt. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 6%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant J.D. restrictions are recorded. , 'i ¡¡\~L'~ AU G ,,~ -1 2 0 Oí; SC/\N~~~!j=JJ t~~ J _ "\J I Field Engineer: N. Kesseru Analyst: M. Lawrence Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, TX 77497 Ptlone: (281) 01" (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudlloe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ck3s. Well: Field: Company: Country: 10-117 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Weight 9.3 ppf Grade & Thread L-80 EUE 8RD Nom.OD 3.5 ins Penetration and Metal Loss (% wall) _ penetration body 150 _ metal loss body 100 50 . o 0 to 1 to 1% 10% 10 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 143) pene. 0 2 58 54 29 0 loss 14 129 0 0 0 0 Damage Configuration ( body) 100 80 60 40 20 o isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total == 131) 99 30 2 0 0 ( PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.ID 2.992 ins July 30, 2005 MFC 24 No. 99628 1.69 24 M. Lawrence Upper len. 12 ins Lower len. 12 ins Nom. Upset 3.5 ins Damage Profile (% wall) _ penetration body o °1 - - )-- 48 . IIIi1m1 metal loss body 50 100 i= ==-- ==- 98L ...... ~: L I, ¡ I GLM 1 -r-- Bottom of Survey == 138.5 Analysis Overview page 2 ~ '~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: 10-117 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal 1.0.: 2.992 in Country: USA Survey Date: July 30, 2005 Joint J1. Depth Pen. Pen. Pen. MC'till Min. Damage Profile No. (F1.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) 0' (Ins.) 0 50 100 10 .1 21 0 0.03 13 2 2.91 PUP Shallow pitting. 1 26 0 0.03 13 () 2.93 Shallow corrosion. 1.1 58 0 0.03 13 () 2.90 PUP Shallow pitting. 1.2 67 0 0.03 11 2 2.90 2 72 0 0.04 17 4 2.94 Shallow corrosion. 3 104 () 0.03 13 6 2.92 Shallow pitting. 4 135 0 0.03 13 1 2.91 Shallow corrosion. 5 167 () 0.03 13 2 2.92 Shallow pitting. 6 198 0 0.03 13 2 2.93 Shallow corrosion. 7 230 0 0.05 18 2 2.92 Shallow pitting. 8 261 0 0.04 15 2 2.93 Shallow corrosion. 9 293 0 0.03 12 2 2.93 10 324 0 0.04 18 2 2.91 Shallow pittin~. L1. Deposits. 11 356 0 0.03 12- 2 2.93 12 387 0 0.03 13 2 2.92 Shallow pitting. 13 419 0 0.04 14 'I 2.93 Shallow corrosion. 14 450 0 0.03 13 2 2.92 Shallow pittin~. 14.1 480 0 0 0 0 2.81 OS Landing Nipple 15 481 0 0.03 13 1 2.91 Shallow corrosion. 16 513 0 0.03 13 1 2.92 Shallow corrosion. 17 544 0 0.04 14 3 2.92 Shallow pitting. 18 576 0 0.04 16 1 2.91 Shallow corrosion. 19 608 0 0.03 13 2 2.92 Shallow pitting. 20 639 0 0.04 17 2 2.91 Shallow corrosion. 21 668 0 0.03 11 2 2.91 22 700 0 0.03 12 1 2.93 23 731 0 0.04 15 2 2.91 Shallow corrosion. 24 761 0 0.04 16 2 2.92 Shallow pitting. Lt. Deposits. 25 792 0 0.04 17 2 2.93 Shallow corrosion. 26 824 0 0.03 13 2 2.93 Shallow corrosion. 27 854 0 0.03 12 2 2.93 28 886 0 0.04 15 2 2.94 Shallow pitting. 29 917 () 0.04 15 2 2.92 Shallow corrosion. 30 947 0 0.04 14 2 2.92 Shallow pitting. 31 977 () 0.04 14 2 2.93 Shallow corrosion. 32 1009 0 0.03 13 2 2.92 Shallow corrosion. 33 1040 () 0.04 16 2 2.91 Shallow pitting. 34 1071 0 0.03 11 2 2.94 35 1102 0 0.04 16 2 2.92 Shallow corrosion. 36 1134 0 0.05 19 3 2.93 Shallow pitting. 37 1165 0 0.03 12 3 2.93 Shallow pitting. 38 1197 0 0.04 17 2 2.92 Shallow corrosion. 39 1228 0 0.05 19 2 2.92 Shallow corrosion. 40 1258 0 0.04 15 1 2.92 Shallow corrosion. 41 1290 0 0.11 42 2 2.92 Line of Pits. 42 1321 0 0.05 20 2 2.92 Line of Shallow Pits. 43 1353 0 0.07 28 2 2.93 Line of Pits. 44 1384 0 0.11 43 2 2.93 Line of Pits. 45 1416 0 0.04 15 1 2.93 Line of Shallow Pits. 46 1447 0 0.04 17 1 2.90 Line of Shallow Pits. I Penetration Body Metal Loss Body Page 1 ~ t PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: 10-117 Body Wall: 0.254 in Field: Kuparu k Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal 1.0.: 2.992 in Country: USA Survey Date: July 30,2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 47 1478 () 0.09 33 2 2.92 Line of Pits. 48 1510 () 0.03 11 2 2.91 49 1541 0 0.03 12 2 2.92 50 1572 0 0.06 24 2 2.91 Line of Pits. 51 1604 0 0.12 46 2 2.90 Line of Pits. 52 1636 0 0.03 12 2 2.91 Line of Shallow Pits. 53 1667 0 0.09 34 2 2.93 Line of Pits. 54 1698 0 0.08 30 4 2.87 Line of Pits. 55 1730 0 0.08 31 2 2.88 Line of Pits. 56 1762 () 0.08 31 2 2.90 Line of Pits. 57 1793 0 0.09 36 4 2.86 Line of Pits. 58 1825 0 0.07 26 2 2.89 Line of Pits. 59 1855 0 0.08 33 2 2.88 Line of Pits. 60 1886 0 0.09 36 4 2.90 Line of Pits. 61 1918 0 0.07 26 2 2.86 Line of Pits. 62 1949 0 0.07 26 2 2.89 Line of Pits. 63 1980 0 0.07 29 2 2.87 Line of Pits. Lt. Deposits. 64 2011 0 0.06 25 2 2.88 Line of Pits. 65 2043 0 0.05 19 2 2.86 Line of Shallow Pits. Lt. Deposits. 66 2074 0 0.07 27 2 2.86 Line of Pits. 67 2104 0 0.13 50 4 2.88 Line of Pits. 68 2136 0 0.13 50 :3 2.88 Line of Pits. 69 2167 0 0.14 56 4 2.91 Line of Pits. 70 2199 0 0.13 49 3 2.89 Line of Pits. 71 2231 0 0.05 19 :3 2.86 Line of Shallow Pits. 72 2262 0 0.08 31 2 2.90 Line of Pits. 73 2294 0 0.05 21 2 2.90 Line of Pits. 74 2325 0 0.03 12 2 2.91 75 2357 0 0.02 9 :3 2.92 76 2388 0 0.06 25 3 2.91 Line of Pits. 77 2420 0 0.15 58 :3 2.89 Line of Pits. 78 2451 () 0.12 47 :3 2.89 Line of Pits. Lt. Deposits. 79 2483 0 0.06 23 1 2.87 Line of Pits. 80 2514 0 0.09 33 2 2.86 Line of Pits. 81 2546 0 0.13 53 :3 2.86 Line of Pits. 82 2578 0 0.03 13 2 2.88 Line of Shallow Pits. 83 2609 0 0.04 15 1 2.87 Line of Shallow Pits. 84 2641 0 0.09 36 2 2.89 Line of Pits. 85 2672 0 0.08 31 2 2.89 Line of Pits. 86 2703 0 0.08 31 ,) 2.89 Line of Pits. -) 87 2734 0 0.09 35 2 2.87 Line of Pits. 88 2766 0 0.07 27 2 2.89 Line of Pits. 89 2796 0 0.06 25 2 2.89 Line of Pits. 90 2828 0 0.07 29 2 2.90 Line of Pits. 91 2858 0 0.13 51 6 2.87 Line of Pits. 92 2890 () 0.11 43 3 2.88 Line of Pits. 93 2921 0 0.08 32 2 2.89 Line of Pits. 94 2953 0 0.10 38 2 2.91 Line of Pits. 95 2984 0 0.08 33 3 2.92 Line of Pits. 96 3015 0 0.12 48 5 2.92 Line of Pits. I Penetration Body ':';,1j1 Metal Loss Body Page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: 10-117 Body Wall: 0.254 in Field: Kuparu k Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal 1.0.: 2.992 in Country: USA Survey Date: July 30, 2005 Joint J1. Depth Pc'n. Pen. Pen. .I-v\c t a I Min. Damage Profile No. (F1.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) 'Yo (Ins.) 0 50 100 97 3047 0 0.04 15 1 2.90 Line of Shallow Pits. 98 3078 0 0.09 34 2 2.90 Line of Pits. 99 3110 () 0.05 21 2 2.91 Line of Pits. 100 3141 0 0.03 10 2 2.88 101 3172 0 0.07 27 2 2.89 Line of Pits. 102 3203 () 0.13 53 3 2.93 Line of Pits. 103 3234 0 0.07 26 1 2.92 Line of Pits. 104 3265 0 0.07 27 2 2.88 Line of Pits. 105 3296 0 0.10 39 2 2.91 Line of Pits. L1. Deposits. 106 3328 0 0.05 20 2 2.92 Line of Shallow Pits. 107 3359 0 0.09 34 J 2.91 Line of Pits. L1. Deposits. 108 3391 0 0.12 45 4 2.93 Line of Pits. 109 3422 0 0.04 14 2 2.92 Line of Shallow Pits. 110 3454 0 0.03 13 1 2.91 Line of Shallow Pits. 111 3485 0 0.08 32 4 2.93 Line of Pits. 112 3517 0 0.08 32 2 2.94 Isolated Pitting. 113 3548 0 0.09 34 :~ 2.93 Isolated Pitting. 114 3579 0 0.10 38 4 2.93 Isolated Pitting. 115 3611 0 0.07 27 2 2.92 Isolated Pitting. 116 3643 0 0.12 47 4 2.92 Isolated Pitting. 117 3675 0 0.10 40 3 2.92 Isolated pitting. 118 3706 0 0.10 41 5 2.94 Isolated pitting. 119 3738 0 0.12 48 3 2.89 Corrosion. L1. Deposits. 120 3769 0 0.12 46 :; 2.94 Corrosion. 121 3799 0 0.10 40 4 2.94 Corrosion. 122 3831 0 0.11 42 4 2.92 Corrosion. 123 3862 0 0.12 47 4 2.93 Isolated pitting. 124 3893 () 0.09 34 4 2.92 Corrosion. 125 3924 0 0.10 38 3 2.94 Isolated pitting. 126 3955 0 0.13 50 5 2.94 Isolated pitting. 127 3987 0 0.11 45 5 2.94 Line corrosion. 128 4018 0 0.09 36 3 2.91 Isolated pitting. 129 4050 0 0.10 40 4 2.94 Corrosion. 130 4081 0 0.08 30 5 2.94 Line corrosion. 131 4112 0 0.08 33 3 2.93 Isolated pitting. 132 4144 0 0.15 57 4 2.94 Isolated pitting. 133 4175 0 0.11 43 3 2.93 Corrosion. 134 4206 0 0.12 49 5 2.93 Isolated pitting. 135 4238 0 0.05 21 4 2.91 Isolated pitting. 136 4268 0 0.12 47 3 2.94 Isolated pitting. 136.1 4291 () 0 0 0 N/A PUP (Tool Hang Up) 136.2 4303 0 0 0 0 N/A GLM 1 (No Deviation) , 136.3 4312 () 0.07 28 5 2.88 PUP Corrosion. L1. Deposits. t 137 4319 0 0.14 55 3 2.95 Isolated pitting. 137.1 4349 () 0 0 0 2.75 o Nipple 138 4351 0 0.11 41 :3 2.91 Isolated pitting. 138.1 4383 0 0.08 33 2 2.90 PUP Corrosion. 138.2 4388 0 0 0 0 N/A PBR 138.3 4401 0 0 0 0 N/A Packer 138.4 4406 0 0 0 0 N/A Seal Assembly I Penetration Body ,'tl!, Metal Loss Body Page 3 l PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: 10-117 Body Wall: 0.254 in Field: Kuparu k Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal 1.0.: 2.992 in Country: USA Survey Date: July 30, 2005 Joint J1. Depth Pen. Pen. Pen. ,\;\('1<11 Min. No. (F1.) Upset Body 0/0 Loss I.D. Comments (Ins.) (Ins.) % (Ins.) 138.5 4414 () 0 0 0 N/A Tubing Tail Page 4 Damage Profile (% wall) o 50 100 I I I I I I I I I I Penetration Body Metal Loss Body ··~~-->lS ~ .' PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 0-11 7 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ppf L-80 EUE 8RD Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 30, 2005 MFC 24 No. 99628 1.69 24 M. Lawrence Cross Section for Joint 77 at depth 2449.48 ft Tool speed = 51 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 97 % Tool deviation = 54 0 Finger 11 Penetration = 0.148 ins Line of Pits 0.15 ins = 58% Wall Penetration HIGH SIDE = UP Cross Sections page 1 .. .1--->lS ~ ~. PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 0- 11 7 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ppf L-80 EUE 8RD Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 30, 2005 MFC 24 No. 99628 1.69 24 M. Lawrence Cross Section for Joint 1 32 at depth 41 60.83 ft Tool speed = 56 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 96 % Tool deviation = 4 0 Finger 18 Penetration = 0.146 ins Isolated Pitting 0.15 ins = 57% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ·PHILLlPS Alat..a, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY 1D-117 TUBING (0-4414, 00:3.500, 10:2992) SURFACE (0-6190, 00:1.625, wt:29.70) NIP (43554356, 00:4,520) PBR (4393-4394, 00:5.900) SEAL (4412-4413, 00:5,000) PACKER (44134414, 00:6.750) Perl (4524-4554) Perf (4547-4554) . I; ~. Perf (4588-4608) Perf (4635-4650) Perf (4692-4722) Perf (4746-4776) Perf (4820-4828) I Perf (4862-4870) API: 500292284400 SSSV Type: Nipple Well Type: INJ Orig 1/211998 Completion: Last W/O: 5/19/2002 Annular Fluid: Reference Log: Last Tag: Last Tag Date: Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SURFACE 7.625 PROD LINER 4.000 Tubing String - TUBING Size I Top 3.500 0 Perforations Summary Interval TVD 4524 - 4547 3727 - 3750 Ref Log Date: TD: 5205 ftKB Max Hole Angle: 50 deg @ 2816 KRU 1 D-117 Angle @ TS: deg @ Angle @ TD: 1 deg @ 5205 Rev Reason: Format update by ImO Last Update: 8115/2002 Top Bottom TVD Wt Grade Thread 0 121 121 62.58 H-40 WELDED 0 5190 4393 29.70 L-80 BTCM 4413 4880 4083 11.50 L-80 SLHT TVD Wt I Grade I Thread 3617 9.30 L-80 EUE 8RD Status Ft SPF Date Type Comment 23 20 11/3/2000 RPERF 4.5" HSD Frac guns w/43cj UP II RDX 7 16 1113/2000 APERF 4.5" HSD Frac guns w/43cj UP II RDX 20 16 1113/2000 RPERF 4.5" HSD Frac guns w/43cj UP II RDX 5 4 2/12/1998 IPERF Zero deg phasing 10 16 11/3/2000 RPERF 4.5" HSD Frac guns w/43cj UP II RDX 30 4 2/5/1998 IPERF 30 8 2/1/1998 RPERF Zero de9 phasing 8 12 11/3/2000 APERF 4.5" HSD Frac guns w/43cj UP II RDX 8 12 1113/2000 APERF 4.5" HSD Frac guns w/43cj UP II RDX VMfr V Type VOD Latch Port TRO Date Vlv Run Cmnt DMY 1.0 BK 0.000 0 5/27/2002 (1) I Bottom 4414 Zone WSD 4547 - 4554 3750 - 3757 WSD 4588 - 4608 3791 - 3811 WSB 4635 - 4640 3838 - 3843 WSA4 4640 - 4650 3843 - 3853 WSA4 4692 - 4722 3895 - 3925 WSÞ3 4746 - 4776 3949 - 3979 WSA2 4820 - 4828 4023 - 4031 WSA2 4862 - 4870 4065 - 4073 WSA1 Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 4311 3514 Cameo KBMM-2 1. 2900# Shear Out Other l3lugs, equip., etc.: . JEWELRY Depth TVD Type 498 497 NIP 4355 3558 NIP 4393 3596 PBR 4412 3615 SEAL 4413 3616 PACKER Description CAMCO DS LANDING NIPPLE CAMCO D NIPPLE BAKER POLISHED BORE RECEPTABLE 80-40 BAKER ANCHOR TUBING SEAL ASSEMBLY E22 80-40 BAKER SC-1 PACKER (left in place from previous WO, 110' above top perfs) 4414 3617 Tn. General Notes Date Note 11/6/1998 Tag spline @ 4352' 0/31/200C Nordic 3 Workoverto Gravel Pack completion (10/31 -11/6/00) ID 2.812 2.750 4.000 3.000 0.000 2.992 Sperry-Sun Drilling Services LIS Scan Utility Wed Jan 21 08:48:45 1998 Reel Header Service name ............. LISTPE Date ..................... 98/01/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/01/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific 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 1 AK-MM-80069 P. SMITH G. WHITLOCK 1D-117 500292284400 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 21-JAN-98 23 liN 10E 91 597 .00 111.40 70.40 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.750 5205.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 3. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ROB KALISH OF SPERRY-SUN DRILLING SERVICES AND MIKE WERNER OF ARCO ALASKA, INC. ON 19 JANUARY, 1998. 4. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5205'MD, 4408'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 ....... 98/01/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED i~D Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR ROP $ START DEPTH 120 0 120 0 120 0 120 0 120 0 120 0 121 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 5160 5 5160 5 5160 5 5160 5 5160 5 5168 0 5205 0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 120.0 5205.0 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 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 O~ 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 120 5205 2662.5 10171 120 ROP 8.2593 7741.41 283.954 10168 121.5 GR 10.3046 123.088 56.2855 10097 120 RPX 1.2098 2000 201.362 10082 120 RPS 1.3555 2000 195.8 10082 120 RPM 1.3059 2000 170.734 10082 120 RPD 0.8659 2000 253.911 10082 120 FET 0.0839 3.299 0.392152 10082 120 Last Reading 5205 5205 5168 5160.5 5160.5 5160.5 5160.5 5160.5 First Reading For Entire File .......... 120 Last Reading For Entire File ........... 5205 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/21 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 ....... 98/01/21 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: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE. START DEPTH STOP DEPTH FET 120.0 5160.5 RPD 120.0 5160.5 RPM 120.0 5160.5 RPS 120.0 5160.5 RPX 120.0 5160.5 GR 120.0 5168.0 ROP 121.5 5205.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA 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) : 29 -DEC- 97 ISC 5.06 CIM 5.46 MEMORY 5205.0 120.0 5205.0 .0 49.8 TOOL NUMBER P0913CRG6 P0913CRG6 9.750 9.8 SPUD MUD 176.90 9.0 MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 1 AAPI 4 1 68 RPX MWD 1 OHFIM 4 1 68 RPS MWD 1 OHMM 4 1 68 RPM MWD 1 OHMM 4 1 68 ROP MWD 1 FT/H 4 1 68 FET MWD 1 HOUR 4 1 68 RPD MWD 1 OHMM 4 1 68 450 8.2 5.000 4.320 5.500 4.500 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32.8 Name Min Max DEPT 120 5205 GR 10.3046 123.088 RPX 1.2098 2000 RPS 1.3555 2000 RPM 1.3059 2000 ROP 8.2593 7741.41 FET 0.0839 3.299 RPD 0.8659 2000 Mean Nsam 2662.5 10171 56.2855 10097 201.362 10082 195.8 10082 170.734 10082 283.954 10168 0.392152 10082 253.911 10082 First 120 120 120 120 120 121.5 120 120 Last Reading 5205 5168 5160.5 5160.5 5160.5 5205 5160.5 5160.5 First Reading For Entire File .......... 120 Last Reading For Entire File ........... 5205 File Trailer Service name ............. STSLIB.002 OT~T~UeTOS OT~T~U~TDS SeOTA~eS IeOTuqo~& 'X~exqT% DUTqTXM SI% SAS ................. squeu~oo NMON->INfl ........... ~ureN I~ I0 ...... ~cIura~ uo~nu~uoo N/v~ON-ZNZ ................ amen Taa~ S~S ................... uT~O I~/I0/86 ..................... [~ASI5 ............. @ureu 'X~=qTq BuI~T~M SI% S&S ................. s~uoum~OD NMON-~N_rl ........... aureN ~d~A I0 ...... ~aquraN 5T~40~ ................ a~ S&S ................... uTbT~O I~/I0/86 ..................... ~SI~ ............. aureu ~0~ I~OTsXqd £O0'~I~SLS ........... aureM aIT~ ~xaM Oq ................ ocLZ~L aIT~ I5/I0/86 ....... uos~m~auaD ~o 0'0'I ........... ~oqum~ UOTS~OA --'aur~ iaAa~ qns a~A~aS
