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199-089
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 16, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-14 KUPARUK RIV UNIT 1D-14 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/16/2026 1D-14 50-029-22950-00-00 199-089-0 W SPT 6120 1990890 1530 1999 2007 2001 2000 586 735 722 716 OTHER P Austin McLeod 12/26/2025 Post patch. Sundry 325-610. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1D-14 Inspection Date: Tubing OA Packer Depth 960 2820 2755 2735IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM251227122831 BBL Pumped:2 BBL Returned:2 Friday, January 16, 2026 Page 1 of 1 KƌŝŐŝŶĂƚĞĚ͗ ĞůŝǀĞƌĞĚƚŽ͗ϭϳͲĞĐͲϮϱ,ĂůůŝďƵƌƚŽŶ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵ͘tŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ ƚƚŶ͗͘EĂƚƵƌĂůZĞƐŽƵƌĐĞdĞĐŚŶŝĐŝĂŶƚƚŶ͗&ĂŶŶLJ,ĂƌŽƵŶ ϯϯϯtĞƐƚϳƚŚǀĞŶƵĞ͕^ƵŝƚĞϭϬϬϲϵϬϬƌĐƚŝĐůǀĚ͘ ŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϬϭŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϭϴKĨĨŝĐĞ͗ϵϬϳͲϮϳϱͲϮϲϬϱ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵdŚĞƚĞĐŚŶŝĐĂůĚĂƚĂůŝƐƚĞĚďĞůŽǁŝƐďĞŝŶŐƐƵďŵŝƚƚĞĚŚĞƌĞǁŝƚŚ͘WůĞĂƐĞĂĚĚƌĞƐƐĂŶLJƉƌŽďůĞŵƐŽƌĐŽŶĐĞƌŶƐƚŽƚŚĞĂƚƚĞŶƚŝŽŶŽĨƚŚĞƐĞŶĚĞƌĂďŽǀĞt >>ED W/η ^ Zs/ KZ Zη &/ >ED :KdzW ddzW >K''/E'd WZ/Ed^η /'/d>η ^ dηϭ ϭͲϭϰ ϱϬͲϬϮϵͲϮϮϵϱϬͲϬϬ ϵϭϬϱϬϴϬϭϭ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϭͲĞĐͲϮϱ Ϭ ϭϮ ϭͲϭϯϬ ϱϬͲϬϮϵͲϮϮϴϭϱͲϬϬ ϵϭϬϰϳϰϬϵϵ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮϳͲEŽǀͲϮϱ Ϭ ϭϯ ϭ ͲϬϯ ϱϬͲϬϮϵͲϮϬϰϳϳͲϬϬ ϵϭϬϰϯϮϬϱϱ <ƵƉĂƌƵŬZŝǀĞƌ DƵůƚŝ&ŝŶŐĞƌĂůŝƉĞƌ&ŝĞůĚΘWƌŽĐĞƐƐĞĚ ϮϭͲEŽǀͲϮϱ Ϭ ϭϰ ϭ ͲϬϯ ϱϬͲϬϮϵͲϮϬϰϳϳͲϬϬ ϵϭϬϰϯϮϬϱϱ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮϯͲEŽǀͲϮϱ Ϭ ϭϱ ϭ ͲϬϰ ϱϬͲϬϮϵͲϮϬϰϳϴͲϬϬ ϵϭϬϰϯϮϭϱϰ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϵͲEŽǀͲϮϱ Ϭ ϭϲ ϭ Ͳϭϴ ϱϬͲϬϮϵͲϮϬϵϬϰͲϬϬ ϵϭϬϰϳϰϮϯϯ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϵͲĞĐͲϮϱ Ϭ ϭϳ ϭ'ͲϭϮ ϱϬͲϬϮϵͲϮϭϬϬϵͲϬϬ ϵϭϬϱϬϴϬϮϯ <ƵƉĂƌƵŬZŝǀĞƌ WĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϱͲĞĐͲϮϱ Ϭ ϭϴ ϯͲϭϴ ϱϬͲϬϮϵͲϮϮϲϵϮͲϬϬ ϵϭϬϰϳϯϯϲϴ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϮϵͲEŽǀͲϮϱ Ϭ ϭϵ ϯ<ͲϬϯ ϱϬͲϬϮϵͲϮϭϲϬϮͲϬϬ ϵϭϬϰϯϮϬϰϬ <ƵƉĂƌƵŬZŝǀĞƌ WůƵŐ^ĞƚƚŝŶŐZĞĐŽƌĚ &ŝĞůĚͲ&ŝŶĂů ϭϲͲEŽǀͲϮϱ Ϭ ϭϭϬ ϯ<ͲϯϮ ϱϬͲϬϮϵͲϮϮϳϲϯͲϬϬ ϵϭϬϰϳϰϯϬϭ <ƵƉĂƌƵŬZŝǀĞƌ >ĞĂŬĞƚĞĐƚ>ŽŐ &ŝĞůĚͲ&ŝŶĂů ϮͲĞĐͲϮϱ Ϭ ϭW> ^ <EKt> ' Z /Wdz^/'E/E'EZ dhZE/E'KWzK&d, dZE^D/dd>> dd ZdKd, dd Ed/KEK&͗&ĂŶŶLJ,ĂƌŽƵŶ͕,ĂůůŝďƵƌƚŽŶtŝƌĞůŝŶĞΘWĞƌĨŽƌĂƚŝŶŐ͕ϲϵϬϬƌĐƚŝĐůǀĚ͕͘ŶĐŚŽƌĂŐĞ͕<ϵϵϱϭϴ&Z^ͺEΛŚĂůůŝďƵƌƚŽŶ͘ĐŽŵĂƚĞ͗^ŝŐŶĞĚ͗dƌĂŶƐŵŝƚƚĂůĂƚĞ͗199-089197-183180-056180-057183-016183-132196-133186-103197-076T41200T41201T41202T41202T41203T41204T41205T41206T41207T41208Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.12.17 13:38:53 -09'00'199-089ϭϭͲϭϰϱϬͲϬϮϵͲϮϮϵϱϬͲϬϬ ϵϭϬϱϬϴϬϭϭ<ƵƉĂƌƵŬZŝǀĞƌWĂĐŬĞƌ^ĞƚƚŝŶŐZĞĐŽƌĚ&ŝĞůĚͲ&ŝŶĂůϭϭͲĞĐͲϮϱϬϭ 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 KRU 1D-14 Yes No 9. Property Designation (Lease Number): 10. Field: KRU Kuparuk River Oil Kuparuk River Oil 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8702 6635 8385 6433 Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Shelby Sumrall Contact Email: Contact Phone: 907-265-6678 Authorized Title: Well Integrity Specialist Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 11/18/2025 8692773 3.5 6629 Baker FHL packer & Baker ZXP LTP. No SSSV Perforation Depth MD (ft): L-80 4905 8350 - 8495 8037 4.5 6411 - 6503 7 Perforation Depth TVD (ft): 116 4940 62348068 16 9.625 80 7955 MD 116 4321 Size Proposed Pools: PRESENT WELL CONDITION SUMMARY TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025650 199-089 P.O. Box 1000360, Anchorage, Alaska 99510 50-029-22950-00 ConocoPhillips Alaska, Inc AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7886 MD/ 6120 TVD & 7935 MD/ 6151 TVD Shelby.Sumrall@conocophillips.com Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Length m n P 1 6 5 6 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Shelby Sumrall DN: OU=Alaska, O=Conocophillips, CN=Shelby Sumrall, E= Shelby.Sumrall@conocophillips.com Reason: I am the author of this document Location: Anchorage Alaska Date: 2025.10.07 12:35:14-08'00' Foxit PDF Editor Version: 13.1.6 Shelby Sumrall 325-610 By Grace Christianson at 1:07 pm, Oct 07, 2025 DSR-10/15/25 10-404 AOGCC witnessed MITIA post-stabilized injection. J.Lau 10/29/25 A.Dewhurst 23OCT25 X JLC 10/30/2025 10/31/25 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 7, 2025 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-14 (PTD 199-089) to pull and reset a retrievable tubing patch to allow access for a subsidence surveillance drift. If you need additional information, please contact us at 265-6678. Sincerely, Shelby Sumrall Well Integrity Specialist ConocoPhillips Alaska, Inc. Digitally signed by Shelby Sumrall DN: OU=Alaska, O=Conocophillips, CN=Shelby Sumrall, E=Shelby.Sumrall@conocophillips.com Reason: I am the author of this document Location: Anchorage Alaska Date: 2025.10.07 12:43:06-08'00' Foxit PDF Editor Version: 13.1.6 Shelby Sumrall Well Work Jus ca on & Objec ves (and date required if appropriate): 1D-14 is coming due for a subsidence dri 11/25/25. The shallow tubing patch will need to be pulled to complete the subsidence dri and reset once the dri is complete. Risks/Job Concerns (Include Dri informa on on high devia on wells, or wells with tag issues): Tubing patch installed on 11/27/24 at 170' RKB (OAL ~35') Dri ed with dummy 2.812" CA-2 plug to DS nipple at 7929' RKB on 11/25/24 Previous upper P2P elements set at 173' & 174' RKB Previous lower P2P elements set at 202' & 203' RKB Need approved 10-403 prior to pulling tubing patch Steps(Author: please include SSSV notes and note any future work required to capture rate bene t listed above (include es mated days/units in cost)): Relay 1. RIH to dri to the top of the patch at 170' RKB. Note any weight swings or ght spots in WSR. 2. RIH to pull upper patch assembly at 170' RKB (OAL = ~31'). 3. RIH to pull lower P2P at 200' RKB (OAL = ~4'). 4. RIH to brush and ush tubing down to DS nipple at 7929' RKB. 5. RIH to dri with simulated se ng tool and dummy 2.81" CA-2 plug down to DS nipple at 7929' RKB. Note any weight swings or ght spots in WSR. 6. Pump 20 bbls 100° F diesel down tubing to preheat for patch set. 7. RIH with lower 2.72" P2P and set mid element at 200' RKB 8. S ng into lower P2P with test tool and perform CMIT TxIA to 2500 psi. Record pre, ini al, 15 min & 30 min TIO's. Pull test tool. 9. RIH with upper patch assembly and s ng into lower P2P. The patch should be 30' element to element se ng the upper P2P at 170' RKB. 10. Perform MITIA to 2500 psi. Record pre, ini al, 15 min & 30 min TIO's. 11. If everything passes, RDMO. Turn well over to Opera ons. 12. DHD to perform state witnessed MITIA once BOI and stabilized. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 8,532.0 1D-14 3/10/2014 hipshkf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Conductor Ext. 1D-14 6/8/2024 cborge1 Notes: General & Safety Annotation End Date Last Mod By NOTE: Welded 10" Conductor Ext 6/8/2024 cborge1 Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 35.8 115.8 115.8 62.58 H-40 WELDED SURFACE 9 5/8 8.83 34.6 4,939.5 4,320.8 40.00 L-80 BTC PRODUCTION 7 6.28 30.9 8,067.9 6,233.8 26.00 L-80 BTC LINER 4 1/2 3.96 7,919.2 8,692.0 6,628.8 12.60 L-80 IBT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 28.7 Set Depth 7,955.2 Set Depth 6,163.5 String Max No 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection 8rd EUE ID (in) 2.87 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 28.7 28.7 0.00 HANGER 6.250 FMC TUBING HANGER w/ 2.25' x 4 1/2" IBT pup 4.500 498.0 498.0 0.94 NIPPLE 4.500 CAMCO 'DS' NIPPLE 2.875 7,804.8 6,068.8 50.94 GAS LIFT 5.390 3 1/2" x1" Camco KBMG CAMCO KBMG 2.920 7,859.4 6,103.3 50.76 PBR 4.980 BAKER PBR 80/40 Spaced out 7' from located 2.990 7,886.4 6,120.3 50.87 PACKER 5.980 BAKER FHL PACKER 2.920 7,929.4 6,147.3 51.21 NIPPLE 4.500 CAMCO DS NIPPLE 2.812 7,930.2 6,147.9 51.22 SHOE 3.500 Mule Shoe 2.867 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 174.0 174.0 0.24 PACKER - PATCH - UPR Upper patch assembly P2P packer, XO, spacer pipe & anchor latch. (28' OAL) CPP3 5330/ CPAL 35201 7/10/2023 1.600 178.0 178.0 0.25 SPACER PIPE Spacer pipe (part of upper packer assembly) CPAI 7/10/2023 1.600 186.0 186.0 0.28 LEAK - TUBING 1/29/2023 2.992 202.0 202.0 0.34 PACKER - PATCH - LWR Set P2P packer CPP3 5367 7/10/2023 1.625 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,804.8 6,068.8 50.94 1 GAS LIFT DMY BK 1 0.0 6/8/2010 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,919.2 6,141.0 51.13 PBR 4.500 BAKER PBR 3.958 7,935.4 6,151.1 51.26 PACKER 6.151 BAKER MODEL ZXP LINER TOP PACKER 4.590 8,624.2 6,585.4 50.17 LANDING COLLAR 4.500 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,350.0 8,370.0 6,410.9 6,423.6 C-4, 1D-14 10/22/1999 4.0 IPERF SWS DP 180 deg. phase +/- 90 deg 8,447.0 8,457.0 6,472.6 6,478.9 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 8,466.0 8,476.0 6,484.6 6,491.0 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 8,480.0 8,495.0 6,493.5 6,503.0 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 1D-14, 6/10/2024 3:57:07 PM Vertical schematic (actual) LINER; 7,919.2-8,692.0 FLOAT SHOE; 8,690.3-8,692.0 FLOAT COLLAR; 8,657.1- 8,658.5 LANDING COLLAR; 8,624.2- 8,625.7 APERF; 8,480.0-8,495.0 APERF; 8,466.0-8,476.0 APERF; 8,447.0-8,457.0 IPERF; 8,350.0-8,370.0 PRODUCTION; 30.9-8,067.9 FLOAT SHOE; 8,066.4-8,067.9 FLOAT COLLAR; 7,979.4- 7,980.7 HANGER; 7,940.8-7,948.0 SHOE; 7,930.2 PACKER; 7,935.4-7,940.8 NIPPLE; 7,929.4 PBR; 7,919.2-7,935.4 PACKER; 7,886.4 PBR; 7,859.4 GAS LIFT; 7,804.8 SURFACE; 34.6-4,939.5 FLOAT SHOE; 4,937.7-4,939.5 FLOAT COLLAR; 4,858.7- 4,860.2 NIPPLE; 498.0 PACKER - PATCH - LWR; 202.0 SPACER PIPE; 178.0 LEAK - TUBING; 186.0 PACKER - PATCH - UPR; 174.0 CONDUCTOR; 35.8-115.8 HANGER; 34.6-36.0 HANGER; 30.9-33.1 HANGER; 28.7 KUP INJ KB-Grd (ft) RR Date 10/7/1999 Other Elev 1D-14 ... TD Act Btm (ftKB) 8,702.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292295000 Wellbore Status INJ Max Angle & MD Incl (°) 54.17 MD (ftKB) 5,707.28 WELLNAME WELLBORE1D-14 Annotation Last WO: End Date 6/5/2010 H2S (ppm) DateComment SSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, January 27, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-14 KUPARUK RIV UNIT 1D-14 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/27/2025 1D-14 50-029-22950-00-00 199-089-0 W SPT 6120 1990890 1530 2317 2316 2308 2319 234 310 311 312 OTHER P Sully Sullivan 12/28/2024 MIT-IA post tubing patch per sundry #324-388 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1D-14 Inspection Date: Tubing OA Packer Depth 530 1800 1770 1765IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS241228173810 BBL Pumped:1.2 BBL Returned:1.2 Monday, January 27, 2025 Page 1 of 1 9 9 9 9 9 9 999 9 9 9 9 9 9 9 post tubing patch per sundry #324-388 James B. Regg Digitally signed by James B. Regg Date: 2025.01.27 00:30:08 -09'00' Originated: Delivered to:17-Jan-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 TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1A-26 50-029-22115-00 909678321 Kuparuk River Packer Setting Record Field- Final 14-Nov-24 0 12 1A-26 50-029-22115-00 909619342 Kuparuk River Packer Setting Record Field- Final 21-Oct-24 0 13 1A-27 50-029-22124-00 909781603 Kuparuk River Multi Finger Caliper Field & Processed 25-Dec-24 0 14 1B-19 50-029-22475-00 909619036 Kuparuk River Packer Setting Record Field- Final 17-Oct-24 0 15 1B-20 50-029-23164-00 909619415 Kuparuk River Plug Setting Record Field- Final 8-Oct-24 0 16 1B-20 50-029-23164-00 909678322 Kuparuk River Plug Setting Record Field- Final 13-Nov-24 0 17 1C-04A 50-029-20547-01 909677469 Kuparuk River Packer Setting Record Field- Final 23-Nov-24 0 18 1C-158 50-029-23761-00 909810535 Kuparuk River Injection Profile Field & Processed 11-Jan-25 0 19 1D-05 50-029-20417-00 909607635 Kuparuk River Correlation Record Field- Final 9-Oct-24 0 110 1D-14 50-029-22950-00 909677466 Kuparuk River Packer Setting Record Field- Final 26-Nov-24 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:T39991T39991T39992T39993T39994T39994T39995T39996T39997T39998190-166190-180194-064203-115217-078223-056179-095199-0891/23/2025101D-1450-029-22950-00909677466Kuparuk RiverPacker Setting RecordField- Final26-Nov-2401179 095199-089Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.01.23 15:06:40 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8702'feet None feet true vertical 6635' feet None feet Effective Depth measured 8702'feet 170', 201', 7886', 7935', feet true vertical 6635'feet 170', 200', 6120', 6151' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 7955' MD 6163' TVD Packers and SSSV (type, measured and true vertical depth) 170' MD 201' MD 7886' MD 7935' MD N/A 170' TVD 200' TVD 6120' TVD 6151' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 4939' 4321' Burst Collapse Liner 8037' 773' Casing 6234' 6629' 8068' 8692' 4905' 116'Conductor Surface Production 16" 9-5/8" 80' measured TVD 7" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 199-089 50-029-22950-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: Kuparuk River Field/ Kuparuk River Oil Pool KRU 1D-14 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 116' ~ ~~ INJECTOR ~~ ~ 324-388 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: Baker FHL Packer Packer: Baker ZXP Liner Top Packer SSSV: None Shelby Sumrall shelby.sumrall@conocophillips.com (907) 265-6678Staff Well Integrity Engineer 8350-8370', 8447-8457', 8466-8476', 8480-8495' 6411-6424', 6473-6479', 6485-6491', 6493-6503' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 7. Property Designation (Lease Number): ADL0025650 By Grace Christianson at 10:56 am, Dec 10, 2024 Digitally signed by Shelby Sumrall DN: OU=Alaska, O=Conocophillips, CN=Shelby Sumrall, E=Shelby.Sumrall@conocophillips.com Reason: I am the author of this document Location: Anchorage Alaska Date: 2024.12.10 10:09:32-09'00' Foxit PDF Editor Version: 13.0.0 Shelby Sumrall DTTMSTART JOBTYP SUMMARYOPS 11/25/2024 ACQUIRE DATA PULLED UPPER P2P PACKER & SPACER PIPE FROM 174' RKB, PULLED LOWER P2P PACKER FROM 202' RKB, RAN CA-2 DMY DRIFT TO 2.812" DS NIPPLE @ 9229' RKB....JOB IN PROGRESS. 11/26/2024 ACQUIRE DATA TIED INTO LDL 1-29-2024, SET, 3-1/2 P2P LOWER PACKER ME @ 203' RKB, (CCL=189') (14' CCL-ME) (LIH=4.01) (ser#CPP35184), PASSING 2500 PSI CMIT....IN PROGRESS ***packer pinned 2400 lbs to release*** 11/27/2024 ACQUIRE DATA SET 3-1/2 P2P PACKER, SPACER, & ANCHOR LATCH ME @ 173' RKB, (ser#CPP3552, CPAL35114, CPP35184) (LIH=30.88'), PASSING 2500 PSI MIT-IA. JOB IS READY FOR SW MITIA ONCE BOL & STABALIZED ***PINNED 2400 LBS TO RELEASE*** 1D-14 Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 8,532.0 1D-14 3/10/2014 hipshkf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added patch after subsidence drift 1D-14 11/27/2025 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: Welded 10" Conductor Ext 6/8/2024 cborge1 Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 35.8 115.8 115.8 62.58 H-40 WELDED SURFACE 9 5/8 8.83 34.6 4,939.5 4,320.8 40.00 L-80 BTC PRODUCTION 7 6.28 30.9 8,067.9 6,233.8 26.00 L-80 BTC LINER 4 1/2 3.96 7,919.2 8,692.0 6,628.8 12.60 L-80 IBT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 28.7 Set Depth 7,955.2 Set Depth 6,163.5 String Max No 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection 8rd EUE ID (in) 2.87 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 28.7 28.7 0.00 HANGER 6.250 FMC TUBING HANGER w/ 2.25' x 4 1/2" IBT pup 4.500 498.0 498.0 0.94 NIPPLE 4.500 CAMCO 'DS' NIPPLE 2.875 7,804.8 6,068.8 50.94 GAS LIFT 5.390 3 1/2" x1" Camco KBMG CAMCO KBMG 2.920 7,859.4 6,103.3 50.76 PBR 4.980 BAKER PBR 80/40 Spaced out 7' from located 2.990 7,886.4 6,120.3 50.87 PACKER 5.980 BAKER FHL PACKER 2.920 7,929.4 6,147.3 51.21 NIPPLE 4.500 CAMCO DS NIPPLE 2.812 7,930.2 6,147.9 51.22 SHOE 3.500 Mule Shoe 2.867 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 170.1 170.1 0.22 PACKER - PATCH - UPR 2.725" PIIP UPPER PACKER, MOE = 173', OAL = 30.42' (INCLUDES UPPER PACKER, SPACER PIPE, & ANCHOR LATCH) TTS PIIP CPP3 5352/ CPPA L3511 4 11/25/2024 1.625 174.2 174.2 0.24 ANCHOR LATCH ON SPACER PIPE SPACER PIPE & ANCHOR LATCH, AOL = 30.04' 11/25/2024 1.590 186.0 186.0 0.28 LEAK - TUBING 1/29/2023 2.992 200.6 200.5 0.34 PACKER - PATCH - LWR 2.725" PIIP LOWER PACKER, MOE = 203', OAL = 4.43' TTS PIIP CPP3 5184 11/25/2024 1.625 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,804.8 6,068.8 50.94 1 GAS LIFT DMY BK 1 0.0 6/8/2010 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,919.2 6,141.0 51.13 PBR 4.500 BAKER PBR 3.958 7,935.4 6,151.1 51.26 PACKER 6.151 BAKER MODEL ZXP LINER TOP PACKER 4.590 8,624.2 6,585.4 50.17 LANDING COLLAR 4.500 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,350.0 8,370.0 6,410.9 6,423.6 C-4, 1D-14 10/22/1999 4.0 IPERF SWS DP 180 deg. phase +/- 90 deg 8,447.0 8,457.0 6,472.6 6,478.9 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 8,466.0 8,476.0 6,484.6 6,491.0 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 8,480.0 8,495.0 6,493.5 6,503.0 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 1D-14, 12/5/2024 9:57:58 AM Vertical schematic (actual) LINER; 7,919.2-8,692.0 APERF; 8,480.0-8,495.0 APERF; 8,466.0-8,476.0 APERF; 8,447.0-8,457.0 IPERF; 8,350.0-8,370.0 PRODUCTION; 30.9-8,067.9 PACKER; 7,886.4 GAS LIFT; 7,804.8 SURFACE; 34.6-4,939.5 NIPPLE; 498.0 PACKER - PATCH - LWR; 200.5 ANCHOR LATCH ON SPACER PIPE; 174.2 LEAK - TUBING; 186.0 PACKER - PATCH - UPR; 170.1 CONDUCTOR; 35.8-115.8 KUP INJ KB-Grd (ft) RR Date 10/7/1999 Other Elev 1D-14 ... TD Act Btm (ftKB) 8,702.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292295000 Wellbore Status INJ Max Angle & MD Incl (°) 54.17 MD (ftKB) 5,707.28 WELLNAME WELLBORE1D-14 Annotation Last WO: End Date 6/5/2010 H2S (ppm) DateComment SSSV: NIPPLE 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 KRU 1D-14 Yes No 9. Property Designation (Lease Number):10. Field: KRU Kuparuk River Oil Kuparuk River Oil 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8702 6635 8385 6433 Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Jan Byrne Contact Email: Contact Phone: 907-265-6471 Authorized Title: Well Integrity Specialist Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 7886 MD/ 6120 TVD & 7935 MD/ 6151 TVD Jan.Byrne@conocophillips.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025650 199-089 P.O. Box 1000360, Anchorage, Alaska 99510 50-029-22950-00 ConocoPhillips Alaska, Inc Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY TVD Burst 7955 MD 115 4321 115 4934 62348067 16 9.625 115 4934 8350 - 8495 8067 4.5 6411 - 6503 7 Perforation Depth TVD (ft): 7/28/2024 8692784 3.5 6629 Baker FHL packer & Baker ZXP LTP No SSSV Perforation Depth MD (ft): L-80 m n P 1 6 5 6 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E= jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2024.07.08 10:12:17-08'00' Foxit PDF Editor Version: 13.0.0 Jan Byrne 324-388 By Grace Christianson at 10:58 am, Jul 08, 2024 X VTL 7/15/2024 DSR-7/8/24 10-404X SFD 7/15/2024 *Well Completion Report of 11/16/99 SFD4939* SFD *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.15 15:41:24 -08'00'07/15/24 RBDMS JSB 071624 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 8, 2023 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-14 (PTD 199-089) to pull and reset a retrievable tubing patch to allow access for a subsidence surveillance drift. If you need additional information, please contact us at 265-6471. Sincerely, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Well Work JusƟĮcaƟon & ObjecƟves (and date required if appropriate): 1D-14 is due for a subsidence compliance driŌ. The tubing patch at 174' needs to be pulled to allow for the subsidence driŌ and then reset aŌerward. Risks/Job Concerns (Include DriŌ informaƟon on high deviaƟon wells, or wells with tag issues): • Tubing patch at 174 installed 7.10.23 • DriŌed with 2.75" CA-2 plug on 7.8.23 • Need approved 10-403 from AOGCC prior to work Steps(Author: please include SSSV notes and note any future work required to capture rate beneĮt listed above (include esƟmated days/units in cost)): Relay or Slickline/Eline 1. DriŌ to top of patch at 174'. Note any weight swings or Ɵght spots on WSR. 2. Pull patch from 174'. 3. Brush and Ňush tubing down to DS nipple at 7929' 4. DriŌ dummy plug down to DS nipple at 7929'. 5. Pump 20 bbls 100°F diesel down tubing to preheat for patch set. 6. RIH with lower P2P to set mid element at ~202'. 7. RIH with test tool to sƟng into lower P2P. 8. Perform CMIT-TxIA to 2500 psi. Record pre, iniƟal, 15 min & 30 min TIO's. Pull test tool. 9. RIH with upper P2P & spacer pipe assembly to sƟng into lower P2P. Patch should be ~28' element to element seƫng the upper P2P at ~174'. 10. Perform MIT-IA to 2500 psi. Record pre, iniƟal, 15 min & 30 min TIO's. 11. RDMO. Return well to Ops. 12. DHD to perform state witnessed MITIA once BOI and stabilized. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 8,532.0 1D-14 3/10/2014 hipshkf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Conductor Ext. 1D-14 6/8/2024 cborge1 Notes: General & Safety Annotation End Date Last Mod By NOTE: Welded 10" Conductor Ext 6/8/2024 cborge1 Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 35.8 115.8 115.8 62.58 H-40 WELDED SURFACE 9 5/8 8.83 34.6 4,939.5 4,320.8 40.00 L-80 BTC PRODUCTION 7 6.28 30.9 8,067.9 6,233.8 26.00 L-80 BTC LINER 4 1/2 3.96 7,919.2 8,692.0 6,628.8 12.60 L-80 IBT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 28.7 Set Depth … 7,955.2 Set Depth … 6,163.5 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection 8rd EUE ID (in) 2.87 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 28.7 28.7 0.00 HANGER 6.250 FMC TUBING HANGER w/ 2.25' x 4 1/2" IBT pup 4.500 498.0 498.0 0.94 NIPPLE 4.500 CAMCO 'DS' NIPPLE 2.875 7,804.8 6,068.8 50.94 GAS LIFT 5.390 3 1/2" x1" Camco KBMG CAMCO KBMG 2.920 7,859.4 6,103.3 50.76 PBR 4.980 BAKER PBR 80/40 Spaced out 7' from located 2.990 7,886.4 6,120.3 50.87 PACKER 5.980 BAKER FHL PACKER 2.920 7,929.4 6,147.3 51.21 NIPPLE 4.500 CAMCO DS NIPPLE 2.812 7,930.2 6,147.9 51.22 SHOE 3.500 Mule Shoe 2.867 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 174.0 174.0 0.24 PACKER - PATCH - UPR Upper patch assembly P2P packer, XO, spacer pipe & anchor latch. (28' OAL) CPP3 5330/ CPAL 35201 7/10/2023 1.600 178.0 178.0 0.25 SPACER PIPE Spacer pipe (part of upper packer assembly) CPAI 7/10/2023 1.600 186.0 186.0 0.28 LEAK - TUBING 1/29/2023 2.992 202.0 202.0 0.34 PACKER - PATCH - LWR Set P2P packer CPP3 5367 7/10/2023 1.625 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,804.8 6,068.8 50.94 1 GAS LIFT DMY BK 1 0.0 6/8/2010 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,919.2 6,141.0 51.13 PBR 4.500 BAKER PBR 3.958 7,935.4 6,151.1 51.26 PACKER 6.151 BAKER MODEL ZXP LINER TOP PACKER 4.590 8,624.2 6,585.4 50.17 LANDING COLLAR 4.500 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,350.0 8,370.0 6,410.9 6,423.6 C-4, 1D-14 10/22/1999 4.0 IPERF SWS DP 180 deg. phase +/- 90 deg 8,447.0 8,457.0 6,472.6 6,478.9 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 8,466.0 8,476.0 6,484.6 6,491.0 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 8,480.0 8,495.0 6,493.5 6,503.0 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 1D-14, 6/10/2024 3:57:07 PM Vertical schematic (actual) LINER; 7,919.2-8,692.0 FLOAT SHOE; 8,690.3-8,692.0 FLOAT COLLAR; 8,657.1- 8,658.5 LANDING COLLAR; 8,624.2- 8,625.7 APERF; 8,480.0-8,495.0 APERF; 8,466.0-8,476.0 APERF; 8,447.0-8,457.0 IPERF; 8,350.0-8,370.0 PRODUCTION; 30.9-8,067.9 FLOAT SHOE; 8,066.4-8,067.9 FLOAT COLLAR; 7,979.4- 7,980.7 HANGER; 7,940.8-7,948.0 SHOE; 7,930.2 PACKER; 7,935.4-7,940.8 NIPPLE; 7,929.4 PBR; 7,919.2-7,935.4 PACKER; 7,886.4 PBR; 7,859.4 GAS LIFT; 7,804.8 SURFACE; 34.6-4,939.5 FLOAT SHOE; 4,937.7-4,939.5 FLOAT COLLAR; 4,858.7- 4,860.2 NIPPLE; 498.0 PACKER - PATCH - LWR; 202.0 SPACER PIPE; 178.0 LEAK - TUBING; 186.0 PACKER - PATCH - UPR; 174.0 CONDUCTOR; 35.8-115.8 HANGER; 34.6-36.0 HANGER; 30.9-33.1 HANGER; 28.7 KUP INJ KB-Grd (ft) RR Date 10/7/1999 Other Elev… 1D-14 ... TD Act Btm (ftKB) 8,702.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292295000 Wellbore Status INJ Max Angle & MD Incl (°) 54.17 MD (ftKB) 5,707.28 WELLNAME WELLBORE1D-14 Annotation Last WO: End Date 6/5/2010 H2S (ppm) DateComment SSSV: NIPPLE 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Conductor Ext Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,702' feet N/A feet true vertical 6,635' feet N/A feet Effective Depth measured feet 7,886' feet true vertical feet 6,120' feet Perforation depth Measured depth 8,350' - 8,495' feet True Vertical depth 6,411' - 6,503' feet Tubing (size, grade, measured and true vertical depth) 3 1/2" L-80 7,955' MD 6,164' TVD Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Brennen Green & Roger Mouser Contact Email:N1927@conocophillips.com Authorized Title: Well Integrity Field Supervisor Contact Phone: Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SSSV: CAMCO 'DS' Nipple 498' MD / 498' TVD 907-659-7506 323-414 Tubing Pressure MD measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Size 115.8' Burst Collapse 4,321' 7" 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Packer: Upper P2P packer / Lower P2P packer/BAKER FHL PACKER / BAKER MODEL ZXP LINER TOP PACKER Gas-Mcf Upper P2P packer: 178' MD / 178' TVD - Lower P2P packer: 202' MD / 202' TVD FHL Packer: 7,886' MD / 6,120' TVD - ZXP Liner Top Packer: 7,935' MD / 6,151' TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 199-089 500292295000-00P.O. Box 1000360, Anchorage, Alaska 995103. Address: 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025650 KUPARUK RIVER/KUPARUK RIVER OIL ConocoPhillips Alaska, Inc KUPARUK RIV UNIT 1D-14 80.8' 4,905' 115.8'Conductor Surface 16" 9 5/8" 4,940' measured TVD Production Liner 8,037' 773' Casing 6,234' 4 1/2" 8,068' 8,692' 6,629' Plugs Junk measured Length p k ft t Fra O s 199 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E =n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2024.06.10 16:08:08-08'00' Foxit PDF Editor Version: 13.0.0 Brennen Green By Grace Christianson at 8:23 am, Jun 11, 2024 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 10, 2024 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Please find the enclosed 10-404 from ConocoPhillips Alaska, Inc. for well KRU 1D-14 (PTD # 199-089) 10 Conductor extension. Please contact Brennen Green or Roger Mouser at 659-7506 if you have any questions. Sincerely, Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2024.06.10 16:07:28-08'00' Foxit PDF Editor Version: 13.0.0 Brennen Green Date Event Summary Executive Summary Welded Conductor Extension 08/07/23 Received Sundry #323-414 for conductor extension. Approved 8/4/23 by AOGCC. 05/31/24 8.5" Tree Rise, Gas readings in the cellar and in the conductor: Normal 06/08/24 NES welders welded 16" x 10" x .500" conductor extension. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 8,532.0 1D-14 3/10/2014 hipshkf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Conductor Ext. 1D-14 6/8/2024 cborge1 Notes: General & Safety Annotation End Date Last Mod By NOTE: Welded 10" Conductor Ext 6/8/2024 cborge1 Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 35.8 115.8 115.8 62.58 H-40 WELDED SURFACE 9 5/8 8.83 34.6 4,939.5 4,320.8 40.00 L-80 BTC PRODUCTION 7 6.28 30.9 8,067.9 6,233.8 26.00 L-80 BTC LINER 4 1/2 3.96 7,919.2 8,692.0 6,628.8 12.60 L-80 IBT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 28.7 Set Depth 7,955.2 Set Depth 6,163.5 String Max No 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection 8rd EUE ID (in) 2.87 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 28.7 28.7 0.00 HANGER 6.250 FMC TUBING HANGER w/ 2.25' x 4 1/2" IBT pup 4.500 498.0 498.0 0.94 NIPPLE 4.500 CAMCO 'DS' NIPPLE 2.875 7,804.8 6,068.8 50.94 GAS LIFT 5.390 3 1/2" x1" Camco KBMG CAMCO KBMG 2.920 7,859.4 6,103.3 50.76 PBR 4.980 BAKER PBR 80/40 Spaced out 7' from located 2.990 7,886.4 6,120.3 50.87 PACKER 5.980 BAKER FHL PACKER 2.920 7,929.4 6,147.3 51.21 NIPPLE 4.500 CAMCO DS NIPPLE 2.812 7,930.2 6,147.9 51.22 SHOE 3.500 Mule Shoe 2.867 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 174.0 174.0 0.24 PACKER - PATCH - UPR Upper patch assembly P2P packer, XO, spacer pipe & anchor latch. (28' OAL) CPP3 5330/ CPAL 35201 7/10/2023 1.600 178.0 178.0 0.25 SPACER PIPE Spacer pipe (part of upper packer assembly) CPAI 7/10/2023 1.600 186.0 186.0 0.28 LEAK - TUBING 1/29/2023 2.992 202.0 202.0 0.34 PACKER - PATCH - LWR Set P2P packer CPP3 5367 7/10/2023 1.625 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,804.8 6,068.8 50.94 1 GAS LIFT DMY BK 1 0.0 6/8/2010 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,919.2 6,141.0 51.13 PBR 4.500 BAKER PBR 3.958 7,935.4 6,151.1 51.26 PACKER 6.151 BAKER MODEL ZXP LINER TOP PACKER 4.590 8,624.2 6,585.4 50.17 LANDING COLLAR 4.500 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,350.0 8,370.0 6,410.9 6,423.6 C-4, 1D-14 10/22/1999 4.0 IPERF SWS DP 180 deg. phase +/- 90 deg 8,447.0 8,457.0 6,472.6 6,478.9 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 8,466.0 8,476.0 6,484.6 6,491.0 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 8,480.0 8,495.0 6,493.5 6,503.0 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 1D-14, 6/10/2024 3:57:07 PM Vertical schematic (actual) LINER; 7,919.2-8,692.0 FLOAT SHOE; 8,690.3-8,692.0 FLOAT COLLAR; 8,657.1- 8,658.5 LANDING COLLAR; 8,624.2- 8,625.7 APERF; 8,480.0-8,495.0 APERF; 8,466.0-8,476.0 APERF; 8,447.0-8,457.0 IPERF; 8,350.0-8,370.0 PRODUCTION; 30.9-8,067.9 FLOAT SHOE; 8,066.4-8,067.9 FLOAT COLLAR; 7,979.4- 7,980.7 HANGER; 7,940.8-7,948.0 SHOE; 7,930.2 PACKER; 7,935.4-7,940.8 NIPPLE; 7,929.4 PBR; 7,919.2-7,935.4 PACKER; 7,886.4 PBR; 7,859.4 GAS LIFT; 7,804.8 SURFACE; 34.6-4,939.5 FLOAT SHOE; 4,937.7-4,939.5 FLOAT COLLAR; 4,858.7- 4,860.2 NIPPLE; 498.0 PACKER - PATCH - LWR; 202.0 SPACER PIPE; 178.0 LEAK - TUBING; 186.0 PACKER - PATCH - UPR; 174.0 CONDUCTOR; 35.8-115.8 HANGER; 34.6-36.0 HANGER; 30.9-33.1 HANGER; 28.7 KUP INJ KB-Grd (ft) RR Date 10/7/1999 Other Elev 1D-14 ... TD Act Btm (ftKB) 8,702.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292295000 Wellbore Status INJ Max Angle & MD Incl (°) 54.17 MD (ftKB) 5,707.28 WELLNAME WELLBORE1D-14 Annotation Last WO: End Date 6/5/2010 H2S (ppm) DateComment SSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, September 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-14 KUPARUK RIV UNIT 1D-14 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/12/2023 1D-14 50-029-22950-00-00 199-089-0 W SPT 6120 1990890 1530 1093 1095 1095 1095 463 656 650 644 OTHER P Guy Cook 7/23/2023 Post patch MIT-IA per Sundry 323-266. Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1D-14 Inspection Date: Tubing OA Packer Depth 180 1830 1800 1790IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230722072346 BBL Pumped:1.7 BBL Returned:1.6 Tuesday, September 12, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 Post patch MIT-IA per Sundry 323-266. James B. Regg Digitally signed by James B. Regg Date: 2023.09.12 15:11:46 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8702'feet None feet true vertical 6635' feet None feet Effective Depth measured 8532'feet 174', 202', 7886', 7935' feet true vertical 6527'feet 174', 202', 6120', 6151' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 7955' MD 6163' TVD Packers and SSSV (type, measured and true vertical depth) 174' MD 202' MD 7886' MD 7935' MD N/A 174' TVD 202' TVD 6120' TVD 6151' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 4934' 4321' Burst Collapse Production Liner 8037' 773' Casing 6234' 4-1/2" 8068' 8692' 6629' 4905' 115'Conductor Surface Intermediate 16" 9-5/8" 80' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 199-089 50-029-22950-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025650 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1D-14 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 115' ~ ~~ INJECTOR ~~ ~ 323-266 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: Baker FHL Packer Packer: Baker ZXP LTP Packer SSSV: None Jan Byrne jan.byrne@conocophillips.com (907) 659-7224Senior Well Integrity Engineer 8350-8495' 6411-6503' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 4:12 pm, Sep 12, 2023 Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN =Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorge Alaska Date: 2023.09.12 07:58:05-08'00' Foxit PDF Editor Version: 12.1.2 Jan Byrne DTTMSTART JOBTYP SUMMARYOPS 7/8/2023 REPAIR WELL PULLED EQ PRONG FROM 2.75" CSA-2 PLUG @ 7929' RKB, IN PROGRESS 7/9/2023 REPAIR WELL PULLED 2.81" CSA-2 PLUG BODY FROM 7929' RKB. PERFORMED SBHPS (3085psi @ 8350' RKB), BRUSH & FLUSHED PATCH SETTING INTERVAL @ 186' RKB, RAN 2.72" x 30' DUMMY PATCH DRIFT TO 300' SLM, IN PROGRESS 7/10/2023 REPAIR WELL SET 2.72" P2P (CPP35367) LOWER PACKER @ 202' RKB. 3000 PSI COMBO MIT TxIA PASSED, SET 2.72" P2P (CPP35330) UPPER PACKER W/ SPACER PIPE & ANCHOR LATCH(CPAL35201) @ 174' RKB, 3000 PSI MITIA.PASSED, JOB COMPLETE 1D-14 Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 8,532.0 1D-14 3/10/2014 hipshkf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set patch 1D-14 7/10/2023 fergusp Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB)Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 35.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.83 34.6 4,939.5 4,320.8 40.00 L-80 BTC PRODUCTION 7 6.28 30.9 8,067.9 6,233.8 26.00 L-80 BTC LINER 4 1/2 3.96 7,919.2 8,692.0 6,628.8 12.60 L-80 IBT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB)28.7 Set Depth 7,955.2 Set Depth 6,163.5 String Ma 3 1/2 Tubing DescriptionTUBING Wt (lb/ft)9.30 GradeL-80 Top Connection8rd EUE ID (in)2.87 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB)Top (TVD) (ftKB)Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 28.7 28.7 0.00 HANGER 6.250 FMC TUBING HANGER w/ 2.25' x 4 1/2" IBT pup 4.500 498.0 498.0 0.94 NIPPLE 4.500 CAMCO 'DS' NIPPLE 2.875 7,804.8 6,068.8 50.94 GAS LIFT 5.390 3 1/2" x1" Camco KBMG CAMCO KBMG 2.920 7,859.4 6,103.3 50.76 PBR 4.980 BAKER PBR 80/40 Spaced out 7' from located 2.990 7,886.4 6,120.3 50.87 PACKER 5.980 BAKER FHL PACKER 2.920 7,929.4 6,147.3 51.21 NIPPLE 4.500 CAMCO DS NIPPLE 2.812 7,930.2 6,147.9 51.22 SHOE 3.500 Mule Shoe 2.867 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 174.0 174.0 0.24 PACKER - PATCH - UPR Upper patch assembly P2P packer, XO, spacer pipe & anchor latch. (28' OAL) CPP3 5330/CPAL 35201 7/10/2023 1.600 178.0 178.0 0.25 SPACER PIPE Spacer pipe (part of upper packer assembly)CPAI 7/10/2023 1.600 186.0 186.0 0.28 LEAK - TUBING 1/29/2023 2.992 202.0 202.0 0.34 PACKER - PATCH - LWR Set P2P packer CPP3 5367 7/10/2023 1.625 Mandrel Inserts : excludes pulled inserts Top (ftKB)Top (TVD) (ftKB)Top Incl (°) Station No/S Serv Valve Type Latch Type OD (in)TRO Run (psi) Run Date Com Make Model Port Size (in) 7,804.8 6,068.8 50.94 1 GAS LIFT DMY BK 1 0.0 6/8/2010 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB)Top (TVD) (ftKB)Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,919.2 6,141.0 51.13 PBR 4.500 BAKER PBR 3.958 7,935.4 6,151.1 51.26 PACKER 6.151 BAKER MODEL ZXP LINER TOP PACKER 4.590 8,624.2 6,585.4 50.17 LANDING COLLAR 4.500 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB)Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,350.0 8,370.0 6,410.9 6,423.6 C-4, 1D-14 10/22/1999 4.0 IPERF SWS DP 180 deg. phase +/- 90 deg 8,447.0 8,457.0 6,472.6 6,478.9 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 8,466.0 8,476.0 6,484.6 6,491.0 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 8,480.0 8,495.0 6,493.5 6,503.0 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 1D-14, 9/11/2023 12:37:00 PM Vertical schematic (actual) LINER; 7,919.2-8,692.0 APERF; 8,480.0-8,495.0 APERF; 8,466.0-8,476.0 APERF; 8,447.0-8,457.0 IPERF; 8,350.0-8,370.0 PRODUCTION; 30.9-8,067.9 PACKER; 7,886.4 GAS LIFT; 7,804.8 SURFACE; 34.6-4,939.5 NIPPLE; 498.0 PACKER - PATCH - LWR; 202.0 SPACER PIPE; 178.0 LEAK - TUBING; 186.0 PACKER - PATCH - UPR; 174.0 CONDUCTOR; 35.0-115.0 KUP INJ KB-Grd (ft) RR Date10/7/1999 Other Elev 1D-14 ... TD Act Btm (ftKB)8,702.0 Well Attributes Field NameKUPARUK RIVER UNIT Wellbore API/UWI500292295000 Wellbore StatusINJ Max Angle & MD Incl (°)54.17 MD (ftKB)5,707.28 WELLNAME WELLBORE1D-14 AnnotationLast WO:End Date6/5/2010H2S (ppm) DateCommentSSSV: NIPPLE 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 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 Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,702' Casing Collapse Conductor Surface Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 907-695-7506 4 1/2" 6,411' - 6,503' 8/19/2023 8,692'773' 3 1/2" 6,629' 7 16" 9 5/8" 80' 4,905' N1927@conocophillips.com 8,068' Perforation Depth MD (ft): 8,350' - 8,495' 8,037' MD 115' 4,321' 6,234' 115' 4,940' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025650 199-089 P.O. Box 1000360, Anchorage, Alaska 99510 500292295000-00 ConocoPhillips Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): L-80 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Other: Conductor Ext KUPARUK RIV UNIT 1D-14 KUPARUK RIVER KUPARUK RIVER OIL N/A Brennen Green & Roger Mouser TVD Burst 7,955' Well Integrity Field Supervisor 6,635' SSSV: CAMCO 'DS' Nipple BAKER FHL PACKER / BAKER MODEL ZXP LINER TOP PACKER SSSV: 498' MD / 498' TVD FHL Packer: 7,886' MD / 6,120' TVD - ZXP Liner Top Packer: 7,935' MD / 6,151' TVD Packer: Upper P2P packer / Lower P2P packer /Upper P2P packer: 178' MD / 178' TVD - Lower P2P packer: 202' MD / 202' TVD Length Size m n P 1 6 5 6 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:08 am, Jul 20, 2023 323-414 Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2023.07.19 10:12:34-08'00' Foxit PDF Editor Version: 12.1.2 Brennen Green MDG 7/24/2023 DSR-7/24/23 10-404 VTL 8/3/2023 X Photo document the repair GCW 08/04/2023JLC 8/4/2023 08/04/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.08.04 16:53:29 -08'00' RBDMS JSB 080823 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 19, 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Please find the enclosed 10-403 application for Sundry Approval from ConocoPhillips Alaska, Inc. for well KRU 1D-14 (PTD199-089) to extend the conductor. Summary: Conductor has subsided or well has grown 7.5” or more so we would like to add conductor to cover the surface casing. Please contact Brennen Green or Roger Mouser at 659-7506 if you have any questions. Sincerely, Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. ConocoPhillips Alaska, Inc. Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2023.07.19 10:12:10-08'00' Foxit PDF Editor Version: 12.1.2 Brennen Green P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Kuparuk Well 1D-14 (PTD 199-089) SUNDRY NOTICE 10-403 APPROVAL REQUEST July 19, 2023 This application for Sundry approval for Kuparuk Well 1D-14 is to extend the conductor to original height to stabilize tree and prevent corrosion to the surface casing. At some point during normal operations the conductor subsided about 7.5”. With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Extend the conductor to starter head. 3. File 10-404 with the AOGCC post repair. Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set patch 1D-14 7/10/2023 fergusp Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 35.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.83 34.6 4,939.5 4,320.8 40.00 L-80 BTC PRODUCTION 7 6.28 30.9 8,067.9 6,233.8 26.00 L-80 BTC LINER 4 1/2 3.96 7,919.2 8,692.0 6,628.8 12.60 L-80 IBT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 28.7 Set Depth … 7,955.2 Set Depth … 6,163.5 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection 8rd EUE ID (in) 2.87 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 28.7 28.7 0.00 HANGER 6.250 FMC TUBING HANGER w/ 2.25' x 4 1/2" IBT pup 4.500 498.0 498.0 0.94 NIPPLE 4.500 CAMCO 'DS' NIPPLE 2.875 7,804.8 6,068.8 50.94 GAS LIFT 5.390 3 1/2" x1" Camco KBMG CAMCO KBMG 2.920 7,859.4 6,103.3 50.76 PBR 4.980 BAKER PBR 80/40 Spaced out 7' from located 2.990 7,886.4 6,120.3 50.87 PACKER 5.980 BAKER FHL PACKER 2.920 7,929.4 6,147.3 51.21 NIPPLE 4.500 CAMCO DS NIPPLE 2.812 7,930.2 6,147.9 51.22 SHOE 3.500 Mule Shoe 2.867 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 174.0 174.0 0.24 PACKER - PATCH - UPR Upper patch assembly P2P packer, XO, spacer pipe & anchor latch. (28' OAL) CPP3 5330/ CPAL 35201 7/10/2023 1.600 178.0 178.0 0.25 SPACER PIPE Spacer pipe (part of upper packer assembly) CPAI 7/10/2023 1.600 186.0 186.0 0.28 LEAK - TUBING 1/29/2023 2.992 202.0 202.0 0.34 PACKER - PATCH - LWR Set P2P packer CPP3 5367 7/10/2023 1.625 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,804.8 6,068.8 50.94 1 GAS LIFT DMY BK 1 0.0 6/8/2010 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,919.2 6,141.0 51.13 PBR 4.500 BAKER PBR 3.958 7,935.4 6,151.1 51.26 PACKER 6.151 BAKER MODEL ZXP LINER TOP PACKER 4.590 8,624.2 6,585.4 50.17 LANDING COLLAR 4.500 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,350.0 8,370.0 6,410.9 6,423.6 C-4, 1D-14 10/22/1999 4.0 IPERF SWS DP 180 deg. phase +/- 90 deg 8,447.0 8,457.0 6,472.6 6,478.9 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 8,466.0 8,476.0 6,484.6 6,491.0 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 8,480.0 8,495.0 6,493.5 6,503.0 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase APERF; 8,480.0-8,495.0 APERF; 8,466.0-8,476.0 APERF; 8,447.0-8,457.0 IPERF; 8,350.0-8,370.0 PRODUCTION; 30.9-8,067.9 PACKER; 7,886.4 GAS LIFT; 7,804.8 SURFACE; 34.6-4,939.5 NIPPLE; 498.0 PACKER - PATCH - LWR; 202.0 SPACER PIPE; 178.0 LEAK - TUBING; 186.0 PACKER - PATCH - UPR; 174.0 CONDUCTOR; 35.0-115.0 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 KRU 1D-14 Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: KRU Kuparuk River Oil Kuparuk River Oil 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8702'6635 7929 6147 7929 Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Well Integrity Specialist Conditions of approval: Notify AOGCC 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 AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 8350 - 8495' 8067 4.5 6411 - 6503 8692784 3.5 6629 7 16 9.625 115 4934 Perforation Depth MD (ft): MD 115 4321 115 4934 62348067 Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025650 199-089 P.O. Box 1000360, Anchorage, Alaska 99510 50-029-22950-00 ConocoPhillips Alaska, Inc Tubing Grade:Tubing MD (ft): 7886 MD/ 6120 TVD & 7935 MD/ 6151 TVD Perforation Depth TVD (ft):Tubing Size: L-80 7955 5/22/2023 Baker FHL packer & Baker ZXP LTP No SSSV 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Jan.Byrne@conocophillips.com 907-265-6471 Jan Byrne m n P 1 6 5 6 t Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-266 By Kayla Junke at 11:47 am, May 03, 2023 Digitally signed by Jan Byrne DN: CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2023.05.03 09:41:08-08'00' Foxit PDF Editor Version: 12.0.1 Jan Byrne MDG 5/3/2023 WAG X VTL 5/4/2023 DSR-5/9/23 10-404 X GCW 05/10/23JLC 5/10/2023 5/10/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.10 10:32:35 -08'00' RBDMS JSB 051523 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 3, 2023 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-14 (PTD 199-089) to install a retrievable tubing patch over a known tubing leak. Please contact me at 265-6471 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 have reviewed this document Location: Anchorage tower Date: 2023.05.03 09:40:35-08'00' Foxit PDF Editor Version: 12.0.1 Jan Byrne Well Work JusƟĮcaƟon & ObjecƟves (and date required if appropriate): 1D-14's IAP recently equalized with tubing pressure. Slickline secured the well with a CSA-2 plug and passed a CMIT to 3000 psi. A leak point LDL located a tubing leak at 186'. A tubing caliper reported cork screwed tubing with some isolated penetraƟons up to 75%. This WWR is to patch over the tubing leak at 186' and get the well back on injecƟon. Risks/Job Concerns (Include DriŌ informa Ɵon on high deviaƟon wells, or wells with tag issues): • TxIA LLR of 6 GPM LLR at 3000 psi • Passed CMIT TxIA to 3000 psi • Need approved 10-403 from AOGCC prior to patch install. Steps(Author: please include SSSV notes and note any future work required to capture rate beneĮt listed above (include esƟmated days/units in cost)): Relay or Slickline/Eline 1. Pull CSA-2 plug from 7929'. 2. Brush and Ňush tubing focusing on patch area at ~150' - 250'. 3. DriŌ dummy patch 2.72" OD x 32' OAL (to be run in two secƟons ~4' & ~28'). 4. RIH with lower P2P and set mid element at 202'. Correlate to LeakPoint LDL run 1/29/23. 5. SƟng into P2P with test tool and perform CMIT TxIA to 3000 psi. Record TIOs. Pull test tool. 6. RIH with upper patch assembly and sƟng into lower P2P. - The patch should be 28' element to element seƫng the upper P2P at 174'. 7. Perform MITIA to 3000 psi. Record TIOs. 8. RDMO, turn well over to OperaƟons. 9. Once well is online and stablilized DHD to perform SW MITIA. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 8,532.0 1D-14 3/10/2014 hipshkf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Tubing leak identified @ 186' RKB (Acoustic LDL run 1/29/23) 1D-14 1/29/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 5/21/2010 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 35.0 115.0 115.0 62.58 H-40 WELDED SURFACE 9 5/8 8.83 34.6 4,939.5 4,320.8 40.00 L-80 BTC PRODUCTION 7 6.28 30.9 8,067.9 6,233.8 26.00 L-80 BTC LINER 4 1/2 3.96 7,919.2 8,692.0 6,628.8 12.60 L-80 IBT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 28.7 Set Depth … 7,955.2 Set Depth … 6,163.5 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection 8rd EUE ID (in) 2.87 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 28.7 28.7 0.00 HANGER 6.250 FMC TUBING HANGER w/ 2.25' x 4 1/2" IBT pup 4.500 498.0 498.0 0.94 NIPPLE 4.500 CAMCO 'DS' NIPPLE 2.875 7,804.8 6,068.8 50.94 GAS LIFT 5.390 3 1/2" x1" Camco KBMG CAMCO KBMG 2.920 7,859.4 6,103.3 50.76 PBR 4.980 BAKER PBR 80/40 Spaced out 7' from located 2.990 7,886.4 6,120.3 50.87 PACKER 5.980 BAKER FHL PACKER 2.920 7,929.4 6,147.3 51.21 NIPPLE 4.500 CAMCO DS NIPPLE 2.812 7,930.2 6,147.9 51.22 SHOE 3.500 Mule Shoe 2.867 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 186.0 186.0 0.28 LEAK - TUBING 1/29/2023 2.992 7,929.0 6,147.1 51.21 TUBING PLUG 2.812" CSA-2 Plug (28" OAL) CAMCO CSA-2 1/15/2023 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,804.8 6,068.8 50.94 1 GAS LIFT DMY BK 1 0.0 6/8/2010 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,919.2 6,141.0 51.13 PBR 4.500 BAKER PBR 3.958 7,935.4 6,151.1 51.26 PACKER 6.151 BAKER MODEL ZXP LINER TOP PACKER 4.590 8,624.2 6,585.4 50.17 LANDING COLLAR 4.500 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,350.0 8,370.0 6,410.9 6,423.6 C-4, 1D-14 10/22/1999 4.0 IPERF SWS DP 180 deg. phase +/- 90 deg 8,447.0 8,457.0 6,472.6 6,478.9 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 8,466.0 8,476.0 6,484.6 6,491.0 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 8,480.0 8,495.0 6,493.5 6,503.0 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 1D-14, 1/30/2023 5:06:23 AM Vertical schematic (actual) LINER; 7,919.2-8,692.0 FLOAT SHOE; 8,690.3-8,692.0 FLOAT COLLAR; 8,657.1- 8,658.5 LANDING COLLAR; 8,624.2- 8,625.7 APERF; 8,480.0-8,495.0 APERF; 8,466.0-8,476.0 APERF; 8,447.0-8,457.0 IPERF; 8,350.0-8,370.0 PRODUCTION; 30.9-8,067.9 FLOAT SHOE; 8,066.4-8,067.9 FLOAT COLLAR; 7,979.4- 7,980.7 HANGER; 7,940.8-7,948.0 SHOE; 7,930.2 PACKER; 7,935.4-7,940.8 TUBING PLUG; 7,929.0 NIPPLE; 7,929.4 PBR; 7,919.2-7,935.4 PACKER; 7,886.4 PBR; 7,859.4 GAS LIFT; 7,804.8 SURFACE; 34.6-4,939.5 FLOAT SHOE; 4,937.7-4,939.5 FLOAT COLLAR; 4,858.7- 4,860.2 NIPPLE; 498.0 LEAK - TUBING; 186.0 CONDUCTOR; 35.0-115.0 HANGER; 34.6-36.0 HANGER; 30.9-33.1 HANGER; 28.7 KUP INJ KB-Grd (ft) RR Date 10/7/1999 Other Elev… 1D-14 ... TD Act Btm (ftKB) 8,702.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292295000 Wellbore Status INJ Max Angle & MD Incl (°) 54.17 MD (ftKB) 5,707.28 WELLNAME WELLBORE1D-14 Annotation Last WO: End Date 6/5/2010 H2S (ppm) DateComment SSSV: NIPPLE C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\OLDB5O34\2023-01-29_22071_KRU_1D-14_LeakPoitSurveu_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 22071 KRU 1D-14 50-029-22950-00 LeakPoint Survey 29-Jan-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM By Meredith Guhl at 10:10 am, Feb 06, 2023 199-089 T37484 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.02.06 10:11:28 -09'00' C:\Users\mdguhl\AppData\Local\Temp\Temp1_199089_1D-14_30-Jan-23.zip\2023-01-30_22072_KRU_1D-14_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 22072 KRU 1D-14 50-029-22950-00 Caliper Survey w/ Log Data 30-Jan-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM By Meredith Guhl at 2:35 pm, Feb 02, 2023 199-089 T37484 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.02.06 10:09:04 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1D-14 (PTD 199-089) Report of suspect IA pressure increase Date:Tuesday, January 10, 2023 9:02:16 AM Attachments:AnnComm Surveillance TIO for 1D-14.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, January 3, 2023 10:02 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1D-14 (PTD 199-089) Report of suspect IA pressure increase Chris, KRU 1D-14 (PTD 199-089) exhibited suspect IA pressure increase over the New Year holiday. Operations bled the IA pressure down, but it quickly repressurized back to equalize with tubing pressure. The well was shut in and freeze protected. DHD is performing initial diagnostics today after which a plan forward will be formulated. Any required paperwork for corrective action or continued injection will be submitted once a plan forward has been made. A 90 day TIO trend and wellbore schematic is attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 35.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.835 Top (ftKB) 34.6 Set Depth (ftKB) 4,939.5 Set Depth (TVD) … 4,320.8 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.276 Top (ftKB) 30.9 Set Depth (ftKB) 8,067.9 Set Depth (TVD) … 6,233.8 Wt/Len (l… 26.00 Grade L-80 Top Thread BTC Casing Description LINER OD (in) 4 1/2 ID (in) 3.958 Top (ftKB) 7,919.2 Set Depth (ftKB) 8,692.0 Set Depth (TVD) … 6,628.8 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,919.2 6,141.0 51.13 PBR BAKER PBR 3.958 7,935.4 6,151.1 51.26 PACKER BAKER MODEL ZXP LINER TOP PACKER 4.590 7,940.8 6,154.5 51.30 HANGER BAKER MODEL HMC LINER HANGER 4.880 Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.867 Top (ftKB) 28.7 Set Depth (ft… 7,955.2 Set Depth (TVD) (… 6,163.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection 8rd EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 28.7 28.7 0.00 HANGER FMC TUBING HANGER w/ 2.25' x 4 1/2" IBT pup 4.500 498.0 498.0 0.94 NIPPLE CAMCO 'DS' NIPPLE 2.875 7,859.4 6,103.3 50.76 PBR BAKER PBR 80/40 Spaced out 7' from located 2.990 7,886.4 6,120.3 50.87 PACKER BAKER FHL PACKER 2.920 7,929.4 6,147.3 51.21 NIPPLE CAMCO DS NIPPLE 2.812 7,930.2 6,147.9 51.22 SHOE Mule Shoe 2.867 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (shots/f t)Type Com 8,350.0 8,370.0 6,410.9 6,423.6 C-4, 1D-14 10/22/1999 4.0 IPERF SWS DP 180 deg. phase +/- 90 deg 8,447.0 8,457.0 6,472.6 6,478.9 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 8,466.0 8,476.0 6,484.6 6,491.0 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 8,480.0 8,495.0 6,493.5 6,503.0 C-2, 1D-14 5/6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 7,804.8 6,068.8 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 6/8/2010 Notes: General & Safety End Date Annotation 5/21/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Comment SSSV: NIPPLE1D-14, 3/12/2014 1:41:06 PM Vertical schematic (actual) LINER; 7,919.2-8,692.0 APERF; 8,480.0-8,495.0 APERF; 8,466.0-8,476.0 APERF; 8,447.0-8,457.0 IPERF; 8,350.0-8,370.0 PRODUCTION; 30.9-8,067.9 SHOE; 7,930.2 NIPPLE; 7,929.4 PACKER; 7,886.4 PBR; 7,859.4 GAS LIFT; 7,804.8 SURFACE; 34.6-4,939.5 NIPPLE; 498.0 CONDUCTOR; 35.0-115.0 HANGER; 28.7 Annotation Last Tag: SLM Depth (ftKB) 8,532.0 End Date 3/10/2014 Annotation Rev Reason: TAG Last Mod By hipshkf End Date 3/12/2014 KUP INJ KB-Grd (ft) Rig Release Date 10/7/1999 Annotation Last WO: End Date 6/5/2010 1D-14 H2S (ppm) Date... TD Act Btm (ftKB) 8,702.0 Well Attributes Wellbore API/UWI 500292295000 Field Name KUPARUK RIVER UNIT Wellbore Status INJ Max Angle & MD Incl (°) 54.17 MD (ftKB) 5,707.28 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 22, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-14 KUPARUK RIV UNIT 1D-14 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2022 1D-14 50-029-22950-00-00 199-089-0 W SPT 6120 1990890 1530 1140 1140 1140 1140 200 235 240 235 4YRTST P Guy Cook 7/10/2022 Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1D-14 Inspection Date: Tubing OA Packer Depth 650 2000 1950 1940IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC220709074313 BBL Pumped:1.4 BBL Returned:1.4 Friday, July 22, 2022 Page 1 of 1 9 9 9 9 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.07.22 16:25:01 -08'00' MEMORANDUM ~ State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, July 26, 2010 TO: JimRegg ~~~~ ~~~ (~~ P.I. Supervisor ~ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-14 FROM: Jeff Jones xuPAxux Rtv UNIT 1D-la Petroleum Inspector Src: Inspector Reviewed Bye P.I. Suprv ~J NON-CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1D-14 API Well Number: 50-029-22950-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ100721190251 Permit Number: 199-089-0 Inspection Date: 7/5/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ID-la ~Typ Ine ~ w TVD 6120 ~ IA 695 2500 ~ 2430 2410 P.T.DL1990890~ TypeTe~ SPT I Te$t pSl 1530 OA 545 744 734 721 P/F P Tubing IriterVal INITAI' ~ 900 900 875 875 __ _ Notes: 1.8 BBLS diesel pumped. 1 well inspected; 1 exception noted: the flow line is not properly su pported outside the well house. I also noted that the flow lines on wells 1D-101, ID-102 & 1D-105/~vere similarly unsupported. Monday, July 26, 2010 Page 1 of 1 Secure Message • • Page 1 of 2 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] ~~~`. ~j+~;(rJ Sent: Thursday, August 26, 2010 9:40 AM ~~ 1 To: Regg, James B (DOA); NSK Well Integrity Proj; Maunder, Thomas E (DOA) Cc: DOA AOGCC Prudhoe Bay; NSK Problem Well Supv Subject: RE: KRU 2F, 1 D MITs -Noted Exceptions Jim, The well lines noted in the 1 D exception report (1 D-14, 1 D-101, 1 D-102, and 1 D-105) have been re "~ supported. Additionally all wells with near future planned RWO's on 1 D will have the well lines adjusted and reconfigures as part of the RWO and a separate project is being developed to address subsidence related piping issues for the wells that are not part of the RWO program. Please let me know if you have any questions or require more information. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, July 27, 2010 12:41 PM To: NSK Well Integrity Proj; NSK Problem Well Supv Cc: DOA AOGCC Prudhoe Bay Subject: KRU 2F, 1D MITs -Noted Exceptions State of Alaska Official Correspondence PLEASE DO NOT DELETE n1617@conocophillips.com, you have received a secure Email from Regg, dames B (DOA) with the State of Alaska Government Read your secure a-mail by opening the above attachment, securedoc.html. You will be prompted to open (view) the file or save (download) it to your computer. For best results, save the file first, then open it in a Web browser. To access from a mobile device, forward this message to mobile@res.cisco.com to receive a mobile login URL. If you have concerns about the validity of this message, contact the sender directly. First time users -will need to register after opening the attachment. Get the User Guide here -htto•//doa alaska aov/ets/SecureEmail/UserGuide.odf About IronPOrt Encryption -httos://securemail.alaska.oov/websafe/about 8/26/2010 Secure Message • Page 2 of 2 Help -httos://securemail.alaska.oov/websafe/help?topic=ReoEnvelooe • ' IF YOU'D PREFER TO RECEIVE THESE COMMUNICATIONS UN-ENCRYPTED please contact the State of Alaska Service Center at htto://doa.alaska.aov/ets/serviceDesk/ and request "that a TLS connection be configured for your Email domain." You'il need to provide the Service Center with the domain information for which you receive Email, such as yourname@yourdomain.com. 8/26/2010 ' Regg, James B (DOA) __ From: Regg, James B (DOA) Sent: Tuesday, July 27, 2010 12:41 PM ~~(t 7 ~Z"Z ~~~ To: 'NSK Well Integrity Proj'; 'NSK Problem Well Supv' T ~ Cc: DOA AOGCC Prudhoe Bay Subject: KRU 2F, 1 D MITs -Noted Exceptions Attachments: MIT KRU 2F-13 7-5-10.pdf; MIT KRU 1 D-14 7-5-10.pdf Inspectors reports attached referring to excetions noted during 7/5/10 MITs at KRU 2F-13 (also exceptions on 2F-14 and 2F-16), and KRU 1 D-14 (exceptions also noted on 1 D-101, 1 D-102, and 1 D- 105). Please provide status of addressing these exceptions. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 Page 1 of 1 7/27/2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS f. operations Performed: Abandon ~"" Repair well ~ Plug Perforations Stimulate "'` Other "` ARer Casing ~ Full Tubing P~i•forate New Fbol "" Waiver Time Extension Change Approved Program Operat. Shutdow n Perforate °" Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development "" Exploratory `"' 199-089 3. Address: ~fii. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50-029-22950-00 7. Property Designatidq: 8. Well Name and Nun~er: ADL 25650 1 D-14 9. Field/Pool(s): \ Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8702 feet Plugs (measured) 7995 true vertical 6635 feet Junk (measured) 7992 Effective Depth measured 8624 feet Packer (measured} 7886', 7935' true vertical 6585 feet (true verucal) 6120', 6151' Casing Length Size MD ND Burst Collapse CONDUCTOR 115 16 115 115 SURFACE 4934 9.625 4934 4321 PRODUCTION 8067 7 8067 6234 LINER 784 4.5 8692 6629 ~~''xsl~~,~ M ~LJ Perforation depth: Measured depth: 8350'-8370', 8447'-8457', 8466'-8476', 8480'-8495' True Vertical Depth: 6411'-6424', 6473'-6479', 6485'-6491', 6494'-6503' ~V~ ~ ,`~ Zp ~~ A1~$k~ Odl C nn~. Cs~~rssi ~ra Tubing (size, grade, MD, and TVD) 3.5, L-80, 7955 MD, 6164 TVD AB~~~f Packers & SSSV (type, MD, and TVD) BAKER FHL PACKER @ 7886 MD, 6120 TVD, BAKER ZXP LINER TOP PACKER 7935' MD, 6151' TVD NIPPLE - 3.5" x 2.875"Camco "DS" Nipple @ 498 MD and 498 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Si Subsequent to operation 3590 585 13. Attachments 4. Well Class after proposed work: Copies of Logs and Surveys run Exploratory """ Development `" Service . Well Status after work: Oil Gas "' WDSPL Daily Report of Well Operations XXX GSTOR "` WAG GASINJ '° WINJ "" SPLUG ~";, 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310-156 contact Howard Gober ~ 263-4220 Printed Name Howard Gober Title Wells Engineer Signature Phone: 263-4220 Date ~/i ~I~ r r RBDMS JUL 0 2 Form 10-404 Revised 7/2009 7- ~-i a Submit Original Only ~~'~0~~~ ConocoPhillips Time Log & Summary We~N3ecv Web RepoRing Report Well Name: 1 D-14 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 5/30/2010 11:30:00 PM Rig Release: 6/3/2010 2:00:00 PM Time Logs _ Date From To Dur 5. De th E. De th Phase Gode Subcode T Comment 5/30/2010 24 hr Summary Move Rig From 3K-Pad to 1 D-Pad. Acce ted Nordic Ri 3 2330 hrs on 5-30-10 08:00 12:00 4.00 MIRU MOVE MOB P Load & hang tree for 1 D-14 in celllar. Adjust rig mats for narrow area getting around CTD-2. Move rig from 3K pad to CPF 3 intersection. Wait here for 30 min. to let rig camp office ass. 12:00 17:30 5.50 MIRU MOVE MOB P Rig camp (office) moved on to 1 D pad, spotted and set up communications. Rig continued move from CPF 3 intersection to the 1 R s ine road intersection. 17:30 19:00 1.50 MIRU MOVE OTHR P Rig Stage @ 1R-SPine Road Intersection for rig crew change out and field crew chan a out. 19:00 20:00 1.00 MIRU .MOVE MOB P Rig Started Moving Again. 20:00 20:30 0.50 MIRU MOVE MOB P Rig @ KCC. 20:30 00:00 3.50 MIRU MOVE MOB P Rig On Location & Spotted over well and rig mates. Spot & Stage Surface Equipment Nordic Rig Accepted @ 2330 hrs on 5/30/2010 5/31 /2010 Pull BPV. Observe well. Static. Set BPV. ND tree. NU BOP. Test 250/3000 psi. Pull hanger and Pulled seals free @ 130k. Pull hanger to rig floor.Reverse Circulated well out @ 8 bpm at 850 psi.Monitor well Static . Started TOOH la in down 4 1/2" tb . 00:00 00:15 0.25 COMPZ MOVE SFTY P PJSM On Plan Forvvard.Berm Cellar Walls 00:15 01:45 1.50 COMPZ WHDBO MPSP P Loading Equipment On Rig Floor for Pullin BPV 01:45 02:00 0.25 COMPZ WHDBO MPSP P V 02:00 04:30 2.50 COMPZ WHDBO OWFF P Watch Well for Flow / No Flow. Observe no flow, Install BPV. ND Tree. Install Blanking plug, Function LD Screws 04:30 08:30 4.00 COMPZ WHDBO NUND P PJSM. NU BOPE. 08:30 16:00 7.50 COMPZ WHDBO BOPE P Test BOPE including annular 250/3000 si. Page 1 of4 Time Lo s .Date From To Dur S. De th E. De th Phase Code Subcode T Comment 16:00 17:30 1.50 COMPZ RPCOM PULL P MU landing jt and pull blanking plug. MU safety valve. Verify well is dead. Pull BPV. MU tools on floor for 4.5" NSCT. MU landing jt for same. BOLDS. PU pull hanger from tubing head, continue pulling and pulled seals free @ 130K. Pulled hanger to ri floor and break out. 17:30 18:30 1.00 COMPZ RPCOM CIRC P MU head pin. Line up and reverse circulate well at 8 BPM @ 850 psi wilth 9.6# brine. Crew Change, PJSM 18:30 19:00 0.50 COMPZ RPCOM OWFF P BD-TD, Monitor well. (Static) Lost Shore Power @ 1930 hrs. Back on Generator Power for now. 19:00 00:00 5.00 7,920 4,276 COMPZ RPCOM PULL P TOOH laying down tubing, Looking for holes in jt 72 of 265 jt logged. Lost Shore Power @ 1930 hrs. On Generator Power For Now. 6/01 /2010 Complete POOH and lay down 4 1/2" Tubing. Swap out 4 1/2" Pipe Rams and install 3 1/2" Pipe Rams. Test same. Pick-up Mule Shoe Joint and 7" Casing Scraper. Single with 3 1/2" Tubing in to PBR at 7,919-ft. Reverse circulate Well. 00:00 06:30 6.50 4,276 0 COMPZ RPCOM PULL P Continue to POOH laying down 4.5" tb LD seal assembl and Ni le. 06:30 15:30 9.00 0 0 COMPZ WELLPF OTHR P Start rack & tailing 3 1/2" tubing in pipe shed. Change out upper rams from 4 112" to 3 1/2" and test. Witnessing of test waived by Chuck Scheve (AOGCC) @ 10:00 hrs 6-1-2010. Drift tubing to 2.867" except tubing above 2.875" DS ni le at +/- 500', drifted it to 2.992". 15:30 22:30 7.00 0 7,919 COMPZ WELLPF TRIP P Install wear ring. PU from pipe shed and RIH with new 3 1/2" 9.3#, L-80 8rd EUE AB-Mod tubing and 7" casing scraper with 25' cut off'oint (mule shoe) of 3 1/2" tubing below to to of PBR 7919'. 22:30 23:00 0.50 7,919 7,946 COMPZ WELLPF TRIP P Up Weight = 85K. Down Weight = 77K. Bring pump on line at 3.7 bpm/300 psi. Enter PBR at 7,919-ft with Mule Shoe (Joint #253). Pressure did not increase as Mule Shoe continued down inside PBR. However once the XO just below the 7" Casing Scraper bottomed out on the top of the PBR, pressure increased to 600 psi. Mule Shoe de th now at 7,946-ft. 23:00 00:00 1.00 7,946 7,943 COMPZ WELLPF CIRC P Pick up 3-ft. off of PBR. Line up to reverse circulate. Reverse in with a 25 bbl HI-Vis Swee and reverse sweep back to surface at 7.0 b m1,090 si. Page 2 of 4 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 6/02/2010 24 hr Summary Finish reverse circulation. Slip and cut drilling line. POOH with tubing and scraper. RU S-Line and PDS tool. Record Caliper/GR/CCL Log in the 7" Casing. MU and run 3 1/2" Completion as designed. Set Baker FHL Packer. Shear PBR. Circulate well with Corrosion Inhibited Sea Water. Land Tubin Han er. RILDS. 00:00 01:00 1.00 7,943 7,802 COMPZ WELLPF CIRC P Finish reverse circulating Well clean (saw nothing intresting come across Shaker). Blow down Top Drive. Monitor Well static, POOH to 7,802-ft. 01:00 02:30 1.50 7,802 7,802 COMPZ WELLPF SVRG P Scheduled rig service. Slip and cut Drill Line 84-ft . 02:30 06:00 3.50 7,802 0 COMPZ WELLPF TRIP P Up Weight = 88K. Down Weight = 77K. Trip out from 7,802-ft standing back 3 1/2" Tubing in Derrick. Break out mule shoe, scra er and xovers. 06:00 13:00 7.00 0 0 COMPZ WELLPF SLKL P PJSM w/HES slick line crew and PDS Eng. Install 7" shooting nipple and close annular. RU slickline and _. PDS tali er/GR/ RKB to surface. RD logging tools, RD HES slickline and removed 7" shootin ni le. 13:00 13:30 0.50 0 0 COMPZ WELLPF OTHR P Remove wear ring. 13:30 19:00 5.50 0 7,919 COMPZ RPCOM RCST P PJSM w/rig crew & Baker Rep. RIH with new completion, Baker Loc the mule shoe jt to the 2.813" DS nipple. Run Completion as follows: Mule Shoe Joint, 2.813" DS-Nipple, 1 Jt 3 1/2" 9.3 Ib/ft L-80 EUE 8rd Tbg, 3 1/2" Pup Jt, Baker FHL Packer, Baker PBR, 3 1/2" Pup Jt, 1 Jt 3 1/2" 9 3 Ib/f L-80 EUE 8rd Tbg, Camco KBMG GLM w/SOV, 233 Jts 3 1/2" 9.3 Ib/ft L-80 EUE 8rd Tbg, 2 875" DS Nipple, 13 Jts 3 1/2" 9.31b/ft L-80 EUE 8rd Tbg. Up Weight = 88K. Down Wei ht = 77K. 19:00 21:00 2.00 7,919 COMPZ RPCOM RCST P Enter the Baker PBR at 7,919-ft with_ the Mule Shoe Joint with no problems. Set down on the top of the PBR with the DS Nipple. Pick up 1-ft. Drop Packer setting Ball/Rod (fishing neck = 1 3/8") and wait to go on seat. Pressure up on Tubina to 2.100 gsi and saw Packer set. Increase pressure to 2,300 psi. Test Tubing at 2,300 psi x 10 minutes. Bleed pressure down to 1,050 psi. Pressure upon 7" x 3 1/2"Annulus to 1,500 psi x 10 minutes. Good tests. Record FHL Packer tests on chart. Top of PBR at 7,859-ft. Mule Shoe at 7,872 (inside PBR). Baker FHL Packer set at 7,886-ft. Top of original Baker PBR at 7,919-ft. End of Mule Shoe at 7,930-ft inside the PBR . Page 3 of 4 , Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 21:00 22:00 1.00 COMPZ RPCOM RCST P aker 80/40 PBR from Baker FHL Packer with 22 k over string weight. Lay down 3 Joints of Tubing. Add 24 .33-ft of space out subs. Pick up 1 Joint, Make XO and Tubing Han er. 22:00 23:30 1.50 COMPZ RPCOM CIRC P Circulate 265 bbls of Corrosion ea Water @ 5 BPM/890 si. Blow down lines and To Drive 23:30 00:00 0.50 COMPZ RPCOM RCST P Make up Landing Joint. Land Tubing Hanger. RILDS. Top of New PBR at 7,859-ft. Mule Shoe at 7,872-ft. 6/03/2010 PT tubing to 4025 psi for 30 min. Held good. Bleed down tubing to 1750 psi. PT IA to 3000 psi for 30 min. Held good. Bleed tubing and IA down to 0 psi. Pressure up IA and shear SOV. Set BPV. Nipple Down BOPE. Nipple up Injection Tree. PT hanger void to 5000 psi. Freeze protect well. Set BPV. Release ri 1400 hrs on 6/3/10. 00:00 02:00 2.00 COMPZ RPCOM CIRC P Rig up Lines. Perform MIT. Beginning pressures Tbg = 0 psi, IA = 0 psi, OA = 700 psi. Pressure up on Tubing to 4,025 psi x 30 minutes. (Lost 50 psi in 30 minutes). IA Remained at 0 psi and OA remained steady at 700 psi. Bleed pressure on Tubing down to 1,750 psi. Pressure up on IA to 3,000 psi. Tubing increased to 2,250 psi and OA increased to 1,020 psi. Pressures remained flat for 30 minutes. All tests recorded on chart and documented on AOGCC MIT Form. Blow down Lines. 02:00 04:30 2.50 COMPZ WHDBO NUND P Install BPV. Nipple down BOP Stack and set back on stum . 04:30 08:30 4.00 COMPZ WHDBO NUND P Nionle u T~Re-configured tree for proper orientation valves etc on backwards. Confirmed with Pad O erator. 08:30 09:00 0.50 COMPZ WHDBO DHEQ P Test tubing hanger void to 5000 psi for 10 min. 09:00 09:30 0.50 COMPZ WHDBO DHEQ P Pull BPV, set two way check. Test tree to 250/5000 si. 09:30 11:00 1.50 COMPZ RPCOM FRZP P RU hoses for Little Red pump truck. PJSM. Pressure test circ. lines 25/2500 psi. Pumped 82 bbls diesel freeze rotect 2.8 BPM 1800 si. 11:00 12:00 1.00 COMPZ RPCOM FRZP P RU hose and let U-tube for 1 hr. 12:00 14:00 2.00 COMPZ RPCOM MOB P Set BPV. RDMO. Remove mats. Clean cellar. Released Nordic 3 rig 1400 hrs 6-3-2010 Page 4 of 4 1 D-14 Pre and Post Rig Wellwork DATE ~ SUMMARY 05/15/10 DRIFT W/ 10.5' OF 2 7/8 DUMMY GUN AND TAGGED @ 8556' SLM. PULLED DV @ 7867' RKB. READY FOR ELINE IBP. 05/20/10 SET 2.5" BAKER IBP Cad 7995' ELMD (CORRECTED TO JEWELRY LOG), BAKER SETTING TOOL WOULD NOT RELEASE AFTER SETTING SEQUENCE, PULL 850# OVER LINE TENSION AND RELEASED AT DISCONNECT LEAVING 3.23' FISH ATOP IBP. ESTIMATED 6-8 FT MOVEMENT AFTER OVERPULL PLACING CENTER ELEMENT @ 7987' TO 7989' ELMD. TURN OVER TO LRS TO CMITIA (IN PROGRESS) 05/22/10 CIRCULATED TUBING AND IA OVER TO DIESEL, PERFORMED COMBO MITTx IA TO 2500 PSIG AGAINST IBP (GOOD), PERFORMED NO FLOW TEST ON TBG & IA (GOOD). TURN OVER TO SLICKLINE TO COMPLETE RWO PREP. 05/24/10 DUMP BAILED 12' OF CaCO3 ON RUNNING TOOL /IBP @ 7992' RKB. WELL READY FOR BRINE. 05/27/10 CIRCULATE & LOAD WELL 290 BBLS OF 9.6 BRINE. BPV ORDERED. 06/07/10 PULL 4" "H" BPV.SET BAITED 2.7" BELLGUIDE/PULLING TOOL @ 7905' SLM.IN PROGRESS 06/08/10 REPLACED CSG SOV WITH 1" DV @ 7805' RKB 3000# MITIA PASSED.4000# MITT PASSED.PULLED BAITED CATCHER SUB WITH BALL AND ROD FROM 7929' RKB 06/11/10 PULLED 2.81" RHC PLUG BODY ON CR LOCK FROM 7929' RKB.BAILED TO 7960' SLM.IN PROGRESS. 06/12/10 BAIL FROM 7960' SLM TO 7966' SLM HARD PACKED IN THIS AREA.APPROX 1' TO TOP OF FISH 06/13/10 BAILED FILL OFF TOP OF FISH. PULLED BAKER SETTING TOOL & 2.5" IBP f/ 7980' SLM (ONE 5.75" SEAL ELEMENT STILL IN HOLE) IN PROGRESS. 06/14/10 TAGGED @ 8546' SLM WITH BLB AND 2 PRONG GRAB RETRIEVED MISSING SEALING AND STIFFNER ELEMENTS. PERFORM 30 MIN SBHPS @ 8423' RKB = 2639 PSI, 141 DEG F. 15 MIN GRADIENT STOP MADE @ 8275' = 2598 PSI. CONDUCTOR, 35-115 NIPPLE. 498 SURFACE, 35-4,939 GAS LIFT. ],805 PBR, ],659 PACKER, ],886 NIPPLE, 7,929 SHOE, ] 930 PROOUCnoN, 31-8.066 IPERF, 8.350-6.3]0 APERF APERF, 8,680-8.495 LINER, ],9194,692 TD, 6,]02 NIPPLE I¢ SLM KUP i.0 ~ 6/14/2010 Rev Reason: TAG ing 0 16 ... String ID ... 15.062 Top (ftKB) 35.0 Set C 1 ing O_. 9 5/8 String ID ... 8.697 Top (ftKB) 34.6 Set C 4, ing 0 7 ... String ID ... 6.151 Top (ftKB) 30.9 Set C 8, ing 0... 4112 String ID ... 3.958 Top (ftKB) 7,919.2 Set [ 8, Inc! 1 D-14 Max An le & MD TD Inc! (°) MD (ftKB) 54.17 5,707.28 Act Btm (ftKB) 8,702.0 ate 6/5/2010 KB-Grd (tt) Rig Release Date 10!7/1999 Last Mod ... Imosbor End Date 6/16/2010 rth (TVD) ... 15.0 String Wt... 62.58 String ... H-40 String Top Thrd WELDED 1th (ND) ... 320.8 String Wt... 40.00 String... L-80 String Top Thrd BTC rth (ND) ... 234.0 String Wt... 26.00 String ... L-80 String Top Thrd BTC rth (ND)... 628.8 String Wt... 12.60 String... L-80 String TOp Thrd IBT Comment Nomi... ID (in) 9.30 I L-80 I 8rd EUE lop Inc! l°I Item Inc l/ L.LD' X x 3 1/2" 7 Too IftKBI Btm IftK81 T (ftKB D) Btlft B D) Zone Date ~ h s Type Comment p~~.~EIJ ~C~~3~i~ `-~~~~ (ND) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (°) Make Motlel (in) Serv Type Type lin) (psi) Run Date Com... 1 7,804.8 6,068.3 50.24 CAMCO KBMG 1 GAS LIFT P/Bw Q BK 0.000 0.0 651"fy~B"!9 V ' O P., ~~~ ~13~( o Regg, James B (DOA) Page 1 of 1 [~ l--G~~ From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, June 05, 2010 3:17 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: 1 D-14 MITIA performed on the rig Attachments: KRU 1 D-14 MITIA performed by Nordic 3 06-03-10.x1s All, Please find the attached MIT form for the MITIA on 1 D-14 (PTD 199-089) that was performed on Nordic 3 once the workover was complete. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 6/15/2010 Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.ao~.prudhoe.bay@alaska.gov OPERATOR• ConocoPhillips Alaska Inc P~~ L ~~ I ~ ~ FIELD /UNIT /PAD: Kuparuk /KRU / 1 D DATE: 06/03/10 OPERATOR REP: L. Hinkel -Nordic 3 Company Man AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Packer Depth Pretest Initial 15 Min. 30 Min. Well 1D-14 Type Inj. N TVD 6,108' Tubing 0 2,250 2,250 2,250 Interval I P.T.D. 1990890 Type test P Test psi 3,000 Casin 0 X3,000 3,000 '3,000 P/F P Notes: 7" x 3 1/2" Annulus Test OA 700 1020 1020 1020 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In'. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 1D-14 6-03-10.x1s • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 1D-14 Run Date: 5/20/2010 May 21, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1D-14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22950-00 ~, ~~'S. 1~ c" PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.b o.h~hb~rton com.~ ~ _ __ ~. Date: ~ ~ ~ ~' 1 ~ ~- ~~- Signed: ~, ~- t • • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, June 08, 2010 4:01 PM To: 'NSK Problem Well Supv'; Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: RE: 1D-14 MITIA performed on the rig Thanks Brent. As usual, please notify the Inspectors after the well has reached thermal equilibrium for the "official test". Tom From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Saturday, June 05, 2010 3:17 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: 1D-14 MITIA performed on the rig All, Please find the attached MIT form for the MITIA on 1 D-14 (PT 1[~ 99-O~,q) that was performed on Nordic 3 once the workover was complete. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 t~. ~~A~ 6/8/2010 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION IVlechanical Integrity Test Email to:jim.regg~alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocDPhillips Aiaska Inc. FIELD /UNIT 1 PAD: Kuparuk /KRU ! 1 D DATE: 06/03/10 OPERATOR REP: L. Hinkel -Nordic 3 Company Man AOGCC -REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 1 D-14 T e In'. N TVD 6,108' Tubi 0 2,250 2,250 2,250 Interval I P:T.l7: T` test P Test psi 3,000- Casin 0 3;000 3,000 3,000 P7F P Notes: 7" x 3 1!2" Annulus Test OA 700 1020 1420 1020 Well T In'. TVD Tubin Interval P.T.D. T test Test i Casin P/F Notes: OA We{I T e Inj. TVD Tubi Interval P.T.D. Type test Test psi Casi P/F Notes: OA Well T In'. TVD Tubin Interval P.T.D. Type test Test psi Casin PIF Notes: OA Well T e Inj. TVD Tubin interval P.T.D. T test Test i Casin P/F Notes: OA ~~~~ TYPE INJ Codes TYPE TEST Codes [NTERVAL Codes D =Drilling Waste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R = Intemal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 11/27(07 KRU 1 D-14 MITIA performed by Nordic 3 06-03-10.x1s f~ PROACTIVE DM~jNOS11C SERVIC£S~ (NC. • .~ ~~ ~~~ . ~~~ ~. ~'_ ~: ~~ .~ ' To: AoGCC . Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanioal Logs and /or Tubing Inspection[Caliper/ MTT) The technical data listed below is being submitted herewith, Please acknow{edge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road t t (` Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report 02-Jun-10 1 D-14 1 Report/ EDE 2) !~~-d~9 ~~~~~~ vac Signed Print Name: 50-029-22950-00 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: {907245-88952 E-MAIL: ~dsanc~c~r~g~c~r~a~rr~rntsv~.rs~r~ WEBSITE:1~.nv+rr.l~errr>r~sloU.y~r~ V V~~.or~ LQ~J 1~14A~/TTAL C:\Documanls and Set~gslDiane WeiliamslDesktop\Ttanscnit_Conooo.docx • • Memory Multi-Finger C~Iliper S Log Results summary Company: ConocoPhiltips Alaska, Inc. Well: 1D-14 Log Date: June 2, 21)10 Field: Kuparuk Log No.: 7412 State: Alaska Run No.: 2 API No.: 50-029-22950-00 Pipet Desc.: 7" 26 Ib. L-80 BTC Top Log Intvl1.: Surtace Pipet Use: Production Casing 13ot. Log Intvl1.: 7,14 Ft (MD) ' Inspection Type : Corrosive & Mechanical Damage -nspection COMMENTS This caliper data is correlated to the Sch/umberger Cement Bond Log dated October 4, 1999. This log was run to assess the condition of the production casing with respect to corrosive and mechanical damage. The caliper recordings indicate the 7" production casing logged appears to be in good condition, with nv significant wall penetrations, areas of cross-sectional wall loss or l.D. restrictions recorded. This is the second time a PDS caliper has been run in this well and the first time the 7" production casing has been logged. MAXIMUM RECORDED WALL PENETRATIONS: No significant wal{ penetrations (> 15°1°) are recorded throughout the production casing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No sign cant areas of cross-sectional wall loss {> 3°~} are recorded throughout the production casing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the production casing logged. Field Engineer: tNm. McCrossan Anal st: C. Waldrop Witness: C.Kennedy FroActive Diagnostic Senlices, Inc. / P,C3, Box 1369, Stafford, 7X 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDSi~~memorylog.com Prudhoe Bay Field Office Phone: {907) 659-2307 Fax: (907) 659-2314 U a-L' r~9 - ~~~ (~'~iJb • Correlation of Recorded Damag Pipe 1 7. in (17.1' - 7894.8') Well: Field: Company: Country: Survey Date: • ;e to Borehole Profile 1 D-14 Kuparuk ConocoPhillips Alaska, Inc. USA June 2, 2010 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e 1 25 17 1012 50 2024 75 3043 w ~ .c Z 100 4090 Q c ' . ~ o 1 p 125 5124 150 6158 175 7189 192 7895 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 192 • • __ PDS Report Overview ~-°L_ s,, Body Region Analysis Well: 1 D-14 Survey Date: June 2, 2010 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Ana st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 7 ins 26 f L-80 BTC 6.276 ins 7 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°k wall) ~ penetration body '»-.n. metal loss body 200 150 100 50 0 0 to 1 to 10 to 20 ro 40 to over 1% 10% 20% 40% 85% 85% Number of'oints anal s ed total m 192 pens loss . 0 186 6 113 79 0 0 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general Ilne ring hole / poss pitting corrosion corrosion conrosion iblehole Number of'oints dam ed total = 8 8 0 0 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 1 51 Bottom of Survey = 192 100 101 151 Analysis Overview page 2 • PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf L-80 BTC Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • -LATION SHEET 1 D-14 Kuparuk ConocoPhillips Alaska, Inc. USA )une 2, 2010 Joint No. )t. Depth (Ft.) I'c•n. Upset (In,.) Pen. Bady (Ins.) I'en. % Mct•~I I oss `~<, Min. LD. (Ins.) Comments Damage Profile (% wall) 0 50 100 1 17 U 0.01 4 ' 6.2 2 59 U 0 01 4 ~ 6.21 3 102 ti ,O1 ~~ 6.25 4 142 a 0.01 ~ ~i 6.20 5 185 a 0.01 3 ~ .21 6 224 u 1 ~ I 6.26 7 66 U 0.01 3 I 6. 2 8 05 i~ 001 4 I 6. 4 4 i) 0.01 I 6 21 10 391 U 0.01 3 1 .21 11 432 t 1 0.01 3 6.22 1 474 U 0. 1 3 I 6. 9 13 514 ti 0.01 } 6.20 14 55 (i 0.0 7 I 6.2 15 598 t? 0.05 1:3 6.27 Shallow ittin . 16 641 t) 0. 1 I 6.27 17 683 t) 0.01 3 _' 6.21 18 725 ci 0.01 4 I 6.22 19 766 (i 0.01 4 I 6.21 2 8 7 U 1 3 I 6. 1 21 8 (i 0.01 4 1 .27 22 889 ti 0.01 3 I 6.25 3 u 0.01 4 1 6.2 4 970 ti 0.01 ~ I 6. 5 5 101' U D.01 i I 6.26 26 1055 ti 0.01 s 6.21 27 10 7 U 0. 1 -1 6. 0 28 1137 a 0.0 4 I 6.20 9 1177 !' 0.02 V 6.18 30 1 14 t) 0.02 ~ i 6.22 1 1257 tl .01 4 1 6.23 32 1298 i i 0.01 ; I 6.20 33 1336 ti 0.01 4 I 6.2 34 1379 a 0.01 .3 I 6.26 5 14 7 ~~ .02 0 6. 5 3 1458 !? 0. 1 4 I 625 3 1498 t i 0.0 6 1 6.22 1 40 U 0.0 -1 1 7 9 5 u .01 4 I .25 40 16 t i 0.01 ~; 3 41 1660 t i .01 4 1 6. 7 42 170 t) 0.01 ~ I 6.2 43 1740 U 0.01 3 1 6. 5 ` 44 1780 U 0 01 3 I 6.' S 45 18 2 u 0.02 4 I 6.20 1861 ti 0.0 ~ I 6 47 1902 U 0.01 4 I 6.24 48 1943 i) .01 3 I 6.22 49 19 2 ~i 0.01 3 I 6.26 5 2024 U .01 4 I 6 1 Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABI, Pipe: 7. in 26.0 ppf L-80 BTC WeII: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • ELATION SHEET 1 D-14 Kuparuk ConocoPhillips Alaska, Inc. USA June 2, 2010 Joint No. )t. Depth (Ft.) Pcn. t llsc~r (fns.) Pen. Body (Ins.) I'c~n. °i~ Mct.~l I oss °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 51 2063 t t 0.01 4 1 6.2 5 2103 ~~ 0 O1 4 I 6.21 53 146 ~! 0.01 ~ I 1 54 2185 ~) Q01 1 6.20 55 1 u 001 ~ 1 6.19 56 2263 t) 0.01 3 1 6.27 57 2306 t~ 0.01 > I 6.24 58 348 a 0.01 ~> t 6. 1 59 391 t) .01 ~ I 6.2 6 24 3 t) 001 ~ 6. 1 61 2474 i) 0.01 4 1 6.25 62 2514 U 0.01 3 1 6.24 63 2554 a 0.01 4 I 6.20 64 2595 i) .01 ~; I 6.2 65 2636 ll 0.01 ~ I 6.19 66 678 ! 1 0.01 3 I 6.27 67 2720 a 0.02 U I 6.24 68 2763 t? 0.01 4 t 6.19 69 803 U 0.01 4 I 6.25 70 2 2 0 .01 3 1 2881 U 0.01 4 I 6. 4 7 292 U 0. 1 3 r 4 73 2961 ~) 0.02 4 I 6.21 74 3002 ! ~ 0.03 ti I 7 303 U 0.1 4 1 76 3084 U U.01 ~ i 6. 0 77 3126 U 1 4 6.2 78 3168 tl 0.01 4 _' 6.23 79 3 11 a .01 4 I 6.17 80 3253 U 0.02 -~ I 6.20 81 3 96 tt 0.0 4 I 6.25 82 3338 i1 0.01 4 I 6.23 3381 i ~ 0.01 4 1 6.25 84 34'24 n 0.01 ~ 1 6.18 8 3466 U 0. 1 ~ ? 6.1 86 350 U .01 ~ 1 6.23 7 3550 O 0.02 4 ~' 6. 2 88 3 89 ~ 0.01 ~ 1 6.25 89 3632 ~) 1 4 I 6.20 90 3675 U 0 01 4 I .23 91 3717 c) 0.01 ~ I 24 ` 92 3760 it 0.01 4 I 6.20 3 3801 U 0.01 4 1 6.17 94 3842 (~ 0.0 6 t 6.24 95 3$85 t) 0.02 6 1 6.18 6 9 4 c) 0. 3 t3 i 6. 4 97 3967 t~ 0.01 4 6.16 98 08 a .0 U ' 6.23 99 4051 U 0.03 £s I 6.21 100 409 t ~ 0.01 -1 I 6.17 _ Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf L-80 BTC Well: Body Wall: 0.362 in field: Upset Wall: 0.362 in Company: Nominal LD.: 6.276 in Country: Survey Date: • iLATION SHEET 1 D-14 Kuparuk ConocoPhillips Alaska, Inc. USA June 2, 2010 Joint No. Jt. Depth (Ft.) I'c•n. Ulxe~ (Ins.) Pen. Body (lns.) Pen. % Metal loss ",4, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 101 4132 t) 0.01 3 I 6.20 10 4 73 i1 0.01 3 2 6.16 103 421 U 0.02 6 _' 6.16 1 4 4 55 ~~ 001 4 1 .2 105 4296 a 0.01 3 1 6.20 1 6 4 36 O 0.01 4 2 6.1 107 4377 tt 0.01 3 1 6.17 108 4417 U 0.06 1 i ? 6.14 Shallow ittin . 109 t) 0.0 1 6.17 110 4501 0 0.0 7 6. 0 111 4544 i) 0.01 ; I 6.18 112 4584 U 0.01 -1 6.22 113 4628 t~ 0.02 c, 1 6.22 114 4670 t) .01 -1 I .1 115 4712 t i 0.02 U 6.19 116 475 (? 0. 1 4 I .20 117 4789 t ~ 0.01 4 2 6.14 118 4832 t ~ 0.01 3 ~' 6.19 ~ 119 4875 (1 0.02 6 1 6.16 120 491 t~ 0.0 4 1 .17 121 4956 t ~ 0.02 t> 5 122 4995 t; 0.02 i 1 6. 3 23 5038 t~ 0.03 7 .' 6.18 1 4 081 U 0.03 7 I 6.13 25 5124 (? 0.02 7 ~ 6. 126 5167 t! 0.01 4 _' 6.15 127 5 10 u 1 ~ 6.11 1' 8 5253 t) 0.02 4 6.2 129 5 96 0 0.01 3 6.23 130 5339 U 0.01 d I 6.23 131 538 t) 0.02 ~ I 6.2 132 5425 +~ 0.02 4 .14 13 5468 ! ~ 0.02 6 .1 134 5507 t~ 0.03 7 ! 6.17 13 5549 t ~ 0.01 4 ~' 6.15 136 5S 2 t ~ 0 03 7 6.19 137 5630 ti OA 6 _' 6.19 138 S 73 t~ 0 2 6 I 6.18 1 9 5713 ~.~ 0 2 ~ 6.21 140 5755 t~ 0.02 6 ~' 6.14 141 5 98 t~ 0.02 t~ 0 14 5833 ~ I 0.03 t~ I 6.21 143 587 t~ 0.01 4 2 6.2 144 5915 ! ? O.U2 6 1 6.19 145 5958 U 0. 2 6 _' 6.17 146 001 t~ 0.02 6 i 17 147 6041 U 0.02 6 1 6.21 148 6077 ti .01 3 1 6.2 149 6115 t ~ 0.03 i I 6.14 150 6158 t~ 0.01 4 :' 6.16 Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABS Pipe: 7. in 26.0 ppf L-80 BTC Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: i ~LAT1ON SHEET 1 D-14 Kuparuk ConocoPhillips Alaska, Inc. USA June 2, 2010 Joint No. )t. Depth {Ft.) I'c~n. U~~sc•I (In~.l Pen. Body (Ins.) I'en. % ~Ic•tal I toss °.~~. Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 151 6 97 U 0.01 ~ I 6.21 152 6240 t? 0.01 d _' 6.15 153 62 3 t! 0.01 ~l 1 6.18 5 63 4 ~~ .0 ~ I 6.19 155 6 66 t! 0.02 I 6.15 56 6407 t! 0.0 s I .17 1 7 6449 n 0.03 7 _' 6.22 158 6488 t! 0.02 (~ 6.21 1 9 6522 U 0. 1 s 6. 1 160 65 U 0.01 i ~ .18 161 6608 U 0.03 8 ~' 5.99 6 66 1 t) 3 £ 6.17 163 6692 a 0.01 4 ? 6.17 1 4 6734 i } 0.01 s 6.19 165 6772 t ! 0.01 3 6.17 166 6 11 U 0.01 3 1 6.15 167 6852 U 0.01 t _' 6.23 168 6 94 U 0.01 3 6.16 69 9 7 tt 0.01 4 6.14 170 6977 i! 0. 3 7 ~' 6.19 171 7D 7 t? 0.01 4 _' 6.14 17 7060 a 0.03 7 6 7 173 710 t) 0.0 6 _' 6.1 174 714 t? 0.0 4 .12 175 71 t? ~ .02 (~ ~ 6.17 176 722 t ~ 0.01 3 I 6.16 177 70 a 0.01 3 _' 6.1 178 7310 t? 0.01 ; I 6.1 179 7348 U 0.0 i Z 6.15 180 7389 t1 0.02 i Z 6.16 181 743 t 1 0 02 6 I 6.1 182 7473 !) 0.01 4 6.18 '' 183 75 6 U 0.04 i U _' 6.1 hallow it6n . 184 7557 U 0.03 "~ 6.18 Shallow ittin . 1 5 76 0 u 0.02 6.19 1 6 64 t t 0. 2 6 ' 6 1 187 7686 U 0.0 7 ~ 6.13 188 7729 U .03 7 { 6.13 89 777 t) .0 11 6.19 hallow ittin 1 0 781 t) 0.04 7 % 6.1 Sh Ilo iltin . 191 785 t! 0.0 1 ~ I 6.1 Shallow itti 192 789 !! 0.04 l_' 6.13 Sh Ilow ittin . ;Penetration Body Metal Loss Body Page 4 ` ~-' ~ KU P 1 D-14 ConocoPhillips I n nm~x,ies a., ~ ~ nuo m :I^`... , ore elaRame I) U 1 _ _ _ _ ( 500292295000 KUPARUK RIVER UNR INJ 54.17 5,707.28 8,702.0 coNwcroa, 3s-ns NIPPLE, 556 SURFACE. 354,939 GAS LIFT, 7,867 NIPPLE.7917 SEPL,7 FISH. 7, PLUG, 7, PPERF, 8,4668,476 APERF, 8,480-8 695 LINER, 7,9t9A.692 TD, 8.702 H. Gober Page 8 of 26 May 27, 2010 • • ~~Q~[~ Ofd Q~Q~~(Q /,E..M.~..~o~.,~ Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. ~~~~~ j,~!~, ~ E_. ~? 2C~'C~ P.O. Box 100360 Anchorage, AK 99510 ~ ©~ ~~~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 D-14 Sundry Number: 310-156 Dear Mr. Gober: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair `fl DATED this day of May, 2010. Encl. • • ~onocoPh i I I i p~ Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 18, 2010 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7"' Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 1 D-14 (PTD 199-0$9). Well 1 D-14 was drilled and completed as a Kuparuk C sand water injector in October of 1999. In mid-2009, 1 D-14 failed an MITIA with a liquid leak rate of nine gallons per minute. A caliper log run in October of 2009 showed line corrosion on the low side of the tubing with probable holes in 72 of the 265 joints logged. A prime suspect in the cause of this low side corrosion in tubing less than ten years old is low injection velocity. The primary objective of this workover project is to restore the integrity of the tubing and inner annulus interface and return the well to MWAG service. This single completion well will be downsized from 4-1/2 inch tubing to 3-1/2 inch tubing in order to reduce the risk of corrosion due to low injection velocities and increase the fife of the tubing. A stack packer will also be run to provide a nipple profile below the packer. This nipple will allow for reservoir isolation on f subsequent workovers. The packer will be 510' MD (320'TVD) above the fir. -~-o`o ~~rt z?-<~ If you have any questions or require any further information, please contact me at 263-4220. Sincerely, ~~ Howard B. Go er Wells Engineer CPAI Drilling and Well /D STATE OF ALASKA ~k~1~ y~.~1'~LAS~IL AND GAS CONSERVATION COMMISS• ~,.ti APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ~i AY 1 9 20'!10 1. Type of Request: Abandon "" Rug for Redrill Perforate New Pool Repair w ell ~ ang~~ Program Suspend ~"'" Rug Perforations J"•` Perforate '"` Pull Tubing Time Extension '"° Operational Shutdown ~"" Re-enter Susp. WeII Stimulate ~ Alter casing ~"°" Other: ~"® 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~" Exploratory ~ 199-089 3. Address: Stratigraphic ~ Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22950-00 7. If pertorating, 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 No ', 1D-14 9. Property Designation: 10. Field/Pool(s): ADL 25650 Kuparuk River Field /Kuparuk River OiI Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effeaive Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8702 6635 8624' 6585' Casing Length Size MD ND Burst Collapse CONDUCTOR 115 16 115' 115' SURFACE 4934 9.625 4934' 4321' PRODUCTION 8067 7 8067' 6234' LINER 784 4.5 8692' 6629' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8350'-8370' 6411'-6424' 4.5 L-80 7920 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) no packer Camco DB nipple MD= 554 TVD= 554 12. Attachments: Description Sunrnary of Proposal ~' 13. Well Class after proposed work: Detailed Operations Program BOP Sketch ~ Exploratory "'; Development Service w 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/29/2010 Oil Gas WDSPL ~ Suspended 16. Verbal Approval: Date: WINJ " GINJ ~"' WAG Abandoned ~"" Commission Representative: GSTOR SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Howard Gober @ 263-4220 Printed Name Howard Gober Title: Wells Engineer ~ ~~ ~ ~ Phone: 263-4220 Date Signature C mmi i n nl Sundry Number:31 l~- ~ 5(,0 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ]''~';, BOP Test Me rityTest ~"/ Location Clearance chanical Integ //~~ ~ * ~ PSc. /.>~ ~ (e S 1~ - M ~ ~ tG u-~~ Oth r e : / p _ ,QI~r..,.~. ~~ P rte.«•~.<..,~- Subse uent Form Re uired: q q APPROVED BY /~ 1 / ~ ~ ~ Approved by: COMMISSIONER THE COMMISSION Date: r `°m-"° *'"" ORIGINAL g,~ s Z7~a Submit in Duplicate Cond~oPhillips rr Iti++.d ~rU.. CONDUCTOR. 115 NIPPLE. 554 SURfACE. 4,934 GAS LIFT, 7,867 NIPPLE. 7,512 SEAL. 7,920 PRODUCTION. B.O67 IPERF, 8.350-8.370 LINER. 8.692 TD, a N2 KUP ~ 1 D-14 ,ttributes __ Max Angle & MD i TD APW WI Fieltl Name (Well Status Inc! (°) MD (ftK6) Act Blm (ftK8) 92295000 KUPARUK RIVER UNIT '~INJ 54.17 5,707.28 8,702.0 .Comment H2S (ppm) KBGrd (H) (Rig Release Date Annotation ' End Date Date SSSV: NIPPLE ( I I ( Last WO: ~ I 10/7/1999 (Annotation Depth (ftK8) (End Date Annotation Last Mod By End Date (Last Tag' SLM 8,514.0 ', 12/21/2009 Rev Reason: POST FCO SIL TAG Imosbor L_ 12/30/2009_ Casin Strin s String OD String ID Set Depth Set Dapih (ND) String Wt String Casing Description (in) (inl Top (ftK6) (ftK6) (fiKB) (Ibslft) Grade String TOp ThN CONDUCTOR i6 15062 0.0 115.0 115.0 6258 H-00 WELDED 'I SURFACE 9 5/8 8.697 0.0 4,934 0 4.3175 40.00 L-80 BTC ?RODUCTION 7 6.151 00 8,0670 6,233.5 26.00 L-80 BTC '_INER 4112 3-958 7,908.0 8,692.0 6.6288, 12.60. L-80 IBT i Strings Tubing . __ ___ ____ . Strng OD String ID Set Depth Set Depth (ND) String Wt i Str ng Tubing De iption (n) (in) Top (ftKBJ (ftK8) (kK8) (Ibs/ft) G de I Str g T pThrd TUBING ~ 4112 3.958 0.0 7,9200 6,1414 12.60 LSOIIBT 11111 Other In Hole A ll Jewel :Tubin _ g Run & Retrievable, Fish, etc.) _ _ _- --- Top Depth (TVD) lop Inc! Top (NKB) (ftK6) ! (°) Description Comment Run Date ID (in) 554 5540 1.17 NIPPLE CAMCO DB nipple 10/6/1999 ~, 3.813 7.867 6,108.1 50.72 GAS LIFT CAMCO/KGB-2-LS/1 /DMY/DCK-3/// Comment STA 1 10/22/1999 13.833 7,912 6,136.3 51.07 NIPPLE !OTIS "X" nlpple 10!6/1999 3.812 7 920 6,141.4 51.14 _ SEAL (Baker GBH 22 SEAL ASSEMBLY 10/6/1999 1I4.500'. _. -,_.~_.~.__ _. _.. _._L_- __. Perfora tions 8 S lots i I _ __ _ _ Shot Top (TV D) Btm (TVD) Dens Top (ftK8) 8trn (ftK6) (ftK8) ~ (kK6) Zone Data (sh... Type Comment 8,350 8,370 ,_ I 6.410.8 6,423.5',C-4, 1D-14 10/22/1999 4.0 1PERF SWS DP 180 tleg. phase+l-g0 deg .~ 1 D-14 Expense Rig Workover PTD #199-089 5/18/10 Current Status: The well is currently shut in awaiting workover. No plugs are set at this time. IBP is scheduled to be set in the liner on 5/19/10. Scope of Work: Replace 4-1/2", 12.6# L-80 IBT tubing with 3-1/2", 9.3# L-80 EUE 8rd-Mod tubing. General Well info: MPSP: 2,000 psi Reservoir pressure: 2647 psi at 6457' TVD ~ 7. $ ~o~ Eµw FMC Gen 5 5M Wellhead BOP configuration: Annular/Pipe/Blind/Flow cross/Pipe CMIT TxIA to 3000 psi passed on 11/11/09. OA has open shoe. OA low pressure test to 300 psi passed on 11/13/09 Well Type: Injector Estimated Start Date: May 28, 2010 Production Engineer: Erica Kappel Wells Engineer: Howard Gober 263-4220; howard.gober@conocophillips.com Pre-Rig Work: 1 Drift tubing and liner to 8450' RKB. Pull DV at 7867' RKB. Leave pocket open. DONE 5/15/10. 2 Set IBP in liner at -7995' RKB (mid joint). IBP must be able to come through 2.812" min ID after the workover. Scheduled to be set 5/19/10. 3 CMIT TxIA to 2500 psi. Bleed pressure down to 0 psi. 4 Dum bail CaCO3 on top of IBP. Load well with 9.6 pp brine if time allows 5 Set BPV in the tubin han er. 6 Remove the wellhouse & flow line. Level the pad as needed for the ri . Min of 2 barriers at this time IBP and BPV along with tested hanger seals. Proposed Procedure 1. MIRU. Pull BPV. Load well with 9.6 ppg brine if not done pre-rig. Set BPV. ND tree. NU BOPE with VBR pipe rams or 4-1/2" rams. Pressure test Blind Rams, VBR's or pipes, and annular to 250/3,000 psi. Pull BPV. 2. Pull and LD 4-%z" tubing string and seal assembly. 3. If necessary, change pipe rams to 3-1/2". Pressure test rams and body to 250/3,000 psi. 4. RIH and scrape the casing. 5. Run 3'/2" L-80 completion with Baker FHL packer and PBR. Position packer at _7,840' MD. Note: This packer will be set so that a nipple profile is available for reservoir isolation on, subsequent workovers. This packer will be -510' MD (320' TVD) above the top pert. 6. Displace the well to corrosion inhibited seawater 7. Set the packer. Land hanger. Test tubing to 4,000 psi and IA to 3,000 psi. 8. Set 2-way check. ND BOPE. NU and test tree. Pull 2-way check. Freeze protect well. Sei BPV. RDMO. Planned Post-Rict Work: 1 Set catcher sub. Pull SOV and install DV. MIT-Tubing to 4000 psi. MIT-IA to 3000 psi. Pull catcher sub. Pull ball and rod. Pull RHC plu body. 2 Bail CaCO3 off IBP at 7995' RKB. Pull IBP at 7995' RKB. Note: Reservoir pressure is +/-7.9 ppg equivalent below the plug. 3 Ta fill. Obtain 30 min SBHP at 8423' RKB 4 Return well to injection. W ' ne~3~.0 M T" STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS~J REPORT OF SUNDRY WELL OPERATIONS R~~~tVED MAY ~ ~ 2010 1. Operations Performed: Abandon ~ Repairwell ~°" Plug Perforations ~ Stimulate r Alaska OiP~$~`Cens. bo~~t~t®lg Alter Casin Pull Tubin g "'" g ~ Perforate New Fbol Waiver Time Extensio ~t1~AfA Chan e A roved Pro ram erat. Shutdown g pp g ~"`, Op Perforate ~', Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development "-" Exploratory `°" 199-089 3. Address: API Number: ~fi Stratigraphic Service . P. O. Box 100360, Anchorage, Alaska 99510 50-029-22950-00 7. Property Designations 8. Well Name and Number: ADL 25650 ~ 1 D-14 9. Field/Pool(s): ~ Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8702 feet Plugs (measured) None true vertical 6635 feet Junk (measured) None Effective Depth measured 8624 feet Packer (measured) 0 true vertical 6585 feet (true vertucal) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 115 16 115 115 SURFACE 4934 9.625 4934 4318 PRODUCTION 8067 7 8067 6234 LINER 784 4.5 8692 6629 Perforation depth: Measured depth: 8350'-8370', 8447'-8457', 8466'-8476', 8480'-8495' True Vertical Depth: 6411'-6424', 6473'-6479', 6485'-6491', 6494'-6503' qq (r~~ Tubing (size, grade, MD, and TVD) 4.5, L-80, 7920 MD, 6141 TVD Packers &SSSV (type, MD, and TVD) no packer no SSSV SEaL mss ~ 7gZo ~ µ~ 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation si Subsequent to operation si 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory "°`., Development ~' Service . Well Status after work: Oil Gas WDSPL Daily Report of Well Operations XXX GSTOR ,~ WAG GASINJ WINJ SPLUG ~" 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: none contact John Peirce ~ 265-6471 Printed Name John Peirce Title Wells Engineer Signature 9 ~~,1.. ~~ _ Phone: 265-6471 Date ,,--~~~~~ ~ ~ .~~~ Form 10-404 Revised 7/2009 RBOM3 MAY 26 ~q~ ~ ~ =~ ~ ,~ Submit Original Only ,~ ~~~~/~ • 1 D-14 Well Events Summary DATE SUMMARY 4/23/10 ATTEMPTED DRIFT TBG WITH 2 3-3/8" DUMMY GUN; UNABLE TO WO~AST @ 8295' RKB. BRUSHED TBG. DRIFTED TBG WITH 11' x 3.5" DUMMY GUN TO 8500' SLM. READY FOR E/L. 4/25/10 DRIFTED TBG WITH 20' x 3.20" BARBELL DRIFT TO 8515' SLM. READY FOR E/L. 5/5/10 PERFORATED USING 3 1/8", 6 SPF, 60 PHASING, MILLENIUM DEEP PENETRATING CHARGES. PERFORMED 2 GUN RUNS AND PERFORATED AT DEPTHS OF 8485'-8495', AND 8480'-8485'. CORRELATED TO SCHLUMBERGER CBL DATED 10/04/99 5/6/10 PERFORATED 8466'-8476' AND 8447'-8457' WITH 3.125" MILLENNIUM EXPRESS DP CHARGES, 6 SPF, 60 DEG PHASING. CORRELATED TO SC1-ILUMBERGER CBL DATED 10/04/99. PERFORMED STATIC BOTTOM HOLE PRESSURE SURVEY. 2647 PSI, 144 DEG AT 8423' AND 2603 PSI, 145 DEG AT 8265'. C~~tiPh~l~i~s 7~ -Iti'K a. ~~1C, Well COnf g:.-1p-16, 51': B12( coy N NIF PRC L KUP ~ 1 D-14 ell Attributes ;Max Angle & MD TD Itwre API/UWI 'Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) Sf1l17(1 J')QSl1f1U IKI IPARIIK RIVFR I1NIT INJ ~ 54.17 5.707.28 8,702.0 Comment '~H2S (ppm) End Date KB~rd (ft) Dafe (Annotation Rig Release Date SSSV: NIPPLE I ( Last WO. I 10/7/1999 Annotation Depth (ftKB) 'End Date Annotation ', Last Mod By End Date Last Tag: SLM 8, 556 0 ~ 5/15/2010 Rev Reason' ADD PERFS, TAG, GLV C!O Imosbor 5/15/2010 Casin Strin s String OD String ID ~ Set Depth Set Depth (ND) I String Wt String ; Casing Description (in) (in) Top (ftKB) (ftKB) (ftKB) (Ibs/ft) Grade ' String Top ThM CI ONDUCTOR 161 15.062 0.0 115.0 115.0 G258 H-40 WELDED !SURF-ACE 95/8'. 8.697 0.0 4,934.0 4,317.5 40.00 L-80 BTC PRODUCT ION ~ 71 6.151 0.0 8,067.0 6,233.5 26.00 L-80 BTC LINER 4 1/2 3.958 7,908.0 8,692.0 6,628.8 12.60 L-80 IBT '(Tubing Strings String OD String ID Set Depth Set Depth (ND) String Wl Strmg TubingD ription (in) (inl Top (ftKB) (ftKB) (ftKB) (IDS/k) G de Stang TOp ThM TUBING 4112 3958 0.0 7,9200 6,1414'1 12.601 L-SO IBT l Other In Hole A etrievable, Fish, etc.) ll Jewelry; Tubin Run 8 R Top Depth - ~ __ __ _ _ (TVD) Top Inc! ~~ ~TOp (ftKB) (ftKB) (°) Description Comment Run Date ID (in) 554 554.0 1.1711 NIPPLE CAMCO DB nipple 10/6/1999 3.813 7,867 6,108.1 50.72 GAS LIFT ~GAMGG/KGB-2-LS/1/OPEN////Comment STA 1 5/15/2010 ' 3.833 7 912 6,136.31 I 51.07 NIPPLE OTIS "X" nipple 10/6/1999, 3.812 7,920 6,141411 51.14 SEAL (Baker GBH 22 SEAL ASSEMBLY 10/6/1999 II 4.500 Perfora tions 8r Slots - _ ' _ -_ snot Top (TV D) Btm (TVD) Dens Top (ftKB) Btm (ftKB) ~ (ftKB) (ftKB) Zone Date ian-~ Type CommaM 8,350 8,370 6,410.8 6,423.5 C -4, 1D-14 10/22/1999 4.0 IPERF SWS DP 180 tleg. phase +/- 90 deg _ _. 8,447 8,457 6,472.5 6,478.9 C _ - -2, 1 D-14 5/6/2010 6.0 _ APERF HES 3.5"Millenium DP, 60 deg phase 8,466 8,476 6,484.6 6,491.0 C -2, 1 D-14 5!6/2010 6.0 APERF HES 3.5"Millenium DP, 60 deg phase 8,480 8,495 6,493.5 6,503.0 C -2, 1 D-14 5/6!2010 6.0 APERF HES 35"Millenium DP, 60 deg phase ! • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record /Bottom Hole Pressure Survey: 1D-14 Run Date: 5/5/2010 May 7, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1 D-14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22950-00 E~~~.,G~ ,ri_:~ ~ ?,a ~ ,_ _ PLEASE ACKNOWLEDGE RECEII'T BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto c~ rafael.barreto@ •- y r -~ Date: ~4AY ~ ~ 2010 I~C~G/~s Signed: ,~~'"~ z ,~ ~; ~~ w . Coot 6 u • ~ 1/If~L~ ~~iJ ~/"~f-~~ V~7fV/~~.f-~~ ~~, PxoAaivE Dinynos~ic SeavicES, lnc. To: A(]GCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) fi59-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caiipe~ / MTT) The technical data (isted below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the fol(owing : ProActive Diagnostic Services, lnc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 ~ax (907) 245-8952 1) Caliper Report 03-0ct~09 2) ~Z ~ ~~~-D~S`?~ ~ '~ ~'~ Signed : Print Name: 1 D~14 1 Report / EDE 50-029-22950-00 _~~~~~~k~ ~~~ ~' t' C ~ 2~~~ Date : . PROQCTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SURE C, ANCHORAGE, AK 99518 PHONE: (807~245-8951 FAU: (907)245~8952 E-nnE-tL . ~~ _ ,v _._ ________ ___._._ .._ ~ WsBSITE : ~_______ _.__ .-_ <. C-\Documen6 and Settrngs\Owner\Desktop~Transenit_Conoco_docx i~ ~ 1 ~ _ r i Memory Multi-~inger Galiper Log Results Summary Company: ConocaPhillips Alaska, Inc, Welt: 1D-14 Log Date: Octaber 3, 2009 Fieid: Kupatuk Log No. : 6297 State: Alaska Run No.: 1 API No.: 50-029-22950-00 Pipe1 De,sc.: 4.5" 12.6 ib. L-80 IBT Top Log Intvl1.: Surtac~e Pipe1 Use: Tubing and Liner Bot. Log Intvl1.: 7,945 Ft. (MD) , inspection Type : Corrosive & Mechanical Damage /nspection COMMENTS: ' This caliper data is tied inta ff-e Otis X Nipp/e @ T,972' (Drl/ler's DepthJ. This log was run to assess the condition of the tubing and liner with respect to corrosive and mechanical , damage. The caliper recordings indicate the 4.5" tubing and liner loggeci is in good to poor condition with respect to corrosive and mechanical damage. 7he caliper recordings indicate holes, probable holes and possible ~oles in 72 af the 265 joints logged. Additional recorded damage appears as isolated pitting (surtace ---2,400'} and a line af pits / line corrosion recarded on the !ow side of the tubing from ~2,400' to ', ~ the bottom of the intervat logged, with some broade~ areas of generaf corrosion. Cross-sectional wall loss from 15% to 29% wall thickness is indicated in 44 of the 265 joints logged, with a maximum cross-sectional wall loss of 29°~ recorded in an area of corrosion in joint 219 (6,810'). The caliper recordings indicate ' deposits from -5,100' to the bottom of the interval logged, and restrict the I.D. to 3.15" in pup joint beiow X nipple (7,922'). A graph illustrating minimum recorded diameters on a joint-by joint basis is included in this report. 4.5" TUBING ~ LINER - MAXIMUM RECORDED WALL PENETRATlONS: Multiple Holes (100%) Jt. 223 (c~ 6,945 Ft. (MD) Hole ! Possible Muttiple Holes (100°1a) Jt. 134 @ 4,193 Ft. (MD} Hole {1009~0) Jt. 163 @ 5,088 Ft. (MQ} Hote 1 Possible Multiple Holes (100%) Jt. 231 ~ 7,186 Ft. (MD) Hole (100°~) Jt. 213 c~,,'0 6,642 Ft. (MD) 4.5" TUBlNG ~ LINER - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Possible Hole / Corrosion { 29%) Jt. 219 ~ 6,810 Ft. (MD) Possible Hole / Corrosion ( 22°~) Jt. 201 (~ 6,254 Ft. (MD} Corrosion ( 21°l0) Jt. 2p7 ~ 6,439 Ft. {MD) Possible Hole! Corrosion ( 21%) Jt. 225 ~ 7,015 Ft. (MD) Une Corrosion ( 21%) Jt. 191 ~ 5,942 Ft (MDj 4.5" TUBiNG ~ LtNER - MAXIMUM RECC?RDED ID RESTRIC7iC?NS: Depasits Minimum I.D. = 3.15" Jt. 253.2 ~ 7,922 Ft. (MD) Deposits Minimum I.D. = 3.57" Jt. 210 ~ 6,540 Ft. (MD) Deposits Minimum I.D. = 3.58" Jt. 215 ~ 6,699 ~'t. {MD) Deposits Minimum I.D. = 3.66° Jt. 211 @ 6,569 Ft. (MD) Deposits Minimum I.D. = 3.s8" Jt. 206 '(r'cD 6,421 Ft. ~MD) Field Engineer: D. Cain Analyst: HY. Yang Witness_ C.Kennedy ~~~ ~ ProACCive Diagnostic Services, Tnc. / P.Q Box 13~9, Stafford,, TX 7?497 Phone: (281~ or (888) 565-90SS F~x: {281) 565-1369 E-mail: PDS~;a~memorylog.com Prudhoe Bay Field OfFice Phone: (907) 659-2307 Fax: (907} 659-2314 ' ~..L ~ ~ ~` ~~ ` ~~ V ~ ~ . Correlation of Recorded Damage to Borehole Profile , Pipe 1 4.5 in (26.9' - 7922J') Well: 1 D-14 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: October 3, 20b9 ^ A pprox. Tool De viaUon ^ A pprox. Borehol e Profil e 1 29 25 " 809 50 ~ 1580 75 2353 10U ~~ 3125 --, ~ p :- ~ -a ~ ~ 125 3895 .c Z .,~ c ~ Q- ~ o ~ 15(~ ~~ ~~, M 4664 175 ` 5436 2(1O ~ ~ _ - 6211 225 ~- ~ 6989 GLM 1 ~'~~ 7765 254 7923 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 254 • ~ PDS Report Overview ~ 5,.. Body Region Analysis Wel~: 1 D-14 Survey Date: October 3, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal sr HY. Yan Tubing: Nom.OD Weight Grade & Thread NornJD Norri. Upset Upper len. Lower len. 4.5 ins 12.6 f L-80 IBT 3.958 ins 4.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~~ metal loss body 150 100 ~ 50 ~ 0 to 7 to 10 to 'LO to 40 to over 1% 10% 20% 40 % 85% fl5% Number of 'oints anal sed total = 262 pene. 2 48 15 22 105 70 loss 50 1 Z 5 82 5 0 0 Damage Configuration ( body ) 80 60 ~ ~10 ' 20 0 isotatcd y,cncral linc nng hole~poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 211 63 26 50 0 72 Damage Profile (% wall) ~ penetration body ~,~~ metal loss body 0 50 100 n GLM 1 Bottorn of Survey = 254 Analysis Overview page 2 ~ ~ _~~ Minimum Diameter Profile Well: 1D-14 Survey Date: October 3, 2009 Field: Kuparuk Tool: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 3.958 inches 1.69 0.1 5 12 163 23 30 37 44 51 58 65 72 79 86 93 100 107 y 114 .a ~ 127 ~ Z 128 ~ 135 ~ 142 149 156 163 170 777 184 791 198 205 212 279 226 233 240 247 2 52 Minimum Measured Diameters (In.) 2.19 2.69 3.19 3.69 ~ ~ PDS REPORT JOINT TABULATION SHEEf Pipe: 4.5 in 12.6 ppf L-80 IBT Well: 1 D-14 Body Wail: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 3, 2009 Joint No. Jt. Depth (Ft.) I'~~n. U~~,~~i !In._1 Pen. Body Qns.) I'en. % ~tc~t,~l I c~~s "~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 27 ~.~ 0.01 i 1 3.94 PUP 1 2 !i 0. 1 6 > 3.89 1. 60 U .01 G ~ ~ 3.95 P P 1. 70 i) 0.02 6 I 3.9 PUP 2 79 (~ A ~t 1 392 3 10 ~) .00 1 1 3.94 4 141 t~ 0.03 1 U ~ 3.96 5 173 U ~.01 ? I 3.93 204 ~~ 0.0 ~ I 3 93 7 235 ~? 0.01 2 1 3.94 8 266 u 0.01 2 I 3.93 9 97 ~l 0.01 3 1 3.93 10 328 ~~ 0.01 2 I 3.93 1 359 ~~ OA t3 ~ 3.95 1 391 (~ 0.01 2 ? 3.93 13 42 ~~ 0.01 2 I 3.94 14 453 (~ 0.01 Z I 3.95 1 484 U 0.02 f3 -l 3. 6 16 51 S U 0.03 10 -~ 3.92 16.1 47 ~) 0.01 2 1 3.96 PUP 16.2 553 t~ 0 0 0 3.81 Camco DB Ni le 16.3 555 ~> 0.00 1 U 3.95 PUP 17 560 ~~ 0.01 ~ 1 3.94 18 591 ~~ 0.02 ~) -~ 3.96 19 622 ~ ~ 0.0 1 u i '.94 20 653 ~~ 0.01 ~~ I 3.86 21 684 ~~ 0.03 i t) -k 3.93 22 716 u 0.01 ~ 1 3.93 23 747 i 1 0.01 4 1 3.95 24 778 ~ 1 0.03 1O 2 3.95 5 ~~ D.O1 2 1 3.94 26 840 ~? 0.01 ? 1 3.94 27 871 u 0.03 I u ~_' 3.95 28 903 c~ 0.01 4 3.97 29 934 U 0.01 3 3.90 30 965 ~~ 0.01 3 ,' 3.91 31 994 ~~ 0.02 ~) 4 3.92 32 1024 u 0.01 Z 1 3.93 1055 t~ 0.01 i 1 3.95 34 1086 ~~ 0.07 Z ~ > 3.91 Isolated ittin . 35 1116 u 0.03 13 1 3.94 I olate itti . 36 1147 t~ 0.01 2 1 3.94 37 1178 (~ 0.04 15 ~a .9a solat d ittin . 38 1209 n 0.03 I t 1 3.94 Isolated ittin . 39 1240 ~1 0.01 2 1 3.94 40 1271 ~t OA :.' 1 3.94 41 1302 ~~ 0.04 15 1 3.95 Isolated ittin . 42 1333 ~ 1 0.01 2 1 3.94 43 1364 U 0.05 1~) 3 3. 8 I lat d itbn . 44 1394 ~ 1 0.01 4 I 3.93 ~ Penetra6on Body Metal Loss Body Page 1 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-Sp IBT Well: 1 D-14 Body Wall: 0.271 in Field: Kuparuk Upset Wail: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 3, 2009 Joint No. Jt. Depth (Ft.) I'~~n. l 1E~~~~i (In~.) Pen. Body (Ins.) I'en. %, 1~I~~t,~l I oss `ii> Min. I.D. (Ins.) Comments Damage Pr~file (%wall) 0 50 100 45 1425 ~~ 0.03 1 I I 3.92 46 1456 t~ 0.01 2 ' 3.92 47 1487 ~~ 0.05 17 4 3.94 Isolated ittin . 48 1518 ~ 1 0.02 ~~ ? 3 92 49 1549 ~! 0.01 d -1 3.86 50 1580 ~? 0.05 lt~ 7 3.88 I lated ittin S1 1611 u 0.04 I t 1 3.93 Isolated ittin . 52 1643 ~~ 0.01 ? 1 3.93 Pi ttin . 53 1674 (1 0.0 19 ~ 393 Isolated ittin . 54 1705 U O.Ol ~ I 3.93 55 1736 t~ 0.06 Z i _' 3.93 Isolated ittin . 56 7767 ~~ 0.10 ~~~ a .9'l Isolate ittin . 57 1798 ~~ 0.09 ~ I i 3.87 Isol ted it'n . 58 1829 i~ 0.06 ~ I I . 3 Isolated ittin . 59 1860 i~ 0.09 3.8 Isolated ittin . 60 1891 ~~ 0.03 1~) ' 3.92 61 1922 u 0.06 Z I 1 3.93 Isolated ittin . 62 1953 1~ 0.06 Z ~ ~ 3.88 Isolated ittin . 63 1983 (1 0.05 I i 1 3.92 Isolated ittin . 64 2015 ~1 0.07 17 1 3.93 Isolated ittin . 65 2045 U 0.1 -i ~ ~ 3.92 Iso~ated ittin . 66 2076 ~~ 0.04 I ~i 1 3.92 Isolated ittin . 67 2107 l~ 0.02 t~ 1 3.91 68 2136 U 0.05 1 Ei I 3.94 Isolated ittin . 69 2167 ~~ 0.06 1 ' 3.90 Isolated ittin . 70 2198 U 0.06 Zt) I 3.87 Isolated ittin . 71 2229 ~1 0.06 2:; 1 3.93 Isolated ittin . 72 2260 O 0.11 4O 1 3.87 I~ne of its. 73 291 l~ 0.08 3U I 3.87 Isolated itti 74 2322 ll 0.04 1 E, _' 3.93 Isolated ittin . 75 2353 tl 0.07 ~'4 1 3.94 Isolated ittin . 76 2384 U 0.10 35 ~' 3.94 Isolated itbn . 77 2415 t) 0.10 ~3~ ~i 3.93 Line of its. 78 2445 t).U~~ 0.10 ~t3 Z 3.92 Line of its. 79 2476 U 0.14 ~i3 -1 3.93 Line of its. 80 2507 ~) 0.11 ~i~) ~~ 3.93 Is lated ittin . 81 2 38 u 0.09 i4 I 3.94 Isolated iitin . 82 2569 u 0.10 tt3 I 3.93 Isolated ittin . 83 260 U 0.12 a"~ ? 3.94 Isolated ittin . 84 2631 ~~ 0.11 4U 9 3.93 Line of its. 85 2662 t~ 0.14 51 S 3. 4 Li of its. 86 2692 U.U7 0.11 ~1 ! 3.92 Line of its. 87 2723 U.(~8 0.13 49 3.93 Line of iYs. 88 2754 U 0.18 G6 5 3.89 Line of its. 89 2785 U 0.17 6<' s 3. 2 Line of its. 90 2817 O 0.09 35 3.94 Isolated ittin . 91 2~348 U 0.14 5' -l 3.93 Line of its. 92 2879 U 0.15 5b ~ 3.94 Line of its. 93 910 ~~ 0.14 5~ Z 3.95 Line of its. 94 2941 ~ 1 0.17 (, 3 -'I 3.8~~ Line of its. _ Penetration Body Metal Loss Body Page 2 • ~ PDS REPORT JOINT TABULATION SHEEf Pipe: 4.5 in 12.6 ppf L-80 IBT Well: 1 D-14 Body Wail: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 3, 2009 )oint No. Jt. Depth (Ft.) I'~~n. tJE~tc~l (In~.) Pen. Body (Ins.) I'en. % ~tc~t~~l Io~S ,~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 9 2972 (~ 0.18 66 5 3.92 Line of its. 9 3003 ~~ 0.18 66 i 3. 3 in of its. 97 30 4 t~ .1 55 -~ 3.89 i e of i. 8 062 t~ 0. 1 - 1 .89 Line of its ?~ 99 30 5 U.~)~ O.V b~1 -I 3.94 Line of its. 1 0 3 25 (~. t~' 0. 7 (~2 > .91 C rrosion. 101 3156 ~~.~~~~ 0.18 ~,5 1 3.94 Line of its. - 102 3188 U 0.1 -3i 3.93 Line o it . 103 3219 U ,16 bl) -3 3.93 Line f" 104 3250 ~~ 0.22 t3 i 5 3.94 Line of its. 105 3 81 n 0.24 t3£~ ~~ 3.95 Possible Hole. 106 3 1' ~~.~> i 0. " ti~, ~~ 3.93 Possible Hole. 107 3343 ~~.Ut> .21 3.89 Corrosion. - 1 8 3 74 ~~ 0.17 ~~ 1 ~ 3.93 Li f its. - 109 3405 U 0.17 63 -3 3.90 Line f its. - 110 3437 l).IC~ 0.21 ~Ef 7 3.93 Linecorr si n. 111 3467 0.1 _S 0. t~t~ ~~ . 3 Line rrosion. 112 3498 l~ 0.20 i 4 t3 3.93 Li e rrosion. 113 3529 U O.ZO i 4 I ll 3.91 Line corrosion 114 3559 ! LUts 0.19 t,~) b .94 Line corrosion. 115 3590 t~ 0.17 t~; 4 3.95 Line of its. 116 3621 t~ 0. 0 ~ 5 -1 394 L'ne of its. 117 36 2 ~~ 0.19 ~t) ~i 3. 3 Line of i. 118 3682 t1.~~ti 0.17 ~>Z 5 3.90 Line corrosion. - 119 " 71 ~_? .19 ~ I 5 3. 9 Li e rrosi 120 3744 U.u~) 0.25 ~)~' 13 3.94 Possible Hole. 121 377 t).(1 i 0.24 F3~t ~1 3 93 Possible Hol . 122 3805 (~.~~tS 0.21 78 t3 3.91 Corrosion. 123 3834 ~~ 0.21 '7 ti ine corros'on. 124 3865 u 0.20 -~ -~ 3.94 Line of its. 1 5 389 U.1 I 0.2 ts_~ - .93 Co rosion. i26 3927 ~? 0.22 7~> ~~ 3.93 Line corrosion. 127 3957 ~~.I: .22 f~l ri 3.88 in corrosion. 128 3988 U 0.25 93 (, 3.93 Possible Hole. ' 129 4019 l~.l~~i 0.22 £i2 Il) 3.9 Corrosion. 130 4D48 U 0.24 E37 ~ 3.91 Possible Hole. 131 4080 U.15 .23 t34 ~) 3.87 Line corrosio . 132 4110 ~a.~~~, 0.25 '~ ~ ~~ 3.94 Possible Hole. ~ 133 4141 ~1.U i 0. 3 t~_~ I~) 3.9 Corro ion. 134 4171 ~~.~~; 0.28 lUt1 I s 3.91 Hole ! Possible Multi le Holes. Line corrosion. 13 4202 ~~ t35 b 3.93 Line corrosion. 136 4233 U.Uf~ 0.25 94 b 3.92 Possible Hole. 137 4264 U.1 1 . 4 £37 ~ 3.91 Po sible Hole. 138 4295 U.t~S 0.25 91 ~) 3.86 Possible Hole. ~ 139 4326 t~.~~t3 0.24 89 E3 3.91 Possible Hol . 140 4357 l) 0.23 86 IO 3.91 Possible Hole. 141 4386 l~.Ufi 0.23 E33 I_' 3.89 Corrosion. 142 4417 ~~ 0.22 t31 t~ 3.95 Line corrosion. 14 4448 ~~!!~ 0.23 fs5 3.94 Corrosion. 144 4479 0.21 3.86 Line corrosion. Nenetration Body ~ Metal Loss Body Page 3 • ~ PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 IBT Well: 1 D-14 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 3, 2009 Joint No. Jt. Depth (Ft) I'~~n. lJEnc~t (Ins.) Pen. Body Qns.) Pr~n. °/, ~Ic~t,il loss `;~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 145 4510 ~). I~ 0.22 ~iZ tt 3.9 Line corrosion. 146 4540 u 0.22 S i I i 3.90 Line corrosio . 147 4571 ~) 0.22 t~Z -1 3.94 Line corrosion. 148 4603 ~~~~~ 0.21 7' ~ I~ 3.94 Line corrosion. 149 4634 i~ 0.21 ~ ti - 3.89 Line corrosion. 150 4664 ~~.i~ ~ 0.23 ~i~> ~ 3.94 Possible Hole. 151 4696 t~ 0.22 ti 1 I ~ ~ 3.94 Line corrosion. 152 4726 t~ 0.22 ~3:i ~> 3.94 Corrosion. 153 475 ~~ 0.22 f~l 1~~ 3.86 Corrosion. 154 4787 ll.l~~ 0.24 9U ~i 3.95 Possible Hole. 155 4818 (~ 0.24 89 i' 3.95 Possible Hole. 156 4849 O.Uti 0.22 t31 ~ 3.95 Line corrosion. 157 880 l) Q25 ~?2 1 t 1 3.94 Possible Hole. 158 4911 (~ 0.23 f;4 i 3. 2 Line corrosion. 159 4940 l~ 0.23 t36 '~? 3.94 Possible Holc. 160 4971 ~ L 1:r 0.26 ~)4 15 3.87 Possible Hole. 161 5002 U. I I 0.26 ~?(~ tt 3.93 Probab~e Hole. 162 5032 U 0.25 9 ~~ 3.91 Possible Hole. 163 5064 O.1 t a 0.27 1 Ul) I_' 3.92 Hole ! Line cor sion. 164 5095 U.Uf9 0.22 82 1l~ 3.91 Line corrosion. Lt. De its. 165 5126 U.Oti 0.20 ; 5 13 3.77 Line corrosion. Lt. De sits. 166 5156 U 0.21 76 I I 3.79 Linc corrosion. Lt. De sits. 167 5187 (~.l 1 0.24 ti8 1-1 3.87 Possible Hole. 168 5218 1~.1 1 0.24 ~)t) 1 1 3.77 Possible Hole. 169 5250 O.I i 0 3 4 1 1 3. 9 in rosion. osits. 170 5280 tL115 0.23 85 I Z 3.90 Line corrosion. Lt. De sits. 171 531 1 U.U9 0.26 ~)5 I? 3.87 Ho e! 172 5342 ~~.t)H 0.24 ft7 i s 3.85 Possible Hole. 173 5374 t~.14 0.24 ti7 ; is 3.82 Possible Hole. 174 5405 U.1 i 0.26 ~~5 I I 3.80 fiole! 175 5436 ~~. I~' 0.23 tS-1 I-~ 3.81 Line c rrosion. Lt. e osit~. 176 5467 l~. I i 0.23 ti~l I!~ 3.91 Line corrosion. Lt. De sits. ` 177 5498 i~. I~ U.21 ~~7 „ 3.82 Line corrosion. LL De osits. 178 5529 U 0.21 ~ 7 I u 3.87 Line corrosion. Lt. De sits. 179 5561 tl.Uti 0.22 £32 15 3.77 Corrosion. De sits. ' 180 5591 U.t~Yf 0.21 7; l i 3.80 Line corrosion. Lt. De sits. 181 5623 u.~' t 0.21 ~ 7 f-~ 3J5 Line corrosion. Lt. De sits. 182 5654 u 0.22 f3U I ts 3.89 Corrosion. Lt. De osits. 183 5686 U.12 0.22 t~1 Iu 3.89 Line corrosion. Lt. De sits. 184 5717 ~~. I I 0.24 t3; !~. ~ 3.92 Possiblc Hole. 185 5748 i~. I~ 0.21 7i, I ts 3.80 Line corrosion. Lt. De sits. 186 5778 U.1U 0.24 '~t) I-k 3.88 Possible Hole. 187 5808 ~1.IU 0.23 FS6 I~t 3.80 ossibleHole. 188 5840 U.U_; 0.25 ~JZ I> 3.80 Possible Hole. 189 5871 U. I I 0.24 ~~(1 I-1 3.6 Possible Hole. 190 5903 (~. I? 0.21 7~) I ts 3.86 Corrosion. Lt. De osits. 191 5934 1~.1 ~ .20 75 ' I 3.f31 Linc corrosion. Lt. De osi . 192 5965 l~.UtS 0.23 <> ; ~-1 3.87 Corrosion. Lt De osiYs. 19 5996 U.Ut3 is3 17 3.84 Cor osi n Lt De osits. 194 6027 O 0.23 ti i I' 3.80 Possible Hole. ''' ~7~ ` "' ~~"~ Penetration Body ~ Meta) Loss Body Page 4 ~ • PDS REPORT JOINT TABULATION SHEEf Pipe: 4.5 in 12.6 ppf L-80 16T Well: 1 D-14 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Cornpany: ConocoPhillips Alaska, lnc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 3, 2009 Joint No. Jt Depth (R.) I'~~n. Il~~s~~i {Ins_~ Pen. Body (Ins.) I'e~n. %, Nl~~t,il Ivss °4~ Min. I,D. (Ins.) Comments Damage Profite (%wall) 0 50 100 195 6058 t).1 3 0.23 Yib 1 t> 3.81 Possibl Hole. 196 6089 i~ 0.24 88 I t~ 3.71 Possible Hole. 197 G120 11.1 i 0.22 £3O 1 F3 3.80 Corrosion. Lt. De osits. 198 6152 i~. I' 0.24 tt~) - 3.80 Possible Hole. 199 6181 ~~. I 3 0.22 ts I I ti 3J9 Corrosion. L~ De osits. 200 6 11 U.O7 0.23 t5 3 I G 3.79 Corrosion. Lt. De osits. 201 242 ~~.~?E~ 0. 4 tS' ?_' 3J9 Possible Hole. Corrosion. 202 6274 U. I 1 Q.2U 75 I tt 3.80 Corrosion. De osits. 203 6305 O.2U 0.22 ti3 1(> 3.&1 Line corrosion. Lt. De osits. 204 6336 U.1 U 0.23 t3(> 'U 3.79 Possible Hole. 205 6368 (1.1 ~~ 0.22 tSll I~ 3J6 Line corrosion. De osits. 206 6399 U.1 ~? 0. 2 tiu I~ 3.68 Line corrosion. De osits. 207 6429 1~.1 Z 0.23 tt ~ ' I 3.81 Corrosion. Lt. De osits. 208 6460 l} 0.24 ts; I~ 3.78 Possible Hole. 209 6492 t).?i! 0.22 t5~' I ~ 3.81 Line corrosion. Lt. De osits. 210 6523 t~.1 U 0.24 ti7 1 U 3.57 Po sible Hole. De osiis. 211 6552 l).I I 0.25 ~)1 It4 3.66 Possible Hole. 212 6585 U. I~1 0.24 t~t~ I; 3.77 Possible Hole. 213 6614 U 0.27 1O0 I t, 3.80 Hole. Corrosion. 214 6646 U.11 0.26 ~)' I i~ 3.84 Probable Hole. 215 6677 1~.1 ft 0.23 ti-1 I t~; 3.58 Corrosion. De sits. 216 6708 t~. I S 0.21 ~(~ 1~ 3.83 Corrosion. Lt. De osits. 217 6739 U. I ~ 0.25 ~)<' I 1 3. Possi le Hol . 218 6770 U.15 0.23 84 I i 3J8 Line corrosion. Lt. De sits. ~ 21 680 t).15 0.24 t3i ") 3J5 Pos ible Hole Corr si n. 220 6832 U.14 0.24 tii ~~ 3.81 Possible Hole. 221 6863 U.14 0.26 ')4 I t~ 3J6 Possible Hol . De osits. 222 6895 U. I 1 0.24 tSff I(~ 3.78 Possible Hole. 23 6925 U. IU 0.30 1~~~? I% 3.89 Multi le Holes ! Corrosion. 224 6958 U.14 0.27 `1t~ I-l 3.90 Probable Hole. 225 6989 U.Ut3 0.26 ')~3 ' I 3.80 Possibl Hole. Corrosion. 226 7019 U 0.22 t~ ~ I' 3.94 Line corrosion. Lt. De sits. 227 7051 C).U~3 0.24 ~)l) I> 3.83 Po sible Hole. 228 7081 C).t)~) 0.23 t36 tf 3.85 Possible Hole. 229 717 2 u.l ~' 0.24 89 I t3 3.83 Possible Hole. 230 7144 U.l~~~ 0.24 238 f t; 3.88 Possible Hole. 231 7174 l1 0.27 I~iO I~ 3.91 Hole ! Possible Multi le Holes. Corrosion. 232 7207 ~~.I ; 0.27 77 ~> 3.90 Line c.orrosion. Lt De sits. 233 7238 l).(1t~ 0.22 ftl ~'U 3.88 Line corrosion. Lt. De osi . 234 7270 U.l)~) 0.22 t3~' I,' 3.87 Line corrosion. Lt. De ~osits. 235 7301 U.U4 0.23 t36 I I 3.92 Possible Hole. 236 7333 U.0~3 0.22 82 15 3.81 Line corrosion. Lt. De sits. 237 7363 U.1~ 0.24 ')l) Zi) 3J9 Possible Hole. 238 7393 U.U6 0.25 90 I.~ 3.86 Possible Hole. 239 7425 ~~.1;~ 0. 7 99 I fi 3.87 Probable Hole. 240 7456 l~. l I 0.26 ~)5 I is 3.86 Fiole ! 241 748£3 !~.1 i~ 0.25 ~~~' I~ 3.85 ossible Hole. 242 7518 t~.Ut3 0.24 ~)O lu 3.89 Possible Hole. 43 550 ~?. I I 0.26 ~>(> I~ 3.88 Probable Hole. 244 7580 ~?. I I 0.24 '~i ~ I~ 3.81 Possible Hole. Penetration Body ~ Metal Loss Body Page S • • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 tBT Well: 1 D-14 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: October 3, 2009 Joint No. Jt. Depth (Ft) N~~n. UE~s~~t Uns.j Pen. Body (Ins.) I'en. % ~1~~t,il lo~s °~~ Min. I.D. (Ins.) Comments 0 Damage Profile (%wall) 50 100 245 7613 U.1(~ 0.25 9~' _'U 3.85 Possible Hole. 246 7643 U.O~ 0.22 £33 I(1 3.90 Line corrosion. Lt De sits. 247 7675 ~~.~~~~ .24 8£~ 1; 3.86 o sible Hole. 248 7705 ~~ 0.24 ~~i) ~~ 3.92 N siblc Hole. 49 7736 U 0.23 2~5 I' 3.90 Possible Hol . 50 7765 l~.ll~ 0.23 tS5 ~? 3.89 Corro ion. Lt. De osits. 251 7795 U 0. 2 - 3.92 Line corrosion. Lt. De sits. 252 7828 it.t~'i 0.20 ;! ~ ~ ~ 3.69 Line corrosion. De osits. 252.1 7859 u.t~; 0.25 ~>Z - 3.93 PUP Possible Hole. 252.2 7866 ll 0 U ~i N A GLM 1 Latch ~ 830 252.3 7873 lt p.20 75 3.90 PUP Corrosion. Lt. De osits. 253 7881 ~).1 U 0. 2 80 I-! 3.80 Corrosio . Lt. De osits. 253.1 7912 l~ 0 l) ~) 3.81 OtisX Ni le 253.2 7914 U 0.17 Ei I (, 3.1 S PUP Corrosion. De o its. 254 7923 i r 0.12 44 I~ 3J6 Liner to . Line corrosion. Lt. De osits. Penetration Body Metal Loss Body Page 6 r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~+~ PDS Report Cross Sections Well: 1 D-14 5urvey Date: October 3, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of fingers: 24 Tubin : 4.5 ins 12.6 f L-80IBT_______ Analyst: HY. Yang Cross Section for Joint 223 at depth 6945.3 ft Too) speed = 43 Nominal ID = 3.958 Nominal OD = 4.500 Remaining walf area = 92 % Tool deviation = 53 ° Finger 14 Penetrafion = 0.304 ins ~ ~ Cross Sections page 1 Multiple Holes HIGH SIDE = UP ~ ~ r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~~ PDS Report Cross Sections Well: 1 D-14 Survey Date: October 3, 2009 Fieid: Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA ,\'o. of Fingers: 24 Tubing: 4.5 ins 12.6 ppf L-80 IBT Analvst: HY. Yan~ Cross Section for Joint 134 at depth 4192.58 ft Tool speed = 43 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 95 % Tooi deviation = 51 ° Finger 12 Penetra6on = 0.279 ins Hole / Possible Multiple Holes HiGH SIDE = UP • ~ Cross Sections page 2 w~ ~ r ~ ~ ~ ~ r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections ~---'~ - `-'c"~ ,. V bNell: 1D-14 Survey Date: October 3, 2009 Field; Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Coimtry: USA No. of fingers: 14 Tubing: 4.5 ins 12.6 ppf t•80 IBT Analyst; _ HY. Yang Cross Section for Joint 2?9 at depth 6809.65 ft Tooi speed = 43 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 71 % Tool deviation = 55 ° Finger 12 Penetration = 0.194 ins Corrosion 29% Crosssec6onal Wall Loss HIGH SIDE = UP ~ ~ Cross Sections page 3 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~r ~ ~ ~ ~ r ~ s ~ PDS Report Cross Sections C~~ _ ~'~ ,. Well: 1D-14 Sutvey Date: October 3, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Too~ 5ize: 1.69 Country: USA No. of Fingers: 24 Tubin : 4.5 ins 12.6 f L-80 IBT Anal st: HY. Yan '~~i Cross Section for Joint 201 at depth 6254.4 ft Tool speed = 43 ~ Nominal ID = 3.958 ~ Nominal OD = 4.500 ;~ Remaining wall area = 78 °~ ~ Tool deviaHon = 52 ° Finger 5 Penetration = 0.174 ins Corrosion 22°Jo Crosssec6onal Wai) Loss HIGH SIDE = UP • • Cross Sec6ons page 4 ~ ~ ~ i ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections ^,u _ '~~~ ~~ Well: 1D-14 Survey Date: October 3, 2009 field: Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 T~bina: 4.5 ins 12.6 ppf L-80 IBT Analvst: HY. Yang Cross Section for Joint 253.2 at depth 7921.99 ft Tool speed = 43 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 100 % Tool deviation = 53 ° finger 21 Projection = -0.808 ins Deposits Minimum I.D. = 3.15 ins. HIGH SIDE = UP • ~ Cross Sections page 5 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections C~~u ___ ~'~ , VVell: 1 D-14 5urvey Date: October 3, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin : 4.5 ins 12.6 f L•80 IBT Analvst: HY. Yan Cross Section for Joint 210 at clepth 6539.767 ft Tool speed = 44 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 96 % Tool deviation = 54 ° Finger 17 Projection = -0.394 ins Deposits Minimum I.D. = 3.57 ins. HIGH SIDE = UP • • Cross Sections page 6 TUBING ~a~s2o, 0o a ~oo, ID:3.958) SURFACE (0-4934, OD:9.625, wt:no.oo~ DUCTION ~asos~, OD:7 000, Wt:26.00) Gas Lift valve 1 (7867-7868, OD:4.500) LINER (7908-8692, OD:4.500, 1Mt:12.60) NIP (7912-7913, OD:4.500) SEAL (79247921, OD:6.500) Perf (83548370) ~ • KRU 1 D-14 1 D-14 API: 500292295000 Well T e: INJ An le TS: 51 de 8344 SSSV Type: None Orig Com letion: 10/7/1999 Angle @ TD: 50 deg ~ 8702 Annular Fluid: Last W/O: Rev Reason: TAG Reference Lo : Ref Log Date: Last Update: 10/28/2006 Last Ta : 8620' RKB TD: 8702 ftKB Last Tag Date: 10/24/2006 Max Hole An le: 54 deg @ 5707 Casin Strin - CASINGS Descri tion Size To Bottom ND Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.58 H-40 WELDED SURFACE 9.625 0 4934 4317 40.00 L-80 BTC PRODUCTION 7.000 0 8067 6233 26.00 L-80 BTC LINER 4.500 7908 8692 6629 12.60 L-80 IBT Tubin Strin - TUBING Size To Bottom ND Wt Orade Thread 4.500 0 7920 6141 12.60 L-80 IBT Pertorations Summa Interval ND Zone Status Ft SPF Date T e Comment 8350 - 8370 641~1 - 6424 C-4 20 4 ~22/199 IPERF SWS DP 180 deg. hase +/_ 90 de Gas LiR MandrelsNatves St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 7867 6108 CAMCO KGB-2-LS CAMCO DMY 1.0 DCK-3 0.000 0 0/22/199 Other lu s ui . etc. - JEWELRY De h ND T e Descri tion ID 554 554 NIP CAMCO DB ni le 3.813 7912 6136 NIP OTIS "X" ni le 3.812 7920 6141 SEAL Baker GBH 22 SEAL ASSEMBLY 4.500 RE: 1D-14 (PTD# 199-089) R~rt of Suspected TxIA Communicatiol~ Schwartz, Guy (DOA sponsored) From: Regg, James B (DOA) Sent: Wednesday, June 17, 2009 9:35 AM To: Schwartz, Guy L (DOA) Subject: FW: 1 D-14 (PTD# 199-089) Report of Suspected TxIA Communication Attachments: 1 D-14 90 day TIO plot.png Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.comJ Sent: Wednesday, June 10, 2009 4:27 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; CPF1 Prod Engr; CPF1 DS Lead Techs; Kappel, Erica J Subject: RE: iD-14 (PTD# 199-089) Report of Suspected TxIA Communication Jim, Page 1 of 2 On 06-09-09, 1 D-14 failed an MITIA. The TIO prior to the test was 1025/1880/490. The well has been SI and freeze protected. Diagnostics will be performed to identify the leak. It will be ConocoPhillips intention to repair the well if possible. The proper paperwork will be submitted at that time. Attached is a current 90 day TIO plot. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 «1 D-14 90 day TIO plot.png» From: NSK Problem Well Supv Sent: Tuesday, June 02, 2009 3:12 PM To: 'Regg, James B (DOA)'; Tom_Maunder@admin.state.ak.us' Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPFl Prod Engr; CPFl DS Lead Techs Subject: 1D-14 (PTD# 199-089) Report of Suspected TxIA Communication 6/17/2009 RE: 1D-14 (PTD# 199-089) R~rt of Suspected TxIA Communication Page 2 of 2 Jim/Tom, Kuparuk WAG injector 1 D-14 (PTD# 199-089) is suspected of having TxIA communication based upon recent frequent bleeds during conversion to water injection. The conversion to water injection has been completed and the welt will continue to inject for at least 7 days until the miscible injectant has been displaced from the near wellbore region. Diagnostics will begin as soon as it is safe to do so. CPAI will add the well to the Monthly MIT Report and will submit a 10-404 to repair or an administrative application to continue injection as appropriate. Attached is a 90 day TIO plot and wellbore schematic. « File: 1 D-14 Wellbore Schematic.pdf » « File: 1 D-14 TIO Plot.ppt » Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 6/17/2009 • • KRU 1 D-14 1 D-14 TueING - - ~ '~ _ API: 500292_2.95000 _Well T e: INJ _Ar~le~a TS: 51 d 8344 (a7s2o. ~ I SSSV Type: None Orig 10/7/1999 Angle @ TD: ! 50 deg @ 8702 ~ oD:a.SOO. ' Completion: ID:3.958) _ Annular Fluid: Last W/O: _ Rev Reason: TAG Reference'' 'Ref Lo Date: Last Update: 10/28/2006 SURFACE - LO _ _ __ ~ _ (aas3a, ~ Last Ta :8620' RKB ~ TD:' 8702 ftK6 OD:9.625. - - --- -- - Last Tag 10/24/2006 Max Hole 54 deg @ 5707 wt:ao.oo) Date: An le: Casin String -CASINGS ~ Bottom scri ption Size T De TVD _Wt Grade ~ _Thread_ _ _ _ _ 16.000 0 115 CONDUCTOR 115 62.58 H-40 WELDED _ 0 4934 I SURFACE ~ 9.625 4317 40.00 L-80 BTC _ _ _ __ - PRODUCTION 7.000 ' 0 8067 _ 6233 _26.00 _L-80 BTC LINER 4.500 7908 ' 8692 __6629 ~ 12.60 L-80 IBT Tubing String -TUBING _ Size Top Bottom ~ TVD Wt Grade Thread 4.500 0 __ 7920 ___ 6141 I 12.60 L-80 __ IBT Summer Perforation s , _ __ _ T e Comment Status Ft SPF Date Interval TVD Zone PRODUCTION - _ _ 8350 - 8370 6411 - 6424 C-4 20 4 0/22/199 IPERF SWS DP 180 deg. (aaos7. 00:7.ooo, ~ _ , ~_ - hase +/- 90 de --_ -_ wt:2s.oo) Gas Lift Mandrels/Valves Gas Liit ~ St MD TVD Man Man Type V Mfr V Type V OD I Latch Port TRO Date Vlv IandreVDummy Mfr ~ Run Cmnt valve ~ 1 7867 6108 CAMCO'KGB-2-LS CAMCO DMY 1.0 ~ 000 0 0/22/199 DCK-3 0. (76x7-7868, -- -- -- - - -- _ OD:4.500) Other (plugs, e quip., etc.) -JEWELRY __ _ __ TVD Type _Description ID D epth_ - -- - - __ _ _ 554 554 - NIP CAMCO DB nipple __ 3.813 - _ 6136 !, NIP ' OTIS "X" nipple - 7912 ' 3.812 _ 7920 6141 ' SEAL Baker GBH 22 SEAL ASSEMBLY 4.500 LINER (790&8692. OD:4.500, WC12.60) NIP (7912-7913, OD:4.500) SEAL (792x7921. OD:6.500) Perf (835x8370) • Gv~~ Robert Christensen ~/ pC~ 2 ~ 2~~~ Production Engineering Specialist. ~ ~ ~ (;;~i1~'~ a~~Y~t3~a~a:t~3' PO BoxK96105k Unit , NSK-69 ConocoPh~ I I ~ p ~!~ ~ ~~ Anchorage, AK 99519-6105 ~ ~'~ £~ Phone: (907) 659-7535 ~11G~OGi c,.~ , Fax: 659-7314 October 18, 2008 Tom Maunder, P.E. Y 0 ~q Senior Petroleum Engineer ~~~ 1 State of Alaska, Oil & Gas Conservation Commission 33 W. 7t1' Ave. Ste. 100 Anchorage, AK 99501 ''~''~~-'~~~~1' ~~ ' =- ~ ~~~~ Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has begun Gas Injection is association with the Kuparuk River Oil Pool 1D FOR Expansion. Enclosed you will find 10-404 Report of Sundry Well Operation for ConocoPhillips Alaska, Inc. for 1D-14. This report records the commencement ofwater-alternating-gas injection service. If you have any questions regarding this matter, please contact myself at 659-7535. Sincerely, ~aaR~,_nz_„ _r Robert D. Christensen Attachments RECElVEC7 ~ ~ OCT 2 1 2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIONAI3Ska O1I & G8S CII~, '~~ir'~~.! d°si,~',Sip? REPORT OF SUNDRY WELL OPERATIONS ArICS~I~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q. WINJ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ to Waiver ^ Time Extension ^ WAGIN Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConoCOPhlllips Alaska, InC. Development ^ Exploratory ^/ 199-089 - 3. Address: Stratigraphic ^ Service 0 ~D ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 0 50-029-22950-00 - 7. KB Elevation (ft): 9. Well Name and Number: RKB 105' 1 D-14 8. Property Designation: 10. Field/Pool(s): ADL 25650 ALK 468 Kuprauk River Oil Pool , 11. Present Well Condition Summary: Total Depth measured 8702' feet true vertical 6635' feet Plugs (measured) Effective Depth measured 8624 feet Junk (measured) true vertical 6585 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 115' 16" tts' 115' SURFACE 4829' 9-5/8" 4934' 4317' PRODUCTION 7962' 7" 8067' 6233' LINER 784' 4-1/2" 8692' 6629' Perforation depth: Measured depth: 8350-8370 true vertical depth: 6411-6424 Tubing (size, grade, and measured depth) 4-1/2", L-80, 7920' MD. Packers &SSSV (type & measured depth) Packer =Baker GBH 22 Seal Assembly Packer = 7920' SSSV =Nip SSSV = 554' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 4620 ~ 331 1655 Subsequent to operation 6393 20 2856 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run X Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _ 16. Well Status after proposed work: Oil^ Gas^ WAGQ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: N/A contact Bob Christensen/Vacant Printed Name o D. istense Title Production Engineering Technician ~ ~~l/ Signature - Phone: 659-7535 Date ~ O ` ~~~ PO ~l Submit Origirl"aL my 1 D-14 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/08/08 Commenced MWAG Gas Injection . . conocóPÍ1illips Alaska RECEIVED AUG 2 9 2007 Alaska Oil & Gas Cons. Commission Anchorage P.o. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 23, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 scANNED SEP 0 6 2007 ~q~-o<t1 Dear Mr. Maunder: . Enclosed please find a spreadsheet with a list of wells trom the Kuparuk field (KRU). Each of thesé wells was tôund to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water trom 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 corrosion inhibitor/sealant was pumped between August 19 & 21, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. ~¡~~~. M.J.¿el~d ConocoPhillips Well futegrity Projects Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/21/2007 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 gal 1 0-28 204-237 18" N/A N/A N/A 10 8/19/2007 1 0-30 200-104 24" N/A N/A N/A 6.5 8/19/2007 10-34 200-143 14" N/A N/A N/A 4 8/19/2007 10-12 199-084 1" N/A N/A N/A 1.7 8/20/2007 10-14 199-089 2" N/A N/A N/A 3.4 8/20/2007 10-140 200-136 29'9" 3.4 12" 12/16/2006 14.5 8/20/2007 10-141 200-112 SF N/A N/A N/A 0.5 8/20/2007 '1C-11 199-172 - SF NA NA NA 0.5 8/21/2007 1C-12 196-177 SF NA NA NA 0.5 8/21/2007 1C-15 198-229 SF NA NA NA 0.5 8/21/2007 1C-16 198-246 22" NA NA NA 8 8/21/2007 1C-17 198-224 17" NA NA NA 1.7 8/21/2007 1C-18 199-005 SF NA NA NA 0.5 8/21/2007 1C-24 201-248 20" NA NA NA 11 8/21/2007 1 C-26 199-051 3" NA NA NA 0.85 8/21/2007 1 C-27 199-043 4" NA NA NA 1.7 8/21/2007 1 C-28 205-104 SF NA NA NA 0.5 8/21/2007 1C-117 201-121 26" NA NA NA 12.3 8/21/2007 MEMORANDUM e e State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor '-:; I I\er1 7~)lú(c c DATE: Wednesday, July 12, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ID-14 KUPARUKRIVUNIT ID-14 \q~/O~~ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :r~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT ID-14 API Well Number 50-029-22950-00-00 Inspector Name: Jeff Jones Insp Num: miuJ060711180401 Permit Number: 199-089-0 Inspection Date: 7/10/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! ID-14 ¡Type Inj. i w !TVD I 6141 , IA I 700 1830 1805 I 1805 I I , I P.T. i 1990890 iTypeTest ¡ SPT i Test psi I 1535.25 lOA 580 I 700 725 I 725 , i ! , I -------J--- Interval 4YRTST PIF P /' Tubing ¡ 1025 1020 1020 I 1020 ----L Notes I bbl diesel pumped. I well house inspected; no exceptions noted. ¡ ~, L~ Wednesday, July 12,2006 Page I of I SURFACE (0-4934, 00:9.625, Wt:40.00) 'ROOUCTION (0-8067, 00:7.000, Wt:26.00) Gas Lift 3ndrel/Dum m y Valve 1 (7867-7868, 00:4500) LINER (7908-8692, 00:4.500, Wt:12.60) NIP (7912-7913, 00:4.500) SEAL (7920-7921, 00:6.500) Perf (8350-8370) ConocoPhUlips Alaska, jnc. 1 D.14 e e KRU 1 D-14 ~; .:: :: Thread WELDED BTC BTC IBT ;{ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg. '\2.Ftí.â b( Î ( Ol¡ P.I. Supervisor l [ DATE: Wednesday, June 02, 2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-14 KUPARUK RIV UNIT ID-14 (qq- ùgo FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :ßD- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT ID-14 API Well Numbe 50-029-22950-00-00 Inspector Name: Chuck Scheve Permit Number 1990890 Inspection Date: 5/30/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: 1D-14 Type Inj. p TVD 6635 IA 900 2010 1990 1980 P.T. 1990890 TypeTest SPT Test psi 1535.25 OA 500 500 500 500 Interval 4YRTST P/F P Tu bing 1800 1800 1800 1800 Notes: The pretest pressures were observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Wednesday, June 02, 2004 Page I of I DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Permit to Drill No. 1990890 Well Name/No. KUPARUK RIV UNIT 1D-14 Operator PHILLIPS ALASKA INC. APl No. 50-029-22950-00-00 MD 8702 TVD 6635 Completion Date 11/6/1999 Completion Status IWINJ Current Status IWINJ UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey No -- DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ lnterval Data Digital Digital Log Log Run OH / Dataset lype Media Format Nam,,q~~' Scale Media No Start Stop CH Received Number Comments CMT 5 FINAL 6700 8620 CH 11/30/1999 BL(C) 10/4/99UIC R' SRVY RPT 0 8702 OH 10/28/1999 SPERRY . ~J./"~ DGR/EWR4-TVD 25 FINAL 4318 6635 OH 1/11/2000 L CBL ~ ' 5 FINAL 7800 8616 CH 11/23/1999 BL(C) 10/22/99UIC ~. · GR/EWR4-MD , 25 FINAL 4946 8702 OH 1/11/2000 j DGR/CTN-TVD · 25 FINAL 6234 6635 OH 1/11/2000 ., ~,,.,-'/DGR/CTN-M D ,, 25 FI NAL 8034 8702 OH 1/11/2000 ~ O 12/16/1999 09082 ,----'4874-8648 Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL IN FORMATION Well Cored? Y/~) Daily History Received? ~/N Formation Tops Receuived? ~/N Comments: DATA SUBMITTAL COMPLIANCE REPORT Permit to Drill No. 1990890 Well Name/No. KUPARUK RIV UNIT 1D-14 2/5/2002 Operator PHILLIPS ALASKA INC. APl No. 50-029-22950-00-00 MD 8702 TVD Compliance Reviewed By: 6635 / ff Completion Date 11/6/1999 ! Completion Status 1W1NJ Current Status Date: Annular Dis vosal durin the second quarter of 2001: h(1) ~ h(2) ' h(3) ' TOtal for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date / 1C-17 33139 100 0 33239 0 33239 May 01 Jun 01 1¢-13~, lC-12~, lc-123, lc-127 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N'-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May 01 Jun 01 CD2-24 1C-27 3533 ,100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total Volumes into Annuli for which Disposal Authorization Expired during the second quarter 2001' ' Total Voiume ~ ~ Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus ~ 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 ' 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- ~ 2000 35, CD 1-32, CD 1-24, CD1-22A, CD1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only - CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CDI~NQ1 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 31, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEivED AnChorage C°rnmiSsio0 Re: Kupamk Area Annular Disposal, Second Quarter, 2001 - REVISED Dear Ms. Mahan: Please find attached the revised report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. We have revised the amount for CD2-42 because the original manifest incorrectly reported the CD2-24 annulus used for the disposal. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Annular Disposal durin the second quarter or2001' h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date , 1C-17 33139 100 0 33239 0 33239 May01 Jun01 1c-133, lC-121, 1¢-123,. ~C-~27 2N-318 2883 100 0 2983 13995 16978 . Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May 01 Jun 01 CD2.24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total Volumes into Annuli for which Disposal Authorization Expired during the second quarter 2001: ~ ' Total Voiume Start I End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume VOlume Volume Status of Annulus 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- 2000 35, CD1-32, CD1-24, CD1-22A, CD1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD 1-NQ 1 200 -o l 7 .?_ rx~ . o PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 17, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Second Quarter, 2001 Dear Ms. Mahan: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader RECEIVED PM/skad JUL 1 S 200 CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files Alaska 0il & Gas Cons. Commission Anchorage Annular Disposal durin the second quarter o r 2001' h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-17 33139 100 0 33239 0 33239 May 01 Jun 01 1C-133, 1C-121, 1C-123, 1C-127 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J~09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 16902 100 0 17002 0 17002, May 01 Ju,n 01 CD2-24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun O1 1C-127 Total Volumes into Annuli Cor which Disposal Authorization Expired during the second quarter 2001: ' Total Voiume ~ ' Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- 2000 35, CD1-32, CD1-24, CD1-22A, CD1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD 1-NQ1 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 October 13, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 2000 Dear Ms. Mahan: :<~'r~s&:~ G? ~ ¢~ t¢~.¢;.r..~. .... ,, Please find repoaed below the volumes injected into surface casing by p~rOfluct~on casing annuli during the t~rd queer of 2000, as well as total volumes injected into annuli for which injection authorization expired during the t~rd queer of 2000. Annular Injection during the third quarter of 2000: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD1-45 5036 100 0 5136 365 5501 CD1-03 33505 100 0 33605 385 33990- 1D-14 33916 100 0 34016 1487.5 35503.6 CD1-25 24860 100 0 24960 8627 33587 2N-341 13544 100 0 13644 20506 34150 2N-335 25395 100 0 25495 0 25495 2N-347 14666 100 0 14766 340 15106 1D-38 33907~ 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 340 CD1-43 285 100 0 385 0 385 o~q. o%q -Loo. oqo Ms. Wendy Mahan AOGCC Third Quarter 2000 Annular Injection Report Page Two Total Volumes into Annuli for which Injection Authorization Expired during the third quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CD1-39 31408 100 0 31508 Open, Freeze Protected 1D-12 32791 100 0 32891 Open, Freeze Protected CD 1-37 32487 100 0 32587 Open, Freeze Protected CD1-23 33886 100 0 33986 Open, Freeze Protected CD1-01 5121 100 0 5221 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files 1 O-14 ~nular injection Subject: 1D-14 annular injection Date: Fri, 22 Sep 2000 11:45:07-0900 From: "Randy L. Thomas" <RLTHOMAS~ppco.com> To: Blair Wondzell <blair_wondzell~admin.state.ak.us>, Tom_Maunder~admin.state.ak.us CC: "Sharon Allsup-Drake" <SALLSUP~ppco.com>, "Lisa Pekich" <LPEKICH~ppco.com>, "Morrison&Overstreet" <N1335~ppco.com>, "Paul Mazzolini" <PMAZZOL~ppco.com>, "R Marty Lemon" <RMLEMON~ppco.com> Please see the short note below regarding an over injection on 1D-14 annulus. To avoid any incidents such as this in the future, we are revising our current written procedures on annular injection to reflect an internal limit of 32,000 bbls instead of the stated mandated limit of 35,000 bbls. This will give us a 10% buffer to ensure any math errors or other factors do not result in exceeding the legal limit. We are also implementing a standard daily report form that is formatted to more easily catch simple things such as math errors. There are a few other minor modifications to our procedures related to better spill management. Let me know if you need any additional information regarding this incident or a more formal report of this incident. These volumes will of course be reported in the normal quarterly report that is sent to the state. (Bobby - Can you forward to the Environmental Dept on the slope ? Not sure what their email address is. Thanks.) - Forwarded by Randy L. Thomas/PPCO on 09/22/2000 11:36 AM Sharon Allsup-Drake 09/22/2000 11:10 AM To: Randy L. Thomas/PPCO@Phillips CC: Subject: 1D-14 annular injection Randy - we have exceeded the maximum allowable injection down the annulus of 1D-14. On July 30, we had-a total of 35505 bbls. We stopped injecting at that point. The error occurred on July 4 by a simple addition miscalculation and kept the erroneous total until the end of the month. Sharon 1 of 1 9/25/00 7:49 AM [Fwd: 1 D- 14 annular injection] .__ ~ Subject: [Fwd: 1D-14 annular injection] Date: Fri, 22 Sep 2000 13:00:16-0800 From: Tom Maunder <torn_maunder~admin.state.ak.us> Internal To: Cammy Oechsli <Cammy_Oechsli~admin. state.ak.us>, Daniel Seamount <dan_seamount~admin.state.ak.us>, Blair Wondzell <blair_wondzell~admin.state.ak.us>, Wendy Mahan <wendy_mahan~admin.state.ak.us> Randy Thomas called this morning and left a message for Blair regarding the exceedance. He then called me on the chance that Blair was flexing. I suggested he send the attached email. I believe Wendymay have already received some information on this subject since she told me of PPCo having gone over the 35000 bbl mark by some small amount earlier this week. Although they did exceed the volume, I think this is an example of how the system is working. They tracked their volumes and know the limit, when it was realized they exceed the limit they reported it to us. They also have revised their operational plans to work with a lower limit and increase their tracking of the volumes. Looks good to me. Tom Subject: 1D-14 annular injection Date: Fri, 22 Sep 2000 11:45:07 -0900 From: "Randy L. Thomas" <RLTHOMAS~ppco.com> To: Blair Wondzell <blair_wondzell~admin.state.ak.us>, Tom_Maunder~admin.state.ak.us CC: "Sharon Allsup-Drake" <SALLSUP~ppco.com>, "Lisa Pekich" <LPEKICH~ppco.com>, "Morrison&Overstreet" <N1335~ppco.com>, "Paul Mazzolini" <PMAZZOL~ppco.com>, "R Marty Lemon" <R_MLEMON~ppco.com> Please see the short note below regarding an over injection on 1D-14 annulus. To avoid any incidents such as this in the future, we are revising our current written procedures on annular injection to reflect an internal limit of 32,000 bbls instead of the stated mandated limit of 35,000 bbls. This will give us a 10% buffer to ensure any math errors or other factors do not result in exceeding the legal limit. We are also implementing a standard daily report form that is formatted to more easily catch simple things such as math errors. There are a few other minor modifications to our procedures related to better spill management. Let me know if you need any additional information regarding this incident or a more formal report of this incident. These volumes will of course be reported in the normal quarterly report that is sent to the state. (Bobby - Can you forward to the Environmental Dept on the slope ? Not sure what their email address is. Thanks.) Forwarded by Randy L. Thomas/PPCO on 09/22/2000 11:36 AM Sharon Allsup-Drake 09/22/2000 11:10 AM To: Randy L. Thomas/PPCO@Phillips CC: Subject: 1D-14 annular injection Randy - we have exceeded the maximum allowable injection down the annulus of 1D-14. On 1 of 2 9/25/00 7:47 AM [Fwd: iD- 14 annular injection] July 30, we had a total of 35505 bbls. We stopped injecting at that point. The error occurred on July 4 by a simple addition miscalculation and kept the erroneous total until the end of the month. Sharon Tom Maunder <tom maunder~admin, state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 9/25/00 7:47 AM PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 25, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Second Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the second quarter of 2000, as well as total-volumes injected into annuli for which injection authorization expired during the second quarter of 2000. /9' Annular In/ection during the second quarter of 2000: h(1)' h(2)' h(3) Totai for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-341 20406 100 0 20506 0 20506 2L-313 4640 100 0 4740 12533 17273 CD1-40 108 100 0 208 32669 32877 CD1-23 16751 100 0 16851 17135 33986 CDI-16 25 0 0 25 29025 29050 CD1-32 82 100 0 182 33331 33513 CD1-38 11056 100 0 11156 9164 20320 CD1-27 32333 100 0 32433 381 32814 1L-28 5853 100 0 5953 3984 9937 ~' 1D-11 135 100 0 235 0 235 1D-14 1337.6 100 0 1437.6 0 1437.6 CD1-25 8141 100 0 8241 386 8627 CD1-34 278 100 0 378 0 378 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ He-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X Annular Injection 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 209' FSL, 595' FEL, Sec. 14, T11N, R10E, UM At top of productive interval 1227' FNL, 2616' FWL, Sec. 14, T11N, R10E, UM At effective depth At total depth 980' FNL, 2492' FWL, Sec. 14, T11N, R10E, UM 5. Type of Well: Development__ Exploratory __ Stratigraphic __ Service __X 6. Datum elevation (DF or KB feet) RKB 35' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1D-14 9. Permit number/approval number 99-89 10. APl number 50-029-22950 11. Field / Pool Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total depth: measu red 8702 true vertical 6635 Effective depth: measured 8624 true vertical 6585 Casing Length Size Conductor 80' 16" Surfaco 4904' 9.625" Production 8033' 7" Liner 8657' 4.5" feet Plugs (measured) feet feet Junk (measured) feet Cemented 8 cu yds High Early 608 sx Class G, 640 sx Class G 225 sx Class G 145 sx Class G Measured Depth True vertical Depth 115' 115' 4939' 4321' 8068' 6234' 8692' 6629' Perforation depth: measured 8350'-8370' true vertical 6411 '-6424' Tubing (size, grade, and measured depth 4.5", 12.6#, L-80 @ 7936' Packers & SSSV (type & measured depth) Baker ZXP LT packer @ 7935' 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 __ X 14. Estimated date for commencing operation March 31,2000 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,.,-_, Title: Drilling Engineering Supervisor G. C. A~ord FOR COMMISSION USE ONLY Questions? Call Chip Alvord 265-6120 Date Prepared b,V Sharon AIIsup-Drake Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance__ Mechanical Integrity Test__ Subsequent form required 1~ ORIGINAL SIGNED BY O°¥'~ Approved by order of the Commi~ion Robe~ N. Chdstenson ~¢x >~ ~missioner Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company Casing Detail 7" 26# Casing WELL: DATE: 1 OF 06/01/99 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool 6 RT to LDS = 30.93' TOPS 7" Landing Joint (RKB) 30.93 7" FMC GEN V FLUTED MANDREL HANGER 2.20 30.93 jts3-198 7", 26#, L-80 BTC-MOD (200jts) 7946.23 33.13 Gemeco Float Collar 1.30 7979.36 jts 1-2 7", 26#, L-80 BTC-MOD (2jts) 85.74 7980.66 Gemeco Float Shoe 1.47 8066.40 BTM OF SHOE @ 8067.87 Shoe @ 8068' 8067.87 TD of 8-1/2" hole = 8077'MD 18 Gemeco Bow Spring CENTRALIZERS on jts 3-20 p - CI'IVED ~.'-. · - & Gas Cons. Comm~', ,s~or Remarks: String Weights with Blocks: 300k Up, 150k Dn, 70k Blocks, Ran 200joints of casing. Drifted casing with 6. 151" plastic rabbit. Used Best-o-Life 2000 thread compound on all connections. Pool 6 Drilling Supervisor: ARCO Alaska, Inc. Cementing Details Well Name: 1D-14 Repod Date: 10J01/99 Report Number: 10 Riq Name: Pool 6 AFC No.: AK0030 Field: KRU Casing Size7. H°le Diameter: I Anglethru KRU: I Sh°e Depth:8-1/2" 52 8067 MD LCDepth: I °/°wash°ut:79?9' MD Centralizers State type used, intervals covered and spacing Comments: 2 ridgid cents on middle Jt I &2,18 bow type on csg collars Jt 4-20 Mud Weight: PV(pdor cond): PV(after cond): YP(pdor cond): YP(after cond): Comments: 9.3 18 15 17 15 Gels before: Gels after. Total Volume Circulated: 8~11 6/8 600bbl Wash 1 Type: Volume: Weight: Comments: ARCO 20 8.4ppg Spacer 2 Type: Volume: Weight: Comments: ARCO Spacer 40 12.0 ppg Lead Cement 3 Type: I Mix wtr temp: No. of Sacks: Weight: Yield: Comments: G I 80 F 225 15.8 ppg 1.16 Additives: 0.1% DS00, 0.2% D46, 0.3% D65 Tail Cement 0 Type: I Mix wtr temp: I No. of Sacks: Weight: Yield: Comments: Additives: Displacement 4 Rate(before tail at shoe): Rate(tail around shoe): Slr. Wt. Up: Comments: 6 bpm 6 bpm 240 Reciprocation length: Reciprocation speed: Str. Wt. Down: 10' 2-6 fpm 170 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 3380 3377 Calculated top of cement: CP: Bumped plug: Floats held: 7077'MD Date:l 0/1/99 Y Y Time:IS:20 Remarks:Hole in good shape reciprecated pipe until 3200 stks, Full rtns throughout Cement Company: Rig Contractor: Approved By: Dowell POOL M. Winfree RECEIVED MAR 2 8 2000 Alaska 0il & Gas Ijul~s. uu~l'~m~ssmr Anchorage ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company Casing Detail 9.625" 40# Casing WELL: 1 D- 14 DATE: 09/26/99 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool 6 RT to LDS = 34.60' TOPS 9.625" Landing Joint 34.60 9.625" FMC GEN V FLUTED MANDREL HANGER 1.35 34.60 jts 3-127 9.625", 40#, L-80 BTC (125 jts) 4822.74 35.95 Gemeco Float Collar 1.54 4858.69 its 1-2 9.625", 40#, L-80 BTC (2jts) 77.50 4860.23 Gemeco Float Shoe 1.73 4937.73 BTM OF SHOE @ 4939.46 T.D. @ 4946' leaving 7' of rathole 25 Gemeco Bow Spring CENTRALIZERS I\/ u,m 2 8 20()0 Alaska 0il & Gas C~I~. hnrhnr~aR ARCO Alaska, Inc. Cementing Details Well Name: 1D-14 Report Date: 09/26/99 Report Number: 1 Rig Name: Pool 6 AFC No.: AK0030 Field: KRU i i Casing Size Hole Diameter: I Angle thru KRU: Shoe Depth: I LC Depth: % washout: 9.625" 12.25"I N/A 4939' MDI 4859'; Centralizers State type used, intervals covered and spacing Comments: - 25 GEMECO BOW SPRING CENTRALIZES. RUN ON STOP COLLARS JTS 1,2, & 3; ON COLLARS JTS 4 THRU 25. Mud Weight: PV(pdor cond): PV(after cond): I YP(pdor cond): YP(after cond): Comments: 10.0 50 31I 68 28 ._ Gels before: Gels after: Total Volume Circulated: 25/55 12/15 1440 BBLS Wash 0 Type: Volume: Weight: Comments: ARCO B47 20 BBLS 8.33 PPG Spacer 0 Type: Volume: Weight: Comments: ARCO B45 50 BBLS 10.5 PPG Lead Cement 0 Type: I Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: GI 70 DEC F 608I 10.7 PPG 4.43 Additives: 30°/. D053, .6%D046, 1.5% D079, 1.5% S001, 50% D124, 9% D044. TailCement O Type: I Mixwtrtemp: ' No. ofSacks: ' Weight: Yield: Comments: GI I 170 DEC F 640 15.8 PPG 1.17 Additives: .2% D046, .3% D065, 1% S001. Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 6 BPM 6 BPM 260k Reciprocation length: Reciprocation speed: Str. Wi. Down: 10' 10 FPM 160k Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 348 BBLS 352 BBLS Calculated top of cement: CP: Bumped plug: Floats held: SURFACE Date:9-26-99 YES YES Time:21:56 HRS Remarks:Displaced w/rig pumps bumped plug & pressured up to 500 psi over (2100 psi) & held f/5 min. Floats held. Landed casing 76 bbls into rig displacement. Full returns for entire cement job. Cement to surface @ 2900 stks (245 bbls) into rig displacement. Estimate 108 bbls of cement returns. Cement Company: DS Rig Contractor: POOL Approved By: S.D. REYNOLDS RECEIVED MAR 2 8 2000 Ara:borage ~E:EtE~E~E,E,E,E,[,E 0 CASING TEST and FORMATION INTEGRITY TEST Well Name: 1D-14 Date: 3/22/00 Supervisor: Overstreet~A/infree Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8", 40#, BTC Casing Setting Depth: 4,943' TMD Hole Depth: 4,966' TMD 4,321' TVD 4,337' TVD Mud Weight: 6.9 ppg Length of Open Hole Section: 23' EMW = Leak-off Press. + Mud Weight 0.052 x TVD : 1,450 psi + 6.9 ppg 0.052 x 4,337' EMW for open hole section = 13;3 Ppg Pump output = 0.1000 bps Fluid Pumped = 3.3 bbl 1.7oo Ps STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE .................... .0..s_t.k. ~ ... L _ ..°..?A' ..... .................... .................... -5__s__tk_s___L_?__s_o..p..s_L_ .................... ................... ! _o_.s..t.k..s_ i_. 1,_~_o__o.._p__~!. ................... ..................... ..................... !~..s..t.k..s...,.. 1,..4.0..0..~ .si. ~ ..................... _2._0..s_.t.k._s_ _,__ 1,_.3.-5.o__p__S_L ..................... _2A _s_t_k__s_ _ ,__ !,__3_-5_o__P_sj__j , 25 stks 1,350 psi j ................................................. 28 stks 1,350 pm .................... ~__0__s._t_k__s___.__ 1.A-5_o___P_.~L CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE 0 stks i 0 psi ................... ~..s!.k~_.i_ _!.2.~..P..s! .................. ! _o___s!k__s___ L_~_o_P__ _p~_~ .... .................. .- ............... . 30 stks j 1,550 psis. ~ i 35stks ~ 1,850p~ .................... _4_ -5__?!k_%.J.. & .4.-5.0_.~ .~.L J .................... _-5 _o___s_t_k_% j _.2. ,..7.-5.0.. p_.s_L j 54 stk$ 3,050 ps~ , 33 stks 1,350 psi : SHUT IN TIME SHUT tN PRESSURE ___!:o_.m. Ln_ .................... Z,~.2~.~.sj.. ._~:92EE ...................... 4.0 mJn .... ~:9_~!E ..................... SHUT IN TIME SHUT IN PRESSURE ...9:.o..?j.n..._ i 3,050 psi l 1.0 min i 3,050 psi 2.0 min i 3,050 ps~ , 3.0 min ~ .3.,.9..5.0- ~ 4.0 min j 3,050~. ____6:_0___m__i_n_ .................. j _ _ .3. ,~9.-5~;.p_ .s.i~.- 7.0 min j 3 050 psi 8~0 .._9:.°..L~J!~. ................... L..1.~z.O..~.IE..L ............... , 15.0mm , , 3050ps~ 8.0min : 1,075psi J i 20.0min J 3,050psi J 90mn 1075ps 250mn 3050Ds , 10.0mln , , 1,075ps~ , 30.0m~n , , 3~050psl , NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY WELL LOG TRANSMITTAL To: State of Alaska January 11, 2000 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1D-14, AK-MM-90158 The technical data listed below- is being submitted herewith. Please address any problems or concerns to the attention oL Jim Galvin, Sperry-Sun Drilling Ser¢ices, 5631 Silverado Way, #G, Anchorage, AK 99518 11)-14: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22950-00 2"x 5" TVD._Re~vity & Gamma~-~: 50-'029-22950-00 2"x 5"MD Neutron & Density Logs: 50-029-22950-00 2" x 5" TVD Neutron & Density Logs: 50-029-22950-00 1 Blueline 1 Folded Sepia _l_Bhmline 1 Folded Sepia . l_Blueline 1 Folded Sepia 1 Folded Sepia '-'RECEIV,.E ? 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 A Halliburton Company To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs December 16, 1999 1D-14, AK-MM-90158 1 LDWG formatted Disc with verification listing. APl#: 50-029-22950-00 PLEASE ACKNO~GE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF ~ TRANSMITYAL LETrER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jan Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Date: -.? ] 6 1999 ~aOil&GasCons,~ 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company 11 / 18~99 Schlumberger NO. 12948 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1D-12 PERFORATION RECORD & SBHP 991105 I 1 2F-16 L,Lt ~ INJECTION PROFILE 991108 I 1 2M-15 PRODUCTION PROFILE 991110 I 1 2M-21 PRODUCTION PROFILE 991109 I 1 2N-345 PRODUCTION PROFILE W/PSP 991104 I 1 2N-345 DEFT W/PSP 991104 I 1 1O-~ /~-~ L~l¢.-. 99404 SCMT 991004 I I 1 ~._~~_~~.~~~.~/ I~I~V ~0 3999 ~t~a 0il & Gas Cons. C0[amis~t0~i Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Schlumberger NO. 12916 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1G-10A STIM-STICK RECORD 991024 I 1 2C-02 txl ¢.. INJECTION PROFILE 991028 I 1 2C-06 } INJECTION PROFILE 991029 I 1 2C-08J" INJECTION PROFILE 991030 I 1 1D-11 99413 USIT 991023 1 1D-14 ~C_. 99411 CBL 991022 I SIGN DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to ~ncl~orage 11/10/99 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 10, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-14 (Permit No. 99-89) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on 1D-14. If there are any questions, please call 265-6120. Sincerely, G. C. Alvord Drilling Engineering Supervisor AAI Drilling GCA/skad ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r-] Gas Fl Suspended Fl Abandoned BI Service ]"~ Injector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 99-89 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-22950 4. Location of well at surface ~ : I ~' 9. Unit or Lease Name 209' FSL, 595' FEL, Sec. 14, T11N, R10E, UM~ ? '~''''': '~"- ~ ,, rr'" --"'%,..'"' Kuparuk River Unit At Top Producing Intervalii? ._//~, "~'/¢.~ ._ ~...*, - -,t~t,,,~,_,_ I, .. :,---~,... 10. Well Number 1227' FNL, 2616' FWL, Sec. 14, T11N, R10E, UM ~ '- i 1D-14 At Total Depth !i ~,,,2:. -'.¢'-v/-'~'~--''' -- ..._-" . 1~.~..~ ;! 11. Field and Pool 980' FNL, 2492' FWL, Sec. 14, T11 N, R10E, UM ; ........... - .......... ~- Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 35 feetI ADL 25650 ALK 468 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions September 21, 1999 October 2, 1999 October 6, 1999I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost MD/6585'TVD YES [~] No BII N/A feetMD 1811' 87O2' MD / 6635' TVD 8624' 22. Type Electric or Other Logs Run GR/Res, CCL, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP BO-II-OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 115' 24" 8 cu yds High Early 9.625" 40# L-80 Surface 4939' 12.25" 608 sx Class G, 640 sx Class G 7" 26# L-80 Surface 8068' 8.5" 225 sx Class G 4.5" 12.6# L-80 7908' 8692' 6.125" 145 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 7936' 7935' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8350'-8370' MD 6411'-6424' TVD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press, xx psi 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. . N/A ,-.'.. :?."..:"" .!'..~ ~:; '": :? :i~'' ~... Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ' ..... '"?'" Submit in duplicate 29. NAME GEOLOGIC MARKERS TRUE VERT. DEPTH Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A MEAS. DEPTH 8344' 8570' 87O2' 8702' 6407' 6551' 6635' 6635' 30. FORMATION TESTS Include interval tested, pressure dala, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 31. LIST OF A-I-FACHMENTS Summary of Daily Operations, Directional Survey 32. 1 hereby certify that the following is true and correct to the best of my knowledge. Signed /,//'~'~ O~ Title Drillinq Engineering Supervisor Date G. C. Alvord INSTRUCTIONS Prepared by Sharon Aflsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 showthe producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Fo rm 10-407 Date: 10/25/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-14 WELL_ID: AK0030 TYPE: STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:09/21/99 START COMP: --_ RIG:POOL 6 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22950-00 09/21/99 (D1) MW: 9.7 VISC: 147 PV/YP: 41/40 APIWL: 6.2 TD/TVD: 706/706 (706) DRILLING ~1302' SUPV:R. MORRISON/S. REYNOLDS Accept rig at 0100 hrs. 9/21/99. Nil diverter and function test. Held pre-spud meeting. Spud well at 1300 hrs. 9/21/99. Drill 12.25" hole from 115' to 706' 09/22/99 (D2) MW: 10.0 VISC: 125 PV/YP: 37/36 APIWL: 5.8 TD/TVD: 2945/2913 (2239) DRILLINGS3192' SUPV:R. MORRISON/S. REYNOLDS Drill 12.25" hole from 706' to 2477' CBU. Pump slug. Wipe hole from 2477' to 1076'. Run to bottom, no tight spots, no fill. Directional drill from 2477' to 2945' 09/23/99 (D3) MW: 10.1 VISC: 183 PV/YP: 58/64 APIWL: 5.6 TD/TVD: 3801/3570 ( 856) POOH WITH BHA #2 SUPV:R. MORRISON/S. REYNOLDS Directional drill 12.25" hole from 2945' to 3100'. Upper gravel zone fell in. Overloaded ball mill pits. Directional drill 12.25" hole from 3100' to 3584'. Held field wide safety stand down. Directional drill from 3584' to 3801' Pump and back ream out from 3495' to 2763'. Intermittent minor packing off while pumping out. Circulate hole clean. Had abundant amounts of clay-gravel and then more clay. Continue POOH. Hole packed off at 2014'. Regain full returns and circulate hole clean. Minimal cuttings returns on bottoms up. 09/24/99 (D4) MW: 10.1 VISC: 232 PV/YP: 59/78 APIWL: 5.2 TD/TVD: 3801/3570 ( 0) DRILLING ~ 4250 SUPV:R. MORRISON/S. REYNOLDS RIH to 1046', hit bridge. Could not work through bridge. Make up 12.25" hole opener. RIH, ream through bridges at 192', 1046', 1261', 1326' Ran to bottom at 3801' Circulate at 3801' Increase viscosity to 250. Pump work and ream through knot at 1395' POOH, hole free. 09/25/99 (D5) MW: 10.1 VISC: 186 PV/YP: 54/60 APIWL: 4.8 TD/TVD: 4946/4295 (1145) RIGGING UP TO RUN 9-5/8" CASING SUPV:R. MORRISON/S. REYNOLDS Directional drill from 3801'-4946'. Pump weighted barofiber sweep. Circulate hole clean. Date: 10/25/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 09/26/99 (D6) MW: 10.0 VISC: 63 PV/YP: 31/28 APIWL: 4.6 TD/TVD: 4946/4295 ( 0) NIPPLE UP 13 5/8" BOPE SUPV:R. MORRISON/S. REYNOLDS PJSM. Run 9.625" casing. Cemented 9-5/8" casing. 09/27/99 (D7) MW: 8.4 VISC: 44 PV/YP: 9/15 TD/TVD: 4946/4295 ( 0) CIRCULATING HOLE TO 8.5 PPG LSND MUD. SUPV:S.D. REYNOLDS Test BOPE to 250/5000 psi. APIWL: 12.8 09/28/99 (D8) MW: 9.1 VISC: 49 PV/YP: 16/23 APIWL: 7.6 TD/TVD: 6290/5132 (1344) TIH SUPV:M. WINFREE Drill cement stringers from 4830, float collar ~ 4854, good cement from 4854 to shoe, clean out rat hole to 4946' make 20' new hole to 4966'. FIT 13.2 ppg EMW. Drill from 4966' to 6290' 09/29/99 (D9) MW: 9.1 VISC: 49 PV/YP: 16/22 APIWL: 7.6 TD/TVD: 7171/6574 ( 881) DRILLING AT 7733' SUPV:M. WINFREE Observe well. Pump dry job. POOH (attempted to swab 5500'-5000'). Change bit. 1 nozzle plugged, nose balled up. Drill from 6290' to 7171' 09/30/99 (D10) TD/TVD: 8077/6574 SUPV:M. WINFREE MW: 9.3 VISC: 48 PV/YP: 15/17 906) RUNNING 7" APIWL: 4.6 Drilling from 7171' to 7950' Safety stand down. OH LOT ~ 6160, EMW=ll.7 ppg. Drill from 7950' to 8077'. Circ and try to survey, no good. 10/01/99 (Dll) TD/TVD: 8077/6574 SUPV:M. WINFREE MW: 11.1 VISC: 54 PV/YP: 21/18 0) RIH APIWL: 4.4 PJSM. Run 7" casing. PJSM. Pump cement. Install packoff and test to 5000#, OK. 10/02/99 (D12) TD/TVD: 8702/6574 SUPV:M. WINFREE MW: 11.1 VISC: 62 PV/YP: 28/33 625) POOH W/ DP APIWL: 4.2 Clean out to float collar. Drill FC ~ 7983', drill cement to 5' above FS. Drill out FS clean out rat hole drill 18' Perform LOT 14.2 ppg EMW. Drill 8096' to 8702' 10/03/99 (D13) TD/TVD: 8702/6574 SUPV:M. WINFREE MW: 11.1 VISC: 56 PV/YP: 22/18 0) POOH W/ DP Run 4.5" liner. APIWL: 5.4 Date: 10/25/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 10/04/99 (D14) TD/TVD: 8702/6574 SUPV:M. WINFREE 10/05/99 (D15) TD/TVD: 8702/6574 SUPV:G.R. WHITLOCK 10/06/99 (D16) TD/TVD: 8702/6574 SUPV:G.R. WHITLOCK 10/07/99 (D17) TD/TVD: 8702/6574 SUPV:G.R. WHITLOCK 10/08/99 (D18) TD/TVD: 8702/6574 SUPV:G.R. WHITLOCK MW: 11.1 VISC: 63 PV/YP: 29/35 APIWL: 5.2 0) POOH W/ SEAL ASSY. PJSM. Pump cement. Log 4.5" liner. MW: 8.5 VISC: 28 PV/YP: 1/ 0 APIWL: 0.0 0) RUNNING COMPLETION Test liner to 3000 psi, OK.RIH w/tieback liner packer. Sting into TOL w/tieback packer ~ 7886' Packer not set. POOH. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0) RIG RELEASED ~ 04:00 HRS 10/7/99 READY TO MOVE TO 1D-1 Hold safety meeting. Run 4.5" tubing. Freeze protect tubing and annulus. N/D BOPE. NU tree and test to 5000 psi, OK. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0) MOVING RIG TO iD-ii N/U tree and test to 350/5000, OK. Prep rig to move. RDMO. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0) RIG MOVED TO iD-ii Continue to rig down, move rig. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~. WELL SERVICE REPORT ~' K1(1D-14(W4-6)) WELL JOB SCOPE JOB NUM'BER " 1 D-14 DRILLING SUPPORT-CAPITAL 1018990513.1 DATE DAILY WORK UNIT NUMBER 10/22/99 CBL/PE R F 2128 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 YESI YES SWS-ELMOR E SCH U D EL FIELD AFC# CC# Signed ESTIMATE AK0046 230DS10DG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 100 PSI 850 PSI 0 PSI 0 PSII 600 PSII 600 PSI DAILY SUMMARY I PERF'S SHOT UNDERBALANCED FROM 8350'-8370'.[Perf] CBL SHOWED LITTLE TO NO CEMENT ABOVE 8260', GOOD CEMENT 8260'-8330', LITTLE TO NO CEMENT BELOW 8330'. TIME LOG ENTRY 10:30 MIRU SWS 2128 ELMORE, TGSM, WAIT ON HES TO FINISH S/L WORK. 11:40 BEGIN RU. PT 3000#. 12:40 RIH W/SWIVEL, WTBAR, SCMT. 13:45 CHECK UP TENSION AT 7700', RIH TO TD. 14:00 LU REPEAT PASS 1, 8624'-7800'. 30 FPM. 900 PSI WHP. CORRECTED ELM TAG DEPTH=8624'. 14:35 LU PASS 2, 8624'-7800', W/900 PSI WHP. POOH. 16:30 RIH W/CCL, MPD, SAFE, 20' X 2 7/8" 4 SPF, DEEP PENETRATING CHARGES, +/- 90 FLSH. OAL=29.8'. 17:15 LOG TIE IN PASS. 18:00 LU TO SHOOT 8350'-8370'. PUMPED UP TBG TO 650# WHP. BHP FROM PREVIOUS CBT RUN WAS 3060#, WITH 900 PSI ON WH. PERFORATED @ +/- 500 PSI UNDERBALANCE. WHP INCREASED TO 850 PSI WHEN PERF'D. POOH. 19:00 AT SURFACE, RD. 20:00 RDMO TO HOUSE. Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 1D, Slot 1D- 14 1D-14 Job No. AKMM90158, Surveyed: 2 October, 1999 SURVEY REPORT ORIGINAL RECEIVED 20 October, 1999 ~,,~ ~ 28 ~999 Alal~ Oil& Gas Cons. Commission Your Ref: API-500292295000 Alll~llO~a~e Surface Coordinates: 5959873.87 N, 560490.50 E (70° 18' 03.3733" N, 149° 30' 36.2478" W) Kelly Bushing: 104.61ft above Mean Sea Level I~...R, I L L. I N ~ S E R V I C:: 6 S Survey Ref: svy8880 Sperry-Sun Drilling Services Survey Report for 1D- 14 Your Ref: API-500292295000 Job No. AKMM90158, Surveyed: 2 October, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -104.61 0.00 115.00 0.000 0.000 10.39 115.00 200.18 0.340 352.800 95.57 200.18 293.63 0.540 18.890 189.02 293.63 381.48 0.630 356.950 276.86 381.47 472.63 0.840 357.680 368.00 472.61 567.16 1.220 1.080 462.52 567.13 655.66 0.590 324.260 551.01 655.62 746.41 0.590 321.530 641.75 746.36 838.13 0.850 296.930 733.47 838.08 929.88 0.730 292.090 825.21 929.82 1018.60 0.680 295.790 913.92 1018.53 1112.20 1.000 284.360 1007.51 1112.12 1206.50 .2.670 316.130 1101.76 1206.37 1303.30 4.380 315.440 1198.37 1302.98 1395.10 4.930 317.210 1289.87 1394.48 1487.51 5.940 316.990 1381.86 1486.47 1580.68 8.210 318.190 1474.32 1578.93 1674.36 8.540 327.280 1567.00 1671.61 1770.40 8.290 327.560 1662.01 1766.62 1862.48 8.040 328.140 1753.16 1857.77 1956.47 8.080 329.060 1846.22 1950.83 2050.89 7.840 329.140 1939.73 2044.34 2145.67 7.660 327.170 2033.64 2138.25 2239.27 7.760 329.210 2126.40 2231.01 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5959873.87 N 560490.50 E 0.00 N 0.00 E 5959873.87 N 560490.50 E 0.25 N 0.03W 5959874.12 N 560490.47 E 0.94 N 0.08 E 5959874.81N 560490.57 E 1.82 N 0.18 E 5959875.69 N 560490.67 E 2.98 N 0.13 E 5959876.86 N 560490.61E 4.68 N 0.12 E 5959878.55 N 560490.58 E 5.99 N 0.13W 5959879.86 N 560490.33 E 6.74 N 0.69W 5959880.60 N 560489.76 E 7.42 N 1.59W 5959881.27 N 560488.85 E 7.95 N 2.74W 5959881.79 N 560487.70 E 8.39 N 3.74W 5959882.23 N 560486.70 E 8.83 N 5.03W 5959882.66 N 560485.40 E 10.62 N 7.35W 5959884.43 N 560483.07 E 14.88 N 11.50W 5959888.66 N 560478.88 E 20.27 N 16.64W 5959894.01N 560473.69 E 26.68 N 22.60W 5959900.37 N 560467.68 E 35.17 N 30.33W 5959908.79 N 560459.89 E 46.00 N 38.55W 5959919.56 N 560451.58 E 57.85 N 46.11W 5959931.34 N 560443.92 E 68.92 N 53.07W 5959942.36 N 560436.87 E 80.17 N 59.94W 5959953.55 N 560429.92 E 91.39 N 66,66W 5959964.72 N 560423.11 E 102.24 N 73.40W 5959975.52 N 560416.28 E 112,91 N 80.01W 5959986.14 N 560409.58 E Alaska State Plane Zone 4 Kuparuk 1D Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.00 0.000 0.00 0.399 0.24 O.298 O.79 0.273 1.51 0.231 2.57 0.407 4.07 0.935 5.34 0.031 6.26 0.434 7.29 0.150 8.30 0.076 9.16 0.384 10.16 2.009 12.83 1.767 18.55 0.619 25.73 1.093 34.20 2.441 45.33 1.455 58.77 0.264 72.78 0.286 85.83 0.144 98.99 0.254 112.05 0,339 124.80 0.311 137.33 Continued... 20 October, 1999 - 15:06 - 2 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 1D- 14 Your Ref: API-500292295000 Job No. AKMM90158, Surveyed: 2 October, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2332.75 9.140 331.270 2218.86 2323.47 2427.63 9.080 331.630 2312.54 2417.15 2518.48 11.760 330.520 2401.89 2506.50 2612.40 14.060 331.700 2493.43 2598.04 2706.76 16.130 334.090 2584.53 2689.14 2801.23 18.920 333.740 2674.60 2779.21 2893.73 21.770 334.620 2761.32 2865.93 2987.52 23.930 333.470 2847.75 2952.36 3078.91 25.430 330.740 2930.79 3035.40 3172.52 28.270 331.420 3014.30 3118.91 3266.20 30.980 330.770 3095.73 3200.34 3360.39 34.090 330.070 3175.13 3279.74 3452.57 37.330 331.020 3249.97 3354.58 3547.05 39.760 332.730 3323.86 3428.47 3643.18 42.120 333.580 3396.47 3501.08 3737.31 45.020 332.880 3464.66 3569.27 3830.73 48.000 332.120 3528.95 3633.56 3922.96 50.450 331.760 3589.18 3693.79 4018.05 49.940 332.120 3648.77 3753.38 4110.90 52.130 331.910 3708.42 3813.03 4204.59 50.930 331.910 3766.70 3871.31 4298.64 51.620 332.360 3825.54 3930.15 4392.91 52.280 332.030 3883.64 3988.25 4489.34 51.390 331.930 3943.23 4047.84 4584.27 52.910 332.310 4001.47 4106.08 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 124.85 N 86.81W 5959998.01N 560402.69 E 138.04 N 93.99W 5960011.15 N 560395,40 E 152.41 N 101.96W 5960025.46 N 560387.32 E 170.79 N 112.08W 5960043.75 N 560377.05 E 192.68 N 123.24W 5960065.55 N 560365.71E 218.22 N 135.75W 5960090.99 N 560353.00 E 247.17 N 149.74W 5960119.83 N 560338.77 E 279.91 N 165.69W 5960152.44 N 560322.56 E 313.61N 183.57W 5960185.99 N 560304.42 E 350.62 N 204.00W 5960222.84 N 560283.69 E 391.15 N 226.39W 5960263.19 N 560260.97 E 435.19 N 251.40W 5960307.02 N 560235.60 E 482.04 N 277.84W 5960353.66 N 560208.79 E 533.97 N 305.57W 5960405.36 N 560180.64 E 590.17 N 334.00W 5960461.33 N 560151.76 E 648.08 N 363.23W 5960519.01 N 560122.07 E 708.19 N 394.53W 5960578.86 N 560090.28 E 769.82 N 427.39W 5960640.22 N 560056.93 E 832.92 N 461.03W 5960703.05 N 560022.78 E 898.04 N 495.63W 5960767.89 N 559987.65 E 962.75 N 530.17W 5960832.33 N 559952.60 E 1027.62 N 564.46W 5960896.91 N 559917.78 E 1093.28 N 599.09W 5960962.30 N 559882.63 E 1160.21 N 634.71W 5961028.94 N 559846.47 E 1226.47 N 669.76W 5961094.91 N 559810.89 E Alaska State Plane Zone 4 Kuparuk 1D Dogleg Vertical Rate Section (°/100ft) (ft) Comment 1.511 151.06 0.087 166.08 2.958 182.51 2.465 203.49 2.290 228.05 2.955 256.48 3.099 288.60 2.352 324.99 2.061 363.14 3.052 405.41 2.913 451.71 3.326 502.35 3.566 556.13 2.808 614.99 2.522 677.96 3.123 742.81 3.244 810.57 2.673 880.41 0.623 951.92 2.315 1025.67 1.281 1099.02 0.823 1172.39 0.752 1246.62 0.927 1322.44 1.632 1397.39 Continued... 20 October, 1999 - 15:06 -3- DrillQuest Sperry-Sun Drilling Services Survey Report for 1D- 14 Your Ref: API-500292295000 Job No. AKMM90158, Surveyed: 2 October, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 4677.58 52.420 332.940 4058.06 4162.67 4771.68 53.390 332.550 4114.82 4219.43 4866.79 52.760 332.920 4171.96 4276.57 4897.06 52.410 332.200 4190.35 4294.96 4958.67 52.440 332.160 4227.92 4332.53 5050.83 51.760 331.750 4284.53 4389.14 5144.83 51.190 330.800 4343.08 4447.69 5239.75 54.040 332.800 4400.71 4505.32 5330.96 53.380 335.080 4454.70 4559.31 5425.49 52.860 333.960 4511.43 4616.04 5521.23 52.280 334.130 4569.62 4674.23 5614.79 51.780 333.840 4627.18 4731.79 5707.27 54.170 330.370 4682.88 4787.49 5801.88 53.790 330.900 4738.51 4843.12 5896.59 53.120 331.800 4794.91 4899.52 5990.73 52.520 330.660 4851.80 4956.41 6085.00 51.870 331.280 4909.59 5014.20 6178.86 53.890 331.730 4966.23 5070.84 6271.55 53.800 330.270 5020.91 5125.52 6366.31 53.550 331.990 5077.05 5181.66 6460.55 53.280 331.520 5133.22 5237.83 6555.77 53.170 330.980 5190.22 5294.83 6649.21 52.730 330.770 5246.52 5351.13 6742.76 51.770 329.750 5303.80 5408.41 6835.74 51.260 330.810 5361.66 5466.27 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1292.35 N 703.87W 5961160.51 N 559776.25 E 1359.07 N 738.25W 5961226.96 N 559741.34 E 1426.66 N 773.08W 5961294.26 N 559705.96 E 1448.00 N 784.16W 5961315.51 N 559694.71 E 1491.18 N 806.94W 5961358.51 N 559671.58 E 1555.36 N 841.13W 5961422.41N 559636.87 E 1619.85 N 876.47W 5961486.62 N 559601.01E 1686.32 N 912.09W 5961552.79 N 559564.87 E 1752.35 N 944.39W 5961618.57 N 559532.04 E 1820.61N 976.91W 5961686.56 N 559498.96 E 1888.97 N 1010.19W 5961754.65 N 559465.14 E 1955.25 N 1042.53W 5961820.67 N 559432.26 E 2020.47 N 1077.10W 5961885.60 N 559397.17 E 2087.16 N 1114.62W 5961951.99 N 559359.11 E 2153.93 N 1151.10W 5962018.46 N 559322.09 E 2219.68 N 1187.20W 5962083.92 N 559285.47 E 2284.80 N 1223.35W 5962148.75 N 559248.80 E 2350.57 N 1259.05W 5962214.23 N 559212.57 E 2416.03 N 1295.33W 5962279.39 N 559175.77 E 2482.88 N 1332.19W 5962345.94 N 559138.37 E 2549.54 N 1368.00W 5962412.31N 559102.02 E 2616.41N 1404.68W 5962478.88 N 559064.80 E 2681.55 N 1440.98W 5962543.74 N 559027.98 E 2745.78 N 1477.67W 5962607.67 N 558990.78 E 2808.99 N 1513.75W 5962670.58 N 558954.18 E Alaska State Plane Zone 4 Kuparuk 1D Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.751 1471.57 1.083 1546.62 0.732 1622.64 2.215 1646.68 0.071 1695.51 0.817 1768.23 0.996 1841.77 3.438 1917.17 2.141 1990.63 1.096 2066.15 0.622 2142.12 0.588 2215.82 3.956 2289.63 0.605 2366.13 1.041 2442.22 1.156 2517.22 0.863 2591.69 2.186 2666.53 1.275 2741.36 1.486 2817.69 0.492 2893.37 0.469 2969.63 0.504 3044.20 1.340 3118.14 1.047 3190.90 Continued... 20 October, 1999 - 15:06 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D- 14 Your Ref: API-500292295000 Job No. AKMM90158, Surveyed: 2 October, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 6929.54 52.180 330.850 5419.77 5524.38 7020.74 51.890 330.940 5475.87 5580.48 7114.35 51.670 330.990 5533.79 5638.40 7208.48 51.450 331.730 5592.31 5696.92 7304.57 51.300 329.280 5652.30 5756.91 7397.03 50.950 329.730 5710.33 5814.94 7492.44 52.010 331.830 5769.75 5874.36 7586.85 51.890 331.470 5827.94 5932.55 7678.46 51.280 331.660 5884.86 5989.47 7773.79 51.040 331.320 5944.65 6049.26 7867.92 50.730 330.630 6004.03 6108.64 7966.73 51.500 332.090 6066.06 6170.67 8021.83 51.300 332.640 6100.44 6205.05 8121.19 51.520 333.610 6162.41 6267.02 8216.93 51.050 334.120 6222.29 6326.90 8315.17 50.740 333.860 6284.26 6388.87 8415.79 50.500 333.630 6348.10 6452.71 8506.94 50.620 333.120 6406.00 6510.61 8602.71 50.240 333.490 6467.01 6571.62 8633.24 50.140 333.330 6486.56 6591.17 8702.00 50.140 333.330 6530.63 6635.24 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2873.28 N 1549.64W 5962734.58 N 558917.78 E 2936.10 N 1584.61W 5962797.12 N 558882.30 E 3000.40 N 1620.31W 5962861.13 N 558846,09 E 3065.11 N 1655.65W 5962925.55 N 558810.23 E 3130.44 N 1692.60W 5962990.58 N 558772.75 E 3192.46 N 1729.13W 5963052.31N 558735.73 E 3257.61 N 1765.56W 5963117.16 N 558698.78 E 3323.04 N 1800.86W 5963182.30 N 558662.95 E 3386.16 N 1835.04W 5963245.15 N 558628.26 E 3451.41 N 1870.48W 5963310.11 N 558592.30 E 3515.27 N 1905.91W 5963373.68 N 558556.35 E 3582.77 N 1942.77W 5963440.88 N 558518.95 E 3620.92 N 1962.75W 5963478.87 N 558498.67 E 3690.19 N 1997.85W 5963547.86 N 558463.01 E 3757.26 N 2030.76W 5963614.66 N 558429.56 E 3825.77 N 2064.19W 5963682.90 N 558395.58 E 3895.52 N 2098.59W 5963752.37 N 558360.62 E 3958.45 N 2130.14W 5963815.04 N 558328.56 E 4024.40 N 2163.30W 5963880.73 N 558294.87 E 4045.38 N 2173.80W 5963901.61 N 558284.20 E 4092.54 N 2197.49W 5963948.59 N 558260.13 E Alaska State Plane Zone 4 Kuparuk 1D Dogleg Rate (°/100ft) Vertical Section (ft) Comment 0.981 0.327 0.239 0.659 1.998 0.536 2.049 0.326 0.685 0.375 0.657 1.389 0.860 0.795 0.643 0.376 0.297 0.452 0.496 0.519 0.000 3264.52 3336.41 3409.95 3483.67 3558.71 3630.64 3705.27 3779.61 3851.39 3925.64 3998.67 4075.58 4118.64 4196.28 4270.93 4347.10 4424.83 4495.20 4568.99 4592.44 4645.20 PROJECTED SURVEY Continued... 20 October, 1999 - 15:06 - 5- DrillQuest Sperry-Sun Drilling Services Survey Report for 1D- 14 Your Ref: API-500292295000 Job No. AKMM90158, Surveyed: 2 October, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 1D All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 331.766° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8702.00ft., The Bottom Hole Displacement is 4645.20ft., in the Direction of 331.766° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 8702.00 6635.24 4092.54 N 2197.49 W PROJECTED SURVEY 20 October, 1999 - 15:06 - 6- DrlllQuest l::l Ft I I._1._ I ~ [:i C~ER~/I r' Ec; 20-Oct-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-14 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 8,702.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) OCT 2 8 1999 ~011 & Gas Cons. Commissio~ 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION September 16. 1999 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 G. C. Alvord Drilling engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0361 a¢~ Kuparuk River 1 D- 14 ARCO Alaska. Inc. Permit No: 99-089 Sur Loc: 209'FSL, 595'FEL. Sec. 14, T11N, R10E. UM Btmhole Loc. 971'FNL. 2493'FWL. Sec. 14. T1 IN, R10E. UM Dear Mr. Alvord: 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. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 1D-14. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 1D must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35.000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice mav be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · Robert N. Christenson, P.E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC~ Department of Fish & Game. Habitat Section w/o encl. Deparm~ent of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 · . la. Type of work: Drill [] Redrill [] J lb. Type of well. Exploratory [] StratigraphicTest BI' Development Oil [] Re-entry [] Deepen []J Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 35 feet 8. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-036l ADL 25650 ALK 468 Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 209' FSL, 595' FEL, Sec. 14, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1199' FNL, 2616' FWL, Sec. 14, T11N, R10E, UM 1D-14 #U-630610 At total depth 9. Approximate spud date Amount 971' FNL, 2493' FWL, Sec. 14, T11N, R10E, UM September 20, 1999 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 971 @ TD feet 1D-01 27.7' @ 980' feet 2560 8692 ' MD / 6608 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 1200 MD Maximum hole angle 52° Maximum surface 2543 psig At total depth (TVD) 3018 psig 18. Casing program Setting Depth size Specifications Top Bottom Quanti~ of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" 62.5# R-3 Weld 100' 35' 35' 135' 135' 230 sx ASI 12.25" 9.625" 40# L-80 BTC 4908' 35' 35' 4943' 4312' 610 sx AS III L & 640 sx Class G 8.5" 7" 26# L-80 BTC-Mod 8019' 35' 35' 8054' 6218' 220 sx Class G 6.125" 4.5" 12.6# L-80 ABT-Mod 788' 7904' 6126' 8692' 6608' 190 sx Class G ,. 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production ;: ;'._ i!:-ill !]ii?I' i: Linerh ORIGINAL ~, .... ~ %?] ,',; Perforation depth: measured true vertical ~'-'-';!] (; i 20. Attachments Filing fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby cedify that the foregoing is true and correct to the best of my knowledge Questions? Carl William Lloyd 265-653 Signed Date G.C. Alvord ~.~,~.~ Title:DdllingEngineedngSupervisor _ pr~.n~rp.d hv .Rh~rnn / Commission Use Onl~ Permit Num~,e/~;2 APl number I Approvaldate~ , qq ISee cover letter -(~ 50-(:~...~"%."' ,~..-~-.-~',,~-(~ y'~/~ ~' for other requirements Conditions of approval Samples required [] Yes ~ No Mud Icg required [] Yes [] No Hydrogen sulfide measures ~ Yes [] No Directional survey required .~ Yes [] No Required working pressure for BOPE [] 2M; [] 3M; [] 5M; [] 10M;E] '[~ ~.~ ! Other: _ Approved by ORIGINAL SIGNED BY Commissioner the commission Date Robert N. Christenson Form 10-401 Rev. 12/1/85 · Submit in triplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 September 3, 1999 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill: KRU 1D-14 Surface Location: 209' FSL, 595' FEL Sec 14 TllN R10E, UM Target Location: 1199' FNL, 2616' FWL Sec. 14, TllN, R10E, Ut4 Bottom Hole Location: 971' FNL, 2493' FWL Sec. 14, TllN, R10E, UM Dear Commissioner Christenson, ARCO Alaska, ]:nc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of 1D pad. The well is designated as a conventional Znjector using a 9 5/8" surface casing string, a 7" intermediate casing string, a 4 1/2" liner and 4-1/2" tubing. 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). 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) 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. 9) ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. Robert Christenson Application for Permit to Drill - 1D-14 Page 2 10) Due to the large volume of regional information available, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. The following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Technologist (20 AAC 25.070) Sharon AIIsup-Drake, Drilling 263-4612 2) Geologic Data and Logs Bill Raatz, Geologist (20 AAC 25.071) 263-4952 The anticipated spud date for this well is September 20, 1999. If you have any questions or require further information, please contact Bill Lloyd at (907) 263- 6531 or Chip Alvord at (907) 265-6120. CC: Kuparuk 1D-14 Well File Chip Alvord ATO-1200 MJ Loveland NSK6 ARCO Alaska, Inc. Drill and Case Plan for 1D-:!.4 Kuparuk Producer General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. :Install diverter & function test same. 3. Spud and directionally drill 12 1/4" hole to the surface casing point at 4943' IVlD/4311' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. · Employ lightweight permafrost cement lead slurry to assure cement returns to the surface in a one stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. · TAM Port Collar will be placed in the casing string at 1000' MD to be used in the event that cement does not reach the surface in the primary one stage job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify AOGCC 24 hours before test 7. Make up 8 1/2" bit and BHA and R]:H to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 8. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 9. Drill 8 1/2" hole to intermediate casing point at +8054' IVlD/6217' TVD · Perform a second LOT and determine an acceptable kick tolerance · ]:f kick tolerance is acceptable, 8 1/2" hole will be drilled to TD · Tf kick tolerance is unacceptable, 7" casing will be run to top Kuparuk 10. Run and cement 7" 26# L80 BTC-Mod (if required from step #9) Steps 11-14 are only applicable if we are required to top set the Kuparuk with 7" casing 11. Make up 6 1/8" bit and BHA and R[H to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 12. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 13. Drill 6 1/8" hole to TD at 8692' MD/6608' TVD · Condition hole and mud for casing 14. Run and cement 41/2'' 12.6#/ft L-80 ABT-IVlod Liner 15. Make a cleanout run with bit and scrapers if necessary · Displace to filtered seawater · Pressure test well to 3000 psi for 30 minutes · Record results and fax to town 16. Run and land 4 1/2" tubing 17. Nipple down BOP's. ]:nstall production tree and pressure test same. 18. Secure well, release rig ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS We~i f(RU ID-14 Drillinq Fluid Pro Density PV YP Funnel Vis ]:nitial Gel 10 Minute Gel AP]: Filtrate pH % Solids )erties: Spud to surface casing point 9.5-10.2 ppg 16-26 25-35 100 - 300* Drill out to TD 9.5- 11.1 ppg 7-21 7-22 35-50 10-20 15-40 7-15 9.5-10 +10% 2-6 4-8 <6 through Kup 9.0-10 <11% Drilling Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge IPit Level ]:ndicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Degasser *Spud mud should be adjusted to a FV between 200-300 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Haximum anticipated surface pressure (HASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2,543 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. HASP = (4,311 ft)(0.70- 0.11) = 2,543 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of 1D pad are expected to be N3,400 psi (0.52 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 11.1 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 6,136'. Target (Kuparuk C4) (3400+ 150)/(0.052'6136)= 11.1. An additional risk is associated with gas pressurization of sand stringers within the Kalubik interval. These stringers have become charged with gas due to historic gas injection in the GSA area. ]:dentification of, and degree of charging of these sands is unpredictable and best determined by offset records. ]:n the area of 1D-14 it is anticipated that the mud weight required to balance gas in the Kalubik zone may be as high as 11.8 ppg ARCO Alaska, Inc. Well Proximity Risks: The nearest well to ID-14 is 1D-01. The wells are 27.7f from each other at a depth of 980' HD. Drillinq Area Risks: Drilling risks in the ::[D-::t4 area are surface interval hydrates, lost circulation and potential borehole instability in and below the permafrost formation. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of pipe, controlled drilling rates, and optimum rheological properties to safely appropriate gas breakout. Lost circulation will be addressed with lost circulation material (LCM) Annular Pumpinq Operations: Tncidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class ]:]: disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The ~.D-:t4 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. Tf isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We anticipate that :ID-:[4 will be requested to be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. All necessary documentation for the permitting of this well for annular injection will be provided after the well is completed. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300- 500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. 16" Conductor Casing at 135' MD / RKB permafrost 1,811' MD Top of West Sak 3,870' MD Base of West Sak 4,616' MD Sudace Casing at 4,943' MD Top of Cement at 7.000' MD Intermediate Casing at 8,084' MD 4-1/2" Production Liner @ 7,904' MD to 8,692' MD 1D-14 WELLBORE SCHEMATIC and CEMENT DESIGN 9/3/1999 FMC Prudhoe Gert V --i 9-5/8 x 7~ -- 9-5/8 Mandrel Hangel Base of permafrost at 1,811' MD/1,806'TVD 12-1/4" Top of West Sak at 3,870' MD / 3,654' TVD Base of West Sak 4,616' MD / 4,112' TVD 9-5/8" 40 ppf L-80 BTC Surface Casing 4,943' MD / 4,312' TVD 8-1/2" Hole Baker 4.5" x 7" SLZXP LTP and Hanger w/PBR @ 7,906' MD Weatherford Gemoco 7" Float Collar and Float Shoe Baker 4-1/2" Landing Collar, Float Collar and Float Shoe (1 jt. spacing between each) Completion Type 2 16" Conductor Weatherford Gemoco 9-5/8" PORT Collar Standard Grade, BTC 1.000' MD / 1.000' TVD Mud Weight in Surface hole: 10.0 ppg by 1100' TVD 10.2 ppg by 1900' TVD Weather[oral Gemoco 9-5/8" Float Collar and Float Shoe Mud Weight in Production hole 10.8 to 12.5ppg 7" 26 L-80 BTC Mod Csg 8,054' MD 6.218' TVD 4-1/2" 12.6#/ft L-80 ABT-Mod 9/3/1999 Completed 1D-14 FMC Pmdhce Gert V 9-5/8 x 7 x 4V~ Sase of permafrost at 1,811' MD / 1,806' TVD 12-1/4" Hole Weat.h,,erford Gemoco 9-5/8 PORT Collar Standard Grade, BTC 9-5/8" 40 ppf L-80 BTC-Mod Surf.Csg. 4,943' MD / 4,312' TVD 81/2" Hole 4Y~" 12.6ppf L-80 ABT-Mod w/15' seal bore extension tied into top of liner 7" 26 ppf L-80 BTC Intermediate. Csg. 8,054' MD / 6,218' TVD Baker 4.5" x 7" SLZXP LTP and Hanger. TOL @ 7,906' MD/6,126' TVD 6-1/8" Hole 3.813" CAMCO DB or Otis X nipple for SCSSV at 500' + MD Camco 41/2'' x 1" side pocket GLM's station# MD TVD #1 7843 #2 #3 #4 #5 CAMCO or Otis 3.75 nipple 6088 1,000' 2,000' 3,000' 4,000' 5,000' 6,000' 7,000' 8,000' 9,000' 10,000' GSA Development Drilling 1D-14 Planned -~=-Actual 0 1 2 3 4 5 6 7 8 9 10 Days 11 12 13 14 15 16 17 18 9/27/]999 Cn~t,d ~ r~, FOR: LLOYD Dote !~ottecl: 2-~ep-1999 Plot Relerence Is t 4 Version ~2. Coordinates ute ;n feet reference elot ~t4. Frue Vertical Depths ore reference ;;KB Pool 400 80O 1200 1600 2000 2800 3200 5600 4000 4400 4800 5200 5600 6000 6400 6800 ~RKB ELEVATION: 105' ARCO Alaska, Inc. Structure: Pad 1D Well: 14 Field : Kuparuk Rl~er Unh' gooaflon : North Slope, Alaska Begin Nudge .5.00 6.00 End of Nudge TD LOCATION: 971' FNL, 2493' FWL SEC, 1¢, T11N, RIOE 2700 2400 I I I TARGET LOCATION: 1199' FNL, 2618' FWL SEC. 14, T11N, RIOE <- West (feet) 2100 1800 1500 1200 900 I I I I I I I I I I TD/4-1/2 Coslng Pt Top B Shale Top C1 Top C3 Top C2 Target-Top C¢ 1 D-14 Vet#2 Top Kuporuk D K-1 7 Casing Pt-Bose HRZ C20 C50 i C40 Bose Permafrost 331 85 Azimuth 4392; (TO TARGET) ~ c5o ***Plane of Proposal*** Begin Build 12.oo \ 15.00 18.00 DLS: 5.00 deg per 100 ft 21.00 % 27.00 ~, 30.00 \ 'x 33.00 , 39.00 C80 % 45.00 -~.00 T°PFo~eSt Sak ~X'~ Bose West Sok "~.. Bose West Sok 9-5/8 Casing Pt C50 AVERAGE ANGLE ~ Bose Permofrost 52.22 DEG '~c4o ~ c3°c2o 7 Casing K-I- Top C1 Top B Shale TD/4-1/2 Casing Pt 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 400 800 1200 1600 2000 2400 2800 3200 5600 4000 4400 4800 60D 300 0 300 I I I I I I i 9-5/8 Casing Pt EOC Top West Sok Begin End of Nudge Begin Nudge -4200 5900 3600 5500 3000 2700 2400 2100 1800 1500 1200 9OO 60O 500 $00 /x I Z 0 SURFACE LOCATION: 209' FSL. 595' FEL SEC. 14, T11N, RIOE Vertical Section (feet) -> Azimuth 331.85 with reference 0.00 N, 0.00 E from slot #14 ICreated by r~xse FOR: LLOYD Dote plotted: 2-Sep-1999 Plot Reference i's 14 Version Coordinates ore in feet reference slot 1~14-. True Verticol Depths ere reference RKB Pool ~6. ARCO Alaska, Inc. Sfrucfure : Pad 1D Well : 14 Field : Kuporuk River Unlf Locofion : North Slope, Alosko Point Begin Nudge End of Nudge Base Permafrost Begin Build Top West Sak EOC Base West Sak 9-5/8 Casing Pt C80 C50 C40 C50 C20 7 Casing Pt-Base HRZ K-1 Top Kuparuk D Target-Top C4 1D-14 Top C5 Top C2 Top C1 Top B Shale T_D_Z/_4_- 1/2 Casinq Pt PROF MD 1200.00 1500.00 1810.05 2500.00 5870.21 3940.64 4616.15 4942.59 5224.97 6584.66 7069.44 7679.91 7892.11 8053.70 8192.45 8329.56 8363.83 8445.45 8478.O9 8562.97 8584.19 8691.92 0 9 9 9 50 52 52 52 52 52 52 52 52 52 52 52 52 52 52 52 52 52 LE COMMENT Inc Dir O0 351.85 O0 351.85 O0 331.85 O0 331.85 11 331.85 22 551.85 22 551.85 22 551.85 22 551.85 22 351.85 22 551.85 22 551.85 22 351.85 .22 551.85 .22 551.85 .22 551.85 .22 551.85 .22 551.85 .22 551.85 .22 551.85 .22 551.85 .22 551.85 TVD 1200.00 1498 77 1805 O0 2486 46 5655 O0 5697 17 4111 O0 4311 O0 4484 O0 5317 O0 5614.00 5988.00 6118.00 6217.00 6302.00 6386.00 6407.00 6457.00 6477.00 6529.00 6542.00 6608.00 DATA North 0.00 20.73 65.50 158.66 741.86 790.23 1260.97 1488.47 1685.26 2632.80 2970.64 3396.06 5545.94 5656.55 5755.24 5848.79 5872.68 3929.55 5952.50 4011.45 4026.24 4101.51 Eas( 0.00 - 11.09 -33.98 -84.90 -596.95 -422.81 -674.68 -796.40 -901.69 - 1408 66 -1589 42 -1817 O4 -1896 16 -1956.41 -2008 1 4 -2059.27 -2O72.05 -2102.48 -2114.65 -2146.50 -2154.21 -2194.58 V. Sect Deg/ '~ 0.00 0.00 25.51 5.00 72.02 0.00 179.95 0.00 841.38 3.00 896.23 3.00 1430.12 0.00 1688.13 0.00 1911.32 0.00 2985.96 0.00 3369.11 r -~,0 3851.61 0.00 4019.32 0.00 4147.04 0.00 4256.69 0.00 4365.06 0.00 4392.15 0.00 4456.66 0.00 4482.46 0.00 4549.54 0.00 4566.51 0.00 4651.46 0.00 cr~t~ ~ ~ FOR: LLOYD Dote p~tted: 2-~p-1~ P~t R~n~ ~ 14 Vem~ ~ ~at~ am in f~[ ~mn~ s~t ~14. ARCO Alaska, Inc. Strucfure: Pad 1D Well: 14 Field : Kuparuk River Unff L~flon : Nor'fh Slope, Alaska TD LOCATION: 971' FNL, 2493' FWL SEC. 14, T11N, RIOE 2700 2400 I I I TARGET LOCATION: l 1199' FNL, 2615' FWL SEC. 14, TllN, RIOE <- Wesf (feel) 2100 1800 1500 1200 900 I I I I I I I I I TD/4-1/2 Casing Pt Top B Shale Top C1 Top C5 Top C2 Tar§el-Top C4 1D-14 Vet#2 Top Kuporuk D K-1 7 Cosfng Pt-Base HRZ C20 C50 600 500 0 I I I I I I C40 C50 C80 --~ 9-5/8 Casing Pt WesL Sok ~LEOC st Sok Bose Permofrost'~ End of Nudge/"l~--1 Begin Nudge t,.7.,/ 300 42OO 5900 5600 5500 5000 27OO 2400 2100 1800 1500 1200 900 6O0 $00 0 $00 I Z 0 SURFACE LOCATION: 209' FSL, 595' FEL SEC. 14, T11N, RIOE c.~-~e~ ~ ~ FOR: LLOYD ~t~ ~oO, ed: 2-S~-1999 ~[~ ~ in f~ r~ V~o] ~p~. ere ~n= ARCO Alaska, Inc. Structure : Pad 10 Well: 14 Field : Kuparuk River Unit Location : North Slope, Alaska 260 24O 220 200 180 1 $o 14o 120 lOO 80 6O 40 20 20 <- West (feet) 220 200 180 160 140 120 100 80 60 40 20 0 20 40 60 BO 100 40 1aa I I I I I I I I I I I I I I I I lOOO 1500 \ \ \ 2800 ~ \ \ \ 2?00 900 \ 2600 %\ 2500 ~ 2400X 2500~ \ 220~\ 2100 1000 2OOO 800 1100 1500 I I i i i i I 90O 7OO I I I I I ~ I 2300 2400 2200 ! 2500 2100 2000 2200 260 24O 1900 1800 1700 2100 \ 900~,\ 1600 1 \ 18O0 ,~ 1500 \ ,1400 1700~\ 2000 1600X ~1300 \ ~ 499.99 1500 ~, 1400 ~, 500'~ 1900 80~ 220 200 180 160 .~ 1 600 ~ 50C 30 1500 lOOO 14o 120 lOO I Z 0 .iii 8O 60 (13 600 40 20 220 200 180 160 14-0 120 1 O0 80 60 40 20 0 20 40 60 BO 1 O0 20 40 60 80 lOO <- West (feet) c~te~ ~ ~ FOR: LLOYD Date p/at'ced: 2-Sep-19g9 Pl~t R~fer~me ~ 14 V~'an ~12. Coord[nab~ ~'e in ~ ~ ~ ~4. r~ ~a~ ~s are ~ ~ ~1 ARCO Alaska, InC. Structure: Pad 1D Well: 14 Field : Kuparuk Rrver Unit Location : North Slope, Alaska 560 520 840 ~ ~ 800 760 720 680 640 600 560 520 480 440 400 480 I 44O 400 I I I I 2300 560 I I 1500 \ \ \ \ \ 2100 1500 360 $20 ~ 560 520 480 440 400 560 <- West (feet) 320 280 240 200 160 120 80 40 0 40 I I I I I I I I I I I I I I J I I I I I 4700 3700 \ o ~lgoo \ \ \ / ' 1100 \\ ~ ~700 , \ ~ ~ 2700 ~ ~ \~ ~1oo ~ ' V / ..... 80 840 800 760 720 680 64O 6OO 560 52O 480 4O0 360 320 280 240 200 160 ,520 280 240 200 160 120 80 40 0 40 <- West (feet) 120 8O A I Z 0 ANCO Alaska, Inc. Structure : Pad 1D Well: 14 Field : Kuparuk River Unit Location : Nor'th Slope, Alaska 2400 2500 22oo 2100 2000 1900 1800 1700 '~- 1600 1500 0 Z 1400 1300 1200 11oo lOOO 900 800 700 <- West (feet) 1800 1700 1600 1500 1400 1500 1200 1100 1000 gOO 800 700 600 500 400 300 200 I I I I I I I I I I I I I I I I I I I I I I ! I I I I I 2500 1900 I I 1 2100 ~2500 \\ ~ \\~(910 2300 \\\ 2500 ,,~21 O0 \\ ~ 4100~ 1900 O0 500 4300 4100 59o~ 370~ \ 45°° 3900 2100 1900 \ 330~ \ \ \ 6500 6500 6100 5900 1 Ob% 410C \ \ 5700 2900\ 1700 ' \ oo 3O0 [ i I i I i i i i i i i i i I i i i i I I I 1800 1700 1600 1500 1400 1500 1200 1100 1000 900 800 700 600 500 400 500 200 2400 2500 22O0 2100 2000 1900 1800 1700 1600 1500 1400 1500 1200 11oo lOOO 900 800 700 <- West (feet) ~ ~,, FOR: LLOYD Date plotted: 2-Sep-1999 P~ ~ ~ t4 ~'on ~2. ~ ARCO Alaska, Inc. Structure : Pad 1D Well: 14 Field : Kuparuk River Unit Location : North Slope, Alaska 5000 48OO 4600 44OO 4200 40OO 5800 5600 3400 5200 5000 2800 2600 2400 2200 2000 1800 1600 1400 <- West (feet) 3200 $000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 4100 3900 5700 3500 3500 3100 \ ~ \~oo %~oo ~oo ~ ~oo ~oo ? ~o ~oo ~ ~ ~oo ~oo ~ ~~00 ',:900 ~ 5900 k2900 ~ ~ ~ 5700 ~ ~oo 77oo ~oo ~oo 700 ~ k~ 5500 5300 % ~oo ~ % ~ ~300 X ~ 2300 ~2500 % 2700 X X ~ 4900 .......... ~ ............ .~,~,' ~,,, 3200 JO00 2800 26~24~~ 2~ 1~ 1~01400 1200 1000 800riO0 400200 <- West (feet) 5000 4800 4600 4400 4200 4000 3800 $600 34oo 5200 5000 2800 2600 2400 2200 2000 1800 1600 1400 ~ ~,~ FOg: LLOYD Dote p~otted: 2-~-1~ P~[ ~e ~ 14 ~on ~2. PROfILe ..... Pent .....~ Beg~n Nudge 1200,00 E~I ~t NU~ 1500,00 Top ~ ~k ~1 ~11 K-1 ~1~ ~t-T~ ~ 10-1~ ~ r~ C1 ~g7 ARCO Alaska, [nC. Structure : Pad 1D Well: 14 Field : Kuparuk River Unlf Location : North Slope, Alaska COMMENT DATA 35O 34O FRUE NORTH 0 10 2O 330 3O 2700 3O( 2900 4O lO0 ~oo 29O 7O 28C 27~ 26O 1500 + 8O 9O 100 25O 110 120 21 200 190 180 170 160 150 140 130 Normal PlQne TrQvelling Cylinder - Feet All depths shown ore Measured depths on Reference Well ARCO Alaska, Inc. Pad 1D 14 slot #14 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref : 14 Version#2 Our ref : prop2745 License : Date printed : 2-Sep-1999 Date created : 4-Feb-1998 Last revised : 2-Sep-1999 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 18 3.371,w149 30 36.255 Slot Grid coordinates are N 5959873.667, E 560490.261 Slot local coordinates are 209.00 N 595.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad iD, 14 Kuparuk River Unit, North Slope, A1 ~ska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES 0.00 0.00 331.85 0.00 0.00 N 0.00 500.00 0.00 331.85 500.00 0.00 N 0.00 1000.00 0.00 331.85 1000.00 0.00 N 0.00 1200.00 0.00 331.85 1200.00 0.00 N 0.00 1300.00 3.00 331.85 1299.95 2.31 N 1.23 1400.00 6.00 331.85 1399.63 9.22 N 4.94 1500.00 9.00 331.85 1498.77 20.73 N 11.09 1810.05 9.00 331.85 1805.00 63.50 N 33.98 2000.00 9.00 331.85 1992.61 89.70 N 47.99 2500.00 9.00 331.89 2486.~6 158~66 N 84~.9~ 2600.00 12.00 331.85 2584.77 174.73 N 93.49 2700.00 15.00 331.85 2682.00 195.31 N 104.50 2800.00 18.00 331.85 2777.87 220.35 N 117.90 2900.00 21.00 331.85 2872.12 249.78 N 133.65 3000.00 24.00 331.85 2964.50 283.52 N 151.70 PROPOSAL LISTING Page 1 Your ref : 14 Version~P2 Last revised : 2-Sep-1999 Dogleg Vert Deg/lOOft Sect E 0.00 0.00 E 0.00 0.00 E 0.00 0.00 E 0.00 0.00 Begin Nudge W 3.00 2.62 W 3. O0 10.46 W 3.00 23.51 End of Nudge W 0.00 72.02 Base Permafrost _W O. O0 101.73 W 0.00 179.95 Begin Build W 3.00 198.17 W 3.00 221.51 W 3.00 249.91 W 3.00 283.29 W 3.00 321.55 3100.00 27.00 331.85 3054.75 321.47 N 172.01 3200.00 30.00 331.85 3142.62 363.54 N 194.52 3300.00 33.00 331.85 3227.87 409.60 N 219.16 3400.00 36.00 331.85 3310.28 459.54 N 245.88 3500.00 39.00 331.85 3389.60 513.21N 274.60 W 3.00 364.60 W 3.00 412.31 W 3.00 464.55 W 3.00 521.19 W 3.00 582.05 3600.00 42.00 331.85 3465.63 570.47 N 305.23 W 3.00 3700.00 45.00 331.85 3538.16 631.15 N 337.70 W 3.00 3800.00 48.00 331.85 3606.99 695.10 N 371.92 W 3.00 3870.21 50.11 331.85 3653.00 741.86 N 396.93 W 3.00 3900.00 51.00 331.85 3671.93 762.14 N 407.79 W 3.00 3940.64 52.22 331.85 3697.17 790.23 N 422.81 W 3.00 4000.00 52.22 331.85 3733.53 831.60 N 444.95 W 0.00 4500.00 52.22 331.85 4039.85 1180.04 N 631.38 W 0.00 4616.13 52.22 331.85 4111.00 1260.97 N 674.68 W 0.00 4942.59 52.22 331.85 4311.00 1488.47 N 796.40 W 0.00 646.99 715.82 788.35 841.38 Top West Sak 864.38 896.23 EOC 943.15 1338.33 1430.12 Base West Sak 1688.13 9-5/8" Casing Pt 5000.00 52.22 331.85 4346.17 1528.48 N 817.81 W 0.00 1733.51 5224.97 52.22 331.85 4484.00 1685.26 N 901.69 W 0.00 1911.32 C80 5500.00 52.22 331.85 4652.49 1876.92 N 1004.24 W 0.00 2128.69 6000.00 52.22 331.85 4958.82 2225.36 N 1190.67 W 0.00 2523.87 6500.00 52.22 331.85 5265.14 2573.80 N 1377.10 W 0.00 2919.05 6584.66 52.22 331.85 5317.00 2632.80 N 1408.66 W 0.00 2985.96 C50 7000.00 52.22 331.85 5571.46 2922.24 N 1563.53 W 0.00 3314.23 7069.44 52.22 331.85 5614.00 2970.64 N 1589.42 W 0.00 3369.11 C40 7500.00 52.22 331.85 5877.78 3270.68 N 1749.96 W 0.00 3709.41 7679.91 52.22 331.85 5988.00 3396.06 N 1817.04 W 0.00 3851.61 C30 7892.11 52.22 331.85 6118.00 3543.94 N 1896.16 W 0.00 4019.32 C20 8000.00 52.22 331.85 6184.10 3619.13 N 1936.39 W 0.00 4104.59 8053.70 52.22 331.85 6217.00 3656.55 N 1956.41 W 0.00 4147.04 7"Casing Pt-Base HRZ 8192.45 52.22 331.85 6302.00 3753.24 N 2008.14 W 0.00 4256.69 K-1 8329.56 52.22 331.85 6386.00 3848.79 N 2059.27 W 0.00 4365.06 Top Kuparuk D 8363.83 52.22 331.85 6407.00 3872.68 N 2072.05 W 0.00 4392.15 Target-Top C4 1D-12 Ver.#2 8445.45 52.22 331.85 6457.00 3929.55 N 2102.48 W 0.00 4456.66 Top C3 8478.09 52.22 331.85 6477.00 3952.30 N 2114.65 W 0.00 4482.46 Top C2 8500.00 52.22 331.85 6490.42 3967.57 N 2122.82 W 0.00 4499.77 8562.97 52.22 331.85 6529.00 4011.45 N 2146.30 W 0.00 4549.54 Top C1 All data is in feet unless otherwise stated. Coordinates from slot #14 and TVD from RKB Pool ~15 (105.00 Ft above mean sea level). Bottom hole distance is 4651.46 on azimuth 331.85 degrees from wellhead. Total Dogleg for wellpath is 52,22 degrees. Vertical section is from wellhead on azimuth 331.85 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ 'ARCO Alaska, Inc. .. Pad 1D,14 Kuparuk River Unit,North Slope, AlJska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 8584.19 52.22 331.85 6542.00 4026.24 N 2154.21 W 8691.92 52.22 331.85 6608.00 4101.31N 2194.38 W PROPOSAL LISTING Page 2 Your ref: 14 VersionS2 Last revised : 2-Sep-1999 Dogleg Vert Deg/lOOft Sect O. O0 4566.31 Top B Shale 0.00 4651.46 TD/4-1/2" Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #14 and TVD from RKB Pool #6 (105.00 Ft above mean sea level). Bottom hole distance is 4651.46 on azimuth 331.85 degrees from wellhead. Total Dogleg for wellpath is 52.22 degrees. Vertical section is from wellhead on azimuth 331.85 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ A, - ARCO Alaska, Inc. Pad 1D. 14 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 14 VersionS2 Last revised : 2-Sep-1999 Comments in wellpath MD TVD Rectangular Coords. Comment 1200.00 1200.00 1500.00 1498.77 1810.05 1805.00 2500.00 2486.46 3870.21 3653.00 3940.64 3697.17 4616.13 4111.00 4942.59 4311.00 5224.97 4484.00 6584.66 5317.00' 7069.44 5614.00 7679.91 5988.00 7892.11 6118.00 8053.70 6217.00 8192.45 6302.00 8329.56 6386.00 8363.83 6407.00 8445.45 6457.00 8478.09 6477.00 8562.97 6529.00 8584.19 6542.00 8691.92 6608.00 0.00 20.73 63.50 158 66 741 86 790 23 1260 97 1488 47 1685 26 2632 80 2970 64 3396 06 3543 94 3656 55 3753 24 3848 79 3872.68 3929.55 3952.30 4011.45 4026.24 4101.31 N 0.00 E Begin Nudge N 11.09 W End of Nudge N 33.98 W Base Permafrost N 84.90 W Begin Build N 396.93 W Top West Sak N 422.81 W EOC N 674.68 W Base West Sak N 796.40 W 9-5/8"~ ~sing Pt 90~.69 W C80 N 1408.66 W C50 N 1589.42 W C40 N 1817.04 W C30 N 1896.16 W C20 N 1956.41W 7"Casing Pt-Base HRZ N 2008.14 W K-1 N 2059.27 W Top Kuparuk D N 2072.05 W Target-Top C4 1D-12 Ver.#2 N 2102.48 W Top C3 N 2114.65 W Top C2 N 2146.30 W Top C1 N 2154.21 W Top B Shale N 2194.38 W TD/4-1/2" Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 4942.59 4311.00 1488.47N 796.40W 9-5/8" Casing 0.00 0.00 O.OON O.OOE 8053.70 6217.00 3656.55N 1956.41W 7" Casing 0.00 0.00 O.OON O.OOE 8691.92 6608.00 4101.31N 2194.38W 4 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised Target-Top C4 1D-12 558387.000,5963729.000,2.0000 6407.00 3872.68N 2072.05W 2-Sep-1999 ARCO Alaska, Inc. Pad ID 14 slot #14 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 14 Version#2 Our ref : prop2745 License : Date printed : 2-Sep-1999 Date created : 4-Feb-1998 Last revised : 2-Sep-1999 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 18 3.371,w149 30 36.255 Slot Grid coordinates are N 5959873.667, E 560490.261 Slot local coordinates are 209.00 N 595.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <291 - 5795'>,,125,Pad 1D PMSS <0-5126'>,,106,Pad 1D PMSS <0-5047'>,,124,Pad 1D PGMS <O-8930'>,,5,Pad 1D PMSS <256 - 5973'>,,1lO,Pad 1D PMSS <294 - 8250'>,,112,Pad 1D PMSS <290-6245'>,,116,Pad 1D GSS <0-175'>,,116,Pad 1D PMSS <287-6055'>,,123,Pad 1D GSS <0-173'>,,123,Pad 1D PMSS<O-7045'>,,111,Pad 1D PMSS <0 - 6270'>,,114,Pad 1D PMSS <0 - 5445'>, 122,Pad 1D PMSS <0 - 6580'>, 128,Pad 1D PMSS <467 - 5802'> ,132,Pad 1D PMSS <377 - 6224'> ,134,Pad 1D PMSS <0 - 6472'>, 131,Pad 1D PMSS <0 - 7432'>, 127,Pad 1D PMSS <0 - 6716'>, 126,Pad 1D PMSS <0-4530'>,,120,Pad 1D PGMS <O-8070'>,,3,Pad 1D PMSS <0-5142'>,,115,Pad 1D PGMS <O-7502'>,,4,Pad 1D PMSS <O-4778'>,,130,Pad 1D MSS <3311-8200'>,,7,Pad 1D PMSS <0-5015'>,,135,Pad 1D PMSS <1957-5265'>,,133,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 19-Aug-1998 492.2 400.0 400.0 2-Jun-1998 69.6 1344.4 1344.4 2-Jun-1998 471.9 760.0 760.0 13-Nov-1997 449.3 1060.0 1060.0 5-0ct-1998 104.2 800.0 6260.0 21-Sep-1998 172.2 820.0 820.0 17-Sep-1998 272.7 700.0 700.0 8-Sep-1998 284.8 160.0 160.0 13-Sep-1998 420.0 100.0 100.0 4-Sep-1998 420.0 100.0 100.0 3-Sep-1998 141.3 980.0 7420.0 2-Sep-1998 136.0 1377.8 6140.0 29-Aug-1998 405.0 100.0 580.0 17-Aug-1998 539.2 460.0 460.0 6-Aug-1998 645.0 100.0 100.0 3-Aug-1998 719.2 300.0 300.0 23-Ju1-1998 630.0 100.0 100.0 6-Ju1-1998 523.4 300.0 300.0 1-Ju1-1998 508.8 360.0 360.0 2-Jun-1998 369.4 1120.0 1120.0 13-Aug-1998 206.1 1233.3 1233.3 2-Jun-1998 222.8 820.0 4880.0 4-Aug-1992 297.9 1520.0 1520.0 2-Jun-1998 614.9 420.0 420.0 6-Nov-1997 692.0 440.0 440.0 2-Jun-1998 734.3 680.0 680.0 2-Jun-1998 657.1 340.0 340.0 PMSS <0-4850'>,,109, 1D PMSS <0-5205'>,,117,Pad 1D PMSS <0-4515'>.,119,Pad 1D PMSS <0-4414'>,,121,Pad 1D PMSS <0 - 7340'>,,lO,Pad 1D TOTCO Survey,,WS-8,Pad 1D PGMS <0-8365'>,,1,Pad 1D PMSS <381-6092'>,,105,Pad PGMS <0-9783'>,,2,Pad 1D PMSS <556-7024'>,,9,Pad 1D PMSS <293 - 6866'>,,113,Pad 1D PMSS <0 - 7150'>,,108,Pad 1D PGMS <0-8850'> 28-May-81,,MP I 17-II-II,Pad 1D PMSS <0-5462'>,,129,Pad 1D PGMS <0-8610'>,,6,Pad 1D- PMSS <0.4590'>,,118,Pad 1D GMS <0-7780'>,,1,Pad 1C MMS <6948-7570'>,,WSt~24,Pad 1C PMSS <0-11300'>,,11,Pad 1C Unknown Data,,WS1,Pad 1C PMSS <0-8677'>,,13,Pad 1C GMS <O-9700'>,,3,Pad 1C GMS <0-7~3'>,,5,Pad 1C GMS <0-10243'>,,6',Pad 1C GMS <0-9784'>,,7,Pad 1C GMS <O-9600'>,,8,Pad 1C PGMS <0-9002'>,,lOGI,Pad 1C MSS <0-7000'>,,gGI,Pad 1C PMSS <0 - 10969'),,17,Pad 1C GMS <0-7575'>,,4,Pad 1C PMSS <0 - 11918'>,,16,Pad 1C PMSS <0-10980'>,,14,Pad 1C PMSS <0-9390'>,,15,Pad 1C' GMS <0-7615'>,,2,Pad 1C PMSS <0 - 8095'>,,18,Pad 1C PMSS <0-17089'>,,12,Pad 1C PMSS <0-6529'>,,23 PB1,Pad 1C PMSS <1840-13975>,,23A,Pad 1C PMSS <O-10140'>,,25,Pad 1C PMSS <0-14630'>,,26,Pad 1C PMSS <0-13910'>,,27,Pad 1C 2-Jun-1998 92.6 2-Jun-1998 255.7 2-Jun-1998 _ 351.7 2-Jun-1998. 383.3 28-Apr-1998 765.0 11-Jun-1999 805.6 10-Dec-1997 27.7 2-Jun-1998 56.0 4-Aug-1992 67.5 29-Apr-1998 321.5 22-Sep-1998 205.6 28-0ct-1998 80.8 23-Apr-1999 7997.2 2-Jun-1998 599.3 13-Nov-1997 572.0 2-Jun-1998 79.4 11-Mar-1999 7602.8 17-Dec-1997 15578.9 19-Mar-1997 8157.2 2-Nov-1998 10341.3 1-Dec-1998 7766.3 18-Dec:~998 2660.3 18-De~:~I998 7502.2 18-Dec-1998 8170.3 18-Dec-1998 7827.5 18-Dec-1998 6490.3 18-Dec-1998 3629.3 2-Jan-1998 5960.2 2-Dec-1998 7820.6 18-Dec-1998 4739.8 8-Jan-1999 8227.5 18-Mar-1998 8308.1 17-Dec-1998 8173.6 18-Dec-1998 4272.5 22-Feb-1999 6757.4 7-Jan-1998 7701.5 13-Ju1-1999 8138.1 8-Jun-1999 8138.1 4-Jun-1999 7959.1 24-Aug-1999 6968.4 7-Ju1-1999 7977.2 .!040. 920.0 880.0 880.0 100.0 1222.2 980.0 720.0 940.0 1180.0 740.0 700.0 3850.1 300.0 20.0 2120.0 7760.0 8691.9 8160.0 8691.9 7980.0 8691.9 869i.9 7840.0 8691.9 8691.9 7120.0 8691.9 8300.0 8691.9 7480.0 7020.0 7320.0 8691.9 8691.9 7220.0 7069.4 7069.4 7140.0 6740.0 7160.0 5100.0 920.0 1211.1 880.0 100.0 1222.2 4220.0 720 0 940 0 3066 7 6920 0 7560 0 3850 1 300 0 660.0 2120.0 7760.0 8691.9 8560.0 8691.9 8640.0 8691.9 8691.9 8120.0 8691.9 8691.9 7120.0 8691.9 8620.0 8691.9 8478.1 8478.1 7580.0 8691.9 8691.9 7220.0 8100.0 8100.0 8691.9 6740.0 8260.0 ARCO Alaska, Inc. Pad 1D, 14 Kuparuk River Unit,North Slope. Alaska PROPOSAL LISTING Page 1 Your ref : 14 Version #2 Last revised : 2-Sep-1999 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 0,00 0.00 331.85 0.00 0.00 N 0.00 E 500.00 0.00 331,85 500.00 0.00 N 0.00 E 1000.00 0,00 331.85 1000.00 0.0~ N 0.00 E 1200.00 0.00 331.85 1200.00 0.00 N 0.00 E 1300.00 3.00 331.85 1299.95 2.31 N 1.23 W 0.00 0.00 0.00 0.00 N/A 0.00 1.31 1.31 0.75 N/A 0,00 2.61 2.61 1.50 N/A 0.00 3.13 3.13 1.80 N/A 2.62 3,40 3.39 1.95 N/A 1400.00 6.00 331.85 1399.63 9.22 N 4.94 W 1500.00 9.00 331.85 1498.77 20.73 N 11.09 W 1810.05 9.00 331.85 1805.00 63.50 N 33.98 W 2000.00 9.00 331.85 1992.61 89.70 N 47.99 W 2500.00 9.00 331.85 2486.~6 158~66 N 84~.9~ W 10.46 3.70 3.66 2.10 331.85 23.51 4.07 3.93 2.25 331.85 72.02 5.58 4.80 2.73 331.85 101.73 6.51 5.34 3.03 331.85 179.95 9.32 6.80 3.80 331.85 2600.00 12.00 331.85 2584.77 174.73 N 93.49 W 2700.00 15.00 331.85 2682.00 195.31 N 104.50 W 2800.00 18.00 331.85 2777.87 220.35 N 117,90 W 2900.00 21.00 331.85 2872.12 249.78 N 133.65 W 3000.00 24.00 331.85 2964.50 283.52 N 151.70 W 198.17 10.04 7.11 3.96 331.85 221.51 10.92 7.44 4.12 331.85 249.91 11.97 7.78 4.29 331.85 283.29 13.20 8.15 4,48 331.85 321.55 14.63 8.54 4.67 331.85 3100.00 27.00 331.85 3054.75 321.47 N 172.01 W 3200.00 30.00 331.85 3142.62 363.54 N 194.52 W 3300.00 33.00 331.85 3227.87 409.60 N 219.16 W 3400.00 36.00 331.85 3310.28 459.54 N 245.88 W 3500.00 39,00 331.85 3389.60 513.21 N 274.60 W 364.60 16.27 8.95 4.89 331.85 412.31 18.13 9.38 5.13 331.85 464.55 20.21 9.83 5.40 331.85 521.19 22.53 10.29 5.70 331.85 582.05 25.09 10.77 6,05 331.85 3600.00 42.00 331.85 3465.63 570.47 N 305.23 W 3700.00 45.00 331.85 3538.16 631.15 N 337.70 W 3800.00 48,00 331.85 3606.99 695.10 N 371.92 W 3870.21 50.11 331.85 3653.00 741.86 N 396.93 W 3900.00 51.00 331.85 3671.93 762,14 N 407.79 W 646.99 27.89 11.26 6,44 331.85 715.82 30,93 11.76 6.88 331.85 788.35 34.20 12.26 7.37 331.85 841.38 36.67 12,62 7.76 331.85 864.38 37.71 12.76 7.93 331.85 3940.64 52.22 331.85 3697.17 790.23 N 422.81 W 4000.00 52.22 331.85 3733.53 831.60 N 444.95 W 4500.00 52.22 331.85 4039.85 1180.04 N 631.38 W 4616.13 52.22 331.85 4111.00 1260.97 N 674.68 W 4942.59 52.22 331.85 4311.00 1488.47 N 796,40 W 896.23 39.18 12.97 8.16 331.85 943.15 41.33 13.26 8.52 331.85 1338.33 59.73 15.81 11.64 331.85 1430.12 64.06 16.41 12.41 331.85 1688,13 76,23 18.11 14.54 331.85 5000.00 52.22 331.85 4346.17 1528.48 N 5224.97 52.22 331.85 4484,00 1685.26 N 5500.00 52.22 331.85 4652,49 1876.92 N 6000.00 52.22 331.85 4958.82 2225.36 N 6500.00 52.22 331.85 5265.14 2573.80 N 817.81W 1733.51 78,37 18.41 14.92 331.85 901.69 W 1911.32 86.81 19.59 16.42 331.85 1004,24 W 2128.69 97.11 21.03 18.26 331.85 1190.67 W 2523.87 115.91 23.68 21.64 331.85 1377.10 W 2919.05 134.73 26.35 25.04 331.85 6584.66 52.22 331.85 5317.00 2632.80 N 7000.00 52.22 331.85 5571.46 2922.24 N 7069.44 52.22 331.85 5614.00 2970.64 N 7500.00 52.22 331.85 5877,78 3270.68 N 7679.91 52.22 331.85 5988.00 3396,06 N 1408.66 W 2985.96 137.92 26,80 25.62 1563.53 W 3314.23 153.57 29.02 28.46 1589.42 W 3369,11 156.19 29.40 28.93 1749.96 W 3709.41 172.43 31.71 31.88 1817,04 W 3851.61 179.21 32.68 33.12 331.85 331.85 331.85 331.85 331.85 7892.11 52.22 331.85 6118.00 3543.94 N 8000.00 52.22 331.85 6184.10 3619.13 N 8053.70 52.22 331,85 6217,00 3656.55 N 8192.45 52.22 331.85 6302.00 3753.24 N 8329.56 52.22 331.85 6386.00 3848.79 N 1896,16 W 4019.32 187.22 33.82 34.57 331.85 1936.39 W 4104.59 191.29 34.40 35.31 331.85 1956.41W 4147.04 193.32 34.69 35.68 331.85 2008.14 W 4256.69 198.55 35.43 36.64 331.85 2059.27 W 4365.06 203.73 36.17 37.58 331.85 8363.83 52.22 331.85 6407.00 3872.68 N 2072.05 W 4392.15 205.02 36.36 37.81 331.85 8445.45 52.22 331.85 6457.00 3929.55 N 2102.48 W 4456.66 208.10 36.80 38.38 331.85 8478.09 52.22 331.85 6477.00 3952.30 N 2114.65 W 4482.46 209.33 36.97 38.60 331.85 8500.00 52.22 331.85 6490.42 3967.57 N 2122.82 W 4499.77 210.16 37.09 38.75 331.85 8562.97 52.22 331.85 6529.00 4011.45 N 2146.30 W 4549.54 212.54 37.43 39.18 331.85 All data is in feet unless otherwise stated. Coordinates from slot #14 and TVD from RKB Pool ~6 (105.00 Ft above mean sea level). Bottom hole distance is 4651.46 on azimuth 331.85 degrees from wellhead. Vertical section is from wellhead on azimuth 331.85 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ - ARCO Alaska, Inc. Pad 1D, 14 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 14 Version#2 Last revised : 2-Sep-1999 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 8584.19 52.22 331.85 6542.00 4026.24 N 8691.92 52.22 331.85 6608.00 4101.31N 2154.21 W 4566.31 213.34 37.55 39.33 331.85 2194.38 W 4651.46 217.41 38.13 40.07 331.85 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. '~ ............................................. 8692 ARCp (H~A. Mag) ~'~ ........ User~ ..... specified~'"~ ............................... 217.41 38.13 40.07 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. All data is in feet unless otherwise stated. Coordinates from slot #14 and TVD from RKB Pool ~6 (105.00 Ft above mean sea level). Bottom hole distance is 4651.46 on azimuth 331.85 degrees from wellhead. Vertical section is from wellhead on azimuth 331.85 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska. Inc. Pad ID, 14 Kuparuk River Unit,North Slope, A1 aska PROPOSAL LISTING Page 3 Your ref : 14 Version#2 Last revised : 2-Sep-1999 Comments in wellpath MD TVD Rectangular Coords~ Comment 1200.00 1200.00 0.00 N 0.00 E Begin Nudge 1500.00 1498.77 20.73 N 11. 1810.05 1805.00 63.50 N 33. 2500.00 2486.46 158.66 N 84. 3870.21 3653.00 741.86 N 396. 3940.64 3697.17 790.23 N 422. 4616.13 4111.00 1260.97 N 674. 4942.59 4311.00 1488.47 N. 796 5224.97 4484.00~ 1685.26 N 901 6584.66 5317.00 2632.80 N 1408 7069.44 5614.00 2970.64 N 1589 7679.91 5988.00 3396.06 N 1817 7892.11 6118.00 3543.94 N 1896 8053.70 6217.00 3656.55 N 1956 8192.45 6302.00 3753.24 N 2008 8329.56 6386.00 3848.79 N 2059 8363.83 6407.00 3872.68 N 2072 8445.45 6457.00 3929.55 N 2102 8478.09 6477.00 3952.30 N 2114 8562.97 6529.00 4011.45 N 2146 8584.19 6542.00 4026.24 N 2154 8691.92 6608.00 4101.31 N 2194 09 W End of Nudge 98 W Base Permafrost 90 W Begin Build 93 W Top West Sak 81 W EOC 68 W Base West Sak 40 W 9-5/8"~ ¢~sing Pt 69 W C80 66 W C50 42 W C40 O4 W C30 16 W C20 41 W 7"Casing Pt-Base HRZ 14 W K-1 27 W Top Kuparuk D 05 W Target-Top C4 1D-12 Ver.~2 48 W Top C3 65 W Top C2 30 W Top C1 21 W Top B Shale 38 W TD/4-1/2" Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 4942.59 4311.00 1488.47N 796.40W 9-5/8" Casing 0.00 0.00 O.OON O.OOE 8053.70 6217.00 3656.55N 1956.41W 7" Casing 0.00 0.00 O.OON O.OOE 8691.92 6608.00 4101.31N 2194.38W 4 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised Target-Top C4 1D-12 558387.000,5963729.000,2.0000 6407.00 3872.68N 2072.05W 2-Sep-1999 ARCO Alaska, Inc, . PROPOSAL Pad 1D,14 Your Kuparuk River Unit,North Slope, Alaska Last revi Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S Dogleg Vert Deg/lOOft Sect 0,00 0,00 331,85 0,00 O,OON O,OOE 0,00 0,00 500,00 0,00 331,85 500,00 O,OON O.OOE 0.00 0,00 1000,00 0.00 331,85 1000,00 O,OON O,OOE 0.00 0,00 1200,00 0,00 331,85 1200,00 O,OON O,OOE 0,00 0.00 1300.00 3,00 331,85 1299,95 2,31N 1,23W 3,00 2,62 LISTING Page 1 ref : 14 Version ~2 sed : 2-Sep-1999 GR I D C OORDS Easting Northing 560490,26 5959873,67 560490.26 5959873,67 560490,26 5959873,67 560490,26 5959873,67 560489,01 5959875,96 1400,00 6,00 331,85 1399,63 9,22N 4,94W 3,00 10,46 560485,25 5959882,85 1500,00 9,00 331,85 1498,77 20,73N 11,09W 3,00 23,51 560479,00 5959894,31 1810,05 9,00 331,85 1805,00 63,50N 33,98W 0,00 72,02 560455,77 5959936,88 2000,00 9,00 331,85 1992,61 89,70N 47,~!W ' 0,00 101,73 560441,54 5959962,96 2500,00 9,00 331,8~ 2486,~6 158,66N 8~i~OW 0,00 179,95 560404,09 5960031,62 2600,00 12,00 331,85 2584,77 ' 174,73N 93,49W 3,00 198,17 560395,36 5960047,61 2700,00 15,00 331,85 2682,00 195,31N 104,50W 3,00 221,51 560384,18 5960068,10 2800,00 18,00 331,85 2777,87 220,35N 117,90W 3,00 249,91 560370,58 5960093,03 2900,00 21,00 331,85 2872,12 249,78N 133,65W 3.00 283,29 560354,60 5960122,33 3000,00 24,00 331,85 2964,50 283,52N 151,70W 3,00 321,55 560336,28 5960155,91 3100,00 27,00 331,85 3054,75 321,47N 172.01W 3,00 364,60 560315,66 5960193,70 3200,00 30,00 331,85 3142,62 363,54N 194,52W 3,00 412,31 560292.82 5960235,58 3300.00 33.00 331.85 3227,87 409,60N 219,16W 3,00 464,55 560267,80 5960281,44 3400,00 36,00 331,85 3310,28 459,54N 245,88W 3,00 521.19 560240,68 5960331,15 3500.00 39,00 331,85 3389,60 513,21N 274,60W 3,00 582,05 560211,53 5960384,58 3600,00 42.00 331,85 3465,63 570,47N 305,23W 3,00 646,99 560180,43 5960441,58 3700,00 45,00 331,85 3538,16 631,15N 337,70W 3,00 715,82 560147.47 5960501,99 3800,00 48,00 331,85 3606,99 695,10N 371,92W 3,00 788,35 560112,74 5960565,66 3870,21 50,11 331,85 3653,00 741,86N 396,93W 3,00 841.38 560087,35 5960612,20 3900,00 51.00 331,85 3671,93 762,14N 407,79W 3.00 864,38 560076,33 5960632,40 3940,64 52,22 331,85 3697,17 790,23N 422,81W 3,00 896,23 560061,08 5960660,36 4000,00 52.22 331,85 3733,53 831,60N 444,95W 0.00 943,15 560038,61 5960701,54 4500,00 52,22 331,85 4039,85 1180,04N 631,38W 0.00 1338,33 559849,37 5961048,42 4616,13 52,22 331,85 4111,00 1260,97N 674,68W 0,00 1430,12 559805,42 5961128,99 4942,59 52,22 331,85 4311,00 1488,47N 796,40W 0,00 1688,13 559681,86 5961355,47 5000,00 52,22 331,85 4346,17 1528,48N 817.81W 0.00 1733.51 559660.13 5961395,30 5224,97 52,22 331.85 4484,00 1685,26N 901,69W 0,00 1911.32 559574,99 5961551,38 5500,00 52,22 331,85 4652,49 1876,92N 1004,24W 0.00 2128,69 559470,90 5961742,18 6000,00 52,22 331,85 4958,82 2225,36N 1190,67W 0,00 2523,87 559281.66 5962089,06 6500,00 52,22 331,85 5265,14 2573,80N 1377,10W 0,00 2919,05 559092,42 5962435,94 6584,66 52,22 331,85 5317,00 2632,80N 1408,66W 0,00 2985,96 559060,38 5962494,67 7000,00 52,22 331,85 5571,46 2922,24N 1563,53W 0,00 3314,23 558903,18 5962782,82 7069,44 52,22 331.85 5614,00 2970,64N 1589,42W 0,00 3369,11 558876,90 5962831,00 7500,00 52,22 331,85 5877,78 3270,68N 1749,96W 0,00 3709.41 558713,94 5963129,70 7679.91 52,22 331,85 5988,00 3396,06N 1817,04W 0,00 3851,61 558645,85 5963254,52 7892,11 52,22 331,85 6118,00 3543,94N 1896,16W 0,00 4019,32 558565,54 5963401,73 8000,00 52,22 331,85 6184,10 3619,13N 1936,39W 0.00 4104,59 558524,70 5963476,59 8053,70 52,22 331,85 6217,00 3656,55N 1956,41W 0,00 4147,04 558504,38 5963513,84 8192,45 52.22 331.85 6302,00 3753,24N 2008,14W 0,00 4256,69 558451,87 5963610,10 8329.56 52.22 331,85 6386,00 3848,79N 2059.27W 0.00 4365.06 558399.97 5963705,22 8363,83 52,22 331,85 6407,00 3872,68N 2072,05W 0,00 4392,15 558387,00 5963729,00 8445,45 52.22 331,85 6457,00 3929,55N 2102,48W 0,00 4456.66 558356,11 5963785,62 8478.09 52,22 331,85 6477,00 3952,30N 2114.65W 0,00 4482.46 558343,76 5963808,27 8500,00 52,22 331,85 6490,42 3967,57N 2122,82W 0,00 4499,77 558335,46 5963823,47 8562,97 52.22 331,85 6529,00 4011,45N 2146,30W 0,00 4549,54 558311,63 5963867,15 All data in feet unless otherwise stated, Calculation uses minimum curvature method, Coordinates from slot #14 and TVD from RKB Pool #6 (105,00 Ft above mean sea level), Bottom hole distance is 4651.46 on azimuth 331,85 degrees from wellhead, Total Dogleg for wellpath is 52,22 degrees, Vertical section is from wellhead on azimuth 331,85 degrees. Grid is alaska - Zone 4, Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Wughe$ INTEQ .... -ARCO Alaska, Inc. Pad 1D, 14 ' Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 14 Version Last revised : 2-Sep-1999 Measured Inclin Azimuth True Vert R E C TAN G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 8584.19 52.22 331.85 6542.00 4026.24N 2154.21W 0.00 4566.31 558303.60 5963881.88 8691.92 52.22 331.85 6608.00 4101.31N 2194.38W 0.00 4651.46 558262.83 5963956.61 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #14 and TVD from RKB Pool #6 (105.00 Ft above mean sea level). Bottom hole distance is 4651.46 on azimuth 331.85 degrees from wellhead. Total Dogleg for wellpath is 52.22 degrees. Vertical section is from wellhead on azimuth 331.85 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ' ARCO Alaska, Inc. Pad 1D, 14 Kuparuk River Unit, North Slope, A1 ~ska PROPOSAL LISTING Page 3 Your ref : 14 Version#2 Last revised : 2-Sep-1999 Comments in wel 1 path MD TVD Rectangul ar Coords. Co~ent 1200.00 1200.00 000N O,OOE Begin Nudge 1500.00 1810.05 2500.00 3870.21 3940.64 4616.13 4942.59 5224.97 6584 66 7069 44 7679 91 7892 11 8053 70 8192 45 8329 56 8363 83 8445 45 8478 09 8562.97 8584.19 8691.92 1498 77 1805 O0 2486 46 3653 O0 3697 17 4111 O0 4311 O0 4484 O0 5317.00' 5614.00 5988.00 6118.00 6217.00 6302.00 6386.00 6407.00 6457.00 6477.00 6529.00 6542.00 6608.00 20 73N 63 50N 158 66N 741 86N 790 23N 1260 97N 148847N 1685.26N" 2632.80N 2970.64N 3396.06N 3543.94N 3656.55N 3753.24N 3848.79N 3872.68N 3929.55N 3952.30N 4011.45N 4026.24N 4101.31N 11.09W End of Nudge 33.98W Base Permafrost 84.90W Begin Build 396.93W Top West Sak 422.81W EOC 674.68W Base West Sak 796.40W 9-5/8".~.~asing Pt . 9~1.69W C80 1408.66W C50 1589.42W C40 1817.04W C30 1896.16W C20 1956.41W 7"Casing Pt-Base HRZ 2008.14W K-1 2059.27W Top Kuparuk D 2072.05W Target-Top C4 1D-12 Ver.#2 2102.48W Top C3 2114.65W Top C2 2146.30W Top C1 2154.21W Top B Shale 2194.38W TD/4-1/2" Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 4942.59 4311.00 1488.47N 796.40W 9-5/8" Casing 0.00 0.00 O.OON O.OOE 8053.70 6217.00 3656.55N 1956.41W 7" Casing 0.00 0.00 O.OON O.OOE 8691.92 6608.00 4101.31N 2194.38W 4 1/2" Casing Targets associated with this wellpath Target name Geographic Locati on T.V.D. Rectangul ar Coordi nates Revised ...... ..... ....... ARCO Alaska, Inc. Diverter Schematic Pool #6 Flowline 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. POOL #6 13-5/8" 5,000 PSI BOP COMPONENTS L 3" 5,000 psi WP OCT ~J MANUAL GATE V KILL LINE ~r~ 3" 5,000 psi WP Shaffer GATE VALVE I w/hydraulic actuator E~ / I / DSA 13-5/8" 5,000 psi WP '"'~L x 11" 3,000 psi WP \ r-I 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi WP Shaffer GATE VALVE ~J [~Tl~lraulic actuator ~_~,~._L~ ~0 psiwC~oOcKTE LINE 13-5/8" 5,000 psi WP DRILLING SPOOL w/two 3" 5M psi WP outlets I J SINGLE 13-5/8" 5,000 psi WP, I HYDRIL MPL BOP w/pipe rams ARCO Alaska, Inc. ALPINE DISBURSEMENT ACCOUNT P.O. Box 103240 Anchorage, AK 99510-3240 PAY TO THE ORDER OF: CHECK NUMBER 249004856 73-426 839 0990337 JULY 22, 1999 ALASKA DEPT ALASKA..~...., ,~,.,-OIL'& 'GAS~...cONSERVATION COMMI 300 1: : :: :. : :. ~':, ~:~ .: ,,,: ,,. ::'~:: :'"':':~: .":~ O CENTS : : .: EXACTLY ***:*~***~**~IO0'DOLLARS AND~O: ': ********************* ',.::: ~: :~ :.~ :3: :, ']:: : :~. ~.. . .. The First NatiOnal: j Bank of Chicago-0710 ~:.]~,,;' ~ , : Payable Through Republic Bank Shelbyville, Kentucky TRACE NUMBER: 249004856 ,' 8h qooh8 SF=u' ~-'08 ~,qoh 8F= 8,,' oqqo ~, ~ ?,' WELL PERMIT CHECKLIST __ dev X~' redrll serv ~ wellbore seg ann. disposal para req ~ FIELD & POOL COMPANY ,,~,' ~ WELL NAME/~/'/Z~) ---/,~¢' PROGRAM: exp INIT CLASS GEOL AREA ADMINISTRATION N ENGINEERING 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... (~ 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 ........ ..)c,~ N 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... ~/rd'~ 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... ~ N 25. BOPEs, do they meet regulation ................ ,,~ N 26. BOPE press rating appropriate; test to ~t[~ psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... .~ N 29. Is presence of H2S gas probable ................. ~ N GEOLOGY ANNULAR DISPOSAL APPR DATE UNIT# ,,////"_,~r~ ON/OFF SHORE 30. 31. 32. 33. 34. 35. With proper cementing records, this plan /~~ (~g~r,~.,~-c~ (A) will contain waste in a suitable receiving zone; ....... Y (B) will not contaminate freshwater; or cause ddlling waste... Y to surface; (C) will not impair mechanical integrity of the well used for disposal; Y (D) will not damage producing formation or impair recovery from a Y pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y Permit can be issued w/o hydrogen sulfide measures ..... Y~NN ~ YY N // Data presented on potential overpressure zones ....... Y Seismic analysis of shallow gas zones ............. Y. N Seabed condition survey (if off-shore) ............. Contact name/phone for weekly progress reports [exploratory~ly] Y N ',,.o,..;z.J_ ,, / N N GEOLO.,C.-r~(: ENGIN E~E/~I.N~: UIC/Annular COMMISSION: RPC, WU-, " JDH~ _~ - CO Comments/Instructions: c:\msoffice\wordian\diana\checklist Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX.' No special 'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Dec 16 02:43:29 1999 Reel Header Service name ............. LISTPE Date ..................... 99/12/16 Origin ................... STS Reel Name ................ UNK/COWN Continuation Number ...... 01 Previous Reel Name ....... UNKI~OWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 99/12/16 Origin ................... STS Tape Name ................ UNK/~OWN Continuation Number ...... 01 Previous Tape Name ....... UNKI~OWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER kTJPA_RUK RIVER UNIT MWD/MAD LOGS WELL NAME: API N-UMBER: 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: MWD RUN 3 AK-MM-90158 B. HENNINGSE M. WINFREE 1D-14 500292295000 ARCO ALASKA, Sperry Sun 16-DEC-99 MWD RUN 4 AK-MM-90158 G. GRIFFIN M. WINFREE lin 10E 209 595 .00 INC. MWD RUN 5 AK-MM-90158 G. GRIFFIN M. WINFREE RECEIVED !":,?C '/6 1999 chora DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 104.61 70.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 16.000 115.0 12.250 9.625 4939.0 8.500 7.000 8068.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-2 A_RE DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUNS 3-4 A_RE DIRECTIONAL WITH DUAL GA_MMA P~AY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS. 4. MWD RUN 5 IS DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN) , AND STABLILZED LITHO-DENSITY (SLD). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE EMAIL FROM D. SCHWA_RTZ OF ARCO ALASKA, INC. ON 12/14/99. MWD DATA IS CONSIDERED PDC. 6. MWD RUNS 1-5 REPRESENT WELL 1D-14 WITH API#: 50-029-22950-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8702'MD, 6635'TVD. SROP = SMOOTHED R_ATE OF PENETP~ATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED COMPENSATED THERMAL NEUTRON POROSITY (SS MATRIX, FIXED HOLE SI CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY COMPENSATED (BEST BIN). SC02 = SMOOTHED STANDOFF CORRECTION (BEST BIN). SNP2 = SMOOTHED NE~LR DETECTOR ONLY PHOTOELECRTIC ABSORPTION FACTOR. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 10.6 - 10.9 PPG MUD SALINITY: 650 PPM CHLORIDES FORMATION WATER SALINITY: 13000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP NCNT FCNT NPHI FET RPD RPM RPS RPX PEF DRHO RHOB $ BASELINE CURVE FOR SHIFTS: Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 START DEPTH 4874.5 4947 0 8060 0 8060 0 8060 0 8060 0 8060 0 8060 0 8060 0 8060 0 8065 5 8065 5 8065 5 CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD STOP DEPTH 8648 0 8702 0 8610 5 8610 5 8610 5 8655 0 8655 0 8655 0 8655 0 8655 0 8626 5 8626 5 8626 5 EQUIVALENT UNSHIFTED DEPTH ...... BIT RUN NO MERGE TOP MERGE BASE 300 4946.0 6290.0 400 6290.0 8077.0 MWD $ REMARKS: 500 8077.0 8702.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Do~rn Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD PU-S 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 4874.5 8702 ROP MWD FT/H 0 359.24 GR MWD API 30.96 569.95 RPX MWD OHMM 1.2 640.29 RPS MWD OHMM 1.02 623.23 RPM MWD OHMM 0.78 2000 RPD MWD OHMM 0.92 2000 FET MWD HOUR 0.48 45.68 NPHI MWD PU-S 11.47 60.33 FCNT MWD CNTS 109.42 1266.62 NCNT MWD CNTS 13732.8 39583.6 RHOB MWD G/CM 1.98 3.07 DRHO MWD G/CM -0.13 0.23 PEF MWD BAJAN 2.48 11.63 Mean Nsam 6788.25 7656 129.649 7511 131.643 7548 6.20323 1191 6.30475 1191 23.6105 1191 13.8993 1191 2.08364 1191 34.7305 1102 351.88 1102 22359.8 1102 2.42817 1123 0.0556367 1123 5.83336 1123 First Reading 4874.5 4947 4874.5 8060 8060 8060 8060 8060 8060 8060 8060 8065.5 8065.5 8065.5 Last Reading 8702 8702 8648 8655 8655 8655 8655 8655 8610 5 8610 5 8610 5 8626 5 8626 5 8626 5 First Reading For Entire File .......... 4874.5 Last Reading For Entire File ........... 8702 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/16 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4874.5 6250.0 ROP 4947.0 6292.0 $ LOG HEADER DATA DATE LOGGED: 28-SEP-99 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWN-HOLE SOFTWARE VERSION: 630.9 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 6290.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 51.2 MAXIMUM ANGLE: 54.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P1362HGV6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 8.500 Water Based 9.10 49.0 8.8 4OO 7.6 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 API 4 1 68 8 3 .0 97.6 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 4874.5 6292 5583.25 2836 ROP MWD 3 FT/H 0 359.24 167.084 2691 GR MWD 3 API 41.49 173.89 99.6666 2752 First Reading 4874.5 4947 4874.5 Last Reading 6292 6292 6250 First Reading For Entire File .......... 4874.5 Last Reading For Entire File ........... 6292 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6250.5 8034.0 ROP 6293.0 8076.5 $ LOG HEADER DATA DATE LOGGED: 30-SEP-99 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 630.9 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 8077.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 50.7 MAXIMUM ANGLE: 53.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P1362HGV6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STA1W-DOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Water Based 9.10 46.0 9.0 450 7.2 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 4 FT/H 4 1 68 4 2 GR MWD 4 API 4 1 68 8 3 .0 111.6 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 6250.5 8076.5 7163.5 3653 ROP MWD 4 FT/H 0.3 321.94 115.048 3568 GR MWD 4 API 65.55 569.95 165.748 3568 First Reading 6250.5 6293 6250.5 Last Reading 8076.5 8076.5 8034 First Reading For Entire File .......... 6250.5 Last Reading For Entire File ........... 8076.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR NCNT FCNT NPHI FET RPD RPM RPS RPX DRHO RHOB PEF ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 7986 0 8060 0 8060 0 8060 0 8060 0 8060 0 8060 0 8060 0 8060 0 8065 5 8065 5 8065.5 8077.0 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 STOP DEPTH 8648.0 8610.5 8610 5 8610 5 8655 0 8655 0 8655 0 8655 0 8655 0 8626 5 8626 5 8626 5 8702 0 03-0CT-99 Insite 041 Memory 8702.0 MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MI/D CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 50.1 51.5 TOOL NUMBER P1367NLM4 P1367NLM4 P1367NLM4 P1367NLM4 6. 125 Water Based 11.10 54.0 9.0 450 4.4 2.000 1. 120 1.900 2.100 69.0 126.4 69.0 69.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 5 FT/H 4 1 68 4 2 GR MWD 5 API 4 1 68 8 3 RPX MWD 5 OHMM 4 1 68 12 4 RPS MWD 5 OHMM 4 1 68 16 5 RPM MWD 5 RPD MWD 5 FET MWD 5 NPHI MWD 5 FCNT MWD 5 NCNT MWD 5 RHOB MWD 5 DRHO MWD 5 PEF MWD 5 OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 20 24 28 32 36 40 44 48 52 6 7 8 9 10 11 12 13 14 Name Service Unit DEPT FT ROP MWD 5 FT/H GR MWD 5 API RPX MWD 5 OHMM RPS MWD 5 OHMM RPM MWD 5 OHMM RPD MWD 5 OHMM FET MWD 5 HOUR NPHI MWD 5 PU-S FCNT MWD 5 CNTS NCNT MWD 5 CNTS RHOB MWD 5 G/CM DRHO MWD 5 G/CM PEF MWD 5 BARN Min 7986 0 30.96 1.2 1 02 0 78 0 92 0 48 11 47 109 42 13732.8 1.98 -0.13 2.48 Max 8702 336.17 251.59 640.29 623.23 2000 2000 45.68 60.33 1266.62 39583.6 3.07 0.23 11.63 Mean Nsam 8344 1433 90.8734 1251 104.264 1230 6.20323 1191 6.30475 1191 23.6105 1191 13.8993 1191 2.08364 1191 34.7305 1102 351.88 1102 22359.8 1102 2.42817 1123 0.0556367 1123 5.83336 1123 First Reading 7986 8077 7986 8060 8060 8060 8060 8060 8060 8060 8060 8065.5 8065.5 8065.5 Last Reading 8702 8702 8648 8655 8655 8655 8655 8655 8610 5 8610 5 8610 5 8626 5 8626 5 8626 5 First Reading For Entire File .......... 7986 Last Reading For Entire File ........... 8702 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/12/16 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 99/12/16 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
