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Home My WebLink About203-091CAUTION: 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:McLellan, Bryan J (OGC) To:Stefan Reed Cc:Donna Ambruz Subject:RE: CLU-07 - Fox Coil Unit Test Date:Tuesday, September 23, 2025 1:25:00 PM Attachments:image001.png Stefan, Confirmed, no sundry, no BOP test and no other AOGCC reporting requirements for this operation. Regards Bryan From: Stefan Reed <stefan.reed@hilcorp.com> Sent: Tuesday, September 23, 2025 1:01 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: CLU-07 - Fox Coil Unit Test Bryan, As discussed, Fox would like to use a well to confirm the new coil unit (Unit #1) is fully operational before the next operation. This would involve running coil in and out of hole to confirm the injector and all surface equipment is functioning properly. We plan to use CLU-07 as the test well which has no open perforations and two tested plugs. I have attached the schematic and job reports for your review. I would like to confirm that this operation does not require any sundry, BOP test, or any other reporting requirements to the state. Thanks for your time. Regards, Stefan Reed Operations Engineer Kenai Asset Team Cell: 206-518-0400 Hilcorp Alaska, LLC The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 2025-0331_Surface_Abandon_KRU 3S-03_ae Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 4-1-2025 P. I. Supervisor FROM: Adam Earl SUBJECT: Surface Abandonment Petroleum Inspector KRU 3S-03 CPAI PTD 2030910 Sundry 323-622 March 31, 2025: I traveled to KRU 3S-03 to inspect the surface abandonment marker plate and cut-off. All strings had good, set-up cement. The well was cut off at 9.5 feet below tundra grade. The correct information was verified and welded on the marker plate nicely. Approval was given to weld on the plate and bury the well. Attachments: Photos (3) 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.05.01 15:29:10 -08'00' 2025-0331_Surface_Abandon_KRU 3S-03_ae Page 2 of 3 Surface Abandonment – KRU 3S-03 (PTD 2030910) Photos by AOGCC Inspector A. Earl 3/31/2025 2025-0331_Surface_Abandon_KRU 3S-03_ae Page 3 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 18 Township: 12N Range: 8E Meridian: Umiat Drilling Rig: n/a Rig Elevation: n/a Total Depth: 7,970 ft MD Lease No.: ADL 0380107 Operator Rep: Suspend: P&A: X Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 9-5/8" O.D. Shoe@ 3,107 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 7960 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3-1/2" O.D. Tail@ 7,543 Feet Tbg Cut@ 7,340 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bridge plug 5,156 ft 3,027 ft 8.6 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1700 1600 1560 IA 1700 1600 1560 OA 100 100 100 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Intermediate plug on KRU 3S-03 for a P&A. The 3 1/2-inch tubing has been cut and removed. Slickline ran in the hole with a 2 1/2-inch drive down bailer, oil jars, spangs, and a 10-ft piece of 1 7/8-inch weight pipe for a tool string length of 33 ft and roughly a 150 LBS. Good solid tag at 3,027 ft MD - no change in depth after pounding on it with several hard hits. Returned a good cement sample back. Passing MIT: 1.4 bbls pumped and 1.4 bbls returned. January 18, 2025 Josh Hunt Well Bore Plug & Abandonment KRU 3S-03 ConocoPhillips Alaska Inc. PTD 2030910; Sundry 323-622 none Test Data: P Casing Removal: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0118_Plug_Verification_KRU_3S-03_jh 9 9 9 9 9 9 9 9 9 99 9 9 9 9 99 9 9 999 9 99 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.02.03 14:39:40 -09'00' Originated: Delivered to:7-Nov-24 Alaska Oil & Gas Conservation Commiss 07Nov24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 3S-03 50-103-20458-00-00 203-091 Kuparuk River WL IBC-CBL FINAL FIELD 10-Oct-24 2K-19A 50-103-20118-01-00 211-034 Kuparuk River WL Cutter FINAL FIELD 11-Oct-24 MT7-83 50-103-20891-01-00 224-102 Greater Mooses Tooth WL TTiX-USIT-CBL FINAL FIELD 19-Oct-24 1C-157 50-029-23754-00-00 223-038 Kuparuk River WL IBC-CBL FINAL FIELD 23-Oct-24 CD1-33A 50-103-20357-01-00 222-105 Colville River WL PERF FINAL FIELD 30-Oct-24 MT7-09 50-103-20837-00-00 222-011 Greater Mooses Tooth WL TTiX-Plug&Perf FINAL FIELD 1-Nov-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39755 T39756 T39757 T39758 T39759 T39760 3S-03 50-103-20458-00-00 203-091 Kuparuk River WL IBC-CBL FINAL FIELD 10-Oct-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.08 08:38:26 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:18 Township:12N Range:8E Meridian:Umiat Drilling Rig:n/a Rig Elevation:n/a Total Depth:7,970 ft MD Lease No.:ADL0380107 Operator Rep:Suspend:P&A:X Conductor:16"O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface:9 5/8"O.D. Shoe@ 3107 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 7960 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3 1/2"O.D. Tail@ 7543 Feet Tbg Cut@ 7340 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bridge plug 5,162 ft MD 4,714 ft MD 8.6 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1800 1700 1610 1570 IA 1800 1700 1610 1570 OA 90 90 90 90 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Plug back for redrill. Slickline tagged good cement at 4,714 ft MD., Tubing cut at 7,340 ft MD. Pre-test pressures: Tbg and IA = ZERO; OA = 50psi. 3bbls in / 3 bbls back. August 21, 2024 Brian Bixby Well Bore Plug & Abandonment KRU 3S-03 Conoco Phillips Alaska Inc. PTD 2030910; Sundry 232-622 none Test Data: P Casing Removal: John Hansen Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-0821_Plug_Verification_KRU_3S-03_bb                 Originated: Delivered to:22-Jul-24 Alaska Oil & Gas Conservation Commiss 22Jul24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 3S-03 50-103-20458-00-00 203-091 Kuparuk River WL Perf FINAL FIELD 27-Jun-24 CD2-45 50-103-20395-00-00 201-212 Colville River WL Patch FINAL FIELD 8-Jul-24 CD1-40 50-103-20298-00-00 199-044 Colville River WL LDL FINAL FIELD 10-Jul-24 CD4-24 50-103-20602-00-00 209-097 Colville River WL LDL FINAL FIELD 11-Jul-24 CD4-93A 50-103-20690-01-00 215-026 Colville River WL LDL FINAL FIELD 13-Jul-24 2W-01 50-029-21273-00-00 185-010 Kuparuk River WL LDL FINAL FIELD 16-Jul-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39255 T39256 T39257 T39258 T39259 T39260 3S-03 50-103-20458-00-00 203-091 Kuparuk River WL Perf FINAL FIELD 27-Jun-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.22 10:48:54 -08'00' ORIGINATED TRANSMITTAL DATE: 6/26/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4617 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4617 3S-03 501032045800 SECURE WELL 15-Dec-2023 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature DNR DIGITAL FILES PRINTS CD'S 203-091 T39057 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.26 15:20:06 -08'00' 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com tom.osterkamp@conocophillips.com 203-091 T38930 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.13 08:47:12 -08'00' TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger COPA Wireline Backlog – Batch 2 DATE: 03/01/2024 Transmitted: North Slope, KKuparukk Via SFTP drop - DEVELOPMENT - AOGCC – SCHLUMBERGER 2 of 2 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 192-103/ T38565 188-118/ T38564 192-050/ T38566 184-164/ T38567 185-284/ T38568 185-246/ T38569 203-091/ T38570 202-210/ T38571 202-206/ T38572 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 11:44:20 -09'00' 203-091/ TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 3G-10 50-103-20134-00 190084_3G-10_IPROF_08Jan2023 3G-13 50-103-20137-00 190116_3G-13_Puncher_03Oct2022 3G-20 50-103-20141-00 190123_3G-20_IPROF_28Apr2022 3H-35 50-103-20805-00 219064_3H-35_IPROF_03Aug2023 3I-11A 50-029-21932-01 210074_3I-11A_SBHPS-PLUG_25Jul2023 3M-05 50-029-21706-00 187025_3M-05_TBG_09Jan2022 3O-04 50-029-21826-00 188062_3O-04_CBL Post BiSN_24Aug2023 188062_3O-04_LDL_04Jan2022 3O-06 50-029-21824-00 188060_3O-06_CBL Pre-BiSN_24Aug23 3R-18 50-029-22249-00 192017_3R-18_LDL_21Feb2022 192017_3R-18_PressTemp_22Mar2022 3S-03 50-103-20458-00 203091_3S-03_IBC-CBL_04Sep2023 203091_3S-03_MechCut_14Jul2023 9of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38395 T38396 T38397 T38398 T38399 T38400 T38401 T38402 T38403 T38404 2/29/2024 3S-03 50-103-20458-00 203091_3S-03_IBC-CBL_04Sep2023 203091_3S-03_MechCut_14Jul2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 12:12:37 -09'00' 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: ___________________ 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? 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): 7970'None 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: 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) 263-4131 Staff Well Intervention Engineer KRU 3S-03 6156' 7415' 5680' 1440 7415', 7543', 7643', 7678' N/A 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: jill.simek@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7511' MD and 5753' TVD 498' MD and 497' TVD Jill Simek STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380107 203-091 P.O. Box 100360, Anchorage, AK 99510 50-103-20458-00-00 Kuparuk River Field N/A - Suspended (Kuparuk River Oil Pool) ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY N/A- Abandoned (Kuparuk River Oil Pool) TVD Burst 7543'' MD 108' 2585' 108' 3107' 6147'7960' 16' 9-5/8' 79' 3078' 7633-7666' (cemented) 7934' 5859-5887' (cemented) 7" Perforation Depth TVD (ft): 3-1/2" Packer: Baker SAB-3 Packer SSSV: Camco DS Nipple w/ NoGo Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 11/20/2023 Jill Simek Digitally signed by Jill Simek Date: 2023.11.16 12:58:52 -09'00' 323-622 By Grace Christianson at 1:32 pm, Nov 16, 2023 11/20/2023 DSR-11/16/23SFD 11/19/2023 Nov 16, 2023 X 10-407 X AOGCC inspection is required after cutoff and before any remedial cementing. X VTL 11/20/2023JLC 11/20/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.20 09:20:07 -09'00'11/20/23 RBDMS JSB 112023 Changes requested to Approved Sundry Procedure (Sundry #323-421): Replace Step 3 on Approved Sundry Procedure with 3S-03 Forma on as a Barrier Evaluaon steps, below. Change Step 4 on Approved Sundry Procedure from “RIH with perf guns and perforate 7.0” casing as required to get exposure to top ~50’ of Coyote formation and ~100’ into the confining zone above it” to “RIH with perf guns and perforate 7.0” casing across Coyote confining interval/ Seabee shale”. 3S-03 Forma"on as a Barrier Evalua"on Objec"ves: 1. Establish forma"on breakdown pressure 2. Test for pressure communica"on across Forma"on as a Barrier interval Test Interval: 4,9803 to 5,0343 MD Eline/LRS: 1. MIRU eline. 2. RIH with CIBP; set at 5,3153 MD. Correlate to Open Hole log. 3. RIH and perforate 5,032-5,0343 MD with 23 x 2-7/8" HSD S2906D RDX (15.4g/6spf/60deg) perforang gun. 4. RIH and perforate 4,980-4,9823 MD with 23 x 2-7/8" HSD S2906D RDX (15.4g/6spf/60deg) perforang gun. 5. RIH with RBP w/ gauges hung below. Set at 5,0193 MD. • Ensure gauges are set to record at 1 second intervals 6. Rig up LRS to pump diesel down producon casing. Ensure pump unit DAS is recording accurate pump rates. 7. Perform leak-o< test below: NOTES: • Discuss test with the pump operator prior to execuon. • Record rates electronically by obtaining pressure and rate data every 1 second. • Note exact me of pumping/test start, for gauge data e-in. 1. Start pumps, establish injecon rate at ~1/4 bpm (pump as slow as possible, maintaining constant pump rate) 2.Plot casing pressure vs me 3. ACer leako< point is seen on pressure vs volume plot, pump addional 3 bbls. 4. Shutdown pump. Monitor pressures for minimum 10 minutes unl shut-in pressure stabilizes. 3S-03 Forma"on as a Barrier Evalua"on 4,9803 to 5,0343 MD 8. Perform step-rate test below: NOTES: • Discuss test with the pump operator prior to execuon. A single pump with capacity to reach up to 4 to 5 bbl/min at expected pressures must be used. • Record rates electronically by obtaining pressure and rate data every 1 second. • It is not important to obtain exact rates as planned, but extremely important that the "me intervals between rate changes are same for all the steps. • Rate changes should be quick and crisp; if operator does not get the exact requested rate, no worries – just hold what they get for 30 seconds. 1. Start with minimum rate possible – e.g., 0.25 bpm (or less if possible). Hold for 30 seconds. 2. Increase by 0.25 bpm. Hold for 30seconds. 3. Keep increasing pump rate by 0.25 bpm and holding (30 seconds each step) 0.25 – 0.5 – 0.75 – 1.0 – 1.25 – etc. in 0.25 bbl/min increments ll associated pressure responses are no longer “shoulder” type but sharper. Based on esmates, this should occur before 2.0 bbl/min. 4. Extend the last step to 1 min and halt pumping with a quick shut-down. You will have pumped around 5 bbl in this test. 5. Observe fall-o< for 30 min. 9. RIH and pull RBP and gauges. 10. Ensure pump report (pressure/rate/me/density) is gathered prior to leaving locaon. Email pump report to Intervenons Engineer: jill.simek@conocophillips.com 11. RDMO. Schlumberger IBC/DSLT Log: ORIGINAL APPROVED SUNDRY #323-421 3S-03 Plug and Abandon Procedure PTD #203-091 General Well info: Wellhead type/pressure rating:FMC Gen 5 Production Engineer: Brian Lewis Surveillance Reservoir Engineer:Lynn Aleshire Estimated Start Date:August 1, 2023 Interventions Engineer:Jill Simek (265-4131/ jill.simek@conocophillips.com) Current Operations:This well is currently suspended with cement across Kuparuk. Rig operations are planned to cut and pull tubing from 7,340ft KB. Well Type:Producer Scope of Work:Perform Plug and Abandonment of 3S-03: Perf/Wash/Cement in production casing x OH annulus, cement well to surface, excavate and remove wellhead. MPSP:1440 psi using 0.1 psi/ft gradient Static BHP: 1857 psi / 4166’ TVD estimated from 3S-24B BHP. Sl/El/Coil will be exposed to pressure once perf guns are fired. Procedure Eline 1. MIRU. 2. RIH with CBL and log 7.0” casing to confirm TOC of original cement job. POOH a. If TOC is BELOW Top of Moraine, then do additional production casing x open hole (OA) perf/wash/cement 50’ into Moraine and 100’ into confining zone above it to isolate for a total of ~150’ cement OA plug. 3. RIH and set 7” CIBP at base of perforation zone, approximately 5,315ft KB. POOH. 4. RIH with perf guns and perforate 7.0” casing as required to get exposure to top ~50’ of Coyote formation and ~100’ into the confining zone above it. (Note CIBP set depth and perf intervals may be adjusted, based on log response and/or well conditions encountered) POOH. 5. RDMO Coil 6. MIRU. 7. RIH with wash/cement tool. Gently tag the CIBP. 8. PU and wash perfs per wash/cement tool’s vendor procedure. 9. After wash procedure, cement OA through perforations per wash/cement tool’s vendor procedure. POOH. Job is planned for ~67.8bbls cement, including excess. 10. Leave Top of Cement in production casing ~150ft above top perforation at ~4,989ft KB (Note, TOC depth may be adjusted, based on log response and/or well conditions encountered). Circ out excess. 11. RDMO. Wait on cement. Slickline 12. Notify the AOGCC Inspector of timing for TOC tag and pressure test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 13. MIRU. 14. SL: RIH and tag top of cement (witnessed) 15. SL: Perform MIT on production casing (witnessed) 16. RDMO. Page 1 of 2 3S-03 Plug and Abandon Procedure PTD #203-091 Page 2 of 2 Coil 17. MIRU. 18. Pump cement plug in production casing, from top of cement to surface. Job is planned for 191 bbls cement (final cement volume to be determined based on actual TOC). 19. RDMO. Pumping 20. MIRU. 21. Perform OA down squeeze to place cement from surface to 3,107ft KB. Job is planned for 107 bbls of cement, including excess. 22. RDMO. Wellhead Excavation / Final P&A: 23. Confirm production casing and production casing x surface casing annulus pressures are at 0psi. 24. Notify the AOGCC Inspector of timing for surface plug witness and marker plate installation (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 25. Remove the tree, in preparation for the excavation and casing cut. 26. Excavate and remove wellhead and all casing strings at 4 feet below original ground level. 27. Verify that cement is at surface in all strings. Perform cement “top off” job(s) if required. AOGCC witness and photo document required. 28. Send the casing head w/ stub to materials shop. Photo document. 29. Weld ¼” thick cover plate (16” O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips KRU 3S-03 PTD #: 203-091 API #: 50-103-20458-00 30. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 31. Obtain site clearance approval from AOGCC. RDMO. *If two plugs are deemed to be required due to Moraine formation exposure in the OA to the Coyote, then a lower plug will be performed first with the above steps to isolate top of Moraine. Then a 2 nd plug will be performed as described at the top of the Coyote. Current Completion Proposed P&A 3S-03 P&A PTD #: 203-091 16” 62.5# H-40 Conductor @ 108' KB JS 7-17-2023 7" 26# L-80 Production Casing @ 7,961' KB 3-½” 9.3# L-80 Tubing @ 7,543' KB 9 5/8" 40# L-80 Surface Casing @ 3,107' KB Perfs: 7,633' – 7,666' KB (bottom perfs isolated with IBP/ sand/cement; TOC @ 7,643' KB) Calculated Top of Cement (7" x Open Hole) = 6,835' KB Kuparuk HRZ/Kalubik Shales Moraine 6,782' – 7,035' KB Coyote 5,239' – 6,208' KB Packer depth = 7,511' KB Tubing cut at 7,340ft KB TOC (tubing) at 7,395ft SLM Cement retainer at 7,530ft KB CIBP @ ~5,315' KB Cement Plug (Production Casing x Open Hole Annulus) Approx. 5,139' – 5,289' KB Moraine Cement Plug (IF REQUIRED) (Production Casing x Open Hole Annulus) Approx. 6,682' – 6,832' KB CIBP (IF REQUIRED) @ ~6,858' KB Cement Plug (Production Casing) Approx. 5,315' KB to Surface Cement Plug (Production Casing x Surface Casing Annulus) 3,107' KB to Surface Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,664.0 3S-03 11/10/2021 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set DMY 3S-03 7/15/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By Note: Dump bailed cement on sand plug 2/24/2022 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 29.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 29.0 3,106.8 2,585.1 40.00 L-80 BTC PRODUCTION 7 6.28 26.3 7,960.5 6,147.1 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 7,340.0 Set Depth … 7,543.0 Set Depth … 5,780.2 String Max No… 3 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD ID (in) 2.99 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) 7,494.1 5,737.8 29.96 LOCATOR 5.000 LOCATOR SUB & PBR SEAL ASSEMBLY 3.000 7,496.4 5,739.8 29.94 PBR 5.890 BAKER 80-40 PBR/SBR BAKER 80-40 3.000 7,509.8 5,751.4 29.87 ANCHOR 3.500 KBH-22 ANCHOR TUBING SEAL NIPPLE KBH-22 2.992 7,510.7 5,752.2 29.87 PACKER 5.968 BAKER SAB-3 PACKER BAKER SAB-3 3.250 7,515.6 5,756.4 29.84 MILL 4.600 80-40 MILLOUT EXTENSION 80-40 3.720 7,534.9 5,773.2 29.73 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750 7,542.1 5,779.4 29.70 WLEG 4.510 WLEG w/ SHEAR OUT SUB BAKER 2.950 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) 7,530.0 5,768.9 29.76 CEMENT RETAINER Cement Retainer Quadco SCVR 7/3/2023 0.000 7,664.0 5,885.7 29.01 SAND 1400LBS sand on top of IBP 11/5/2021 0.000 7,678.0 5,897.9 28.94 IBP 2.5" Baker IBP (OAL 11.04', top at 7678') 10464 043 10/26/2021 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,633.0 7,666.0 5,858.6 5,887.4 C-4, 3S-03 6/26/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg ph Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,643.0 7,664.0 5,867.3 5,885.7 Cement Plug 2/24/2022 7,543.0 7,664.0 5,780.2 5,885.7 Cement Plug Pumped 20 bbls of 15.8 ppg class G cement into perfs 7/3/2023 7,395.0 7,543.0 5,652.5 5,780.2 Cement Plug 1 bbl 15.8 ppg cement above retainer 3S-03, 11/16/2023 10:16:50 AM Vertical schematic (actual) PRODUCTION; 26.3-7,960.5 IBP; 7,678.0 SAND; 7,664.0 Stage Cementing; 7,643.0 ftKB IPERF; 7,633.0-7,666.0 Cement Plug; 7,643.0 ftKB Cement Plug; 7,543.0 ftKB NIPPLE; 7,534.9 CEMENT RETAINER; 7,530.0 PACKER; 7,510.7 Cement Casing; 6,835.0 ftKB Cement Plug; 7,395.0 ftKB SURFACE; 29.0-3,106.8 Cement Casing; 29.0 ftKB CONDUCTOR; 29.0-108.0 KUP PROD KB-Grd (ft) 33.26 RR Date 6/22/2003 Other Elev… 3S-03 ... TD Act Btm (ftKB) 7,970.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032045800 Wellbore Status PROD Max Angle & MD Incl (°) 47.43 MD (ftKB) 2,923.23 WELLNAME WELLBORE3S-03 Annotation Last WO: End DateH2S (ppm) 52 Date 3/5/2022 Comment SSSV: NIPPLE 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 194' FNL, 4263' FEL S19 T12N R8E 9. Ref Elevations: KB: 17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 16" B 108'96 sx ArcticCrete 9.625" L-80 2585' 7" L-80 6147' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate 7415-7543' 1bbl of 15.8ppg Class G 7543-7666' 20bbls of 15.8 Class G ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 256 sx Class G w/GasBlok8-1/2" 7543'3.5" 7511'MD/5753'TVD BOTTOM 12-1/4" 430 sx ASLite, 270 sx LiteCrete CASING 50-103-20458-00-00 KRU 3S-03 6/13/2003 7970'MD/6156'TVD 7415'MD/5670'TVD 24' P.O.Box 100360, Anchorage, AK 99510-0360 476403 2469' FNL, 857' FEL S18 T12N R8E 294' FNL, 4386' FEL S19 T12N R8E 6/20/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 7/30/2023 203-091/323-219 1619'MD/1539'TVD SETTING DEPTH TVD 5990853 TOP HOLE SIZE AMOUNT PULLEDTOP SETTING DEPTH MD PACKER SET (MD/TVD) 42" 5993946 Kaparuk River Field/ Kuparuk River Oil Pool ADL0380107 ALK4624 29' 29' 3107' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): WT. PER FT.GRADE 472999 472875 CEMENTING RECORD 5990953 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Gas-Oil Ratio:Choke Size: suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A N/A 29' 29' Per 20 AAC 25.283 (i)(2) attach electronic information 26# 26' 62.5# 40# 108' 26' 7961' SIZE DEPTH SET (MD) Sr Res EngSr Pet GeoSr Pet Eng N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment RECEIVED by James Brooks on 8/15/2023 at 1:35PM Suspended 7/30/2023 JSB RBDMS JSB 081723 xGDSR-8/31/23SFD 12/30/2024 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 1619' 1539' N/A Suspended N/A Suspended N/A Suspended N/A Suspended 31. List of Attachments: Directional Survey, Well Schematic, Cement Operations, Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Dusty Ward Digital Signature with Date: Contact Phone:907-265-6531 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Formation Name at TD: g Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Top of Productive Interval: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and INSTRUCTIONS Contact Email: dusty.ward@conocophillips.com Authorized Title: Wells Engineer Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,664.0 3S-03 11/10/2021 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set DMY 3S-03 7/15/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By Note: Dump bailed cement on sand plug 2/24/2022 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 29.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 29.0 3,106.8 2,585.1 40.00 L-80 BTC PRODUCTION 7 6.28 26.3 7,960.5 6,147.1 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 7,340.0 Set Depth … 7,543.0 Set Depth … 5,780.2 String Ma… 3 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD ID (in) 2.99 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) 7,494.1 5,737.8 29.96 LOCATOR 5.000 LOCATOR SUB & PBR SEAL ASSEMBLY 3.000 7,496.4 5,739.8 29.94 PBR 5.890 BAKER 80-40 PBR/SBR BAKER 80-40 3.000 7,509.8 5,751.4 29.87 ANCHOR 3.500 KBH-22 ANCHOR TUBING SEAL NIPPLE KBH-22 2.992 7,510.7 5,752.2 29.87 PACKER 5.968 BAKER SAB-3 PACKER BAKER SAB-3 3.250 7,515.6 5,756.4 29.84 MILL 4.600 80-40 MILLOUT EXTENSION 80-40 3.720 7,534.9 5,773.2 29.73 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750 7,542.1 5,779.4 29.70 WLEG 4.510 WLEG w/ SHEAR OUT SUB BAKER 2.950 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) 7,530.0 5,768.9 29.76 CEMENT RETAINER Cement Retainer Quadco SCVR 7/3/2023 0.000 7,664.0 5,885.7 29.01 SAND 1400LBS sand on top of IBP 11/5/2021 0.000 7,678.0 5,897.9 28.94 IBP 2.5" Baker IBP (OAL 11.04', top at 7678') 10464 043 10/26/2021 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,633.0 7,666.0 5,858.6 5,887.4 C-4, 3S-03 6/26/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg ph Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,643.0 7,664.0 5,867.3 5,885.7 Cement Plug 2/24/2022 7,543.0 7,666.0 5,780.2 5,887.4 Cement Plug Pumped 20 bbls of 15.8 ppg class G cement into perfs 7/3/2023 7,415.0 7,543.0 5,669.6 5,780.2 Cement Plug 1 bbl of 15.8 ppg class G cement on top of retainer 7/3/2023 3S-03, 8/14/2023 1:16:33 PM Vertical schematic (actual) PRODUCTION; 26.3-7,960.5 IBP; 7,678.0 SAND; 7,664.0 Stage Cementing; 7,643.0 ftKB IPERF; 7,633.0-7,666.0 Cement Plug; 7,643.0 ftKB Cement Plug; 7,543.0 ftKB NIPPLE; 7,534.9 CEMENT RETAINER; 7,530.0 PACKER; 7,510.7 Cement Plug; 7,415.0 ftKB Cement Casing; 6,835.0 ftKB SURFACE; 29.0-3,106.8 Cement Casing; 24.0 ftKB CONDUCTOR; 29.0-108.0 KUP PROD KB-Grd (ft) 33.26 RR Date 6/22/2003 Other Elev… 3S-03 ... TD Act Btm (ftKB) 7,970.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032045800 Wellbore Status PROD Max Angle & MD Incl (°) 47.43 MD (ftKB) 2,923.23 WELLNAME WELLBORE3S-03 Annotation Last WO: End DateH2S (ppm) 80 Date 10/14/2014 Comment SSSV: NIPPLE Page 1/4 3S-03 Report Printed: 8/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/21/2023 18:00 7/21/2023 19:00 1.00 MIRU, MOVE RURD P Secure rig floor for move, go over rig move checklist 0.0 0.0 7/21/2023 19:00 7/21/2023 21:00 2.00 MIRU, MOVE RURD P PJSM pull sub base off 3G-08 Finish cleaning up cellar area 0.0 0.0 7/21/2023 21:00 7/22/2023 00:00 3.00 MIRU, MOVE RURD P PJSM break BOP components apart, remove rams and koomey lines KDTH hauling rig mats for rig move to 3S pad 0.0 0.0 7/22/2023 00:00 7/22/2023 18:00 18.00 MIRU, MOVE RURD P Cont. to break BOP components apart, remove rams and koomey lines, prep cellar area for new BOP's, clean and prep BOP components for N/U Housekeeping around rig and clean up around outside of rig Replace top drive grabber dies Prep rig floor for laying derrick over, unhook top drive and bridle up derrick C/O driller side cellar bridge crane cable KDTH hauling and setting rig mats for rig move to 3S pad 0.0 0.0 7/22/2023 18:00 7/23/2023 00:00 6.00 MIRU, MOVE RURD P PJSM, N/U BOP stack components, TQ bolts, hook up koomey lines KDTH hauling and setting rig mats for rig move to 3S pad 0.0 0.0 7/23/2023 00:00 7/23/2023 16:30 16.50 MIRU, MOVE RURD P Cont to N/U BOP stack components, TQ bolts, hook up koomey lines, rack back BOP stack on stump Housekeeping around rig KDTH hauling and setting rig mats for rig move to 3S pad 0.0 0.0 7/23/2023 16:30 7/23/2023 20:00 3.50 MIRU, MOVE MOB P PJSM, lower cattle chute, pull derrick pins, lay derrick over Start hooking up trucks to shop, loading rig equipment on trailers to move to 3S pad, prep rig office for move Hook up truck to pits 0.0 0.0 7/23/2023 20:00 7/24/2023 00:00 4.00 MIRU, MOVE MOB P Move pits, shop, rig office and other rig components to 3S pad 0.0 0.0 7/24/2023 00:00 7/24/2023 01:00 1.00 MIRU, MOVE MOB P PJSM, move sub base to 3S pad 0.0 0.0 7/24/2023 01:00 7/24/2023 03:30 2.50 MIRU, MOVE MOB T Sub base sink on 3G pad while getting up on matting boards on road to 3S Add dunnage under tires to get up on matting boards 0.0 0.0 7/24/2023 03:30 7/24/2023 04:30 1.00 MIRU, MOVE MOB P Move sub base down road to 3S 0.0 0.0 7/24/2023 04:30 7/24/2023 18:00 13.50 MIRU, MOVE MOB T Sub base sink in road after coming off matting boards and onto portable road. Try pulling out with winch trucks from KDTH with no success. Add dunnage under tires in an attempt to get unstuck with no success. At 13:15 HRS call NES for sow trucks and dozer's 0.0 0.0 7/24/2023 18:00 7/24/2023 19:30 1.50 MIRU, MOVE MOB T NES on location PJSM, hook up cats to subbase and have them assit getting sub base up on matting boards 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/30/2023 Page 2/4 3S-03 Report Printed: 8/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/24/2023 19:30 7/24/2023 20:45 1.25 MIRU, MOVE MOB T Sub base up on matting boards, unhook cats, pick up old matting boards and lay out good ones to drive sub base on back to 3G 0.0 0.0 7/24/2023 20:45 7/24/2023 21:30 0.75 MIRU, MOVE MOB T Move sub base back onto 3G pad 0.0 0.0 7/24/2023 21:30 7/25/2023 00:00 2.50 MIRU, MOVE MOB T KDTH pull up matting boards and portable road mats. Fill in holes in road and lay out portable road and matting boards for rig move to 3S pad 0.0 0.0 7/25/2023 00:00 7/25/2023 09:30 9.50 MIRU, MOVE MOB T KDTH pull up matting boards and portable road mats. Fill in holes in road and lay out portable road and matting boards for rig move to 3S pad 0.0 0.0 7/25/2023 09:30 7/25/2023 09:45 0.25 MIRU, MOVE MOB T Start moving sub base from 3G pad to 3S pad Make it past soft spot in road 0.0 0.0 7/25/2023 09:45 7/25/2023 11:30 1.75 MIRU, MOVE MOB T Move sub base to 3S pad on matting boards, move sub base 1.1 miles down road to 3S Then continue to move sub base to 3S pad utilizing the leap frog method using 250 matting boards 0.0 0.0 7/25/2023 11:30 7/26/2023 00:00 12.50 MIRU, MOVE MOB T Move sub base to 3S pad utilizing the leap frog method using 250 matting boards 0.0 0.0 7/26/2023 00:00 7/27/2023 00:00 24.00 MIRU, MOVE MOB T Move sub base to 3S pad utilizing the leap frog method using 250 matting boards Unhook jeep from pits, housekeeping around 3S pad, shop and rig office 0.0 0.0 7/27/2023 00:00 7/28/2023 00:00 24.00 MIRU, MOVE MOB T Move sub base to 3S pad utilizing the leap frog method using 250 of the 6" matting boards. Prep 3S-03 cellar area for subbase 0.0 0.0 7/28/2023 00:00 7/28/2023 07:00 7.00 MIRU, MOVE MOB T Move sub base to 3S pad utilizing the leap frog method using 250 of the 6" matting boards. 0.0 0.0 7/28/2023 07:00 7/28/2023 17:00 10.00 MIRU, MOVE MOB P Sub base on 3S pad. Matted pad to move rig over well without coming off rig mats. Backed rig sub over well, Spotted pits to the sub base. Raised the derrick. Spot cuttings tank. 0.0 0.0 7/28/2023 17:00 7/28/2023 20:30 3.50 MIRU, WELCTL RURD P Rig up rig floor for opertions, bring on 9.6 PPG brine to pits, build 30 BBL deep clean pill, rig up squeeze manifold to circulate 9.6 NaCI brine 0.0 0.0 7/28/2023 20:30 7/29/2023 00:00 3.50 MIRU, WELCTL DISP P PJSM, flood lines to tiger tank test lines Pump 30 BBLS deep clean pill, chase with 9.6 PPG NaCI brine 4 BPM 960 PSI Pump a total of 265 BBLS 0.0 0.0 7/29/2023 00:00 7/29/2023 00:30 0.50 MIRU, WELCTL CIRC P Circulate 50 additional bbls, shut down 0.0 0.0 7/29/2023 00:30 7/29/2023 01:15 0.75 MIRU, WELCTL OWFF P Observe well for flow 0.0 0.0 7/29/2023 01:15 7/29/2023 01:30 0.25 MIRU, WELCTL NUND P Set BPV 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/30/2023 Page 3/4 3S-03 Report Printed: 8/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/29/2023 01:30 7/29/2023 02:00 0.50 MIRU, WHDBOP PRTS P Test BPV way of flow 1000 psi for 10 mins 0.0 0.0 7/29/2023 02:00 7/29/2023 04:30 2.50 MIRU, WHDBOP NUND P Blowdown secondary Kill and surface lines, Nipple down tree, inspect threads, remove bushing, check with 3.5" EUE8RD XO (good), install test dart. 0.0 0.0 7/29/2023 04:30 7/29/2023 08:30 4.00 MIRU, WHDBOP NUND P MU DSA and N/U stack 0.0 0.0 7/29/2023 08:30 7/29/2023 10:00 1.50 MIRU, WHDBOP RURD P Rig up BOP test equipment, fill stack and lines with water, purge air out of system Obtain good shell test 0.0 0.0 7/29/2023 10:00 7/29/2023 18:00 8.00 MIRU, WHDBOP BOPE P Test BOP Test annular with 3 1/2" test joint to 250/2500 PSI F/5 min. All other test to 250/5000 PSI F/5 min each, UVBR and LVBR with 3 1/2" test joint, Test blinds rams, Choke valves #1 to #16, upper/lower IBOP valves. Test 3-1/2" HT -38 FOSV/Dart Valve, Test 2" rig floor Demco kill valves, Test manual and HCR kill and choke valves.Test two ea 2 -1/16" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 3200 PSI, after closure = 1600 PSI, 200 PSI attained = 15 sec, full recovery attained = 216 sec. UVBR = 5 sec, LVBR = 5 sec, Annular = 29 sec, Simulated blinds = 5 sec, HCR choke/kill = 1 sec each, 5 back up nitrogen bottles average = 1900 PSI, Prechare bottles = 11 @ 1100 PSI, Test gas detectors, PVT and flow show. AOGCC Rep. Adam Earl witness test 0.0 0.0 7/29/2023 18:00 7/29/2023 19:00 1.00 MIRU, WHDBOP OTHR P Crew change, blow down, testing equipment, 0.0 0.0 7/29/2023 19:00 7/29/2023 20:15 1.25 COMPZN, RPCOMP TRIP P Inspect/Service Top Drive, Skate, Pulling equipment, swap out elevators 0.0 0.0 7/29/2023 20:15 7/29/2023 20:45 0.50 COMPZN, RPCOMP SFTY P KBU, Latch up elevators, PJSM with rig team 0.0 0.0 7/29/2023 20:45 7/29/2023 21:15 0.50 COMPZN, RPCOMP TRIP P Pull free 105 k, KBD, 0.0 0.0 7/29/2023 21:15 7/29/2023 23:15 2.00 COMPZN, RPCOMP OWFF T Check well for flow, well not balanced, KBU, circulate BU, well still unbalanced, circulate SXS, 9.7 ppg all the way around 0.0 0.0 7/29/2023 23:15 7/29/2023 23:45 0.50 COMPZN, RPCOMP OWFF P Monitor well for flow 0.0 0.0 7/29/2023 23:45 7/30/2023 00:00 0.25 COMPZN, RPCOMP TRIP P KBU, pull hanger to RF Brake out TOOH L/D 3.5" EUE8RD EUE atubing to pipe shed Fighting every connection as if they are over torqued. 7,470.0 7,440.0 7/30/2023 00:00 7/30/2023 10:00 10.00 COMPZN, RPCOMP TRIP P L/D 3.5", 9.3#, L-80, R2 tubing, UWT=85K DWT=60K 7,440.0 0.0 7/30/2023 10:00 7/30/2023 11:00 1.00 COMPZN, RPCOMP FRZP P Freeze protect the well with 10 bbl diesel. 0.0 0.0 7/30/2023 11:00 7/30/2023 11:30 0.50 COMPZN, RPCOMP OWFF P Flow check well for flow. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/30/2023 Page 4/4 3S-03 Report Printed: 8/14/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/30/2023 11:30 7/30/2023 14:30 3.00 COMPZN, WHDBOP NUND P PJSM, Nipple down BOPE and NU FMC 7 1/16" dry hole tree. 0.0 0.0 7/30/2023 14:30 7/30/2023 15:30 1.00 COMPZN, WHDBOP PRTS P Test tree to 1500 psi for 30 minutes. Starting OA 150 psi 15min OA/IA 400 psi/1580 psi 30 min OA/IA 400 psi/1570 psi 0.0 0.0 7/30/2023 15:30 7/30/2023 18:00 2.50 DEMOB, MOVE RURD P RD LRS, secure well, clean up cellar and lay rig matts to pull off well. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 7/30/2023 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 3S-03 JBR 09/20/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 Lower rams were cycled a few times FP / Rental TIW failed and was getting replaced. Did not see a replacement show up before I left location. Decent test for 5K psi Test Results TEST DATA Rig Rep:Cozby/CoyneOperator:ConocoPhillips Alaska, Inc.Operator Rep:Phillips/Kiser Rig Owner/Rig No.:Nabors 7ES PTD#:2030910 DATE:7/29/2023 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopAGE230806083352 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 8 MASP: 1440 Sundry No: 323-219 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 1 F 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8 P #1 Rams 1 3 1/2 x 5 1/2 P #2 Rams 1 Blind P #3 Rams 1 3 1/2 x 5 1/2 FP #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8 P HCR Valves 2 3 1/8 P Kill Line Valves 2 3 1/8 P Check Valve 0 NA BOP Misc 2 2 1/16 P System Pressure P3200 Pressure After Closure P1600 200 PSI Attained P15 Full Pressure Attained P116 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P5@1900 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P29 #1 Rams P5 #2 Rams P5 #3 Rams P5 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9999 9 9 9 9Lower rams TIW failed 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: ___________________ 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? 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): 7970'None 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: 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) 263-4131 Staff Well Intervention Engineer KRU 3S-03 6156' 7415' 5680' 1440 7415', 7543', 7643', 7678' N/A 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: jill.simek@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 7511' MD and 5753' TVD 498' MD and 497' TVD Jill Simek STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380107 203-091 P.O. Box 100360, Anchorage, AK 99510 50-103-20458-00-00 Kuparuk River Field N/A - Suspended (Kuparuk River Oil Pool) ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY N/A- Abandoned (Kuparuk River Oil Pool) TVD Burst 5781' MD 108' 2585' 108' 3107' 6147'7960' 16' 9-5/8' 79' 3078' 7633-7666' (cemented) 7934' 5859-5887' (cemented) 7" Perforation Depth TVD (ft): 7/1/2023 3-1/2" Packer: Baker SAB-# Packer SSSV: Camco DS Nipple w/ NoGo Perforation Depth MD (ft): L-80 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 10:23 am, Jul 25, 2023 323-421 Jill Simek Digitally signed by Jill Simek Date: 2023.07.24 17:46:38 -08'00' VTL 7/26/2023 DSR-7/26/23 X MDG 7/25/2023 X 10-407X AOGCC inspection is required after cutoff and before any remedial cementing. GCW 07/26/2023JLC 7/26/2023 07/28/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.28 16:31:46 -06'00' RBDMS JSB 080123 3S-03 Plug and Abandon Procedure PTD #203-091 Page 1 of 2 General Well info: Wellhead type/pressure rating: FMC Gen 5 Production Engineer: Brian Lewis Surveillance Reservoir Engineer: Lynn Aleshire Estimated Start Date: August 1, 2023 Interventions Engineer: Jill Simek (265-4131/ jill.simek@conocophillips.com) Current Operations: This well is currently suspended with cement across Kuparuk. Rig operations are planned to cut and pull tubing from 7,340ft KB. Well Type: Producer Scope of Work: Perform Plug and Abandonment of 3S-03: Perf/Wash/Cement in production casing x OH annulus, cement well to surface, excavate and remove wellhead. MPSP: 1440 psi using 0.1 psi/ft gradient Static BHP: 1857 psi / 4166’ TVD estimated from 3S-24B BHP. Sl/El/Coil will be exposed to pressure once perf guns are fired. Procedure Eline 1. MIRU. 2. RIH with CBL and log 7.0” casing to confirm TOC of original cement job. POOH a. If TOC is BELOW Top of Moraine, then do additional production casing x open hole (OA) perf/wash/cement 50’ into Moraine and 100’ into confining zone above it to isolate for a total of ~150’ cement OA plug. 3. RIH and set 7” CIBP at base of perforation zone, approximately 5,315ft KB. POOH. 4. RIH with perf guns and perforate 7.0” casing as required to get exposure to top ~50’ of Coyote formation and ~100’ into the confining zone above it. (Note CIBP set depth and perf intervals may be adjusted, based on log response and/or well conditions encountered) POOH. 5. RDMO Coil 6. MIRU. 7. RIH with wash/cement tool. Gently tag the CIBP. 8. PU and wash perfs per wash/cement tool’s vendor procedure. 9. After wash procedure, cement OA through perforations per wash/cement tool’s vendor procedure. POOH. Job is planned for ~67.8bbls cement, including excess. 10. Leave Top of Cement in production casing ~150ft above top perforation at ~4,989ft KB (Note, TOC depth may be adjusted, based on log response and/or well conditions encountered). Circ out excess. 11. RDMO. Wait on cement. Slickline 12. Notify the AOGCC Inspector of timing for TOC tag and pressure test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 13. MIRU. 14. SL: RIH and tag top of cement (witnessed) 15. SL: Perform MIT on production casing (witnessed) 16. RDMO. 3S-03 Plug and Abandon Procedure PTD #203-091 Page 2 of 2 Coil 17. MIRU. 18. Pump cement plug in production casing, from top of cement to surface. Job is planned for 191 bbls cement (final cement volume to be determined based on actual TOC). 19. RDMO. Pumping 20. MIRU. 21. Perform OA down squeeze to place cement from surface to 3,107ft KB. Job is planned for 107 bbls of cement, including excess. 22. RDMO. Wellhead Excavation / Final P&A: 23. Confirm production casing and production casing x surface casing annulus pressures are at 0psi. 24. Notify the AOGCC Inspector of timing for surface plug witness and marker plate installation (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 25. Remove the tree, in preparation for the excavation and casing cut. 26. Excavate and remove wellhead and all casing strings at 4 feet below original ground level. 27. Verify that cement is at surface in all strings. Perform cement “top off” job(s) if required. AOGCC witness and photo document required. 28. Send the casing head w/ stub to materials shop. Photo document. 29. Weld ¼” thick cover plate (16” O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips KRU 3S-03 PTD #: 203-091 API #: 50-103-20458-00 30. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 31. Obtain site clearance approval from AOGCC. RDMO. *If two plugs are deemed to be required due to Moraine formation exposure in the OA to the Coyote, then a lower plug will be performed first with the above steps to isolate top of Moraine. Then a 2nd plug will be performed as described at the top of the Coyote. Current Completion Proposed P&A 3S-03 P&A PTD #: 203-091 16” 62.5# H-40 Conductor @ 108' KB JS 7-17-2023 7" 26# L-80 Production Casing @ 7,961' KB 3-½” 9.3# L-80 Tubing @ 7,543' KB 9 5/8" 40# L-80 Surface Casing @ 3,107' KB Perfs: 7,633' – 7,666' KB (bottom perfs isolated with IBP/ sand/cement; TOC @ 7,643' KB) Calculated Top of Cement (7" x Open Hole) = 6,835' KB Kuparuk HRZ/Kalubik Shales Moraine 6,782' – 7,035' KB Coyote 5,239' – 6,208' KB Packer depth = 7,511' KB Tubing cut at 7,340ft KB TOC (tubing) at 7,395ft SLM Cement retainer at 7,530ft KB CIBP @ ~5,315' KB Cement Plug (Production Casing x Open Hole Annulus) Approx. 5,139' – 5,289' KB Moraine Cement Plug (IF REQUIRED) (Production Casing x Open Hole Annulus) Approx. 6,682' – 6,832' KB CIBP (IF REQUIRED) @ ~6,858' KB Cement Plug (Production Casing) Approx. 5,315' KB to Surface Cement Plug (Production Casing x Surface Casing Annulus) 3,107' KB to Surface Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,664.0 3S-03 11/10/2021 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set DMY 3S-03 7/15/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By Note: Dump bailed cement on sand plug 2/24/2022 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 29.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 29.0 3,106.8 2,585.1 40.00 L-80 BTC PRODUCTION 7 6.28 26.3 7,960.5 6,147.1 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.1 Set Depth … 7,543.5 Set Depth … 5,780.7 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD ID (in) 2.99 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) 24.1 24.1 0.03 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 497.7 497.4 4.78 NIPPLE 5.390 CAMCO DS NIPPLE w/ 2.875" NO GO CAMCO DS 2.875 2,996.5 2,509.2 46.88 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 4,669.4 3,693.8 43.94 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 5,901.4 4,556.9 45.73 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 6,791.1 5,186.3 43.68 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 7,395.4 5,652.9 31.75 GAS LIFT 6.018 CAMCO KBUG-M CAMCO KBUG-M 2.920 7,447.1 5,697.2 30.50 SLEEVE - C 4.490 BAKER CMU SLIDING SLEEVE w/ CAMCO 2.812" NO GO PROFILE (Closed 10/1/2014) BAKER CMU 2.812 7,494.6 5,738.2 29.95 LOCATOR 5.000 LOCATOR SUB & PBR SEAL ASSEMBLY 3.000 7,496.9 5,740.2 29.94 PBR 5.890 BAKER 80-40 PBR/SBR BAKER 80-40 3.000 7,510.3 5,751.8 29.87 ANCHOR 3.500 KBH-22 ANCHOR TUBING SEAL NIPPLE KBH-22 2.992 7,511.2 5,752.6 29.86 PACKER 5.968 BAKER SAB-3 PACKER BAKER SAB-3 3.250 7,516.1 5,756.9 29.84 MILL 4.600 80-40 MILLOUT EXTENSION 80-40 3.720 7,535.4 5,773.7 29.73 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750 7,542.6 5,779.9 29.69 WLEG 4.510 WLEG w/ SHEAR OUT SUB BAKER 2.950 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) 7,340.0 5,606.1 32.95 CUT WELLTEC MECHANICAL CUT @ 7340' RKB, TATTLE- TAIL INIDICATED GREATER THAN 3.5" BLADE TRAVEL 7/14/2023 2.992 7,530.0 5,768.9 29.76 CEMENT RETAINER Cement Retainer Quadco SCVR 7/3/2023 0.000 7,664.0 5,885.7 29.01 SAND 1400LBS sand on top of IBP 11/5/2021 0.000 7,678.0 5,897.9 28.94 IBP 2.5" Baker IBP (OAL 11.04', top at 7678') 10464 043 10/26/2021 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) 2,996.5 2,509.2 46.88 1 GAS LIFT DMY BK5 1 0.0 7/15/2023 0.000 4,669.4 3,693.8 43.94 2 GAS LIFT DMY BK5 1 0.0 5/13/2015 0.000 5,901.4 4,556.9 45.73 3 GAS LIFT DMY BK5 1 0.0 6/22/2003 0.000 6,791.1 5,186.3 43.68 4 GAS LIFT DMY BK5 1 0.0 6/22/2003 0.000 7,395.4 5,652.9 31.75 5 GAS LIFT OV RK 1 1/2 0.0 5/13/2015 0.250 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,633.0 7,666.0 5,858.6 5,887.4 C-4, 3S-03 6/26/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg ph Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,643.0 7,664.0 5,867.3 5,885.7 Cement Plug 2/24/2022 7,543.0 7,666.0 5,780.2 5,887.4 Cement Plug Pumped 20 bbls of 15.8 ppg class G cement into perfs 7/3/2023 7,415.0 7,543.0 5,669.6 5,780.2 Cement Plug 1 bbl of 15.8 ppg class G cement on top of retainer 7/3/2023 3S-03, 7/24/2023 4:20:26 PM Vertical schematic (actual) PRODUCTION; 26.3-7,960.5 IBP; 7,678.0 SAND; 7,664.0 Stage Cementing; 7,643.0 ftKB IPERF; 7,633.0-7,666.0 Cement Plug; 7,643.0 ftKB Cement Plug; 7,543.0 ftKB NIPPLE; 7,535.4 CEMENT RETAINER; 7,530.0 PACKER; 7,511.2 Cement Plug; 7,415.0 ftKB GAS LIFT; 7,395.4 Cement Casing; 6,835.0 ftKB CUT; 7,340.0 GAS LIFT; 6,791.1 GAS LIFT; 5,901.4 GAS LIFT; 4,669.4 SURFACE; 29.0-3,106.8 GAS LIFT; 2,996.5 Cement Casing; 24.0 ftKB NIPPLE; 497.7 CONDUCTOR; 29.0-108.0 KUP PROD KB-Grd (ft) 33.26 RR Date 6/22/2003 Other Elev… 3S-03 ... TD Act Btm (ftKB) 7,970.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032045800 Wellbore Status PROD Max Angle & MD Incl (°) 47.43 MD (ftKB) 2,923.23 WELLNAME WELLBORE3S-03 Annotation Last WO: End DateH2S (ppm) 80 Date 10/14/2014 Comment SSSV: NIPPLE 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: ___________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" B 108' 9.625" L-80 2585' 7" L-80 6147' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 256 sx Class G w/GasBlok8-1/2" 5781'3-1/2" CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 7/13/2023 2469' FNL, 857' FEL, Sec. 18, T12N, R8E, UM 294' FNL, 4386' FEL, Sec. 19, T12N, R8E, UM P.O. Box 100360, Anchorage, AK 99510-0360 476403 5993946 194' FNL, 4263' FEL, Sec. 19, T12N, R8E, UM 7415' MD/ 5670' TVD 7970' MD/ 6156' TVD ADL0380107 ALK4624 50-103-20458-00-00 KRU 3S-03 June 13, 2003 June 20, 2003 9. Ref Elevations: KB: 24' Kuparuk River Field/ Kuparuk River Oil Pool WT. PER FT.GRADE CEMENTING RECORD 5990953 SETTING DEPTH TVD 5990853 TOP HOLE SIZE AMOUNT PULLED 472999 472875 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. BOTTOM N/A 1619' MD/ 1539' TVD N/A 7511' MD/5753' TVD PACKER SET (MD/TVD) 42" 12-1/4" 96 sx ArcticCrete 29'430 sx ASLite, 270 sx LiteCrete 29' 3107'29' 29' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# 7415-7530' 1 bbl 15.8ppg Class G cement on top of retainer Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 7633-7666' SUSPENDED 7633-7666' MD and 5859-5887' TVD (cemented) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 20 bbls 15.8 ppg Class G cement into perfs 7961' SIZE DEPTH SET (MD) 26' 62.5# 40# 108' 26' Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment 14. Permit to Drill Number / Sundry: 203-091/323-171 By Grace Christianson at 10:03 am, Jul 25, 2023 Suspended 7/13/2023 JSB RBDMS JSB 072623 G DSR-8/18/23 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1619' 1539' Top of Productive Interval N/A 31. List of Attachments: Schematic, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Jill Simek Digital Signature with Date:Contact Email:jill.simek@conocophillips.com Contact Phone:(907) 263-4131 Staff Well Integrity Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A - Suspended Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. N/A - Suspended Authorized Name and Formation Name at TD: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Jill Simek Digitally signed by Jill Simek Date: 2023.07.24 19:12:14 -08'00' Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,664.0 3S-03 11/10/2021 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set DMY 3S-03 7/15/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By Note: Dump bailed cement on sand plug 2/24/2022 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 29.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 29.0 3,106.8 2,585.1 40.00 L-80 BTC PRODUCTION 7 6.28 26.3 7,960.5 6,147.1 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.1 Set Depth … 7,543.5 Set Depth … 5,780.7 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD ID (in) 2.99 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) 24.1 24.1 0.03 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 497.7 497.4 4.78 NIPPLE 5.390 CAMCO DS NIPPLE w/ 2.875" NO GO CAMCO DS 2.875 2,996.5 2,509.2 46.88 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 4,669.4 3,693.8 43.94 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 5,901.4 4,556.9 45.73 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 6,791.1 5,186.3 43.68 GAS LIFT 5.390 CAMCO KBUG-M CAMCO KBUG-M 2.920 7,395.4 5,652.9 31.75 GAS LIFT 6.018 CAMCO KBUG-M CAMCO KBUG-M 2.920 7,447.1 5,697.2 30.50 SLEEVE - C 4.490 BAKER CMU SLIDING SLEEVE w/ CAMCO 2.812" NO GO PROFILE (Closed 10/1/2014) BAKER CMU 2.812 7,494.6 5,738.2 29.95 LOCATOR 5.000 LOCATOR SUB & PBR SEAL ASSEMBLY 3.000 7,496.9 5,740.2 29.94 PBR 5.890 BAKER 80-40 PBR/SBR BAKER 80-40 3.000 7,510.3 5,751.8 29.87 ANCHOR 3.500 KBH-22 ANCHOR TUBING SEAL NIPPLE KBH-22 2.992 7,511.2 5,752.6 29.86 PACKER 5.968 BAKER SAB-3 PACKER BAKER SAB-3 3.250 7,516.1 5,756.9 29.84 MILL 4.600 80-40 MILLOUT EXTENSION 80-40 3.720 7,535.4 5,773.7 29.73 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750 7,542.6 5,779.9 29.69 WLEG 4.510 WLEG w/ SHEAR OUT SUB BAKER 2.950 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) 7,340.0 5,606.1 32.95 CUT WELLTEC MECHANICAL CUT @ 7340' RKB, TATTLE- TAIL INIDICATED GREATER THAN 3.5" BLADE TRAVEL 7/14/2023 2.992 7,530.0 5,768.9 29.76 CEMENT RETAINER Cement Retainer Quadco SCVR 7/3/2023 0.000 7,664.0 5,885.7 29.01 SAND 1400LBS sand on top of IBP 11/5/2021 0.000 7,678.0 5,897.9 28.94 IBP 2.5" Baker IBP (OAL 11.04', top at 7678') 10464 043 10/26/2021 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) 2,996.5 2,509.2 46.88 1 GAS LIFT DMY BK5 1 0.0 7/15/2023 0.000 4,669.4 3,693.8 43.94 2 GAS LIFT DMY BK5 1 0.0 5/13/2015 0.000 5,901.4 4,556.9 45.73 3 GAS LIFT DMY BK5 1 0.0 6/22/2003 0.000 6,791.1 5,186.3 43.68 4 GAS LIFT DMY BK5 1 0.0 6/22/2003 0.000 7,395.4 5,652.9 31.75 5 GAS LIFT OV RK 1 1/2 0.0 5/13/2015 0.250 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,633.0 7,666.0 5,858.6 5,887.4 C-4, 3S-03 6/26/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg ph Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,643.0 7,664.0 5,867.3 5,885.7 Cement Plug 2/24/2022 7,543.0 7,666.0 5,780.2 5,887.4 Cement Plug Pumped 20 bbls of 15.8 ppg class G cement into perfs 7/3/2023 7,415.0 7,543.0 5,669.6 5,780.2 Cement Plug 1 bbl of 15.8 ppg class G cement on top of retainer 7/3/2023 3S-03, 7/24/2023 4:20:26 PM Vertical schematic (actual) PRODUCTION; 26.3-7,960.5 IBP; 7,678.0 SAND; 7,664.0 Stage Cementing; 7,643.0 ftKB IPERF; 7,633.0-7,666.0 Cement Plug; 7,643.0 ftKB Cement Plug; 7,543.0 ftKB NIPPLE; 7,535.4 CEMENT RETAINER; 7,530.0 PACKER; 7,511.2 Cement Plug; 7,415.0 ftKB GAS LIFT; 7,395.4 Cement Casing; 6,835.0 ftKB CUT; 7,340.0 GAS LIFT; 6,791.1 GAS LIFT; 5,901.4 GAS LIFT; 4,669.4 SURFACE; 29.0-3,106.8 GAS LIFT; 2,996.5 Cement Casing; 24.0 ftKB NIPPLE; 497.7 CONDUCTOR; 29.0-108.0 KUP PROD KB-Grd (ft) 33.26 RR Date 6/22/2003 Other Elev… 3S-03 ... TD Act Btm (ftKB) 7,970.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032045800 Wellbore Status PROD Max Angle & MD Incl (°) 47.43 MD (ftKB) 2,923.23 WELLNAME WELLBORE3S-03 Annotation Last WO: End DateH2S (ppm) 80 Date 10/14/2014 Comment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 4/28/2023 ACQUIRE DATA (P&A) FUNCTION TEST ALL T & IC LDS/GN's , TPOT PASSED , T PPPOT PASSED , IC POT PASSED , IC PPPOT PASSED 6/24/2023 ACQUIRE DATA WHILE DRIFTING W/ 2.75" DUMMY CA-2 PLUG TOOLS GOT DETAINED @ 7261' RKB, AFTER ATTEMPTING TO FREE TOOLS BY BLEEDING OFF PRESSURE & PUMPING TOOL STRING @ ~60' OF WIRE STILL IN WELL, RAN 2.68" LIB UNABLE TO PASS 6096' RKB LIB INCONCLUSIVE, ATTEMPT TO BOX OFF WIRE FISH MOVING DOWN FROM 6096' TO 6148' RKB, RAN BAITED 3 1/2 BRUSH & 2.62" WIRE GRAB RECOVER THICK SCALE & ASPHALTENES. IN PROGRESS. 6/25/2023 ACQUIRE DATA FLUSH TBG W/ 95 BBLS HOT DIESEL, TAG WIRE W/ 2.68" LIB @ 7488' RKB, RAN 2.34" BLIND BOX TAG TOP OF TOOLS STRING @ 7501' RKB, ATTEMPT TO RECOVER W/ UNABLE TO PASS GLM @ 6791' RKB. IN PROGRESS. 6/26/2023 ACQUIRE DATA RECOVER ~ 25' OF WIRE & TOOL STRING @ 7502' RKB, TAG W/ 2.5" BAILER W/ 2.65" BTM @ 7653' RKB. LRS PUMPED 20 BBL STEP RATE FROM .5 BPM TO 3 BPM MAX 300 PSI, LRS PERFORMED INJECTIVITY TEST DOWN OA OF 1.5 BPM @ 1000 PSI W/10 BBLS DIESEL. READY FOR CTU. 7/2/2023 ACQUIRE DATA MIRU RAN IN HOLE W / A 2.80" MILL TAGGED D-NIPPLE AT 7512' CTMD 7535' RKB TRIED MILL AND STALLED CONFIRMING NIPPLE POOH. RBIH W / CEMENT RETAINER TAG NIPPLE AT 7535' RKB PUH 5 ' AND SET RETAINER AT 7530' PUMP 20 BBLS OF CEMENT INTO RETAINER AND PLACE 1 BBL ON TOP. RDMO. READY FOR STATE WITNESSED TAG. 7/10/2023 ACQUIRE DATA PRE STATE WITNESS TAG TOC @ 7393' SLM, PERFORM MITT TO 1500 PSI (PASSED) DDT TO 0 PSI (PASSED), READY FOR STATE WITNESSED TAG & MIT. 7/13/2023 ACQUIRE DATA STATE WITNESS (BOB NOBLE) TAG TOC @ 7395' SLM. PERFORM MITT TO 1500 PSI, (PASSED) MIT FORM IS IN ATTACHMENTS. 3S-03 Suspend Summary of Operations MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:18 Township:12N Range:8E Meridian:Umiat Drilling Rig:N/A Rig Elevation:N/A Total Depth:7970 ft MD Lease No.:ADL0380107 Operator Rep:Suspend:P&A:X Conductor:16"O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface:9 5/8"O.D. Shoe@ 3107 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 7960 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3 1/2"O.D. Tail@ 7543 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Retainer 7532 ft 7395 ft 7 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1675 1600 1580 IA 1200 1200 1200 OA 390 390 390 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): I traveled to KRU to witness a tag and test one a plug on well 3S-03. I met with CPA's representative Sid Ferguson and he had paperwork that I requested. We went over what they were going to do. A wireline tag was performed with a 2 inch bailer and top of cement was found at 7395 ft MD. Small hard cement chips and diesel were found in the bailer. Then a passing MIT-T was performed. July 13, 2023 Bob Noble Well Bore Plug & Abandonment KRU, 3S-03 ConocoPhillips Alaska Inc PTD 2030910; Sundry 323-171 none Test Data: P Casing Removal: rev. 11-28-18 2023-0713_Plug_Verification_KRU_3S-03_bn             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: ___________________ 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? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7970'None 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: 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 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 Dusty Ward dusty.ward@conocophillips.com (907) 265-6531 Senior Workover Engineer Tubing Grade: Tubing MD (ft): 7511' MD and 5753' TVD 498' MD and 497' TVD Perforation Depth TVD (ft): Tubing Size: L-80 7544' 6/4/2023 Packer: Baker SAB-3 Packer SSSV: Camco DS Nipple w/NoGo STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380107 203-091 P.O. Box 100360, Anchorage, AK 99510 50-103-20458-00-00 ConocoPhillips Alaska, Inc. KRU 3S-03 Kuparuk River Oil PoolKuparuk River Oil PoolKuparuk River Field N/A Length Size Proposed Pools: TVD Burst 6156' 7664' 5886' 1440 7643' MD 108' 2585' 108' 3107' 6147'7961' 16" 9-5/8" 79' 3078' Perforation Depth MD (ft): 7633-7666' MD Cemented from 7643-7664' MD 7934' 5859-5887' TVD Cemented from 5867-5886'TVD 3-1/2" 7" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov VTL 5/23/2023 BOP test to 2500 psig Annular preventer test to 2500 psig DSR-4/13/23 Re-enter Susp Well X 10-407 SFD 5/23/2023 X GCW 05/24/23JLC 5/24/2023 5/24/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.24 12:32:45 -05'00' RBDMS JSB 052423 ISSUED AS:PRELIMINARYDATE:ISSUED BY:AS BUILTFOR:APPROVALMARK-UPQUOTEREVIEW07-JUN-21PKMXX17'-314"[5261]3'-912"[1156]4'-734"[1418]2'-0"[610]2'-934"[859]2'-0"[610]2'-0"[610]BY NABORSBY OPERATORPIPE RAMCL WELLCHOKE LINE7BILL OF MATERIALS413121NOQTY DESCRIPTIONBOP, RAM 1358" 5M CAMERON "U" (DOUBLE)1DRILL SPOOL 1358" 5M w/ (2) 318" 5M OUTLETS.BOP, RAM 1358" 5M CAMERON "U" (SINGLE)36GATE VALVE, MANUAL 318" 5MGATE VALVE, HYDRAULIC 318" 5M22BOP, ANNULAR 1358" 5M CAMERON T-9012434455556724" HEIGHT.678KILL LINE5API TARGET BLIND FLANGE 318" 5M48DSA 318"5M x 2116" 5M1FF-TICKET #:THIS DRAWING IS SHOWN TRUE SCALE ONLY WHEN PRINTED ON THIS SIZE PAPERTHIS DOCUMENT AND THE INFORMATION CONTAINED HEREIN IS A CONFIDENTIAL DISCLOSURE. IT IS SHOWN TO YOUR COMPANY WITH THE UNDERSTANDING IT IS NOT TO BEREVEALED TO OTHERS OR USED FOR ANY PURPOSE WITHOUT THE WRITTEN CONSENT OF NABORS INDUSTRIES.REV.XREFDESCRIPTION APP.DATEBYTITLE COPYRIGHTEDDATE:DRN BY:ER:BDWG:APP:RIG:SCALE:NABORSSHT NO. OFNABORS RIG 7ES13 5/8" 5M BOP STACK LAYOUT14002 7ESPKM NTS27-MAY-21 SMB7ES-0008-01B REVISED AND ISSUED FOR INFORMATION 07-JUN-21 PKM3470945 01 01DRILLER SIDEOFF DRILLER SIDE DSR-3/22/23SFD 3/24/2023 10-407 VTL 4/24/2023 X Suspension approved through 12/31/2023. P&A, including surface abandonment must be completed by 12/31/2023. X JLC 4/26/2023 4/26/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.26 11:52:26 -08'00' RBDMS JSB 042723 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. 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:Simek, Jill To:Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]KRU 3S-03(PTD 203-091, Sundry 321-563) Sandback/Cement Plug Change APPROVAL Date:Tuesday, December 14, 2021 1:06:17 PM Acknowledged! Thank you Victoria. From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Tuesday, December 14, 2021 10:53 AM To: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 3S-03(PTD 203-091, Sundry 321-563) Sandback/Cement Plug Change APPROVAL CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Jill, Approval is granted to proceed as outlined below. Please include this approval with your copy of the original sundry and on site. Thanx, Victoria From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Tuesday, December 14, 2021 9:25 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: 3S-03 Sandback/Cement Plug (Sundry #321-563) Hi Victoria, Can you give approval for us to proceed on 3S-03 with changes outlined below? Thanks! Jill From: Simek, Jill Sent: Thursday, November 18, 2021 1:52 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: 3S-03 Sandback/Cement Plug (Sundry #321-563) Victoria, Per 3S-03 approved sundry, ConocoPhillips pumped a “water shut-off” sand plug on 11/4/2021 and 11/5/2021. However, the subsequent slickline tag found the plug to be lower than expected. Instead of pumping more sand, ConocoPhillips plans to dump cement on slickline, to bring the plug depth to the originally planned depth of 7,650ft KB. Please let me know if AOGCC approves this change to the procedure. Original Sundry Approval attached, and amended steps below: Slickline: 1. MIRU. 2. RIH and tag top of sand plug at ~7,664 ft KB. 3. RIH with bailer and place cement to 7,650ft KB. Bailer capacity: 2gal/run Approximately 12 runs required 4. RDMO. Allow 48hrs cure time before BOL. Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-4131 | Cell: 907-980-7503 From:Simek, Jill To:Loepp, Victoria T (OGC) Subject:FW: [EXTERNAL]RE: 3S-03 (PTD 203-091) 10-403 Sand Back Date:Wednesday, November 3, 2021 10:18:05 AM Hi Victoria, We have the 3S-03 Sandback job tentatively scheduled for tomorrow, 11/4. Is verbal approval possible? Thanks, Jill From: Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov> Sent: Monday, November 01, 2021 11:36 AM To: Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Cc: Simek, Jill <Jill.Simek@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: [EXTERNAL]RE: 3S-03 (PTD 203-091) 10-403 Sand Back CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Received for processing From: Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Sent: Monday, November 1, 2021 11:28 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Simek, Jill <Jill.Simek@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: 3S-03 (PTD 203-091) 10-403 Sand Back Hello, I have attached the 10-403 for KRU 3S-03 (PTD 203-091) sand Back/ Water Shut-off. Please let me know if you need any additional information. Thank you, Amy Amy A. Conklin Well Integrity Analyst ConocoPhillips Alaska 700 G Street, ATO 1307, Anchorage, AK 99501 Office: (907) 265-1484 Cell: (907) 841-2477 Amy.A.Conklin@conocophillips.com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y Samantha Carlisle at 3:36 pm, Mar 22, 2022 Jill Simek Digitally signed by Jill Simek Date: 2022.03.22 14:53:46 -08'00' RBDMS SJC 032222 DSR-3/22/22SFD 12/30/2024 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: Loepp, Victoria T (OGC) Sent: Tuesday, December 14, 2021 10:53 AM To: Simek, Jill Subject: [EXTERNAL]KRU 3S-03(PTD 203-091, Sundry 321-563) Sandback/Cement Plug Change APPROVAL CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Jill, Approval is granted to proceed as outlined below. Please include this approval with your copy of the original sundry and on site. Thanx, Victoria From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Tuesday, December 14, 2021 9:25 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: 3S-03 Sandback/Cement Plug (Sundry #321-563) Hi Victoria, Can you give approval for us to proceed on 3S-03 with changes outlined below? Thanks! Jill From: Simek, Jill Sent: Thursday, November 18, 2021 1:52 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: 3S-03 Sandback/Cement Plug (Sundry #321-563) Victoria, Per 3S-03 approved sundry, ConocoPhillips pumped a “water shut-oī ” sand plug on 11/4/2021 and 11/5/2021. However, the subsequent slickline tag found the plug to be lower than expected. Instead of pumping more sand, ConocoPhillips plans to dump cement on slickline, to bring the plug depth to the originally planned depth of 7,650Ō KB. Please let me know if AOGCC approves this change to the procedure. Original Sundry Approval aƩached, and amended steps below: Slickline: 1. MIRU. 2. RIH and tag top of sand plug at ~7,664 Ō KB. 3. RIH with bailer and place cement to 7,650Ō KB. Bailer capacity: 2gal/run Approximately 12 runs required 4. RDMO. Allow 48hrs cure Ɵme before BOL. Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-4131 | Cell: 907-980-7503 ! " ! #$ #" # %!# #%# ! #%!# # $ &# " #$ % $ %% $$# # % ! &'! ( " %$# # "%%' ! ))) ))) %* + ,&$'$! -%*% + &"! . % &$$! / % % 0 ($*1% # &"! ( ($ &$! ' , ($ &$! 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y Samantha Carlisle at 11:32 am, Nov 01, 2021 321-563 Jill Simek Digitally signed by Jill Simek Date: 2021.11.01 11:23:45 -08'00' DLB 11/01/2021 DSR-11/1/21 X 10-404 X VTL 11/2/21 dts 11/3/2021 JLC 11/3/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.11.03 12:21:48 -08'00' RBDMS HEW 11/3/2021 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est. 130' of Rathole) 7,796.0 7/8/2019 3S-03 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set IBP 10/26/2021 3S-03 spilch Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 29.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 29.0 Set Depth (ftKB) 3,106.8 Set Depth (TVD) … 2,585.1 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 26.3 Set Depth (ftKB) 7,960.5 Set Depth (TVD) … 6,147.1 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 24.1 Set Depth (ft… 7,543.5 Set Depth (TVD) (… 5,780.7 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) Make Model OD Nominal (in) 24.1 24.1 0.03 HANGER 3.500 8.000 497.7 497.4 4.78 NIPPLE 2.875 CAMCO DS 5.390 7,447.1 5,697.2 30.50 SLEEVE - C 2.812 BAKER CMU 4.490 7,494.6 5,738.2 29.95 LOCATOR 3.000 5.000 7,496.9 5,740.2 29.94 PBR 3.000 BAKER 80-40 5.890 7,510.3 5,751.8 29.87 ANCHOR 2.992 KBH-22 3.500 7,511.2 5,752.6 29.86 PACKER 3.250 BAKER SAB-3 5.968 7,516.1 5,756.9 29.84 MILL 3.720 80-40 4.600 7,535.4 5,773.7 29.73 NIPPLE 2.750 CAMCO D 4.540 7,542.6 5,779.9 29.69 WLEG 2.950 BAKER 4.510 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,678.0 5,897.9 28.94 IBP 2.5" Baker IBP (OAL 11.04', top at 7678') 10/26/2021 0.000 10464043 Mandrels Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) Make Model OD Nominal (in) 2,996.5 2,509.2 46.88 GAS LIFT 2.920 CAMCO KBUG-M 5.390 4,669.4 3,693.8 43.94 GAS LIFT 2.920 CAMCO KBUG-M 5.390 5,901.4 4,556.9 45.73 GAS LIFT 2.920 CAMCO KBUG-M 5.390 6,791.1 5,186.3 43.68 GAS LIFT 2.920 CAMCO KBUG-M 5.390 7,395.4 5,652.9 31.75 GAS LIFT 2.920 CAMCO KBUG-M 6.018 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,996.5 2,509.2 46.88 1 GAS LIFT GLV BK5 0.188 2,286.0 5/13/2015 2 4,669.4 3,693.8 43.94 1 GAS LIFT DMY BK5 0.000 0.0 5/13/2015 3 5,901.4 4,556.9 45.73 1 GAS LIFT DMY BK5 0.000 0.0 6/22/2003 4 6,791.1 5,186.3 43.68 1 GAS LIFT DMY BK5 0.000 0.0 6/22/2003 5 7,395.4 5,652.9 31.75 1 1/2 GAS LIFT OV RK 0.250 0.0 5/13/2015 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,633.0 7,666.0 5,858.6 5,887.4 C-4, 3S-03 6/26/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg ph Notes: General & Safety End Date Annotation 12/17/2010 NOTE: View Schematic w/ Alaska Schematic9.0 3S-03, 11/1/2021 9:20:12 AM Vertical schematic (actual) PRODUCTION; 26.3-7,960.5 IBP; 7,678.0 IPERF; 7,633.0-7,666.0 WLEG; 7,542.6 NIPPLE; 7,535.4 TUBING COLLAR; 7,521.7 MILL; 7,516.1 PACKER; 7,511.2 ANCHOR; 7,510.3 PBR; 7,496.9 LOCATOR; 7,494.6 SLEEVE - C; 7,447.1 GAS LIFT; 7,395.4 GAS LIFT; 6,791.1 GAS LIFT; 5,901.4 GAS LIFT; 4,669.4 SURFACE; 29.0-3,106.8 GAS LIFT; 2,996.5 NIPPLE; 497.7 CONDUCTOR; 29.0-108.0 HANGER; 24.1 KUP PROD KB-Grd (ft) 33.26 Rig Release Date 6/22/2003 3S-03 ... TD Act Btm (ftKB) 7,970.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032045800 Wellbore Status PROD Max Angle & MD Incl (°) 47.43 MD (ftKB) 2,923.23 WELLNAME WELLBORE3S-03 Annotation Last WO: End DateH2S (ppm) 80 Date 10/14/2014 Comment SSSV: NIPPLE 1 Winston, Hugh E (CED) From:Carlisle, Samantha J (CED) Sent:Wednesday, March 10, 2021 11:00 AM To:Winston, Hugh E (CED) Subject:FW: Cancel Sundry 320-347 From: Conklin, Amy A (Swift Technical Services LLC) <Amy.A.Conklin@contractor.conocophillips.com> Sent: Wednesday, March 10, 2021 10:59 AM To: Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov> Cc: Simek, Jill <Jill.Simek@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: Cancel Sundry 320‐347 Hi Samantha, Please cancel sundry # 320‐347 for 3S‐03 (PTD 203‐091) Sandback Water Shutoff. We will not be completing this work until later in the year and we will reapply at that time. Thank you, Amy Amy A. Conklin Well Integrity & Interventions Technical Aide ConocoPhillips Alaska (Fairweather, LLC) 700 G Street, ATO 1307, Anchorage, AK 99501 Office: (907) 265-1484 Cell: (907) 841-2477 Amy.A.Conklin@contractor.conocophillips.com RBDMS HEW 3/10/2021 Originated:Delivered to:15-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 2V-02 50-029-21037-00 906786479 Kuparuk River Multi Finger Caliper Field & Processed 30-Oct-20 0 1 2 2V-02 50-029-21037-00 n/a Kuparuk River Hole Finder Record Field- Final 8-Oct-20 0 1 3 2V-02 50-029-21037-00 n/a Kuparuk River Packer Setting Record Field- Final 10-Oct-20 0 1 4 2V-02 50-029-21037-00 n/a Kuparuk River Hole Finder Record Field- Final 25-Oct-20 0 1 5 3C-12 50-029-21354-00 906791278 Kuparuk River Multi Finger Caliper Field & Processed 28-Oct-20 0 1 6 3C-12 50-029-21354-00 906786466 Kuparuk River Packer Setting Record Field- Final 28-Oct-20 0 1 7 3N-07 50-029-21539-00 906745120 Kuparuk River Multi Finger Caliper Field & Processed 3-Oct-20 0 1 8 3S-03 50-103-20458-00 n/a Kuparuk River Plug Setting Record Field- Final 3-Oct-20 0 1 9 10 PLEASE 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 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/16/2020 12/16/2020 Abby Bell PTD: 2030910 E-Set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y Samantha Carlisle at 4:49 pm, Aug 20, 2020 320-347 Jill Simek Digitally signed by Jill Simek Date: 2020.08.20 16:31:35 -08'00' SFD 8/20/2020VTL 8/28/20 SFD 8/20/2020 10-404 DSR-8/20/2020 -00 X " 8/28/2020 JLC 8/28/2020 RBDMS HEW 8/31/2020 ! !" 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' ' ' " 6 7!'8(89(+# $+ -&/ 6 '0 9): '+ C 4!(2 + -,1+0 61>+ Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est. 130' of Rathole) 7,796.0 7/8/2019 3S-03 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag Depth 7/8/2019 3S-03 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 29.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 29.0 Set Depth (ftKB) 3,106.8 Set Depth (TVD) … 2,585.1 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 26.3 Set Depth (ftKB) 7,960.5 Set Depth (TVD) … 6,147.1 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 24.1 Set Depth (ft… 7,543.5 Set Depth (TVD) (… 5,780.7 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 24.1 24.1 0.03 HANGER FMC GEN V TUBING HANGER 3.500 497.7 497.4 4.78 NIPPLE CAMCO DS NIPPLE w/ 2.875" NO GO 2.875 7,447.1 5,697.2 30.50 SLEEVE - C BAKER CMU SLIDING SLEEVE w/ CAMCO 2.812" NO GO PROFILE (Closed 10/1/2014) 2.812 7,494.6 5,738.2 29.95 LOCATOR LOCATOR SUB & PBR SEAL ASSEMBLY 3.000 7,496.9 5,740.2 29.94 PBR BAKER 80-40 PBR/SBR 3.000 7,510.3 5,751.8 29.87 ANCHOR KBH-22 ANCHOR TUBING SEAL NIPPLE 2.992 7,511.2 5,752.6 29.86 PACKER BAKER SAB-3 PACKER 3.250 7,516.1 5,756.9 29.84 MILL 80-40 MILLOUT EXTENSION 3.720 7,535.4 5,773.7 29.73 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,542.6 5,779.9 29.69 WLEG WLEG w/ SHEAR OUT SUB 2.950 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,633.0 7,666.0 5,858.6 5,887.4 C-4, 3S-03 6/26/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg ph 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 2,996.5 2,509.2 CAMCO KBUG- M 1 GAS LIFT GLV BK5 0.188 2,286.0 5/13/2015 2 4,669.4 3,693.8 CAMCO KBUG- M 1 GAS LIFT DMY BK5 0.000 0.0 5/13/2015 3 5,901.4 4,556.9 CAMCO KBUG- M 1 GAS LIFT DMY BK5 0.000 0.0 6/22/2003 4 6,791.1 5,186.3 CAMCO KBUG- M 1 GAS LIFT DMY BK5 0.000 0.0 6/22/2003 5 7,395.4 5,652.9 CAMCO KBUG- M 1 1/2 GAS LIFT OV RK 0.250 0.0 5/13/2015 Notes: General & Safety End Date Annotation 12/17/2010 NOTE: View Schematic w/ Alaska Schematic9.0 3S-03, 8/19/2020 1:14:46 PM Vertical schematic (actual) PRODUCTION; 26.3-7,960.5 IPERF; 7,633.0-7,666.0 WLEG; 7,542.6 NIPPLE; 7,535.4 TUBING COLLAR; 7,521.7 MILL; 7,516.1 PACKER; 7,511.2 ANCHOR; 7,510.3 PBR; 7,496.9 LOCATOR; 7,494.6 SLEEVE - C; 7,447.1 GAS LIFT; 7,395.4 GAS LIFT; 6,791.1 GAS LIFT; 5,901.4 GAS LIFT; 4,669.4 SURFACE; 29.0-3,106.8 GAS LIFT; 2,996.5 NIPPLE; 497.7 CONDUCTOR; 29.0-108.0 HANGER; 24.1 KUP PROD KB-Grd (ft) 33.26 Rig Release Date 6/22/2003 3S-03 ... TD Act Btm (ftKB) 7,970.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032045800 Wellbore Status PROD Max Angle & MD Incl (°) 47.43 MD (ftKB) 2,923.23 WELLNAME WELLBORE3S-03 Annotation Last WO: End DateH2S (ppm) 80 Date 10/14/2014 Comment SSSV: NIPPLE Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760 fax Delivered to: a AOGCC ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision • 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 20309 r TRANSMI7TAl DATE � • TRANSMITTAL# WELL NAME API # SERVICE ORDER d SERVICE FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE Color DATE LOGGED Prints CD's A Transmittal Receipt signature confirms that a package (box, / ,�/� G envelope, etc.) has been received and the contents of the X �J l package have been verified to match the media noted above. SAat I Date The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this return via courier or sign/scan and email a copyto Sch umberger and CPA]. point. Schlumberger -Private . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comrn. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14, 2006 RE: MWD Formation Evaluation Logs: 3S-03, 3S-06, 3S-06A, 3S-08 3S-08A 3S-08B,3S-l4, - - 3S-15. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3S-03: Qö:3 -ODl/ -d: I4fV~d. Digital Log Images: 50-103-20458-00 1 CD Rom 3S-06: l>:rc.. 803 -OS-"?- r:t-¡L.{'-/é93 Digital Log Images: 50-103-20454-00 SCANf.ED FEB 0 1 2007 1 CD Rom 3S-06A: u::r:~ QO"3-()ÍS"~ :It /LIL./Ð-I Digital Log Images: 50-103-20454-01 3S-08 3S-08A 3S-08B: dD3 -Od~ j dó3 -O~ I ;;0"3-043 Digital Log Im~ges: ~ ¡'-/4.fÐS ¡'-/L¡Q(P I..{L/d7- 50-103-20450-00, 01, 02 1 CD Rom 1 CD Rom 3S-14: UI~ dÓ~-d!O 11: IL.¡L/{)O Digital Log Images: 50-103-20439-00 1 CD Rom 3S-15: dOd -;)54 ti 1'-/'-/;)'-/ Digital Log Images: 50-103 - 20444-00 1 CD Rom t Scbllll~BPgel' 12/19/06 Œ~ __~._.~ e NO. 4077 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ,er' ,'~u\-,n,;.;¡' .) '-1-1 .J ., ¡ ~'-' ,,;¡ ;b) {":.' é;03-óc;¡ Field: Kuparuk Well BL CD Job# Date Color Log Description 1 R-03A (REDO) 11483497 INJECTION PROFILE 11/30/06 1 1 B-09 11483500 INJECTION PROFILE 12/03/06 1 3S-26 11538769 INJECTION PROFILE 12/10/06 1 1 F-04 11538770 INJECTION PROFILE 12/11/06 1 3S-08B 11538771 PRODUCTION PROFILE 12/12/06 1 3H-10B 11534187 PRODUCTION PROFILE 12/08/06 1 1J-136 11534188 US IT 12/10/06 1 2M-12 11534189 PRODUCTION PROFILE 12/11/06 1 1F-10 11534192 INJECTION PROFILE 12/12/06 1 1 Y -27 N/A PRODUCTION PROFILE 12/14/06 1 2Z-20 N/A SBHP SURVEY 12/15/06 1 1 H-21 11551832 SBHP SURVEY 12/16/06 1 1 F-05 N/A INJECTION PROFILE 12/13/06 1 1 F-09 11548550 PRODUCTION PROFILE 12/14/06 1 3S-03 11551831 PRODUCTION PROFILE 12/15/06 1 3J-18 11548550 PRODUCTION PROFILE 12/16/06 1 1 H-14 11551835 SBHP SURVEY 12/18/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . . ~illips Alaska RECEIVED AUG 0 9 2006 Alaska Oil & Gas Cons. Commission k , _ Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 7, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 clÓ3- øq I 3£,:·-03 ~" -.- -" IU(~¡\ (; /1\ SC^N~'lt:.C H 1 'J 0 ..'- Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on November 18,2003 and was previously reported to the Commission as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 4 -5, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7043, if you have any questions. Sincerely, J ~: C-/ ConocoPhillips Well Integrity Supervisor Attachment ~ ,~ . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field Au ust 7,2006 Well Name Initial top Vol. of cement Final top of Cement top PTD # of cement urn ed cement off date ft bbls ft Corrosion inhibitor/ sealant date 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite] 00 Anchorage, Alaska 9950] February] 1, 2004 13lQ-r3 RE: MWD Fonnation Evaluation Logs 3S-03, AK-MW-2482635 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Speny-Sun Dri1ling Services, 6900 Arctic Blvd., Anchorage, AK 99518 .., C' 0 ',:Z ~: C)......) - '_J Digital Log Images 50-103-20458-00 ;J03-0Q \ ./ 1 CD Rom /\ -- 0~ / ~I'Ø/rh ~ ~ J \N~ Â.' Ii¡ \~ DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 Permit to Drill 2030910 Well Name/No. KUPARUK RIV UNIT 3S-03 Operator CONOCOPHILLlPS ALASKA INC 5 (.Ad- ì ))....-.- ~ 3 API No.~0-103-20458-00-00 MD 7970 ~ , I 5'"~ TVD 64'56 .--- Completion Date 6/26/2003 -- Completion Status 1-01L - REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Type ~/ qø Electr Digital Dataset Med/Frmt Number D Asc Name Directional Survey hiS VCI ;fiootion J"'\ ~ K {J 3 Log Log Scale Media Run No final ~o D jßPt WD Asc Jµg/ I i LIS Verification Directional Survey Perforation 3 final 5 Blu Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? '~ Daily History Received? Formation Tops Analysis Received? v...LbI--- Comments: ------~ 'L t Compliance Reviewed By: Interval Start Stop o 7970 3086 7938 3086 o 7350 Current Status 1-01L UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) OH/ CH Open Open ~ Received Comments 7/1/2003 MWD 7/1/2003 br; ËUJ'~ ~ ~í..:,n~1 c¡Vf/" '..s~ ß¡ A(:)y: ^-(~£, ¡ i 7938 7970 7778 Open 7/1/2003 Open 7/1/2003 Case 7/23/2003 Perforating Record w/Jewelry Log & SBHP Sample Set Number Comments &/N jJ;/N - Date: fj ~ ~~- ') Conoc;Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 26,2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 ) ~~C€'/(Ij Ví:c ~D ~(¡<IGas~ 1 ¿>UOJ ~, Dear Mr. Maunder: Enclosed please find a spreadsheet with a short list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the circulation ports in the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. The top-fill operation was completed on November 18,2003. Dowell-Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender for each well. The cement was pumped from the bottom of the void to the top of the conductor on each well via high-pressure hose. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call Nina Woods or me at 907-659-7224, if you have any questions. Sincerel~, ~'l' I"~, ,l /:~7 // " .,,/ / //< /7 -~ /", L' /' / ,.:,/~ MJ / ConocoPhillips Problem Well Supervisor Attachment ::t:.\.'\ ~~~«. ~'~N.~" ~,'-<t~~~- +0 tr ~\\ 'o~c:.-'<_t. ~~~ b<:d"~ ~~.".S~...> \ \ '-/ I:..~""«-"~~ -\ð S<::.~. Þ. \ \ o~ -\-'-'a. "TC:> <...'t ~~" S ~~ I.::>«-'l-'J f\.CLo.~ +"<ë. S~~~. \--.J 0 .Çù ~4- "" <L \ a.. c:. ~ \ 0 '" t\<"L<::t.. <:ð<:.t.., 'i ß-)!.¥7l~Á-a-S ' ,.,,' ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-o Kuparuk Field Well Well TOC Volume Sacks Name PTD# Type ft BBLS Cement 3S-03 2030910 Prod 8 0.6 3.6 3S-07 2021870 Prod 8 1.5 9.1 3S-09 2022050 Inj 14 2.5 15.1 3S-1 0 2022320 Prod 12 1.5 9.1 3S-14 2022210 Inj 3 1.5 9.1 3S-15 2022540 Prod 8 0.8 4.8 3S-17 A 2030800 Prod 12 1.1 6.6 3S-18 2022060 Prod 10 1.1 6.6 38-19 2030960 Prod 5 1.1 6.6 38-21 2030310 Inj 5 0.5 3.0 38-22 2030110 Inj 7 0.9 5.4 3S-23 2030450 Prod 2 0.3 1.8 ') ) ; Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocriP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 July 21 , 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 3S-03 (APD # 203-091) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 38-03. If you have any questions regarding this matter, please contact me at 265-6830 or Scott Lowry at 265-6869. Sincerely, 0~~ R. Thomas Kuparuk Drilling Team Leader CP AI Drilling RT/skad RECEr\!Er~ . , ~ ~ .=.... ~k""(· JUL 2 2 2003 Alaskï3 Oil & ~\f:chorJ'::;;~ OR\G\Ni\L ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged 0 Abandoned 0 20AAC 25.105 Suspended 0 WAG D 20AAC 25.110 Gas U 1a. Well Status: Oil 0 1b. Well Class: Development 0 Exploratory 0 Service D Stratigraphic Test D 12. Permit to Drill Number: WINJ 0 WDSPL 0 GINJ D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): No. of Completions _ Other 5. Date Comp., Susp., ~/J:> or Aband.: JuneX2003 6. Date Spudded: June 13, 2003 7. Date TD Reached: June 20, 2003 8. KB Elevation (ft): RKB 24' 9. Plug Back Depth (MD + TVD): 7791' MD 1 5997' TVD 10. Total Depth (MD + TVD): 7970' MD 1 6156' TVD 203-091 1 13. API Number: 50-1 03-20458-00 14. Well Name and Number: 3S-03 15. Field/Pool(s): Kuparuk River Field Kuparuk River Oil Pool Surtace: 2469'FNL, 857'FEL, Sec. 18,T12N, R8E,UM At Top Productive Horizon: 194' FNL, 4263' FEL, Sec. 19, T12N, R8E, UM Total Depth: 294'FNL,4386'FEL,Sec. 19,T12N, R8E,UM 4b. Location of Well (State Base Plane Coordinates): Surtace: x-476403 y- TPI: x- 472999 y- Total Depth: x- 472875 y- 18. Directional Survey: Yes 0 NoU 16. Property Designation: ADL 380107 Zone-4 Zone-4 Zone- 4 5993946 5990953 5990853 11. Depth where SSSV set: Land Nipple @ 498' 17. Land Use Permit: ALK 4624 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1619' MD 21. Logs Run: GR/Res, Density-Neutron 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surtace 108' Surtace 3107' Surtace 7961' CEMENTING RECORD AMOUNT PULLED CASING SIZE WT. PER FT. 16" 62.5# 9.625" 40# 7" 26# GRADE B L-80 L-80 HOLE SIZE 96 sx ArticCrete 42" 430 sx ASLite & 270 sx LiteCrete 12.25" 8.5" 256 sx Class G w/GlasBok TUBING RECORD DEPTH SET (MD) 7544' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 24. SIZE PACKER SET (MD) 7511' 3.5" 7633' - 7666' MD 5859' - 5887' TVD 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) July 7, 2003 Flowing Date of Test Hours Tested Production for OIL~BBL GAS-MCF WATER-BBL CHOKE SIZE 7/15/2003 7.5 hours Test Period --> 1662 706 686 100% Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 256 psi 1530 24~Hour Rate ~> 4872 2611 2007 n~v~l§. 27,' .... , . CORE DATA . N:r:l~t:r\lErJ: Bnef descnptlon of lithology, pOroSity, fractures, apparent dips and presence of 011, gas or water (attach separate sheet, If necessary). ~,," ,-"~". GAS-OIL RATIO 536 JUL 2 .2 2003 Submit core chips; if none, state "none". rL(:::~~;';~:':':~:;' ~ ~:;'.;··l 4 "". __ ' f ~~:.~ ! 'Þ1F -; - ---,¡ .-.....,,' .. , ""1." \......-..-~,.ì A~ask2 0;1 [1 C:u;,} NONE Form 10-407 Revised 2/2003 CONTINUED O~E~I., R~, E, SIDE, _ . '4, "J f f', 1 . Ml60". G« OR\G\NAL Submit in duplicate ~8fL. 28. \ ) 29. ') GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. list intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 3S-03 Top C Sand Top A Sand 7635' 7665' 5860' 5886' N/A V·~ E"" {'" ), E C E' .... t:,:::, ,',..~ JUl 2 2 2003 MaS\la Œ\ & 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Scott Lowry @ 265-6869 Printed Na~ ~. IT~n. mas ( Sìgnature \ ' ~\ \.. ~ Title: Kuparuk Drilling Team Leader t-'ft1:::1I'':¡ Date 7/'2.. ..(D) Prepared by Sharon AI/sup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: list all test information. If none, state "None". Form 10-407 Revised 2/2003 ORIG\NAL ) ) ... ....< .. .pon()çbPhililips~I~§~~< >...... .. .' . .. .. . . . ,:.. :.....:.:......."' . ." ,". .. ".". ..... . "' . .. ...... ".' ......... .. ." "". . ... . ()pe~âti.;()ns..~lJf1'1rl1~ry ···Flep(jrt Rigged down and moved from 3S-24 to 3S-03. Rigged up. Accepted rig @ 1215 Hrs. 06/12/03. Nippled up riser and connected flowline. Installed berms around cellar, ball mill, and injection skid. Picked up tools and cleared rig floor. Loaded pipe shed with 90 Jts. DP and 24 Jts. HWDP. Picked up DP and stood back in derrick. PJSM and rigged up slick line for Gyro. Finished picking up DP and HWDP stood back in Derrick. Picked up BHA. Picked up BHA and shifted stabilizers to correct position. Orient tools. Filled conductor and checked for leaks. Tested lines to 3000 PSI. Spudded well @ 0315 Hrs. Drilled and kicked off well with 121/4" hole from 80' to 1167'. ART 3.61 Hrs. AST 3.74 Hrs. TD RPM 70. WOB 10/15 K. GPM 477. Torque Off Btm. 3000 Ft Lbs. On Btm. 4000 Ft Lbs. Up Wt 80 K. Down 60 K. Rot 70 K. Worked on mud pumps. Drilled 12 1/4" hole from 1167' to 1890'. ART 1.51 Hrs. AST 3.28 Hrs. TO RPM 70. WOB 10/15 K. GPM 477. Torque Off Btm. 4000 Ft Lbs. On Btm. 4000 Ft Lbs. Up Wt 85 K. Down 68 K. Rot 80 K. Drilled 12 1/4" hole from 1890' to 3117'. ART 6.98 Hrs. AST 1.14 Hrs. TD RPM 100. WOB 10/12 K. GPM 550. Torque Off Btm. 5000 Ft Lbs. On Btm. 8000 Ft Lbs. Up Wt 110 K. Down 85 K. Rot 85 K. Circulated @ 550 GPM pumped sweeps and dropped two carbide lags, Did not see the carbide on gas detector. POOH SLM. Laid down BHA. Rigged up to run casing. PJSM for casing job. Ran 28 Jts. 9 5/8" 40# L 80 BTC casing. Ran 52 Jts. 95/8" 40# L-80 BTC casing (Ave make up 9000 Ft Lbs) to 3107' circulating every 1000'. CBU increasing rate to 7 BPM. Rigged down GBR fill up tool and RU Dowell cement head. Circulated and conditioned mud for cementing. PJSM. RU Dowell, Pumped 10 bbls CW 100 Chem Wash, Tested Lines to 3,500 Psi, Pumped 40 bbls CW 100 Chem Wash at 8.3 ppg @ 6 Bpm @ 175 Psi, Red Dye in CW 100 Spacer, Dropped Btm Plug, Mixed & Pumped 327.7 bbls, 430 sxs of Lead Cmt. Arctic Set @ 10.7 ppg & 4.28 Yield, Ave rate 6.3 bpm @ 150 Psi, , Observe Nut Plug at Shaker Switched to Tail Cmt, Pumped 270 sxs (107.7 bbls) of Lite Crete Cmt @ 12.0 ppg & 2.29 Yield,Pumped @ 6.3 Bpm @ 180 Psi, Dropped Top Plug & Dowell Pumped 20 bbls Wash Water, Turned over to Rig, Rig Pumped 214.0 bbls of 9.3 ppg mud, Ave Disp Rate 7.0 bpm @ 450 Psi, Reciprocated Pipe Until Lead Cmt was at surface -Landed Csg, Slowed to 3 bpm @ 380 Psi, Did not bumped Plug, Used 95% Eff on Rig Pumps to calc.displacement, Had 158.9 bbls of 10.7 ppg Cmt back to Surface, Had Full Returns throughout Job- CIP at 0940 Hrs 6/15/03, Check Floats & Held 1.00 CEMENT RURD SURFAC Rigged down cement head, laid down landing jt. and changed bales. 1.00 CEMENT RURD SURFAC Nippled down riser. 1.00 CASE NUND SURFAC Installed and tested FMC speed head. 1.50 WELCTL NUND SURFAC Nippled up BOP. Legal Well Name: 3S-03 Common Well Name: 3S-03 Event Name: ROT - DRILLING Contractor Name: N 1268 @ ppco.com Rig Name: Nabors 7ES Date· From;.To Hours.. ··Codß Sub Phas¢ Code 6/12/2003 06:00 - 12:15 6.25 MOVE MOVE MOVE 12:15 - 14:30 2.25 DRILL RIRD SURFAC 14:30 - 15:30 1.00 DRILL RIRD SURFAC 15:30 - 16:00 0.50 DRILL OTHR SURFAC 16:00 - 17:15 1.25 DRILL PULD SURFAC 17:15 - 19:45 2.50 DRILL PULD SURFAC 19:45 - 20:30 0.75 DRILL RIRD SURFAC 20:30 - 23: 15 2.75 DRILL PULD SURFAC 23:15 - 00:00 0.75 DRILL PULD SURFAC 6/13/2003 00:00 - 02:45 2.75 DRILL PULD SURFAC 02:45 - 03: 15 0.50 DRILL OTHR SURFAC 03:15 - 15:30 12.25 DRILL DRLG SURFAC 15:30 - 17:00 1.50 RIGMNT RGRP SURFAC 17:00 - 00:00 7.00 DRILL DRLG SURFAC 6/14/2003 00:00 - 11 :30 11.50 DRILL DRLG SURFAC 11 :30 - 13:45 2.25 DRILL CIRC SURFAC 13:45 - 16:45 3.00 DRILL TRIP SURFAC 16:45 - 19:30 2.75 DRILL PULD SURFAC 19:30 - 21:15 1.75 CASE RURD SURFAC 21:15 - 21:30 0.25 CASE SFTY SURFAC 21 :30 - 00:00 2.50 CASE RUNC SURFAC 6/15/2003 00:00 - 04:00 4.00 CASE RUNC SURFAC 04:00 - 05:00 1.00 CASE CIRC SURFAC 05:00 - 05:30 0.50 CASE RURD SURFAC 05:30 - 07:30 2.00 CEMENTCIRC SURFAC 07:30 - 10:00 2.50 CEMENT PUMP SURFAC 10:00 - 11 :00 11 :00 - 12:00 12:00 - 13:00 13:00 - 14:30 Start: 6/5/2003 Rig Release: 6/22/2003 Rig Number: Spud Date: 6/13/2003 End: 6/22/2003 Group: . .' .. . . . DèscriptlonofOperationá . Printed: 7/11/2003 11:19:15AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-03 3S-03 ROT - DRILLING N1268@ppco.com Nabors 7ES . [)a.te ... Sub FrQrn-To HÖur$QOde· Códê.. Start: 6/5/2003 Rig Release: 6/22/2003 Rig Number: Spud Date: 6/13/2003 End: 6/22/2003 Group: . ,.. . . , . .... .... '" . .. . < Desçtiption qf Qþefé~tiör1s 6/15/2003 14:30 - 15:00 15:00 - 18:00 0.50 WELCTL BOPE SURFAC 3.00 WELCTL BOPE SURFAC 6/16/2003 18:00 - 18:30 18:30 - 19:30 19:30 - 20:00 20:00 - 00:00 00:00 - 04:00 04:00 - 06: 15 06:15 - 07:45 07:45 - 09:00 09:00 - 10:45 10:45 - 11 :45 11 :45 - 12:30 12:30 - 12:45 12:45 - 00:00 0.50 DRILL OTHR 1.00 RIGMNT RSRV 0.50 RIGMNT RSRV 4.00 DRILL PULD 4.00 DRILL PULD 2.25 DRILL TRIP 1.50 DRILL CIRC 1.25 DRILL DEaT 1.75 DRILL OTHR 1.00 DRILL CIRC 0.75 DRILL FIT 0.25 DRILL OTHR 11.25 DRILL DRLG SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC 6/17/2003 00:00 - 19:15 19.25 DRILL DRLG INTRM1 19:15 - 20:45 1.50 DRILL CIRC INTRM1 20:45 - 22:00 1.25 DRILL CIRC INTRM1 22:00 - 22:30 0.50 DRILL TRIP INTRM1 22:30 - 22:45 0.25 DRILL CIRC INTRM1 22:45 - 00:00 1.25 DRILL OBSV INTRM1 6/18/2003 00:00 - 02:15 2.25 DRILL CIRC INTRM1 02:15 - 02:30 0.25 DRILL TRIP INTRM1 02:30 - 03:00 0.50 DRILL CIRC INTRM1 03:00 - 04:30 1.50 DRILL DRLG INTRM1 04:30 - 05:15 0.75 DRILL CIRC INTRM1 05:15 - 06:15 1.00 DRILL DRLG INTRM1 06:15 - 07:15 1.00 DRILL TRIP INTRM1 07:15 - 10:00 2.75 DRILL TRIP INTRM1 10:00 - 10:30 0.50 DRILL TRIP INTRM1 3.75 DRILL TRIP INTRM1 10:30 - 14:15 Pick up and set test plug. filled stack with water. Tested BOP's, Choke Manifold & Valves to 250 psi Low, 5,000 Psi High, Annular to 250/3,500 psi, with Test Pump, Note: John Spaulding with AOGCC Waived Witnessing of Test, RD Test Tools and Install Wear Bushing. Blow down test pump and kill line. Slipped and cut 81' drilling line. Serviced top drive. Pick up and stand back 75 Jts. 5" DP. Picked up and made up BHA. RIH picking up 5" DP to 2966' tagged cement. Circulated out clabbered mud and cleaned hole. Rigged up and tested casing 2500 PSI for 30 min. Drilled shoe track, cleaned out rat hole and drilled 20' to 3137'. Displaced to LSND mud system. Rigged up and did FIT to 18 PPG EMW. Blow down choke and kill lines and prepare to drill. Drilled 8.5" directional hole from 3137' to 4556'. ART 6.63 Hrs AST .12 Hrs. TD RPM 100, WOB 15/30 K, GPM 550, PP 2312 PSI. Up Wt 110 K, Down 85 K, Rot 95 K. Torque Off Btm 5000 On 6000 to 7000 Ft. Lbs. Drilled 8.5" directional hole from 4556' to 6855'. ART 11.17 Hrs AST .5 Hrs. TD RPM 100, WOB 15/30 K, GPM 550, PP 3370 PSI. Up Wt 140 K, Down 100 K, Rot 120 K. Torque Off Btm 10000 On 9500 to 10000 Ft. Lbs. Lost returns at Est. 160 Bbls./Hr. Put well on trip tank while mixing LCM pill. Hole static while not pumping. Spotted 29 Bbls LCM pill mixed @ 20 Lbs/Bbl. pumped at 200 GPM 661 PSI. lost 77 Bbls. while spotting pill. Losing 66 Bbls/Hr. POOH to 6489'. Circulated and checked loss rates 66 Bbls/Hr at 210 GPM. Total mud lost 330 Bbls. Checked well flowing slowly with pump off. Did exhale test while mixing LCM pill and building volume. No Pressure. Worked pipe while building mud volume. RIH to 6855' Pumped 30 Bbl. LCM pill with 20 PPB LCM @ 300 GPM losses down to 60 BPH. Attempted to drill (cleaned pump screens) but were not getting any response from mud motor. Tried to unball bit no success. Unable to get differiental pressure on bottom. Stood back 1 stand and mixed nut plug pill to unball BHA. Mixed LCM pill. Pumped nut plug and attempted to drill without success. Losing 100 PSI when weight was put on bit. Spotted 30 Bbl20 PPB LCM pill on bottom and POOH to check mud motor. Backream tight hole from 6394' to 6205',168 gpm 1540 psi, 60 rpm. Increased pumps to 410 gpm 11590 psi, 85 rpm and backream from 6205' to 5636' - Rot up wt. 127K torque 9-13K to 5921' 1 8-10K f/5921 t/ 5636'. Monitor well, static. POH from 5636' to 5500' worked through tight sopts 30-40K over, well swabbing. Backream from 5500' to 4317',410 gpm 1 1520 psi 1 85 rpm. Rot up wt. Printed: 7/11/2003 11:19:15AM ) ) . ... ........... .··9Ónpcof>hillipsAI~Sk~ .... ···.·Operijtiol'1$ §l.Jl11rnäry:Rf3p().rt Legal Well Name: 3S-03 Common Well Name: 38-03 Event Name: ROT - DRILLING Contractor Name: N1268@ppco.com Rig Name: Nabors 7E8 Date Frorn·-Tþ Hours Code· Sub Cbdê 6/18/2003 10:30 - 14:15 3.75 DRILL TRIP INTRM1 14:15 - 14:30 0.25 DRILL TRIP INTRM1 14:30 - 16:00 1.50 DRILL TRIP INTRM1 16:00 - 16:30 0.50 DRILL TRIP INTRM1 16:30 - 16:45 0.25 DRILL OBSV INTRM1 16:45 - 19:00 2.25 DRILL TRIP INTRM1 19:00 - 22:00 3.00 DRILL PULD INTRM1 22:00 - 22:30 0.50 DRILL PULD INTRM1 22:30 - 00:00 1.50 DRILL PULD INTRM1 6/19/2003 00:00 - 01 :30 1.50 DRILL PULD INTRM1 01 :30 - 02:45 1.25 DRILL TRIP INTRM1 02:45 - 04:00 1.25 RIGMNT RSRV INTRM1 04:00 - 06:00 2.00 DRILL TRIP INTRM1 06:00 - 07:00 1.00 DRILL CIRC INTRM1 07:00 - 16:15 9.25 DRILL DRLG INTRM1 Start: 6/5/2003 Rig Release: 6/22/2003 Rig Number: Spud Date: 6/13/2003 End: 6/22/2003 Group: 1.50 DRILL CIRC INTRM1 Circ to lower ECD, reduced LCM additions to 0.5 ppb and increased mud wt. to 11.35 ppg - 480 gpm / 2150 psi / 12.4 ppg ECD - no further losses. 6.25 DRILL DRLG INTRM1 Drill from 7458' to 7844'. ART 3.51 Hrs. AST 0 Hrs. PUW 190K SOW 125K ROT 150 K - 480 GPM / 2461 psi Torque on/off 12K / 13.5K Max gas 839 IU from top of Kup Sd. Top of K 1 7555' MD 5791' TVD Top of Kup. Sand 7636' MD 5861' TVD Base K S 7665' MD 5886' TVD Drill from 7844' to 7970'. ART .72 Hrs. AST 0 Hrs. PUW 195K SOW 130K ROT 155 K - 480 GPM / 2464 psi Torque on/off 12K / 13.5K . CBU and flow checked well. POOH Backreamed 1 st 6 stands. Pulled 2 stands hole was tight on stand #9 with 30 K overpull. Backreamed out to 6667'. Flow checked well. RIH to 7970' with out problem. Circulated and raised MW to 11.6 PPG. 3200 IU of trip gas that lasted 10 mini utes. Spotted LCM pill and POOH backreamed to 6203'. Flow checked well and continued POOH flowchecked at casing shoe and BHA. Laid down BHA. Pulled wear bushing. Rigged up to run casing. PJSM. 16:15 - 17:45 17:45 - 00:00 6/20/2003 00:00 - 02:00 2.00 DRILL DRLG PROD 02:00 - 02:45 0.75 DRILL CIRC PROD 02:45 - 05:00 2.25 DRILL WIPR PROD 05:00 - 06:00 1.00 DRILL WIPR PROD 06:00 - 10:00 4.00 DRILL CIRC PROD 10:00 - 18:30 8.50 DRILL TRIP PROD 18:30 - 21 :30 3.00 DRILL PULD PROD 21 :30 - 22:00 0.50 CASE OTHR PROD 22:00 - 23:30 1.50 CASE RURD PROD 126- 120K / 7 - 8.5K torque. Monitor well, static. Attempted to POH, swabbing. Backream from 4317' to 3190',410 gpm /1450 psi /85 rpm - 5.5-7K torque. Observed increase in cuttings last 3 stands. Increased rate to 500 gpm /2110 psi / 85 rpm / 5.5K torque. Backream from 3190' to 3125' circ 2 x BU, large amount of cuttings back thru first BU. Monitor well, static. POOH to BHA. POOH BHA and downloaded MWD. Found Motor had seized up due to bearing failure. Broke off bit and changed ou t mud motor. Made up bit on new motor and picked up BHA. Tested mud motor and finished picking up BHA. RIH to 3093'. Serviced rig and top drive. Adjusted brakes. RIH to 6955'. Precautionary ream last 80' to bottom - circ and cond mud, staged pumps up to 450 gpm / 1750 psi / 80 rpm 1 OK torque -final ECD 11.57ppg - no losses throughout. PUW 170K SOW 111 K Rot wt 135K Drill from 6855' to 7458'. ART 4.45 Hrs AST 1.56 Hrs. PUW 180K SOW 115K ROT 145K - 480 GPM /2110 psi Torque on/off 12K / 11.5K Pumped 30 bbls 2.5 ppg over mw @ 7085' and 7265' saw slight increase in cuttings with sweep back. Increased mud wt. to 11.15 ppg last 100' drilled, had slight losses -25 bph with 12.88 ppg ECD. Increased LCM additions to 4 ppb regained full returns. Estimated total losses 40bbls. BGG 175-250 units through Moraine - ave 70-125 units below Moraine. Printed: 7/11/2003 11: 19: 15 AM ) ) . . . ··GÓn()êqPhillip~AI~skél. .... ,".. ......,. '. '. '.. ,: .". . ... ,".. .. . ...", . 9P~~élti()n§ISYmrtlé~rYR~þort. ... Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-03 3S-03 ROT - DRILLING N 1268 @ ppco.com Nabors 7ES Start: 6/5/2003 Rig Release: 6/22/2003 Rig Number: Spud Date: 6/13/2003 End: 6/22/2003 Group: Date . Frortt~ TO HOLJrs GOdè Jo~e 6/20/2003 6/21/2003 pescriptionOf Oþeration$ Ran 4 Jts. 7" L 80 26# BTC casing. Run casing to 4501', PUW 118K SOW 82K Stage pumps up to 5.0 bpm /525 psi cond mud, reduce mud in to 11.5 ppg. adding 3 ppb mixll med LCM full returns throughout. Run casing to 6533', PUW 180K SOW 11 OK Stage pumps up to 5.0 bpm / 720 psi full returns for 5 min. then lost all returns. reduce rate to 3.5 bpm (min to keep fill-up tool open, increased LCM additions to 7 ppb, no returns back. Lost 122 bbls of mud. 2.00 CASE RUNC PROD Run casing to 7931', MU hanger and LJ -land casing with shoe @ 7961', FC @ 7791'. 0.33 CEMENT PULD PROD LD fill up tool and MU cement head. 1.92 CEMENTCIRC PROD Pumped 2 - 2.5 bpm / 240 psi, added 7 ppb LCM mud wt in 10.45-10.5 ppg, no retrurns. Reciprocate pipe untill1420 hrs PUW 230K SOW 120K, then pipe stuck on bottom, unable to move pipe with 1 OOK over. PJSM / started batching cement @ 1420 hrs. Lost 315 bbls of mud. 1.00 CEMENT PUMP PROD l.ine up to cementers, pump 10 bbls of CW, test lines to 3500 psi. Pumped additional 10 bbls of CW, drop bottomplug and reload head. Pumped 43 bbls of 12.5 ppg Mudpush, dropped bottom plug and pumped 53.5 bbls of 15.8 G cmt. 1.25 CEMENT DISP PROD Flushed cement line to rig floor, dropped top plug and displaced cement @ 4.5 bpm / 340 - 835 psi, increased rate to 6.0 bpm with Mudpush at shoe 975-1542 psi, slowed rate to 4 bpm last 20 bbls pumped 1275-1700 psi, plugs bumped, floats held, CIP @ 1705'. Rigged down cement head and flushed lines. Installed and tested pack off. Rigged down casing tools and changed bales. Rigged up to run tubing. Picked up and ran Completion. Found a piece of broken metal in first GLM. Waited for Halliburton Slick line to check GLM (MMM 1 1/2" with Ann. shear valve). Inspected GLM with Halliburton SL. Recommended we not run it. Laid down sliding sleeve and 1 Jt. tubing. PU pup Jt and stood back packer. Rigged up to lay down excess drill pipe while waiting on new GLM. Rigged up to lay down DP from derrick. Laid down 141 Jts DP from derrick. Rigged up to run 3.5" tubing. Ran completion on 236 Jts 3.5" tubing 9.3# L-80 EUE Mod. Did pressure injeectivity on 7" X 9 5/8" annulus while running tubing. Flushed and freeze protected. PICKED UP 1 Jt tubing + 5' pup Jt. and made up pumping head. Tested lines, pumped up chart recorder gauge. Tested casing to 3500 PSI for 30 min. on chart Drop Baker 2" packer setting ball. Will set SAB-3 packer @ 7511.19', Slowly pressure 3-1/2" tbg. to 2500 psi. Wait 5 min. Bleed pressure to zero. Slack off to 15K on pkr to comfirm packer set, then pressure tbg string to 3000 psi and hold 5 min. Bleed pressure to 1000 psi. PU 40K over & shear PBR. Bleed pressure to zero. Slack off, tag locator w/ 15K. Pressure tbg to 3500 psi to shear ball seat. Bleed off all pressure. 0.75 CMPL TN PCKR CMPL TN Laid down 1 jt. + pup Jt. Picked up tubing hanger spaced out and landed out tubing spaced 2' out of PBR. Pressured up on annulus and sheared DCR shear out valve with 3500 PSI. 0.50 CMPL TN RURD CMPL TN Laid down landing Jt. and installed 2 way check valve. 1.25 WELCTL NUND CMPL TN Nippled down BOP. 23:30 - 00:00 0.50 CASE RUNC PROD 00:00 - 06:30 6.50 CASE RUNC PROD 06:30 - 07:00 0.50 CASE CIRC PROD 07:00 - 09:30 2.50 CASE RUNC PROD 09:30 - 10:45 1.25 CASE CIRC PROD 10:45 - 12:45 12:45 - 13:05 13:05 - 15:00 15:00 - 16:00 16:00 - 17:15 17:15 - 18:00 0.75 CEMENTRURD PROD 18:00 - 19:00 1.00 CASE DEQT PROD 19:00 - 20:30 1.50 CASE RURD PROD 20:30 - 21 :30 1.00 CMPL TN PULD PROD 21 :30 - 22:30 1.00 CMPL TN OTHR PROD 22:30 - 23:00 0.50 CMPL TN OTHR PROD 23:00 - 23:45 0.75 CMPL TN PULD PROD 23:45 - 00:00 0.25 DRILL PULD PROD 6/22/2003 00:00 - 00:30 0.50 DRILL PULD PROD 00:30 - 05:00 4.50 DRILL PULD PROD 05:00 - 05:30 0.50 CMPL TN RURD CMPL TN 05:30 - 13:00 7.50 CMPL TN RUNT CMPL TN 13:00 - 13:30 0.50 CMPL TN PULD CMPL TN 13:30 - 15:30 2.00 CASE DEQT CMPL TN 15:30 - 17:00 1.50 CMPL TN PCKR CMPL TN 17:00 - 17:45 17:45 - 18:15 18:15 - 19:30 Printed: 7/11/2003 11:19:15 AM ) ') . . . . qohpcoPt1i1IipsAIªska. ..... .' . . .. .. ....... ... .".. . .." .... ()pêrät~on~:§llmmélry .11t~pørf· . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-03 3S-03 ROT - DRILLING N1268@ppco.com Nabors 7ES Start: 6/5/2003 Rig Release: 6/22/2003 Rig Number: Spud Date: 6/13/2003 End: 6/22/2003 Group: 6/22/2003 19:30 - 21 :00 21 :00 - 21 :15 21:15-23:00 SLib' HóursCödè' ÇöëJë 1.50 WELCTL NUND CMPL TN Nippled up Xmas tree and tested to 5000 PSI. 0.25 WELCTL NUND CMPL TN Pulled 2 way check valve. 1.75 CMPLTN FRZP CMPLTN Rigged up Little Red, PJSM, pumped 126 Bbls. diesel down tubing. Tubing pressure after pumping 310 PSI. 1.00 CMPL TN NUND CMPL TN Rigged up FMC lubricator and set back pressure valve. Rigged down and Released rig at 2400 Hrs. 6/22/03. 23:00 - 00:00 Printed: 7/11/2003 11:19:15AM Date 06/12/03 06/13/03 06/24/03 06/26/03 ) } 38-03 Event History Comment RIG SUPPORT, IN PROGRESS. [STANDBY] GYRO RUNS TO 100',190' & 280' SLM, RIG SUPPORT. TAGGED @ 7785' RKB; DRIFTED WI 22' X 2.625" DUMMY GUN TO 7785' RKB; PULLED DCR & SET 1.5" DV @ 7395' RKB, PT'D TBG & CSG TO 3000#, PASSED. [PERF] BHP AT 7650' PRIOR TO PERF= 2527.3 PSIA WITH WHP= 820 PSI -- PERFORATED: 7633' - 7666', 6 SPF -- AFTER PERF SBHP AT 7650'= 3435.3 PSIA, TEMP= 159.5 DEGF AND SBHP AT 7450'= 3360.8 PSIA, TEMP= 151.4 DEGF [PERF] Page 1 of 1 7/11/2003 ) AOGCC Lori Taylor 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ) 30-Jun-03 Re: Distribution of Survey Data for Well 3S-03 Dear Lori Taylor Enclosed are two survey hard copies and one disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 'MD 'MD 7,970.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~D3-D91 RECEIVED JUL 0 1 2003 Alaska o;i & Gas Cons. Commillion Anchomge ~Jð.~ Sperry-Sun Drilling Services Western North Slope ConocoPhillips Kuparuk 38 Pad 38-03 Job No. AKZZ0002482635, Surveyed: 20 June, 2003 Survey Report 26 June, 2003 YourRe!: API 501032045800 Surface Coordinates: 5993946.19 N, 476402.92 E (70023'40.5329" N, 150011'31.1806" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 993946.19 N, 23597.08 W (Grid) Kelly Bushing: 56.06ft above Mean Sea Level Elevation relative to Project V Reference: 56.06ft Elevation relative to Project V Reference: 56.06ft SpE!!r'I''J-!5UJ! DRILLING SERViCes A Halliburton Company JEF N TIVE '-,' Survey Ref: svy2051 Sperry-Sun Drilling Services Survey Report for Kuparuk 35 Pad - 35-03 Your Ref: API501032045BOO Job No. AKZZ0002482635, Surveyed: 20 June, 2003 ConocoPhiflips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) eft) (ft) (ft) (o/100ft) 0.00 0.000 0.000 -56.06 0.00 0.00 N 0.00 E 5993946.19 N 476402.92 E 0.00 Tolerable Gyro 87.00 0.100 12.000 30.94 87.00 0.07 N 0.02E 5993946.26 N 476402.94 E 0.115 -0.07 174.00 0.600 60.000 117.94 174.00 0.38N 0.43 E 5993946.56 N 476403.35 E 0.619 -0.56 AK-6 BP _.IFR~AK 294.82 1.350 180.850 238.75 294.81 0.738 0.95E 5993945.46 N 476403.87 E 1.437 -0.05 383.39 2.850 193.370 327.26 383.32 3.928 0.43 E 5993942.27 N 476403.34 E 1.761 2.72 ---- 478.07 4.380 192.270 421.74 477.80 9.748 0.88W 5993936.45 N 476402.00 E 1.618 8.03 - 567.87 6.190 191.390 511.16 567.22 17.84 8 2.57W 5993928.36 N 476400.29 E 2.018 15.32 656.57 9.240 193.670 599.05 655.11 29.45 8 5.20W 5993916.76 N 476397.63 E 3.455 25.90 750.86 12.070 194.580 691.70 747.76 46.35 8 9.47W 5993899.87 N 476393.30 E 3.007 41.59 839.64 14.660 197.460 778.07 834.13 66.05 8 15.18 W 5993880.19 N 476387.53 E 3.011 60.35 936.93 17.260 204.250 871.61 927.67 90.96 S 24.80 W 5993855.31 N 476377.83 E 3.286 85.62 1031.32 19.130 208.120 961.28 1017.34 117.378 37.84 W 5993828.94 N 476364.71 E 2.358 114.24 1125.63 21.720 213.600 1049.66 1105.72 145.54 8 54.79 W 5993800.82 N 476347.67 E 3.411 146.71 1218.80 23.670 218.770 1135.62 1191.68 174.498 76.05 W 5993771.94 N 476326.32 E 2.992 182.55 1314.05 25.990 223.160 1222.07 1278.13 204.638 102.30 W 5993741.89 N 476299.97 E 3.110 222.51 1410.63 28.350 226.840 1307.99 1364.05 235.76 8 133.51 W 5993710.86 N 476268.67 E 2.999 266.42 1505.46 32.270 230.520 1389.85 1445.91 267.27 8 169.49 W 5993679.46 N 476232.59 E 4.572 313.69 1599.84 36.160 232.050 1467.88 1523.94 300.428 210.91 W . 5993646.43 N 476191.06 E 4.221 365.71 1695.18 39.670 232.070 1543.09 1599.15 336.44 8 257.11 W 5993610.56 N 476144.75 E 3.682 422.99 1789.67 42.240 231.840 1614.44 1670.50 374.61 8 305.88 W 5993572.55 N 476095.86 E 2.725 483.58 1884.47 45.160 233.360 1682.97 1739.03 414.368 357.91 W 5993532.96 N 476043.70 E 3.273 547.48 1979.30 45.200 233.330 1749.82 1805.88 454.52 8 411.87W 5993492.97 N 475989.61 E 0.048 612.93 2074.38 44.500 234.060 1817.22 1873.28 494.22 S 465.91 W 5993453.44 N 475935.45 E 0.914 678.08 2168.33 46.410 232.010 1883.13 1939.19 534.50 8 519.39 W 5993413.33 N 475881.85 E 2.559 743.31 2262.74 46.800 232.110 1947.99 2004.05 576.68 8 573.49 W 5993371.33 N 475827.61 E 0.420 810.39 2356.10 46.790 231.540 2011.91 2067.97 618.748 626.99 W 5993329.44 N 475773.98 E 0.445 877.00 2451.31 47.090 229.730 2076.91 2132.97 662.86 8 680.76 W 5993285.49 N 475720.07 E 1.424 945.36 2546.33 47.060 228.740 2141.63 2197.69 708.29 8 733.46 W 5993240.22 N 475667.23 E 0.764 1014.04 2640.03 45.210 228.070 2206.56 2262.62 753.138 783.98 W 5993195.54 N 475616.56 E 2.041 1080.86 2733.68 44.860 228.700 2272.74 2328.80 797.138 833.52 W 5993151.69 N 475566.89 E 0.605 1146.42 2829.69 46.810 229.430 2339.63 2395.69 842.25 8 885.55 W 5993106.74 N 475514.71 E 2.103 1214.42 2923.23 47.430 229.780 2403.28 2459.34 886.67 S 937.76 W 5993062.49 N 475462.37 E 0.717 1282.00 3017.81 46.720 229.930 2467.69 2523.75 931.328 990.69 W 5993018.00 N 475409.29 E 0.760 1350.24 3048.73 46.380 229.800 2488.95 2545.01 945.798 1007.86 W 5993003.59 N 475392.08 E 1.141 1372.35 3124.36 46.190 229.460 2541.22 2597.28 981.198 1049.50 W 5992968.31 N 475350.32 E 0.411 1426.25 26 June, 2003 - 9:53 Page 20f5 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad ·3S-03 Your Ref: API 801032045800 Job No. AKZZ0002482635, Surveyed: 20 June, 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 3219.98 46.310 229.030 2607.34 2663.40 1026.29 8 1101.83 W 5992923.39 N 475297.86 E 0.348 1494.42 3311.60 46.160 228.540 2670.72 2726.78 1069.88 8 1151.60 W 5992879.95 N 475247.95 E 0.420 1559.81 3407.60 45.630 228.290 2737.53 2793.59 1115.64 8 1203.16 W 5992834.36 N 475196.24 E 0.583 1628.00 3500.51 45.280 228.460 2802.70 2858.76 1159.628 1252.66 W 5992790.53 N 475146.61 E 0.399 1693.51 3592.50 44.560 229.410 2867.84 2923.90 1202.29 S 1301.63 W 5992748.01 N 475097.50 E 1.070 1757.68 3686.58 44.350 229.060 2935.00 2991.06 1245.31 8 1351.53 W 5992705.15 N 475047.46 E 0.343 1822.71 --~ 3780.09 43.980 228.550 3002.07 3058.13 1288.22 8 1400.56 W 5992662.39 N 474998.30 E 0.549 1887.10 3872.80 43.680 229.050 3068.95 3125.01 1330.51 8 1448.86 W 5992620.26 N 474949.86 E 0.494 1950.54 3968.16 45.110 230.250 3137.09 3193.15 1373.708 1499.71 W 5992577.23 N 474898.88 E 1.739 2016.31 4063.44 44.510 228.870 3204.69 3260.75 1417.258 1550.82 W 5992533.84 N 474847.64 E 1.199 2082.52 4157.06 44.750 229.520 3271.31 3327.37 1460.23 8 1600.60 W 5992491.02 N 474797.72 E 0.551 2147.45 4250.75 44.180 228.970 3338.18 3394.24 1503.07 8 1650.31 W 5992448.34 N 474747.87 E 0.734 2212.22 4345.58 44.450 228.020 3406.03 3462.09 1546.97 8 1699.92 W 5992404.59 N 474698.12 E 0.756 2277.74 4439.19 44.470 228.910 3472.85 3528.91 1590.45 8 1749.00 W 5992361.27 N 474648.91 E 0.666 2342.59 4533.50 44.280 229.300 3540.26 3596.32 1633.63 S 1798.86 W 5992318.25 N 474598.91 E 0.352 2407.71 4629.22 44.080 228.640 3608.90 3664.96 1677.42 S 1849.18W 5992274.62 N 474548.45 E 0.524 2473.61 4723.44 43.740 229.090 3676.78 3732.84 1720.40 S 1898.40 W 5992231.79 N 474499.10 E 0.490 2538.17 4817.48 45.740 229.730 3743.58 3799.64 1763.46 8 1948.66 W _ 5992188.89 N 474448.70 E 2.180 2603.47 4911.61 45.570 229.750 3809.37 3865.43 1806.97 8 2000.03 W 5992145.55 N 474397.19 E 0.181 2669.81 5005.53 45.430 230.170 3875.20 3931.26 1850.06 8 2051.32 W 5992102.61 N 474345.77 E 0.352 2735.79 5099.63 45.450 229.880 3941.23 3997.29 1893.148 2102.70 W 5992059.70 N 474294.25 E 0.221 2801.82 5193.75 45.010 229.770 4007.51 4063.57 1936.24 8 2153.76 W 5992016.75 N 474243.06 E 0.475 2867.66 5287.91 45.300 229.740 4073.91 4129.97 1979.37 8 2204.71 W 5991973.78 N 474191.97 E 0.309 2933.45 5382.91 46.100 229.740 4140.26 4196.32 2023.31 8 2256.60 W 5991930.01 N 474139.95 E 0.842 3000.46 5477.69 45.880 229.170 4206.11 4262.17 2067.638 2308.40 W 5991885.86 N 474088.01 E 0.491 3067.70 5572.66 45.830 229.040 4272.26 4328.32 2112.248 2359.91 W 5991841.41 N 474036.35 E 0.111 3134.99 5666.62 45.940 228.680 4337.66 4393.72 2156.628 2410.71 W 5991797.19N 473985.41 E 0.299 3201.65 5761.09 46.150 228.420 4403.23 4459.29 2201.64 S 2461.69 W 5991752.33 N 473934.29 E 0.298 3268.90 5856.51 45.880 228.300 4469.50 4525.56 2247.268 2513.00 W 5991706.88 N 473882.84 E 0.297 3336.82 5950.75 45.560 228.170 4535.30 4591.36 2292.20 8 2563.32 W 5991662.09 N 473832.37 E 0.354 3403.60 6045.90 45.100 227.390 4602.19 4658.25 2337.678 2613.44 W 5991616.78 N 473782.12 E 0.757 3470.64 6140.56 45.040 227.050 4669.04 4725.10 2383.18 S 2662.62 W 5991571.42 N 473732.79 E 0.262 3537.13 6236.00 45.670 229.250 4736.11 4792.17 2428.48 8 2713.20 W 5991526.29 N 473682.07 E 1.768 3604.33 6330.62 45.390 229.380 4802.40 4858.46 2472.498 2764.40 W 5991482.43 N 473630.72 E 0.312 3670.97 6425.11 45.130 229.510 4868.91 4924.97 2516.138 2815.40 W 5991438.96 N 473579.59 E 0.292 3737.17 26 June, 2003 - 9:53 Page 3 0'5 Dri/lQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad· 3S-03 Your Ref: API 801032045800 Job No. AKZZOo02482635, . Surveyed: 20 June, 2003 ConocoPhil/ips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 6519.76 44.950 229.440 4935.79 4991.85 2559.65 S 2866;31 W 599t395.60 N 473528.55 E 0.197 3803.23 6614.39 44.320 229.110 5003.13 5059.19 2603.03 S 2916.69 W 5991352.38 N 473478.02 E 0.709 3868.85 6708.88 43.950 229.690 5070.94 5127.00 2645.85 8 2966.65 W 5991309.72 N 473427.93 E 0.580 3933.76 6800.68 43.650 229.060 5137.20 5193.26 2687.22 8 3014.88 W 5991268.50 N 473379.58 E 0.577 3996.45 6895.64 43.620 229.190 5205.93 5261.99 2730.10 S 3064.43 W 5991225.78 N 473329.89 E 0.100 4061.15 6990.73 43.170 229.590 5275.02 5331.08 2772.62 8 3114.02 W 5991183.41 N 473280.16 E 0.555 4125.61 - 7084.52 40.740 229.500 5344.77 5400.83 2813.30 8 3161.73 W 5991142.88 N 473232.33 E 2.592 4187.44 7178.82 37.480 230.610 5417.93 5473.99 2851.51 S 3207.31 W 5991104.82 N 473186.62 E 3.536 4246.00 7274.08 34.220 230.900 5495.13 5551 .19 2886.80 8 3250.51 W 5991069.67 N 473143.31 E 3.427 4300.80 7368.06 32.410 230.700 5573.66 5629.72 2919.42 S 3290.51 W 5991037.17 N 473103.21 E 1.929 4351.51 7462.57 30.130 231 .200 5654.44 5710.50 2950.33 8 3328.60 W 5991006.38 N 473065.02 E 2.428 4399.67 7557.67 29.610 230.790 5736.91 5792.97 2980.148 3365.41 W 5990976.69 N 473028.12 E 0.587 4446.16 7651.90 29.070 230.990 5819.05 5875.11 3009.268 3401.23 W 5990947.68 N 472992.20 E 0.582 4491.50 7745.01 28.610 230.960 5900.61 5956.67 3037.54 8 3436.12 W 5990919.51 N 472957.22 E 0.494 4535.59 7839.35 28.020 230.790 5983.66 6039.72 3065.78 8 3470.84 W 5990891.38 N 472922.42 E 0.631 4579.54 7904.64 27.420 230.910 6041 .46 6097.52 3084.95 8 3494.39 W 5990872.28 N 472898.81 E 0.923 4609.36 7970.00 27.420 230.910 6099.48 6155.54 3103.93 S 3517.75 W 5990853.38 N 472875.39 E 0.000 4638.92 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 3S-03. Northings and Eastings are relative to 38-03. Global Northings and Eastíngs are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 3S-03 and calculated along an Azimuth of 220.000° (True). Magnetic Declination at Surface is 25.076°(06-Jun-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 7970.00ft., The Bottom Hole Displacement is 4691.37ft., in the Direction of 228.576° (True). 26 June, 2003 - 9:53 Page 4 0'5 Dri/lQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-03 Your Ref: AP/501032045BOO Job No. AKZZ0002482635, Surveyed: 20 June, 2003 ConocoPhílfips Western North Slope Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment *_..- 7970.00 6155.54 3103.93 S 3517.75 W Projected Survey .~ Survey tool program for 35-03 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 174.00 0.00 174.00 174.00 7970.00 174.00 Tolerable Gyro 6155.54 AK-6 BP _'FR-AK .-.-' 26 June, 2003 - 9:53 Page 50f5 DrillQuest 3.03.02.005 ) AOGCC Lori Taylor 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ') 30-Jun-03 Re: Distribution of Survey Data for Well 3S-03 MWD Dear Lori Taylor Enclosed are two survey hard copies and one disk Tie-on Survey: Window I Kickoff Survey: Projected Survey: 'MD 'MD 7,970.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) :;;"'03 -0 q I RECEIVED JUL 0 1 2003 Aiaí!f.r;, O~ & G~a (;(¡r¡fj. c:.Dmm~n ~~ ~ D I r() a C6 Sperry-Sun Drilling Services ~, Western North Slope ConocoPhillips Kuparuk 35 Pad 35-03 MWD Job No. AKMWOO02482635, Surveyed: 20 June, 2003 Survey Report 26 June, 2003 ¡-. Your Ref: API 501032045800 Surface Coordinates: 5993946.19 NI 476402.92 E (70° 23' 40.5329" N, 150° 11 r 31.1806" W) Grid Coordinate System: HAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 993946.19 HI 23597.08 W (Grid) Kelly Bushing: 56.06ft above Mean Sea Level Elevation relative to Project V Reference: 56.06ft Elevation relative to Project V Reference: 56.06ft !5pe!r"ray-sUl! DRILLING SeRVices A Halliburton Company Survey Ref: svy2053 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad· 3S-03 MWD Your Ref: AP/501032045800 Job No. AKMW0002482635, Surveyed: 20 June, 2003 ConocoPhif1ips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -56.06 0.00 0.00 N O.OOE 5993946.19 N 476402.92 E 0.00 Tolerable Gyro 87.00 0.100 12.000 30.94 87.00 0.07N 0.02 E 5993946.26 N 476402.94 E 0.115 -0.07 174.00 0.600 60.000 117.94 174.00 0.38N 0.43 E 5993946.56 N 476403.35 E 0.619 -0.56 MWD Magnetic 294.82 1.350 181.050 238.75 294.81 0.73 S 0.95E 5993945.46 N 476403.87 E 1.438 -0.05 5- 383.39 2.850 193.280 327.26 383.32 3.92 S 0.42E 5993942.27 N 476403.33 E 1.758 2.73 478.07 4.380 192.190 421.74 477.80 9.748 0.88W 5993936.45 N 476402.01 E 1.618 8.03 567.87 6.190 191.190 511.16 567.22 17.84 8 2.54W 5993928.35 N 476400.32 E 2.018 15.30 656.57 9.240 193.900 599.05 655.11 29.458 5.18W 5993916.76 N 476397.64 E 3.462 25.89 750.86 12.070 194.480 691.70 747.76 46.35 8 9.47 W 5993899.87 N 476393.30 E 3.003 41.59 839.64 14.660 197.380 778.07 834.13 66.068 15.15 W 5993880.18 N 476387.56 E 3.013 60.34 936.93 17.260 204.800 871.61 927.67 90.92 8 24.88 W 5993855.35 N 476377.75 E 3.392 85.64 1031.32 19.130 208.810 961.28 1017.34 117.198 38.21 W 5993829.13 N 476364.34 E 2.383 114.33 1125.63 21.720 214.270 1049.66 1105.72 145.158 55.49 W 5993801.21 N 476346.97 E 3.407 146.86 1218.80 23.670 219.630 1135.62 1191.68 173.81 8 77.13 W 5993772.62 N 476325.24 E 3.049 182.72 1314.05 25.990 223.880 1222.07 1278.13 203.59 8 103.80 W 5993742.93 N 476298.48 E 3.072 222.67 1410.63 28.350 227.530 1307.99 1364.05 234.33 8 135.38 W 5993712.29 N 476266.80 E 2.991 266.53 1505.46 32.270 231.610 1389.85 1445.91 265.27 8 171.85W 5993681.47 N 476230.23 E 4.667 313.67 1599.84 36.160 232.810 1467.89 1523.95 297.768 213.80 W 5993649.11 N 476188.18 E 4.183 365.52 1695.18 39.670 233.800 1543.09 1599.15 332.748 260.78 W 5993614.27 N 476141.09 E 3.736 422.52 1789.67 42.240 235.510 1614.45 1670.51 368.55 8 311.30W 5993578.63 N 476090.46 E 2.967 482.43 1884.47 45.160 234.780 1682.98 1739.04 405.988 365.04 W 5993541.36 N 476036.60 E 3.126 545.64 r'-'~" 1979.30 45.200 234.710 1749.82 1805.88 444.81 8 419.96 W 5993502.71 N 475981.55 E 0.067 610.69 2074.38 44.500 235.360 1817.23 1873.29 483.24 8 474.91 W 5993464.45 N 475926.48 E 0.880 675.45 2168.33 46.410 233.210 1883.13 1939.19 522.34 8 529.26 W 5993425.53 N 475872.02 E 2.606 740.33 2262.74 46.800 231.840 1948.00 2004.06 564.07 8 583.70 W 5993383.96 N 475817.44 E 1.132 807.30 2356.10 46.790 231.810 2011.91 2067.97 606.138 637.19 W 5993342.07 N 475763.82 E 0.026 873.91 2451.31 47.090 230.240 2076.92 2132.98 649.89 8 691.27 W 5993298.49 N 475709.60 E 1.245 942.18 2546.33 47.060 229.150 2141.63 2197.69 694.89 8 744.33 W 5993253.65 N 475656.40 E 0.841 1010. n 2640.03 45.210 228.620 2206.56 2262.62 739.31 S 795.23 W 5993209.39 N 475605.36 E 2.016 10n.51 2733.68 44.860 227.660 2272.74 2328.80 783.52 8 844.58 W 5993165.34 N 475555.88 E 0.816 1143.10 2829.69 46.810 227.700 2339.63 2395.69 829.89 S 895.50 W 5993119.13 N 475504.81 E 2.031 1211.35 2923.23 47.430 227.380 2403.28 2459.34 876.16 S 946.06 W 5993073.02 N 475454.09 E 0.709 1279.30 3017.81 46.720 229.140 2467.70 2523.76 922.27 8 997.73 W 5993027.07 N 475402.28 E 1.556 1347.83 3048.73 46.380 230.240 2488.96 2545.02 936.79 S 1014.85 W 5993012.60 N 475385.12 E 2.807 1369.96 3124.36 46.190 227.530 2541 .23 2597.29 972.73 S 1056.03 W 5992976.80 N 475343.83 E 2.602 1423.96 --------.-.-- --.----------- 26 June, 2003 - 9:49 Page 2 0'5 Dri1fQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Kuparuk 38 Pad - 3S-03 MWD Your Ref: API 501032045800 Job No. AKMW0002482635, Surveyed: 20 June, 2003 ConocoPhimps Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3219.98 46.310 226.140 2607.36 2663.42 1019.98 S 1106.40 W 5992929.71 N 475293.30 E 1.058 1492.53 3311.60 46.160 227.560 2670.73 2726.79 1065.23 S 1154.67 W 5992884.61 N 475244.89 E 1.131 1558.23 3407.60 45.630 227.940 2737.55 2793.61 1111.58 S 1205.70 W 5992838.42 N 475193.72 E 0.621 1626.53 3500.51 45.280 228.460 2802.72 2858.78 1155.72 S 1255.06 W 5992794.44 N 475144.22 E 0.549 1692.07 3592.50 44.560 229.990 2867.86 2923.92 1198.14 S 1304.24 W 5992752.17 N 475094.90 E 1.411 1756.18 ;/~, 3686.58 44.350 230.170 2935.01 2991.07 1240.42 S 1354.78 W 5992710.05 N 475044.23 E 0.260 1821.05 3780.09 43.980 229.330 3002.09 3058.15 1282.52 S 1404.50 W 5992668.11 N 474994.38 E 0.740 1885.26 3872.80 43.680 230.310 3068.97 3125.03 1323.94 S 1453.55 W 5992626.84 N 474945.20 E 0.800 1948.52 3968.16 45.110 230.570 3137.11 3193.17 1366.43 S 1504.99 W 5992584.52 N 474893.63 E 1.512 2014.13 4063.44 44.510 230.440 3204.71 3260.77 1409.13 S 1556.80 W 5992541.98 N 474841.68 E 0.637 2080.15 4157.06 44.750 230.570 3271.33 3327.39 1450.97 S 1607.56 W 5992500.31 N 474790.79 E 0.274 2144.82 4250.75 44.180 231.950 3338.20 3394.26 1492.03 S 1658.74 W 5992459.40 N 474739.48 E 1.198 2209.18 4345.58 44.450 230.940 3406.05 3462.11 1533.33 S 1710.55 W 5992418.27 N 474687.54 E 0.797 2274.11 4439.19 44.470 230.880 3472.86 3528.92 1574.67 S 1761.44 W 5992377.09 N 474636.52 E 0.050 2338.49 4533.50 44.280 231.400 3540.27 3596.33 1616.05 S 1812.79 W 5992335.87 N 474585.03 E 0.435 2403.21 4629.22 44.080 229.890 3608.92 3664.98 1658.35 S 1864.37 W 5992293.74 N 474533.32 E 1.119 2468.76 4723.44 43.740 230.490 3676.80 3732.86 1700.18 S 1914.57 W 5992252.06 N 474483.00 E 0.570 2533.08 4817.48 45.740 230.190 3743.59 3799.65 1742.43 S 1965.52 W 5992209.97 N 474431.91 E 2.139 2598.19 4911.61 45.570 230.380 3809.39 3865.45 1785.44 S 2017.30 W 5992167.12 N 474379.99 E 0.231 2664.43 5005.53 45.430 230.570 3875.22 3931.28 1828.08 S 2068.97 W 5992124.65 N 474328.19 E 0.207 2730.30 5099.63 45.450 230.190 3941.24 3997.30 1870.83 S 2120.62 W 5992082.06 N 474276.40 E 0.289 2796.25 5193.75 45.010 229.140 4007.53 4063.59 1914.08 S 2171.55 W 5992038.98 N 474225.33 E 0.920 2862.12 ~ 5287.91 45.300 229.950 4073.93 4129.99 1957.39 S 2222.35 W 5991995.82 N 474174.40 E 0.683 2927.95 5382.91 46.100 229.730 4140.28 4196.34 2001.24 S 2274.31 W 5991952.14 N 474122.30 E 0.858 2994.94 5477.69 45.880 228.910 4206.13 4262.19 2045.68 S 2326.01 W 5991907.87 N 474070.46 E 0.664 3062.21 5572.66 45.830 230.050 4272.28 4328.34 2089.95 S 2377.81 W 5991863.75 N 474018.52 E 0.863 3129.42 5666.62 45.940 229.390 4337.68 4393.74 2133.56 S 2429.28 W 5991820.30 N 473966.92 E 0.518 3195.91 5761.09 46.150 228.500 4403.26 4459.32 2178.23 S 2480.56 W 5991775.80 N 473915.50 E 0.714 3263.09 5856.51 45.880 228.520 4469.52 4525.58 2223.72 S 2531.99 W 5991730.48 N 473863.93 E 0.283 3330.99 5950.75 45.560 228.150 4535.32 4591.38 2268.57 S 2582.39 W 5991685.79 N 473813.38 E 0.441 3397.75 6045.90 45.100 227.400 4602.21 4658.27 2314.04 S 2632.50 W 5991640.47 N 473763.13 E 0.740 3464.79 6140.56 45.040 227.440 4669.06 4725.12 2359.38 S 2681.84 W 5991595.28 N 473713.64 E 0.070 3531.25 6236.00 45.670 229.830 4736.13 4792.19 2404.25 S 2732.80 W 5991550.58 N 473662.54 E 1.900 3598.37 6330.62 45.390 229.710 4802.42 4858.48 2447.86 S 2784.35 W 5991507.14 N 473610.85 E 0.309 3664.92 6425.11 45.130 229.960 4868.93 4924.99 2491.15 S 2835.64 W 5991464.01 N 473559.43 E 0.333 3731.05 --_.-.------ ----~-- 26 June, 2003 - 9:49 Page 3 of5 DrillQlIest 3.03.02.005 DrillQuest 3.03.02.005 Page 4 of5 26 June, 2003 - 9:49 -------- ----- Based upon Minimum Curvature type calculations, at a Measured Depth of 7970.00ft., The Bottom Hole Displacement is 4689.86ft., in the Direction of 229.057° (True). Magnetic Declination at Surface is 25.076°(06-Jun-03) The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 3S-03 and calculated along an Azimuth of 220.000° (True). r~ All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 3S-03. Northings and Eastings are relative to 3S-03. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. Sperry-Sun Drilling Services Survey Report for Kuparuk 38 Pad· 38..03 MWD Your Ref: API501032045BOO Job No. AKMW0002482635, Surveyed: 20 June, 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 6519.76 44.950 230.120 4935.81 4991.87 2534.16 S 2886.98 W 5991421.16 N 473507.95 E 0.225 3796.99 6614.39 44.320 230.100 5003.15 5059.21 2576.80 S 2937.99 W 5991378.68 N 473456.81 E 0.666 3862.45 6708.88 43.950 231.290 5070.97 5127.03 2618.48 S 2988.90 W 5991337.16 N 473405.77 E 0.960 3927.10 6800.68 43.650 228.960 5137.23 5193.29 2659.21 S 3037.66 W 5991296.59 N 473356.88 E 1.787 3989.64 6895.64 43.620 228.670 5205.95 5262.01 2702.36 S 3086.98 W 5991253.59 N 473307.43 E 0.213 4054.39 ,.- 6990.73 43.170 228.820 5275.05 5331.11 2745.43 S 3136.09 W 5991210.67 N 473258.18 E 0.485 4118.96 7084.52 40.740 229.010 5344.79 5400.85 2786.64 S 3183.35 W 5991169.61 N 473210.79 E 2.594 4180.91 7178.82 37.480 231.170 5417.96 5474.02 2824.83 S 3228.94 W 5991131.57 N 473165.08 E 3.746 4239.46 7274.08 34.220 231 .420 5495.16 5551.22 2859.71 S 3272.47 W 5991096.82 N 473121.44 E 3.426 4294.17 7368.06 32.410 231 .250 5573.69 5629.75 2891.96 S 3312.77 W 5991064.70 N 473081.04 E 1.929 4344.77 7462.57 30.130 231.830 5654.47 5710.53 2922.4 7 S 3351.18 W 5991034.31 N 473042.54 E 2.433 4392.84 7557.67 29.610 231.370 5736.94 5793.00 2951.89 S 3388.29 W 5991005.01 N 473005.33 E 0.598 4439.23 7651.90 29.070 231.850 5819.08 5875.14 2980.57 S 3424.48 W 5990976.45 N 472969.05 E 0.625 4484.46 7745.01 28.610 232.070 5900.64 5956.70 3008.24 S 3459.85 W 5990948.89 N 472933.59 E 0.507 4528.40 7839.35 28.020 231.810 5983.69 6039.75 3035.83 S 3495.09 W 5990921.41 N 472898.27 E 0.639 4572.18 7904.64 27.420 231.630 6041.49 6097.55 3054.64 S 3518.93 W 5990902.67 N 472874.37 E 0.928 4601.91 7970.00 27.420 231 .630 6099.51 6155.57 3073.32 S 3542.52 W 5990884.06 N 472850.71 E 0.000 4631.39 Projected Survey Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-03 MWD Your Ref: AP/501032045800 Job No. AKMW0002482635, Surveyed: 20 June, 2003 ConocoPhillips Western North Slope Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment ;.-. 7970.00 6155.57 3073.32 S 3542.52 W Projected Survey Survey tool program for 35-03 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 17 4.00 0.00 174.00 174.00 7970.00 174.00 Tolerable Gyro 6155.57 MWD Magnetic ~. --------------- 26 June, 2003 - 9:49 Page 50f5 DrillQuest 3.03.02.005 ") ) ól-Þ3 -D<f ( 1 1 000 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West ih Avenue, Suite 100 Anchorage, Alaska June 26, 2003 RE: MWD Formation Evaluation Logs 3S-03, AK-MW-2482635 1 LDWG formatted Disc with verification listing. API#: 50-103-20458-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, AR!œIVED JUL 01 2003 Date: AJaeka o¡.¡ &. Gã$ C\inK Colh~ Anoht1'!g,e f?~ I.'."Ã~',' ~.1., Œ[~.· I iJ l'! E ","r~_ L¡ ":1 ) (IDJ !Æ~!Æ~IA!Æ ) FRANK H. MURKOWSKI, GOVERNOR AIASIiA OIL AND GAS / CONSERVATION COMMISSION Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage AK 99510 333 w. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field 3S-03 ConocoPhillips (Alaska), Inc. Permit No: 203-091 Surface Location: 2469' FNL, 857' FEL, Sec. 18. T12N, R8E, UM Bottomhole Location: 292' FNL, 4417' FEL, Sec. 19, T12N, R8E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~ ;f~~~ Randyh.uedrich Commissioner BY ORDER OF THE COMMISSION DATED this;¿day of May, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section pennits/sundries needed this week ) 'l~ / Subject: permits/sundries needed this week Date: Tue, 27 May 2003 08:22:54 -0800 From: "Sharon Allsup-Drake" <Sharon.K.Allsup- Drake@conocophillips.com> To: jody _ colombie@admin.state.ak.us Jody - Good Morning - the only permit we will need this week is the 3S-03 permit. Our initial spud date was 6/2/03 but it looks like we will be needing the new permit by late this week. Let me know if this is a problem. Thanks, Sharon work: (907) 263-4612 fax: (907) 265-6224 office ATO-1530 sallsup@ppco.com 1 of 1 5/27/20039:59 AM ~") COnocoPhiUips ) Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.l.thomas@conocophillips.com May 14, 2003 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, producer 3S-03 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore producer well, KRU 3S-03, a development well. Note that it is planned to drill the surface hole without a diverter. There have been 13 wells drilled on 3S pad with no significant indication of gas or shallow gas hydrates. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). If you have any questions or require any further information, please contact Scott Lowry at 265-6869. /.....',.... Sincerely, ./'/ ..,{..':,,":..."" ~./.,/./~Z?~/ //"/i" '" '-(ø~.,·? ,... t.''Z/ ¿''-''~ ""<:::7 Randy Thomas ~. GKA Drilling Team Leader Ýþ~~ ({....~/ RECEIVED MAY 1 5 2003 Alaska Oil & Gas Cons. Commission Anchorage . ORIGINAL ~I )rtif}Û ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 22. I hereby cert~'fy th.. at thef regOing. is truelnd c ect to the best of my knowledge. Contact Scott Lowry@265-6869 Printed Name ä.~m ¡:" Title Kuparuk .Drilling Team Lea,de. r Signature '---â ~' (!, í40. Phone 2.~3-'-f { 3--- Date ..cjÍi (v.3 // l _,'~ j .' I Tl1. c¡ ~ > PreDared bv Sharon AIIsuD-Drake ð Commission Use Only Permit to Drill /'API Number: Permit Approval :2D 3 - De¡I 50- /D3 - 26 t/~ -6ö · Date: èJ Yes Jð:)'NO D Yes ~NO 1a. Type of Work: Drill0 Re-entry D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Redrill U 1b. Current Well Class: Stratigraphic Test D P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 2469' FNL, 857' FEL, Sec. 18, T12N, R8E, UM Top of Productive Horizon: 197' FNL, 4301' FEL, Sec. 19, T12N, R8E, UM Total Depth: 292' FNL, 4417' FEL, Sec. 19, T12N, R8E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 476403 y- 5993946 ' Zone- 4 16. Deviated wells: Kickoff depth: 300 ft. Maximum Hole Angle: 45° 18. Casing Program Size Specifications Hole Casing Weight Grade Coupling Length 42" 30"x16" 62.5# H-40 Weld 80' 12.25" 9.625" 40# L-80 BTC 3046' 8.5" 7" 26# L-80 BTC-M 7918' 19 Total Depth MD (ft): PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) Casing Structural Conductor Surface Length Size Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments: Filing Fee [2] Property Plat D BOP Sketch U Diverter Sketch D Drilling Program~ Seabed Report D 21. Verbal Approval: Commission Representative: Number: Conditions of approval : Samples required Hydrogen sulfide measures Exploratory U Development Oil L::J Multiple Zone D Service D Development Gas D Single Zone [2] 5. Bond: U Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 3S-03 6. Proposed Depth: 12. Field/Pool(s): MD: 7946' TVD: 6101' Kuparuk River Field 7. Property Designation: AÞ'- ÞÆ:Ii( 380107 ,¿ t 8. Land Use Permit: Kuparuk River Pool 13. Approximate Spud Date: 6/2/2003 ADL 4624 9. Acres in proPØ {)"4 4i~ 10. KB Elevation 14. Distance to Nearest Property: 4417' 15. Distance to Nearest Well within Pool: 3S-07 . 46' @ 700' (Height above GL): 28 feet 17. Anticipated Pressure (see 20 AAC 25.035) Max. Downhole Pressure: 3446 psig 1 Max. Surface Pressure: 2804 psig Setting Depth Quantity of Cement Bottom c. f. or sacks TVD (including stage data) 108' 96 sx ArcticCrete 2591' 430 sx AS Lite, 250 sx LiteCrete 6101' 240 sx Class G Top MD 28' 28' 28' TVD 28' 28' 28' MD 108' 3074' 7946' (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Cement Volume MD TVD Perforation Depth TVD (ft): Time v. Depth Plot D Drilling Fluid Program [2] Date: Shallow Hazard Analysis U 20 AAC 25.050 requirements [2] See cover letter Mud log required Directional survey required ~rn~s'V[D ..~esM~ r05 2003 Other: ~5aD ~..;\ ~b~~~\-",-~.......\~~~ Approved by: ~J t4:J¡~ D F~j¡'rf'RL Form 10-401 Revised 3/2003 · , J I ~ , \øt ~i ~.! i ", Alaska Oil & Gas Cons. Commission ~~or:g~ Date: 5/ 2~ Z7ì Submit in duplicate BY ORDER OF THE COMMISSION ) "lication for Permit to Drill, Well 3S-03 Revision No.O . Saved: 14-May-03 Permit It - Kuparuk Well 35-03 Application for Permit to Drill Document MaximizE We-II VglUI; Table of Contents 1. Well Name. ................................................................................................................ 2 Requirements of 20 AAC 25.005 (f).... ........ ......... ........... ..... ........... ....... ................................ ...... ........... 2 2. Location Sum mary ....................... ....... .................................. .............. ... .................. 2 Requirements of 20 AAC 25. 005(c) (2) . ........ ..... ...... .......... ........ ........... ...... ......... .......... .........................2 Requirements of 20 AAC 25. 050(b)...... ..... ....... ....... ................ ............. ........ .......... ....... ............ ..... ........ 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25. 005(c) (3) ................ ..... ........................ ....... ........ ........ .......... ........... .......... 3 4. Dri II i ng Hazards Information ...... .............. ..... .................................. ...... .................. 3 Requirements of 20 AAC 25.005 (c)( 4) ........ ....................... ................. ...... ...... ................................ ...... 3 5. Procedure for Conducting Formation Integrity Tests........................................... 3 Requirements of 20 AAC 25.005 (c)(5) ....... ................ ............ ......... ............... ....................................... 3 6. Casing and Cementing Program.............................................................................4 Requirements of 20 AAC 25.005(c)(6) ....... .......... ............... .............................. .................... ........ .........4 7. Diverter System Information ......................... ...................... ......... ... ..... ... ............. ... 4 Requirements of 20 AAC 25.005(c)(7) ... ...... ........ ............. ........ ..................................... ........................ 4 8. Dri II i ng FI uid Program ............... ... ...... ................................................ ............ ......... 4 Requirements of 20 AAC 25. 005(c) (B) ... .......... ........... ............ ................... ............ ....... ........... ..............4 9. Abnormally Pressured Formation Information ......................................................5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ........................................................................ ...... ..................... ... 5 Requirements of 20 AAC 25.005 (c)(10) ...... ........... ....................................... .......... ..............................5 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 12. Evidence of Bondi ng ........................... ............... ... ... ....................... ...... .................. 6 Requirements of 20 MC 25.005 (c)(12) ................................. ...................... .... ....................... .............. 6 13. Proposed Drilling Program .....................................................................................6 JR G ~ .¡,~ , ~ ! {~,.,. 35-03 PERMIT IT. DOC Page 1 of 7 Printed: 14-May-03 ) ,. "'~ication for Permit to Drill, Well 3S-03 } Revision No.O Saved: 14-May-03 Requirements of 20 AAC 25.005 (c)(13) .... ...... ............. ...................... ....... ........................ .............. ...... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ........................................................................................... ..... 6 15. Attach ments .................................................................. ...................................... ..... 7 Attachment 1 Directional Plan ......................... ........ ....... ................. .................... ..... ................ ............. 7 Attachment 2 Drilling Hazards............................................................................................. 6 Attachment 3 Well Schematic.............................................................................................. 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be ìdentified by a unìque name designated by the operator and a unique API number assìgned by the commission under 20 MC 25.040(b). For a well with multiple well branches, each branch must simila/1y be Identified by a tinique name and API number by adding a suffix to the name designated for the well by the operator and to the number assi..qned to the well by the commission. The well for which this application is submitted will be designated as 35-03. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dnll must be accompanied by each of the following items, except lor an item already on file wIth the commission and identified in the application: (2) a plat identifylÌ7g the property and the property':; owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of eacl7 objective formation, and at total dept/7, referenced to governmental section lines. (B) the coordlÌ7ates of the proposed location of the well at the surface, referenced to the state plane coordinate sY!:Jtem for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface NGS Coordinates Northings: 5,993,946 12469' FNL, 857' FEL, Sec 18, T12N, R8E, UM RKB Elevation Eastings: 476,403 Pad Elevation 56.1' AMSL 28.0' AMSL Location at Top of Productive Interval (Kuparuk "C" Sand) NGS Coordinates Northings: 5,990,950 197' FNL, 4301' FEL, Sec 19, T12N, R8E, UM Eastings: 472,960 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 7646' 5841' 5785' Location at Total Depth 1292' FNL, 4417' FEL, Sec 19, T12N, R8E, UM NGS Coordinates Measured Depth, RKB: Northings: 5,990,856 Eastings: 472,845 Total Vertical Depth, RKB: Total Vertical Depth, 55: 7946' 6101' 6045' and (D) other information required by 20 AAC 25.050{b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Onll (Fom710-401) must (1) include a plat, drawn to a sUItable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well,' Please see Attachment 1: Directional Plan Ofi' ~ .:,,,, ~\ 'ì ~ l "," "I ,II " ,r . .~ I ' 'f. T ',: &~J i \,~ {,\~ ,,:n 38-03 PERMIT IT. DOC Page 2 of 7 Printed: 14-May-03 ) Þ'"'qlication for Permit to Drill, We1l3S-03 \. Revision No.O '. Saved: 14-May-03 and (2) for all wells within 200 feet of the proposed we//bore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) 5·tate that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accomplmied by each of the fiJllowing Items, except for an Item already on file with the commission and identified in the application: (3) a diagram and desCliption of the blowout prevention equipment (BOPE) as ¡equired by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable,: Please reference BOP schematics on file for Nabors 7E5. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill mu:.t be aCGVmpanied by each of the following Items, except for an Item already on file with the GVmmission and identified in the application: (4) infO/mation on drilling hazards, including (A) the mlfximum downhole pressure that may be encountered, cnteria used to detelmine it and mc1ximum potentÙ11 surface pressure based on a methane gradient; A pressure build-up test performed on Palm lA (35-26) in 4/01 indicated a reservoir pressure in the Kuparuk C sand of 3597 psi at 5830' tvd, 0.62 psi/ft or 11.9 ppg EMW (equivalent mud weight). Due to pressure depletion, the predicted reservoirpressure for 35-03 is predicted at 3468 psi at 5841' tvd, 0.59 psi/ft or 11.4 ppg EMW. The maximum potential surface pressure (MP5P) while drilling 35-03 is calculated using above maximum reservoir pressure, a gas gradient of 0.11 pSi/ft, and the Kuparuk C sand target at 5841' tvd: MP5P =(5841 ft)*(0.59 - 0.11 psi/ft) = 2804 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lo:,t circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Pem7it to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030{f); A procedure is on file with the commission for performing LOT's. For 35-03 the procedure will be followed with one exception. The surface casing shoe will be pressured until leak-off occurs and the 16.0 ppg EMW maximum will not be observed. (see step 6 in the procedure) J i"" N ,A ~ .~. , ~ L '. J" ~ ........ . .J I' ~ ·'1 .r .~ I'. . "'~. II \¡;f'~~.~:ll'., 35-03 PERMIT IT. DOC Page 3 of 7 Printed: 14-May-03 ) "'1ication for Permit to Drill, We1l3S-03 Revision No.O Saved: 14-May-03 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a PermIt to Drill mu~t be accompanied by each of tIle following Item~ except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.03~ and a description oflmy slotted liner; pre- perforated liner; or screen to be installed; Casinq and Cementinq Proqram Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD 00 (in) (in) (/b/ft) Grade Connection (ft) (ft) (ft) Cement Program 30 X 16 42 62.5 H-40 Welded 80 28 / 28 108 / 108 9 cy High Early Insulated 9-5/8 12-1/4 40 L-80 BTC 3046' 28'/28' 3074'/2591' Lead: 430 sx 10.7 ppg AS Lite Tail: 250 sx 12.0 ppg 'LiteCRETE' . (Yield=2.40 cuft/sk) Planned TOC=Surface 7 8-1/2 26 L-80 BTC-Mod 7918' 28'/28' 7946'/6101' 240 sx 15.8 ppg 'G' w/ add. Planned TOC= 6846' 3-1/2 9.3 L-80 EUE 8rd 7518' 28' / 28' 7546'/5757' SAB- 3 packer set at Mod 7546' MD. If 7" casing must be top-set above the Kuparuk C sand, 6 1/8" hole would be drilled to total depth and a 3 V2" 9.3 ppf L-80 SLHT production liner will be cemented across the productive interval. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified Ii? the application: (7) a diagram and de!:1""Cription of the diverter system as required by 20 MC 25.03.~ unless this requirement ir; waived by the commission under 20 MC 25.035(11)(2); Please reference diverter schematic on file for Nabors 7ES. ConocoPhillips plans not to use a diverter on well 35-03. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file wIth the commission and Identified in the application: (8) a drilling flUId program, includlÌ7g a diagram and description of the drilling fluid system, as required by 20 MC 25. 033; Drilling will be done using mud systems having the following properties: O Fro" J "."" .", ., ..'" l I:,' ,:' ~ q f~rr;.., ""':'I.!!" :' . ¡ ~¡, J f. ¡,\ ~¡ ~ ~ {"l! fj I 3 l(¡,V'l II !l1 {, ...;WI 35-03 PERMIT IT. DOC Page 4 of 7 Printed: 14-May-03 ) þ. ,Iication for Permit to Drill, Well 3S-03 Revision No.O Saved: 14-May-03 Sulface Hole mud properties Spud to Base of Permafrost Base of Permafrost to Total Depth Initial Value Final Value Initial Value Final Value Density (ppg) 8.6 9.0* 9.0* 9.4* Funnel Viscosity 120-130 120-130 120-130 120-130 (seconds) Yield Point 35-45 27 -40 25-35 20-30 (cP) Plastic Viscostiy 8-15 11-22 15-30 15-30 (lb1100 sf) 10 second Gel 10-30 10-25 10-25 10-25 Strength (lb1100 sf) 10 minute Gel 25-55 25-55 20-40 15-35 Strength (/b1100 sf) pH 8-9 8-9 8-9 8-9 API Filtrate(cc) 12-15 7-8 7-8 7-8 Solids (%) 6-9 6-12 6-12 6-12 * 9.8 if hydrates are encountered Production Hole mud properties initial C40 Top Morraine Top HRZ Kuparuk Density (ppg) 8.8 10.2 10.6 10.8 11.9 Funnel Viscosity 40-55 42-55 42-58 42-58 42-58 (seconds) Yield Point 11-15 20-25 20-25 20-25 20-25 (cP) Plastic Viscostiy 6-12 8-15 8-16 8-18 15-25 (lb1100 sf) 10 second Gel 2-5 3-6 3-6 4-7 4-8 Strength (/b1100 sf) 10 minute Gel 4-10 7-10 7-112 7-12 8-16 Strength (lb1100 sf) pH 9-9.5 9-9.5 9-9.5 9-9.5 9-9.5 API Filtrate(cc) <6 <6 <6 <4 <4 Solids (%) 6-11 9-14 1 0-15 1 0-15 15-19 Diagram of Nabors 7ES Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item a/ready on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 MC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the fol/owing item~ except for an item already on file with the commission and Identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 MC 25.061(a)/ N/A - Application is not for an exploratory or stratigraphic test well. O ~ ~ y"':'¡ , I~ ~A ~¡, \ ~. . : . i';¡'~ ~ ~ 0."' ~~' .,'. '.,',' . J . I II ~ ~~ ~ f ."~"'~~ ~ 3S-03 PERMIT IT. DOC Page 5 of 7 Printed: 14-May-03 ) "."'(, lication for Permit to Drill, Well 38-03 J Revision No.O Saved: 14-May-03 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill mu~t be accompanied by each of the following items, except for an Item already on file with the commission and identified in the appliÓltion: (11) for a well drilled from an offshore platform, mobile bottom-fòunded structure, jack-up Jig, or floating drilling vesse~ an analysis of seabed conditions as required by 20 AAC 25.061(b); N/ A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of tl7e following items, except for an item already on tile with the commission and identified in the application: (12) evidence showing that the requirement!?; of 20 AAC 25.025 {Bonding}have been met,· Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on tile with the commission and Identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. MIRU Nabors 7ES. 2. N/U riser (no diverter). 3. Drill 12-1/4" hole to 9-5/S" surface casing point according to directional plan. No LWD logging equipment required. 4. Run and cement 9-5/S" 40#, L-SO BTC casing string to surface. Employ lightweight permafrost cement lead slurry and LiteCRETE tail slurry. Pump adequate excess to ensure cement reaches the surface. If cement does not circulate to surface, perform top job. Install and test BOPE to 5000 psi. Test casing to 2500 psi. 5. Drill out cement and 20' of new hole. Perform LOT. 6. Drill S-1/2" hole to total depth according to directional plan. Run LWD logging equipment with GR, resistivity, and density-neutron. Run 7" 26# L-SO BTCM casing to surface and cement. Note: If significant hydrocarbon zones are present above the Kuparuk C sand, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). 7. Run 3-1/2" 9.3#, L-SO Srd EUE Srd-Mod completion assembly w/ SAB-3 permanent packer and PBR. Set packer 100' above top planned perforation, shear out of PBR, P/U tubing hanger, and land tubing. Pressure test tubing to 3500 psi. Pressure test 3 V2" x 7" annulus to 3500 psi. Burst shear valve for freeze protect. S. Set TWC and ND BOPE. Install and pressure test production tree. 9. Freeze protect. Secure well. Rig down and move out. 10. Handover well to Operations Personnel. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of tl7e following items, except for an item already on file with the commission and Identified in the application: (14) a general description of how the operator plans to dispose of dnlling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 3S pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on 3S pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. ....." ~ ".~ /'¡! ,l'! :)'" \ :'I..:'~', ~\ , Q,.' ... I', : ,wf i I I , \;~ I ~ 4~' ' ~ 3$-03 PERMIT IT. DOC Page 6 of 7 Printed: 14-May-03 ) ^ 1lJ. lication for Permit to Drill, Well 3S-03 J Revision No.O Saved: 14-May-03 At the end of drilling operations, an application may be submitted to permit 35-03 for annular pumping of fluids occurring as a result of future drilling operations on 35 pad. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. OR,'Ci¡l L 35-03 PERMIT IT. DOC Page 7 of 7 Printed: 14-May-03 CJ ::J:J ---....,. , "'" !:t) ~'''''"~--'.-~ """--". ~ '1:.~~~_= ", ,_~~'Jt;. r-- Sperry-Sun Drilling Services Western North 510 ConocoPhil . 35-03 Plan:1~l - ~~~,~ . _ 7 .,' _ . _ _ _._ - -_~_ -. --- --._"- - - -~- _ ..-.'- "-. -_"-__ .-. -.- -' --~__e.,... -~~~::Sraposal Report 8 May, 2003 -~ Surface Coordinates: 5993946.19N, 476402.92 E (70023'40.5329" N, 150011'31.1806" W) Grid Coordinate System: NAD27 A/aska State Planes, Zone 4 Kelly Bushing: 55. 80ft above Mean Sea Level spe.....l'y-su., DFU~~I~c:t__ Se!AV,.ceS A HamburtQn Company ~' Proposal Ref: pro2028 ) SI:l&!r"'r"'Y-SUf1 North Slope OR~L.L.INm slilltvlc:;es . . AHølllbul'IonCttM,p4/1Y ConocoPhllllps Vertical Origin: ~~~~~~a~~~~¡ts : North Reference: Scale: 1 inch = 1000lt -3000 I ) Kuparuk 3S Pad 3S-03 Wp 5.0 Eastings(3S-03) -2000 -1000 I I DrillQuest" SHL (2.468.94' FNL &856.72' FEL, SEC. 18- T12N - R KOP Begin Dir @ 2.500'/10011: 299.701t MD, 299.701t TVD -. - - - - - -¡ncreãšëõ]';:""'Rãte @ 3.000õï1õõiï:699JOIIMD,697.67iITiiD 3S-03 (wp05) Proposal Data 3S-03 3S-03 It True North e~~i~~IS~~~\~~ Äzimuth: ~~8rgg8yer 100 feet (US SUlVey) Vertical Section Description3S-03 Vertical Section Origin: 0.00 N,O.OO E Measured Incl. Azlm. Vertical Depth Depth 0.00 0.000 0.000 0.00 299.70 0.000 <),000 299.70 699.70 10.000 185.000 697.67 1997.71 45.483 230.141 1836.00 7129.40 45.483 230.141 5433.91 7645.52 30.000 230.151 5840.80 7945.52 30.000 230.151 6tOO.61 Total Depth: 7945.521t MD, 61oo.61ft TVD (291.84' FNL & 4416.63' FEL, See 19-T12N-R8E) I /SHL (2483' FNL & 915' FEL, SEC. 18- T12N - R8E?) O-~------------'--- /KOP Begin Dir @ 2.500'/10011 : 299.7011 MD, 299.7011 TVD 1500 - g o en ~ ..s::: ã.. 3000 - () o (¡j o 1:: () > 4500 - ê II .s::; '-' ;§ 6000 - Qj (ij rX DrillQuest 3.03.02.002 ¿Increase Dir Rate @ 3.000'/100lt: 699.70IlMD,697.67ftTVD ¡iilOO.OO Target C..oordlnate Vertical Depth \ Name Point Type 3S-03 (ft) 3$-03 Geo-Poly Entry Point 5840.80 I 1600.00 i '~, I I·'··· .. ... End Dir, Start Sail @ 45.479': 1997.711tMD,1836.00ltTVD I. .... ......... ..... .'" 'iii' ~O.OO L, , ,~ . ~. ...,. .,12 HoI. , 307<001I MD, 25....ft lVD I... .' ..' .'.. 200.00 I " : I: I I 400.00 a~ .~ ~. ~~ .-Æ. egin Dir@3.000'/100lt:7129.111tMD,5434.02ltTVD ?SO, '\620000 J.<;"(l3(;"...I',:ly .'\ End Dir, Start Sail @ 30.000' : 764S.52ftMD,5840.8OftTVD Cicek.Ro.. dillS: 15U'()(ifL~. ": ( 196.99' FNL & 4301.44' FEL. See 19-T12N-R8E) 5W;¡O: 8U TVlJ. - .1(J()6.04 S. .1433.4S II" ).~ Total Depth: 7945.52ft MD, 61oo.61ft TVD (291.84' FNL & 4416.63' FEL, See 19-T12N-R8E) Northings Eastings Vertical Dogleg Sectlo n Rate 0.00 0.00 0.000 28.52 2.500 598.38 3.000 4 99.83 0.000 4509.74 3.000 4657.39 0.000 0.00 N 0.00 N 34.69 8 460.05 8 2805.208 3007.048 3103.168 0.00 E 0.00 E 3.03W 382.82 W 3191.Ò6W 3433.45 W 3548.6 L W Be9in Dir @ 3.000'/100ft : 7129.401t MD, 5433.911t TVD End Dir, St3rt Sail @ 30.000° : 7645.52ftMD,5840.8OftTVD ( 1 96.99' FNL & 4301.44' FEL, See 19-T12N-R8E 38-(13 (;e(l-I'(lly Circle, Rlltlill.\·: I S(J.()(Jf/ 5840.8() TV/). .1()06,(14 8. .14.n.4S W i Set 9 5/8 Begin 8 1/2 Hole: 3074.00ft MD, 2590.68ft TVD - -1000 Ci) o cb C') 00 0) c: :E t: o Z - -2000 ~PhP '-II- Conoco ··1 . IPS 8 ~ II - -3000 ~ Qj ~ (/) r Northings 3$003 (ft) 3007.04 $ Vertical Depth Mean Sea Level (ft) 5785.00 Eastlngs 3S-03 (ft) 3433.45 W Northings ASP (ft) 5990950.00 N Eastings ASP (ft) 472960.00 E Target Shape Ci.rcle Well: Current Well Properties 3S-03 Horizontal Coordinates: Ref. Global Coordinates: Ref. Project H Reference: Ref. Geographical Coordinates: 5993946.19 N, 476402.92 E 993865.75 N, 26734.52 W 70° 23' 40.5231" N, 150° 11' 31.1805" W 55.8011 above Mean Sea Level RKB Elevation: North Reference: Units: True North Feet (US Survey) The "Directional Difficulty Index" for this profile is 5.3 The "Along Hole Displacement" for this profile is 4735.77ft o Scale: 1 inch = 150011 I I I 1500 3000 4500 Section Azimuth: 220.000' (True North) Vertical Section (3S-03) CR'''''''' .,~, il ' .! ;'.",1 .' '¡ } . t. .\ ,~.' ,J. I \,;;~. ~ d /"cß'l <::) :J::) ~-.:-4 ,--=v ':-:5 ~.,- -~ ......._._<:'"~ ~~ i--- Western North Slope Measured Depth (ft) 100.00 200.00 299.70 300.00 400.00 500.00 600.00 699.70 700.00 ,~ 800.00 900.00 1000.00 1100.00 1200.00 Incl. 0.00 0.000 0.000 0.000 0.000 0.008 2.507 5.007 7.507 10.000 10.005 12.032 14.398 16.962 19.647 22.410 1300.00 25.224 1400.00 28.074 1500.00 3Ô.951· 1600.00 3:.t84Y' 161 &~iÕ' 34.39b 1700.00 1800.00. 1900.00 1997.71 39.758 ~9.680 - 42.612 45.483 Azim. 0.000 0.000 0.000 0.000 185.000 185.000 185.000 185.000 185.000 185.042 196.684 204.789 210.572 214.844 218.1 J~/' 220.6$}t 222.£80;; 224:51 (iF. <225.972 j~26.221 227.229 228.325 229.293 230.141 2000.00 45.483 230.141 2100.00 2200.00 2247.02 2300.00 2400.00 8 May, 2003 - 14:59 45.483 45.483 45.483 45.483 45.483 230.141 230.141 230.141 230.141 230.141 Sub-Sea Depth (ft) -55.80 44.20 144.20 243.90 244.20 344.17 443.95 543.34 641.87 642.17 740.33 837.68 ~~~~~6 :,~~~~~}~ . ,.. -.-,~ <,$i1,2;f~ª1~ti~Y' Lj:303~-Ö8 1390.10 1474.52 1490.00 1556.13 1634.68 1709.98 1780.20 1781.81 1851.92 1922.03 1955.00 1992.14 2062.25 Vertical Depth (ft) 100.00 200.00 299.70 300.00 399.97 499.75 599.14 697.67 - 1269.51 1358.88 1445.90 1530.32 1545.80 1611.93 1690.48 1765.78 1836.00 1837.61 1907.72 1977.83 2010.80 2047.94 2118.05 Sperry-Sun Drilling Services Proposal Report for 35-03 Plan - 35-03 (wp05) Revised: 7 May, 2003 Local Coordinates Northings Eastings (ft) (ft) 0.00 0.00 N 0.00 E 0.00 N 0.00 N 0.00 N 0.00 E 0.00 E 0.00 E 0.00 N 3.04W 6.80W 15.00 W 27.64 W 44.67 W 66.04 W 184.83 S 218.27 S 253.88 S 291.59 S 298.86 S 91.70 W 121.59 W 155.60 W 193.66 W 201.22 W 331.27 S 372.82 S 416.14 S 460.05 S 235.66 W 281.48 W 331.00 W 382.82 W 461.09 S 384.08 W 506.79 S 552.49 S 573.98 S 598.19 S 643.89 S 438.81 W 493.55 W 519.29 W 548.28 W 603.02 W Page 2 of7 Global Coordinates Northings Eastings (ft) (ft) 5993946.19 N . 5993946.19.Ncc 5993946.1 ~1\f 599~-1 g.:,~~ ~-_,_ _ -0.=- ~C"~c_. ',c;599ì946.t~ N'- 476402.92 E 5993911.46 N 5993892.83 N 5993871.58 N 5993847.77 N 5993821.46 N 5993792.73 N 5993761.65 N 5993728.31 N 5993692.80 N 5993655.22 N 5993647.97 N 5993615.67 N 5993574.26 N 5993531.10 N 5993487.35 N 5993486.31 N 5993440.78 N 5993395.26 N 5993373.85 N 5993349.73 N 5993304.21 N 476402.72 E 476402.13 E 476401.15 E 476399.78 E 476399.77 E 476395.96 E 476387.68 E 476374.97 E 476357.86 E 476336.39 E 476310.63 E 476280.65 E 476246.52 E 476208.34 E 476200.76 E 476166.22 E 476120.26 E 476070.61 E 476018.65 E 476017.39 E 475962.51 E 475907.63 E 475881.82 E 475852.75 E 475797.87 E 2.500 2.500 2.500 2.500 2.500 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 0.000 0.000 0.000 0.000 0.000 0.000 ConocoPhillips 0.00 SHL (2468.94' FNL & 856.72' FEL, SEC. 18- T12N - R8E) 0.00 0.00 0.00 KOP Begin Dir @ 2.500°/1 OOft : 299.70ft MD, 299.70ft TVD 0.00 - 1.80 7.17 16.09 28.52 Increase Dir Rate @ 3.000o/100ft: 699. 70HM D, 697. 67ftTVD 28.56 45.26 66.83 93.23 124.37 160.17 200.54 245.35 294.50 347.85 358.28 B. Permafrost 405.24 466.53 531.54 598.49 ~ End Dir, Start Sail @ 45.479° : 1997.71ftMD,1836.00 ftTVD 600.10 670.29 740.48 773.49 Top W. Sak 810.67 880.86 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Proposal Report for 35-03 Plan - 35-03 (wp05) Revised: 7 May, 2003 ConocoPhilHps Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 2500.00 45.483 230.141 2132.37 2188.17 689.59 S 657.75 W 5993258.68 N 951.05 2600.00 45.483 230.141 2202.48 2258.28 735.29 S 712.49 W 5993213.15 1021.24 2700.00 45.483 230.141 2272.59 2328.39 780.99 S 767.22 W 5993167.63 1091.43 2800.00 45.483 230.141 2342.70 2398.50 826.69 S 821.96 W 5993122.1 1161.63 2881.73 45.483 230.141 2400.00 2455.80 864.04 S 866.69 W 59 1218.99 Base W.Sak 2900.00 45.483 230.141 2412.81 2468.61 872.39 S 475523.48 E 0.000 1231.82 -...-- 3000.00 45.483 230.141 2482.92 2538.72 918.09 S 475468.60 E 0.000 1302.01 3074.00 45.483 230.141 2534.81 2590.61 951.91 S 475427.99 E 0.000 1353.95 Set 9 5/8 Begin 8112 Hole: 3074.0( MD, 2590.68ft TVD 9 5/8in Casing 3100.00 45.483 230.141 2553.03 2608.83 5992985.52 N 475413.72 E 0.000 1372.20 3174.12 45.483 230.141 2605.00 2660.80 5992951 .78 N 475373.04 E 0.000 1424.22 Top C-80 C) 3200.00 45.483 230.141 2623.15 1040.90 W 5992939.99 N 475358.84 E 0.000 1442.39 ::t:J 3300.00 45.483 230.141 2693.26 1095.63 W 5992894.47 N 475303.96 E 0.000 1512.58 3400.00 45.483 230.141 2763.37 1150.37 W 5992848.94 N 475249.08 E 0.000 1582.77 --- 3500.00 45.483 230.141 ~-ªgR"·,~8 1205.11 W 5992803.41 N 475194.20 E 0.000 1652.96 C") 3600.00 45.483 230.141 29Ò3r~9 1259.84 W 5992757.89 N 475139.32 E 0.000 1723.15 :-- ~'--O"<a 230.141 --~, -, 3700.00 45.483 '>~9 ,," . ~r~¡ 3029.50 1237.98 S 1314.58 W 5992712.36 N 475084.44 E 0.000 1793.34 'ê::-~ 3800.00 45.483 230.14.1 ;~~~-,ªJ;- 3099.61 1283.68 S 1369.31 W 5992666.84 N 475029.56 E 0.000 1863.53 h 3900.00 45.4ßa, 230·14;1; rª113:93 3169.73 1329.38 S 1424.05 W 5992621.31 N 474974.68 E 0.000 1933.73 ¡-- 4000.00 45.483' 2ªQ~1~ F"· {'3184.04 3239.84 1375.08 S 1478.78 W 5992575.78 N 474919.81 E 0.000 2003.92 4100.00 45Aß3, - ~30.141 3254.15 3309.95 1420.78 S 1533.52 W 5992530.26 N 474864.93 E 0.000 2074.11 4200.00 ; 49.48a., 230.141 3324.26 3380.06 1466.48 S 1588.25 W 5992484.73 N 474810.05 E 0.000 2144.30 4300.00 '4$.483 230.141 3394.37 3450.17 1512.18 S 1642.99 W 5992439.20 N 474755.17 E 0.000 2214.49 4400.00 45.483 230.141 3464.48 3520.28 1557.88 S 1697.72 W 5992393.68 N 474700.29 E 0.000 2284.68 .,-"' 4500.00 ' 45.483 230.141 3534.59 3590.39 1603.58 S 1752.46 W 5992348.15 N 474645.41 E 0.000 2354.87 4600.00 45.483 230.141 3604.71 3660.51 1649.28 S 1807.19 W 5992302.62 N 474590.53 E 0.000 2425.06 4700.00 45.483 230.141 3674.82 3730.62 1694.98 S 1861.93 W 5992257.10 N 474535.65 E 0.000 2495.25 4800.00 45.483 230.141 3744.93 3800.73 1740.68 S 1916.66 W 5992211.57 N 474480.77 E 0.000 2565.44 4900.00 45.483 230.141 3815.04 3870.84 1786.38 S 1971.40 W 5992166.04 N 474425.89 E 0.000 2635.63 5000.00 45.483 230.141 3885.15 3940.95 1832.08 S 2026.13 W 5992120.52 N 474371.01 E 0.000 2705.83 5100.00 45.483 230.141 3955.26 4011.06 1877.78 S 2080.87 W 5992074.99 N 474316.13 E 0.000 2776.02 8 May, 2003 - 14:59 Page 3 of7 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Proposal Report for 3S-03 Plan - 3S-03 (wp05) Revised: 7 May, 2003 ConocoPhilHps Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 5200.00 45.483 230.141 4025.38 4081.18 1923.48 S 2135.60 W 5992029.47 N 2846.21 5216.58 45.483 230.141 4037.00 4092.80 1931.05 S 2144.68 W 5992021 .92 2857.85 Top C-40 5300.00 45.483 230.141 4095.49 4151 .29 1969.18 S 2190.34 W 5991983.94 2916.40 5400.00 45.483 230.141 4165.60 4221.40 2014.87 S 2245.07 W 5991938. 2986.59 5500.00 45.483 230.141 4235.71 4291.51 2060.57 S 2299.81 W 59 3056.78 5600.00 45.483 230.141 4305.82 4361.62 474041.74 E 0.000 3126.97 ~ 5700.00 45.483 230.141 4375.93 4431.73 473986.86 E 0.000 3197.16 5800.00 45.483 230.141 4446.04 4501.84 473931.98 E 0.000 3267.35 5900.00 45.483 230.141 4516.16 4571.96 473877.10 E 0.000 3337.54 6000.00 45.483 230.141 4586.27 4642.07 473822.22 E 0.000 3407.73 6100.00 45.483 230.141 4656.38 2 5991619.73 N 473767.34 E 0.000 3477.93 a 6200.00 45.483 230.141 4726.49 ~~~ 5991574.20 N 473712.46 E 0.000 3548.12 ::cJ 6300.00 45.483 230.141 4796.60 ~2~6~1~~ 5991528.67 N 473657.58 E 0.000 3618.31 ~-- 6400.00 45.483 230.141 4866.71 ....~. .?1-11.8~ 5991483.15 N 473602.70 E 0.000 3688.50 ~~~-. ..~~ 6500.00 45.483 230.141 4936.82 C~\"~2b17.57S 5991437.62 N 473547.83 E 0.000 3758.69 rtJ 6600.00 45.483 230.141 ,SOÖg194 5 563.27 S 2901.90 W 5991392.10 N 473492.95 E 0.000 3828.88 ~O::-·"'~_L~ ~~':~_-.-;4- 6700.00 45.483 230.1.l'\.1r :. "~~~~~~~~~ 51~.85 2608.97 S 2956.63 W 5991346.57 N 473438.07 E 0.000 3899.07 ;~:"tr...J~ 6782.66 45.483 230.14:1 5190.80 2646.74 S 3001.87 W 5991308.94 N 473392.71 E 0.000 3957.09 Top Moraine :x~ 6800.00 45.483 230.14t ;;§14.þ~1~f 5202.96 2654.67 S 3011.37 W 5991301.04 N 473383.19 E 0.000 3969.26 r-- 6900.00 45.48$ 230.14f '5217.27 5273.07 2700.37 S 3066.10 W 5991255.52 N 473328.31 E 0.000 4039.45 7000.00 45A83 230.141 5287.38 5343.18 2746.07 S 3120.84 W 5991209.99 N 473273.43 E 0.000 4109.64 710Q;00 . 45:483 . '230.141 5357.49 5413.29 2791.76 S 3175.57 W 5991164.46 N 473218.55 E 0.000 4179.83 7129.40 45.483 230.141 5378.11 5433.91 2805.20 S 3191.67 W 5991151.08 N 473202.41 E 0.000 4200.47 Begin Dir @ 3.000c/100ft : 7129 Ar MD, 5433.91ft TVD 7188.24 43.718 230.142 5420.00 5475.80 2831.68 S 3223.38 W 5991124.70 N 473170.62 E 3.000 4241.14 Top HRZ --- 7200.00 43.366 230.142 5428.52 5484.32 2836.87 S 3229.60 W 5991119.53 N 473164.38 E 3.000 4249.11 7300.00 40.366 230.143 5502.99 5558.79 2879.64 S 3280.82 W 5991076.92 N 473113.02 E 3.000 4314.80 7400.00 37.366 230.145 5580.84 5636.64 2919.85 S 3328.99 W 5991036.87 N 473064.73 E 3.000 4376.56 7436.43 36.273 230.146 5610.00 5665.80 2933.84 S 3345.75 W 5991022.93 N 473047.93 E 3.000 4398.05 Base HRZ 7500.00 34.366 230.147 5661.87 5717.67 2957.39 S 3373.96 W 5990999.47 N 473019.64 E 3.000 4434.23 7571.94 32.207 230.149 5722.00 5777.80 2982.68 S 3404.27 W 5990974.27 N 472989.25 E 3.000 4473.09 K1 7600.00 31.366 230.150 5745.85 5801.65 2992.16 S 3415.62 W 5990964.83 N 472977.88 E 3.000 4487.64 7645.52 30.000 230.151 5785.00 5840.80 3007.04 S 3433.45 W 5990950.00 N 472960.00 E 3.000 4510.50 End Dir, Start Sail @ 30.000° : 7645.52 ftMD, 5840.80ftTVD Target - 3S-03 Geo~Poly, 150.00 Radius., Current Target 7651 .29 30.000 230.151 5790.00 5845.80 3008.89 S 3435.66 W 5990948.16 N 472957.77 E 0.000 4513.35 Top Kuparuk 8 May, 2003 - 14:59 Page 4 of 7 Dri/lQuest 3.03.02.002 a :::):J l~_. .-:-.J f~ _) ~J._-;....--;...J'C!'2D ~- ....,.ß -r_4~_~ '1..'.:..'"100 r- Sperry-Sun Drilling Services Proposal Report for 3S-03 Plan - 3S-03 (wp05) Revised: 7 May, 2003 Western North Slope Measured Sub-Sea Vertical local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 7675.54 30.000 230.151 5811.00 5866.80 3016.66 S 3444.97 W 7700.00 30.000 230.151 5832.18 5887.98 3024.50 S 3454.36 W 7800.00 30.000 230.151 5918.79 5974.59 3056.53 S 3492.75 W 7900.00 30.000 230.151 6005.39 6061.19 3088.57 S 3531.14 W 7945.52 30.000 230.151 6044.81 6100.61 3103.16 S 3548.61 W All data is in Feet (US Survey) unless otherwise stated. Directions and coordínat¢!W~r Vertical depths are relative to 3S-03. Northings and Eastings are relative to 3S:;Q3. . Global Northings and Eastings are relative to NAD27 Alaska State Planø§'Ç'~gri~;1~ ~= The Dogleg Severity is in Degrees per 100 feet (US Su rveYl;:~;:;.~ =;":- -.- :-i-'o,. ..~ _~~_~ ~,~~._ Vertical Section is from 3S~03 and calculated along an AziniJjttìQh:?20.t~þOo:{True). > .' _ _ _0_ .."- '._ ~__ _"_ -_0 ~'c _ ._~_ _ .-õ'"_ _ _ _~ _ .---C-.- .-......-..--,. '. -=--.. - - - -- -- _.- _.uu _ _ __ ~ Based upon Minimum Curvature type calcufä1í6Ws: at 3 MeaSured Dêpth of7945.52ft., The Bottom Hole Displacement is 4714.04ft., in the Direction of 228.8310 (True). ,'. ,. .~-',- ,"' The Along Hole Displacement is 47':.3,§.42ff~Jh~~t?~Aned Tortuosity is 1.284c/100ft and the Directional Difficulty Index is 5.3. Comments Measure(i Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 0.00 299.70 699.70 1997.71 3074.00 0.00 299.70 697.67 1836.00 2590.61 0.00 N 0.00 N 34.69 S 460.05 S 951.91 S 0.00 E 0.00 E 3.03W 382.82 W 971.93 W SHL (2468.94' FNL & 856.72' FEL, SEC. 18- T12N - R8E) KOP Begin Dir @ 2.500°/1000: 299.70ft MD, 299.700 TVD Increase Dir Rate @ 3.0000/100ft: 699.70ftMD,697.67ftTVD End Dir, Start Sail @ 45.479°: 1997.71ftMD,1836.00ftTVD Set 9 5/8 Begin 8 1/2 Hole: 3074.00ft MD, 2590.681t TVD 8 May, 2003 - 14:59 PageS of7 0.000 0.000 0.000 ConocoPhilHps 4525.28 Base Kup 4537.32 4586.54 4635.75 4658.16 Total Depth : 7945.52ftMD,6100.61ftTVD ( __ 291.840' FNL & 4416.630' FEL, See 19- T12N-R8E ) 7ìn Casing -" DrillQuest 3.03.02.002 '0 ~~~tJ ~;;-~~'. G~') L:.:"..;-.;.,.--_...,. - ~~""--= ,i..~ ~:.~ \', Western North Slope Comments (Continued) Sperry-Sun Drilling Services Proposal Report for 35-03 Plan - 35-03 (wp05) Revised: 7 May, 2003 Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7129.40 7645.52 7945.52 7945.52 5433.91 5840,80 6100.61 6100.61 Formation Toos Formati on Plane (Below Well Origin) Sub-Sea Dip Up-Dip (ft) Angle Dim. ConocoPhilHps TVD , 0.80ftTVD (196.99' FNL & 4301.44' FEL, See 19-T12N-R8E) D ( 291.840' FNL & 4416.630' FEL, See 19- T12N-R8E ) 2805.20 S 3007.04 S 3103.16S 3103.16 S 3191.66W 3433.45 W 3548.61 W 3548.61 W Begin Dir @ 3.000o/100ft : 71,2 End Dir, Start Sail @ 30.00 Total Depth: 7945.52 Total Depth : 79 Prof' e Measured Ve"" Depth D (ft)< ( 1490.00 0.000 0.000.,' ·····:i...1J,18.1r1);.·¡;h 154;~~ 0 1955.00 0.000 0.000' '2247.02':l:; 2010.80 2400.00 0.000 0.000 ?&8~!:K~;E' - 2455.80 2605.00 O.OQO 0.00.0;: 3J74.12 2660.80 4037.00 0.000 O,QOO' . "5216.58 4092.80 5135.00 O.ÖOÖ 0.000 6782.66 5190.80 5135.00 5420.00 0.000 0.000 7188.24 5475.80 5420.00 5610.00 <0.000 0.000 7436.43 5665.80 5610.00 5722.00 :0.000 0.000 7571.94 5777.80 5722.00 5790.00 0.000 0.000 7651.29 5845.80 5790.00 5811.00 0.000 0.000 7675.54 5866.80 5811.00 8 May, 2003 - 14:59 '- Poi n t Eastings Formation Name (ft) 298.86 S 201.22 W B. Permafrost 573.98 S 519.29 W Top W. Sak 864.04 S 866.69 W Base W.Sak 997.66 S 1026.73 W Top C-80 1931.05S 2144.68 W Top C-40 2646.74 S 3001.87 W Top Moraine 2831.68 S 3223.38 W Top HRZ 2933.84 S 3345.75 W Base HRZ 2982.68 S 3404.27 W K1 3008.89 S 3435.66 W Top Kuparuk 3016.66 S 3444.97 W Base Kup -~ Page 60f7 DrillQuest 3.03.02.002 a :ïr=) ....J....;. ~~~. C" ) . -p~ "--¿--..~ 1-~~ g--- Western North Slope Casing details Fr om Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (1t) <Surtace> <Surtace> 3074.00 2590.61 3074.00 2590.61 <Run-TD> <Run-TD> TarQets associated with this wel/oath Target Name 3S-03 Geo-Poly 8 May, 2003 - 14:59 Sperry-Sun Drilling Services Proposal Report for 3S-03 Plan - 3S-03 (wp05) Revised: 7 May, 2003 Casing Detail 9 5/8in Casing 7in Casing Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) ConocoPhillips ---- Target Target Shape Type a Level/Global Coordinates: Geographical Coordinates: Target Radius: 5840.80 3007.04 S 3433.44 W 5785.00 5990950.00 N 472960.00 E 70023' 10.9484" N 1500 13' 11.7088" W Circle 150.00ft Page 70f7 Current Target -~~ DrillQuest 3.03.02.002 50.0 45.0 ,........, ~ L.-...I 40.0-:·.·· ~ 0 . ,.-..4 35.0 ~ ~ ro 0.. 30.0-: Q) r:/l Q) 25.0 ~ a ~ ~ ~ Q) 20.0-: ~'-4._¡ u ~.':... 5~~~~ . .) 0 15.0 _. " ~ --",;'j, Q) -~--~-:a ~ -"1.2-,. ~ ,~.:;.:. ~ 10.0 ~-- Q) U 5.0 0.0 0 Plan: 3S-03 (wp05) (Plan: 3S-03/Plan: 3S-03) ,.1 ; -, ¡ , , ; ; ! " j ¡ I - ~ - T·f:t::E ¡ -, .;...:.,. i ,-',. } : :. (::.:-::;.. I , , " r ¡ '" , , ¡ , ~ ,,-I t I ( ~:'" ¡-I I , ¡ :r,u Ut "/111- HI; IVI /I 'II¡-~.II LJ I ~ I i11 II ~t""; I 110.. ~¡ ¡ , T '. -.- ,.:-. ~ ...- '.-- .. ' ¡ T , i ¡ ~ , .. ,- . -- - - ¡ T J :- ;--- ,- 14 ; i , . - .. . .'. -+,..¡ - " n, -( T ¡ ..." . : ,,' - T , '- :~~t' ., ',. ,,- - : -' ¡ ¡ i i -- '"--, .- _1 ; t -- "- ~J~ -'j -- -,- - T-,:' -.,'. ..... , ..." " ,-··~-~F.:~ .~ . .--; '," --, , ."-,.. ,.- " , ( 'f~ lan_ - ~ ~- "0 ,._. - ~ ....~ ,." - L, d . .-.- , d .. .. 7,/ '. " .: " r ¡ , :-- "i' - , ..... , , :'d j -,- -, ,'.' " '-,- :" ¡ ¡ r ; , -- c_ _.- n' - -- -- - - .- ' , , - - - .- - --- -- _. '0-- ___ ·+t·, -- ... . '''d' : , ; i - : : , : , : ; -. -- - - -- i -' : ; ',' c, :¡ . ¡ ... ,,' ,'," ,n,' : -. -,. :;": I' i ¡J -- - --- -~ '----- ." ",' : . :',:...' "" -. :~:t:·=t ,. ."',' ·:t--- ".- o 'r ',- := -- ~ ,.'... '.--- - -" .~--- ..,..-. ... , .~._---- ...-.~ nO .. d =f= : : ~. - -- ---- ,- -- - ..n., .. ,- ",' .'-; .¡.- e " -:,':. .' , ¡ ....-''', ; T ¡ . , - -::: ---' - -- r=-T=}:~: . '. ,"; , .' : ,d ¡ : '. ,¡~;.,: ~..'" <'" 'f - ¡ , ¡ : ¡ , ¡ I I I I I I --- '---- 100 200 400 500 800 1200 900 1000 1100 600 700 300 Measured Depth [ft] ;¢9~l'a~y:, .':' Fi~.d:. ....'............\\. .......,..". :;J{~f~re~c¢'Si~e: '.,. ....,... ;.,. , 'Ref~re~c~'WeU:' ." ,:~~feJ:'e~ceW~llPath:,' ) Sperry-Sun Anticollision Report , ',' ··Pt1illipstx1å$kalqc{ K~parU~River Uqit Kuparuk3$ Pad" 8Ian;3S-03,' ' Pl.ari;3$~03 ') ,',¡jriú:, "S/8/206:3 Time~ 14:J8:t9 ;:,Pag~:; ',i I ',',1 "', ':',;\ "":' ,':1 ".,' ,,:, ':", ,","',:',,1 ',', I,.: .,,':, I.,' "','I" ,:',,1,.',", :,",", "":,',' I:.' '.,1 "', ,"I: " ,I', ";",, ",'',,, ';:.'" ",,1",1.',' :.. 'I, I,., "i:', .'.,' ",,"','., ",'" ' ',," 'Ço;o~din})te(~E}R~f~r~~ce~', Well:Plan:3$~03;'TrUèNÒtt~ Y~rti~~I(rY~J~ef~~e~ce:, . .. ftK~=~$:~".~$~55,¡,8' ' , ,', 'Ðb:Ör.å6Ie,' ' NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.000 ft Depth Range: 28.100 to 6574.599 ft Maximum Radius: 854.650 ft Casing Points ,. Diameter' ,'" ,.', 'In',' 7906.000 6066.756 7.000 Plan: 38-03 (wp05) Principal: Yes 8.500 7" Summary " . '<~~~~~~;;-~-~7~"~--,~~-~O'fset W ellpath ~..u_~~".._.'~~~~~.".~; :,~'i~e, .., ., . ,'.' ,'. "'.' "W~l~ . '. . " '..','. . ',... . " \y~~lpâf~ Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 3S Pad Kuparu k 38 Pad Kuparu k 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 3S Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad 38-07 38~08 38~08 38-08 38-09 38-10 38-14 38-15 38-16 3S-18 38-21 38~22 38~23 38-26 38-26 Plan: 38-06 Plan: 38-06 Plan: 38-17 Plan: 38-17 Plan: 38-17 Plan: 38-19 Plan: 38-19 Plan: 38-20 Plan: 38-24 38-07 V5 38-08 V5 38-08A V3 38-088 V4 38-09 V2 38-10 V6 38-14 V2 38~15 V4 38-16 V4 38-18 V4 38-21 V4 38-22 V1 38-23 V4 38-26 V2 38-26A V3 Plan: 38-06 V3 Plan: 3 Plan: 38-06F V2 Plan: 38-17 (Rig) V3 Plan: 38-17 V1 Plan: 3 Plan: 38-17F V2 Plan: Plan 38-19F V3 Plan: 3 Plan: 38-19 V2 Plan: 3 Plan: 38-20 V2 Plan: 3 Plan: 3S-24 V7 Plan: 3 Site: Kuparuk 38 Pad Well: 38-07 Wellpath: 38-07 V5 Reference ' MD TVD ftft 28.100 28.100 49.430 49.430 99.429 99.429 149.427 149.427 199.423 199.423 Offset MD TVD ft ft 28.670 28.670 50.000 50.000 100.000 99.999 150.000 149.997 200.000 199.993 ',.' ·.R,efeí¢l1c~' 'MD; ft, " 695.620 954.994 954.994 954.994 691.429 645.657 649.000 299.054 1283.316 249.517 2119.003 664.187 300.609 1719.013 1719.013 851.616 851.616 299.805 299.991 299.805 299.992 299.992 299.993 299.997 Date Composed: Version: Tied-to: Reference: Error Model: Scan Method: Error Surface: Plan: 38-03 (wp05) & NOT PLANNED PR03RAM 18CW8A Ellipse Trav Cylinder North Ellipse + Casing 5/14/2002 12 From Well Ref. Point "..'.()~.C~r ... .....~O"(jo : Pis~J;lceAre~ " ,,',ft~ " "i Jt, ,..()ffset' ;;':(\t1D , .' 'ft' 700.000 950.000 950.000 950.000 700.000 650.000 650.000 300.000 1250.000 250.000 1850.000 650.000 300.000 1650.000 1650.000 850.000 850.000 300.000 300.000 300.000 300.000 300.000 300.000 300.000 Sélui-Major Axis Ref Offset TFO+AZI TFO-HS CaSing ft ft deg deg in 0.000 0.000 256.83 256.83 9.625 0.072 0.012 256.82 256.82 9.625 0.240 0.041 256.66 256.66 9.625 0.535 0.069 256.34 256.34 9.625 0.832 0.115 255.87 255.87 9.625 45.919 56.471 56.471 56.471 94.593 124.978 217.060 240.785 211.850 301.691 370.899 371.154 399.486 284.018 284.018 31.552 31.552 280.294 281.387 280.294 321.644 321.644 341.369 421.209 11.651 17.221 17.221 17.221 12.532 11.264 11.761 7.550 22.463 6.149 71.530 10.309 7.559 35.161 35.161 14.028 13.566 7.627 8.363 7.690 8.160 8.160 7.825 7.807 Rule Assigned: Inter-Site Error: Ctr-CtrNo~Go ])jstance' Area ft ft 80.138 0.756 80.136 1.185 80.1152.192 80.074 3.527 80.052 4.911 249.417 249.417 250.000 249.987 1.096 0.144 255.35 255.35 9.625 299.405 299.405 300.000 299.975 1.360 0.163 254.95 254.95 9.625 349.946 349.942 350.000 349.937 1.363 0.183 255.09 70.09 9.625 400.341 400.309 400.000 399.846 1.363 0.212 256.30 71.30 9.625 450.501 450.393 450.000 449.692 1.211 0.275 258.66 73.66 9.625 500.397 500.141 500.000 499.490 1.061 0.347 262.24 77.24 9.625 549.927 549.430 550.000 549.221 1.024 0.431 267.83 82.83 9.625 598.985 598.135 600.000 598.869 0.988 0.515 276.40 91.40 9.625 647.561 646.227 650.000 648.472 1.027 0.602 288.57 103.57 9.625 nF' :I!I. ~-J, ,; , [., ,,~/ i J '~ ";~.':I'~~: ~ .! ~ 79.923 6.168 78.989 7.398 76.922 7.961 73.380 8.536 68.655 8.786 63.223 9.056 57.309 9.613 51.514 10.169 47.214 10.909 ~ll~~ljl~, ,.' .·p~Yblti¿"" "'ft",,, ' 34.336 41.322 41.322 41.322 82.061 113.714 205.320 233.238 189.509 295.549 331.399 360.873 391.930 249.615 249.615 17.825 18.334 272.671 273.024 272.608 313.484 313.484 333.544 413.402 1"',,, ',r' ',",I,:,: ',:"'"",,-. ':', . ":,"',11,':".0 -,.",,'.':.,:":: W.a...r..n.'.i.n.·. I!. :""" I" '.....,., .,',' ',9 Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Major Ris k 0.000 ft AlloWable Deviation Warning ft 79.382 78.951 77.924 76.548 75.141 73.756 Pass 71.591 Pass 68.966 Pass 64.873 Pass 59.925 Pass 54.259 Pass 47.822 Pass 41.502 Pass 36.441 Pass Pass Pass Pass Pass Pass 55.8Oft ~~VD 0.00 '" 1li.P ATH DEf AIU; PM: 35-03 NìES RKB = 55.S· MSL ~ +~ 0.00 0.00 Rig: Ref. Ihtum: V.Section Ang\; 220.00' Tool CB-:\-!AG·S M\VD Sl:RVEY PROGRA\! Deplh Fm Deplh To SUIW.yIPM 28.10 500.00 P].<,¡¡œd: 35-03 (0.1'05) V12 500.00 7!»5.06 PJanœ<l: 35-03 <0.1'05) V12 LEGESD ..tI7, \lo,,,, f~" I I r-:1 \t..~., .~ t ~ JI·.~I \Lr..h.k JI~.r.1 \1_.,." r.: Io..k ..II'J! \t.p" i~ . . ..' 't.p·, i: -.... :r" \t.p', i: . :r. \, "l.p', 'r. '."L.r. ,".111"01 \{a}or Risk I".I~·LTI 1"'Ir-lJ,MajorRisk Ij(.~. 1/11('1.:." Major Risk I~IJ'L~-, ,', IiI. \fujorRisk I.' .i·!....r. ,', ,71 '. Major Ris:k .;11 II·!....;, ¡'-. :111 "{ajar Risk .'" ,. ." Fl' to . KOTl:SE3S-03A1C),ldI. ;:~ IJ'l;. ,'..:J I \1ajor Risk ~ - Iñ.te.: 05/0812003 Dare: Date.: D&te.: Plan: 3S-03 <0.1'05) (plan: 3S-03IPlan: 3S-03) CIoilld By: &It Goff Checked: ."L..ia j"L,;, hJ' ........;, h...i' ¡"l." j'L.1I ·L....i¡ j"L" , - ToW 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 Colour 90 From o 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 CO:\-IPA,'iY DEfAIU; PY~lnc. CakuIati:m :Method; :Minimum O.lr\'ature- ~: ~d: ¥¿v~Sy~<r North Error Surf.<~ EllipricID + Casing Warning Method: RuIos Based ToMD 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 ANTI·COLLISION SETTINGS Interval: 50.00 To: 5933.14 Reference: Plan: 3S-03 (w-pü5 Interpolation Method:MD Depth Range From: 33.00 Maximum Range: 790.01 WELL DETAILS +~. +EI·W Sonhing Eastr.g L:.1irod<. Longirud~ Slot 103.01 ·5Hl 59939-16. ~76J02.92 70'23'~0.533N 15O'11'31.181W NIA :S~IT.e -W.O -15.0 -15.0 -20.0 -10.0 -S.O Colour 90 From o 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 Re.\1e.woo: Approved: Centre Separation [15ft/in] Centre to [deg] vs Travelling Cylinder Azimuth (TFO+AZI) SECTION DEfAIU; See MD lnc An TVD +KI-S +EI-W Dug TFac.e. VSec- Targá 28.10 0.00 0.00 28.10 0.00 0.00 0.00 0.00 0.00 299.70 0.00 0.00 299.70 0.00 0.00 0.00 0.00 0.00 699.70 10.00 IS5.00 697.67 -34.69 -3.03 2.50 IS5.00 28.52 1997.60 ~5.4S 230.15 1335.94 -459.92 -382.82 3.00 53.5--1 598.39 7129.11 45.4S 230.15 5--134.00 -28<».31 ·3191.76 0.00 0.00 4199.S5 7&15.06 30.00 230.15 5840.78 -3006.05 -3-133.47 3.00 IS0.00 4509.76 7!»5.06 30.00 230.15 6100.58 -310217 -35--18.63 0.00 0.00 -1657.41 0 ~ - ( ~ 41 < J - - ¡ : \ ~ 8 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [50ft/in] 3oc/ / / I I I { -121 -100 -100 -75 ---SO -25 Q ~¡ ~........ -1 ~r j-~ . ~ --""---...~-~ i -75 -121 ',) ì ') 35-03 Drillina Hazards Summary 12-1/4" Hole / 9-5/8" Casina Interval Event Broach of Conductor Gas Hydrates Gravel/Sand Sloughing to 500' Hole Swabbing/Tight Hole on Trips Possible thaw bulb / water flow around 1200' Lost Circulation Risk Level Low Low Moderate Moderate Low Low 8-1/2" Hole / 7" Casina Interval Event Shale stability in HRZ, K-1, and Miluveach High ECD and swabbing with higher MW's required Barite Sag Differential Sticking Abnormal Reservoir Pressure Lost Circulation Risk Level Low Moderate Low Moderate Moderate Moderate OR! M itiqation Strate~y Monitor cellar continuously during interval. If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Drilltreat. Increase mud weight / viscosity, High viscosity sweeps. Monitor fill on connections Circulate hole clean prior to trip. Proper hole fill (use of trip sheets), Pumping out of hole as needed. Watch return viscosity for signs of thinning. Increased mud weight/viscosity as needed. Prevent by keeping hole clean. If losses occur- reduce pump rates and mud rheology, use LCM M iti~ation Strate~y Control with higher MW and proper drilling practices. Condition mud prior to trips. Monitor ECD's with PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Good drillinq practices as documented in well plan. Periodic wiper trips. Do not leave pipe static for extended period of time. Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 3S-03 Drilling Hazards Summary. doc prepared by Scott Lowry 7/30/02 rr \ ~.~ ~ L Page 1 of 1 ~ ij I' KRU - 38-03 PI,.2iucer Proposed Completion Schematic Single Completion wI Jet Pump Contingency 16"x30" insulated I I conductor @ I ~ +1-109' MD ~ ~ I ~ TAM 9-518" Port./, ,Jj Collar Stnd ~ Grade BTC ~ Threads (+/- ~ 1000' MD/TVD) ~ I ~ Surface csg. I 9-5/8"40# L-80 ~ BTC (3074' MD I ,¿z 2591' TVD) Casing point 100' above the C80 sand C Sand Perfs (to be done after rig moves off) Production csg. 7" 26# L-80 BTCM (+1- 7946' MO) r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ....J ....---~ :-:-:~ l r I ~ ~ I ~ ~ I ~ ~ ~ ~ ~ ~ I ~ -.... ~I ~r ~ a ~ I ~ ~~ =:1- I ~ ~ ~ ~~ ~ ~ ~ ""'rr-m,. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ru - ~ ~ ~ ~ =1 ~ t -Il i..-_- r ~ ~ ~ ~ ~ ~ J ~ ~~~~~ ~ ~ ~ ~~--- J ï:"¡" ._-,-~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ).. ....... ·········~·~I··I····· COnQ£Qrl !II · IpS 3-1/2" FMC Gen V tubing hanger, 3-1/2" L-80 EUE8RO pin down. Special Drift 2.91" 3-1/2", L-80, 9.3# EUE8RD Spaceout Pups as Required. Special Drift 2.91" 3-1/2" Cameo DS Landing Nipple with 2.875" 10 No-Go profile set @ +1- 500' MD. Use of port collar at the discretion of the drilling team. GLM Placement: Valves #1-4: 3-%" x 1" KBUG Place gas-lift mandrels at the following depths: TVD Approximate MO 2500' 2945' 3700' 4656' 4560' 5883' 5180' 6767' Valve #5: 3-1/2" x 1-1/2" 'MMG' GLM wI OCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Baker 'CMU' sliding sleeve wI 2.813" Cameo No-Go profile, EUE8RD box x pin. 3-1/2" x 6' L-80 EUE8RD handling pups installed above 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 6' Handling Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker '80-40' PBR. Baker 7" x 3-1/2" 'SAB-3' Permanent Packer set +1-100' MD above top planned perf. Minimum ID through the packer 3.00". 6' Pup Joint 3-112", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Camco 'D' nipple wI 2.75" No-Go profile. 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker 3-1/2" WL Re-entry Guide wI shear out sub. Tubing tail 50' above top planned perforation. TD @ 7946' MD I 6101' TVD (300' MD below Miluveaeh) Scott L Lowry 5/13/03 0* l~, I ,;? .~ ',J i ~Î ,1 1 ~:l1D ') \, r S. K. ALLSUP-DRAKE CONOCOPHILLlPS 711 G STREET - A T01530 ANCHORAGE AK 99501 1043 L 1jl ~ ,,' ~ " 'I ~ DATE II ì !!;¡ ~3 62-141311 :;~~~~ 6~E ðT Æ-TG o-F A L-J4sú4-tfk;t?:¡CC I $ 100. DO __ /),,, / r I ~ f /, /I /kø /Iðo- 0. 5"",,'~r"nI"'" /k- ~ LI -J! !I lJuLLARS ill ~~:~~:~"ß"k, ..... CHASE Chase Manhattan Bank USA, N.A. Valid Up To 5000 Dollars '-, _.'þ"".~, 0,__ -,~ œ "''' d MEMO --.~J4~])~·-~ I: 0 ~ . . 0 0 . ~ ~ I: 2 . BODO 0 ~ 2 7 2 5 7111 . 0 ~ ~ "'''P'.'!' '1"""J"'·'~"'\""1I-1I"~"'·.' "0,0"1\,1",,: .'! \": 'l", ,;:' ", Rev: 07/10/02 ajody\templates ) ,) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIAT:Ê LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ¡¿:"ea 3S' - D 3 PTD# 203-09/ CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) Pn.,OT (PH) "CLUE" The permit is for a new wellboresegment of existing well Permit No, API No. Production, should continue to be reported as a function' of the original API number, stated above. BOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to fuD compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing ,exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. WELLPERMl"rCHE~KLU)T Company _C_QNQÇ_OJ~.ttlL.L,lJ:.S_~.Lð.sJ~AJt~LC Well Name: .KU.EAB!JJ~..RIV_Ut~HI_._=tS-=.Q_3 Program ..QEV Well bore seg PTD#: 2030910 Field & Pool KUPARUJSBJVER....KlJEAR.UK RV O..'-L-=A.9PJ_Q..D Initial ClassfType _!2~V 11-=.QLL,.__ GeoArea 890 Unit 11160 On/Off Shore -P-'L- Annular Disposal Administration 1 Per:mit fee attached. . . . . . . . . . . . . . . . . . . . . . . _ _ . . . . . . . . . . . . . . . . . . . . Yes. . - - . . . . . . . . . . . . - . . . . . . .. . . . . . . . - . . . - . . - . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2 .Lease.numbe.r _appropriate. _ . . . . . . . . . . . . . . . . . . . _ . . . . _ _ _ _ . . . . _ _ _ . _ . . Yes. . . - - . . - . . - . . . . - . . - . - . . . . . . . . . . . . . . . - . . - . . - . . . . - . . . . . . . . - - . - . - . - . . . . . - . 3 .u.ni.que well. name .and oU.mb.er: _ _ . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . - . - . . - . - . - - - - . . . - - . . . . - . - - - - - - . . . - - - . . . 4 .We..lIJQcated i.n.a.d.efil1e_dpOQI. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ Yes. . . . . . . . . . . . . . . . - - . . . - . . . . . - - . . . . . . . . . . . . . . . . . . . . . . . . - - . . . . . . . . - . . - . - . . . . . . 5 _We.ll JQCÇlteo prppe.r .di.stance. from. dri)ling unit. bpund.ary. . . . . _ _ _ _ _ _ . . . . . . _ . . . . . . Yes . . . _ _ _ . . _ . _ _ . _ . . _ _ . _ _ . . . . . . . . . . . . . . - . - - . - - . . . . . - .. ... . . . . . - . - . . - . . . . - . . . . 6 We.ll .IQcated prppe.r di.stance. from Qthe.r wel!s. . . _ . _ . . . . . . _ _ . . . . _ . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . - - . . - - - - - - - - - . . . - - . - . . - - . . . . . . - - - - . - - - . . 7 _S_ufficiel1t.açreag.e.ayailable in.drilJilJg unjt. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . - - . . . . . . . . - . . . . . . . . . . . . -. ..... - - 8 .If.deviated, .is. weJlbQre pl;;¡Uncluded . . . . . _ . . . . . . _ _ . . . . . . . . . . . . . _ _ _ . _ . . . Yes . . . . . . . . . - .. . - . . . . . . - - . - . . . . . . . . . . . . . - - - . . . - . . . . . - - - - . . - . . . - 9 .Oper:ator Ol'll~ affeçted party. . . . . . . . . _ . . . . . . . _ _ _ . . . . . . . . . . . . .. . . . . . . Yes - - - . - - . . . - . . - . . . . . . - - . - . - - . . . . .. ....... - . - . - - - - . . . . . . . . . . . . . - - . . . . - . . . . . 1 0 _Oper.ator b~s. appropriate.t>.onc;l i.n Jorçe. . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . _ . Yes . . . . . . . . . . . - - . . . - . - . . . . . . . . . . . . . . . .. - - . . . . - - . . . . . . . . . . . . . . . . . . . . .. . .. ...... 11 Permit can be i.ssuep wjthQut conserva.tiol'l order. . _ . _ . . . . . . . . . _ _ . . . . . . . . . _ . . Yes. - . . . - - . . - . . . . . - - . . . . . . . . . . . . . . - . .. . - . - - . . - . .. . . . . . . . . . . . . . . .. . - . . . - Appr Date 12 Permit can be i.ssu.eçl wjthQut ad.mil1istr:ati\(e.approvaJ . . . . . . . . . . . . . . . . . . . . . .. - - - Yes. - - . . - - - . - - - - - . . . . . . . . . . - - - - - - - - - - - - . . - . - . . . . . . . . . . - . . - - . - . - . . S FD 5/19/2003 13 .C.an permjt.be aPPJQveo before .15-pay. waJt. . . . . . . _ _ . . . . . . . . . - . . - . . . . . . . . . Yes . . . . . . . - . . . . . . - - . . . . . . . . . . . . . . . . - . - - - - . . . - . . . . . . . . . . . . . . . - . . . . . . . . . . . . . . . . . 14 .We.IIJQcatedwi.thil'lé!reaé!n.d.strç¡taautnori.zedby.lojec.tiolJOrder: # (P!JUO# in_cor:nmeots).(For. NA... _...... _...................... -.... -...... -.... -. - - -.' -... .............. 15 .AJlwel)s.witni.n.1t4.mil.e.are.a.ofr:eyiewideotified (For.$.erv.icewelJ onl~L . . . . . . _ _ _ _ _ _ . . NA _ _ _ _ . _ . . . _ . _ . _ . . . . . . . . . . - - . - - - . - - - - . . . - - . . . - . . . . . . . . . . . . . . . . . . . . . . . . . - . . . . . 16 Pre-produ.cectinjector; durat.io.n.ofpre-:produc.tiOlJless.tné!n.3mOl'lths.(For.ser:vi.cewell. Qn!y) .. NA....................................................... -. - - -.' -. -. -.... 17 .A.GMP. F:inding _of Consist.ency.h.as bee.n .Î$.sued. forJbis prpject. . . . . . . _ . _ .. . . . . . _ . . NA . . . . - . . - . . . . . . . . .. . . . . . . . . . . . . . . . - . . . - - . . . . . . . . . . . . . . . . . . . - - - . - - - - . . - - . . . . . . 18 .C.ondu.ct.or $tr:il'lg.prQvided . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . _ . . . . Yes. . . . . . . .. . . . . - . . . . . . . . . . . . - . . . - .. . . . . . . - - - - . . - . . . . . - . . . . . - .. . . - . . - - . . . - - . . . . . 19 .S.ur:fé!ce.ca$.il'lg.PJotec.ts.~IIJnown.USOW$. _ . . . . . _ _ . . . _ . . . . . . . . . . _ . . . _ _ _ . _ NA _ . . _ . . . All.aquifeJ$.exer:npted,AO.CFR.H7.:lQ2.(ÞH3).. - - . _ . - . . . . . . . . . - . - . . . . . . - . - . . . . . . . . . . . . . 20 .CMT.v_ol.~dequ.ate.to circ_utate.o.n..cOl1d.uçtor.& $UJf.CSg _ _ _ . _ . . _ . . . . . . . . _ . _ .. _ _ _ _ Yes - - - . . - . - . . . . - . - - - - - . - - . . - . . . - . - - . . - - - - . - . . - - . . . . - . - . . . - . - . . . . . . . . . . . . - . - . . . 21 _CMT.vpl.~dequ_ate.t9tie-i..nJQng_stringtoß!JdÇ$.g_ ~ _ _ _ _ _. _ _ _ _ _ _ _ _. _. _ _ _ _ _ _ _.. No_ _ _ _ _ _ _ _an_nular.dJsp9saJr:nç¡ybe..plan_ned._ _ _ _ _ _ -.. -.. _ _ -.. _ _ ~ _ _ _ _ _ _ _ -.. _ _ _ -... - - - -. -. - -.. _ _ -- 22 .CMT. will coyer .aU !<IJOW..n .pro.duc.tiYe bQri?ons. . .. _ _ . _ . _ . _ . . . . . . . _ . . . . . . _ _ . . . Yes . . . . . - . - - . . - . . - - - . - . . . . . . - . . . . . . - . . - . . . . - - - . . - . . . . . . . . . - . . - . . . . . . . . . - . 23 .C.aging de..signs é!d.eçua.te. for: C,.T, B .&. p-erm~frost. . . . . . . . _ _ . . . . . . _ . . _ _ _ _ . . . _ Yes - . . . . . . . . . . . - . . . . . . - . . - . - - . . . . . . . - - . . . . . . - - . . . . . - . . . . . . - . . . - . . . - - . . . . . - . . . . 24 .AdequateJan.kç¡ge.oJ re.serye pit. . . . . . . . _ _ _ _ . _ . . . _ _ . . . _ . . . . . . . _ _ . . . . _ Yes _ . . . . _ . Big js.e.quippe.dwith steel.pits. .NQ rese.r\(e.p.it.planlJe.d, Wa.steJo al1.nJ,JI.us or.Glas.sJI, .. . _ . . .. _ . .. .. . _ . . . . . 25 .If.a. n~-dr:ill. né!s_a. 1.0A03 fQraba.nponme.nt beeo ;;¡pp.rQved . _ . . _ . . . .. . . . . . . . . _ . _ . .. NA. . .. . . . . . .. . . - . . . . - - - -. . . . . . . . . . . . . . . . .. - - - - - . - - . . . . . . . . . . . . - . . . - . - - . . 26 AdequateweUbore.. $.eparatjo.n .proposep. . _ . _ _ . . . . _ . _ _ . . . . _ _ . . . _ . . _ . _ _ . _ . Yes _ . . . . _ . I?roximety aoaJy.sts.pedQrmed. _ Clos.ew.eU$. idenJifie_d, . _ . _ . . _ . _ . . _ . . . _ _ _ . . _ . . _ . . . . . . . _ _ _ . _ 27 Jtdjvecter .re.q.uire.d, dQes it meet. reguJatiol1s. . . . _ . . _ . . . . . _ . . . _ . . . . . _ _ _ _ _ . _ . NA . . . . . . . Thi$. is the .4th. weJlp(opos.ed to. d.riJI wltho.ut a dive_rter:. .S.hallow.gas nas. not be.en see.n .at 3$.. . _ . . . . _ . . _ .. . Appr Date 28 .D.ril.liOgflujd.PJogramsc.hem;;¡t[c_&.eq.uipJistadequate... _. _.. ................ _ yes...... .M;;¡ximumexpectectel-:l~,.1~A.EMW..f?lan.nedMWup_to.11.9ppg................ -.. .. -..... TEM 5/20/2003 29 .BQPEs,. d.o .they .m.eet. reguJa.tiOI1 . . . . . . . . . _ _ _ . . . . _ _ . . . . _ . . . _ . . . _ _ _ _ . _ _ Yes _ . _ . - - - - - . . . . . - - - . - . . - . . . - . . - - - - - - - - . - - - - . . - - - - . . . . - . . . . - - - .. - - - - . . - . - . - . . . . 30 _B.OPE.pre..ssraJiogap-propr:iate;.te.sHo.(pu.tPSigi.n.comment$)............. _ _ _ _ _ _. yes...... . Mt\Sf?e$.tirn.atepat.2.804 psi.. 350..Dpsi_approprtate,Pf?CQltkely to.te$.tto.50PQ.. _ _. _" _.............. 31 .C.hoke. manjfold çQmpJie$. wI API. R~-53. (May ß4). . _ . . . . . . . _ . . . _ . . _ _ . . _ . _ _ . . . .Yes . . . . . . . . . - . - - - - - . . . .. . . . . . . . . - . . - . - . . . . . . -. .......... - . . - . . . . . - . - - . . . . - . . . . 32 .WQrk will oçc.ur: withputoperation .sQutc;lQw.n. . _ _ . . . _ . _ .. . . . . . . . _ . . _ . _ . . . _ . . . Yes. . - . - - . . . . . . . . . - . . . . . . - - - . - - - - . . . . - - - . . - - . - . . . . . . . . - . . - . . - . - - - - . - - . - - - - . . . . 33 J$. pre$.ence_ Qf H2S gas_ prob_aÞle. . . . _ . . . . . _ . _ _ . . . . . _ . . . . _ . . _ _ . . . . _ . . . No_ . . . . . .. - . - . - . . . . - - - . .. . - . . . . . . . . . .. . - - . . . . . . . - . . . . . . . . . . . - . - . . - - . . - - - . . . . . . . 34 Meçha.nicçll.coodJtlon of we..lIs wiJhin AQß yerifiect (for.s.ervlce w~1) onJy) _ . . . . . . . _ . . . . . NA . . . . . _ . . . . . . . . .. .. . .. . . . . - . . . . - . . - . ... .' - - . . . . . . . . . . . . . . . . - . . . . - . . . . . . . .. . . . . . 35 Per:mit. c.an Þe i.ssuep wlo. hyç1r.ogen. s.ul.fide OleaS.ur:e$. _ _ _ . _ . _ . . _ _ . . . . . . . . . _ . . . Yes . .. . - . . . . - . . . . . . . .. - - . - . . . - . . . . . . . - . . . - - . . . . . . . . . - - . . . - . . . . . . . . . . . . . . . . . . 36 .D.at.a.p.reseoted on_ pote.ntial pvemres_sl,Jr~ .zones. . . . . . . .. . _ . . .. . . _ . . . . . _ . . . . . Yes. . . . . _ _ I;xpeçted. ~U.p_re$.ervpir pr.es$.ure. i$ :11..4 ppg. ~MW;. Kupw.ill. b.e.d.rilJe..d.witn .11.9 ppg muct.. . _ . . . . . . . . . . Appr Date 37 .Seisr:nic.a.nalysJs. Qf shaJlow gas.zooe.s. . . . . . _ . . . . . . . _ . _ . . . . . . . . _ _ _ _ _ . . . _ NA _ . _ . _ _ . . . . . _ . _ . . . . . . . . . . . _ . _ _ . _ . _ . _ . . _ . . . _ . . . . . _ . . . . . . . _ . _ _ _ _ _ _ _ _ _ _ _ . . . _ . . _ SFD 5/19/2003 38 _Seabep _col'ldjtioo survey.(if off-shor:e) . . . _ . . _ . _ . _ . . _ . . . . . . . . . . . . _ _ . . . _ . . NA . . . . . . _ . . _ . _ . . . _ . . _ _ . _ . . _ . . . _ . . . .. . _ . _ _ . . _ . . _ . . . _ . _ . . . . . _ _ . _ _ . _ . . _ . . .. . . . _ . . . 39 . CQnta.ct na.01.etpnol'leJor.weekly prpgre$.s.reports [e~pIQratory .only]. . . . _ _ . _ . . _ . . . . _ . NA _ . . . . . _ . . _ _ . . . . . . . . . . . . . . . . . - - - . . . . . . - . . . . . . . . . . - - . . . . . . - . . . - - . - - . - .. . . . . . . . Engineering ~<tV\ Geology Geologic D~ioner: Date: os} <-7 /o:s Engineering c~ Public Commissioner if~~ Date ConocoPhillips plans not to use a diverter on this well. Mitigation measures for overpressure in 8 1/2" production hole are discussed in the Drilling Hazards Summary. Date ¡< W'~ D [J ( {' '\. ) ) Welll-1istory File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to sim'plify finding infomlation. infomlalion of this nature is accumulated at the end of the file under APPEN,DIX. No special effort has been made to chronologically organize this category of information. ) ) ~3-oq ( l\ ~OÒ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jun 26 14:40:37 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/26 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............. ...UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.................... .03/06/26 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number... ...01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 3S-03 501032045800 ConocoPhillips Alaska, Inc. Sperry-Sun Drilling Services 26-JUN-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0002482635 P. SMITH M. THORNTON MWD RUN 3 MW0002482635 E. QUAM D. BURLEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 18 12N 8E 2469 857 MSL 0) 56.06 27.70 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 16.000 108.0 8.500 9.625 3106.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE ) ) PRESENTED. 4. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY - PHASE 4 (EWR4); COMPENSATED THERMAL NEUTRON POROSITY (CTN); STABILIZED LITHO-DENSITY (SLD); ACOUSTIC CALIPER (ACAL); AND PRESSURE WHILE DRILLING (PWD). 5. MWD DATA ARE CONSIDERED PDC PER E-MAIL AUTHORIZATION FROM THE GKA GEOSCIENCE GROUP. 6. MWD RUNS 1 - 3 REPRESENT WELL 3S-03 WITH API#: 50-103-20458-00. THIS WELL REACHED A TOTAL DEPTH (TO) OF 7970'MD I 6156'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, ACAL-DERIVED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW- COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = SLIDE INTERVAL ADJUSTED FOR THE SLD SENSOR-TO-BIT DISTANCE. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (8.5" BIT) MUD WEIGHT: 9.3 - 11.6 PPG MUD SALINITY: 600 - 1000 PPM CHLORIDES FORMATION WATER SALINITY: 25000 PPM CHLORIDES FLUID DENSITY: 1.0 GICC MATRIX DENSITY: 2.65 GICC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .03/06/26 Maximum Physical Record..65535 File Type..... .......... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE NPHI 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3030.5 STOP DEPTH 7881.5 ) ') PEF NCNT FCNT GR RPX RPS RPM RPD FET RHOB DRHO ROP $ 3043.0 3050.0 3050.0 3086.5 3095.5 3095.5 3095.5 3095.5 3095.5 3108.5 3108.5 3117.5 7894.5 7881.5 7881.5 7938.0 7930.0 7930.0 7930.0 7930.0 7930.0 7894.5 7894.5 7970.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 2 3 MERGE TOP 3030.5 6858.0 MERGE BASE 6858.0 7970.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units....... ... .Feet Data Reference Point............. .Undefined Frame Spacing.......... .......... .60 .1IN Max frames per record............ .Undefined Absent value................... ...-999 Depth units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3030.5 7970 5500.25 9880 3030.5 7970 ROP MWD FT/H 0.89 375.03 192.326 9706 3117.5 7970 GR MWD API 43.19 456.84 121. 556 9704 3086.5 7938 RPX MWD OHMM 0.93 2000 4.6033 9670 3095.5 7930 RPS MWD OHMM 0.07 367.63 4.25533 9670 3095.5 7930 RPM MWD OHMM 0.07 269.8 4.24647 9670 3095.5 7930 RPD MWD OHMM 0.04 2000 5.04178 9670 3095.5 7930 FET MWD HOUR 0.14 49.41 0.944426 9670 3095.5 7930 NPHI MWD PU-S 11.32 52.73 32.8969 9703 3030.5 7881.5 FCNT MWD CNTS 595 2776 1004.23 9664 3050 7881.5 NCNT MWD CNTS 111880 185786 137618 9664 3050 7881.5 RHOB MWD G/CM 1.981 3.092 2.32508 9573 3108.5 7894.5 DRHO MWD G/CM -0.107 0.298 0.0500232 9573 3108.5 7894.5 PEF MWD BARN 1. 92 13.94 3.76368 9704 3043 7894.5 ) First Reading For Entire File......... .3030.5 Last Reading For Entire File......... ..7970 File Trailer Service name........... ..STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/26 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...... .03/06/26 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI PEF NCNT FCNT GR RPD FET RPM RPS RPX DRHO RHOB ROP $ 2 ) header data for each bit run in separate files. 2 .5000 START DEPTH 3030.5 3043.0 3050.0 3050.0 3086.5 3095.5 3095.5 3095.5 3095.5 3095.5 3108.5 3108.5 3117.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ # STOP DEPTH 6770.0 6783.0 6770.0 6770.0 6826.0 6819.0 6819.0 6819.0 6819.0 6819.0 6783.0 6783.0 6858.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 18-JUN-03 Insite 66.37 Memory 6858.0 3117.0 6858.0 43.7 46.3 TOOL NUMBER 124724 56933 151842 181190 8.500 ') ') DRILLER'S CASING DEPTH (FT): 3106.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 10.70 58.0 8.5 600 4.4 2.200 1. 260 2.000 2.400 70.0 127.4 70.0 70.0 # 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.....O Logging Direction................ .Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing..... ... ............ .60 .1IN Max frames per record............ .Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3030.5 6858 4944.25 7656 3030.5 6858 ROP MWD020 FT/H 8.31 375.03 218.864 7482 311 7.5 6858 GR MWD020 API 52.81 184.92 116.825 7480 3086.5 6826 RPX MWD020 OHMM 1. 03 2000 4.1545 7448 3095.5 6819 RPS MWD020 OHMM 0.07 16.25 3.70232 7448 3095.5 6819 RPM MWD020 OHMM 0.07 189.49 3.74111 7448 3095.5 6819 RPD MWD020 OHMM 0.04 2000 4.79137 7448 3095.5 6819 FET MWD020 HOUR 0.14 49.41 0.655835 7448 3095.5 6819 NPHI MWD020 PU-S 11.32 52.73 33.7251 7480 3030.5 6770 FCNT MWD020 CNTS 595 2776 966.509 7441 3050 6770 NCNT MWD020 CNTS 111880 185200 135804 7441 3050 6770 RHOB MWD020 G/CM 1.981 2.742 2.29191 7350 3108.5 6783 DRHO MWD020 G/CM -0.038 0.298 0.0467971 7350 3108.5 6783 PEF MWD020 BARN 1. 92 13.94 3.41886 7481 3043 6783 First Reading For Entire File.. ....... .3030.5 Last Reading For Entire File.......... .6858 ) File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/26 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...... .03/06/26 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Cormnent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT PEF RHOB DRHO RPM RPS RPD FET RPX GR ROP $ 3 ) header data for each bit run in separate files. 3 .5000 START DEPTH 6770.5 6770.5 6770.5 6783.5 678 3.5 6783.5 6819.5 6819.5 6819.5 6819.5 6819.5 6826.5 6858.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT); BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 7881. 5 7881. 5 7881.5 7894.5 7894.5 7894.5 7930.0 7930.0 7930.0 7930.0 7930.0 7938.0 7970.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS 20-JUN-03 Insite 66.37 Memory 7970.0 6858.0 7970.0 27.4 45.7 TOOL NUMBER 124724 56933 151842 181190 8.500 3106.0 ) ) 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: LSND 11.40 46.0 9.0 800 3.6 1.700 1. 080 1. 500 2.200 86.0 138.6 86.0 86.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units.... . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6770.5 7970 7370.25 2400 6770.5 7970 ROP MWD030 FT/H 0.89 207.76 103.048 2224 6858.5 7970 GR MWD030 API 43.19 456.84 137.469 2224 6826.5 7938 RPX MWD030 OHMM 0.93 818.22 6.10769 2222 6819.5 7930 RPS MWD030 OHMM 0.95 367.63 6.10899 2222 6819.5 7930 RPM MWD030 OHMM 0.94 269.8 5.94041 2222 6819.5 7930 RPD MWD030 OHMM 0.98 239.83 5.88111 2222 6819.5 7930 FET MWD030 HOUR 0.28 36.29 1.91176 2222 6819.5 7930 NPHI MWD030 PU-S 17.02 43.43 30.11 2223 6770.5 7881. 5 FCNT MWD030 CNTS 738 2160 1130.5 2223 6770.5 7881.5 NCNT MWD030 CNTS 121190 185786 143691 2223 6770.5 7881.5 RHOB MWD030 G/CM 2.223 3.092 2.43477 2223 6783.5 7894.5 DRHO MWD030 G/CM -0.107 0.298 0.0606896 2223 678 3.5 7894.5 PEF MWD030 BARN 2.28 8.99 4.92409 2223 678 3.5 7894.5 First Reading For Entire File......... .6770.5 Last Reading For Entire File.......... .7970 File Trailer ~ . " ) ) Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/26 Maximum Physical Record. .65535 File Type............... .LO Next File Name....... ... .STSLIB.004 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/26 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. . . . . . . . . . . . . . . . . . . . .03/06/26 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