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185-048
Originated: Delivered to:10-Apr-25 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 # E SET# 1 1Y-27 50-029-22379-00 909953476 Kuparuk River Packer Setting Record Field- Final 1-Apr-25 0 1 2 1Y-27 50-029-22379-00 909915690 Kuparuk River Packer Setting Record Field- Final 20-Mar-25 0 1 3 1Y-27 50-029-22379-00 909953476 Kuparuk River Packer Setting Record Field- Final 31-Mar-25 0 1 4 1Y-29 50-103-21852-00 909915382 Kuparuk River Multi Finger Caliper Field & Processed 23-Mar-25 0 1 5 2A-04 50-103-20026-00 909976821 Kuparuk River Multi Finger Caliper Field & Processed 31-Mar-25 0 1 6 2K-20 50-103-20120-00 909966603 Kuparuk River Multi Finger Caliper Field & Processed 26-Mar-25 0 1 7 2T-20 50-103-20215-00 909915691 Kuparuk River Multi Finger Caliper Field & Processed 13-Mar-25 0 1 8 2V-10 50-029-21310-00 909915383 Kuparuk River Packer Setting Record Field- Final 17-Mar-25 0 1 9 3T-731 50-103-20905-00 909991288 Kuparuk River Cement Evaluation with CAST Field & Processed 2-Apr-25 0 1 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: 193-088 188-091 184-053 189-118 195-029 185-048 224-156 T40310 T40310 T40310 T40311 T40312 T40313 T40314 T40315 T40316 4/10/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.10 14:23:59 -08'00' 82V-10 50-029-21310-00 909915383 Kuparuk River Packer Setting Record Field- Final 17-Mar-25 0 1 185-048 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: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7575'1889 7434' Casing Collapse Conductor Surface Production 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: 907-263-4529 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 None 9-5/8" 66' BAKER HS Packer Baker FB-1 Permanent Packer SSSV: None 6204'7351'6018' 7" 16" KRU 2V-10 7060-7103' 7110-7118' 7124-7130' 7233-7239' 7247-7262' 7274-7314' 7318-7322' 7513' 5774-5811' 5817-5823' 5828-5833' 5920-5925' 5932-5944' 5954-5987' 5991-5994' 3308' 7548' Perforation Depth MD (ft): 101' 3/27/2025 3-1/2" 3-1/2" 101' 3343' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025644 185-048 P.O. Box 100360, Anchorage, AK 99510 50-029-21310-00-00 ConocoPhillips Alaska, Inc AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 6952'MD/5683'TVD 7162'MD/5860'TVD 7166' 7185' 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. Proposed Pools: 2908' Burst Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field TVD Perforation Depth TVD (ft): MD 6182' Adam Klem adam.klem@conocophillips.com CTD Engineer Subsequent Form Required: Suspension Expiration Date: L-80 J-55 m n P s 1 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:46 am, Mar 28, 2025 Digitally signed by Adam Klem DN: CN=Adam Klem, E=adam.klem@ conocophillips.com, C=US Reason: I am approving this document Location: Date: 2025.03.28 08:20:41-08'00' Foxit PDF Editor Version: 13.1.6 Adam Klem 325-180 Biennial MIT-T with plug set below packer at 6954’MD and Biennial IA DDT with fluid levels or MITIA Ensure upper packer is set in cemented production casing Note: These conditions of approval may change to be in-line with the outcome of the 3M-19 request for reconsideration and docket OTH-25-016. DSR-4/2/25A.Dewhurst 28MAR25 10-404 JJL 3/28/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.03 10:46:56 -08'00'04/03/25 RBDMS JSB 040425 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 28, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Adam Klem Staff CTD/RWO Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for a Change to approved Sundry to work over KUP Producer 2V-10 (PTD# 185-048). Well 2V-10 was worked over as per the approved sundry. However after setting the upper selective packer, a casing leak was discovered. It was identified below 6491'MD, so we intend to set an additional packer above the leak to isolate it from the reservoir. See the red text in the summary for changes to approved program. If you have any questions or require any further information, please contact me at 907-263-4529 Digitally signed by Adam Klem DN: CN=Adam Klem, E= adam.klem@conocophillips.com, C=US Reason: I am approving this document Location: Date: 2025.03.28 08:20:51-08'00' Foxit PDF Editor Version: 13.1.6 Adam Klem 2V-10 RWO Procedure Kuparuk Producer - RWO PTD #185-048 Page 1 of 3 General Well info: Wellhead type/pressure rating: FMC Gen IV Production Engineer: Kristian Fredagsvik Reservoir Development Engineer: Kevin Wiggs Estimated Start Date: March 27, 2025 Workover Engineer: James Ohlinger (265-1102/ James.J.Ohlinger@conocophillips.com) Current Operations: This well is currently shut in; since May 2020 Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to the pre-rig cut above the packer. Remove the upper packer and tubing in the selective. Run new tubing stabbed into the SBE of the lowest packer with a new selective completion to surface. BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Ram Following subject to change/be updated with pre-rig work: CMIT&MIT NA – with current tubing leaks and patches MIT-OA: Passed 2/2/24 @ 1800 psi IC POT & PPPOT Passed 10/27/23 T POT Passed 9/18/21 MPSP: 1889 psi using 0.1 psi/ft gradient Static BHP: 2471 psi / 5820 TVD measured on 11/24/23 Remaining Pre-Rig Work 1. Static Bottom Hole Pressure 2. IC-POT, IC-PPPOT, T-PPPOT and T-POT tests. 3. Open lowest GLM in upper completion, dummy all other GLM 4. Cut the tubing at ~6665’ RKB in the middle of the first full joint above the packer @ 6995’ RKB 5. Prepare well within 48 hrs of rig arrival. 2V-10 RWO Procedure Kuparuk Producer - RWO PTD #185-048 Page 2 of 3 Rig Work MIRU 1. MIRU Nabors 7ES on 2V-10 (a BPV will be set before/after RU/RD) 2. Confirm BPV as barrier, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing – Part 1of2 3. Pull BPV 4. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 5. MU landing joint and BOLDS. 6. Pull 3-1/2” tubing down to pre-rig cut (~6665’ RKB). 7. RU E-line: Run CBL 7” Surface Casing Grow & Stretch 8. If KWF has been static at surface or 1 barrier already exists in the well, then set RBP or IBP at ~200’ RKB. 9. ND BOPEs 10. RU casing de-tensioning equipment. ND tubing head and allow 7” production casing to grow per procedure recording pressure and growth through each cycle. 11. Land casing in slips 12. Cut off excess with Wachs Cutter. 13. Install PO, NU Tubing Head, Test IC-PO. NU BOPE with necessary adapters and spacer spools. Test break to 2500 psi against RBP. 14. If shallow IBP/RBP was set, then RIH and pull RBP or IBP. TOOH and LD plug. 7” Surface Casing Subsidence Repair – Contingency since there’s only 47” of subsidence 15. Set RBP in 7” casing below TOC, pressure test or perform 30 min NFT, dump 50’ of sand on top of RBP. 16. RIH with multistring cutter on DP, cut 7” casing above the TOC, POOH and stand back DP 17. Circulate out the Arctic Pack from the OA 18. ND BOP, ND Tubing head, NU BOP a. At this point we won’t be able to test the break 19. Spear the 7” casing. POOH and lay down the 7” casing 20. RIH w/ tandem string mills to gauge the 9-5/8” casing for the ES cementer & Sealing Overshot 21. RU casing crew and RIH w/ new 7” casing, ES Cementer, and Sealing Overshot, PT casing to 2500 psi 22. RU cementer and cement 7” x 9-5/8” annulus to surface 23. ND BOPE, pull 7” casing in tension and land in the slips. Cut excess 7” casing with Wachs cutter. 24. NU new tubing head and BOP stock. Test break 25. RIH w/ 6-1/8” bit&mill to TOC, mill through cement. POOH standing back drillpipe. 26. Pressure test the casing to 2500 psi, chart for 30 minutes 27. RIH w/ wash string assembly and circulate out sand on top of RBP that was set below TOC 28. Pull RBP Retrieve Tubing – Part 2 of 2 29. Pull remaining 3-1/2” tubing stub from the PBR (6982’ RKB) 30. RIH w/ a work string or tubing to the packer. 31. RU E-line: perform 2 tubing cuts in the selective; ~7010’ and 7120’ RKB 32. Pull the upper packer (6995’ RKB) 33. Pull the tubing from the selective and the SBE (7166’) 2V-10 RWO Procedure Kuparuk Producer - RWO PTD #185-048 Page 3 of 3 Install in 3-1/2” Completion 34. MU 3-1/2” completion with seal assembly, GLM, Packer, PBR, and GLM; RIH with completion. 35. Once on depth, circulate CI brine, space out as needed, land hanger, RILDS, drop B&R, and set packer. 36. Pressure test tubing to 3000 psi for 30 minutes and chart. 37. Pressure test inner annulus to 2500 psi for 30 minutes on chart. Pressure test failed Identify Casing leak 38. MU test packer and RIH to identify leak. Passing pressure tested casing from 6491’ RKB to surface. 39. Failing pressure test from 6583’ RKB to surface 40. Set test packer at 6897’ RKB and test below it to verify upper selective packer. Passing test. 41. POOH LD test packer Install in 3-1/2” Completion 42. MU 3-1/2” completion with seal assembly, GLM, Packer, PBR, and GLM; RIH with completion. 43. Once on depth, circulate CI brine, space out as needed, land hanger, RILDS, drop B&R, and set packer. 44. Pressure test tubing to 3000 psi for 30 minutes and chart. 45. Pressure test inner annulus to 2500 psi for 30 minutes on chart ND BOP, NU Tree 46. Confirm pressure tests, then shear out SOV with pressure differential. 47. Install BPV. 48. ND BOPE. NU tree. PT tree. 49. Pull BPV, freeze protect well at opportune time, and set BPV if necessary. 50. RDMO. Post-Rig Work 51. Install GLD. 52. Pull Ball and Rod 53. Pull any remaining plugs in well. 54. Turn over to operations. * Ensure upper packer is set in cemented production casing - JJL 2V-10 Proposed Completion COMPLETION FMC Gen IV Tubing Hangar 3.5" EUEM tubing 3.5" MMG GLMs @ TBD SLB BluePack Permanent packer @ ~6480'MD 2.813" X nipple @ ~6430'MD 3.5" MMG GLM @ ~6460' MD Baker 40-80 Seal Assembly 6927' MD Baker HS Packer @ 6954'MD w/ PBR @ 6930'MD 2.813" X nipple @ 6979' MD 3.5" MMG @ 7000'MD Blast Joints 7023-7147'MD Baker CMU sliding sleeve @ 7151'MD Baker GBH-22 Locator Seal Assembly 7161' RKB Baker FB-1 Permanent Packer @ 7162' RKB Baker SBE @ 7166' RKB Camco D-Nipple @ 7177' RKB (2.75" ID) Baker SOS @ 7184' RKB Surface Casing 3343' MD Production Casing Conductor A-sand perfs 7233' - 7322' RKB C+B Perfs 7060' - 7130' RKB TOC~ 1987' RKB Estimated TOC ~ 6225’ MD (SLB CBT Log 4/21/85) Casing leak identified ~6500' MD From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL]RE: 2V-10 (PTD 185-048) Update and plan forward Date:Wednesday, April 2, 2025 12:42:51 PM From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Thursday, March 27, 2025 5:53 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: Re: [EXTERNAL]RE: 2V-10 (PTD 185-048) Update and plan forward Jack-one slight change is we don’t plan to run a GLM between the two upper packers From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Thursday, March 27, 2025 4:50:06 PM To: Klem, Adam <Adam.Klem@conocophillips.com> Cc: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: [EXTERNAL]RE: 2V-10 (PTD 185-048) Update and plan forward 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. Adam, Thanks for the call and email. You have verbal approval to move forward as outlined below. Please submit a 10-403 for change of approved program within 3 days. As discussed, until 3M-19 is resolved, the AOGCC will require the following conditions of approval. These conditions of approval may change to be inline with the outcome of the 3M-19 decision. Biennial MIT-T with plug set below packer at 6954’MD Biennial DDT or MITIA Jack 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: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Thursday, March 27, 2025 2:13 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: 2V-10 (PTD 185-048) Update and plan forward Jack, As I mentioned on the phone earlier, we located an unexpected hole in the production casing on 2V-10 RWO. We should be wrapping up with our test packer run shortly and then will be ready to run the proposed completion later today. Here’s a summary and plan forward: Summary of operations to date: 1. We were able to pull the upper tubing completion 2. We grew and stretched the casing, and determined we did not need to pursue the subsidence contingency 3. Pulled the remaining tubing above the upper HB packer 4. Pulled the HB packer 5. Pulled the secretive completion along with the blast rings 6. Pulled the remaining tubing stub from the lower Baker FB packer 7. We ran the new completion stabbing seals into the FB packer. 8. We pressured up against the bridge plug in the tubing tail and set the new Baker HS packer 9. We got a good tubing pressure test to 3000psi 10. We then were unable to get a good IA pressure test 11. We pulled the tubing from the new Baker HS PBR and racked it back 12. We picked up a test packer and ran in hole to identify the depth of the casing leak 13. We got a passing pressure test from 6491’MD to surface. 14. We had failing pressure test from 6583’MD to surface Plan Forward: 1. Run in hole to above the new Baker HS packer and pressure test below the test packer to confirm the HS packer is holding 2. Once packer is confirmed to be holding pressure, POOH LD test packer 3. Run new completion consisting of seals to stab into PBR and permanent packer to straddle the casing leak at ~6480’MD 4. Set packer 5. Pressure test tubing and IA 6. Proceed with rig down operations as per plan. Notes: 1. The casing leak will be isolated above and below by tested packers 2. The casing leak is below logged TOC by CBL 3. See attached for new proposed schematic Adam Klem Staff RWO/CTD Engineer ConocoPhillips Alaska 700 G St ATO 566 Anchorage, AK 99510 907-263-4529 Office 970-317-0300 Cell Adam.Klem@conocophillips.com ORIGINATED TRANSMITTAL DATE: 3/31/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5352 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 5352 2V-10 50029213100000 Tubing Cut Record 18-Mar-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 lorna.c.collins@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 185-048 T40248 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.01 13:09:17 -08'00' DNR DIGITAL FILES PRINTS CD'S 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 AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ORIGINATED TRANSMITTAL DATE: 3/18/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5332 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 5332 2V-10 50029213100000 Cement Bond Log 7-Mar-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street lorna.c.collins@conocophillips.com Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 185-048 T40216 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.18 09:33:02 -08'00' DNR DIGITAL FILES PRINTS CD'S 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 AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ORIGINATED TRANSMITTAL DATE: 3/18/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5349 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 5349 2V-10 50029213100000 Tubing Cut Record 13-Mar-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 lorna.c.collins@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 185-048 T40216 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.18 09:32:10 -08'00' DNR DIGITAL FILES PRINTS CD'S 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 AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 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) To:Ohlinger, James J Cc:Lau, Jack J (OGC); AOGCC Records (CED sponsored) Subject:RE: 2V-10(PTD 185-048, Sundry 324-538) Date:Monday, March 3, 2025 11:28:45 AM James, This email notification will suffice for rig change. Please include this change with your approved copy of the sundry. Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Sent: Monday, March 3, 2025 10:59 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: 2V-10: Sundry_324-538_10-403 We are finally getting to 2V-10, work is to be conducted on Nordic 3. From: Ohlinger, James J Sent: Monday, December 16, 2024 10:54 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: 2V-10: Sundry_324-538_10-403 Good morning I have Sundry_324-538_10-403, it was originally planned to be conducted in November by Doyon 25. It is now on Nordic 3 for February 2. Do you require anything for this change? James J. Ohlinger CPAI CTD Staff Engineer Office: 907-267-1102 Cell: 907-229-3338 ORIGINATED TRANSMITTAL DATE: 10/30/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5138 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 5138 2V-10 50029213100000 Tubing Cut Record 23-Oct-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 185-048 T39722 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.30 12:48:35 -08'00' DNR DIGITAL FILES PRINTS CD'S 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 AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 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: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7575'1889 7434' Casing Collapse Conductor Surface Production 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: 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 Kuparuk River Field James Ohlinger james.j.ohlinger@conocophillips.com CTD Engineer Subsequent Form Required: Suspension Expiration Date: J-55 TVD Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6669'MD/5446'TVD 6669'MD/5471'TVD 6718'MD/5486'TVD 6995'MD/5720'TVD 7162'MD/5860'TVD 1837'MD/1711'TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025644 185-048 P.O. Box 100360, Anchorage, AK 99510 50-029-21310-00-00 ConocoPhillips Alaska, Inc Proposed Pools: Burst 7185' MD 101' 2908' 101' 3343' 6182'7" 16" 9-5/8" 66' 3308' 7548' Perforation Depth MD (ft): 10/9/2024 4"x3-1/2" Weatherford ER Packer Weatherford ER Packer Weatherford ER Packer Baker HB Retrievable Packer Baker FB-1 Permanent Packer SSSV: Otis FMX 6204' 7351' 6018' None KRU 2V-10 7060-7103' 7110-7118' 7124-7130' 7233-7239' 7247-7262' 7274-7314' 7318-7322' 7513' 5774-5811' 5817-5823' 5828-5833' 5920-5925' 5932-5944' 5954-5987' 5991-5994' Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Contact Phone: 907-265-1102 By Grace Christianson at 2:39 pm, Sep 19, 2024 Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E=James.J.Ohlinger@ cop.com Reason: I am the author of this document Location: Date: 2024.09.19 13:17:30-08'00' Foxit PDF Editor Version: 13.0.0 James J. Ohlinger X DSR-9/27/24 BOP test to 2500 psig Annular preventer test to 2500 psig 11/5/2024 10-404X A.Dewhurst 19SEP24 VTL 10/3/2024JLC 10/3/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.10.07 12:09:14 -08'00' 10/07/24 RBDMS JSB 100824 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 19, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: James J Ohlinger Staff CTD/RWO Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 2V-10 (PTD# 185-048). Well 2V-10 was drilled and completed in April of 1985 by Parker 141 as a producer into the C & A-sands. The well was worked over in 1991. Has been shut in since April '20 for high water cut. The tubing leaks now require that the well be recompleted . If you have any questions or require any further information, please contact me at +1-907-229-3338. Pull the existing 3-1/2” completion down to the pre-rig cut above the packer. Remove the upper packer and tubing in the selective. Run new tubing stabbed into the SBE of the lowest packer with a new selective completion to surface. 2V-10 RWO Procedure Kuparuk Producer - RWO PTD #185-048 Page 1 of 5 General Well info: Wellhead type/pressure rating: FMC Gen IV Production Engineer: Kristian Fredagsvik Reservoir Development Engineer: Kevin Wiggs Estimated Start Date: November 9th, 2004 Workover Engineer: James Ohlinger (265-1102/ James.J.Ohlinger@conocophillips.com) Current Operations: This well is currently shut in; since May 2020 Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to the pre-rig cut above the packer. Remove the upper packer and tubing in the selective. Run new tubing stabbed into the SBE of the lowest packer with a new selective completion to surface. BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Ram Following subject to change/be updated with pre-rig work: CMIT&MIT NA – with current tubing leaks and patches MIT-OA: Passed 2/2/24 @ 1800 psi IC POT & PPPOT Passed 10/27/23 T POT Passed 9/18/21 MPSP: 1889 psi using 0.1 psi/ft gradient Static BHP: 2471 psi / 5820 TVD measured on 11/24/23 Remaining Pre-Rig Work 1. Static Bottom Hole Pressure 2. IC-POT, IC-PPPOT, T-PPPOT and T-POT tests. 3. Open lowest GLM in upper completion, dummy all other GLM 4. Cut the tubing at ~6665’ RKB in the middle of the first full joint above the packer @ 6995’ RKB 5. Prepare well within 48 hrs of rig arrival. 2V-10 RWO Procedure Kuparuk Producer - RWO PTD #185-048 Page 2 of 5 Rig Work MIRU 1. MIRU Nabors 7ES on 2V-10 (a BPV will be set before/after RU/RD) 2. Confirm BPV as barrier, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing – Part 1of2 3. Pull BPV 4. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 5. MU landing joint and BOLDS. 6. Pull 3-1/2” tubing down to pre-rig cut (~6665’ RKB). 7. RU E-line: Run CBL 7” Surface Casing Grow & Stretch 8. If KWF has been static at surface or 1 barrier already exists in the well, then set RBP or IBP at ~200’ RKB. 9. ND BOPEs 10. RU casing de-tensioning equipment. ND tubing head and allow 7” production casing to grow per procedure recording pressure and growth through each cycle. 11. Land casing in slips 12. Cut off excess with Wachs Cutter. 13. Install PO, NU Tubing Head, Test IC-PO. NU BOPE with necessary adapters and spacer spools. Test break to 2500 psi against RBP. 14. If shallow IBP/RBP was set, then RIH and pull RBP or IBP. TOOH and LD plug. 7” Surface Casing Subsidence Repair – Contingency since there’s only 47” of subsidence 15. Set RBP in 7” casing below TOC, pressure test or perform 30 min NFT, dump 50’ of sand on top of RBP. 16. RIH with multistring cutter on DP, cut 7” casing above the TOC, POOH and stand back DP 17. Circulate out the Arctic Pack from the OA 18. ND BOP, ND Tubing head, NU BOP a. At this point we won’t be able to test the break 19. Spear the 7” casing. POOH and lay down the 7” casing 20. RIH w/ tandem string mills to gauge the 9-5/8” casing for the ES cementer & Sealing Overshot 21. RU casing crew and RIH w/ new 7” casing, ES Cementer, and Sealing Overshot, PT casing to 2500 psi 22. RU cementer and cement 7” x 9-5/8” annulus to surface 23. ND BOPE, pull 7” casing in tension and land in the slips. Cut excess 7” casing with Wachs cutter. 24. NU new tubing head and BOP stock. Test break 25. RIH w/ 6-1/8” bit&mill to TOC, mill through cement. POOH standing back drillpipe. 26. Pressure test the casing to 2500 psi, chart for 30 minutes 27. RIH w/ wash string assembly and circulate out sand on top of RBP that was set below TOC 28. Pull RBP Retrieve Tubing – Part 2 of 2 29. Pull remaining 3-1/2” tubing stub from the PBR (6982’ RKB) 30. RIH w/ a work string or tubing to the packer. 31. RU E-line: perform 2 tubing cuts in the selective; ~7010’ and 7120’ RKB 32. Pull the upper packer (6995’ RKB) 33. Pull the tubing from the selective and the SBE (7166’) 2V-10 RWO Procedure Kuparuk Producer - RWO PTD #185-048 Page 3 of 5 Install in 3-1/2” Completion 34. MU 3-1/2” completion with seal assembly, GLM, Packer, PBR, and GLM; RIH with completion. 35. Once on depth, circulate CI brine, space out as needed, land hanger, RILDS, drop B&R, and set packer. 36. Pressure test tubing to 3000 psi for 30 minutes and chart. 37. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 38. Confirm pressure tests, then shear out SOV with pressure differential. 39. Install BPV. 40. ND BOPE. NU tree. PT tree. 41. Pull BPV, freeze protect well at opportune time, and set BPV if necessary. 42. RDMO. Post-Rig Work 43. Install GLD. 44. Pull Ball and Rod 45. Pull any remaining plugs in well. 46. Turn over to operations. 2V-10 RWO Procedure Kuparuk Producer - RWO PTD #185-048 Page 4 of 5 2V-10 Existing Completion COMPLETION FMC Gen IV Tubing Hangar Otis FMX Safety Valve @ 3313' RKB (6" OD) Crossover 4" x 3.5" @ 4984' RKB Baker PBR @ 6982' RKB (3.0" ID) Baker HB Retrievable Packer @ 6995' RKB Camco CB-1 Sliding Sleeve @ 7146' RKB Closed 5/2/2006 Baker GBH-22 Locator Seal Assembly 7161' RKB Baker FB-1 Permanent Packer @ 7162' RKB Baker SBE @ 7166' RKB Camco D-Nipple @ 7177' RKB (2.75" ID) Baker SOS @ 7184' RKB Surface Casing 3343' MD Production Casing Conductor A-sand perfs 7233' - 7322' RKB C+B Perfs 7060' - 7130' RKB Tubing Leak 7050' RKB Tubing Leak 6711' RKB ER Packer ~ 6669' ER Packer ~ 6699' ER Packer ~ 6718' ON RIG Mechanical Tubing Cut ~6745' RKB ON RIG Tubing Cut 7120' RKB ON RIG Tubing Cut 7010' RKB GLM ~6543' RKBPRE-RIG Tubing Cut ~6665' RKB GLM ~6931' RKB 47" of subsidence TOC ~ 1987' RKB 330' Stub Estimated TOC ~ 6225’ MD (SLB CBT Log 4/21/85) 2V-10 RWO Procedure Kuparuk Producer - RWO PTD #185-048 Page 5 of 5 2V-10 Proposed Completion COMPLETION FMC Gen IV Tubing Hangar Crossover 4" x 3.5" @ xxx' RKB GLM @ xxxx' RKB PBR @ xxxx' RKB (3.0" ID) Packer @ xxxx' RKB Nipple profile xxxx' RKB GLM @ xxxx' RKB Baker Steel Blast Joints GLM @ xxxx' RKB Locator Seal Assembly 7161' RKB Existing COMPLETION Baker FB-1 Permanent Packer @ 7162' RKB Baker SBE @ 7166' RKB Camco D-Nipple @ 7177' RKB (2.75" ID) Baker SOS @ 7184' RKB Surface Casing Production Casing Conductor A-sand perfs 7233' - 7322' RKB C+B Perfs 7060' - 7130' RKB >6995' Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,351.0 2V-10 9/29/2019 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled catcher, slip stop & D&D packoff plug. 2V-10 12/5/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTIPLE ATTEMPTS TO PULL STA #5 ON 9/4/20 & 10/19 & 20 OF 2012, UNABLE TO LOCATE 9/5/2020 condijw 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 34.6 101.0 101.0 65.00 H-40 WELDED SURFACE 9 5/8 8.92 34.6 3,343.0 2,908.0 36.00 J-55 BTC PRODUCTION 7 6.28 34.6 7,547.9 6,181.5 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 33.0 Set Depth … 7,185.0 Set Depth … 5,879.6 String Max No… 4 Tubing Description TUBING 4"x3.5" @ 4984' Wt (lb/ft) 11.00 Grade J-55 Top Connection DSS-HTC ID (in) 3.48 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) 33.0 33.0 0.37 HANGER 10.800 FMC GEN IV TUBING HANGER 4.000 1,836.7 1,710.5 38.53 SAFETY VLV 6.000 OTIS FMX SERIES 10 SAFETY VALVE 3.313 2,835.6 2,506.3 37.45 GAS LIFT 5.898 CAMCO KBUG 3.351 3,745.7 3,216.1 42.21 GAS LIFT 5.898 CAMCO KBUG 3.351 4,184.5 3,539.5 42.77 GAS LIFT 5.898 CAMCO KBUG 3.351 4,584.1 3,832.2 43.16 GAS LIFT 5.898 CAMCO KBUG 3.351 4,983.7 4,126.3 41.93 XO Reducing 4.000 CROSSOVER 4 x 3.5, ID 2.992, #9.3, J-55 & L-80, EUE8rdABMOD 3.500 4,990.6 4,131.4 41.91 GAS LIFT 5.968 CAMCO MMG 2.920 5,387.6 4,430.0 40.31 GAS LIFT 5.968 CAMCO MMG 2.920 5,784.2 4,736.1 38.36 GAS LIFT 5.968 CAMCO MMG 2.920 6,180.9 5,051.0 37.24 GAS LIFT 5.968 CAMCO MMG 2.920 6,543.3 5,342.4 35.28 GAS LIFT 5.968 CAMCO MMG 2.920 6,931.2 5,665.4 32.15 GAS LIFT 5.968 CAMCO MMG 2.920 6,981.5 5,708.1 32.17 PBR 5.125 BAKER 10' STROKE PBR 3.000 6,995.2 5,719.7 32.18 PACKER 6.062 BAKER HB RETRIEVABLE PACKER 2.890 7,036.8 5,754.8 32.36 PRODUCTION 5.968 CAMCO MMG-W 2.920 7,050.9 5,766.7 32.43 BLAST RINGS 4.500 CARBIDE BLAST RING (1) 2.867 7,081.2 5,792.3 32.59 BLAST RINGS 4.500 CARBIDE BLAST RINGS (2) 2.867 7,146.3 5,847.1 32.87 SLEEVE-C 4.312 CAMCO CB-1 SLIDING SLEEVE; CLOSED 5/2/2006 2.812 7,161.1 5,859.5 32.92 SEAL ASSY 4.500 BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 7,162.1 5,860.3 32.93 PACKER 5.875 BAKER FB-1 PERMANENT PACKER 4.000 7,165.5 5,863.1 32.94 SBE 5.000 BAKER SEAL BORE EXTENSION 4.000 7,176.5 5,872.4 32.99 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750 7,184.1 5,878.8 33.02 SOS 3.500 BAKER SHEAR OUT SUB 2.992 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) 6,669.0 5,445.7 34.25 PACKER - PATCH - UPR WEATHERFORD ER PACKER (OAL 30.84') 10/18/2012 1.810 6,671.0 5,447.4 34.24 PATCH SPACER PIPE, SNAP LATCH SEAL ASSEMBLY 10/18/2012 1.750 6,699.0 5,470.5 34.06 PACKER - PATCH - MID WEATHERFORD ER PACKER (OAL 23.01') 10/11/2012 1.810 6,701.9 5,472.9 34.03 PATCH SPACER PIPE, SNAP LATCH SEAL ASSEMBLY 10/11/2012 1.750 6,711.0 5,480.5 33.93 LEAK - TUBING LEAK FOUND IN A COLLAR AT 6711 8/28/2012 6,718.1 5,486.4 33.85 PACKER - PATCH - LWR WEATHERFORD ER PACKER 10/9/2012 1.750 7,050.0 5,766.0 32.43 LEAK - C- SAND C-SAND TUBING LEAK, CONFIRMED 4/7/97, 2/17/2005, 7/3/2010 4/7/1997 7,146.3 5,847.0 32.87 ISO SLEEVE CB-1 ISO FRAC SLEEVE, 49" OAL, 5/4/2006 2.310 7,434.0 6,086.9 33.83 FISH 1 1/2" CV Lost One CV 4/22/1996 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) 2,835.6 2,506.3 37.45 1 GAS LIFT GLV BK 1 1,253.0 10/13/2019 0.156 3,745.7 3,216.1 42.21 2 GAS LIFT GLV BK 1 1,292.0 10/12/2019 0.188 4,184.5 3,539.5 42.77 3 GAS LIFT OV BK 1 0.0 10/13/2019 0.250 4,584.1 3,832.2 43.16 4 GAS LIFT DMY BK 1 0.0 4/13/1996 0.000 2V-10, 12/6/2023 8:08:05 AM Vertical schematic (actual) PRODUCTION; 34.6-7,547.9 FISH; 7,434.0 RPERF; 7,318.0-7,322.0 IPERF; 7,318.0-7,322.0 IPERF; 7,274.0-7,314.0 RPERF; 7,274.0-7,314.0 IPERF; 7,247.0-7,262.0 RPERF; 7,247.0-7,262.0 IPERF; 7,233.0-7,239.0 RPERF; 7,233.0-7,239.0 PACKER; 7,162.1 ISO SLEEVE; 7,146.3 IPERF; 7,124.0-7,130.0 RPERF; 7,124.0-7,130.0 RPERF; 7,110.0-7,118.0 IPERF; 7,110.0-7,118.0 IPERF; 7,090.0-7,103.0 CMT SQZ; 7,090.0 ftKB RPERF; 7,079.0-7,090.0 IPERF; 7,079.0-7,090.0 RPERF; 7,060.0-7,079.0 IPERF; 7,060.0-7,079.0 LEAK - C-SAND; 7,050.0 PRODUCTION; 7,036.8 PACKER; 6,995.2 GAS LIFT; 6,931.2 PACKER - PATCH - LWR; 6,718.1 LEAK - TUBING; 6,711.0 PATCH; 6,701.9 PACKER - PATCH - MID; 6,699.0 PATCH; 6,671.0 PACKER - PATCH - UPR; 6,669.0 GAS LIFT; 6,543.3 GAS LIFT; 6,180.9 GAS LIFT; 5,784.2 GAS LIFT; 5,387.6 GAS LIFT; 4,990.6 GAS LIFT; 4,584.1 GAS LIFT; 4,184.5 GAS LIFT; 3,745.7 SURFACE; 34.6-3,343.0 GAS LIFT; 2,835.6 SAFETY VLV; 1,836.7 CONDUCTOR; 34.6-101.0 KUP PROD KB-Grd (ft) 34.98 RR Date 4/5/1985 Other Elev… 2V-10 ... TD Act Btm (ftKB) 7,575.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292131000 Wellbore Status PROD Max Angle & MD Incl (°) 43.20 MD (ftKB) 4,600.00 WELLNAME WELLBORE2V-10 Annotation Last WO: End Date 10/15/1991 H2S (ppm) 100 Date 12/13/2019 Comment SSSV: TRDP 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) 4,990.6 4,131.4 41.91 5 GAS LIFT DMY RK 1 1/2 0.0 3/29/2007 SEE NOTE 0.000 5,387.6 4,430.0 40.31 6 GAS LIFT DMY RK 1 1/2 0.0 6/7/1995 0.000 5,784.2 4,736.1 38.36 7 GAS LIFT DMY RK 1 1/2 0.0 3/29/2007 0.000 6,180.9 5,051.0 37.24 8 GAS LIFT DMY RK 1 1/2 0.0 3/29/2007 0.000 6,543.3 5,342.4 35.28 9 GAS LIFT DMY RK 1 1/2 0.0 4/12/1996 0.000 6,931.2 5,665.4 32.15 1 0 GAS LIFT DMY RK 1 1/2 0.0 4/12/1996 0.000 7,036.8 5,754.8 32.36 1 1 PROD CV RK 1 1/2 0.0 5/31/2006 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,060.0 7,079.0 5,774.4 5,790.4 C-4, 2V-10 5/3/1985 13.0 IPERF 4 1/2" CG 7,060.0 7,079.0 5,774.4 5,790.4 C-4, 2V-10 10/12/1991 12.0 RPERF Deep Hole Gun 7,079.0 7,090.0 5,790.4 5,799.7 C-4, 2V-10 5/3/1985 1.0 IPERF 4 1/2" CG 7,079.0 7,090.0 5,790.4 5,799.7 C-4, 2V-10 10/12/1991 12.0 RPERF Deep Hole Gun 7,090.0 7,103.0 5,799.7 5,810.6 C-4, C-3, C-1, 2V-10 5/3/1985 1.0 IPERF CMT SQU 10/91; 4 1/2" CG 7,110.0 7,118.0 5,816.5 5,823.3 UNIT B, 2V-10 5/3/1985 1.0 IPERF 4 1/2" CG 7,110.0 7,118.0 5,816.5 5,823.3 UNIT B, 2V-10 10/12/1991 12.0 RPERF Deep Hole Gun 7,124.0 7,130.0 5,828.3 5,833.3 UNIT B, 2V-10 5/3/1985 1.0 IPERF 4 1/2" CG 7,124.0 7,130.0 5,828.3 5,833.3 UNIT B, 2V-10 10/12/1991 12.0 RPERF Deep Hole Gun 7,233.0 7,239.0 5,919.7 5,924.7 A-5, 2V-10 10/12/1991 12.0 RPERF Deep Hole Gun 7,233.0 7,239.0 5,919.7 5,924.7 A-5, 2V-10 5/3/1985 4.0 IPERF 4/ 4 1/2" 7,247.0 7,262.0 5,931.4 5,943.9 A-4, 2V-10 10/12/1991 12.0 RPERF Deep Hole Gun 7,247.0 7,262.0 5,931.4 5,943.9 A-4, 2V-10 5/3/1985 4.0 IPERF 4/ 4 1/2" 7,274.0 7,314.0 5,953.9 5,987.2 A-3, 2V-10 5/3/1985 4.0 IPERF 4/ 4 1/2" 7,274.0 7,314.0 5,953.9 5,987.2 A-3, 2V-10 10/12/1991 12.0 RPERF Deep Hole Gun 7,318.0 7,322.0 5,990.5 5,993.8 A-3, 2V-10 5/3/1985 4.0 IPERF 4/ 4 1/2" 7,318.0 7,322.0 5,990.5 5,993.8 A-3, 2V-10 10/12/1991 12.0 RPERF Deep Hole Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,090.0 7,103.0 5,799.7 5,810.6 CMT SQZ 2V-10, 12/6/2023 8:08:10 AM Vertical schematic (actual) PRODUCTION; 34.6-7,547.9 FISH; 7,434.0 RPERF; 7,318.0-7,322.0 IPERF; 7,318.0-7,322.0 IPERF; 7,274.0-7,314.0 RPERF; 7,274.0-7,314.0 IPERF; 7,247.0-7,262.0 RPERF; 7,247.0-7,262.0 IPERF; 7,233.0-7,239.0 RPERF; 7,233.0-7,239.0 PACKER; 7,162.1 ISO SLEEVE; 7,146.3 IPERF; 7,124.0-7,130.0 RPERF; 7,124.0-7,130.0 RPERF; 7,110.0-7,118.0 IPERF; 7,110.0-7,118.0 IPERF; 7,090.0-7,103.0 CMT SQZ; 7,090.0 ftKB RPERF; 7,079.0-7,090.0 IPERF; 7,079.0-7,090.0 RPERF; 7,060.0-7,079.0 IPERF; 7,060.0-7,079.0 LEAK - C-SAND; 7,050.0 PRODUCTION; 7,036.8 PACKER; 6,995.2 GAS LIFT; 6,931.2 PACKER - PATCH - LWR; 6,718.1 LEAK - TUBING; 6,711.0 PATCH; 6,701.9 PACKER - PATCH - MID; 6,699.0 PATCH; 6,671.0 PACKER - PATCH - UPR; 6,669.0 GAS LIFT; 6,543.3 GAS LIFT; 6,180.9 GAS LIFT; 5,784.2 GAS LIFT; 5,387.6 GAS LIFT; 4,990.6 GAS LIFT; 4,584.1 GAS LIFT; 4,184.5 GAS LIFT; 3,745.7 SURFACE; 34.6-3,343.0 GAS LIFT; 2,835.6 SAFETY VLV; 1,836.7 CONDUCTOR; 34.6-101.0 KUP PROD 2V-10 ... WELLNAME WELLBORE2V-10 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Cc:Regg, James B (OGC) Subject:FW: KRU 2V-10 (PTD 185-048) Exceeding IA DNE Date:Wednesday, September 4, 2024 1:42:10 PM Attachments:AnnComm Surveillance TIO for 2V-10.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, September 4, 2024 1:34 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2V-10 (PTD 185-048) Exceeding IA DNE Hi Chris, KRU 2V-10 (PTD 185-048) is a gas lifted producer which is shut in for known TxIA. The IA pressure exceeded the DNE of 2000 psi on August 28, 2024 with a pressure of 2010 psi before Operations were able to bleed the well. The well has a patch and patch extension set above the production packer and attempts to recover the patch to secure the well were unsuccessful. The well is scheduled for a rig workover in 2025. Following the pressure excursion, the IA and Tubing were then bled from 1980 psi to 165 psi in preparation for a kill weight fluid loading. The kill weight fluid loading of the IA and tubing was executed on August 31st, 2024. The kill weight fluid loading will be re- executed as needed to manage the high IA pressure ahead of the rig workover. The production casing is 7” 26# J-55 casing burst rating is 4980 psi (45% of burst is 2241 psi). Please let me know if you have any questions or disagree with the plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2V-10 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2V-10 2024-08-03 2100.0 2100 0.0 IA 2V-10 2024-08-28 2010.0 1900 -110.0 IA 2V-10 2024-08-30 1980.0 8 -1972.0 IA 2V-10 2024-08-30 710.0 1 -709.0 OA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,351.0 2V-10 9/29/2019 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled catcher, slip stop & D&D packoff plug. 2V-10 12/5/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTIPLE ATTEMPTS TO PULL STA #5 ON 9/4/20 & 10/19 & 20 OF 2012, UNABLE TO LOCATE 9/5/2020 condijw 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 34.6 101.0 101.0 65.00 H-40 WELDED SURFACE 9 5/8 8.92 34.6 3,343.0 2,908.0 36.00 J-55 BTC PRODUCTION 7 6.28 34.6 7,547.9 6,181.5 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 33.0 Set Depth … 7,185.0 Set Depth … 5,879.6 String Max No… 4 Tubing Description TUBING 4"x3.5" @ 4984' Wt (lb/ft) 11.00 Grade J-55 Top Connection DSS-HTC ID (in) 3.48 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) 33.0 33.0 0.37 HANGER 10.800 FMC GEN IV TUBING HANGER 4.000 1,836.7 1,710.5 38.53 SAFETY VLV 6.000 OTIS FMX SERIES 10 SAFETY VALVE 3.313 2,835.6 2,506.3 37.45 GAS LIFT 5.898 CAMCO KBUG 3.351 3,745.7 3,216.1 42.21 GAS LIFT 5.898 CAMCO KBUG 3.351 4,184.5 3,539.5 42.77 GAS LIFT 5.898 CAMCO KBUG 3.351 4,584.1 3,832.2 43.16 GAS LIFT 5.898 CAMCO KBUG 3.351 4,983.7 4,126.3 41.93 XO Reducing 4.000 CROSSOVER 4 x 3.5, ID 2.992, #9.3, J-55 & L-80, EUE8rdABMOD 3.500 4,990.6 4,131.4 41.91 GAS LIFT 5.968 CAMCO MMG 2.920 5,387.6 4,430.0 40.31 GAS LIFT 5.968 CAMCO MMG 2.920 5,784.2 4,736.1 38.36 GAS LIFT 5.968 CAMCO MMG 2.920 6,180.9 5,051.0 37.24 GAS LIFT 5.968 CAMCO MMG 2.920 6,543.3 5,342.4 35.28 GAS LIFT 5.968 CAMCO MMG 2.920 6,931.2 5,665.4 32.15 GAS LIFT 5.968 CAMCO MMG 2.920 6,981.5 5,708.1 32.17 PBR 5.125 BAKER 10' STROKE PBR 3.000 6,995.2 5,719.7 32.18 PACKER 6.062 BAKER HB RETRIEVABLE PACKER 2.890 7,036.8 5,754.8 32.36 PRODUCTION 5.968 CAMCO MMG-W 2.920 7,050.9 5,766.7 32.43 BLAST RINGS 4.500 CARBIDE BLAST RING (1) 2.867 7,081.2 5,792.3 32.59 BLAST RINGS 4.500 CARBIDE BLAST RINGS (2) 2.867 7,146.3 5,847.1 32.87 SLEEVE-C 4.312 CAMCO CB-1 SLIDING SLEEVE; CLOSED 5/2/2006 2.812 7,161.1 5,859.5 32.92 SEAL ASSY 4.500 BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 7,162.1 5,860.3 32.93 PACKER 5.875 BAKER FB-1 PERMANENT PACKER 4.000 7,165.5 5,863.1 32.94 SBE 5.000 BAKER SEAL BORE EXTENSION 4.000 7,176.5 5,872.4 32.99 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750 7,184.1 5,878.8 33.02 SOS 3.500 BAKER SHEAR OUT SUB 2.992 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) 6,669.0 5,445.7 34.25 PACKER - PATCH - UPR WEATHERFORD ER PACKER (OAL 30.84') 10/18/2012 1.810 6,671.0 5,447.4 34.24 PATCH SPACER PIPE, SNAP LATCH SEAL ASSEMBLY 10/18/2012 1.750 6,699.0 5,470.5 34.06 PACKER - PATCH - MID WEATHERFORD ER PACKER (OAL 23.01') 10/11/2012 1.810 6,701.9 5,472.9 34.03 PATCH SPACER PIPE, SNAP LATCH SEAL ASSEMBLY 10/11/2012 1.750 6,711.0 5,480.5 33.93 LEAK - TUBING LEAK FOUND IN A COLLAR AT 6711 8/28/2012 6,718.1 5,486.4 33.85 PACKER - PATCH - LWR WEATHERFORD ER PACKER 10/9/2012 1.750 7,050.0 5,766.0 32.43 LEAK - C- SAND C-SAND TUBING LEAK, CONFIRMED 4/7/97, 2/17/2005, 7/3/2010 4/7/1997 7,146.3 5,847.0 32.87 ISO SLEEVE CB-1 ISO FRAC SLEEVE, 49" OAL, 5/4/2006 2.310 7,434.0 6,086.9 33.83 FISH 1 1/2" CV Lost One CV 4/22/1996 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) 2,835.6 2,506.3 37.45 1 GAS LIFT GLV BK 1 1,253.0 10/13/2019 0.156 3,745.7 3,216.1 42.21 2 GAS LIFT GLV BK 1 1,292.0 10/12/2019 0.188 4,184.5 3,539.5 42.77 3 GAS LIFT OV BK 1 0.0 10/13/2019 0.250 4,584.1 3,832.2 43.16 4 GAS LIFT DMY BK 1 0.0 4/13/1996 0.000 2V-10, 12/6/2023 8:08:05 AM Vertical schematic (actual) PRODUCTION; 34.6-7,547.9 FISH; 7,434.0 RPERF; 7,318.0-7,322.0 IPERF; 7,318.0-7,322.0 IPERF; 7,274.0-7,314.0 RPERF; 7,274.0-7,314.0 IPERF; 7,247.0-7,262.0 RPERF; 7,247.0-7,262.0 IPERF; 7,233.0-7,239.0 RPERF; 7,233.0-7,239.0 PACKER; 7,162.1 ISO SLEEVE; 7,146.3 IPERF; 7,124.0-7,130.0 RPERF; 7,124.0-7,130.0 RPERF; 7,110.0-7,118.0 IPERF; 7,110.0-7,118.0 IPERF; 7,090.0-7,103.0 CMT SQZ; 7,090.0 ftKB RPERF; 7,079.0-7,090.0 IPERF; 7,079.0-7,090.0 RPERF; 7,060.0-7,079.0 IPERF; 7,060.0-7,079.0 LEAK - C-SAND; 7,050.0 PRODUCTION; 7,036.8 PACKER; 6,995.2 GAS LIFT; 6,931.2 PACKER - PATCH - LWR; 6,718.1 LEAK - TUBING; 6,711.0 PATCH; 6,701.9 PACKER - PATCH - MID; 6,699.0 PATCH; 6,671.0 PACKER - PATCH - UPR; 6,669.0 GAS LIFT; 6,543.3 GAS LIFT; 6,180.9 GAS LIFT; 5,784.2 GAS LIFT; 5,387.6 GAS LIFT; 4,990.6 GAS LIFT; 4,584.1 GAS LIFT; 4,184.5 GAS LIFT; 3,745.7 SURFACE; 34.6-3,343.0 GAS LIFT; 2,835.6 SAFETY VLV; 1,836.7 CONDUCTOR; 34.6-101.0 KUP PROD KB-Grd (ft) 34.98 RR Date 4/5/1985 Other Elev… 2V-10 ... TD Act Btm (ftKB) 7,575.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292131000 Wellbore Status PROD Max Angle & MD Incl (°) 43.20 MD (ftKB) 4,600.00 WELLNAME WELLBORE2V-10 Annotation Last WO: End Date 10/15/1991 H2S (ppm) 100 Date 12/13/2019 Comment SSSV: TRDP 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) 4,990.6 4,131.4 41.91 5 GAS LIFT DMY RK 1 1/2 0.0 3/29/2007 SEE NOTE 0.000 5,387.6 4,430.0 40.31 6 GAS LIFT DMY RK 1 1/2 0.0 6/7/1995 0.000 5,784.2 4,736.1 38.36 7 GAS LIFT DMY RK 1 1/2 0.0 3/29/2007 0.000 6,180.9 5,051.0 37.24 8 GAS LIFT DMY RK 1 1/2 0.0 3/29/2007 0.000 6,543.3 5,342.4 35.28 9 GAS LIFT DMY RK 1 1/2 0.0 4/12/1996 0.000 6,931.2 5,665.4 32.15 1 0 GAS LIFT DMY RK 1 1/2 0.0 4/12/1996 0.000 7,036.8 5,754.8 32.36 1 1 PROD CV RK 1 1/2 0.0 5/31/2006 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,060.0 7,079.0 5,774.4 5,790.4 C-4, 2V-10 5/3/1985 13.0 IPERF 4 1/2" CG 7,060.0 7,079.0 5,774.4 5,790.4 C-4, 2V-10 10/12/1991 12.0 RPERF Deep Hole Gun 7,079.0 7,090.0 5,790.4 5,799.7 C-4, 2V-10 5/3/1985 1.0 IPERF 4 1/2" CG 7,079.0 7,090.0 5,790.4 5,799.7 C-4, 2V-10 10/12/1991 12.0 RPERF Deep Hole Gun 7,090.0 7,103.0 5,799.7 5,810.6 C-4, C-3, C-1, 2V-10 5/3/1985 1.0 IPERF CMT SQU 10/91; 4 1/2" CG 7,110.0 7,118.0 5,816.5 5,823.3 UNIT B, 2V-10 5/3/1985 1.0 IPERF 4 1/2" CG 7,110.0 7,118.0 5,816.5 5,823.3 UNIT B, 2V-10 10/12/1991 12.0 RPERF Deep Hole Gun 7,124.0 7,130.0 5,828.3 5,833.3 UNIT B, 2V-10 5/3/1985 1.0 IPERF 4 1/2" CG 7,124.0 7,130.0 5,828.3 5,833.3 UNIT B, 2V-10 10/12/1991 12.0 RPERF Deep Hole Gun 7,233.0 7,239.0 5,919.7 5,924.7 A-5, 2V-10 10/12/1991 12.0 RPERF Deep Hole Gun 7,233.0 7,239.0 5,919.7 5,924.7 A-5, 2V-10 5/3/1985 4.0 IPERF 4/ 4 1/2" 7,247.0 7,262.0 5,931.4 5,943.9 A-4, 2V-10 10/12/1991 12.0 RPERF Deep Hole Gun 7,247.0 7,262.0 5,931.4 5,943.9 A-4, 2V-10 5/3/1985 4.0 IPERF 4/ 4 1/2" 7,274.0 7,314.0 5,953.9 5,987.2 A-3, 2V-10 5/3/1985 4.0 IPERF 4/ 4 1/2" 7,274.0 7,314.0 5,953.9 5,987.2 A-3, 2V-10 10/12/1991 12.0 RPERF Deep Hole Gun 7,318.0 7,322.0 5,990.5 5,993.8 A-3, 2V-10 5/3/1985 4.0 IPERF 4/ 4 1/2" 7,318.0 7,322.0 5,990.5 5,993.8 A-3, 2V-10 10/12/1991 12.0 RPERF Deep Hole Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,090.0 7,103.0 5,799.7 5,810.6 CMT SQZ 2V-10, 12/6/2023 8:08:10 AM Vertical schematic (actual) PRODUCTION; 34.6-7,547.9 FISH; 7,434.0 RPERF; 7,318.0-7,322.0 IPERF; 7,318.0-7,322.0 IPERF; 7,274.0-7,314.0 RPERF; 7,274.0-7,314.0 IPERF; 7,247.0-7,262.0 RPERF; 7,247.0-7,262.0 IPERF; 7,233.0-7,239.0 RPERF; 7,233.0-7,239.0 PACKER; 7,162.1 ISO SLEEVE; 7,146.3 IPERF; 7,124.0-7,130.0 RPERF; 7,124.0-7,130.0 RPERF; 7,110.0-7,118.0 IPERF; 7,110.0-7,118.0 IPERF; 7,090.0-7,103.0 CMT SQZ; 7,090.0 ftKB RPERF; 7,079.0-7,090.0 IPERF; 7,079.0-7,090.0 RPERF; 7,060.0-7,079.0 IPERF; 7,060.0-7,079.0 LEAK - C-SAND; 7,050.0 PRODUCTION; 7,036.8 PACKER; 6,995.2 GAS LIFT; 6,931.2 PACKER - PATCH - LWR; 6,718.1 LEAK - TUBING; 6,711.0 PATCH; 6,701.9 PACKER - PATCH - MID; 6,699.0 PATCH; 6,671.0 PACKER - PATCH - UPR; 6,669.0 GAS LIFT; 6,543.3 GAS LIFT; 6,180.9 GAS LIFT; 5,784.2 GAS LIFT; 5,387.6 GAS LIFT; 4,990.6 GAS LIFT; 4,584.1 GAS LIFT; 4,184.5 GAS LIFT; 3,745.7 SURFACE; 34.6-3,343.0 GAS LIFT; 2,835.6 SAFETY VLV; 1,836.7 CONDUCTOR; 34.6-101.0 KUP PROD 2V-10 ... WELLNAME WELLBORE2V-10 Im~ ~roject Well History File' Cz e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 1 5'- o w.,, DIGITAL DATA RESCAN [] Color items: u Grayscale items: [] [] Poor Quality Originals: ~ · /~ [] Oth er: ~. I ' -.,. NOTES: " [] Diskettes, No. Other. No/Type OVERSIZED (Scannable) D Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scann able) Logs of various kinds BY: BEVERLY BREN Vl~ SHERYL MARIA LOWELl. [] Other Project Proofing ,. IIIIIIIIIIIIIIIIIII ScaNning Preparation -'~ x 30 = ~) + '~' = TOTAL PAGES BY: BEVERLYi/~VINCENT SHERYL MARIA LOWELL Production Scanning ' ~ ",, - ~, Stage I PAGE COUNT FROM SCANNED FILE: PAGE COUNT BATCHES NUMBER IN SCANNING PREPARATION: BY: X YES IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES Stage 2 BEVERLY BREN VINCE~ARIA LOWELL NO NO sY: (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAyscA!.E OR COLOR INIAGES) ReScanned (individual page [special attention] scanning completed) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General'Notes or Comments aboUt this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd STATE OF ALASKA AIWA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS -I-b 1. Operations Performed: Abandon r Repair w ell r Plug FZ'rforations r Perf orate f Other Install Latch Alter Casing r Pull Tubing r Stimulate - Frac Waiver Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development (° Exploratory r -185 -048 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21310 - 00 " GO 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25644 - - 2V -10 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): .. none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7575 feet Plugs (measured) None true vertical 6204 feet Junk (measured) 7434 Effective Depth measured 7455 feet Packer (measured) 6669, 6699, 6718, 6995, 7162 true vertical 6103 feet (true vertical) 5446, 5471, 5486, 5720, 5860 Casing Length Size MD TVD Burst Collapse CONDUCTOR 66 16 101 101 SURFACE 3308 9.625 3343 2908 RECEIVED PRODUCTION 7513 7 7548 6182 NOV 19 2012 AOGCC Perforation depth: Measured depth: 7060 -7103, 7110 -7118, 7124 - 7130, 7233 - 7239, 7247 - 7262, 7274 - 7314, 7318 - 7322 True Vertical Depth: 5774 - 5811, 5817 -5823, 5828 -5833, 5920 -5925, 5932 -5944, 5954 -5987, 5991 -5994 Tubing (size, grade, MD, and TVD) 3.5, J -55, 7184 MD, 5879 TVD Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD ER PACKER @ 6669 MD and 5446 TVD PACKER - WEATHERFORD ER PACKER @ 6699 MD and 5471 TVD PACKER - WEATHERFORD ER PACKER @ 6718 MD and 5486 TVD PACKER - BAKER HB RETRIEVABLE PACKER @ 6995 MD and 5720 TVD PACKER - BAKER FB -1 PERMANENT PACKER @ 7162 MD and 5860 TVD SSSV - OTIS FMX SSSV @ 1837 MD and 1711 TVD 12. Stimulation or cement squeeze summary: SCANNED MAR 11 2013 Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 475 2565 5554 - - - 216 Subsequent to operation 772 1066 4199 -- 190 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development Service r Stratigraphic r 16. Well Status after work: r Oil 17 Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ f`" WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce @ 265 -6471 Email John .W.Peirce @conocoDhillips.com Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date JJ �/ Cam.i2 t 1 J Form 10104 Revise 1 /2012 11 A NOV 4 1 2 j2 34 l L ->y /L- Submit Original Only 00/ „. �, KUP 2V -10 4 COnoCOPhithpS ,� °t� Well Attributes Max Angle & MD TD Alaska. k1C Wellbore API /DWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) Lnxxcltvlbpz 500292131000 KUPARUK RIVER UNIT PROD 4120 4,600.00 7,575.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: TRDP 80 12/6/2011 Last WO: 10/15/1991 34.98 4/5/1985 Well Conk' - 2V -10, 11/8/2012 2 43 57 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,246.0 10/5/2012 Rev Reason: PULL TEST TOOL, GLV C/O ninam 11/8/2012 HANGER.33 Casin Strin s ' Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String... String Top Thrd - - - CONDUCTOR 16 15.062 34.6 101.0 101.0 65.00 H - 40 WELDED ® Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 34.6 3,343.0 2,907.7 36.00 J - 55 BTC i Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR, PRODUCTION 7 6.276 34.6 7,547.9 6,181.5 26.00 J - 55 BTC 35-101 Tubing Strings SAFETY VIN, Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1,637 TUBING 4"x3.5" 4 3.476 33.0 7,185.0 5,879.6 11.00 J-55 DSS -HTC @ 4984' GAS LIFT, Completion Details 2,836 Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) (1 Item Description Comment ID (!n) 33.0 33.0 1.13 HANGER FMC GEN IV TUBING HANGER 4.000 SURFACE, ,I L 353,343 1,836.7 1,710.6 38.62 SAFETY VLV OTIS FMX SERIES 10 SAFETY VALVE 3.313 GAS LIFT. 3,748 4,983.7 4,126.3 41.93 X0 Reducing CROSSOVER 4 x 3.5, ID 2.992, #9.3, J - 55 & L EUE8rdABMOD 3.500 GAS LIFT, 6,981.5 5,708.1 32.17 PBR BAKER 10' STROKE PBR 3.000 4,185 6,995.2 5,719.7 32.18 PACKER BAKER HB RETRIEVABLE PACKER 2.890 GAS LIFT, 4,584 7,050.9 5,766.7 32.48 BLAST RINGS CARBIDE BLAST RING (1) 2.867 7,081.2 5,792.3 32.60 BLAST RINGS CARBIDE BLAST RINGS (2) 2.867 7,146.3 5,847.0 32.87 SLEEVE -C CAMCO CB-1 SLIDING SLEEVE; CLOSED 5/2/2006 2.812 GAS 14_197,, 4 991 , __ 7,161.1 5,859.5 32.92 SEAL ASSY BAKER GBH -22 LOCATOR SEAL ASSEMBLY 3.000 I= 7,162.1 5,860.3 32.93 PACKER BAKER FB-1 PERMANENT PACKER 4.000 7,165.5 5,863.1 32.94 SBE BAKER SEAL BORE EXTENSION 4.000 GAS uF 7,176.5 5,872.4 32.99 NIPPLE CAMCO D NIPPLE NO GO 2.750 5,388 8 i 7,184.1 5,878.8 33.02 SOS BAKER SHEAR OUT SUB 2.992 MO Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) GAS LIFT, Top Depth 5.784 (TVD) Top Inc! - Top (ftKB) (RKB) (°) Description Comment Run Date ID (in) _ 6,669 5,445.8 34.38 PACKER WEATHERFORD ER PACKER 10/18/2012 1.810 GAS LIFT, 6,181 6,671 5,447.4 34.36 PATCH SPACER PIPE, SNAP LATCH SEAL ASSEMBLY 10/18/2012 1.750 !♦ 6,699 5,470.5 34.06 PACKER WEATHERFORD ER PACKER 10/11/2012 1.810 6,702 5,472.9 34.03 PATCH SPACER PIPE, SNAP LATCH SEAL ASSEMBLY 10/11/2012 1.750 GAS gI� 6,718 5,486.4 33.85 PACKER WEATHERFORD ER PACKER 10/9/2012 1.750 Mr - 7,146 5,847.0 32.87 ISO SLEEVE CB-1 ISO FRAC SLEEVE, 49" OAL, 5/4/2006 2.310 PACKER. 6,669 ! . 7,434 6,086.9 33.83 FISH 1 1/2" CV Lost One CV 4/22/1996 PATCH, 6.871 ■. PACKER, 6,699 Perforations & Slots PATCH, 6,702 IY Shot Igo PACKER. 6,718 ' _ _ Top (TVD) Btm (TVD) Dens • To ftKB Btm ftKB (ftKB) RKB Zone Dale leh- T Comment p( 1 (ftKB) ) 1 1 rPe - 7,060 7,079 5,774.4 5,790.4 C- 4,2V -10 5/3/1985 13.0 IPERF 412 "CG G LIFT, 7,060 7,079 5,774.4 5,790.4 C -4, 2V -10 10/12/1991 12.0 RPERF Deep Hole Gun UM 7,079 7,090 5,790.4 5,799.7 C-4, 2V -10 5/3/1985 1.0 IPERF 4 1/7' CG PBR, fi,962 7,079 7,090 5,790.4 5,799.7 C-4, 2V -10 10/12/1991 12.0 RPERF Deep Hole Gun PACKER, 6,995 -\ i I 7,090 7,103 5,799.7 5,810.6 C-4, C-3, C-1, 5/3/1985 1.0 IPERF CMT SOU 10/91; 4 1/7' CG PRODUCTION, 2V-10 7,037 ^ IPERF, 7,0607.079 7,110 7,118 5,816.5 5,823.2 UNIT B, 2V -10 5/3/1985 1.0 IPERF 41 /2'CG RPERF, 7,060 -7.079 7,110 7,118 5,816.5 5,823.2 UNIT B, 2V -10 10/12/1991 12.0 RPERF Deep Hde Gun IPERF, 7,079-7,090 ( 1 7,124 7,130 5,828.3 5,833.3 UNIT B, 2V -10 5/3/1985 1.0 IPERF 4 1/2' CG RPERF, 7,079-7,090 ''': -, 1 7,124 7,130 5,828.3 5,833.3 UNIT B, 2V -10 10/12/1991 12.0 RPERF Deep Hde Gun PER,, 7. 090 -7,1oJ 7,233 7,239 5,919.8 5,924.8 A -5, 21-10 5/3/1985 4.0 IPERF 4/4 1/2" cM 090 7 7,233 7,239 5,919.8 5,924.8 A -5, 2V -10 10/12/1991 12.0 RPERF Deep Hole Gun IPERF, 7,110 - 7,118 7,247 7,262 5,931.5 5,944.0 A -4, 21-10 5/3/1985 4.0 IPERF 4/ 4 1/2" RPERF, 7.110-7,116 7,247 7,262 5,931.5 5,944.0 A-4, 2V -10 10/12/1991 12.0 RPERF Deep Hole Gun RPERF, 7.124- 7,130 7,274 7,314 5,953.9 5,9872 A -3, 22-10 5/3/1985 4.0 IPERF 4/4 1/2" PERF, 7,17.4 -7.130 7,274 7,314 5,953.9 5,987.2 A -3, 2V -10 10/12/1991 12.0 RPERF Deep Hole Gun I50 SLEEVE, 7.146 % 7,318 7,322 5,990.5 5,993.8 A -3, 2V -10 5/3/1985 4.0 IPERF 4/412" SLEEVE -C, 7,146 7,318 7,322 5,990.5 5,993.8 A - 3, 2V - 10 10/12/1991 12.0 RPERF Deep Hole Gun SEAL ASSY, Cement Squeezes 7,,161 161 PACKER. 7,162 Top Depth Btm Depth SSE, 7.185 (TVD) (TVD) 1 J Top (ftKB) Btm (ftKB) (*KB) (ftKB) Description Start Date Comment 7,090.0 7,103.0 5,799.7 5,810.6 CMTSQZ 10/1/1991 NIPPLE, 7,176 Ili SOS, 7.184 -� _ Mandrel Details RPERF. Top Depth Top Port 7,233 -7,239 (TVD) Inc! OD Valve Latch Size TRO Run 7,23 Stn Top (ftKB) (ftKB) (1 Make Model (!n) Sery Type Type (in) (psi) Run Date Com... RPERF, ® 1 2,835.6 2,506.4 37.60 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/5/2012 7,247 -7,262 IPERF, 2 3,745.7 3,216.0 42.21 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/6/2012 7,247 -7,282 IPERF, MI 3 4,184.6 3,539.5 42.77 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/6/2012 7,274 -7,314 RPERF, 4 4,584.2 3,832.2 43.16 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/13/1996 7,274 -7,314 all lin RPERF, 5 4,990.6 4,131.4 41.91 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 3/29/2007 7,318 -7,322 IPERF, 7,318 -7,322 ® 6 5,387.6 4,430.0 40.26 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6/7/1995 7 5,784.2 4,736.1 38.36 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 3/29/2007 FISH, 7,434 • 8 6,180.9 5,051.0 37.24 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 3/29/2007 9 6,543.3 5,342.5 35.28 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/12/1996 PRODUCTION. 10 6,931.2 5,665.4 32.15 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/12/1996 35 -7,548 TO 7,575 ,' ■ KUP • 2V -10 ConocoPhillips 01 Alaska, Inc conmAtitsps KB-Grd (ft) Rig Release Date ••• 34.98 4/5/1985 Well Con8e.-2V-10,/212 S &2,0e- ACl0 2 43 7 PM ual HANGER. 33 Notes: General & Safety End Date Annotation - 4/17/1997 NOTE: E/L Logged C -Sand production thru TBG leak @ 7050'. 2/17/2005 NOTE: E/L Logged significant C -Sand production thru TBG leak @ - 7052' 7/3/2010 NOTE: E/L Logged probable TBG leak © `7050' CONDUCTOR, 35101 12/9/2010 NOTE: View Schematic w/ Alaska Schematic9.0 8/28/2012 NOTE: E/L IDENTIFIED TUBING LEAK @ 6711' RKB SAFETY VLV, f � -.:I 1,837 ;1 llllllllll GAS LIFT, 2.838 SURFACE, J L 35 -3,343 GAS LIFT. 3,746 I a GASLIFT, 8 L■.., aaa:.. GAS LIFT, i 4,564 GAS LIFT, 4.991 GAS LIFT, 5,388 MEM GAS LIFT, 5.784 GAS LIFT. 6.781 GAS fi,543 PACKER, 8,669 PATCH, 6,671 i, PACKER, 6,699 PATCH. 6,702 ■i PACKER. 6,718 GAS LIFT,.. 6,931 1 r PBR, 6,982 -� PACKER, 6,995 PRODUCTION, 1 L 7,037 IPERF, 7,060 -7,079 RPERF, 7,060 -7,079 _ IPERF, 7,079 -7,090 RPERF, 7,079 -7,090 IPERF. 7,090 -7,103 li CMT SOZ, 7,090 IPERF, 7,110 -7,118 RPERF, 7,110 - 7,116 - -- RPERF, 7,124-7,130 IPERF, 7,124-7,130 ISO SLEEVE, 7,146 SLEEVE C, 7,146 .....•� SEAL ASSY. ._ PACKER, 7,181 7,162� SBE, 7,165 NIPPLE, 7,176 SOS, 7,184 Mandrel Details RPERF, ' Top Depth Top Port 7,233 -7,239 (TVD) Inc! OD Valve Latch Size TRO Run 7,233-7.239 Stn Top (ftKB) (ftKB) (I Make Model (In) Senv Type Type ( (poi) Run Date Con1... RPERF, 11 7,036.8 5,754.8 32.43 CAMCO MMG 1 1/2 PROD CV RK 0.000 0.0 5/31/2006 7,247-7,262 IPERF, IPERF, \ \V 7,247-7,262 PER IPERF, 7,274-7,314 RPERF, RPERF, 7,274-7,314 RPERF, RPERF, 7,318 -7,322 IPERF, 7,318 -7,322 FISH, 7.434 • PRODUCTION, 35-7,548 TD, 7,575 10/11/12 SET TEST TOOL IN LOWER ER PKR @ 6721' RKB. CMIT 2500 PSI, PASSED. SET 21' UPPER PATCH ASS'Y @ 6699' RKSTED IA 1625 PSI, GOOD. SET ER T•TOOL IN UPPER ER PKR @ 6699' RKB. IN PRO SS. 10/13/12 ATTEMPTED TEST IA. AT 2400 PSI, TBG / IA BEGAN COMMUNICATING. PRESSURED UP TBG, IA COMMUNICATING. PULLED ER TEST TOOL @ 6699' RKB. SET HOLEFINDER ON ER PKR @ 6699' RKB, IA COMMUNICATING. GOOD TBG TEST WITH HOLEFINDER @ 6650' RKB. IN PROGRESS. 10/14/12 WITH HOLEFINDER IDENTIFIED APPARENT LEAK ABOVE PATCH BETWEEN 6686' & 6679' RKB. SET ER TEST TOOL IN PATCH @ 6699' RKB. WITH PONY TAIL IDENTIFIED LEAK AT EST. 6680' RKB. CMIT 2400 PSI, PASSED. PULLED ER TEST TOOL @ 6699' RKB. READY FOR ADDITIONAL PATCH. 10/18/12 SET UPPER ER PACKER PATCH ASSEMBLY ( 32' OAL) @ 6669' RKB. (( LRS PASSING MITIA TO 2500 PSI )) JOB IN PROGRESS 10/19/12 SET ER TEST TOOL IN ER PACKER @ 6669' RKB; MAKE SEVERAL ATTEMPTS TO PULL DV @ 4991' RKB ( NO SUCCESS / WELL HAS HISTORY OF SCALE ). IN PROGRESS. 10/20/12 UNABLE TO PULL DV @ 4991' RKB ( APPEARS SCALED OVER ). ( CHANGE GLD) . PULLED DV'S @ 4186' AND 3745' RKB. JOB IN PROGRESS 10/21/12 PULLED DV @ 2835' RKB; SET OV @ 4186' RKB; SET GLV @ 3745' RKB; MAKE SEVERAL ATTEMPTS TO SET GLV @ 2835' RKB ( UNSUCCESSFUL) . IN PROGRESS 10/22/12 SET GLV @ 2835' RKB; GOOD TEST ON TUBING; PULLED ER TEST TOOL @ 6669' RKB. JOB COMPLETE 10/30/12 RE -TIFL FAILED W/205 PSI BUR, INFLOW OF 525' DURING 1 HR MONITOR. 11/5/12 SET 3 -1/2" TEST TOOL / CATCHER ASSEMBLY IN PATCH @ 6669' RKB. PULLED GLVs @ 4185', 3746' & 2836' RKB. SET DV @ 2836' RKB. ATTEMPTED SET DV @ 3746' RKB. IN PROGRESS. 11/6/12 SET DV @ 3745' RKB. LOADED TBG & IA WITH DSL. SET DV @ 4184' RKB. TESTED TBG 1550 PSI, GOOD. ATTEMPTED MIT IA, IA & TBG COMMUNICATING. IN PROGRESS. 11/7/12 MIT IA 2500 PSI, PASSED. PULLED 3 -1/2 ER TEST TOOL / CATCHER ASSEMBLY @ 6669' RKB. COMPLETE. IF 2V -10 Well Work Summary DATE .SUMMARY 7/29/12 (AC EVAL) : TIFL FAILED due to inflow of 2905' 7/31/12 DRIFTED TBG TO 2.77" DN TO PACKER @ 6995' RKB, ATTEMPT LEAK DETECT HOLE FINDER AND UNABLE TO LOCATE LEAK IN 3.5" TBG. , ATTEMPTED TO PULL OV @ 4184' RKB W/ NO SUCCESS ( KOT FULL OF SCALE ); ATTEMPT TO BRUSH AND FLUSH AND UNABLE TO GET PAST 65'. . IN PROGRESS 8/1/12 BROACH SCALE FROM 60' SLM TO 2000' SLM, BRUSH AND FLUSH TBG DN TO 4862' SLM, ATTEMPT TO PULL OV FROM STA # 3 @ 4184' RKB ( NO SUCCESS) . IN PROGRESS 8/2/12 PULLED OV ( CHECK SCALED OPEN ) @ 4184' RKB AND REPLACED IN KIND. BLED IA DOWN FOR A 300 PSI DP. COMPLETE 8/4/12 TIFL, FAILED DUE TO 50 PSI INCREASE DURING MONITOR AND 2925' OF INFLOW DURING BLEED. 8/7/12 PULLED GLV (HEAVY SCALE ON CHECK) @ 3746' RKB; REPLACED IN KIND. IN PROGRESS. 8/8/12 ATTEMPTED TEST TBG BELOW AND ABOVE PKR @ 6995' RKB, UNSUCCESSFUL. REPLACED GLV @ 2836' RKB. WITH HOLEFINDER @ 6560' SLM TESTED TBG 1975 PSI, NO COMMUNICATION TO IA. COMPLETE. 8/10/12 (AC EVAL) RE -TIFL- FAILED (INFLOWED 3282FT.) 8/18/12 ATTEMPT TO IDENTIFY LEAK IN 4" TBG W/ PONYTAIL. RESULTS INCONCLUSIVE. WITH HOLEFINDER SET @ 5330' SLM, PSI TEST TBG TO 2400 PSI. IN PROGRESS. 8/19/12 BRUSH AND FLUSH TBG f/ 6950' TO 7040' SLM. READY FOR WRP. 8/20/12 SET WEATHERFORD WRP (2.77" OD) AT 7026' RKB. DID NOT SET WRP IN THE PUP JOINT AT 7033' RKB, DUE TO ANOMALY SEEN ON CCL AND TENSION PULL IN THIS AREA. CORRELATE TO TUBING DETAIL DATED 15 -OCT 1991. 8/23/12 SET 2.75" AVA CATCHER @ 6989' SLM. PULLED OV FROM 4185' RKB. POCKET LEFT OPEN. PULLED GLV's FROM 3746' & 2836' RKB; REPLACED W/ DV's. LOAD TUBING & IA W/ 110 BBLS INHIBITED SEAWATER & 76 BBLS DIESEL. IN PROGRESS. 8/24/12 CMIT TO 2500 PSI FAILED (3 TESTS). SET DV @ 4186' RKB. ATTEMP TO PT TUBING, FAILED. CONFIRMED DV's @ 3746' & 2836' RKB IN POCKET. RAN D &D HOLEFINDER TO IDENTIFY LEAK BETWEEN 6700' AND 6538' SLM. ESTABLISHED LEAK RATE OF 1.5 BBLS /MIN © 1500 PSI WHILE PUMPING DOWN TUBING TAKING RETURNS UP IA TO FLOWLINE.. WELL IS READY FOR E -LINE. 8/28/12 LOGGED LEAK DETECT LOG IN CONJUNCTION WITH 24 ARM MIT CALIPER FROM 7010' TO SURFACE. WRP WAS FOUND TO BE HOLDING AT 2500 PSI. TXIA LEAK WAS FOUND IN A COLLAR AT A DEPTH OF 6711'. 9/12/12 RAN TECWEL ACOUSTIC NOISE TOOL.TO 6996' RKB, FOR LEAK DETECTION LOG. UNABLE TO DUPLICATE FAILING COMBO MIT. RIGGED LRS TO IA, PRESSURE UP TO 3000 PSI, UNABLE TO ESTABLISH SUSPECTED LEAK. LRS PERFOMED 30 MINUTE COMBO MIT (PASSED), 60 PSI LOSS OVER FIRST 15 MIN, 15 PSI LOSS OVER FINAL 15 MIN. 9/29/12 IA DDT - PASSED WITH 0 PSI BUR IN 1 HOUR. CMIT- PASSED TO 3000 PSI. 10/3/12 ATTEMPTED PULL CATCHER ON WRP @ 7026' RKB; ENCOUNTERED APPARENT FILL @ 6957' SLM. IN PROGRESS. 10/4/12 BAILED SCALE FROM 6959' TO 6978' SLM. PULLED CATCHER @ 7026' RKB, PULLED WRP @ SAME. IN PROGRESS. 10/5/12 TAGGED © 7246' SLM. MEASURED BHP @ 7278' RKB: 2451 PSI. BRUSHED & FLUSHED TBG f/ 6580' TO 6750' SLM WITH BLB AND 2.78" G /R. ATTEMPT DRIFT WITH 20' DUMMY PATCH, SAT DOWN © 5353' SLM. WORKED 2.79" BROACH, 6' STEM, 2.75" BROACH THRU TIGHT AREAS f/ 5353' TO 5373' AND 6514' SLM. IN PROGRESS. 10/6/12 RAN 2.84" BARBELL BROACH ASS'Y THRU TIGHT AREA f/ 5353' TO 5374' AND 6515' SLM. DRIFTED TBG WITH 20' DUMMY PATCH TO 6750' SLM; TBG TIGHT f/ 5353' TO 5374' SLM. READY FOR E -LINE. 10/9/12 SET LOWER ER PACKER WITH MID ELEMENT SET DEPTH OF 6721' CCL TO MID ELEMENT 9.9' CCL STOP DEPTH 6711.1'. TOOL SET DOWN AT 5352' WHILE RUNING IN THE HOLE PULLED 1500 LBS TENSION TO GET MOVING AGIAN. SECOND PASS TOOLS WENT RIGHT THROUGH. DID NOT PULL ANY TENSION IN THE SAME SPOT ON THE WAY OUT OF THE HOLE. STATE OF ALASKA ALlikA OIL AND GAS CONSERVATION COMMON . ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other r;. Set tubing patch Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r lime Extension r Change Approved Program r Operat. Shutdown r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r .. - 185 -048 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 - 50 - 029 - 21310 - 00' ®0 7. Property Designation (Lease Number): 8. Well Name and Number:. ADL 25644 - 2V -10 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7575 feet Plugs (measured) None true vertical 6204 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 6669, 6671, 6699, 6702, 6718, 6995 true vertical 0 feet (true vertical) 5446, 5447, 5471, 5473, 5486, 5720 Casing Length Size MD TVD Burst Collapse CONDUCTOR 66 16 101 101 SURFACE 3308 12 3343 2908 RECEIVED PRODUCTION 7513 7 7548 6182 4... =.�. NOV 13 2012 AOGCC Perforation depth: Measured depth: 7060 -7103, 7110 -7118, 7124 - 7130, 7233 - 7239,7247- 7262,7274- 7314,7318 -7322 True Vertical Depth: 5774 - 5800, 5817 - 5823, 5828 - 5833, 5918 - 5923,5930- 5942,5952- 5986,5989 -5992 Tubing (size, grade, MD, and TVD) 4" x 3.5 ", J -55, 4984' / 7185' MD, 4126' / 5879' TVD Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD ER PACKER © 6669 MD and 5446 TVD PATCH - SPACER PIPE, SNAP LATCH SEAL ASSEMBLY @ 6671 MD and 5447 TVD PACKER - WEATHERFORD ER PACKER @ 6699 MD and 5471 TVD PATCH - SPACER PIPE, SNAP LATCH SEAL ASSEMBLY @ 6702 MD and 5473 TVD PACKER - WEATHERFORD ER PACKER @ 6718 MD and 5486 TVD PACKER - BAKER HB RETRIEVABLE PACKER © 6995 MD and 5720 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation n/a n/a n/a n/a n/a Subsequent to operation n/a n/a n/a n/a n/a 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r✓ - Service r Stratigraphic r 16. Well Status after work: . Oil 1 Gas r WDSPL r Daily Report of Well Operations x GSTOR WA GINJ r WIND r r r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: • N/A Contact Kelly Lyons / Brent Rogers Email n1617 a( conocophillips.com Printed Name Kcliv Lyons Title Problem Wells Supervisor Signature _7 v / Phone: 659-7224 Date 11 -10 -12 NA : ,Viz--: NOV! 14 20 t'i� Form 10 -404 Revised 10/2012 j Submit Original Only • • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 November 10, 2012 Mr. Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 2V-10 (PTD 185 -048) for a retrievable patch set in the tubing above the packer. Please call Brent Rogers or myself @ 659 -7224 if you have any questions. Sincere Ad Kelly Lyons / ConocoPhil ips Problem Wells Supervisor Enclosures • 2V -10 • • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/09/12 SET LOWER ER PACKER WITH MID ELEMENT SET DEPTH OF 6721' CCL TO MID ELEMENT 9.9' CCL STOP DEPTH 6711.1'. TOOL SET DOWN AT 5352' WHILE RUNING IN THE HOLE PULLED 1500 LBS TENSION TO GET MOVING AGIAN. SECOND PASS TOOLS WENT RIGHT THROUGH. DID NOT PULL ANY TENSION IN THE SAME SPOT ON THE WAY OUT OF THE HOLE. 10/11/12 SET TEST TOOL IN LOWER ER PKR @ 6721' RKB. CMIT 2500 PSI, PASSED. .$ET 21' UPPER PATCH ASS'Y @ 6699' RKB. TESTED IA 1625 PSI, GOOD. SET ER TEST TOOL IN UPPER ER PKR @ 6699' RKB. IN PROGRESS. 10/13/12 ATTEMPTED TEST IA. AT 2400 PSI, TBG / IA BEGAN COMMUNICATING. PRESSURED UP TBG, IA COMMUNICATING. PULLED ER TEST TOOL @ 6699' RKB. SET HOLEFINDER ON ER PKR @ 6699' RKB, IA COMMUNICATING. GOOD TBG TEST WITH HOLEFINDER @ 6650' RKB. IN PROGRESS. 10/14/12 WITH HOLEFINDER IDENTIFIED APPARENT LEAK ABOVE PATCH BETWEEN 6686' & 6679' RKB. SET ER TEST TOOL IN PATCH © 6699' RKB. WITH PONY TAIL IDENTIFIED LEAK AT EST. 6680' RKB. CMIT 2400 PSI, PASSED. PULLED ER TEST TOOL @ 6699' RKB. READY FOR ADDITIONAL PATCH. 10/18/12 SET UPPER ER PACKER PATCH ASSEMBLY ( 32' OAL) © 6669' RKB. LRS performed MITIA. Initial T /I /0= 2000/700/250. Start MITIA T /I /0= 2050/2500/260, 15 min T /I /0= 2050/2200/280. Bump IA back up, restart MITIA T /I /0= 2050/2500/280, 15 min T /I /0= 2050/2500/280, 30 min T /I /0= 2050/2500/280. Summary Set 21' ER Weatherford retrievable tubin• •atch with an additional 32' •atch extension. Confirmed tubing integrity with MITIA. • 2 \ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 10, 2012 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2V -10 Run Date: 10/9/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2V -10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21310 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: `o Zvi e2 Signed: ,7, 6 • • �,�;�� WELL LOG TRANSMITTAL PROAcrivE DiA osTiC SERVICES, INC. To: AOGCC Christine Shartzer 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2 - 1 900 Benson Blvd. Anchorage, AK 99508 : ,, Nig` -, t I(I L ?'Cry? and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Point Survey 10- Sep-12 2Z -20 1 CD 50 -029- 21876 -00 2) Leak PointTm Survey 12- Sep-12 2V -10 1 CD 50 -029- 21310 -00 Signed : ige if Date : `2'i (V2- Print Name: J\ Lj Jb- PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -8952 E -MAIL : PDSANCHORAGEPMEMORYLOG.COM WEBSITE :WWW.MEMORYLOG.COM D \ Archives\ Distribution \TransmittalSheets\BP Transmit docx l WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 30, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) /Leak Detect Log: 2V -10 Run Date: 8/28/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2V -10 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 21310 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: i � 2� Signed: fildapie.e\ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 21, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 2V -10 Run Date: 8/20/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2V -10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21310 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907-273-3535 klinton.wood @halliburton.com Date: Si ed: /, / // ° /, • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT): 2V-10 Run Date: 7/7/2010 July 23, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2V-10 Digital Data in LAS format, Digital Log Image file, Casing Inspection repc 1 CD Rom 50-029-Z 1310-00 `~ iitt~t ~ J r ~.. ~-~ T: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 / ~S~ ~`~~ /~31 Fax: 907- - ~ ~ rafael.b ~ tt~c ,t;i. ,~f ~J ~_ ~ _ Date: =~ ,~ Signed: Cc~nc~coPhllips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 17, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission ,y ~ ~ ~;"~, 333 West 7~' Avenue, Suite 100 ~ °~ `~~!~~- ~~ ~ "" Anchorage, AK 99501 ~~~~~~~ Dear Mr. Dan Seamount: ~~~~~~ ..APR 2 7 2010 .raska Oil ~ ~~ Cans. Commission ~nchca~aQe ~ ~s a~-~ a~- io Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRin. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 16, March 21, 2010. The corrosion inhibitor/sealant was pumped April 15, 16 and 17, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. " Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Projects Supervisor .. Ir ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 4/17/2010 26, 2E 2G 2H 2K 2M 2V 2W 2X 2Z ~ 3S PAD's Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 26-05 50029210870 1840040 24" n/a 24" n/a 4.2 4/16!2010 2B-08 50029210790000 1840260 21" 3.30 7" 1/16/2010 2.5 4/16/2010 26-16 50029211460000 1841140 92" 0.65 3/21/2010 2.5 4/16/2010 2E-10 50029212460000 1842300 SF Na n/a n/a 5.9 4/16/2010 2E-17 50029224190000 1931740 8'9" 1.50 19" 1/16/2010 3.4 4/16/2010 2G-13 50029211800000 1841290 SF n/a 22" n!a 3.4 4/16/2010 2H-07 50103200450000 1851700 SF n/a 17" Na 2.1 4/15/2010 2H-09 50103200500000 1852590 SF Na 17" n/a 2.5 4/15/2010 2H-15 50103200340000 1840860 SF n/a 17" n/a 2.5 4/15/2010 2H-16 50103200350000 1840870 SF n/a 17" Na 2.5 4/15/2010 2K-19 50103201180000 1891090 53" 0.50 9" 1/16/2010 2.1 4/15/2010 2M-07 50103201780000 1920800 SF n/a 17" n/a 3.4 4/15/2010 2M-08 50103201840000 1921010 SF Na 17" Na 2.1 4/15/2010 2M-20 50103201690000 1920480 SF Na 17" Na 2.5 4/15/2010 2M-22 50103201700000 1920490 SF n/a 17" n/a 2.5 4/15/2010 2M-28 50103201740000 1920700 SF Na 18" Na 2.1 4/15/2010 2V-06 50029210540000 1831790 SF Na 19" Na 7.6 4/16/2010 2V 10 50029213100000 1850480 SF Ne 19" Na 2.5 4/16/2010 2V-16 50029212960000 1850330 SF Na 21" Na 5.1 4/16/2010 2W-03 50029212740000 1850110 SF n/a 3T' Na 4.2 4/16/2010 2X-11 50029211880000 1841640 SF Na 17" Na 6 4/17/2010 2Z-11 50029213790000 1851380 SF n/a 19" n/a 2.5 4/15/2010 2Z-12A 50029213800100 1951480 SF n/a 19" Na 2.5 4/15/2010 2Z-13A 50029213600100 2061700 SF n/a 22" n/a 4.25 4/15/2010 2Z-19 50029218820000 1881300 SF n/a 16" Na 2.1 4/15/2010 3S-09 50103204320000 2022050 SF n/a 45" Na 23 4/17/2010 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 2, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 2V -10 Run Date: 8/17/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2V -10 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 21310 -00 Production Profile Log 1 Color Log 50- 029 21310 -00 idt;'Wy i 2. 20` S PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating 04 Attn: Rafael Barreto 6900 Arctic Blvd. t '`b t Anchorage, Alaska 99518 Office: 907 273 -3527 Fax: 907 273 -3535 rafael.barreto@halliburton.com Date: NOV 0 5 7009 Signed: A a~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description / / ~( i ~ /. ; A f / .' - NO. 5005 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 12/17/08 2X-10 11978476 PRODUCTION PROFILE / - / 08/17/08 1 1 2V-09 12100460 PRODUCTION PROFILE (p 11/16/08 1 1 1Y-06A 12100461 PRODUCTION PROFILE 11/17/08 1 1 2X-12A 12100464 PRODUCTION PROFILE (9 '~- 11/21/08 1 1 2U-08 12096574 PRODUCTION PROFILE - 11/28/08 1 1 3K-108 12100466 USIT 11/23/08 1 1 3K-30 12097433 LDL _ / 11/28!08 1 1 30-01 12097434 LDL -Q '~- 11/29/08 1 1 1 E-04 12097436 LDL T 11/30/08 1 1 3A-04 12097432 INJECTION PROFILE L - 11/27/08 1 1 i H-16 12096581 PRODUCTION PROFILE ~ 12/05/08 1 1 3A-06 12114994 BAKER LOWER STRADDLE PACKER 11/26/08 1 1 2U-14 12096578 INJECTION PROFILE L -~ j 12/02/08 1 1 1G-06 12096580 INJECTION PROFILE 12/04/08 1 1 2V-10 12096582 PRODUCTION PROFILE 12/06/08 1 1 3F-01 12086694 PRODUCTION PROFILE - 12/07/08 1 1 2W-14 12086695 INJECTION PROFILE ~ 12/08/08 1 1 1J-102 12086701 INJECTION PROFILE 12/14/08 1 1 1 D-07 12114999 USIT _ ~ 12/15/08 1 1 3C-02 12114997 INJECTION PROFILE ~ 3 12/13/08 1 1 2T-18 12086703 INJECTION PROFILE = 12/17/08 1 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. RECEIVED A.UL; () () 2006 08/01/06 Scblumberger ~ Oil & Gas Cons. Comm~ NO. 3899 Anchorage -1 ;1 ?f1n's .~('>\t..1NED i\UG .i. ';t-""" ·.",v' .ì":' Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth i -'6'5' -·cL/íf Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Log Description Date BL Color CD 1J-101 (REDO) 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 1 D-125A (REDO) 11213778 INJECTION PROFILE 07/17/06 1 2K-24 (REDO) 11213781 INJECTION PROFILE 07/20/06 1 1 G-05 11249932 INJECTION PROFILE 07/28/06 1 3A-08 11249933 PROD PROFILE W/DEFT 07/29/06 1 1 D-117 11216305 INJECTION PROFILE 07/08/06 1 3F-18 11235384 SBHP SURVEY 07/25/06 1 3F-17 11235383 BHP SURVEY 07/25/06 1 1 Y -32 11213707 SBHP LOG 07/25/06 1 3G-25X 11216313 PROD PROFILE WIDEFT 07/31/06 1 1Y-24A 11216315 GLS/FBHP SURVEY 08/01/06 1 1 R-36 11249931 LDL 07/27/06 1 2V-10 11216311 SBHP SURVEY 07/28/06 1 1 D-1 07 11216309 INJECTION PROFILE 07/12/06 1 1 D-130 11249928 INJECTION PROFILE 07/09/06 1 31-03 11213788 PROD PROFILE W/DEFT 07/26/06 1 1Y-05 11216310 LDL 07/27/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Schlumberger NO. 3357 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth /Y5 -of? 02/28/05 SCf\NNED ~JUN 1 {} 2005 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Î7)5 -c5C 2V-12 10942845 PROD PROFILEIDEFT 02/16/05 1 t8t.f-IJ 3 2D-03 10922538 PROD PROFILE/DEFT 02/06/05 1 &2 i.YO - 7... ì 0 1 D-39 10942838 INJECTION PROFILE 02/11/05 1 I~- -C~f>- 2V-10 10942846 PROD PROFILE/DEFT 02/17/05 1 ~Ol- Jg3 1 C-131 10942848 INJECTION PROFILE 02/19/05 1 /70 - /61 1A-19 10942839 PRODUCTION PROFILE 02/12/05 1 /79-0/0 2N-308 10942843 PRODUCTION PROFILE 02/14/05 1 /9/- ~ 1 L-17 10942850 INJECTION PROFILE 02/21/05 1 2.0 if.- i? Iv 1 B-15A 10922540 SCMT 02/24/05 fli..,lJfv~ 1 L-24 (REDO) 10942834 RST WFL & PPROF 01/26/05 1 Kuparuk Color .~ CD -. SIGNdÁt~j !~h~ DATE: ~þ- Please sign and returle copy of this transm iltal to Beth at the above address or fax to (907) 561-8317. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing 2. Name of Operator A. RCO Alaska, Inc. i3. Address =p. Stimulate X Plugging ~ Perforate Repair well Other O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1283' FSL, 110' FWL, Sec. 8, T11N, R9E, UM At top of productive interval 1412' FSL, 1414' FEL, Sec. 8, T11N, RgE, UM At effective depth 1449' FSL, 1199' FEL, Sec. 8, T11N, R9E, UM At total depth 1460' FSL, 1134' FEL, Sec. 8, T11N, R9E, UM 12. Present well condition summary Total Depth: measured -~ true vertical 6. Datum elevation (DF or KB) RKB 111 7. Unit or Property name Kuparuk River Unit 8. Well number 2V-10 feet 9. Permit number/approval number 85-48 10. APl number 50-029-21310 11. Field/Pool Kuparuk River Field/Oil Pool 7575 feet Plugs (measured) None 6203 feet Effective depth: measured 7455 feet Junk (measured) None true vertical 61 03 feet 13. Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 245 Sx CS I 1 01 ° 1 01 ° Surface 3310' 9-5/8" 880 Sx CS III & 3343' 2908' Intermediate 390 Sx CS I Production " 7511' 7" 270 Sx Class G & 7544' 61 77' liner 250 Sx CS I Perforation depth: measured 7061'-7070',71 10'-71 18',7124'°-7130',7233'-7239',7247'-7262°,7274'-7314',7318°-7322' true vertical 5774'-5782~~5817~-5823'~5828'-5833~~5918~-5923'~593~~-5942~~5952'-5986~~5989~-5992' Tubing (size, grade, and measured depth) 4" 11#/ft J-55 & 3.5", 9.3#/ft J-55 @ 4591'/7185' Packers and SSSV (type and measured depth) PKR: Baker-HB @ 6995'; Baker FB-1 @ 7162'~ SSSV: OTIS FMX @ 1837' Stimulation or cement.~., squeeze summary Fracture '~timulate 'A' Sands Intervals treated (measured)_ 7233'-7239',7247'-7262',7274'-731 4',731 8'-7322' Treatment description including volumes used and final pressure 8.0 Mlbs 20/40~ 120.0 Mlbs 12/18 & 19.6 Mlbs 10/14 Mesh ceramic proppant. · ~ Re0resentative Daily Average Production or In!ection Data ~ ~ ' . - Oii-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 751 1721 65 1425 Subsequent ~ to' operation 697 1486 504 1377 RECEIVED Alaska 0il & Gas Cons. C0rnrnis Anch0ra,~e Tubing Pressure 174 232 15;: Attachments CopieS of Logs and' Surveys run Daily Report of Well Operations X.L 16. Status of well classification as: Oil X Gas Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title Wells Superintendent SUBMIT I~N DUJ=LICATE ion ARCO Alaska, Inc. ~ Subsidiary of Atlantic Richfield Company WELL 2V-10 DATE 1/11/95 DAY 1 DESCRIPTION OF WORK A SAND REFRAC CONTRACTOR / KEY PERSON DOWELL/GALLEGOS PBTD (RKB) LAST TAG (RKB) - DATE 7455' 7407' - 11/12/94 TIME LOG ENTRY KUPARUK R/VER UNIT WELL SERVICE REPORT AFC/CC# - SCA# 998373 I FIELD COST EST. ACCUMULATED COST $145,256 $147,723 SSSV TYPE / STATUS OTIS FMX10/FRAC SLEEVE INSTALLED · 0630 M1RU DOWELL/LIL' RED. SITP - 1913#, IA - 1000#, OA - 0#. 1045 SET TREE SAVER. PT TO 7400#. TEST OK. 1105 BEGIN BREAKDOWN STAGE; AFTER PUMPING 160 BBLS OF X-LINK GELLED WATER NOTED THAT SAND BELT NEEDS TO BE TIGHTENED. CANNOT TRANSPORT ANY SAND. SHUT DOWN TO REPAIR SLIPPING BELT; HAD PUMPED 225 BBLS OF GELLED WATER TOTAL 1145 BELT REPAIRED; START UP BREAKDOWN STAGE AGAIN. PUMPED 125 BBLS OF GW. 1200 SD. COMPLETED THE CONDITIONING STAGE; ISIP 2068#. 1249 COMPLETED DATAFRAC; ANALYSIS INDICATE THAT PAD SIZE SHOULD BE 205 BBLS RATHER THAN THE ORIGINALLY PLANNED 190 BBLS. 1355 BEGIN PUMPING JOB PER PROCEDURE WITH THE CHANGE MADE IN PAD VOLUME. 1513 JOB SCREENED OUT. 147600# TOTAL PUMPED: 8000g 20/40, 120000# 12/18, 19600g 10/14, 144323 # IN FORMATION AND 14.7 PPA FLUID AT PERFS. JOB A SUCCESS. 1730 RD DOWELL; WELL SECURE. SITP - 2100g, IA- 1000g. ,. SUMMARY: COMPLETED A SAND REFRAC. 147600g TOTAL PUMPED: 8000g 20140, 120000g 12/18, 19600g 10/14, 144323 # IN FORMATION AND 14.7 PPA JOB A SUCCESS. ~, ]2 k~ ~ ~ · "' Gas ConS. CHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK Weather ITemp' IChili Fact°r IVisibility IWindVei. J Report mil~st mphl COMPLETE INCOMPLETE ALASKA OIL AND GAS CONSERVATION ~MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Pull tubing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Operation Shutdown m Stimulate X Alter casing Repair well 5. Type of Well: Development X Exploratory _ IStratigraphic _ 4. Location of well at surface 1283' FSL, 110' FWL, SEC 8, T11N, RgE, UM At top of productive interval 1412' FSL, 1414' FEL, SEC 8, T11N, R9E, UM At effective depth 1449' FSL, 1199' FEL, SEC 8, T11 N, R9E, UM At total depth 1460' FSL, 1134' FEL, SEC 8, T11 N, RgE, UM '12. Present well condition summary Total Depth: measured 7575' feet Plugs (measured) Plugging __ Perforate _ Other 6. Datum elevation (DF or KB) RKB-MSL 111'. PL78' 33' GL 7. Unit or Property name Kuparuk River Unit 8. Well number 2V-10 9. Permit number/approval number 85-48 10. APl number 50-029-21310 11. Field/Pool Kuparuk Ri~ 13i1~. ~11% I F L~,.L I V LL/ true vertical 6203' Effective depth: measured 7455' true vertical 61 03' Casing Length Size Structural 8 0' 1 6" Conductor Surface 331 0' 9-5/8" Intermediate Production 751 1 ' 7" Liner Perforation depth: measured feet G 2 4 1992 feet Junk (measured) Alaska 0il & Gas Cons. Commissi0a feet Anchorage Cemented Measured depth 245 SX CS II 101' True vertical depth 101' 880 SX CS III 3343' 2908' & 39O SX CS I 270 SX CLASS G 7544' 61 77' 250 SX CS I 7247'-7262', 7274'-7314', 5930'-5942', 5952'-5986', 13. 7061 '-7070', 7110'-7118', 7124'-7130', 7233'-7239, true vertical 5774'-5782', 5817'-5823', 5828'-5833', 5918'-5923', Tubing (size, grade, and measured depth) 4' X3-1/2", 11#/9.3#, J-55 DSS-HTC/EUE-MOD @ 4591'/7185' MD Packers and SSSV (type and measured depth) 7318'-7322',(Reperf'd) 5989'-5992' BAKER HB RETR PKR ~6995' MD,BAKER FB-1 PKR @7162' MD, OTIS FMX-SERIES 10 SSSV ~ 1837' MD Stimulation or cement squeeze summary 14. Intervals treated (measured) 7233'-7239', 7247'-7262', 7274'-7314', 7318'-7322' Treatment description including volumes used and final pressure Fracture stimulated with 10.1 Mlbs 12/18 mesh proppant as shown on attached Well Service Report. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 826 454 12 500 209 2083 1054 53 1750 230 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 05/17/89 Date SUBMIT IN DUPLICATE ARCO Alaska, i~,v~' Subsidiary of Atlantic Richfield Com~ WELL CONTRACTOR 8J {FIELD- DISTRICT- STATE ! WELL SERVICE REPOI {OPERATION AT REPORT TIME IDAYS :DATE . , i,,/~,/~, REMARKS 0900 1~ RDMO C~ K~JSJO RECEIVED Alaska 0il .& Gas Cons. CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK !'Signed Weether Report Temp. l Chill Factor { Visibility eF °F I miles IWind Vel. knots 0 R I 6 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown__ Stimulate __ Pull tubing x Alter casing __ Repair well Plugging __ Perforate _ __ Other X Rec0mplete ~S 4' ~; 3-1/2" SS 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratig raphic Service 4. Location of well at surface 1283' FSL, 110' FWL, SEC8, T11N, R9E, UM ECEIVED At top of productive interval 1412' FSL, 1414' FEL, SEC 8, T11N, R9E, UM At effective depth J U L - ? 1992 1449' FSL, 1199' FEL, SEC 8, T11N, R9E, UM At total depth Alaska 0ii & Gas Cons. C0mmissi 1460' FSL, 1134' FEL, SEC 8, T11N, R9E, UM .a. nch0ra~'o 12. Present well condition summary Total Depth: measured 7575' feet Plugs (measured) true vertical 6203' feet 6. Datum elevation (DF or KB) RKB-MSL 111', PL78' 7. Unit or Property name Kuparuk River Unit 33' Gl. 8. Well number 2V-10 9. Permit number/approval number 85-48 /Conserv Order ~261 10. APl number 50-029-21310 t111. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7455' feet Junk (measured) true vertical 6103' feet Casing Length Size Structural 8 0' 1 6" Conductor Surface Intermediate Production 751 1 ' 7" Liner Perforation depth: measured 7061'-7070', 7110'-7118', 7124'-7130', true vertical 5774'-5782', 5817'-5823', 5828'-5833', Tubing (size, grade, and measured depth) 3310' 9-5/8" Cemented 245 SX CS II Measured depth 101' True vertical depth 101' 880 SX CS III 3343' 2908' & 39O SX CS I 270 SX CLASS G 7544' 61 77' 25O SX CS I 7233'-7239, 7247'-7262', 7274'-7314', 7318'-7322',(Reperf'd) 5918'-5923', 5930'-5942', 5952'-5986', 5989'-5992' 4"X 3-1/2", 11#/9.3#, J-55 DSS-HTC/EUE-MOD @ 4591'/7185' MD Packers and SSSV (type and measured depth) BAKER HB RETR PKR @6995' MD,BAKER FB-1 PKR @7162' MD, OTIS FMX-SERIES 10 SSSV @ 1837' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 F~e~) 05/17/89 Title Area Drilling Engineer SUBMIT ItCDUP[.ICATE ARCO ALASKA INC. DAILY OPERATIONS PAGE: i WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 2V-10 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 50-029-21310 85-48 ACCEPT: 10/03/91 06:10 SPUD: RELEASE: 10/15/91 11:10 OPERATION: WORKOVER DRLG RIG: NONE WO/C RIG: NORDIC 1 10/04/91 (1) TD: 0 PB: 7455 10/05/91 (2) TD: 0 PB: 7455 10/06/91 (3) TD: 0 PB: 7455 WO BRINE DELIVERY "@ 7544' MW: 8.5 Seawater MOVE RIG TO 2V-10. PULL BPV AND RU SLICKLINE. PULL DV F/6898'. RD SLICK- LINE. CIRC WELL TO SEAWATER. SITP=920 PSI AND SICP=840 PSI. WO DELVERY OF 12.3 BRINE. LOAD 11.7 PPG THIXSAL INTO RIG TANKS. POH W/3.5" COMPLETION "@ 7544' MW:ll.9 THXL CONDITION 150 BBLS 11.7 PPG THXL,WAIT ON 12.3 PPG THXL F/M-I PLANT, RECEIVE 210 BBLS 12.3 PPG THXL,MIX W/ll.7 PPG THXL IN PITS,SITP=920 PSI,SICP=820 PSI,KILL WELL W/ll.9 PPG THXL, BULLHEAD THXL INTO PERFS,CONT CIRC THXL TO SURFACE, SITP= 0 PSI, SICP=0 PSI,WELL DEAD,PUMPED 292 BBLS THXL/LOST 25 BBLS,SET BPV, ND TREE, NU BOPE, PULL BPV, SET TEST PLUG, OPEN 7" ANNULUS,ANNULUS ON VACUUM, PULL TEST PLUG, FILL HOLE WITH 4 BBLS THXL, SET TEST PLUG, TEST BOPE/CHOKE TO 3000 PSI, OK, RU CIRC. EQUIP/MU LANDING JT.,PULL PBR W/69K#,STRING WT=65K#,FILL HOLE W/8 BBL CIRC ONCE AROUND @ 3BPM/600 PSI, LOST 5 BBLS,MONITOR WELL, LD LANDING JT AND TBG HGR, MIX AND PUMP 12.2 PPG DRY JOB, LOST 2 BBLS,POH W/3-1/2" COMPLETION, LD SSSV AND 59 JTS 3-1/2" TBG, CONT. POH MIX DRY JOB "@ 7544' MW:ll.9 THXL CONT POH W/COMPLETION, LD SAME,LOST 28 BBLS,CLEAR FLOOR TO RUN DP,SET WEAR RING STRAP BHA, MU BKR PKR RETR. TOOL/BUMPER SUB/OIL JARS/DC, RIH W/BHA ON DP,LOST 4 BBLS,CIRC 50 BBLS @ 3 BPM/800 PSI,PU SINGLE AND LATCH PKR @ 6914' DPM, ROTATE 11 TURNS TO RT./RELEASE PKR, CIRC @ 3 BPM/1000PSI,PKR BEGAN PACKING OFF,LOST 10 BBLS,WORKED PIPE AND REDUCED PUMP RATE TO 2 BPM/900 PSI,CBU, RETURNS GAS CUT, SHUT DN AND DEGAS MUD IN PITS,LOST 12 BBLS DURING CIRC,GAINED 6 BBLS PRIOR TO SHUTTING DN, PIT VOL. DROPPED 24 BBLS DURING DEGAS OPS,ADD 75 BBLS 11.7 PPG THXL TO PITS TO BUILD VOLUME, CIRC WELL @ 2 BPM/800 PSI,LOST 4 BBLS,WELL DOES NOT FLOW, RETURNS GAS CUT, 11.9 PPG THXL IN AND OUT, PULL 1 STD WET,MIX AND PUMP 30 BBL 12.2 PPG DRY JOB RECEIVED d u L - 1 1992 Alaska Oil & Gas Cons. Commission Anchorage WELL : 2V-10 OPERATION: RIG : NORDIC 1 PAGE: 2 10/07/91 ( 4) TD: 0 PB: 7455 10/08/91 ( 5) TD: 0 PB: 7455 10/09/91 (6) TD: 0 PB: 7455 POH W/BIT AND SCRAPER "@ 7544' MW:ll.9 THXL SERVICE RIG, FUNCTION BOPS/CROWN-O-MATIC, PULL 16 STDS, BULLHEADING REQUIRED TO KEEP HOLE FULL DUE TO PKR SWABBING, CONT POH, LD BHA/PKR/TAILPIPE,MU 6-1/8" BIT AND 7" CSG SCRAPER/BIT SUB/BUMPER SUB/OIL JARS/DC, RIH W/103 STDS DP,PU 6 SINGLES,TAG FILL @ 7076' DPM, UP WT=134K#, DN WT=76K#,RU CIRC EQUIP,C/O SHAKER SCREENS,WASH DN F/7076' TO 7266',WASH AND REAM TO 7286',HIT HARD JUNK,WORKED PAST JUNK TO 7290', CONT TO WASH AND REAM TO 7469' (NORDIC RKB-7455' PARKER 191 RKB),RETURNS CONTAIN SOFT RUBBER FRAGMENTS,LOST 17 BBLS WHILE WASHING TO BTM, CIRC HOLE AT 3.5 BPM/1050 PSI, BRINGING UP LARGE AMOUNTS OF FINE WHITE SAND, LOST 10 BBLS, POH 7 STDS TO 7000' (50' ABOVE C SAND PERFS),CIRC HOLE @ 3.5 BPM/ 1050 PSI,CONT TO GET SAND RETURNS,CIRC 2+ BTMS UP, SAND RETURNS DIMINISHING, PUMP 30 BBL 12.3 PPG DRY JOB, POH W/3-1/2" DP POOH W/CMT STINGER "@ 7544' MW:12.0 THXL SERVICE RIG, POOH W/DP, LD, RU SWS, RIH W/6.0" GR-JB TO 7240' WLM, POOH, RECOVER SOME RUBBER IN JB, RIH W/HALLIBURTON BRIDGE PLUG, WORK & SET PKR @ 7145', POOH, RIH W/HALLIBURTON EZSV, SET RETAINER @ 6960', POOH, RIH W/CMT STINGER & 3-1/2" DP, TAG RET @ 6942' NORDIC MD, CIRC TO CLEAR LINES, STING INTO RET, ESTABLISH INJECTION RATE, UNSTING CLOSE ANN, PT CSG TO 2500 PSI, LOST 50 PSI IN 30 MIN, TEST GOOD, PUMPED 150 SX, (30 BBL), 15.6 PPG CLASS G, PUMP 2 BBL FRESH WATER SPACER & SWITCH TO 11.9# THIXSAL FOR DISPLACEMENT, INJECTION PRESSURE DOWN TO 770 PSI WHEN CMT HIT PERFS, SAW SLIGHT PRESSURE INCREASE. REDUCED INJ RATE TO 1 BPM, INJECTED 14 BBL CMT, PRESS 1100-1420 PSI, MOST OF PRESSURE INCREASE IS DUE TO DECREASED DENSITY OF FLUID BEING PUMPED, SHUT DOWN, ISIP 1300 PSI, 5 MIN 800 PSI, UNSTING, REVERSE OUT WATER SPACER AND 2 BBL CMT FROM DP, CONT REVERSE OUT TO BRING PH OF RETURNS DOWN FROM 10.0 TO 8.0, RD HALLIBURTON, MIX & PUMP DRY JOB, 41 BBL 12.4 PPG, RIG FLOOR TO POOH POOH W/BIT "@ 7544' MW:ll.9 NaC1 SERVICE RIG, POOH LD STINGER, RIH W/BIT-JB-BUMPER SUB-OILJAR, TAG @ 6938' NORDIC RKB, DISPLACE THIXSAL FORM WELL W/30 BBL 9.9 SWEEP, 230 BBL 11.9 BRINE, RECOVERED SIGNIFICANT AMOUNTS OF SAND W/DISPLACEMENT, CLOSE BACK SIDE & TEST CSG TO 2500 PSI, LOST 50 PSI IN 15 MIN, TEST GOOD, DRILL ON EZSV, PUCH DOWN 2' & DRILL UP. DRILL ON CMT, APPROX 2' VOID OF CMT BELOW EZSV, HARD CMT TO 6942'-7116', APPROX 8' VOID OF CMT ABOVE BRIDGE PLUG, TAG BP @ 7123' NORDIC, CIRC HOLE CLEAN, CLOSE BACK SIDE, PRESS ANN TO 1500 PSI TO TEST SQUEEZE CMT, LOST 900 PSI IN 8 MIN, FAIL TEST, CIRC @ 3.5 BPM & 700 PSI, FLUID LOSS 5 BBL, STOP PUMPING, MONITOR FLUID LOSS, POOH, NO FLUID LOSS RECE'IV D Alaska Oil & Gas Cons. CommissiO~ Anchorage WELL : 2V-10 OPERATION: RIG : NORDIC 1 PAGE: 3 10/10/91 (7) TD: 0 PB: 7455 10/11/91 ( 8) TD: 0 PB: 7455 10/12/91 ( 9) TD: 0 PBi 7455 10/13/91 (10) TD: 0 PB: 7455 10/14/91 (11) TD: 0 PB: 7455 POH W/OEDP "@ 7544' MW:ll.9 NaCl SERVICE RIG, WELL UNBLANCED, REV 1 DP VOLUME, MONITOR WELL-OK, POH AND LD, RIH W/OEDP, TAG EZSV-BP @ 7123', BREAK CIRC, BRINE BALANCED, RU HOWCO, BATCH MIX CMT, ESTABLISH INJECTION RATE, 1.5 BPM, 1275 PSI, PUMP 20.5 BBLS CLASS G CMT, HELD 350 PSI BACK PRESSURE WHILE SPOTTING, NO LOSS, PULL 12 STANDS, SLOW, REVERSE OUT i+DP VOLUME, SQUEEZE & HESTITATE 11-3/4 BBLS AWAY, FINAL SQUEEZE PRESSURE 2200 PSI, CIP @ 21:15 10/9/91, RD HOWCO, WOC, POH, LD 17 JTS DP FILL PITS WITH THIXSAL "@ 7544' MW:ll.9 THXL SERVICE RIG, FUNCTION BOPE/CROWN-O-MATIC,POH W/3-1/2" DP,MU 6-1/8" BIT,2 JUNK SUBS,BIT SUB,BUMPER SUB, OIL JARS,DC,RIH, TAG CMT @ 6975',PU KELLY,DRILL TO 7013 CLOSE PIPE RAMS,TEST CSG TO 1500 PSI,2000 PSI,2500 PSI,LOST 80 PSI IN 15 MIN, DRILL TO 7065',UP WT 150K,DN WT 80K, ROT WT 100K, PENETRATION RATE DBL F/7058-59 THEN BACK TO ORIGINAL RATE, TEST CSG TO 1500 PSI,LOST 950 PSI IN 15 MIN, TESTED AGAIN AT 1250 PSI, LOST 790 PSI IN 15 MIN, DRILL CMT F/7065-85' AT 80 FPM, CLOSE RAMS AND PRESSURE UP ON DP,HOLE TOOK FLUID AT 1150 PSI/.75 BPM, PRESSURE BLED TO 725 PSI IN 1 MIN, 300 PSI IN 4 MIN, 0 PSI IN 9 MIN, DRILL OUT CMT TO BRIDGE PLUG AT 7123',CIRC HOLE CLEAN, TRANSFER BRINE FROM PITS TO UPRIGHT TANK, CLEAN PITS,FILL PITS WITH THIXSAL BRINE AT 11.9 PPG, CONDITION THIXSAL RIH W/PERF GUN "@ 7544' MW:ll.9 THXL WEIGHT UP 269 BBL THIXSAL TO 11.9 PPG AND CIRC, DRILL BP @ 7123', WASH DOWN TO 7464', CIRC, MIX & PUMP 20 BBL DRY JOB, BLOW DOWN & STAND BACK KELLY, POOH W/DP, RIH W/BIT & 7" CSG SCRPR, CBU, PUMP DRY JOB, POH, RU SOS, RIH W/GUN RIH W/OVERSHOT "@ 7544' MW:ll.9 THXL RIH & PERF F/7070'-7322' GROSS IN 8 RUNS, 96 MISFIRES, RIH W/GRJB W/6" RING, JB/GR STUCK @ 7045', PUMP DOWN AND ATTEMPT TO WORK FREE, NO GO, PUMP JB OFF ROPE SOCKET, PULLED WEAR RING, SET TEST PLUG, TEST EQUIP TO 3500 PSI, CHANGE ELEMENT IN ANNULAR, TEST GOOD, PULL TEST PLUG, WAIT ON TRI-STATE, SET WEAR RING, RIH W/OVERSHOT POOH W/MILL & CSG SCRPR "@ 7544' MW:ll.9 THXL SERVICE RIG, TAG FISH @ 7024' AND PUSH TO 7463', MIX & PUMP DRY JOB, POH & LD FISH & BHA, RIH W/6" TAPERED MILL & 7" CSG SCRPR, TAG TITE SPOT @ 7039' REAM TO 7047', OVSERVED GAS CUT MUD RETURNS, CIRC OUT TO GAS, REAM F/7047-7460', CBU, POOH Alaska Oil & Bas Sons. AnchOrage WELL : 2V-10 OPERATION: RIG : NORDIC 1 PAGE: 4 10/15/91 (12) TD: 0 PB: 7455 10/16/91 (13) TD: 0 PB: 7455 RIH W/COMPLETION "@ 7544' MW:ll.9 THXL SERVICE RIG, BLOW DN KELLY,MIX DRY JOB,POH W/DP,MILLS,CSG SCRAPER, RU SWS,MU 5.970" GR/JB, TEST LUBRICATOR TO 1000 PSI, RIH TO 7225',POH,MU BAKER FB-1 PERM PACKER AND TAILPIPE ON W/L WITH BALL IN PLACE, SET PACKER AT 7160'WLM, TUBING TAIL AT 7183'WLM, POH, RD SWS,PULL WEAR RING, RU TO RUN COMPLETION, NU FLOW NIPPLE SLIP AND CUT 50' DRLG LINE,MU AND RUN COMPLETION AS PER PROCEDURE RIG RELEASED "@ 7544' MW:ll.9 THXL SERVICE RIG,WAIT ON OTIS SSSV HAND,MU SSSV, TEST TO 5000 PSI F/10 MIN, CONT RIH W/COMPLETION AS PER PROCEDURE, SPACE OUT AND LAND HANGER, PRESSURE TEST TBG TO 2500 PSI F/10 MIN, 1000 PSI ON ANNULUS F/10 MIN, PU SHEAR PBR @ ll0K#,TEST SSSV W/500 PSI DIFF F/15 MIN, SET BPV, ND BOPE,NU TREE,TEST TO 5000 PSI,TEST PACKOFF TO 5000 PSI,DISPLACE WELL WITH22 BBLS SPACER, 60 BBLS SEAWATER, 80 BBLS DIESEL, SHEAR OUT BALL IN SHEAR OUT SUB AT 3500 PSI,SITP=1450 PSI,SICP=225 PSI,CHECK VALVE IN MANDREL LEAKING, SECURE WELL, CLEAN PITS,NO BPV SET, RELEASE RIG AT 2300 HRS,OCT 15,1991 SIGNATURE: DATE: RECEIVED d U L - ? 1992 Alaska Oil & Gas CoDs. OornmissioD Anchorage To: Re: Well Namc [.oe'_ TYpe lZ.n i)atc Kuparuk Kupamk Kuparuk Kuparuk iKupamk Kupatuk Kupamk. Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kupamk Kupatuk Kuparuk River Unit IA-Il River Unit 1 L-10 River Unit 11,-14 River Unil IL-17 River U,,it ~vcr Unit IR 04 lrdver U,it 1Y-10 ,qiver l.rnii iV-ii River Unit fY-12 River Unit rY.-IS River Unit 2B-08 River Unit 2C-02 Rive,' Unil 2C-04 ni,;,;r Unit 2c 05 Kuparuk River Unit 2C-06 Kupamk Hiver Unit Kuparuk river 'Unit 2V-13 Kupm'uk River Unit 3G-12 Kt, paruk l',iver Unit 3H-02 Kuparuk River Unit 30-20 Water i:iow I,og ("Iq)T-P) Injection Profile Injection Profile Injection Profile Injection Profile lnjc-ction P,'ofile Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile Survey Injection Profile Survey Injection Profile Production l.og Production Log Injection Profile Injection Profile Survey Injection Profile 07.IA N 1991 10-1-91 03 NOVEMBER1991 4 NOVEMBER 1991 4 NOVEMBER 1991 11-.06-1991 6/30/91 12-13---1991 1 I-i9-91 11-.17-1991 12-2-91 12-27~1991 26 DE(.' 1991 10-27--1991 11/25/91 11-16--1991 8-JIiNE-1991 31 -JU'LY--1991 11 NOV 1991 lO/119/91 11~29-1991 Received by: Dated: Copy sentto :;ender: Yes RECEIVED MAR 2 6 1992 Alaska 011 & Gas Cons. Commisflon Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 19, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ~ Dear Mr. Chatterton' Attached in duplicate are multiple Report of Sundry Well Operations notices in the Kuparuk field. The wells are listed below. Well Action 2 V- 1 0 Perforate 1Q-06 90C 1 Q- 0 3 Acidize 2H-12 ~ 2X- 01 Fracture 2 X- 1 3 Storm Ck. 2X-09 ~ 2X-10 S~C 2X-11 ~ 2X-15 ,93C If you have any questions, please call me at 265-6840. Sincerely, G. B. Srfiallwood Senior Operations Engineer GBS:kjr CC: · J. Gruber ATO 1478 J. R. Brandstetter ATO 1120 L. L. Perini ATO 1130 KOE1.4-9 w/o attachments RECEIVED JUN 2 2 1989 Alaska 0il & Gas Cons. Corrlrnissiorl Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMk.'-~SION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown m Stimulate Plugging Perforate Pull tubing Alter casing Repair well Pull tubing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory ServiceStratigraphic 4. Location of well at surface 1283'FSL, 110'FWL, Sec. 8, T11N, R9E, UM At top of productive interval 1412' FSL, 1414' FEL, Sec. 8, T11N, R9E, UM At effective depth 1449'FSL, 1199'FEL, Sec. 8, T11N, R9E, UM At total depth 1460' FSL, 1134' FEL, Sec. 8, T11N, R9E, UM Other 6. Datum elevation (DF or KB) 109' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number_ 2V-10 /~,~, J_~,,c_, ~ 9. Permit numb7 85-48 ~-- ?O~ · 10. APl number 5o-02 9-2131 0 11. Field/PoolKuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured true vertical 7575 feet Plugs (measured) 6 2 0 3 feet None Effective depth: measured 7455 feet Junk (measured) true vertical 61 03 feet None Casing Length Size Cemented Structural Conductor 1 01' 1 6" 245 sx CS II Surface 3343' 9 5/8" 880 sx CS III Intermediate 390 sx CS I Production 754 4' 7" 270 sx Class G Liner 250 SX CS I Perforation depth: measured 7059-71 03' ,711 0'-711 8',7124'-7130',7233'-7239',7247'-7262', true vertical 5773'-581 0',581 7'-5823',5828'-5833',591 8'-5923, 5930'-5942', Tubing (size, grade, and measured depth Measured depth True vertical depth 101' 101' 3343' 2908' 7544' 6177' 7274'-7314', 7318'-7322' MD 5952'-5986', 5989'-5992' TVD 3 1/2" J-55 tbg w/tail @ 6981' Packers and SSSV (type and measured depth) Baker FVL SSSV @ 1891; Baker FHL pkr @ 6951' 13. Stimulation or cement squeeze summary RECEIVED 'JUN 2 2 '1989 Intervals treated (measured) Treatment description including volumes used and final pressure Alask~ 0il & 6as Cons. Commission Anchorage 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2503 1537 0 4728 2599 3458 TubingPressure 1450 165 1450 22O 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,/~ ~ ~J' itle Senior Operations Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICAIE W~ELL ARCO Alasl(a, III ~ . Subsidiary of Atlantic Richfield Coml'~-. CONTRACTOR REMARKS FIELD- DISTRICT- STATE OPERATION AT R~PORT TIME ~r..m..m., oc:~vm~,-- ncrvn m OqOt, I ()Ho T, e l o q..5' ~j COL,. ,ZO' eo,,-~ ~j~.,, . OI ,.,,, e I( f~O H '-7 i2~ '- / ! 3 oo S .T IC~OO 17o0 705'9'- 70~1~ .... _z_ R :LI:iVI:iJ ,J U t'~ -- a-J ~,-, Alaska U~l m Gas Cons. Commission Anohnmnn ['-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK AL .(A OILAND GAS CONSERVATION COMM, ,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate X Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1283'FSL, 110'FWL, Sec. 8, T11N, R9E, UM At top of productive interval 1412' FSL, 1414' FEL, Sec. 8, T11N, R9E, UM At effective depth 1449'FSL, 1199'FEL, Sec. 8, T11N, R9E, UM At total depth 1460' FSL, 1134' FEL, Sec. 8, T11N, R9E, UM 7575 6203 12. Present well condition summary Total Depth: measured true vertical feet Plugs (measured) feet NOlle 6. Datum elevation (DF or KB) RKB 10~) 7. Unit or Property name Kuparuk River Unit 8. Well number 2V-10 9. Permit number 85-48 10. APl number s0-02 9-21 31 0 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool REC, E, IVED 13. Effective depth: measured true vertical 7 4 5 5 feet 61 0 3 feet Casing Length Structural Conductor I 01 ' Surface 3 3 4 3' Intermediate Production 7 5 4 4' Liner Perforation depth: measured 7233'-7239', true vertical 591 8'-5923, Size 16" 9 5/8" 7" 7247'-7262', 5930'-5942', Tubing (size, grade, and measured depth 3 1/2" J-55 tbg w/tail @ 6981' Packers and SSSV (type and measured depth) Baker FVL SSSV @ 1891; Baker FHL pkr @ 6951' Attachments Description summary of proposal _ Initial Perforations in C Sand. Junk (measured) NOne Cemented 245 sx CS II 880 sx CS III 3.90 sx CS I 270 sx Class G 250 sx CS I DEC u 5 ]98.8 ,.!~!as~ 0il & Gas Cons. C0ma]issi0rt Measured 'c'l~; ~l~c~r~ic~" depth 101' 101' 3343' 29O8' 7544' 61 77' 7274'-7314', 7318'-7322' MD 5952'-5986', 5989'-5992' TVD Detailed operation program __x BOP sketch x__ 14. Estimated date for commencing operation December 7, 1988 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas m Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~'~~ j/ Title ..... FOR COMMISSION USE ONLY' Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test m Location clearance Mechanical Integrity Test __ Subsequent form ORIGINAL SIGNED BY Approved by the order of the Commissi~r,n~Hr' r, ~..~T~ I,,,,~:,~lllllil,~ U, ~Jl¥11 I I I Form 10-403 Rev 06/15/88 require 10- Commissioner IApproval Approved Copy Returned ~ SUBMIT IN TRIPLICATE Following is the procedure for through tubing perforation of the C Sand in Well 2V- 10. This sand has not been previously perforated because this area was used for gas storage in the past. We now believe the C Sand will produce at GOR's our facilities can accomodate. Wireline lubricator and BOP's will be used for well control. Also, no special fluids are required for perforating. Finally, A Sand pressure is estimated at 3900 psi and C Sand pressure is estimated at 2800 psi (at 6200' subsea). Well 2V-10 Perforate C Sand 230DS28VL Notes: Restrictions Minimum ID 2.812" at SSSV (1899' MD). ID 2.813" at 'X' Nipple (6969' MD). Tubing tail at 6981' MD. Length from robing tail to top perforations -- 79 feet. Guns Load guns one shot per foot with zero degrees phasing. Schlumberger -- 2 1/8" Enerjet with 13.5 g charge. Gearhart -- 2 1/8" E-Jet II with 16 g charge. Atlas Wireline -- 2 1/8" Silver Jet with 16 g charge. RECE, IVED DEC 0 ~4 lsd8 t~iI & Gas Cons. Commission ' ~,.~ gnchorage 1. MIRU Perforating Unit. 2~ Tie-in and perforate the following depths. Perforate underbalanced with the well flowing. It is not necessary to fully open the well -- just enough to lower the bottom hole pressure by 300 to 500 psi. DIL 4/3/85 CBL 4/21/85 Shot Dens./Phase .Sand Length 7124-7130 7124-7130 1 SPF / 0° B 6' 7110-7118 7110-7118 1SPF/0° B 8' 7060-7104 7059-7104 1 SPF / 0° C 44' After shooting, flow the well to clean up perforations and minimize chance of getting stuck while pulling out of hole. 3. RDMO Perforating Unit. 4. Return well to production and obtain a 24 hour well test as soon as practical. Contact Engineering if excessive gas is apparent. 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANOE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 5. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF W ! REL ! NEBOP EOU ! PMENT i i i ! 5[0084006 ~Ev." ,- ' -" STATE OF ALASKA ~--' ALASKAt~L AND GAS CONSERVATION CO,viMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REV I SED OIL J~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-48 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 9951 0-0360 50- 029-21310 4. Location of well at surface 9. Unit or Lease Name 1283' FSL, 110' FWL, Sec. 8, T11N, RgE, UH Kuparuk River Unit At Top Producing Interval 10. Well Number 1412' FSL, 1414' FEL, Sec. 8, T11N, R9E, UM 2V-10 At Total Depth 11. Field and Pool 1460' FSL, 1134' FEL, Sec. 8, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.)16.Lease Designation and Serial No. Kuparuk River 0il Pool RKB 109'I ADL 25644 ALK 2575 12. Date Spudded 13. Date T,D. Reached 14. Date Comp., Susp. or Aband. I 1S. Water Depth, if offshore I 16. No. of Completions 03/26/85 04/03/85 04/05/85*I N/A feet MSLI 1 17. Total Depth {MD+TVD} 18.Plug Back Depth {MD+I-VD} 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7575'MD, 6203'TVD 7455'MD, 6103'TVD YES [~ NO [] 1899' feet MD 1400' (approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP, FDC/CNL, Cal, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SUrf 101' 24" ' 245 sx CS II 9-5/8" 36.0# J-55 Surf 3343' 12-1/4" 880 sx CS Ill & 39(~ st CS I ,,_ 7" 26.0# J-55 Surf 7544' 8-1/2" 270 sx Class G & 250 Dx CS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/4 spf, 120° phasing 3~1/2,, 6981' 6951' 7233'-7239'MD 5918'-5923'TVD 7247'-7262'MD 5930'-5942' TVD 26. ACID, FRACTURE, CEMENT sQuEEZE, ETC. 7274'-7314'MD 5952'-5986'TVD DEPTH INTERVAL (MD) AMOUNT& KIND OF M/~q:ERIA'L'USED 7318'-7322'MD 5989'-5992'TVD . .See attached Addenclum~ dated 12/29/87, for fracture dal;a. 27. N~A' PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION 'FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD II~ · , Flow Tubing Casing Pressure CALCULATED~=1~! OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NoneRECEIVED J A N 2 2 I:'; ~; $ Alaska Oil & Gas Cons. Commission *Note: Tubing was run and the well perforated on 5/2/85. Fractured wel 1 5/22/85. Anchorage Form 10407 WC/~/28 :DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ 29. 30. GEOLOGIC MARI~E~S FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7059t 5772~ N/A Base Upper Sand 7105~ 5811~ Top- Lower Sand 7225~ 5912t Base Lower Sand 7382~ 60/+2~ 31. LIST OF ATTACHMENTS Addendum (dated 7/26/85 & 12/29/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injectiOn, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "nOne". Form 10-407 ADDENDUM WELL: 5/22/85 2V-10 Frac Kuparuk "A" sand perfs 7233'-7239', 7247'-7262', 7274'- 7314' and 7318'-7322' in 8 stages per procedure dated 5/17/85 as follows: Stage 1: 40 bbls 130° diesel w/5% J40 @ 5.1 BPM, 3030 psi Stage 2: 65 bbls gelled diesel @ 20.5 BPM, 3650 psi Stage 3: 12 bbls gelled diesel @ 20 BPM Stage 4: 19 bbls gelled diesel 1# 100 mesh @ 20.4 BPM, 3630 psi Stage 5: 40 bbls gelled diesel @ 20.3 BPM, 3410 psi Stage 6: 18 bbls gelled diesel 3# 20/40 @ 19.9 BPM, 3400 psi Stage 7: 33 bbls gelled diesel 8# 20/40 @ 20 BPM, 3320 psi Stage 8: 83 bbls gelled diesel flush @ 19 BPM, 3950 psi Load to recover: 298 bbls diesel Pumped 750# 100 mesh & 10,100# 20/40 sand in formation leaving zero in casing. Well release to Production. RECEIVED ,JAN Alaska Oil & Gas Cons. Commissior~ Anchorage ADDENDUM WELL: 4/~18~ 5~23~85 2V-10 Arctic Pak w/250 sx CS I, followed by 59 bbls Arctic Pak. Frac well in 8 stages w/298 bbls gelled diesel, 750# of 100 mesh & 10,100# of 20/40 mesh. RECEIVED JAN 2 Alaska Oil & Gas Cons. 6ommissiorl Anchorage Drilling S~perintende~t - ' ISate ARCO Alaska. I'~ Post Office Uox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALAS~, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 04-15-86 TRANSMITTAL # 5629 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: -Dresser Atlas: One * of each 2H-2 Comp. Neu. Gamma Ray 12-03-85 Run #3 7400-7655 2V-10 Comp. Neu. Gamma Ray 12-02-85 Run # 7000-7300 2V-13 Comp. Neu. Gamma Ray 12-02-85 Run #3 8210-8314 3J-10 Carbon/Oxygen Gamma Ray 01-29-86 Run #1 2460-2770 3J-15 Carbon/Oxygen Gamma Ray 01-30-86 Run #1 2530-2980 Receipt Acknowied~ed: tate of AK*bl/se : NSK C!erk*b! ARCO Alaska, Inc. _Post Oflice E '60 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 10-07-85 Transmittal No: 5381 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Library Tapes plus listings/ Dresser Atlas/ One of each 2H-2 09-20-85 7395'-7676'/.-~.~ do2 70~/'l~-4'z~ed- 75 c/,.5'- 75 ~ 9V-10 09-20-85 6979'-7315~ ~ ~ ~ 2v~13 09-18-85 8092'-8316~~7~-~ -~d~-- ~?~ --P3/~ ' Receipt Acknowledged: B' Currier Drilling DISTRIBUTION BPAE **~Geolog~L.Johnst°n Exxbn Sohio Chevron Mobil Phillips Oil Union D & M NSK Drill Clerk J. Rathmell K. Tulin/Vault ARCO Alaska, In Post Offic~ ..,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DA%'E: 09-19-85 T~<ANSMITTAL NO: 5360 ARCO ALASKA, INC. KUPARUK OPLRATIONS ENGINEEktNG RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHO~AGE, AK 99510 TRANSMITTED HEPJ~WITH ARE THE RECEIPT AND RETU~4 ONE SIGNED FINAL~PRINTS/ SCHL/ CBL'S ~'-~iQ-1~ 04-26-85 04-26-85 04-16-85 03-02-85 04-21-85 04-21-85 04-25-85 04-25-85 RUN ~{UN kUN RUN RUN KUN RUN RUN FOLLOWING ITEMS. PLEASE ACKNOWLEDGE COPY OF '£HIM TRANSMITTAL. f2 7600-8842 fl 5500-8018 fl 6095-9046 fl 3650-6690 5595-7888 fl 5~95-7383 #1 5900-7818 fl 75U0-~123 RECEIPT ACKNOWLEDGED: sPAE B. CURRIER CHEVRON D & ~J DIbTKIBUTIUN: DI<ILLING* ~L W. PASHER L. JOHNSTON EXXON MOBIL P~ILLIP$ 0I~. N~K CLEF, K*BL J. P,A?~MELL . SOHIO /SE UNION K. TU L IN/VAU LT* FI LM ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfie!dCompany ARCO Alaska, Inc. Posl OIIice Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date:08-08-85 Transmittal No:5282 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Production Finals--Dresser Atlas 2V-10. Epilog 05-26-85 2V-13 Comp. Neu-Gamma Ray 06-23-85 2H-2 Epilog 04-07-85 Run #1 Run #1 Run #1 8210-8310 Receipt Acknowledged: B. Currier BPAE Chevron D&M Date: DISTRIBUTION Drilling W. Pasher Geolog~L.Johnston Exxon Mobil Phillips Oil NSK Drill Clerk J. Rathmell x!f:,..~, 'fl";' Cf,~. t' State of "~'?~.~ '";/"~/.%';,-:./, ~, Sohio Union K. Tulin/Vault ARCO Alaska, Inc. .:7 Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 06-24-85 TRANSMITTAL NO: 5227 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 AI.]CIIORAGE, AK 9Q510 T F~d~SM ITTED RECEIPT AND KUPARUK WELL 1B2'3~ 04-2 lC-4~ 04-2 1!!-3 ~ 03-0 1Q-l.. 05 ~ 1~-?-, 05 -2 HEREWITII ARE TIIE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. PRESSURE REPORT ENVELOPE DATA- 1-85 PBU BOTH SD. CAMCO 5-U5 SBIIP BOTH SD. CAMCO 6=85 PBU' BOTII SD. CAMCO 6-85 SBHP 'A' SD. CAMCO 6-85 SBHP 'A' SD. CAMCO 1Q-3~ 1Q-4~ lQ-5,, lQ-6.. lQ-7 ,. lQ-8-,. 2A-2 2A-41 2C-5x 2C-9'- 2C-!0\ 2C-11,, 2C-12~ 2C-14,,~ 2G-l-. 2H-1 -, 'IH-! ~- 2H-2" ~'I-3 2H-4 x 2V-9-- IV-!0',. !V-il 2V-12-~ 2X-2 -- 2X-2 -. ~X-5~ 2Z-6~ ~ECEIP'£ 05-!8-85 SBHP 'A' SD. CAMCO 05-14-85 SBIIP BOTiI SD. CAMCO 06-06-85 SBIIP 'C' SD. CAMCO 04-23-85 SDt!P CAMCO 04-17-85 SBHP 'A' SD. CAMCO 04-03-85 SBHP 'A' SD. CAMCO 05-27 05 SBHP '~' -~ ~. SD. OTIS 05-!!-85 SBI1P · 'A, SD. CAb!CO 04-23-85 PBU 'A~ SD. BAKER NORTH SLOPE 04-06-85 SBIIP 'A' SD. OTIS 04-40-~5 SBIIP BOTH SD. OTIS 03-29-85 SB!tP 'A' SD. OTiS 03-26-85 SB!tP 'C' SD. OTIS 04-23-85 PBU 'A' SD. OTIS & BAKER 04-29-85 FBIIP 'A ' SD. CAMCO 05-°~ 85 o'~ -~'~'~o'~oov CAMCO 05-27-~5 SEHP 'A' SD. OTIS 05-23-85 ???? ???????? CAMCO 05-23-85 ~n,,n 'A ' ~ .... SD. OTIS 05--~3-85 ~cD'l~. ~ 'A' SD. OTIS 05-18-85 SBHP 'A' SD. OTIS 05-!7-85 SBi!P 'A' SD. OTIS 05-12-85 SBHP 'A' SD. OTIS 05-14-85 SBIIP OTIS " 1 00-_6-85 SB!IP BOTH SD. OTIS 0G-14-85 SBllP BOTII SD. OTIS 06-12-85 SB!iP BOTIJ SD. OTIS 04-08-85 SB!iP 04-2 '~' 05 PBU BOTH SD 04-01-85 S~IIP BOTH SD. ACKN OW LED CE D: ,PAE* Cl'T',~.t'~-r ~ ~ · !lEw~,'m * & M* D-i S TI~/DUT'iON: DR~- r-~,G .L.~.~. W PASHER I.. JC>iINSTON EXXON MOBIL* PHILLIPS OIL* NSK CLERK J. RAT!D~ELL* BAKER NOTH SLOPE Anchora2s OTIS DATE: ...... ~.r~"-', ......... ~ .... "~"" ~' ~STATE' OF'ALASKA*- SOIlIO* UNION* RETURN TO: ARCO ' ska, Inc. · _st Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 PAGE ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 AS~HORAGE, AK 99510 D.~ ~'E: 06-19-85 TRANSMITTAL NO: 5230 2 OF 2 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACK~4OWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. * * * CONT I 2D-5 2D-3 2D-3 2E-9 2E-13 2E-!4 2E-15 2G-1 2H-1 2H-! 5 2H-1 2H-3 2H-4 2H- 14 2U-5 2U-6 2U-7 2U-8 2U-'9 2U-10 2U-16 2U-16 2V-10 2V-ll 2V-ll 2W-13 2X-12 2Z-2 NUED. FROM PREVIOUS PAGE*** FLOWING BHP ETC 05-06-85 CAMCO ACID JOB PREP 05-0 7-85 BAKER ACIDIZE 'C'SD 05-11-85 DOWELL G.R. SBHP 06-11-85 OTIS SBHP 06-10-85 OTIS SBHP 06-10-85 OTIS SBHP 06-09-85 OTIS FLOWING BHP 04-29-85 CAMCO BHP&TCL 05-27-85 OTIS SBHP & ETC. 04-2 9-85 OTIS BHP & ETC. 05-23-85 CAMCO BHP & ETC. 05-23-85 OTIS COMP BHP 05-23-85 OTIS INT. SBHP&ETC 04-28-85 OTIS SBHP 05-02-85 CAMCO SBHP & TCL 05-03-85 CAMCO SBHP PRE PROD 05-04-85 CAMCO SBHP & ETC. 05-04-85 BAKER/CAMco PRESSURE TEST 05-27-85 OTIS BHP SAMPLE 06-05-85 OTIS 'A'SD FLUID ID 06-09-85 OTIS PBU 06-07-85 OTIS BHP & ETC. 05-17-85 OTIS STATIC 05-12-85 OTIS STATIC 05-23 -85 OTIS 'C'SD ACID STIM 05-20-85 DOWELL 'C'SD ACID JOB 05-12-85 DOWELL E/LINE FLUID ID 05-03-85 OTIS/CAMCO RECEIPT ACKNOWLEDGED: B PAE * B. CURRIER CHEVRON* D & M DRILLING L. JOHNSTON MOBIL * NSK CLERK · DATE: DIS TRIB UT I ON: W. PASHER E XXO N PHILLIPS OIL* J. RAT}~ELL STATE OF ALASKA SOHIO* UN ION * K.TULIN/VAULT ARCO Alaska, In-;"'"' Post Office ,-:,ox 100350 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 06/18/85 TRANSMITTAL NO: 5218 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 bl TTED HERL~qITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE : ~ECEIP~ AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. L/FINAL PRINTS/SCHL OPEN HOLE DATA (ONE * OF EACH) 2C-9 5" DIL/SFL-GR 03-12-85 RUN #1 4162-9584 2" DIL/SFL-GR 03-12-85 RUN Ti 4162-9584 5" DEN/NEU-GR PORO 03-12-85 RUN #1 4800-9559 2" DEN/NEU-GR PORO 03-12-85 RUN #1 4800-9559 5" DEN/NEU-GR RAW 03-12-85 RUN #1 4800-9559 2" DEN/NEU-GR RAW 03-12-85 RUN #1 4800-9559 CYBERLOOK 03-12-85 RUN #1 4800-9530 2E-14 '7 2V-10 5" DIL/SFL-GR 11-26-84 RUN #1 4030-8658 2" DZL/SFL-GR ~i-2~-84 RUN ~,! 403'0-865o 5" DEN/NEU-PORO 11-26-84 RUN ~1 8100-8632 2" DEN/NEU-PORO 11-26-84 RUN #1 8100-8632 5" DEN/NE U-RAW 11-26-84 RUN #1 8100-8632 2" DEN/NEU-RAW 11-26-84 RUN #1 8100-8632 · COMPUTOR PROCESS 11-26-84 RUN #1 8150-8600 ~" DIL/SFL-GR 04-0 3-85 RUN #1 2" DIL/SFL-GR 04-03-85 RUN #1 5" DEN/NEU-GR PORO 04_0° o J-o5 RUN ~! 2" DEN/NEU-GR PORO 04-03-85 RUN #1 5" DEN/NEU-GR RAW 04-03-85 RUN ~,~1 2" DEN/NEU-GR RAW 04-03-85 RUN ~1 CYBERLOOK 04-03-85 RUN ~1 RECEIPT ACKNOWLEDCED: B PAE B. CURRIER C HE VRON D & M*BL DRILLING*BL L. JOHNSTON MOBIL NSK CLERK*BL 3345-7567 3345-7567 6860-7542 6860-7542 6860-7542 6860-7542 6860-7542 JUl',,' 2 ~ ;~,,.. I., D~TE: ;'.:.~ .."" DISTRIBUTION: W. PASHER E XXO N PHILLIPS OIL J. RATHMELL*BL .r~ 7~ r~ .~, S,~.z, OF ALASKA*BL/ SOHIO SE UNION K. TUL IN/V~,-~ ~,,"* m* FILMS ARCO Alaska, Inc. Post Office Box ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 18, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2V-10 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263 -4944. Sincerely, Gruber Associate Engineer JG/tw GRU9/L83 Enclosures RECEIVED JUN 2 0 1985 Alaska 0il & Gas Cons, Commission Anchorage ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany .-, -~. STATE OF ALASKA .~,-. ALASKA £ _ AND GAS CONSERVATION CO. AISSION WELL COMPLETION OR RECOMRLETION REPORT AND LOC 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE ~ ' I ' 2[ Name of ope~ato~ 7. Permit Number ARCO Alaska, Inc. 85-48 3. Address " 8. APl Nu~nber ' ' ' P. 0. Box 100360, Anchorage, AK 99510 50- 029°21310 4. Location of well at surface 9. Unit or Lease Name 1283' FSL, 110' FWL, Sec. 8, T11N, RgE, UN ~ Kuparuk River Unit At Top Producing Interval .I- J'~ H '_d{ 10. Well Numl~er I ' 1412' FSL, 1414' FEL, Sec.8, T11N, RgE, UN [~'--~'~un~i 2V-10 At Total Depth ~~ '. ~'_¥~ ! ~1. Field and Pool 1460' FSL, 1134' FEL, Sec.8, TllN, RgE, UN IS:'~'J-?-~'~.!-~.. Kuparuk River Field .... ~. Eievation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No~ Kuparuk Ri var 0i 1 Pool 109' RKBJ ADL 25644 ALI( 2575 , , .... 12. Date SpUdded -13. DateT.D. Reached 14. Date Comp., Susp. orAband. [l~.Waterl~epth~ifoffshore116. No. of Completions 03/26/85 04/03/85 04/05/85J IN/A feet MSL 1 i~.TotaiDepth(MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directi°nalSurvey I 20. Depth where SSSV set J 21.ThickInessofPermafro~t 7575'MD,6203'TVD 7455'MD,6103'TVD YES ~X NO [] 1899 feet MD. i 1400' .(Approx.) 22. TyPe [ZlectrIic' or OtHer Logs Run D IL/SFL/GR/SP, FDC/CNL, Cal~ Gyro 23. CASING, LINEI~ 'AND cEME'NTING RECORD ....... SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED ........... 16" 62.5# H'40 Surf 10i' 24" _ .245. sx CS I. I 9-.5/8" 36.0# J-55 Surf 3343' 12-1/4" I , 880 SX ~ III & 390 SX 7" 26'0# J--55 Surf 7544' 8--1/2" 270 sX Class "G" & 250 .x CS I '2~. 'Perforationsopen toIProduction {MD;~VD of Top and Bottorr; and' E25. ' TUBING RECSRD interval, size and number) SIZE' DEPTH SET (MD) ~ACKE'R SET ii'ID)' ' · .... 7318' - 7322' 3-1/2".. 6981' 6951 7314~ - 7274' 7262' - 7247' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, E'TC. 7233' - 7239' DEPTH INTeRVAl_ (MD) AI~IOUNT & KIND OF MATERIAL ~sED ..... N/A ...... ...... 27, N/A PRODUCTION TEST ........ Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of'¥est hoU;s :Tested PRODUCTION FOR ~'IL~BBL GAs~McF WATER-BBL CI~tOKE SIZE ] GAs-OIL RATIo'' TEST PERIOD I~ I FIo~v Tubing Casing Pressure cALCULATED OIL-BBL GAS-MCF WATER-BBL OIL G~AvITY-API (corr) .... Press. 24-HOUR RATE II~ .......... 28. CORE DATA Brief description of lith°logy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED J U N 2 0 1985 Alaska 0ii & Gas Cons. Comrn}ssion Anchorage ..... · . Form 10-407 * NOTE: Tubing was run and the well perforated on 5/2/85. TEMP/WC29 Submit in duplicate Rev. 7-I-80 CONTINUED ON REVERSE SIDE 29. . -. · , .~.. ~30. , ~ GEOLOGIC MARKERS ' "- ~' FORMATION TESTS · NAME u. Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. .. Top Upper Sand 7059' 5772' N/A Base Upper Sand 7105' 5811' Top Lower Sand 7225' 5912' Base Lower Sand 7382' 6042' ~ . ~ . . .~ 31. LI~T OF ATTACHMENTS We]] H~s:l;ory. ~,~tro{rnn{ ~_¢ ..... . .... S,,rvey [~,_ cop~,~-I__, ..... 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed_ /~ ~. . .~.~j . _ Title Associate Engi hoer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used tor reporting the entire operation if space is available. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 603996 Completion WWS #1 Accounting cost center code ICounty or Parish State North Slope Borough Alaska ADL 25644 2V-10 ITitle Operator I A.R.Co. ARCO Alaska, Inc. Spudded or W.O. begun ~ Date Complete Date and depth as of 8:00 a.m. Complete record for each day reported API 50-029-2] 3] 0 W.I. [Total number of wells (active or inactive) on this Icost center prior to plugging and I 56.24% labandonment of this well I IHour I Prior status if a W.O, 4/30/85 ! 0315 hrs. 5/01/85 5/02/85 7" @ 75~.~.' 10.3 ppg NaC1 Accept tis @ 0315 hrs, 4/30/85. w/bit & csg scrprs. 7391' WLM PBTD, RIH w/bit & scrpr ~ ND tree, NU & tst BOPE. RIH 7" @ 7544' 7479' PBTD, RU DA 10.3 ppg NaC1 FIH w/DP, drl firm cmt f/7408'-7479'.Rev circ to displ contam- inated brine w/cln brine,POOH,LD DP & DC.NU perf flange. RD DA. 7"'@ 7544' 7479' PBTD, NU tree 10.2+ ppg NaC1 RU DA, RIH & perf 7233'-7239', 7247'-7262', 7274'-7314' & 7318'-7322'. Rn JB/GR to 7380', RD DA. PU tailpipe, Bkr FHL pkr w/SBR & RIH on 3½" tbg. Rn & tst Bkr FVL SSSV. Lnd 218 jts, 3½", 9.3#, J-55 8RD EUE IPC tbg% Set pkr. Shear SBR. Relnd tbg. Tst ann. Set BPV. ND BOPE, NU tree. SSSV @ 1899', FHL Pkr @ 6951', X Nipple @ 6969', TT @ 6981' 5/03/85 7" @ 7544' 7479' PBTD, RR Crude/Diesel NU & tst tree, pull BPV. Displ well w/30 bbls diesel, followed by crude. Tst tbg, annulus & SSSV; OK. Shear out ball. Bleed tbg press to 600 psi. Secure well. Set BPV.RR @ 1100 hrs, 5/2/85. OIdTD tlNewTD PBOeplh 7479' PBTD Released rigI Date JK nd of rig 1100 hrs. 5/2/85 J Rotary Classifications (oil, gas, etc.) J! Type completion (single, dual, etc.) producing method Official reservoir name(~) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day R:ECFIvF Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effectlve~a[e ' corrected ~ I~,~-- ~., The above is correct ...... '~ L/Il Signature For orm p eparation and ~tribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date 5/15/85 ITM Anchqrage Drilling Superintendent ARCO Alaska, Inc. Post Office Bo,, ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 31, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2V-10 Dear Mr. Chatterton' Enclosed is an addendum to the 2V-10 Well History to include with the Well Completion Report dated 05/24/85. If you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU9/L28 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED JUN l 2 985 Alaska Oil & Gas Cons, G~mmissior, Anchorage WELL: 2¥-10 Arctic Pa~ w/250 sx CS I, followed by 59 bbls ArctiC pak. RECEIVED J u N ~[ ~ Alasl<a Oil & Gas Cons. CommJssJor, Anchorage WELL: '~/~5/s5 ArctiC pak. 2V-10 ArctiC pak w/250 sx CS I, followed by 59 bbls RECEIVED JUN 1 2 1~85 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office By,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 28, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2V-10 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 2V-10. The bottomhole location, geologic markers, TVDs, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU9/L11 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~'% STATE OF ALASKA 0 R 16 IN A L ALASKA -AND GAS CONSERVATION cC "MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED I-~X ABANDONED [] SERVICE [] _ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-48 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21310 4. Location of well at surface 9. Unit or Lease Name 1283' FSL, 109' FWL, Sec.8, T11N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 2V-10 At Total Depth 11. Field and P°ol To be submitted when gyro is run, Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 109' RKBI ADL 25644 ALK 2575 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore i 16. No. of Completions 03/26/85 04/03/85 04/05/85I N/A feet MS LI N/A 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7575'MD 7455'MD YES [] NO E3XJ N/A feet MD 1400' (Approx) ,._ 22. Type Electric or Other Logs Run D IL/SFL/GR/SP, FDC/CNL, Cal 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 101' 24" 245 sx CS II 9-5/8" 36.0# J-55 Surf 3343' 12-1/4" 880 sx CS Iii & 390 sx :S I 7" 26.0# J-55 Surf 7544' 8-1/2" 270 sx Class "G" & 250 ix CS I ., 24. Perforations open to Production (MD+TVD of Top and BottOm and 25. TUBING RECORD' interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A ; . 27. N/A PRODUCTION TEST Date First Production t Method of Operation {Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I1~ I ~low Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE J~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED · MAY ;3 o 3.985 Alaska 0il & Gas Cons, Commission Anchorage Form 10-407 TEMP/WC11 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE · ,, 29. : I '30.., GEOLOGIC MARKERS FORMATION TESTS . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. N/A N/A · .. , . . · : 21. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/o ~j(~3~ ~J_~t..~ Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a Complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Oii and Gas COmpany Well History- Initial Report- Dally Prepare and submit the "Initial Rl~e~' on the flat Wednesday after a well is .spudded or wort<over operations are started. Dally work prior to s;uddlng st~ould be summarized o~ the form giving inclusive dates only. District ICounty. pan~ or bOrougrt Istete Alaska I North Slope Borough I Alaska Field I Lea~e or Unit . Well no. Kuparuk River IT.,e ADL #25644 2V-I0 I I Drill, Complete & Perforate Auth. or W.O. no. AFE 603996 Parker #191 API 50,029-21310 Operator IARCO W.I- ARCO Alaska, Inc. Spudded or W.O. begun IDate IHour IPrIor status if a w.O. Spudded 3/26/85 1315 Hrs. Coml~lete record for each day reported Date and depth as of 8:00 a.m. 3/26/85 3/27/85 -:: i: ::- 3/28/85 i-~-':_ ~-~ 3/29/85 3/30/85 thru 4101185 The above ia COrreCt For form preparation a~d dl~trlb~'tio~:' ~ see Procedures Ma~uaJ, Sectio~ 10. Drilling, Page~ 8~ and 87. 16" @ 100' Accept rig @ 0330 hrs, 3/26/85. NU diverter sys. 16" @ 100'IOIA,~ Wt. 9.7, PV 17, YP 20, PH 9.5, WL 14, Sol 6 NU diverter sys. Spud well @ 1315 hfs, 3/26/85. 12¼" hole to 1470'. 433', Assumed vertical 585' 1039' 1341' DD & surv , 3.9°,.N73.25E, 584.91 TVD, 4.97 VS, N1.49, E4.95 , 18.3°, S85.75E, 1029.01 TVD, 93.59 VS, N4.36, E93.56 , 27.6°, S85.75E, 1306.39 TVD, 211.81 VS, S6.52, E211.88 16" @ 101' 3230', (1760'), DD Wt. 9.8, PV 15, YP 16, PH 9.0, WL 12.5, Sol 7 DD & surv 12¼" hole to 3230'. 1493', 32.3°, S85.75E, 1438.09 TVD, 287.43 rS,- 12.14S, 287.56E 1985', 38.3°, S84.75E, 1830.48 TVD, 582.78 VS'~..:.~5.77S, 583.15E 2810', 37.6°, S88.75E, 2485.48 T~,. 1081.63'¥~8Z. 6~_ I082.47E 9-5/8" @ 3343' 3368', (138'), ND diverter Wt. 9.6, PV 17i YP 9, PH 10.5, WL --, Sol 7 DD & surv to 1650', circ hi-vis pill, POOH. RU & rn 76 jts, 9-5/8", 36#, J-55 BTC w/FS @ 3343', FC @ 3253'. Cmt w/880 sx CS III, followed by 390 sx CS I. Displ using rig pmps, did not bump plug. CIP @ 0200 hrs, 3/29/85. ND diverter. 3273', 37.9°, S89.75E, 2851.57, 1365.01, 86.39S, 1365.90E 9-5/8" @ 3343' 6437', (3069'), DD Wt. 9.5, PV 15, YP 12, PH 9.5, WL 7.8, Sol 7 NU BOPE &tst. TIH w/BHA, tag cmt @ 3188', tst csg to 1500 psi. Drl, DD & surv 8½" hole-to 6437'. 3545', 39.9°, S89.75E, 3063.25 TVD,-1535.80 VS, 87.14S, 1536.70E 4024', 42.4°, S88.75E, 3420.43 TVD, 1854.91VS, 87.83S, 1855.84E 4493', 42.8°, N89.25E, 3765.65 TVD, 2172.34 VS, 89.22S, 2173.29E 5272', 41.0°, N82.25E, 4344.16 TVD, 2692.10 VS, 42.61S, 2692.63E 6237', 37.2°, N82.25E, 5094.84 TV]), }293.50 VS, 39.13N, 3293.28E IDate 4/12/85 ITM RECEIVED 56.24~ Alaska O~i&l~a~ I~m~merllama~aa~la Anchorage i-CC ARCO Oil and Gas Company Daily Well History--Interim Inlln~ctlona: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed, Number all drill stem tests sequentially. Attach descriplion of all cores. Work performed by Producing Section will be reported on "Interim" sheets unbl final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled DUI but not less frequently tt~an every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly ~'or workovers and following setting of oil strin§ untd completion. District Field Date and deptl~ as of 8:00 a.m. J County or Parish Alaska North Slope Borough I Lease or Unit Kuparuk River ADL #25644 Complete record for each day while drilling or workover in progress 4/o2/85 4/03/85 The above is correct 4104/85 ISlate Alaska IWell no. 2V-10 9-5/8" @ 3343' 6919', (482'), TIH Wt. 10.2, PV 17, YP 14, PH 10, WL 8.6, Sol 8 Drl & surv 6437'-6919', started loosing mud. C&C, TOH & chg bit. TIH, broke circ& lost total rtns. Spot LCM pill w/o success. TOH to 4834', regained circ. Stage back in hole. 6550', 35.1°, N80.25E, 5347.58 TVD, 3476.25 VS, 67.22N, 3475.77E 9-5/8" @ 3343' 7575', (656'), Short trip Wt. 10.3, PV 14, YP 23, PH 9.5, WL 6.4, Sol 10 Fin staging in hole. Drl 6919'-7156'. Mud wt cut w/l/2 ppg, C&C well. Drl 7156'-7575', C&C well, start short trip. 7315', 34°, N79.25E, 5986.12 TVD, 3890.53VS, 147.66N, 3889.29E 9'5/8" @ 3343' 7575', (0'), C&C Wt. 10.2, PV 13, YP 6, PH 9.5, WL 6.8, Sol 9 Fin short trip, C&C, TOH. RU Schl, rn DIL/SFL/GR/SP f/7575'-3343' FDC/CNL f/7575'-~', RD Schl. TIH to cond well, no fill or circ problems.'~'~C~C~well, TOH, LD DP. / RECEIVED Alaska 0il & Gas Cons. C0nKnissJor~ Anchora,~e Signature ~ For form pr~p~-atio~-and d[s~'ri~ution-- - see Procedures Manual Section10. Drilling, Pages 86 and 87 JDate 4/12/85 ITM Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Firlel Report" on the first Wednesday alter allowable has been assigned or well is Plugged. Abandoned, or Sold. "Filial Rel~ort" should be submilted also when operations are suspenaed for an indefinite or aopreciaole length of time. On workovers when an official tesl is not re(luired upon completion, reDort completion and representative test data in blocks provided. The "Final Report" form may be used for rel:)orhng the entire operation if space is available. Accounting cost center code District Alaska Field North Slope Borough State County or Parish Alaska Lease or Unit JWell no. Kuparuk River ADL #25644 I 2V-10 Auth. or W.O. no. T t e AFE 603996 Drill, Complete & Perforate Parker #191 Operator ARCO Alaska, Inc. Spudded or W.O. begun IA.R.Co. w.t- 56.24% IOate 3/26/85 Spudded Date and depth as of 8:00 a.m. ,~I%/~ - 4106185 Complete record for each day reported 7" @ 7544' 7575', (0'), RR 10.3 NaCl/NaBr Fin C&C hole, TOH, LD DP. API 50-029-21310 Iotal number of wells (active or ~nactive) on this Dst center prior to plugging and I bandonment of this well I our I Prior s~atus if a W.O. I 1315 Hrs. its, 7", 26#, J-55, butt csg w/FS @ 7544', FC @ 745X~, C&C, POH. Cmt w/270 sx C1 "G" w/3% KC1, .7% D-19, .3% D-31 & 1% D-6. Start displ'g w/brine, transfer pmp caught fire. Extinguished immediately. Cont displ w/BJ, bump plug. CIP @ 0400 hrs, 4/5/85. ND BOPE, set slips, cut off csg. Instl & tst pack-off to 3000 psi.- RR @ 1200 hrs, 4/5/85. Chg rams to 7" & tst. RU & rn 174 Old TD I PB Depth '~ ~1// Kind of rig Rotary New TD 7575, (4103/85) Released rig Date 1200 Hrs. 4/5/85 Classifications (oil, gas, etc.} Oil . P. r0du~ing method I Type completion (single, dual, etc.) I Single - IOfficia! rese~oir namb(s) I ' Kuparuk Sands Wait on Completion rig - Potential test data Well no. Date i Reservoir Producing Inter~al Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T_P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature -~;~~ I Date For form preparation and di'tri'~uutio~, ---- ~ see Procedures Manual, Section 10. Drilling, Pages 86 and 87. 4/12/85 ITM Drillin~ Su~erintendent $ UB-S URFA CE DIRECTIONAL SURVEY ~-~] UIDANCE [~ONTINUOUS ~-~100 L Company Well Name ATLANTIC RICHFIELD COMPANY 2V-lO (1283' FSL~ 110' FWL~ S8~ TllN~ R9E, Field/Location K~~, NORTH SLOPE, ALASKA Job Reference No. 70459 Lo~fled By: MCBRIDE Date 23-MAY-1985 Computed By: STEVENS DIRECTIONAL SURVEY FOR ARCO 2V-10 KUPARUK NORTH DATES 22-APR-85 ENGINEER! MCBRIDE METHODS OF COMPUTATION TOOL LOCATZON: TANG~NTIAE- averaqed deviation and' azimuth ~NTERPOLATION: LINEAR V~RTICAL SECTION~ HORIZ, OXST, PROJECTED ONTO k TARGET AZZMUTH OF NORTH 89 DEG 27 ARCO AbRSKA, TNC. 2V-10 KUPARUK NORTH SLOP£,AhASKA COMPUTATION DATEI 24-'MA¥.,85 PAGE DATE OF SURV£¥! KELLY BUSHING EIaEVATXONI {,09,09 ENGINEERI MCBRIDE INTERPOLATED VALUE:5 FOR EVE:N lO0 FEET Or MEAISURE:D DEPTH TRUE SUBeSEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMU?H DEPTH DEPTH DEPTH DEG M~N DEG 0 O0 "109 O0 99 99 "9 O1 199 97 90 97 95 ~5 499 89 190 89 599 69 69 11 59 64 688 08 786 11 7 49 64 ti, 31 08 14 24 21 67 ,55 38 55 572.2! 38 38 oq1729 09 ]7 5R 06 180~'. 06 ]7 43 31 X~87:3! 37 28 84 X~66 ~4 37 2 19 2127-.19 36 2~ 84 2207.84 ~6 ~ 44 2288.44 36 20 57 236W,57 37 21 87 2447.~2 37 38 O0 2635 99 2926,99 37 40 O0 2715 ti 2606.il 37 44 O0 2794 12 2685.i2 37 44 O0 2873 25 2764,~5 ]7 34 O0 2952 8 ,1 3 ~9 28 O0 ~106 61 2~97.6! 40 46 O0 IiSi 58 O0 ]255 53 3146.53 42 30 O0 3329 26 3220.26 42 30 0.00 tO0 O0 ?00 O0 300 O0 40O O0 500 O0 60O O0 700 O0 699 800 O0 797 900 O0 895 1000 O0 90~ liO0 O0 t08 200 O0 ii7 300 1261 I,oo ~00 00' 1442 I~00 O0 i5,4 O0 O0 iSn3 1800 O0 168 {,900 O0 175[ 2000 O0 1838 oo O0 1996 2300 O0 2075 2400 O0 2155 50~ O0 2236 ~60 O0 2316 2700 O0 ~397 2800 O0 2477 2900 O0 2556 Ooo 3100 3200 3]00 3400 3500 3600 3700 3800 3900 VgRTTCRb DOGI~EG RECTANGUbAR COORDINATES HORIZ,:~ DEPAR'rURE:~ SECTION SEVERITY NORTH/SOUTH EAST/NEST DiSTil,' AZIMUTH FEET DEG/tO0 FEET FE~T F~T, DEG MXN 0.00 0 30 15 $ 67 11 32 2~ 78 3 7{, 61 09 88 9 121 ~3 6~ 356 96 ~2 542 44 S 84 Il. E 603.91 S 83 48 E 664.85 $ 83 3i E 725,40 S 83 3 E 785 54 ~ e2 34 E 844 88 $ ~ 45 E 903 S 8 08 48 E. 114 45 $ g9 26 E 1203,53 S ~9 2! ~ 1264,68 S ~9 0 E 1325,96 s 88 47 E 1387,07 S 88 46 E 1449.31 S 8 29 · 164 $ 88 32 £ 170g,g3 S88 39 [ 1776,35 O0 O* 50 57 3 79 3 23 1 69 36 0 54 0 4~ 0 26 O4 0 67 0 O0 N 0 7O 'N 247N 6, N 8 O1 ~ 0 0 O0 E 58 E 40 95 E 62 000 N 00E 76 N 22 0 N 47 ' i4 N 60 6 N ,70 4,a'E 61 N '76 45 E i4,79 88,45 89, N 80 0 '3,14 ~ ~ 68 N 3 9t 83 48 121. 121,20 08 159, E 159,49 22 ' .,, ,.o. ,,,.oo 542, E 543,~3 ' 87 39 E 28 17 87 19 S 604 2i 604 86 59 $ 906 ~ ~ 963 39 ~ 965 Ii45 ARCO AbASKA, ZNC, 2V'10 KUPARUK NORTH SbOPE, ALASKA TRUE SUB-SEA COURSE MEASURED VgR?ZCAb VERTICAb DEVIATXON AZZMUTH DEPTH DEPTH DEPTH DEG MIN DEG MZN COMPUTATION DAT~I 24-MAY'B5 DATE OF SURV£¥~ ~2-A~R-85 KEGb¥ BUSHZNGEbEVA~ONI ENGIN£ERI MCSR~DE iNTERPObATED VALUES FOR EVEN ~00 FEE~ OF MEASURED DEPTH VERtiCAL DQGbEG RECTANGUbAR COORDINATEs HORZZ,:i DEPARTURE SECTION SEVERITY NOR?H/SOUTH EAST/WEST DI$T,:, AZIMUTH PAGE' ~o~.oo 4000 oo 34o3 o8 4t00 O0 3476 4200 4300 440O 4500 4600 4?0O 4800 4900 O0 3550 O0 O0 O0 3769 O0 )842 O0 3915 O0 3989 O0 4063 358 3733 98 3806 4~ 28 i08° 954 95 4 56 91 43 ~2 98 42 ~ 42 42 28 42 15 5000 O0 4137 50 4028 5i00 5~00 5300 5400 5500 O0 4514 5500 5700 5800 5900 415~ O0 4212 O0 4287 O0 4362 O0 4418 O0 4591 O0 4669 O0 4747 O0 4826 ,50 09 4178'0 9 4 47 4253 7 40 43 4~20 40 14 94 4405 39 5~ 77 4482.77 39 3' 2~ 4560.23 38 50 28 4717,28 37 32 6000 O0 4905 81 4?96 6'00 O0 4985:5t 4876 6200 O0 5065.06 4956 6300 O0 5144.77 5035 15 O0 5 ,85 5i9~ 6600 O0 5 87.48 527 6?00 O0 5470.03 5361 6800 O0 5553,38 5444 6900 O0 5637.72 5~28 51 37 2 06 37 5 ?7 37 0 95 36 14 85 35 44 48 34 42 03 34 38 32 58 72 32 7000.00 5722 7i00.00 5806 7200.00 5890 7300.00 5974 7400.00 6057 7500.00 6140 7575,00 6202 i 5613,41 )2 11 5~.83 32 41 80 .80 33 5 29 ~865,29 33 45 38 5948,38 33 50 44 603~.44 33 50 74 609 ,?4 33 50 89-34 E 19 ],44 .; 89 E 204 8729 ~ 2115 ~6 7 ~ 2~3 N 84 tSE 2 83 3] E 2 ~8 83 32 E 2454 83 33 ~ 2520 96 83 25 ~ 2586 98 82 35 ~ 27 68 8219 ~ 2846 '9 N 8~ 1 ~ 2~ 08 81 45 ~ 2-,~ 78 8 3 g 30 69 8 8t ? E 3335 65 81 to 80 59 i tTM 45297 8046 ~ 3510 I I ~0 13 ~ 3565,65 79 3 ~ 3673' 79 46 E 3725.~4 80 t5 E 3778.42 80 18 ~ 3832 04 80 2~ E 3883 40 ~0 24 E {94t ]5 80 24 E {996 ]4 80 24 E 40{1 58 37 55 52 03. 10 0 28 0 85 I 6o 1,10 0 65 o 0 0 3~ 42 40 47 49 73 57 51 61 78 59 O0 O0 O0 89 64 57 2454 2 E 1846 0 E 1914 26 £ 1982 20 E 2050 2185 41 E2253 32 76 £2455 95 '8 81 $ 8 E 6'[ 42 $ 88 .0 E: 6 $ 2782 86 034 52 ~ ~095 98 £ 2783 82 g 2846 39 6O $ o, , ,, II i 83 $ 89 E 3215 ~ 3155,68 89 , 46 9 ~ 3275 ~ 3275.84 69 89 57 3 3335 3335.75 93 12 3566,35 103 ~ 3619 50 ~ 3620,98 113 367227 3674.03 123.5i N 3724.52 ~ 3726.57E 8786 ~I 132.76 ~ 3777.32 3779.65 141,96 3830.85 ~ 3833.48 87 ,,,,.o, 160 3939 ~ 3943,25 169.69 : 3994.69 ~ 3996.49 176,64 4036,0? ~ 4039,93 N ARCO AbASKA, TNC. 2¥-10 KUPARUK NORTH SLOPg,A~ASKA COHPUTATION DAT£1 24'MA¥-85 DEPTH DEPTH 0 oo O0 99! O0 O0 2 o0 oo 41) O0 4905 O0 5?2 O0 620~ O0 1729 9q 2526 08 )294 5O 4028 81 4796 lO00 000 3000 4000 5000 000 000 7575 VERTTCAb DOGbgG RECTANGUbAR COORDiNATEs HORIZ ~DEgAR~URE 0 O0 88 59 603 9i ~1.55 8 37 0 O0 314 0 54 0 O9 0 28 ° 0 1~00 0,00 0;00 0 0 ~ 88,45 68 280 ,604,21 6040 76. i ~ 86 E 1204.32 1206, 3 _ 8 1844~72 1846~ 87 2521,36 , 3155~50 . V 10 KELSY BUSHTNG R~EV ~U;ARUK ZNTERPObATED VAbUE~ FOR ~VEN ~00 FEET OF SUB-SEA OEPTH COURSE VERTZCAb DOGbEG RECTANGUbAR cOORDINA~E~ NEASUR~D VERTICAb VERT~ A AZIMUTH SECTION SEVERITY NORTH/SOUTH ~DEPTH DEPTH DEPT D~G MIN DEG ~YN FEET DEG/iO0 ~EE~ 0 O0 0 O0 -109 O0 0 0 N 0 0 E 0,00 O, O0 0 O0 N 0 O0 E 0 ~ooo~ ~o~ ~oooo~~~ ~,~ o,~o~ o ,~ ~o, o~ ~o~ oo~oo oo ~~~ ~, ~ ~ ~, o ~ ~ 309 05 309 O0 200 O0 I 16 ~ 36 10 ~ ~ 44 0 409 08 O0 ~00 _ _.. , ,9 2 E 6 O0 5 92 E .o9 98 ?o9 oo 6o0 oo ~ N 67 2t E , 52' 13 ,N 95, 43050 - E. 234, S 92 46 610 ,7 2466 15 2209 O0 ~ 82 23 683 96 0 46 684 S 1331 47 i942 94 N BT ~ 2126 59 81! 60 809 O0 ?00 O0 ,o~ ?o ~oo~ oo ~oo oo oo ~,oo oo t300 O0 3Z 30 70 ~00 ~8 4~ 2~0~ O0 90 36 O0 2000 O0 ~.,o ~o~.oo ~oo.oo 3603,69 3009,00 2900.00 39 7 . t5 ]t09.00 3000.00 40 &O0 .01 ~409.00 ~0 .00 42 29 4143.98 3509.00 ~40~.00 42 43 4280.~2 ~609.00 SO ~00 42 46 4416,65 ~709~00 ]~00~00 42 59 455S,44 SS09,00 STO0,O0 4S It 94 :~09.00 PT !RIZ..DEPAR?URE ' DEG, kilN: O0 N 0 0 E ARCO AI.,A.SKAw I:NC, KUPARUK NORTH SLOPEC, AIr~ASKA MKASUR~D V~R?IeAb VER Ab D~VI~TION A~IMU?H 4690 47 3909 O0 3900,00 42 54 400 O0 1 5229 15 4309 049420 0 oD ,oo OD $622 33 4 0 0 4~0~ 0 4500 5500 O0 32 23 ,76 6009,00 00,00 33 746.,15 6109,00 6000,00 33 50 7575.00 6202.74 6093°74 33 50 COMPUTATION DATEi '24'MA¥'95 KELLY BUSHIN b VATION~ 109000 Fl ENGTNEERI:MCSRIDE ~ . O6 64 49 83 529 2313 2~71 92 44 ; 2 57 8223 E 3082 N 8~ 0 ~ 31 .OB N 81 5t E: 3309 N 9 4 ~ 33 N gO 39 E 3524 N 7~ q 79 39 ~3773719 2 N ~0 ~5~ 0 0 32 0 1.9 0 52 0 0 35 o 0 0 1.,18 0 6 o 0 o 0 4 26?2 31 r 26?2 O E 27~8 ~004 ~l ~ ~004 23 80 N 3092 20 E 3092 7~ 3454 3524 ' 52 I 0 122 22 i ) N 80 )4 ~ 3843,79 0,027 14~ N 90 4 I~ 3909,;2 ~. 0 15 N 80 24 £ 3975, 2 ,00 166 N 80 24 ~ 4037,58 0,00 176 ARCO AbASKA, ZNC, 2V-lO KUPARUK NORTH SLOPE,AbASKA HARK~R TOP UPPER SAND BASE UPPER SAND TOP bOWBR SAND BASE bOWER SAND TOTAL DEPTH C~MPUTATXON DATES 24-MAYe85 M~ASURED DEPTH ~ELOH KB 9059 O0 73B2 oo 75 O0 SURFkCg, LOcATXON . TI~N ,R9£, U OR GIN= 1283' FSL, 110' rwb SEC TV RECTAN~ULAR~,COORDXN~TE$ FROM KB SUB-S£A NORTH/SOUTH E~ST/WEST 597 .04 5702.04 6103, 5994, , 6093,74 ! 4. 3944, ! ~,$1 , ~$ 4036, ,64 ARCO AbASKA, ~N~. 2v-t0 KUPARIlK NORTH SLOPE,ALASKA MARKER TOP UPPER SAND BA$~ LOWER SAND TOTAb DEPTH C~MPUTATXON DATE; 24-MAY-B5 ************ 5TRATZGRAPHIC BELOW KB 7105 O0 O0 SUMMARY ********~*** 1283' sue.s FROM KB 5702'.~4 5802.72 5933,43 5994.06 6093.74 10 .t $202 PAGE lOg. OO !44 25 N 3844'.34 E .. , U FINAt, Wgbb bOCATION AT TDI TRUK SUB-SEA MEASURED VERTX~AL VERTICAL ~EPTH DEPTH DEPTH 7575,00 6202.74 6093.74 HORTZONTAL DEPARTURE 4039.93 N 8? 29 E SCHLUMBERGER B I RE C T I ONAL SURV. E Y COMPANY ARCO ALASKA INC NELL 2V-lO FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOED 22-APR-SS REFERENCE 0000?0459 269. WELL NAME: 2V- 10 SURFACE LOCATIO:~~ '1283' FSL, 110' FI,~, S8, TllN, ./E, UM VERTICAL PROJECT ION -2000 .... 4-¢.4-L.LLi--.Li -..~.: --¢4-4-.~¥-++- --~:-i...+...~...;t-..!-?-5-..~:... ,..4-:?..-¢..?,...¢-¢.-¢-~. ........ ......... ........ : . : : t : : : : ........ : : : . I : : : : .... : : : , : : ; . : , : : : : . . : · : : ; ~ : : : : ....... -'?'?i'"f'-f'?-...-?~ .... ....... -.L.L.L L.L.J....L.L--; .... 2OO0 · --~---¢--~--..-."--.i--. ¥-~--.-~-- ¢- &.!...i...~4.-~--i..-L.; .... ¥-¢-?:-.~-F+-+---¢.-~ .... .... T..?T..:..-t-..?..-T.-?---? .... .... --¢-4--.¢-4-+-¢.4.-.~ .... ~000 4000 SO00 '-~-.-~...:z-~-4...;...?;...i-.-1-+..¢-~.i.-1-.~.4...: .......... ~.+.;..-;...l...i...,'...~..-;-... "'+.--: -75-5-'t'"!"5+'5't"'i"-~'-i-'5'i-'i'"~"+": ..... +'"'i'"5'i"~'"i'"i'"i'''~ :::::::::::::::::::::::::::::::::I ::~-.:~:::~:::i:::t'::;::'i:";:'";:-:::::::::::::::::::::::::::::::::::::::: -.:...,:--L-L.L..L.~...,L-~ ..... ?,...;...L.Ii..~...;,..L-; ..... 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"T"T'T , "F-:-..?'"? .... ~ . . ~ ..... : 't'"~'"':'"';"': .... : non ~: ...... l li . i:::~:::i:i::::! ......... "'?'":'"';".-"-"~'"~-"~'"?'"; !::::::,.::::~:::::'.i:::::':i._!.,:. ........... :..i -'~'-5'+'-5'!---5-?'-i"! KS-?--~---:---!--+-~ ....... : ....... ~--'-~ .... ~ !.+.4-': --.-. ....................... ~ "'-'-', ......: ~'"~:'+-?----+",,.... .... .... : , . . .: ............ ~:~ .... '"~"'r-!'-';"! ...... o ...... :. ,.- , : - ~'- i-!~ : ,.+: ~ .... ,...~...~..~-..~~::~~ ~+,..-....+, ? ........ ~ .................. ..... , ................................... ~.~ .................. .... ~ ................ ~. ................................................... , . ., ........... :, ....... ~ o ¢-¢--.---~--4---~.--:-.--~ ....... l...:...--...~ ............... :, ....... ~ ....... ~ ........ ~ ....... : ....... , .... 1 ...................... : ........ ..T.........:...~: ............. : o i-.-.~ ....... ~..-~--4-.-; ....... ~-.4-..1 .................... ~....:--~ ........ o ~4---~---~-+-i--~--¢~ ---~---~..--i---i---~-.~---!.--:---~: =================================== !: j: i !:' ' ::::::::::::::::::::::::::::::::::::: LI., - - - : ~ : ' : i ill[ , ' ....... : ~ ' ' - i '-t PROJECTION ON VERTICAL PLi::INE 89. - 269. SCALEO IN VERTICAL OEPTHS HORIZ SCALE = 1/lO00 IN/FT WELL NAME: 2V-10 SURFACE LOCATIOI< '~1283' FSL, 110' FWL, S8, TllN, ,E, UM HORIZONTAL PROJECTION NO~TH 4000 gooo 1ooo -tooo REF 0000704S9 - T'T.: ".:'-t-T"T-T"T - ...... '"T"":'"T'"T'" i'"~"+"~ ...... ~ . 1 · :::::::::::::::::::::::::::::::::::::::::::::::: ~: i";:i:::i':;~:':!':i ...... ::::;============================================================== ....... :;:: :.:: ...... :::'':'::f~.; ...................... :' L:: .......... : ........ . : : '~ .......... : ...... ..' ......... ; ..... i ............... f ..... ..... ---:;---~---:---½--4'---~---~--;--~---: ~ ~ ~ ~ ~ : * ~ ......... : ~ : * * ~ ' :: . . .: ........ ~ ....... f...~ ............... SOUTH -4000 -2000 - 1000 0 ] 000 2000 9000 WEST 4000 SO00 6000 EAST Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Reports and Materials to be received by: Date Required Da'te Received Remarks' · , Completion Report ~. ~ ~.. ~_. ~, ._~~ We~ ~o~:¥ Ye ~ ~-,~-~~ ..~..~. Samples ~u~ ~o~ ~a -pt ...... , ~1~ ,, Core Chips ,.~~~ Core Description Registered Survey Plat ,,, / Inclination Survey _ ports Production Test Reports , , . , ,/ ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 3, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2V Pad Wells 9-16 Dear Elaine- Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/LI02 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany PHASE II-AS-BUILT WELL~ ' 'hru 16 · I0 ·12 W=LL 9 1 ,966,048 36 Lal X: 508,701.86 LOOg ,49°5§:46.]6 Pod Elev. 79.7 0.$ E~ev. 74.C I10' FWL I,:345' FSL WELL I0 Y= 5,965,988.4l Lot. 7C°19'05 ~.6~" x: 508,702. I0 -cng !49°55'46,356" Pod Elev. 79 6 0 G Elev. 74.C. I10' FWL 1,283' FSL WELL I I Y = 5,965,92-8.39 Lct 7,~° 19'05 £70" X: 508,7C2.06 Long i4-3055'46-¢'9" Pod Elev. 79.8 3.G. Elev. 74.C 109' FWL 1,223' FSL WELL 12 Y: 5,565,~J68.43 Lat. 70°19'04.68i'' X = 508,702.16 L2ng. !49055' 46.C58" Pod Elev 80.0 O.G Elev. 74.0 109' FWL 1,163' FSL WELL 13 Y=5,965,868.44 Let. 70°19'0468 X: 508,4i 1.94 Long. ~49°55'54.52'-''' Pod Elev. 79.9 O.S. Elev. 73.2 181' FEL 1,16:3' FSL WELL 14 Y: 5,965,928.44 Lot. 70°i905.2-z4'' ×: 508,4 I ;~.00 Long. 149¢55'54 52-4'' POd Elev. 79.9 O.G. Elev. 73.2 181' FEL 1,223' FSL WELL 15 Y = 5,965,988.35 L(]t. 70° 19'05.863" X: 508,412-.01 Long. 149°55'54 52!" Pod Elev. 80.0 O.G. E!av 73.3 180' FEL 1,283' FSL WELL 16 Y: 5,966,048.45 Lat. 70°19'06 454'' '~(: 508,412.01 Long. 149° 55'54.519'' Pcd Ele¥. 79.8 O.G. Elev. 73 180' FEL 1,343' FSL ", LOCATED IN '~ROTRACTED S788, TIIN;''r~'/4 ~, -~ (/.-,'(;~r'/- '¢,~. 4Z80'.5' ! .~,~ LOCATION ~-_-' '.,_"~_~ENTS 2V NORTH & 2V MID. '' '~ LICENSED TO PRAC?IC:E LAND SURVEY'NG IN THE STATE OF P"'~k~k ¢ i~ i ! ..~, MY u,RECT SUPERVISION AND THAT ALL DETAILS / / hm I/ 11 Ii,mi CONDUCTOR AS- BUILT ~HIS'"~ )I~N" ~ *WI MUll LOC~T~ONS ARCO Alaska, Inc. · Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 "~:ETURN TO' ARCO AL.A£KA, INC. ATTN' R I:E C; O F< I) ,? CLEF~i< A'FO-tt tSB P.O. BOX t00360 AI~CI'iOi~<AGE, Al< 9951 0 i-I:~AN£HII'TEI) HER[':'.WITH ARI!:'. I'HE D A T 15 ' 0 _) -. (.>... '~ -.. ,-~" .~'::' 'FRANS'MIT'FAI_ NO · 51 70 I T I:: n.S, F"I... E A,S'E A[;I<NOWL. EI)GE '::['.'".Ci.T. IF'T AND RETU i;~l::'r:.-'.N HOLE L.I~' TA =CHLL!Hr~EF<GER tQ 3 03-30-85 ,¢U'-8 03 o -,~ -.,_ 8'- 8..:, -2t J-9u'/ RN ONE ,."7I(;NliF. D C, OF'Y OF Ti--II&' '[RAN..?MIT'FAL, i~B--'t I,/ ..24-1,.~'"-- ]B-J .~B-t 6--04-06 85 F E,.~ F' I... U ,.', I... ]; ,? l' I N [; (ONE COPY OF lEACH) R t. JN :.".: t '::'"~ ...,,.. 'i O O-' 1 0 81 5 5 R r.: r.:.,,.-;, · n L./ 'Il' I ~]~../V RUN ~'i ~9 ~'.:o · ,-.. 5-6963 '5 ",- ,,.' ..... . I,,I=F.,,. ?~).....:>o.. RLli',/ ¢:i 36"'7 "''' ,'~,-,='z .. o . .., - o v/.,,.~. 5 I::: I.".'] F :,",:'? 02 '?'? RUN ~"¢'1 3t t6,5-7(')38,5 REFZ:~:Tf.~'2.'?t -- ,,,..~ · 'l ' ".H. RUN :,":1 -z3.78 .':~-',"'",;'03.0 F, EF'..-TOSO3 RL/N :,"F t 399'2.0-8463. O RIEF":,",:TO25 t RUN :.":t S38t . 5-"/'846.0 F::EF'~:'?0276 · A C K N C'I W 1._ E I) [~- [-" D - ;; C.. E l F'T 'AE DRIL.! ING CLJRRIER ! .... ~',_'_il-.l N,~ T C) N I IZ V R 0 N /'i 0 Ii-,' ;[ ! & M .:~ I: ;" L. EIN: K ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 15, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the April monthly reports for the following wells: 1Q-1 2U-10 2V-12 3B-16 9-28 1Q-2 2U-11 2V-13 3-16 (workover) 17-14 1Q-16 2U-12 3B-1 4-32 L1-1 1R-5 2V-10 3B-2 9-16 (workover) LJ~-9 2U-9 2V-11 3B-3 9-27 L2-28 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU6/LI06 Enclosures Alaska Oil & Gas Co,is. Commission Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanlicRichfieldComl~anv , ~" ~-~, STATE OF ALASKA ~,. ALASKA L _ AND GAS CONSERVATION CC .vllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [~X Workover operation [] 2. Name of operator ARCO Alaska, inc. 3. Address P, 0. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 1283' FSL, 109' FWL, Sec.8, T11N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 109' RKB 6. Lease Designation and Serial No. ADL 25644 ALK 2575 7. Permit No. 85-48 8. APl Number 50-- 029-21310 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2V-10 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. April ,19. 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1315 hrs, 03/26/85. Drld 12-1/4" hole to 3368'. Ran, cmt, & tstd 9-5/8" csg. Drld 8-1/2" hole to 7575'TD as of 4/3/85. Ran OHL. Ran, cmtd, & tstd 7" csg. PBTD = 7455'. ND BOP. NU tree. Secured well & RR ~ 1200 hrs, 4/5/85. Arctic packed 4/14/85. 13. Casing or liner rgn and quantities of cement, results of pressure tests 16" 62 5#/ft, H-40, weld conductor set ~ 101' Cmtd w/220 sx CZ II (approx) 9-5/8" 36 O#/ft J-SS BTC csg w/FS ~ 3343' Cmtd w/880 sx CS III + 390 sxs CS I 7" 26.0#/ft, J-55, BTC csg w/FS ~ 7544'. Cmtd w/270 sx Class "G" cmt + 250 sx CS I. 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/SFL/SP/GR f/7575' - 3343' FDC/CNL f/7575' - 6860' Cal f/7575' - 5000' 6. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. /~0/~/~ ~~ TITLE Associate Engineer DATE ~'~'~-'/~'2)'~z~' SIGNED / ............ NOTE--Ftepo~ on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 JMM2/MR03 Submit in duplicate MEMORANDUM TO: THRU: State of Alaska ALASKA OIL AI~D GAS CONSERVATION CO~-{ISSION Lonnie C. Smith Co~issiOner FROM: Bobby VosterF-z~-i.~-- SUBJECT: Petroleum Inspector DATE: April 12, 1985 FILE NO: D.BDF 26 TELEPHONE NO: Witness BOPE Test on ARCO' s 2V-10, Sec. 32, T12N,R9E,tR-~, Permit No. 85-~J~. ~ Monday, Apr~il 8,. 1985: ~"Vne BOPE test began at 10:45 am and was conCluded at 11:45 am. As the attached BOPE test report shows, there was no failures. In summary, I witness the BOPE test on ARCO's 2V-10 Attachment 02-00IA(Rev. 10/79) O&G ;;4 '5/84 / STATE OF ALASKA g/~ASKA OIL & GAS CONSERVATION COMHISSION B.O.P.E. Inspection Report Mud Systems Trip Tank Pit Gauge Flow Monitor G~s Detectors ~ P era t or /Z~/~~ ' Drillin8 Contractor Location, General ~/~ Well General Housekeeping~__Rig Reserve Pit p/d Ri Audio Visual Test Pressure BOPE Stack Annular Preventer / Pipe Rams ~ Blind Rams / Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: Failures Well -~-- ~" /Z~ Representative Representative ACCUMULATOR SYSTEM Full Charge Pressure Pressure After' Closure psig psi~ Pump incr. clos. pres. 200 psi~ - Full Charge Pressure Attained: ~ N2 /7/~ ,~E3~ /~ /~S'O psig Controls: Master V~ Remote~f~ Blinds switch cover~/~ . Kelly and Flo~r Safety Valves / Upper Kelly / Lower Kelly. / Ball Type / Inside BOP. / Test Pressure Test Pressure Test Pressure Test Pressure Choke Manifol~~ Test Pressure No. Valves /~ No. flanges 3 ~ Adjustable Chokes ~ · , Hvdrauicall~ ed choke / min.~ ~sec. mica_sec. Test Time . ,' hrs. Repair or Replacement of failed equipment ~o be made Within ~ days and Inspector/ Commission office notified. Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor MEMORANDUM TO: TN.~U: FROM: State of Alaska ALAS~IL AND GAS CONSERVATION COMMISSION C. V rton OATE: April 3, FILENO: D.BHL.21 Lonnie C. Smith Co~issioner ~( ~o~ ~o: Ben LeNoman Petrole~ Inspector 1985 SUBJECT: Witness BOPE Test on ARCO' s Kuparuk 2V-10, Sec. 8, TllN, R9E, UM, Kuparuk River Unit. Wednesday, March 17, 1985: I departed my home at 1:50 pm for a 2120 :pm:'sh0w~p and--3::20 ~m departure via Alaska Airlines, Flt. ~57 for Deadhorse, arriving at 5:00 pm. Weather: -12°F, calm, clear. Thursday, March 28, 1985: Testing of iow pilots, SSV's and SSSV's ~.~ ~PF~ w~li'S ~egam a'~ 8:00 am . . . Friday, March 29, ~_985: . . . and was completed at 11:00 am, the subject of'a Separate report. BOPE tests on ARCO's Kuparuk 2V-10 began at 2:30 pm and were completed at 4:30 pm. BOPE inspection report is attached. Saturday, March 30, 1985: Testing of low pilots, SSV's and SSSV's on-~F .:~i-~elI~~ b~a~ ~-~ 7:30 am . . . ~ril 1, 1985: and was completed at 1:00 pm the su e~- a sePara~ repo~t~ ' I departed Deadhorse via Alaska Airlines, Flt. #56 at 5:40 pm arriving in Anchorage at 7:30 pm and at my home at 7:50 pm. in s~ary, I witueSsed successful BOPE tests on ARCO's Kuparuk 2V-10. Attac~hment 02-00IA(Rev, 10179) O&G 5184 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Z ~:- ~,,~,~;~,~ ~ Operator ~ ~,~ Well ~,~,¢.,ZU/~ ..~ W--W ,~ Location: Sec ~ T//~R~ M ~//'~ Date ~~qC~ ~ ~/ /~'~'~,~ Representative ~'~'~,~' Drilling Contractor ~~~ Rig ~]/~/ Representative Location, General ~)/~ Well Sign a~/~ General Housekeeping~/~ Rig ~ Reserve Pit ~_ Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors Test Pressure BOPE Stack Annular Preventer Pipe Rams ~,% ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: psig ~ ¢DO~ min ~R sec. .~ min~--~sec. N'2 ~~ ~~ ~oo/~~psig Controls: Master ~ Remote ~Blinds switch cover ~~ Kelly and Floor Safety Valves Upper Kelly Test Pressure Lower Kelly Test Pressure Ball Type Test Pressure Inside BOP Test Pressure Choke Manifold Test Pressure No. Valves /-~ No. flanges ~¢~ Adjustable Chokes ~ Hydrauically operated choke Test Time ~ hrs. Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: Failures Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified. Remarks :' '"~-..~" ~ ,~'~ ,~ ~' .,~ .' ~ ~~ ~~ ~,~_~~~ ~.2~,~'~,~ -- Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector ,~_~,~/ .,~. _,~ ~.,~,.~,~/ March 19, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 ~nchorage, Alaska 995!0-0360 Re: Kuparuk River Unit 2V- 10 ARCO Alaska, Inc. Permit No. 85-48 Sur. Loc. 1283'FSL, !09'FV.rL, Sec. 8, TllN, R9E, UM. Btmhole Loc. 1322'FSL, 1082'FEL, Sec. 8, TllN, R9E, %rM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above' referenced well. if coring is conducted, a brief 'description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be subm~_tted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of Ithe State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Ke~zn Kuparuk River Unit 2V-10 -2- March 19, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very .truly ~v?urs, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY OP2DER OF ~E CO~MISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office Bo,~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 7, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2V-10 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2V-10, along with a $100 application fee ° Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat ° A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment Since we estimate spudding this well on March 18, 1985, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, JBK/LST/tw PD/L55 Enclosures 1985 Cons. C;or~lmjsslo~ Ancl~orag~ ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany STATE OF ALASKA "-~ ALASKA falL AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL 20 AAC 25.0O5 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL []X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE E~X MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 /-,-~ ~'~,~ 4. Location of well at surface *' (. y/~,'- I 9. Unit or lease name 1283' FSL, 109' FWL, Sec.8, TllN, R9E, UM ~,, A~;'"..~, ~ ~/~ Kuparuk River Unit At top of proposed producing interval -¥~ '~:~}~ ~ ~ * ~] ~0. ~ell number At total depth ~ ~ ~ ~C~-' ~7~~ 1322' FSL, 1082' FEL, Sec.8, T11N, R9E, UM ~0~°~ ~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no~c' 0~ Kuparuk River Oi 1 Pool RKB 109', PAD 78' ~ ADL 25644 ALK 2575 ~ ~ ~2. ~ond information {see 20 AAC 25.025) Fe0era] Insurance Company Type Statewide Surety and/or number ~8088-26-27 Amount $500~000 13. Distance and direction from nearest town 30 mi, NW of Deadhorse 16. Proposed depth (MD & TVD) 7589' MD, 6184' TVD 14. Distance to nearest property or lease line miles 1082 ' feet 17. Number of acres in lease feet +2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 270:~ KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 39 Ol(see20AAC25.035 (c) (2) 3104 21 SIZE Proposed Casing, Liner and Cementing Program Hole Casing Weight 16" 62.5# 9-5/8" 24" 12-1/4" 18-1/2- 36.0# CASING AND LINER Grade H-40 J-55 HF-ERW 7" 26.0# J-55 HF-ERW 22. Describe proposed program: CouplingI Length Wel~ 80' BTC~ 3328' BTC/ 7555' SETTING DEPTH MD TOP TVD 36' 136' 35' I35' I I 34' I ~ 34' t15. Distance to nearest drilling or completed V-9 well 60' (~ surface feet 18. Approximate spud date 05/18/85 M D BOTTOM TV D 116' I 116' 3363' 12912' I 7589' I 6184' I psig@ . 80°F Surface psig@ 6029 ft. TD (TVD) QUANTITY OF CEMENT (include stage data) ± 200 cf 900 sx AS Ill & 350 sx Class G 300 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7589'MD (6184'TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" ~m~J surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig ( psi for annular). Expected maximum surface pressure is 2703 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to~si prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2V-10 will be 60' away from 2V-9 at the surface. CThere are no clo2er wellbores amvwhere,downhole, .Reservepit fluids will be disposed of by ¢.v-/~.~t/j,. ~7~,~,~,4~, ,,t~-ys,_ ~'y~$¢4o,.- ~¢,#-~...~tu)~~ . pumping them ~own one /" x ~-~/~" annulus o~ ~hfs we~l,' me /" x ~-~/~' annulus will be left with a non-freezing fluid during any interruptions in the disposal process, (see attached sheet), 23. I hereby certi/f,y-~at the foregoing is true and correct to the best of my knowledge // The space b n'~se CONDITIONS OF APPROVAL Samples required []YES ~NO Permit number APPROVED BY Form 10-401 Mud log required I--lYES ~NO Directional Survey required I APl number ~YES []NO J 50- O 7--- ~ "Z,'/,~/ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE March 19: 19~5 by order of the Commission Submit in triplicate PERMIT TO DRILL 2V-10 The well will be completed by the workover rig using 3-1/2", 9.2#/ft, J-55, 8rd, BTC tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage -- L i i WE:¸ ' [.oc,~ 283'~ FSI..,' .109' 1320', FSL,~ ~0e' . .: j ; ! · · i i ;' T : · I NO TE*~'-'VEt:L---PATHS- J_ , *' I i · , I ' I -23To +,., . * ! · I.' ! , . ! ! ' ] .'__ ¥ 16"-2000 Psf Tankco s~:artfn ?ankco qufck connect aSsy. 16" X 20" 2000 20" 2000 ps{ d~]?~9 Spool w/]O, S;de **'~ 1~, baT~ valves, hyd~aul~ca]]** . ~/et~. ~o rese~e p~t. ~ actuated. ~ ,, P~even~e~. ~cal ]y upon 20" 2000 ps~ annular Preven=er. Upon fnftfa~ fns~alTa~fon'close annular P~'eventer verffy (:hat halt VaTves /~ve OPened property. and CTose annuTar preventer and blow aft throug~ dfverter ?~nes eve~ 72 hours. C]Ose annUZar Preventer fn ~e event ~aC gas or fTufd RECEIVED Alaska Oil & Gas Cons. Commission Anchorage 6 5 i 2 4. F~C::C3~ C:~ NCOC I;~:'I~T. TIE AC, C:E3~ABLE LDI'~ LII~T J3-~/,8' ~ STACK TEsT FIJ_LY ~ SF_AT TEST PLL~ IN ~TH i~II~G JT ~ RLN IN LC~ S~. L2NE VAL.~:/.S ADJ,~ENT TO BO> ST AOC AU. ~ 4. Pii:~DD.I::~ LIP 'TO 250 PS! AND I-O.D FCR IO 14ZN. ~ I:f~SD.l~ TO 3,C:CID P$~ AND I-IDI. D ~ ID M2N. DI.EF.D ~ TO 0 PSI. L~IhE VALVES. C:L~ TCI:~ PIP~ ~ AND ~ VALVES CIN KILl. AND ~ LINE~. WiTH A ~ P~:2 LC~ ~ 3000 P~! I-rJGI-L TE~' A.~ 2N 8. C~ TCP P]:I~Z. P~ AND CLC~ BO'm'13Vi F:'Ii~ P.~ TE~T I~Fi'C~ PIPE RANS TO 250 PSI At~) ~ I0. CLt~ BLIhD RAIv~ AhD 'I~T TO ~50 P~! AhD i~I. I~FCI_D A~D .LII~.S ~ FLLL CF RI.UID. ~T Ali. VALYE~ IN ~:tILL]h~ I:~ITI~ 12. 9-?..~ S'TA~IP~ VALV~ KELLY. ~O~l.l.Y ~ DRILL PIPE SAFETY VALVF... ~ 2~2~ ~ TO 250 PSI r~ SI(~I, ~ ~ ~0 ~2LLIN~ PE_EKI.¥ ~-E3~F. AFTi~ F~I~Y C:PEI:~ATE ~ I::~IL¥. RECEIVED IAR 1 2 ]985 Alaska ,Oil & Gas Cons. Commission Anchorage 51008400 t~..,V I CHECK LIST FOR NEW WELL PERMITS Lease & Well No. ~/~ f-~,_ ?~ %/- / ~ Company ITEM APPROVE DATE (1) Fee (2) Loc thru 8) -'~. 4. 5. :5. $. (8'~)~ (3) Admin ~/~L-,~- D' l?,,-~'f'" 9. (9 thru 12) 10. . (10 aha r2)' 12. (13 thru 21) 13. 14. 15. 16. 17. 18. 1,9. 20. 21. Is well to be loCated 'in a defined pool ......,.' .... . .... Is well located proper distance from property line ' Is well located proper distance from other wells .. . Is sufficient undedicated,acreage available in this pool ..... Is well to be deviated and is wellbore plat inclUded ......... YES NO e e ® i · e e ~ Is operator, the only affected party ................................. Can.permit be approved before ten-day wait .......................... fl_:.. Does. OPerator have a bond in force '. ................................. Is a,conservation order needed .................... Is administrative approval needed ................................... , Is the lease number appropriate ..................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give.adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ REMARKS ( ) o //:// (22 thru' (6) Add: 22. 23. 24. 25. 26. 27. Is a diverter system required .................................... Are'necessary diagrams of diverter and ~6~ equipment attached . .. Does BOPE have sufficient pressure rating - Test to ~,,~-~-~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks:~?-/f) ZUIZ/~ R~ ~z~z F/COM ~z~-~ F~/c! Jz//~F, qC~ 7-z~ .~06/7-UD ,,g/VD ~//~/~ ;~ 71 Geology:~ ~ngineerin~: ~VA_,~__ ~ HJH / .. rev: 10/29/86 6. C~T POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi .. No special'effort has been made to chronologically organize this category of information. ,o JNLT JN O JO O30 uOO 030 OOO 0 0~3 0 ,.) O O00 000 OOO 030 OOO O 3 ! R .~ F = 3. :~ 7 0 = 3.070 .= i.~,'5iS ~ '7:".0 9": :;.', 7.7,. ,0 g F' i 73.O CF .~F D!'E a T G~. ? T ':+ !'7. '= 3. *' 5 5, 6 N "J, ',i L 7 :; .7Z 5~, £L U -476, 3.0 0 S 0 f'~k 4T ,']. !] t ::: .5 , k 4 T .-, £ '. 38b'7 .:£9, :70']0 ~.. i 7 .~ '? 3. 3234. .~6 6.. 00;) 0 Z ,95!2 ,., ~ N 4 ~ .l L ,~ N R ,~ l ,L M C &L.~. R Ni~. ,~, CA~_l OR£C-35 C, O0 JO 0,3'30 O000 'J GO 0 O O,J O0 O,.) 0:00 o 00000200000003 OOO 30,0030'30 003 GOO 38'300000¢30 ] 000 O 0,3 OOO O03:0 3 0 30 JO J GOO O0"OO ) 0.30 3COCOO 3000 ] 030002000000'3 } 0,3 O.OCO C O0 O0 O0 ,,; O00OOO0000CO0~ 030 O030 O0 30 :]'j 2 OOOuCOO~, £797 37.50 ,,,: . 7. '~ '0 '.", El7 30 _ 6 .. 7500 · ': $ .'.-. '.3 ]. ~- 7 , . 27'3. - ~ '-~ ~. "g :.. ';' = .. L 3'3.. Z 52,0 ] · ' i l u:. -':) 9 '~ · · 3 .'~. .S.57~1 9' . -} S } .tLC RNR~ CA,' L il L. ;'~ gAL i R N :~ A GALL LLM R~A lam SP J~ P T Rh .5 ,. 0 ':' ? ~ .-L :,. - :, S :.) ,: '5 i,t 0',~ R :, 'f -99 :'.,L~00 =CNL ,2 ,., _5.. - 9 9 3,, ~.:" 5 0 0 : i.,.. '3:.L L .',,.. '~, N ~ A , .;... M C&L,Z R N ~< .~ CALL R N~, A ,~ N R A -79:::i. Z:)JO - ,~ 9 '.:).. g 5 :'J: 0 - ~9S . ,L.50 0 .5 P -;. Z. i ..:: .J .5 ~ i~P -!. -: S :, o :.' :,_',0 .~C J .,:5. ,"' T ~ C J., ,)?." ""--, .5 ',~ ,_ u SP -52. :362,55. :..:, R RhJS - ~5;'9. 'Z 5'30 SP --'-: ~.55lZ !'~ P r'~ _ - ) 9 ",,, :.: 5 0 0 ~'~ t., ',.~ L -,""i ' "~ 5 P -' !~ ] .: '.','. £ 5 S k - -5'? .~. L:,O0 .:. '" L7 · L ?,.2500 '~R.;T -- 5 ? :','. Z, :~0 C FC~,L 9 7 ,,,. 0 5 Z 5, G R · -' = '. ,;. ,,". ,500 F C ~'q L :L...4-2 97 ZL L' .... :,,5 t:~, 'L 5, 3 O -9 .'? ',?-,. ~ 530 R N .< A -5 .)" . Z530 .... : 0 "'2, :5 ",_ r.'. 3,2. L:.OO S A L", - ..~ '? ",:, · .£ :.5 0 0 R r..,i .q ~ - ~, 95). 2 5 :.) 0 .;. Z ,L. :L 7 ;, C "A_: -'5 .S '~. Z 5 ] 0 L" 3,,,, 1250 C~Li - :,, '5 .:) · Z '5 ..:: 0 ~N~A .3 · o 4 .L 0 .i L ,'4 - :~ 9 9 ,,, :.Z 5 ;] 0 .LOg ,,, :~ :.5.' O C, - :)'9 ,. .:,, f. '5 :] ' 7158 2...5,-.,5..5, '9. Z 9 :_., 9 - 5, 99, ,Z 5 '] 0 :-Z .. 7,,+ ~0 - i .-5 3, ,.':55 30 3. ,. ~) 3 5 ,Z - .3 9 ~ ,, ;,:. '5 0 0 "; ,. :, 7 .: 9 , m ! d 7 5 -..3' 9 .':;,..z 50 ,.3 ~., 54,'] o ] L J 3 r... ¢ 'f' 3 !; 2 3 ,, 3 0 ',J 0 .} ,': L u 'N ~ n .,. - ] 9 .~. ':' F, ) L2 ',, L i,, L 75O0 2530 :L 3 . f L ,- :,, .L 7 .::: L ,'2,. :' ,'i :? '9 .-g':: .. 2,5 LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO ALASKA, INC. Well D.S. 2V-t0 Field KUPARUK County, State NORTH SLOPE, ALASKA Date SEPTEMBER 20, 1985 Curve ~-; ame ,',Ah~rev. ) Standard Curve TM.,ame- Lo:~.~. Used Sca~ e CN1 i ! ~ CN~. ~CO~[PgNSATED NEUTRON ; CNL 60 - 0 60 - 0 NLAV CN HODGES/LEHMAN AVERAGE SE I STANDARD ERROR TH THE MEAN Il II II II II II CN4 " " " " CN5 " " " " GR ~ G~!~iA RAY " 0 - 100 SD ~ STA~DARD DEVIATION " L. v, /. . ?5 0 .-7. · . 5 I .,5c ;,.Tz -;7 &1 ?, 7'l 1 .?7 3. ~;7 _ I .15 ..'-,.5? 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