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Home My WebLink About190-090Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/24/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251024 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BR 11-86 (REVISED) 50733207370000 225057 8/1/2025 HALLIBURTON RMT3D BRU 241-34T 50283201810000 220052 9/23/2025 AK E-LINE Perf END 2-36 50029220140000 190024 10/13/2025 READ Caliper Survey MPI 2-72 50029237810000 224016 10/2/2025 AK E-LINE Patch MPU I-01 50029220650000 190090 9/25/2025 AK E-LINE Punch MPU J-08A 50029224970100 199117 10/22/2025 HALLIBURTON COILFLAG MPU R-109 50029238220000 225073 9/24/2025 YELLOWJACKET SCBL NCIU A-06A 50883200260100 225071 9/25/2025 AK E-LINE CBL NCIU A-06A 50883200260100 225071 9/26/2025 AK E-LINE Perf PBU A-24B 50029207430200 225067 10/20/2025 HALLIBURTON RBT PBU GC-2E 50029227400000 197018 10/21/2025 HALLIBURTON TEMP PBU W-35A 50029217990200 225076 10/10/2025 HALLIBURTON RBT SP-03-NE2 50629236390000 219089 9/25/2025 AK E-LINE Caliper Please include current contact information if different from above. T41022 T41023 T41024 T41025 T41026 T41027 T41028 T41029 T41029 T41030 T41031 T41032 T41033 MPU I-01 50029220650000 190090 9/25/2025 AK E-LINE Punch Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.24 13:32:55 -08'00' From:Rixse, Melvin G (OGC) To:Ryan Thompson Subject:20250903 2157 APPROVAL MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Date:Wednesday, September 3, 2025 10:00:26 PM Attachments:image002.png Ryan, Hilcorp is approved to test IA with pressure on the OA and tubing as described below. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Wednesday, September 3, 2025 4:24 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Mel, On 8/4/25 the 11 bbl cement plug on MPI-01 P&A was pumped down tubing and up the IA from ~700’ to ~400’ as outlined below (witnessed TOC was tagged at ~300’). In performing subsequent CMIT-TxIA’s to 1500 psi we were unable to establish stabilization to pass the MIT criteria until we applied ~1000 psi of OA pressure. In troubleshooting the wellhead on 8/29/25 a PPPOT-IC failed indicating IAxOA communication through the wellhead. Once this was established a non-witnessed CMIT-TxIAxOA to 1592 psi was performed and passed as outlined below: The program calls out a CMIT-TxIA to 1500 psi in order to establish integrity of the cement in the tubing and IA. Due to the IxO wellhead communication we would like to perform a CMIT- TxIAxOA, testing top of cement integrity in all three voids. Please let me know if you approve a CMIT-TxIAxOA to 1500 psi and we will submit for witness. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Thanks, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Thursday, May 22, 2025 5:39 PM To: Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Ryan, Hilcorp is approved to execute plan forward as described in yellow highlighted text below. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Thursday, May 22, 2025 3:10 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Mel, We have attempted to establish injectivity into the IA, below are the pressure bleed off results. IA lost 164 psi/15 min @ 1600 psi. IA lost 336 psi/15 min @ 2600 psi. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. We were not able to establish consistent injectivity to confidently attempt an IA squeeze from surface. Here is the plan forward proposed in my initial email, please let me know if this is acceptable or if you have any further guidance. Plan forward – Shoot tubing punch (T->IA) @ ~700’. Pump cement balance plug T->IA to ~400’ TOC (~11 bbls 15.3 ppg cement). AOGCC witness tag TOC in tubing & CMIT to 1500 psi. Perform planned Surface cement plug (T->IA-> OA from 250’) as outlined in sundry. Since the CMIT-TxI of this last plug did not pass, we did not call out AOGCC for the CMIT/cement tag, as we plan to pump another cement job as described above with witnessed CMIT/tag. Please advise if you want an AOGCC witnessed tag of the cement top at ~743’. Thanks, Ryan From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Tuesday, May 20, 2025 10:06 AM To: Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Ryan, I will look forward to hearing from you. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Monday, May 19, 2025 10:13 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Mel, We will attempt to get a LLR down the IA and I will let you know if a squeeze will be feasible. Thanks, Ryan From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, May 16, 2025 2:22 PM To: Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Ryan, Can you squeeze cement to the IA to get a passing test? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, May 16, 2025 1:17 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Mel, I would like to update you on where we are at with this P&A and get your approval on the CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. plan forward as we will now need an additional cement plug based on the failing CMIT described below: 1. We have pumped the cement plug in the tubing/IA bringing cement from the existing tubing punch @ 2825’ to ~743’ (SL tag depth of cement in tubing, recovered cement). This was the first fullbore step in the attached sundry after “above complete/below plan forward”. Our CMIT to 1500 psi failed. An MIT-T has passed to 1500 psi but the IA is leaking off at ~200 psi/15 min. Cement tops are now estimated at T-743’, IA - ~750’, OA - ~400’ (based on information from OA downsqueeze performed during completion). Plan forward – Shoot tubing punch (T->IA) @ ~700’. Pump cement balance plug T->IA to ~400’ TOC (~11 bbls 15.3 ppg cement). AOGCC witness tag TOC in tubing & CMIT to 1500 psi. Perform planned Surface cement plug (T->IA-> OA from 250’) as outlined in sundry. Since the CMIT-TxI of this last plug did not pass, we did not call out AOGCC for the CMIT/cement tag, as we plan to pump another cement job as described above with witnessed CMIT/tag. Please advise if you want an AOGCC witnessed tag of the cement top at ~743’. Thanks, Ryan From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Wednesday, February 26, 2025 10:32 AM To: Ryan Thompson <Ryan.Thompson@hilcorp.com> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Ryan, Your procedure looks good. Please submit a new 10-403 for approval. Mel Rixse Senior Petroleum Engineer (PE) CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Wednesday, February 26, 2025 9:50 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Thank you Mel for the feedback, I have edited the revision (attached) to reflect your comments below. We will have a planned TOC in the T&IA at ~850’ to achieve pumping 5 bbls behind the cement job. In summary as below: 1. Pump cement down tubing, squeezing the communication path to formation, then opening the IA bringing cement to 850’ TOC in both the tubing and the IA. We will leave 9.8 ppg brine in both T & IA between the cement top and our next tubing punch @ ~250’. 2. SL tag TOC in tubing and CMIT-TxIA to 1500 psi. 3. Punch T->IA->OA @ ~250’. 4. Perform surface cement job bringing cement to surface in T & IA & OA from 250’. 5. Cut and cap as in the original sundry. Please let me know your thoughts or approval. Thank you, Ryan From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, February 21, 2025 2:45 PM To: Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Ryan, AOGCC would like to confirm a deep cement plug integrity to the holes at 2870’ MD of the IA. So, for that reason I would like to see cement in the tubing and IA to say ~700’ MD where a pressure test can confirm that the IA does not have a leak path below to the SC shoe. I have a concern that when you punch at ~250’ MD, you may not have pressure integrity which would create confusion as to where communication is occurring. If the IA and tubing have already demonstrated pressure integrity of a cement plug at ~700’, it is not an issue later. Call me if you want to discuss over the phone. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Thursday, February 20, 2025 2:52 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Mel, The below tubing punch (revision #1) was performed in August 2024. In October 2024 in preparation, for the surface cement job, circulation was established from T->IA but circulation up the OA to surface was not established. Multiple pumping configurations/pressures were attempted to establish OA communication until last month paper files were found in the slope file showing an OA cement downsqueeze was performed between the drilling and completion phase of the well in Dec 1990 leaving a cement top in the OA @ ~400’ (OA downsqueeze report attached). Additionally after the tubing punch at 2825’, a communication path to formation has been established out the OA. Attached is Revision #2 to the program to complete the P&A of the well, in summary our plan forward is: 1. Pump cement down tubing, squeezing the communication path to formation, then opening the IA bringing cement to surface in the IA and a cement top in the tubing at ~700’. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2. SL tag and MIT-T the tubing to 1500 psi. 3. Punch T->OA @ ~250’. 4. Perform surface cement job bringing cement to surface in T & OA. 5. Cut and cap as in the original sundry. The current wellbore schematic and planned final schematic have bee updated in revision #2. Also attached is the original sundry for reference. Please let me know if you have any questions or with approval for revision #2. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Thursday, August 1, 2024 9:03 AM To: Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Ryan, Hilcorp is approved to punch tubing at 2825’ MD for circulation of surface plugs in all annuli. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Wednesday, July 31, 2024 3:07 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: MPI-01 (PTD# 1900900) P&A Sundry #323-018 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. Mel, Attached is a revision for approval to the MPI-01 P&A sundry adding a line to make an additional TxIxO punch above our IA cement top (CBL log attached for reference). Below is the background. 1. Coiled tubing performed the reservoir cement plug on 10/2/23. 2. SL performed state witness tag of TOC in the tubing @ 3117’ and a passing CMIT-TxI to 1500 psi on 10/29/23. 3. EL performed TxIxO punch @ 3050’ on 11/18/23 4. Multiple attempts to establish circulation TxIxO were unsuccessful. Decision made to run CBL to identify IA TOC (Doyon 14 was on I pad from Feb-May and EL was unable to access the well during this timeframe) 5. EL ran CBL and found TOC in the IA is at ~2870’, on 7/20/24. The request is to perform a second tubing punch @ ~2825’, 1 joint above the IA TOC, once TxIxO circulation is established, perform the remainder of the P&A as approved. Please let me know your thoughts. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual orentity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by returnemail or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted bythe company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual orentity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by returnemail or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onwardtransmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted bythe company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual orentity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by returnemail or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted bythe company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual orentity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by returnemail or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onwardtransmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual orentity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onwardtransmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted bythe company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual orentity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by returnemail or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted bythe company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual orentity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by returnemail or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onwardtransmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20250522 1739 APPROVAL MPI-01 (PTD# 1900900) P&A Sundry #323-018 - Date:Friday, May 23, 2025 8:51:14 AM From: Rixse, Melvin G (OGC) Sent: Thursday, May 22, 2025 5:39 PM To: Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Ryan, Hilcorp is approved to execute plan forward as described in yellow highlighted text below. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Thursday, May 22, 2025 3:10 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Mel, We have attempted to establish injectivity into the IA, below are the pressure bleed off results. IA lost 164 psi/15 min @ 1600 psi. IA lost 336 psi/15 min @ 2600 psi. We were not able to establish consistent injectivity to confidently attempt an IA squeeze from surface. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Here is the plan forward proposed in my initial email, please let me know if this is acceptable or if you have any further guidance. Plan forward – Shoot tubing punch (T->IA) @ ~700’. Pump cement balance plug T->IA to ~400’ TOC (~11 bbls 15.3 ppg cement). AOGCC witness tag TOC in tubing & CMIT to 1500 psi. Perform planned Surface cement plug (T->IA-> OA from 250’) as outlined in sundry. Since the CMIT-TxI of this last plug did not pass, we did not call out AOGCC for the CMIT/cement tag, as we plan to pump another cement job as described above with witnessed CMIT/tag. Please advise if you want an AOGCC witnessed tag of the cement top at ~743’. Thanks, Ryan From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Tuesday, May 20, 2025 10:06 AM To: Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Ryan, I will look forward to hearing from you. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Monday, May 19, 2025 10:13 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Surface Abandonment Plugs Mel, We will attempt to get a LLR down the IA and I will let you know if a squeeze will be feasible. Thanks, Ryan From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, May 16, 2025 2:22 PM To: Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Ryan, Can you squeeze cement to the IA to get a passing test? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, May 16, 2025 1:17 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Mel, I would like to update you on where we are at with this P&A and get your approval on the plan forward as we will now need an additional cement plug based on the failing CMIT described below: CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 1. We have pumped the cement plug in the tubing/IA bringing cement from the existing tubing punch @ 2825’ to ~743’ (SL tag depth of cement in tubing, recovered cement). This was the first fullbore step in the attached sundry after “above complete/below plan forward”. Our CMIT to 1500 psi failed. An MIT-T has passed to 1500 psi but the IA is leaking off at ~200 psi/15 min. Cement tops are now estimated at T-743’, IA - ~750’, OA - ~400’ (based on information from OA downsqueeze performed during completion). Plan forward – Shoot tubing punch (T->IA) @ ~700’. Pump cement balance plug T->IA to ~400’ TOC (~11 bbls 15.3 ppg cement). AOGCC witness tag TOC in tubing & CMIT to 1500 psi. Perform planned Surface cement plug (T->IA-> OA from 250’) as outlined in sundry. Since the CMIT-TxI of this last plug did not pass, we did not call out AOGCC for the CMIT/cement tag, as we plan to pump another cement job as described above with witnessed CMIT/tag. Please advise if you want an AOGCC witnessed tag of the cement top at ~743’. Thanks, Ryan From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Wednesday, February 26, 2025 10:32 AM To: Ryan Thompson <Ryan.Thompson@hilcorp.com> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Ryan, Your procedure looks good. Please submit a new 10-403 for approval. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Wednesday, February 26, 2025 9:50 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Thank you Mel for the feedback, I have edited the revision (attached) to reflect your comments below. We will have a planned TOC in the T&IA at ~850’ to achieve pumping 5 bbls behind the cement job. In summary as below: 1. Pump cement down tubing, squeezing the communication path to formation, then opening the IA bringing cement to 850’ TOC in both the tubing and the IA. We will leave 9.8 ppg brine in both T & IA between the cement top and our next tubing punch @ ~250’. 2. SL tag TOC in tubing and CMIT-TxIA to 1500 psi. 3. Punch T->IA->OA @ ~250’. 4. Perform surface cement job bringing cement to surface in T & IA & OA from 250’. 5. Cut and cap as in the original sundry. Please let me know your thoughts or approval. Thank you, Ryan From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, February 21, 2025 2:45 PM To: Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Ryan, AOGCC would like to confirm a deep cement plug integrity to the holes at 2870’ MD of the IA. So, for that reason I would like to see cement in the tubing and IA to say ~700’ MD where a pressure test can confirm that the IA does not have a leak path below to the SC shoe. I have a concern that when you punch at ~250’ MD, you may not have pressure integrity which would create confusion as to where communication is occurring. If the IA and tubing have already demonstrated pressure integrity of a cement plug at ~700’, it is not an issue later. Call me if you want to discuss over the phone. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Thursday, February 20, 2025 2:52 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Mel, The below tubing punch (revision #1) was performed in August 2024. In October 2024 in preparation, for the surface cement job, circulation was established from T->IA but circulation up the OA to surface was not established. Multiple pumping configurations/pressures were attempted to establish OA communication until last month paper files were found in the slope file showing an OA cement downsqueeze was performed between the drilling and completion phase of the well in Dec 1990 leaving a cement top in the OA @ ~400’ (OA downsqueeze report attached). Additionally after the tubing punch at 2825’, a communication path to formation has been established out the OA. Attached is Revision #2 to the program to complete the P&A of the well, in summary our plan forward is: 1. Pump cement down tubing, squeezing the communication path to formation, then opening the IA bringing cement to surface in the IA and a cement top in the tubing at ~700’. 2. SL tag and MIT-T the tubing to 1500 psi. 3. Punch T->OA @ ~250’. 4. Perform surface cement job bringing cement to surface in T & OA. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 5. Cut and cap as in the original sundry. The current wellbore schematic and planned final schematic have bee updated in revision #2. Also attached is the original sundry for reference. Please let me know if you have any questions or with approval for revision #2. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Thursday, August 1, 2024 9:03 AM To: Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: [EXTERNAL] 20240801 0902 MPI-01 (PTD# 1900900) P&A Sundry #323-018 - APPROVAL Surface Abandonment Plugs Ryan, Hilcorp is approved to punch tubing at 2825’ MD for circulation of surface plugs in all annuli. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Wednesday, July 31, 2024 3:07 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: MPI-01 (PTD# 1900900) P&A Sundry #323-018 Mel, Attached is a revision for approval to the MPI-01 P&A sundry adding a line to make an additional TxIxO punch above our IA cement top (CBL log attached for reference). Below is the background. 1. Coiled tubing performed the reservoir cement plug on 10/2/23. 2. SL performed state witness tag of TOC in the tubing @ 3117’ and a passing CMIT-TxI to 1500 psi on 10/29/23. 3. EL performed TxIxO punch @ 3050’ on 11/18/23 4. Multiple attempts to establish circulation TxIxO were unsuccessful. Decision made to run CBL to identify IA TOC (Doyon 14 was on I pad from Feb-May and EL was unable to access the well during this timeframe) 5. EL ran CBL and found TOC in the IA is at ~2870’, on 7/20/24. The request is to perform a second tubing punch @ ~2825’, 1 joint above the IA TOC, once TxIxO circulation is established, perform the remainder of the P&A as approved. Please let me know your thoughts. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual orentity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onwardtransmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted bythe company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual orentity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by returnemail or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted bythe company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by returnemail or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted bythe company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual orentity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by returnemail or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onwardtransmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted bythe company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual orentity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onwardtransmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted bythe company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual orentity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by returnemail or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted bythe company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6,182'N/A Casing Collapse Conductor N/A Surface 2,020psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager 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 MILNE PT UNIT I-01 MILNE POINT SCHRADER BLUFF OIL N/A 4,301' 6,076' 4,215' 807 N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 3/10/2025 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 190-090 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22065-00-00 Hilcorp Alaska LLC C.O. 477.05 Length Size Proposed Pools: 105' 105' 6.5# / L-80 / EUE 8rd TVD Burst 3,928' MD N/A 3,520psi 7,240psi 2,539' 4,282' 3,274' 6,157' 70' 13-3/8" 9-5/8" 7" 3,239' 6,122' Perforation Depth MD (ft): See Schematic See Schematic 2-7/8" Otis Versa-trieve & Otis AWD and N/A 5,250 MD/ 3,553 TVD & 5,790 MD/ 3,980 TVD and N/A Ryan Thompson ryan.thompson@hilcorp.com 907-564-5280 No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-128 By Gavin Gluyas at 1:07 pm, Mar 05, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.03.05 12:57:09 - 09'00' Taylor Wellman (2143) * State to witness slickline tag TOC in tubing ~850' MD. CMIT-TXIA to 1500 psi of cement plug at 850'. * Photo document as described. * State to witness TOC in all annuli before welding abandonment plate. 10-407 MGR27MAR24 A.Dewhurst 05MAR25 DSR-3/10/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.03.28 09:07:40 -08'00'03/28/25 RBDMS JSB 040225 Plug and Abandon Well: MPI-01 PTD: 190-090 API:50-029-22065-00-00 Revision #2 – Additions/edits from original sundry (323-018) in red Well Name:MPU I-01 API Number:50-029-22065-00-00 Current Status:SI ESP producer Rig:Eline/Pumping Estimated Start Date:3/10/25 Estimated Duration:5days Reg.Approval Req’d?Yes Date Reg. Approval Rec’vd:TBD Regulatory Contact:Tom Fouts Permit to Drill Number:1900900 First Call Engineer:Ryan Thompson 907-564-5005 907-301-1240 Second Call Engineer:Erik Nelson 907-903-7407 AFE Number:TBD Current Bottom Hole Pressure:1156 psi @ 3493’ TVD I-15 SBHP Offset well Maximum Expected BHP:1156 psi @ 4300’ TVD 6.4 PPGE Max. Anticipated Surface Pressure:807 psi Gas Column Gradient (0.1 psi/ft) Min ID:1.79” @ 5807’ XN Nipple Brief Well Summary I-01 was drilled as a vertical producing well in October of 1990 and left suspended. The well was later completed in January 1991 in the Schrader Bluff O with fracture stimulation treatment and in the Schrader Bluff N sands with a gravel pack. An ESP with tubing were run for artificial lift. In July 1991 the ESP died and in December of 1991 a RWO was performed to replace the ESP. During the RWO the ESP was pulled and slickline tag found fill at 5970’ (45’ below the bottom O sand perforations). A clean up treatment was pumped across the perforations and gravel pack and a new ESP was run. A second RWO was performed in February 1998 to again replace a failed ESP which occurred in November 1997. During the workover a clean out string was able to run to PBTD of 6050’. In December of 1998 the well plugged of with solids at ~2575’ with unsuccessful attempt to bail with slickline. The ESP was declared dead following attempts to return the well to production. A follow up slickline run in July of 2002 found sand at ~3900’ slm and bailed 16’ of sand to a final depth of 3915’ slm.Feb 2025, a new 10-403 is submitted for approval of revised abandonment plan based on recently discovered information on the 1990 OA cement downsqueeze. A recent workover attempt was abandoned when damaged casing was identified at ~350’. A kill string was set to a depth of 3,928’. There is no future utility or value from this well and therefore P&A is planned. *Hilcorp requests a variance from 20 AAC 25.112 Well Plugging Requirements. Slickline tag confirmed sand fill at 5,272’ (~370’ above top perforation and ~800’ above PBTD). Notes Regarding Wellbore Condition x Kill string was ran to 3,928’ x Casing obstruction @ ~350’ x 9 5/8” surface casing x 7” x 9 5/8” annulus cemented from (3274’ – 400’) with an OA downsqueeze between drilling and completion operations in 1990. x 9 5/8” x open hole/conductor cemented from 475’ to surface. x Reservoir cement plug complete x Current Injectivity to formation from tubing, 1 bpm @ 1000 psi. Objective: x To perform a complete P&A of the well. Procedure Slickline Plug and Abandon Well: MPI-01 PTD: 190-090 API:50-029-22065-00-00 1. Drift and Tag (Complete 12/5) Coil Tubing (Reservoir Cement Plug) 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min each test. 3. PU RIH W/ cementing nozzle, dry tag. 4. Lay in 54 bbls of 12-15.8 ppg Class G cement taking returns from the TBG x Coil annulus. 5. Pump 18 bbls of 12-15.8 ppg Class G cement down the coil, taking returns from the IA (placing cement behind tubing tail). 6. POOH circulating fresh water as needed to remove any cement. Lay in freeze protect from 2500’ to surface. Slickline (Wait on cement 3 days) 1. AOGCC Witnessed cement tag (est cement top @ 3100’) 2. Drift for Eline TBG Punch Fullbore 1. AOGCC Witnessed CMIT-TxIA to 1500 psi Eline 1. Perforate tubing x IA x OA at ~ 3,050’ a. Unable to circulate tubing x IA x OA, TOC established in IA @ 2870’ based on post cement job CBL. 2. Perforate tubing x IA x OA at 2825’.(Revision #1 addition) a. Established communication T x IA, unable to circulate T x OA. b. Found drilling files confirming OA (7” x 9 5/8”) annulus has been cemented up to ~400’ from 1990 OA downsqueeze. c. Pumped 40 bbls diesel down the IA w/ no returns, communication to formation. ABOVE COMPLETE / BELOW PLAN FORWARD Fullbore – Intent of this operation is to pump cement and squeeze off the path to formation in the OA, once squeeze pressure builds, swap on the fly to the IA, pumping cement to ~850’ and leaving cement top in the tubing at ~850’ in order to perform a further surface cement job on the Tubing -> IA -> OA 1. Rig up to the IA pumping into formation 2. Pump: a. 20 bbls of surfactant wash b. 85 bbls 9.8 ppg brine 3. Rig up to the tubing, establish injectivity into the formation with the IA shut in, ~10 bbls. 4. Pump 5 bbl freshwater spacer. 5. Mix/Pump ~81 bbls of 14-15.8 ppg Class G cement with the IA initially shut in, pumping cement into formation. a. Once cement hits formation (~16-18 bbls depending on which punch takes the cement) watch pump pressure, once pump/squeeze pressure builds to 500 psi (or max 10 bbls to formation), open IA and begin to take returns up the IA. b. Pump 81 bbls cement. c. Once cement is pumped displace w/ ~5 bbls of 9.8 ppg brine and shut in the IA. This should leave a cement top of ~850’ in the tubing and in the IA. d. Cement Volumes: IA = 60 bbls, Tubing = 11 bbls, OA/formation = 10 bbls (81 bbls) Plug and Abandon Well: MPI-01 PTD: 190-090 API:50-029-22065-00-00 Slickline 1. Tag TOC in tubing ~850. (AOGCC witnessed) 2. Perform CMIT-TxIA to 1500 psi (AOGCC witnessed) 3. Punch tubing w/ ~1.56” guns @ ~250’ to establish communication to the IA/OA. Establish circulation up the IA/OA w ~15 bbls diesel. The diesel will FP the T/I/O prior to the cement job. Fullbore 1. Rig up to the tubing. 2. Establish circulation from the tubing through the OA to surface. a. Pump 20 bbls seawater followed by 10 bbls surfactant wash. 3. Pump 5 bbl freshwater spacer. 4. Pump ~25 bbls of 14-15.8 ppg Class G cement (~8.5 bbls of excess cement). a. Taking returns from the OA pump T->OA cement, (OA volume = ~7bbls) b. Shut in the OA, taking from returns from the IA pump T->IA cement, (IA volume ~8bbls) c. Tubing volume to 250’ is ~1.5 bbls. Shut in, leaving cement top at surface in TxIAxOA: Operations 1. Photo document all steps 2. Cut off all casings and wellhead 3’ below tundra 3. Top off tubing and annuli with cement if needed 4. AOGCC witness welding marker cap on the outermost casing string. The marker plate should have the following information bead welded onto it: a. Hilcorp Alaska,LLC b. PTD# 190-090 c. Well Name – MPU I-01 d. API Number - 50-029-22065-00-00 *** Notify AOGCC Inspector of wellhead removal. (24-hour minimum notice) Attachments: 1. OA Cement Downsqueeze - 1990 2. As-built Schematic 3. Proposed Schematic Plug and Abandon Well: MPI-01 PTD: 190-090 API:50-029-22065-00-00 OA Cement downsqueeze Plug and Abandon Well: MPI-01 PTD: 190-090 API:50-029-22065-00-00 _____________________________________________________________________________________ Revised By: DH 2/18/202 Current Milne Point Unit Well: MP I-01 PTD: 190-090 Last Completed: 9/1/2022 TD =6,182 (MD) / TD = 4,301’(TVD) 13-3/8” Marker Jt @ 5,485’ Orig. KB Elev.: 52’/ Orig. GL Elev.: 35.0’ RKB – Hanger: 35.0’ (Nabors 27E) 7” 9-5/8” Casing damage from surface to ±350’ – 8/31/2022 5 7 Est. TOC @ 4,550’ 8 OA TOC @ 400’ Tubing TOC @3,071’ 1st tubing punch 3,050’ 2nd tubing punch 2,825’ PBTD =6,076’ (MD) / PBTD = 4,215’(TVD) N Sands O Sands 4 Calc. Cement Void ~475’ to 1,700’ 2 & 3 6 TOS @ 5,272’ SLM Tagged 12/5/2022 IA TOC @ 2,870’ 7 8 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8"Conductor 54.5 / K-55 / N/A 12.459 Surface 105'0.1545 9-5/8"Surface 36 / K-55 / Btrc.8.765 Surface 3,274’0.0773 7"Production 26 / L-80 / Btrc 6.151 Surface 6,157’0.0382 TUBING DETAIL 2-7/8 Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 3,928’0.0058 PERFORATION DETAIL Schrader Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status NA Sand 5,644’5,670’3,859’3,880’26 1/24/1991 Open NB Sand 5,674’5,693’3,884’3,899’19 1/24/1991 Open NC Sand 5,713’5,724’3,916’3,925’11 1/24/1991 Open NE Sand 5,733’5,770’3,932’3,963’37 1/24/1991 Open OA Sand 5,830’5,864’4,013’4,041’34 1/24/1991 Open OB Sand 5,902’5,938’4,072’4,102’36 1/24/1991 Open ‘N’ Sands Perfs: 12SPF. ‘O’ Sands Perfs: 5SPF. WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle =60 deg. From 570’ to 4,270’ MD TREE & WELLHEAD Tree WKM 2-9/16”5M Wellhead 11”x 2-9/16” 5M WKM. 11”Hanger w/ 2-7/8” EUE 8rd Top & Bottom 2-1/2” “H” BPV Profile GENERAL WELL INFO API: 50-029-22065-00-00 Drilled and Cased by Nabors 27 -1/28/1991 ESP Replacement by EWS Rig #4 –12/15/1991 ESP RWO by Nabors 5S –2/13/1998 Install Killstring by ASR#1 –9/1/2022 OPEN HOLE / CEMENT DETAIL 13-3/8”500sx Permafrost “C”in a 30” Hole 9-5/8”247sx of Class “E”,942 sx of Class “G” in a 12.25” Hole 7”400sx of Class “G” a 8.5” Hole STIMULATION DETAIL Interval: 5,830’ to 5,938’’ – 85,284 lbs. 16/20 mesh Proppant JEWELRY DETAIL No Depth Item 1 3,925’WLEG –Btm @ 3,928’ 2 5,250’7” Otis “VST” Versa-Trieve Packer 3 5,257’Otis “MCS” Closing Sleeve 4 5,609’H-S 12 Gauge Screen (167’) ID = 2.44” –Btm @ 5,776’ 5 5,777’H-S 12 Gauge Screen (167’) ID = 2.44” –Btm @ 5,788’ 6 5,790’7” Otis “AWD” Sump Packer, ID = 4.0” 7 5,806’Otis XN No-go Landing –Min ID= 1.791” 8 5,808’Otis Re-Entry Guide _____________________________________________________________________________________ Revised By: RT 2/26/2025 Proposed Milne Point Unit Well: MP I-01 PTD: 190-090 Last Completed: 9/1/2022 TD = 6,182 (MD) / TD = 4,301’(TVD) 13-3/8” Marker Jt @ 5,485’ Orig. KB Elev.: 52’/ Orig. GL Elev.: 35.0’ RKB – Hanger: 35.0’ (Nabors 27E) 7” 9-5/8” Casing damage from surface to ±350’ – 8/31/2022 5 7 Est. TOC @ 4,550’ Proposed IA & tubing top of cement @~ 850’. Proposed tubing punch @ ~250’ 8 OA TOC @ 400’ Tubing TOC @3,071’ 1st tubing punch 3,050’ 2nd tubing punch 2,825’ PBTD = 6,076’ (MD) / PBTD = 4,215’(TVD) N Sands O Sands 4 Calc. Cement Void ~475’ to 1,700’ 2 & 3 6 TOS @ 5,272’ SLM Tagged 12/5/2022 IA TOC @ 2,870’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top BtmBPF 13-3/8"Conductor 54.5 / K-55 / N/A 12.459 Surface 105'0.1545 9-5/8"Surface 36 / K-55 / Btrc.8.765 Surface 3,274’0.0773 7"Production 26 / L-80 / Btrc 6.151 Surface 6,157’0.0382 TUBING DETAIL 2-7/8 Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 3,928’0.0058 PERFORATION DETAIL Schrader Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status NA Sand 5,644’5,670’3,859’3,880’26 1/24/1991 Open NB Sand 5,674’5,693’3,884’3,899’19 1/24/1991 Open NC Sand 5,713’5,724’3,916’3,925’11 1/24/1991 Open NE Sand 5,733’5,770’3,932’3,963’37 1/24/1991 Open OA Sand 5,830’5,864’4,013’4,041’34 1/24/1991 Open OB Sand 5,902’5,938’4,072’4,102’36 1/24/1991 Open ‘N’ Sands Perfs: 12SPF. ‘O’ Sands Perfs: 5SPF. WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle =60 deg. From 570’ to 4,270’ MD TREE & WELLHEAD Tree WKM 2-9/16”5M Wellhead 11”x 2-9/16”5M WKM. 11”Hanger w/ 2-7/8” EUE 8rd Top & Bottom 2-1/2” “H” BPV Profile GENERAL WELL INFO API: 50-029-22065-00-00 Drilled and Cased by Nabors 27 -1/28/1991 ESP Replacement by EWS Rig #4 –12/15/1991 ESP RWO by Nabors 5S –2/13/1998 Install Killstring by ASR#1 –9/1/2022 OPEN HOLE / CEMENT DETAIL 13-3/8”500sx Permafrost “C” in a 30” Hole 9-5/8”247sx of Class “E”,942 sx of Class “G” in a 12.25” Hole 7”400sx of Class “G” a 8.5” Hole STIMULATION DETAIL Interval: 5,830’ to 5,938’’ – 85,284 lbs. 16/20 mesh Proppant JEWELRY DETAIL No Depth Item 1 3,925’WLEG –Btm @ 3,928’ 2 5,250’ 7” Otis “VST” Versa-Trieve Packer 3 5,257’ Otis “MCS” Closing Sleeve 4 5,609’H-S 12 Gauge Screen (167’) ID = 2.44” –Btm @ 5,776’ 5 5,777’H-S 12 Gauge Screen (167’) ID = 2.44” –Btm @ 5,788’ 6 5,790’ 7” Otis “AWD” Sump Packer, ID = 4.0” 7 5,806’Otis XN No-go Landing –Min ID= 1.791” 8 5,808’Otis Re-Entry Guide Plug and Abandon Well: MPI-01 PTD: 190-090 API:50-029-22065-00-00 Current Schematic as of 2/18/25 Superceded Plug and Abandon Well: MPI-01 PTD: 190-090 API:50-029-22065-00-00 Superceded Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/04/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241004 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 214-13 50283201870000 222117 9/26/2024 AK E-LINE Perf END 2-72 50029237810000 224016 8/26/2024 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 8/29/2024 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 8/29/2024 HALLIBURTON RBT MPI 2-16 50029218850000 188134 9/9/2024 AK E-LINE Perf MPI 2-16 50029218850000 188134 9/20/2024 AK E-LINE Perf MPU B-16 50029213840000 185149 9/28/2024 READ CaliperSurvey MPU B-24 50029226420000 196009 8/20/2024 HALLIBURTON PERF MPU B-28 50029235660000 216027 9/28/2024 HALLIBURTON TUBINGCUT MPU I-01 50029220650000 190090 8/17/2024 HALLIBURTON PERF MPU R-103 50029237990000 224114 9/20/2024 AK E-LINE Hoist MRU M-02 50733203890000 187061 9/23/2024 AK E-LINE Perf PBU 02-21B 50029207810200 211033 9/30/2024 HALLIBURTON RBT PBU L2-10 50029217460000 187085 8/23/2024 HALLIBURTON RBT PBU L-212 50029232520000 205030 9/24/2024 HALLIBURTON IPROF PBU L-254 50029237520000 223030 9/20/2024 HALLIBURTON IPROF PBU P1-17 50029223580000 193051 9/7/2024 HALLIBURTON RBT PBU S-09A 50029207710100 214097 8/21/2024 HALLIBURTON RBT PBU Z-235 50029237600000 223055 9/19/2024 HALLIBURTON IPROF Please include current contact information if different from above. T39619 T39620 T39620 T39620 T39621 T39621 T39622 T39623 T39624 T39625 T39626 T39627 T39628 T39629 T39630 T39631 T39632 T39633 T39634 MPU I-01 50029220650000 190090 8/17/2024 HALLIBURTON PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.04 15:10:24 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 8/13/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240813 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 222-24 50283201800000 22Ϭ043 8/1/2024 AK E-LINE CIBP BRU 222-26 50283201950000 224035 7/21/2024 AK E-LINE Plug BRU 232-04 50283100230000 162037 7/25/2024 AK E-LINE Perf BRU 241-26 50283201970000 224068 7/24/2024 AK E-LINE CBL BRU 241-26 50283201970000 224068 7/31/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/10/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/18/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/23/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/28/2024 AK E-LINE Hoist IRU 44-36 50283200890000 193022 8/3/2024 AK E-LINE CBL IRU 44-36 50283200890000 193022 7/31/2024 AK E-LINE CIBP IRU 44-36 50283200890000 193022 7/29/2024 AK E-LINE RCT MPU I-01 50029220650000 190090 7/20/2024 AK E-LINE CBL MRU M-02 50733203890000 187061 7/20/2024 AK E-LINE Plug PBU PTM P1-08A 50029223840100 202199 7/23/2024 AK E-LINE CBL PBU V-220 50029233830000 208020 6/28/2024 READ InjectionProfileAnalysis PTU DW-01 50089200320000 214206 7/16/2024 READ CaliperSurvey PTU DW-0ϭ 50089200320000 214206 7/17/2024 READ TemperatureSurvey Please include current contact information if different from above. T39418 T39419 T39420 T39421 T39421 T39422 T39422 T39422 T39422 T39423 T39423 T39423 T39424 T39425 T39426 T39427 T39428 T39428 MPU I-01 50029220650000 190090 7/20/2024 AK E-LINE CBL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.13 13:58:22 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/12/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240112 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 221-35 50283201930000 223077 11/4/2023 AK E-LINE CBL END 1-27 50029216930000 187009 11/16/2023 YELLOWJACKET PERF KALOTSA 4 50133206650000 217063 9/28/2023 YELLOWJACKET PERF KALOTSA 8 50133207050000 222003 11/29/2023 YELLOWJACKET PERF KBU 13-8 50133203040000 177029 11/5/2023 YELLOWJACKET PERF KBU 22-06Y 50133206500000 215044 11/9/2023 YELLOWJACKET GPT KBU 22-06Y 50133206500000 215044 11/17/2023 YELLOWJACKET PLUG-PERF KBU 11-08Z 50133206290000 214044 8/24/2023 AK E-LINE GPT/CIBP/PERF KBU 22-06Y 50133206500000 215044 10/9/2023 AK E-LINE CBL KBU 23-05 50133206300000 214061 10/10/2023 AK E-LINE PLT KBU 43-07Y 50133206250000 214019 10/6/2023 AK E-LINE CIBP/PERF MPU I-01 50029220650000 190090 11/18/2023 YELLOWJACKET PERF PAXTON 12 50133207100000 223014 11/20/2023 YELLOWJACKET PERF PAXTON 7 50133206430000 214130 9/18/2023 YELLOWJACKET CBL PAXTON 7 50133206430000 214130 10/7/2023 YELLOWJACKET PERF SRU 224-10 50133101380100 222124 12/27/2023 YELLOWJACKET GPT-PLUG-PERF SRU 224-10 50133101380100 222124 11/4/2023 YELLOWJACKET PERF SRU 231-33 50133101630100 223008 11/8/2023 YELLOWJACKET PERF-PLUG-GPT SRU 231-33 50133101630100 223008 11/3/2023 YELLOWJACKET PERF SRU 231-33 50133101630100 223008 10/17/2023 YELLOWJACKET PLUG-PERF-GPT SRU 232-15 50133207140000 223091 12/6/2023 YELLOWJACKET GPT-PERF SRU 232-15 50133207140000 223091 12/2/2023 YELLOWJACKET SCBL Please include current contact information if different from above. T38273 T38275 T38277 T38278 T38279 T38280 T38280 T38281 T38282 T38283 T38284 T38285 T38286 T38287 T38288 T38288 T38289 T38289 T38289 T38290 T38290 1/18/2024 T38287 MPU I-01 50029220650000 190090 11/18/2023 YELLOWJACKET PERF Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.18 11:52:00 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:33 Township:13N Range:10E Meridian:Umiat Drilling Rig:n/a Rig Elevation:n/a Total Depth:6182 ft MD Lease No.:ADL 025906 Operator Rep:Suspend:P&A:X Conductor: 13 3/8"O.D. Shoe@ 105 Feet Csg Cut@ Feet Surface:9 5/8"O.D. Shoe@ 3274 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 6157 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:2 7/8"O.D. Tail@ 3928 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Fill 5272 ft 3134 ft 6.7 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1737 1713 1693 1678 IA 1747 1713 1693 1678 OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Jess Hall Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Reservoir abandonment. Plug founded on sand fill at 5272 ft MD in monobore well. Cement sample was good. 1.1 bbls in, 1.0 bbls out October 29, 2023 Kam StJohn Well Bore Plug & Abandonment Milne Point Unit I-01 Hilcorp Alaska LLC PTD 1900900; Sundry 323-018 none Test Data: P Casing Removal: rev. 3-24-2022 2023-1029_Plug_Verification_MPU_I-01_ksj                 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6,182'N/A Casing Collapse Conductor N/A Surface 2,020psi Production 5,410psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY jerimiah.galloway@hilcorp.com 907-564-5005 Jerimiah Galloway Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: 6.5# / L-80 / EUE 8rd 3,928' 1/20/2023 Otis Versa-trieve & Otis AWD and N/A 5,250 MD/ 3,553 TVD & 5,790 MD/ 3,980 TVD and N/A See Schematic See Schematic 2-7/8" Perforation Depth MD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 190-090 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22065-00-00 Hilcorp Alaska LLC SCHRADER BLUFF OIL N/A C.O. 477.05 MILNE PT UNIT I-01 4,301'6,076'4,215'807 N/A Proposed Pools: 105'105' TVD Burst PRESENT WELL CONDITION SUMMARY 13-3/8" MILNE POINT N/A 3,520psi 7,240psi 2,539' 4,282' 9-5/8" 7" 3,239' 6,122' MD 3,274' 6,157' Length Size 70' m n P s t _ 66 Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 10:35 am, Jan 13, 2023 323-018 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.01.10 08:48:01 -09'00' David Haakinson (3533) SFD 1/13/2023 1/20/2023 DSR-1/17/23MGR01FEB2023 * AOGCC to witness slickline tag and pressure test (to 1500 psi) of reservoir abandonment plug with TOC ~ 3100' MD. * State to witness cement across all annuli before welding on marker plate. * Photo document as described. 10-407 . GCW 02/02/23JLC 2/2/2023 2/2/23Brett W. Huber. Sr.Digitally signed by Brett W. Huber. Sr. Date: 2023.02.02 12:21:18 -09'00' RBDMS JSB 020723 Plug and Abandon Well: MPI-01 PTD: 190-090 API: 50-029-22065-00-00 Well Name: MPU I-01 API Number: 50-029-22065-00-00 Current Status: SI ESP producer Rig: Coil TBG/Eline/Pumping Estimated Start Date: 1/20/ 2023 Estimated Duration: 5 days Reg.Approval Req’d? Yes Date Reg. Approval Rec’vd: TBD Regulatory Contact: Tom Fouts Permit to Drill Number: 190-090 First Call Engineer: Jerimiah Galloway 907-564-5005 828-552-2537 (M) Second Call Engineer: Brian Glasheen 907-545-1144 (M) AFE Number: TBD Current Bottom Hole Pressure: 1156 psi @ 3493’ TVD I-15 SBHP Offset well Maximum Expected BHP: 1156 psi @ 4300’ TVD 6.4 PPGE Max. Anticipated Surface Pressure: 807 psi Gas Column Gradient (0.1 psi/ft) Min ID: 1.79” @ 5807’ XN Nipple Brief Well Summary I-01 was drilled as a vertical producing well in October of 1990 and left suspended. The well was later completed in January 1991 in the Schrader Bluff O with fracture stimulation treatment and in the Schrader Bluff N sands with a gravel pack. An ESP with tubing were run for artificial lift. In July 1991 the ESP died and in December of 1991 a RWO was performed to replace the ESP. During the RWO the ESP was pulled and slickline tag found fill at 5970’ (45’ below the bottom O sand perforations). A clean up treatment was pumped across the perforations and gravel pack and a new ESP was run. A second RWO was performed in February 1998 to again replace a failed ESP which occurred in November 1997. During the workover a clean out string was able to run to PBTD of 6050’. In December of 1998 the well plugged of with solids at ~2575’ with unsuccessful attempt to bail with slickline. The ESP was declared dead following attempts to return the well to production. A follow up slickline run in July of 2002 found sand at ~3900’ slm and bailed 16’ of sand to a final depth of 3915’ slm. A recent workover attempt was abandoned when damaged casing was identified at ~350’. A kill string was set to a depth of 3,928’. There is no future utility or value from this well and therefore P&A is planned. *Hilcorp requests a variance from 20 AAC 25.112 Well Plugging Requirements. Slickline tag confirmed sand fill at 5,272’ (~370’ above top perforation and ~800’ above PBTD). Notes Regarding Wellbore Condition x Kill string was ran to 3,928’ x The well currently has no injectivity. x Casing obstruction @ ~350’ Objective: x To perform a complete P&A of the well. Procedure Slickline 1. Drift and Tag (Complete 12/5) Coil Tubing (Reservoir Cement Plug) 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min each test. 3. PU RIH W/ cementing nozzle, dry tag. 4. Lay in 54 bbls of 12-15.8 ppg Class G cement taking returns from the TBG x Coil annulus. Plug and Abandon Well: MPI-01 PTD: 190-090 API: 50-029-22065-00-00 5. Pump 18 bbls of 12-15.8 ppg Class G cement down the coil, taking returns from the IA (placing cement behind tubing tail). 6. POOH circulating fresh water as needed to remove any cement. Lay in freeze protect from 2500’ to surface. Slickline (Wait on cement 3 days) 1. AOGCC Witnessed cement tag (est cement top @ 3100’) 2. Drift for Eline TBG Punch Fullbore 1. AOGCC Witnessed CMIT-TxIA to 1500 psi Eline 1. Perforate tubing x IA x OA at ~ 3,050’ Fullbore 1. Assist Eline: establish circulation after tubing perforation. *** Surface Cement Plug 2. Rig up to the tubing. 3. Circulate 120 bbls of seawater followed by 20 bbls of surfactant wash taking returns from the OA. Shut in the OA. 4. Circulate 135 bbls of seawater followed by 20 bbls of surfactant wash taking returns from the IA. Shut in the IA. 5. Pump 5 bbl freshwater spacer. *If not cementing on the same day, load the well with 9.8 brine to prevent freezing. 6. Mix 14-15.8 ppg cement. 7. Swap to cement and pump 90 bbls of Class G cement (taking returns from the OA). Shut in the OA. 8. Continue to pump 120 bbls of cement, taking returns from the IA until clean cement returns are seen at surface. Operations 1. Photo document all steps 2. Cut off all casings and wellhead 3’ below tundra 3. Top off tubing and annuli with cement if needed 4. AOGCC witness welding marker cap on the outermost casing string. The marker plate should have the following information bead welded onto it: a. Hilcorp Alaska b. Permit to Drill Number – 190-090 c. Well Name – MPU I-01 d. API Number - 50-029-22065-00-00 *** Notify AOGCC Inspector of wellhead removal. (24-hour minimum notice) Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Coil BOP Schematic , LLC. _____________________________________________________________________________________ Revised By: TDF 1/4/2023 SCHEMATIC Milne Point Unit Well: MP I-01 PTD: 190-090 Last Completed: 9/1/2022 TD =6,182 (MD) / TD = 4,301’(TVD) 13-3/8” Marker Jt @ 5,485’ Orig. KB Elev.: 52’/ Orig. GL Elev.: 35.0’ RKB – Hanger: 35.0’ (Nabors 27E) 7” 1 5 7 Est. TOC @ 4,550’ 9-5/8” ALERT: Extensive Casing Damage from Surface to ±350’ – 8/31/2022 8 PBTD = 6,076’ (MD) / PBTD = 4,215’(TVD) N Sands O Sands 4 Calc. Cement Void ~475’ to 1,700’ 2 &3 6 TOS@5,272’ SLM Tagged 12/5/2022 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 54.5 / K-55 / N/A 12.459 Surface 105' 0.1545 9-5/8" Surface 36 / K-55 / Btrc. 8.765 Surface 3,274’ 0.0773 7" Production 26 / L-80 / Btrc 6.151 Surface 6,157’ 0.0382 TUBING DETAIL 2-7/8 Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 3,928’ 0.0058 PERFORATION DETAIL Schrader Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status NA Sand 5,644’ 5,670’ 3,859’ 3,880’ 26 1/24/1991 Open NB Sand 5,674’ 5,693’ 3,884’ 3,899’ 19 1/24/1991 Open NC Sand 5,713’ 5,724’ 3,916’ 3,925’ 11 1/24/1991 Open NE Sand 5,733’ 5,770’ 3,932’ 3,963’ 37 1/24/1991 Open OA Sand 5,830’ 5,864’ 4,013’ 4,041’ 34 1/24/1991 Open OB Sand 5,902’ 5,938’ 4,072’ 4,102’ 36 1/24/1991 Open ‘N’ Sands Perfs: 12SPF. ‘O’ Sands Perfs: 5SPF. WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle =60 deg. From 570’ to 4,270’ MD TREE & WELLHEAD Tree WKM 2-9/16”5M Wellhead 11” x 2-9/16” 5M WKM. 11” Hanger w/ 2-7/8” EUE 8rd Top & Bottom 2-1/2” “H” BPV Profile GENERAL WELL INFO API: 50-029-22065-00-00 Drilled and Cased by Nabors 27 - 1/28/1991 ESP Replacement by EWS Rig #4 – 12/15/1991 ESP RWO by Nabors 5S – 2/13/1998 Install Killstring by ASR#1 – 9/1/2022 OPEN HOLE / CEMENT DETAIL 13-3/8” 500sx Permafrost “C” in a 30” Hole 9-5/8” 247sx of Class “E”, 942 sx of Class “G” in a 12.25” Hole 7” 400sx of Class “G” a 8.5” Hole STIMULATION DETAIL Interval: 5,830’ to 5,938’’ – 85,284 lbs. 16/20 mesh Proppant JEWELRY DETAIL No Depth Item 1 3,925’ WLEG – Btm @ 3,928’ 2 5,250’ 7” Otis “VST” Versa-Trieve Packer 3 5,257’ Otis “MCS” Closing Sleeve 4 5,609’ H-S 12 Gauge Screen (167’) ID = 2.44” – Btm @ 5,776’ 5 5,777’ H-S 12 Gauge Screen (167’) ID = 2.44” – Btm @ 5,788’ 6 5,790’ 7” Otis “AWD” Sump Packer, ID = 4.0” 7 5,806’ Otis XN No-go Landing –Min ID= 1.791” 8 5,808’ Otis Re-Entry Guide _____________________________________________________________________________________ Revised By: TDF 1/4/2023 PROPOSED Milne Point Unit Well: MP I-01 PTD: 190-090 Last Completed: 9/1/2022 TD =6,182 (MD) / TD = 4,301’(TVD) 13-3/8” Marker Jt @ 5,485’ Orig. KB Elev.: 52’/ Orig. GL Elev.: 35.0’ RKB – Hanger: 35.0’ (Nabors 27E) 7” 1 5 7 Est. TOC @ 4,550’ 9-5/8” ALERT: Extensive Casing Damage from Surface to ±350’ – 8/31/2022 8 PBTD = 6,076’ (MD) / PBTD = 4,215’(TVD) N Sands O Sands 4 Calc. Cement Void ~475’ to 1,700’ 2 &3 6 TOS@5,272’ SLM Tagged 12/5/2022 Est. TOC @ ±3,300 1 7 8 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 54.5 / K-55 / N/A 12.459 Surface 105' 0.1545 9-5/8" Surface 36 / K-55 / Btrc. 8.765 Surface 3,274’ 0.0773 7" Production 26 / L-80 / Btrc 6.151 Surface 6,157’ 0.0382 TUBING DETAIL 2-7/8 Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 3,928’ 0.0058 PERFORATION DETAIL Schrader Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status NA Sand 5,644’ 5,670’ 3,859’ 3,880’ 26 1/24/1991 Open NB Sand 5,674’ 5,693’ 3,884’ 3,899’ 19 1/24/1991 Open NC Sand 5,713’ 5,724’ 3,916’ 3,925’ 11 1/24/1991 Open NE Sand 5,733’ 5,770’ 3,932’ 3,963’ 37 1/24/1991 Open OA Sand 5,830’ 5,864’ 4,013’ 4,041’ 34 1/24/1991 Open OB Sand 5,902’ 5,938’ 4,072’ 4,102’ 36 1/24/1991 Open ‘N’ Sands Perfs: 12SPF. ‘O’ Sands Perfs: 5SPF. WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle =60 deg. From 570’ to 4,270’ MD TREE & WELLHEAD Tree WKM 2-9/16”5M Wellhead 11” x 2-9/16” 5M WKM. 11” Hanger w/ 2-7/8” EUE 8rd Top & Bottom 2-1/2” “H” BPV Profile GENERAL WELL INFO API: 50-029-22065-00-00 Drilled and Cased by Nabors 27 - 1/28/1991 ESP Replacement by EWS Rig #4 – 12/15/1991 ESP RWO by Nabors 5S – 2/13/1998 Install Killstring by ASR#1 – 9/1/2022 OPEN HOLE / CEMENT DETAIL 13-3/8” 500sx Permafrost “C” in a 30” Hole 9-5/8” 247sx of Class “E”, 942 sx of Class “G” in a 12.25” Hole 7” 400sx of Class “G” a 8.5” Hole STIMULATION DETAIL Interval: 5,830’ to 5,938’’ – 85,284 lbs. 16/20 mesh Proppant JEWELRY DETAIL No Depth Item 1 3,925’ WLEG – Btm @ 3,928’ 2 5,250’ 7” Otis “VST” Versa-Trieve Packer 3 5,257’ Otis “MCS” Closing Sleeve 4 5,609’ H-S 12 Gauge Screen (167’) ID = 2.44” – Btm @ 5,776’ 5 5,777’ H-S 12 Gauge Screen (167’) ID = 2.44” – Btm @ 5,788’ 6 5,790’ 7” Otis “AWD” Sump Packer, ID = 4.0” 7 5,806’ Otis XN No-go Landing –Min ID= 1.791” 8 5,808’ Otis Re-Entry Guide Valve, Swab, WKM-M, 7 1/16 5M FE Valve, Wi n g, W K M- M, 7 1/1 6 5 M F E Valve, Upper Master, Baker, 7 1/16 5M FE, w/ Hydraulic Valve, Lower Master, WKM-M, Blind Blind Lubricator 4 1/16 15M Slip Slip Shear Shear Pipe Pipe Manual Gate 2 1/8 5M Crossover spool 4 1/16 15M X 4 1/16 10M Manual Gate 2 1/8 5M Pump-In Sub 4 1/16 5M 1502 Union Crossover spool 4 1/16 10M X 4 1/16 5M To injection head Crossover spool 4 1/16 5M X 7 1/16 5M Coil Tubing BOP Stack 1.5" Double Stripper David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/3/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20220930 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU I-17 500292321200 204098 3-Aug-22 READ CaliperSurvey MPU B-24 500292264200 196009 7/19/2022 READ CaliperSurvey MPU F-38 500292261400 195168 9/19/2022 READ CaliperSurvey MPU F-73A 500292274401 200198 7/31/2022 READ CaliperSurvey MPU I-01 500292206500 190090 8/31/2022 READ CaliperSurvey MPU I-30 500292371000 222023 7/12/2022 READ Inj_Profile MPU J-27 500292355700 215153 8/11/2022 READ CaliperSurvey MPU L-47 500292355000 215117 7/23/2022 READ CaliperSurvey Please include current contact information if different from above. T37121 T37122 T37123 T37124 T37125 T37126 T37127 T37128 MPU I-01 500292206500 190090 8/31/2022 READ CaliperSurvey Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.05 13:20:28 -08'00' 5HJJ-DPHV%2*& )URP%URRNV3KRHEH/2*& 6HQW:HGQHVGD\6HSWHPEHU30 7R$ODVND16$65:HOO6LWH0DQDJHUV &F5HJJ-DPHV%2*& 6XEMHFW5(%23(7HVW $WWDFKPHQWV+LOFRUS$65[OV[ ƚƚĂĐŚĞĚŝƐĂƌĞǀŝƐĞĚƌĞƉŽƌƚƌĞŵŽǀŝŶŐƚŚĞĚĞĐŝŵĂůƐĨƌŽŵƚŚĞŽŶƚƌŽů^ǇƐƚĞŵZĞƐƉŽŶƐĞdŝŵĞĂŶĚŵŽǀŝŶŐƚŚĞŽƚƚůĞ WƌĞĐŚĂƌŐĞϭϬϬϬƉƐŝƚŽƚŚĞƌĞŵĂƌŬƐ͘WůĞĂƐĞƵƉĚĂƚĞǇŽƵƌĐŽƉǇ͘ dŚĂŶŬǇŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗ůĂƐŬĂE^Ͳ^ZͲtĞůů^ŝƚĞDĂŶĂŐĞƌƐфůĂƐŬĂE^Ͳ^ZtĞůů^ŝƚĞDĂŶĂŐĞƌƐΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗dƵĞƐĚĂǇ͕ƵŐƵƐƚϯϬ͕ϮϬϮϮϱ͗ϱϭD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх Đ͗ůĂƐŬĂE^Ͳ^ZͲtĞůů^ŝƚĞDĂŶĂŐĞƌƐфůĂƐŬĂE^Ͳ^ZtĞůů^ŝƚĞDĂŶĂŐĞƌƐΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗KWdĞƐƚ͕ϬϴͲϯϬͲϮϬϮϮ WůĞĂƐĞĨŝŶĚĂƚƚĂĐŚĞĚKWƚĞƐƚ͘ ZĞŐĂƌĚƐ͕ ^Z^D͛Ɛ ,ŝůĐŽƌƉ^D͗ϵϬϳͲϲϴϱͲϭϮϲϲ ,ŝůĐŽƌƉůĂƐŬĂ͕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y Samantha Carlisle at 8:00 am, Sep 07, 2022 MGR20SEP2022 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:ASR 1 DATE: 8/30/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1900900 Sundry #322-387 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:807 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2 7/8" x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16"P Time/Pressure Test Result HCR Valves 1 2 1/16"P System Pressure (psi)3050 P Kill Line Valves 2 2 1/16"P Pressure After Closure (psi)1700 P Check Valve 0NA200 psi Attained (sec)5 P BOP Misc 0NAFull Pressure Attained (sec)46 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4 / 2050 PSI P No. Valves 16 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 29 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:6.0 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 8/27/22 14:15 Waived By Test Start Date/Time:8/29/2022 20:00 (date) (time)Witness Test Finish Date/Time:8/30/2022 4:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Bob Noble Hilcorp Tested with both 2-7/8" and 3-1/2" test joints. Bottle Precharge - 1000 psi. D. Schultz / J. Werlinger Hilcorp Alaska LLC S. Heim / C. Huntington MPU I-01 Test Pressure (psi): askans-asr-toolpushers@hilcorp.c ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022) 2022-0830_BOP_Hilcorp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y Samantha Carlisle at 1:23 pm, Jun 30, 2022 'LJLWDOO\VLJQHGE\'DYLG +DDNLQVRQ '1FQ 'DYLG+DDNLQVRQ RX 8VHUV 'DWH 'DYLG+DDNLQVRQ ; 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^WZĞƉůĂĐĞŵĞŶƚďǇt^ZŝŐηϰʹϭϮͬϭϱͬϭϵϵϭ ^WZtKďǇEĂďŽƌƐϱ^ʹϮͬϭϯͬϭϵϵϴ KWE,K>ͬDEdd/> ϭϯͲϯͬϴ͟ ϱϬϬƐǆWĞƌŵĂĨƌŽƐƚ͟͞ŝŶĂϯϬ͟,ŽůĞ ϵͲϱͬϴ͟ ϮϰϳƐǆŽĨůĂƐƐ͕͟͞ϵϰϮƐǆŽĨůĂƐƐ͞'͟ŝŶĂϭϮ͘Ϯϱ͟,ŽůĞ ϳ͟ ϰϬϬƐǆŽĨůĂƐƐ͞'͟Ăϴ͘ϱ͟,ŽůĞ ^d/Dh>d/KEd/> /ŶƚĞƌǀĂů͗ϱ͕ϴϯϬ͛ƚŽϱ͕ϵϯϴ͛͛ʹϴϱ͕Ϯϴϰ ůďƐ͘ϭϲͬϮϬŵĞƐŚWƌŽƉƉĂŶƚ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭϭϰϱ͛^dϭ͗ϮͲϳͬϴ͟ǆϭ͟'>DϮ͘ϴϳϱ͟ǆϭ͟<DD'>D Ϯ ϱ͕ϭϮϮ͛ WƵŵƉ͗&WDdZϭ͗ϱWƵŵƉ͕ƐĞƌŝĞƐϱϭϯ͕ϭϳϴdW^ƚŐ͘ ϯ ϱ͕ϭϯϴ͛ /ŶƚĂŬĞ͗&W/Ed,Wϯ ϰ ϱ͕ϭϯϵ͛ ^ĞĂů^ĞĐƚŝŽŶ͗>ϱ'^ϯhd,>&>^Θ'^ϯ>d,^E ϱ ϱ͕ϭϱϮ͛ DŽƚŽƌ͗<DϭƐĞƌŝĞƐϲϱ,WDŽƚŽƌ͕ϭϮϱϬͲǀ͕ϯϬĂŵƉƐ ϲ ϱ͕ϭϲϬ͛ ŝƐĐŚĂƌŐĞ͗W,͕ďŽƚƚŽŵΛϱ͕ϭϲϮ͛ ϳ ϱ͕ϮϱϬ͛ ϳ͟KƚŝƐ͞s^d͟sĞƌƐĂͲdƌŝĞǀĞWĂĐŬĞƌ ϴ ϱ͕Ϯϱϳ͛ KƚŝƐ͞D^͟ůŽƐŝŶŐ^ůĞĞǀĞ ϵ ϱ͕ϲϬϵ͛ ,Ͳ^ϭϮ'ĂƵŐĞ^ĐƌĞĞŶ;ϭϲϳ͛Ϳ/сϮ͘ϰϰ͟ʹƚŵΛϱ͕ϳϳϲ͛ ϭϬ ϱ͕ϳϳϳ͛ ,Ͳ^ϭϮ'ĂƵŐĞ^ĐƌĞĞŶ;ϭϲϳ͛Ϳ/сϮ͘ϰϰ͟ʹƚŵΛϱ͕ϳϴϴ͛ ϭϭ ϱ͕ϳϵϬ͛ ϳ͟KƚŝƐ͞t͟^ƵŵƉWĂĐŬĞƌ͕/сϰ͘Ϭ͟ ϭϮ ϱ͕ϴϬϲ͛ KƚŝƐyEEŽͲŐŽ>ĂŶĚŝŶŐʹ DŝŶ/сϭ͘ϳϵϭ͟ ϭϯ ϱ͕ϴϬϴ͛ KƚŝƐZĞͲŶƚƌǇ'ƵŝĚĞ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϲͬϯϬͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DW/ͲϬϭ Wd͗ϭϵϬͲϬϵϬ >ĂƐƚŽŵƉůĞƚĞĚ͗Ϯͬϭϰͬϭϵϵϴ dсϲ͕ϭϴϮ ;DͿͬdсϰ͕ϯϬϭ͛;dsͿ ϭϯͲϯͬϴ´ 0DUNHU-W# ¶ KƌŝŐ͘<ůĞǀ͗͘ϱϮ͛ͬKƌŝŐ͘'>ůĞǀ͗͘ϯϱ͘Ϭ͛ Z<ʹ,ĂŶŐĞƌ͗ϯϱ͘Ϭ͛;EĂďŽƌƐϮϳͿ ϳ͟ (VW72&# ¶ ϵͲϱͬϴ͟ Wdс ϲ͕Ϭϳϲ͛;DͿͬWdсϰ͕Ϯϭϱ͛;dsͿ 16DQGV 26DQGV &DOF&HPHQW 9RLGa¶WR ¶ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ W& ϭϯͲϯͬϴΗ ŽŶĚƵĐƚŽƌ ϱϰ͘ϱͬ<ͲϱϱͬEͬ ϭϮ͘ϰϱϵ ^ƵƌĨĂĐĞ ϭϬϱΖ Ϭ͘ϭϱϰϱ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϯϲͬ<ͲϱϱͬƚƌĐ͘ ϴ͘ϳϲϱ ^ƵƌĨĂĐĞ ϯ͕Ϯϳϰ͛ Ϭ͘Ϭϳϳϯ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬƚƌĐ ϲ͘ϭϱϭ ^ƵƌĨĂĐĞ ϲ͕ϭϱϳ͛ Ϭ͘ϬϯϴϮ dh/E'd/> ϯͲϭͬϮ dƵďŝŶŐ ϵ͘Ϯͬ>ͲϴϬͬhϴƌĚ Ϯ͘ϵϵϮ ^ƵƌĨĂĐĞ цy͕yyy͛ Ϭ͘ϬϬϴϳ WZ&KZd/KEd/> ^ĐŚƌĂĚĞƌ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚ ƵƐ E^ĂŶĚ ϱ͕ϲϰϰ͛ ϱ͕ϲϳϬ͛ ϯ͕ϴϱϵ͛ ϯ͕ϴϴϬ͛ Ϯϲ ϭͬϮϰͬϭϵϵϭ KƉĞŶ E^ĂŶĚ ϱ͕ϲϳϰ͛ ϱ͕ϲϵϯ͛ ϯ͕ϴϴϰ͛ ϯ͕ϴϵϵ͛ ϭϵ ϭͬϮϰͬϭϵϵϭ KƉĞŶ E^ĂŶĚ ϱ͕ϳϭϯ͛ ϱ͕ϳϮϰ͛ ϯ͕ϵϭϲ͛ ϯ͕ϵϮϱ͛ ϭϭ ϭͬϮϰͬϭϵϵϭ KƉĞŶ E^ĂŶĚ ϱ͕ϳϯϯ͛ ϱ͕ϳϳϬ͛ ϯ͕ϵϯϮ͛ ϯ͕ϵϲϯ͛ ϯϳ ϭͬϮϰͬϭϵϵϭ KƉĞŶ K^ĂŶĚ ϱ͕ϴϯϬ͛ ϱ͕ϴϲϰ͛ ϰ͕Ϭϭϯ͛ ϰ͕Ϭϰϭ͛ ϯϰ ϭͬϮϰͬϭϵϵϭ KƉĞŶ K^ĂŶĚ ϱ͕ϵϬϮ͛ ϱ͕ϵϯϴ͛ ϰ͕ϬϳϮ͛ ϰ͕ϭϬϮ͛ ϯϲ ϭͬϮϰͬϭϵϵϭ KƉĞŶ ͚E͛^ĂŶĚƐWĞƌĨƐ͗ϭϮ^W&͚͘K͛^ĂŶĚƐWĞƌĨƐ͗ϱ^W&͘ t>>/E>/Ed/KEd/> <KWΛϱϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϲϬĚĞŐ͘&ƌŽŵϱϳϬ͛ƚŽϰ͕ϮϳϬ͛D dZΘt>>, dƌĞĞ t<DϮͲϵͬϭϲ͟ϱD tĞůůŚĞĂĚ ϭϭ͟ǆϮͲϵͬϭϲ͟ϱDt<D͘ϭϭ͟,ĂŶŐĞƌǁͬϮͲϳͬϴ͟ hϴƌĚdŽƉΘŽƚƚŽŵϮͲϭͬϮ͟͞,͟WsWƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϬϲϱͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďǇEĂďŽƌƐϮϳͲϭͬϮϴͬϭϵϵϭ ^WZĞƉůĂĐĞŵĞŶƚďǇt^ZŝŐηϰʹϭϮͬϭϱͬϭϵϵϭ ^WZtKďǇEĂďŽƌƐϱ^ʹϮͬϭϯͬϭϵϵϴ KWE,K>ͬDEdd/> ϭϯͲϯͬϴ͟ ϱϬϬƐǆWĞƌŵĂĨƌŽƐƚ͟͞ŝŶĂϯϬ͟,ŽůĞ ϵͲϱͬϴ͟ ϮϰϳƐǆŽĨůĂƐƐ͕͟͞ϵϰϮƐǆŽĨůĂƐƐ͞'͟ŝŶĂϭϮ͘Ϯϱ͟,ŽůĞ ϳ͟ ϰϬϬƐǆŽĨůĂƐƐ͞'͟Ăϴ͘ϱ͟,ŽůĞ ^d/Dh>d/KEd/> /ŶƚĞƌǀĂů͗ϱ͕ϴϯϬ͛ƚŽϱ͕ϵϯϴ͛͛ʹϴϱ͕Ϯϴϰ ůďƐ͘ϭϲͬϮϬŵĞƐŚWƌŽƉƉĂŶƚ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ цy͕yyy͛ ^ůŝĚŝŶŐ^ůĞĞǀĞ Ϯ цy͕yyy͛ ,W' ϯ цϱ͕ϬϬϬ͛ ϳ͟yϰͲϭͬϮ͟WĂĐŬĞƌ ϰ цy͕yyy͛ yEEŝƉƉůĞǁͬZ,WƌŽĨŝůĞ ϱ цy͕yyy͛ t>'ʹƚŵΛцy͕yyy͛ ϲ ϱ͕ϮϱϬ͛ ϳ͟KƚŝƐ͞s^d͟sĞƌƐĂͲdƌŝĞǀĞWĂĐŬĞƌ ϳ ϱ͕Ϯϱϳ͛ KƚŝƐ͞D^͟ůŽƐŝŶŐ^ůĞĞǀĞ ϴ ϱ͕ϲϬϵ͛ ,Ͳ^ϭϮ'ĂƵŐĞ^ĐƌĞĞŶ;ϭϲϳ͛Ϳ/сϮ͘ϰϰ͟ʹƚŵΛϱ͕ϳϳϲ͛ ϵ ϱ͕ϳϳϳ͛ ,Ͳ^ϭϮ'ĂƵŐĞ^ĐƌĞĞŶ;ϭϲϳ͛Ϳ/сϮ͘ϰϰ͟ʹƚŵΛϱ͕ϳϴϴ͛ ϭϬ ϱ͕ϳϵϬ͛ ϳ͟KƚŝƐ͞t͟^ƵŵƉWĂĐŬĞƌ͕/сϰ͘Ϭ͟ ϭϭ ϱ͕ϴϬϲ͛ KƚŝƐyEEŽͲŐŽ>ĂŶĚŝŶŐʹ DŝŶ/сϭ͘ϳϵϭ͟ ϭϮ ϱ͕ϴϬϴ͛ KƚŝƐZĞͲŶƚƌǇ'ƵŝĚĞ DŝůŶĞWŽŝŶƚ ^ZZŝŐϭKW %23( Εϰ͘ϰϴΖ Εϰ͘ϱϰΖ Ϯ͘ϬϬΖ ϱϬϬϬη ϮͲϳͬϴΗǆϱΗsZ ϱϬϬϬη ůŝŶĚ ^͕ϭϭϱDyϳϭͬϭϲϱD;/ĨEĞĞĚĞĚͿ ϮϭͬϭϲϱD<ŝůů>ŝŶĞsĂůǀĞƐ ϮϭͬϭϲϱDŚŽŬĞ>ŝŶĞsĂůǀĞƐ ,ZDĂŶƵĂůDĂŶƵĂůDĂŶƵĂů ^ƚƌŝƉƉŝŶŐ,ĞĂĚ Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ] q0~- (~"'~(~ File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: _~ TO RE-SCAN Notes: Bren Vincent Nathan Lowell Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: /si NOTScanned.wpd • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 "' Post Office Box 196612 Anchorage, Alaska 99519 -6612 0 December 30, 2011 ArANNED FEB 1 7 2012 Mr. Tom Maunder 6 d Alaska Oil and Gas Conservation Commission p 333 West 7 Avenue 0 I Anchorage, Alaska 99501 Mc? t Subject: Corrosion Inhibitor Treatments of MPI -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPI -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 .404) MPI -Pad 10/9/2011 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor! Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal i� MPI -01 1900900 50029220650000 0.1 NA 0.1 NA 8.5 9/5/2011 MPI -02 1900910 50029220660000 Sealed coductor NA NA NA NA NA MPI-03 1900920 50029220670000 Sealed coductor NA NA NA NA NA MPI-04A 2010920 50029220680100 Sealed coductor NA NA NA NA NA MPI -05 1951200 50029225830000 2.7 NA 2.7 NA 27.2 11/2/2009 MPI-06 1971950 50029228220000 Open Flutes - Treated NA NA MPI -07 1951510 50029226020000 1.7 NA 1.7 NA 16.2 8/21/2011 MPI -08 1971920 50029228210000 1.3 NA 1.3 NA 15.3 11/2/2009 MPI-09 2001030 50029229640000 1.3 NA 1.3 NA 13.6 11/1/2009 MPI -10 2001090 50029229660000 Open Flutes - Treated NA NA MPI -11 2011370 50029230330000 1.3 NA 1.3 NA 10.2 8/19/2011 MPI -12 2011630 50029230380000 0.2 NA 0.2 NA 7.7 10/9/2011 MPI -13 2010750 50029230120000 0.85 NA 0.85 NA 8.5 9/5/2011 MPI -14 2041190 50029232140000 1.9 NA 1.9 NA 16.2 8/23/2011 MPI -15 2021520 50029231060000 1 NA 1 NA 9.4 8/19/2011 MPI -16 2041580 50029232210000 1.75 NA 1.75 NA 17.0 8/19/2011 MPI -17 2040980 50029232120000 1.75 NA 1.75 NA 13.6 8/23/2011 MPI -19 2041350 50029232180000 1.4 NA 1.4 NA 10.2 8/19/2011 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 2000 P M C:LORILMFILM.DOC E E L E W A TE R IA L U N D ER TH IS M A.R K ER STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska Operation Shutdown I--I Stimulate i--] Plugging [,I Perforate Pull Tubing r'-]AIter Casing [~ Repair Well [~ Other ESP Replacement 5. Type of well: 6. Datum Elevation (DF or KB) [~ Development KBE = 70' [--] Exploratory 7. Unit or Property Name i--] Stratigraphic Milne Point Unit 99519-6612 [--I Service 4. Location of well at surface 2951' SNL, 3696' WEL, Sec. 33, TI3N, R10E, Umiat Meridian At top of productive interval 4432' SNL, 454' WEL, Sec. 33, T13N, R10E At effective depth 4544' SNL, 238' WEL, Sec. 33, T13N, R10E At total depth 4566' SNL, 197 WEL, Sec. 33, T13N, R10E 12. Present well condition summary Total depth: measured 6182 feet Plugs (measured) true vertical 4301 feet Effective depth: measured 6076 feet Junk (measured) true vertical 4214 feet 8. Well Number MPI-01 9. Permit Number / Approval No. 90-90 10. APl Number 50-029-22065 11. Field and Pool Milne Point Unit / Schrader Bluff Casing Length Size Structural Conductor 70' 13 3/8" Surface 3239' 9 5/8" Intermediate Production 6122' 7" Liner Cemented MD TVD 500 sxs Permanfrost C 105' 105' 606 sxs PermaF E, 3351 sxs E 3274' 2538' 528 sxs E 400 sxs G 6157' 4281' Perforation depth: measured true vertical 5644'-5670',5674'-5693',5713'-5724',5733'-5770',5830'-5864',5902'-5938' (subse~ 3789'-3801',3814'-3829',3846'-3855',3862'-3894',3943'-3971',4002'-4032' Tubing (size, grade, and measured depth) 2 7/8" 6.5 ppf, L-80 at 5122' Packers and SSSV (type and measured depth) 7" Otis "VST" Versa-Trieve packer set at 5250' and 7" Otis "AWD" sump packer set at 5806' ~ I--II '"',~,,~,__ ,", 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 In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [--] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [--I Gas F-I Suspended Service 17. I hereby certify that the foregoing is true an~c~rrect to the best of my knowledge n~-d_.,~ ,,~.. /J/.c'"-~L;~.~./~ Title Staff Technical Assistant Signed Jea ~l~' Prepared By Name/Number: Jeanne L. Haas, 564-5225 Facility Date/Time 05 Feb 98 06 Feb 98 07 Feb 98 08 Feb 98 09 Feb 98 10 Feb 98 11 Feb 98 12 Feb 98 13 Feb 98 M Pt I Pad Progress Report Well MPI-01 Page 1 Rig Nabors 5S Date 05 March 98 11:30-18:00 18:00-06:00 06:00-18:00 18:00-18:15 18:15-03:00 03:00-06:00 06:00-06:30 06:30-11:30 11:30-13:00 13:00-18:00 18:00-18:30 18:30-04:00 04:00-06:00 06:00-06:15 06:15-07:00 07:00-12:00 12:00-17:00 17:00-21:00 21:00-21:15 21:15-03:30 03:30-06:00 06:00-08:30 08:30-11:30 11:30-15:30 15:30-18:00 18:00-21:00 21:00-21:15 21:15-22:30 22:30-02:30 02:30-05:30 05:30-06:00 06:00-06:15 06:15-10:00 10:00-11:00 11:00-12:00 12:00-13:00 13:00-14:00 14:00-18:00 18:00-18:30 18:30-19:30 19:30-21:00 21:00-02:00 02:00-06:00 06:00-06:15 06:15-09:00 09:00-18:00 18:00-18:15 18:15-00:30 00:30-03:30 03:30-04:30 06:00-06:15 06:15-07:00 07:00-09:00 09:00-10:00 Duration 6-1/2 hr 12hr 12hr 1/4 hr 8-3/4 hr 3hr 1/2 hr 5 hr 1-1/2 hr 5hr 1/2 hr 9-1/2 hr 2 hr 1/4 hr 3/4 hr 5 hr 5 hr 4 hr 1/4 hr 6-1/4 hr 2-1/2 hr 2-1/2 hr 3 hr 4 hr 2-1/2 hr 3 hr 1/4 hr 1-1/4 hr 4 hr 3hr 1/2 hr 1/4 hr 3-3/4 hr 1 hr 1 hr 1 hr 1 hr 4 hr 1/2 hr 1 hr 1-1/2 hr 5 hr 4 hr 1/4 hr 2-3/4 hr 9 hr 1/4hr 6-1/4 hr 3 hr 1 hr 1/4 hr 3/4 hr 2hr 1 hr Activity Rig moved 0.00 % Rig moved 0.00 % Rig moved 100.00 % Held safety meeting Rigged up Draw works Rigged up High pressure lines Held safety meeting Circulated at 5150.0 ft Removed Xmas tree Rigged up All rams Held safety meeting Tested All rams Retrieved Hanger plug Held safety meeting Removed Tubing hanger Laid down 0.0 ft of Tubing Laid down 0.0 ft of Tubing Laid down 400.0 ft of Tubing Held safety meeting Laid down 3100.0 ft of Tubing Pulled Tubing in stands to 100.0 ft Pulled Tubing in stands to 0.0 ft Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Ran Tubing in stands to 0.0 ft Ran Tubing in stands to 0.0 ft Held safety meeting Ran Tubing in stands to 1950.0 ft Ran Tubing to 5250.0 ft (2-7/8in OD) Circulated at 5250.0 ft Pulled Tubing in stands to 5250.0 ft Held safety meeting Pulled Tubing in stands to 5250.0 ft Rigged down sub-surface equipment - Other sub-surface equipment Repaired Draw works Rigged up Tubing handling equipment Ran Tubing to 849.0 ft (lin OD) Ran Tubing in stands to 849.0 ft Held safety meeting Ran Tubing in stands to 3300.0 ft Circulated at 3300.0 ft Pulled Tubing in stands to 3300.0 ft Ran Tubing to 3300.0 ft (2-7/8in OD) Held safety meeting Ran Tubing in stands to 5250.0 ft Reverse circulated at 5800.0 ft Held safety meeting Reverse circulated at 6050.0 ft Pulled Tubing in stands to 6050.0 ft Laid down 850.0 ft of Tubing Held safety meeting Installed Tubing hanger Installed ESP Installed Tubing hanger Facility M Pt I Pad Progress Report Well MPI-01 Rig Nabors 5S Page 2 Date 05 March 98 Date/Time 10:00-13:00 13:00-15:00 15:00-16:00 16:00-18:00 18:00-18:15 18:15-21:00 21:00-06:00 Duration 3 hr 2 hr 1 hr 2 hr 1/4 hr 2~3/4 hr 9 hr Activity Rigged down BOP stack Installed Xmas tree Tested Xmas tree Freeze protect well - 90.000 bbl of Diesel Held safety meeting Cleared Flowline Rig moved 50.00 % MAR 1 6 1995 Alsska Oil & Gas Cons. Commi~, .,-.anoco Inc. Anchorage Division ,-...,'cord of Shipment of Confidential Information To Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 [] Under Separate Cover Enclosed Date From Steve Davies Conoco Inc. 3201 C Street, Suite 200 June 10, 1993 Anchorage, Alaska 99503 (907) 564-7640 Via Petroleum Couriers Subject Quantity Contents 1 L~Ot ~IE-7 Final Drilling & Completion Report C~\ ~-' ~E..7 core Analysis Report _ 1 ~..~E;7 Sidewall Descriptions C~01'~? ,~-2 Final Drilling Report C~)1~_~.,~ ~-i-3 Final Drilling Report ~:)1-%~1 ~.~1-4 Final Drilling Report (~JO1~~1-1 Final Drilling Report ~:~1.~ ~ ,, 1-2 Final Drilling Report ~~ ~ 1-3 Final Drilling Report I-3 No Whole Core or Sidewall Cores taken as noted on completion report. I-4 Final Drilling Report ~'-4A Core Analysis Report U-1 Final Drilling Report Core Analysis Report Core Description Report Final Drilling Report Completion History Final Drilling Report Final Drilling Report Final Drilling & Completion Report Final Drilling & Completion Report Final Drilling & Completion Report Core Description Report Core Analysis Report RECEIVED 0JJ & (]as Cons. Commission Anchorage ¢ Signed Transmittal Approved By .. Date Instructions: Please ng second copy. Received By Date Remarks "'June 10T-1-993 Transmittal Copy Only To Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 March 10, 1993 Mr. Larry Grant State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Grant: Enclosed are magnetic tapes in LIS format for Milne Point Unit wells H-2, H-3, H-4 and i-1. Verification lists for the tapes are also enclosed. The well locations, AP! numbers and tapes enclosed are as follows' Well# APl# Location Tape Tape Date Depths H-2 50-029-22062 Sec 34, T13N, R10E OH EDIT 10/25/90 3082.0 - 6208.5 H-3 50-029-22063 Sec 34, T13N, R10E OH EDIT 03/17/91 2825.0 - 5680.5 H-4 50-029-22064 Sec 34, T13N, R10E OH EDIT 03/17/91 2493.5 - 4543.5 i-1 50-029-22065 Sec 33, T13N, R10E OH EDIT 11/14/90 3222.0 - 6248.0 You had also requested two logs for Well No. H-3, titled "4-Arm Caliper" and "Gamma Ray-CCL". We didn't run logs with these specific titles, however, the "Borehole Geometry Log" was run using a 4-Arm caliper tool, and the Gamma Ray curve and CCL may be found on the "Completion Record" log. Both of these logs have previously been provided to AOGCC. To confirm arrival of these data, please sign the second copy of the letter and return it to me at the letterhead address. Should you have any questions, please phone me at 564-7614. Sincerely, Linda M. Starr Technical Assistant cc: SFD · . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing ~ Alter casing __ Repair well ~ Pedorate __ Other ~ Replace ESP 2. Name of Operator CONOCO INC. 3. Address 3201 "C" St., Suite 200 Anchorage, AK 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 2951' FNL, 3696' FEL, Sec. 33, T13N, R10E, U.M. 6. Datum elevation (DF or KB) 70 KB 7. Unit or Property nam_e Milne Point Unit 8. Well number I-1 feet At top of productive interval 4492' FNL, 476' FEL, Sec. 33, T13N, R10E, U.M. At effective depth At total depth 4622' FNL, 204' FEL, Sec. 33, T13N, R10E, U.M. 9. Permit number/approval number 90-90 Cll -2gq 10. APl number 50-- 029-22065 11. Field/Pool Kuparuk River/Schrader Blur 12. Present well cOndition summary Total depth' measured true vertical Effective depth: measured true vertical 6182 ' feet 4301 ' feet 6076 ' feet 4214 ' feet Plugs (measured) None None Junk (measured) None Casing Length Size Structural Conductor 70 ' 13-3/8" $udace 3239 ' 9-5/8" Intermediate Production 6122 ' 7,, Liner Perforation depth: measured true vertical Tubing (size. grade, and measured depth) Cemented 500sxsPermaFrostC 606sxsPermaFrostE 3351sxsg/528sxsE 400sxs G 5644'-5670' 5674'-5693' 3776'-3797' 3800'-3816' 2-7/8" L-80 , · 5713'-5724' 5733'-5770' 3915'-3923' 3931'-3962' 5137' MD Packers and SSSV (type and measured depth) None Measured depth True vertical depth 105' 3274' 105' 2538' 6157' 4281' 5830'-5864' 5902'-5938' 4011'-4040' 4071'-4102' RECEIVED 13. Stimulation or cement squeeze summary intervals treated (measured) N/A Treatment description including volumes used and final pressure JAN - 7' t992 Alaska 0il & 6as Cons. Commission Anchorage 14. Prior to well operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure 423 95 0 395 Tubing Pressure 395 Subsequent to operation Not Tested 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. i hereby certify that the foregoin~ is true and correct to the best of my knowledge. _Signed /~ (~ ,~' / Title Form 10-404 F~eev 06/19~8 ~' ' Date SUBMIT IN DUPLICATE CONOCO MPU I-1 ACTIVITY REPORT SUMMARY ESP REPLACEMENT 12/11/91: Move on rig location to I-1 Well. Set up rig for killing of well. Pull BPV out of hanger. Circulate (reverse) 291 BBLS of 8.6 NACL: returns of 240 BBLS - non- recoverable 51 BBLS. Pump rate of 2.3 BBLS/minute. 0 on tubing and annulus. Install BPV in WKM hanger. Nipple down well head. Resistance check on cable. Possible break @ 6' to 20' according to reading on Echoflex meter. Nu BOP's & pull BPV & install 2-way check for BOP test with AOGCC (change ram rubbers from 3-1/2" to 2-7/8"). 12/12/91: Complete BOP inspection with AOGCC. Had problems with Totco mud panel; tested BOP's 5000 & annular to 2500. Pull 2-way check & loosened lock down lugs. Sting into hanger; PU with 37,000 LBS's on indicator. Lay down hanger (WKM). Cable connector to penetrator on bottom of hanger (damaged). POOH with 2-7/8" EUE. Found cable splice below hanger to be pulled apart. Cable blown out 140' below hanger. Top of pump exposed; pump would not turn freely, very little sand indicated at pump discharge. Found metal fragments, mill varnish from tubing and both frac and formation sand around the flanged areas of assembly. Protector and motor would turn free. Break down pump assembly and lay down in pipe shed. Took fluid samples from ESP assembly. RU slickline with 1.5" pump down bailer. RIH to 5178' and tagged top of Otis gravel packer. Could not make through packer. POOH with bailer. Found no indication of sand or metal markings on bottom of bailer. Rig down slickline from floor; call out Otis with seal unit & HRS APR-M2 circulating valve. Will RIH to top of gravel packer & circulate tubing volume with 8.6 PPG NACL. Stab into Otis Versa-trieve gravel packer and RIH with bailer to tag fill. A;aska Oil & Gas Cons. 12/13/91: Wait on APR-M2 circulating valve & seal assembly for Otis type Versa-trieve packer). Clean up rig & rig down slickline unit. PU seal unit APR-M2 & 2-7/8" EUE TBG. RIH and tag packer at 5231.63'. Pickup 5' from packer entry (5251.63' from EWS rig floor). Circulate TBG volume with 8.6 ppg NACL. Sting Otis seal unit into top of gravel packer with 5000 LBS of weight. Pump brine down TBG (2 BBLS) with no communication to annulus. RU slickline unit with 1-1/2" dump bailer. RIH and tag fill @ 5970' WLM (45' below perforations). Set up for clean-out treatment. Press upon annulus in order to shear disc. on HRS APR-M2 circulating valve. Pressure up to 1000 PSI and held. Finally sheared @ 2150 PSI. Tubing press had 150 PSI increase. Mix up pills for clean-out treatment; 50 BBLS source HzO/dirt magnet. Pump on TBG. Take returns up annulus. Pump 30 BBLS down 3.5#/BBL and ~%J~displace with 210 BBLS of NAOL 8.6 PPG. RU to pump 6 ~YBBLS of super pickle down tubing with 24 BBLS of source Hz0. Reverse 41 BBLS to displace TBG. Hole looks real PU Otis seal unit out of packer 30,000 LB's. 12/14/91: POOH with HRS APR-M2 circulating valve & Otis seal unit, 2-7/8" EUE TBG. Left 2000' of TBG in derrick. Breakout circulating valve & seal unit. PU ESP assembly & equipment and lay in pipe shed. Start setting up to unload rice Eng. 2-7/8" TBG in pipe shed. RU ESP cable sheave (54") with safety line. Strap Reda ESP equipment. PU ESP equipment and MU. Take oil samples and hi-pot. RIH Reda ESP assembly 2 JTS 2-7/8" EUE, 2-7/8" check valve, 2 JTS 2-7/8" EUE 6.5#/ft 4' PUP, CAMCO 2-7/8" GL Mandrel, 4' PUP, 60 JTS 2-7/8" EUE TBG. RU to RIH with 2-7/8" EUE rice wrap TBG (file dies to prevent coating damage). RIH with 3001.29 of 2-7/8" EUE rice wrap TBG, E-Sub, 2-7/8" SUB, 2- 7/8" GL Mandrel, 2-7/8" SUB, TBG hanger. Made 1 repair on box end of rice wrap TBG. Space out bottom of pump 5137 KBM. Measure for splice to hanger penetrator. Start splice below hanger. Set alignment pin for TBG head and penetrator in hanger. 12/15/91: Complete cable splice below TBG hanger. Land tubing hanger & lock down lugs. Fished E-Sub cable through annulus valve. Retrieved electrical tape that was rapped around wiring. Hook up annulus 2" threaded connections & stuffing box for E-sub heat wiring. Nipple down BOP's & nipple up wellhead. Test wellhead to 5000 PSI. Tested OK. Pulled 2-way check after completion of test. Unable to freeze protect annulus or TBG until sub-structure moved from well head. Installed annulus valve on reserve pit side - pulled VR plug and freeze protected annulus with 70 BBLS of diesel. Then pumped 20 BBLS of diesel down tubing. Took returns in slop tank. Cleaned out brine tanks, slop tank. Installed VR plug on annulus valve next to reserve pit on I-2. Rig down and move to the I-2 well. Install BPV in I-1 hanger. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage TO: THRU: FROM: MEMORANOUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C S DATE: December 13, 1991 Commiss ioneC FILE NO: LG1213- 3. DOC Blair Wondzell Sr Petr Eng TELEPHONE NO: SUBJECT: BOP Test Conoco I-1 Permit No. 90-90 Milne Point Unit Louis R Grimaldi/~ Petr Inspector Thursdav~. ,.Dg~ember.. 12. 199! I traveled to Milne Point on December 11, 1991, to witness the initial BOP test on EWS Rig 4 which was preparing to work over Conoco's Well I-1. The test did not get under way until 3 AM the following morning. The test went fairly well with all equipment holding the pressure test adequately. The flow meter would not function and after many hours of diagnostics, the problem appeared to be in the panel. After conferring with Henry Harrington (Conoco Rep) about well conditions, these being that the well will constantly take fluid, he requested that he be allowed to proceed with the program. I agreed under the following stipulations: A) The well will be filled every 10 joints with 120% displacement; B) A man will be assigned to watch the trip tank and at the first sign of flow, the well will be shut in and kick procedures followed. The Conoco Rep agreed to this and work commenced. Ail else went well and I plan to stay in daily contact with the rig to monitor repairs to the flow meter. In summary, I witnessed a BOP Test on Conoco's Well I-1 in the Milne Point Unit. The EWS Rig had one noncompliance which was the flow meter not operating. Attachment 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 ~d/Opns. ID~3,~.07-659-7609 DEC ~.]_5,'91 9:0~,' No.O05 P.Ob TO: Lonnie C Smith Comm is s ioner THRU: Blair E wondze]l Sr ?etroleum Engr FROM' LOU Grimaldi Petr Inspector AND O]-%$ C!OMMISSION DATE: SUBJECT: ~)~ c D DEC 1 ~ 1991 Alaska Oil & Gas Cons. Commission .d/Opns. ID..4907-659-7609 DEC [.TL'91 9'02 No.O05 P.06 STATE OF ALASKA At~SKA OIL AND (~A5 CONSERVAT ION CONMiSS ION BOP Te~ Re~or~ Drtg__.__ Wkvr._~_~ HUD SYSTF.~S= Trip ~ank P~t gauge Flow monitor Cas deCeotors BOPE STACK= Annular preventer Pipe rams Blind ram~ Choke line valves HCR valve Kill line valves Check valve Test Pre~sure ,, ~0o ,F'oo 0 TE$___~T: Inittal..~ Weekly , Other .... Ca~tng ~e% ~ ft ACC~U~TOR SYSTEM: Pump incr clos press 200 psig ~ m{n Full charge press attained / mtn ~sec Control s~ Master Remote ~ 81~nd ~wi:oh cover KELLY AND FLOOR SAFETY VALVES: Upper Kelly ~ / Te,t pres,ute Ball type inside BOP Choke mantfold_~__~ Number valves Number fl enges Adjustable chokes ..... __ . .... Hydraul(call~ operated choke TEST RESULTS~ Remarks; Repair or replacement o~ fa~led ~qu~pmen~ to be made w~h~n the ln~pec~or~ and follo~ w~th wri::en/rAXed verlf~ca~ion /~- ..-- ..... r i- ... -- -- .. ~. -~, m,,[ .... il il ,11 ,,,~, _ m "----- ..... . '-- ......... RECEIVED/. o~.- ^o~cc DEC 1 ~ 199I w,T.~ss .. /.., .. c - Operator e - Supervi sot Alaska Oij & Gas Cons. ~mmission C.OOQ (rev 07/08/gl ) ~chorage 1. Type of 'Request: Abandon STATE OF ALASKA ALAbr~,A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Suspend m Operation shutdown Re-enter suspended well / . ,. Alter casing Repair well Change approved program __ Plugging __ Time extention Stimulate Pull tubing. X Variance Perforate __ Other Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 Location of well at surface 2951' FNL, 3696' FEL, Sec. 33, T13N, R10E, U.M. At top of productive interval 4492' FNL, 476' FEL, Sec. 33, T13N, R10E, U.M. At effective depth At total depth 4622' FNL, 204' FEL, Sec. 33, T13N, R10E, U.M. 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 7O KB 7. Unit or Property name Milne Point Unit 8. Well number I-1 9. Permit number 90 -90 10. APl number 5O-O29-22O65 11. Field/Pool Kuparuk River/Schrader Bluff feet 12. Present well condition summary Total depth: measured 6182 feet true vertical 4301 feet Effective depth: measured 6076 feet true vertical 4214 feet Casing Length Size Structural Conductor 70' 13-3/8" Surface 3239' 9-5/8" Intermediate Production 6122' 7" Uner Perforation Depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Plugs (measured) None Junk (measured) None Junk (measured) None Cemented 500 SXS. PermaF C 606 sxs PermaF E 3351 sxs. E/528 sxs. E 400 sxs. G Measured depth True vertical depth 105' 105' 3274' 2538' 6157' 4281' 5644'-5670' 5713-5724' 5830-5864' 5674'-5693' 5733'-5770' 5902'-5938' 3776'-3797' 3915-3923' 4011'-4040' 3800'-3816' 3931'-3962' 4071'-4102' 2-7/8", 6.5#, L-80 EuE 5223' MD None RECEIVED S E P 0 3 199 Alaska Oil & Gas Cons. c0mmiss[e[t 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 10/01/91 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas ... Suspended Service 17. I hereby certify that the for .egoing is true and correct to the best of my knowledge. Signed ~.~..~ ~'~4~~. G. Augustine Title Sr. Production Engineer / FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test . Location clearance Mechanical Integrity Test __ SUbsequent form required 10-../~ c ,-J't' ORIGINAL SIGNED BY Approved by order of the Commission LONNIE C ~MITH Commissioner I^..row,.o. # :~pproved Copy Returned ~1. ;z e - q I Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MIRU EWS #4 rig. MILNE POINT UNIT OUT FILL AND RUN NEW SUMMARY PROCEDURE 2. Kill well with 8.5 ppg NaCl. ND production tree. NU BOPE and test. 3. POOH with tubing, ESP, and ESP cable. LD ESP and cable. 4. RU slickline unit and RIH with wireline tools. Tag fill. 5. POOH with wireline and RD unit. 6. RIH with seal assembly on 2-7/8" tubing and sting into gravel pack packer at 5250'. Pressure test annulus to 500 psi. 7. RU coiled tubing unit. RIH with coiled tubing and circulate out fill to PBTD. 8. POOH with coiled tubing and RD coiled tubing unit. 9. POOH with 2-7/8" tubing and seal assembly. 10. PU new ESP, motor, and cable. RIH with ESP assembly and tubing. Set bottom of pump at 5200'. 11. ND BOPE and NU production tree. RDMO rig. 12. Return well to production. RECEIVED 8 £ P 0 ~ ~991 Alaska Oil & Gas Cons. Commissi_~r~ Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-76OO July 15, 1991 Mr. David Johnston Commissioner, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: RE: Reservoir Pressure Report; Report of Sundry Well Operations Attached please find a Reservoir Pressure Report for Well G-8 and a Report of Sundry Well Operations for Well I-1. Both wells are located on the Milne Point Unit. If you have any questions or require additional information please contact me at 564-7617. Yours very truly, Bob Soptei Environmental Coordinator RJS(bgs) Attachments CC G-8 Well File I-1 Well File STATE OF ALASKA ALA~r,~ OIL AND GAS CONSERVATION COMMI$~,.,,q REPORT OF ,SUNDRY WELL OPERATIONS 2. Name of Operator CONOCO :[NC. 3. Address P.0. Box 340045, Prudhoe Bay, AK Location of welt at surface 2951' FNL, 3696' FEL, SEC 13, At too of ¢)mductive interval 4492' FNL, 476' FEL, SEC 13, At effective de~th 4539' FNL, 190' FEL, SEC 13, AI total depth Type of Well: Development _--X t~xolor~toty __ Stratiqra~nic __ Ser,~e __ ........ T13N, RZOE, UH T13N, RZOE, UH T13N, RZOE, UH 12. Present welt condition summary Total de~ti~; measurec¢ true vertical Effective depth: :measured true vertical 6182 4301 6O76 4214 feet Plugs (measured) feet feet Junk (measured) feet Casing Length Size Cemented Structural Conductor 105' 13-3/8" 500 sxs PERHAF C Surface 3274' 9-5/8 1485 sxs PERNAF E intermediate PrOduCtion 6,157' 7" 400 SXS G Liner =erforation deptl~:measured 5644-5670 5713-5724 5674-5693 5733-5770 true vertir.~t 3776-3797 3915-3923 3800-3816 3931-3962 Tubing($ize,.qrade, andmeasureOcteptn) 2-7/8",6.5#,L-80 EUE 5223' ND Pack, em aha SSSV (type and measured deCh) 13. Stimulation or cement squeeze summary 'N/A Other .._X 6. Daium elevation (OF or KB) ....... Z.q' KB feet 7, Unit or Property name Milne Point Unit j., · . 8, Well numOer f-1 9. Permit number/doctoral numD~r-- go-go IL 10. APl number 5O-- 029-22065 __ "11. Field/Pool Kuoaruk R_iver Fi el d Schlrader Bluff Pool none none Measured depth True vertical depth 105' 3,274' 6,157' 105' 2,538' 4,281' 5830-5864 5902-5938 4011-4040 4071-4102 I ntervats treated (measured) N/A Treatment description including volumes used anti final pressure Rep_r_e. _~entative Daily Average-.~)cluction or tnjectJon D_a._t_a OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pre. ute Prior to well operation SubseQuent to operation 15. Attact~ments Copies of Logs and Surveys run _._ Daily Report of Welt Ooerations 487 225 6 487 225 6 · 16. S~tusofwetlclassifica~onas; 376 376 376 376 O11 _X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the be~t of my knowledge. Form 10-404 Rev 06/15/88 TrUe SENIOR PRODUCTION FORgt4AN Date, ,,'-7..1~ ~'~ q t SUBMIT IN DUPLICATE CONOCO MILNE POINT UNIT MPU I-1 WELL ACTIVITY SU~Y June 23, 1991 MIRU Frac Master CTU w/1.5" coil. MIRU HB&R hot oil truck. RU to 1000 gal. slop tank through choke manifold. Hold safety meeting. Pressure test lines/coil to 3000 psi. Good test, no leaks. RIH w/2.15" nozzle, 2 checks to 1000' CTM. Begin heating and pumping diesel @ 1 bpm/2000 psi/150 F. Take returns to tank. Vac out oil/circulate diesel clean. Soft tag at 1860' CTM. Work through ice/hydrates to 2644'. Tagged hard. Work through numerous plugs to 2700' CTM. RIH to 5100' CTM. Circulate bottoms up. POOH pumping at .25 bpm. RDMO. Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 June 21, 1991 Mr. David Johnston Commissioner, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: RE: Application for Sundry Approval Attached please find an Application for Sundry Approval for Well I-1 on the Milne Point Unit. If you have any questions or require additional information please contact me at 564- 7617. Yours very truly, Bob Soptei Environmental Coordinator RJS(jcd) Attachments cc I-1 Well File RECEIVED JUN ~ 6 t991 .Alaska 0ii & Gas Cons. Commission Anchorage 1. Type of Request: Abandon STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Suspend __ Operation shutdown Re-enter suspended well Alter casing Repair well Change approved program__ Plugging__ Time extenfion Stimulate__ Pull tubing Variance __ Perforate ~ Other X 2. · . 12. Name of Operator Conoco Inc. Address 3201: C Street, Suite 200 Anchorage, AK 99503 5. Type of Well: Development X Exploratory Stratigraphic , ,. Location of well at surface 2951' FNL, 3696' FEI., Sec. 13, T13N, R10E, Umiat Meridian At top of productive interval 4492' FNL, 476' FEL, Sec. 13, T13N, R10E, Umiat Meridian At effective depth 4539' FNL, 190' FEL, Sec. 13, T13N, R10E, Umiat Meridian At total depth 4622' FNL, 204' FEL, Sec. 13, T13N, R10E, Umiat Meridian 6. Datum elevation (DF or KB) 70 KB feet Present well condition summary Total depth: measured 6182 true vertical 4301 Effective depth: measured 6076 true vertical 4214 feet feet feet feet Plugs (measured) None ':" Junk (measured) None 7. Unit or Property name Milne Point Unit 8. Well number I-1 9. Permit number 10. APl number 50-029-22065 11. Field/Pool Kuparuk River Field Casing Length SiZe Structural .. . Conductor 105' 13-3/8' Surface "3274' .. 9-5/8' Intermediate Production 6157'.:. 7' Uner Perforation Depth: measured 5644'-5670' 5674'-5693' true vertical 3776'-3797 3800'-3816' Tubing (size, grade, and measured depth) . 2-7/8", 6.5#, L-80 EUE 5223' MD Packers and SSSV (type and measured depth) None Cemented Measured depth 500 sxs PermaF C 105' 1485 sxs PermaF E 3274' .. 400 sxs G 6157' .. / 5713'-5724' 5830'-5864' 5733'-5770' 5902'-5938' 3915'-3923' ': 4011'-4040' 3931'-3962' 4071'-4102' True vertical depth 105' 2538' 4281' RE(ZEIVEO JUN 2:6 Alaska 0il & 6as Cons. Anchorage 13. Attachments Description summaryof proposal X _ Detailed operations program _- BOP sketch 14. Estimated date for commencing operation 6/22/91 · : . 16. If.pro_pOsal was verbally approved Name of approver - Mike Minder : 6/21/91 Date approved 15. Status of well classification as: Oil X Gas Suspended~ Service 17. I hereby ce~ifythat the ~is true and correct to the best of my knowledge. · S gned ~ B.' G. Aucjustlne Tit~e Senior Production Engineer' FOR COMMISSION .USE ONLY Conditions of approval: Notify Commission so representative may witness ... Plug integrity BOP Test __ Location clearance _.~ OrlglnalMechaniC~lsigned I[~/grity Test ---- Subsequent form required 10- ~0~ David W. Johnston Approved by order of the COm~t~[=='~ ~;~ Form 10-403 ReV 06/15/88 . Date 06/21/91 IApproval No.. Approved Copy ... °'" SUBI~IIT'IN I'RIPLICATE MILNE POINT UNIT I-1 COILED TUBING CLEAN-OUT PROCEDURE This operation was verbally approVed by Mike Mind,r, AOGCC, on June 21, 1991. Hold pre-job safety meeting to diSCuss workover procedure and safety ·-considerations. . · MIRU coiled tubing unit. Spot 1000 gal. tank and choke manifold. RU hot oiler with 50-70 bbls. of diesel. Heat diesel to 150 degrees F. 3. Pressure test surface eqUipment to 2000 psi. 4.- RIH with coiled tubing, displacing with diesel from hot oiler. Take returns from 1-1/2" x 2-7/8" annulus through choke manifold and into the 1000 gal. tank. 5. Tag ice plug at approximately 1850' and circU'late hot diesel. Work through ice plug. After working through ice plug, continue to RIH to AVA isolation sleeve at 5113'. Circulate bottoms up. 6. POOH with coiled tubing. RDMO coiled t'Ubing ~nit. 7. Consult Engineering before ESP start-up. RECEIVED · · dUN 2 ~ 't§D~ .Alask~ Oil & (.'~:~s L:;ons. Commiss~.o~-. Anet~omge STATE OF ALASKA ¢~-- : "' ALASKA _ AND GAS CONSERVATION Ct 41SSION ~; WELL COMPLETION OR RECOMPLETION REPORT AND LOG Status of Well Classification of Service Well , OIL [~ GAS [] SUSPENDED' ~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number CONOCO INC. ! ~.,,'~;;i~:~;:{i~ 90-90 3. Address i :_'~u~~'I~ 8. APl Number POUCH 340045, Prudhoe Bay, Alaska 99734 !~:~,~ so-029-22065 . 4. Location of well at surface '!~~..~' I 9. Unit or Lease Name . ,.¢~~/~ Milne Point Unit 2951'FNL x 3696'FEL Sec. 33, T13N, R10E, Umiat Mer~d~a~E~lR~ At Top Producing Interval 10. Well Number 4492'FNL x 476' FEL of Same Section At Total Depth 11. Field and Pool 4622'FNL x 204' ~EL of Same Section. KUPARUK RIVER FIELD 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 70 KB ADL - 25906 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. N,o. oi Completions 10-18-90 10-24-90 1-28-91I N/A feet MSt 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 6182 + 4301 6076 + 4214 YES ~ NO [] NONE feet MDI + 1800 22. Type Electric or Other Logs Run DITE, LDT, CNL, AMS, NGT, PIT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8 54.5~ K-55 35 105 30 500 sxs PermaFrostC NONE "9-5/8 36~f J-55 35 3274 12-]/4 See Attch. Descpt. NONE 7 26~f L-80 35 6157 8-1/2 400 sxs G NONE 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) N Sand 2-7/8 5223 NONE 5644-70 MD 3862 TVD 12 SPF, 24 GM 5674-93 26. ACID, FRACTURE, CEMENT sQuEEzE, ETCi 5713-24 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5733-70 MD 3967 TVD 5830-5938 85284¢/ 16-20 Mesh Proo~an¢_ 0 Sand 5830-5864 MD 4016TVD 5 SPF, 37 GM 5902-5938 MD 4106TVD 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc,) Not Tested Submersible Pump , -- Date of Test Hours Tested PRODUCTION FOR OIL~BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RA'TIo TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)" Press. 24-HOUR RATE ~ 28.. CORE DATA Brief description of lithotogy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS -- NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top of "N" Sand 5644' 3862' NA Top of "0" Sand 5830' 4016' 31. LIST OF ATTACHMENTS Cement Addendum, Plat, Gyro Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~J~-~/~~~) Title Sr. Prod. Foreman Date 4-28-91 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". Form 10-407 CONOCO INC. MILNE POINT UNIT WELL: I-1 FORM: 10-407 ADDENDUM SUBJECT: STAGE CEMENT JOB ON 9-5/8" CASING A. DATE OF JOB: 10-21-90 B. CASING: 9-5/8" 36# K-55 BUTT, @3274 TWO STAGE COLLAR @ 475' C. FIRST STAGE: LEAD: 606 SXS PERMAFROST E @ ll.6PPG TAIL: 3351 SXS E CALCULATED TOC @ 12.3PPG @ 1700' D. SECOND STAGE: SINGLE SLURRY: 528 SXS E @ 12.6PPG CEMENT CIRCULATED 2.'3 4'41" NOTES: 1. STATI~ PLANF., COORDINATES ARE ZONE 4, 2, ALL CIEOOETIC POSITIONS ARE BASEl) ON N,A.D, 192.7, 3. OFFSI-"T~ TO SECTION LINES ARE 0OMPUTED BASED ON PR0,'rEACTED VALUt:'S OF THE SECTION CORNER POS1T~ONS, i PAD PROPOSED i .___ __ EXPANSION PI ~ I-3. $ 87'25'19" E Y 6,009,284.4.86 4.10,00' X 5.51,787.589 ~LNE POINT UNIT ..---~ I PAD ~ '"~ P/~VYOYR gaY ~IL~£ Po~Nf ~ ~OnO ~' ~ ~ ~E MILNE PT. V[CINIT"( MAP MILES LEGEND EXISTING' WELL O PROPOSED WELL AS-BUILT WELL DATA LOCATED WITHIN SECTION 33 T. 13 N., R. 10 E., U.M., ALASKA PLANT COORD$ A.$.P. ZONE 4. [ LATITUDE ¢OORD$ LONGITUDE SEC. LINE OFFSETS 1120.60 Y 6,009,445.29 70' 26' 11.584' 2951' FNL 1380.4.6 X ,551,675.16 1¢9' ,34' 4.3.261" 3696' F'EL 1120.4,7 Y 6,009,4,47.85 70' 26' 11.614.' 294,8' FNL 1320.,51 X ,551,615.27 14.9' 34/ 4.5.019' 3756' FEL Nl120.14, Y 6,009,4.50.22 70' 26' 11.64.1" 294.5' FNL 1260,4.1 X 5,51,555.2.3 1¢9' 54.' 4.6.780' ,3816' FEL 1119,98 Y 6,009,4,57_..80 70' 26' 11.670" 294,2' FNL 1199,66 X 551,494,,$4 14.9' 34/ 4.8.561" 3876' FEL sLJ'R'(~EYOR'S CERTIFICATE tim I HEREBY CERTIFY THAT ~ AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF' ALASKA, AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY DIR- ECT SUPERVISION,AND THAT ALL DIMENSIONS AND OTHER DE;TAILS ARE CORRECT, SURVEYED FOR: Cconoc.o_) DATE: 3-27-91 DRAWN: ATOLL C.~-CX~:HE..:Ne WELL CONDUCTOR AS-BUILTS aOBNO.:~oosg I-1 I-2 I-3 & I-4 SCALE: !" ,,, 300' ~ ' i ii iiii --- . OPERATOR: CONOCO, INC. MILNE POINT UNIT I-1 FINAL DRILLING REPORT WELL: MPU I-1 CASING: 133/8"@ 110 FIELD: KUPARUK 9 5/8" @ 3274 7"@ 6160' -~/r~? - / 7. PT~.' 6109 MD PR~(~GRESS: 726 CURRENT TD: 61 82 DATE: 10-20-90: 10-21-90: 10-22-90: 10-23-90: 10-24-90: 10-25-90: 10-26-90: 10-27-90: 10-28-90 DESCRIPTION OF OPERATIONS: Move rig f/H to I pad. RU. PU rig at 0100 hrs 10-19-90. NU diverter. MU 12 1/4" BHA. Spud well at 1330 hrs 10-19-90. Drill 110 to 935. Drill 935 to 1335. Short trip. Ream 1204 to 1335 for dogleg. Drill to 2080. Ream dogleg f/2015 to 2080. Drill to 2363. Short trip. Drill to 2689. Drill to 3435. C & C. Short trip. Ream tight spots @ 2193, 2383, & 2540. Circ. Short trip. POOH. Run 4 arm caliper on E/L. RU to run 9 5/8" csg. Run 84 jts 9 5/8" csg, 36#, J-55, Butt. Circ. Cmt w/270 8BL 12.3 PPG E cmt, 218 BBL 11.8 PPG E cmt, & 72 BBL 15.8 PPG G cmt. Lost returns before pumping G cmt. Unable to land csg in WH (30 ft high). Bump plug. TOC est @ 1700 ft. Test csg to 1500 psi. ND diverter. Weld on emergency slips. Cut csg. NU diverter. RIH w/FO R/T and RTTS. Open 9- 5/8" FO collar @ 475. Establish circ thru FO tool. Cmt 9 5/8" csg f/475 to surface w/190 BBL 12.3 PPG Permafrost E cmt. Good cmt returns. Close FO tool. Test csg to 2000 psi. POOH. ND diverter. Weld on 9 5/8" coupling. Install screw on speed head. NU BOP. Test same. MU 8 1/2" steerable BHA. RIH. Circ out contaminated cmt f/475 to 649. C & C. RIH. Drill out FC. Test csg to 1500 psi. Drill out FS & 10' formation to 3445. Circ. Perform LOT to 12.8 PPG EQUIV. Drill to 3660. Drill 3660 to 4323. Short trip. Drill to 5171. MWD quit. POOH. Change out MWD. RIH. Drill to 5456. Drill 5456 to 6182. C & C. Short trip. C & C. POOH. RU w/DITE-LDT-CNL-AMS-NGT-PIT. Could not get below 4050. POOH w/E/L. bow spring and PIT. RIH. Log f/TD to 3274. POOH. RIH w/bit. C & C. E/L. RIH Remove Circulate and condition hole to run casing. Change pipe rams to 7". POOH and LD drill pipe and BHA. Pull wear bushing. R/U casing crew to run 7" casing. Ran 154 joints of 7" casing and cemented with 84 bbl class G cement displace with 210 bbls brine followed with 22 bbls diesel. Bumped plug with 1,500 psig held for 2 minutes and released. Held ok. Tested casing at 1,500 psig for 30 minutes ok. Inject 822 bbls mud from pits into 7"x 9-5/8" annulus. Pumped 65 bbl. diesel artic pack. Finished cleaning pits released rig at 1030 hrs 10-27-90. Operations suspended. RIG RECEIVED: 10-19-90 SPUD DATE: 10-19-90 RIG: NABORS 27 DAYS: 9 / 10 FOREMAN: POLYA DATE: 10-29-90 Milne Point I No. 1 COMPLETION HISTORY Kuparuk River - SBP - North Slope Borough, Alaska W.I. 1.0 Milne Point I No. 1 (P) CONFIDENTIAL AFE 10-61-1255 Location: 2951' FNL, 3696' FEL, Sec. 33, T13N, R10E, U.M., NSB AK Location: Bottom hole, 4725' FNL, 265' FEL, Sec. 33, T13N, R10E, U.M. Objective: 6182' MD- Schrader Bluff 01-17-91: MIRU on I-1. Rig accepted @ 1500 hrs 01/16/91. Thaw / ND tree. NU BOP. Modify overflows in pits to increase pit volumes. Off-load 227 bbls 8.6 ppg NaCl w/ 12% MeOH. Set up berm for filter unit. Load pipe shed w/ 3-1/2" DP. Need to change hydril rubber. Mud wt. 9.2 Viscosity: N/A Cum. Cost: $ 1,081,448 POOL 102 (0-9-1) Drillinq Foreman: STEVENS 01-18-91: Continue NU BOP. Change to 3-1/2" pipe rams. Test BOP's & blind rams. Begin P/U drillpipe to RIH. Wash & drill ice f/ 500' to 580'. Continue P/U pipe & RIH. Mud wt. 9.2 Viscosity: N/A Cum. Cost: $ 1,103,785 POOL 102 (0-9-2) Drillinq Foreman: STEVENS 01-19-91: Continue P/U drill pipe & RIH, tagged fill @ 6017'. Reverse out 9.2 ppg brine & dilute w/ MeOH & H20 to 8.6. Filter same. Attempt to reverse out Pill, washed f/ 6017' to 6035', couldn't work any deeper. P/U kelly & drill f/ 6035' to 6054' could not drill off at 6054' Reverse out brine , · contaminated w/ cement. Pump 20 bbls H20 w/ 1/2 drum of dirt magnet. 01-20-91: Circulate & filter 1 hole vol. POOH f/ 6054'. R/U E/L, RIH w/ GCT to 6003' & log. R/U GR/CCL/perf guns, test packoff to 500 psi. Perf f/ 5938' - 5918'; shot 5 SPF, 37 gm charge. RIH w/ CCL/perf guns, perf f/ 5902' - 5918'. RIH w/ CCL/perf guns, perf f/ 5844' - 5864'. RIH w/ CCL/perf guns, perf f/ 5830' - 5844'. R/D Schlum., P/U 3 JTS 2-7/8" tbg/Champ III PKR/Big J. Jars/4 DC - RIH, set PKR @ 5622'. 01-21-91: Test PKR to 1100 psi. Perform frac job. R/D. Press tbg to 800, would not fall off; press annulus to 700 psi & open bypass in PKR. No change in pressures. Monitor csg press - gradually fell to 300 psi. R/U slickline w/ 2" impression block. RIH. Could not fall past 3820'. POOH. Found frac sand on impression block. R/U 1" OD bullnose/20' wt bars/spangs. RIH tagged up @ 3820' - soft tag; no spang action. POOH (tools had frac sand on them). R/D slickline. Monitor csg pressure (200 psi @ 2000 hrs). Mud wt. 8.4/8.6 Viscosity: N/A Cum. Cost: $ 1,348,669 POOL 102 (0-9-5) Drillin~9~a~:_BRADY Milne Point I No. 1 Completion History Page 2 01-22-91: Allow wellbore pressure to fall to 90 psi. Bled tbg pressure to zero; annulus press still 90 psi; strip out of hole 5 stands; bled annulus pressure to zero; allow well to bleed down. POOH to 3800' Attempt to reverse sand out of pipe - no success. ContinUe POOH, found sand f/ tbg tail. P/U bailer assby w/ 30 jnts of cavity (5.9 bbls). RIH. Mud wt. 8.6 Viscosity: N~m. Cost: $ 1,404,036 POOL 102 (0-9-6) Drillinq Foreman: BRADY 01-23-91: RIH w/ bailer. Bail f/ 5930' - 6050'. POOH, retrieved 4.7 bbls of sand. P/U bit/csg scraper/4 DC. RIH. Tagged fill @ 6033' reverse & work down to 6040' recovered some sand over shakers. Filter brine. POOH. R/U E/L. Mud wt. 8.6 Viscosity: N~m. Cost: $ 1,435,775 POOL 102 (0-9-7) Drillinq Foreman: BRADY 01-24-91: R/U Schlum. RIH w/ 6.0" OD gauge ring & junk basket to 5800'; POOH. RIH w/ sump PKR. Set PKR @ 5790. POOH. P/U seal assby w/ straight slot locator. P/U TCP guns (12 SPF), to shoot following intervals: 5644-5670, 5674-5693, 5713-5724, 5733-5770. RIH. Space out guns by stacking out on PKR then P/U to perf location. Set Champ III PKR; test annulus to 500 psi. Pump 36 bbls diesel; 350 psi underbalance; drop bar - no detonation. Press up to 3000 psi, guns fired. Allow well to flow; no pressure @ surface; well flowed 1 bbl. Open APRM to annulus; reverse out 2-1/2 TBG vols. Recovered diesel cut crude @ surface. P/U 15' , allow junk to settle. Work 3-1/2" OD pup in & out of sump PKR. POOH w/ TCP assby. Mud wt. 8.6 Viscosity: N~m. Cost: $ 1,531,558 POOL 102 (0-9-8) Drillinq Foreman: BRADY 01-25-91: POOH w/ TCP assby. P/U gravel pack assby. RIh, snap into collet locator. Drop ball. Tests lines to 5000 psi; set PKR @ 5250'. Test annulus to 1500 psi. Shift to reverse & press up to shift ball seat. Pump gravel pack. Bleed press & observe falloff; reverse out. Wait on gels, reverse out 1.6 tbg volumes @ 5 bpm. Recovered 10 bbls of slurry; continue to reverse. Retest Pack to 3000 psi - good test. R/D Howco. Mud wt. 8.6 Viscosity: N~m. Cost: $ 1,594,110 POOL 102 (0-9-9) Drillinq Foreman: BRADY/MARTIN 01-26-91: POOH. L/D drillpipe. RIH w/ TDT/GR; Log f/ 5788' to 5100'; good pack indicated f/ 5788' to 5500' (91' above top of main screen). R/U 1.75" wt bars/bull nose - RIH attempt to break disk @ 5788', no success; P/U 2 more wt bars & spangs (4 total wt bars = 250 lbs.) RIH, attempt to break disk - no success; POOH, R/D. R/U slickline; RIH w/ spangs/ wt bars/bullnose. Work tools to break disk; disk broken, POOH. Found perforation junk in spangs & knuckle joints. R/D MO slickline. Milne Point I No. 1 Completion History Page 3 01-27-91: Pull wear bushing. P/U REDA ESP assby. Run tubing. Splice cable to lower pigtail. Land tbg hanger in wellhead, test body seals to 5000 psi; install BPV. N/D BOP. 01-28-91: N/D BOP. N/U tbg head adapter spool. Breakdown tree & reorient valves. Test tree to 5000 psi, pull 2-way check, install BPV. Pump 55 bbls diesel into annulus; pump 5 bbls into tbg. Rig released 1330 01-27-91 to I-2. Operations Suspended. Mud wt. 8.6 Viscosity: N~m. Cost: $ 1,840,578 POOL 102 (0-9-11) Drillinq Foreman: BRADY RECEIVED 'ONIGIN4 l' SUB. SURFACE DIRECTIONAl. SURVEY )-~UIDANCE [~]ONTINUOUS ~____]OOL Company c0.oco INC. Well Name MPU I-1 (2951' Field/Location FNL, 3696' FEL, SEC 33, T13N, RIOE) SCHRADER BLUFF, NORTH SLOPE, ALASKA Job Reference No. 74308 Logaed 8~. BARNARD/WEST MICROFILMED °.,, ..... Computed KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR CONOCO INC. MILNE POINT UNIT I-1 SCHRADER BLUFF NORTH SLOPE, ALASKA SURVEY DATE: 19-JAN-91 ENGINEER: BARNARD/WEST METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- Averaged deviation eno azimuth INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 65 DEG 19 MIN EAST COMPUTATION DATE: 24-JAN-91 PAGE CONOCO INC. MILNE POINT UNIT I-1 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 19-JAN-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: BARNARD/WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTh DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORD]NATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN O.O0 0.00 -70.00 0 0 N 0 0 E 100.00 100.00 30.00 0 14 S 27 53 E 200.00 199.99 129.99 0 34 S 44 19 E 300.00 299.99 229.99 0 30 S 51 6 E 400.00 399.98 329.98 0 46 S 37 46 E 500.00 499.94 429.94 2 45 S 58 27 E 600.00 599.67 529.67 5 23 S 63 6 E 700.00 699.06 629.06 7 11 S 64 45 E 800.00 798.02 728.02 9 23 S 66 11 E 900.00 896.31 826.31 12 9 S 66 19 E 0.00 0.00 0.00 N 0.00 E 0.00 N 0 0 E 0.31 0.15 0.24 N 0.45 E 0.51 N 61 41 E 0.97 0.37 0.36 S 0.90 E 0.97 S 68 22 E 1.87 0.00 0.93 S 1.63 E 1.85 S 60 9 E 2.77 0.99 1.71 S 2.27 E 2.84 S 52 54 E 5.40 2.96 3.55 S 4.31 E 5.55 S 50 30 E 12.68 1.43 6.88 S 10.79 E 12.80 S 57 28 E 23.59 1.68 11.62 S 20.62 E 23.67 S 60 36 E 37.96 2.07 17.57 S 33.70 E 38.01 S 62 28 E 56.29 3.5,4 24.96 S 50.48 E 56.31 S 63 41 E 1000.00 993.27 923.27 16 5 1100.00 1088.71 1018.71 18 30 1200.00 1182.32 1112.32 22 32 1300o00 1273.54 1203.54 25 23 1400.00 1362.66 1292.66 28 16 1500.00 1449.67 1379.67 30 45 1600.00 1534.60 1464.60 33 41 1700.00 1615.58 1545.58 36 49 1800.00 1695.48 1625.48 36 43 1900.00 1774.72 1704.72 38 43 S 66 7 E 80.67 3.33 S 66 13 E 110.49 3.33 S 66 37 E 145.60 3.87 S 66 9 E 186.54 2.15 5 66 52 E 231.86 2.00 S 67 23 E 281.10 1.81 S 67 22 E 333.84 6.16 S 68 38 E 392.42 0.68 S 68 32 E 452.44 1.00 S 67 44 E 513.35 2.20 34.78 S 72.80 E 80.68 S 64 28 E 46.84 S 100.07 E 110.49 5 64 55 E 60.88 S 132.26 E 145.60 S 65 17 E 77.31 S 169.77 E 186.54 S 65 31 E 95.35 S 211.35 E 231.86 S 65 43 E 114.51 S 256.74 E 281.12 S 65 58 E 134.93 S 305.39 E 333.88 S 66 10 E 156.81 5 359.81 E 392.50 5 66 27 E 178.57 S 415.87 E 452.58 S 66 46 E 201.37 S 472.43 E 513.55 S 66 55 E 2000.00 1851.23 1781.23 41 3 2100.00 1925.90 1855.90 43 56 2200.00 1994.34 1924.34 48 51 2300.00 2059.03 1989.03 49 41 2400.00 2122.79 2052.79 52 10 2500.00 2181.16 2111.16 55 49 2600.00 2235.03 2165.03 58 16 2700.00 2285.17 2215.17 61 48 2800.00 2331.79 2261.79 62 47 2900.00 2376.19 2306.19 64 D S 67 44 E 577.67 S 67 28 E 644.12 S 66 54 E 716.96 S 66 49 E 793.18 S 66 20 E 870.19 S 66 5 E 951.35 S 65 36 E 1035.58 S 66 3 E 1122.08 5 65 54 E 1210.54 S 65 55 E 1300.14 0 24 8 25 421 0 85 5 90 3 15 0 49 2 23 3 34 1.60 225.77 5 532.00 E 577.92 5 67 0 E 251.08 5 593.50 E 644.42 5 67 4 E 279.46 5 660.62 E 717.29 S 67 4 E 309.36 5 730.76 E 793.55 S 67 3 E 340.11 5 801.38 E 870.57 $ 67 0 E 372.75 S 875.71 E 951.74 S 66 57 E 407.17 S 952.59 E 1035.96 S 66 51 E 442.68 S 1031.46 E 1122.44 S 66 46 E 478.76 S 1112.24 E 1210.90 S 66 43 E 515.29 S 1194.05 E 1300.50 S 66 39 E 3000.00 2419.17 2349.17 64 50 3100.00 2461.97 2391.97 64 32 3200.00 2505.62 2435.62 63 51 3300.00 2549.90 2479.90 63 16 3400.00 2595.02 2525.02 62 34 3500.00 2641.42 2571.42 61 33 3600,00 2689.67 2619.67 61 4 3700.00 2735.79 2665.79 64 9 3800.00 2779.36 2709.36 64 22 3900.00 2820.45 2750.45 67 25 S 66 45 E 1390.41 S 66 8 E 1480.77 S 65 29 E 1570.73 S 64 41 E 1660.39 5 63 28 E 1749.62 S 61 37 E 1838.06 S 61 14 E 1925.46 S 61 4 E 2013.93 S 62 11 E 2103.74 S 65 25 E 2194.84 1.02 1.04 0.91 2.35 3.02 2.49 1.23 2.29 2.85 5.07 551.37 S 1276.82 E 1390.78 S 66 39 E 587.48 S 1359.67 E 1481.16 S 66 38 E 624.33 5 1441.75 E 1571.12 S 66 35 E 661.99 S 1523.11 E 1660.76 5 66 31 E 700.73 S 1603.51 E 1749.93 5 66 24 E 741.99 S 1681.88 E 1838.28 S 66 12 E 783.81 S 1758.85 E 1925.59 5 65 59 E 826.72 S 1836.49 E 2013.99 S 65 46 E 869.66 S 1915.60 E 2103.76 S 65 35 E 910.16 5 1997.24 E 2194.85 S 65 30 E COMPUTATION DATE: 24-JAN-91 PAGE 2 CONOCO INC. MILNE POINT UNIT I-1 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 19-JAN-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: BARNARD/WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPT~ DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTh FEET DEG/100 FEET FEET FEET DEG 4000.00 2856.83 2786.83 69 4 4100.00 2894.16 2824.16 66 5 4200,00 2937.56 2867.56 63 5 4300.00 2983.81 2913.81 62 6 4400.00 3032.55 2962.55 59 42 4500.00 3085.92 3015.92 55 34 4600.00 3143.07 3073,07 54 52 4700.00 3201.32 3131.32 53 55 4800.00 3260.81 3190.81 52 58 4900.00 3321.95 3251.95 52 5 S 65 55 E 2287.97 5 67 18 E 2380.71 S 68 3 E 2470.69 S 67 32 E 2559.27 S 68 20 E 2646.48 S 68 1 E 2730.92 S 68 2 E 2812.87 5 65 55 E 2894.10 5 64 52 E 2974.48 5 62 42 E 3053.58 1.29 6.65 985.49 S 2167 2.24 1019.23 5 2250 1.25 1052.70 5 2332 1.42 1085.36 S 2413 2.52 1117.04 S 2492 1.68 1147.65 S 2568 3.23 1178.93 S 2643 1.68 1212.57 S 2716 0.68 1247.69 S 2787 947.96 S 2082 37 E 2287.99 5 65 31 E 19 E 2380.74 S 65 33 E 71E 2470 74 5 65 38 E 81E 2559 33 5 65 43 E 78 E 2646 57 5 65 47 E 15 E 2731 04 5 65 51E 28 E 2813 04 S 65 55 E 30 E 2894 29 S 65 58 E 30 E 2974 67 5 65 57 E 21E 3053 73 5 65 53 E 5000.00 3383.25 3313.25 52 14 5 62 9 E 3132.48 5100.00 3446.84 3376.84 48 45 5 63 7 E 3209.54 5200.00 3515.29 3445.29 44 31 5 63 54 E 3282.37 5300.00 3588.27 3518.27 41 57 5 62 4 E 3350.66 5400.00 3663.83 3593.83 40 43 5 62 12 E 3416.07 5500.00 3741.11 3671.11 37 42 5 63 0 E 3479.43 5600.00 3821.28 3751.28 35 6 5 63 35 E 3539.14 5700.00 3903.81 3833.81 34 10 5 63 45 E 3595.60 5800.00 3986.63 3916.63 34 10 5 63 I E 3651.60 5900.00 4069.28 3999.28 34 24 S 62 37 E 3707.84 1 .91 3.50 4.39 3.40 1 .08 1 .98 3.39 0.53 0.39 O. 64 1284,35 5 2857.19 E 3132.59 5 65 48 E 1319.89 5 2925.67 E 3209.62 5 65 43 E 1352.40 5 2990.88 E 3282.43 5 65 40 E 1383,58 5 3051.71 E 3350.70 5 65 37 E 1414.03 S 3109.70 E 3416.10 5 65 33 E 1443.44 5 3165.92 E 3479.45 5 65 29 E 1470.33 5 3219.27 E 3539.15 S 65 27 E 1495.24 S 3269.96 E 3595.61 5 65 26 E 1520.33 S 3320.06 E 3651.60 5 65 24 E 1546.06 5 3370.13 E 3707.84 S 65 21 E 6000.00 4151.64 4081.64 34 44 6100.00 4233.81 4163.81 34 44 6170.00 4291.34 4221.34 34 44 S 61 52 E 3764.48 S 61 52 E 3821.35 S 61 52 E 3861.17 0.13 O.O0 0.00 1572.50 S 3420.31 E 3764.48 S 65 19 E 1599.46 S 3470.51 E 3821.35 S 65 15 E 1618.28 5 3505.68 E 3861.17 5 65 13 E COMPUTATION DATE: 24-JAN-91 PAGE 3 CONOCO INC. MILNE POINT UNIT I-1 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 19-JAN-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: BARNARD/WEST INTERPOLATED VALUE5 FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/5OUTH EAST/WEST DIST. AZIMUT~ DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG M]N 0.00 0.00 -70.00 0 0 N 0 0 E 0.00 1000.00 993.27 923.27 16 5 5 66 ? E 80.67 2000.00 1851.23 1781.23 41 3 S 67 44 E 577.67 3000.00 2419.17 2349.17 64 50 5 66 45 E 1390.41 4000.00 2856.83 2786.83 69 4 5 65 55 E 2287.97 5000.00 3383.25 3313.25 52 14 5 62 9 E 3132.48 6000.00 4151.64 4081.64 34 44 S 61 52 E 3764.48 6170,00 4291.34 4221.34 34 44 S 61 52 E 3861.17 0 O0 0.00 N 0 O0 E 0.00 N 0 0 E 3 33 34.78 S 72 80 E 80.68 5 64 28 E 0 24 225.77 S 532 00 E 577.92 S 67 0 E 1 02 551,37 S 1276 82 E 1390.78 5 66 39 E 1 29 947.96 5 2082 37 E 2287.99 5 65 31 E 1 91 1284.35 $ 2857 19 E 3132.59 5 65 48 E 0 13 1572.50 $ 3420.31 E 3764.48 5 65 19 E 0 O0 1618.28 5 3505.68 E 3861.17 5 65 13 E COMPUTAT[ON DATE: 24-JAN-91 PAGE 4 CONOCO INC. MILNE POINT UNIT I-1 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 1g-JAN-B1 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: BARNARD/WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/5OUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN O.O0 0.00 -70.00 0 0 N 0 0 E 70.D0 70.00 0.00 0 12 S 43 56 E 170.00 170.00 100.00 0 31 S 38 5 E 270.01 270.00 200.00 0 31 S 52 51 E 370.01 370.00 300.00 0 36 5 31 19 E 470.03 470.00 400.00 1 54 S 49 44 E 570.21 570.00 500.00 4 52 S 63 29 E 670.72 670.00 600.00 6 40 $ 64 51 E 771.63 770.00 700.00 8 44 S 65 45 E 873.13 870.00 800.00 11 10 S 66 18 E 0.00 0.00 0.00 N 0.00 E 0.22 0.69 0.34 N 0.39 E 0.71 0,09 0,14 5 0.72 E 1.61 0.00 0.77 S 1.42 E 2.47 0.49 1.42 S 2.06 E 4.20 3.10 2.85 S 3.32 E 10.01 2.66 5.68 S 8.40 E 20.06 2.04 10.12 S 17.43 E 33.49 2.23 15.75 S 29.62 E 50.84 3.98 22.77 5 45.49 E 0 O0 N 0 0 E 0 52 N 49 21E 0 73 5 78 46 E 1 61 $ 61 25 E 2 50 5 55 30 E 4 37 S 49 17 E 10 14 5 55 56 E 20.15 5 59 52 E 33.54 5 62 0 E 50.87 5 63 24 E 975.83 970.00 900.00 15 1080,29 1070.00 1000.00 17 58 1186.69 1170.00 1100.00 22 2 1296.08 1270.00 1200.00 25 18 1408.34 1370.00 1300.00 28 26 1523.70 1470.00 1400.00 31 8 1643.21 1570.00 1500.00 36 7 1768.16 1670.00 1600.00 37 0 1893.94 1770.00 1700.00 38 35 2024.87 1870.00 1800.00 41 0 S 66 B E 74.14 3.79 5 66 9 E 104.32 2.15 S 66 36 E 140.54 3.55 5 66 9 E 184.86 2.01 S 66 53 E 235.81 2.13 S 67 16 E 293.28 1.46 S 69 6 E 358.58 3.95 S 68 53 E 433.38 1.21 5 67 45 E 509.57 2.03 S 67 42 E 593.98 0.43 32.14 S 66.83 E 74.15 S 64 19 E 44.35 S 94.43 E 104.32 S 64 50 E 58.87 S 127.61 E 140.54 S 65 14 E 76.63 S 168.23 E 184.86 S 65 31 E 96.90 S 214.99 E 235.82 S 65 44 E 119.21 5 267.98 E 293.30 S 66 1 E 144,32 5 328.31 E 358.63 S 66 16 E 171.64 S 398.08 E 433.50 S 66 41 E 199.93 5 468.92 E 509.76 S 66 54 E 231.96 S 547.10 E 594.25 S 67 1 E 2163.49 1970.00 1900 O0 47 31 2316.96 2070.00 2000 O0 49 41 2480.28 2170.00 2100 O0 55 16 2669.37 2270.00 2200 O0 60 47 2985.93 2370.00 2300 O0 63 52 3118.6t 2470.00 2400 O0 64 23 3344.97 2570.00 2500.00 63 32 3559.40 2670,00 2600.00 61 5 3778.47 2770.00 2700.00 64 7 4036.57 2870.00 2800.00 68 41 5 66 57 E 689.76 S 66 44 E 806.11 S 66 12 E 935.10 5 65 54 E 1094.32 5 65 53 E 1287.50 5 66 5 E 1497.56 S 64 27 E 1700.62 S 61 29 E 1890.03 S 61 48 E 2084.38 S 65 40 E 2322.09 2.85 0.68 2.39 5.29 0.61 0.98 2.25 1.15 2.00 1.68 268.78 5 635.59 E 690.09 S 67 5 E 314.49 5 742.64 E 806.48 S 67 3 E 366.17 S 860.84 E 935.48 $ 66 57 E 431.38 $ 1006.11 E 1094.69 S 66 48 E 510.13 S 11B2.52 E 1287.86 S 66 40 E 594.29 S 1375.02 E 1497.95 $ 66 38 E 679.30 S 1559.43 E 1700.96 S 66 28 E 766.78 S 1727.68 E 1890.19 S 66 4 E 860.55 S 1898.48 E 2084.41 $ 65 37 E 961.97 5 2113.48 E 2322.10 5 65 32 E 4270.38 2970.00 2900.00 62 16 4471.55 3070.00 3000.00 56 31 4646.48 3170.00 3100.00 54 26 4815.22 3270.00 3200.00 52 43 4978.33 3370.00 330b.00 52 24 5134.71 3470.00 3400.00 47 32 5275.29 3570.00 3500.00 42 36 5408.13 3670.00 3600.00 40 38 5536.41 3770.00 3700.00 37 15 5659.12 3870.00 3800.00 34 15 S 67 43 E 2533.09 S 67 47 E 2707.36 S 67 41 E 2850.72 5 64 36 E 2986.61 S 62 12 E 3115.35 S 63 24 E 3235.37 S 62 9 E 3334.04 S 62 10 E 3421.36 S 63 11 E 3501.57 5 63 56 E 3572.61 0 83 4 72 0 49 2 63 0 94 3 68 2 35 1 46 1 81 0.37 1042.72 S 2308.58 E 2533.14 5 65 42 E 1109.16 5 2470.30 E 2707.47 5 65 50 E 1161.94 5 2603.37 E 2850.90 S 65 57 E 1217.75 S 2727.27 E 2986.79 S 65 56 E 1276.34 5 2842.02 E 3115.47 S 65 49 E 1331.52 S 2948.75 E 3235.44 S 65 42 E 1375.79 5 3037.00 E 3334.09 5 65 38 E 1416,50 5 3114.38 E 3421.39 5 65 33 E 1453.46 5 3185.68 E 3501.58 S 65 29 E 1485.10 5 3249.32 E 3572,62 $ 65 26 E COMPUTATION DATE: 2a-JAN-gl PAGE 5 CONOCO INC. MILNE POINT UNIT I-1 SCHRADER BLUFE NORTH SLOPE, ALASKA DATE OF SURVEY: 19-JAN-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: BARNARD/WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 5779.90 3970.00 3900.00 34 7 S 63 9 E 3640.33 5900.87 4070.00 4000.00 34 25 S 62 37 E 370B.33 6022.35 4170.00 4100.00 34 44 S 61 52 E 3777.18 6144.04 4270.00 4200.00 34 44 S 61 52 E 3846.40 6170.00 4291.34 4221.34 34 44 S 61 52 E 3B61.17 0.52 1515.22 5 3310.00 E 3640.33 S 65 24 E 0.65 1546.29 5 3370.57 E 3708.33 5 65 21 E 0.00 1578.59 5 3431.50 E 3777.18 5 65 18 E 0.00 1611.30 S 3492.64 E 3846.40 S 65 14 E O.OO 1618.28 S 3505.68 E 3861.17 5 65 13 E CONOCO INC. MILNE POINT UNIT I-1 SCHRADER BLUFF NORTH SLOPE, ALASKA MARKER LAST GCT READING PBTD TD DRILLER COMPUTATION DATE: 24-JAN-91 PAGE 6 DATE OF SURVEY: 19-JAN-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: BARNARD/WEST INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 2951' FNL & 3696' FEL, 5EC33 T13N RIOE MEASURED DEPT~ TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 6002.59 4153.77 4083.77 1573.20 S 3421.61 E 6060.00 4200.94 4130.94 1588.71 S 3450.41 E 6170.00 4291.34 4221.34 1618.28 S 3505.68 E CONOCO INC. MILNE POINT UNIT I-1 SCHRADER BLUFF NORTH SLOPE, ALASKA MARKER LAST GCT READING PBTD TD DRILLER COMPUTATION DATE: 24-JAN-91 PAGE 7 DATE OF SURVEY: 19-JAN-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: BARNARD/WEST SURFACE LOCATION = 2951' FNL & 3596' FEL. SEC33 TI3N RIOE MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUT~ EAST/WEST 6002.59 4153.77 4083.77 1573.20 S 3421.61 E 6060.00 4200.94 4130.94 15BB.T1 S 3450.41 E 6170.00 4291.34 4221.34 1618.28 S 3505.68 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 6170.00 4291.34 4221.34 3861.17 S 65 13 E SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY CONOCO I NC. WELL MILNE POINT UNIT I-I FIELD SCHRADER BLUFF COUNTRY USA RUN ONE DATE LOOOED 19 - JAN - 9! REFERENCE ?4308 WELL' MPU.,I-1 ,(2951~'FNL, 3696' FEL, SEC 33, )N, RIOE ) HORIZONTAL PROJECTION 2OOO SOUTH -4000 -201~ SCRI..E ~ 1/1000 IN/FT L]].rlJl !1 j ill!J! Ci~ : i j ~ ~ i [ 'i'"?rq~ ~ ~ i ~ ~d~ r i~ i ~ i ~ ~ -'~"t'-~'-~'~'~--t"~'"t'"?b'r"t'"t"~'"t ...... ?4...h.~ ............. +,.~.e ...... , ~.~ ~- , ~ . fe , ~ +~~--~-f~-~~.~.~.~.--~4...~..~..+-~..~..~ .......... ~-..~..-~-.~...+..~ ...... 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CONTACT ("/~..,,~.~.~ _~_.. -- check off or list data as it is received.*list received date for 407. if not reouired list as NR drillino history survey well tests .core cored intervals core analysis ditch intervals I diQital data LO G 'r..,n,~ i ,k,-lr'[:'~,, ~, o , ,r--- RUN SCALE 114 i --: ...... NO. , {to thc nearest foot~ ,,, [inchll ! ........ / ! ,~-..,~-,,,~,,?~z ....... "~ ~ ~T~~ ~ ~ ) '.' .... ~ ~ i Ull 8) ~/ , ,,/,, ~~-~~,, q~ , 11) i ii i~ i u i i i iii i , i . ~ il. i ii u ii, IL ~ ~ _ IllL · I II I IlUlP I I I ' 'IU~J I 14) ,, ' ' Il "~"'"' '"'"" " '" ' i " ,.~q ..... ~,, , .................. i ii ii 1~] i u ii i i i iiii i i u ii ii iii i i i ! , , q ~ , SCHLUMBERGER WELL SERVICES DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2:175 ~N 2 ~ l,ggl CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineberser ~SE REPLY TO SCHLUMBERGER WELL SERVICESPouch 340069 ?rudhoe Bay, AK 99734-0069 Attn: Bern/e/Shelley Gentlemen: Enclosed ore2 Bl. prints of the Gravei Pack Log, Run 1, 1/25/9I Company CONOCO, Inc. Well Milne Point unit I-1 on~ Field Milne Poi nt Additional prints ore being sent to: I BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER County ,North Slope State, Alaska _/__BL__prints, I RF Sepia CONOCO; Tnc~ 1000 South Pine Ponca City, OK 74603 Attn: Glenn Welch 7360RDW I BL prints, 1RF Sepia OXY U.S.A., Ipq. 6 .Desta Drive Midl. a~d. TX 79710 Attn: John Carro] *(915/685-5600) _l_JlLprints, I RF Sepia Chevron U.S.A. . _11111 South Wi]craft_ Attn: Priscilla MacLeroy 7713/561-3652_ Oil'& Gas Conse~'V'a'tion.. Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: John Boyle :,/" The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. prints , .. prints prints Anc:l'mr~g.~, -,~ bOtr'~t~iSsioH _ ReceJ ved by: Date: Very truly yours, SCHLUMBERGER WELL SERVICES David M. Saalwaechter DISTRICT MANAGER SW$-- 1327-F SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLO(.~Y CORPORATION HOUSTON. TEXAS 7725 JAN 2 7 lggl CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineber_ ger ~ REPLY TO SCHLUMBERGER WELL SERVICESPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed ore_2_BL_prints of the Packer Steeing Rec, Run 1, 1/22/91 Company CONOCO, Inc Well Milne Point Unit I-1 on: Field Milne Point /Schrader Bluff County~ North Slope Additional prints ore being sent to: 1 BL prints CONOCO, Inc. 600 .North Dairy Ashford Houston, TX 77079 _Attn: George Lamb - OF 20!8 PER State Alaska _l_JlL__prints, 1 RF Sepia C~N~C~; ThC: 1000 South Pine Ponca City, OK 74603 _Attn: Glenn Welch 7360RDW I BL prints, 1 RF Sepia OXY U.S.A., Inc. __~_s t a Drive Midland, TX 79710 Attn: John Carrel *(915/685-5600) _L_]lL_prints, 1RF Sepia Chevron U.S.A. _J~l!ll South_WJ]cro~t_ _ Hn~]~t~n: TPw~ 77~qq Attn: Priscilla MacLeroy .'713/561-3652 Ala~8~k~ Oil,. & Gas Conse~tion ,/"Commission ~ /~001 Porcupine D6ive ... J [Attn: John Boyle ~.-:~' The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. prints prints prints Received by' A~ AI . Date: Very truly yours, SCHLUMBERGER WELL SERVICES Sws-- 1327-F .David M. Saalwaechter DISTRICT MANAGER SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 JAN ~ 3 1991 CONOCO, Inc. 3201 "~C'~' Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineberger ~ RElY TO SCHLUMBERGER WELLSERVICESPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed ore_2__BL_prints of the Company CONOCO, Inc. GCT/perforatin8 Record, ruq 1, 1/19/91 Well Milne Point Unit I-1 on: Field Milne Point/Schrader Bluff Additional prints ore being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn:.. George Lamb - OF 2018 PER County North Slope %tote Alaska __l_~rints, 1RF Sepia CONOCO~ Tnc= 1000 South Pine Ponca City, OK 74603 Attn: Glenn Welch 7~60RDW 1BL prints, I RF Sepia OXY U.S.A., Inc, 6 Desta Drive Midland., TX 7.9710 Attn: John Carrol *(915/685-5600) _l_]tL_prints, 1RF Sepia Chevron U.S.A. ~.Jllll South Wilcrms~_ _H~u~tnn; Tp~n~ 77~qq Attn: Priscilla MacLeroy 7713/561-3652 - Commission 0'1 pOrcupine Dr'ive Anchorage, AK' 99501 n Boyle The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. prints prints prints Received by: da' e: - ' vw - Very truly yours, SCHLUMBERGER WELL SERVICES David M, Saalwaechter DISTRICT MANAGER SWS-- 1327-F TO: THRU: FROM: MEMORAN M Sta,e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C. Sm DATE: January 24, 1991 Commissioner / ~- FILE NO: JT. DA. 12491.1 TELEPHONE NO: SUBJECT: BOPE test Conoco's MPU I-1 Permit No. 90-90 Kuparuk Rv Field Doug Amos~~ Petroleum Inspector ~~ Jan. 17~, 1991: I traveled from Conoco's MPU BOC to I pad to witness the BOPE test at Pool Rig 102. The testing commenced at 11:30 a.m. and was concluded at 4:30 p.m. With the exception of the one choke manifold valve that failed, all other failures were repaired and retested during this test. The parts to repair the choke manifold valve failure (one of the block valves below the hydraulic choke) were not on location and had to be ordered.. i contacted Conoco rep., Steve Brady, on 1/20/91 but was unable to obtain a firm date for delivery of these parts to the north slope. During the BOPE test, I found two non-compliance items in the , dovmstream lines from the choke manifold. There is a hammer union with threaded cOnnection upstream of the gas buster and a flange and valve arrangement with threaded connection downstream of both chokes. This arrangement is used to bypass the choke during back flow procedures. I informed both Dave Lancaster, Pool rep., and Steve Brady, Conoco rep., of these non-compliance items and was assured that they would be corrected after the diesel base mud was removed from the pits. I filled out an AOGCC BOPE inspection report which is attached. In sum~nary: I witnessted the BOPE test at Conoco's MPU I-1 well at 'Pool Rig 102. 02-00lA (Rev. 6/89) 20/Ii/MEMO1.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report . Well sign Rig Location: Sec ~5 T Drlg contrctr Location (general) Housekeeping (general) Visual Reserve pit., ~/~ Audio Rig# MUD SYSTEMS: Trip tank Pit gauge Flow monitor Gas detectors BOPE STACK: Annular preventer~J Pipe rams ~ j ,, . Blind rams )/ -'.~'~ Choke line valves i,~'; ' 'HCR valve ~/ Kill line,valves · ..Check valve Test Pressure DATE d~T~ Iq, J~fil TEST: Initial / Weekly,~ Other Representative JJ~:~. j ~ .~ '( ~,~ -': :? ~ ~ Permit # ~'Cg--~'O ~ Il Casing set , . [0~ Rep ~C~,~V(~~ ACCUMULATOR SYSTEM: ft Full charge pressure Press after closure Pump incr clos press 200 psig Full charge press attained ! / Controls: Master / Remote L~/~ B1 KELLY AND FLOOR SAFETY VALVES ~), OO¢~ ' psi g ),, ~0~ psig min ~ sec ~__ min DC~) sec psig ~- Upper Kelly , .. J, Test Lower Kelly J Test Ball type I b-~est Inside BOP J ,/×'Test Choke manifold J ~/Test Number valves Number flanges Adjustable chokes Hydraulically operated choke ind switch cover pressure pressure pressure pressure pressure I TEST RESULTS: Failures Test time ~ hrs Repair or replacement of failed equipment to be made within ~ days. Noti fy the Inspector, and follow with written/FAXed verification to Commission office. Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 05/10/90) WITNESS 21 '91 IG:50 FROM ,~NOCO-POOL 102 PAGE.00! ....................................... RECEIVED .... . ....................... ] ............ ?!~:, . u~l &eas Con.. ,., " M~de ~y ... ,~. .¢ Chcck~d By Dote ............ l::>ag¢ .............. of Title Conoco lnG. Calculation Sheet dob No. Field State Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (9O7) 564-7600 January 9, 1991 Mr. Lonnie C. Smith Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Milne Point Unit Wells I-1, I-2, I-3 and I-4 Applications for Sundry Approvals Dear Mr. Smith' Attached are the Applications for Sundry Approvals (Form 403) requesting approval to complete the MPU wells I-1, I-2, I-3 and I-4 with a workover rig. If there are any questions pertaining to these wells please call me at 564-7625. Very truly yours, C. Van Lineberger Sr. Production Engineeh'-" RECEIVED JAN 1 1 1.991 .~Ojl .& Gas Cons. ,CI~S_~, ~,J~ cc: CVL, PMS, Sr. Production Foreman, I-1 thru I-4 Well Files - , STATE OF ALASKA ALASKA' OIL AND GAS CONSERVATION COMMIS~,,)N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well __ Alter casing __ Repair well _~. Plugging __ Time extention Stimulate X Change approved program Pull tubing __ Variance Perforate X Other X Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 5. Type of Well: Development X Exploratory.. Stratigraphic Service Location of well at surface 2951' FNL, 3696' FEL, Sec. 33, T13N, R10E, U.M. At top of productive interval 4500' FNL, 700' FEL, Sec. 33, T13N, R10E, U.M. At effective depth NSB AK NSB AK At total depth 4725' FNL, 265' FEL, Sec. 33, T13N, R10E, U.M. NSB AK 6. Datum elevation (DF or KB) KB 35' AGL feet 7, Unit or Property name Milne Point Unit 8, Well number I-1 9. Permit number 10. APl number 50-029-22065 11. Reid/Pool Schrader Bluff 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 115' Surface 3274' Intermediate Production 6170' Uner Perforation Depth: measured 6182' feet 4272' feet true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) feet feet Plugs (measured) Junk (measured) Size Cemented 13-3/8" Surface 9-5/8" Surface 7" T.O.C. @ 4300' Measured depth 115' 3274' 6170' True vertical depth 115' 2519' 4264' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 1/13/91 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended Service 17. I here_by c~ify~at t.~.~regoing istrue and correctto the best of my knowledge. Signe(~ . ineberger Title Sr. Production Engineer [~--~-~.~.~-~---'~a~--L FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Mechanical Integrity Test Approved by order of the Commission Date 1/9/91 Location clearance Subsequent form required 10- DY LONNIE C. Si~i~Tit Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MILNE POINT UNIT I-1 WELL PROPOSED COMPLETION PROCEDURE - SUMMARY 1/7/91 - CVL NOTE: Hold frequent on site safety/environmental meetings prior to all potentially hazardous tasks. 1. MIRU on I-1 well. Test BOP's. 2. GIH w/ bit and scraper to PBTD. Reverse circulate well clean. 3. RU electric line. Run Gyro survey (if necessary). Correlate with open hole logs and perforate "0" sands at 5 SPF over 5830'-70' and 5902'-38'. RD electric line. 4. GIH with squeeze packer and set above top perf. 5. MIRU frac equipment. Pressure test all lines. Pump frac job to stimulate "O" sand perf's. RD frac equipment. 6. Clean out proppant from wellbore, if necessary. 7. RU electric line and set gravel pack sump packer above "0" sand perf's and below proposed "N" sand perfs. 8. Perforate "N" sands at 12-24 SPF over 5644'-70', 5674'-93', 5713'-24' and 5733'-70' utilizing electric line or tubing conveyed perforating (TCP). If TCP is used, apply 300 psi underbalance and allow well to flow for approximately 20 bbls. Kill well and POOH. 9. PU gravel pack assembly and GIH. pumps/blenders and test surface lines. packer. RU gravel pack Set gravel pack 10. Pickle workstring. Establish injection profile. Pump gravel pack. Stress test gravel pack and POOH. 11. PU and run electric submersible pump (ESP) on tubing. Freeze protect. ND BOP's and NU tree. 12. Leave well shut in until surface equipment installation is complete. C. Van Linebe.rg~r) Sr. Prod. Engineer December 7, 1990 Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 David W. Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-1433 RE: Milne Point Unit Wells I-1, I-2, I-3 and I-4 Applications for Sundry Approval Attached are the Applications for Sundry Approval (Forms 403) requesting approval to shutdown operations on MPU wells I-1, I-2, I-3 and I-4 with the drilling rig, pending completion with a workover rig. Aisc attached is the Form 403 for Well I-4 initiating plug back and coring operations. Verbal approval to plug back and core was previously received from Bob Crandall. If there are any questions pertaining to these wells please call me at 564-7637. Very truly Yours, R. S. Rossb Sr. Drilling Engineer RSR:jcd cc: MPS file # 500.21.08 RECEIVED DEC 1 1 1990 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown X__ Re-enter suspended well __ Plugging ' Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator Conoco Inc. 3. Address 99503 3201 C Street, Suite 200, Anchorage, AK 4. Location of well at surface 2951' FNL, 3696' FEL, Sec. 33, T13N, RIOE, 5. Type of Well: Development _X_ Exploratory __ Stratigraphic __ Service __ U.M., N.S.B., AK 6. Datum elevation(DForKB) KB 35 AGL l UnitorPropedyname Milne Point Unit 8. Well number I-1 At top of productive interval 4500' FNL, 700' FEL, At effective depth Sec. 33, T13N, RIOE At total depth 4725' FNL, 265' FEL, Sec. 33, T13N, RIOE 9. Permitnumber 9O-90 10. APInumber 50-- 029-22065 11. Field/Pool Schrader Bluff feet 12. Present well condition summary Total depth: measured true vertical 6182 feet 4272 feet Plugs (measured) Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Structural Conductor 115 ' 13-3/8" Surface Sudace 3274 ' 9-5/8" Surface Intermediate Production 6170 ' 7" T.O. C, @ 4300' Liner Perforation depth : measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Measureddepth 115' 3274' 6170' ~uevedicaldepth 115' 2519' 4264' RECEIVED DEC 1 1 1990 Alaska 011 & Gas Cons. CommiSS%On Anchorage 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch __ Shutdown operation with drilling rig pending completion with workover rig . 14. Estimated date for commencing operation 16. If proposal was verbally approved Oil X Name of approver Date approve( Service 17. I , that the foregoing is true and correct to the best of my knowledge. Signed b'~.~~:.erg ¢'~ Title Sr Drilling Engineer teve RosS ~' ' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ORIGINAL SIGNED BY Approved Copy LONNIE C. SMITH Returned Approved by order of the Commission ..... !~! ~ 0- { Date 12/7/90 15. Status of well classification as: l Approval No. ~ ..-,,~7 ¢ / / Gas __ Suspended __ Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. [~A~ ~7~g10-2 t 75 I~.EASE REPLY TO SCHLUMBERGER WELL SERVICES Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineber&er Gentlemen: Phasor DIL/NGT/Porosity/Raw Data/Cyberlook Enclosed are_Z_BL_prints of the. Run 1, 10/25/90 Company CONOCO, Inc, Well Milne Point Unit I-1 Field Milne Point Additional prints are being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 A~n: Georg~ Lamb - OF 2018 PER. County North Slope State_ Alaska _l_BL_prints, 1RF Sepia 1000 South Pine Ponca City, OK 74603 Attn: Log Library .on' 1BL prints, 1RF Sepia OXY U.S.A., Inc. 5 Desta Drive __ Midland, TX 79710 Attn: John Carrol *(915/685-5600) ~rints, 1 RF Sepia .Chevron U.S.A. . §O01BollJnger Canyon Road San Ramon, CA 94583-0943 Attn: Priscilla MacLeroy -*(415/842-100 .O_)__ AlaSka 9~,1 & Gas ConservationXk ' commission . ~3001Porcupine DriVe ,,,// X'A-mchoraEe,-AK 99501 ~,z A~'~.'~ John Boyle_ The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. prints prints £CFiVEr ~]OV 0 I 1990 -41aska Oil pnnTs & Gas Cons. Commissioi; Anchorage Date: Very truly yours, SCHLUMBERGER WELL SERVICES David M. Saalwaechter DISTRICT MANAGER Sws-- 1327-F CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 AHention: Van Lineber~er SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 772.% !-2 ! 75 Pr. EASE REPLY TO ~ '~. ~ SCHLUMBERGER WELL SERVICES .(~,X~ ~ '~ Pouch 340069 . ~.,~ ,-" Prudhoe Bay, AK 99734-0069 ?: ..~,?., ~c?'. Attn: Bernie/Shelley ., '(:% Gentlemen: Enclosed ore_2_BL_prints of the Company CONOCO, Inc, Well Milne Point Unit I-1 Field Milne Point /Schrad~_r Additional prints are being sent to: I BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn; George Lamb - OF 2018.PER _ BGT, Run 1, 10/21/90 on: Counly North Slope , State Alaska _l__BL__prints, 1 RF Sepia CONOCO~ T. nc -_ 1000 South Pine Ponca City, OK 74603 Attn: Log Library 1BL prints, 1RF Sepia OXY U.S.A., Inc. 6 Desta Drive Midland, TX 79710 At,n: John Carro] *(915/685-5600) _~rints, 1RF Sepia Chevron U.S.A. 6001BollJnger Canyon Road San Ramon, CA 94583-0943 Attn: Priscilla MacLeroy *(415/842-1000) 1 BL nrints, 1 RF Sepia Alaska Oil&' CommiSsion 3001 Porcupine Drive /AnchoraKe, AK 99501 ~!~At t n: John Boyle The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. prints prints prints Very truly yours, SCHLUMBERGER WELL SERVICES $W$-- 1327.F David M. Saalwaechter DISTRICT I~ANAGER July 27, 1990 Telecopy~ (907)276-7542 David L. MountJ oy Sr. Drilling Foreman. Conoco Inc. 3201 C Street, Suite 200 Anchorage, Alaska 99503 Re: Milne Point Unit No. I-1 ' · Conoco 'Inc. Pe~t No. 90-90 Sur. Loc. 2951'FNL, 3696'FEL, Sec. 33, T13N, R10E, UM. Btmhole Loc. 4725'FNL, 265'FEL, Sec. 33, T13N, R10E, UM. Dear Mr. MountJoy: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to ~itness. ~Very truly yg~rs ,_ David W. John~,ton Commissioner of Alaska Oil '~'a~~ Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environm~nta! Conservation w/o encl. ALA,_. ,A la. Type of work Drill ~ Re-Entry __ ~--'h% STATE OF ALASKA .-. --- _ AND GAS CONSERVATIC C ,MISSION PERMIT TO DRILL 20 AAC 25.005 Redrill lb. Type of well. Exploratory ~ Stratigraphic Test ~ Development Oil ~ Deepen Service - Developement Gas - 2. Name of Operator CONOCO INC. 3. Address Pouch 340045. Prudhoe Bay, AK. 99734 4. Location of well at surface 2951' FNL, 3696' FEL, SEC. 33, T13N, R10E At top of productive interval U,N., NSB, AK 4500' FNL, 700' FEL, SEC. 33, T13N, RIOE At total depth 4725' FNL, 265' FEL, SEC.33~ T13N.~.. RIOE 12. Distance to nearest I 13. Distance to nearest well property line 555 feet 1ST WELL ON PAD feet 16. To be completed for deviated wells Kickoff depth 500 feet Maximum hole angle 66° 5. Datum Elevation (DF or KB) KB 35 AGL feet 6. Property Designation ADL-25906 7. Unit 'or property Name MILNE POINT UNIT 8. Well number I-1 9. Approximate spud date SEPTEMBER 22~ 1990 Single Zone' ~ Multiple Zone 10. Field and Pool KUPARUK RIVER FIELD 11. Type Bond (see 20 AAC 25.025) BLANKET Number 8086-15-54 Amount $2.oo,00o, ,, ,,, 14. Number of acres in property 15. Proposed depth(MD and TVD) 2560 ~ 182'MD~ 4255'TVD*feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 1900 psig At total depth FFVD) 2000 psi.o 18. Casing program size Hole Casing yOm. 12 1/,4 -- · 8.5 1"4 q E/R · AR(; 7 Specifications Weight! Grade I Coupling I._ n I'" n I 26~ IL-801 BTRS, ) Le;13g:h' J6147' 35' ~erations. MD Setting Depth Top Bottom 1118' ! Quantity of cement (include stage data) Effective depth: +485 +773 ~288 +129 SKS PERMAFROST C SKS PERMAFROST E SKS CLASS_ G mmm SKS PERMAFROST E +333 SKS CLASS G ......... 19. To be completed for Redrill, Re-entry, and Deepen O Present well condition summary Total depth: measured feet Plugs (measured) DOWNSQUEEZE true vertical feet +355 SKS PERMAFROST C +60 BBLS ARCTIC PACK measured feet Junk (measured) - true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True Vertical depth RECEIVED JUL 1 1 1990 measured A)a,~k~ OJJ & ¢:iaS CO~S, .C0[ll~j~i,~,;::t true vertical ~ltl~Ch01-a[lll~ ' PIT SKETCH X 20. Attachments Filing fee~3 Property platZZ] BOP Sketch~ Diverter SketchX_~ Drilling program)~2 Drilling fluid program ~3 Time vs depth plot ~ Refraction analysis [] Seabed report [3 20 AAC 25.050 requirementsX2_. ~ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge " ' ~ ' Title SR. DRILLING FOREMAN Signed /'~Commission Use Only Permit Number J APl number J (~l~pfe)vcl/~14e 50 08 Conditions of approval Samples required l~/Yes ~ NO Mud log required ~' Yes L] No Hydrogen sulfide measures ~ Yes ~ No" 'Directional survey required .,~ YSs ,L7 No Required working' pressure for BOPE /~2M; ~ 3M; ~ 5M; [] 1OM; [] 15M Other: ~'- ~ *"--'~'~( ~~"~, %,,~ "'-,, [..~t,,"~__ ~,,, .", by order of Approved b Commissioner the commission Form 10-401 Rev. 12'1-85 -- ' ) -" Submit in triplicate JSee cover letter for other requirements SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT I-1 Conoco Inc. P. O. Box 340045 Prudhoe Bay, Alaska 99734 I. Casing and Cementing Program a. The 13-3/8" conductor will be set at 80' below the surface, then cemented to the surface with ±485 sacks of Permafrost Type "C". . The 9-5/8" surface casing will be cemented with ±773 sacks of Permafrost "E" cement followed by ±288 sacks of Class "G" Cement. A top job will be done if cement is not circulated to the surface. C. The 7" production casing will be cemented in two stages. The first stage will consist of ±129 sacks of Permafrost "E" cement pumped around the casing shoe followed by ±333 sacks of Class "G" cement. The secondary cement job will consist of ±355 sacks of Permafrost "C" cement followed by ±60 barrels of Arctic Pack pumped down the 7"x 9-5/8" annulus. II. Drilling Fluid Program a~ 0' - 3287' 9.0 ppg freshwater spud mud. B. 3287' - 5329' 9.2 ppg low solids non-dispersed. C. 5329' - TD 9.4 low solids non-dispersed. III. Drilling Program Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River Field (Upper Cretaceous-West Sac). The mud system will be low solids, non-dispersed with a mud weight in surface hole of 9.0 ppg. Mud weight at TD will be 9.4 ppg. A 20", 2000 psi diverter will be installed on the 13- 3/8" conductor for drilling surface hole. A 13-3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure tests will be performed as per State Regulations. BOP's, choke manifold, upper and lower kelly safety valves will be tested to 500 psig and 5000 psig, the Hydril to 350 psig and 3500 psig. Casing will be pressure tested to 1500 psig. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. This is the first well on the pad. The well will not be completed or tested at 2UL 1 1 1990 Gas Con,~ A® Be Ce Drill a 30" conductor hole to ±80' and set 13-3/8" conductor. Drill a 12-1/4" surface hole to ±2500' TVD 3315' MD and set 9-5/8" casing. Drill a 8-1/2" production hole to ±4255' TVD to 6182' MD and set 7" casing. TVD MD FORMATION BIT MUD WT YD PV VIS FL 0 0 Gravel 1-1-4 9.0 32 20 90 15 500 500 Sand/Clay 1-1-4 9.0 25 20 65 15 3306 5003 "K" Sand 1-1-4 9.2 25 15 35 10 3556 5329 "M" Sand 1-1-4 9.4 25 15 35 10 3772 5593 "N" Sand 1-1-4 9.4 25 12 35 05 3955 5816 "0" Sand 1-1-4 9.4 25 12 35 05 4255 6182 TD 1-1-4 9.4 25 12 35 05 *The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300 feet TVD, a Sundry Notice will be submitted. NOTES: -~'"'-~"TE PLANE COORDINATES ARE ZONE 4 ALL GEODETIC POSITION3 ARE BASED ON N,A.D, 19'27 3, OI::I::~ET8 TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUE8 Or THE SECTION CORNER POBTION8 1_ MILN~ POINT UNIT i MILNE PT, VICINITY MAP MILES Ii II. I II - __,..(~ LOCATION IN SEC, 33, T13N, R1OE, UMIAT MERIDIAN I-2 37~6' 2948' I-3 3816' 2944' I I ~j ~ RESERVE PIT ~/ O , Il 1.~,-~_= ,~-. ,'l~ ,~.,~ STATE PLANE OO~DINATES-ZONE 4 ~. , . :'~'RAVEL ROAD ............. I-4 6,009,46~80' 68~494,a8' I PAD 10' 170' _L ao' _~_40'_~ 1~~ GEODETIC POSITIONS NAD 1927 ~ ] ' - ~O' -' 2~"- ' ~ WELL NORTH LATI~E , 1-1 70' 26'11,6787' i49' *' , .... I-4 70' 26'11,6705' 149' 34'48,66F HO 3CALE .,F. Robert_~ AJ~ka 0il & Gas Cons, ~mmissis~'t ...... ' Cc b) ~u~ve',,~[::) ~o~i DATE DEC, !,3, 1989 D~AWN CHECKED F~ELD BOOK JUL l~ 1990 :~il & G; ,s ,o is, ~ : Mchora~ . >) ..... ,,,, ~ROPO~ED ~.~E~ JOB t';O. 87033 T 13 N R g E T 13 N R 10 E T 13 N R 1 1 E MILNE POIN' II I I II ! I I I ill 7 8 _. .10 11 12 ~ , ~-255~ 2533.C ADL-47434 25~0 AC ADL-47433 ~60 AC ~RON ......... -' ...... ' ' ....... 18 1~ 23 24 1~ 20 Al 22 23 24 21 22 · OL-3tS~4I ADL'25516 ADL'47439 ADL'31584 ~-25514 2560 AC *DL-25515 2~4 AC ;2.~ *C 1280,AC,,,,. ADL'47437 2560, AC ~DL'47438 4~C .1280., AC .,'1280 ,AC ~ EXH 3~ 33 34 Bmeed on Umla / 35 36 31 32 o A~'25517 ~ A~ MIl'' ~l I 2236 AC 20 ~ II I r UNIT numbers 35,744 Act 6/84 6 XHIBIT A CH[Y, ' .... ' AlqCO IOHIO UNIT AREA Metldlin,Alellle I 2 t ' J Scale 13-5/8" 58888 Fill Lln~ APl 13-5/B' ~ AH F low Llne Annubr Preventor Ram Ram Ram Tub~n~ Spoo! w/ 2"-5000~ Side APl 11' 5M Casing Spool w/ 3"-5000~t Side Threaded Comectton 9-5/8" SurFace Choke Line: 3" 5080~ Manual & 3" HCR VALVE Kill Line: Two 3" 5088~t Manual Valves Outlets Outlets Casing 13-3/8" Conducton Casing BOP SYSTEM Valve Oa~e l, BOP STACK SIZE RATING HEETS AP] RP53 & SPEC 6A FOR CLASS 5H 2, BOPE TO BE OPERATED EACH TRIP AND TESTED WEEKLY, 3, BOP HYDRAULIC CONTROL SYSTEM TO INCLUDE (5) STAT]ON CONTROL MAN]FOLD LOCATED REMOTE WITH 168 GALLON ACCUHULAT'OR, RESERVOIR UN]T, & AUXILIARY ENERGY SOURCE FOR SYSTEH ACT]VAT]ON, ~r, MINIMUM ONE SET BL]ND RAMS & TWO SETS APPR. OPR]ATE PIPE RAMS, 5, CHOKE & KILL MANIFOLDS SHOWN SEPARATELY TO MEET APl RP 53 CLASS 5M REQUIREMENTS, PRESSURE PUMP ---'" KILL B,a. NIFOLD FROM RE~,~OTE HIGH ,NOTE: !. H~RAULIC CONTROL SYSTEM FOR BOP STACK B CHOICE WAN:FOLD TO INCLUDE (5) STATION CCNTROL ~ANIFOLO LOCATED REHOTEL¥ WITH 3(X)O PSI ACCUMULATOR 160 GAL. RES£RVO~R a ~ux. ENERGY SOURCE. STA ~NTROL WA~IF~ PLUS VARIABLE CHOKE ~NT~L TO BE ~CATED ON RIG FLOOR. Z KILL B CHG~ WAN)FOLDS ~ MEET A~ RP~) SW ~. KILL U~N)F~D SIZE- RATING Z'- ~ CHOKE W~N)FO~ SIZE-RATING )'- RF.MOTE PRESSURE G.tSE SENSOR HYDR:ULIC CONTROLLED REMOTE OPERATED DRILLIN6 SPOOl. HYDRAULIC CONTROLLED REMOTE OPERATED REMOTE PRESSURE GAGE SENSOR ADJUSTABLE C~OKE ADJUSTABLE CHOKE CHOKE MANIFOLD BLEED LINE TO PIT __ VARIABLE CHOKE RZt4,0TE CONTROL 1 TO ATMOSPHERIC MUD/GAS SEPARATOR --.- TO SH,~LE SHAKER CHOKE 8 ~<ILL ~,ANIFOLDS FOR qs/8" 8 7" OD CASING BOP STACK BOP I,IANIFOLD LAYOUT - CONOCO, INC. , CONOCO, INC, MILNE POINT UNIT DIVERTER STACK FOR 13 3/8' CONDUCTOR FILL UP LIN[ ~ _ _ IQ' IELI,, NIPPLE -~FLOW LINI I tOe A~I tO00 I~1~ ANNULAR PREV[NT£R DlVERTER QUICK CONNECT ASSEIdBL, Y SAVER 'SUB STARTI~O l. The hydraulic control syste~ will be in accordance with API specifications and AOG43C requiremer, ts. 2. The HCR valve will open when th~ preventer closo-~. A singl~ I0" relief line will pun off of the drilling spool HCR valve and will have a targeted downstream tee for downwind diversion. Valves on both sides of the tee will be full opening and linked together to enabla one to always be open and the other to be closed. MUO TgOUGH ' I MUD CL[ANER I:~ldP$ wATE~ Puea~ FiLL ~S Va. AGII,~ T(~ DEVELOPMENT WELL WELL NAME: mpu i-1 15-Jan-90 CONDUCTOR SETTING DEPTH: SURFACE CASING SETTING DEPTH: INTERMEDIATE CASING SETTING DEPTH: PRODUCTION CASING DEPTH (OR TD): 80 3287 0 6109 DEPTH OPERATION: 0 1 RIG MOVE: 0 2 RIG-UP; SET CONDUCTOR: (3,287) 3 DRL/SURVEY SURFACE HOLE: ~ (3,287) 4 SURFACE HOLE LOGGING: (3,287) 5 CONDITIONING TRIP: (3,287) 6 RU/RUN SURFACE CASING: (3,287) 7 RU/CEMENT SURFACE CASING: (3~287) 8 CHNG BOPs; PU BHA; RIH: (5,387) 9 DRL OUT; '[EST; TOOH; RIH: (3,387) 10 DRILL INTERMEDIATE HOLE: ~ (3,387) 11 LOGGING OPERATIONS: (3,387) 12 CONDITIONING TRIP: (3,387) 13 RU/RUN INTERMEDIATE CASING: CUM HOUR DAYS DAYS 6 0.25 O. 25 12 0.50 O. 75 58 2.43 3. 18 0 0.00 3.18 3 O. 14 3.32 10 0.42 3.74 6 0.25 3.99 9 0.39 4.37 10 O. 41 4.79 0 O. O0 4.79 0 0. O0 4.79 0 O. O0 4.79 0 0. O0 4.79 0.00 4.79 0. O0 4.79 0.00 4.79 2.61 7.40 O. 00 7.40 0 · 00 ~ 7 · 40 0.42 7.82 16 O. 65 8.47 6 0.25 8.73 1. ~ 0 . 50 9.23 12 0.50 0.50 12 0.50 1.00 1~-° 0 .50 1.50 12 0.50 2.00 12 0.50 2.50 12 0.50 3.00 12 0.50 3.50 (3,387) 14 RU/CEMENT INTERMEDIATE CASING: 0 (5,587) 15 CHNG BOPs; PU BHA; RIH 0 (3,387) 16 DR[_ OUT; TEST; TOOH; RIH 0 (6,109) 17 DRILL PRODUCTION HOLE: 63 (6,109) 18 CORING OPERATIONS: 0 (6,109) 19 =OGGING OPERATIONS (MWD ONLY): 0 (6,109) 20 CONDITIONING TRIP: 10 (6,109) 21 RU/RUN PRODUCTION CASING: (6,109) 22 RU/CEMENT PRODUCTION CASING: (6,109) 23 RD DRLG RIG (6,109) 24 RU COMPLETION RIG: (6,109) 25 RD DRLG RiG (6,109) 26 RU COMPLETION RIG: (6,109) 27 RD DRLG RIG (6,109) 28 RU COMPLETION RIG: (6,109) 29 RD DRLG RIG (6,109) 30 RU COMPLETION RIG: 10 E~I-R',IL L_II".,I!3 DA,'r'5 C, ONOCO. !. ~ · Pad I. Well No' 1 MI Ins Polni: Unli:. Revised P~'oposal No~'th Slope, Alaska 0 . RKB ELEVATION' ~ 1000 _ 2000 _ 3000 _ 4000 5000 .,, KOP TVD=500 TMD=500 DEP:~ ~ ~G MAXIMUM ANGLE ~ ~ ~ 65 DE G 30 M IN 21 BUILD 3 DEe [oa ~VD=~2~ /e' C~ P~ ~VD=2SO0 ~D=~)S s~ BEGIN ANGLE DEOP s~5~~- TVD=2g) 4 THD=43] 3 DEP=2600 ~ 0 SNDS TVD=3955 THD 5816 DEP=3652 TARGET ANGLE TD / 7' LINER TVD=4255 THE=6182 DEP=3862 35 DEG I I I I 1000 2000 3000 4000 VERTICAL SECT[ON HORIZONTAL SCALE 1 IN. PROJECTION, = 1000 FEET CONOCO, Inc. Pad I. Well Not 1 HI Ine Point Unit, Revised Proposal North Slope, Alaska SURFACE LOCATION~ 2951' FNL. 3696' FEL SEC. 33. T13N. RIOE 1000 m 1000 _ 2000 _ S 62 3373' WEST-EAST 1 000 0 1000 2000 :3000 I I I I SURFACE .... TVO=3556 THD=$329 OEP=Z3?'3 SOUTH 1549 EAST 2996 DEG 40 HI N E (TO TARGET) 4000 I TARGET LOCATION~ 4500' FNL. ?00' FEL SEC. 33. T13N. RIOE TD LOCATIONs 4725' FNL. 265' FEL SEC. 33. TIZN. RIOE CHECK LIST FOR NEW WELL PERMITS Company ) ~ ~?r ~ 1. Is the permit fee at=ached .................................. t~ru 8) 3. Is well located proper distance from property line .......... (8) (3) Admin ~?/ ~ 9. ('9 -:btu lo. .¢4,r. -¢,¢, (10 ~d ~3) 12. 13. (14 thru 22) 4. Is well located proper distance from other wells ............ 5. Is sufficient undedicated acreage available in this pool .... 6. Is well to be deviated and is we!lbore piat included ........ 7. Is operator the oniy affected party ......... i ............... 8. Can permit be approved before fifteen-day wait .............. 14. 15. (5) BOPE (23 thru 28) 16. 17. 18. 19. 20. 21. 22. 23. 24. 25, 26. 27. 28. eeeeeeee eeeeeeee eeeeeeee Lease & Well No. · YES NO £ , / , ? / , Does operator have a bond in force .................................. ~. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~_ Does the well have a unique name and number ......................... Is adnductor string provided ........................................ Wi!i surface casing protect all zones reasonably expected to sez~e as an underground source of drinking water ..................... 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 all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an ezisting we!lbore ............. Is old we!!bore abandonment procedure included on 10-403 ............ is adequate wei!bore separation proposed ............................ Is a diverter system required ....................................... .~ Is the drilling fluid program schematic and list of equipment adequate ~ Are necessary diagrams and descriptions of dive:re: and BOPE attached..-~ Does BOPE have sufficient pressure rating - Test to ~mc)a) psig .. ~ Does the choke manifold comply w/API RP-53 (May 84) .................. /~ Is the presence of H2S gas probable ............................. ~... thru 31)' Geo___lo gy~ Engineering: " DW~~'Lcs BEW ., rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ..... ~ ........................................ INITIA~ GEO. UNIT I ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: 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. *------- SCHbU~BE~G~P COMPANY NAME : cbNOco INC. WEI,L NAME : MILNE POINT UNIT I - ! FIELD ~A~E ~ SCHRADER BLUFF BOROUGH ~ NORTH SLOPE STATE ~ ALASKA API NUMBER ~ 50-029-22065 PEFERBNCE NO ~ 93i0~. JvIICROFILMEE) .$ Tame. Verification L.!stln~ :hlumberqer ~lasKa Comp,~tiD~ Center 9-MAR-1993 09:08 O~XC!N ~ FLTC ~E~ ~E ~ 74~59 CnNTINU~TIO~ # CO~ENT ! CONOCO, SCHRADER BLU~F,MILNE POINT UNIT I-l, 50-02Q-22065 **** TAPE HE~D~R **** SERVICE NA.~E : gD~T D~TF : 90/11/14 U~IGIN ~ ~b!C T~P~ ~AME : 74159 COUTINUATIUN ~ ! 1, P~EvlO!~$ ~ADE ~ C~EUT : CONOCD, SChRaDER BLU~F,MILNE ~OINT UNIT I-1, 50-029-22065 PAGE: **** FILF HEADER FII, F NAUE : EDIT .00! VERSION : O01A06 D~T~ : 90/11/14 MAX ~EC S~ZE : 8102 FTL~ TYPE : ~0 LAST FILE cnMPANY N.~: CONOCO IUC. w~bS: UIbN~ POINT UNIT I-1 PTE[.,O~ SCHRADER BLUFF BOROU~}'t~ ~ORTH SLOPE STATE: API NIJ~BER: 50'0~9'22065 LnCATIO,: 2951' FNL & 3696' FEb SECTION: 33 TOWNSH!P~ 1.3N RANGE: 10E P~R~ANENT OAT!IN: MSL ELEVATION: 0 9-MAR-1993 09'~08 75-0~T-1990 TWO 6180 ABOVE PERMANENT DATUM 3/8" 0 DRILLER DEPTH OF 105 AND LOGGER DEPTH OF 105 5/~" ~ OR!bLER DEPTH OF 3274 AND LOGGER DEPTH OF 3276 BTT SIZE t: 12 1/4" B~T SIZE 2: 12 1/4" TYPE FLUID IN gObE: LSND DENS!TY~ 9.4 PH: 9,5 RESISTIVITY: F~b?RATE ~ESISTIVITY: CAKE RESISTIVITY~ VISCOSITY: 40 FLUID bOSS: 7 ~.71 ~ 68 1.54 ~ 68 1o85 ~ 68 , . TTHE CIRCULATION ENDED: 1~,:00 25-0CT TT~E LO~GER ON BOTTOm: 17~00 25-0CT ~.AXIgUM T~MP RECORDED: 87 LOGGING D!STRTCT: LOG(;I~G ENGINEER: PRUDHO~ BAY WEST DIbLON/PObYA TOOL N[~P~BMRS: AMM A~ 724 NGD B 739 C~C ii 33? DPS 4847 GPlC ~ 834 DIS HC ~40 TCC A 123 NGC C 1934 NSC 760 PGG5 1800 DIC g~ 15 FIELD REMARKS: TOOL STRING (BOT-TOP): DITE LDTD CNTH NGTD TCCA AMS RAN 1 5" TEPbON STANDOFFS ON THE TOOLS AND AN HOLM FINDE~ TO HE~P ~ET DOWN. JST ATTEMPT TO GET DOWN WAS UNSUCCESSFUL. TOOL STOPPED WOVIMG AT 4100' (98 DE~). REMO'VED T~E GPIT AND T THE CNh BOWSP~ING TO GET DOWN "E ~ND ATTEMPT NEJgRON "AT~I×= SAN!), HOLE CORRECTION : CALIPEr6 DENSITY MATRIX: ~65 G/CC, FLUID DEN$ITYm ~ 0 G/CC. HOLE R~ECTION: NONE, NGT FILTERING: L~ST SQUARES' PH&,SOR P~OCESSING SELECTZD AT ~0 KHZ FOR ALL DATE JOB STARTED: 7-NOV-90 JOB REFERENCE NO: 74159 bDP/ANA! KOHRING CO,PI)TING CENTER REMARKS: PA~E: Vert.ficatlon [,lsttn~ Alaska Computlnq Center 9-MAR-1993 09:08 RESISTIVITY DATA FROM FIELD IS N~ ~OoD, IMPH WAS MOT ~FC'ORDED ON FIELD PRINT EITHER. AKCC PHASOR PROCESSED ENHanCED R~SISTIVITY DATA ALSO INCLUDED ON THIS LIBRARY TAPE: InPH.PHS: OPGRADED PHASOR ILD RESISTIVITY IDER,~HS= EMHANCED RESOLUTION PHASOR ILD RESISTIVITY IDVP,PHS= VERY ENHANCED RESOLUTION PHASOR ILD RESISTIVITY ****************************************************************************** F%LE - CONOCO IMC, SCHRADER BLUFF ~IL~'E POINT UNIT I - ! 50-029-22065 DTE/LDT/C~.Ib ~I.~-I PASS LOG ~ATA FROM FIELD FILE 013 .NC.,T M~I~I P~.$S bOG D/~T~ FRO~ FIEI.,D F~bE ;0~0 (LEAST SQUARES FILTER) SAMPLED EV~;R¥ -,5000 FEET DATA IMC~,UDMD - TOOL MXTEMS!ON TOOL TYPE USED MA~E DIT-E ,DTE DIT-E ,P;{S LDT ,bDT CNT-~/D/H ,CML ~GT ,NGT PHASOR DUAL INDUCTION SFL 6168' TO 3~76' PNA,$OR PROCE.M.$ED EMI~.AMCED IbD 6~.68: TO 39-76' bITHO DEMSXTY 6170: TO 3976 CO~PENSATF~D NEUTRON .. 61~6: TO 3276' N~TUR~5 G;~MMA SPECTROSCOPY 6114' TO 3276' ****************************************************************************** PA~E: 1 66 0 2 66 0 3 73 312 4 66 ~. 6 73 7 65 8 68 0,5 9 65 FT WaDe.verification Listing :hlumberger A].a~Ka Computing Center 9-MA.-t993 09:08 PAGE: mmmmmmmm~mmmmmm#mmmmmmmmmmm#mm TYP~ ~P~ CODE VALU~ 1! 66 26 1~ 68 13 66 0 14 65 )5 66 68 16 66 1 0 66 ~mm~mm~mm~~mmm~mm~m~ ** DEOT FT I~,~ DTE ILb OTE OHP~ SP ~TE ~V IDP~ DTF OHM~ IPRF DTE In0? I"O? DTE C~DP OTM MMHO C~MP ~TE I!Rn OTE MMHO IIXn OTE IIR~ DTE SGP DT~ GAPI C~R OTE GaPI TENS DTE b~ ~ES OTE O~MM HTE~ OTE LB IDPW ~HS IDED PHS OHM~ ~DVD OHS DDHT !,DT PU D~HO LOT G/C3 P~F [,DT ~LS t, DT QSS 1,8 ~,D~ CPS L~~ LOT CPS I.,L !~DT CPS L~T$~ LOT CPS SSi LOT CPS $~2 LDT CPS LSHV LDT V SS.v !,DT V TYPE - CH OROEP # 548177 548177 549~77 548~77 548177 548177 548177 548177 54~177 548177 548177 548177 548177 548177 548177 54~177 548177 54~177 548177 548177 548177 548~77 548177 ~48!77 5~8177 54~177 54~177 548177 548177 548177 5~8~77 54~177 54~177 54~177 548~77 5~177 54~77 O0 nO0 On 0 1 1 1 4 6~ 0000000000 O0 000 O0 0 1 ! I 4 6~ 0000000000 O0 000 O0 0 1 ! i 4 68 0000000000 O0 000 O0 0 1. ! 1 4 6~ 0000000000 O0 000 O0 0 1 ! 1 4 68 0000000000 O0 000 O0 0 1 I 1 4 68 0000000000 O0 000 O0 0 1 I 1 4 68 0000000000 O0 000 O0 0 I 1 ! 4 68 0000000000 O0 000 O0 0 1 1 1 4 6S 0000000000 O0 000 O0 0 1 1 1 4 68 O000000OO0 O0 000 O0 0 1 1 1. 4 68 0000000000 O0 000 O0 0 t 1 I 4 68 0000000000 On 000 O0 0 1 1 i ~ 68 0000000000 O0 000 O0 0 I 1 1 4 6~ 0000000000 O0 000 O0 0 1 1 ~ 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 6~ 0000000000 O0 000 O0 0 1 1 ! a 68 0000000000 O0 000 O0 0 1 I 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 I ! ~ 68 0000000000 O0 000 O0 0 1 I i 4 6~ 0000000000 O0 000 O0 0 I I 1 4 68 0000000000 O0 000 O0 0 1 I 1 4 68 0000000000 O0 000 O0 0 I ! 1 4 68 0000000000 O0 000 O0 0 1 1 I 4 68 0000000000 O0 000 O0 0 ! ! i 4 68 0000000000 O0 000 O0 0 I 1 1 4 68 0000000000 O0 000 O0 0 1 ! ! 4 6~ 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 ! 1 4 68 0000000000 O0 000 OO 0 ! 1 1 4 68 0000000000 O0 000 O0 0 1 I 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 I ! 1 4 68 0000000000 O0 000 O0 0 1 1 ! 4 68 0000000000 O0 000 O0 0 t ! ! 4 6~ 0000000000 O0 000 00 0 1 1 lm 4 6~ 0000000000 iS Tare Vert.ftcatton List].no :hlumbePq. er ..alaska Computlno Center g-MAR-IN93 09:08 PAGE: ORDER LSgw LDT L'!WM LOT CALT LOT SGw 5DT C~R LOT TFNS LOT ~T~ LOT T~3Pw N~Op RCNm CNL ~CFT CNL C~T~ C~L 8GR CNb C~ CNb CaLl C~L SGR NGT CC~ WGT TuOD ~GT POT.~ MGT U~A~ W1M~ W]N~ NGT TK~S NGT G/C3 54~177 C.,/C3 548177 IN 548~77 GAP! 548177 GAPI 54~177 bB 548177 DEGF 548177 OH~M 548177 [.,~ 548177 PU 548177 ~U K48177 549177 PU 548177 CPS 548177 CPS 5~8177 CDS 548177 CPS 548177 GaPI 548177 GAPI 54~77 IM 54~77 bB 548177 OH~ ~48177 DEGF 548177 58 548177 GAP! 548~77 GAPI 548177 PPM 548177 PU 548177 PP~ 548177 CPS 548~77 CPS 548177 CPS 548177 CPS 548177 CPS 548177 LB 54~177 DEGF 5&8177 OMM~ 5~77 7/~ 548177 LB 548177 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 I 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 I 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 ! ! 1 4 O0 000 O0 0 1 I 1 4 O0 000 O0 0 l 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 oo 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 I 1 ! 4 O0 000 O0 0 1 1 I 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 ! 4 O0 000 O0 0 ! ! 1 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 ~ 1 4 no 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 I 1 4 Od 000 O0 0 ! 1 1 4 O0 000 O0 0 1 1 I 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 1 1 1 4 O0 000 O0 0 I t I 4 O0 000 O0 0 i 1 1 O0 000 O0 0 1 1 1 4 O0 000 O0 0 I 1 1 4 O0 000 O0 0 1 1 1 4 00 000 00 0 1 1 1 4 O0 000 O0 0 1 t 1 4 O0 000 O0 0 1 1 ! 4 O0 000 O0 0 I 1,. 1 4 CODE (HEX) '"";; .... 68 0000000000 68 0000000000 68 0000000000 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 0000000000 6R 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000oo0 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 000000o000 68 0000000000 6R 0000000000 68 0000000000 68 0000000000 0000000000 68 0000000000 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 DATA SD.DTF IDOr. DTM CG~.DTE 48.000 8FI, U.DTE 8.016 I[,~,DTE 6'2t.!72 IDPH.DTE 3.613 I,,PH.DTE 3 000 IMOF DTE ~,000 CIDP.,DTE 235~750 IIxD:DTE 3 406 II~,.OTE 0,000 TENS DTE 1470=:000 MTEE,DTE -503.750 IDPFI~PHS 3,615 IDER,P~S 1950.000 ILD. DTE 1950.000 :FR~:DTE ~76.500 CI~P.DT~ -907.000 SG~.DTE 87,938 ~RES,DTE 3.609 IDVR.PHS 3.592 20.000 -907,000 0,000 1.179 3.603 Tame Veri.~tcation !,Isttno 'hlumb~oer AlasKa Comuuttno Center DvHI.LDT ?4.707 ~HO6.LOT OLS.I, Dm 0.005 QSS.LDT L!,.I,Dw 223.$75 LITH.LDT {.,$HV.t.,DT 1~7.000 SSNV.LDT ~D~I.CNL 45.341 TN~H.CNL ~C~T.CD!, ~037.413 RCFT.CNL $~.CNL 0.000 CGR.CUL ~ES.C~L 1.179 MTEM.CNL cG~.NGT 76.856 THO~.NGT W{NG.NGT 295.693 W2NG.NGT WLN~.NGT 8.149 TENS.NGT C$.NGT ~804.0n0 HTEN.~GT DEPT. 6200.000 SFLU,.DTE SP.DTK -~4.172 IDPH.DTE IDOr. DTE 3.000 I~OF.DTE ~{RD.~TE 2]5.750 IIXD.DTE CGP.nTE 44.106 TEN$.DTE HTE~.DTF 574.500 IDPH.PHS DPH~.LDT 24.707 RHOB bDT OLS.LDT 0.005 OS$:LDT bI,..LDT 2~3.875 LITH.LDT LS~V.LDT t247.000 SSHV.LDT bURH.bDT 2.207 CALl, LOT T~N$.LDT 4785.00,3 ~TEM~LOT NDt.!I.CNL 45.341 TN~H.CNb ~CNT.CNI, ~037.413 ~CFT.CNb SG~ CNL 87.749 CGR.CNL ~E$[CNI, 1'179 HTE'~.CNL CG~.~GT 44.097 THOR.NGT W~N~.NGT 295.693 W~NG.N~T WL~C.~GT 8.149 TENS. NGT C~.NGT ~807o000 MT~N~NGT D~P~. 6100.000 SFLU.DT~ SD.OT~ -28.500 IDPH.DT~ IDOF.DT~ 0.000 IMOF.DTE I]'Pn ~T~ 237.375 IIXD.~TE CG~'OTE 50.425 TEN$.DTE HTE~DTE 445.750 IDPH.P~S DP~?.LDT ~1.~69 RHOB.LDT OL~.Lt)T -O.0~3 OS&,bDT LI.,.LDT 1~4.875 LITHiLDT t, SHU.[,DT 1247 000 SSH¥,LDT t,U,~.I,~T 2~7 ~ALI.bUT TE~.LUT 4500 000 ~TE~.LDT N~HT.CNL 44~453 T~PH.CNL RCN~.CN!, 2067.774 RCFT.CNL SG~.C~t, 100.119 CGR.CNL ~ES.CNI, 1.181 ~TF~ CML · . · ~ ~ ~G~.NGT 55 836 PH_R~NGT ,~I~C.NGT 301.301 W~NG.NGT WLNC.NGT 6.006 TEN$.NGT O-MAR-lOg3 09:08 ? 242 DRHO.LDT ~!3.500 SSI.LOT ]lo.ooo ~.652 SGR.LDT 87.938 ,RES.bDT 38.044 TNRA.C~L 580.634 CNTC.C~L 0.000 CALI.CNL 87.938 NTEN.CNL 13.207 POTA.NGT 125.728 WLNG.NGT !470,000 ~TEg,~GT 503.75O 8.016 IbM'.DTE 3.609 I~PH.DTE 2 000 CXDP.DTE 34:406 IIR~.DTE ooo 2.242 DRHO.LDT 0'O41 LS.bDT 1.1 .5oo SSl. OT 1310.000 S1R,.bDT 2682 87]938 MRES,.LDT ,~06 CALI.CNL 87,938 HTEN,CNb 6.416 POTA.NGT 125.728 WLNG.NGT 4785.000 MTE~.NGT 574'500 2 ~0 IbM.DTE I~PH..DTE 17.844 IIRM.DTE 4500.000 MTEM.DTE 3 5~3 IDER PHS o.o a MRES,LDT 0.050 415.250 227.500 2.07~ 0.000 1.179 3.251 2029.515 2.682 -503.750 1.638 40.745 87.938 1950.000 i95o:ooo 276.750 -907.000 81.938 .617 0 0 415: s ~0 227.500 2.072 87.749 3.251 2020.534 2.682 574.500 1.224 40.745 87.938 1950.000 1950 000 -9 :soo 3 o:g lO ]52.500 lo:2so 2.248 100.119 i.lii 3.629 6 866 °59:24 445.750 1.64~ 62 062 871938 PEF.I.,DT !,U.LDT $S2.LDT LSRF.LDT CGR.LDT HTEN.!.,QT ~POR.CNL CFTC.CN~. TENS.CqD SGR.NGT URAN.NGT W4HG.~GT ~RE$.~GT ILD.DTE IFRE.DTE CI~P.DTE SGR.DTE ~RES.DTE IDVP.PHS PEF.LDT Ltl.bDT SS2.LDT bSRH,LDT CGR.L~T HTEM.LOT NPOR.CNb CFTC.CNL TENS.CNL SG~.NGT UWAN.NGT W4NG.NGT ~RES.NGT !LD.DTE IFRE DTE SGR.DTE ~RE8 DTE PE~.t, DT LU.LDT SS~.LDT LSRH.LDT CG~.LDT HTEN.LDT NPO~.CNL CFTC.CNL T~NS.CNL SGR.NGT U~AN.MGT W4NG.NGT ~RES.NGT PAGE: 0 312. 2. 0. -503. 38. 633. 1470. 87. 2. 9. 1. 3. 20. -90~. 1o 3, 3. 382. 312 574. 38 6331 4785. 87. 5. 9. 1. 3. 20. -899. 100. 1. 3. 2. 335 2. 50. 445. 42. 58O 4500: 99. 5, 23. 1. 605 75O 750 191 000 750 044 32O 000 749 426 313 !79 592 000 000 749 179 610 160 750 750 191 106 5OO 045 320 000 749 .3.13 179 5!6 000 5O0 119 181 688 836 5OO 5OO 287 425 750 918 014 000 552 885 023 18.,1. I,~ ~a~-e Vert.~icatiom :hlumbe')"oer Alaska ComPutin~ Center Cs. NGT 1805. 000 HTEN. NGT DFD*. 6000,000 SFLU.DTE SP.DTE -2g.8.K9 IDPH.DTE IOOF.DIM 0.000 I~{OF.DTE IIRn. PTE 246.750 II%D.Dgf CGP.DTE 76.184 TENS. ~TE HTE[~. DTE 507.250 IDPH.PUS OPUS.LOT ~.874 RNOB.bDT nbS.BDT 0.000 OSS.D~T Lb. [,BT 174.750 BITH.BDT bS~V.LDT 1247.000 SSMV.LDT bU~.bDT 2.334 CALI.bDT T~S.LDT 45~0.000 ~T~M.bDT ~P~I .CNt, 44.331 TNP~.CNL RC~,T.CNb ~128.347 ~CFT.CNL SG~, CNB 97,3~ 1 CGR., CNL ~ES.CNL 1,199 ~TEM,CN5 CG~.NGT 85.784 THOR,NGT W{ N~.NGT 297,595 W2NG.MGT WbN~.MGT 8,016 TENS,NGT CS.NGT 1783,000 HTEM.NGT r~pT 5000.000 SFLU.~TE SP:DTM -31,938 IDPH,DTE I~9F.DTE 0.000 IM~F.DTE II~D.DTE 209.750 IIXD.DTE CG~.DTE 75.837 TENS DTE HTE~.DTE 539.000 IDPH:P~S DPg!.LDT 20'43~ RHOB.bDT ObS. LOT -0. 022 OSS. LOT bI~. bDT !83.875 LITH BDT bSuV.LDT ~247.000 SSHV~LDT UII~H. [..,DT 2,~9 C~LI.LDT T~NS. [.,DT ~5!0,000 MT~M.LDT NP~ .C~L 4!, 154 TNPH. CML ,~CNT.CNL ~964.502 RCFT.CML SGP, CN[, I 01,489 CGR, CML ~I~ES. C~L I, lO~ ~TEM, C~IL rgb. UGT g2. 507 T~OR. NGT W~NC,NGT 317,635 W2NG.NGT wbNC.NGT ~ 3.0~6 TENS, NGT CS.MGT 180~,000 HTEN.NCT DEPT, 5~00,000 SFLIJ,DTE SP.DTE 35.875 IDPg,DTE IDOF,BTE O,000 T~OF,DTE Ii~D.DT~ !!2 563 IIXD.DTE CG~.IPTE 45:840 TENS.DTE MTE~.DTE 5~9.000 IDP}i. PHS DPHI.LDT 8,252 RHOB.bDT OL~.LDT -0.039 OSS hOT bi.,. bDT 137.~75 LITH~LDT LSMV.LDT 1247.000 SSHV.LDT b!~. I,,DT 2.436 CALl.bDT 9-MAR-1993 O9:08 4~5.750 3,025 IL,.DTE 3.500 IMPH..DTE o.ooo 2. 9 DPHO.bDT 0.021 LS,bDT 93,063 SSI.bDT 1310,000 M1RH,LDT 9,180 $GR,bDT 88.000 MRES.bDT 41. 087 TNRA.CNL 55.499 CNTC.CWb 576,184. CAbI.CNb' 88,000 HTEN,CNb 11,006 POTA.NGT 145 ~1 W3NG.NGT 4520: 0 MTE~.NGT 507,250 .119 .975 .000 2 .953 4510.000 ~.977 2 313 0:042 100,250 1310.OOO 9.305 87.688 41 75 837 87 12 060 i55 311 4510 000 539 13.695 8.469 0.000 g477 2,514 0 037 1309.000 8.664 ILM.DTE IMPH.DTE CIDP'DTE IIR~,DTE MTE~ DTE ID~R:PH8 DRHO.hDT L$.bQT SSI,LDT $1RH.bDT SGR,LDT ~RFS.bDT TNRA.CNL CNTC.CNb CALI.'CNL HTEM.CML POTA.NGT W3NG.NGT NTE~.NGT IL~.DTE IMPH.OTE CIDP.DTE NTEM.DTE IDER.PHS DRHO.LDT LS.L~T SS1.LDT S1RH.L~T SGR,:LDT 1950.000 1950.000 785.500 -910.500 88.000 3.340 0.012 330.500 209.000 2.~79 97,.32i 1.199 3.617 ~147.06~ 9.180 507.250 2.741 57.114 88.000 1950.000 1950.000 251.500 -947.500 87.688 3,970 0.~21 350. 50 214,375 2.221 !01.489 ,192 3.454 193~.040 53910o0 2.909 63.~26 87.688 1950.000 1050.000 -994 500 R72063 9,342 0.074 271.500 8.500 212.279 6~.999 ILD.DTE IFRE.DTE CINP.DTE SGR.DTE MRMS.DTE IDVR.PHS PEF.bDT bU.LDT SS2.LDT [,$RH,bDT CGR.bDT HTEN,bDT NPOR.CNL CFTC.CNb TENS,CML SGR.NGT URAN.NGT W4NG.~GT ~RE$.MGT ILD.DTE IFRE.DTE CIMP.BTE $GR.DTE MRE$.DTE IDVP.PHS PEF.LDT t,U.bDT $S2.LDT LSRH.LDT CC~.LDT HTEN.LDT NPCR,CNL CFTC.CNb TEN$.CNL SG~.~GT URAN.NGT W4N~.NGT M~ES.NGT ILD.DTE !FRE.DTE CIMP.DTE SGR.DTE ~RES.DTE IDVR.PHS PEF.[,DT LU bDT LSR~.LDT CGR.bDT PAGE: . 20. -909. 97. 1. 3. 2. 311. 288. 2. 76. 507. 41. 626. 4520. 98. 1. 14. . 20. -940. 101. 1. 3. 2. 334. 289. 2. 75. 539. *0. 559. 4510. 99. O. ~0. t. 20. -994, 62, 1. 3, 267, 2~6o 2 430 000 000 321 !99 286 799 750 500 326 184 250 682 726 000 016 610 O28 199 934 000 500 489 1.92 965 730 000 500 291 837 000 919 239 000 266 941 020 ,192 156 000 000 999 204 751 273 500 500 439 840 iS Wane Verification !~Istin~ rhl~mbe~qer Alaska ComDutina Cemter TFH~.LDT 4435.000 ~TEM.LDT ~mMI.C~,~I., ~0.6~3 TNPH.CNL RCNT.CNL 38~8.8~3 ~CFToCML $~P.C~!L 6~.999 C~R,CML ~ES.CNL 1.20~ MTE~.CNL CGm.~GT 49.2~4 THOR.NGT W~NC.NGT 190.381 W~NG.NGT wb~G.WGT 8,0!6 TENS,NGT CS.NGT 1803.[)00 HT~N,NGT D~DT, 5700,000 SFLU,DTE SD.DTE -36,011 IDPH,I)TE IDOF.DTE 0,O00 I~OF,DTE !]~D.DTE 131.1~5 IIXD,DTE CG~.DTE 49.7q4 TENS.DTE HTEN.OT~ 571.000 IDPH.PHS DP~].LDT 25,066 ~HOB,LDT OLS.L{)T '0.020 O$S.LDT LL.bDT 2nl.6~5 LITH.LDT !~SHV,LDT 1247,000 SSHV,LDT LUR~,LDT 2.2~2 CALI,LDT TEN$,LI)T 4155,000 'MTEM.LDT ~HI,CHL 41,661, TNPH,CNL ~CMT,CN5 ?014 ~58 ~CFT,CNL SGR,CM[, 64:655 C~R,CNb uPES,CNb 1,219 ~T~,C~L CG~,MGT ~7,432 THOR,~GT W1NG,NGT 207,623 W2NG.NGT WbN~.NGT 8,094 TENS.NGT C$,NGT 1798,000 HTEN.NGT C~,~T~ 56,8~1 TENS. DTE HT~,~T~ 547.000 IDDH:PH$ DPHT.LDT 3~,692 RHOR,LDT OLS.LDT -0.006 OS$.LDT LL.{,DT 252.695 bITH.LDT LSHV.bDT ~246.000 SSHV.LDT LU~,t, DT 2.135 CALI,LDT TENS,bDT 4185,ooo MTEM.LDT NPH~.CNL 40.702 TNPH C~L PCN, C~b 2357.792 RCFT:CNL SG~,CNL 69.862 CGR.CNL ~P~$.CNL 1'24! ~TE~.C~L CG~.NGT 64.~57 THOR.NGT W!W~.MGT 216,650 W2NG,NGT WbN~,MGT 5,015 TEN$,NGT C$.NGT iR03.000 HTEN.NGT 9-~AR-1993 09:08 87.063 MRES,LDT 24,138 TNRA,CNb 1341.016 CUTC,CNb 45.840 CALI,CNb 87.063 HTEM.CNL 7,176 POT~.N~T 90,180 W3NG,M T 4435.000 ~TEM,MGT 589,000 5,234 IL~.DTE 6,89! I~PH,DTE 0,000 CIDP,DTE 12,875 IIR~,DTE 4155.000 MTEM.DTE 6.894 XDER,PHS 2,2)6 DRHO,bDT '0,006 LS,DDT 115,750 SSI,bDT 1310.000 S1RH,LDT 9,484 SGR',bDT 8~,375 ~RE$,bDT 3 ,762 TNRA,CNL 39,8~8 CNTC,CNb 549,7 4 C~LI,CMh 8~.~15 HTE~ C~b . 8 POTA:NGT 319 W3NG,~GT 571.000 3,67~ IL~,DTE 3,398 IMPH,DTE 0 0~0 CIDP,DTE 31:~ 7 IIPu.,DTE 4!85.000 HTEM,DTE 3,401 IDER,PH$ 2,127 DRHO.L, DT 0,023 kS,bDT 160 ~25 SSI.,bDT 1310~000 '$1RH.LOT 8.844 SGR.bDT 85.563 MRES.bDT 39 948 TNRA.CNb 6291661 CNTC,CNb 56 881 CALI.,CNb 85 563 HTEN.CNL 4185 000 "TE~.NGT 547 000 t.204 2.130 297i.675 8.66~ 589.000 ~,~99 33,066 87,063 1950.000 1950.000 145.000 -994,500 86.]75 6,999 -0,008 381,750 202.50O 1.219 3,496 5O6 208~'484 ... 571,000 ~.427 24.072 86.375 1950,000 1950.000 294,000 -897.000 B~.563 .401 4~0,005 8.500 209,875 6e n62 3.391 5 g00 547,000 85.563 HTEN.LDT NPOR,CNL CFTC.CNL T~NS.CNL, SG~.NGT iJRAN.NGT W4NG.NGT ~RES,~GT IbD.DTE IFRE.DTE CXMP.DTE SG~.QTE M~E$.DTE IDVR.PHS PEW.bDT bU.bDT 8S2.,bDT LSRH,bDT CGR.bDT HTEN.LDT NPOR,CNb CFTC.CNL TEN$,CNb $GR,NGT URAN,MGT W4NG.NGT ILD,DTE CI~P,DTE SG~.DTbl MRES,DTE IDVR,PHS DEF.LDT LU,LDT SS2,LDT L,S~M,LDT CGR.LDT HTEN.bDT ~POP.CN{, C~TC,CNL TENS,CNL SGR.NGT IJRAN NGT MRES.NGT PAGE: 589,000 16.702 1285,374 4435,000 ~5,570 2.452 10.020 1.204 6,836 20.000 -994,500 64,655 7.025 2,537 360,250 294,750 2.244 49.794 571.000 41.559 621,269 4!55.000 62,904 2,3~7 R,024 1.2!.9 3,357 20.000 69,862 1,~41 3.405 2 2o 300.250 2.!3~ 56.881 547.000 38.521 6~1.431 4185 000 70:528 1,2~7 7.021 1,241 IS TaDe. Veri.flcatlon Llstino rhlU~berqer Alaska ComputiDo Center DFPT. 5500,000 SP.PT~ -56,656 TDPH.DTE ]O0~.DTE 0.000 IMOFoDTE Itgn. DTF 256.250 !IXD.DTE CG~.DTE ~1.557 TENSoDTE ,TE~.~TF 507,000 IDPH,P}!S DPH?.T,OT 37,155 RHnB.I,DT OL~.LDT -0,009 Q$S.bDT LL.LDT 295,250 bITH.bDT I.,$HV.LDT 1246.000 SSHV.bDT I,U~n. LDT 2.043 CAbI.LDT TENS.bDT 4055.000 ~TEM,LDT NP}{~.CNL 34,8d4 TNPH,CML RCNT.CML 2]63 726 RCFT.CMb SG~,CML 48:679 CGRoCMb ~ES.CNL 1,249 CG~,NGT 22,6~4 T~OR.NGT W~NC NGT 1~5.2ul W2WG MGT CS.WGT 1844,000 HTEN.NGT DEPT, 5400.000 SFLU,DTE SP.DTE -41.!88 [DDH,DTE IDO~.~TE 0.000 I~OF,DTE IIRD,DTE 105,688 II×D,DTE CG~ DTM 52 653 TEN$,DTE HTEN:DTE S47:500 IDPH.PH$ DPH!.LDT ~5.652 RHOB.bDT 05S.[OT -0.0 4 OSS. OT [,!,.LOT 2il.6~5 bITH.bDT LSHV.bDT 1246.000 SSHV.LDT LUmP.bDT 2.207 CALl.bDT T~NS.LDT 4075.000 ~TEM.LDT NPHT.CNT., 4~ 631 TNPH.CN~ RCNT,cNL 1949~912 RCFT.CML SG~.CNb 72.304 CGR.CNb ~E$.CNL 1.25'1 CG~ NGT a~ n73 THOR.~C ... W~iC~t~GT 24~:731 W2NG.N~T WLN~.~GT 7.021 TENS NGT CS.NGT lSa3'O00 HTFN:N(;T D[tPT. 5300.000 SFLU,DTE ~.DT~ -5~..375 IDPH.DTE !DQF.DTF n,000 I~QF..DTE IIRm.~TM 138,500 IIXO.DTE fG~.DTE 36,661 TEN$.DTE MTE~.DT~: 573.500 IDPH.PHS DPgY.LDT 34.3&4 ~HOB.LDT O[,S.I,,DT 0,005 DSS.bDT [,~,.LDT 272.750 LITH.LDT LSHV.LDT ~245.000 SSHV.bUT LUR~.LD? 2.102 CALI.bDT TENS.bDT 3830 000 ~TE~,LD'r N~!.~,CNL 40:307 TNPB.CNb 9-MAR-lNg3 09:08 3.43~ I[,M.OTE 3.283 IMPH.DTE 0.O00 CIDP.DTE 35.469 IIRM.OTM 4055.000 MTEM.DTE 3.285 IDER.PH$ 2,037 DRHO.LDT 0.029 LS,LDT 200.250 $SI.LBT i309.000 ~IRH.LDT 11.078 SGR.bDT 84.68~ ~RES.bDT 36,381 TNRA.CNb 6~.608 CNTC.CNL .557 CALI.CNL 84.688 HTEN.C~b 1.492 POTA,NGT 81.168 W3NG.NGT 405 .000 ~TE~.NGT 507.000 . 0 0 000 7!664 4075 000 8 580 2,227 0,038 121.125 1309.000 10.297 84 250 43 483 536 584 52 653 84 ~50 .026 10 .319 407~.000 54 .500 5,547 6.281 0.000 1~.188 383 .000 6,288 2,083 0 004 1309.000 9.109 83 375 401224 ILMDTE IMPH:DTE CIDP.DTE XIR~..DTE MTEM.DTE IDER.P~S DRHO.bDT LS.bDT SSi.bDT S1RH.bDT SGR.LDT ~RES,~DT TNRA,CNL CNTC,CNb CALI.Cg5 HTEN.CNb POTA.NGT W3NG.,NGT NTE~,~GT II.,~.DTE IMPH..DTE CIDP.DTE II~U.DTE ~ITEM.OTE IDER.PHS DRHO.LDT LS.LDT SSi.bDT $1RH.,bDT SGR.LDT MRESobDT TN~.CNb 1950.000 1950.000 304,500 -888.500 84.688 3.289 -0.011 548.000 211.125 2.090 48.679 1.~49 3.233 2316.764 11.078 507.000 1.068 26.052 84,688 1950.000 1950.000 !16.563 -994.500 84.250 8..483 0,013 402.500 216,125 2.162 72 304 3.615 2080.81.4 10 ?97 5471soo 1.127 39.117 84.250 1950.000 1950.000 150.125 -994.000 83.375 6.31! -0014 206.750 1.250 3.391 I[,D.DTE IFRF.DTE CIMP.DTE 8GR.DTE IDVR.PH$ PEF.LDT LU.LDT S$9.LDT [,SRM.LDT CGP.LDT HTEN.LDT NPOR.C~L CFTC.CNL TENS.CNL SGP,NGT URAN,NGT W4NG,NGT ~RES.NGT ILD.DTE IFRE.DTE CIMP.DTE SGR.OTE ~RES.DTE IDV~.PHS PEF.LDT LU.LDT SS2.LDT LS~H.I, DT CGR.LDT HTEN.LDT NPOR.CNL CFTC.CNL TEN$.CNL SGR.MGT URAN.NGT W4NG.NGT gRES.~GT ILD.DTE IFRE.DTM CIMP.DTE SGP.OTE ~PE$.DTE IDVR.PHS PEF.LDT LU.[,DT SS2.LDT LSRH.bDT CGR.LDT TEN LDT POR:CNb PAGE 3.254 20.000 -889.500 48.679 1.249 3.3~6 2.045 505.750 304.250 ~.047 31.557 507.000 35.689 721.304 4055.00O 47.941 3.~64 5.0~0 1.249 8 438 o:ooo -994.500 72.304 1,251 8.607 2.504 382.000 298.000 ~.213 52.653 547'500 46.943 574.718 4075.000 74,309 4.09l !0.030 1,251 6.246 2O 000 -994:o o 53.559 1.258 6.315 2.008 457.000 305.250 2.096 36.661 573.500 39.986 !~ ?a~e.¥eri,ficatto~ bi~tin.~ ;h]um~erqer, AlasKa Comp~lttnO Cente~ RCNT.C~!, 2271.999 PCFT.CM[, ~GP.CNL 53.559 CGR.CNL ~PEK.C~}, 1.258 CGR.gGT 32.346 THOR,NGT W~NC.~GT 181.363 W~NG.NGT WK~G.~GT 5.010 CS.NGT ~84~,000 HTEN.NGT DFPT. 5200.000 SFbU.DTE SP.DTE -5~.813 IDPH.DTE IDQF.DT~ 0.000 IMQF.DTE I~RD.DT~ 92.313 IIXD,DTE C~P.~T~ 26.2~8 TEN~,DTE HT~.DTE 505,250 I~PH,PHS DPH!.LDT 36.038 RHOS.bDT OLS.bDT 0.oll OS$,bDT LL.~,DT 297,000 LITH,bDT LS~V.LQT 1~6.000 SSHV.LDT bUR~.L~? 2.059 CALI,L~T Tw~$.LDT ' 37~5 000 ~TE~.bOT NPHI,CNL 36~594 TN~H,CNL ~e~T.CNL 2445.210 RCFT CML ~GP,CNb ]1,6~1 CGR:CNb ~RE$.CNb 1.279 ~TE~.CNh CG~.NGT 32.442 THOR.NGT W~N~.N(;T 103.966 W2NG.NGT wb~.UGT 4.2~7 TE~$.NGT CS.~GT ~846.000 gT~N.~GT DEPT. 5!00 000 SFLU,DTE SD.DT~ -49~56~ IDPH,DTE IDOF.DTE 0.000 IMOF,DTE I~N0.DTF 87,500 II×D,DTE CGP.DT~ 55,812 TEN$.DTE {,{T~.DTE 490.000 IDPH.PHS DPHT.LDT ~2,1~0 ~HOg. DDT OLg. LOm 0.017 QS$,5DT DL.I, DT 201.500 bITH.LDT LSHV,LDT 1246,000 SSHV.DDT bUPg [DT ~,270 CALI.LDT TFNg:LDT 3495.000 ~TEM.LDT N~I,C~L ]~.738 T~PH.CNL RC~m.C~L 2203.1~8 RCFT.C~L SGP.Cg!,., 73.676 CGR.CML ~PES.CNL 1,272 ~T~.CNL CGP ~GT 62.440 THOR.MGT wLNC,~(;T 8.008 TENS NGT C$.NGT 1850'00{i) DEPT. 5000.000 SFLU.DTE SO.DT~ -44,406 IDPH,DTE IDOW.DTE 0.000 I~OF.DTE IIRD.OTE 143.1~5 II×D.DTE CG~.DT~ 63.10~ TENS.DTE 9'~AR-1993 09:08 620.~88 CNTC.CNb 36.661 CALI.C~h 83.375 HT~N.C~L 3.91] POT.~ ~GT 9t.182 3830.000 573,500 10,]98 ILH.DTE 10,273 !MPH.DTE 0.000 CIDP.DTE 9,539 IIR~,DTE 3785.000 MTEM.DTE 10.282 IDER,PHS 2.055 DRHO,bDT 1309,000 S1RH.BDT 9,344 SGR,bDT 8~.)~3 ~RES.bOT 3 , 1 TNRA.CNL 733.~3 C~TC,C~b 26. 8 CAbI.CNb 82.563 HTEN,Cflb 3.644 POTA.NGT 4~.872 W3NG.NGT 378 ,000 ~TEM.NGT 505,250 ' ' 8,648 IbM.DTE 10.281 IMPH,DTE O ~00 CIDP.DTE 4:41 IIR'~.DTE 3495 000 ~TE~,OTE 10:~89 IDER.PHS ~.284 D~HO,LDT 0.038 LS.LDT 112 ~3 SSi,bDT 1309~ 0 S1RH,hDT 9 GR, 81:~4 S bDT 5 MRES,bDT 39 548 TN~A,CNL 563~027 CNTC,CNL !2~I 2 W3NG,NGT 490 000 5,086 Ib~,DTg 6,141 IHPH,DTE 0.O00 CIDP.DTE !~,631 II~,,DTE ,000 ~TE~.DTE 2251.552 9.109 573.500 1.091 20,040 83.375 1950.000 1950.000 97.250 -993.500 82.563 10,580 0.000 543 5OO 2.057 1.279 3.20~ 2407,489 9.344 505.250 t,163 17.149 82,563 1950.000 1950.000 97,188 -993.500 81.875 10.2O2 0.027 373.750 218.000 2.174 73.676 1.27~ 3 304 9 094 9o:ooo 8! .875 1950.000 1950.000 162.750 -993.50O 81.375 CFTC,CML TENS.CML SG~.~GT L{R&~.NGT W4NG.WGT MR~$.NGT ILD.DTE IFRE.DTM CIMP.OTE SGR.DTE MRES,DTE IDVR.PHS PEF.LDT U.LDT 8'2,LDT bSRN.LDT CGR,LDT ~TEN,LDT NPOR.CNI, CFTC.CML T~MS.CNb SG~,NGT UR~N.NGT w4~G.~GT ~RES,NGT I[,D.DT~ IFRE,DTE CI~P.DTE SGR,DTE MRE$.DTE IDVR.PHS PEF.LDT LU.LDT SS2.LDT LSRH.LDT CGR.bDT HTEN,bDT M~OR.CML CFTC,CML TENS,CML SGR.NGT URAN,~GT W4NG,NGT ~ES,~GT ILD,DTE IFRE,DTE C!~P.DTE SGR.DTE PAGE~ 668.327 3830.000 51.640 2.597 5.010 1.258 9.828 20.000 -994.000 31.681 1.279 !0.741 1.,9~8 493.250 3i3.500 2,055 26.248 505.250 36.763 753,700 3785.000 32.389 -0.054 0.000 !,~79 10.125 20.000 -994.000 73.676 1.272 10.1,71 2.6~9 344.750 298.000 2.256 55 812 490:000 37.222 626.362 3495.000 75.~59 1.581 8,008 1.272 6,070 20.000 -993,500 78.553 1.282 wane Vert,ficatto. Listina .'hlumberger Alaska Computin~ Center H~FN.DTE 400.750 IDPH.PH$ DPHI.I.,DT 31.428 RHOB.bDT O%K.bDT 0.000 O$$.LDT bL.L~T 251.000 LITH.LDT [,~HV.LDT ~245.O00 SSHV.LDT [,{!~g. t,DT 2.143 CALI.bDT TENS.LDT 33~5.000 MTEM.LDT ."g?,C~L 46.753 TNPH.C~L ~CNT.CNL 1~2.9~4 ~CFT.CN5 SGR.CN5 78.553 CGR.C~5 ERES,C~L 1.282 ~TE~.CNL CG~.UGT 65.575 THOR..NGT WlNC.NGT 264.5~9 W2NG.NGT wS~C.~G? 13.026 TEN$..NGT C~.~GT 1841.000 HTEN.NGT [)EDT. 4900.000 ~FbU.DTE $~.DTE -47.813 IDPH.DTE IDOF.DTF ~,000 I~OF.DTE II~D.DTE 113.313 II×D.DTE CG~.DTE 52.030 TENS.DTE HT~%,.nT~ 539.500 IDPH.PHS DPg?.LDT 29.796 RHOB.LDT OL$,LDT -0.005 QS$.LDT 5L.L~T 24~.~5 bITH.LDT LSHV,LDT ~245.000 SSHV.LDT [,,U~M.LQT 2.158 CALI.LDT T~M$.L~T 3540.090 MTEM.bDT NPHl.CNb a~,153 TNP}{.CNL ~CNT.CNL ~59.370 ~CFT.CN5 ~G".CNL 64.937 CGR.CN~ ~$.CMb 1.2~2 mT~ CN5 CG~.MGT 56.!~0 THOR:NGT WING.MGT 2~2,675 W~MG.NGT wS~C.WGT ~.593 TEM$.NGT CS.wGT ~842.000 ~TEN.WGT D~PT. 4800.000 SF[,U.DTE SU.DTE -47.375 IDPH.DTE !DO~.DTE 0.000 IMOF.DTE I~n.DT~ 121.500 IIXD.DTE CGg.UTE 50.4{0 TEN$.DTE HTE~{.DT~ 437.500 I!)PH.PHS DP~I.LDT 32.34.5 RHOB.LDT OL$.LDT -0.009 QSS.LDT LL.I.,,DT 260.000 LITH.LDT LSHV.LDT ~245.000 SSHV.LDT [,URM. LD~ 2.117 CALI. bDT TMg$.LDT 3395.000 ~TE~.LDT MUM? .CN! 40.~70 TNPH.CNL RCNT.C~t, 2270.465 RCFT.CNL SG~.CNL 55.0~7 C~R.CNL M~E~.CML 1.295 ~m" CML CG~.~T 53.802 ~HOR.NGT W~.~ ' . ..G~ ~79 ~0 ~NG.N~T 9-~AR-1993 09:08 2 1~1 DRHO.bDT 0:0 4 [,S.LDT 143.625 $SI.bDT 1308.000 SlRH.LDT 9.969 SGR.L~T 8~.375 ~RES.LDT 45.~13 TNRA.CN[, 442.756 CNTC.CNL 63.101 CALI.CNb 81. 75 HTEN.CNb 10.160 POTA.NGT 123.246 W3NG.NGT 3315.000 MTE~.NGT 400.750 6.855 ILM.DTE 7.918 IMPH,DTE 0.000 CIDP.DTE 12.633 IIR~.DTE 3540.000 MTEM.DTE 7.920 IDER PHS ~.lS8 DRHO:LDT 0.gg6 bS.bUT 14~. 0 S$1.LDT 1309,000 $1RH,LDT 9.500 8GR.hDT 80.438 MRES.bDT 40.]4! TNRA.CNG 58~ 716 CNTC.CNL 5~030 CALI.CNL 80.438 HTEN,CNb 8.428 POTA..NG? 97.744 W3NG.NGT 3540. 000 MTEM 539.500 6340 0 000 11i977 3395000 7.459 2.116 0,022 173.250 1,308.000 10 297 80 125 39 491 594 786 50 410 80 6 508 96~903 ILM.DTE IMPH..DTE IDP.DTE ~IRM IDER.PH8 DRHO.LDT SSI.LDT SI~H,LDT SGR,LDT MR~$.LDT TNRA.CNL CNTC.CNL CALI CN5 HTEN:CND POTA.NGT W3NG.NGT 6.20t -0.003 463.750 211.125 2.146 78.553 1.282 3.814 1845.450 9.969 400.750 1.668 35.070 81.375 1950 000 1950!000 126 250 -993.500 80.438 8.035 0.006 44'9.500 215.125 2.129 64.937 1.282 3.524 2141 422 9:500 539.500 1.492 3~,520 8 .438 1950.000 1950.000 .134.000 993.500 475 -0.002 482.250 212.750 2.123 58.087 1.295 3.486 2253.476 1~.297 43 .500 1.821 22.977 !DVR.PHS PEF.LDT LU.LDT SS2.LDT L$~H.LDT CGR.LDT HTEN.LDT NPO~.CNI., CFTC.CNL TENS.CNL SGP.NGT URAM.NGT W4NG.~GT M~E$.~GT !LD.DTE IFRE.DTE CI~P.DTE SG~.DTF MRES.DTE IDVR.PHS PEF.LDT t,!!.LDT SS2.LDT [,S~E.I, DT CG~.LDT HTEN.[,DT NPOR.CN[, CFTC.CNL TENS.CNL SGR.NGT U~AN.NGT W4NG.~GT I'LD.OTE IFRE.DTE CIMP.DTE SGR.DTE uRE$.DTM IDVR.PHS ~EF.LOT LU.LDT SS2.LDT LSRH.LOT CGP.DDT HTEN.I, DT ~PO~.CNI., CFTC.CNL TENS.CNL SGR.NGT URAN.NGT W4NG.NGT P AGE: 1 1 6.195 2.721 425.750 305.250 2.133 63.10~ 400.750 44.140 496.953 33!5.000 73.483 1.496 8.016 1.282 7.809 20.000 -993.500 64.937 1.282 8.026 2,271 415.000 305.000 2.152 52.030 539.5O0 40.!35 631.051 3540.000 67.7~6 1.506 5.371 1.282 7.277 20.000 -993.500 58.087 1.295 7.402 2.1.56 444.250 305.500 2.1!7 50.410 437,500 39.3~6 667.789 3395.000 60,963 0.808 5.994 Verification [,istinq Alaska ComDuttnq Center WbN~.MGT 4.995 TEN$.NGT C$.MGT 1839.000 HTEM.NGT 4700 000 SFLU.DTE TDPH DTE D ,,_ -~6: 219 . IDQF.DT~ 0.009 IHOF.DTE II~.DT~ 95.813 IIXD.DTE CG~.DTE 53.!64 T~NS.QTE HT~.DT~ 482.000 IDPH.PHS DPH~.[DT 31.4~ ~HO~.LQT bDT -0.011 O$5.bDT Lb. t, DW 260.250 LITH.LDT [.,$HV. LOT 1245.000 SSHV.LDT bDT ~. 11.7 CAI, I. bDT TFNS.LDT 3325.000 HTEM.bDT NPMI.C~b 49.170 TUPM.CNL RCNT.C~,b ~ 803.4~3 RCFT.CNb CN[, 69. 567 CGR. CNb ~ES. C~t., I .2B5 ~T~M.CN5 CG~.NGT ~7.4~ 3 THO~. NGT W~C.NGT ~16.649 W2NG.NGT WbNG.NGT 3.~2 TENS.NGT C~, k~GT 1840.000 HTEM.NGT DF.P?. 4600.000 SFLU.DTE ~T~ -48.063 If)PM DTE T nO~: o"r'E O.OOO T.~OF.*DTE OTE ~15.6fl8 IIXD.DTE .DT~ 51.140 TENS.DTE HTE~t. I)TE 5~6.500 IOPH PHS ,LOT 30.685 RHOB:LDT . bDT -0. O01 OSS. bDT LL. [.,DT 256,500 LITH. I, DT [,,SgV, LDT 1245.000 SSHV bDT , bDT 2, I 3 1. CALI: LOT T~N$.LDT 3~45.000 ~TE~.bDT .CNL 41.5~,9 TNPH.CNL PCNT.CNb 1867 ~14 RCWT.CNb .tNb - 73:,,16 CGR.CNn M~E~.CNL I .297 ~TE~.CNb CG~.NGT 51.332 T}{O~. NGT w~N~.~GT 232.303 W~NG NGT wSMG.NGT 5.982 TENS~]GT CS.NGT 1873.000 HT~.N. NGT g-~AR-~g93 09:0~ 3395.000 437.500 6.277 ILM.DTE 9.344 IMPH.DTE 0.000 CIDP.DTE 8.477 IIR~.DTE 3325.000 MTEM.DTE 9.349 IDER.. 2.131 DRHO.LDT 0.021 bS.bDT 1.6~.625 SSI.bDT 130 .000 S1RH,bDT 10.~73 SGR.bDT 79. 00 MRES,bDT 48.0~1 TNRh. C~L 464,6.6 CNTC,CNb 53.164 CALI.CNL 79.500 HTEN.CNb 5.~1 POTA.NGT 1.29, 6 W3NG.NGT 332~.000 ~TE~.NGT 48 .000 6.305 7,7['10 0.000 ~0 469 31451000 7.796 2.144 0,038 148.750 000 672 79 438 44 303 457 087 51. 140 79.4388 7.3 4 110,668 3145.000 526.500 ILM.DTE IMPH.DTE CIDP.DTE IIRM.DTE ~TE~.DTE IDER.PHS DRHO,LDT L$,LDT SSI..LDT SIRH bDT SGR:LDT MR£S,bDT TNRA,CNb CNTC.CNL CALI,CNL HTEN.,CNL POTA.NGT W3NG.NGT ~TEM.NGT SP.r)T~ -51.531 IDPH.DTE 10:o~4 IMPFt. DTE 1Boc. D..,E, 0.000 I~OF.DTE 0.000 CIDP,DTE !!RO.DTE 87.938 I!×O.DTE 7.891 IIRM.DTE .... . · ~' N 'e · ~ ~G~ [~T~ 46 236 TE $ DTE 3200 0 MTEm,DTE 0 H?EW.DT~ 468.250 IDPH.PWS 10.~1 IDER.P~S D~I.!.,DT 32.152 R~OB bDT 2.!19 DRHO.LDT ~,.bS.LDT -0.008 OSS:LDT 0.001 LS.LDT LL.LDT 2~4.375 LITH.LDT 162.500 SSi.bDT LSHV.LDT 1245.000 SSHV.LDT 1308.000 SIRH.LDT 80.125 1950.000 1950.000 106.938 -993.000 7~.500 .278 0.015 48~.750 222.750 2.055 69.557 1.285 3.971 1968.379 10.273 482.000 1.635 37.353 79.500 1950.000 1950.000 128.250 -993,000 79.438 7.849 0.021 474.000 223.875 2.051 73.216 1.297 ~:640 189 519 12.67~ 35.892 79:438 1950.000 1~50.000 96.~25 -993. O0 78 38 4~0 009 1ooo 208.000 2.164 ~PFS.NGT ILD.DTE IFmE.DTE CI~P.DTE SGR.DTE ~RES.DTE IDV~.P~S PEF.LDT LU.LDT $S2.LDT I.,$RH.LDT CGR.LDT HTEM.LDT NPOR.CNL CFTC.CML TENS.CNb SGR.NGT URAN.NGT W4NG.NGT ~RES.NGT ILD.DTE IFRE.DTF CT~P.DTE S~R.DTE IDVR.PHS PEF.LDT LU.LDT SS~.LDT LSRH.LDT CG~.LDT HTEN.LDT NPOR.CNL CFTC.CNL TENS.CNL SGR NGT URAN:NGT W4NG.NGT MRES.NGT .. ILO.DTE IFRE.DTE CIMP.DTE !DYR.PHS PEF.LDT t,t!.LDT SS2.LDT LSRH.LDT PAGE: 1~ 1.295 9.242 20.000 -993.000 69.567 1.285 9.214 2.301 445.~50 320.250 2.115 53.164 482.000 53.000 505.509 3325.000 67.919 2.571 6,403 1,2~5 7,633 20.000 "993,000 73.216 1.297 7 ~7l 2:604 435.000 314.250 2.121 51.1~,o 526.500 45.224 503 959 3t45~000 69.0~9 2.650 7.976 1.297 1.0.078 20.000 -993.000 55.805 1.321 10.143 2.348 435,000 306.500 2.127 [,~ ?a~e. Ver],f.{cat~on Llstinn ~-hlu~.erqer AlasKa Computing Center g-MAR-1993 09:08 W1Na. NGT 180.363 W2NG.NGT 84.312 W3NG,NGT 26.681 W~C.~.'GT 4.269 TE~$.NGT 3200.000 MTEM.NGT 78.43~ C$.~GT 1874.000 gTE~,~GT 468.250 DFPT. 4400.000 SFLU.DTE SP.DTE -49.O06 IDPH.Q?E ].DOW.DTF 0.000 I~OF.DTE I?~D.DTE 07.438 II×~.DTE CGn.DT~] 47 154 TEN$.DTE ~TEN.DTE ,3~7~750 IDPH,P~$ DP~.LDT 35.197 RMOB.LDT OLd.bDT -0.001 O$S.LDT L!,.bDT 286,750 LITH.bDT LSHV.I,,DT ~245.000 $SHV.LDT LUR~.LDT ~.068 CALI.LDT T~N$.LDT ~940.000 ~TE[~.LDT NP~I.CNL 40,906 TNPH.CNL RCNT,CNL 2260.453 RCFT.CNL $~P.CN!, 6!.~04 C~R.C~L ~ES.C~L 1.314 MTEM,CN5 CG~.NGT 56.763 TMOR,NGT W1NC.MGT 198.405 W2MG,.NGT WS~n. NGT 6.979 TENS.MGT C$.NGT 1876.00~ HTEN.MGT 7.543 ILM.DTE 1950.000 9.~81 I,PH.DTE 1950.000 0.000 CIDP.DTE 107.688 9.055 IIR~.DTE -992.500 2940.0~0 MTEM.DTE 77.938 9.2 8 IDER.PHS 9.401. 2.069 DRHO.LDT 0.003 0.034 LS.bDT 52~.500 1~.125 SS~.LOT ~18.375 13 .000 S1RH.LDT 2.051 9.~66 SGR,LDT 61- 204 77.938 MR~$.LDT 1~314 40.639 T~RA..CNL 3.437 59~.~0~ C~TC,CNL ~21~.752 47. 54 CALI.CNL 9.266 93.7'9 W3N~,NGT 3..o95 ~940 000 MTEMoNGT 77.938 387: 75O DEPT. 4300.000 SFLU.DTE 7 117 II, M,DTE 1950.000 · SP.D~.,'R -52.i88 IDPH DTE 6:53t IMpH.DTE 1950.000 IDOF.DTE 0.000 I~OF:DTE 0.000 CIDP.DTE 153.000 1~0. ~DT~ 139.500 IIXD.DTE 23.641 II~M.DTE -992.000 I'CG~DT~ 41.079 TENS.DTE 2765.000 MTEM.DTE 76.875 HTEN.DTE 383.500 IDPH.P~S 6.536 IDER,.PHS 6.607 DgHI.I, DT 34.551 ~HOB.bDT ~.0~0 D~O.LDT -0.00~ OL$.bDT 0 013 O$$.LDT 0.028 LS.SDT 514.000 [,L.LDT 2~7~000 [,ITH.LDT 183.875 SSI.LDT ~14.125 LSHV bDT 1.245.000 SSHV LDT 1308.000 S1RH,[,DT 2.092 i, UI~LDT 2.0~0 CALI~LDT 10.086 ' SGR.LDT 55.504 T~N$. bDT 2765.000 MTEM. LDT 76.875 MRES.LDT 1.330 NDHI.CNL 38.508 TNPM.CNL 38.474 TNRA.CNL 3 373 ~CNT.CNL ~3~8.506 ~CFT.CNL 610 394 CNTC.CN[, 2313~898 SG~.CNL 5~ .. · . . .... ~.504 CGR.CNL 41~07~ CALl CN5 10 086 ~E~.CN[., ~.3~0 ~TE~.CNL 76.875 HT£N.CN5 CGP.NGT ~4.657 THOR.NGT 4.664 POT~.NGT 1.687 W~NG.NGT 163.4.62 W2NG.NGT 88.675 W3NG.NGT 33.120 WSN~.NG~ '5.34~ TEF~$.NGT 2765.000 ~TEg. NGT 76.875 CS.NGT !878.000 gT~N.NGT 383.500 CGR.L, DT HTEN.LDT NPOR.CNL CFTC.CNL TENS.CNL SGR.NGT URA~.NGT W4~G.NGT MRES.~GT II~D.DTE IFRE.~TE CI~P.DTM SGR.DTE ~RES.DTE !DVR.PHS PEF.LDT I, tI.t, DT S$2.LDT GSR~.LDT CG~.LDT HTEN.LDT NPO~.CNL CFTC.C~L TEN$.CN[, IJ~A~ NGT M~E$.MGT IbD.DT~ IFRE.DTE CIMP.DTE SGR.OT~ MRES.DTE IDVR.PHS PEF.I.,QT t,U.LDT SS~.LDT LSRH,LDT CG,.LDT HTEN.LDT NPOR.C~L CFTC.CNL SGR.NGT U~A~.NGT WaNG.~GT PAGE: 13 46.236 468 250 40:497 722.82g 3200.00o 56.485 3.003 2.134 1,321 9.102 20.000 -992.500 61.204 1.314 9.454 2.244 48~,750 311.750 2.064 47.154 387.750 39,834 650.501 2940,000 60.608 0.400 2.991 1.314 6 363 201000 -996.000 55.504 1.330 6.636 2 248 474i250 307 000 2.0P2 41.079 383.500 38.559 700.596 2765.000 55,7~9 1.524 3.205 1.330 IS Tape Vert. flcation [.istlno ~hlUm~eroer A}aska Computino Center DFPT. 4200.000 SPLU.DTE SP.DT~ -54.1~5 TOP!J.DTE IDOF.DT~ 0.0~O IMQF.DTE IT~n. DT~ ~1.563 IIXD.DTE CG~.DT~ 40.598 TENS.DTE HTE~!.DTE 3R5.750 tDPH.PH$ OP~.LDT 34.g~1 R~OO.LDT OL$.I,DT -0.019 DSS.bDT bT,.LDT 28~.000 ~ITH.bDT LSHV.!,DT 1245.000 LUg~.LD~ 2.064 CAbI.LDT TFNS.LDT 2565.000 MTEM.LDT N~H~.CNL 38,151 TNDH*CNL PCN?.CNL 2272.414 RCFT..CNb SG~.CNL 51,191 C~.CNL M~S.CNI, 1.3~9 ~TEM.CNL CG~.NGT 44.~]2 THOR.NGT WbNC.N~? ~'134 TEN NGT CS.NGT 1876.000 HTEN.NGT DMPT 4!00 000 SFbU DTE SP.:!)TE 531969 IDPH:DTC ]mO? DT~ 0 000 .[MOF DTE C~ ~TF ~7.530 TEN~.~TE HT~U:DTE 2~2.250 IDP~. DPH~.[,DT 33.749 R~OB.LDT ObS. LDT -0.016 085, bDT L!,.LD~ 268.750 LITH.L~T LSHV.LDT {245.000 S$~V.LDT LURH.LDT 2.096 CALI,bDT TFN~.!,DT ~465.000 WTEM.LDT NPH! CN[, 5~ 706 TNPH CML RCM~:CN!, ~78~:845 ~CFT:C~L ~PES.CNL 1.334 MTE~.CNL C~.NGT 57 ~88 Wi~.NGT 247~~58 W2NG.NGT WbUG.NGT 5.982 TENS.NGT C~.NGT t878.000 ~TMM'NGT DEPT. 4000.000 SFbU.DTE SP.DTF -54.063 IDPH.DTE IDO~.DTE 0.000 I~OF.DTE IT~D.DT~ 75.563 IiXD.DTE CG~.DTE 45.70,3 TEN$.DTE ~TEN.DTE 538.500 !DPH.PHS DDHT.LDT 38.442 ~HOB.LDT OLS,LDT n.O!J DSS.bDT LL.LDT 304.750 LITH.LDT I,S~V.LDT ~245.000 SS~V.LD'r T~NS.bDT 2515.000 ~TEM LDT NPHI.¢~I, 37.133 TNDH:CNb 9-~AR-1993 09:08 8.219 ILM.DTE 11.227 IMPH.DTE 0.000 ¢IDP.DTE 6.543 II~.DTE 2565.000 MTEM.DTE 11.236 XDER.PHS 2.074 DRHO.LDT 0.032 LS.LDT 188.250 S$1.LDT 1308,000 S1RH.LDT 11.086 SGR.L~T 76,688 MRES.LDT 38.855 TNRA.CNL 5~.947 CNTC.C~b 64 .,~98 CALI..CNb 76.688 HTEN.CNL 5,813 POTA.NGT 77.908 W3NG.NGT 2565.000 ~TE~oNGT 385.750 6.0~0 ILM.DTE 7.8 6 0.000 CIDP DTE ~,828 2465.000 MTEM.DTE 7.839 IDER,PHS ~.093 DRHO.LDT 0.011 LS.LDT 625 6 W)NG.~GT 2465 0 ~TE~4 NGT 8.586 IbM.DTE 12.375 IMPH..DTE 0.000 ¢IDP DTE 7'69! IIRM.:DTE 2515:000 ~TE~.DTE 1~.388 IDER.PHS 2.0 6 0.02! L$.bDT 195.000 SSI.bDT 1308 000 $1RH:.bDT 101844 SGR.bDT 76.3!3 MR~S.LDT 36.425 TNRA.CN5 1950.000 1950.000 89.000 -992.500 76.688 11.158 0.004 525.500 218.375 2.055 51.191. 1.329 3.414 2257.649 1].086 ]85.750 1.373 28.815 76.688 ILD.DTE IFRE.DTE CIMD.DTE SGR.DTE IDVR.PH$ PEF.bDT LU.[,DT S$2.LDT LSRH.LDT CGR.LDT HTEN.5DT NPOR.CNL CFTC.CNL TENS.CNb SGR.NGT URAN.NGT W4NG.NGT 1950.000 ]LD DTE 1950.000 IF~E:DT~ !27.563 CIMP.DT~ -99~.000 SGR.DTE 6.3~3 ~RES.DTE 77.906 IBVP.PHS -0.001 PEF.LDT 500.000 LU.LDT ~14.375 SS2.t, DT 2.098 LSRH.LDT 7~.403 CGR.bDT 1.334 HTEN.LDT 4.104 NPOP,CNL 1R32.923 CFTC.CNL 10.211 TENS.CN[, 242.~50 SGR.NGT 1.906 URAN ~GT 36:889 W4NG:NGT 76.313 MRES.NGT 1950.000 1950.000 80.750 -992.000 76.313 12..834 -0.018 559.5OO ~os.noo 2.~o4 57.858 1..343 3.352 IbD.DTE IFRE.DTE CI~D.DTE SGR.DTE ~RES.DTE IDVR.PHS PEF. LDT LU. LDT SS2 . LDT LSRH. bDT CGR.LDT HTEN.LDT ~POR.CNL PAGg: 10.922 20.OO0 -992.500 51.191 1.399 11.!06 2.170 487.000 312.000 2.068 40,595 385.750 38.736 670.558 2565.00. 51.918 1.1~8 6.403 le329 7.672 20.000 '992.000 78.403 1.334 7.884 2.438 462.250 3 750 3 22o94 57.530 24~.250 52.056 453,532 2465.000 78.142 2.693 7.976 i.334 11.96l 20,000 -992.000 57.858 1.343 13.O71 2.363 509,750 303,750 2.033 45.703 538 500 t 4 AlasKa ComPut. inq Center pCN~.C~b 2227,57! RCWT.CNL SG~.CNL 57.858 CGR.CNb MwE$.CNL 1,343 C~.~!GT 38.100 ~lug.~G~ 179.296 W2NG,NGT WSNc,MGT 5,336 TENS,NGT C$.MGT 1992.O00 HTEN,NGT D~:P~. 39n0.O00 SFLU,DTE Sn. DTE -53,563 ~DPH.DTE IDQW,DTE 0,000 I~OF,DTE I~D,DT~ 9?,063 I!×D,DTE CG}.DTF 6P.636 TEN$,DTE HTE~,OTE 335,750 IDPH,PHS DPgT.LDT 3~,066 ~HOB,LDT ObS,LDT 0,000 Q$S,bDT LL.LDT ~54.375 LITH,LDT LSHV.bDT 1245,000 SSHV,LDT t. UR~.LDT 2,135 C~LI,L~T T~S.bDT 2~55,O00 WTE~,LDT NP~I,CNL 49.648 TNPH,CML ~CN' CNL ~.752 288 RCFT.CWb ~RE~,CMt, 1,359 MTFM,CNb CG~,NGT 60,297 THO~,NGT wlNC.~GT 304,7~1 W2~G,NGT WSNG,NGT 11.952 TENS,NGT C$,NGT 1885,000 MTEN.MGT ~ "~ IDOM.DTE 0.000 I~R~.DTE 92,438 IIXD,DTE CGP.DTE 43.497 TENS,DTE ~TE~.OT~ 306,000 IDPH,PHS DP!~I.LDT 35.283 ~HO~,LDT 0LS,bDT -0,005 QS$.LDT LL,LDT 284,750 LITH,LDT LSNV.LDT ]245,000 SSHV,LDT LURW.LDT 2,070 CALi,LDT T~M~,LDT 2325,000 MTEM,LDT CML 39,876 TNDH,CNP RCWT~CNL 1950,818 RCFT,CNL 50.735 ,DES.CNL 1,35~ NTE~,CNL ~YGT 52,A~4 THOR NGT WSN~.NGT 4.2~3 TEN$,NGT cs. o t o.ooo 9-MAR-1993 0~:08 617.181 CNTC,CNL 45,703 CALI.CNb 76.]I] ~TEN,CNb 4 443 POTA.NGT 87:5 3 2515.000 MTE~,~GT 538,500 6,777 ILM,DTE 9,789 IMPH.DTE 0.000 CIDP.DTE 7.375 IIRM,DTE 2455 0~0 MTEM,DTE · 9:7 7 IDER,P~S ~.121 DRHO,LDT 0.008 bS,bDT 130 000 SIRH,LDT 9.24~ SGR.bDT 68,636 CALI,CNL 76.063 NTEN,CNL 8,752 POT'A,NGT 140.438 W3NG,NGT 2455.000 ~TEM,NGT 335.750 8 570 IL~,DTE 10:670 tMPH,DTE 0.000 CIDP,DTE 7,984 IIR~,DTE 2325 99o ~TE~,DTE 10:o74 IDER,PH$ 029 LS,LDT ooo 1.1,164 SGR,LDT 75,125 39,681 TNRA,CNL 5~&.467 CNTC,CNL 43 497 75 1 5 .TE .C 5 6.460 OT .N T 2325.000 306.000 9,039 IL~4.DTE 11.672 IMPH.,DTE 0,000 CIDP,DTE 5,94] IIRM,DTE 2395,000 ~4TEM.DTE 2250.570 10.844 538.5O0 1.326 29.88t 76.313 1950.000 1950.000 102.063 -991.500 76.063 9.805 -0,008 470,000 208.500 ~,162 89,485 1.359 3.913 8.136 1739.242 335.750 1.678 41,833 76.063 000 g:ooo 99.250 -991,500 75.125 9,661 0.000 526.000 2i6.000 2,070 50.735 1.352 3 510 199!~567 ll,164 306.000 1,744 29.97q 75.]25 1950.000 1950 000 74.750 CFTC.CNI, TEN$.CNL !IRAM.NGT W4NG. NGT MRES. NGT ?LD.DTE IFRF.DTE CI~P.DTE SG~.DTE MRES.DTE IDVR.PHS PEF,LDT LU.LDT $S2.LDT LSRM,LDT CGR.LDT HTEN.LDT NPOR.CNL CFTC.CNL T~N$.CNL SGR.NGT URAN,NGT W4NG,NGT MRES.MGT ILD.DTE IFRE,DTE CIMP.DTE SGR.DTE M~ES,DTE IDVg,PHS PEF,LDT LU.LDT SSP.LDT LS~M.LDT CGR.LDT HTEN,LDT NPO~.C~L CFTC.CML TENS,CNL SGR.NGT U~AS'.NGT W4MG,NGT MRES.MGT IbD.DTM IFRE.DTE CI~P.DTE SG~.DTE PAGE: 15 702.156 2515.000 59.6!5 2,770 9.605 1.343 9.625 20.000 -991.500 ~9.485 1.35g 9.770 ~,590 431,000 304.5O0 2,~99 68,636 335,750 46.789 459,301 2455,000 ~7.003 3.582 7.968 1,359 9.609 20.000 -992.000 50.735 1.352 9.660 2,268 483,250 3J. 0.250 2.066 43.497 306.0~0 ~0.815 582,098 23~5.000 50,970 -0,193 5,353 1,352 11,344 20.000 -991,500 70.778 !,353 H?5,~. DTE 374.?$0 IDPH.PHS D~Ul .!,DT 32.557 OLS. LnT -0.0 ~ 7 DSS. LL.LDT 256,750 LITH.LDT [,SHV.[,DT 1245.0n0 SSRV.LDT m~'$.bDT 2395.0n0 ~TEM.LDT ~:PHT.CNL 46.641 TNPH.CNL ~CN~.CNL 2026. 154 RCFT. C~L SG~.CN[, 70. 778 CGR.CML ~ES.CNb 1. ]53 ~TEu.CNL CG~.NGT 48.882 THOR.NGT wIN~.UGT 224.775 W2NG.NGT ~BN~.NGT 8.99! TENS.NGT C$.NGT 19~9.000 NTEN.NGT DFUm. 3600.000 SFLU.DTE SP DTE -57.281 TDPH.DTE !DOF:DTF 0.000 I~OF.DTE I~R~.DTE 121.438 IIXD.DTE CG~.DTE 63.684 TEN$.DTE HT~, ~T~ 335 25~ IDPH.PH$ DPH~LDT 3~37.. ~HOB.LDT OL~.LDT -0.01~ OS$.LDT L~.LDT 259.000 [,ITH.LDT LSHV.bDT 1.245.000 SSHV.bDT LURH.LDT 2.119 CALI.BDT TEN$.LQT 2205.000 ~TEH.BDT ~PHT.CML 46.990 TNPH.CNL ~CNT.CNb !6g~.738 RCFT.CNL ~G~.CNL 9~.~40 C~R.CNL ~PES.CNL 1.350 ~TE~.CNL CGW.NGT 7~.590 THOR.NGT WlN~.NGT 298.077 W2NG.N(;T WBN¢.~GT ~3.889 TENS. NGT C$.NGT 1916.000 HTEN.NGT 8P~DTE '-54.03i ..DPH.DTE 69.0oo I OF..OTE CG~.DTE 41.157 TE'$.DTE HTE~.DTE 389.250 DPHT.LDT ~7.578 RHOB.LDT OL$.LDT -0.011 DSS.bDT L~.,.L~T 302.750 LITH..LDT LSHV.LDT 1245.000 SSHV.LDT L[!RP. ~UT 2.0~9 CA[,I T~NS.bDT 24J0o000 ~TEg.LDT NPHT CNL 37.266 TNPH CNL ~C~!T~CNL 2300.952 RcFT~cNL 8GP.CNL 47.475 CGR.CNL NPES.CNL ~.3~6 ~TE~.CNL t.G~ NGT 42.278 THO[~.NGT wJ~tC:~GT 152.778 9-~AR-!.993 0Or08 li.687 XDER,PHS 2.1!3 DRNO.bDT 0.015 L$,LDT 155.O00 SSi.BDT 1308.000 S1RH,b~T 9.023 SGR.LDT 74.750 ~RES.~DT 46.204 TNRA.c~L 524.553 CNTC.C~5 51.435 CALI.CNB 74.750 HTE,.C.5 7.~1 POT~.NGT 116. 3 W3NG.~GT 2395.000 MTE~.NGT 374.250 6.047 IL,~.DTE 6.531 'IMPH.DTE 0.000 CIDP.DTE 3.717 IIR~.DTE 2205.000 MTE~.DTE 6 4 IDER.PHS 2:~f6 DR~O..LDT 0 ~1 bS.BDT 145~. 5 $SI,bDT 1~O7 ~00 SI~H,LDT 4.37'729 CNTC.CNb 63:684 CABI.CNL 3 I POTA,NGT 15~,i88 W3HG.NGT 2205.000 ~TE~.NGT 335,250 0.000 CIDP,DTE 4 750 II~.DTE 2410i000 ~TEM.DTE 14 937 IDER.PHS 2.030 D~HO,LDT 0,03~ LS.5DT 204.625 SSi,BDT 1307.000 S1RH,LDT 12.313 SGR.5DT 73.938 ~RES,LDT 39 5!7 TNR~.CNL 584 458 CHTC.C 5 4J.~57 CALI.CNL 73,938 HTEN.CNL 6 621 POTA.MGT 61 966 W3NG. GT 1!.765 -0.006 478.750 210,500 2,141 70.778 1.353 3.730 2040.~14 9.023 374.~50 ~.28! 28.971 74.750 1950.000 1950,.000 153,000 -991.000 74.063 5,331 0.002 480,750 2 tO5 9~:240 1,350 3,834 1.695.837 10,055 335 25O 37.393 74.063 1950"000 1950.000 66.938 -991:500 73.938 15.12.4 -0002 216.750 2.041. 47.475 1,346 3.398 2235.~36 12.3t3 389.250 1.058 28.846 IDVP~. PEF. L!t. 882. C~. ~TEN. NPOR. CFTC. TFNS. SGR. LIRAN. W4MG. Y~ES. PHS bDT bDT LD~ LDT LDT LOT CNL CNL Ca~L NGT NGT VGT NGT IL, D.DTE CI~P.DTE 8GR.DTE gRE$.OTE IDV~.PH8 PEF.LDT LU.LDT SS2.LDT LSRH.LDT CGR.bDT HTE~.LDT NPO~.CNL CFTC URAN.NGT w4MG,~GT ~E~.~G? ILD. IFRE. CI~P. PEF. LSRN. CG~. HTEN. NPOR. CFTC. T~NS. SUP. [JRAN. W4NG. DTE DTE DTE DTE DTE PHS bDT bDT bDT BDT LDT LOT NGT K~GT NGT 11.772 2.354 44].750 305.250 2.117 51.435 374.250 46.755 546.288 ~395.000 70.254 2.864 11.9~8 1.353 7.039 20.000 -960.000 91.240 1.350 4.688 2.537 44.3.750 09.5oo 2.113 ~3.684 335.250 46.427 449.509 2205.000 86.698 2.261 10.~84 t,350 14.461 2O.0OO -991.500 47.475 1.346 15.21.4 2.1.86 519.500 311,000 2.031 41.157 389,250 38.223 647,022 2410.000 49,9~5 0.905 5,3a2 Tape Veri.f. tcation I, istlnO :hlumbefqer Alaska Computing Center wS~G. ~g? 9. 615 -TENS.NGT C,~. NG? 19~6.000 HTFN.~IGT DFPT. 3400.000 SFI,U.DTE SP.DTE -58.219 IDmM.DTE IDO~.DTE 0.000 IMOF.DTE !IRn. DTE 7].938 IIXD.DTE CGD.DTE 35.334 TEN$.DTE HTE~.DT~ ~33.750 IDPH.PHS DPHT.LDT 34.220 RHOB.LDT OLS.LDT -0,014 O$$.LDT bb. LDT ~70.2~0 LITH DDT [,~HV.LD? !245.000 SSHV:bDT I,!IRN.SD? 2.092 CALI.LDT TFN$.LDT 2~75.000 ~TE~.LDT NPH~.CHL 40.043 TNPH.CNL ~¢NT.CNL 2096.976 RCFT.CNb SG~ CNL 50.959 CG~.CN~ M~E$~CN[, '~.327 MTEM.CNb CGR.NGT 43.066 THOR.NGT w~N~.~GT !50.480 W2NG.NGT wSNG.NGT 4.269 ?EN$.MGT C$.~GT 1926.000 HTEN.NGT DF:PT. 3300.000 SFLU.DTE $~.DTE -72.438 ZDP~, DTE IDQW.DTE 0,000 I~O' :DT~r I?~D.DTE 84.063 IIXD.DTE CG~.DTE ~.004 TENS.DTE HT~N.DTW 3n3.o00 I~PH PHS O[.,~.LDT -0.002 O$S.bgT Lt,.LD? 277.250 blTH.LDT I..,~HV.LDT 1247.000 S$~V.LOT LI!Pn. LDT 2.090 CALI.LDT T~NS.LD~ 2300.000 ~TEM.LDT NP~?.CNL 5~.7~3 TNP~.C~L R~N~.C~[., t73~.677 ~CFT.CNL SGD.CNL 66.~g C~R.CNL ~ES.CNL 1.327 ~TEM.CNL CGD.~CT 47.691 THOR.~GT W~N~.NGT 2~0.695 W~NG.N~T wSNC.NGT 6.4!7 TEN$.NGT CS.WGT ~9~4.000 HTEN.NGT /)EpT 3222 000 SFt:J. DTE IOO~.DTE 0.000 I~OF.DTE ITRD,DTE 63,219 IIXD,DTE CG~.DTF 20.128 TENS.DTE HmEN.~Tw 391.000 IDPH. PHS DPNT .I,DT 52.754 RHOB. [,PT O[,S. LDT h. 103 USS. LDT b~,.LDT 129.125 LITH.LDT LSHV.LDT t247.000 SSNV.LDT 9-MAR-1993 09:08 2410.000 389.250 5.969 ILM.DTE 12.39~ IMPH..DTE 0.000 CIDP.DTE 4.977 IIRM.DTE 2275.000 ~TE~.DTE 12,412 IDE~.PH$ 2.085 D~O.hDT 0 018 LS.LDT 55 ' 34 CNTC:CNL 35.334 CASI.CN5 74.7so 4.~22 POTA.N~T 7 .ooo 333.750 5.71g ILM.DTE 10.977 IMPH.DTE 0.000 CIDP.DTE 6.961 IIRM.DTE 2300.000 MT~.DTE 10 986 IDER.Pi{$ 2:092 DRHO.LDT 0.027 L,S.hDT 16~.250 S$1,LDT 1310.000 S1RH.LDT 9.656 SGR.LDT 73.938 ~RE$.LDT 49.5~9 TNRA.CNL 395.076 CNTC.CNL 48.004 CASI.CNL 73 938 NTEN CNL 6i626 PoTA:NGT 1OS 882 W3NG.NGT 2~00 000 ~TE~.NGT 383:000 ' 688 IL~.DTE o ooo - oiooo ooo 14'980 !D~R,PHS. 1,780 DRHO,LDT -O.X04 SS,bDT 26,~97 $$1,LDT ~]10.000 S~RHoLDT 73.93g 1950.000 1950.000 80.625 -991.000 74.750 12.i75 ~0.O09 5 2.750 209.625 2.131 5O.959 1.327 3.571 2109.389 3 .750 ~.719 41.622 74.750 1950.000 1950.000 91.063 -99i 000 7:938 10 779 0:0O9 510.750 220.750 2.047 66.21g 1.327 4.114 1707.906 9.656 383.000 1.400 23.529 73.938 1950.000 1950.000 66.~75 -239.625 73.375 14.873 i0.691 2 6.750 7.063 3.949 ~WMS.NGT ILD.DTE IFRE.DTE CI~P.DTE SGR,DTE MRE$.DTE IDVR,PH$ PEP.bDT bU.bDT SS2.LDT LSRH.LDT CG~.b~T HTEN.LDT NPOR.CNL CFTC.CNL TENS.CNL SGR.NGT [IRAN.NGT W4NG.NGT ~RES.NGT ILD,DTE IFRE,DTE CIMP,DTE SGR,DTE. MRES.DT~ IDVR,PHS PEF.LDT LtJ.I, DT SS2.LDT LS~H.LDT CG~.bDT HTE~ LDT CF~'C.CNL SGD.NGT URAN.NGT W4NG.NGT ~ES.NGT ILD.DTE IFRE.DTE ClgP.DTE SGR.DTE MRES.DTE IDVR,PHS PEF.LDT LU.LDT SS2.LDT LS~H.LDT PAGE: 17 1,346 11.992 20.O00 -991.000 50.950 1.327 !1.882 2,205 464.750 304.000 2.094 35.334 333.750 39.605 609.097 2275000 51:042 i.071 5.336 ~.327 10.602 20.000 -996.000 66.219 1.327 10.542 2.~59 467.000 3~6.750 2.082 48,004 383,000 4g,772 431,190 2300,000 67.758 2.497 6.417 ~.327 14.438 20,000 -252.750 ~6,239 1.34~ 14.615 P2.969 235.250 127.188 2.469 IS q'aoe Veri. fication Listino :Mlbmbef0er Alaska Computln0 Center i,'.'qu, t, DT 2.5?5 CALI.LDT T~'~,{,~.. L DT 2260.000 ~4TEM.bDT ~°UT.CNL 51 .9~5 TNpH.CNL ~C~,~.CNI, ~ 369.21 5 PCFT.CNb SGm.CNL 26.239 CGR.CVb ~PES C~'L 1.34~ ~TM~,~ CNb CCR.N~T -99g.250 TgOR,NGT ~I~.MGT -999.250 W2NG.NGT W~MG.MGT -999.250 ~ENS.NGT C,q. WGT -909. 250 HTEU. N~T ** EMD O? DATA 9-MAR-).gg3 OO:OR A.938 SGR.LOT -999. 0 POT~. ~GT -~9.250 W3NG.~GT -. 9.250 ~TEq. NGT -999.~50 26.~3g 1.348 4.015 1312.468 8.938 381.000 -999.750 -999.250 -999.250 CGR.LDT HTEM.LDT NPOR.CML CFTC.CNL TENS.CML SG~.NGT URAW.NGT W4MG.MGT ~RE$.~GT PAGE: ~0.128 49.620 3~.017 2260.000 -999.250 -999.250 -999.250 -999,250 **** FILE TRAI{,EP, **** F[[,F lqA~?7 .' EDIT .001 SFPVIC~ : FLOC VER~!O~) ~ OOlA06 D~T~I : 90111/!4 ~X ~EC SIZE : qlO2 F{LF TYPE : LO **** TAP~ TRAIt, ER **** SERVICE NA~.,!F : EgIT DATF : 90/1!/!4 O~IC!N ; PL!C T~.P~ NA~E i 74!59 COMTI~UATION ~ : !. P~EV!OUS T~PE : Cn'4~EWT : CONOCO, SCHRAI)ER **** ~MEI, TRAIT~ER **** SFRV~CE ~4E : EDIT D~T~ : 90/1~/~4 OPIC!U : FL, lC REEL NA~E : 74).59 CnqUl/.;WT : CUMOCO, SCHRADER BLUPF,~I[,NE POINT UNIT BLUF?,MI'bN~ pOINT UNIT 50-029-22065 50-029-22065