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166-003
1 Gluyas, Gavin R (OGC) From:McLellan, Bryan J (OGC) Sent:Thursday, November 6, 2025 12:36 PM To:Casey Morse Subject:RE: [EXTERNAL] RE: CCL/GR log on Ba-6 Casey, Apologies again for the late reply. I know this work has already been completed, but for the record, yes, I was comfortable proceeding with the tag without the inspector present because we have the correlation logs before and after pumping cement to verify TOC. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Monday, August 25, 2025 10:49 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Brad Whitten - (C) <Brad.Whitten@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com> Subject: RE: [EXTERNAL] RE: CCL/GR log on Ba-6 Bryan, We ran through witnessed MIT’s and tags the past two days on the wells from this year’s P&A program. The Ba-06 (MGS St 17595 06, PTD 166-003) well conditions of approval in Sundry 325-262 also ask for GR/CCL to verify the top of cement, and we did not have an available eline crew the past few days to perform that work while the AOGCC inspector was onboard. We have crew available for this afternoon to perform the tag, but we did not place the required 48-hour advance notification for opportunity to witness. Are you comfortable with us proceeding this afternoon with the eline tag of TOC on Ba-06 without witness? We have the jewelry log from last week to correlate back to for reference. This would be easiest for us, since we still have the platform fully staƯed right now. Please reach out to me if you have any questions or concerns on this. Thank you, Casey Morse Operations Engineer Cook Inlet OƯshore 2 Hilcorp Alaska, LLC (907) 777-8322 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, August 20, 2025 8:59 AM To: Brad Whitten - (C) <Brad.Whitten@hilcorp.com>; Casey Morse <Casey.Morse@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com> Subject: RE: [EXTERNAL] RE: CCL/GR log on Ba-6 Brad, Casey, So I’m getting tag at 5757’ + 6’ = 5763’ MD, which is acceptable. Hilcorp has approval to proceed with next step in the sundry. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Brad Whitten - (C) <Brad.Whitten@hilcorp.com> Sent: Wednesday, August 20, 2025 8:55 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Casey Morse <Casey.Morse@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com> Subject: RE: [EXTERNAL] RE: CCL/GR log on Ba-6 Bryan, It was 6’ from CCL to end of tool string. Regards, Brad Whitten Cell (907)350-5202 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, August 20, 2025 8:52 AM To: Casey Morse <Casey.Morse@hilcorp.com>; Brad Whitten - (C) <Brad.Whitten@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com> Subject: [EXTERNAL] RE: CCL/GR log on Ba-6 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 3 Casey, Looks like you got line tension back at 5767’ MD, minus 10’ correction is 5757’ MD. It looks like the depth was zeroed at the CCL, so how much length between CCL and end of toolstring? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Wednesday, August 20, 2025 6:03 AM To: Brad Whitten - (C) <Brad.Whitten@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: CCL/GR log on Ba-6 All, Comparing this log to the open-hole gamma and the gravel pack tally, I believe the depths on this recent log would need to be shifted up 10’ to align with the original KB values. This should put our tag depth right at the CIBP ~5,770’. I put some annotations on an excerpt from the bottom portion of the log shown below. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 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. 4 Casey Morse Operations Engineer Cook Inlet OƯshore Hilcorp Alaska, LLC (907) 777-8322 5 From: Brad Whitten - (C) <brad.whitten@hilcorp.com> Sent: Tuesday, August 19, 2025 8:02 PM To: Casey Morse <Casey.Morse@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: CCL/GR log on Ba-6 Regards, Brad Whitten Cell (907)350-5202 From: Brad Whitten - (C) Sent: Tuesday, August 19, 2025 7:53 PM To: Casey Morse <Casey.Morse@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: CCL/GR log on Ba-6 Baker Platform Sundry # 325-262 MGS ST 17595 06 Conditions of Approval. Here is the CCL/GR log after cleaning out to CIBP on Ba-06. Jim Regg waived witness of tag. Tagged at 5748’. Regards, Brad Whitten Cell (907)350-5202 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, 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 onward transmission, 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 or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, 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 onward transmission, 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 or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this 6 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 onward transmission, 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. 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 From:McLellan, Bryan J (OGC) To:Casey Morse Cc:Dan Marlowe; Juanita Lovett Subject:RE: MGS St 17595-06 PTD 166-003_Sundry_325-262 Date:Thursday, November 6, 2025 12:30:00 PM Casey, Apologies for the delay in responding. This one was buried in my inbox. As you stated, COA #4b in the sundry required TOC <10’ below the tubing tail because there was only 50’ between top of open hole gravel pack SC-1 packer and tubing tail, compared to the 100’ of cement required by 20 AAC 25.112(c)(1)(C). The TOC tag is ~34’ below the tubing tail, leaving approximately 16’ of cement plug above the top of the SC-1 Gravel pack screen packer. The annulus between the screen and 7” casing is likely not full of cement, so there is a flow path from top perf through the gravel pack to the bottom of the SC-1 packer, leaving effectively only 16’ of cement above the perfs. The passing CMIT LSxSSxIA is evidence that the cement plug is sufficient to put this well into suspension status, however, additional cement may be required between existing TOC and tubing tail when the final P&A is performed on this well, unless a variance is granted in the future P&A sundry application. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Casey Morse <casey.morse@hilcorp.com> Sent: Tuesday, August 26, 2025 10:44 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: MGS St 17595-06 PTD 166-003_Sundry_325-262 is safe. Bryan, The sundry 325-262 for the Baker 06 (MGS St 17595-06) well includes condition of approval 4.b. that requires TOC to be within 10’ of the tubing tail. This is described as a condition of approval for a variance to 20 AAC 25.112(c)(1)(C) “to isolate the MGS A sands below a cement plug, placed by displacement method, of less than 100’ MD. There is only 50’ of space between top of gravel pack packer and tubing tail.” Condition of approval 5 also states that we must provide 48 hours’ notice for AOGCC opportunity to witness cement tag. Below are some comments on these conditions of approval: Attached is the email notification made for opportunity to witness the cement tag. Notification was placed on 8/21 with a planned date of operation on 8/25. Our goal was to perform the tag while the inspector was on the facility. An inspector was onboard 8/23 and 8/24. A witnessed CMIT was conducted on 8/24 with passing results; however, eline crews were unavailable during those days. The eline crew became available on 8/25, so we proceeded to conduct the tag operation without the inspector present. I previously had emailed you about this because I misunderstood the specifics of our prior notification, so I just wanted to clear that up. I attached our daily reports for this well for your reference also. 20 AAC 25.112(c)(1)(C) says “a cement plug placed from the well's plugged-back total depth to 100 feet above the top of the perforated interval.” The top perforation in the MGS A sand is at 5,300’. The top gravel pack screen is at 5,282’, and the gravel pack packer is set at 5,123’ as referenced in the sundry conditions of approval. Regardless, it is my understanding that the top of the perforated interval as described in the State rules is 5,300’. The cement tag (also attached) placed top of cement at 5,104’ which would be 196’ above the top of the perforated interval. This complies with the language of 20 AAC 25.112(c)(1)(C). Based on this information, I believe we have achieved the intent of the specific sundry and the rules regarding reservoir abandonment. Could we close this sundry with the well as is? Thank you, Casey Morse Operations Engineer Cook Inlet Offshore Hilcorp Alaska, LLC (907) 777-8322 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Well Name: MGS ST 17595 06 API #:50733100730000 Field:Middle Ground Shoal Start Date:5/22/2024 Permit #:165038 Sundry #:325-262 End Date: 8/19/2025 8/20/2025 8/24/2025 8/25/2025 Activity Report CMIT LSxSSxIA to 1500psi. IniƟal 1730psi, 15 minutes 1711psi, 30 minutes 1704psi. 19 psi drop in first 15 minutes, 7psi drop in second 15 minutes. 1bbl in, 1bbl out. Was not able to get CCL/GR tag and log due to e-line being unavailable. Witnessed by AOGCC rep Guy Cook E-line crew arrive on Platform. PTW, PJSM. R/u e-line on Ba-6 LS. RIH with GR/CCL, tagging TOC at 5104, logging up to 4800'. Send log into OE to confirm correlation. R/d e-line, crew departs platform. Test BOPE 250psi low, 2500psi high, No failures. BOP test witness waived by AOGCC's Jim Regg. M/u wash nozzle BHA. check well, LS static. RIH with wash nozzle down LS, started taking weight at 5426' CTM. Circulation at 1.5bpm, 2900psi, washing down to hard tag at 5753' CTM (CIBP) with 4k down, wt not washing off. Seeing fine black solid in returns while washing down. P/u and wash to WLEG and back down to CIBP. POOH while circulating. R/u E-line on Ba-6 LS. RIH w/ CCL/GR logging tool. Tag CIBP at correlated depth 5763' KB, log up to 4800' POOH. R/d e-line. Send log to AOGCC for approval to proceed with cement job. AOGCC's Jim Regg waived witness of tag. M/u cement BHA. Stab Lubricator on to the well. PT 250/2500 psi, good test. RIH to 5000'. got approval to proceed with cement operaƟons from AOGCC. RIH tagging at 5750' CTM. P/u to 5740'. 1. Break circulaƟon. Shut in and PT cement lines to 3000psi. 2. Open up and lead with 5bbls FIW at 1 bpm, 2100psi. 3. Pump 10 bbls 14ppg cement starƟng at 0.8bpm, 1600psi, FCP 3000psi . 4. Chase with 5.5bbls 9.8ppg brine starƟng at 0.8bpm, 2730psi, dropping to 1750psi. Cement at nozzle. 5. Let 0.5 bbls cement get around coil then pull at 56 fpm laying cement from CIBP to WLEG (5074'), CIP 10:25. 6. Pull into tubing tail and pump addiƟonal 4 bbls. 7. Shut down, close in reel and pump down IA up LS at 2.5 bpm, 600psi for 2 BU. POOH while circulaƟng at minimum pump rate. R/d coil Package and load on boat for Tyonek. Daily Operations: Page 1 of 16 1 Gluyas, Gavin R (OGC) From:Casey Morse <Casey.Morse@hilcorp.com> Sent:Wednesday, August 20, 2025 6:03 AM To:Brad Whitten - (C) Cc:Dan Marlowe; McLellan, Bryan J (OGC) Subject:RE: CCL/GR log on Ba-6 All, Comparing this log to the open-hole gamma and the gravel pack tally, I believe the depths on this recent log would need to be shifted up 10’ to align with the original KB values. This should put our tag depth right at the CIBP ~5,770’. I put some annotations on an excerpt from the bottom portion of the log shown below. 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. 2 Casey Morse Operations Engineer Cook Inlet OƯshore Hilcorp Alaska, LLC (907) 777-8322 3 From: Brad Whitten - (C) <brad.whitten@hilcorp.com> Sent: Tuesday, August 19, 2025 8:02 PM To: Casey Morse <Casey.Morse@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: CCL/GR log on Ba-6 Regards, Brad Whitten Cell (907)350-5202 From: Brad Whitten - (C) Sent: Tuesday, August 19, 2025 7:53 PM To: Casey Morse <Casey.Morse@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: CCL/GR log on Ba-6 Baker Platform Sundry # 325-262 MGS ST 17595 06 Conditions of Approval. Here is the CCL/GR log after cleaning out to CIBP on Ba-06. Jim Regg waived witness of tag. Tagged at 5748’. Regards, Brad Whitten Cell (907)350-5202 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, 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 onward transmission, 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. 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: 09/12/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250912 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 8/28/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/19/2025 AK E-LINE CIBP BRU 224-34T 50283202050000 225044 8/17/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/22/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/27/2025 AK E-LINE Perf BRU 241-23 50283201910000 223061 8/20/2025 AK E-LINE Plug/Perf GP 11-13RD 50733200260100 191133 8/29/2025 AK E-LINE Perf KALOTSA 6 50133206850000 219114 8/14/2025 AK E-LINE PPROF MGS ST 17595 06 50733100730000 166003 8/19/2025 AK E-LINE Drift MGS ST 17595 06 50733100730000 166003 8/26/2025 AK E-LINE Drift MGS ST 17595 11 50733200130000 167017 8/17/2025 AK E-LINE CBL MGS ST 17595 20 50733203770000 185135 8/21/2025 AK E-LINE CBL MPI 1-61 50029225200000 194142 8/19/2025 AK E-LINE Patch NCIU A-21A 50883201990100 225075 8/23/2025 AK E-LINE Perf END 1-23 50029225100000 194128 7/14/2025 HALLIBURTON MFC40 END 2-74 50029237850000 224024 7/12/2025 HALLIBURTON MFC40 END 3-07A 50029219110100 198147 7/13/2005 HALLIBURTON COILFLAG END 3-15 50029217510000 187094 7/15/2025 HALLIBURTON MFC24 NS-20 50029231180000 202188 9/2/2025 HALLIBURTON COILFLAG PBU 01-13A 50029202700100 225052 8/18/2025 HALLIBURTON RBT-COILFLAG PBU 07-24A 50029209450100 225045 8/3/2025 HALLIBURTON RBT-COILFLAG PBU C-34C 50029217850300 225068 8/25/2025 HALLIBURTON RBT SD-07 50133205940000 211050 8/14/2025 HALLIBURTON TMD3D ODSK-14 50703206100000 209155 9/8/2025 READ CaliperSurvey Please include current contact information if different from above. T40874 T40875 T40875 T40875 T40875 T40876 T40877 T40878 T40879 T40879 T40880 T40881 T40882 T40883 T40884 T40885 T40886 T40887 T40888 T40889 T40890 T40891 T40892 T40893 MGS ST 17595 06 50733100730000 166003 8/19/2025 AK E-LINE Drift MGS ST 17595 06 50733100730000 166003 8/26/2025 AK E-LINE Drift Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.12 14:33:03 -08'00' From:McLellan, Bryan J (OGC) To:Brad Whitten - (C); Casey Morse Cc:Dan Marlowe Subject:RE: [EXTERNAL] RE: CCL/GR log on Ba-6 Date:Wednesday, August 20, 2025 8:59:00 AM Attachments:image002.png Brad, Casey, So I’m getting tag at 5757’ + 6’ = 5763’ MD, which is acceptable. Hilcorp has approval to proceed with next step in the sundry. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Brad Whitten - (C) <Brad.Whitten@hilcorp.com> Sent: Wednesday, August 20, 2025 8:55 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Casey Morse <Casey.Morse@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com> Subject: RE: [EXTERNAL] RE: CCL/GR log on Ba-6 Bryan, It was 6’ from CCL to end of tool string. Regards, Brad Whitten Cell (907)350-5202 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, August 20, 2025 8:52 AM To: Casey Morse <Casey.Morse@hilcorp.com>; Brad Whitten - (C) <Brad.Whitten@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com> Subject: [EXTERNAL] RE: CCL/GR log on Ba-6 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. Casey, Looks like you got line tension back at 5767’ MD, minus 10’ correction is 5757’ MD. It looks like the depth was zeroed at the CCL, so how much length between CCL and end of toolstring? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Wednesday, August 20, 2025 6:03 AM To: Brad Whitten - (C) <Brad.Whitten@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: CCL/GR log on Ba-6 All, Comparing this log to the open-hole gamma and the gravel pack tally, I believe the depths on this recent log would need to be shifted up 10’ to align with the original KB values. This should put our tag depth right at the CIBP ~5,770’. I put some annotations on an excerpt from the bottom portion of the log shown below. Casey Morse Operations Engineer Cook Inlet Offshore Hilcorp Alaska, LLC (907) 777-8322 From: Brad Whitten - (C) <brad.whitten@hilcorp.com> Sent: Tuesday, August 19, 2025 8:02 PM To: Casey Morse <Casey.Morse@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: CCL/GR log on Ba-6 Regards, Brad Whitten Cell (907)350-5202 From: Brad Whitten - (C) Sent: Tuesday, August 19, 2025 7:53 PM To: Casey Morse <Casey.Morse@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: CCL/GR log on Ba-6 Baker Platform Sundry # 325-262 MGS ST 17595 06 Conditions of Approval. Here is the CCL/GR log after cleaning out to CIBP on Ba-06. Jim Regg waived witness of tag. Tagged at 5748’. Regards, Brad Whitten Cell (907)350-5202 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 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): 7,400 N/A Casing Collapse Structural Conductor 520psi Surface 1,130psi Intermediate Production 3,270psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Casey Morse Contact Email:Casey.Morse@hilcorp.com Contact Phone:(907) 777-8322 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: CTCO, Cementing Middle Ground Shoal Middle Ground Shoal Oil N/A 7,396 5,770 5,768 2,240 5,770 & 6,750 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): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017595 166-003 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-10073-00-00 Hilcorp Alaska, LLC MGS ST 17595 06 Length Size Proposed Pools: 450 450 4.6# N-80 (SS) & 6.4# N-80 (LS) TVD Burst 5,041 (SS) & 5,074 (LS) 4,360psi MD 1,530psi 2,730psi 612 2,010 612 2,010 450 36" 20" 13-3/8" 612 2,010 5,300 - 5,720 7,397 5,298 - 5,718 7,3937" N/A 6/1/2025 2-3/8" (SS) & 2-7/8" (LS) SC-L1 Packer / Sump Packer & N/A 5,123 (MD) 5,121 (TVD) / 5,745 (MD) 5,743 (TVD) & N/A 7,397 Perforation Depth MD (ft): No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.04.25 15:32:14 - 08'00' Dan Marlowe (1267) 325-262 By Grace Christianson at 3:42 pm, Apr 25, 2025 X BJM 5/27/25 DSR-4/29/25 10-407 * BOPE test to 2500 psi. 48 hour notice to AOGCC.May 31, 2030 See additional conditions of approval page attached behind this form. A.Dewhurst 23MAY25*&: 5/28/2025Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.28 14:42:52 -08'00' RBDMS JSB 052925 MGS St 17595-6 (PTD 166-003) Suspension Sundry 325-262 Conditions of Approval 1. BOPE test to 2500 psi. 2. Variance to 20 AAC 25.112(c)(1)(C) is approved to accept the existing CIBP at 6750’ with 5 sx of cement to be acceptable for isolating the MGS BCD from the MGS EFG. The cement height is less than what the regulation calls for, however the minor æôIJôƱťϙĺċ ťĺŕŕĖIJČϙĺƯϙťēôϙèôıôIJťϙťĺϙıôôťϙŘôČŪīÍťĺŘƅϙŘôŗŪĖŘôıôIJťϙĖŜϙIJĺťϙſĺŘťēϙťēôϙ operational complexity and risk. 3. Variance to 20 AAC 25.112(c)(1)(C) is conditionally approved to isolate MGS BC&D sands below a cement plug, placed by displacement method, of less than 100’ MD. Conditions of approval: a. If CT tools cannot pass the 1.90" ID restriction in the gravel pack screen completion (O-Ring Seal Sub), the ID must be milled out to allow CT tools to pass so cement plug can be placed by displacement method from the top of the bridge plug at 5770’ to the 4-1/2” sump packer at 5749’ MD. This will be a 21-foot cement plug to isolate the MGS BCD sands. b. ēôϙèīôÍIJĺŪťϙîôŕťēϙıŪŜťϙæôϙŽôŘĖƱôîϙſĖťēϙ [ϯ@ϙĤôſôīŘƅϙīĺČϙŕŘĖĺŘϙťĺϙŕīÍèĖIJČϙ cement to ensure the maximum length cement plug above the CIBP at 5770’ MD. [ĺČϙťĺϙæôϙŘŪIJϙċŘĺıϙ͔͖͖͏ЍϙıîϙŪŕϙto at least 4900’ md. Provide 48 hrs notice for opportunity to witness plug tag. Send log to AOGCC petroleum engineer and obtain approval before placing cement. c. Due to the small volume of cemôIJťϙŘôŗŪĖŘôîϙťĺϙƱīīϙťēĖŜϙŜŕÍèôϙæôīĺſϙťēôϙ screens (<1 bbl), a combination plug will be acceptable, whereby the plug isolating the BC&D sands can be combined with the plug isolating the A sand and laid in by the displacement method as one continuous plug. 4. Another Variance to 20 AAC 25.112(c)(1)(C) is conditionally approved to isolate MGS A sands below a cement plug, placed by displacement method, of less than 100’ MD. There is only 50’ of space between top of gravel pack packer and tubing tail. Conditions of approval: a. [ÍƅϙèôıôIJťϙċŘĺıϙťĺŕϙĺċϙ IϙÍťϙ͔͖͖͏ДϙŪŕϙĖIJťĺϙťŪæĖIJČϙťÍĖīϙÍťϙ͔͏͖͒ДϙıîϙťĺϙôIJŜŪŘôϙ maximum fullbore cement coverage inside 7" casing above and below screens. Reverse circulate down IA and up tubing long string as necessary if maintaining ÍϙƲĺw path from Tbg to IA after cementing is desired. This will maximize plug length between top of screens and tubing tail. Alternative èôıôIJťϙŕŘĺèôîŪŘôŜϙſĖīīϙæôϙèĺIJŜĖîôŘôîϙŪŕĺIJϙŘôŗŪôŜťϟ b. «ôŘĖċƅϙi ϙŘôīÍťĖŽôϙťĺϙťŪæĖIJČϙťÍĖīϙæƅϙťÍČČĖIJČϙſĖťēϙ@ϯ [ϙÍIJîϙīĺČČĖIJČϙacross ťŪæĖIJČϙĤôſôīŘƅϙťĺϙ͓͘͏͏Ѝϙıîϟ TOC should be <10’ below end of tubing. 5. Provide 48 hrs notice for AOGCC opportunity to witness cement tag. Oil Zone P&A Program Well: Ba-06 Well Name:Ba-06 API Number:50-733-10073-00-00 Current Status:Shut-In Producer Rig:SL, CT, cement Regulatory Contact:Juanita Lovett First Call Engineer:Casey Morse 907-777-8322 603-205-3780 (M) Second Call Engineer:Eric Dickerman 907-564-4061 Current Bottom Hole Pressure (est):2576 psi @ 5709’ TVD (SBHPS from 2007, EMW: 9.3 ppg) Max. Potential Surface Pressure:2240 psi Gas Column Gradient (0.1 psi/ft) Current Pressures (LS/SS/IA/OA/OOA):vac/vac/vac/60/40 psi History Drilled and completed in 1966 and put on production in 1966 as an oil producer. A number of workovers were performed including fracs, plug-backs, perf adds, squeezes, and recompletes. The well produced until the platform was SI in 2003. The well was then circulated with 9.8 ppg brine and a 38 bbl pill of LCM was pumped to plug off the perforations. The LS, SS, and IA were freeze-protected with diesel. 20” Casing set @ 612’ MD. Cement: Class G Neat, Bulk, 742 Sacks plus 450 Sacks w/ 2% CaCl2. Top-jobbed the 20” x 36” with 275 sxs plus 2% CaCl2. 13-3/8” Casing set @ 2010’ MD. Cement: 1200 Sacks class A w/ 6% Gel and 100 sacks class A w/ 2% CaCl2. Ran 2”, 1-1/4” & 1” pipe down outside of 13-3/8” casing to 710’, Cemented w/ 450 sacks Class A w/ 2% CaCl2. 7” Casing set @ 7397’ MD. Cement: 960 sacks Class G w/ 1% TIC and 940 sacks Class G Neat. CBL indicated TOC @ 2900’ MD. On file with T# 34803. Current Status Shut-in. LS, SS, and IA were loaded with 9.8 ppg brine. Pre-P&A Diagnostics Performed 1. Initial pressures (SS/LS/IA/OA/OOA): 3psi / 25psi / 110psi / 60psi / 80psi 2. Circulate 9.8 ppg brine: a. Pump down LS up IA @ 400psi / 2 BPM b. Pump down IA up LS @ 600psi / 3 BPM c. Pump down LS up SS @ 750psi / 2 BPM d. Pump down SS up LS @ 750psi / 2 BPM 3. Injection into perfs: started pumping 9.8 ppg brine at 1 bpm, caught pressure after 10 bbls. After 16.5 bbps, pressure stabilized at 1225 psi. Increased pump rate to 1.5 bpm @ 1450 psi, pumped additional 10 bbls at stable rate / pressure. Total of 30 bbls injected. 4. RU slickline. RIH w/ 2.3” GR on LS to 5030 SLM (tag Kobe cavity). RIH w/ 2-7/8” D&D Holefinder, set at 5000’. Pressure up LS to 500 psi with 0.45 bbls. Hold pressure for 5 minutes – good test. 5. Check pressures one month later (SS/LS/IA/OA/OOA): vac / vac / vac / 60psi / 40psi Oil Zone P&A Program Well: Ba-06 6. RU slickline on SS. RIH w/ ponytail pumping 9.8 ppg brine down SS up IA @ 0.5 bpm / 125 psi. At 5010’ SLM, pum pressure rose to 800 psi. Gain overpull. Shut down pump and lose overpull. Confirm flow through Kobe in SS. 7. RU slickline on LS. a. RIH w/ 2.0” gauge ring, tag at 5430’ SLM. b. RIH w/ ponytail while pumping 0.7 bpm. Continue in hole to 5440’ and set down. Slight overpull when picking up. Made several passes from 5080’ to 5440’ with no repeatable changes in weight or pump pressure. c. RIH w/ 2.22” blind box to 5300 SLM. Pull up from 5300 to 5120’ SLM at full speed while injecting at 0.7 bpm / 1900 psi. Make 3 passes, pump pressure spiked 100psi on each pass. POOH. Objective Plug and abandon the Middle Ground Shoal Oil Pool perforations and perform MIT on casing. This well will be evaluated for future sidetrack potential or uphole gas recompletion. Hilcorp requests a variance to 20 AAC 25.112 (c) (1) (E). Hilcorp requests the existing mechanical plugs set at 6,750’ and 5,770’ be considered sufficient for abandonment of the perforated intervals beneath each respective plug. The bridge plug at 6,750’ was set in 1968 and topped with 5 sx cement. The bridge plug at 5,770’ was set in 1991 and has no cement placed on top. Since that time, a gravel pack was installed above the upper plug, and debris has accumulated within the gravel pack above the upper plug. The gravel pack was installed in two separate interventions utilizing an internal seal mechanism with a 1.90” inner diameter sealing mechanism at 5,733’. Coil tubing intervention to clean out the wellbore below this depth requires tools not currently available in the Cook Inlet Basin. Even with the correct coil tubing tools, drilling through the bridge plug at 5,770’ would be a high-risk operation with limited chance of success. Hilcorp requests the proposed P&A plug be placed with coil tubing via the displacement method. Hilcorp intends to perform a wellbore cleanout through the gravel pack to place the cement plug as deep as practical. Availability of coil tubing tools will dictate whether cleanout is feasible below the 1.90” restriction within the gravel pack. The proposed cement plug will be placed across all the open A zone perforations from the coil tubing cleanout depth to above the top of the MGS Oil Pool. Procedural steps Coil Tubing 1. MIRU Coiled Tubing and pressure control equipment 2. PT lubricator to 250 psi low / 2500 psi high 3. MU cleanout BHA and clean down to 5770’ (Baker N-1 bridge plug) or as deep as practical. Note: gravel pack has ID of 1.90” at 5,733’. a. Working fluid will be 9.8 ppg brine b. Take returns to surface up the CT x tubing annulus c. Taking returns to formation is also acceptable 4. MU cement nozzle BHA 5. RIH through end of tubing and into gravel pack to tag. PU off bottom ~10’ and confirm circulation. 6. Pump reservoir abandonment plug as follows: a.10 bbl 14 ppg cement, monitoring return volumes b. Displace cement out coil If CT tools cannot pass the 1.90" ID restriction, It must be milled out to allow CT tools to pass. -bjm Cement plug must be placed by displacement method between plug at 5770' and bottom of sump packer at 5749' MD and across all A-zone perforations. This variance is to allow <100' (21 feet of space is available for cement) of cement plug between the MGS A and MGS BCD. -bjm A second variance to 20 AAC 25.112(c)(1)(C) is required to place <100' of cement by displacement method on top of the plug above the top of the MGS A perfs. There are only 50' between tubing tail and top of the screended interval. Both variances are conditionally approved. See attached CoA's -bjm Consider pumping additional cement to account for some losses into gravel pack. -bjm -bjm 10 bbl 14 ppg cement Oil Zone P&A Program Well: Ba-06 c. Pull up into the tubing above cement top and ensure cement is circulated out of coil d. Estimated TOC ~5100’ 7. POH and RD coil Fullbore/Slickline 1. CMIT LSxSSxIA to 1500 psi (AOGCC Witnessed). 2. RU slickline to LS and tag TOC (AOGCC Witnessed). Bottomhole Pressures x Frac pressure: estimated at 0.9 – 1.1 psi/ft as per AIO 7. TVD of top perf: 5298’ x Full column of 9.8 ppg brine: 2700 psi o Frac pressure >2000 psi with 9.8 ppg brine in well x Full column of 14 ppg cement: 3860 psi o Frac pressure >900 psi surface pressure with full column of cement. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Coil Tubing BOP Diagram See attached conditions of approval. -bjm Desired cement top < 10' below tubing tail. See attached conditions of approval. -bjm Updated by: CDM 04/23/25 Middle Ground Shoal Well: Ba-06 (MGS ST 17595 #6) Last Completed: 10-28-1997 PTD: 166-003 API: 50-733-10073-00 SCHEMATIC Size Type Wt/ Grade/ Conn ID Top Btm Cement Sacks CMT Top 36” Structural 1.25” Wall 27.5 Surf 450 20” Conductor 94, H40, STC 19.124 Surf 612 1192 Surf 13-3/8” Surface 54.5, J55, STC 12.459 Surf 2010 0.8º1300 Surf 7” Surface 26, J55, LTC 6.276 0 2071 1900 2900 CBL 23, J55, LTC 6.366 2071 3022 23, J55, STC 6.366 3022 4825 26, J55, STC 6.276 4825 6388 26, J55, STC 6.276 6388 7397 Completion Long String 2-7/8 Prod Tubing 6.4, N80, BTC w/ SCC 2.441 30.72 5074 Short String 2-3/8 Prod Tubing 4.6, N80, BTC w/ SCC 1.995 30.72 5041 Completion Jewelry Detail # Depth Length ID OD Item Long String (Power Fluid) 30.72 7.063 CIW Hanger @ 30.72’ 31.40 .40 2.441 2.875 Pup Jt, 2-7/8” L-80 6.4# Butt 31.80 4984 2.441 2.875 2-7/8” 6.4# L-80 Butt w/ SCC Tubing 5015 .83 2.500 3.220 Crossover, 2-7/8” Butt B x 2-7/8” EU 8RND P 5016 10.10 2.441 2.875 Pup Jt, 2-7/8” 6.5# L-80 8rd w/ SCC 5026 14.40 2.250 5.626 Type A Single Parallel KOBE Cavity 2.5” 5040 .67 2.441 3.625 Crossover, 2-7/8 Butt P x 2-7/8 8rd B 5041 31.11 2.441 2.875 2-7/8 L-80 6.4# Butt Tubing 5073 .75 2.437 3.500 WLEG Short String (Production) 30.72 .68 7.063 CIW Dual Split Hanger 31.77 1.40 1.995 2.375 Pup Jt, 2-3/8” 4.6# L-80 Butt 33.17 6.10 1.995 2.375 Pup Jt, 2-3/8” 4.6# L-80 Butt SC 39.27 6.10 1.995 2.375 Pup Jt, 2-3/8” 4.6# L-80 Butt SC 45.37 4972 1.995 2.375 2-3/8 4.6# L-80 Butt Tubing 5017 .87 1.625 2.700 Crossover, 1-1/4 10rd P x 2-3/8 Butt B 5018 8.12 1.375 1.626 Pup Jt, 1-1/4 10rd 5026 14.40 5.625 Type A Single Parallel Cavity 2.5” * 06/2024 – Tag @ 5,430’ with 2.0” gauge ring. Work ponytail to 5,440’ SLM while pumping. * 10/2010 – Circ 9.8 ppg brine in LS, SS, and annulus. Pumped 38 bbls LCM pill. Has diesel cap. * 07/2005 – Slickline tagged 2.0” GR @ 5737’ (1.90” ID in gravel pack at 5733’) FISH None Perforation Data Doglegs 2.5 3500 5300 5720 A Open Gravel Pack 2.5 3600 4.0 7200 5782 6607 BCD Isolated by BP @ 5770’ 4.3 7310 7092 7131 D Isolated by BP & 5sx cmt @ 6750’ 4.3 7350 4.3 7400 PBTD =5770’ TD = 7396’ MAX HOLE ANGLE = 2.5 O @ 3500’ 36” RKB: MSL = 101’ Mudline= 203’ Water Depth= 102’ 7” 7397’ 5123’ SC-1 Packer 20” 612’’ 13-3/8” 2010’ 5745’ Sump Packer 5770’ Baker N-1 BP 6750’ CIBP w/ 5 sx cmt 2900’ TOC CBL 5421’ MGS Oil Top 5440’ Tagged Fill 4536 MGS Gas Base 7092.5’ - 7131.5’ Open Perfs 5300’ - 5720’ Open Perfs 5782’ - 6607’ Open Perfs 3-1/2” 9.2 # N-80 0.012 Wire Wrapped Baker Weld Screen Gravel Pack 20—40 Mesh Ottawa Sand 9.8 ppg Brine KB: MSL Mean Sea Level Mud Line Ba-06 Schematic 2025-04-23.docx3 Page 2 of 2 Gravel Pack Jewelry Detail Depth Length ID OD Item 5123 4.18 4.00 5.937 Baker Model SC-1L Gravel Pack Packer 70B4-40 5128 4.81 4.875 5.50 Upper Extension 5132 1.66 4.43 5.50 Sliding Sleeve 5134 1.49 4.00 5.562 Seal Bore 5136 21.8 4.50 5.00 Lower Extension 5157 0.25 2.99 5.00 Crossover Sub 5158 124.44 3.50 2.99 Blank Tubing 5282 451.33 2.99 4.11 3-1/2” 0.012 Gauge Bakerweld Screen 5733 0.58 1.90 4.25 O-Ring Seal Sub 5734 10.08 2.99 4.11 3-1/2” Bakerweld Lower Tell Tale Screen 0.012 Gauge 5744 0.84 2.375 4.625 Baker Snap Latch Seal Assy 80-32 5745 3.45 3.25 5.63 Baker Model D Sump Packer 84-32 Updated by: CDM 04/23/25 Middle Ground Shoal Well: Ba-06 (MGS ST 17595 #6) Last Completed: 10-28-1997 PTD: 166-003 API: 50-733-10073-00 PROPOSED SCHEMATIC Size Type Wt/ Grade/ Conn ID Top Btm Cement Sacks CMT Top 36” Structural 1.25” Wall 27.5 Surf 450 20” Conductor 94, H40, STC 19.124 Surf 612 1192 Surf 13-3/8” Surface 54.5, J55, STC 12.459 Surf 2010 0.8º1300 Surf 7” Surface 26, J55, LTC 6.276 0 2071 1900 2900 CBL 23, J55, LTC 6.366 2071 3022 23, J55, STC 6.366 3022 4825 26, J55, STC 6.276 4825 6388 26, J55, STC 6.276 6388 7397 Completion Long String 2-7/8 Prod Tubing 6.4, N80, BTC w/ SCC 2.441 30.72 5074 Short String 2-3/8 Prod Tubing 4.6, N80, BTC w/ SCC 1.995 30.72 5041 Completion Jewelry Detail # Depth Length ID OD Item Long String (Power Fluid) 30.72 7.063 CIW Hanger @ 30.72’ 31.40 .40 2.441 2.875 Pup Jt, 2-7/8” L-80 6.4# Butt 31.80 4984 2.441 2.875 2-7/8” 6.4# L-80 Butt w/ SCC Tubing 5015 .83 2.500 3.220 Crossover, 2-7/8” Butt B x 2-7/8” EU 8RND P 5016 10.10 2.441 2.875 Pup Jt, 2-7/8” 6.5# L-80 8rd w/ SCC 5026 14.40 2.250 5.626 Type A Single Parallel KOBE Cavity 2.5” 5040 .67 2.441 3.625 Crossover, 2-7/8 Butt P x 2-7/8 8rd B 5041 31.11 2.441 2.875 2-7/8 L-80 6.4# Butt Tubing 5073 .75 2.437 3.500 WLEG Short String (Production) 30.72 .68 7.063 CIW Dual Split Hanger 31.77 1.40 1.995 2.375 Pup Jt, 2-3/8” 4.6# L-80 Butt 33.17 6.10 1.995 2.375 Pup Jt, 2-3/8” 4.6# L-80 Butt SC 39.27 6.10 1.995 2.375 Pup Jt, 2-3/8” 4.6# L-80 Butt SC 45.37 4972 1.995 2.375 2-3/8 4.6# L-80 Butt Tubing 5017 .87 1.625 2.700 Crossover, 1-1/4 10rd P x 2-3/8 Butt B 5018 8.12 1.375 1.626 Pup Jt, 1-1/4 10rd 5026 14.40 5.625 Type A Single Parallel Cavity 2.5” * 06/2024 – Tag @ 5,430’ with 2.0” gauge ring. Work ponytail to 5,440’ SLM. * 10/2010 – Circ 9.8 ppg brine in LS, SS, and annulus. Pumped 38 bbls LCM pill. Has diesel cap. * 07/2005 – Tagged fill @ 5712’ FISH None Perforation Data Doglegs 2.5 3500 5300 5720 A Open Gravel Pack 2.5 3600 4.0 7200 5782 6607 BCD Isolated by BP @ 5770’ 4.3 7310 7092 7131 D Isolated by BP & 5sx cmt @ 6750’ 4.3 7350 4.3 7400 PBTD =5770’ TD = 7396’ MAX HOLE ANGLE = 2.5 O @ 3500’ 36” RKB: MSL = 101’ Mudline= 203’ Water Depth= 102’ 7” 7397’ 5123’ SC-1 Packer 20” 612’’ 13-3/8” 2010’ 5745’ Sump Packer 5770’ Baker N-1 BP 6750’ CIBP w/ 5 sx cmt 2900’ TOC CBL 5421’ MGS Oil Top 5440’ Tagged Fill 4536 MGS Gas Base 7092.5’ - 7131.5’ Open Perfs 5300’ - 5720’ Open Perfs 5782’ - 6607’ Open Perfs 3-1/2” 9.2 # N-80 0.012 Wire Wrapped Baker Weld Screen Gravel Pack 20—40 Mesh Ottawa Sand 9.8 ppg Brine 10 bbls cmt @ ~5730’ TOC ~5100’ KB: MSL Mean Sea Level Mud Line Ba-06 Schematic Proposed 2025-04.docx3 Page 2 of 2 Gravel Pack Jewelry Detail Depth Length ID OD Item 5123 4.18 4.00 5.937 Baker Model SC-1L Gravel Pack Packer 70B4-40 5128 4.81 4.875 5.50 Upper Extension 5132 1.66 4.43 5.50 Sliding Sleeve 5134 1.49 4.00 5.562 Seal Bore 5136 21.8 4.50 5.00 Lower Extension 5157 0.25 2.99 5.00 Crossover Sub 5158 124.44 3.50 2.99 Blank Tubing 5282 451.33 2.99 4.11 3-1/2” 0.012 Gauge Bakerweld Screen 5733 0.58 1.90 4.25 O-Ring Seal Sub 5734 10.08 2.99 4.11 3-1/2” Bakerweld Lower Tell Tale Screen 0.012 Gauge 5744 0.84 2.375 4.625 Baker Snap Latch Seal Assy 80-32 5745 3.45 3.25 5.63 Baker Model D Sump Packer 84-32 KLU A-1 Well Head Rig Up 1 1 1 1 4 1/16" 15K Lubricator - 10 ft 100" Gooseneck HR680 Injector Head 4 1/16" 10K Flow Cross, 2" 1502 10k Flanged Valves 4 1/16" 15K Lubricator - 10 ft API Flange Adapter 10K to 5K for riser/wellhead Hydraulic Stripper 4 1/6" 15K API Bowen CB56 15K 4 1/16" 10K Combi BOPs Blind/Shear Ram Pipe/Slip Ram 4 1/16" 10K bottom flange 4 1/16" 5K flanged Riser - 10 ft if necessary 45_COAL 40_COAL A-1 C E1_ST 44_COAL E F-1 29_COAL B-3 D-2 46_COAL 34_COAL A-2X F 32_COAL 24_COAL 41_COAL Base MGS Gas Pool (MGS State 18746-1) 42_COAL C-2 39_COAL D-1 F-2 D-3 E_ST B-1 30_COAL A-2 37_COAL 38_COAL F2_ST A A-3 28_COAL 31_COAL A-1X E-1 F-3 F2_BASE B A-4 Top MGS Oil Pool (MGS State 18746-1) 33_COAL F-4 B-2 G-1A_ST E-2 47_COAL C-3 35_COAL 43_COAL B-4 D 36_COAL F_SAND_TOP C-4 HEMLOCK F_SAND_BASE E1_BASE C-1 Cement WLEG Packer Screen Active Screen Active Screen Active Screen Active Fill Packer Plug Inactive Inactive Inactive Inactive Inactive Inactive Inactive Inactive Cement Plug Inactive 2516.3 7392.2 2550 2575 2600 2625 2650 2675 2700 2725 2750 2775 2800 2825 2850 2875 2900 2925 2950 2975 3000 3025 3050 3075 3100 3125 3150 3175 3200 3225 3250 3275 3300 3325 3350 3375 3400 3425 3450 3475 3500 3525 3550 3575 3600 3625 3650 3675 3700 3725 3750 3775 3800 3825 3850 3875 3900 3925 3950 3975 4000 4025 4050 4075 4100 4125 4150 4175 4200 4225 4250 4275 4300 4325 4350 4375 4400 4425 4450 4475 4500 4525 4550 4575 4600 4625 4650 4675 4700 4725 4750 4775 4800 4825 4850 4875 4900 4925 4950 4975 5000 5025 5050 5075 5100 5125 5150 5175 5200 5225 5250 5275 5300 5325 5350 5375 5400 5425 5450 5475 5500 5525 5550 5575 5600 5625 5650 5675 5700 5725 5750 5775 5800 5825 5850 5875 5900 5925 5950 5975 6000 6025 6050 6075 6100 6125 6150 6175 6200 6225 6250 6275 6300 6325 6350 6375 6400 6425 6450 6475 6500 6525 6550 6575 6600 6625 6650 6675 6700 6725 6750 6775 6800 6825 6850 6875 6900 6925 6950 6975 7000 7025 7050 7075 7100 7125 7150 7175 7200 7225 7250 7275 7300 7325 7350 2516 7388 2550 2575 2600 2625 2650 2675 2700 2725 2750 2775 2800 2825 2850 2875 2900 2925 2950 2975 3000 3025 3050 3075 3100 3125 3150 3175 3200 3225 3250 3275 3300 3325 3350 3375 3400 3425 3450 3475 3500 3525 3550 3575 3600 3625 3650 3675 3700 3725 3750 3775 3800 3825 3850 3875 3900 3925 3950 3975 4000 4025 4050 4075 4100 4125 4150 4175 4200 4225 4250 4275 4300 4325 4350 4375 4400 4425 4450 4475 4500 4525 4550 4575 4600 4625 4650 4675 4700 4725 4750 4775 4800 4825 4850 4875 4900 4925 4950 4975 5000 5025 5050 5075 5100 5125 5150 5175 5200 5225 5250 5275 5300 5325 5350 5375 5400 5425 5450 5475 5500 5525 5550 5575 5600 5625 5650 5675 5700 5725 5750 5775 5800 5825 5850 5875 5900 5925 5950 5975 6000 6025 6050 6075 6100 6125 6150 6175 6200 6225 6250 6275 6300 6325 6350 6375 6400 6425 6450 6475 6500 6525 6550 6575 6600 6625 6650 6675 6700 6725 6750 6775 6800 6825 6850 6875 6900 6925 6950 6975 7000 7025 7050 7075 7100 7125 7150 7175 7200 7225 7250 7275 7300 7325 7350 2445 7317 2475 2500 2525 2550 2575 2600 2625 2650 2675 2700 2725 2750 2775 2800 2825 2850 2875 2900 2925 2950 2975 3000 3025 3050 3075 3100 3125 3150 3175 3200 3225 3250 3275 3300 3325 3350 3375 3400 3425 3450 3475 3500 3525 3550 3575 3600 3625 3650 3675 3700 3725 3750 3775 3800 3825 3850 3875 3900 3925 3950 3975 4000 4025 4050 4075 4100 4125 4150 4175 4200 4225 4250 4275 4300 4325 4350 4375 4400 4425 4450 4475 4500 4525 4550 4575 4600 4625 4650 4675 4700 4725 4750 4775 4800 4825 4850 4875 4900 4925 4950 4975 5000 5025 5050 5075 5100 5125 5150 5175 5200 5225 5250 5275 5300 5325 5350 5375 5400 5425 5450 5475 5500 5525 5550 5575 5600 5625 5650 5675 5700 5725 5750 5775 5800 5825 5850 5875 5900 5925 5950 5975 6000 6025 6050 6075 6100 6125 6150 6175 6200 6225 6250 6275 6300 6325 6350 6375 6400 6425 6450 6475 6500 6525 6550 6575 6600 6625 6650 6675 6700 6725 6750 6775 6800 6825 6850 6875 6900 6925 6950 6975 7000 7025 7050 7075 7100 7125 7150 7175 7200 7225 7250 7275 45_COAL 40_COAL A-1 C E1_ST 44_COAL E F-1 29_COAL B-3 D-2 46_COAL 34_COAL A-2X F 32_COAL 24_COAL 41_COAL Base MGS Gas Pool (MGS State 18746-1) 42_COAL C-2 39_COAL D-1 F-2 D-3 E_ST B-1 30_COAL A-2 37_COAL 38_COAL F2_ST A A-3 28_COAL 31_COAL A-1X E-1 F-3 F2_BASE B A-4 Top MGS Oil Pool (MGS State 18746-1) 33_COAL F-4 B-2 G-1A_ST E-2 47_COAL C-3 35_COAL 43_COAL B-4 D 36_COAL F_SAND_TOP C-4 HEMLOCK F_SAND_BASE E1_BASE C-1 BA-06 [SSTVD] Spud date: 01/28/1966 UWI: 507331007300 Completion Date: 06/13/1966 Gas Rate - 10.03.23: Oil Rate - 01.03.23: Water Rate - 01.03.23: Cum. Gas - 10.03.23: Cum. Oil - 01.03.23: Cum. Water - 10.03.23: Max inc: 4.25 deg Petra WSN #: 65 TD (MD): 7400.0 ft MD 19.86 69.59mV SP 3.22 133.29gAPI GR -0.300 0.300ft3/ft3 NPHI_DPHI_265 0.00 1.00 CoalLog_GR_RESD_DTC 0.00 1.00 CoalLogRHOB CoalLog_GR_RESD_DTC - GR < 50 & RESD > 45 NPHI-DPHI_2.65 CoalLogRHOB <= 1.95 RHOB TVD Perforation_Log Perforation_Log_ShortString SSTVD 1:750 1.00 100.00ohm.m RESS 1.0000 100.0000ohm.m RESM 1.0000 100.0000ohm.m RESD 1.00 100.00 CoalLog_GR_RESD_DTC 0.00 1.00 CoalLogRHOB CoalLog_GR_RESD_DTC - GR < 50 & RESD > 45 CoalLogRHOB <= 1.95 RHOB > 14 ohms < 14 ohms 0.600 0.000ft3/ft3 DPHI_265 0.600 0.000ft3/ft3 SPHI_MJP 1.65 2.65g/cm3 RHOB 150.00 50.00us/ft DTC 0.00 1.00 CoalLog_GR_RESD_DTC 0.00 1.00 CoalLogRHOB CoalLog_GR_RESD_DTC - GR < 50 & RESD > 45 CoalLogRHOB <= 1.95 RHOB SPHI_MJP DPHI_265 >= 0.12 Proposed Cement MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:31 Township:9N Range:12W Meridian:Seward Drilling Rig:Rig Elevation:Total Depth:7400 ft MD Lease No.:ADL 0017595 Operator Rep:Suspend:P&A:X Conductor:20"O.D. Shoe@ 612 Feet Csg Cut@ Feet Surface:13 3/8"O.D. Shoe@ 2010 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 7397 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet SS Tubing:2 3/8"O.D. Tail@ 5041 Feet Tbg Cut@ Feet LS Tubing: 2 7/8"O.D. Tail@ 5074 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Initial 15 min 30 min 45 min Result Tubing 1730 1711 1704 IA 1730 1711 1704 OA 60 60 60 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Brad Whitten Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): The OOA= 110 psi for the duration of the MIT-IA. No cement tag was done due to the Sundry 325-262 calling verification of top of cement relative to tubing talley by by tagging with E-line run of GR/CCL and logging across tubing jewelry to 4900 ft MD. E- Line was not on location at this time. August 24, 2025 Guy Cook Well Bore Plug & Abandonment MGS ST 17595 Baker-06 Hilcorp Alaska LLC PTD 1660030; Sundry 325-262 None Test Data: P Casing Removal: rev. 3-24-2022 2025-0824_Plug_Verification_MGS_State_17595_Baker-6_gc David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/16/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL T20240716-2 Mudlog Image Files for each of the well bores listed in the table below: Well Name PTD # API # MGS ST 17595 6 166-003 50-733-10073-00-00 SFTP Transfer - Data Folders: Please include current contact information if different from above. 166-003 T39220 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.16 15:36:34 -08'00' �y'�@T�^+ +LBL/gL►i�►t7�'HA �0Y 11L A�l`�f�+i�+�r/GAS C�l'1�SERV1�Jl�i O fv®l�ll��i'i►71SIO June 22, 2009 SARAH PALIN, GOVERNOR i 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dale Haines scumu i 0 3 2014 UNOCAL 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubert�aalaska.gov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Company Permit No. Well Name UNOCAL Union Oil Company of California 168-024 Granite Pt St 17587 5 Union Oil Company of California 194-149 Granite Pt St 18742 03RD Union Oil Company of California 179-033 Granite Pt St 18742 14 Union Oil Company of California 167-077 Granite Pt St 18742 16 Union Oil Company of California 168-012 Granite Pt St 18742 18 Union Oil Company of California 100-266 Granite Pt St 31-14RD2 Union Oil Company of California 182-020 _ Trading Bay Unit D-06RD Union Oil Company of California 169-004 Trading Bay Unit D-18 Union Oil Company of California 188-098 Trading Bay Unit D-30RD2 Union Oil Company of California 182-083 Trading Bay Unit D-40RD _ Union Oil Company of California 178-045 _ Trading Bay Unit G-08RD Union Oil Company of California 176-032 Trading Bay Unit G-24 Union Oil Company of California 179-013 Trading Bay Unit D-06RD Union Oil Company of California 188-028 _ Trading Bay Unit G-34RD Union Oil Company of California 168-038 Trading Bay Unit K-06RD Union Oil Company of California 169-066 Trading Bay Unit K-09 _ Union Oil Company of California 179-016 Trading Bay Unit K-21 RD Union Oil Company of California 178-004 _ Trading Bay Unit K-23 Union Oil Company of California 165-038 MGS St 17595 05 _ Union Oil Company of California 166-003 MGS St 17595 06 Union Oil Company of California 167-017 MGS St 17595 11 Union Oil Company of California 167-049 MGS St 17595 13 Union Oil Company of California 176-075 MGS St 17595 18 Union Oil Company of California 185-135 MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD Union Oil Company of California 193-119 MGS St 17595 28 Union Oil Company of California 193-118 MGS St 17595 29 Union Oil Company of California 193-120 MGS St 17595 30 Union Oil Company of California 195-199 MGS St 17595 31 Union Oil Company of California 175-007 S MGS Unit 02RD Union Oil Company of California 167-028 _ S MGS Unit 03 _ Union Oil Company of California 167-058 S MGS Unit 04 Union Oil Company of California 175-044 _ S MGS Unit 13 Union Oil Company of California 175-066 S MGS Unit 14 Union Oil Company of California 176-045 S MGS Unit 15 Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 Union Oil Company of California 194-098 S MGS Unit 18 Union Oil Company of California 175-057 Soldotna Ck Unit 12A-10 Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 Soldotna Ck Unit 23B-03 Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 Union Oil Company of California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 _ Union Oil Company of California 100-269 Soldotna Ck Unit 41 B-09 _ _ Union Oil Company of California 162-031 Soldotna Ck Unit 43-09 _ Union Oil Company of California 174-066 Soldotna Ck Unit 44-04 _ Union Oil Company of California 160-018 Swanson Riv Unit 212-10 Union Oil Company of California 161-033 Swanson Riv Unit 212-27 Union Oil Company of California 160-041 _ Swanson Riv Unit 234-15 _ Union Oil Company of California 167-076 Trading Bay St A-10 _ Union Oil Company of California 172-020 Trading Bay St A-23DPN _ Union Oil Company of California 173-014 Trading Bay St A-30 ) ) Chevron III Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com October 10, 2005 Commissioner John Norman Alaska Oil & Gas Conservation Commission 333 W. th Avenue Anchorage, Alaska 99501 1M.. t;:~.' ~I t~~O'~ ~) t~ 2\)00.;.':::<.: SCANf¡~~t.-· ~'{\.., Re: Baker Platform Pilot Pre-Abandonment Work Summary Ibb-003 {;ft,h Dear Commissioner Norman, This letter is intended to update the Alaska Oil and Gas Conservation Commission on the status of Unocal's pilot pre-abandonment work on the Baker Platform in Cook Inlet, Alaska. On October 22, 2004, Unocal proposed that a pilot program be initiated on the Baker platform to develop a safe, cost effective, and optimal method for the abandonment of multiple well bores. As noted in the letter of October 22, 2004, Unocal has operated the Baker and Dillon Platforms under a "lighthouse" mode where all oil and gas production has been shut-in. The Dillon Platform was shut-in December 2002 and the Baker Platform was shut-in August 2003. Unocal commenced the pilot study with a diagnostic program on five water injection wells and three oil wells on the Baker Platform in July 2005. The diagnostic program consisted of pressure and temperature surveys for baseline data, mechanical integrity of the completion, injectivity tests to the formation, and pressure measurement on the outer casing annuli. The injection wells initially surveyed were Baker 7, 8rd, 12, 15rd, and 27. The oil wells surveyed were Baker 13, 28, and 30. Unocal did not anticipate that any of the oil wells on the Baker platform would have a bottom hole pressure (BHP) gradient exceeding seawater. However, when it was discovered that Baker well 28 had a static BHP of9.0 ppg, the diagnostic program was expanded to include all of the oil wells and water injection wells on the Baker Platform as well as six wells on the Dillon Platform. The Baker water injection wells have mostly held their residual pressure since being shut-in. Their BHP gradients range from 5.8 to 9.4 ppg. Three oil wells on the Baker platform have BHP gradients that exceed a seawater gradient. Two additional wells have pressures that exceed an oil gradient but are below a seawater gradient. Under the right conditions, these wells could be capable of unassisted flow. The Baker Platform Well BHP Summary is attached. The Dillon well BHPs are all below a seawater gradient of 8.4 ppg. No additional diagnostic well work on the Dillon platform has been initiated. n~J,n~ \·r ·I\<>JE ^" t-i.- ~ ~"d~ M Union Oil Company of California / A Chevron Company http://www.chevron.com ) ) Commissioner John Norman Alaska Oil & Gas Conservation Commission October 10, 2005 Page 2 No temperature anomalies were noted on the Baker platform with the exception of Baker well 28. Baker 28 exhibited a temperature anomaly at approximately 5,000 feet MD, as noted on the attached Baker Composite Temperature Chart. An assessment of Baker 28 is attached with the recommendation of no remedial activity. Chevron intends to conduct annual temperature/pressure surveys on Baker 28 to monitor the well status. There were no temperature anomalies noted on the Dillon platform wells. The pilot abandonment program commenced with plugging perforations on the water injection wells initially identified (i.e. Baker wells 7, 8rd, 12, 15rd, and 27). The plugging of the perforations received Sundry approval and the integrity testing of the cement plugs was witnessed by an AOGCC representative. In addition, perforations were plugged in the water supply well Baker SOland in the gas well Baker 32. In light of the Chevron Corporation acquisition of Unocal, the well plugging operations for the oil wells on the Baker platform has been omitted from the 2005 pilot program to allow time to reassess economic potential under Chevron's criteria. Furthermore, the gas potential from the Baker is also being re-assessed. To better prepare for the winter, Chevron will be applying heat on both the Baker and Dillon platforms. In addition, the wells capable of receiving a freeze protect fluid in their respective annuli will be freeze protected. If you have any questions or concerns, please contact me at 907-263-7657. Sincerely, ~ --a_/?c' ,2 ~ c-~ .-/~~~/' Timothy C. Brandenburg Drilling Manager Attachments Cc: Dale Haines Gary Eller Union Oil Company of California / A Chevron Company http://www.chevron.com Baker Platform Well BHP Summary Last Updated: October 7,2005 Pressure Survey Measured Gradient Equivalent Mud Well Well Type Date MD (ft) TVD (ft) BHP (psia) (psi/ft) Weight (ppg) Notes Ba-4 Injector 27-Jul-05 7850 7843 3141 0.400 7.7 Ba-5 Producer 30-Jul-05 6284 5566 2753 0.495 9.5 ~Ba-6 Producer 20-Jul-05 5712 5709 2811 0.492 9.5 Ba-7 Injector 7-Jul-05 6244 5630 2712 0.482 9.3 Ba-8rd Injector 7-Jul-05 7100 6937 3288 0.474 9.1 Ba-9rd2 Injector Perfs cemented, no survey planned -- Ba-11 Producer 21-Jul-05 8379 8113 3273 0.403 7.8 Ba~12s Injector 6..Juh05 Sa-121 Injector 16-Jul-05 7121 6106 2941 0.482 9.3 Sa -13 Producer 6-Jul-05 7916 7661 3236 0.422 8.1 Ba-14 Gas No survey Ba-15rd Injector 5-Jul-05 6480 6286 3050 0.485 9.3 Ba-16 Injector No survey Ba -1 7 Injector No survey Ba-18 Gas No survey Ba-20 Producer 28-Jul-05 4134 4030 1242 0.308 5.9 Obstruction in tubing at 4139' Ba-23 Injector 23-Jul-05 8841 8499 2584 0.304 5.8 Ba-25rd Producer 22-Jul-05 9495 9033 3208 0.355 6.8 Ba-27 Injector 6-Jul-05 7779 5999 2928 0.488 9.4 Ba-28 Producer 3-Jul-05 8441 5308 2497 0.470 9.0 Ba-29 Producer 28-Jul-05 7923 7594 2165 0.285 5.5 Ba-30 Producer 4-Jul-05 10966 9109 3593 0.394 7.6 ~ Ba-31 Producer 29-Jul-05 11433 10636 3795 0.357 6.9 Ba-32 Producer No survey ¡-m 'l=-¡:¡ 'M;\' ....'1;:¡¡ r? ,\ "=>. '¡ ¡:, ", :1 :1:) 1-, Y\ " )),1 '.-.j _ '" '. . '\ I L\ \ '1:\ .1" ill) :1, I r\', ) :111 ~'1-;:l.J ,..;iw ~ '/-::::"'\n. " .',f-:::J.. ' I) ':\1 \ I\.'!I!:= l,J J 'i! .'-- '-' /I\ r¡ \ (\GiV7 ./~ i j Iii I, q, ì \' .1 L\ \ fj-;j Lb U-:·j CU )d\~ .u~ FRANK H. MURKOWSKJ, GOVERNOR A.IIA.~1iA OIL AND GAS CONSERVATION COlWlISSION 333 W. 7'H AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Brandenburg Drilling Manager UNOCAL P.O. Box 196247 Anchorage, Alaska 99519 Re: Middle Ground Shoal Baker-06 Sundry Number: 305-230 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. t~~-OD3 SCANNED J\UG 1 7 2005 Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls 0 holiday or weekend. A person may not appeal a Commission deci . n 0 Superior Court unless rehearing has been requested. .-- in 1 ( DATED this /~day of August, 2005 Encl. ( UNOCAL~ .".- Alaska Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 Re: Application for Well Plugging (Form 10-403) Baker Platform Well #06 \~~I 003 RECEIVED AUG 1.3 2005 Alaska Ojl Þ G, ~ 1M CO '" n~. eam . . to ht,. \. mlSSiQn ; ,,, , IØf,~9t1 ., August12,2005 Alaska Oil and Gas Conservation Commission Commission Chair John Norman 333 West ih Avenue Anchorage, Alaska 99501 Dear Commissioner Norman, Attached for your approval is an application for plugging the perforations of Baker Well #06 in the Middle Ground Shoal Unit. Unocal proposes to abandon the active production interval with cement and leave a 9.8 ppg kill fluid in the well bore in accordance with AOGCC Regulation 20 MC 25.112(c). The production of oil and gas from the Middle Ground Shoal Tyonek A-G sands on the Baker Platform had previously been deemed uneconomic, and the Baker Platform was shut down in 2003. Since that time, the wells have remained shut-in. Evaluation for gas potential is ongoing in intervals above the Tyonek A-G sands, and the wellbore may have future utility for gas production. Unocal proposes a phased abandonment program starting with plugging the perforated completion intervals. A pilot program has been initiated during the summer of 2005 to begin abandonment of up to 5 injectors and 3 producers. The intent of the trial zonal abandonment is to prove up a cost effective, tree-on abandonment program to be used on the remaining Baker Platform wells and Dillon Platform wells. Unocal intends to continue with the permitting of the eight (8) wells, and will continue execution of operations until freezing temperatures halt forward progress. The overall success of the abandonments and their effectiveness will be evaluated for the 2006 work program. Unocal commenced well diagnostic work on the Baker Platform in early July 2005. The reservoir pressures in the water leg of the reservoir exceed a water gradient with the highest recorded gradient being 9.6 ppg EMW. In addition to the injection interval being charged, we found two producers with pressures exceeding a water gradient. In light of this information, UNOCAL is communicating with ADEC regarding our Spill Contingency Plan and will also better secure the wells for the 2005 I 2006 winter. The Baker well #06 attachments include: · 10-403 requesting plugging of the Tyonek Reservoir Sands A-G, · Procedure for plugging the perforations and pumping of kill fluids, · Summary of the Slickline Wells Diagnostics, Union Oil Company of California I Unocal Alaska 909 West 9th Avenue, Anchorage. Alaska 99501 http://www.unocal.com { Commissioner John Norman, AOGCC August 12, 2005 Page 2 · Recent pressure and temperature profile showing confinement of fluids to the reservoir, . Current Well Schematic If you have any questions, please contact myself at 263-7657. For any technical questions on the 10-403, please or Mr. Steven Lambe @ 263-7637 or Mr. Gary Eller @ 263-7848. s:;rel~' h _C Tim Brandenburg 7 Drilling Manager SSL/s Enclosure Union Oil Company of California I Unocal Alaska 909 West 9th Avenue, Anchorage, Alaska 99501 http://www.unocal.com Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 79' 8. Property Designation: Baker Platform 11. Total Depth MD (ft): 7937' 1 . Type of Request: Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 5300'-5720' CfJ1 8-/b-e5 ()TJ ð/16/5 ( STATE OF ALASKA il" REC-II E p Ir::· :""~A AL¡~r\.A OIL AND GAS CONSERVATION COM~I~SION .J "" ~ \J l:: U . APPLICATION FOR SUNDRY APPROVAL AUG 15 2005 ,e: 20 AAC 25.280 J Operational shutdown U Perforate U Alaska GNé&'~~ Cons. Coml~ Plug Perforations 0 Stimulate 0 Time ExtensiofultJlOrage Perforate New Pool 0 Re-enter Suspended Well 0 4. Current Well Class: Suspend U Repair well 0 Pull Tubing 0 Development Stratigraphic o o ~~O~~N¿~~'5~ 6. API Number: fS¡, s- 50-733-10073-00 V Exploratory 0 o Service 9. Well Name and Number: MGS ST 17595, Baker-06 10. Field/Pools(s): MIDDLE GROUND SHOAL, B C AND 0 PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 7932 Effective Depth MD (ft): 5770' Effective Depth TVD (ft): 5767' Plugs (measured): 5770' Junk (measured): n/a Collapse Length Size MD TVD Burst 612' 2010' 20" 612' 2010' 612' 2010' n/a n/a 2730 psi 1130 psi 4360 psi 3270 psi 13-3/8" 7397' 7" 7397' 7394' Perforation Depth TVD (ft): 5298'-5717' Tubing Size: Tubing Grade: Tubing MD (ft): LS: 5073', SS: 5018' Packers and SSSV Type: Baker SC-L 1 gravel pack packer @ 5123', "0" sump packer @ 5745' 12. Attachments: Description Summary of Proposal U Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: LS: 2-7/8", SS: 2-3/8" Packers and SSSV MD (ft): Baker SC-L 1 gravel pack packer @ 5123', "0" sump packer @ 5745' 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: 8/18/2005 Oil 0 Gas 0 WAG 0 GINJ 0 o o 16. Verbal Approval: L-80 Service D Date: Plugged WINJ o o WDSPL Abandoned Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Timothy C. Brandenburg Title Drilling Manager Signature '7 :';"çi? c..þ Ç2 Phone 907-276-7600 Date c::.,./ ¿;::J COMMISSION USE ONLY J. Gary Eller 263-7848 ?!--/ S-- DS Conditions of approval: Notify Commission so that a representative may witness Other: \.)~\~-¡:~~C-\C\~~\~~ \;G.~ S~ ~l¡~ \LI(ß.\> CoI/'I'4^..'t: ~O" ',,~c~J O~Ck~1 þf'CCít~o,) 'rû...~ <.~~. Subsequent Form eqUin~(-:: \ ... RBDMS 8Fl AIIG 1 7 7005 o RIG ! l'\~! , L APPROVED BY THE COMMISSION Plug Integrity ~ Sundry Number: 3oS--.;t30 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 ¥fÍ'f COMMISSIONER Date: ~ Form 10-403 Revised 11/2004 AFE XXXXXX Submit in Duplicate Well Ba-6, Middle Ground Shoals Unit Plugging Procedure AFE 164_ Recent Well History: In July 2005, a gauge ring tagged fill at 5737' in the longstring completion of well Ba-6. A static BHP survey showed a 9.6 ppg formation gradient (2811 psi at 5712' MD, 5630' SSTVD), and the temperature survey showed no abnormalities. The highest perforation in well Ba-6 is at 5300' MD (5298' TVD). The longstring tubing and shortstring tubing were both successfully tested to 1700 psi. Objectives: 1. Isolate all hydrocarbon-bearing zones as per 20 AAC 25.112(c)(I)(C) 2. Test the cement plug to verify zonal isolation and 7" casing integrity as per 20 AAC 25.112(g) 3. Fill the wellbore with kill-weight fluid as per 20 AAC 25.112(f) Procedure: 1. Rig up to circulate filtered Inlet water (FIW) down the longstring (LS) tubing and pressure test to 3000 psi. Rig up a returns manifold and a choke off of the shortstring (SS) tubing and 7" casing. Pressure test returns line to 2500 psi. 2. Circulate FIW down the LS while taking returns up the 7" casing following the Driller's Method. Formation pressure = 9.6 ppg EMW, so major losses are not expected while circulating FIW. When clean returns are established, shut in the 7" casing and take returns up the SS tubing while still following the Driller's Method. Do not place any additional back-pressure on the well during this stage of the procedure. The objective of this step is to fill the wellbore above the tubing tail with FIW and remove all free hydrocarbons. Calculated tubular volumes are as follows: a. LS = 29.3 bbl b. SS = 19.4 bbl c. 7" casing below tubing tail = 8.5 bbl d. 7" x tubing annulus volume = 131 bbl , '1-\\()\0~ \~ Sù\..c'~\e."-~ ~ Q.\\t)~~~'>~""'-tè. S\.~e:e..~~ 3. Blend 40 bbl of 14.5 ppg cement to abandon all open perfs. Notify AOGCC with 24-hour notice of planned plugging operations. This is sufficient volume to place cement from the top of the existing retainer at 5770' to 500' above the highest perf (planned TOC = 4800'). Prepare to pump cement down the LS while taking returns off the SS tubing and 7" casing simultaneously via the returns manifold. B-06 Plugging Procedure August 12,2005 Well Ba-6 Well Plugging Procedure AFE 164_ Page 2 4. Shut-in the SS tubing and 7" casing. Begin bullheading cement down the LS tubing. Continue bullheading into the perfs until a total of 15 bbl of cement has exited the LS tubing (sufficient to fill the sump). The objective is to encourage cement to get down to the retainer at 5770'. Maximum allowable squeeze pressure on 7" casing = 1500 psi. If 7" casing pressure reaches 1500 psi during the squeeze, begin taking returns off the 7" casing and SS tubing but adjust the choke to maintain ±1500 psi back pressure. After squeezing 15 bbl of cement out the tubing tail, reopen the returns line and finish circulating the planned cement volume. Maintain enough back-pressure to keep the formation from going underbalanced. Drop a wiper dart for 2Yg" tubing down the LS tubing and displace with 27.8 bbl FIW to 4800' l\ID. Strap the displacement tank to ensure an accurate displacement volume if the well is on vacuum during displacement. 5. Wait on cement 12 hours. While waiting, make sure that LS tubing, SS tubing, and 7" casing pressure stay equalized to help ensure that the cement plug is balanced across all strings. RD cementing equipment. 6. Pressure test LS, SS, and 7" casing to 1500 psi. Contact Project Manager if any of these fail to pressure test. While holding 1500 psi on the 7" casing, pump down the 130/g" casing to verify communication with the 13%" shoe. Monitor pressure on 20" conductor while pumping down 13%" casing. Maximum allowable pump pressure on the 13%" casing = 1000 psi. Maximum allowable pressure on the 20" conductor = 300 psi. Freeze protect the 130/g" casing by pumping 11 bbl of base oil into the 130/g" casing. 7. MIRU electric line on LS tubing. Pressure test lubricator and conduct pre-job safety meeting. RIH with 5' of tubing punches for 2Yg, 6.4 ppf tubing. Tag the top of cement at ±4800', and then PU to ±500' above previous tag. Fire tubing punches while holding 500 psi on the LS tubing. POOH. 8. RU e-line on SS tubing, pressure test lubricator. RIH with tubing punches for 20/g", 4.6 ppf tubing. Tag cement at ±4800', and then PU to ±500' above the tag in the SS tubing. Fire tubing punches in the SS tubing while holding 500 psi on the SS tubing. POOH, RDMO e-line. 9. Blend 250 bbl of 9.8 ppg kill-weight NaCl brine. (Note: Requires 95 lbs of NaCl per barrel of fresh water. The freeze point of 9.8 ppg NaCl brine is 5° F.) 10. Circulate kill-weight brine down the LS while taking returns up the 7" casing following the Driller's Method. When kill-weight brine is returned, shut in the 7" casing and take returns up the SS tubing while still following the Driller's Method. Secure well, RDMO pumping equipment. B-06 Plugging Procedure August 12,2005 Well DiaQnostic Data Well #1 Ba-6 IAPI# 150-733-10073-00 IWell Class: I ISpud Date: 1/28/19661 Condition: Casing Structural Top MD Top TVD Btm TD Btm TVD Wt Grade 70% Burst* 70% Collapse* TOC Conductor, 20" surface surface 612 612 79.6" Armco S.W. Lost circulation during CMT job, performed top job between 20" and 32" pile with 23/8" string at 130', pumped 275 sks with 2% CaCI 2. FIT 11.67 MWE Lost circulaton during last 8 minutes of displacement during cmt job. No cement to surface. Ran tubing down 20" x 13 3/8" annulus to 710'. Cemented with 450 sks g cement with 2% CACL 2. No record of LOT or FIT performed Cemented with 1900 sks cmt, lost returns for 19 minutes of job. Avg PR 7 bpm. CBL shows TOC at 3090' Surface, 13-3/8" surface surface 2010 2010 54.5# J-55 8rd 1911 psi 791 psi Production, 7" surface surface 7397 7392 23-26# J-55 and N-80 3052 2289 Liner ,. Based on weakest string Tubing Size Wt Grade 70% Burst* 70% Collapse* Btm TD Btm TVD MinlD Min Depth Long String 2 7/8" 6.4 L-80 7399 7812 5073 5071 2.25 cavity 5026 Short String 23/8' 4.6 L-80 7840 8246 5026 5024 1.375 5018 KOBE MD TVD Size LS Size S5 Below Cavity 5026 5024 27/8" 2 3/8" Test Bundle: 11700 good test ISIiCkline Above Cavity Tag MD TVD Size Test LS Only: INA Fill 5737 5734 2 Test SS/Cavity: NA BHP PSI MD TVD PSI/FT I BHT Deg. F I MD I TVD 2811 5737 5734 0.49 9.4 EMW 127 5737 5764 Testing Test Pressure Injection Rate PSI Casing Age LS Test U 1/4 bpm 39+ SS Test U 112 bpm Tubing Age Casing Test U 3/4 bpm 8 Initial pressure 400 psi, 7" x tbg 850 psi. pumped 40 bbls at 2 2bpm BPM, injection pressure 1520, 7" x tbg 1580 psi Pressure SPPSI SITP (0) SITP (1 hr) SITP (3 hr) SITP (6 hr) SITP (12 hr) SITP (24 hr) SITP (48 hr) SITP (96 hr) Structural x Conductor Conductor x Surface 20" = 100 gas, 5 psi 0 0 0 0 0 0 0 Surface x Intermediate 13-3/8" = 100 gas,S psi 10 10 10 20 22 20 20 gas, oil 80 Production x Tubing 7" = 850 psi 300 360 380 380 400 400 400 Long String 500 gas, 5 psi 200 285 295 300 305 305 300 5 psi, string bled off while bleeding 7" Short String 550 and LS 200 250 250 250 300 300 300 AFE: XXXXXX last revised: 8/12/2005 Thursday, August 04,2005 07-20-05 07-21-05 07-23-05 07-23-05 Baker #6 Summary Rig up Pollard slick line with 2" gauge ring - Pressure test lubricator- Rlli and tag fill at 5,712' rkb slm (btm of screen) - Trip for Pressure/ Temperature tools - Survey in and out of hole at 60' /min - Max tool depth = 5,712' rkb slm (+/- 5,709' tvd). BlIP = 2,811psi at 127 deg F, 9.5ppg EMW. Drop 21,4" standing valve - Bundle test completion to 1700psi. Starting pressures = LS 300psi, 55 350psi, 7" by tubing = 860psi - End of test pressures = LS = 1700psi, SS = 1,800psi, 7" by tubing = 880psi - Test indicates good tubing strings to Standing valve Ba-6 - Make up equalizing prong for standing valve - RIH with same & shear equalizing ports - Trip for pulling tool- RIH latch standing valve- Trip out of hole with same - Secure well, rig down Pollard move to Ba-11 Ba-6 - Rig for injection test - Starting Pressures LS = 450psi, 7" by tubing = 850psi. Injected 32bbl at 2bbl/min. Max pressure = LS 1,520psi, 7" by tubing = 1,580psi Ba-6 - LS bled 500 psi to 200 psi gas, 22 bbls water-oil. SS allowed to bleed down while bleeding LS and 7" annulus 550 psi to 5 psi. T' x tbg 850 psi to 50 psi, big gas cap, bled 9 bbls crude. 130/8" x 7" bled from 100 psi to 5 psi. Gas, 5 bbl water. 100 psi to 0 psi all gas Unocal Well:IB-6L Field: I Baker7-20-2005 0 0 Pressure -Temperature Profile 1. Going in hole TVD 500 1000 1500 2000 2500 d > 3000 I— t a 4) 3500 0 4000 4500 5000 5500 Pressure (psia) 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 6000 40 Report date: 8/12/2005 50 60 70 80 90 100 110 120 130 140 150 160 Temperature (Deg. F) Pressure — Perfs Temperature REVISED: 9/19/97 DRAWN BY: tcb PBTD = 5,770' TD = 7,397' MAX HOLE ANGLE = 2.40 JEWELRY DETAIL NO. Depth ID OD Item Long String / Tail Pipe 30.72' Cameron Dual Half, 2-9/16" Tubing Hanger, 2-7/8" 8 rd Top 2 5,015' 2.50 3.22 Crossover, 2-7/8" Buttress Box x 2-7/8 rd Pin 3 5,016' 2.44 2.87 Pup, 6.5#, L-80,.2-7/8" 8 rd Box x Pin 4 5,026' 2.25 5.62 Kobe, 2-1/2", Model "A" Single Parallel Cavity 5 5,040' . 2.44 2.87 Crossover, 2-7/8" 8 rd Pin x 2-7/8" Buttress Pin 6 5,041' 2.44 2.87 I Joint, 2-7/8",6.4#, L-80, Buttress SC Tubimg 7 5,073' 2.43 3.50 Mule Shoe Short String A 30.72' Cameron Dual Half, 2-1116" Tubing Hanger, 2-3/8" 8 rd Top B 5,017' 1.62 2.70 Crossover, 2-3/8" Buttress Box x 1-1/4 NU 10 rd Pin C 5,018' 1.37 1.62 Pup, 1-1/4,2.3#, L-80, 10 rd Box x Pin Gravel Pack Assembly 5,123' 4.00 5.93 Baker Model SC-Ll Gravel Pack Packer Size 70B4-40 IT 5,282' 2.99 4.11 Bakerweld Screen, 3-112", .012 Gage III 5.745' 3.25 5.63 Baker Model '0' Sumo Packer Size 84-32 PERFORA TION HISTORY Interval Acam D:Ite ZOne "op tEn Þnt spf Present OJncition 1/29'95 A 5,'ID 5,:m' æ ~ t-æka:i 1/29'95 A 5,444 5,481' ::J( Cß\eI t-ækOO 1/29'$ A 5,522' 5,548 26 Cß\eI t-ækOO 1/29'$ A 5,fSlrJ 5,€Œ ffi' Cß\eI Péd<Ed 11'2fðæ A 5,644' 5,rðJ IS Cß\eII-ækej 1/1/67 A 5,'ID 5,:m' æ S:;µ3eæ:I 1/1/öf A 5,446' 5,481' æ S:;µ3eæ:I 1/1/fJl A 5,522' 5,548' 26 S:;µ3eæ:I 1/1/ffl A 5,õlfj 5,638' 62' S:µ3eza:I 1/1/fJl A 5,644' 5,f!fE 11' S:;µ3eæ:I 1/1/ffl B,C,u 5,7fQ 5,a:S' 23 IsdatOO t1¡ retainer at 5,m 1/1/& I::S,C,U 5,8fIJ 5,910' '00 IsdatOO t1¡ retainer at 5, f (Ij 1/1/õ7 I::S,C,O 5,925' 6,(1:11 75' IsdatOO t1¡ retainer at 5,770' 1/1/õI B,G,O 6,œ:J 6,Œ!JS 3S Isdatoo t1¡ retainer at 5,TlO' 1/1/õI l::S,c,u 6,13::>' 6,240' 110' Isdatoo t1¡ retainer at 5,770' 1/1/õI I::S,G,O 6,2ro 6,æJJ 100' IsdatOO t1¡ retainer at 5,m 1/1/& ~C,U 6,42)' 6,400' 40' Isdatoo t1¡ retainer at 5, f (Ij 1/1/ffl B,C,O 6,400' 6,540' fJJ Isdatoo t1¡ retainer at 5, f fIJ 1/1/ffl B,C,O 6,6:>1' 6,f!IJ7' 6 Isdatoo t1¡ retainer at 5,T/rJ 1/1/67 I::S,C,u 7,Œ!2 ',CJ3ð: 2 Isdatoo t1¡ retainer at 5, f fIJ 1/1/õI B,c,u 7,131 7,131' l' IsdatOO t1¡ retainer at 5,m 5,015' 5,017' 30.72' 30.72' BTCSC BTC SC L-80 L-80 2.441 1.995 BTM. 612' 2,010' 7,397' J-55 L-80 ~-5S , TOP Surface Surface Surface 8 rd BTC CASING AND TUBING DETAIL GRADE CONN ID 19.124 12.615 6.276 Baker Well No.6 Actual Completion 10/28/97 ~ Ba6Schem Revised 10-28-97 L ><= ~ ~\\~~~ù,'~\ ><= ~sl,i C\ .S ~~ x .:.:.:.:.:~:~:~~:~:~~:~:. .:~~:~:~:.:.:.:-:..:..:.:.: :~:~:~:.;:~:~:--:~~:~~:~:. .:.:.:-:.:.:.:.:.:-:.:.:.: .:.:.:~:.:.:.:.:.:.:-:.:.: .:.:.:-:.:--:.:.:.:.:~:.:.: ~ B ~ C SIZE WT 20" - 13-3/8" 54.5 A 7" 26-23 Tubing: 2-7/8" 6.4 2- 3/8" 4.6 ~ ) \C,.) S l~") l '1\~~\~S) :g III :;:;:;~~:;:::::::::::::: II ............. _:;:;:;:;:~;:;:~:::::::: ------- z I L II 'j ; _'. l L 2 3 4 5 6 7 RKB to TBG Head = 30.72' UNOCAL. ) r' ~ ~~!Æ~E :} fÆ~~~~«fÆ AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSK'. GOVERNOR 333 W. JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Dave Cole Oil Team Manager UNOCAL P.O. Box 196247 Anchorage, AK 99516-6247 I........"".I.:".,...",......,J..'...".,..,..."..'(J03 l¡lttl Re: Middle Ground Shoal Unit Platforms Dillon and Baker Dear Mr. Cole: This letter confirms your conversation with COlnmission Engineer Tom Maunder last week regarding the multiple Applications for Sundry Approval (Form 403) you submitted in mid October regarding changing the monitoring frequency on the 16 wells on Dillon Platform and 23 wells on Baker Platform. Production and injection operations were halted on these platforms in 4th Q 2002 and 2nd Q 2003 respectively. Attached, please fmd the Sundry Applications, which are being returned without approval"j because the relief you request needs to be sought through a different procedure. The intent of submitting sundry notices for each well was to establish a monthly pressure and general monitoring frequency for all wells on Dillon and Baker. There is a requirement in place for some of the water injection wells that pressures and rates are to be monitored daily and reported monthly. Since the platforms are unmanned and not operating, it is not possible to obtain daily information. When operations were curtailed, a monthly monitoring frequency was established in the Plans of Development (POD) annually filed with the Division of Oil and Gas and Unocal desires to assure that this monitoring scheme is accepted by the Commission. As noted in the conversation, changing the monitoring frequency where presently in place and establishing a monthly monitoring frequency in general is not an action that is best accomplished with multiple sundry notices. A letter application requesting the desired monitoring schedule should be made under the applicable Area Injection Orders (Ala 7 for Baker and AIO 8 for Dillon) and Conservation Oiders (CO 44 and CO 54) for the platforms/unit. The Commission looks forward to receiving your letter applications. If prior monthly monitoring information has not been submitted to the Commission, that information should be ubmitted forthwith. ~, Sincer~~ . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this _day of November, 2004 SCANNED NOV 2 4 2004 Enel. ¡::ø ~ STATE OF ALASKA . ~) ALASKA OIL AND GAS CONSERVATION COMMIS~ION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Suspend U Repair well 0 Pull Tubing 0 Perforate U Waiver U Annular Dispos. U Stimulate 0 Time Extension 0 Other 0 Re-enter Suspended Well 0 Monitor Frequency 5. Permit to Drill Number: Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Union Oil of California aka Unocal 1. Type of Request: 3. Address: 909 West 9th Ave. Anchorage AK 99501 Development Stratigraphic 0 0 Exploratory 0 1660030 /1 Service 0 6. API Number: / 50-733-10073-00 / / 7. KB Elevation (ft): 79' 9. Well Name and Number: 7,397' Casing Structural Conductor Total Depth TVD (ft): 7,392' Length Ba-06 10. Field/Pools(s): MIDDLE GROUND SHOAL PRESENT WELL CONDITION SUMMARY 7'. Effective Depth MD (ft): Effective Depth TVD (ft): Plu (measured): 5,778' 5,777' MD Burst Junk (measured): 8. Property Designation: BAKER 11. Total Depth MD (ft): 7" 612' 2,010' 7,397' Collapse Size Surface Intermediate 612' 20" 612' Production Liner 2,010' 7,397' 133/8" 2,010' 7,393' 2,734 psi 7,240 psi 1,130 psi 5,410 psi I Perforation Depth MD (ft): 5300 to 5720; Packers and SSSV Type: Perforation Depth TVD (ft): 5298 to 5717; Tubing Size: Tubing Grade: Tubing MD (ft): LS: 5,073' SS:5,040' Baker 7" SC-1 L At 5,129' Baker Model D Sump packer @ 5,745' 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for LS: 2-7/8" S: 2-3/8" LS: 6.4#, L-80 SS 4.6#, L-80 Packers and SSSV MD (ft): Date: 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 0 Service 0 Commencing Operations: 16. Verbal Approval: Plugged WINJ 0 0 Abandoned WDSPL 0 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct the best of my knowledge. Contact Title Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY Printed Namy¡ . ~. Cole Signature ÁUr./d~ 27 -Sep-2004 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3c4-wf Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: RBDMS BFL NOV 2 2 LDD4 APPLICATION RETURNED 11/17/04 NOT APPROVED BY COMMISSION ::CE\\/E,D )[11 2 7.004 Subsequent Form Required: Approved by: ORIGINAL COMMISSIONER BY ORDER o~\aS¡\8 THE COMMISSION CornrnlSSWiì ~\1f:tlorage ~ Form 1 O~ Revised 12/2003 Submit in Duplicate • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Suspend Operation Shutdown Lj Perforate Waiver Other Performed: Alter Casing ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Time Extension[—] Change Approved Program ❑ Pull Tubing ❑ Perforate New Pool ❑ Re-enter Suspended Well F-1 Shut in & secure 2. Operator Union Oil of California 4. Current Well Class: 5. Permit to Drill Number: Name: aka Unocal Development F21 Exploratory❑ Stratigraphic❑ Service[—] 1660030 3. Address: 909 West 9th Ave. 6. API Number: Anchorage AK 99501 50-733-10073-00 7. KB Elevation (ft): 9. Well Name and Number: 79' Ba -06 t' 8. Property Designation: - <- 10. Field/Pool(s): BAKER 1 .� C ff MIDDLE GROUND SHOAL ,� f34-- 3,; L 11. Present Well Condition Summary: Total Depth measured 7397 feet Plugs (measured) 7" CIBP at 6,750' true vertical 7392 feet Junk (measured) Effective Depth measured 5,778' feet true vertical 5,777' feet �olapse Casing Length Size MD TVD Burst Structural a Conductor r s V4 Surface Surface 612' 20" 612' 612' Intermediate 2,010' 13 3/8" 2,010' 2,010' 1,130 psi m Production 7,397' 7" 7,397' 7,393' 7,240 psi Vol 0 psi Liner Perforation depth: Measured depth: 5300 to 5330; 5444 to 5481; 5522 to 5548; 5570 to 5635; 5644 to 5720; True Vertical depth: 5298 to 5328; 5438 to 5479; 5520 to 5546; 5567 to 5632; 5641 to 5717; Tubing: (size, grade, and measured depth) LS: 2-7/8", 6.4#, L-80, 0-5,073' SS: 2-3/8", 4.6#, L-80, 0-5,040' Packers and SSSV (type and measured depth) Baker 7" SC -1 L At 5,129' Baker Model D Sump packer @ 5,745' 12. Stimulation or cement squeeze summary: Intervals treated (measured): h SCANNED w Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 42 170 40 60 Subsequent to operation: 0 0 420 on 10/05/03 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory❑ Development Service ❑ 16. We" ^'atus after proposed work: Daily Report of Well Operations Oi' Gas ❑ WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Printed Name P. M. Ayer Title Petroleum Engineer Signature Phone 263-7620 Date 07 Jun 2004 rib S MAY292QtL Form 10-404 Revised 12/2003 �� • Depth 1D OD • Baker �f Long String / Tail Pipe 1 30.72' Well No. 6 Cameron Dual Half, 2-9/16" Tubing Hanger, 2-7/8" 8 rd U N O CAL 76 Top 2 Actual Completion 10/28/97 2.50 3.22 Crossover , 2-7/8" Buttress Box x 2-7/8 rd Pin CASING AND TUBING DETAIL 5,016' 2.44 RKB to TBG Head = 30.72' SIZE WT GRADE CONN ID TOP BTM. 5 20" - 2.87 - 19.124 Surface 612' 2.87 1 Joint, 2-7/8", 6.4#, L-80, Buttress SC Tubimg 7 5,073' 2.43 3.50 Mule Shoe 13-3/8" 54.5 J-55 8 rd 12.615 Surface 2,010' Cameron Dual Half, 2-1/16" Tubing Hanger, 2-3/8" 8 rd 7" 26-23 L-80 BTC 6.276 Surface 7,397' 5,018' 1.37 1.62 Pup, 1-1/4, 2.3#, Lr80, 10 rd Box x Pin A .111 �.^ - '.. c. • ar. a . 1 Gravel Pack Assembly I 5,123' 4.00 5.93 Baker Model SC -Ll Gravel Pack Packer Size 70B4-40 II 5,282' 2.99 4.11 Bakerweld Screen, 3-1/2", .012 Gage ili 5.745' Tubing: 5.63 Baker Model `D' Sumn Packer Size 84-32 • � 1 a"�iii:`��L�/ll' �•��i�l���+jam-l�i'Ftit.. 2-7/8" 6.4 L-80 BTC SC 2.441 30.72' 5,015' � 2-3/8" 4.6 L-80 BTC SC 1.995 30.72' 5,017' 91i imm" 4 5 6 7 I II III NO. Depth 1D OD JEWELRY DETAIL Item Long String / Tail Pipe 1 30.72' Cameron Dual Half, 2-9/16" Tubing Hanger, 2-7/8" 8 rd Top 2 5,015' 2.50 3.22 Crossover , 2-7/8" Buttress Box x 2-7/8 rd Pin 3 5,016' 2.44 2.87 Pup, 6.5#, L-80,.2-7/8" 8 rd Box x Pin 4 5,026' 2.25 5.62 Kobe, 2-1/2", Model "A" Single Parallel Cavity 5 5,040' 2.44 2.87 Crossover, 2-7/8" 8 rd Pin x 2-7/8" Buttress Pin 6 5,041' 2.44 2.87 1 Joint, 2-7/8", 6.4#, L-80, Buttress SC Tubimg 7 5,073' 2.43 3.50 Mule Shoe Short String A 30.72' Cameron Dual Half, 2-1/16" Tubing Hanger, 2-3/8" 8 rd Top B 5,017' 1.62 2.70 Crossover, 2-3/8" Buttress Box x 1-1/4 NU 10 rd Pin C 5,018' 1.37 1.62 Pup, 1-1/4, 2.3#, Lr80, 10 rd Box x Pin ��.. .111 �.^ - '.. c. • ar. a . 1 Gravel Pack Assembly I 5,123' 4.00 5.93 Baker Model SC -Ll Gravel Pack Packer Size 70B4-40 II 5,282' 2.99 4.11 Bakerweld Screen, 3-1/2", .012 Gage ili 5.745' 3.25 5.63 Baker Model `D' Sumn Packer Size 84-32 PBTD = 5,770' TD = 7,397' MAX HOLE ANGLE = 2.4° Ba6Schem Revised 10-28-97.doc DRAWN BY: tcb REVISED: 9/19/97 �i1 - ems-1'*77 ��,,,�,�L',,;r.•• 07 v .i -. • cr. 0 1 ��W��6y1���i�1�Lpi�������:�1�•�����.t����- w,l �iiY�-I��7i-_'.il.. a1ii'�ro�'�i.•�/l'1' ��� �i-� ��.. .111 �.^ - '.. c. • ar. a . 1 �� • � 1 a"�iii:`��L�/ll' �•��i�l���+jam-l�i'Ftit.. �• ISI ����y��-1�:.Fiiil•. a•�/ll' � PBTD = 5,770' TD = 7,397' MAX HOLE ANGLE = 2.4° Ba6Schem Revised 10-28-97.doc DRAWN BY: tcb REVISED: 9/19/97 0 BAKER CLEANING TASK LOO Task Completed Confirmed BY Date By Tom McCaughey 6/28/2003 Rick Lewis Shutdown Wells and Pull Pumps Note. Pull Kobe pumps now, before source water is circulated. If they are circulated out with water, the wells will be very difficult to put on vacuum. Pull pumps one at a time so oil will be replaced with produced water. Tom McCaughey 6/28/2003 Rick Lewis Shut in well B-13 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/29/2003 Rick Lewis Shut in well B-6 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/29/2003 Rick Lewis Shut in well B-5 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/29/2003 Rick Lewis Shut in well B-11 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6x29/2003 Rick Lewis Shut in well B-30 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/29/2003 Rick Lewis Shut in well B-29 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/30003 Rick Lewis Shut in well B-28 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/30/2003 Rick Lewis Shut in well B-25 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/30/2003 Rick Lewis Line up well B-13 to circulate 125 bbls of water down long string and up short string. Once flushed, pull standing valve with wireline. Tom McCaughey 6/30/2003 Rick Lewis Line up well B-6 to circulate 125 bbis of water down long string and up short string. Once flushed, pull standing valve with wireline. Tom McCaughey 6/30/2003 Rick Lewis Circulate B-20 by operating the pump with power water for 50+ bbls. Pull CT Jet pump in Well B-20. Tom McCaughey 7/1/2003 Rick Lewis Circulate Well B-5 one tubing volume of 102 bbis. Pull standing valve in B-5. Tom McCaughey 7/1/2003 Rick Lewis Circulate Well B-11 one tubing volume of 71 bbls. Check for clean returns. Pull standing valve in B-11. Tom McCaughey 7/1/2003 Rick Lewis Circulate Well B-28 one tubing volume of 146 bbis. Pull standing valve in B-28. Tom McCaughey 7/1/2003 Rick Lewis Circulate Well B-30 one tubing volume of 65 bbis. Unable to pull standing valve in B-30. Tom McCaughey 7/1/2003 Rick Lewis Circulate Well B-29 one tubing volume of 140 bbls. Pull B-29 standing valve. Tom McCaughey 7/1/2003 Rick Lewis Circulate Well B-25 one tubing volume of 134 bbis. Check for clean returns. Pull B-25 standing valve. Tom McCaughey 7/1/2003 Rick Lewis Operate Well #31 while metering power fluid for one complete tubing/casing volume of 480 bbis. There is no standing valve so operating the pump will circulate out any power oil remaining in the well. Tum well over to Wireline to pull pump. Tom McCaughey 7/6/2003 Brett Aldridge Blind Well #14 gas in Leg Room 1 to isolate it from the LP Dehy. Rick Lewis 8/24/2003 Rick Lewis Blinded Injection Well B-16 after completing final injection and flush. Note that this information was extracted from the overall Baker Cleaning Task Log by Rich Novcaski 6/10/04. 0 LAST WORK: 10/26/97 Date Finaled 1966 6/13 1967 1-67 7-67 1968 4-23-68 • BAKER PLATFORM API # 50-733-10073-00 MGS ST. 17595 # 6 WELL HISTORY Work Performed COMPLETED AS AN OIL WELL. Perf additional BCD. Prior: 1450 BOPD After: 2000 BOPD Treat with 500 gal. MCA x 30691 SCF N2. Flush with 135889 SCF N2. Killed well with 9.7 PPG CaC12 water. CO to 7000'. Abandon EFG with BP at 6750' capped with 5 sx cement. Attempted to run submersible pump without success. Treat well with 150 barrels diesel with 5 gallons Dowell's W26 per 1000 gallons diesel. Return well to gas lift. After: 738 BOPD x 2 BWPD 5-13-68 Killed well with CaC12 water. Displaced with diesel. Attempted to re -run BJ submersible pump without success. Flush well with 1500 gallons mud acid. Attempted to run submersible again without success. Return to gas lift. After: 599 BOPD x 38 BWPD 1973 5-14-73 Kill well with oil base mud. Perf additional BCD and open A zone. Had to shut-off the sleeve to the A zone due to sand production. Prior: 83 BOPD x 2 BWPD x 363 MCFD After: 706 BOPD x 24 BWPD x 529 MCFD 1997 1/10 Open swab, RIH to 5052' WLM with 2.5" SB pulling tool baited to overshot. Jar for 1 1/2 hours, shear off, POOH. Strip wire, change dogs on pulling tool. RIH to 5,052' WLM, start jarring, open short string to long string to equalize by production. Hit 1700# to 1800# jar licks. Shear off and jar down for 5 minutes, POOH, no movement. 10-2-97 RIH w/2.5 SB baited on overshot to 5052' jar down 20 licks. strip wire, retie, repin tool. RIH to 5052 start jarring, jar for 1 1/2 hours, Shear off, jar down 20 more times. POOH Rig Down, Stand-by Production circulated and spotted acid. Rig back up. RIH to 5052' latch pump and jar for 1 1/2 hours no luck. Shear off POOH. Rig Down. Shut down for night. Start Rig up with braided line, 5 sections lubricator. Change over blocks in BOP for 1/4" line Open swab, stand by to empty lubricator into separator. RIH to 5014' WLM, Hit 2400# jar lick, Hit 3000# jar lick, Hit 3600# jar lick, Hit 3800# Jar lick, Hit 4000# jar lick, came free. POOH. Lift lubricator, pulled pump apart below packer cups. Rig Down 10-3-97 Start Rig up with braided line, 5 sections lubricator. Change over blocks in BOP for 1/4" line Open swab, stand by to empty lubricator into separator. RIH to 5014' WLM, Hit 2400# jar lick, Hit 3000# jar lick, Hit 3600# jar lick, Hit 3800# Jar lick, Hit 4000# jar lick, came free. POOH. Lift lubricator, pulled pump apart below packer cups. Rig Down. 10/17-26 WO - Workover Summary: DAY 1 (10/17/97) SET BPV, NIPPLE DOWN TREE, NIPPLE UP BOPE. SET TWO WAY CHECK, TEST BOPS, LEAKING AROUND HANGERS. DAY 2 (10/18/97) CONT. TEST BOPE. DUAL 2-7/8" X 2-3/8" RAMS LEAKING. OPEN DOORS CHECK RAMS. CHANGE OUT SEALS ON RAM BLOCKS. ANNULAR FAILED. REPLACE WITH DSR'S SHAFFER 13-5/8" 5M. GOOD TEST. RIG UP HYDRAULIC WORKOVER (HWO) UNIT. DAY 3 (10/19/97) CONT. RIG UP HWO UNIT. RIG UP APRS. RIH WITH 1-9/16" TUBING PUNCH AND PERF AT 5,048'. PRESSURE UP AND VERIFY SUCESSFUL PUNC. POOH WITH APRS. DISPLACE TUBING AND ANNULUS WITH FRESH WATER MIXED WITH 3% KCI. PULL TUBING HANGERS AND UNSTING FROM BAKER SC -1 L PACKER. HANG 2-7/8" AND SECURE WITH FLOOR SAFETY VALVE. PULL SHORT STRING AND YIELD 1-1/4" 10 RD CONNECTION ON TOP OF KOBE CAVITY. POOH AND LAY DOWN 2-3/8" SHORT STRING DAY 4 (10/20/97) SLIGHT FLOW FROM WELL. PUMP 20BBL 33# KCI PILL. CONT. POOH WITH SHORT STRING. REPAIR PIPE WINCH HOSE. REPAIR WEATHERFORD DUAL SPIDERS TO PREVENT CRUSHING OF 2-3/8". FULL RECOVERY OF SHORT STRING. SET TEST PLUG, CHANGE TO SINGLE 2-7/8" PIPE RAMS. TEST RAMS. POOH WITH 2-7/8" LONG STRING • 0 DAY 5 (10/21/97) CONT PULL LONG STRING. DROP 16 JOINTS OF LONG STRING, KOBE CAVITY AND TAIL PIPE. ALSO IN HOLE: 1 EA. 2-7/8" LIFT NUBBIN, SHACKLE, SWIVEL AND 250'3/8" CONTERBALANCE CABLE. RIH WITH WIRELINE GRAB (SPEAR WITH BARBS) ON 2-7/8" TUBING. DAY 6 (10/22/97) POOH WITH FISHING ASSEMBLY NO. 1. RECOVER 160'3-8" CABLE. RE -RUN ASSEMBLY. WELL FLOWING WITH ASSEMBLY AT 4,075'. SHUT IN WELL. 45 PSI ON TUBING AND CASING. CIRCULATE 140 BBLS AT 3 BBLS/MIN. THROUGH CHOKE AT 400 PSI HOLDING 150 PSI ON CHOKE. CBU. 0 PSI ON TUBING. SLIGHT FLOW ON ANNULUS. CONTINUE IN HOLE. MIX KCI, WEIGHT UP TO 8.9PPG. DISPLACE WELL OVER TO 8.9PPG CICULATING THROUGH CHOKE TAKING RETURNS TO PRODUCTION. DAY 7 (10/23/97) CONT. CHANGING WELL OVER TO 8.9PPG KCI. WELL DEAD. POOH WITH WIRELINE GRAB. RECOVERED 140'3/8" CABLE (FULL RECOVERY). MAKE UP BHA NO. 3 OVERSHOT "CLUELOW SOCKET". REPAIR WEATHERFOR TONGS. RIH. DAY 8 (10/24/97) CONT. RIH. ENGAGE FISH AT 4,518'. SWALLOW 9' OF FISH. POOH /LAY DOWN FISH (FULL RECOVERY). CHANGE TO 2-7/8" X 2-3/8" DUAL RAMS. TEST SAME. PICK UP BHA. DAY 9 (10/25/97) RIH WITH 2-7/8" X 2-3/8" COMPLETION. SPACE OUT AND LAND DUAL DCB HANGERS. DAY 10 (10/26/97) RIG UP SLICKLINE ON LONG STRING. RIH WITH 2.347 GAUGE RING. RIH TAG CAVITY AT 5,039'. POOH. INSTALL STANDING VALVE IN LONG STRING. BREAK CIRCULATION DOWN LONG STRING TAKING RETURNS UP SHORT. PRESSURE TEST TUBING. PULL LANDING JOINTS. SET BPV'S. RIG DOWN HWO UNIT. NIPPLE DOWN BOP'S. NIPPLE UP TREE. SET TWO WAY CHECKS. TEST HANGER BODY, NECK AND TREE. RELEASE WELL TO PRODUCTION AT 2100 HRS. 1998 06/30/03 Shut in well B-6 and reverse circulate pump to surface. Kill well and pull pump as usual. Line up well B-6 to circulate 125 bbls of water down long string and up short string. Once flushed, pull standing valve with wireline. All casing and tubing valves closed; pipe connections removed and blind flanges installed. Gauges installed to monitor pressure. C� Pertinent Data: MIDDLE GROUND SHOAL ADL 17595 WELL NO. 6 Spud Date: 6-13-66 • Surface Location: Slot 4, Leg 2, 1989' FSL, 588' FWL, Sec. 31, T9N, R12W, S.M. Subsurface Location: 1906' FNL, 737' FWL, Sec. 31, T9N, R12W, S.M. Elevation: 71.36' RKB MSL Total Depth: 7400' Plug Back Depth: 6750' Casing: 20", 79.6# @ 612'w/1 192 sx 13-3/8", 54.5# @ 2010' w/1300 sx 7" 23 x 26# @ 7397' w/1900 sacks 0 0 Initial Potential: FLW 1680 BOPD, 1.9% BS&W @210# FTP GOR 492; Gr. 37 Initial Stimulation: Pfs. 7092 1/2 - 7131 1/2'. FLW test 204 BOPD x GOR 168. Frac w/10000 gallon pad, 9550 gallons CaC12 water containing 60 lbs J-140 gel w/3300 lbs 10-20 sd - flow 1850 BOPD GOR - 64 on 1/4 Ch. Pfs. 6276-6330'. Swb in x flw 1128 BOPD x 0.1% BS&W x GOR 338. Frac w/17700 gallons treated water and 8200 lbs 10-20 sd followed by 27400 gallons water w/4650 lbs 12-20 walnut shells and 11500 lbs Amoco 506 spacer - flow 1585 BOPD, 3 BS&W, GOR 241 @ 275 FTP. Pfs. 6206-6239 1/2'. Test x communicate x perfs 6276 at 400 psi. Frac w/12000 gallons treated water, 8000 lbs 10-20 sd, 32000 gallons treated water x 5000 lbs 12-20 walnut shells x 10000 lbs 12-20 Amoco spacer. Pfs. 6142-6171'. Frac w/16000 gallons treated water, 8000 lbs 10-20 sd, 26000 gallons treated water x 4200 lbs 12-20 walnut shells, x 7450 lbs 12-20 Amoco 506 spacer. MIDDLE GROUND SHOAL ADL 17595 WELL NO.6 Perforation Record: Date Zone Interval 3-66 EFG 7130-31 1/2' 7092 1/2-94' x thru tubing gun in CaC12 water. Perfs in communication. FWL 204 BOPD on 5/8" ch, GOR 168 natural. 3-66 BCD 6276-77 1/2' 6328 1/2-30' x thru tubing gun in CaC12 water. FLW 1128 BOPD x 0.1% BS&W on 1/2" ch, GOR 338 natural. 4-66 BCD 6206-7 1/2', 6238-39 1/2'x thru tubing gun in CaC12 water. In communication with 6276'. No natural test. 4-66 BCD 6142-43 1/2', 6169 1/2-71'x thru tubing gun in CaC12 water. 5-66 BCD 6274-75, 6332-33' 7092-93' x thru tubing gun in well fluid. 1-67 BCD 6274-75', 6332-33', 7092-93'x tubing gun. 1-67 BCD 5795-5805', 5860-70', 5885-95', 5940-50', 5970-80', 6035-40', 6140-45', 6060-70', 6200-10', 6230-40', 6270-80', 6325-35', 6348-53', 6420-25', 6440-45', 6520-30', 6602-07'x thru tubing gun. 4-7 BCD 5782-5805', 5854-5905', 5920-50', 5960-90', 6022-54', 6134-50', 6156-86', 6200-40', 6260-80', 6290-6310', 6325-35', 6348-53', 6420-30', 6434-48', 6508-40', 6602-07'x casing gun in oil base mud. (368'). 4-73 A 5300-30', 5446-81', 5522-48', 5576-5638', 5644-55'x casing gun in oil base mud. I MIDDLE GROUND SHOAL ADL 17595 WELL NO.6 (Continued) Reservoir Data: Zone Depths: A zone: 5300-5740' BCD zone: 5740-6765' EFG zone: 6765-7400' Cored Intervals: A zone: 5602-5628' BCD zone: 5846-5898', 5918-5945', 6123-6179' EFG zone: 7067-7103' DST Intervals and Results: None Selective Tests: As listed above Log Inventory: Open Hole Dual Ind -1-1-8 Sonic Density Prox-M L CBL Temperature ~ STATE OF ALASKA . ' ALAbr~A OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate ~ Plugging m Perforate ~x Pull tubing _~x Alter casing m Repair well m Pull tubing m Other Union Oil Company of California Devel°pmentX-X-' Exploratory __ 3. Address "' Stratigraphic__ P.O. Box 190247, Anch., AK, 99519 Service__ 4. Location of well at sudace Leg # 2, Cohctuctor 1989' FNL & 588' FWL, Sec 31, T9N, R12W, SM At top of prod~l~in~al "A" Zone at 5300' MD 1929' FNL & 676' FWL, Sec 31, T9N, Ri2W, SM Ate:ff,ectivede~_[_T Re_,tai_n__er at 5770' 1915 FNL & 685 FWL, Sec 31, T9N, R12W, SM TD at 7400' MD 768' FWL, Sec 31, T9N, RI2W, SM 1 '6. DatUm elevati(~n (DF or KB) " 101 ' RKB ABOVE MLW'eet '7. Unit or Property name MGS STATE 17595 8. Wellnu No. 6 10. ~,PI nu~b~] _ 10 0 7 3 50-- 11'. Fie~_~:~le Ground Shoal 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 612 ' Conductor Sudace 2 010 ' Intermediate Production Liner 7397 ' Perforation depth: measured true vertical 7,400 ' feet Plugs (measured) 7,396' feet feet Junk (measured) 6,750' feet 6,747' Size 'Cemented 20" 1192 SXS Measured depth True vertical depth 612' 612' 13-3/8" 1300 SXS 2010' 2010' 7" 1900 SXS See attached sheet 7397' ~bing(size. grade, andmeasumddepth) LS: 2-7/8", 6.4#, N-80 Buttress at 5149' SS: 2-3/8" 4 6#, N-80 Buttress at 5075' PackersandSSSV(typeandmeasur~depth) Baker Model "D" pkr @ 5745'; Baker SC-iL pkr @ 5129'; Baker "FVLE" safety valve @ 51( 13. Stimulation or cement squeeze summary Intervals treated (measured) See attached history 14. Treatment description including volumes used and final pressure Represe'~tative Daily Avg. rage Production or Iniection Data' OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation O 210 Subsequent to operation ,,, Tubing Pressure 0 0 0 0 - 715 0 0 Service Drilling Manager Date SUBMIT IN DUPLICATE ' 15. Attachments ' ' 116. Status of well classification as: ' Copies of Logs and Surveys run __ I Daily Report of Well Operations __ Oil ar_ Gas __ Suspended __ 17. I hereby ce'rfi¥ that the f~regoing is true and correct to the b~ of my knowledge. " Gary ~ Bush~ Regional Signed ~~--~. (~ ,~L.Q ~ T',Io SHEET A W~ REC%,..~ PAGE NO. LEASE MGS STATE 17595 WELL NO. 6 SPUD DATE 01/19/91 COMP DATE 2/26/91 FIELD MIDDLE GROUND SHOAL CONTRACTOR PAA RIG NO. 61 LOCATION: LEG #2, CONDUCTOR #4 TYPE UNIT OIME 2000 1989' FNL & 588' FWL, SEC. 31, DRILL PIPE DESCRIPTION 3-1/2" 15.5# E&S TgN, R12W ELEVATIONS WATER DEPTH 102' PERMIT NO. 66-3 SERIAL NO.50-133-10073 RKB TO OCEAN FLOOR 203' TD 7400' TVD 7396' RKB TO ~[LW 101' DEVIATION (BHL) 1906' FNL & 737' FWL RKB TO DRILL DECK 23.16' SEC. 31, T9N, R12W, SM RKB TO PROOU(~ON DECK 39~6 coMp~' ~Im~ER CHUDm~OV, G~UU~ ~U'P~OV~'~ /_~,~_-~, '~,-~oUx HARNESS 0 ~ CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMAP/(S 20 SPIRAL WELD 612' CMT'D W/1192 SXS 13-3/8" 54.5# ST&C 8RD J-55 2010' CMT'D W/1300 SXS 7" 23 & 26# ST&C/LT&C 8RD J-55/N-80 7397' CMT'D W/1900 SXS PERFORATING RECORD DATE 01/29/91 INTERVAL 5300'-5330' 5444'-5481' 5522'-5548' 5570'-5635' 5644'-5720' E.T.D. REASON PRESENT CONDITION 5770'(CMTRET) PRODUCTION "A" ZONE-OPEN(GRAVEL PACK) 5770'(CMT RET) PRODUCTION "A" ZONE-OPEN(GRAVEL PACK) 5770'(CMT RET) PRODUCTION "A" ZONE-OPEN(GRAVEL PACK) 5770'(CMTRET) PRODUCTION "A" ZONE-OPEN(GRAVEL PACK) 5770'(CMTRET) PRODUCTION "A" ZONE-OPEN(GRAVEL PACK) LOWER PERFS ISOLATED BY CMT RETAINER AT 5770' (SEE ATTACHED PERF RECORD) INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS WELL HEAD ASSEMBLY TYPE: CAMERON IRON WORKS/FMC CASING HEAD: 20" SOW X 20" 2M HOUSING W/13-3/8" CSG PREP CASING SPOOL: 20" 2M X 12" 3M SPOOL W/9-5/8" CSG PREP TUBING HEAD: 12" 3M X 7" 5M DCB SPOOL W/2 EA 2" 5M OUTLETS TUBING HANGER: 2-7/8" X 2-3/8" NOMINAL DUAL SPLIT HANGERS, CS HYDRIL-UP, BUTTRESS-DOWN TUBING HEAD TOP: 7" 5M (RX-46) MASTER VALVES: 2-7/8" X 2-3/8" 5M DUAL BLOCK MASTER VALVe.J/, MGS 17595 #6 PERFORATION RECORD ( 3/6/91 ) "A" ZONE 5300'- 5330' MD 5444'- 5481' MD 5522'- 5548' MD 5570'- 5635' MD 5644'- 5720' MD 5298'- 5327' TVD 5441'- 5478' TVD 5519'- 5545' TVD 5573'- 5433' TVD 5641'- 5717' TVD GRAVEL PACKED-OPEN GRAVEL PACKED-OPEN GRAVEL PACKED-OPEN GRAVEL PACKED-OPEN GRAVEL PACKED-OPEN "B,C,D" ZONES 5782'- 5805' MD 5850'- 5910' MD 5925'- 6000' MD 6020'- 6055' MD 6130'- 6240' MD 6260'- 6360' MD 6420'- 6460' MD 6490'- 6540' MD 6601'- 6607' MD 7092.5'- 7094' MD 7130'- 7131.5' MD 5779'- 5802' TVD 5847'- 5907' TVD 5922'- 5997' TVD 6017'- 6052' TVD 6127'- 6237' TVD 6257'- 6356' TVD 6416'- 6456' TVD 6486'- 6536' TVD 6597'- 6603' TVD 7088.5'- 7090' TVD 7125'- 7126.5' TVD "B, C & D" ZONES PERFS ISOLATED BY RETAINER AT 5770' PLATFORM BAKER 17595 WELL #6 (BA-6) WELL HISTORY DATE MW ETD COMMENTS 01/19/9i 64 PCF 6750' COMMENCED. OPERATIONS ON WELL ADL 1.7..595 #6, LEG #2. SLOT #4. BAKER PLATFORM. SKID RIG FROM LEG #4 TO LEG #2, SLOT #4. MODIFIED STAIRS TO RIG FLOOR. RIGGED UP MUD AND SERVICE LINES. PRODUCTION COULD NOT UNSEAT THE PUMP WITH POWER OIL. RIGGED UP OTIS SLICKLINE UNIT AND TESTED LUBRICATOR. RAN IN AND LATCHED PUMP. JARRED PUMP OUT OF BHA. PULLED PUMP OUT OF THE HOLE WITH 500 TO 900# OF DRAG. RAN IN WITH PRONG TO SHEAR KNOCKOUT PLUGS TO EQUALIZE ACROSS THE STANDING VALVE. 01/20/91 64 PCF 6750' COMPLETED TRIP TO EQUALIZE ACROSS THE STANDING VALVE. MADE A SECOND TRIP TO RECOVER THE STANDING VALVE. RIGGED DOWN OTIS SLICKLINE. KILLED WELL BY PUMPING THE FOLLOWING FLUIDS: CIRCULATED FIW DOWN THE LONG STRING TAKING RETURNS TO PRODUCTION FROM CASING/TUBING ANNULUS UNTIL RETURNS WERE CLEAN; PUMPED DOWN THE LONG STRING TAKING RETURNS TO PRODUCTION UP THE SHORT STRING; BULL HEADED 12 BBLS DOWN THE LONG STRING TO CLEAR THE RAT HOLE. INSTALLED BACK PRESSURE VALVES IN THE TUBING HANGER. REMOVED PRODUCTION TREE. INSTALLED BOPE. MODIFIED THE FLOW LINE. PULLED BACK PRESSURE VALVES. RIGGED UP SLICKLINE. SET A "G" TUBING STOP AND PLUG IN THE LONG STRING. ATFEMPTED TO SET A "G" TUBING STOP IN THE SHORT STRING. 01/21/91 64 PCF 6750' MADE SEVERAL ATFEMPTS TO SET "G" STOP IN THE SHORT STRING. IT APPEARED TO SET. ATTEMPTED TO SET PLUG ON TOP, BUT "G" STOP HAD MOVED DOWN HOLE. FOUND "G" STOP AT 1500' WLM. RECOVERED AND SET "G" STOP AT 70' WLM. SET PLUG ON TOP. RIGGED DOWN WIRELINE. BEGAN BOPE TEST AND SHORT STRING WOULD NOT HOLD PRESSURE. TESTED BOPE SHELL, UPPER PIPE RAMS, AND CHOKE MANIFOLD TO 500 PSI (LOW) AND 3500 PSI (HIGH). TESTED ANNULAR-PREVENTER TO 500 PSI (LOW) AND 2500 PSI (HIGH). RIGGED UP WIRELINE AND RECOVERED PLUGS AND "G" STOPS FROM BOTH TUBING STRINGS. RIGGED DOWN SLICK LINE. RIGGED UP ELECTRIC LINE AND MADE 1-13/16" GAUGE CUTFER RUN TO 5730' WLM. TRIP FOR 1- 13/16" JET CUTTER. CUT SHORT STRING AT 5720' WLM. RIGGED DOWN ELECTRIC LINE. PULLED 2- 3/8" SHORT STRING HANGER ABOVE ROTARY TABLE. FOUND THE FIRST COLLAR BELOW THE HANGER SEVERELY CORRODED AND THE FIRST JOINT OF TUBING HAD A HOLE. CIRCULATED WELL TO BALANCE THE FLUID. PULLED AND LAID DOWN 186-1/2 JOINTS OF 2-3/8" SHORT STRING DATE MW ETD 01/21/91 (CONT). 01/22/91 64 PCF 01/23/91 64 PCF PLATFORM BAKER 17595 WELL #'6 (BA-6) WELL HISTORY PAGE 2 COMMENTS TUBING. WELL WAS TAKING 50 BPH flW. MIXED A SIZED SALT PILL TO CONTROL FLUID LOSS. 6750' FINISHED MIXING SIZED SALT PILL. PUMPED PILL DOWN THE LONG STRING INTO THE "B, C & D" ZONE PERFORATIONS. FLUID LOSS REDUCED TO 5 BPH. PULLED AND LAID DOWN 2-7/8" LONG STRING, NATIONAL CAVITY, AND TAIL ASSEMBLY. APPROXIMATELY 50% OF THE TAIL HAD MODERATE TO HEAVY SCALE BUILDUP ON THE OUTSIDE. CHANGED TOP PIPE RAMS TO 3-1/2" AND FUNCTION TESTED SAME. MADE UP A USED 5-7/8" BIT BELOW A 7" SCRAPER AND RAN IN TO 2100' PICKING UP 3-1/2" DRILL PIPE. CIRCULATED WELL CLEAN. TRIP FOR RETRIEVABLE BRIDGE PLUG. RAN IN WITH PLUG AND ATTEMPTED TO SET AT 1965' DPM-NO SET. PULLED UP TO 1870' DPM AND SET PLUG. TESTED PLUG TO 2500 PSI. SANDED OUT TOP OF PLUG WITH 5 FT3 FRAC SAND AND PULLED OUT OF HOLE. RAISED BOPE AND REMOVED 13-5/8" 3M X 7-1/16" 5M NATIONAL TUBING SPOOL. 6750' FINISHED REMOVING NATIONAL TUBING SPOOL. FOUND TOP OF 7" CASING HAD CORRODED IN PLACES, LEAVING A 3-1/8" CUT OFF LENGTH INSTEAD OF THE REQUIRED 4" MINIMUM. CAMERON "X" BUSHING WOULD NOT SEAL ON THE REMAINING CASING STUB. RIGGED TO PICKUP 7" CASING TO EXPOSE ENOUGH GOOD PIPE TO PROVIDE A SEAL SURFACE FOR THE TUBING SPOOL. INSTALLED A STRONG BACK ON TOP OF THE 7" CASING SLIPS TO ALLOW THE BOPE. STACK WEIGHT TO HOLD THEM IN PLACE. MADE UP TRI-STATE CASING SPEAR AND LATCHED 7" CASING AT 50' FT. PULLED CASING UP 2" WITH 225 K OVERPULL. RELEASED SPEAR AND PICKED UP THE STACK. REDRESSED THE CASING STUB. (NOTE: THERE IS STILL A SPOT 1.5"W X 6" L THAT HAS MATERIAL LOSS FROM THE ID). INSTALLED CAMERON 13-5/8"3 M X 7-1/16"5 M DCB TUBING SPOOL. PRESSURE TESTED APl RING AND SECONDARY SEAL TO 2500 PSI. NIPPLED UP BOPE. WORKED ON A HYDRAULIC LEAK ON THE ANNULAR PREVENTER. INSTALLED THE BELL NIPPLE, FLOW LINE, AND MISCELLANEOUS SERVICE LINES. PREPARE TO TEST THE BOPE. PLATFORM BAKER 17595 WELL #6 (BA-6) WELL HISTORY PAGE 3 DATE MW ETD COMMENTS 01/24/91 64 PCF 5770' PRESSURE TESTED BOPE AS FOLLOWS: RAM PREVENTERS, CHOKE MANIFOLD, AND ALL VALVES TO 500 PSI (LOW)AND 3000 PSI (HIGH); PRESSURE TESTED ANNULAR PREVENTER TO 2500 PSI. RAN IN WITH BRIDGE PLUG RETRIEVING TOOL. CIRCULATED OUT SAND AND LATCHED PLUG AT 1867' DPM. PULLED OUT AND LAID DOWN RETRIEVABLE BRIDGE PLUG. RAN IN WITH 5-7/8" BIT AND CASING SCRAPER PICKING UP 3-1/2" DRILL PIPE TO 6000' DPM. CIRCULATED WELL CLEAN. PULLED OUT AND LAID DOWN BIT AND SCRAPER. RIGGED UP WIRELINE. RAN IN WITH CBL AND SET DOWN AT 5797' WLM. TIED INTO GAMMA RAY CURVE ON 5" FDC LOG DATED 3-12- 66. ATTEMPTED TO WORK LOG DEEPER-NO GOOD. RAN HLS ACOUSTIC CEMENT BOND LOG FROM 5790' TO 2510' D~L. RIGGED DOWN WIRELINE. MADE UP BAKER "N-l" DRILLABLE BRIDGE PLUG AND RUNNING TOOL. RAN IN, SPACED OUT, AND SET BRIDGE PLUG AT 5770' DPM ON 3-1/2" DRILLPIPE. RIGGED UP TO PRESSURE TEST THE BRIDGE PLUG. 01/25/91 72 PCF 5770' PRESSURE TESTED THE BRIDGE PLUG AT 5770' DPM AGAINST THE TOP PIPE RAMS TO 1000 PSI. TRIP FOR BAKER "RETRIEVAMATIC" SQUEEZE PACKER. RAN IN AND SET PACKER AT 5676' DPM. PRESSURE TESTED BRIDGE PLUG AT 5770' TO 3000' PSI. PULLED TO 5250' DPM AND RESET PACKER. PRESSURE TESTED THE ANNULUS TO 3000 PSI. PRESSURE TESTED SQUEEZED "A" ZONE PERFORATIONS FROM 5300' TO 5855', AT INTERVALS TO 1500 PSI THROUGH THE PACKER. RELEASED PACKER AND PULLED OUT OF HOLE. MADE UP CASING SCRAPER AND WIRE BRUSH. RAN IN HOLE PICKING UP 2-7/8" BUTTRESS TUBING TO 5762' TM. DISPLACED HOLE WITH CLEAN FIW TAKING RETURNS TO PRODUCTION. PUMPED A 100 BBL SWEEP CONTAINING 1 DRUM OF DIRT MAGNET. CHANGED OVER TO 72 PCF BRINE (FIW WEIGHTED WITH NACL). CIRCULATED AND FILTERED BRINE. PLATFORM BAKER 17595 WELL #6 (BA-6) WELL HISTORY PAGE 4 DATE MW ETD 01/26/91 76 PCF 5770' COMMENTS CONTINUED TO CIRCULATE AND FILTER FLUID. TRIP FOR PERFORATING ASSEMBLY. MADE UP TEST HEAD AND LAID DOWN SAME. MADE UP PERFORATING ASSEMBLY AND RAN IN HOLE. RIGGED UP SURFACE LINES AND PRESSURE TESTED THE SAME TO 3000 PSI. SHOT A FLUID LEVEL TO CONFIRM THE UNDERBALANCE IN THE TUBING. RIGGED UP WIRELINE FOR CORRELATION LOG. PLACED GUNS ON DEPTH AND SET PERFORATING PACKER. RAN CONFIRMATION LOG (CORRELATE TO FDC DATED 3/12/66). RIGGED DOWN WIRELINE. RIGGED UP SHOT DETECTION EQUIPMENT. OPENED THE OMNI VALVE WITH 1500 PSI ANNULUS PRESSURE. PRESSURED TO 2300 PSI TO FIRE THE PERFORATING GUNS AT 1445 HOURS. PERFORATED LOWER "A" ZONE AS FOLLOWS: 5522'-5548' DIL; 5570'-5635' DIL; 5644'- 5720' DIL WITH 25 GRAM AT 12 HPF (6 HPF "BIG HOLE" AND 6 HPF "DEEP PENETRATOR"). CYCLED THE OMNI VALVE TO THE REVERSING POSITION AND REVERSED THE DRILL PIPE CLEAN (SOME OIL TO SURFACE). CIRCULATED AND BALANCED FLUID AT 72 PCF. CYCLED THE OMNI VALVE OPEN AND HAD 200 PSI SURFACE PRESSURE. RELEASED THE PACKER AND CIRCULATED AROUND 72 PCF FLUID TO BALANCE THE WELL. SHUT-IN DRILL PIPE PRESSURE STABILIZED AT 150 PSI. BUILT 200 BBLS OF 76 PCF NACL/NABR BRINE. CIRCULATED AROUND 76 PCF FLUID. CHECK FOR FLOW-WELL STATIC. 01/27/91 76 PCF 5770' PULLED OUT AND LAID DOWN PERFORATING ASSEMBLY (ALL SHOTS FIRED). RAN IN WITH OEDP TO 5770' DPM. CIRCULATED THE WELL CLEAN. MIXED 47 FT3 OF 20-40 OTFAWA GRAVEL IN FILTERED FLUID AT 8#/GAL AND SPOTTED ON BOTFOM. PULLED TO 5525' DPM AND WORKED PIPE WHILE ALLOWING THE SAND TO SETTLE. RAN IN AND TAGGED PLUG AT 5624' DPM. CIRCULATED OUT SAND TO 5655' DIL (5661' DPM). CIRCULATED AND FILTERED FLUID TO 40 NTU'S AT FLOWLINE. TRIP FOR FRAC PACKER. RAN IN AND SET PACKER AT 5499' DPM. RIGGED UP SURFACE LINES. DATE 01/28/91 PLATFORM BAKER 17595 WELL #6 (BA-6) WELL HISTORY PAGE 5 MW ETD COMMENTS 78 PCF 5770' CONTINUED TO RIG UP SURFACE LINES. PRESSURE TESTED SURFACE EQUIPMENT TO 6500 PSI. DISPLACED THE TUBING WITH 3% AMMONIUM CHLORIDE WATER WITH I GAL/1000 GAL FRW-13 (FRICTION REDUCER). CLOSED BYPASS AND ESTABLISHED AN INJECTION RATE OF 12.5 BPM AT 3700 PSI. MIXED 60 BBL OF GELLED AMMONIUM CHLORIDE WATER WITH BREAKER. INJECTED 38 BBLS BRINE AND 11 BBLS GELLED BRINE AT 12.5 BPM AT 3900 PSI. LEFT TUBING AND RAT HOLE FULL OF GELLED 3% AMMONIUM CHLORIDE BRINE. MIXED SAND SLURRY FOR FRAC. PUMPED FRAC JOB AS FOLLOWS: 198 BBLS GELLED 3% AMMONIUM CHLORIDE PRE-PAD AT 11.5 BPM AT 4400 PSI; 79 BBLS GELLED 3% AMMONIUM CHLORIDE WITH 8#/GAL 20-40 OTFAWA GRAVEL. SCREENED OUT AT A MAXIMUM SURFACE PRESSURE OF 6500 PSI. CALCULATED SAND OUTSIDE PERFORATIONS WAS 138 CU FT (13,800#). SLOW PRESSURE BLEED OFF FROM 4500 PSI TO 1000 PSI. OPENED THE TUBING TO THE OVERBOARD LINE WITH 1500 PSI ON THE ANNULUS AND OPENED THE PACKER BYPASS TO REVERSE OUT THE EXCESS SAND. REVERSED OUT TWO TUBING VOLUMES. PULLED PACKER LOOSE TO CONFIRM TUBING WAS FREE AND REVERSED ONE MORE TUBING VOLUME. SHUT-IN WELL TO ALLOW PRESSURE TO DISSIPATE. PRESSURE BLED FROM 500 PSI TO 340 PSI IN TWO HOURS. BLED 10 BBLS FROM TUBING AND SHUT- IN PRESSURE WAS 50 PSI. CIRCULATED TWO HOLE VOLUMES ON THE CHOKE HOLDING CONSTANT BOTTOM HOLE PRESSURE. SHUT-IN PRESSURE WAS 100 PSI. INCREASED BRINE WEIGHT TO IN ACTIVE SYSTEM TO 78 PCF WITH NABR. CHANGED WELL OVER TO 78 PCF BRINE. CHECKED FOR FLOW-WELL STATIC. TRIPPED FOR OEDP. RAN IN TO 5495' DPM AND CIRCULATED AND FILTERED FLUID FOR PERFORATING RUN. PULLED OUT OF HOLE. RIGGED UP TO PICK UP PERFORATING ASSEMBLY. DATE MW 01/29/91 78 PCF PLATFORM BAKER 17595 WELL #6 (BA-6) WELL HISTORY PAGE 6 ETD COMMENTS 5770' PICKED UP PERFORATING ASSEMBLY FOR UPPER "A" ZONE. RAN IN WITH TCP GUNS FILLING PIPE WITH COMPLETION FLUID FOR A 500 PSI UNDERBALANCE. RIGGED UP SURFACE EQUIPMENT AND WIRELINE LOGGING UNIT. PRESSURE TESTED SURFACE EQUIPMENT TO 3000 PSI. RAN GAMMA RAY CORRELATION LOG AND TIED GUNS IN WITH DIL USING AN FDC LOG DATED 3/12/66. SET PACKER AND RERAN CORRELATION LOG. RIGGED DOWN WIRELINE. SHOT A FLUID LEVEL TO CONFIRM THE UNDERBALANCE. INSTALLED SHOT DETECTION EQUIPMENT. CYCLED THE OMNI VALVE OPEN AND PRESSURED THE ANNULUS TO 2300 PSI TO FIRE THE GUNS. PERFORATED THE UPPER "A" ZONE AS FOLLOWS: 5300'-5330' DIL; 5444'-5481' DIL WITH 25 GRAM AT 12 HPF (6 HPF "BIG HOLE" AND 6 HPF "DEEP PENETRATOR"). CYCLED THE OMNI VALVE TO THE REVERSING POSITION AND REVERSED THE DRILL PIPE CLEAN. CYCLED THE OMNI VALVE OPEN AND REVERSED THE WELL THROUGH THE RI-rs BYPASS. MONITOR WELL-STATIC. CIRCULATED THE SYSTEM THROUGH THE FILTER WHILE BUILDING 50 BBLS OF BRINE. PULLED OUT AND LAID DOWN PERFORATING ASSEMBLY (ALL SHOTS FIRED). RAN IN AND TAGGED FILL AT 5564' DPM. PULLED TO 5532' DPM AND CIRCULATED WELL CLEAN. SPOTTED 20 CU FT FRAC SAND THROUGH OEDP AT 5532' DPM. PULLED TO 5448' DPM AND WORKED PIPE WHILE SAND SETTLED. TAGGED SAND PLUG AT 5487' DPM. WASHED DOWN TO 5500' DPM AND CIRCULATED WELL CLEAN. CIRCULATED AND FILTERED FLUID TO 78 NTU'S AT THE FLOW LINE. TRIP FOR FRAC PACKER. 01/30/91 78 PCF 5770' MADE UP FRAC PACKER AND RAN IN HOLE TO 5275' DPM. RIGGED UP SURFACE LINES AND TESTED TO 3000 PS1. SET PACKER AND ATTEMPTED TO PRESSURE TEST ANNULUS-NO GOOD. PICKED UP 7' AND ATTEMPTED TO RETEST-NO GOOD. PULLED ONE STAND AND ATTEMPTED TO RETEST-NO GOOD. TRIP TO CHECK PACKER. CHANGED OUT R~-FS BYPASS VALVE. RAN IN TO 1865' DPM AND ATTEMPTED TO TEST PACKER-NO GOOD. PULLED OUT AND CHECKED DRILL COLLARS. RAN IN TO 1865' DPM USING DIFFERENT TUBING AND ATTEMPTED TO TEST PACKER-NO GOOD. CONTINUED IN TO 5275' DPM (TAIL AT 5286' BPM). ATTEMPTED TO SET PACKER-NO GOOD. RESET PACKER AND TESTED BACKSIDE TO 2500 PSI. HELD SAFETY MEETING. TESTED PUMPS AND SURFACE LINES TO 8000 PSI. SPOTTED 30 BBLS 3% NH4CL/FIW BRINE WITH 1 GAL FRW13/1000 GAL TO TOOLS THROUGH THE BYPASS. CLOSED BYPASS AND ESTABLISHED AN INJECTION RATE OF 15.2 BPM AT 4250 PSI WITH 30 BBLS OF FLUID. MIX FRAC SAND. PUMPED DATE MW 01/31/91 PLATFORM BAKER 17595 WELL #6 (BA-6) WELL HISTORY PAGE 7 ETD COMMENTS FRAC JOB AS FOLLOWS: 134 BBLS 3% NH4CI/FIW BRINE GELLED WITH 70# HEC/1000 GAL AT 15 BPM WITH 4200 PSI; 53 BBLS 8#/GAL 20-40 Oq-TATA GRAVEL SLURRY. JOB SANDED OUT (36 CU FT OUTSIDE PERFORATIONS) WITH 6800 PSI. 02/01/91 02/02/91 77 PCF 76 PCF 5770' 5770' REVERSED EXCESS SAND OUT OF THE TUBING.REVERSED ONE ADDITIONAL TUBING VOLUME OVER THE SHAKERS. SHUT WELL IN AND WAITED FOR PRESSURE TO DISSIPATE, BUILT ACTIVE SYSTEM BACK UP TO 78 PCF WITH NABR (CUT TO 74 PCF). REVERSED WELL CLEAN AND PULLED OUT WITH TIE FRAC ASSEMBLY. LAID DOWN THE FRAC ASSEMBLY AND MADE UP A 5- 7/8" BIT ON DRILL COLLARS. RAN IN HOLE AND TAGGED SAND AT 5371' DPM. CLEANED OUT SAND TO 5770' DPM ETD (BRIDGE PLUG). CIRCULATED THE WELL CLEAN AND PULLED OUT OF HOLE. TESTED BOPE TO UNOCAL SPECIFICATIONS. ADDED A CASING SCRAPER TO THE CLEAN OUT ASSEMBLY AND RAN IN HOLE. TAGGED SAND AT 5764' DPM AND CLEANED OUT TO 5770' DPM. CIRCULATED OUT SAND. CIRCULATED AND FILTERED FLUID FOR THE GRAVEL PACK. TRIP FOR SUMP PACKER. MADE UP 7" BAKER MODEL "D" GRAVEL PACK SUMP PACKER ON 3-1/2" DRILL PIPE. RAN IN HOLE AND SET PACKER AT 5745' DIL (5751' DPM). MADE UP 4.11" OD BAKERWELD GRAVEL PACK LINER AND TOOLS. RAN IN HOLE ON 2-7/8" TUBING AND LATCHED INTO THE SUMP PACKER AT 5751' DPM. PULLED OUT AND SPACED OUT TUBING AT SURFACE. LATCHED BACK INTO THE SUMP PACKER. BROKE CIRCULATION AND DROPPED THE SETTING BALL. WAITED 30 MINUTES FOR THE BALL TO SETTLE. SET 7" BAKER SC- 1L GP PACKER (70 B4-40) ON TOP OF THE LINER AT 5133' DPM. SCREEN SECTION FROM 5739'-5288' AND BLANK FROM 5288' TO 5163'. TESTED PACKER FROM THE BACKSIDE TO 1000 PSI. LOCATED AND MARKED THE VARIOUS POSITIONS ON THE GRAVEL PACK TOOLS. ESTABLISHED RATES AND PRESSURES. STARTED TO PUMP GRAVEL PACK AT 1919 HOURS. PUMPED AS FOLLOWS: 10 BBL PREPAD; 35 BBL SLURRY WITH 100 FT3 20-40 GRAVEL; 5 BBL POST PAD; DISPLACED WITH COMPLETION FLUID. SCREENED OUT AT 15.75 BBLS DISPLACEMENT. PLACED 74 FT3 OF GRAVEL BEHIND THE SCREEN (110% THEORETICAL). FINAL PACK PRESSURE WAS 1700 PSI. REPRESSURED PACK TWICE TO 1700 PSI. REVERSED OUT EXCESS GRAVEL. PULLED UP HOLE 80' AND ALLOWED PACK TO SETTLE. DATE MW 02/02/91 (CONT) PLATFORM BAKER 17595 WELL #6 (BA-6) WELL HISTORY PAGE 8 ETD COMMENTS REARRANGED DRILL PIPE IN DERRICK TO ACCOMODATE TUBING WHILE PACK WAS SETTLING. 02/03/91 75 PCF 02/04/91 76 PCF 02/05/91 74 PCF 02/06/91 74 PCF 5770' 5770' 5770' 5770' FINISHED REARRANGING DRILLPIPE. RETESTED GRAVEL PACK. PULLED OUT OF HOLE AND LAID DOWN GRAVEL PACK TOOLS. RIGGED UP WIRELINE. RAN GRAVEL PACK EVALUATION LOG. TOP OF GRAVEL IS IN THE SECOND BLANK JOINT FROM THE TOP AT 5224'. NO VOIDS IN THE PACK. PULLED OUT AND RIGGED DOWN WIRELINE. WAITING ON 2-3/8" TUBING TO BE DELIVERED. ALASKA HUSKY WORKBOAT HAD MECHANICAL PROBLEMS. LAID DOWN EXCESS 2-7/8" TUBING AND PERFORMED RIG MAINTENANCE WHILE WAITING ON TUBING. OFFLOAD TUBING. RAN IN HOLE PICKING UP 2-3/8", 4/6#, N-80 TUBING. FINISH RUNNING IN PICKING UP 2-3/8" TUBING. PULLED OUT OF HOLE STANDING BACK TUBING FOR THE PRODUCTION COMPLETION. CHANGED TOP PIPE RAMS TO DUAL 2-7/8" X 2-3/8" RAM BLOCKS. RIG UP FLOOR TO RUN DUAL COMPLETION. WAITED TWO HOURS FOR KOBE CAVITY TO BE DELIVERED. TESTED CAVITY WITH DUMMY PUMP AND STANDING VALVE IN PLACE TO 5000 PSI. PULLED PUMP AND STANDING VALVE. ATTEMPTED TO PLUG TEST CAVITY AND FOUND WRONG THREAD ON SHORT STRING PUP JOINT. DOWN FIVE HOURS TO HAVE A CROSSOVER MADE. PLUG TESTED CAVITY. STARTED RUNNING DUAL 2-3/8" X 2-7/8" PRODUCTION COMPLETION HYDROTESTING TO 5000 PSI. FINISHED RUNNING DUAL 2-3/8" X 2-7/8" PRODUCTION COMPLETION ASSEMBLY. HAD TO SPACE OUT TWICE. LANDED TUBING WITH TAIL AT 5149' TM AND KOBE CAVITY AT 5075' TM. ENTIRE COMPLETION WAS HYDROTESTED TO 5000 PSI. BOTH TIMES THE CiW HANGER WENT INTO THE BOWL THE SEALS WERE DAMAGED. DOWN AT 1700 HOURS WAITING FOR SEALS TO BE DELIVERED FROM THE LOWER 48. TESTED PACKER AGAINST THE PIPE RAMS TO 1000 PSI. RIG CREWS PERFORMING RIG MAINTENANCE AND GENERAL CLEAN UP. PERFORMED GENERAL RIG MAINTENANCE AND PLATFORM CLEANUP WHILE WAITING ON REPLACEMENT SEALS FOR THE ClW DUAL SPLIT HANGERS. DATE MW 02/07/91 02/08/91 PLATFORM BAKER 17595 WELL #6 (BA-6) ..... WELL HISTORY PAGE 9 ETD COMMENTS 74 PCF 5770' CONTINUED TO WAIT ON HANCaERS SEALS. SEALS ARRIVED ON PLATFORM AT 0300 HOURS. REDRESSED HANGERS WITH NEW SEALS. LOWERED HANGERS INTO THE DCB SPOOL BOWL PREPARATION AND RAN IN THE HOLD DOWN PINS. PACKED OFF THE HANGERS. PRESSURED 7" CASING x TUBING ANNULUS TO 1000 PSI AND FLUID LEAKED BY THE HANGERS. PREPARED TO RAISE THE BOP STACK TO CHECK TH~S. WHILE ATTEMPTING TO PICKUP THE STACK ONE OF THE BRIDGE CRANES FAILED. REPAIRED BRIDGE CRANE WITH PARTS FROM PLATFORM BRUCE. PICKED UP AND SECURED STACK. INSTALLED NEW SEALS, LOWERED INTO PLACE, RAN IN HOLD DOWN PINS, AND ENERGIZED SEALS WITH PLASTIC PACKING. ATTEMPTED TO TEST SEALS TO 3300 PSI-FLUID LEAKING BY THE HANGERS. REPLACED SEALS AND ATTEMPTED TO ENERGIZE SAME WITH CAMERON PLASTIC PACKING. PRESSURE TESTED AND SEALS LEAKED. NIPPLED DOWN ROPE AND RISER. 74 PCF 5770' NIPPLED UP DUAL TREE. PACKED OFF HANGER AND VOID AT TREE CONNECTION WITH PLASTIC. PRESSURE TESTED ON TOP OF HANGER AT THE TEST PORT FOR THE TREE CONNECTION TO 5000 PSI. A3-FEMPTED TO TEST ANNULUS TO 3300 PSI AND HAD COMMUNICATION PAST THE HANGERS. INSTALLED TWO WAY CHECKS IN THE TUBING STRINGS. PRESSURE TESTED AGAINST THE CHECKS TO 5000 PSI. PULLED CHECKS AND INSTALLED BACKPRESSURE VALVES. ~ OPERATIONS ON ADL 17595 #6 (BA-6) AT 0600 HRS ON 2/8/91, RESUMED OPERATIONS ON ADL 17595 #6 (BA-6) AT 2100 HOURS ON 2/8/91. SKID RIG BACK OVER BA-6 AND RIG UP OTIS SLICKLINE UNIT. PRESSURED TESTED LUBRICATOR TO 1000 PSI. RAN IN WITH 2-7/8 .... RA" PLUG AND SET SAME IN SLEEVE AT 5097' TM. PULLED OUT AN RIGGED DOWN WIRELINE. 02/09/91 74 PCF 5770' FINISHED RIGGING DOWN OTIS SLICKLINE UNIT. INSTALL BACKPRESSURE VALVE IN THE LONG STRING. PREP TO SKID RIG TO BA-27. ~ OPERATIONS ON ADL 17595 #6 AT 0130 HOURS ON 2/8/91. PLATFORM BAKER 17595 WELL #6 (BA-6) WELL HISTORY PAGE 10 DATE MW 02/22/91 ETD 73 PCF 5700' 02/23/91 75 PCF 5770' COMMENTS-- SKID RIG FROM BAKER ~27 TO BAKER ~ AT 061313__ HRS 2/22/91. REMOVED PRODUC ION MANIFOLD. CHECKED BPV'S-NO PRESSURE. REMOVED TREE, AND INSTALLED BOPE. CHANGED TOP RAMS TO 2-3/8" X 2-7/8" DUAL. PULLED BPV'S AND INSTALLED 2 WAY CHECK VALVE IN S.S. AND LANDING JT IN L.S. TESTED BOPE TO 3000 PSI. REMOVED 2 WAY CHECK VALVE F/S.S. RIH W/OTIS EQUALIZING PRONG TO R.A. PLUG AT 5097' TM- EQUALIZING AGAINST PLUG. TRIP FOR=PULLING TOOL AND RETRIEVED R.A. PLUG. PULLED DUAL HANGERS TO RIG FLOOR AND INSPECT WITH CIW REPRESENTATIVE. RECOMMENDED TO CHANGE TBG SPOOL. CIRC AND ATTEMPT TO KILL WELL-WELL FLOWING SLIGHTLY. HAD MAXIMUM SHUT-IN PRESSURE OF 50 PSI. CIRC AND INCREASED MUD WT F/73 PCF TO 75 PCF WITH CACI2. WELL WAS DEAD. POOH WITH DUAL COMPLETION. INSTALL TEST PLUG AND PREP TO CHANGE RAMS. 02/24/91 75 PCF 5770' INSTALLED TEST PLUG AND CHANGED BTM PIPE RAMS TO 2-7/8". TESTED RAMS TO 500 PSI AND 3000 PSI. PULLED TEST PLUG. SET HOWCO RBP AT 2512' DPM. TEST RBP TO 3000 PSI. P.U. BCE AND CHANGED OUT CIW DCB SPOOL. INSTALLED AND TESTED BCE TO 3000 PSI. LAND NEW HANGERS IN SPOOL. LOCKED DOWN AND PACKED OFF TO 100 FT- LBS-OK. CIW RECOMMENDED TO NOT PRESSURE TEST HANGERS BELOW AS THEY COULD DEFORM THE LOCK DOWN HOLES AND DAMAGE THE SPOOL. PULLED HANGERS-OK, RIH AND RETRIEVED RBP. WELL BEGAN TO TAKE FLUID. SURFACE TESTED KOBE BHA TO 5000 PSI. R.U. AND RAN 2-3/8" x 2-7/8" DUAL COMPLETION. 02/25/91 75 PCF 5770' CONTINUED TO RUN DUAL 2-3/8" x 2-7/8" COMPLETION. INSTALLED TBG HANGERS AND LANDED SAME WITH MULE SHOE AT 5149' TM, LOCATOR AT 5138', KOBE CAVITY AT 5075'. TEST HANGERS AND SEALS TO 2000 PSI-OK. R.U. OTIS W.L. AND INSTALLED STANDING VALVE IN KOBE CAVITY. RIH WITH DUMMY PUMP-HAD TO PUMP IT DOWN. TEST AGAINST DUMMY PUMP-OK. PULLED PUMP AND STANDING VALVE. INSTALL BPV'S. REM. BCE. INSTALLED AND TESTED TREE. RIH TO SHIFT RA SLEEVE. 02/26/91 63 PCF 5770' OPENED RA SLEEVE AT 5097' TM. DISPL S.S. W/FIW AND NALCO 3900 PACKER FLUID. CLOSED RA SLEEVE W/OTIS. TESTED ANNULUS TO 2000 PSI FOR 15-MIN-OK. RAN AND INSTALLED GU3'TED; STANDING VALVE. DROPPED PUMP AND SEATED WITH POWER OIL. CONFIRM PUMP WORKING OK. RELEA,~D RIG TO BAKER 17 AT 0800 HRS '¥UGULAR DETAIL DATE 4 FEB _1.991 PAGE ON~ TUB i NG X FACILITY BAKER STRING LONG ~IZE ~ 7/8 WT CASING INO, IDESCRI~TI~N IHULE SHOE 3 15/16 X 5.00 B~KER SEALS 4.00 X 3.00 LUCATUR SUB 4.25 X 3.00 XO 2 ~/8 EU >-> 3 1/2 EU 3.75 X 2.~0 ~UiDE SUB 2 3/8 EU >-> ~ 3/8 EU GUIDE FIN OD 6.00 BODY OD ~.00 ID 2.0625 BODY HA~ 4 EIN~ HI 90 DEG Z~ 5/8 EU OTIS "XN" NIPPLE WITH COLLA~ 2.625 X 1.791 ~ 3/8 EUE 4.6# N-80 PUP ~ ~/8 EU O~IS "XA" GLEEVE 3.00 X 1.875 ~ 3/8 EU 4.6# N-80 PUP BAKE~ 2 5/~ EU 5US SURFACE SAFETY VALV~ MOD~L FVLE THERE IS A EXTURNAL P~ESS YRANMISSION LINE F~UM TH~ BUTTOM OF THE KOBE CAVITY TO 1.5~ ~LUW FHE TOP OF THI~ ITEM. THE LINE IS ~T~APPED TU 1HE OD OF TOOLS IN BETWEEN UDs 0 -1.5 ~.0625 / 1.5 - 6.7~ 3.00 / 6.72 - Z. 22 4.00 / 7.~ / 8. i2 3.50. ID 1.875 ×0 ~ Z/8 EU )->2 ~/8 EU ~'~.625 X 1.995 2 7x8 EU 6.4# N-80 PUP OTIS 2 7/8 EU "RA" SLEEVE ~.937D X 2.313 KOBE CAVITY. ~E ATTACHED DRAWING XU 2 7/8 BUTT )-> 2 '?/8 EU ~ 7/8 6.4# N-80 BUTT PUP' 2 7/8 6.4# N-BO BUTT TBG 2 '7/8 6.4~ N-80 BUTT PUP 2 7/8 6.4# N-80 BUTT TBG 2 7/8 6.4# N-80 BUTT ~'UP 2 7/8 6.4# N-80 BUTT TBG i' 7/~ 6.4~ N-8~ BUTT PUP 6. 4# LENGTH .30 10.78 · 82 .96 1.28 12. 10 ~. ~b ~. 07 · 84 4.14 1.34 1~.1'? 6.13 2044.93 931.~9 GRADE N-80 THD TOP 51~9.46 5138.70 515'7.88 j136, gE 51S4.07 51..r 3~,79 5120.69 5117.44 ~115.~7 5105.25 5104.41 ~100.27 5097.06 5075.32 507~.98 ~061.81 4~67.5~ 4961.~6 2916.53 ~911.30 1979.~1 19/d.~l BO'r TOM ~149.7G 514~.46 5138.70 5137.8~ ~136.9C 5134.07 5152.79 5120.69 5117.44 ~104.41 5100. 27 5097.06 507~.d~ 5073.58 5081.81 4967.59 4961.~6 2916.53 ~91i.$0 1979.~1 ~ iii ii iii _ TUBULAR D~TAIL DATE PAGE FUUR WELL ~ 't'UL~ I Nd~ CH.51 Nb SI' RING FACILITY WT I Nu. IDE~.'CRIPl-ION 1.50 I I < .... 5.0615 OD · - ~-- I I I I I ( .... 3. ,50 OD I I · ,-+ (---4.00 OD I KEY TO ODs ON BAKER FVLE SUB SUNFACE SAFETY VALVE GRADE ~HD LENGTH ITUP BOTTOM I TUBULAR DETA!L DAlE 4 FEB 1991 PAGE THRE~ WELL. TUB I FRCILII-Y BAKER S'FRIN~ SHORT SIZE ':'-' J;/@ WT 4.6# CA51 No I Nu. I I)E~CRIP'TION P,O~E CAVITY. 5~ ATTACHED DETAIL XU 1 1/4 NU 10 RD (-) 1 1/4 EU 10 RD 1 12/16 X I 1/4 COLLA~ 1 1/4 NU 10 RD 1 t/4 ~.~# N-80 1 1/4 10 RD PUP XU 2 3/8 BUTT )-) 1 1/4 NU l~l RD ~,875 X 1.28 2:d/8 4,6~ N-80 BUTT TBG 2 3/8 4.6# N-80 BUFT PUP' ~ 3/8 4,6~ N-80 BUTT T'B6 ~ 5/8 4,6# N-80 BU~T PUP E 3/8 4.6~ N-80 BUTT PUP' ~ ~/8 4.6~ N-80 BUTT PUP ~ 3/8 4.6# N-80 BUTT PUP ~ 3/B 4.~ N-80 BUTT PUP ~2 3/8 4.6# N-80 BUTT P'UP 1/2 6°' ~IW DUAL tB~ HANGER 2 ,~/8 BUTT )-< ~ 3/8 CS HYDNIL '[ O'TAL JOINTS 'TOTAL HANGING LENGTH ALL~':' ~/8 BUTT PU;:'5 CAME F NOM liHCK 161 GRADE .... ~.~..~.8L '1' HD BU'["F LENGTH ~1.74 1.78 .29 10.10 1.41 9~.19 3.12 4906.94 5-0~ 5.08 5.1'*~ 2.10 5.18 1.45 0.67 30,7~ 5066.34 ITOP I BOTTOM I 15075.32 I 1~073,25 I I ~4968.55 ~4965.4~ 15~.49 1~,~7 t41.~7 I I 5097.06 5075, ~P 007~. = 54 507~,. .... 5063.15 5061.'74 4968,5~ 4965.4~ 58.49 53.47 48.39 43.27 41.1Z 58.02 32,~4 =1 39 ~0. 72 I I I i 1 I I I I I I -I-- TUBULAR DETAIL DATE 4 FEB 1991 ~GE TWO WELL. ~ 6 ['UB I NG X UAL41NI.3 FACILITY BAKER ~iitNING LONG SIZE ~ 7/8 WT 6.4# iNL). IDLSCRIPTION P1 41 16I 7/~ 6.4# N--80 BUT¥ T~G 7/8 6.4~ N-80 BUTT PUP 7/8 ~.4~ N-80 BUTT TBG '7/8 6.4# N-80 BUTT PUP' 7/8 6.4# N-80 BUI'T PUP 7/8 ~.4# N-80 BUTT PUP ?/8 6.4# N-80 BUTT PUP 7/8 6.4# N-80 BUTT PUP 7/8 ~.4~ N-80 BUTT PUP 1/:'~ CIW DUAL ~BG HANGEN 7/~ BUTI' )--< 2 7/8 C~ HYDRIL K.B. TU'TAL JOINTS 'TOTAL J~ANGING LENGTH LANDED LOCA'¥OR SUB 1.5' ABOVE PKR DEPTH DIL ~129.54 F'KR DEPTH TBG 5140.20 USED 10 PUPS FROM RA~K <THE TOP 10 IN THE STRING) LENGTH 641.99 5.12 1266.71 10.10 5.10 2.05 6.10 1.53 0.67 ~0. 72 GRADE N-80 'FHD BU'r'r TOP 1331.~ 1~6.10 59.39 49.~9 44.19 4~.14 39.02 31.39 Z,O. 72 0.00 BOT TOM 197~. 1331. 1326. 10 59. 4~. 2~ ~4. 19 z+~. 14 39.02 31. ~9 3k~. 72 , o 2.1','1 .H ,Dab 8. H.A. -.q. lO OD 54.5#/1 @ 2010' BAKER SC-I PKR @ 512,3' DIL 3-1/2" 9.2# N-80 0.012" WIRE WRAPPED BAKER WELD SCREEN GRAVEL PACK 20-40 MESH OI-I'AWA SAND BAKER SUMP PKR @ 5745' DIL 7" 23 & 26# @ 7397' TUBING DETAIL lLONG STRING (POWER FLUID) 1) CAN HANGER, BUTTRESS O 30.72' 2) 2-7/8 BUTT PIN x 2-7/8 BIJTF PIN PUP [3) 2-7/8" 6,4~ N-80 I'BG, BUTT W/ SP CL CPL. GS 4.) 2-7/8 BUn' BOX x 2-7/8 EU 8RD PIN X-OVER · 5074' 5) KOBE 2-1/2' MODEL "D" BHA · 5075' SHORT STRING (PRODUCTION) A) CIW HANGER, BU1TRESS · 30.72' B) 2-3/8 BU1T PIN x 2-3/8 BUTT PiN PUP c) 2-;¥8" 4.6# N-80 roG, Burr w/sP cl. CPLOS D) 2-~/8 BUIT BOX x 1-1/4 NU lORD PIN X-OVER e 5062' Lr) 1-1/4' 2.~# N-80 PUP NU lORD ~ 506~' TAIL ASSEMBLY 6) 2-7/8' EU 8RD OTIS "RA' SLEEVE O 5097, 7) 2-7/8" 6.4# N-80 EU 8RD PUP · 5100' 8) 2-7/8" EU 8RD BOX x 2-3/8" ELI 8RD PIN X-OVER ~ 5104' 9) 2-3/8" BAKER FIVE TUBING SAFETY VN..VE ~ 5105' 10) 2-3/8" 4.6# N-80 EU 8RD PUP · 5113' 11) 2-3/8" EU 8RD OTIS "XA" SLEEVE · 5117' 12) 2-3/8" ¢.6tll N-80 EU 8RD PUP · 5121' 13) 2-3/8' EU 8RD OTIS "XN" NIPPLE · 5133' 14) 2-3/8" ELI 8RD BOX x PIN CE3~m;~J~,LIZER SUB ~ 5134' 1) BAKER SEAL ASSY W/ 2-3/8" EU 8RD BOX UP ~ 5138' 16) MULE SHOE · 5150' 'A" ZONE INTERVAL ,==r 5300'- 5330' 5444'-- 5481' 5522'-- 5548' 5570'-- 5635' 5644'- 5720' CUT RET W/ BP KIT @ 5770' PERFS F/ 5782'- 6607' @ INTERVALS CAST IRON BP @ 6750' PERFS F/ 7092.5' - 7131.5' @ INTERVALS ADL 17595 WELL NO. 6 COMPLETION SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dbo UNOCAL) DRAWN: DAC SCALE: NONE DATE: 3-8-91 TUBULAR DETAIL DATE 1 FEB 1991 PAGE ONE WELL ~ 6 TUBING FACILITY BAKER STRING SIZE 3.5 WT 9.2 CASING GRAVEL PACK LINER I NO. DESCRIPTION BAKER MODEL "D" SUMP PACKER 7" 84-32 5.63 X 3.25 BAKER SNAP LATCH ASSY 80-32 4.625 X 2.375 3 1/2 BAKERWELD LWR ]'ELL TALE SCREEN .012 GAGE 4.25 X 2.99 BAKER O-RING SEAL SUB 4.25 X 1.90 JOINTS OF 3 1/2 BAKERWELD SCREEN 4.11 X 2.99 .012 GAGE 4.11X 2.99 BLANK PIPE 3 1/2 9.2# N-80 3.50 X 2.99 XO SUB 5.00 X 2.99 LWR EXTENSION 5.00 X 4.50 SEAL BORE 5.562 X 4.00 SLIDING SLEEVE 5.812 X 4.43 UPPER EXTENSION 5.50 X 4.875 7" BAKER SC-iL G.P. PACKER 70B4-40 5.937 X 4.00 15 TOTAL LENGTH ILENGTH 3.45 GRADE N-BO THD 10RD TOP BOTTOM · 84 10.08 .58 ! I I I I I I I I I I I i I I i I 124.44 .25 21.80 1.49 1.66 4.81 4.18 624.91 5751.00 5750.16 5740.08 5739.50 5288.17 5163.73 5163.48 5141.68 5140.19 5138.~3 5133.72 5129.54 5754.45 5751.00 5750.16 5740.08 5739.50 5288.17 5163.73 5163.48 5141.68 5140.19 5138.~3 I I I I I i I I I I I I i I I I ! I I I I i I I I I I I I I I I I I I I I I I i I I I I I I I I I I I I I I I I I I I i I I I I I HIGHER. NOTE: DEPTHS ARE PIPE MEASUREMENTS DIL MEASUREMENTS ARE 6 FEET 51~3.72 BIAKIER SAND CONTROL A Baker Hucjhe~ company 4792 BUSINESS PARK BLVD, BUILDING F, SUITE 3 ANCHORAGE, ALASKA 99503 TELEPHONE (907) 563-0825 FAX NO.(90?) 563-0385 February 21,1991 Unocal Oil & Gas Division P.O. Box 190247 Anchorage, Alaska 99519-0247 Attn: Don Chudanov Re: Completed Gravel Pack Summary Platform Baker's MGS 17595 # B-6 Baker Sand Control is pleased to submit this summary of the completed gravel pack on platform Baker's MGS 17595 # B-6. Enclosed is a detailed job report with steps and procedures that were implemented on the job. PRE-PACK LOWER "A" ZONE INTERVAL Perfs: 102': 5522' - 5548'; 5570' - 5635'; 5644' - 5655' Guns: 4-5/8" OD TCP guns, 8 SPF, 25 gram Big Hole Charges Sand Plug Depth: 5655' Retrievable Packer Depth: 5500' Volume Placed Outside Perfs: 138 cubic feet Pump Rate: 9 BPM Pump Pressure: 4200 PSI Pre-Pack Sand: 20-40 Baker Low Fine Gravel PRE-PACK UPPER "A" ZONE INTERVAL Perfs: 67': 5300' - 5330'; 5444' - 5481' Guns: 4-5/8" OD TCP guns, 8 SPF, 25 gram Big Hole Charges Sand Plug Depth: 5500' Retrievable Packer Depth: 5275' Volume Placed Outside Perfs: 37 cubic feet Pump Rate: 15 BPM Pump Pressure: 4500 PSI Pre-Pack Sand: 20-40 Baker Low Fine Gravel SINGLE ZONE GRAVEL PACK Perfs: 234': 5300' - 5330'; 5444' - 5481'; 5522' - 5548'; 5570' - 5635'; 5644' - 5720' Sump Packer: 5745', Model "D" Size 84-32 Lower Tell Tail: 10' 3-1/2" 0.012 Gage Bakerweld Screen screen Length: 451' 3-1/2" 0.012 Gage Bakerweld Screen G.P. Packer: 5123' Calculated Volume: 67 cubic feet Actual Volume Placed: 74 cubic feet Gravel Pack Sand: 20-40 Baker Low Fine Gravel Fluids: Filtered with a D.E. press to a 2 micron absolute Polymers: A HEC Baker Clean Gel was mixed to yield a 350 cp viscosity. The gel was then cycled through a hydraulic hydrator to remove any micro-fisheyes. It was then filtered through a 25 Whatman filter paper. BAKi~R SAND CONTROL CONCLUSION Overall the Single Zone Gravel Pack with the High Volume Pre-Pack Fracs was successful. By Pre-Pack fraccing the zones separately a larger percentage of excess gravel was placed prior to gravel packing thus increasing the effective inlet area radially over the entire interval. Baker Sand Control would like to thank you for your business and we look forward to providing you with quality service and products in your upcoming gravel packing and perforating completions. Sincerely, Baker Sand Control, a Division of · Baker Hugh~s Production Tools Inc. Alaska Sal~s Representative DS:rr BAK~=R SAND CONTROL UNOCAL ALASKA MGS 17595 #B-6 * TOOLS (SALEABLE): TOOLS (RENTAL): FILTERING: PUMP ING: 65,967.00 11,300.00 30,928.48 188,844.69 TOTAL: $297,040.17 UNOCAL BAKER B-6 FILTRATION FlEeT 1/25/91 flL'T~ HLE~ tq UNOCAL BAKER B-6 FILTFtATiON FIEPOFrI' 1/27/gl NIU'5 WI;IL ~ Pti REIURI4~ MOO UNOCAL BAKER B-6 FILTRATION REPORT 1/26,27/91 I=1LTI~I gull UNOCAL BAKER B-6 FILTRATION FiEP(~T 1/28/01 1413 ~;3DIUM BROMIDE 781 PPCF 130 ~=:_~_: ............................................................. I~ ..................... =- ~' ............................................ .... ~ ........................ ;~;' .;~ ....... ~;~;;~_. .................... ~ ................................................... ~ ..... ~;;;.-;;~. .................................................................... ~ ................... P'ER'F~~N' '~Oa ........................ TIME IN I:ILTI~i NlM dig FILTIE]i RIM ~'4 UNOCAL BAKER B-6 FILTRATION RE~T 1/29/91 ...... :SODIUM IBROMIDE 78 PPCF ! ~ ...... .:-..~.~ .-.: ....................................................... I~ .......................... "-:'"~'- ........ :.:..L:.~.' .............................. - -~-.~.~._. ~ ............................................... .-:.~ ....... :_::_t~.--_._-____ ....... FILTERIN~I HOLE AFTER :BECOND ...................................................................... P ERFORATINgl JOB. TIME IN HOUR'~ WELL ~ Pil FI~TUFI~ PP~:lffi, DISOI~I~E FILTER ALE ~ UNOCAL BAKER B-6 FIL.TF~TION REI:~T 1/:31/91 AMMONIUM CHLOFilDE 72 PPCF ~ ........................................................................ FILTERIN~k :250 I~L~ F(~ FRAC #2 ~,~ ........................................................................ TIME IN HOI. JIR~ UNCX.~L BAKER B-6 FILTRATION REPORT 1/30/9'I UNOCAL BAKER B-6 FILTRATION REPORT 1/31/9'i 2/1/91 200-- ~DILiM BROMIDE 7e PPCF ~ ~ ...... -.. :.: ........ .: ..:. ~ :.....: j..~ .................................. ~ .......................... ~'.' ~-~:~ ~ :':. :~_~ .... :... .............. tl~e IM ~OU~ WELl.. q;~ PII FUP.1UFIt~ '- P1~86 DIS(IHARQE FIL'Tl~lNllildltrr FILTI~TilONIIM/6 UNOCAL BAKER B--6 FILTRATION REPORT 2/1/91 NTU'S 2,,5 2 1.5 0.5 AMMONIUM CHLORIDE SODIUM BROMIDE FILTERED 6,5 BBLS FOR GRAVEL PACK FLUID 0800 0900 TIME IN HOURS IOO0 PRESS DISCHARGE FILTEI~ RUN #9 ~£REEN ~-~ 5282,17~ ~_ EQUIPMENT al{ !:~VICE$ LOCATION: 3P£RATOR FAX~ UNDCAL ALASKA 30MPANYR~. PH~ DON CHUDANDV / LARRY GRAHAM -IELJ~ WELL MIDDLE GROUND SHOAL ]~-6 5TALE ALASKA ,.OADING OOCK PH~ · G NA¥£ PH,J~ PLATFORM BAKER ~TE SUBMll'rED JOB ~ FEBRUARY E, lCJgl =REPAEED BY DARRYL SNOW DEPTH 5123.54 5127,72 5132,53 5134,19 5135.68 5157.48 5157,73 5188,85 5219,95 5251,05 5282,17 5318,24 5342.35 5272.40 5402,3] 5432,58 5462,68 54cJE,79 5522.89 5552,98 5583,05 5613,15 5643,~2 5673,31 5703,42 5733,50 5734,08 5744,16 5745,00 RMATION: LENGTH 4,18 4,81 1,66 1,49 21,80 ,25 31,12 3LlO 31,10 3t.12 30,07 30,11 30,05 30.ti 30,07 30,[0 30,1.1 30,10 30.09 30.07 30,10 30,07 30,09 30.11 30,08 ,58 10,08 ,84 3,45 563-08P5 O.D. ll.D. 5,50 I 4,875 5,812 5.562 5,00 5,00 3,50 3,50 3.50 3,50 4,11 4,11 4,11 4.11 4,11 4,11 4,11 4,11 4.11 4,11 4,11 4,11 4,11 4.11 4,11 4.25 4,11 4,685 5.63 4,43 4,00 4,60 239 2,99 2,99 2.99 2,99 E,99 2,99 2,99 2.99 2,99 2.99 2,99 2.99 2.99 2,99 239 2,99 2,99 2.99 2,99 1.90 2,99 2,375 3.25 PERFORATION INTERVALS, 5300'-5330' 5444'-548t' 5522'-5548' 5570'-5635' 5644'-5720' SAND CONTROL i Baker Hughes company ' CASING LINER TUBING WKSTRG SIZE.. 7' 7/8' WEIGHT - 26# 6,5# .GRADS' J55 NB0 THREAD BUTTRESS LISTED BELOW :ONP. FLUID INHIBITOR ]OOATING I 10,2 PPG 3% ECL ~ONLLN SIZE [,AND SIZE 3 1/2' ,012 GAGE 20-40 ~.. DESCRIPTION BAKER MODEL SC-IL GRAVEL PACK PACKER SIZE 70B4-40 UPPER EXTENSIDN SLIDING SLEEVE SEAL BDRE SOWER EXTENSION CROSSOVER SUB 3 1/2' 9,2fl N80 BLANK PIPE 124,44' BLANK 3 1/2' ,012 GAGE BAKER~ELD SCREEN 45t.33' SCREEN D-RING SEAL SUB 3 1/2' BAKERWELD LOWER TELL TALE SCREEN ,018 GAGE BAKER SNAP LATCH SEAL ASSY, SIZE 80-38 BAKER MODEL 'D' SUMP PACKER SIZE 84-38 Baroid Drilling Fluids, Inc. March 5, 1991 Mr. Don Chudanov Unocal Oil & Gas Division P.O. Box 190247 Anchorage, Alaska 99519-0247 Re: Workover/Completion Fluids Recap Baker Platform BA-6 Dear Mr. Chudanov: Enclosed is the material usage and cost associated with the above referenced well. Please refer to the recap for specific details in reference to the operations involving the completion fluid. The costs are broken down as follows: Ammonium Chloride Calcium Chloride Sodium Bromide Sodium Chloride Total Salt Cost 60 Barrel Litesal Pill Technical Service Miscellaneous Total Well Cost $ 5,987.52 $ 5,956.80 $ 89,554.40 $ 14,919.45 $116,418.17 $ 8,175.38 $ 8,505.00 $ 4,016.99 $137,115.54 The base formulation and cost of the 78 pcf fluid is as follows: Filtered Inlet Water .926 Barrels (63.5 pcf) 3% KC1 12 ppb NaC1 60 ppb Yields 1 barrel 71.8 pcf (9.6 ppg brine) Cost per barrel $11.88 2000 West Int'l. Airport Road, Suite A-10 · Anchorage, Alaska 99502 (907) 248-3511 · Fax (907) 248-5390 Pa§e 2 Mr. Don Chudanov Unocal Oil & Gas Division Re: Workover/Completion Fluids Recap Baker Platform BA-6 March 5, 1991 71.8 pcf (9.6 ppq) brine .965 Barrels Sodium Bromide 48 ppb Yields 1 barrel 78 pcf NaBr/NaC1/KC1 Brine Cost per barrel $86.5? If you require any additional information or have any questions please do not hesitate to contact me. Sincerely, BAROID DRILLING FLUIDS, INC. T. Jay Olive Technical Sales Representative cc: Bush Neve' File Attachment s Unocal Oil & Gas Division Material Usage and Cost BA-6 Workover MATERIAL Ammonium Barazan Calcium Chloride Dirt Magnet FL-7 Liteplug Liteplug-F Liteplug-X Litesal-XCP Plugsal Salt SDI Defoam Sodium Bromide TOTAL PRODUCT COST Technical Service Roundtrip Airfare Rework Charges Kenai Borough Tax UNIT USAGE COST/UNIT 66 LBS 126 $ 47.52 50 LBS 2 $ 378.42 80 LBS 170 $ 35.04 500 LBS 1 $1,600.00 50 LBS 1 $ 68.50 50 LBS 30 $ 65.50 50 LBS 30 $ 65.50 50 LBS 30 $ 65.50 50 LBS 26 $ 86.63 50 LBS 28 $ 32.27 80 LBS 1,365 $ 10.93 50 LBS 5 $ 94.37 55 LBS 1,040 $ 86.11 $ 405.00 1 $ 111.00 1 $ 73.74 10 $ 10.00 AMOUNT 5,987.52 756.84 5,956.80 1,600.00 68.50 1,951.50 1,951.50 1,951.50 2,252.38 903.56 14,919.45 471.85 89,554.40 $128,325.80 $ 8,505.00 $ 111.00 $ 73.74 $ 100.00 TOTAL WELL COST $137,115.54 Unocal Oil BA-6 & Gas Division Workover Order Document Numbers: Charqes: Z34669 Z34673 Z34674 Z34676 Z34688 Z34696 Z34697 Z34705 Z34713 Z34724 Z34743 Z3474 Z34748 Z34759 Z34749 Cred i t s: Z34702 Z34717 Z34718 Z34719 Z34753 Z34754 Z34755 Amount: $ 8,426.10 $16,725.36 $31,447.51 $68,898.00 $14,619.55 $ 5,712.40 $ 5,638.95 $26,378.80 $ 4,981.00 $ 2,440.00 $ 9,821.20 $20,540.07 $11,640.81 $ 1,225.00 $18,171.92 Total Charges $14,815.26 $10,785.07 $17,545.11 $12,754.64 $19,283.12 $11,640.81 $22,~7.12 $246,666.67 Total Credits - $,109,551. 13 Total Well Cost - $137,115.54 Drilling Mud Record Petroleum Services COMPANY Unocal 0il & Gas Division STATE Alaska CASING PROGRAM inch at ft. · WELL DA-6 Workover COUNTY Kenai inch at ft. CONTRACTOR Baker Platform LOCATION Cook Inlet_ SEC TWP RNG inch at ft. STOCKPOINT Rig Tenders Dock DATE 2/6/91 BAROIDENGINEER Wallace, Thomas TOTALDEPTH ft. DATE DEPTH WEIGHT VISCOSITY Yp GELS FILTRATION RETORT SAND CEC pH FILTRATION ANALYSIS -, fee[ lb/gal Sec APl PV 10 sec/ mi HTHP Cake Sotids Oil Water % Mud Strip ] Pm Pr/ P,/P2 CI CA REMARKS AND TREATMENT 19 91 __:F _:F 10 min APl __:F 32nds % % % me/mt Meter ;Z Uf Ppm ppm (See Operations Sheet) , ....... 1-19 MOVE ~ I G" "'FI ,OM #7 to ~6 1-20 D'ISPLt~CE #~ W/FI~I/ND TREI',/NU BOi AND TI:ST SAItE 1-21 PULL f~RODU(:TION i'UBI IG/MiX LITE:;AL PI[IL/FIW ,,,19000 ,,, ~.~ 1-22 2100 63 FIW 7.5 [9000 1L23 2100 63 FIW 7.5 [9000 1'24 5170 63 F'iW 7.5 19000 1--25 5170 72 FIW I~ND laC1 7.5 19000 ,,, 1-26 5579 76 FIW ~nd laC1 and Na~r 7.5 145000 .... 1'27 5519 76 FIw ~nd laC1 and Na[r 7.5 [40000 1-28 5519 78 FIW ~nd laC1 and Na~r 7.5 140000 1'29 548~ 78 FIW ~nd laC1 and Nadir 7.0 148000 1-30 5487 78 FIW ~nd laC1 and Natlr 7.0 145000 1L31 5470 77 FIW ~nd llaCl and Natr 7.0 160000 2-1 5768 76 FIW ~nd ~laC1 and Na[tr 7.5 172000 2-2 5768 75 FIW ~nd /laC1 and Na[lr 7.0 162000 2-3 5768 74.8 FIw ~nd /laC1 7.0 I57000 2-4 5'130 74 FIW ~ nd ~laC1 7.0 1580001 2-5 5130 74 FIW ~nd tlaC1 7.0 158000 2-6 5130 70 FIW ~nd tlaC1 7.0 141000 '2-23 5134 75.2 7.5 138000 !2-24 5134 74.9 8.0 153000 '2-25 5134 FIW ~TIH Nal¢:o 3900 ..... .... ,,, ,. : .... Unocal Oil & Gas Division OPERATIONS Baker SA-6 D~TE OPE~TIONS 1-19 1-20 1-21 1-88 1-83 1-84 1-85 1-26 1-8? 1-28 1-29 1-30 Move rig from #7 to #6, rig up wireline and pull pump and standing valve. Displace #6 w/FIW, ND tree, NU BOP, rig up to test same. Test BOP, RU and pull one string production tubing, circulate prepare to mix and spot sized salt pill. RIH w/bit and scraper for clean out run. Had to change out tubing spool, casing seat bad, pulled casing up and cut off, put on BOP's, will run in and retrieve plug after testing. Ran bond logs, RIH w/bridge plug. Set plugs' and tested casing, mixed one drum Dirt Magnet, circulated around, shipped returns to production, mixed 400 bbls of 78 lb/ cu. ft. NaC1/FIW, displaced hole, sheet tested returns and discharged overboard. Mixed 840 bbls of HH4C1, 3% FIW to add fracing fluid, weighted up active system to 76 pcf w/NaBr built additional 180 bbls 78 lbs NaC1/FIW. POH w/drill pipe, RIH w/tubing, spotted sand plugged circulated bottoms up. Mixed fracing fluid. Frac job got approximately 90 bbls of sand pumped into formation before pressing up, needed to bring brine weight up to 78 lbs/cu, ft. to kill well after frac., POH w/tubing, RIH with drill pipe, circulate and filter fluid. RIH w/perf tools, perforate, reverse out, circulate TOH, RIH open, pump sand plug, WO sand to settle, tag sand @ 5487', circulate and filter tool. TOH, pickup RTTS, TIH, packer failed to test, TOH, pick up new RTTS( TIH, packer failed to test, TOH clean and break RTTS, TIH, test Okay, establish flow ~ate fo~ feat. BAROID DRIU. ING FLUId, INC. Page 2 Unocal Oil & Gas Division Operations BA-6 Workover DATE OPERATIONS 1-31 2-1 2-2 2-3 2-4 2-5 2-6 2-23 2-24 Reverse out after pressure pack, caught sample for discharge circulate, TOH, lay down tools, RIH open, clean out sand, circulate and filter TOH. POH w/bit and scraper, RIH w/sump packer, POH, RIH w/slotted liner assembly, pump gravel pack, reverse out wait 3 hours and test, lost 86 bbls to hole last 24 hours. Pressure test gravel pack, TOH, WO tubing, RIH with tubing. Run KOBE assembly and dual string tubing, lost 61 bbls volume to hole. Finish running dual string tubing, unable to test seat. Wait on seal for well head. Test well head, move to well #27. Skid rig over well, NU and circulate well. Built 70 bbls 73 pcf NaCl fluid, add 70 bbls NaC1 to circulating volume 75 to 77 pcf. Well still flowing with 74 pcf fluid, built 75 pcf CaC12 to kill well, pull tubing. Changed out tubing spool , tubing hangeps, running tubing. Rigged up Halco wireline, retrieve plugs, tested tubing hangers, etc., displaced well with Nalco 3900 packe~ fluid. BAROID DRILLIN6 FLUII)6, INC. TO: THRU: FROM: MEMORANDUM State of Alaska ALAS~ OIL ~ GAS CONSERVATION COMMISSION / Lonnie C. Smi~,~ March 13 1991 commissioner r-u DATE: ' FILE NO: DA313 TELEPHONE NO: Doug Amo~ Petroleum ih~Pector SUBJECT: BOP Test Shell Baker Pltfrm MGS Oil Pools Friday Feb. 22, :1991: I travelled this date from Anchorage to Kenai to witness the BOP test at Shell's Baker Platform. I arrived in Kenai at 2:00 p.m. and proceeded to the Shell/Amoco Heliport at Wick Road. By the time I reached the heliport, the weather conditions had deteriorated to zero visibility and I was unable to reach the platform. I stood by at the heliport until 7:00 p.m. at which time I was . informed that all flights were cancelled until the morning of 2/23/91. I stayed overnight in Kenai and returned to Anchorage at 7:50 a.m. on 2/23/91. In summary: I was unable to witness the BOPE test at Shell's Baker Platfo~ due to severe weather condition. The BOPE test was ~erfor~ed 2/22/91 by platform personnel and a copy of the BOPE Inspection report is attached. Attachment. 02-00lA (Rev. 6/89) 20/11]MEMO1.PM3 ITATE O{r AI, A{KA AI, ASKA OIL AN{) OAS CONSERVATION L.o,:.~,., h,~ '3/..__ 'T_~W' ,~, _ Lo=stion (gen,ral) Y/' #oll &iOn _~_.__~__.. B,OP~ ~TACK, Annul~P preventer Ptlm~ rams TEST ~E$UUTS, rlllure, ../ .__ . . _ Reprlltf)~a~tvl Permtt t . ~._: .;7.//__._ CaJ --. Rig #..~_..~ Rep Pump Inet olo, Rem~te ~ELkY~ND F~_OOW Upper Kelly Lower xe{ly _ 8ill type Choke manifold , Number Nvmbwr fllnQel AdJvltlble ghok,, HydPaulqeally ope time ~_._~ hr. i~epllr or rtJ)llv~ment of filled equtpmeAt to be made wtthin · and Inspect. or/C<~mniIliOn off lei fl~i;lfied. ,': ..' _ __tJ, iii e - Supervisor tCEI.VED FEB 2 51991 · Alaska UJI.& Gas Oon8. _ _ -_ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ri APPLICATION FOR SUNDRY APPROVALS"' R 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well ~ Pluggi.ng __ Time extension ~ Stimulate Change approved program __ Pull tubing ~,- Variance ~ Perforate _~ (Jt~er x__ 2. Name of Operator 5. '~ of e: · Union Oil Company of Californi~ (~Q~~ent'~ ~u~ev~~.o~ ! Exploratory __ 3'AdOre~.o. Box 190247, Anch., AK, 991519-02~rPv~;--- 7'~rP~P~t~a~595 4. Location of well at surface Leg #2, Conductor # 4 1989' FNL & 588' FWL, Sec. 31, T9N, R12W, SM At top of productive interval Top of "A" zone at 5300' MD 1938' FNL & 668' FWL, Sec. 31, T9N, R12W, SM At effective depth CI Bridge Plug at 6750' MD 1918' FNL & 717' FWL, Sec. 31, T9N, R12W, SM At total depth TD at 7400 ' MD 1906' FNL & 737' FWL, Sec. 31, T9N, R12W, SM 8. Well num~i;il~ll No. 6 9. Permit number 66-3 10. APl number 50-- 1.33-10073 11. Field/Pool Mid. Ground Shoal feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 612 ' Conductor 2010 ' Surface 7397' Intermediate Production Liner Perforation depth: measured 7400 ' feet Plugs(measured) feet 7396' feet Junk (measured) 6750 ' feet 6747' Size Cemented 20" 1192 SXS 13-3/8" 1300 SXS 7" 1900 SXS See attached true vertical LS: 2-7/8", 6.4#, SS: 2-3/8", 4.6#, N-80 N-80 Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) Measureddepth 612' 2010' 7397' BUTT AT BUTT AT ~ueve~icaldepth 612' 2010' 7393' oRECEIVED 5737 SEP 2 7 ]990 A aska Oil & 6as Cons. '' ~ch0ra~e" 13. Attachments Description summary of proposal .z_ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: DECEMBER 16, 1990 16. If proposal was verbally approved Oil x__ Gas __ Suspended __ Name of approver Date approved Service 17. I hereby certify that the fore~n..g is tru~.snd correct to the best of my knowledge. Signed GARY S U~ 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 LONNIE C. S~tT~I Approved by order of the Commission Approved Copy Return/ed IO/I/qO Form 10-403 Rev 06/15/88 [ Approval No¢~ _. '~-~ ! ! Commissioner Date (~/~)~ I~ SUBMIT IN TRIPLICATE ~cs z7595 #6 PERFORATION RECORD "A" ZONE '5,300'-5,330'MD '5,446'-5,481'MD '5,522'-5,548'MD '5,576'-5,638'MD '5,644'-5,655'MD 5,298'-5,327'TVD 5,443'-5,478'TVD 5,519'-5,545'TVD 5,573'-5,435'TVD 5,641'-5,562'TVD "B,C,D" ZONE 5,782'-5,805'MD 5,850'-5,910'MD 5,925'-6,000'MD 6,020'-6,055'MD 6,130'-6,240'MD 6,260'-6,360'MD 6,420'-6,460'MD 6,490'-6,540'MD 6,601'-6,607'MD 7,092.5'-7,094'MD 7,130'-7,131.5'MD 5,779'-5,802'TVD 5,847'-5,907'TVD 5,922'-5,997'TVD 6,017'-6,052'TVD 6,127'-6,237'TVD 6,257'-6,356'TVD 6,416'-6,456'TVD 6,486'-6,536'TVD 6,597'-6,603'TVD 7,088.5'-7,090'TVD 7,125'-7,126.5TVD *CEMENT SQUEEZED RECEIVED SEP 2 7 1990 Oil & Gas Cons. Com~issior~ ~ Anchoracj~ MGS 17595 #6 WORKOVER PROCEDURE (9-12-90) · · MOVE RIG OVER MGS 17595 #6, LEG #2, SLOT #4. KILL WELL WITH COMPLETION FLUID. · · · · INSTALL BPV'S, NIPPLE DOWN TREE, NIPPLE UP BOPE. PULL AND LAY DOWN DUAL KOBE PRODUCTION STRING. RUN BIT AND SCRAPER TO 6750' (BRIDGE PLUG). SET RETAINER AT 5778' TO ISOLATE LOWER COMPLETION. 7. PRESSURE TEST 7" CASING WITH RTTS PACKER. 8. CHANGE OVER TO CLEAN COMPLETION FLUID. · REPERFORATE "A" ZONE UNDERBALANCED WITH TUBING CONVEYED GUNS FROM 5300' TO 5720' AT INTERVALS. 10. 11. FRACTURE STIMULATE "A" ZONE IN THREE STAGES. SET SUMP PACKER AT 5745'. RUN 3.5" OD GRAVEL PACK LINER ASSEMBLY WITH TOP PACKER. 12. GRAVEL PACK THE ZONE FROM 5300' TO 5720'. 13. RUN SINGLE KOBE PRODUCTION STRING WITH PUMP CAVITY AT 5100'. 14. REMOVE BOPE AND INSTALL TREE. 15. RETURN WELL TO PRODUCTION AND MOVE OFF. NOTE: SBHP ANTICIPATED TO BE 2970 PSI AT 6600' TV~.- WORKOVER FLUID WILL BE FILTERED INLET WATER WITH 3% KCL AND NACL AS REQUIRED FOR WELL CONTROL. BELL NIPPLE I FLOWLINE 5" KILL LINE WITH TWO 3" 5M VALVES ! d'; d'; KILL LINE FROM MUD PMP & CEMENT UNIT 15-5/8" 5000 PSi ANNULAR I ! I I PIPE RAMS BLIND RAMS I I PIPE RAMS 15-5/8" 5M FLANGE ADAPTER 5M x 5M 15-5/8" 5M FLANGE DOUBLE GATE 5M 1,5-5/8" 5M FLANGE 4" CHOKE LINE WITH ONE REMOTE & I MANUAL 4" 5M VALVE CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) 15-5/8" 5M FLANGE SINGLE GATE 5M 15-5/8" 5M FLANGE RISER i 10" 5M x 15-5/8" 5M ADAPTER CAMERON 5M SPOOL I 5--5/8" DOPE 5M STACK BAKER PLATFORM UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC APP'D' GSB SCALE: NONE DATE: 9/12/90 s4.s I @ 2010' BAKER WELD SCREEN GRAVEL PACK 20-40 MESH OTTAWA SAND 7" 23 & 28# @ 7397' ~ 3 TUBING DETAIL 3-1/2", 9.2#, N-80 TBG BT&C, 1) PRODUCTION STRING 2) WIRELINE REENTRY GUIDE .3) 3-1/2% 9.2#, J-55, 0.012" WIRE WRAPPED SCREEN BAKER SC-1 PKR @ 5175' "A" ZONE INTERVAL 5500'- 5350' 5444'- 5481' 5522'- 5548' 5570'- 5635' 5640'- 5720' BAKER SUMP PKR @ 5745' CMT R~@ 5778' _ ,, PERFS F/ 5782'- 6607' @ INTERVALS CAST IRON BP @ 6750' PERFS F/ 7092.5'- 7131.5' @ INTERVALS ADL 17595 WELL NO. 6 PROPOSED WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dbo UNOCAL) DRAWN: DAC SCALE: NONE DATE: 8- 14-90 ~,~d DaLe: Surface Locetlan: ~ubswfoce Locotlom Bevotlan: I~0.' Caring: Perfol-atlanl: InlUd Pc~mUal: InWal SUmula~Jon: DST and Re.ulte.' MIDDLE GROUND SHOAl. ADL 17595 WELL NO, 6 KENAI CONGLOMEIRATE PLATFORM BAKER got 4, ~ 2 lgSe' ~ 588' ~ ~eo. 31. TeN. RI2W. S.IL TD - 1908' .FHL, 7.37' P4tL, SeG. 31, TgH, R12W, S.LI. 74O0' 675O' 79.8 4 at 612' wl~h 1102 ax oemant ~S/~'. .Sdi Cbebg ot 7". 23 and 2dtll cadng Nt 4t 7307' with 1900 ix cement ~ S~0-0330'~ B~. 0702-580~' 042o-040o' 5448-6481'* 5850-5e10' 64B0-8~40' 5522-6548'. 592,','-6000' 6601-6007' 5576-5038'e 8020°-8055® 709Z.5-7094' 5644-$655'e 6130-6240' 7130-7131.5' · q~lnWnt 8queezed 8200-0360' FLW 1880 BOPD, 1.0:~ BS&W cst 210J~ F'TP, G0R 4612, G~vlty 37 ~C~r?plet]on Reoord I. Tubing hanger 2. 2 7.;B" 3. Natlond 220 2 4. 2 7/0' Tm~ldpo 5. Iduloohoe B. 2 3/8" Bu~treee x I 1-/4 101~ XO C. I I/4# IOFcD pup (M nJn I I.~/~5) t. P~ 7092.5-7131.O: FI.W tot 204 BOPO x C01t 168. FrQc u/10,000 OM Pod, ~ COCI2 water cantoJfling 60 b J-140 gM ur/3300 I~e 10-20 od - flow 1850 BOPO ~ - 84 on 1/4 Ch 2. Pre 8278-8330': S4b in x fie 1128 EIOPD. O.l~ BS4~. ~ 338. Fmc treQted water ~ 8200 lb, 10-20 Sd fallo,ed by 27.400 gal wohr w/4650 12-20 walnut .helle and 11.500 II)e &noco 506 ,para' - fio~ 1585 BOPD. BS&W. ~ 241 at 275 3. Pre 6208-6239.5. Te~t and r.c~m~dcate wl~h plo 6276' at 400 pal. Fraa ,/12.000 gm treated uater. ~000 lb8 10-20 Sd. 32.Q00 gal trantid water and 5000 lbs f2-20., walnut ,hah and I O. OOQ lbs 12--20 Am~co 50~ 4. Pr, 8142-0171: Fra~ w/le. OOOgal trsoted wohr. 8000 Ibc 10-20 Sd. 21.ooo c~l__lreated water and 4200 lbs 12-20 walnut ghelb and 7450 I1~ 12--20 ouo ,pacer A zon~ 58O2-5828' BCD zooe: 5848-5858% 58t8-5845% 6123-6179' D'G zone:. 7007-7103' Mono S726' 5703' 6439' 8440' 5726" 5727. 0737* t 79.6t 812' C~ 2010' 5055' i 5782' ~60o1' .~'~6, 6o7. Iron Bridge I~g ~ sot et 6750*I17092-5' 7131.5' 74OO* ~~- 23 & 2el CSA 7397' APril 6, 1990 Amoco Production Company Denver Region 1670 Broadway P,O. Box 800 Denver, Colorado 80201 303~30~4040 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attention: Larry Grant File: KJO-396-WF Information Requested Middle Ground Shoals Wells 17595 ~501, $4 and and Granite Point Well 17586 $5RD Platforms Baker and BruCe,. Cook Inlet, A/asks Per your request I am forwarding a copy of the directional surveys for the Middle Ground Shoals wells. The tape log for the Granite Point well that you requested is not available. If you require any additional information on Amoco operated wells in Alaska, please contact Julie Victor at (303) KJO/fjb cc: J. A. Victor RECEIVED APR 1 2 1990 0il & 6a~ Oon~. Commi~lon ~choraga W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 November 13, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 ~Porcupine Drive Anchorage, Alaska 99501 Fi 1 e' TJZ-385-WF Dear Sir' Subsequent Noti ce MGS 17595 Well No. 6 Platform Baker, Cook Inlet, Alaska Commission Attached in duplicate for your approval is a Sundry Notices and Reports on Wells, for Very truly yours, W. G. Smith District Manager Attachments JCB/dds ~" ~' ~ State of repai rs made Alaska Form 10-4.03, to Well No. 6. RECEIVED Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION S i i RY NOTICES AHD REPORTS ON WE LS , : ...... "~ · . 1. DRILLING WELL [] COMPLETED WELL,~ Name ' ' ' ' ~' '" Company .. 66,3 ~ ',~ I · 8. APl Number so- 733-1 f)f173-fll i 3. Address P, 0, Box 100779, Anchoraqe, Alaska 99510 4. Location of Well 9. Unit or Lease Name Leg 2, Slot 4, NGS Platform Baker MGS 17595 1,989' FNL, 588' FWL, Sec. 31, T9N, R12W, S.M. 10. WellNumber 11. Field and Pool Middle Ground Shoal 5. Elevation in feet (indicate KB, DF, etC.) I 6. Lease Designation and Serial No. Kenai Sand. BCD I m 79' KB ADL 17595 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made ~ "Other [] Pull Tubing [] Other [] Pulling Tubing .1~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed OPerations (Clearly State all pertinent details and give pertinent dates, including estimated date of starting any proposed work, fOr Abandonment see 20 AAC 25.105-170). Between October 28, 1985 and November 9, 1985, Amoco Production Company: 1. Circulated and killed well. 10. 11. 2. Nippled up BOP's and pressure tested. 3. Pulled tubing. Parted at bottomhole assembly. 4. Fished and retrieved bottomhole assembly. 5. Milled and retrieved packer set @ 5,735 feet. 6. Pressure tested previously squeezed 'A' zone perforations. Interval between 5,576 - 5,655 feet would not pressure test~ 7. Cement squeezed 5,576 - 5,655 feet with 15 sx Class 'G'. 8. Drilled out cement and pressure tested to 2,000 psi. 9. Set bridge plug at 2,031 feet. Nippled down BOP's and single tubing spool. Nippled up new dual tubing spool and BOP's. Pulled bridge plug at 2,031 feet. Cleaned well out to 6,750 feet. Perforated the following intervals at 4 JSPF, 0.4 inch holes: 14. I hereby certify that the~a~going.j~Crue and correct to the best of my knowledge. Signed Title District ManaoP_r The space below for Commission use Datl 1/!3/85 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 tier.. 7-1 ~80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION S N )RY IOT C -S AHD 'REPORTS ON WE LS 1. DRILLING WELL COMPLETED WELL OTHER [] 2. Name of Operator Amoco Production Company 3. Address P. 0. Box 100779, Anchorage, Alaska 99510 4. Location of Well Leg 2, Slot 4, MGS Platform Baker 1,989' FNL, 588' FWL, Sec. 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 7. Permit No. 66 -3 8. APl Number 50- 7~-!nn73-01 9. Unit or Lease Name MP,(; 1 7r~Q~ 10. Well Number 6 11, Field and Pool Middle Ground Shoal Kenai Sand - BCD 12. . 7g' KB ADL 17595 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: suBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Welt [] Change Plans [] Repairs Made Pull Tubing [] Other E] Pulling Tubing (Note: Report multiple completions on Form 10~t07 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) ~ Altering Casing [] [] Abandonment [] ~ Other I-'l 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 12. 13. 14. Interval Footage 5,850 - 5,910 5,925 - 6,000 6,020 - '6,060 6,130 - 6,240 6,260 - 6,360 6,420 - 6,460 6,490 - 6,540 Total 60 feet 75 feet 40 feet 110 feet 100 feet 40 feet 50 feet 475 feet Ran dual tubing and new bottomhole assembly. Nippled up tree and pressure tested." Returned well to production. RECEIVED NO Alaska 0]1 & Gas Cons. Commission Anchorage 14. I hereb~f~~ng ~:l:~ue a~nd corre~,~e The space below for Commission use the best of my knowledge. Title District Manaapr Da~1/!3/85 Conditions of Approval, if any: Approved by BY Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1430 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 October 2, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage., Alaska 99501 File- TJZ-346-WF Dear Sir: Notice of Intent Middle Ground Shoal 17595 Well No. 6 Platform Baker, Cook Inlet, Alaska Attached in triplicate for your approval is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, tO notify you of our intent to pull tubing, cement squeeze the A zone to eliminate sand production, and reper- forate the pay to return Middle Ground Shoal 17595 Well No. 6 to optimum hydrocarbon production. The well is currently shut-in due to fill existing above the bottomhole assembly which will not allow a new pump to be circulated in to produce the well. We plan to begin this work as soon as possible. Any questions concerning this project may be directed to Mike Schwein in our Anchorage office. Very truly yours, _~nager _ ~.~ ~: ~ MTS/dds Attachment cc: R. J. Criswell -Denver Gas Cons. Commission Anchorage O02/mtsl /% STATE OF ALASKA .;-. ALASKA( ~ AND GAS CONSERVATION CC' MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL J:J~ OTHER [] 2. Name of Operator Amoco Production Company 3. Address P. 0, Box 100779, Anchorage,..Alaska 995:10 Location of Well Leg 2, Slot 4, Middle Ground Shoal Platform Baker 1,989' FNL, 588' FWL, Sec. 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 71' .KB MSL 12. I 6. Lease Designation and Serial No. 7. Permit No. 66-3 8. APl Number so- 733-10073 9. Unit or Lease Name MGS ;~7595 10. Well Number 6 11. Field and Pool Middle Ground Shoal Kenai Sand - BCD APL 17595 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well ~' Change Plans [] Repairs Made [] Other [] Pull Tubing ~ Other ]~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco Production Company plans to perform the following work: 3. 4. 5. 6. 7. 8. Circulate and kill the well. Set back-pressure valves, nipple down tree, nipple up BOP's and test .to 2,500 psi. Pull back-pressure valves. Mill out and retrieve the packer set at 5,735 feet. Pressure test the previously squeezed "A" zone perforations and resqueeze if necessary.. Reperforate the pay with tubing-conveyed perforating guns fired underba 1 an ced. Run dual tubing and new bottomhole assembly. Set back-pressure valves, nipple down BOP's~nipple up tree and test to 4,000 psi. Pull .back-pressure valves. Circulate well with power oil and return to production. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEIVED OCT o 198 Alaska 0il & 6as Cons. 0cram Signed The space betow for Commission use Conditions of APproval, if any: Approved by. ORIGINAL SIGNED BY LONPlI[ C. SMITH Title District Manager Anchorage Date 10/02/85 ~,®turned BY Order of COMMISSIONER the Commission ~sion Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow Area Superintendent March 4, 1977 File: LAD-178-WF Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 Mr. Hoyle Hamilton, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Sundry Notices and Reports on Wells MGS 17595 Well No. 6 Attached is a State of Alaska Form 10-403 summarizing work recently completed on MGS 17595 Well No. 6. The subject well was acidized to remove accumulated scale and squeezed with a scale inhibitor to retard future scale formation. This work was performed on February 24, 1977. Yours very truly, L. A. Darsow Area Superintendent Attachment Form ! (~403 :'~"~- Submit "1 ntentions" in Triplicate REV. 1-10-~3 & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) WELL 2. NAME OF OPERATOR Amoco :Production Company 3. ADDRESS OF OPERATOR ?' 0, BO× 779, /~chorage, Alaska 99510 4. LOCATION OF WELL Atsurface Leg 2, Slot 4, MGS Platform Baker, 1989' FNL, 588' FWL, Section 31, T9N, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RKB 71.36 ' above MSL 14. CheCk Appropriate Box To Indicate Nature of Notice, Re !5. APl NUMERICAL CODE 50-133-10073 6. LEASE DESIGNATION AND SERIAL NO. ADL-17595 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME MOS 17595 9. WELL NO. 6 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31, TgN, R12W, S.M. 12. PERMIT NO. 66-3 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING ~1~'~3~ ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Production prior to work: Production after work: ;16. I hereby certify that the foregoing is true and correct 1. Acidized with 7875 gallons of 15% HC1, 1.25 BPM at maximum pressure of 3400 psi. 2. Followed acid with 165 barrels of diesel pad, 1.4-1.5 BPM at 3300 psi. 3. Injected 2000 gallons of Arcohib S-239 polymer scale inhibitor, 1.4 BPM at 3200 psi. 4. Flushed inhibitor with 100 barrels diesel pad, 1.4 BPM at 3300 psi. 5. Shut well in for 24 hours. 6. Returned well to production at 5:00 p.m., February 25, 197~ [~ C. '!~i~/. 400 489 BOPD, 78 BWPD March 4, 1977 DATE (This space for State office use) APPROVED BY. CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 G. J. Ross Area Superintendent September 7,.1976, File: GJR-681-WF Mr. Hoyle Hamilton, Acting Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Sundry Notices and Reports on Wells MGS 17595 Well No. 6 Attached is a State of Alaska Form 10-403 requesting permission to work on MGS17595 Well No. 6. We intend to acidize the well to remove accumulated scale and inject an inhibitor to prevent future scaleformation. Yours very truly, Area Superintendent Attachment Form 10 -403 ~EV. 1% 10-~ · "Intentions" irt T~ipllcate "Sub,~quent Reporls" tn Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SuNDRy NOTICES AND REPORTS ON WELLS (DO not usc this form for proposals to drill or to deepen Use "APP~,ICATION 'FOR Ib'EP, i~iT-~' '/or such 'proPosals.) · WELL WELL OTHER 2. NAME OF OPERATOR Amoco ProductiOn Company 3. ADDRESS OF OPERATOR P. 0. Box 779, Anchorage, Alaska 9'9510 4. LOCATION OFW~L` A'tsm:£ace Leg 2, Slot4, MGS Platform Baker, 1989' FNL, 588' FWL, Sec.. 31, T9N, . R12W, S'M. APl NU'B'I.ER~CAL CODE 50-133-10073 6. LEASE DES, IGNATION AND SERIAL, NO. ADL-17595 7. IF INDIA/q, A. LL`O'rrI~E OR TRIBE NA~LE 8. UNIT, FARM OR LE, ASE NAME MGS 17595 9. WELL NO. 6 10. FLEL`D A~D POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31, T9N, R12W, S,M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.' 12. PERMIT NO. RKB 71.36' above MSL 14. Check Appropriate Box To Indi'cate Nature of NOtice, Re ~ort, or Other Data NOTICE OF INTENTION ~O: FRACTUaE TREAT 8HOOT OR ACIDIZE REPAIR WELL MULTIPLE COMPI,ETle ABANDON' CHANOE PLANS Other) SUBSEQUENT R~POJT OF: FRACTL'RE TREATMENT ALTERIN0 CABIN0 SHOOTINO OR ACIDIZIN0 ABANDONMENT' (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE I'ROP08E'D OR CO.MPLETED OPERATION8 (Clearly state all pertinent details, and ,71vp pertinent dates, includin$, estimated dst~. of starting an)' proposed work. The following procedure is 'intended to inhibit future scale formation. 1. Acidize well with 8000 gallons 15% HC1. , 0 Inject' 5 drums scale inhibitor into formation (Arcohib S-239 polymer inhibitOr). Shut-in well for 12 hours. 16. I hereby ~tLfy that the fore~olngia true and correct (This apace for St~ttt office,~se) co~zTzo~ OF~'4~I~FKOYAr,, XF U TITLE Area Superintendent TITLE ~~~-~1--(~ ~ DATE September 7, 1976 . See Instructions On Reverse Side Al~mved Copy ~m No. P---4 P,~L~, a- I-?0 STATE G, AI.ASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS :~. NAMF. OF OPerATOR Amoco Production Company 3.ADDreSS OF OPm~OR P. O. Box 779, Anchorage, Alaska 4 LOCATION OF %VELA, Leg 2, Slot 4, MGS Platform Baker, Sec. 31, T9N, R12W, S.M. SUBMIT IN DUPLICAT~ ,i 99510 50-133-10073 6 LEASE DESIGNATION AND SERIAL NO. ADL-17595 ? IF INDIA~,Y. AL,O] I-EE OR TRIBE NAME 8. t~,'IT FA/IA{ OR LEASE NAME MGS State 17595 9 WELL NO 6 10 FLKLD AND POOL. OR WILDCAT Middle Ground Shoal SEC. T,. R. M. 0~OTTOM HOLE Sec. 31, TgN, R12W, S.M. PERMIT NO 66-3 "13. REPORT TOTAL DEPTH AT END OF MONTH. CHANGES IN HOLE SIZE, CAS1NG AND CEMENTING JOBS INCLUDING DEPTH SET AN]3 VOLLrMES USED. PERFOHATIONS. TESTS ANT) RESULTS FISHING JOB~ Jbq~;K LN HOLE AND SIDE-TRACKED HOLE A2qD A3~Y Oq~IER SIGNIFICANT CHA3~ IN HOLE CONDITIONS The 'subject well was worked over to abandon the sand and water producing "A" zone and convert the well to a single "BCD" zone Kobe lift pr~ci. A summary of the workover operations follows: Hay 26 Rig OC at 0001 hours. ,JJjJ May 26- Attempted to pull tubing. Tubing stuck at Model "F" sea~iVlSlON OFOIL AND { May 27 assembly at 5743'. Cut tubing at 5404' and fished for and ANCHORA , retrieved fish. May 28 Milled over,retrieved Model "F" packer at 5749'. May 29 Cleaned out with bit and scraper to 5775'. Set CIBP at 5760' and cement retainer at 5558'. Squeezed perforations 5576-5638' add 5644-5655' with 250 sacks Class G cement. Set cement retainer at 5498' and squeezed perforations 5522-5548' with 100 sacks Class G cement. Squeeze unsatisfacto=y. May 30 Resqueezedlperforations 5522-5548' with 150 sacks Class G cement. Set cement retainer at 5360' and squeezed perforations 5446-5481' with 150 sacks Class G cement. Set cement retainer at 5204'. May 31- Squeezed perforations 5300-5330' with 150 sacks Class G June 2 cement. Milled over and retrieved retainer set at 5204' and cleaned out to 5325' with bit. Pressure tested perforations 5300-5330' to 2000 psi and held okay. Milled over and retrieved retainer set at 5360' and cleaned out to 5498' with bit. Pressure tested perforations 5446-5481' to 2000 psi and held okay. Milled over and retrieved retainer set at 5498' and cleaned out to 5562' with bit. Pressure tested perforations 5522-5548' and pump in at 2-1/2 BPM at 500 psi. ~continued attached pa~e) , 14. I he~b, ~ Ft the ~rego~u27~n~ct S~GN~ ~-~4u-~o-~ ~-~--~' ~ Ar~a Superintendent D~T~, July. 15, 1974 NOTE--Report on thie'~rm is required ~r ~ calendar monthS regardless of the status of operations, and must ~ tiled In dupli~te with the oil and gas coneervat~n commlflee bythe 15~ of the succ~ding ~n~, ~le~ otherwise directed. State of Alaska Form P-4 MGS 17595 Well No. 6 July 15, 1974 Page 2 (continued) June 3 Set cement retainer at 5495' and resqueezed perforations 5522-5548' with 150 sacks Class G cement. June 4 Milled over and retrieved retainer set at 5495' and cleaned out to 5558' with bit. Pressure tested perforations 5522-5548' to 2000 Psi and held okay. June 5 Recovered retainer set at 5558' and cleaned out to 5600' with bit. June 6 Cleaned out to 5656' with bit. Pressure tested perforations 5576-5655' and pump in at 3/4 BPM at 1200 psi. Set cement retainer at 5559' and resqueezed perforations 5576-5655' with 250 sacks Class G cement. June 7- June 9 Recovered retainer set at 5559' and cleaned out to 5758' with bit. Pressure tested perforations 5576-5655' and pump in at 2 BPM at 1750 psi. Pressure tested annulus and. pump into perforations 5522-5548' at 2 BPM at 1450 psi. Set cement retainer at 5500' and resqueeze perforations 5522-5548' and 5576-5655' with 175 sacks Class G cement. Recovered retainer set at 5500' and cleaned out to 5565' with bit. Pressure tested perforations 5522-5548' to 2000 psi and held okay. Cleaned out to 5760' with bit. June 10 Pressure tested perforations 5576-5655' and pump in at 1-1/2 BPM at 1500 psi. Set cement retainer at 5562' and resqueeze per- forations with 100 sacks Class G cement. June 11 Recovered retainer set at 5562' and cleaned out to 5760' with bit. Pressure tested perforations 5576-5655' to 2500 psi and held okay. June 12 Milled over and retrieved bridge plug set at 5760'. Cleaned out to 6750' with bit. Set retrievable bridge plug at 6700' and packer at 6370' and acidized perforations 6420-6607' with 1500 gallons 15% HC1 acid and 1500 gallons scale inhibitor. June 13 Set bridge plug at 6400', packer at 6065' and acidized per- forations 6134-6353' with 1500 gallons 15% HC1 acid and 1500 gallons scale inhibitor. Set bridge plug at 6110', packer at 5730' and acidized perforations 5782-6054' with 1500 gallons 15% HC1 and 1500 gallons scale inhibitor. Pulled packer and (continued)bridge plug. Set permanent packer at 5750~ ~ ~ ~ ~ ~ ~~ ,IIIL ? I974 DI¥ISIOI'4' OF {)iL AND (;AS ANCI{0RAC,£ State of Alaska Form P-4 MGS 17595 Well No. 6 July 15, 1974 Page 3 (continued) June 14- Installed tubing and 2-1/2" Type E OPF Kobe cavity. RREL June 16 1300 hours 6-15-74. June 17 Reverse circulated power oil to clean out well and put on pump. June 18- Pumping N.G. June 22 June 23 Final report. Production prior to recompletion - "A" zone producing sand and water, "BCD" zone producing 344 BOPD, 4 BWPD, 122 MCFD. Production after recompletion - "BCD" zone producing 613 BOPD, 58 BWPD, 270 MCFD. 01L AND GAS Amoco Production Company P. O. Box 779 Anchorage, Alaska 99510 May 24, 1974 File: GJR-341-WF Mr. Homer L. Burrell, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Workover of MGS 17595 Well No. 6 Please find attached a State of Alaska Form 10-403 detailing the pro- posed work on the'subject well. This work was reviewed May 24, 1974 by telephone between your Mr. Hamilton and our Mr. Chism and verbal approval was given to proceed with the project. Yours very truly, George J. Ross Area Superintendent Attachment MAY ANCHORAG~ ~ For-~a .10-403 ' REV.,, ! - $0-7'J Subm/t "Intentions" in Triplic~t~ & "Sub.sequent l~eports" in Duplicate STATE OF A[3%SKA OIL AND GAS CONSERVATION CONVV%ITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this foTM for proposals to drill or to deepen use "APPLICATION 'FOR 15'ER~IT-L~' 'for such 'p~o~osals.) WELL WELL OTHI~R 2. NA,ME OF OPERATOR Amoco Production Company 3. ADDRESS OF OPERATOR P. 0. Box 779, Anchorage, Alaska 99510 4. LOCATION OF WFJ.I. At surface Leg 2, Slot 4, MGS Platform Baker 1989' FNL, 588' FWL, Sec. 31, T9N, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc. 14. PJ3B 7!. 36 ' above MSL Check ApproFriate I~ox To Indicate Nature of NOtice, Re NOTICE OF INTENTION TO : __ TEST WATEI~ SHUT-OFF PULL OR ALTER CA~IN0 FR&CTUaE TREAT MULTIPLE COMPLETE 8HOOT OR ICIDII[ i~i~.DONs . ~EPAIR W~LL CHANG[ PLAN] APl N~CAL CODE 50-133- 10 3a n C IF I~i~, ~'i-r~ ~IB~N~ ~,~c-N ~ ~: OiL AND GAS gNIT, FA~ ~'C~SE ~ MGS State 1~MORA~ 9. WELL NO, 6 10. FLEL,D A2qD POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31, TgN, R12W, S.M. 12, PEI~M_.IT NO. 66-3 WATER SHUT-OFF FRACTURE TREATMENT J eaooriNo o. ACmZZINO (Other) :ort, or Other Dete · ~.~,~E,T R,PO.T 0.: ALTERIN0 CASINO ABANDON ME~fT· tOther) (Norz: Report results of multiple completion on Completion or Reeompletion Report and Log form,) 15. DESCRIBE PROPOSED OR COMPLETED OPERAT1ONe (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting proposed work. The subject well was completed in the "A" zone in April 1973 and dually completed with the-"BCD" zone. The "A" zone very quickly began producing large volumes of sand and water and was shut-in by closing the sliding sleeves opposite the zone. Subsequently, the well has been produced as a single "BCD" producer with the "A" zone shut-in. Recently the "A" zone com~nunicated with the "BCD" and the well was shut-in due to sand and water production. We proposed to abandon the "A" zone and complete the well as a single "BCD" zone Kobe lift producer as follows: 1. Squeeze the "A" zone intervals 5576-5638' and 5644-5655' with 250 sacks Class G cement. 2. Squeeze the "A" zone interval 5522-5548' with 100 sacks Class G cement. 3. Squeeze the "A" zone interval 5446-5481' with 125 sacks Class G cement. 4. Squeeze the "A" zone interval 5300-5330' with 100 sacks Class G cement. 5. Drill out and test each zone to 2000 psi and resqueeze if necessary. 6. Acidize the "BCD" zones in three separate stages with 1500 gallons 15% HC1 per stage and isolate the stages by packer and bridge plug. 7. Set a Baker Model "F" packer at 5750' and put the well on Kobe lift. Verbal approval given for the above work by telecon May 24, ~974 between'Messrs. Hoyle Hamilton and Lloyd ChiSm. 16. I hereby c~ffy that the fore--freer S~ONmD ~/~':_a~lC~-~, (~ya--~"~;I, ?,VLm Area Superintendent May 24 1974 (This space for State office use)__ See Instructions On Reverse Side l~rm No. STATE Or-' AI.A~KA OIL AND GAS CONSERVATION COMMll-I'EE SUBMIT IN DUPLICA~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1, OIL L...J OTHER WELL [] GAR WELL NAME OF OPEP,.ATOR Amoco Production Company 3. ADDRESS OF OPEP,,ATOR P. O. Box 779, Anchorage, Alaska 4. LOCA~'~ON OF WELL 99510 At surface: Leg 2, Slot 4, MGS Platform Baker, 1989' FNL, 588' FWL, Sec. 31, T9N, R12W, S.M. ~. API'NU~iEFLICAL CODE 50-133-10073 'LEASE DESIGN'A'i~ION AND SEBIAL NO. ADL-17595 IF INDIA]~, ALOTT'EE 0]~ TRIBE NAME 8. L.~IT FARM OR LEASE BLAME MGS 17595 9 WELL ?,,'o 6 10. FIF_.LD A.ND POOL, OR WILDCAT Middle Ground Shoal 11 SEC., T., R., M., fROm'TOM HOLE oa,rF, m-n~ Sec. 3!., T9N, R12W, S.M. 12, PEP. MIT NOr 66-3 -13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED. PERFORATIONS. TESTS AND RESULTS FISHING JOBI$ SU'NK LN HOLE AND SIDE-TI~ACKED HOLE A~ND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Summary' of 0Perations. D. urin.g. July, 1973: July 1- 31: Producing "BCD" zones under gas lift. Recompleted as "BCD" zone producer ("A" zone shut-in). AUa 2 3 Production Su, t.... Au~.ust 22, 1973 August 16, 1973 File: WMJ-447-WF Mr. Homer L. Burrell, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504. Dear Sir: Re: Recompletion Report MGS 17595 Well No. 6 Amoco Production Company P. O. Box 779 Anchorage, Alaska 99510 Attached is a State of Alaska Form P-7 reporting recompletion of the subject well. Our original intent was to commingle production from the "A" and "BCD" zones in this well, but the "A" zone was shut-in May 12,. 1973 due to the severe sand production problem associated with producing that zone. Inasmuch as the "A" zone is shut-in, we do not plan to perform semi-annual spinner surveys as authorized by Division of Oil and Gas Administrative Approval 44.14 dated March 21, 1973. As discussed during a telephone conversation between Messrs. O. K. Gilbreth and G. R. McGregor on August 14, 1973, we were unable to obtain a separate production test of the "A" zone and presently no additional work is planned to attempt to restore production from that zone. Yours ver_~ Dist r±c[ 7od'~c~ion Superintendent Attachments Dl~';~clCi"4' · .--, ' ' CF ,~£~ AND GAS A,~CHORAG~C PRODUCING INTI~atVAL(S), OF THIS C(~MPLETIO~--TOP, BOTTOM, NAME (MD AND TVD)* '5782-6607', B, C, D zones, ~Middle Kenai Member FO r m ~)---'7 , ~i ,' SUBMIT IN DUPI it. I* STATE OF ALASKA ~seeot.;,r ' r' structions on OIL AND GAS CONSERVATION COMMITTEE re~,'~ ~d~ ~'aP~ 50-~33-~0073 i. i ii i i i i~-m ................--- WELL COMPLETION OR RECOMPLETION REPORT AND LOG* ~L-17595 ii la. TYPE OF WELL: OIL ~ ,;AS ~ WELL WELL DRY Olbor ?. 1F I~1~, ~'I'TEE OR TRIBE N~ b. TYPE OF COMPLE~OH: W~bL OV~a ~N ~ACK RESVa. Other a. :UNIT,F~ OR L~SB a. s~ o~ o~,~oa ' ~ MGS State 17595 ~oco Production Company ~ '3. ~,oa~ss o~ o~Ea~To~' ~. ' ~ 6 0. BOx f79~ Anchorage~ Alaska 99510 ~. LOCATION OF WELL (Report location clearl~ and in accordance with a~p ~tate requirem~flts)* Middle Ground Shoal xt~,~ce Leg 2, Slot 4, ~GS Platform Baker, ~989' FNL, n,s~c.,~.,~.,~.,~o~o~o~ 588' ~L, Sec. 31, T9~, R12W, S.M. At top prod. Interval reported below · : 1921' FNL, 688' ~L, Sec. ;31, JT9N, R12W, S.M. Sec. 31, T9N, R12W, S.M. At total dep~ ' -;~ 1906' F~L, 737'' FWL, Sec. ~'31, ;TgH~ R12~ S.H. ~ ' ~ 66-3 ' 13. DA~SPUDD~ [14. DATET.D.~CHED[15. D~CO~PSUSPOaABAND. II6.'~EVATIONS,DF RKB KT Ga ~)*',q EL,V CASINGHEA-- ' ' I - ' ' ~' ' IB~h~e'n~ea~ O6~let 1-28-66 3-1~-66 7-~8-73 [ ~B 71.36' above HSL ~6~.56' above HSL 18. T~AL DMH, ~ & TVD ~9. PLUG, ~CK7400' 16750 6747' MD & ~D~. ~ ~L'I'~LE CO~L., TVD : lin. ~OW~Y* ROTAR~ TOOLS CABLE TOOI.,~ ,____'~D, ..... 0 - 7400 --- 23. WAS DIRE~ONAL SURVEY MADE Yes '124. TYPE ELECTitIC AND OTHE, It LOGS RUN. ~: , CASING SIZE 20" 13-3/8" DIL, Sonic, FDL,, PML, CBL, Temperature -' CASING RECORD (Re rt all );trings set in well) ' . 79.6 {a~.,~.o [ 612' 26" 742 sx neat, 450 w/ CaCl{ 54.5 ! J-55 { 2010' 17-1/2" 1200 sx w/ OEL~ 100 sx w/] CaC1 26 ] J-55 ~ 7397' 8-,5/8" 960 sm w/ TIC, 940 sx' ne~t 26. LINER R~CO~tD 27. TUBING RECOI~D SIZB TOP (1VID) IaOTTO1V[ (MD) SACKS CmlENT* SCREEN (MD) SIZE DEPTI{ SET (MD) [ PACKER SET (MD) 3-1/2" 5743 5265' 2-7/8" '6602' 5743' 28. PERFORATIONS OPEN TO (Interval, size and number) 5782-5805', 5854'5905', 5920-5950', 5960- 5990', 6022-6054', 6134-6150', 6156-6186' , 6200-6240', 6260-6280', 6290-6310', ?6325- 6335', 6348-6353'., 6420-6430', 6434-6448', 650 8-6540' , 6602-6607' all 2JSPF ~ : 29. ACID, SI!OT, D~PTII iICi'EttVAL (MD) 30. · PI~ODUCTION DATE FIRST PiZODUCTION [ PI~ODUCTION MEIHOD (Flowing, gas lift, pumping--size and type of pump) [WELL ~"l~A~l'0§ (P~oducing or 4-29-66 't Orig. Completion-~flowing; Present Method-gas li~t producing 'DATI~ OF T~I~T. 1I-['6URS TF~STEiD'[~IOIiE SIZE [P~OD'N' FOR OI~BBL. ' ~A~CF. WATEr--BBL. [ GAS-OIL ~ATIO 5-22~7} [ 24 !124/64 { ~' 1. 706 . { 529 { 24 { 749 FL~W,~.~BING [CASING P~SSU~ {2.~-HOUR R~L~~ .... OI~BBL. GA~N~. WA~BBL. ,lOlL dRAVITY-~I (CORR ... ll0 I --- I r' > 706 [ 529 I 24 I 32'2° 31. uxseos~ws ce ~as (~old, Used yor ]~e{, vented, etc.) I TEST WITNESSED BY Used for f nd sold 32. LIST OF ATTACHMENTS .~ hereby 8n~ attaehe~ lnformstion ~ w~wnn' District Production Supt. p~ 8-~-73 , and Space's [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion rep. orr and log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- 'merits given in other spaces on this form and in any' attachments. Items 20, and 22:: If this well is completed for separate production from more than one interval zone "(multiple completion), so state in item 20, and in item 22 show the prcducing interval, or intervals, - top(S), bottom(s) and name (s) (if any) for onlY. the interval reported in item 30. Submit a separate report ' :-(page) on this form~ adequately identified, for each additional inte, val to be. seperately"produced, show- - ' ing'the acklitional data pertinent to such interval. ' ..... ' _ - . . ' Item26: ",%cks Cement": Attached supplemental records for this well should show the details of any mul- -.~ · ..tiple stage cementing and the location o~ the cementing tool · Item 28:-Submit a '~separate completion report on this form for each interval tO be separ'ately produced.· '- (See instruction for items 20 and 22 above).. · · 34. SUMMARY OF' FO~'ViATION TESTS.INCLUDING INTERVAL TESTED, Pl~ _k'~-_qURE DATA A.N'D ~ECOVERIES OF OIL, GAS, ' ' .' ' . · ~ - ....... ' · ' ',,."'L GEOLOGIC ,.~'A~-~,~.,.,,..,.,.,.~.~ "" ~'- ' · WATER AND MUD .. .: . . .. . .......... _- . ~ HAME .MEAS. DEPTH ; . · .. L. ~ . · . .... · . . . ; . .... .. , · . · . . · .. . ,. .,~ -. ~ ~ ..... . . ,~ . 35. CORE DATA. ATTACtt BRIEF DESCRIPITIOlqS OF LITHOLOGY, POHOSITY, FRACTURE~, APPAP,.ENT DIPS .'-:' ~'-'' '"'-.,' '. .: ,~- "'. AND DETEC~I'ED SHOWS.OF OIL,, GAS OR W.A'I~IR. .~ .. .~ '2'. , ! t ! · .... . ,. .~. . . . · · . ........ · · · . .. _ . . · . ~ / · ...... · · RECOMPLETION HISTORY Middle Ground Shoal 17595 Well No. 6 4-7/9-73 4-10/14-73 Killed well and pulled production equipment. Cleaned out to 6720' and perforated 5782-5783' and 5654-5655' with 4JSPF. Set retrievable bridge plug at 5840' and retrievable packer at 5670' and pressured tubing to 1500 psig and verified no communication between "A" and "B" zones. Perforated the following "BCD" zone intervals with 2JSPF: 5782-5805' 5854-5905' 5920-5950' 5960-5990' 6022-6054' 6134-6150' 6156-6186' 6200-6240' 6260-6280' 6290-6310' 6325-6335' 6348-6353' 6420-6430' 6434-6448' 6508-6540' 6602-6607' Perforated following "A" zone intervals with 4JSPF: 5300-5330 ' 5446-5481' 5522-5548' 5576-5638' 5644-5655' Cleaned out to 6720'. Ran permanent production packer and set at 5743'. Ran gas lift equipment and set hydroset packer at 5245'. Pressure tested packer seal at 5245' to 1500 psig and okay. Returned well to production gas lifting "BCD" zones only. 4-15/30-73 Opened "A" zone sliding sleeves at 5405' and 5677' on 4-15-73 and producing "A" and "BCD" zones commingled. 24-hour production test of "A" and "BCD" zones com- mingled on 4-30-73: 1062 BOPD, 373 BWPD, 730 MCFD at 110 psig TPF. 2 0 'I 73 DIV:51C i,l C;F O~L AIqD CAS /' !' '.CHORAGE Recompletion History MGS 17595 Well No. 6 Page 2 5-1/4-73 Ran flowing gradient pressure survey. Ran tubing plug with BHP bomb and unable to set. Ran second plug 5-3-73 with BHP bomb and set in "F" nipple at 5779'. "A" zone would not produce under gas lift. 5-5/9-73 Attempt to pull plug and BHP bomb and found sand fill in tubing at 5754'. Bailed sand out of tubing to plug and recovered plug and BHP bomb. "BCD" zone BHP build- up under plug to 1784 psig in 120 hours (5-4-73 to 5-9-73). 5-10/11-73 Returned well to producing "A" and "BCD" zones commingled. "A" zone producing large volume of sand. 5-12-73 Closed "A" zone sliding sleeves at 5405' and 5677'. 5-13/21-73 Producing "BCD" zones under gas lift. 5-22-73 24-hour production test of "BCD" zones: 706 BOPD, 24 BWPD, 529 MCFD at 110 psig TPF. 5-22-73 to 7-17-73 Producing "BCD" zones under gas lift ("A" zone sliding sleeves closed 5-12-73). Reviewing additional workover alternatives. 7-18-73 RecomPleted as "BCD" zone producer under gas lift. 24-hour production test of "BCD" zones on 4-4-73 prior to this recompletion: 83 BOPD, 2 BWPD, 363 MCFD at 80 psig TPF. Special. production tests of this well by spinner survey to allocate "A" and "BCD" zones production as authorized by Division of Oil and Gas Administrative Approval No. 44.14 dated March 21, 1973 will not be per- formed due to "A" zone shut-in. l~rm No. REV, ~- I-?0 STATE O~ ALASKA OIL AND OAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1, OIL [] GAB ~'~ OTHER WELL wELL NAME OF OPI~%ATOR Amoco Production Company P. 0. Box 779, Anchorage, Alaska 4. LoCATIoN OF V/gl.l, At Surface: SUBMIT IN DIJP. LICAT~ 99510 Leg 2, Slot 4, MGS Platform Baker, 1989' FNL, 588' FWL, Sec. 31, T9N, R12W, S.M. APl 'NIn~EPdCAL CODE 50-133-10073 LEASE DESIGNATION AND SERIAL NO. ADL- 17595 7 IF INDIA~, AI.~TTEE OR TRIBE NAME . 8. I~,'IT FAP,~ OR LEASE NAME MGS State 17595 9 WEIJ., NO 6 i' 10.' FI~) ~.x;I) POOL. OR WILDCAT Middle Ground Shoal '1I SF~, T.. R.,'M. (BO'I~FoM HOI~E Sec. 31, T9N, R1.2W.,. S.M. 19.. PIgR1VIIT NO. 66r:~ , 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUM]~ USED. PF~H.FOHATIONS, TESTS AND RESULTS FISHING JOB~ JUNK IN HOLE AND SIDE-TRACKED HOLE AND ~NY OTHER SIGNIFICANT CH.A_NGES IN HOLE CONDITIONS Summary. of Operations During June-1973:. June 1-30: Producing "BCD" zones under gas lift. ("A" zone sliding sleeves were closed May 12, 1973.) JUl_ 2 4 1973 DIVISION OF OIL AND GAS ANCHORAGE i4. I- hereby...~ertify t~at the ~ore~oir~ is~true and correct tlO~'E ---Rel)ort on this form it required for~,e~h colendar months regerdiess of the etotus of operations, and must oo filed in duPliOQte with the oil and gee coneervat/on committee bythe 15th of the succeeding month, tmle~ otherwise directed. June 14, 1973 File: WMJ-329-WF Amoco Production Compan P. O. Box 779 Anchorage ,- Alaska 99 51¢ "J C. GEOLJ ! c. ~ ~. I ~ ENG, ~ J 3 ENG --]' 4 ENG. J ,5 ENG I ~ O~OL J_/L --T'~'. g~o~-'.~ I 8 GEOL I R~v '~_ I DRAFT "-I s'~c .... CONFER: FILE: - Mr. Homer L. Burrell, Director Division of Oil and Gas Department of Natural Resources State of AlaSka 3001 Porcupine D~ive Anchorage, Alaska 99504 . Dear Sir: Re: MonthlY RepOrt of Drilling and Workover Operations GMGS 17595 Well No. 4 S 17595 Well No. 6 SMGS Unit Well No. 11 Attached are State of Alaska Forms P-4 reporting workover operations on the subject wells for the month of May 1973. Yours very truly, W. M. Jones District Production Superintendent At t a chmen t s OiL ,"-ND .GAS Form ~o. P--4 I~V. 3-1-70 STATE Ol--ALASKA OIL AND GAS CONSERVATION COMMI'rI'EE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS ~. NA~ OF O~R~TO~ Amoco Production Company ~. ADDRESS Or OPERATOa P. O. Bo× 779~ Anchorage~ Alaska 4. ~CA~ON OF W~ SUBMIT IN 13UPLICAT~ Surface: 99510 Leg 2, Slot 4, MGS Platform Baker, 1989' FNL, 588' FWL, Sec. 31, T9N, R12W, S.M. AP1 NUMER/CAL CODE 50-133-10073 6 LF, ASE DESIGNATION AN'D SERIAL NO. ADL-17595 IF INDIAI~, ALOTTEE OR TRIBE NAME 8. L,~IT FAR~ OR LEASE NAME MGS State 17595 9 WELL 6 10 FIEI~ AND POOL, OR WILDCAT Middle Ground Shoal .... n sm:, T., R.', M. CBOe'rOM ~OLE oaJr~-rrv~ Sec. 31, T9N, R12W, S.M. 12, PERMIT N'O, 66-3 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA~NGES IN HOLE SIZE, CASING AND C~/IENTING JOBS INCLUDING DEPTH SET AND VOLUM]~ USED. PERFO~TIONS, TESTS A/qD RESULTS FISHING JOB// JUNK I3q HOLE AND SIDE-TRACKED HOLE A~D A~Y OTHER SIGNIFICANT CHA~GES IN HOLE CONDITIONS. S ..ummary of: Op.eratio. ns During May 1973: May 1 Commenced packer leakage tests. May 2 - 4 Ran BHP bomb and tubing, plug to set above "BCD" zones. "A" zone woUld not produce under gas lift. May 5 - 9 Unable to retrieve BHP bomb and tubing plug. Cleaned sand from tubing and removed BHP bomb and tubing plug. Returned well to producing "A" and "BCD" zones under gas lift and producing significant quantity of sand from "A" zone. Closed "A" zone sliding sleeves. Producing "BCD" zones under gas lift. May 10 - 11 May 12 May 13 - 31 14. I hereby certify that the ior~in~g is 7~e and corre~ s]~m,r~:~ '~')', ','~/ ' /.~~.7~r ~T~S District Prod: ~E~ ~ June 12~ 1~7~ oil arid gas conservotlon commiflee bythe 15~ of the succ~4ing ~n~, ~le~ otherwise directed. Amoco Production Company P. O. Box 779 Anchorage, Alaska 99510 May 21, 1973 File: WMJ-274-WF Mr. Homer L. Burrell, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: Re: Monthly Report of Drilling and Workover Operations MGS 17595.Well No. 6 Attached is a State of Alaska Form P-4 reporting workover operations on the Subject well for the month of April 1973. rs very i~' WDis tM~icJ%n~r~Uction supsy/ erint endent Attachment ,,V'orm N'o. P.--4 R, EV. 3- I-?0 STATE Or ,a&ASKA OIL AND GAS CONSERVATION COMAAITTEE SUBMrT llW DUPLICAT~ MONTHLY REPORT OF DRILLING AND WOR'KOVER OPERATIONS WELL ~. NAME OF OPIIRATOR Amoco Production Company. . 3. ADDRESS ~DF OPERA. TOR P.O. Box 779~ Anchorage~ Alaska 4. LOCA'nON or Wr. LL 99510 At surface: Leg 2, Slot 4, MGS Platform Baker, 1989' .FNL, 588' FWL, Sec. 31, T9N, R12W, S.M. AP1 NUA~ER/CAL CODE 50-133-10073 LEASE DESIGNATION AND SE1RIAL NO. ADL 17595 7 IF INDIA~T, ALOTTEE OR TRIBE NAME 8. L~IT FA/%M OR LEASE NAME MGS State 17595 g WELL NO 6 10 FLF_J~D A-~D POOL, OR WILDCAT tidd,l,e Ground Shoal II SEC., T., R., M.. (BOTTOM HOLE oa,rmc'rnz~ Sec. 31, T9N, R12W, S.M. 11. PERMIT NO 66-~ , , '13. REPORT TOTAL DEPTH AT END OF MONTH, CHA.NGF_,S IN' HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLU1VIES USED. PERFORATIONS. T~,STS AND H.ESULTS FISHIATG JOt$S JUNK IN HOLE AND SIDE-TP,,ACKED HOLE AND ANY OTHER SIGNIFICANT CH. ANGI~S IN HOI.~ CONDITIONS. Summary .of Operations During. April. 1973: April 7 - 9 April 10 - 14 April 15 - 30 Killed well and pulled production equipment. Cleaned out to 6720', perforated 5782-5783' and 5654-5655' with 4JSPF. Tested for communication between "A" and "B" zones and okay. Perforated "BCD" zones: 5782-5805', 5854-5905', 5920-5950', 5960-5990' , 6022-6054' , 6134-6150' , 6156-6186' , 6200-6240' , 6260-6280', 6290-6310', 6325-6335', 6348-6353', 6420-6430', 6434-6448', 6508-6540' and 6602-6607' with 2JSPF. Perforated "A" zone at 5300-5330', 5446-5481', 5522-5548', 5576-5638' and 5644-5655' with 4JSPF. Cleaned out to 6720'. Ran packer and set at 5750'. set hydroset packer at 5252'. gas lifting "BCD" zone. Ran production equipment and Returned well to production, Opened "A" zone sleeve April 15, 1973 and producing "A" and "BCD" zones commingled. Obtaining production tests. District Prod. Sup_~___~,~. May 21, 1973 ,, April 4, 1973 File: WMJ-176-WF Mr. Homer L. Burrell, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: Re: Sundry Notice of Intent - Recompletion of Middle Ground Shoal 17595 Well No. 6 Attached herewith is a State of Alaska Form P-3 reporting our intent to recomplete the subject well. Ultimately, Well No. 6 will be a commingled producing well from the "A" and "BCD" zones, which has been authorized by Division of Oil and Gas Administrative Approval No. 44.14 dated March 21, 1973. Work is expected to begin about April 6, 1973. The recompletion plans were discussed during a telephone conversation between Mr. O. K. Gilbreth and Mr. B. R.~k~ard on April 3, 1973. /z W. M. JoneseS.. District ~14~dtion Superintendent Attachment " ~ ~u GAS Form ~'-3 REV. 9-30-6 9 S~brntt "Intentions" in Triplicate ~ "Subseqaent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION: COMMII-[EE SUNDRY NOTICES AND REPORTS ON WELLS 56. APl N~CAL CODE 50-133-10073 · LEA~E DESiGNATiON A.ND SERIAL NO. (Do not use this form for proposals to drill or to deepen ADL- 17595 7. IF INDIA_N. ALLOTTEE OR TRIBE NAME 2. NAME OF OPERATOR Amoco Production Company APR 5 P. O. Box 779 ~. ~choraae~ Alaik~.,r~l~ . ' 4. LOCATION OF W~L ~ ~ ~t,~,-r~ Leg 2,. Slot 4, ~S Platform Baker, 1989' ~L, 588' ~L, Sec. 31, TgN, R12~., S.R. 8. UNIT, FARM OR LEASE NAME MGS State 17595 9. WELL NO, 6 10. FIEIA) AND POOL, OR WILDCAT l~ddle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOI.~E OBJECTIVE) Sec'. 31, TDN, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc. 12. PE'HiVIIT N'O. ! RDB 71.36' aboVe MSL ] 66-3 ,4. Check Appropriate Box To I,nd}c~te Nature of Notice, Report, or Other D~ta NOTICE OF INTENTION TO: TEST WATER 8HUT-0FF PULL OR ALTER CASIIN0 FRACTURE TREAT MULTIPLE COMPI.ETE SHOOT OR ACIDIZE ABANDON® REPAIR %','ELL CHANGE PLAN8 ~Other) { ~ 8UBmEQUENT R~PORT OF: WATER 8ItUT-OFF [ FRACTURE TR,ATMENT 8HOOTINO OR ACIDIZINO REPAIRINO WELL ALTERINO CASINO ABANDON MEBfT$ (Other) (NOTE: Report results of multiple completion on Well Completion or Reeompletion Report and Log form,) !5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. We propose to recomplete this well from a "BCD" zone producer to an "A-BCD" zone commingled producer. Commingling of the "A" zone with the "BCD" zones was authorized under Division of Oil and Gas Administrative Approval No. 44.14 dated March 21, 1973. The plan for the recompletion work will be: (1) Kill well and pull existing downhole equipment. (2) Clean out to PBTD at 6750'. (3) Perforate 4 holes at 5654-5655' (bottom of "A" zone) and 5782- th~ "A" "B" 5783' (top of "B" zone) and test for communication between and zones with packer and bridge plug. If communication exists, cement squeeze to provide zone isolation. (4) Perforate the "BCD" zones as follows at 2JSPF: 5782-5805', 5854-5905', 5920-5950', 5960-5990'., 602'2-6054', 6134'6150', 6156-6186', 6200-6240', 6260-6280', 6290-6310', 6325- 6335', 6348-6353' , 6420-6430', 6434-6448', 6508-6540', and 6602-6607'. Perforate the follow- ing "A" zone intervals at 4JSPF: 5300-5330', 5446-5481', 5522-5548', 5576-5638' , and 5644- 5655'. (5) Clean out to PBTD at 6750'. (6) Set a permanent production packer at 5750' between the "A" and "B" zones. (7) Run a single, tubing string with gas lift mandrels and a hydroset packer to be set at approximately 5250', above the "A" zone. (8) Land tubing and set hydroset packer. (9) Test packer at 5250' for competent seal. (10) Put well on commingled production and obtain commingled production test. (11) Run packer leakage test on packer at 5750' and obtain production test on the "A" zone only. (12) Assuming all packers are sealing properly, put well on commingled production. On a semi-annual basis, special production tests utilizing spinner surveys will be conducted for zone production allocation as_~er Divis'~ of Oil and Gas Administrative Approval No. 44.15 dated March 21, 1973. Recomp~etion?'~rk ~s anticipated:to begin about April 6, 1973. 16.1 hereby eertif/h~ fo/~oin,yirue/ /' and correct ////] /~V//~~ m District P~Oduction Su t 4-4-7~3 ___ (This space for CONDITIONS 0'~ 'Ai~I~9~AL, IF l~; '~' ~ -'- See Instructions On Reverse Side Approved R~turned Form P--12 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE RESERVOIR PRESSURE REPORT *See Instructions on Reverse Side Operator Pan American Petroleum Corporat2on Address Box 779, Anchorage, Alaska 9950'1 Field I 1 Date lVli&lle Ground ~ih0al , County : Kenai Borough ?roducingBCD Formationpool Oil~..: Gradient Water Gradient Initial Completion* Special* AnnualGeneral Survey*~llrv~]j. t --6000Datum PlaneM~L Gas Gravity ' ' ~'~ :: c ,' 1~ Shutkln Bom~ Test Da'ta ~, , .:. ' , .:, Sonic Instrun~ent Tdst Data ' ..... Pressure 'T ' Prod. T~-~" Wt. of Wt.' of :' ~ ~ Date ~ ~ 'Tubing Test B.H. Observed (Bbls. Der Day) Liquid Liquid tLiquid Gas Casing at Lease .. · ~ ~ ' Tested ~ PresSure ' ,, Temp. pressure~. Level Gradient O ~ Depth .Oil ~ Pressure Datum ' '~ Wa*er Column Column 17595 .. 6'.r 0 4/2169 24 6074 MD 1607 0.33 1607 ' , ' ,: I -6000 M~L , · - .. , .. . . . . : · . ~ · .. O , ,,, )esignate type of report by "X". CEaTIFICATE: I, the undersigned, state that ! am the.A.....r..~a ~U~.~t. of the ~.n._A_m....e..T.i..c_a..n._.pet, Corp, (company), and that I am authorized by said company, to make this report; and that this report was prepared under my supervision and direction and that the facts stated therein are true, correct and complete to the best of my knowledge. Or~ S/./~l By · ~ L IEREBI.L.L Signature MINER PUBLISHING; CO. INSTRUCTIONS FOR RUNNING AND REPORTING BOTTOM HOLE PRESSURES This report shall be mailed, in duplicate, not later than the l~;th day of the month immediately following the month in which the tests were made. All bottom hole pressure tests reported herein shall be made by a person qualified by both training and experience to make such tests° 1. Oil gradient shall be in pounds per square inch per foot. 2. Water gradient shall be in pounds per square inch per foot. 3. Datum plane shall be in feet plus or minus sea level. 4. Gas gravity shall be determined from an analysis of the casinghead gas. Date Tested--Enter in this column the month and day on which the bottom hole pressure test was made. ~;. Shut-in Time--Shall be reported accurately to nearest hour. The well tested shall have produced its normal daily rate of production or allowable within the 24-hour period immediately preceding the time at which it was shut in. (Any deviations shall be certified to on this report and shall be approved by Alaska Division of Oil and Gas.) ?. Test Depth--Shall be reported in feet as the lowest point to which the bomb was run and shell be reported in feet plus or minus sea level. 8. Bottom Hole Temperature--Shall be reported in degrees Fahrenheit as determined at test depth by either a recording or maximum read- lng thermometer. Observed Pressure---Shall be reported as the pressure in pounds per square inch gauge observed at test depth before any necessary tem- perature correction has been made. 10. Production Test--The oil and water reported shall be from a representative production test immediately preceding the time at which the well was shut in. l 1. Fluid Level--The fluid level reported shall be in feet above the datum plane. 12. Fluid Gradient--Shall be in pounds per square inch per foot and shall be representative of both the oil and water gradient where the well produces water as well as oil. 13. Weight of Oil Column shall be in pounds per square inch. 14. Weight of Gas Column shall be in pounds per square inch. lS. Casing Pressure---Shall be reported as the pressure in pounds per square inch gauge. 16. Datum Pressure-- (a) In the case of bomb measurements, this pressure shall be the observed pressure after the corrections for reservoir temperature and for the difference between test depth and datum plane have been made. (b) In the case of sonic measurements, this pressure shall be determined from the weight of the fluid column plus the weight of any gas present above the fluid column plUs casinghead pressure after proper corrections are made for temperature. Calibration--the subsurface pressure instrument shall be calibrated against a dead weight tester both prior and subsequent to the dates at which ali tests reported hereon are made, and in no case shall this time exceed a period of one month. The prior and subsequent calibra- tions shall not disagree by more than on~ per cent (1%). The dead- weight tester used for the calibration shall be approved by the Alaska Division of Oil and Gas. Fo~m No. P--4 P~E~. 9-30-67 STATE OF ALASKA O~L AND GAS CONSERVATION COMMITTEE , . tMONT'HLY REiPORT OF DRILLING AND WORKO¥~ OPERATIONS SUBMIT IN DEPLICATE l. WELL WELL OTHER 2. NA/VIE OF OPEI{ATOR Pan American Petroleum Corporation 3. ADDRESS OF OPERATOR ~' -~. AP1 NU~¢ERICAL CODE None Assigned 6. LEASE DESIGNATION AND S~IAL NO. ADL - 17595 7. IF INDIAN, ALOTTEE OR TRIBE NAME 8. LrNIT,FA_R~M OR LEASE NAAIE Middle Ground Shoal State 17595 9. WELL NO. P. O. Box 779- Anchorage, Alaska 99501 6 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M.. {BOTTOM HOLE OBJECT~) Sec. 31, T9N, R12W, S.M. 12. PERMIT NO. 66-3 4. LOCA~ON O~ WELL Leg 2, Slot 4, MGS Platform 'B'; 1989' FNL, 588' FWL, Section 3, T9N, R12W, S.M. 13. REPORT TOTAL DEI~TH AT END OF MONTH, CH-A_NGES IN HOLE SI~E, CASING ANT) CEMENTING JOBS INCLUDING DEPTH SET AND VOL~ USED, P~ORATIONS, TESTS A-ND RESULTS, FISHING JOBS, JUNK IN HOLE A_ND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICA2qT CHA~ES IN HOI.~ CONDITIONS. 5/21 5/l 5/2 5/3-6 5/7 5/8-9 5/10-13 5/14-20 PBTD 6750'. Recompleted as a flowing oil well. Reran pump. Pumped 242 bbls load diesel and pump broke down. Repaired and reran pump to 6006'. Pumped 2-1/4 hours and broke down. Pulled pump and scraped casing. Flushed perfs 6607-5795' with 1500 gal mud acid and squeezed perfs with 50 bbls acid at 0-500 psi. Reran pump. Pumped 266 BF in 8 hours. Elec. pump cable arced across wellhead stuffing box, blowing out stuffing box. Tubing parted at wellhead. Prior to failure, pumped 433 BF in 13 hours at FTP 1200-100 psi. Fished out tubing and pump. Installed tubing with gas lift valves and set at 6675' with packer at 5742'. Gas lifting. 14. I hereby certify ~e for;~mg ct smmm '/<' ' /"~'/{'~r ~TLE Ass't. Area Admin. Supvr. nA'~'~ 6-11-68 NOTE--Report on this fOrm is r~re'd for each calendar month, regardless of the status of operations, an~ must ~ file~ in duplicate wKh the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~ise directed. '/ Form P--7 ' ~ ~ SUBMIT !N DUPLICi. ~fATE OF ALASKA ',Seeother OIL AND GAS CONSERVATION COMMITTEE re~e,'~e la. TYPE OF WELL: oH, ~ WZI. L W~LI, ~ DaY ~ Other b. TYPE 0F COMPLE~ON: ~VELL OVER gN haCK RE~VR. Other DATA UNCHANGED F~OM PREVIOUS REPORTS EXCEPT AS SHO~'? BELOW: 2. NAME OF OPERATOR Pan American Petroleum Corporation 3. ADDRESS OF OPERATOR :~ ~ P. 0.' B~X 779- Anchorage, Alaska 99501 ~. LOCATION OF WELL (Report location clearlp and in accordance with any State requirements)* 5.. AP1 NUMEI~CAL CODE ~ . Non.e__A.s_,s_._i_gned 6. I/EASE DESIGNA'VION AND SERLA~ NO. ADL- 17595 7. IF INDIA. N, AJ-J-A)TTEE OR TRIBE NAME 8. UNIT,FAa'I~ OR LEASE NAME MGS State 17595 9. WELL NO. 6 10i FLELD A~D POOL, OR WILDCAT Middle Ground Shoal At surface At top prod. interval reported below · At total depth 11. SEC., T., R., M., (BOttOM HOLE OBJECTIVE) ;,Sec 31, T9N, R12W, S.M. lZ. PI~RJVIIT NO. 66-3 13. DATE SPUDDED 14. DAT'~. T.D. RF_d~CI-I~:I.) 15. DATE CO.NIP SUSP OR ABAND. 16.' EI-~VATIONS (DF, RKB, 5/,12/6s 6750' ' ~ow~w* .OT~X- TOOLS I~. PRODUCING IN'rP_kHVAL(S). OF THIS COMPI-~TIOi~--TOP, BOTTOM, NAME (MD AND TV]))* 5795 - 6607' "B,C D" Middle Kenai Member , , zones, · . · 24. TYPE F-J-~C'i'itlC AND OTHER LOGS RUN. ~ C~SLNG SIZE ,~ ,. .i II CASING RECORD (Report all strings set in well) WEIGHT, LB/FT. DEPTH SET. (M.D) HOLE SIZE ! RT, GR, ~FC)*[17. ELEV. CASINGHEAD 'iNTERVALS~ DRILLED BY t CABLE TOOLS 23, WAS DIRECTIONAL SURVEY MADE t CEMLNTING RECOH,D AMOUNT PUI,!,ED 26. LINER HECO~R.D 27. TUBING RECORD 28. PEP,~FORATIONS OPEN TO PRODUc-A'ION (interval, size and number) 29. 'ACID, SHOT, FRA~C~t'LrRE, CF~IENT SQUEEZE, ETC. 5795-5805' 5860-70' 5885-95' 5940-50' I ~ ~ ~ ~_ DIiIPTII INUfEHVAL (MD) [ AMOUNT ;dWD KIND O.F MAT'ER,IAL USED 5970-80' 6035-40' 6140-45' 6160-70' 6 00- ' ' ' ' : 6607-5795' 1500 ~al mud acid flushing 10' 6230-40' 6270-80' 6325-35' 6348-53' i ' - ' ' ' ' ' ' " "I 50 bbl acid squeeze 6420-25' 6440-45' 6520-30' 6602-07' all ' with 4 jspf. 30.. PRODUCTION DATE FIi~ST PR,ODUCT/ON [ PRODUCTION ME'I.IIOD (Flowing, gas lift, pumping--size and type of pump) [ WELL .STATUS (Producing or ~nut-m) Produc lng DATE OP TEST. [HOURS TES'Iq~D ' [CHOXE SIZE [pROD'NTEs£ P~.,Ti~IoDFOR OIL--BBL. GA~-]VICF. WATEH,--BBL. ]GAS-OIL RATIO 5___/21/68 , 1= 2/4 !124/64 t "~' ] 525 . ! 784 [ 34 i 1289 ~_~_o_w, TUBING lCA~nWG Pv~.ssumg [CALCULATM 'OIL--BBL GAS--MCF. WATER--BBL. [OIL GRAVITY-APl (COl~.) i'M. ESS. · ' 124-HO'UR RATE ,i ' , 100 I ,! ~ '[ ' '~ I I I 35'60 31. mSVOS~TION OV O~S (~old, used Ior ~ael, vented, etc.) . , ' .... [TEST WITNESSED BY Used for fuel and flared 82. LIST 0~' ATtaCHMENTS Re;Cb/dP 1,e t'/ott~: Hi s.t or.y,~i:..~., 33. I herebY, certify that the foregoi~, and attached information is complete and correct as determined from allYavailable records SIGNED.''' ~-~--~z~ TITLE :ASs' t., Area Admin. Supvr DATE 5-24-68 .... *(See Instructions and Spaces [or ~dditional Data o1~r Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end Iocj' on ali types of lands-and leases in Alaska. - Item: 16: Indicate which elevation is used as reference (where'not otherwise shown) fro; depth measure- 'meats given in ather spaces on this form:and in any attachments. Items 20, and 22:: If this well is completed for sepaFate Production from more than one interval zone (multiple completion), so state in item 20, and ]n item 22 show the prcducjng interval, or intervals, 'top(~)i' bottom(s) and name (s) (if ~n-ny) for. only the interval reported in item 30. Submit a separate.report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the adiditional data pertinent t° such interval. - ~ . "item26:. "S~cks Cement% Attached suppiemental 'r~i:oi'ds f0r"this well should show the details of any m'ul- tiple i-stage cementing and-the location Of the cementing t°°l. . .Item 28: Submit a separate completion report on this for.m' for'each interval to be separately produced. '(,See instruction for item~ 20 and 22 above). · 3~. -ClUMI~IARy OF F~)~ATION 'rF. STS IN~L~DIN(~ INT~VAL'~D P~UR~ DATA ~ ~O~ :'3 WA~ AND MUD . . i i i i i ii . . . . . . . · . , 36. 'COH.E DATA, A~ACIt BRIEF. D~CRIPI~ONS OF LITHOLOGY, POHOSITY, FRAC~R~, APP~NT DIPS ".' ,' : AND D~FEC~EI) SHOWS OF OIL, G~ OR WA~. . '.. ,. · _ ,- . · . : ~. · . . , , . , .. .. . . : . . ' . ~'~. [ . , ~ .. ,. . ~.', : .... : · :., . -' ~7' ~ ~ ' ., ~, ..... , RECOMPLETION HISTOR ~ Middle Ground Shoal 17595 #6 1/15-18/68 1/19-zz/68 1/z3/68 1/24-31/68 2/1-4/68 Z/.5-6/68 Z/7-1Z/68 2/13/68 to 3/7 318.'1z/68:.-' ' 3113,31/68 ~ -. 4/1-19/68 4/zz/68 4129/68 to 5/1 5/z/68 513-6/68 517168 518-9/68 5-10-13/68 5/14-Zo/68 5/z1/68 Killed well. Milled packer at 5597' and set bridge plug at 6750' with 5 sacks cement above. Set retrievable bridge plug at 150', and ran BJ pump. Pulled pump and repaired. Landed 2-7/'8" andl-'l/4" tubing'with packer set at 371' Dead short in electric cable. to pull packer. Killed well and attempted Milled over packer to lower hold-down slips and pulled packer. Pulled pump arid pump.cable. Found junk in top of pump and re-ran pump and packer. Pump landed at 5943' and packer set at 355'. Wellhead leaked and soaked electrical cable. TriPped out with packer and tubing. Pulled pump and cable and tripped in with completion string rigged for gas lift.. Packer set at 5659.'. Gas lifted to clean up well. Pulled gas lift valves and 'swabbed. Flowed to clean up:: .... .. . :'.; .:. ~ ...'.. Flow tested.-- Install'ed gas lift valves gn'd'injected gas at 950' psi. ' ........ ~ PBTD 6750. Flowed and worked on gas ,lift equipment. Ran and pulled submersible pump and temporarily suspended work. ., Pulled tubing and pump, repaired, and re-ran pump. Pumped 242 bbls. load diesel and pump broke down. Repaired and re-ran pump to 6006'. hours and broke down. - . Pumped 2-1/4 Pulled pump and scraped casing. Flushed perfs 6607'-5795' w/1500 gal. mud acid and squeezed, perfs with 50 bbls. acid at 0-500 psi. Re-ran pump. Pumped 266 BF in 8.hours, Elec.. pump cable arced acrosJ wellhead stuffing box, blowing out stuffing bo~/. 'Tu~'{ng~ parted at Wellhead. Prior to failure, pumped 433 BF in !3-hours-at FTP 1200-100 psi. Fished out tubing and pump.' Installed tubing with gas lift valves and set at 6675' with packer at 5742'. Gas litting. Recompleted as a flowing oil well. Form No. P---4 REV, 9-30-67 STATE OF ALASKA SUBMIT IN DEPLICATE 15. API NI/MERICAL CODE O~L AND GAS CONSERVATION COMMITTEE None Assigned 6. LEASE DESIGNATION AXD SE/RIAL NO. ~MONT'HLY REPORT OF DRILLING ADL - 17595 AND WORKOV[R OPERATIONS '{~ ' 7. IF INDIAN, ALOTTEE OR TRIBE NAME WZLL WELL OTHER 2.N~E OF~0P~TOR 8,~'IT,FA~ OR LEASE N.~ME Pan American Petroleum Corporation MGS State 17595 3, ADDRESS OF' OP~TOR 9. WELL NO. P. 0. Box 779 - Anchorage, Alaska 99501 6 4~ LOCA~ON O'F W~ 10. FIM ~ND P~L, OR WILDCAT Middle Ground Shoal Leg 2, Slot 4, MGS Platform 'B'; 1989' FNL, 588' FWL, Section 3, T9N, R12W, S.M. 11, SEC., T., R., M.. (BO]'I'OM HOLE OBJECTIVE) Sec. 31, TgN, R12W, S.M. 12. PEIR2VIIT NO. 66-3 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SI~E, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AN~ VOLUMES USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOBS, JUNK IN HOLE AND SIDE-TIR~CKED HOLE AND ANY OTI~IER SIGNIFICA2~T CH_4d~ES IN HOL~ CONDITIONS. 4/30 PBTD 6750'. Running submersible pump. 4/1-19 4/22 4/29 PBTD 6750'. Flowed and work on gas lift equipment Reran and pulled submersible pump and temporarily suspended. Pulled tubing. RECEIV[D MAY 0 t968 DIVISION OF MINES & MJNERAIJ ANCHOP. AGE ing is~u%and c2rre 14. I hereby certify that the fqre~ et NOTE--Report on this form is r~l~ired for each calendar month, regardless of the status of operations, an0 must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Form No. P---4 REV. STATE, OF AL/~KA SUBMIT I1V DEPLICATE O~L AND GAS CONSERVATION ,COMMITTEE r MONTHLY REPORT O'F 'DRILLING AND WORKOVER OPERATIONS · Wr. LL ~q~ELL, -.. ~'] OTHER 2. ~N~E OF OP~TOR , Pan American Petroleum Corporation 3, AD'DRESS OF OP~TOR P. O. B~ 77?- Anchorage~ Alaska 97501 Leg 2, Slot 4, MGS Platform 'B'; 1989' FNL, 588' FNL, Section 3, T9N, RIZW, S.M. -5. API NLrN[ERICA~L CODE None assil/ned 6. LEASE DESIGNA'IION AND SERIAL NO. ADL - 17595 7. IF INDIAN, ALOTT'EE OR TRIBE NAME 8. I.~'IT,FA~M OR LEASE NAME MGS State 17595 9. WELL NO. 6 10. FIELD A_NDPOOL, OR WILDCAT , Middle Ground Shoal 11. SEC., T., R., i~4., tBOTTOM HOL~ OBJECTIVE) Sec. 31, T9N, R1ZW, S.M. 12. PERMIT NO. 13, REPORT TOTAL DE3PTH AT END OF MONTH, CH. A2qGES IN HOLE SI~-E, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLLrMES USED, PEHFOHATIONS, TESTS A/WD RESULTS, FISHING JOBS, JUNK IN HOLE AND SlDE-TR~CKED HOLE AND ANY O~IER SIGNIFICANT CI-[A_NGF~ IN HOI. J~ CONDITIONS. ,,(W ? r,k0ve,r) 3/31 PBTD 6750'. Flow testing 3/1-7 3/8-12 3/13-31 Gas lifted Pulled gas lift valves and swabbed. Flowed to clean up. Flow tested. Installed gas lift valves and injected gas at 950 psi. RECEIVED APR 16 1968 ~;'I$tON OF MINES & MINEEAtS ANCHCmAO~ 14.! hereby certi,y ~l~e~(~r~and ~e~ i NOTE--Report on this form is required for each calendar month, regardless of the status of operations, anO must ~ file~ in duplicate with the Division of Mines & Minerals by the 15th of the succeedin~ month, unless othe~ise directed. r, , STATE OF ALASKA SUBMrr nv D~LZCA~ OIL AND GAS CONSERVATION COMMITTEE A~ONT'HLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL , WELL OTHER 2. NA1Vi~ OF OP~-TOR ADDRESS OF OPEI~ATOR P. 0. Box 779 - Anahorag... Ala"ka LOCA/~ION O'F WELL qQ~nl MS 2, Slot 4, MC, SPlatfo~m 'B'; 1989' FNL, 588' FNL, Section 3, T9N' R12W, S.M. 7. IF INDIAN, ALOTTEE OR TRIBE NAME 10. FlF..t,r~ A--ND POOL6OR WILDCAT OBJECTIVE~ , Sec. 31~ TgN, R12W, S.M. 1~-. PEIP~MIT HO. 66-3 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SI~E, CASING ANT) C~¥IENTING JOBS INCLUDING DEPTH SET AN'D VOLLrlVIES USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOBS, JLVNK IN HOLE AND SIDE-TILACKED HOLE A-NY OTHER SIGNIFIC~NT ~ES rN HOLI!: CO1%FDITIONS. 2/29 GaS l!fttns. No gau~e. 2/1-4 M~lled over packer to lc~er hold-down slips and pulled packer. Pulled pump and pump cable. 2/5-6 Found Junk in ~op of pump and re-runnin~ pump and packer. Pump landed at $943! and packer se~ at 355~. 2/?o12 ~el-lhead leaked and soaked electrical cable. T~ipped ou~ ~ith packer and tubing. Pulled pump and cable and tripped in ~tth comple~ion s~r[n~ ri~ed [or §as l~fft. Packer set a~ 5659'. 2/13-29 GaS lifted, attempted to clean up ~ell. RECEIVED MAR 2 1 1968 DI¥I$1ON OF MINES & · certi t th fo ~going ' _true and correct 1 DA'i'E NOTE--Report on this form is required for each calendar month, regardless of the status of operations, anO must ~ fJle~ Js duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~ise directed. Form i'qo, P---4 REV. STATE OF ALASKA SuBMrr IN DEPLICATE '5. AP1 NUAIERICAL CODE O~L AND GAS CONSERVATION COMMITTEE A~IONT'HLY REPO'RT OF DRILLING AND WORKOVER OPERATIONS None Assigned ~ 6. LF. ASE DESIGNATION AN'D SE!~IAL NO. ADDRESS OF OPE1R. ATOR P, O, Box 779 - Anchorage, Alaska 99501 LOCATION O'F V~rELL Leg 2, Slot /4, HGS Platform 'B'; 1989' FNL, 588' FWL, Section 3, TgN, RI2W, S.Pi. ADL- 1 7595 . 7. IF IIX'DIAN, ..%LOTT~E OR TRIBE NAME OIL ~ GAS ~-~ ......... WELL WELL OTHER 2. NA1VIE OF OPEB2kTOR 8. U'NIT,FAi:LM OH LEASE N.~ME P~n g~rican Petroleum Cor~ration ~GS State 17595 9. ~VELL NO. 10. FIELD AND POOL, OR WILDCAT Hiddle Ground Shoal .~-~ 11. SEC., T., R., M.. (BOTTOM Sec. 31, T9N,.--Rf2W, S.M. 13. REPORT TOTAL DE/~TH AT END OF MONTH, CI-IA-tXIGES IN HOLE SIZE, CASING AND CE1Vi~"I*I~NG JOBS INCLUDING DEPTH SET .~ VOLU/VIF~ USED, PF~ORATIONS, ~I'F_.STS ~ i~SULTS. FISHING JOt~, JI/NI~--EN HOLE ~ND SIDE-/q{ACKED HOLE AND ANY OTHER SIGNIFICANT CIiANG~ IN HOLI~ CONDITIONS. ~ plug at 6750' with 5 sx cement above. ~ 1/19-22 - Set retrievable bridge plug at 150', and ran BJ pump. Pull pump and wait on repati' parts. 1/23 - Landed 2-7/8" and 1-1/4" tubing and packer set at 371'. 1/24-30 Attempted to pull packer. Dead short in electric cable. Kil led well, 14. I hereby certify t~l~he £ore, goj~ is J~:3~a~d correct NOTE--Report on this form is re for each calendar month, regardless of the status of operations, ancl must be filecl in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed, Form P--3 /--'% REV. 9-30-67 STATE O,F ALASKA Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION ,COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for Proposals to dril! or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR P~IT~" for such proposals.) 0IL [] OAS E~ WELL WELL OTHER 2. NAME OF OPERATOR Pan American Petrol.eum Corporation 31 ADDRESS OF OPERATOR P. O. Box 779 - Anchorage, Alaska 99501 4. LOCATION. O,F WELL At surface Leg 2, Slot 4, MGS Platform 'B'; 1989' FNL, 588' FWL, Section 31, TgN, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc. API NUMERICAL CODE None Assigned LEASE D]gSIGNATION AND SERIAL NO. ADL-17595 7. IF INDIA.N, ~uLO~I~ OR TRIBE NAtVI~ 8, UNIT, FAi~I OR LEASE NAME MGS State 17595 9. WELL NO. 10. FIELd) AaN'D POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31, T9N, R12W, S.M. 12. PEPdVIIT NO. 66-3 Check Appropriate Box To [ndi'cate NatUre of N~oti'ce, Report, or 'Other 'Data NOTICE OF INTENTION TO: FRACTURE TREAT [ [ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONS REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER 8HUT-OFF : REPAIRING WELL ~ FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZINO ABANDONMEN'Ts (Other) NoTE: Report results of multiple completion on Well ompletion :or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR CO.MPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work, · TD 7400', PBTD 7356'. Well is presently producing from the B-C-D and F zones with a packer set at 5596'. We propose to seal off the F zone perforations (7092-94' and 7130-31-1/2') and install a B-J submersible puriip. The well will be cleaned out to 7000' and a cast iron bridge plug will be set at 6750' with 4-5 sacks cement on top. A dual packer will be set at 500'. Tile pump will be set at 6000' on a 3-1/2" tubing string (2-7/8" from the surface to the packer). 'A 1-2/3't vent string will be set from the surface to the packer. Ball valve nipples will be installed in each string at 300'. 1 I hereby ,/ l certify that :the foregoing is.true and correct RECEIVED j Al'4 I i; !":: ANCHORAGE TiTLEAS S 't. Area Admin. Supvr. i/i5/68 (This space for State officezuse) APPROVED BY /] ~ /~ ~ ' ' ' ~'" TITLE CONDITIONS O~ APPROVAL, IF A~: DATE DATE See l,nstrucfions On Reverse Side FORM 470 2-57 PANAMERICAN PETI OLEUM COtillION P. O. Box 779 Anchorage, Alaska '99501 May 9, 1967 File: Re: FKK-678-WF Plugback of MGS State 17595 Well No. 6 Mr. Thomas R. Marshall, Jr. Division of Mines and Minerals Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: Late last year we met with you and discussed the problem of perforated intervals in our MGS State 17595 Well No. 6. You will recall that your approval to proceed with a completion program involving perforations over the interval 7261' to 5300' was provided on Form P-3 on March 18, 1966. On August 4, 1966, Conser- vation Order No. 26 was entered, defining MGS Oil Pools A through G, and establishing rules for commingling of Pools B, C and D, as well as Pools E, F and G. At this point, our perforations at 7130' to 7131~' and 7092' to 7094' in Pool F in the subject well were in violation of Order No. 26, since all other perforations are in Pools B, C and D. The end result of our earlier meeting was that Pan American was given until June, 1967 to effect repair of the well. At the time this decision was made, we anticipated re-entering the well and working it over to install artificial lift equipment. Prior to the anticipated workover the well was extensively re-perforated in Pools B, C and D, and a very satisfactory producing rate has been maintained ever since. The need for an expensive workover operation to install artificial lift equipment no longer exists. Attached is a reproduction of a portion of the Dual Induction Log of Well No. 6, with Pool tops and present perforated intervals marked. Also, indicated in red on the log are depths at which bottom has been found with a bottom hole pressure bomb on various dates. The log illustrates the gradual filling-up of the casing with solids, presumably mud solids and formation fines, that has been experienced. The latest measurement found the top of the solid material at 6632' on May 1, 1967. This means we now have 460 feet of fill material above the top Pool F perforation at 7092'. We believe it is highly unlikely that a significant amount of production can be coming from the Pool F perforations under these RECEIVED DIVISION OF MINES & MINERA~ ANCHORAGE Mr. Thomas R. Marsha_~, Jr. -2- May 9, 1967 conditions. Accordingly, we respectfully ask your approval to further defer any remedial plug back work until such time as it becomes necessary to re- enter the well and clean out to improve producing rate. Yours very truly, ~~./ K. Kreb'[ 11 Area Super±ntendent Attachment RECEIVED 01¥151ON OF MINES & MINERA~ ANCHORAGE 0 0 , · · Form P--3 STA, OF ALASKA SUSMIT IN TRIP~-,.. ,ATE* ~ (Other instructions .~n re- OIL AND GAS CONSERVATION COMMISSION verse side) SUNDRY NOTICES AND REPORTS ON WELLS (:Do not use this form for proposals to drill or to deepen or plu, g back to a different reservoir. Use "APPLICATION FOR PERMIT--" for SUCh proposals.) Effective: July 1, 1964 5. LEASE DEI~XGNATION AND IIIERIAL NO. ADL 17595 6. IF INDIANt ALLOTTEE OR TRIi]E, NAME 1. 7. UNIT AGREEMENT NAME OiL [] OAS WELL WELL OTHER - 2. NAME OF OPERATOR 8.FARM oR LEASE NAME Pan Amc rican Petroleum Co rporation MGS-17595 9. W~L NO. 10. FIELD AND POOL, OR WILDCAT Middle G,round shoal 11. IE0.,' ~., i., ;l.,'Ol'aLl, iND : ~IURVE~ OR AR~A tec. 31-TgN, R1ZW, SM 12. BOROUGH -. ' [18. s~i~E Renal ' -- ~las~ 8. ADDREII~! OF OPERATOR Box 779, Anchorage, Alaska 99501 4. LOCATION OF WELL (Report location clearly and 'in accordance with any State requirements.* See also space 17 below.) At surfece Slot 4, Leg Z, 1989' FNL, 588' FWL, Sec. 31, TgN, R1ZW, SM BHL: 1906~ FNL, 7~t FWL, 8cc. 31, TgN, RlgW, SM 1~. ~~. I 1[. ~mva~o~ {Show whirr n~, a~, o~, ~) 66-~ ~ ~T. ~1.6~ abov~ 8e~ 16. Check Appropriate Box T° Indicate .Nature of Notice, RepOrt, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [ [ PULL OR 'ALTER_CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING ~ ABANDONMENT* (Other) NOTE: Report results of multiple .completion on Well ompletion or Recompletion Report and Log' form.) · 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including, e~timated date of starting any proposed work. If well is direetionally drilled, ~ive subsurface locations and measured and true vertical depths for all markers and zones perti- nent to this work.) * Work performed as described in P-3 dated IZ/$0/66. ANCHORAGE 18. I hereby eertifF that the for.e.~oi~n_~?_.~u~ ill~ ,correct SIGNED ~'; ~ ~ TITLE Area Superintendent DATE 1/lZ/67 (This space for Federal or State office use) CONDITIONS OF APPROVAL, IF ANY: *See Inductions on Rever~e Side Form 1~--3 STA1 )F ALASKA SUBMIT IN TRIP1 (Other instructions ,,n re- OIL AND GAS CONSERVATION COMMISSION verse side) SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) Effective: July 1, 1964 LEASE DEHIGNATION AND SERIAL NO. ADL 17595 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. 7. UNIT AGREEMENT NAME OIL ~ GAS ~'-] WELL WELL OTHER 2. NAME OF OPERATOR ~ 8. FARM OR I~EABE NAME Ptm ~ri~ Pe~ole~ ~ ~ ~S 17595 ~, ADDRE~8 O~ 0PERiTOI 9, W~ N0, ~ 779, ~~~, ~ ~1 6 4. LOCA~XO~ OF WE~ (~eport lo~ation clearl~ ~nd In accordance with an7 State requirements.* See also s~aee 17 below.) it su~ce $1OC &o I~8 2, li~JD* FILL, ~* ~; I~' ~, 737' ~, Sim. 14. PERMIT NO. I 15. E~-~.VA?XONS (Show wl~ether DF,-BT, OB, et~) 66-3 [ 1~ 71.6' ~e ~e~ Ls~BI 10, FIELD AND POOL; 0R WILDCAT Hlddle Oround ~ 11. SEC,, 7,, R., M,, OR BY.K, ~D 8URVEX OR AR~A bc, 31o T~, ~0 12. BORO~GH- -. 'J ~8. STATE 16. Check Appropriate Box T° Indicate .Nature oF Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [ [ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE. COMPLETE SHO0~ ABANDON $ REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF WATER SHUT-OFF RIPAIRING WEL~, FRACTURE TREAT'~ENT ALT~.aXNG CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) NOTE: Report results of multiple: completion on Well om~letion or Reeompletion Re~or~. and Lo~'form.) DESCRmE PROPOSED OR C0lfPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including.estimated date of starting any proposed work. If well is direotionally drilled, ~ive sub~ttrface locations and measured and true vertical depths for all markers and zones perti- nent to this work.) * I. Propose Co Per£o~ate. actd:Lttonal intervals uiCh 4 JSFF aB follmm I 5860' - :5870' 5970* - $~' 6140' - 6145' 61~' - 6170' f~O0' - 6210' ~30' - ~' f~70' - 6ZOO' 63LS' - 6335' 63~' - 63~3' 6420' - 6520' - 6530' 6602' - 6607' 2. FI~ ~ el~ ~p, eval~, and place on production. 18. I hereby certify th~ t~-foregoinf is true and correct CONDITIONS OF APPROVAL, ~ AH: }~'-- TITLE l:×e¢~$ive Se¢~Ct~l"/ AIc.~k~ Oil & DATE *See Instructions on Reverse Side BOTTOM HOLE Field County Well Shut In Csg Psig Tbg Psig B. H. Temp Zero Level Grd (_ Co. Zero Point Grd £_ ,,, Perf's Lease State Elevation Csg Set Tbg Set B. H. Choke ~ RKB (__ ~) Other ~) RKB (__ , ,. ) Other Datum SURVEY Formation Size Size Paoker _Depth (ft) Extension (.in) Pressure (ps~).. Gradient (~/100~) · FORM 4?0 2.57 PAN AMERICAN PETP. OLEUM CO P. ATION P. O. Box 779 Anchorage, Alaska 99501 December 5, 1966 File: FKK-1809-WF Re: MGS State 17595 No. 6 Mr. Thomas R. Marshall, Jr. Division of Mines & Minerals Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska Dear Sir: Enclosed please find a Chronological Well History and tests for MGS State 17595 No. , 6 as requested in your letter of October 25, 1966. Yours very truly, F. K. Krebill Area Superintendent Enclosures GIVISi©IN ~pk N',tlqi.:b ~ t~, ANCHORAGE Chronological 'Well History MGS State 17595 No. 6 1/z8/66 1/31/66 z/ 6/66 3/14/66 3/20/66 3/23/66 3/24/66 3/Z5/66 3/2,6/66 3/Z7/66 3/30/66 3/31/66 4/ Z~ 66 4/ 3/66 SpUdded. Drilled 26" hole to 620' and set 20" casing at 612'. Drilled 17-1/2" hole to 2025', logged and set 13-3/8" casing at 2010' Drilled 9-5/8" hole to 7400', logged and set 7" casing at 7397'. Plugged back to 7352'. Perforate 7130-7131-1/2', 7092-1/2-7094' with 4 jspf. Test 7130-7131-1/2' and 7092-1/2-7094'. Two hours on 1/4" choke flowed 71 BF, indicated 852 BFPD, 53.5 MCFPD, GOR 62. 8 CF]B, AP1 38. 5°· Two hours on 1/2" choke flowed 35 BF, indicated 420 BFPD, 53. 5 MCFPD, GOR 127 CFB. Two hours on 5/8" choke flowed 17 BF, indicated 204 BFPD, 34.4 MCFPD, GO1R 168.5 CFB, AP1 38.2°· Frac 7~30-7~31-1/2' and 7092-1/2-7094' with 2Z,200 gallons treated water~, containing 3300 pounds sand. Test 1:55 on 1/2" choke; flowed 174. 5 BO and 12.3 MCFG, indicated 2185 BOPD, 154.2 MCFPD, GOR 70.5 CFB, AP1 29.1° with 13% ]BS&W. FTP45 PSI. Perforate 6276-6277-1/2' and 6328-t/2-6330'. Test 3-1/4 hours on 1/2" choke. Flowed indicated 1128 ]BFPD, GO1R 338 CFB, AP1 34°, 0.1% BS&W. Set ]BP at 6550', frac 6276-6277-1/2' and 6328-1/2- 6330' with 59, 620 gallons water containing 8200 pounds sand, 4650 pounds nut hulls and 11,500 pounds resin. Test 6 hours on 1/2" choke; flowed 384 BO and 95.5 MCFG; indicated 1585 BFPD, 382 MCFPD, GO1R 241 CFB, 3% BS&W. Perforate and frac 6206-6207-1/2 and 6238-6239' with 60,000 gallons treated water containing.8000 po. unds sand, 5000 pounds nut hulls and 10,000 pounds resin. No tests before or after frac. Chronological Well l- .tory MGS State 17595 No. 6: 4/ 4/66 Perforate and frac 6169-1/2-6171' and 6142-6143-1/2' with 54,600 gallons treated water containing 8,000 pounds sand, 4,200 pounds nut hulls and 7,450 pounds resin. No tests before or after frac. 5/ 7/66 5/10/66 5/21/66 5/22/66 5/29/66 Squeeze with 220 BO. Test 19-1/2 hours on 3/4" choke; flowed 37.1 BFPH with 3% BS&W. Reperforate 62?2-62?5', 6332-6333' and ?092-?093' with 8 jspf. Test 24 hours on 1-10/64" choke; flowed 42.1 BFPH, TPF 130, 2. 5% BS&W. Test 24 hours on 1-10/64" choke; flowed 8?6 BFPD, TPF 110, BS&W 1.7%. Squeeze with 500 BO. Test 24 hours on 3/4" choke; flowed 1665 BFPD, TPF250, 3.7% Bs&w. S~,bsurfac(: ,'~ressure Survey Prcss~-e at Datu~ e ) Shut-in Time ) 3. a-b Sl~u%-ir: Ta'bi~f Pressure Skut-i~ Casin~. Presage Ton of Oil Top. of Watep Tez,:perat~e at 6959 feet Date of Last Test Pressupe ~ Darns% Last Shut-in Time~ Last'Test Flow Test Data Co A o ~q-~ite S & S } hP o ciook 9-3o-66 prig' 729 p~i~ Packer psiR' i~2 °F 9-19-66 .psi~ Choke Size Period '° a,= Stabi. lizea Flow Stabilized Production Oil l,i~3./'day bbls/da'~- Gas . Wat er bb!s Pio~ng' Tubir4 Pressure Flcw%m~ Casing' Press-~re Omv. u].ative P.',?oduction (,~) 0!~. Water 'i% is Effect. Prod. Life, ~ = ~ ~/q '}~'s Re~,~rks: This well was not flowed from the time o£ the last test on 9-19-66. R'ECEiVE Bob Hill 6276-6277½, 612+2- o12+3 ~- 0 ~:~!000 2000 ~oooJ 4~OO, ?O0 5000 65oo 6600 6800 6900 6959, Well No. 6 State Ai~.,sk~- i Time °235 o 244 ~7 ,,660. ,,765 °826 . ,se1 729 757 I050 1389 1722 2053 2379 2569 2616 2666 2719 2772 Static ~cs~ 2800 j ,J Taggld bottom a 6959 Gradie~_t °900 Press. Dui! d.-up Test krs P!ui 5. 1 .t i DIVI$10N OF MINES & M!NERAL,~ ANCHORAGE .~AN~, ..~ }'~ERTC~Xl'~ _ . PET]ZO~¢,UH CORPOi~TiON Subsurface Pressure Su:vey Corn? ~.ny R~mmin2- Su~.rcey Element - - Calibration Date ~ ~'''~ ..... " ~ ' ' Well No. State 02 }'o-c27 Pc .~ Time °235 ?: }psi 729 ?5? Gradient Static Pres~,u'.:¢ Data ~ressuz, e at Datum ¢~ ) Shut-in Time ) D a% ' 'cz u ~u:. Shu'~-in ri"abi.~! Pressure Shut-i~ Casim~ Press~e Toe of Oil Top. of Water Tez, L~erat~a at 6959 Date of Last Test Pressure ~ Da'h=. Last Tess Shut-i= Time, ~ast Test psis' 729 Packer -psi{ .7.L32 °F' 9--19-66 psi~ Flow Test Data Choke Size Period of Stabilized Plow Stabilized Production k.m.s bb !s/day t..blslday Mater F!o~=ng Tubi.n~' ~ress'~-e Plov~ng Casin~' Prossume O,~::u].at ire Production Oil psi2' psiE bbis ,Sas ~ater 'Lb i s Effect. Prod. Lift z =~Li ~./g Remarks: T}'~is well was not flowed from the time of the last test on 9-19-66. Bob Hill RECEIVED 2oool oppo 1050 pO~O .h~7 !)~9 LO00,.! .554 1722 >Ouui .660 2053 6000 ~765 2379 6500 ~826 2569 6600 ogg! 2616 6700{ .857 2666 6800 .874 2719 6900[ o891 2772 6959! 0900 2800 NO~: Tags d bottom a' 6959 o Bui}d--uo Tes~ -"__ + ! Press, ct hfs A~.. ~ ' c' Heifht Press. of Fluid , DIVISION OF MINES & MINERAL8 ANCHORAGE pAT~F A'~,,FFD, rDT?,3.?q :D~(-'tTT?TT'M- ~'D^,'->, mT ",T S~,b~urface Pressure Su:vcy 9-3o-66 Press~m-e at Datum e ) 'psif Shut-in Tim~:~ ) b_rs ~ at Dat-m~ psis ShuCk-in Tahiti[ Pressure 729 pci~ Shut-in Casing Press~a Packer 'psi2' Tqp. of Water D~t~ or L~st ?~t 9-19-66 Pressure ~ Datumb Last T~st psi2' Shut-in Time, Last'TeSt Flow Test Data ill Choke Size ' "' · ' 4 ] q Period o£ ~'c~O ..... zed Flow hr's Stabilized Production (q) . ~ ~ab~ ~- bbls/day ,Sas. War em b b iL s Tub i-~' =Y'-' Casing' Press-ore O~v.u].ative Production (~) Re:r. arks: This well was not flowed from the t~ne of the last test on 9-19-66. RECEIVED DEC 1 1966 Bob Hill O !000 2000 ~OO0 5000 ~ooo 6500 6600 6uOO 69oo 6959( 62 Time °235 °554 0660 ~765 °826 .874 .891 ~900 Tags · I 'i Press. Timei ?, psif ?29 , ~7 !369 k722 2379 2569 2666 2719 2772 2800 sd OO'C,,O,:- a 6959 Static Test Gradient t DIVISION OF MINES a ANCHORAGE . I Casing Hoight of Tubin~ Press. Press. 0,~5'oo d? ~'3 .Oz (? ..q-I l~mmsm ]~. Mazatmli, Form No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 ~-~,=~ Anchorage NuMs£~ ADL 17595 oR u~,, N^M~ MGS State 17595 Well No. 6 LESSEE'S MONTHLY REPORT OF OPERATIONS Corrected Report State ............... ._.~.___l_~_s___k___a__ ............ Borough ............. _K.__e__~..a-_ ~ ................. Field ............... . _D..e...v_?_._l__°..P._m. _..e._.n~ Tke followir~ is a correc~ repor~ of opera~ior~s and prod~ctior~ (incl~din~ drilli~,~ and prod~zcin~ wells) for the month of ........... __J..u__l_y_ ....................... 19_6___6__, ............................................................................ .4~er~t's address P. 0 Box 779 ,~ Pan American Petroleum Co ................................................................... uorr~pany~~ ...................................... rp. ........................................ A___n_ _c_h _o_ ~_ _a_ g_e_ _,. __ _A__i_ _a__s_. _k__a_ ............... Si~n, ed, __~~.._ £hon, e ............................. Z7_Z_-__8__4_7_!_ .................................... ,~ ge~ s title .... __A__r___e__a____S__d_~_e._r.!_n.t..e._n__d..e.._n_.t. ......... SEC. AND BARRELS OF Orr. Cu. FT. OF (]AS ~ OF ~ (In' thousands) 31 SW NW *15047. 7 7193 *Subj .gh unprov cor factor is lished. Prod ,nds. Corr, ,w correct tount of pr (]ALLONS OF (~ASOLINE RECOVERED ~d mete BARREI21 OF WA?ER (If none, so state) 240 Volurr RE]YIARKS (If drilling, depth: if shut down, oau~e; d~te and result of test for ~dolln® content of ~e subject to ,duction EC'EIVED SEP 13 1966 ON OF MINES & MINERALS ANCHORAGE -,- 15047 7 NO NOTE.~There were .................... : ........................... runs or sales of oil; ................................................ M cu. ft. of gas sold; ............................................................ runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month, unless otherwise directed. FORM 470 2-57 PAN AMERIC PETP OLEUM ( 0 ION P. O. Box 779 Anchorage, Alaska 99501 DP,/ISION OF MIIxlI~S & MI,NERAL.~ A,NCHORAGE File: FKK-957-~ Re: Completion Report, MGS State 17595 #6 Mr. Thomas Marshall, Jr. Division of Mines & Minerals Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: Attached are three (3) copies of executed From P-7, Com- pletion Report for MGS State 17595 ~6, with Attachments 'A' and 'B' for your consideration. Yours very truly, F. K. Kre~fill Area Superintendent Attachments Form ~--~7 . SUBMIT IN DUPLIO. j" :~i'ATE OF ALASKA ': (See6th~ril~: struction~ on reverse s~de) OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG*· la. TYPE OF WELL: b. TYPE OF COMPLETION: NEW ~] WOnKO ~VELL OVER OIL M GAS WELL WELL [-] DRY [] Other :-": I "ff [ ~.,: ~-- i. ~' "' DEEP' ~ BAcKPLUG D RESyR.DIFF' ~, .,O~her ........ " Pan American Petroleum Corporation 3. ADDRESS OF OPERATOR ann g'-cLora-e, Alaska Box 4. LOCATION OF WELL (Report location clearl~ and in accorSa~ce with any ~tate requirements)* ~s.~ace Slot~o.6, Leg ~o.2, 1989~ F~, 588' F~, Sec.3I, Tgi, R1 ~ ' it totaldep~9211 ~L, 688' F~, Sec.31, T9N, R12W, S.M. ~ 1906' F~, 737' F~, Sec.31 [ 14. PggMl~ NO. DATE ISSUED Tgi, R12W, S.~. 66-3 ~ 1/28/66 15. DATE SPUDDED Effective:· July 1, 1964'(~ 5. LEASE DESIGNATION 'AND SERIAL· NO. ADL- 17595 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGREEMENT NAME 8. FARM OR. LEASE NAME MGS State 17595 9. WELL NO. 6 10, FIELD AND POOL~ OR WILDCAT Middle Ground Shoal 16. DATE T.D. REACHED 17. DATE COMPL. (Ready to prod.) 3/11/66 6/13/66 11. sEC., T., R., M., OR BLOCK AND SURVEY OR. AREA Sec.31, T9N, R12W, S.M. 12. BOROUGH .. l' 13. sTATE Kenai ] Alaska 1/28/66 18. ELEVATIONS (DF, RKB, RT, GR, ETC.)* I 19. ELEV. CASINGHEAD · IBradenhead 0utlet IRKB 71.36' Above MSL { 41.56' 'Above MSL 20. TOTAL DEI~H, MD & TFB [ 21. PLUO, BA~ T.Do, MD & ~D 22. IF MULTIPLE COMPL., HOW MANY* DRILLED BY 7400 IPB7352 TYD same .... ,.,, ,--7-w~, ~. I 0-7400 'RODUCING INTER AL(S), OF HiS COMPL .TION--TOP, BOTTOM, NAME (MD ANB TVD)' 6142 - 7131~ Middle Kenai Oil Zone 26. TYPE ELECTRIC AND OTHER LOGS RUN : DIL~ Sonic~ FDL~ PML~ CBL~ Temperature 23.INTERVALS ROTARY TOOLS CABLE TOOLS ~5. WAS DIRECTIONAL SURVEY MADE ,.iii! i '> 'i[:]:.~.' Yes I 27. WAS WELL CORED · ,~ ~')F :..':1 !!":':: :: '~, ',,, Yes 28. CASING RECORD (Report all strings set t~'WdlO'!:'''' '': ': CASING SIZE 13-3/8" 7~' WEIGHT, LB./FT. 79.6 54.5 26 DEPTH SET (MD) 612 2010 7397 HOLE SIZE 26" 17~" 8-5/8" ] CEMENTING RECORD ] AMOUNT PULLED ~'42 Sx ne--~-~-t:~5~--~/-w/CaC'l '~.200 Sx w/6EL, 100 Sx w/CaC[I. 160 Sx w/TIC,940 Sx neati 29, LINER RECORD 30. TUBING RECORD size TOP (MD) BOTTOM (MD) SACKS CEMENT* SCREEN (MD) SIZE DEPTH SET (MD) PACKER SET (MO) 31. PERFORATION RECORD (Interval, size and number) 82. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. .. · ~ 7130- 7131~ 6206- 6207~ ? .... 7092½- 7094 6238- 6239~ % -6~~328'~ L' ~ ~'/~. '~o 6169½- 6171 6276 - 6277~ 6142 - 6143~2 DEPTH 'INTERTAL (MD! ] AMOUNT Afl).KIND OF MATEBI.AL US. ED ' '§e-~ kt[ach~ ~Xi PRODUCTION· DATE FIRST PRODUCTION [ PRODUCTION METHOD (Flowing, gas lift, pumping--size and t~pe o! pump) WELL STATUS (Producing or shut-in) ' 4/29/66 [ Flowing Producing DATE OF TEST HOURS TESTED CHOKE SIZE PROD'N. FOR OI~BBL. GAS--MCF. WATER--BBL. 6/13/66 24 1 10/64' '~' ~,o~ > 1680 827 1.9% [492 CFPB 34. DISPOSITION OF OAS (8old, used ]oryuel, vented, etc.) Tes~ wz~N~ss~o s~ Vented ... 35. LIST OF ATTACHMENTS · . Attachment 'A' (list of perforations & fractures) & electric log 36. I hereby certify that,.the fore. going and attaehed information is complete and correct as determined from all available records *(See Instructions and Spaces I:or Additional Data on Reverse Side) 1966 INSTRUCTIONS - General: This form is designed for submitting a complete and correct well completion report 'and log on all t~pes~bf~lahds and. leases to either- a Federal agency or a State agency, or both, pursuant to applicable Federal and/°r State laws'and regulations. Anynecessary special instructions con~erning~the use:~f this form and the number of copies to be submitted, particularly .with' regard to local, area, or regional procedures and practices, either are "shown beio~v or Wi~il'-be issued b~ or maY~ be obtained from, the local Federal and/or State office. See instructions on items 22 and 24, and 33, below.regarding separate reports for'separate eompletions~ · ::. --. · If not filed prior to the time this sumihary record is submitted, copies of all Currently available 16gs (d~illers, geologists,' kampl'e and core 'an~'iysis, all types electric, etc~) ti0n and pressure tests, and dir6ctlon~l surveys, should be attached hereto~ to the exten~ required by applicable Federal-and/~r '~tate laws and regulations. All attacli'ments should be listed on this form, see item' 35. - I~em .4: I~'there are no applicable St~te~ requirements, locations on Federal or indian i'and should be described in accordance 'wi~h Federal requirem6nts. Consult 16C~I state or Fekleral office for specific instructi6hs. .. - .... - I$¢m ]~: Ind. icate which, elevation is used as reference (where not otherWise Sl~°Wn) for depth .measurements given in-othe~ spaces on this form and in any attachment~?.. I~¢m~' 22 ~d.24: If th~s well is completed for separate prdduction from more th~n :~)ne~interval zone (multiple completion),.:s6 state,in item 22, and in item 24 ~how ~he pro~tu~ing interval, or intervals, top(s), bottom(s) and name(s) (is'. anY) for only-the intervaI reported in item 33. Submit a ..separate report (page) on thi~ form, adequately identified, for each additional interval to. be separately produced, showing the additional~ data Pertinent to such interval. ' .... - I~¢m 2~: "Sacks Cement'.!: At~ched supplemental records for this welI should show the details of any multiple sta~e cementing and 'the loca~ion of the c~menting tool. _ .I.fcm ~3: Submit a separate completion report on th~ form for each inter~al to.be.separately produced. (See instraction for items 22 and 24 above.~) ,-:.., - ~.~." · · ~ -. ,·~' - .. . ~. -. . _ · .': ..: ' ,., ... . -~ .:;,. _. ':~, - .. .. .~ :..:'- -, .. :. . . " : '. ~ ~,~ - 37. SUM~IARY OF POROUS"ZONES: ~' ~ ~ '.- ........... : ~'-:. SHO~::ALL IMPORTANT ZONES OF POROSITY AND'CONTENTS' ~HEREOP; CORED INTERV~LSi~' A~D ALL DRILL-STEM TESTS, INCLUDING DE.H; INTERVAL TESTED~ CUSHION USED~ TIME TOOL OPEN~'~FLOWING AND SHUT-IN '~RE~SURES, AND RECOVERIES FO~MATION ~Or~: ~ I BOTTOM ~ ~' DESCRIPTION, CONT~N~S, ~TC. ". ~'" -: ... . -. . .... -- : · : .~ .. MEAS. DEPTH 7-3 : .. .: : . . .- , . .. .... .~ '. ~. : , . -. :,~ , :.~ '..~ ... ,-: ., ~ · . ..... - -. ' .... 2 ...... ~ . 5 -. ~: - ~ ~'. .- .-' '--._ . .. .. .. : .~ .-: . . ~. . - .'._. ~-., ..... : : . ~ -. : . . . . .. "- , .,.. .. . .... ,. ~ ~ PAN AMERICAN P-7 MGS State 17595 ~6 Item ~;32 - Attachment 'A': DePth Interval 7130 - 7131~ 7092½- 7094. 6327 - 6328~ 6276- 6277-~ 6206- 6207~ 6238- 6239~ 6169~2- 6171 6142 - 6143~2 Amount & Kind of Material Used 22,200 gal. treated water containing 3,300 lb. sand. 59,620 gal. treated water containing 8,200 lb. sand, 4,650 lb. nut hulls, and 11,500 lb. resin. 60,000 gal. treated water containing 8,000 lb. sand, 5,000 lb. nut hulls, and 10,000 lb. resin. 54,600 gal. treated water containing 8,000 lb. sand, 4,200 lb. nut hulls, and 7,450 lb. resin. PAN AMERICAN P-7 MGS State 17595 I~6 Item 4/33 - Atta¢~nt 'B': .Depth %,nterval 7130- 7131~ 7092%- 7094 Amount &.iKind..,of..~tgrial Used Tested for 1 hour 55 minutes 3-26-66 on %" choke. Test results: flowed 174.5 BO & 12.3 MCFG. Indicated 2185 BOPD, 154.2 MCFPD, GOR 70.5 CF/B. API gravity 29.1° with 13% BS & W. Flowing TP 45. 6276- 6277% 6327- 6328% Tested for 6 hours 4/2/66 on %" choke. Test results: flowed 384 BO & 95.5 MCFG. Indicated 1585 BFPD, 382 MCFPD, GOR 241 CF/B, 37. BS & W. Separate tests r~e* run on intervals: 6206 - 6207% 6169%-6171 6238 - 6239~ 6142 -6143% DM-12 ~lease Date State of Alaska Department of Natural Resources Sec., 31 DIVISION OF MINES AND MINERALS Petroleum Branch INDIVIDUAL WELL RECORD 7/13/66 T. 9N R. 12N S Meridian Permit No. 66-3 Issued 1/28/66 Operator Pan American Pet. Corp. Location (Surface) 1990' FNL & 570 '_ ..FWL, Sec._:3L .... Lease No. ADL 17595 or Owner MGS State 'Loc (Bottom) Well No. 17595 #6' Spud Date:_ .:,.1/28/66 Area Middle Ground Shoal Drilling ceased Suspended Abandoned Completed (F~ 6/13/66 IP .... /~0 B/D, Gray, Total Depth 7400' Elevation 160 ' 3~ ~ _API Cut._/,/ % Casing; Size Depth Sx Cmt Perf: 7130'-31. 1/2'; Plugs: + 275 at surfJ092%~-7094' w/foU~ ¥' holes .... -- - 20" -_~ _612 ' 1192 -- 710 ' 450 13 3/8" 2010' 1300 7" 7397 ' 1900 '; - ' ,~ , ,,,, 4& .... · Surface Lowest Tested_ psi -7352' a~d sand ~raced .w/3300 lb~_.ad_.__ _ .... _ & 26,270 gal treated water. 5800 psi. 6276'-77~ & 6327'- ,~ , , ~, ~,~ ~-- ~- 28% four '¥' holes. Sd fraced 57,100, gal'. treated water w/8200 lbs sd & 4650 lb nut hulls 4650 , See-below. ' .... PRoDUCT'IVE HORIZONS Name Depth~ Contents . WELL STATUS Year Jan Feb Mar Apr May June July Aug Sept Oct Nov Dec _ , Perf. 8~_~9.!es 6206'-07%' & 6238',39%' Frae .W/ 60,000 Ra!_ t.reat, ed~water, 8000 lb sd + 5000 lb nut hulls & 10,000 "lb resin. Perf. 8 holes 6169%'-71' & 6142'-43½' Frac w/54,600 gal treated water, 8000 .lb sd + 4200 lb : nut hulls_ & 7450 lb resin. Remarks: RECEIvED ' .::) o SURVEY TABULATION SHEET '" ~c~o~ cu~,o.~. P~ A~,c~ P~. Co~.~. : ~ w~ ~o. ~ C.~, 175 ~5 ~o ~ w ~ s~.v~ · ... . .. + , ~o. ~,~o /~O~L~ ~o~ 0.. ~o~ ~ .. s ~T~ ............ COR~ECTED ~ ...... OF ~'OUR~[ L CE E · '~ F~ ................. ~ -- ' ~--CU.. ~'~ ~ [ -: --I ....................... j '" '1't " ' , '," ' '. ,' t' · · '] ' ~ ....... c '~ ............ , ' ' ~ I t ..... t ....... ~ ..................... ~ ' - · ~ ~4-zo' ~ ~.o ~ ~o~ ;:~,.o I00 ' I ~ 05 , ,~ n~ ~ .,.~ ~ I .n~ .... 1~ -,- ~._ ~ '.- _2~_. ,~..~ ..... ~_.., ....................... ~.~_~_,~.~.~ , ... ~___: .... = ~.:.~.~ ,. . 't }' ~ · ' t ' t · · ~ I' ' . ~ .' ' ~ ~ . I / . , ,~/ ~ ... '~ .... ,~1 ~: ~ ~ i~, ~ }~1 2OlC ~ , ' ~ ~ , : ....... ~-~o J. _. ',4~ ~¢.~ Cz4,~z',~' W 77 ~' ~",N 7Z ~! ,z~: ~-4~i .~ ~ . ~ ~Z ; ~ o', : I ~ . ' ~ ~ ........ 1 ' ~ ...... -' ' I ; ; ~ I f , I ; ', : :' · ....... : ...... : ......... : " .......... · - · ; ..... ~ [ · · I ~ . . : ......... ' i ~ ~ -- [ i ~ - . ............. . ...... : ' i / i I ; , , : ' , ......... l ................................................. ~ .~ ~ ........ . ............ ............... ' .......... ' ' -'. ........ ; ..:. _'. L,.L.;:':.' WE'LNO /);'GS. 5r~-a 175:?E /V'o, (o RECEIVED CORREC let'; ~IME Mtr A~IJ t~'~- [) |)E PI H (,('ltJ~4 t 10 FAL 15'-~o [3o0 2 Z-OD ~ I c~ a3 -~ ..... ~4 -co ~ 7-co 2 ~-2o 29-20 3~-~o _~.~_~ .... 33.4o ~ ~ -~o ~1-4o 42 ~5-zo ~-oo ]3mo .~0-co '3~0 Ii /tDD I .~ 'lnnn SURVEY TABULATION SHEET '~-- ~,~JaliJ~JtJJaJ~JJ-&fias~ns'C0111~~''- c~ W .... j .... E ~tJRVEY : _ ~o, .o S DATE .,i~o ff?,9':/ // -1~'. 75~ %/~ ,Al, 75 icc.co ?7. '~ ~ ,N. ~o E ~_. ._~,..~O.~ Icc.cc 12 '?q. 7E ........... ? I~oo 100,o0 ,/5-7'?, 75 ' 17oo I oo.~.o .//,, ~'7. 75' V~, /,I, 77 & : · ~/4 .; ......... :Iq.._.'74. '~-"r .......... ~7, ' ,/V 7S~ N .N. 7.3 ~/ .N. Fo v,/ .tV.4Z. F. N 7z E .N ~'z .N 77 'E '7~ E _7~, ~ ?7 E :/v 7~' ,A/ '79 E A/.7~ ~-.", · .. I ,N c.,i d, ?,3 -'''~ " IC,'9 / /_!,.~.7. ......... 12.~¢ /4.09. tg SURVEY TABULATION SHEET FIELD TIME .5Z-oo .54 ~o ~-4 N o [ AN,,LI i I t)lHt L.I'ION 01. II'JC'I.IN,tlICh'M '¢ £ I~ I Ir, a,! .................. t L)) ; , I'l,",l ........ · ................. ~-- · t ~11~,'% [ C'I{%t I.",'l"i'( 't¢tt ~ Ctil,'ltl('lt '.) 1',41)l.'rH q.?.~z ' ~ ~? /7 }."74"! 'iV 5 ~r E i 3° :iv. ~ I qq.=to 2 ¢z. , 45 I · ':f?. f6 .2 'lz.. dO .1'¢.9z.. ; I/4. /V 4.'7 34q"L cTj qq.'-?.+ 37~£;.?,?, .... 2,._..~. ...... /',J _~7 iq'.':t4 ~¢ y.e, 77 ',L. /'J ~-3 .2 9 "I' ~, 71, 2. i . N .50 4c ?,¢,~5'j 2. I. /V ~o ~'0-4O .j 4700 . ~'t"'t.q5 44. ?~.31;/'V4 I .._!i?,%5.4 7 l~,.~:c: / al4 ~ ._ 74 -cc ~ 7~-co , DON E !1 CK BY I F._: ,N 4G E F_.~ .N .C3 E' iq 50'F._ ,5.1 ..... lq (¢ Q E ~ , 4° Ixl "4- F- E. ./V. 61 E; .... A/. ~,5 E. /'4 ~ E. N E.o F_ A/ 7z ./,,v' 7~ N ...74- N 73 A/ ~5 .,/v .IV 17 E.~ ~N :/x/ z5 ~' /,J xq E ;/V' ,SG/Z 'N~40 i . , / · .... '7 -b ...... j . ...... [ ....... I ' ,, ; I, qo ./ .,~. 4,3 . . a,o3 . 3,14 2,43. .. ~. 48. 2.52 ,.~,o I /, 75 ......... E.o~ /,4~. 3,~ 2 ,c5 ~ ,~Z /.47 ............. ~./~ ~_ ~.~/. .... ~,,~? _. ;,7~ 2.~.44a,. .......... [X-~ .3 '~ ~. .... ~.~7 [ ZA7. 4 ~o ' . i ! ,~, z.o,?0 , 2. b,) 7-... zZ.,~'3 ' gO.L(... z6,¢&. - Z'O ,7 3. _'.! ..... : ': ,- .......... ,.:.:,'77.._ <g'.4,0 . ~/, z 7' : 2,';.,, z7 $$, 74 ~ ~.'2.7¢ ~$..zt '. gs.7.-y. /,. 7, z/-J7 ............. 72.70 . . SURVEY TABULATION SHEET FIELD N + $ bHEET NO, 5, LIRVF. Y JOB NO. 51JHVFY DAlE (.)ONE B~ . j i SURVEY TABULATION S'HEET N $t4EIr T NO. $0~ NO ~IRV~¥ rJATE ,ZH - /o oz~r ~;~-oo 7~1.. 7~ ~s.o,, 7~.~ 21-qO 25' /dO t =.%0 ' 25 -,to ?; 175 ~-~oi l~.oo ~oo ,z 't - o o ! ~ :~ 5 0 2~o-_oo I~' ~75 *~F-'~o I',-2~0' 3~-zoI ;375 ~.oo I ' ,45~ ~,~ ~4-oo ['"'~75 4.5-zo ',' ~ ~co DIRECTION OF INCLINATION iJV, '7 ._.'I °...N '___7 ,5' , qo t 5:58 ;~_ :., .o1.: .~ a'IN.sq :E · ~ .. .oci ~ .!d.--o.~ .... ~ )t,',~ 'J ..... N; o5 .~ ...11 : ..... ol .. . , . , ~ .. 0~ N 41 .w ,o~ ,. . 4q ~ ,Ill .1~ "aa'" ra .~ .o~ i . q*:~ ]~ .~ ,~o~. _ ' .5o ,;N..N~ .W ,l~.I ...~ ,78 ,Z~ ; .... ,al i ,Z7 , .... TOIAt. DtSPLAC[ MIrN ! ·: f .Z5 ' , · ~ . .oZ. .,z7 . C. /.04- /.54 · :2,32. .... ;3. Zl .4,11 ........ .... .~.74 . ..;~,57 7. Z~ SURVEY TABULATION SHEET ~c~.o nj, c=& 5r/~ J759~ /V'o. 6 t~:/~/ w ..... -J ...... ~ ~:~,'i';~ r ....................................... c ......................................... <.ohm:.' ~ t. __.":~:..: . I ............. J t- t ......... ! ..................... ' ............. i i ~ ~ ~ ' ' ~ ,,. ')a-~o ~oi~eoi ~o. co.~'~.~i %'i :~ ~ ~'. I~ :N ~ ~ /q-~o,/~ 700 I ~.~ 0~.~3.; / ! .N. ~t ~. .N 7o ~ ~/.~o : 't~L~i~.:t~:z~,7~._ /.._L .... ,/V...~..~._ 10..N_ ~7 .~ ~-~ol. .~o/"7~.-?ff'/~z~: a~ / .N' ~ ~'. :~ Gl ~ 2~-~o . Igoo ', I~.0o./5.i,7, 75, ~/~ ~ ~. ~o . E, .N ~z . ff 29-2o : . :17~ Ito°'e°.l&PY'75:. V~i .~: 75 E I .~ 77 E 30-~o .18~ I/~o~/7~Y. 75, V~, ~. 77 a[ N 79 E a]-xa I']~o i ~Z.?? /~z¢74 ~/4; .'/~..7~ .~.; ........ N..76 E 3~.4o ~$~co~ ~.~ ac.:~?.?l. / ; ~ 7~ ~, .N. 74 E _.~o.~ ~o,.l~,~.z~?,¢:_./'/~, ....... I~v. ~7 ~ I.. z' :~ .... ~.~ ~.~c :>7co I 79.97 ~9~.5~, I V~. . ,N 67 ~ ~ N. 7C ~ . ~5-zo . ;~ool '?~.?7.~72ZSR l Y~i .~ 71 .EI ~: 7~ E ~-oo ~3~oo 17.94 3a?f.37 ~ I ,~. T.~ ~2: . ~ 7~ .E ............ - ................................ ~ ....... , + ..... I ..... s :. .4g ..... · ~3. .73. · 73 /.72.,. . -.i :':c.,I-. _. i ___ 3,C. 2., .. 5,4f. 3,4-1. .//,/,, ? ..... 12.~t¢ 14,o9. 15,7Z,. 1~.4.5 /7,/P. SURVEY TABULATION SHEET the capt'~ uetX. l~ese Form l~j: P~4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE LESSEE'S MONTHLY REPORT OF OPERATIONS Effective: July 1, 1964 ~NO =rr,=~ Anchorage L~,s~ NuMB~RADL 17595 L~^s~ =R "N,T ~^M~ MGS State 17595 Well No. 6 ! State ...... __A_3__a__s__k_a_ ....................... Borough ....... _K.__e__n___a__i__ ........................ Field ..... P_ev._e.3.o. Em_e..n__~ ............................................. T~e followi~ is a correot report of operations a~d prod~etio~ (i~el~di~ drilli~ and prod~cin~ wells) for tY't,e rn, o~t~ of ......... ~_a__y ............................ 19_6__.6__, ............................................................................ ./lffe~t's address P.O. Box 779 Co~,~an~ Pan American Petroleum Corp.. .................................. ......................... ...... ,. .... ..... e~o,~e ........................ _2_ _7_ _2_ :_ _8_ _~. ! -! ........................................... .~e~ s Uae __A_~.__s_~r~.r__~.~mmd__~__m~_ ............. ~EC. AND ~o~ ~ 31, SW/NW *Well pz Flow .testi **Me a s u r e when meter rWF. 9N duc g ~ fac RANGE 12W :ougl ;or WELL NO. ter~ Re. me~ s e~ DA] s Pi IOD~ Omb ~25 itten perfo er wh tabli BARRELS OF On'. 19,998.01 tly. Did cated 627z ich has n~ shed. }RAVITY 37.6 ot a~ 75, ~ bee~ Cu, FT. OF OAS (In' thousands) 8659 .tually pro .332-33, 7G proved. OALLONS OF (~ASOLINE I~ECOVERED None duce 24 92-93, w tolume s BARREL8 OF WATER (If none, so state) 367 lours ea¢ t8 JSPF. ~bject tc REC DIVISION REC DIVISION REMARKS (l! drilling, depth; i! shut down, oau~; date and result of teet for ~oltne content of ga*) See remarks :h day. correction EIVED 1966 MINIMS & MINERAL~ 4CHOP, AGF- EIVED '-' t966 MINES & MINFRAL$ ICHORAGF **16801 1 no NOTE--There were .................... :---~ ....................... runs or sales of oil; ................................................ M cu. ft. of gas sold; no runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be fined in duplicate with thc Division of Mines & Minerals by the 6th of the succeeding month, unless otherwise directed. FORM 470 2-57 AMERIC PETnOLEUM CORPOILATION P. O. Box 779 Anchorage, Alaska 99501 May 11, 1966 File: FKK- 608-WF Re' Forms P-3, MGS State 17595 No. 4 and MGS State 17595 No. 6 Mr. Thomas R. Marshall, Jr. Division of Mines and Minerals Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska Dear Sir: Enclosed are two Forms P-3 describing: 1. Change in production interval for MGS State 17595 No. 6, and 2. Resumption of operations on MGS State 17595 No. 4. With replacement of the caisson by J. Ray McDermott & Co., Inc. , the mechanical problems on Well No. 4 mentioned in the P-1 for Well No. 6 have been overcome. Well No. 4 will be completed in the conglomerate section and Well No. 6 in the sand section as detailed in the Forms P-3 for the respective wells. 'Yours very truly, F. K. Krebill Area Superintendent Enclosures FORM 4'70 2.5'7 PAN AMEmCAN PETI OLEUM CORPORATION P. O. Box 779 Anchorage, Alaska 99501 May ll, 1966 File: FKK- 6 0 5- WF Re: Form P-3, Sundry Notice, MGS State 17595 No. 6 Mr. Thomas R. Marshall, Jr. Division of Mines and Minerals Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska Dear Sir: Enclosed please find three copies of our application P-3, Sundry Notice, describing our intention to change production interval of MGS State 17595 Well No. 6, Permit No. 66-3. Please return one approved copy at your earliest convenience. yoUrs very truly, F. K. Krebill Area Super intendent Enclosure s Form P--3 - STAT~ ,F ALASKA SUBMIT IN TRIPT,. £E* (Other instructions o. re- OIL AND GAS' CONSERVATION 'COMMISSION verse ~de) SUNDRY NOTICES AND REPORTS ON WELLS (:Do not use this form for proposals to driN. or to deepe- or plag baek to a different reservoir. Use "APPLICATION FOR PERMIT~" for such proposals.) OIL [~ OAS WELL WELL OTHER 2. NAME OF OPERATOR Pan American PetrOleum Corporation 8. ADDRESS OF OPERATOR 'Box 779; .Anchorage, Alaska 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At Surfeee Slot No. 4, Leg No. 2, 1989' FNL' 588' FWL, Sec. T9N, R1ZW, S.M. 31 BHL 2072' FNL, 747' FWL, Sec. 31, T9N, R12W, S.M. 14. PERMIT NO. 66-3 15. EL~VATZ0NS (Show whether DF, RT, OB, et~) RT 71.6' Above SL Effective: July 1, 1964 5. LEASE DESIGNATION AND SERIAL NO. ADL-17595 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGREEMENT NAME 8. FARM OR LE,~SE NAME MGS State 17595 9. WELL NO. 6 10. FIELD 'AND POOL, OR WILDCAT Middle Ground Shaal 11. SEC., T., R., !1., Oa BLE. AND SUUVE~ OR AREA Sec. 31, T9N, R12W, S.M. 12. BOROUGH .... '{ 18. STATE Kenai [ Alaska 16. Check Appropriate Box T° Indicate .Nature Gl~ Notice, Report, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE- COMPLETE SHOOT OR ACIDIZE ABANDON$ REPAIR WELL ,CHANGE PLANS (Other) Change production zone SUBSEQUENT REPOR~ OF ** FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) . NOTE: Report results of multiple completion on Well ompletion or Recompletion Report and Log'form.) 17. DESCRIEE PROPOSED OR coMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including e~tima~ted date of .starting any proposed work. If well is directionally drilled, give sul~m-face locations and measured and true vertical depths for all markers and zones perti- nent to this work.) * This notice sets out our' plans to change the production interval on this well from the conglomerate section to the sand section above 7~00 feet. Statement in original P-1 for this well called for completion in conglomerate section. This well will be completed in sand only. MGS State 17595 Well No. 4 is being changed from a shut-in status to a productive status and will be completed in the conglomerate. 18. I hereby ee~~--~-~/ foresoinf Is/~ue and correct TITLE Area Engineer Z)ATE M.ay 11, . 1966 TITLE SUBJECT TO PERIODIC INSPECTION OF RESERVOIR DATA *See Instructions on Reverse Side ~O~M 4?0 PANAMEPJCAN PETROLEUM COP. POP. ATION P. O. Box 779 Anchorage, Al~s~ 99501 May 10, 1966 File: FKK-597-WF Re: Spud New Well, MGS State 17595 No. 6 Director, Division De~r~ent of Natural Resources $~te of 344 Sixth Avenue 2~ucho rage, Alas~ Dear Sir: RECF!VFI') MAY 1 ~1966 DIVISION OF MINES & MINERAL2 ANICHORAGE This is to notify you. t~t Well. No. 6 was spudded on State Lease ADL-17595 at 2,200 hours on Janu&ry 21~, 1966. The surface location of tMs well is in ~'g N'~'~'o. 2, 1,989 it. FSL, 5~ it. FWL, Sec. 3i, T~gN, We plan no directional work on this well, so the bottom hole location will be the same az the surface location. We regret the ~rdineSs of this letter due to an oversight on our part. Yours very truly, F. K. KP, EBILL F. K. Krebill Area Superintendent Form No. P 4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: Suly 1, 1964 ~ i Anchorage ADL 17595 ~ MGS State 17595 Well No. 6 LESSEE'S MONTHLY REPORT OF OPERATIONS SW Sec. TD , 6, 10- W, up. ul fill Tl, e followin~ is a eorreot report of operations and production (inelzeclin~ drillin~ and produein~ wells) for tl, e rr~ontl~ of ....... -A--P_~[1_ ......................... 19~_~- .............................................................................. Corr~..an,,. l~n American Petroleum Corp. ___P__,___O_._____B__o__x___!7_? ................................... ............................ _A___n__c_bg__r_ ......................... a, ................ ............ = ....... .................. ............................................... uue .... ......... 6, 23 %1/2' ./ . nut /2'- w/25 ., , WELL D&es. CU. F~. OF (]AS GALLONS OV BARRELS OF REMARKS SEC. AND r~WF. RANGE ~O. Pao~o,v (~' tho~) ~ ~d rmult of ~t for ~ OF ~ BABRE~ OF O~ GRAVY OASO~E ~ATEB (~ (If ~, d~th: if shut down, RECOVERED ~on0~ So s~to) 0~t of ~) 1/4 1/4 - Esti~te/Est. Esti~teC Est. . .31 TgN 12W 6 4 4,4~7.6~ 3~ 2,311 0 224 None 7,400'. I>BTI) 7, ~52'. Producing wel'L. Perfor~ted 6, 2~6'-6, 20'1-1/2' and 6, 23~'- .th u 1/2' JSi)F Fraced inter--Is ps:flora,ed wi60, 000 gal. trel,ted ~ter w/40 11 000 gmllon~ J ]40 ~ nd l ]b. /1, 000 {aliGn{W-Z6 uSi~ti ~,Z00{lbs. 10-!0 sand, 5,000 lb ils.ant 10,000 lbs. 12-23 506 resi:a s~,:er. Perf,>rated 6 142'-6,]4~-1/Z' and 6,169 171' w I~ - 1/2" JSI'F. ]rraced in, ~rul~{ perforat~d w/54, 600 tall~,ns treated ~ter Ibm./1,000 8allo~mCa Z12, t0 lbs./1, )00 g{~llo~J-140, 1 lb./1,000 galiomW-.Z6 umin8 ~, 000 Ibm. -20 stand, 4, 200 lb ~. 12.,20 nut hulls ami 7,450 lb~ . 12-20 506 resi:a spacer. ell being f..owe.i iniermi~:teutly to {:lean up. No po,entel ~ill be taken until well is c ,. Th~ es,isled oil, ~[ter and g{~s pr,)duced is t~ubject t,) c~nge ~r local offict .s reci,mmended to m~.gement that pr,,duction b~ based ~ pon oil {.elivered to Kenai ne Co: nD~Y. If aI ~prov, ld, this w~:ll ag:cee with the procec ure uses[ by the other ope [lizin8 the oil { ath~ ring system, and efl[ectively we would aG, ~ve produced during 66. T ae 44U7.6U h ~rrels as reflex:ted c n this rep,)rt ~ve not beeu corrected by a ctor o r BS&W :o~t. O:f the ~7.6~ ~,rrels, 1925.29 ba~ relm ~ve been placed in t theri~t syste~[ an{ 256~;. 39 ~rrels were con~im~d in ~u~$ aboard Platform B as D0 a. = i. 5..1-6t g ppro:d~tely 1, 0~5 {[dditio~l l~rrels ,)f crude will be required t 1 hn &m~rican'm ')ortit,u of the g{~theri,ng system before ,il will he run for sale. .......... cleaned 'Pipe )e rato r · April meter the 'NOTE.--There were .............. ..n...O.. ........................... runs or sales of oil' . ................ .~..0.. ......................... M cu. ft. of gas sold' ............................. .~..O.. ........................ runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month, unless otherwise directed. Et£ective: July 1, 1964 LEASE DESIGNATION AND SERIAL NO, Form P--3 STAT tF ALASKA SVgMIT IN TRIP] (Other instructions OIL AND GAS CONSERVATION COMMISSION verse side) SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT~" for such proposals.) ADL 17595 O. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. 7, UNIT AGREEMENT NAME 2. NAME OF OPERATOR 8. FARM OR LEASE NAME Pan American Petroleum Corporation MGS State 17595 9. W~LL NO. 6 Slot No. 4 of Leg No. 4 (1,989' FNL and 588' FWL), Pan American MGS 'Platform "B"; Sec. 31, T9N, R12W, S.M. 10. FIELD AND POOL, 0R WILDCAT Middle Ground Shoal Il. SEC., T., a., M., OR BL,r. AND SURVEY OB' AREA Sec. 31, T9N, R12W, 12. BOROUGI-I ~' '1 18. STATE Kenai Alas ka 8. ADDRESS OF OPERATOR ,:iii P.O. Box 779, Anchorage, Alaska 99501 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surfece 14. PERMIT NO. 66-3 15. ELEVATIONS (Show whether DF,-ST, GR, eta.) RT 71. 6' Above SL S, M, 16. Check Appropriate Box T° Indicate .Nature o[ Notice, Report, or Other Data NOTICE OF INTENTION TO; FRACTURE TREAT MULTIPLE- COMPLETE SHOOT OR ACIDIZE ABANDONS REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPOR~ OF: WATER SHUT*OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING AEANDONMENT' (Other) N OTE: Report results of multiple e0mpletton on We~ ompletion or Recompletion Report and Log form.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, ~ive sub~trface locations and measured and true vertical depths for all markers and zones perti- nent to this work.) * 1. Perforated 7,130 - 7,131'-1/2 and 7, 092-1/2 - 7, 094 feet w/4 jspf. Fracture with 22,200 gal. treated water containing 3,300 lb. sand. , Perforated 6,327 - 6,328-1/2 and 6,276 - 6,277-1/2 feet w/4 jspf. Fracture with 59,620 gal. treated water containing 8, 200 lb. sand, 4,650 lb. nut hulls and 11,500 lb. resin. o Perforated 6,206 - 6,207-1/2 and 6,238 - 6,239-1/2 feet w/8 jspf. Fracture with 60,000 gal. treated water containing 8,000 lb. sand, 5,000 lb. nut hulls and 10,000 lb. resin. . Perforated 6,169-1/2 - 6,171 and 6,142 - 6,143-1/2 feet w/8 jspf. Fracture with 54, 600 gal. treated water containing 8,000 lb. sand, 4,200 lb. nut hulls and 7, 450 lb. resin. R E C [ I V [ 9 18 1 66 DIVISION Of MINES & ~INERAL$ ANCHORAGE 18. I hereby certify that/tho f~egolng~ls true agd . correct TITLE Area Superintendent D~Tm 4-14-66 (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE *See Instructions on Reverse Side Form No. P 4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: July 1, 1964 /~¢~.,~,~/( =,-,=,- Anchorage ~ ~,'. .u.~. ADL 17595 ~' ~ ~'~ ~MGS State 17595 Well. No, 6 ~"'~ LESSEE'S MONTHLY REPORT OF OPERATIONS State ....... __k__l_._a__s___k.__a_ .................... Borouph ........ __K.__e_:~.a._! ....................... Field ....... _D_ _ ~_ _v. -e-_]:_o_ .p_._r~._ .e_._n__t_ T]~e followir~ is a eorreot reporg of operatior~s arid prod~etion (ir~el~di~ drillin~ and prod~einff wells)/'or the month of ....... ._M_._a__r_c___h__ ..................... ,19_6__6_. .............................................................................. ,~1fleet' s address ..... ?_:____0__:__~.o_.x___7__7__9_ ................................. Company __?__a___n___A_._m_ _e__r.i~c__a___n_._?_._e__t.r_.9__l_e_._u__.m.....C__.o- rp. A n c ho_ _r a_ _g__e__,_ _ _ _ _A_ _1_ _a__s__ _k__a_ ....................... s~a'_ .... ~~ ............... ..................... ' ......... SW 1 NW 1 Sec o TD 7 Cu. F~. ov GAS GAIJ. ONs o~ BAaEErS O~ REMARKS SEC. AND ~wP. RANGE WELL D~s. BARRE~ OF O~ ORA~Y OASO~E WATER (~ (If ~lling, depth; if shut down, aa~; ~ OF ~ NO. Pao~oe~ (~'tho~) RECOVERED none, so state) da~ ~d r~ult et t~t for ~l~e oon~t of ~) . . . , . /4 3t TgN12W 6 0 0 0 0 0 0 None ,400' Pt~TD 7,~52'. ~esting well. {:ore No. 6-6,144' - 6,15~', Core No. 7_ 6, .5~' - 6, [79', Core No. a- 7 067' - ?,103' ~a:~ Dual Ir.duction Laterolo~ So ~ic, Ga~ma- )ensity, }roxi~MW-Micrclog. ?" Casing ~et at w/960 sx Class 'G" w/l% TIC and 940 sx Class "C~" Neat. ~an P~rforated 7,~)~ - 7,1~1-~/2~ and 7, 092-]./2' - 7, )94~ w/4-1/a Te~ted. S;md ~acedwell usina 26,270 gallons tr~..atedwa':er with ~,~00 lbs saad a~ average injection ~'5,800 psi. Perforatei 6,276~ - 6, ~77-1/~' and 6, ~aT' - 6,~a-]./~'.with4-1/~ ~SP~. Te~tedand sand fraced well ~sing 57 100 gallons t::eated water wi;h a, ~00 1~. sand 4,650 lbs. n~t hulls avaraae in~ectioa of 5,000 psi. AP~ 131966 ~IVISION , ~~E ............ 'NOTE.--There were ............ .n...o.. .............................. runs or sales of oil; ..................... n..0.. ..................... M cu. fl. of gas sold; no. runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month, unless otherwise directed. Form~P 3 STAT ~F ALASKA SU~MIT I~ TRIm rE* (Other instructions .; re- OIL AND 'GAS cOnSERVATION COMMISSION verse a~de) SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) OIL ~[ GAS [~] WELL WELL OTHER 2. NAME OF OPERATOR Pan American Petroleum Corporation ADDRESS OF OPERATOR Box 779, Anchorage, Alaska 99501 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surfece Conductor No. 4, Leg No. 2 (1989' S of NL and 588' E of WL); Pan American MGS Platform "B," Sec. 31, T9N, R12W, S .M. 14. PERMIT NO. ~66-3 15. Ev-~,VATIONS (Show whether DF,-RT, (IR, et~) ET 71.6' above MSL Effective: July 1, 1964 ADL 17595 5. LEASE DESIGNATION AND SERIAL NO. 6. IF INDIAN, ALLOTTEE OR TRIBE: NAME ?. UNIT~&GREEMENT NAME 8. FARM :OR LEASE NAME MGS state 17595 , 9. Wi~LL hO. 6 10. FIELD AND POOL, 0E WILDCAT Middle: Ground Shoal 11. SEC., T., R., M., OB BLK. AND SURYE~ OR 'AREA Sec. 31, T9N, R12W, S.M. 12. BOROUdTI ,~,,118. STATE Kenai AlaSka 16. Check Appropriate Box T° Indicate Nature oF Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF II PULL OR 'ALTER CASING FRACTURE TREAT MULTIPLE. COMPLETE SHOOT OR ACIDIZE ABANDONS REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT O~ ': WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ~ ALTERING CASING SHOOTING OR ACID,ZING ABANDONMENT* (Other) BToTE: Report results of multiple eompleUon on Well ompletion or Recompletion Report and Log'form.) , 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is direotionall¥ drilled, give subsurface locations and measured and true vertical depths for all markers and zones perti- nent to this work.) * · This is to report an intended selective perforating and fracturing program in some 12 zones between the intervals of 7261' and 5300' using a 30,000-or 60,000-gallon fracturing treatment, depending on the size of the selected zones. 0pera~tions to commence around March 25, 1966. 18. I hereby certlAY that f~'e fo~oing is true and correct TITLE Area Superintendent DATE March 17, 1966 TITLE *See Instructions on Reverse Side Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: July 1, 1964 ~r~,~.~ Ancho rage qq~A N"~8~R ADL 17595 aR uN,~ N^~E MGS State 17595 Well No. 6 LESSEE'S MONTHLY REPORT OF OPERATIONS State ............. _A___~_~_s___k__ ~_ .............. B o r o u ~ h ........... .K___e_n__~._~_ .................... Field Tl~e followi~ is a oorreot report of operations arid prod~otio~ (iz~et~di~ drilli~ a~d prod~ein~ for of ....... ................ ............................................................................. ~l~er~t's address P.O. Box 779 'Corn-an' Pan American Petroleum Corp. .................................................... ~ .............. p Y ............ ~~~,~~.-_-~' ....................................... ................................ _ ~A__ _n__c___h_9_ _r_ _~_ g _e__,_ _ _ _A_ _ ]._ _a__s_ __k~_ _ ...................... Si,Jned ......................................... Pl, or~e ...................... _2__?_2___-_~__4__7_!. ................................ ~ .......... ,4~ er~t' s title ..... .A__?__e__a__~_S___u_p___e__r_~__n_t..e___n__d__e..n__t. ......... ~EC. AND ~o= K SW 1/4 NW 1/4 Sec. ~1 TD 6,144'. Or. FT. or B&R~ELZ O~ On. (Inthousands) GALLONS OF BARRELS OF O,somsr W,~ZR (If RECOVERED none, so state) O' 0 0 0 e. Ceme: etween 20' casing and 32" C12. Set 8" casing at 2,010 with 1, )0 sx Clas with 2% aC12. ,an tern nd 20" ca~ ~ith 450 Class" 'plus temp and C Cut llowing 846' REMARKS (If driillng, depth; if shut down, oau~e; date and result of t~t for gm~olLae co. taut of ~a~) None )ile with 275 sx ,00 sx Class "A" survey. Cemented % CaC12 from ores: NOTE.--There were .............. n...°.. ............................ runs or sales of oil; ............ ..n.o. .............................. M cu. ft. of gas sold; ......................... .n...©. ............................. runs or sales of gasoline during the month. (Write "no" wher~e applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6'th of the succeeding month, unless otherwise directed. ' Form No. P 4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: July 1, 1964 · ~No =rF,c~ Anchorage L~A~ N--MB~R ADL 17595 L~A~E oR ~,~ ~MGS State 17595 Well .No. 6 LESSEE'S MONTHLY REPORT OF OPERATIONS TI~e followir~ is a eorre,g report of operatior~s a~d prod~egior~ (ir~cl~dir~ drilli~ and produeir~ wells) for ~h,e month of ...... _~_~__n_~__u~___r_~_ .................... 19_6___0__, .4ge~'s address ____P.,____Q;____~___o__x___7___7__~_ .................................. Com,~an~, Pan Axne ric&n._Petr4:~l,eum Co rp. ............................. _~_b__o__r__a__~_~,___~_~_a___~.~_a__ ......... i ........ ~ ..... -- ,_ ~ .......... O~~'s~n~-~r ............. ~e~e~ ................... F-.--K,--tG~BILL ................. ~o~e ................... ~_7___~__-_~_7__1 ............................................... ~f~'s u u e __ A_r__e__a____S.__~__e_ ~_i__n_ ~ .e__n.__d__e._n__t_ ........... SEc. AND TWP. RANGE WELL D~rs. CU. FT. OF GAS GALLONS 01~ BARREL~ O~ RE~ARKS OASO~E WATER (~ (If ~, depth; If shut down, ~ OF ~ ~O. Pao~o~ BARRE~ OF O~ GRAVY (~'thous~) ~ECOVEEED none, so s~te) d~te ~d r~ult of ~t for O~t Of . . · ......... 1/~ 31 T~NlgW 6 0 0 - 0 0 0 0 Non~ 5Z0~. Tril~pin~:. grell spudded Zgt}0 ho~[r~ Jan~r~ Z~, 19 ~6. Set ~0'~ ca,ing at 61Z~ with 742 sacks Cl~ss "G" a~d 45( sacks Cl~[ss "G" with Z% oaCl/ Cemented betvreen Z0" casi~ g and 32" pile ~rith 275 s~,cks plus Z% CaC[~ I ................ SW 1 NW Sec. TD NOTE.~There were ........... .~..0.. ............................... runs or sales of oil; ............... ..n..0. ........................... M cu. ft. of gas sold; ....................... ..n...o...- ............................. runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.~Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month, unless otherwise directed. : J - FORM SA-I B -.. · DATE : ~ ~ ~ . SUBJECT.: ~~~~'~. ~ ~ :~ '-~: ' '~ , ' d, '~. ~ ~ ':.' : - _ -- . .. , . .. . rm P 1 _ . ~:,_ .... . .... . . SUBMIT IN TR17 · - ' -' '~ '* ,S.T~ E OF'ALASKA' . ": .-..- (Other tnstruetio., on . .- . -. alL AND.GAS CON:SE~VATION cO~ISSlON-, : ..: APPLICATION ~FOR-PERMIT'TO~DRILL, ~DEEPEN; :OR 'PLUG, i:BACK' :DRILL_[] DEEPEN I~ '~' PLUG BACK, I-'] WELL · WE~L QTHE~ .... ~. ZON~ . · ZONE Pan American Petroleum CorporatiOn . . , ADDRES~ OF OPERATOR ' w'~; ~d: - ~ ~ ' -~A~'~ . P. O. Box 779, Anchorage, LOCt~IOI'OF~IL~ (Report location 'el~rlFand~in,;aee~an~:~'anY~B~,r~uirements.*) At surface 5?0' E>o~-~.est Line,,:19901-.S-ofNL, Sec.-..3t, TSN-~iZW, SM tt proposed prod. zone (Conductor 4 Leg 2 of Pan Am MGS Plat- Same ' form B) I~. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICEs 1§. 45 Miles SW of Anchorage, Alask~ DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTYOR LEASE LINE, FT. (Also tonearest drlg. unit line; if any) ~,9l! DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL, DRILLING, COMPLETED, OR APPLIED FOR, ON THIS LEASE, FT. 16. NO. OF ACRES IN LEASE 5106 ~s. PROPOSED DEPTH 7300' 21. ELEVA~ONS (Show whether DF, RT, GR, etc.) Est. RT 70' above MSL 23. PROPOSED CASING AND CEMENTING PROGRAM SIzE OF HOLE SIZE OF CASING WEIGHT PER FOOT SETTING DEPTH Z6" 20" 76.# 600' 'July 1~ 1964 ~'. LEASE DESIGNATION AND SERIAL NO. ' -ADL i-7'5-95 - 6. IF INDIAN, ALLOTTEE OS TRIBE NAME 7. UNIT AGREEMENT NAME' · - , 8.' ~iaM Ga MGS -State 1'7595 · 9. WELr~ NO. 10:'FiBISD AI~ 'POOIJ~' OR WILDCAT Middle Grour/d Shoal 11. S~c., T., a., M.,, Ga BLK. " A~Y~S~a¥~ Oa Aims Sec. 31, T9N-R12~W, S ewa r d .Me ridian 12. B. OROUGH SHJ 13. STATE Kenai I Alaska 17.NO. OF ACRES ASSIGNED TO THIS WELL 20.ROTARY 'ORCABLE TOOLS Rotary 22[ AFF~OX. DATE WORK WILL START* 2-1-66 17-1/2" ]- 13-3/8" 9-7/8"- [ 7" 54.5# 26.# 2000' 7300' QUANTITY OF CEMEN~ To surface, Class A w/2~0 CRC1 To surface, Class A W/2%, C~C1 To be determined from logs To be replacement well for Middle Ground Shoal 17595 No. 4 Well which is shut in due to mechanical problems. This well to be drilled for completion in the conglomerate. If mechanical problems are overcome in Well No. 4 completion will be made in upper sands. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program, if any. 24. I hereby certif~ that ~he Foregoing is..~True and C~;rect. TITLE Area Superintendent DATE January 27, 1966 (This space for Federal or State office use) PERMIT NO. ~ " ~/ /fi '. ii. / APPROVED B~ - CONDITIONS OF APPROVAL, IF AN~ ~ TITLE APPROVAL DATE THOMAS R. MARSHALL, JR. Execu||y~ ~Qcrefe~ry Alaska 0~1 & Ocs Conservation Committee DATE *See Instructions On Reverse Side MERIDIAN , ALASKA · LEG F;O. I LEG N"3 2 TgN :51 LAT. 60° 49' 4.5.75" LA''r. 60° 4~)' 45.2~" LAT. 60° 4,9' 44.70" LONG 151° 29' 00.95'' LONG ~51~ 29' 00.07" LONG 151° Y = 2,498,069.8 Y = 2,498,014.46 Y = 2 497,963.55 X : 235, 255.0 X ; 255,297, 30 X : 235,230.30 FROM N.W. COR, FROM N.W. COR. FROM N.W. COR. ~,954'SOUTH ~ 198g' SOUTH & 2041 SOUTH 8, 544' EAST 588' EAST 522 EAST SCALE I"= logo' ilo TBN LEG NO 3 [ _EG NO 4 t LAT. 60° 49' 45.25" LONG 151° Y= 2,4981018.88 235,187.78 FROM N.W COR. ~987 SOUTH -~TB' EAST ~J OTE The Ioca'.,'~,")n of '~,',.3'=orrr was occom$!:shec, i ,_'~). ' -' Boulder,end Cost, trol points CET "-) , and Granite Point Nc':-,ve and triangulation ~tation: .... Foreland Light O';:fse? , c.:-. Arness Dock. 32 COOK INLET CORRECTION LINE CERTIFICATE OF SURVEYOR · t hereby Certify that I om properly registered and I¥censed to practice land surveying in the Store Al~sko end thmt this plat represents a location survey made by me or under my supervision und that ~11 dimensions and other detoils crc correct. Date SurVeybr ~' LOCATION SURV~-'~,_, OF A FIRST ORDER CONTROL. "PA H" ON ,°LATFO,fi'M SURVEYED FOR PAN AMERICAN PETROLEUM PO BOX 779 ¢,;':~'H'h~,",%~, _. , ..~, A sL)R'v EYED-'' 5¥ F. M. LINDSEY o, LAND SURVEYORS 8, CiV',L 1415 W NORTHERN LIGHTS ANCHORAGE, ALASKA
