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Home My WebLink About195-199You don't often get email from casey.morse@hilcorp.com. Learn why this is important From:Rixse, Melvin G (OGC) To:Casey Morse Cc:McLellan, Bryan J (OGC); DOA AOGCC Prudhoe Bay Subject:20240718 APPROVAL for reservoir plug revised bottom of plug - Sundry Status - Ba-31 & Ba-06 Date:Friday, July 19, 2024 11:38:00 AM Attachments:image001.jpg Casey, Hilcorp is approved to pump cement as describe below on PTD 195-199 reservoir plug. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Bryan McLellan, AOGCC Inspectors From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Friday, July 19, 2024 11:17 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: FW: [EXTERNAL] RE: Sundry Status - Ba-31 & Ba-06 Mel, Per our phone call, here is the description of the procedural change for the Baker 31. Thank you, Casey Morse Well Integrity Engineer Hilcorp Alaska, LLC (907) 777-8322 From: Casey Morse Sent: Friday, July 19, 2024 8:58 AM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: RE: [EXTERNAL] RE: Sundry Status - Ba-31 & Ba-06 Good morning, Bryan. After cleaning out the tubing on Ba-31, we ran out of coil on the reel with the end of coil at 10,686 (corrected depth). My plan is to pump 27 bbl of cement to fill the 5” liner and bring the cement up into the tubing tail. We will then pull coil up above the sliding sleeve and circulate down coil and up the IA to make sure the sliding sleeve is still clear. We were unable to inject into the perfs after cleaning out the tubing. The tubing / IA pressured up to ~2000 psi and only lost about 100 psi in 5 minutes. Please let me know if you have any concerns with this revised plan. Thank you, Casey Morse Well Integrity Engineer Hilcorp Alaska, LLC (907) 777-8322 From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Tuesday, July 16, 2024 9:57 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL] RE: Sundry Status - Ba-31 & Ba-06 Bryan, I just spoke with our coil vendor and will need to propose a change to the Ba-31 procedure. After cutting a substantial amount of coil off the reel during our recent Steelhead work, the offshore reel is only capable of running to ~10,800 ft, which I did not account for in the Ba-31 sundry. In the sundry, I requested a variance to 25.112(c)(1)(A) in case we were unable to clean out to TD. That same variance request would apply here as well. If we lay in the cement from 10,800 ft, the plug would extend from there across the top of perforations at 10,220’ and to the estimated top of cement at ~9,500’. This will require 37 bbls of cement instead of the 60 bbls in step 7 of the Coil Tubing procedure in the sundry. Could we please modify the procedures accordingly to reflect this equipment limitation? Thank you, 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 Morse Well Integrity Engineer Hilcorp Alaska, LLC (907) 777-8322 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, July 12, 2024 11:52 AM To: Casey Morse <Casey.Morse@hilcorp.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL] RE: Sundry Status - Ba-31 & Ba-06 Casey, I’ve reviewed Ba-31 and your plan seems good to me. The sundry still needs some internal reviews but I believe we’ll have you an approved sundry by Tuesday. I haven’t looked at Ba-06 yet, but will prioritize it for early next week. 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: Friday, July 12, 2024 9:11 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Sundry Status - Ba-31 & Ba-06 Bryan, Have you been able to look through the deep cement plug / suspend sundries for the Baker 6 and 31? I’m trying to coordinate the crews for their next hitch coming up on Tuesday and figure out what work we can line up for those guys. Please reach out with any questions you have about those procedures. Thank you, Casey Morse Well Integrity Engineer 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. 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 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 the onward 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. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,636 feet 9,345 feet true vertical 10,807 feet N/A feet Effective Depth measured 9,345 feet 9,214 feet true vertical 8,846 feet 8,735 feet Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 9,296 (MD) 8,804 (TVD) 9,214 (MD) 316 (MD) Packers and SSSV (type, measured and true vertical depth) VTL Pkr 8,735 (TVD) FMX TRSCSSSV 316 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 0 N/A Sr Pet Eng: 7,250psi Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Daniel Taylor dtaylor@hilcorp.com 907 777-8319Operations Manager N/A 303 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 303 N/A 0 Size 303 801 000 0 00 13-3/8" 9-5/8" 8,290psi 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 195-199 50-733-20469-00-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0017595 Middle Ground Shoal / MGS Oil MGS ST 17595 31 Plugs Junk measured Length measured TVD Liner Liner 6,070 5,610 2,368 Casing Structural 5,937 8,991 5" 6,070 9,520 11,636 10,806 801 2,073 801Conductor Surface Production 32" 18-5/8" 4,760psi 7,020psi 3,450psi 6,870psi 8,160psi 2,073 2,072 Burst Collapse 1,950psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:48 pm, Aug 01, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.08.01 14:22:56 - 08'00' Dan Marlowe (1267) DSR-9/10/25 RBDMS JSB 080725 BJM 11/19/25 Offshore Baker Platform Ba-31 Middle Ground Shoal Cook Inlet Basin, Alaska Middle Ground Shoal Last Completed: 05-29-1996 Oil Well Size Type Wt/ Grade/ Conn ID Top Btm CMT Top 32” Structural Weld Surface 303’ surface 18-5/8” Conductor 97#,X-56,QTE-60 17.621” Surface 801’ surface 13-3/8” Intermediate 68#, K55, BTC 12.385” Surface 2073’ 1º Surface Calc 9-5/8” Intermediate 47#,L-80, BTC 8.661” Surface 6070’ 26º 1935’ Calc 7” Drilling Liner 29#, L-80, BTC 6.184” 3910’ 9520’ 7050’ CET 5” Production Liner 15# L-80, BTC 4.401” 9268’ 11636’ 9570’ CBL Completion 3-1/2” Production Tubing 9.2#, L-80, IBTM 2.992” Surface 9296’ N/A Completion Jewelry Detail # Depth Length ID OD Item 316’ 2.813” HES “FMX” TRSCSSSV 9161’ 2.750” HES “XN” nipple w/2.813” packing bore 9173’ 2.813” HES “XD” Dura-sleeve w/2.813” “X” nipple profile (opened 10/2/2010) (Down to open) 9180’ 2.750” HES 2.75” ID Polished nipple 9214’ HES “VTL” Production Packer w/8’ SBE 9262’ 2.750” HES “X” nipple profile 9296’ 2.992” WLEG FISH None 10/2024: CMIT to 2400 psi –success. Tag cement top @ 9345’ SLM. 07/2024: CTCO to 10,686’ (end of reel). Spot 27 bbl cement 10/2010: Tubing circulated w/9.8 ppg brine. Tubing plugged after LCM pill pumped. 10/2010: RIH w/ 2.73” GR to 9270’ RKB. RIH w/3.5” BO shifting tool to HES XD sleeve at 9173’ RKB. Hit twice and tool fell through –sleeve opened. 8/27/07: RIH w/2” GR and tagged fill at 11456’ KB w/o issues. 1996: Complete loss of returns during displacement of 13-3/8” cement. Perforation Data Top Btm 10220’ 11448’ Isolated 11470’ 11543’ Isolated PBTD =9345’ TD = 11636’ Max Hole Angle = 34.5º@ 9532’ MD 18-5/8” 801’ 9.8 ppg Brine RKB: MSL = 118’ 9-5/8” 6070’ G&G Top of Oil 8300’ 13-3/8” 2073’ SSSV 316’ 32” 7”9520’ 5”11636’ 11456’ tagged w/2” gauge ring Perfs 10,220’-11543’ TOC Calc 1935’ TOL 3910’ TOC CET 7,050’ TOC CBL 9570’ SS at 9173’ opened 10/2/10 5” TOL 9268’ Spot 27 bbl cement @ 10,686’ Tag cement 9345’ 9.8 ppg Brine SSSV 316’ KB: MSL 118’ Mean Sea Level 0’ Mud Line -102’ ADL: 17595 PTD: 195-199 Leg 4, Slot 6 API: 50-733-20469-00 Wellbore Schematic Suspended Well Inspection Data Well: BA-31 Surface Location: 235’ FSL, 1444’ FWL, Sec 19, T9N, R12W, SM, AK Permit to Drill: 195-199 API: 50-733-20469-00 AOGCC Inspection Date: 2025-07-20 AOGCC Inspector: Witness Waived by Mr. James B. Regg, AOGCC, 2025-06-29 Size Pressure (psi) Tubing 3-1/2” 30 Casing 9-5/8” 5 Casing 13-3/8” 80 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: x Well was suspended in November 2024. The perforated interval was isolated with cement to 9,345’. Well on suspension while being evaluated for possible sidetrack. x Condition of Wellhead: Good x Condition of Surrounding Surface Location: Good x Follow up actions needed: None Attachments: x Current Well Schematic x Picture(s) x Plat - 1/4mile radius of wellbore ") ! ) ) !##D D #!! !) ! !#! !#( ! ! ! D #!##) ! D ! ! )#! ) ! BA-29 BA-08 BA-09RD1 BA-05 BA-12 BA-23 BA-31PB1 BA-28PB2 BA-07 MGS-A23-01LW MGS-A12-01LN BA-11 BA-15 BA-20 BA-30 BA-08RD BA-25RD BA-28 BA-09RD2 BA-501 MGS-A12A-01 BA-18 BA-27 BA-31PB2 BA-15RD BA-13 BA-17 BA-04 BA-25 BA-14 BA-28PB1 BA-06 MGS-A11-01 BA-10 BA-16 BA-32 BA-09 BA-31 Baker 29 31 2 25 6 30 32 1 36 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Casey Morse; Regg, James B (OGC) Cc:Juanita Lovett; Dan Marlowe; Daniel Taylor Subject:RE: Baker P&A Scheduling Date:Monday, June 23, 2025 3:24:00 PM Casey, The answer to both questions in your email below is yes. 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: Monday, June 23, 2025 2:02 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com>; Daniel Taylor <dtaylor@hilcorp.com> Subject: Baker P&A Scheduling Jim / Bryan, We are solidifying our plans for this year’s campaign of Baker P&A work, and we are hoping to start executing our coil and cement work in early August. It will take us several weeks to prepare the platform for staging equipment and hosting our crews, so that process is underway. Our intent is to conduct coil, eline, and cement work in the first phase. Once cement plugs are set in accordance with the approved sundries, we could place notice for witness of all the tags and MITs to coincide. With that in mind, there are a couple deadlines coming due in July, and I want to be sure we are aligned on work timing and coordinating for the most efficient use of time and resources. Baker-05 (PTD 165-038): Sundry 324-367 includes work scope to tag cement tops and perform a CMIT after providing 48 hours’ notice to AOGCC for opportunity to witness. This work was not completed during last year’s program. The sundry was approved 7/1/24 and has a one year expiration. Could we extend this sundry expiration date to continue work under this sundry and coordinate the tags, MIT’s, and suspended well inspections to coincide with others on the platform before the end of the 2025 work season? Baker-31 (PTD 195-199): Sundry 324-387 placed this well into Suspended status with an approval date of 7/16/24. The Suspended well inspection will be due in July for the 12-month inspection. Could we also push this deadline to coincide with the inspections for the remaining wells at the end of the 2025 work season? We are unable to continue work beyond mid-November due to weather constraints and facility limitations. It is our intent to complete the sundried work with enough time to issue notice and conduct all the witnessed tags and MITs in advance of that time. 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 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. 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: n/a Rig Elevation: n/a Total Depth: 11636 ft MD Lease No.: ADL0017595 Operator Rep: Suspend: P&A: X Conductor: 18-5/8" O.D. Shoe@ 801 Feet Csg Cut@ Feet Surface: 13-3/8" O.D. Shoe@ 2073 Feet Csg Cut@ Feet Intermediate: 9-5/8" O.D. Shoe@ 6070 Feet Csg Cut@ Feet Liner: 7" O.D. Shoe@ 9520 Feet Csg Cut@ Feet Liner: 5" O.D. Shoe@ 11636 Feet Csg Cut@ Feet Tubing: 3-1/2" O.D. Tail@ 9296 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bottom 11618 ft 9345 ft 8.6 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2598 2551 2529 IA 2598 2551 2529 OA 99 99 99 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Good tag, good test. MIT - pumped 2.1 bbls, returned 2.0 bbls. October 8, 2024 Kam StJohn Well Bore Plug & Abandonment MGS ST 17595 Baker-31 Hilcorp Alaska LLC PTD 1951990; Sundry 324-387 none Test Data: P Casing Removal: Brad Whitten Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-1009_Plug_Verification_MGS_ST_17595_Ba-31_ksj 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 99 9 9 9 9 &0,77[,$ James B. Regg Digitally signed by James B. Regg Date: 2024.11.19 11:20:04 -09'00' 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 T20240716-1 Mudlog Image Files for each of the well bores listed in the table below: Well Name PTD # API # MGS ST 17595 31 195-199 50-733-20469-00-00 SFTP Transfer - Data Folders: Please include current contact information if different from above. 195-199 T39219 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.16 14:46:39 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: CTU cleanout 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): 11,636 N/A Casing Collapse Structural Conductor Surface 1,950psi Intermediate 4,760psi Liner 7,020psi Liner 7,250psi 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 N/A 6/30/2024 11,636'2,368' 3-1/2" 10,806' VTL Pkr & FMX TRSCSSSV 9,214 (MD) 8,735 (TVD) & 316 (MD) 316 (TVD) 9,520' Perforation Depth MD (ft): 6,070' 10,220 - 11,543 5,610' 5" 9,595 - 10,730 8,991'7" 303' 32" 18-5/8" 13-3/8" 801' 9-5/8"6,070' 2,073' MD 6,870psi 3,450psi 801' 2,072' 5,937' 801' 2,073' Length Size Proposed Pools: 303' 303' 15# / L-80 TVD Burst 9,296 8,160psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017595 195-199 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20469-00-00 Hilcorp Alaska, LLC MGS ST 17595 31 AOGCC USE ONLY 8,290psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager 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 Middle Ground Shoal Middle Ground Shoal Oil N/A 10,807 11,618 10,792 2,802psi N/A Perforate Repair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test 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: 2024.07.05 11:15:04 - 08'00' Dan Marlowe (1267) 324-387 By Grace Christianson at 12:05 pm, Jul 05, 2024 10-407 CT BOP test to 3000 psi 7/12/2029 A.Dewhurst 15JUL24 DSR-7/8/24 X Provide 48 hrs notice for AOGCC to witness tag and pressure test of cement plug to 2400 psi BJM 7/12/24($8 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.16 09:58:32 -08'00'07/16/24 RBDMS JSB 071624 Oil Zone P&A Program Well: Ba-31 Well Name: MGS ST 17595 31 (Ba-31) API Number: 50-733-20469-00-00 Current Status: Shut-In Producer Rig: CTU, EL, SL, cement Estimated Start Date: July 2024 Estimated Duration: 2 days Reg.Approval Req’d? Yes Regulatory Contact: Juanita Lovett First Call Engineer: Casey Morse 603-205-3780 (M) Second Call Engineer: Ryan Rupert 907-301-1736 (M) Current Bottom Hole Pressure (est): 3800 psi @ 9980’ TVD (PT survey 2005, 7.3 ppg EMW) Max. Potential Surface Pressure: 2802 psi Gas Column Gradient (0.1 psi/ft) Current Pressures (T/IA/OA): 5/20/110 psi History Drilled and completed in 1996 as an oil producer. The well was shut-in in 2003. In 2010 the well was circulated w/ 9.8 ppg brine and the perforations plugged with 15 bbls of LCM pill displaced w/ 60 bbls 9.8 ppg brine (~7000’ MD). The tubing subsequently plugged off. 18-5/8” casing set @ 801’ MD in 24” UR hole. Cemented w/ 811 sxs 12.9 ppg lead and 636 sxs 15.8 ppg tail. 60 bbls of clean cement circulated to surface. 13-3/8” casing set @ 2073’ MD in 17.5” hole. Cemented w/ 330 bbls 12.9 ppg lead and 119 bbls 15.8 ppg tail. Lost all returns 194 bbls into displacement. Calculated cement top with 10% washout would have been at surface before losing circulation. Daily report says, “annulus fluid level fell roughly 30’ and gradually rose back to flowline level as plug bumped. Returns were good until that point.” 9-5/8” casing set @ 6070’ MD in 12.25” hole. Cemented w/ 1263 sx 12.9 ppg lead and 171 sx 15.8 ppg tail. Lost 237 bbls during displacement. 7” Liner set @ 9520’ MD in 8.5” hole. Cemented w/ 324 bbls 15.8 ppg. No cement circulated off LTP. TOC @ 7150’ from bond log of 4/29/96. Current Status Shut-in. Perforations are plugged with a Calcium Carbonate LCM pill and the Tubing and IA are loaded with 9.8 ppg brine. Tubing was plugged off with LCM. Sliding sleeve is open. Pre-P&A Diagnostics Performed: 1. T: 0 psi / IA: 0 psi / OA: 87 psi 2. Attempt to inject down Tubing, took 3 bbls 9.8ppg brine, pressured up to 500psi, held for 5 minutes – good test. 3. Attempt to circulate down tubing and up IA, pressured up to 1700psi w/ 0.6 bbls. Bled down to 1200psi in 5 minutes. 4. Pump down IA, pressure up to 880psi (tubing climbed to 440psi.) Held pressure on IA, lost 60 psi in 10 min. No change observed in tubing pressure. Bled off IA, tubing pressure dropped to 270psi. No change observed in OA pressures throughout. 5. Total bbls to fill IA=181bbls. Oil Zone P&A Program Well: Ba-31 6. RIH w/ 2.75” GR to 7660’ SLM. POOH and add knuckle joint on tool string. RIH to 8865’ SLM. Unable to work any further. RIH w/ bailer, work down to 8872’. POOH with thick sludge in bailer. 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) (A). Hilcorp will attempt to clean out fill across the perforation to the historical plugged back TD @ 11,618’ and cement via the displacement method. This would put the bottom of the proposed cement plug 75 feet below the base of the perforations. There is only one Pool between that depth and the top of perforations at 10,220’ MD, the Middle Ground Shoal Oil Pool as defined in Conservation Order 44 A. Procedural steps Coil Tubing 1. MIRU Coiled Tubing and pressure control equipment 2. PT BOP to 250psi low / 2500psi high 3. MU Millout BHA a. Working fluid will be FIW (8.6ppg) b. Take returns to surface up the CT x tubing annulus c. Taking returns to formation is also permissible 4. RIH and cleanout / mill through end of tubing. Tagged fill inside tubing @ 8872’ 5. Continue into 5” liner and attempt to cleanout through perfs to PBTD @ 11,618’. Previous tag depth was 11,456’ 6. While on bottom, drop ball and open circulating sub. Circulate wellbore to 9.8 ppg brine. a. Check T x IA circulation through the sliding sleeve, and circulate IA to 9.8 ppg brine if possible 7. Pump reservoir abandonment plug as follows: a. 60 bbl 14 ppg Class G cement i. Places top of cement inside the 5” Liner ~9500’ b. Pull up into the tubing and circulate to clean out coil 8. POH and RD coil Fullbore/Slickline 1. CMIT TxIA to 1500 psi (AOGCC Witnessed). 2. Tag TOC (AOGCC Witnessed). E-Line 1. If unable to establish T x IA circulation after coil cleanout, pick up tubing punch on E- line. RIH and punch tubing at ~8,870’. Fullbore 1. Fluid pack the tubing and IA with 9.8 ppg brine if not already done during coil work. Cement Tops: x 13-3/8” Casing: CMIT TxIA to 2400 psi per 20 AAC 25.112(g)(2) 0.25 x 2593' TVD of top perf = 2400 psi. -bjm Variance is not required. 20 AAC 25.112(c)(1)(C) allows for cementing from PBTD to 100' above top perf. If hard fill is encountered below top perf interval, the entire perf interval need not be cleaned out before placing cement from top of fill to at least 100' above top perf interval. -bjm PT BOP to 3000 psi high. -bjm Oil Zone P&A Program Well: Ba-31 o 330 bbls (940 sks) 12.9 ppg Class G lead and 119 bbls (571 sks) of 15.8 ppg Class G tail o Lost all returns 194 bbls into displacement o Annulus volume with 10% washout: 274 bbls 1987 to 801: 1186 ft * 0.1237 bpf = 147 801 to surf: 801 * 0.1279 bpf = 102 o Casing volume: 1987 ft * 0.1498 bpf = 298 bbls o Displacement required to get cement to surface: 298 + 274 – 449 = 123 bbls o 123 < 194 bbl actual displacement pumped before returns were lost. Cement would be at surface x 9-5/8” Casing: o 2488 cu-ft (1263 sks) of lead Class G slurry mixed to 12.9 ppg, 200 cu-ft (171 sks) Class G tail mixed to 15.8 ppg. o Total pumped volume: 2688 cu-ft o Returns lost during displacement: 225 bbl o Bbls cement less losses: 254 bbl o Annular volume (12 ¼ x 9-5/8) = 0.056 bbl/ft o Height of cement column: 4548 ft - 10% washout = 4135 ft o Top of cement: 6070 – 4135 = 1935 ft x 7” Liner: CET Bottomhole Pressures x Frac pressure: estimated at 0.9 – 1.1 psi/ft as per AIO 7 o TVD of top perf is 9593’. x Full column of 9.8 ppg brine: 4890 psi o Do not exceed 2500 psi with 9.8 ppg brine in well Attachments: Current Schematic Proposed Schematic Coil Tubing BOP Diagram WBD_Ba-31_Jan2011.docx Page 1 of 1 10-7-2010 MQ – 12/2010 Offshore Baker Platform Ba-31 Middle Ground Shoal Cook Inlet Basin, Alaska Middle Ground Shoal Last Completed: 05-29-1996 Oil Well Size Type Wt/ Grade/ Conn ID Top Btm CMT Top 32” Structural Weld Surface 303’ surface 18-5/8” Conductor 97#,X-56,QTE-60 17.621” Surface 801’ surface 13-3/8” Intermediate 68#, K55, BTC 12.385” Surface 2073’ 1º Surface Calc 9-5/8” Intermediate 47#,L-80, BTC 8.661” Surface 6070’ 26º 1935’ Calc 7” Drilling Liner 29#, L-80, BTC 6.184” 3910’ 9520’ 7050’ CET 5” Production Liner 15# L-80, BTC 4.401” 9268’ 11636’ 9570’ CBL Completion 3-1/2” Production Tubing 9.2#, L-80, IBTM 2.992” Surface 9296’ N/A Completion Jewelry Detail # Depth Length ID OD Item 316’ 2.813” HES “FMX” TRSCSSSV 9161’ 2.750” HES “XN” nipple w/2.813” packing bore 9173’ 2.813” HES “XD” Dura-sleeve w/2.813” “X” nipple profile (opened 10/2/2010) (Down to open) 9180’ 2.750” HES 2.75” ID Polished nipple 9214’ HES “VTL” Production Packer w/8’ SBE 9262’ 2.750” HES “X” nipple profile 9296’ 2.992” WLEG FISH None 10/2010: Tubing circulated w/9.8 ppg brine. Tubing plugged after LCM pill pumped. 10/2010: RIH w/ 2.73” GR to 9270’ RKB. RIH w/3.5” BO shifting tool to HES XD sleeve at 9173’ RKB. Hit twice and tool fell through – sleeve opened. 8/27/07: RIH w/2” GR and tagged fill at 11456’ KB w/o issues. 1996: Complete loss of returns during displacement of 13-3/8” cement. Perforation Data Top Btm 10220’ 11448’ 05-09-1996 Open 11470’ 11543’ 05-09-1996 Covered by fill PBTD =11618’ TD = 11636’ Max Hole Angle = 34.5º@ 9532’ MD 18-5/8” 801’ 9.8 ppg Brine Top of Ghost Hole w/BHA 6930’ RKB: MSL = 118’ 9-5/8” 6070’ G&G Top of Oil 8300’ 13-3/8” 2073’ SSSV 316’ 32” 7”9520’ 5”11636’ 11456’ tagged w/2” gauge ring Perfs 10,220’-11543’ TOC Calc 1935’ TOL 3910’ TOC CET 7,050’ TOC CBL 9570’ SS at 9173’ opened 10/2/10 5” TOL 9268’ Top of Ghost Hole w/BHA 9806’ 9.8 ppg Brine SSSV 316’ P L U G G E D KB: MSL 118’ Mean Sea Level 0’ Mud Line -102’ ADL: 17595 PTD: 195-199 Leg 4, Slot 6 API: 50-733-20469-00 Current Schematic WBD_Ba-31_Proposed 7-2024 Page 1 of 1 10-7-2010 MQ – 12/2010 Offshore Baker Platform Ba-31 Middle Ground Shoal Cook Inlet Basin, Alaska Middle Ground Shoal Last Completed: 05-29-1996 Oil Well Size Type Wt/ Grade/ Conn ID Top Btm CMT Top 32”Structural Weld Surface 303’surface 18-5/8”Conductor 97#,X-56,QTE-60 17.621”Surface 801’surface 13-3/8” Intermediate 68#, K55, BTC 12.385” Surface 2073’ 1º Surface Calc 9-5/8” Intermediate 47#,L-80, BTC 8.661” Surface 6070’ 26º 1935’ Calc 7” Drilling Liner 29#, L-80, BTC 6.184” 3910’ 9520’ 7050’ CET 5” Production Liner 15# L-80, BTC 4.401” 9268’ 11636’ 9570’ CBL Completion 3-1/2” Production Tubing 9.2#, L-80, IBTM 2.992” Surface 9296’ N/A Completion Jewelry Detail # Depth Length ID OD Item 316’2.813”HES “FMX” TRSCSSSV 9161’2.750”HES “XN” nipple w/2.813” packing bore 9173’ 2.813” HES “XD” Dura-sleeve w/2.813” “X” nipple profile (opened 10/2/2010)(Down to open) 9180’2.750”HES 2.75” ID Polished nipple 9214’HES “VTL” Production Packer w/8’ SBE 9262’2.750”HES “X” nipple profile 9296’2.992”WLEG FISH None 10/2010: Tubing circulated w/9.8 ppg brine. Tubing plugged after LCM pill pumped. 10/2010: RIH w/ 2.73” GR to 9270’ RKB. RIH w/3.5” BO shifting tool to HES XD sleeve at 9173’ RKB. Hit twice and tool fell through – sleeve opened. 8/27/07: RIH w/2” GR and tagged fill at 11456’ KB w/o issues. 1996: Complete loss of returns during displacement of 13-3/8” cement. Perforation Data Top Btm 10220’ 11448’ 05-09-1996 Open 11470’ 11543’ 05-09-1996 Covered by fill PBTD =11618’ TD = 11636’ Max Hole Angle = 34.5º@ 9532’ MD 18-5/8” 801’ 9.8 ppg Brine RKB: MSL = 118’ 9-5/8” 6070’ G&G Top of Oil 8300’ 13-3/8” 2073’ SSSV 316’ 32” 7” 9520’ 5” 11636’ 11456’ tagged w/2” gauge ring Perfs 10,220’-11543’ TOC Calc 1935’ TOL 3910’ TOC CET 7,050’ TOC CBL 9570’ SS at 9173’ opened 10/2/10 5” TOL 9268’ Cleanout to PBTD 60 bbl cement @ 11,618’ 9.8 ppg Brine SSSV 316’ KB: MSL 118’ Mean Sea Level 0’ Mud Line -102’ ADL: 17595 PTD: 195-199 Leg 4, Slot 6 API: 50-733-20469-00 Proposed Schematic 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 David Douglas Hilcorp Alaska, 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: 6/24/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240624 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MGS ST 17595 #5 50733100710000 165038 02/16/1966 SCHLUMBERGER CBL MGS ST 17595 #31 ST2 50733204690000 195199 04/28/1996 SCHLUMBERGER CET Scanned Log Images (PDF and TIF FORMAT)gg( ) Please include current contact information if different from above. T39003 T39004MGS ST 17595 #31 ST2 50733204690000 195199 04/28/1996 SCHLUMBERGER CET Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.24 15:34:52 -08'00' STATE OF ALASKA ALASKOL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Repair Well LJ Plug Perforations LJ Stimulate U Other U Cancel Procedure Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ �� u 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: "•-•7.• CO" Name: Development 0 Exploratory ❑ 195 -199 6 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ 6. API Number: 50- 733 - 20469 -00 4-' 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017595 [Baker Platform] MGS ST 17595 31 ' 9. Field /Pool(s): Middle Ground Shoal Field/ E, F and G Oil Pool 10. Present Well Condition Summary: Total Depth measured 11,635 feet Plugs measured N/A feet true vertical 10,806 feet Junk measured 11,456 feet Effective Depth measured 11,456 feet Packer measured 9,214 feet true vertical 10,658 feet true vertical 8,734 feet Casing Length Size MD TVD Burst Collapse Structural 303' 32" 303' 303' Conductor 801' 18 -5/8" 801' 800' 2,250 psi 630 psi Surface 2,073' 13 -3/8" 2,073' 2,072' 3,094 psi 1,540 psi Intermediate 6,070' 9 -5/8" 6,070' 5,937' 8,160 psi. 7,020 psi Production 5,610' 7" 9,520' 8,991' 6,870 psi 4,760 psi Liner 2,368' 5" 11,636' 10,806' 8,290 psi 7,250 psi Perforation depth Measured depth See Attached Schematic FEB True Vertical depth See Attached Schematic t,. NE B 6 6 LO1Z Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2 #/ L -80 9,296' 8,809' HES "VTL" HES "FMX" Packers and SSSV (type, measured and true vertical depth) Production Packer 9,214'MD/ 8,734' _ •'' , • ' D 11. Stimulation or cement squeeze summary: N/A RECEIVED Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A JAN 2 7 2012 12. Representative Daily Average Prod.ictiglf&6kdjbi 7 On Cons. Commission Oil-Bbl Gas -Mcf Water-Bbl Casing/Tye Tubing Pre sure Prior to well operation: 0 0 0 —2-10 psi 80 pci Subsequent to operation: 0 0 0 0 psi 0 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Development 151 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil • 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -295 Contact Hilcorp Drilling Dept. at 777 -8301 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ` `= � Phone 276-7600 Date 1/25/2012 49 Form 10-404 Revised 1‘3 re MS JAN Submit Original Only ,...... r evro Cook Inlet Basin, Alaska J► Offshore Baker Platform Ba -31 Middle Ground Shoal . Middle Ground Shoal Last Completed: 05 -29 -1996 ■k . '` I Oil Well RKB: MSL = 118' KB: MSL 118' ADL: 17595 PTD: 195 -199 'r i . Mean Sea Level 0' Leg 4, Slot 6 API: 50- 733 - 20469 -00 a - Mud Line -102' Current Schematic 32" :4 - :::: st y;: >; 18 -5/8" 801 Size Type Wt/ Grade/ Conn ID Top Btm CMT Top ,' 2073' L 13-318" 32" Structural Weld Surface 303' surface I 9.8 , pp9 1. 8- 5/ 8° ... ..........................._ Conductor -- ........_ # , X - 56 _ QTE - 60 .... ._._..._ Surface ................_... .. ........._......_ Brine 2073' Surface 13 -3/8" Intermediate 68#, K55, BTC 12.385" Surface 1° Calc P 9 -5/8" I ntermediate 4 7 #,L -80, BTC 8.661" S urface 6 06 0 TOL 3910' " " 7" Drilling Liner 29#, , 39 BO' 5 " Production Liner 15# L -80, BTC 4. 9268' 11636' CBL TOC Calc `: 4954' Completion i 3 -1/2" I Production Tubing 9.2 #, L -80, IBTM 1 2.992" Surface I 9296' I N/A ' Completion Jewelry Detail 9 5 /$" # Depth Length ID OD Item 6070' L 316' 2.813" HES "FMX" TRSCSSSV Top of 9161' 2.750" HES "XN" nipple w/2.813" packing bore Ghost Hole HES "XD" Dura- sleeve w/2.813" "X" nipple CBL ' w /BHA 9173' 2.813" profile (opened 10/2/2010) (Down to open) 7 7,1515 0' 6930' 9180' 2.750" HES 2.75" ID Polished nipple 9214' HES "VTL" Production Packer w /8' SBE 9262' 2.750" HES "X" nipple profile 9296' 2.992" WLEG G&G Top of • .. _ ........................_ ..._....._....... ............................... ....,................_..—..................................... .............. :300' \\ . FISH ..............._.. .... ... ...................._._ None _ ... I S 9173' — ...... ..........................._.._ ..... ............................. z..........__..................:......................................_. i__.................................................. .._.........._....._..__.. —__.. _._......................... opens 1 /2010: w/9.8 ppg brine. Tubing after LCM pumped 10/2/10 RIH w/ 2.73" GR to 9270' RKB. RIH w/3.5" BO shifting tool to HES XD sleeve at 9173' RKB. Hit twice and tool fell through — sleeve opened. 8/27/07: RIH w /2" GR and taggedfill at 11456' KB w/o issues. 1996: Complete loss of returns during displacement of 13-3/8" cement. 5 " TO MI 92 7" 9520' — -- ..............---_............................._._...—_................................_...............................------......................._......................................_......................_............ ............................... ..............._................................... .........................._.... TOCCBL — ... .................__............ ...................._......................._.._.................................................._..........................._......_.................................... ............................... 9570' Ghost st of Gst Hole w /BHA Perforation Data • _. 9806' . • Top Btm Perfs ..._....._ .... ......................i.. 10220' i 05 -09- 1996 ......_ Open ......_..__... ..._._......................... ' 10,220'- 11543' ' I i i 11456' tagged ` _ 11470' i 11543' F05-09-1996 Covered by fill w /2" gauge ring ' ; r 5 "11636' E , PBTD = 11618' TD = 11636' Max Hole Angle = 34.5° 0 9532' MD WBD Ba -31 Jan2011.docx Page 1 of 1 10 -7 -2010 MQ — 12/2010 Chevron • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) Ba -31 MGS ST 17595 31 ADL0017595 5073320469 BH1677 118.00 Jpp�a , . Primary Job Job Category Objective Actual Start Date Actual End Date Well Preparation Well 10/2/2010 10/3/2010 Services Primary Wellbore Affected Wellbore UWI Well Permit Number Ba -31 507332046900 1951990 1012/2010 00:00 - 10/3/2010 00:00 Operations Summary R/U slickline and pressure test lubricator to 250 psi low/ 2500 psi high. RIH with 2.73" GR to 9,270' RKB. RIH with 3.5" BO shifting tool to XD sleeve at 9,173' RKB - open sleeve. R/D slickline. 10/20/2010 00:00 - 10/2112010 00:00 Operations Summary R/U on Ba -31. Pressure test lines to 300 psi low and 2000 psi high. Pump 9.8 ppg KWF down tubing taking returns up 9 5/8" annulus holding BHP constant. Saw good, clean 9.8 ppg KWF at 483 bbls pumped. Bullhead with 2 bbls 9.8 bbp KWF and well pressured to 1460 psi. Shut down and monitor well. ISIP =1460 psi, 1 min =1398 psi, 5 min =1257 psi. Bleed down well. Pump 15 bbl LCM pill and displace with 60 bbls 9.8 ppg KWF. Shutdown pumps. Well dead. R/D. 10/26/2010 00:00 - 10/26/2010 00:00 Operations Summary R/U on Ba -31. Pressure test lines to 500 psi low and 2000 psi high. Attempt to pump down tubing and up 9 5/8" annulus but tubing pressured up to 1300 psi. Lined up to pump down 9 5/8" annulus and up tubing. Pumped 10.5 bbls diesel at 1 bpm. Chased with 47 bbls 9.8 ppg KWF, caught pressure to 650 psi. Tubing pressure went from 80 psi to 400 psi. Attempted again to pump down tubing but was unable to circulate. Bleed off pressure, Shut -in well. R/D. 10/26/2010 00:00 - 10/27/2010 00:00 Operations Summary R/U on Ba -31. Pressure test lines to 500 psi low and 2000 psi high. Pump down tubing with 9 5/8" casing shut -in, attempt to squeeze. Shut down with 0.4 bbls pumped and 2000 psi. 1 min bleed = 1950 psi, 5min =1940 psi. No change in annulus pressure = 0. Pump down 9 5/8" annulus at 1 bpm and caught pressure at 5 bbls pumped. Pumped a total of 17 bbls = 1800 psi with very little returns. Pumped down tubing, taking returns up annulus. Pumped 0.5 bbls increments pressureing up to 2000 psi, then bled to 1000 psi. Pumped total of 7.3 bbls before pressure locked up at 2075 psi. 1 min bleed =2063 psi, 5min =2020 psi. Bleed pressure off, Shut -in well. R/D. ) " 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 0 3 2005 Alaska Oil & Gas Conservation Commission 5tANNEX.}NO'~ 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Baker Platfonn Pilot Pre-Abandonment Work Summary \ q5 -' l ú q \ ~../1J ~~' Dear Commissioner Nonnan, This letter is intended to update the Alaska Oil and Gas Conservation Commission on the status of U nocal ' s pilot pre-abandonment work on the Baker Platfonn in Cook Inlet, Alaska. On October 22, 2004, Unocal proposed that a pilot program be initiated on the Baker platfonn 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 platfonn would have a bottom hole pressure (BlIP) 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 BlIP 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 Platfonn 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 platfonn has been initiated. ~..~Jn~ 1,r AJE . ,,:)¡ ¡ - ~. ,Þ" ~....~..... à ~~~ Union Oil Company of California I 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 ofUnocal, 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, ~ --Ôé, .2 ~ L-~ /~~ ~ Timothy C. Brandenburg Drilling Manager Attachments Cc: Dale Haines Gary Eller Union Oil Company of California I 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-J ul~05 Ba-121 Injector 16-Jul-05 7121 6106 2941 0.482 9.3 Ba-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-17 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-J u 1-05 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 Sa-30 Producer 4-Jul-05 10966 9109 3593 0.394 7.6 .~~ ~ Ba-31 Producer 29-Jul-05 11 433 10636 3795 0.357 6.9 Sa-32 Producer No survey ) .i>~~A~~ :} !Æ~!Æ~~~!Æ A.'IfA.SK& OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOW5KI, GOVERNOR 333 W. -¡m AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)27&7542 Mr. Dave Cole Oil Team Manager UNOCAL P.O. Box 196247 Anchorage, AK 99516-6247 tq~~ lq1 Re: Middle Ground Shoal Unit Platfonns Dillon and Baker Dear Mr. Cole: This letter confirms your conversation with Commission Engineer Tom Maunder last week regarding the multiple Applications for Sundry Approval (Fonn 403) you submitted in mid October regarding changing the. monitoring frequency on the 16 wells on Dillon Platfonn and 23 wells on Baker Platfonn. Production and injection operations were halted on these platfonns in 4th Q 2002 and 2nd Q 2003 respectively. Attached, please fmd the Sundry Applications, which are being returned without approval"5 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 platfonns are unmanned and not operating, it is not possible to obtain daily infonnation. 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 (AlO 7 for Baker and AIO 8 for Dillon) and Conservation Orders (CO 44 and CO 54) for the platfonns/unit. The Commission looks forward to receiving your letter applications. If prior monthly monitoring infonnation has not been submitted to the Commission, that infonnation should be ubmitted forthwith. ,~' SinC~~~ . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this _day of November, 2004 Ene!. , (,~ A '2UGE, CANNED NO\ (,; ~ . SJ Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil of California aka Unocal 1. "l:ype of Request: 3. Address: 7. KB Elevation (ft): 118 RKB above MSL 8. Property Designation: BAKER 11. Total Depth MD (ft): 11636' Casing Structural Conductor Su rface Intermediate Production Liner Perforation Depth MD (ft): 10,040 to 11,543 Packers and SSSV Type: 909 West 9th Ave. Anchorage AK 99501 Total Depth TVD (ft): 10806' Length 748' 2,023' 6,017' 5,610' '\ STATE OF ALASKA '\ ALA~._.{ OIL AND GAS CONSERVATION COMMI~v10N APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Suspend U Repair well D Pull Tubing D Perforate U Waiver U Annular Dispos. U Stimulate D Time Extension D Other [2] Re-enter Suspended Well D Monitor Frequency 5. Permit to Drill Number: Development Stratigraphic [2] D Exploratory D 1951990 Service D 6. API Number: 50-733-20469-00 PRESENT WELL CONDITION SUMMARY / Effective Depth MD (ft): Effective Depth TVD (ft): Plu~~aSUred): 11618' 10792' / MD TV~ Burst ?63' 801' / 800' 2,076' 2,075' 6,070' / 5,937' 9,520' / 8,991' 11,636/ 10,806' Tubing Size: Tubing Grade: 9. Well Name and Number: Baker 31 10. Field/Pools(s): Middle Ground Shoals Size 32" 303' 18-5/8" 13-3/8" 9-5/8" 7" 2,368' 5" Perforation Depth TVD (ft): Printed Nam/j D'>7ole SignafJJre~-/1.d¡¿; á~ L-80 @ 9296' Packers and SSSV MD (ft): HES VTL pkr @ 9214', HES FMX TRSC 316' 9,437 to 10,729 BOP Test ~ Form 10.,.ffl4 Revised 12/2003 12. Attachments: Description Summary of Proposal ~.~ / Detailed Operations Program D BOP Sketch D / 14. Estimated Date for Commencing Operations: / / Junk (measured): Collapse 2,250 psi 630 psi 3,094 psi 1,540 psi 8,160 psi 7,020 psi 6,870 psi 4,760 psi 8,290 psi 7,250 psi Tubing MD (ft): 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil [2] GasD WAG D GINJ D Date: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correc. to the best of my knowledge. Contact Title Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY / Phone / Conditions of approval: Notify Commission so hat a representative may witness Plug Integrity D Other: Subsequent Form Required: Approved by: D Location Clearance Mechanical Integrity Test [2] D Service Plugged WINJ D D WDSPL Abandoned D D 27-Sep-2004 Sundry Number: :?t~L/-4 37 D RBDMS BFL NOV' 2 2D04 APPLICATION RETURNED 11/17/04 NOT APPROVED BY COMMISSION COMMISSIONER BY ORDER OF THE COMMISSION OR\G\NA- Date: Submit in Duplicate oN OR BEFO ANUARY 03 00 C:-L,O~-DOc AOGCC Individual Well Geological Materials Inventory PERMIT DATA T DATA PLUS Page: 1 Date: 05/13/98 RUN DATE RECVD 95-199 95-199 95-199 COMP RCD 6/26/96 L MYLOR 10930-11100 COMP RCD 7/23/97 L MYLAR 10400-11222 COMP RCD 8/22/97 L MYLAR 10230-10550 1 07/10/96 1 09/16/97 1 09/16/97 10-407 R COMPLETION DATE . / / / DAILY WELL OPS R / / / TO / / / Are dry ditch samples required? yes no And received? Was the well cored? yes no Analysis & description received? Are well tests required? yes no Received? yes no Well is in compliance Initial COMMENTS / / / / / / yes no yes no Unocal Energy Resources D~;¢~on 909 West 9th, P.O. BOX lC.. Anchorage, AK 99519-6247 Telephone (909) 276-7600 Fax (907) 263-7828 UNOCAL Debra Childers Clerk DATA TRANSMITTAL 96-15 July 9, 1996 To: Howard Oakland 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items. Granite Point 22-13 RD ./blackline/fiim Completion Record, Run 1 5/28/96 Granite Point AN-21 ,.,iblackline / film Completion Record, Run 1 6/04/96 ~ Granite Point AN-39 RD.~-'" blackline/film Completion Record, Run 1 5/30/96 ~"~ MGS 17595-31 ST2 --'" blackline / film Completion Record, Run 1 6/26/96 SCU 341-4 .,. blackline / film Completion Record, Run 1 5/11/96 --J,4 SCU 341-4 ~ blackline / film Completion Record, Run 2 5/30/96 SCU 341-4 /' blackline / film TDT, Run 1 5/29/96 -)..~ TBU G-26 ~/' blackline / film Completion Record, Run 1 5/30/96 ¢"' ~'~ TBU K-26 RD ,/' blackline / film Completion Record, Run 1 6/09/96 TBU K-26 RD ,..-~blackline / film Completion Record, Run 1 6/19/96 TBU K-26 RD -/ blackline / film Completion Record, Run 2 6/28/96 ~ TBU K-3 RD ~ blackline / film Completion Record, Run 1 6/21/96 ;1.~'~i 'TBU M-2 S v/ blackline / film TDT, Run 1 6/23/96 TBUM-25 .,/blackline / film Completion Record, Run 1 6/21/96 TBU M-25 (/ blackline/film Completion Record, Run 1 6/25/96 TBU M-25 /'- blackline / film Completion Record, Run 3 6/27/96 --'"'"TBU M-5 ~ blackline/film TDT, Run 1 6/22/96 Please acknowledge receipt by signing and retuming one copy of this transmittal or FAX to (907) I Received by: Date: AlaskaOii& 6as Cons. ~ A~c~orage . FRI 08:10 RM UNOORLqNOHORRGE ~-a× NO. 9OY .~ f55~ ~, ui -. .----.- --_ · 1,,-~---- _... ~_ . .-. ~, _J~ .-. '. , , . STATE OF ALASKA · " · .. .'., c . ALASKA. 0IL AND' GAS CONSERVATION OMMISSION , :. · .,::' ,. ': APPLICATION FOR SUNDRY APPROVALS'. ":-" '" '.'-..'- '-. ·" ' ' Alter casing.----" ." · Repair~l:., · . ' ..Plugging: .?.ime eXtension: . . · stir~ia-~,,. :.'-'. ,'. . ". ' '" · · ' . · .C;_hang_e approvCd_'~ograrfl; -' '" PUll tubing; 'vad-'~ce; ,: "'Pe4rerate'-?X Oiher. """- .... 2, Na~l~e of Ol~eratar ..... : .... .. '"'' · 5. T~e of well: ~,' De~um ele.vatio~ ~t~.or KI~) . . . i : ' U~ia~ O,.!1Co~,.pany of..C, aliforrlia (U,..N..0CAL) ..... · r, Oevelopmenti x. l'18'R~,B.ab~¥e-MSL. '-" .' · · 3. Address. .. .. .... ... .,..'. ,. .. . Exp~orat0ry: ~ 7. Un~ ~r Property na'~e . ,- · " : Strafig~aphi¢:.. . .' : · ' P,.O, Box 1~24.7., Anchorage, AK ~gs19 '.." ' · ' '. .... $e~¢~: '-~'... . C,haka_c_hatr~ '!'~,.I,0~oi~ofwelf'atsL~'ace Bal<eriSlatfo~Leg'#41!Slot#'~ ' " "' 8,1W~llnumber.." -' ', '.'" '" ..'.. · . .;. .. .. . '" ; ' 1S~8.7"ENL,..44~3' F'WL,.Sec~ 31; T..SN, R12W,'SM.:". '..'" ' I... 'l~ker.3! ' ' At t~p'¢ pre2~h/e lntencal' . (10783~ MD/10~88' ,'I~VD) . "~,' Permit n~m~'r 'i :: .... . .. · 34, FNL, .1074' FWL, Se~..,3'1, .TgN, RI2W, ,SM. . '.. . ~--¢21'~' "." ·" ' ":"" . ' ' At,er~a4~i~¢ ' : ' ' . ' ~b. ^~,;~,~ber .. · "- · ,......., .., .. . · . ... .so_. _. 73,20~ :.~3: · .. At t0~'~lepth (11636' MD/1080~ T.VD)' .' .. .. ., :...' 11, Field/~'ool ' "· '. - ' :' '"-~ : . · · ..- Z35' ESL; 144~ FWL, Sec. 30, 'I:gN, R'f~ .W,'SM,', .....'. ,, , ' '; '" Middle <3r~und ...T0tal. depth:...'.' · ' 'rnea~red ..' ' 1t~36' feet "- "Piug~'.(meas~re~) "" '. · i ' · ; . . . · .. · . .'.. ' ....... :.' t~ue vert~,al 10806' . 'feet.: . · .. ', '... .. ' . .: :. .. ; '. ;..' :.'. . . . . .. .. . . ·..'. EffeCtive del~h: . . . .measured ' . '. '~1818'-' . feet.. Junk(measured) - .. '" "' . . " true verll~l ' .I0792' · feet '. " "' ' :" ..'. . . . . ...'.; . .. . . .. .'. :.. . ... . . . .. 'C,a.sing' '. ""' . 'l::Lm~'th .... ~i~e :(~er,,~ted. ' MeasUred'd~Fth' Trim vertical depth · Structu~l '. . . '. . ". -,' . . . . . . · .'.... ..' .. . .. '. . C~nductor , .. 78~",. .'. 18,S/'¢ .23~9..¢F. . .' .. ' ' .. ~01" '. .... 'Surfaoe.. ' 202,~3' 13-,3/8" " ~.$21 OF 2076' ..... .. '" 207~' ... :' ... 'lnte~medlat~ . ~0'17" ..... e-,53" 2b'8~.6F' ' . 607i3 ..... ., · · ~93T. i','.' . · . 'P. mdUSti0n' ". ' ' ' .". "'.."S~'JO' ' ' ' 7" ' 181'¢ CF' ; 952O' · . ..' Liner .... '. '2368':. ~ 427 <2F :11836' 10806' .'. · - ,EIVED " Perforation depth; me'asur~:{. {0783'-~09~'; 10997Ll1030'; 11107'd ft40'i.11200'-'~123;)': 'J'1312',1134,¢, ~ 14~[~1 .... .. "· ....... 1"1470'-11.503', 1:'1533'-11~4.3', . ' .... ' '"" '- ' '. ' .... "' ' ' ' .. . . . . · . . ' ' ' .' ' I. -.....' .. ~e'~,,~,,~ · '~o~-~o"zCZ;.~'~?z,~.. ~03ec-~o~',..~"o444"4047'z, ~os3$'4oses'. ~'0~2,~'4065~', .... ." ... . . . .. '.. · " . : ... 10669'~10696', 10721'-10729', ' '" " . T~,t,~r;,(~iz,.¢~¢;~.',~,,~',~,;,,~,,¢h). i, .~.~,TZ.:etZ~L_~¢.gZ~.- . ...' '" ' .. ."". "..dUN .'.~ ]':... i9"9..6 :' .. .... · . · .. .. .. . . .' .Pa¢N~rs a',{:{ $$$V (t~3}e and flleasured dept~) .~ES .V'I'L p~:~l'921,4',: .HE,S FMX TR$6 {~ 3'16" . · .'.: .... ' .' ' . '. ..' ; . ' ' . ':.. ...... .='. .". .,, · ,.. · .. _ -- . , .., . 1.4.. Es~imleted date fo~: ~om.m' .en~ln.g ~peratl.on .; ... .,.- .. 15.,:..S. tatu.~ of w~ll Cfassific~tio~ aC: '. " '" . '. ' ".. · . · ., . .. .r¢23~26/96.. '. ' ., ..... . ... .:-... ... ",' .. -~-e-. ~f..~,o~..~i,~,;,~,b~/.;~,p~;4: . : '-. ' ' . .. . o,: x · .. "'~,,~:'__, ". s',,}~.~',~; · ." .: . · :'. .. · . .. , · ., . . . : , . · . , : · ., · ... · .. ,=.~-,. · ,.. Nam? of appr,o,,,ver . · .. . Date acpro'vec{ Service: .' ' · . · .. . , '...: . '. .' .. .. ', ' ..':' ' : ~i,,~: U,~"H,ir~ "."' · . T'~":.'C~,'i,,~Ma,,~e, .. . ' . .... ., .. ,. ...... · . '_:': ' ' , ,.:,,.FOR OOMMlS$1ON USE ONLY' .. . :-7'. .. ,. .... " -' '" · ." . ..'. ~lu~ ~eor~...2.~ '.' I~O.P... l~et. . ". . I-~a~ion... ei~ne~' " .. :; ' .' ' ... ~:han~ ~nu~rav'r~m_~.__ Sub~equent.'iorm requi~ 10- · ~..~f : . ' .. "~ ' ' '·"7 '.' ". g .... · .. ~' : '" .... " ' ' ' "" '~' " '" ' .... ' '" " · ' : ~' ' .. ' · ·~.' .. .. .~- .i . . . : · .. : · . .. .. . . , . · ; ,, . · . · ., .., . :.. .:.'. "'..'. ... . · . , . . ' .. . . . ~pl~rOved hy or,:~' or m';'C,~mmissi~der' ,,,.. ./" "," ' ,',. ." ' Com'missidner', ,, ." .. ' Da~.. ~). -. Appro~/eci'Co~Y. , . Returned.. . SUBMIT IN TRIPLICATE · . · . . · . o ER I 08:10 RH UNOORI~6NOHORRGE BAKER'PLATFORM ' ': ' COMPLETION'DiAORAM $/29/96 · · .. '"" ..'"';'.2.,': . ,'..'!/~' H~S~'~.V'a'jW. · · ~, ~.) , · . .:.... - .' .mss ':x'~' ::sl~' ~,~.~:iT~.'~°C,o' · . a: 9161" '.. " . .. . .. . · .'",¢. '.. aEs"xw ~s~~ ~. :'" " 9173' '"'- , ... . ~S 2.7r m ~0US~'~LE'-" ,..: ,. ~tso' . ... <., ... ..... · . . '. . ....~w'. · .. ~ . · .. .. .j. · - ,. . ... :' .,.... ~s.~:~r ~r'"~~.~~?:...' ' .. .. '.' ; · · . s. ...~m~-~~.,~~ .- :.. ,. ..... 9{96' ' ' ' "'.'. · :" . .. '... . '. .... · , , , . · . , .. , , . ... :i~ ~ IlS' " , . . ~ . ~ .; · . . · . . . .. .. . . . ,. . . . , .: .. . .. . . .. ., ..... .. . : .~ . ~.. . ...., . . . · . ·.' .:...~ ".,. ' :.; .. ....,. . · . . ' } ~, · .. . :- .'.' .-. . · . .1. I107'-1 ii~c' ..: . · .. ... .. . . ~j. 5.. "~ '''' '. . . . .. . . .. · . .. .. : · ,.. , ',.-. ..: . ... . . . ... · . , . . . .. . : · .%.. . HE,S V'rL P. ark(~ th~ 9~ ~a; " - · '.. '. '. '." . TOt.@~S' ,. .. ".....' ·. · /~q~o'-: ~oq~o.t .... . ' ." · . .RE. CEi. v'E'D...'....-... . , . . . . · . ' ,. s,,t~o~Tg.~z~e,e, 'JUN 2"'1 !996 .'" .": .:.'.. '.. , . ' . . ' . ,., .. ". . .', . "' '"'" ': '"- ..Alaska Oil'& ¢'~s OonS, ccm~B~¢o~,.' " · .; '.-. ..a~t,~m~e .~ · .. . . '' .. . / .',. :. . .' . . .'. ~o FRI 08: 11 ~Pl UNOON~_~NOHORRGE :. ; · · ~ . . ., · · . . .,. , ·..: . :',June 20, 1996 . : ;.. .: .. · · .. . .. ... · . , · · .. · .. · Flq× NO, 907 26~7884 · . : . Baker Platform, Well Baker-3 .... 1' Pe '_ffoiati'n~ Proeedaare. · .. 1,-. · Ri'g.up.siiCkiine....."' ... · . , 2. uetrie :TRsv ' 8~ · .Hold safely m~'!in§. ' 1-', U:,3 Review uNOCAL Al:a~ka.- P~fforadng/Explosive~ Safet~ :Checklist..' '. Rig tip ~i..e~.tri¢;line unit, .' , ... · PresSUre mst.lubricator to 2500 psi for five.'minhtes: ."' " ..Not.e.:.' A.pump4n. ,ub .with:a. valve is'required;'. . . : .. · . . · . . . . Perforate intervals as in:structed by Unocal witness. ' .. Hemlock' . ,,, · · "HemlOCk. .'. · . · · .. ·.10,930-10,970 "i1,040' I 1',i00 · TOTAL: .. 100. · . .., · .. ... · .. .. ..' ... .... STATE OF ALASKA ALASKA uIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG t. Status of Well Classification of Service Well OIL: X GAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number ...... ~ ......... 95-199 Union Oil Company of California (UNOCAL)'_~-~-~-¥~"¥"~ ~?--.!.~"-~:~'~;--~ ~. Address 8. APl Numar P.O. Box1~247 Anchorage, AK 9~19 ~ ::~2~ 50-733-20~9 4. L~tion of well at sudace Baker Platform Lea ~4_~;~.~ ~::-- :;c.Sl°t#6.:~~.~_~ .~~;~'.q~"~[ )J' 9. Unit or Lease Name 198~ FNL, ~3' FWL, S~. 31, T9N, RI~, SM ......... ' .... ~ ~:~ ~¢~~ Chakachatna MGS At Top Pr~ucing Inte~al (10783' MD/1~88' ~D) ~;~-~ / ~~--~ -~ 'z 2:'"~: 10. Well Numar ,., ,.,, ,o.., ,.,, .,, T.., .,.., s. ORIGINAL Baker31 At Total Depth (11~'MD/10~'WD) } ~~ ~ ~.Fieldand~ool 235' FSL, 1~ ~L, S~. 30, T9N, R12W, SM ~ ..... - ........ } Middle Ground Shoals 5. Elevation in f~t (indi~te KB, DF, etc.) ~ 6. Lea~ Designation and Serial No. E, F & G Pool [18' R~ a~ve MSL~ ADL 17595 '17. Total Depth (MD+~D) 18. Plug Back Depth (MD+~D) I'"' Dir~tional Su~ey I=0-Depth where SSSV set 21. Thickness of Permafrost 11~6' MD/10806 ~D 11618' MD/1079Z TVD~ Yes: x No:~ 316 feet MD N/A 22. Ty~ Electric or Other L~s Run G~CNULDT/FMS/CBUDIUEWR 23. CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 18-5/8" 97¢ X-56 53' 801' 24" 2319 cf 0 1~3/8" 6~ K-55 53' 2076' 17-1/2" 2521 cf 0 9-5/8" 47¢ L-80 53' 6070' 12-1/4" 2688 cf 0 7' 2~ L~0 3910' 9520' 8-1/2" 1819 cf 0 5" 1 ~ L-80 9268' 11636' 6" 427 cf 0 24. Pedorations o~n to Production (MD+TVD of Top and Bo~om and 25. TUBING RECORD inte~al, size and numar) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9.~ L-80 9214' 9214' See a~ach~ list 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED None RE~riVe.u 27. PRODUCTION TESTJUN 0 6 i996 "~ate First Pr~uction I Method of Operation (Flowing, gas lift, etc.) 5/1~I Jet Pump At~ka 0tt & ~as C0n~, ~~~ Date of Test Hours Test~ PRODUCTION FOR OIL-EEL GAS-MCF WATER-EEL CHOKE sI~C~OIL RATIO /o 5/19/~ 24 TEST PERIOD => 36 0 27 Flow Tubing Casing Pressure CALCU~TED OIL-EEL GAS-MCF WATER-EEL OIL GRAVIS-APl (corr) Press. 2~HOUR RATE => 36 0 27 37.9 28. CORE DATA Bdef description of lithol~, ~ms~, fractures, apparent dips and presence of oil, gas or ~ter. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Tyonek "A" 5,835' 5,727' Tyonek "F"' 10,330' 9,690' Hemlock 10,783' 10,088' RECEIVED JUN 0 G t996 Alaska Oil & Gas Cons. Commission Anchorage 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,f~- ~". ~'~ Title ~A~ '.9~A, Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BAKER 31 PERFORATIONS OPEN TO PRODUCTION 5/29/96 ALL PERFORATIONS SHOT WITH 2-1/8" 0 PHASED 6 JSPF ENERJET STRIP GUNS. MEASURED DEPTH TRUE VERTICAL DEPTH 10783'-10915' 10088'-10202' 10997'-11030' 10272'-10300' 11107'-11140' 10366'-10393' 11200'-11233' 10444'-10472' 11312'-11345' 10538'-10565' 11415'-11448' 10624'-10651' 11470'-11503' 10669'-10696' 11533'-11543' 10721'-10729' RECEIVED BAKER PLATFORM WELL # 31 MIDDLE GROUND SHOALS COMPLETION DIAGRAM 5/29/96 o . . 3-1/2" 9.2# L-80 BTC 0' - 9214' 3-1/2" I-lES "FMX" TRSV ~ 316' I-lES "XN" 2.813" PB / 2.75" NOGO ~ 9161' HES "XD" DURASLEEVE ~ 9173' lIES 2.75" ID POLISHED NIPPLE 69180' HES "VTL" PACKER W/8' SBE ~ 9214' HES 2.75 .... X" NIPPLE ~ 9262' WIRELINE RE-ENTRY GUIDE ~ 9296' 32" Structural Casing @ 303' RKB (83'BML) 8-5/8" 97# X-56 QTE60 Surface Casing ~ 801' 13-3/8" 68# K-55 BTC Intem~ediate Casing ~ 2076' TOL @ 3910' 9-5/8" 47# L-80 BTC Intermediate Casing ~ 6070' RKB = 118' PERFORATION DEPTHS BASED ON CASED HOLE CNL DATED 4/29/96. PERFORATIONS 10783'-10915' 10997'-11030' 11107'-11140' 11200'-11233' 11312'-11345' 11415'-11448' 11470'-11503' 11533'-11543' PBTD ~ 11618' TD~11636' HES VTL Packer ~ 9214' TOL ~ 9268' 7" 29# L-80 BTC Liner ~ 9520' 5" 15# L-80 BTC Liner ~ 11636' RECEIVED JU~ O~ 1996- Alaska Oil & Gas Cons. Gomm~ssion Anchorage BAKER 31 DAY 1 (2/29/96) COMMENCED OPERATIONS ON BAKER 31 ON 2/29/96 AT 06:00 HRS. N/U RISER. PRESSURE TEST MUD LINES. FILL WELL CONDUCTOR WITH WATER TO CHECK FOR ANY OIL IN IT , NONE FOUND. RIH W/17.5" X 25" CENTER PUNCH ASSY. SHUT DOWN 4 HRS WORKING ON TOP DRIVE. DAY 2 -4 (3/1196 - 3/3/96) CENTER PUNCH CONDUCTOR F/303' - 352'. POOH. RIH W/MOTOR ASSBY. DRILL 17-1/2" HOLE F/352' - 814'. POOH. RIH W/HOLE OPENING ASSBY. OPEN HOLE FI 303' - 814' TO 24". POOH. R&C 18-5/8" CASING F/ 801' TO SURFACE, CIRC CMT. ND RISER, NU 20-3/4" BOP. DAY 5 (3/4/96) CONT. NU 20-3~4" BOP, AND TEST SAME. RIH W/MOTOR ASSBY. TEST 18-5/8" CASING, DRILL TO 824' & CONDUCT LOT. DRILL 17-1/2" HOLE F/ 824'- 976'. DAY 6 (3/5/96) DRILL 17-1/2" HOLE F/976'- 1272'. POOH F/BIT. DRILL 17-112' HOLE F/ 1272' - 1377' DAY 7 (3/6/96) DRILL 17-1/2" HOLE F1 1377'- 2090'. CCH. POOH F/CASING. DAY 8 (3/7/96) CONT POOH F/CASING. CHANGE RAMS & TEST BOP. RIH W/13-318" CASING. CEMENT 13-3/8" CASING @ 2073' W/2521 CF CLASS "G". CIP @ 1540HRS 3~7~96. ND 20-3/4" BOP. DAY 9 - 11 (3/8/96 - 3/10/96) NU & TEST WELLHEAD. NU 13-5/8" BOP. RIH W/ROTARY ASSBY, TST CSG, DRILL OUT CMT & FORM TO 2100'. CONDUCT LOT. DRILL 12-1/4' HOLE FI 2100' - 3947'. POOH FI BIT. DRILL 12-1/4" HOLE F/3947' - 4245'. RECEIVED JUN 0 G 199G AIm~J,~ 01t & ~mo (~n;, Commission Anohorage BAKER 31 PAGE 2 DAY 12 (3/11/96) DRILL 12-1/4" HOLE F/4245' - 5212'. DAY 13 (3/12/96) DRILL 12-1/4" HOLE F/5212' - 5955'. ClRC OUT GAS CUT MUD. INCREASE MUD WEIGHT TO 9.4 PPG. DAY 15 (3/14/96) RIH TO BOTTOM 6070' WITH 9 5/8" CASING SPACE OUT LAND HANGER. R/U DOWELL AND PERFORM CEMENT JOB. PUMP 20 BBLS CHEM. WASH FOLLOWED BY 50 BBLS SPACER. PUMP 1263 SXS. OF 12.9 PPG LEAD CEMENT FOLLOWED BY 171 SXS OF 15.8 PPG TAIL CEMENT. LOST 237 BBLS OF RETURNS DURING DISPLACEMENT. BUMPED PLUG WITH 2600 PSI. RECIPROCATED CASING THROUGH OUT JOB. TOP OF CEMENT CALCULATES TO BE AT 13 3~8" CASING SHOE. INSTALL PACKOFF BUSHING AND TEST BOPS, HAD TO REPLACE IBOP ON TOP DRIVE. DAY 15- 17 (3/15- 17/96) L/D 12 1/4" EQUIP. P/U 8 112" BHA RIH W/BHA. TEST 9 5/8" CASING TO 3600 PSI FOR 30 MIN. CLEAN OUT SHOE TO 6070' AND DRILL NEW HOLE TO 6080' . PERFORM FIT TO 19.7 PPG EMW, NO LEAK OFF. DIRECTIONALLY DRILL 8 1/2" HOLE FROM 6080' TO 7230'. DRILL LARGE COAL SECTION 7230' TO 7280' . STUCK DRILL PIPE AT 7293' WHILE SLIDE DRILLING, ATTEMPTED TO ROTATE, COULD FOR A SHORT TIME. HOLE PACKED OFF COULD NOT CIRCULATE OR ROTATE . ATTEMPT TO JAR FREE W/O SUCCESS.' PERFORM FREE POINT PIPE FREE AS DEEP AS FREE POINT COULD BE RUN , TOP OF MWD AT 7154'. RUN STRING SHOT, ATTEMPTED TO BACK OFF W/O SUCCESS. STARTED LOSING JAR ACTION. SHOT CIRCULATION HOLES AT 7210' TO 7206', COULD NOT CIRCULATE. SHOT PERF HOLES AT 7116' TO 7118' COULD NOT CIRCULATE. LOST JAR ACTION. RAN FREE POINT, FREE AT 6940' BAKER 31 PAGE 3 DAY 18 (3/18/96) RAN STRING SHOT, BACK OFF IN HW PIPE AT 6940' CIRCULATE HOLE CLEAN LOTS OF SAND IN RETURNS. HIGH BOTTOMS UP GAS. SPOT HI- VIS PILL POOH. DECISION WAS MADE TO SIDETRACK WELL DUE TO LOW PROBABILITY OF FISHING SUCCESS. RIH W/3 112" TUBING STINGER TO 6930' . LAY 62 BBLS OF 17 PPG CEMENT PLUG FROM 6230' TO 6233'. POOH L/D STINGER. DAY 20 (3/20/96) POOH W/CEMENT STINGER. RIH W/8 1/2" CLEAN OUT ASSY. CLEAN OUT WELL TO 6681' CBU POOH. RIH W/510' OF 3 112" CEMENT STINGER TO 6681'. LAY 62 BBL 17 PPG CEMENT PLUG. POOH. RIH WI DIRECTIONAL DRILLING ASSY. TO 6450' CBU FOUND CONTAMINATED AND GREEN CEMENT. POOH TO SHOE AT 6020' DAY 21 (3/21/96) MIX NEW MUD VOLUME. WHILE WOC. RIH TAG CEMENT AT 6477' DRILL FIRM CEMENT TO 6549' . KICKOFF WELL FOR SIDETRACK 1 AT 8:30 HRS. ON 3121196. DIRECTIONALLY DRILL 8 112" HOLE TO 6825' CHANGE HOLE TO NEW MUD DRILL TO 6920' DAY 22 - 24 (3/22/96 - 3/24/96) DRILL 8-1/2" HOLE F/6920' - 7246'. POOH F/BIT. FOUND ONE CONE MISSING. RIH W/RCJB. COULD NOT WORK PAST 6740'. POOH. RIH W/ RCJB WHILE CIRCULATING, COULD NOT WORK PAST 6585'. POOH. RIH MTB ON ROTARY ASSBY. DRILL 8-1/2" HOLE F/7246' - 7256'. POOH W/ MTB. MTB HAD SEVERE JUNK DAMAGE. RIH W/8-3/8" MILL ON MOTOR ASSBY. MILLED ON JUNK F/7256' - 7265'. POOH. RIH W/8-1/2" BIT ON MOTOR ASSBY. DRILLED 8-1/2" HOLE F/7265' - 7283'. DAY 25 (3/25/96) DRILLED 8-1/2" HOLE F/7283' - 7750'. POOH F/BIT. HAD BEARING FAILURE. RIH W/8-1/2" BIT ON MOTOR ASSBY. BAKER 31 PAGE 4 DAY 27 (3/27/96) CONT RIH W/BIT ON MOTOR ASSBY. DRILL 8-1/2" HOLE F/8033' - 8345'. DAY 28 (3/28/96) DRILL 8-1/2" HOLE F1 8345'- 8455'. POH F/BIT. RIH W/8-1/2" MOTOR ASSBY. DRILL 8-1/2" HOLE F/8455'- 8587'. DaY 29 - 31 (3/29/96 - 3/31/96) DRILL 8-1/2" HOLE F/8587'- 9006'. TRIP F/BIT. CONDUCT BOP TEST. RIH W/MOTOR ASSBY. DRILL 8-1/2" HOLE F/9006' - 9248'. POOH TO CHECK TOOLS DUE TO SLOW ROP. RIH W/MOTOR ASSBY. DAY 32 (4/1/96) DRILL 8-1/2" HOLE F1 9248' - 9839'. DAY 33 (4/2/96) POOH F1 BIT. RIH W/MOTOR ASSBY. SPOT REAM F1 9517' - 9839'. DRILL 8-1/2" HOLE FI 9839'- 10165'. DAY 34 (4/3/96) DRILL 8-1/2" HOLE F1 10165' - 10518'. CCH. POH F/BIT. RIH W/MOTOR ASSBY. DAY 35 - 38 (4/4/96 -4~7~96) CONT RIH W/MOTOR ASSBY. DRILL 8-1/2" HOLE F/10518' - 10979'. POH F/BIT. RIH W/MOTOR ASSBY. REPAIR TOP DRIVE. DRILL 8-112" HOLE F/ 10979'- 11569'. POH FI BIT. LD MWD. RIH W/MOTORASSBY. DRILL 8- 112" HOLE F/11569' - 11735'. DAY 39 (4/8/96) DRILL 8-1/2" HOLE F/11735' - 11755' TD. CCH. POH TO SHOE FOR SHORT TRIP. RIH. POH WORKING TIGHT HOLE. RU SCHLUMBERGER. RIH W/ TRIPLE COMBO TO 5552', TOOL FAILURE. POH & REPLACE DENSITY. RECEIVED Jr,IN n c 1996 Ala~h;a Oit & (;!~ d~ilr~. 6ommlss~on Anchorage BAKER 31 PAGE 5 DAY 40 (4/9/96) RIH W/TRIPLE COMBO. SET DOWN AT 7164' & COULD NOT WORK DEEPER. POH F/REAMING ASSEMBLY. RIH W/REAMING ASSBY. REAM HOLE F/7091' - 11661' SEVERE HOLE PROBLEMS @ 11651. POH F/ LOGS. DAY 41 (4/10/96) CONT POH FI LOGS. RU WlRELINE LOGGERS. RIH W/TRIPLE COMBO, SET DOWN AT 10249'. LOG FI 10249'- 6070'. RIH W/FMS. SET DOWN AT 8309'. LOG FI 8309'-6070'. RD WlRELINE. PU LWD BHA. RIH. DAY 42 (4/11/96) CONT RIH W/LWD. LOG DOWN f/9783' - 11585' W/ LWD GR/RES. PULL 200' REPEAT. POH. RU CASING CREW, CHANGE RAMS & TEST BOP. DAY 43 - 45 (4/12/96 - 4/14/96) RIH WI 7" LINER & SET DOWN AT 9520'. COULD NOT WORK LINER UP OR DOWN HOLE. CEMENTED LINER IN PLACE W/ 1542 SX @ 15.8 PPG. SET LINER HANGER AND LINER TOP PACKER. REV CIRC OFF LINER TOP W/ NO CEMENT RETURNS. POH W/DRILL PIPE & SETTING TOOL. RIH W/6" ROTARY CLEANOUT ASSBY. TEST CSG TO 3500 PSI. DRILL OUT FE & CLEAN OUT 8-1/2" HOLE TO 9755'. COULD NOT WORK DEEPER. POH. RIH WI TAPERED MILL & BENT JOINT OF DRILL PIPE. CLEANOUT TO 9765' & COULD NOT WORK DEEPER, NOT FINDING ORIGINAL HOLE. POH. RIH W/ 6" MOTOR ASSBY W/ 1.3 AKO. RIH & TAG @ 9760'. ATTEMPT TO ORIENT TO ORIGINAL HOLE DOWN TO 9806'. HOLE APPEARS TO HAVE SIDE TRACKED @ 9720'. DAY 46 (4/15/96) POH W/ 6" MOTOR ASSBY. RIH W/ 3-1/2" CEMENTING STRING TO 9806'. SPOT 87 BBLS CMT @ 9806'. POH TO 9275' & REV CIRC. REV OUT 40 BBLS CMT. CCH. POH. BAKER 31 PAGE 6 DAY 47 (4/16/96) CONT POH. REPAIR SWIVEL. PU BHA. RIH W/MOTOR ASSBY & TAG CMT @ 9239'. CLEANOUT CMT F/9239'- 9552' KOP. KICK OFF PLUG & DRILL 6" HOLE F/9555' - 9596'. POH. DAY 48 (4/17/96) CONT POH. RIH W/MOTOR ASSBY. DRILL 6" HOLE F/9596' - 9801'. POH F/BIT. DAY 49 (4/18/96) CONT POH. RIH W/MOTOR ASSBY. DRILL 6" HOLE F/9801' - 10021' POH FI BIT. DAY 50- 52 (4/19/96 -4/21 96) CONT POH F/BIT. RIH W/BIT ON MOTOR ASSBY. DRILL 6" HOLE F/10021' - 10330'. POH F/BIT. RIH W/MOTOR ASSBY. DRILL 6" HOLE F/10330' - 10575'. POH. RIH WI ROTARY ASSBY, PU LWD. DRILL 6" HOLE F/10575' - 10818'. DAY 53 (4/22/96) DRILL 6" HOLE F/10818' - 10843'. CBU. POOH. TITE @ 10608', 10545', 10420'. TEST BOPE. MU MOTOR ASSY. DRILL 6" HOLE F/10843' - 11070'. DAY 54 (4/23/96) DRILL 6" HOLE F/11070' - 11103'. POH F/BIT. RIH W/ROTARY ASSBY. LWD MAD PASS 9520' - 10600'. FINISH RIH, HUNG UP AT 10844' & WORKED FREE. DRILL 6" HOLE FI 11103'- 11250'. DAY 55 (4/24/96) DRILL 6" HOLE F/11250' - 11282'. POH F1 BIT. RIH W/ROTARY ASSBY. DRILL 6" HOLE FI 11282' - 11404'. POH FI BIT. HOLE NOT TAKING CORRECT FILL. RIH & CIRC BTMS UP. RECEIVED dtJN 0 g 1996 Alaska 0tl & Gas Cons. Commission Anchorage BAKER 31 PAGE 7 DAY 56 (4/25/96) CBU. CHECK FOR GAS. PULL TO 7" SHOE. DROP DART & POOH FOR WlRELINE LOGS AND BIT CHANGE. DAY 57-59 (4~26~96 -4/28~96) CONT. POOH FOR LOGS. RU SWS. RUN FMS. SET DWN @ 10590'. WORK THRU. LOG UP F/10582'. RIH W/ROTARY ASSBY. DRILL 6" HOLE FI 11537'- 11636'. CCH, POH F/LINER. RIH W/5" LINER ON DRILL PIPE TO 11636'. CMT 5" LINER W/362 SXS, SET HANGER AND REVERSE CIRCULATE. NO CMT TO SURFACE. POH. RIH W/CLEANOUT ASSBY. TAG TOC @ 11414'. PRESSURED LINER TO 2800 PSI AND PUMPED INTO LINER LAP. CLEANOUT CMT FI 11414' - 11618'. CIRC WELL CLEAN. DaY 60 (4/29/96) POH F/CASED HOLE WIRELINE LOGS. RUN BOND LOG FI 11608'- 6100'. RUN CNL F/11582' - 8900'. RIH WI POLISH MILL. POLISH TIE BACK EXTENSION FI 9287'- 9293'. POH. DAY 61 (4/30/96) CONT POH. RIH W/TIE BACK PACKER. SET PACKER IN LINER TOP AND TEST SAME TO 3500 PSI. POH. RUN & SET 7" RTTS @ 9193'. DRY TEST 5" LINER TOP W/200 PSI WATER CUSHION, OK. POH. RUN & SET 9-5/8" RTTS @ 3848'. DRY TEST 7" LINER TOP WI 400 PSI WATER CUSHION, OK. POH. DAY 62 (5/1/96) CONT POH. RIH W/CLEANOUT ASSBY TO 11544'. WASH DOWN TO 11618'. CHANGE WELL OVER TO 3% KCL. POH LD 2-7/8" DP. DAY 63 (5/2/96) FINISH POH LD 2-7~8" DP. RIH W/PACKER ASSBY ON 3-1/2" DP. SET PACKER @ 9215'. PRESSURE TEST ANNULUS TO 3500 PSI, LOST 120 PSI IN 10 MIN. SHEAR OFF PACKER & POH LD 3-1/2" DP. BAKER 31 PAGE 8 DAY 64 -66 (5/3/96 - 5/5/96) RIH W/SEAL ASSBY ON 3-1/2" TUBING. STAB SEALS INTO PACKER. CLOSE BAG ON TBG & CONTROL LINE. TEST ANNULUS, ON COMMUNICATION TO TBG, LOST 200 PSI/3 MIN THRU ANNULAR. SPACE OUT, LAND TUBING & HANGER. TEST PACKER SEALS TO 2600 PSI, OK. ND BOP, NU & TEST TREE. TEST ANNULUS & FOUND LEAK. ND TREE, NU & TEST BOP. POH W/3-1/2" TBG. RIH W/TIE BACK SEAL ASSBY & STING INTO TIE BACK EXTENSION. TEST 9-5~8" CASING TO 3500 PSI, OK. TEST DOWN TUBING TO 2900 PSI, LEAKED OFF 1135 PSI IN 5 MINUTES. POH. RIH W/7" RTTS. MADE VARIOUS SETS AND FOUND LEAK IN LINE HANGER. POH. RIH WI 7" RBP & SET @ 5995'. SPOT 50 SAND ON RBP. RIH WI 9-5/8" RTTS & STINGER. ESTABLISH INJECTION RATE OF .5 BPM @ 2400 PSI. SPOT CEMENT PLUG F/4020' - 3794'. PUH & CIRCULATE DRILL PIPE CLEAN. SQUEEZE LEAK W/4500 PSI, NO MEASURABLE PLACEMENT OF CEMENT INTO LEAK. HELD 4500 SPI F/1 HR. DAY 67 (5/6/96) RELEASE PRESSURE & POH. RIH W/8-1/2" CLEANOUT ASSBY. TAG TOC @ 3766'. CLEANOUT CMT TO TOL @ 3923'. POH. RIH W/6" CLEANOUT ASSBY. CLEANOUT CMT FI 3923'-4015'. RIH & TAG TOP OF SAND @ 5952'. PRESSURE TEST CASING TO 3500 PSI, OK. POH. RIH W/9-5/8" RTTS & MSV. SET PACKER @ 3860'. DRY TEST LINER WI NO WATER CUSHION, OK. TEST CASING TO 2500 PSI, OK. DAY 68 (5/7/96) POH. RIH WI RETRIEVING TOOL. TAG SAND @ 5952'. CLEANOUT SAND FI 5952'- 5995'. RETRIEVE BRIDGE PLUG & POH. RIH W/3-1/2" COMPLETION. TAG PACKER & TEST SEALS, OK. SPACE OUT & LAND HANGER. RIH W/SLICKLINE & TAG ETD @ 11554'. ND BOP, NU & TEST TREE & FLOWLINES. DAY 69 (5/8/96) FINISH NU & TEST TREE & FLOWLINES. OPEN "XD" SLIDING @ 9173'. DISPLACE WELL WITH POWER OIL. DISPLACE POWER OIL IN TUBING TO 3500' WITH N2. SHIFT SLEEVE @ 9173' CLOSED. BLEED OFF N2 PRESSURE. RU PERFORATERS. RIH & PERFORATE HEMLOCK W/2-1/8" ENERJET GUNS @ 6 JSPF @ 10882'-10849', 10849'-10816', 10816'-10783'. FLUID LEVEL @ 2970'. MAKE 2-1/8" GAUGE RUN TO 11543' ETD. BAKER 31 PAGE 9 DAY 70 (5/9/96) RIH TO SHOOT 11543'-11533', MISFIRE. PERFORATE HEMLOCK W/2-1/8" ENERJET GUNS @ 6 JSPF F/11543'-11533'; 11503'-11470'; 11448'-11415'; 11345'-11312'; 11233'-11200'; 11140'-11107'; 11030'-10997'. RAN SHIFTING TOOL ON SLICK LINE TO OPEN "XD' SLEEVE AT 9172'. DAY 71-73 (5/10-12/96) OPEN "XD" SLEEVE AT 9172' AND DISPLACE TUBING WITH POWER OIL. RAN JET PUMP AND NUMEROUS ATTEMPTS TO SET IN PROFILE AT 9172'. HAD PROBLEMS GETTING PUMP TO SEAT, AND WITH SLEEVE INADVERTENTLY CLOSING. MODIFIED PUMP. FINALLY GOT IT INSTALLED AND OPERATIONAL. STARTED PUMPING WELL RELEASE RIG AT 12:00 HRS ON 5/12/96 TO WELL NO. 23. UNOCAL BAKER Platform Ba-31St2 slot ~4-6 NiddLe Ground Shoals Cook Inlet, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : PMSS <9611-11467'> Our ref : svy5102 License : Date printed : 30-May-96 Date created : 18-Apr-96 Last revised : 26-Apr-96 Field is centred on n60 50 4.803,w151 29 11.941 Structure is centred on nO0 50 4.803,w151 29 11.941 Slot location is n60 49 45.236,w151 29 2.199 Slot Grid coordinates are N 2498019.136, E 235192.39? SLot local coordinates are 1987.00 S 48~.00 E Reference North is True North UNOCAL BAKER Platform, Ba-31St2 Niddte Ground Shoals,Cook Inlet, Alaska SURVEY LISTING Page 1 Your ref : PMSS <9611-11467'> Last revised : 26-Apr-96 Measured Inc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 0.00 0.00 0.00 0.00 0.00 N ' 0.00 E 0.00 0.00 100.00 0.50 130.00 100.00 0.28 S 0.33 E 0.50 0.07 150.00 0.50 241.00 150.00 0.53 S 0.31 E 1.65 -0.11 200.00 0.50 138.50 200.00 0.80 S 0.26 E 1.56 -0.32 250.00 0.75 155.50 249.99 1.26 S 0.54 E 0.62 -0.41 305.00 1.00 142.00 304.99 1.96 S 0.99 E 0.59 -0.54 366.00 0.50 160.50 365.98 2.63 S 1.40 E 0.90 -0.66 456.00 1.00 278.50 455.98 2.89 S 0.76 E 1.46 -1.31 544.00 1.50 343.50 543.96 1.67 S 0.33 W 1.60 -1.34 633.00 1.50 2.50 632.93 0.61 N 0.61 W 0.56 -0.06 722.00 1.50 350.50 721.90 2.92 N 0.75 W 0.35 1.35 821.00 1.50 357.00 820.86 5.50 N 1.03 ~ 0.17 2.82 910.00 3.00 31.00 909.80 8.66 N 0.11 E 2.19 5.74 993.00 3.50 18.50 992.66 12.92 N 2.03 E 1.04 9.99 1082.00 3.75 2.00 1081.49 18.40 N 3.00 E 1.20 14.30 1179.00 3.00 344.50 1178.32 24.02 N 2.43 E 1.30 17.55 1263.00 2.25 344.50 1262.23 27.73 N 1.40 E 0.89 19.20 1385.00 1.15 9.73 1384.18 31.24 N 0.97 E 1.07 21.17 1479.00 0.32 327.74 1478.17 32.40 N 0.98 E 1.00 21.94 1573.00 0.55 314.77 1572.17 32.94 N 0.52 E 0.26 21.94 1666.00 0.52 291.95 1665.16 33.41 N 0.18 ~ 0.23 21.72 1761.00 0.69 343.04 1760.16 34.12 N 0.75 ~ 0.57 21.75 1855.00 0.64 286.25 1854.16 34.80 N 1.42 W 0.67 21.69 1950.00 0.48 307.42 1949.15 35.19 N 2.24 ~ 0.27 21.32 2040.00 0.86 329.81 2039.14 36.01 N 2.88~ 0.50 21.37 2137.00 0.86 7.64 2136.13 37.36 N 3.15 W 0.57 22.05 2231.00 0.89 15.00 2230.12 38.76 N 2.87 ~ 0.12 23.19 2323.00 0.91 19.31 2322.11 40.14 N 2.44 W 0.08 24.41 2417.00 1.07 1.45 2416.10 41.72 N 2.17 ~ 0.37 25.65 2511.00 0.92 6.14 2510.08 43.35 N 2.07 ~ 0.18 26.79 2605.00 1.08 14.09 2604.07 44.96 N 1.78~ 0.22 28.07 2701.00 1.25 16.09 2700.05 46.84 N 1.26 ~ 0.18 29.69 2794.00 1.42 8.29 2793.02 48.96 N 0.82 W 0.27 31.41 2887.00 1.60 356.42 2885.99 51.40 N 0.73 ~ 0.39 33.07 2980.00 1.78 7.29 2978.95 54.12 N 0.63 ~ 0.39 34.93 3074.00 1.85 6.50 3072.90 57.08 N 0.27 ~ 0.08 37.13 3168.00 1.63 3.43 3166.86 59.92 N 0.02 W 0.25 39.18 3261.00 1.72 6.60 3259.82 62.63 N 0.22 E 0.14 41.13 3355.00 1.89 11.18 3353.78 65.55 N 0.68 E 0.24 43.40 3451.00 2.17 15.46 3449.72 68.86 N 1.47 E 0.33 46.16 3546.00 2.12 22.25 3544.65 72.22 N 2.62 E 0.27 49.22 3637.00 2.41 26.33 3635.58 75.49 N 4.10 E 0.36 52.48 3729.00 2.50 29.97 3727.49 78.96 N 5.96 E 0.20 56.16 382.4.00 2.46 30.98 3822.40 82.50 N 8.05 E 0.06 60.06 3917.00 2.67 34.04 3915.31 86.01 N 10.29 E 0.27 64.04 3996.00 1.71 57.54 3994.25 88.16 N 12.31 E 1.64 66.99 4089.00 0.72 106.36 4087.23 88.75 N 14.04 E 1.45 68.68 4182.00 1.00 310.88 4180.23 89.11 N 13.99 E 1.81 68.88 4275.00 3.82. 296.73 4273.14 91.04 N 10.61 E 3.08 67.58 4369.00 6.4:~ 294.0:~ 4366.76 94.58 N 3.01 E 2.78 64.15 All data is in feet unless otherwise stated Coordinates from slot f4-6 and TVD from RKB (Rig ~428) (118.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 49.14 degrees. DecLination is 0.00 degrees, Convergence is -1.30 degrees. CaLculation uses the minimum curvature method. Presented by Baker Hughes [NTEQ UNOCAL BAKER PLatform, Ba-31St2 Middle Ground Shoals,Cook Inlet, ALaska SURVEY LISTING Page 2 Your ref : PHSS <9611-11467'> Last revised : 26-Apr-96 Measured IncLin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 4462.00 8.38 294.84 4458.98 99.55 N 7.89 W 2.11 59.16 4556.00 9.68 302.33 4551.81 106.65 N 20.78 W 1.86 54.05 4649.00 11.12 301.22 4643.28 115.48 N 35.06 W 1.56 49.03 4742.00 12.98 299./+6 4734.23 125.27 N 51.82 W 2.04 42.75 48~?.00 15.30 296.61 4826.35 136.13 N 72.32 ~ 2.55 34.35 4932.00 17.19 298.28 4917.55 148.40 N 95.90 ~ 2.05 24.55 5025.00 18.92 299.99 5005.9? 162.45 N 121.06 W 1.94 14.71 5117.00 21.19 300.61 5092.3 178.37 N 148.29 W 2.48 4.53 5212.00 24.60 296.47 5179.89 195.93 N 180.78 W 3.97 -8.56 5306.00 26.85 294.07 5264.58 213.31 N 217.67 ~ 2.62 -25.09 5399.00 29.86 292.37 5346.42 230.68 N 258.25 W 3.37 -44.42 5492.00 29.58 292.81 5427.19 248.40 N 300.82 W 0.38 -65.03 5586.00 29.67 293.37 5508.90 266.62 N 343.56 ~ 0.31 -85.44 5684.00 29.36 293.54 5594.18 285.83 N 387.85 W 0.33 -106.36 5776.00 28.51 294.01 5674.70 303.78 N 428.59 W 0.96 -125.44 5870.00 27.04 296.45 5757.87 322.42 N 468.21 W 1.98 -143.21 5961.00 26.36 301.26 5839.17 342.12 N 504.01 W 2.49 -157.39 6075.00 26.00 301.92 5941.48 368.4? N 546.85 W 0.41 -172.56 6167.00 26.15 306.13 6024.12 391.08 N 580.34 ~ 2.02 -183.10 6262.00 26.59 312.~4 6109.25 417.75 N 612.97 g 2.94 -190.34 6356.00 23.78 320.86 6194.34 446.64 N 640.50 ~ 4.87 -192.26 6449.00 21.97 326.96 6280.03 475.77 N 661.82 ~ 3.20 -189.33 6542.00 23.91 331.64 6365.68 506.94 N 680.27 W 2.86 -182.89 6630.00 21.45 342.23 6446.90 537.98 N 693.66 ~ 5.41 -172.71 6725.00 20.74 349.06 6535.55 571.04 N 702.15 W 2.69 -157.51 6819.00 20.70 358.93 6623.50 604.00 N 705.62 W 3.71 -138.57 6912.00 21.67 8.04 6710.2~ 637.45 N 703.52 W 3.69 -115.11 7005.00 21.91 13.32 6796.60 671.34 N 697.12 ~ 2.12 -88.10 7099.00 21.03 18.8~ 6884.08 704.37 N 687.64 W 2.34 -59.31 7194.00 20.58 21.89 6972.89 736.00 N 675.91 ~ 1.24 -29.75 7287.00 21.22 22.94 7059.7/ 766.66 N 663.26 ~ 0.80 -0.12 7381.00 22.01 29.38 7147.17 797.68 N 647.98 W 2.66 31.72 7474.00 22.29 33.07 7233.32 827.65 N 629.81 ~ 1.52 65.07 7569.00 23.31 36.39 7320.89 857.88 N 608.8.~ W 1.73 100.72 7663.00 25.21 40.44 7406.60 888.10 N 584.80 ~ 2.68 138.66 7757.00 27.00 42.40 7491.00 919.09 N 557.43 W 2.11 179.64 7808.00 28.41 43.28 7536.16 936.47 N 541.30 ~ 2.88 203.20 7864.00 29.38 44.28 7585.18 956.01 N 522.58 ~ 1.94 230.14 7944.00 30.67 48.47 7654.46 983.59 N 493.60 ~ 3.08 270.11 8037.00 30.25 50.87 7734.62 1014.10 N 457.67 W 1.38 317.24 8130.00 30.61 51.39 7814.81 1043.66 N 421.00 W 0.48 364.32 8223.00 30.24 51.69 7895.00 1072.95 N 384.12 W 0.43 411.37 8318.00 29.85 51.29 7977.24 1102.57 N 346.90 W 0.46 458.90 8411.00 30.51 52.44 8057.63 1131.43 N 310.12 ~ 0.94 505.59 8506.00 31.08 52.11 8139.24 1161.19 N 271.65 ~ 0.62 554.16 8598.00 31.54 50.52 8217.84 1191.08 N 234.34 W 1.03 601.93 8689.00 31.98 49.39 8295.22 1221.90 N 197.68 ~ 0.81 649.82 878~.00 33.02 50.75 8~74.50 1254.31 N 158.95 W 1.34 700.32 8878.00 33.79 51.12 8453.80 1287.28 N 118.34 ~ 0.84 752.59 8970.00 33.97 53.53 8530.18 1318.61 N 7/.76 ~ 1.47 803.79 Alt data is in feet un[ess otherwise stated Coordinates from slot #4-6 and TVD from RKB (Rig ~428) (118.00 Ft above mean sea Level). Vertical section is from wellhead on azimuth 49.14 degrees. Declination is 0.00 degrees, Convergence is -1.30 degrees. Calculation uses the minim~mn curvature method. Presented by Baker Hughes INTEQ UNOCAL BAKER Ptatform,Ba-31St2 Hidd[e Ground Shoals,Cook Inter, Ataska SURVEY LISTING Page 3 Your ref : PMSS <9611-11467'> Last revised : 26-Apr-96 Measured Inc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 9063.00 33.84 54.21 8607.37 1349.20 N 35.86 W 0.43 855.49 9157.00 32.03 51.80 8686.26 1379.93 N 4.97 E 2.38 906.47 9250.00 31.34 51.35 8765.40 1410.28 N 43.24 E 0.78 955.27 9345.00 33.77 46.86 8845.48 1443.78 N 81.81 E 3.60 1006.36 9438.00 32.96 47.28 8923.15 1478.62 N 119.26 E 0.90 1057.47 9532.00 34.52 49.93 9001.32 1513.11 N 158.43 E 2.28 1109.66 9611.00 32.02 46.09 9067.37 1542.06 N 190.66 E 4.14 1152.97 9666.00 31.31 40.62 9114.20 1563.02 N 210.47 E 5.38 1181.67 9756.00 29.60 40.11 9191.78 1597.77 N 240.01 E 1.92 1226.75 9841.00 29.81 41.27 9265.61 1629.71 N 267.48 E 0.72 1268.42 9936.00 29.99 38.38 9347.97 1666.07 N 297.79 E 1.53 1315.13 10031.00 30.29 37.28 9430.12 1703.74 N 327.05 E 0.66 1361.90 10123.00 29.25 42.33 9509.99 17'58.83 N 356.24 E 2.95 1406.94 10217.00 29.00 43.88 9592.11 1772.23 N 387.50 E 0.84 1452.43 10285.00 29.70 48.70 9651.39 1795.23 N 411.59 E 3.62 1485.70 10345.00 30.60 53.00 9703.28 1814.24 N 434.95 E 3.90 1515.80 10439.00 28.43 50.94 9785.08 1842.74 N 471.44 E 2.55 1562.04 10530.00 27.61 45.05 9865.42 1871.29 N 503.19 E 3.17 1604.74 10563.00 27.81 45.15 9894.64 1882.12 N 514.06 E 0.62 1620.04 10655.00 28.134 46.65 9975.93 1912.10 N 545.00 E 0.80 1663.06 10747.00 28.92 49.94 10056.80 1941.27 N 577.75 E 1.95 1706.90 10E431.00 29.62 51.31 10103.90 1958.01 N 598.16 E 1.79 1733.30 10837.00 29.80 51.80 10135.17 1969.11 N 612.14 E 0.84 1751.12 10931.00 31.44 47.52 10216.07 2000.11 N 648.58 E 2.90 1798.97 11024.00 31.54 49.20 10295.38 2032.39 N 684.88 E 0.95 1847.54 11094.00 32.18 51.49 10354.83 2055.96 N 713.33 E 1.95 1884.47 11187.00 32.92 52.98 10433.22 2086.59 N 752.88 E 1.17 1934.44 11223.00 33.00 53.84 10463.43 2098.27 N 768.61 E 1.32 1953.97 11316.00 33.18 56.15 10541.35 2127.39 N 810.19 E 1.37 2004.47 11410.00 33.81 57.62 10619.74 2155.72 N 853.64 E 1.09 2055.86 11467.00 34.38 58.97 10666.94 2172.51N 880.83 E 1.66 2087.41 11537.00 35.08 60.63 10724.48 2192.57 N 915.29 E 1.68 2126.60 Projected Data / Released Att data is in feet unless otherwise stated Coordinates from slot ~4-6 and TVO from RKB (Rig #428) (118.00 Ft above mean sea level). Vertical section is from we[thead on azimuth 49.14 degrees. Declination is 0.00 degrees, Convergence is -1.30 degrees. Calculation uses the minim~ curvature method. Presented by Baker Hughes INTEQ UNOCAL SURVEY LISTING Page 4 BAKER Platform, Ba-31St2 Your ref : PMSS <9611-11467'> Middle Ground Shoals,Cook Inlet, Alaska Last revised : 26-Apr-96 Comments in wellpath ND TVD Rectangular Coords. Conlnent 11537.00 10724.48 2192.57 N 915.29 E Projected Data / Released Casing positions in string 'A' Top MD Top TVO Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 801.00 800.87 4.97N 1.00W 18 5/8" Casing 0.00 0.00 O.OON O.OOE 2076.00 2075.14 36.49N 3.0914 13 3/8" Casing 0.00 0.00 O.OON O.OOE 6055.00 5923.51 363.83N 539.40W 9 5/8" Casing Targets associated with this wel[path Target name Position T.V.D. Local rectangular coords. Date revised Ba31 Tgt2 Hemlk 17-N 235860.000,249~50.000,0.00009918.00 1945.53N 623.?0E 17-Nov-95 Ba31Tgtl A Snd Rvsd 234710.000,2499000.000,0.00007618.00 969.70N 504.51~ 1?-Nov-95 RECEIVED JUN 0 ]99G Alaska Oil & Gas Cons (.;Oltitili~$1Ol, Anchorage AIl data is in feet un[ess otherwise stated Coordinates from slot #4-6 and TVD from RKB (Rig //428) (118.00 Ft above mean sea Level). Bottom hole distance is 2375.94 on azimuth 22.66 degrees from wellhead. Vertical section is from wellhead on azimuth 49.14 degrees. Declination is 0.00 degrees, Convergence is -1.30 degrees. Calculation uses the minin~zn curvature method. Presented by Baker Hughes INTEQ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Jo~n,'~ Chairmar~r~ - DATE: March 8, 1996 THRU: Blair Wondzell ~J~.' P. I. Superv~' FROM: Bobby Foster,~ / SUBJECT: Petroleum Inspector FILE NO: AUBICHDD.doc BOPE Test - Baker Pit. UNOCAL- TBU - B-31 PTD # 95-0199 McArthur River Field Friday, March 8, 1996:. i traveled this date to UNOCAL's Baker Platform and witnessed the BOPE test on Pool rig 428 drilling well #31. As the attached AOGCC BOPE Test Report shows the test went very good with no failures of any equipment tested. While standing by for the test to begin ! spoke with Don Byme, UNOCAL drilling rep. concerning the cement job on the 13.325~ casing. Don said the job went good except they lost circulation 100 bbis. before the job was done. Don said that he calculated the cement and the 100 bbis. was just above the shoe of the 18.625~ conductor pipe. During the test of the BOPE, Don had Dowell test the 18.625" surface casing to 500 psig and the pressure held for 30 minutes. The rig was in good condition and ali equipment seemed to be in very good working order. I made a walk thru of the platform which was clean and orderly. I spoke with Allen Dorman, the production foreman, concerning the gas wells on the platform. Allen told me that the 3 gas wells did not produce anymore. Well #28 which was brought as a gas and oil producer had quit flowing and was now being lifted by pump. Summary: ! witnessed the BOPE test on UNOCAL's well Baker # 31 being drilled by Pool rig 428 - test time 2.5 hours - No failures. Attach: AUBICHDD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drig: X Workover: Drlg Contractor: POOL ARCTIC Operator: UNOCAL Well Name: BAKER #31 Casing Size: 13.375" Set @ Test: Initial X Weekly DATE: 3/8/'96 Rig No. 428 Ptd # 95-0199 Rig Ph.# 776-6648 Rep.: DON B YRNE Rig Rep.: DOUG NIENHAUS 2076' Location: Sec. 31 T. gN R. 12W Meridian SEWARD Other Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location ~/E~ Standing Order Posted YES Well Sign OK Dri. Rig OK Hazard Sec. YES FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F 500/5,000 P 500/5,000 1 500/5,000 P 500/5,000 P BOP STACK: Annular Preventer 1 Pipe Rams Lower Pipe Rams Blind Rams 1 Choke Ln. Valves HCR Valves 2 Kill Line Valves Check Valve N lA Quan. Test Press. P/F 300/3,000 500/5,000 500/5, OO0 500/5, OO0 CHOKE MANIFOLD: No. Valves 15 No. Flanges Manual Chokes Hydraulic Chokes 2 500/5,000 Test Pressure P/F 500/5,000 P 38 500/5,000 P Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure 3,100 I P Pressure After Closure 1,650 I P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure 0 minutes 31 Trip Tank YES YES System Pressure Attained 4 minutes 4 Pit Level Indicators YES YES Blind Switch Covers: Master: YES Remote: Flow Indicator YES YES Nitgn. Btl's: 12 ~, 2000 Avg. Meth Gas Detector YES YES Psig. H2S Gas Detector YES YES sec. sec. YES Number of Failures: 0 ,Test Time: 2.5 Hours. Number of valves tested 21 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. !. Supervisor at 279-1433 I I . Il ] [ . I [ I I II I I I I . I I I I I I I REMARKS: GOOD TEST Distribution: orig-Well File c - Oper./Rig c- Database c - Tdp Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: BOBBY D. FOSTER FI.-021L (Rev. 12/94) AUBICADD.XLS TONY KNOWLE$, GOVERNOR ~ ~, & OIL AND GAS CONSERVATION CO~IMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 19, 1995 G. Russell Schmidt, Drilling Manager Union Oil Company of California P O Box 196247 Anchorage, AK 99519 Re: Company Permit # Surf Loc Btmhole Loc Middle Ground Shoal Baker 31 Union Oil Company of California 95-199 1987'FNL, 483'FWL, Sec 31, T09N, R12W, SM 315'FSL, 1518'FWL, Sec 30, T09N, R12W, SM Dear Mr. Schmidt: Enclosed is the approved application for permit to ddll the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting ddlling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. David W Johnston ~ Chairman ~ BY ORDER OF THE COMMISSION Ijb/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Re-Entry D Deepen B Service E) Development Gas E) Single Zone E) Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company of California (Unocal) 118' RKB above MSL feet Middle Ground Shoals 3. Address 6. Property Designation E, F, & G Pool P.O. Box 196247, Anchorage, AK 99519 ADL 17595 4. Location of well at surface Baker Pit Leg #4, Slot #6 7. Unit or property name 11 .Type Bond (SEE 20 ACC 26.026) 1987' FNL, 483' FWL, Sec. 31, TgN, R12W, SM Chakachatna MGS AK Statewide Oil & Gas Bond At top of productive interval '(7922' MD/7618' TVD) 8. Well number Number 1017' FNL, 22' FEL, Sec. 36 TgN, R13W, SM Baker 31 U62 - 9269 At total depth {11663' MD/10757' TVD) 9. Approximate spud date Amount 315' FSL, 1518' FWL, Sec. 30, TgN, R12W, SM 1/1/96 8200,000 1 2. Distance to nearest J 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3762 feet 37' @ 2500' MD feet 5106 11,063' MD/10757' TVD feet 1'8. To be completed for deviated wells 17. Anticipated Pressure (see 20 AAC 25.035 {e}{2)) Kickoff depth 4100 feet Maximum hole angle 33 deg Max surface 887 psig At total depth (TVD) 4841' psig 18. Casing program Setting Depth size Specifications Top - Bottom Quantity of cement .. Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24' 18-5/8" 97 X-56 QTE 60 744 56 56 800 800 2600 cf 17-1/2" 13-3/8" 68 K-55 BTC 1944 56 56 2000 2000 2500 cf 12-1/4" 9-5/8" 47 L-80 BTC 0104 50 56 6160 6000 2500 cf 8-1/2" 7" 29 L-80 BTC 5663 6000 5860 11663 10757 2100 cf '1'9. To be completed for Redrill, Re-entry, and Deepen Operations Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural 247 32" Driven 303' RKB (83' BML) Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat E) BOP Sketch r~ Diverter Sketch B Drilling program Drilling fluid program B Time vs depth plot r'~ Refraction analysis O Seabed report O 20 AAC 25.050 requirements 21. I hereby certify that the foregoing i,~,tWe/~nd corr~ to~hg~es~t o~ knowledge Signed Commission Use Only Per~t~um~ I API number I Appreciate/~ ~ , for other requirements Condi~onsofa~p I Sampl~required ~ Y~ ~ No Mud Icg required ' ~ Yes ~ No .ydro~en sulfide measures ~ Yes D No Direcfionalsu~eyrequired ~ Yes D No R°quir°dw°~kin0pressure0ri~) Signe0 By~ 2M; ~ 0M; ~SM; ~ 1OM; 15M David W. Johnston ~ t,~ by tho order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit ii~ triplicate OEC 1 1 1995 Al~ka 0il & Gas Cons. Commission Anchorage Baker Well #31 November 14, 1995 Drilline Hazards: Lost circulation zones: Low pressure zones: Over pressured zones: Shallow gas zones: 4750' - 5800' (150 - 300 bbl/day) Baker 30 0' - 6718' TVD None 0' - 6718' Time Est. .5 1 1 1 2.5 1 6 2 13 1 1 1 1 1 1 .5 1 .5 Cum Time .5 1.5 2.5 3.5 6 7 13 15 28 29 3O 31 32 33 34 34.5 35.5 36 Preliminary Procedure: 1. MIRU, Leg g4, Conductor 2. Drill 1%1/2" hole to 18-5/8' casing point of +/- 800'. 3. Open hole from 17-1/2' to 24'. 4. Run and cement 18-5/8' casing. Install 20" BOP. 5. Drill 17-1/2' hole to 13-3/8" casing point of+/- 2000'. 6. Run and cement 13-3/8' casing. Install 13-5/8' BOP. 7. Drill 12-1/4' hole to 9-5/8" casing point at +/- 6178'. 8. Open hole log. Run and cement 9-5/8' 9. Drill 8-1/2' hole to 7" casing point at +/- 11640'. 10. Run open hole logs. 11. Run and cement 7" liner f/11640' - 6000'. 12. Clean out 7" liner. 13. Draw down 7" liner top. 14. Change well over to complefon fluid. 15. Run and hang TCP guns. 16. Land 3-1/2" tubing. 17. Nipple down BOP. ~ and test tree. 18. Pressure well and perforate. Depth Baker31 Depth vs. Days 0 5 10 15 20 25 30 35 40 45 50 55 60 Baker #31 AFE Days BAKER PLATFORM WELL # 31 MIDDLE GROUND SHOALS PROPOSED COMPLETION COMPLETION DESCRIPTION 1) Single 3-1/2' 9.2# L-80 SCBT 2) SCSSSV @ +/- 300' 3) Sliding Sleeve 4) Permanem Production Packer 5) Through Tubing Perforations as Required RKB-- 118' 32" suucmtm cum~ @ 3o3' ~ (~'nM~) X 18-5/8' 97# X-56 QTE60 Surface Cub~ ~ soo' ~. 13-3/g' 68# K-55 BTC Imermedi~e Caa~g ~ 2000' 47# L-g0 BTC Intermediate Casing (~ 6160' 7"2~L-~BTCLin~II663' I I V soo 1000 i500 2000 25OO 3000 3500 4000 4500 _ 5000 _ 5500 _ 6500 7000 _ 75oo 8000 8500 _ 9000 95OO Tie on Begin Nudge :.oo 2.00End Angle ~u;id 2.00 Begin Angm Drop 1.00 End Nudge 1oo00 10500 ~ 11000t ~Tojected ID [ 500 0 500 ~ 000 1500 2000 UNOCAL Structure : BAKER Plaffon'n Well : Ba-$1 Field : Middle Ground Shoals Location : Cook Inlet, Alast<a~ WELL PROFILE DATA Point MD nc git lYD North Ne on 0 0.00 ~0.00 0 0 End of Hold 800 0.O0 BO.O0 800 0 End of Build !050 2.50 ~_~).00 1050 1 End of Hold 1350 2.50 gO.O0 1350 .3 End of Drop 1600 0.OO SO.00 1600 4 KOP 4100 0.OO 301,95 41OO 4 :End of Build 5246 28.64 301.95 5198 152 5971 28.64 301.95 5835 337 End of Hold ;Target 7922 32.96 49.14 7618 970 ;Target 10663 32.97 49.14 9918 1946 End of HOI~ 11§63 32.97 49,14 10757 2301 £ost Oeg/1 O, 0.0Ol 0 o.~ol 5 1 .ool ~8 0.0al 24 I .OOI 24 0.001 -214 2.5oi 0.0O -504-5102,50 0.00 624 1035 i 2.50 7.50 il 2.50 17, 50 22.50 '~ 27.50 EO~ \ \\ , !9.39 '% 20.31 ~ 22.30 ~ zo.~o 28.48 i32.24 ~;, ~'1 / A Sand / ~nal EOC L B~I Tgt~. Hemlk 17--Nov--95 '. :,oo.oo Eas± --> 800 600 400 200 O 200 400 600 800 1 OOO Tgt ~1 / A Sand / Final EOC ~8egin Final Build & Turn to Targets 1200 _2400 _2.200 i_2000 f1800 1600 1400 ]_ ~ 200 ~_I000 ~ 800 _600 _ _ _ 200 _ _ 0 _ icra~ted by : jone~ Fo~ PAT RYAN ioote plotted : 50-Nov-95 ?lot Reference ii 8031 VerNon ~8. Coo~dir~:l'teI are in feet mfer~ elD{. ~14-6. jTrue Ver6c~ Depf. J'~ ore reference RKB (l~g ~428).1 A I I Z E!TL-UP ,. FLOW ANNULAR BOP 20~2000 om ~IVERTER--~ SPOOL ~;' 3000 PIPE RAMS 20%" 3000 pst 3"-!0M BLIND RAMS CWrO'~ VA~W~ 20,%"3000 psi '~"~" '-""" HCR ' · ~ , ,.; HCR ..... i / ~ ,,,_~o~1/~ ~ GATE VALVES PIPE 20~4" 3000 psi I, t I ~oa/~'' 13000 GATE VALVES LINE~ CHAKACHATNA RIG 428; BOP/DIVERTER" S TACK 21 +,t' 2000psi/20%," 3000psi FLOW ANNULAR BOP 3%"5000 psi PIPE RAMS ~ 3%"5000 pst ..~ ' 0M BLIND RAMS ~13 i 35/8"5000 DS1 ,..,,ECK VALVE KILL ~'- . ~.IANUAL . DRI~NGI MANUAL ~, -~~~~3%5ooo ps,~~~ CHOKE LINE--~ LINE 3"-:OM// GATE VALVES [ PIPE RAMS 13r'/s"5000 pst ~~ 4"-t0M GATE VALVES RISER ~3%" i CHAKACHA-TNA RIG 4-2 . BOPET_ S~~~ 13 %" 5000~-~Ji~ Alaska 0il & Gas Cons. Commi~ion Anchorage VENT OUTSIDE OF ~VlNDWALLS FLANGE PANIC LINE 4' 5,000 PSi BALL VALVE X ~ 1/16-51~ HUB 5M T~Er ~ BLIND HUB BLIND WILU$ AOJ. I/FI, IT UP DERRICK fl" RELIEF VALVE SET AT ~0 PSI -- ID" 150 lb. BLIND FLANGE (TIP.) 10' 150 lb. FLANGE CLAMP HUB CONNECTION BUFFER TANK SEPER~TOR SIPHON UNE 150 lb. FLANGE 11 I TO SHAKER 4 ~/1~" -SM FLG. 1 O, 000 PSi FifO. CHOKE TO PRODUCTION SEP~TOR 8" MUO RETURN UNE UNOCAl. CHOKE t4ANIFOLfl OWC,. Cl~-I:12592 PLAN VIEW ON SOUTHWEST LEG :--- : -"---- "------"'t .... --',,~" vIE}~ SftOWN ON NOIdTIIEAS'T 1,1~';(; DIVERIER LINE LAYOUT SOUTNWEST &: EAST LEG POSITIONS POOL RIP, 428 PLAFFOI~ ~iAK[~ PLATFORMS HIGH PRESSURE RISERS lAYOUT DIVERTER STACK AND BOP STACK UOC PLA1TORMS BAKER. DII.LION, 4c ANNA PM ~.8 ,., I : LIC)UIJ)$ ~, ' ! /~_:~.~:~.~,.¢,.¢~.~~::::.:,'.:~_~:~u.:~.~':!:::,:':u'~.~":I. , ,.,,, ...... ...... ' -'~ t I ~ : I : : ', ' ~ ' 't .......... ''' i ' ' ,. - .............. , II ,,,,, IlL 2..~ ,S~:T:::.,~,~ .......... I ~,. -, ,. , ~ ~ ...... I ~ ~ ................ ~ l ........ ~'' ' t ~ J~ ~ I I I '. ~ ~ ~t.e I '.-.Pl.-.~ "~ ...... ~ 4 ~' ~ j ~ ~ 0,,'u~ .~ ,,uu~,~ - I I 'o' ' ....... F .... . : , ~ L ._.~ ~,,~ : .~ ~ ~ :, ~ FI.IL ',· L-'44 ~' ""~ . i . ._. J i ~ ~,_.,.~.~l~ - ......... ~ ...................... ,:;,;,,'~o,,,~, II : ~. '~' ~ ~ ',~" "-H H ......... -I : ~ ~ ~ '" ' ' ' I i ~ , ~ r: ~ ..... ~-~,,'-- . ~. ,~ ~ i~:~, ~ I i I III J '~"__. II '~.u._ ~ I ~l~, l ll,I ~ I i : I II J i ~ ~ ~ J J --' "' ~ : ~ I~llJ~._. ~:~_tl~ :~ ~h I-.tq.~i ~ ..... I~'~ .... ~-~ i : ~ ~ ~~ o,,~,,.,., ..... .,, ~wz~~ I i ' · i : ' -' ' ' - ~ j'' REVISED ~ ~a~f~yy~m~ I ~ ~ ~-~ ~~;~l "~ .............. ~ .... ~ '- - - - ~ ~~~ I .'~ , ~/__J -~ ~.~ ~ I I ~' ' ~ l~ ~ ~'' / i '-C ~.~._ __%':. 1.1 .............................. ~ .... h.. ' ............. ~ - -': .... 7--II .... ~ .... t~,~,L , .... ,...,,.. ,s~u~ ........ ~ll~l~ I ~ ....... ~-- - :~ ........ I' t ............................ I [~ LO~ PI~[SSU~E ~U~ ~IE~ I E ~ 428 I BAKER PLATFORM WELL # 31 MIDDLE GROUND SHOALS ROTARY KELLY BUSHING (RKB) Elev. 11~' DRII,I_. DECK LEVEL Elev. 78' PRODUCTION DECK LEVEL Elev. 62' L x SEA LEVEL (MLW) Elev. 0' MUD LINE Elev. -102' 32' Structural Casing (~ 303' RKB (83'BML) 18-5/8" 97# X-56 QTE60 Surface Casing ~ 800' 13-3/8' 68# K-55 BTC lnt~'mediate Casing (~ 2000' 9-5/8" 47# L-80 BTC ~ Casing (~ 6160' CASING DESIGN WELL: BAKER #31 FIELD: MIDDLE GROUND SHOALS DATE: 28-Nov-95 1. MUD WT. I 8.8 PPG 2. MUD WT. II 9.4 PPG 3. MUD WT. III 9.4 PPG DESIGN BY: P.A. RYAN M.S.P. 385 psi 819 psi 968 psi INTERVAL DESCRIPTION CASING SIZE BOTI'OM TOP LENGTH WT, GRADE THREAD I 18-5/8" 800 58 744 97 X-52 QTE-80 TVD 800 58 2 13-3/8" 2000 58 1944 68 K-55 BTC TVD 2000 58 3 9-5/8" 6180 58 6104 47 L-80 BTC TVD 8000 58 4 7" 11663 6(X)0 5863 29 L-80 BTC TVD 10757 5860 TENSION MINIMUM WEIGHT TOP OF STRENGTH W/O BF SECTION TENSION LBS LBS lQ00 LBS 72188 72168 1594 132192 132192 1069 288888 286888 1086 164227 164227 676 COLLAPSE COLLAPSE PRESS Q RESIST. BOTI'OM TENSION 8.09 572 1950 3,79 1716 4750 4.12 3O77 7020 NOTES: See attached for oaloulation of MS,P, Including ..sumptlon. & estimates. * Collapse pre~ure is calculated; Difference between two cement slurdes (i.e. Avg of a 15.8 ppg (tail) & 12 ppg (lead) = 14 ppg, subtract a mud of 9.5 ppg = 5.5 ppg = .286 psi/It gradient X TVD of the csg string). " Burnt pre~sure is calculated; (BHP (~ depth next cag X TVD next csg) X (0.5 haft evacuated). BURST MINIMUM PRESSURE YIELD CDF PS~" PS~ D.D_F 4.20 450 1372 3.05 3.41 1350 3450 2.58 2.77 2420 6870 2,84 2.28 2420 8160 3.37 Bakar Platform Well # 31 Pressure Calculations Baker Platform Well # 31 Middle Ground Shoals November 28, 1995 Hole Section 1 0'-800' 17-1/2" hole size Open to 24' 18-5/8" casing to 800' MM weight: Shoe depth 08-5/8"): Est. fracture gradient of 18-5/8" shoe: Depth of next hole section (17-1/2"): BHP gradient: Gas gradient (assume worst case): 8.8 ppg=0.46 psi/it 800' MD/800' TVD 0.80 psi/it 2000' MD/2000' TVD 0.45 psi/it o.o psi/it Gas kick situation in wellbore. Assume 3/4 mud & 1/4 gas. MSP=-B~ - Hydrostatic Pressure MSP=-BHP - (3/4 mud + 1/4 gas) MSP--(2000'x.45 psi/it) - ((.75(2000'x0.46 psi/fi)) + (.25(2000'x0.0 psi/fi))) MSP=- 210 psi TMnffore, the hydrostatic pressure at the 18-5/8" shoe (Hpsh) is the greatest when the gas (kick) bubble reach~ the 18-5/8" shoe, ifa constant BHP is applied. A conservative estimate would be the MSP plus the hydrostatic pressure at the 18-5/8" casing depth (Hpcsg). Hpsh= MSP + Hl:~sg I-Ipsh= 210 + (800'x0.46 psi/it) HPsh= 578 psi This (Hpsh = 578 psi) is less than the fxacu~ pressure at the same shoe (Fpsh) and thus adequate to haMie the well kick scenario. Ht~ = 578 psi < Fpsh = 0.80 psi/fi x 800' = 640 psi. Baker Platform Well # 31 Pressure Calculations Hole Section 2 Depth Interval: 800' -2000' 17-1/2" hole size 13-3/8" casing to 2000' Mud weight: Shoe depth (13-3/8'): Est. fxactum gradient of 13-3/8" shoe: Depth of next hole section (12-1/4"): BHP gradient: Gas ~ (ammae worst case): 9.4 ppg=0.49 psi/fl 2000' MD/2000' TVD O.8O psi/fi 6160' MD/6000' TVD 0.45 psi/R o.o ps~'ft Gas kick situation in wcllbore. Assume 3/4 mud & 1/4 gas. MSP=BHP - Hydrostatic Pressure MSP=BI-IP - (3/4 mud + 1/4 gas) MSP--(60(X)'x.45 psiS) - ((.75(6000'x0.49 psi/R)) + (.25(6000'x0.0 psifft))) MS1:~- 495 psi Therefore, the hydrostatic presmm: at the 13-3/8' shoe 0tpsh) is the greatest when the gas (kick) bubble reaches thc 13-3P8" shoe, if a constant BlIP is apphed. A conservative estimate would be the MSP plus the hydrostatic pressure at the 13-3/8" casing depth (Hpcsg). Hpsh= MSP + Hpcsg Hpsh= 495 + (2000'x0.49 psi/R) HPsh= 1475 psi This (Hpsh = 1475 psi) is less than the fracture pressure at the same shoe (Fpsh) and thus adequate to handle the well kick scenario. Hpsh = 1475 psi < Fpsh = 0.80 psi/fi x 2000' = 1600 psi. Baker Platform Well # 31 Pressure Calculations Hole Section 3 Depth Interval: 2000'-6160' 8-1/2' hole size 9-5/8' casing to 6160' Mud weight: Shoe depth (9-5/8"): Est. fracture gradient of 9-5/8' shoe: Depth of next hole secaon (8-1/2"): BHP gradient: Gas gradient (assume worst case): 9.4 ppg=0.49 psi/fl 6160' MD/60(g)' TVD 0.80 psi/fi 11663' MD/10757' TVD 0.45 psi/fi 0.0 psi/ft Gas kick situation in wellbore. Assume 3/4 mud & 1/4 gas. MSP=-BHP - Hydrostatic Pressure MSP=-BHP - (3/4 mud + 1/4 gas) MSP--(lO757'x.45 psiffi) - ((.75(10757'x0.49 psi/ffi) + (.25(10757'x0.0 psi/ffi)) MSP=- 887 psi Therefore, the hydrostatic pressure at the 9-5/8" shoe (Hpsh) is the greatest when the gas (kick) bubble reaches the 9-5/8" shoe, ff a constam BHP is applied. A conservative estimate would be the MSP plus the hydrostatic pressure at the 9-5/8" casing depth (Hpcsg). Hpsh= MSP + Htx:sg I-Ipsh= 887 + (6000'x0.49 psi/fO I-IPsh= 3827 psi This (Hpsh = 3827 psi) is less than the fracture pressure at the same shoe (Fpsh) and thus adequate to handle the well kick scenario. Hpsh = 3827 psi < Fpsh = 0.80 psi/ft x 6000' = 4800 psi. File name: bkr3 lcal.d~x; Well # Date Baker Platform Ba 28 10-10-93 Ba 30 10-24-93 Ba 30 10-28-93 Ba 28 11-17-93 Ba 29 12-1%94 Ba 29 12-29-93 Ba 30 01-27-94 Ba 28 03-01-94 Grayling Platform G-40 01-24-90 G-40 Monopod Platform A-lrd 04,4M-91 A-8rd 07-01-89 A-20rd 03-30-90 A-20rd 04-13-90 A-28rd 11-20-89 A-28rd 11-27-89 Granite Point Platform 11-13rd 02-14-92 51 08-07-92 51 07-28-92 51 08-25-92 50 05-2%92 50 06-04-92 50 06-27-92 Dillon Platform Leak Off' Test (LOT) Data Cook Inlet, Alaska Revised June 3, 1995 Unocal Energy Resources Alaska Csg Size Shoe Depth Fmc Grad. (TVD) (psi/ft.) EMW 24" 802' 0.94 18.10 24" 803' 0.83 15.90 18-5/8" 2011' 0.94 18.10 18-5/8" 2135' 0.75 14.50 18-5/8" 2054' 0.76 14.61 13-3/8" 5869' 0.85 16.33 13-3/8" 5467 0.93 17.96 13-3/8" 3509' 0.75 14.40 16" 1926' 0.96 18.46 13-3/8" 4977' 0.86 16.54 9-5/8" 1132' 1.07 20.57 9-5/8" 3760' 1.02 19.61 13-3/8" 755' 0.95 18.20 9-5/8" 1931' 0.85 16.30 20" 240' 0.75 14.42 13-3/8" 1140' 0.97 18.65 9-5/8" 9966' 0.96 18.40 13-3/8" 3803' 1.00 19.20 18-5/8" 1010' 0.87 16.80 9-5/8" 9592' 1.05 20.20 18-5/8" 982' 0.91 17.50 13-3/8" 4208' 0.84 16.20 9-5/8" 9877' 0.93 17.90 1.12 0.82 NA 1.01 0.83 NA 1.02 0.80 16 04-22-94 18-5/8" 1131' 16 06-16-94 13-3/8" 3640' 16 07-04-94 9-5/8" 9469' 17 04-27-94 18-5/8" 1142' 17 05-01-94 13-3/8" 3560' 17 05- 9-5/8" 9213' 18 07-26-94 18-5/8" 1132' 18 08-01-94 13-3/8" 3988' 21.72 15.80 14.2 (FrD 19.47 15.90 16.S (Frr) 19.63 15.3 Leak Off Test (LOT) D~' Page 2 Anna Platform 1 ! rd 10-23-94 13-3/8" 2976' 1 lrd 11-11-94 9-5/8" 8750' 3rd 12/10/94 9-5/8" 7839' 50 2/8/95 18-5/8' 1160' 50 2/13/95 13-3/8" 4251 50 3/8/95 9-5/8" 9844' 51 1/29/95 18-5/8" 1130' 51 5/15/95 13-3/8" 3796' 51 6/3/95 9-5/8" 9842' 52 213/95 18-5/8" 1153' 52 3/27/95 13-3/8" 3940' 52 4/15/95 9-5/8" 9470' 7rd2 8/25/95 9-5/8" 4439' Note~ 0.89 0.92 0.75 1.38 1.01 .86 1.36 .71 .88 1.41 .84 .91 .96 17.2 17.7 (FIT) 14.5 26.6 19.5 16.5 26.2 13.6 17.0 (FrD 27.0 16.15 17.6 (Frr) 18.5 UNOCAL BAKER PLATFORM WELL #31 DEPTH INTERVAL MUD TYPE 0.+800' 17-1/2"/24" HOLE 18.5/8" CASING F.I,W./GENERIC MUD #2 MUD ADDITIVES M-I GEL/M-! BAli/SODA ASH/ CAUSTIC/LIME POTENTIAL PROBLEMS HOLE CLEANING/GRAVEL/ GAS KICK/LOST CIRCULATION COST PER BARREL $6,71 ESTIMATED o ,TREATMENTS/PROCEDURES, Build spud mud system with prehydrated bentonite in fresh water and filtered inlet water. . Treat ddll water with Soda Ash as required to reduce calcium content to 4.0± ppm. b. Pre-hydrate 25 Ibs/bbl bentonite aha allow to hydrate for 4-6 hours. Just prior to spud add filtered inlet water as required to yield a 50-70 sec/qt spud mud. Drill hole. 3. 4~ Ddli to +_ 800'. Under-ream hole to 24", Use ali solids control equipment, Raise viscosity if gravel sections are encounterea. Run 18-5/8" casing. Evaluate quality of mud and if possible save for use in the next interval. OM-18~.W~ ANTICIPATED SPUD MUD PROPERTIES~ Mud Density 8.8 - 9.4 ppg Funnel Viscosity 45-100 sec/qt Plastic Viscosity 10-15 cps "field Point 10-30 #/100f¢ Gels 8-20 Fluid Loss (APl) No Control pH 8.5 - 9.5 NOTE: DO NOT E:XCEED M,A.C. of products or use products not approved in the discharge permit. See letter requesting authorization for list of approved products and M.A.C. DM-182.WP UNOCAL BAKER PLATFORM WELL #31 DEPTH INTERVAL MUD TYPE MUD ADDITIVES POTENTIAL PROBLEMS HOLE/BIT BALI_lNG/ ENLARGEMENT/GAS KICKS/ COST PER BARREL _~ 800'- _.+ 20C0' 17-1/2" HOLE 13-3/8' CASING GENERIC MUD #2 M-I GEL/M-I BAR/SODA ASH/ PO LYPA C/SPER SEN E/X P-20/ SODIUM BICARBONATE/ CAUS'RC HOLE CLEANING/TIGHT GUMBO CLAYS/HOLE COAL SLOUGHING $5,68 ESTIMATED e 4, TREATMENTS[PROC. EDURE$ Use the surface mud to ctdil the 18-5/8" collar, cement and shoe, Treat tills fluid as required to avoid excessive cement contamination. Build additional volume as required with prehydratecl bentonite in fresh water and filtered inlet water. Pump viscous sweeps if required by hole conditions. Control density with bante, F.I.W, water, and solids control equipment. Dump all sand traps as required. DM.182.W1· . . . , . 10. Report ddii solids analysis on mud check sheet. Report hydraulics calculations on mud check sheet. Use Defoam-X if foaming becomes a problem. Prehydrate all bentonite in freshwater. Drill to _ 2000'. If hole conditions warrant, spot a viscous pill on bottom. 13-5/8" casing. Evaluate quality of mud and save for reuse. Run ANTICIPATED 13-3/8" MUD PROPERTIES Mud Density 9.0-9,6 ppg Funnel Viscosity 40-70 sec/qt Plastic Viscosity 10-15 cps Yield Point 10-20 #/100f¢ Gels 6/12/18 APl Fluid Loss NO CONTROL pH 8.5 - 11.0 MBT < 30 ppb Drilled Solids < 75 ppb Note: This mud program is a guideline only, Hole conditions should dictate actual mud properties, DO NOT EXCEED M,A.C. of products or use products not approved in the discharge permit. See letter requesting authorization of list of approved products end M,A.C, UNOCAl. BAKER PLATFORM WELLS 31 DEPTH INTERVAL MUD TYPE MUD ADDITIVES CAUSTIC/FLO-V~S POTENTIAL PROBLEMS CIRCULATION/ DIFFEREN~qAL COST PER BARREL 2000' - 6200' I2-1/4" HOLE 9.-5/8" CASING GENERIC MUD #2 M-I GEL/M-I BAR/SODA ASH/ AQUAPAC/GELEX/TAN NATHI N/ SODIUM BICARBONATE/ SOLTEX/RESINEX TIGHT HOLE/GAS KICKS/LOST COAL SLOUGHING/ S'[qCKING $33.~ ESTIMATED , e e , TREATM ENTS/PROCEDURES Build mud system with prehydrated bentonite, Aquapac and barite, Treat this system for cement contamination. Pump viscous sweeps if required. Control density with badte, fresh water, inlet water, and solids control equipment. Dump ell se. nd traps as required. Keep mud weights as iow a practical. Mud weights should range from 9.2 ppg to 9.6 ppg. Potential problems exist in coal sections. DM-18?_.WP (LO~c/~ ~/':J.5) . . . 8, Report drill solids analysis on mud CheCK sheet. Report hydraulics calculations on mud check sheet. Add Soitex end Resinex only if required by hole conditions. products must be added. Drill to 12-1/4" T.D. Run 9-5/8" casing, Notify town if these AN.TlC!PATED,12-,1/4" MUD PROPERTIES Mud Density 9.2- 9.6 ppg Funnel Viscosity 42 - 75 sec/qt Plastic Viscosity 10 - 15 cps Yield Point 10- 20 #I100f¢ Gels 6/12/18 #/100f¢ APl Fluid Lcss 8- 12 cc pH 8.5 -9.5 MBT <25 ppb Drilled Solids <75 ppD Note: This mud program is a guideline only. Hole conditions should dictate actual mucl properties. DO NOT EXCEED M.A.C. of products or use products not approved in the discharge permit. See letter requesting authorization for list of approved products and M.A.C. DM.18~.WP UNOCAL BAKER PLATFORM WELL #31 DEPTH INTERVAL MUD TYPE MUD ADDITIVES 6200' - 11,600' 8-1/2" HOLE 7" LINER GENERIC MUD M-! GEL/M-I BAR/SODA ASH/ AQUAPAC/GELEX/TAN NATHIN/ CAUSTIC/SPERSENE CF/ SODIUM BICARBONATF_.J SOLTEXJREStN~FLO-~S POTENTIAL PROBLEMS KICKS/BIT B, ALLING/COAL SLOUGHING/SEEPAGE LOSS COST PER BARREL HOLE CLEANING/TIGHT HOLE/ HOLE ENLARGEMENT/GAS $38,00 ES-rlMATED . . TR EATM ENTS/PR OCED URES Use the intermediate mud to drill the 9-5/8" collar, cement and shoe. Treat this fluid as required to avoid excessive cement contamination. Drill 10' of new hole, perform leak. off test, Build additional volume as required. Treat system with Soltex and Resinex as required. Pump viscous sweeps as recluired. Add Xanvis as required for hole cleaning in the build section and in high angle hole. , , . , , 10. Control density with badte, drill water, and solids control equipment. sand traps as required. Report drill solids analysis on mud check sheet. Report hydraulics calculations on mud check sheet. Report hydraulics calculations on mud check sheet. Ddll to 8-1/2" T,D. Run 7" liner. Tre~t and save this mud system for use on next Baker well. Displace well to 3% KCI for completion. Dump all ANTICIPATED MUD PRO. PE.RTIE$ Mud Density Funnel Viscosity Plastic Viscosity Yleld Point Gels APl Fluid Loss HPHT Fluid Loss MBT Drilled Solids 9,5 - 9.6 ppg 42- 75 sec/qt 10- t5 cps 15- 20 ,,¢t100f'¢ 6/12/18 #/100f¢ 6 cc 12- 25 cc <25 ppb <75 ppb Note: This mud program is a guideline only. Hole conditions should dictate actual mud Properties. DO NOT EXCEED M.A.C. of products or use products not approved in the discharge permit. See letter requesting authorization for list of approved products end M.A,C, UNOCAL BAKER Platform Ba-31 slot #~-6 ~iddLe Ground Shoals Cook [nLet, ALaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : aa51 Version #8 Our ref : prop1458 License : Date printed : 30-Nov-95 Date created : 17-Nov-95 last revised : 30-Nov-95 Field is centred on n60 50 4.803,w151 29 11.941 Structure is centred on n60 50 4.803,w151 29 11.941 Slot Location is n60 49 45.236,w151 29 2.199 Slot Grid coordinates are N 2498019.136, E 235192.397 Slot local coordinates are 1987.00 S 483.00 E Reference North is True North UNOCAL BAKER Platform,Ba-31 Middle Ground Shoals,Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : Ba31 Version Last revised : 30-Nov-95 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 0.00 0.00 80.00 0.00 0.00 N 0.00 E 0.00 500.00 0.00 80.00 500.00 0.00 N 0.00 E 0.00 800.00 0.00 80.00 800.00 0.00 N 0.00 E 0.00 900.00 1.00 80.00 899.99 0.15 N 0.86 E 1.00 1000.00 2.00 80.00 999.96 0.61 N 3.44 E 1.00 1050.00 2.50 80.00 1049.92 0.95 N 5.37 E 1.00 1350.00 2.50 80.00 1349.64 3.22 N 18.26 E 0.00 1400.00 2.00 80.00 1399.60 3.56 N 20.19 E 1.00 1500.00 1.00 80.00 1499.56 4.01 N 22.T7 E 1.00 1600.00 0.00 80.00 1599.56 4.17 N 23.63 E 1.00 0.00 0.00 0.00 Begin Nudge -0.26 -1.05 -1.64 End Angle Build -5.57 Begin Angle Drop -6.16 -6.95 -7.21 End Nudge 1700.00 0.00 301.95 1699.56 4.17 N 23.63 E 0.00 -7.21 1800.00 0.00 301.95 1799.56 4.17 N 23.63 E 0.00 -7.21 1900.00 0.00 301.95 1899.56 4.17 N 23.63 E 0.00 -7.21 2000.00 0.00 301.95 1999.56 4.17 N 23.63 E 0.00 -7.21 2100.00 0.00 301.95 2099.56 4.17 N 23.63 E 0.00 -7.21 2200.00 0.00 301.95 2199.56 4.17 N 23.63 E 0.00 -7.21 2300.00 0.00 301.95 2299.56 4.17 N 23.63 E 0.00 -7.21 2400.00 0.00 301.95 2399.56 4.17 N 23.63 E 0.00 -7.21 2500.00 0.00 301.95 2499.56 4.17 N 23.63 E 0.00 -7.21 2600.00 0.00 301.95 2599.56 4.17 N 23.6.3 E 0.00 -7.21 2700.00 0.00 301.95 2699.56 4.17 N 23.63 E 0.00 -7.21 2800.00 0.00 301.95 2799.56 4.17 N 23.6.3 E 0.00 -7.21 2900.00 0.00 301.95 2899.56 4.17 N 23.63 E 0.00 -7.21 3000.00 0.00 301.95 2999.56 4.17 N 23.63 E 0.00 -7.21 3100.00 0.00 301.95 3099.56 4.17 N 23.63 E 0.00 -7.21 3200.00 0.00 301.95 3199.56 4.17 N 23.63 E 0.00 -7.21 3300.00 0.00 301.95 3299.56 4.17 N 23.63 E 0.00 -7.21 3400.00 0.00 301.95 3399.56 4.17 N 23.63 E 0.00 -7.21 3500.00 0.00 301.95 3499.56 4.17 N 23.63 E 0.00 -7.21 3600.00 0.00 301.95 3599.56 4.17 N 23.63 E 0.00 -7.21 3700.00 0.00 301.95 3699.56 4.17 N 23.63 E 0.00 -7.21 3800.00 0.00 301.95 3799.56 4.17 N 23.63 E 0.00 -7.21 3900.00 0.00 301.95 3899,56 4.17 N 23.63 E 0.00 -7.21 4000.00 0.00 301.95 3999.56 4.17 N 23.63 E 0.00 -7.21 4100.00 0.00 301.95 4099.56 4.17 N 23.63 E 0.00 -7.21 KOP 4200.00 2.50 301.95 4199.52 5.32 N 21.78 E 2.50 -5.33 4300.00 5.00 301.95 4299.30 8.78 N 16.23 E 2.50 0.30 4400.00 7.50 301.95 4398.70 14.54 N 6.99 E 2.50 9.67 4500.00 10.00 301.95 4497.53 22.59 N 5.92 W 2.50 22.77 4600.00 12.50 301.95 4595.60 32.91 N 22.47 W 2.50 39.57 4700.00 15.00 301.95 4692.72 45.49 N 42.64 ~ 2.50 60.03 4800.00 17.50 301.95 4788.72 60.29 N 66.38 g 2.50 84.12 4900.00 20.00 301.95 4883.41 77.30 N 93.65 ~ 2.50 111.80 5000.00 22.50 301.95 4976.60 96.47 N 124.40 W 2.50 143.00 5100.00 25.00 301.95 5068.12 117.78 N 158.58 ~ 2.50 177.68 5200.00 27.50 301.95 5157.80 141.18 N 196.10 W 2.50 215.76 5245.55 28.64 301.95 5198.00 152.52 N 214.29 ~ 2.50 234.21E06 5500.00 28.64 301.95 5421.32 217.05 N 317.78 ~ 0.00 339.22 5971.49 28.64 301.95 5835.13 336.62 N 509.53 W 0.00 533.79 Begin Final Build & Turn to Targets 6000.00 28.13 302.99 5860.21 343.90 N 520.96 W 2.50 545.52 All data is in feet unless otherwise stated Coordinates from slot #4-6 and TVD from RKB (Rig ~428) (118.00 Ft above ~d~:~e~",[:~e~ ~-~ ~ ~ Vertical section is from wellhead on azimuth 332.51 degree~. Declination is 0.00 degrees, Convergence is -1.30 degrees. Calculation uses the minimumcurvature method. Prosonte~ ~v Ba~er .u~es I.~E~ UNOCAL BAKER Platform,Ba-31 Middle Ground Shoals,Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : Ba31 Version #8 Last revisect : 30-Nov-95 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/lOOFt Sect 6100.00 26,40 306.94 5949.10 370.10 N 558.51 g 2.50 586.10 6200.00 24.80 311.39 6039.29 397.33 N 592.02 g 2.50 625.72 6300.00 23.35 316.38 6130.60 425.55 N 621.43 ~ 2.50 664.33 6400.00 22,07 321.95 6222.86 454.69 N 646.68 ~ 2.50 701,83 6500.00 21.00 328.11 6315.88 484.70 N 667,73 ~ 2.50 738.17 6600.00 20.17 334.82 6409.51 515.52 N 684.54 ~ 2.50 7-/3.27 6700.00 19.62 341.99 6503.56 547.10 N 697.07 ~ 2.50 807.07 6800.00 19.37 349.45 6597.84 579.38 N 705.30 ~ 2.50 839.50 6900.00 19.42 356.98 6692.18 612.28 N 709.21 g 2.50 870.50 7000.00 19.78 4.36 6786.40 645.76 N 708.80 g 2.50 900.00 7100.00 20.43 11.39 6880.32 679.74 N 704.06 ~ 2.50 92?.9? 7200.00 21.34 17.92 6973.76 714.17 N 695.01 g 2.50 954.33 7300.00 22.48 23.88 7066.55 748.97 N 681.67 ~ 2.50 9~9.05 7400.00 23.83 29.25 7158.50 784.09 N 664.05 g 2.50 1002.07 7500.00 25.34 34.05 7249.44 819.44 N 642.20 ~ 2.50 1023.35 7600.00 26.98 38.32 7339.20 854.98 N 616.15 ~ 2.50 7700.00 28.74 42.11 7427.62 890.62 N 585.96 g 2.50 7800.00 30.60 45.50 7514.50 926.30 N -551.67 ~ 2.50 7900.00 32.54 48.52 7599.71 961.96 N 513.36 W 2.50 7921.75 32.96 49.14 7618.00 969.70 N 504.51 ~ 2.50 1042.85 1060.53 1076,36 1090.31 1093.09 Tgt #1 / A Sand / Final EOC 8000.00 32.96 49.14 7683.65 99?.56 N 472.30 ~ 0.00 1102.94 8100.00 32.96 49.14 7767.55 1033.15 N 431.15 ~ 0.00 1115.52 8200.00 32.96 49.14 7851.45 1068.75 N 390.00 W 0.00 1128,11 8300.00 32.96 49.14 7935.35 1104.35 N 348.84 W 0.00 1140,69 8400.00 32.96 49.14 8019.25 1139.94 N 30?.69 ~ 0.00 1153.28 8500.00 32.96 49.14 8103.15 1175.54 N 266.53 ~ 0.00 1165.86 8600.00 32.96 49.14 8187.05 1211.14 N 225.38 ~ 0.00 1178.44 8700.00 32.96 49.14 8270.95 1246.73 N 184.23 ~ 0.00 1191,03 8800.00 32.96 49.14 8354.85 1282.33 N 143.07 W 0.00 1203.61 8900.00 32.96 49.14 8438.75 1317.93 N 101.92 ~ 0.00 1216.20 9000.00 32.96 49.14 8522.65 1353.52 N 60.76 ~ 0.00 1228.78 9100.00 32.96 49.14 8606.55 1389.12 N 19.61 ~ 0.00 1241.36 9200.00 32.96 49.14 8690.45 1424.72 N 21.55 E 0.00 1253,95 9300.00 32.96 49.14 8774.35 1460.31 N 62.70 E 0.00 1266,53 9400.00 32.96 49.14 8858.25 1495.91 N 103.86 E 0.00 1279,12 9500.00 32.96 49.14 8942.15 1531.50 N 145.01 E 0.00 1291,70 9600.00 32.96 49.14 9026.05 1567.10 N 186.16 E 0.00 1304.28 9700.00 32.96 49.14 9109.95 1602.70 N 22?.32 E 0.00 1316,87 9800.00 32.96 49.14 9193.85 1638.29 N 268.48 E 0.00 132(~.45 9900.00 32.96 49.14 92T7.75 1673.89 N 309.63 E 0.00 1342.03 10000.00 32.96 49.14 9361.65 1709.49 N 350.79 E 0.00 1354,62 10100.00 32.96 49.14 9445.55 1745.08 N 391.94 E 0.00 1367.20 10200.00 32.96 49.14 9529.45 1780.68 N 433.10 E 0.00 13T9.78 10300.00 32.96 49.14 9613.35 1816.28 N 474.25 E 0.00 1392.37 10400.00 32.9? 49.14 969?.25 1851.87 N 515.41 E 0.00 1404.95 10500.00 32.97 49.14 9T81.15 1887.47 N 556.56 E 0.00 1417.53 10600.00 32.9? 49.14 9~5.05 1923.06 N 597.T2 E 0.00 1430,12 10663.12 32.97 49.14 9918.00 1945.53 N 623.?0 E 0.00 1438.06 Tgt #2 / Hemlock 11000.00 32.9? 49.14 10200.64 2065.45 N 762.34 E 0.00 1480.45 11500.00 32.9? 49.14 10620.14 2243.43 N 968.13 E 0.00 1543,36 All data is in feet unless otherwise stated Coordinates from slot #4-6 and TVD from RKB (Rig ~428) (118.00 Ft above mean sea (eve[). Vertical section is from we[[heed on azimuth 332.51 degrees. Declination is 0.00 degrees, Convergence is -1.30 degrees. Calculation uses the minim~m~ curvature method. Presented by Baker Hughes INTEQ UNOCAL BAKER Platform,Ba-31 Middle Ground Shoals,Cook Inlet, Alaska PROPOSAL LISTING Page 3 Your ref : Ba31 Version ~8 Last revised : 30-Nov-95 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 11663.12 32.97 49.14 10757.00 2301.50 N 1035.26 E 0.00 1563.89 Projected TD All data is in feet unless otherwise stated Coordinates from slot #4-6 and TVO from RKB (Rig #428) (118.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 332.51 degrees. Declination is 0.00 degrees, Convergence is -1.30 degrees. Catculation uses the minim~ancurvature method. Presented by Baker Hughes INTEQ UNOCAL PROPOSAL LISTING Page 4 BAKER Platform,Ba-31 Your ref : Ba31 Version #8 Middle Ground Shoals,Cook Inlet, Alaska Last revisea : 30-Nov-95 Co~m~ents in wetlpath MD TVD Rectangular Coords. Co~rnent 800.00 800.00 0.00 N 0.00 E Begin Nudge 1050.00 1049.92 0.95 N 5.37 E End Angle Build 1350.00 1349.64 3.22 N 18.26 E Begin Angle Drco 1600.00 159<2.56 4.17 N 23.63 E End Nudge 4100.00 409<2.56 4.17 N 23.63 E KOP 5245.55 5198.00 152.52 N 214.29 g EOC 5971.49 5835.13 336.62 N 509.53 W Begin Final Build & Turn to Targets 7921.75 7618.00 969.70 N 504.51W Tgt #1 / A Sana / Final EOC 10663.12 9<718.00 1945.53 N 623.70 E Tgt #2 / HemlocZ 11663.12 10757.00 2301.50 N 1035.26 E Projected TD Targets associated with this wetlpath Target name Position T.V.D. Local rectangular coords. Date revised Ba31Tgt2 Hemlk 17-N 235860.000,2499950.000,0.00009918.00 1945.53N 623.70E 17-Nov-95 Ba31Tgtl A Snd Rvsd 234710.000,2499000.000,0.00007618.00 969.70N 504.51W 17-Nov-95 CRC 1 1 1 95 A!8,ska 0ii & Gss Cr..,F~s. Coma'~ission Att data is in feet unless otherwise stated Coordinates from slot #4-6 and TVO from RKB (Rig g428) (118.00 Ft above mean sea [eve[). Bottom hole distance is 2523.62 on azimuth 24.22 degrees from wellhead. Total Dogleg for we[[path is 82.40 degrees. Vertical section is from wellhead on azimuth 332.51 degrees. Declination is 0.00 degrees, Convergence is -1.30 degrees. Calculation uses the minimmmt curvature method. Presented by Baker Hughes INTEQ UNOCAL BAKER Platform Ba-31 slot #4-6 Middle Ground Shoals Cook Inlet, Alaska CLEARANCE REPORT by Baker Hughes !NTEQ Your ref : Ba-31 Version #? Our ref : prop1458 License : Date printed : 27-Nov-95 Date created : 17-Nov-95 Last revised : 17-Nov-95 Field is centred on n60 50 4.803,w151 29 11.941 Structure is centred on n60 50 4.803,w151 29 11.941 Stol Location is n60 49 45.236,w151 29 2.199 Stol Grid coordinates are N 2498019.136, E 2~5192.397 Slot local coordinates are 1987.00 S 48~.00 E Reference North is True North Main calculation performed with Travelling Cylinder method Object wettpath GMS <8300-9445'>,,7,BAKER Platform PMSS <2721-10582'>,,28 St#2,BAKER Platform PMSS <1420-4~20'>,,Ba-28,BAKER Platform PMSS <3617-5479'>,,28 $t#1,BAKER Platform MSS <5626-10231'>,,18,BAKER PLatform MSS <765-9543'>,,11,BAKER Platform MSS <2653-11495'>,,9,BAKER Platform GMS <0-9?60'>,,9Rd~2,BAKER Platform MSS <6757-9944'>,,9Rd~l,BAKER PLatform GMS <0-11128'>,,5,BAKER PLatform MSS <3165-10455'>,,14,BAKER PLatform MSS <6?0-10000'>,,12,BAKER Platform PGM$ <0-9642'>,,20,BAKER Platform GMS <O-?400'>,,6,BAKER PLatform GMS <0-11600'>,,2?,BAKER Platform GMS <0-10691'>,,13,BAKER PLatform PGM$ <0-9544'>~,15,BAKER PLatform MSS <6950-10116'>,,15Rd,BAKER PLatform GMS <0-1894'>,,MGSSO1,BAKER Platform PGMS <0-9?22'>,,23,BAKER Platform GMS <0-9250'>,,BRd,BAKER Platform MSS <2008-10314'>,,8,BAKER Platform MSS <0-9215'>,,4,BAKER Platform PGM$ <?200-9800'>,,25Rd,BAKER Platform MSS <711?-8642'>,,25,BAKER Platform PMS$ <2180-10280'>,,Ba-29,BAKER PLatform PMSS <843 - 11275'>,,Ba-30,BAKER Platform MSS <1039-12500'>,,lO,BAKER Platform GMS <O-7232'>,,17,BAKER Platform CLosest aPlaroach with 3-D minin~mn distance method Last revised Distance M.D. Diverging fro~ M.D. 24-Ma¥-93 7.5 220.0 8200.0 21-Mar-94 83.4 100.0 10100.0 3-Dec-93 83.4 100.0 4200.5 3-Dec-93 83.4 100.0 4200.5 24-May-93 75.8 100.0 120.0 23-May-93 '36.8 2500.0 2500.0 23-May-93 79.9 640.0 1146].1 23-May-93 79.9 640.0 10400.0 23-May-93 79.9 640.0 10860.0 24-May-93 84.6 100.0 11120.0 2]-May-93 85.0 280.0 10999.2 24-Jan-93 105.5 340.0 7166.7 24-May-93 9?.6 1100.0 1100.0 24-May-93 57.1 1550.0 1550.0 24-May-93 102.0 240.0 1146].1 2J-May-93 101.1 1100.0 10000.0 3-Jun-93 110.0 100.0 9200.0 3-Jun-93 110.0 100.0 11100.0 3-Sep-93 96.4 1500.0 1500.0 24-May-93 6.3 480.0 5280.0 3-Jun-93 8.2 620.0 620.0 3-Jun-93 8.2 620.0 8600.0 24-May-93 90.0 1500.0 1500.0 3-Jun-93 3.9 220.0 10284.1 3-Jun-93 3.9 220.0 9092.2 1?-Jan-94 44.8 2000.4 2000.4 6-Ju[-94 78.5 0.0 1550.0 23-May-93 3.2 760.0 11463.1 24-May-93 4.1 260.0 8000.0 GMS <0-9645'>,,!~BAKER Platform 24-May-93 110.1 0.0 9200.0 Unocal North American '-- Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region December 1, 1995 Mr. David JohnSon Commissioner Alaska Oil & Gas Conservation Commissioner 3001 Porcupine Drive Anchorage, AK. 99501-3192 Dear Mr. Johnston: Please find enclosed application for Permit to Drill (Form 10-401) for the Baker Platform well/t31. The timing to spud this well is approximately January 1, 1996 upon the completion of the rig move. UNOCAL is requesting that the AOGCC waive the diverter system requirement on both the (32") structural and (18-5/8") surface casing strings. This waiver request is similar to our August 1993 request for wells #28, 29, & 30 at the Baker Platform which was subsequently approved by the AOGCC. As outlined in the well procedure, UNOCAL is intending to drill out the 32" structural casing to +800' with a flow nipple then install a 20-3/4" 3M BOPE stack on the 18-5/8" casing that will be cemented at ±800' to surface. The 18-5/8" casing will then be drilled out to a depth of +_2000' and 13-3/8" intermediate casing will be cemented at that depth. UNOCAL has selected the casing points for the 18-5/8" at ±800' and the 13-3/8" at ±2000' to be areas of competent formations. No gas bearing zones are evident above ±800', based on offset well data. It is anticipated that the minimum formation fracture gradients at both shoe depths to be 0.80 psi/fi. UNOCAL's recent experience in the Middle Ground Shoals Field at the Baker and Dillon Platforms and elsewhere in the Cook Inlet (see Leak Off Test Data) has demonstrated true fracture gradients ranging from 0.75 - 0.94 psi/fi. In the Baker #31, maximum surface pressure (MSP) expected while drilling below the 18-5/8" surface casing will be far less than the anticipated fracture pressures. Since the casing shoes will not break down in a well kick situation and the setting depths are in competent formations, UNOCAL believes these are prudent casing designs and warranted operations. OEC 1 1 1995 Al~ka Oit & Gas Cons, Commission ~chorage Mr. David Johnston December 1, 1995 Page - 2 UNOCAL plans to complete the Baker #31 as a flowing completion; although an option to hydraulically pump is available if artificial ~ is required for production of oil reserves. If you should have any questions regarding this permit please contact Pat Ryan (Senior Drilling Engineer) assigned to this project. Thank you for your attention to these matters. ~Sincerely, G. Russell Schmidt Drilling Manager PAR/par enclosure: Unoc~,t Nc-th American Oil and Gas Division Unocal Corpora~n P.O. Box 190247 Anchorage, ~aska 9957g-0247 Telephone (907) 276-7600 UNOCAL Alaska Region August 20; 1993 State of Alaska AOGCC Attn: Bob Crandell 3001 Porcupine Drive Anchorage, AK 99501 Mr. Crandell In response to your question about productive gas sands at Middle Ground shoals that~would affect the proposed new wells at Baker Platform (Ba. ~28, 29 & 30) the following information is provided for your review. At the north 'end of the Middle Ground Shoal Field, Baker Platform, gas productive sandstones occur within the middle and upper portions of the Tyonek Formation. The sandstones range in thickness from 10 to 50 feet, are interbedded with siltstones, shales and coals, and are interpreted as meandering fluvial channel sandstones. Good sorting and upper-medium to very coarse/pebbly grain size characterize the gas reservoirs which typically exhibit permeabilities in the range of several hundred to several thousands millidarcies. Porosity values are also high, usually 25 to 32 percent. Pores pressures are considered normal to sub- normal with the gradients being 0.33 to 0.45 psi/ft. The type log for the gas reservoir is the Pan American Petroleum Corporation Middle Ground shoal State $4 well. These known productive gas Sands at Baker Platform will be present in the proposed wells (Be. ~25, 29, & 30) from 3200' to 4300' TVD, with the interval being subdivided into Zones 3 and 4. Presently, the Baker Platform has two wells (Baker #14 & 18) producing gas from'these zones. . cc: Wellfile(s) Be.28, 29, & 30 Regards, C. Lee Lohoefer Senior Drilling Engineer RECEIVED AU 6 2 0 199, Alaska 0ii & Gas Cons. 6omm~sS~OTt Anchorage Memorandum State of Alaska Oil and Gas Conservation Commission To~ August 19, 1993 Fm: Staff Subj: Unocal Request for Diverter Waiver Middle Ground Shoal Platform Baker Wells 28, 29, and 30 DRAFT Unocal has requested a waiver of diverter requirements on the subject wells. They propose to drill the surface hole with a drilling nipple then drill the surface hole with a combination 20 3/4" 3000 psi. BOPE system. They state in their application letter that the fracture gradient anticipated at the surface and intermediate casing shoes are .85 psi/foot and the rock is competent enough to shut in the well and circulate a kick rather than divert. The estimated fracture gradient is based on recent leak off tests which were taken all the way to leak off' in the Cook Inlet area. I was told that some of the shallow tests showed a gradient of .9 psi/foot or greater; I did not get a list of wells. I reviewed 7 wells which offset the subject wells. Drilling histories in our files indicate no shallow gas kicks were encountered nor was there any lost circulation. On #25RD (83- 72) a DST was done to test a sand at about 3700' TVD and recovered gas cut mud. The most recent well drilled was #17 (85-217) offthe Baker platform. Unocal states that there is no gas above 3200' in the vicinity of the Baker platform based on the information available to them. Regulation 20 AAC 25.035 (b) (3) and (c) (2) authorizes the Commission to waive diverter requirements if drilling experience in the near vicinity indicates a diverter system is not necessary. The same approach and arguments were used to waive diverter requirements on Granite Pt. 42. The proposal to drill the conductor hole, 303-800', with a drilling nipple means there is no annular preventer to divert the well and returns go straight to the shakers and pits. For the hole sections frim 800-6200', their permit application shows a 20 3/4" BOP system that has a diverter spool and a 2000 psi annular preventer. I understood in my conversation with Lee Lohoefer that if the waiver is approved, the diverter would be blinded' off' and not used. Unocal believes the diverter is not necessary and would rather use positive control measures and shut in on kicks. Batch drilling entails doing each casing segment of the three wells consecutively. As each section of the hole is completed and cased the well will be secured with a wellhead assembly, flanged such that there is a drill pipe connection and gauge to monitor the shut Page 2 in well. This drilling procedure is unusual, however, it is not unlike an operations shutdown. I would advocate a stipulation in the permit allowing this method and waive application for operations shutdown after each hole segment conditioned on securing the well (which they plan to do an?way). In summary, drilling history indicates no shallow gas has been encountered above 3200' at the Baker platform. A review of AOGCC well histories on seven wells in the vicinity of the 3 proposed wells indicated no shallow gas nor lost circulation zones. Most recent drilling at Baker occurred in 1985. The section of hole drilled from the structural pipe (303' RKB) to the conductor depth of 800' RKB would be done without any means to divert. Drilling from 800' RKB to total depth would be accomplished with BOP equipment. Recommendation: Based on no shallow gas in the vicinity of the wells to be drilled, I recommend approval of the waiver of diverter requirements. If there are other circumstances which the Commission thinks would cause a need for diverter use, Unocal should be allowed to address those ci?cumstances in a meeting. _ - The batch drilling procedure should be approved with a stipulation that each casing segment be secured prior to moving the rig to the next well. I don't recommend requiring a 10-403 (operations shutdown) for each segment in that it requires at least 6 filings and operations will be resumed within 60 days baring unforeseen circumstances. FIELD & POOL ,_m vllT CHECKLIST UNIT# PROGRAM: exp [] de~ redrll [] serv [] ADMINISTRATION DATE ENGINEERING 1. Permit fee attached ................... 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ...... 7. Sufficient acreage available in drilling unit ...... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... N N N N N N N N N N N N N REMARKS 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ............... Surface casing protects all known USDWs ........ CMT vol adequate to circulate on conductor & surf csg. CMT vol adequate to tie-in long string to surf csg . . CMT will cover all known productive horizons ...... Casing designs adequate for C, T, B & permafrost .... Adequate tankage or reserve pit ............. If a re-drill, has a 10-403 for abndnmnt been approved. Adequate wellbore separation proposed .......... If diverter required, is it adequate ........ ~/~.Y Drilling fluid program schematic & equip list adequate''-- ROPEs adequate ..................... ROPE press rating adequate; test to ~/~D~pstg. Choke manifold complies w/API RP-53 (May 84) Work will occur without operation shutdown Is presence of H2S gas probable ............ GEOLOGY DATE 30. Permit can be issued w/o hydrogen sulfide measures 31. Data presented on potential overpressure zones ..... 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ 34. Contact name/phone for weekly progress reports . . [exploratory only] GEOLOGY: ENGINEERING: COMMISS ION: Comments/Instructions: HOWlljb - A:\FORMS~cheklist rev 1!/95