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Home My WebLink About193-120MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:31 Township:9N Range:12W Meridian:Seward Drilling Rig:Rig Elevation:Total Depth:11,275 ft MD Lease No.:ADL 0017595 Operator Rep:Suspend:X P&A: Conductor:24"O.D. Shoe@ 803 Feet Csg Cut@ Feet Surface:18 5/8"O.D. Shoe@ 2013 Feet Csg Cut@ Feet Intermediate:13 3/8"O.D. Shoe@ 5836 Feet Csg Cut@ Feet Production:9 5/8"O.D. Shoe@ 9526 Feet Csg Cut@ Feet Liner:7"O.D. Shoe@ 11275 Feet Csg Cut@ Feet SS Tubing:3 1/2"; 2" CT O.D. Tail@ 9295 Feet Tbg Cut@ Feet LS Tubing:3 1/2"O.D. Tail@ 9487 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Long String Fullbore Bridge plug 9424 ft 8178 ft 14 ppg Wireline tag Short String Fullbore Bridge plug 9424 ft 7534 ft 14 ppg Wireline tag Initial 15 min 30 min 45 min Result Test 1 Tubing 2600 2498 2419 IA 2600 2498 2419 OA 430 405 385 Initial 15 min 30 min 45 min Result Test 2 Tubing 2615 2538 2474 IA 2615 2538 2474 OA 440 410 400 Remarks: Attachments: Two attempts were made to get a passing MIT-IA. Both are included above. The OOA and the OOOA stayed stable throughout both tests at: OOA = 78 psi OOOA= 34 psi. The bbls pumped in the first attempt was 4 bbls in and 3.5 bbls back. For the second attempt it was 3.8 bbls in and 3.5 bbls back. The LS cement tag was at 8178 ft and the SS cement tag was at 7534 ft. Both of these depths include a correction of 41 feet. Good cement samples were found in the drive-down bailer that was ran by Pollard Wireline for both the LS and the Velocity String. August 24, 2025 Guy Cook Well Bore Plug & Abandonment MGS ST 17595 Baker-30 Hilcorp Alaska LLC PTD 1931200; Sundry 324-561 None Test Data: F Casing Removal: Brad Whitten F Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0824_Plug_Verification_MGS_State_17595_Baker-30_gc                                    Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/14/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251114 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# PBU 01-10A 50029201690200 225055 8/29/2025 BAKER MRPM BRU 224-34T 50283202050000 225044 8/9/2025 AK E-LINE CBL MGS ST 17595 30 50733204560000 193120 8/13/2025 AK E-LINE CBL MPU H-11 50029228020000 197163 8/17/2025 AK E-LINE JetCut PCU D-10 50283202080000 225082 10/6/2025 AK E-LINE CBL Please include current contact information if different from above. T41100 T41101 T41102 T41103 T41104 MGS ST 17595 30 50733204560000 193120 8/13/2025 AK E-LINE CBL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.14 12:58:13 -09'00' 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 Cc:Juanita Lovett; Dan Marlowe Subject:RE: MGS ST 17595 30 PTD 193-120_Sundry_324-561 Date:Tuesday, August 19, 2025 2:27:00 PM Casey, The top of cement in the IA +/-7675’ MD is sufficient to meet the requirements in the sundry. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Casey Morse <casey.morse@hilcorp.com> Sent: Tuesday, August 19, 2025 10:57 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: MGS ST 17595 30 PTD 193-120_Sundry_324-561 Bryan, In accordance with the conditions of approval in Sundry 324-561, we applied additional pressure to the long string while allowing the cement to cure in order to slightly over-displace the LS cement top. Attached is the approved sundry and CBL obtained from the LS, which shows a delineation of the cement top in the IA above the tag depth in the LS. Thank you, Casey Morse Operations Engineer Cook Inlet Offshore Hilcorp Alaska, LLC (907) 777-8322 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently 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. 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 Cc:Dan Marlowe; Juanita Lovett Subject:RE: MGS ST 17595 30 PTD 193-120_Sundry_324-561 Date:Saturday, August 9, 2025 3:35:00 PM Casey, Hilcorp has approval to proceed per your request below. 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: Saturday, August 9, 2025 11:44 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: MGS ST 17595 30 PTD 193-120_Sundry_324-561 Bryan, We are in the hole with coil tubing on the Baker 30 well right now. We tagged fill at 10,410’. Coil tagged 3 times with 6k slackoff weight in the same spot. It looks like this is the top of fill in the wellbore now. We plan to lay in 34 bbls at this depth in accordance with the conditions of approval for Sundry 324-561 and 20 AAC 25.112(c)(1)(C). Please confirm if this still meets the objectives of 20 AAC 25.112(c)(1). Thank you, Casey Morse Operations Engineer Cook Inlet Offshore Hilcorp Alaska, LLC (907) 777-8322 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently 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. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,275 N/A Casing Collapse Structural Conductor Surface 630psi Intermediate 1,950psi Production 4,760psi Liner 7,020psi 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 Middle Ground Shoal MGS Oil N/A 9,272 11,192 9,227 2,920psi N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 8,160psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017595 193-120 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20456-00-00 Hilcorp Alaska, LLC MGS ST 17595 30 Length Size Proposed Pools: 83' 83' L-80 & HS-80 TVD Burst 9,295 (SS) 9,487 (LS) 9,224 (CT) 6,870psi MD 3,450psi 2,250psi 803' 2,011' 5,467' 803' 2,013' 83' 32" 24" 18-5/8" 803' 13-3/8"5,836' 2,013' 5,836' 8,370 - 11,015 9,526' 7" 7,608 - 9,135 8,295'9-5/8" N/A 10/11/2024 11,275'1,889' 3-1/2" & 2" 9,272' BOT FA-1 PKR and N/A 9,250 (MD) 8,115 (TVD) & N/A 9,526' Perforation Depth MD (ft): No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:02 pm, Sep 27, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.09.27 14:38:54 - 08'00' Dan Marlowe (1267) 324-561 X -bjm See attached conditions of approval. SFD 10/4/2024 X May 31, 2030 DSR-9/27/24 10-407 X BJM 5/30/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.02 08:09:42 -08'00' 06/02/25 RBDMS JSB 060225 MGS St 17595-30 (PTD 193-120) Suspension Sundry 324-561 Conditions of Approval 1. CT BOPE test to 3000 psi. 2. ôıôĲťϙťĺϙæôϙīÍĖîϙĖĲϙċŘĺıϙťĺŕϙĺċϙƱīīϙŕôŘϙ͑͏ϙϙ͔͑ϟ͐͐͑ϼèϽϼ͐ϽϼϽϙϼĲĺťôîϙĺĲϙſôīīæĺŘôϙ îĖÍČŘÍıϙÍťϙ͐͏͐͘͘Ѝϙa"ϽϙæôċĺŘôϙèĖŘèŪīÍťĖĲČϙèôıôĲťϙĖĲťĺϙ[ϙťŪæĖĲČϙÍĲîϙIϟϙϙēôϙ ÍîîĖťĖĺĲÍīϙèôıôĲťϙŽĺīŪıôϙťĺϙƱīīϙťēôϙ͖ЋϙèÍŜĖĲČϙċŘĺıϙťĺŕϙĺċϙƱīīϙťĺϙôĲîϙĺċϙ[ϙťŪæĖĲČϙťÍĖīϙ is ͔͕ϙææīŜϠϙÍŜŜŪıĖĲČϙĲĺϙôƄèôŜŜϙċĺŘϙīĺŜŜôŜϙťĺϙĺŕôĲϙŕôŘċŜϟ 3. «ÍŘĖÍĲèôϙťĺϙ͑͏ϙϙ͔͑ϟ͐͐͑ϼČϽϙĖŜϙŘôŗŪĖŘôîϙċĺŘϙÍīťôŘĲÍťĖŽôϙıôÍĲŜϙĺċϙŽôŘĖċƅĖĲČϙèôıôĲťϙĖĲϙ ťēôϙI æôèÍŪŜôϙĖťϙèÍĲϙĲĺťϙæôϙťÍČČôîϟϙϙ«ÍŘĖÍĲèôϙÍŕŕŘĺŽôîϙĺĲϙťēôϙċĺīīĺſĖĲČϙèĺĲîĖťĖĺĲŜϡϙ a. ôıôĲťϙťĺŕϙĖĲϙIϙıŪŜťϙæôϙŜēÍīīĺſôŘϙťēÍĲϙèôıôĲťϙťĺŕϙĖĲϙ[ϙŜĺϙťēÍťϙiϙĖĲϙIϙ èÍĲϙæôϙŽôŘĖƱôîϙſĖťēϙ[ϟ b. ŪĲϙ[ϙĖĲϙ[ϙÍċťôŘϙèôıôĲťĖĲČϙťĺϙŽôŘĖċƅϙiϙĖĲϙIϙĖŜϙÍťϙīôÍŜťϙ͐͏͏ЍϙÍæĺŽôϙťĺŕϙ ŕôŘċϙϼıŪŜťϙŽôŘĖċƅϙiϙĖĲϙIϙĖŜϙŜēÍīīĺſôŘϙťēÍĲϙ͖͗͑͏Ѝϙa"Ͻϟ ŪæıĖťϙ[ϙťĺϙ i@ϙÍŜϙŜĺĺĲϙÍŜϙŕŘÍèťĖèÍæīôϙÍċťôŘϙĺæťÍĖĲĖĲČϙīĺČϟϙϙ èϟ aIIϙϼĺŘϙaIϙæČƄIϽϙıŪŜťϙŕÍŜŜϙťĺϙ͓͑͏͏ϙŕŜĖϙŕĺŜťϙèôıôĲťĖĲČϟ 4. ŘĺŽĖîôϙ͓͗ϙēŘŜϙĲĺťĖèôϙċĺŘϙi@ϙĺŕŕĺŘťŪĲĖťƅϙťĺϙſĖťĲôŜŜϙ[ϙЭϙϙèôıôĲťϙťÍČs and aIϙ[ƄƄƄIϙťĺϙ͓͑͏͏ϙŕŜĖϙϼ͏ϟ͔͑ϙƄϙ«"ϙĺċϙèÍŜĖĲČϙŜēĺôϠϙŕôŘϙ͑͏ϙϙ͔͑ϟ͐͐͑ϼČϽϼ͑Ͻ. MGS Oil Pool Abandonment Program Well: Ba-30 Well Name: MGS ST 17595 30 (Ba-30) API Number: 50-733-20456-00-00 Current Status: Shut-In Producer Rig: EL, SL, FB, cement Estimated Start Date: Oct 2024 Estimated Duration: 2 days 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): 3831 psi @ 9108’ TVD (Ca. 2007 SBHPS, EMW: 8.1 ppg) Max. Anticipated Surface Pressure: 2920 psi Gas Column Gradient (0.1 psi/ft) Current Pressures (LS/SS/IA/OA/OOA/OOOA): 74/10/1022/102/80/10 psi History Drilled and completed in 1993/1994 and put on production as an oil producer. There have been no rig workovers performed on this well. In 2002 a coiled-tubing retrofit jet-pump completion was run int the short string. The well was SI in 2003. It was then circulated with 9.8 ppg brine and a 110 bbl pill of LCM was pumped down the LS to plug off the perforations. LCM displaced to KOBE cavity w/ 43 bbls 9.8 ppg brine. The LS, SS, and IA were freeze-protected with diesel. 24” Casing set @ 803’ MD in 30” UR hole. Cemented w/ 160 bbls 12.9 ppg lead, 106 bbls 15.8 ppg tail. Good cement to surface. 18-5/8” Casing set @ 2013’ MD in 24” UR hole. Cemented w/ 450 bbls 12.9 ppg lead and 121 bbls 15.8 ppg tail. Mud report noted intermittent returns. Returns swapped over to cement and were measured at 11 ppg, then lost full returns. 13-3/8” Casing set @ 5836’ MD in 17.5” hole. Cemented w/ 589 bbls 12.9 ppg lead and 124 bbls 15.8 ppg tail. No mention of lost returns in daily drilling reports or mud report. 9-5/8” Casing set @ 9562’ MD in 12.25” hole. Cemented w/ 54 bbls 13.2 ppg lead and 205 bbls 15.8 ppg tail. Ran SBT and CBL showing complete bond ~8100’ with intermittent cement up to ~7600’. 7” Production liner set from 9385’ to 11274’ MD in 8.5” hole. Cemented w/ 150 bbl cement. Liner top packer set and tested to 3000 psi (good). Had 10 bbls cement contaminated mud to surface. Ran SBT and CBL showing top of cement ~9,820’. Current Status Shut-in. The LS and IA were loaded with 8.6 ppg FIW. CT and CT x SS annulus are plugged off. Pre-P&A Diagnostics Performed 1. Initial pressures (LS/CT/SS/IA/OA/OOA/OOOA): 65 / 0 / 15 / 1030 / 170 / 100 / 20 psi 2. Pump 8.6 ppg FIW: a. Pump down LS up IA, FCP = 400psi / 2.75 BPM b. Pump down IA up LS, FCP = 175psi / 2.75 BPM c. Pump down SS up CT, FCP = 1150psi / 1.3 BPM MGS Oil Pool Abandonment Program Well: Ba-30 d. Pump down CT up SS, FCP = 1900psi / 1.7 BPM e. No communication between LS or IA with CT or SS in either direction f. Bled down OOA to 50psi, all air, no communication across annuli 3. Attempt to inject down LS, pressured up to 1500psi, bled down to 1310psi in 5 min. 4. RU slickline on LS. a. RIH w/ 2.80” gauge ring to 9312’ SLM tagging KOBE cavity, pooh. b. RIH w/ 2.5" RB w/ 3.5” DD holefinder, set at 9289’, PT tubing to 575psi, hold for 5 minutes, good test, pooh. L/d lubricator. 5. RU slickline on CT a. RIH w/ 1.25” gauge ring, tag at 9226’ SLM. POOH. 6. Check pressures (LS/CT/SS/IA/OA/OOA/OOOA): 0 / 0 / 0 / 155 / 40 / 75 / 12 psi a. OA is fluid packed. Pressure up to 560psi, dropped to 530psi in 15 minutes. No change in other annuli pressures. Bled down and stabilized at 10psi b. Bled off 75psi gas from OOA. Top off w/ 19 bbl FIW, pressured up to 560psi. Pressure dropped to 530psi in 15 minutes. OA pressure increased from 10psi to 150psi while pressuring up and dropped to 15 psi when bled off. Bled down OOA and stabilized at 40 psi. c. Bled off 12 psi from OOOA, top off w/ 10 bbl FIW. Pressure up to 560psi, dropped to 400psi in 15 minutes. No change in other annuli pressures. Bled down and stabilized at 20 psi. Objective Plug and abandon the Middle Ground Shoal Oil Pool perforations. Procedural steps E-line 1. RU E-line to CT. MU coil tubing punch or cutter. RIH to ~9200’ and punch or cut CT to establish circulation CT x SS. Fullbore / Cement 1. Fluid pack the tubing strings and IA with 9.8 ppg brine. 2. Pump reservoir abandonment cement plug as follows: ¾ 30 bbls FIW w/ Surfactant Wash (down LS and out IA) ¾ 80 bbls 14 ppg Class G cement. Record volumes of fluid recovered i. Start pumping down LS and out IA ii. Return 80 bbls from IA (IA cement volume of 68 bbls plus LS cement volume of 12 bbl) ¾ Foam Wiper Ball ¾ 70 bbls of 9.8 ppg brine displacement of cement (continuing returns up IA). i. This puts TOC in LS / IA @ ~8100’ 3. Swap cement to CT to pump SS / CT abandonment cement plug as follows: ¾ 20 bbls FIW w/ Surfactant Wash down CT and up SS ¾ 8 bbls 14 ppg Class G cement. Record volumes of fluid recovered i. Start pumping down CT and out SS x CT annulus ii. Return 8 bbls from SS x CT annulus (SS volume of 5 bbls plus CT cement volume of 3 bbl) ¾ Foam Wiper Ball Lay in cement with CT from top of fill at 10991 ft MD to tubing tail at 9487' before pumping LS x IA cement plug. See attached conditions of approval. -bjm Diagnostics above state that communication already exists between CT & SS. Additional holes may not be needed, but are permitted if needed for better circulation rate. -bjm MGS Oil Pool Abandonment Program Well: Ba-30 ¾ 22 bbls of 9.8 ppg brine displacement of cement (continuing returns up SS x CT annulus). i. This puts TOC in CT / SS @ ~8100’. ¾ LS volume from tubing tail to 8100’: 0.0078 bpf * (9487’-8100’) = 12 bbls ¾ IA volume from tbg tail to 8100’ = 68 bbls o 9487 to 9386: 0.0252 bpf * 101’ = 3 bbls (tubing tail x liner) o 9386 to 9305: 0.0626 bpf * 81’ = 5 bbls (tubing tail x 9-5/8) o 9305 to 7500: 0.0494 bpf * 1205’ = 60 bbls (LS/SS x 9-5/8) ¾ CT volume from 9200 to 8100: 0.0028 bpf * 1100’ = 3 bbls ¾ SS volume from 9200 to 8100: 0.0048 bpf * 1100’ = 5 bbls ¾ LS volume from 8100’ to surface: 0.0087 bpf * 8100’ = 70 bbls ¾ IA volume from 7500’ to surface: 0.0494 bpf * 8100’ = 400 bbls ¾ CT volume from 7500’ to surface: 0.0028 bpf * 8100’ = 22 bbls ¾ SS volume from 7500’ to surface: 0.0048 bpf * 8100’ = 39 bbls Fullbore/Slickline 1. Notify AOGCC for opportunity to witness CMIT LSxCTxSSxIA to 1905 psi (Top perf 7607 TVD). 2. Notify AOGCC for opportunity to witness Tag TOC in LS and CT. Cement Tops: x 24” Casing o Cement returns to surface noted in drilling report x 18-5/8” Casing o Complete loss of returns noted as cement first came to surface. Anticipated top of cement at or near surface. o OOOA failed to hold pressure during diagnostics x 13-3/8” Casing o Open hole annuluar volume: (5835’ – 2013’) * 0.1237 bpf = 473 bbl With 50% washout: 710 bbl o Cement volume: 3300 cu-ft lead + 695 cu-ft tail = 3995 cu-ft = 711 bbl o Calculated top of cement at or near the 18-5/8” casing shoe @ 2013 ft o OOA held pressure during diagnostics Attachments Current Schematic Proposed Schematic Provide 48 hrs notice for witness. -bjm 2400 psi (0.25 x TVD of casing shoe, per 20 AAC 25.112(g)(2)). -bjm 3. Verify TOC in IA with a CBL run in the LS after cementing. See attached conditions of approval. -bjm Calculated volumes are from 8100' to surface, not 7500', per Casey Morse email 5/30/25. -bjm 8100 -bjm IA TOC should be higher than LS TOC so IA TOC can be verified with a CBL. Pump enough extra cement to allow for that. See attached conditions of approval. -bjm WBD_Ba-30 Dec2010 Page 1 of 1 ARD 02-2010 / Updated 12-2010 Offshore Baker Platform Ba-30 N Middle Ground Shoal Cook Inlet Basin, Alaska Middle Ground Shoal Last Completed: 11-16-1997 CT Jet Pump Cavity Install 5-26-2002 Size Type Wt/ Grade/ Conn ID Top Btm Depth / Volume 32”Structural Surf 83 Surf 24” Conductor 156, X-42, MTS60AR 19.124 Surf 803 Est TOC 136’ / 210 Bbls 18-5/8” Surface 97, X-56, QTE60 17.653 Surf 2,013 7.9º Est TOC 737’ / 571 Bbls w/ heavy losses 13-3/8” Intermediate 68, K-55, BTC 12.415 Surf 5,836 24.9º Est TOC 2,393’ / 711 Bbls w/ heavy losses 9-5/8”Production 47, L-80, BTC 8.755 Surf 9,526 7610’VDL / 259 Bbls 7”Liner 29, L-80, BTC 6.184 9386 11,275 9,820’ VDL / 150 Bbls Completion Long String Wt / Grade / Conn ID Top Bottom 3-1/2 Prod Tubing 9.2, L80, BTC SC 2.992 Surf 9,304 Short String 3-1/2 Prod Tubing 9.2, L80, BTC SC 2.992 Surf 9,294 2” CT Coiled Tbg 3.075, HS-80 1.688 Surf 9,224 Completion Jewelry Detail # Depth Length ID OD Item Long String 1 50.75 2.950 Cooper 13-5/8” x 3-1/2” x 3-1/2” Tubing Hanger 2 9,304 3.000 3.865 Crossover, 3-1/2” Butt box x 3-1/2” EUE 8rd pin 3 9,305 2.687 7.250 Kobe, 3”, Type “B” Double Parallel, Pump Cavity 4 9,328 3.000 4.500 Crossover, 3-1/2” EUE x 3-1/2” Butt 5 9,329 2.992 3.500 5 jts. 3-1/2”, 9.2#, L-80, Buttress 6 9,487 3.000 4.250 WREG Short String A 9,224 9,179 1.688 2.000 2” Coil Tubing, HS-80 Grade, 0.156” Wall B 9,225 5.85 1.75 2.026 6’ x 2-1/16”, 3.25#, IJ 10rd Pup Joint C 9,231 4.54 1.393 2.260 1-1/2” “Oilmaster” Jet Pump Cavity 2.26” OD X 53” Length w/ 1.393” Min ID @ Standing Valve Seat D 9,235 3.45 1.342 2.200 BOT Model “G-22” Locator Seal Assy. Size 21-18. with 9’ of seal. Landed 3.5’ above top of PBR. 9,239 9.12 1.963 2.540 BOT 10’ PBR 9,248 0.28 1.135 2.625 Otis “N” No-Go Profile, Size 1.25”, 2-3/8” IBTC BxP, 9 Chromaloy 9,249 0.77 1.625 2.700 Crossover,2-3/8” IBTC B x 1.90” NU 10rd P E 9,250 0.43 1.437 2.200 BOT Anchor Latch Seal Assy F 9,250 2.42 1.531 2.765 BOT Packer FA-1 size 35FA20 (E/line Conveyed) G 9,294 1.995 3.500 Crossover, 3-1/2” Butt Box x 2-3/8” 8rd Pin 9,295 1.995 2.375 Pup, 2-3/8”, 4.6#, N-80, 8rd Fill LS:10,991 7/7/05 Tag w/2.20” GR, static survey to 10966 w 3592psi/162F Fill SS:8,260 6/30/06 Tag w/1” tool string & 1-1/4” JDC inside SS (inside CT) 10/10 –After KWF circulation, CT and CT x SS annulus plugged. Unable to freeze protect. No communication from LS to SS FISH None Perforation Data 8,370 11,015 Zones 1-5 All Open (Fill @ 10,991’) PBTD = 11192’ TD = 11275’ MAX HOLE ANGLE = 60O @ 10900’; 5 32” 83’ Float Collar 5752’ TOC VDL 9820’ Tag thru CT in SS @ 9226’ MGS Oil Top 6454’ RKB: MSL =101’ Mudline= 203’ Water Depth= 102’ 13-3/8” 5836’ 9-5/8” 9526’ Top of Perfs 8370’ C E F 2 3 4 1 LOT @ 5885’ = 17.9 ppg EMW 9274’ – 9280’ Tubing Punch 24” 803’ 18-5/8” 2013’ 7” 11275’ Tag Fill thru LS @ 10991’ TOL @ 9386’ Float Collar 1981’ Base MGS Gas 4979’ A B D LOT @ 2041’ = 16.6 ppg EMW BHT = 150 @ 7600’ TVD Pore Psi = 3800 psi @ 9100’ TVD (8.3 ppg EMW) TOC SBT 7600’ Est TOC 2000’ C E F 2 3 4 B D 1 A 5 4 P L U G G E D Mean Sea Level Mud Line ADL: 17595 PTD: 93-120 API: 50-733-20456-00 Leg 1, Slot 2 MGS St 17595 30 WBD_Ba-30 Proposed_20240927 Page 1 of 1 ARD 02-2010 / Updated 12-2010 Offshore Baker Platform Ba-30 N Middle Ground Shoal Cook Inlet Basin, Alaska Middle Ground Shoal Last Completed: 11-16-1997 CT Jet Pump Cavity Install 5-26-2002 Size Type Wt/ Grade/ Conn ID Top Btm Depth / Volume 32”Structural Surf 83 Surf 24” Conductor 156, X-42, MTS60AR 19.124 Surf 803 Est TOC 136’ / 210 Bbls 18-5/8” Surface 97, X-56, QTE60 17.653 Surf 2,013 7.9º Est TOC 737’ / 571 Bbls w/ heavy losses 13-3/8” Intermediate 68, K-55, BTC 12.415 Surf 5,836 24.9º Est TOC 2,393’ / 711 Bbls w/ heavy losses 9-5/8”Production 47, L-80, BTC 8.755 Surf 9,526 7610’VDL / 259 Bbls 7”Liner 29, L-80, BTC 6.184 9386 11,275 9,820’ VDL / 150 Bbls Completion Long String Wt / Grade / Conn ID Top Bottom 3-1/2 Prod Tubing 9.2, L80, BTC SC 2.992 Surf 9,304 Short String 3-1/2 Prod Tubing 9.2, L80, BTC SC 2.992 Surf 9,294 2” CT Coiled Tbg 3.075, HS-80 1.688 Surf 9,224 Completion Jewelry Detail # Depth Length ID OD Item Long String 1 50.75 2.950 Cooper 13-5/8” x 3-1/2” x 3-1/2” Tubing Hanger 2 9,304 3.000 3.865 Crossover, 3-1/2” Butt box x 3-1/2” EUE 8rd pin 3 9,305 2.687 7.250 Kobe, 3”, Type “B” Double Parallel, Pump Cavity 4 9,328 3.000 4.500 Crossover, 3-1/2” EUE x 3-1/2” Butt 5 9,329 2.992 3.500 5 jts. 3-1/2”, 9.2#, L-80, Buttress 6 9,487 3.000 4.250 WREG Short String A 9,224 9,179 1.688 2.000 2” Coil Tubing, HS-80 Grade, 0.156” Wall B 9,225 5.85 1.75 2.026 6’ x 2-1/16”, 3.25#, IJ 10rd Pup Joint C 9,231 4.54 1.393 2.260 1-1/2” “Oilmaster” Jet Pump Cavity 2.26” OD X 53” Length w/ 1.393” Min ID @ Standing Valve Seat D 9,235 3.45 1.342 2.200 BOT Model “G-22” Locator Seal Assy. Size 21-18. with 9’ of seal. Landed 3.5’ above top of PBR. 9,239 9.12 1.963 2.540 BOT 10’ PBR 9,248 0.28 1.135 2.625 Otis “N” No-Go Profile, Size 1.25”, 2-3/8” IBTC BxP, 9 Chromaloy 9,249 0.77 1.625 2.700 Crossover,2-3/8” IBTC B x 1.90” NU 10rd P E 9,250 0.43 1.437 2.200 BOT Anchor Latch Seal Assy F 9,250 2.42 1.531 2.765 BOT Packer FA-1 size 35FA20 (E/line Conveyed) G 9,294 1.995 3.500 Crossover, 3-1/2” Butt Box x 2-3/8” 8rd Pin 9,295 1.995 2.375 Pup, 2-3/8”, 4.6#, N-80, 8rd Fill LS:10,991 7/7/05 Tag w/2.20” GR, static survey to 10966 w 3592psi/162F Fill SS:8,260 6/30/06 Tag w/1” tool string & 1-1/4” JDC inside SS (inside CT) 10/10 –After KWF circulation, CT and CT x SS annulus plugged. Unable to freeze protect. No communication from LS to SS FISH None Perforation Data 8,370 11,015 Zones 1-5 All Open (Fill @ 10,991’) PBTD = 11192’ TD = 11275’ MAX HOLE ANGLE = 60O @ 10900’; 5 32” 83’ Float Collar 5752’ TOC VDL 9820’ Tag thru CT in SS @ 9226’ MGS Oil Top 6454’ RKB: MSL =101’ Mudline= 203’ Water Depth= 102’ 13-3/8” 5836’ 9-5/8” 9526’ Top of Perfs 8370’ C E F 2 3 4 1 LOT @ 5885’ = 17.9 ppg EMW 9274’ – 9280’ Tubing Punch 24” 803’ 18-5/8” 2013’ 7” 11275’ Tag Fill thru LS @ 10991’ TOL @ 9386’ Float Collar 1981’ Base MGS Gas 4979’ 80 bbl cement down LSxIA 8 bbl cement down CTxSS Est TOC ~8100’ Punch holes in CT ~9200’ A B D LOT @ 2041’ = 16.6 ppg EMW BHT = 150 @ 7600’ TVD Pore Psi = 3800 psi @ 9100’ TVD (8.3 ppg EMW) TOC SBT 7600’ Est TOC 2000’ 1 A 555 Mean Sea Level Mud Line ADL: 17595 PTD: 93-120 API: 50-733-20456-00 Leg 1, Slot 2 MGS St 17595 30 Cement to be laid in with CT from top of fill @ 10991' to tubing tail at 9487' md. See CoA. -bjm 1 McLellan, Bryan J (OGC) From:Casey Morse <casey.morse@hilcorp.com> Sent:Friday, May 30, 2025 1:29 PM To:McLellan, Bryan J (OGC) Cc:Juanita Lovett; Wyatt Rivard Subject:RE: [EXTERNAL] MGS 17595-30 (PTD 193-120) suspension sundry Bryan, The cement volumes are based on a target TOC of 8100’. It looks like some of the text in the backup calcs pulled through an older version of the document with reference to the 7500’ target depth, but the calculations all factored in the 8100’. Below is the corrected text for this section of the sundry: ¾ LS volume from tubing tail to 8100’: 0.0078 bpf * (9487’-8100’) = 12 bbls ¾ IA volume from tbg tail to 8100’ = 68 bbls o 9487 to 9386: 0.0252 bpf * 101’ = 3 bbls (tubing tail x liner) o 9386 to 9305: 0.0626 bpf * 81’ = 5 bbls (tubing tail x 9-5/8) o 9305 to 8100: 0.0494 bpf * 1205’ = 60 bbls (LS/SS x 9-5/8) ¾ CT volume from 9200 to 8100: 0.0028 bpf * 1100’ = 3 bbls ¾ SS volume from 9200 to 8100: 0.0048 bpf * 1100’ = 5 bbls ¾ LS volume from 8100’ to surface: 0.0087 bpf * 8100’ = 70 bbls ¾ IA volume from 8100’ to surface: 0.0494 bpf * 8100’ = 400 bbls ¾ CT volume from 8100’ to surface: 0.0028 bpf * 8100’ = 22 bbls ¾ SS volume from 8100’ to surface: 0.0048 bpf * 8100’ = 39 bbls To your third point, we did not include any explanation for future utility for this well. It is our intention to fully abandon the well once we agree upon a procedure. Thanks, Casey Morse Operations Engineer Cook Inlet OƯshore Hilcorp Alaska, LLC (907) 777-8322 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, May 28, 2025 4:47 PM To: Casey Morse <casey.morse@hilcorp.com> Subject: [EXTERNAL] MGS 17595-30 (PTD 193-120) suspension sundry CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Casey, A couple of questions and points on this sundry application. 1. The calculations for cement and cement displacement show some discrepancies on cement top, some showing it at 7500’ MD and others at 8100’ MD. Could you verify which TOC is correct? 2. I will add a condition of approval to lay in cement with CT from top of Ʊll in the 7” casing per 20 AAC 25.112(c)(1)(C). 3. This will be a suspension sundry. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MGS ST 17595 30 JBR 10/08/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Good test once thet got started. Test Results TEST DATA Rig Rep:Jeremy HartOperator:Hilcorp Alaska, LLC Operator Rep:Jack Cho Rig Owner/Rig No.:Fox 9 PTD#:1931200 DATE:8/8/2025 Type Operation:WRKOV Annular: Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopJDH250810154615 Inspector Josh Hunt Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 2 MASP: 2920 Sundry No: 324-561 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 0 NA Inside BOP 0 NA FSV Misc 0 NA 5 PNo. Valves 2 PManual Chokes 0 NAHydraulic Chokes 0 NACH Misc Stripper 1 1.75"P Annular Preventer 0 NA #1 Rams 1 Blind/Shear P #2 Rams 1 1.75" Pipe Sli P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 2 2" MSI P HCR Valves 0 NA Kill Line Valves 2 2" MSI P Check Valve 0 NA BOP Misc 0 NA System Pressure P2900 Pressure After Closure P2300 200 PSI Attained P5 Full Pressure Attained P62 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)NA ACC Misc NA0 NA NATrip Tank NA NAPit Level Indicators NA NAFlow Indicator NA NAMeth Gas Detector NA NAH2S Gas Detector 0 NAMS Misc Inside Reel Valves 1 P Annular Preventer NA0 #1 Rams P10 #2 Rams P10 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke NA0 HCR Kill NA0      Middle Ground Shoal Baker Platform Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / O/~.-/¢~) File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs-of various kinds Other COMMENTS: Scanned by ianna Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ ') 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 . ". O\i K\ 8 2(\135 SCANNEO N , u Commissioner John Norman Alaska Oil & Gas Conservation Commission 333 W. th Avenue Anchorage, Alaska 99501 Re: Baker Platform Pilot Pre-Abandonment Work Summary { Cf3-l~o 8vt"·-ao Dear Commissioner Norman, This letter is intended to update the Alaska Oil and Gas Conservation Commission on the status of Unocal's pilot pre-abandonment work on the Baker Platform in Cook Inlet, Alaska. On October 22, 2004, Unocal proposed that a pilot program be initiated on the Baker platform to develop a safe, cost effective, and optimal method for the abandonment of multiple well bores. As noted in the letter of October 22, 2004, Unocal has operated the Baker and Dillon Platforms under a "lighthouse" mode where all oil and gas production has been shut-in. The Dillon Platform was shut-in December 2002 and the Baker Platform was shut-in August 2003. Unocal commenced the pilot study with a di~gnostic program on five water injection wells and three oil wells on the Baker Platform in July 2005. THe diagnostic program consisted of pressure and temperature surveys for baseline data, mechanical integrity of the completion, injectivity tests to the formation, and pressure measurement on the outer casing annuli. The injection wells initially surveyed were Baker 7, 8rd, 12, 15rd, and 27. The oil wells surveyed were Baker 13, 28, and 30. Unocal did not anticipate that any of the oil wells on the Baker platform would have a bottom hole pressure (BHP) gradient exceeding seawater. However, when it was discovered that Baker well 28 had a static BlIP 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 Platform Well BHP Summary is attached. The Dillon well BHPs are all below a seawater gradient of 8.4 ppg. No additional diagnostic well work on the Dillon platform has been initiated. r'\~J.n' ,:r AcoJ. E ',,_ :- ~_ ~ ~~; 1-\ 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 501 and in the gas well Baker 32. In light of the Chevron Corporation acquisition of Unocal, the well plugging operations for the oil wells on the Baker platform has been omitted from the 2005 pilot program to allow time to reassess economic potential under Chevron's criteria. Furthermore, the gas potential from the Baker is also being re-assessed. To better prepare for the winter, Chevron will be applying heat on both the Baker and Dillon platfonns. 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, -¿:gc·-A~·7 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..Jul-05 7080··· $()66 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-Jul-05 8841 8499 2584 0.304 5.8 Ba-25rd Producer 22-Jul-05 9495 9033 3208 0.355 6.8 Ba-27 Injector 6-Jul-05 7779 5999 2928 0.488 9.4 Ba-28 Producer 3-Jul-05 8441 5308 2497 0.470 9.0 Ba-29 Producer 28-Jul-05 7923 7594 2165 0.285 5.5 --7Ba-3O Producer 4-Jul-05 10966 9109 3593 0.394 7.6 - Ba-31 Producer 29-Jul-05 11433 10636 3795 0.357 6.9 Ba-32 Producer No survey ) .' ~7~~~ :~ !Æ~!Æ~~!Æ AT1A-SKA OIL AND GAS CONSERVATION COMMISSION Mr. Dave Cole Oil Team Manager UNOCAL P.O. Box 196247 Anchorage, AK 99516-6247 Re: Middle Ground Shoal Unit Platforms Dillon and Baker Dear Mr. Cole: ) FRANK H. MURKOWSK/, GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 . '1--0 t~0/ I cr This letter confirms your conversation with COllunission Engineer Tom Maunder last week regarding the multiple Applications for Sundry Approval (Form 403) you submitted in mid October regarding changing the monitoring frequency on the 16 wells on Dillon Platform and 23 wells on Baker Platform. Production and injection operations were halted on these platforms in 4th Q 2002 and 2nd Q 2003 respectively. Attached, please frod the Sundry Applications, which are being returned without approval~ because the relief you request needs to be sought through a different procedure. The intent of submitting sundry notices for each well was to establish a monthly pressure and general monitoring frequency for all wells on Dillon and Baker. There is a requirement in place for some of the water injection wells that pressures and rates are to be monitored daily and reported monthly. Since the platforms are unmanned and not operating, it is not possible to obtain daily information. When operations were curtailed, a monthly monitoring frequency was established in the Plans of Development (POD) annually filed with the Division of Oil and Gas and Unocal desires to assure that this monitoring scheme is accepted by the Commission. As noted in the conversation, changing the monitoring frequency where presently in place and establishing a monthly monitoring frequency in general is not an action that is best accomplished with multiple sundry notices. A letter application requesting the desired monitoring schedule should be made under the applicable Area Injection Orders (AlO 7 for Baker and AIO 8 for Dillon) and Conservation Orders (CO 44 and CO 54) for the platforms/unit. The Commission looks forward to receiving your letter applications. If prior monthly monitoring information has not been submitted to the Commission, that information should be ubmitted forthwith. ~, smcer~~ . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this _day of November, 2004 Enel. SCANNED NOV 2. 4 2004 Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Union Oil of California aka Unocal 1. Type of Request: 3. Address: 909 West 9th Ave. Anchorage AK 99501 7. KB Elevation (ft): 118' 8. Property Designation: BAKER 11. Total Depth MD (ft): 11,275' Casing Structural Total Depth TVD (ft): 9,271' Length Conductor Surface 749' 1960' 5783' Intermediate Production 9,473' Liner Perforation Depth MD (ft): \ STATE OF ALASKA ) ALA~..A OIL AND GAS CONSERVATION COMMISSION 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 TubingD Perforate U Waiver U Annular Dispos. U Stimulate 0 Time Extension D Other 0 Re-enter Suspended Well D Monitor Frequency 5. Permit to Drill Number: Development Stratigraphic 0 D Exploratory D 1931200 Service D 6. API Number: 50.733.20456.00 11,245' /' /" // // ~/ / // /// Plugs (me~ured): 1/ / TVD / ,/ ;2,011' 1/ 5,466' 8,294' / 8,268' - 9,271' Tubing Grade: SS: .5" Both: 9.2# L-80 Pa ers and SSSV MD (ft): 9. Well Name and Number: Ba-30 10. Field/Pools(s): Middle Ground Shoals PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 9'255' Size MD Burst Collapse 24" 803' 2013' 5836' 9526' 9386'.11275' Tubing Size: 2250 psi 630 psi 3,450 psi 1,950 psi 6,870 psi 4,760 psi 8,160 psi 7,020 psi Tubing MD (ft): LS: 9,486 SS 9,295 18-5/8" 13-3/8" 9-5/8" 1889' 7" Perforation Depth TVD (ft): 7,607 to 9,134 LS : 3.5" KOBE "BB" 3" Cavity @ 9305', SS Set in SS: BOT "FA.1" pkr @ 9250', 1- 1/2" OilMaster Cavity @ 9231'. 12. Attachments: Description Summary of Proposal 2J Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 8,370 to 11,015 Packers and SSSV Type: 16. Verbal Approval: Date: Abandoned WDSPL D D 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil 0 GasD WAG D GINJ D 0 Service D D D Plugged WINJ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the b Printed Nail Y'J. . ~Ie. Signatu~/atl4- t of my knowledge. Contact Title Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY 27-Sep-2004 3D4' - Lf 3:?5 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test D Other: Subsequent Form Required: Approved by: ¥ð.$ Form 1 O~Revised 12/2003 Sundry Number: Mechanical Integrity Test D Location Clearance 0 RBDMS BFL NOV 2 2 2004 APPLICATION RETURNED 11/17/04 NOT APPROVED BY COMMISSION \G\NAL . BY ORDER OF COMMISSIONER THE COMMISSION Date: Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL.OPERATIONS 1. Operations performed: Operation shutdown: Pull tubing: 2. Name of Operator Union Oil of California (Unocal) 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 Plugging: Perforate: Repair well: X Other: 5. Type of Well: 6. Datum elevation (DF or KB) Development: X 118' RKB above MSLfeet 7. Unit or Property name Chakachatna MGS 4. Location of well at surface 1932' FNL, 539' FWL, Sec. 31, T9N, R12W, SM At top of productive interval 809' FSL, 368' FWL, Sec. 30, T9N, R12W, SM At effective depth At total depth 1871' FSL, 2449' FWL, Sec. 30, T9N, R12W, SM 12. Present well condition summary Total depth: measured 11,275 feet true vertical 11,275 feet Plugs (measured) 8. Well number Baker # 30 9. Permit number/approval number 93-120 10. APl number'" 50- 733-20456-00 11. Field/Pool Middle Ground Shoals, G Pool Stimulate: Alter casing: Exploratory: Stratigraphic: Service: Effective depth: measured 11,245 feet Junk (measured) true vertical 9,241 feet Casing Length Size Cemented Measured depth Structural 749' 24" 2263 cf 803' Conductor 1960' 18-5/8" 3164 cf 2013' Surface 5783' 13-3/8" 3995 cf 5836' Intermediate Production 9508' 9-5/8" 1454 cf 9562' Liner 1889' 7" 843 cf 9386'- 11275' Perforation depth: measured See Attachment True vertical depth 799' 2O09' 5465' 8317' 9271' true vertical See Attachment Tubing (size, grade, and measured depth) LS= 3-1/2" 9.2# L-80 @ 9304' SS= 3-1/2" 9.2# L-80 @ 9294' w/2", 0.156", HS-80 coil tubing ran concentrically to 9224'. Packers and SSSV (type and measured depth) Bad 3" Cavity @ 9305', Set in SS: BOT "FA" pkr @ 9250', 1-1/2" OilMaster Cavity @ 9231'. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments: Copies of Logs and Surveys run: Daily Report of Well Operations: 16. Status of well classification as: Oil: X Gas: Suspended: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Form 10-404 Rev 06/1 Title: Baker 30 Perforations Zone Top-1 G-1,2,3 G-3 G--3 G-4 G-5 G-5,4 G-4,3,2,1 G-1 G-1 G-1 G-1 G-1 Top-1 Interval MD 8,370' 8,575' 8,729' 8,844' 8,852' 8,860' 8,876' 9,043' 9,046' 9,140' 9,158' 9,578' 9,617' 9,960' 10,120' 10,195' 10,470' 10,554' 10,585' 10,655' 10,690' 10,740' 10,705' 10,837' 10,860' 10,873' 10,945' 11,015' Interval TVD 7,6O8' 7,734' 7,818' 7,880' 7,884' 7,889' 7,897' 7,990' 7,991' 8,047' 8,058' 8,329' 8,355' 8,560' 8,656' 8,700' 8,854' 8,897' 8,913' 8,949' 8,967' 8,992' 8,974' 9,042' 9,054' 9,061' 9,098' 9,134' SCANNED JUN ~, .~: 2002: 21 -May-02 22-May-02 23-May-02 24-May-02 25-May-02 26-May-02 Baker Ba-30 Daily Report of Operations May 21 to May 26, 2002 RU slickline onto SS. Run 2.86" GR to XO @ 9274'. Run 2.77" x 3.05' Dummy Pkr to XO @ 9274'. Flush SS w/102 bbls of power oil. Fluid level @ 800'. SDFN. RU APRS E/line. RIH w/1-9/16" tbg punch gun. Perf tbg f/9274' to 9280'. POOH. RIH w/BO'I- model "FA" pkr w/shear-out plug. Set pkr @ 9250'. POOH. Attempt to pressure test pkr to 600 psi. No good. Tbg on vacuum. SDFN. RU E/line. RIH w/1" CCL tool string. Set down on plug @ btm of pkr. POOH. RU slickline. RIH w/seal assy. Stab into pkr @ 9250'. Pressure test SS to 1000 psi f/ 15 min. Bleed off pressure. POOH w/seal assy. RIH w/1.25" BB. Set down on plug in pkr @ 9250'. Beat down 4 times. Sheared/knock plug free. POOH. RD. RU slickline. RIH w/"K" anchor, "N" profile w/plug & PBR assy. Latched isolation assy into pkr. POOH. Tested tbg to 1000 psi. RD slickline. NU CT hngr spool & XO's. Lock-out/Tag-out of Master valves. RU 2" Coil Tubing Unit. MU seal assy, 1-1/2" Jet Pump Cavity, pup jt & CTC. RIH w/completion BHA on 2", 0.156" wall, HS-80 CT. Locate/stab seals into PBR. PU space out, install segmented CT hngr. RI land CT. Test hangr to 1500 psi. Cut CT. ND CT BOPE, Window & injector head. Made final cut on CT. Install wireline entry guide. NU Swab valve. RU slickline. RI CT latch retrieve isolation sleeve. RIH latch retrieve prong. RIH latch & retrieve plug in "N" nipple. RD. Release Coil unit. SCANNED jUN !;::~a k e r Platform :,~ell No. 30 Original Completion Date 11/16/97 CT Jet Pump Cavity Installed 5/26/02 Rig 428 RKB to TBG Head = 50.75' 428 RKB to CT Hn: · = 45.25 PBTD= 11,192' TD= 11,275' MAX HOI,E ANGLE = 60° (~) 10 900' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP [ BTM. 32" Structural Surlhce I 83~ 24" 156 X42 M FS60AR 19 t 24 Surlhce 800' 18-5/8" 97 X-56 QTE60 17.653 Sm'face 2013' 13-3/8" 68 K-55 BTC 12.6t5 Surthce 5,836' 9-5/8" 47 L-80 BTC 8.755 Surface 9,526' 7" 29 L-80 BTC 6.184 ¢,~86 I 1.275' Tubing 3-I/2" I 9._~ L-80 BTC SC 2992 9,304' Short String I 3-I/2" 192 L-80 BTCSC 2.992I 9.294' 2" Cod Tbg 3.075 HS-80 0 [56" ~all 1688 Surf 9224' JEWELRY DETAIL NO__:~' Depth ] ID I~ Item Long String I 50.75 2.950 Cooper 13-5/8" x 3-1/? x 3-1/? Tubing Banger 2 9.304' 300 3865 Crossover. 3 I/2" Buttress Box x EUE 8 rd Pin 3 I 9.305' 2687 7250 Kobe. 3", fype '~B" Double Parallel Pump Cavi~ 4 9.~8 3.00 45 Crossover, 3-1/2" EUE Pin x Buttress Pin 5 9,329' 2 992 350 5 its 3-I/2'. 9 2#, L-80, Buttr~s 6 9.486' 300 4.250 Wireline Ent~. Guide Short String A. 45' to 9224' 1688 20 2" Coil Tubing. IdS-S0 Grade, 0.156" Wall B. 9225' 175 2.026 6' x 2-1/16", 325~, lJ (0rd Pup Joint ~'. 923 t' 1393" 226 1-I/2" ~Oihnaster" .let Pump Cavity 2.26" OD X 53" Length w/1.393" Min ID ?re Standing Valve Seat D 9235' 1.342 220 BOT Model ;'G-22" I.ocator Seal Assy Size 21-18 witb 9' of seal Landed 3.5' above top of PBR. 9239' 1963 2.54 BOT 10' PBR PERFORATION HISTORY Zone Top Btm SPF [ Date Comments 8414 8522 6 2/94 8532 8575 6 2/94 8729 874t 6 2/94 8750 8844 6 2/94 8852 8860 6 2/94 8876 9043 6 2/94 9046 9140 6 2/94 9158 9376 6 2/94 9385 9578 6 2/94 9617 9960 6 2/94 t0,470 t0.554 6 2/94 Ba-30 Actual Scl= 5-25-02 AOGCC !udividual Well Geological Materials Inventory Page ' 1 Date ' 10/13/95 PERMIT DATA T DATA_PLUS RUN DATE_RE CVD . 93-120 ~086 T 1900-10700, OH-MAIN 04/21/94 93-i'~0 ~ nRY DITCH S 2040-1i275 04/19/94 93-120 ~/~ R COMP DATE:02/27/94 07/08/94 93~120 p. DAILY WELL OP R 09/28/93-03/01/9A 07/08/9A 93-120 ~RVEY R 0.00-11275 07/08/94 9R-!20 ~CA/GR/CAL L 1930-10645 1-3 04/21/94 93-120 ~qCA/GR/CAL L 1930-106~5 1-3 04/21/94 e3-1~0~ ~ ~eDL/CNL/GR/CAL L !930-i0n02. 1-3 04/2i/94 93-120 ~D~/CN,,,,~R~.A~ L 1930-10~02 1-3 04/21/94 9o-120 a=~u~/~-~ L 1930-I0~45 1-3 04/21/94 93-!20 p~FL/GR L 1930-10645 1-3 04/21/94 93--120 LMTJb L 2041-11275 04/21/94 93~120 /~,/,/,/,/,/,/,/,/~~T/~G~. L 7390-11180 1 04/21/94 Are dry ditch samples required? yes ~ And received? Was the 'well cored? yes An~.lysis & description received.? - yes---~e Are we±~ test~ z,=.qm~_e~.. /lyes Received? Well is in compliance _~ Initial COMMENTS -~--- STATE OF ALASKA ALA;. OIL AND GAS CONSERVATION COty' ~SiON WELL COMPLETION OR RECOMPLETION h, PORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS ~-] SUSPENDED[-] ABANDONED~-] SERVICE[~ 2. Name of Operator 7. Permit Number UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 93-120 3. Address ? ................... ~ 8. APl Number 1932' FNL & 539' FWL Section 31, TgN, R12W, SM P.O. BOX 196247 ANCHORAGE, AK 99519'~'~ ~;~/_~/~.~ ,...: , 50-733-20456 4. Location of well at surface Baker Plal~orm, Leg #1 Slot #2i 9. Unit or Lease Name ' At Top Producing Interval 8414' MD/7637' TVD ~-~.-~=~;~ ~ ~ 10. Well Number 809' FSL & 368' FWL Section 30, ~~~_~. - #30 At Total Depth 11275' MD/9271' TVD ii ~ " ~ 11. Field and Pool E, F, & G Pools 5. Elevation118'KB in feet (indicate KB, DF, etc.) 6. Lease DesignationADL 17595 and SeriaJ No. 12. Date Spudded 09/28/93 13. Date T.D. Reached 02/21/94 114' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re l 16' N°' °f C°mpleti°ns 102/27/94 102 Feet MS L 1 22. lype Eloc~'i¢ or Other logs Run DILJGR/SP/DEN/N EU/SONIC/SBT- G R 7" 29 L-80 9386' 11275' 8-1/2" 843 CU.FT. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE I DEPTH SET (MD) I PACKER SET (MD) 3-1/2". 9.2#, L-80 (~ 8299' NA See Attached 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED N/A ~7 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) N/A I Date of Test Hours Tested PRODUCTION FOF OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I I TEST PERIOD ...... FlowTubing Casing Pressure i CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVlTY-API (corr) Press. I 24-HOUR RATE --- 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. JUL. '"g ..,".,-..~!~sl¢ ()ii & Gas 6or~s. · -~. _Anchorage Form 10-407 Submit in duplicate rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS NAME 31. LIST OF ATTACHMENTS MEAS, DEPTH TRUE VERT. DEPTH 30. , ,.,RMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and lJrne of each phase. 32. I hereby/c~ertify that the foregoing is true and correct to the best of my knowledge Signed G. RUSSELLSCHMIDT TrUe DRILLING MANAGER INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). item 23: Attached supplemental records forthis 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 jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate 'none'. 32" Structural @ 83' BLM 24" Conductor @ 803' 156#, X-42, MTS60AR 18-5/8" Surface @ 2013' 97#, X-56, QTE60 COMPLETION DESCRIPTION 1) Dual 3-1/2", 9.2#, L-80, SCBTC 2) KOBE BHA F/8299'-8325' 3) TCP guns 4-5/8" OD F/8414'-10860' @ INTERVALS RKB = 118' 13-3/8" Intermediate @ 5836' 68#, K-55, BTC TOL @ +/-9386' 9-5/8" Production @ 9562' Hemlock @ Intervals + 1000' 7" L @ 11275' 29#, L80, BTC BAKER 3O ACTUAL COMPLETION UNOCAL ENERGY RESOURCES ALASKA DRAWN' CLL DATE: 6-10-94 FILE: BA30.drw Baker 30 Perforations Open to Production July 7, 1994 Measure Depth 8414'-8522' 8532'-8575' 8729'-8741' 8750'-8844' 8852'-8860' 8876'-9043' 9046'-9140' 9158'-9376' 9385'-9578' 9617'-9960' 10470'-10554' 10705'-10837' 10860'-10873' Total Perforations 1509' UNOCAL DALLY HISTORY BAKER #30 BAKER PLATFORM DAY 1 (09/28/93) SKID RIG TO SLOT #2, WELL #30. ACCEPT RIG @ 08:30 HRS. NU 30" RISER & PU CENTER-PUNCH BHA. RIH, TAG BTM AT 184'. REPAIR RIG, DN 1.5 HRSo C/OUT COND F/184'-302', LARGE AMT OF JUNK & TRASH. UNABLE TO C/OUT DEEPER. POOH, JUNK BASKET HAD LARGE PIECES OF JUNK STEEl_ BAKER PLATFORM DAY 2 (09/29/93) MU BLADED JUNK MILL & RIH. MILL JUNK F/302'-317'. POOH, EMPTY JUNK BASKET. RIH W/SAME BLADED JUNK MILL. MILL TO 325', POOH. MU DRLG BHA & RIH TO 325'. RIH F/GYRO SURVEY. DIREC DRILLED 17-1/2" HOLE F/325'-608', PROXIMITY TO OTHER WELLS IS TIGHT. BAKER PLATFORM DAY 3 (09/30/93) DRILLED 17-1/2" HOLE F/608'-825'. POOH. MU UR BHA & RIH. UR HOLE TO 30" F/307'-455'. DAY 4-6 (10/01-03/93) UNDERREAM 17.5" HOLE TO 30" FROM 455' TO 815'. POOH HAD PROBLEMS AT 32" SHOE @ 303'. RAN MILL ASSY WORKED BAD SPOT AT SHOE. RUN 24" CASING TO 341' WHERE IT HUNG UP. PULLED CASING. RAN 25.2" MILL ASSEMBLY ROTATE AND MILL SHOE AT 303'. RIH TO 815' CIRCULATE. POOH MILL HUNG UP AT 303'. RAN 25.2" MILL AND 24" STABILIZER. ROTATED AND MILL SHOE AT 303'. POOH. RAN 24" CASING TO 369' WHERE IT PLUGGED INTERNALLY. RAN INNER STRING TO CLEAN OUT. POOH W/INNER STRING. RAN CASING TO 803' AND LANDED ON LAND RING AT SURFACE. DAY 7 (10/04/93) RIH WITH INNER STRING CEMENT STINGER. STAB IN CIRCULATE WELL AND PERFORM CEMENT JOB W/GOOD CEMENT RETURNS TO SURFACE. WASH OUT CASING HEAD, N/D RISER. INSTALL BLIND FLANGE, TEMP. SUSPEND OPERATIONS ON BAKER NO. 30 AT 12:00 HRS ON 10/4/93. ,.! U l.. "' 8 'i9 9 ¢i. ~.~ .-,~-, r~i, a Gas Co~'is. (;ommission _ :, ~.,-. ,,.,. ., ¢&nchorage UNOCAL DALLY HISTORY BAKER #30 DAY 8-9 (10/23-24/93) SKID RIG #428 TO BA #30. NU BOP & TEST SAME, INCURRED 3 HRS DN TIME. MU CENTER-PUNCH BHA & RIH TO 676'. REPAIR STD PIPE, 2.5 HRS DN TIME. PRESS TEST CSG TO 1000 PSI F/5 MIN, OK. DRLD HARD CMT F/677'- 835'. CBU. PERFORM LOTTO 15.9 PPG EMW (.83 PSI/F0. POOH. MU DRLG BHA & RIH. DIREC DRILLED 17-1/2" HOLE F/835'-1206'. DAY 10 (10/25/93) DRILLED 17-1/2" HOLE F/1206'-2031'. CBU. POOH. DAY 11 (10/26/93) MU 24" UR BHA & RIH TO 806'. UR 17-1/2" HOLE TO 24" F/806'-1965'. DAY 12 (10/27/93) POOH. RAN 18-5/8" CASING. MADE UP HANGER, CIRCULATED PIPE DOWN AND LANDED WITH SHOE AT 2013'. CIRCULATED WELL. RAN INNER CEMENTING STRING; ENGAGED SEALS AND CEMENTED CASING WITH 450 BBLS LEAD SLURRY AT 12.9 PPG AND 121 BBLS TAIL SLURRY AT 15.8 PPG. (LOST RETURNS AFTER PUMPING 327 BBLS OF LEAD SLURRY; COMPLETED JOB WITH NO RETURNS). FLOAT CHECKED OK. CLEARED AND POOH WITH INNER CEMENTING STRING. DAY 13 (10/28/93) P/U 5" DP. P/U DTU DIRECTIONAL DRILLING BHA. RIH, TEST 18-5/8" CASING TO 2000 PSlo DRILL SHOE TRACK AND 10' OF FORMATION TO 2041' PERFORM FIT TO 780 PSI, 18.1 PPG EMW, FRAC GRAD OF .94 PSI/FT. DIRECTIONALLY DRILL 17-1/2" HOLE TO 2049'. DAY 14-16 (10/29-31/93) DRILLED 17-1/2" HOLE F/2049'-3031'. POOH F/BHA, EXPERIENCE DP GALLING PROBLEMS. TEST BOPE. MU BHA & RIH. DRILLED F/3031'-3163', MWD TOOL FAILED. POOH. UNOCAL DALLY HISTORY BAKER #30 DAY 17 (11/01/93) MU BHA W/BACKUP MWD TOOL, FUNCTION TEST SAME, NEGATIVE. WAIT ON NEW MWD TOOL & SERVICE RIG, FOUR HRS. MU BHA W/NEW MWD TOOL & RIH. DRILLED 17-1/2" HOLE F/3163'-3364'. BHA BLDG INCLINATION, POOH. DAY 18 (11/02/93) CONT POOH. MU BHA & RIH TO 3364'. DRILLED 17-1/2" HOLE F/3364'-4036'. CBU. DAY 19 (11/02/93) CONT CBU. POOH TO CK TOOLS, ALL TOOLS OK. MU MTR BHA & RIH. DRILLED 17-1/2" HOLE F/4036'-4387', LOSS PUMP PRESS & 20 K WT. POOH. DAY 20 (11/03/93) POOH, 70' OF FISH IN HOLE. STAB ON TOP MWD BROKE. TOF AT 4317'. SERVICE RIG & WAIT ON FISHING TOOLS. MU FA #1 & RIH. ENGAGE TOF AT 4317', PULL UP HOLE TO 4311'. FISH FELL LOOSE. RE-ENGAGE FISH SEVERAL TIMES, COULD NOT HOLD ONTO FISH. POOH. CHG OUT GRAPPLE TO 8-7/8" ID & RIH W/FA #2. A~I'EMPT TO ENGAGE FISH, NEGATIVE. APPEARS TO BE ALONG SIDE OF FISH. POOH. PU 16.5" STAB & MU FA #3. RIH, ENGAGE FISH AT 4317'. WORK & CIRC FISH FREE. DAY 21-23 (11/05-07/93) POOH (SLOW). REC'D 100% OF FISH. MU DRLG BHA & RIH. DRILLED 17-1/2" HOLE F/4387'-4704'. ST TO CSG SHOE. REPAIR RIG. RIH & CONT DRLG F/4704'-5116'. ST TO 4112', HOLE OK. DAY 24 (11/08/93) DRILLED TO 5229'. A'I-I'EMPT TO PU, NEG. STUCK ON BO'rTOM AT 5229'. JAR ON FISH, NEG. RIH W/FREE PT SURVEY, FREE TO 5063' (TOP STAB). A'I-I'EMPT TO BACK OFF AT 5033' TWICE, NEG. A'I-I'EMPT TO BACK OFF AT 5001', OK. POOH, LY DN DC & JARS. MU FA #1. UNOCAL DALLY HISTORY BAKER #30 DAY 25 (11/09/93) CONT MU FA #1 & RIH. TAG TOF AT 5001', SCREW-IN SAME, JAR ON SAME. JAR FISH FREE & CIRC SAME. POOH, LY DN TOOLS & PART OF BHA, (100% RECOVERY). TEST BOPE. PREP TO PU BHA. DAY 26 (11/10/93) MU BHA (ROTARY) & RIH WHILE PU EXTRA DP. REAM F/4831'-5231'. DRILLED 17-1/2" HOLE F/5231'-5333'. MECH PROBLEMS W/TOPDRIVE UNIT. DRILLED TO 5346', MORE PROBLEMS W/TOP DRIVE. PULL TO CSG SHOE. PURSUE PROBLEM W/TOP DRIVE. DAY 27 (11/11/93) CORRECT TOP DRIVE ELEC/SCR PROBLEM. DRILLED 17-1/2" HOLE F/5346'- 5503'. PMP HI-VIS SWEEP. DRILLED F/5503'-5690'. DAY 28-30 (11/12-14/93) DRILLED 17-1/2" HOLE FROM 5760' TO 5843' PENETRATION RATE SLOWED. POOH. RAN ATLAS CN/CDL/BHC-AC/DISL/GR LOG, ON RUN 2 RAN DIPMETER. RAN BOTH LOGS FROM BOTTOM AT 5835' WLM TO 2013'. RIH WITH WIPER TRIP ASSY. TO 5843' DRILL TO 5871' HIGH TORQUE AND LOW PENETRATION RATE° POOH TO RUN CASING. R/U TO RUN 13-3/8" CASING, RIH WITH CASING. DAY 31 (11/15/93) RUN & CMT 13-3/8", 68#, K-55 CSG TO 5836'. CMT CSG W/3300 FT3 OF 12.9 PPG LEAD CMT & 695 F'P OF 15.8 PPG TAIL CMT. CIP AT 1345 HRS, PARTIAL CMT RETRNS EST NET 60%. REM LANDING JT & RIH W/WASH TOOL TO CLEAN WELLHEAD. MU SEAL ASSY & RIH. SET SEAL ASSY W/20K OVERPULL & PRESS TEST TO 3000 PSI, OK. UNOCAL DALLY HISTORY BAKER #30 DAY 34 (01/26/94) 24"@ 803' 18-5/8" @ 2013' 13-3/8"@ 5836' 9.1 PPG SKID R428 F/BAKER 29. RESUME WELL CPS ON BAKER #30 AT 0000 HRS 01/26/94. NU 13-5/8" 5M BOP, TEST SAME. MU MILL & RIH TO 3539', DRLG FLOW NIPPLE NEEDS REPAIR. POOH. REPAIR DRLG NIPPLE. RIH, TAG TOC AT 5696'. DRLD CMT F/5696'-5738'. PRESS TEST CSG TO 2700 PSI F/30 MINS, OK. DRILLED TO 5824', REPF_AT PRESS TEST F/10 MINS, OK. DAY 35 (01/27/94) 24" @ 803' 18-5/8"@ 2013' 13-3/8" @ 5836' 9.3 PPG DISPLACE WELL FLUID TO PHPA MUD SYSTEM. CCM. DRILLED CMT & CSG SHOE F/5824'-5844'. POOH F/DRLG ASSY. RIH, DRILLED CMT & NEW HOLE TO 5885'. PERFORM LOTTO 17.9 EMW. DRILLED 12-1/4" HOLE F/5885'-6032'. DAY 36-38 (01/28-30/94) 24" @ 803' 18-5/8"@ 2013' 13-3/8" @ 5836' 9.4 PPG DRILLED 12-1/4" HOLE F/6032'-6478', ST TO CSG SHOE W/TIGHT HOLE AT INTERVALS. DRILLED F/6478'-7062', ST TO CSG SHOE, BACKREAM AT INTERVALS. DRILLED TO 7158'. DRILLED LARGE (155') COAL SF_AM F/6985'- 7140'. POOH F/BHA & BIT CHG. MU BHA & RIH REAM F/7007'-7158'. DRILLED F/7158'-7357'o UNOCAL DALLY HISTORY BAKER #30 DAY 39 (01/31/94) 24"@ 803' 18-5/8" @ 2013' 13-3/8" ~ 5836' 9.3 PPG DRILL TO 7442', ST TO CSG SHOE. TIGHT HOLE IN COAL SEAM & SECTIONS ABOVE. DRILLED 12-1/4" HOLE F/7442'-7654'. ST TO 6258', TIGHT HOLE F/7146' TO 7007'. DRILLED TO 7705'. DAY 40 (02/01/94) 24" ~ 803' 18-5/8" ~ 2013' 13-3/8" ~ 5836' 9.3 PPG DRILLED 12-1/4" HOLE F/7705'-7805'. ST TO 6822', TIGHT F/7142'-6988' NO IMPROVEMENT. RIH, SET DN AT 7058' UNABLE TO WORK DN, ROTATE F/7058'-7068'. RIH, DRILLED COAL SECTION F/7805'-7830' W/DIFFICULTY. DRILLED TO 7947'. DAY 41 (02/02/94) 24"@ 803' 18-5/8" @ 2013' 13-3/8" ~ 5836' 9.4 PPG ST TO 6730', SOME IMPROVEMENT. DRILLED F/7947'-8121'. ST TO 6819', TIGHT HOLE AT INTERVALS. DRILLED TO 8183'. DAY 42 (02/03/94) 24" @ 803' 18-5/8" @ 2013' 13-3/8" @ 5836' 9.4 PPG DRILLED TO 8240'. CBU. POOH, TIGHT HOLE AT INTERVALS. TEST BOPE. CHG BHA PERFORM BOPE TEST. RIH, CUT & SLIP DRILL LINE. UNOCAL DALLY HISTORY BAKER #30 DAY 43-45 (02/04-06/94) 24"~ 803' 18-5/8" @ 2013' 13-3/8" ~ 5836' 9.4 PPG DRILLED 12-1/4" HOLE F/8240'-8498'. ST TO 7594', BACK REAM HOLE AT INTERVALS. DRILLED F/8498'-8867'. ST TO 6821', TIGHT HOLE AT INTERVALS. DRILLED F/8867'-8971'. POOH F/BIT & BHA CHG. RIH, REAM F/8776'-8971' DAY 46 (02/07/94) 24"@ 8O3' 18-5/8"@ 2013' 13-3/8" @ 5836' 9.4 PPG DRILLED F/8971'-9315'. DAY 47 (02/08/94) 24"@ 803' 18-5/8" @ 2013' 13-3/8" ~--~ 5836' 9.4 PPG DRILLED F/9315'-9385'. ST TO 8450'. DRILLED F/9385' - 9586'. DAY 48 (02/09/94) 24"@ 803' 18-5/8" @ 2013' 13-3/8"@ 5836' 9.4 PPG CBU, ST TO 13-3/8" CSG SHOE W/TIGHT HOLE CONDITIONS AT INTERVALS. RU WL. RIH W/LOG RUN #1 (DIL/SONIO/CNL/FDC/SP/GR) & SET DN @ 7901', UNABLE TO WORK DN. POOH, REM SONIC TOOL W/CENTRAILIZERS. RIH W/LOG RUN #2. SET DN ~ 7898', UNABLE TO WORK DN. LOG F/7898' TO 13-3/8" CSG SHOE. MU C/OUT BHA & RIH. UNOCAL DALLY HISTORY BAKER #30 DAY 49 (02/10/94) 24" @ 803' 18-5/8"@ 2013' 13-3/8" ~ 5836' 9.4 PPG RIH, SET DN AT 6980' & 7084', WORK DN W/O ROTATION TO 8500'. RIH TO 9586', CBU. POOH. RU WL & RIH W/LOG RUN #3 (DIL/SONIC) TO 9560', LOG INTERVAL F/9560'-5836'. PREP CBIL LOG TOOL, NEGATIVE FAILURE ON SURFACE TEST. RIH W/LOG RUN #4 (DIPMETER) UNABLE PASS 7103', LOG F/7098'-5836'. RD WL & MU BHA. DAY 50-52 (02/11-13/94) 24" ~ 8O3' 18-5/8" ~ 2013' 13-3/8"@ 5836' 9-5/8"@ 9562' 9.4 PPG RIH TO 9586', CCH F/CSG. POOH. CHG RAMS TO 9-5/8" & TEST SAME. RU & RIH W/9-5/8" 47# 1_80 CSG TO 9562'. COM. M&P 54 BBLS OF 13.2 PPG TLW CMT FOLLOWED W/205 BBLS OF 15.8 PPG "G" CMT, DISPL SAME W/MUD. ClP AT 1000 HRS 2-12-94. PRESS TEST CSG TO 4800 PSI F/30 MINS. RUN CSG PACKOFF & TEST SAME 5M & 10K OVERPULL. CHG RAMS & PERFORM DOPE TEST. MU DRLG BHA & RIH. DRILL FC @ 9474', CMT & CSG SHOE @ 9563'. DRILLED 8-1/2" HOLE F/9563'-9990'. DAY 53 (02/14/94) 24" @ 803' 18-5/8"@ 2013' 13-3/8" @ 5836' 9-5/8"@ 9562' 9.4 PPG DRILLED 8-1/2" HOLE F/9990'-10175'. POOH F/BIT CHANGE & REPLACE MUD MOTOR. RIH, REAM F/9822' TO 10122'. DRILLED TO 10175'. UNOCAL DALLY HISTORY BAKER #30 DAY 54 (02/15/94) 24"@ 803' 18-5/8" @ 2013' 13-3/8" @ 5836' 9-5/8" ~ 9562' 9.4 PPG DRILLED 8-1/2" HOLE F/10175'-10386'. POOH F/HI-TORQUE. BIT SEVERELY UNDERGAUGE. MU BHA & RIH. DAY 55 (02/16/94) 24"@ 803' 18-5/8" @ 2013' 13-3/8" @ 5836' 9-5/8" @ 9562' 9.4 PPG RIH, REAM F/10272'-10386'. DRILLED F/10386'-10548'. FAILURE OF KELLY HOSE. POOH, WAIT ON NEW HOSE. LAY DN BAD HWDP & MU NE-VV BHA (ROTARY) & BIT. RIH, RIG DN & REPLACE KELLY HOSE. DAY 56 (02/17/94) 24"@ 803' 18-5/8" ~ 2013' 13-3/8"@ 5836' 9-5/8" @ 9562' 9.4 PPG CHANGED OUT KELLY HOSE° RIH TO 9649'. SPOT REAMED F/9649'-10548'. DRILLED F/10548'-10858'. UNOCAL DALLY HISTORY BAKER #30 DAY 57-60 (2/18-21/94) 24" ~ 8O3' 18-5/8"@ 2013' 13-3/8" @ 5836' 9-5/8"@ 9562' 9.8 PPG DRILLED 8-1/2" HOLE F/10858'-10945'. POOH, TIGHT OT 10178'. CHG BIT & RIH, REAM F/10527'-10945'. DRILLED F/10945'-11275' TD, INCR MW TO 9.8 PPG. ST TO CSG SHOE & CBU (FIN AMT SAND). RIH TO 11275', CCH F/E- LINE LOGS. POOH. RU WL & RIH W/LOG RUN #1 (DIL/CNL/FDC/SONIC/GR/SP). SET DN 10050', TOOL FAILURE. POOH, CHG OUT TOOL & RIH W/RUN #2 TO 10475' UNABLE TO WORK DEEPER. LOG HOLE F/10442' TO 9562'. RIH W/RUN #3 (DIL/SONICGRSP), UNABLE TO PASS 10472'. POOH. MU WIPER BHA & RIH, SET DN F/10500'-10864' AT INTERVALS. CCH. POOH. RIH W/LOG RUN #4 (DIL/SONIC/GR/SP) TO 10675' WLM. LOG F/10620'-10400'. POOH, LAY DN SONIC TOOL. RIH W/LOG RUN #5 (DIL/GR/SP)(TO 10623', UNABLE TO WORK DEEPER. POOH. TEST BOPE. DAY 61 (02/22/94) 24" @ 803' 18-5/8" ~ 2013' 13-3/8"@ 5836' 9-5/8" @ 9562' 10 PPG TIME REQ'D: 54 DAYS CMPT BOP TEST. RIH W/OEDP, PREP F/SLIM-HOLE E-LINE TOOL THRU DP. RIH W/DP TO 11275', CIRC WELL CLEAN. PULL TO 10670'. RU WL & RIH W/LOG RUN #6 (GR/AC/IEL) THRU DP. ATTEMPT TO WORK DN BELOW DP W/O SUCCESS. POOH, RIG DN WL. RIH TO 11275', CCH. POOH. DAY 63 (02/24/94) 24"@ 8O3' 18-5/8"@ 2013' 13-3/8"@ 5836' 9-5/8"@ 9562' 7"L FROM 9386'-11275' 10 PPG RIH W/6" BIT W/7" CSG SCRAPER ON 3-1/2" TBG. WORKED THROUGH LINER TOP. TAGGED FLOAT COLLAR @ 11192'. CHANGED HOLE OVER TO INLET WATER. POOH TO RUN CEMENT EVALUATION LOG. 10 UNOCAL DALLY HISTORY BAKER #30 DAY 64-66 (02/25-27/94) 24" @ 803' 18-5/8" @ 2013' 13-3/8" @ 5836' 9-5/8" @ 9562' 7"L FROM 9386'-11275' 6.9 PPG (DIESEL) RAN SBT-VDL. RIGGED OUT LOGGERS. RIH W/6" BIT & 9-5/8" SCRAPER TO TOP OF LINER. REVERSE CIRCULATED WELL OVER TO DIESEL. MONITORED WELL. STRAPPED OUT OF HOLE. CHANGED TOP PIPE RAMS. P TESTED TO 5000 PSI, OK. PICKED UP PERF GUNS & KOBE ASSEMBLY. RIGGED UP TO RUN DUAL COMPLETION. RAN DUAL COMPLETION. HYDROTEST & DRIFT LONG STRING. RIGGED UP LOGGERS. CORRELATE RA TAG. (TBG 2' TO GR) SPACED OUT TBG. ORIENTED & LANDED TBG HANGER. TESTED SEALS TO 5000 PSI FOR 30 MINS, OK. RAN 2 WAY CHECKS. NIPPLED DOWN DOPE. NIPPLED UP TREE. TESTED TREE TO 5000 PSI, OK. SKIDDED TO WELL 29. CHANGED OUt JET PUMP FOR RECIP PUMP. SKIDDED BACK TO WELL 30. INSTALLED PUMP IN TREE. RIG RELEASED TO WELL 28 @ 11:59 HRS 02/27/94. DAY 67 (02/28/94) 24"@ 8O3' 18-5/8"@ 2013' 13-3/8" @ 5836' 9-5/8" @ 9562' 7"L FROM 9386'-11275' 6.9 PPG (DIESEL) INSTALL SURFACE FLOWLINE EQUIP & TEST SAME. INSTALL JET PUMP IN PLACE AND BEGIN PUMPING FLUID. FLUID LEVEL AT 5450' AT 0600 HRS 3-1- 94. 11 UNOCAL DALLY HISTORY BAKER #30 DAY 68 (03/01/94) 24"~ 803' 18-5/8" @ 2013' 13-3/8"@ 5836' 9-5/8"@ 9562' 7"L FROM 9386'-11275' 6.9 PPG (DIESEL) CONT PUMPING FLUID LEVEL DN TO 6960'. DETONATE 4-5/8" TCP GUNS AT 1820 HRS, PERFORATING TYONEK "F" & HEMLOCK AT INTERVALS. INITIALLY HAD 564' OF FLUID RISE IN 15 MIN. AT 0600 HRS WELL TEST 400/112 (GROSS/NET). FLUID LEVEL AT 5100'. UNOCAL BAKER Platform Ba-30 slot #1-2 Middle Ground Shoals Cook Inlet, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : PMSS <843 - 11275'> Our ref : svy4092 License : Date printed : 6-Jul-94 Date created : 26-0ct-93 Last revised : 6-Jul-94 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 45.778,w151 29 1.069 Slot Grid coordinates are N 2498072.852, E 235249.628 Slot local coordinates are 1932.00 S 539.00 E Reference North is True North UNOCAL BAKER Platform,Ba-30 Middle Ground Shoals,Cook Inlet, Alaska SURVEY LISTING Page 1 Your ref : PMSS <843 - 11275'> Last revised : 6-Ju[-94 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 0.00 0.00 0.00 N 0.00 E 0.00 0.00 251.00 0.60 65.00 251.00 0.56 N 1.19 E 0.24 0.52 281.00 1.00 83.00 280.99 0.65 N 1.59 E 1.56 0.61 311.00 1.20 67.00 310.99 0.81 N 2.14 E 1.22 0.74 371.00 0.90 48.00 370.98 1.37 N 3.07 E 0.76 1.28 462.00 2.50 7.00 461.94 3.82 N 3.84 E 2.10 3.70 552.00 2.70 326.50 551.85 7.53 N 2.91 E 2.01 7.44 626.00 2.80 326.50 625.77 10.49 N 0.95 E 0.14 10.46 650.00 2.80 339.00 649.74 11.53 N 0.42 E 2.54 11.51 736.00 2.10 0.00 735.66 15.07 N 0.33 W 1.31 15.07 750.00 2.60 350.00 749.65 15.64 N 0.39 W 4.60 15.64 843.00 2.50 2.00 842.56 19.74 N 0.68 ~ 0.58 19.75 932.00 2.70 7.00 931.46 23.76 N 0.36 W 0.34 23.76 1026.00 2.20 0.00 1025.38 27.76 N 0.09 ~ 0.62 27.75 1126.00 1.80 325.00 1125.32 30.97 N 0.99 ~ 1.26 30.98 1343.00 0.50 286.00 1342.28 34.02 N 3.86 W 0.67 34.12 1434.00 0.20 330.00 1433.27 34.27 N 4.32 ~ 0.42 34.38 1524.00 0.30 30.00 1523.27 34.61 N 4.28 ~ 0.29 34.72 1619.00 0.60 37.00 1618.27 35.22 N 3.85 ~ 0.32 35.32 1717.00 1.70 335.00 1716.25 36.95 N 4.16 W 1.54 37.06 1811.00 3.20 332.00 1810.16 40.53 N 5.98 W 1.60 40.69 1905.00 4.60 329.00 1903.94 46.08 N 9.15 ~ 1.50 46.33 1986.00 6.50 327.50 1984.56 52.73 N 13.29 ~ 2.35 53.10 2091.00 9.10 327.30 2088.58 64.73 N 20.97 ~ 2.48 65.32 2185.00 11.70 327.70 2181.03 79.04 N 30.08 ~ 2.77 79.90 2278.00 14.60 328.50 2271.58 97.01 N 41.25 W 3.12 98.19 2373.00 16.70 330.00 2363.05 119.04 N 54.33 ~ 2.25 120.60 2466.00 19.30 330.30 2451.49 143.97 N 68.63 W 2.80 145.94 2561.00 22.20 332.90 2540.32 173.59 N 84.58 ~ 3.20 176.02 2655.00 25.50 334.20 2626.28 207.63 N 101.49 ~ 3.55 210.54 2750.00 26.20 335.20 2711.78 245.08 N 119.18 W 0.87 248.50 2844.00 27.30 338.60 2795.72 283.99 N 135.75 W 2.00 287.88 2937.00 27.00 338.90 2878.48 323.54 N 151.14 ~ 0.35 327.87 2986.00 27.30 338.20 2922.08 344.35 N 159.31 g 0.89 348.92 3146.00 28.60 338.50 3063.41 414.05 N 186.98 W 0.82 419.41 3240.00 29.40 340.00 3145.62 456.67 N 203.11 ~ 1.15 462.48 3334.00 30.10 340.50 3227.24 500.57 N 218.87 ~ 0.79 506.83 3459.00 29.50 341.70 3335.71 559.34 N 239.00 ~ 0.68 566.17 3549.00 28.90 342.60 3414.27 601.13 N 252.46 ~ 0.83 608.34 3648.00 28.20 343.10 3501.23 646.34 N 266.42 W 0.75 653.94 3720.00 27.90 343.70 3564.77 678.78 N 276.09 ~ 0.57 686.66 3817.00 27.80 345.20 3650.54 722.43 N 288.24 ~ 0.73 730.65 3911.00 27.50 346.50 3733.80 764.73 N 298.90 ~ 0.72 773.25 3991.00 26.40 348.10 3805.12 800.09 N 306.88 ~ 1.65 808.83 4059.00 26.80 347.00 3865.92 829.82 N 313.45 ~ 0.93 838.74 4134.00 26.80 348.90 3932.86 862.89 N 320.51 W 1.14 872.00 4229.00 26.30 348.60 4017.85 904.54 N 328.79 ~ 0.54 913.88 4350.00 26.10 349.50 4126.42 956.99 N 338.94 ~ 0.37 966.60 4439.00 25.90 346.30 4206.41 995.12 N 347.11 g 1.59 1004.97 4533.00 25.00 343.70 4291.29 1034.13 N 357.55 ~ 1.53 1044.27 All data is in feet unless otherwise stated Coordinates from slot #1-2 and TVI) from wellhead (118.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 358.30 degrees. Declination is 0.00 degrees, Convergence is -1.30 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL SURVEY LISTING Page 2 BAKER Platform,Ba-30 Your ref : PMSS <843 - 11275'> Middle Ground Shoals,Cook Inlet, Alaska Last revised : 6-Ju[-94 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 4624.00 24.90 343.10 4373.80 1070.92 N 368.51 W 0.30 1081.36 4718.00 25.40 344.30 4458.89 1109.26 N 379.72 W 0.76 1120.02 4814.00 25.60 345.40 4545.54 1149.15 N 390.52 W 0.54 1160.22 4906.00 25.70 343.50 4628.47 1187.52 N 401.20 W 0.90 1198.88 4997.00 26.10 343.40 4710.33 1225.62 N 412.52 W 0.44 1237.30 5092.00 26.30 343.40 4795.57 1265.81 N 424.50 W 0.21 1277.83 5162.00 26.20 343.30 4858.35 1295.48 N 433.37 W 0.16 1307.74 5255.00 26.70 343.70 4941.62 1335.19 N 445.14 W 0.57 1347.79 5351.00 26.10 343.80 5027.61 1376.17 N 457.08 ~ 0.63 1389.11 5443.00 24.40 344.60 5110.81 1413.93 N 467.78 ~ 1.88 1427.16 5534.00 25.90 344.40 5193.18 1451.20 N 478.11 W 1.65 1464.72 5631.00 25.50 345.50 5280.59 1491.82 N 489.04 W 0.64 1505.64 5723.00 24.40 348.60 5364.00 1529.62 N 497.75 W 1.86 1543.69 5763.00 24.60 348.30 5400.40 1545.87 N 501.07 W 0.59 1560.03 5871.00 24.90 348.30 5498.48 1590.15 N 510.24 W 0.28 1604.56 5965.00 24.60 352.20 5583.85 1628.91 N 516.91 W 1.76 1643.50 6058.00 25.70 350.00 5668.04 1667.95 N 523.04 W 1.55 1682.71 6151.00 26.30 349.30 5751.62 1708.05 N 530.37 W 0.72 1723.01 6245.00 26.70 344.90 5835.76 1748.91 N 539.74 ~ 2.13 1764.13 6337.00 27.10 346.80 5917.80 1789.27 N 549.90 ~ 1.03 1804.7-/ 6431.00 27.20 344.90 6001.45 1830.85 N 560.39 W 0.93 1846.65 6525.00 28.20 343.00 6084.68 1872.84 N 572.48 W 1.42 1888.97 6620.00 27.50 350.50 6168.70 1915.95 N 582.67 W 3.76 1932.36 6714.00 27.70 349.50 6252.00 1958.83 N 590.23 W 0.54 1975.46 6807.00 28.40 348.80 6334.08 2001.78 N 598.47 W 0.83 2018.63 6899.00 28.20 352.20 6415.09 2044.78 N 605.67 W 1.76 2061.83 6990.00 27.70 0.60 6495.50 2087.25 N 608.36 W 4.36 2104.36 7086.00 27.00 2.90 6580.7'/ 2131.33 N 607.03 W 1.32 2148.37 7149.00 27.00 4.60 6636.91 2159.87 N 605.16 W 1.22 2176.84 7241.00 30.20 9.10 6717.68 2203.55 N 599.82 W 4.19 2220.35 7334.00 32.10 12.40 6797.28 2250.78 N 590.81 W 2.74 2267.30 7426.00 33.30 15.40 6874.70 2299.01 N 578.86 W 2.19 2315.15 7520.00 31.60 19.30 6954.03 2347.14 N 563.86 W 2.87 2362.81 7613.00 32.80 26.10 7032.75 2392.78 N 544.72 W 4.10 2407.86 7/07.00 33.50 29.50 7111.45 2438.22 N 520.74 W 2.11 2452.58 7801.00 36.60 36.80 7188.43 2483.27 N 491.16 W 5.54 2496.73 7893.00 39.40 41.80 7260.94 2527.02 N 455.26 W 4.52 2539.39 7987.00 40.30 43.90 7333.11 2571.16 N 414.29 W 1.72 2582.30 8080.00 40.60 48.50 7403.89 2612.90 N 370.76 W 3.22 2622.73 8174.00 43.90 54.00 7473.49 2652.34 N 321.46 W 5.27 2660.70 8265.00 47.00 58.10 7537.34 2688.49 N 267.66 W 4.60 2695.24 8359.00 48.00 62.30 7600.86 2722.90 N 207.53 W 3.46 2727.85 8452.00 50.60 65.90 7661.51 2753.64 N 144.12 W 4.05 2756.70 8545.00 54.70 67.00 7/17.92 2783.16 N 76.35 W 4.51 2784.20 8639.00 57.20 69.10 7770.55 2812.25 N 4.12 W 3.24 2811.13 8733.00 58.00 69.90 7820.92 2840.04 N 70.22 E 1.11 2836.71 8826.00 57.50 67.10 7870.55 2868.86 N 143.39 E 2.60 2863.35 8920.00 57.00 67.90 7921.40 2899.11 N 216.43 E 0.89 2891.43 9013.00 56.00 66.80 7972.73 2928.97 N 288.00 E 1.46 2919.16 9105.00 53.40 69.60 8025.90 2956.87 N 357.68 E 3.76 2944.98 All data is in feet unless otherwise stated Coordinates from slot #1-2 and TVD from wellhead (118.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 358.30 degrees. Declination is 0.00 degrees, Convergence is -1.30 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL BAKER Platform,Ba-30 Middle Ground Shoals,Cook Inlet, Alaska SURVEY LISTING Page 3 Your ref : PMSS <843 - 11275'> Last revised : 6-Ju[-94 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 9199.00 51.40 70.10 8083.25 2982.53 N 427.60 E 2.17 2968.56 9293.00 50.30 69.00 8142.60 3008.00 N 495.90 E 1.48 2991.99 9385.00 49.80 66.30 8201.68 3034.80 N 561.12 E 2.31 3016.85 9479.00 47.40 65.00 8263.84 3063.86 N 625.36 E 2.76 3043.99 9545.00 48.00 65.10 8308.26 3084.45 N 669.62 E 0.92 3063.27 9633.00 50.40 63.20 8365.76 3113.51 N 729.55 E 3.18 3090.54 9664.00 50.65 62.83 8385.46 3124.37 N 750.87 E 1.22 3100.76 9763.00 53.98 61.57 8445.98 3160.92 N 820.15 E 3.51 3135.24 9857.00 54.41 61.78 8500.97 3197.09 N 887.26 E 0.49 3169.41 9949.00 54.64 60.44 8554.36 3233.29 N 952.86 E 1.21 3203.65 10042.00 53.10 62.01 8609.20 3269.45 N 1018.68 E 2.14 3237.84 10082.00 52.70 63.14 8633.33 3284.14 N 1047.00 E 2.46 3251.70 10131.00 53.21 63.70 8662.85 3301.64 N 1081.98 E 1.38 3268.15 10223.00 53.87 61.36 8717.52 3335.78 N 1147.62 E 2.17 3300.32 10318.00 55.84 59.00 8772.21 3374.42 N 1214.99 E 2.90 3336.95 10412.00 58.03 57.54 8823.50 3415.85 N 1281.98 E 2.67 3376.39 10506.00 58.38 58.40 8873.02 3458.22 N 1349.71E 0.86 3416.73 10900.00 60.00 58.40 9074.82 3635.53 N 1637.92 E 0.41 3585.43 Projected Azimuth 10900 - 11225' 11225.00 57.00 58.40 9244.62 3780.72 N 1873.92 E 0.92 3723.56 11275.00 57.00 58.40 9271.85 3802.69 N 1909.63 E 0.00 3744.46 Projected Data - NO SURVEY All data is in feet unless otherwise stated Coordinates from slot #1-2 and TVD from wellhead (118.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 358.30 degrees. Declination is 0.00 degrees, Convergence is -1.30 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL SURVEY LISTING Page 4 BAKER Platform, Ba-30 Your ref : PMSS <843 - 11275'> Middle Ground Shoals,Cook Inlet, Alaska Last revised : 6-Jul-94 Comments in wellpath MD TVD Rectangular Coords. Comment 10900.00 9074.82 3635.53 N 1637.92 E Projected Azimuth 10900 - 11225' 11275.00 9271.85 3802.69 N 1909.63 E Projected Data - NO SURVEY Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 5836.00 5466.72 1575.74N 507.26g 13 3/8" Csg Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised Ba30 T/Hemlock#3 not specified 7600.00 2700.OON 80.OOW lO-Apr-93 G-1R not specified 9268.00 3682.00N 1811.00E 13-Ju[-93 All data is in feet unless otherwise stated Coordinates from slot #1-2 and TVD from wellhead (118.00 Ft above mean sea level). Bottom hole distance is 4255.25 on azimuth 26.66 degrees from wellhead. Vertical section is fromm wellhead on azimuth 358.30 degrees. Declination is 0.00 degrees, Convergence is -1.30 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes [NTEQ ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 JUNE 7,1994 Russell Schmidt Union Oil Company of California P O Box 190247 Anchorage, Alaska 99519 RE: 93-0118 MGS ST 17595 28 93-0119 MGS ST 17595 · 29 93-0120 MGS ST 17595 30 COMPLETION 407 FORM COMPLETION 407 FORM COMPLETION 407 FORM Dear Mr. Schmidt, A review of our well records and correspondence indicates the the referenced wells are producing at this time and to date, the required 10-407 Well Completion Report has not been received. You are out of compliance with 20 AAC 25.072 (2). The attached request, in responce to MGS 29, has gone unanswered. I spoke with Lynn Goard about the other two wells (MGS 28 and MGS 30) the end of April 1994 after the monthly production Was reported for March 1994. The Commission requests this material immediately to correct the problem and update our well files. Sincerely, Steve McMains Statistical Technician atch: letter dated March 4, 1994 Unocal Energy Resources g'-"~*ion Unocal Corporation 909 West 9th Avenue, P.O. Bo), ,247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOF. AL- DOCUMENT TRANSMITTAL Alaska April 21, 1994 TO: Larry Grant FROM: Dan Seamount LOCATION: 3001 PORCUP~ DRIVE LOCATION: P.O.BOX 196247 ANCHORAGE, AK 99501 ANCHORAGE AK 99519 ALASKA OIL & GAS CONSERVATION COMM. UNOCAL TRANSMITTING AS FOLLOWS 1 blueline and 1 sepia of each of the following MGS BAKER 28 ¢/BHC Acoustilog/Gamma Ray X/Compensated Densilog/Neutron/Gamma Ray v/Compensated Neutron/Gamma Ray V/Dual Induction Focused Log/Gamma Ray ~'Dual Propagation Resistivity/Gamma Ray (Measured Depth)/r~&~ /Dual Propagation Resistivity/Gm Ray (Subsea TVD) (~ ~ ~ v~ormation Mudlog U'~BT/Neutron/Gamma Ray Tape & Listing .~Openhole LIS Tape 2025-10491 MGS BAKER 29 JBHC Aeoustilog/Gamma Ray/C.:ati~r ~Borehole Profile (Compensated Dens[log) '~Compensated Dens[log/Neutron/Gamma Ray VT)ual Induction Focused Log/Gamma Ray FOmfion Mudlog ormation Multi-Tester/Gm Ray ,,/S.egmented Bond Log Tape &v/Listing Openhole LIS Tape 1879-10281 MG$ BAKER ~0 .C Acoustilog/Gamma Ray/Caliper (2" & ~) /Dual Induction Focused Log/Gamma Ray ~r~and~) sB rmation Mudlog T/Gamma Ray Tape & Listing v/Openhole LIS Tape 1900-10700 PLEASE ACKNOWLEDGE RECEIFF BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMrI'rAL TO DEBRA CHIL ~ER~~,~OU RECEIVED BY: DATED: % Unocal Energy Reso, .... ,s Division Unocal Corporation 909 West 9th Avenue, F..... Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOEAL Alaska DOCUMENT TRANSMITTAL April 19, 1994 TO: Larry Grant LOCATION: 3OOl PORCUPINE DRIVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. FROM: Dan Seamount LOCATION: P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL TRANSMITrlNG AS FOLLOWS BOX1 300 - 1710 2040 - 3390 2040-3330 BOX2 1710 - 3000 3390 - 4680 3330 - 4560 BOX3 3000-4320 4680-5940 4560-6000 BOX4 4320 - 5550 5940 - 7200 6000 - 7500 BOX 8 8700- 9900 9450- 9900 9550- 9900 BOX 9 9900- 10582 9900- 10280 9900- 10250 BOX 10 10250 - 10600 BOX 11 10600- 11000 BOX 12 11000- 11275 PLEASE ACKNOWLEDGERECEIPT BY,SIGNING THIS DOCUMENT~AL DATED: , ~. ~ ~. ~,~. AND RE~G ONE COPY OF THANK YOU _, ORANDUM TO: David Johns.t/pr~ Chairma~j~, THRU: Blair Wondzell ~.~ P.I. Supervisor FROM: Bobby Foster~~ Petroleum Inspector STATE O P . LA $1(A ALASKA OIL AND GAS CONSER VA TION COMMISSION DA TE: January 26, 1994 FILE NO: AV81AZBD.DOC PHONE NO.: 279-1433 SUBJECT: BOPE Test - Pool 428 UNOCAL - MGS # 30 Baker Platform PTD # 93 - 120 Wednesday, January 26, 2994: I traveled to UNOCAL's Baker platform after completing a BOPE test on the Bruce platform, the subject of another report, at 5:30 pm on 1- 25 - 1994. The BOPE test began at 3:30 am and was completed at 6:00 am. As the attached AOGCC BOPE Test report shows there were no failures. i made a walk thru of the platform and found that the platform was clean, most areas were clear of extra equipment. There is a lot of remodeling and replaceing lines going on in the production handleing areas. ! told Dusty Rhodes, production foreman and Evan Harness, drilling foreman, that I though the platform looked OK, considering the rig had just completed a well, moved tO another well, and with all the other work in progress. They both said the platform would cleaned up in the next couple of days. Summary: I witnessed the satisfactory BOPE test Pool - Artic rig 428 - test time 2.5 hours - no failures. ATTAC HMENT:AV81AZBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: POOL - ARTIC Operator: UNOCAL Well Name: 30 Casing Size: 13 3t8 Set @ Test: Initial X Weekly Rig No. 428 PTD# Rep.: Rig Rep.: 5,836 Location: Sec. Other 93 - 120 DATE: 1/26/94 Rig Ph.# 776 - 6647 EVAN HARNESS JOHN Mc COY 31 T. 9N R. 12W Meridian S MISC. INSPECTIONS: Location Gen.: OK Housekeeping: O1~ (Gen) Reserve Pit N / A Well Sign OK Drl. Rig OK BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure P/F 1 500\5000 P 1 500\5000 P 1 500~000 P 1 500\5000 P I 500~000 P 2 500\5000 P 1 500\5000 P NV~ NW FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quan. Pressure P/F I 500\5000 P I 500\5000 P 2 500\5000 P 1 500\5000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Te~ Pressure P/F 15 500\5000 P 38 500\5000 P ACCUMULATOR SYSTEM: System Pressure 3,000 I P Pressure After Closure 1,800 '1 P MUD SYSTEM: V'~sual Alarm 200 psi Attained After Closure 0 minutes 17 Tdp Tank YES YES System Pressure Attained 1 minutes 37 Pit Level Indicators YES YES Blind Switch Covers: Master: YES Remote: Flow Indicator YES YES Nitgn. Btl's: 12 ~ 2100 AVG. Gas Detectors YES YES Psig. sec. sec. YES Number of Failures: 0 ,Test Time: 2.5 Hours. Number of valves tested 24 Repair or Replac'e'~ent 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 N 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. I. Supervisor at 279-1433 REMARKS: GOOD TEST Distdbu'don: odg-Weil 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: F1-021L (Rev. 7/19) AV81AZBD.XLS ALASKA OIL AND GAS CONSERVATION COM~IISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 ~anuary 10,1994 Russell Schmidt Unocal P O Box 196247 Anchorage, AK 99519-6247 Dear Mr Schmidt: The Commission is compiling statewide drilling statistics for 1993. Attached is a list of outstanding Permits to Drill issued to your engineering group (permits for which no form 10-407 has been received by this office). Please review this list to determine if any of the wells were drilled in 1993. If so, please note the well name, total measured depth, and class (development, service or exploratory). If any wells were drilling as of 12/31/93, estimate the depth at 12:00 midnight. We would appreciate your reply by the end of January if possible. Thank you for your cooperation with this project. If ! may be of any assistance, please call me at 279-1433. Yours very truly, Robed P Crandall Sr Petr Geologist encl joiA: RPC.~,ddstats 1/03/94 OPERATOR UNION OIL CO OF CALI UNION OIL CO OF CALI UNION OIL CO OF CALI UNION OIL CO OF CALI I/NION OIL CO OF'CALI U~ON O~L CO OF C-ALI I/NION OIL CO OF C. ALI I/SION OIL CO OF C-ALI LTNION OIL CO OF CALI I/NION O~L CO OF CALX ALASKA WELLS BY UNOCAL PERMIT 92-0152-0 93-0073-0 93-0118-0 93-0119-0 93-0120-0 93-0127-0 93-0129-0 93-0165-0 93-0182-0 93-0190-0 WELL NAME IVAN RIVER UNIT 14-31RD1 GRANITE PT ST 18742 42 CHAKAC~ATNA MGS B-29 CHAKACHATNA MGS B-28 C~A~CACHATNA MSS B-30 GRANITE PT ST 17586 3RD TRADING BAY UNIT K-24RD TRADING BAY UNIT K-26 AMETHYST STATE 1 TRJkDING BAY UNIT M-31 PAGE Unocal North Arneri; Oil lind Gas Division Unocal Corp~radon P.O. Box 190247 Anchorage, Alaska 99579-0247 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 si~e charaoterize 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 S4 well. These known productive gas sands at Baker Platform will be present in the proposed wells (Ba. #28, 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) Ba.28, 29, & 30 Regards, C. Lee Lohoefer Senior Drilling Engineer RE(ZEIVED AU G 2 0 199; Alaska Oil & Gas Cons. CommisSiO~ 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 oft' 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) off the 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 anyway). 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 circumstances 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. ALASKA OIL AND GAS CONSERVATION COMMISSION September 3, 1993 G. Russell Schmidt Regional Drilling Manager UNOCAL P O Box 196247 Anchorage, AK 99519-6247 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re: Chakachatna MGS Baker #30 UNOCAL Permit No: 93-120 Sur. Loc. 1932'FNL, 539'FWL, Sec 31, T9N, R12W, SM Btmhole Loc. 1786'FSL, 2420'FWL, Sec 30, T9N, R12W, SM Dear Mr. Schmidt: Enclosed is the approved application for permit to drill the above referenced well. The Commission hereby waives the diverter system requirements per 20 AAC 25.035 and waives the requirements for operational shutdown (20 AAC 25.072) since drilling operations will not be disrupted for more than a 60-day time period. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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. Sincerely, Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . STATE OF ALASKA · ALASKA 'AND GAS CONSERVATION CON, SSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill E~ Redrill E~ ] lb. Type of well. Exploratory ~ Stratigraphic Test ~] Development Oil [] Re-Entry ~] Deepen ~I Service ~ Development Gas [~ Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Comapny of California (UNOCAL) 118' RT ABOVE MSL feet Middle Ground Shoals 3. Address 6. Property Designation E,F & G Pool P.O. Box 196247, Anchorage, AK 99519-6247 ADL 17595 4. Location of well at surface Baker Pit. Leg #1, Slot #2 7. Unit or property name 11. Type Bond (SEE 20 ACC 25.025) 1932' FNL & 539' FWL SECTION 31, T9N, R12W, S.M. Chakachatna MGS UNITED PACIFIC INS. CO. At top of productive interval 8388'MD / 7600'TVD 8. Well number I Number 768' FSL & 459' FWL SEC. 30, T9N, R12W, S.M. Baker #30 U62-9269 At total depth 11194'MD / 9330'TVD 9. Approximate spud date Amount 1786'FSL & 2420'FWL SEC. 30, T9N, R12W, S.M. September 7, 1993 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (~ and TVO) property line 3300 feet 4' @ SURFACE feet 5106_ 11,194' / 9,330' feet 16. To be completed for deviated wells 17. Anticipated Pressure(se.~OAAC25.o35 (.)(2)) Kickoff depth 1500 feet Maximum hole angle 52 DEG Maximum surface 770 psigAttotaldepth0%/D) 4198 pslg 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) 28" 24" 156 X42 MTS60 744' 56 56 800' 800' 1400 cu.ft. 24" 18- 5/8" 97 X56 QTE60 1944' 56 56 2000' 2000' 2500 cu.ft..+- 17-1/2" 13-3/8" 68 K55 BUTT 6144' 56 56 6200' 5784' 2700 cu.ft. 12-1/4" 9-5/8" 47 N80 BUFF 11138' 56 56 11194' 9330' 1400 cu.ft. -- 19. To be completed for Redrill, Re-entry. and Deepen Operations Present well condition summary Total depth: measured 303 feet Plugs (measured) true vertical 303 feet Effective depth: measured 303' feet Junk (measured) true vertical 303' feet Casing Length Size Cemented Measured depth True vertical depth Structural 247 30" DRIVEN 303 RKB (83' BML) Conductor Surface ~;~' ~, .~. Production ·, a '-.~' Liner ~., ~¢'; '~ ~',, Perforation depth: measured /~...,.t_~ ,.~ true vertical Ai~3.sk~ [)ii ~!~ (::;~-:; (.;~i !s, ~-; Ai;ch0i'a.~o 20. Attachments Filing fee ~, Property plat [-] BOP Sketch~, Diverter Sketch ~ Drilling program ~; Drilling fluid proJ;Iram ~ Time vs d~pth plot ~;; Refraction analysis ~ Seabed report ~ 20 AAC 25.050 requirements 21.1 hereby cer~t~n~rect tothe best of my knowledge I.~,. ~t,,,,F-~, Signed G. RUSSELLSCHMIDT Title REGIONAL DRILLING MANAGER Date Commission Use Only Permit Number APl number Approval date See cover letter ?~.-/~_~ ~ 50- ~',Y~ - ~-, o ~7¢,5"~' ~,.. ,~ .. ~ .~ for other requirements Conditions of approval Samples required ~ Yes,~ No Mud log required ~ Yes ,~ No Hydrogen sulfide measures ~ Yes '~ No Directional survey required ~ Yes ~ No Required working pressure for BOPE [-1 2M; ~, 3M; ~. 5M; ~ 10M; [-[ 15M Other: ORIGINAL SIGNED BY by the order of Approved by RUSSELL A. DOUGLASS Commissioner the commission Date Submit in trPlicate Form 10-401 Rev. 12-1-85 Unocal North Ameri Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 .... Telephone (907) 276-7600 Alaska Region UNOCAL ) August 5, 1993 AOGCC Attn: David Johnston Commissioner 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Johnston: Please find enclosed applications for a Permit to Drill (Form 10-401) for Baker Platform wells #28, 29 & 30. These wells are scheduled to begin in mid-September and are the first wells of a $120 MM Development drilling program to be drilled with a new drilling rig. The rig is a minimum space modular design drilling system that was designed to accommodate four different platforms; Anna, Baker, Bruce and Dillon. As part of this development drilling program Unocal is requesting that the AOGCC waive the diverter system requirement on both the (30") structural and (24") conductors casing strings for all three wells. As outlined in each well procedure Unocal is intending to drill out the 30" structural casing to ± 800' with a flow nipple then install a 20-3/4" 3M BOP stack on the 24" conductor casing that will be cemented at ± 800'. The 24" casing will then be drilled out to a depth of ± 2600' and 18-5/8" surface casing will be cemented to depth. It has been Amoco's practice (previous operator) at Baker platform to drill and set 20" conductor at ± 600' with a flow riser, install a diverter and drill to ± 3500' at which point 13-3/8" casing is set. Unocal has selected casing points for 24" at ± 800' and 18- 5/8" at ± 2600' to be areas of competent formations. It is anticipated that the minimum formation fracture gradients at both shoe depths will be 0.85 psi/ft. The fracture pressures will be above the maximum expected surface pressures (see MaP calculation in each permit). Since the casing shoes will not break down in a well kick situation and the setting depths are above any indications of known gas sands, Unocal believes these are prudent casing designs and warranted operations. RECEIVED AU6 1 3 199 _Alaska Oil & Gas Col~s. uummission Anchora9( Letter to David Johnston August 5, 1993 Page 2 Additionally, Unocal is proposing to batch drill (see outline) these three wells for the 24" 18-5/8" and 13-3/8" casing strings Once 13-3/8" casing is set on all three wells, then each well will be drilled to total depth and completed one after another. It is Unocal's understanding that for a batch drilling process a single Permit to Drill (Form 10-401) and a single subsequent Well Completion (Form 10-407) is required for each well. Please note that documents in support of a spacing exception, made pursuant to 20AAC25.055, accompany the Permit to Drill for Baker Platform Well #29. Unocal is prepared and willing to discuss with the AOGCC the request for waiver on the diverter system and/or the batch drilling process. Early resolution of these issues will allow Unocal to pursue alternatives if so required. If you have any questions please contact C. Lee Lohoefer (Senior Drilling Engineer) assigned to this project. Thank you for your attention to these matters. Sincerely, G. Russell Schmidt Drilling Manager Enclosures CLL / 1 eg Baker #30 (New Well) RWP Option 4.0 AFE Estimate August 13, 1993 Procedure Days · · 4. 5. 6· 7. 8. 9. MIRU, Leg #1, Conductor #8, Install 30" riser. Drill 17-1/2" hole to 800', underream 17-1/2" hole section to 28". Run and cement 24" casing to 800'. Install combination 20-3/4"BOP/Diverter stack Drill 17-1/2" hole to 2000' (ROP 600') Underream 17-1/2" hole section 24". Run and cement 18-5/8" casing. Install 20" BOPE. Drill 17-1/2" hole to 6200'. (ROP 500') Run open hole logs. 10. Run and cement 13-3/8" casing. Install 13-5/8" BOP. 11. Drill 12-1/4" hole to 11194' TD. (ROP 275') 12. Run open hole logs. 13. Run and cement 9-5/8" casing. 14. Run CET/CBT and gyro survey. 15. Clean out, pressure test, change over to 3% KCL. 16. Run Vann TCP guns (4-5/8" OD, 4 spf, DP charge) in combination with Dual 3-1/2" KOBE BHA. 17. Set BPV, Rem BOPE, Install tree and flowlines. 18. Detonate TCP guns and produce well. 2 1 2 2 2 8.5 1.5 2 18 2 2 1.5 1.5 4 Time (Days) 54 Depth 0 Baker 30 NEW WELL Depth vs. Days July 20, 1993 (2,000) AVG. ROP 80O FPD RUN 24' CSG AVG. ROP 600 FPD RUN 18-5/8' CSG TIME: 54 DAYS COST: $4.35 MM (4,000) AVG. ROP 5OO FPD (6,000) (8,000) ( o,ooo) (12,000) I 10 LOG & RUN 13-3/8' CSG ROP 275 FPD ~ COMPLETION LOG & RUN 9-5/8' CSG 20 30 40 50 60 70 Days Estimate Actual IKOBE BI-lA 32" Structurol @ 83' BLM 24" Conductor @ 800' 156#, X-42, MTS6OAR 18-5/8" Surface @ 2000' ~ 97#, X-56, QTE60 MISC. DATA RKB = 118' WATER DEPTH = 102' 13-3/8" Intermediate @ 6200' 68#, K-55, BTC COMPLETION DESCRIPTION 1) Dual 5-1//2'', 9.2#, k-80, SCBTC 2) KOBE BHA @ 8600' 5) TCP guns 4-5//8" OD net 1000' Hemlock @ Intervals +1000' 9-5/8" Production @ 11194' 47#, L-80, BTC BAKER 50 PROPOSED COMPLETION UNOCAL ENERGY RESOURCES ALASKA DRAWN: CLL DATE: 7-20-92 FILE: BASO.drw i UNOCAL Structure · BAKER Platform Well : Ba-30 1050_ _ 1400_ 1750_ 3150_ 3500_ 5950~, 7350t 770'31 8750! L 24- Csg Pt. KOP 5.00 BUILD 2.5 DEG / 100' ~~1 18 5/8' Csg Pt 0.00 15.00 20.00 5.00 EOC V E2P~A 3G 6E ANGLE DEG \\ 13 3/8' Csg Pt~ \ , \ \ Begin Build/Turn to l-ergot ~ 26.1,5 \ 3 DEG / 100' OOGLEG 25.93 26.97 i29.15 32.24 35.99 40.23 44.8O TARGET - Top Hemlock(G-l) -%-- 49.62 MAXIMUM ANGLE / 51.95 DEG t i Field : Middle Ground Shoals Location : Cook Inlet, Alaska ! .... WELL PROFILE DATA ..... i Point .... MD Inc 0ir ~ Nodh Eastl Tie on 0 0.00 0.00 0 0 i KOP 1500 0.00 ..342.771500 0 O! ~End of Build 2555 26.36 542.77 2518 228 -71! iEnd of Hold 6651 26.36 342.77 6188 1965 -6101 ',Target 8388 51.94 62.56 7600 2700 -8oi !End of Build 11094 51.95 62.56 9268 3682 1811i End of Hold 11194 51.9~5_ 62.56 9330 5718 1881J E a s f - - > 1000 750 500 250 0 250 500 750 1000 1250 1500 1750 2000 I fI II II I I I! II II I[ II II II II TD - 9 5/8 Casing Pt TARGET #2 (G-1R) ~,~- Iock(O - t ) % Begin Build/Turn to Target 3 3/8 Csg Pt EE0 N 1.7 DEG W 3661' (TO TD -,,PLANE OF PROPOSAL,,- C \ TARGET #2 (G-1R) ~, TD - 9 5/8" Pt Casing I i I I I I I I I I I I I I I i ~ I I i I 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 Scale 1 : 175.00 Vertical Section on 558.50 azimuth with reference 0,00 N, 0.00 E from slot #1-2 - _3250 ..500~ 2750 _2500 _ _2250 2000 1750 _ _1500 _ _1250 _ _100.0 750 500 0 250 Created by : jones For: L LOHOEFER Dote plo(ted : 28-Jul-93 Plot Reference is Bo30 Version #4. Coordinates ore in feet reference $1o[ #1-2. lrue Vel-ticol Depths ore reference wellhead. Baker Hughes INTEQ /% I I z UNOCAL BAKER PLatform Ba-30 slot #1-2 Middle Ground Shoals Cook Inlet, Alaska PROPOSAL L I ST I N G by Eastman TeLeco Your ref : Ba30 Version #4 Our ref : prop758 License : Date printed : 14-Jul-93 Date created : lO-Apr-93 Last revised : 13-Jul-93 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 45.778,w151 29 1.069 Slot Grid coordinates are N 2498072.852, E 235249.628 Slot local coordinates are 1932.00 S 539.00 E Reference North is True North UNOCAL BAKER Platform,Ba-30 Middle Ground Shoals,Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : Ba30 Version #4 Last revised : 13-Ju[-93 Measured Inclin. Azimuth True Vert. R E C T A N G U L A Depth Degrees Degrees Depth C 0 0 R D I N A T E 0.00 0.00 0.00 0.00 0.00 N 0.00 100.00 0.00 342.77 100.00 0.00 N 0.00 200.00 0.00 342.77 200.00 0.00 N 0.00 300.00 0.00 342.77 300.00 0.00 N 0.00 400.00 0.00 342.77 400.00 0.00 N 0.00 R Dogleg Vert S Deg/lOOFt Sect E 0.00 0.00 E 0.00 0.00 E 0.00 0.00 E 0.00 0.00 E 0.00 0.00 500.00 0.00 342.77 500.00 0.00 N 0.00 E 0.00 600.00 0.00 342.77 600.00 0.00 N 0.00 E 0.00 700.00 0.00 342.77 700.00 0.00 N 0.00 E 0.00 800.00 0.00 342.77 800.00 0.00 N 0.00 E 0.00 900.00 0.00 342.77 900.00 0.00 N 0.00 E 0.00 1000.00 0.00 342.77 1000.00 0.00 N 0.00 E 0.00 1100.00 0.00 342.77 1100.00 0.00 N 0.00 E 0.00 1200.00 0.00 342.77 1200.00 0.00 N 0.00 E 0.00 1300.00 0.00 342.77 1300.00 0.00 N 0.00 E 0.00 1400.00 0.00 342.77 1400.00 0.00 N 0.00 E 0.00 1500.00 0.00 342.77 1500.00 0.00 N 0.00 E 0.00 1600.00 2.50 342.77 1599.97 2.08 N 0.65 W 2.50 1700.00 5.00 342.77 1699.75 8.33 N 2.58 W 2.50 1800.00 7.50 342.77 1799.14 18.73 N 5.81 ~ 2.50 1900.00 10.00 342.77 1897.97 33.26 N 10.31 ~ 2.50 2000.00 12.50 342.77 1996.04 51.89 N 16.09 W 2.50 2100.00 15.00 342.77 2093.17 74.59 N 23.13 ~ 2.50 2200.00 17.50 342.77 2189.17 101.31 N 31.42 W 2.50 2300.00 20.00 342.77 2283.85 132.01 N 40.94 W 2.50 2400.00 22.50 342.77 2377.04 166.62 N 51.68 W 2.50 2500.00 25.00 342.77 2468.57 205.09 N 63.61 W 2.50 2554.62 26.36 342.77 2517.80 227.70 N 70.62 ~ 2.50 3000.00 26.36 342.77 2916.84 416.61 N 129.22 ~ 0.00 3500.00 26.36 342.77 3364.83 628.69 N 195.00 ~ 0.00 4000.00 26.36 342.77 3812.82 840.77 N 260.78 W 0.00 4500.00 26.36 342.77 4260.81 1052.85 N 326.57 ~ 0.00 5000.00 26.36 342.77 4708.80 1264.93 N 392.35 ~ 0.00 5500.00 26.36 342.77 5156.79 1477.01 N 458.13 W 0.00 6000.00 26.36 342.77 5604.78 1689.09 N 523.91 W 0.00 6200.00 26.36 342.77 5783.98 1773.93 N 550.22 ~ 0.00 6500.00 26.36 342.77 6052.77 1901.17 N 589.69 W 0.00 6651.02 26.36 342.77 6188.08 1965.23 N 609.56 W 0.00 6700.00 26.12 346.05 6232.01 1986.09 N 615.38 ~ 3.00 6800.00 25.87 352.87 6321.91 2029.11 N 623.40 ~ 3.00 6900.00 25.94 359.74 6411.88 2072.64 N 626.21 W 3.00 0.00 0.00 0.00 0.00 24" Csg Pt 0.00 0.00 0.00 0.00 0.00 0.00 0.00 KOP 2.10 8.40 18.89 33.55 52.34 18 5/8" Csg Pt 75.24 102.20 133.16 168.08 206.88 229.69 EOC 420.25 634.19 848.12 1062.06 1276.00 1489.93 1703.87 1789.44 13 3/8" Csg Pt 1917.80 1982.42 Begin Build/Turn to Target 2003.44 2046.68 2090.28 7000.00 26.33 6.49 6501.68 2116.56 N 623.80 ~ 3.00 2134.10 7100.00 27.02 13.00 6591.06 2160.74 N 616.19 W 3.00 2178.04 7200.00 28.00 19.14 6679.76 2205.06 N 603.38 W 3.00 2221.96 7300.00 29.23 24.85 6767.56 2249.40 N 585.41 ~ 3.00 2265.75 7400.00 30.69 30.11 6854.21 2293.64 N 562.34 ~ 3.00 2309.29 7500.00 32.34 34.90 6939.47 2337.66 N 534.23 ~ 3.00 2352.46 7600.00 34.16 39.26 7023.11 2381.34 N 501.15 Y 3.00 2395.14 7700.00 36.11 43.22 7104.90 2424.56 N 463.20 W 3.00 2437.22 7800.00 38.18 46.81 7184.62 2467.20 N 420.47 ~ 3.00 2478.57 7900.00 40.36 50.08 7262.04 2509.14 N 373.09 W 3.00 2519.09 All data is in feet unless otherwise stated Coordinates from slot #1-2 and'TVD from wellhead (118.00 Ft above mean sea level) Vertical section is from wellhead on azimuth 358.30 degrees. Declination is 0.00 degrees, Convergence is -1.30 degrees. Calculation uses the minimum curvature method. Presented by Eastman Teleco UNOCAL BAKER Platform, Ba-30 Middle Ground Shoals,Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : Ba30 Version #4 Last revised : 13-Ju[-93 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 8000.00 42.61 53.06 7336.95 2550.27 N 321.19 W 3.00 8100.00 44.94 55.80 7409.16 2590.48 N 264.91 W 3.00 8200.00 47.33 58.32 7478.45 2629.65 N 204.40 W 3.00 8300.00 49.77 60.65 7544.65 2667.68 N 139.82 ~ 3.00 8387.69 51.94 62.56 7600.00 2700.00 N 80.00 ~ 3.00 2558.67 2597.19 2634.55 2670.65 2701.18 TARGET - Top Hemlock(G-I) 11093.68 51.95 62.56 9268.00 3682.00 N 1811.00 E 11193.68 51.95 62.56 9329.64 3718.29 N 1880.88 E 0.00 3626.75 TARGET #2 (G-1R) 0.00 3660.95 TD - 9 5/8" Casing Pt All data is in feet unless otherwise stated Coordinates from slot #1-2 and TVD from wellhead (118.00 Ft above mean sea level) Vertical section is from wellhead on azimuth 358.30 degrees. Declination is 0.00 degrees, Convergence is -1.30 degrees. Calculation uses the minimum curvature method. Presented by Eastman Teleco UNOCAL PROPOSAL LISTING Page 3 BAKER Platform, Ba-30 Your ref : Ba30 Version #4 Middle Ground Shoals,Cook Inlet, Alaska Last revised : 13-Ju[-93 Comments in wettpath MD TVD Rectangular Coords. Comment 800.00 800.00 0.00 N 0.00 E 24" Csg Pt 1500.00 1500.00 0.00 N 0.00 E KOP 2000.00 1996.04 51.89 N 16.09 W 18 5/8" Csg Pt 2554.62 2517.80 227.70 N 70.62 W EOC 6200.00 5783.98 1773.93 N 550.22 W 13 3/8" Csg Pt 6651.02 6188.08 1965.23 N 609.56 W Begin Build/Turn to Target 8387.69 7600.00 2700.00 N 80.00 ~ TARGET - Top Hemlock(G-I) 11093.68 9268.00 3682.00 N 1811.00 E TARGET #2 (G-1R) 11193.68 9329.64 3718.29 N 1880.88 E TD - 9 5/8" Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 800.00 800.00 O.OON O.OOE 24" Csg 0.00 0.00 O.OON O.OOE 2000.00 1996,04 51.89N 16.09~ 18 5/8" Csg 0.00 0.00 O.OON O.OOE 6200.00 5783,98 1773.93N 550.22W 13 3/8" Csg 0.00 0,00 O.OON O.OOE 11193.68 9329,64 3718.29N 1880.88E 9 5/8" Csg Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised Ba30 T/Hemlock#3 not specified 7600.00 2700,00N 80.00~ lO-Apr-93 G-1R not specified 9268.00 3682,00N 1811.00E 13-Jul-93 All data is in feet unless otherwise stated Coordinates from slot #1-2 and TVD from wellhead (118.00 Ft above mean sea level) Bottom hole distance is 4166.94 on azimuth 26.83 degrees from wellhead. Total Dogleg for wellpath is 78.47 degrees. Vertical section is from wellhead on azimuth 358.30 degrees. Declination is 0.00 degrees, Convergence is -1.30 degrees. Calculation uses the minimum curvature method. Presented by Eastman Teleco UNOCAL BAKER Platform Ba-30 slot #1-2 Middle Ground Shoals Cook Inlet, Alaska CLEARANCE REPORT by Eastman Teleco Your ref Ba30 Version #4 Our ref : prop758 License : Date printed : 14-Jul-93 Date created : lO-Apr-93 Last revised : 13-Jul-93 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 45.778,w151 29 1.069 Slot Grid coordinates are N 2498072.852, E 235249.628 Slot local coordinates are 1932.00 S 539.00 E Reference North is True North Main calculation performed with 3-D minimum distance method Object wellpath Ba29 Version'#5,,Ba-29,BAKER Platform Ba-28 Version #7,,Ba-28,BAKER Platform GMS <0-9645'>,,16,BAKER Platform MSS <0-10000'>,,12,BAKER Platform PGMS <0-9642'>,,20,BAKER Platform GMS <0-7400'>,,6,BAKER Platform GMS <0-11600'>,,27,BAKER Platform GMS <0-10691'>,,13,BAKER Platform MSS <1039-12500'>,,lO,BAKER Platform PGMS <0-9722'>,,23,BAKER Platform GMS <8300-9445'>,,7,BAKER Platform GMS <0-7232'>,,17,BAKER Platform MSS <5626-10231'>,,18~BAKER Platform MSS <765-9543'>,,11,BAKER Platform MSS <6757-9944'>,,9Rd#1,BAKER Platform GMS <0-9760'>,,9Rd#2,BAKER Platform MSS <2653-11495'>,,9,BAKER Platform GMS <0-11128'>,,5,BAKER Platform MSS <3165-10455'>,,14,BAKER Platform MSS <0-9215'>,,4,BAKER Platform PGMS <0-9544'>,~15wBAKER Platform MSS <6950-10116'>,,15Rd,BAKER Platform PGMS <7200-9800'>,,25Rd,BAKER Platform MSS <7117-8642'>,,25,BAKER Platform GMS <0-9250'>,,8Rd~BAKER Platform MSS <2008-10314'>,,8~BAKER Platform Closest approach with 3-D minim~zn distance method Last revised Distance M.D. 8-Jul-93 5.4~') 1500.0 14-Jun-93 5 0z 400.0 24-May-93 8011/ 200.0 23-May-93 78.7 500.0 24-May-93 76.3 500.0 24-May-93 54.9 1500,0 24-May-93 59.2 1200.0 23-May-93 71.8 1200.0 23-May-93 58.1 1300.0 24-May-93 81.3 1533.3 24-May-93 59.3 1533.3 24-May-93 5.6~ 2107.1 24-May-93 1.5-'~ 500.0' 23-May-93 8.1,? 200.0 23-May-93 10.0 200.0 23-May-93 10.0 200.0 23-May-93 10.0 200.0 24-May-93 9.9~i 300.0 23-May-93 7.3/j 400.0 24oMay-93 63.6 1400.0 3-Jun-93 77.1 200.0 3-Jun-93 77.1 200.0 3-Jun-93 68.8 1566.7 3-Jun-93 68.8 1566.7 3-Jun-93 85.9 700.0 3-Jun-93 85.9 700.0 Diverging frown M.D. 7575.0 11193.7 300.0 9198.8 500.0 1500.0 11193.7 8712.1 11193.7 6441.1 1533.3 2107.1 8387.7 6640.0 10172.2 9847.8 11093.7 8874.4 10010.0 1400.0 11180.0 7950.2 1566.7 1566.7 700.0 11180.0 Scale 1 · 400.00 F. 4OO 0 400 800 1200 1 600 2000 2400 5500 350C 6500, 3500 250 4500 2500 500 iO0 I I I 4500 8500 8500 25OO 500 8500 7500 5500 500 2OOO _ 1 600 _ 1200 _ 8OO _ 4OO _ 0 _ 400 _ 8OO 200 _ 1600 _ 2000 /k I I Z 0 I I V 0 0 Scale 1 · 20.00 klasf 440 46O 48O I I I I I I 5OO 120C 1800 1200 1400 2OO 1600 520 1800 5200 540 560 58O I O0 1200 26OO 800 4800 2OOO 2200 5000 2400140( 2200 1800 2600 ~ 'E '-,~ "'""':' · -,..~-%:. ~..--- ~.. ~,¢:'~','~,.~ ;~C,.~, 600 · 1840 _1860 _1880 1900 1920 1940 1960 1980 0 2O40 0 V "AGE J = Driiling Fluids Co. J J MagcolDar,,IMCO A Dresser Halliburton Company _ I OF II II UNOCAL BAKER PLATFORM CHAKACHATNA DEVELOPMENT 929, #30, AND #28 DEPTH INTERVAL 0 - 800 ' 17½"/28" HOLE 24" CASING MUD TYPE MUD ADDITIVES POTENTIAL PROBLEMS COST PER BARREL F.I.W./GENERIC MUD #2 M-I GEL/M-I BAR/SODA ASH/ CAUSTIC/LIME HOLE CLEANING/GRAVEL/ GAS KICK/LOST CIRCULATION $6.71 ESTIMATED TREATMENTS / PROCEDURES 1) Build spud mud system with prehydrated bentonite in fresh water and filtered inlet water. a) Treat drill water with Soda Ash as required to reduce calcium content to 40± ppm. b) Pre-hydrate 25 lbs/bbl bentonite and 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. i I i 2) Drill hole. 3) Drill to 800'. Underream hole to 28". Use all solids control equipment. Raise viscosity if gravel sections are encountered. Run 24" casing. 4) Save and reuse mud on wells 29 and 30. Build additional volume as required. · ,~, 7 DM- 131. WP , ,: · -' "'" ,¢.~X~;,;~ (4/93) .. .. ,.,._,.,..,:.;,~.,.¢'"" 11 l ' Drilling Fluids Co. ! ~' / Magcobar;IMCO A Dresser/Halliburton Company / -- ! '~..L. '~ HOEFER ? P, ". } ;993 ANTICIPATED MUD PROPERTIES Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels Fluid Loss (API) pH 8.8 - 9.4 ppg 50-100 sec/qt. 10-15 cps 15-30 #/100ft2 8-20 No Control 8.5 - 9.5 DM-131 .WP (4/93) i 1 DEPTH INTERVAL OF ' Driiling Fluids Co. ! .... j MaacoDar IMCO A Dresser;Halliburton Company !. ,/ UNOCAL BAKER PLATFORM CHAKACHATNA DEVELOPMENT #29, #30, and #28 ~.,-. LOHOEFER 800' - 3000' 17-1/2"/24" HOLE 18-5/8" CASING MUD TYPE MUD ADDITIVES F.I.W./GENERIC MUD #2 M-I GEL/M-I BAR/SODA ASH/ POLYPAC / SPERSENE / XP- 20 / SODIUM BICARBONATE / CAUSTIC 1 POTENTIAL PROBLEMS COST PER BARREL HOLE CLEANING/TIGHT HOLE/BIT BALLING/ GUMBO CLAYS/HOLE ENLARGEMENT/GAS KICKS/ COAL SLOUGHING $5.68 ESTIMATED TREATMENTS/PROCEDURES 1) Use the surface mud from well #28 to drill the 24" collar, cement and shoe. Treat this fluid as required to avoid excessive'cement contamination. 2) Build additional volume as required with prehydrated bentonite in fresh water and filtered inlet water. 3) Pump viscous sweeps as required. i d 4) Control density with barite, F.I.W. water, and solids control equipment. Dump all sand traps as required. If MBT exceeds 25 lbs/bbl, or if low gravity solids exceed 75 ppb, then the system should be diluted to reduce unwanted drill solids. DM- 131. WP (4/93) ~J~~Drilling Fluids Co. / . . ] Ma~cobar.'lMCO ~, Dresser ~all~burton Company i ! OF '"__,.~..~ LOHOEFER "PR ;.11995 11 ! 1 ! 1 II t 5) Report drill solids analysis on mud check sheet. 6) Report hydraulics calculations on mud check sheet. 7) Use Defoam-X if foaming becomes a problem. 8) Prehydrate all bentonite in freshwater. 9) Drill to 3000'. Underream hole to 24". Run 18-5/8" casing. ANTICIPATED MUD PROPERTIES Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels API Fluid Loss pH MBT Drilled Solids 9.0-9.4 ppg 45-75 sec/qt 10-15 cps 10-20 #/100ft~ 6/12/18 NO CONTROL 8.5-9.5 < 25 lbs/bbl < 75 lbs/bbl Note: This mud program is a guideline only. should dictate actual mud properties. Hole conditions 1 DM-131 .WP (4/93) 11 '~GE ' Driiling Fluids Co. / I MagcoDar. IMCO A Dresser htall~Durton Comoany OF '.L. LOHOEFER IJ Ii DEPTH INTERVAL MUD TYPE UNOCAL BAKER PLATFORM CH~J(3~CHATNA DEVELOPMENT #29, #30, AND #28 3000' - 7500' 17½" HOLE F.I.W./GENERIC MUD #2 lJ ti MUD ADDITIVES POTENTIAL PROBLEMS COST PER BARREL M-I GEL/M-I BAR/SODA ASH/ POLYPAC / SPERSENE / XP- 20 / SODIUM BICARBONATE/ CAUSTIC HOLE CLEANING/TIGHT HOLE/ BIT BALLING/GUMBO CLAYS/ HOLE ENLARGEMENT/GAS KICKS/ COAL SLOUGHING $7.32 ESTIMATED TREATMENTS/PROCEDURES 1) If possible, isolate a small pit volume of surface mud to drill the 18-5/8" collar, cement and shoe. Treat this fluid as required to avoid excessive cement contamination. 2) Displace this mud with uncontaminated surface mud to drill the 17-1/2" hole. 3) Reduce filtrate with Polypac or Polypac UL to 15 cc (API). 4) Control density with barite, F.I.W. water, and solids control equipment. Dump all sand traps as required. If MBT exceeds 25 lbs/bbl, or if low gravity solids exceed 75 ppb, then the system should be diluted to reduce unwanted drill solids. 5) Report drill solids analysis on mud check sheet. 6) Report hydraulics calculations on mud check sheet. 7) Use Defoam-X if foaming becomes a problem. DM-131 .WP (4/93) Ii OF J ' Drilling Fluids Co. / J MagcoDar. IMCO A Dresser?Halliburton Comoany ! I *' LOHOEFER "993 8) Prehydrate all bentonite in freshwater. 9) Drill to 7500'. Run 13-3/8" casing. 10) Save and re-use mud on wells 30 and 28. ANTICIPATE MUD PROPERTIES Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels API Fluid Loss pH MBT Drilled Solids 9.0-9.4 ppg 45-65 sec/qt 10-15 cps 10-20 #/100ft2 6/12/18 15 cc 8.5 - 9.5 < 25 lbs/bbl < 75 lbs/bbl Note: This mud program is a guideline only. should dictate actual properties. Hole conditions i DM-131 .WP (4/93) .... · E DF Driiling Fluids Co. / ! ,MaacoDar iMCO .~. DresserHalhburton Company i I UNOCAL BAKER PLATFORM CHAKACHATNA DEVELOPMENT ,%29, #30, AND #28 '~.' LOHOEFER i II ii DEPTH INTERVAL MUD TYPE MUD ADDITIVES POTENTIAL PROBLEMS COST PER BARREL STANDARD 12,000' 12-1/4" HOLE CONTINGENT 14,000' 8-1/2" HOLE F.I.W. GENERIC MUD #2 W/PHPA POLYMER M-I GEL/M-I BAR/SODA ASH/ PHPA/TACKLE/DRISPAC/XCD POLYMER/PH-6/CAUSTIC/ SODIUM BICARBONATE/ SOLTEX/RESINEX/TEKMUD 8533 TIGHT HOLE/HOLE ENLARGEMENT/GAS KICKS/ LOST CIRCULATION/ PRESSURED SHALE/KEY SEATING/COAL SLOUGHING/ DIFFERENTIAL STICKING $38.00 ESTIMATED TREATMENTS/PROCEDURES 1) Isolate a small pit volume of surface mud to drill the 13-3/8" collar, cement and shoe. Treat this fluid as required to avoid excessive cement contamination. 2) Pre-mix the PHPA system as follows: a) Pre-hydrate 8-10 ppb of bentonite. b) Add PHPA 0.5-1.0 ppb through shearing device. NI ~AG E Drilling Fluids Co. / , j Magco[~ar IMCO A Dresser Haihburton Comoany / ./ OF *' LOHOEFER 4) Control density with barite, drill water, and solids control equipment. Dump all sand traps as required. If MBT exceeds 17 ppb, or if low gravity solids exceed 50 ppb, then the system should be diluted to reduce unwanted drill solids. 5) Report drill solids analysis on mud check sheet. 6) Report hydraulics calculations on mud check sheet. 7) Use Defoam-X if foaming becomes a problem. 8) Tekmud 8533 may be added to the system to reduce torque and drag. 9) Use Polypac UL and/or SP-101 for additional fluid loss control. 10) Add Soltex @ 4-6 ppb for coal stability. 11) Drill to T.D. Short trip to check for fill. Log, run, and cement the 7.0" liner. If fluid is in good condition, reuse on next well. 12) If contingent 5" liner is run, treat the PHPA mud system for cement contamination with PH-6 and Bicarb. ANTICIPATED MUD PROPERTIES it i1 Mud Density (ppg) Funnel Viscosity(sec/qt) Plastic Viscosity (cps) Yield Point (#/100ft~) Gels (#/100ft2) API Fluid Loss (cc) *HPHT Fluid Loss (cc) MBT (lbs/bbl) Drilled Solids (lbs/bbl) Polymer Conc. (lbs/bbl) 9.5 13.5 40-50 40-65 10-20 12-25 10-25 10-25 4/12/18 6/12/18 5 5 10 10 <17 <17 <35 <35 0.5 0.5 Note: This mud program is a guideline only. should dictate actual mud properties. Hole conditions * 500 psi @ 150°F or BHT +25°F. DM-131 .WP (4/93) FILL-UP I MSP ANNULAR BOP 20s/~'' 2000 psi II sPoo~, tl I 1 27~4:'3000 PIPE RAMS 20s/~'' 3000 psi FLOW BLIND RAMS 3"- 1 OM 20s/4''3000 psi CHECK VALVE HCR HCR _~ [~ MANUAL I DRILLING [ MANUAL ~ KILL -~ ~~x~~~~'A~O3/S2P30%(~Lpsl~~[~/~ CH 0 KE LINE 3"-ZOM// Il '~% 4"-tOM I GATE VALVES PIPE RAMS ] 20s/~'' 3000 psi I GATE VALVES LINE~ RISER 20%" 3000 psi CH-AKACH-ATNA RIG. 428 BOP/DIVERTER STACK 21 +J; 2000psi/2Oa/~'' 3000psi FILL- UP ~ FLOW ANNULAR BOP 354"5000 psi i ?tPE RAMS 135/8"5000 psi ! 3" - 10M BLIND RAMS CT--T~PT~ ~r^T~r~' 135/8"5000 psi ~ -X, fANUAL I DRILLINGI MANUAL l~,~, ~ SPOOL s,~.l~]T~~ LINE ~]2::> ~"~'~8s/~'5000 p CHOKE GATE VALVES PIPE RAMS } GATE VALVES 13s/d'5000 psi I LINE~ RISER 5000 psi CHAKACHATNA RIG 4-28 ' BOP[ STACK 13 %" 5000 psi VENT OUTSIDE OF WlNOWALLS 4' 5,000 PSI BALL ~ 7/76-5M FL~. X ,~ 7/76-SM HUg 5M TARGET BLIND HU9 Eli_LIS AD J, TEST 3" RELIEF' VALVE SET AT 40 PSI 10" VENT LINE CLAMP HUg CONNECT/ON BUFFER TANK ~o" ~5o lb. BUNO FLANCE 10" 150 ~. FLANGE MUD CAS SEPERATOR SIPHON LINE 150 lb. FLANGE II I TO SHAK~ t5 c~,.~P ,y Bx~55 I0, 000 PSI I..IYD. CHOKE ,~. TO PRODUCT/ON SEPARATOR $" MUO RETURN UNE UNOCAL CHOKE AANIFOLO COOK INLET OW& CM-1:12592 A III PLAN VIE~ @ NO~,,~T~$T LEC ¥IE~' A-A arc ft-6 ri- l I I I I I I I I I I I WHEN CLOSe, VALVE ~T/CALLY 6. WHEN VALVE V,~.VE 'B* CLOS~ 7. ~ "~, V~ PA4 RIG 428 20 3/~" - 3u BLOW-OUr PREVENTE~ ST,~CK RSRRdSA ISSUEI JUL 20 1995 REFERENCE DRAWING 428.5039 FOR FURTHER INFORI/IAllO~ PERTAINING TO OlVERTER LINE SPOOLS. DIVERTER UNE LAYOUT NORTHWEST LEG PosmoN POOL RIG 428 ~lk fg-B PLAN A VIEW ON SOUTHWEST LEG I:1 1111/\ II1 ~' "-~/",x/Ill I1',! I - 22'-4' il( ::'~ .-, :,~ I - 1'--4 I/4' Ira' IfF WX 11-4 NOFTH-EA~T LEG ! - ~'-o' I - r-a i/1' NORrH- I~ES T ! - ! - ~'-o' ~Y4Ci71 T~E PLAN WEW I - I - lit SOUTH-#~T I.~.G I - I0'-~' ~E SHOWN VIEW A-A ON NORTHEAST LEG NOTE: REF£REIVCE ORAWlNC, 428.5059 FOR FUR[H£R INFORI~4TION PERTAINING TO DIVER[ER LINE SPOOLS. DIVERTER LINE LAYOUT SOUTHWEST & EAST LEG PosmoNs POOL RIG 428 TOP OF PW RAIL i , I :1 TOP OF BOP STACK TOP OF P/N R4A. :[ PLATFORMS I S.$ U E DILLON/,~W~ .,.~,'~ . ,c . . ~ I I 19'-~ W~ ]7'-2;19~6 11/1~ W~ 19:-7 1/1~; i HIGH D~ER~R STACK ~D BOP STAC[ UOC P~ORMS ~, DI~ON, P~ RIO 428 I I I ~~~ ~ ~ ~ v~-,'~ - AL ' £'RNA TE .)PPER OSITION · ' 'FRAtiSF[:.R TO/FRO~! t;D~Tr,"OR!,., ..... ..... ' '""~"-- ................. i ~. DITCH GATES I '~' . ~1 ' ; , ; ~ :~: ~ ~,~ : . L~l . i , · . I -- I ' FN '~ ,~ I I ' · I ' '. I , . ,,,_ :., ~,~. ~ ~ ~ ~ F-: ~ : ~"~, , .... ~n .... I ~. ',: ~.~' ' '~ ~ - I I I ~ [ : PU~P '~ J ' ' '. I : ~ . __. L - I I &' : J ' : '~ ' ~CR~W _ .............. , .: .. . · -.~.-.~--:.-. - ........ ~- ...... -..~ ~ ............... ~ .... ~ ........ ~ ~. , ~':~ ~? ~ ~- ~ ~, ~ ? i i -'~' "~ ............ ~.;; E~ ~-.1 ''! ' i ~~ "- ~ F..~.L7~ . .~~ ~ ~u~ r : '~ ~ ~ FH ~ :, ~ ~--~ pu~P~ I i ,, fl inn x~l~l I'~d E '. . : n '~.._u._j._u. N :. I m II IIIII ,~111 I_M : ~ ''- ',., TRANSFER mOM PM~ORAt i i ~"~' --' n ~ ' I : ~' P-t~ ; : ~11 OJL~L.L A-i/OOPT ' ~ ' ' '.- ....i ~"~'~ ........~ [ bid i : ~ ~ - i i ~ ' ~ ..-~ ........ ~ ~ ....... ~}~ ............... ~ ~~~~~~~'~ i i -~ ....... +-~ ~ ~ ~:;,, i ~ /~~t ................ ~N ...... ,... LOW .REssU~ ~UO ~a P/O~R dUL g U ~ DE. HOER ~ . PM RIG 428 '~l~l~,l~%l~l,~ i 428.5011 PILL PIT -'"' 55 BBL ...~ "2/'~×~ ~.,- ~ J SUCTION TANK ; ~ ~O ~.L ~ ~ i~' - -- ~ .,~ ~ i '-~ ~ ~ .... .--~ ~0 ...... J OE24~OER I ~ PIT ~ ~ x . DEG~SER ....I ~ ,~, 105 BBL ~O TRAP O~R~O~' , 50 BBL WE'IR _ ~. ~. / _, ..... PIONEER S-800 SIDEWINDER MUD HOPPER Rotary Kelly Bushing (RKB) Drill Deck Level Production Deck Level Dev. 118' Dev. 78' Elev. 62' Seo Level (MLW) El ev. O' Mud Line Elev. - 102' Lk 30" Structural @ 303' RKB (83' BLM) 24" Conductor @ 800' RKB (580' BML) 156#, X-42, MTS6OAR 18-5/8" Surface @ 2000' 97#, X-56, QTE60 13-3/8" IntermedicC. e @ 6200' 68#, K-55, BTC 9-5/8" Production @ 109 15' 47#, L-80, BTC BAKER PLATFORM ELEVATION DIMENSIONS UNOCAL ENERGY RESOURCES ALASKA DRAWN' CLL DATE: 7- 15-92 FILE: BAKELEV. drw WELL: 1. 2. 3. BAKER ~30 MUD WT. I 8.8 PPG 9.0 PPG 9.5 PPG CASING SIZE 1. 24" 2. 18-5/8" 3. 13-3/8" 4. 9-5/8" 5o INTERVAL BOTTOM 800' 800' 2000 2000 6200 5784 11194 9330 FIELD: MIDDLE GROUND SHOAL CASING DESIGN DATE: AUGUST 2, 1993 DESCRIPTION TOP LENGTH WT. GRADE THREAD WEIGHT TENSION MINIMUM W/ BF -TOP OF STRENGTH W/O BF X SECTION TENSION LBS LBS 1000 LBS 56' MD 744 156#, X-42, MTS 60 AR 116,064 56' TVD 56' MD 1944 97#, X-56, QTE 60 188,568 56' TVD 56' MD 6144' 68#, K-55, BTC 417,792 56' TVD 56' MD 11138' 47#, L-80, BTC 523,486 56' TVD SAME SAME SAME SAME 1928 1594 1069 1086 TDF 16.61 8.45 2.55 2.07 DESIGN BY: COLLAPSE PRESS @ BOTTOM PSI C.L. LOHOEFER M.S.P. 280 psi 564 psi 770 psi COLLAPSE RESIST. BURST TENSION PRESSURE PSI CDF PSI MINIMUM YIELD PSI 229 860 3.75 350 1970 960 1.69 1372 1950 1.17 2100 4750 1.13 2100 572 1654 4199 2630 3450 6870 BD___EF 5.63 1.92 1.64 3.27 NOTES: See attached for calculation of M.S.P. including assumptions & estimates. ,.. .. .:., .- ~.; - . .'~ %:' ...... ':~.'_" "::'~i~. '"'~'"' 'i ... .... Depth Interval= Baker Platform Well #30 Pressure Calculations August 02, 1993 0 - 800' 17-1/2" / 28" 24" casing hole size Mud weight: ............................. 8.8 PPG = .46 psi/ft. Shoe (24") depth: .............................. 800'MD/800'TVD Estimated fracture gradient (24" shoe): .......... 0.85 psi/ft. Total depth: ................................. 2000'MD/2000'TVD Bottom hole pressure gradient: ................... 0.35 psi/ft. Maximum surface pressure cannot exceed maximum bottom hole pressure: 800' * 0.35 psi/ft = 280 psi Depth Interval: 800' - 2000' 17-1/2" / 24" hole size 18-5/8" casing Mud weight: ............................. 9.0 PPG = .47 psi/ft. Shoe (18-5/8") depth: ....................... 2000'MD/2000'TVD Estimated fracture gradient (18-5/8" shoe): ...... 0.85 psi/ft. Total depth: ................................. 6200'MD/5784'TVD Bottom hole pressure gradient: ................... 0.45 psi/ft. Gas gradient (assume worst case) .................. 0.0 psi/ft. Wellbore volume with gas kick situation: 3/4 mud & 1/4 gas. Maximum surface pressure = Btm hole press - Hydrostatic press MSP = BHP - (3/4 mud + 1/4 gas) MSP=(5784 ft * .45 psi/ft) - ((.75 (5784 ft * .47psi/ft.)) + (.25 (5784 ft * 0 psi/ft.))) MSP = 564 psi. Therefore, the greatest hydrostatic pressure at the 18-5/8" shoe (HPsh) is when the gas bubble reaches the shoe if a constant BHP is applied. A conservative estimate would be the maximum surface pressure (MSP) plus the hydrostatic pressure at that casing depth (HPcsg). HPsh = MSP + HPcsg HPsh = 564 psi +(2000 ft * .47 psi/ft.) HPsh = 1504 psi Baker Platform Well #30 This (HPsh = 1504 psi) is less than the fracture the same shoe (FPsh = .85 psi/ft * 2000 ft = 1700 psi) thus sufficiently adequate to handle the well kick. Depth Interval: 2000' - 6200' 17-1/2" hole size 13-3/8" casing Maximum surface pressure calculation; Mud weight: ............................. 9.5 PPG = .49 psi/ft. Shoe (13-3/8") depth: ....................... 6200'MD/5784'TVD Estimated fracture gradient (13-3/8" shoe): ...... 0.90 psi/ft. Total depth: ................................ ll194'MD/9330'TVD Bottom hole pressure gradient: ................... 0.45 psi/ft. Gas gradient (assume worst case) .................. 0.0 psi/ft. Wellbore volume with gas kick situation: 3/4 mud & 1/4 gas. Maximum surface pressure = Btm hole press - Hydrostatic press MSP = BHP - (3/4 mud + 1/4 gas) MSP=(9330 ft * .45 psi/ft) - ((.75 (9330 ft * .49psi/ft.)) + (.25 (9330 ft * 0 psi/ft.))) MSP = 770 psi. Therefore, the greatest hydrostatic pressure at the 13-5/8" shoe (HPsh) is when the gas bubble reaches the shoe if a constant BHP is applied. A conservative estimate would be the maximum surface pressure (MSP) plus the hydrostatic pressure at that casing depth (HPcsg). HPsh = MSP + HPcsg HPsh = 770 psi +(5784 ft * .49 psi/ft.) HPsh = 3604 psi HPsh - Pore Pressure at shoe < Yield 13-3/8" casing 3604 - (5784'*0.45) < 3450 1001 psi < 3450 psi This (HPsh = 3604 psi) is less than the fracture pressure at the same shoe (FPsh = .90 psi/ft * 5784 ft = 5205 psi) and thus sufficiently adequate to handle the well kick. These scenarios are considered extreme since actual well kicks of recent history have seen a maximum of 300 psi on the shut-in casing pressure. Memorandum UNOCAL ) Pre-Spud Drilling Prognosis Baker Platform July 28, 1993 The following information is intended to familiarize the individual with the upcoming drilling Program at Baker Platform. Though this drilling prognosis is not a detailed drilling procedure it should serve as an outline. Many ongoing plans within Unocal and other service companies can and will change this program. Please read it carefully. Batch drilling (Baker wells #28, 29, 30) thru the 13-3/8" casing depths is a planned objective and is expected to yield many practical benefits. Benefits - Eliminates (12)NU/ND requirements of Div/BOPE. - Eliminates RU/RD of dimensional OD equipment. - Allows drilling mud to be re-cycled. - Less transportation of equipment. - Increases crew familiarization with opers. - Improves safety in all aspects. - Minimizes consumable inventory & prioritize usage. - Increases geologic.interpretation time allowed. - Maximizes equipment utilization. - Develops learning curve quicker. - Maximizes overall efficiency in all operations. - Decreases well interference (collision) problems. Batch Drilling Procedure ******* STAGE ONE ******* Well ]~29 (24" Casing) 1) 2) 3) 4) Install 30" drilling nipple or diverter system and drill 17-1/2" hole to 800' MD. Underream from 17-1/2" hole section to 28". Run and cement 24" casing to 800'. Secure wellbore, skid rig to next well #30. FORM 1-0C03 (REV_ 8-85) PRINTED IN U.S.A. Baker Pre-Spud Drilling Prognosis July 28, 1993 Page 2 Well ~30 (24" Casing) 1) 2) 3) 4) Install 30" drilling nipple or diverter system and drill 17-1/2" hole to 800' MD. Underream from 17-1/2" hole section to 28". Run and cement 24" casing to 800'. Secure wellbore, skid rig to next well #28. Well #28 (24" Casing) 1) 2) 3) Install 30" drilling nipple or diverter system and drill 17-1/2" hole to 800' MD. Underream from 17-1/2" hole section to 28". Run and cement 24" casing to 800'. ******* STAGE TWO ******* Well ~28 (18-5/8" Casing) 1) Nipple up combination 20-3/4" 3M BOPE / Diverter System. 2) Drill 17-1/2" hole to 2600' underream same to 24" 3) Run and cement 18-5/8" casing to 2600'. 4) Secure wellbore, skid rig to well #29. Well #29 (18-5/8" Casing) 1) Nipple up combination 20-3/4" 3M BOPE / Diverter System. 2) Drill 17-1/2" hole to 2000' underream same to 24" 3) Run and cement 18-5/8" casing to 2000'. 4) Secure wellbore, skid rig to well #30. Well #30 (18-5/8" Casing) 1) Nipple up combination 20-3/4" 3M BOPE / Diverter System. 2) Drill 17-1/2" hole to 2000' underream same to 24" 3) Run and cement 18-5/8" casing to 2000'. Baker Pre-Spud Dri11ing Prognosis July 28, 1993 Page 3 STAGE THREE ********* Well ~30 (13-3/8" Casing) 1) 2) 3) 4) Nipple up combination 20-3/4" 3M BOPE. Drill 17-1/2" hole to 6200' MD. Run and cement 13-3/8" casing to total depth. Secure wellbore, skid rig to well #28. Well ~28 (13-3/8" Casing) 1) 2) 3) 4) Nipple up combination 20-3/4" 3M BOPE. Drill 17-1/2" hole to 6000' MD. Run and cement 13-3/8" casing to total depth. Secure wellbore, skid rig to well #29. Well ~29 (13-3/8" Casing) 1) 2) 3) Nipple up combination'2'0-3/4" 3M BOPE. Drill 17-1/2" hole to 6200' MD. Run and cement 13-3/8" casing to total depth. This completes the batch drilling process. Each well is now drilled to total depth (12-1/4") using the 13-5/8" 5M BOPE stack and completed one at a time. Since Well #29 is the last well of recent work it will be the first well drilled to total depth and completed. ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE ( 1 ) Fee ~/~6 [2 thru 8] [9 thru 13] ~/~. [10 & 13] [14 thru 22] (4) Casg [23 thru (5) BOPE (6) Other ~(: ~ [29 thru 31] (7) Contact/_~/'_ _~ [32] (8) Addl ~ '~- ,1, geology' engineering: DWJ MTM RAD~ RPC//~-' BEWj~ JDH TA~ ~,,-~ rev 6/93 jo/6.011 Company ~//(~ / YES 1. Is permit fee attached ............................................... ~ 2. Is well to be located in a defined pool .............................. L 3. Is well located proper distance from property line ......... ' ......... 4. Is well located proper distance from other wells ..................... ~ 5. Is sufficient undedicated acreage available in this pool ............. /~ . 6. Is well to be deviated & is wellbore plat included ................... ~ 7. 8. · 10. 11. 12. 13. 14. 15. Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease ntrnber appropriate .......................................... Does' well have a unique name & nLrnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required .............. ~ ......................... Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE ~.tt~ched .... Does BOPE have sufficient pressure rating -- test to Does choke manifold comply w/API RP-53 (May 84) ........ ~ ............ Is presence of H2S gas probable ...................................... Lease & Well NO REMARKS 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26 27. 28. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone nLrnber of contact to supply weekly progress data ...... 29. 30. 31. 32. 33. Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE UM Exp~e~ Inj MERIDIAN: SM ~ WELL TYPE: Redr[TT- Rev · Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. -'ape Subfile 2~ is ~ype: LIS .001 1024 CN WN FN COUN STAT : UNOCAL : BAKER 30 : MIDDLE GROUND SHOAL : KENAI : ALASKA LIS COMMENT RECORD(s): SPLICE'POINTS: DIFL/GR: 5830, 9536, 10395 BHC-AC : 9508, 10380 DEN/CN : 5774 * FORMAT RECORD (TYPE~ 64) RECEIVED AP~ ~ ~ 1994 Alaska 0il & Bas Cons. Commission A,Bchorage - ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 Name Tool Code Samples Units AC AC 68 1 US/F ACQ AC 68 1 CHT AC 68 1 LB RB AC 68 1 DEG SPD AC 68 1 F/MN TTEN AC 68 1 LB GR AC 68 1 GAPI CN 2435 68 1 PU-L CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S LSN 2435 68 1 CPS SSN 2435 68 1 CPS CAL CDL 68 1 IN CORR CDL 68 1 G/C3 DEN CDL 68 1 G/C3 CILD DIFL 68 1 MMHO RFOC DIFL 68 1 OHMM RILD DIFL 68 1 OHMM RI~,[-DIFL 68 I OHMM SP DIFL 68 1 MV VILD DIFL 68 1 MV API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 48 852 89 1 4 81 285 47 0 4 95 558 30 1 4 69 189 02 1 4 61 094 30 1 4 95 558 30 1 4 06 969 49 6 4 52 326 75 5 4 98 211 23 1 4 98 211 23 1 4 84 023 70 1 4 83 368 34 1 4 87 374 67 0 4 34 168 75 6 4 59 047 24 5 4 34 704 23 6 4 27 515 24 6 4 04 903 06 0 4 06 213 78 0 4 53 419 67 0 4 04 522 10 6 84 * DATA RECORD (TYPE~ 0) Total Data Records: 3201 974 BYTES * Tape File Start Depth = 10700.000000 Tape File End Depth = 1900.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 774423 datums Tape Subfile: 2 3207 records... Minimum record length: Maximum record length: 62 bytes 974 bytes Tape Subfile 3 is type: LIS **** TAPE TRAILER **** 94/ 3/14 01 **** REEL TRAILER **** 94/ 3/14 01 Tape Subfile: 3 2 records... Minimum record, length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 14 MAR 94 11:27a Elapsed execution time = 3!).16 seconds. SYSTEM RETURN CODE = 0