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Home My WebLink About175-0441a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _0 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: N/A BF: N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 92' (ft MSL) 22.Logs Obtained: N/A 23. BOTTOM 20"659 13-3/8" K-55 1,516 9-5/8" N-80 9,978 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 9,293 9,255 3-1/2" LS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 6/3/2023 175-044 / 323-230 50-733-20277-00-00 S MGS Unit 13 ADL0018746 734' FSL, 1817' FWL, Sec 35, T8N, R13W, SM, AK N/A 9/8/1975 10,100 / 10,000 Surface 100' 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 229263.9115 2463907.2384 N/A 210' FSL, 881' FWL, Sec 35, T8N, R13W, SM, AK CASING WT. PER FT.GRADE 11/3/1975 CEMENTING RECORD N/A N/A SETTING DEPTH TVD 2463404.7476 TOP HOLE SIZE AMOUNT PULLED N/A 228317.0601 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM SIZE DEPTH SET (MD) N/A PACKER SET (MD/TVD) 3-1/2" SS Surf Surf 1,516Surf Surf 40, 43.5 & 53.5 Surf 68 659 Surf 10,086 N/A N/A Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Middle Ground Shoal / MGS Oil N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 12:01 pm, Jun 29, 2023 Abandoned 6/3/2023 JSB RBDMS JSB 062923 xGDSR-7/19/23BJM 1/8/24 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A N/A N/A Top of Productive Interval N/A N/A N/A N/A 31. List of Attachments: Wellbore schematic, Well operations summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Aras Worthington Digital Signature with Date:Contact Email:Aras.Worthington@hilcorp.com Contact Phone: 907 564-4763 Operations Manager General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS INSTRUCTIONS Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Authorized Name and Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.06.29 11:28:22 - 08'00' Dan Marlowe (1267) SMGS Di-13 Actual Completion 2/28/98 JLL 06/26/23 Cement Plug #1: IA: 9293’ MD to 4000’ MD (Est’d) LS: 9,293' MD to 4233’ MD (Tag 8/29/22) SS: 9,225’ MD to 3777’ MD (Tag 8/29/22) SCHEMATIC Surface Cement Plug: OOA: Cemented to surface (Tag @ 8’ MD) and squeezed from 400’ MD OA: 400’ MD to Surface IA: 400’ MD to Surface LS: 400’ MD to Surface SS: 400’ MD to Surface Rig Start Date End Date Cmt Pump 5/31/23 6/20/23 06/20/2023 - Tuesday Verify TOC. OOA-tag TOC 8' below outlet, OA-TOC visual at surface, IA-TOC visual at surface, SS-TOC visual at surface, LS- TOC visual at surface Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 13 50-733-20277-00-00 175-044 06/03/2023 - Saturday Inject waste fluid displaced from spotting cement pre-wash on wells Di-04 and Di-13. 244bbl injected @2bpm/2600psi while holding 1900-2200psi on the backside. Cementing Di-13 for abandonment: Pre-job, pressure test lines t/1000psi- good, caught returns almost immediately. Pump 28bbl 14ppg cement @3bpm/400psi dwn the LS and up the OA , good cement returns from the OA seen at surface. Shut dwn & swap over and pump 21bbl 14ppg cement up the IA, good cement returns from the IA, good cement returns from the IA seen at surface. Shut dwn & swap over and pump 4bbl up the SS, good cement returns from the SS seen at surface. Shut down and swap over to pump up the OOA @.5bpm/500psi, shut in with 500psi and squeeze for 5min, bleed down, shut in LS, SS, IA, OA and OOA and divert un-used cement to cuttings boxes and wash up. Sheen test each cutting box of un-used cement/rinsate-good and dispose of same. R/D hard line and r/u on Di-04 for cementing in the morning. 05/31/2023 - Wednesday R/U pump down LS take returns up SS, unable to get circulation, make several attempts pumping both directions with no luck, check surface flow paths confirm good. Secure well f/night. 06/01/2023 - Thursday R/U pump down LS up IA, circ out freeze protect& spot 20 bbls wash @2bpm 100psi. Pump out OOA pressured up t/500psi & held, pumped out OA 44bbls @2bpm 100psi, spot 40bbls wash. Mobe out E-Line, R/U, m/u toolstring= FN, Weight bar, CCL, Swivel, tubing punch=13', 3' from CCL to top shot. RIH t/450' pull correlation log, IRH pull up t/ place CCL @ 397', placing top shot @ 400' btm @ 402', fire gun, good indication shots fired. POOH t/70' clean, pressure up IA t/90psi pressure tracking on SS. Bleed off, POOH w/e-line & rig down. R/U circ lines, Pump 8bbls down LS up SS @ 2bpm, 150psi, pump down LS out OOA pressure up t/ 500psi w/ .75 bbls. Inject waste fluid displaced from spotting cement pre-wash on wells Di-04 and Di-13. 244bbl injected @2bpm/2600psi while holding 1900-2200psi on the backside. C Note: All waste fluid was injected into SMGS-17. -bjm Shut dwn & swap over and pump 4bbl up the SS, good cement returns from the SS seen at surface. Shut down and swap over to pump up the OOA @.5bpm/500psi, shut in with 500psi and squeeze for 5min, Shut dwn & swap over and pump 21bbl 14ppg cement up the IA, good cement returns from the IA, good cement returns from the IA seen at surface. Pump 28bbl 14ppg cement @3bpm/400psi dwn the LS and up the OA , good cement returns from the OA seen at surface. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Aras Worthington To:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] SMGS-13 (PTD 175-044) 10-407 report Date:Monday, August 14, 2023 12:51:29 PM Attachments:image001.jpg Bryan, Apologies for the confusing entries on these. All of our waste fluid from all of the wells in 2022 and 2023 P&A and Pre-P&A wellwork campaigns were injected into SMGS-17, which we have prior approval (AA) for. Aras From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, August 14, 2023 12:35 PM To: Aras Worthington <Aras.Worthington@hilcorp.com> Subject: [EXTERNAL] SMGS-13 (PTD 175-044) 10-407 report Aras, I have a question about the 10-407 for this well. The operations summary report says “Inject waste fluid displaced from spotting cement pre-wash on wells Di-04 and Di-13. 244bbl injected @2bpm/2600psi while holding 1900-2200psi on the backside.” Where was the waste fluid disposed of? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: Middle Ground Shoal 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,100 N/A Casing Collapse Structural Conductor Surface 1,950psi Intermediate Production 3,090psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Aras Worthington Contact Email:Aras.Worthington@hilcorp.com Contact Phone:907 564-4763 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Operations Manager Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 9.2# / L-80 9,293 & 9,225 5/1/2023 N/A & N/A N/A & N/A See schematic See schematic 3-1/2" LS & SS 3,450psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ALD0018746 175-044 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20277-00-00 Hilcorp Alaska, LLC S MGS Unit 13 Middle Grnd Shoal Oil N/A N/A Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY See schematic 1,516 Perforation Depth MD (ft): 10,086 9-5/8" 13-3/8"1,516 1,516 5,750psi9,97810,086 4,233 (LS) 3,777 (SS)10,000 4,231 (LS) 3,775 (SS) ~3145 20"659 MD 659 659 Length Size nnss eee ololloll nn mm _ Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-230 By Kayla Junke at 4:22 pm, Apr 17, 2023 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2023.04.17 15:13:55 -08'00' Dan Marlowe (1267) DSR-4/17/23BJM 5/1/23 MDG 4/19/2023 10-407 Flush OA and OOA with at least 2X bottoms-up before pumping cement. GCW 05/02/23 5/2/2023 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.05.02 13:45:05 -08'00' RBDMS JSB 050323 P&A Sundry Well: Di-13 PTD #175-044 Well Name:S MGS UNIT (Dillon) 13 API Number:50-733-20277-00-00 Current Status:Shut-In Producer Rig:FB Estimated Start Date:May 2023 Estimated Duration:1 month Regulatory Contact:Juanita Lovett 777-8332 Reg.Approval Req’d?Yes - 403 First Call Engineer:Aras Worthington 907-564-4763 (O) Second Call Engineer:Ryan Rupert 907-777-8503 (O) Current Bottom Hole Pressure (est):4314 psi @ 9851’ TVD (ca. 2006) Maximum Expected BHP:4400 psi Maximum Potential Surface Pressure:~3415 psi Gas Column Gradient (0.1 psi/ft) Current Pressures (LS/SS/IA/OA/OOA):0/0/0/14/0 History An oil well drilled and completed in 1975 as South Middle Ground Shoal Unit No. 13. Workovers were performed in 1981, 1982, and 1998. The well was Shut-In in 2002 and subsequently killed with a 10.8 ppg pill and freeze protected. The lower abandonment cement plug was pumped on 8/16/2022 per approved Sundry #322- 400. Cement was tagged in the LS @ 4233’ SLM and in the SS @ 3,777’ SLM. Two separate witnessed CMITs were performed (LSxSSxIA) to 2500 psi but both were deemed inconclusive/fails by AOGCC inspectors. Pressure loss in the second 30-minute test was <10% (113 psi the first 15 mins, 70 psi the second 15 mins). The second witnessed CMIT was reviewed by AOGCC staff and it was communicated via email to Hilcorp that the second test was deemed a passing test. Hilcorp then perforated the LS, SS, 9-5/8”, and 13-3/8” casing @ 400’ MD in preparation for the surface cement job. However, it was later communicated to Hilcorp that the reviewed CMIT was not a passing test. The well pressures were monitored on monthly intervals throughout the winter of 2022/2023 with no pressure buildup on the LS, SS, or IA, which validates the integrity of the lower cement plug. The TOC in the OOA was tagged @ 7” below the outlet. The OA and OOA have no injectivity @ ~500 psi. Current Status The LS, SS, and IA have been freeze-protected with diesel to ~120’ MD. Objective Install surface cement plug to complete the P&A. See attached pressure trend chart. -bjm P&A Sundry Well: Di-13 PTD #175-044 Hilcorp requests a variance to 20 AAC 25.112 (d) (1).Hilcorp requests that the surface cement plugs extend up to the wellhead and tree valves. This is to ensure the well is properly cemented and to avoid any uncertainty as to the cement top. The platform legs and wells will need to be severed completely at or near the seafloor to remove the legs eventually, and the extra cement in the casings should not impede this operation significantly. Variance granted. -bjm P&A Sundry Well: Di-13 PTD #175-044 Procedural steps Fullbore 1. Circulate diesel freeze-protect out (max tubing pressure 500 psi): ¾ Pump 3 bbls FIW down IA and out LS ¾ Pump 3 bbls FIW down IA and out SS ¾ Pump 12 bbls FIW down LS and out IA 2. Establish circulation with FIW down LS, through perforations @ ~400’ MD and out OA and OOA if possible. Max tubing pressure 500 psi. 3. Pump LS x OOA x OA x IA x SS surface cement plug as follows: ¾ 50 bbls FIW w/ surfactant Wash (down LS and displace 20 bbls ea. into OA and OOA. Displace 10 bbls into IA). ¾ 124 bbls 12 - 15.8 ppg Class G cement i. Circulate out the OOA if circulation up the OOA is established until good cement returns are seen at surface ii. Circulate up the OA until good cement returns are seen at surface iii. Circulate up the IA until good cement returns are seen at surface iv. Circulate up the SS until good cement returns are seen at surface ¾ Mix on the fly and pump excess cement as needed to get good cement returns across all annuli ¾ SI all annuli but the OOA and squeeze to 500 psi for at least 5 minutes Volumes: ¾ LS from 400’ to surface: 0.0087 bpf * 400’ =3.5 bbls ¾ SS from 400’ to surface: 0.0087 bpf * 400’ =3.5 bbls ¾ OOA from 400’ to surface: 0.18 bpf * 400’ =72 bbls ¾ OA from 400’ to surface: 0.060 * 400’ = 24 bbls ¾ IA from 400’ to surface: 0.052 bpf * 400’ =21 bbls Total Cement Volume: 124 bbls Attachments: 1. Current Schematic 2. Proposed Schematic Flush OA and OOA with at least 2X bottoms-up before pumping cement. -bjm Verified cement calcs. -bjm P&A Sundry Well: Di-13 PTD #175-044 Current Schematic: P&A Sundry Well: Di-13 PTD #175-044 Proposed Schematic: SMGS 13 (PTD 175-044) Pressure Trends Reservoir abandonment plug pumped 8/16/22 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,100 feet See schematic feet true vertical 10,000 feet N/A feet Effective Depth measured 4,233 LS; 3,777 SS feet N/A feet true vertical 4,231 LS; 3,775 SS feet N/A feet Perforation depth Measured depth 8,865 - 9,994 feet True Vertical depth 8,796 - 9,887 feet 3-1/2" LS 9.2# / L-80 9,293 (MD) 9,205 (TVD) Tubing (size, grade, measured and true vertical depth) 3-1/2" SS 9.2# / L-80 9,225 (MD) 9,140 (TVD) Packers and SSSV (type, measured and true vertical depth) N/A & N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Middle Ground Shoal Oil 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 3,090psi 3,450psi 5,750psi 1,516 1,516 Burst Collapse 1,950psi measured TVD Production Liner 10,086 Casing Structural 9,97810,086 659 1,516 659Conductor Surface Intermediate 20" 13-3/8" 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 175-044 50-733-20277-00-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0018746 Middle Ground Shoal / Middle Ground Shoal Oil S MGS Unit 13 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD N/A 0 Size 659 0 00 0 00 0 322-400 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Aras Worthington Aras.Worthington@hilcorp.com 907 564-4763Operations Manager N/A pp kk tt Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Anne Prysunka at 4:03 pm, Dec 08, 2022 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2022.12.08 13:03:41 -09'00' Dan Marlowe (1267) SMGS Di-13 Actual Completion 2/28/98 JLL 12/05/22 Tag TOC LS @ 4,233 SLM Tag TOC SS @ 3,777 SLM Cement Plug #1: IA: Est. 4,000 LS: 4,233 9,293' SS: 3,777 9,225 SCHEMATIC Tbg Punch 400-405 Rig Start Date End Date SL 8/16/22 11/11/22 09/09/22 - Friday 08/29/22 - Monday Held PJSM, approve PTW Service and warm eq. Spot and R/u SL unit on LS, Heliport on weather hold, wait on Inspector to arrive. RIH on LS w/1.75" DD Bailer tag @ 4233'slm, POOH, sample of wet cmt. R/u on SS, RIH w/ 1.75 Bailer tag @ 3777slm, POOH sample of wet cmt. R/d SL. Sent pictures of tag depths to Inspector Sean Sullivan. 08/28/22 - Sunday R/u circulating lines and test eq. Fluid packed well and tested lines. CMIT-LSxSSxIA t/2500psi per Sundry, Pretest: LS/SS/IA/OA/OOA=0/0/0/20/0 BBL Pump: 2.5 Initial: LS/SS/IA/OA/OOA= 2840/2840/2840/120/0 15mis: LS/SS/IA/OA/OOA=2675/2675/2675/115/0 30mins: LS/SS/IA/OA/OOA=2550/2550/2550/110/0 BBL Return: 1.25 CMIT failed, witness by State Inspector Sean Sullivan. R/d circulating lines and test eq. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 13 50-733-20277-00-00 175-044 08/16/22- Tuesday Held PJSM, checked well pressures on DI-13 LS/SS/IA/OA/OOA=10/10/0/0/0;Strapped tanks, check well pressures, DI-07 Tbg/IA/OA/OOA= 0/0/50 (bled of gas)/0. DI-12 LS/SS/IA/OA= 0/0/0/23 DI-17 OA/OOA= 60/50. R/u circulating eq, Circulated 365 of FIW down LS returns up SS/IA , recovered 265bbls of 9.8 brine and 97bbl oil cap. R/u circulating eq. on DI-17, pressured up IA to 2200psi and held, injected 93bbls of oil/brine down LS @ 3.5bpm/2600psi. R/d circulating eq. R/u HAL cement eq. PT lines t/3000psi, lined up to pump dn LS returns up SS, pumped 50bbls of Inlet water w/surfactant wash followed by 116bbls of 9.8brine, (lost returns @ 85bbls and pump pressure increased, shut in master on SS, broke tree cap and recovered D&D hole finder lost in SS on 6-17-22), Shut-in SS and opened returns up IA pumped 107bbls of 9.8 brine. Mixed and pumped 356bbls (1325sks) of 14ppg Class G cement @ 5bpm/1685psi taking returns up IA holding 400psi back pressure, Shut-in the IA and opened returns up SS, pumped 10.5bbls of 14ppg Class G Cement, dropped wiper ball and pumped 35bbls of 9.8 Brine displacement, SD pump. Cmt in place @ 21:30 hrs. Washed and cleaned unit, Static sheen test on cmt cleanup showed (no sheen). Calculated job volume was 421bbls Actual volume returned was 418bbls Shut-in SS and opened returns up IA pumped 107bbls of 9.8 brine. Mixed and pumped 356bbls (1325sks) of 14ppg Class G cement @ 5bpm/1685psi taking returns up IA holding 400psi back pressure, Shut-in the IA and opened returns up SS, pumped 10.5bbls of 14ppg Class G Cement, dropped wiper ball and pumped 35bbls of 9.8 Brine displacement, SD pump. brine and 97bbl oil cap. R/u circulating eq. on DI-17, pressured up IA to 2200psi and held, injected 93bbls of oil/brinebrine and 97bbl oil cap. R/u circulating eq. on DI-17, pressured up IA to 2200psi and held, injected 93bbls of oil/brine down LS @ 3.5bpm/2600psi. R/d circulating eq. R/u HAL cement eq. PT lines t/3000psi, lined up to pump dn LS returns Rig Start Date End Date SL 8/16/22 11/11/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 13 50-733-20277-00-00 175-044 R/u circ eq. could not establish communication pumping down down LS or SS. R/u EL on LS, M/u 2x weight bars, 1.69" CCL and 2" x6' gun. RIH set down on swab valve, Valve shows to be open, troubleshoot and remove bonnet and found pin sheared on the stim. Manual opened gate and put bonnet back on. Found same issues on SS and repaired. R/d EL, verified circulation with TxIAxOA no channel with OOA 11/11/22 - Friday Freeze protested well with diesel down to 120'. R/d circulating eq. 11/10/22 - Thursday 09/19/22 - Monday Move over to leg 1. Rig up on DI 13, stab on well. Unable to get master open all the way, work valve able to pass thru. RIH with 1-11/16 tool string wt bars, CCL, 2" gun loaded 5' production charges, 6.5 grams, 6 shots per ft. total of 30 shots, locate collars at 420' & 390', spot CCL at 397 ft. 3' to top shot perf interval 400 ft to 405 ft. fried shots pooh all shots fired. Rig down E-line. CMIT' LS x SS x IA to 2500 psi per Sundry Pretest: LS/SS/IA/OA/OOA = 0/0/56/20/0 BBLS PUMP: 2 Initial: LS/SS/IA/OA/OOA = 2767/2767/2767/ 160/0 15 MIN.: 2654/ 2654/2654/150/0 30 MIN: 2584/2584/2584/145/0 Test witness by AOGCC Brian Bixby Bleed off pressure and rig down test equipment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tate of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 13 Township: 8N Range: 13W Meridian: Seward Drilling Rig: N/A Rig Elevation: N/A Total Depth: 10100 ft MD Lease No.: ADL0018746 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 659 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 1516 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 9 5/8" O.D. Shoe@ 10086 Feet Csg Cut@ Feet SS Tubing 3 1/2" O.D. Shoe@ 9225 Feet Csg Cut@ Feet LS Tubing 3 1/2" O.D. Tail@ 9293 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Balanced LS Tbg 4233 ft Wireline tag Fullbore Balanced SS Tbg 3777 ft Wireline tag Initial 15 min 30 min 45 min Result Tubing 2840 2675 2550 IA 2840 2675 2550 OA 180 160 150 OOA 0 0 0 Remarks: Attachments: 200 lb Tool string consisted of rope socket, knuckle joint, 2x 45 lb weight bars, and hydraulic spangs (spangs/bailer when sampling). SS tbg sample was wet cement with liquid; LS tubing sample was wet cement schmoo. MIT failed due to exceeding max allowed pressure loss (10%) August 28, 2022 Sully Sullivan Well Bore Plug & Abandonment S MGS Unit 13 Hillcorp Alaska LLC PTD 1750440; Sundry 322-400 none Test Data: Casing Removal: Wade Hudgens Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): F rev. 11-28-18 2022-0828_Plug_Verification_SMGS_Di-13_ss 9 9 9 g(p g MIT failed due to exceeding pg) g p max allowed pressure loss (10%) James B. Regg Digitally signed by James B. 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Haines Union Oil Company of California Manager, Oil & Gas 3800 Centerpoint Drive, Suite 100 ^ Operations Anchorage, AK 99503 Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com August 3, 2009 � AUG,0 � 2009Cathy Foerster Commissioner Alpskp dal hes Nm Commiggion Alaska Oil & Gas Conservation Commission `9raS;hoPa4 333 W. 7th Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, �,e, I � Dale Haines Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 14-42 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 16-42 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 18-42 1680120 Apr -89 Colla sed Casing 100% water production Phase I Abandon abandon at end of platform life GP 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubing -to -casing communication Failed MIT Possible restore injection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D40RD 1820830 Sep -01 Shallow hole in tubing near #2 GLM Stopped producing Phase I Abandon abandon at end of platform Iife G-8RD 1780450 Sep -02 E -Line wire in LS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-24 1760320 Mar -03 No known damage High Water Cut Phase I Abandon abandon at end of platform life G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase I Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase I Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life DO 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di4 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 13-4 1750150 Jul -03 no known damage no flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -01 no known damage no flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN SCU 21-8 1620190 Aug -9 parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21A-4 1801050 Dec -0 no known damage no flow Possible shallow gas Remove due to SI date SCU 21B-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 2313-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov -0 no known damage no flow Possible Sidetrack to G-Zone/Hemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 3213-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for Tyonek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 44-4 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct -91 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 Dec -0 no known damage no flow Possible shallow gas or gas storage 2011-2014 Monopod A-10 1670760 -81 Colla sed casing Producin Coal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 'Apr Jun -81 Collapsed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-30 1730140 Oct -91 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of platform life tF Wf �se�li l=. ! h o{��. ALA, SKA 011L AND GALS CONSlu'RVAn-Olin COMUSSION June 22, 2009 \ `15 - G `-`.,- SARAH PALIN, GOVERNOR r. r ' 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279.1433 FAX (907) 276-7542 Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100�� Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubert0kalaska.gov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Company Permit No. Well Name UNOCAL Union Oil Company of California 168-024 Granite Pt St 17587 5 Union Oil Company of California 194-149 Granite Pt St 18742 03RD Union Oil Company of California 179-033 Granite Pt St 18742 14 Union Oil Company of California 167-077 Granite Pt St 18742 16 _ Union Oil Company of California 168-012 Granite Pt St 18742 18 Union Oil Company of California 100-266 Granite Pt St 31-14RD2 Union Oil Company of California 182-020 Trading Bay Unit D-06RD Union Oil Company of California 169-004 Trading Bay Unit D-18 Union Oil Company of California 188-098 Trading Bay Unit D-30RD2 _ Union Oil Company of California 182-083 Trading Bay Unit D-40RD Union Oil Company of California 178-045 Trading Bay Unit G-08RD _ Union Oil Company of California 176-032 Trading Bay Unit G-24 Union Oil Company of California 179-013 _ Trading Bay Unit D-06RD Union Oil Company of California 188-028 Trading Bay Unit G-34RD Union Oil Company of California 168-038 Trading Bay Unit K-06RD Union Oil Company of California 169-066 Trading Bay Unit K-09 Union Oil Company of California 179-016 Trading Bay Unit K-21 RD _ Union Oil Company of California 178-004 Trading Bay Unit K-23 _ Union Oil Company of California 165-038 MGS St 17595 05 Union Oil Company of California 166-003 MGS St 17595 06 Union Oil Company of California 167-017 _ MGS St 17595 11 Union Oil Company of California 167-049 MGS St 17595 13 Union Oil Company of California 176-075 MGS St 17595 18 Union Oil Company of California 185-135 MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD Union Oil Company of California 193-119 MGS St 17595 28 Union Oil Company of California 193-118 MGS St 17595 29 Union Oil Company of California 193-120 MGS St 17595 30 Union Oil Company of California 195-199 _ MGS St 17595 31 Union Oil Company of California 175-007 S MGS Unit 02RD Union Oil Company of California 167-028 S MGS Unit 03 Union Oil Company of California 167-058 S MGS Unit 04 Union Oil Company of California 175-044 S MGS Unit 13 Union Oil Company of California 175-066 S MGS Unit 14 Union Oil Company of California 176-045 _ S MGS Unit 15 Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 Union Oil Company of California 194-098 S MGS Unit 18 Union Oil Company of California 175-057 Soldotna Ck Unit 12A-10 Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 Soldotna Ck Unit 23B-03 Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 Union Oil Company of California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 _ Union Oil Company of California 100-269 Soldotna Ck Unit 41 B-09 _ Union Oil Company of California 162-031 _ Soldotna Ck Unit 43-09 Union Oil Company of California 174-066 Soldotna Ck Unit 44-04 _ Union Oil Company of California 160-018 Swanson Riv Unit 212-10 Union Oil Company of California 161-033 Swanson Riv Unit 212-27 Union Oil Company of California 160-041 Swanson Riv Unit 234-15 Union Oil Company of California _ 167-076 Trading Bay St A-10 _ Union Oil Company of California 172-020 Trading Bay St A-23DPN Union Oil Company of California 173-014 Trading Bay St A-30 ) ~t!Æ~! :} fÆ~fÆ~~«IÆ AT1ASliA.OILAND 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. MURKOWSKI, GOVERNOR 333 W. "TfH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ç~ø~ t1 This letter confirms your conversation with COIumission EngLl1eer Tom Maunder last week regarding the multiple Applications for Sundry Approval (Form 403) you submitted in mid October regarding changing the monitoring frequency on the 16 wells on Dillon Platform and 23 wells on Baker Platform. Production and injection operations were halted on these platforms in 4th Q 2002 and 2nd Q 2003 respectively. Attached, please fmd the Sundry Applications, which are being returned without approval~ 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 Oiders (CO 44 and CO 54) for the platforms/unit. The Commission looks forward to receiving your letter applications. If prior monthly monitoring information has not been submitted to the Commission, that information should be ubmitted forthwith. . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this _day of November, 2004 '..-.c AN¡\iE'f""',., 1\10\1 ~» Ii 200~, ,::, ~ 'I \.,0' I '~ I.. , h' Enel. Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil of California aka Unocal ~ l' 1. Type of Request: 3. Address: 7. KB Elevation (ft): 110' KB ABOVE MSL 8. Property Designation: Dillon 11. Total Depth MD (ft): 10,100' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 8,865 to 9,994' Packers and SSSV Type: EC IVE' OCT 1 .2 2004 '\ STATE OF ALASKA ) ALA",,,.A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Alaska Oil & G~~ C~:~~S. r I : : Operational shutdown U Perforate U waiv~q 'fl!.~~~U~W§~B~ Plug Perforations D Stimulate D Time Extension [:f!tr~ Other0 Perforate New Pool D Re-enter Suspended Well ç.¡,/ 4. Current Well Class: 5. Permit to Dri umber: Suspend U Repair well D Pull Tubing D P. O. Box 196247 Anchorage, Ak. 99519-6247 Development Stratigraphic 0 D Exploratory D D Service ~ -733-20277-00 9. Well Name and NU:¿ber: Di-13 10. Field/Pools(s): Middle Ground Shoa G" PRESENT WELL CONDITION SUMM Y Effective Depth MD (ft): Total Depth TVD (ft): 10,000' Length Plugs (measured): Junk (measured): 10,028' / / ~9' 1,516' 10,086' Burst Collapse Size MD TVD 659' 1,516' 10,086' 20" 659' 3,450 psi 5,750 psi 1,498' 9,975' 13-3/8" 9-5/8" 1,950 psi 3,090 psi Tubing Grade: Tubing MD (ft): Perforation Depth TVD (ft): 8794 to 9885' Pulled from well Packers and SSSV MD (ft): 9,290' 12. Attachments: Description Summary of Pr posal ~ Detailed Operations Program D BOP ketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil 0 GasD WAG D GINJ D WDSPL 0 Service D Abandoned D D D D Plugged WINJ 17. I hereby certify that the foregoing i Printed Nam/) . D.0. Cole Signature ~u¥/ áí. true and correct to the best of my knowledge. Contact Title Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY 28-Sep-2004 Phone 3oLj- 4 ;;-3 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 Other: Subsequent Form Required: BOP Test D D D Mechanical Integrity Test Location Clearance RBDMS BFL NOV 2 2 2004 APPLICATION RETURNED 11/17/04 NOT APPROVED BY COMMISSION Approved by: 'to? Form 10-4fr.(Revised 12/2003 0 ~re;'t~ A L BY ORDER OF THE COMMISSION Date: Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIÒÑ¡(:F.:I\/t~-:r'-~~ --.- no 1. Operations Abandon U Suspend U Operation Shutdown U Perforate D r t.Ö !aÐettillJlf Other ~ Performed: Alter Casing D Repair Well D Plug Perforations D Stimulate ~, . . Tim-? ~~e~~io~ D Shut in. and secure Change Approved Program D Pull Tubing D Perforate New Pool D ~ ~À~ Subpen~~ wgjIÐ~'j~'; > ':~'un 2. Operator Union Oil of California 4. Current Well Class: 5. Permif\RQ!)rJI!t{Pmber: Name: aka Unocal Development 0 Exploratory D 75-44 3. Address: P. O. Box 196247 Stratigraphic D Service D 6. API Number: Anchorage, Ak. 99519-6247 50-733-20277-00 7. KB Elevation (ft): 9. Well Name and Number: 110' KB ABOVE MSL Di-13 8. Property Designation: 10. Field/Pool(s): Dillon Middle Ground Shoall"G" 11. Present Well Condition Summary: Total Depth measured 10,086' feet Plugs (measured) true vertical 9,975' feet Junk (measured) Effective Depth measured 9,995' feet true vertical 9,886' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 659' 20" 659' 659' Surface 1,516' 13-3/8" 1,516' 1,498' Intermediate Production 10,086' 9-5/8" 10,086' 9,975' Liner Perforation depth: Measured depth: 8,865'-8,910',9,017'-9,052', 9,087'-9,112', 9,215'-9,245', 9,322'-9,370', 9,420'-9,500', 9;537'-9,567', 9,565'-9,585',9,595'-9,675', 9,700'-9,772', 9,800'-9,910', 9,935'-9,955', 9,974'-9,994' True Vertical depth: 8794-8837',8938-8972',9006-9030', 9128-9157', 9231-9278', 9326-9404', 9440-9469', 9467-9486' 9496-9574',9598-9669',9696-9803', 9827-9847', 9866-9885' Tubing: (size, grade, and measured depth) LS: 31/2" 9.2# L-80 @ 9,225' 55: 3 1/2" 9.2# L-80 @ 9,203' Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 79 0 774 90 80 Subsequent to operation: Shut in subsequent to operation 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory D Development 0 Service D Daily Report of Well Operations 16. Well Status after proposed work: ,,-- ~@.. , Gas D WAG D GINJ D WINJ D WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ¡Sundry Number or N/A if C.O. Exempt: Contact Printed Name P. M. Ayer 'Â~(j"I\f~nG:\~If:"~ ¡HI III fì\ 1 @ ~OOI.l Title Petroleum Engineer Signature ~.".o.".. '""~"' - . £.. , Phone 263-7620 Date 18-Feb-2004 Form 10-404 Revised 12/2003 n 0 I h I ~, fj FæMS FES 2 7 .2fJO~ UNOCAL8 Dillon Well No. 13 Actual Completion 2/28/98 RKB to TBG Head = 34.15' Han er connection: 3-1/2" 8rd Tight @ 5,416' KB/SLM Drifted 2.867" 7 1 2 E 3 4 8 5 9 F 6 10 2 3 4 5 6 Fill Cleaned out to 9,995' ELM 9,995' DPM ETD 9,995' ELM TD 10,086' MAX HOLE ANGLE = 19° D-13 2-28-98 SIZE 20 13-3/8" 9-5/8" Tubing: LS 3-1/2" WT CASING AND TUBING DETAIL GRADE CONN ID 68 K-55 40,43.5,53.5 N-80 9.2 NO. Depth 34.20' 7 8 9 10 ID 3,462' 2.992" 9,222.' 2.992" 9,230' 3.00" 9,231' 2.687" 9,255' 3.00" 9,293' 3.00" 34.20' 6,964' 2.992" 9,222' 2.992" 9,224' 2.00" 9,225.' 1.995" OD 3.880" 3.880" 3.865" 7.250" 4.438" 5.454" 3.880" 2.880" 3.865" 2.375" Butt, LT&C 12.415 8.535 TOP Surf Surf Surf BTM. 659' 1,516' 10,086' L-80 (Used) Butt. SC JEWELRY DETAIL Item CIW Dual Hanger, Cameron Type 'H' BPVP, PIN: 663-09-01 3-1/2" 8rd Lift Thread x 3-1/2" Buttress Suspension Thread Pup, 3-1/2", 9.2#, L-80, Buttress SC Pup, 3-1/2", 9.2#, L-80, Buttress SC Crossover, 3-1/2" Buttress Box x 3-1/2" 8rd Pin Kobe 3", "ALP" OPF Parallel Cavity, No. 231-B-2-98 Crossover, 3-1/2" 8rd Box x 3-1/2" Buttress Pin WLRG, (Bell Guide), 3-1/2" Buttress Box Short String CIW Dual Hanger, Cameron Type '1-1' BPVP, PIN: 663-09-01 3-1/2" 8rd Lift Thread x 3-1/2" Buttress Suspension Thread Pup, 3-1/2", 9.2#, L-80, Buttress SC Pup, 3-1/2", 9.2#, L-80, Buttress SC Crossover, 3-1/2" Buttress Box x 2-3/8" 8rd Pin Pup, 2-3/8", 4.7#, L-80, EVE 8rd 2.992 34.2' 9,222' E F F F G-1 G-2 G-2 G-2 G-3 G-3 G-4 G-4 G-5 8,865' 9,017' 9,087' 9,215' 9,322' 9,420' 9,537' 9,565' 9,595' 9,700' 9,800' 9,935' 9,974' PERFORATION DATA (DEPTHS DIL) 8,910' 45' 4 2/27/1998 New, 2-1/8, UJ, 0 deg. 9,052' 35' 4 2/27/1998 New, 2-1/8, UJ, 0 deg. 9,112' 25' 4 2/26/1998 New, 2-1/8, UJ, 0 deg. 9,245' 30' 4 2/26/1998 New, 2-1/8, UJ, 0 deg. 9,370' 48' 12 3/28/1998 Reperf, 2-1/8, UJ, 0 deg. 9,500' 80' 4/12 3/28/1998 Reperf, 2-1/8, UJ, 0 deg. 9,567' 30' 4 3/27/1998 New, 2-1/8, UJ, 0 deg. 9,585' 20' 4 3/27/1998 New, 2-1/8, UJ, 0 deg. 9,675' 80' 4/12 3/27/1998 Reperf, 2-1/8, UJ, 0 deg. 9,772' 72' 4/8/12 3/26/1998 Reperf, 2-1/8, UJ, 0 deg. 9,910' 110' 4/12 3/26/1998 Reperf, 2-118, UJ, 0 deg. 9,955' 20' 4/12 3/25/1998 Reperf, 2-1/8, UJ, 0 deg. 9,994' 20' 4 2/26/1998 New, 2-1/8, UJ, 0 deg. Rev. 3/29/98 By tcb DILLON PLATFORM API # 50-733-20277-00 SMGS. ST. # 13 WELL HISTORY Well DI-13 DATE COMPLETED 1975 11/13 1998 2/4-3/1 2/4-8 2/9-13 EVENT Completed as a development oil well. Workover Summary: DAY 1-5 TEST BOPE. TEST O.K. PULL TWO WAY CHECKS ACCEPT RIG AT 0600 HRS. PULL BPV'S. PULL SHORT SRING. ATTEMPT TO PULL LONG STRING. UNABLE TO PULL SEALS FROM PACKER WITH 165K. NO-GO. RIG UP FOR CHEMICAL CUT. RIH. CUT TUBING ABOVE KOBE CAVITY AT 9,217'. POOH. RIG DOWN E-LlNE. POOH LAYDOWN HANGER. POOH LAY DOWN 3-1/2" LONG STRING. COMPLETE POOH WITH LONG STRING. MAKE UP MILLING ASSEMBLY NO.1. 8-3/8" BURNSHOE, 99.81' 7-5/8" WASH PIPE. RIH WITH MILLING ASSEMBLY. CONT. RIH WITH MILLING ASSEMBLEY NO.1. TAG AT 9,239'. WASH AND ROTATE FROM 9,239' TO 9,280' TAG PACKER HIGH. MILL 3'. CHASE PACKER TO 9,293'. CLEAN OUT TO 9,309'. TAG AT 9,310' MILL TO 9,311'. CO NT. MILLING TO 9,313'. LITTLE PROGRESS. TORQUE INCREASING TO 6,000 FT/LBS. POOH. LAY DOWN BHA. PIPE STRAP FOUND TO BE 18.34' SHORT. PACKER HAD NOT MOVED DOWN HOLE. MAKE UP BHA NO.2. NEW 8-3/8" BURNSHOE. DAY 6-10 CONT. RIH WITH MILLING ASSEMBLY NO.2. TAG CAVITY AT 9,245'. ROTATE TO 9,260'. BURN FROM 9,278' TO 9,281'. WASH AND ROTATE TO 9,292'. MILL FROM 9,292' TO 9,295'. MILL OVER PACKER FROM 9,295' TO 9,297'. CONT. MILLING AT 9,297' NO PROGRESS. CIRCULATE HIGH VIS SWEEP. RECOVER 1 CUP UF PACKER RUBBER. CONT. MILLING. NO PROGRESS. POOH. CO NT. POOH WITH MILLING ASSEMBLY NO.2. MAKE UP BHA NO.3. 5-3/4" OVERSHOT ASSEMBLY DRESSED TO CATCH 3-1/2" TUBE. RIH. CONT. RIH WITH BHA NO.3. TAG TOP OF FISH AT 9,227'. SWALLOW FISH TO 9,237'. PU WITH 55K OVER. PULL AND LAY DOWN SINGLE. PU 40K OVER. WEIGHT FELL OFF. ATTEMPT TO RE-ENGAGE FISH. NO-GO. POOH WITH BHA NO.3. LAY DOWN BHA. NO OBVIOUS PROBLEMS WITH OVERSHOT. TEST BOPE. TEST O.K. MAKE UP BHA NO.4, 5- Di-13hst3-28-98.doc, last revised 2/18/2004 page 1 2/14-17 2/18-21 2/22-25 3/4" OVERSHOT DRESSED TO CATCH 4-1/4" TUBING COUPLING. RIH TO TOP OF FISH AT 9,227'. DAY 11-14 ATTEMPT TO ENGAGE TUBING COLLAR AT 9,244'. UNABLE TO GET MORE THAN 15K OVERPULL. CONTINUE TO ATTEMT ENGAGING FISH WITH NO SUCCESS. POOH WITH BHA NO.4. GRAPPLE HAD NOT ENGAGED FISH. CONTROL FLARRED TO 4-1/2" O.D. MAKE UP BHA NO.5, 8- 3/8" BURNSHOE, 7-5/8" WASH PIPE. RIH WITH BHA NO.5. CONT. RIH WITH BHA NO.5. CHANGE FAILED GEARBOX ON POWER PACK. MILL AND CLEAN OUT FROM 9,294' TO 9,298'. PACKER FELL FREE. CHASE TO BOTTOM. CHASE FISH TO 9,9913'. UNABLE TO WORK DEEPER. POOH WITH BHA NO.5. PICK UP BHA NO.6, 5-3/4" OVERSHOT WITH 3-1/2" GRAPPLE. RIH. CONT. RIH WITH BHA NO.6. TAG TOP OF FISH AT 9,851'. SLACK OFF TO 9,868'. PU TO 155K OVER. JAR ON FISH. MOVEMENT AFTER FOUR HITS. PULLING UP HOLE WITH 50K DRAG FOR FIRST 30'. POOH WITH FISH. DAY 15-18 CONT. POOH WITH FISH. 100% RECOVERY. MULE SHOE, 1 JT.3-1/2" TUBING, SEALL ASSEMBLY, 3-1/2" PUP, 4-1/2" BLAST JOINT, KOBE CAVITY, 3-1/2" PUP, 3-1/2" CUT JOINT. MAKE UP CLEAN OUT ASSEMBLY. 8-3/8" JUNK MILL. RIH. TAG AT 9,916'.WASH TO AND SET DOWN AT 9,924'. ATTEMPT TO CLEAN OUT AT 9,924'. HIGH TORQUE AT 7-8K FT/LBS. POOH WITH BHA NO.7. TEST BOPE WITH STATE WITNESS. TEST O.K. MAKE UP BHA NO.8, 7-13/16" JUNK MILL. RIH. CO NT. RIH. TAG AT 9,925' MILL WITH 8K FT/LBS TO 9,927'. WASH AND CHASE JUNK TO 9,946'. JUNK APPEARING TO BE ALONG SIDE MILL. ATTEMPT TO REVERSE. RECOVER SAND, RUBBER AND METAL CUTTINGS. WASH TO 9,973' WITH NO ROTATION. TAG FIRM FILL AT 9,973' MILL TO 9,978' HIGH TORQUE AND STALLING. PU WEIGHTS TO 150K. REVERSE CIRCULATE AND RECOVER SAND AND SOME RUBBER. PIPE ROTATION OFF BOTTOM PROBLEMATIC. CONT. MILLING TO 9,979'. POOH TO 9,850'. RIH AND TAG AT 9,972'. REVERSE CIRCULATE TO 9,980'. MILL PLUGGING. UNABLE TO CONTINUE REVERSING. ATTEMPT TO MILL. HIGH TORQUE. APPERANT JUNK ALONG SIDE MILL. POOH. DAY 19-22 CONT. POOH. RECOVER 4.2LBS. METAL IN JUNK BASKETS. MAKE UP BHA NO.9, 8" BLADED JUNK MilL. RIH. MILL FROM 9.980' TO 9,989'. CONT. MILLING FROM 9,989' TO 9,993'. REVERSE CIRCULATE, RECOVER RUBBER. CONTINUE MILLING AT 9,993'. REVERSE CIRCULATE, RECOVER SMALL AMOUNTS OF RUBBER. CONT. MILLING TO Di-13hst3-28-98.doc, last revised 2/18/2004 page 2 2/26 2/27 2/28 9,994'. REVERSE CIRC. AND RECOVER SMALL AMOUNTS OF RUBBER. POOH 3 JTS. RETURN TO BOTTOM. TAG l' HIGH AT 9,993'. POOH. CONT. POOH. CHANGE TO 3-1/2" DUAL RAMS. SHELL TEST BOP'S. TEST O.K. RIG UP TO RUN 3-1/2" DUAL COMPLETION. PU TAILPIPE AND KOBE CAVITY. RIH. CONT. RUNNING 3-1/2" DUAL COMPLETION. Day 23 SPACE OUT AND MAKE UP TUBING HANGERS. LAND COMPLETION WITH TUBING TAIL AT 8,575'. RIG UP E-LlNE. RUN GR/CCL FROM 9,999' TO TUBING TAIL AT 8,575'. RIH WITH GUN RUN NO.1, 2-1/8", 0 DEG. 4 SPF. TAG 4' HIGH AT 9,995'. PERFORATE 9,973.6' - 9,993.6'. POH. RIH WITH GUN RUN NO.2, 2-1/8" 0 DEG. 4 SPF. PERFORATE 9,235'-9,245', 9,214'-9,234'. POOH. RIH WITH GUN RUN NO.3, 2-1/8",0 DEG. 4 SPF. PERFORATE 9,106'-9,111',9086'-9,106' Day 24 POOH WITH RUN NO.3. RIH WITH GUN RUN NO.4, 2- 1/8",0 DEG, 4 SPF. PERFORATE FROM 9,031' - 9051' POOH. RIH WITH GUN RUN NO.5, 2-1/8", 0 DEG. 4 SPF. PERFORATE FROM 8,904'-8,909',9,016'-9,013'. POOH. RIH WITH GUN RUN NO.6, 2-1/8", 0 DEG, 4 SPF. PERFORATE 8,884'-8,904'. POOH. RIH WITH GUN RUN NO.7, 2-1/8", 0 DEG., 4 SPF. PERFORATE 8,864'-8,884'. POOH. RIH WITH GUN RUN NO.8, 2-1/8", 0 DEG., 4 SPF. PERFORATE 8,724'-8,729',8,704'-8,724'. POOH. RIG DOWN E-LlNE. PULL HANGERS TO WORK WINDOW AND REMOVE. CONTINUE RIH WITH COMPLETION. FOPUND SLIPS TO BE CRUSHING LONG STRING. RU SLICK LINE AND RUN 2.867" GAGE RING TO VERIFY LON LONG STRING IS NOT DAMAGED. SET DOWN AT 5,416'. WORK THROUGH WITH LITTLE RESISTANCE. CO NT. IN HOLE TO 9,216'. POOH. Day 25 WAIT ON NEW SLIPS TO ARRIVE. SLIGHT FLOW FROM BACK SIDE. PUMP 91 BBLS DIESEL DOWN LONG STRING. LONG STRING FLOWING BACK. CBU. BOTH STRINGS FLOWING BACK. PUMP 5 BBLS WATER DOWN EACH STRING. STILL SLIGHT FLOW. PUMP AN ADDITIONAL 5 BBLS DOWN EACH. WELL DEAD. SPACE OUT AND LAND COMPLETION WITH TUBING TAIL DEPTH OF 9,294'. RU SLICKLINE. RUN 2.867" GAGE RING TO 500'. POOH AND RD. DROP STANDING VALVE TEST COMPLETION TO 4,000PSI. O.K. INSTALL BPV'S. RIG DOWN. Di-13hst3-28-98.doc, last revised 2/18/2004 page 3 3/1 3/4-5 3/6 3/9 3/22 3/23 3/25 3/26 3/27 Day 26 COMPLETE RIG DOWN. INSTALL TREE. TEST TREE, SEAL FLANGE, HANGER. O.K. PULL TWO WAY CHECKS. RELEASE WELL TO PRODUCTION AT 1200 HRS. WL - (Made drift run and bailer run to check tubing and SV) RIH with 2.86" swedge to 9,200'. POOH Fluid level at 400'. RIH with equalizing prong to 9,300'. Work tool string well went on light vacuum POOH good marks on prong. RI H with Hyd bailer to standing valve at 9,334'KB. Work bailer. POOH. Disc sheared bailer empty. Fluid at 600'. Latched and pulled standing valve (trash in SV). Ran new standing valve. WL - RIH w/2.33" SWEDGE TO 10,075'KB. POOH. RIH w/2.74" BLIND BOX TO 9,312. SAT ON PUMP. JAR DOWN SOLID. POOH. WL - RIH w/3" kobe equalizing tool. SID @ 9,334' KB. Jar down. Well went on vacuum. POOH. Check tool: good marks. RIH w/3" kobe pulling tool. Latch SV @ 9,334' KB. Tap up, POOH w/ SV. WL - Made five runs, trying to pull pump, no luck. Fluid level dropping in tbg. Made five runs to 9257' KB. latch pump, jar up. Unable to pull pump. WL - Retrieved pump; hard to pull! Retrieved standing valve. RIH w/2 1/2 SB. Pulled pump @ 9257' KB. Equalized and pulled SV @ 9280' KB. Day 27 RIG UP E-LlNE. RUN GR/CCL FROM TAG DEPTH OF 9,997' TO TAIL AT 9,296'. ALL PERFORATING PERFORMED WITH 2-1/8",0 DEG. 4 SPF. GUN RUN NO.1, 9,936'-9,956'. Day 28 RUN NO.2, 9,891'-9,901', 9,871'-9,891'. RUN NO.3, 9,861 '-9,871', 9,841 '-9,861'. RUN NO.4, 9,831' - 9,841', 9,811'- 9,831'. RUN NO.5, 9,801'-9,811' (MISFIRE), 9,753'-9,773'. RUN NO.6, 9,801'-9,811', 9,733'-9,753'. RUN NO.7, 9,723'-9,733', 9,711-9,723'. RUN NO.8, 9,701'-9,711', 9,656'-9,676'. Day 29 RUN NO.9, 9,646'-6,656', 9,626'-9,656'. RUN NO. 10, 9,616'-9,626',9,596'-9,616'. RUN NO. 11,9,566'-9,586',9,490'- 9,500'. RUN NO. 12,9,546'-9,566',9,536'-9,546' (SHOT OUT OF ZONE, SHOULD HAVE SHOT 9,470'-9,490',9,460'-9,470'). RUN NO. 13,9,480'-9,490',9,468'-9,480'. RUN NO. 14,9,458'-9,468', 9,438' -9,458' . Di-13hst3-28-98.doc, last revised 2/18/2004 page 4 3/28 Day 30 RUN NO. 15,9,418'-9,438'. RUN NO. 16,9,348'-9,368'. RUN NO. 17,9,340'-9,348',9,320'-9,340'. RIG DOWN E-LlNE. TURN WELL OVER TO PRODUCTION. 2002 12/06/2002 This well was shut in and isolated at the surface with multiple flanges to isolate the well from surface flow lines. Di-13hst3-28-98.doc, last revised 2/18/2004 page 5 Don Sta dual LEG ROOM #1 185/8]{ 13 3/S ~ 13 !tIS. 13 3/S. x 9 5/S. 9 5/8" x 3 II:!' 28 bbIs 22 bbIs 15.5bbIs 30 bbIs 1)1-9 ABN-I0 DI-13 LEG ROOM #2 E 01-18 1.2 ÞbI 20bbIs 01-17 0.75 bbls 15.5bb1s 20 bbIs 01-16 15 bbIs 20bbIs DI-ll 5 bbIs 7;4bbfs 01-8 01-7 ABN-6 ~ LEG ROOM #4 01-5 -:= ¡abbls ~ 01-3 12 bbIs 25 bbls 20 x 13 SI8 0.1815 300 54.45 3 1/2 tbg. 0.0087 300 18 5/8 x 13 3/8 0.1291 300 38.73 27/8 tbg. 0.00579 300 133/8 x 9 5/8 0.0671 300 20.13 depth 656 334 9 5/8 x dual 3 1/2 0.0507 300 15.21 355 9 5/8 x dual 2 7/8 0.0571 300 17.13 pump limit 21 psi 9 5/8 x 3 1/2 0.0626 300 18.78 wen #2 well #4 wen #9 Wen" 10 Well 813 Wen #7 Well #8 Well 811 well #16 Wen 17 Wen#18 wen Ð Wen #5 Wen # 12 Wen #14 wen #15 WELL BAY # 1 Pumped down tbg.tbg on vac, bled down 9 5/8 x tbg. Pumped 28 bbls. Gas still at surface. Pumped down 2Ox135/8 2bbIs 100 psi. 20 bbls In 133/8. Try to pull eclipse paker with wire line could not get out. Well had 180 on annulus and 150 on tbg would not bleed down, Tryied pumping down short side old pump in hole could not pump. Put 30 bbls of 9.8 in annulur 9 5/8x tbg. Pumped down 1.5. tbg. Retumed up short side 100 bbls. Put 15 bbls in 13 5/8x9 5/8. 4 bbIs in 20" ann. Hook up to 20" took approx 1 bbl with charge press on ann. 13 3.8x 9 5/8 Rump and bleed 3 bþIs i~ ann. 9 5/8xtbg fluid packed with oil. 14.4 bblsin tbg. well10 Is abandoned Fill 20" ann 2 bbls, tbg on vac 7bbls in 13 3/8 x 9 5/8 28 bbls 9 5/8 x tbg. 51.5. 5 s.s.bbls down short side did tbg. And ann same time WELL BAY # 2 . 20" fluid packed,13 3/8 x 9 5/8 2 bbls and started getting diesel fluid back to surface. Pumped Sbbls in tbg.' 20 bbls in 9 5/8 ann.Annulus and tbg. Have oil returns 0 press on well. 20" fluid packed,13 3/8 x 9 5/8 2 bbls and started getting diesel fluid back to surface. Pumped 5bbIs in tbg.' 20 bbIs in 9 5/8 ann.Annulus and tbg. Press up to 500 psi. on both tbg. Strings had oil to top no press on tbg. Pumped and bled 7bbls in tbg. Annulus. When annulus was fluid packed. 011 at surface.5 bbls In 13 5/8 x 9 5/8 press limit. .5 bbls in 20" Well had SOpsi. On 13 3/8x 9 5/8 bleed down to 20psi put bbls of 9.8 fluid, 95/8ann. 20 bbls fluid, tbg.5bb1s each, wells 185/8 has 110 psi. bled off and fluid packed with press limit of 50 psi..75 of a bbl. Well had l00psi. On 13 3/8x 9 5/8 bleed down to 20psi put TSbbIs of 9.8 fluid, 95/8ann. 20 bbls fluid, tbg.5bb1s each, wells 185/8 has 60 psi. bled off and fluid packed ann with .75 bbls. Well had 150psi. On 13 3/8x 9 5/8 bleed down to 20psi put 20bbls of 9.8 fluid, 95/8ann. 20 bbls fluid, tbg.SbbIs each, wells 185/8 has25 psi bled off and fluid packed with 9.8 salt took 1.2 bbls. WELL BAY # 4 Rig up pump 4 bbls 1.5. 4 bbl $.S. 9 5/8 x tbg. 25 bbls, 13318 x 9518 fluid packed wI 12 bbls, 20" ann. 2 bbls. Auid packed Pumped 4 bbls 1.5. tbg. 4 bblss.s.Rlu to 9 5/8 x 3 1/2 ann. Pumped 15 bbls fluid packed on to sulface. Pumped 4bbls down tbg Is, 4 bbls s.s. both went on vac. Pumped 15 bbls 95/8 x31/2. Wdh50 psi press limit 0 bbls in 13 3/8x 95/8 Fluid packed 20x 133/8 2 bbls, Auid packed 13 3/8x9 5/8 12 bbls press up to 200 psi and held. Rig up pump 5 bbls I.s. 25 bbl 5.5. Be 9 5/8 x tbg. 8 bbls fluid packed oil to surface 13 5/8x9 5/8. R/U to 20" ann fluid pack 5 bbls. Press limit 20 psi. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnsto ~..~J. DATE' Chairman'-'~:~~ February 19, 1998 THRU: Blair Wondzeil, .~~ FILE NO: P. I. Supervisor ~_!2 o FROM: Lou Grimaldi~¢~'~ SUBJECT: Petroleum InSpector AD9JBSFE.DOC BOP Test, HWC #1 UNOCAL Dillon #13 S.M.G.S. Field PTD #75-0044 Thursday, February 19, 1998: I witnessed the weekly BOP test on HWC rig #1 working over UNOCAL well #D13 in the South Middle Ground Shoal Field. I arrived to find the rig almost ready to test. I made a cursory tour of the rig and its surrounding area and found all to be in good shape although the deck was slightly slick from the diesel that had been used for a workover fluid. The crew was working to clean this up. The test, once started went well and noticeably quicker than the test I witnessed in January, this could attributed to the crews better familiarity with test procedures and this particular rigup. All BOPE were tested and one failure was observed. The Methane detector in the "window" although registering the proper concentration the high alarm failed to soUnd. This was attributed to a bad card and once changed the high alarm sounded properly. The rig crew did a good job testing the BOPE and I found Gene Bouqet (Toolpusher) had developed a procedure that moved the test along in a sure and methodical manner. During the Accumulator test I observed a somewhat shorter time (3+ minutes) during the recharge portion than the previous test. Although the time was shorter it was still on the long side for this size equipment. Gene informed me that they had cleaned the pump inlet screens as was suggested during my previous visit. SUMMARY: The initial/weekly BOPE test I witnessed on rig # revealed the following; Test time 4 hours, One Failure. Attachments: A9DJABSE.XLS CC;, Dan Williamson (Unocal Drilling Supt.) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X DATE: Drlg Contractor: ydraulic Workover consultant Rig No. WC# PTD # 75-0044 Rig Ph.# Operator: UNOCAL (Dillon Platform) Rep.: Doug Niehaus Well Name: D-13 Rig Rep.: Gene Bouqet Casing Size: Set @ Location: Sec. 35 T. 8N R. Test: Initial Weekly X Other 2/19/98 776-6680 13W Meridian SEWARD MISC. INSPECTIONS: Location Gen.: fair Housekeeping: fair (Gen) PTD On Location N/A Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec. N/A' BOP STACK: Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams N/A Blind Rams 1 Choke Ln. Valves 1 HCR Valves 1 Kill Line Valves Check Valve Quan. Test Press. P/F P 250/3,000 250/3,000 P 250/3,000 N/A 250/3,000 P 250/3,000 P 250/3,000 P 2 250/3,000 P N/A · 250/3,000 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P F , H2S Gas Detector P P*. FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly /IBOP Ball Type Inside BOP Test Quan. Pressure N/A 250/3,000 N/A 250/3,000 250/3,000 I 250/3,000 P/F IN/A CHOKE MANIFOLD: No. Valves 9 No. Flanges Manual Chokes Hydraulic Chokes I Test Pressure P/F 250/3,000 P 24 250/3,000 P 1 Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained 3 Blind Switch Covers: Master: Nitgn. Btl's: Four Bottles 2200 psi average 3,000 J P 1,600 P X minutes 54 sec. minutes 58 sec. Remote: X Psig. · ~TEST RESULTS ~' Number of Failures: 1 ,Test Time: 4.0 Hours. Number of valves tested 15 Repair or Replacement of Failed Equipment will be made within N/A days. otify the Inspector and. follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: High Alarm on "Window" methane sensor failed to trigger, Seacorp changed out panel and tested "OK" H2S audible alarm weak, ~Jhould be tied into platform system to insure quarters residents are alerted to alarm.~l'est went much quicker than last witnessed test indicating crews familiarity with BOPE test procedure. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Leu Grimaldi FI-021 L (Rev.12/94) A9djbsfe.xls STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California {Unocal) Development: X 110' KB ABOVE MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: PO BOX 190247 ANC, AK. 99519 Service: South Middle Ground Shoal 4. Location of well at surface Leg 1, Cond. 7, Dillon Platform 8. Well number 743' FSL, 1,818' FWL, Sec. 35-T8N-Rt3W-SM No. 13 At top of productive interval 9. Permit number 269' FSL, 1,002' FWL, Sec. 35-T8N-R13W-SM 75-44 At effective depth 10. APl number 204' FSL, 861' FWL, Sec. 35-T8N-R13W-SM 50-733-20277-00 At total depth 11. Field/Pool 194' FSL, 843' FWL, Sec. 35-T8N-R13W-SM Middle Ground Shoall"G" 12. Present well condition summary Total depth: measured 10,100' feet Plugs (measured) None true vertical 10,000' feet Effective depth: measured 10,028' feet Junk(measured) None 0RI( INAL true vertical 9,918' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 659' 20" 1,250 Sx 659' 659' Surface 1,516' 13-2/8" 750 Sx 1,516' 1,498' Intermediate Production 10,086' 9-5/8" 1,000 Sx 10,086' 9,975' Liner Perforation depth: measured (See Attached Perforation Data Sheet) RE~E!VED true vertical Tubing (size, grade, and measured depth) Pulled from well Packers and SSSV (type and measured depth) BakerMod. 'D' Packer @ 9,290' Alaska 0il & Gas Cons, C0mmissi0rl Anchorage 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 2/14/98 16. If proposal well verbally approved: Oil: X Gas: Suspended: Jack Hartz 2/13~98 Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: /r~ ¢.~ i~ O.~2-,',. Dale Haines Title: Drilling Manager Date: FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval ~.~ Plug integrity BOP Test ~ Location clearance L '" Mechanical Integrity Test Subsequent form required lO- Approve~l Cop~ Returned !- -'! David W. Johnston Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLI( ~,TE Dillon 13 Actual Perforations Zone Top (MD) Btm (MD) Top (TVD) Hemlock G-1 9,338' 9,358' 9,246' Hemlock G-2 Btm (TVD) Amt ASPF Comments 9,266' 20' 8 9,334' 7' 4 9,940' 9,617' 9,655' 9,710' 9,765' 9,818' 9,858' 9,907' 9,950.~ .~'_ . 9,832' 9,422' 9,429' 9,327' Hemlock G-2 9,447' 9,492' 9,352' 9,395' 45' 8 Hemlock G-3 9,610' 9,510' 9,517' 7' 4 Squeezed 5-1-81 Hemlock G-3 9,648' 9,547' 9,554' 7' 4 Squeezed 5-1-81 Hemlock G-3 9,703' 9,581' 9,607' 7' 4 Hemlock G-3 9,720' 9,617' 9,661' 45' 8 Hemlock G-4 9,808' 9,703' 9,714' 10' 8 Hemlock G-4 9,830' 9,724' 9,752' 28' 8 Hemlock G-4 9,887' 9,780' 9,800' 20' 8 Hemlock G-4 9,841' 10' Proposed Perforations Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt ASPF Comments Tyonek E 8,705' 8,730' 8,637' 8,660' 25' 6 New Tyonek E 8,865' 8,910' 8,793' 8,726' 45' 6 New Tyonek F 9,017' 9,052' 8,938' 8,971' 35' 6 New Tyonek F 9,087' 9,112' 9,004' 9,028' 25' 6 New Tyonek F 9,215' 9,245' 9,127' 9,046' 30' 6 New Hemlock G-1 9,322' 9,370' 9,231' 9,277' 48' 12 Reperforate Hemlock G-2 9,422' 9,500' 9,327' 9,403' 78' 4/12 Reperforate Hemlock G-2 9,565' 9,585' 9,465' 9,485' 20' 4 New Hemlock G-3 9,595' 9,675' 9,495' 9,572' 80' 4/12 Reperforate Hemlock G-3 9,700' 9,772' 9,579' 9,667' 72' 4/8/12 Reperforate Hemlock G-4 9,800' 9,910' 9,695' 9,802' 110' 4/12 Reperforate Hemlock G-4 9,935' 9,955' 9,827' 9,846' 20' 4/8 i Reperforate Hemlock G-5 9,978' 10,028' 9,870' 9,918' 50' New Unocal Alaska Business Unit Dillon Platform Well No. D-13 UNOCAL$) I IrlrTll Irltlll rlrllll Illl'll I No. ~Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) IlrllU IOILll IIIIIII IIIIIrl 1 Rig up E-Line 5.5 6 0.2 2 Perforate Tyonek E and F 20.0 26 1.1 3 Rig down E-Line 3.0 29 1.2 4 Ru to run completion ............................ 4.0 33 1.4 5 PU Kobe Cavity 1.5 34 1.4 6 PU new 3-1/2" x 3-1/2" Com. p,.i!,~.,t?.n to 9,200' 38.0 72 3.0 7 Land completion ........ : .............. ...,. 4.0 76 3.2 8 Run standing valve, pressure.~?.:, ...... 2.0 78 3.3 9 Run slickline gage ring run. . .......................... 5.0 83 3.5 10 Rig down. 10.0 93 3.9 11 Install Tree/Flowlines 2.0 95 4.0 12 Perforate Hemlock G-1, 2, 3, 4,, 5 after Workover. - -. - Illllll Illllll Ilfllll flllll[ Subtotal (Days) Loss/Trble Time (11%) 4.0 0.4 Total Project Days 4.4 UNOCALe RKB to TBG Head = 34.15' ?? 1 2 3 4 SIZE 2O 13-3/8" 9-5/8" Tubing: 3-1/2" 3-1/2" Depth 34.15' 9,245' 9,246' 9,270' 9,330' 34.15' 8,688' 9,290' ' illon Well No. 13 Proposed Completion CASING AND TUBING DETAIL WT GRADE CONN ID TOP BTM. 68 40, 43.5, 53.5 9.2 9.2 ID 2.992" 2.687" 2.992" 2.411" 2.995" 4.75 K-55 12.415 N-80 Butt, LT&C 8.535 L-80 Butt. SC 2.992 L-80 Butt. SC 2.992 JEWELRY DETAIL Itg, m Surf 659' Surf 1,516' Surf 10,086' 9,245' 9,245' CIW Dual Hanger Crossover, 3-1/2" Buttress Box x 3-1/2" 8rd Pin Kobe 3", "ALP" Cavity Crossover, 3-1/2" 8rd Box x 3-1/2" Buttress Pin Mule Shoe, 3-1/2" Buttress Box Short String CIW Dual Hanger Crossover, 3-1/2" Buttress Box x 2-7/8" 8rd Pin Baker, Mod. 'D', 9-5/8" Permanent Packer G1 G3 :G3 G4 G5 PBTD = 10,028' MAX HOLE ANGLE = 19° 2one · G:4 G-4 G-5 .. q ii Tiii iii Fill Cleaa~ ~t 't6 10,028: Top 8,705' 8,865' 9,017' 9,087' 9,215' 9,322' 9,422' 9,565' 9,595' 9,700' 9,800' 9,935' 9,978' PERFORATION DATA Btm 8,730' 8,910' 9,052' 9,112' 9,245' 9,370' 9,500' 9,585' 9,675' 9,772' 9,91 O' 9,955' 10,028' Amt Proposed 25' New 45' New 35' New 25' New 30' New 48' Reperf 78' Reperf 20' Reperf 80' Reperf 72' Reperf 110' Reperf 20' Reperf 50' New D- 13 PropdrawB.doc STATE OF ALASKA ~ Al. ..,,A OIL AND GAS CONSERVATION COMMk ,~N APPLICATION FOR SUNDRY APPROVALS OR IGIN4H. 1. Type of Request: Abandon __ Suspend'__ Operation shutdown ~__ Re-enter suspended well ..1,._ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate __ Other .~ 2. Name of Operator _ .. .. ,I 5. T,y.p.~.o.f.V~l[;., 6. Datum elevation (DF or KB) Union Oil Company of ~;a±i~orn~a [UN~r~ent.¢~ ' / Exploratory-- !00 ' ~--~ -~-ST- 3. P. O. pox 1 ~ fo 2 z~ y, z~rtcrz. , z% , ~! - Service -- Address ............. K 9~1519 6~t,r~i)g~raphic 7. Unit or Property name / feet 4. Location of well at surface Leg iCl, Slot 7, Platform Dillon 741' FSL, 1814' FWL, Sec. 35, T8N, R13W, SM At top of productive interval 269' FSL, 1002' FWL, sec. 35, T8N, R13W, SM At effective depth 227' FSL, 888' FWL, Sec. 35, T8N, R13W, SM At total depth 206' FSL, 866' FWL, Sec. 35, T8N, R13W, SM 8. Well number 13 9. Permit number 75-44 10. APl number 50-- "133-20277 11. Field/Pool SMGS/Hemlock 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 620 ' Surface 1481 ' Intermediate Production 1 0 0 5 5 ' Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 1010 0 ' feet Plugs (measured) 9989 ' feet 10028 ' feet 9919 ' feet Junk (measured) Size Cemented 20" 1250 SX 13-3/8" 750 SX 9-5/8" 1000 sx See attachment 3-1/2", 9.2iC, N-80 Measured depth True vertical depth 659' 659' 1516' 1516' ' AJaska Oil & Gas Cons. Commission Anchorage @ 9,342' Packers and SSSV (type and measured depth) Baker Mode 1 "D" @ 9,288 ' 13. Attachments DesCription summary of proposal __ 'Detailed operations program ~ BOP sketch __ 14. Estimated date for commencing operation October 30f 1991 16. If proposal was verbally approved Name of approver Date approved ! 15. status of well classification as: Oil __ Gas __ Suspended ..,.., ~' ~ Service 17. I hereby certify4bat the foregoing is true and correct to the best of my knowledge. g ~R9%- S . 'BU~[ Title REGIONAL [, ) L..,' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ ~/..oZt Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commissioner OR~GtI',,!AL S!GNED BY i..O~,?,!IF C. SMITH DRILLING MAiX~I~t~ER ii-AS-hi Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Alaska Oil & Gas Cons. 'Ancbol'a.~lo Imlk i Pertinent Data: Spud Da~e: Surface Location: Sub,urface Location: Elevation: TO: PBD: Ce,lng: Parlor, fiche: Initial Potential: Initial Stimulation: .~e~ervolr Da~a: Cored Intervals: DST IntervQie and Re.ulb: Log SOUTH MIDDLE GROUHD SHOAL ADL 18746 WELL NO. 13 HEMLOCK CONGLOMERATE PLATFORM DILLON 9/8/75 Leg 1, Slot 7 741' F'SL, 1814' FWI.. Sea. 35, TBN. R13W. $.M. 11:) - 206' FSI., BG6' FWL. Sea. 35, 1'8N. R13W, S.M. 100' KB 10100' TVD ggBg' 10028' TVD gglg' ComplefJon Record I. DCB Cam,mn Dual hanger 2. 3 1/2" g.2lf Butfl'e.. tubing 3. 3 1/2" Buttresa and ;3 1/2" BRD XO 4. 3" Kobe ~ *E' COvEy a/h 3440 5. 3 1/2" 8RD and 3 1/2" ButL,'e,. XO 6. Blast joint 7. 3 1/2" Buttress pup B. Seal Iocator g. 4.75" Seal aseembly 10. 3 1/2" Buttre,, tublng 20". 85 and golf H-40 Callng eat at 659' with 1250 Ix cement 11. Mule,hoe 13 :~/B", 68ti l':.-SS Ca.lng eat at 1518' with 750 ex cement 9 5/8", 40, 43.5 and 53.5~l Ca,lng set at 10086' with 1000 ex cement G-l: ' 9338-9358' 0-2: 9422-9429' 9447-9492' 0-3: 9610-g$17'e 9648-9655'e 9703-971 O' 9720-9765' 0-4: 9B08-9818' 9830-9880' gB87-9907' 0-5: 9940-9950' Cement Squeezed 2343 BOPD. 209 BWPD, 589 MCFD Nolle None DIL--SP, BHC-GR. FDC-G4, 11/4/75 GR-Neutmn 11/g/7S Gamma Ray 7/29/7B, 3/8/80. 1/26/85 ! (A~ run 7/8/82) J Dep~ 35' 9237' 9242' 9262' 9263' 9283' 9287' 9288' 9309' 9341' 9342' Baker Model D Packer Ta~gedFlil 0920rl/26/85 POD 10028' TD 1~100' 20" 85 & g0f cea 659' 1.3 3/~ ..... ~. CSA 1~' · 9338-6358' 6422' 9492' 0610' 6655' 9703' 9765' 9808' 9907' 9940-9950' ~ ~ ~VB'* 40, CSA10086' South Middle Ground Shoal ADL 18746 Well No. 13 Procedure for suspending and freeze protecting well: 1) Reverse the hydraulic pump out of the hole. The tubing and the tubing X 9 5/8" annulus will be freeze protected by power oil at this point. 2) Close all valves on the wellhead. 3) Install gauges on the tubing and 9 5/8" casing X tubing annulus. STATE OF ALASKA ~ ALASKA OiL AND GAS CONSERVATION COI,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~X OTHER [] 2. Name of Operator 7. Permit No. Amoco Production Company 75-44 3. Address 8. APl Number P.O. Box 779 Anchorage, Alaska 99510 50- 7332027700 4. Location of Well Leg 1, Slot 7, S~IGS Platform Dillon 743' FSL, 1818' FWL, Section 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 100' RKB 6. Lease Designation and Serial No. ADL 18746 9. Unit or Lease Name South Middle Ground Shoal 10. Well Number 13 11. Field and Pool South Middle Ground Shoal 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing IX} (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Tubing was pulled, the bottomhole assembly replaced and the tubing rerun. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Title District Superintendent Date '-~ ~% ~ I~-.~ Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent July 2, 1982 Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907-272-8471 File- LAD-709-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Notice of Intent to Perform Work SMGS Unit Well No. 13 Platform Dillon, Cook Inlet, Alaska Attached in triplicate for your approval is the State of Alaska Form 10-403, Sundry Notices and Reports on Wells, to perform work on the subject well. This work should begin in early July 1982. Verbal approval was received from Russ Douglass on July 2, 1982. Yours very truly, L. A. Darsow Di stri ct Superintendent Attachment LMP/klt RECEIVED J U L - 6 1982 Alaska 0ii & Gas Cons. Commission Anchorage STATE OF ALASKA ~ ALASKA (JIL AND GAS CONSERVATION CO,,,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2. Name of Operator ,: Amoco Production Company 3. Address P. O. Box 779, Anchorage, Alaska 99510 4. Location of Well Leg 1, Slot 7, SMGS Platform Dillon 743' FSL, 1818' FWL, Section 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. lO0' RKB SMGS 18746 12. 7. Permit No. 75-44 8. APl Number 50- 7332027700 9. Unit or Lease Name South Middle Ground Shoal 10. Well Number 13 11. Field and Pool South Middle Ground Shoal Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco Production Company plans to pull tubing, replace the bottomhole assembly, and rerun tubing. Verbal approval was received from Russ Douglass on July 2, 1982. Subsequent Work tleportecl RECEIVED J U L - 6 i982 Alaska 0ii & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~)~O~~ Title District Superintendent The space below for Commission use Conditions of Approval, if any: Approved by 8¥ /.ONNIE C. SMIT~i Date July 2, 1982 Approved Copy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 June 29, 1981 Fi le' LAD-745-WF Mr. Hoyle H. Hamilton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchor. age, Alaska 99501 Dear Sir: Notice of Subsequent Report of Work SMGS Unit Well No, 13 Platform DillOn, ·CoOk Inlet, 'Alaska Attached in duplicate is our State of Alaska Form 10-403, Sundry Notices and Reports on Wells. The subject well was repaired April 30, 1981 through May 13, 1981, and returned to production as a pumping oil well. Yours very truly, · L. A. Darsow District Superintendent Attachment KEO/klt RECEIVED JUL 0 2 1981 Aiaska Oil & Gas Cons. Commission Anchorage /-"', STATE OF ALASKA ~ ALASKA ~,,,. AND GAS CONSERVATION C£ MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL)~ OTHER [] 2. Name of Operator 7. Permit No. Amoco Production Company 75-44 3. Address 8. APl Number P. 0. Box 779, Anchorage, Alaska 99510 50- 733 202 7700 9. Unit or Lease Name South Middle Ground Shoal 4. Location of Well Leg 1, Slot 7, SMGS Platform Dillon 743' FSL, 1818' FWL, Section 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) lO0' KB 6. Lease Designation and Serial No. SMGS 18746 10. Well Number 13 11. Field and Pool South Middle Ground Shoal 12. Check Appropriate Box To Indicate Nature of Notice, RepOrt, or Other Data NOTICE OF iNTENTiON TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations IXl Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made ~ Other [] [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following repair work was performed 4/30/81 to 5/13/81' 1. Pulled tubing and milled out packer. e e Se 6, Cleaned out to lO,O00' MD. Cement squeezed perforations 9610-9617' MD and 9648-9655' MD to 2800 psi. Tested cement squeeze to 2000 psi, okay. Reperforated 9338-9358', 9447-9492' 9720-9765' 9808-9818' 9830-9880', 9887-9907', 9940-9950' with 4 SPF casing guns. Ran tubing, packer and new bottomhole assembly. Returned wel EEEI¥EB to production. JUL 02 1981 Alaska 011 & Gas Cons. Corem Anchorage 14. I hereby certify that the, foregoing is true and correct to the best of my knowledge. Signed/, The space below for Commission use Date June 29, 1981 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1430 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 April 21, 1981 File- LAD-506-WF Mr. Hoyle H. Hamilton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchoraage, Alaska 99501 Dear Sir: Notice of Intent to Per.form Work SMGS Unit 18746 Well No. 13 Platform Dillon, Cook Inlet, Alaska Attached in triplicate for your approval is our State of Alaska Form 10-403, Sundry Notices and Reports on Wells, to perform repair work on the subject well. We plan to pull tubing, cement squeeze high water production zones, and reperforate other zones. We plan to start this work in early May 1981. Yours very truly, L. A. Darsow District Superintendent Attachment KEO/klt RECEIVED, APR £ £ 1981 Alaska O# & 8as Cons. AnChorage C°rnrJ?ission ~'~ ' STATEOF ALASKA ALASKA ,~i'L AND GAS CONSERVATION C~..,,,vllSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL IX1 OTHER [] 2. Name of Operator 7. Permit No. Amoco Production Company 75-44 3. Address 8. APl Number P. 0. Box 779, Anchorage, Alaska 99510 50- 7332027700 4. Location of Well Leg 1, Slot 7, SMGS Platform Dillon 743' FSL, 1818' FWL, Section 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 100' RKB I 6 . Lease Designation and Serial No. SHGS 187.46 12. 9. Unit or Lease Name South Middle Ground ShOal 10. Well Number 13 11. Field and Pool South Middle Ground Shoal Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] ~ Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well ~ Change Plans [] Repairs Made [] Other Pull Tubing ~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Compl'eted Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco plans to' 1. Pull tubing, mill out packer, and clean out to lO,O00' MD. e Cement squeeze upper G-3B perfOrations, 9610-9617' MD and 9648-9655' MD. e Clean out and reperforate the following' 9338-9348', 9447-9472', 9720-9765' 9808-9818' 9830-9880' 9885-9890' 9905-9910' , , , , , 9940-9950'. 4. Run new bottomhole assembly and tubing. Se Return well to production. RECEIVED APR 2 2 1981 Alaska 0il & Gas Cons, Commission Anchorage 14. I hereby cer .... ng is true and correct to the best-Of my knowledge. Signed ~&,. ~~ Title District Superintendent The space below for Commission use Conditions of Approval, if any: Approved by COMM ISSlO N ER Form 10-403 Rev. 7-1-80 ~q:~proVed Copy li~. Returned By Order of the Commission Date 4/2]/8] Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SCHI~"N1BERGER OFFSHORE SER~E$ · Division of Schlumberger Limited HOUSTON. TEXAS 77001 - I"LEAI[ ;II£1"Ly 'FO APRIL 9, 1980 II"MLUW'I:I~6[Ill OYYlHO'l' 'I:"VIC;I"' 500 W INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99502 STATE OF ALASKA ALASKA OIL AND GAS CONSEi~VATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501 Attention: Gentlemen: 1 RFOLDED SEPI A ' Enclosed ore_ .=_=p_.rints of the GAHMA RAY, E~)G I NE~-I~xPRODUCT ION LOG Cam on' AMOCO PRODUCTION CO ','Well SMGS -15{ D-13) D'4~', D:8'RD, FieldP ~OUTH MI.DDLE GROUND SHOAL., County. KENAI ~ State ALA~]cA , Additional prints ore being sent to: ,, prints prints prints prints prints prints prints prints The film is RETURNED TO AMOCO We appreciate the privilege of serving you. RECEIVED ........ --, .-,. Very truly yours, /" ', · SCHLUMBERGER OFFSHORE SERVICES AMOCO PRODUCTION COMPANY P.O. BOX 779 ANCHORAGE, ALASKA 99501 AHention: RAND! ROSENBURG Gentlemen: Enclosed are 2 B ll~rints of the GAMMA R AY --- Company AMOCO PRODOCT ION i. Well SO Field. SOUTH M! DDLE GROUND SHOAL , Count~ 2~Ns At 3 ENG --~--F~-G 1 GEOL 2 GE~ 3 GEO[ / STAT TEC STAT TEC JcTd~ FI_~[ D D L E ~0 W. INTERNATIONAL ICHORAG E, AIRPORT ALASKA 99502 GROUND SHOAL D-13 State ALASKA on: Additional prints ore being sent to: 2 B L' r~rints DIVISION PRODUCTION MANAGER DENVER 'D'IViS ION SECURITY LIFE 'BLDG. DENVER, 'COLORADO 80202 1 BL nrints CHEVRON U.S.A.., INC. P.O. BOX 7-839 ANCHORAGE~ ALASKA ATT. MR. K IRKVOLD RD l~rints DIVISION GEOLOGIST, EXPLOITATION SECURITY LIFE BLDG, DENVER, COLORADO 80202 1 B L r)rints DEPARTMENT OF NATURAL RESOURCES DIVi'S'ION OF OIL & GAS CONSERVATION 3001' PORCUPINE DRIVE ANCHORAGE, ALASKA 99501 ATT. HOYLE HAMILTON 1 BL prints GETTY .OIL COMPANY THREE PARK CENTRAL_,_SUJ_IZ 700 ._15.1 ~ A~A_P_AHOE ST. D_QENVER , COLORADO 80202 1 BL prints PHILLIPS PETROLEUM COMPANY ,7800 EAST DORADO PLACE ENGLEWOOD, COLORADO 80111 ATT. MR. DENNY LB_[__prints ATI ANT I C. R I £HFI FI D COMP.aNY P.O. BOX 360 ...... ANCHORAGE, ALASKA 99501 The film is, RETURNED TO AMOCO DENVER We appreciate the privilege of serving you. prints DATE Very truly yours, SCHLUMBERGER OFFSHORE SERVICES DI STR IC'T t,I ~. N ~. ~ [11 G. J. Ross Area Superintendent Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 December 18, 1975 File: GJR-1006-WF 'Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: State of Alaska Form P-7 SMGS Unit Well No. 13 Attached is the State of Alaska Form P-7 furnishing the completed drilling operations for South Middle Ground Shoal Unit Well No. 13. Yours very truly, Area Superintendent Attachment Form P--7 SUBMIT IN STATE OF ALASKA structionv on s{~) OIL AND GAS CONSERVATION COMMITTEE WELL cOMPLETION OR RECOMPLE~ION REPORT AND LOG* i la. TYPE OF WELL: OH, ~ ~s ~V~LL~ WELL ~ DR? ~ Other b. TYPE OF COMPLE~ON: IVELL OYER EN BACK n~sv~. Other 2. NAME OF OPERATOR Amoco Production_. ComPanY 3. AI}DRESS O1' OPERATOR ::'~} .'; '-:! . _' ~.: - P. !~0,"_Box 779,:~A~ch6rage,-Alaska 99510 ~. L~CATiON HF WELL':IRe~ort location tie,ribband'lin ~ccordance with any State requirements)* ~t~ace" fLeg~I' Slot 7, S~GS-Piatform D~llon, 743~ rSL, 18t8' F~; Sec.: 35, TS~, R13~, S.~. A~ tqp pr°d. InterVal ~ep~rted.below - ? 269.6 rsL, ~002.5 ~, Sec 35, At t0.tal d~p~ : _: ' ': Last gyro'- survey;: takeq at ~10 ~ 000 ~206;2 FSL~ :865.'~8 ,F~,~Sec,: '35, TSN, R13~, S.~. ORIGINAL 5. API NUIVIF~ICAL CODE 50-133-20277 , ~L-~8746 7. iF INDIA.N, ALLQ~ OR TRIBE NAlVlE 8. TUNIT,FAi~NI OR LEASE NAME SMGS ~Uni t 9. WELL .NO. 13 10.~ FLELD A~D POOL; OR WILDCAT SOuth Middle Ground Shoal 'IL SEC., T., R., M., (BOTTOM HOLE ' OBJECTIVE) .: /-I.00' FSL, 925' Fl/L, 8~c'~35, T8N, R13W, S.M. ~.> 75-44 13' D~ ~P~ [~' 'DA~ T'D~ r~C~ 13~' D~ ~CO~ ~USP ~ A~A~' lle..~.~.vA~o~s (~r, RKB, RT, GR, .~Iq2,'t17. ELEV. CASINGHEAD 9~8:7S":~ : [ !:11.3.7.25 2 j- -~1-13-75 I + 100' ~ . ' 59.4' 18..T~D~,~ a T~[9. PLUG, ~ :' MD :~ ~D~. m.~LTm~ CO~L., 21. ,, 4 DRILLED ~. ~Us~UU-i .... 1: ~. '-5 ' ~ _[ ~ow~* ao~s~ TOOLS ~aW[S '[ S~ ~. PRODUCING~ ~VAL(S) -"OF'-~S ~P~TIO~P, ~OM, N~E (MD AND ~)* ~ 23. W~ DIRE~ON~ - : - . 7: .2~ :: ' ~ SURVEY ~DE TVD 9246,:8 ¢ 985~.1 ~ " [ Yes .. ~ 9338.' 9960f- . : Lower Kenai Conglomerate i ~'~4. TYPE EI_JECTRIC AND OTHER. LQGF~:RUN . . :,-- IES, Sonic,}~ D tar, Ga~ Ray w/. Caliper .. ' ' CAS~ RE~ (Re~ all ~tri~s set in well) ~ .- . ~. , ,,= , , 20 :.~ ~ [r-85i~:& ~90~ [:: '40.[ 659' 26" ~ 1250 sacks 13-3/8.'t:: [ . 68~) I"':K=55[ 1.516' ~7-1/2"[ 750 sacks '9-5/-8" / 40~;, 43.5~t1' s'95'! m2'oa6' ~2-1/4"1 1000 sacks ~6. ' ~ LINER ~CO~' 28. PERORATIONS OP~ TO PRODU~OH (Inte~al, size and 'number) 9422-29' 9455-62' 9610-17' ' ~aa-55' 9344-51' 9703-10' All with -9736443' 4JSPF 9810,17' 9851£58' , .q898~05' 'i , - PRODUCTION P~ECOi:~D t27, SIZE ~9. ACID, SHOT, F~q3~CTURE, CEATENT 'SQUEEZE, ETC. ,_.DI~'TIi I1N-TI~RVAL (MD). [. k~O~T ~ ~ND O.F MA~ U~ AMOUNT PULLED DATE FIR.S~ Pi%ODUCTION :I 'PRooucTiON METHO'D (Flowing, gas lif.~, pnmping--$ize and type of pump) IWELL STATUS (Producing or ' ' - ~oua T~Sr~' .... "2~1/8" , ~,,ut-~> ' i DATE 11--19-75~ s..[ --Kobe.hydraul±c pump,: 3 x [ produc ng o TEST. ! ~' . " ~lci~(~X~. SYZE IP~OD'~ ~0'a Om--S~.. ' %x~cr. w~r~. ~s~s-om z~xo ' salest fuel, flare LIST OF ATTAC~M~NTM Chronological well history, logs and g ro surVe attached lnformatlon ts complete and eoF~eet as determlned from allVavallable records sm~ .~~~ .k~~ ~Tnz' ~Area SuPerintendent 12-18-75 TUBING . DEPTH SET (MD) j PACKER SET (MD) 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: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in.cther spaces on this form and in; any attachments. Items :20, ,nd :2:2:: If th. is well iS completed for separate production from more than one interval zone (multiple completion)i so state in item 2'0, and in item 22 show the prc. Jucing interval, or intervals, top(s), bott0m(s).and name (s) (if any)..f.or only. the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional inte~ val to be seperately produced, shOw- ing the ackiitional data pertinent Jo such interval. .. :Item26: "Sacks Cement": Attached supplemental records for this well should show the.details of any mul- .. tiple.:stage cementing and the location of the cementing tool. Item '~8:..Submit a separate completion report on this form for each interval to be separately produc~. , . (Se..e instruction for items 20 and 22 a.bove). , ,, , ' 34. SUMIV~'A. RY OF POI:LM'ATION TESTS INCLUDIN(; INTERVAL TF__,STED. PRF_,SSURE DATA ~ R.F~OVERIES OF OIL. GAS. 35. G]~OL~G IC MARK~ WATF_AR AND MUD NAME N/A . , , : Hemlock 9338 ' 9246.8 ' , · · · . ...... % "J~. COI~1~ DATA, Aq~'ACII' BRIEF, DESCRIPITIONS OF LITI£OLoGY, POROSITY, FRACTURES, APPARENT DIPS , ) AND DETEC'TEI) SII.OWS OI~ ()IL. GA.S OR WATE'R, · ~"';'~ .. :: , .. . · · · · ,, Chronological Well History SMGS Well No. 13 September 1-11: September 11-22: September 23- October 2: October 3-5: October 6-7: October 8-9: October 10- November 4: Drilled and surveyed from 659' to 1525' with 17-1/2" bit. Cleaned out 20" surface casing to 659'. Drilled to 1525' and cemented 13-3/8" casing at 1516' with 750 sacks Class G + 2% gel + .12 gallons D-80 per sack at 12.8 ppg, followed by 500 sacks Class G + 2% CaC1 at 15.8 ppg. Drilled and surveyed from 1525' to 5277' with 12-1/4" bit. While cleaning out bridge at 5203', twisted pin off in box with bit 74' off bottom. Tripped out with 148' of drillpipe. Recovered fish and bit was split in welds and three cones sheared off. Drilled and milled junk to 5337'. Directionally drilled and surveyed from 5337' to 7228' with 12-1/4" bit. Drill string torqued up and backed off at 149' from the surface. Tripped in overshot and latched onto fish at 2335'. Recovered 2946' of drillpipe, leaving two separate fish in the hole, one comprised of 1597' of 4-1/2" drillpipe and the second comprised of the drilling assembly and remaining drillpipe. Tripped in with overshot and latched onto the drill- ing assembly fish but could not move. Ran free- point and backed off at 6809'. Tripped out with fish and recovered 2109' of drillpipe. String dragged badly until it cleared the top of the second fish at 5281'. Tripped in for second fish but was unable to catch. Tripped in and spotted 300 sacks Class G cement with 0.23 gallons per sack D-80 and 20% sand at 5270'. Reversed out at 4800'. After WOC, drilled cement stringers from 5080-5270'. Tripped in to 5270' and spotted 300 macks Class G cement with 0.1 gallons per sack D-80 and 20% sand. Reversed out at 4700'. After WOC, drilled cement stringers from 4810-5092' and hard cement 5092- 5124'. Sidetracked fish, directionally drilled and surveyed from 5124-10,000'. Chronological Well History SMGS Well No. 13 Page 2 November 5-13: November 14-15: Rigged up logging tools and ran the following logs: IES, Gamma Ray, Density, Sonic, Dipmeter. Ran 243 joints 9-5/8" casing to 10,086'. Circulated hole and cemented with 1000 sacks Class G cement and had full returns during cementing. Cut off casing and installed tubing spool and successfully tested to 2000 psi. Tripped in with bit and scraper and tagged bottom at 10,028'. Tripped out and ran gyro survey from 10,000' to 1500' with 100' stops. Ran cement bond log. Estimated top of cement 7600'. Displaced hole with power oil and ran gauge ring and junk basket to 9350'. Tripped in with packer and set at 9298'. Tripped out and ran in seal assembly, 3" Type "E" Kobe BHA and 294 joints of 3-1/2" Buttress tubing. Perforated the following intervals with 4JSPF: 9344-9351' 9703-9710' 9422-9429' 9736-9743' 9455-9462' 9810-9817' 9610-9617' 9851-9858' 9648-9655' 9898-9905' Installed 3" x 2-1/8" Kobe hydraulic pump and 24-hour test yielded: 2343 BO, 209 BW, 589 MCF, 251 GOR. 27 D LEG, NO, I 34 LAT. 60 LONG, 151 o 30' 45,8,5' ¥ = X = 229,266 FROM S.W, COR. 745' NORTH 1818~ EAST ii 1765' 2 SEWARD MERIDIAN ALASKA LEG. NO. 2 LEG. NO. LAT. 60044, 07.72" LAT. 60° 44' LONG, 151° 30' 44,78" LONG, 151° $0' 45,86" Y -- 2,463,871 Y = 2,4(;3,807 X = 229~ ~19 X = 2£9,265 FROM S.W. COR. FROM S.W. COR. 699' NORTH ~ 653' NORTH 1872' EAST 1818' EAST TSN TTN LEG, NO, 4 LAT. 60° 44' 07.52" LONG. 151° 30' 46.94" ¥ = 2,46.3, 853 X : 229,211 FROM S.W. COR. 678' NORTH i'765' EAST CERTIFICATE OF SURVEYOR I hereby certify that ! am properly registered and licensed to practice land surveying in the State of Alaska end tho! this plat' rep~resents o location survey made by me or under my supervision and that all dimensions and other del']ils ore correct. Date Surveyor ~ SURVEYORS NOTE The localion of S.M.G.S. by use of U.S.C. 8, G.S. Light", and "Boulder" ii il Plat form D was accomplished "CO " " ' stolions st , Eosl Foreland and C.E.T. 18 (Offset 2) SCALE · 26 55 55 ~" io°'d 2- 25 FINAL PLAT OF S.M.G.S. PLATFORM "g" LOCATED IN PAN ANiERICAN ?ETitC)LF~U',: P,O, BOX 779 ANCHORAGE~ ALASKA SURVEYED DY E M. LINDSEY LAND SURVEYORS ::5201 ARCTIC BLVD, ,) WELL ~SURVEYING COMPANY AMOCO PRODUCTION SMGS UNIT 18746 NO. _15 SOUTH RYDDL~ GROUND SHOAL ALASKA AN-c-ROA~G'~-~--'~LA SKA ..'. PAGE 5 "?"" :DA-TE ~O~.;SURVEY NOVEMBER 9, 1975- "- ......... COMPUTATION DATE '-' :-NOg EM-e~ R--io '-- 1975 .. -- .. . INTERPOLATED VALUES FOR EVEN 100 FEET OP'SUB-SEA DEPTH 'TRUE SUB-SEA ~ASURED VERTICAL VERTICAL __~ TH DEPTH DEPTH -'TOTAL RECTANGULAR COORDZNATES 'NORTH/SOUTH EAST/WEST -. '-' MD-TVD :: VERTICAL DIF'~ERE. N_~E,_ ........ -CO.R..REcTION 1280 1278.17 1168.17 1211 1210.00 1100.00 1311 1510,00 1200.00 .55.8~ S #7.15 U .,! ~ :".;".~9.0& W~'!. '1.891"87 S ":~ 50.12 W ;.~.....,..-. .... S 51.17 W 1.91 .141.1 .lq10,00 .... 1~00.00 1511 : '1510;00 lqO0.O0 1611 1610.00 :'.15b0.00 171! 17.10,00 1600,00 1811 1810.00 1700,00 1911 1910,00 1800.00 ' 38~.39 59.70 40.65 2011 2010,00 1900.00 2111 2110,00 ~2000.00 ~'212-- 2210.0d .......... 2312 2510,00 2200.00 2q12 241o.oo '25oo.oo 25i~ 251o.oo =2'~'00~"~ 2612 . 2610,00 :2500.00 2712 2710,00 2600,00 2812 2810.00 2TO0'*'"O0' 2912 2910.00 2800.00 51.9'6 W 1.92 $ .':". 52.'8'3-~"~';:i;:?~:'::: I~95 42,25 S 5~,37 W ..-;.~' 1,9q ~2.55 S 56.51 W ''~''; 1.97 · q2,'29 S 62,4q W 2.06 ~2.15 $ 65.95 W 2.12 -~1--'-88'S A9,~9-~'-:'~' 2.18 ~1.65 S 75.09 W ?" 2,25 q1.34.$ ~6.56 W ' 2,31 41.18-§ ...................... 80',08 W 2:37 41.07 S 85.75 ~ ' 2.~ -0.02 0.03 0.05 0,01 0.00 0,01 0.00 ~. 0.00 0.01 0,'02 .... 0,05 0..05 O,O& 0,0~ O,O& 0,0~ -. . -'AMOCO PRODUCTION SHGS UNTT 1871~-G NO. 13 '.SOUTH H YDDLE GROUND-SHOAL 'ALASKA . · ' .','.' . .~.:' .~-.]-,.'/:::i:.:~2,~:?:,,.-., -". - ~.~ ..};:i.~!~-:~:':~':'.?i;'~?!~!~i?~ ' '.' .... .*:~::::.. ~'.:' .' "~ - ., . . - ~,~.~.. ~:."~?,-:, "~?:SPERRY-SUN'~ELL suRvEYTN~ COMPANY '..::,.::, '"' .... ~. ,: . ~. ,: __ -- ...... . COHPUTA'T[oN .DATE ' -;.':' _ -. ,' NO.VE~B~R-"-.iO*; .... i975 -' .,..~ .: .. . ; - :. :.'...- . . .: .: .. ..~ , .- ..,-. PAGE _."DAT£' O~ suRvEY...NOVEHBER 9, 1975 '.2SHR/aEL sYRoS£OP[C HULTI~HOT SURVEY .L ~10 O0 FT, ~E~LY BUSHIN~ ELEV. INTERPOLATED .,- VALUES FOR~_EVEN 100 FEET OF.. SUB-SEA 'TRUE SUB-SEA EASURED VERTICAL .'VERTICAL ~TH DEPTH -DEPTH 'TOTAL ': RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST ..... '- HD-TVD ;VERTTCAL DIFFERENCE ' CORRECTION 5012 5512 3613 37'13 3813 3913 ~113 ~213 ~313 30i0,00 2900.00 3110,00 .300~0..,00 3210,00 3100,00 /.3310,00 ;3200,00 35to.oo -361o.'oo "35oo.oo 3710,0o 3600.00 '381o,oo 370'0'~o 39to,oo 3800.00 ~0~0.00 3900,00 #110.00 4210,00 4310.00 ~413 ~513 ~61~ ~Tlq ~81~ qO00.O0 ~100,00 4200o00 ~.~4~o.oo .... ~'o'b~-O ~5~o.oo -~oo.oo ~61o.oo .~5oo.oo 40,85 S #0,53 S · qo~33 S ? .~, .~0.18 S · " ':':i:.. ,:?: :. !:? '-, '.: 39.92 'S ~0,54'S ~1,'07 .S a7,~7 W : 2,51 0.06 '90,99 W 2.57 0,06 e~,,r:,~-'~''-'''~ " 2~ 6~+ -::"~:' ..... ~'~ ..... o. o6 ... 116.33 W 3,12 O,OB :?". 0,09 - ".'"-.~: - '0,08 0,10 0,11 23 0.11 33 0.10 ~3 0.09 3,53 ..................0,10 ..................................................... 3.63 0,10 3,73 0,09 _., 3,82 0.0~ ' 3,90 0,08 4.00 : 0,09 4,11 .................... 0,10 #.22 0,11 4 Y'i:~-; 00 ......... ~6002'00 q810,O0 ~700,00 -~1,41 S 125,55: ~0,91 S 129,87.~ 39.89'-S .......... 1~;17'~ 3~.5~ ~ 13B.53 37.06 S 1~2.6~ 35-,~'7'S 3~.27 S 150.39 ,32.78 S 15~.56'~- -. '31 ;'28"-S ......... :7'158 ."9 ~'-'~ 29.65 s 163.33 W - !SPERRY-SUN WELL 'SURVEYINR COMPANY AMOCO PRODUCTION -.'sMGs UNZT, 18746 NO. 13 :-i$OUTH 'flIDOl:[ "GROUND SHOAL .: . ."~ALASKA PAGE 7 --ANCHORAGE. ALASKA . ..... COMPUTATION DATE : .' :,.:'.-,/... ,.., j . DaTE oF'.SURVEY NOVEMBER 9, 1975 ..... '-.~: ..... SllRU£L.GYRQSCOPIC MULTZSHOT .SURVEY .'dOA'"NdhhER su3£16031 KELLY BUSHING [LEV. = ~10~00 FT. . INTERPOLATED"VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ~ ~ 'TRUE SUB-SEA ~.:MEASUREO ~ERTICAL -VERTICAL ~_~ ~TH DEPTH DEPTH "TO TAL :-';. "-':' ..................................... -: ............ 'RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EART/WEST. D~FFERENcE ' ~ORR£CTION ~910o00 q800.O0 5010.00 ~900.00 5110.00 .5000.00 5100.00 :5200,00 5~16 '5~10.00 -5517 .5510.00 5gt9 5610.00 5720 5821 ,5810.00 5923 5910.00 602~ 6,010.00 6125 6110.00 622& G210.00 ,6427 · 652~ .'..-65~0.'00 ~'5300.00 2 .6o s 17[.7s u 2o .-a6'-A--. ..... '77','ik u .6626 6610,00 672~ 6710.00 -.~5~00.00 :-'~,q'#.'75 S S S S S S S S S S -~214.9~ 'W 5500.00 57.92 5700 o 0'0 81.11 22q,.88 'W w 6.70 0.97 7.99 9.35 1.35 11.89 1,22 13.03 1~15 .................. 1.11 15.11 0.96, 16,01 0.90 16~'85 ............................ 0,83 17.58 0.72 18.26 0.6,7 18.95 0.69 19.70 0.75 :5800,00 91.~q ~90'0'~-~'0' I0-1.22 6,000.00 110.09 6100.00 118o~7 6300.00 133'25 139.8;3 152.50 2~6.85. W '258.0SW '269~2~ W 279.95 W 290.50 W 510"75-U 4,q6 0.13 ~,68 ..-:, 5.14 .. 5,73 ... 0,59. .........'~ £ ............................ 6q. O0. O0 6600.00 S ~320.32 ,"W S '.330'~21-'~ s 340.73 W AMOCO PRODUCTION SMGS UNTT 187~ NO. 13 SOUTH MIDDLE ~EOUND SHOAL "'ALASKA · ~ SPERRY-SUN WFLI~ SURvEYYNG COMPANY ANCHORAGE, ALASKA COMPUTA?IDN DATE .'NOVEmbeR "'~ 0 ~'--' 1 ~75 . .. .... ~._ PAGE 8 · D~TF OF SURVEY.NOVEMBER 9, 1975 SI.IRt4EL-GYROSCOPZC MULTI.~HOT SURVEY aoI~---NUMBER-su3;160~1 ............................ KF~'LY BUSHING ELEV'. = ~"lo,OO FT. INTERPOLATED-VALUES FOR EVEN 100 FEET OF SUR-SEA DEPTH "TRUE SUB-SEA ~EASUREO VERTICAL VERTICAL .__( ~TH DEPTH DEPTH T'~TAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST ·MD-TVD VERTICAL DIFFERENCE .cORREcTION 6830 6810.00 6931 6910.00 7032 :7010.00 7132 7110.00 7233 ;72~0.00 75~ 7310.00 7~35 "7~10.00 7556 7510.00 7638 '.7610.00 77~! 7710.00 78~ 7810.00 79~7 7910 80~9 8010 8152 8110 6700,00 6800.00 -6900o00 '7000.00 ~100-'00 7300.00 *?~00.00 158.~1 s 351.6~ w 1~3.82 s -3~2.93 w "~' I72.26 S 385.91'~ '20,~.26 S ~1.12 W 7600.00 2s~.$z s ~+61.1~, u 7700.00 .-- 251.2.0 S .q, 79.02 ~ · 00 ............. :'78 00'; 00 .00 7900.00 .00 8000.00 ...ii,:( s2 o.oo 8557 8310,00 8~61 .Sq. lO,O0 8565 8510.0~ 8670 8610,00 8100.00 8200.00 8300.00 8~+0-0-,""00 8500.00 28'1.78 S 513,89 W 295.69 S 5~2.~7 W ~22.27 S 572.~;.W 336,32 S 595,89 ~ · _ 570o77 S .6~,96 20.~6 0,7~ 21.25 0,78 22.00 .........' .............. 0.75 22.7~ 0.73 ."23.~5 ~ -. 0.7O '2~',30 O,~S -25.39 1.09 26.82 1.q2 ;28.'7q ........................ 1.92. 31.37 2,62 3~.50 2.93 '37.'05 .................... 2,75 39'61 2,56 ~2.27 2,~G ~7.91 ' 2.95 . 5i,20 3.29 55~2 60.51 5,08 AMOCO PRODUCTION SM6S UNiT 187~6 NO. 13 ;:~::'SOUTH .RIDDLE GROUND SHOAL . .ALASKA ;SPERRY,SUN WFLL SLJRVEY~:Nc. COMPANY Ai~HORAGE, ' COFIPUTAT:i::ON DATE NO~'£~BER 10', 1975 . ::". . PAGE 9 DAT~ O; SURVEY NOVEMB£R 9, 1975 SHRUEL.GYRoScoPIC MULTIRHOT SURVEY 'dnB-'NON~ER SU3-160"31 ............. K~LY BUSHING ELEVo = ~10o00 FT, · INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA OEPTH ~EASURED .___~ ~TH TRUE VERTICAL DEPTH 8776 8710.00 / 8881 8810o00/ 89'87 8910.00; SUB-SEA TOTA'L VERTICAL RECTANGULAR COORDINATES DEPTH NORTH/SOUTH EAST/NEST .DIFFERENCE 9091 9010.00 8600.00 ;589o8~ S 67;5.87 8700.00 ~08.17 S 702.09 U 71.85 880-0'~00 --:~'~5;-59--~ ....... ~9;'6~ ~ :~- 77.01 8~oo,oo ~i.~ s 75e.t~ u ~ e~.~2 9195 9299 9210 ~p~05 -'.9310 950~ '9~10 9609 9510 9712 -":'~610 981~ i7971.0 .9917 9810 10000 9891 .pp_ ~9ooo.oo ·~se.~o s -'?~t.7~_:w ..... : .......... 85.~9 .00 ~'~200.00 ':~':8.0.90 S :830.52 W '93.33 .00 9300.00 ~9t,73 S '8B3,·50 W '9e.51 .00 9500.00 511.21 S -698.2'0 W ' 102.~8 .00 9600.00 519.96 S 918,33 W 10~.77 .00 9700'~'00 529,16'-'"'A .............. '9~7.55-"~'-~ .............. 107.01 o~1 9781.31 556.79 S 9~2.22 ~ 108.68 VERTICAL ~ORR~cTIou 5.83 5.51 5.15 ~.71 3°88 3.i7 3.09 2,77 2.38 1,66 CALCULATZO.N PROCEb-URE~-:TUS-~:-A--L'~NEAR~NTE'~POLA'Y[ON:B--B~'~'UE£'N ..................................... THE NEAREST EO FOOT ~O (FROR RADIUS 'OF .cURVATURE) POINTS . . G. J. Ross Area Superintendent D~ember 16, 1975 File: GJR-1000-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: P.O. Box 779 Anchorage. Alaska 99510 Amoco Production Company I '~ :;.NC-, 0 '1 .... DR~FT _.1 ..... s~.c__L COt,iF.ER: F!LE: Re: Monthly Report of Drilling and Workover Operations SMGS Unit Well No. 13 Attached is the State of Alaska Form P-4 furnishing November 1975 drilling operations for South Middle Ground Shoal Unit Well No. 13. Yours very truly, Area Superintendent Attachment ~)rm No. P--.4 ]~'~, 3- I-?0 STATE OF ALASKA SUBMIT IN DUPLICAT~ OIL AND OAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~ Alii NU~EPdCAL CODE t ~,~.-. OF OPm~ATOS Amoco Production Company 50-133-20277 LEASE DESIGNA~ON AND S~IAL NO. ADL-18746 8. L,~IT F.~ OR LEASE NAME SMGS Unit , , 3. AnDRESS OF P. O. BOX 779, Anchorage, Alaska 99510 4. LOCATION OF Leg 1, Slot 7, SMGS Platform Dillon, 743' FSL, 1818' FWL, Section 35, TdN, R13W, S.M. 9 WELL N'O 13 10 FIFJ~D A.ND POOL. OR WILDCAT South Middle Ground Shoal n SEC. T.. R.. ~. (~OM HO~ o~~ Sec. 35, TdN, R13W, S.M. I~. P~IVIIT NO 75-44 13. RE~ORT TOTAL DEPTH AT E~D OF MON'I'H. CHA~NGF~S IN HOLE SIZE. CASING ANTD C~V[ENTING JOBS INCLUDING DEPTH SET ~ VOLLrlVIES USED, PERFORATIONS. TESTS ~ RESULTS FISHII%tG JOBS JUq~IK L~T HOLE AND SIDE-T]~ACKED HOLE AfqD A.N'Y OTI-~R SIGNIFICANT CI-IANGF~ IN HOL,~ C~NI)ITIONS Monthly Report of Operations for November 1975: November 1-2: Directionally drilled and surveyed from 9490-9870'. Tripped out and worked stuck pipe at 9455'. Circu- lated hole and pipe came free. Tripped in and reamed 9440-9633'. November 3-4: Directionally drilled from 9870-10,100' TD. Tripped out and hole was tight. Reamed from 9808-9905'. Circulated hole to condition mud for logging. November 5-13: (continued) Rigged up logging tools and ran the following logs: IES, Gamma Ray, Density, Sonic, Dipmeter. Ran 243 joints 9-5/8" casing to 10,086'. Circulated hole and cemented with 1000 sacks Class G cement and had full returns during cementing. Cut off casing and installed tubing spool and successfully tested to.2000 psi. Tripped in with bit and scraper and tagged bottom at 10,028'. Tripped out and ran gyro survey from 10,000' to 1500' with 100' stops. Ran cement bond log. Estimated top of cement 7600'. Displaced hole with power oil and ran gauge ring and junk basket to 9350'. Tripped in with packer and set at 9298'. Tripped out and ran in seal assembly, ~"~- .~"~" Kob~ BHA and 294 joints of 3-1/2" Buttress , ~k~~' ~-~/'''% w ~. 14. sm~ ,-.~~.'-- ~/~~~ ~ _ =~ Area Superintendent n.~ December 16, 1975 NOTE--Re~ort on this form is required for ea~ calendar ~ths regardless of the status of operations, and must ~ flied i. dupll~te with the oil and got conservation commiflee bythe 15~ of the suoc~ding ~n~, uflle~ Otherwise d~rscted. State of Alaska Form P-4 Amoco Production Company SMGS Unit Well No. 13 December 16, 1975 November 14-15: Perforated the following intervals with 4JSPF: 9344-9351' 9422-9429' 9455-9462' 9610-9617' 9648-9655' 9703-9710' 9736-9743' 9810-9817' 9851-9858' 9898-9905' Installed 3" x 2-1/8" Kobe hydraulic pump and 24-hour test yielded: 2343 BO, 209 BW, 589 MCF, 251 GOR. Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 G. J. Ross Area Superintendent November 14, 1975 File: GJR-918-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Monthly Report of. Drilling and Workover Operations SMGS Unit Well No. 13 Attached is the State of Alaska Form P-4 furnishing October's drill- ing operations for South Middle Ground Shoal Unit Well No. 13. Yours very truly, Area Superintendent Attachment btm No, P---4 R,~. 3- I-?0 STATE OF ALASKA OIL AND GAS CONSERVATION COMMI~EE SUBMIT IN DU!~LICAT~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS APl NUMERICAL bODE 50-133-20277 LEASE DESIGNATION AND SElqlAL NO. ADL-18746 1. ? IF INDIA]~. ALOTTEE OR TRIBE NAME OIL ~ OAS ~ ~[LL ~[LL ~. N~E OF OP~TOR 8. L~IT F~ OR LEASE ~oco Production Company SMGS Unit 3. AD~RESS OF OPhiR P. O. Box 779, Anchorage, Alaska 99510 4 LOCA~ON OF WEL~ Leg 1, Slot 7, SMGS Platform Dillon, 743' FSL, 1818' FWL, Sec. 35, T8N, R13W, S.M. 9 WELL KO 13 l0 FLELD A_~ID POOL, OR WILDCAT South Middle .Ground Shoal I1 SEC . T.. R.. M. (BOTTOM HOL~: oamcTrv~ Section 35, TSN, R13W, S.M. ' 12. PERMI~ NO 75-44 13. REPORT TOTAL DEPTH AT END OF MONTH. CH~.NGES IN HOLE SIZE, CASING AND CLI/ENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED. PEH,FOHATIONS, TESTS AbrD RESULTS FISHING JOBS JI/NK IN HOLE AND SIDE-TI~ACKED HOLE A3CD A~Y OTHER SIGNIFICANT ~GES IN HOLE CONDITIONS Monthly Report of Operations for October 1975: October 1-2: Directionally drilled and surveyed from 6808' to 7228'. Drill string torqued up and backed off at 149' from the surface. Tripped in overshot and latched onto fish at 2335'. Recovered 2946' of drillpipe, leaving two separate fish in the hole, one comprised of 1597' of 4-1/2" drill- pipe and the second comprised of the drilling assembly and remaining drillpipe. October 3-5: Tripped in with overshot and latched onto the drilling assembly fish but could not move. Ran free point and backed off at 6809'. Tripped out with fish and recovered 2109' of drillpipe. String dragged badly until it cleared the top of the second fish at 5281'. October 6-7: Tripped in for second fish but was unable to catch. Tripped in and spotted 300 sacks Class G cement with 0.23 gallons per sack D-80 and 20% sand at 5270'. Reversed out at 4800'. After WOC, drilled cement stringers from 5080-5270'. October 8-9: Tripped in to 5270' and spotted 300 sacks Class G cement with 0.1 gallon per sack D-80 and 20% sand. Reversed out at 4700'. After WOC, drilled cement stringers from 4810- 5.092' and hard cement 5092-5124'. October 10-31: Sidetracked fish, directionally drilled and surveyed from s,=~'~J~(L~· k~~~ =~ Area Superintendent mA~ November 14, 1975 ~T- ~ ~ N E--R,~o o, ~ form i~ r~q,ir~4 for ~,~ c~l~nd,r oil .nd g,t conlerv, tion com~iffie bythe 15~ of t~e ~u~c~ding mon~. ~le~ ot~er~iI~ dir~cIed. G. J. Ross Area Superintendent October 10, 1975 Amoco Production Company P.o. Box 779 Anchorage, Alaska 99510 File: GJR-837-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Monthly Report of Drilling and Workover Operations SMGS Unit Well No. 13 Attached herewith is the State of Alaska Form P-4 describing the September drilling operations for South Middle Ground Shoal Unit Well No. 13. Yours very truly, George J. Ross Area Superintendent Attachment STATE OF ALASKA suB~rr n~ OIL AND GAS CONSERVATION COA/V~ITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Wl:LL 2. NAME OF OP~ATOR Amoco Production Company 3. ADDRESS OF' O~ER~TOR P. O. Box 779, Anchorage, Alaska 99510 4 bOCA~ON OF W~T.T~ Leg 1, Slot 7, SMGS Platform Dillon, 743' FSL, 1818' FWL, Sec. 35, T8N, R13W, S.M. AP1 NLrlVIERICAL CODE 50-133-20277 LEASE DESIGI~ATION AND SERIAL NO. ADL-18746 Ii IF INDIA~, ALOI t~: O~ TRIBE 8. L,~IT FAR~I OR LEASE SMGS Unit WELL NO 13 10 FIFJ~D A-ND POOL, OR WILDCAT South Middle Ground Shoal 11 SEC , T.. R. M. (HO~TOM HOI~E o~r~rrv~ Section 35, T8N, R13W, S.M. 12 PER~IIT NO 75-44 i3. REPORT TOTAL DEPTH AT END OF MONT'H. CHA.NGES IN HOLE SIZE, CASING AND CE!VIENTING JOBS INCLUDING DEPTH SET AND VOLLrlVIES USED, PER~ORATIONS. TESTS AND HEMULTS FISHING JOB~ Jb~NK IN HOLE AND SIDE-TRACKED HOLE A2qD A3qY aTelIER SIGNIFICANT CH2d~ES IN HOI~E CONDITIONS Summary of Operations for September 1975: September 1-11: Drilled and surveyed from 659' to 1525' with 17-1/2" bit. Cleaned out 20" surface casing to 659'. Drilled to 1525' and cemented 13-3/8" casing at 1516' with 750 sacks Class G + 2% gel + .12 gallons D-80 per sack at 12.8 ppg, followed by 500 sacks Class G + 2% CaC1 at 15.8 ppg. September 11-22: Drilled-and surveyed from 1525' to 5277' with 12-1/4" bit. While cleaning out bridge at 5203', twisted pin off in box with bit 74' off bottom. Tripped out with 148' of drillpipe. Recovered fish and bit was split in welds and 3 cones sheared off. Drilled and milled junk to 5337'. September 23-30: Directionally drilled and surveyed from 5337' to 6808' with 12-1/4" bit. Hole was found in excellent condition and no drag. iii il i lB i -l" I hereby ~fY~7;~e ,ore~.Lru~ar~d correct, sm~.~W~. ~~ ~ Area Superintendent~ .... ~,~ 0ctober. !0, 1975 f h ~th ~ NOTE -- Report on this form ti required or .eaC calendar regardless of [h~ status 0f operations, and must ~ filed In duplioole with the oil and gas conservation commi~ee bythe 15~ of the suoc~ding mon~, unle~ Otherwile directed. G. J. Ross Area Superintendent September 10, 1975 File: GJR-754-WF Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Non-Operator Approval to Drill SMGS Unit Well No. 13 Platform Dillon, Cook Inlet, Alaska Attached is Shell Oil Company's signature of approval for drilling SMGS Unit Well No. 13. Please refer to the~attached copy of our letter of August 11, 1975, File: GJR-670-WF. Yours very truly, George J. Ross Area Superintendent Attachments STA~c O'F ALASKA Form 10 - 403 REV. I - t0-73 ISmbmit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION COMMI'I-I'EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to devpen use "APPLICATION FOR Ib'EP,~I'£-L'' 'for such-p~o~osalS.) 99510 WELL WELL OTHER 2. NAME OF OPEJRATOR Amoco Production Company 3. ADDRESS OF OPERATOR P. O. Box 779, Anchorage, Alaska 4.LOCATION OF %VELL At surface Leg 1, Slot 7, SMGS Platform Dillon, 743' FSL, 1818' FWL, Section 35, T8N, R13W, S.M. Check Appropriate Box To Indicate Nature of NOtice, Re 13. ELEVATIONS (Show whether DF, RT, OR, etc. RDB 100' above HSL 14. NOTICE OF INTENTION TO: T£ST WATER 8HUT-OFF PULL OR ALTER CASINO FRACTURE TREAT MULTIPLE COMPI,ETE 8HOOT OR ACIDIZE ABANDONs REPAIR WELL CHANO~ PLAN~ ~ Other) ,5. APl NUi~IF.~H~CAL CODE 50-133-20277 6. LEA-sE DECmlGNAT1ON A. ND SERIAL NO. ADL-18746 7. IF INDIA. N, ALLOTTEE OR TRIBE NA~LE 8. UNIT, FARM OR LEASE NAME SMGS Unit WELL NO. 13 10, FIELD AND POOL, OR WILDCAT South Middle Ground Shoal 11, SEC., T., R., M,, (BOTTOM HOLE OI&JEC~FIVE) Sec. 35, T8N, R13W, S.M. 12, PERMIT NO. WATIIR 8HUT-OFF FRACTURE TREATMENT SHOOTING OR ACIDIZINO (Other) 75-44 )ort, or Other Data I i REPAIR~NO W~LL ALTERI N0 CASINO ABANDONMenT* (NoT=: Report results of multiple completion on Well C.mpletion or Recompletlon Report and Log form,) 15 DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and giv~ pertinent dates, including estimated date of starting an}' proposed work. Reference is to Permit Application Form 10-401 dated August 11, 1975. Operator proposes to change casing program per verbal approval given August 25, 1975 by John Miller to Bill Halvorson. New design is as follows: 13-3/8": 0-1500' 68#, K-55 Buttress 9-5/8": 0- 300' 300-3000' 3000-5400' 5400-8400' 8400-TD 43.5#; E-95 Buttress 40#, N-80 Buttress 40#, S-95 Buttress 43.5#, E-95 Buttress 53.5#, S-95 LT&C 16. I hereby c. ettffy' that the foregoigg-Ia, true and correct TITLE Area Superintendent DATE August 25, 1975 CONDITIONS or~/~, PRO-VlL, TITLE See Instructions On Reverse Side DATE Amoco Production Com?-gy ENGINEERING CHART FILE APPN .¥ /', , ~ '/ ] I / Zg C.'" L? c:'c-C) / '~'') I I t/./.~]). G. J. Ross Area Superintendent August 25, 1975 File: GJR-713-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001Porcupine Drive Anchorage, Alaska 99501. Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 ! ! I I I I l-!. l · I CONFER: Dear Sir: Re: Application for Permit to Drill SMGS Unit Well No. 13 ' Reference is to'our letter of August 11, 1975 transmitting an Applica- tion for Permit to Drill SMGSiUnit Well No. 13, and to conversation this date between your Mr. JohnMillerand Bill Halvorson of this office. Per subject conversation, Amocoplans to set 13-3/8,', 68#, K-55 Buttress casing at.1500' rather~than 2000' as originally planned, as noted on the attached Form 10-403.~ Also, please note the~revised design for the -9-5/8,' casing. We haVe modified the~design in order to use existing stocks of 40#,.~N-80 and 53.5#,. S-95 casing. Also attached is a sketCh of the'20", 2000. Psi BOP-diverter stack which we plan to use for drilling the~17-1/2"~hole, from 659' to 1500'. Yours very truly, George J. Ross Area Superintendent Attachments cc: A. M. Roney Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 G. J. Ross Area Superintendent August 15, 1975 File: GJR-675-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 AU8 8 1975 Dear Sir: Re: Application for Permit to Drill SMGS Unit Well No. 13 Reference is to our letter of August 11, 1975, File: GJR-670-WF, sub- mitting subject application. As your Mr. Harry Kugler pointed out by phone call August 13, 1975, we inadvertently neglected to enclose the $100 permit fee with the application. Enclosed please find our draft, payable to the State of Alaska, Department of Revenue, in the amount of $1oo. Also, please be advised that there are no other affected operators, as Section 3,'T7N, R13W is an Amoco, et.al., lease ADL-18746 and is held by production. Section 34, TSN, R13W was formerly an Amoco, et.al., lease which expired in 1972and is currently open. Yours very truly, Supervisor in Charge Enclosure August gO, lg75 Re: S~S Unit No. 13 ~ Productt~ Company 75-~ lit. John C. Schtllere¢¢ Supervisor in Charge Amoco Production Coa~ny P. O. ~ox 779 ~r~ge, Alaska g~lO Sir: ~losed is the approved application for permit to drill the above referenced well at a location, in Section 35, Township 8N, Range 13W, SM. Well samples, core chips, and a mud log are not required. A directional survey is ~t~ed. Polluti~ of any Waters of t~ State ts prohibited by_AS 46, Chapter 03, Artlcle'7 aad the regu)atiens p~tgated thereunder (Title 18, Alaska _ A~inistratl~ C~, Chapter 70) and by the Federal Water Pollution Control Act, as amende~. Prior to commenci~ ope~tions you may be contacted by a representative of the Department of Environmental Conservmtton. Pursuant to AS '-~..40, Local Hire Under State Leases,. the Alaska Department of Labor is being notified of the issuance of this permit to drill. In the event of suspension or abandonment please give this office adequate advance notification so that we. may have a witness present. Very f Enclosure cc: ~par~t of Fish and Game, Habitat Section w/o encl. De~r~t of Envtr~~' tal Conservation w/o e~cl. Oepar~t of Laber, Supe~sor, Labor Law Compliance O! on wlo encl. (B~ No~e to Shm~ lPlea~e signify you~ approva~ to of ~he subject well by si~ b~o~ and ~o~arding ~o copies zo ~h~s off,ce. ~~ you.) Approve of drilltnt ~$ Unit No. 13 as described above. Shell Oil ¢ompa!ct~y G. J. Ross Area Superintendent August 11, 1975 File: GJR-670-WF Amoco Production Companyp. o. Box 779 Anchorage, Alaska 99510 Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001. Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: ApPlication for Permit to Drill SMGS Unit Well No. 13' Attached is an application for a permit to drill South Middle Ground Shoal Unit Well No. 13.' The Proposed location at the~top of the Hemlock (cOnglomerate) is 400' FSL, 925.' FWL, Section 35, T8N, R13W, S.M. ThiS well will be the third producer in SW 1/4. Section.35 and is re- quired to recover trapped oil east of the'fault whiCh forms the western productive limit tothe field. Pursuant to Conservation Order No. 44, Rule 6-d, we are requesting Administrative Approval of the subject drilling application. By copy of this letter, Shell Oil Company is being requested to furnish non-operator approval as is required by the above referenced Rule 6. Yours very truly, ~ohn C. Schillereff Supervisor in Charge Attachment cc: Ken LaGrone Shell Oil Company, Anchorage Porto I0-- 401 REV. I --I--71 ~. TYP~ oF WOrK SUBMIT IN TRII (Other lnstructior,. reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE' PERMIT TO DRILL OR DEEPEN API ~, 50-13,3-20277 DRILL [~ DEEPEN I-'l o,L 7~ °'" 7'1 o,., ,.o,. W,LL __ WmLL 2. NAME OF OPER.ATOR Amoco Production Company 3. ADDRESS O~ OPEP. ATOR 8. ~E DI~IGNATION ~ S~L NO. ADL-18746 r. IF INDIAN, Al~L~'l-i'~:l~ OR TRIBE NAM~ '8. UNIT F~RM OR LEASE NAME SMGS Unit P. O. Box 779, Anchorage, Alaska 99510 4. LOCATION OF WELL Ats~rface Leg 1, Slot 7, 743' FSL, 1818' FWL, Sec. 35, T8N, ?~atform Dillon) R13W, S.M At proposed prod. ' · 400' FSL, 925' FW1, Sec. 35, T8N, R13W~ S.M. 13. DISTANCE IN MILES AND DIRECTION I~ROM NEAREST TOWN OR POST OFFIC]g* 15-1/2 miles NNW 0f)~ Kenai 14. BOND INFORMATION: Blanket Bond - Division of Lands Bond File B-11 TYPE Surety and/or No. 15. DISTANCE FROM PROPOSED* ' i18. NO. OF ACl~.E~ IN LEASE. LOCATIONTO NEAREST 925' FWL at urod PROPERTY OR LEASE LINE. :1~1'. . ~. · {Also to nearest drig. unit, if any) 680v at TD ~zone 4160 18. DISTANCE FROM PROPOSED LOCA~ON' 19. PRO~S~ D~ TO NEAREST WELL DRILLING, cOMpL~. OR APPLIED FOR, 850~ 8~ of s~Gs Unit ~ell No. 6 10,350~ 21. ELEVATIONS (Show Whether DF, RT, CB,' etc.) RDB 100' above MSL 23. PROPOSED CASING AND CEMENTING PROGRAM WE'LL NO, 13 10. i~IELD AND POOL, OR WILDCAT South Middle Ground Shoal 11, SEC., T., R., M., (BOq[rOM HOLE OBJECTIVE) Sec. 35~ T8N. R13W, S.M. 12o ~-~, $100,000 ':17. NO. ACR~ ASSIGNED TO TltiS WELL 8O 20. ]~OTARY OR CABLE TOOLS , rotary 22. APPROX. DATE WORK WILL START* , August 20~ 1975 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GJ~.D'~: SET'fJ~G D~P'I~ quantity of cement 17-1/2" 13-3/8" . 5.4.5~I : ~K_55 2.000, :CircUlate to surface .. 12-1/4" 0-5/8" 40: 43.5t~ S-95 10.'350' Min.' 500' above top of. pay _ Operator Plans to drill 17-1/2'' hole vertically from existing 20" casing set at 659' to a depth of 2000' and set 13-3/8" casing. A 12-1/4" hole will be drilled to TD and 9-5/8" casing set. The 12-1/4" hole will be drilled vertically to approximately 5500' and kicked directionally to the proud target at -9100' There are no affected operators· possiblyIntervals stimulated indicated productive by log analysis will be perforated BOP specifications are attached. ~ .~. ':-. _ ~ ABO~ SPACI{I D~ISC'RIBE IWROPOSED PI~O~RAM: I' ~po=l iS tO d,.;~n ,ive dat~ on p,esen, productive new productive zone. _lf_lLro._vo_s~.l m__ tQ.drlll_ Or tl~2pen Hiller. tonally, live pertinent ~ata' on'$t/bsurface li~.~tions and vertical depths. Give blowout preve_nter l~rOg.ram. ~.~.,-. 24. I hereby certify that the Fore~goingl$ True an~ CO1TeC~ STG ~'- - ~f DAT~ August 11, 1975 DI~ON~ SURVEY R~~ A.P.L ~g~ CODJ CHAIRHAN trn~ Supervi_~.~?n ~ August 20, 1975 August 20~ 1975 CHECK LIST FOR NEW WELL PERMITS 1. Is the permi~t fee attached ..................... Company /~oco Lease &.Well 'No. Yes_ NO :" Remarks'-":' ~ ....... ~ ' 0~ l!ed 2'~ , ~ ~ ~. +' 2. Is well to be located in a defined pool ............... 3. Is a registered survey plat attached . ............... 4. Is well located proper distance from property line ........ 5. Is well located proper distance from other wells .......... 6. Is sufficient Undedicated acreage available in this pool ...... 7. Is well to De deviated ....................... ,, 8. Is operator the only affected party ................ 9. Can permit be approved before ten-day wait ............. . I0. Does operator have a bond in force ................. ~x: __ Il. Is a conservation order needed . - ........... , o ~ 12. Is administrative approval needed ................. A/oFf____ 13. Is conductor string provided ................. · .... 14. Is enough cement used to circulate on conductor and surface .... 15. Will cement tie in surface and intermediate or'productiOn strings . 16. Will cement cover all known productive horizons .......... 17. Will surface casing protect fresh water zones ............. 18. Will all casing give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure rating ............. ~dditional Requirements- ~jA_+, o,[[, 7