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Home My WebLink About175-0661a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ 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): Middle Grnd Shoal GL: N/A BF: N/A Total Depth: 1703' FNL, 657' FWL, Sec 2, T7N, R13W, SM, AK 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: 23. BOTTOM 20" J-55 610 13-3/8" K-55 1,511 9-5/8" S-95/N-80 9,140 7" P-110 9,985 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 N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST Sr Res EngSr Pet GeoSr Pet Eng Flow Tubing 3/6/1976 Date of Test: Oil-Bbl: N/A Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 34.5# / 40# 10,500 Surf 8,897 85# 54.5# / 68# 610 Surf 9,624 CASING WT. PER FT.GRADE 26# N/A 228050.5 TOP SETTING DEPTH MD Surf 9,363 Surf Surf 2463848.4 N/A 12/20/1976 CEMENTING RECORD N/A N/A SETTING DEPTH TVD 2461497.2 TOP N/A 12/2/1975 10,500 / 9,985 Surface 100 HOLE SIZE AMOUNT PULLED suspension, or abandonment, 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 if necessary E,F G Oil, Middle Grnd Shoal Oil & SMGS Undefined WDSP Pools 229216.8 Hilcorp Alaska, LLC 9/18/2022 175-066 / 322-385 50-733-20281-00-00 S MGS Unit 14 ADL0018746 674' FSL, 1771' FWL, Sec 35, T8N, R13W, SM, AK 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG WAG Gas N/A BOTTOM 33' (SS) & 9,548 (LS)3-1/2" SIZE DEPTH SET (MD) 9,536 / 9,058 PACKER SET (MD/TVD) TUBING RECORD Surf 1,511 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 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, Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment RECEIVED by James Brooks at 12:46 pm, 9/30/2022 Abandoned 9/18/2022 JSB RBDMS JSB 102722 xGBJM 11/9/23 SFD 11/15/2022 DSR-10/27/22 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. Dan Marlowe Contact Name: Aras Worthington Operations Manager Contact Email:Aras.Worthington@hilcorp.com Authorized Contact Phone:907 564-4763 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: 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). 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. 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. 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. This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 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). INSTRUCTIONS Authorized Name: Authorized Title: Signature w/Date: 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS 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, 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. Formation at total depth: If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2022.10.26 13:12:38 -08'00' Dan Marlowe (1267) WBD_DI-14 Schematic 2022-09-28.doc Updated by JLL 9/28/22 Dillon Platform DI-14 Dillon Platform Well DI-14 P&A: 09/18/2022 Oil well >Disposal>Injection well Dual String Jewelry Detail # Depth (RKB) Length ID OD Item Long String 1 Surface 1.0’ 10” Cameron dual tubing hanger 2 9,469’ 1.25’ Jet pump adapter 3 9,489’ 20.25’ 3.0” Kobe type “E” Cavity w/ adapter SN-2095 4 9,490’ 0.50’ 3-1/2” 8RD x 3-1/2” Butt crossover 5 9,527’ 0.50’ 3.0” 4.25” Locator size 80-40 6 9,536’ 4.0” 5.875” Baker model F-1 production packer size 85-40 7 9,547’ 19.87’ 3.0” 4.0” Seal assembly size 80-40 8 9,548 0.66’ Mule shoe Short String A Surface 1.0’ Cameron dual tubing hanger B 33’ 32.0’ 2.992” 3.5” 1 jt. 3-1/2” Butt tubing Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 20” Conductor 85#, J-55 Surface 610’ 1250 sxs 13-3/8” Surface 68#, K-55 Surface 1,220’ Butt / 12.415”1250 sxs, Calc TOC=122’, (Incli.=0.8°)54.5#, K-55 1,220’ 1,305’ Butt / 12.615” 68#, K-55 1,305’ 1,511’ Butt / 12.415” 9-5/8” Intermediate 43.5#, S-95 Surface 312’ Butt / 8.755” 880 sxs, Calc TOC=8,121’ (20% washout) 40#, N-80 312’ 1,837’ Butt / 8.835” 40#, S-95 1,837’ 6,171’ Butt / 8.835” 43.5#, S-95 6,171’ 9,624’ Butt / 8.755” 7” Liner 26#, P-110 9,363’ 10,500’ BU EL/6.276” 250 sxs, CBL TOC=TOL Tubing 3-1/2” Production 9.2#, N-80 Surface 9,548’Butt / 2.992”Long String (LS) Surface 33’ Short String (SS) Perforation Data ZONE TOP BTM Shot (jspf) Condition G-1 9,809’ 9,824’ 4 Open G-2 9,885’ 9,952’ 4 Open G-3B 10,067’ 10,250’ 4 Open G-4 10,270’ 10,310’ 6 Open Fish Detail Fish # Depth Length Item Description 1 9,738’ WLM ~369’ 25 jts of 5” heavy weight drill pipe& BHA, Cemented behind casing [2/2/76] 2 10,408’ 17’ Go-Internationals 2-1/8” gun [12/21/76] 3 10,408’ ? Perf gun (similar to fish #2) [12/21/76] 4 10,408’ 16.167’ two (2-1/8”) 5’ guns w/ 3 blank & centralizer [3/15/77] TD =10,500’ PBTD = 10,463’ MAX HOLE ANGLE =26.8O @ 7,200’ MD 1 13-3/8” @ 1,511’ 8 RT-THF: 35.88’ KB 7” @ 10,500’ 9-5/8” 9,624’ G&G Oil Top 9,758’ MD A 3 4 5 TOL 9,363’ 2 Rotating Hours 20” Conductor 25.5 hrs 13-3/8” csg Total rotating hrs 651.5 hrs 9-5/8” csg Total rotating hrs 138 hrs 7” csg Total rotating hrs 30 hrs B 6 7 20” @ 610’ Perfs 9,809’ – 10,310’ Calc TOC 8,121’ Cemented BHA at 9,738’- 10,107’ WLM TOF/junk 10,351’ KB SLM ADL: 18746 PTD: 175-066 Leg 4, Slot 3 API: 50-733-20281-00 Notes: x 08/2011 – Well circulated with 9.8 ppg brine. Pumped 28 bbls LCM pill (w/fibers), squeezed 12.7 bbls into perfs. Well dead. Freeze protected. x History of scale buildup in the tubing. x 10/28/2009 – LS: RIH with tandem gauges to 9600’ KB. 1 A B Cement plug #2: LS: Surface - 402’ MD SS: Surface - 33’ MD IA: Surface - 402’ MD OA: Surface - 402’ MD OOA: Surface –1,511’ MD Cement plug #1: LS: 9454’ - 3722’ MD (SL Tag 8/28/22) IA: 9454’ – 3,000’ MD (Est) Rig Start Date End Date EL 7/30/22 9/18/22 08/02/22- Tuesday R/U to circulate down LS out SS,;Pump 31 bbls @ 2.6 BPM 540 psi getting back oil/gas turning to brine, cont circulate taking returns out IA till oil cap off and brine @ 9.7 ppg, pump total 177 bbls.;R/U circulate down IA out LS, pump 140 bbls @ 3 BPM @ 140 psi. looking for good brine, s/d for night. 07/30/22 - Saturday Mobe crews to platform, orientate same, R/U w/l unit & lubricator, P/u tubing punch;P/T lubricator 200/3000 good, RIH w/ 1 11/16 tubing punch, correlate on depth off down hole jewelry, punch 8 holes f/9454-9456, drop down log punch good indication, POOH all shots fired. R/D secure well. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 14 50-733-20281-00-00 175-066 08/03/22 - Wednesday R/U circulate down LS out IA, pump 176 bbls till good brine back 9.7, shut down. Mobe Halliburton crews. Work on rigging up CMT eq & circulating lines. Welder working on mix tank hopper install. R/U pump lines to DI-17 for injection of displaced fluids. Cont. r/u CMT eq. inject 68 bbls into DI-17. Pump gear end over heating, s/d mobe out Mechanic. Electrician wire up & bump test mix pump. Cont. r/u tank manifolds & lines for CMT unit. Unload boat with backup mud pump, troubleshoot pump overheat issues. Test run pump injecting 63 bbls into DI-17 @1.45BPM 2730psi good. Secure well, SDFN. 08/04/22 - Thursday PTSM, open up & inject 197bbls circulated fluid from well into DI-17, 2.7BPM, 3450psi. R/U circulating lines. Cementers continue r/u. Arrange decks, spot product at pump. Cementers mix make up water, finish tie into LS DI-14, top off water tanks. PJSM, line up HCU fill lines shut in at well. PT lines 700/2750 good. Open well, LS psi 263, IA 0, pump 20 bbls surfactant wash down LS, out IA. Swap to fluid pump, circulate 192 bbls 9.7brine down LS, s/d. LS psi 0, IA 110 psi, secure well. 08/05/22 - Friday R/u Pollard SL Unit. M/u tools and Lubricator, Master valve would make 10 out 22 turns open, troubleshoot and could not get valve fully opened. Contact wellhead rep to trouble shoot. 08/27/22 - Saturday PTSM, Eq. checks, start eq. & walk lines. PJSM with hands involved in job. Open well check pressures, LS 0, IA 0, OA 95. Pump 5 bbls water, mix & pump 1660sx 461bbls, 14 ppg cmt, @ 5BPM 200 psi. SD, launch wiper ball w/3 bbls pump 26bbls 9.7 brine, total @ 4bpm, FCP 695psi. S/d monitor 30 min, IA 0, LS 230, OA 95, secure well. Wash up unit, R/D off well. & pump 1660sx 461bbls, 14 ppg cmt, @ 5BPM 200 psi. SD, launch wiper ball w/3 bbls pump 26bbls 9.7 brine, t Rig Start Date End Date EL 7/30/22 9/18/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 14 50-733-20281-00-00 175-066 08/28/22 - Sunday Held PJSM, approve PTW Service and warm eq. R/d SL and moved to Di-3. Heliport weather delay, wait on wellhead rep. Wellhead service rep on platform, repaired master valve. R/u circulating lines and eq. Pumped 7.5bbls to fluid packed LSxIA. CMIT-LSxIA t/ 2500psi per Sundry as following: Pretest: LS/IA/OA/OOA=0/0/20/0 BBL Pump: 2.5 Initial: LS/IA/OA/OOA= 2850/2850/120/0 15mis: LS/SS/IA/OA/OOA=2740/2740/115/0 30mins: LS/SS/IA/OA/OOA=2675/2675/110/0 45mins: LS/SS/IA/OA/OOA=2650/2650/110/0 BBL Return: 1.25 MIT-LSxIA Passed. R/d circulating eq. and move to D1-13. R/u SL on LS, RIH w/2" Bailer tag 3722'. POOH recover sample of wet cement, witness by State Inspector Sean Sullivan. 09/17/22 - Saturday Held PJSM. Flange up for surface cement job, on OOA, OA, IA, S/S, L/S. Assist Slick line rigging down to free up crane. Rig up fluid pump to DI 17 injection well, injecting 160 bbls oil Diesel & water into DI 17 from DI 10 well. Moving cutting pallets on deck, spot cutting boxes, top off upright FIW tanks. Change out two valve cover gaskets and tighten same. Finish injecting the fluid out of the Rain for rent tank, DI 10 fluid to DI 17 injection well pump total of 280 bbls. Move cmt hoses from DI 10 well and arrange on deck to run to the DI 14 well. Hook up pump and return hoses to well OOA, OA,IA, SS, & LS, install tees' in return line and pump lines. 09/01/2022 -Thursday Well pressures Tbg/IA/OA/OOA=0/0/0/0psi , Spot and R/u EL unit, assembly tool string, 2x wt/b, ccl, 2" gun loaded 6' w/production charges (6.5grams 6spf ). RIH w/tool string t/ CCL depth 399' and fired gun perf 402'-408', POOH, confirmed all shots fired, Check well OA is communicating with IA /Tbg, no change with OOA. R/d EL. d fired gun perf 402'-408', MIT-LSxIA Passed. RIH w/2" Bailer tag 3722' Rig Start Date End Date EL 7/30/22 9/18/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 14 50-733-20281-00-00 175-066 Held PJSM. Check line up to tree, attempt to circulate LS x OOA, thru perforations at 402 - 408 elm, pressure up to 550 psi with 2 bbls pumped, holding for 3 minutes, bleed to "0" with 2 bbls. back. Pressure up to 750 psi with 1.5 bbls pumped, pressure bleed back 600 psi in two minutes, and holding Bleed off LS x OOA thru LS x OA. Circulate the LS x OA thru perforations at 402-408 elm, at 2.25 bpm at 150 psi after pumping first Bottoms up ( 28 bbls ). Increased rate to 2.50 bpm at 275 psi, with total of 39 bbls back at return tank, pressure increased to 600 psi, shut down pump, pressure bleed off slowly. Attempt regain circulation pressure up to 600 psi, bleed off pressure, regain circulation on LS x OA at 2.8 bpm, at 325 psi, pumped total 68 bbls with clean returns. Open LS x IA thru perforations at 402' to 408' at 3.0 bpm at 250 psi, pump total of 52 bbls two bottoms up had clean returns back at return tank. Shut down pump well static, close in IA open LS x SS pump 5 bbls with clean returns. Held PJSM with cmt crew. Pump 80 bbls of Mud flush III spacer at 3.0 bpm at 200 psi, pumping 40 bbls down LS x OA and 40 bbl down LS x IA. Mix and pump 290 sxs of Cl "G" cmt 80 bbl slurry, at 3 bpm at 210 to 280 psi, mix at 14.0 ppg, Pumping 35 bbls on LS x OA, 29 bbls on LS x IA, & 9 bbls on LS x SS good cmt back surface 14.0 ppg. Close S/S, IA, & OA, pressure up to 500 psi with 1.3 bbls holding for 5 minutes, pressure bled from 500 to 379 psi, pressure back up to 500 psi, with .2 bbls holding for 5 minutes, pressure bleed f/ 500 psi to 440 psi, bleed off to "0" with 1/5 bbl back to cmt unit. Well static, close LS, cmt in place at 1500 hrs. Had full return during job. Rig lines clean up after job. 09/18/22 - Sunday attempt to circulate LS x OOA, thru perforations at 402 - 408 elm, pressure up to 550 psi with 2 bbls pumped, pump 290 sxs of Cl "G" cmt 80 bbl slurry, at 3 bpm at 210 to 280 psi, mix at 14.0 ppg, Pumping 35 bbls on LS x OA, 29 bbls on LS x IA, & 9 bbls on LS x SS good cmt back surface 14.0 ppg. Circulate the LS x OA thru perforations at 402-408 elm, From:McLellan, Bryan J (OGC) To:Aras Worthington Cc:Regg, James B (OGC) Subject:RE: Dillon P&A Witnessed MITs Date:Monday, September 19, 2022 5:47:00 PM Aras, Hold off on the Dillon 13 shallow P&A for now. It looks like I spoke to soon. This one was deemed inconclusive and will require a re-test. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: McLellan, Bryan J (OGC) Sent: Friday, September 16, 2022 4:39 PM To: Aras Worthington <Aras.Worthington@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: Dillon P&A Witnessed MITs Aras, Jim and I have reviewed the Inspector’s reports and agree that the following wells meet at least one of the two following criteria, and Hilcorp can therefore continue with the sundried P&A work on these wells: 1. <10% pressure loss over 30 minutes and pressure loss trending toward zero. 2. <2.5% pressure loss over 30 minutes. D-03 D-07 D-08 D-12 D-13 D-14 D-15 Well D-04 did not meet these criteria and will need something else done before moving up hole for the surface plug. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Aras Worthington <Aras.Worthington@hilcorp.com> 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. Sent: Monday, September 12, 2022 1:22 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Dillon P&A Witnessed MITs Bryan, I understand you are in an all-day-meeting today. Below is a summary of each of the witnessed MITs we performed this last weekend. I took these numbers straight from the digital data files (I can send those too as needed). Give a call anytime if you’d like to discuss or would like the full data files, or any other information. We would like to proceed with the P&A completion on all of these wells, which typically means the perforating @ ~400’ MD and circulating in the surface cement plug. Please advise if we can proceed with these P&As. We are ready to do so. Thanks and Best Regards, Aras Worthington Hilcorp Alaska LLC Senior Technical Advisor for Alaska Operations, PE Aras.worthington@hilcorp.com 907-564-4763 907-440-7692 mobile Di-03: Time (Hrs:Mins)Pressure (psi)Pressure loss per 15 minutes (psi) Pressure loss as a % of total pressure 00:02 2840 00:17 2726 114 4 00:32 2655 71 2.6 00:47 2597 58 2.2 Total pressure loss/last 30 minutes 129 Total pressure-loss for last 30 mins is 129 psi, less than 10% pressure-loss. Pressure loss per 15-minute interval is consistently less than the previous 15-minute interval and the percentage of pressure-loss of each interval is less than the previous interval. This verifies a stabilizing pressure trend and therefore a passing MIT. Di-04: Time (Hrs:Mins)Pressure (psi)Pressure loss per 15 minutes (psi) Pressure loss as a % of total pressure 00:04 2816 00:19 2679 137 4.9 00:34 2581 98 3.6 00:49 2497 84 3.2 Total pressure loss/last 30 minutes 182 Total pressure-loss for last 30 mins is 182 psi, less than 10% pressure-loss. Pressure loss per 15-minute interval is consistently less than the previous 15-minute interval and the percentage of pressure-loss of each interval is less than the previous interval. This verifies a stabilizing pressure trend and therefore a passing MIT. Di-07: Time (Hrs:Mins)Pressure (psi)Pressure loss per 15 minutes (psi) Pressure loss as a % of total pressure 00:03 2840 00:18 2756 84 2.9 00:33 2726 30 1.1 00:48 2701 25 0.9 Total pressure loss/last 30 minutes 55 Total pressure-loss for last 30 mins is 55 psi, less than 10% pressure-loss. Pressure loss per 15-minute interval is consistently less than the previous 15-minute interval and the percentage of pressure-loss of each interval is less than the previous interval. This verifies a stabilizing pressure trend and therefore a passing MIT. Di-08: Time (Hrs:Mins)Pressure (psi)Pressure loss per 15 minutes (psi) Pressure loss as a % of total pressure 00:05 2788 00:20 2608 180 6.4 00:35 2528 80 3.1 00:50 2472 56 2.2 Total pressure loss/last 30 minutes 136 Total pressure-loss for last 30 mins is 136 psi, less than 10% pressure-loss. Pressure loss per 15-minute interval is consistently less than the previous 15-minute interval and the percentage of pressure-loss of each interval is less than the previous interval. This verifies a stabilizing pressure trend and therefore a passing MIT. Di-12: Time (Hrs:Mins)Pressure (psi)Pressure loss per 15 minutes (psi) Pressure loss as a % of total pressure 00:05 2781 00:20 2578 203 7.3 00:35 2479 99 3.8 00:50 2414 65 2.6 Total pressure loss/last 30 minutes 164 Total pressure-loss for last 30 mins is 164 psi, less than 10% pressure-loss. Pressure loss per 15-minute interval is consistently less than the previous 15-minute interval and the percentage of pressure-loss of each interval is less than the previous interval. This verifies a stabilizing pressure trend and therefore a passing MIT. Di-13: Please note that only 30 mins of data were recorded. The MIT pressure-up started at about 30- minutes into the data file. We did not run this test out 45 minutes like the others. Time (Hrs:Mins)Pressure (psi)Pressure loss per 15 minutes (psi) Pressure loss as a % of total pressure 00:30 2695 00:45 2612 83 3.1 1:00 2551 61 2.3 Total pressure loss/last 30 minutes 144 Total pressure-loss for last 30 mins is 144 psi, less than 10% pressure-loss. Pressure loss per 15-minute interval is consistently less than the previous 15-minute interval and the percentage of pressure-loss of each interval is less than the previous interval. This verifies a stabilizing pressure trend and therefore a passing MIT. Di-15: Time (Hrs:Mins)Pressure (psi)Pressure loss per 15 minutes (psi) Pressure loss as a % of total pressure 00:12 2808 00:27 2755 53 1.9 00:42 2712 43 1.6 00:57 2675 37 1.4 Total pressure loss/last 30 minutes 80 Total pressure-loss for last 30 mins is 80 psi, less than 10% pressure-loss. Pressure loss per 15-minute interval is consistently less than the previous 15-minute interval and the percentage of pressure-loss of each interval is less than the previous interval. This verifies a stabilizing pressure trend and therefore a passing MIT. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 35 Township: 8N Range: 13W Meridian: Seward Drilling Rig: N/A Rig Elevation: N/A Total Depth: 10500 ft MD Lease No.: ADL0018746 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 610 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 1511 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 9 5/8" O.D. Shoe@ 9624 Feet Csg Cut@ Feet Liner: 7" O.D. Shoe@ 10,500 Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 9548 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Other 9450 ft 3722 ft 9.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2850 2740 2675 2650 IA 2850 2740 2675 2650 OA 120 115 115 110 OO 0 000 Remarks: Attachments: Wade Hudgens Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): P 200 lb Tool string consisted of rope socket, knuckle joint, 2x 45 lb weight bars, and hydraulic spangs (spangs/bailer when sampling). Completion packer in place of bridge plug @9450 ft MD. Wireline ran in with bailer - sample looked good but not completely hard. August 27, 2022 Sully Sullivan Well Bore Plug & Abandonment S MSG Unit 14 Hillcorp Alaska LLC PTD 1750660; Sundry 322-385 none Test Data: Casing Removal: rev. 11-28-18 2022-0828_Plug_Verification_SMGS_Di-14_ss 9 9 9 James B. Regg Digitally signed by James B. 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Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Monday, November 23, 2009 1:57 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Aubert, Winton G (DOA) Cc: Nash, R Scott; Newell, Jack R [FEP]; Quick, Mike [ASRC]; KRAMER, TED E; Ross, Gary D Subject: Dillon D -14 (S MGS Unit 14 PTD 1750660) Compliance Reporting for Admin Approval AIO 8.004 Attachments: Di -14 Post Injection Report 11- 23- 09.pdf To all, The Dillon disposal operations have been completed and the Di -14 is now shut -in again. This e-mail will provide the documentation of the adherence to the conditions of approval for the AA on the Di -14 well. The attached pdf contains the following: Pg 1 -2) Copy of AA AIO 8.004 with the six conditions listed for use of the Di -14 well. Pg 3 -4) Record of wellhead pressure and rate monitoring (Condition #1). Pg 5) Record of injected fluid source, type and volume (Condition 2). Pg 6) Plot of post- injection wellbore temperature survey as compared to the pre- injection survey (Condition #6). The inner annulus (IA) pressure was limited to 2000 psi throughout the disposal operations (Condition #3). The well didn't exhibit any indication of a change in mechanical condition during the disposal operations so Conditions #4 #5 were never needed. The post- injection temp survey did not show the temperature anomaly above the packer as you can see on the plot. We believe this is due to the reduced rate of injection over time resulting from the IA pressure limitations and the quality of the fluids injected into the well. Slower injection allows more time for the temperatures of the injected fluid to rise toward the temperatures of the surrounding rock and would decrease the size of the anomaly. As demonstrated by the temp survey, there isn't any indication that the injected fluids went outside of the approved disposal zones. If there are any questions, please feel free to call me. Larry NEC: NOY 2 200S 263 -7661 «Di -14 Post Injection Report 11- 23- 09.pdf» 11/24/2009 ID t 7 t I I t (hi) 1 i t r l t i t i 1 l I r 't SEAN PARNELL, GOVERNOR ;j t 1_ ALASKA. OIL AND GAS 333 W. 7th AVENUE. SUITE 100 CONSERVATION COMMISSION ANCHORAGE. ALASKA 99501.3539 PHONE (907) 279 -1433 FAX (907)2764542 ADMINISTRATIVE APPROVAL AIO 8.004 Mr. Larry Greenstein Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519 -6247 Re: South Middle Ground Shoal (S MGS) Unit 14 (PTD 1750660) Request for Ad- ministrative Approval Middle Ground Shoal Oil Pool, Dillon Platform Dear Mr. Greenstein: In accordance with Rule 9 of Area Injection Order (AIO) 008.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby approves Union Oil Company of California (Union)'s request for administrative approval to inject non- hazardous oil field fluids into the subject well. A wellbore temperature survey indicates that well S MGS Unit 14 exhibits a production casing liner leak, and thus does not meet the mechanical integrity requirement of AI0 008.000. The Commission finds that Union does not intend to repair the well at this time. However, injected fluid appears to be confined to subsurface strata that are approved by AIO 008.000 to receive injected fluids. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to inject non hazardous oil field fluids in S MGS Unit 14 is conditioned upon the following: 1. Union shall monitor wellhead pressures and injection rate continuously during in- jection; 2. Union shall submit to the AOGCC a post injection report of injected fluid source, type, and volume; 3. Union shall limit the inner annulus pressure to 2000 psi; 4. Union shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 5. After well shut -in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and AIO 8.004 September 15, 2009 Page 2 of 2 6. Union shall perform and submit to the AOGCC a post- injection wellbore tem- perature survey. DONE at Anchorage, Alaska and dated September 15, 2009. OIL .1�� ttI q ie Seamount, Jr. O Ca y P Foe r t ai an Commissioner 41 '3Tfr ii.7 c.o. RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. lithe notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration. upon denial. this order or decision and the denial of re- consideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Com- mission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by in- action, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on re- consideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on re- consideration. As provided in AS 31.05.080(b), "(tlhe questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to inn is not included in the period; the last day of the period is included, unless it fhlts on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. DataProTM Pump Report AlaskaDillion2] i O perator Rhett Moncrief Report Date 26 WeatiErfati E Location 0 Days On Loc 7 Well DI -14 Injection Well Spud Date 19- Oct -09 Days Since 7 Injection Meter Cur. Cur. Cur. Depth Pump Pump p i p Date Time (MD) Turbine Turbine Pressure Flow Rate Volume (12) (11) (11) (f! [bpm) [8W) WW1 w 25- Oct -09 19:15 0.0 0.00 0 0 25- Oct -09 19:30 0.0 0.00 0 -1 25- Oct -09 19:45 0.0 0.00 0 13 25- Oct -09 20:00 0.0 0.05 0 390 25- Oct -09 20:15 0.0 i 0.05 1 414 25- Oct -09 20:30 0.0 0.05 2 390 25- Oct -09 20:45 0.0 0.05 2 323 25- Oct -09 21:00 0.0 0.05 3 320 25-Oct-09 21:15 0.0 0.05 4 320 25- Oct -09 21:30 0.0 0.05 5 319 25- Oct -09 21:45 0.0 0.05 5 320 25- Oct-09 22 :00 0.0 0.05 6 318 25- Oct-09 22:15 0.0 0.05 7 318 25 -Oct -09 22:30 0.0 0.05 8 318 25 -Oct -09 22:45 0.0 0.05 6 318 25 -Oct -09 23:00 0.0 0.05 9 318 25 -Oct -09 23:15 0.0 0.05 10 318 25 -Oct -09 23:30 0.0 0.05 11 317 25 -Oct -09 23:45 0.0 0.05 11 317 26- Oct -09 00:00 0.0 0.05 12 309 26 -Oct -09 00:15 0.0 0.05 13 323 26 -Oct -09 00:30 0.0 0.75 14 371 26 -Oct -09 00:45 0.0 0.81 24 666 26 -Oct -09 01:00 0.0 0.47 36 672 26 -Oct -09 01:15 0.0 0.45 42 620 26- Oct -09 01:30 0.0 0.55 49 778 26- Oct -09 01:45 0.0 0.48 57 676 26 -Oct-09 02:00 0.0 0.48 64 983 26-Oct-09 02:15 0.0 0.47 71 1,034 26- Oct -09 02:30 0.0 0.46 78 1 ,079 26- Oct -09 02:45 0.0 0.46 85 797 26 -Oct -09 03:00 0.0 0.00 92 949 26- Oct-09 03:15 0.0 0.48 93 804 26- Oct -09 03:30 0.0 0.53 100 846 26- Oct -09 03:45 0.0 0.50 107 1,102 26- Oct -09 04:00 0.0 0.45 114 936 26- Oct -09 04:15 0.0 0.38 121 1,006 26- Oct -09 04:30 0.0 0.31 127 1,295 26- Oct -09 04:45 0.0 0.46 134 1.229 26- Oct -09 05:00 0.0 0.00 140 1,120 26 -Oct-09 05:15 0.0 0.25 144 1,115 26- Oct -09 05:30 0.0 0.25 147 1,050 26 -0d -09 05:45 0.0 0.06 150 1,108 26- Oct -09 06:00 0.0 0.00 151 1,006 omments 0 DataProTM Well Head Report Alask aDiilion2] Operator Rhett Moncrief Report Date 26- Oct -09 0 W eatherford. Location Well DI -14 Injection Well Days On Loc Spud Date 19- Oct -09 Days Since 7 1 Well Head Depth Cur. Cur. Cur. Date Time (MD) Tubing Outer Inner pm g' Mules Anulas (8) PSIG (2) (ft) [psis) insist [psis] 25 -Oct -09 19:15 0.0 0 0 -9,999 25 -Oct -09 19:30 0.0 0 0 1 25-Oct-09 19:45 0.0 17 87 921 25- Oct -09 20:00 0.0 372 94 1,032 25- Oct -09 20:15 0.0 377 94 1,037 25- Oct -09 20:30 0.0 363 90 1,025 25 -Oct -09 20:45 0.0 317 79 930 25- Oct -09 21:00 0.0 324 76 926 25- Oct -09 21:15 0.0 324 75 925 25- Oct -09 21:30 0.0 325 74 924 25 -Oct -09 21:45 0.0 324 74 924 25 -Oct -09 22:00 0.0 324 74 923 25- Oct -09 22 :15 0.0 324 74 923 25 -Oct -09 22:30 0.0 323 75 923 25- Oct -09 22:45 0.0 323 75 923 25- Oct -09 23:00 0.0 323 75 923 25 -Oct -09 23:15 0.0 320 76 923 25- Oct -09 23:30 0.0 321 76 923 25- Oct -09 23:45 0.0 322 77 922 26- Oct -09 00:00 0.0 271 77 922 26- Oct -09 00:15 0.0 349 82 990 26 -Oct -09 00:30 0.0 471 89 1,089 26- Oct -09 00:45 0.0 720 102 1,301 26- Oct -09 01:00 0.0 770 96 1,258 26 -Oct -09 01:15 0.0 667 83 1,148 26-Oct-09 01:30 0.0 730 83 1,156 26 -Oct -09 01:45 0.0 780 82 1,160 26 -Oct -09 02:00 0.0 823 82 1,168 26- Oct -09 02:15 0.0 875 81 1,157 26 -Oct -09 02:30 0.0 919 80 1,166 26 -Oct-09 02:45 0.0 967 80 1,163 26 -Oct -09 03:00 0.0 982 77 1,134 26- Oct-09 03:15 0.0 890 73 1,050 26 -Oct -09 03:30 0.0 1,019 77 1,133 26 -Oct -09 03:45 0.0 1,068 79 1,183 26- Oct -09 04:00 0.0 1,074 80 1,209 26- Oct -09 04:15 0.0 1,125 82 1,233 26- Oct -09 04:30 0.0 1,158 84 1,300 26- Oct -09 04:45 0.0 1,217 86 1,312 26 -Oct -09 05:00 0.0 1,184 86 1,321 26 -Oct -09 05:15 0.0 1,132 81 1,257 26- Oct -09 05:30 0.0 1,150 82 1,274 28 -Oct -09 05:45 0.0 1,118 80 1,247 26- Oct -09 06:00 0.0 1,012 71 1,079 Comments Dillon Platform: S MGS Unit 14 PTD: 175 -066 Di -14 Disposal Well History Table 1: South Middle Ground Shoal (S MGS Unit 14) PTD 175 -066: Oct 25, 2009 Injection Summary Fluid Source Type Volume S MGS Unit 7 PTD:167 -069 Diesel 3.7 Barrels S MGS Unit 16 PTD: 194 -057 Diesel 3 Barrels S MGS Unit 17 PTD: 194 -056 NO Fluid N/A S MGS Unit 18 PTD: 194 -098 Hydrocarbon, Oil 6.7 Barrels S MGS Unit 13 PTD: 175 -074 Hydrocarbon, Oil 13 Barrels S MGS Unit 2RD2 PTD: 175 -007 Hydrocarbon, Oil 10.1 Barrels S MGS Unit 15 PTD: 176 -045 NO Fluid N/A S MGS Unit 3 PTD: 167 -028 Hydrocarbon, Oil 3 Barrels Platform: Rain Water, Deck drains Water 39 Barrels Platform: Water Rinsate, No Solids Water 18 Barrels Platform: Oil, water Diesel Flushed Fluids Diesel 25 Barrels Platform: Post water flush Water 25.2 Platform: Methanol, Freeze Protection Methanol 4.8 Table 2: Gas Bleed Volumes Fluid Source Type Volume S MGS Unit 7 PTD:167 -069 Gas Negligible S MGS Unit 16 PTD: 194 -057 Gas 2500 CF S MGS Unit 17 PTD: 194 -056 Gas 3789 CF S MGS Unit 18 PTD: 194 -098 Gas 43,471 CF S MGS Unit 13 PTD: 175 -074 Gas 3480 CF S MGS Unit 2RD2 PTD: 175 -007 Gas 630 CF S MGS Unit 15 PTD: 176 -045 Gas 66,900 CF S MGS Unit 3 PTD: 167 -028 Gas 1400 CF Wage Chevron WeII:1Di 14 1 Field 'Dillon 110 -28 -2009 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 1 1 f i 500 Pressure Temperature Profile 1 Going in hole MD 1000 1 2 Well Shut -In 1500 f 2000 2500 i 3000 3500 f 4000 W 4500 Ci 5000 5500 ci 6000 6500 7000 7500 8000 I 8500 9000 1 9500 10000 E i 40 50 60 70 80 90 100 110 120 130 140 150 160 Temperature (Deg. F) 10 -29 -09 Pressure Perfs 20" 13 3/8" 9 -5/8" 3 -1/2" TBG 7" —10-28-09 Temp —8-25-09 Temp August 3, 2009 Dale A. Haines Manager, Oil & Gas Operations Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 -0-ftmMrr Dear Commissioner Foerster, \ `1 �s (--) c -t -u , c) Union Oil Company of California 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com 'AUG 0 2009 Alapk,i p i & las Cons, Cnmmigsinn Anphna -- v7,� 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, �) 1JCtk,.- 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 31-14RD42 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 life 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 1 ife 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 Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di4 1670580 Jul -98 H draulic 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 1 Abandon abandon at end of platform 1 ife Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase 1 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 134 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 2113-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 23B-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Sep -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 T onek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 444 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct -9 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 Apr -8 Collapsed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 Jun -8 Collapsed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-30 1730140 Oct -9 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of pl form life ALASKA 011L GAS CONSERVATION COMUSSION June 22, 2009 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 �( ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dale Haines UNOCAL AwEr 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubert(@alaska.g-ov. Sincerely, 4404-'. 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 • • Fleckenstein, Robert J (DOA) From: Greenstein, Larry P [Greensteinlp@chevron.com] Sent: Monday, June 09, 2008 3:40 PM To: Fleckenstein, Robert J (DOA) Subject: Di-14 Completion Guide Attachments: Di-14 Completion Guide.jpg Di-14 Completion Guide.jpg (37... «Di-14 Completion Guide.jpg» Here is th~e___d_oc_~en used, Bob, to establish the packer depth in SMGS 18746 #14,~(~PL- TD #1750660. Larry ~~-~ ~~~NB~E~ JUN ~ .~ 2008 • urJV i v• ~ • • Fleckenstein, Robert J (DOA) From: Greenstein, Larry P [Greensteinlp@chevron.com] Sent: Monday, June 09, 2008 1:31 PM To: Fleckenstein, Robert J (DOA) Subject: RE: PKRTVD Project Attachments: An-19 Dec84 Schem Updated.doc; GP 24-13RD Final 10-4-97.DOC; D114DrawingSchematic1985-08-25.PDF; SRU 32-33WD schematic 8-28-02.doc Here is what I based our depths on Bab. Please iet me know if these will suffice to update your records. Thanks Larry From: Greenstein, Larry P Sent: Thursday, June 05, 2008 10:20 AM To: 'Fleckenstein, Robert J (DOA)' Subject: RE: PKRTVD Project Will do Bob. I'm at 263-7661, but I've been gone the last two days, so I'm just catching up now. I'll get the back up data to you as soon as I can. The 1680360 GRANITE PT ST 18742 25 is getting the MIT done the same way a bunch of other Anna wails are, which is by using temperature surveys to confirm every other year where the water is being injected. Sorry for the delay in getting back with you. Larry From: Fleckenstein, Robert J (DOA) [mailto:bob.fleckenstein@alaska.gov] Sent: Wednesday, June 04, 2008 10:15 AM To: Greenstein, Larry P Cc: Regg, James B (DOA) Subject: PKRTVD Project Larry, have reconciled all the PKRTVD differences except for the following wells. Please send me your paperwork on these wells that verify your data. 1680060 GRANITE PT ST 18742 19 =__> An-19 1750660 S MGS UNIT 14 =__> Di-14 1801150 SWANSON RIV UNIT 32-33WD =__> SRU 32-33WD 1801160 GRANITE PT ST 24-13RD =__> GPP 24-13RD If 1680360 GRANITE PT ST 18742 25 does not have a packer in the well what are you testing against? Thanks, 6/9/2008 BobF Robert J. Fleckenstein Statistical Technician II Alaska Oil and Gas Conservation Commission Office: 907-793-1242 Fax: 907-276-7542 "[iii. ~~c, i'.li( ~ ",1~ _`3?2ii!! i1{~{~4~c y boh. fleclenstei n(u~alasl.a.~o~~ 6/9/2008 Fleckenstein, Robert J (DOA) From: Regg, James B (DOA) Sent: Thursday, May 29, 2008 1:46 PM To: Fleckenstein, Robert J (DOA) Subject: FW: UNOCAL PKRMC & PKRTVD Spreadsheet Attachments: UNOCAL PKRMD & PKRTVD.xIs • This attachment may reflect the changes since you spoke with him yesterday - I have not checked. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 ~,~. From: Greenstein, Larry P [mailto:Greensteinlp@chevron,com] Sent: Thursday, May 29, 2008 9:59 AM To: Regg, James B (DOA) Subject: FW: UNOCAL PKRMC & PKRTVD Spreadsheet Hi Jim, Since your name is on the letter i gat from Commissioner Foerster, i wanted you to get the packer depth reconciliation spreadsheet, I like using the color coded version just because it focuses me on the more problematic wells. Cleared four mare wells since !sent this to Bob yesterday. The TVD calc on G-29RD was recalculated and now matches yours and the An-19, D-14 RD & D-29RD wails have been confirmed by schematic to be those few feet off from your depths. There are a lot of small differences in depths that won't make any difference in the required test pressure for an MIT (coded yellow). And a few that had some clear reasons why our depths didn't match (coded purple). The two blue colored wells are the only ones where our depths just don`t seem to match up with yours without anything to explain why except maybe just some sort of typo. Let me know if you would like to discuss any of these or anything else further. You don't need a formal response letter back on this, do you?? I assumed the data attached to this e-mail would suffice. Thanks Larry From: Greenstein, Larry P Sent: Wednesday, May 28, 2008 10:21 AM To: 'Fleckenstein, Robert J (DOA)' Subject: RE: UNOCAL PKRMC & PKRTVD Spreadsheet Here you go Bob. Lots of updates seem to be coming out of this. Didn't worry about differences of a few pounds on the required test pressure calc as this doesn't change the pressure test for the MIT. 6/3/2008 iu~~.~.v1.~ • Hope this helps. Larry From: Fleckenstein, Robert J (DOA) [mailto:bob.fleckenstein@alaska.gov] Sent: Tuesday, May 06, 2008 3:21 PM To: Greenstein, Larry P Subject: RE: UNOCAL PKRMC & PKRTVD Spreadsheet Larry, Attached is a revised sheet for you to use. I have added 3 columns for your use Thanks, BobF Robert J. Fleckenstein Statistical Technician II Alaska Oil and. Gas Conservation Commission Off ce: 907-793-1242 Fax: 907-276-7542 '€ I::~S~. 1?U$:t L1YLt% Ce;:}~i.t. 21d_!r3-;~, bob. flec_k_ enstetl~r;;alaska.~ov From: Greenstein; Larry P [mailto:Greensteinlp@chevron.com] Sent: Monday, May 05, 2008 3:28 PM To: Fleckenstein, Robert J (DOA) Cc: Regg, James B (DOA); McMains, Stephen E (DOA) Subject: RE: UNOCAL PKRMC & PKRTVD Spreadsheet Thanks Bob (and Steve}. An electronic copy will make it easier for me to make updates and corrections. Larry From: Fleckenstein, Robert J (DOA) [mailto: bob.fleckenstein@alaska.gov] Sent: Monday, May 05, 2008 3:26 PM To: Greenstein, Larry P Cc: Regg, James B (DOA) Subject: UNOCAL PKRMC & PKRTVD Spreadsheet Attached is the data you requested. BobF Robert J. Fleckenstein Statistical Technician II 6/3/2008 • rage 3 or ~ Alaska Oil and Gas Conservation Commission Office: 907-793-1242 Fax:907-276-7542 ~~~ 5 bc~l~ tl~elc~,r~stcin~t a?c~s~ca.goy 6/3/2008 r ASK . >aev+n~c roq comma WV tc~co,.oaE aAt6 ~..~ Fr- b r ff' Et p NhME w«t _1HF 6013 NTX 5TA'[@ FiI' ~1 , M 1 ~ NF `" .m _. -__r_ ~~ -.. „,~ ~H. Q~A~E - r~~~ ~ {j~EP,,, GP,.Sl N._.......~ ~~~~ _~~~ ~ ~ ~r ~~ t t ~~ .ti' t/i .. '"'zE t W~ G T G12ACA£ Tt<NE A¢ -pt.. l.tNEft ~ i ~~ ~ ~ ~ ec~f~ I L! t) f ~) SAFETY tQUI#h{EFdI' ~~AS LfFT Et~UiPR4EtJT ~ %'~C~ERS RNC} ACCES~bRtES ~CC}MPLET6~C}N EQUiPM~NT ~?pSF GOARRL~Td~/~! F<~UVPtJE~*;? 7t1 iti~ UT j !+a:no ~ ~. _ tT DES~i21RTEl}N QR E(~JfRMENT ANp SERViGfS £STfiw,AxE r ` # _ ~.__... ~, Uc~ --cam-^ ~},, ~ - f -- - - ~~i ~ ~ ~ ,- N _. _~ ~~ !t o G<' a :, x'sF~~ .~` ~ ,~`y ,siv ,. ~ : , ,f-a? -~ ~, r~.~ ,~ r ~ 3 ~~ c- - __ _ ~. .. s ~ r _._...- __ f ~ ., F _ t,. ~t ~ .' r ~ - ~ _- 1 ~ ~`~ ~ ~D 'S f`5 ~r. ~. t - - t ~ - - - ~ . f.. -- r-..-- / ~} q ~3 . . _... - wtty } f i << _ ~} i t -~ C ~ i w ~ ~,:~ -- - ~ .n '..'~r"j q. 3 c ___ ~ -----_. ,.._ _.., , .: a ~ S` 1 Ga` ~ ,- s ~.._ _.__.~~ ~ __.. ., I '~ ~~ ~.s~c"C~ TC~?At e`rirEa~.A?'E ------ b-- - -~.~ r L1,~_~ .. ~? ~ -, _., r ,Jyrr w /~ ~ ~ ~.' }. ~~ ~~~~~ ~~ ~~i - A i :...~ ~~ - : t., dr' . -:~-t of=rscs __- _ _._.__._ -- -- --~...-.~.._. ~,_ -.o.- ~_~ ffA.,s c,:-: _.__~ " _ STATE OF ALASKA ~' 9 2007 ALAS.IL AND GAS CONSERVATION COMMI " N REPORT OF SUNDRY WELL M 1 "'ttI!. Commission nCharage 1, Operations Abandon U Repair Well LJ Plug Perforations 0 StimulateU Other L:J Convert to Injector Performed: Alter Casing 0 Pull TubingD Perforate New Pool D WaiverD Time ExtensionD Change Approved Program D Opera!. Shutdown D Perforate D Re-enter Suspended WellD 2, Operator Union Oil Company of California (Unocal) 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 ExploratoryD 1750660 ... 3. Address: P. O. Box 196247 StratigraphicD ServiceD 6. API Number: Anchorage, Ak. 99519-6247 50-733-20281-00 ..- 7. KB Elevation (ft): 9. Well Name and Number: 100' KB ABOVE M5L Di-14 .., 8. Property Designation: ,tiP ~ I!>'ý.(, .D 1 10. Field/Pool(s): Dillon p~ .'" . Middle Ground 5ho",lr~::_ 11. Present Well Condition Summary: Total Depth measured 10,500' / feet Plugs (measured) true vertical 9,985' " feet Junk (measured) Effective Depth measured 10,351' feet SGANNED MAR 2 0 2007 true vertical 9,835' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 575' 20" 610' 609' Surface 1,496' 13-3/8" 1,511' 1,510' Intermediate Production 9,589' 9-5/8" 9,624' 9,140 Liner 1,137' 7" 10,500' 9,985' Perforation depth: Measured depth: 10,270-10,31010,243-10,248 10,235-10,240 10,215-10,22510,200-10,205 10,189-10,194 10,177-10,18210,128-10,13310,102-10,107 9,947-9,952 9,922-9,937 9,885"9,895 9,809-9,824 True Vertical depth: 9,760-9,7999,733-9,738 9,725-9,7309,706-9,7169,691-9,6969,680-9,685 9,669-9,6749,621-9,6269,596-9,601 9,447-9,4529,423-9,4389,388-9,3979,315-9,329 Tubing: (size, grade, and measured depth) 553-1/2" N-80 @ 67' L5 3-1/2" N-80 @ 9,463' Packers and SSSV (type and measured depth) HE5 V5T Retrievable packer @ 9,172' 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: 0 0 0 620 630 Subsequent to operation: 0 0 0 620 630 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run none ExploratoryD Development D Service 0 . Daily Report of Well Operations 16. Well Status after work: OilD Gas D WAG D GINJ 0 WINJ D WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. rUndry Number or N/A if C.O. Exempt: Contact Larry P. Greenstein ~~4J7 Printed Name Larry P. Greenstein Title Production Technician , /~ ¿;J & ,~ Signature / "/1"Aul./( ;..Æ{ ~~ Phone 263-7661 Date 3/8/2007 I V ,~ ...- Form 10-404 Revised 04/200t) R , G J N A L RBDMS 8Ft MAR 2 0 2DD7 h ~, "~,~ 2A,' Submit ~nal Only 1 ~",i¢? /- 3.1,·0 . ... 20" 85 .Ie 951 CS4 810' ~ 13 318" aSf CSÞ. 1511' 2 .4 SOUTH MIDDLE GROUND SHOAL ADL 18746 \\'ELl NO, 1 4 HEMLOCK CONGlOMERAit: PLATFORM DlLLO~ .4 Depth ;)5' 9463' 9468' 9469' g<t8g' 9490' 9!S2S' 9527' g:!!];) 954a' ~1I'I~r.~()n R.eor~ L.an9 String: \. 10" COmtr'Ofl Dual !>CB HGrlg__ 2. 3 1/2" N-80 Suttru. tubing J, ;) 1/2" 8IIttrutI tubing pup 4. Jet Pump Adaptor 5. Kobe J" ~ "E" CavIty .ro-2095 6. ;) \/2" &'W GrId J 1/2" ButtN.. xo 7. 3 1/2" arttre.. tubing pup a. Seal locctor .t. S.at~ly 10. tdul.,hoe - Shc.rt String: A. ;) 1/2" 11-80 Buttrea. tubIng f~':'~~ ~~ Spud Dat~: 11/2&'75 Surfa~ LocctIon: lag 4, Slot 3, SUGS Plotfonn omon n1' FSt.. 1770' FWL. s.c, 35, TaN, R13W, S.u. Subaurloce Locatton: ro - 18&8' f1\t. 88" fWl. See. 2, T7N, R13\4', SOU. ElevotJon: 100' KB-USl ro: 10500' 00: 891W P90: 10410' TVD: '1145' eo.Inø: 20", e:s, = H-40 Ca.lnQ ..t at 610' fifth 1250 !IX. cmt 13 ;,¡1!", K-5S Cc.nC.J Nt at 1S1 l' with 750 .11. cmt Q 5f&", -40. 43.5f £-85 CG.mC.J ..t at 9624' with 9S() ~, cmt 7", 'l.6f lIner..t at 9363-10500' with 750 aK. ~ment 7" 261 t1IIer Top at 9383' 67' !12~) (Mrun Junk: 10235-10240' 10243-10248' 1 021()-1 031 0' G-4: 0-1: 9809-9824' 0-2: 9885-9895' 8922-119:"1' 91147-9952' 0-3B: t0102-10t07" 1017&-101'3' 10177-10152' ~O'1I9-'Q194' 10200- 1 0205' 10215-t0225' Perforation.: ( '>'f::;z_ . 9 518" 40 a: 4;¡~ CSA 9824' 981>9-9824' 9eaS' 9952' 1 01 02' :0 ;. :0 10248' 10270-10310' ....:// /7,- !L:L/-//L Junk end t1.h . 'Q~W PSTD 10460' TD 10500' Gun Gun 1-1/16" 1-11/16" Vi re Centra 11 Ie,. Blank x 2-1/8" 1-11/1'" 1-11/16" -1-11/16- i 2-1/8" \4" x Ž'-'x 8" Jt X X 5' 3' 5' 6" 6" 2" 2001 BOPD, 556 BWPO. 482 UCftJ Non, Nona Non. OIL.-SP, F'DC-QR. roc-GR. 4 Ñm Dlpmeter 2120176 CR 12121/76,1/29178, 1'2/4180 InItial Potential: initial stlrrtufatfon: ~!I...-votr Do.ta.L Cored Inbrvol.: osr tnt_r. and Ruurta: L~ lmentwy. . One followup to our phone call earlier today; I spoke with Bob Fleckenstein about lO-404; he said that we would not need a new 10-404 if there was additional injection into either of the wells ( I believe that is different than I said in our conversation). ~...... ott;~ . \ 1 ~ / \~ So, what we need from you to clanfy the files are: ~ ~ 1) 10-404 for Di -12 to change well from producer to inj ector (status will be 1 WINJ) 2) revised 10-404 for Di-14 to change well from producer to injector (status also I WINJ); previous 10-404 indicated conversion to disposal and showed well status as WDSPL Clear as mud? Thank you. Jim Regg AOGCC Greenstein, Larry P wrote: No problem Jim" ! understand the origins of the L TSI wells and report. It has been a great grouping for a certain class of injection wells (those that have been shut in for a while with no immediate intention of bringing them back on). Perhaps I applied the grouping too broadly. SRU 213-10 was a producing gas wen which required an annual MIT Since it depleted the existing gas zone and, until recently, there had been no discussions of returning this well to production, I lumped this we!! into the L TSI well group. I did this not because it was (or wasn't) an injector, but because of the MIT requirement along with the long term shut-in status. Figuring that any well with an MIT requirement that was to remain shut-in for a long time should be included in this L TSI monitoring report. Oi-14 is a little different. This well was successfully tested and Admin Approval #8.2 converted it (along with Oi-12) into a Class II disposal well. Turns out we only used Oi-12 during the intial disposal operations, so this well sat ready as a back-up. Didn't want the idling of the platform to affect this AA, so I added this well (along with Oi-12) to the L TS! group. I would be glad to continue reporting this two 'different' wells anywhere you would Hke. If a separate report for these wells works out better for you, I'll set one up. If you would like to return them to the L TSI report, I'm fine with that too, Just don't want to miss the reporting requirements for any well, especially ones that are sort of unique. (I believe that 213-10 is the only producing well in C¡ that has a specific MIT requiremenLlet alone an annual schedule). Thanks Jim. Appreciate the discussions. Let me know how you would like to get the monitoring reports for these two wells and I'll make it happen. Larry From: James Regg [mailto:iim reqq@admin,state.ak.us] on 3/16/20073:13 PM Ke: t'UlI L I-,-IV Æ UI-I'I on report - LVUb rOl.uarters L l ~l we.. . Sent: Monday, February 26, 2007 4:05 PM To: Greenstein, Larry P Subject: Re: Pull 213-10 & Di-14 off report - 2006 Fourth Quarter's L TS1 Well Monitoring Report Guess I should have been more clear... My comment was motivated by the fact that SRU 213-10 and Di-14 are not injectors; the report for L ISI wells and previous emails that set that whole effort in motion was directed toward injection wells only (if my memory is not failing me). You still must comply with the requirements of the Conservation Order for these producers. ~... O{gb \1 Jim Regg AOGCC Greenstein, Larry P wrote: Jim, Wanted to make sure we aren't doing something we shouldn't here. For SRU 213-10, the CO #474 rule #3 requires an annual MIT on this gas well. With the well shut-in for so long, we put it on the L TSI list and were feeding you the daily pressure plots quarterly. Your e-mail says we don't have to do this anymore and I have no problem with that. CO #474 rule #4 requires a quarterly repo!i of daily pressures be sent to the A.oGCC, which seenlS to contradict your e-mail. Are we OK with not following rule #4 based on your e-mail?? Thanks Jim Larry From: James Regg [mailto:iim reqq@admin.state.ak.us] Sent: Friday, January 26, 20079:11 AM To: Greenstein, Larry P Cc: Thomas Maunder; Cole, David A; Whitacre, Dave S; Martin, J. Hal; Lambert, Steve A; KRAMER, TED E; Smetanka, Jeff W; Ayer, Phil M; Dolan, Jeff J Subject: Pull 213-10 & Di-14 off report - 2006 Fourth Quarter's L TSI Well Monitoring Report producers 213-10 (I-Gas) and Di-14 (I-OIL) do not need to be on this list Jim Regg AOGCC Greenstein, Larryr P \Víote: Hi Tom & Jim, Here is the fourth quarter's report for the l TSI wells utilizing pressure monitoring in lieu of an MIT to determine any mechanical integrity problems. 20f3 3/16/20073:13 PM I\.e. LUU L 1.J-IV o¿ U!- ¡ '+ U¡ I repon - Lvva ¡Ounn ~uaner S L ! è)[ we. . . Attached is the latest update from Steve lambert on the other two wells that seemed to show communication between the 9 and 13 3/8" The seals in both trees test out as OK, both wells still appeal" to have some annular comrY1un¡cation. The 9 5/8" pressure vvas bleed in G-09 to 1 but annulil dropped and stayed low. The 9 5/8" in GP 33-14RD well was also bleed off and returned to the 13 3/8" pressure quickly to confirm communication in this well Both of these wells are being turned over to the mechanical integrity guy in the driillng group to begin their assessment procedures. All the other wells appear to be fairly stable and show no indications of any well integrity problems. OVJ0 ~~~v Larry «Master Well List TIO Report 2006 12 31.xls» communication» «RE: L TSI well casing 30f3 3!l6/2007 3:13 PM Re: Disposal e e Danny, After talking to our engineer, these 4 wells (MGS 12, 14, 16 &17) are not disposal wells, they remain water injection that can injection special fluids down they into an oil pool. There was NO Disposal Injection Order written for these wells. The field & pool code doesn't need changed or the type of fluid on the monthly injection report 10-406. Sorry for all the confusion and MGS 14 will be changed back to a oil well. There has been no injection of any type into Well MGS - 14. If this well is tobe use for injection, a 10-403 needs submitted to convert the well. Steve Shehata, Danny wrote: Îr Steve, When did it change? Can you please send me paperwork on this well changing the field and pool? Everything I have suggests this well should be reported in field and pool 524114. The only well I see in the l\OGCC database assigned to f&p 524018 is api 5073310076. A MGS well, 09, that appears to have been P&A'd back on 9/3/1976. DamlY From: McMains, Stephen E -AOGCC Sent: Friday, March 31, 2006 2:27 PM To: Shehata, Danny Subject: Re: Disposal You have the wrong pool code for the well. should be 524018. steve Shehata, Danny wrote: Steve, These should work. Danny Shehata Production Accountant - Gas Union Oil Company of California P: (907) 263-7617 F: (907) 263-7607 (:li3:I.1!lYE?~;C::}!:§Y¡;(?I!:.:..5?c:JrTl -----Original Message----- From: McMains, Stephen E -AOGCC Sent: Friday, March 31, 2006 10:12 AM To: Don Page Cc: janet dormady; Danny Shehata Subject: Disposal lof? 4/l?/?OOÓ o''ió AM Kt:: U1SPUSlil e e Don, A disposal order was written for 2 wells on the Dillion Platform, SMGS - 12 and SMGS - 14. January thru April 2003, there was 7,912 bbls of water injected into well SMGS - 12. This volume for the 4 months was submitted as water injection on the 10-406 and not as disposal volumes. Could someone follow-up and check this out with an engineer? If revision are needed please forward to me, thanks. Steve 200301 12L 73320126005524114900000000046500000003 000000000000139400000000IPOOOOOOOOOOOOOOOOOOOOOOOO 200302 12L 73320126005524114900000000021700000019 000000000000412300000000IPOOOOOOOOOOOOOOOOOOOOOOOO 200303 12L 73320126005524114900000000017100000013 000000000000222400000000IPOOOOOOOOOOOOOOOOOOOOOOOO 200304 12 73320126005524114900000000005700000003 000000000000017100000000IPOOOOOOOOOOOOOOOOOOOOOOOO 20f2 4/12/20068:56 AM e e /1j', Jk b ilL,: H, ~,,~ FRANK H. MURKOWSKI, GOVERNOR A",A~1iA OILAlU) GAS CONSERVATION COMltllSSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 March 23, 2006 Ms. Laura L. Hammond Waste Management Coordinator U nocal Alaska 909 West 9th Avenue Anchorage, AK 99501 8C~t"t1~~5.n I...,] £1 Dear Ms. Hammond: Unocal Alaska ("Unocal"), by letter dated March 21, 2006, requested confirmation that liquid wastes developed from gas/oil gathering line cleaning and from well plugging may be legally injected into service wells previously approved for limited disposal of Class II wastes on South Middle Ground Shoal Dillon ("Dillon") Platform offshore Cook Inlet. The Alaska Oil and Gas Conservation confirms that the liquid wastes described in your letter may be legally disposed into the approvd ,,,t'lls on Dillon Platform. Production operations ceased on Dillon in Uel:tn:ber 2002 and Unocal "cleaned" the production equipment on board the platform in early 2003. PrìOl tl) initiating the cleaning operations, Unocal sought administrative approval under Area Injection Order ("Ala") 8 to dispose of liquid wastes in either of two existing enhanced recovery ("EaR") wells on the platform. Injecting wastes into an EaR well is prohibited by Commission regulations. However the C0mmission determined that the liquids, mostly water and oil with some detergents, would not be damaging to the reservoir. Ala 8.2 issued January 29, 2003 authorized disposal of up to 50,000 barrels of liquid wastes into either Di -12 or Di -14. The planned cleaning operations were performed during February and March 2003 with a: total of 6,347 barrels of waste liquid injected into Di-12. No waste fluid has been injected into Di-14. At this time Unocal is proposing to conduct downhole plugging operations on up to 16 wells on Dillon and purge the subsea oil and gas gathering lines connecting Dillon with XTO Platform A to the northwest. The anticipated wastes include fluids circulated from wells (filtered and unfiltered Inlet water, cement and small quantities of oil) and fluids circulated from the subsea gathering lines (unfiltered Inlet water and small quantities of oil and condensate). As allowed by Ala 8.3, Unocal will also dispose of any deck drainage resulting from rainfall onto the platform. Some solid wastes may be generated by these operations. However Unocal is not seeking to dispose of solids on board Dillon. Nor is Unocal seeking approval to inject domestic sanitary wastes that may be generated by the crews performing the operations. e e Ms. Laura L. Hammond March 23, 2006 Page 2 of2 The Alaska Oil and Gas Conservation Commission has completed its review of your request. Liquid wastes resulting from the described well plugging and flowline cleaning operations qualify as Class II fluids and may be injected into either Di-12 or Di-14 according to AIO 8 and Administrative Approvals Ala 8.2 and 8.3. Prior to resuming injection operations, Unocal must confirm the continued integrity of the injection wells with a mechanical integrity test as outlined in Rule 6 of Ala 8. Please have your operations personnel contact Jim Regg at 793-1236 to schedule an Inspector for witness. As provided in AS 31.05.080(a), within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless reconsideration has been requested. , Alaska and dated March ~, 2006 CC~ Tim Brandenburg, Unocal Evan Harness, Unocal e e Chevron Laura L. Hammond Advising Environmental Engineer & Waste Management Coordinator Union Oil Company of California 909 W. 9th Avenue Anchorage, AK 99501 Tel 907 263 7898 Fax 907 263 7901 Emaillhammond@chevron.com MAR 2 1 2006 March 21, 2006 AlaSKa Oil & Gas GorIS. Commission Anchorage Commissioner John Norman Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Re: Description of Proposed Work on Dillon Platform in 2006 and Future Dear Commissioner Norman: The purpose of this document is to communicate to you the scope of work proposed on Dillon Platform during 2006 and subsequent work seasons by Union Oil Company of California (UOCC), an indirectly owned subsidiary of Chevron Corporation, and the disposition of the associated waste streams. Attacheå please find "Description of Proposed Dillon Platform Well and Pipeline Work and Related Waste Disposal." Mr. Tom Maunder recommended that this information be sent to you to secure your concurrence that the fluids associated with the gathering line cleaning and the well work may legally be injected into Dillon Wells #12 and #14 under existing permitting and authorizations. Thank you very much for your consideration of these matters, and please contact me at (907) 263-7898 if you would like additional information about the proposed work. Best regards, '¡f~Ä~~ Laura L. Hammond Attachment: 2 pages Cc: Evan Harness Faye Sullivan Mike Lott Tom Maunder, AOGCC Union Oil Company of California I A Chevron Company http://www.chevron.com íI e e Description of Proposed Dillon Platform Well and Pipeline Work and Related Waste Disposal Purpose Project Type and Planned Timeline Waste Streams by Projeét and Planned Disposition The purpose of this document is to provide an overview of the proposed Union Oil Company of California (UOCe), an indirectly owned subsidiary of Chevron, Dillon Platform work scope as requested by Mr. Tom Maunder. The following is a list of the project types and the possible timeframe: Year Proiect 2006 Well Work up to 16 wells (Most Likely 12 - 13) Future Clean and abandon Dillon Pipelines Future Well Work up to 16 wells (Most Likely 3 - 4) The following table delineates the expected waste streams and their planned disposition for each type of project: Project/Origin Type Waste Stream Disposition Well Work Fluids Inject in Well # 12 or # 14 Deck Drainage Fluids Inject in Well #12 or #14 Clean and abandon Fluids Inject in Well # 12 or # 14 Dillon Pipelines Clean and abandon Solids from Pwductic!l Offsite disposal at Commercial Dillon Pipelines Test Separator and Disposal Vendor, likely G&I in Shaker Texas at Newpark, or ~crrtingent disposal if UOCC has a Class IT (or Class I) Disposal Well set up for G&I such as NNA #2 Clean Baker Gas Pipeline Residual Trapped Gas Vent, maximum amount based on total pipeline volume, actual volume to be reported Both Pipeline & Well Oily Burnable Solids Incineration by Envirotech, Work Nikiski, AK Both Pipeline & Well Greywater NPDES Discharge or ISO Tank Work to Onshore Disposal by Envirotech Both Pipeline & Well Blackwater/sewage Omni-Pure System followed by Work NPDES Discharge Both Pipeline & Well Clean Trash KPB Landfill Work Continued on next page t e e . .. Description of Proposed Dillon Platform Well and Pipeline Work and Related Waste Disposal, Continued Only Fluids To Only fluids will be injected into Well # 12 and/or Well # 14; UOCC does not Be Injected plan to mobilize Grind and Inject equipment; we plan to containerize solids captured in shakers and separators and ship them off of the Platform for approved disposal. 9/27/2005 10:37 AM 1 of 1 SCANNED NOV () 92005 Phil Ayer Chevron Corporation 909 W. 9th Ave, Anchorage, AK 99515 email: P~9.:.Y.~..~.~~~~.~.?S:..~..~...:...S?_?..~ 907-263-7620 (work) 907-250-2711 (mobile) 907-263-7847 (fax) As per your request: Changing the status of well Di-14 from producer to disposal status on 1/29/03 required no changes to downhole tubulars. This is the back up disposal well and to the best of my knowledge has never been used. -----Original Message----- From : Aye r, Phi 1 M [!n.9.:J..~..~:g...~..P..!n.9.:.Y.~E.~?~~S?.s:.9.:..~...~....çg.!n] Sent: Tuesday, September 27, 2005 9:40 AM To: Greenstein, Larry P Cc: Eller, Gary Subject: Dillon Disposal: Di-14 Temporary Disposal Larry Call if you have any more questions. Does this sound right to you too Bob?? For Dillon 14, I believe we would have to use the 3/5/03 date for official approved conversion from producer to temp disposal. An injectivity test with multiple temp surveys were completed 1/16/03 and the final approved sundry specific to Dillon 14 (303-022) was signed off on 3/5/03. \15/Ololo Confirmed this with the engineer involved with this conversion at the time (see below). The well tubulars, packer, perfs, etc were not modified at all as part of the conversion from producer to injector. The 1/29/03 date is for Admin Approval 8.2 that allowed disposal injection operations in Dillon 12 & 14 wells. Hi Bob, ) FW: Dillon Disposal: Di-14 Temporary Disposal ) ) Unocal Alaska ) Union Oil Company of Cá...Jrnia 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL8 Larry P. Greenstein Production Technician September 23,2005 Tom Maunder Alaska Oil and Gas Conservation Commission 1_'_ 333 W 7th Ave # 100 -c ." O"l~ Anchorage, Alaska 99501-3539 \ 1./ CONVERSION TO TEMPORARY DISPOSAL DILLON PLATFORM WELL NO.14 MIDDLE GROUND SHOAL FIELD Dear Tom: Unocal is reporting the completion of the conversion to temporary disposal of Di-14 (API # 50-733-20281- 00). Enclosed is form 10-404. Well Di-14 (PTD #175-066) was approved for conversion to a disposal well as part of the suspension of the wells on the Dillon platform with sundry # 303-022 on 3/5/03. Additionally, Admin Approval # 8.3, 3/4/03, authorized the conversion of Di-14 to disposal. Although the well was not used at the time for disposal, the conversion took place and the attached 404 is to document this conversion. Please let me know if you require additional information. ~tANNEV NOV 0 ~ 20D5, Sincerely, p ~ 6eenstein Enclosure O:\OOE\OOEFields\MGS\Dillon\Wells\Di-14\Well History\D-14 Conversion to Temp DisposaI3-4-03.doc 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown 0 2. Operator Union Oil of California Name: aka Unocal ) STATE OF ALASKA ) RECEIVED ALASKA OIL AND GAS CONSERVATION COMMI~SION SE REPORT OF SUNDRY WELL OPERATIONS P 2 6 2005 Alaska 0;1 " Gas Con r'í . !. . StimulateU Other ~ c~nvert~ö"ð_14011 WaiverO Time Extension C nc 0"1( Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 175-066 Service D 6. API Number: 50-733-20281-00 9. Well Name and Number: Di-14 10. Field/Pool(s): Middle Ground Shoal/Hemlock Plug Perforations U Perforate New Pool D Perforate D 4. Current Well Class: Development 0 Stratigraphic D P. O. Box 196247 Anchorage, Ak. 99519-6247 7. KB Elevation (ft): 100' KB ABOVE MSL 8. Property Designation: Dillon 11. Present Well Condition Summary: 3. Address: Total Depth measured 10,500' feet true vertical 9,985' feet Effective Depth measured 10,351' feet true vertical 9,835' feet Casing Length Size Structural Conductor 575' 20" Surface 1,496' 13-3/8 " Intermediate Production 9,589' 9-5/8" Liner 1 ,137' 7" Plugs (measured) Junk (measured) MD TVD Burst Collapse 610' 609' 1,511' 1,510' 9,624' 9,140 10,500' 9,985' Perforation depth: Measured depth: 10,270-10,310 10,243-10,248 10,235-10,240 10,215-10,225 10,200-10,205 10,189-10,194 10,177-10,182 10,128-10,133 10,102-10,1079,947-9,9529,922-9,937 9,885-9,895 9,809-9,824 True Vertical depth: 9,760-9,7999,733-9,738 9,725-9,7309,706-9,7169,691-9,6969,680-9,685 9,669-9,6749,621-9,6269,596-9,601 9,447-9,4529,423-9,4389,388-9,3979,315-9,329 Tubing: (size, grade, and measured depth) SS 3-1/2" N-80 @ 67' LS 3-1/2" N-80 @ 9,463' Packers and SSSV (type and measured depth) HES VST Retrievable packer @ 9,172' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS BFl SEP 21 2005 Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure Tubing Pressure 13. Prior to well operation: Subsequent to operation: This well was shut in prior to and subsequent to operations 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory D Development D Daily Report of Well Operations 16. Well Status after proposed work: OilD Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 0 GINJ D WINJ D WDSPL 0 Sundry Number or N/A if C.O. Exempt: be /0 tV Printed Name LA rr! Gree 0S---k:,¿/A.. Signature rø.ÞY;: 1Ia~ . Phone d-~ 3 -7Ø6/ Form 1 0-404 Revi~ 04/2004 0 K , G , N A L Contact Title ~ì~ Date rxyo5 Submit Original Only ,. . ) ) C~T~~E :J !Æ~!Æ~~«!Æ AI/ASIiA OIL AlQ) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI. GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Dave Cole Oil Team Manager UNOCAL P.O. Box 196247 Anchorage, AK 99516-6247 Re: Middle Ground Shoal Unit Platforms Dillon and Baker (J~/f)f)P Dear Mr. Cole: This letteï confirms your conversation with Commission Engineer Tom Maunder last week regarding the multiple Applications for Sundry Approval (Form 403) you submitted in mid October regarding changing the monitoring frequency on the 16 wells on Dillon Platform and 23 wells on Baker Platform. Production and injection operations were halted on these platforms in 4th Q 2002 and 2nd Q 2003 respectively. Attached, please fmd the Sundry Applications, which are being returned without approval., because the relief you request needs to be sought through a different procedure. The intent of submitting sundry notices for each well was to establish a monthly pressure and general monitoring frequency for all wells on Dillon and Baker. There is a requirement in place for some of the water injection wells that pressures and rates are to be monitored daily and reported monthly. Since the platforms are unmanned and not operating, it is not possible to obtain daily information. When operations were curtailed, a monthly monitoring frequency was established in the Plans of Development (POD) annually filed with the Division of Oil and Gas and Unocal desires to assure that this monitoring scheme is accepted by the Commission. As noted in the conversation, changing the monitoring frequency where presently in place and establishing a monthly monitoring frequency in general is not an action that is best accomplished with multiple sundry notices. A letter application requesting the desired monitoring schedule should be made under the applicable Area Injection Orders (AlO 7 for Baker and AIO 8 for Dillon) and Conservation Orders (CO 44 and CO 54) for the platforms/unit. The Commission looks forward to receiving your letter applications. If prior monthly monitoring information has not been submitted to the Commission, that information should be ubmitted forthwith. .f:' SinC~~~ . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this _day of November, 2004 Enel. -'C" N~\Er~'j NO\i 2: 4: '2.004 S P\ ~~ "L~ ;~t~~~~~~~;~WiS~~~~~N¡~~~~ECE'V 20 AAC 25.280 6} ?nM Operational shutdown U Perforate U OCT 1 'NafvM-'LJ ~nn~lar DiSP/, U Plug Perforations D Stimulate 0 Oi,T~t. i. r- (;iJmmlsSlon ~her 0 Perforate New Pool D M~~er SusPßR~~~~U~ D MO~ Frequency 4. Current Well Class: 5. Permit to Drill..7umb . Development D Exploratory D 75-66 Stratigraphic D Service [2] 6. API Numy 50-733P'81-00 9. Well Name and Number: / Di-14 , 10. Field/Pools(s): _/ Middle Ground Shoal/He~ck PRESENT WELL CONDITION SUMMARY/ Effective Depth MD (ft): Effective Depth TV~.TV (ft): 10,351' 9,8~ . MD 1/ TVD / / 6;0< 1,496' 13-3/8" ~511' 1,510' 9,589' 9-5/8" / 9,624' 9,140' 1,137' 7" / 10,500' 9,985' Perforation Depth TVD (ft): ~ing Size: Tubing Grade: 9,680 to 9,799 / LS 3-1/2" SS 3-1/2" Both N-80 ,,,,,aL Packers and SSSV MD (ft): Seal aS7"b1Y 12. Attachments: Description Summary of ?6posal ~ Detailed Operations Program D Boptketch D 14. Estimated Date for Commencing Operations: 10' Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil of California aka Unocal Suspend U Repair well D Pull Tubing D 1. Type of Request: 3. Address: P. O. Box 196247 Anchorage, Ak. 99519-6247 7. KB Elevation (ft): 100' KB ABOVE MSL 8. Property Designation: Dillon 11. Total Depth MD (ft): 10,500' Casing Structural Total Depth TVD (ft): 9,985' Length Size Conductor Surface 575' 20" Intermediate Production Liner Perforation Depth MD (ft): 10,189 to 10,310 Packers and SSSV Type: 16. Verbal Approval: Commission Representative: Phone 17. I hereby certify that the foregoin Printed Nam; 7. ~. Cole signatureMvy/a ~ ~ Plugs (measured): Junk (measured): Burst Collapse 609' 3,450 psi 1,950 psi Tubing MD (ft): LS :9,463' SS: 67' 9,547' 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil [2] GasD WAG D GINJ D D Service [2] D D Abandoned D 0 Plugged WINJ WDSPL s true and correct to the best of my knowledge. Contact Title Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY 28-Sep-2004 Conditions of approval: N~ Commission so thai a representative may witness Plug Integrity D BOP Test D Mechanical Integrity Test Sundry Number: 30 '-1-4 r?ð D Location Clearance n Other: RBDMS BFL NOV 2 2 2004 Subsequent Form Required: Approved by: Form 1 o-~7:,ised 12/2003 APPLICATION RETURNED 11/17/04 NOT APPROVED BY COMMISSION ORIGINAL COMMISSIONER BY ORDER OF THE COMMISSION Date: Submit in Duplicate I"f-"L.." ."\,,;;J.....r, 'N STATE OF ALASKA i"'( t.: (~~ F~ ~. \ / ;1".. ALASKA OIL AND GAS CONSERVATION COMMISSION . ".., .. ~ REPORT OF SUNDRY WELL OPERATIONg:EB 262004 1. Operations Abandon Performed: Alter Casing D Change Approved Program D 2. Operator Union Oil of California Name: aka Unocal Suspend RepairWell D Pull Tubing D Operation Shutdown Plug Perforations D Perforate New Pool D 4. Current Well Class: Development D Stratigraphic D . .+.. ir .:>, Í'. Perforate -- Wãi~ër ;.;, c""'" ::: ~~ iD rother oJ Stimulate D Time ~~íÈffi~~ Shut in and secure Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 75-66 Service 0 6. API Number: 50-733-20281-00 9. Well Name and Number: Di-14 10. Field/Pool(s): Middle Ground Shoal/Hemlock 3. Address: P. O. Box 196247 Anchorage, Ak. 99519-6247 7. KB Elevation (ft): 100' KB ABOVE MSL 8. Property Designation: Dillon 11. Present Well Condition Summary: Total Depth measured 10,500' feet true vertical 9,985' feet Effective Depth measured 10,480' feet true vertical 10,361' feet Casing Length Size Structural Conductor 575' 20" Surface 1,496' 13-3/8" Intermediate Production 9,589' 9-5/8" Liner 1 ,137' 7" Plugs (measured) Junk (measured) fish @ 10,341' MD TVD Burst Collapse 610' 609' 1,511' 1,510' 9,624' 9,140 10,500' 9,985' Perforation depth: Measured depth: 10,270-10,31010,243-10,24810,235-10,240 10,215-10,22510,200-10,20510,189-10,194 10,177-10,18210,128-10,13310,102-10,107 9,947-9,952 9,922-9,937 9,885-9,8959,809-9,824 True Vertical depth: 9,760-9,7999,733-9,738 9,725-9,7309,706-9,7169,691-9,6969,680-9,685 9,669-9,6749,621-9,6269,596-9,601 9,447-9,4529,423-9,4389,388-9,3979,315-9,329 Tubing: (size, grade, and measured depth) SS 3-1/2" N-80 @ 67' LS 3-112" N-80 @ 9,463' Seal Assembly @ 9,547' 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. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: This well was shut in prior to and subsequent to operations 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory D Development D Daily Report of Well Operations 16. Well Status after proposed work: ôTrr:r""" Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 0 GINJ D WINJ D WDSPL 0 Sundry Number or N/A if C.O. Exempt: Contact Printed Name P. M. Ayer Signature fi \1 1 @ 200~. Title Petroleum Engineer Phone 263-7620 Date 18-Feb-2004 Form 10-404 Revised 12/2003 2 7 llJtH. p~~ ~.~~ Spud Dete: SUrfa~ Loc:ctfon: Subaurfaœ løcat1on: EJe'JOtfbn: m: PBO: CasIng: Perforctfo.'t': InltJct PotentloJ: rnJt1al Stimulation: ~tr ~~L Cðred rnt8l\o'øl8: osr rntervar. and Ruulb: L04 Inve~ry: SOUTH MtDDLE GROUND SHOAL ADl 1 8746 \\-'Ell NO. 14 HEMLOCK CONGlOtJERATE PLATFORM D(LlON 11/28115 let 4, Slot 3, SUGS Platform D1Uon 631" FS4 1170"' fWL. See. 35. TaN. R13W. SJJ. ~ - , 8~ No. 88" AlL. See. 2. T7N, R13W. S.U. 100'J<8-LISl 1 0500" 1\'0; 998... 104CO' 1VD: 1945' 20", a,# 90f 11-40 ec.rng ..1 at 610' with 1250 ft. cmt 13 ~", 681 K-55 Cafng Nt crt 1511" with 750 8k. cmt Q SJa", 40. 43.5f £-15 eaam, ..t at '~24' w1th 950 ø. cmt ""1 261 Un.,. Ht at GJ63-10500. arfth 150 ... ~nt C-1: 9809-9824' 10235-10240" G-2: 9885-9895' 10243-10248' 9'22-'937 G-4: 1021~10310' 9947-9852' G-J8: tDt02-tQtG1" 10128-10133' t0177-101SZ' ~O"59-'Q'9o\" , 0200- , 0205' 10215- 1 0225' 200! SOPD, $56 SWPD. 482 UCFD Non. Nont Nom DtL.-SP, F'OC-cR. roc-CR. 4 Arm OtpmeteF 2120176 ~ r V21flG. 1/291781 12/-4/80 ~~~~~on R.c.~. Lmc¡ String: ,. 10" Camtron DuaJ X8 Hcrn~ 2. 3 1/2" No-80 Suttru8 Wbtng J. 3 1;r IMtreø tubfng pup 4. Jet Pump Adaptor 5. Kobe J" type 'T' ~ ""0-209,5 6. 3 112" a:œ cmd J 1/2" ButtN.. Y.O 1. 3 1/2"' Bdtreu tuNng pup a. Seat Locctor .$.;. s.at. .~Iy 10. MI.II~hoe -n . SflÞtt String: It.. ;) 112" "-80 ButtNu tub1ng (As run al25J8~) Junk: 5' x' 2-1/8" Gun 3' BTank 51 x 2.1/8" Gun a- Wire Centralizer o.pth 35. 1if463' 9'"8' 90469' 90489' 904S0' 9526' 9527"., .n_. . . 9:¡4~/ 9548' &7' .1~ V~- Junk Gl1d f1ah . 1Q~"1' PSTD '0480' TD 10500' .J l 20" 85 It 905' CSA 810" 2 , J 318" as, CS4 15t l' 7'. 261 Un.,- Top at 9;HJ' 9 5;8" .ø & 4~.5f CSA 9824' 9809-982". 98S~' -I . 9952' 10102. DILLON PLATFORM API # 50-733-20277-00 SMGS. ST. # 14 WELL HISTORY Well DI-14 DATE COMPLETED EVENT 1968 10/1 Well drill 1977 3/31 Clean out and perf 1979 9/21 Replace BHA 1981 11/10 Clean out, perf, change BHA 1985 8/9 Replace BHA 1996 12/20 Perform scale inhibitor squeeze 2000 2/24 2003 Production enhancement work 03/05/2003 Converted to temporary disposal 04/06/2003 This well was shut in and isolated at the surface with multiple flanges to isolate the well from surface flow lines. Di-14hst3-28-03.doc, last revised 2/18/2004 page 1 01. S -:= ¡abtû 11s-bblS - 01- 3 12 bbIs 25 bbls 20 x 13 5/8 0.1815 300 54.45 3 1/2 tbg.. 0.0087 300 185/8 x 13 3/8 0.1291 300 38.73 2 7/8 tbg. 0.00579 300 13 3/8 x 9 5/8 . 0.0671 300 20.13 9518 x clu8' 31/2 0.0507 300 15.21 9 5/8 x dU8' 2 7/8 0.0571 300 17.13 9 5/8 x 3 1/2 0.0628 300 18.78 Don Sta dual LEGROOM.' 18518 x 13318 133/88 x 9 5/8" 9518" x 3 I/Z' 22 bbls ~ 4 bbIs 115.5bbIs 130 bbIs ~ ABN.I 0 01.13 LEG ROOM 112 01-18 1.2bb1 22bbIs 20bbIs 01-17 0.75 bbls 15.5bbIs 20 bbls 01-16 15 bbIs 20bbIs 01.11 5 bbIs 7;4bbls 01.8 2 bbIs 25 btû DI-7 ABN-6 ~ LEG ROOM '4 I.~ 8H 334 I pump limit ~ psi wen .2 wellM wen n Wen #I 10 Wen #113 Wen .7 wen .8 wen .11 wen 816 Well 17 Wen #I 18 wen n Wen .5 Wen812 WeI. #114 wen 815 WELL BAY # 1 Pumped down Ibg.lbg on vac. bled down 9 5/8 x Ibg. 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 Ibg 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 I.s. Ibg. Returned up short side 100 bbIs. Put 15 bbls In 13 5/8x9 5/8. 4 bbls in 20" ann. Hook up to 20" took approx 1 bbl with charge press on ann. 13 3.81< 9 5/8 RumP and bleed 3 bþls i~ a~. 9 5/8xtbg fluid packed with oil. 14.4 bblsin tbg. well 10 Is abondoned Fill 20" ann 2 bbls, Ibg on vac 7bbls In 13 3/8 x 9 5/8 28 bbls 9 5/8 x Ibg. 51.5. 5 s.s.bbls down short side did Ibg. 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 sulface. Pumped Sbbls in tbg.' 20 bbls in 9 5/8 ann.Annulus and Ibg. Have oil returns 0 press on weD. 20" fluid packed.13 3/8 x 9 5/8 2 bbls and started getting diesel fluid back to sulface. Pumped Sbbls in tbg.' 20 bbls in 9 5/8 ann.Annulus and tbg. Press up to 500 psi. on both tbg. Strings had 011 to top no press on tbg. Pumped and bled 7bbls In tbg. Annulus. When annulus was fluid packed. Oil at surface.5 bbls in 13518 x 9 5/8 press limit. .5 bbl. In 20" Well had SOps!. On 13 3/8x 9518 bleed down to 20psI put bbls of 9.8 fluid. 95/8onn. 20 bbls fluid. tbg.5bbls each. wells 185/8 has 110 psi. bled off and fluid packed with press limit of SO psl..75 of a bbl. Well had 100psl. On 13 3/8x 9 5/8 bleed down to 20psi put 15bb1s of 9.8 fluid, 95/8onn. 20 bbls fluid, Ibg.5bbls each. wells 185/8 has 60 psi. bled off and fluid packed ann with .75 bbls. Well had lSOpsl. On 13 3/8x 9 5/8 bleed down to 20psi put 20bbls of 9.8 fluid. 95/8onn. 20 bbls fluid, Ibg.5bb1s each, wells 185/8 has25 psi bled off and fluid packed with 9.8 saUtook 1.2 bbls. WELL BAY # 4 Rig up pump 4 bbls 1.5. 4 bbl 5.5. 9 5/8 x tbg. 25 bbls, 13318 x 9518 fluid packed wI 12 bbls, 20" aM. 2 bbIs. Ruid packed Pumped 4 bbls 1.5. Ibg. 4 bblss.s.R/u to 9 5/8 x 3 1/2 aM. Pumped 15 bbls fluid packed oil to sulface. Pumped 4bbls down Ibg Is. 4 bbls s.S. both went on vac. Pumped 15 bbIs 95/8 x31/2. WIfhSO psi press limit 0 bbls In 13 3/8x 95/8 Fluid packed 20x 133/82 bbls, Auld packed 13 3/8x9 5/812 bbls press up to 200 psi and held. Rig up pump 5 bbls 1.5. 25 bbl S.s. Be 9 5/8 x Ibg. 8 bbls fluid packed 011 to surface 13 5/8x9 5/8, RJU to 20" ann fluid pack 5 bbls. Press limit 20 psi. Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7805 UNOCAL ) '" Alaska January 22, 2003 State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Attn: Tom Maunder Dillon Application for Temporary Disposal Well DJ-12, Di-14 Dear Mr. Maunder: In anticipation of the successful conclusion of the request to dispose at Dillon, please find enclosed forms 10-403 for two candidate wells requesting permission for temporary disposal. As mentioned in the "Dillon Platform - Proposal for Fluid Disposal" letter, submitted to the AOGCC on December 23, 2002, we are anticipating disposal of up to 50,000 barrels of fluid. If you have any questions regarding this, please contact myself at 263-7620. Philip M. Ayer Advising Petroleum Engineer Enclosures RECEIVED SCANNED' ~l/~R Aogcg SMOS Dillon - Application for temporaW disposal.doe ..JAN 2 2 2.005 Alaska 0ii & Gas Cons. Commission Anchora~le STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Typo 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: Other: Temp Disposal 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union OII Company of California (Unocal) Development: 100' KB ABOVE MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: ADL 18746 PO BOX 196247 ANC, AK. 99519 Service: X South Middle Ground Shoal 4. Location of well at surface Dillon Platform Leg 4 Slot 3 8. Well num,,,ber 678' FSL, 1,765' FWL, Sec. 35-T8N-R13W-SM 14 At top of productive interval 9,809' MD / 9,315' TVD 9. Permit nu~m/ber 1,550' FNL, 726' FWL, Sec. 2-T7N-R13W-SM 75-66 ~ At effective depth 10,351' MD / 9,835' TVD 10. APl number 1,670' FNL, 675' FWL, Sec. 2-T7N-R13W-SM 50-733-20281-00 At total depth 11. Field/Pool 1,698' FNL, 655' FWL, Sec. 2-T7N-R13W-SM Middle Ground Shoal / Hemlock 12. Present well condition summary Total depth: measured 10,500' feet Plugs (measured) None true vertical 9,985' feet Effective depth: measured 10,351' feet Junk (measured) None true vertical 9,835' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 575' 20" 1,250 sx 610' 609' Surface 1,496' 13-3/8" 750 sx 1,511' 1,510' Intermediate Production 9,589' 9-5/8" 950 sx 9,624' 9,140' Liner 1,137' 7" 750 sx 10,500' 9,985' Perforation depth: measured see attached sheet true vertical Tubing (size, grade, and measured depth) SS 3 1/2" N-80 @ 67' LS 3 1/2" N-80 @ 9,463' Packers and SSSV (typo and measured depth) HES VST Retrievable packer @ 9,172' 13. Attachements Description summary of proposal: Detailed operations program: ~ BOP sketch: ~ Well bore schematic Temperature survey 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil:~ Gas: Suspended: Name of approver Date approved Service: X 17. I hereby certify that the foreg~)ing/.[s true and correct to the bast of my knowledge. Signed: ' Title: Advising Petroleum Engineer Date: 1/21/2003 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No.,~.~ Plug integrity.__ BOP Test Location clearanceI ~, 2--'~ Mechanical Integrity Test Subsequent forrp-r~quired 10- t..~.('~ ~3 !'~ !-, ,~ . . Alaska 0il & Gas Cons. Commission Approved by order of the Commissioner /~"~ / ~~~ ~"~ Comm,ss'~l]or~,o Dat~- Note To File Re: Sundry Approval # 303-022 South Middle Ground Shoal Unit #14 (Dillon14) PTD: 175-066 APl #: 50-733-20281-00 Under separate cover, an administrative approval (AIO #8, AA 8.2) has been issued giving regulatory approval to dispose of liquid wastes developed while cleaning the production equipment on Platform Dillon. This note concerns the specific approval to employ Dillon Well 14 (Di-14) as a disposal well. Dillon Well 12 was previously approved for disposal service (Sundry # 303-021) on January 29, 2003. Since disposal into Di-12 was approved, the well has performed as expected. Unocal has reported that at constant pressure (-1400 psi), the pumping rate has declined. The surface pressures in both the tubing and annulus have been tracking with no abrupt pressure change that would indicate any change in the Jreceiving zone. Unocal has stated that Di-14 would be as an alternate candidate for disposal service should problems be encountered with Di-12. With the declining injection rate, Unocal is concerned that if the recent rain events were to continue, their available fluid storage could be exceeded. As of the morning of February 14, operations on Dillon were not "in a bind" and it is likely that Di-12 will be the only well employed for disposal. However, if the weather were to change it is possible that fluid would be disposed into both wells. In the past few months, Unocal has been conducting pressure and temperature investigations on several of the Dillon wells in order to confirm mechanical integrity (MI). Over some 36 hours, nearly 2300 barrels (bbls) of heated sea water was pumped into this well at rates between 2.1 and 1 barrel per minute (bpm) with a surface pressure of about 1500 psi. The inner annulus (IA), was filled with sea water prior to initiating the injectivity test and remained full during the pumping. The IA surface pressure was equal to the tubing pressure while pumping. At constant surface pressure, the rate slowly decreased during the injection period. After performing the injectivity test, Unocal ran 2 temperature logs to determine if any thermal anomalies developed due to the placement of the injected fluid. The temperature log runs do not indicate any thermal anomalies above the perforation depth. The log passes do show cooling and subsequent warming evident in the perforated interval. Given the injectivity test performance and the temperature logs, Unocal has reasonably demonstrated that DJ-14 has mechanical integrity. Approval of sundry 303-022 is recommended. In order to confirm disposal operations are occurring as planned, once operations are underway, Unocal should contact the AOGCC Inspector so that arrangements may be made to observe the disposal operations. February 14, 2003 Di-14 Baseline Temperature Survey IOO0 2000 3000 4000 ~5000 ~6000 7000 8000 9O0O 10000 Di-14 Bottom Gauge Temperature 60 80 100 120 140 160 180 ~--~ ~~~l > POH 12/17/2002 Basel,ne ......... ~--~'~~ ~ ~RIH 01/15,2003 I + 00=30 gin in ~4 Hours ~ 72° water 2 Open perorations 9,809 to 10,310' 11000 Jeff Dolan \~,k-anchorage\groups\OOE\OOEFields\MGS\Dillon\Wells\Di-14\Surveys\Temperature\Di*14 QT Composite QT 20030117.xls Temperature chad DJ-14 Pressure Survey 1000 2000 3OOO 4000 5000 6000 PSI 0 500 1000 1500 2000 2500 3000 3500 4000 700O 8000 9OOO 10000 11000 Jeff Dolan V`Ak~anch~rage~gr~ups\~E\~EF~e~ds\MGS\D~n\~e~is\Di~14\Surveys\TemperaturetDi~14 QT Composite QT 20030117.xls 1/21/2003 7:44 AM Pressure chart DILLON PLATFORM APl # 50-733-20084-00 MGS. ST. 17595 # 14 WELL HISTORY LAST WORK: 7/9~99 Well D1-14 DATE COMPLETED EVENT 1968 4/8 Completed as an Oil Well. 1982 ~9 Completed as a Gas Well. 1996 12/6 WL -. Equalized and pulled standing valve @ 9,497'. Ran in hole with redressed standing valve and shake off @ 4,000'. POOH RD. 12/30 Ran in hole and pulled 2.50" Kobe Pump @ 9.497'. Equalized and pulled standing valve @ 9,497'. Ran in hole and pulled pump dummy @ 9,497'. Ran in hole with redressed standing valve and shake off @ 8,600'. POOH RD. 12/31 SOC - scale inhibitor squeeze to treat for BaSO4 scale that was building up in the pump and standing valve. The job started on 12/27/96 and ended on 12/31/96. Pumped 20 bbl. pill to establish flow and check equipment, not exceeding 3000 psi or 5 bbls per minute. Pumped blend of 715 gals. of scale inhibitor in 113 bbls. of filtered produced water (using 3 micron filters), well was on vacuum. Pumped 772 bbls filtered produced water, well remained on vacuum. Rigged down and begin 24 hr. shut in. Pulled blanking tool with wire line and ran in new standing valve. Began producing well at "slow" rate (20bbls per hr.) taking samples at the prescribed intervals. Well was monitored as per program for inhibitor residuals and returned to full production. 1997 1998 1999 SIS - Scale Inhibitor Squeeze using a mutual solvent pre-flush to water-wet the formation. A scale inhibitor pill designed to last for one year follows the pre-flush. The pill is pushed back into the formation using a double displacement over-flush of produced water. Pump Preflush. Pump Scale Inhibitor Pill. Pumping 1st SC~4NNED !~,~ ~ 7 2003 Overflush. Shut-in well for 12 hour soak. Pump 2nd Displacement. 4 hour soak. SCANNED MAR ~t ? ~.003 Shut-in well for SOUTH MIDDLE GROUND SHOAL ADL 18746 ~¥ELL NO. 1 4 HEMLOCK CONOLOI~ERAT[ PLATFORM DILLON P~: Codng: ~04~0' ~: ~4~* 13 ~". ~ K--55 C~g ~ et 1511' ~ 7~ ex. ~t ~'. Z6F ~ Nt ~ g~10~' ~ 750 ~. ~t ~1: g~g--g~4' 10~10240' gg47--g~2' 101~--101~' ~01 ~g-~ 0194' 1~10205' 10215-1~23' 2001 BOPD. 556 W/PD. 4a2 UCFD D&-$P, FDC--O~, lq)C-GE, 4 ~ PZpmeter 2~20/76 CaR t2/2~/76, 7/20/78. 12/4/80 lunk: L~mg St~n~ D~th L 1~ Co~ Duet ~B ~ng~ 3, 3 1~ ~ ~ng pup ~ ~ t~ ~ ~d 5 I~' B~ee ~0 9490' 7. · 1~ ~o ~g ~p 9526' 8, ~ol L~t~ 9527' Sh~ S~ng: ~ ~ 1~" ~--BO ~s ~ng 6~ run 5' x 2ol/8" GLm --~,j 8" ¥tre Cefltraltmr ~ CANNED d ? 2003 .] Junk ar~d PBTD 10460' 10 1050~ 20" gs~ cS~ 81o' CSK 1,511' 7- 2e~ Top ~t. 4:~.Stt CSA 0824' 0809-9824' 9952* 10102' 10248' 10270-10~10' Subject: ~W: Dillon water injectivity tests Date: Thu, 30 Jan 2003 10:35:08 -0800 From: "Greenstein, Larry P" <greensteinlp~unocal.com> To: "McMains, Stephen E -AOGCC" <Steve_McMains~admin. state.ak.us> Here you go Steve. ..... Original Message- .... From: Dolan, 3eft 3 Sent: Wednesday, 3anuary 29, 2003 4:41 PM To: Dormady, 3anet N Cc: Ayer, Phil M -Alaska; Carlos, Phil C.; Greenstein, Larry P Subject: Dillon water injectivity tests Janet, I wanted to get the ball rolling on any updates to Pdsm we might need to properly report to AOGCC our testing and disposal activities at Dillon. The pdme candidate, Di-12 (Permit # 1680750, APl # 50-733-20126-00) was an injector. 1,394 bbls of water were used in January for an injectivity test. I assume a well status change order would not be needed since Di-12 is already in Prism as a water injector. 1~.._I~=t=7~O, APl # 50-733-20281-00) is the backup candidate. 2,650 bbls of water were used in an injectivity tests in January. This is classified as an oil well. I touched bases with Steve McMains at the AOGCC. He was going to verify with the Petroleum engineer but he didn't think we needed to report the test volume at all since it was a "test". If we don't use the well for disposal then there should not be any further action. If we do end up using Di-14 we will need to send you a change order and report itto the AOGCC. Regards; JeffDolan Water Flood Technician Oil Asset Group Alaska Business Unit Unocal 76 Voice 907.263.7807 Fax 907.263.7884 Email dolanjj~unocaLcom SCANNED FEB 0 4 2003 1 of 1 1/30/2003 11:40 AM STATE OF ALASKA AL ..... A OIL AND GAS cONSERVATION coMMk. )N APPLICATION FOR SUNDRY APPROVALS' 1. Type of Request: Abandon __ Alter casing __ Change approved program ~ Pull tubing ._, Variance 2. Name of Operator ] 5. Type of Well: _ Union Oil Company of California ('UN~r~ent..~ . . ] Exploratory __ 3. Address ........... 9 ..i 519 6 ~t.~3t~raphic P. O. BOX 19624'/, Ancn. , A/%, 1 - Service Suspend __ Operation shutdown .,_. Re-enter suspended well __ Repair well __ Plugging __ Time extension __ Stimulate m Perforate m Other .,)(. 6. Datum elevation (DF or KB) 7. Unit or PrG~y na~ "'~ feet 4. Location of well at surface Leg #4, Slot 3, Platform Dillon 678' FSL, 1765' FWL, Sec. 35, T8N, R13W, SM At top of productive interval 1549' FNL, 727' FWL, Sec. 2, TTN, R13W, SM At effective depth 1685' FNL, 665' FWL, Sec. 2, TTN, R13W, SM At total depth 1688' FNL, 661' FWL, Sec. 2, TTN, R13W, SM 8. Well number 14 9. Permit number 75-66 10. APl number 50--'1_.33-20281 11. Field/Pool SMGS/Hemlock 12. Present well condition summary Total depth: measured true vertical 10500' feet 9986 ' feet Plugs (measured) Effective depth: measured true vertical Casing Length Structural Conductor 572 ' Surface 1477 ' Intermediate Production 9 5 9 4 ' 1137' Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 10460' feet 9949 ' feet Junk (measured) See attached schemat Size Cemented Measured depth True vertical depth 20" 1250 SX 13-3/8" 750 SX 610' 610' 1511' 1511' 9-5/8" 950 SX 7" ~0 SX See attached schematic 3-1./2", 9.2#, N-80 3-1/2", 9.2#, N-80 Baker Model F-1 @ 9624' 9140' 9363'-10,500' 8897'-9985' RECEIVED @ 9,548' 9,5 3 6 ' AJaska OJJ & GSS Cons. C0mmissi Anch0ra e 13. Attachments Description summary of proposal __ Detailed operations program .,~ BOP sketch __ 14. Estimated date for commencing operation 115. Status of well classification, as: 0~tober 9, 1991 16. If proposal was verbally approved Oil__ Gas__ Suspended.,._,, Name of approver Date approved · ServiCe i'"~'7. I hereby certify ~,h,at the foregoing is trUe and correct to the best of my knowledge. g ~'~v ..~i.. R~RH ' REGIONAL Si ned ( ~' ~ % ~ '"'"~'~'"' Title DRILLING MANOR I,)k....) FOR'COMMISSION USE ONLY Conditions of approv~ NotifY Commission so representative may witness' I Approval Plug integrity __ BOP Test m Location clearance __ ~ ' 4 I Mechanical IntegrityTest__ Subsequent form required 10- ~-o :..,;::~!-~ ~,, · :: i ~ ~ :::.~:' ,' ;..: :2:3 Approved by order of the Commissioner ORIGINAL SIGNED B'~' LONNIE C, SMITH Commissioner Date Lc Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE RECEIVED Alaska OJ] .& 6as 6o~s. 6olr~missio~ /~nchorage Pertinent Data,' Spud Date: Surfo=e LocaUon: Subsurface Location; E]evatJon: TO: PBD: Casing: PeHoratlons: lnltJal Potential: InPJol Stimulation: ~eservolr Data: ~ored Intervals: DST Intervals and Resultm Log Inventory:. SOUTH MIDDLE GROUND SHOAL ADL 18746 WELL NO. 14 HEMLOCK CONGLOMERATE PLATFORM DILLON 11/28/75 Leg 4, Slot 3, SIdGS Platform Dillon 681' F~Le 1,"70' ~ See. :)5, TaN. R1;3W, S.U. TO - 1668' FNL. 681' FWL, 100' KB-USL 10500' TVD: g984' 10460' I~/D: gg4$' 20". 85, 91~ H-40 Caging Get at 610' with 12:50. ex. cmt 13 3/B", 8811 K-55 Caging ~et at 1511' with 750 ox. cmt O EVB", 40, 43.5tli E-95 Casing set at 9624' with 950 ox, cmt 7", 26~ Liner oat at 9363-10500* with 750 sx. cement 0-.1: 9809-9824' G-2: 088~-0805' 9922-g937* 9047-9952' G-SB: 10102-10107' 10128-1013;3' 10177-10182' 10189-10194' 10200-10205' 10215-10225' 2001BOPD, $561~D. 482 UCFD None Norle 10235-10240' 10243-10248' 10270-10310' o c~ I None DIL-SP, FDC-QRo FDC-OR, 4 Arm Dlpmeter 2/20/76 OR 12/21/76, 7/29/78. 12/4/80 __~_CompleUon Record. Long String: Depth 1. I0" Cameron Dual DCB Hanger 35' 2. 5 1/2" N-80 Buttress tubing 946;3' ;3. ;3 I/2" Buttreu tubing pup 9468' 4. Jet Pump Adaptor g46g* 5. Kobe ;3" type "E'* CavlLy a/n-20g5 g48g* 6. 3 1/2" 8RD and 3 1/2" Buttress XO 9490' 7. :3 1/2" Buttress tubing pup g:526* 8. Seal Locotor 0527' g. Seal A~sembly 0547' 10. Mule~hoe 9548' Short SLing: A. ;3 1/2" N-BO Buttress tubing 67' run B/25/B5) · ~: ~ 3' Blank r'" '1. $' x 2-1/8' Gun .... · , ii 5' x' 2-1/8" Gun ~ ~~ r $* x 1-11/16' Guide 6" x 1-11/16' Sub Z' x-l-Il/16' Sub [4' x 1-7/16" Sub ~f'~ 1-I1/16" Sub 8' Yfre Centralizer Junk and Hah · 10341' Pl~ 10460' TO 10500' 20" 85 &- 05~ cs~ 610' , 13 3/8" .~' ~ 151 7" 26f Uner Top at g;363' u S/8" ,JO& 4;3.~cskge24' 98og-0824* 9885* 9052* 10102' 10248' 10270-10310' South Middle Ground Shoal ADL 18746 Well No. 14 Procedure for suspending and freeze protecting well: 1) Reverse the hydraulic pump out of the hole. Long string will be protected against freezing by power oil at this point. 2) Circulate power oil into 9 5/8" casing X tubing annulus taking returns up short string. Short string and tubing X 9 5/8" annulus will be freeze protected at this point. 3) Close all valves on the well head. 4) Install gauges on the tubing and 9 5/8" casing X tubing annulus. RECEIVED W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 August 29, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: TJZ-309-WF Dear Sir' Subsequent Notice SMGS Unit Well No. 14 Platform Dillon, Cook Inlet, Alaska Attached in duplicate for your approval is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, informing you of work recently completed on the subject .well. Very truly yours, W. G. Smith District Manager Attachments JCB/dds RECEIVED S''''~,: ~ 0 6 1995 0il & Gas Cons, Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION S iI RY lOTl $ AND REPORTS ON WE LS 1. DRILLING WELL [] COMPLETED WELL,I~ 2. Name of Operator 7. Permit No. Amoco Production Company 75-66 3. Address 8. APl Number P. 0. Box 100779, Anchorage, Alaska 99510 50- 733-20281 OTHER [] 4. Location of Well Leg 4, Slot 3, NGS Platform Dillon 678' FSL, 1,765' FWL, Sec. 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 100' KB I 6 . Lease Designation and Serial No. ADL. 18746 12. 9. Unit or Lease Name SMGS Unit 10. Well Number 14 11. Field and Pool South Middle Ground Shoal Heml oc k 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). Between August 23, 1985 and August 26, 1985, Amoco Production Company: 1. Installed BOP's and pressure tested. 2. Pulled tubing and bottomhole assembly. 3. Ran tubing and new bottomhole assembly. 4. Nippled up tree and pressure tested. 5. Returned well to production. RECEIVED Gas Cons. C0r~m. Jssior~ Anchora~je 14. I hereby certify that the~f~regoing~i~ truce and corre~ct The space below fOr Commission use to the best of my knowledge. District Manager Title Da~8/29/85 Conditions of Approval, if any: Approved by, COMMISSIONER BY Order of the Commission Date Form 10-403 Submmt "Intentions" in Triplicate W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 August 9, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: TJZ-289-WF Dear Sir: Notice of Intent SMGS Unit Well No. 14 Platform Dillon, Cook Inlet, Alaska Attached in triplicate for your approval is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, outlining our intentions to repair SMGS Well No. 14. Please direct any questions concerning this matter to Jeff Blagg at 263'2211. Very truly yours, W. G. Smith Di strict Manager Attachments JCB/dds RECEIVED AUG 2 o AlasKa 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOTIIC!ES AND RI PORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ 2. Name of Operator 7. Permit No. Amoco Production Company 75-66 3. Address 8. APl Number P. 0. Box 100779, Anchorage, Alaska 99510 50- 733-20281 9. Unit or Lease Name SMGS Unit OTHER [] 4. Location of Well Leg 4, Slot 3, SMGS Platform Dillon 678' FSL, 1,765' FWL, Sec. 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DJ:, etc.) 100' KB 12. 6. Lease Designation and serial No. ADL 18746 10. Well Number 14 11. Field and Pool South Middle Ground Shoal Heml oc k · 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). In August, 1985, Amoco Production Company proposes to:1. Install BOP's and pressure test. 2. Pull tubing and bottomhole pump assembly. 3. Run tubing and new bottomhole pump assembly. 4. Nipple up tree and pressure test. 5. Return well to production. RECEIVED AUG 2 0 1,985 Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the f?~p~ing~/~ue and correct to the best of my knowledge. Signed ..... Title District Manager The space below for Commission use Date08/09/85 Conditions of Approval, if any: 9RIG!ItAL StIIEI' 8Y LOH~IE C. SMITII Approved by Approved Returnm;I By Order of COMMISSIO~B the Commission Date Form 10-403 Submit "Intentions" in Triplicate L. A. Darsow District Superintendent April 21, 1982 Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 File' LAD-384-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subsequent Report SMGS Unit Well No. 14 Platform Dillon, Cook Inlet, Alaska Attached in duplicate is State o'f Alaska Form 10-403, Sundry Notices and Reports on Wells, subsequent to the repair work done on SMGS Unit Well No. 14. Yours very truly, L. A. Darsow Di stri ct Superintendent Attachment LMP/klt RECEIVED APR 61982 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of OperatOr 7. Permit No. Amoco Production Company 75-66 3. Address 8. APl Number P. 0. Box 779, Anchorage, Alaska 99510 50- 133-20281 4. Location of Well Le~ 4, Slot 4, SMGS Platform Dillon 678' FSL, 1765' FWL, Section 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) +100' RKB MSL 6. Lease Designation and Serial No. ADL 18746 9. Unit or Lease Name SMGS Unit 10. Well Number 14 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 ~ (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). Work Performed' · 2. 3. 4. Pulled tubing, bottomhole assembly, and milled out packer. Cleaned out to 10,341'. Set packer at 9536' and reran tubing and bottomhole assembly. Perforate 9885-9895' 9922-9952' 10,080-10 140' 10 165-10 250' 10,270-10,310'. 5. Return well to production. RECEIVED APR 5 982 0i~ & Gas Cons. C0mmissi0~ Anchorage 14. I hereby cer~fy that tl~4.qrqgoing is true and correct to the best of my knowledge. Signed ~, .... '/! ~4''~'''"~Title District Superintendent The space below for Commission use Date 4/21/82 Conditions of Approval, if any: By Order of Approved by. 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 February 1, 1982 Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 File' LAD-121-WF Mr. Lonnie C. Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir' Notice of Intent to Perform Work SMGS Unit Well No. 14 Platform Dillon, Cook Inlet, Alaska Attached in triplicate for your approval is State of Alaska Form 10-403, Sundry Notices and Reports of Wells, to perform work on the subject well. We plan to pull tubing, perforate, and change the bottomhole assembly. We plan to start this work in February 1982. Yours very truly, L. A. Da rs ow Di stri ct Superintendent Attachment LMP/klt RECEIVED FEB 0 2 ]982 Alaska 0il & Gas Cons. Commission Anchorage · / STATE OF ALASKA --~' ALASKA ~J,L AND GAS CONSERVATION CO,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~ OTHER [] 2. Name of Operator 7. Permit No. Amoco Production Company 75-66 3. Address 8. APl Number P. O. Box 779, Anchorage, Alaska 99510 50-133-20281 4. Location of Well Leg 4, Slot 3, SMGS Platform Dillon 678' FSL, 1765' FWL, Section 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) +100' RKB MSL I 6. Lease D~.at~o~6Serial No. 12. 9. Unit or Lease Name SMGS Unit 10. Well Number 14 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 [Xl Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing ![X-I 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' 1. Pull tubing, mill out packer, and clean out to 10,460' MD. 2. Perforate the following intervals' 9,885-9,895' 9,922-9,952' 10,080-10,140' 10,165-10,250' 10,270-10,310' . Set packer and run new bottomhole assembly and tubing. Return well to production. RECEIYED ae ,o t a FEB 0 2 ]982 Alaska 0il & Gas Cons. C0mmissim Anchorage 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 2/1 / 82 Conditions of Approval, if any: Approved by. O~IG'HAL StGN£O LOlt, lE SI ITIt Approved ';op¥ Returned By' OFdeF of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow Area Superintendent June 6, 1977 File: LAD-450-WF Mr. Hoyle Hamilton, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Compam,~'' P.O. Box 779 Anchorage, Alaska 99510 /COhw. R: Dear Sir: Re: Sundry NOtice SMGS Unit Well No. 14 Attached is a State of Alaska Form 10-403 subsequent to perforating SMGS Unit Well No. 14 as described herein. Very truly yours, L. A. Darsow Area Superintendent Attachment RECEIVED JUN - ? 1977 Division of 0il and Gas Consecration Anchorage Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate Ferm 10-403 REV. 1-10~73 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) ~' O,L ~ GAS II WELLI~X~I WELL OTHER 2. NAME OF OPERATOR .~zoco Production Company 3. ADDRESS OF OPERATOR P. O. Box 779.~ Anchorage~ Alaska 99510 4. LOCATION OF WELL Atsurface Leg 4, Slot 3, 678' FSL, 1765' FWL, Sec. 35, TdN, R13W, S. M. Platform Dillon 13. ELEVATIONS (Show whether DF, RT, G_R, etc.) lO0' KB above MSL 14. CheCk Appropriate Box To Indicate Nature of Notice, Rel 5. APl NUMERICAL CODE 50-133-20281 6. LEASE DESIGNATION AND SERIAL NO. ADL-18746 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME SMGS Unit 9. WELL NO. 14 10. FIELD AND POOL, OR WILDCAT South Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 2, T7N, RiSW, S.M. 12. PERMIT NO. 75-66 3orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) , (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. The following intervals were perforated on May 22, 1977 at 4 JSPF. 9809-9824' 9885-9895' 9922-9937' 9947-9952' 10,102-10,107' 10,128-10,133' 10,177-10,182' 10,189-10,194' 10,200-10,205' 10,215-10,225' 10,235-10,240' 10,243-10,248' Production Prior: 246 BOPD, 12 BWPD May 17, 1977 Production After: 542 BOPD, 164 BWPD, 117 MCFD May 31, 1977 RECEIVED JUN - ? 1977 Division of Oil and Gas Conservation Anchorage 16. I hereby certify that the foregoing is true and correct TITLE Area Superintendent · --DATE. .lllnm 6; !977 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.' TITLE DATE See Instructions On Reverse Side G. J. Ross Area Superintendent December 13, 1976 File: GJR-913-WF Mr. Hoyle Hamilton, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 Dear Sir: Re: Sundry NoticeOf Intent SMGS Unit Well No. 14 Attached is State of Alaska Form 10-403 for reperforating SMGS Unit Well No. 14. Your~ very truly, George J. Ross Area Superintendent Attachment 1976 DIVIS~©N OF OIL AND GAS " Fc%-~ :[0-403 Submit "lnte.tluns" In Triplicate RE~V, 1.10-73 ~ & "Subsequent Reports" In Duplicate ~. STATE Ok ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REpoRTS ON WELLS (Do not use thi's form for proposals to clrlll or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. ~PI NUMERICAL CODE 50-133-20281 6. LEASE DESIGNATION AND SERIAL NO. ' ADL-18746 7. IF INDIAN, ALLOTTEE OR TRIBE NAME E] 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Amoco Production Company SMGS Unit m ADDRESS OF OPERATOR 9. WELL NO. P. 0. Box 779, Anchorage, AlaSka 99510 14 4. LOCATION OF WELL Atsurface Leg 4, Slot 3, SMGS Platform Dillon, Section 35, T8N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RDB 100' above MSL 14. Check Appropriate Box To Indicate Nature of N~tice, Re 10. FIELD AND POOL, OR WILDCAT South Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 2, T7N, R13W, S.M. 12. PERMIT NO. )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER sHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE . REPAIR WELL (Other) PULI]. OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLAN5 SUBSEQUENT REPORT OF: WATER SHUT-OFF ~] REPAIRING WELL FRACTURE TREATMENT~ ALTERING CASING 5HOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, an~ give pertinent dates, including estimated date of starting any proposed work. 1. Pullpump and standing valve. 2. Run Gamma Ray log from,PBD to 9700'. 3. Perforate-the fotlowingintervais with 4JSPF: 9809-9824' 9~85-9895' 9922-9937' 9947'9952' 10,102-10,107' 10,128-10,133' 10,177-10,182' 10,189-10,194' 10,200-10,205 ' ~-10,0j~'~0~0' ~o ~35- ~qo 10,, 043-10,04~ ~o Z~H3 - IOZH~ . All depths from Density log dated February 20, 1976. 16. I hereby certify that the foregoing is t. yjje and correct SiGNE~_/./2~z?~../..~C.~.~- /./2.~(._~~_.pzt.~. TITLE Area Superintendent ..... /'-- -, .f./ (/ " DATE December 13, 1976 (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: See InstrUctions On Reverse Side DATE 12-17-7~ ~pproved Returned G. J. Ross Area Superintendent March 17, 1976 Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 File: GJR-221-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. 14 Attached is the State of 'Alaska' Form P-7. furnishing the completed drilling operations for South Middle Ground Shoal Unit Well No. 14. Yours. very truly, orge O. Ross Area Superintendent Attachments ~ , .. . . SUBMIT IN DUPI.IC~ STATE OF ~ALASKA ,'see other in- structions on reverse side) 5. API N~M. FARJCAJh GOD~ OIL AND GAS CONSERVATION COMMITTEE 50-133-2028Z Ill I FII ............... WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYFE OF WELL: OILwELL[ ~ GASwELL ~ ' DRY ~ Other b. TYPE OF COMPLE~ON: WELL 2. ~,.~ or o~.~o~ ~ SMGS Unit . ~oco Production Company . ~. w~ ~o. 3. ~ss o'~ o~o~ ' ~ 14 ~ P. '0.. Box 779,--Anchorage, Alaska 99510 ~. LOCATION OF WELL' (-RePort lqcation clearly, and<~in accordanCe with any ~tate requirem,nts )* xt~,~e Leg 4, Slot 3, 678' FSL, ~765'~ ~, Sec. 35, n.~c..~..a..~..(~o~o~ TSN, R13~, S.~., Platfom Dillon omz~w) It top prod. interval reported below 1569' F~, 727' F~,. Sec. 2, TTN, R13~, S.~. Sec. 2, T7N, R13~, S.~. At total dep~ ~ 1688' F~, 661' ~, Sec. 2, TTN, R13~, S.~. ~.~m~o. 75-66 12-2-75 ] 2-20-76 ~ I' ' 3-6-76 - { + 100' ~ ~SL '~ 59.;' MD'& WD~. ~:~LT~ CO~L., [ 21. iNTERVALS DRILLED BY ' ]. ~OW~Y* ~ aO~aRr ~OOLS · CASLZ ~OOLS ~ 10,500; .T~ 99861~ 10,463', T~ 99~9 ' i 0- TD [ PRODUCING ~V~(S), OF ~S CO~P~TIO~P,' , ~. W~ DI~E~ONAL ~. BO~O~,. N~E (D AND ~)* ~ SURVEY ~ADE ~ 9809-10~263-'; T~ 9314~97~'; Lower Kenai Conglomerate j yes 24. ~E ~cTRIc ~D OTHE L~S:RUN- . !ES, So~ic, :~G~a Ra~ w/ Cali~er, Diameter . ~. "'~ CASCO RE~ (Re~t all ~trings set in wtll) . _ ,, ~ HOLE SIZE ~ C~NTING ~CO~ ~OUNT PULL~ las# / a 40 I 20" I / 6'8# [ Z-551 17-1/2"I 20'' :610 ~] 13-3/8" 1,151,1 ..... 9-5/8" 26. LINER ~CO~ ' SIZE 'i TOP (MD) BOTTOM (MD) [ SACKS CEMEi~T* 28. PE~O~TIONS OP~ TO PRODU~O~ (Inte~al, size and ~umber) 9812-9817 ' 10,102-107 ' 1-11/16" gun 9885-9890' 10,128-133" with 4JSPF 9923-9928' 10, ~77-182' 9947-9952' 10,215-220' 6. LE.&SE D~_qlGN&TION AND SERIAL NO. ~L-~8746 : g. IF I~I~, ~T~ OR TRIBE N~ 10i FIEI~) A~ND POOL, OR WILDCAT SOuth Middle Ground Shoal 1250 sacks 750 sacks 950 sacks I PACI~ER SET (MD) I 27. i~'UB LI~TG SC--'~ (iVID) SIZE D~I~I SET (MD) 3-1/2" 9320' ' 93i1' ACID. S~!O~. ?I~-~TI{ INT~VAL (MD) AMOUNT AND KIND O,F M~TER/AL USED i i 80. PI%0DUCTION DATE FIEsT:P'I%ODUCTION [ PRODUCTION METHOD (Flowh~ gas lift pumping--size and type of pump) ~WELL STA.TIJS (~rgdu~r%g .or . ,, ,, . D ......... i 3-6-76 pump,~.ng 3 .x 2-1/8 hydraul~.c pum~ ~D,~,,~,.,,prpduc ng D~TII: OF TIST, ~I-iOI/RS TE-~TED J [C/-IOXE SIZE [PROD'N' FOR OI~BBL. "~A~CF. WA'~B~. [ GAS-OIL ~TIO [ [ ITEST P~OD I ~ , I __ 3-12-~61 '24 , I 124 ] ~'~ ! 2001 [ 482 i 556 i 241 FBOW, ~BING ~S~G P~S~ ICAL~~ OI~BBL. GA~I~. WA~B~. ]OIL GRAVITY-~I (C~.) I I~ [ 2001J.. 482 I 556 ] 32.6 31. mSPOS~T~0N OF OAS (Mold, used )or tuel, vented, etc.) ' "~:~ TEST WITNESSED BY sales, fuel, flare 32. LIST OF ATTACHMENTS chronological well history, logs .and gyro survey 33. I hereby cerAify/,_ -~--~.that the foregoing and attached information is cOmplete an;{ correct as determined from allVavailable records . , _..,~ Area Superxntendent SICNE '*'r*'~,~ ~ pATE 3-17-76 . *(See Instructions and Spaces I:or Additional Data on Reverse Side) 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- mentsgiven~in other spaces on this form and in any attachments. Items 20, i~nd 22:: If this well is completed for separate produclion from more than one interval zone . ~(multiple completion), so state in item 20, and in item 22 show the prc. Jucing interval, or intervals, 'top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report · (page) on, this form, adequately identifiedi for each add~itional inte~ val to be seperately produced, show- . ing: t.he a:dtditional data pertinent 'to such. interval. ' · Item26: "Sacks Cement": Attached supplemenfal records for this well Should show the details of any mul- .'tiple 'stage cementing and the location of the cementing tool. .. Item 28: Submit a separate completion report on this form for each interval to.be separately Produc~. '(See. instr0ctioh:for items 20. and 22 above). . ., . sUMMA.H.Y OF F'OP~MATION .TESTS INCLUI')IN(; INTEFC~AL, TESTED', pFLESSU'RE DATA AND '~ECOVERIES' OF OII'., GAS, · '' WATER AND MUD .. Hemlock 9809 . , , CORE DATA. A'ITI'ACll 13RIEI~ DESCRIPITIONS OF LITHOLOGY. POtlOS~TY. FRACTURES. APPARENT DIPS AND DE'FEC~I.'EI) $tlOWS Ol~' {.)IL, GAS OH . SMGS Unit Well No. 14 Chronological Well History December 1-5: (1975) December 6-10: December 11-29: December 30- January 31: (1976) February 1-2: February 3-14: Conductor casing previously set at 610'. Rigged up rotary tools and drilled and surveyed to 1515'. Ran 40 joints 13-3/8", 68#, K-55 Buttress casing and 2 joints 13-3/8", 54.5#, K-55 casing. Cemented with 750 sacks Class G + 2% gel + .12 gallons D-80 per sack, 12.8 ppg, followed by 500 sacks Class G + 2% calcium chloride, 15.8 ppg. Had good cement returns with an estimated 80 barrels excess. Work suspended. Drilled and surveyed to 7800'. Hit coal break and pipe stuck at 6433'. Worked pipe loose and hole cleaned up. Reamed bridges of coal 6608-6839'. Tripped out at 8048' and hole was tight at 6730', 6690', 6023' and 4970'. Rotated through tight spot at 4970'. Tripped in and circulated and reamed from 5000' to bottom. Worked pipe during tight connec- tion at 8243'. Made connection at 8305' and pipe was stuck on bottom. Circulated and jarred and recovered fish. Drilled and surveyed tql/10,107'.~.. Tripped out and bit stuck at 9980'. Circulated and worked stuck pipe without sUccess. Ran free-point and free at first joint of Hevi-Wate drillpipe. Ran string shot and backed off at 9738'. Ran back to fish, jarred and circulated and tripped out with drillpipe and 25 joints of Hevi-Wate drillpipe. Ran IES log and tagged fish at 9741'. Total length of fish in hole 242'. Tripped in and reamed 5860-6000' and circulated. Ran 9-5/8" casing and set at 9624' .with 550 sacks Class G + .06 gallons D-81 per sack. Good returns throughout. Drilled out and no cement below shoe. Cleaned out to 9738,' at top of fish and spotted 150 sacks Class G + .04 gallons D-81 per sack + 10% sand. Drilled hard cement from 9580-9650'. Attempted to kick-off cement plug but drilled back into old hole. Circulated hole clean and cemented with 125 sacks Class G + .04 gallons D-81 per sack. Cement did not set. Circulated hole clean and cemented with 125 sacks Class G + .23 gallons D-80 per sack + .04 gallons D-81 per sack + 7 sacks of cement from 9672-9673' I~ ~li~ I} vt .~i;. }~.!;/ -2- February 14-19: February 20-27: February 28 - March 12: Dynadrilled off cement plug at 9673'. Drilled and surveyed to TD of 10,500'. Ran the following logs: IES, Gamma Ray, Density, Sonic, Dipmeter. Ran 7" casing liner from 9363- 10,500' and cemented with 250 sacks Class G + .04 gallons D-81 per sack. Had good returns. Pressure tested liner to 2000 psi and okay. Tripped in with bit and scraper and tagged bottom at 10,460'. Tripped out and ran gyro survey from 10,431-570' with 100' stops. Ran cement bond log. Displaced hole with power oil and set packer at 9311'. Ran in seal assemblies, 3" Type "E" Kobe bottom hole assembly and 3-1/2" N-80 Buttress tubing. Perforated the following intervals with 1-11/16" through-tubing gun at 4JSPF: 9812-17' 10,102-107' 9885-90' 10,128-133' 9923-28' 10,177-182' 9947-52' 10,215-220' Installed 3" x 2-1/8" Kobe hydraulic pump and 24-hour test yielded: 2001 BOPD, 556 BWPD, 482 MCFD on March 12, 1976. - ~ 2: :;s-? ~F~E~RY-SUN WELi]-SuRVEy!NG COMPANY · PAGE .................................... ' ........ ~'~5' ~ ........ ~ ANCHORAGE, ALASKA ................ ~ AaOCO PRODUCTION COF]PANY ~ :~ ~o ?:=::.~ 'DATE OF SURVEY FEBRUARy 23~ 197~ SFiGS NO,~ ~;--~:~ ~ CO~qPUTATION DATE SUR :" ' ~ t'.~!. GikOSCOPIC MULT[SHOT SURVEY SOUTH ~'IIDDLE GROUD SHOU ~ L ,'.~ :':~,~'-'¢ ~:?.::~ 'FEBRUARY 25,' 1976 ....................... dOB N[Ji'i~ER SU~!6050 ........... A L A S K A A L A 81< A ;:~: ~':.E~' , ~ r~') KELLY BUSHZNG ELEV. = ............................................................ TRUE SUB-SEA' LL:;~.L~~OURSE COUHSE FiEASURED VERTICAL VERTICAL INCLINATION' DIRECTI DEPTH .......... DEPTH ......... DEPTH ........ DEG 'MIN ........ DEGREE 570 570,00 ~59,50 1 0 .S 89, 0 ..... 600 ...... 599,99 .... 489;29 ........... I:" 12 .......S'57,'22 700 699.96 589e.26 800 799,'9~ 689,25 ...... ~00 .........899,~91 ........ 789,21 .......... 1---- 0 ....... 1000 999,89 889,~9 0 58 S .28,99 1100 1099,88 . 989,1~ 0 .56 S.88,55 ...... 1200 ......1199,87 ..... 1089,17 1800 1299,85 1189~15 0 56 S 1400 1~99,8~ 1289,14 0 55 S - 1500 ...... 1~99,8~ ...... 1J89. 1600 1599o82 1~89, 1700 1699,81 1589, 1800 " 1799,80 !509, 1900 1899,80 1789, 2000 1999,79 1889. ..... 2100 .......... 2099.79- ~1989, 2200 2199.78 2089, 2SO0 2299.7& 2!89. " 2~00 .... 2599.7~ 2289, 2500 2499.69 2688. 2600 2599.65 2488. .... 2700 .... 2699,62 .... 2588. 2000 2799,58 2688, 2900 2899.5ff 2788, -~' ~000 .... 2999,~9 ..... 2888, ~100 '~099.~3 2988, ~200 5199.56 ~088. --~500-.'- 5299.22 ...... 5188. 3400 3598,84 ~288, 1~ ............ 0 ..... 50 ...... 12 0 51 .S 8~27 ~1 0 ~2 $ 16,52 10 ....... 0 -'~1 ......S 1,~0 10 0 '27 S 15,21 09 0 2~ S 8,38 09 0---34 ..... S--'~7.-:2 08 0 5~ S 71,~6 06 1 8 S 76,62 04 ....... 1--'37--~S 78,54 99 1 ~1 S 8~, ? 95 1 3~ S 92 ..... 1-"29--- S 88,55 88 I 32 S 85,10 8q 1 ~2 S 80.85 79 ....... 1 ..... 52 .... S89,''9 73 2 7 S 88,48 66 2 21 S 55.69 52 ....... 5 -33.- .... S 28.91 14 6 5 S 25,68 3500 DOG-LEG ON SEVERITY RECTANGULAR S ........... DEG/IO0 --'NORTtt/SOUYH E 0 E .............. 2 E 0 E 0 E 0 E' 0 E 0 E: .........0 E 0 E 0 E ..... 0 U 0 W 0 E ..........0 ~ 0 £ 0 W-- 0 W 0 W 0 W ........ 0 W 0 W 0 W 0 W 0 W 0 W 0 W 0 W W ............ W 2,5~ 5~98.05. 3587,35 8 21 S l~,g& W 2,&2 : ,00 0,92 N ,10 ............ 0,74 N ,55 0,86 S ,2~ :2,0~ S ,35 ....... :~,51 S .0~ .6,00 ,16 7.~7 .~3 .... 8.71 ,06 10,!~ S ,2~ lle~? S ,~8 .... 12,79 S ,26 1~,2~ S ,18 15,56 S ,21 ............ 16,7q S .26 17.72 S ,07 18,44 S ,~7 ~19.I2 S ,~5 19,71 S ,25 20.19 S .~8 20,70 S .~7 21.13 s ,16 21,32 S .08 21.59 S .lO 21.5~; S .20 21,09 S .~0 ..........22,15 S .25 22.23 S .79 ...........27.~0 $ ~6.57 S TOTAL iIA L L Vv' COORDINATES VERTICAL "EAST/WEST ............ SECTION ~,93 E -2,.) ........ 5,~5 E ........... -2.98 7,19 E -2.25 8,73 E -1,12 ........... 9,85 E ............ -0,07 ' S 10,71 E 0,91 S .1!,62 E 1.76 S ...."12.5~ E .......... 2.59 .13,32 E 1~.21 E ...... 1~,86 E 5.30- 1~,88 E 6.61 1~},60 E 7.92 ' 1~[,~ E ....... 9.06 14,56 E 9.89 1~.71E lO.~a .... 1~,40 E .......... 11' '13,29 E i2.2 11,59 E 13.~9 ........ 9,2~ E ...... 1'~.8~ 6,40 E 0,91 E ....... 19.00 1.70 W 20.24 ~.50 W 21.74 ........ 7,59 W ....... 23.29 11,07 W 24.82 14,61W 27,~1 ...... 17,80 W 52.26 -' 21.59 W 40.65 25,76 W 53.10 · ArJCHORAGE, ALASKA ' .:.iOCO PRODUCTION COFiPANY :-tG$ NO,i~ COHPUTATiON DATE 'OUTH HIDDLE GROUD SHOUL ................. FEBRUARY 25, 1976 - .LASKA ALASKA · TRUE · £ASURED VERTICAL '%PTH DEPTH 3600 3596.70 3700 369~.72 ~800 ~792.00 5~00 $888,~2 ~O00 - 398~,96 oFC_[:~<.t"~UN r~ELL ,.%URVEYING CO;-~PANY DATE C;--' SURVEY FEBRUARy SUR-',;EL CVROSCOPIC HULTISilOT StJRV£'F 00~ t'!U:};;i£R SU$-'i6050 KELLY GUSHING ELEV, = 110,70 FT, · SUB-SEA COURSE COURSE DOG-LEG TOTAL V£HTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH ..... DES MIN .... DEGREES - 'OEG/100 NORTH/SOUTIt ~06,00 10 2~ S 13,16 W 2,05 62,36 S '~58b,02 ...... 12 23 .... S.~l,ql W ............. 2,02 .... : ....... 81,65 S 3681,30 1~ 20 S 11,7~ W 1,95 10~,28 S 3777,72 16 .20 S 1~,29 W 2,0~ 1~0o06 S : ~,25 W '.3873e26 ............ 18 .... 0 .......... $.1~,81-W ........ 1,67 ........ - 158.77 S ' 51,17'W EAST/WEST - SECTION 29,69 W 69,07' ~3,86 W 68.31 · $8.50 W 110,78 ~100 q200 ~00 ~00 ~500 ~600 q700 qSO0 5000 5100 5200 5300 5~00 5500 5600 5700 5800 5900 6000 '6100 6200 6300 6qO0' 6500 6600 q078.66 ~967.96 19 27 S 1.,79 W I..8 189,87 S' q172.61 ' q06!.91 20 35 S 15,72 W 1.~7 222,89 8 q265.89 ~}155'19 ....... 21" ~0 ' -' S 17.56 W ............. 1.27 ............. 257.ql S ~358.38 ~2~7.68 2~ 0 S 18.q8 W 1.57 293.5~ $ q~9.98 .~359,28 2q 17 S' 19.86 W 1,59 S31.~l S ~5~0.56 q.~29,06 ........ 25' 50 .... ~S'20,9~ W .......... 1,61 ........... 371,10 S ~630.57 q5!9.87 25 50 S 20,80 W 0,05 ~I1,82 S ~720.76 96!0.06 25 20 S 2!.97 W 0,71 ~52,03 $ q8!1,18 ~700.~}8 25 15 ...... S 22,28 W - ' 0,15 ~1,60 S q901,62 ~790.92 25 15 S 23.~0 W 0.~3 550.95 S ~992.70 g082.00 25 50 S 25.70 W 1,75 568.77 S 50~.~7 ~97S.67 ..... 2~ -56 - --S 2~,70 W ........ 0,~1 ...... 605.22 S 5175.95 5065.25 25 ~6 S 25.18 W 0,25 6~1.6~ S 52&7.~5 5156.65 2z; 6 S 2ff.52 W 0.~2 678.~}5 S 5358.51 52ff7.61 ..... 25 0 ......S 25. ~ W ......... 0.92'' 716.!~ S 5q~8.91 5~58.21 25 5 S.26,26 W 0.52 75q.52 S 5559,72 5~29.02 '2~; 25 S 27.67 W 0.09 791.6~ S 59,11 W 197,06 68.12 W 250.79 78,~G'W ..... 90,22 W ~0~,15 103,qO W 3~,0~ 118,17 W .... ~86,25 - 135,69 165,52 182,G~ 198,~9 21~,87 251,81 2q8.85 266.27 28q,59 503,57 ~29.71 515,~7 558.10 599,55 639.~0 ) 679.[~6 720,05 761.58 - 803,90 8~,7~ 5630,96 5520,28 .23 51 5722,q~ 5611,7~ 25 50 581q,15 5703.~5 25 10 5906.06 5795.3G ....... 23 -15 '5998.30 5887,60 22 10 60-90,80 5~80,10 22 50 618~.47 6072,77 -'- 21 39 6276,2~ 6165,5~ 22 12 6~68,96 6258,26 21 g6 . . 27.q3 W 27,18 W 0.10 863,80 S 27.26 W 0.66 899,26 S 27,6~ W .... 0.16 93~$.23 ~ 27,38 W 1,08 968.g7 S 27.37 W 0.~3 1002.22 S 25.93 W 1,UO .... 1035,80 S 27, 7 W 0.69 1069.21 S 28, 8 W 0,57 1102,37 S 0,57 .... 827.89 S ' 322.~8 3q1.02 377.~2 -395.25 4!2,75 886.58 - 926,97 966.82 1006,19 - 10q~.76 1682.72 ;~29,59 W' - 1120.29 ~g6,25 W 1!57.6I g63,58 W 1195,00 . 156,59 165,52 ~PER,'~Y SUN U£LL SURVEYING CO~iPANY .'~CrlU~&Ob ~ AI.A~KA AF-iOCO P;qODUCfION CO[iPANY SDiGS NO,~ SOUTH H~DDLE GROUD SHOUL ALASKA ALASKA ~"iEASURED DEPTH TRUE VERTICAl, DEPTH 6700 6~61,58 6800 6555,70 6900 7000 7100 7200 7500 7~00 7500 7500 7700 7800 7900 8000 8100 8200 8500 8qO0 8500 6GO0 6700 8800 8900 ~000 9100 9200 9500 9~00' 9500 902q.09 9600 ·9117,05 9700 9211.09 · PACE DATE OF SU'~VEY.. FEBRUARY 23, ~976... COEPUTATION DATE SURf;EL GYROSCOPIC NULTISHOT SURVEY " ....... NtJ~-lu¢R SU$=&G050 FES~UARY 25, 1976 dOB ' .... KELLY BUSHING ELEV, : 110,79 FT, ~LLW ......... : SUO-SEA COURSE COURSE DOG-LEG 'TOTAL VERTICAL ZNCLINAT~ON D~RECTZON' SE¥£R~TY RECTANGUEAR cOORDiNATES YE,qTIcAL DEPTH DEG PIN '- DEGREES DEG/IO0 ' NORTIi/SOUTH EAST/WEST ...... SECTION 6550,88 22 32 S 28.q5 W 0,77 1155.60 S ~81,~3 W 1.:32, 6~5.00 25 15 S 29,76 W ......... O,SB ".' ~169,59 S 500.55 655~,~. .2q 50 S 30.28 W 1.26 120~.63 S 520,60 W 1311.76 6755,72 6625.02 25 ~7 S ~0.8~; W 1.l~ ' 12~l,09 S- 5~2.15 N 1355.91 6825.51 -' 671~.81 ...... 26'" ~$ ......S 5~',S~ W ..........1.00 .... 1278~78 S 55~.86 W ' 1597.67 691~,86 680~.16 .26 ~6 S 35.25 W 0.86 !516,7~ S 588.8~ W 1"" 700¢~.58 S895.88 25 ~9 S 28, 7 W 2,5~ ~$5~.67 S &11,56 W 7095.18' '- 696'~,~8 .......... 2~' '~0 .... S 20.~9 W ........... ~.~0 .... 159~.20 S 628.81 W - 1528.~1 7186,70 7076,00 23 0 S 20,!5 W 1,50 1~50,97 S 6~2,79..W 7278,95 7168,25 .22 2~ S 18,55 ~ 0,8~ 1t~67,37 S 655,59 W 7371,65 7260,9~ ........ 21'i -qt; ..... S. 18,69 ~ ..... 0,65 - ~502,97= S 6S7,59 7t~G5,0G 755~;,55 20 0 S 20~71N 1,87 1555,50 S 679,57 W ~579.73 7559,!0 7~8,~}0 19 ~5 S 20,59 ~ 0,27 ~56~,5[; S 69~,50 N '1715.62 7652.99 75~2.29 ........ 20 51 .... S 2!,53 W ......... 0,86 1GOODLY S 705,82 N 17~7.9G 77~6,50 7G55.80 .21 0 S 2~.89 W 1.28 1633,05 S 717.79 W 1735.37 7839.22 7728.52 22 56 S 25,~3 W 1,9~ 1666.88 S 755.70 W 1820.77 7950.~9 7819,79 .... 25 !5 S 25, 0 W ....... 2,52 -- i705,80 S 751.08 W ~ i8G1,5' 8020,88 7910,18 25 2q S 26, 9 W 0,48 i7~;2.~0 S 769,55 W 8111,4q 8000,7~ 2~ q7 S 26,85 W 0.69 1730,'56 S 788.~3 W B202,qO 8091,70 ........ 2~ ~9' S 29,7~ W .... 1,27 1816,9~ S - 808,~0 W 8295,~7 8182,67 2~ 45 S 29,70 W 0,~ ~85~,0! S 828.67 W .2029.59 858~,02 8275,~2 25 12 S 28.58 W 0,65 1889,88 S 8~9,25 W 2071,70 8~7~,q6 8~65,76 .... 25 20 S'28,87 W .... 0,~8' ~927,51S 869,7~ 856~,91 8q5~,2~ 25 8 S 28,55 N 0,2~ ~96q,70 S 890,22 W 2156,8~ 8655.86 85~5,16 2~ 0 S 25,6~ W 1.21 2001,0~ S 910,~5 87~7,~1 8656,6~ ..... 25 ~q .... S 28,~ W '" 0,55-' 20S6,~0 'S ' 9~0,07 W ..... 22~B.67" 8859,08 872B,~8 25 ~ S 29,10 W 0,71 2071,22 S 9~9.18 W 2278.50 893!,58 8820,68 22 12 S 50,~5 W 0,98 .210q,6~ S' 958,25 W 2516,65 8915.~9 .... 21 q9 S 51.25 W ..... 0.51 213~85 S ' 987.~ W 2353.95 9006..55 21 25 . S 32.38 W 0.57 2168.1q S 1006.85 W . 23~0.51 9100,39 18 20 S 27.~0'W 3.51- 2%97.53 S 1025.87 W 2q2,.3~ · ANCflORAGE, ALASKA 'ZOCO P2,0DUCT]ON CO~',PANY DAT~ 0;: ~URVEY FEBRUARY 2~, ~976 .FIGS NO.~ '- CO?;PUTAT~ON DATE SURL:Et. GYRoscoPic MULTIS~iOT OUTH HIODLE GROUD SHOUL' ............. ' .................. FEBRUARY 2~, 1976 ............. ~OB NU?I~ER SU3=!6050 .LASKA ALASKA KELLY BUSHING ELEV. : 110.70 FT, ....... ~L~ ........................... TRUE SUB-SEA COURSE , COURSE DOG-LEG TOTAL ~EASURED VERTICAL VERTICAL INCLINATIO~ DIRECTION SEVERiTy RECTANGULAR COORDINATES VERTICAL "JPTH '- 'DEPTH DEPTH ............. DEG ....... RIN DEG.,~ES°~ ..... DEG/IO0 NORTH/SOUTH ' EAST/WEST ....... SECTIO~.' ' 9800 9306,21 9195,51 17 37 S 22,85 W 1,57 2225,t~3 S 1036,98 W '2~55,18 9900 9:~01.'92 ' 9291.22 ............ 16 .... 2 ......S '2~.12 W ......... 1.62 ....... 2251.98 S 10~8,50 W ........ 2%34.11 -- 10000 9ff98.~0 9~87.~0 15 .~5 S 2~.~1 W 0,$~ 2277.0~ S _. ~059,5~ W 25!!.ff8 10100 ~59,.65 9~;8~,95 !~ 25 8 2~,95 N 1 ~ 2500 87 S 10~ ~8 W i0200 -- 9~9i.7~ ..... 958i,0~ ............iS -Z5 ....... S 2~,~5 U ............. l~ ......... ~2~9 S ..... 'IO~O~ZT-N 10~00 9789e21 '9678.51 12 ~5 S 29e~1 .W 0.89 2~+2.23 S 1090.65 W '258~.71 !0~00 9888e95 '9776,25 11 ~8 S ~0,51 W 0,82 2~60.5~-~ S 1101,17 W 2G0~.75 !0~'~1 9917e~0 - 9006.60 ........... 11-'-~0 - S '~2', '8 'W ............. I',ll ......... 2565~9~ S ..... 1!0',~ W HORIZONTAL DISFLACE¢-]ENY .= 2611,02 FEET AT SOUTH, 25 DEG, 1 ['lIN, WESY AT HD = 10'~1 ' TtIE CALCULATION PROCaDUkES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE [~ETItOD. _. G. J. Ross Area Superintendent February 11, 1976 File: GJR-120-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Compan, · P.O. Box 779 Anchorage, Alaska 99510 Dear Sir: Re: Change of Plans SMGS Unit Well No. 14 Permit No. 75-66 Reference is to the Permit to Drill SMGS Unit Well No. 14 which was approved by your office on November 12, 1975. The casing program pro- vided for 9-5/8" production casing to be set at total measured depth of 10,650'. On January 31, 1976, hole problems resulted in pipe being stuck after drilling to 10,107'. A fish was left in the hole with the top at 9738'. Due to upper hole problems, the decision was made to set 9-5/8" protec- tive casing above the fish. Casing was set at 9624' on February 4, 1976. We are currently preparing to directionally drill 8-1/2" hole around the fish and will set a 7" liner through the pay. Attached is a Form 10-403, Sundry Notice of Change of Plans, reflecting the proposed casing design. We respectfully request your approval of the proposed change. Yours very truly, Area Superintendent 1976 Agtachmcnt DIVt~ION OF OIL AND F~t'fn I0 - 403 ~ Submit "Intentions" in Triplicate REV. I - t0-7~J & "Subsequent Reports" in Duplicate STATE O'F ALASKA OIL AND GAS CONSERVATION COMMI'I'[EE SUNDRY NOTICES AND REPORTS ON 'WELLS (Do not use this form for proposals to drill or to deepen uSe "APPLICATION 'FOR I~EP,.~I'r-'' '/or such 'proposals.) OIL ~ ~AS [~ OT~ER w£LL wE~.~ Drilling 2. NAME Of' OPEH. ATOR Amoco Production Company 3. ADDRESS OF OPERATOR P. O. Box 779~ Anchorage, Alaska 4. LOCATION OFW~L Atsurface Leg 4,.Slot 3, 678' FSL, 1765' .FWL, Sec. 35, T8N, R13W, S.M.,'Platform Dillon 99510 !/5.AP1 N~CA.L CODE 50-133-20281 6. LEASE DEC:dGNAT1ON A.ND SERIAL NO. ADL-18746 7. IF IN-DIA.N, A.I..,L~'A-I'~:E OR TRIBE NA.1VLE 8. UNIT, FAI~I OR LEASE NAME SMGS Unit 9. WELL NO. 14 10. FIEL~ ~N'D POOL, OH. WILDCAT SouCh M±ddle Ground Shoal 11. SEC., T., R., M., (BOT"roi~I HOI...~ OBJECTIVE) Sec. 2, T7N, R13W~ S.M. 13. ELEVATIONS (Show whether DF, RT, OR, etc. 12. PERMIT N'O. RDB 100' above MSL 75-66 Check Appropriate Box To Indicate Nature of N~tice, Re ~ort, or Other Data NOTICE OF INTENTION TO : TEST. WATER SHUT-OFF j j PULL OR ALTER CASINO FRACTURE TREAT 8HOOT OR ACIDIZI). REPAIR WI~LL ~ Othec~ ' I WATER Sll UT-OF~' J J RIIPAIRINO WIILL ZJ ALTI~RINO CaSINg ABANDON M IIHT* MULTIPLE COMPI,ETI: ABANDON* CHANOE PLANS FRACTURE TREATMENT BHOOTINO OR ACIDIZIN0 (Other) __ (NOTE: Report results of multiple completion on Well C~,mpletlon or Recompletion Report and Log form.) 15. DL'iqCRIBE PROPOSED OR C0.MPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an)' proposed work. The Permit to Drill which was approved November 12, 1975 provided for 9-5/8" production casing to be set through the Lower Kenai Conglomerate at TMD of 10,650'. Due to hole problems, operator set 9-5/8" protective casing at 9624' on February 4, 1976. Operator proposes to drill 8-1/2" hole to TMD of 10,500', hang 7", 26# P-110 Buttress liner in 9-5/8" casing from 9400' .to TD and cement'liner with 250 sacks Class G cement. Well will be logged and selectively completed in the Lower Kenai Con- glomerate. , ...;, t ', i, J '' '. !.;., ,: ', i 16. I hereb7 c~ttf7 that the forego~ng'btrue ~nd correct StoNED ,~P.~Y't ::(L~'~. k~t-~.~' ' rlTL~ Are~ pp~erin~ende~t (Thi~ space for State~ce~ ) ~ See Instructions On Reverse Side DATE 2-11-76 DATE Approved Copy Returned Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 G. J. Ross Area Superintendent January 23, 1976 File: GJR-075-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-4 SMGS Unit Well No. 14 Attached is the State of Alaska Form P-4 furnishing December's drilling operations for South Middle Ground Shoal Unit Well No. 14. Yours very truly, George J. Ross Area Superintendent Attachment ~'. S- I-?0 STATE OF ALASKA SUBMIT 1~ DUPLICAT]~ OIL AND OAS CONSERVATION COMMIT-tEE MONTHLY REPORT OF DRILLING ~ AND WORKOVER OPERATIONS Amoco Production Company 3. ADSR~SS OF OPERATOR P. O. Box 779, Anchorage, Alaska 99510 4 LOCA~ON OF W,~I.,L Leg 4, Slot 3, 678' FSL, 1765' FWL, Section 35, T8N, R13W, S.M., Platform Dillon APl NU~ERICAL CODE 50-133-20281 LEASE DESIGNATION AND SERIAL NO, ADL-18746 ? IF INDIA]~ AL~)~ lkl~ OR TRIBE NAME 8. L~.'IT FA/iA{ OR LEASE HAME SMGS Unit g WELL NO 14 i0 F~J.D ~ND POOL, OH WILDCAT South Middle Ground Shoal I1SEC,T..R..M (BOTTOM HOI~ Sec. 2, T7N, R13W, S.M. 1~ PEP. MIT NO 75-66 13. REPORT TOTAL DEPTH AT F~ND OF MONTH, CHANGES IN HOLE SIZE, CASING AND C~wIENTING JOBS INCLUDING DEPTH SET ~ VOL~ US~, P~O~TIONS. ~TS ~ ~SULTS FISHING JO~ J~K ~ HO~ AND SIDE-~CKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS December 1-5: Conductor casing previously set at 610'. Rigged up rotary tools and drilled and surveyed to 1515'. Ran 40 joints 13-3/8", 68#, K-55 Buttress casing and 2 joints 13-3/8", 54.5#, K-55 casing. Cemented with 750 sacks Class G + 2% gel + .12 gallons D-80 per sack, 12.8 ppg, followed by 500 sacks Class G + 2% calcium chloride, 15.8 ppg. Had good cement returns with an estimated 80 barrels excess. December 6-10: Work suspended. December 11-21: Dynadrilled and surveyed to 6060'. Lost No. 1 cone at 1585'. Tripped in with Globe basket and recovered cone, bearings and loose metal. December 22-29: Dynadrilled and surveyed to 7800'. Hit coal break and pipe stuck at 6433'. Worked pipe loose and hole cleaned up. Reamed bridges of coal 6608-6839'. December 30-31: Dynadrilled and surveyed to 8305'. Tripped out at 8048' and hole was tight at 6730', 6690', 6023' and 4970'. Rotated through tight spot at 4970'. Tripped in and circulated and reamed from 5000' to bottom. Worked pipe during tight connection at 8243'. Made connection at 8305' and pipe was stuck on bottom. Jars w°rking g°°d but n° pipe m°vem~ E .~.~ ~ ~ ~ JAN oil and gas conservation commlHee bythe 15~ of the suoc~ding mon~, ~le~ Gtherwise dir.cted. G. J. Ross Area Superintendent January 19, 1976 File: GJR-052-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: Change in Casing Design SMGS Unit Well No. 14 Permit No. 75-66 Reference is to a recent telephone conversation between your John Miller and Bill Halvorson of this office regarding a proposed change in design of the 9-5/8" production casing string for subject well. Mr. Miller gave verbal approval to substitute 43.5 lb., E-95 casing for 47 lb., S-95 casing originally proposed in the Application for Permit to Drill which you approved on November 12, 1975. The resultant collapse safety factor for the casing at TMD of 10,650' (TVD 10,000') is 1.06 for 10.2 ppg mud, which is below the 1.125 normally specified. The remainder of the string meets design safety factors accepted by the Division of Oil and Gas-. As we pointed out, we believe this design is adequate and it will allow the use of casing stock on hand. The attached form 10-403 is submitted to show the complete casing design. Your cooperation in this matter is appreciated. Yours very truly, George' J. Ross Area Superintendent Attachment cc: A. M. Roney, w/ attach. Form 10 -403 IR.EV. I - 10-7~ Submit "Intentions" in Triplicate & "Subsequent Reports" tn Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this lorm for proposals to drill or to deepen Use "APPLICATION 'FOR ~'EB.~rr-L? '/or such 'p~o~osals.) WKLL WELL OTHER 2. NAME OF OPEKATOR Amoco Production Company 3. ADDRESS OF OPERATOR P. O. Box 779, Anchora~e,...Alaska 99510 4.LOCATION OF %YELL ^tsu,'f,¢e Leg 4, Slot 3, 678' FSL, 1765' FWL, Section 35, T8N, R13W, S.M., Platform Dillon 13. ELEVATIONS (Show whether DF, RT, GR, etc. RDB 100' above MSL 14. 5. AP1 NUNiEP. ICAL CODE 50-133-20281 6. LF_JkSE DES/GNATION AND SERIAL NO. ADL-18746 !7. IF INDIAN, ALLO'i-r~'E OR TIIIUE NA~LE $. UNIT, FAB.W/ OR LEASE NAME SMGS Unit 9. V~ELL NO. 14 ' 10. FIELD A~D POOL, OR WILDCAT South Middle Ground Shoa1 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 2, TTN, R13~, S.M. 12, PERM/'T NO. 75-66 Check Appropriate Box To Indicate Nature of N~tice, Re ~ort, or Other Data NOTICE OF INT~NTIOlq ~O: TEST WATER FRACTURE TREAT aHOOT OR ACIDIZ~ REPAIR PULL OR ALTER CA~INO MULTIPLE COMPI.tTE ABANDON* CHANO~ PLAN~ Other BUB"EQUENT RBPOIT OF : WAT,R BIIUT-0FF RIIP&IRINO WELL SHOOTING 0[I ACIDIZINO , ABANDONMKNT* (Other) (NOTE: Report relulte of multiple completion on Well C.mpletlon or Reeompletlon Report and Log form,) 15. DESCRIBE PROPOSED OR COMPLETED 0PERATION8 (Clearly state all pertinent details, and give pertinent dates, Includin~ estimated date of starting an)' proposed work. Confirming telephone conversation between John Miller and Bill Halvorson, Amoco requests approval of the following 9-5/8" casing design. This design differs from that proposed in the permit to drill which was approved on November 12, 1975 in that 43.5 lb., E-95 will be run in place of 47 lb., S-95 on bottom. The collapse safety factor at TD of 10,650' TMD, 10,000' TVD, will be less than the 1.125 normally specified. The proposed design is as follows: Casing ~ Size Weight Grade Setting Depth 9-5/8" 43.5 E-95 Buttress 407' 40 N-80 Buttress 1,912' 40 SS-95 Buttress 6,286' 43.5 E-95 Buttress 10,650' Anticipated mud weight is 10.0 to 10.2 ppg. 1~.I heteb7 ce~y that the fore~oin~fJ _~r~_ a and correct ... -.- ,. _, (Thil space for State ~ce u~) ~ ~ TITLE Area Superintendent OATZ January 19, 1976 CONDITION~ OF ~PROVAL, IF ANT: TITLE See Instructions On Reverse Side DATE · . DEPARTMENT OF NATdRAL RESOURCES Division of Oil and Gas ~ -.~ m.. j-- O. K. Gilbreth, ,.lt. Thru-: FROM: Di rector Hoyle 'fi. Hami I ton Acting Director Ben Le Norman Petroleum Ins~tor D^TE :.,~ January 5, 1976 SUBJECT: BOPE Stack Test .Amoco SMGS Unit #14 Platform Dillon Russ Douglass and I departS':=~ office at 9:30 AM, Wednesday, December. 10,. 1975 for International Airport for~ Check in.:for, ll:O0 AM flight via AAI Twin Otter to Kenai. We arrived in Kenai at ll:30rA~ and found no rental cars..available. We had hoped to witness partial meter provingat .East~Forelands before departing from the heliport there at 3:30 PM for Platfom Ol]lon, We took a regularly scheduled, bus from. Kenat at 2.:15 PM, arriving at the East-Foreland's heliport at 2:45..PM. We departed from the heliport via helicopter .a~t 3:30 .PM and arrived .on ~Platfom Dillon at 4:00 PM. We were met on the {blatform by. J~im McMaster, .Amoco Drilling Foreman, and later introduced to Wade Pace, Parker~RIg ~]50 Toolpusher. Ntppling up was still in progress and tests were delayed. At 6:40 AM, Thursday, Decea~. )1, 1975 testing be~n.. Pressuring was by mud pump using clear water. Two sets PiPe rams, bl~ind rams, two. wing valves and check valve on kill line and two wing valves on choke line were tested, successfully to 3000 psig. Hydril was tested to 1500 psig. Eight plug valves and forty- ~-~- ~r-~- flan~cms in. the choke manifold were. tested~ to 3000 . psig. The Swago superchoke and manual adjustable.choke were actuated to check operation. The positive choke in ~the manifold was orificed with a l/2" choke bean. The kelly cock and lower kel.ly valve were tested to 3000 psig.. Gray ball type floor valve was on hand. Tests wete concluded at 12:45 PM.. We noted no nitrog~en backup at. the accumulator and discussed this with .Mr. McMaster and lair with Mr. Bill Hal~verson.,..Amoco Drilling Engineer, on his arrival at the platform.. They stated this backuP system would be installed as soon as possible. A field inspection report was~.]Prepared, the original given to Mr. McMaster, a copy to Mr, Halverson and a copy at.tached to this report We departed Platform Dillon a~t.]~:.lO PM via helicopter arriving at East Forelands at i :20 PM and then by bus to Kenat ·airport at 1:45 PM. We departed .Kenai airport .at 2:55 PM arriving in Anchorage at 3:.25 PM and at our home at 4:05 PM. In summary, we witnessed B°PE Stack .t~st'at Amoco's SMGS Unit #14 on Platform Dillon before drilling shoe on 13 3/8" surface pipe. BLN :bjm 024~1B STATE of ALASKA DEPARTMENT OF NATURAL RES(RICES Division ofOil and Gas ...... TO: ~-- O. K. Gilbreth, Jr. Director Thru: ,oyle 'I4. ,amilton~~.'i Acting Director- D~-r" SUBJECT: F.oM.. Ben Le Norman Petroleum Inspector Function of manual and automatic adjustable chokes in choke manifolds Since differences of opinion .eX'.st as to. the exact function of manual and automatic adjustable chOkes in. choke ~ .mani:folds,.we talked with. representatives of five choke manufacturers whose optntons~,~]~sted below .reflect API specification 6A, Figures lO.1 · and 10.10, page 55. ~ .. -'~~n !r0n.~orks - Don otetz~Distric,t. Manager ~.. The type H2 choke should be '~$1~zed as a .throttling devtce and .not as at.valve. An engineerlng release advises ~stomers not.to fUlly close the choke as damage to the seat will occur ................ .,-~ The Cameron automatic choke"is .~t designed to. fully.close and will not test using mediums such as water or diesel ......... Gray Tool. ComPany- Marvin McD.~niel. Area .Manager It is not recommended that adjlu$.table chokes.be fully closed as the carbide tip on. the stem will probably break of..f..:~ Using blind f]an§es, choke bodies only are tested. to design working pressures.a.t the i~actory~. 14o~mver, the complete choke is never factory tested ..... M_~cE~oy~- Horace Smith, District .r~nager . Quoting API standards, he advised ~their. choke shou]d be considered an adjustable orifice or throttling device and not a.fu]l closing valve. Oil Center Tool - Dan Settles, l)istrict,Manager ...... ~ ::: -.. . . Adjustable chokes assembled on. wellhead equipment i~ Anchorage .are tested to rated working pressures. However.,.-after~ periods,of throttling, the choke cannot be expected to fully close due to cutting out.of .either the stem or seat. Swaco - Dresser - Larry Dow,. ~rea Manager The superchoke is a positive sealing device and can. be tested .to lO,O00 psig. Their rubber choke of which there, are only two,,In operation in the State, is not full closing. According to Mr. Dow, the on~..automa.tic adjustable .choke not .a Swaco operating in Alaska is a Cameron utilizedon..Nabors 18-E. BLN :bjm () () lugged - ( ) ( ) 13. Clean,up (1~)~ ( ) 30. Lower Kelly valve~si~ r(~, ( ) 31. Safety Floor valves-(~BV ( )Dart t ( ) ( ) 14. Pad leveled Total inspection observa-tion time ~ hrs/~ta?s Total number leaks and/or equip, f.~?lures · Remarks ,~,-' ~~..~. .~ ~'~ '~'~.~-~'~-~ ~:;-~'~-- . - .':~: ,~, .... . ~..~"' . ~ , , ._ . .. . ~ _~?'~ . ... ,-: . .. - . ....... · .... · , ,??T~,'~:~T'~-' - ~ '. . .. ". ' T.- . ~ ' cc: .~...~,~~ Not]fy ~n . days or when ~eady Inspected by [~.-z ~~.'Date~!~ 1975 ~ ~~t ntendent ~o Preductt~ ~y P. O. Box 779 Arc--age, Alaska 9gS10 Oear Sir: Enclosed is tt~ approved appl.tcatton for permtt to drill the above referenced well at a iocatton tn Section 2., Township 71~, Range 13g, !~elI samptes, core chtps, aed a mud log are not required. A directional survey t s required. Pan~ rtvers tn Rlaska and thelr, drainage s~stees have been classified as l~ant for tt~ spawntng .or m~grat~on of anadros~us ftsh. Operations tn these areas are subject te AS 16.~0.870 and the regulatlons premulgated there- under (Title $, Alaska Administrative Code).. Prtor to caneenctng operations you ~ay be contacted by the~Flabttat Coordfnator's offtce, Oeparteent of Ftsh and 'Gmae. /lutton of an~t weters of the Sta~ !s P. rO~_. tbtted' ticle 7 and tl~ regulations p_roeul.gated t~uno~r. ~. t~.ltt_e .s?,.a.~as~ .... 1 ~i~tstratlve Code, Chapter 70) and by the Federal ~ater POllUtion t~n~r~ Act, as ~. Prior to ~cing operations you may be contacted by a representative of the Oepar~t of Envlr~tal Conservation. Pursuant to AS .38...40, Local Hire Under State. Leases, the Alaska Oepart~ent of Labor Is betag notlfted of the issuance of this permtt to drt11. To aid us t-~ scheduling fteld ~ork, we would appreciate your notifying thts office within 48 horn's after the ~ell ts spudded. ~e would also 11ke to be nottf~ted so that a representative of t~ 01~tston may be present to wttness testing of b1~ preveater _equipment befoee surface caslng shoe ts drilled, ~~ J. R~ss Thomas R. Marshall, ~. ~ge 2 November 12, 1975 ]~n the event of suspe-nsJ~ ~: abaft please gtve thls oCftce adequate advance ~ttft*~tten so ~t we my have a wt~ss present. Very truly yotn's, Thomas R. Marshall., ~lr. Executive Secretary Mas~ 0tl a~d Gas ~xmservatton ~tt~ Enclos~ cc: Oepar~t of Fish aad ~, Habltat Sectton w/o encl. ~taeat ~ Eavt~ntal ~nservatton w/o encl. Oepar~t of ~, Supervisor, Labor Law Compliance O~vts~ w/o eric1. Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 G. J. Ross Area Superintendent November 3, 1975 File: GJR-881-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: Drilling of SMGS Unit No. 14 Please find attached a Form P-1 requesting authorization to drill SMGS Unit Well No. 14. The subject well is to be directionally drilled from Leg 4, Slot 3, Platform Dillon, to a bottom hole location of 600' FWL, 1575' FNL, Section 2, T7N, R13W, S.M. The bottom of the well will be slightly within 500' of the section line, but is beyond the stipulated 500' from the ownership lease line as the South Middle Ground Shoal Unit includes the SE NE and W/2 SE Section 3, T7N, R13W. Please find attached the required BOP specifications for both the 17-1/2" and 12-1/4" holes. Also enclosed is our draft for the $100 permit fee. Yours very truly, George 3'. Ross Area Superintendent Attachments Porrn I0-- 401 l?~rV'. I--I--71 , ~ ~ · reverse side) STATE OF A.~A.SKA "/:'~::,:i ) i', O~L AND GAS CONSERVA,T~ON cgMM~I..~.~:i~?, PERMIT TO DRILL OR DEEPEN ~m. TYPE OF DRILL WELL WELL DEEPEN [] 2. NAME OF OPE~R.ATOR Amoco Production Company 3. ADDRESS O~ OPERATOR P. O. Box 779, Anchorage, Alaska 99510 4. LOCATION OF WELL Atsurface Leg 4, Slot 3, 678' FSL, 1765' FWL, Sec. 35, T8N, At proposed pro~w' S.M. (Platform Dillon) 600' FWL, 1575' FRL, Sec. 2, T7N, R13W, S.M. 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFI~* 15-1/2 miles NNW of Kenai APT~50-133-20281 6. LEASln DmlGNATION ~ S~.AL NO, ADL-18746 7. IF IlqDIAN. ~.l-~:,c OR TRIBE NAME 8. UNIT FARM OR LEASE NAME SMGS Unit g. W~L NO. 14 10. FIELD AND POOL, OR WILDCAT ~iddle ~round Shoal 11. SEC., T., R.. M., (BOTTOM HOLE OBJECTIVE) Sec. 2, T7N, Ri3W, S.M. 1~. 14. BOND INFORMATION: Blanket bond - Division of Lands Bond File B-il TYPE Surety and/or No. 15. DISTANCE FROM PROPOSED* Top' 725 FNL i,e, NO. OF ACRE~ IN I'-EASE ' LOCATION TO NEARES B' PROPERTY OR LEAsE LINE, FT. t--: ~,3~ ~'WL of (Also to nearest drig, unit, if any) Sec. 2, T7N, R13W 4160 1~. DISTANCE FROM PROPOSED LOCATION* ' i1~. PROI~SED DEPTH TO NEARESI' WELL DRILLING, COMPLETED. i OR APPLIED FOR. FT. 1050' South of sMGS No, 3 10~650 21. ELEVATIONS (Show whether DF, RT. CH, etc.) RDB 100' above MSL .,,~,0~,! $100,000,,, 17. NO. ACRES ASSIGNED TO THiS WELL 8O 20. ROTARY OR CABLE TOOLS , Rotary 22. APPROX. DATE WORK WILL STAHT* December 15, 1975 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZEOF CASIN~!. WEIOH~ PER ~OO~ GRAI:I~ $~I~I'INO DEPTH quantity ~f cement 17-1/2 '13-3/8 -' 54.5# :~ K_55 1,500' Circulate to surface '- 12-1/4 9-5/8 40: 4~iS.&ii 8-95 10.650~m~( Min...500' above pay 47# , , , Operator plans to drill 17-1/2" hole vertically from existing 20" casing set at 610' to a depth of 1500' where 13-3/8" casing will be set. A 12-1/4" hale will be drilled t° TD and 9-5/8" casing set. The 12-1/4" hole Will be drilled vertically to about 3200' and then kicked direc- tionally to the proposed target at -9150'. There are no affected operators as the SMGS Unit includes the SE NE Sec. 3 and W/2 SE Sec. 3, T7N, R13W, S.M. Intervals indicated to be productive by log analysis will be perforated and possibly stimulated. BOP specifications are attached for both the 17-1/2" and 12-1/4" holes. ~ ABOV~ SPACE D~SCRIB~ I~ROPOSED I~ROGRAM: If ;wo~ml is to dee~n give ~m on p~sent pvodu~tve zo~ ~d p~sed (This space for State use) SAMPLES AND CORE CHIPS D*~ November 3, 1975 . CONDITIONS Or APPROVAL, 'IF ANY":" JM,UD LO'kN ~YES 0 A.P.I. ~CAL CODE i Area Superintendent i~:RI~NO APPROVALDAT~ Nnv~mh~r 12~ 1975 A~O~a~~ 4'~ ~,, , ,=. Executivq S?qretar~ ~.~ November 12, 1975 *~ In--on, ~ Reve~ ~de ID · 27 '2G , :34 35 ? . . ~ . 1765' SEWARD MERIDIAN ALASKA LEG. NO. I LEG. NO. 2 LEG~ NO. 3, LAT 60°44' 08.16" LAT 60044, 07.72" LAT. 60° 44' 07.08" LONG. 151° :30' 45.85" LON G.151° $0' 44.78" LONG. 151° 30' 45.86" Y = 2,4-65,9l? Y = 2,463,871 Y = 2,463,807 X = 229,266 X : 229,319 X = 229,26:5 FROM S.W. COR. FROM S,W. COR. FROM S.W. COR. 743' NORTH 8, 699' NORTH 8, '655' NORTH 8, 1818' EAST 1872' EAST 1818' EAST CERTIFICAT~- OF SURVEYOR hereby T7N , LEG. NO. 4 LAT. 60° 44' 0752" LONG, 151° 30' 46, 94" Y = 2~463,853 X : 22 9..~ 211 FROM S.W. COR. 678' NORTH 8: 1765' EAST certify that I am properly registered and licensed to practice land sur.veying in the State of Alaska fhaf this plat represents a location survey made by me or under my supervision and thal all dimensions and other details are correct. Dote Surveyor SURVEYORS NOTE The location of S.M.G.S. by use of U.S.C. &.G.S. Light" .... , and ' Boulder ii ,i, Platform D was occomplished stations "Cost", "Easl Fore,and and C.E.T. 18 (Offset 2) 26 35 35 SCALE ' I"-=' lO00' 2 25 .36 I FINAL' PLAT O.F'~ S.M.G.S. PLATFORM "O" LOCATED IN SE I/~, SW I/4, PROTRACTED SEC. 35,T 8N,P. 13W,$ M. SURVEYED FOR PAN AMERICAN PETROLEUM CORP. P.O, BOX 779 ANCHO,~,AGE, ALASKA SURVEYED BY E M. LINDSEY & ASSOC. LAND SURVEYORS 8. CIVIL ENGINEERS 3201 ARCTIC BLVO. ANCHORAGE, ALASKA /~ooo) SUBJECT Amoco Production Comp~"~( ENGINEERING CHART ~ L"O Cu~ L ~ L-I / i'~E.U L EXHIBIT BOP-3000 MINIMUM BLOW-OUT PREVENTER REQUIRMENTB S,000 pen W.P. IOTE: I 600D COIIDI1101 ].DOB fsi W.f. NIKIHUN. ALL FITTIIIGS FO Il FLANGED. SCBEWED CONNECTIONS DOWISIB~AII liON CHOKES PIB#I$SIBLE. SAfElY YALVt NUSl IE AVAILABLE ON BIG FLOOB AT ALL ;INES WlIH PIOPEI CO~UiCTION OK SUB, VALVE TO BE FULL lOBE S.Itl isa W.P. NIIINUN. 4 ALL CNOUE Alii KILL ~IIES FO Ii SECUBELY AIICHOBiD, ESPECIALLY IIIDS Of CHOKE LILIES. $ EQUIPNEIIT lllrOUGH WHICH 111 BUS1 PASS SHALL AS LAIGE AS IISlDI DIAIdEIEBOf IHt CASING BEIIIG DRILLED I#BOUGN. t. liLLY COCE OI lILLY. I. IXTEISIOI WBIICNES AIB HA10 WIIEELS TO IE PDOPEBLT IISIALLE! All IrACE! AT ALL TINES. I. ILOW-Olil PIEVEIFEB COITrOL TO I! LOCATED AS CLOSE TO IBILLEIS POSIIIOI AS FIASIILE. 9. BLOW-OUT FIEVEIIEI CLOSII& EQUIPNEIIT FO ilCLUDE It &ALLOI ACCUNULAIOI, TWO IKDEPENOEIT SOURCES PUNP POWEr OI EACN CLOSlI6 UIIT INSTALLAFIOI. ill NEll AL~ IAIC SPECIIICAIIOlS. IOTE: ! BIILLIll IIPPLE I0 Ii SO COISTII/CIEI IIi! I! CAI Ii lABOrED WITHOUT IISI OF A WILDE1, TNIOUGN rOTArY TABLE OPEIII6; WITli NIIINUN I.l. EQUAL ~ DrESSEr COUPLIr6 lONit TAll lO PIEYEITE! BOLE. 1llSSll (~OUPLII6 ~ tILL UP Lift lO PUNP ,,STA,L,, ,, ,IA,. ].iii psi lilY! lilt IIAPNIAN PIOTECTED (~ lltt till lO PUNP " ~J IQ AUIItlAIY fll CIIOKE ASSEMBLY VtilICii FOB ~i111111101 SHOULO Ii HOIJZOalAL ON i~,' STINt ALi LIltS loft: SECURELY ~ lid Al t~ OF ALL VALVES TO I[ FULL OPEIli6 i " flit UP tile ', l C#OKE i ABC, SWACO Ol EQUal IANF ii I TWO fOOT PLUGGEI EXTEISIQI FULL OPilln6 · NIl. Ill' VALVE 4" IllLL PIPE OI TUIll6 A AUXELIAI! PI! IOTE: IIEECTIQI OF.. #AIIFOLD JUl A-A OPTIQIAL WITKll ge' ARC AS SIOWl IltOW : , CEITEILllE OPTIOIAL I r---£-~-- : . W l~ JILL LIIE YALYE SUBSTlUCTURE FLOW Line ~ I <~ b.,a: : co,,,OL : NAnlFOLO ' lOLl: Alia PLAi OF IlS FLO01 DRILL )IPt OR IUSING AUXILIARY Line TQ BE INSTALLED On 6BOUlP IESIDE WALKWAY IF lfQUIBED. IOTi: STEEL HUD PiT TUBnED DOWl 4S' FBON #OIIZOnTAL ' CHOKE I FOOT PLUGGED [XTfNSION ! ALL UINAIKED VALVES TO It PLUG OR GATI HETAL TO NETAL SEAL ~lsi WOinlnG PRESSURf. ALL UIHAKED PIPE Nil;HUN Z" O.D. GLADE I-8! TUBII6 Ol EOIIVALEIT. 3 PEILI HOUSE HOLE 1J" OTF CEnT[I LIKE IF HOOKUP Of CHOIR AID HAnIFOLO IS UKIE! I&Kf. 4 NAnlFOLD nUI A-A TO BE STRAIGHT THIU IUI. Amoco Production Company STANDARD ASSEMBLY FOR FLUID OPERATED OOUBLE BLOW-OUT PREVENTER 3,000 p.i W.P. 1-31-1S CHECK LIST FOR NEW WELL PERMITS Company .. ~km?O~ Yes No Rema'rks 1. Is the permit fee attached ..................... /~Z' Lease & Well No. ~~~ ~/~/ ~z/wz~:[~ 2. Is well to be located in a defined pool .............. 3. Is a registered survey plat attached ................ ~a/~ 4. Is well located proper distance from property line ......... ~ 5. Is well located prope, r distance from other wells .......... A~: 6. Is sufficient undedicated acreage available in this pool ...... ~/q 7., ....... Ts well to be deviated ....................... lwao~: 8. Is operator the only affected party ................ ~' ~ 9. Can permit be approved before ten-day wait ............. 10. Does operator have a bond in force ................. ~-- ll. Is a conservation order needed ................... 12. Is administrative approval needed ................. 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 11 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 .............. Additional Requirements' Approval Recommended' Geology Engi nee ri ng: Revised 1/15/75