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Home My WebLink About168-0561a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _0 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: N/A BF: N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 92 (ft MSL) 22.Logs Obtained: N/A 23. BOTTOM 26"280 13-3/8" J-55 1,559 9-5/8" N-80 9,024 7" S-95 10,455 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 11,085 / 9,613 10,034 10,047 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 9/21/2022 168-056 / 322-377 50-733-20126-00-00 S MGS Unit 12 ADL0018746 667' FSL, 1764' FWL, Sec 35, T8N, R13W, SM, AK 867' FSL, 61' FEL, Sec 3, T7N, R13W, SM, AK N/A 8/28/1968 12,000 / 10,479 Surface 100 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 229210.4 2463841.3 N/A CASING WT. PER FT.GRADE 10/24/1968 CEMENTING RECORD N/A N/A SETTING DEPTH TVD 2458804.5 TOP HOLE SIZE AMOUNT PULLED N/A 227272.3 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM SIZE DEPTH SET (MD) 10,051 / 8,652 PACKER SET (MD/TVD) 2-7/8" Surf 23# / 26# Surf 10,174 1,586Surf Surf 40# / 43.5# 11,973 Surf 8,762 54.5# 280 Surf 10,461 N/A N/A Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Middle Ground Shoal / A Oil & E,F and G Oil & Middle Grnd Shoal Oil & SMGS Undefined WDSP N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment RECEIVED by James Brooks at 4:33 pm, Oct 10 2022 Abandoned 9/21/2022 JSB RBDMS JSB 102722 xGSFD 11/15/2022BJM 11/9/23 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. Contact Name: Aras Worthington Digital Signature with Date: Dan Marlowe Contact Email:Aras.Worthington@hilcorp.com Contact Phone:907 564-4763 Operations Manager General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS TPI (Top of Producing Interval). Authorized Name and Formation Name at TD: Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. INSTRUCTIONS Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2022.10.26 13:12:24 -08'00' Dan Marlowe (1267) Updated by: JLL 10/10/22 Dillon Platform Di-12 Dillon Platform Well DI-12 Oil Well>Injector>>Disposal>>>Injector Dual String Jewelry Detail # Depth (RKB) Length ID OD Item Long String 1 34.2’ 10.0” Cameson 10Ǝ Nom Dual Tubing Hanger 2 10,036’ 0.70’ 2 Ǭ” x 3 ½ƎButt crossover 3 10,047’ 1.50’ 8.125” Baker Parallel Flowhead 4 10,051’ 2.50’ 6.00” Baker Model 7-1 Packer 5 10,051’ 4.875” 6.00” Baker seal assembly 6 11,070 1.12’ 2.250” Baker 7 nipple 7 11,071 1.20’ 3 ½Ǝ x 2 ǬƎButt crossover 8 11,072 0.96’ 4.00” Seal locator 9 11,085’ 2.50’ 4.00” Baker Model 7-1 Packer 10 11,092’ 20.45’ 3.00” 4.00” Seal assembly 11 11,093’ 0.8’ Bull nose shear out sub Short String A 34.2’ 10.0” Cameson 10” Nom Dual Tubing Hanger B 10,034’ 1.20’ 3 ½Ǝ x 2 ǬƎ Butt crossover C 10,047’ 0.83’ 2.197” Baker 2 ǬƎR-nipple Concerns/Comments: x 08/2011 – Well circulated with 9.8 ppg brine. Placed 2 - 10 bbls LCM pills down tubing. Squeezed 3.6 bbls of 1st pill into perfs, remaining pill gravity fed into perfs. Squeezed 3.2 bbls of 2nd pill into perfs. Well dead. Freeze protected. x 07/24-29/2011 – RIH on LS w/2” GR to 10,036’ tag (fill or obstruction). RIH on SS w/2” GR to 10,026 tag. RIH on SS and punch from 9978’ - 9983’. RIH on LS and punch from 9986’ – 9991’. All shots fired on both and pressure changes seen after firing on both. x 8/4/2009 – Last survey run to 10,100’ KB, found scale and gritty residue on tool string. x 8/11/2005 – SS: Tagged “R” Nipple at 10,028’ KB. LS: Tagged fill at 11,141’ KB SLM Several external corrosion found along with tubing parts, opposite of injector zone between top 2 packers (11,016’- 10,679’).possible cause by stimulation acid trapped behind tubing in this zone. Possible 70% liner corrosion between 10,679’ to 11,016’. Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other (26”?)*Conductor Surface (280’)* *As per mud reports (could be 20” Conductor) [No info on Conductor] 13-3/8” Surface 54.5#, J-55 Surface 1,586’ 17.8°ST&C / 12.615”1770 sxs, TOC @ surface 9-5/8” Intermediate 43.5#, N80 Surface 5,139’ 8RD / 8.755” 1060 sxs, Calc TOC = 8,651’ (20% washout)40#, N80 5,139’ 10,461’ Butt / 8.835” 7” Liner 23#, S-95 10,174’ 10,454’ ST&C / 6.366” 360 sxs, Calc TOC = 10,594’ 20% washout)26#, S-95 10,454’ 11,973’ LT&C / 6.276” Tubing 3-1/2” Production 9.2#, N-80 34.2’ 10,035’Butt / 2.992”Long String 34.2’ 10,034’ Short String 2-7/8” Production 6.4#, N-80 10,035’ 11,070’Butt / 2.441”Long String 10,034’ 10,047’ Short String TD =12,000’ PBTD = 11,923’ MAX HOLE ANGLE = 39.8O @ 6,666’ 1 13-3/8” @ 1,586’ Pkr @ 11085’ G&G Oil Top 10767’ MD 10 Perfs 10,825-10,963’ RT-THF: 34.2’ KB 7” @ 11,973’ 9-5/8” @ 10,461’ A 3 Pkr @ 10051’ 5 TOL 10,174’ 8 Rotating Hours Conductor 37 hrs 13-3/8” csg Total rotating hrs 359 hrs 9-5/8” csg Total rotating hrs 300.5 hrs 7” csg Total rotating hrs 174 hrs 2 C Fill 10,141’ Perfs 11,138’-11,450’ Calc TOC 10594’ B Calc TOC 8,651’ 6 7 11 Drilled out BP at 11,744’ 7777777777777777 Tbg Punch 9986’-9991’ Tbg Punch 9978’-9983’ ADL: 18746 PTD: 168-056 Leg 4, Slot 6 API: 50-733-20126-001A Cement plug #1: LS: 4,213’ MD’ - Est. 9,986’ MD SS: 4,160’ MD’ - Est. 9,978’ MD IA: Est. 4,000’ MD – Est. 9,986’ MD Cement plug #2: LS: Surface - 400’ MD SS: Surface - 400’ MD IA: Surface - 400’ MD OA: Surface - 400’ MD Rig Start Date End Date SL 8/9/22 9/21/22 08/15/22 - Monday Held PJSM. Filling upright #2 with FIW, while waiting on crew change, orientate personnel. Checking well pressure on DI 7 iA "0" TBG "0", D-12 (LS "0") (SS '0") (IA "0"), service equipment. Pumping oily water into D-17 injecting fluid from D-12 ,781 bbl. at 3.5 bpm at 2350 psi FCP 3030 PSI AT 450 BBLS PUMPED slowed pump to 2.5 bpm at 2500 psi, packing leaking finished injecting fluid. Rebuild other two cylinders on yellow jacket pump test run pump ok offload cmt pods from workboat. 08/14/22 - Sunday Held PJSM. Pumped out H-1 fluid tank injecting into D-17 at 3.5 bpm at 2500 psi holding 2200 on IA. Check pressure on D- 12 L/S 350 psi, S/S "0"and IA 80 psi OOA 20k, verify circulation up S/S, L/S, and IA pumping FIW at 3 bpm at 1100 psi. Pumped 73 bbls of FIW. Circulating down L/S X IA with 250 bbls of FIW at 3.5 bpm at 1150 psi hold 280 on choke catching 9.8 ppg brine in H-2. Pump out H-1 holding tank injecting 136 bbl of dirty water down DI 17 at 3.5 bpm at 2500 psi hold 2200 on IA. Held PJSM. Break with 5 bbls water test lines to 1000 psi and 3000 psi, pump 50 bbls mud push II, displace same with 126 bbls of 9.8 brine at 3.0 bpm at ICP 890 FCP 375, down LS X IA, then pump 10 bbls LS X SS. swap back to LS X IA total of 200 bbls, at 3.5 bpm 700 psi. Swapped to LS X SS and pump additional of 31 bbls at 3.5 bpm at 1375 psi holding 280 on choke. Mixed and pumped 414 bbls of Cl G Cmt 1495 sxs at 14.0 ppg with 1.56 yld, with 8.08 gal/sxs mix water, total water 287 bbls. pumping LS x SS at 87 bbls cmt, continue pump LS x IA for a total of 397 bbls, swap to LS X SS continue pumping additional 17 bbls total of 414 bbls cmt, launch wiper ball displace cmt with 35 bbls of 9.8 brine, shut down TBG pressure 250 SS at 140 bleed off to "0" well static. Calculated cmt job 469 bbl. total retruns to return tanks 475 bbl. Clean up after job. 08/09/22- Tuesday R/U circulating lines on LS, & IA, rev circ 4.5bbls till clean fluid, pump down LS 58 bbls till clean & good 9.8 brine, line up on ss circulate till clean 3.8 bbls. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 12 50-733-20126-00-00 168-056 pumped 414 bbls of Cl G Cmt 1495 sxs at 14.0 ppg with Rig Start Date End Date SL 8/9/22 9/21/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 12 50-733-20126-00-00 168-056 09/07/22 - Wednesday Held PJSM, approve PTW. R/u flanges and circulating lines, CMIT TxIA and recorded data. Pre=0psi, Initial=2744psi, 15min=2586psi, 30mins=2505psi,45mins=2448,60mins=2400psi. R/d circulating eq. Moved Eq. to Di-3. 08/27/22 - Saturday Held PJSM, Approved PTW Walk around check and service eq. Arranged deck. MIRU SL Unit on LS, MU 2" GR. wait on state inspector to arrive to witness tag. RIH and tagged @ 4213'slm. POOH. R/u on SS, M/u 2" Bailer and RIH tagged TOC @ 4160'slm, POOH sample of cement in Bailer. R/u circulating flanges and hoses to LS/SS/IA. R/u Test eq. Pumped 7.5bbls to pressure up, CMIT LSxSSxIA for 30mins, first test final leaking valve on manifold, retest LSxSSxIA and charted for 45mins, bled off 4.5bbls. MIT failed-witnessed by AOGCC Inspector Sean Sullivan Pretest: LS/SS/IA/OA=0/0/0/20 Initial: LS/SS/IA/OA= 2800/2800/2800/260 15mis: LS/SS/IA/OA=2500/2500/2500/235 30mins: LS/SS/IA/OA=2450/2450/2450/220 45mins: LS/SS/IA/OA=2400/2400/2400/210 R/u lines and test eq. on IA, Pressure up on IA and recorded pressures: Initial=2657psi, 5mins=2582psi, 10mins=2527psi,15mins=2482psi,20mins=2473psi, 25mins=2408psi, 30mins=2380psi.;R/u lines and test eq. on LS, Pressure up on LS and recorded pressures: Initial=2715psi, 5mins=2685psi, 10mins=2665psi, 15mins=2650psi, 20mins=2639psi, 25mins=2628psi, 30mins=2618psi.;R/u lines and test eq. on SS, Pressure up on SS and recorded pressures: Initial=2730psi, 5mins=2715psi, 10mins=2705psi, 15mins=2696psi, 20mins=2693psi, 25mins=2689psi, 30mins=2684psi. R/d test eq. 08/31/22 - Wednesday MIT failed-witnessed by AOGCC Inspector Sean Sullivan RIH and tagged @ 4213'slm. POOH. R/u on SS, M/u 2" Bailer and RIH tagged TOC @ 4160'slm, Rig Start Date End Date SL 8/9/22 9/21/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 12 50-733-20126-00-00 168-056 09/21/22 - Wednesday PTSM. R/U circulating lines & flanges on wellhead, unload cmt pods from boat, blow off into silos. Pump down LS out OA @ 1.6BPM, 500 psi, 2.5x bottoms up, pump down LS up IA 2x Bottoms up 2.6bpm, 500 psi, pump down LS out SS 2.9 bpm 500 psi. Prep for surface cmt plug, mix surfactant wash, PJSM. Fill surface lines, PT 500/2500 good. Pump 23 bbls surfactant wash, (10 bbls up OA, 10 bbls up IA, 3 bbls up SS ) 3 bpm, 400-470 psi. Pump, 26bbls 14 ppg cmt down LS out OA, pump 22 bbls down LS out IA, Pump 10 bbls down LS out SS, pump 6 bbls down L/S out OA @ 3-2 BPM 270-800 psi, getting cmt to surface out of each. Shut in well, flush all surface lines clean. Clean up cmt unit. R/D circulating flanges from wellhead & move to Di-15. 09/19/22 - Monday Pick up 1-11/16 wt bars, CCL, 2" gun loaded 5' with production charges 6.5 grams 6 spf, 30 shots total ( AOL 12 ft. , Max OD 2) RIH locate collars, at 428' to 398 ft. spot CCL at 400 ft., CCL to top shot 4' perf interval 404.0 to 409.0 ft. fired gun, pooh all shots fired. Rig down off leg 4 CMIT- LS x SS x IA to 2500 psi per sundry Pretest: LS/SS/IA/OA=38 / 38 / 38 / 50 BBL pump 1.5 Initial; LS/SS/IA/OA= 2800 / 2800 / 2800 / 235 15mis: LS/SS/IA/OA= 2582 / 2582 / 2582 / 205 30mins: LS/SS/IA/OA= 2480 / 2480 / 2480 / 198 45mins: LS/SS/IA/OA=2414 / 2414 / 2414 / 183 bleed bank 1.5 BBL AOGCC Brian Bixby witness test 09/10/22 - Saturday t 4' perf interval 404.0 to 409.0 ft. fired gun, CMIT- LS x SS x IA to 2500 psi per sundry Pump, 26bbls 14 ppg cmt down LS out OA, pump 22 bbls down LS out IA, Pump 10 bbls down LS out SS, pump 6 bbls down L/S out OA @ 3-2 BPM 270-800 psi, getting cmt to surface out of each. S 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: 12000 ft MD Lease No.: ADL 0018746 Operator Rep: Suspend: P&A: XXX Conductor: 26" O.D. Shoe@ 280 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 1586 Feet Csg Cut@ Feet Intermediate: 9 5/8" O.D. Shoe@ 10461 Feet Csg Cut@ Feet Liner 7" O.D. Shoe@ 11973 Feet Csg Cut@ Feet SS Tubing: 3 1/2" O.D. Tail@ 10034 Feet Csg Cut@ Feet LS Tubing: 3 1/2" O.D. Tail@ 11093 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Pre-Test Initial 15 min 30 min 45 min Result Tubing 38 2800 2582 2480 2414 IA 38 2800 2582 2480 2414 OA 50 235 205 198 183 Remarks: Attachments: Long and Short Tubing strings were twinned in with the IA for the test. Pressure loss was -218 psi / -102 psi / -66 psi. I told the company rep that town would make the pass-fail call. 1.5 bbls in, 1.5 bbls returned. September 10, 2022 Brian Bixby Well Bore Plug & Abandonment S MSG UNIT 12 Hilcorp Alaska LLC PTD 1680560; Sundry 322-377 Test graph Test Data: I Casing Removal: Howard Hooter Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 11-28-18 2022-0910_Plug_Verification_SMGS_Di-12_bb 7HVW5HVXOWFKDQJHGWR3$66EDVHGRQSUHVVXUHORVVGXULQJILQDO PLQXWHV-5HJJ$2*&&,QVSHFWLRQ6XSHUYLVRU 3 James B. Regg Digitally signed by James B. Regg Date: 2022.09.20 13:28:18 -08'00' 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: 12000 ft MD Lease No.: ADL0018746 Operator Rep: Suspend: P&A: X Conductor: 26 O.D. Shoe@ 280 Feet Csg Cut@ Feet Surface: 133/8 O.D. Shoe@ 1586 Feet Csg Cut@ Feet Intermediate: 9 5/8 O.D. Shoe@ 10461 Feet Csg Cut@ Feet Liner: 7 O.D. Shoe@ 11973 Feet Csg Cut@ Feet SS Tubing: 3 1/2" O.D. Shoe@ 10034 Feet Csg Cut@ Feet LS Tubing: 2 7/8" O.D. Tail@ 11093 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Balanced 9991 ft SS Tbg 4160 ft 9.8 ppg Wireline tag Fullbore Other LS Tbg 4213 ft 9.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2800 2550 2450 IA 2800 2550 2450 OA 260 235 220 Remarks: Attachments: Wade Hudgens Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): 200 lb Tool string consisted of rope socket, knuckle joint, 2x 45 lb weight bars, and hydraulic spangs (spangs/bailer when sampling). Visual inspection of cement sample from bailer: top foot very schmoo but solid at the tip . Completion Packer used in place of bridge plug. MIT Fail - exceeded max allowed pressure loss (10%). August 28, 2022 Sully Sullivan Well Bore Plug & Abandonment S MGS Unit 12 Hilcorp Alaska LLC PTD 1680560; Sundry 322-377 none Test Data: F Casing Removal: rev. 11-28-18 2022-0827_Plug_Verification_SMGS_Di-12_ss 9 9 9 pppy MIT Fail - exceeded max allowed pressure loss (10%). James B. Regg Digitally signed by James B. 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STATE OF ALASKA . MAR 092007 ALAS.IL AND GAS CONSERVATION COMMI f& D1 & REPORT OF SUNDRY WELL OPERATIONS' AGashCons. Commission nc Orage Stimulate Other.¡ Convert to Injector WaiverO Time Extension 0 Re-enter Suspended WellO 5. Permit to Drill Number: Plug Perforations Perforate New Pool 0 Perforate 0 4. Well Class Before Work: Development 0 StratigraphicO ExploratoryO 1680560 ServiceO 6. API Number: 50-733-20126-00 .- 9. Well Name and Number: Di-12 10. Field/Pool(s): Middle Ground Shoall"G" 1. Operations Abandon Repair Well Performed: Alter Casing 0 Pull TubingO Change Approved Program 0 Opera!. ShutdownO 2. Operator Union Oil Company of California (Unocal) Name: 3. Address: P. O. Box 196247 Anchorage, Ak. 99519-6247 7. KB Elevation (ft): 110' KB ABOVE MSL 8. Property Designation: 4(, fh . ø" Dillon ,A~ 1*1 ~... ,.,f. 11. Present Well Condition Summary: Total Depth measured 12,000' true vertical 10,461' j feet feet Plugs (measured) Junk (measured) Effective Depth measured 11,923' true vertical 9,443' feet feet Casing Structural Conductor Surface Intermediate Production Liner Length Size MD TVD Burst Collapse 1,587' 13-318" 1,587' SQ\NNED MAR 2 0 2007 10,439' 9-518" 10,439' Perforation depth: Measured depth: 10825-10840',10915-10950',10963-10988',11060-11065', 11076-11081',11102-11275',11305-11390',11405-11450' True Vertical depth: 9,365-9,3799,451-9,4849,496-9,5209,588-9,593, 9,604-9,6089,628-9,791 9,819-9,8999,913-9,956 Tubing: (size, grade, and measured depth) (See Attached Well bore Schematic) Packers and SSSV (type and measured depth) BakerMod. 'F1' Packer@ 10,174' 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 Gas-Met Water-Bbl Casing Pressure o 0 55 o 0 55 15. Well Class after work: ExploratoryO 16. Well Status after work: OilO Gas 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl Tubing Pressure Prior to well operation: 0 Subsequent to operation: 0 14. Attachments: Copies of Logs and Surveys Run none Daily Report of Well Operations o o Development 0 Service 0 ' WAG 0 GINJ 0 WINJ 0 WDSPL Sundry Number or N/A if C.O. Exempt: o Contact Larry P. Greenstein ¿Jp¿~~/t;/ Printed Name Larry P. Greenstein Title Production Technician Signature Phone 263-7661 Date 3/8/2007 Form 10-404 Revised 04/2006 ORIGINAL ..41> "$.1(,..07 !&;\...., ~ < /- Submit Original Only ~ P/~/or f..ertfM(lt Qat..$. Spud Dota: Surlo~ location: SuIaurlOM location: EJ.-,atlan: TtI: f'8O~ Co.lng: P&rforat/Cln.: Inltløl Potential: Initial stimulation: .B..eørvoIr Da~a.=-- Cored rnt.va18: tlST Intel'\'Gl8 and RelUltI: lDg I".,."tory: SOUTH MIDDLE GROUND SHOAL ADL 18746 WELL NO. 12 HEMLOCK CONGLOMERATE PLATFORM DILLON 812M! 1Þ9 4, Slot 8 873' FSL. "e:u' ~ s.c. 35, T8N. R1:w1. S.M. Tt) - 82' f'EL. 4-431' FNL. Sec. 3, T7N, Fe13\\', Uf. 110' I<B 12000' 1VD 10481' ~ ~ '~3' 'NO '.43' 1) JIB", 5(.51 Co.lnJ ..t at 1587' \WIth 1770 .. ~m.nt ø M", .0 and 43-'1 N-8Q ond s-e5 Colfn, Nt at 10.39' wfth 1060 III ~1MtIt .,.. 23 and 281 $-95 U"., Nt at 10174-11873' with 360 III ~ment /', "."}.".,") t..!-:;I\ 0-1: 10825- 1 D840' 0-2: 101115- 1 09~' 73 10983-10988' 0-3: 1 1080- 1 1 Qe5'. 1107S-11081'. ¡ ~. '.:' 11102-11275' 0-.: 11305-113V0' 1'10 1 1405-1 ~ 4SO' /./f.~.~' l/,,<'r , ~ .Cement SqtMeZ~ 881 BOPD, 337 BWPD, 2.48 uern None None None I£t-SP, BHc-oR. CR 1 V:Zo4lS8, ~ M0I70, trocer-t.m~ J/JO/7%. ~"""'*' 711817J, tnJger-temperatllre 12/11173, tracer-tempenIture 10131174, AA tracer profile 1V22177, 1 Q/11J79, 712&183, 1/23/85 .E!rY1p'-tlcn ~eç~~- Lcn9 Str(~: 1. Cameron 10" Nom Dual tubIng hotlVV 2. 3 112" ~. tubing pup 3, 3 112" Buttre.. tubIng w/AB coupll!1g. 4. 3 112- Buttre.. and 2. 118" Buttr.J. xo '- 2. 7/8" Buttru. tubing pup S. 8.r parallel flowMGd a 118" cd 7. 2. 7/8" Buttreaa tubing W/AB ooupd!1p !. 2. 7/8" euttt.8. pup L t. 2 7/f1' Bok.r 'f' nIpple 2.251d 10. 2. 7/8" Buttnm and J 112" euttre.. XO 1 1. S.aI locator 12. Seal a_mbly 13. Bull no.. ~.or out .ub Shcrt Sttf!1g: A. 3 1/2" Butnu tubing w/AS coup"!1g. B. J 112" auttre.. and 2. 7;8" au~' XO C. 2. 718" Buttre.. pup It. D. Ba.,2 718" R-Nlpple 2_197 Id. Oeptto 35' 31' 1003~' 10036' 100.¡e' 10041' - 1 10Sf' 11 089' 11070' 11071' 11072' 11093' 11094' 10033' 10034' 1oo.¡e' 10041' Baker Mod.! F-1 pier wi"" bore Baker Sea! 0'11)' .tcbbeicr thlOugh pier but not attøched to low.. tbg. <.... nm fl/U!a4) /2 L. - ¡,hi"'Ù/"'<' /·/r7 O¡?S1";i'Jc rr"·.,; e /(J,oZ7 9 518" 40 ok 43.51 CSA 10439' 11 Baker ,fod.1 F-l pia' 12. PBO "923' TtI 1 2000' 1# ~ 2 J A 13 ;vB" 54.51 CSA 1 M7' . B . ! ø 10 0825-10840' 1ot15' 1098S' 1106/)' 110S1' Re: Pull 213-10 & Di-14 off report - 2006 Fourth Quarter's LTSI We... . . One followup to our phone call earlier today; I spoke with Bob Fleckenstein about 10-404; 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). So, what we need :ITom you to clarify the files are: 1) 10-404 for Di-12 to change well from producer to injector (status will be lWINJ) 2) revised 10-404 for Di-14 to change well from producer to injector (status also 1 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" I 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 well 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. 1 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. Di-14 is a little different. This well was successfully tested and Admin Approval #8.2 converted it (along with Di-12) into a Class II disposal well. Turns out we only used Di-12 during the intial disposal operations, so this we!! sat ready as a back-up. Didn't want the idling of the platform to affect this M, so ¡ added this well (along with Di-12) to the L TSI group. I would be glad to continue reporting this two 'different' wells anywhere you would like. 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 CI that has a specific MIT requirement...let 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 [ma¡¡to:jim reqq@admin.state.ak.us] lof3 3/16/20073:13 PM Re: Pull 213-10 & Di-14 off report - 2006 Fourth Quarter's LTSI 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 TSI 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 TSI 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. ~ ~,tJ 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 TSllist 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 report of daily pressures be sent to the AOGCC, which seems to contradict your e-mail. Are we OK with not following rule #4 based on your e-mail?? Thanks Jim La rry From: James Regg [mailto:jim 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, Larry P wrote: 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 Re: Pull 213-10 & Di-14 offreport - 2006 Fourth Quarter's LTSI We... . . Attached is the latest update from Steve Lambert on the other two wells that seemed to show communication between the 9 5/8" and 13 3/S" casings. The seals in both trees test out as OK, but both wells still appear to have some annular communication. The 9 5/8" pressure was bleed off in G-09 to under 10#, but both annu!ií dropped and stayed low. The 9 5/S" in GP 33-14RD well was also bleed off and returned to the 13 3/S" pressure quickly to confirm communication in this well. Both of these wells are being turned over to the mechanical integrity guy in the drilling group to begin their assessment procedures. All the other wells appear to be fairly stable and show no indications of any well integrity problems../\r¡ Larry ~\g<loJ '\)~ v «Master Well List TIO Report 200612 31.xls» communication» «RE: L TSI well casing 30f3 3/16/20073:13 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 to be use for injection, a 10-403 needs submitted to convert the well. Steve Shehata, Danny wrote: .e p (' Steve, When did it chmlge? Can you please send me paperwork on this well changing the field and pool? Everything r have suggests this wen should be reported in field and pool 524114. The only well r see in the AÜGCC 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. Danny 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 dannys@chevron.com ..........·......_................._m........................_m...._.......mn_.__................ -----Original Message----- From: McMains, Stephen E -AOGCC Sent: Friday, March 31, 2006 10:12 AM To: Don Page Cc: janet dormadYi Danny Shehata Subj ect:. Disposal 1 of? 4/pnooó O'Só AM K\::: l.J1SpOSäl 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 /løF-()5' & FRANK H. MURKOWSKI, GOVERNOR A",A~1iA. OIL AND GAS CONSERVATION COMMISSION 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 \' {(" I:¡'~"'¡' ÍÍì.\ (¡:(") "\ûN)~ij'\,!<". ,~~ ¡;~ 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 approved wells on Dillon Platform. Production operations ceasect on Dillon in December 2002 and Unocal "cleaned" the production equipment on board the platform l.ìl ~arly 2003. Prior to initiating the cleaning operations, Unocal sought administrative approval under Area Injection Order ("Ala") 8 to dispose of liquid wast~s in either of two existing enhanced recovery ("EaR") wells on the platform. Injecting wastes into an EOR well is prohibited by Commission regulations. However the Commission determined that the liquids, mostly water and oil with some detergents, would not be damaging to the reservoir. AIO 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 includè 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 Ala 8 and Administrative Approvals AIO 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. 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 REC IVED MAR 2 1 2006 March 21, 2006 Alaska Oil & Gas Cons. 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 COrTIm!!;sioner Norman: The purpose of this docum¿:"t is to communicate to you the scope of work proposed on Dillon Platform during 2006 and subset.¡t.:I'mt work seasons by Union Oil Company of California (UOCC), an indirectly owned subsidiary ~f Chevron Corporation, and the disposition of the associated waste streams. Attached 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 !t¡at 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, , 'lf~~~~ 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 ¡.": e e Description of Proposed Dillon Platform Well and Pipeline Work and Related Waste Disposal Purpose Project Type and Planned Timeline Waste Streams by Project and Planned Disposition The purpose of this docwnent is to provide an overview of the proposed Union Oil Company of California (VOCe), an indirectly owned subsidiary of Chevron, Dillon Platfonn work scope as requested by Mr. Tom Maunder. The following is a list of the project types and the possible timeframe: Year 2006 Future Future 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 Production Offsite disposal at Commercial Dillon Pipelines Test Separator and Disposal Vendor, likely G&I in Shaker Texas at Newpark, or contingent disposal ifUOCC has a Class II (or Class 1) Disposal Well set up for G&I such as NNA #2 Clean Baker Gas Pipeline Residual Trapped Gas Vent, maximwn amount based on total pipeline volume, actual volwne 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 Onmi-Pure System followed by Work NPDES Discharj1;e Both Pipeline & Well Clean Trash KPB Landfill Work Continued on next page ( . 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. 1- . ') ) ~~~~! :F !Æ~!Æ~~~!Æ ATtASIiA OIL AlVD GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7fH 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 '70 \ ~.}~( 0 Re: Middle Ground Shoal Unit Platforms Dillon and Baker Dear Mr. Cole: This letter confirms your conversation with Commission Engineer Tom Maunder last week regarding the multiple Applications for Sundry Approval (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. . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this _day of November, 2004 Enel. SCANNED NO\! 2, 4 20Dl} , t. Type of Request: 3. Address: 7. KB Elevation (ft): 110' KB ABOVE MSL 8. Property Designation: Dillon 11. Total Depth MD (ft): 12,000' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 10825 to 11450' Packers and SSSV Type: 16. Verbal Approval: Commission Representative: '\ STATE OF ALASKA ) AlA~_.Á Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: RECEI 0 OCT 1 2 2004 Suspend U Repair well D Pull Tubing D Perforate LJlaska Oil &!@)w CdnS.tt)D~BÏ§RR~' U Stimulate D Time ExterAfRmGihge Other 0 Re-enter Suspended Well D Monitor Frequency 5. Permit to Drill Number: Exploratory D 68-56 Service 0 6. API Number: /'/'~ /' 50-733-20126:9»' ,,// ,/1" ",f'f ,;1' // /F PRESENT WELL CONDITION SUMMARY /1 Effective Depth MD (ft): Effective Depth TVD (ft): I~PIUgS (measured): 11,923' 9,443' / MD /TVD Burst ./ / / / / I' I 1,587' / 101439' 11,9 ' Tubing Size: LS : 3 A" SS: 3 1/2" / Packers and SSSV MD (ft): 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil D Gas D WAG D GINJ D P. O. Box 196247 Anchorage, Ak. 99519-6247 Development Stratigraphic D D Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil of California aka Unocal Baker Mod. 'F1' Packer Baker seal assembly 12. Attachments: Description Summary of Proposal ~ / Detailed Operations Program D BOP Sketch D / 14. Estimated Date for / Commencing Operations: 9. Well Name and Number: Di-12 10. Field/Pools(s): Middle Ground Shoall"G" Total Depth TVD (ft): 10,461' Length Size 1,587' 10,439' 133/8" 9-5/8" 7" Perforation Depth TVD (ft): 9,365 to 9,956 Tubing Grade: D Plugged WINJ Date: 17. I hereby certify that the foregoing is true and correct 0 the best of my knowledge. Contact Title Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY Printed Nam¡; . D)7 Cole Signature ¡(:/a()-d.f/(i ~ Conditions of approval: Notify Commission so at a representative may witness Plug Integrity 0 Other: Subsequent Form Required: Sundry Number: BOP Test D D Mechanical Integrity Test Location Clearance R8DMs 8FL Nav 2 2 2004 G\ N ~ l OR\ ,~/-:.. Junk (measured): Collapse Tubing MD (ft): LS: 11,094 SS: 10,047 10,174' 11,093' Service 0 D D Abandoned WDSPL D 0 28-Sep-2004 ~) 0 y'- (I'd- L( APPLICATION RETURNED 11/17/04 NOT APPROVED BY COMMISSION COMMISSIONER BY ORDER OF THE COMMISSION Date: Approved by: I{q;¿ Form 1 O~evised 12/2003 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS:=EB 262004 ?:,~.;("" C" .".:'. ~ 't... ~-- ¡j""" >b. (~ "" ~ ~ ~ .I ,,""'" i4 t .,"~. -. ~ \r L,.2 L./ '" . 1. Operations Abandon U Suspend U Operation Shutdown U PerforateU'~C: .1\0 !.</ .' Wã~èit!.nS. CO¡11P,',,:sÎcHther 0 Performed: Alter Casing D RepairWell D Plug Perforations D Stimulate D Time E~~~~. Shut in and secure Change Approved Program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Union Oil of California 4. Current Well Class: 5. Permit to Drill Number: Name: aka Unocal Development D Exploratory D 68-56 3. Address: P. O. Box 196247 Stratigraphic D Service 0 6. API Number: Anchorage, Ak. 99519-6247 50-733-20126-00 7. KB Elevation (ft): 9. Well Name and Number: 110' KB ABOVE MSL Di-12 8. Property Designation: 10. Field/Pool(s): Dillon Middle Ground Shoal/"G" 11. Present Well Condition Summary: Total Depth measured 12,000' feet Plugs (measured) true vertical 10,461' feet Junk (measured) Junk @ 10,087' Effective Depth measured 11,923' feet true vertical 9,443' feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,587' 13-3/8" 1,587' 1,560 Intermediate Production 10,439' 9-5/8" 10,439' 9,003 Liner 1,799' 7" 10,174-11,973 8761-10,452 Perforation depth: Measured depth: 10825-10840', 10915~10950', 10963-10988', 11060-11065', 11076-11081', 11102-11275', 11305-11390', 11405-11450' True Vertical depth: 9,365-9,379 9,451-9,484 9,496-9,520 9,588-9,593, 9,604-9,6089,628-9,791 9,819-9,8999,913-9,956 Tubing: (size, grade, and measured depth) Dual 3 1/2" @ 10,047' Single 3 1/2" @ 11,094 Packers and SSSV (type and measured depth) BakerMod. 'F1' Packer @ 10,174' BakerMod. 'F1' Packer @ 11,093' 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: 502 0 2400 Subsequent to operation: Shut in subsequent to operations 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory D Development D Service 0 Daily Report of Well Operations 16. Well Status after proposed work: .._fI öITLr"~ Gas D WAG D GINJ D WINJ D WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Printed Name P. M. Ayer ,. , ,. ;;(' .,r-"'" Pll ~ ~ ~ @ 2004 Title Petroleum Engineer Signature 0 'IIAI1~~'~I\ ,1M ~~, I {'... ",. ~-' Phone 263-7620 Date 18-Feb-2004 Form 10-404 Revised 12/2 ~03 OR'!G'~'¡A,~BFl FEB 2,' . f..~t ~ Spud [)atl: Surface locatfon: SUb8Utfoø Locatfcr:: Elevatton: TO: P80: Ca.mg: Putorctlenl: Inlttal Potential: In!tIcl StIm:lfatfon: .R..~rvotr Do~a.L Cored InteM1t8: DST tnterwt8 and RUI,lIt8: l.o9 Inventory: SOUTH MIDDLE GROUND SHOAL ACt 18746 WElL NO. 12 HEMLOCK CONGLOMERATE PLATFORM DILLON 8128168 Lq 4. Slat 6 673' FSL. , 163~' FW4 Sec. 35, T8N. R13W. SJf. TO - 82' FEL. 4431' FNl. Sec. 3, T7tJ. R13W" S.U. 110' KB 12000' 'NO 1048" 11923. 'Nt) i«3' 13318", 54-.5' CG.!n.9 Mt at t587" wtth 1770 tX ~tMftt ø 518". -40 end 43.11 N-8Q and $-95 Cvmg Nt at 10439' trfth 1060 IX eøtent 7'" 23 and 281 S-SS Un8r set ot 10174-118". with 380 IX eern.nt Q~y. ,-;-"..,,¿J f..l~ .:- ;~ '<.j~" 0-1: 1082S-tÐ8<40. 0-2: 1081&-10950. 10983-10988' 0-3: , 1080-1 1085'. 11076-1 ~081'. 11102-1 '27S. 0-4: 11305-11300' 11405-1 ~450' / S 73 .1!~ 1"1 ~. .c.ment SquMnd 881 BOPD, 337 BWPD. 248 UCFD None None None a-sp. BHC-cR, aft 1'124/68. trocw tV20170. trocer--~ 3130172. trocet-.,tnner 711S173. trac8r-ternperotuN 12111173. tracer-temperature 10131174. RA tracer pr'DfI\e 8122/77. t0l11n9, 7128183. 1/23/85 ~~.~~~an . ~..~~ Lent Strll\g: 1. Cœneron 10" Nom Dual tubtng hatlg.r 2. 3 1/2" Buttre.. tubfng pup 3, 3 t/2" Buttret. tubing v/AB COupJfng8 4. J 1/2" 8uttreu and 2 718" 9uttreJ8 XO 5. 2 718" Buttreta tubing pup 6. 8ak1t parallel flowhead . 1/8(1 ad 7. 2 7/8" Buttreø tubtng W/ÞB couplIß98 8. 2 7/8u Buttrua pup Jt. 9. 2 7/r Boker'" ntpp18 2.2:!11d 10. 2 718" Buttren and 3 112" Buttreta XO , 1. Seal locator 12. 5.01 anembly 13. 8ull no.. 8h.or cut aub Short Strfng: A. 3 t/2" Buttreta tubtng w/NJ caupfLI'Ujl8 B. :) 111" 9uttreta ond 2 718'" Buttrell XO C. 2 7;'8" Suttreta pup It. D. aak8r 2 7181' R-Nfppf. %..197 1d. (~ nm 811718~) /2 L.. - t-h/Û..h.r£ /.1/7" ()ß,j"r¡å.lc. r~a.'Ý'(~ IO,oZ7 Depth J5' 31' 1 003~' 10038' 10048' 10047' - , 1 OS8' 11068' 1 , 070. 11071' t 1 072' , 1 093' , 1 094' 10033' 10034' t 0048' 100.47 Baker Mode! F-1 pier ../6" bore Bckv See! alllY Itabbecr through pier but not attuched to low.. tb9. 8 5/8" 40 - 4J.51 CSA 10439' 11 Baker ),foô" r-1 pkl' 12 PaT) 1 192~' 11) , 2000. 2 3 It. 13 3Ir 54.51 CSA 19r 0825-10S40' ,1'0115' 0 10888' :, 1 oeo' 11081' 11102-11215' DILLON PLATFORM API # 50-733-20126-00 S. MGS UNIT # 12 WELL HISTORY Well #12 DATE COMPLETED 1968 1/13 EVENT Completed as an Oil Well. 1970 4/9 Completed as a Water Injection Well. 1972 7/21 Acidize/perforate 1980 9/15 Remove junk in hole. 2003 01/29/2003 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. 01-5 -;:S~ 1:2~ ~ 01- 3 25 bbls 20 x 13 518 0.1815 300 54.45 31/2 tbg. 0.0087 300 2.61 18 5/8 x 13 3/8 0.1291 300 38.73 27/8 tbg. 0.00579 300 1.737 13 3/8 x 9 5/8 0.0671 300 20.13 depth 656 334 9 5/8 x dU8. 3 1/2 0.0507 300 15.21 355 9 5/8 x dU8. 2 7/8 0.0571 300 17.13 pump limit 21 psi 9 5/8 x 3 1/2 0.0628 300 18.78 Don Sta dual LEG ROOM '1 IG :0/0 A .~ ~/U -- ---,- 13 3/88 X 9 5/88 9 SIt/' x 31/2' 28 bbls 22 bbls ......... 15.5bb1s 30 bbIs 1 bbII 3 bbIs no ~10 01-13 LEGROOM.F.- 01-18 1.2 bbI 2ØbbI$ 01-17 0.75 bbls 15.5bbls 20 bbIs 01-16 15 bbls 20ÞÞIs 01-11 7;4bbls 01-8 25 bbIs Q!:L ABN-6 lEG ROOM'" ~ wen 112 wellN w.n n w.nll10 Wen 1113 Wen 117 wen tI8 w.n 1111 wen 818 w.n17 Wen 818 wen 113 Wen 85 Wen" 12 Wen 1114 w.n 1115 WELL BAY # 1 Pumped down tbg.tbg on vac, bled down 9 5/8 x tbg. Pumped 28 bbls. Gas still at surface. Pumped down 2Ox135/8 2bbls 100 psi. 20 bbls in 133/8, Try to pull eclipse poker with wire line could not get out. Well had 180 on annulus and 150 on tbg would not bleed down, Tryied pumping down short side old pump in hole could not pump. Put 30 bbls of 9.8 in annulur 9 5/8x tbg. Pumped down I.s. tbg. Returned up short side 100 bbls. 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 3.8)( 9 5/8 p'ump and bleed 3 bþ~ i~ an~. 9 5/8xtbg fluid packed with oil. 14A bblsin tbg. well 10 Is abondoned Fill 20" ann 2 bbls, tbg on vac 7bbls In 13 3/8 x 9 5/8 28 bbls 9 5/8 x tbg. 5 I.s. 5 s.s.bbls down short side did tbg. And ann same time WELL BAY # 2 20" fluid packed,13 3/8 x 9 5/8 2 bbls and started getting diesel fluid back to surface. fSumped Sbbls in tbg.' 20 bbls in 9 5/8 ann.Annulus and tbg. Have oil returns 0 press on well. 20" fluid packed,13 3/8 x 9 5/8 2 bbls and started getting diesel fluid back to surface. Pumped Sbbls in tbg.' 20 bbls in 9 5/8 ann.Annulus and tbg. Press up to 500 psi. on both tbg. Strings had of to top no press on tbg. Pumped and bled 7bbls in tbg. Annulus. When annulus was fluid packed. Oil at surface.5 bbls in 13 5/8 x 9 5/8 press limit. .5 bbls In 20" Well had SOpsl. On 13 3/8x 9 5/8 bleed down to 20psi put bbls of 9.8 fluid, 95/8onn. 20 bbls fluid, tbg.5bb1s each, wells 185/8 has 110 psi. bled off and fluid packed with press limit of 50 psl..75 of a bbl. Well had l00psl. On 13 3/8x 9 5/8 bleed down to 20psi put TSbbIs of 9.8 fluid, 95/8onn. 20 bbls fluid, tbg.5bbls each, wells 185/8 has 60 psi. bled off and fluid packed ann with .75 bbls. Well had 150psl. On 13 3/8x 9 5/8 bleed down to 20psi put 20bbls of 9.8 fluid, 95/8onn. 20 bbls fluid, tbg.5bb1s each, wells 185/8 OOs25 psi bled off and fluid pocked with 9.8 sa" took 1.2 bbls. WELL BAY # 4 Rig up pump 4 bbls 1.5. 4 bbl 5.5. 9 5/8 x tbg. 25 bbls, 13 3/8 x 9 5/8 fluid packed w 112 bbls, 20" ann. 2 bbis. Auid pocked Pumped 4 bbls I.s. tbg. 4 bblss.s.R/u to 9 5/8 x 3 1/2 ann. Pumped 15 bbls fluid packed oil to surface. Pumped 4bbls down tbg Is, 4 bbls s.S. both went on vac. Pumped 15 bbls 95/8 x31/2. W'1fh50 psi press limit 0 bbls in 13 3/8x 95/8 Fluid pocked 20x 133/82 bbls, Auld packed 13 3/8x9 5/8 12 bbls press up to 200 psi and held. Rig up pump 5 bbls 1.5. 25 bbl 5.5. Be 9 5/8 x tbg. 8 bbls fluid packed 011 to surface 13 5/8x9 5/8, RIU 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 Di-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. Enclosures Aogcc SMGS Dillon - Application for temporary disposal.doc SG,~NNED FEB 0 A 2003 Sincerely, Philip M. Ayer Advising Petroleum Engineer RECEIVED JAN £ 2 2005 Alaska 0ii & Gas Cons. Commission Anchorage jjd STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: Temporary Disposal 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: 110' KB ABOVE MSL feet 3. Address Exploratory: ~ 7. Unit or Property name Stratigraphic: PO BOX 196247 ANC, AK. 99519 Service: -~' South Middle Ground Shoal 4. Location of well at surface Leg 4, Cond. 6, Dillon Platform 8. Well number 673' FSL, 1763' FWL, ~ec. 35-TSN-R13W-SM No. 12 At top of productive interval Hemlock @ 10,824' MD 9. Permit number 1,230' FSL, 116' FEL, Sec. 3-T7N-R13W-SM 68-56 At effective depth 10,000' 10. APl number 1,545' FSL, 35' FEL, Sec. 3-TTN-R13W-SM 50-733-20126-00 At total depth 11. Field/Pool 862' FSL, 60' FEL, Sec. 3-T7N-R13W-SM Middle Ground Shoal/"G" 12. Present well condition summary Total depth: measured 12,000' feet Plugs (measured) None true vertical 10,461' feet Effective depth: measured 11,923' feet Junk (measured) None true vertical 9,443' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1,587' 13-3/8" 1770 Sx 1,587' Intermediate Production 10,439' 9-5/8" 1,060 Sx 10,439' Liner Perforation depth: measured (see Attached Wellbore Schematic) true vertical Tubing (size, grade, and measured depth) (see Attached Wellbore Schematic) Packers and SSSV (type and measured depth) BakerMod. 'Fl' Packer @ 10,174' 13. Attachements Description summary of proposal: Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil: Gas: Suspended: SCANNED FEB 0 ~ 2003 Name of approver Date approved Service: X l) ~ ~ ? ~, s ~ 17. I hereby certify that the foregoi~jlis true and correct to the best of my knowledge. Signed: Title: Advising Petroleum Engineer Date: 01/21/2003 ' - '"/ ~/ FOR COMMISSION USEONLY Conditions of approval: Notify Commission so representative may witness IApprov,~ ~ Plug integrity.__ ~JOP Test Location clearance __ Mechanical Integrity Test__,~_ Subsequent form required 10-~ ~ ~ ~., · , JAN 2 2 2005 Approved by order of the Commissioner M L. BillAlaska 0il & Gas Cons. Commission -- C orr~ll~01r~go Date Cover letter at \Vkk-Anchorage\Groups~AOGCC\Correspondences~,ogcc Di 12 SI MIT 12-11-01 .doc Form10-403 Rev 06/15/88 ~B0~S BFL ~_~/.""~'-~ ~yj ' JAN 3 0 2003 / SUBMIT IN TRIPLICATE 40 0 1000 2000 3OOO 4000 5OOO 6000 7OOO 8OOO 9000 6O injected 1,394 barrels 72 degree water 2 Temperature Surv Di-12. Temp Degree F 80 100 120 140 160 ~RIH 21/17/2003 I + 03:00 hrs In - POH 01/17/2003 I + 09:21 hrs. Out ........ RIH 21/18/2003 I + 11:00 hrs. in POH 21/18/2003 I + 17:52 hrs. oUt 10000 11000 / Jeff Dolan 1/21/2003 7:16 AM \~Ak-anchorage\groups\OOE\OOEFields\MGS\Dillon\Wells\Di- 12\Surveys\Temperature\Di 12 QT composite 20030118.xls Temperature chad Pressure Su Pressure PSiA 0 500 1000 1500 2000 2500 3000 3500 1000 2OOO FL casing after 1,144 bbls into LS 583'~'' ~""-RIH 01/17/2003 I + 11:00 hfs In ~ POH 01/17/2003 I + 03:00 hrs In ........ RIH 01/18/2003 I + 11:00 hrs In POH 01/18/2003 I + 17:52 hfs Out 3000 FL casing after 535 bbls into LS 2,650' /, 4OOO FL casing at start 4,002' 5000 6000 7000 8000 9000 10000 11000 Injected 1,394 barrels 72 degree water Jeff Dolan \~Ak~anch~rage\gr~ups\~E\~EFie~ds\MG~\Di~n\~e~s\Di-12\~urveys\Temperature\Di 12 QT composite 20030118.xls 1/2112003 7:29 AM Pressure chart Spud Z~ts: Surface Locegon: Subma~aee LocalJo~: Devotion: TO: FaO: Co~lng: P~rforel~enl: SOUTH MIDDLE GROUND SHOAL ADL 18746 WELL NO, 12 HFJ~LOCK CONGLOMERATE PLATFORM DILLON 8/28/6B Lag 4. Slot 6 673' F~L. 1763.~' IrWL. ~e. 35. T~N. RI3W. SJ~. TD - g2' FT:L. 44~g' FNL. ~a. 3. TTli. R1 110' KB 12000' ~ 10461' ~ ~023' 1~) J443' 13 3/B", 54.~ ¢odr~ set at 1587' wlt~ 1770 ox ~t O ~VB*** 40 and ¢3,5lll N-80 and S--g5 Cedflg sot at 10439' wt~ ! 060 ex 7~ 2:~ and 2(~ $-95 Llml~ set at 10t74-~ 1073* wlt~ 360 ex cement G-I: 10825-10840' ' 0-2: 1091~-10050' 73 1006~-1 O--~: 11060-I 1065'~ 11076-11081 '* 11102-~.1275' 0-4: 11:305-11390' 11405_1 ~. 450, .Cement Squeezed 881 BOPD, 337 gWJ~. 248 MCFD None 1. C~fl 1~ Nam Dual ~b~g hoflg~ 2. 3 1~" B~o ~Mng pup 4. 3 1~" Bu~, and 2 7~" B~l XO ~ 2 7~" ~ ~M~ F~ 8, 2 7~" B~e pup J~ 10. 2 7~" Bu~a end ~ 1/2" ~ XO 11, ~ I~tor 12. ~ =e~m~ Shor~ String: A. 3 I/2" Buttre~ tubing *~Afl aoupllng~ 9, ~ 1~" ~e and 2 ~" ~o XO ~ 2 7~" ~. pup it. D. Bo~r 2 7~" R-~e 2.107 id. (Aa ~ N~ .oar--temperature 12/1 I/'/3, troeer-tempemtu~ 10/31/74, tro~er profl]~ eV22/7'/. 10/I 1/'70, 7/2Bv'83, 1/23/85 10035' 1 10048' 10047 - 11059° 11069~ 11070' 11071' 11072' 11093' 11094° 1 100;34' 10046' 10047 Baker Model F-1 pkr ~/~" bom Boker Smd Qouy Itobbed" though pl(c but n~t ~ttoeh~d 0 5/8" 40 & 4~ csx IO4~0, Baker Model F-1 pkr TI) 12~00' Urm'~ e'. 10174~ 10825-10940' !10915* 11 11081' 11102-11275' 11305' SCANNED FFB 0 A 21 03 Note To File Re: Sundry Approval # 303-021 South Middle Ground Shoal Unit #12 (Dillon12) PTD: 168-056 APl #: 50-733-20126-00 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 12 (Di-12) as a disposal well. Unocal has also identified Dillon Well 14 as an alternate candidate for disposal service should problems be encountered with Di-12. 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 1400 barrels (bbls) of heated sea water was pumped into this well at rates between 0.75 and 1 barrel per minute (bpm) with a surface pressure of about 1400 psi. No pressure was observed on the inner annulus (IA), however it was reported that the fluid level in the annulus did slowly rise 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. No anomalies were noted on the logs. Given the injectivity test performance and the temperature logs, reasonably demonstrated that Di-12 has mechanical integrity. sundry 303-021 is recommended. Unocal has Approval of 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. Tom Maunder, PE ',.. SG,~ED [:~B 0 & 'Z~3 Sr. Petroleum Engineer January 29, 2003 [Fwd: Unocal Dillon - D-12 Injectivity Test and MI Request] Subject: [Fwd: Unocal Dillon - D-12 Injectivity Test and MI Request] Date: Fl'i, 17 Jan 2003 08:07:57 -0900 Fr.,om: Tom Maunder <tom_maunder@admin.state.ak.us> To: Daniel T Seamount JR <dan_seamount@admin.state.ak.us>, Mike Bill <mike_bill@admin.state.ak.us>, Cammy Oechsli <Cammy_Oechsli@admin.state.ak.us>, Jim Regg <jim_regg@admin.state.ak.us>, Bob Crandall <bob_crandall@admin.state.ak.us>, John D Hartz <jack_hartz@admin.state.ak.us> All, Enclosed is the latest message from Phil Ayer at Unocal. He has kept searching for a well that might meet the necessary criteria and he may have found one. Di-12 is an injector and it appears that they may have demonstrated MI. He has performed an injectivity test and from the information he has provided, it appears that this well has passed a MIT. Their rate was about .75 bpm and he indicates that there was 0 pressure on the IA. Demonstrating MI via observation is acceptable and I can support acceptance of this information. What are your thoughts?? I indicated to Phil in a message that this information was encouraging and that I would forward it on. One remaining task we would have would be to do the file review. Any comments and suggestions would be appreciated. Tom Subject: Unocal Dillon - D-12 Injectivity Test and MI Request Date: Thu, 16 Jan 2003 20:53:46 -0800 From: "Ayer, Phil M -Alaska" <pmayer@unocal.com> To: "tom_maunder@admin.state.ak.us" <'tom_maunder@admin.state.ak.us'>, "winton_aubert@admin.state.ak.us" <'winton_aubert@admin.state.ak.us'> CC: "Dolan, Jeff J" <dolanjj@unocal.com> Tom An injectivity test is currently being performed on Di-12. Injection began at 10:00 p.m. on 1/15/03. A total of 370 bbls of 72 degree water has been injected as of 1:00 p.m. today. Injection rates down the LS have been in the range of 950 b/d at 1400 psig with 0 psi.q on the casing/tubing annulus. The well is indicating that tubing/packer mechanical integrity exists as there is a 1400 psig differential between the tubing and the annulus with no indication of flow. Unocal requests MIT approval on this well based on the injectivity data attached. If needed, we intended to follow the injectivity test with static temp survey(s) but since the well is indicating pressure integrity we question whether the temperature surveys are needed. There is a real risk of sticking the temp tools in this shut-in injector so if it is not necessary we would rather not run them. In addition a w/I gauge run on 1/4/03 could not progress beyond 5,129' and this may preclude a survey form beyond this point. If on the other hand we need the temp surveys, the time to run them is immediately after the injectivity test which should end tomorrow evening. Your prompt review of this matter is requested. I will call tomorrow to discuss. Thank you. Phil SCANNED FEB 2003 Phil Ayer Unocal Corporation 909 W. 9th Ave, Anchorage, AK 99515 email: pmayer@unocal.com 907-263-7620 (work) 1 of 2 1/28/2003 10:21 AM [Fwd: Unocal Dillon - D-12 Injectivity Test and M~L~,equest] 907-250-2711 (cell) 907-263-7847 (fax) ......................................................... #12 Hot Sheet.xls I Name: Well #12 Hot Sheet.xls t ~ DWell Type: Microsoft Excel Worksheet (application/vnd.ms-excel Encoding: base64 Description: Well #12 Hot Sheet.xls Tom Maunder<tom maunderC, admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 1/28/2003 10:21 AM Dillon Platform Well Injectivity Test Date '1/15/03 - 1/16/03 Well # 12 Meter Daily Long Short 9 518" Injection Csg Date Hour Reading Rate String String Annulus Wtr Fluid Barrels PSI PSI PSI Temp. Level 1/15/03 10:00 0 0 01Start filling up LS 72 400; 11:00 80 0 ILong string full 80 bbls 11:00 0 t450 IZero'd meter. Began Injection 72 11:15 22 1000 1450 0 72 11:30 33 950 1450 0 72 11:45 43 950 1400 0 72 1/16/03 12:00 53 950 1400 0 72 12:15 63 950 1400 0 72 12:30 73 950 1400 0 72 12:45 83 950 1400 0 72 1:00 92 950 1350 0 72 1:15 102 950 1400 0 72 1 '30 112 950 1400 0 72 1:45 122 950 1400' 0 72 2:00 132 950 1400 0 72 2:15 142 950 1400 0 72 2:30 152 950 1400 0 72 2:45 162 950 1400 0 72 3:00 172 950 1400 0 72 4002 3:15 182 950 1400 0 72 3'30 191 950 1400 0 72 3:45 201 950 1400 0 72 4:00 211 950 1400 0 72 4:15 221 950 1400 0 72 4:30 231 950 1400 0 72 4:45 241 950 1400 0 72 5:00 251 950 1400 0 72 5:15 261 950 1400 0 72 5:30 271 950 1400 0 72 6:30 308 900 1400 0 72 7:30 332 900 1200 0 72 8:30 370 900 1400 0 S/D to access TK # 5 72 12:30 370 0 0 0 72 12:45 Start fill L~ 72 1:00 1250 LS full. Resume injection. 72 2:00 I 72 II 1/28/2003 10.21 AM Well #12 Hot Sheetl.xls Well #12 Hot Sheetl.xls Test Sep. Well Test Unocal Corporation 909 West 94 Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCALe December 11, 2001 Tom Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Re: Modified MIT on Dillon 12 Shut-in Injection well Dear Tom: A consecutive, seven. (7) day pressure surveillance was finished on the Dillon 12 shut-in injector (Permit # 1680560 API 733-20126-00) on 05/10/01. The tubing, production casing and outer casing pressures were monitored and recorded for three (3) consecutive days. The production casing pressure was altered by 200 psi. Pressures were then monitored and recorded for an additional four (4) consecutive days. See attached data sheet and well schematic. The pressure surveillance data indicates a minor tubing / casing communication but since the 9 5/8 casing is holding @45 psi. with the tubing at zero or on vacuum, Dillon 12 cannot flow from the productive interval into the 9 5/8" casing. The water flood system on the Dillon Platform has been disassembled and we are not currently planning to resume further injection on this platform. Therefore we ask that you approve the shut-in MIT for the well. Attachments: 10-403 Pressure Test Results Wellbore Schematic Sincerely, Christopher A. Ruff Senior Reservoir Engineer Cook Inlet Waterflood Management RECEIVED DEC 3 1 2001 Ala Oil&GaaCo . n Aogcc Di 12 SI MIT 12-11-01.doc JJD ;" STATE OF ALASKA '~/'~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well Plugging: Time extension Stimulate: Change approved prograrr Pull tubing: Variance: Perforate: Other: Shut-in MIT 2. Name of Operate 5. Type of well 6. Datum elevation (DF or KB Union Oil company of California (Unocal', Development 110' KB ABOVE MSL feet 3. Address Exploratory 7. Unit or Property name Stratigraphic: PO BOX 190247 ANC, AK. 9951,~ Service: X South Middle Ground Shoal 4. Location of well at surfac~ Leg 4, Cond. 6, Dillon Platform 8. Well number 673' FSL, 1763' FWL, Sec. 35-T8N-R13W-SIV No. 12 At top of productive interv~ 9. Permit numbe~ 68-56 At effective deptl' 10. APl number 50-733-20126-00 At total deptl- 11. Field/Poe Middle Ground Shoal/"G" 12. Present well condition summar Total depth: measured 12,000' feel Plugs (measured', None true vertica 10,461' feel Effective depth: measured 11,923' feet Junk (measured', None true vertica 9,443' feel Casing Length Size Cementec Measured deptl' True vertical depth Structural Conductor Su dace 1,587' 13-3/8" 1770 Sx 1,587' Intermediate Production 10,439' 9-5/8" 1,060 Sx 10,439' Liner Perforation depth measured (See Attached Wellbore Schematic: true vertica Tubing (size, grade, and measured deptl- (See Attached Wellbore Schematic', Packers and SSSV (type and measured deptl- BakerMod. 'Fl' Packer @ 10,174 13. Attachement~ Description summary of proposal X Detailed operations prograrr BOP sketch: 14. Estimated date for commencing operatic 15. Status of well classification as 16. If proposal well verbally approve~ Oil: Gas: Suspended: Name of approver Date approved Service X 17. I hereby certify thaxt.~t.he foregoing i>~true and correct to the best of my knowled.( Signed: Title: Senior Reservoir En~inee Date: 12/20/2001 - - - r FOR COMMISSION USE ONLY Conditions of approval: Notify Com mission so representative may witness IApproval No.~,_) ' Plug integrity .... BOP Test Location clearance ~.,,---t ' Integrity Test ~. ~ _I~' Subsequent form required 10- tl~t-~lr.. Mechanical Original Signed By Approved by order of the Commissioner Cammy 0echsli Commissioner Date ~/C2~ '7/~. Cover letter at \~Z~k-Anchorage\Groups~,OGCC\Correspondences~,ogcc D, 12 SI MIT ~"~'RECEIVED Form 10-403 Rev 06/15/88 DEC 3 ! 2001 Alaika 0il & Gas Cons. Cmnmission SUBMIT IN TRIPLICATE MAY;.~3 '01 0~: 17PM UMO~L DILLON -'~"~ P.3 i "' ' Ptocm~r~ fo.i, MIT. on Dillon Di.'12'$hut41:~ Ini~tor "' o ! , , " 1. Record daily tubing, ~asing, and,0uter casing Pressures for a consecutive, · , throe day peri6d..' ' . . ., , Increase casing pressure bY 200psi. C0ntiriue recoi'ding daily tubing, casing,' and outer casing pressute~ for an additional, consecutive, four, ay period,.. i , , D. itt~, ' Tubin9 P~ssu. re casing PressUre Outer Caeing Pre!~re 5-_~,.. ~z~-t~.~ .0~ 3 ~, ~. .. ' / ~, , , - . ~_~ t~~ ~- ~-~ r~ ' y~' ~ ii · iii _ i * ~ ,1 , , · I. · ,p Spud ~ Surfaol LocoUon: (' 'ttia! Potential: initial SfJrnufaUon: R~9 .r~otr D~a,:_. Cared lnt4uYal~: DST tntervele and Roeultl: Log Invento~ SOUTH MIDDLE OROUND SHOAL ADL 18746 WE~.L NO. 12 HEMLOCK ¢ONGLOUL=T~TE: PLATFORU DILLON 8/28/6B Lei 4. Slat 8 87~' F'~I., 1783.5' FWtq Set. 3.5, TSH, R1 ~ - 02' ~ ~' ~ See. 11~ ~ 12~' ~ I 0~1' ~ ~', ~ ~d 43J~ N-~ ~d ~g5 C~n9 ~t ~ 1043~ 1107~1~I~* 11102-1 ~ 275' ~4:11~113~ ~. 11 ~ 1 ~ 4~' 881 ~, 337 ~, 248 M~ None tEL-SP, 9H0-(2~, OR 12/24/88, trm:~ ~/20/70. tro=m,-temperotur, .%~3(V72, ~~fnn~ Vooer-temperot~re t.2(11/7'3, trooe~~~ 1(~1/74, booer profile e/22/77, 10/11/76, 7/2W83, 1/23/85 1. 2. 3. 4. 5. 7. 6. 11o 12. 13. Cor~roft 1~ N~ ~ol ~g ha~ 3 t~-~~d27~~~XO 2 7~ ~ pup J~ 2 7~ ~ker ~ ~I~ '2.2~ ld 2 7]" Bu~ and 3 1/2' ~&8 XO ~ I~or · Dull n~ ~a~ out ~b' 35' 10035' 0036' I0047' 1059' 1069' 11 O70' 1071' 11072' 1093' 11094' Short B, C. O. 1003:)' 10034' 10046' 10047' Baker Uodef I=-1 per through p~ but not attooh4d to Iowm' tbg. o ~Vs" 40 & 43.5~ CSA 10439* Baker Model r- 1 pkr Pi~ 11923' 12O00' ~3 3/a- 54.5~ 7- 23 k 0174' 10825-1 ~40' 109. 15' 10968' 1 OeO' 11102-11275' 450' ,"'"" STATE OF ALASKA "'" AL. ,<A OIL AND GAS CONSERVATION COMM, .... ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon w Suspend -- Operation shutdown Alter casing __ Repair well Plugging Change approved program __ Pull tubing __ Variance 2. Name of Operator Union Oil Company of Californ Exploratory __ 3. Address t - '~;t~sraphic -- P o O. BOX 196247, Anch. , AK, 9 519 6 ervice 4. Location of well at surface Leg #4, Slot 6, Platform Dillon 673' FSL, 1763' FWL, Sec. 35, T8N, R13W, SM Re-enter suspended well __ · -Time extension __ Stimulate __ Perforate __ Other. X 6. Datum elevation (DF or KB) 1 O O ' KB _N~_~T_ 7. Unit or Property name SMGS Unit 8. Well number 12 At top of productive interval 1160' FSL, 139' FEL, Sec. 3, T7N, R13W, SM At effective depth 913' FSL, 55' FEL, Sec. 3, TTN, R13W, SM At total depth 833' FSL, 98' FEL, Sec. 3, TTN, R13W, SM 12. Present well condition summary Total depth: measured true vertical 12000' feet 10490' feet Effective depth: measured 11923 ' feet true vertical 10417 ' feet 9. Permit number 68-56 10. APl number 50--'i33-20126 Plugs(measured) DEC - 9 1991 · asJ&3 J)jj & Bas Cons. Commission Junk (measured) .... [q!~J~0rag{~ feet Casing Length Size Cemented Structural Conductor Surtace 154'8' 13-3/8" 1770 Intermediate Production 10403 ' 9-5/8" 1060 1799 ' 7" 360 Liner Perforation depth: measured true vertical Measured depth See attachment True vertical depth SX 1587' 1561' SX 10439' 9013' SX 10174'-11973' 8772'-10464' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80, Dual @ 10,046' 2-7/8", 6.5#, N-80, Single @ 11,094' Packers and SSSV (type and measured depth) Baker Model "F-i" packer @ 11,080' 13. Attachments Description summary of proposal __ Detailed operations program ..2f, BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: October 28, 1991 16. If proposal was verbally approved Oil __ Gas ~ Suspended .... Name of approver Date approved Service 17. I hereby cd, fy that the foregoing,j~rue and correct to the best of my knowledge. iD ~ ' FOR COMMISSION USE ONLY C°nditi°ns °f appr°val: N°tify C°mmissi°n s° representative may witness I Appr°val N°'¢f Plug integrity __ BOP Test __ Location clearance __ '-- Mechanical Integrity Test_ Subsequent form required 10- Approved by order of the Commissioner ORlulN~,- SIONED BY LONNIE C. SMITH FOrm 10-403 Rev 06/15/88 ~-~-0m~.ssioner Date /G~-/¢-?/~ SUBMIT IN TRIPLICATE RECEIVED EC - 9 1991 & Gas Cons. Commission Anchorage P_..e~J. ne~. t .Data~: Spud Date: Surface LocaUon: Subeurface Location: Elevation: TO; PBD: Caelng: Perforatlone: Initial Potential: InlUal Stimulation: ~_e~. r~olr Da.to:_. Cored Intervalm DST Intervole and Reeultm Log Inventory: SOUTH MIDDLE GROUND SHOAL ADL 18746 WELL NO. 12 HEMLOCK CONGLOMERATE PLATFORM DILLON G-l: 10825-10840' 0-2: lOglS-10g$0' lOg63-1098B' G--3: 11060-11065'e 11076-I 1081'e 11102-11275' 0-4:I1305-113g0' 11405-I 1450' eCement Squeezed 881 BOPD, 337 BWPD, 246 UCFO B/2B/BB Long 1. Leg 4, Slot 6 673' F~L, 1763.5' F'WI., See. 35, TaN, R13W, $.U. 3. TO - 92' FEL. 443g' FNL, See. 3. I~N. R13W. $.U. 4. 5. 110' KB 6. 12000' TVD 10461' 7. 11923' ~ g443' 10. 15 3/r, 54.51~ Caelng let at 1587' wl~ 1770 ex cement 11. g 5/B", 40 and 43.5jl N-BO and S-g5 Cooing eot at I043g' 12. with 1060 ix cement 1 7" 23 and 26~ ,9-95 Uner eot at 10174-1197~l~wlth 360 ex cement c~ Short C:) B. ~o iT1 D. None None None IEL-SP, BHC-GR, OR 12/24/68. tracer 6/20/70, tracer,-tempemture 3/30/12, traeer,-eplnner 7/1 tracer-temperature 12~11/73, trocer,-temperature 10/~1/74, RA tracer profile 0~22/77, 10/1 I/'/9. 7/28/83. 1/23/85 ___Completion String: Cameron 10" Nora Dual tubing hanger 3 1/2" Buttro,e tub!ng pup 3 1/2" Buttre~e tubing w/AB coupllnge 3 1/2" Buttreee and 2 7/8" Buttreee XO 2 7/8" Buttre~a tubing pup Baker parallel flowhead B 1/8" od 2 7/8" Buttreea tubing w/AB couplings 2 7/8,' Buttreel pup Jr. 2 7/8" Baker 'F' nipple 2.25 Id 2 7/8" Buttreea and 3 1/2" Buttree, ×0 Seal locater Seal aeaembly Bull naee cheer out cub Dep~ 35' 37' 10035' I0036' 10046' 10047~ 11056' 1106g' 11070' 11071' 11072' 11093' 11004' CSA 15 String: 3 1/2" Buttreee tubing w/AB couplinge 10033' :3 I/2" Buttre~e and 2 7/8" Buttrese XO 10034' 6 2 7/8" Buttreel pup Jr. 10046' L, ._.___ Il Baker 2 7/9" R-Nipple 2.197 Id. 10047' . ,. . Bak,r Uod,I F-1 pkr ~ dUner top at LA, run 6/17/84) w/6" bare .-' -'-' ~: /10174" .ak.r S,o ,tabb. ' /' through pkr but not attached "LJ 11 ~ 11061' Bak,r Uod,I F- 1 lP2~-~ I 1~ ~ 11102-1127.¥ TO 12000' 'f~'.'/. / South Middle Ground Shoal ADL 18746 Well No. 12 Procedure for suspending and freeze protecting well: 1) Run temperature survey from 10,047' to surface. 2) Bullhead power oil down both strings to 100'. Both tubing strings will be protected against freezing by power oil at this point. 3) Run hose to 100' inside 9 5/8" casing X tubing annulus. Circulate power oil into 9 5/8" casing X tubing annulus taking returns up hose. The 9 5/8" casing X tubing annulus will be freeze protected at this point. 4) Install blind flanges on all wellhead outlets. 5) Install gauges on the tubing and 9 5/8" casing X tubing annulus. RECEIVED DEC - 9 !991 AlaS~ Oil & Gas Cons. CommiSsion ', ~mchorage Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-562-2147 W. G. Smith District Manager March 13, 1987 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: C. V. Chatterton, Chairman File: FEW-O47-WF Report of Sundry Well Operations MGS 17595 Well No. 12 Platform Baker, Cook Inlet, Alaska Attached for your records is a State Form 10-404 reporting the results of a tubing/packer to annulus integrity test run on the subject well on February 11-12, 1987, and March 3-5, 1987. The test results indicate that there is communication between the tubing short string and the annulus. Our plans for correcting this situation will be outlined in a State Form 10-403 and forwarded under separate cover. Amoco proposes to keeP the well active until corrections are made. Very truly yours, W. G. Smith District Manager' Attachments JCB/dds 052/jcb RECEIVED MAR 2,0 1987 Alaska Oil & Gas Cons. Commissio~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL 'OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other 2. Name of Operator Amoco Production Company 3. Address P Box 100779 Alaska 99510 4. Location of well at surface 743' FSL, 1818' FWL, Sec. 35, T8N, R13W At top of productive interval 1342' FNL, 2513' FEL, Sec. 35, T8N, R13W At effective depth 1279' FNL, 2536' FEL, Sec, 35, T8N, R13W At total depth 1260' FNL, 2543' FEL, Sec. 35, T8N, R13W. 11. Present well condition summary Total depth: measured 10',550 feet true vertical 9,785 feet Plugs (measured) 5. Datum elevation (DF or KB) 100' (KB) 6. Unit or Property name SMGS 7. Well number 9RD2 8. Approval number 7-69 9. APl number 50-- 733-20086-01 10. Pool Hem1 oc k Feet Effective depth: measured 10,445 feet true vertical 9,699 feet '.Casing Length Structural Conductor 598 ' Surface 2015' Intermediate Production 10898 ' Liner 3554' Perforation depth: measured true vertical Junk (measured) Size Cemented Measured depth 20" 1700 sx 598' 13 3/8" 1900 sx 2015' 9 5/8" 1250 sx 10898' 7" 900 sx 6,996 '.-10550' 10267'-10435' 9526'-9682 ' Tubing (size, grade and measured depth) 3½" N-80 @10217' Packers and SSSV (type and measured depth) Baker Model F-1 at 10,200' True Vertical depth 598' 1983' 9948' 6469 '-9788' RECEIVED FEB 2 0 1987 Alaska 0ii & Gas Cons. C0mmi~:~is: 12. Stimulation or cement squeeze summary Intervals treated (meaSured) Anchorsfle Treatment description including volumes used and final pressure 13. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Shut-In ' Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Subsequent to operatio, n Shut-In 14. Attachments : Daily RepOrt of Well Operations [] Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my ~nowledge . Signed _ Form 10-404 Rev. 12-1-85 Title ' District Manager" Date Submit in Duplicate Time 08'55 09:00 09:05 09:10 09:15 09:30 09:45 10:00 11:00 12:00 15:00 18:00 21:00 03:00 09:00 ~ t 0 5 Min 10 Min 15 Min 30 Min 45 Min 1 Hour 2 Hours 3 Hours 6 Hours 9 Hours 12 Hours 18 Hours 24 Hours Annulus Pressure Test MGS 17595 Well No. 12 February 11-12, 1987 Short String Long String Tubinq Tubinq Annulus Comments 1,000 psi 1,000 825 800 800 790 775 750 750 750 750 725 700 700 700 2,600 psi 640 psi S.S. Injecting at 701 BPD L.S. Injecting at 1,842 BPD 2,600 640 2,500 640 2,450 640 2,440 64O 2,400 640 2,350 640 2,310 640 2,240 640 2,150 630 2,000 630 1,950 630 1,925 620 1,875 620 1,850 610 ], Shut- n well MAR 2 o 19B? Oi~ & Gas cons. commission Anch,q, r3.r!8 Annulus Pressure Test SMGS 17595 Well No. 12 March 3-5, 1987 Time 08'55 09:00 09:30 10:00 11:00 15:00 21:00 03:00 09:00 13:00 17:00 21:00 01:00 05:00 09:00 z~:O0 A t 0 30 Min 1 Hour 2 Hours 6 Hours 12 Hours 18 Hours 24 Hours 28 Hours 32 Hours 36 Hours 40 Hours 44 Hours 48 Hours 60 Hours Short String Tubinq 900 psi 900 psi 750 725 710 610 580 560 560 550 550 540 525 520 520 1,600 Long String Tubinq Annulus b640 psi 640 psi 1,650 640 1,650 640' 1,650 640 1,650 620 1,650 610 1,650 610 . 1,640 610 1,640 600 1,650 600 1,650 590 1,650 600 1,630 600 1,610 600 1,610 590 Comments S.S. Injecting at 880 BPD L.S. Injecting at 1570 BPD Shut- In Well Begin S.S. Injections RECEIVED. MAR 2 0 1987 Alaska Oil & Gas (Ions. Commission g '1 Fll'i!' ,~, L. A. Darsow District Superintendent Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 August 14, 1981 Fi 1 e: LAD-943-WF Mr. Hoyle.H. Hamilton, Commissioner Alaska Oil and Gas Conservation Commission 3001 POrcupine Drive Anchorage, Alaska 99501 Dear Sir' Subsequent Report of Repair Work SMGS Unit Well No-.12 - 'Platform'Di 1 lon; 'COOk' Inlet; 'Alaska Attached in:duplicate is our State of Alaska Form 10-403, Sundry Notices and Reports on Wells,'which summarizes the recent well repair. The current status of. the subjectwell is injection thrOugh two strings of tubing. The short string (12S) injects into the Hemlock G-1 and G-2 zones, while the long string (i2L) injects into the Hemlock G-3B and G-4 zones. Yours very truly, L. A. Darsow District Superintendent Attachment KEO/LMP/kl t RECEIVED 1 9 Alaska 0~1 & ~as Cons. Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CCh.',,IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator 7. Permit No. Amoco Production Company 68-56 3. Address 8. APl Number P. O. Box 779, Anchorage, Alaska 99510 50-733 201 2600 4. Location of Well Leg 4, Slot 6, South Middle Ground Shoal Platform Dillon 673' FSL, 1763' FWL, Section 35, T8N, R13W, S.M. 9. Unit or Lease Name South Middle Ground Shoal 5. Elevation in feet (indicate KB, DF, etc.) 110' KB 12. 6. Lease Designation and Serial No. ADL 18746 10. Well Number 12 11. Field and Pool South Middle Ground Shoal Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter·Casing [] ~ Perforations IX-I Altering Casing E] Stimulate Fl Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made ~l 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). SMGS Unit 18746 Well No. 12 was repaired as follows, during the period May 13, 1981 to June 17, 1981' 1. Pulled all tubing, packers, and mandrelS. e Cement squeezed perforations 11,060-11,065', Il,076-11,081', and 11,102-11,180'. e Cleaned out to PBTD of 11,702'. e Installed long string packer at 11,085' and dual string packer at 10,051'. Se Ran dual string tubing and returned well to injection June 20, 1981. RECEIVED AUG 1 9 198] Alaska 0ii & Gas Cons. C0mmissJ0n 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,,,~,~.. f~~a~.~ Title District Superintendent The space below for Commission use ~'"~' OateAUgust 14, 1981 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 ~-'"~ STATE Of ALASKA ~ ALASKA ,.,~L AND GAS CONSERVATION CL..AMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER 2. Name of Operator 7. Permit No. Amoco Production Company 68-56 3. Address 8. APl Number P. 0. Box 779, Anchorage, AlaSka 99510 5o-733,201 2600 4. Location of Well Leg 4, Slot 6, South Middle Ground Shoal Platform Dillon 673' FSL, 1763' FWL, Section 35, TSN, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) llO' KB 6. Lease Designation and Serial No. ADL 18746 12. 9. Unit or Lease Name South Middle Ground Shoal 10. Well Number 12 11 ~ Field and Pool South Middle Ground Shoal Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF.' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion,) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco plans to repair SMGS Unit 18746 Well No. 1. Pull tubing, packers, and mandrels. 2. Clean out to PBD 11,704'. 3. . NOTE' 12 as follows' Cement squeeze perforations 11,060-11,065', 11,076-11,081', and 11,102-11,160'. Clean out cement fill. Reperforate lower G-lB and G-4 zones. · Convert well to dual string injection with short string injecting in G-l/G-2 zones and long string injecting in lower G-lB/G-4 zones. Verbal approval obtained 5/11/81 from Mr. Hoyle H. HamiltoKnI'L~:I¥~:U. s¥.~::~.~t Wo~-k ~,~p.o~,~a MAY 1 3 1981 14. I hereby certify th~ f,oregoing is true and correct to the best of my knowledge. Signed ~_~,,~'~'~'-~'"--~~¢~-~/~ Title. District Superintendent The space below for Commission use Conditions of Approval, if any: /'MIbJIUI cl~JO Date 5/12/81 Approv~ Copy . By Order of Approved by COMMISSIONER the Commission Retumed Date -~-/~ ~ / Form 10~,03 Rev. 7-1-80 Submit "1 ntentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 May 12, 1981 File' LAD-569-WF Mr. Hoyle H. Hamilton, 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. 12 Platform Dillon' COok Inlet, Alaska Attached in triplicate for your approval is our State of Alaska Form 10-403, Sundry Notices and Reports on Wells., to perform repair work on the subject well. The objective of this work is to improve conformance by segregati.ng injections and increasing water injections into the G-3B and G-4 zones. YourS very truly, L. A. Darsow Di stri ct Superintendent Attachment KEO/klt RECEIVEI) MAY 1 3 1981 ;Naska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA, L AND GAS CONSERVATION C ~/1MISSION SUNDRY'NOTICES AND REPORTS ON WELLS' 1. DR ILLING WELL [] 2. Name of Operator Amoco Production Company 3. Address P. 0. Box 779, Anchorage, Alaska 99510 COMPLETED WELL OTHER [] 4. Location of Well Leg 4, Slot 6, South Middle Ground Shoal Platform Dillon 673' FSL, 1763' FWL, Section 35, TSN, R13W, S.M. 7. Permit No. 68-56 8. APl Number 50- 733.201 2600 9. Unit or Lease Name South Middle Ground Shoal 10. Well Number 12 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 110' KB I ADL 18746 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF iNTENTION TO: SUBSEQUENT REPORT OF: South Middle Ground Shoal (Submit in Triplicate) Perforate IX] Alter Casing [] ~ Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion,) (Submit in Duplicate) [] Altering Casing I"] . [] Abandonment [] [] Other [] 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 plans to repair SMGS Unit 18746 Well No. 12 as follows: 1. Pull tubing, packers, and mandrels. 2. Clean out to P. BD 11,704'. 3. Cement squeeze perforations 11,060-11,065', 11,076-11,081 ', and 11,102-11,160''. 4. Clean out cement fill. 5. Reperforate lower G-3B and G-4 zones. 6. Convert well to dual string injection with short string.injectl~rl~l,i~qI G-l/G-2 zones and long string injecting in lower G'3B/G-4 zonel~.h~,-~u NOTE: Verbal approval obtained 5/11/81 from Mr. Hoyle H. Hamil~A¥ 1 ~ 1981 Subsequent Work l~eportecl _._~_.~ Ala$1~.~ 0il & Gas Cons. Commission on Form No. ~ Dated /~ch0rago 14. I hereby certify th..~-t~ fgregoing is true and correct to the best of my knowledge. Signed ~ Title Dis tri ct Superintendent The space below for Commission use Date 5/12/81 Conditions of Approval, if any: Approved by (J ~-~' COMMISSIONER Form 10-403 Rev. 7-1-80 By Order of the Commission Date · Retumec! ~-----14--~/ Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ,, RETAIN THIS SECTIO~ FOR YOUR RECORDS ~ E ..~'.~..:~ ........ .,5.6~:~'"':~_..Z~'c.c,f:(....~,:...~,. ........ i. ............................... / PRINTS NEG. SEPIA ............................................................ PRINTS .............. NE® ............... SEPIA ............................................................ PRINTS .............. NE® ............... SEPIA ............ ~.:.. ;:-.-,...,,:,..,,_..,.. ~...= ..................... PRINTS .............. NE® ............... SEPIA ~(" i ...... i~ "'''~ ABOVE 'RECEIVED FROI";.41: i' DRESSER ATLAS ~m ~To. ~,~ STATE Or ALASKA I'~.EV. ~- I-?0 OIL AND GAS CONSERVATION COMMI'rI'EE SUBMIT IN DUPLICAT~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS OZLw,LL I'--] o,,,..LL [--J o.t,,~,~ Water Injection '~. NA.ME OF OP~*ATOR Amoco Production Company 3. ADDRESS OF' OPEP,~T01~ P. O. Bo× 779~ Anchorage~ Alaska 4. LOCATION Or W~LL 99510 At Surface: Leg 4, Slot 6, South Middle GrOund Shoal Platform "D," 673' FSL, 1763' FWL, Sec. 35, T8N, R13W, S.M. AP1 NUi~{ER1CAL CODE 50-133-20126 LEASE DESIG]~ATION AXD SEIRIAL NO. ADL-18746 T IF INDIA]~. ALOT~EE 0]~ TRIBE /~AME 8. U,'IT FARM OR LEASE NAME SMGS Unit 9 WELL KO 12 10. ~-I~:i,r) A-ND POOL. OR WILDCAT South Middle Ground Shoal 11. SEC., T., I~., M.. {BO~rTOM HOL~ omJmc-rn~ Sec. 3, T7N, R13W, S.M. 1~. PERMIT ~0. 68-56 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN' HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLU1VIES USED. PERFOHATIONS. TESTS A.N'D RESULTS FISHING JOBS JUNK IN HOLE A. ND SIDE-TR~CKED HOLE AND A.NY OTHER SIGNIFICANT CH.A.N~ES IN H012/1 CONDITIONS. Summary.of Operations Durin~ September 1973: September 1- 10: Well on water injection. Ran spinner survey September 10. Attempted to retrieve flow- through dummy valves in mandrels at 10,746' and 10,949' and unable to unseat. Returned well to injection. Operations complete September 10, 1973. Final Report. S,~l~r~ /-/"~/)/~/~.-"~"/~,/'-" -~r~.m Dist, Production Supt. D,'~: October i0, 1973 - oil and go~conler~tJofi commie by the 15~ of the succ~ding mon~, ~le~ otherwise directed. Form 10-405 '~ 8~tbrntt "Intentions" tn Triplicate REV. '! - t0-7~J . ' & "Sut~sequent Reports" in Duplicate STATE OF ALa~SKA OIL AND GAS CONSERVATION. COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APP-L1CATION 'FOR f~'EP,~IT-L' ~or such 'pt;o~osal$.) 1. 01L WeLL OASw~L~, ['--} o~-.s Water InjectiOn 2. NAME OF OPEHATOR Amoco production C0_m__p~ny 3. ADDRESS OF OPERATOR P. O. Box 779, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface Leg 4, Slot 6, SMGS Platform "D," 673' FSL, 1763' FWL, Sec. 35, T8N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc. RDB 100 ' above MSL ,4. Check Approprim Box To I,ndir. ate N~ture of N~ti'ce, Re NOTIC~ OF INTENTION ~: TEST WATmB SHUT-OFF PULL OR *LTER CASINO rRACTURg T.m&T MULTIPL~ COMPI.ETE s.oor o. ~C,DZz~ {~ REPAIR WELL CHANO~ PLA~B 5. APl NUNLEBiCAL CODE 50-133-20126 6. I~E D~IGNATION ~ND S~:BIAL NO. ADL-18746 ?. IF INDIAN, AI~O'l~r~:~- OR TRIBE NANIE UNIT, FA.RNI OR LEASE NAME SMGS Unit 9. WELL NO. 12 10. FIEI.,D A~D POOL, OR WILDCAT South Middle Ground Shoal 11. SEC., T.i, R., M., (BOTTOM HOLE OBJECTIVE) Sec. 3, T7N, R13W, S.M. ~. P~tM/T No, 68-56 SHOOTINO sa AcmIzzso (Other) cement squeeze xa't, or Other Data ' · SUBSeQUeNT RIPOBT O~: RI~PAIRINO W~LL &LTmRINO CASINO (NoTz: Report results of multiple completion on Well ~Other) Completion or Reeompletion Report and Lol~ form,) 15. v~:sc~a£ pRO?osED OR CO.~fPLZTZD OPZRATWXS (Clearly state all pertinent details, and dive pertinent dates, includin~ estimated date of startin~ any proposed work. Operations to improve the water injection profile of this well commenced June 29, 1973. The following is a chrOnological outline of the work' performed: June 29-30:. Pulled injection tubing and drilled out permanent packer at 10,650'. Cleaned out~to 11,704'. Set bridge plug at 11,295' and spotted 40 sacks sand on toP. Set second bridge plug at 11,095' and cement retainer at 10,982'. July 1 - 4: Set cement retainer at 10,990' and cement squeezed perforated intervals 11,060- 11,065' and 11,076 - 11,081' with 120 sacks Class G cement. Cleaned ~out to 11,090' and pressure test of squeeze interval unsuccessful. July 5-9: Set cement retainer at 10,995' and resqueezed intervals 11,060- 11,081' with 75 sacks Class G cement. Cleaned out ~t.o 11,090' and pressure tested squeeze interval 11,060-11,081' to 3300 psi and okay. ~Set retrievable packer at 10,850' and //-'~injected 360 BWPD rate at 2500 psi into perforated intervals uj' /' 10,915-10,950' and 10,963-10,968'. (contin on a~tache~/Page) 1~.I hereby certlf/thJ~J~~il~llj~ SIONED fi./ /~/,~~ ~',,,5, Dist' Production Supt. ~,,, October 10, 1973 (Thi~ ~paC~ for State °'~ce u~~ .... ' ~ ' "~ ' ~"' / / · APPROVED BY. ~ . TIT~ .... DATE ~ ~ s ~ ~ ---~; . OCT Sundry Notices and Reports on Wells SMGS Unit Well No. 12 October 10, 1973 Page 2 July 10- 12: July 13- 18: Cleaned out to 11,744'. Perforated intervals 10,825-10,840'; 11,120-11,275'; 11,305-11,390'; and 11,405- 11,450' with 2JSPF. Reperforated intervals 10,915 - 10,950' and 10,963 - 10,968' with 2JSPF. Isolated perforations 10,915-10,950' and 10,963-10,968' with bridge plug and packer. Injected water at 3 BPM and 1900 psi pressure to test injectivity. July 19 - 22: Acidized interval 11,405 - 11,452' with 4700 gallons 12-10 Ultra Mud Acid. Prepared to acidize perforated interval 11,305 - 11,390' and communicated to casing-drillpipe annulus. Acidized intervals 11,102-11,275' and 11,305- 11,390' with 25,800 gallons 12-10 Ultra Mud Acid using diverter. Acidized interval 10,825 - 10,840' with 672 gallons 12-10 Ultra Mud Acid. July 23-25: Set bridge plug at 11,500' and packer at 11,096' and ran spinner and radioactive tracer surveys of perforated intervals 11,10.2-.11,452'. Isolated perforations 11,060-11,065' and 11,076- 11,081' with bridge plug and packer and conf.irmed additional cement .squeeze required. Set bridge plugs at 1i,~095" and 11,104' and retainer at 10,985' and cement squeezed interval 11,060- 11,081' with 50 sacks Class G Cement. Pressure test of squeeze interval unsuccess- ful. Drilled out-bridge plugs at 11,095' and .11,104'. Re- perforated intervals 10,915-10,956' and 10,963-10,968' with 2JSPF~.~ While perforating interval 10,963-10,968' perforator selector switch failed and perforated interval 10,968-10,9'88' with 2J. SPF. C~leaned Out to 11,923' PBD. Isolated. interval 11,102-11,275~ with packe~ and bridge .plug and tested for communication to perforated intervals 10,915- 10,956' and 10,963-10,968' and okay. Ran injectivity test into interval 10,915-10,968,. Set permanent packer at 11,086'. July 26- 27: July 27 '31: AugUSt 1', 6: Ran subsurface water injection flow control equipment and two retrievablePackers. ~Set retrievable packers at 10,679' and 11,016'. Returned Wel.i to water injection service and only injlecting into zones below permanent packer .at 11,086' Inj~ecting water into zones below i1,086'. Injection rate 7~30-73: 2484 BWPD at'3250 psig. Attempt to .retrieve dUmmy plugs from tubing mandrel~s (located at 10,746~'; 10,814'; 10,881,; and 10,949') and unable to do . s° due to wireline tools stuck in 'tubing. Recovered wireline ~i .~'~.. ~ ®.. ~ ~.~ ~ ~ i~~i~}! t°~' get ~t'oolsand to'els. Ma dedoTMsec°ndt° mandrels.attempt Returnedt° lo catewellmandrelsto injeCtion.and unable Sundry Notices and Reports on Wells SMGS Unit Well No. 12 October 10, 1973 Page 3 August 7: Acidized injection tubing with 2000 gallons 15% HCL to remove scale. Returned well to injection. August 8- 12: Injecting water below packer at 11,086'. Water injection rate 8-12-73: 1752 BWPD at 3250 psig. August 13- 15: Pulled mandrel dummy plugs and ran subsurface flow-through dummies in mandrels at 10,746' and 10,949'. Returned well to injection. August 16- 31: Injecting water. Injection rate 8-18-73: 3852 BWPD at 3150 psig. September 1 - 10: Ran spinner and radioactive tracer surveys 9-10-73. Attempted to retrieve flow-through dummy valves in mandrels at 10,746' and 10,949' and unable to unseat. Returned well to water in, jection. Operat'ions complete 9-10-73. Water injection rate Prior .to workover: 6'27-73, ~4621 BWPD at 3350 psig Water injection rate after workover: ' 9-10-73., 3972 .BWPD at 2850 psig Final Report. ~ ~°' ~'"'~ STATE Ot REV. 3-1-70 OIL AND GAS CONSERVATION CoMMrI-I'EE SUBMIT IN DUPLICAT~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1, 0z~ j-'j o~. [~ o?~E, Water Injection W~LL WELL 2. NAME OF OP~R.A.TOR Amoco Production Company ~. ADDRESS OF OPER~TOB P. 0. Bo× 779, Anchorage, Alaska 4. LOCATION OF WF/~ 99510 At Surface: Leg 4, Slot 6, SMGS Platform "D, 673'-FSL, 1763' FWL, Sec. 35, T8N, R13W, S.M. APl NUMERICAL CODE 50-133-20126 6 LEASE DESIGNATION AND SERIAL NO. AI)L-18746 T IF INDIAN. ALOTTEE OR TRIBE NAME 8. L~.'IT FA.MM OR LEASE NAME SMGS Unit 9 WELL NO 12 10. FLEIA') A.N'D POOL. OR WILDCAT South Middle Ground Shoal n. s~c., r., ~., ~,,~. (BO'm'o~ Ho~ o~ Sec. 3, T7N, R13W, S.M. Il, PI~qJ~IIT I¢O. 68-56 13. REPORT TOTAL DEPTH AT END OF MONTH. CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AI~rD VOLUMES USED, P~OHATIONS. TESTS AND RESULTS FISHING JOBS JLrN'K LN HOLE AND SIDE-T'P,,ACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOL1/I C~ONDITIONS. Summaz~y of. Operations - During. August · 19 73: August 1- 6: Unable to retrieve dummy plugs from tubing mandrels (located at 10,746'; 10,814'; 10,881'; and 10,949') due to wireline tools stuck in tubing. Recovered wire- line and tools. Made second attempt to locate mandrels and unable to get tools down to mandrels. Returned well to injection. August 7: Acidized injection tubing with 2000 gallons 15% HC1 to remove Scale and returned well to injection. August 8-12: Injecting water below packer at 11,086'. August 13 - 15: Pulled dummy plugs and ran subsurface flow-through dummies in mandrels at 10,746' and 10,949' and returned well to injection. August 16- 31: Well on water injection. DIVISION L,I.: OIL AND GAS AHCHORAG~ ~ Dist Production Supt. D,~ Se tember 24 1973 oi! and ges/con~4r.J~o~¢omlittee by the ISm of the succeeding month, unle~ othe,wis, l~rm ~o, P---4 REV, ~- I-?0 STATE OF AI.ASKA SUBMIT 11~ DUPLICAT~ OIL AND GAS CONSERVATION COMMI~EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS O,L J~ o,, ~] o~,,,~. Water Injection WKLL 'W~LL Amoco Production Company 3. Ab~RESS OF OPEKATOR P. 0. Box 779, Anchorage, Alaska 99510 At surface: Leg 4, Slot 6, South Middle Ground Shoal Platform "D" 673' FSL, 1763' , FWL, Sec. 35, T8N, R13W, S.M. !5. AP1 NI~ERICAL CODE 50-133-20126 LEASE DESIGINtAT'ION AND SE'tRIAL NO. ADL-18746 ? IF INDIA~T, ALO*f iE~; Ok TRIBE NAME 8. L.~IT FAIRM OR LEASE NAME South Middle Ground Shoal Unit 9 WELL NO 12 10. FIELD A.ND POOL, OR WILDCAT .... South Middle Ground Shoal Il SEC., T., R., M.. (BOTTOM HOL,E o~ Sec. 3, T7N, R13W, S.M. 1~, PEi~MIT NO, 68-56 13. REPORT TOTAL DEi~TH AT END OF MONTH, CHA2qGES IN HOLE SIZE, CASING AN'D C-]/~WIENTING JOBS INCLUDING DEPTH SET AN~ VOLUIVfES USED. PEH.~OHATIONS, 'I"ESTS A.bFD HESULTS FISHING JOB~ JLrNrK IN HOLE A.ND SIDE-TRACKED HOLE A_.'~D A2qY OTHER SIGNIFICANT CH.A-~T~ES IN HOI~ CONDITIONS. Summary of Operations: Durin~ July 1.973: July 1 - 4: Set cement retainer at 10,990' and cement squeezed perfor- ated intervalS 11,060- 11,065' and 11,076- 11,081' with 120 sacks Class G~cement. Cleaned out to 11,090' and pressure test of squeeze interval unsuccessful. July 5 - 9: Set cement retainer at 10,995' and resqueezed intervals 11,060- 11,081' with 75 sacks Class G cement. Cleaned out to 11,090' and pressure tested squeeze interval 11,060- 11,081 to 3300 psi and okay. Set retrievable packer at 10,850' and injected 360 BWPD rate at 2500 psi into per- forated intervals 10,915- 10,950' and 10,963-10,968'. 10 - 12: July 13- 18: Cleaned out to 11,744'. Perforated intervals 10,825 - 10,840'; 11,120- 11,275';-.11,305-11,390'; and 11,405- 11,450' with 2JSPF. Reperforated intervals 10,915-10,950' and 10,963 ' 10,968' with 2JSPF. Isolated perforations 10,915-10,950 and 10,963-10,968' with bridge plug and packer. Injected water at 3 BPM and 1900 psi pressure to test injectivity. Acidized interval 11,405-11,452' with 4700 gallons 12-10 Ultra Mud Acid. Prepared to acidize perforated interval 11,305 - 11,390' and communicated to casing - drillpipe annulus. Acidized intervals 11,102- 11,275' and 11,305- 11,390' with 25,800 gallons 12-10 Ultra Mud Acid using diverter. Acidized interval 10,825 - 10,840' with 672 gallons 12-10 Ultra Mud Acid. ('~ntinue~ttached page) , oil and guT//~rvatlon committee by the 15th of the succeeding month, unle~ otherwlee directed. SMGS Unit Well No. 12 Summary of Operations During July ]973 Page 2 July 19- 22: July 23- 25: July 26- 27: July 27- 31: Set bridge pug at 11,500' and packer at 11 096' and ran spinner and radioactive tracer surveys of perforated intervals 11,102-11,452'. Isolated perforations 11,060- 11,065' and 11,076-11,081' with bridge plug and packer and confirmed additional cement squeeze required. Set bridge plugs at 11,095' and 11,104' and retainer at 10,985' and cement squeezed interval 11,060-11,081' with 50 sacks Class G cement. Pressure test of squeeze interval unsuccessful. Drilled out bridge plugs at 11,095' and 11,104'. Reperforated intervals 10,915- 10,956' and 10,963-10,968' with 2JSPF. While perfor- ating interval 10,963- 10,968' perforator selector switch failed and perforated interval 10,968-10,988' with 2JSPF. Cleaned out to 11,923' PBD. Isolated interval 11,102 -11, 275 ' with packer and bridge plug and tested for communication to perforated intervals 10,915-10,956' and 10,963- 10,968' and okay. Ran injectivity test into interval 10,915-10,968'. Set permanent packer at 11,086'. Ran subsurface water injection flow control equipment and two retrievable packers. Set retrievable packers at 10,679' ann 11,016'. Returned well to water injec- tion service and only injecting ~nto zones below per- manent packer at 11,086'. Injecting water into zones below 11,086'. Form No. P--~I STATE OF ALASKA OIL AND OAS CONSERVATION COMMITTEE MONTHLY REPORt OF DRIllING AND WORKOVER OPERATIONS 1, O,Lw,~L ~]--~°A' [] OTHZ, Water Injection J. N~E OF OP~TOR ~oco ~rod~c~on Comp~n~ 4. ~CA~O~' OF At Surface: SUBMIT ]~ DUPLICA. T~ 99510 Leg 4, Slot 6, South Middle Ground Shoal Platform "D," 673' FSL, 1763' FWL, Sec. 35, T8N, R13W, S.M. A~'I ~t~Emc~ come 50--133--20126 LEASE DESIGNATION AND SE'RIAL NO, ADL-18746 ? IF INDIA~. ALOTT'EE OR TRIBE HAME 8. L.~IT FARM OR LEASE NAME South I~ddle Ground Shoal Unit WELL 12 PI~AD AND POOL. OR WILDCAT _South Middle Ground Shoal n SEC., z., R., ~.. (BO'r'~o~ '~o~.~. .......... Sec. 3, T7N, R13W, S.M. _ . 12. PIgP,.MIT N'O. 68-56 RF~OI~T TOTAL DI~'TH AT END OF MONTH, CliA.NG~' ~H' HOLE sIZz, CkSi~G A~ 'C~~& jO~S }NCLUDiNG DEPTH SET ~ VOL~ US~, P~O~TIONS. ~TS ~ ~SULTS FISHING JO~ J~K ~ HO~ ~D SIDE-~CKZD HO~ ~D ~Y O~ SIGNIFIC~' ~G~ ~ HO~ ~ITIONS. Summa.ry. o~. O.p.erations. During June.. 1973: June 29-30: Pulled injection tubing and drilled out permanent packer at 10,650'. Cleaned out to 11,704'. Set bridge plug at 11,295' and spotted 40 sacks sand on top. Set second bridge plug at 11,095' and cement retainer at 10,982'. JUl. I~ 4 IgT~,~ DIVISION OF OIL AND GAS ~CHORAGE ~ ......... ii i -- --, ,q I , · ,i Il b. erebli~certify treat the/~oreg°tr~ isdtr~ e arid oorrec~ ,; ,,, ~ TXTL~ SuPerVisor in Charge o,~ . Ju!~ 23~ 1973 ..................... oil ~e~ June 27, 1973 File: WMJ-357-WF Amoco Production Compani P. O. Box 779 Anchorage, Alaska Mr. Homer L. Burrell, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: Re: Sundry Notice of Intent SMGS Unit Well No. 12 Attached for your approval is a State of Alaska Form 10-403 reporting our intent to cement squeeze a thief zone and reperforate and acidize selected intervals in the subject well to improve the water injection profile. We expect to begin about June 30, 1973. W. M. Jo~ . Dis trict,~~~duction Superintendent Attachment Form IO - 405 It~:v. ', - ~o-ws . · Bubmit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATIO. N COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to dr/il or to deepen Use "APP-LACATION 'FOR f~'EP,~V~iT-L~' ~or such 'p~o~osals.) 0,Lw~LL ~ OAawELL [] OT.-R Water Injection 2. NA~IE OF OPER2kToR Araoco Production COmpany 3. ADDRESS OF OPERATOR P. O. Box 779, ~orage, Al~ka 99510 4. LOCATION OF WELL At surface Leg 4, Slot 6, South Middle Ground Shoal Platform "D," 673." FSL, .1763' FWL, Sec. 35, T8N, R13W, S.M. 13. ELEVA'rlONS (Show whether DF, RT, OR, etc. RDB 100' above MSL Check Apprepriate I~x To Indfrmte Nature of NOtice, Re 5. AP1 NUiW. F,I~CA~ CODE 50-133-20126 6. LE, A~E DESIGNATION A~D SERIAL NO. APL-18746 ?. IF INDIAN, ~tL~L~'I'l'~:~- OR TRIBE NAME South Middle Ground Shoal Unit WELL NO. 12 10. FIEIA) A~TD POOL, OR WILDCAT South Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 3, T7N, R13W, S.M. 12. PERlV~T NO. 68-56 2~)rt, or Other Data NOTICE OF INTENTION TO: TEST WATER aHUT-OFF I II I~ 1 I 'PULL OR ALTER CASING!j~ FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE I X I ABANDONS REPAIR WELL CHANO~ PLAN~ ,Other) Cement squeeZe SUBSEQUENT RBPORT OF: WATER aHUT-OFF REPAIRING W~LL J FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING , ABANDONMEN'T$ (Other) (NOTE: Report results of multiple completion on Well Completion or Res.repletion Report and Lol~ form.) 15. DFSCRIBE I'n0P0SED OR COMPLETED OPERATIoNs (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work, We propose to perform the following work to improve the water injection profile of thiS well: lo Pull tubing, drill out permanent packer at 10,650' and clean out to 11,600.' . me Set bridge plug at 11,295' and plug back with 10-20 sand to approxi- mately 11,120'. to protect perforated intervals below the thief zone 11,060 - 11,081'. 0 Set bridge plug at 11,095' and cement retainer at 10,980' and cement squeeze perforations 11,060 11,065' and 11,076-11,081' with 120 sacks Class "G" cement. ~ pressure test cement squeeze interVal to 2500 psig. ~ 5. Clean out to 11,700'. co¢ ( nue tached page) slo~D .. ~~ ~I~1 Distric~ P~°du~ti°~ pupt' DaWm ~e ~, 1973 RA CO~DX~XO~S ~.~R~AL, z~ ~ intrusions ~ Rever~ Side Form 10-403 SMGS Unit Well No. 1'2 June 27, 1973 Page 2 . Perforate fOllowing intervals at 2JSPF: 10,825 - 10,840'; 11,120 - 11,275'; 11,305-11,390'; and 11,405-11,450'. · Acidize following intervals with a total of 32,000 gallons of 12-10 Ultra Mud Acid using retrievable' bridge plug and packer to isolate each interval: Per.forated 'Interval 12-10 Mud Acid Volumes 11,405- 11,452' 11,305 - 11,390 ' 11,102.- 11,275' 10,825 - 10,840 ' 4,700 gallons 8,500 gallons 17,~300 gallons 1~500 gallons TOTAL 32,000 gallons · Clean out to 11,600" land set a retrievable packer on drillpipe at 1I¢090'' · Inject water and run radioactive tracer/spinner water.injection profile survey across perforated intervals 11,102 - 11,45'2'. Pending results of the.water injection profile survey of Step 9, water injection equipment willbe installed in one of the following configurations.: 11. a· Set permanent packer at 11,090'. Run subsurface water injec- tion flow ~contrO1 equipment and retrievable Packer on tubing ~and sting intopermanent packer. Set retrievable packer at 10,670'. ~Se.t permanent packer at 11,290'. Run subsurface water, injec- tion' flow c~ntrol..equipment and two re~trievab!e packers on tubing and sting into permanent packer· Set retrievable packers at 10,670' and 11,090'. Return well to water injection service. We. anticipate this work-wi!I begin about ~June~ 30, 1973. Form P--3 STATE O,F ALASKA Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION CO,MMITTEE .. SUN:DRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR P~IT--" for such proposals.) 1. WELL WELL OTHER 2~ NA_~iE OF OPERATOR Pan American ~etroleum CorpOration -~i ~D~ss oF OP~ATOR P. O. Box 779, Anchorage~ Alaska 99501 ~OCATION. O.F W~LL At~,~ce Leg 4, Slot 6', South Middle Ground Shoal platform "D" 673' FSL 1763' FWL, Sec 35, T8N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, C~R, etc. RDB 100' above MSL HLB '5 AP1 NUIVI. FA~CAL CODE i 50-133-20126 UNIT, F~ OR ~SE N~E South Middle Ground Shoal Unit ]9. w~L NO. '" ' ~ i2 T t_____ _ _' _ I 8ec._3~7~~ R13~ 8.~. Check Appropriate Box To I~ndi'c~te Nlature of NOtice, Report, or Other 'Data SUBSEQUENT REPORT OF: WATER SItUT;OFF REPAIRING WELL . FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZINO ABANDONMElgT* (Other) COnvert to W~tter Injection NOTz: Report results of multiple completion on Well ompletion or Recompletion Report and Lo~ form.) NOTZCE OFZ~TZO~TO: TEST WATER SHUT-OFF ~-- PULL OR ALTER CASING ~ FRACTURE TREAT __ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANGE PLANS (Other) ~5. DESCRIBE I'nOP0SED OR COMPLETE~ OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting an.y proposed work. Water injections into this well commenced at 2:30 p.m. on April 9, 1970. The initial in~ection rate was 394 BWPD at 1500 psig, The injection rate has increased to 3500 BWPD at 2000 psig as of April 13, 1970. The folloWing is a chronological outline of the conversion: · 4/6 - 4/8/70: Pulled Kobe pumping equipment and cleanout the wellbore. 4/9/70: Run single 3%" tubing string for water injeCtion and ni'pple u'p wellhead. Start water injections at 2:30 'p.mo RECEIVED APR i976 DIVISION OF OIL AND OAS ANCHORAOI~ 16. I hereby certify ths~ :th~ fore~oin~ is true and corree~ (This space for State office use) TITLE Area Superintendent DATE APPROVED BY CONDITI~ONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Approved Copy Returned Form P--3 REV. 9-30-67 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE O,F ALASKA OIL AND GAS CONSERVATIO,Ni CO,MMII'I'EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PERiViITM" for such proposals.) 0IL ~. OAS ~--~ WELL WELL OTHER 2. NAME OF OPERATOR Pan Axnerican Petroleum Corporation 31 ADDRESS OF OPERATOR 4.LOCATION. O,F WELL At surface Leg 4, Slot 6, South Middle Ground Shoal Platform "D", 673' FSL, ~763' FWL, Sec. 35, T8N, R13W, S. Mo API NU'NXFA~CAL CODE 50-133-20126 LE~E DEC~IGNATION ~ND SER~ NO. ADL- 18746 , ?. IF INDIAN, ALLOTTEE OR TRIBE NA1ViE 8. UNIT FAi~IVX OR LEASE NAME South Middle Ground Shoal Unit 9. W1~L,L NO. P. O. Box 779, Anchorage, Alaska 99501 lZ 10. FIELD AdND POOL, OR WILDCAT South Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 3, T7N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc- 12. PER1VIIT i~O. RDB 100' above MSL 68-56 Check Appropriate Box To I~nd',i'cete Niature of N~oti'ce, Re ~ort, or Other' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I ] PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPI,ETE SHOOT OR ACXDIZE ~ ABANDONs REPAIR WELL L____J___ cHANGE PLANS (Ot. her~ Convert to Water Injection SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACXDXZXNG ABANDONMENT$ (Other) . (NOTE: Report ~esults 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 an.y proposed work. we'plan t© convert this producing well to water injection service as per our application of April 16, 1969, .-File: AMR-967~986. 511, and State approval of April 23, 1969. Estimated date that work will begin is about April 1, 1970. 16. I hereby certify tha~ :-the foregoln~ is true and correct (This spacZor State o~'eeTuse)/~ _ TITLE Area Superintendent CONDITIONS O]~/'~PPROVAL, IF ANY: TITLE DATE DATE March 10, 1970 See 1,ns~rucfions On Re,~erse Side pproved Copy Returned ,;,.':?-':- :!:;.!....,... :.. *:':'121!.¢:':.; .o ,. m P--7 :: SUBMIT ~N DUPLICATL~ , . STATE OF ALASKA (See other struct ions on OIL AND GAS CoNsEI~VAT!ON coMMITTEE - reverse side) , ,, ~ i ?J ' - - WELL cOMPLETION O.R RECOMPLETION REPORT AND LOG* Othe~ WELL~ ~ELL DRY TYPE OF COMPLE~ON: .'- WELL EN BACK EESVR. OVER - Pan ~eri~.~e~ro.!e_um C~rpP~.%.~ ........... : ...... -~:; ~, . ADDRISS OF OPERATOR ~ , P. 0. Box 779 - Anchorage, Alas~ 99501 :~ . . . ~ocaw:os or wz~n (R~or~ ~o~o~ olear~ ~ng ~ ~oo~aoe"~i~ ~ ~ r6~¢rem~nt~ ) * Le ~, 8lot 6, 8~8 'D'; 673~ ~S~ 1763~ ~L~.} 8ec.;35, 1160~ ~8L, 139~ FEL, Sec. 3~ TT~ :R13W~ S.~. ~t total ~ ~: ~' ' . D. Alii NU1VIF. ZtlC, AL CODE 50-133- 20126 6. I.~A~E DE~IGNA.TION AND SERIAL NO. ADL- 18746 ?. IF INDI~, A.I.Z~ OR THIBE NA1VIE 8. UNIT,F2A~/~I OR LEASE NAME South Middle Ground Shoal 9. vn~L No. Unit 10. Fr~,r~ A~TD POOL; OR WI"LD~T . soUth Middle Ground Shoal 11. SEC,: T.,.'R.; M., (BOTTOM HOL~ OB~F~'rlv~) Section 3:, T7N, R13W, S.M. -- '-- Xs, PERM~ NO. ! 833' FSL, 98' FEL, Sec. 3, T7N, RI3W, :$.M. ~ ; - t~_,6 . 8/28/68 ] 10/i4/68 / 11/13/68 Ii :R~ 100' above MSL 18~ T~ D~H .~ & TVD~9. ~LUG ~ MD & ~D~. ~ ~LT~ ~L., "~ [ ~1. ' INTERVALs DRILLED BY i ' "D~' . ~W~Y* ~ ':'1ROTARY TOOLS :'l ' CA ab,: TOOLS ~ ':~ ~0~825 - 11,452': ~Lo~er Kenai Member ' " '-' ~.~ ~E ~.~C ~D OT~ ~S:~. ~ , '. · lES GR-Sonic~ Dipmetc~ ~. ~ .... ~ ' C~G ~ (Re~ all str~s set ~ '~!1) , - . i2- ~/8" 1587' 1770 sacks ~ 9- 5/8" 461 ' ,,: 1060 sacks -. : 'l 't.: '-t-" ~.: PE~O~TIONS OPEN ~ PROD~ON (In~l, size ~d numar) m. : AC~, SHOT,'F~'~,-'~ SqU~ZE, ~C. 11,076-81,~11,102-~2~ ;I1,138-68, 11~178-98, '~' /..'J ' · il,203-08~ 11,215-30~:~11,240-55, 11~265-75, ~ il,305-15~ 11,320-55~3.11~345-55, 11,360-70~ [ 11,375-90~ 11:405-25, :I1~437-52, DATE FIRST P~ODUC~ON [ .~6C~ON MmI'HO'D (~owh~, ~ li~t. pump~s~ze~ and~tYpe~ of p~P) il/3/68 I :~ ':-.Pumpin~ :: :. :, _ ] Producing ~ ~ o~ T~ST. -[HO~S T~ - [~O:<E S~ZE [~OD'N FOA O~ . ~CF. : WA~B~.. [ G~-O~ ~O ~ ' H ~T P~OD 11/13/68 , [ 24 ' ':~[ 40/64 .-~ ~ [. 881 [ i72 ..~ 377 FLOW ~mm~ ~m~ ~s~ IC~~ o~n.~. ~~. WA~m~. Iota o~v~w-~ (c~.) ] ' ,":,[ t'>~t' ' I ~ ' [ ] 34'40 : Used, for fuel and f~:ared. ~ .IES~ Chronological ~11 History~ Directional Data ' 33. I hereby eert~y that the ~oregoing a~ attached information is ebmglete and eorrebt as determined from all:available records : SlONmm ~- ~ .. T~W~m A ea Admin;~ Supervisor DATE 12/12/68 I I ~ I ' '~ ' '' INSTRUCTIONS General: This form is designed for subm~li~n9 a complete and correct ,,,veil completion fei>orr and Io9 on all types of lanJs a~d leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachments. Items:'~0, .nj :2:2:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the p~cJucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each ad6itional inte~ val to be seperately produce, J, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this wel~l 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 produced. (See instruction for items 20 and 22 above). , , 34. SUMMARY OF FORMATION TESTS INCLUDIN(; INTERVAL TESTED. I,RF_.SSURE DATA A.N'D I:LECOVERIES OF OIL. GAS. 35. GEOLOGIC WA"I~,R AND MUD NAME MEAS. D ElY TI-I, , c H±ddle :Kena± 563/4 ('~ ,.-. ~ :~-.: '. ..... "~ Lower Kenai ' · t , ".', :.,~ '~. ',':.' Conglomerate 10,820 ~'~ ~O ' , ~ , 36. CORE DATA, Aq~FACI{ BRIEF D~CRIPI~ONS OF LiTHoLoGy, POROSITY, FRAC~R~: APP~NT DIPS AND DETECt'El) SIIOWS OF OIL, GAS OR wa~. , , . , .. , . . SMGS UNIT WELL NO. 12 Chronological Well History 8/28 8/29- 9/1 9/2- 10/7 10/8- 10/26 10/27- 10/30 11/1- 11/3 11/4- 11/12 11/13 Spudded from surface. Conductor pile was bent and caused bit to drill into another well. Moved to Leg 4, Slot 6, and re- spudded. Drilled 12~" hole 1500'-3480', opened to 17~" to 1600', and set 13-3/8" casing at 1587' with 1770 sacks. Drilled 12~" hole 3480-10,467', logged and set 9-5/8" casing at 10,461' with 1060 sacks. Drilled 8-5/8" 10,467'-12,000', logged, and set 7" liner 10,174- 11,973' with 360 sacks. Cleaned out to 11,923' and ran tubing. Attempted to perforate after running tubing. Guns would not pass through BHA. Pulled and reran tubing. PBTD 11,923'. Perforated intervals between 10,825' and 11,425'. Installed pump. Pump tested. PBTD 11,923'. Completed as a pumping oil well. O'qqoq J ~<~J~l 1212.. ! · :¢o, 'lg i:,'o 1, I~ .'1 ,;'II l l07&.:to: t, ~%- "1 q4 992~ IO 109 ~'7 I irection Course Dep th Factor PAN AMERICA~ PETROLEUM CORPORATION Lat. Def. /% TVD 2~.~ 2. Factor Factor J.~, ~f. / . J,:.7<A'"' -- ' '78'99. Oq ~7. 19. o~- II ~'.'i5 o .'7 ~. ~_1, 05- I Ii,?-.I ~.'P', 'P t J ,q I.._% w N DIRECTIONAl, CONTROl, J S ;2.1 o,75 I E J W 125-q,Tq ~ .... l, ZO J l4o~,~8 ~ o.oo J4 5~-S ,~5 Z~ ! !~ 59o, ~3 1 i~'o 3 5 J J 9,~d~ .oE 0 ?)0 O,~-- Z,~' D~rection O, Depth PAN AMERICAN PETROLEUM CORPORATION Lat. Def. DIRECTIONAl, CONTROL ~RG ,Z.O LCD [14o~,.~8 ~ o.oo c~z.t 0,~o0 '9 I0 I 1082_0 112. .01 Ii zo, ~0 Direction ;o ! PAN I ! l,qT,,oq i il~, tko ilO, Oq .',,52. [Z~.l FORM 470 2-57 PA A mnCA PETROLEUM COILOO ION P. O. Box 779 Anchorage, Alaska 99501 December 20, 1968 File: FKK- 1313-501 Mr. Homer L. Burrell, Director Division of Oil and Gas State of Alaska Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99504 Re: Granite Point and Middle Ground Shoal Completion Reports Dear Sir: With reference to your December 13th request 'for completion reports and data on certain Granite Point and Middle Ground Shoal Wells, please be advised of the following: 1. SMGS Unit Well No. 12: Completion Report, Form P-7, and aSsociated data were filed on December 12, 1968. 2. MGS State 17595 Well No. 14: Packer leakage test data are being assembled, after which Completion Reports will be filed, probably during the 'first week in January. 3. Granite Point State 18742 Well No/ 27: This well has been shut-in for some time for lack of production, pending analysis of the frac job on G. P. State 18742 Well No. 6. It has been decided to frac Well No. 27 and preparations for this job are now underway. With your concurrence, we will defer filing a Completion Report until after the frac job has been completed. 4. G. P. State 18742 Wells No. 14 and 22: Future status of these wells is currently under consideration. We expect a final decision during the first week of January, after which the applicable reports will be filed. 5. SMGS Unit Well No. lQ:. Our Sundry Notice dated October 4, 1968 stated our intention to abandon this well. It is currently being analyzed, however, for possible inclusion in a SMGS waterflood program. As with G. P. State 18742 Wells No. 14 and 22, a decision as to this well's future status will be made in early January, after which the appropriate forms will be filed. I~ RECEIVED DEC 24 196 DIVISION OF OII. AND GAS ANCHORAGE Homer L. Burrei~~ - 2 - December 20, 1968 We regret the delay in final completion of these wells and hope that you will find satisfactory the filings set forth above. Yours very truly, Area Superintendent Fielq t'ndtcates th,at certain da'~a haw not b~oj;~ s.u6~d'~t~.d t<~ t,~is office, ~ cai 1 your att~.a'ti o~ to ~'~e i te~s ~er ti ~e~:t to t:~:~:e fo:l 1 owi:~g ~ t ! ~ ~tary tr~;ly Form No. P--4 REV. 9-30-6~ SUBMIT IN DEPLICATE STATE O,F ALASKA O~L AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF ~DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER 2.NAA~E OF OPElq2%TOE Pan American Petroleum Corporation ~DnRESS 'OF OPER~'roa P., 0. Box 779 - Anchora~e~ Alaska 99501 4.LOCATION O'F Leg 4, Slot 6, SMCS Platform Dillon; 673' FSL, ~763' FWL Section 35, TSN, R13W, S. API NUA, SERICAL CODE 50-133-20126 LEASE DESIGNATION AXD SERIAL NO. ADL - 18746 T. IF INDIAN, ALOTTEE OR TRIBE NAME 8, UNIT,FARM OR LEASE N.~ME South Middle Ground Shoal Unit 9, WELL NO. 12 10. FIEI~ AND POOL, OR WILDCAT South Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTrVE) Sec.? 2, T7N, R13W, S. M. 1% PERMIT NO. 68-56 13, REPORT TOTAL DEPTH AT F2~D OF MONTH, CHANGES IN HOLE SI~.E, CASING AiTD CEMENTING JOBS INCLUDING DEPTH SET AND VOL~ USED, PERFOiRATION$, TESTS A1TD RESULTS, FISHING JOBS, JUNK IN HOLE A3~D SIDE-TRACKED HOLE AND A2~Y OTHER SIGNIFICANT CH3%N-~ES IN HOL,~ CONDITIONS. 11/1- 11/3 11/4- 11/12 PBTD 11,923'. Installed Pump, Pump tested. 11/13 PBTD 11,923'. Perforated intervals between 10,825' and 11,425' Completed as a pumping oil well. RECEIVEI) DEC 1 DIVISION OF OIL AND GAS ANCHORAGE 14. I hereby certify t~t t correct SZGNED ~ ~ITLE Asst. Area Admin. Supvr. hA'ri December 12, 1968 NOTE--Report on this form is uire~l for each calendar month, regardless of the status of operations, ancl must be filecl in duplicatt with the Division of Mines & Minerals by the 15th of the succeeding menth, unless otherwise directed. F*or'm ~o. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICA~I"~ MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS A~ Sm{EmCAL ~OnS 50-133-20126 LEASE DESIGNATION A.X'D S~RIAL NO. ADL- 18746 :~. N,~-*~E O~ OP~,.TOe Pan American Petroleum Corporation 3. ADDRESS OF OPERd~TOR P. 0. Box 779 - Anchorase, Alaska 99501 4. :rnCA~ON o~ wm,n Leg 4, Slot 6, SMGS Platform~Dillon; 673' FSL, 1763' FWL, Section 35, T8N, R13W, S. M. 8. UNIT,FARM OR LEASE NAME South Middle Ground Shoal Unit g. WELL NO. 12 10. FIELD AND POOL. OR WILDCAT South Middle Ground Shoal 1].. SEC., T.,~ R., M., (BOTTOM HOLE Sec. 2~ T7N, R13W, S. M. 1~-. P~P. MIT NO. 13. REPORT TOTAL DEP~I-I AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CI~ViENTING JOBS INCLUDING DEPTH SET ~ VOLUMES USED, PER~FORATIONS, TESTS A1%rD RESULTS, FISHING JOB~, JLTNK L~ HOLE A_ND SIDE-TR~CtCED HOLE A_~TD A~TY OTHF..R SIGNIFICANT CTIA_N~ES IN HOL]~ CONDITIONS. 10/.31 10/1- 7 10/8- 26 lO/27- 30 PBTD 11,923'. Preparing to perforate. Drilled 12~" hole 9960'-10,467', logged, and set 9-5/8" casing at 10,461' with 1060 sacks. Drilled 8-5/8" 10,467'-12,000', logged, and set 7" liner 10,174- 11,973' with 360 sacks. Cleaned out to 11,923' and ran tubing. Attempted to perforate after running tubing. Guns would not pass through BHA. Pulled and reran tubing. 14. I hereby certify that the foregoing is ~gue:and ~rrect S~GN~D - 'n~ Asst. Area Admin. Supvr.nA~ November 11~ 1968 , ~ NOTE--Report on this form is raq~red for each calendar month, regardless of the status of operations, and must I)e filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. SUBMIT IN DUPLICATE ~. API NU~EmC~L CODE Form No, P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF ~DRI. LLING AND WORKOVER OPERATIONS WKLL IVELL 2. NAME OF OPERATOR Pan American Petroleum Corporation 3. ADDRESS OF OPEI%ATOR P. O. Box 779 - Anchorage, Alaska 99501 4. LOCATiON OF WELL Leg 4, Slot 6, SMGS Platform Dillon; 673' PSL, 1763' FWL, Section 35, T8N, R13W, S. M. 50-133-20126 LEASE DESIGNA~--ION AND S~%RIAL NO. ADL- 18746 ?. IF INDIAL[, ALOTTEE OR TRIBE NAME 8. UlN'IT,FARA~ OR LEASE NAME South Middle Ground Shoal Unit 9. WELL NO. 12 10. F!F.T.r~ AND POOL, OR %VILDCAT South Middle Ground Shoal I1. SEC., T., R., M., (BOT"FOM HOLE oB,mc-riv~ Sec. 2, T7N, R13W, S. M. li. PERMIT NO. 68-56 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA~NGES IN HOLE SIZE, CASING AIN-D CEMENTING JOBS INCLUDING DEPTH SET Ala-D VOLUMES USED, PERFORATIONS, TESTS A_N-ID RESULTS, FISHING JOB~, JU!~K IN HOLE AND SIDE-TI{AC~ HOLE ANT) AJqY OTIiER SIGNIFICANT CI-IAN,GES IN HOI~ CONDITIONS. 9/30 TD 9960'. Drilling. 9/1 Drilled 12~" hole 1500'-3480', opened to 17~" to 1600', and set 13-3/8" casing at 1587' with 1770 sacks. 9/2 - 30 Drilled 12~" hole 3480'-9960'. RECEIVED OCT 15 19 8 DIVISION OF MINES & MINERALS ANCHORAGE 14. I hereby .certify that the correct S~N~n ~-~' Asst. Area Admin. SUpvr. n.T~ 10-14-68 NOTE--Report on this form ~uired for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Form No. P-.--4 REV. 9.~,.61 STATE OF ALASKA OIL AND GAS CONSERVATION COMMI~EE MONTHLY RE*PORT O:F DRILLING AND WORKOVER OPERATIONS =. ~i~E' oF oP~roR SUBMIT IN DUPLICATE AP1 NLr~IERICAL CODE 50-133- 20126 6. LEASE DESiGNA~'ION AN-D SE%RIAL NO. ADL- 18746 ?. IF INDIAN, AI~D'I tEE OH TRIBE BLAME 8. LTIN-IT,F.~I OR LEASE NAME Pan American Petroleum Corporation 3. ADDRE$SOF'd~ERATOR P. 0. Box 779 - Anchorage, Alaska 99501 4. ~.~CA~6N '0~ WELL Leg 4, Slot 6, SMGS Platform 'D'; 673' FSL, 1763' FWL, Section 35, T8N, R13W, S.M. SMGS Unit g. wE.!,L ~0. 12 10. FiEi .r3 A_ND POOL. OR WILDCAT South Middle Ground Shoal 11. SEC., T., R., M.. (BOCci'OM HOI~E OB0~TrvE) Sec. 2, T7N, R13W, S.M. 1~.. PER1ViIT NO. 68-56 '13. REPORT ~oTAb DEPTH AT F2qD OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET ~ VOL~ US~, p~O~TIONS. ~TS ~ ~SULTS, FISHING JO~. J~K ~ HO~ ~D SIDE-~C~D HOLE ~ ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS. 8/31 8/27-28 8/29-31 TD 1500'. ~rilling. Spudded from surface. Conductor pile was bent and caused bit to drill~0~p Moved to Leg 4, Slot 6 and re-spudded. , Drilled 12-1/4" hole 0 -1500'. ANCHORAGE ~4. I hereby certt}y_%h~t ~hl~ore~oiDg is ~e and eorrec~ .... ~. ~/~. ~)~ _~ Asst. Area Admin. ~va~ 9-12-68 NOTE~Report on this rm is required for each calendar month, regardless of the status of operations, ancl must~ be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Form REV. 9-30-6? Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMII-[EE J , . 50-133-20126 SUNDRY N'OTIC'ES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a di££ieren% reservoir. I ADL - 18746 Use "APPLICATION FOR PERMIT--" for such proposals,) Wr. LL WELL 2. NAME OF OPERATOR .[ 8. UNIT, FA~tl~ OR LEASE NA_ME Pan American Petroleum Corp. ~ SMGS Unit 3. ADDRESS OF OPERATOR ] 9. WELL 1UO~ P. 0. Box779-Anchorage, Alaska 99501 ,t10 FiEi~D 4. LOCATION O,F WF_~L . ~ O1% WII.~CA.T At surface Ground Shoal le New Location: Leg 4, Slot 6, SMGS Platform 'D'', ~ OB~CrZVE) (myrTo~ 673' FSL, 1763' FWL, Section 35, T8N, R13W, S.M. ] Sec. 2, T7N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, Cvl~, etc. ~ ~-- ,~12' ~'~:HAEIT I~O. RKB 100' above MSL [ 68-56 ! Check Appropriate Be~'To I,nd',icate N~at'ure of N~oti'ce, Report, or .Other 'Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPL~ COMPI,ETE SHOOT OR ACIDIZE ABANDONs IIEPAIR WELL CHANGE PLANS (Other) Change drilling slot SUBSEQUENT REPORT OF: WATER SHUT-OFF REPAIRING WELL I FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMEI~'Ts (Other) NOTE: Report results of multiple completion on Well ompletion or Recompletion Report and ~Log form.) ii i, 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an? propo.ed work. Surface location of Leg 2, Slot 5, shown on Permit to Drill #68-56, has been changed to Leg 4, Slot 6. 16. I hereby certify that -the fore~oin~ l~ &n~correet (Thia ,pace for State office use) CONDITIONS OF APPROVAL, IF A~: ~ ' TITLE Asst. Area Admin. Supvr. DAT~ 8- 29-,68 See ~nstrucfions On Reverse Side P. O. Box 779 Anchorage, Alaska ~o=n~. August 29~-1968 File: FKK- 946-'~.~ Re: Spud ,Ye~-~ Well, SMGS Unit ?~12 Director Division of Lands State of Alaska Department of llatural Resources 344 Sixth Avenue Anchorage, .~lnska Dear Sir: This is to notify y~ that the subject veil ',~as 5~udded 9'~ 1968. %~.e su~-face loca- on State Lease ~DL-18746 oh Jugust ~o, tion of this ~.,ell is at SE~t4 [S'~';~/4, Section 35~ TSN, R13W, $.M. We plan to drill this we}Il directionally to a bottom hole location of S;7/4 SW/4, SectiOn 2, Yours very truly, C):['~gma, ~igned by; F, K. K.P BILL F. K. Krebiil Area Superintendent' MCW: sp FORM SA- I B 125.5M 8/67 MEMORANDUM TO: ~' FROM: ~ ~ lbzdm11, Jr. rdrl Lo Vemdmmtm state of Alaska DATE : SUBJECT,' FORM SA- I B 125.5M 8/67 MEMORANDUM TO: [- FROM: 'State of Alaska DATE : SUBJECT~ ? Form P--1 REV. 9-30-67 SUBMIT IN (Other instruction~'M~ reverse side) STATE OF ALASKA OIL AND. GAS CONSERVATION ,COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK ~¥P~ OF WORK PLUG BACK [] MULTIPL~ ~_~ ZONE DRILL IR] DEEPEN [-1 ~INOL~ L ~ WmLLOA8 ~ OTH"R ZONE ~LL ~ME OF OPERATOR Pan American Petroleum Corporation )DRESS ~ OP]gR~TOR P. 0. Box 779 - Anchorage~ Alaska_ 99501 ;ATION O'F WELL surface Leg 2, Slot 5, SMGS Platform 'D'; 1874.5' FWL, 694.5' FSL, Section 35, T8N, R13W, S.M. ', proposed prod. zone 380' FSL, 330' FWL, Sectioff 2, T7N, Rt3W, S.M. ISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 15-1/2 miles NEW of Kenai, Alaska ~ ~OND INFORMATION: 'YPE Blank~etpaojq~r ~. force DISTANCE FROM PROPOSED* ~ ~-~.! ~__~" ~ ,', ~ ..]16. NO, OF.ACRES IN LE~SE LOCATION TO NEAREST ~U, zou ~rom mornn ~RO,ERTY O~ LEASE LINE. ~. ~--- ~= ~ :~o.,. = [ 4160 (A~ tO nearest drig, unit if any) ~1~ ~l ~-- ~O~ DISTANCE FRO~ PROPOSE~ LOCA~ON* ' '- ~] 19. PROP~S~ D~ TO NEAREST ~ELL DRILLING, COMPLETe, ] OR APPLI~ FOR, ~. ' / 1970' South of S~GS Unit t~5 [ 12,000' API 50-133-20126 §. 6. LF_dkSE DI~IGNATION A/NqD SERIAL NO. ADL- 18746 1. IF INDIAN, ALI~TTEE OR TRIBE NAA~[E 8. UNIT~ FAR/VI OR LEASE NAME SMGS Unit 9. WELL NO. 12 10. FIELD AND POOL, OR WILDCAT South Middle Ground Shoal er 11 SEC.., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 2, T7N, R13W, S.M. 12. ~ouJ~.t l?. N~O. ~I~Es ASSIGNED TO THiS WELL 80 20. ROTARY OR CABLE TOOLS Rotary · ELEVATIONS (Show whether DF, RT. CR, etc.) 22. APPROX. DATE WORK WILL START* RKB 100' above MSL ~ July 5, 1968 I. PROPOSED CASIN~-AND CEMENTING PROGRAM .... ' '- , SIZE OF HOLE: SIZE OF CASINGJ 'WEIGHT ~ER F~OT ' GRA]DE~ [' SETTING DEPTH ':' ~,- -.; . ,QU,NTiT,-.._ . OF'CEMEN~ _ l ~7-1/2" 13-3/8" 54.5~ J-55 1600' Circula~e to surface 12-1/4" 9-5/8" 40 & 43.5~ S-95 & 10,~50,0' ~Miuimum~of:500' above shoe N-80 ..... ~: ', ~ :' , 8-5/8" 7" l~ner' ' 26~) S-95 10 ~ 200-12 , 000 Complete f~tlup from shoe to ~an~ ,, . , , . .- ~J. , · , .,~ 1. Deviation required to reach BHL from permanent platform. 2. There are no affected operators. 3. BOP specifications attached. 4. Intervals of interest will be perforated and may~i~e stimulated. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zor~e and proposed r~ew productive zoz~e. If pr(~posal is %o drill or deepen directlonally, give pertinent da~ on s~bsurface locations and measu~d a_nd true vertical depths.Give blowout 1,reventer program. ,. June 14 1968 (This space for State office use) '~.', CONDITIONS OF APPROVAL, IF ANY: SAMPLES ANI~.,~ cHIps REQUIRED ~ tl~---~U~S: [D~i~ETONAL sUR~y.~~ ; A.P.I. ~CAL CODE ~YES [] NO ~'~:"'" ': ':" ',:.':.:~.~... ~4~d> -/.~J '-- 2 O/Z ¢ . Asst.Area Admin. Supvr. ~(~' ~ ~ APPROVAL DATE PERlVlIT NO_ / f/~~~,,.., t~l'' 8~; ~ txecutive becreta rY APPROVED BY.. - TI~.. Conser~fipn Commiffeo *See In~ucti°ns On Revere I I I ! I I I I I 1 . l-lydr.i i 2" Check Valve Spool --+----Pipe Rams · 4" plug or Igate valve 2"Plu Valve 2" Plug or Gate .Valve i-2" Plug Valve on side Equipment below gl'lis point furnished by Pan 4" pzug v~ive- 4" line w/shop made s.'..;ae',~ ~:/no more ~han 45c' ~end lank -~. 2" plug valve .... ~ = ... 2" line 2" choke ~ 2" i .-,~{ud ~au~e ~"- plug valve ~.'~ All preventers to be hydraulically operated from ar~ accumulacor which will open and ¢io$e hydz~i! a~ %'a'as~ ~hree times'without recharging. 2. All equipmen~ thru which bit mus= pass to have at least as large iD as casing being drilled through. 3. Kelly cock to be on Kelly fa-om =ime of spud. 4.~ Drill pipe safety valve equivalen= ~o Shaffef Mod. 55 or 0MSC0, with proper connections, ~o ba on rig floor at all ~imes. 5. All equipnien~ men=ioned above ~o be 5000~ WP or stronger. 6. All connections to be fleeted, 7 0perat~n~ r,,~r, ifoid to be in easy reach of drillers station w/~l ~'erao~e opera~ing s~a:ion. . ,