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167-028
1a. 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 30"450 20" H-40 596 13-2/8" J-55 1,986 9-5/8" N-80 & S-95 10,261 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 Sr Res EngSr Pet GeoSr Pet Eng Middle Ground Shoal / E,F and G Oil, Middle Grnd Shoal Oil N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing N/A Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 54.4# 10,439 Surf Surf 97# 450 Surf 2,006 SIZE DEPTH SET (MD) 9,361 / 9,191 PACKER SET (MD/TVD) 2-7/8" Surf 40#, 43.5#, 47# Surf Surf 596Surf Surf CASING WT. PER FT.GRADE 9/14/1967 CEMENTING RECORD N/A N/A SETTING DEPTH TVD 2462538.9 TOP HOLE SIZE AMOUNT PULLED N/A 228086.5 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 50-733-20023-00-00 S MGS Unit 03 ADL0018746 670' FSL, 1771' FWL, Sec 35, T8N, R13W, SM, AK 661' FNL, 670' FWL, Sec 2, T7N, R13W, SM, AK N/A 6/22/1967 10,500 / 10,322 Surface 100 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 229217.0 2463844.3 N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 9/20/2022 167-028 / 322-402 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 9,275 9,356 3-1/2" 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 9/20/2022 JSB RBDMS JSB 102722 xGDSR-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: 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. Authorized Title: 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. 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. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. 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 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 13:12:05 -08'00' Dan Marlowe (1267) Di-03 Cement plug #2: LS, SS, IA, OA, & OOA: Surface - 400’ Cement plug #1: LS: 3,750’ MD - Est. 9,273’ MD SS: 3,233’ MD - Est. 9,273’ MD IA: Est 3,000’ MD - Est. 9,273’ MD Rig Start Date End Date SL 8/2/22 9/20/22 08/02/22- Tuesday Rig up to circulate well, check pressures SS 140, IA 200, pump @ 1.4 BPM, down SS taking returns up IA, took 35 bbls to catch returns, getting back gas/oil, mix. Pump total 65 bbls no change. Decision made to circ out later due to wind direction. S/D secure well. 08/18/22 - Thursday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 03 50-733-20023-00-00 167-028 Held PJSM and approve PTW. Di-03 well pressures, LS/SS/IA/OA/OOA= 0/210/195/10/10 Began filling uprights with FIW. Injected 320 bbls of brine/oil from return tanks into Di-17, SD pump due to packing leak. R/d HAL cement pump and eq., loaded on boat, sent to beach for upcoming rig 169 cement job, repaired packing on fluid pump. Cont. injecting 420bbls of brine/oil from return tanks into Di-17. R/u circulating eq. on LS. SS and IA, found master and swab leaking on SS, greased and cycled valves to make hold. Housekeeping around work areas. 08/19/22 - Friday Held PJSM, Approved PTW. Checked well pressures, LS/SS/IA/OA/OOA= 0/210/195/10/10, Bled off SS and IA all oli/gas. Lined up to pum p dn LS returns up SS, Began pumping 2bpm and broke circulation @ 2bbls away, circulated 12 bbls w/good brine returns. SI the SS and opened IA, pumped 22bbls and catch returns, circulated 120bbls @ 2bpm/800psi, hold WHP @ 400psi, returns oil/gas/light wt brine. Work boat arrived, SD pumping due to wind direction to work crane, back load Solos and sent to beach. Continued circ down LS returns f/IA @ 2bpm/psi hold WHP @ 600psi, after 200bbls seen good 9.8 brine at surface, increased rate to 3bpm/1200psi holding WHP @ 600psi, continued circulating until returns @ 9ppg. SD pump. Recovered 195bbls of 9.8 Brine for upcoming cement job. Removed tree caps on D-4 and installed circulating flanges on the LS, SS and IA. Work Boat arrived, off loaded solos and HAL cmt plug and eq. from boat. 08/20/22 - Saturday Held PJSM and approve PTW. Check well pressure, LS/SS/IA/OA/OOA 100/60/100/10/10 , Top of upright tanks with FIW, rolled tank 3 with HRS water. MIRU HCU pump and equipment, emptied transport solos, work boat arrived, loaded solos on boat and sent to beach to fill. Pre-job, filled and PT lines t/3200psi, lined up to pump dn LS returns up IA, pumped 50bbls of FIW w/Mud wash, followed by 168bbls of 9.8ppg Brine 3.5bpm/950psi, mixed and pumped Pump 447bbls (1610) of 14ppg class G cement @ 5bpm/1400psi, after409bbls swapped returns to from IA to SS, dropped wiper ball, displaced w/17bbls of 9.8 brine. Cal job vol 500bbls Total vol returned 483bbls. Monitored well for 30mins, LS/SS/IA 0/0/0 Performed sheen test (no sheen), cleanup lines and pump overboard. Filled Upright Tank and mixed HRS and rolled tank. Work boat arrived, assist crane with off loading solos. Rig Start Date End Date SL 8/2/22 9/20/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 03 50-733-20023-00-00 167-028 Held PJSM, approved PTW Serviced and worked eq. R/u SL Unit, wait on state inspector to fly out and witness tag. Heliport on weather hold. Inspector arrived 10:00hrs. R/u on LS, RIH w/2" GR tag TOC @ 3750' POOH, R/u on SS, RIH w/2" bailer tag TOC @ 3233'slm. POOH, recovered wet cement in bailer. R/u on LS, RIH w/2" bailer tag TOC @ 3750'slm. POOH, recovered wet cement in bailer, R/d SL. Tag witness by State Inspector Sean Sullivan. 08/27/22 - Saturday Held PJSM, approved PTW Check and service eq. R/d circulating eq. off Di-16, blow lines dry, R/u flanges and lines to Di-3 LS/SS/IA, R/u Testing eq. Helicopter on weather hold, wait on State Inspector to witness MIT. Pumped 2.5bbls to pressure CMIT LSxSSxIA for 30mins, first test final leaking valve on manifold, retest LSxSSxIA and charted for 45mins, Bled off 2.5bbls, MIT failed witnessed by AOGCC Inspector Sean Sullivan. Pretest: LS/SS/IA/OA/OOA=0/0/0/5/0 Initial: LS/SS/IA/OA/OOA= 2900/2900/2900/5/0 15mis: LS/SS/IA/OA/OOA=2850/2850/2850/5/0 30mins: LS/SS/IA/OA/OOA=2750/2750/2750/5/0 45mins: LS/SS/IA/OA/OOA=2650/2650/2650/5/0 08/28/22 - Sunday 09/10/22 - Saturday CMIT - L/S x S/S x IA to 2500 psi as per sundry pretest = LS / SS / IA / OA / OOA = 84 / 84 /84 /5 / 0 pump 1.5 bbls Initial = LS/SS/IA/OA/OOA = 2828 / 2828 / 2828 / 5 / 0 15 min= LS/SS/IA/OA/OOA = 2720 / 2720 / 2720 / 5 / 0 30 min = LS/SS/IA/OA/OOA = 2651 / 2651 / 2651 / 5 / 0 45 min= LS/SS/IA/OA/OOA= 2593 /2593 / 2593 / 5 / 0 bled bask 1.5 bbls AOGCC Brian Bixby witness test Rig Start Date End Date SL 8/2/22 9/20/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 03 50-733-20023-00-00 167-028 Held PJSM, Spot E-line on leg #4, prep to perf Di 3, DI 12, Rig up on DI 03, RIH With 1-11/16 Wt bar, CCL, 2" gun loaded 5 ft. with production charges ( AOL 12 ft. Max OD 2", pressure up on SS to 200 psi, logged up locate collars at 425 ft. & 395 f.t spot CCL at 397 ft CCL to top shot 3 ft. Perf interval at 400 ft. to 405 ft. fired gun SS bleed to "0" pooh all shot fired. Rig down E line off DI 3 move to DI 12. Continue to rig up return line f/ OOA, OA, IA, SS, and pump line to long string. Start injecting, 260 bbls Brine, Diesel, oil from well DI 14 to DI 17 at 2.25 bpm at 2400 to 2550 psi. Swap pump line to DI 03 LS attempt to circulate the LS by OOA, pressured up to 600 psi with 2 bbls, bleed off to "0" in 30 seconds. Attempt to circulate pressure to 750 psi with 3/4 bbls, bleed down to 400 psi in 3 minutes and holding, bleed off with 1/2 bbls back, close OOA open OA start pump got returns, pumping at 600 psi at 1.3 bpm, pump 5 bbls. Line up to reverse circulate OA pump at 1.3 bpm at 650 psi, pump 5 bbls FIW, swap to LS x IA pump bpm at 2.5 bpm at "0" psi. shut down pump and secure well for night. 09/20/22- Tuesday Held PJSM with crews. Circulate OA with FIW at 1.3 bpm at 650 psi two bottoms up, swap to LS x IA at circulate 28 bbls FIW at 3.9 bpm at 250 psi, swap to LS x SS pump 7 bbls shut down pump well static, attempt to circulate OOA pressured up to 650 psi and bleed down to 300 psi in two minutes. Halliburton brk circulation with 5 bbls test lines to 500/2500 psi, good. Pump 80 bbls of Mud flush III spacer at 4.0 bpm at 500 psi, pumping 40 bbls down LS x OA and 40 bbl down LS x IA. Mix and pump 290 sxs of Cl "G" cmt 80 bbl slurry, at 2-4 bpm at 240-960psi, mix at 14.0 ppg. Pumping 32 bbls on LS x OA, 28 bbls on LS x IA, & 8 bbls on LS x SS good cmt back surface 14.0 ppg. Close S/S, IA, & OA, pressure up to 500 psi bump up as needed .5bpm, squeezing 6 bbls with OOA open shut in well. R/D & flush surface lines, clean up cmt eq., pull flanges & move to Di-12. 09/19/22 - Monday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ames B. Regg Digitally signed by James B. Regg Date: 2022.09.20 12:47:01 -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: 10,500 ft MD Lease No.: ADL0018746 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 596 Feet Csg Cut@ Feet Surface: 13 3/8 O.D. Shoe@ 2006 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 9 5/8 O.D. Shoe@ 10,439 Feet Csg Cut@ Feet SS Tubing 3 1/2" O.D. Shoe@ 9275 Feet Csg Cut@ Feet LS Tubing 2 7/8" O.D. Tail@ 9356 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Balanced 9361 ft LS Tbg 3750 ft 9.8 ppg Wireline tag Fullbore Balanced 9361 ft SS Tbg 3233 ft 9.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2550 2700 2650 IA 2550 2700 2650 OA 50 55 55 oo 0 0 0 Initial 15 min 30 min 45 min Result Tubing 2890 2850 2750 2650 IA 2890 2850 2750 2650 OA 50 55 55 55 oo 0 0 0 0 Remarks: Attachments: 200 lbs Tool string consisted of rope socket, knuckle joint, 2x 45 lb weight bar, and hydraulic spangs (spangs/bailer when sampling). Well has a 30-inch structural casing at 450 ft MD. Initial test had leaking test equipment. Retest (Fail) - pressure loss fail to trend toward zero . RIH w/ bailer - SS tubing sample mostly sand; LS tubing sample wet cement. August 27, 2022 Sully Sullivan Well Bore Plug & Abandonment S MGS unit 03 Hillcorp Alaska llc. PTD 1670280; Sundry 322-402 none Test Data: Casing Removal: Wade Hudgens Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): F F rev. 11-28-18 2022-0827_Plug_Verification_SMGS_Di-03_ss 9 9 9 9 gypg(pg . Initial test had leaking test equipment. Retest (Fail) - pressure losspg) fail to trend toward zero James B. Regg Digitally signed by James B. 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Chmielowski Digitally signed by Jessie L. 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Haines Manager, Oil & Gas Operations Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7t" Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, a 2- y c) Union Oil Company of California 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com AUG 0 b 2009 A120A Oil & Gas Cons,. Commission Anf,,hignwF crAMM OCT 03 201 Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, �) 1 J CC&, -,- Dale Haines Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 14-42 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of latform life Br 16-42 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 18-42 1680120 Apr -89 Colla sed Casing 100% water production Phase 1 Abandon abandon at end of platform 1 ife GP 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubing -to -casing communication Failed MIT Possible restore injection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D-40RD 1820830 Sep -01 Shallow hole in tubing near #2 GLM Stopped producing Phase I Abandon abandon at end of platform life G-8RD 1780450 Sep -02 E -Line wire in LS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-24 1760320 Mar -03 No known damage High Water Cut Phase I Abandon abandon at end of platform life G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase 1 Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase I Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di4 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 134 1750150 Jul -03 no known damage no flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -01 no known damage no flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN SCU 21-8 1620190 Aug -9 parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21A-4 1801050 Dec -0 no known damage no flow Possible shallow gas Remove due to SI date SCU 21B-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 2313-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov -0 no known damage no flow Possible Sidetrack to G-Zone/Hemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 3213-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for Tyonek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 44-4 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct -9 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 Dec -0 no known damage no flow Possible shallow gas or gas storage 2011-2014 Mono od A-10 1670760 Apr -8 Collapsed casing Producing Coal Phase 1 Abandon abandon at end of platform life Monopod A-23 1720200 Jun -8 Collapsed casing Producing Coal Phase I Abandon abandon at end of platform life Mono od A-30 1730140 Oct -9 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of latform life ALASKA 011L AND GAS CONSERVATION C®MMSSION June 22, 2009 \ L4 --(-02Y F,. SARAH PALIN, GOVERNOR �f t 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276.7542 Dale Haines UNOCAL SCANNuMm OCT 05 2; 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubert(a�alaska.ov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Company Permit No. Well Name UNOCAL Union Oil Company of California 168-024 Granite Pt St 17587 5 Union Oil Company of California 194-149 Granite Pt St 18742 03RD Union Oil Company of California 179-033 Granite Pt St 18742 14 Union Oil Company of California 167-077 Granite Pt St 18742 16 Union Oil Company of California 168-012 _ Granite Pt St 18742 18 Union Oil Company of California 100-266 _ Granite Pt St 31-14RD2 Union Oil Company of California 182-020 Trading Bay Unit D-06RD _ Union Oil Company of California 169-004 Trading Bay Unit D-18 Union Oil Company of California 188-098 Trading Bay Unit D-30RD2 Union Oil Company of California 182-083 _ Trading Bay Unit D-40RD Union Oil Company of California 178-045 Trading Bay Unit G-08RD _ Union Oil Company of California 176-032 Trading Bay Unit G-24 Union Oil Company of California 179-013 _ Trading Bay Unit D-06RD Union Oil Company of California 188-028 _ Trading Bay Unit G-34RD _ Union Oil Company of California 168-038 Trading Bay Unit K-06RD Union Oil Company of California 169-066 Trading Bay Unit K-09 Union Oil Company of California 179-016 Trading Bay Unit K-21 RD _ Union Oil Company of California 178-004 _ Trading Bay Unit K-23 Union Oil Company of California 165-038 MGS St 17595 05 _ Union Oil Company of California 166-003 MGS St 17595 06 Union Oil Company of California 167-017 MGS St 17595 11 Union Oil Company of California 167-049 MGS St 17595 13 Union Oil Company of California 176-075 _ MGS St 17595 18 Union Oil Company of California 185-135 MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD Union Oil Company of California 193-119 MGS St 17595 28 Union Oil Company of California 193-118 MGS St 17595 29 Union Oil Company of California 193-120 MGS St 17595 30 Union Oil Company of California 195-199 MGS St 17595 31 Union Oil Company of California 175-007 S MGS Unit 02RD Union Oil Company of California 167-028 S MGS Unit 03 Union Oil Company of California 167-058 S MGS Unit 04 Union Oil Company of California 175-044 S MGS Unit 13 Union Oil Company of California 175-066 S MGS Unit 14 Union Oil Company of California 176-045 S MGS Unit 15 Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 Union Oil Company of California 194-098 S MGS Unit 18 Union Oil Company of California 175-057 Soldotna Ck Unit 12A-10 Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 Soldotna Ck Unit 23B-03 Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 Union Oil Company of California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 _ Union Oil Company of California 100-269 Soldotna Ck Unit 41 B-09 Union Oil Company of California 162-031 Soldotna Ck Unit 43-09 Union Oil Company of California 174-066 Soldotna Ck Unit 44-04 Union Oil Company of California 160-018 Swanson Riv Unit 212-10 Union Oil Company of California 161-033 Swanson Riv Unit 212-27 Union Oil Company of California 160-041 _ Swanson Riv Unit 234-15 _ Union Oil Company of California 167-076 Trading Bay St A-10 Union Oil Company of California 172-020 Trading Bay St A-23DPN _ Union Oil Company of California 173-014 Trading Bay St A-30 ) "~7!Æ~E: 1 !Æ~fÆ~XfÆ A.TtA.SIiA OIL AND GAS CONSERVATION COMMISSION Mr. Dave Cole Oil Team Manager UNOCAL P.O. Box 196247 Anchorage, AK 99516-6247 Re: Middle Ground Shoal Unit Platforms Dillon and Baker Dear Mr. Cole: ) FRANK H. MURKOWSKI, GOVERNOR 333 W. -,-rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)27~7542 ..~r/~r ¡k1;.-lJ V This letter confirms your conversation with Connnission EngLl1eer Tom Maunder last week regarding the multiple Applications for Sundry Approval (Form 403) you submitted in mid October regarding changing the monitoring frequency on the 16 wells on Dillon Platform and 23 wells on Baker Platform. Production and injection operations were halted on these platforms in 4th Q 2002 and 2nd Q 2003 respectively. Attached, please fmd the Sundry Applications, which are being returned without approval~ because the relief you request needs to be sought through.a different procedure. The intent of submitting sundry notices for each well was to establish a monthly pressure' and general monitoring frequency for all wells on Dillon and Baker. There is a requirement in place for some of the water injection wells that pressures and rates are to be monitored daily and reported monthly. Since the platforms are unmanned and not operating, it is not possible to obtain daily information. When operations were curtailed, a monthly monitoring frequency was established in the Plans of Development (POD) annually filed with the Division of Oil and Gas and Unocal desires to assure that this monitoring scheme is accepted by the Commission. As noted in the conversation, changing the monitoring frequency where presently in place and establishing a monthly monitoring frequency in general is not an action that is best accomplished with multiple sundry notices. A letter application requesting the desired monitoring schedule should be made under the applicable Area Injection Orders (AlO 7 for Baker and AIO 8 for Dillon) and Conservation 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. ¡:, SinC~~~ . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this¿Z.ßay of November, 2004 Enel. SCAN?IE-"-' N ~ -., J~ Lj >O\j t: :3 2004 Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Union Oil of California aka Unocal 1. Type of Request: 3. Address: 7. KB Elevation (ft): 110' RKB 8. Property Designation: Dillon 11. Total Depth MD (ft): 10,500' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 9,503 to 10,084' Packers and SSSV Type: ') STATE OF ALASKA ') ALASt\.Ä OIL AND GAS CONSERVATION COMMlbSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Suspend U Repair well 0 Pull Tubing D P. O. Box 196247 Anchorage, Ak. 99519-6247 Development Stratigraphic 0 0 E OCT I 2 2004 Perforate U ^,ì~~'Wa9Jl:U~:f3t~~~~ ~i~~ðs:LJ"<¡ Stimulate 0 Time Extension ÖnC,U)f(jg! Other 0 Re-enter Suspended Well 0 MJPitor Frequency 5. Permit to Drill Nu~: Exploratory D 67-28 / Service D 6. API Num r: 9. Well Name and Number: Di-03 10. Field/Pools(s): SMGS Hemlock Total Depth TVD (ft): 10,323' Length PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): 10,392' Size MD 600' 2,006' 10,439' 20" 13-3/8 " 95/8" Plugs (measured): Junk (measured): TVD Burst Collapse 600' 1,530' 2,730 psi 8,150 psi 520 psi 1,130 psi 5,090 psi 1,985' 10,262' Perforation Depth TVD (ft): 9,334 to 9,911' ITUbing Grade: ITUbing MD (ft): 3-1/2" 9.2# N-80 BTC, 2-7/8' 6.5# N-80 BTC @8276' tailpipe. Tailpipe @ 9356' Packers and SSSV MD (ft): 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 12. Attachments: Description Summary of Proposal Detailed Operations Program D BOP Sketch 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Date: 9,355' 0 Service 0 Plugged WINJ 0 0 WDSPL Abandoned 0 0 Commission Representative: 17. I hereby certify that the foregoing is true and c rrect to the best of my knowledge. Contact Title Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY Printed Name/) P. Cole Signature 1< ,/ / ~ /J /)~ ,AkU.l7~ ~ í4.~ Phone Conditions of approval: Notify Commissio so that a representative may witness Plug Integrity Other: 0 BOP Test 0 0 Mechanical Integrity Test RBDMS BFL NOV 2 2 2004 Subsequent Form Required: Approved by: 28-Sep-2004 Sundry Number: 3DY -<t2J;r-- Location Clearance D APPLICATION RETURNED 11/17/04 NOT APPROVED BY COMMISSION 0 0 \ ~ \ t\ 1 A L BY ORDER OF Gðtv1L1I~ðJ::)\ THE COMMISSION tit)'"? Form 1 O..48'2r Revised 12/2003 Date: Submit in Duplicate STATE OF ALASKA ~'"') ç: C,,' ....,. E~ rV' E'~: r') ~,.,~:. !i,.~",,' .... ~ .. ..." ".~.,{' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS FES 262004 1. Operations Abandon Performed: Alter Casing 0 Change Approved Program 0 2. Operator Union Oil of California Name: aka Unocal Suspend Repair Well 0 Pull Tubing 0 Operation Shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic 0 3. Address: P. O. Box 196247 Anchorage,Ak.99519-6247 7. KB Elevation (ft): 110' RKB 8. Property Designation: Dillon 11. Present Well Condition Summary: Exploratory 0 67-28 Service 0 6. API Number: 50-733-20023-00 9. Well Name and Number: Di-03 10. Field/Pool(s): SMGS Hemlock Total Depth measured 10,500 true vertical 10,323 feet feet Plugs (measured) Junk (measured) Effective Depth measured 10,392 true vertical 9,356' feet feet Casing Structural Conductor Surface Intermediate Production Liner Length Size MD TVD Burst Collapse 600 20" 2,006 13-3/8" 10,439 95/8" 600 2,006 600 1,985 10,439 1 0,262 Perforation depth: Measured depth: 9,503-9,513' 9,770-9850' 9,875-9,950' 9,955-9,992' 9,992-10,033' 10,053-10,084' True Vertical depth: 9,334-9,344' 9,599-9,679' 9,704-9,778' 9,783-9820' 9,820-9,860' 9,880-9,911' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) LS: 3-1/2" 9.2# N-80 BTC, 2-7/8' 6.5# N-80 BTC @9,356' 55: 3-112" 9.2# N-80 BTC @ 9,275' See attached schematic 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-Met Water-Bbl Casing Pressure Prior to well operation: 81 27 608 90 Subsequent to operation: This well was shut in subsequent to operation 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 0 Development 0 Daily Report of Well Operations 16. Well Status after proposed work: Oil0 Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Tubing Pressure 80 Service 0 GINJ 0 WINJ 0 WDSPL 0 Sundry Number or NIA if C.O. Exempt: Contact . "'",,":,:,'1''''''' Printed Name P. M. Ayer Title Petroleum Engineer Signature Phone 263-7620 Date 18-Feb-2004 ~~ 6? 2n" O} h.' tJ]) -U l.t SOUTH MIDDLE GROUND SHOAL ADL 18746 WELL NO.3 HEMLOCK CONGLOMERATE PLATFORM DILLON ~ ~ Cdn"r.1b\ Reconf Spwct Date 6'22187 I.òng Stdng: o.pth Surfeoe LocotIon: ItItI 4. Sot 4 1. to'" Cameron 0uaI HcInør :w 787' FSl. 1m- FtL. ~ 35. 11M. R1JW- s.u. f : ~ === ami 2..,¡r Sutt.nu xo ~ ~ tAc:oØDII: 1D - ew ~ Qt- f18. Sea. ~ T1N. Rt.. 5.11. ~4~ 2 1/1r Buttras CL, 9218- .s. 2 lIP/" Buttnn pup 821a- ~ l1er IC8 e. 2 1IB- Buttnn 8M J 1n:- .httrwa xc 927r "fft. 1A"'- -- 10"~'" "'... 7r J an-.... and 3 IAr 8RD 10 nn- .- ~ 'IIW' 01- . ßI L KaH 2 lna IMIftIII8I T ~ -.,b-2OS82Ir ~ .... tor M~ .. pImp8 fI8D: 103tr IJID t021~ 1W . 9_J In-- 8 RD and 3 112" ~ xc ~ Ca81ng: 2r. .'* ~ - at 8ØO* .. t2U.. ~ 10.. 3 112'" ButtAM tuIint uw 13~. 54.51 ClUJng - at 2001- w1tt\ 1200 h HIft8nt 1t.3 112"" pup ~. .518"".40" 43.5 - 471 N-8O and 5-Ið Co8tng - at 1OQrl2.""'" Hat ~ QldIacqtQr '3~ Mth 1250 - ~ 1~ 3 1/2" UuIeaboe 1356- $bed StrIng: A.. 3 In- pup 38' .. .! 1œ ~ tubIftca 82W C. .3 112" 8YtInn and f 3IØ- 8RD XO 8285' D. 2 JI&" 8R() pup 9215. Per'foratfoM: k1ft1Gt ø.c t.. tL.J,. kIItJø1 StJrnukdJ'oa: R88M\mIr ~ r:cnd ~ œr~ cd Raub: 1.øt Irw8nt«y: C-1: 84.15-8.... G-2: 9503-9$1Y" 95.10-8$75'* G-3: 985O-SI1Cr.. 1685-'74&. 9770-1850" 1875-8950' S te5-1812' . qtI8a8d 558111OPO. 0 BWPD. 4..1 UUt:fI) None 1. 95J0-e55-. cut 25~ l...ca~ IT 2. IH2-tl71I¡... 2": ntCO-- ,.. 3. 9753-8780'. cqt T. jaca-.4" HoD8 EL-SP. BHC-G8t 1114181 ÇQmma ~ 7mne GommtIIaJ' 1121J81 ¡;zJ¡s¿ I ) 9s Ik-f I / 10053 - /f}O~1 (Aa ftIn 11nG181i~ Model "Ð'" Pocket NItta - ~ cammuotocucI fnMn 81~.11tr h({ (! 19 00 /71/& /?h3 TGIIØ8d FJø . 101S"" -11/15/81 .'j'1lli6 P~T ~ -r Cft;~2. - '~Q3 ) ~~L~ .- '1513 iIJIJ 1038T 10 10S00" j .. 13 1 ~t«- 8 13 ~. 34.51 200r i43S-948W ~t 1Ø15- .. 1740" J71O-MSCr ~ t815-QSO- H55-ftW See I 518'" 40. 4.1.5 . 41' CS4 1CH38' ATTACHMENT #1 SMGS WELL D-3 AP I 50-733-20023-00 BENCH MD TVD G2 9503 9513 9334 9344 G3 9770 9850 9599 9679 G3 9875 9950 9704 9778 G3 9955 9992 9783 9820 G4 9992 10033 9820 9860 G5 10053 10084 9880 9911 f¡;..",.' -'",''',',' ~ !j1<.I'.., ~, ~ /I, .' ~¡,.",. r') ~ .~ t."" ~J)~ ~\..w.. \I '~, 6"",,,.. c."'''''~ MAR 0 6 19S6 A!as!tß Oil & Gas Cons. Commif~s¡on i\nGhf. m~w DILLON PLATFORM API # 50-733-20023-00 S. MGS UNIT # 3 WELL HISTORY Well #3 DATE COMPLETED EVENT 1967 9/27 Completed as an Oil Well. 1995 11/28 Clean out fill to reperf G-5 1998 6/9 GR - RIH wI Kobe equalizing prong to 9,320', beat down two times, POOH. RIH wI SV pulling tool to 9,320', pulled SV , POOH with SV. RIH wI 2.20" GR to 10,120' RKB, POOH. RIH wI 30' 2 1/8" Dummy Guns to 9,313', hit two times, fell through to 10,120' RKB, POOH. Pick up weight 1500# . 6/14 WL - RIH wI Kobe EQ Prong to 9,299' KB. Jarred down, well went on vacuum, POOH. RIH wI Standing Valve Pulling tool, latched standing valve, POOH, no valve. Looked Pulling toll over, looks OK. RIH wI Standing Valve Pulling tool, latched valve, POOH. 1999 7/30-31 TAG - Pulled standing valve & tagged fill @ 10,141 KB, wI 1 .87" gauge ring, no problems, no tight spots, POOH. 2002 12/09/2002 This well was shut in and isolated at the surface with multiple flanges to isolate the well from surface flow lines. Di # 3 Hist 7-31-99.doc, last revised 2/18/2004 page 1 Don Sta dual LEG ROOM '1 .w.m....t 2O"x 13 3/88 133/88 x 9 5/a- 95/a- x 3 1/'Z' 1 bbIs 28 bbIs 22 bbIs 4 bbIs 15.5bb1s 30 bbIs ~ DI-I3 LEG ROOM #2 ~ DI-I8 20bbIs DI-17 15.5bb1s 20 bbIs DI-16 15 bbIs 20ÞÞIs DI-11 7;4bbfs DI-S 2 bbIs 25 bÞIs ~ ABN-6 ~ LEG ROOM #4 DI-5 _~5:S ¡abbls ~ 01-3 12 bbIs 20 x 13 518 0.1815 300 54.45 31/2 tbg. 0.0087 300 18 5/8 x 13 3/8 0.1291 300 38.73 2 7/8 tbg. 0.00579 300 13 3/8 x 9 5/8 0.0671 300 20.13 I~ 858 334 9 518 x dual 3 1/2 0.0507 300 15.21 355 9 518 x dual 2 7/8 0.0571 300 17.13 u_pump limit 21 psi 9 5/8 x 3 1/2 0.0628 300 18.78 we" #2 welll4 well #9 We" # 10 We" #13 We" #7 We" #8 We" 1111 well #16 Well 17 We" # 18 we" n We" #5 We" # 12 We" #14 we" 1115 WELL BAY # 1 Pumped down 1bg.1bg on vac, bled down 9 5/8 x Ibg. Pumped 28 bbls. Gas still at surface. Pumped down 2Ox135/8 2bbls 100 psi. 20 bbls in 133/8, Try to pull eclipse paker with wire line could not get out. Well had 180 on annulus and 150 on tbg would not bleed down, Tryied pumping down short side old pump in hole could not pump. Put 30 bbls of 9.8 in annulur 9 5/8x Ibg. Pumped down 1.5. tbg. Returned up short side 100 bbIs. Put 15 bbls In 13 5/8x9 5/8. 4 bbls in 20" ann. Hook up to 20" took approx 1 bbl with charge press on ann. 13 3.8)( ~ 5/8 RumP and bleed 3 bþ~ i~ an~. 9 5/8xtbg fluid packed with oil. 14.4 bblsln Ibg. well 10 Is abandoned Fill 20" ann 2 bbls, tbg on vac 7bbls in 13 3/8 x 9 5/8 28 bbls 9 5/8 x tbg. 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 95/82 bbls and started getting diesel fluid back to surface. Pumped Sbbls in tbg.' 20 bbls in 9 5/8 ann.Annulus and Ibg. 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 011 to top no press on tbg. Pumped and bled 7bb1s in tbg. Annulus. When aMulus was fluid packed. Oil at surface.5 bbls In 135/8 x 9 5/8 press Omit. .5 bbls in 20" Well had SOpsi. On 13 3/8x 9 5/8 bleed down to 20psi put bbls of 9.8 fluid, 95/8onn. 20 bbls fluid, tbg.5bbls each, wells 185/8 has 110 psi. bled off and fluid packed with press limit of 50 psi.,75 of a bbl. Well had lOOps!. On 13 3/8x 9518 bleed down to 20psi put lSbbIs of 9.8 fluid, 95/8onn. 20 bbls fluid,Ibg.5bb1s each, wells 185/8 has 60 psi. bled off and fluid packed ann with .75 bbls. Well had 150psi. On 13 3/8x 9 5/8 bleed down to 20psI put 20bbls of 9.8 fluid, 95/8onn. 20 bbls fluid, 1bg.5bb1s each, wells 185/8 has25 psi bled off and fluid packed with 9.8 salt took 1.2 bbls. WELL BAY # 4 Rig up pump 4 bbls I.s. 4 bbl s.s. 9 5/8 x tbg. 25 bbls, 13 3/8 x 9 5/8 fluid packed w 112 bbls, 20" ann. 2 bbls. Ruld packed Pumped 4 bbls I.s. tbg. 4 bblss.s.R/u to 9 5/8 x 3 112 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 95/8x31/2. W'1th50 psi press limit 0 bbls In 13 3/8x 95/8 Fluid packed 20x 133/82 bbls, Auld packed 13 3/8x9 5/812 bbls press up to 200 psi and held. Rig up pump 5 bbls I.s. 25 bbl s.$. & 9 5/8 x tbg. 8 bbls fluid packed on to surface 13 5/8x9 5/8, R/U to 20" ann fluid pack 5 bbls. Press limit 20 psi. 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: Repair well: Other: Reperforate 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Amoco Production Company Development: X 110' KB MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 100779, Anchorage, AK 99515 Stratigraphic: Service: SMGS Unit 4. Location of well at surface 8. Well number Leg 4, Slot 4, SMGS Dillon 1765' FWL, 678' FSL, Sec. 35 T8N, R13W, S.M. 3 At top of productive interval 9. Permit number/approval number At effective9435' MD, 768' FWL, 573' FNL, Sec. 2 T7N, R13W, S.M.depth ORIGINAL 10.67-28APi number 10392' MD, 611' FVVL, 633' FNL, Sec. 2, T7N, R13W, S.M. 50- 733-20023-00 At total depth 11. Field/Pool 10500' MD, 653' FWL, 636' FNL, Sec. 2, R7N, R13W SMGS Hemlock 12. Present well condition summary Total depth: measured 10,500 feet Plugs (measured) true vertical 10,323 feet Effective depth: measured 10,392 feet Junk (measured) true vertical 10,215 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 600' 20" 1265 sx 600' 600' Surface 2006' 13 3/8" 1200 sx 2006' 1985' Intermediate Production 10,439' 9 5/8" 1250 sx 10,439' 10,262' Liner Perforation depth: measured (See Attached List) true vertical Tubing (size, grade, and measured depth) Dual: 3 1/2" 9.2~ N-80 BTC, 2 7/6' 6.5# N-80 BTC ~ 8276' tailpipa. Tailpipe {~ 9356'. ~,. "-'~ .... ~. ~. , Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary ,,*,~aS Cons. Coi~tri'~i$$ioi'~ Intervals treated (measured) A~chomge Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 134 0 70 PSI Subsequent to operation 91 47 185 0 70 PSI 15. Attachments: 16. Status of well classif'mation as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: ~ Gas:, Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE,~ BENCH ATTACHMENT #1 SMGS WELL D-3 APl 50-733-20023-00 MD TVD G2 9503 9513 9334 9344 G3 9770 9850 9599 9679 G3 9875 9950 9704 9778 G3 9955 9992 9783 9820 G4 9992 10033 9820 9860 G5 10053 10084 9880 9911 !',~AR 0 6 1996 Alaska Oil & Gas Cons. Commission Anchomge Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7676 UNOCAL ) G. Russell Schmidt Drilling Manager Tuesday, February 27, 1996 Ms. Joan Miller Alaska O&G Cons. Comm. 3001 Porcupine Drive Anchorage, AK 99501-3192 DILLON PLATFORM WELL D-3 APl NUMBER 50-733-20023-00 Dear Ms. Miller: The following intervals were perforated in Well D-3 in the Middle Ground Shoal Field: DATE BENCH TOP (MD) BOTTOM (MD) FEET 12/28/95 G5 10,053 10,084 01/09/96 G2 9,503 9,513 01/09/96 G4 9,992 10,033 31 10 41 Total 82 Sincerely, Russell Schmidt GRS:dma Attachment Unocal Energy Resourr 909 West 9th, P.O. BO',,. Anchorage, AK 99519-6247 Telephone (909) 276-7600 Fax (907) 263-7828 UNOCAL Debra Childers Clerk DATA TRANSMITTAL 96-4 February 13, 1996 To: Larry Grant I 3001 Porcupine I Anchorage, AK 99501 [,'Alaska Oil & Gas From: Debra Chiiders 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items. SRU 32A-33 ,.//BLUELINE / SEPIA 12/5/95 PERFORATING RECORD SMGS #3 BLACKLINE / SEPIA 12/28/95 COMPLETION RECORD .SMGS #3 ~,-BLUELINE / FILM 1/9/96 COMPLETION RECORD GP 42-23 RD ~,'BLUELINE / SEPIA 12/27/95 BRIDGE PLUG SETTING RECORD GP 42-23 RD BLUELINE 1 SEPIA 12/29/95 MUDLOG - FORMATION SCU 43-4 ,/ BLUELINE / SEPIA 12/21/95 PERFORATING RECORD SCU 343-33 c,"'BLUELINE / SEPIA 12/5/95 COMPLETION RECORD SCU 321-9 ,, /BLUELINE / SEPIA 12/21/95 PERFORATING RECORD I Please acknowledge receipt by signing and returning one copy of this transmittal [ Re.c~ivM by: }Date: ,.~ STATE OF ALASKA :~" 0 RIGIN ~ Al ,(A OIL AND GAS CONSERVATION COMM, _,ON 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 .~. 2. Name of O.perator rL--~5' T~PT~I~~ 6. Datum elevation (DF or KB) Union Oil Company of Californ nt~ 3. Addre' ~ | Exploratory __ 110 S~.o. Box 196247, Anch., AK, 9~519-6~rjjti[~r,P,~h~ic-- 7. Unit or Property name 4. Location of well at surface Leg #4, Slot 4, Platform Dillon 1771' FWL, 767' FSL, Sec. 35, T8N, R13W, SM At top of productive interval 768' FWL, 573' FNL, Sec. 2, TTN, R13W, SM At effective depth 611' FWL, 633' FNL, Sec. 2, TTN, R13W, SM At total depth 653' FWL, 636' FNL, Sec. 2, TTN, R13W, SM 8. Well number 3 9. Permit number 67-28 10. APl number 50-- 733-20023 11. Field/Pool SMGS/Hemlock feet 12. Present well condition summary Total depth: measured true vertical 10500 ' feet 10323' feet Plugs (measured) Effective depth: measured 10392 ' feet Junk (measured) true vertical 10217 ' feet See attached schematic Casing Length Size Cemented Measured depth Structural Conductor 555' 20" 1285 SX 600' Surface Intermediate 1968' 13-3/8" 1200 sx 2006' Production 10404' 9-5/8" 1250 SX 10439' Liner Perforation depth: measured true vertical See attachment ~uevedicaldepth 600' 1985' 10262' Tubing (size, grade, and measured depth) Dual 3-1/2", 9.2#, N-80 BTC, @ 8276'. Tailpipe @ '9356'. Packers and SSSV (type and measured depth) Baker Model "D" @ 9342' 2-7/8" 6.5# N-80 ~ RECEIVED Description summary of proposal __ 13. Attachments 14. Estimated date for commencing Operation October 28, 1991 16. If proposal was verbally approved Name of approver Date approved Detailed operations program ..~ BOP sketch __ DEC - 9 15. Status of well classification as: Alaska Oil & Gas Cons. Co Oil __ Gas __ Service Anchorage Suspended ..,_ 7,,d~ 17. I hereby certify that the foregoing is true and Qqrrect to the best of my knowledge. Signed GARY e REGIONAL DRILLING MAN~e~ER ( ) ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test __ Subsequent form required 10- ~ ~' Approved by order of the Commissioner OR)GiNAL SIGNED BY LONNtE C. Si~J~TH .,, I A ppr°val N °~'/---,,~'~/~ Commissioner Date ~-,/~-- ¢/ TC FOrm 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE RECEIVED DEC - 9 1991 Alaska Oil & Gas Cons. Commission Anchorage PorforaUmm: Initial PobnffGl: DST ~ md ~ SOUTH MIDDLE GROUND SHOAL ADL 1874-6 WELL NO. 3 HEMLOCK CONGLOMERATE PLATFORM DILLON C4:rnpbtion Umg Str~g: D~)th 0... 8, 2.o-- ~e ~d 3 I~- au~ xo 0278' 7, 3 1~- ~ ~d 3 1~ ~ xo .7? ~dond~for · ~~l ' 9.3 1~8~d3 ~t~~ 12~~ lO~31~~~g 13 ~; ~ Cooing ~ et 2~r w~ t2~ n o~t Il. ~ 1~" p~ 1~4' 9 ~, ~, ~ md 47~ N~ md S-~ ~g ~ ~ 10~9'12. B~ seal aN~bly ~ S~ ~ 3 I~*' ~8' ~3 ~~13'* 9275' O77O-B~ , Squ~-eeo2* (Ada run 11/20,/BG)B~ Idochl ~ PQr, i~r 074O-*077O* Tugged fin · 10157'-! 1/1~/86 t:'flO 103~2° 11) I0.100' 943,,~-9480' I illenO3* 074o* 077o-080o* 0878-005o* ogo~-.ooo2* &47j cs& 10430' South Middle Ground Shoal ADL 18746 Well No. 3 Procedure for suspending and freeze protecting well: 1) Reverse the hydraulic pump out of the hole. Long and short strings will be protected against freezing by power oil at this point. 2) Run hose to 100' in 9 5/8"X tubing annulus. 5/8" casing annulus taking returns up hose. freeze protected at this point. Circulate power oil into tubing X 9 Tubing X 9 5/8" annulus will be 3) Close all valves on the well head. 4) Install gauges on the tubing and 9 5/8" casing X tubing annulus. RECEIVED DEC - 9 1991 Alaska Oil & Gas Cons. Commission Anchorage J. D. Hamrick Division Production Manager Amoco Production Company Northern Division 1670 Broadway P.O. Box 800 Denver, Colorado 80201 303-830-4040 May 20, 1988 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99503 Attention: C. V. Chatterton File: GLH-309-WF Gentlemen: Report of Sundry Well Operations SMGS Unit Well No. 3 Platform Dillon - Cook Inlet, Alaska Attached in triplicate is State of Alaska Form 10-404, to notify you of the recent repair/workover of the subject well. Please reference our former letter dated February 3, 1988, File: WEN-008-WF, transmitting our notice of intent to reperforate this well. Very truly yours, BAF/mla LTR942 RECEI /ED Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMN,,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] ~e6~i~le.~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator Amoco prOduction Company 3. Address P.O. Box 100779, Anchorage, Alaska . 99515 Location of well at surface Leg 4, Slot 4, SHGS Dillon 1765' FWL, 678' FSL, Sec. 35 T8N, R13W, S.N. At top of productive interval 9435' MD, 768' FWL, 573' FNL, Sec. 2 T7N, R13W, S.M. At effectivedepth 10392' MD, 611' FWL, 633' FNL, Sec. 2, T7N R13W, S.M. At.t. otal depth 10500' MD, 653' FWL, 636' FNL, Sec 2, R7N, R13W 5. Datum elevation (DF or KB) 110' KB MSL 6. Unit or Property name SMGS Unit 7. Well number 3 8. A~'_o~ number 9. APl number 50-- 733- 20023 10. Pool SMGS Hemlock Feet 11. Present well condition summary Total depth: measured 10,500 feet Plugs (measured) true vertical 10,323 feet Effective depth: measured 10,392 feet Junk (measured) true vertical ]0,215 feet Casing Length Size Cemented Measured depth Structural Conductor 600' 20" 1285 SX 600' Surface 2006' 13 3/8" 1200 SX 2006' Intermediate Production ]0439' 9 5/8" 1250 SX 10439' Liner Perforation depth: measured (See Attached Li st) true vertical Tubing (size, grade and measured depth) Dual- 3½" 9.2# N-80 BTC, 2 7/8" 6.5# N-80 BTC @ 8276' tailpipe. Packers and SSSV (type and measured depth) True Vertical depth 600' 1985' 10262' RECEIVED AJaska 0ii & Gas Cons. Commission Anchorage Tai I pipe @ 9356' 12. Stimulation or cement squeeze summary Intervals treated (measured) Please refer to attached Operations Report for 2/18/88 Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 115 23 6 n/a 134 22 52 n/a ~bing Pressure 72 PSI 72 PSI 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 knowledge Signed ~, F/ ,J Title Adm. Services Manager Form 10-404 Rev. 12-1-85 Date 5/20/88 Submit in Duplicate Perforation Data SMGS No. 3 Zone MD TVD Status ....... G-1 9,435 - 9,460 9,265 - 9,289 Squeezed G-2 9,503- 9,513 9,530- 9,575 9,332- 9,342 9,360- 9,405 Squeezed I! G-3A 9,650- 9,670 9,479- 9,499 Squeezed G-3B 9,695- 9,740 9,770- 9,850 9,524- 9,568 9,5O8- 9,677 Squeezed II G-4 9,875- 9,950 9,955- 9,992 9,702 - 9,777 9,782- 9,819 Open Open Oil & Gas Cons. Commi~ion /L~chcra.go AMOCO PRODUCTZON CD~PANY DENVER PEG[ON ~= ANCHORAGE CHRONOLOGICAL'REPORT JOB [N[T[ATZON REPORT: COHPAN¥ OPERATED - .REPAZR - DEVELOPNENT 50?332002300 FLOC 986133 SOUTH MGS UNZT-'TE~TZ~RY~ 3~ KENA! O/S STATE~ ALASKfl OPER~TOR~ A~OCO PRODUCT[ON 0.6250 AUTH HORIZON ZONE: 02 - SOUTH MG~ UNI'T-TERTIARY~ 3 AUTH D~TE 0E/0~/88 OPERATIONS COH~ENCED 02/'12/86 DENVER REGION DISTRICT ~ 05/19/88 ~ PAGE SOUTH ~'GS UNIT TERTInRY 3, ~ ~ A~OCO PRODUCTION, FLOC 986].33-C2- s qPI ~0733~002300~ ~MOCO W.I. 0,6250 OPEm~T~QNS~ TO ~050~ CT~ PBTB 10392t COMPLETE~ F~ CRUDE OIL COSTS:. DGILY WELL $10306t CU~ WELL S1030G CH~ON TI~E D~STRI~UTION ]0.00 - PFRF, PERFORATE qq~- JOE I~ITZAT~ON REPORT: DTRECTZO~AL HOLE CURRENT WELL ACTIVZTY-COMPLT-O~Gs DATE Amoco Production Company Po O. Box 100779 Anchorage, ^laska 99510 (907) 562-2147 February 3, 1987 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Attention' Mr. C. V. Chatterton File- WEN-OO8-WF Gentlemen- Notice of Intent SMGS Unit No. 3 Platform Dillon, Cook Inlet, Alaska Attached in triplicate is a State of Alaska Form 10-403, Application for Sundry Approvals, to notify you of our intent to reperforate SMGS Well No. 3. If there are any questions, please contact John Mummery in our Anchorage office at 562-2147. Very truly yours, W. E. Nielsen Supervisor- i n-Charge JFM/dds f · STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM,,~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend ' ' Operation Shutdown ' i Re-enter suspended well ~--; Alter casing Time extension Change approved program . Plugging F} Stimulate :.] Pull tubing . Amend order ,r. Perforate ,Y,: Other 2. Name of Operator Amoco Pr`eduction Company . Address P.O. Box 100779, Anchor'age, Alaska 99515 . Location of well at surface Leq 4, Slot_-4q MSMGS Dillon 1765' FWL, 678' FSL, Sec 35 TSN, R13W, : . At top of productive interval 9435' MD, 768' FWL, 573' FNL, Sec 2 T7N,R13W, S.M. At effectivedepth 10392' MD, 611' FWL, 633' FNL, Sec 2, T7N R13W, S.M. At total depth 10,500' MD, 653' FWL, 636' FNL, Sec 2, R7N, R13W 5. Datum elevation (DF or KB) 110' KB MSL 6. Unit or Property name SMGS Unit 7. Well number 3 8. Permit number 67-28 9. APl number 5o- 733-20023 10. Pool SlVIGS Hemlock feet 11. Present well condition summary Total depth: measured 10,500 feet true vertical 10'323 feet Plugs (measured) Effective depth: measured 10,392 feet true vertical 10,215 feet Junk (measured) Casing Length Size Cemented Structural Conductor 600' 20" 128'5 sx Surface 2006' 13 3/8" 1200 sx Intermediate Production 10439' 9 5/8" 1250 sx Liner Perforation depth: measured (See Attached List) true vertical Tubing (size, grade and measured depth) Measured depth 600' 2006' True Vertical depth 600' 1985' 10439' 10262' , )ual- 3½" 9.2# N-80 BTC, 2 7/8" 6.5# N-80 BTC @8276' tailpipe Tailpipe @ 9356' Packers and SSSV (type and measured depth) 12.Attachments Description summary of proposal © Detailed operations program [l.] BOP sketch © 13. Estimated date for commencing operation Feb.,ru.ary ~15 ~ 1988 14. If proposal was verbally approve5,~l~~ ~fea'~, ~epo~ed Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~~'""~~ Title Distr'ict 0per`ations Super'visor' Date Commission Use Only 02./.0_4/88 -- Conditions of approval Notify commission so representative may witness I Approval No. ~ Plug integrity [] BOP Test D Location clearance ORIGINAL SIGNED BY Approved by LO.NN!E ~. _~.~!T,u. Form 10-403 Rev 12-1-85 Approved Copy Returned_ _ Commissioner by order of ~... the commission Date o~- 2~ Submit in triplicate/~ Perforation Data SMGS No. 3 Zone G-1 G-2 G-3A MD TVD 9,435 - 9,460 9,503 - 9,513 9,530 - 9,575 9,650 - 9,670 9,265 - 9,289 9,332 - 9,342 9,360 - 9,405 9,479 - 9,499 Status Squeezed Squeezed Squeezed G-3B G-4 9,695 - 9,740 9,770 - 9,850 9,524 - 9,568 9,508 - 9,677 Squeezed 9,875 - 9,950 9,702 - 9,777 Open 9,955 - 9,992 9,782 - 9,819 Proposed Description Summary of Proposal Shut-in the well and circulate out the pump. RIH with a wireline perforating tool and~perforate the lower G-4 from 9,955 to 9,992 feet MD at 4 JSPF, 0v phasing. Remove the perforating tool, install a pump in the hole and return the well to production. le me Be Description Summary of Proposal Rig up a coiled tubing unit and pressure test to 4,000 psig. RIH with a coiled tubing to 10,050 feet MD. Pump 70 barrels fresh water mixed with 2,240 pounds Na~H~ EDTA. Open perforations are at 9,800'-9,844' MD, 9,876'-9,95~'~MD, and 9,975'-10,042' MD. Squeeze the EDTA into the formation at 1-2 BPM and overflush with 150 barrels crude oil. Rig down the coiled tubing unit. Leave well shut in for 24 hours and then return to production. W. G. Smith District Manager Amoco Production Company Post office Box 100779 Anchorage, Alaska 99510 907 -562-2147 January 9, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: FEW-OO5-WF Report of Sundry Well Operations SMGS.Unit Well No. 3 Platform Dillon, Cook Inlet, Alaska Attached in duplicate for your records in a State of Alaska Form 10-404, Report of Sundry Well Operations, outlining work recently completed on SMGS Unit Well No. 3. Questions concerning this report may be directed to Kurt Unger at 562-2147, extension 211. Very truly yours, W. G. Smith District Manager KWU/dds Attachments RECEIVED JAN 72 t987 Oil & Gas Co~s. uu,,i~;~i~,~ Anchorage STATE OF ALASKA ALASK,-, OIL AND GAS CONSERVATION COMrv,,,sSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other E)K Cement Squeeze 2. Name of Operator Amnco D~oduct,.'on Company 3. Address P.O. Box 100779, Anchorage. Alaska'." 4. Location of well at surface Leq 4', Slot 4, S~S Platform.Dillon 1765' FWL ' ' ': Sec..` '35 . . At top of procluc~v~ in~:~ral · T8N, R13W, S,M 9,435' MD,-768' FWL,573' FNL' Sec. 2, T7N, R13W, S.M. At effective depth 10,392' MD, 661' FWL, 633' FNL, Sec. 2, T7N, R13W, S.M. At total depth 10,500" MD, 653' FWL, 636' FNL, Sec'. 2, T7N, R13W, S.M. 11. Present well condition summary Total depth: measured 10,500,' feet Plugs (measured) true vertical 10,323' feet Effective depth: measured 10,392 feet Junk (measured) true vertical 10,'215 ' feet Casing Length Size Cemented Structural Conductor 600 20" 1285 sx Surface 2006 13- '3/8." 1200. sx Intermediate ,~ Production 10439.' 9 5/'8.". .1.250. sx Liner -~ .... :' '- . Perforation depth: measured - 5. Datum elevation (DF or KB) l!r) '~R ~ ~SL 6. Unit Or Property name SMGS Unit' 7. Well number Feet 8. Approval number 67-,28 9. APl nUmber 50-- 733,,20023 10. Pool SMGS H~mlock Measured depth True Vertical depth 600 600 2006. 1985 10439. 10262' true vertical (See attached List of .Perforations) Tubing (size, grade and measured depth) Dual 3½, 9.2 lb N-80 'BTC x 2 7/8, 6.5 lb, N80 BTc at 9,276' - Tailpipe at 9356' Packers and SSSV (type and measured depth) Baker Model IlDll Packer at 9,$42', ~ [" C ~ ,~''~' , -.~ 12. Stimulation or cement squeeze summary ' Intervals treated (measured) (See attached) Treatment description including volumes used and final pressure Alast~ Oil & Gas Cons. - A~ch0rage 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 0 o 140 30 165 Tubing Pressure 6.5 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 knowledge /~_-~ District Manager Form 10-404 Rev. 12-1-85 Date 01/07/87 Submit in Duplicate 11. Perforation Depth: Measured Depth f9435 - 9460 9503 - 9513 Squeezed ~ 9530 - 9575 9650 - 9670 9695 - 9740 9770 - 9850 9875 - 9950 True Vertical Depth 9265 - 9289 9332 - 9342 9360 - 9405 9479 - 9499 9524 - 9568 9598 - 9677 9702 - 9777 12. Cement Squeeze Summary Interval (MD) . Squeeze Type 9435 - 9740' Block 5617 - 5651' Block 4541 - 4601' Block 4541 - 4601' Block 4541 - 4601' Block Final Total Squeezed Squeeze Volume (BBL) Volume (BBL) Pressure (PSI) 50 17.2 3200 30 19.8 2240 40 20.3 2350 40 25.0 2600 40 26.8 2700 I E[EIVED JAN, 2 !987 Oil & Gas Cor~. Anchorage AMOCO PRODUCTION COMPANY CHRONOLOGICAL REPORT DENVER REGION *** ANCHORAGE DISTRICT *** 01/06/87 *** PAgE *** dOB INiTiATION REPORT- COMPANY OPERATED - REPAIR - DEVELOPMENT AP I .~ ~ ~3~002300 FLAC 986133 S. MID COROUND SHOAL, SOUTH MIDDLE COROUND SHOAL., ~3, KENAI O/S STATE, ALASKA OPERATOR' AMOCO PRODUCTION AMOCO W. I.° 62. 5000 AUTH HORIZON ZONE' 02 - SOUTH MIDDLE gROUND SHOAL, AUTH DATE 10/q=4/86, AUTH COS]' $396000 ~.~-~ rn.~-'~mirTOR(S)~.~ ,,,..~ . . INFORMATION~ PARiiER~ 4B, RIO~ MOVE ON 10~- ~_~,/86 DENVER REGION ~** ANCHORAGE DISTRICT *** 0i/06/87 *~* PAgE 10/29/86 SOUTH MIDDLE gROUND SHOAL ~3, S. MID gROUND SHOAL, PARKER 4~, AMOCO PRODUCTION, FLAC 986133-02_-3, AP1 5073o~0~300~ AUTH COST $396000~ AMOCO W~ I. 62. 5000 OPERATIP~-~°'~,~. TD 10500 FT~ ~o=.~C)~,~ 103'~. , PULLiNg TUBIN~ PERTINENT DATA' RIg MOVE ON 10/27/86 C ~ ]"S' 0.~ DAILY MUD $5912, CUM MUD $5912, DALLY WELL $17933, CUM WEL.L $17933 REMARKS- I HR WAS SPENT PULLtN<P WORKIN~ OUT OF PACKER W/L STRIN¢. CHRON TIME DISTRIBUTION (HRS)' 2 O0 - OTHER, MIX KILL FLUID 3 50 - C IRC, 770 BBLS 8. 5 FLUID 0 50 - OTHER, INSTALL BPV 7 50 - NUBOP, NIPPLE DOWN TREE~ NU BOPS '~ 50 - OTHER, TEST BOPS .,° 00 - PTQ, P/SS TO SURFACE ~ - RTM ~ LOST WHEN C IRC ~ 00 CIRC, 50 BBLS TO F!LL HOLE~ 70 3 ~ - 'PT¢, PULL LS AND STAND BACK; PULL 160000 TO QET OUT SEAL ASSY dOB INITIATION REPORT: DIRECTIONAL HOLE RigCONTRACT DATA: CONTRACTOR BA CODE 611312, PARKER, Rig OFFSHORE-DERRiCK, TYPE- DAYWOR~4 CURRENT WELL ACTIVITY-COMPLT-O~G, DATE 11/20/86 **~ i0/30/86 *** SOUTH MIDDLE gROUND SHOAL ~3, S. MID gROUND SHOAL, PARKER 4B, ;1 Fl_AC 986133-02-3, API 50733~00~300, AUTH COST $396000, AMOCO W.I. 62. 5000 OPERATIONS: TD 10500 FT, TIH W/PACKER COSTS: CUM MUD $5912, DAILY WELL ~11518, CUM WELL $~9451 REMARKS: CAVITY WAS SANDY AND gRITTY AT STANDINg VALVE. NO TROUBLE REMOVIN~ S.V. CAVITY NOT SCRATCHED. WATER USED iN HOLE LAST 24 HRS - 737 BBLS. TOTAL 857 BBLS. CHRON TIME DISTRIBUTION (HRS): 2. 50 - PT~, POH W/3 IN. F CAVITY 13. 50 - PU, DP X RIH W/8-I/2 IN. BIT; NO TIGHT SPOTS. TAg PKR AT c]3~1 FT i. O0 - RRIg, REPAIR CATHEAD 3. 50 - TRIP, OUT W/8-1/2 IN. BIT 3~ 50 - TRIP, IN W/RETRtEVAMATIC PACKER *** 10/31/86 *** SOUTH MIDDLE gROUND SHOAL #3, S. MID ~ROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, --FLAC 986133~-0~-30 API 50733200P_300~- AUTH COST $396000~ ~AMOCO W. I. 62. 5000 .... OPERATIONS: TD 10500 FT, WORK ON RI~ ~ _ DENVER REGION *** ANCHORAGE DISTRICT -~-** 01/06/87 *~-...~ PAgE 3 COSTS: DAILY MUD $1480, CUM MUD $7392, DAILY WELL $14498, CUM WELL $43949 REMARKS: FLUID LOSS TODAY- 430; TOTAL 1287. SET IN PACKER - PUMP AWAY AT 1350 PSI AT 9391 FT. SET IN PACKER - PUMP AWAY AT 1350 PSi AT 9381 FT. SET IN PACKER - PUMP AWAY AT 1350 PSI AT 8915 FT. SE-[ IN PACKER - PUMP AWAY AT 1350 PSI AT 8449 FT. HELD 900 PSI FOR ID MIN - PUMPING 5 BBLS/MIN SET PKR - PUMP AWAY AT 1350 PSi AT 7982_ FT. ].3-3/8 ANN 150 PSI. SET IN PACKER - PUMP AWAY AT 1350 PSI AT 7055 FT. PMP 15 BBLS SET PKR - PUMP AWAY AT 1350 PSI AT 6.963 FT. I3-3/8 ANN 150 PSI. SET iN PACKER -- PUMP AWAY AT t350 PSI AT 603i FT. SET ZN PACKER -PUMP AWAY AT !350 PSi AT 5097 FT. SET PKR - PUMP AWAY AT t350 PSI AT 4485 FT. HELD 2500 PSI 8 MIN 5ET IN PAC~qER- PUMP AWAY AT 1330 f'SI AT DOg7 FT. SET IN PACKER - PUMP AWAY AT 1350 PS! AT 4915 FT. SET iN PACKER - PUMP AWAY AT 1350 PSt AT 4822 FT. SET iN PACKER - PUMP AWAY AT 1350 PSi AT 4635 FT. SET PKR - PUMP AWAY AT 1350 PSI AT 454i FT. HELD 2500 PSI I0 MIN CHRON TiME DISTRIBUTION (HRS): 4. 50 - TSTCSG, SET PACKER X TEST 1. 50 - CIRC, WELL 5. O0 - TSTCSG, SET PACF, ER X TEST. HOLE BETWEEN 4541 - 4635. ].3. O0 - RRIg, TRANSMISSION BAD ON DRAWWORKS. REMOVIN.~ TRANSMISSION. 11/01/86 SOUTH MIDDLE GROUND SHOAL ~3, S. MID GROUND SHOAL, PARKER Z~B, AMOCO PRODUCTION, FI_AC 986133-02-3, AP1 507332002300, AUI'H COST $396000, AMOCO W.I. 62. 5000 OPERATIONS: TD 10500 FT' TIH W/PACKER MILL COSTS: CUM MUD $7392, DAILY WELL $16697, CUM WELL $60646 REMARKS: FLUID LOSS DAILY- 105 BBLS; TOTAL 1392 BBLS. CHRON TIME DISTRIBUTION (HRS): 16. 50 - PRIG, REPLACE DRAWWORKS TRANSMISSION AND HEAD ON RIQ ENGINE. 2. 50 - TRIP, OUT W/PACKER i.00 - OTHER, P/U PACKER MILL 4. O0 - TRIP, IN W/PACKER MILLING TOOLS 11/02/86 *** SOUTH MIDDLE OROUND SHOAL ~3, S. MID OROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, FLAC 986133-02-3, AP1- 507332002300, AUTH COST $396000, AMOCO W. I. 62. 5000 OPERATIONS' TD 10500 FY, LOOOINO W/SCHLUMBERgER - COSTS: DAILY MUD $148, CUM MUD-$7540, DAILY WELL $176&6, CUM-WELL $78312 REMARKS- FLUID LOSS DAILY - 80 BBLS; TO~AL ~147~ BBLS. CHRON TIME DISTRIBUTION (HRS)- - O. 50 - TRIP, IN W/PACKER MILLINg TOOLS DENV£R REt}iON **~ ANCHORAGE DISTRICT *** 0i/06/87 *** PA~E P. 50 - OTHER, MILL AND PLUCK MODEL "D" PKR AT 9391 FT. 1. 50 - CIRC, BOTTOMS UP 5. O0 - TRIP, OUT W/PACKER 1. O0 - OTHER, L/D PKR AND MILLINg TOOLS 4. O0 .... TRIP, O. 50 -- RSER, 1. O0 - TRIP, 2. O0 - C IRC, 4. 50 - TRIP, IN W/8-1/2 IN. BIT X SCRAPER SLIP X CUT DRL LINE P. U DP; TIH; TAg FILL AT 10157 FT. BOTTOMS UP OUT SLM. RU SCHLUMBERC;ER; RUN CET LOC~ 11/03/86 SOUTH MIDDLE gROUND SHOAL ~3, S. MID gROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, FLAC 9B6133-02-3, AP1 507332002300, AUTH COST $3~6000, AMOCO W.I. 62. 5000 OPERATIONS: TD 10500 FT, TIH W/RETRIEV-O-MATIC PKR COSTS' CUM MUD $7540, DAILY WELL $14518, CUM WELL $92830 REMARKS'FLUID LOSS DAILY - 185 BBLS; TOTAL 1657 I~BLS. AFTER PLUg WAS AT 2100 HRS HOLE TOOK 30 BBLS AT 0600. CHRON TIME DISTRIBUTION (HRS)' 10. 50 - LOg, ATTEMPT TO RUN CET LOC-' FM 10157-6400 FTC LO(} WOULD NOT REPEAT. CHANGED TOOL; SAME RESULTS 4. 00 - TRIP, IN W/BAKER CMT RETAIN 0. 50 - OTHER, SET RET AT 9760 2. O0 - C IRC, B TMS UP - NO gas 3. 50 - TRIP, OUT X L/D SETTINg TOOL O. 50 - TRIP, IN 9 STDS {8_9 FT. } 3-1/2 IN. TBg P/U BAKER RETRIEV-O-MATIC O. 50 - RSER, SLIP DRL LINE 25 FT. 2. 50 - TRIP, IN W/3-1/2 D. P. W/RETRIEV-O-MAT!C X TAILPIPE 04/86 *** SOUTH MIDDLE gROUND SHOAL #3, S. MID gROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, FLAC 986133-02-3, AP1 507332002300, AUTH COST $396000, AMO{;u W. I 62. 5000 OPERATIONS: TD 10500 FT, LOggiNg W/SCHLUMBERgER COSTS: CUM MUD $7540, DAILY WELL $19833, CUM WELL $112663 REMARKS: MIX SLURRY W/2% KCL; 1. 35% FL19; 3% CD31; 1 gaL/lO0 SX FP61; AT 15. 8 PPg. DISPL W/68 BBLS KILL FLUID TO SPOT BALANCED PLUg. TOP CMT EST AT 9315 FT. LEAK LOCATED AT 4541-4635 FT. CHRON TiME DISTRIBUTION (HRS): 0..50 - TRIP, 2.- 50 - C IRC, 3. 50 ~---.-- CMT., O. 50 = TRIP, 2. O0 - SO, IN; TAg BP AT 9760: FT:. P. U 3 FT. AT 9757 FT - BTMS UP - BATCH-MIX X PUMP 50 BBL SLURRY OUT 9~-STDS;-REV 75 BBLS X SET RETRIEV-O-:MATIC AT 8080;~ PRESS ANN 500 PSI ~ S(~UEEZE 16. 2-5 BBL- C'MT] FINAL PRESS 2400 PSI DENVER REGION *** ANCHORAGE DISTRICT ~* 01/06/87 ~*~ PA~E 5 8. O0 -- WOC, WAIT ON CMT 2. O0 - TRIP, OUT TO 4637 PKR DEPTH 1. O0 - OTHER, SET RETRIEV-O-MATIC AT 4637; T.P AT 5474; PRESS CSt 1400 PSI BLED TO 900 PSI IN 2. MINi SET PKR AT 4665~ PRESS CS~} W/SAME RESULTS. 1. 50 - TRIP, OUT X L/D RETRiEV-O-MATiC ~ 50 - LO(}, W/SCHLUMBERgER/CET 11105/86 *** SOUTH MIDDLE gROUND SHOAL f~3, S. MID gROUND SHOAL~ PARKER 4B, AMOCO PRODUCTION, · 0 ' F'LAC 9~_.~133-0~-3, API 50733200~300, AUTH COST $396000, AMOCO W. !. 6~. 5000 OPERATIONS: TD 10500 FT, TIH W/8-I/2 IN. BIT COSTS: CUM MUD $7540, DAILY WELL $39447, CUM WELL $1521i0 REMARM. S- FOLLOW!N~ ARE ABOVE PRR TESTS AT 463i FT 14.00 PSI AT {HELD i100}; AT 4616 1400 PSI AT 5 BBL/M!N {HELD 1100}; AT 4601 1400 PSI AT 5 BBL/MIN {HELD 1100}. LEARS AT 4541-4601; 5617-5651 CHRON TIME DISTRIBUTION (HRS)~ 3~ 50 - LO~, SCHLUMBERQER-CET. HOLES INDICATED AT 7186 X 7~36. 3. 50 - TRIP~ IN X SET BP AT 7~75; PRESS UNDER BP KO00 PSI X HELD O~ TRiP OUT X L/D SETTIN~ TOOL 1~ O0 - TRIP, IN W/7 STD DP X RETRIEV-O I~ O0 - RSER~ CUT DRLg LINE 130 ET 3. O0 - TRIP, IN; SET PKR AT 6619 - TAILPIPE AT 7274 FT 4. 50 - OTHER, ATTEMPT PUMP INTO SUSPECT HOLES AT 7186-7~36 HELD ~000 PSi PULL UP TO 5643 PRR DEPTH; HELD ~i00 PSi UNDER PER; PULL UP TO 5~6; TOOK 1700 PSI AT 5 BBL/MIN; BLED TO 900 PSI UNDER PKR X TOOK 1300 PSI AT 5 BBL/MIN; BLED I100 PSI ABOVE PKR AT 5590 FT. 1800 PSI AT 5 BBL/MIN {HELD 1100}; AT 5663 FT. HELD ~300 PSI; AT 5651 FT. HELD ~00 PSI; AT 5617 FT 1800 PSI AT 5 BBL/MIN {HELD 1100}; 2~ O0 - TRIP, OUT X L/D PRR i. 50 - OTHER, WAIT ON TOOLS 1~ O0 - TRIP, IN W/8-1/~ IN. BIT; ~ dUNK BASKETS X 8 EA. 4-3/4 IN. DC *** 11/06/86 *~* SOUTH MIDDLE gROUND SHOAL ~f3, S. MID gROUND SHOAL, PAR~ER 4B~ AMOCO PRODUCTION, FLAC 986133-02-3, AP1 507332002300, AUTH COST $396000, AMOCO W.I. 6~. 5000 OPERATIONS' TD 10500 FT, WOC - S(]UEEZE #~ ~ COSTS: CUM MUD $7540, DAILY WELL $40151, CUM WELL $192~61 _~ CHRON TIME DISTRIBUTION -(HRS)o _ ~. O0 - TRIP,-~ IN W/BIT TO BP AT 7~75 4. O0 - OTHER, DRILL UP BRIDQE PLUQ 3. O0 - TRIP/ OUT X L/D BIT X dUNK BASKET 2. 50 - TRIP,- IN X SET BP A-T 5765; PRESS TEST UNDER BP 2000 PSI--- OK . DENVER REGION *** ANCHORA~TE DISTRICT *** 01/06/87 *** PAOE 6 3. O0 - TRIP, OUT X L/D RUNNINQ TOOL 1. 50 - TRIP, IN W/5-I/3 STDS TAILPIPE X PKR O. 50 - RS{R, SLIP DRLO, LINE O. 50 - TRIP, IN TO 5674 W/TAILPIPE 5. 50 - OTHER, SET PKR AT 5t65~ TST LINES TO 3500 PSI; PUMP INTO BREAK W/RILL FLUID AT 1o 5 BBL/MIN 1250 PSI; MIX 30 BBL CMT SLURRY W/146 SX CMT-3% KCL; . 7% FL19; 3% CD31; I gAL/lO0 SX FP6L. PUMP SLURRY X DISPL W/38 BBLS KILL FLUID {BALANCED}; PULL 5-1/3 STDS; REV C IRC 50 gBLS; SET PKR AT 4669 X TAILPIPE AT 5!76; CONDUCT HESITATION SQUEEZE W/19-3/4 BBLS FINAL SQUEEZE PRESS AT 0600 = 2240 PSi. 1. 50 - WOC 0'7/86 *** SOUTH MIDDLE ~ROUND SHOAL #3, S. MID ~ROUND SHOAL, PARK, ER- .q.B, AMOCO PRODUCTION, FLAC 986133-02-3, AP1 507332002300, AUTH COST $396000, AMOCO W.t. 62. 5000 OPERATIONS: TD 10500 FT, WOC- SGUEEZE ~3 t C- - CO~,TS CUM MUD $7540, DAILY WELL $24458 CUM WELL $216719 CHRON TiME DISTRIBUTION (HRS) 6. 50 -- WOC, FINAL PRESS 2000 PSI O. 50 -- OTHER, RLSE PRESS; i B13L 13ACIE; TOH 60 FT. RESET PI&R. TST CSO,- BELOW 2000 PSI - 3. O0 - TRIP, OUT X L/D RETRIEV-O-MATIC '3. O0 - TRIP, IN X SET BP AT 4603 FT ~ O0 - TRIP OUT W/SETTINO, TOOL 2. O0 - TRIP, IN W/8 STD TAiLPiPE X PKR 3. 50 SC, .q~ - ~r_T PKR AT 3854 FT; TST LINES 3000 PSI. ESTABLISH RATE 1 BBL/MIN AT 1250 PSI. UNSEAT PKR. gAl'CH MIX 40 BBLS CMT W/19~ SX CMT; 3% ECL; .7% ~L19; 37. CD3!; 1 GAL/lO0 SX FP6L. PUMP SLURRY X DISPL X BALANCE W/30 BBL_ KILL FLUID. TOH 8 STDS; REV 40 BBLS; SET PER AT 3110 X TAILPIPE AT 38~4. CONDUCT HESITATION S(~UEEZE. 3. 50 - WOC, FINAL PRESS AT 0600 = 1350 PSI. *** 11/08/86 *** SOUTH MIDDLE gROUND SHOAL #3, S. MID ~ROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, 'FLAC 986133-02-3, AP1 507332002300, AUTH COST $396000, AMOCO W.I. 62. 9000 OPERATIONS' TD iO500~FT, SGUEEZE #4 COSTS: CUM MUD $7540, DAILY WELL $23770, CUM WELL $240489 _. -CHRON TIME. DISTRIBUTION (HRS)- -' 5. 50 - WOC,-- FINAL .PRESS 800 DP; 700 ANN 2. 50 - TRIP, OUT X L/D RETR-O-MAT_IC - : 2. O0 - TRIP, IN W/8-1/2 BIT X 2 IN. dUNK SUBS 3. O0 - DRLCMT, F/4400 - 4547 FT {HARD} DEI',tVER REGION *** ANCHORAGE DISTRICT ~.4 01/06/87 4.4 PAgE 7 t O0 - CIRC, OUT CUTTINGS 1 50 - DRLCMT, TO BP AT 4605 1 50 - CIRC, OUT CUTTINGS 0 50 - OTHER, TEST CSG <1600 PSI AT 5 BBL/MIN> 1 O0 -- C IRC, CLEAN 2 O0 -- TRIP, OUT X L/D BIT X JUNK SU~S 2 O0 - TRIP, IN W/8 STDS 3-1/2 IN. DP TAILPIPE X RETR-O-MATIC i 50 - S(~, SET PKR AT 385z~J TST LINES 3000 PSI - OK. ESTABLISH RATE 1 BBL/MiN AT t400 PSi. RELEASE PKR. BATCH MIX 40 BBL. SLURRY W/192 SX CMT; 3% KCL; .7% FL19; 3% CD3i; 1 GAI_/iO0 SX FP6L. PMP SLURRY. DiSPL X BALANCE W/30 BBLS KILL_ FLUID 109188 **~ SOUTH MIDDLE (~ROUND SHOAL ~3, S. MID GROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, , ',.~- ~5__ F'L~'-' 98.B13._, O: .d, AP1 507332002300,. AUTH COST $396000, AMDCO W.I. ~2. 5000 OPERATIONS: TD 10500 FT, TOH FOR PKR AT TAILPIPE COSTS' CUM MUD $7540, DAILY WELL $22552, CUM WELL $263041 CHRON TIME DISTRIBUTION (HRS)' 2. O0 - S(~, PULL 8 STDS 3-1/2 DP; REV CIRC 50 BBLS. SET PKR AT 3i13 FT W/TAILPIPE AT 3862 FT. CONDUCT HESITATION SQUEEZE W/25 BBL. CMT; MAX PRESS 2600 PSI. FINAL PRESS 2300 PSI {HELD 625 ON ANNULUS} 9. 50 - WOC, FINAL PRESS 1600 PSI {3/4 BBL BASE} 2 O0 - TRIP, OUT X L/D PKR 2. 50 - TRIP, IN. TA~ CMT AT 4454 2. O0 - DRLCMT, F/4454- 4550 FT {SOFT} 1 O0 - C IRC, CLEAN ! O0 - DRLCMT, TO BP AT 4&05 1 50 - C !RC, CLEAN 1 O0 -- OTHER, PRESS TST W/RIO PUMP; 1900 PSI BLED TO 1200 4 MIN; t~O0 PSI BLED TO 1200 1 MINi 1900 PSI BLED TO 1200 30 SEC. RI~GED UP BJ TITON; PUMPED WATER 4 BBL/MIN AT 2200 PSI 1. 50 - TRIP, OUT **~ il/10/86 *** SOUTH MIDDLE gROUND SHOAL ~3, S. MID GROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, F-LAC 986133-02-3, AP1 507332002300, AUTH COST $3c~6000, AMOCO W.I. 8~. 5000 ', OPERATIONS: TD 10500 FT, DRLCMT - COSTS:. CUM MUD '$7540, DAILY WELL $22&57, CUM WELL $285698 CHRON TIME DISTRIBUTION._ (HRS): O. 50 - TRIP, OUT X L/D BIT ASSY 2. 50-- TRIP, - 4. O0 - S(~, IN. TAO BP AT 4600 SET PKR ~T ~m56 F~. Trot L INE8 3000 P~I - OK. E8TABLISH INd RATE W/FIW WATER 4-1/4 BBL/MIN AT ~500 PSI. RELEASE DENVER REGION *** ANCHORAGE DISTRICT *** 01/06/87 *.** PAgE PKR. BATCH MIX 40 BBL SLURRY W/192 SX CLASS '°g"; 5% MCL; 1% FL19; . 3% CD31; . 3% A3; 1 OAL/IO0 SX FP6& {15. 8 PPO}; PUMPED SLURRY. DISPL X BALANCE W/29 BBLS KILL FLUID. PULL 8 STDS. REV C IRC 40 BBLS. SET P[4R AT 3113 FT {TAILP!PE 3862 FT}. CONDUCT HESITATION SQUEEZE W/26-7/8 BBLS~ MAX PRESS 2700 PSI. FINAL PRESS 2500 {SLOWLY BLEEDINg OF[--}. 9o O0 - WOC, PRESS 1250 PSI - BAC~4 1/2 BBL 2z. O0 - TRIP, OUT X L/D RETR-O-MATIC 3. 50 - RSER, CH£~ SWIVEL PACW. INg ~- c)O TRIP iN W/BIT m~o.o TAg CMT 4455 O. 50 - DRLCMT, CMT IS HARDER 'THAN PLUg ~4 BUT SOFTER THAN PLUg ~.3. /86 **~ SOU]'H MIDDLE gROUND SHOAL ~3, S. MID gROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, FLAC 986133-02-3~ AP1 50733~2002300, AUTH COST $396000, AMOCO W. I. 62. 5000 OPERATIONS' TD 10500 FT, CHg BI'[ X CLEAN JUNK BAS~ETS COSTS' CUM MUD $7540, DAILY WELL $1].518, CUM WELL $297216 REMARKS- DRILL PIPE X ANNULUS CAPCITY WAS 400 BBLS CHRON TiME DISTRIBUTION (HRS)' [2~ O0 - DRLCMT, MEDIUM 1. O0 - CIRC O. 50 - DRLCMT, TO 460T FT. =.~ 50 - CIRC~ CLEAN O. 50 - TSTCSg, 1500 PSI 30 M IN- OK ~' O0 - TRIP, OUT; P/U dUNK BASKETS 2. O0 - TRIP, IN 3. 50 - OTHER, DRILL UP BRIDGE PLUg AT 4605 FT O. 50 - TRIP, IN; TAg CMT AT 5533 FT i. 50 - OTHER, DRILL JUNK AT TOP OF CMT '~ O0 - DRLCMT, HARD TO 5675 FT ~.~ O0 - CiRC, CLEAN 1. O0 - TSTCSg, PRESSURE 'TS]' CSg TO 1500 PSI W/P-3/4 BBLS RILL FLUID. PRESSURE BLED TO 1300 PSI IN iO MIN; FROM i300 TO l~7D IN 10 MIN~ FROM 1275 TO 1250 IN 10 MIN. 2_. O0 - TRIP, OUT FOR NEW BIT SOUTH MIDDLE gROUND SHOAL #3, S. MID ~ROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, FLAC 986133-02=3, APl 50733~_002300, AUTH COST $396000, AMOCO W.I. 62..5000 OPERATIONS: TD 10500 FT, DRL BRIDQE PLUQ JUNK AT 9310 COSTS: CUM MUD $7540, DAILY WELL $722, CUM-WE~L $297938 - REMARKS:: COST REFLECTS $10746 CREDIT!FOR BJ TITONS HIOH ESTIMATE' - - CHRON TIME DISTRIBUTION (HRS): ? 2. 50 - TRIP, IN W/NEW BIT TO 5675 FT' DENVER REGION ~**. ANCHORAGE DISTRICT ~** 01/06/87 *~* PAgE 4. O0 - OTHER, DRILL BRIDO~E PLUO AT 5675 FT 1. 00 - RSER, REPLACE QOOSE~qECR SEAL J~. 00 - OTHER, DRILL UP BRIDGE PLUQ 1. O0 - TRIP, IN X TAg dUNK AT 9225 FT 1~ 50 - TRIP, OUT X L/D 17 ,)TS D.P. NEEDED TO DRILL dUNK X CMT 3. 00 - OTHER, DRILL ON BP dUNK AT 9310 4. 00 - TRIP, OUT FOR NEW BIT O0 - TRIP, IN · 2. O0 - OTHER, DRILL ON BRIDGE PLUg JUNK AT 9310; PIECES F/~f2 X #3 BP ARE SPINNING ATOP ONE ANOTHER 11/13/86 *** SOUTH MIDDLE gROUND SHOAL ~3, S. MID (~ROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, FLAC 986133-02-3, AP1 50733200~300, AUTH COST $396000~ AMOCO W. I~ 6P. 5000 OPERATIONS' TD i0500 FT~ PREPARE TO TRIP FOR BIT COSTS' CUM MUD $7540, DALLY WELL $16160, CUM WELL $314098 REMARKS· CHECKED FOR FLUID LOSS 9315-9505 FOR 5 M!N - CHECKED FOR FLUID LOSS 9DOO-96D9 FOR CHECW, ED FOR FLUID LOSS 9659-9760 FOR 15 MIN - CHRON TIME DISTRIBUTION (HRS)~ 7 O0 - OTHER~ DRIL UP dUNK AT 9315 FT ~ O0 - DRLCMT~ TO 9505 FT 1 50 - C IRC, OUT CEMENT CUTTINGS 4 O0 - DRLCMT, TO 9659 FT i 50 - C iRC, OUT CEMENT CUTTINGS 2 50 - DRLCMT, TO TOP oF BP AT 9760 FT =.~ 50 - C IRC, CLEAN 14/86 *** SOUTH MIDDLE ~ROUND SHOAL f~3, S. MID gROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, FLAC 986133-02-3~ AP1 507332002300, AUTH COST $396000, AMOCO W.I. 62. 5000 OPERATIONS: TD 10500 FT, CIRC AT 10157 FT COSTS: CUM MUD $7540, DAILY WELL $7876, CUM WELL $321974 REMAR~4S:DAILY FLUID LOSS = 59 BBLS OF FRESH WATER W/5~/BBL ~CL TOTAL FLUID LOSS = 1716 BBLS. CHRON TIME DISTRIBUTION (HRS): 3. 50 - TRIP, OUT FOR NEW BIT 2. 50 - RRIQ, CATHEAD'BEARiNQ LOCKED UP O~ 50 - .RSER, CUT DRL LINE 120 FT 1. O0 - TRIP~ OUT X CLEAN dUNK SUBS 4. 50 - TRIP, IN W/NEW 8-1/2 IN. BIT -- 5.00 - OTHER'~ ' DRILL BP AT 9760. FT ~ 3. O0 - DRLCMT, TO 99L~2-~ B.P. DROPPED TO 97~0~ DRLD ~IRM CHI~ 9772-9~2~ FT {CMT COMMUNICATED BELOW BRIDGE PLUg AT 9760 FT} ., DENVER REOiON *** mNCH_~AGE DISTRICT *** 01/06/87 **~ PAGE 10 :..'-' O0 - CIRC, O. 50 - TRIP, 1. 50 - C IRC C LEAN IN TO 10157 FT 5/86 *** SOUTH MIDDLE gROUND SHOAL 4,3, S. MID GROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, -X-'.~. ~" ~. -""~ "-" ~.~-~. ~. ,, ***************-************ ****************************************************** FL_AC 986133-02-3, AP1 507332002300, AUTH COST $396000, AMOCO W.I. 62. 5000 OPED~."rT''-~.~q'. _,,., .... ,,-,,.., TD 10500 FT, P/U =."~-7/8 IN. TBO COSTS: CUM. MUD $7540, DAILY WELL $13331, CUM WELL $335305 REMARKS' DAILY FLUID LOSS = 0 BBLS; TOTAL FLUID LOSS = 1716 BBI_S. CHRON TiME DISTRIBUTION (HRS)' 1. O0 - C tRC, 5. O0 - TRIP, 5. O0 - TRIP, 2. O0 - C IRC 9. 50 - LD, i. 50 - PU, C LEAN OUT; L/D BIT~ P/U SCRAPER IN W/9-5/8 IN. SCRAPER 3-1/2 IN. DP X SCRAPER 2-7/8 IN. BUTT TBG SOUTH MIDDLE GROUND SHOAL ~3, S. MID GROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, FLAC 986133-02-3, API 507332002300, AUTH COST $396000, AMOCO W.I. 62. 5000 OPERATIONS' TD 10500 FT, ]"OH COSTS: CUM MUD $7540, DAILY WELL $11518, CUM WELL $346823 CHRON TIME DISTRIBUTION (HRS)* 8. 50 - PU, 2-7/8 IN. BUTT TBG ~):. O0 - CIRC 4~ O0 - TRIP, OUT X STANDBACK TBG '~ 50 - OTHER, P/U 5 IN. VANN GUNS ~- o 5. 50 - TRIP, IN W/3-1/2 IN. TBg; FILL 5034 FT. W/½CL WATER 1. O0 - OTHER, RIGGED UP SCHLUMBERGER TO CORRELATE GUN DEPTHS; TBG WAS FULL OF KCL WATER {LOST UNDERBALANCE} O~ 50 - TRIP, OUT INSPECTING FOR TBG OR TOOL LEAF, PERFORATIONS' 11/16/86, TOP 9770 FT, BOTTOM 9850 FT, TYPE-OPEN, SHOTS/FT. 4, PERF DIAM. O. 450 IN, TOTAL NO. SHOT GUN-NON-EXPENDABLE, SIZE 5.000 IN, PHASING 90 DEG, FLUID TRT-WATER, DENSITY 8.4 PPG, LEVEL '5000 FT 11/16/86, TOP 9875 FT, BOTTOM 9950 FT, TYPE-OPEN, SHOTS/FT. 4, PERF DIAM: O. 450 IN, TOTAL NO. SHOT ~50o GUN-NON~-EXPENDABLE, SIZE 5.000 IN, PHASING 90 DEG, FLUID TRT-WATER, DENSITY 8.4-PP~, LEVEL 5000 *** 11/.17/86 . ***- DENVER REGION *** ANCHORAGE DISTRICT *** 01/06/87 *~* PAgE 11 SOUTH MIDDLE gROUND SHOAL #3, S. MID gROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, FLAC 986133-02-3, API 507332002300, AUTH COST $396000, AMOCO W.I. 62. 5000 OPERATIONS- TD 10500 FT, RUN PRODUCTION PKR ON WIRE COSTS: CUM MUD $7540, DAILY WELL $11518, CUM WELL $358341 REMARKS' NOTE: MODEL "D" PACKER SET AT 0700 HRS. CHRON TiME DISTRIBUTION (HRS)- 3. oo - TRIP, OUT; FOUND HOLE IN T~Q 60-i/3 STDS OUT; El IN. FROM BOX. REST OF TBg LOOKS OK O. 50 - OTHER, PRESS ANNULUS 800 PSI; NO CiRC UP TB~}¢ TOOL MUST BE CLOSED ABOVE PERF gUNS I. 50 - TRIP, IN. LEFT 5000 WATER CUSHION ?. 50 - LOg, CORRELATE gUN DEPTH i. O0 - PERF, ADJ DEPTH DN 4 FT DROPPED FIRINg BAR. gUNS FIRED. NO BUBBLE BUCKET BLOW FOR 15 MIN. 30 MIN STRONg BUBBLES BUT NO PRESSURE. PACKER SET AT 9686 FT. '~' O0 - C IRC RELEASE PKR X REV BOTTOM UP SAMPLE WATER 6. 50 - TRIP, OUT X L/D gUNS- ALL FIRED 7. O0 - OTHER, RAN MOD "D" PKR W/SCHLUMBERgER TO 9361 FT; NO SET. FLOODED COLLAR LOC. RERAN TO 9361 FT. BURNED HEAD ROD. NO SET. ATTEMPT AGAIN. AS OF 6 AM *** il/i8/86 *** SOUTH MIDDLE gROUND SHOAL #3, S. MID GROUND SHOAL, PARKER 418, AMOCO PRODUCTION, F'LAC 986i33-02-3, API 507332002300, AUTH COST $396000, AMOCO W.I. 62. 5000 OPERATIONS- TD 10500 FT, RIH W/DUAL TUBINg COSTS: CUM MUD $7540, DAILY WELL $117305, CUM WELL $475646 REMARKS- "E" 2-1/2 IN. PARALLEL CAVITY S/N 2056 W/AN EXTENSION ON TOP WITH SEAL SLEEVE FOR RUNNINg 2-1/2 IN. TYPE "A" PUMP. CHRON TIME DISTRIBUTION (HRS)- 1. O0 - RU, CHANO~E TO 2-7/8 X 3-1/2 IN. RAMS 2. O0 - RU, WEATHERFORD AND P/U 2-1/2 IN. "E" CAVITY 2. O0 - RU, P/U 2 STANDS AND Rig UP HYDRO-TEST 19.00 -RT¢, R IH W/3-1/2 IN. BUTT X 2-7/8 IN. BUTT. HYDRO-TEST X BROACH *** 11/19/86 *** SOUTH MIDDLE gROUND SHOAL ~3, S. MID gROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, FLAC 986133-02-3, AP1 507332002300, AUTH COST $396000, AMOCO W.I. 62. 5000 OPERATIONS' TD 10500 FT, Rig REPAIR COSTS: CUM--MUD $7540, DAILY WELL $29568, CUM WELL $505214 CHRON TIME DISTRIBUTION (HRS)' ~- -' 2. O0 - -RT~, RIH W/DUAL 21-7/8 -X 3-1/2 IN. T-B~ 2. 50 -' CtRC, ANNULUS W/INHIBITED WATER W/PH OF 11 " I , , DENVER RE(~tON ~*~ ANCHORAGE DISTRICT ~*~ 01/06/87 *** PAgE 12 O. 50 - OTHER, LAND TBQ AT 9356 FT~ LS IN TENSION 4000# W/8 FT SEAL ASSY ABOVE PACKER; 12 FT. BELOW PKR 1. O0 - RD, 6. O0 - NDBOP 1.2. O0 - RREP, R I(~ DOWN WEATHERFORD X HYDRO-TEST Rig REPAIRS WHILE WAITINg ON PUMP TO START PUMPINg IN WELL. REPLACINg Rig ENGINE. REPLACE CATHEAD. REPAIR ROTARY CLUTCH. REPAIR WATER SPEAR; HAVINO. PROBLEMS WITH PUMP X 4-WAY VALVE. SOUTH MIDDLE gROUND SHOAL 1¢3, S. MID O. ROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, ***. ~ ~*** ~.*** ***.. ~***.. **.~. ~, ~** ~,.~.. ~.~.. ~.~. ~.~..**~. ~, ~*** ~ ~...~,~ ~** ~.~ FLAC 986133-02-3~ API 507332002300~ AUTH COST $396000~ AMOCO W.I. 62. 5000 OPERATIONS; TD 10500 FT, SERVICE MUD PUMP COSTS: CUM MUD $7540, DAILY WELL $14190~ CUM WELL $519404 REMARKS; PUMP DOWN X STROKiNg AT 2:O0 PM CHRON TIHE DISTRIBUTION <HRS)'. 12. O0 - OTHER, REPAIR RIg ENglBIE; CATHEAD; ROTARY CLUTCH X MISC PP.O~I_EM5. 8. O0 -- MO, SKID RIcO TO STORAGE '4. O0 - OTHER, CLEAN PITS; LEO= ROOM~ SERVICE MUD PUMP 11/21/86 *** SOUTH MIDDLE O=ROUND SHOAl_ ~3, S. MID gROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, FLAC 986133-0.9-3, AP1 50733200~300, AUTH COST $396000~ ~.M.~d W.I. ~. ~OOO OPERATIONS: TD 1OSOO FT, PUMPINQ COSTS: CUM MUD $7540, DAILY WELL $7967, CUM WELL $527371 REMAR~<S: RIO RELEASED 1~ NOON 1R/~0/86. 6 HR TEST: ROBE ~-1/2 "A" PUMP LIFT. 64 BOPD; 260 BWPD; MCFD 7. ~ ~OR 11~; BPOPD 500 AT ~500 PSI; SPM 71~ PUMP EFFICIE~Y 93%; ENOINE EFFICIENCY 100%. CHRON TiME DISTRIBUTION (HRS}: t.. O0 - OTHER, STACK DECK OUT; REPLACE HANDRAILS; SERVICE CRANES; CLEAN DEC~ 18. O0 - OTHER, PUMPINg - TESTIN~ /22/88 *** SOUTH MIDDLE QROUND SHOAL #3, S. MID QROUND SHOAL, PARKER 4B, AMOCO PRODUCTION~ F_LAC ~86133-02-3~ API 507332002300~ AUTH CCF3T $3~6000~ ~MOCO W.I. 62. 5000 - OPERATIONS: TD 10500-FT, PUMPINQ COSTS: CUM MUD $7540, CUM WELL $527371 - REMARKS: 6 HR TEST:-'- 100 BOPD;' ~36 BWPD; (~RAVITY 3:>. 8; MCFD' 10; : - O=OR 100; BPOPD 142 AT .9600-PSIi SPM 81 DENVER REGION *** ANCHORAGE DISTRICT -~** 01/06/87 ~** PAgE 13 CHRON TIME DISTRIBUTION (HRS)' 24o00 - OTHER, PUMPINC~ - TESTINg OUTH MIDDLE gROUND SHOAL ~3 S. MID GROUND SHOAL, PAR~,ER 413 AMOCO PRODUCTION, FLOC 9~6133-02-3~ API 507332002300~ AUTH COST $396000, AMOCO W.I. 6~. 5000 OPERATIONS' TD 10500 FT, PUMPtN~ Cnc'Tc- CUM MUD $7540, CUM WELL $5~7371 REMARKS'6 HR TEST: 88 BOPD; ~48 BWPD~ gRAVITY 3~. 7; MCFD 11. ~; gar i~7; BPOPD 150 AT 2600 PSI; SPM 8~ CHRON TIME DISTRIBUTION (HRS)' ~'~ O0 OTHER, PUMPIN~ - T=~TIN~ SOUTH MIDDLE (~ROUND SHOAL I$3, S. MID ~ROUND SHOAL, PARKER 4i3, AMOCO PRODUCTION, FLAC 986133-02-3, AP1 507332002300, AUTH COST $396000, ,-~, ,u,,_.O I. 62. 5000 OPERATIONS: TD 10500 ET, PUMPING CASTS: CUM MUD $7540, CUM WELL $527371 REMARKS~ 12 HR TEST: 100 ~OPD; 238 9WPD; MC~ 14; ~OR 140; BPOPD 301 AT 2500 PSi; SPM 83 . - ~ 24.00 - OTHER, PUMPIN~ - TESTIN~ *** 11/25/86 *** ~-~ OlJ & u~i~ b{;~o, ~'"~i~,raissiorl SOUTH lfllDDLE GROUND SHOAL ~3, S. MID GROUND SHOAL, PARKER 4B, AMOCO P~DUCTION, FLAC 986133-02-3, API 507332002300, AUTH COST $396000, AMOCO W.i. 62. 5000 OPERATIONS: TD 10500 FT, PUMPIN~ COSTS: CUM MUD $7540, CUM WELL $527371 REMARKS' 12 HR TESI' 152 BOPD; 182 BWPD; MCFD 14; QOR 92; BPOPD 602 AT 2500 PSI; SPM 83; ~RAVIIY 30.2 CHRON TIME DISTRIBUTION (HRS): 24. O0 - OTHER, PUMPIN~ - IESTIN~ *** 1 I-/26/86 *** - SOUTH MIDDLE GROUND SHOAL ;#3, S. MID ~ROUND SHOAL, PARKER 4B, AMOCO pRODUCTION, - FLAC 986133-02-3, APl' 50733200~300, AUTH COST $396000, AMOCO W. I. ~62. 5000 DENVER REGION *** ANCHORAGE DISTRICT ~** 01/06/87 *** PAgE 14 OPERATIONS: TD 10500 FT, PUMPINg COSTS: CUM MUD $7540, CUM WELL $527371 REMARKS: 6 HR TEST: 151 BOPD; 185 BWPD; MCFD 10. 4; gOR 69; BPOPD 600 AT -°500 PSI; SPM 84 CHRON TiME DISTRIBUTION (HRS)' 24.00 - OTHER, PUMPINg - TESTIN~ SOUTH MIDDLE ~'ROUND SHOAL $~3, S. MID gROUND SHOAL~ PARKER 4B, AMOCO PRODUCTION, FLAC Q86133-0~-3~ AP! 50733~00~300, AUTH COST AMOCO W.i. 6~. 5000 OPERATIONS: TD 10500 FT~ PUMP!N~ COSTS: CUM MUD $7540, CUM WELL $527371 REMAR~4S: 6 HR TEST: 100 BOPD~ ~1~ BWPD~ MCFD 17. 6~ ~OR 176; BPOPD 600 AT 2500 PSI~ SPM 81; GRAVITY 30.9 CHRON TIME DISTRIBUTION (HRS): ~4~00 - OTHER, PUMPINg - TESTINg 11/28/86 *~ SOUTH MIDDLE gROUND SHOAL .~.3, S. MiD gROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, FLAC ~6133-02-3 APl 50/J~_00c_300~ AUTH COST $396000 AMOCO W.I. 62. 5000 OPERATIONS: TD 10500 FT~ PUMPIN~ COSTS: CUM MUD $7540, CUM WELL $5R7371 CHRON TIME DISTRIBUTION (HRS): 24.00 -OTHER, PUMPINg- NO gUA(~E 11129/86 *** SOUTH MIDDLE gROUND SHOAL #3, S. MiD gROUND SHOAL., PARKER 4B, AMOCO PRODUCTION, FLAC 986!33-02-3, API 507332002300, AUTH COST $396000, AMOCO W.I. 62. 5000 OPERATIONS' TD 10500 FT, PUMPINg COSTS~ CUM MUD $7540~ CUM WELL $527371 REMARKS-6 HR TEST' 144 BOPD; 19~ BWPD; MCFD 19.2; gOR 133; BPOPD 600 AT 3000 PSI; SPM 41; gRAVITY 32.8 CHRON TIME DISTRIBUTION ~ 24.00 - OTHER~ PUMPINg - TESTINg - ***~ 11/30/86 *** '- '~ _ SOUTH MIDDLE gROUND. SHOAL #3, S. MID QROUND SHOAL~ PARKER 4B, AMOCO PRODUCTION~ DENVER 'REGION *.~* ANCHORAGE DISTRI~,~, ~*~ .... 01/06/87 ~** PAgE · Fi_AC 986133-02-3, API 507332002300, AUTH COST $396000, AMOCO W.I. 62. 5000 OPERATIONS: TD 10500 FT, PUMPINg COSTS' CUM MUD $7540, CUM WELL $527371 REMARK. S' 6 HR TEST' 124 BOPD.; 204 BWPD; MCFD 17.6~ gOR 142~ BPOPD 604 AT 3000 PSI; SPM 40; gRAVITY 3P. 8 CHRON TIME DISTRIbUTiON (HRS)' 24.00 - OTHER, PUMPINg - TESTiNO~ 15 SOUTH MIDDLE ~ROUND SHOAL ~3, S. MID gROUND SHOAl_, PARKER 4B, AMOCO PRODUCTION, FLAC 986133-02-3 AP1 507,_,o~.00=~00 AUTH COST $3~6000~ AMOCO W.I. 62. 5000 OPERATIONS: TD 10500 FT, PUMPtNO~ COSTS~ CUM MUD $7540, CUM WELL $5~7371 REMARKS- 6 HR TEST~ 136 BOPD; 184 BWPD~ MCFD 19. 6~ gOR ;1.44; BPOPD 612 AT 3000 PSI; SPM 40 CHRON TiME DISTRIBUTION (HRS)~ 24.00 - OTHER, PUMPINg - TESTINg *** i2102/86 **~ SOUTH MIDDLE gROUND SHOAL .~3,' S. MID OROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, ***~***~*****~******~*~*******~***~**~****~***~*.***~*~**~*******~*******~**** FLAC 986i33-0~-3, AP1 507332002300, AUTH COST $396000, AMOCO W.I. 62. 5000 OPERATIONS: TD 10500 FT.,. PUMPINg COSTS' CUM MUD $7540, CUM WELL $527371 REMARKS' 12 HR TEST' 160 BOPD; 168 BWPD; MCFD 18. 8; OOR 118~ BPOPD 608 AT 3100 PSI; SPM 42 CHRON TIME DISTRIBUTION (HRS)' °4 O0 - OTHER PUMPINg - TEST IN6; ~** 12/03/86 *** SOUTH MIDDLE gROUND SHOAL ~3, S. MID gROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, FLAC 986133-02-3, APl 507332002300, AUTH COST $396000, AMOCO W.I. 62. 5000 OPERATIONS- TD 10500 FT~ PUMPIN~ COSTS' CUM MUD $7540, CUM WELL $527371 _ REMARKS' 6 HR TEST' 202 BOPD; 154 BWPD; MCFD 24.8; OOR 123; BPOPD _ - 744 AT 3500 PSI; SPM 58~: gRAVITY, 31.7 CHR.ON TIME D~STRIBUTION (HRS)' ' . 24. O0 - OTHER, PUMPINg - TESTINg __ - DENVER REg.ION *** ANCHORAGE DISTRICT *** 01/06/87 *~* PAgE 16 *** 12/04/86 *** SOUTH MIDDLE gROUND SHOAL #3, S. MID gROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, FLAC 986133-02-3, API 50733FZ00~300~ AUTH COST $396000, AMOCO W.I. 62. 5000 OPERATIONS' TD 10500 FT, PUMPINg COSTS' CUM MUD $7540, CUM WELL $527371 REMAR~;S' 6 HR TEST' 240 BOPD; 120 BWPD; MCFD 25. 2; gOR ].05; BPOPD 744 AT 36010 PSI; SPM 60.~ gRAVITY 30. 4 CHRON TIME DISTRIBUTION (HRS)' =~z~,. O0 - OTHER, PUMPINg - TESTINO~ · ~/05/86 **4 SOUTH MIDDLE gROUND SHOAL ~$3, S. MID gROUND SHOAL~ PARKER 4B, AMOCO PRODUCTION, ****. **~ .**** **** **** **** ***....~. ~..** **~. ~**. ~.. **~ ~ .~....~ ~ ~**~ ~. **~. ~ ** ~ ~.~ FLAC 986133-02-3, AP1 507332002300, AUTH COST $396000, AMOCO W.I. 62. 5000 OPERATIONS: TD 10500 FT, PUMPIN~ COSTS: CUM MUD $7540, CUM WELL $527371 CHRON TIME DISTRIBUTION (HRS): 24.00 -OTHER, PUMPINg- NO ~UAQE ***. 1P_/06/86 *** SOUTH MIDDLE gROUND SHOAL #3, S. MID gROUND SHOAL, PAR~ER ~B, AMOCO PRODUCTION, ~*** **** **** **~. **** **~. ~*** ~.~ ~**~ .~. ~..~. ~.~ ~ *** ~,.~ ~ ~ .~..~ **~. ~ ~**~ ~ FLOC 986133-0~-3, ~RI 50733~00~300~ ~UTH COST $396000, AMOCO W.I. 6~. 5000 OPERAT!ONS~ TD 10500 FT, PUMPINO COSTS~ CUM MUD $7540, CUM WELL $5~7371 REMARKS' 6 HR TEST' BOPD 204; BWPD 188; QRAVITY 31. 9~ MCFD 24; OUR t17; BPOPD 808 AT 3650 PSI; SPM 68 CHRON TIME DISTRIBUTION ~4.00 - OTHER, PUMPINg - TESTINg *** 12/07/86 *** SOUTH MIDDLE gROUND SHOAL #3, S. MID gROUND SHOAL, PARW. ER 4B, AMOCO PRODUCTION, FLAC 986133-0~-3, API 50733~00~30O, AUTH COST $396000~ AMOCO W.I. 62. 5000 OPERATIONS~ TD 10500FT~ PUMPINO - COSTS: CUM MUD $7540, CUM WELL $527371 REMARKS: 6 HR TEST~ BOPD ~15; 'BWPD 16~; gRAVITY 30. 3; MCFD ~3. 6; OOR llO;-BPOPD 800 AT 3750 PSI; SPM-72 ' CHRON ~IME DISTRIBUTION 24. O0~ - OTHER, PUMPINg - TESTINg' _ DENVER REGION *** ANCHORAGE ,, DISTRICT *** 01/06/87 **~ PAgE i7 SOUTH MIDDLE gROUND SHOAl_ ~3, S. MID gROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, FLAC '?86133-02-3, AP1 507332002300, AUTH COST $396000, AMOCO W.I. 62. 5000 OPERATIONS: TD 10500 FT, PUMPINg COSTS: CUM MUD $7540~ CUM WELL $527371 REMARKS: 6 HR TEST: BOPD i93~ BWPD 183~ gRAVITY 31. 4~ MCF'D 23. 2_~ (;OR 120; BPOPD 782 AT 3750 PSI; SPM 76 CHRON TIME DISTRIBUTION (HRS): 224.00 - OTHER, PUMPINg - TESTINg SOUTH MIDDLE gROUND SHOAL ~3, S. MID gROUND SHOAL., PARKER 4B, AMOCO PRODUCTION, *******~ ~*****~. ~*** **~. ~.~. ~ ~.~. ~.~. ~..~* ~** ***~ .~..~. **~. ~..~ **~ ~. FL_AC D~6133-0~-3, ~I 507332002300, AUTH COST AMOCO W.I. 62. 5000 OPERATIONS: TD 10500 FT, PUMPINg COSTS: CUM MUD $7540, CUM WELL $527371 REMARKS: 6 HR TEST: BOPD 180; BWPD 17~; MCFD 24~ QOR 133; BPOPD 804 ~T ~600 PSI; SPM 76. ENQINE EFF 87~, PUMP EFF 51% CHRON TIME DISTRIBUTION (HRS)' ~4.00 - OTHER, PUMPIN~ - TESTINg 4 1987 *** 12/10/86 *** Ale.:,,,,.,. Oil & SOUTH MIDDLE O-ROUND SHOAL #3, S. MID ~.ROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, FLAC ~86133-02-3~ APl 507332002300~ AUTH COST $3~6000~ AMOCO W.I. 62. 5000 OPERATIONS~ TD 10500 FT~ PUMPIN~ COSTS~ CUM MUD $7540~ CUM WELL $527371 REMARKS~ 6 HR TEST~ ~OPD 13~ ~WPD 1~2~ MCFD 31.7~ ~OR 240; ~POPD 812 AT 3700 PSI~ SPM 76. CHRON TIME DISTRIBUTION (HRS)~ ~4.00 - OTHER~ PUMPINg - TESTINg 1/86 *** SOUTH MIDDLE gROUND SHOAL #3, S.--MID gROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, _ ' ..FLAC 986133-02-3, API 5073320-02300, _AUTH COST $396000, -AMOCO W.I. 62. 5000 - - OPERATIONS: TD 10500 FT, PUMPINg - '- COSTSi CUM MUD $7540, CUM WELL $527371 DENVER REG-ION *** ANCHORAGE CHRON TIME DISTRIBUTION (HRS): 24° O0 - OTHER, PUMPING - NO QUAGE DISTRICT -~*~ 01,;06/87 ~*~ PAGE 18 SOUTH MIDDLE GROUND SHOAL #3, S. MID GROUND SHOAl_., PARKER 4B, AMOCO PRODUCTION, FLhtC 986133-02-3, API 507332002300, AUTH COST $396000, AMOCO W.I. 62. 5000 OPER/4Ti£)NSi TD 10500 FT, PUMPIN~ COSTSi CUM MUD $7540~ CUM WELL $57Z7371 REMARKS~ 6 HR TEST: BOPD 156; BWPD 144; MCFD 29; GOR 186; I~POPD 788 AT 3750 PSI~ SPM 6F~; GRAVITY 30.7 CHRON TiME DISTRIBUTION (HRS): 24~00 - OTHER, PUMPING - TESTING 12/i3/86 *** SOUTH MIDDLE GROUND SHOAL $~3, S. MID GROUND SHOAL., PARKER 4B, AMOCO PRODUCTION, FLAC 986133-02-3, API 507332002300, AUTH COST $3c~6000, AMOCO W.I. 62. 5000 OPERATIONS: TD 10500 FT, PUMPING COSTS: CUM MUD $7540, CUM WELL $527371 CHRON' TIME DISTRIBUTION (HRS>: 24.00 -OTHER, PUMPING- NO GUAQE **~ 121 14/86 *** SOUTH MIDDLE GROUND SHOAL ¢3, S. MID OROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, ************-************************************************************************** FLAC 986133-0~-3, API 50733~002300, AUTH COST $396000, AMOCO W.I. 62. 5000 OPERATIONS.' TD 10500 FT, PUMPINO COSTS: CUM MUD $7540, CUM WELL $527371 REMARKS: 6 HR TEST: BOPD I00; BWPD 156; MCFD ~9. 6; GOR 296; BPOPD 664 AT 3750 PSI; GRAVITY 31.7 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, PUMPING - TESTING ~** 12/15/86 *** SOUTH MIDDLE GROUND SHOAL #3, S. MID GROUND SHOAL, PARKER 4B, ~OCO PRODUCTION~ -FLAC 9861.33-02-3, API 507332002300, AUTH- COST $396000, '" ~'AMOCO W. I:. 6P. 5000 - - O~ERATION8:' TO~ 10500 FT, POMPINO ~' DENVER REGION *** ANCHORAGE DISTRICT *** 01/06/87 ~*~ PAO. E REMARKS: 6 HR TEST' BOPD 80; BWPD 164; MCFD 30; QOR 375; BPOPD 667 AT 3750 PSI; gRAVITY 31. 1; SPM 51 CHRON TIME DISTRIBUTION (HRS)'. 24o00 - OTHER, PUMPINg - TESTINg 19 ~** 12116/86 **~ SOUTH MIDDLE (~ROUND SHOAL ~3, S. MiD gROUND SHOAl_, PARKER 4B, AMOCO PRODUCTION, FLAC 986133-0~-3, ARI 50733~00~300~ ~UTH COST $396000, AMI]CO W.I. 6~. ~000 OPERATIONS~ TD i0500 FT, PUMPINg COSTS~ CUM MUD $7540, CUM WELL $527371 REMARKS~ 6 HR TEST~ BOPD 88; BWPD 140; MCFD 30; QOR 340; BPOPD 612 AT 3750 PSI; ~RAVITY 30. 7; SPM 51 CHRON TiME DISTRIBUTION (HRS); 24. O0 - OTHER PUMPINg - T=~,TINQ SOUTH MIDDLE gROUND SHOAL ~3, S. MID ~ROUND SHOAL, PAR~ER 4~, AMOCO PRODUCTION~ ************ ~******* ~****~************~***~******.*******~*~***~***~* ~..~***~***** FLAC 986133-02-3~ API 507332002300~ AUTH COST $396000, AMOCO W.I. 62. 5000 OPERATi-' o. bN,~. TD 10500 FT, PUMPINg COSTS' CUM MUD $7540, CUM WELL $527371 REMARKS' 6 HR TEST: BOPD 96; BWPD 132; MCFD 29. 6; (~OR 308; BPOPD 596 AT 3850 PSI; gRAVITY 30. 8; SPM 49 CHRON TIME DiSTRII~UTION (HRS)~ ~4.= ~,,_,"-"-' - OTHER, PUMPINg - TESTIN~ *** 12/18/86 *** SOUTH MIDDLE gROUND SHOAL #3, S. MID gROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, **~***************~.~.~***** ~.~*****~.~********* ~*************~***~*********~** FLAC ~86133-02-3~ AP1 50733200~300~ AUTH COST $396000~ AMOCO W.I. 62. 5000 OPERATIONS: TD 10500 FT, PUMPINg COSTS: CUM MUD $7540, CUM WELL $5P7371 REMARKS: 6 HR TEST: BOPD 100; BWPD 148; MCFD 29.2; ~OR 292; BPOPD 560 AT 3850 PSI; gRAVITY 31.~_; SPM 49 CHRON TIME DISTRIBUTION (HRS): 24. O0 - OTHER, PUMPIN~ - TEST lNg _ *** lP/19/86 ***~ SOUTH MIDDLE OROUND sHOAL-#3° S. MID gROUND SHOAL, PARKER 4B, AMOCO-PRODUCTION, DENVER REg-ION *** ANCHORAGE DISTRICT *** 01/06/87 *** PAGE 2O FLAC 986133-02-3, AP1 507382002300, AUTH COST $396000, AMOCO W.I. 62. 5000 OPERATIONS: TD 10500 FT, PUMPING COSTS: CUM MUD $7540, CUM WELL $527371 REMARKS: 6 HR TEST: BOPD 76; BWPD 176; MCFD 28. 2; gOR 371J BPOPD 696 AT 3800 PSI; gRAVITY 30.4~ SPM 56 CHRON T!ME DISTRIBUTION (HRS): 24. 00 - OTHER, PUMPINg - TESTINg 20/86 *** SOUTH MIDDLE gROUND SHOAL ~.3, S. MID gROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, **-~***** ~-~************~*******.4.******~***~***************~* .******~***** ~***~*** FLAC 986133-02-3, API 507332002300, AUTH COST $396000, AMOCO W.I. 62. 5000 OPERATIONS: TD 10500 FT, PUMPING COSTS: CUM MUD $7540, CUM WELL $527371 REMARKS: 6 HR TEST: BOPD 961 BWPD i64~ MCFD 28. 2~ QOR 294; BPOPD 648 AT 3850 PSI; gRAVITY 29.7; SPM 54 CHRON TiME DISTRIBUTION (HRS)' .=4.00 - OTHER, PUMPIN~ - TESTINg 12/21/86 ~** SOUTH MIDDLE ~ROUND SHOAL ~3, S. MID ~ROUND SHOAL~ PAR~ER ~-I~, AMOCO PRODUCTION, **** ~*** .~** **** **** ~.~**..-~. -~**~ **** **~***~.. **~. ~.~*****. ~.. ~ ~.~. ~.~. ~..** ~*** .~**... F'LAC 9861S3-0~-3, APl 5073B~OOP300, AUTH COST $396000, AMOCO W.I. 62. 5000 OPERATIONS' TD 10500 FT, PUMPINg COSTS' CUM MUD $7540, CUM WELL $527371 REMARKS: 6 HR TEST- BOPD 96; BWPD 160~ MCFD 28. 8~ GOR 300; BPOPD 724 AT 3850 PSI~ GRAVITY 28. 6; SPM 58 CHRON TIME DISTRIBUTION (HRS)' ~--4. O0 - OTHER, PUMPING - TESTING *** 12122/86 *** SOUTH MIDDLE gROUND SHOAL ~3, S. MID gROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, **..~. ****. *** **~. ~.~. ~ *** **** ~.~..**~. ~.~. ~.~. ~..~* ~.~. ~.*** **** ***..** .~. ~..~. **~. ~ ~. FLAC 986133-02-3, API 507332002300, AUTH COST $396000, AMOCO W.I. 62. 5000 OPERATIONS' TD 10500 FT, PUMPING COSTS: CUM MUD $7540, CUM WELL _$527371 REMARKS' 6 HR TEST: BOPD 76; BWPD 264~ MCFD 28. 2; GOR 374~ BPOPD' _ _ 696 AT 3800 PSI; GRAVITY-30. 4~ SPM 56 CHRON TIME DISTRIBUTION (HRS)' _ - 24. O0 - OTHER, PUMPINg - TESTINg ._ _ ECEiVE. D DENVER REGION ~*~ ANCHORAGE DISTRICT ~** 01/06/87 *~* PAGE SOUTH MIDDLE GROUND SHOAL ~3, S. MID GROUND SHOAL, PARKER 4B, AMOCO PRODUCTION, *********************.*********~'~*** ~*********~****************************** .*** FLAC 986133-02-3, APi 507332002300, AUTH COST $396000, AMOCO W.I. 62° 5000 OPERATIONS; TD 10500 FT, PUMPiNg CO~,o: CUM MUD $7540, CUM WELL $527371 CHRON TIME DISTRIBUTION (HRS)- ;-2_.4. OO -OTHER, PUNPING- NO L4UA,,:,.E ~ECEIVED · .,,'c~v 1 4 1987 Oil & [~ Con~. Coan~issiorl DENVER RE~iON *** ANCHORAGE DISTRICT *** 01/06/87 *** PAgE 22 *****~********************~***~************************* .***~**~***************~ **~ END-OF-dOB SUMMARY' ~.~m-.***.. **** **** **** .***~ **~...*** **** **~. **.** **~. ~.~* **** ~**~ **~* **** ~*.*~ ~*** *~** ~*~ F!NALLED dOB INFORMATION' S. MID ¢¢ROUND SHOAL, SOUTH MIDDLE gROUND SHOAL, ~3, KENAI O/S STATE, ALASKA OPERATOR' AMOCO PRODUCTION TOTAL DEPTH 10500 FT, PLUg BACK TOTAL DEPTH 10392 FT CUMULATIVE dOB COST $527'37t, CUMULATIVE MUD COST $7540 OPERATIONS COMPLETED DATE II/20/86 USELESS FOOTAGE 0 FT *** HORIZON DESCRIPTION' HORIZON ZONE SUB 2 HORIZON RENAl, LW CON(~ STRAT MNEMONIC 41KENIL, ORigINAL COMPLETION DATE 09/11/78, HORIZON CLASS DEVELOPMENT, TOP OF PAY 9435 FT END OF REPORT g£££1V£D W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 October 23, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive , Anchorage, Alaska 99501 File: FEW-262-WF Dear Sir: Notice of Intent SMGS 18746 Well No. 3 Platform Dillon, Cook Inlet, Alaska Attached in duplicate for your approval is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, for repairs to be made to Well No. 3. This well was shut-in on October 17, 1986, when a new pump failed. Prior to the pump failure, the well started producing coal, indicating a poten- tial casing problem. The proposed workover will investigate the casing integrity and repair by setting a seven-inch liner from PBTD to above the bad casing. The well will then be perforated and returned to production. We plan to begin this work on October 27, 1986, A BOP sketch, and present wellbore diagrams are attached. Sufficient notice will be given so that a representative from your office may witness the BOP testing. Any questions concerning this project may be directed to Kurt Unger in our Anchorage office. Very truly yours, W. G. Smith District Manager Attachments KWU/dds STATE OF ALASKA ~ ALASI',,, . OIL AND GAS CONSERVATION COMb,. ~$1ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing~ Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other 2. Name of Operator Amoco Production Comp~13y 3. Address P.O. Box 100779, Anchorage, Alaska 99510 4. Location of well at surface Leg 4, Slot 4, SMGS Plat. Dillon 1765' FWL, 678' FSL, Sec. 35, T8N, R13W, S.M. At top of productive interval 9435' ND 768' FWL, 573' FNL, Sec 2, TTN, R1,3W, S.M. At effective depth 10392' MD 661' FWL, 633 ~NL Sec 2, T7N, R13W, S.M. At total depth 10500' MD, 653' FWL, 636 FNL Sec 2, T7N, R13W, S.M. 11. Present well condition summary Total depth: measured true vertical 10,500 feet Plugs (measured) 10,323 feet Effective depth: measured 10,392 feet Junk (measured) true vertical 10,215 feet 5. Datum elevation (DF or KB) 110 KB, MSL 6. Unit or Property name SMGS Unit 7. Well number 3 8. Permit number 67-28 9. APl n~r~§e_~o023 50-- 10. Pool SMGS Hemlock feet Casing Length Size Cemented Structural Conductor 600 20 1285 SX Surface 2006 13 3/8" 1200 SX Intermediate Production 10439 9 5/8" 1250 SX Liner Perforation depth: measured true vertical Measured depth 600 2006 10439 (See Attached List of Perforations) True Vertical depth 60O 1985 10262 Tubing (size, grade and measured depth) 3~:~':-9;12'lb~.N-80 BTC - 9408' MD Packers and SSSV (type and meas~"red~aKerdeD.th),FIOQel. "D" Packer 9391' MD ktask,~ 0il & O3s Cons. Comm[ss[c,~ 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation October 27, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certif%tha~fore.~g~ng is tru~nd correct to the best of my knowledge Signed ~v.,,~../.,~...~i¢'~'~--" Title Commission Use Only Conditions of aPproval [] Plug integrity [] BOP Test Approved by ~,~__' "-~/". L Form 10-403 Rev 12-1-85 ~f / / Notify commission so representative may witness [] Location clearance Commissioner Date 1 I1/o-~/or- the commission Dat;u~mit .~ triplicate 11. Perforation Depth: Measured Depth 9435 - 9460 9503 - 9513 9530 - 9575 9650 - 9670 9695 - 9740 9770 - 9850 9875 - 9885 9905 - 9915 9930 - 9940 True Vertical Depth 9265 - 9289 9332 - 9342 9360 - 9405 9479 - 9499 9524 - 9568 9598 - 9677 9702 - 9712 9732 - 9742 9757 - 9767 12. Description Summary of Proposal 1. Determine wellhead pressure, mix kill fluid, and kill well. 2. Set back-pressure valves, nipple down tree, nipple up BOP's and test to 2,500 psi. Pull back-pressure valves. 3. Pull tubing. 4. Investigate casing integrity to determine location of leak. Mill out packer at 9,391' and clean out to PBTD. Run 7" liner from PBTD to cover casing damage. Cement liner. 0 6. 7. 8. 9. 10. Clean out wellbore. Run new BHA and tubing. Perforate .pay zones. Return well to production. SUBJECT b Amoco ProdUction Compar~ ENGINEERING CHART Sheet No. File Of Appn ~B~a. 011 E GP.s Cons. Mc,'g,o~'age Amoco Production Company ENGINEERING CHART -4 ....[ .... ~. ' ~ [---~ ..... . ApPN ~1 LXN5 I~ ' t~h, r4 'TX f'E ?:,~P · [ I I i ~.. 1~- c ItOV. E I~n~l ro t~ {.z" L. A. Darsow District Superintendent Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 January 20, 1984 File' WEN-O57-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 995.01 Dear Si r' Subsequent Notice SMGS Unit Well No. 3 Platform Dillon, Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, subsequent to changing the artificial lift system from electric submersible to hydraulic and reperforating the pay in Well No. 3. The well is currently producing 308 BOPD, 1,890 BWPD, a'nd 87.4 MCFD of gas. Very truly yours, W. E. Nielsen Superv i sor-i n-Charge Attachments MTS/seh "", STATE OF ALASKA ~-"- ALASKA ~)IL AND GAS CONSERVATION C~JMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Amoco Production Company 3. Address ,.P. 0. Box 100779, Anchoraqe, Alaska 99510 4. Location of Well Surface Location: Leg 4, Slot 4, SMGS Platform Dillon Subsurface Location: 660' FWL, 634' FNL, Section 2, T7N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) _ ~n, ~R MSL 12. 6. Lease Designation and Serial No. ADL .18746 7. Permit No. 67-28 8, APl Number s0- 733-20023 9, Unit or Lease Name SMGS Unit 10. Well Number 3 11. Field and Pool South Middle Ground Shoal Hemlock 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 I~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco Production Company performed the following work' . . . Determined wellhead pressure, mixed emulsified brine-in-diesel kill fluid, and killed well. Set back-pressure valves, nippled down tree, nippled up BOP's, and tested to 2,500 psi. Pulled back-pressure valves. Pulled tubing and electric submersible pump. Ran seal assembly, bottomhole assembly, and tubing. Utilized packer previously set at 9,391 feet during workover performed in April 1982. Mule shoe set at 9,408 feet and bottomhole assembly set at 9,365 feet. Reperforated_pay zones. ,~/i~-~ .~ Returned the well to production. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signe~ ~_~'"'~J~____----~~ Title Supervisor-in-Charge The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 December 1, 1983 ~File- LAD-1114-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Notice of Intent SMGS Unit Well No. 3 Platform Dillon, Cook Inlet, Alaska Attached in triplicate for your approval is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, to notify you or our intent to change the artificial lift system from electric submersible to hydraulic and to reperforate the pay. During the installation of the ESP (electric submersible pump) in May 1983, formation damage caused by using filtered Cook Inlet water as a kill fluid resulted in lower than anticipated production rates. Replacing the ESP with a hydraulic pump will allow reperforation of the pay which is expected to increase the productivity of the well. The replacement will also increase the AC power availability on Platform Dillon which will be utilized to expand the waterflood system. If possible an emulsified brine-in-diesel kill fluid Will be used to minimize formation damage during the workover. We plan on completing this work before the end of this year. Any questions concerning this project can be directed to Mike Schwein in our Anchorage office. Very truly yours, L. A. Darsow Di stri ct Superintendent Attachments MTS/seh STATE OF ALASKA ~ ALASKA C._ AND GAS CONSERVATION CO:..,vllSSlON SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL ~ . 1, 2. Name of Operator . . 7. Permit No. Amoco Production Company .. 67-2.8 3. Address 8. APl Number P. O. Box 100779, Anchorage, Alaska 99510 so- 733-20023 OTHER [] 4, Location of Well . Surface Loc~'tion' Leg 4, 'Slot 4, SMGS-Platform Dillon Subsurface Location-.'660' FWL, '634' FN[, Section 2, I7N, R13W, :S.M~ --'- ~ · - : 9. Unit or Lease Name .. SMGS Unit 10. Well Number 1 1. Field and Pool South Middle Ground Shoal , , 5. Elevation in feet (indicate KB, DF, etc.). '- ] 6. Lease Designation'and Serial No. Hem] 0ck 110' KB~MSE · - ' . I"" ADL 18746 '- '.''- 12.~ -. ' Check Appropriate BoX To Indicate Nature of-Notice, Report, or Other Data ' SUBSEQUENT REPORT OF: · · - · NOTICE OF INTENTION TO':. -- - . . . .... ' (Submit in Triplicate) ' ._ -. . Perf0~ate - - '- . '[~q Alter Casing [-1 ' - - .Perforations Stimula;;. I~l '- Abandon -El ' '~ ' 'stimulation " · Repair Well '1~ - change Plans' _[~].' - :. -- 'Re~airs Made Pull Tubing" I~q' - Other . '.:' ~ '' '.Pulling Tubing -: (Note: R;port multiple completions on Form 10-40') with a ;ubmitted Form 10-407 for each'completiOn.). (submit in Duplicate) E] Altering .Casing [] Abani:10nment Other ' . O. 13. Describe Proposed or Completed Operations (Clearly state all pertinent' .details' and give pertinent dates, including estimated date of starting any proPosed 'work, for Abandonment see 20 AAC 25.105.-170). ': "'- . . Amoco Production' company plans to: ' ...--.- ' . . 1. Determine wellhead 3ressUre., mix..iki:li f]uid,"and .kill well. 2 Set back-pressure valVes,' ni'pplb doWn tree,' nipple up BOP's, and· test 'to'2,500 psi- Pull back-pressure valves' . 3. Pull tubing.and elec-t;ric-.submersible pumP. -. . 4. Mill out packer set'-a.t.9,391'. ' 5. Cl-e.an out' the wellbore'. .... · '- 6. Set packer and-run sea-1.; assembly, bottomhOle assembly, ·and' tub·lng.. 7. Reperforate pay zones; .. · 8. Return the well-to..produCtion. ' · ~. .. · - · · · . . 14~ I hereby certify ~hat t~.f,oregoing is true and correct to the beSt'of my knowledge. The space b~low for Commission Jitions of Approval, if any: Approved' Copy Returned -. ...... .... ... . : the Commission ' .Dale / '.~ ~ ' ' Form 10-403 Rev. 7-I -80 Submit "ln.ten'tions" m Tr,phcate and "Su'bsecluen; Reports" in Duplicate L. A. Darsow District Superintendent Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 June 24, 1983 Fi 1 e' LAD-661-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subsequent Notice SMGS Unit Well No. 3 Platform Dillon, Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, subsequent to the repair work done on SMGS Unit Well No. 3. The pumping system was changed from hydraulic to electric submersible. The operational aspect of running the electric submersible pump has been a success. However, the filtered Cook Inlet water which was used as a kill fluid apparently damaged the permeability of the formation. The formation appears to be cleaning up and total fluid production from the formation has risen from 976 BFPD to 1,268 BFPD. The well is currently producing 187 BOPD, 1,081BWPD, and 114 MCFD of gas. It is anticipated that after the formation cleans up the well will produce approximately 450 BOPD, 2,200 BWPD, and 150 MCFD of gas. Yours very truly, L. A. Darsow Di stri ct Superintendent Attachment MTS/seh RECEIVED JUN 2 8 ifJ~S Alaska oil & Gas Cons. Commission Anchorage "-" STATE OF ALASKA ALASKA dlL AND GAS CONSERVATION C,.,.vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Amoco Production Company 3. Address P, 0. Box 100779, Anchorage, AK 99510 4 Location of Well Surface Location: Leg 4, Slot 4, SMGS Platform Dillon Subsurface Location: 660' FWL, 634' FNL, Section 2, T7N, R13W, S.M. 7. Permit No. 67-28 8. APl Number 50- 733-20023 9. Unit or Lease Name SMGS Unit 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 110' KB, MSL I ADL 18746 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' 10. Well Number 3 11. Field and Pool 5outh Middle Ground Sh0al Hemlock (Submit in Triplicate) Perforate [] 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.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] 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 Production Company performed the following work- 1. Determined wellhead pressure, mixed brine, and killed well. e Set back-pressure valves, nippled down tree, nippled up BOP's, and tested to 2,500 psi. Pulled back-pressure valves. 3. Pulled tubing and bottomhole assembly. Ran in electric submersible pump and tubing. Packer previously set at 9,391' during May 1982 workover left in hole. Bottom of electric submersible pump apparatus set above packer at 9,353'. Se Returned well to production. REEEIVE jUN 2 8 ',983 AlasF, a Oil & Gas Cons. Commission Anr, hor2ge 14. I hereby certify that the~foreigoing is true and correct to the best of my knOwledge. Signed .... f ~~7~..~~ Title Di strict Superintendent The space below for Commission use Date Conditions of Approval, if any: Approved by_ By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent April 14, 1983 Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907-272-8471 File: LAD-409-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Si r' Notice of Intent SMGS Unit Well No. 3 Platform Dillon, Cook Inlet, Alaska Attached in triplicate for your approval is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, to notify you of our intent to change the artificial lift system from hydraulic to electric submersible. This will lower the pump intake pressure and increase production. Any questions concerning the work can be directed to Mike Schwein in our Anchorage office. Yours very truly, L. A. Darsow District Superintendent Attachment MTS/seh C£ V£D APR l a 1983 "-" STATE OF ALASKA '-" ALASKA O,L AND GAS CONSERVATION CO,,,,vtlSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator Amoco Production Compan.v 3. Address P. 0. Box 100779, Anchorage, Alaska 99510 4. Location of Well Leg 4, Slot 4, SMGS Platform Dillon 660' FWL, 634' FSL, Section 2, T7N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) I10' KB, MSL I 6 . Lease Designation and Serial No. ADL 18746 OTHER 7. Permit No. 67-28 8. APl Number s0- 733-.20023 9. Unit or Lease Name SMGS Unit 10. Well Number 3 11. Field and Pool South Middle Ground Shoal Hemlock 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing J~ Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] 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 Production Company plans to' 1. Determine wellhead pressure, mix brine, and kill well. 2. Set back-pressure valves, nipple down tree, nipple up BOP's, and test to 2500 psi. Pull back-pressure valves. 3. Pull tubing and bottomhole assembly. 4. Run in an electric submersible pump and tubing. 5. Return the well to production. RECEIVED 14. I hereby certify that the for.egoing is true and correct to the best of my knowledge. Signed ~. ' Title District Superintendent The space below for Commission use Dale Conditions of Approval, if any: Approved by ORIGINAl. SIGNED BY LONNIE C. SMITIi Approved Copy Returned COMMISSIONER the Commlss,on Dat,~ .. Form 10-403 Rev. 7-1-80 Suhm~,, "lnlent~ons" m Triplicate and "Subsequent Reports" ~n Duplicate L. A. Darsow District Superintendent May 13, 1982 Amoco Production Company Post Office Box 779 Anchorage. Alaska 99510 907 - 272-8471 File' LAD-510-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subsequent Report SMGS Unit Well No. 3 Platform Dillon, Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-403, Sundry Notices and Reports on Wells, subsequent to the work on SMGS Uhit Well No. 3. Yours very truly, L. A. Darsow Di stri ct Superintendent Attachment LMP/klt RECEIVED MAY 1 8 1982 Alaska 0il & Gas Cons. Commission Anchorage :~' STATE OF ALASKA ~ ALASKA ~,L AND GAS CONSERVATION CO,~,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Amoco Production Compan~v 67-28 3. Address 8. APl Number P. 0. Box 779, Anchorage, Alaska 99510 50- 133-20023 9. Unit or Lease Name SMGS Unit OTHER [] 4. Location of Well Leg 4, Slot 4, SMGS Platform Dillon 660' FWL, 634' FSL, Section 2, T7N, R13W, S.M. 5. Elevation in feet (indicate-KB, DF, etc.) IlO' KB, MSL I 6 . Lease Designation and Serial No. ADL 18746 12. 10. Well Number 3 11. Field and Pool South Middle Ground Shoal Heml cc k Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing ~] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent' details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco performed the following work on the subject well- · 2. 3. 4. 5. Pulled tubing and Kobe bottomhole assembly and milled out packer. Ran electric submersible pump. Pump failed after three days. Pulled tubing and pump. Ran packer, tubing, and Kobe bottomhole assembly and returned well to production on hydraulic lift. RECEIVED Alaska 0il & Gas Cons. C0mrniss/0n Anchorage 14. I hereby certify t~ is true and correct to the best of my knowledge. Signed ,~,~ ~ ~ Title District Superintendent The space below for Commission use Date 5/13/82 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 'Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent March 19, 1982 Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 File' LAD-202-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Notice of Intent SMGS Unit Well No. 3 Platform Dillon, Cook Inlet, Alaska Attached in triplicate for your approval is State of Alaska Form 10-403, Sundry Notices and Reports on Wells, regarding our plans to install an electric submersible pump in SMGS Unit Well No. 3, replacing the current hydraulic pumping system. This work will entail pulling the existing tubing .and bottomhole assembly, milling out the existing packer, and runnin~g the electric submersible pump. The estimated starting date for this work is April 1982. Yours very truly, L. A. Darsow District Superintendent Attachment RLW/klt RECEIVED MAR 2 21982 0il & Gas Cons. Commissio~ Anchorage STATE OF ALASKA ..-'x ALASKA OIL AND GAS CONSERVATION CC,,,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Amoco Production Company 67-28 3. Address 8. APl Number P. O. Box 779, Anchorage, Alaska 99510 50- 133-20023 4. Location of Well Leg 4, Slot 4, SMGS Platform Dillon 660' FWL, 634' FSL, Section 2, T7N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) llO' KB, MSL I 6 . Lease Designation and Serial No. ADL 18746 12. 9. Unit or Lease Name SMGS Unit 10. Well Number 3 11. Field and Pool South Middle Ground Shoal Hem1 cc k Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other J~ Pulling Tubing [] (Note: Report multiple completions on Form 10~407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco Production Company plans to: 1. Pull tubing and mill out packer. 2. Run in an electric submersible pump. 3. Return the well to production. On Form No. ~ Date~ RECEIVED MAR AlasKa 0il & Gas Cons. Commission Anchorage 14: I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of Approval, if any: Approved by Title District Superintendent COMMISSIONER ! ,approved "opy Returned By Order of the Commission Date 3/19/82 Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form No. 1:'----4 : R~V. 9°30-67 / / .' STATE OF ALASKA SgBMnr IN OEPLZCA~ O~L AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. WELL WELL OTHER 2. N;2~[E OF OPERJ~TOR Pan American Petroleum Corporation 3. ADDRESS OF OPERATOR Box 779~ Anchorage, Alaska 99501 4. LOCATION OF WELL Leg 4 Slot 4 SMGS Platform D 678' FSL, 1765' FWL, Sec 35, T8N, R 13 W, S.M. ~. API NUAiERICAL CODE 50-133-20023 LEASE DESIGNATION A%'D S~IAL NO. ADL- 18746 7. IF INDIAN, ALOI 1~.,% OR TRIBE NASIE 8. I/NIT,FAi~M OR LEASE NAAIE SMGS Unit 9. WELL 3 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal-EFG Pool 11. SEC., T., R., M.. (BOTTOM HOLE OBJECTIVE) Sec. 2, TTN, R13W, S.M. 12. PER_MIT NO. 67-28 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SI~E, CASING AND CE1VIENTING JOBS INCLUDING DEPTH SET AND VOLLrMES USED, PERFORATIONS, TESTS ANT) P~ESULTS, FISHING JOBS, JLrNK IN HOLE A~ND SIDE-TRACKED HOLE ANT) A_NY OTHER SIGNIFICANT CH-A~GF-~ IN HOI~ ~ON'DITIONS. Operations commenced 12:00 Midnight, 7/22/70. Retrieved Kobe pump. Displaced with oil base mud. Nippled up and tested BOP. Rigged up Dialog, and cut off short tubing string. Pulled tubing and Iipbe bottom hole assembly. Tripped in with packer retrieving tool on drill pipe, and milled out perm- anent packer at 9284'. Tripped in with bit and casing scraper and circulated wellbore clean to 10349 '. Rigged up Schlumberger and perforated the following intervals with 2 shots per foot, using 4-in casing carrier guns: 9435 ~ 9460 9503 - 9513 9530- 9575 9650- 967O 9695- 9740 977O- 985O Set Guiberson Type A drillable permanent packer at 9275' on Schlumberger wire line. Re-ran Kobe tandem bottom hole assembly a_nd tubing. Rigged down BOP and installed and tested wellhead. Displaced mud with power oil. Ran standing value and new Kobe pump. Rig released 6:00 PM, 7/28/70, and well returned to pumping oil well status. FINAL REPORT. OF OiL AND GAS DI¥1SIO~'1NCHORAG~ 14. I hereby ~~rrect S~GN~D~/~~~ ' ~ ' ' =TL~ Area Superintendent hA',-,'. August 3, 1970 NO E--R this form is u red for each calendar month, regardless of the status of operations, and must be file{~ in duplicat~ with the Division of Mines & Minerals by the 15th of the succeeding menth, unless othe~ise directed. Form l~v-. 9-30-6~ Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate API N~CAL CODE ~K~ 50..133-20023 KW ........ ... ~ STATE O'F ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS fOG not use this form for proposals to dril! or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PER/VIIT~" for such proposals.) . 6. LF, ASE DESIGNATION AND ADL-18746 UNIT FAR/VI OR ~SE NA/VIE 9.. NAIViE OF OPERATOR S. S 1VfGS Unit Pan American Petroleum Corporation 3~ADDRESS OF OPERATOR 9.WELL NO. Box 779, Anchorage, Alaska 99501 3 4. LOCATION O,F WELL At surface Leg 4 Slot 4, SMGS Platform D 678' FSL, 1765' FWL, Sec. 35, T8N, R13W, S.M. ?. IF INDIA-N, ALLOTTEE OR TtLIB]~ "J- FILE 10. FIELD AaN-D POOL, OR WILDCAT B. Middle Ground Shoal-EFG Pool 11. SEC., T., R,, M., (BOTTOM HOLE OBJECTIVE) Sec. 2, T7N, Ri3W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc. 12. PEPu%/IIT NO. 6 7-Z 8 RKB 100' above MSL 24. Check Appropriate Box To I~ncli'cate Nlature of Nloti'ce, Re ~ort, or Other 'D~lta NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~--~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE 6UBEEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING ABANDONMENT' s.ooTOR AC,DIZE k[[Ov~e ABANDON' I~x'l I SHOOTING OR ACIDIzING REPAIR WELL CHANGE PLANS (Other) (Other) Wot r (NOTE: Report results of multiple completion on Well CompletiOn or Recompletion Report and Log form,) 15. DESCRIBE I'ROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an~' proposed work. PropoSe to pull tubing, mill out permanent packer, circulate wellbore clean with oil base mud, and perforate the following intervals with 2 shots per foot with casing carrier guns: 9435-9460 95~03-9513 95~0' 9575 9650-9670 · 9695-9740 9770-9850 Will re-install permanent packer and Kobe pumping equipment. Anticipate work will begin about July Z0, 1970. RE:C[!VFO JUL 1970 DIVISION OF OIL AND GAS ANCHORAGE 16. I hereby eertffy~.ha~ :-th~ fore~oin~ is true and correct Are a Superintendent July 7, 1970 (This space for State o~ice use) CONDITIONS OF APPROVAL, IF ANY: TITLE · DATE TITLE DATE ," ' See 1,nstrucfions On Reverse Side Approved Copy Returned __/7./?'/7 Form ~ ; SUBMIT IN DUPLIC.' · ~,rATE OF ALASKA ', See~rher in- structions on i OIL AND GAS CONSERVATION COMMITTEE reverse side) WELL cOMPLETION. OR. RECOMPLETION REPORT AND LOG* tR. TYPE OF WELL: OZL'" ~] WELL wELL ~ --DAY ~ Other b. TYPE OF COMPLE~ON: N,W ~ w onK~ DEEP- ~PLUG ~ DIFF. ~ Other OVER ~EN BACK RESVR. ._ WELL i. NAME OF OPERATOR Pan American Petroleum Corporation 3. ADDRESS OF OPERAT(~R ~.- /. r P._..O. BOx ~779 - Anchorage, :Alaska 99501 ~. LOCATION OF WELL ('Report)~locatiGn clearlg~and- in a~cordance with any State requirements)* At surface · At top prod. interval reported below tt total depth · APl NI~IF-~ICAL CODE 50-133-20023 ADL - 18746 ~ IF nVOIAN, ALLOTTEE OR TRZB~ a.-U~IT,FA3R,~I OR LEASE NAME SMGS Unit 9. WELL NO. 3 10. FIE~D AaND I~OOL; OR WILDCAT SOuth Middle Ground Shoal ~L;s~c., T., R., M., (BOTTOM HOLE OBJF, C'ITVE ) Sec. 2, T7N, R13W, S.M. 12." ~ER1V~T N'O. 67-28 : : ,, .' ~ ~6-2.8-68 18. TOTAL DE~H, 1VLD & TVD[19. PLUd, IP~CK MD ~ ~, ~ ~LE CO~L. I '21. *INTERVALS ~DRILLED BY .[' . _.~- '-,7 [ ~W~Y* ] ROTARX TOOLS ~ CABLE T00LS ~. PRODUCING ~v~(S), OF ~S ~M~TI~P,' ~M, H~E (~ A~ ~)* ~. W~ DIR~ON~ SURV~ ~DE 24. TYPE ELECTRIC AND OTHER-LOGS-RUN ~ CASING RECORD (Repoi*t all strings set in w~ll) CA, SaNG SIZE LB/FT. DEPTH SET. (MI)) HOLE SIZE 2~. LINER RECO~D S,I.~,I~ ,' ' TOP CiVLD) BO'I'TO_i~, (M'D) SACKS C~ViE~iN'T' 28. PEP~'ORATiONS OpF2q TO I~RODUCTION' ' (Interval, size and humber) i i i 30. ~OD~C-~O~ - CEh~W~G RECO1RD A1VIOITNT PULLED 27. "TUBING REOOI~D S~(MD) S!~E I DEP'I~ SET (MD~ I PACKER SET (MD) 3. 1/2" 9905' ~'8~'i 2~. .cm. s~o~. ~'~.C~T s~u~. D~t ~'I~V~(MD) KIND OF ~~ U~ 6-10- 68 ~ -: Pumping ~,~.t-~) Producing DATI~ OF TI~ST, IHOUI~S TE~TED ' [CI-IOI"IE SIZE [t~OD'N FOR OIL--BBL. GA~,%--iV~CF. WATEI~---BB,L. [ GAS-OIL PATIO I · ! ITEST PER~OD '.... .... ,,, 6-28"~6a / 24 ! 124/64"1 ~'-"~' [ i I I 291 PLow, Tm3IRTG ' ! ' 124-I-IOUR RATE ,I ~'~0 / I > '[ 2890 ': I 888 I 158 I 35'30 31'. DISPOSITION OF ~AS (~01d, i~sed j~o~' j~u61~ ~ent¢~, etc.) ' ' [TEST WITNESSED BI ' "' m-- Used for fuel and flared t 32. LIST OF ATTACHMENTS ...... WorkoYer Well History 33. I hereb~ certify that the foregoinl~ ~"~in~/~t~ched information is complete and corree't as determined from allravatlable records SIGNED ~' '- ~ /~"~//~' wIwLE ' .Area Admin. Supervis°r DAT~, 9-12-68 · (See Instructions and Spaces I:or Additional Data on Reverse Side) INSTRUCTIONS. General: This form is desilgned"' for isubmitting a complete and correct' v, Jell!~completion rep6rt end 'l~g on all types'oS lands and leases in Alaska. ! · ,~ . I · Item: 16: Indicate which elevation is used as reference, (where not'otherWise shown) for depth mebsu:re- merits given in cther spaces on this form and in any attachments.' · Items 20, ~,nd 22:: If this well is completed for separate prOdUction from more than one:' interva'l zone (multiple completion), so state in item 20, and in item. 22 show the producir~g interval, or intervals, 'top(s), bottom(s) and name (s) (if any) for only the interval repor,ted in item.:'.'~ 30. Submit a separate repor.t (page) on this form, adequately identified, for each adctition~l ihte, val to be seperately produced, show- ing the ack{iti0nal data pertinent to such interval. Item26: "Sacks Cement": Attached .supplemental, recsrds for this well~ shoul,~ show the det~ils'of ar~'mdl'~'':'' tiple sta.ge cementing and;'the location of the cementing tool. Item 28: Submit a separate completion report on.,·this form for 'each interval to be separately pr0du .c~l.:! (See instruction for items· 20 and 22 above). 34. SUM~.MAR¥ OF FORMATION TESTS INCLUDING INTER~AL T~tED, P~Ua~ DATA ~ I~ov~~ 0F OI~ G~. . "AND" ~ ': ~": ~'' ~S. O~GIC .M~R~ WA~ MUD : '" N~ ; '"' : ;. .. , : MEAS. ' .. . . . ., . . , . ,., ~8. CORE DATA. A~FACl[ ~RIEF D~CRIPI~ONS OF ~ITIIOLOGY. POROSITY. FRACWR~. APP~NT DIPS AND DE'I'EC~'E1) StlOWS OF OIL. ~ OR WAT~. , . . ~ . . . . ~ .. Form P-~7 · - SUBMIT IN DUPLIk, ._ STATE OF ALASKA (See~thertn: structions on OIL AND GAS CONSERVATION COMMISSION reverse side) WELL COMPLETION OR RECOMPLETI~N REPORT AND LOG * la. TyPE .OF. WELL: _ OIL... WELL - ~] G~S. WELL I-_l DRY D' Other b. TYPE OF COMPLETION: _ NEW ~-] WOnK [~ DEEP- ~'~ PLUG[] DIFF,,-: BACK nESV~,[-~ Other EN WELL OVER : 2. NAME OF OPERATOR / Pan American Petroleum Corporation 3. ADDRES.S.' Or. 0PE.RATOR P. 0. Box 7?9 - Anchorage, Alaska 99501 4. LOCATION OF WELL (_~epor~ location elearl~l and ~su~ace Leg ~, Slo~ ~, S~GS Platform?D; 67g~ FSL, 1765~ F~ Sec. 35, T8N, R13W, S.M, At top prod. interval reported below ~83' F~, ~6' ~, Section ~, TTN';; R13W, S.~. At total dep~ ~ .~ 63~-.~ FNL, 660' ~, Sec. 2, ~. ~ ~o. ,~ ~ss~o API 50-133-20023 5. LEASE DESIGNATION ' AND SERIAL' NO. A ~-:18 46 ' 7..UNIT AGReEMeNT NAME :SOUth: MGS pn.i~ $. FARM OR' LEASE NAM~ So~uth MGS Unit 9.- WELL NO. 10. FIELD AND POOL, (~R WILDCAT South Hiddle Ground-.Shoal 11. SEC., T., R., M;, ORBLOCK AND SURVEY OR. AREA B~L: Sec. 2, T~N, S.~. 12. BOROUGH · 13. S.TATE .Kena~ .[' Alaska ~ 100~ above ~ . 20. TOTAL DEPTH, MD & ~ i10,500' MD PLUG, BAC.,K T.D., MD & ~ 10,392 ' 'MD .... 22~"~IF-MULTIPLE! 'COMPL., 23, INTERVALS R~0TARY TOOLS CABLE TOOLS · d.HO~ MANY* DRILLED BY ' ~: ~ :'": ~ I '0- TD I ...... I' 25. WAS ~IEECTIONAL SURVEY' MADE -. ] 27. WAS WELL'COI~ED 24. PRODUCING INTERVAL(S), OF THIS COMPLETIO~---4TOP~ BOTTOM, NAME (M.D-.]AI~I~ TVD)* ;_- :.; [ .:. ~9440-9940' ~, State "O" ~d~'~ Lowe; ~ena~':ComglOmerate Fomation 26. ~PE ELECTRIC AND OTHER LOGS RUN IES, Sonic, Dipmeter, Colla~ ~ocat0~. 28. CASINO SIZE · 20" 13-3/8" 9-5/8" 29: -. ' C~J~S~G RECORD[:(RepaPt~ a~ strings set in well) WEIGHT' LB'/FT'ID'~T~'-~S~ (MD)]/' HOL'" S'Z"160 [: CEMENTING R'CORD : '~0~'~' :' .... 26ic ~; ~' 12.85 sx - [ I sx EIZE 31. PERFORATION RECORD (Interval~:size anvl number) 9930---40~ , 9905-15'!,, 9ig75-85~ 9805.15~, 9770.90:;i~, 9730-~0' 9655-65~ 9560-70~ 9530-40~ 'and 9440-50~ all ~±th 4 jspf 82. ;79530-50/!, DEPTH '~NTERVAL (ME) ,i~.:9700_10¥, -- . , 9503-13', i~RODVcTION AMOUNT PULLED TUBING RECORD SIZE DEPTH SET (MD} PACKER SET .(MD) 3-1~2" 9-294 ~ 3-1/2" 9927~ ACID. SHOT, FRACTURE, 0EMENT SQUEEZE, ETD. AMOUNT AND KIND OF MATERIAL USED DATE FIRST PRODUCTION PRODUCTION METHOD (.Flowing, gas lift, pumping--size and type o! pump) [ WELL STATUS (Producing or shut-in) ' 9/28/67 " Flowing I Producing 10/2/67 4 .: [f265/64"f: TEST PERIO~ ,- ~: L-~i;12 S-ll L--FLOW'150TUBINGS-- 200'--S' I CASING PRESSURE I'-'~-CALCULATE' F':24'HOU" ~'A'' I ~_~0~'~ ~: I -~~'~_ ~ r la~-e d WATER--BBL. [ oAs~oIL RATIO. GAS--~._~i1 1~-4 s-~ I 739 $-374 . ~ ' WATER--BBL. [ OIL GRAVITY-AP1 (CORR.) TEST WITNESSED BY LIST OF ATTACHMENTS IES, Well History and attached information is complete a~nd correct ~as determined from all available records 36. I hereby certify that the foregoing SIGNED '~ ,. TiTLE-ASS ' t.' Area A'dmin. Supvr. D '*(See In~truction~~ Spaces l°r Additional Data' on Reverse Side) ' 0Cq 3 0 t967 A~O~E INSTRUCTIONS - . ~$~ne~el~This form is designed for submitting a complete and correct well completion report and log on all types of lands and lea~s to either a Federal agency or a State agency, '.~g botl~-~pursuant to applicable Federal and/or State laws and regulations. Any necessary special instructions concerning the us'e df this form and the number of copies to 'snbmitt6d, particularly with regard to local, area, or regional procedures and practices, either are shown beloW or will be issued by,. or may be obtained from, the local Federal and/or 'State office. See instructions on .items 22 and 24, ~nd 33, below regarding separate reports for'separate completions. ' - ' - - :'Ig no~ jfil.~d prior to the time this summary record is submitted, copies of all currently available logs (drillers, geologists, sample and e0re analysis, all types eiectric,~etc.), forma-'~ 't£on and ..pressure tests, and directional surveys, should be attached hereto, to the exten~ required by applicable Federal and/or State laws and reg~latiOns~ All~ attachment~~ ~s]iould~,be listed on this form, see item 35.- l~m 4: I~ there are no applicable State requirements, locat{ons on Federal or Indian land should be described in accordance with Federal requirements. Consult local '~r Fed~'~l office for specific instructions. , l~m T~fj:Indicate which elevation is us4d as reference (where not other~-ise shown) for depth measurements, given in other spaces on this form and in any attachmentm :.lfcm~ 22 ~nd 24: If this well is completed for separate pr6duction from more than one interval zone (multiple completion), so state in item 22, and in' item 24 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any~) for only'~he interval reported in item 33. Submit a separate report (page) on thin.form, adequately identified~-~ for each additional interval to be separately, produced, showing the additional data 'pertinent to such interval . · .... ~ .... I~m 2?: "Sac~s Cement": Attached supplemental records for this ~ell should show the details of any multiple stage cementing and the loc~tion of the~cementing tool. i~¢m 33: Submi~ a separate co/npletion report on this forr~ for each interval to be separately produced. (See instruction for items 22 and 24 above.) 87J SUMMARY OF POROUS ZONES: ~ ......... -' ,'- ~ sHOw ALL IMPORTANT ZONES OF POROSITY AND CONTENTS THEREOF; CORED INTERVALS';' AND' ALL DRILL-STE~ TESTS, INCLUDING 38. ~ GEOLOGIC MARKERs .~. i ' DEPTH INTERVAL TESTED~ CUSHION USED, TIME TOOL 0PEN~ ·FLOWING AND ~HU~-IN PRESSURES, AND RECOVERIES FORMATION ~ _.TOP' [ . BOTTOM ' ~ ~ DESCRIPTION, CONTENTS, ETC.-. --~ 8700' SS, Lpoor-to'fair .sorting~ tite to ..... ' '. .. .. .. ''~ ,. ..... ,: ,': " :.":. ";~ Por°si~y,' ~Ey:, mi~ 's~y ' ~cs sa~ ~e~r : 4~SS' ~4S~4'~' . ,. .... :].; ' ~'. . '. ~,~o~k 9430~ ' 'ray~ F-CG, P sort P-F Poro ' " ~'~ ..... " , , ~',' ' '~ ':l .- . · · ~ .., : ~ ,. ,. · ~. ,. -- ; · chLy. ~/~ree~ .& red 'CHL, mica,' sl~; ' H'~mloc~' '~ --g430' ' g260' , - . , , .. .. ~ ,- .-.~ ~' ,- ,. . .-: ; , · ' ............ .. ": :ore~' ~.' '~_5~' ' ::~-~ '-'~':" - - :~' ..... ::" ' ' ...... ~-:' "' -VC~, cgl,'P:~ sor~,'~'-~ .poro., .' ..~ 9555' SS, '~ / ~..;]~ ~ ...... chty, ~/red and' g~een chert, also~' ' ~ ,. · ~i ' - - ' :' '. "' f'- ~-' '~ ' ';' ': -. : ,... - ::blk &:gray. i neous grains,, mica', . . < . ~ :: ~ ,..- ' :' ' ~ :.;'-:'" ~': : ~ ..... ~lty ~ ...... :~': " ' 'I ~ ' .............. :.:: '..s . " .. ;- ',. ~:. . , .. ',ore #2 .:..: ... 9 . 97 s~m~" as abo~e . '"' :::~ - - ,, . ~ , .... ,. ',ore #~ " ; '~ g7~3~; g750~ ~me: ~s ~bove :' ~ .... ";' ~:'"'. '~ ' ~' , ~:' :, : : , ._ ,, , ..... ~, ~:~ ',, : : : , .. , :. ~ ' . :"' , , . , ., . ...... , :. : '-c , ' "~ ;- 1 -. :.. - '"' .... .. . : . _ ....... - . , ~ ..., . , = ' ' ::. .,~ r . ~ : ......... ,- - :.. ........ . : -- ,.. : ): ~.: ~.,.:..: .... · ... ... :' . -... ... ~. . , . , - ,-. .::. -. .: - ~. -. ~-. . - ,, ::. -. : ., ;! , - ,?, :. ~ ', . ,:' ' ~' . : .,, · .... , - · . .... '. . , :.,~, ~ . ' : ; . CHRONOLOGICAL WELL HISTORY SMGS Unit #3 6/12-21/67 6/22/67 6/25/67 7/02/67 8/Ol/67 s/18/67 9/07/67 9/08/67 9/11/67 9/18/67 9/19/67 9/22/67 9/25/67 9/26/67 9/27/67 Rigging up workover rig. Spud from Leg 4, Slot 4, SMGS Platform D; 678' FSL, 1765' FWL, Section 35, T8N, R13W, S.M. Drilled to 670' and set 20" casing at 600' with 1285 sx. Drilled to 2061', set 13-3/8" casing at 2006 with 1200 sx, and temporarily suspended operations. Moved workover rig back on well. Drilled to 5636', set bridge plug at 560' and switched to drilling rig. Drilled to 9530'. Core #1, 9530-9555', recovered 17 feet. Core #2, 9692-9718', recovered 16 feet. Core #3 9753-9760', recovered 7 feet. Drilled to 10,500', logged and set 9-5/7" casing at 10,439 with 1250 sx. Drilling rig released and well temporarily suspended. Moved on workover rig. Perforated 9930-40', 9905-15', 9875-85', 9B30-50', 9805-15', 9770-90', 9730-40', 9700-10', 9655-65', 9560-70', 9530-40', 9503-13' and 9440-50' with 4 jSpf, and ran dual tubing strings. Flow test. Well completed as a single completion flowing oil well. SMGS Unit 18746 No. 3 Workover Well History 6/7-9/68 - 6/10-27/68 - 6/28/68 - Pulled and reran tubing and Kobe equipment. Pump tested. PBTD 10,392'. Workover completed as a pumping oil well. A.,~!. COOE-SO. 133.20023_ DH- !.2 Release Date ...... !0.27-69 State of Alaska Department of Natural Resources DIVISION OF MINES AND MINERALS Pet roleum Branch INDIVIDUAL WELL RECORD OperatorPa~_Ame_t._:[~an_~e_t.. _Co.,1~p.. . Location (Surface) Lease No. ADL-187/~6 Sec. (35). 2 T. (SN) .... ? N _ .~ R. , 13 I~ _ 13 .... S _- _ Meridian Permit No. ,_,, 67~8 ~8 4~ Slot 4 678~ VS~ ~_1765.~ _~_ or Owner _._So,_Middle_G'toPad ShoaluniLtDc. (Bottom) 636* FlqL;& 672* trw'L Sec, 2 - _ ., - ........ _ .- =. _._ ,. '- ,. ~ ....... : _ _ _ -. ~ _ _. We l 1 No. 3 Area So. Htddle Ground Shoal -- - .... ------- ........ -- · -.-.- -. ...................... Spud Date_. 6-22-67 Ori I I lng Ceased Total Depth 10,500 _-- L' . -. __ -.'_: . t .... !. _ .... I1_1 _ _ L± IL_ IL , iL Sospended _ _~ __ Abandoned Elevation 105 MSL Est. = S '-' 28~0 .......... "- .................. O. 0 Completed (F-GL-P)9_-_27-67. _ ..... IP_,,L 2685 B/D, Grav 35.3 AP! Cut 0.1 Ga~L~HCF/D, Bean_!_2/+..5/61t CP ..... . ..... psi,: TP - ----=11~g200 ......... .... psi Casing:_ Size 20" .... 13 3/8" ' 9 518" 2 tbs strinp ;:- '~_ · '~ _ _ _ ._,,. ,._. L .. GEOLOGIC FORI~TIONS Surface Lowest Tes ted SxCmt Perf: 9930-40': 9905-15':.. _ .................. . ...... ..~ ..... 128~ 2006~ ~ 1200 9770-90~ 9730-~.I 9700-10~ 10~391 1250 9503-13'; 2 9927 ~ ~ ~_~ · ....... .~: .... ~- ~ ~ . .- , ,,, ..... ~_ s~ .... ~ : ~ -:- _: ' ~ _ : -- PRODUCT! VE HORIZONS WELL STATUS Year Jan~ [e,b; Hat Apr Hay.. June July Aug Sept Oct Nov Dec · -;.~?_'-_~.'L'k"'"-".f '_.. ~'-- 4:':~~ _~_-,:-_:L~,i;'- : ::i:=..:...,_~c: 7~, ..-.::,~'~,;~_=:~:'--':"-'~-~'--'-~ ~','-,_,.=,,,-:::: ~::~Z.-:~: :~. - ~'~":. ::'" '~_.~::~_~=:~:~c'~""~'_:'-=~'' __ . _.. ....... · . _ :..~.._ _~... _-_. .. ___ .~- ,,_ : -- .- ,~ ,,_ , - ~; -.- .. · ._'.- _=___ t'~ ~ ' -' '_'' ' 7_. -'~--'-- : :~: : ~-~ - :.:: _ i1 , i . i L~ IlL_ i, :"" L' -.. ' J --" -- ' L" .... ?., - . _,,.~-, ,_, U_ . _t._ _' : _.:- _ -? ..... : _-: ' ; :;tj · ,, , ..... ~::: _~ ~ ~ _ _-.? ~_ , ~.__...~ ..... Remarks: - Contr: Reading & Bates · _On_ So, tt!ddle Gr.o.~d Shoal. Platform '~)tllon". ~ ,,,, ....,, :_ ._ :.--~-.:.~.a : -- ~ - _ _ _ _..-. ~ .................. z - DJ. rect:J, on Gourse Depth PAH AHERICA1/ FETROLEI~I4 CORt'OIh~TION Lat. Def. ~actor Factor .. o, Direction Course Depth Factor Lat. Def. /% TVD I .~VD Factor Factor N ~ Do '' ' PAN AMERICAN PETROLEUM CORPORATION "' Direction ~ Depth ,~ . ~ ' ' ' '"' : ..... , ' :":' :'' ' · ...... · '- Lat. , Def. M (Cor.) Course Factor ./% TV/) I TVD Factor Factor ~$~ ~~t ..... : ............ ,, :~-.~, .-' , ...... ,~- ~~..'--~:'~, >-- --: J~---- ,~~ ,~.~7 ~ , - ~~~.~o ~~~~~~'~,~:~:, ~.-. - ' ""' "':" ~':'-'. :~ ' ' ' ' .'- /'"<'"'-' i~-'' '"~' STATE-'OF"ALASKA ,--"x · '. '. ' ~ 'OIL AND GAS CONSERVATION COMMII~EE ~.-,~o o~,:. Anchorage .~.. NUM.. ADL - 18746 ~... o...,. ~M~ SMGS Unit LESSEE'S MONTHLY REPORT oF OPERATIONS . , Tl~e followin~ is a correc~ reporg of operations and prodz~c~io~ (includi~ drilliv,~ and produein~ wet,s) fOr of .............. .S-..em-t-.e-mb.e..r. ....... m--6-7- ........................................................................ : ..... Corn-am Pan American PetroleUm Corp. 'dl~en.t,s address ...................... ~:----O--:---~-9--x----7--7--9- ................ ~, v ....................... gv- ...................... . ' ' Anchorage,` Alaska $ivn, ed ......... JG.~..:~-~'(.?."/;~--.- .................... ;i;i;-'--: .......................... ; ..... '~'~-"~;'~-~ ........................... --: -, .... Ass't Area A~min. Su.~.vr. ~,~o¢?~, $ Z;l~/~ ............ '- ......................................... Co. FT. OF OAS AND BARREL~ OF OIL or }~ (~ thousands) BHL: NW SW 35 45-14 386' Flo' 10, 386 , flow te,' 386'. Reh 'BTD 10, 3 2167 ing. eeze, per: ~ab, and fl GASOLINE %VATER (If (If driltinz, dept~': If ,hut down, ~ECOYERED ~ODO~ SO state) date and retult of t~t for g~ol~e e~tent of 0 0 rated, st, )~v test-. ,rkover rig. Test? . AP1 50-133-20022 Produced from Lower Kenai Conglomerate G zone NW NW 2 11, 354 8391 0 0 39Z' as flowi Lg well. AP1 50-133-20023 Produced from Lowe Kenai Conglomerate ~ zone ill and co 0' to TD 1 500'. 'D 10,500 , set 9-5/ ' casin at ith 1250 s ease drill!ng rig temper rily TD 10, 3 se rated and ran tubing, NOTE.--There were ................................................ 15,868 runs or sales of oil' . ............... ..N....o. ......................... M cO. ft. of gas s0~Id; ............................................... runs or sales of gasoline during the month. (Write "no" where applichble.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines &-Minerals by the 6th of the succeeding month, unless otherwise directed. . ' ~ . ...... Page 1 of 2 .. . , _ Form No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 ~r~,--tAnchorage N,,M.~. ADL - 18746 o...,~ .AM~ SMGS Unit LESSEE'S MONTHLY REPORT OF OPERATIONS TI~e followir~ff is a eorreot~ 'repot* of operatior~s arid prod~etior~ (ir~el~din~ drillir~ a~,d prod~ei~ wells) for th, e mont[~ of .............. _S_.e_~D_t__e__.m___b___e_.r_. ....... 19_6..7_._, _ ........................................................................... Pan American Petroleum Corp, .4~ent'saadress ..................... .~_~_:____O__:___..B__p_x_._7___7__9._ ................ Corr~pa~y ............ OH~T//~I - 'Si-~ii~'a ' B ~; ................... ............................................... _ _A_ _ _n_ _c_ _ _h_ 9_ _r_ _a_ _g _e: :___A3_~:~___k__a_ ....... S~ea .................... c~-:I~:--m~.-Tz ....................... 272-8471 ....................................................... Pkor~e ................................................................................... ~lgent's titleA~s't' Area Admin. Supvr. C~. F~. or (lAS S~.c. AND BAaRE~S o~ Om ~4 o~ ~ . (In' thousands) BHL: NW SW 35 NW NW 2 Lea 4514 ns. , pe r: 'ab, and fl ~rkove ~ · )w Testi] 11,354 8391 as £1owi] ill and co 0' to TD 1 D 10,500' set 9-5/ :h 1250 ~ase drilli 'BTD 10, 3 rforated se · ok~o~s or GASOLINE RI~COYERED orated. )w test. iS. tg well. ~, 500', ~" casin ag rig and ran BARREL8 OF W~s (If none, so state) ~eSt, at tempor tubing, REMARKS (If drilling, d~i~th; if shut down, oau~; date and rmult o! test for gasoll~ oon~nt of ga~) AP1 50-133-20022 Produced from Lower Kenai Conglomerate G zone AP1 50-133-20023 ProdUced ..,rom Lowee, Kenai Conglomerate G zone rily 'low te st NOTE.--There were 15, 868 runs or sales of oil ................ .N..0.. ......................... M cu. ft. of gas sold; .................... .N....Q ................................. runs or sales o£ gasoline during the month. (Write "no" where applicable.) NOTE.~Report on this £orm is required £or each calendar month, regardless of the status of operations, and must be filed ii1 duplicate with the Division of Mines & Minerals by the 6th of t~ ~cU~nI VT,0nless otherwise directed. OCT 9 19~7 x:,~g~ t o£ z DIVISION OF MINES & MINERA~ Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 V f [' ,_,,No orr,=~ Anchor age · ~.s~ ~,-M.,-. ADL - 18746 L~^~ oa .N,~ ~^M~ South Middle Ground Shoal LESSEE'S MONTHLY REPORT OF OPERATIONS umt ,. Am ~0-~-z00z~ State ............ Alaska~ ............... Borough _~ .......... ~_~l~,ai ................. F/eld ........ ~ 2u.t h__Mid~cll.e...Gr_o..~nd_, $1'xo_a! .... TI~e followin~ is a correo~ repor~ of operations and prodz~etioT~ (ineh~dir~5 drillir~ and produein~ wells) for the month of ................ ._A_~.u_g_U__s__t_ ........... , 19_6..7___, ............................................................................ BHL: NW of NW diderot's address .................... _,P_ .... O...__B.ox__TT_~ ................. CompanF Aach~Zage_,__Ala~_ka ............................................... ........ .......... ........... Phone .................................... _!_7_.g__-:_8___~_!! ............................. .~e,~t's tit~e ....... A _r__e___a___S___u_~__e__r_.'_m__.t_e_..n.~.e_._n.t. ....... ~EC. AND 7~ ;/ 3W] 3 '[ 0 ri~§i~ ~ up BARREUi OF On. .g ahead o: o drill ah( 9~1167' 0 id. 18/4, TD 2 OALLON8 OF OtASOLINE RECOVERED ~19'. dri WA~ER none, so state) Lling ahe REMARKS (If drillln/g, devth: 1! ~hut down, onus; date and result o! te~t for ga~olin® content of g~) ad. NOTE.--There were ............. ..N.0. ............................. runs or sales of oil; ........................ ..N..0 .................. M cu. ft. of gas sold; ................... .N....°. .................................. runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.~Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines& Minerals by the 6th of the succeeding monthr~uli~e~i KkL IVE directed. . DIVISION OF MINES & MINERA~ Form No. P--4 Effective: July 1, 1964 STATE OF ALASKA ~ANO =r~,=~ Anchorage OIL AND GAS CONSERVATION COMMITTEE ,~^s~ ~uMB~. ADL - 18746 .~.s~ o. uN,~ ~.M~ South Middle Ground Shoal LESSEE'S MONTHLY REPORT OF OPERATIONS Ur it ~50-133-20023 Ti~e followin~ is a eorreot repor~ of operations and prod~etio~ (inel~dir~ drillin~ and produein~ wells) for tke month of ................ __3__u__l_y_,_ ................ 19__6__7__, ............................................................................ dl~ent' s address ................ P_~__O~__t~_2_7_9_ ..................... Company _.P__e~.A. me_~i_ca~.P_e~rola.urr~.Co_rp. .......................................... :_~_~_c_ _h__q _r_ _a_ g__e_, _ __~_1_ ~_ _s_ _k_.a__ ........... Si~ned ...... ~~__.~ .............. Pkone ................................ _2__7__2_-_.8_4_7_.1_ ................................. d~ent' s title _._z%~r.~a__Sla3zae rinter~iea~t .......... ,,, . Co, FT. Gl, GAS GAU,.ONS or BARRELS Ol, RE]kIARK~ SEC. AND TWP. RANGE WELL D~s BARR~ O~ O~ GRA~TY ~ASO~NE WATER (If (I~ ~Uiu~, d~th; ff ~hut dow., ~ og ~ No. Pao~c,~ (~'tho~) RECOVERED none, so s~te) date ~d r~ult of ~t for g~o~e e~t o{ e~) f NW 7N 13W 3 0 0 0 0 0 0 ~,D 2961, ope~'atior.s temporarily ~:uspended )n 8/1/6~. ~/3, TD ~061'~, set 13-3/8" c~sing at 2006'; ~:emente( with 600 sx (:las~ G ~,lus B3~/sack Diace~ D plus 2% CaG12 and 6)0 sx Glo,ss ( ne~,t. '~/4~ TD 2061', suspend operations ~o set re[nforcin~ strings. .............. BHL: NW of NOTE.--There were .................... .N...0. ..................... runs or sales of oil; ................ ..N...O. ......................... M cu. ft. of gas sold; ................................. ,N...O. ..................... runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding mc~thr~u~e~a directed. IV U AUG 1 0.1967 DIVISION OF MINES & MINERAL~ Form No. OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 LAND mrr,c~ Anchorage L~AS~ N,,M.~. ADL 18746 LE^s~ =~ "N,~ N^.~£ South Middle Ground Shoal Unit LESSEE'S MONTHLY REPORT OF OPERATIONS TY~e followinff is a eorreot report of operations and prod~etion (ineh~di~ drillin~ a.,d prod~ein~ wells) for tY~e rnontY~ of .................. __J-__u_n_e_ ................ 19__.6__7_ ............................................................................. ~l~e~t's address ___P_,___Q:___B_o_x__ZZ_9_ ...................................... Company _P_a._n____A_.m___e_r___i.9..a..n__._P_9__t..r_9_l__e_.u..m__..C._°.~P.~.._ ............................. .............................. .................... Pkone .................. _2_72_-__8_4_Z1 ................................................ J~ent' s title __A_r_._e__a____S__u_p__e_~_n.~.e.u.d.' - ' '.e._n..t. ............... SRC. AND D~s CU. F~. o~' GAS GALLONS o~' BARRE~S or REMARKS ~ OF ~ TWP. RANGE WELL BARRE~ OF O~ GRA~TY GASO~NE WATER (If (If ~ng, deDth; If shut down, No. Pao~o=~ (~ tho~) RECOVERED none, so s~te) date ~d r~ult of t~t for eou~t of L: of ~ 7N 13W 3 0 0 0 0 0 0 TD 2061' r,~amin~ on 6-30-~7 Spud 12 Noo~ 6-2:?67. 6-25-67, TD 670', ~et 20" casing at ~00', ceu.enteJ wi::h 18~ sx Class=C plu~ 33~ Diac,~l D per sx plus ~7o CaC12 an5 110) sx Ct~s~ C plus ~ CaC12. 6-27- ~7, TD 670' drilling ahead. ......... BH NOTE.--There were . .............. N...O. ............................ runs or sales of oil; ........... .N..0 ................................ M cu. ft. of gas sold; ................................ .N...O. ...................... runs or sales of gasoline during the month. (Write "no" ,.-here applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals bY the 6th of the succeeding mont~u~l~ ~th[erVs~. directed. JUL l :1.,1967 DIVISION OF MINES & MINERAL3 FORM 4TO 2-57 PETROLEUM CORPO ION P. O. Box 779 Anchorage, Alaska 99501 June 23, 1967 File: FKK- 871-WF Spud New Well - SlVIGS Unit #3 Director Division of ~nds State of Alaska Department of Natural Resources 344 Sixth Avenue Anchorage, Alaska Dear Sir: This is to notify you that the subject well was spudded on State Lease ADL-18746 at 1200 hours on Suns 22, 1967. The surface location of t~s well is at SE/4 SW/4, Section 35, TSN, Ri3W, S.M. We plan to drill this well directionally to a bottom hole lo- cation of NW/4 NW/4, Section 2, T?N, R13W, S.M. Yours very truly, Original Signed By: F. K. KHEBILL F. K. Krebill A rea Sups rintendent Mr. T.R. Mars~ll, Jr. Division o£ Mines & Mhaerals RECEIVED JUN 2 G. tg ? DIVISION OF MIN~:S & ~iNEP, At~ ANCHORAGE: Juno 12, 1967 FORM SA - lB 50M 1/67 ' M;EMORANDU.M TO: J-- FROM: State of Alaska DATE : SUBJECT~ FORM SA - tB ....-,--~ .~.,,~ 50M 1/67 ' ~ ~ MEMORANDUM TO: J-- FROM: State of Alas~ka DATE : SUBJECT,' .'For~.-"~ I . STATE OF-ALASKA OIL' AND'~'GAS ¢ONSERYATION COMMITTEE SUBMIT IN TRL ATE* (Other instructions on reverse side) Effective: July 1, 1964 LEASE DESlONATION AND SERIAL NO APL - 18746 6. IF INDIAN, ALLOTTEE OR TRIBE NAME APPEICATION~,FORPERMIT: TO DRILL, DEEPEN, OR:PLUG BACK. la. TYpE-OF WOR~ .... ~', ." ~'.,,;; DRI[L;:I~] ~- .... - .. D£EPEN [71:. PLUG BACK [-! o-~' WEL-~. ,, ' ~ .... .-. ...... : b, TYPE .... ~ .~% m~.--:.: . . . W~LL W~L~ O~H~R Zo~ ZON~ 2. NAMEh0F OPERATOR : ' " -' : ~ ""' .' " Pan American Petroleum Corporation, · 8. ADDRESS' OF' 6PER~T01~ '~ ...... -- ' ;~ ~ ,. P. O. Box 779 - Anch;r, age, :A~is~a ~oe!~zo~ .o~ w,~ (ge~ort !oeaUon e!ea~l~ an~ !n a~eordanee w!~.any 8rote r~ulrement,,*) ~t,,~faee Leg .4,' S10t 4, l'765'FWL; "6?Sr"'FSL~ Sec. 35, TSN, R13W ..... . .... . At proposed prod. zone 660' FWL, 660' FNL, Sec. Z, T?N, R13W 14. 9IS'INCI IN MILE" AND D'REC'ION FROM NEARE~' TOWN OR POST 15-1/2 miles NNW of Kenai. 7. UNI~ AGREEMENT NAME "8. fARM OR LEASE NAME Unit 9. WELL. NO.' 10, :FIELD AN~ POOL, OR WI~,DCAT South Middle Ground Shoal SEC., T., R., M., OR BLK. AND SURYEY OR AREA BHL: Sec. 2, TTN, R13W" 12. BDROUGH SHJ 13. STATE Kenai J Alaska 1~, DISTANCE FROM PROPOSED* - - -- ~ ,---- ------ I-- I LOCATION TO NEAREST z}bY'-U {q; ~ ~D~DU ~ tO J PROPERTY OR LEASE LINE, FT. . I (AlSo to nearest drlg. ~n~t line, If any~U~t ~O~~ ~ I8. Dm~NC~ r~O~ ~RO~os~ L0C~O~*~I~'~ ~ 1~ ~'tO~ TO NEAREST WELL, DRILLING, COMPLETED. J NO. OF ACRES IN LEASE 4160 ~9. ~ROFOSED DEPTH 10,500' 17.NO. OF ACRES ASSIGNED TO THIS WELL 160 20. ROTARY OR CABLE TO~)LS Rotary 21. EU~VA~0NS (Show whether DF, RT, GR, etc.) 105' above MSL ~st. } 23. PROPOSED CASING AND CEMENTING PRO~RAM j 22.' APPROX. DATE WORK WILL STARTS 6 25 67 (Psssibly,o - - ooner~ SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT QUANTITY OF CEMEN~ 26" 85# SETTING DEPTH 606' 20" Circulate to surface 17-1/2" 13-3/8" 54.5# 2000' Circulate to surface 12-1/4" 40#, 43.5# 9-5/8" 10500' Minimum of 500' above shoe; additional cement may be used depending upon interpretation of electric log. Reason fOr deviation: To reach BHL from permanent platform. There are no affected operators. Intervals of interest will be per- forated and may be stimulated. BOP arra~ngement attached. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proPosal is to deepen or plug back, give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionaily, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program; if any. ruo c rre . SIGNED .~..~o---~.~~/~-- TITLE Area Superintendent DATE 6/1/ 67 (This space for Federal or State office use) pERMiTNO. C7 -- ~ ~ -- ~ -~ -- ~ lJ i CONDITIONS O~ ~/PPROVAL, mA~: TITLE iH6~PROVAL DATE ~MAS R. MARSHALL, JR. Executive Secretary Alaska OiJ ~ gas Con~or~ation Committee *See Instructions On Reverse Side RECEIVED ,'uN 2.1967 DIVI~,3H',,t OF MINES & Mt~ FORM ])AN AMERICAN PETI~OLEUM COI~POOATION 34 26 35 35 1765' T8 N 2 SEWARD MERIDIAN ALASKA T 7 N SCALE' · LEG. NO. I LEG. NO. 2 LEG. NO. ;5 LEG. NO. 4 · LAT. 60044' 0~16" LAT. 60044' 07.72" LAT. 60;~ 44' 07.08" LAT. 60° 44' 0752" ~j.3~ 5~-~~ LONG. 151° 30' 4§.85" L~3 NG. 151° 50' 44.78" LONG. 151° 30' 45.@6" LONG. 151° 30' 46 94" Y = 2,463,917 Y = 2,463,871 Y = 2,463,807 Y = 2,463,85:5 X = 229,266 X = 229,319 .X = 229,263 X = 229~211 FROM S.W. COR. FROM S.W. COR FROM S.W. COR. FROM S.W. COR. 743' NORTH ~ 699' NORTH & 635' NORTH ~ 678' NORTH ~ 1818' EAST 1872' EAST 1818' EAST 1765' EAST CERTIFICATE OF SURVEYOR I hereby certify thdf I em properly registered rind licensed fo pr(]ctice lend surveying in the State of Ateske end th(]t this pier represents a Ioc(]tion survey mode by me or under my supervision end th6! (]11 dimensions (]nd other detdils er6 correct. D(]te Surveyor SURVEYORS NOTE ii ii Pl(]t form D weis (]ccomplished stotions "Cost", "E(]st Fore,rind (]nd C.E.T. 18 (Offset 2) The toc(]fion of S.M.G.S. by use of U.S.C. & G.S. Light" .... , and Boulder 26 35 35 I": I000' 2 25 36 I FINAL PLAT OF S.M.G.S. PLATFORM "D" LOCATED IN I/4 SW I/4, PROTRACTED SEC, 35, T 8N,RISW,S.M. SURVEYED FOR PAN AMERICAN PETROLEUM CORP. P.O. BOX 779 ANCHORAGE, ALASKA SURVEYED BY E M. LINDSEY & ASSOC. LAND SURVEYORS 8~ CIVIL ENGINEERS 3201 ARCTIC BLVD. . ~cosi~g=heod BLOWOUT PREVENTER )NSTALLAT)ON WHEN DOUBLE PREVENTER V/)TH SlOE OUTLET )$ USED ANDHYDRIL. S)NGLE PREVENTORS W)TH DR)LL)NG SPOOL ARE SATISFACTORY 7. 9. · NOTES Blowout preventers, master valve, plug valves and all fittings must be in good condition. Use new APl Seal Rings. All fittings (gates, valves, etc.) to be of equivalent pressure racing as preventers. Valves to be flanged and at least 2". Valves next to BOP to be plug type and nominal 3". Equipment through which bit must pass shall be at least as large as the inside diameter of thl casing that is being drilled through. Nipple above BOP shall be split so it can be easily re=owed. Full opening safety valve (Omsco or equivalent) =rust be available on rig floor at all times and with proper connections. Kelly safety valve installed, same ~orktng pres- sure as BOPtso - All lines and controls to preventers must be connected and tested before drilling out of surface pipe. BOP's must be fluid operated with controls on derrick floor and Hydril complete with accumula- tor and I (one) remote c~ntrol station. If fillup line is' tied to drilling nipple, ~ne connection must be belcw and approximately 90° to the flow line. 10. 11. Side outlet must be below bottom ram. - , 12. Caginghead and casinghead fittings to be fur- nished by PAN AHERICAN ?ETROLE~t CORPORATION. 13. Chokes =ay be either adjustable or positive. . . 14. Drilling spool with choke outlet below BOP's is satisfactory.: 15. Casingheads furnished by PAN A~RICAN PETROLEI~I CORPORATION will be 12" Series 900 and 10" Series 1500. ~tEN Cuage may be left out while drilling.. DRILLING USE -- Top preventer -- drill pipe ram~ ~ottom preventer-blind rams or master valve. RUNNING CASING USE --- Top preventer -- casing rams Bottom preventer-blind rams or master valve PAN AMERICAN PETROLEUM CORPORATION CASPER , WYOMING BLOWOUT PREVENTER ARRANGEMENT "O" ,~ TN CK APP I' ,,Pi ',.A,.I '~.°.".i ".~"i ,o-?-~,
