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Home My WebLink About175-0071a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _0 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: N/A BF: N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 92' (ft MSL) 22.Logs Obtained: N/A 23. BOTTOM 20"601 13-3/8"2,006 9-5/8" N-80 & S-95 6,664 7" S-95 9,972 7" Liner 6,434 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 / MGS Oil N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing N/A N/A Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 40 & 43.5 10,304 Surf 6,434 85 54 601 Surf 6,770 SIZE DEPTH SET (MD) 9,170 / 8,949 PACKER SET (MD/TVD) 3-1/2" 6,24229 Surf 26 Surf 6,536 2,016Surf Surf CASING WT. PER FT.GRADE 5/27/1975 CEMENTING RECORD N/A N/A SETTING DEPTH TVD 2465707.7941 TOP HOLE SIZE AMOUNT PULLED N/A 228831.1953 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 50-733-20022-01-00 S MGS Unit 02RD ADL0018746 731' FSL, 1823' FWL, Sec 35, T8N, R13W, SM, AK 2524' FSL, 1344' FWL, Sec 35, T8N, R13W, SM, AK N/A 4/21/1975 10,304 / 9,972 Surface 100' 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 229270.7415 2463904.3884 N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 5/26/2023 175-007 / 322-487 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 6,536 6,147 9,188 / 8,966 9,102 64 3-1/2" Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 3:53 pm, Jun 21, 2023 Abandoned 5/26/2023 JSB RBDMS JSB 062723 xGDSR-7/19/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A N/A N/A Top of Productive Interval N/A N/A N/A N/A 31. List of Attachments: Wellbore schematic, Well operations summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Aras Worthington Digital Signature with Date:Contact Email:Aras.Worthington@hilcorp.com Contact Phone: 907 564-4763 Operations Manager General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). 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. INSTRUCTIONS Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Authorized Name and 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) Date: 2023.06.21 14:51:00 - 08'00' Dan Marlowe (1267) Updated 08/2011 Kobe 3” (‘A’ cavity, Long stroke Piston, Open Power Fluid, w/(6) 1” holes, 2 for power oil return , 4 for production) Offshore Dillon Platform Di-02RD S Middle Ground Shoal Cook Inlet Basin, Alaska Middle Ground Shoal PBTD = 10,140’ TD = 10,320’ Max Hole Angle = 27.5 q RKB to TBG Head = 33.28’ Hngr. connection: 3-1/2” 8rd I 9 20” 601’ 13-3/8” 2016’ 9-5/8” 6770’ 7” TOL 6242’ 7” TOL 6536’ Baker Pkr 9170’ Perfs 9502’ – 10070’ TOF @ 9864’ Eclipse Pkr 9188’ 2 8 CRA Top 9128’ TOC CBL stops at 270’; TOC tagged @ 2” below outlet valve TOC 7270’ CBL G&G Oil Top 9373’ Tbg Punch 9094’ – 9099’ CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. TOC CMT 20 85 19.19 Surf 601’ Surface 13-3/8” 54 12.58 Surf 2,016’ 9.8º 270’ or higher (CBL) 9-5/8” 40 & 43.5 N-80 & S-95 8rd LT&C 8.755 Surf 6,770’ 11.8º Very Poor Bond (CBL) 7” 26 S-95 6.276 6,536’ 10,304’ 7270’ CBL 7” 29 Scab Liner 6.184 6,242’ 6,536’ Tubing: 3-1/2” LS 9.2 N-80 Butt. 2.992 33.28’ 9,102’ 3-1/2” SS 9.2 N-80 Butt. 2.992 33.28’ 64’ JEWELRY DETAIL NO.Depth ID OD Item 34.15 CIW ‘DCB’ Dual Hanger 1 9,102’ 2.992 4.375 Crossover, 3-1/2” Buttress Box x 3-1/2” 8 rd Box 2 9,111’ 2.687 4.189 Kobe, 3”, “ALP” OPF Cavity S/N: 231-A-8-98 3 9,128’ 2.992 4.500 Crossover, 3-1/2” 8rd Pin x 3-1/2” Buttress Pin 4 9,129’ 2.992 3.500 1 Jt. 3-1/2” , 9.2#, L-80, Buttress 5 9,161’ 2.992 3.500 Pup, 3-1/2”, 9.2#, L-80, Buttress SC 6 9,170’ 2.992 4.000 Locator Seal Assy. w/ 9.80’ of seals 7 9,177’ 2.992 3.500 1 Jt. 3-1/2” , 9.2#, L-80, Buttress SC 8 9,188’ 1.75” 2.67”Eclipse packer w/CRA attached top = 9,128’ w/2.5” Internal fishing neck & 2.813” OD 1.063” ID thru 9 9,210’ 2.992 3.875 Baker Mule shoe, 3-1/2” Buttress Box A 9,170’ 4.00 5.875 Baker Model “F-1” Production Pkr. Note:Holes in tubing @ 2550’, 2900’, 3050’, 3700’, and 6526 I 9,864’ Top of Fish F-1 Packer with, tail pipe, seal assy., parted cavity. Tagged at 9864’ SLM 3/28/98 10/24/2009 – Bled pressures on SS, LS, and 9-5/8, pressure returned within 24 hours. 8/16/2007 – 2.0” GR hand spanged from 59’-125’ then RIH to 9172’ SLM w/no indication of tagging. 12/7/2001 – Could not pull CRA at 9128’. Beat on assy for 30 min @ 2000# then sheared off. **Collapsed casing behind 7” scab liner. PERFORATION DATA Zone Top Btm Amt Accum SPF Last Perf Date Present Condition G-1 9,425' 9,430' 5 4 12/20/1967 9,440' 9,480' 40 4 4/26/1969 (G-1?) 9,502' 9,522' 20 3/28/1998 (G-1?) 9,527' 9,547' 20 3/28/1998 G-2 9,550' 9,605' 55 Cmt Sqz'd G-3 9,629' 9,839' 210 3/28/1998 9,839' 9,890' 51 3/28/1998 G-4 9,920' 10,070' 150 3/28/1998 Notes: x 8/14/2011 – Well circulated with 9.8 ppg KWF and (2) - 24 bbls LCM pills (No Fibers) down LS and squeezed into perforations. x 7/26-28/2011 – RIH w/ 2” GR to 9140’ (tag top of KOBE cavity). Tubing Punch from 9094’ – 9099’. x 08/2011 –Well circulated with 9.8 ppg brine and LCM pill placed. Pressures indicate well Sidetrack @ 6800’ MD Cement plug #2: Tbg: ~5233’ - ~9100’ MD IA: ~5600’ - ~9100’ MD Cement Retainer set @ ~8918’ MD Cement plug #1: 13-3/8” x 9-5/8” Annulus Down-squeezed from Surface to SC Shoe Cement plug #3: LS: Surface - ~2125’ MD SS: Surface – ~33’ MD IA: Surface - ~2125’ MD Tbg punch @ ~2125-28’ MD CIBP @ ~2150’ MD Rig Start Date End Date SL 8/17/22 6/20/23 10/17/22 - Monday Cleaning cmt out of Rain for rent tanks #1, vacuum slug out of tanks out of #2, on loading full cutting boxes onto work boat, and remove hatch for downstairs, place heaters, test pump& tote, downstairs, install hatch. Picking up and cleaning work area. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 02RD 50-733-20022-01-00 175-007 10/15/22 - Saturday Held PJSM. Arrange equipment on deck. Turn Coil reel on subbase & move injector to leg # 1. Running hard lines & control lines, roll up data cables from leg 2 & run to leg #1. Stab bops onto well DI 02 LS 10/16/22 - Sunday Back load boat with ISO, and off load empty ISO's stripping R4R tanks into ISO, and backloading ISO, cleaning cmt from rain for rent tank. Coil crew perform maintenace on equipment while waiting on Coil Supervisor Daily Operations: 08/17/22 - Wednesday Held PJSM and approved PTW. Check well pressures LS/SS/IA/OA/OOA=0/0/0/5/5. Work boat arrived, assisted crane with loads. Disconnected and swapped out the rain for rent charge pump, replaced the socks in the filter pods for the IW. Began filling uprights with FIW. Installed mist plates on the open top gas buster tank, R/u circulating line to the OA on DI-02, while waiting on tanks to fill for the cement job we injected 105 bbls of brine/oil down DI-17. R/u HAL cement unit, PT lines 2200psi (max pressure for job 1500psi). Opened OA and began pumping, catch pressure 1.5bpm after 2bbl away catch pressures, worked rate up to 4bpm/250psi, pumped 15bbls and est injection @ 4bpm/240psi. pumped 60bbls of FIW w/Surfactant Wash @ 4bpm/240psi. Mixed and pumped 50bbls of 14ppg Class G Cement w/LCM @ 4bpm/150psi, followed by 80bbls of 14ppg Class G Cement @ 4bpm/100psi. With cement/LCM @ the shoe, SD and monitored pressure falling to below 20psi, began hesitation squeeze @ .5-1bpm w/2-4bbl stages, Pump 4 bbl @ 1.5 bpm 55 psi, SD 4min, Pump 2 bbls @ 1 bpm @ 44 psi, SD 4mins, Pump 3 bbls @ 1 bpm @ 61 psi, SD 4min, Pump 2 bbls @ 1 bpm @ 70 psi, SD 3mins, Pump 2 bbls @ 1 bpm @ 93 psi, SD 5mins, Pump 2 bbls @ .5 bpm @ 88 psi, SD 4mins, Pump 2 bbls @ .5 bpm @ 66 psi, SD 5mins. Pump 2 bbls @ .5 bpm @ 97 psi, SD 5mins, SD 12mins, Pump 3 bbls @ .5 bpm @ 107 psi, SD 20mins pressure stabilized @ 40psi, Pump 4 bbls @ .5 bpm @ 111 psi, SD and SI the OA. Preformed sheen test (no sheen) Cleaned pumps and lines overboard, SDFN Total of 150bbls of 14ppg cement (550 sks) pumped Rig Start Date End Date SL 8/17/22 6/20/23 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 02RD 50-733-20022-01-00 175-007 Daily Operations: 11/04/22 - Friday CMIT TxIA with state inspector Guy Cook witnessing Pre Test 24psi Initial 2746psi 15mins 2712psi 30mins 2687psi 10/23/22 - Sunday PTSM. R/U W/L w/2" bailer, on LS. PT lub 2500psi good. RIH tag cmt @ 5233', tag witnessed by AOGCC inspector Brian Bixby. POOH R/D w/l, secure well. Recover 2 cups cmt interface. AOGCC witnessed By Inspector Brian Bixby, CMIT LS, IA Initial 2743 15 min 2662 30 min 2614 45 min 2575 OA pre-test - 0 Initial 2739 15 min 0 30 min 0 45min 0 BBLS in 3.3 BBls out 3.3 10/18/22- Tuesday PTSM, fuel & warm eq., P/U Inj. Head M/U lub. M/U connector, pull test 1k & 25k good, pressure test good, M/U cmt retainer assy., stab IH onto well. PT250/4000 good. RIH t/8918', drop setting ball, circ on seat, observe pressure increase & drop, set down wt 10k, verify setting retainer @ ~8918'. PJSM for CMT job. Prep & pump 5bbls drill water, shut in PT lines good. Pump & spot 118 bbls 14PPG class G cmt down coil spotting up IA. Un-sting from retainer & lay remaining 30 bbls cmt in tubing while POOH, t/ ~5600' (EST TOC in IA/tubing) cont. Pump OOH t/5000', CBU x2 clean, POOH laying 9.8 brine in tubing. Bump Up & shut in well, break off lubricator, recover setting ball, insp cmt stinger Good, stack out IH, secure well. Note: recovered full displacement from CMT job. Unload & backload boat, M/T 4 cmt pods into SILO's, backload MT pods. Rig Start Date End Date SL 8/17/22 6/20/23 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 02RD 50-733-20022-01-00 175-007 Daily Operations: 05/26/2023- Friday Safety Meeting-Change out day, cement operations. Get cuttings bins ready for cement job, Load E line unit on boat. Break circulation with FIW LS through IA @ 2 bpm with cement unit taking returns to diffuser tank, line up injection skid pump. Pressure test lines to 1000 psi., Spot 20 bbl. surfactant wash down LS out IA. Pump159 bbl. 14 ppg class G 4%+FCG + .3% FFL cement @3 bpm got cement returns to surface, Swap to down LS up SS pump 3 bbl. cement returns to surface, Pump down .3 bbl down OA, instant 500 psi. Shut all valves on well head wash down cement lines final strap on diffuser 51" 191 bbl. Inject 182 bbl. of well fluid from DI-2 to DI-7, 2100 on LS, 2100 IA 2100. R/u EL on LS. M/u 2.75" OD CIBP (for 3-1/2" Tbg), Setting tool, 1.69" CCL and weight bars. RIH log collar @ 2156'. P/u to CCL depth @ 2143', set CIBP @ 2150' tagged plug and confirmed set. POOH L/d setting tool. M/u 2" x 3' tbg puncher, 1.69" CCL and weight bar, RIH and punched holes in tbg @ 2125-28', POOH all shots fired. R/d EL. R/u circulating eq. Pumped down LS returns up IA @ 3bpm/500psi, freeze protected LS,SS and IA with diesel to 120'. R/d circulating eq. 11/10/22 - Thursday 06/20/2023- Tuesday Verified TOC, OOA- TOC 2" below outlet. OA-TOC visual at surface, IA-TOC visual at surface, LS-TOC visual at surface, SS- TOC visual at surface. 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: 10304 ft MD Lease No.: ADL 0018746 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 601 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 2016 Feet Csg Cut@ Feet Intermediate: 9 5/8" O.D. Shoe@ 6770 Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 10304 Feet Csg Cut@ Feet Liner: 7" O.D. Shoe@ 6536 Feet Csg Cut@ Feet LS Tubing: 3 1/2" O.D. Tail@ 9102 Feet Tbg Cut@ Feet SS Tubing: 3 1/2" O.D. Tail@ 64 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Initial 15 min 30 min 45 min Result Tubing 2746 2712 2687 IA 2746 2712 2687 OA 5 5 5 OOA 10 10 10 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: This is a CMIT retest for SMGS Di-2RD; the well was tagged on 10/23 (AOGCC Inspector B. Bixby witness). In the first 15 minutes the pressure dropped 34 psi. In the second 15 minutes it dropped 25 psi. 2.9 bbls pumped in and returned after the test. November 4, 2022 Guy Cook Well Bore Plug & Abandonment S MSG unit Dillon 2RD Hilcorp Alaska LLC PTD 175-007; Sundry 322-487 none Test Data: I Casing Removal: Wade Hudgens Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 11-28-18 2022-1104_Plug_Verification_SMSG_Di-2RD_gc 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: 10304 ft MD Lease No.: ADL 0018746 Operator Rep: Suspend: P&A: XXX Conductor: 20" O.D. Shoe@ 601 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 2016 Feet Csg Cut@ Feet Intermediate: 9 5/8" O.D. Shoe@ 6770 Feet Csg Cut@ Feet Liner 7" O.D. Shoe@ 6536 Feet Csg Cut@ Feet Production 7" O.D. Shoe@ 10304 Feet Csg Cut@ Feet SS Tubing: 3 1/2" O.D. Tail@ 64 Feet Tbg Cut@ Feet LS Tubing: 3 1/2" O.D. Tail@ 9102 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Balanced 9094 ft 5233 ft 9.8 ppg Wireline tag Pre-Test Initial 15 min 30 min 45 min Result Tubing 109 2743 2662 2614 2575 IA 109 2743 2662 2614 2575 OA0 0 000 Remarks: Attachments: Harold Soule Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): I Long and Short Tubing strings were twinned in with the IA for the test. Pressure loss was -81 psi / -48 psi / -39 psi. I told the company rep that town would make the pass-fail call. 3.3 bbls in, 3.3 bbls returned. September 23, 2022 Brian Bixby Well Bore Plug & Abandonment S MSG UNIT Dillon 2RD Hilcorp Alaska LLC PTD 1750070; Sundry 322-487 none Test Data: Casing Removal: rev. 11-28-18 2022-1023_Plug_Verification_SMGS_Di-2RD_bb 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 9 ) 7HVWUHVXOWFKDQJHGWR)$,/GRHVQRWPHHW$2*&&FULWHULDIRU SUHVVXUHWUHQGLQJWRZDUG]HURSVLWRWDOSUHVVXUHORVVIRU PLQLQWHUYDOIRUPLQLQWHUYDO-5HJJ$2*&& ,QVSHFWLRQ6XSY Pressure loss was -81 psi / -48 psi / -39 psi. James B. Regg Digitally signed by James B. Regg Date: 2022.10.27 16:43:04 -08'00' From:McLellan, Bryan J (OGC) To:Aras Worthington Cc:Roby, David S (OGC); Boyer, David L (OGC); Davies, Stephen F (OGC) Subject:RE: [EXTERNAL] SMGS-02RD (PTD 175-007) OA squeeze Date:Tuesday, August 16, 2022 2:51:00 PM Aras, You have verbal approval to proceed with the 13-3/8” x 9-5/8” OA cement downsqueeze as described in the first two steps of the sundry revision submitted on 8/16/22 for this well. You will need to wait for the approved sundry before performing the remainder of the work described in the sundry (Reservoir plug and surface plug). FYI, The sundry number assigned to this job is 322-487. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Tuesday, August 16, 2022 2:14 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] SMGS-02RD (PTD 175-007) OA squeeze Roger that Bryan. Good idea. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, August 16, 2022 12:51 PM To: Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] SMGS-02RD (PTD 175-007) OA squeeze Good plan. As long as you don’t fill up the OA with liquid, you can just fill it up with a second stage cement job. Do you want to incorporate the pump till you bump into your surface cement plug job? I mean, you can start filling up tubing and IA, pumping until you get good returns to surface, then just swing a couple valves and divert cement into the OA and pump till you bump. That way you don’t have to mix another batch of cement for an annulus that might be full already. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Monday, August 15, 2022 6:43 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Re: [EXTERNAL] SMGS-02RD (PTD 175-007) OA squeeze Bryan, As you pointed out it is very uncertain if the shoe will plug off enough with LCM to hold a column of cement. But if it does we can verify with a tag of TOC via plumb bob down the OA (or visual of cement if it doesn’t drop at all). If it doesn’t hold the column it will suck a vacuum in the OA which we can fill via cement top job. We’ve handled this before by just pumping cement again till we bump. Aras Sent from my iPhone On Aug 15, 2022, at 5:15 PM, McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> wrote: Aras, How will you be able to verify cement top in the OA? Do you think it will support a full column of cement, given how easily it’s pumped away? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. 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Haines Manager, Oil & Gas Operations Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, \ -t S- C) C.3-1 o 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 2009 Alhsk n I & Gas Cans, Nmmissior, AnrhgrF p 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, SCANNED 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 platforin life Br 14-42 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 16-42 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 1842 1680120 Apr -89 Colla sed Casing 100% water production Phase I Abandon abandon at end of platform life GP 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubing -to -casing communication Failed MIT Possible restore injection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D40RD 1820830 Se -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 I Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase I Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -4 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 2113-16 1852550 Sep -0, no known damage no flow Possible shallow gas 2011-2014 SCU 23B-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 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 T onek 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 I Abandon abandon at end of platform life Monopod A-23 1720200 Jun -8 iCollapsed 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 pl form life 1:� ATASKA. 011L AND GALS June 22, 2009 SARAH PALIN, GOVERNOR r 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 �� Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells a _ 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.gov. Sincerely, IV4�� 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 ) .~~~~! ':} ~~~~~~~ A.1~A.~1i& OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Dave Cole Oil Team Manager UNOCAL P.O. Box 196247 Anchorage,. AK 99516-6247 : 1§..(JO 1 Re: Middle Ground Shoal Unit Platforms Dillon and Baker Dear Mr. Cole: This letter confirms your conversation with Commission Engineer Tom Maunder last week regarding the multiple Applications for Sundry Approval (Form 403) you submitted in mid October regarding changing the. monitoring frequency on the 16 wells on Dillon Platform and 23 wells on Baker Platform. Production and injection operations were halted on these platforms in 4th Q 2002 and 2nd Q 2003 respectively. Attached, please fmd the Sundry Applications, which are being returned without approval"j because the relief you request needs to be sought through a different procedure. The intent of submitting sundry notices for each well was to establish a monthly pressure and general monitoring frequency for all wells on Dillon and Baker. There is a requirement in place for some of the water injection wells that pressures and rates are to be monitored daily and reported monthly. Since the platforms are unmanned and not operating, it is not possible to obtain daily information. When operations were curtailed, a monthly monitoring frequency was established in the Plans of Development (POD) annually filed with the Division of Oil and Gas and Unocal desires to assure that this monitoring scheme is accepted by the Commission. As noted in the conversation, changing the monitoring frequency where presently in place and establishing a monthly monitoring frequency in general is not an action that is best accomplished with multiple sundry notices. A letter application requesting the desired monitoring schedule should be made under the applicable Area Injection Orders (AlO 7 for Baker and AIO 8 for Dillon) and Conservation Orders (CO 44 and CO 54) for the platforms/unit. The Commission looks forward to receiving your letter applications. If prior monthly monitoring information has not been submitted to the Commission, that information should be ubmitted forthwith. . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this _day of November, 2004 Enel. SCANNED NO\; 2, 4; 200,~ 4,062' 7" / 6,242-10,304' Perforation Depth TVD (ft): J/ Tubing Size: / paCke:':~: ~:~~~:~e: 7640 to a:iJ 12. Attachments: Description Summary of ;Øposal [2] Detailed Operations Program 0 . etch 0 14. Estimated Date for Commission Representative: 17. I hereby certify that the foregoing is tr e and correct to the best of my knowledge. Contact Title Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Union Oil of California aka Unocal 1 . Type of Request: 3. Address: P. O. Box 196247 Anchorage, Ak. 99519-6247 7. KB Elevation (ft): 110' 8. Property Designation: Dillon 11. Total Depth MD (ft): Total Depth TVD (ft): 10,320' 9,994' Casing Structural Conductor Length Surface Intermediate 601' 2,061' Production Liner 6,770' Perforation Depth MD (ft): Commencing Operations: 16. Verbal Approval: Plug Integrity 0 Printed Name/. 7 D~ ~e. ç Signature Þ/éWf/ /~ (j ) STATE OF ALASKA) ALASKA Oil AND GAS CONSERVATION COMMI~"ION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: RECEiveD OCT 2004 Suspend U Repair well 0 Pull Tubing 0 Perforate LAiaska Oil 'ciWítlkPnsAmmi'à.~M U Stimulate 0 xtenAartdmage Other [2] Re-enter S pended Well 0 Monitor Frequency 5. Pe~it to Drill Number: / 7f>-7 6. API Number: Size 1,530' 520 psi 2,730 psi 1,130 psi 7,510 psi 4,130 psi 8,597 psi 5,885 psi Tubing MD (ft): LS: 9,102' SS: 64' Development Stratigraphic [2] 0 50-733-20022-01 PRESENT WELL CONDITI SUMMARY Effective Depth MD (ft): Effec ve pepthTVD (ft): Plugs (measured): IJUnk (measured): F-1 Packer with, tail pipe, seal assy., parted cavity @ 9,853' Burst 9,864' 9,876' TVD Collapse 20" 601' 2,016' 6,770' 600' 2,006' 6,663' 13-3/8" 9-518" 6,148'-9,971' Tubing Grade: LS: 3-1/2" SS: 3-1/2" Both 9.2#, N-80 Packers and SSSV MD (ft): 9,170' 13. Well Class after proposeçl work: Exploratory 0 Development 15. Well Status after proposed work: Oil [2] Gas 0 WAG 0 GINJ 0 WDSPL [2] Service 0 Abandoned 0 0 0 0 Plugged WINJ Phone 28-Sep-2004 Conditions of approval: Notify ommission so that a representative may witness Sundry Number: 30'1..373 Other: Subsequent Form Required: Approved by: 1JD7 Form 1 o~evised 12/2003 Mechanical Integrity Test 0 RBDMS BFL NOV 2 2 2004 0 Location Clearance APPLICATION RETURNED 11/17/04 NOT APPROVED BY COMMISSION ORiG\NAl COMMISSIONER BY ORDER OF THE COMMISSION Date: Submit in Duplicate STATE OF ALASKA .,.... ALASKA OIL AND GAS CONSERVATION COMMISSION t'(~ E C E .. REPORT OF SUNDRY WELL OPERATIONS FEe. IVEO PerforateAl8'k . Waiv Stimulate D < . :)ifÌrÛ!~iteBW~ ,. l Re-enter Suspend~ II 5. Permit to Drill NLi Exploratory D 75-7 Service D 6. API Number: 50-733-20022-01 9. Well Name and Number: Di-2RD 10. Field/Pool(s): Middle Ground Shoal/"G" 1. Operations Abandon Performed: Alter Casing D Change Approved Program D 2. Operator Union Oil of California Name: aka Unocal Suspend Repair Well D Pull Tubing D 3. Address: P. O. Box 196247 Anchorage, Ak. 99519-6247 7. KB Elevation (ft): 110 8. Property Designation: Di lion 11. Present Well Condition Summary: Total Depth measured 10,320' feet true vertical 9,994' feet Effective Depth measured 9,864' feet true vertical 9,876' feet Casing Length Size Structural Conductor 601' 20" Surface 2,061' 13-3/8" Intermediate 6,770' 9-5/8" Production 3,768' 7" Liner 290' 7" Perforation depth: Operation Shutdown Plug Perforations D Perforate New Pool D 4. Current Well Class: Development 0 Stratigraphic D Plugs (measured) Junk (measured) fish @ 8,802' MD TVD Burst Collapse 601' 2,016' 6,770' 6,536-10,304' 6,242'-6,536' 600' 2,006' 6663' 6,435'-9,971' 6,148'-6,434' Measured depth: 9,425-9,430' 9,440'-9,480' 9,502'-9,522' 9,527'-9,547' 9,550'-9,605' 9,629'-9,839' 9,839'-9,890' 9,920'-10,070' True Vertical depth: 7,640-7,643' 7,650-7,678' 7,693-7,706' 7,710-7,723' 7,725-7,762' 7,778-7,924' 7,924-7,960' 7,981-8,090' Tubing: (size, grade, and measured depth) LS: 3-1/2", 9.2#, N-80, Buttress @ 9,102' SS: 3-1/2", 9.2#, N-80, Buttress @ 64'. Baker Model F-1 Packer@9, 170' Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation: 19 6 150 80 Subsequent to operation: This well has been shut in subsequent to operation 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory D Development 0 Daily Report of Well Operations 16. Well Status after proposed work: Oil0 Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Contact Printed Name P. M. Ayer Signature Tubing Pressure 90 Service D GINJ D WINJ D WDSPL 0 Sundry Number or N/A if C.O. Exempt: Title Petroleum Engineer Date 18-Feb-2004 UNOCAL8 Dillon Well No. 2rd Actual Completion 1/26/98 RKB to TBG Head = 33.28' Hn r. connection: 3-1/2" 8rd 2 4 6 A 7 G1 8 1'011' 9,864' 81..M. (2-118" GUll Tag at 9,853' ELM) G3 A G3 B G4 I PBTD = 10,140' TD = 10,320' Max Hole Angle = 21.50 D-2rd 1-26-98 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20 94 Surf 601' 13-3/8" 54 Surf 2,016' 9-5/8" 40 & 43.5 N-80 & S-95 8rd LT&C 8.755 Surf 6,770' 7" 26 S-95 6,536' 10,304' 7" 29 Scab Liner 6,242' 6,536' Tubing: LS 3-1/2" 9.2 N-80 Butt. 2.992 33.28' 9,102' SS 3-1/2" 9.2 N-80 Butt. 2.992 33.28' 64' JEWELRY DETAIL NO. Depth ID OD Item 34.15 CIW 'DCB' Dual Hanger 1 9,102' 2.992 4.375 Crossover, 3-112" Buttress Box x 3-1/2" 8 rd Box 2 9,111' 2.687 4.189 Kobe, 3", "ALP" OPF Cavity SIN: 231-A-8-98 3 9,128' 2.992 4.500 Crossover, 3-112" 8rd Pin x 3-112" Buttress Pin 4 9,129' 2.992 3.500 1 J1. 3-112" , 9~2#, L-80, Buttress 5 9,161' 2.992 3.500 Pup, 3-112",9.2#, L-80, Buttress SC 6 9,170' 2.992 4.000 Locator Seal Assy. wi 9.80' of seals 7 9,177' 2.992 3.500 1 J1. 3-112" , 9.2#, L-80, Buttress SC 8 9,210' 2.992 3.875 Baker Mule shoe, 3-1/2" Buttress Box A 9,170' 4.00 5.875 Baker Model "F -1" Production Pkr. I *9,802' F-l Packer with, tail pipe, seal assy., parted cavity * TOF. 9,864' SLM 3/28/98. PERFORATION DATA Accum Last Zone Top Btm Amt SPF Perf Date Present Condition G-1 9,425' 9,430' 5 4 12/20/67 9,440' 9,480' 40 4 4/26/69 (G-1?) 9,502' 9,522' 20 3/28/98 (G-1?) 9,527' 9,547' 20 3/28/98 G-2 9,550' 9,605' 55 Cmt Sqz'd G-3 9,629' 9,839' 210 3/28/98 9,839' 9,890' 51 3/28/98 G-4 9,920'1 '0,070' 150 3/28/98 DATED: 4/18/98 BY: tcb Well #2RD DATE COMPLETED 1968 6/17 1994 1995 1996 1997 3/5 3/12 3/20 4/3 DillON PLATFORM API # 50-733-20022-01 S. MGS UNIT # 2RD WEll HISTORY EVENT Completed as an Oil Well. WL - (LS) Routine pump change found sand in pump. Unable to pressure up new pump. Bailed 1/4 cup sand off STV. WL - (LS) (Pump Trouble Shooting): Pulling STV. Well did not equalize after several attempts to shear STV equalizing pins (FL @ 700' MO) on 3/5,6,&7. Suspect fill plugging equalizing ports. Negative attempt to breakdown fill in equalizing ports with power oil manifold pressure down L string on 3/7. Swabbed well to 3600' WLM to assure STV equalized on 3/8&9. Bailed fill w/hydrostatic bailer. Unable to latch STV - only friction bite. Suspect fill entering pump cavity from casing (casing is S string side of pump completion). Recovered STV. Reverse circulated 200 bbls power oil. Ran gutless STV and jet pump. Well back on production, currently optimizing pump. STV was bailed/pulled from the well with a snorkel bailer. WL - (LS) (Pump Trouble Shooting): Pump ran 3/12 did not seal properly, unable to build pump pressure. Pump seal showed no signs of fluid washing. Well successfully returned to production 3/19 with temporary pump seal extension (+25ft) to 3-1/2" tubing at a gross production rate of 16 - 18 bbls/hr. Temporary pump seals washed out 3/20 and piston pump was ran in with normal seals. Pump unable to pressure up and only producing 11 bbls/hr gross rate, confirming suspected tubing/cavity leak above top pump seal. Pre-problem well test = 95 BOPO, 319 BWPO. WL - (LS) (Pump Trouble Shooting): Ran permanent tubing seal/packer extension on top of pump to seal in 3-1/2" tubing on 3/25. Pump operating pressure and rate indicates leak still exists. Pump unable to pressure up and only producing 11 bbls/hr gross rate. Identified tubing leak @ 6,132' WLM on 3/27 with nylon flag O:\DiIlon_ShuCin_2003\Di-2rdHist3-21-03.rttDi-2rdHist3-21-03. rtf, last revised 2/18/2004 page 1 4/25 5/27 7/24 1 0/29-31 1998 1/9-27 tool while circulating power oil down tubing with G-packoff plug at bottom of tubing. Ran jet pump. Set tubing patch from 6,1241 to 6,1451 WLM on 3/28. Pump operating pressure and rate indicates leak still exists. Pulled patch on 4/3. Tested tubing with plug at 6,1411 and 6,1181 WLM still leaking. Changed out bad flow controller. Waiting on leak testing tool arrival to identify leak location(s). WL - Circulated out pump. Set tubing patch from 6,1201 to 6,1601. Patch would not hold; pulled patch 4/23. Set tubing patch from 6,110' to 6,1601. Patch would not hold; pulled patch 4/25. Tubing patch ran 5/21 appears to successfully sealed across the tubing leak @ 6,132' WLM. Well test 5/27 with a jet pump was 84 BOPD, 355 BWPD, and 1,449 BPD power oil. Platform production rates also confirm the well's repair. Initially, a tubing patch with g- packoffs was used, but failed to seal after several tries. The successful patch used heavy wall packoffs and sealed on the first try. The patch is slickline/braided line set and retrievable. WL - Fishing WL tools. RIH W/2.6 LIB to 2,348' and jarred dwn. The impression showed wire. RIH W/JDC and pulled 40' of .108 wire RIH W/JDC and pulled 40' of .108 wire. The impression showed clean rope socket, Attempted to pull tools and failed. RIH W/JDC to 2,354' and pulled 5' of .108 wire. RIH W/blind box to 2,357' and jarred tool string dwn to 2,359'. POOH. WO - (Pull tubing patch) Resume jarring on upper packoff.. Sheared tool POOH. Added 81stem to tool string. Cut off 50' wire, tie new knot, check tools. RIH w/ GS to 6,1121 latch begin jarring, moved tools up hole 501, continue jarring up hole. OOH w/ 30' of upper packoff section. RIH w/ GS to 6,1441 WLM and latch lower packoff. POOH with 301 lower packoft section. Lay down lubricator and SDFN. Upper G-stop , upper and lower pack-off sections out of hole. One G-stop left. 60' tubing patch pulled; upper and lower G- stops pulled. Workover Summary: DAY 1-3 SET BPV, NIPPLE DOWN TREE, NIPPLE UP BOPE, RIG UP HYDRAULIC WORKOVER UNIT (HWO). CONT. RIG UP OF UNIT. SET TWO WAY CHECKS. TEST BOPE WITH STATE WITNESS. TWO FLANGES ON CHOKE LEAKING. TIGHTEN O:\Dillon_ShuCin_2003\Di-2rdHist3-21-03.rttDi-2rdHist3-21-03 .rtf, last revised 2/18/2004 page 2 SAME. 8RD THREADS IN HANGER LEAKING. RUN PORTED SUB ON TEST JOINT. TEST O.K. PULL TWO WAY CHECKS. SET BPV'S. CONT. RIG UP OF UNIT AND WIND WALLS. CONT. RIG UP OF UNIT AND WIND WALLS. DAY 4-8 ACCEPT RIG AT 0600 HRS. PULL BPV'S. PULL SHORT SRING. ATTEMPT TO PULL LONG STRING. UNABLE TO PULL SEALS FROM PACKER WITH 165K. HYDRAULICS FAILED ON JACK. ATTEMPT TO TROUBLESHOOT SAME. RESUME WORK ON LONG STRING. NO-GO. RIG UP FOR JET CUT. JET CUT TUBING AT 9,210'. RIG DOWN APRS. POOH WITH 3-1/2" LONG STRING. FINISH POOH WITH LONG STRING. PICK UP FISHING ASSEMBLY NO.1, 5-3/4" OVERSHOT. RIH WITH SAME. SET DOWN ON LINER TOP. ROTATE OFF. CONT. RIH WITH OVERSHOT. TAG AND DRESS TOF AT 9,217'. ATTEMPT TO CATCH FISH. NO-GO. UNABLE TO CATCH FISH IN OVERSHOT. POOH. CONT. POOH WITH FA NO.1. RECOVERED 2" X 18-1/2" STRIP OF METAL WADDED UP IN THROAT OF OVERSHOT. PU ASSEMBLY NO. 2,5-15/16" CONCAVE MILL. RIH. SET DOWNJH ON LINER TOP. ROTATE OFF. TAG FISH AT 9,223'. DAY 9-12 DRESSTOFMILLING 17". POOH. MILL HAD PERFECT 3-1/2" CIRCULAR WEAR PATTERN. GOOD TOF. PU FISHING ASSEMBLY NO.3, 5-3/4" OVERSHOT. RIH. SET DOWN ON LINER TOP. ROTATE OFF. CONT. RIH. CATH FISH WITH OVERSHOT. ATTEMPT TO PULL SEALS FROM PACKER. NO-GO. ATTEMPT TO JAR SEALS FREE. NO-GO. CONT. JARRING. JAR FREE. POOH. CO NT. POOH. PARTIAL RECOVERY. FOUND KOBE CAVITY HAD PARTED IN TWO. NEW TOF AT 9,277'. TEST BOPE. PU FISHING ASSEMBLY NO. 4.6" BURN SHOE, 5-3/4" WASHPIPE. RIH WITH FA NO.4. TAG LINER TOP. ROTATE OFF. CONT. RIH. SWALLOW FISH. MILL FROM 9,276'-9,324' APPEAR TO MILL UPPER SLIPS, RUBBER AND LOWER SLIPS ON PACKER. UNABLE TO PUSH FISH DOWN HOLE. TORQUE ERRATIC. DAY 13-18 STOP MILLING. CIRC. POOH. SHOE IN GOOD SHAPE. I.D. OF WASH PIPE POLISHED APPROX. 2'. PU NEW SHOE. RIH WITH FA NO.5. RIH. INDICATION OF SWALLOWING FISH AT 9,269'. WASH AND REAM TO 9,324'. MILL TO 9,326' ERRATIC TORQUE. TROUBLE STAYING ON BOTTOM. ABLE TO STACK WEIGHT WITH NO TORQUE INCREASE. CONT. MILLING. CIRC. OUT GAS BUBBLE. CONT. MILLING. SHUT DOWN PUMP AND DRY MILL. PUMP 50 BBL. PILL. CO NT. DRY MILLING. PACKER MOVING DOWN HOLE. CHASE TO 9,515'. REPAIR COUNTER BALANCE CONTROL VALVE. CHASE FISH. O:\Dillon__ShuCin_2003\Di-2rdHist3-21-03.rtfDi-2rdHist3-21-03.rtf, last revised 2/18/2004 page 3 TAG UP AT 9,859'. ATTEMPT TO SWALLOW FISH. CIRCULATE OUT GAS BUBBLE. RIH TO 9,900'. HAVING TROUBLE ROTATING PIPE AT 9,900'. PUMP 50 BBL. SWEEP. POOH. CONT. POOH. LAY DOWN FA. NO.5. RIG UP E-LINE. MU BAKER F-1, 7" PERMANENT PACKER. RIH. SET DOWN AT 6,508'. POOH. LD PACKER. PU 5.9" GAGE RING, JUNK BASKETS. RIH. SLIGHT INDICATION AT 6,508' CONT. RIH TO 9,200'. POOH WITH E-LINE. PU 7' F-1 PERMANENT PACKER. RIH. SET DOWN AT 6,508'. WORK PAST. CONT. RIH TO 9,170'. POOH. RD E-LINE. PICK UP 3-1/2" LONG STRING COMPLETION. RIH. STAB SEALS INTO PACKER. ATTEMPT TO CIRC. DOWN LS. PRESSURE UP TO 1,000 PSI. AND BLEED OFF. FOUND ICE IN STAND PIPE AT SURFACE. PULL 1 JT. ABLE TO CIRC. STAB SEALS. GOOD INDICATION. SPACE OUT AND LAND LONG STRING. DAY 19-20 RUN AND LAND SHORT STRING (1 JT.). RU SLICK LINE. RIH WITH 2.857" GAGE RING TO 9,188'. POOH. RD SLlCKLINE. SHUT IN. TEST PACKER/SEALS. NO LEAK OFF IN 15 MIN. SET BPV'S. RIG DOWN UNIT. NIPPLE UP TREE. TEST OK. RELEASE WELL TO PRODUCTION AT 2400 HRS. RU SLlCKLINE, RETRIEVE STANDING VALVE. RIH WITH 2.34" GAGE RING AND TAG AT 9,89,884'. POOH, RIG DOWN SLlCKLINE. RIG UP E-LINE RIH WITH GUN RUN NO.1, 2-1/8", 0 DEG., 4 SPF. SET DOWN AT 9,853'. PERFORATE 9,829'- 9,839',9,809-9,829'. POOH. RIH WITH GUN RUN NO.2, 2-1/8", 0 DEG. 4SPF. PERFORATE 9,799'-9,809',9,779'-9,799'. POOH. DAY 21 RIH WITH GUN RUN NO.3, 2-1/8", 0 DEG. 4 SPF. PERFORATE 9,769'-9,779',9,749'-9,769'. POOH. RIH WITH GUN RUN NO.4, 2-1/8", 0 DEG. 4 SPF. PERFORATE 9,719'-9,739'. POOH. RIH WITH GUN RUN NO.5, 2-1/8", 0 DEG. 4 SPF. PERFORATE 9,739'-9,749',9,699'-9,719'. POOH. RIH WITH GUN RUN NO.6, 2-1/8", 0 DEG. 4 SPF. PERFORATE 9,689'-9,699',9,669'-9,689'. POOH. RIH WITH GUN RUN NO.7, 2-1/8",0 DEG. 4 SPF. PERFORATE FROM 9,659'-9,669', 9,639'- 9,659'. POOH. RIH WITH GUN RUN NO.8, 2-1/8", 0 DEG, 4 SPF. PERFORATE 9,629'-9,639',9,527'-9,547'. POOH. RIH WITH GUN RUN NO.9, 2-1/8", 0 DEG, 4 SPF. PERFORATE 9,502'-9,522'. POOH. RIG DOWN E-LlNE EQUIPMENT. RELEASE WELL TO PRODUCTION. 3/28 TAG - (Pulled SV @ 9,161' KB. Made tag fill run to 9,884' KB.) RIH w/3" Kobe equalizing prong. SID @ 9161' KB Jar down. Well went O:\Dillon_ShuCin_2003\Di-2rdHist3-21-03.rttDi-2rdHist3-21-03.rtf, last revised 2/18/2004 page 4 on vacuum. POOH. Pulled SV w/equalizing prong. Prong somehow got wedged between Kobe knockouts and came out w/prong. Talk w/foreman. RIH w/2.34" gauge ring. SID @ 9,884' KB. unable to go deeper. Existing fish on bottom. 3/30 WL - Pulled SV @ 9,161' KB. Reran redressed SV. Fluid level @ 300'. 2001 9/17 Identify breach, restore completion 2002 12/06/2002 This well was shut in and isolated at the surface with multiple flanges to isolate the well from surface flow lines. O:\Dillon_ShuCin_2003\Di-2rdHist3-2 1-03.rttDi-2rdHist3-2 1-03. rtf, last revised 2/18/2004 page 5 STATE OF ALASKA ALASKA 0 -AND GAS CONSERVATION C MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: X Alter casing: Repair well: X Olher: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 100' RKB MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, AK 99519 Service: South Middle Ground Shoal 4. Location of well at surface Leg No. 1, Slot No. 5, Dillon Platform 8. Well number 739' FSL, 1,821' FWL, Sec. 35, T8N, R13W, SM No. 2rd At top of productive interval 9. Permit number/approval number 2,229' FSL, 1,166' FWL, Sec. 35, TSN, R13W,SM 75-7 At effective depth 10. APl number 2,446' FSL, 1,291' FWL, Sec. 35, T8N, R13, SM 50- 733-20022-01 At total depth 11. Field/Pool 2,449' FSL, 1,288' FWL, Sec. 35, TSN, R13W, SM South Middle Ground Shoal/"G" 12. Present well condition summary Total depth: measured 10,320' feet Plugs (measured) true vertical 9,994' feet Effective depth: measured 9,864' feet Junk (measured) 9,864' true vertical 9,867' feet 9,867' Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 601' 20" 1,285 sx 601' 600' Surface 2,016' 13-3/8" 1,200 sx 2,016' 2,006' Intermediate 6,770' 9-5/8" 600 sx 6,770' 6,663' Production 3,768' 7" 900 sx 6,536'-10,403' 6,435'-9,994' Liner 290' 7" 98 sx 6,242'-6,532' 6,148'-6431' Scab Liner Perforation depth: measured (See Attached Perforation Data Sheet) true vertical Tubing (size, grade, and measured depth) Packers Baker L~S~:3~1/2''~9~2#~L~8~~33.28~~9~1~2~(Tai~pipe@9~21~~)SS:3~1~2'~~9~2#~L~8~~33~28~~64~and ModeISSSV F-I,(type withand 4" Bore measured at 9,170'depth)SLM .. R E C ~.IV ED O~IGINAI ~ 13. Stimulation or cement squeeze summary 5 Intervals treated (measured) Treatment description including volumes used and final pressure "j~,Sk~ Oil & Gas Cons. L;0~I'QtsS~O~; :' - Anchorage 14. Representative Daily Average Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3/15/1998 74 19 245 40 80 Subsequent to operation 4/1/1998 125 26 843 40 80 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: signed: Dale Haines. ,..~ ¢..~ 0'~ I O-,,r--~ Title: Drilling Manager Date: ~/,~'4 ",'~" Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Dillon 2RD Actual Perforations 3/28/98 Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt ASPF Comments Hemlock G-1 9,425' 9,430' 0' 0' 5' 4 12/20/67 i~ Old ! :: , ! , , Hemlock G-1 9,440 ~ 9,480 0 0 40 4 4/26/69 ii Old Hemlock G-1 9,502' =: 9,522' 9,251' 9,269' 20' 4 3/28/98 ii New Hemlock G-1 9,527' ii 9,547' ii 9,274' 9,292' 20' 4 3/28/98 [New ~ 9,295 9,344' 55' 4 3/28/98 [!Cmt Sqz'd Hemlock G-2 9,550' 9,605 Hemlock G-3 9,629' 9,890' ?: 9,366' 9,599' 261' 4 3/28/98 ii New Hemlock G-4 9,920' 10,070' 9,626' 9,761' 150' 4 3/28/99 [New Hemlock G-3B 9,800' 9,844' 9,518' 9,558' 44' 4 3/1 2/85 !!i Old Hemlock G-4 9,876' i~ 9,954' i:: 9,586' 9,656' 78' 4 ~; 3/1 2/85 i~ Old Hemlock G-4 9 975' i! 10,042' ~i 9,675' 9,736' 67' 4 il 3/12/85 iiOId t:7, UNOCAL ) RKB to TBG Head = 33.28' connection: 3-1/2" 8rd TOF 9,864' SLM (~-1/8" Gun Tag at 9,853' ELM) G1 G2 G3 A G3 B G4 PBTD = 10,140' TD = 10,320' Max Hole Angle = 27.5 ° D-2rdActdraw.doc Dillon Well No. 2rd Actual Completion 1/26/98 SIZE CASING AND TUBING DETAIL WT GRADE CONN ID TOP BTM. ss 20 13-3/8" 9-5/8" 7" 7" Tubing: 3-1/2" 3-1/2" 94 54 40 & 43.5 N-80 & S-95 8rd LT&C 8.755 26 S-95 29 Scab Liner 9.2 N-80 Butt. 2.992 9.2 N-80 Butt. 2.992 NO. Depth ID 34.15 I 9,102' 2.992 4.375 2 9,111' 2.687 4.189 3 9,128' 2.992 4.500 4 9,129' 2.992 3.500 5 9,161' 2.992 3.500 6 9,170' 2.992 4.000 7 9,177' 2.992 3.500 8 9,210' 2.992 3.875 JEWELRY DETAIL OD Item Surf 601' Surf 2,016' Surf 6,770' 6,536' 10,304' 6,242' 6,536' 33.28' 9,102' 33.28' 64' ClW 'DCB' Dual Hanger Crossover, 3-1/2" Buttress Box x 3-1/2" 8 rd Box Kobe, 3", "ALP" OPF Cavity S/N: 231-A-8-98 Crossover, 3-1/2" 8rd Pin x 3-1/2" Buttress Pin 1 Jt. 3-1/2", 9.2#, L-80, Buttress Pup, 3-1/2", 9.2#, L-80, Buttress SC Locator Seal Assy. w/9.80' of seals 1 Jt. 3-1/2", 9.2#, L-80, Buttress SC Baker Mule shoe, 3-1/2" Buttress Box A 9,170' 4.00 5.875 Baker Model "F-I" Production Pkr. I *9,802' Zone Top Btm F-1 Packer with, tail pipe, seal assy., parted cavir * TOF. 9,864' SLM 3/28/98. PERFORATION DATA ACcum Last Amt SPF Perf Date Present Condition G-1 9,425' 9,430' 5 9,440' 9,480' 40 (G-l?) 9,502' 9,522' 20 (G-1 ?) 9,527' 9,547' 20 G-2 9,550' 9,605' 55 G-3 9,629' 9,839' 210 9,839' 9,890' 51 G-4 9,92,0' 10,070' 150 4 12/20/67 4 4/26/69 3/28/98 3/28/98 3/28/98 3/28/98 3/28/98 Cmt Sqz'd DATED: 4/18/98 BY: tcb Workover Summary South Middle Ground Shoal Field, Dillon 2 rd 1/9/98 -1/27/98 DAY 1 (1/9/98) SET BPV, NIPPLE DOWN TREE, NIPPLE UP BOPE, RIG UP HYDRAULIC WORKOVER UNIT (HWO). DAY 2 (1/10/98) CONT. RIG UP OF UNIT. SET TWO WAY CHECKS. TEST BOPE WITH STATE WITNESS. TWO FLANGES ON CHOKE LEAKING. TIGHTEN SAME. 8RD THREADS IN HANGER LEAKING. RUN PORTED SUB ON TEST JOINT. TEST O.K. PULL TWO WAY CHECKS. SET BPV'S. CONT. RIG UP OF UNIT AND WIND WALLS. DAY 3 (1/11/98) CONT. RIG UP OF UNIT AND WIND WALLS. DAY 4 (1/12/98) ACCEPT RIG AT 0600 HRS. PULL BPV'S. PULL SHORT SRING. ATTEMPT TO PULL LONG STRING. UNABLE TO PULL SEALS FROM PACKER WITH 165K. HYDRAULICS FAILED ON JACK. ATTEMPT TO TROUBLESHOOT SAME. RESUME WORK ON LONG STRING. NO-GO. RIG UP FOR JET CUT. DAY 5 (1/13/98) JET CUT TUBING AT 9,210'. RIG DOWN APRS. POOH WITH 3-1/2" LONG STRING. DAY 6 (1/14/98) FINISH POOH WITH LONG STRING. PICK UP FISHING ASSEMBLY NO. 1, 5-3/4" OVERSHOT. RIH WITH SAME. SET DOWN ON LINER TOP. ROTATE OFF. DAY 7 (1/15/98) CONT. RIH WITH OVERSHOT. TAG AND DRESS TOF AT 9,217'. ATTEMPT TO CATCH FISH. NO-GO. UNABLE TO CATCH FISH IN OVERSHOT. POOH. DAY 8 (1/16/98) CONT. POOH WITH FA NO. 1. RECOVERED 2" X 18-1/2" STRIP OF METAL WADDED UP IN THROAT OF OVERSHOT. PU ASSEMBLY NO. 2, 5-15/16" CONCAVE MILL. RIH. SET DOWNJH ON LINER TOP. ROTATE OFF. TAG FISH AT 9,223'. DAY 9 (1/17/98) DRESS TOE MILLING 17". POOH. MILL HAD PERFECT 3-1/2" CIRCULAR WEAR PATTERN. GOOD TOF. PU FISHING ASSEMBLY NO. 3, 5-3/4" OVERSHOT. RIH. DAY 10 (1118198) SET DOWN ON LINER TOP. ROTATE OFF. CONT. RIH. CATH FISH WITH OVERSHOT. ATTEMPT TO PULL SEALS FROM PACKER. NO-GO. ATTEMPT TO JAR SEALS FREE. NO- GO. CONT. JARRING. JAR FREE. POOH. DAY 11 (1/19/98) CONT. POOH. PARTIAL RECOVERY. FOUND KOBE CAVITY HAD PARTED IN TWO. NEW TOF AT 9,277'. TEST BOPE. PU FISHING ASSEMBLY NO. 4. 6" BURN SHOE, 5-3/4" WASHPIPE. DAY 12 (1/20/98) RIH WITH FA NO. 4. TAG LINER TOP. ROTATE OFF. CONT. RIH. SWALLOW FISH. MILL FROM 9,276'-9,324' APPEAR TO MILL UPPER SLIPS, RUBBER AND LOWER SLIPS ON PACKER. UNABLE TO PUSH FISH DOWN HOLE. TORQUE ERRATIC. DAY 13 (1/21/98) STOP MILLING. CIRC. POOH. SHOE IN GOOD SHAPE. I.D. OF WASH PIPE POLISHED APPROX. 2'. PU NEW SHOE. RIH WITH FA NO.5 DAY 14 (1/22/98) RIH. INDICATION OF SWALLOWING FISH AT 9,269'. WASH AND REAM TO 9,324'. MILL TO 9,326' ERRATIC TORQUE. TROUBLE STAYING ON BO'I-rOM ABLE TO STACK WEIGHT WITH NO TORQUE INCREASE. DAY 15 (1/23/98) CONT. MILLING. CIRC. OUT GAS BUBBLE. CONT. MILLING. SHUT DOWN PUMP AND DRY MILL. PUMP 50 BBL. PILL. CONT. DRY MILLING. PACKER MOVING DOWN HOLE. CHASE TO 9,515'. DAY 16 (1/24/98) REPAIR COUNTER BALANCE CONTROL VALVE. CHASE FISH. TAG UP AT 9,859'. ATTEMPT TO SWALLOW FISH. CIRCULATE OUT GAS BUBBLE. RIH TO 9,900'. HAVING TROUBLE ROTATING PIPE AT 9,900'. PUMP 50 BBL. SWEEP. POOH. DAY 17 (1/25/98) CONT. POOH. LAY DOWN FA. NO. 5. RIG UP E-LINE. MU BAKER F-l, 7" PERMANENT PACKER. RIH. SET DOWN AT 6,508'. POOH. LD PACKER. PU 5.9" GAGE RING, JUNK BASKETS. RIH. SLIGHT INDICATION AT 6,508' CONT. RIH TO 9,200'. DAY 18 (1/26/98) POOH WITH E-LINE. PU 7' F-1 PERMANENT PACKER. RIH. SET DOWN AT 6,508'. WORK PAST. CONT. RIH TO 9,170'. POOH. RD E-LINE. PICK UP 3-1/2" LONG STRING COMPLETION. RIH. STAB SEALS INTO PACKER. ATTEMPT TO CIRC. DOWN LS. PRESSURE UP TO 1,000 PSI. AND BLEED OFF. FOUND ICE IN STAND PIPE AT SURFACE. PULL 1 JT. ABLE TO CIRC. STAB SEALS. GOOD INDICATION. SPACE OUT AND LAND LONG STRING. DAY 19 (1/27/98) RUN AND LAND SHORT STRING (1 JT.). RU SLICK LINE. RIH WITH 2.857' GAGE RING TO 9,188'. POOH. RD SLICKLINE. SHUT IN. TEST PACKER/SEALS. NO LEAK OFF IN 15 MIN. SET BPV'S. RIG DOWN UNIT. NIPPLE UP TREE. TEST OK. RELEASE WELL TO PRODUCTION AT 2400 HRS. Day 20 (3/28/98) RU SLICKLINE, RETRIEVE STANDING VALVE. RIH WITH 2.34" GAGE RING AND TAG AT 9,89,884'. POOH, RIG DOWN SLICKLINE. RIG UP E-LINE RIH WITH GUN RUN NO. 1, 2-1/8", 0 DEG., 4 SPF. SET DOWN AT 9,853'. PERFORATE 9,829' - 9,839', 9,809-9,829'. POOH. RIH WITH GUN RUN NO. 2, 2-1/8", 0 DEG. 4SPF. PERFORATE 9,799'-9,809', 9,779'-9,799'. POOH. Day 21 (3/29/98) RIH WITH GUN RUN NO. 3, 2-1/8", 0 DEG. 4 SPF. PERFORATE 9,769'-9,779', 9,749'-9,769'. POOH. RIH WITH GUN RUN NO. 4, 2-1/8", 0 DEG. 4 SPF. PERFORATE 9,719'-9,739'. POOH. RIH WITH GUN RUN NO. 5, 2-1/8", 0 DEG. 4 SPF. PERFORATE 9,739'-9,749', 9,699'-9,719'. POOH. RIH WITH GUN RUN NO. 6, 2-1/8", 0 DEG. 4 SPF. PERFORATE 9,689'-9,699', 9,669'- 9,689'. POOH. RIH WITH GUN RUN NO. 7, 2-1/8", 0 DEG. 4 SPF. PERFORATE FROM 9,659'- 9,669', 9,639'-9,659'. POOH. RIH WITH GUN RUN NO. 8, 2-1/8", 0 DEG, 4 SPF. PERFORATE 9,629'-9,639', 9,527'-9,547'. POOH. RIH WITH GUN RUN NO. 9, 2-1/8", 0 DEG, 4 SPF. PERFORATE 9,502'-9,522'. POOH. RIG DOWN E-LINE EQUIPMENT. RELEASE WELL TO PRODUCTION. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David J o h n s,t~,~'~ DATE: Chairman January 12, 1998 THRU: FILE NO: Blair Wondzell,~/zo~/ P. I. Supervisor FROM: Lou Grimaidj, ~ SUBJECT: Petroleum Inspector AD9JAJFE.DOC BOP Test, HWC #1 UNOCAL Dillon #2 S.M.G.S. Field PTD #75-0007 1998; I witnessed the initial BOP test on HWC rig #1working over UNOCAL well #D2 in the South Middle Ground Shoal Field. I arrived to find the rig not ready to test. I made a cursory tour of the rig and its surrounding area and found all to be in good shape. I witnessed the remainder of rigging up the BOPE for this snubbing unit. The test, once started went fairly well although slowly, with all BOPE being tested and two failures observed. The inside flange on the manual choke line valve leaked and required it to be tightened then it retested "OK". The floor safety valve leaked from the key stem, A spare valve was picked up and tested "OK". The rig crew did a good job testing the BOPE and I found Sterling Bourgeois (Driller) procedure to insure a methodical test of the BOP equipment. Gene Bouqet (Toolpusher) was also on hand to help with the test. During the Accumulator test I observed a somewhat long time (4+ minutes) during the recharge portion. Although the time was barely acceptable I advised the Toolpusher to check the screens on the inlet side of the hydraulic pump. It should be noted that the test time was rather long (7 hours). Part of this is due to a slow test pump and the tightening of the leaking flange on the choke line. The rig was in Fair shape and should perform well during this workover. I enjoyed working with this crew. SUMMARY: The initial/weekly BOPE test I witnessed on rig # revealed the following; Test time 7 hours, Two Failures. ~- Attachments: A9DJAJFE.XLS CC; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initia X Workover: X DATE: 1/10/98 ~ Hydr Rig No. we# PTD # 75-0007 Rig Ph.# 776-6680 UNOCAL (Dillon Platform) Rep.: Larry McAlister D-2 Rig Rep.: Gene Bouqet(pusher) Sterling Bourgeois(driller) Set @ Location: Sec. 35 T. 8n R. 13w Meridian SEW Weekly Other ~ Test Well Sign P Drl. Rig P Hazard Sec. N/A MISC. INSPECTIONS: Location Gen.: fair Housekeeping: fair (Gen) PTD On Location N/A Standing Order Posted P FLOOR SAFETY VALVES: Quan. Pressure P/F Upper Kelly / IBOP N/A I 250/3,000 I N/A Lower Kelly / I BOP N/AI 250/3,000 I N/A Ball Type ~ 250/3, 000 F Inside BOP ~ 250/3~000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F I 250/3,000 P I 250/3,000 P N/A 250/3,000 N/A I 250/3,000 P 1 250/3,000 P 1 250/3,000 P 2 250/3,000 P N/A 250/3,000 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 9 250/3,000 P 24 250/3,000 F 1 P Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure ~ System Pressure Attained 4 Blind Switch Covers: Master: Nitgn. Btl's: Four Bottles 2200 psi average 3,000 I P ~,600 P minutes 54 sec. minutes 4 sec. X Remote: X Psig. Number of Failures: 2 ,Test Time: 7.0 Hours. Number of valves tested '/4 Repair or Replacement of Failed Equipment will be made within N/A days. otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Floor safety valve leaked, spare brought up and tested OK. Inside flange on manual choke valve leaked, ~ightened and retested "OK". - Distribution: orig-Well File c - Oper./Rig c - Database C - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Lou Grimaldi FI-021 L (Rev. 12/94) A9djajfe.xls , :~'-"~ STATE OF ALASKA '-~ _ A. KAOIL AND GAS CONSERVATION COMM._.,,ION _0 APPMCATION FOR SUNDRY APPROVALS RIG INA L 1. Type of Request: Abandon __ Suspend_ Operation shutdown _ Alter casing ~ Repair well __ Plugging ~ Change approved program __ Pull tubing __ Variance __ 2. Name of Operator ! 5. Tv~..~ of Well: . Union Oil Company of California ( N[~/e~ent__ . ! Exploratory __ 3. Address ....... ~ .... 1519 6S~[{~raphic P.O. Box 190247, Ancn. , At%, ~ -- ServiceZ / Re-enter suspended well __ Time extension __ Stimulate __ Perforate __ Other 6. Datum elevation (DF or KB) .... 7. Unit or Pr name 4.~cationofwellatsudace Leg #1, Slot 5, Platform Dillon 739' FSL, 1821' FWL, Sec. 35, T8N, R13W, SM ~top~productiveinterval 2229' FSL, 1166' FWL, Sec. 35, T8N, R13W, SM Ateffectivedepth 2446' FSL, 1291' FWL, Sec. 35, T8N, R1-3W, SM ~totaldepth 2449' FSL, 1288' FWL, Sec. 35, T8N, R13W, SM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor .561 ' Surface 'i 981 ' Intermediate 6740 ' Production 3768 ' Liner 290 ' Perforation depth: measured 8. Well number 2RD 9. Permit number 75-7 10. APl number 50-- 733-20022-01 11. Field/Pool £) r" ~' !" IS~~eml°ck r, L ~ L I v ~J.~-: ' 1 0 3 2 0 ' feet Plugs (measured) 9994' feet DEC - 9 1991 10140 ' feet Junk(measured) Alaska 0il & Gas Cons. CommiSsion 9 8 2 5 ' feet Anchorage Size Cemented Measured depth True vertical depth 20" 1285 SX 601' 600' 13-3/8" 1200 SX 2016' 2006' 9-5/8"~ 600 SX 6770' 6663' 7" 900 SX 6536'-10304' 6453'-9994' 7" 98 SX 6242'-6532' 6148'-6431' See attaChment true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3-1/2", N-80, 9244', Tailpipe @ 9345' Baker Model F-1 with 4" BORE @ 9322' feet 13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing oPeration 115. October 22~ 1991 16. If proposal was verbally approved Oil Name of approver Date approved ServiCe ,, 17. I hereby certify that/,q~ foregoing is true and correct to the best of my knowledge. ~gne GAR~ ~ DUSH Title REGIONAL 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- Status of well classification as: Gas __ Suspended __ Approved by order of the Commissioner ORIGINAL sIGNED BY LONN!E C. s~ITH FOrm 10-403 Rev 06/15/88 DRILLING MAN~ER ,....:...;:?J Appr°val N °' ~/--.,~,¢ Commissioner Date/2 -/~' ~ SUBMIT IN TRIPLICATE ~PUd Date: ~ub,urfoe. PBD: Ca~lng: Peffora~lono: InltJol PotenUal: InlUal SUmulaUon: Cored Inte~al,: DST Intervola and RiJults: Log Inventory: SOUTH MIDDLE GROUND SHOAL ADL 18746 WELL NO. 2RD HEMLOCK CONGLOMERATE PLATFORM DILLON 4,/21/75 L4g 1, Slot 5 739' FSI., 1821' ~ S~o. 35, TSN, R13W, $.M. T~ - 1288' ~ 2449' F~ ~ ~, ~N, R13W, S.M. 100' ~ ~0320' ~O g~g4' ~ I01~' UD 8825' ~ 20". g~ C~lng --t ~ 801' ~ 1~8~ ,. ~t 3 ~". 5~ ~,~g **t at 2018' ~1~ 1200 ,x. ~t ~". ~ and 43.5~ H-~ and ~-85 Ce,lng 7'. 28~ ~95 Uner ~t at 8538-10304' wl~ gO0 ~1: 9418-8423'e 9800-9844' ~-2: 0506-g~11'e ~4: 0876-8054' 9517-g~22'e 0973-10042' 9549-9554'6 ~2~ 96~98Jg'e · ~ent .qu~zed 9725-9730'e 97~-g78S'e 1692 BOP[), 483 BWFq3, 354 IdCF1} None 1. 8840--0886', cut 28% re,overed 6' 2. 8880--8808'o out 24', recovered 17' 3. 8690-8703', cut 13% no reaovery None DIL-SP, BHC-CA% FDC-OR 4---arm Dlpmeter ~ammo Rcr~ - Differential Temperature Sunmy 9/3/77 (3ammo Ray 1/28/81 Oommo R~ Long $trlng: I. lC)" Cameron Dual DC9 tubing hanger 2. 3 l/J," 13uttr~84 pup 3. 3 1/2" Buttr~, N-80 tubing 4. 3 I/2" Buttre,e pup S. 2 1/2" Kobe "E" ¢crdty ,k~n-3143 $. 2 7/8" 8RD and 3 1/2" Buttre=e XO 7. 3 I/2" Buttm=o N-80 tublng 8. 3 I/2" Buttmoo pup 9. Baker Lo¢otor one ~eal a,embly 10. ;3 I/7" Buttre** N-80 tubl, g 11. Uule~hae Short string: A, 3 1/2" Buttr~, N-80 tubing run ~ Z~z/as) Depth 34' 38' 8240' 9244' 9261' 9262' O2go' 8284' 9313' 8344' 9345' 20" g4f c~ 501' . C,~ 2016' 7- 2gt S~ab 8242-6532' 7- 28/Un~ 6770* Baker Uedel F'-I Peeker with 4" bore set et 0322' 0418-0423' 8508* 0554' I ~oe.~4-ge~g. J fl'"" I · i [~10800--0844. Togged Fill · I. Moe78' ~oo~o. 1/28/81 J~,:.' ¥;.-~i 10042. 11) 10320' South Middle Ground Shoal ADL 18746 Well No. 2RD Procedure for suspending and freeze protecting well: 1) Reverse the hydraulic pump out of the hole. Long string will be protected against freezing by power oil at this point. 2) Circulate power oil into 9 5/8" casing X tubing annulus taking returns up short string. Short string and tubing X 9 5/8" annulus will be freeze protected at this point. 3) Close all valves on the well head. 4) Install gauges on the tubing and 9 5/8" casing X tubing annulus. DEC - 9 1991 Alaska Oil & Gas Cons. Anchora0e 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-308-WF Gentlemen: Report of Sundry Well Operations SMGS Unit Well No. 2 RD 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 4, 1988, File: WEN-007-WF, transmitting our notice of intent to stimulate this well. Very truly yours, BAF/mla LTR942 STATE OF ALASKA ~ ALAS~,~ OIL AND GAS CONSERVATION COMtv,,,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator Amoco Production Company 3. Address P.O. Box 100779, Anchorage, Alaska 99510 4. Location of well at surface Leg l, Slot 5, SMGS Platform Dillon 739' FSL, ]82l' FWL, Sec. 35 T8N, RI3W, S.M At top of productive interval ' 2,229' FSL, 1166' FWL,SEc. 35, T8N, R13W, S.M. At effective depth 2,446' FSL, 1291' FWL, Sec. 35, TSN, R13W, S.M. At total depth 2,449' FSL, 12~8' FWL, Sec. 35, TSN, R13W, S.M. 5. Datum elevation (DF or KB) 100' KB MSt 6. Unit or Property name SI~S Unit 7. Well number 2RD 8. Approval number 75-7 9. APl number 50-- 733-20022-0] 10. Pool South Middle Ground Shoal -Hell ock Feet 11. Present well condition summary Total depth: measured true vertical 10,320 feet Plugs (measured) 9,994 feet Effective depth: measured l 0,1::40 feet Junk (measured) true vertical 9,825 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 601' 20" ] 285 SX 601' 600' Surface 2016' 13 3/8" 1200 sx 2016' 2006' Intermediate 6770' 9 5/8" 600 SX 6770' 6663' Production 3768' 7" 900 sx 6536' -6532' 6435'-9994' Liner 290' 7" 98 Sx 6242' -6532' 6148' -6431 ' Perforation depth: measured See Attached E E V E D true vertical Tubing (size, grade and measured depth) 3½.", N-80, @9,244', tailpipe @ 9345' A,,~.-~- 0il & Gas Cons. Commis,~ Packers and SSSV (type and measured depth) Baker Model F-I with 4" Bore set (~ 932~.ch°ra~e 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 ~bing Pressure 103 13 6 n/a 70 PSI 96 7 8 n/a 70 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 ....~; '~/~~ --~ Title Adm. Services Manager Form 10-404 Rev. 12-1-85 Date 5/20/88 Submit in Duplicate Perforation Data SMGS No. 2RD Zone G-1 G-2 G-3A HD 9,418- 9,423 9,506- 9,511 9,517- 9,522 9,549 - 9,554 9,654 - 9,659 TVD 9,176- 9,181 9,254 - 9,259 9,265 - g,270 9,297 - 9,302 9,392 - 9,397 Status Squeezed Squeezed Squeezed Squeezed Squeezed G-3B G-4 9,696- 9,701 9,725- 9,730 9,780 - 9,785 9,800 - 9,844 9,876 - 9,954 9,975 - 10,042 9,955 - 9,992 9,424 - 9,429 9,453 - 9,458 9,508 - 9,513 9,517 - 9,561 9,582 - 9,660 9,681 - 9,748 9,782 - 9,819 Squeezed Squeezed Squeezed Open Open Open Proposed RECEIVED __, APE]CO I::::RODUCTII~N COmPaNY C'NRONr'JLOGICAL REPORT DENVER REGIO~ ~ot: ~NChORAGE DISTRICT ~:~ OC./l~/Se ~me PaGE I ~ JO~ INITIATZON PEPORT~ COMPANY OPERATED - REP~I~ - CEVELOPM~NT SOUTH ~G$ UNI?-?ERT~ARYe A~OCO ~.I.: 0.~250 AUTH H~R~ZON ZONE: ~3 - SCUTH NOS UNIT-TE~TIARY~ 2 AUTN DaTE OPERATIONS COM~EACED DENVER ~EGION ~ ~CHOR~GE DISTRICT ~ 05/L9/88 **~ PAGE 2 SOUTH ~GS UkIT-TERT~aRY 2t t ~ A~OCO PROOUCTIONt " FLaC q86132-O3-Ot aPI 50?332002201? DPERaTION$= TD 10~?0 ~T~ P~TD ~OZ~O~ JO~ CO~PLETE~ REMarKS= COIL TU~ING COUND ~ILL AT ~00~0 FT USED 122BBLS OF POWER OUE TO PRESSURE RESTRIC, OF 3000PSI ?,DO - RUt PIG UP CQIL TUBING 2eSC -- RIHt RUN IN hOLE W/COIL TU~ING AND ~X EDTA ACID 2.00 - PUMP~ PUMP EDTA 8.3 ~LS PRES 1000 ~.50 - PUMPt PUMP 17 )~LS ESL ).0~ - S'Qt SQUEEZE EgTA W/POWER OIL - PRES 3000 R~TE 1-J/q TO 1/q BBL PER 1.50 - POHt ART)C COIL TUEING OUT OF WELL - WELL SI 2q HOURS JO~ INiTIaTION REPORT: DtRECTIONaL HOLE CURRENT WELL ~CTIVITY-COMPLT-O~G, D~TE Amoco Production Company P. 0. Box 100779 Anchorage, Alaska 99510 (907) 562-2147 February 4, 1987 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Attention- Mr. C. V. Chatterton File' WEN-OO7-WF Gentlemen- Notice of Intent SMGS Unit Well No. 2RD 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 stimulate SMGS Well No. 2RD. 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 RECC,.JVEO AJaska Oil & Gas Cons. Commissiot'i Anchorage "'" STATE OF ALASKA ALASK,~ OIL AND GAS CONSERVATION COMIVb,~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend ' ' Operation Shutdown '} Re-enter suspended well F-; Alter casing El Time extension Change approved program . Plugging ~ Stimulate X] Pull tubing . Amend order F. Perforate [' Other 2. Name of Operator Amoco Production Compan.y 3. Address P.0. Box 100779~ Anchorage, Alaska 99510 4. Location of well at surface Leg 1, S1 ct 5, SMGS Platform Di 1 lon 739' FSL, 1821' FWL, Sec. 35, T8N, R13W, S.M. At top of productive interval 2,229' FSL, 1166' FWL, Sec 35, T8N, R13W, S.M. At effectivedepth 2,446' FSL, 1291' FWL, Sec. 35, T8N, R13W, S.M. At total depth 2449' FSL, 1288' FWL, Sec 35, T8N, R13W, S.M. 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10,320 feet Plugs (measured) 9,994 feet 10,140 feet Junk (measured) 9 ~825 feet 5. Datum elevation (DF or KB) 100' KB MSL 6. Unit or Property name SMGS Unit feet 7. Well number 2RD 8. Permit number 75-7 9. APl number 50- 733-20022-01 10. Pool South Middle Ground Shoal - Hemlock Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 601' 20" 1285 sx 601' 600' Surface 2016' 13 3/8" 1200 sx 2016' 2006' Intermediate 6770' 9 5/8" 600 sx 6770' 6663' Production 3768' 7" 900 sx 6536'-6532' 6435'~-9994' Liner 290' 7" 98 sx 6242'-6532' 6148'-6431' Perforation depth: measured R E C E I VED See Attached true vertical Tubing (size, grade and measured depth) 3-~''2 , N-80, @9,244' , tailpipe @ 9345' Packers and SSSV (type and measured depth) Baker Model Al~ska Oil & Gas Cons. Comrni Anchorage F-1 with 4" Bore set @ 9322' 12.Attachments Description summary of proposal ~ Detailed operations program [; BOP sketch 13. Estimated date for commencing operation February 15, 1988 14. If proposal was verbally approved.~.ub~u.s~ Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed.~~.~_~../_~_-%-~_~_~' ~ Title District Operations SupervisorDate 02/0.4/88 Commission Use Only Conditions of approval Notify Commission so representative may witness I Approval No. [] Plug integrity [] BOP Test ~ Location clearance ORIGINAL SIGNED BY Approved by LONNIF P,. PM!TH Form 10-403 Rev 12-1-85 Approved Copy Returned Commissioner by order of the commission Date Submit in triplicate ;sJ'0r~ Perforation Data SMGS No. 2RD Zone G-1 G-2 G-3A MD 9,418 - 9,423 9,506 - 9,511 9,517 - 9,522 9,549 - 9,554 9,654 - 9,659 TVD 9,176 - 9,181 9,254 - 9,259 9,265 - 9,270 9,297 - 9,302 9,392 - 9,397 Status ,,,, Squeezed Squeezed Squeezed Squeezed Squeezed G-3B G-4 9,696 - 9,701 9,725 - 9,730 9,780 - 9,785 9,800 - 9,844 9,876 - 9,954 9,975 - 10,042 9,955 - 9,992 9,424 - 9,429 9,453 - 9,458 9,508 - 9,513 9,517 - 9,561 9,582 - 9,660 9,681 - 9,748 9,782 - 9,819 Squeezed Squeezed Squeezed Open Open Open Proposed W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 December 11, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: FEW-O25-WF Dear Sir: Subsequent Notice SMGS 18746 Well No. 2RD 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 made to Well No. 2RD. Very truly yours, W. G. Smith Di strict Manager Attachments JCB/dds RECEIVED Alaska Oi~ & Gas Cons. commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY IOTIC S AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Amoco Production Company 3. Address P. O, BOx 100779: Anchorage.. Alaska cJq61~l 4. Location of Well Leg 1, Slot 5, SMGS Platform Dillon 743' FSL, 1,818' FWL, Sec. 35, T8N, R13W, S.M. 7. Permit No. .... 75-7 8. APl Number 50- 733-20022-01 9. Unit or Lease Name lO. We'ri'~b~r .... 9Dll 11. Field and South Middle Ground 5. Elevation in feet (indicate KB, DF, etc.) ! 6. Lease Designation and S.erial No. Shoal Hemlock 100' vn I An/ lo'7~c 12. "~' Check Appropriate Box ~n~c~a't~lature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing r-I Perforations [] Altering Casing Stimulate E] Abandon [] Stimulation [] Abandonment Repair Well I--I Change Plans C] Repairs Made ~ ~ Other Pull Tubing [] Other [] Pulling Tubing {~ [] [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Between November 22, 1985 and December 4, 1985, Amoco Production Company: e 9. 10. 11. 1. Nippled down tree, nippled up BOP's and tested. 2. Pulled tubing. 3. Fi shed bottomhole pump assembly. 4. Pressure tested packer to 1,500 psi. 5. Swaged out casing at 6,458 feet to 8½ inches. 6. Ran 7 joints 7-inch 20-pound butt casing liner from top of old liner at 6,532 to 6,242 feet. Cemented with 20 bbl class G, reversed out 9 barrels. 7. Tagged cement top at 6,239 feet. Drilled and washed out to packer at 9,322 feet. Tested packer to 1,800 psi. Ran tubing and bottomhole assembly. NDBOP's, NUTREE and tested. R E C E I V E D Returned well to production. 14. I hereby certify that ~Z]a~ Signed ~ v The space below for Commission use the best of my knowledge. Title F)i ~.tri rf M~nRn~w Conditions of Approval, if any: A~ask~ Oi~ & 6as (;0ns. Commission Anchorage D.~2/~ ~ ~ Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 November 21, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File' FEW-O14-WF Dear Sir: Notice of Intent SMGS Unit Well No. 2RD 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 make the necessary repairs to Well No. 2RD,'Platform Dillon. Very truly yours, W. G. Smith Di strict Manager Attachments JCB/dds RECEIVED Oi~ & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUI I RY NOT CF.S AND REPORTS ON WELLS 1. DRILLING WELL [] ' '2. Name of Operator Amoco Production Compan~v COMPLETED WELL ~, OTHER [] 3. Address P. 0. Box 100779, Anchoraqe, Alaska ]¢. Location of Well Leg 1, Slot 5, SMGS PlatfOrm Dillon 743' FSL, 1,818' FWL, Sec. 5. Elevation in feet (indicate KB, DF, etC.) 100 ' KB 12. 99510 35, T8N, R13W, S.M. 7. Permit No. 75-7 8. APl Number 50- ,733-20g72-0! 9. Unit or Lease Name SMGS Unit 10. Well Number 6. Lease Designation and Serial No. ADL 18746 Check Appropriate Box To Indicate Nature of Notice, RepOrt, or Other Data 2RD 11. Field and Pool South Middle Ground Shoal Hemlock NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate . E] Abandon E] Stimulation I-] Abandonment Repair Welt ~] Change Plans [] Repairs Made [] Other r'-I Puli Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). In November, 1985, Amoco Production Company plans to' 1. Circulate and kill well. 2. Nipple up BOP's and test. 3. Pull tubing and stuck pump. 4. Repair casing' tear at 6,458 feet. 5. Run tubing and new pump assembly. 6. Nipple up tree and test. 7. Return well to production. RECEIVED NOV 2 6 1985 Alaska 0ii & Gas Cons. Commission Anchorage 14. I her hat the~fore,g6)n nd correct to the best of my knowledge. Si,ned "f~~/h~c] it/-~ ~i,,e D,,~r, ct ManagpY' The space below for Commission use Da]e1 Conditions of Approval, if any: Appro~d bv COMMISSIONER Approvec~ Copy Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 October 23, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: TJZ-371-WF Dear Si r: Subsequent Noti ce SMGS 18746 Well No. 2RD 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 made to Well No. 2RD. Very truly' yours, N. G. Smith District Manager Attachments JCB/dds RECEIVED Alasi<a Oil & Gas Gons. Oommissmr~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOTiCeS AHD RI.PORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Amoco Production Company 75-7 3. Address 8. APl Number P. 0. Box 100779, Anchorage, Alaska 99510 s0- 733-20022-01 4. Location of Well Leg 1, Slot 5, SMGS Platform Dillon 743' FSL, 1,818' FWL, Sec. 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 100' KB 12. I 6 . Lease Designation and Serial No. ADL 18746 9. Unit or Lease Name SMGS Unit 10. Well Number 2RD 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 [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10~,O7 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). On October 2, 1985, Amoco Production Company: 1. Rigged up a coiled tubing unit and pressure tested. 2. Pumped 199 barrels fresh water mixed with 32 pounds per barrel Na2H2 EDTA into the open perforation intervals 9,800 - 9,844 feet, 9,876 - 9,954 feet, and 9,975 - 10,042 feet. 3. Rigged down the coiled tubing unit. 4. Returned the well to production. RECEIVED Alaska Oil & Gas C0r~s. C0mm/ssj0, AnChorage 14. I hereby certify that t. be/l~orego,~g is true and correct to the best of my knowledge. ,' ' District Manager Signed ~' "~¢:~/' ~/'~/~'~~ Title The space below for Commission use DatlO/23/85 ?-¢7,,--f'-,/ i Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev, 7-1-80 Subml! "Intentions" in Triplicate and "Subsequent Reports" in Duplicate W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage. Alaska 99510 907-272-8471 September 27, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: TJZ-340-WF Dear Sir: Notice of Intent SMGS Unit Well No. 2RD 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 acid treat the perforation interval in the subject well. We plan to commence this work in ~r~]1985. Very truly yours, W. G. Smith Di strict Manager Attachments JCB/dds RECEIVED SEP 3 0 Alaska Oil & Gas Cons. Commission Anchorage ~" ' STATEOF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~' OTHER [] 2. Name of Operator Amoco Production Company 3. Address P: O: Box 100779, Anchorage~ Alaska 99510 4. Location of Well Leg 1, Slot 5, SMGS Platform Dillon 743' FSL, 1,818' FWL, Sec. 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 7. Permit No. 75-7 8. APl Number 5o- 733-20022-01 9. Unit or Lease Name CM~C 11.4+ 10. we~ ~'"'~er ..... ORD 11. Field and Poo~T South Hiddle Ground Shoal Hemlock 100' 12. ,xu Check Appropriate Box '~(~ ~'ndlca{e I~ature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ^¢1~ 5,~EE~E ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (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). Between g~~e'rfa3- ~r 8, Amoco Production Company' 1. Rig up a coiled tubing unit and presSure test. ,2. RIH with coiled tubing unit to 10,050 feet. 3. Pump 225 barrels of fresh water mixed with 7,200 pounds Na2H2EDTA. The open perforation intervals are 9,800 - 9,844 feet, 9,876 - 9,954 feet, and 9,975 - 10,042 feet. 4. Rig down the coiled tubing unit. 5. Return the well to production. o~ ~'¢~rm Ho.l' -- ' 14. I hereby ce~ th~p~'reg~is true and corr~to the best of my knowledge. Signed Title District Ma. pager The space below for Commission use Date 09/27/85 Conditions of Approval, if any: Approved by. Approved Copy Returned .._/o- ,/-o~,5 By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate W. G. Smith District Manager March 19, 1985 File: TJZ-O92-WF Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Si r: Subsequent Notice South Middle Ground Shoal Unit 18746 Well No. 2RD 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, to notify you of work recently completed on SMGS 18742 Well No. 2RD. Any questions concerning this may be directed to Jeff Blagg in our Anchorage office at 272-8471. Very truly yours, District Manager Attachment JCB/dds RECEIVED .t , 985 Alaska Oil & Gas Cons. Cor~missior~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Amoco Production Company 75-7 3. Address 8. APl Number P. O. Box 100779, Anchorage, Alaska 99510 so- 733-20022-0] 4. Location of Well Leg 1, Slot 5, Granite Point Platform Dillon 743' FSL, 1818' FWL, Sec. 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 100' KB 12. I 6 . Lease Designation and Serial No. ADL 18746 9. unit or Lease Name SMGS Unit 10. Well Number 2RD 11. Field and Pool South Hiddle Ground Shoal Unit 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 J~' Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made J:~ Other [] Pull Tubing [] Other [] Pulling Tubing J~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly ~tate all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Between February 20, 1985 and March 3, 1985, Amoco Production Company: 1. Circulated and killed- well. 2. Rigged up wireline and lubricator, tested to 2,500 psi, pulled standing valve, 'rigged down wireline. 3. Set back-pressure valves, rippled down tree, rippled up BOP's and tested, pulled back-pressure valves. 4. Pulled well, milled out packer at 9,350', cleaned out to 10,140'. 5. Ran Gamma Ray and cement bond logs from 10,000' to 8,880'. 6. Squeezed perforations 9,418' - 9,824' with 100 sx class G at 3,000 psi. 7. Perforated the following intervals with 4 JSPF: 9,800' - 9,844' 44' 9,876' - 9,954' 78' 9,975' - 10,042' 67' 8. Set packer at 9,325'. Ran hydraulic lift assembly. 9. Set back-pressure valves, rippled down BOP's, rippled up tree pulled back-pressure valves, i/j Placed well on production. Alaska. Con.~ ~'~. 10. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,gned ~J.~,.~-~A~.'~ /q('~~, Title District mallager The space below for Commission use Conditions of Approval, if any: '~"Chorage-' ,,umr, ~ate03/19/85 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 W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 February 7, 1985 File: TJZ-O50-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Notice of Intent South Middle Ground Shoal Unit 18746 Well No. 2RD 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 pull tubing, run a gamma ray and cement bond log, cement squeeze zones of water breakthrough, and perforate additional pay in SMGS 18746 Well No. 2RD. We plan on commencing this work during February 1985. Any questions concerning this project may be directed to Jeff Blag§ in our Anchorage office. Very truly yours, W. G. Smith District Manager Attachment JCB/dds RECEIVED l:.'E 0 8 1985 ~las~a Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COb, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of. Operator Amoco Production Company 3. Address P. O. Box 100779, Anchorage, Alaska 99510 4. Location of Well Leg 1, Slot 5, Granite Point Platform Dillon 743' FSL, 1,818' FWL, Sec. 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 100' KB 12. I 6 . Lease Designation and Serial No. ADL 18746 7. Permit No. 75-7 8. APl Number 50- 133-20022-01 9. Unit or Lease Name SMGS Unit 10. Well Number 2RD 1 1. Field and Pool South Middle Ground Shoal Unit Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well ~ Change Plans [] Repairs Made [] Other Pull Tubing ~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). In February, 1985, Amoco Production Company plans to: Circulate and kill well. Rig up wireline and lubricator, test to 2,500 psi, pull standing valve, rig down wireline. 3. Set back-pressure valves, nipple down tree, nipple up BOP's and test, pull back-pressure valves. 4. Pull well. Mill out packer at 9,350', clean out to 10,140'. 5. Run gamma ray and cement bond logs from 10,140' - 9,000'. 6. Cement squeeze zones of water breakthrough determined by GR log. 7. Se 10. Perforate the following Hemlock zones with 4 JSPF' ~ 9,378 - 9,388 10' - RECEIVED 9,768 - 9,844 76' 9,876 - 9,954 78' FE~ 0 8 ]985 10,028 - 10,042 14' 196' Alaska 0il & Gas Cons. C0mmissi0 Run a hydraulic lift pump assembly. ~c~rage Set back-pressure valves, nipple down BOP's, nipple up tree, back-pressure valves. P1 ace wel 1 on producti on. S~l~s~,~t Work lBcl~e~l 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~.~' ~'~.~/~l /'/~/~_. Title District Manager The space below for Commission use Conditions of Approval, if any: Approved by COMMISSIONER ~eturn~ ._ By Order of the Commission Date02/07/85 Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate (AMO00) Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 G. J. Ross Area Superintendent July 16, 1975 File: GJR-603-WF Mr.'O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Monthly Report of Drilling and Workover Operations SMGS Unit Well No. 2 i'"',i~ ~-';~_,, ~'.~,~u,,,, j .~ SMGS Unit Well No. 9 N,~ Attached herewith are the State of Alaska Forms P-4 furnishing monthly workover operations information for South Middle Ground Shoal Unit Well No. 2 and South Middle Ground Shoal Unit Well No. 9. Very truly yours, Supervisor in Charge Attachments BI¥1SIOI I OF OIL AND GAS Fm-m No. P---4 ~, 3-1-70 STATE OF ALASKA SUB~ IN mm. ~.ICAT~ OIL AND OAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPERATOR Amoco Production Company 3. ADDRESS OF p. 0. Box 779, Anchorage, Alaska, 99510 4 bOCA~ON OF WELL Leg 1, Slot 5, SMGS Platform "D", 743 FSL, 1818 FWL, Sec. 35, T8N, R13W, S.M. NUMERICAL CODE 50-133-20022-01 LEASE DESIGNATION AN'D SEHIAL ADL-18746 ? IF INDIA}~. ALOTI~- OR TRIBE NAME 8. L,~IT FAr/~ OR LEASE NAME SMGS Unit 9 WF-T.T, KO 2RD i0 F~l~..!_.r) A-ND POOL, OH WILDCAT South Middle Ground Shoal ll SEC . T.. R., M (HOT'TOM HOLE o~ Sec. 35, T8N, R13W, S.M. 12 P]~qJVIIT N'O 75-7 REPORT TOTAL DEPTH AT END OF MONTH. CHA~NGES IN HOLE SIZE, CASING AND C~VlF~N-IuNG JOBS INCLUDING DEPTH SET AN~ VOL~ USED, PEP~OHATIONS, 'rESTS AND HESULTS FISHING JOB~ JIL'NK IN HOLE AND SIDE-TRACKED HOLE A-~D A~Y OTHER SIGNIFICANT CH.A.N~ES IN HOI~E COI~-DITIONS S-mmary of Operations for June 1975: June 1-3 Waited on cement. Cleaned out cement stringers from 5616' to 6537'. Tested liner lap to 1500 psi. Tripped in with 6" bit and tagged plug at 10,140'. Displaced well with filtered sea water. Displaced sea water with power oil. Laid down drillpipe and attempted to run cement bond log. Could not get past liner top. Tripped in and cleaned out liner lap. Tripped in and pushed junk to 10,090'. Ran Gamma Ray-correlation- variable density cement bond log from 6400-10,074'. Ran gyro 1900-10,067 with 100' stops. June 4-10 Set Baker Model F-1 production packer at 9350'. Ran and landed Kobe cavity on single string 3-1/2" tubing. Ran second string of 3-1/2" tubing and hung off open ended at 502'. Nippled down BOPs and nippled up tree. Tested tree to 2500 psi. Perforated 9891-9896', 9909-9914' and 9975-9985' with 4 SPF. Attempted to acidize but pressured up to 4600 psi at rate of 0.5 BPM. Perforated the following intervals at 4 SPF: 9418-9423 9654-9659 9506-9511 9696-9701 9517-9522 9725-9730 9549-9554 9780-9785 9819-9824 (continued) stam~-g~ (L.'~f-'Z~-'/-Z~'~"Z/~'~r~ Supervisor in Char~ge ~ 7-16-.75 Ni(E--Rel)ort on this form is recluired '°re/~o~ calendar ~.,h, regQrdlfl, oft,e .,otus o, operations, and ..,, ~ tiled In dupli=te oil and gas conservation commiflee by the 15~ of the suec~ding mfl~, ~le~ otherwisa directed. Form No. P-4 State of Alaska Amoco Production Company SMGS Well No. 2 RD Page 2 June 11-16 ~ ~InS~l~ Kobe Type "E" hydraulic pump and began production testing. 24 Hour Test Results: FINAL REPORT BOPD 1672 BWPD 463 MCFD 354 GOR 212 Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 G. J. Ross Area Superintendent June 17, 1975 File: GJR-512-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Monthly Report of Drilling and Workover Operations MGS 17595 Well No. 5 SMGS Unit Well No. 2~ Attached herewith are the State of Alaska Forms P-4 furnishing monthly workover operation information for Middle Ground Shoal 17595 Well No. 5 and South Middle Ground Shoal Unit Well No. 2. Yours very truly, George J. Ross Area Superintendent Attachments DtV:$1ON O}: OIL AND GAS ANCHORAGE :PoTm ~To, P.-4 ~', ~- I-?0 STATE OF~ ALASKA OIL AND GAS CONSERVATION CON~II-i'EE SUBMIT IN DUPLICA'I~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS i._, WELL wELL OTHER ~I~ATOR Amoco Production Company ~ P. O. Box 779, Anchorage, Alaska 99510 ~ Leg 1, Slot 5, SMGS Platform Dillon, 743' FSL, 1818' FWL, Sec. 35, T8N, R13W, S.M. AP1 NUAiERICAL CODE 50-133-20022-01 LEASE DESIGNAT/ON AND SE1RIAL NO. ADL-18746 ~ IF INDIA~ ALOTTEE OR TI~IBE NAN~E 8. L,~IT FAIR~I OR LEASE NAME SMGS Unit 9 WELL NO 10~ A_ND PC~)L, OR %VILDCAT South Middle Ground Shoal ~f£ s~c, T.. R. M. (BoTTOM ~O12g Sec. 35, T8N, R13W, S.M. _ 12 P~GMIT NO 67-27 -'"--------' INCLUDING DEPTH · 13. REPORT TOTAL DKPTH A'r END OF MONTH, CHA~NGES IN HOLE SIZE, CASING ANT) CEMENTING JOBS SET ~ VOLU1VIE~ USED. pEI{FO.P~ATIONS. %-ESTS ~ F. ESULTS FISHING JOB~ JI/NK IN HOL~ AND SIDE-/q~ACKED HOLE A,HD A..,%TY OTHER SIGNIFICANT C'H. ANGF,$ IN HOI.~ CONDITIONS May 1-4: Summary of Operations for May 1975: Waited on cement and tripped in with bit. Tagged soft cement at 6756', pumped out to 6765' (5' below top of window), and drilled to 6787'. Tripped out and tripped in open-ended to 6787'. Spotted 60-sack cement plug and waited on cement. Tripped in and drilled hard cement 6735-6765'. May 5-19: Oriented dyna-drill at 6765'. Directionally drilled and surveyed 6765-9640'. (Survey details will be given on final report.) May 20-25: May 26-28: May 29-31: Cored 9640-9703'. Laid down core barrel and tripped in with drilling assembly. Drilled from 9703-10,320' and tripped out to log. Ran IES from 6764-10,310', top of G-1 9380', bottom of G-4 10,050'. Ran density log 10,311-7350'; sonic log 10,311- 8250'; 4-arm dipmeter 10,308-6765'. Tripped out and laid down drillpipe. Picked up and ran 3768' of 7" 26 lb/ft S-95 liner. Landed liner at , ' 10,304' with top of hanger assembly at 6536'. _Cemen~ed liner with 570 sacks Class G cement with 2% g~~. ~ ! i ~ E ~ follow with 330 sacks Class G cement. DIV:SION O i.: Ol~ AND GAS ANCHORAGE 14 I hereby ce~*tify that the ~oregoi~g~e and correct -- ~ ~ · ~-Yn,~. ~x. ~4~~ =r~ Area Su erin ,,~ June ii, z~,o NOTE--Repot on this fo~ il required for l~Ch calendar ~nths regardless of the status of operations, and must ~ flied in dupli~te wit~ tho oil and gas conservation coomiflee by the 15~ of the suec~ding ~n~, ~le~ OtherwiRe directed. G. J. Ross Area Superintendent June 18, 1975 File: GJR-522-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99504 Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 Gentlemen: Re: Completion Report for SMGS Unit No. 2 Redrill Attached is the State of Alaska form P-7 and supplemental information concerning the final completion of SMGS Unit No. 2. The date of the official test is June 16, 1975. Very truly yours, George J. Ross Area Superintendent Attachments D,~L':SI.OI4 OF OIL AND O;..,. ANCHORAGE Form P--7 I. I I WELL COMPLETION OR RECOMPLEiION R~PORT AND LOG* .. la. TYPE OF WELL: on, ~-~ WELL WELL ~ ~DR~ Other- b. TYPE OF COMPLE~ON: ~ Redrill WELL OVER EN BACK ~SVR. Other ~ - ~ .i. , ~ , 2. NAME OF OPERATOR ~oco Prod.uctipn,.ComPagy - ._, } , _. P. O. ,Box( 779, :(~A~ch~r~ge, ~aska 9~510 ~ LOCATION '0F W-EL~R'~ort-loeatid~ clearl~"andi~ ~cordane~ wi~h anY:~tate requirements)* At' top prOd. interval rep~ted,b~w "I 218.9 -FS~ -~ :- ~2450 FSL 10304 ~ - 1.. !0080~ : -,.~ ,1~3.. ': .::;:., ] - ~. PRODUCING ~VAL(S), OF. ~S O~TI~P, ~OM, N~E (~ AND ~)* -- G unit LOwe~ Ka-nai Co~lo~$ra~e _ - .9380--10050 ,-[-~':''~ :~ '--'rigs,-kR-sonic,f-D~nait~, ~DiPmeter,;: 'cement Bond Log ~ -~ F- CAS~ RE~ all set (Re~ ~tri~s in we'll) SUBMIT IN Dtrp).I, ! .., ~ATE OF ALASKA ',s~e ,,t,,~ l--I' ! : structions on ~ : -' OIL AND GAS CONSERVATION COMMITTEE reverse side~ [ ~.~avz ~taw. mv,~c,a~ Coo~ 50-133-20022-01 i8. AND SHRLAJ_, NO. LEASE DES!~NATLON ~L-18746 ~. ~ ~, ~~ OR TRIBE N~ ~. ~m~,~ ~ ~SE SMOS unit 10) r~ ~P~L; OR W~CAT ~Sough ~ddle Ground ShOal ~ o~w5 See; 35, ,T8~, R13~, S.~. ~.:: 75-7 . RTl GR, ~)']17: ~. CASINGHEAD ~ ~ i~,: 77' MSL , iNTERVAL~ DRILLRD BY WAS DIRECTIONAL SURVEY MADE Yes j.. ~ rz~ ._ [ I Ill il ~,a~S~IG SiZE "' ] ~ WEIG.]I~, LB/FT. ~/:!.~G~DE/:~I DEi:~FH ~T. (~) 13:-5/8d :' / .54,5# [(:JE-555/ 201~i ~ g7-1/2',' 1200 sx ' ' 26. '? LINER ~CO~ .' cj- ~ 7" : -6536' 'i03063 ~ ~60 SX 3-1/2" 9350 9350 r I ' . [ ]- I ' [i I i ~ Ii [ II [[ 28. PE~O~TIONS OP~ TO PRODUC ~O~: (Inte~al size ~d humbe{) [ 29 ACID, SHOT, ~'U~, C~T SQU~ZE, ~C. : - see attadhed list ' [ . see attached list ~' I I I I - 1 I : I ~'1 I ~. "~ :' - ~DU~ON ~ .... - ' DATE FIRST P~ODUC~ON [ ~ODUCT!ON METHO'D (Flowing, gas lii~', pump~g~siz~ and type 6-~-75 :'[ 2-~/2'L E Kobe Hydraulic Pump -. [ on pump '- 6-16-751 :. 24_..' I open t ~-. OW, ~B~G ]CaSinO r~s~ ig~L~~ OI~BBL. ; GA~. WA~BBL. [OIL GRAVITY-~I (C~.) ~. ' ' ~-~OUR ~ , ' . . : a0 psi ] S0 ,psi t - ' ' 1672 ' 354 463 38 81. umvos~io~ ov oas (~otg, u, eg for.fuel, ve, teg, etc.) sold and fuel ' ]TEST WITNESSED BY 32. LIST OF ,TTICHMENT8 ~. ; ~ , .... . --I ' 3 . I hereb~ eert~ that the~ore~oin~attaehed information Is complete and eorreet asl4e~mlned from all:available r~d~ ~ k~ ~ ~ .... ' ' ' -~ ~ :' ~ "' .......... f~r' --'l i&:m,, .' / *(see Instructions and $p=cel plugged bac~ to INSTRUCTIONS General: This form is designed for submitting a, complete and correct well completion report end log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in ather spaces on this form and in any attachments. . Items 20, and 22:: If this well is completed for separate production from more than one interval zone (~ult]ple completion), so state in item 20, and in item 22 show the prcclucing interval, or intervals, 't0p(S),:. bottom(s) and name (s);(if any) for only the interval reported in item 30. Submit a separate report (page} on this form, adequately identified, for each ad6itional intel val to be seperately produced, show- ing the adiditional data pertinent to such interval. 'Item26: "Sacks Cement": AttaChed supplemental records for this well should show the details of any mul- tiple;.'~tage cementing and the lacation of the cementing tool. .Itemh2~8: Submit a separate completion report oh ~.his form for:each interval to be separately produced. (See!'i~struction for items 20 and 22 above). '~ 4..I~A~Y O1~ ]L~OP,.MATiON jTF_.~TS~iNCLUDiN(i INTERVAL TE, STED, PH~URE DATA ~ ~OV~ OF OIL, GAS, ' WA~ AND MUD .1. .Perfs.. .9891-g6'.. . , 9909-1~~ slight blow ,, , ' , pump'test recovered only power o51 . Lower Kena5 9380 ,~ Conglomerate i"~... : -.. . DATA. A~CII BRIE~ D~CRIPI~ONS OF LITfIO~GY. POHOSlTY. FRA~R~. APP~T DI~ .... . : AND D~CEC~EI) StlOWS OF OIL, G~ OR WA~. . .. .. . - ~ ~ I ~ , '~ . . · - ,. , · ~ :~see:iatthched- Core analys~s report . . ,.. · , SMGS Unit No. 2 Redrill Section 28 - Perforations (4SPF) 9418-23. ~9725-30 9506~11 9780-85 9517-22 9819-24 9549-54 9891-96 9654-59 9909-14 9696-9701 9975-85 Section 29 - Acid, Squeeze, Etc. 9145-10360' Squeezed with 150 sacks (abandonment of unused portion of existing wellbore) 6990' Squeezed with 200 sacks (window area) DIV:SION OF OIL AND GAS ANCHORAGE 4/21/75 .4122175 4/26-29/75 4/29-5/3/75 5~4~75 5122175 5/23/75 5~24/75 5128175 513o175 615175 617175 619/75 6/11/75 SMGS Unit No. 2 Redrill History Set cement retainer @ 9080' and squeezed existing perfor- ations (9145-10360') with 150 sacks of cement. Perforated @ 6900 amd 6600 and attempted to circulate cement between perforations.- Pumped 200 sacks. None came out upper perforations. Mill out window from 6760-6824. Attempt to spot kickoff Piug. Good hard plug was finally established on the third try. Kicked off and drilled to core point (9640') Cut core No. 1 (9640-9666'). Cut 26' and recovered 6'. Cut core No. 2 (9666-9690'). Cut 24' and recovered 17'. Cut core No. 3 (9696-9709'). No recovery. Drill to TD (10304'). Run open hole logs. Run liner and cement top to TD (6536-10304'). PBD - 10080'. Perforated G-4 zone @ 9891-96 and 9975-85'. Put well on test. No production. Attempted an acid job through the hydraulic pump bottomhole assembly. Could not put anything away. Perforated the interval 9418-9985'. Well flowing? Ran pump and commenced production. DIV:SION OF OIL Al,ID GAS ANCHORAGE CHEMICAL & GE~OLOGICAL LABORATORIES OF ALASKA, INC. TELEPHONE (907) 27.9-f ' i~.O. BOX 4-1276 0" 2603 ARCTIC BLVD. ANCHO"AGE; ALASKA'99509 '.ompany ~?ell No. ~'ield :ounty ~tate. CORE ANALYSIS REPORT Amoco Production ,Company ._ SMGS #2 Re-drill Alaska , I -11 Il I , , , C--Crack F~Practure H--Horisoutd O--Op~ )3ate June 13, 1975 Location Formation_. Depths~ , Drilling Fluid . · LEGEND NIP--No J'~re IS---lnmu~ficlent Smmple , Lab. N0,31_47. i. St--$~Jn Vu--Vup HC VHC HC OEP'TM, Iflrr 9642-43 9643-44 9645-46 9646-47 9666-67 -, 9667;68 9668-69 9670-71 9671-72 9672-73 9673-74 9674-75 9675-76 9676-77 9677-78 .9679-80 9680-81 EPPKCTIVK" pOI~OSITY . PERCENT 13.1 11.0 18.6 19.4 19.7 22.2 18.7 13.6 24.4 18.9 20.7 21.8 8.1 .' PERME& BII,.IT¥ 1411.1.1DAliC I El HORIZONTAL. ...... .3C 5000+ 5000+ 35 ll 43 58 47 39 48' 56 27 40 4.8l 47 21 74 VERTICAL '.19 3000 5000+ S, ATURATIOKS RESIDUAL, 011,. 'Trace 5.9 TOTAL. 1~ ATE N' 60.7 48.6 COKNAT£ WATER 18 7,96 lO 56 29 37 4O 47 19 33 3.90 31 20 53 · · d 11,7 10.5 9.3 8.7 40.5 39.7 42,8 ' 49.3 9.7 10.3 12.5 14.6 13.3 14.0 13.6 1,O 40.7 36.4 40.7 43.1 40.9 41,1 47.4 59.8 10.6 0.8 0.3 47.6 57.4 69.3 DIV:SICIq A~ IOI. UE l/ I T 'I1' MUD ACID GF OIL .~ CHORAG ,m % AClP o o ND GAS D RECTIONAL SURVEY REPORT FOR .l GYROSCOPIC MULTISHOT TYPE OF SURVEY: 0 ,y,l'O .... A~CHOR '~ SURVEY DEPTH: FROM 17,00 ~.AS~? SMGS Rmdr~ ] 1 REm.~: SMG$ COUNTY/PARISH Kenai , DATE OF SURVEY .-6-~-75 OFRC£: ,,, , An.chorage. A~'laska FT. TO 10,067 .,, FT. WELL NO. 2 ...... .. STATE -'OB NO. Su3-,16987 ..... q-5 ...... S' ...... 3 3 .... 6[<OCU PF.C,DL"CT~ .... x; COi,:F~,'~,.:Y DATE '~ ~ '" _ ~'"-'z"T" C. ATE SLiF. k,E~ G[~x. OMCC..~iC ?<bLTISHOT S~V v "L'= 5~.;~ K~LLY :~= ~LEV, , . .. .................................................................................................................................................................................. r ..................................................... ' '"' .:::'3 -. - TOTAL ..- T$~UE ~L;~-SEA COURSE COURSE OCS LES '~- T ~ '~' . -' ..' " :.:G~L D~p-'u ....................... n -~ ................ ~ ............ "<~ '~ .... ...-':' ,,.~T~/~ ~,. ,,, ~A,.T/,: ~S1 ~C'TI ~:~'-"~ ~ I,, ,:Er:T7 ................................ UEgT~.[' uEG ........ ~T'[q z.~::~Ec.~ K:m~:/ibC ='~m ":-"?Gr'~ ....... ff'~ ...... ==~ 77 , 95 £!7 -' SO--' 13 ...... : 93 ':.8" Z..~ VERTicAL -- i-¢i ...... + ..... , .,.'-' 7c -. t · -' 75: 7-' . ?" ' :-5 7' , ?: 77 · _) SFE,~F.Y-SL~, :'JELL S~.7 ~ i:.-" "' .................................................................................................. A !'.lC ~ '"] F" ..... ,...-~=~., .LL~..SF:,_ ~'-:~ ':;"-'~...,CT~ ¢t:~ _,"O~'FA[,. , , Y ~ ~" '~ ,~:'~ ........ ¢ ~, ~ ~ ,~ ~~'~ ...... ~ : KELLY ZERO 'RE"E'EY i F:TERFCL'~;TEF.-;-'TVT, LTJEb-'"F C K-'£VEF; ...... %~ ~-0--FE'ET'-'6F-'-:T.T;::'XTUFEE! ..... ~£P1 ~ TaL;E SU:.~. - ~n ~ ,.,.',. TOT ,~ L ~.cSUP,~.L! ......... VERTi'CTiTU- ...... VE'RTIC~iE ..... "~.~'~'T:''~:'~rw'~ COO~'~''' '~ . E~T~~ DEPTH OEPT~ NO~TH/~C]UTh EAST -' . ,._ a_P O:' c_ ,b~ c,... THFEE il. .-:.t;?.; ,r':g i':,:LCL'LATTO?t FRCCEI]UREn ;,.;'!E El'-,'*""-" T<-.:- i: ...... --' · 6,39 iPTEF. FOL.;:~'-~'~ ~,~.. VALL:E~ F:R EVE?<~ ~60.,- FEET UF ~ .::...: E, - e, ;' A' _. '~'U;EF~h-~" : ..... _ : ~.~.;,L ,- : ~CAL F. hCTAf:'.'-:'.fUL~?. CO:'-)P, CI:' A. TES ;-:D-T\"O VE~TiCi, L OgPTd ~3 E~.TE DEPTr~ NC RTH/d, UUT:-: £A ST/;-~E ='-r ,SiFFE~:''- ~ ,_ ,-. ...._;~uE C~, ?.i~'C'~ i C ?,, :) ~EASURCO V. Ep, TIC!,~L VERTICAL DE,.'T~ ~eRT~ ~EPTH NORTH/$r,;U'Fh aO80,O0 21~' .0~ 115,10 ,, ~, c.. r, 2 ? O '0. 2~ ~l ~'~10.~0 3800.00 lf.'~ -~ 53i0, ..... .-.. - , 5+%" .5~U.:)O 3503.00 ~7.~'Z - 55,3 32.5 :j ............ USJ 0, C :3 ......... 3-:; 3'C, ~ u ,:~'¢. ~2 - .., 34= " . :>c5~ .-~610,.'~n 3mr>O,O0 2'Zi,97 - 3,..,.. ) VALUES FEET O.F '.T ~J~E S u ,3 ;-SE', .., -- MEASUF, C:3 VE,-,,' T i CAL VERTICAL rjEPTi4 9ER'Th OEmTM COORD i,'!A Tc ~ E~., - I'-'- .- ,-, !..' .................. 557, ~5" · VERTICAL REC FiD-T'V .. _ 5'9'~'/ ~,~:'~O,,.,~'~q 5500,00 665,77 ~-~ 7~3,..~5 ?~:' ';~ .... ............. ~2Y5'. . . : ........ o~0. u,,'"-~-'4'"' ...... :;~ .................. ~O O,..n. 08 o°¢ 3 ....... .'& 7 -" ............... 775 . ~,o ~ > .... ¢' .............~ ~;. · S510,. JO 6~dO.O0 ....-. :---,-g ~. C O 6530,,.00 ~95, o 7 757. ,5 7 7G3o~0 75-4: ~ -- 527,07 6..3 -,.. 0,.00 67C.~ _ .¢ _~_ t -' '"- 71~l, 0 e QO . 72~_ 0.3 r}., 7'~.30 75;34.. WELL 781u.~0 '770o,no 8~57 7310.60 7800.00 ........... :'< ~>: ......... :"'-: n *" O;"O'S'------7~ n n--.~"~ .!':277' CI~O.G9 8000,00 ............... 5~..=: .......... 53~ ...... --. .......... ~O,nn 5200';'OU ................. G",:~T~ .... ........ 5~'':'~!O . uu ~SOO.~..'-~O.. -) .) _ ........................ , .......................... : ....... - _' __~ ' Z ~ ........................ :: ...............-- ...... ~E~SUi~E3 V~.T. ICAL VERTICAL R :C.'F~:~::~UL&.~ Cu,~,xO ~,.AT ~. · .. SURVEY TABULATION sHEET . . , , , '" ' MEASURED '- VERTICAL DEPTH, ANGLE DIRECTION'OF INCLINATION MEASURED COURSE DISPLACEMENT "- TOTAL DISPLACEMENT CORRECTED _ DEPTH' OF couRse INCLIN- DEV. ~ TIME ~ TOTAL COURSE . TO~AL ATION OBSERVED CORR. CORRECTED NORTH SOUTH .EAST WEST ~ NORTH SOUTH EAST WEST , ~ bq3o bg2~.ll~ n~ ~ ~¢7 ~ 5,~ .' BONE BY: j j .. , i. ' ', · ' SURVEY' TABULATION SHEET ,, : ' -~ _ . . -.. JOB NO. . *' , C DEPTH . VERTICAL DEPTH ANGLE DIRECTION OF INCLINATION 'MEASURED COURSE DISPLACEMENT TOTAL DISPLACEMENT :, OF COURSE TIME ~ INCLIN- DEV. ~ ~ TOTAL COURSE TOTAL ATION OBSERVED CORR. ~ORRECTED NORTH SOUTH EAST WEST NORTH ~ SOUTH EAST WEST , ,. . .- ~. ~._~ , ~ . . . - , I, ! " I t" Amoco Production Company ?. O. Box 779 Anchorage, Alaska 99510 May 13, 1975 File: GJR-410-WF Mr. O. K. Gilb~th, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Monthly Report of Drilling and Workover Operations MGS 17595 Well No. 5 SMGS Unit Well No. 2 ~ Attached herewith are the State of Alaska Forms P-4 furnishing monthly workover operation information for Middle Ground Shoal 17595 Well No. 5 and South Middle Ground Shoal Unit Well No. 2. Yours very truly, Supervisor in Charge Attachments A~,,cHORAG~ l~tm No. P--4 ~, 3-1-70 STATE OF ALASKA OIL AND OAS CONSERVATION COMMITTEE SUBM1T IN DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WgLL ~. NAM~ OF OPERATOR Amoco Production Company 3. ADDRESS OF OPEP~ATOR ?. 0. Box 779, Anchorage, Alaska 99510 4 LOCATION Leg 1, Slot 5, SMGS Platform Dillon, 743' FSL, 1818' FWL, Sec. 35, T8N, R13W, S.M. AP! N~IERICAL ~ODE 50-133-20022-01 LEASE DESIGI~ATION AN'D SERIAL NO. ADL-18746 IF INDIA]~. ALO] lEE O]~ TRIBE NAME 8. L,~IT FAiRAI OR LEASE NAME SMGS Unit 9 WELL 10 F'LFJ~D AND POOL. OR WILDCAT South Middle Ground Shoal 11 SEC, T.. R. M (BOTTOM HOLE Sec. 35, T8N, R13W, S.M. 12 P]gR1VIIT NO 67-27 13. REPORT TOTAL DEPTH AT END OF MONTH. CHANGES IN HOLE SIZE. CASING AND CEMENTING JOBS INCLUDING DEPTH SET A/WI) VOLUMES USED. PEHFOP, ATIONS. 'rESTS A/XlD RESULTS FISHING JOB~ JU'NK LN HOLE AND SIDE-TB. ACKED HOLE AND ANY OTHER SIGNIFICANT CH. ANGES IN HOL~ CONDITIONS Summary of Operations for the month of April 1975: April 16-20: Nippled down tree and nippled up BOP's. Tested BOP's to 1000 psi. Tested 9-5/8" - 3-1/2" annulus with 1000 psi for 15 minutes, okay. Pulled tubing out of Model "D" packer at 9090'. Tested wing valve and choke manifold to 1000 psi. Set cement retainer at 9080' on wireline. April 21-22: Stung into retainer at 9080'. Pumped 104 sacks Class G cement below retainer and left +10' plug on top retainer. Set bridge plug at 7000' on wireline. Perforated 6900- 6901' and 6600-6601' with 4SPF. Set cement retainer at 6740' on wireline. Stung into retainer and circulated into perforations at 6900-6901' and out perforations at 6600-6601'. Circulated 200 sacks Class G cement behind casing. April 23-24: Drilled contaminated cement 5840-6213' and washed to top of retainer at 6735' DPM. Drilled out retainer and tagged bottom at 6986'. Tested perforations to 1500 psi, okay. Tested annulus and drillpipe to 1000 psi for 10 minutes, okay. Reset packer at 6640' and attempted to circulate between perforations at 6600' and 6900'. Pressured drillpipe to 1500 psi and could not circulate. April 25-30: Tested BOP's and Kelly cock to 3000 psi, okay. Milled window in 9-5/8" casing from 6760-6824'. Spotted 80 sacks Class G cement from 6600-6862'. Tagged soft cement at 6737' and pumped down to 6752'. Drilled out irregular cement to 6824' with hard and soft spots. Spotted 50 sack Class G cement from 6756-6824'. 14. I he~by_~lfY that the~orego~g~ tr~,e and ~ .rf~t . ,, .,GNm~,~,~ ~-~L~/.~)~n-~ Supervisor in Chaise oil and ga~ conlervat~n commiflee bythe 15~ of the succ~din9 mon~. ~le~ otherwi8~ directed. DIV!SICN C:[: Ci~ AMD Ah,CHOR^.~5 Amoco Production Company P. O. Box 779 Anchorage, Alaska 99510 January 13, 1975 File: GJR-035-WF Homer L. Burrell, Director Division of Oil and Gas State of Alaska Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Notice of Intention to Drill SMGS 18746 Well No. 2 Enclosed is a draft for $100.00 in payment of the fee required for the Notice of Intention to Drill SMGS 18746, Well No. 2, filed on December 23, 1974. The liner size to be used for the redrill is 7" 26# S-95 buttress. Very truly yours, George J. Ross Area Superintendent Enclosure DIVISIONOIL AND GAS OiV!SlC;I'4 C,i:: Ol[- A~ ~A$ AN¢t,IC)II^ December 23, 1974 File: GJR-906-WF Mr. Homer L. Burrell, Director Division of Oil and Gas State of Alaska Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Notice of Intention to Drill SMGS 18746 Well No. 2 Amoco Production Company P. O. Box 779 Anchorage, Alaska 99510 c .... 4 ~' ::.3 .... ...... 3' ~ ---ksv ......... ......... O~AFT .... ..... S~C ...... : CONFER= ~ILE, Please find attached an application for a permit to redrtll SMGS 18746 Well No. 2 to a new bottomhole location in the Lower Kenai Conglomerate. Your approval of this application would be greatly appreciated. Very truly yours, George~. Ross Area Superintendent Attachments rorrn I0-- 401 P, EV. I --I--71 SUBMIT IN (Other mstructions reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE IA. TYP~ OF WOIiK b. TYP~ OF WI~LL PERMIT TO DRILL OR DEEPEN DRILL ~] DEEPEN [] API #50-133-20022-01 S. 6.I.,E~SE D~IGNATION A2~D S~:~.A~ NO. ADL-18746 7. IF INDIAN, ALL~'i-I~. OR TI~BE NAME 8, UNIT FARM OR LEASE NAME SMGS Unit g. W~LL NO. 2 .r> ~IN(IL~ [] MUI,TIPI,~[-~ OIL ~-~ OAJl ["=[ OTJJBJ ZONg ZONE W~LL __ WELL 2. NAME OF OPEI:LATOR Amoco Production Company 3. ADDRESS O~ OPEB~TOR P. O. Box 779, Anchora~e~ Alaska 99510 ~ 4. LOCATION%e~E~ Slot 5 SMGS Platform "D"' 743' FSL 1818' F~, At surface , , . . ~ ~ Sect ion. -. 35, TSN, R13W, S.M. ~,~/~,~.~..~ At p. roposed prod. zone 1275 FWL, 2265 FSL, Sec. 35, TsN S.M. 13, DISTANCE IN MILES ANI~ DIRECTION FROM NEAREST TOWN OR P~E 15-1/2~miles NNW of Kenai' AlaSka 10. P'IELD AND POOL, OR WILDCAT South Middle Ground Shoal Il. SEC., T., R., M., (BO'I'TOM HOLE OBJECTIVE~ ./"~-~ /~ /~ W Sec. '35, T8N,~ S.M. 14, BOND INFORMATION: Statewide 0il and Gas Bond.-Division of Lands Bond File B-il TYPE Surety and/or No. . DISTANCE FROM PROPOSED' 1260' W of unit Boundary LOCATION TO NEAREST- , PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 18. DISTANCE FROM PROPOSED LOCATIOIW* NO, ~OF ACRES IN LEASE. PROPOSED DEPTH , 10'5o0, TO NEAREST WELL DRILLING, COMPLETED. OR APPLIED FOR, FT. 1110' SW of SMGS N°' 4 21. ELEVATIONS (ShOw whether DF, RT. CR, etc.) 100' KB above MSL 23. PROPOSED CASING AND CEMENTING PROGRAM ~o.~, $100,000 { m . TO THiS WELL 80 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START* Feb.ruary 1~ 1975 SIZEOFHOLE SizEOF'CASIN(~ ~IGwr PER rOOT GRAI:~ ~ S~mGD~ quantity of cement 12-1/4''~ ~'9-5/8"0 "i0~401' prev:.ouslY ..;ce Proposed ~n4ow at 6770' ~ ~' 8-1/2" 7" T ? 10.,500'~o. 7V~ Cmt.,,b~,gk ~o sidetrack point in 9 ,,, , , . ' ' '" ' ~ , ., ,, , , ,,, ~ We propose to sidetrack SMGS 18746 Well No. 2 to a new bottomhole location in the Lower Kenai Conglomerate. The Well is currently a~a.~er injection well and will be converted to an oil prpduc$,~p~__~.we~? proposed dePth of 10,500' is a true vertical depth of appr°ximatelYlocation plot are9100'' Drillingattached. procedure, description of blowout pr~n~r~ ~ ~ f ~ DEC 2 4 1974 DIVI$1CN wF OIL AND OAS ~w prffdu~ive ~ne. Jf_~l ~ ~.arllL or ~n ~[oMlly, ewe ~men~ ~' on'~Su~a~ ~t~ ~d mca 're,teal dept. Give bio--ut preveoter PasTam. - /8" 24. I hereby~ertify that the Fol'egoLni~h~u, ~,ri~ ~orreet (This space for S~te of~ u~) CONDI~ONS OF ~VE, IF ~: [ SAMPL~ AND CORE CHIPS R~~ M,U'D LO'G ~ ~U~: a ~ ~.o J m ~ ~.o SEE TRANSMITTAL LETTER g~o.~ su.wv .m~ ~.~.L ~C~ co~= ~"~Y~ O NO 5~0 - /33" ~ .... :._. a o ?-'* '0! Area Superintendent --I February 7, 1975 . , , ..rs February 7. 1975 Form 10-401 State of Alaska SMGS 18746 Well No. 2 Page 2 Plan of Procedure: 1. Skid rig over Slot No. 5, Leg 1 and rig up. 2. Sidetrack hole in 9-5/8" csg. at approx. 6770'. 3. Drill 8-1/2" directional hole to + 10,500' MD. 4. Run 7" csg. to 10,500' and cement as required. 5. Run required logs. 6. Recomplete well as a Lower Kenai Conglomerate ("G" zone) producer. Estimated Total Time: Redrilled and complete 52 Days DIV!SION bi:: OiL AND GAS AJ,,,'cHORAG~ --e---Pipe Rams 2" Check Vglve 4" pie% or tga~e valve 2"Plug ,~ a lye 2" Plug or Ga~e .Valve 4" pi~g vg ~'-"' li-e., w/shop made s:.:,~.e') w/no more than /;.5c bend ' i-2" Plug Valve on side ouct'e t Equipmenn below ~his ' i .'- fu',n~ished by Pan Am. ~ · · va lye 2" Iine 2" ~choke ~ a.. All preventor's to be hydraulically operated from an a¢cumulacor which will open and ~ ctosa hydri~ an %eas~ three ~imas w~thou~ recharging. 2. All equipment ~n~u which b~t must pass to have at least as large iD aa casing oelng ~r~.~ied through. , 3. Kelly cock to be on Kelly from time of '. 4. Drill pipe slfc~y valve equ~.valen~ to Sheller~ ~fod. 55 or OMSCO, with proper contractions, to b~ on rig floor at all times. ~ 5. All equipment r, entioned above to b'e 5000~~ WP or stronger. '~ ~ ~.-~ 1~ 6, Ail connections be ' · OEC 2-4 ~ 7. Operat-'~no ~' mani,~o"..d uo be in easy rcacl; of drillers station w/~ ~;~ opera,ins station. ~'~ ,~l~t'4 ~.~ OIL AND . 8 N~ T. 7 ~AN AM~:RICAN-- SKELLY-SiNCLAIR- PHILLIPS ADL 18750 PAN AMERICAN- SINCLAIR- PH .o® - ADL 18744 AD.L 1874 6 ADL 18750 Federal leases 0 Ac. State leases 4160 Ac. Total 4160 Acres R. 13 W. }2crt;z[ l(cc~'diug Disu'io:: OL /874 3KELLY LLIPS 36 ,.3 8 N~ 7 --LEGEND- .L .- · ,~-.= ~ ~=,UNIT BOUNDARY ~,~.=~..~,.?=~tl" : " -' TRACT R. 13W. BOUNDARY · DEC 2, 4 1~74 D!V!SIGI'4 ~,.F OIL AND E X H I B I T Ah~C,~)RAGE'-- TO ACCOMPANY 'PDt F 6:-;0'"' SOU°FH P,S, ~:.. , .... ",,~i.: D UNI'T A''~ ~'' .... .COOK INLET BASIN, ALASXA 1765' 35 MER SEWARd, LEG. NO. I LEG NO. 2 LEG. NO. :3 I TSN IDIAN ALASKA T 7' N LAT. 60~44' 08.16" LAT. 60o44' 07.72" LAT. 60~ 44' 0?.08" LONG. 151° 30' 45.85" L~NG. 151° $0' 44.7,.3" LONG. 151° 30' 45.86" Y = 2,463,917 Y = 2,463~871 Y = 2,465,80? X = 229,266 X = 229,319 X = 229,263 FROM S.W. COR. FROM' S.W. COR.' FROM S.W. COR. 743' NORTH ~ 699' NORTH ~ 63,3' NORTH I~ 1818' EAST 1872' EAST 1518' EAST CERTIFICATE OF SURVEYOR 26 35 ?,5 SCALE' I" "105O' 2 LEG. NO. 4' LAT. 44' ";1.; LONG. 151° 30' 4,6 94" Y = 2.~465~ 85:5. , X = FROM S.W. COR. 678' NORTH 1765' EAST I herebY certify that ! om properly registered' and licensed to .practice land surveying in the State of Alaska and that this plat represents o location survey made by me or under my supervision and thGl all dimensions and other details ore correct. ' - D~te " Su~'veyor ~ SURVEYORS NOTE 25 36 I The location of S:M.G,S. by use of U.S.C. & G,S. Light" .... , end Boulder 11 Platform D was accomplished stations st , "East Fore and and C.E.T. 18 (Offset 2) DIV!SIGN OF OIL AND GAS r i NAAi~i~AGE ,, , S.M.G.S. PLATFORM "D" LOCATED IN $[ I/4 S'¢,' I/4, PROTRACTEO SEC. 35, I' 8N,~I3W,$ ~, SURVEYED FOR PAN AMERICAN PETROLEUV, P.O. BOX 779 ANCHORAGE, ALASKA SURVEYED BY E M. LINDSEY & ASSOC. LAND SURVEYORS & CIVIL ENGINEERS 3201 ARCTIC BLVD. Company CHECK LIST FOR NEW WELL PERMITS Yes No Remarks Can permit be approved before ten-day wait .............. · Does operator have a bond in force .................. · Is conductor string provided ...................... · enough cement used to circulate on conductor and surface ...... Is well to be located in a defined pool ................. Do statewide rules apply ........................ ' ~ C.O. 5~] ~- ,~/~ Is a registered survey plat attached ............ .... i ' ~.~_~ well located proper distance from property line .......... , Is well located proper distance from other wells .......... Is sufficient undedicated acreage available in this pool ........ Is well to be deviated ...... . ................... Is operator the only affected party .................. · Will cement tie in surface and intermediate or production strings · . Will cement cover all possible productive horizons ...... . . Will surface casing cover all fresh water zones ............ __ . Will surface csg. internal burst equal .5 psi/ft, to next string .... . Will all casing give adequate safety in collapse and tension ...... Does BOPE have sufficient pressure rating ........ ~ditional Requirements' ~i,~_~..~:..~k ~ ~~~/~~ ..... ' A~rovat Recommended' LCS