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167-076
STATE OF ALASKA ALASKA OIL AND GAS CnNSFR\/ATInN ('.n11AMIQSInN WELL COMPLETION OR RECOMPLETION REPORT AND LOG Ia. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned E] Suspended❑ 20AAC 25.105 20AAc 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: _ 0 1b. Well Class: Development Q Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or ✓ Ab nd.: 7/25/2019 14. Permit to Drill Number/ Sundry: . 167-076 / 319-012 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: December 5, 1967 15. API Number: 50-733-20064-00-00 4a. Location of Well (Governmental Section): Surface: 1602' FSL, 570' FEL, Sec 4, T9N, R13W, SM, AK . Top of Productive Interval: N/A Total Depth: 1051' FSL, 2640' FWL, Sec 4, T9N, R13W, SM, AK 8. Date TO Reached: December 30, 1967 16. Well Name and Number: Trading Bay A-10 , 9. Ref Elevations: KB: 101' , GL: 0 BF:40' 17. Field / Pool(s): , Trading Bay Field / Hemlock, Mid Kenai C, D & E Oil Pools 10. Plug Back Depth MD/TVD: 1,095' MD / 1,068' TVD I 18. Property Designation: ADLO18731 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 218864 y- 2523116 r Zone- 4 TPI: x- N/A y- Zone- Total Depth: x- 216795 y- 2522623 Zone- 4 11. Total Depth MD/TVD: 7,073' MD / 6,652' TVD 19. DNR Approval Number: N/A 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: N/A 5. Directional or Inclination Survey: Yes LJ (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 66 (ft MSL) 21. Re-drill/Lateral Top Window MD/ND: 1,095' MD / 1,068' TVD ' 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 1p�rg, C �f n N/A 4 ECEI Y ED NOV 0 8 2019 23. CASING, LINER AND CEMENTING RECORD AMOUNT WT. PER SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD CASING FT GRADE TOP BOTTOM TOP BOTTOM PULLED 20" Cond Cord Surface 264' Surface 264' Conductor N/A 13-3/8" 61# K-55 Surface 1,095' Surface 1,068' 17-1/2" 1200 sx 24. Open to production or injection? Yes ❑ No 0 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Dan Size and Number; Date Perfd): A`_ "Ido �0. S 2C(y V RIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/fVD) NIA 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes—E-1—No r Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity -API (corr): Form 10-407 Revised 5/2017 /'���/ CONTINUED ON PAGE 2 Submit ORIGINIAL only /�ly{b/f`, /i o-7_JS RI MS�NOV 18 2019 TrP.Qr+lALe .4 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071, 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base N/A N/A Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval N/A N/A information, including reports, per 20 AAC 25.071. Formation at total depth: West Foreland 31. List of Attachments: Wellbore Schematic, Decomplete Reports Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Monty Myers Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: cdinQeE@hilcorp.com Authorized Contact Phone: 777_g389 Signature: — Date: . $. 19 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: 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. Item 1b: Well Class- Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: 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. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: 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. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: 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. Item 30: 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. Item 31: 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: care analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only Trading Bay Unit Plug Back for Well #A-10 PTD: 167-076 Hlleorlr Almfw. LLC Sidetrack Schematic API: 50-733-20064-00 Abandoned: 07/25/2019 rASwr nFTAD KB 37', KB to MSL:101', MSL to Mudline 66' 20° 9-5/8" cut Lm 1,393' W/ 527' CMT CIBP 1,540' 13-3/8" - r CIBP @ 4,008' w1373' CMT TOC 3,635' sq. ■TOF &013' t r• e L■�, =20101 e 11 Dvcon.r f s,a4e' 9 12 h 13 14 15 16 D -Zone E Zone 9-5/8, KB ELEV = 101' PBTD = 6,750' TD = 7,073' ANGLE thru INTERVAL = 12.7° Perforation Details on Next Page Updated by: JILL 05/29/19 E CONN ID TOP BTM. DNO epth ID r Pile Henn 2 Junked Retainers Surface 264' 1/2 of ring from hydraulic packer 08/09/1970 6,503' BTC 12.515 Surface 1,095' T2 I CIBPw/527'cement 0 06.4N BTC BTC BTC 8.835 8.835 8.755 1,393' 4,111' 5,600' 4,111' 5,600' ],053' CIBP w/3]3'cemen[ SHORTSTRING ing Detail: Butt 2.992 4,123' 4434' -7/81- -80 Butt 2.441 4435' 5718' S53-1/2" 9.2 N-80 Butt 2.992 4,013' 4145' 2-7/8" 6.4 N-80 But 2.441 4146' 4191' Dip Tube2-3/8"xl-1/2" 6.2 N-80 Butt 1.853 4084' 5537' Perforation Details on Next Page Updated by: JILL 05/29/19 FISH DateDepth IEWELRYDETAIL NO DMD th DNO epth ID OD Henn 2 Junked Retainers 07/14/1973 6,496' 1/2 of ring from hydraulic packer 08/09/1970 6,503' Guiberson Packer model 1,540 1,470' 1 L I CIBPw/527'cement Junked BP 4,008' 3,716' Junked BP 03/21/1968 CIBP w/3]3'cemen[ SHORTSTRING E 4,044' 3,749' 2.875 5.62 GLM#S4-Otis RW4(4.37"Minor OD) F 4,080' 3,781' 2.75 Otis"XA"Sliding Sleeve G 4,145' 3,841' 2.441 Cross over, 3-1/2"X2-7/8" H 4,146' 3,842' 2.380 8.435 Otis"RTH" Triple Hydraulic P -1, -13 -1/2"x2 -7/8"x2-3/8") I 4,189' 3,882' 2.205 Otis"XN" Nipple 1 4,191' 3,884' EOT LONG STRING 6 4,147' 3,843' 3.000 8.435 Otis"8TH"Triple HVd2ullc Packer(3-1/2"x2-J/8"x2-3/8") 7 4,249' 3,937' 2.75 Otis"XA'Sliding Sleeve 8 4,434' 4,109' Cross over, 3-1/2"X 2-7/8" 9 4,497' 4,168' GLM #L4-Camco KBMG-LT 10 4754' 4,874' 4,409' 4,522' Blastloints 11 5,030' 4,668' GLM#L5-Camco KBMG-LT 12 5,442' 5,053' GLM#L6-Camco KBMG-LT 13 5,604' 5,205' 2.313 Otis"XA"Sliding Sleeve 14 5,640' 5,239' Locator Seal Ass . 15 5,641' 5,240' Otis 9-5/8"x4""BD"Perm Packer 16 5,685' 5,281' 2.313 Otis N. NIPPIe D 5,718' 5,312' Mule Shoe, Di Tubing a. 4,084' Topof Dip Tubehperforated jaintl 4,147' 3,843' 1.940 8.435 b. 4,159' 3,85, 1-1/2" Telescoping Joint c. 4,496' 4,167' GLM#L4-Camco KBMG-LT d. 4,513' 4,183' 1-1/2" Telescoping Joint e. 5,030' 4,668' GLM#LS-Camco KBMG-LT f. 5,052' 4,689' 1-1/2" Telescoping Joint g. 5,442' 5,053' GUM #L6-Camco KBMG-LT h. 5,537' 5,142' BUII Plug Perforation Details on Next Page Updated by: JILL 05/29/19 FISH DateDepth Description 10/05/1978 6,500' Junked Perm Packer 07/16/1973 6,494' 2 Junked Retainers 07/14/1973 6,496' 1/2 of ring from hydraulic packer 08/09/1970 6,503' Guiberson Packer model 08/D8/1970 6,503' Junked Retainer 07/30/1970 6,515' Junked BP 03/25/1968 6,525' Junked BP 03/21/1968 6525' lu nked BP Perforation Details on Next Page Updated by: JILL 05/29/19 HPlug Back for Bilenq, Alaska.LLCSidetrack Schematic Trading Bay Unit Well # A-10 PTD: 167-076 API: 50-733-20064-00 Abandoned: 07/25/2019 Zone Top MD) Btm (MD) Top (TVD) Btm (TVD Amt. Accum. SPF Date Last r. Present Condition 3,840' 3,860' 3,563' 3,582' 20' 4 3/22/1968 Isolated 4,148' 4,168' 3,844' 3,863' 20' 4 3/20/1968 Isolated 4,240' 4,241' 3,929' 3,930' 1' 4 3/24/1968 Isolated C 4,2' 4,288' 3,949' 3,973' 26' 4&8 7/30/1970 Isolated C 4,316'26 4,354' 3,999' 4,035' 38' 4&8 7/30/1970 Isolated C 4,398' 4,430' 4,076' 4,106' 32' 4&8 7/30/1970 Isolated C 4,498' 4,514' 4,169' 4,184' 16' 4&8 7/30/1970 Isolated C 4,572' 4,592' 4,238' 41257' 20' 4&8 7/30/1970 Isolated C 4,668' 4,694'4,328' 4,353' 26' 4&8 7/30/1970 Isolated C-7 4,766' 4,864' 41420' 41512' 98' 4,8 & 12 7/30/1970 Isolated C 5,012' 5,050' 4,651' 4,687 38' 4 3/26/1968 Isolated C 51096' 5,100' 4,730' 4,734' 4' 4 7/30/1970 Isolated C 5,124' 5,132' 4,756' 4,764' 8' 4 7/30/1970 Isolated C 5,244' 5,249' 4,868' 4,873' S. 4 7/30/1970 Isolated C 5,325' 5,358' 4,944' 4,975' 33' 4,8 & 12 7/30/1970 Isolated C 5,532' 5,534' 5,137' 5,139' 2' 3/5/1970 Isolated C 5,534' 5,590' 5,139' 51191' 56' 4&8 ]/30/1970 Isolated C 5,590' 5,592' 5,191' 5,193' 2' 1 3/5/1970 1 Isolated D 5,684' 5,712' 5,280' 5,307' 28' 8 ]/30/1970 Isolated 53-8 1 5,787' 1 5,838' 5,3]9' 5,429' 51' 4,8 & 12 3/8/1974 Isolated Sq -5 5,870' 5,80' 8 5,460' 51469' 10' 8 7/16/1973 Isolated 54-9 5,900' 5,954' 5,489' 5,541' 54' 12 7/16/1973 Isolated 0 5,985' 6,020' 5,571' 5,605' 35' 4&8 ]/30/1970 Isolated D 6,030' 6,134' 5,615' 5,716' 104' 4,8,12&16 3/8/1974 Isolated 57-2 6,160' 6,245' 5,742' 5,826' 85' 4,8,12&I6 3/8/1974 Isolated E 6,274' 6,296' 5,854' 5,876' 22' 8 8/8/1970 Isolated E 6,274' 6,296' 5,854' 5,876' 22' 4,8 -&12 ]/16/1973 Isolated E 6,320' 6,352' 5,900' 5,932' 32' 12 7/16/1973 Isolated 6,600' 6,]40' 6,179' 6,319' 140' 4 1/6/1968 Isolated 6,760' 6,840' 6,339' 6,419' 80' 4 1/4/1968 Isolated 6,904' 6,919' 6,483' 6,498' 15' 4 1 1/3/1968 1 Isolated Updated by: ILL 05/29/19 nHilcorp Energy Company Composite Report Well Name: TBN A-10 g rig to earthquake clamps, stairs, and handrails.,RU E -line. Start RIH on SS at 11:00 hrs. Tag up at 327'. PU and pull out of rope Field: Trading Bay North ✓/, County/State: , Alaska on tool alatched on 1 st time. Pulled tool free w/ 100 Ib over pull. POH w/ gyro tool and LD same. MU 1.90 GR and RIH. Set down (LAT/LONG):: ce gyro sH and Pull lubricator off SS side.,Swap 1/2 flanges on the tree so we are set up on LS. RU lubricator and RIH w/ 1.90 OR to ovation (RKB): e taggedD slickline-RU. E -Line on A-10 LS. [Unloading boat with pallets of salt],RIH with Gyro tools on E -line to 913'. POH w/ Gyro API #: tool and lay down same. RD E -line. Spud Date: Cleaning rig pits.,Prep to move rig off A-10. Jack rig north and install base platform for under catwalk and beaver slide. Move jacks from back of sub to front of Job Name: 1910558P A-10RD PreDrill sub. Position jacks on east side of rig. Contractor Continue cleaning pits, mix 9.5 ppg brine and begin filling rig pits for A-31.,Jack rig to A-31. Install cat walk and beaver slide.,This is the last report for A-10 Pre AFE #: 1910558P AFE $: $1.041.766 Activity Date Ops Summary 4/1/2019 g rig to earthquake clamps, stairs, and handrails.,RU E -line. Start RIH on SS at 11:00 hrs. Tag up at 327'. PU and pull out of rope with lineRD E -line and spot slick line unit in place.,Wait on slick line crew. Crew arrived at 1330 hrs. Rigged them up and RIH with a M930'wherewemand on tool alatched on 1 st time. Pulled tool free w/ 100 Ib over pull. POH w/ gyro tool and LD same. MU 1.90 GR and RIH. Set down ce gyro sH and Pull lubricator off SS side.,Swap 1/2 flanges on the tree so we are set up on LS. RU lubricator and RIH w/ 1.90 OR to e taggedD slickline-RU. E -Line on A-10 LS. [Unloading boat with pallets of salt],RIH with Gyro tools on E -line to 913'. POH w/ Gyro tool and lay down same. RD E -line. Cleaning rig pits.,Prep to move rig off A-10. Jack rig north and install base platform for under catwalk and beaver slide. Move jacks from back of sub to front of sub. Position jacks on east side of rig. Continue cleaning pits, mix 9.5 ppg brine and begin filling rig pits for A-31.,Jack rig to A-31. Install cat walk and beaver slide.,This is the last report for A-10 Pre Drill. We will be swagging to A-31 4/6/2019 Finish assisting production wl the tree.,Test line. Attempt to pump down SS taking returns off arm to production. Press up t01950 psi and shut dn. Operate SSSV to check if it was open. Pressure up to 3000 psi and we still couldn't circ. Cycle SSSV again but it didn't make any difference. Shut well in and bleed off pressure. Looks like we won't have to wireline on A-31 so we decided we would move the rig.,Prep to skid the rig. Pull landings and stairs. Remove beaver slide and poney sub under slide. Remove earthquake clamps.,Stop on rig skid and go back down to wellhead room to re -tighten some bolts on A-31 tree.,Skid rig to A-10. Skid to the west. Then skid rig to the south. Move jacks to the north side and continue skidding rig to the south. Pull stairs off west side and re -install on the east. Load poney sub on boat to be stored on the Steelhead., Finish skidding rig over A-10. Safe out and secure seismic clamps and hand rails. Install beaver slide and rear landing on choke side.,Rig up Pollard slickline. Pressure test lubricator at 2500 psi.,Open well (450 psi). Run #1: 2.79 drift to 330'. Run #2'. 1.97 hammer down to 330' and work hammer. Run #3: GS prong. When well opened pushed tools up against lubricator. LID tools and re -head. Run in and retrieve valve. Run #4: 2.5 bailer down to 3019' and work down to 3051' with sludge recovery. Rerun and working down at 3062'. 4/7/2019 Slick line bail on short string. Bailer run #3 we made it to 3105' and recovered a full bailer of black slim. Total bailed on SS=14.16 Ibs.,Set slickline off to the side and put night cap on lubricator. Test lines and mudline to 2500 psi. Bled back and open to well. Attempt to circ In SS. Just pressured up to 2000 Psi with no bleed off. Swap slickline lubricator to LS.,Run #1 on LS. RIH w/ 2.5 bailer. Tagged at 914' and didn't make any hole. Recovered 8.80 lbs scale and sand. Run #2 on LS. Run a star bit and break everything up down to 915'. POH. Run #3 Run a bailer and tag at 915'. POH and recovered 6.3 lbs scale. Run #4. tag at 915' and recovered 8.4 lbs. RD slickline.,RU E-lineon LS. RIH and correlate to where we are in the center of a jt. Press up tbg to match ann and cut tbg at 900'. Had good indication charge going off. POH,Swap everything over to the SS side. MU radial cutter and MU to tools. Open well and RIH. Correlate to 16' above 2 nd GLM. Pressure up do tbg to 400 psi. Fire off cutter and cut pipe at 2960'. Drop down and we could see the cut. Press fell to 200 psi. POH w/ E -line. RD E -line and get ready to circ.,Pump 82 bbis 9.2 ppg brine down SS at 2 BPM/230 psi to production header. Had to shut down and reroute lines due to aerated oil returns.,Reroute and re -plumb lines to bypass shipping pump and go directly into pipeline due to cavitation with production pump. Also, plumb in gauge and sample port for returns.,Pump down SS side taking returns directly to pipeline at 2 - 4 BPM/560 psi. Pumped total of 240 bbls. Shut down to monitor welL.Monitor pressures while building 9,2 ppg brine volume. 1 hour readings: LS/1000 psi, SS/950 psi, annulus/875 psi.,Pump down SS side taking returns directly to pipeline at 2 - 4 BPM/580 psi. Pumped total of 380 bbls with clean 9.2 ppg returns at end. Shut down/shut in at 0245 hrs. Monitor well while building volume..,Monitor pressures while building volume and weighting up to 9.5 ppg. 1 hour readings: LS/410 psi, SS/340 psi, annulus/275 psi. 2 hours: LS/415, SS/375, annulus/325. 4/8/2019 Build 350 bbls 9.5 brine. while monitoring well pressures. SS=390 psi, LS=485 psi, Ann=340 psi.,Pump 300 bbls do SS taking returns back to pipeline at 4 BPM and 600 psi on SS. Started weighting returns at 200 bbls back 9.3 ppg at 300 bbls back 9.8 ppg.,Shut and monitor press. SS=445 psi, LS =520 psi, & Ann =350 psi. Press at noon SS= 400 psi, LS=450 psi, Ann=360 psi. Prep to mix 11.5 mud. Start bringing mud products off boat. Breaking bolts on wellhead one at a time and replacing with good bolts in prep for pulling cog head.,Start building mud in pill pits. Finish bringing mud products and ISO tank off boat. Start mixing Will mud in main pit system. Run cords for derrick, and shaker camera system.,Continue building 11.5 ppg mud. Continue monitoring tubing and annulus pressures. Bolt up riser and spools.,Continue mixing 11.5 ppg KWM. At 0300: LS/1375 psi, S3/1290 psi, annulus/1350 psi. Bled annulus down to 250 psi and SS came down to 600 psi. 0400 pressures: 1-8/1120 psi, SS/1000 psi, annulus/1060 psi. RU line off T from ann to rig choke manifold. Have kill mud weighted up to 10.8 and still mixing bar. Lost coupling on pill pit mix pump. 4/9/2019 Mixing 11.5 Kill wt mud. Had replace couplings on both mix pumps at pill pit. Finish stringing camera cords for pipe deck camera. Shut in pressures: LS11120. SS/1350, annulus/1395.,Pump 11.5 ppg KWM down SS taking returns to production for 197 bbls. Divert returns to rig choke and continue circulating at 4 BPM/390 psi. Pumped a total of 360 bbls. Shut down/shut in.,Build 11.5 ppg volume. Monitor pressures: LS/1050, SS/950, annulus/980.,Continue building 11.5 ppg KWM. Pressures at 1900 his: LS/1120, SS/1000, annulus/1020 psi.,Circulate 11.5 ppg KWM down SS taking returns back to rig. Began at 2 BPM and staging up to 3.5 BPM/350 psi. Holding 150 psi back pressure with choke. Checking mud weights every 20 bbls and adding product to maintain 11.5+ ppg throughout system. Shut down/shut in.,Monitor well. Shut in pressure at 30 minutes: LS/390, SS/310, annulus/320 psi. Shut in pressure at 1 hour: LS/480, SS/500 annulus/500 psi, 4/10/2019 Circulate 11.5 ppg KWM down SS taking returns back to rig. Pump at 3.5 BPM/350 psi. Holding 150 psi back pressure with choke. Checking mud weights every 20 bbls and adding product to maintain 11.5+ ppg throughout system as needed. Shut down/shut in.,Shut down pumping and shut well in due to fire alarm.,Circulate 11.5 ppg KWM down SS taking returns back to rig. Pump at 3.5 BPM/350 psi. Holding 150 psi back pressure with choke. Checking mud weights every 20 bbls and adding product to maintain 11.5+ ppg throughout system as needed. Shut down/shut in.,Shale shakers shut down. Troubleshoot and repair.,Circulate 11.5 ppg KWM down SS taking returns back to rig. Pump at 3.5 BPM/350 psi. Holding 200 psi back pressure with choke. Checking mud weights every 20 bbls and adding product to maintain 11.5+ ppg throughout system as needed. Shut down/shut in.,Attempt to bullhead. Stage pressure up to 2800 psi. Pumped a total of 2.9 bbls. Bleed off.,Circulate 11.5 ppg KWM down SS taking returns back to rig. Pump at 3.5 BPM/350 psi. Holding 200 psi back pressure with choke. Checking mud weights every 20 bbls and adding product to maintain 11.5+ ppg throughout system as needed. Build 60 bbls weighted mud in pill pits to 16.0 ppg . (Need 18.5 ppg). Mixing pumps not able to handle the load and continually over heating and shutting down.,Change directions and line up to mix barite while circulating at 2 BPM/720 psi. Holding back pressure as needed to prevent influx. 4/11/2019 Mix barite while circulating at 2 BPM/720 psi. Holding back pressure as needed to prevent influx. weight up system from 12 ppg in weight to 11.6 ppg out, V12.9 in weight, 12.6 out,Mix barite while circulating at 2 BPM/720 psi. Holding back pressure as needed to prevent influx. Weight up system 013.9 in weight t/13.7 out,Mix barite while circulating at 2 BPM/720 psi. Holding back pressure as needed to prevent influx. Weight up system to 14.2 ppg in/out.,Shut down and shut in for 90 minutes while rigging up Swaco 80 bbl mixing skid. Pressures: SS1205, annulus/205. Continue circulating while weighting up. Mixing 16.0+ in coil tank in 60 bbl batches and adding to system. At midnight circulating system is weighted up to 14.7 in/out.,Cor ince circulating while weighting up. Mixing 16.0+ in coil tank in 60 bbl batches and adding to system. At 0300 hrs circulating system is weighted up to 15.2 in/out. At 0400 hrs circulating system is weighted up to 15.6 in/ 15.4 out. At 0600 him system is weighted up to 15.5 in/15.3 out. 4/12/2019 Continue circulating while weighting up. Mixing 17.0+ in coil tank in 60 bbl batches and adding to system. Mud weight in 15.9, out 15.6,Shut in well monitor well for one hour, pressure increase 10 psi annulus 80-90psi, tubing 80 n- 85 psi,Continue circulating while weighting up. Mixing 17.0+ in coil tank in 60 bbi batches and adding to system. Mud weight in 16.6, out 16.4,Shut in well, monitor well for one hour, no pressure change, open well check for flow, annulus was static, tubing had flow, (appeared to be u-tubing ),Continue to circulate & even out mud weight. 16.5 in/16.6 out.,Shut down and swap to pumping down long string. Circulate STS with 16.5 ppg KWF times 2.,Shut down and monitor well 1/2 hour. LS, SS and annulus all static.,Disconnect and blow down circulating lines. Set BPV in long string. Master valve on SS side not opening completely and valve stem sheared internally. Break bolts on bonnet. Work past valve and set BPV in short string.,Change out lock downs/packing on tubing spool and test void.,Break out bolts on tree and prepare to pull same. 4/13/ 19 Ni le down tree. Broke all bolts loose. Use jack hammer to try to force studs through flange. Able to remove all but 5 studs. Begin cutting bolts with samall-Continue removing studs with various methods. Clean lifting cap threads. Remove tree and set in cellar. Pull tree out of cellar with crane. Prepare lifting threads and install blanking subs. Lifting threads were extremely scaled up and required special tools to clean up enough for integrity.,Have welder fabricate jacking plate for remaining stud as it would not come free as the others. Drive same out.,Clean tubing spool flange. Set spacer spool in well head room. Prepare to lower riser onto tubing s ool. 4/14/2019 Install riser. Nipple up BOPE. orientate single gate to align with dual hangers. re-orientate kill line & finish stacking BOPE, install drip pan flanges, send flow nipple to welder to modify, blow down mud lines, R/U water to MP for test fluid.,Continue torquing bolts on BOP connections. Install turnbuckles and center stack. Install flow nipple.,Pick up Kelly and install test plug on saver sub. Make up test joints and floor valves.,Test dual rams, dart valves and TIW valves at 250 02500 H. AOGCC (Jim Regg) waived witness.,Remove SS test joint. Close annular preventer and purge Kelly, stack and choke manifold.,Attempting to test BOPE on 3 1/2" test joint. Having problems getting a good test due to sensator issues. Troubleshooting and chasing minor leak. 4/15/2019 Isolated test to choke and kill HCR, upper pipe rams and TIW valve. Still losing pressure. Re-fluid pack system and still losing pressure. Set SS test joint and inadvertently backed out blanking sub. Clean up threads and re-set blanking sub in hanger.,Test HOPE 250/2500 psi, AOGCC witness was waived by Jim Regg, Test dual rams at 250 02500 H. Good test-Removed and laid down test joint and had welder spot weld all connections.,Pull BPV and set two-way [�7 0� „ YK check in short string. Re-install blanking plug. Test BOPE at 250 L/2500 H on chart. Got permission from AOGCC (Jin Regg) to perform 'rolling test' if 1 necessary. Begin rebuilding CMV #16 while continuing to test other components. Also, expedite 4 1/16" 5 K valve from beach for back up. Perform accumulator draw down test.,Finish rebuilding CMV #16.,Test blind rams, CMV #15 and #16 at 250 L/2500 H. Test chokes.,Blow down and stand back Kelly. Flush tubing spool and blanking plugs with 2 7/8" landing joint at 6 BPM. Pull blanking plugs, BPV and two-way check valve. 4116/2019 Rig up landing joints & circulating Iines.,Circulate & condition mud, circulate down the SS 1:12960' pump @ 2-4bpm, 300 8000 psi, returns 15 PPG, condition system up t/ 16,3 , swap over & circulate around the LS„R/U handling eq, unload boat, clean out mix tank, r/u mix tank to pits,Back out LDS and pull both hangers to rig floor. (Hangers off seat at 45k PUW). L/D landing joints and hangers with pups (1 rubber control line clamp each on LS and SS pups.),POOH with LS and control line to SSSV. (Pulled 8 jts with 8 rubber control line clamps) Break out of top of SSSV and attempt to break valve out of top of it 9 with no luck. UD joint 9 with SSSV in top. (PUW=17k, unable to go down for SOW, 2 bbl to fill hole at SSSV),Continue to POOH w/ LS (3.5", 9.2#, N-80 IBT TBG) to cut-off joint.( Pulled a total of 27 full joints, 4' pup joint and -1/2 of joint 28 out of hole) 1.1 bbl. to full hole since SSSV. Total hole fill = 3.1 bbl.,M/U pup into SS and PIU out of slips. Rig down dual string handling tools.,POOH with SS (3.5", 9.29, N-80 IBT TBG) and control line to SSSV. (Pulled 9 jts with 9 rubber control line clamps) Break out SSSV and lay down same. Hale fill = 0.7 bbl 4/17/2019 L/D Short String SSSV. R/U and circulate down SS one full circulation @ 4 bpm w/500 psi. mud wt. in 16.1 ppg, out 16.3ppg.,POOH 30 jt (39 total) 3.5" 9.24 N-80 IBT tubing. Showing slight gain in pits. Notified DSM and TP. Install TIW valve with pump in sub.,Circulate one full circulation and perform flow check on well - STATIC.,Continue POOH w/ 3.5" 9.2# N-80 IBT tubing to cut joint. (total pulled of 94 jt., lea. 4' pup jt., 1 GLM and cut joint) Calc. hole fill 5.5 bbl, act fill 6.7 bbl. Performed kick drill while tripping. Response time:93 seconds for all hands at stations.,Clear rig floor of 3.5" handling equipment. Prep tubing in pipe bunk for transport. Monitor well while circ. across top of hole.,Strap and stage Weatherford fishing BHA#1. R/U rig tongs and handling tools.,P/U BHA from 0' to 118%Fold up and tie stabbing board back out of the way.,Continue picking up BHA from 118' to 271',Repair load cell for rig tongs and change out dies in ST- 80.,Continue picking up BHA from 271' to 316.35' - BHA = 8-1/8" Cut Lip Guide w13-112" Dressed ID Insert / 8-1/8" Series 150 OS Bowl / 8-1/8" OS Extension / Top Sub / 6-1/4" NOV Bumper Sub / 6-1/4" NOV Fishing Jar / X-O / 9 ea. 6-1/4" DC / X-O 16-1/4" NOV / Intensifier Jar / X-O,Change elevators from 5" to 3-1/2". RIH w/ 3-1/2" 13.3# 5-135 DP out of derrick to 409'. 4/18/2019 RIH to just above top offish. Pickup Kelly and tag fish @ 9035. PUW 49K, SOW 49K. Break circulation 3 bpm w/ 100 psi. Inch down onto fish with 70 rpm until pump pressure increase. Kill pump and rotary,Slack offset 12k dn, Pickup to 80K (31k) work left hand turn down (11-1/2 turns) until back out obsewed.,POOH to jars @ 25.12',Soft break overshot, UD bumper sub and overshot with 1/2 jt. of 3-1/2" tbg. R/U McCoy tongs and tubing elevators. UD 6 it. 3-1/2" tbg., Remove fish from overshot and re -dress overshot. Clear and clean rig floor., Pickup BHA and RIH w/ 3 std. 6-1/2" DC's,RIH w/ fishing BHA #2 f/ 327' to 1086'. Pick up Kelly, Calc. displacement 13 bbl, Act. displacement recorded was 18 bbl (not accurate due to pit #3 PVT failure) BHA #2 = 5-7/8" Series 70 Short Catch Overshot, I X -O /6-114" NOV Bumper Sub 16-1/4" NOV Fishing Jar / X -O / 9 ea. 6-1/4" DC 1 X -O! 6-1/4" NOV! Intensifier Jar / X -O (312.2l'),Kelly up, break circ. w/ 3 bpm and 125 psi. PUW 52k SOW 51 k. Slack off and tag top of fish @ 1100'. PIU 4' rot @ 20 rpm (49K wt) wash and rot over fish to 1102' (sat down 13k and saw 1000 psi inc.) shut down rot and pmp, bleed off psi. P/U to 107k (55k over string wt) work in left hand turn while work pipe between 107k to 90k, put 20 LH turns in and got 3 back, put in another 17 LH turns w/ BO observed. PUW 56k, Break off Kelly, mud U -tubing out of pipe. Kelly up, circulate to balance mud wt. in and out., Break off Kelly, observe well and pipe (static), stand back kelly, POOH w/BHA #2 and fish 4/19/2019 Work BHA, stand back collars, UD BHA,UD fish, recover 16 its 3 1/2" & one collar, 490' tubing„P,'U BHA #3, = 8 1/8” Short Catch Overshot, ! X -O / 9 ea. 5- 1/4" DC / X -O / 6-1/4" NOV / X -O (283.99'),TIH U tag tof, @ 1597', up M 55k, do wt 48k, space out & engage fish„R/U wireline. Pick up 1-3/4” bailer assembly. Make up and pressure test lubricator to 1500 psi (Good).,RIH with bailor and tag up at 1605'. Unable to work through. Attempt to pump down pipe ( no good, pressured up to 800 psi) POOH with W.L. and change out flat bottom shoe with mule shoe. (No fill in bailer) RIH with W.L. and tag up at 1605' again. Work several times with no progress. POOH and rig down Pollard Wireline.,Rig up McCoy power tongs. Rotate pipe with tongs while working pipe and release overshot from fish-P/U Kelly and makeup to string. PUW 52K SOW 51 k. Tag fish at 1597' and slack off to 30k to engage fish. P/U to 80k (28k over string wt.) Work left hand turns into back off at 13 turns. PUW 62k (+10k).,Stand back Kelly and rig up to POOH (wet trip) 7 std. to 992'. (seeing coal pieces back with mud inside DP),Monitor well to verify hole is static .,Continue wet trip out of hole to BHA and stand back collars,Break off overshot. R/U and UD fish. 4/20/2019 POOH UD fish, I/d 6 its 3 1/2" tubing,Work trapped pressure on it 7 & 8, hot tapped & drilled bleed holes to release, worked through plugging issues until pressure bled off,Cont. UD fish hot tapping connections checking for trapped pressure. (Jt. 22 -28 completely plugged with coal & sand mixture) Pipe came dry afterjt. 28, Total recovered was 35 jt. 3-1/2" tbg., 2 ea. pup jt. and 1 ea. GLM for a total of 1086' (Accumulative total=1774.66') Actual Hole fill = 5.4 bbl, Calc. displacement = 3.7 bbl.,Clear and clean rig floor.,Change out handling equipment for tripping in the hole.,P/U BHA #4 5-7/8" Series 70 Short Catch Overshot,/ X -O 16-1/4" NOV Bumper Sub/ 6-1/4" NOV Fishing Jar 1 X -O 1 9 ea. 6-1/4" DC / X -O / 6-1/4" NOV / Intensifier Jar/ X -O = 312.21',Change elevators. RIH w/ 3-1/2" 13.3#S-135 DP to 2111' 4/21/2019 Cont. RIH f/ 2111' U2653',PIU Kelly, CBU, @ 4 bpm, 400 psi, conditioning mud U16ppg, Max gas units 875,Cont rih to top of fish up wt 69k, do wt 61k, tagged TOF @ 26TT, worked over pressure increase t/900 psi, shut down pump, set do 10k, p/u no OP, repeat cycle with same results.,Stand back Kelly, POOH, work BHA, no recovery, had good marks in top sub,C/O BHA= BHA #5= 5-718" Series 70 Short Catch Overshot, / X -O 16-1/4" NOV Bumper Sub 16-1/4" NOV Fishing Jar / X -O / 9 ea. 6-1/4" DC / X -O / 6-1/4" NOV / Intensifier Jar/ X -O (312.2l'),TIH U 2653', P/U Kelly up wt 68k, do wt 62k,RIH engage fish, p/u 15k over put 1 1/2 turns left tq in string, wk tq down working between 75 & 80k, getting 9 turns & coming free with 70.5k hanging,Stand back Kelly & POOH, work BHA.,UD fish. Recovered 13 joints 3-1/2" tubing and pup it. (405.23') Fish was clear with no trapped pressure. (fop of LS @ 3082'),Clean rig floor, Re -Hang V. Door, Swap over handling equipment and prep for BHA #6,M/U BHA #6 = 8-1/8" Cut Lip Guide w/3-1/2" Dressed ID Insert / 8-1/8" Series 150 OS Bowl / 8- 1/8" OS Extension/ Top Sub 16-1/4" NOV Bumper Sub/ 6-1/4" NOV Fishing Jar / X -O / 9 ea. 6-114" DC/X-0/6-1/4" NOV / Intensifier Jar / X -O 316.35'),Change elevators and RIH w/ 3-1/2" DP t/ 2944', P/U Kelly, up wt 70k, on wt 62k, rot 64k, circ 3 BPM, 300psi 4/22/2019 Wash & ream down dress off fish, engage @ 2967', make back off had 29 turns before free,POOH wk BHA, had fluid expansion from string, attempt to pump, no go, let decompress while monitoring hole static, cont POOH work BHA,UD fish, hot tap joints as needed had plugged pipe. Recovered 14 its, 3 1/2" tubing , GLM, pup & cut it. =464.05',Clean & clear floor, P/U BHA #7 = 5-7/8" Series 70 Short Catch Overshot (3-7/8" Grapple) , / X -O / 6-1/4" NOV Bumper Sub / 6- 1/4" NOV Fishing Jar / X -O / 9 ea. 6-1/4" DC / X -O / 6-114" NOV/ Intensifier Jar 1 X -O (312.21'),Change elevators and TIH to 3068'. No signs of fill. Hole fill= 22.7 bbl,P/U Kelly and tag top of Long String @ 3081'(PUW 70k SOW 65k W/O pump) , CBU @ 8 bpm wl1550 psi, Max gas 505 unfts,Attempt to rotate down over fish, set down 10k but would not go into grapple. Repeat several times with same result. Stand back Kelly .,POOH and work BHA (Hole fill = 23.6 bbl),Swap out Overshot grapple from 3-7/8" to 4-114", TIH to 3068',Pick up Kelly, tag top of fish @ 3081', Work over fish and perform blind back off. 4/23/2019 Engaged top of US @ 3081, up wt 70k, on wt 65k, picked up U 95k, put 2 left turns in string worked tq down got a back off with 9 turns, appears we have 6k # fish,Stand back Kelly, POOH to to fish. Release overshot from fish. (Calc. hole fII=24.7 bbl, Actual hole fill = 24.7),POH LD fish. Hot tapping its above the collars to release trapped pressure. Recovered 1 it, GLM, and 13 more its by 1800 hrs. Filled 2 drums with coal and sand from inside pipe.,Continue POH LD fish, tapping jts above the collars to release trapped pressure. Recovered 3 jts tbg., 10' pup, 8 its tbg., 6' pup, 1 jt. tbg, GLM and 1 jt tbg. (Total fish recovered: 27 it. tbg, 2 GLM's and 2 pups= 856.15' , Calculated top of Long String 3937') Filled 3rd drum with coal and sand from inside pipe. (Actual hole fill for fish = 9.9 bbl, Calc. hole fill = 2.7 bbl),Clear tubing jewelry and equipment off rig floor. Clean rig floor of mud and coal from inside fish. Prep to test BOPE - Blow down surface lines, Drain stack, M/U 3-1/2" test it. , Set test plug in wellhead, Fill stack and surface lines wl FIW. P/U Kelly and make up to test jt,Testing BOPS. (AOGCC witness of BOPE test waived by Mr. James Regg)Continue clearing and cleaning rig floor of mud and coal that came from inside fish. 4/24/2019 Continue testing BOPS. Test annular, Upper rams, Choke manifold valves, Choke line valves, Kill line valves, Floor valve, Dart valve, Upper and lower Kelly valves, to 250 and 2500 psi. Test gas alarms and PVT.,Had an issue with the packing going out on the #2 accumulator pump. Replace packing and test pump.,Perform accumulator test. Test blind rams to 250 and 2500 psi. Test all 3 chokes. Had to pump through hyd choke to wash the debris out of it before it would hold pressure.,Pull test plug and RD test equip.,PU and MU BHA #9. Run 8 1/8 cut lip guide, 8 1/8 bowl (4 1/4 grapple], Dbl pin bushing, 8 1/8 bowl (3 718 grapple], top sub, pump out sub, xo sub, bumper sub, jars, xo, 9 - 6 1/2 DCs, xo, intensifier jar, xo = 324.74,RIH to 3399' (Act. displacement on TIH = 23.8 bbl, Calc. displacement =26.8 bbl)),P/U Kelly and M/U to string. PUW 73k SOW 63k. Tag top of fish @3431'.,Wash over fish @ 30spm w/ 450 psi. Set 10k on fish and P/U to 90k (17 k over) to verify grapple engaged pipe. Attempt to pump down pipe was unsuccessful.,Work pipe to unsting from collet latch. Worked up to 50k over with no success. Jars opening but not hitting. Perform blind back off , came free at 33 turns with 78k string wt. (+5k)+,P/U and break off Kelly (connection between Kelly and DP loose) , drop bar to open pump out sub, Kelly up, circulate and condition mud for balanced mud wt. in and out. Stand back Kelly., POOH to BHA. (Found 6 DP connections loose). Work BHA 4/25/2019 POH laying do Intensifier jars and standing back 3 stds of DC. Pull fish to table and break off bottom bowl to release grapple. Breakout pump out sub --and the rest out the V-door.,RU power tongs and equip to LD 3 112 dog, and POH laying do fish. LD 5 jts of tbg drilling holes above collars and bleeding off press., Flow nipple boot started leaking. Shutdown and got it stopped temporarily. Will change out boot when we get out of the hole.,Continue POH to bottom of jt #6 where we encountered lots of trapped press and coal. Pipe stayed packed off with coal to bottom of jt #9 where we encountered even more press, but it turned into a wet strong pungent smelling liquid instead of coal. Then turned into clear water until the bottom 13 of it where it went to dirty water. Then it was watery sludge up to it 18 where it drained due to 5 holes in the pipe.,Top of GLM was backed off about 112 way. Got a total of 19 jt and 1 GLM out of the hole. Top of SS at 4013'.,UD last it. offish and clear floor., R/U to perform an injectivity test. Fluid pack hole and choke manifold. Close choke and begin to pressure up. Kill line plugged off with coal @ the 2" targeted tee from the hose to kill line valves, Break off kill line and clean out tee. M/U tee and hose to BOPE and attempt to pump again. Kill line again plugged off at tee and both the manual and HCR kill line valves.,While clearing kill line mechanic changed out Hyd motor on ST-80 and crew replaced boot on flow nipple.,Check suction screens on pumps (Clean), PIU Kelly and pump 100 bbl @ 10 bpm to flush out mud lines. Pump 20 bbl @ 10 bpm through kill line to flush.,Line back up to conduct injectivity test. Pressure up to 450 psi w/0.4 bbl pumped. Attempt to bleed off through choke unsuccessful. Bleed off through stand pipe bleed off valve. Tie into annulus valve in well head room to verify no pressure on well bore and open blind rams. Circulate through kill line to verify it was still clear.,Break off choke line at BOPE. 2" targeted tee packed off with coal.,Clean out tee on choke line, blow air from choke manifold to verify hose is clear. M/U tee and hose on BOPE and blow air back through to well to verify HCR and manual valves are clear. Pump 10 bbl @ 7 bpm through choke manifold.,Line up on #2 MP to conduct injectivity test. Begin pressuring up and blew pope-off at 1250 psi.,Line up #1 MP and pump 20 bbl at 10 bpm to flush mud lines. Close in well and perform injectivity test: Pressured up to 2500 psi at 2.7 bbl pumped. Pressure bled off 150 psi over 10 minutes. Bled off pressure and got 2.7 bbl back. Blow down choke manifold.,Stage fishing tools and P/U BHA #10. Run 8 118 cut lip guide, 8 1/8 bowl 14 114 grapple], Dbl pin bushing, 8 1/8 bowl [3 718 grapple], top sub, pump out sub, xo sub, bumper sub, jars, xo, 9 - 6 112 DCs, xo, intensiferjar, xo = 324.74 4/26/2019 Finish PU BHA and RIH checking all the connections on the DP to 3900'. PU 15' pup to space out.,PU Kelly and break circ pumping 3 BPM 500 psi. Up wt 79k, Dn 67k, Rt 72k. Tag top of fish ar 3937'. Rt to get do over fish and work do to 3 7/8 grapple where we had 500 psi increase in pump press. Shut do pump and set down to swallow collar, PU in stages to 200k to attempt to release pkr. Then start cocking the jars and firing them with 100 over for 11 licks, then picking up to 120k over. No movement at pkr.,Talked to town and decision was made to do a manual backoff. Worked pipe f/ 100k t/ 80k while putting 17 rounds to the left before pipe came free. Had 11 k extra wt. Drop bar for pump out sub.,Shear out pump in sub and circ bottoms up. Blow do and set back kelly,POH wl fish from long string. Work BHA„Unable to release 3-7/8" grapple from fish. Lay down top it. with grapple attached. UD remaining fish taping each it. checking for trapped pressure. There was a small amount of pressure on 2 joints and all its; were packed with bar and coal. A # 5 had 3 holes in tube and it 6 had one. Recovered 6 it 3-1/2" tbg, i pup it and a X/O sub for a total length of 186.69'.,P/U bumper sub and fishing jars and break down same. UD all fishing tools form rig floor.,Clear and clean rig floor. Dilute active mud system wt. back for upcoming cement job. Get rig floor and handling equipment ready to TIH with CIBP on 3-112" DP. Crane crew offloading cement equipment and product off boat„P/U TriPoint Bridge Plug assembly and make up on bottom of 3- 1/2" DP pup it. RIH wl3-1/2" DP (running speed<60 ft/min.) BHA= 9-5/8" 36-53.50# MMR Bridge Plug, MMR Mechanical Setting Tool, 3-1/2" IF Box X 2-7/8" EUE Pin Crossover, 3-1/2IF 15' DP Pup Jt= 21.43' 4/27/2019. RIH w/ Tripoint BP to 4000'.,Put BP on depth on the up stroke. Put 10 turns to the right to attempt to set BP without success. Attempt to set twice more with same results. RU head pin and circ while working pipe from 4010' to 3997' to clean up area where we wanted to set BP. On second stroke up BP set at 4008'. Set back do 30k on BP to ensure it was set. PU to do wt and test above BP to 1000 psi for 5 min. Good test. Release f/ BP and PU 5' above.,Circ to get mud wt evened out at 4.5 BPM and 1100 psi. Started with 16.4 ppg coming out. Circ until our mud wt was an even 15.3 ppg.,POH with BP setting tool. LD setting tool and clear floor.,RU tbg equip, MU diffuser on it of 3 112 butt tbg. RIH PU 16 jts 3 1/2 tbg and XO = 529.91 RD tbg equip. Had tripping BOP drill with excellent response time.,PU 15' pup and a sng & RIH w/ 3 1/2 DP. Tag CIBP @ 4008'.,Circulate and condition to balance mud wt. @ 15.3ppg both in and out, Run Haliburton hard line to rig floor and tie into rig floor mud manifold while circulating., PJSM with Haliburton and crews on cement job. Prime Halliburton pumps, fill lines w/ 5 bbl. H2O, Test lines to 500 psi Low / 2000 psi High (Good Test). Pump 3.6 bbl H2O ahead, Mix and pump 31 bbl of 15.8 ppg Class G cmt. @ 3 bpm w/ 600-650 psi., Clear cmt lines w/ 2bbl H2O. Rig displaced cmt with 24 bbl. of 15.3 ppg mud @ 4.5 bpm w/1000 psi.,POOH 5 std @ 30 filmin. Continue POOH 5 more stands to 3000' (CIP@2300 hours),R/U and pump Nerf Wiper ball down string to clean out residual cement in pipe. Circulate and condition mud to balance mud wt, going in and out.,POOH w/DP. UD 1 it. 3-1/2" DP and 15' DP pup. Had tripping BOP drill with response time of 98 seconds.,R/U tbg. equipment. POOH and stand back 5 stands 3-1/2" tbg. UD 1 jt. tbg, and diffuser it. 4/28/2019 Clean cmt out of diffuser and rig floor.,Cut drilling line and clean work on cleaning Swaco mixing tank. Finish picking up all the tools a getting everything set for tripping.,RU to RIH wl bit, & bit sub. RIH and tag cmt at 3635'. Set do 15k.,Test csg and cmt plug to 1650 psi for 30 min on a chart. Lost 100 psi in 30 min. RD test equip.,POH LD all 3 112 DP. (Bled OA off from 90 psi to 6 psi),Clear and clean rig floor of all 3 1/2" DP equipment. Stage 9 5/8" and 5" ram blocks in cellar to be installed in UPR and LPR.,BIow down surface lines and choke manifold. Drain stack,Install 9 518" ram blocks in UPR . Made up 9 5/8" test it. while installina rams. Installing 5" rem blocks in LPR 4/29/2019 Finish changing lower pipe rams to 5". Pu tools and equip.,RU to test upper rams on 9 5/8. Test upper rams, Dart valve, and Floor valve to 250 and 2500 psi. Break do 9 5/8 test jt and MU 5" test it. Test lower rams and annular on 5" to 250 and 2500 psi. RD test equip.,Strap 5" DP. MU Tripoint BP and RIH PU 5" DP to 1520'„5' in the hole to the setting point at 1540'. Slack off to 1545' and pull back up to setting point. Put 10 rounds in and slacked off. We repeated this more times than I can count in different sequence's. We tried pumping on it, Stroking it farther, rotating faster, and slacking it off faster, and we finally got it set at 1540'. Set do 25k and PU to 90k [up wt 41, do wt 39k] Release from BP and PU 5' above.,Circulate and change over mud to 12 ppg mud from reserve pit, taking 15ppg mud back to pits #2 & #3. Continue circulating until mud balanced (12.1 ppg in and out),POH w/ Tripoint running tool and UD same.,M/U casing cutter BHA (#11) and RIH on 5" OP to 1487'. BHA #11= A-1 Casing Cutter, 8 1/2 Stabilizer, X/O, 9 ea. 6 1/2" DC, X10=289.14,P/U Kelly, slack off pumping lbpm w/ 200 psi and locate 9 5/8 casing collar @ 1508'. PIU and prep to cut casing @ 1500'.,Cut casing @ 1500'w/70 rpm, 1.75 torque , 2.7 bpm, 750 psi,R/U hose f/ OA to choke manifold, Close bag and attempted to circ. down hole and out OA unsuccessfully. Pmp 20 bbl @ 1 bpm w/ 750 psi. No pressure increase on pump or sign of flow up OA. Appeared to be injecting. Shut down, bleed off pressure and open bag. Observed well- Static. Attempt to pump down OA with no luck. Pressured up to 1800 psi. Bleed off ressure and rig dawn lines. Break off and stand back Kelly. POH to DCs. Stand back 1 std DC. 4/30/2019 Finish getting floor ready for wireline. Spot wireline equip.,RU E-line. MU lubricator and hang wireline sheaves. MU and arm guns. RIH w/ guns and punch holes f/ 1474' U 1477'. POH., Pump do hole attempting to take returns from ann but mud just pumped away at 1.5 bpm and 50 psi.,RD E-line and prep to run cutter.,St-80 had a stainless steal line develop a leak. Have meth working on getting another line made., PU csg cutter and RIH using chain tongs and rig tongs. PU Kelly., Break circ, locate collar at 318'. PU to 308 and cut csg. 70 RPM, 2.2 BPM, 1050 psi., Bring on pump circ do ann. Pressure built to 900 psi and fell off. Started getting good returns. Circ clean. Loaded shakers with cmt and coal then cleaned up.,Stand back Kelly and POH, LD csg cutter and clear floor., Have PJSM w/ hands involved. Pump out stack. Pull and drain mouseholes. Pull master bushings. clean out drip pan and pull flow nipple. PU pickup slings., Pull all but 4 bolts on casing spool. Remove IA wing valve. Lay down pick up slings and change out with 1 1/4" double Leg slings from ISO tank., Pull casing spool free at 80 K with blocks. Slack back down and remove bolts from DSA, Pick up stack and riser. Run tuggers down through stack and mousehole. Pick up casing spool and set aside. Pick up new spool with riser., Remove plates and rubber from well head. Clean up well head and secure area with fire blanket.,Assist welder with welding emergency slips to casing stub.,Clean well head flange and set ring gasket. Set BOPE and riser down onto well head. Install and torque all bolts. 5/1/2019 Continue tightening up flanges on wellhead and riser., Production went down so we had to get out of the wellhead room while they were getting the wells back on line. Cleaned up and PU csg spear while waiting.,Return to wellhead room and tighten up flange bolts. Install turn buckles.,RIH and spear csg. Work up to 100k on the blocks. This is pulling 85k over. Decided we didn't want to pull anymore and risk the slingshot effect.,RU csg jack. Had to release spear and get jack set on table. Then run down through jack with spear and engage csg. Jack was missing the 3/8" bleed hose so we had to build a hose.,Start jacking csg out at about 230k, Drag increased to 450k after pulling up 20'. After pulling 5' more slip hung up in the stack. Slack back off and closed annular to keep pipe centered. Wt went back to 400k then slowly fell off to about 180k. Start palling with blocks and pull slips up to annular w/ 175k. RU with both tuggers and raise jack up about 15'. Break off 15' pup and sng. Set jack back down and pull pipe.,Pull pipe out of top of the jack. Move the jack over to the v -door and pull it off with the crane. LD sng and pup then pull hanger to the rig floor.,RU to LD 9 5/8 csg. and LD same. Laid down 7 joints including cut-off joint (262.00' total).,Pick up Kelly and flush stack. Make up 9 5/8" test joint.,Fluid pack stack and choke manifold. Shell test at 2500 psi. Test BOPE at 250 U2500 H. Lay down 9 5/8" test joint and install 5" test joint. Test at 250 U2500 H. Reform draw -down test. AOGCC waived witness at 1840 hours on 5-1-19. 5/2/2019 Test chokes, PVTs, and gas alarms. RD test equip and clear floor„MU csg cutter and RIH to 700'. PU Kelly, fill pipe.,Cut window in about 15 min running 70 RPM, 2.5 BPM, 500 to 800 psi. Circ until hole cleaned up. Getting back a lot of cmt from where we pulled the csg. Set Kelly back.,POH to cutter and LD same. Clear floor.,Service rig and repair safety Issues with V-door.,MU spear and RIH. Engage csg cut to ensure we were in it. Then release spear and break off sng.,RU csg jack and prep to pull on csg. Stag csg jack up to 500k. looked like it may have moved 1'. Work up and down but not gaining any ground. PU 100k on blocks and 600k on csg jack and it still wouldn't come free. Worked it up to 700k several times but still not coming free.,RD csg jack, leaving jack on rig floor.,POH and LD spear. MU csg cutter and RIH to 500'.,Cut casing at 500' in about 15 min running 70 RPM, 2.5 BPM, 500 to 800 psi. Circulate hole clean. Got back some cement from where we pulled the casing. Set Kelly back.,POOH and lay down stabilizer and casing cutter.,Pick up spear with jars and drill collars. RIH and engage fish at 310'.,Attempt to jar casing free working up to 150 K. Jarred 38 times with no effect.,Rig up casing jack and attempt to jack casing free. Worked up to 430 K on jack plus 100 K on blocks. Moved up hole 2.3' until no further movement. Jarred on fish up to 150 K 15 times with no success. Using casing jack picked up to 462 K and 100 K on blocks at which time grapple came free. Stopped operation and consulted with engineer.,Secure rig floor and rig down jack.,POOH and lay down spear. Repair ST -80 hose.,MU casing cutter and RIH to+-400'.,Locate collar at 395'. Cut casing at 409' at 70 RPM, 2.5 BPM, 800 to 1000 psi. Circulate hole clean. Got back some cement on returns. Set Kelly back.,POOH and lay down casing cutter. 5/3/2019 POH and LD csg cutter, MU spear w/ jars and RIH En a e csq at 310' and attempt to jar free oulling up to 200k but jarring at 150k. Release from spear.,RU csg jack. Pull 460k and csg came free. Continue pulling csg with jack for 34' until up wt was do to 125k.,RD csg jack and break do dbl that we had hanging.,POH to csg. Break loose grapple and pull out of csg stub. LD grapple. Break off jars and pups and lay them down. MU grapple on 5' pup and stab back in csg stub. Pull csg up to first collar and break out same. Pull grapple out of csg stub and lay do same. LD csg stub. Layed down 2 full its and to cut off csg stubs= 103.60',RD csg equip and clear floor.,MU spear and BHA & RIH to 407'. RU head pin to circ -Circ hole clean at 10 BPM. Got back a lot of thick cuttings and some fair size chunks of cmt. Got csg jack on the floor while circ.,Break off head pin and RU csg jack. Pull up to 385k and csg started moving. It did drag up to 4001k but started falling off as we jacked the csg out. Pulled about 36' and the wt got to 135k where we started pulling with the rig.,RD csg jack and remove jack from rig floor. Break do double and remove head pin.,POH to casing stub and get slips and dog collar clamp on casing at table.,lnstall derrick board mule for working drill collars.,POOH laying down fish. Recovered 1 full joint and 2 cut-off joints. 85.36' total.,Release spear from fish and make up spear BHA. RIH to +-500'.,Circulate hole clean at 10 BPM. Got back a lot of thick cuttings and some fair size chunks of cement. Get casing jack on the floor while circulating.,Rig up casing jack. Engage fish at 505'. Pick up and bleed off jars. Pick up on jack to 384 K /blocks 90 K (474 K total). Grapple released. Tried several times to get another bite and slacked off an additional 20' but grapple continue to slip. Rig down casing jack.,POOH and work BHA. Grapple came apart and missing one segment. Photos in o-drive.,Run spear helix in hole to 782' while waiting on grapple from beach.,Circulate at 10 BPM/240 psi to clean hole. 5/4/2019 POH with circ assem.,Get XO made up for bigger spear. Spear arrived on chopper at 7:22. [800 lbs of tools) Get spear to rig floor and MU on fishing assem.,RIH to top of csg cut at 500'. RU csg jack and sng above csg jack with a floor valve and head pin.,Jack on csg and csg started moving at 500k w/ jack. Then it started to hang up so we started pulling with the rig and jack. Moved up hole 7'. Had 550k on the jack and 150k on the rig and the grapple released making pipe jump., Inspect all our equip and everything look good. RD jack and attempt to break floor valve and head pin off sng w/ ST -80. It kept rising up when we went to grab the pipe. Put ST -80 to the side and use rig tongs., POH using rig tongs to spear. Inspect grapple and it was all there. Break down tools., MU csg cutter and RIH. Kelly up and fill pipe., Locate collar at 596 which is almost 7' higher than it was on the csg tally. Pull up 10' and cut csg at 586'.,Set Kelly back and POH to cutter. LD cutter.,Change out raise and lower control on ST -80. Still didn't solve the issue with it going up when grabber was set. Lubed rails for rig tong counter Ms. Pulled stop off V -door, ground it down where it wasn't dragging, and replaced it.,MU casing spear and RIH to +-500'. Rig up casing jack. Engage fish and set grapple at 513'., Bleed jars. Pull up with jack to 380 K/ blocks 50 K. Jack casing up hole 25' and drag came down to 165 K. Pull stand with 75 K over pull.,Rig down casing jack. Clear rig floor., POOH. Work BHA. No fish. 8.892 grapple had small crack (photos in o -drive) but should not have been enough to lose the fish.,Make up spear assembly with 8.642 grapple. RIH slowly looking. for fish and located at 405'. Work down with spear to 414'. Picked up with 10 K additional weight.,POOH and lay down casing fish. Spear had gone past casing collar and was difficult to release from fish safely. Recovered one full joint and two cut joints: 93.04'.,Clear rig floor. Adjust brake., Make up spear BHA. RIH. 5/5/2019 MU and RIH with spear to 567'.,Circ hole clean at 10 BPM. Got back a lot of cmt some of which were big chunks.,PU sng and engage csg at 596'. Jar 4 times at 175k pulling up to 3001k with no movement.,RU csg jack. Jack on csg pulling 465k before it started moving. Weight fell back to 360k and it was pulling good then grapple released. Re -set grapple and continue pulling at 375k w/ wt falling off. pulled 45' and wt was do to 165k. Pull up to next tool it, w/ wt falling of to 125k.. RD csg jack and POH to csg. 10' csg stub had a 6' long split in it. [Picture in O -drive] Layed down csg sub and secured well.,Shut down and work on ST - 80. Changed out hyd manifold and it still wasn't working right. Changed both return and discharge filters on hyd unit. Still not working properly.,Broke spear off bottom and stood back DC. LD sng DC from mouse hole. RU csg equip and LD csg. Recovered 2 cut its and 2 full its. =105.39, PU clean out BHA. Run 8 1/2 bit, bit sub, jars, 3 DCs, 3 stds DP, XO, 12 1/4 stab, XO. RIH to 150'.,Finish repairs on ST -80 and verify operational.,Continue RIH with clean out assembly (413.39') to 685'. Work through muck from 620' to 685'. Also, sticky going through well head.,Make up floor valve and head pin. Circulate hole clean at 10 BPM/940 psi while reciprocating pipe. Significant amount of cement chunks and fines coming back over shakers.,RIH to 740'. Wash down from 740' to 770'. Circulate at 10 BPM/940 psi while reciprocating pipe. Hole unloading with fist sized chunks of cement.,Wash down from 770'to 881' at 10 BPM/940 psi. Hole continuing to unload chunks of cement.,Circulate and clean hole at 10 BPM/940 psi while troubleshooting and repairing crown-o-matic.,Wash down from 881' to 1065' at 10 BPW940 psi. Stabilizer is 33' above casing stub. Hole continuing to unload chunks of cement.,Circulate hole clean at 10 BPM/920 psi while reciprocating pipe. 5/612019 POH and LD clean out assem.,Change hyd return filter on ST -80. Adjust linkage for functions. ST -80 is working good now.,MU csg cutter and RIH & into csg to 800'., Locate collar at 802', PU to 797' and cut csg. Set Kelly back and RIH to 910'. PU Kelly and locate collat at 920'. PU to 915' and out csg. Set Kelly back. RIH to 1030'. PU Kelly and locate collar at 1040'. PU to 1035' and cut csg.,Set Kelly back and POH. LD csg cutting tool.,MU spear and PU jars. RIH to top of flsh,RU head pin and circ hole clean at a high rate. Get csg jack on the rig floor while circ., RU csg jack. Engage csg. Clear floor and jack on csg working up to 600k. Grapple slipped several times then grabbed again. No movement. Pull slips out of jack and jar with rig at 150 to 175k then pulling up to 200k in an attempt to break csg away from side wall. Go back to csg jack and up to almost 600k pull and grapple started slipping again. Reset grapple. After about 4 time decided grapple wouldn't hold. RD jack.,POH to BHA and work DCs.,Lay down spear BHA. Pick up casing cutter BHA.,RIH with casing cutter to +-710'. Pick up Kelly. Looking for casing collar at 763' but unable to work past 746'. Pick up to 745' and make casing cut.,Set Kelly back. POOH and lay down casing cutter.,Clear rig floor. Service rig.,Pick up and make up Baker 8.681 spear assembly. RIH to 680'.,Engage fish at 684'. 32 K P/U and S/O. Jar on fish at 175 - 200 K. Moving up hole every lick as much as 1 foot. 26 licks and pulling without jarring at 80 K.,POOH with as much as 180 K drag to +-410'. Continue POOH to BHA., Release spear. POOH laying down fish. 5/7/2019 POH laying on 9 5/8 csg. recovered 2 out off jts=51.50'. Csg was swelled just below collar. Lay down 3 its of 5" DP.,Service rig and clean off floor. Prep C/O BHA, wait on bit breaker,MU clean out assem.- 8 112 mill tooth bit, bit sub, bumper sub, fishing jar, 5' pup, xo, 3- 6 1/2" DC, xo, intensifier, 5' pup, 7 its 5" DP, 12 1/4" stabilizer = 375.89',TIH t/ tag @ 750', PIU & I/d single, p/u Kelly.,CBU @ 10 BPM, 270 psi, rot 48 rpm ,up do wt 44k, on wt 43k, rot wt 42k, Packed off cutting chute, shut down & clear.,Pump 10 BPM, 270 psi, rot 48 rpm ,up wt 44k, do wt 43k, rot wt 42k, Wash & ream if 733' U 751', not making headway, stand back kelly,POOH, I/d clean out assembly BHA.,Pick up Baker spear assembly with 8.681 RIH grapple. with same to 720'.,Engage fish at 744' and work spear down to 754'. 34 K P/U and SIO. Attempt to grab without success.,POOH with spear assembly (wet).,Work BHA. Jars were plugged with coal/clear same. Make up clean out assembly: 8.41 Tapered mill, 8.5 reamer, bit sub, bumper sub/fishing jars, pup joint, XO, DC's, XO, intensifier, pup joint, 3 joints DP, 12 1/4 stabilizer = 258.63'.,RIH with clean out BHA to 730'.,Pick up Kelly. Establish parameters: 43 K P/U & S/O, 43 K Rot/75 RPM w/1800 ft/lbs torque. 8 BPM/180 psi. Wash and ream through 750' - 752' with 2.5 K torque (1 hour to work through). Area was pinched., Wash and ream with above parameters at 10 BPM/250 psi. Continue W/R from 752'to 996'. This puts the 12 1/4" stabilizer +-15' above TOF at 744'.,Circulate hole clean at 10 BPM/290 Psi.,POOH with clean out assembly. 5/8/2019 POOH with clean out assembly- Light wear on mill.,P/U BHA # 35- Spear w/bullnose dressed w/ 8.681 grapple, 2- ext, pup it, stop sub, bumper sub, jar, pup it, X0, 3-6 1/4 DC, xo, intensifier = 159.17',RIH U762' engaging fish, P/U jar @ 135k x2, p/u t/ 210 started moving pipe, drug up hole 35' weight fell off U50k„Cont. POOH I/d BHA & release grapple from fish, I/d same recovered 38' (2 -cut jts),P/U BHA # 36- Spear w/bullnose dressed w/ 8.681 grapple, 2- ext, pup jt, stop sub, bumper sub, jar, pup it, xo, 3-6 1/4 DC, xo, intensifier, pup it = 174.28', tih t/736'.,Wash down U 792' @ 10 bpm, 850 psi, tag up attempt to wash and work through without success.,POOH and lay down spear assembly.,Make up BHA #37 clean 8 1/2" out assembly: bit, bit sub, BS/OJ's, pup joint, XO, DC's, XO, intensifier, pup joint, 5" DP, 12 1/4" stabilizer = 194.18. RIH to 760'.,Pick up Kelly. Parameters: 43 K P/U & S/O, 43 K Rot at 75 RPM/2 K torque. 10 BPM/250 psi. Wash and ream from TOF at 790' to 984'. Stabilizer at TOF. Finished repairs on shaker. Increased pump rate to 14 BPM/450 psi.,Circulate hole clean at 15 BPM/500 psi while rotating and reciprocating pipe. Hole unloaded with fist sized chunks of cement. Recovered 5 buckets of cement chunks. "Flow trough is maxed out at 15 BPM.,Set Kelly back. POOH with BHA #37 clean out assembly to BHA.,Work BHA. Pick up Baker spear assembly BHA #38: 8.681 spear, 2 extensions, pup joint, stop sub, BS/OJ, pup joint, XO, DC's, XO, intensifier, pup joint = 174.28,RIH with BHA #38 to 790'. Establish parameters: 43 K PIU & SIO. Rig up jack.,Set grapple at 816'. Jar on fish at 200 K and pull up to 275 K. Moved fish up hole +-10. Using jack pull up to 500 K on jack and 75 K on blocks with no further progress. Rig up cement hose and attempt to hydraulic assist with pump pressure to no avail.,Rig down cement hose. Release spear. 5/9/2019 Attempt to release spear from csg. Tried spudding the pipe down numerous times, tried putting right hand torque in the pipe. Tried circ at a high rate to clean it up. Continued jarring 15 to 20 times then pulling with the jack up to 650k. Csg moved up hole 6 more feet. Jar another 15 time and pull up to 750k with the jack with no movement., Discussed options with town and decided to keep jarring and pulling with jack. Jarred at 200k and pulled back up to 200k the spudding pipe down 25 times with no movement. Jack up to 750k and csg started coming free. Continue iacking up 45' until wt fell back to 175k Pull up to TJ with rig., RD jack and break down stand. Top sng of 5" DP was bent and had grooves cut from the slips.,POH to where top of fish was about 50' from the floor and it started to drag up to 75k. Attempted to work on and it wouldn't go. Work it up to 150k and it slid up hole to 48.89'. Attempt to work it up and do with no movement. Attempt to put left hand torque but it acted like it broke in a service break on the tools. Make it back up and put torque to the right and the grapple released.,Pull spear out of csg and it hung up coming out the top where we had to put another 1/2 turn of right hand torque to release it. Left top of fish at 48.89'.,POH and inspect tools. Everything looked good. Break on and LD the fishing assem. Clear floor and beaver slide off.,MU test jt and put in the door. Ann valve is plugged. PU Kelly w/ a pup on the bottom and flush the stack.,Drain stack and land 9 518 test jt. RU to test BOPS. Fill stack with FIW. Pull test joint due to crew failing to install ported sub on test joint. Reinstall test joint. Fluid pack stack and choke manifold. Shell test at 2500 psi.,Test BOPE on 9 5/8" test joint at 250 1./2500 H. Perform accumulator draw -down test. AOGCC waived witness at 12:00 PM on 5-8-19 (Jim Regg).,Lay down 9 5/8" test joint/make up 5" test joint. Set Kelly back. Test BOPE (annular and lower pipe rams) on 5" test joint at 250 U2500 H.,Rig down test equipment and lay down test joint. Set flow nipple back in place.,Make up spear assembly BHA #39: pack -off, 8.681 grapple, 2 extensions, stop sub, pup joint = 25.13. Set casing jack on rotary. 5/10/2019 RU csg jack. RIH with spear into top of csg at 49'. Engage grapple. RU and attempt to cir but fluid started pumping away. Start to jack on csg and increase pull up to 490k where csg started to move. Jack csg up about 20' to where wt had fallen back to 125k. Pull up with blocks to 2nd tool joint., RD csg jack and LD 2 its 5" DP. Pull up and LD 15' pup. MU 5' pup and pull 5' csg stub and collar to floor. Attempt to release grapple but it wouldn't release.,PU csg with grapple still engaged to 2nd collar. Csg was crushed above, at, and below collar. Had to cut the csg off and put holes in the collar for shackles. LD Fishing tools, Csg stub, and full it of csg. Pull next It with shackles and slings. It was also crushed above, at and below the collar. Collar was 12" X 9 3/4", LO las it and clear floor. Recovered to cut off its, and 2 full its csg. 114' csg recovered.,Clear floor of tools and clean up same while waiting on crane to unload boat.,PU clean out BHA #39. At 60' we sat down and couldn't work through. PU Kelly and washed and reamed through. continued to RIH to 315' and we sat do again. PU Kelly and washed and reamed through chunks that were drug up hole from the csg we pulled. RIH to 850'.,Wash and ream from 850'to 1127' putting 12 1/4" stabilizer on TOF at 915'.,Circulate hole clean at 17 BPM/620 psi while rotating and reciprocating pipe. Got back impressive amount of fist sized cement chunks.,POOH with clean out assembly BHA #39. Laid down 7 working joints., Pick up BHA #40 casing cutter assembly. RIH to TOF at 915'.,Pick up Kelly. Locate collar at 9597cut at 956'. LC at 1000'/cut at 997'. LC at 1080'/cut at 1077'. Locate collar at 11197cut at 1116'.,POOH with BHA #40 casing cutter assembly. 5/11/2019 POH w/ csg cutter BHA #40, and LD same, PU spear assembly BHA #41 and RIH to top of fish at 915'., Engage csg with spear. Set grapple and bleed jars. PU to 160k and casing came free., POH with csg. Release spear and stand spear assem back in drk. LD 41' of csg with one collar 5' on from the top., PU clean out assembly BHA #42. Bit, bit sub, 1 jt DP, 12 1/4 reamer and RIH to 890'.,Wash and ream f/ 895'to 991'. Putting 12 1/4 stb at 956' top of cut. Ream at 16 BPM and or hole clean at 20 BPM getting back large chunks of cmt.,Set Kelly back and LD 2 sngs. POH to 12 1/4 stab and LD stle. Laying jts with bit sub and bit out the door.,Latch up spear BHA #42. We had standing in the derrick and RIH to top of fish at 956'.,Engage csg with spear and set with a left hand turn. PU to 125k to bleed jars and csg came free. LD 2 jt.,POH to top of csg. Lay down fish and stood back spear assembly BHA #42. Recovered 40.85' of fish TOF now 997'.,Pick . up clean out assembly BHA #43: 8 1/2" bit, bit sub, DP, double pin sub, 12 1/8" string mill, XO = 48.16. RIH with same to 930'.,Wash and ream from 930' to 1036' placing string mill on TOF at 997'. Hard cement while reaming. Cuttings now coming back quarter sized pieces due to string mili.,Circulate hole clean at 18 BPM/500 psi while rotating and reciprocating pipe at 75 RPM.,POOH with BHA #43 clean out assembly.,Pick up and RIH with spear assembly BHA # 44. Engage fish at 997'. Jar one time at 135K and fish was free. Pull up 30' with +-4 K over.,POOH with fish. 4 K drag.,Release spear. Lay down fish, recovered 37.60'. New TOF at 1035'.,Clean rig floor and wind walls and recover large cement chunks out of flow box.,Pick up BHA #45 clean out assembly. RIH to 997'.,Wash and ream from 997 to 1030' at 18 BPM/450 psi. 5/12/2019 Wash and ream from 1030' to 1073' at 18 BPM/450 psi, 75 RPM 2k TO, Circ hole clean at 20 BPM, 600 psi.,POH wl clean out assembly BHA #45. LD 12 1/8 string mill and sng w/ bit sub and bit.,PU stand with spear BHA #46. Breakout and change grapple to 8.90. RIH to top of fish at 1035'. Engage csg and set grapple. Bleed jars and pull 160k where csg came free. Wt fell back to 75k after a few feet and 50k after pulling 40'.,POH to csg, Release spear and stand spear assem back in the drk. LD 40.88 csg. New TOF 1077'.,MU clean out BHA#47 assembly and RIH to 1035'.,Wash and ream from 1036to 1117'. Circ hole clean at 20 BPM 600 psi. Got mostly ground up cmt back with very few chunks.,POH with cleanout assemBHA #47.. LD 12 1/8 string mill and lay sng w/ bit sub and bit out the door. 8 1/2 bit is worn out.,Latch onto spear assembly BHA #48 out of the derrick and RIH to top of fish at 1077'. Engage csg and set grapple. Bleed jars off and PU to 140k where csg came free. Pull up with minimal dmg.,POH to casing. Release grapple and stand back spear assem stand. LD 40.47 csg.,Make up BHA clean out assembly BHA #49: 8 1/2" mill tooth bit, bit sub, 6 ea. 5" DP, sub, 12 1/8" string mill, XO = 207.38. RIH to TOF at 1117'.,Pick up Kelly. Wash and ream from 1117' to 1318'. 80 RPM/1.5 K torque. 18 BPM/1120 psi. 18 BPM/1120 psi.,Circulate and clean hole at 20 BPM/1370 psi while rotaing and reciprocating pipe.,Set Kelly back. POOH with BHA #49.,Make up BHA #50 casing cutter assembly: A-1 casing cutter, 8 1/2" stabilizer, XO, 2 as DC's, DP it, XO = 103.86'. RIH to 1115'.,Kelly up. Make several attempts to locate casing collar at 1161' but having no luck. Pull up hole above TOF and unable to get knives to retract after several attempts -Set Kelly back. POOH with casing cutter assembly. Inspect cutter knives (good). Cutters caked with cement/barite, Re -tape knives., RIH with BHA #50 casing cutter to TOF at 1117'., Kelly up. Locate collar at 11617cut at 1158'. Locate collar at 1202'/ cut at 1199'. 5/13/2019 Locate collar at 1243', PU and cut at 1240', Locate neM collar at 1278', PU and cut a[ 1275'.,LD 4 its of DP and POH. LD scg cutting assem. Hole fill 1 bbl over calculated. Mud wt 11 A ppg, vis 46.,PU spear assem and RIH w/ BHA #51 to top. of cut at 1117',Spear into csg and engage grapple. Pull up to 160k and jars went off pulling csg free. Had about 25k drag for 35'. POH to csg. Release grapple and stand back spear assem. LD 40' of csg.,MU clean out assem and RIH to 111 T -Wash and ream from 1117 to 1190'. While picking up to make a connection we lost Rig power. Shut annular and secure well.,Trouble shoot power situation. Decided to put rig on platform AC power while electrician trouble shoots problem with DC power., Platform electrician continuing to trouble shoot the DC power to rig issue. Brought another electrician out and he had us running within 20 min., Finish cleaning out to 1199' at bit and reamer at 1158'. Circ hole clean. [ Did have to rotate to get bit back in csg at 1158' when we pulled back out of it.j,POH wl clean out assembly and lay down string mill.,Make up spear assembly and RIH to 1158'., Engage fish at 1158' setting grapple at 1173'. P/U to 160 K and fish was free. POOH. Recovered 40.92'., Pick up clean out assembly. Wash and ream from 1199' to 1238'. Circulate hole clean at 20 BPM/1350 psi., POOH (lay down 3 working joints) to BHA.,Work BHA. RIH with spear assembly to TOF at 1199'.,Engage TOF at 1200'. Set grapple at 1215'. P/U to 135 K and bleed jars. Pull up to 180 K and fish came free. POOH with fish. New TOF at 1240'.,Work BHA, Rack spear back in derrick. Recovered 40.20'.,Pick up clean out assembly. Wash and ream from 1240' to 1280'. Circulate hole clean at 20 BPM/1360 psi.,Set Kelly back. POOH with clean out assembly. 5/14/2019 POOH with clean out assembly. LD string mill and sng w/ bit sub and bit.,PU spear assem and RIH to top of cut at 1240'. Engage csg and set grapple. PU to bleed jars but csg came free at 120k. Had 100k drag for 10' the fell back to up wt of 55k.,POH to csg. Release grapple and stand back spear assem. LD 34.90 csg.,PU long clean out assem. RIH to 1250' and it started taking some wt.,Wash and ream f,' 1250' U 1409'. Circ hole clean while reciprocating pipe at 19 BPM 1265 psi.,LD 5 sngls and POH. LD 12 1/8 string mill, stand back 1 stand, and LD sng w/ bit sub and bit.,Service rig and adjust clmks brakes. Lock nuts were loose on brake adjustments. Inspect the rest of the brake adjustments.,MU csg cutting tool and RIH to 1270' where it started taking wt.,Work and rotate f/ 1270' into top of csg @ 1275'. Work down to 1300', PU Kelly, wash and work down to locate collar @ 1313'. PU and cut csg @ 1311'.,Work down to 1324' in an attempt to locate collar @ 1355'.,Stand back Kelly, POH and LD casing cutter assembly. Nose of cutter assembly packed off with cement.,PU stand with csg spear assembly, change out grapple and remove pack -off. RIH to TOF @ 1275'. Engage casing and set grapple. PU to 140k to bleed jars, PU to 225k. SO to 30k, PU to 1501k and trip jars, PU to 2251k, SO to 25k, PU to 165k and trip jars, PU to 1751k where pipe came free, up wt fell back to 60k once pipe was frea.,POH to casing. Release grapple and stand back spear assembly. LD 36.35' csg.,PU long clean out assembly, RIH to 1277'. PU Kelly and Wash down into TOF @ 1311'. Took wt at 1314'.,Wash and ream F/ 1314' to 1410' . WOB=1-4k , RPM=65, TQ+500 ft/Ib, 945 psi @ 16 bpm 5/15/2019 Finish washing and reaming f/ 1410't/ 1444'. Circ hole clean.,POH to 1122' working through a couple spots that pulled 15k over. RIH with no tight spots. Circ hole clean while reciprocating the pipe.,Set Kelly back and LD 4 sngs. POH to string mill and LD same. Stand back 1 std, and LD sng w/ bit sub and bit., Dress and MU csg cutter and std of DCs.,RIH w/ csg cutter to top of csg at 1311'.,Had to turn pipe to get into top of csg. Locate collar at 1355', PU to 1352 and out csg. Work do to next collar at 1395', PU to 1393' and cut csg.,LD to sngs and POH laying do csg cutter. Last trip for cutter so we had to break everything dn.,PU spear assem and RIH to top of csg at 1311'. Engage csg and grapple already set. Set jars off at 1501k and pull up to 225k and it pulled free. Lay do extra sng.,POH to csg and break grapple loose. Stand back spear assem and LD 40' csg. New TOF at 1352'.,MU clean out assem and RIH to 1311'.,PU Kelly, wash and ream f/ 1311' to 1383'. WOB =0-5k, -14 bpm w/ 740 psi, 60 rpm w/0.65 TO. Make mouse hole connection. Unable to re-enter TOF @ 1352'. Make multiple attempts to enter TOF w/ no success. Mixed 10 Ib/bbl Baracarb 25 (70 sx) over one circulation., POH with bit and string mill. (Stopped once inside 13-3/8" csg shoe and made soft break on WOTCO tool.) Break off bit and MU 8.25" tapered mlll.,RIH to 1343'. PUW=51 k, SOW=47k,P/U Kelly and tag TOF @ 1252'. Had to rotated and mill f/ 1354'- 1355to get top of mill into csg. PUW=55k, SOW=47k, ROT wt.= 501k, 12 bpm=290 psi, 60 rpm, 0.5k TO. Washed and reamed down to 1386'. Pull up out of csg and attempt to run back in w/o rotary. Took wt at TOR Attempts to re-enter csg were unsuccessful. Discussed with town and decision was made to POH to examine tapered mill. Stand back Kelly.,POH, LID taper mill and string mill assembly.,P/U spear assembly and RIH to TOF at 1352'. Engage csg and set grapple. P/U to 150k and trip jars. Pull back up to 125k and pipe pulled free. L/D extra 2 singles. Pulled 75-125k for first 40' off boftom.,POH to csg and break amoole loose. Stand backs ear assembly and LD 1.65' cs . New 10 of csg 1393' 5/16/2019 PU long clean out assem w/ collars and jars.,RD hyd jack power pac so we could get it on the boat to give the cementers room.,RIH w/ clean out assem to 1376',Wash and ream f/ 1376' tt 1529'. Had to work and put 1/2 turns in the pipe to get into the csg cut at 1393', both times. Run 16 bpm, 1300 psi, 75 RPM -Circ hole clean at 20 bpm, 1700 psi, 20 rpm.,Monitor well and POH laying do 2 sngs. POH to BHA,LD clean out BHA and clear floor of csg tools.,RU to PU and run 3 1/2 tbg cmt stinger. PU defuser, 9 its off deck and run 5 stds out of the derrick. MU XOs. Swap equip back over to 5" and RIH on 5" DP. Didn't even see the tap of the csg and went right to 1529'. RU to circ.,Circ wl rig pump while waiting on Halliburton to get primed up. 5 bpm 350 psi.,PJSM with Haliburton and rig crews. Pmp. 5 bbl water, PT lines w/ 500 psi low and 2500 psi high (Good), Mix cement, pmp. 3 bbl water, 80 bbl 15.8# class "G" cement @ 4.3 bpm 460- 320 psi, displace lines w/ 2 bbl water. Switch to rig pump and displace cmt w/ 9 bbl of 11.1 ppg mud @ 4.6 bpm 230 psi. RID cmt hose and head pin. CIP @ 1945 hours / Calculated TOC-950',POH 7 2/3 stands to 808'. Load wiper plug, M/U head pin and cmt hose. Circ and clear pipe of cmt. RID cmt hose and head pin.,UD 5" pup it and 2 X/O's.,Change out handling equipment and R/U tbg. tongs. POH UD 3 1/2" tbg and diffuser. RID 3 1/2" handling equipment.,RIH w/ 5" DP to 755'. Load wiper in pipe, M/U head pin and cmt hose. Circ and clear pipe of cmt. RID cmt hose and head pin.,POH LID 9 it. DP. Stand remaining 5 stands back in derrick.,L/D stand of 61/2" DC in derrick.,WOC. Clear and clean rig floor. LID rental tools and subs. Transferred 84 bbl of 11.1 ppg mud from active system to ISO tank. Cleaning mud pits. 5/17/2019 Continue cleaning and clearing rig floor of entre tools.,MU 12 1/4 bit W/ 12 1/8 string mill and RIH. Tag cmt at 1013' and set do 10k.,PU Kelly and circ hole clean. Got back cmt and contaminated mud that kept blinding off the shakers. Filled up 1 1/2, 13 bbl totes.,RU and test csg to 1000 psi for 30 min on a chart. Had to pressure up 3 times due to leak on arm valve, and air in system. Lost 75 psi in 32 min.,RU and displace we withat 4 lus cmt line,RTII line, and choke manifold w/ F also.,POH laying do 5" DP and BHA.,Clear floor of tools and equip. RU and fII BOPS with fresh H2O. Pump through cmt line and flush kill line, choke line and choke manifold with fresh H2O. Function BOPE to clean out ram cavities -Drain BOPS with 3" trash pump. Load cargo basket with X/Os off rig floor.,Clean out flow box, pull mouse holes, pull flow riser and remove flow box boot flange and double boot flange from top of annular. Remove choke and kill lines. ND annular. Open double gate BOP and remove ram blocks. Clean ram cavities and grease sealing surfaces. Remove annular from cellar with crene.,Continue with ND and removal of BOPS from cellar. (Remove ram blocks, clean ram cavities and grease sealing surfaces. Clean , grease and cover all ring rooves. 5/18/2019 Nipple down. Remove single gate BOPS from cellar. Clean and grease up ring groves. Put covers on flanges. Pull riser and spools and LD on pipe rack. Remove extra spools and valves from wellhead room.,Clean up wellhead flange. Install dry hole Flange with valve.,Clean up wellhead room, place grating back around wellhead, remove high pressure hoses and 1502 equipment . Cleaning possum belly and shakers. Continue prepping BOP equipment for shipping out.,Continue with cleaning troughs and shakers, begin cleaning pit #1. Assist crane crew as needed loading and unloading boat. Cleaning cellar.,Transfer fluids from pits into ISO tanks. Continue cleaning in pits and cellar. 5/19/2019 Clean solids out of pits i & 2. Cleaning solids out of pits 3 and 4. Put 30 bbl fresh water in pill pit and flushed hopper lines, manifold and transfer line to pit 1.,Continue cleaning solids out of pits 3 and 4. Flush mud pumps, transfer lines and reserve pit out with fresh water. Perform final rinse on mud pits and reserve pit. Blow down pumps and lines with air. Re-route mud line between rig and mud pits.,This will be the final report on the Pre -Drill AFE. UHilcorp Energy Company Composite Report Well Name: TBN A-1 ORD Field: Trading Bay North County/State: , Alaska (LAT/LONG): ;vation (RKB): API #: Spud Date: Job Name: 1910558D A -LORD Drilling Contractor Monopod 56 AFE #: AFE $: Activity Date Ops Summary 7/18/2019 Finish split hatch welding project, Prep and measure flowline for welder. Welders fabricate service loop guard and lock plate for top drive.;Finish welding service loop guard, paint and install same. Install steel flow line. Dress shakers with 120 and 80 screens. Mix first batch of premix.;Pick up 87 jts. of 5" drill pipe w/mouse hole stand back in derrick.. Transfer 1st batch of remix mud to reserve tank and mix 2nd batch. 7/19/2019 Pick up 5" drill pipe, total of 46 stands/138 joints in derrick. Mix pre -mix fluid.;Transfer a batch of pre -mix fluid to storage tank. Transfer 350 bbls. of LVT from ISO's to LVT storage tank and offload mud product from boat.;Mix a batch of pre -mix fluid. Pick up 5" drill pipe and build stands - total of 70 stands/210 joints in derrick.;Start to mix weighted mud. Pick up 5" drill pipe, total of 85 stands 1255 joints. Offload mud product and BOPE from boat. Start to install deck drain plugs around rig. 7/20/2019 Continue picking up 5" drill pipe, ST -80 has issues, troubleshoot and find broken die block. Set up power washer for cleaning shakers with LVT,; Build and weight up MOBM in pits to 9.Oppg, Install 90 degree ducting on hopper fan output. Install manual kill and choke valves on the mud cross. Hook up HPU and Hawkjaw and adjust same. Install LVT manifold for pressure washer.;Transfer 9.0 ppg MOBM from pits to the reserve and pill pits. Finish picking up 5" drill pipe, have a total of 106 stands in the derrick. Assist the crane crew offloading mud product from the boat.;Nipple down the dry hole tree, nipple up the Multi Bowl well head , nipple up riser, dress mud cross, install strong back on single gate. Transfer 340 bbls. of LVT from 3 ISO's to the Rain for Rent tank. 7/21/2019 Nipple up the BOP stack, welder modify the drilling nipple, install same. Align stack and secure same. Assist crane crew offloading mud product and directional drilling tools. Weight mud up in pits and condition same.;Remove 9' bales and install 11' bales. Install sensor on top of gooseneck for Baker MWD. Assist crane crew with lifting hatch and storing Barite in lower level. Hook up Koomey hoses and function test. Seal rig floor with Sikaflex. R/U transfer hose from pits to the trip tank. 712212019 Function test BOPE, had Hyd leak on Kill HCR changed out same, R/U water to MP #1 to fill surface eq for test, mlu 5" TJ, Rig up scaffolding for Rain to Rent tank access. M/U target 90's on mud cross. Assist crane crew with offloading boat. DD & MWD prep BHA.;Commission Centrifuge with rep, had to flip Hyd motor that had been installed incormctly.;Choke manifold valve 916 failed shell test, isolated valve and continued shell test. Start to remove #16 while waiting for AOGC Rep., Bench test 3 mud pump pop offs, install and set same. Bring mud weight up to 9.0 ppg in active pits.;Test BOPE as per Hilcorp & AOGCC requirements. Test witnessed by inspector Adam Earl, tested with 5" test joint, 250/2500 Annular, 250/4000 all other tests, tested gas alarms & PVT system good, super choke failed & CMV#16.;Remove CMV #16, dress flanges and install new valve. M/U manifold and hoses to drain stack. 7/23/2019 Cont. c/o CMV 16 & flush super choke, test CMV 15 & 16 250/4000 good, test super choke good.;Close Blinds, test casing t/50D psi 30 min good.;Cont work on punch list, du lines for fluid displacement, spot cutting tank in mud room at chute, R/U vac to mud room, install wear bushing, rig down test tools.;Continue circulating active system. Install panic line. Strap HWDP. Run communication line for directional drillers. Install DD screen on driller console. Repair ST -80 and rig down Hawkjaws. Adjust link tilt to clear monkey board. Assist crane crew offloading work boat.;Prep rig floor for picking up BHA.;Roll the premix tank. Trouble shoot pill pit hopper, take apart and inspect - OK, Remove and inspect discharge check valves - OK. Make new gaskets and assemble hopper. Silicone the cuttings chute flange and bolt up. WOBaker communication gear, tool communication failure, replacement gear coming.;Roll the active mud system. Install the hopper and test run the pill pit mix pumps. Test vacuum placement for cuttings box. Redo hopper and fix leak. 7/2 412 01 9 Assist Baker directional driller in rig up of BPA. Troubleshoot and repair pill pit hopper. Run rig floor drains to slop tank in cellar.;Mix GELTONE spacer in the pill pit, get ready to pick up BHA.;Make up 12 1/4" BHA as per the Directional Driller, orient the mud motor, sync up the MWD tools.;Run in hole out of derrick F/ 629' and tag cement at 1014'. Make up top drive and prepare to swap hole over to OBM.;The lights in the derrick went out, had to have electrician dry out a junction box and get lights back on, line up to displace brine.;Pump 15 bbl spacer followed by 8.9 ppg OBM at 1.5 to 3 bpm, displace brine to production. at 82 bbls pumped, take returns to cuttings totes until OBM cleans up, about 50 bbls.;Repair leaking pop off, repair trip tank valve leak, condition mud. 7/25/201 Mud pump PRV's not functioning properly. Spare PRV having same issue. Sent 3 hands to Steelhead Platform to pull those PRV's and gather up spare parts. Repair leaking air actuated valve to trip tank. Replaced conduit junction cap in derrick.;Change out PRV on mud pump #2. Test HP lines to rig floor and PRV's on both pumps to 3000 psi. Rig down test equipment.; Establish parameters: P/U 81 K, SIO 79 K, Rot 81 at 38 RPM/3 K torque. 560 GPM/1280 osi. Drill <� cement from 1015' to 1125' with 10 K WOB and 20 - 95 FPR/ROP. Cement very frm.;Circulate and condition mud at 555 GPM/1150 psi until 9.15 ppg mud in and out. Set back one stand.;Perform FIT to 13.0 ppg EMW with 9.15 ppg mud at 1 080'TVD, pump .5 bbl and get .5 bbl back.;Establish parameters: P/U 85 K, S/O 83 K, 550 GPM/1200 psi. Slide directional drill from 1125' to 1178' with 2 K WOB and 20 FPH/ROP.;Slide drill from 1178' to 1196' at 550 gpm/1125 psi, P/U 84 K, S/O 80 K, WOB 5 K, ROP 15 ft/hr.; Rotary drill from 1196'to 1227' at 40 rpm/3K TRQ, WOB 5K, ROP 45.;Slide drill from 122T to 1292' at 550 gpm/1150 psi, WOB 10 K.;Rotary drill from 1292'to 1324' at 550 gpml 1200 psi, 40 rpm/4K trq. Circulate while a -line rigs up to Gyro.;Single shot survey with Pollard a -line in string.;Daily fluid loss: 0 bbls. Total Fluid loss: 0 bbls 133/8 x conductor annulus: 0 psi THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Stan W. Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alosko.gov Re: Trading Bay Field, Hemlock, Middle Kenai C, Middle Kenai D, and Middle Kenai E Oil Pools, Trading Bay St. A-10 Permit to Drill Number: 167-076 Sundry Number: 319-012 Dear Mr. Golis: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, el�o Daniel T. Seamount, Jr. Commissioner DATED this2i�day of January, 2019. " A�3110% ,005 RECENED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION )AN 14 2019 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 .a t; 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ / A/ ` Form 10403 Revised 412017 rOvetl application is va t t d 2 Of a �J Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑Q ' Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q • Stratigraphic ❑ Service ❑ 167-076 3. Address: 3800 Centerpoint Drive, Suite 1400 B. API Number: Anchorage, AK 99503 50-733-20064-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑' Trading Bay St / A-10 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018731 Trading Bay Field /Hemlock Oil, Middle Kenai C Oil, Middle Kenai O Oil & Middle Kenai E Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7,073 • 6,652 6,494 6,073 1,485 psi 5,537 6,494-6,525 Casing Length Size MD TVD Burst Collapse Structural Conductor 264' 20" 264' 264' Surface 1,095' 13-3/8" 1,095' 1,068' 3,090 psi 1,540 psi Intermediate Production 7,053' 9-5/8" 7,053' 6,632' 3,950 psi 2,570 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4,240 - 6,740 3,929 - 6,319 Dual 3-1/2" & 2-7/8" N-80 4,191 & 5,718 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Otis Packers & Otis SSSV 4,146 (MD) 3,842 (ND), 4,147 (MD) 3,843 (TVD), 5,641 (MD) 5,240 (TVD) & 327 (MD) 327 (TVD) 291 (MD) 291 (TVD) 12. Attachments: Proposal Summary Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑Q Exploratory ❑ Stratigraphic ❑ Development ❑2 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/15/2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑� ` GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W. Golis Contact Name: Michael Quick Authorized Title: Operations Manager Contact Email: n1 uick hilcor .Com Contact Phone: (907) 777-8442 - �{ Authorized Signature: 1� Date: I ) COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: /I ` ,,-// Plug Integrity I/ BOP Test LfJ Mechanical Integrity Test ❑ Location Clearance ❑ Other. j00 ,05.; jQ1 f' Post Initial Injection MIT Req'd? Yes ❑ No ❑ L/ Spacing Exception Required? Yes El No 13/ Subsequent Form Required: D - "I Q MS�,JAW 3 1pt9 RBp APPROVED BY r� Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and pp pp �rd�o�'!� � M IfQrtj h/t �t approval. � /1171�enta in Du licate / 7 K Hilo p Alaska, LLC Well Work Prognosis Well: Monopod A-10 Date: 01/07/2019 Well Name: Trading Bay St. A-10 API Number: 50-733-20064-00 Current Status: Gas -Lift Producer Leg: N/A Estimated Start Date: February 15, 2019 Rig: Monopod Rig #56 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 167-076 First Call Engineer: Mike Quick (907) 777-8442 (0) (907) 317-2969 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Current Bottom Hole Pressure: 1,950 psi @ 5,012' (4,651' TVD) 0.419lbs/ It (8.01 ppg)12/20/2013 static BHP A-13 Maximum Expected BHP: 1,950 psi @ 5,012' (4,651' TVD) 0.419 lbs/ It (8.01 ppg) 12/20/2013 static BHP A-13 Maximum Potential Surface Pressure: 1,485 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary Monopod Platform's Trading Bay State A-10 is a Hemlock only gas -lifted producer that has been shut-in since / 1983 due to coal production, likely due to damaged/parted/collapsed casing across the perforated intervals. This ✓ workover will plug the perforations and cut and pull +/-1500' of 9-5/8" casing in preparation for a sidetrack out of the 13-3/8" casing shoe. Procedure: U Phase I: Rieless Work 1. MIRU slickline on 3-1/2" by 2-7/8" Short String, PT lubricator to 2,000 psi High / 250 Low. 2. RIH pull SSSV. POOH. LD SSSV �^ St` 3. RIH to tubing tail at 4191' with GR. POOH. RD. 4. RU slickline on 3-1/2" by 2-7/8" Long String, PT lubricator to 2,000 psi High / 250 Low. 5. RIH pull SSSV. POOH. LD SSSV 6. RIH with GR to tag (last tag 940'), POOH. 7. RIH with bailer and bail through obstruction to attempt to reach tubing tail at 5718'. RD. CNTINGENCY: If tubing obstruction cannot be removed, the tubing will be cut above the tagged Qtill and pulled with the rig, followed by running an overshot and external cutter, cutting the tubing at +/-1800' and pulling. Request waiver to 20 AAC 25.112 (c) to isolate perforations with steps 19 through 24 below as the tubing is plugged and access cannot be gained. L60c, STC21 04 b QJL 8. RU cement unit on 3-1/2" by 2-7/8" Long String, perform injection test not exceedin 500 psi pressure. 9.1 Plug #1 Mix and bullhead +/- 35 bbls (170 sxs) of 15.8 ppg Class G cement do n the 3-1/2" by 2- 7 8 ong String. Displace to leave TOC in tubing at+/,360-3100 Qv )i Note: 9-5/8" annular volume from 5640' to 6400' is 57 bbls. U Tapered string tubing capacity: 3-1/2" = 0.0087 bbl/ft; 2-7/8" = 0.00579 bbl/ft 10. RU cement unit on 3-1/2" by 2-7/8" Short String, perform injection test not exceeding 2500 psi ressure. 55}� 1. Plug #2: Mix and bullhead +/- 15 bbls (73 sxs) of 15.8 ppg Class G cement down the 3-1/2" by 2- 7 8 ort String. Displace to leave TOC in tubing at+/ Y 3SiZ Note: 9-5/8" annular volume from 4146' to 5640' is 73 bbls. Tapered string tubing capacity: 3-1/2" = 0.0087 bbl/ft; 2-7/8" = 0.00579 bbl/ft 12. WOC a minimum of 12 hours. l� 13. Pressure test 3-1/2" by 2-7/8" Short String to 1500 psi for 30 minutes, charttest 14. Pressure test 3-1/2" by 2-7/8" Long String to 1500 psi for 30 minutes, chart test. ell� HiLn.n AbIoka LLC Tom 1#2. "'Y:5 Well Work Prognosis Well: Monopod A-30 Date: 01/07/2019 15. MIRU eline on 3-1/2" by 2-7/8" Short String, PT lubricator to 2,000 psi High / 250 Low. 16. RIH and cut 3-1/2" Short String at+1;000"�OgH, RD. 17. MIRU eline on 3-1/2" by 2-7/8" Long String, PT lubricator AC 2,000 psi High / 250 Low. 18. RIH and cut 3-1/2" Long String at +p00H, RD. -7;: e w Phase II: Rig Work � 3b�a a � f OG w� 19. Skid Monopod rig over A-10 well and rig up 20. ND Wellhead, NU BOP and test to 250psi low/3,D99¢SPhi In (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). QDkkL BJP &/;tS 21. Circulate hydrocarbons from well to production - Workover fluids will be FIW. BOP's will be closed as needed to circulate the well. �dr 22. POOH laying down dual string completion from +/-1800'. 23. MU and RIH with 9-5/8" CIBP on tubing, set at et down 10,000 lbs to ensure set (per 20 AAC 25.112 (g)(1)). 37-�0� Plug #3• Spot 200' (15 bbls) of 15.8 ppg Class G cement on top of CIBP, POOH.--� and RIH with 9-5/8" casing cutter. Cut 9-5/8" casing at +/-1500'. POOH. 26. Circulate KWF down 9-5/8" casing taking returns from the 13-3/8" casing. (Punch 9-5/8" casing if 30 , needed to obtain adequate circulation rates) 27. Monitor well to ensure well is static. 28. ND BOP's, ND 9-5/8" casing hanger and pull pack off/snap rings, NU BOP Note: BOPE cannot be tested on the Shaffer KD wellhead once the pack -off and slips are removed. Cannot test the BOPE breaks until the 9-5/8" is removed from the well. Tested cement barriers are in place prior to this step. 29. POOH with 9-5/8" casing from +/-1500'. 30. Test BOP to 250psi low si high. (Notify AOGCC 48 hours in advance of test to allow them to witness test). 31. Plug #4: RIH with tubing stinger and spot a balanced cement kick off plug from +/-1500' to +/-1000' (+/- 73 bbl of 15.8 ppg Class G cement), POOH. 32. WOC a minimum of 12 hours. 33. Pressure test 13-3/8"lto 000 psi for 30 minutes, chart test. 34. PU 12-1/4" Sidetrack BHA and RIH to TOC. 35. 'Remaining Procedure to be included on the Permit to Drill for the sidetrack' Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form H 11lcorp Alaska, I.LC RKB to TBG Hngr = 37' Tree connection: Dual 3" 5,000# KB ELEV = 101' PBTD = 6,750' TD = 7,073' ANGLE thru INTERVAL = 12.7' SCHEMATIC CASING DETAIL Trading Bay Unit Well # A-10 PTD: 167-076 API: 50-733-20064-00 Last Completed: 10/15/1978 SRE WT GRADE CONN ID TOP BTM. 20" ID Conductor Pile Item 2Junked Retainers Surface -264' 13-3/8" 61 K-55 BTC 12.515 Surface 1,095' 9 5/8 " 43.5 40 40 43.5 N-80 J-55 N-80 N-80 BTC BTC BTC BTC 8.755 8.835 8.835 8.755 Surface 80 4,111' 5,600' 80' 4,111' 5,600' 7,053' 1,963' Junked BP Tubing Detail: C 2,976' 2,780' LS 3-1/2" 9.2 N-80 But 2.992 Surface 4434' 2-7/8" 6.4 N-80 But 2.441 4435' 5718' 55 3-1/2" 9.2 N-80 But 2.992 Surface 4145' 2-7/8" 6.4 N-80 But 2.441 4146' 4191' Dip Tube 2-3/8"x 1-1/2" 6.2 N-80 Butt 1.853 4084' 5537' Perforation Details on Next Page Updated by: DEM 03-02-2018 FISH Date JEWELRY DETAIL NO Depth Depth ID OD Item 2Junked Retainers 37' 37' 1/2 of ring from hydraulic packer 1 1 Cameron Slit Tubing hanger. SHORT STRING 08/08/1970 6,503' Junked Retainer A 327' 327' 2.75 SSSV - Otis Ball Valve B 2,078' 1,963' Junked BP GLM #S1 -Otis C 2,976' 2,780' GLM#S2-Otis 0 3,605' 3,351' GLM#S3-Otis E 4,044' 3,749' GLM #S4 -Otis F 4,080' 3,781' 2.75 Otis "XA" Sliding Sleeve G 4,145' 3,841' 2.441 Cross over, 3-1/2" X 2-7/8" H 4,146' 3,842' 8.38 Otis Triple Hydraulic Packer 1 4,189' 3,882' 2.205 Otis "XN" Nipple 1 4,191' 3,884' EOT LONG STRING 1 291' 291' 2.75" SSSV - Otis Ball Valve 2 2,111' 1,993' GLM#Ll - Otis 3 3,103' 2,896' GLM #L2 -Otis 4 3,892' 3,611' GLM #L3 -Otis 5 4,112' 3,811' 2.75 Otis "XA" Sliding Sleeve 6 4,147' 3,843' 8.38 Otis Triple Hydraulic Packer 7 4,249' 3,937' 2.75 Otis "XA" Sliding Sleeve 8 4,434' 4,109' Cross over, 3-1/2" X 2-7/8" 9 4,497' 4,168' GLM #L4-Camco 10 41754 4,874' 4'409 4,522' BlastJoints it 5,030' 4,668' GLM #L5-Camco 12 5,442' 5,053' GLM #L6-Camco 13 5,604' 5,205' 2.313 Otis "XA" Sliding Sleeve 14 5,640' 5,239' Locator Seal Assy. 15 5,641' 5,240' Otis Perm Packer 16 5,685' 5,281' 2.313 Otis "X" Nipple 17 5,718' 5,312' Mule Shoe. Dip Tubing a. 4,084' 3,785' Top of Dip Tube (1 perforated joint) b. 4,159' 3,854' 1-1/2" Telescoping Joint G 4,496' 4,167' GLM #L4-Camco d. 4,513' 4,183' 1-1/2" Telescoping Joint e. 5,030' 4,668' GLM #L5-Camco f. 5,052' 4,689' 1-1/2" Telescoping Joint g. 5,442' 5,053' GLM #L6-Camco h. 5,537' 5,142' Bull Plug Perforation Details on Next Page Updated by: DEM 03-02-2018 FISH Date Depth Description 10/05/1978 6,500' Junked Perm Packer 07/16/1973 6,494' 2Junked Retainers 07/14/1973 6,496' 1/2 of ring from hydraulic packer 08/09/1970 6,503' Guiberson Packer Model 08/08/1970 6,503' Junked Retainer 07/30/1970 6,515' Junked BP 03/25/1968 6,525' Junked BP 03/21/1968 6525' Junked BP Perforation Details on Next Page Updated by: DEM 03-02-2018 u H lcorp Alpeka. LLC SCHEMATIC Trading Bay Unit Well # A-10 PTD: 167-076 API: 50-733-20064-00 Last Completed: 10/15/1978 Zone Top (MD) Btm (MD) Top (TVD) atm (TVD) Amt. Accum. SPF Date Last Opr. Present Condition 3,840' 3,860' 3,563' 3,582' 20' 4 3/22/1968 DST, Cmt sgz'd, tested to 1500 psi 4,148' 4,168' 3,844' 3,863' 20' 4 3/20/1968 DST, Cmt sgz'd, tested to 1500 psi 4,240' 4,241' 3,929' 3,930' 1' 4 3/24/1968 W50. Tested to 1500 psi C 4,262' 4,288' 3,949' 3,973' 26' 4&8 7/30/1970 Open to Production C 4,316' 4,354' 3,999' 4,035' 38' 4&8 7/30/1970 Open to Production C 4,398' 4,430' 4,076' 4,106' 32' 4&8 7/30/1970 Open to Production C 4,498' 4,514' 4,169' 4,184' 16' 4&8 7/30/1970 Open to Production C 4,572' 4,592' 4,238' 4,257' 20' 4&8 7/30/1970 Open to production C 4,668' 4,694' 4,328' 4,353' 26' 4&8 7/30/1970 Open to Production C-7 4,766' 4,864' 4,420' 4,512' 98' 4, 8 & 12 7/30/1970 Open to Production C 5,012' 5,050' 4,651' 4,687' 38' 4 3/26/1968 Open to Production C 5,096' 5,100' 4,730' 4,734' 4' 4 7/30/1970 Open to Production C 5,124' 5,132' 4,756' 4,764' 8' 4 7/30/1970 Open to Production C 5,244' 5,249' 4,868' 4,873' 5' 4 7/30/1970 Open to Production C 5,325' 5,358' 4,944' 4,975' 33' 4, 8 & 12 7/30/1970 Open to Production C 5,532' 5,534' 5,137' 5,139' 2' 3/5/1970 Ott sqi d w/ 200 sx class G C 5,534' 5,590' 5,139' 5,191' 56' 4&8 7/30/1970 Open to Production C 5,590' 5,592' 5,191' 5,193' 2' 3/5/1970 Gnat sgid w/200 sx class D 5,684' 5,712' 5,280' 5,307' 28' 8 7/30/1970 Open to production 53-8 5,787' 5,838' 5,379' 5,429' 51' 4, 8 & 12 3/8/1974 Open to Production 54-5 5,870' 5,880' 5,460' 5,469' 10' 8 7/16/1973 Open to Production 54-9 5,900' 5,954' 5,489' 5,541' 54' 12 7/16/1973 Open to Production D 5,985' 6,020' 5,571' 5,605' 35' 4&8 7/30/1970 Open to Production D 6,030' 6,134' 5,615' 5,716' 104' 4,8,12&16 3/8/1974 Open to Production 57-2 6,160' 6,245' 5,742' 5,826' 85' 4,8,12&16 3/8/1974 Open to Production E 6,274' 6,296' 5,854' 5,876' 22' 8 8/8/1970 Open to Production E 6,274' 6,296' 5,854' 5,876' 22' 4, 8 & 12 7/16/1973 Open to Production E 6,320' 6,352' 5,900' 5,932' 32' 12 7/16/1973 Open to Production 6,600' 6,740' 6,179' 6,319' 140' 4 1/6/1968 Open to Production 6,760' 6,840' 6,339' 6,419' 80' 4 1/4/1968 DST, curt sqz. Isolated by BP @ 6750' 6,904' 1 6,919' 1 6,483' 67498P 15' 4 1/3/1968 1 DST, curt sqz. Isolated by BP @ 6750' Updated by: DEM 03-02-2018 KPROPOSED SCHEMATIC liacrapaaske.UC For Sidetrack RKB to TBG Hngr = 37' Tree connection: Dual 3" 5,000# KB ELEV = 101' PBTD = 6,750' TD = 7,073' ANGLE thru INTERVAL = 12.70 CASING DETAIL Trading Bay Unit Well # A-10 PTD: 167-076 API: 50-733-20064-00 Last Completed: 10/15/1978 SIZE Wr GRADE CONN ID TOP any. 20" ID Conductor Pile Item 2 Junked Retainers Surface -264' 13-3/8" 61 K-55 BTC 12.515 Surface 1,095' 95/8" TN 40 40 43.5 -80 J-55 N-80 N-80 137E BTC BTC BTC R-755 8.835 8.835 8.755 ..'a... +/-1500' 4,111' 5,600' so, 4,111' 5,600' 7,053' 1,963' Junked BP Tubing Detail: C 2,976' 2,780' LS 3-1/2' 9.2 N-80 But 2.992 +/-1800' 4434' 2-7/8" 6.4 N-80 Butt 2.441 4435' 5718' SS 3-1/2" 9.2 N-80 Butt 2.992 +/-1800' 4145' 2-7/8" 6.4 N-80 Butt 2.441 4146' 4191' Dip Tube 2-3/8" x 1-1/2" 6.2 N-80 Butt 1.853 4084' 5537' Perforation Details on Next Pase Updated by: DEM 03-02-2018 FISH Date JEWELRY DETAIL NO DMDh De'D ID OD Item 2 Junked Retainers i7= 37 1/2 of ring from hydraulic packer 08/09/1970 g SHORT STRING 08/08/1970 6,503' Junked Retainer A 327' 327' 2.75 SSSV - Otis Ball Valve B 2,078' 1,963' Junked BP GLM#Sl - Otis C 2,976' 2,780' GLM #52 -Otis D 3,605' 3,351' GLM #53 -Otis E 4,044' 3,749' GLM#54-Otis F 4,080' 3,781' 2.75 Otis "XA" Sliding Sleeve G 4,145' 3,841' 2.441 Cross over, 3-1/2" X 2-7/8" H 4,146' 3,842' 8.38 Otis Triple Hydraulic Packer 1 4,189' 3,882' 2.205 Otis "XN" Nipple 1 4,191' 3,884' EOT LONG STRING 1 2w 243= 2.76-' ,j,, 2 2,111' 1,993' GLM#LL.-Otis 3 3,103' 2,896' GLM #L2 -Otis 4 3,892' 3,611' GLM #L3 -Otis 5 4,112' 3,811' 2.75 Otis 'XA'Sliding Sleeve 6 4,147 3,843' 8.38 Otis Triple Hydraulic Packer 7 4,249' 3,937' 2.75 Otis "XA" Sliding Sleeve 8 4,434' 4,109' Cross over, 3-1/2" X 2-7/8" 9 4,497' 4,168' GLM #L4-Camco 10 41754 4,874' 4'409 4,522' BlastJoints 11 5,030'M5,312' GLM #L5-Camco 12 5,442' GLM #L6-Camco 13 5,604'3 Otis "XA"Sliding Sleeve 14 5,640'Locator Seal Assy. 15 5,641'Otis Perm Packer 16 5,685'3 Otis "X" Nipple 17 5,718'Mule Shoe. Dip Tubing a. 4,084' 3,785' Top of Dip Tube (1 perforated joint) b. 4,159' 3,854' 1-1/2" Telescoping Joint C. 4,496' 4,167' GLM #L4-Camco d. 4,513' 4,183' 1-1/2" Telescoping Joint e. 5,030' 4,668' GLM #L5-Camco f. 5,052' 4,689' 1-1/2"Telescoping Joint g. 5,442' 5,053' GLIM #L6-Camco h. 5,537' 5,142' Bull Plug Perforation Details on Next Pase Updated by: DEM 03-02-2018 FISH Date Depth Description 10/05/1978 6,500' Junked Perm Packer 07/16/1973 6,494' 2 Junked Retainers 07/14/1973 6,496' 1/2 of ring from hydraulic packer 08/09/1970 6,503' Guiberson Packer Model 08/08/1970 6,503' Junked Retainer 07/30/1970 6,515' Junked BP 03/25/1968 6,525' Junked BP 03/21/1968 6525' Junked BP Perforation Details on Next Pase Updated by: DEM 03-02-2018 KPROPOSED SCHEMATIC Ilik.,Alaska.LLC For Sidetrack Trading Bay Unit Well k A-10 PTD: 167-076 API: 50-733-20064-00 Last Completed: 10/15/1978 Zone Top (MD) Btm (MD) Top (TVD) atm, (TVD) Amt. Accum. SPF Date Last Opt. Present Condition 3,840' 3,860' 3,563' 3,582' 20' 4 3/22/1968 DST, Cant sgid, tested to 1500 psi 4,148' 4,168' 3,844' 3,863' 20' 4 3/20/1968 DST, Cmt sq?d, tested to 1500 psi 4,240' 4,241' 3,929' 3,930' 1' 4 3/24/1968 WSO. Tested to 1500 psi C 4,262' 4,288' 3,949' 3,973' 26' 4&8 7/30/1970 Open to Production C 4,316' 4,354' 3,999' 4,035' 38' 4&8 7/30/1970 Open to Production C 4,398' 4,430' 4,076' 4,106' 32' 4&8 7/30/1970 Open to Production C 4,498' 4,514' 4,169' 4,184' 16' 4&8 7/30/1970 Open to Production C 4,572' 4,592' 4,238' 4,257' 20' 4&8 7/30/1970 Oen to Production C 4,668' 4,694' 4,328' 4,353' 26' 4&8 7/30/1970 Open to Production C-7 4,766' 4,864' 4,420' 4,512' 98' 4, 8 & 12 7/30/1970 Open to Production C 5,012' 5,050' 4,651' 4,687' 38' 4 3/26/1968 Open to Production C 5,096' 5,100' 4,730' 4,734' 4' 4 7/30/1970 Open to Production C 5,124' 5,132' 4,756' 4,764' 8' 4 7/30/1970 Open to Production C 5,244' 5,249' 4,868' 4,873' 5' 4 7/30/1970 Open to Production C 5,325' 5,358' 4,944' 4,975' 33' 4, 8 & 12 7/30/1970 Open to Production C 5,532' 5,534' 5,137' 5,139' 2' 3/5/1970 Cmt sqi d w/ 200 sx class G C 5,534' 5,590' 5,139' 5,191' 56' 4&8 7/30/1970 Open to Production C 5,590' 5,592' 5,191' 5,193' 2' 3/5/1970 Cmt sgz'd w/200 sx clas5G D 5,684' 5,712' 5,280' 5,30T 28' 8 7/30/1970 Open to Pro duction 53-8 5,787' 5,838' 5,379' 5,429' 51' 4, 8 & 12 3/8/1974 Open to Production 54-5 5,870' 5,880' 5,460' 5,469' 30' 8 7/16/1973 Open to Production 54-9 5,900' 5,954' 5,489' 5,541' 54' 12 7/16/1973 Open to Production D 5,985' 6,020' 5,571' 5,605' 35' 4&8 7/30/1970 Open to Production D 6,030' 6,134' 5,615' 5,716' 104' 4,8,12&16 3/8/1974 Open to Production 57-2 6,160' 6,245' 5,742' 5,826' 85' 4,8,12&16 3/8/1974 0 en to Production E 6,274' 6,296' 5,854' 5,876' 22' 8 8/8/1970 Open to Production E 6,274' 6,296' 5,854' 5,876' 22' 4, 8 & 12 7/16/1973 Open to Production E 6,320' 6,352' 5,900' 5,932' 32' 12 7/16/1973 Open to Pfoduction 6,600' 6,740' 6,179' 6,319' 140' 4 1/46/1968 Open to Production 6,760' 6,840' 6,339' 6,419' 80' 4 1/4/1968 DST, curt sqz. Isolated by BP @ 6750' 6,904' 6,919' 6,483' 1 6,498' SS' 1 4 1/3/1968 DST, curt sqz. Isolated by BP @ 6750' Updated by: DEM 03-02-2018 H Hilmrp .Alaeka. LIX Monopod A-10 133/8X95/8X31/2X 3 1/2 Tree assy, dual block, CIW-F, 11 SM X31/85MX 3 1/8 SM, prepped on 5 3/64 center, 3" CIW seal pockets, Y npt control line exits Monopod Platform A-10 Current 01/03/2014 Tubing hanger, dual, CIW- DCB, 11 5M X 3 % EUE 8rd lift X 3 % IBT bottom, w/ 3" type H BPV profile, 1/8 non cont control line ports in hangers Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 SM SSO, X -bottom prep Casing head, Shaffer KD, 135/83MX 13 3/8 SOW, w/ 2- 2" LPO, :IW -F, 21/165M FE, HWO, AA CIW ball valve H HiI.,p Alurk., I.I.C. Monopod Platform 2018 BOP Stack RSM. S & \ \ � � ' @ (� �(� * A MIE � • !!.:!! :_ w . .. | ! !,.`. . , ! 44 \ t- ;l ARMS! / ./\\�§%~ \ §- � • !!.:!! :_ w . .. | ! !,.`. . , ! 44 H Hil.q Alaska, LLC Attachment #1 Monopod Rig # 56 BOP Test Procedure Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Monopod Rig # 56 WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Circulate down tubing taking returns to production off of the annulus and sweep gas and oil to production until returns are clean. 4) Confirm that well is static shooting fluid levels if necessary right before ND/NU. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2 -way check in hanger. 3) Space out test joint so end of tubing (ECT) is just above the blind rams. 4) Set slips, mark same. Test per standard Monopod Rig #56 BOPE test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, establish static fluid level, shoot fluid level with an echometer gun or tag with slick line to establish static fluid level if necessary. 2) Once the fluid level is established to be static, notify Hilcorp Anchorage Operations Engineer. 3) Proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2 -way valve, or prepare lift -threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2 -way check valve by hand, or MU landing (test) joint to lift -threads d) Plug penetrations in hanger. For ESP wells - Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 4) If both set of threads appear to be bad and unable to hold a pressure test and / or a penetrator leaks, notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC - guy.schwartz@alaska.gov ) and Mr. Jim Regg (AOGCC-jim.regg@alaska.gov ) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE Monopod Riga 56 BOP Test Procedure nik.,p A64., LLC Attachment #1 b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 5) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 6) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Note: BOPE high test pressures will be determined upon Approved Sundry. Test joint sizes will be determined upon well work. Subsequent Tests (i.e. Test Plug can be set in the Tubing -head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2 -way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-2 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. if passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position n l l.q Alaska, LLC Monopod Rig # 56 BOP Test Procedure Attachment 81 them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. d) Open C-2. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves, to 250 psi low and 3,000 psi high, for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. ii) Valves, 3, 4, 9. After test, open valves 3 & 4. Leave 9 closed. iii) Valves 5, 6, 9. After test, open valves 5 & 6, leave 9 closed. iv) Valves, 7, 8, 9. After test, open all valves. e) Close C-3. This is the HCR (the hydraulic controlled remote) valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test, open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test C-1, C-2, and C-4 on the kill (pump -in) side by pressuring up on tubing. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre -charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to "Auto", not "Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position H Hik.o p AWeks, LLC Monopod Rig # 56 BOP Test Procedure Attachment #1 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. HHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well A-10 (PTD 167-076) Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the j AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. d Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By Initials HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date Sundry Application Plug for Re -drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re - drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form .10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist j�� work) the initial reviewer will cross out that erroneous entry and initial then_ it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 41 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. HILCORP ALASKA LLC, TRADING BAY ST A-10 (167-076) TRADING BAY, HEMLOCK OIL Monthly Production Rates 10,000,000 1,000,000 L Y 0 0 CL 100,000 U � c 10,000 l9 o� v� LL 1,000 V � Z 3 u v 100 0 0 L H 10 10,000,000 W CIO 1,000,000 0 O 100,000 0 0 0 S 10,000 O t W 1,000 N 0 M 100 0 O 3 10 S 1 1 Jan -1965 Jan -1970 Jan -1975 Jan -1980 Jan -1985 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Jan -2020 SPREADSHEET Prod-InjectCu"es_W e II_V 117_1670760_TB_St_A-10_20190117.xlsx 1/17/2019 — -------- ■■■■�■M■ ---------- ■NCMEMO ■N■■ ----- ■■■ ■■ -- ■ ENEM NONNI �_ ===ice--��•:r.a:CC� ���1�;. ..'• ===OCA mcon— r•21 mom ■■ 9. ■EM■■■■ ■■ oil.���G��� MEN oil _ _- _--------- ___ ■■ ■■NEEM■■■■ ■ ■ MEN rMa__________ C -- ..CCC— -- I=--UMMOM=------ — ------------- ■ ■■■■M■■i■■■E ON ■E■■■■■M■EM■ ii'■ 10,000,000 W CIO 1,000,000 0 O 100,000 0 0 0 S 10,000 O t W 1,000 N 0 M 100 0 O 3 10 S 1 1 Jan -1965 Jan -1970 Jan -1975 Jan -1980 Jan -1985 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Jan -2020 SPREADSHEET Prod-InjectCu"es_W e II_V 117_1670760_TB_St_A-10_20190117.xlsx 1/17/2019 Schwartz, Guy L (DOA) I �o l 0-7 From: Schwartz, Guy L (DOA) Sent: Monday, January 26, 2015 9:22 AM To: 'Juanita Lovett' Cc: Ted Kramer; samantha.carlisle@alaska.gov Subject: RE: Withdraw Sundry: A-10 PTD 167-076 - Sundry # 314-040 Juanita, AOGCC will withdraw sundry 314-040 as requested. sCAHNEv JAN 2 7 2015 Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska. ov). From: Juanita Lovett (mailto:jlovett(d)hilcorp.com] Sent: Monday, January 26, 2015 8:54 AM To: Schwartz, Guy L (DOA) Cc: Ted Kramer Subject: Withdraw Sundry: A-10 PTD 167-076 - Sundry # 314-040 G uy, Please withdraw the above mentioned sundry. Thank you, Juanita Lovett Operations/Regulatory Tech Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Office: (907) 777-8332 Email: Ilovett@hilcorp.com \�\�/�% gd- s i E S T A TS, jA„.. a sem, Viak., rg ,1, i< � e } -e- p — — — 333 west Seventh Avenue 'P':-=r-- N IlARNEr A 'oroge. ;slosKO 9(2,50 35572 s 'v,air, 907.279.'433 pp .thaillia.-io, SCANNED MAY 1 6 ZO)4 Ted Kramer Sr. Operations Engineer /_1 .� 0 4Hilcorp Alaska, LLC ...1--. 7.1--------1-----.��/ 3800 Centerpoint Drive, Suite 100 - Anchorage, AK 99504 Re: Trading Bay Field, Hemlock Oil, Middle Kenai C, Middle Kenai D Oil, and Middle Kenai E Oil Pools, Trading Bay St A-10 Sundry Number: 314-040 Dear Mr. Kramer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /),_22.9 „/„....._ Cathy ^. Foerster Chair Z� DATED this day of January, 2014. Encl. qi STATE OF ALASKA •V ALASKA OIL AND GAS CONSERVATION COMMISSION 0,7 . �,z,5�� APPLICATION FOR SUNDRY APPROVALS 4 ' '' 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate 0 - Pull Tubing 0- Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Complete 0 • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ ' Development 0, 167-076 4 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99504 50-733-20064-00 7.If perforating: 7t-7fixIS 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 932) Will planned perforations require a spacing exception? Yes ❑ No 0 Trading Bay St/A-10 , ��n 9.Property Designation(Lease Number): 10.Field/Pool(s): ft ADL0018731• Trading Bay Field/Hemlock Oil,Middle Kenai C Oil and Middle Kenai D Oil Pools „ytc.Y ,E o. 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7,073 , 6,652 ' 6,494 6,073 6,494'-6,525' Casing Length Size MD TVD Burst Collapse Structural Conductor Surface Intermediate 1,095' 13-3/8" 1,095' 1,068' 3,090 psi 1,540 psi Production 7,053' 9-5/8" 7,053' 6,632' 3,950 psi 2,570 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic• See Schematic Dual 3-1/2" N-80 4,191'&5,718' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Otis Packers& Otis SSSV 4,146'(MD)3,842'(ND),4,147'(MD)3,843'(ND),5,641'(MD)5,240'(ND)&291'(MD)291'(ND) 12.Attachments: Description Summary of Proposal 0 • 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 • Exploratory ❑ Stratigraphic❑ Development 0- Service El 14.Estimated Date for 15.Well Status after proposed work: 2/1/2014 Commencing Operations: Oil 0- Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramertdlhilcorD.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature ' ' .f ' ' ._._ Phone (907)777-8420 Date 1/14/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: *1.- CC) g /c. 7 1-- RBDMS' SAY U 9 2014 Spacing Exception Required? Yes ❑ No li Subsequent Form Required: /p —LitQ 1 APPROVED BY Approved by: ` / Z COMMISSIONER THE COMMISSION Date: /- _-- (/ / `C- f/ oefly Y /'�]//� lzp. Py 1 nIIN 4 L it ��a[e !� Submit Form and Form 10-403(Revised 10/2012) Appr®v dRpiC t i i onths f m th d of approval. Attachments in Duplicate Well Prognosis Well: A-10 Ililcoru Alaska,LL Date:01/14/2014 Well Name: Monopod A-10 API Number: 50-733-20064-00 Current Status: Shut-in Oil producer(Gas Leg: N/A Lifted) Estimated Start Date: February 01, 2014 Rig: Monopod Rig#56 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 167-076 First Call Engineer: Ted Kramer (907)777-8420(0) (985)867-0665 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907)398-9904(M) AFE Number: Current BHP: ^'2,232 psi @ 5,840'TVD 0.38 psi/ft(7.85 ppg)at mid-perf of all perfs. Maximum Expected BHP: 2,232 psi @ 5,840'TVD 0.38 psi/ft(7.85 ppg)No new zones Max.Anticipated Surface Pressure: "Opsi using 0.38 psi/ft Brief Well Summary A-10 is a shut-in dual string gas lifted well on the Monopod Platform. Wellbore has suspected casing damage indicated by coal production. The work plan for the well is to remove the current completion and run a casing evaluation log to determine the condition of the casing. A casing repair will then be determined based on the results of the logs. The Well will then be re-perforated in the C, D, E,and Hemlock zones. Brief Procedure: 1. MIRU Monopod Platform Rig#56. 2. Circulate hydrocarbon off well. ---�Pum- 6°P 3. ND Wellhead, NU BOP and test to 250 psi low/2,500 psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Pull Gas-Lift Completion and production packers. 5. Clean out well to 7,050 recovering junk packers and bridge plugs.Circulate hole clean. 6. RU E-line. RIH with Gamma Ray,CCL and Caliper log to 6,950'. Log out of hole up to 1,095'. RD E- line. 7. Evaluate Caliper log for casing damage. (NOTE: Results of Caliper Log will determine if a liner will need to be ran. If it does,that change will be worked with AOGCC at this step.) lvA.ay 8. PU RTTS packer and RIH to 4,220'. Set and pressure test casing to 1,500 psi for 30 min. Chart same. POOH with RTTS. 9. PU Storm packer. RIH and Set at+/-300'. Pressure test to 1,500 psi. POOH. 10. ND BOP and change out tubing head. Re-test well head to 2,500 psi. 11. NU BOP and re-test all connections broken back to 250 psi low/2500 psi high. 12. Pull Storm Packer. 13. PU TCP perf guns and run into hole, according to the approved Perf Request Form, hanging them off the bottom of a hydraulically set permanent packer. 14. RU E-line. Log TCP Guns and Packer on depth. RIH with Plug and set PKR. RD E-line. 15. PU 2-7/8"8rd EUE production tubing with seal bore assembly,chemical injection Mandrel,GLM's, and SSSV. RIH stabbing the seal assembly into the permanent packer. Pressure test packer and completion tubing on back side to 1,200 psi.for 15 minutes. 11 Well Prognosis Well: A-10 Ililcorp Alaska,LL Date:01/14/2014 16. RU Slick Line. RIH, pull dummy valves in the chemical injection mandrel and the GLM's. Replace with live valves. 17. ND BOP, NU wellhead and test. 18. Drop bar,fire guns,turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Current Wellhead Diagram 3. Proposed Wellbore Schematic 4. Proposed Wellhead Diagram 5. BOP Drawing . , Trading Bay Unit • . fir SCHEMATIC Well #A-10 Re-Completed 10/15/78 Hilcora Alaska,LL(: CASING AND TUBING DETAIL RKB to TBG Hngr=37' SIZE WT GRADE CONN ID TOP BTM. Tree connection: Dual 3"5,000# 13-3/8" 61 K-55 Butt 12.515 Surf. 1,095' 1 I 9-5/8" 40&43.5 K-55&N-80 8rd LT&C 8.755 Surf 7053' Tubing: A o — t o I— 13 LS 3-1/2" 9.3 N-80 Butt. 2.992 0' 4434' 2-7/8" 6.4 N-80 Butt 2.441 4435' 5718' I t• 5S 3-1/2" 2-7/8" 9.3 N-80 Butt. Butt 2.992 0' 4146' 4145' 6.4 N-80 2.441 4191' B io2 ,2 Dip Tube 2-3/8" 6.2 N-80 Butt 1.853 4084' 5537' C _ — Tagged fill @ 940'on 12/29/88 w/ JEWELRY DETAIL I-316"GR 1 C./6'1 D it NO. Depth ID Item Mimi 4 37' Cameron Slit Tubing hanger. E SHORT STRING A 3-1/2"Otis Ball Valve,SSSV,2.75 a B 2078' 3-1/2"Otis Gas Lift Mandrel, FE C 2976' 3-1/2"Otis Gas Lift Mandrel, 0 5D 3605' 3-1/2"Otis Gas Lift Mandrel, G ' (A, E 4044' 3-1/2"Otis Gas Lift Mandrel, H lam/ \/ �/ 6 1 t1�� F 4080' 3-1/2"Otis"XA"Sliding Sleeve �/\ /\ /� G 4145' 2.441 Cross over,3-1/2"X 2-7/8" H 4146' Otis Triple Hydraulic Packer bI 4189' Otis"XN"Nipple I ■ ■ 17¶ J Btm 4191' EOT J o LONG STRING 8 1 291' 3-1/2"Otis Ball Valve,SSSV,2.75 2 2111' 3-1/2"Otis Gas Lift Mandrel, r C r 9 3 3103' 3-1/2"Otis Gas Lift Mandrel, C-Zone 4 3892' 3-1/2"Otis Gas Lift Mandrel, d ) 5 4112' 3-1/2"Otis"XA"Sliding Sleeve 6 4147' Otis Triple Hydraulic Packer 7 4249' 3-1/2"Otis"XA"Sliding Sleeve 10 8 4434' Cross over,3-1/2"X 2-7/8" 9 4497' 2-7/8"Camco Gas Lift Mandrel 10 4754' Blast Joints e 0111 4874' 11 5030' 2-7/8"Camco Gas Lift Mandrel 3/Collar 12 5442' 2-7/8"Camco Gas Lift Mandrel 5388' -1 f I 13 5604' 2-7/8"Otis"XA"Sliding Sleeve 14 5640' Locator Seal Assy. g 12 15 5641' Otis Perm Packer h 16 5685' Otis"X"Nipple = 17 btm 5718' Mule Shoe. o 13 Dip Tubing a. Top 4084' " 14 b. 4159' 1-1/2"Telescoping Joint c. 4496' Camco GLM • ■ 15 ' d. 4513' 1-1/2"Telescoping Joint e. 5030' Camco GLM 16" f. 5052' 1-1/2"Telescoping Joint K. 5442' Camco GLM h. btm 5537' Bull Plug D-Zone FISH Junked BP 3/21/68 @ 6525' E Junked BP 3/25/68 @ 6525' = E Zone Junked BP 7/30/70 @ 6515' = g Junked Retainer 8/870 @ 6503' k`. Guiberson"A"Pkr 8/9/70 @ 6503' AO ' 1/2 of ring from hyd pkr 7/14/73 @ 6496' �_ )ji) ` \•' 2 Junked Retainers 7/16/73 @ 6494' MO Junked Perm Pkr 10/5/78 @ 6500' Perforation Details on Next Page i i KBELEV= 101' PBTD=6,750' TD=7,073' ANGLE thru INTERVAL=12.7° Updated by: .ILL 01-10-14 . . Trading Bay Unit SCHEMATIC Well #A-10 Re-Completed 10/15/78 Hilcora Alaska,LLC Top Btm Top Btm Accum. Date Zone (MD) (MD) (TVD) (TVD) _ Amt. SPF Last Opr. Present Condition 3,840' 3,860' 3,563' 3,582' 20' 4 3/22/1968 DST,Cmt sqz'd,tested to 1500 psi 4,148' 4,168' 3,844' 3,863' 20' 4 3/20/1968 DST,Cmt sqz'd,tested to 1500 psi 4,240' 4,241' 3,929' 3,930' 1' 4 3/24/1968 WSO.Tested to 1500 psi C 4,262' 4,288' 3,949' 3,973' 26' 4&8 7/30/1970 Open to Production _ C _ _ 4,316' 4,354' 3,999' 4,035' 38' 4&8 7/30/1970 Open to Production C 4,398' 4,430' 4,076' 4,106' 32' 4&8 7/30/1970 Open to Production C 4,498' 4,514' 4,169' 4,184' 16' 4&8 7/30/1970 Open to Production C 4,572' 4,592' 4,238' 4,257' 20' 4&8 7/30/1970 Open to Production C 4,668' 4,694' 4,328' 4,353' 26' 4&8 7/30/1970 Open to Production C-7 4,766' 4,864' 4,420' 4,512' 98' 4,8&12 7/30/1970 Open to Production C 5,012' 5,050' 4,651' 4,687' 38' 4 3/26/1968 Open to Production C 5,096' 5,100' 4,730' 4,734' 4' 4 7/30/1970 Open to Production C 5,124' 5,132' 4,756' 4,764' 8' 4 7/30/1970 Open to Production C 5,244' 5,249' 4,868' 4,873' 5' 4 7/30/1970 Open to Production C 5,325' 5,358' 4,944' 4,975' 33' 4,8&12 7/30/1970 Open to Production _ C 5,532' 5,534' 5,137' 5,139' 2' 3/5/1970 Cmt sqz'd w/200 sx class G C 5,534' 5,590' 5,139' 5,191' _ 56' 4&8 7/30/1970 Open to Production C 5,590' 5,592' 5,191' 5,193' 2' 3/5/1970 Cmt sqz'd w/200 sx class G D 5,684' 5,712' 5,280' 5,307' 28' 8 7/30/1970 Open to Production 53-8 5,787' 5,838' 5,379' 5,429' 51' 4,8&12 3/8/1974 Open to Production _ 54-5 5,870' 5,880' 5,460' 5,469' 10' 8 7/16/1973 Open to Production 54-9 5,900' 5,954' 5,489' 5,541' _ 54' 12 7/16/1973 Open to Production D 5,985' 6,020' 5,571' 5,605' 35' 4&8 7/30/1970 Open to Production D 6,030' 6,134' 5,615' 5,716' 104' 4,8,12&16 3/8/1974 Open to Production 57-2 6,160' 6,245' 5,742' 5,826' 85' 4,8,12&16 3/8/1974 Open to Production E 6,274' 6,296' 5,854' 5,876' 22' 8 8/8/1970 Open to Production E 6,274' 6,296' 5,854' 5,876' , 22' 4,8&12 7/16/1973 Open to Production E 6,320' 6,352' 5,900' 5,932' 32' 12 7/16/1973 Open to Production 6,600' 6,740' 6,179' 6,319' , 140' 4 1/6/1968 Open to Production 6,760' 6,840' 6,339' 6,419' 80' 4 1/4/1968 DST,cmt sqz.Isolated by BP @ 6750' 6,904' 6,919' 6,483' 6,498' 15' 4 1/3/1968 DST,cmt sqz.Isolated by BP @ 6750' Updated by: JLL 01-10-14 . Trading Bay Unit PROPOSED Well #A-10 Completion Date: Future HiIcor,Alaska,LLC CASING AND TUBING DETAIL RKB to TBG Hngr=37' SIZE WT GRADE CONN ID TOP BTM. Tree connection:Dual 3"5,000# 13-3/8" 61 K-55 Butt 12.515 Surf. 1,095' 9-5/8" 40&43.5 K-55&N-80 _ 8rd LT&C 8.755 Surf 7053' its 1 Tubing: _ - 2-7/8" 6.58 8rd EUE Surf ±4212' JEWELRY DETAIL NQ Depth ID Item 37' Cameron Slit •'ing hanger. 1 ±320' SSSV 2 1ae? ±2000' GLM ±3000' GL ±4000' G 3 5 i 450' hemical Inj Mandrel 6 ¢4180' Packer �@ ±d130': X-Nipple g' ±4212' WLEG 4 Top Btm Top Btm Accum. Date Zone (MD) (MD) (TVD) (TVD) Amt. SPF Last Opr. Present Condition r 5 11 # 3,840' 3,860' 3,563' 3,58 20' 4 3/22/1968 DST,Cmt sqz'd,tested to 1500 psi 4,148' 4,168' 3,844' 3 •3' 20' 4 3/20/1968 DST,Cmt sqz'd,tested to 1500 psi 6 4,240' 4,241' 3,929' 930' 1' 4 3/24/1968 WSO.Tested to 1500 psi Kt 7 C 4,262' 4,288' 3,949' 3,973' 26' 4&8 7/30/1970 Open to Production III it C-1 ±4,267' ±4,288' ±3,•.4' ±3,973' 21' Future Re-Pert M 8 C 4,316' 4,354' ,•99' 4,035' 38' 4&8 7/30/1970 Open to Production C-2 ±4,318' ±4,354' ±4,001' ±4,035' 36' Future Re-Perf C-3 ±4,396' ±4,434' ±4,074' ±4,109' 38' Future Re-Pert C 4,398' 4,430' 4,076' 4,106' 32' 4&8 7/30/1970 Open to Production E-C-Zone C 4,498' 4,5 4,169' 4,184' 16' 4&8 7/30/1970 Open to Production C-4 ±4,500' ±•, 14' ±4,171' ±4,184' 14' Future Re-Pert ----5 C 4,572' ',592' 4,238' 4,257' 20' 4&8 7/30/1970 Open to Production C-5 ±4,576' ±4,594' ±4,242' ±4,259' 18' Future Re-Pert C 4,668' 4,694' 4,328' 4,353' 26' 4&8 7/30/1970 Open to Production C ±4,68 ±4,696' ±4,341' ±4,355' 14' Future Re-Perf C-7 4, •6' 4,864' 4,420' 4,512' 98' 4,8&12 7/30/1970 Open to Production C-7 + ,767' ±4,868' ±4,421' ±4,516' 101' Future Re-Perf DV Collar ®5 ' = C47-5 5,008' ±5,050' ±4,647' ±4,687' 42' Future Re-Perf = C 5,012' 5,050' 4,651' 4,687' 38' 4 3/26/1968 Open to Production t li PE C 5,096' 5,100' 4,730' 4,734' 4' 4 7/30/1970 Open to Production ric ++� 4 C48- ±5,098' ±5,102' ±4,732' ±4,735' 4' Future Re-Pert �/-3�a°F-N L,/ C4 -7 ±5,123' ±5,133' ±4,755' ±4,764' 10' Future Re-Pert Il5,124' 5,132' 4,756' 4,764' 8' 4 7/30/1970 Open to Production C ±5,244' ±5,249' ±4,868' ±4,873' 5' .: 4 7/30/1970 Open to Production 7C 5,325' 5,358' 4,944' 4,975' 33' 4,it&12 7/30/1970 Open to Production liy,/------ --- ------- ,/' C 50-3 ±5,328' ±5,358' ±4,9471 ±4,975' 30' Future Re-Pert /f i / C 5,532' 5,534' . s,isr 5,139' 2' 3/5/1970 Cmt sqz'd w/200 sx class G /�" C 51-6 ±5,532' ±5,598 ±5,137' ±5,199' 66' Future Re-Pert M C 5,534' 5,590r 5,139' 5,191' 56' 4&8 7/30/1970 Open to Production C 5,590' 5,592' 5,191' 5,193' 2' 3/5/1970 Cmt sqz'd w/200 sx class G D 5,684' 5,712' 5,280' 5,307' 28' 8 7/30/1970 Open to Production D One D 53-0 ±5,684' ±5,722' ±5,280' ±5,316' 38' Future Re-Perf 53-8 5,787' 5,838' 5,379' 5,429' 51' 4,8&12 3/8/1974 Open to Production -/ D 53-8 ±5,790' ±5,838' ±5,382' ±5,429' 48' Future Re-Perf -/ 54-5 5,870' 5,880' 5,460' 5,469' 10' 8 7/16/1973 Open to Production 0 54-5 ±5,870' ±5,883' ±5,460' ±5,472' 13' Future Re-Perf 1 E Zone D 54-9 ±5,899' ±5,958' ±5,488' ±5,545' 59' Future Re-Perf 54-9 5,900' 5,954' 5,489' 5,541' 54' 12 7/16/1973 Open to Production ITSr? ±5,970' ±5,976' ±5,557' ±5,562' 6' Future New Perf D , 5,985' 6,020' 5,571' 5,605' 35' 4&8 7/30/1970 Open to Production D 55-7 ±5,986' ±5,992' ±5,572' ±5,578' 6' Future Re-Perf / D 55-7 ±6,005' ±6,020' ±5,590' ±5,605' 15' Future Re-Perf D 56-1- -1'6,030' ±6,132' ±5,615' ±5,714' 102' Future Re-Perf =7. D 6,030' 6,134' 5,615' 5,716' 104' 4,8,12&16 3/8/1974 Open to Production D 57-2 ±6,160' ±6,242' ±5,742' ±5,823' 82' Future Re-Perf 57-2 6,160' 6,245' 5,742' 5,826' 85' 4,8,12&16 3/8/1974 Open to Production E 58-1 ±6,270' ±6,300' ±5,850' ±5,880' 30' Future Re-Perf E 6,274' 6,296' 5,854' 5,876' 22' 4,8&12 7/16/1973 Open to Production / E 58-7 ±6,316' ±6,352' ±5,896' ±5,932' 36' Future Re-Perf KB ELEV=101' E 6,320' 6,352' 5,900' 5,932' 32' 12 7/16/1973 Open to Production HEM ±6,584' ±6,720' ±6,163' ±6,299' 136' Future Re-Perf PBTD=6,750' 6,600' 6,740' 6,179' 6,319' 140' 4 1/6/1968 Open to Production TD=7,073' 6,760' 6,840' 6,339' 6,419' 80' 4 1/4/1968 DST,cmt sqz.Isolated by BP @ ANGLE thru INTERVAL=12.7° 6750' 6,904' 6,919' 6,483' 6,498' 15' 4 1/3/1968 DST,cmt sqz.Isolated by BP @ 6750' Updated by: JLL 01-13-14 Trading Bay Unit PROPOSED Well #A-10 Completion Date: Future Ilikwrp Alaska,Ill: CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BTM. RKB to TBG Hngr=37' 13-3/8" 61 K-55 Butt 12.515 Surf. 1,095' Tree connection: Dual 3"5,000# 9-5/8" 40&43.5 K-55&N-80 8rd LT&C 8.755 Surf 7053' 0 I- 1 2-7/8" 6.58 8rd EUE Surf ±4212' JEWELRY DETAIL NO Depth ID Item 37' Cameron Slit Tubing hanger. 1 ±320' SSSV 2 2 ±2000' GLM 3 ±3000' GLM 4 ±4000' GLM 3 5 ±4150' Chemical Inj Mandrel 6 ±4180' Packer 7 -4210' X-Nipple 8 -1212' Ported Sub 9 TCP Guns 4 Top Btm Top Btm Accum. Date + 5 Zone (MD) (MD) (TVD) (TVD) Amt. SPF Last Opr. Present Condition # 3,840' 3,860' 3,563' 3,582' 20' 4 3/22/1968 DST,Cmt sqz'd,tested to 1500 psi :111111 Ik. 6 4,148' 4,168' 3,844' 3,863' 20' 4 3/20/1968 DST,Cmt sqz'd,tested to 1500 psi 4,240' 4,241' 3,929' 3,930' 1' 4 3/24/1968 WSO.Tested to 1500 psi X 7 C 4,262' 4,288' 3,949' 3,973' 26' 4&8 7/30/1970 Open to Production • g # :,7' ±4,288' ±3,954' ±_, Future Re-Perf C 4,316' 4,354' 3,999' 4,035' 38' 4&8 7/30/1970 Open to Production C-2 ±4,318' ±4,354' ±4,001' ±4,035' a Re-Perf - C-3 s4,396' ±4,434' ±4,074' ±4,109' 38' Future Re-Pert as C-Zone C 4,398' 4,430' 4,076' 4,106' 32' 4&8 7/30/1970 Open to Production ,w = C 4,498' 4,514' 4,169' 4,184' 16' 4&8 7/30/1970 Open to Production ±4,514' ±4,171' ± 14' Future erf C 4,572' 4,592' 4,238' 4,257' 20' 4&8 7/30/1970 Open to Production 9 = ±4,576' ±4,594' ±4,242' ±4,259' 18' Future Re-Perf = C 4,668' 4,694' 4,328' 4,353' 26' 4&8 7/30/1970 Open to Production l, c C ±4,682' ±4,341' ± 5' 14' Future Re-Perf = C-7 4,766' 4,864' 4,420' 4,512' 98' 4,8&12 7/30/1970 Open to Production 4 DV Collar C-7 ±4,767' 68' ±4,421' ±4. :6' 101' Future Re-Perf ©5388' „ . :47-" x5,008' ±5,050' ±4,647' ±4,687' 42' Future Re-Perf t` ^ _ C 5,012' 5,050' 4,651' 4,687' 38' 4 3/26/1968 Open to Production } * ---=:: C 5,096' 5,100' 4,730' 4,734' 4' 4 7/30/1970 Open to Production C48-5 ±5,098' ±5,102' ±4,732' ±4,735' 4' Future Re-Perf C 48-7 ±5,123' ±5,133' ±4,755' ±4,764' 10' Future Re-Perf 4 * C 5,124' 5,132' 4,756' 4,764' 8' 4 7/30/1970 Open to Production C ±5,244' ±5,249' ±4,868' ±4,873' 5' 4 7/30/1970 Open to Production IC50 C 5,325' 5,358' 4,944' 4,975' 33' 4,8&12 7/30/1970 Open to Production = -3 ±5,328' ±5,358' ±4,947' ±4975' Future Re-Pert C 5,532' 5,534' 5,137' 5,139' 2' 3/5/1970 Cmt sqz'd w/200 sx class G C 51-6 ±5,532' ±5,598' '7' + Future Re-Pert C 5,534' 5,590' 5,139' 5,191' 56' 4&8 7/30/1970 Open to Production r'-' g C 5,590' 5,592' 5,191' 5,193' 2' 3/5/1970 Cmt sqz'd w/200 sx class G D 5,684' 5,712' 5,280' 5,307' 28' 8 7/30/1970 Open to Production r. 1 r D-Zone D 53-0 ±5,684' ±5,722' ±5,280' ±5,316' 38' Future Re-Pert r 53-8 5,787' 5,838' 5,379' 5,429' 51' 4,8&12 3/8/1974 Open to Production D 53-8 ±5,790' ±5,838' ±5,382' ±5,429' 48' Future erf 54-5 5,870' 5,880' 5,460' 5,469' 10' 8 7/16/1973 Open to Production -' D 54-5 ±5,870' ±5,883' ±5,460' ±5,472' Futur= Re-Pert r▪ E Zone D 54-9 ±5,899' ±5,958' ±5,488' ±5,545' F Re-Pert 54-9 5,900' 5,954' 5,489' 5,541' 54' 12 7/16/1973 Open to Production I = D 55-7 ±5,970' ±5,976' ±5,557' ±5,562' F Perf A "A D 5,985' 6,020' 5,571' 5,605' 35' 4&8 7/30/1970 Open to Production D 55-7 ±5,986' ±5,992' ±5,572' ±5,578' 6' Future Re-Perf D 55-7 ±6,005' ±6,020' ±5,590' ±5,605' 15' Future Re-Perf D 56-1 ±6,030' ±6,132' ±5,615' ±5,714' 102' Future Re-Perf - D 6,030' 6,134' 5,615' 5,716' 104' 4,8,12&16 3/8/1974 Open to Production D 57-2 ±6,160' ±6,242' ±5,742' ±5 723' 82' Future Re-Perf 57-2 6,160' 6,245' 5,742' 5,826' 85' 4,8,12&16 3/8/1974 Open to Production E 58-1 ±6,270' ±6,300' ±5,850' ±5,880' 30' Future Re-Perf E 6,274' 6,296' 5,854' 5,876' 22' 4,8&12 7/16/1973 Open to Production E 58-7 ±6,316' ±6,352' 896' ± °2' 36' Future Re-Perf KB ELEV=101' E 6,320' 6,352' 5,900' 5,932' 32' 12 7/16/1973 Open to Production PBTD=6,750' HEM ±6,584 .163' ± 9' 136' Future Re-Serf TD=7,073' 6,600' 6,740' 6,179' 6,319' 140' 4 1/6/1968 Open to Production ANGLE thru INTERVAL=12.7° 6,760' 6,840' 6,339' 6,419' 80' 4 1/4/1968 DST,cmt sqz.Isolated by BP @ 6750' 6,904' 6,919' 6,483' 6,498' 15' 4 1/3/1968 DST,cmt sqz.Isolated by BP @ 6750' Updated by: JLL 01-28-14 Monopod Platform II A-10 Current 01/03/2014 Monopod Tubing hanger,dual,CIW- A-10 DCB,11 5M X 3''A EUE 8rd lift 13 3/8 X 9 5/8 X 3 1/2 X X 3'''A IBT bottom,w/3"type 3 1/2 H BPV profile,1/8 non cont control line ports in hangersii III all Tree assy,dual block,CIW-F, / 11 5M X 3 1/8 5M X '', 3 1/8 5M,prepped on 44i 5 3/64 center,3"CIW seal . pockets,'/npt control line exits '-'r1= r;i el tt" afir I ■ *2UJ11 III Tubing head,CIW-DCB, Valve,CIW-F,2 1/16 5M FE, 13 5/8 3M X 11 5M,w/2- 10, ` _ �� HWO,AA 2 1/16 5M SSO,X-bottom ID I O 0h 8 prep e � - IiI I lit n Casing head, 1.11 i Shaffer KD, 11 I I I 135/83MX 13 3/8 SOW,w/2-2" ® 2"LP CIW ball valve LPO, ISI 1.. 1 1 1. i■-I•; 'II . Monopod Platform A-10 Proposed 9 5/8 01/14/2014 Ililrarp 1IaAka.i.l.(, Monopod Platform Tubing hanger,SME-CL,11 X A-10 3'A EUE lift and susp,w/3" 13 3/8 X 9 5/8 X 2 7/8 Type H BPV profile,2-3/8 CCL,Alloy material BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union ui !,., ti u1Win Valve,Swab,WKM-M, 3 1/8 5M FE,HWO,DO trim °e k 0 C O 0 Valve,Wing,WKM-M,3 1/8 5M FE,w/15"OMNI iliAiiWIlr operator,DD trim - 11 OMNI in^lei pOr Valve,Master,WKM-M, �O 31/85M FE,HWO,DD trim 0 0---61:1 •A�iiiu, mum OP lel DOr Valve,Master,WKM-M, m 1 ,c 3 1/8 5M FE,HWO,DD trim 4.0, 0-6i0, n w i 1—' I i_...:Nom. tom. $ Tubing head,S-8,13 5/8 3M -uu1 I I c�,l��il_r' it -) 1,9 . x 11 5M,w/ G bottom2 1/16 ZP 191 4, � 550,w/BG bottom w/1-21/165MWKM-M = : �l valves Jii � ._i c "� .JiilI ems -I• `� (tai 3 0p°es„ 'I: Casing head, 111 . PIP Shaffer KD, (UI 135/83MXQ 133/8 SOW,w/2-2" M rnH. i ! . I. LPO i > IF Monopod Platform 2013 BOP Stack 03/12/2013 liilrnrr tbiekn.l.IA Rig Floor Bottom of air boot flange • 5'below rig floor 16" 1472' 9.50' Pipe IlltirTillittIIIII 0 O 111111 111 I11 III III I11 III 3.74 Shaffer 135/8SM Aafatirtlithill 26.25' Shaffer LXT f_ 2 7/6-5 Variables mom 2'50 135/8 SM Bllnd r4.1 ,( II 111'III'111'I1 ,�1tt 1.76 I�. Q� f? Mud Cross `/i ii "mai.", •4111111111h- w/31/85M EFO w/2 1/16 5M Choke and Kill valves w/Unbolt enc connections for lines ill iIi Ill 111 I11 283' CIW-U 135'SM Dual Cameron Flex rams . 11 Il 'I:. 111 lir Y .70' III II!III Il -Ili V 14.20" Drill deck UOCD 1911 Riser 14.20' 5 135/85M FE X 135/85M FE IiI lil 111 I1 A, III cI!IfI !1 iII Spacer spool 1.5' 135/85M FEX113M It: I, I..i ,I.. Wellhead @ 15.00' August 3, 2009 Dale A. Haines Manager, Oil & Gas Operations Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, � -1 c5 `7 C,-- 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 AUG 0 h� 2009 NP0,F; flil & Szs ! ns, CnmmigsiAn s�cniM� OCT 03 2014 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, �,F, I � Ctkl- Dale Haines Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 14-42 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 16-42 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 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 Sep -0 I 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 platforrn 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 21B-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 23B-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 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 444 17406601 Oct4 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct -9i no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec4 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 no known damage no flow Possible shallow as or as storage 2011-2014 Monopod A-10 1670760 Collapsed casin ProducingCoal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 �qJun-8 Colla sed casin Producin Coal Phase I Abandon abandon at end of latform life Mono od A-30 1730140 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of pl form life 4.f1/LZSEA ®ice! AND GAS CONSERVATION C®PiMSSION June 22, 2009 Dale Haines SARAH PALIN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 i PHONE (907) 279-1433 FAX (907) 276-7542 UNOCAL SCAMM 0 (; T 0 2X114 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubertnalaska.gov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Company Permit No. Well Name UNOCAL Union Oil Company of California 168-024 Granite Pt St 17587 5 Union Oil Company of California 194-149 Granite Pt St 18742 03RD _ Union Oil Company of California 179-033 Granite Pt St 18742 14 Union Oil Company of California 167-077 Granite Pt St 18742 16 Union Oil Company of California 168-012 _ Granite Pt St 18742 18 Union Oil Company of California 100-266 Granite Pt St 31-14RD2 Union Oil Company of California 182-020 Trading Bay Unit D-06RD Union Oil Company of California 169-004 Trading Bay Unit D-18 Union Oil Company of California 188-098 Trading Bay Unit D-30RD2 _ Union Oil Company of California 182-083 _ Trading Bay Unit D40RD _ 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 Unocal North Americ " Oil & Gas Division ~: Unocal Corporation ~ P.O. Box 190247 ) Anchorage, Alaska 99519-0247/ Telephone (907) 276-760.~ UNOCA.L ) Alaska Region April 16, 199-0 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. JohnSon: I have attached' surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor'but I hope this will meet your needs. Yours very truly, G a~S.~, u s~h'' ~~~ Reglona1 Drilling Manager GSB/lew CORDUCTOR . lO ll 12 13 14 15 16 17 18 19 20, 21 22 25 26 27 28 29 3O 31 32 MONOPOD CENTER FROM SOUTHEAST CORNER, "Y" = 2,523,126 "X" = 218,871 "Y" COORD. 2,523,134.3 2,523,130.2 2,523,125.7 2,523,121.7 2,523,118.2 2,523,114.4 2,523,113.2 2,523,113.2 2,523,114.8 2,523,117.7 2,523,121.8 2,523,126.4 2,523,130.3 2,523,133.8 2,523,137.6 2,523,138,8 2,523,138.8 2,523,137,.2 2,523,132.8 2,523,129.4 .2,523,132,0 2,523,128.4 ...2.52.3._1.~4.8 .-_: ____ 2,523,133.9 2,523',120.9 2,523,131.4 2,523,118.1 2,523,127.2 2,523,123.6 2,523,120.0 2,523,122.6 2,523,119.2 "X" COORD. 218,880.9 218,883.2 218,883.9 218,883.2 218,881.3 218,876.8 218,873.0 218,869.0 218,864.6 218,861.1 218,858.8 218,858.1 218,858.8 218,860.7 218,865.2 218,869.0 218,873.0 218,877.4 218,875.7 218,878.6 218,870.8 218,873.9 .~..9.1 ~. ~7F~. 9 218,867.0 218,878.1 218,863.9 .218,875.0 218,865.1 218,868.1 218,871.1 218,863.4 218,866.3 SECTION 4, TgN, R~I,3W~ , LONG. : 151 ° 34' 4 3 51" ~'~~7't · WELL # FSL _ __ A-28 1621 A-25 1617 A-30 1612 1608 A-27 1605 , A-23 .1601 A-21 and RD 1600 A-22 1600 A-14 1601 A-13 1604 A-17 1608 A-8 1612 A-15 1616 A-24 and RD 1620 A-29 1624 A-9 and RD 1625 A-19 1625 A-18 1624 A-11 1619 A-3 1616 A-1 1618 A-7 1615 A-4 1611 A-6 1600 A-32 1607 A-12 and RD 1617 A-20 1604 A-2 1613 A-16 1610 A-26 1606 A-10 1609 A-5 and RD 1605 1 &2 FEL 554 551 551 551 '553 557 561 565 570 573 576 577 577 574 570 566 562 558 559 556 564 561 '568 556 571 559 570 566 563 571 568 Unocal Oil & Gas Divisio ~""~\ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Environmental Group Alaska District July 18, 1986 Ms. Elaine Johnson AK. Oil & Gas Conservation Comm. 3001 Rorcupine Drive Anchorage, Alaska 99501 Dear Ns. Johnson: Listed below is the information you recently requested on the status of the following wells: ~ GPS 11-13 TBS A-10 & A-16 Hemlock zone 'shut in, not abandoned. The well is still producing from the Granite Point Sands. Sundry notice to abandon .A-lO & A-16 submitted March, 1984. The abandonment was never performed. TBS A-23 G-23RD, G-33 & G-34 A-23S shut in since September, 1983. A-23L has just been shut in. This well is not abandoned. Dual string producer. Middle Kenai "G" shut in March, 1984. K-21RD K-30 Dual string producer shut in July, 1983. The well is not abandoned. Dual string producer, Middle Kenai shut in July, 1982. The well is not abandoned. If you have any further questions, give me a call. Very truly yours, Candace LockwOod 'RECEIVED 00280 J U L 2 1986 Alaska O~l & Gas Cons, Commissi0~ Anchorage ~ STATE OF ALASKA ~.~'~ ALASF ..'L AND GAS CONSERVATION ~ ~,~IlSSION SUNDR OTICES AND REP'ORTSON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator Union Oil Company of California 3. Address P.0. Box 6247, Anchorage, Alaska 99502 4. Location of Well Cond 31, 1609'N & 571'W of SE Cor, Sec 4, T9N, R13 W, SM 6. Lease Designation and Serial No. ADL 1.8731 5. Elevation in feet (indicate KB, DF, etc.) RT 101' MSL 7. Permit No. 67-76 12. 8. APl Number 50-733-20064 9. Unit or Lease Name Trading Bay State 10. Well Number TBS A-lO 11. Field and Pool Trading Bay Field 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). 1. Move rig over TBS A-lO and rig up. 2. Kill well, install BPV, remove tree, install & test BOPE to 3000 psi. 3. Pull and lay down exiSting dual completion assembly. 4. Clean out to permanent ~.tc/k}er at 5640'~TMD. Mill over perma,nent packer,and push~ to bottom + 6463' .~-~,,,./ '~ 7°?3 --TP ~ ~ 5. Run Multi-shot gyro survey from surface to TD. 6. Set cement ret at + 6255' DIL and sqz the "E" zone for abandonment w/+ 100 sxs, cement. - - ~- 7. Set cement ret at + 5660' DIL and sqz the "D" zone for abandonment w/+ 250 sxs cement. - -~Z~ 8. Abandon the "C" zone with balanced cement plugs across the perforations (~ 5590 - 4262'). ~ ~ ~~ ~/~~ ~~, ~ .... ~.~ 14. I h eby cBrti e f oing is ue and correct to the best of my knowledge. R. Callender rideD~Sg. Dr~ll~n~ Superintendent ~t~ 03/07/84 Tho spaco belo~ for Commission use Conditions of Approval, if any: · . ORIG'ftAI. SIG~I-.ED Appi'ovedby BY LOH,'iE C. SMITH COMMISSIONER Date k~--I'~ '(~'¢ Form 10-403 Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate Approved Copy ,-. Returned By Order of the Commission Union Oil C~ny o~ Calitornia P.O. Box 7600 ~enai, Alaska 9951! ATTIC's lifo Bob. Culver Area Product~ ion Superint en~ien~ Res No Flow Tests on Mils A-IOS and A-!0L. Monopod Platfon~ Gentl~n: We have reviewed the test ~ta fr~ the no-flow tests of wells A-10S and A-10L on the ~onopod Platform ~i~ ~re ~tness~ by petrole~ i~~or Doug A~s. These ~lla, A-10S and A-10L, have ~~trat~ that th~ are not cap. lc of unasaist~ fl~ and. therefore, re.va1 of the subsu~ace safety vails fr~ th~ ~11s is approved. LCStJ~/glh ~o. ~.~o lO5 MERI · o ~ iMEMORA, DUM Ste,e of Alaska L AND GAS CONSERVATION COMMISSION TO:g~ - On DATE: February 2, .1.982, FILE NO: ].08A/O Commi s sioner FROM: Doug ~s Petrole~ Ins.~or TELEPHONE NO: SUBJEOT: Witness the No-Flow Test on Wells A-10L and A-10S on . Union ' s Monopod Plat form rida¥,.Jan~azy 7, 1983---I traveled this date to the n'op~' ~"~0~ .%o.-~i~ness. the no-flow.tests. Well A-10L was ~ut-. i~o. ~est separator NO. 1 at 12.00 a.m. this date and ~i'~-'-A~,.~iOS went into test separator No. 2. I arrived at the ~n°~Od at 8=30 .a.m. and marked the sight glasses on the separators and: initialed the charts. At 4: 30 p.m. I checked the sight glasses and observed no increase in volume. As the atta.:~ed charts show the wells were both dead during this te~. I recommend that no-flow status be granted to both A-10L and A-10$ wells. In summary, I witnessed the successful no-flow test on Union's Monopod Wells A-10L and A-10S. Attached to this report are four charts used during this test. 02-O01A(Rev.10/79) FIELD. TRADING BAY FIELD TYPE UNIT__ OILWF_I] F~60 E BEGAN:9/26/78 COMPLETED: 10/15/78 ELEVATIONS: GROUND PERMIT NO. 67-76 SEriaL NO. AD[. 1873]. CASING HEAD COMPANY ENGINEER Boulw~re/Graham/A~a~n-~. . TUBING HEAD AppROVED (~ .S. ~'.,_.-~: .. ,~../~.,' .~- _~'E'?~-?_-~_~ . ROTARY DRIVE BUSHING ~ / CASING & TUBING RECORD SIZE DEPTH WEIGI~T~'' GRADE .................. REMARKS .., . . . 13 3/8" 1095' 61# 0-55 Cmt'd to surface w/1200 SX Cl. "G" Cement. 9 5/8~' 7053' 40 & 43. 5# ]-55&N-80 D.V. collar at 5349' Cmt'd w/750 SX Cl. "G" w/l% CFR-2 1st stage and 250 S× CI."G" w/l% CFR-2 2nd stage. 3 1/2~' Dual 9.2# N-80 See attached'detail .... PERFORATING RECORD DATE INTERVAL E.T.D. REASON , PRESENT CONDITION 1/03/68 6904'-6919' 6984' DST #1 ". Sqz'd thru ret. @ 6875' w/50 S×. t/04/68 6760'-6840' '6875' DST #2 Sqz'd thru ret. @ 6750' w/50 SX. 1/06/68 6600'-6740' 6750' Production Isolated by bridge plug @ 6525' 3/19/68 5330'-5350' 6525 DST ' "D" Zone - Open 50-3 SD 3/20/68 4148'-4168' 6525 DST - Sqz'd w/100 S× 44-7 SD 3/22/68 3840'-3860' 4054' DST . Sqz'd w/200 S× 41-8 SD ~ ' C((L~/~ 3/24/68 4240' 4270' Block Sqz. Sqz'd w/100 SX 4~ :~'~!(:.~ 3/25/68 4262'-4288 6525' Production "C" Zone- Open '~<~ ' ' liP,' 7nn,', nn,-,n 4316 -4354 6525' Production ~ ~ .... - ~ ..... . I 'DATE I INTERVAL NET OIL CUT . GRAV. C.P. T.P. CHOatE MCF GOR lqEMARI~-q , ., ;. -'( ':- ". .~"'.' .i,'!.~',,.;: · ' - ' ' ... : .:' i :- · .- - ' :-:.!"...:(-: :.' :';:j4i . -;-.:':',.il :'~::-7:-";i?:,.'/-- ' ' ;- , · '. ': ' ' ;' ' . - -; ) - ' ":~".; '!'. ~.", . ': .i'; ~:::~! :q' ;.; .-" ,:.- .. · . ' ' . .' . ' ~ '... ,. . . ';:::'.u' - : . :'.'..' · ~ :E'L'~];J';:'~'~. ' '~". - ~::.7:)"~: :. ' ':.-. -;- ":.:::. ';-? .":.~::': '~-: :; ~ ..' --.-... (: :.(. )::j-'" '~ ':??:~....' :.~ ' :2~"U":':.,..''.:~::~:~'.~~(;~:,.;- - , . ?:.-.::.v. ~: , :: ~ ~' . - ...:.:' . -- '. :_'. -':....~ ...,.::':-:~.:: · ; ':;:,?.,-.' ....:~.::;( :~ ..~ .. ". :-::7~ :'~:~;~:: .... ;'- .-. · '. . ~ ." - .' '-' .- · : · '.. : :-:,~.: '. -'-'-. ,':. './-~". ,...'?:~ ,'-'~,: .. .:?. ;:. h? .E:~.' 'L1::-:7~-:-'.~: · · . . '." . · · ' · .., ' .-. ,.: . :'- . ' ..- -- "- :~ ' : . ': "-': ~ -.' ; ?::~-u. ': J-." ". -:a. ~i .' fi) J,::<_: -~ .c- ' ,? .~-. ,: , ' . - :.: - . .. :,, :.j ::- . ,,E~:.:~..~. . . .,: .':: .... ,.. . . ..-':.::-..,. :..-.., . ..', · .:-. % - .~-::,:--~E~ ~ ~:~.~ ~,'~?' ~, .. . . ": ~:-':~'. , - . · : :.~?:'. - ',' ;: ,' ~--:, ", · - . - ........ , ..' ' - -- . '. y' -:.'-..2: ;'.j~>'~:.;-',. -:: ~:'~ .. :.;.' '-¥- '~<.i'c-".-'- .["' .' ' '. -; -; ." - ' _ ;' ~ "1' :'_ · '".' ' '-'/~:-. '-:?: ': .i : ;"..,' . ;: '.': " ., '~ :;' :' -.' · · ":' -'; - .~ 4' ;~ k..~,;~: : ~:~, ~;-~: '.' ' ' ' - ~' 'l ]' ' . . - , ' 1'm.' ' ' / ~'. ~ ~ ~: :": f' ~ ' ' [ ' ' '~ ' .... ~ ' '" ~'"' c'' ' v ';~' ' "' ~ ":' ~ ' - ' C'E ' .. ~ ..:. - . -~ ,.. . ..:.-~ _'.'.- :...; ... :.' .. ' ." ...'.: . ~ . :'-; :..'t :E'~ ~,,~;':'..' ..('?~:~:'?':-~. ' - '~'U;' "-. 'Z':,.' '".-,u-~/-;-:-~ L-'(;..t~.~[-:> :.~ '~jCE.:-.?,'.L'.-:- '" ~ ' ': ' " .-. ...-'c'_] '' '-'~' :-" '" - '~ ~ /~ ' ~ t ~ - : ".-;- ' ~ ~, ';~- . ; .~:~. :- :;"'.::-:- :: ~;::.q~:: ::: ..-; :, ; a. ' ..'j?.;~;-~:;; ~.:."' ~ T:'.<::".:~:..~ ""~::~?;::.::~:'.. J~<~;:f:~:~Z~;~?~ :~':~i~ :~}~:~L);;:':~._ : ." · .-'.- ':.' :, · '.:.' :.. : ...... .".L" -;:??'.' · :":~': :: '-?:',::"~;::: :' '~:~':.E".. ".- ' "h~:~::)'' ,.;"~".~'?. f%:E:; .... :"- ' ' ' "" ' ' ::"'il ' '"-'~-. '" -'~'"~ :::;. ; :-:?" :' ,' ?" ?"':?:7:? "'"' ' ":':' f'' .... ''" ':": '"~:' ??' :]" .... '~ W~,T.L HISTORY 'PRIOR TO REPAIR COMPLETION DATE: '~ 7/21/73 - '- .... '-' ~ -' - ...,-- PRODUCING INTERV~: INITIAL PRODUCTION' LAST .REGULAR PROD. & DATE: ~.UMULATIVE PRODUCTION' REASON FOR REPAIR: To acid/_~nlwnt wash Form D-IOO1-B OF' CALIFORNIA LEASE TRADING BAY STATE ' COMPLETION DATE: 10/15/78 DATE E.T.D'. DATE INTERVAL 3 ~Z5'7-68 4398"-443'0' 4498' ~4514' WELL NOA-1 a Wa_ FIELD__TRAD! NG BAY APPROVED DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS ETD 6525' 6525' REASON ' Production I, PRESENT CONDITION II II .. 4572'-4592' · ,. 4668' -4693' "i~: ;',-i [ 4766'-4864' : (' ~, ' I I ' '-:::'{-"::cT--~L 5330' -: .: 5350' - 5358 -' 5532'-5592 . i' 5684'-5712 ., 5787'-583.8 5900'-5954 . 5985'-6020 6030' -6088 6100'-6130 : < 6160' -6245 7 / 3 o / 4320'-4350' . 4402'-4430' 4500'-4510' 4574'-4592' 4672'-4694' 4834' -4862' . .. 5096'-5100' 5124'-5132' 5244'-5249' 5328'-5354' _ ], 5534'-5590' '~- . ':;:~ - _, .- 5790'-5834' · '·. 5870'-5880' . ~,.::..:L~?i 5900'-5954' · .~.~ 6002'-6012' "' .... 6040' '6130" '.:11%1' 6222'-6240' "~ ¥:~"-:'+~ 2 ' ' 8/8/70 6320'-6352' 7/16/73 - · 6274'-6296' 6222' -6230' 6275'-6296' TYPE: .. ' ' ,, .: '.:, ': . ~, .',, .....,, ../;, v.- ":, "' ·" ':'~. ' ' II ":' '.' ' "~ '' ['' I'; -.'"" II - ' '' .: "i't: '"'.i,-",.'.:~.. '" "~.;'? ~ ~-[:~i~':'i~-'.-_': ::.' "::. " .-' ' "::' Il , .-/'.-'-' '"u -.il Il . ' J :"~: :~:." "' ?:.:. ...,.,, .,..;... ,'%.-,,'~;.,, ...... :.. ,,.,,:~' :'<:'(.:::,:..;~:: .,; .. ;'- ': .' ~"' .:: : .:" :'~' I'1' .. '"" "':- · II .... -' ~1 II - : - . -.:. II . :':.' j,;. II !1 II : ...~, . ,.,. . , . - " ' ~ Sqz' d w/160 SX ' " · - :,''. '"D",~ Zone - Open ~, .. ~. -~,:~: ~,~:;,.:~,:;~:.,:..~ .~- ':. -.. :"-.'-' .. - "- II II II . · : "..,- I1' U . ..... II . ' :" .~; :~:,~... ':..:.:,C Zone ,.Repe_f. -.OPen . ' :' II ' -II ." ~ ~ U ':"~ .(, '?" '--' ...U .. ' I1';" ': :' ::' ' II . II II - - : -, :,.:; ..... ....:', ..... , : :, .-: .-: ,~ ,': ,:.' - . ::~:: : ,. :' ._ · . , , , . ' ;. '(:.""-'- "::', '" , ':"-~:') t::,,"' "': '11~-' ZOn'6 ?' .. '..6503 . ,E" Zone 6494" WELL ~F-AD ASSEMBLY - ~=' ........... ;~": -' ........ .... ::: ~::~. ~.-:, :.,:. ~::.:v '.~: ~?~,,.;~,,;:,.:: · ;,.--:~:, ;~ :~,~ '~ , :~ 4 ~:~`~ ~L;:~z ?: ~~:~h~.~:~ ~` :~:`t".~:~:..Z`~ ~g~?~U:~(?~:~;`~2~y~~:~`:~ ~ ~%· TUBING HEAD TOP' ]0" 5000# '(DUAL ,3 ]/2,,) '' ......... ": "'"' DuAL ~ASTER ~""~A~' '3':] MASTER VALVES: ' /8,,' ' ~-~:':': -..: :. _ z ..... _ .. .... .: :-.-- '. :-:.-~:,:~-::'.t: ';..:.:',: ~.,~),':;:-':--~'~,~.:-~ .`;::~`~::~?~`::<~.:.~`?:~:~:h`~.?~.c~/`~.`t~:~`~.~`?:~`~/.~?~;.7g`4`~:::``L`.~?`~.`t~t~:~.~:f~;~-~:~`U:'' .: ilFc~-rm D-IO01-C ~ Oil LEAsETRADING'BAY STATE COMPLETION DATE: 10/15/78 DATE DATE 7/16/73 5: .. ' -, ." E.T.D. INTERVAL 6320'-635; 5900'-595z 5870'-5881 4795' -483, .... WELT_, NO~'lOWO "FIELD ·'"'TRADING BAY .... APPROVED '" ''~ '" ' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS · ": PRESENT CONDITION '"'·'. ;' ~ ETD . , :~. REASON - '- 6494' Production ' '" !'D" ' ' ' ~'' :' r '' ''-. ;-"' Zone - Reperf. Open . ': ::' : ':,::: :' i~ii;:i-i]:" "C" Zone rf. _ 'Open : :::?i:]::: :~'~ " ..... " , " ' -~. ' -'Repe . - . ~ _' : /;. . .'. ::., , ii::.: . -.' . -'~,' ~ - :'-: :,i ' ,-".;... ,. - . -. -. .. , , ', ._ .; ~ . ... :, . ... , '; .~':. :' ~..,.- .' ', .-'~ .. :: .... , . ..' ,- . , ,.,~ ~: ,<-; ~' · ' ' ": ~ : ' ' .... : -' i ,.;. '" v, "':i -' "' ': :"'"": "]' ' " '":'"; ""'~:'"~'; · ;:, .. :":~ · .. S EET D PAGE !~0, OIL CQ'. ,aJ,h' CF CALIFOR IIA -,IELL LEASE I'~LL IlO, A- 10 FIELD DATE 1 9/26/78 2 9/27/78 3 9/28/78 4 9/29/78 5 9/30/78 6 10/01/78 7 10/02/78 8 10/03/78 9 10/04/78 t0 10/05/78 ETD 7073' TD 6503' ETD(BP) 13 3/8"@1095' 9 5/8"@7055' 7073' TD 6503' ETD(BP) 13 3/8"@1095' 9 5/8"@7055' 7073' TD 6503' ETD 13 3/8"@1095' 9 5/8"@7055' 7073' TD 6503' ETD 1 3 3/8"@1095' 9 5/8"@7055' 7073' TD 6503' ETD 13 3/8"@1095' 9 5/8"@7055' 7073' TD 6503' ETD 1 3 3/8"@1095' 9 5/8"@7055' 7073' TD 6503' ETD 1 3 3/8"@1095 9 5/8"@7055' 7073' TD 6503' ETD 1 3 3/8"@1095 9 5/8"@7055' 7073' TD 6503' ETD 13 3/8"@1095' 9 5/8"@7055' 7073' TD 6503' ETD 13 3/8"@1 095' 9 5/8"@7055' DETAILS OF OPEP2~TIONS, DESCRIPTiG~IS & RESULTS Commenced operations oo:O1 hrs. 9/26/78. Mov. ed rig over A-10 and RU. Pulled gas lift valves from S.S. Displaced annulus w/W.O, fluid. Bullheaded 100 bbls of W.O. Fluid down S.S. and 50 bbls down L.S. Jet cut S.S. at 4186' 15' above triple prk at 4201'. Installed back press, valve removed tree, installed and tested BOPE. Well started taking fluid in L.S. and flowing in S.S. Spotted 100 bbls W.O. fluid w/20 PPB safe seal out L.S. & 50 bbls out S.S. Well was taking 20 bbl fluid per hr., giving up gas, oil cut mud. Pulled gas lift valves from L.S. Perf'd long string from 5295' to 5297' Circ. Well dead .thru long string. POH. & L.D. Short St~ing. Pulled long string loose. Circ. & Cond. to 78 PCF. POOH & L.D. 3 1/2" L.S. left 800' of L.S. & dip tube in. hole. Ran I.B., showed top 2 7/8" fish @4769. RIH & engage fish w/ 3 1/4" grapple. POOH. No rec. Redressed grapple RIH & engaged fish w/ 3 1/4" grapple. Ran dialog free point W.L. Tools wouldn't enter fish. Ran W.L. Scale cutter & cut scale to 4840'. Ran 2 1/4" W.L. Swedge to 4951'. POOH. Left swedge @ 4951'. Ran 2 1/4" tbg. cutter & stuck tools. Ran. W..L. over shot & rec. cutter. Ran 2 1/8" cutter & cut 2 7/8" @4945'. POOH & rec. 4 jts. 2 7/8" tbg. RIH w/ 1 1/2" grapple. Engage 1 1/2" string & POOH. Rec. Tele-scopic its. from 1 1/2" side string. Ran I.B. & found top 2 7/8" fish @ 4983. POOH. & rec. 2 j ts. 2 7/8" tbg. on I.B. Reran I.B. & found' top 2 7/8" @4997. Reran I.B. & found top 2 7/8" @4997. RIH w/ 3 1/4" grapple & engage fish. Free point & string .shot w/ 2 7/8" @5340'. POOH & rec 11 jts. 2 7/8" tbg. Ran I.B. & found top of 1 1/2" fish @ 5133'. RIH w/junk-basket & work over fish. POOH w/junk basket - no rec. Tag fish w/I.B. @5133'. Showed junk on top of 1 1/2" tbg. RIH w/mouse trap over- shot & engaged fish. POOH. Rec. 11 its. of 1 1/2" dip tube. Tag fish w/I.B. @5185' - 1 1/2" upset looking up. RIH w/ 2 1/8" grapple & engage fish @5282'. Backed off 1/2" & POOH. Rec. 4 jts. 1 1/2" tbg. RIIt w/ 2 1/8" grapple & engage fish @5305'. Backed off 1 1/2" & POOH. Rec.. 4 jts. of 1 1/2" tbg. RIH w/3 1/4" grapple & engage 2 7/8" fish @5340'. Pulled fish loose w/15OM# POOH & rec. all of remaining 2 7/8" & 1 1/2" tbg. RIH w/burning shoe to 5657' & mill on junk on top of perm pkr. POOH. RIH w/new mill & mill over perm. pkr. @5658'. Pushed pkr. down hold 20' then it stopped. POOH. RIH w/6 3/4" grapple & engage pkr. POOH. No rec. RIH w/8 1/2" bit & 9 5/8" casing scraper, to 6318. Washed & reamed f/6328' w/bit & scraper POOH. RIH w/ new bit on scraper & washed & reamed f/6353' to 6500'. Circ. hole clean. Pulled to 5000' then back to BTM. Pulled up to 6245'~ & changed over to 78 PCF CACL2 W.O. Fluid. SI-:EET D PAGE ~b, OIL cor-?/ i'h' CS CALIFO 'IIA I ,£LL I' ECOt LEASE l'i~U_ ~I0, A-10 FIELD DATE II 10/06/78 12 10/07/78 13 10/08/78 14 10/09/78 15 10/10/78 16 10/11/78 17 '10/12/78 18 1 0 1 3/78 ]9 10/14/78 ZO 10/15/78 ETD 7073' TD 6053' ETD 1 3 3/8"-@1095' 9 5/8"@7055' 7073' TD 6503' ETD 1 3 3/8"@1 095' 9 5/8"@7055' 7073' TD 6503' ETD 13 3/8"@1095' 9 5/8"@7055' 7073' TD 6503' ETD 13 3/8"@1095' 9 5/8"@7055' 7073' TD 6503' ETD 1 3 3/8"@1095' 9 5/8"@7055' 7073' TD 65031 ETD 1 3 3/8"@1095' 9 5/8"@7055' 7073' TD 6503' ETD 1 3 3/8"@1095' 9 5/8"@7055': 7073' TD 6463' ETD 7073' TD 64631 ETD (Sa~ 7073' TD 6503' ETD(BP) DETAILS OF OPEP~TIONS, DESCRIPTiO~IS & RESULTS POOH. RIH w/retrievatic & set @4250'. Tested' csg. above 4250' @2000 psi - OK. POOH. RIH w/Baker Model "B" Circulating washer to 6249'. Located perfs @6245'. Spot acid to tool & acid washed perfs f/6245' to 6160' 6134' to 6030', 5954' to 5900', 5880' to 5870', 5835' to 5787', 5712' to 5684' w/20 gal/ft. 5% HC1, w/7% Mutual Solvent, .4% A-170 & .5 W-35. (Note' Washed w/bag closing holding approx. 700 psi. on back side) Shut in 1 hr. to soak. Circ. BTMS up. POOH. RIH w/ redressed wash tool. Acid washed perfs f/5590' to 4262' as above. Circ. BTMS up. POOH. Ran gauge ring to 5700' set Otis WD Pkr. @5640'. Well began to flow. RIH. Circ. & cond. mud thru choke to 79 PCF. Circ. & cond. W.O. fluid to 80 PCF. Receiving severly H2S cut mud. Avg. + 150 to 200 PPM H2S. Continued cir. out H2S cut mud (all personnel wearing air packs). Couldn't control well w/Brine. ×-over'th gel mud. Wait on Boat 20 hrs. Build gel-mud to circ. out well Tested pkr. @5640' - No test. POOH. RIH .w/2 3/8" Stinger on D.P. & tag fil @ 6330'. Circ. out ~ill to 6463'. POOH RIH w/retrievamatic & set @5634 Tested pkr. point. - No test. POOH, (Found hole in ~rill pipe - H2S corrosion') RIH w/retrievamatic & set @4102' & test D.P. - OK. RIH & set @5634' & test pkr. point - OK. Reran seal assy on DP & tested Otis perm pkr @5640' - OK. Ran tbg. as per detail. Spaced out - set pkr (_removed BOPE & installed X-mas tree d Fill) 'Disp. well w/FIW. Released well to Prod Dept @ 12:00 PM 10/15/78 & released rig to Monopod De-act AFE #381023. SKEET D PAGF LEASE TRADING BAY STATE OIL CF CALIFO 'IIA I:ECORD I'~LL ,iO, A-10 WO FIELD TRADING BAY FIELD ?DATE ETD JTS 13 16 4 25 DETAILS OF OPEP~TIONS, DESCRIPTiG~IS & RESULTS TUBING DETAIL LONG STRING DESCRIPTION LENGTH BOTTOM 4 1/2" 10RD Mule Shoe 4 1/2" 10RD X 2 7/8" Butt. X-over 2 7/8" 6.4# Butt. Tbg. 2 7/8" Otis "X" Nipple 2 7/8" 6.4# Butt. Tbg. 4 1/2" 10RD X 2 7/8" Butt. X-over Otis Seal Assembly Locator Sub (Otis- Perm. Pkr. (a5640') 4 1/2" lORd X 2 7/8" Butt. X-over 2 7/8". 6.4# Butt. Tbg. 2 7/8" Otis "×A" Sleeve 2 7/8" 6.4# Butt. Tbg. Camco GLM 2 7/8" 6.4# Butt Tbg. Camco GLM 2 7/8" 6.4# Butt Tbg. 2 7/8" Butt X 2 7/8" EUE X-over 2 7/8" Blast Joints 2 7/8" EUE × 2 7/8" Butt. X-over 2 7/8" .6.4# Butt. Tbg. Camco GLM 2 7/8" 6.4# Butt Tbg. 2 7/8" Butt. 'X 3 1/2" Butt. X-over 3 1/2" 9.2# Butt. Tbg. 3 1/2" Otis "×A" Sleeve 3 1/2" 9.2# Butt. Tbg. Otis Tripl-e- Hyd. Pkr. 3 1/2" 9.2# Butt. Tbg. 3 1/2" Otis "×A" Sleeve 3 1/2" 9.2# Butt Tbg. 3 1/2" PUP 3 1/2" 9.2# Butt Tb§~ Otis GLM 3 1/2" 9.2# Butt Tbg. 3 1/2" PUP 3 1/2" 9.2# Butt Tbg. 3 1/2" PUP 3 1/2" 9.2# Butt Tbg. Otis GLM 3 1/2" 9.2# Butt. Tbg. 3 1/2" PUP 3 1/2" 9.2# Butt. Tbg. 3 1/2" PUP 3 1/2" 9.2# Butt. Tbg. Otis GLM 3 1/2" 9.2# Butt. Tbg. 3 1/2" PUP TOP ' , , · 61 ' 5718.43' 571 7.82' .80' 5717.82' 5717.02' 31.10' 5717.02' 5685.92' 1.42' 5685.92' 5684.50' 31.05' 5684.50' 5653.45' .95' 5653.45' 5652.50I 11.50' 5652.50' 5641.00' 1.O0' 5641.00' 5640.00' · 80' 5640.00' 5639.20' 31.00' 5639.20' 5608.20 3.60' 5608.20' 5604.60 156.09' 5604.60 5448.51 6.55' 5448.51 5441.96 405.04' 5441.96' 5036.92 6.72' 5036.92' 5030.20 154.78' 5030.20' 4875.42 1.O0' 4875.42J - 4874.42' 120.181 4874.42' 4754.241 1.22' 4754.24' 4753.02' 249.50' 4753.02' 4503..52' 6.74' 4503.52' 4496.78' 62.21 4496.78' 4434.57' 4434.57I 4433.93' 4253.38: 4248.83' 4157.46' 4147.36' 4116.40' 4111.85' 4052.75' 4048.65 3898.33 3891.71 3861.45 3855.33 3616.14 3606.02 3109.58 3102.9.7 2986.40 2976.42 2211.56 2207.'41 ' 2117.63' 2111 .O5' 2082, O9' .64 180.55 4.55 91.37 10.10 30.96 4.55 59.1'0 4.10 · 150.32 6:62 30.26 6.1.2 239.1'9 10.12 49.6.44 6.61 116.57 9.98 764.86 4.15'~ 89.78' 6.58' 28.96' 5.16' 4433.93 4253.38 4248.83 4157.46 4147.36 4116.40 4111.85 4052'~ 75 4048.65 3898.33 3891.71 3861.45 3855.33 3616.14 3606.02 3109.58 3102.97 2986.40 2976.42 2211.56 2207.41 2117.63 2111.05 2082.09 2076.93 S~EET PAGE IJHIO['I OIL COF?~'h' CS CALIFO~'IIA WELL I',ECOt~ ~E TRADING BAY STATE I';~LL r IO, A-10WO FIELD TRADING BAY FIELD .~ATE ETD JTS 44 14 36 6 141 183 ,.No, DESCRIPTIG~IS & RESULTS DETAILS OF OPEP~ATI~" DESCRIPTION LENGTH BOTTOM 1345.72 4.12 433.60 2.50 243.69 9.30 1.O0 37.00 3 1/2" 9.2# Butt. Tbg. 3 1/2" PUP 3 1/2" 9,2# Butt. Tbg. Otis Ball Valve 3 1/2" 9.2# Butt. Tbg. 3 1/2" PUP Cameron Tbg. Hanger Elevation Total Joints 2 7/8" 6.4# N-80 Butt. Tbg. Total 2 7/8" Blast Joints Total Joints 3 1/2" 9.2# N-80 Butt. Tbg. TOTAL JOINTS 2076.93 731.21 727.09 293.49 290.99 47.30 38.00 37.00 TOP 731.21 727.09 293.49 29O.99 47.30 38.00 37.00 00.00 S EET D PAG UHIC,'[I OIL CF CALIFOR 'IIA 'ELL ,ECO m ~E TRADING BAY STATE I. LL IlO, A-]OWO FIELD TRADING BAY DATE ETD JTS 2 1 14 8 8 4 13 7 9 12 45 9 1 132 133 DETAILS OF OPEPATISNS, DESCRIPTIG~IS ~ RESULTS TUBING DETAIL' SHORT STRING DESCRIPTION LENGTH BOTTOM 2 7/8" Otis "XN Nipple 2 7/8" 6.4# Butt. Tbg. 2 7/8" Butt. X 2 7/8" EUE X-over Otis Tiple Hyd. Pkr. 2 7/8" EUE X 3 1/2" Butt. X-over 3 1/2" 9.2# Butt. Tbg. 3 1/2" Otis "×A" Sleeve 3 1/2" 9.2# Butt. Tbg. Otis GLM 3 1/2" 9.2# Butt. Tbg. Otis GLM 3 1/2" 9.2# Butt. Tbg. 3 1/2" PUP 3'1/2"'9.2# Butt. Tbg. 3 1/2" PUP 3 1/2" 9.2# Butt. Tbg. Otis GLM 3 1/2" 9.2# Butt. Tbg. 3 1/2" PUP 3 1/2" 9.2# Butt. Tbg. 3 1/2" PUP 3 1/2" 9.2# Butt. Tbg. Otis' GLM 3 1/2" 9.2# Butt. Tbg. 3 1/2" PUP 3 1/2" 9.2# Butt. Tb§. Otis Ball Valve 3 1/2" 9.2# Butt. Tbg.~ 3 1/2" PUP Cameron Tbg. Hanger E1 evati on 1.84 31.37 1.05 10.95 .76 61.45 4.05 29.39 6.57 431.94 6.65 241.55 5.10 246.48 10.10 119.66 6.54 391.77 6.10 208.86 10.10 274.85 6.59 362.25 5.21 1 383.02 2.50 277.26 9.35 1.00 37.00 4191.31 4189.47 41 58.1 0 4157.05 4146.10 4145.34 4083.89 4079.84 4050.45 4043.88 3611.94 3605.29 3363.74 3358.64 3112.16 3102.06 2982.40 2975.86 2584.09 2577.99 2369..1.3 2359.03 2084.1 8 2077.59 1715.34 1710.13 327.11 324.61 47.35 38. O0 37.00 Joint 2 7/8" 6.4# N-80 Butt. Tbg. Total Jts. 3 1/2" 9.2# N-80 Butt. Tbg. TOTAL JTS. TOP 4189.47 41 58.10 4157.05 4146.10 4145.34 4083.89 4079.84 4050.45 4043.88 3611.94 3605.29 3363.74 3358.64 3112.16 3102.06 2982.40 2975.86 2584.09 2577.99 2369.13 2359.03 2084.18 2077.59 1715.34 1710.13 327.11 324.61 47.35 38.00 37.00 O0 $ EET D PAGE OIL CF CALIFOF 'IIA I:,£LL I',ECOt LEASE TRADING BAY STATE l'i~Ll_ IlO. A-10 WO FIELD TRADING BAY DATE Ell3 JTS 1 2 10 DETAILS OF OPEPATIONS, DESCRIPTiG~IS & RESULTS TUBING DETAIL SIDE STRING DESCRIPTION LENGTH BOTTOM 2 3/8" Bull-plugged jt. 2 3/8" Tbg. 2 3/8" Butt. X 1 1/2" 10Rd X-over Camco GLM 1 1/2" 10Rd X 2 3/8" Butt. X-over 2 3/8" Butt. Tbg. 2 3/8" PUP 2'3/8" Butt. Tbg. 2 3/8" Butt. × 1 1/2" 10 Rd X-over 1 1/2" Telescoping it. 1 1/2" 10 Rd X 2 3/8" Butt. X-over 2 3/8" PUP 2 3/8" PUP 2 3/8" Butt. X 1 1/2" 10 Rd X-over Camco GLM 1 1/2" 10 Rd × 2 3/8" Butt. X-over 2 3/8" Butt. Tbg. 2 3/8" Butt. × 2 3/8" EUE X-over 2 3/8" Blast Joings 2 3/8" Tbg. 1/2" Telescoping jt. 3/8" PUPS (2) 2 3/8" Butt. X 1 1/2" 10 Rd X-over Camco GLM 2 3/8" Tbg. 2 3/8" PUPS (2) 1 1/2" Telescoping it. X-over X-over )tis Triple Hyd. Pkr. 3/8" Tbg. 2 3/8" Plug§ed & Perf'd Tbg. - Top of 2 3/8" Dip Tube TOP 26.25' 5536.82' 5510.57' 60.52' 5510.57' 5450.05' · 54' 5450.05' 5449.51 ' 7.02' 5449.51 ' 5442.49' .54' 5442.49' 5441.95' 244.67' 5441.95' 5197.28' 4.10' 5197.28' 5193.18! 121.22' 5193.18' 5071.96' · 80' 5071.96' 5071.16' 19.27' 5071.16' 5051.89' 1.09' 5051.89' 5050.80' 6.20' 5050.80 5044.60' 6.15' 5044.60' 5038.45' .53' 8.08' .72' 153.00' 1.O0' 120.51' 217.14' 24.42' 8.13' .50' 8.08' 305.55' 8.30' 23.65' .60' .78 10.90' 30.67' 31.48' 5038.45' 5037.92' 5037.92' 15029.84, 5029.8z~'" 5029.12 5029.12 4876.12 4875.12 4754.61 4537.47 4513.05 4876.12 4875.12 4754.61 4537.47 4513.05 4504.92 4504.92' 4504.42' 4496.34' 4190.79' 4182.49' 41 58.84' 4158.24' 4157.46' 4146.56' 4115.89' 4504.42 4496.34 4190.79 4182.49 4158.84 4158,24 4157.46 4146.5'6 4115.89' 4084.41 ' 4084.41 ' [ ~ [' [ [ i ~ ill [nl LONG STRING 1. 3' 1/2" Otis Ball Valve-291' 2. 3 1/2" Otis GLM-2111' 3. 3 1/2" Otis GLM-3103' 4. 3 1/2" Otis GLH-3892' S. 3 1/2" Otis "XA" Sleeve-4112' 6. Otis Triole Hydraulic Pkr-4146' ?. 3 1/2" Otis "XA" Sleeve-4249' 8. XO 2 ?/8" Butt x 3 1/2" Butt-4434' 9. 2 7/8" Camco GLM-4497' 10. 2 7/8" Camco GLM-5030' 11. 2 ?/8" Camco GLM-5442' l!fr. 2 7/8" Otis "XA" Sleeve-560S' Otis Perm. Packer- 5640'~ 14. 2 7/8" Otis "X" Nipple-S684' 15. Mule Shoe-5718' SHORT STRING A. 3 1/2" Otis.Ball Valve-325' B. 3 1/2" Otis GLM-2078' C. 3 1/2" Otis GLM-2976' D. 3 1/2" Otis GLM-3606' E. 3 1/2" Otis GLM-4044' 3 1/2" Otis "XA" Sleeve-4080' G. XO 2 7/8" Butt x 3 1/2" Butt-4145' H. Otis Triple Hydraulic Pkr-4146' I. 2 7/8" Otis "XN" Nipple-4189' J. End of String-4191' DIP TUBE I. 1 1/2" Expansion Jt-4159' II. Camco GLM-4497' ~II. 1 1/2" Expansion Jt-4513' IV. Camco GLM- 5030' V. 1 1/2" Expansion Jt-5052' VI. Camco GLM-5442' H 1095'-13 3/8" 61# J-55 Buttress Csg. "C" Zone 4262'-5590' (At Intervals) __13 "D" Zone 5684' -6245' .(At Intervals) "E" Zone 6274'-6352 (At Intervals) 6463' -Sand Fill 6503' -Bridge Plug 7053'-9 5/8" 40# & 43.5# J-55 & N-80 Buttress Csg. DATE FORM 247 (NEW TRADING BAY STATE WELL A-10 W.O.- WELL SCH~4ATIC UNION OIL COMPANY OF CALIFORNIA 9/78 A/'P'D. SGAI.~ DATE CKD. I ' I COmmenced Operations Spudded Wcll@ Completed Opo~ations UNION OIL COMPANY OF CALIFORNIA Log, Pwr 'Co. · Co. Rig Direct'l W.L. Cont Fuel Trans Trans. !Prod. Prod.. Rig Daily Accum. l,oc. Cont. Bits Mud Casing Cement Drill. Perf. Lab Rentals Wtr. Pers Mat. Stim. &Sup: Equip.' Fac. Fishing Rep. Misc. Total Total Operation ...... -- - ' .... ~ ~ ' ~ ~,"t~' ~;):'77' ~':)i~ '~q~'/'K~ ;~,{~ .... ' ' ' ....... ,.. , -,.,~~ '~,~.",~c, . . ,.:;'~;~[.~ A~~ ~'~{"' ........ ' ' ' ' cfc .,, ¢' :' ~ c -- ..... ,, , , .. , ,,,,- ,......... _ ,. _ ., . , . _ , , , . · ~ · , .',', " ' r~m c),' , ..... ,. ,~., (~ ~~--"~ ?o%o ":;. ~ % .~ . .... . :~'?,:'~ Io~L L.~,k _ ~"F.r~,- ~ ~]>.:'~F.~', ~)~ '(;) tlq'% "[ C, ~ ,? ,,.,. ¢,t.,, ? . . - .... ' ..... " ' ............. ...... '*--. . ..... , , - ,.. , ..... ~ ,., . . , . , . , ~ , , ~ , ., , ,,, , ,, 1, , ,,, , , , , .... ,, - _ .-,,i .... , .,. ....... , ..... . ~ .... , . , ,, , ........ , ¢ .... , .... . ,~= · ,, . ~ .. , I ..... . ., ' . ~. . .- _ , .... , .,, , ..... , . ..... . .... , ,. , . , . , , , ,, " ' ' ..... ' '' ' ..... I .... ...... . . , . ~ , , ..,, ~ , , ,, ~ .. . I · , ..... , ,_ , ., . ~ _ . ..... ..... ~ . .. ,,.' , , t ,, , · , , . . _ , -_ .... . ..... ] . . .... . , , , _ . ~ .... · .... . ....... . ....... , ..... .... " ,, .' ....... ,, ,,-1 ! ,, · , , , Form No. !0-4~ /'~-"'~'. SUBMIT IN DUPLICATE REVel3.1.70 /t STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE s.APl NUMERICAL CODE 50-133- 20064 6. LEASE DESIGNATION AND SE" MONTHLY REPORT OF DRILLING AND WORKOVER OPE TIONS ADL 1873] , 7. IF INDIAN.ALOTTEE OR TRIBE ~-~' ~ ~ ~ WELL WELL OTHER ~, '~ ~ 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME UNION 0IL C0. 0F .CALIFORNIA ~(~:~ :-~ n ,:~.-?~ TRADING BAY STATE P.0. BOX 6247, ANCHORAGE, ALAS~,ic ......... ~., TBS A-10 4. LOCATION OF W~[ ......... ~ UU ~ GaS 6~s~ali08 m. FI~D AND ~OO~, O~ WISPA .... BAY-"C" ~" ~h,~ra~ TRAD I NG 1609' N & 571' W from SE Corner of Sec. 4, TDN, R13W. S.M. ~.stc. t.,.~.motto,.ot~ OBJECT~VE) Sec. 4, TDN, R13W, 12. PERMIT NO. 67-76 13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 10/1/78 7073' TD 6503' ETD 13 3/8"@1095' 9 5/8"@7055' Reran I.B. & found top 2 7/8" @4997' RIH w/ 3 1/4" grapple & engage fish. Free point &'string shot w/ 2 7/8" @5340'. POOH & rec. 11 jts. 2 7/8" tbg. Ran I.B. & found top of 1 1/2" fish @5133'. RIH w/junk basket & work over fish. 10/2/78 7033' TD 6503' ETD 13 3/8".@1095' 9 5/8"@7055' Pooh w/ junk Basket - no rec. Tab fish w/ I.B. @5133'. Showed junk on top of 1 1/2" tbg. RIH w/mouse trap over- shot & engaged fish. POOH. Rec. 11 jts. of 1 1/2" dip tube. Tag fish w/ I.B. @5185'- 1 1/2" upset looking up . 10/3/78 7073' TD 6503' ETD 13 3/8"@1095' 9 5/8"@7055' RIH w/ 2 1/8" grapple & engage fish @5282'. Backed off 1/2" & POOH. Rec. 4 jts. 1 1/2" tbg. RIH w/ 2 1/8" grapple & engage fish @5305'. Backed off 1 1/2" & POOH- Rec. 4 jts. of 1 1/2" tbg. RIH w/3 1/4" grapple & engage 2 7/8" fish @5340'. Pulled fish loose w/ 15OM# POOH & rec. all of remaining 2 7/8" & 1 1/2" tbg. 10 10/4/78 10/5/78 7073' TD 6503' ETD 13 3/8"@1095' 9 5/8"@7055' 7073' TD 6503' ETD 13 3/8"@1095' 9 5/8"@7055' RIH w/ burning shoe to 5657' & mill on junk on top of perm pkr. POOH. RIH w/new mill & mill over perm pkr. @5658'. Pushed pkr. down hold 20' then it stopped. POOH. RIH w/ 6 3/4" grapple & engage pkr. POOH. No rec. RIH w/8 1/2" bit & 9 5/8" casing scraper, to 6318'. Washed & reamed f/6328' w/bit & scraper POOH. RIH w/ new bit on scraper & washed & reamed f/6353' to 6500'. Circ. hole clean. Pulled to 5000' then back to BTM. Pullei up to 6245' & changed over to 78 PCF CACL2 W.O. fluid. 14. I hereby ceg{ify~hat the fore, g6tng~rue ignd correct SIGNED~_~.-/~"'/'/~L~~TITLE DIST. DRILLING SUPT. DATE 11/17/78 / NOTE~eport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. 11 12 13 14 15 16 17 10/6/78 10/7/78 10/8/78 10/9/78 10/10/78 10/11/78 10/12/78 7073' TD 6503' ETD 13 3/8"@1095' 9 5/8"@7055' 7073' TD 6503' ETD 13 3/8"@1095' 9 5/8"@7055' 7073' TD 6503' ETD 13 3/8"@1095' 9 5/8"@7055' 7073' TD 6503' ETD 13 3/8"@1095' 9 5/8"@7055' 7073' TD 6503' ETD 13 3/8"@1095' 9 5/8"@7055' 7073' TD 6503' ETD 13 3/8"@1095' 9 5/8"@7055' 7075' TD 6503' ETD 13 3/8"@1095' 9 5/8"@7055' POOH. RIH w/retrievatic & set @4250'. Tested csg. above 4250' @2000 psi - OK. POOH. RIH w/ Baker Model "B" circulating washer to 6249'. Located perfs @6245' Spot acid to tool & acid washed perfs f/6245' to 6160' 6134' to 6030', 5954' to5900', 5880' to 5870', 5838' to 5787', 5712' to 5684' w/ 20 gal/ft. 5% HCL, w/7% Mutual Solvent, .4% A-170 & .5% W-35. (Note: Washed w/bag closed holding approx. 700 psi. on back side) Shut in 1 hr. to soak. Circ. BTMS up. POOH. RIH w/ redressed wash tool. Acid washed perfs f/5590' to 4262' as. above. Circ. BTMS up. POOH. Ran gauge ring to 5700' set Otis WD Pkr. @5640'. Well began to flow. RIH.Circ. & cond. mud thru choke to 79 PCF. Circ & cond. W.O. fluid to 80 PCF. Receiving severly H2S cut mud. Avg. +_150 to 200 PPM H2S. Continued cir. out H2S cut mud (all personnel wearing air packs). Couldn't control well w/Brine. X-over to gel mud. Wait on Boat 20 hrs. Builid gel-mud to circ. out well Tested pkr. @5640' - No test. POOH. RIH w/2 3/8" Stinger on D.P. & tag fill @6330'. Circ. out fill to 6463'. POOH. RIH w/retrievamatic & set @5634' Tested pkr. point. - No test. POOH. (Found hole in ~rill pipe - H2S corrosion) RIH w/retrievamatic & set @4102' & test D.P. - OK. RIH & set @5634' & test pkr. point- OK. 18 10/13/78 7073' TD Fc"' 1~403 ' RI~. 1-10.,73 Submit "intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA 0IL.AND GAS CONSERVATION COMMITTEE 5. APl NUMERICAL CODE 50-133-20064 6. LEASE DESIGNATION ANO SE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL, [--J OTHER 2. NAME OF OPERATOR UNION OIL CO. OF CALIFORNIA 3. ADDRESS OF OPERATOR P.O. BOX 6247, ANCHORAGE, ALASKA 99502 ADL 18731 7. IF INDIAN, ALLOTTEE OR TRII 8. UNIT, FARM OR LEASE NAME .... l" TRADING BAY STATE ...... TBS A-10 : 10, FIELD AND POOL, OR WlLDCA~ TRADING BAY-"C" "D" "E 11, SEC., T., R,, M., (BOTTOM HOLE. 4. LOCATION OF WELL At surface 1609' N & 571' W from SE Corner of Sec. 4, 19N, R13W, S.g. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 101' RT Above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re SEC. 4, T9N, R13W, S.M. 12. PERMIT NO. 67-76 )ort, or Other Data NOTICE OF INTENTION TO-' TEST WATER SHUT-OFF L----J FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF.' WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING AC ID I ZING ABAN DO NM ENT'* (Other) SEE BELOW (NOTE-' Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent (letells, and give pertinent dates, including estimated date of starting any proposed work. ACID SOLVENT WASHED ALL "C", "D", AND "E" ZONE PERFORATION~ IN ~E6-[~E~LOWS' , 2. 3. 4. 5. e 7. 8. 9. 10. Removed tree, installed and tested BOPE. 0~r 2 ~ 197[} Pulled and layed down existing 3 1/2" production equipment. Reco~e~Otis perm. pkr. from 5674' with 6 5/8" grappBi~tSi0rI Of Oil & ~aB ~rvatic Cleaned out with 8 1/2" bit and 9 5/8" csg. scraper to ETD of/~j~§r~a Acid solvent washed "C", "D", and "E" zone perforations 6245'-6160', 6134'z6030', 5954'-5900', 5880'-5870', 5838'-5787', 5712'-5684', 5590'-4262', with 20 gal/ft..5% HCL with 7% mutual solvent,.4% A-170 and,5% W-35. Set Otis W.D. perm. pkr. on W.L. @5640'. Cleaned out fill to 6463'. Ran dual 3 1/2" completion assy. w/triple, kyd.. pkr. at 4147'. Removed BOPE, installed and tested tree. Put well on gaslift production, producing from the "C", "D", and "E" zones. 16. I hereby certify that the foregoing is true and correct - '- ~ IT LE 'd i~-i~, ua±±en(l~er ' (This spa~ for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.' TITLE' Dist. Drlg. Supt. 10/2~/78 DATE DATE See Instructions On Reverse Side Form No. P-4 REV. 3-1-70 ~?""~\ SUBMIT IN DUPLICATE ,'~? STATE OF ALASKA · ; OIL AND GAS CONSERVATION cOMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. WELL WELL OTHER 2. NAME OF OPERATOR UNION OIL CO. OF CALIFORNIA 3. ADDRESS OF OPERATOR P.O. BOX 6247, ANCHORAGE, ALASKA 4. LOCATION OF WELL 5. APl NUMERICAL CODE [ 50-133-20064 6. LEASE DESIGNATION AND ,SERIAL 8. ~IT FARM OR LEASE NAME TRADING BAY STATE 9. WELL NO. 10. FIELD AND POOL, OR WI~DCA,~' TRADING BAY -'i 1609' N& 57l'W from SE corner of sec · ;~. ~T~ !F~l?~?.,.~,~M 11. SEC. T.R.M.(BO,OMH~E?:; -OBJECTIVE, SEC. 4 ~ TgN: R13~: S.H. ,, ~' '~ ~;; 12. PE~IT NO. 67-76 13. RE~RT TOTAL DE~H AT END OF MOTH, cHANGES IN HOL~S~~. CAS~G,~D.~EME~TING,~9~UDING SET AND VOL~ES USED, PERFO~TIONS, T~TS AND R~ULT~~~L]~ ~O~V~It~C~ED HOLE ~D ~Y OTHER SIGNIFICA~ CHANGES IN HOLE CONDITIONS. ... 9/26/78 7073' TD Co~enced operations 00'0] hrs. 9/26/78. Hoved c~g over 6503' ETD (BP) A-J0 and RU. Pulled gas lift valves fcom S.S. Displaced ]3 3/8"0]095' annulus w/~.0, fluid. BUllheaded ~00 bbls'of ~.0. Fluid 9 5/8"07055' down S.S. and 50 bb]s down L.S. der cut S.S. at 4186' 15' above tc~ple pkc at 420]'. Installed back press. ~a]ve removed tree, installed and tested BOPE. ~e]] started taking fluid Jn L.S. and flowing Jn S.S. . . 9/27/78 9/28/78 7073' TD Spotted 100 bbls W.O. fluid w/20 PPB safe seal out L.S. 6503' ETD(BP) & 50 bbls out S.S. Well was taking' 20 bbl fluid per hr., 13 3/8"@1095' giving up gas, oil cut mud. PUlled gaslift valves from 9 5/8"@7055' L.S. 7073, TD Perf'd long string from 5295' to 5297' Circ. Well dead 6503' ETD thru long string. POH. & L.D. Short S~ring. Pulled long 13 3/8"@1095' string loose. Circ. & cond. to 78 PCF. 9 5/8"@7055' 4 9/29/78 7073' TD POOH & L.D. 3 1/2" L.S. left 800' of L.S. & dip tube in 6503' ETD hole. Ran I.B., showed top 2 7/8" fish @4769. RIH & 13 3/8"@1095' engage fish w/ 3 1/4" grapPle . POOH. No rec. Redressed 9 5/8"@7055' grapple, RIH & engaged fish w/ 3 1/4" grapple. Ran dialog free point W.L.~'Tools wouldn't enter fish. Ran W.L. Scale cutter & cut scale to 4840'. . 9/30/78 7073' TD Ran 2 1/4" W.L. Swedge to 4951'. POOH. Left swedge @ 6503' ETD 4951'. Ran 2 1/4" tbg. cutter & stuck tools. Ran W.L. 13 3/8"@1095' over shot,& rec. cutter. Ran 2 1/8" cutter & cut 2 7/8" 9 5/8"@7055' @4945'. POOH & rec. 4 its. 2 7/8" tbg. RIH w/ 1 1/2" grapple. Engage 1 1/2" string & POOH. Rec. Tele-scopic its. from ~ ~0~2". &siderec. strinc).2 ,] tg 2R~8~'B'~ tb.q.. & onf°uod"t°p~2~7/8'"~, u. KeKan ~ . ~!sh& found@4983' . 14. lhe~eb¥~!fy~,at~~_'n~ttueandcortect top 2 7/8" 04997. --- __ TITLEDISTRICT DRII I.ING SIIPT. DATE SIGN~~' ~. r~~a~a_~ 1 O/17/7R Noqll~--Fleport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and Oas conservation committee by the 15th of the succeedino month,unless otherwise directed. Form No. P-4 REV. 3-1-70 SUBMIT IN DUPLICATE STA'T "' O F ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1o - WELL WELL OTHER 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR P.O. BOX 6247, ANCHORAGE, ALASKA 99502 4, T9N, R13W, S.M 5. AP1 NUMERICAL CODE 50-133-20099 6. LEASE DESIGNATION AND SER'IA-L'I~tO; ADL 18731 ?.I~ INDI~N'~LOTT~ OR TRIB~ 8.~IT FARM OR LEASE NAME T~DING BAY STATE 9. WELL NO. TBS ~-14 10. FIELD AND POOL, OR WIL~A~ 11. SEC. T. R. M. (BOSOM ~OLE OBJECTIVE) 4. LOCATION OF WELL 1601' N & 570' W from SE corner of Sec. Sec. 4,T9N,R13W, S.M. 12. PERMIT NO. 68-27 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND cEMENTING JOBS INCLUDING DEPTH q TDAND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 10 ll 9/1/78 9/2/78 8070' TD 6300' ETD 13 3/8"@1097' 9 5/8I'07180I 7"Liner @7071 ' - 8068' Killled well after acid work w/80 PCF CACL?. POOH w/ Baker WaSh Tool. Ran Baker Model "D" Prod. Packer & Set @4890' for "C" Zone completiOn. Ran 3 1/2" Prod. Tubing. Packer failed to test. POOH w/3 1/2" Prod. Tbg. 8070' TD Ran Baker Model F-1 Prod. Packer & set @4860' WLM. 6300' ETD Reran 3 1/2" Prod. Tbg. & located on packer @4860! WLM. 13 3/8"@1097' Removed BOPE & installed X-mas tree & tested to 5000 9 5/8"@7180' psi - OK. Displaced well w/ F.I.W. Put well on Production. 7"Liner @7071' Released rig @12:00 P.M. 9/2/78. - 8068' Production Test: (Flowing WEll) Gross Net Cut Choke FM. Gas Tbg/Csg. Press. 370 286 22.7% 17/64 91 MCF/D 590/575 14. I hereby ~ify that theJ~reg~li~g is t/ul~and correct T,TLE DZST, CT SOPT. ' N~port on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Union Oil and Gas Division: Western Region Union Oil Company" ;ifornia P.O. Box 6247, Anchu,'age, Alaska 99502 Telephone: (907) 276-7600 union August 9, 1978 Mr. Hoyle Hamilton Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99510 Dear Mr. Hamilton' Transmitted for approval and information are the following duplicates of State forms that were not received 'in your offi.ce via our transmittal of July 26, 1978' · TBUS G-12RD-2 Completion Report Subsequent Abandonment Sundry Notice TBS A-14 Sundry Noti ce II II II II II II Sincerely yourS, Jim'R. Cal Dist. Drlg. Supt. 131~i$ioo Form 10-403 /~7~-..~ Submit "Intentions" in Triplicate ~ REV. 1-10-73 ~ ' & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) Oil 17-I GAS r-1 WELL~:.J WELL'' OTHER NAME OF OPERATOR Union 0il Co. of California ADDRESS OF OPERATOR P. O. Box 6247, Anchorage, AK 99502 4, LOCATION OF WELL At surface 1609'N & 571'W from SE cdr of Sec. 4, T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 1C)l'ET ahnvo MSI -' Check Appropriate Box To Indicate Nature of Notice, Re APl NUMERICAL CODE 50-133'-20064 6. LEASE DESIGNATION AND SERIAL NO. ADL 18731 7, IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Tradinn Ray ~atP 9. WEI~NO~ " TRS A-10 10. FIELD AND POOL, OR WILDCAT ~ .. ,,r,,"D" & "E" sand TrnHinn ,,av - ,.~ ].1. REC., T., 1~., M.."(BOTTOM ~'IOLE OBJECTIVE) Sec. 4: T9N, R'i3W, S,H. 12. PERMIT NO. 67-76 3orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF E~ PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) ~ ~)~low SUBSEQUENT REPORT OF= 'WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTER lNG CAS lNG SHOOTING OR AClDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. To acid/solvent wash all "C", of 5% HCL and 7% solvent. PROCEDURE' · 2. 3. 4. 5. 6. 7. 8. "D" and "E" Zone perforations in TBS A-10 wit~a mixture £C£1v D Move rig over A-10 and rig up. Remove tree, install and test BOPE. Pull and lay down existing dual 3-1/2" production equipment. Clean out to ETD with bit and scraper. D:vision of Oil and Gas Anchorage Acid/solvent wash all "C", "D" and "E" perforations with 5% HCL and 7% solvent. Run dual 3 1/2" production equipment. Remove BOPE, install and test tree. Put well on gas lift production, producing from "C" and "D/E" sands. ESTIMATED STARTING DATE' October l l, 1978 ESTIMATED OPERATING TIME' 16 days I hereby c~jtify that the foregoing is true and correct - ////~/~//_~_ ~'~~_. Dist .....[~;lg. Supt SI~NE~ ,. - / y_ TI L~ ,, '~ 4' ~ / ' / Olin ~ua I lender f-~ ~<.~-~.~ ¢Z-~,~;,:/.~/~ (This ~ace for State office u~) / CONDITION~ O~PROVAL. IF AN~: .~ See Instructions On Reverse Side DATE 7/25/78 Form D-1001 UNION OIL CO. OF CALIFORNIA RE:PA I R RECORD PAGE NO. I Fi' Y LEASE Tra(_t'.zng Bay State W~ELL NO A'10_WOcoNTRACTOR WODEC0 __FIELD "-T~a-Jing Ba~ Fi~-f~,, /~/r£ ~j/~35 TYPE UNIT_-~~-860'Electric. BEGS: 7/5~73 COMPLETED: 7/21/73 ELEVATIONS: GROUND PERMIT NO. 67-76 SERIAL NO.~L - 18731 CASING H~A~-repor~. COMPActlY ENGinEER ~ l~at ;on-Wester TUBING HEAD APPROVED ~~ '~ ~ ~ ROTARY DRIVE BUSHING ~ '%~. K. "Caiiem.er CASING & TUBING RECORD ....................... ., 8IZr- DEPTH WEIC. HT GRADE ,, Rr. MARK$ 13 3/8" 1095' 61# J-55 Cmt'd to surface .w/ 1200 sx. class "G" cement. 9 5/8" 7053' 40 & 43.5# J-55 & N8) DV. collar at 5349'. Cmt'd w/ 750 sx. class "G" w/ 1% CF.~ 1st stage and 250 sx. class "G" w/ 1% CFR2 2nd stage. 3 1/2" Dual 9.2# N-80 See attaChed detail. ' PERFORATING RECORD --~-~-~-- INTERV--AL E.T.D. nEASON PnESEIqT CONDITION . See att!ached sheet. ~' See attached sheet. · · .. · ~ · . / - . : . ., · · INITIAL DATZ I ' .INTERVAt. HET OIL CUT GRAV. C.P. T.P. CHOKE MCF ...GOR ..R. EMAR. Kll 721/75 Long String 706 40.0% 28.7 980 80 - . .... · Short String 606 .2% 26.9 985 75 - - - '/22/73 Long String 1036 16.1% 25.6 1040 ~ 80 - 4 3 Short String 564 1.2% 27.3 994 85 ' - 88 156 · · .... _ ......... , -. WELL HIS.TORY PRIOR TO REPAIR LAST COMPLETION NO. #3 COMPLETION DATE: _..8_/13/70 ' . PRODUCING :NTERVAL: C-D-lq Zones INITIAL PRODUCTION; 1950 BOPD ............................................................................... LAST REGULAR PROD. & DATE:, 1250 BOPD 6/30/70 CUMULATIVE PRODUCTION:. 3,698;366bbls. .. REASON FOR REPAIR: _To _T_¢CO_mplete¢s .a _dual producer. PAGE NO. 2 PERFORATING RECORD INTERVAL ETD RFASON PRESENT CONDITION 1/3/68 1/4/68 1/6/68 3/20/68 3/21/68 3/23/68 3/24/68 :3/25/68 7/28/70 7/16/73 6919-6904 6760-6840 '6600-6'740 5330-5350 4148,4168 3840-3860 4240-4241 4262-4288 4516-4554 4398-445O 4498-4514 4572-4592 4668-4695 4766-4864 5012-5050 5325-5358 5552-5592 5684-5712 5787-5858 5900-5954 5985-6020 6050-6088 6100-6150 6160-6245 4266-4284 4320-4550 4402-4450 4500-4510 4574-4592 4672-4694 4834-4862 5096-S100 5124-5132 ,.5244-5249 5538-5354 5554-5590 5684-5712 5790-5854 5900-5954 6002-6012 6040-6130 6222-6240 6274-6296 6320-6352 4795-4834 5870-5880 5900-5954 6320-6352 6275-6296 6984 6875 67'50 '6525 6525 II Il 6503 'l l h Il I! DST #1 DST #2 Production Test Test Blk. Sqz. Production · . : .. Il II Squeezed. Squeezed. Bridge plug at 6503' "D" Zone - open for 3roduction. Squeezed. Squeezed. Squeezed. "C" Zone - open for produCtion. ti II t! 11 tl II ti Il Il - Il 11 11 Il ti - "D" Zone - open for production. Squeezed. "D" Zone - open for production. !1 I1 II If Squeezed · tt. Reperf:, "of, "C": Zone:open for" prod.: II !1 II -II II I1 II II 11 I1 I1 Il II I1 11 il II I1 il 11 II · I1 II !I Il ' ti II Reperf. of "IY' Zone-open for prod. II !1 II II 11 ti Squeezed. Reperf. of."D" Zone-open for prod. It ti ~ It ti "E" Zone - open for production. Reperf. "C" Zone - open for prod. Reperf. "D" Zone - open for prod. II I1 11 Reperf. '~" Zone - open for prod. OCT AF,'.CHORAG~ Form D-IOOI-B union Oil CO. Of CALIFORNIA · REPAIR RECORD SHEET B PAGE NO LEASE Trading Bay State COMPLETION DATE: 7/21/73. " DATEI I E.T.D. TYPE: Cameron & Shaffer WELL NO.A-10WO FIELD Trading Bay Field , APPROVED DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS _. -,,:':~L.i:,, i-: OIL AND GAS .. '' '.'r' ,'""~ ' -.".- WELL HEAD ASSEMBLY CASING HEAD: Shaffer Model KD 12". Series 900 CASING HANGER: Shaffer 12" Nominal 9 5/8" Monel' KDKS CASING SPOOL: ~TUBING HEAD: 12" 3000# X10" 5000# DCB Cameron TUBING HANGER: 'Dual DC-B 10" 5000# x 3 1/2" x 5. 1/2" Buttress btm. x 8rd top w/ 1 1/2" BV control ports. TUBING HEAD TOP: 10" 5000# (d~ml 3 1/2"] MASTER VALVES: Dual master dual swab 3 1/8" bore Cameron Type "F" Gate. CHRISTMAS TREE TOP CONN.: 3 1/2" AP1 8rd both strings. U llOit OIL'CCt?? h' 'CF CALIFOI :IAPAC, F: ih, 4 _ t',ELL t C0l LE~E , Tt,,~ding Bay State'.. _ I,£LL ^-10 . FIELD _Trading Bay field 7/5/73 7/6/.7.3 7/'7/73 7/8/7.3 7/9/73 7/10/73 ..DF_TAILS OF OPEFCNTI_OIiS, DESCRIPTiOi~S~,.° RESUL' T°o 7070'TD 6$05'ETD (junk) (Footage 0') Commenced operations at 1.2: 01 am, 7/5/75. ~kidded rig over wel~ :' Fished wireline out of tubing above ball valve. Retrieved ball valve and blanding plug' in both strings. Pulled gas lift valves and closed sleeves in long and short string tubing. Started displacing ,well between packers w/ 72# invermul and circ. to surface indicating that both hydraulic packers were not set. Pulled short string free from top packer at 4195'. t~d excess drag due to tubing being wrapped. Unable to pull up on long string w/o lifting short string. Pooh w/ short string. Tied into long string and unable 'to 'Pull free. Ran free point, enable to get through "XO" sleeve at S605'. Long string tubing free to S603'. Lower dual packer set at S641 '. 7070'TD · 6503'PBTD 7070'TD 6503 'PBTD (Footage 0') Reran short string tubing and tied into upper dual packer at 4195'. Ran tubing cutter and cut short string at 5611' (30' above lower dual packer at 5641'). Ran tubing cutter in long string-unable to get below 5400,. Cut long string tubing at 5592'. Pulled packer up hole approximately 12" and hung-up. Unable to move packer or tubing beyond this point. Checked long string tubing and collar locator indicated seperation in .cut at 5392' Checked short string tubing-no seperation indicated at 5611'. Recut short ~tring tubing at 5616'-still unable to moVe packer w/ long string tubing. (Footage 0') Ran tubing cutter and cut long string at 4169' (2'4' above upper dual packer). Ran jars and overshot dressed with 3 1/2" grapple, on 5"' drill .pipe.. Latched onto top of fish at 4169' and jarred free. Pooh w/ overshot. Upper dual packer had parted in packing element area leaving bottom 25" of packer in hole'. Long string parted 16" below top qf packer body parting Pt. and short string had pulled out of 10rd x-over collar 24" below packer bottom. 1 Set of upper hydraulic slips (8'" x 4" x 1 1/2") had wedged along side of packer and ~s fouling bottom portion body and mandrels (top o.f .fish Ipacker] at 2400 ,). 7070'TD 6503 'PBTD 7070'TD 6503 'PBTD 7070'TD 6503 ' PBTD (Footage 0') Ran tapered tap w/ 2 1/2" blunt nose, unable to jar packer down off of wedging slip. Ran 8 3/8" OD flat bottom .mill and milled 15" down on packer body to.within 1" of long string mandrel. Got indication of packer moving dram hole. Ran 8 3/8" burn-over shoe to move packer down over long string mandrel. Burned over 7" and packer released. Pushed packer body 17" and fouled at 4204 '. · P~oh w/ 8 3/8" burn-over shoe Recovered all of packer in shoe excepting bottom 2" guage ring and (1) sli~ segment and supbort plate. Ran S S/8" OD over shot dressed w/ 3 1/2" grapple to catch long string mandrel.. No recovery. .Ran 8 1/8" magnet to 4203.81. Pooh. No recovery. Ran 3 1/2" spear.- . . (Footage 0') Ran 3 1/2" spear to catch bottom guage ring of upper dual packer. Tagged up on top of fish at 4204'. Rotated spear 90° and moved down hole 2 1/2' w/ spear-had indication of being through guage ring. Pooh. No recovery. Ran 8 1/8" OD impression block and 'tagged top of fish at 4204'. Pooh. Had impression of 4 1/4" OD box up. (top of short string swivel telescoping joint). Ran 7 5/8" overshot w/ 4 1/4" grapple-unable to catch top of short string fish at 4204'. Pooh. Top of fish had passed through mill control but would not enter grapple. Reran 7 S/8" overshot w/ 4 1/2" grapple. Latched onto short string fish at 4204'. Pulled 200M and tubing pulled free. Pooh and laid down short string. Recovery-1422' of 5 1/2" tubing and accessories. Tubing brad parted in lower cut made at S616'WIA.I, 5608' tubing measurement. Picked up 7 5/8" overshot w/ 5 1/2" grapple to catch 5 1/2" 1201' cut off section of long string on' top of dual packer at 5641'. Estimated top to be at 4440'. (Footage 0') Ran 7 5/8" overshot w/ 5 1/2" grapple. Latched onto top' of long string fish at 4422'. Pooh w/ cut-off section of long string. Recovered 41 its. and cut piece of 5 1/2" tubing-Note: Found blast hole in tubing at 4768' opposite top of C-7 sand perforations. Ran 2 5/8" tubing stinger on drill pipe and washed down to top of bottom dual packer at 5641'. Circ. top of packer clean. ,Pooh. Ran 7 5/8" overshot and latched onto top of long string fish at 5592'. Had indicatio~ Of I~acker shear-out on 1st pull Uhable to jar dual packer at 5641' free. ~g~ ~J_~i~e,,~ ~.~;':~ -ran free point tool-unable to get below 5542' due tph~an-d ~rx~lg~ ~n ~[~n~ blade mechaniCal back-off and picked up tubing l~'~chec~ed san~ri~~O' high. OCT ! ,..,'3 },ELL tiCOIS LEASE _ Trnd~ng ]~y ,~tnte I,,;EII t'O, A- O FIELD_ Trading B~¥ Field 7111173 7/12/73 7/13i7: 7114/73 7/15/73 DETAILS OF OPEP~TiO[!S, DESCRIPTIOi!S 8RESULTS_ 7070'TD .CFootage 0') Pooh w/ long string fish,-recovered 10.63' ~ut jt. plus 7 j'ts. 6505'PBTD ~'5 1/2" tubing and 1/2 of "XO" sleeve at S605'. (XO" 'sleeve had backed off in 5605 'Top upper thread.) Ran 7 5/8" OVershot w/ 4 1/4" grapple-caught top of long Fish. string at S605', unable to jar fish (overshot stripped off fish). Pooh. Ran S 5/8" OD overshot w/ 4 1/4" grapple and alighment extention. Latched onto top of long string fish at 5605' and jarred 2 hrs. w/o success. RU wireline unit and ran 1 1/2" OD free point tool. Unable to get wireline free point below S665'. Long string tubing 100% .free 24' below bottom dual packer set at S641'. 'Laid down fishing jars. Ran 2 5/8" OD tubing cutter, unable to get through 'D(O" sleeve at S606'. Ran 2" OD tubing cutter, unable to get below S606'. Ran 2 1/2" OD wireline Swedging tool. Swedged through '9(O" at S606', unable to get below top of dual packer at S641'. ~070'TD 6503 ' PBTD 5669 'Top LS Fish. 7070'TD 6503' 7070 'TD 6503 'PBTD 7070'TD 6503 'PBTD (Footage 0') Ran 2 1./8" OD tubing cutter. GOt through "XO"' sleeve at 5605' ok-unable to get ,below top of dual packer at 5640'. Ran 1 1/2" OD tubing puncher-gun stopped at 5765'. Shot 4 - 1/4" holes/ft, from 5710' to 5714'. Rigged up to circ.-unable to break circ. with 2500 psi. Ran 600 · grain primer cord shot and fired 1 jr. below packer at 5675'-unable to move packer. Ran 2000 .grain primer cord shot and fired at 5675'. Picked and slacked off-packer came free. Pooh to BOP's w/ packer. Picked up BOPE and removed junk from top of packer (upper packer slips-gu,ge ring in 2 pieces etc.).. Short string collet was not in packer and indications were that short string had not been in-packer for long period. Recovered all of bottom dual packer w/tubing stubs above and 23.40' shot off joint below packer in long string. Ran 7 5/8" OD overshot with 3 1/2" hollow mill control and 3 1/2" grapple. Tagged top of long string fish at 5669'. Milled off top of shot tubing and engaged fish· Jarred on fish'unable to pull free from permenaht packer at 6258'. .. (Footage 0') Unable to get into top of fish w/ free point at 5669'. Made mechanical backoff. Recovered 7 its. of 3 1/2" tubing and shot joint, total recovery 209.,1,3'. Top long string fish at 5878'. Cleaned out along the side of 3 1/2 tubing long string w/ 2 3/8'" tubing stinger to top of permanent packer at 6258', Ran 7 5/8" x 3 1/2" overshot. Caught fish at 5878'. Jarred and pulled to 100,000# over string weight. Recovered remainder of fish, 13 its. of 3 1/2". tubing "XO" sleeve, seal assembly, "Q" nipple. Total recovery 386.97', Sand blast indicated on tubing at 6171'. Tubing ~caled badly. . (Footage 0') Ran ~ hole w/ 8" magnet to top of permanent packer at 6258' .- Recovered mill cuttings, and tobing slivers. Ran Tri-State packer picker. Stabbed into permanent packer w/ mandrel. Burned .over and recovered packer. RIH w/ 8 1/2" bit and scraper. Found junk, assumed to be half of ring from hydraulic packer. Pushed junk .and half ring to 6496'. Circ. hole clean. Ran junk basket-guage ring. Recovered packer rubber. · _ (Footage 0') Ran 9 S/8" Howco EZSV bridge, plug on Go-Inernational line set at 6030'DIL. Displaced 10 lin. ft. sand to 6020' thru open end drill pipe-on top of EZSV. Pooh w/ drill pipe. Ran 9 S/8" Howco EZSV cement retainer on Go-International line set at-S970'DIL. St.abbed into retainer for squeeze breakdown at 10 cu. ft~/minute at 2600 psi. Pulled out of retainer, displaced 200 cu. ft. 12-10 mud acid to retainer. Stabbed into retainer and injected acid at S cu. ft. /minute rate at 1500 psi. Annulus pressured to SO0 psi prio to acid injection. Communications around retainer at 5970' indicated. Pulle out of retainer w/ acid across 55-7 Sand. Mixed 150 sx. of class "~" cement w/ 1% CFR2 to a 117# cu. 'ft. slurry, displaced to retainer. Stabbed into retainer and squeezed to a gradual pressure build-up of SO00 psi w/ 185 cu. ft. of cement below retainer w/ approximately 160 cu. ft. cement outside of 9 5/8" casing. Pulled out of retainer w/ 5000 psi leaving 45 cu. ft. cement on top of retainer. Communication around retainer at 5970' stopped after 10 cu. ft._ cement squeezed. Pulled 850' drill pipe. Reversed drill pipe and Pooh. b,hde up 8 1/2" bit and ran in hole to SS84'. Circ. and cond. AFDC, HORAGE t, ELL iLCOl L /L E Trading ,Bay state Trading Bay Field 7/16/73 7/17/73 7/18/73 '7/19/73 7/22/~ 7/2 7070'TD 6494 ' ETD (junk) 6503 'PBTD 7070'TD 6494 ' ETD (junk). 6503 'PBTD 7070'TD 6494 'ETD (junk) 6503 ' PBTD 7070'TD 6494 ' ETD 6503 ' PBTD 7070'TD 6494 ' ETD 6503 ' PBTD 7070'TD 6494 'ETD 6503' PBTD 7070'TD 6494 ' 6503 'PBTD 7070'TD 6494'ETD 6503'PBTI) D~TAILS OF OPEPATiOilS, DESCRIPTIOi!S g RESULTS . (Footage 0') Circ. and cond. invermul'to lower weight. ~Found top of cement at 5842'. Drilled hard cement from 5842' to cement retainer at .5970'. Drilled cement retainer and hard cement from 5970' to sand on lower retainer at 6020'. Cleaned out sand from 6020' to 6030'.- Pushed junk from retainers to 6494' (ETD). Rigged up Go-International. Reperf. w/ 28 gram glass jets w/ 4 I~F the '%" Zone from 6275' to 6296' and from 6320' to 6352', the '~" Zone 54-9 sand from 5900' to-5954' "D" Zone 54-5 Sand from 5870' to 5880' "C" Zone C-7 Sand from 4795' to 4834'- (Footage 0') Ran 8 t/2" bit and 9 5/8" csg. scraper to ETD at 6494'. circ._ bottoms up. Laid down and off loaded heavywall drill pipe and collars. Ran 8 1/4" junk pusher on Go-International line followed by a single. 3 1/2" x 9 5/8" permanent packer set at 5640'DIL. (Footage 0') Made up 2 7/8,, long tubing ~tringw/ 1 1/2" dip tube w/ two Camco mandrels and Otis permanent packer seal assembly w/ 'W' nipple and tapered guide shoe on bottom, plug triple Otis hydraulic 3 1/2" x 3 1/2" x 1 1/2" packer. And 3 1/2" dual tubing strings w/ Otis "CX" mandrels. Ran tubing string to Otis 3 1/2" x 9 5/8" permanent.packer at 5640'. Pressured tubing.to test permanent 'packer and circ. at 300 psi. Set 'W' below permanent packer seals w/ slick line. Pressured tubing to 1500 psi held ok. Tested indicated tubing and seals stabbed into packer. ... (Footage 0') Ran collar locator thru tubing-verified'not stabbed into single permanent packer, at 5648', tubing depth. Worked tt~ing approximately 2 hrs. to work turn on bottom to relocate position of mule shoe guide. Stabbed into 3 1/2" x 9 5/8" permanent packer w/ seal assembly and tested ok. b~de up and tested bail valve lines. Mmded tubing in Cameron tubing head on dual DCB hangers. Installed Cameron dual block x-mas tree. Dropped bali in short string. Set and tested Otis triple hydraulic packer w/ shear' sub at 4200', tubing depth. Opened XA sleeve in long tubing string at 5615'. Displaced invermul w/ diesel down long string, from annulus below hydraulic packer and short string. Opened CXmandrel at 4134' in. short string and displaced invermul w/ diesel down short tubing string and' out annulus above hydraulic packer at 4200'. (Footag? 0')'Riggedup slick line unit. Closed "XA" sleeve in long string at 5615'). Installed ball valves and gas lift valves in long and short stFing. Put well on gas lift. .. (Footage 0') Continued to deactivate rig. 12 hr. test - long StTing. ~0SS NET 'CUT '" GLR GRAVITY TBG/CSG. 1176 706 40.0%-'88~' 28.~'° 80/980 20 hr. test -.short string. ~ROSS 'NET CUT GI~R GRAVITY -607 ~-06 0.2% 184'8 ....... -26.9~ TBG/CSG. 75/985 (Footage 0') Continued to deactivate rig. 20 hr. test -_...short string. FM. GRoss-'NE~ CUT GLR GOR GAS Gr~IVITY ~586' 57f 2.5%'~ 19'3'0' 55' 20 ' 2'6.'8° ' TBG/CSG. 807'9'82 4 hr. test - long string. FM. ~0SS' NET cur GLR GOR GAS ~2~'4 835 33.'0% '817 1i'6' '97 GRAVITY TBG/CSG. ~ 28.'5°'' 10079'95 _8 .hr. tes.t' -.lo.rig string. GROSS NET CUT (;LR 1233 1056 16.0'%""745 12. hr. test - short string, l~i. GROSS NET CUT GLR GOR GAS GRAVITY TBG/CSG. 5'7i ....5-64- 1.2%"-21'37' '1'56 88 2"7.3" 85'/994' GOR GAS GRAVITY '-Ui !. ' " 3 4" ' 25'.'6° . O ,LIFO , ,l[llOII OIL'CCt bF" '" ',ELL RECOIl] ~E Trad_ing Bay State I, ELL kg, ^-io wo FIELD Trading Bay Field I I DETAILS OF QPERATiO[IS, DESCRiPTIOi~S & RgSULTS -.. DESCRIPTION TUBING DETAIL LONG STRING JTS' LENGTtt BOTTOM[ TOP 2 7/8" Mule Shoe Guide 2 7/8" Otis "N" Nipple 2.205"ID I'Io-60 2 1/2" NU 10rd Pup Jr. Otis Seal Assembly-3.25"OD Otis Locator Sub X-over 2 7/8" Butt. x 2 7/8"EUE 2 7/8" 6.4# N-80 Buttress Tbg. 1 2 7/8" Or'is "XA" SleeVe=2.S15"ID 2 7/8" 6.4# N-80 Buttress Tbg. 1 2 7/8" Camco-K~HG ~,~ndrel 2 7/8" 6.4# N-80 Buttress Tbg. 25 2 7/8" 6.4# N-80 Buttress Pup Jr. 2 7/8" Camco KBMG Mandrel 2 7/8" 6.4# N-80 Buttress Tbg. 1 X-over 2 7/8,' Butt. x 5 1/2" Butt. 3 1/2" 9.2# N-80 Buttress Tbg'. 1 Baker Blast Jt.-4 1/2" OD Baker Blast Jr.=4 1/2" OD- S 1/2" 9.2# N-80 Buttress Pup Jr. 3 1/2" 9.2# N-80 Buttress Tubing & S Pup Jts. 17 X-over 3 1/2" Butt.-5 1/2', EUE Otis 9 S/8" Triple R~i packer X-over 5 1/2"EUE-3 1/2" Butt. 3' 1/2" 9.2# N-80 Buttress Tbg. 3 3 1/2" 9.2# N-80 Buttress Pup Jt. 3 1/2" Otis "CX" b,~mdrel 3 1/2" 9.2# N-80 Buttress Tbg. 13 3 1/2" Otis "CX" b-~mdrel 3 1/2" 9.2# N-80 Buttress Tbg. .23 3 1/2" Otis "CX" b'~ndrel 3 1/2"-9.2# N-80 Buttress Tbg. 25 3 1/2" Otis "CX" b~ndrel 3 1/2" 9.2# N-80 Buttress Tbg. 63 $ 1/2" 9.2# N-80 Buttress Pup Jt. 3 1/2" Otis ~pple 3 1/2" 9.2# N-~ess Tbg. 8 Cameron Tubing Hanger Landed Below Zero .8o 1.14 6.50 12.10 1.15 -. .54 31.43 3.35 31.28 7.81 715.98 4.15 7.81 31.23 .70 28.40 20.03 20.07 5.05 538.92 .45 8.20 1.20 8.9.10 5.10 5.75 404.64 5.75 717.96 5.75 781.19 5.75 1881.35 10.05 4.20 24S.16 x 1.00 37.00 5678.04 5677.24 5676.10 5669.60 5657.50 5656.35 5655.81 5624.38 5621.03 5589.75 5581.94 4865.96 4861.81 4854.00 4822.77 4822.07 4793.67 .4773.64' 4753.57 4748.52 4209.60 4209.15 4200.95 '4199.75 4110.65 4105.55 4099.80 3695.16 3689.41 2971.45 2965.70 2184.51 2178.76 297.41 287.36 37.00 -0- L~[: .... _Trading Bay State .- UNIOII OIL CO 'CF I, LL NO, A- O F ELD Trading< P, ay Field DF~TAILS OF OPEPATIO[i$, DESCRIPTIOj!S & RESULTS.. .TUBING DETAIL .- SIDRT STRING DESCRIPTION JTS. LENG~.I BOTTOH TOP 2 7/8" Otis Shear 'SuB 2 7/8'~ Otis '~q" Nipple 2.205"ID No Go Otis 9'5/8" Triple RTH Packer Otis Seal Extension X-over 2 7/8" Butt.-2 7/8'qEUE 2 7/8" 6.4# N-80 Buttress Tbg. 1 X-over 3 1/2" Butt.-2 7/8" Butt. 3,. 1/2" 9.2# N-80 Buttress Tbg. 3 1/2" Otis "CX" Mandrel · 3 1/2" 9.2# N-80 Buttress Tbg. 13 3 1/2" Otis "CX" b~ndrel 3 1/2" 9.2# N-80 Buttress Tbg. 23' 3 1/2" Otis "CX" b'hndrel 3 1/2" 9.2# N-80 Buttress Tbg. 25 3.'1/2" Otis "CX" b~mdrel 3 1/2" 9.2# N-80 Buttress 'Tbg. 63 3 1/2" Otis ~ Valve Nipple 3 1/2" 9.2# N--SU-Butt~ess Tbg. 9 3 1/2" 9.2# N-80 Buttress Pup Jt. 3 1/2" 9.2# N-80 Buttress Pup Jt. Cameron Tubing Hanger -- Landed Below Zero · SIDE STRING 'DESCRIPTION JT$. .45 4211.72 4211.27 1.65 9.20 '2.75 .60 $1.10 1.10 31.50 5.75 405.66 5.75 720.16 5.75 778..42 5.75 1898.88 4.20 259.75 4.10 2.20 '1.00 37.00 LENGTH BOTIDM 1 1/2" Bull Plug 1 1/2,' Camco KBMG Mandrel 1 1/2" NU 10rd Tbg. 1 1/2" Otis Telescoping. Jr. 1 1/2" Camco KBMG B~ndrel -. 1 1/2" N~J 10 rd Tbg. X-over 2 3/8"EUE- 1 1/2" NU 10 rd. 3 1/2" OD Blast Jt. X-over NU 10rd Pup Jt. 1 1/2" NU 10rd Tbg. 1 1/2" NU 10 rd Pup Jt. (Two) 1 1/2" Otis Telescoping Jr. '23 16 .50 7.81 716.40 3.69 7.81 63.39 .64 40.60 6.00 508.55 10.00 5.69 SS9i.25 0C7 !. ig3- Dp./!S~Ot'4 C,i': O~L, At, ID GAS Ai, qcHOP, AG~ 4209.62 4201.42 4198.67 4198.07 4166.97 4165.87 4134.37 4128.62 3722.96 3717.21 2997.05 2991.30 2212.88 2207.13. 308.25 4430 40.20 38.00 37.00 TOP 5589.75 5581.94 4865.54. 4861.85 4854.04 4790.65 4790.01 4749.41 4742.89 4234.34 4224.34 4220.65 I I I I I II I I I I II I I I[ I I IIII II I I i i .. · - i i~ i I II . · LONG STRING. / ' a e~.~ ~ '~ -- 2 '1.. 5 1/2" Otis Ball V lv 2. 3.1/2" Otis "CX" '~ndrel-2179 3. 3 1/2" Otis "CX" ~,~ndrel-2966' 4. 3 1/2" Otis '!CX'$~ndrel-3689' C $. 3 1/2" Otis "CX" ~'~ndrel-4100' --IL- 1095'-13 3/8" 61# J-55 Buttress ~. Triple Hydraulic pkr-4201' -- 7. 4 1/2" OD Blast Jts.-4754' ~ ~ Csg.-Cmt'd to surface· 8 2 7/8" Camco KBMG~ndrel-4854' D'77 9. 2 7/8" Camco K]3b~ b~mdrel-5582' 10. 2 7/8" Otis "XA" Sleeve-5621' 'i! ; ' ' 11 Locator Sub-5656 ' · ' 12. 3.35"0D Seal Assembly-5657" E ,__. 13 Otis Permanent pkr-5658'. ~ ~ ~_~~ ~.~~,.~'?.3. 14. 2 7/8" "N" Nipple-5657' 15. 2 7/8" b~le Shoe-5677' SHORT STRING i ' · · 'A. 3 1/2" Otis Ball Valve-304' H I I 'I B. 3 1/2" Otis "ex" Rmdr~l-2207' ] C 3 1/2" Otis "CX" ~hndrel-2991' · · i ' D. ~ 1/2" Otis·''CX'' ~ndrel-3717' _ ~ E. 3 1/2" Otis "CX" bkndrel-4129' III,, __ F. Triple ~draulic pkr-4201' G. 2 7/8" ~'N" Nipple-4210' . H. 2 7/8" Shear Sub-4211' SIDE STRING . , .' I. 1 1/2" Telescoping Jt.-4221' ' . :---- - " II. 3 1/4" OD Blast Jt.-4749' '~12 21j! " II. Camco KgiG Mandrel-4854 ' ffi ' IV. 1 1/2" Telescoping Jt.-4862'. V. Camco KB~,~ ~'~mdrel-5582'.~~~ .;~ 13 . I ' . .. · · ' ' ' ~ 6503' - Bridge Plug -2 ' ~ '7053' 9 5/8" 40# & 43.5# J-55 & ..... . '- N-80 Buttress Casing. · ~ ii i i LI J I I EY. DAli' D ~i. Wll CI~D. ! TRADING BAY STATE WELL A-10 ^"'~' DAlE , WELL' SCtI~IITIC , .... ..... UNION Oil COMPANY OF CALIFORNIA ..... ~' ' ! I I I i~ I I j iii I i III ' ii I FORM :'47 ('NEW 5/66) Form D-IOO1-A UNION OIL CO. Of CALIFORNIA SHEET A REPAIR RECORD PaGE NO. LEASE Trading. B_ay State W~ELLNO A'10WOcONTRACTOR WODF.:C0 FIELD T~a~ing Bay Fie!'d ~-~ ~/~5.5 TYPE UNIT_-Uil-~lq-ab0 Electric. ' .BEGS: 7/,5/75 COMPLETED: 7/21/7~ ELEVATIONS: GROUND p~{~r t~ nrev~u~ PERMIT NO. 67-76 __SERIAL NO. ~L - 18731 CASING H~A~-repor~. COMPAS;Y ENG~'EER ]Vat~;on-]?ester TUBING HEAD APPROVED ~~ '~ ~ ~ ROTARY DRIVE BUSHING ..... ~ i ~' IC~ilem'cx CASING & TUBING RECORD ......... 'I S~ ZE DEPTH WEIC"HT GRADE ............. REMARKS .13 3/8" 1095' 61# 3-55 Cmt'd to surface w/ 1200 sx. class "G" cement. 9 5/8" 7053' 40 & 43.5#i J-SS.& NS) DV collar at 5349'. Cmt'd w/ 750 sx. class "G" w/ 1% CFR2 1st stage and 250 sx. class "G" w/ 1% CFR2 2nd stage. 3 1/2" Dual 9.2# N-80 See attached detail. PERFORAT;NG RECORD DATE INTERVAL E.T,D, REASON --- PltESI~NT CONDITION " See at~:ached sheet. ~ See attached sheet. . · · , . 0!~ ~ 197'3 ,.' ANCHORAGE . . .. , , ., .......................... ,. ,, INITIAL PRODUCTIO: DATE [ · INTERVAL NET OIL CUT GRJ~V~- - C.P. T.P. CHOKE MCF GOR .... R.EMARI(S ............ . 7/21/73 Long String 706 40.0% 28.7 980 80 - .- - Short String 606 .2% 26.9 985 75 - - - 7/22/75 Long String 1036 16.1% 25.6 1040 80 - 4 5 Short String 564 1.2% 27.5 994 85 ' - 88 156 / . . . __W_ELL HIST.ORY PRIOR. TO ~EPAI~ LAST COMPLETION NO. COMPLETION DATE: _._8_/_13/70 PRODUCING 'NTERVAL: C-D-n -z0hes ................................. INITIAL PRODUCTION; 1950 BOPD LAST REGULAR PROD. & DATE: 1250 BOPD 6/30/70 CUMULATIVE PRODUCTION: ...... 5,698.; 566bbls - REASON FOR REPAIR: To recomplete as a dual producer _in t]!.e. Middle · · PAfZ NO. 2 PERFORATING ~RECORD DATE 1/3/68 1/4/68 1/6/68 3120/68 3/21/68 3/23/68 3/24168 3/25/68 I! · I! 7/28/70 7/16/73 INTERVAL 6919-6904 6760 -6840 6600-6?40 5330-5350 4148-4168 3840-3860 4240-4241 4262-4288 4316-4354 4398-4430 4498-4514 4572-4592 4668 -4693 4766-4864 5012-5050 5325-5358 5532-5592 5684-5712 5787-5838 5900-5954 5985-6020 6030-6088 6100-6130' 6160-6245 4266-4284 4320-4350 4402-4430 4500-4510 4574-4592 4672-4694 4834-4862 5096-5100 5124-5132. 3344-5249 5328-5354 55~4-5590 5684-5712 5790-5834 5900-5954 6002-6012- 6040-6130 6222-6240 6274-6296 6320-6352 4795-4834 5870-5880 5900-5954 6320-6352 6275-6296 ETD 6984 6875 67'50 '6525 6525 I1. 6503 REASON DST #1 DST #2 Production Test Test Blk. Sqz. Production . :. · · PRESENT CONDITION Squeezed. Squeezed. Bridge plug at 6503' "D" Zone - open for ~roduction. Squeezed. Squeezed. Squeezed. "12" Zone - open for production. 1! II ' 91 1' 11 11 91 II ,I Il t! I1 Il II 11 "D" Zone - open for production. Squeexed. "D', Zone - Open for producti°n. II II I! Reperf,"of; "C": Zone~open for' prod.: . . of "D" Zone-open for pr~. ~ueezed. Reperf. of "D" Zone'open for prod. "E'~ Zone - open for production. Reperf. "C" Zone - open for prod. Reperf. "D" Zone - open for prod. Reperf. '~" Zone - open for prod. I! 1! 9! ti II II II I! - I1 II 11 il I1 11 ' II Reperf. Form D- IOOi-B UNION OIL CO. Of CALIFORNIA 'REPAIR RECORD SHEET B PAGE NO. LEASE- Trading Bay State COMPLETION DATE:. 7/21/75. DATE E.T.D. 'TYPE: Cameron ~ Shaffer iWELL NO.A-10t'VO FIELD Trading Bay Field .~,~-~-' '~/~ APPROVED DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS D~V!E.!C'N OP OIL AND GAS AN,,CHORA, G~ WRLL I4RAD ASSEMBLY CASING HEAD: I.. Shaffer Model KD 12" Series 900 CASING HANGER: Shaffer 12" Nominal 9 5/8" Monel KDKS CASING SPOOL: TUBING HEAD: 12" 3000# X10" 5000# DCB Cameron TUBING HANGER- Dual DC-B 10" 5000# x 3 1/2" x 5. 1/2" Buttress btm. x 8rd top w/ 1 1/2" BV control ports. TUBING HEAl)TOP: 10" 5000# (d,~l 5 1/2") MASTER VALVES: Dual master dual swab 3 1/8" bore Cameron Type "F" Gate. CHRISTMAS TREE TOP CONN.: 3 1/2" API 8rd both strings. _ U llOil OIL ,ELL i,O, 4 LEA~["- Trading Bay State'._ A-10 FIELD Trading Bay field 7/5/7:5 7/6/.'73 7/7/7.3 7/8/73 , 7/9/73 7/10/73 PF~TAILS OF OP, EF~TiOIiS, DESCRIP_TIO~!S .& RF. SULTS, 7070'TD 6503 ' ETD (junk) (Footage 0') Commenced operations at 1-2:01 am, 7/5/75. ~kidded rig over wel= :' Fished wireline out of tubing above ball valve. Retrieved ball valve and blanding plug'in both strings. Pulled gas lift valves and closed sleeves in long and short string tubing. Started displacing .well between packers w/ 72# invermul and circ. to surface indicating that both hydraulic packers were not set. Pulled short string free from top packer at 4195'. t~d excess drag due to tubing being wrapped. Unable to pull up on long string w/o lifting short string. Pooh w/ short string. Tied into long string and unable to-pull free. Ran free point, anable to get through "XO" sleeve at 5605'. Long string tubing free to 5602'. Lower dual packer set at 5641 '. 7070'TD 6505 'PBTD (Footage 0') Reran short string tubing and tied into upper dual packer at 4195'. Ran tubing cutter and cut short string at 5611' (50' above lower dual packer at 5641'). Ran tubing cutter in long string-unable to get below 5400'. Cut long string tubing at 5592'. Pulled packer up hole approximately 12" and hung-up. Unable to move packer or tubing beyond this point. Checked long string tubing and collar locator indicated seperation in .cut at 5592' Checked short string tubing-no seperation indicated at 5611'. Recut short ;tring tubing at 5616'-still unable to moVe packer w/ long string tubing. 7070'TD 6505 '.PBTD (Footage 0') Ran tubing cutter and cut long string at 4169' (2'4' above upper dual packer). Ran jars and overshot dressed with 3 1/2" grapple, on 5"' drill pipe.. Latched onto top of fish at 4169' and jarred free. Pooh w/ overshot. Upper dual packer had parted in packing element area leaving bottom 25" of packer in hole'. Long string parted 16" below top qf packer body parting Pt. and short string had pulled out o~ 10rd x-over collar 24" below packer bottom. 1 Set of upper hydraulic slips (8'" x 4" x 1 1/2") had wedged along side of packer and was fouling bottom portion body and mandrels (top of fish .[packer] at 2400' ). 7070'TD (Footage 0') Ran tapered tap'w/ 2 1/2" blunt nose, unable to jar packer 6505'PBTD down off of wedging slip. Ran 8 3/$" OD fiat bottom mill and milled 1S" down on packer body to.within 1" of long string mandrel. Got indication of packer moving down hole. Ran 8 5/8" burn-over shoe to move packer down over long string mandrel. Burned ove,r 7" and packer released. Pushed packer body 17" and fouled at 4204'. Pooh w/ 8 5/8" burn-over shoe Recovered all of pack&r in shoe excepting bottom 2" guage ring and (1) sli3 segment and supbort plate. Ran 5 5/8" OD over shot dressed w/ 5 1/2" grapple to catch long string mandrel.. No recovery. .Ran 8 1/8" magnet to 4205.81. Pooh. No recovery. Ran 5 1/2" spear. 7070'TD (Footage 0') Ran 5 1/2" spear to catch bottom guage ring of upper dual 6505'PBTD packer. Tagged up on top of fish at 4204'. Rotated spear 90° and moved down hole 2 1/2' i~/ spea~-had indication of being through guage ring. Pooh. No recovery. Ran 8 1/8" OD impression block and tagged top of fish at 4204'. Pooh. Had impression of 4 1/4" OD box up. (top of short string swivel telescoping joint). Ran 7 5/8" overshot w/ 4 1/4" grapple-unable to catch top of short string fish at 4204'. Pooh. Top of fish had passed through mill control but would not enter grapple. Reran 7 5/8" overshot w/ 4 1/2" grapple. Latched onto short string fish at 4204'. Pulled 200M and tubing pulled free. Pooh and laid down short string. Recovery-1422' of 3 1/2" tubing and accessories. Tubing had parted in lower cut made at 5616'WI$'I, 5608' tubing measurement. Picked up 7 5/8" overshot w/ 5 1/2" grapple to catch 5 1/2" 1201' cut off section of long string on' top of dual packer at 5641'. Estimated top to be at 4440'. 7070'TD (Footage 0') Ran 7 5/8" overshot w/ 5 1/2" grapple. Latched onto top' of 6S05'PBTD long string fish at 4422'. Pooh w/ cut-off section of long string. Recovered 41 its. and cut piece of 5 1/2" tubing-Note: Found blast hole in tubing at 4768' opposite top of C-7 sand perforations. Ran 2 3/8" tubing stinger on drill pipe and washed down to top of bottom dual packer at 5641'. Circ. top of packer clean. ,Pooh. Ran 7 5/8" overshot and latched onto top I [ of long string fish at 5392'. }-lad indication of packer shear-out on 1st pull Uhable to jar dual packer at 5641' free. Rigged un ~.r~l. in~ji~-¢r,~ free ' ' point tool-unable to get below 5542' due to s~ ~i~e"~~b~l i~Made · ~nechanical back-off and picked up tubing 10'-d~k~d sand br~g,e~ high. UiilUtl UIL LH ,t'i'dl¥ " },ELL t COIS - LEASE DATE 7/11/73 7/12/73 7/14/73 7/15/73 ·. ;, ELL 'hg, A-ZoFIELD Trading Bay 'Field ...]DETAILS OF OP.ER/NTIO[~S, D[~SCRIPTIO~!S:& RESULTS. 7070'TD .(Footage 0') Pooh w/ long string fish,-recovered 10.63' dut it. plus 7 j'ts. 6505'PBTD ~'3 1/2" tubing and 1/2 of "XO" sleeve at 5603'. (XO"-sleeve had backed off in 5605'Top upper thread.) Ran 7 5/8" Overshot w/ 4 1/4" grapple-caught top of long Fish. string at 5603', unable to jar fish (overshot stripped off fish). Pooh. Ran 5 5/8" OD overshot w/ 4 1/4" grapple and alighment extention. Latched onto top of long string fish at 5605' and jarred 2 hrs. w/o success. RU wireline unit and ran 1 1/2" OD free point tool. Unable to get wireline free point below 5665' Long string tubing 100% free 24' below bottom dual packer set at 564i". Laid down fishing jars. Ran 2 5/8" OD tubing cutter., unable to get through '~(0" sleeve at 5606'. Ran 2" OD tubing cutter, unable to get below 5606'. Ran 2 1/2" OD wireline swedging tool. Swedged through '9(0" at 5606', 'unable to get below top of dual Packer at 5641'. ~070'TD 6503'PBTD 5669'Top LS Fish. 7070'TD 6503' 7070 'TI) 6503 ' PBTD 7070'TD 6503 ' PBTD (Footage 0') Ran 2 !/8" OD tubing cutter. Got through "XO"' sleeve at 5605' ok-unable to get,below top of dual packer at 5640'. Ran 1 1/2" OD tubing puncher-gun stopped at 5765'. Shot 4 - 1/4" holes/ft, from 5710' to 5714'. Rigged up to circ.-unable to break circ. with 2500 psi. Ran 600 .grain primer cord shot and fired 1 jt. below packer at 5675'-unable to move packer. Ran 2000.grain primer cord shot and fired at 5675'. Picked and slacked off-packer came free. Pooh to BOP's w/ packer. Picked up BOPE and removed junk from top of packer (upper packer slips-guage ring in 2 pieces etc.). Short string collet was not in packer and indications were that short string had not been in-packer for long period. Recovered all of bottom dual packerw/tubing stubs above and 23.40' shot off joint below packer in long string. Ran 7 5/8" OD overshot with 3 1/2" hollow mill control and 5 1/2" grapple. Tagged top of long string fish at 5669'. b211ed off top of shot tubing and engaged fish. Jarred on fish-unable to pull free from permenaht packer at 6258'. (Footage 0') Unable to get into top of fish w/ free point at 5669'. Hade mechanical backoff. Recovered 7 jts. of 5 1/2" tubing and shot joint, total recovery 209.13'. Top long string fish at 5878'. Cleaned out along the side of 5 1/2" tubing long string w/ 2 3/8" tubing stinger to top of .permanent packer at 6258', Ran 7 5/8" x 3 1/2" overshot. Caught fish at 5878'. Jarred and pulled to 100,000# over string weight. Recovered reminder of fish, 13 its. of 3 1/2". tubing "XO" sleeve, seal assembly, "Q" nipple. Total recovery 386.97'. Sand blast indicated on tubing at 6171'. Tubing ~caled badly. . (Footage 0') Ran in hole w/ 8" magnet to top of permanent packer at 6258'. Recovered mill cuttings and tQbing slivers. Ran Tri-State packer picker. Stabbed into permanent packer w/ mandrel. Burned over and recovered packer. RIH w/ 8 1/2" bit and scraper. Found junk, assumed to be half of ring from hydraulic packer. Pushed junk and half ring to 6496'. Circ. hole clean.- Ran junk basket-guage ring. Recovered packer rubber. i . (Footage 0') Ran 9 S/8" Howco EZSV bridge, plug on Go-Inernational line set at 6050'DIL. Displaced 10 lin. ft. sand to 6020' thru open end drill pipe-on top of EZSV. Pooh w/ drill pipe. Ran 9 5/8" Howco EZSV cement retainer on Go-International line set at' S970'DIL. Stabbed into retainer for squeeze breakdown at 10 cu. ft;/minute at 2600 psi. Pulled out of retainer, displaced 200 cu. ft. 12-10 mud acid to retainer. Stabbed into retainer and injected acid at S cu. ft. /minute rate at 1S00 psi. Annulus pressured to SO0 psi pric to acid injection. Communications around retainer at 5970' indicated. Pulle out of retainer w/ acid across SS-7 Sand. Mixed 150 sx. of class "G" cement w/ 1% CFR2 to a 117# cu. ft. slurry, displaced to retainer. Stabbed into retainer and squeezed to a gradual pressure build-up of SO00 psi w/ 185 cu. ft. of cement below retainer w/ approxim.,ately 160 cu. ft. cement outside of 9 S/8" casing. Pulled out of retainer w/ 5000 psi leaving 45 cu. ft. cement on top of retainer. Communication around retainer at 5970' stopped after 10 cu. ft. cement squeezed. Pulled 850' drill pipe. Reversed drill pipe and Pooh. Made up 8 1/2" bit and ran in hole to S584'. Circ. and cond. mud.. -. f'AC~L:, i&l, u · },ELL t COI D Tradin.$ Bay ,State. _ ELI I,,O, ^-:1o FIELD Tra,.d.ing, ?ay Field DF~TAILS OF OPEp, ATiOII$, DESCRIPTIOi!S o _ c, RESULTS 7/16/73 7070'TD (Footage 0') Circ. and cond. invermul .to lower weight. :Found top of cement 6494'ETD ;: at 5842'. Drilled hard cement from 5842' to cement retainer at .5970'. (junk) Drilled cement retainer and hard cement from 5970' to sand on lower retainer 6503'PBTD at 6020'. Cleaned out sand from 6020' to 6030'.. Pushed junk from retainers to 6494' (ETD). Rigged up Go-International..Reperf. w/ 28 gram glass jets w/ 4 tE~F the "E" Zone from 6275' to 6296' and from 6520' to 6352', the "D" Zone 54-9 Sand from 5900' to-5954', "D" Zone 54-5 Sand from 5870' to 5880', "C" Zone C-7 Sand from 4795' to 4834'; 7/17/73 7070'TD 6494 'ETD (junk). 6503 'PBTD 7/18/73 7070'TD 6494 ' ETD 6503 ' PBTD 7/19/73 7070'TD 6494 ' ETD 6503 ' PBTD (Footage 0') 'Ran 8 5/2" bit and 9 5/8" csg. scr.aper to ETD at 6494'. Circ.- bottom up. Laid down and off loaded heavy wail drill pipe and collars. Ran 8 1/4" junk pusher on Go-International line followed by a single. 3 1/2" x 9 5/8" permanent packer set at 5640'DIL. (Footage 0') Made up 2 7/8" long tubing ~tring w~ 1 1/2" dip tube w/ two Camco mandrels and Otis permanent packer seal assembly w/ '~q" nipple and tapered guide shoe on bottom, plug' triple Otis hydraulic 3 1/2" x 3 1/2" x "1 1/2" packer. And 3 1/2" dual tubing strings w/ Otis "CX" mandrels. Ran tubing string to Otis 3 1/2" x 9 5/8" permanent packer at 5640'. Pressured tubing .to test permanent packer and circ. at 300 psi. Set '~" below permanent packer seals w/ slick line. Pressured tubing to 1500 psi held ok. Tested indicated tubing and seals stabbed into packer. (Footage 0 ') Ran collar locator thru tubing-verified'not stabbed into single permanent packer, at 5648', tubing depth. Worked tubing approximately 2 hrs. to work turn on bottom to relocate position of mule shoe guide, Stabbed into 3 1/2" x 9 5/8" permanent packer w/ seal assembly and testod ok. Made up and tested ball valve lines. Landed tubing in Cameron tubing head on dual DCB hangers. Installed Cameron dual block x-mas tree. Dropped bali in short string. Set and tested Otis triple hydraulic packer w/ shear' sub at 4200', tubing depth. Opened XA sleeve in long tubing string at 5615'. Displaced invermul w/ diesel do~ long string, from annulus below hydraulic packer and short string. Opened CX mandrel at 4134' in. short string and displaced invermul w/ diesel down short tubing String and' out annulus above hydraulic packer at 4200'. 7/20/75 7070'TD 6494 ' ETD 6505 ' PBTD 7070'TD 6494 ' ETD 6503'PBTD (Footage 0') Rigged up slick line unit. Closed "XA" sleeve in long string at 5615'). Installed ball valves and gas lift valves in long and short string. Put well on gas lift. (Footage 0') Continued to deNctivate rig. 12 hr. test - long s.~ring. GR~SS "NET' ' CUT ' GLR GRAVITY TBG/CSG. 11'76 ' 7'06 ~"0.0%' ' 885 28.7° 80/980' 20 hr. test -,short string. P~ROSS "NET ' CUr GLR GRAVITY -607- -B-06 0.2% 184'8' 2'6'.9~ TBG/CSG. 75/985 7/ 7070'TD 6494 ' ETD 6505 ' PBTD (Footage 0') Continued to deactivate rig. 20 hr. test - short string. FM. GROSS "NET - CUT GLR GOR C~qS GI[IVITY TBG/CSG. ~586 ' "~'71 2.5% 19'50 55 '2'0' "'2'6.8°" 80/982 4 hr. test - long string. FM. i3ROSS "NET' ~ 'Gi~R' GOR GAS i244' 855 33.'0% 8'17 ._ 11'6' '~'7 GRAVITY TBG/CSG. 28.5° 100/9~5 7070'TD 6494 ' ETD ' 6505 ' PBTD 12 hr. test - short_ .string. FM. GROSS' -' NET - C[~r GLR GOR GAS -'--5'71 564 ...... 1.2% '2'157' ~'56 88 8 hr. test - long string. GROSS 'NET ClYF ' GLR" GOR -i'235' 1036 "i6.0% 745 3 GRAVITY 2'7.3'° GAS GRAVITY 4 .... 25.6° OIL' RECOI .... I..E~E _Trad_ing Bay State FIELD Trading Bay Field pETAI kS_OF OPER&TIO[ ~S, DESCR I PT I Oi !S ..g RESULTS DESCRIPTION TUBING DETAIL ., LONG STRING JTS. LENG~t BOTrOH TOP 2 7/8" ~hle Shoe Guide 2 7/8" Otis "N" Nipple 2.20S"ID t'Io-60 2 1/2" NU 10rd Pup Jr. Otis Seal Assembly-5.2S"OD Otis Locator Sub X-over 2 7/8" Butt. x 2 ?/8"EUE 2 7/8" 6.4# N-80 Buttress Tbg. 1 2 7/8, Otis"XA" Sleege~2.31S"ID 2 7/8" 6.4# N-80 Buttress Tbg. 1 2 7/8" Camco-tq~HG b,~ndrel 2 7/8" 6.4# N-80 Buttress Tbg. 25 2 7/8" 6.4# N-80 Buttress Pup Jr. 2 7/8" Camco KB~4G Mandrel 2 7/8" 6.4# N-80 Buttress Tbg. 1 X-over 2 ?/8" Butt. x 5 1/2" Butt. 3 1/2" 9.2# N-80 Buttress Tbg: 1 Baker Blast Jr.-4 1/2" OD Baker Blast Jr.:4 1/2" OD- 5 1/2" 9.2# N-80 Buttress Pup Jr. 5 1/2" 9.2# N-80 Buttress Tubing ~ 5 Pup Jts. 17 X-over 5 1/2" Butt.-3 1/2" EUE Otis 9 5/8" Triple R~-{ packer X-over 5 1/2"EUE-5 1/2" Butt. 3-1/2" 9.2# N-80 Buttress Tbg. 5 5 1/2" 9.2# N-80 Buttress Pup Jr. 5 1/2" Otis "CX" ~,hndrel 3 1/2" 9.2# N-80 Buttress Tbg. 13 5 1/2,' Otis "CX" b~hndrel 3 1/2" 9.2# N-80 Buttress Tbg. .25 $ 1/2" Otis "CX" Mandrel 3 1/2" 9.2# N-80 Buttress Tbg. 25 3 1/2" Otis "CX" bl~ndrel 3 1/2" 9.2# N-80 But%ress Tbg.- 63 3 1/2" 9.2# N-80 Buttress Pup Jr. 3 1/2" Otis Ball Valve Nipple 3 1/2" 9.2# N-80 Buttress Tbg. 8 Cameron Tubing Hanger Landed Below Zero .80 5678.04 5677.24 1.14 6.50 12.10 1.15 · . .54 31.45 3.55 31.28 7.81 715.98 4.15 7.81 31.23 .70 28.40 20.03 20.07 5.05 558.92 .45 8.20 1.20 89.10 5.10 5.75 404.64 5.75 717.96 5.75 781.19 5.75 1881.55 10.05 4.20 245.16 1.00 37.00 5676.10 5669.60 5657.50 5656.55 5655.81 5624.58 5621.05 5589.75 5581.94 4865.96 4861.81' 4854.00 4822.77 4822.07 4795.67 .4773.64' 4753.57 4748.52 4209.60 4209.15 4200.95 4199.75 4110.65 4105.55 4099.80 5695.16 5689.41 2971,45 2184.51 2178.76- 297.41 287.36 238.16 58.00 37.00 -0- · · ? LEAS[-_' _ ffra,din~ Bay. State OIL ~,ELL RLCOI~ PAGE I,;ELL hg, ^-~.o wo FIELD Tradinl7 Bay Field '1 I DF._TAILS OF OPE. P, ATiOIiS,. DESCRIP_TI~!S.& RF. SULTS. · lllBING DETAIL S}DRT STRING ' DESCRIPTION JTS. LENtil]I BOTTOH TOP 2 7/8" Otis Shear 'SuB 2 7/8" Otis '~q" Nipple 2.205"ID No Go Otis 9 5/8" Triple RTH Packer Otis Seal Extension X-over 2 7/8" Butt.-2 7/8"EUE 2 7/8" 6.4# N-80 Buttress Tbg. 1 X-over 3 1/2" Butt.-2 7/8" Butt'. 3 1/2" 9.2# N-80 Buttress Tbg. 3 1/2" Otis "CX" b~andrel .3 1/2" 9.2# N-80 Buttress Tbg. 15 3 1/2" Otis "CX" b~ndrel 3 1/2" 9.2# N-80 Buttress Tbg. 23' 3 1/2" Otis "CX" bbndrel 3 1/2" 9.2# N-80 Buttress Tbg. 25 3 1/2" Otis "CX" k~mdrel 3 1/2" 9.2# N-80 Buttress Tbg. 65 3 1/2" Otis Ball Valve Nipple 3 1/2" 9.2# N-80 Buttress Tbg. 9 3 1/2" 9.2# N-80 Buttress Pup Jr.. 3 '1/2" 9.2# N-80 Buttress Pup Jr. Cameron Tubing Hanger "~ Landed Below Zero .45 4211.72 4211.27 1.65 9.20 '2.75 .60 $1.10 1.10 31.50 5.75 405.66 5.75 720.16 5.75 778 ..42 5.75 1898.88 4.20 259.75 4.10 2.20 1.00 37.00 SIDE STRING 'DESCRIPTION LENGI~t BOTrOH 4209.62 4201.42 4198.67 4198.07 4166.97 4165.87 4134.37 4128.62 3722.96 3717.21 2997.05 2991.50 2212.88 2207.15 308.25 304.05 4450 40.20 38. O0 '37.00 '0- TOP 1 1/2" Bull Plug 1 172" Camco KBMG Mandrel 1 1/2" NU 10rd Tbg. 1 1/2" Otis Telescoping. Jr. 1 '1/2" Camco KBMG b~ndrel · 1 1/2" NIJ 10 rd Tbg. X-over 2 3/8"EUE- 1 1/2" NU 10 rd. 5 1/2" OD Blast Jr. X-over NU 10rd Pup Jr. 1 1/2" NU 10rd Tbg. 1 1/2" NU 10 rd Pup Jt. (Two) 1 1/2" Otis Telescoping 'Jt. 23 16 .50 7.81 716.40 3.69 7.81 63.39 .64 40.60 6.00 508.55 10.00 3.69 559i.25 5589.75 5581.94 4865.54 4861.85 4854.04 4790.65 4790.01 4749.41 4742.89 4234.54 4224.34 4220.65 I I I I I II II [ II I I I I I II I I I IIII !I I I i i il ii ii i i i . I ^--- -- I i . LONG STRING I ~_. t - -- 2 , '1. 3 1/2" Otis Ball Valve-283' 'B"'-- --" 2. 3~1/2'' Otis "CX" 'b'~ndrel-2179i ~ I 3. '3 1/2,, Otis "CX" ~landrel-2966, 4. 3 1/2" Otis ':CX'~andrel-3689' C 7;, .'7 3~ S. 3 1/2" Otis "CX" bt~ndrel-4100' --'° -- ~ 1095'-13 3/8" 61#'J-55 Buttress B. Triple Hydraulic pkr-4201' -' i --- 7. '4 1/2" OD Blast Jts.-4754' I Csg.-Cmt'd to surface· 8. 2 7/8" Camco KBMG ~ndrel-4854 ' ~ D i,-7~ 77 4 9. 2 7/8" Camco KB~ bbndrel-SS82' :~ · 10. 2 7/8" Otis "XA" Sleeve-5621' ~ · 11. Locator Sub-5656' · 12. 3.35"OD Seal Assembly-S657" E ;7 ~[ 5 13. Otis Permanent pkr-56.58' i[ 14 2 7/8" "N" Nipple-5657' ' i' ' 15 2 7/8" ~h~le Shoe-S677' F~ Hi ~ ~ SHORT STRING _. 6 ~ : .: . A. 3 1/2"Otis BallValve-304' HG~]"'I [.-'mS .... " " " t · B. 5 1/2" Otis "CX" ~mdr~l-2207' 7i ... .' ' C. 3 1/2" Otis "CX" ~kndrel-2991' ~ . I .. ... D. ~ 1/2" Otis "CX" ~kndrel-3717' _ E 3 1/2" Otis "CX" ~andrel-4129' ~ III __i ~ · ~ [ ' . -- . F. Triple }~draulic pkr-4201' IV ~ .'. G. 2 7/8" ~,N,, Nipple-4210, H. 2 7/8" Shear Sub-4211' ~1 '. . · · ... SIDE STRING - .. · ' V'-~--- c~ · " I. 1 1/2" Telescoping Jt.-4221' :~'-- . .. " V. Camco KBS~ ~mdrel-5582 ' '.~~:m.~ 13 [. . . · '. · . 6503' - Bridge Plug -' ' 7053' - 9 S/8" 40# ~ 43.S# J-SS -'~ '" N-80 Buttress Casing. '~EV. D~T~ " ' ' ' ' ' ' ' ' ' ' ' " D~AW~- C~D.~ ..... ~ · " TRADING BAY STATE WELL A-10 A.'~. ~ ' DATE ..... WELL S(~tEbiiTIC ' .... · ,, , _ ............... COMPANY ...... UNION OIL O~ CALIFORNIA ............ " SHEEI$ I ii ii 11 ' ' ' I ii ill I I ii iii i 1111 i FORM 247 (NEW 5166) Union Oil and Gas/'%sion· Western Region Union Oil Company oT California 909 W. 9th Avenue, Anchorage, Alaska 99501 Telephone: (907) 279-7681 union ~eptember 6, 1975 Mr. K. VonderAhe Petroleum Engineer Division of Oil & Gas 5001 Porcupine Drive Anchorage, Alaska 99S04 TBS A-10 (24-4) MONTHLY REPORT P-5 8/6/73 ' C(]vIP~TION REPORT'P-4 8/7/73. Bar ~. Von~r~e: ~closed please f~d.t~ corrected ¢~ies of t~ ~ove c~tioned State Reports ~r ~i~Bay Sta:e A-10. ~ t~ly yours, ~mR. Callender ~strict Drill~g S~t. JRC/sk ~Enclosures (2) Form REV. 9-30-6 9 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE O'F ALASKA OIL AND GAS CONSERVATIO. N: COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APP~LICATION 'FOR ~R~i'f-~' 'for such 'p~o~osal-~J 1. WIrLL WELL 5, AP1 NU1VIFA~C~ CODE 6. LEASE DESIGNATION AND SERIAL NO, 7. IF IN'DIA~, A.L~O'I"I']~E OR TRIBE NAME OTHER 2. NAME OF OPERATOR 8. UNIT, FAH2~I OR LE~SE NAME 3. ADDRESS OF OPERATOR 9. WIlL NO. 10. FIELD ~ POOL, OR WILDCAT 4. LOCATION OF W~LL At surface 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 13. ELEVATIONS (Show whether DF, RT, GR, etc. 12. PEP,3/IT NO. 14. Check Appropriate B~x To I~ndicate Nature of N~tice, Re~ort, or Other Data ' NOTICE OF INTENTION TO: I TEST WATER SHUT-OFF ____Jj FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OB ALTER CASINO MULTIPLE COMPLETE ABANDON* CHANOE PLANS Other) SUBSEQUENT R~PORT OF: WATER SHUT-OFF REPAIRING WELL FRACTURE TREATMENT ALTERING CASINO SHOOTING OR ACIDIZINO ~ ABANDONMENT* (Other) (.NOTE: Report results of multiple completion on Well Corapletion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an}' proposed work. 6. Set permenant wireline packer at 5640' above "D" Zone. 7. Ran dual string 5 1/2" tubing and set dual packer at 4200' above "C" Zone. 8. Displaced invermul in tubing and annulus w/ diesel. 9. Put well on gas lift and production tested. RIG RELEASED AT 12'00 MIDNITB, 7/51/73. 16. I hereby certif2~hat the foregoing is true and correct Di_qt: r}r!.g, St~t, D*~E 9/6/75 ,,, (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Form REV. 9-30~ 9 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE O'F ALASKA OIL AND GAS CONSERVATIO, N COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen use "APPLICATION 'FOR ~'ER-~iT-~' 'for such 'p~o~osal-~) 0IL ~ GAS ~-~ WELL WELL OTHER 2. NAME OF OPERATOR UNION 0IL COMPANY OF CALIFO~IA 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL At surface 1609'N & 571'W from the S. E. corner. Section 4: TgN, R15W, S. M. 13. ELEVATIONS (Show whether DF, RT, OR, etc. 14. 5. API NU1W_BRICAL CEDI*. 50-133-20064 6. LEA~E DESIGNATION AND SERIAL NO. ADL- 18731 7. IF INDIA/g, A/~O'r'r~E OR TRIBE NAME 8. UNIT, FAPdVI OR LEdkSE NAME Trading Bay State 9. VgELL NO. A-lO 10. ?t~LD A/~D POOL, OR WILDCAT Tradin~ Bay Field n. SEC., T., ~., M., f~OTTOM ~OL~. OBJECTIVE) Section 4' TEN, P13~V, S. M.. 12. PER.MIT NO. 67-76 Check Appropriate Box To I,nd',}cate Nature of NOtice, Re, }ort, or Other D~ta ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASINO FRACTURE TREAT MULTIPLle COMPI,ETE SHOOT 0a ACIDIZE ABANDON* REPAIR WELL CHANOE PLANS ~Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF REPAIRING WELL FRACTURE TREATMENT ALTERING CASINO SHOOTING OR ACIDIZING ABANDONMEN'Ts (Other) *See bel6w -- (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an)' proposed work. *Recompletion as a dual with the "D" _& '~" pools commingled in the long string and the "C" pool in the short string. 1. Moved over well. Displaced tubing and annulus w/ 72# invermul. 2. Fished tubing and packers out of hole. CO to ETD of 6S03'. $. Squeezed the "D" Zone 5S-7 Sand perforations from S98S' to 6020', thru retainer set at S970'. (1S0 sx. class "G" cement tO final pressure of . 5000 psi.) Drilled out retainer and squeeze cement. Reperforated as follows: "E" ZONE SAND INTERVAL 58-7 6520-6552 "D" ZONE SAND INTERVAL F4-z¥ 31tT1J:'g~O 54-9 5900-5954 "C" ZONE SAND INTERVAL ,/4 ~,m.,, No. v--~ STATE (...,, ,~L.ASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT II~ DUPLICA~ 0IL ~] GAB [~] WI~LL WELL OTHER $. APl NlJ~IERICAL CODE' ..g~-I ~-20064 6 LEASE DESIGNA'FION AND S~IAL NO. ABT.-1 g731 T. IF INDIA]~', ALOT~EE O1~ TRIBE NAME 2. NAME OF OP~TOR UNION OIL COMPANY OF CALIFORNIA. , , ~'.' ADDRESS OF OP]~:LATOi~ ' 909 West 9th Avenue~ ,Anchorage, Alaska 4. ~OCAT~OI~ OF WELL 1609'N & 571'W from:the S. g. corner. Section 4' T9N, R13W, S. M. 99501 8. L~IT. F.~R~/I OR LEASE NA.ME 9 WE~ Nd~ A-lo f24,-4) 10. F~ ~ND P~L. OR WILDCAT Trading.....Ba7 Field om~ SectSon 4' TgN, ~3W, S. M. 1~-, PEI~MIT NO. 67-76 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGF_~ IN HOLE SIZE' CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLU1VfES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE A2qD SIDE-TRACKED HOLE A.N'D ANY OTI~IER SIGNIFICANT CI-IANGE~ IN HOI~ CONDITIONS. Commenced operations at 12:01 am, 7/5/73. Moved over well. Displaced tubing and imnuluS w/ 72# invermul. ' FiSheR' thbin.g and packers out of hole. Cleaned out to ETD at 6503'. Squeezed the "D" Zone 55-7 Sa~,d, perforations from 5985' to 6020', thru retainer set at 59?0'. (150 sx. class 'G' cement to final pressure of 5000 psi). Drilled out retainer and squeeze cement. Cleaned out to 6494'DPM. Re- perforated as follows: "E" ZONE- SAND IFTFERVAL 58-7 6320-6352 "D" ZONE SAND INTERVAL FdnY 5Y70~ 54-9 5900-5954 "C" ZONE S.~qD IN~RVAL ~ 4~¥ Set permenant wireline packer at 5640' above "D" Zone. Ran dual str.~ng 5 1/2" tubing and set dual packer at 4200' abOve "C" Zone. Displaced invermul in tubing and annulus w/ diesel. Put well on gas lift and production tested. RIG RELEASED AT 12:00 MI~ITE, 7/31/73. 14. I he.by ~fy~t the f~eg~ NOTE:--Report on this form is required for -ea~ calsndar ~nth! regardless of the status of operations, end must ~ filed Jn duplicate wit~ the oil and gas conservation commtflee bjthe 15~ of the succ~ding mn~, unle~ Otherwise directed, ? ALASKA,, j c. GE~L STATE Oh suBMrr IN mmL, CATZ - OIL AND GAS CONSERVATION CO~I~EE_ .5fl,] 33020064 , ,,, m, , , MONTHLY REPORT O:F 'DRILLING ~ L~s~ ~ES:O~o~ ~x~'~, ~3,.ENG AND WORKOVER OPERATIONS ~ - ~8~3~ .......... ~EOL ..... ~ION OIL C~~ OF ~IFO~IA Trading Bay State j3 . 909 West 9th Avenue, ~chorage, Alaska 99501 A-10 (24-4) ..... I :~e" ! Trading Bay Field CONFEm ' 1609'N & S71'W from the S. E. co~er. 'n.s~c..~..~..~..(~o=~o~ Section 4' T9N, R13W, S.M. o~ .... Section: T9N, R13~', S.~4. 67-76 , , , ,,, follows: "E" ZONE SAND 58-7 "~' Zone SAND 54-9 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA~NGES IN HOLE SIZE. CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS. TESTS AND RESULTS FISHING JOt~ JLrNK I~ HOL~E AND SIDE-TI~ACKED HOLE A~D A24Y O~ SIGNIFICA2~T CI-IANGES IN HOI~ CONDITIONS. Commenced Operations at 12:01 am, 7/5/73. bloved over well. Disp.l..aced tubing and ~ulus W/ 7'2-~'-~nv-ermul. ' 'Fi's~ed tub'~ng" and packers out of hole.~ed out to' ETD at 6503 '. Squeezed the "D" Zone 55- 7.. Sand perforations from(' $~ to 602¢'., thru retainer set at 5970!. (150 sx. class "G'"~cement to final press~' 5000 r/s~). Drilled out retine~ and squeeze cement. Cleaned out to 6494'DPM. :eperforated as /. INTERVAL 6~20-6352.,' INTERVAL 5900r5954. "C" Zone SAND INTERVAL Set permenant w~rel~ne packer ~ set ~ g~cke~ ~t 4ZOO'. ~bov~~e, ~sg~ce~ ~/ d~esel, ~ut ~ll o~ ~S l~Et ~d p~od~ct~o~ teste~, RIG RELF~SED AT 12'00 MIDNITE, 7/31/73. ' OF 0It OAS OlVt~lc ANNcHORAGt 14.1 he~b, . t ~he ~o~~2~~ .~'' 8/7/73 ~'/~~~~ District ~lg. S~t. n~ SIG~ ...... -. ~ - ' - - . ~ ~ . . // J~ K_ t:a~ ~anq~y :~. NOTE--Rsporl o, Ibis form is rt~,irt4 for .~ch coltndor ~t~ r~gor~less of ~ s~,t,s of oper, tio,s. ,,~ m,s~ ~ filsd i, dupli¢ol~ ~ith ~he oil ~.d gas co.serv.tion ~ommiffae by the 15~ of lhe suoc~4iag ~n~. ~1~ Ofher~ise directed. Form P--3 ~ 81abmtt "Intentions" in Triplicate ~V. 9-~9 NS~ & "su~quent ~epo~s" m Dupli~te '_, '1. STATE OF A~KA , 5. AP1 N~C~ CODE OIL AND GAS CONSERVATION: CO:~l~EE ~0-1 ~020064 I~--~NG'~J". " ' SUNNY NOTIC'ES AND REPORTS ON WR~ J 4 ENa use "APPLICATION 'FOR ~iT~'' ~or such'p~o~osal~:) J 5 ENG J . . . . ,,, ~ION 0IL C~~ OF ~IF~IA. Trad~g Bay State ~~v'- 3. a~Dn~SS OF OP~*TOR 909 West 9th Avenue~ ~chorage, Alaska 99501 A-10 (.24-4) '~ s~c 4. ~OC~T~ON OF W~L 10. ~'~ ~D ~OOL, O~ W~C~ ~NFER~ ~,,.,-,~.~ Trad~ Bay Field mm - 1609'N 6 571'W from the S. E. comer, o~w) Section 4: TgN~ R15W~ S.M. Section: TgN, ~5~, S. - ,, 13. ELEVA'rI~NS (Show whether DF, RT, OR, et~.' ......... 67-76 Check Appropriate Box To [nd}cate Niat'ure o~ N~tice, Re, ~ort, or Other Data ' NOTICE OF INTENTIOI~ TO: TEST WATER SHUT-OFF SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ASANDONs CHANGE PLANS ~Other) SUREEQUENT REPORT OF: WATER SHUT-OFF REPAIRING WELL FRACTURE TREATMENT J [ ALTERING CASING sHoOTING o~ ACIDIZING L J ABANDONMEIffTS (Other) "See below, (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) !5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an)' proposed work. *Recompletion as a dual with the "D" & "E" pools comningled in the long string and the "C" pool in the short string. . t Moved over well. Displaced tubing and annulus w/ 72# invemul. Fished tubing and packers out of hole. CO to ETD of 6505'. Squeezed the "D" zone SS-7 Sand perforations from~g' to 6020', thru retainer set at 5970'. (150 sx. class "G" cement to,final pressure of SO00 psi). Drilled out retainer and squeezel ': cement. CO to Reperforated as follows: :: "E"~: Zone SAND INTERVAL |~\ uu · 'B 58'7 6320-6352 ~"""' DIVISION O~ OIL ANO OAS "D" Zone SAND INTERVAL ANC, HORAG~, S4-g 5gOO-Sg54 "C" Zone SAND ' INTERVAL (~h~ace lot ~a~e omce use~ APPROVED BI CONDITIONS OF APPROVAL, IF TITLE DATE See Instructions On Reverse Side Union Oil and Gas ["~;ion' Western Region Union Oil Company eT California 909 W. 9th Avenue, Anchorage, Alaska 995 Telephone: (907) 279-7681 ., union June 25, 1975 Mr. Homer Burrell Oil ~ Gas Division State of Alaska 5001 Porcupine Drive Anchorage, Alaska 99S04 TBS A-10 MONOPOD ' PI~TFORM Dear Mr. Burrell: Enclosed please find three (3) copies of the P-5 form, Cha~ge of Plans, for the above captioned well. District Drilling Supt. JRC/sk cl. (s) Form REV. 9-30-6 9 Smbrnit "Intentions" in Triplicate & "Sut:~equent Reports" in Duplicate STATE O,F ALASKA OIL AND GAS CONSERVATIO,N CO:MMI'F[EE SUNDRY NOTICES AND REPORTS ON W.ELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION'FOR f~'EPu%iiT--' 'for such 'pl:o~osal~j oI, p~ oas ~q WELL WELL OTHER 2. NA~IE OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPERATOR 909 ~eS:t 9th Avenue, Anchorage, Alaska 99501 4.LOCATION OF WELL At surface 1609'N ~ 571'W from SE corner. Section 4: TgN, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc. ,, r Check Appropriate Box To I,ndicate Niature of N~)ti'ce, Re 5. AP1 NUMEILICAL CODE 50-133020064 6. LF-~S~. DI~IGNATION ~ND SERI~kL NO, ADL- 18751 7. IF INDIA.N, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay State 9'A_W~b N°'(24.4) 10. FIELD AND FOOL, OR WILDCAT Trading Bay Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section: T9N, R13W, S. M. 12. PERM/T !~O. 67-76 ~ort, or Other Da~a ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLEABANDON~ COMPI,ETE CHANGE PLAN8 Other) I~UBSEQUENT REPORT OF: WATER SHUT-OFF -- REPAIRING WELL FRACTURE TREATMENT -- ALTERING CASING SHOOTING OR ACIDIZINO ABANDONMEN~T* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an}' proposed work. The purpose of this work is to squeeze off excessive water entry from 55-7 interval and recomplete Trading Bay State A-10 as a dual "C" and "D"-"E" producer. This well is presently a triple completion C5 packers and 2 tubing strings) in the "C", "D" and "E" pools of Fault Block 2A. Comnunication across the packer separating the "C" and "C" Pools has resulted in a loss in well production. It is proposed to recomplete the well as a dual with the "D" ~ "£" Pools comingled in the long string and the "C" Pool 'in the short string. PLAN OF PROCEDURE: Move over well. Change over to invermul. Install BPV's. Remove tree, install and test BOP. Pull dual tubing strings and both dual packers. Mill over and retrieve single permanent packer. Squeeze 55-7 sand to eliminate water entry. 4. [4' ...,~ 6. Clean out to ETD w/ bit and scraper. 7. Set permanent 5 1/2" x 9 5/8" paCker on wirelhe above ~e "D"-.'~" s~ds. 8. ~ d~l tub~g str~gs w/ dml hydra, lc 5 1/2" x 5 1/2" x 9 5/8" hydraulic packer set above "C" s~d. Form P~3 lq~V. 9-30-6 9 Smbmit "Intentions" in Triplicate & "Sub.~quent Reports" in Duplicate STATE O'F ALASKA OIL AND GAS CONSERVATION: CO,MMI'rI'EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or lo deepen use "APPLICATION'FOR [~'EFc[ViiT-L~' 'for such 'p~o~osalsj .... oI,~ g OAS [] WELL WELL OTHER Check Appropriate Box To Indicate Nmture of I~tic'e, Re 2. NAME OF OPEHATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF WF-J-~L At surface 13. ELEVATIONS (Show whether DF, ET, GE, etc. 14. 5. AP1 NUtVLERICAL CODE $0-13~-20064 6. I~E DESIGNATION A-ND SERIAL NO. ADL- 18711 7. IF IN'DIA/~, A/~LOTTEE OR TRIBE 8. UNIT, FAHAi OR I.,F_,ASE NAME Trading Bay State 9. WELL NO. A-10 (24-4) 10. FIELI~ ~ POOL, OR WILDCAT Trading Bay Field 11. SEC., T., R., M., (B(XrTOM HOLE OBJECTIVE) Section 4: T9N, R15W, S. M.. 12. PEt{MIT iN'O. 67-76 tort, Or Other D~ta ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANGE PLANS tother) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASINO SHOOTING OR ACIDIZINO ABANDONME~qT$ (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and gh, e pertinent dates, including estimated date of starting any proposed work. 10. 11. above dual packer. Install BPV's. Remove BOP's and install ,x-mas tree. Return well to production. 16. I hereby/~ify that the~f~reg.~ug is true and correct CONDITIONS OF XPPR0~A~, IF A~: ~ Dist. I)rlg; ,, Supt. TITLE ?I~LE (~llte£ Pet~,oleu~ Engineer See Instructions On Reverse Side June 25, 1973 DATE Af~proved Copy R~turn~Cl STATE OF A~KA %. API N~C~ CODE ~?"1' FN~--~ OIL AND GAS CONSERVATION,, COMMI~EE ., 50-133-200f4 ...... r--.T.~N~_~ SUNNY NOTICES AND REPORTS ON' W.~.j_._.~ (DO not u~e this form for proposa,s ~ drill or to de~,pen ADL-18731 .... use "Am¢~tCA~ION 'FOR CE~ri'~" ~or such 'p~obosax~.) ~. ~ ...... · · - - " ~ ] Cp~l 1. " ~. ~F I~X~, ~0~ OR TRiB~ N~' ~'~.F.~l . w,~ . cso~...1 Union 0il Co. of California Trading Bay State --j REV 909 West 9th Street A-10 (24-4) ~. LOCA~IO~ O~ ~ 10. ~ ~ ~OO~, O~ ~I~CA~ · ~'"~" Tradinq Bay Field ~(m" ii I ~ ~ " ' ' 1609'N & 571'W from SE cor. Sec 4, T9N, R13W, SM ,.s~c.,~.',~,~.,<~o~O~om~w> · .. Sec. 4, T9N, R13W, SM . 12. ~L~VATIONS (Sho~ <whether ~, ~, ~R, e%c. lg. ~ ~O. 67-76 Check Appropriate Box To )nd}cate Niat'ure of NOtice, Re~ort, or Other D~ta ' NOTICE OF INTENTION TO ~ TEST WATER SHUT-OFF PULL OR ALTER CASING TREAT MULTIPLE COMPI,ETE FRACTURE SHOOT OR ACIDIZE ABANDONS REPAIR WELL CHANGE PLANS t Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASINO SHOOTING OR ACIDIZINO ABANDONMEN'T· (Other) (NOTE: Report results of multiple completion on Well Corapletion or Recompletlon Report and Log form.) t5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly 'state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. ~ f,'~ .~.: ..: , The purpose o¢ this work is to recomplete ^-10 as a dual "6" and "D"-"E" producer.. This well is presently a triple completion (3 paCkers and 2 tubing strings) in the "C", "D" and "E" Pools of Fault Block 2A. Communication across the packer separating the "C" and "D" Pools has resulted in a loss in well production..It is proposed to recomplete the well as a dual with the "D" & "E" Pools comingled in the long string and the "C" Pool in the short string. PROCEDURE 1. Move over well. Change over to invermul. 2. Install BPV's. Remove tree, install and test BOP. 3, Pull dual tubing strings and both dual packers. 4. Mill over and retrieve single permanent packer. 5. Clean out to ETD w/bit and scraper. 6. Set permanent 3-1/2" X 9-5/8" pkr. on wireline above the "D"-"E" sands. 7. Run dual tubing strings w/dual hydraulic 3-1/2" X 3-1/2" X 9-5/8" hydraulic packer set above "C" sand. 8. Stab into lower packer and test. Set and test dual packer. Change over to diesel above dual packer. . 16. I hereby ce~that tile f~oip~ is .true and correct s,e.E~,./__--J~;i~~//1~.//a/Z~-~~TIT,,~ District Drlg Supt. DiTE 11-30-72 DE01 DIVISION CF OIL AND GAS ANCHORAGE APPROVED BY CONDITIONS OF ~'PPBOYAL, IF AI~ ~'~ See Instructions On Reverse Side Sabn~tt "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE O,F ALASKA OIL AND GAS CONSERVATION: coMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APP-LICATION 'FOR ~'ER~V~iT-Li' 'for such 'p~o~osalg~) 1, 0IL ~-~ GA8 WELL WELL [] 2. NAME OF OPERATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF WEJ~L At surface OTHER AP1 NUM.F. RICAL CODE, _Ell-1 LE,~SE DE,S,I-GNATI0~ -A.ND SE,RIAL NO. ADL-18731 ?. IF INDIAI~[, ALJ~OTTEE OR TRIBE NA-MJE 8. UNIT, FAP~ OR LEASE NAME Tradinq Bay State 9. WELL NO. A-10 (24-4) 10. FLELD AND POOL, OR WILDCAT Tradina B~v Fi~_ld il, SEC., T., ~.,'~., OBJECTIVE) Sec. 4, T9N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc. 12. PERMIT NO. 67-76 14. Check Appropriate Box To I,ndicate N, ature of N~tice, Re ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI,ETE ~X SHOOT OR ACIDIZE L~ ABANDON* REPAIR WELL CHANOE PLANI~! I Other) ...... I~UBBEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING 0R ACIDIZINO ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, includin~ estimated date of starting any proposed work. . .. Install BPV's. Remove BOP's 'and install xmas tree. Return well to production. Estimated Starting Date' December 8, 1972 DE[; 1 DIVISION CF OIL AND GAS ANCHORAGE 16. I hereby ~ that the for_e~oi~'~m true and correct District Drlg SUpt. 11-30-72 APPROVED BY ~ CONDITIONB Old'APPROVAL, IF : ~ See Instructions On Reverse Side DATE Approved Copy Returned ., -,,,-,~'.',:-'. '" '. /- V,/f:l L L ~COIRD Trading Bay State WELL No.A-10W~ft3 SPUD DATE 7/27/70 ....... o Bay CONTRACTOr. WODEC0 ,~OCA~iON_Conductor 8E corner of Section ~', PAGE NO.. 1 . ._ RIG NO. 56_ TYPE UNIT_ 0ilwell 860 Diesel Electric ~iELEVATiONS: \VATEI[ 1)E~I'H 62' . ~°"~MIT NO. 67-76 SERi,A_L' No. ADL 18731 ~T. TO OCEAN FLOOR 174' t'.,:,~ ~ R.T. TO MLLIV 112' 7073 ' T.V.D. ~iD, - . R, T. TO D~[LL DECK 22. 07' 2()~'IPAN ~ ENGINEER ' ~ CASING TUmNC~ ~ECOn~ ~ y/. 2s8 ]-'~Tzg' wsidri'q THREAD , GRADE ! DEPT~ 3-3/8'! 61~t ~ b~ttress J-55 ,~ . 1095 -9~5/8" ~0 ~"43.5~ buttress J-55, N-80 705: 3-1f2" 9.2# ...... buttress N-80 'short '-~. "." ', ' , ' _ ~'. !'0rig ~ ..... . · Cmtd to surface ~d in two stages ~ :ring set ~ring set--{-~ pkr @ 6258 PERFORATING RECORD _J original wel~ history) .(For ~ ~3168 I liT_~t V kI, erforations bel 3840-3860 21 ' 4148-41~8 ~23 - 4240 '-~28/~0' 4266-84 -~-320-50 4402-30 4500r10 457'4-92 4672-94 /28/7'0 5684-5712 5790-5834 .5870-5880. · 5900-5.954 /28/70 6274-96 ~.~ ,6. 32=,0-5~_ 2__ . ..... )w 6525 ,~see TS-~-' ..... 6503-r------ ii Il - II !1 Iii" DATE 7iW¥6 T1W]R IHTERVAL I NET OIL ~'& "D" ~1 ' commingled f t 4879 '[1.6% , Long S :ring '. ,,c,,-Zone' . SaO t Stri ,gJ'l ' WSO [ ---- --~-69-6~~rforation of Middle Kenai 51'24-32' "'' --'.'(,I ' " 5244~~ ~nal~ pelfs see original history 5328--55 Z'-- :- 5534'90 _J { "-- ' i . , 6002-6012?~Reperforation of bfiddle Kenai-"D" - 60~0~6~-~~ition~l perfs, see,or'igin~l hi'story 6222-%240 Overall interval 568~' '6243 , ~ production Middle Kenai "E" open for production-' INITIAL PHODUCTIO~I ! j_26.6o i 4-roT- 200# - 355# 107/64 11734 i 2,5', 357 flowing %676 ' f lo.w. ing WELL TYPE:' .Cam¢.r°n & Shelf ar CASING HEAD: shaffer Model KD 12" 'Series 900 CASING HANGER: Shaffer 12" Nominal 9-5/8'" Monel KOKS CASING SPOOL:__ TUBING 12" 3000# x 10" 5006# DCB Cameron ' !1 Il ' T R? · rUBtl~G IIANGER:Dual DC-B 10" 5000~t x 3-1/2" x J-l/2 buttress .btm x 8rd top with 1/2 BV control TUBING i!EAD TOP' 10" 5000~ (dual' 3-1/2") ports, Dual master dual swab 3-1/8" bor Cameron Type "F" Gate A~ASTER VALVES: T,',-v,~ 'TREE CONN.: 3.T_1/2" AP1 8rd both string, s C!{R,o ~ tvTAS TOP · . /::~i"i:::!-_-::i,i'..,, ;,-:'i:'~!:,:,',' .::';~!:-(,.' UNIO,N..~OIL CO, OF CALIFOP~IA SHEET B /'-: ~"':"/~':--' ":- :":-, '-- '.--.. ,,'"' -- MUD RECORD ' - ' PAGE NO. 2 ,EASE._=Traaing BaY.State .... '*"',. '-' WELL.NO'-A-10 WO¢3FiELD Trading Bay ~YPE _ _Invermul D~STRiBUTOR Baroid .- __~', DEPTH WEIGHTt ¥IS.~. ,.. W? ~... PI'I .... SALT OIL. SA~D .... SOLIDS REMARKS ~27' 5395" 76 59 Invert ~mu,lsion , ./ , Killed well~''' "' .,'"~ '~8~,~,95" 74 ' 64 ... "' "" ........ /29 5536~ .... 76 63 i, ..... ,, ................. --gO 6515' 76' 63. '" " ..... --' .... ' .... , --~31- 6515' '¢6 63 ' - ' " " '". "Ra~ tbg '- ...... . ' .................. ~1.- D~splac'~d w~th d~e~e]' for cCmpi~t~on .~l~d' .. - 2 D~splac,~d d~es~ ~ w/Ir~vermul '" ~ .~ -- . ............ 7~ff ' 6525"~' 76 -6~ Invermul, ._ 12 · - 5 .... 76..5 62 " ..... 12 ' . "- g 6503' ' ~76 60 " . ' " 12 ................... ' ....... - ............ ~ .... . ..... - ,,..' . ................ . '-' ~ , ...... - ~ , ..... ' ........... ............. , . . ~. - .... . . ~ .. ............. . , ....................' .... .... ..... . , . [ .... __ ~,. ~ ...... ' ...... .... . , ......................... . ............ ....................... ....... - ,, , .......... - . . .............. .... ~ . , ' - · . ....... ....... , . ......... ~. '' , .- ._ ....... . ~ , ~ ' .... .... - ,, ., , , ....... . ...... . ...................... .. . .... , ,,.. } ,,,. .......... .... ~ .......... .... ...... ............. , ..... - ,,, , .......... .......... .... ........... ..... , ....... ......... ~ . ,, ,. .. ,. , ~ , .......... ., . _ · ,. , - . .,, , , -- .... ...... .... . - ,, ,, , , , ..... ~ ~ , , . - ,,.. · . ........ ~ .... I ' ,,, , i. ,,~ ...... · . , ...... ~ .... , ........ .~ _ .. ~ ,,, , -.. , . , , ........I ~ ......... ... ~ . ......... [ - .... ........... . ..... ., -~ - , ,'.,' ...... t~_ '~' ........ ..... ~,, ,-, ' .... _'" ~ .... i .... ' .... , ...... ~ , ' ..... UNION OIL CO. OF CALIFORNIA SHEET D DRILLING RECORD ' PAGE NO. 3 · #3 LEASE_ Trading Bay State WELL NO. A, 10 WO ~IELD. Trad,ing Bay. DATE E.T.D. DETAILS OF OPERATIONS. DESCRIPTIONS & RESULTS 7/'27/70 28 29. 3O 31 8/l/7O 3~ 5395' 5395' 5536' 6515' 6515' 6260' Model "A" packer 6260' 6260' 6525' 6525' Moved rig from A-8 WO to A-10 WO #3 @ 12:00 am 7/27/70. O~ened "CX" mandrel w/wireline @ 4154'. Killed well w/76# Invermul. Installed B.P.V. & ND xmas tree. NU 12" S900 BOE.- Attempted to pull Baker F-1 single hydroset pkr free w/130~000#. Moved pkr approx 10' & stuck both ways. . · '- Attempted to run wireline shifting tool inside tbg to close "CX" @ 4154'. Unable to get below 3700'. Had paraffin on tool. Attempted to unseat packer by closing hydril & pressuring against formation to 800#. Still unable to move pkr w/130,000# pull. Ran shifting tool on Schlumberger line. Closed sleeve. Broke circ around pkr & worked pkr loose. Rmvd ball valve mandrel & control line. Corssed over to dp & ran to top of plug @ 5395'. Circ. out gas cut mud. RU to pull tbg. Pulled & 1.d. 132 its 2-7/8" tbg w/jewelry & a Baker F-1 pkr. Set Howco retrievable BP @ 3200'. Replaced 12 3000# x 10" 3000# tbg head w/ a 12" 3000# x 10" 5000# head. Tested BOE. Retrieved BP. CO fill from 5365' to top of BP @'5395'. Drld BP. Drld fill from 5425' to 5536'. Cont drlg fill .to top of BP @ 5634'. 'DRLD BP & chased to 6515'. Circ hole clean. Schlumberger perfd four 1/2" hpf with 4" & 3" carrier guns as indicated on sheet A (Reperf "C", Reperf "D" & perf "E"). Made bit & Scraper run to ETD @ 6515'. Reversed hole clean. POH &'RU Schlumberger. Made junk basket & gauge, ring run to 6300'. Set Guiberson Model "A" pkr on wireline @ 6260'.- Ran dual 3-1/2" tbg strings and landed w/Guiberson RH-2 pkrs @ 5643' & 4~195'.,- . . Landed tbg hangers in head w/B.P.V, in place. ND BOE & made up 10" 5000# dual 3-1/2" xmas tree. Tested w/5000#. Retrieved both B.P.V. & ball valve dummies. Attempted to open "XO" sleeve in long string @ 6233' w/o success. Disp down annulus and out short string w/diesel. Set pkrs off long string. Tested tbg w/1500# on annulus. Opened-sleeves in long string @ 5609', & 4158' to test top pkrs. Tested top pkr w/1500#. 'Attempted to test lower dual pkr thru "XO" in long string @ 5609'. Had communication between long and short string. Checked all sleeves in short string with wireline & found to be closed. Repressured short .string & still communicated with long string. Killed well with 77# Invermul and RU BOE. Pulled both strings tbg. Pkrs showed to have been set. RIH w/scraper to Model "Am' pkr. Reversed hole clean. POH. RI w/Howco RTTS tool. Set tool @ 5608', 5643' & 5668'. Pressd to 1800 psi each time. No communi- cation outside pipe between Middle Kenai "D" & "C" Zones. POH. RU & ran 12]. jts tbg, Completed, rng 3-1/2" dual tbg strings w/new dual pkrs & XO sleeves. Stabbed into set pkr @ 6260' & landed tbg.. Tstd btm pkr w/1000 psi. Pressure bled off slowly.' RU wireline & ran "Q" plug in LS. Pressd LS w/900 psi OK. Pressd SS. Communicated w/LS. RD wireline. Began pulling tbg. (Communicat£on behind 9-5/8" csg between "E" & "D"). Completed pulling tbg. Chngd rams. RI w/Howco RTTS tool. Tagged top of pkr @ 6271' (drill pipe measurements). Set RTTS tool 5' & 10' above pkr & pressd each time to 850 psi. Circ to surf{ POll. RI w/Dresser seal assy. Stabbed into pkr. Howco pumped 5 ft~ / min @.1700 psi. PO of pkr. Pumped 25 ft3 diesel, ~25 ft3 wtr,-70 ft3 cmt slurry (60 sx), 25 ~t3 wtr & 2~ St3 diesel. Di'sp w/455 ft3 mud. Stabbed into pkr. UNION OIL CO. OF CALIFORNIA DRI.LLI NG RECORD . . SHEET D PAGE NO... LEASE Trading Bay State #3 ltZELL No.A-10 W0/FIELD I Trading Bay DATE E.T.D. DETAILS OF OPERATIONS. DESCRIPTIONS & RESULTS 8/5/79 6525 ' con 6 6525' 7 6251' l0 11 12 6503 ' pkr pushe to btm 6503' junk 6503 ' 6503' 6503 ' Sqzd w/an additional 110 ft3 mud. Held 200 psi on annulus-during sqz. Bled off, PO. CIP @ 11.:0.0, am 8/5/70. WOC. Worked on Rig. WOC. RIH w/bit. Circ & cond mud. RIH found small stringer @ 6205'. Then nothing to 6232' Found med to firm cmt from 6232' to 6261' & no cmt from 6261' to 6271' (~kr). Drld pkr. Found no cmt below pkr. RIH to 6490'. Circ clean. POH. RI w/bit & scrpr to 6470' Circ clean. POH. RIH w/Howco RTTS. Set tool @ 6258', 6265' & 6270; Pressd to 750-800 psi · · Circ to surf. Pulled tool loose. Circ. POH. _ POH. RU Schlumberger. Ran junk basket on wireline to 6350'. Ran Howco EZ drill retainer and set @ 6251'. RD Schlumberger. RIH w/Howco stab in tool. Stabbed into retainer. Pumped 2-1/2 ft / Min @ 1600 psi. PO of retainer. Pumped 25 ft3 diesel, 25 ft3 wtr, 86 ft3 cmt slurry (75 sx), ' 25 ft3 wtr, 25 ft3 diesel & disp w/438 ft3 mud. Closed tool, sqz w/additional 120 ft3 mud. PO of retainer. CIP @ 8:15 am 8/~/.7~. WOC for 16 hrs. RIH w/bit & tagged cmt stringer @ 6160' & firm cmt @ 6203'. Drld cmt to retainer @ 6251', & thru retainer. Had 10' cmt below retainer. Pushed junk to btm @ 6503'. Made scrpr run to ETD & reversed clean. PU Howco RTTS tool & set between Middle Kenai "D" & Middle Kenai "E" zones @ 6262'. Press tstd below tool fo~ communication w/400# OK. RU Schlum- berger & reperfd Middle Kenai "E" 6320'-52' & 6274'-96', and Middle Kenai "D" 6222'-6230'. Made scrpr trip to ETD & reversed hole clean. ~Set Guiberson Model "A" drillable pkr on wireline @ 6260'. Could not get indication of pkr setting. POH & PU wireline junk bskt & located pkr @ 6335'. RIH w/dp & pushed to btm @ 6503'. Reran Dresser OME Model "A" drillable, pkr & set @ 6258'. RU & reran tbg. Unable to latch short string into dual pkr to space out. Pulled tbg to top pkr & discovered broken latch in collett. Attempted to run wireline thru short string to check for junk. Unable to get thru lower "XO" sleeve in short string. Pulled remaining tbg & pkrs out of hole ("XO" seemed to have restricted I.D. Could not pass wireline tools at surface). RIH w/sealJassy on dp & tested lower "A" pkr OK. RU to rerun tbg. Reran 213 its long string and 191 its short string -- 3-1/2" 9.~2# N-80 buttress tbg. Tstd Guiberson Model "A" pkr @ 6258' with 350# OK. Spaced out tbg & landed tbg hangers in head w/Guiberson model RH-2 dual pkrs @ 5641' & 4193'. RU wireline. Set "Q" nipple in long string @ 6270' & set pkrs W/3000#. Tstd csg w/1500# & tbg & pkrs OK. Opened sleeve @ 5603 between 2 hydraulic pkrs. PRessd~to 1000 psi on LS. No press increase -on SS or annulus. Pkrs set OK. Retrieved "Q" plug from LS. Opened Sleeves @ 6227' & 4152' IN LS. RD wireline. Instld BPV in both strings. ND BOE. Instld Cameron 10" 5000# dual 3-1/2" xmas tree. Attempted to disp down LS thru sleeve @ 6227'. Unable to circ. Rigged wireline. Rmvd ball valve dummies. RI found sleeve @ 4152' closed, but opened it. Unsure of'lower sleeves. Disp 76#/ft3 invermul w/diesel in annulus & LS to 4152'. RI to sleeve @ 5603'. ~Appeared open. Unable to open one @ 6227'. RI short string to open sleeve @ 4240'. Disp w/ diesel down LS up SS. Foudn circ was between sleeve @ 4152' LS & 3013' SS. RI closed sleeve @ 3013'. UNION OIL CO. Of CALIFORNIA DRILLING RECORD SHEET D PAGE NO. 5,i LEASE Trading Bay State #3 WELL NO.A-10 WO/,FIELD Trading Bay DATE 8/13/?o E. T. D. 6503' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Checked sleeve @ 4240'. Pumped down SS. Could not circ· RI. LS opened sleeve @ 5603' in LS. Disp w/diesel down LS thru sleeve @ 5603, out SS sleeve @ 4240!. RI & closed sleeve @ 5603'· Opened sleeve @ 6227' in LS Disp w/diesel down. LS out sleeve @ 6227' up SS Pressd SS to check dual pkrs W/600'psi. OK· RD wirelin~. RIG RELEASED TO MOVE TO A-7 @ 6:00 PM 8/13/70. Well flowing Long String: Middle Kenai "E" & "D" ZONES commingled. Short String: Middle Kenai "C" Zone. DIVISION OF DRESSER INDUSTRIES, iF P. O. Box 110g Dallas, Text" Pr. :red For · MR. LeGse CASING LINER TUBING rciu~c;i IIiOLClilCiLBUIB I Ii:ill Size Size FIRST Size STRING Size SECOND STRING THIRD Size ,STRING .. ' jWeight JGrade ] Thread IDepth J Weight Grade J Thread Depth Weight i G rode T hre ad Depth ESTIMATE . It DTAL EST Completion Procedure Prepared By JGuiberson Warehouse I Telephone,; ,~.. ,*,';. ,~. ~., tD T No. DIVISION OF DRESSER INDUSTRIE,.¢~ INC. ~o~ ,,0~. ~,.,,. ~x,, =~, Tubing Detail Report , , '~repared For Company . Date ' . , Lease - . Well No. I Field .. State Co. or P°rish New Completion . , . /2~ ' Workover ._ Size ' Weight Grade Thread Depth CASINO ~ :~ -. ,' Si ze Weight Grade Thread Depth LINER . ' ' 'TYPE OF TUBING FOR STRING NO. S~z~ , I Weight J Grade' J Thread j Depth TUBING ~~" I c= . I _.. I ,.+~ - ._ I ................................................. ~..:~ ......... I ............ ~!:..~ ............. -.! ........ ~E.~?. ............... ! ...... (~?::..~ ...... : .......................... ! ................................................................. . . ~ · ....... ~.~. ~ ~ ,, , ~:-~ r ~ . e:" - . .$ , , ,',~',~ · , , ,, . - ' . .' ~iZo ~,.~i7~ ~¢~ i'/o~'.~0 . ) ~, . . , , ~.~ ,, . Pacl(er ~sta~tion Recor[I Prepared For Company Date MR. Co, or Pari~h State . New Completion Size ~ Weight Grade Thread Depth Si ze Weight Grade Thread Depth LINER . IYPE OF TUBING FOR STRING NO. . . . , , , ,,, .... . I:)IVIIBION OF' O~ESS~:I:;:t INDUSTI~IES. tN(:, . -~ Packer ,u,staJiation Record J~r~pared For Company Date Lease , - ' . . Well No. J Field "' ' ' "' '"'~ ,.q--/oJ ' Co. o~ Parish State J . .J ~ New Completion ' ' ' ' ~77~)~~ A~ ' ' ~ Workover .._ Size Weig ht Grade Thread Depth c~s~.o ~ ~ ... ,. Si ze Weight Grade Thread Depth LINER . r . . .' PE OF TUBING FOR STRING NO ~orl ...Z.~.'.Z~ ...... ! ...... :~'..C ......... ! ........ ~.~- i ~,,~ _ _ ~.~'~-'~¢ . .I ............................................ . . ~ ~. 77, ~ ' _ . , , . ~ ~ ~ , -~ -~ '"" ~ ~t) 7 ~ ,.-~, ~- t U ~' -.... . . '- ~ .~" ..' · ~.. k...~ : ~ ~ '. ~, ~ '~.. O ~ ~, t '~1~ ~ 5. ~t t ~:~ f , 8 ~'. . ,12 o ~. . ~ 5'_ ' ~. ,, .... ,, .:. ,.' ' ,, ~,. 1, ~ ,.t~.~q.~4. qZ/l. 77 ~ . . . ': ,ox ,,o,. ,,,,, Tubi ' Prepared For Company Date MR. . Lease: . ..~.-~Weli No. j Field . Co. or Parish . State I [] New Completion '. ' ' [] Workover , Size 5''~ Weight - Grade Thread .. : Depth C ,SING X' Size Weight Grade ' Thread , , Depth LINER . . ' TYPE OF TUBING FOR STRING NO. ~ J Size Weight J Grade J Thread . J Depth TUBING J ~ ~ . f~- ! - I . .. ' ~ - . . . . . , . . . - . · . .. - . . ,. . . .- - . ./~ , . - ....... ___.; · _' - . .' .. · , , . .... · . - . --' . ' : . - - . ,, , .. . - - .. , . ' .-' . ... , , . . . . .: _'-.. . - - "~ --J"' C:' GE~)L-~-- . Form P--3 /~'~ St~bmit "Intentions" in ~i~ ~. 9-~7 & "S~quent ~po~s" ~ DupH~te ~-J C. · STATE O,F A~KA .... J t ENG~ OIL AND GAS CONSER-VATION~ CO,~l~ 50-~33-2006~ J 2 ENG. ~. ~ g~~o~ S~:~Y NOTICES AND REPORTS ON WE~ (Do not use this fo~ for proposals. ~ drill or to deepen o~1~ b~ ~ ~dV~r~t ~. ADL 18731 J 5. u~e "~L~C~ ~0~ ~--" ~.~ ~po~.~ ~f - .... :~.~ ~.~ ~ .... ~'~ ....... J I grOL W~LL ~ gA8 --- '2. N~E OF OP~TOR /,.'- ~-' ~ ~ i~'f~ ? [~ 8. UNIT F~ Union Oil Company-of California gjyi~JON ~J; cu. A. ND QAS Tra~ing Bay J REV 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 ....... State A-10 J SEC - Section 4, T9N, R13W, SM. O~IVE) -sec. 4, T9N~~R13W, SM. 13. ELEVATIONS (Show whether DF, RT, GR, etc. ~ '~' ~ 12~ P~T 101' RT above MSL 67-76 Check AppropriateB°x Tol,nd}~ Nature ~ N~t~ce~ke~wborOther'Dafa NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDONs CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL XX[ SHOOTING OR ACIDIZlNO (Other) ~ReCOmplete-Middle Kenai "C", , & "E" (NOTE: Report results of multiple completion on Well (Other) Com~oleti~n or Recompletton Report and Log form.) 15. D~SCRIBE Z'nOPOS~.D OR COMPLETED OPERATIONS (Clearly state all pertinent details, and g'ive pertinent dates, including estimated date of starting any proposed work. - Trading'Bay State A-10 was producing 1500 BOPD from the Middle Kenai "D" and Middle Kenai "C" intervals. The well was producing with a very high gas-oil-ratio approaching the 2000 cu.ft./bbl allowable, and production was being curtailed in an effort to reduce gas production. It was proposed to locate the source of gas. entry in the "C" & "D" intervals, squeeze cement as indicated, reperforate the remaining interVals, and return to production as a dual Middle Kenai producer. (See Sundry Notice dated 2/19/70 & Notice dated 3/17/70 representing the first hal~ of the above program). Extensive production testing of the Middle Kenai "C" interval indicated production with an allowable GOR. Information obtained from the recompletion of TBS A-8 indicated the Middle Kenai "E" Zone to contain an oil ban~ in the downstructure position, with majority of gas production coming from the "D" interval. Trading Bay A-lO. was subsequently completed from the "E", "D", & "C" zones with triple packers installed for segregation of the~"D'' high GOR interval. This work was completed as follows: 1. Released rig from A-8 W.O. to A-10 W.O. @ 12:00 am 7/27/70. 2. Killed well with 76# invermul. 3. Removed xmas tree and installed BOE. Tested w/3000# OK-. 4. Pulled 2-7/8" tbg and single hydraulic packer. Form STATE OF ALASKA Submit 'qntemtions" in TriDlicate & "S~bseguent Reports" in Duplicate OIL AND GAS CONSERVATIONi COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a difiierent reservetr. Use "APPLICHTION FOR PEH.MIT--" for such proposals.) 0IL GAs C] WELL WELL OTHER 2. NAA~E OF OPERATOR Union 0il Company-of California 3. ADDRESS OF OPERATOR 4. LOCATION. O,F WELL At surface Check Appropriate Box To I~nd:icate N~ature c6 N~oti'ce, Re 13. ELEVATIONS (Show whether DF, RT, GR, etc, 14. ~..GE TWO AP1 NU'M. ERICJ~L CODE 6.' ~, DESIGNATION AND SERIAL NO. 7. IF INDIA.N, ~J_J~O~f~iE OR TRIBE NA1VLE 8. UNIT, FA/{I~ OR LEASE NAd~E 9. W~L,L NO. tBS A-10 10. FIELD A~D POOL, OR WILDCAT n. SEC., ~., R., M., (BOTTOM HOLE OBJECTIVE) [2. PEB/VitT tort, or 'C)thel' 'Daf~ NOTICE OF INTENTION TO: TEST WATER SHUT-OFF II PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE J [ ABANDONS REPAIR WELL [~J CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR AClDIZ'ING ABANDONMEN'T$ (Other) NOTE: Report results of multiple eompletion on Well oml~letion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an? proposed work, 5. CO W/bit & scrpr to PBTD @ 6503'. 6. Reperfd Middle Kenai "C" interval for increased productivity as follows: 4266'-4284' 4834'-4862' 4320'-4350' 4404'-4430' 4500'-4510' 4574'-4592' 4672'-4694' 5096'-5100' 5124'-5132' 5244'-5249' 5328'-535~' 5534'-5590' Reperfd Middle Kenai "D" interval as follows: 5684'-5712' 6002'-~012' 5790'-5834' 6040'-6130' 5870'-5880' 6222'-6240' 5900'-5954' Perfd Middle Kenai "E" interval as follows: 6274'-6296' & 6320'-6352' Made positive zone segregation squeeze between Middle Kenai-"D" and "E" zones with 135 sx Class "G" cmt (2 jobs) & press tstd same w/500#. Segregation sqz performed across blank interval from 6240'-6274'. · Form P--3 Submit "Intentions" in Triplicate & "$ubse~tuent Reports" ~ Dupl~te STATE O,F A~KA OIL AND GAS CONSER'VATION ,CO~I~EE SUNDRY NOTICES AND REPORTS ON WELLS (I2)o not. use this form for proposals to drill or to deepen or plug back to a dif£ierent reservoir. Use "APPLICATIOtN FOR PER1VIIT~" for such proposals.) Ol,., 1-!. GAs E2 WELL WELL OTHER 2. NAME OF OPERATOR Union 0il Company 'of California 3. ADDRESS OF OPERATOR 4. LOCATION. O,F W~L At surface 13. ELEVATIONS (Show whether DF, RT, Gi~, etc. . . · . 14. Check .A4~propria.te Box 1'o [ndi'case Nmture of N~fi'ce, NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [ I~_~ ~ PULL OR ALTER CASING [~ FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE J J ABANDONs REPAIR WELL CHANGE PLANS (Other) Page Three ~. ATM N~CAL CODE 6. i~kS~, DESIGNATION A_ND SERIAL NO. ?. IF INDIA-N, AIJ-~TTEE OR TRIBE NAiVIE 8. UNIT, FA/~VI OR LEASE NAIVIE 9.- IV~LL NO. TBS A-10 10. Fr~,LD A,ND FOOL, OR WILDC~T 11. sec[,' T., R., M., (BOTTOM HOLE OBJECTIVE) 121 PEIINIIT NO. ~=~t, or :Other 'Data 'L FRACTURE 'TREATMmNT ALTERING CASING SHOOTING OR ~CID~ZING ABANDONMENT' (Other) (NoT~: Report 'results .of multiple completion on Well Comi~!etio, n or Recom,Pletlon Rei~ort and Lbg form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and giv'e pertinent dates, including estimated date of starting any proposed work. · . e 10. 11. 12. Set single 9-5/8" x 3-1/2" wireline packer between Middle-Kenai ("D" and "E" zones at 6258'. Ran dual 3-1/2" tbg strings w/dual hydraulic pkrs set between Middle Kenai "C" and "D" interval at 5641' and above Middle Kenai "C" interval at 4193'. Both strings equipped with g.1. mandrels and ball valves. Long string stabbed into single production packer at 6258' w/short string stabbed into bottom dual packer at 5641'. Both long and short 'strings equipped w/sleeve valves between packers. Se~ hydraulic pkrs. Tstd lower pkr to 500t/ and dual hydraulic pkrs w/15OOtJ. ND B0E & instld dual 3-1/2" 5000~/ xmas tree. Disp invermul w/diesel oil for pkr fluid. Rig released at 6:00 pm 8/13/70. ~Long String: Flowing from Middle Kenai "D" and "E" zones, 'commingled for wellbore cleanup. Short String: Flowing from Middle Kenai "C" Zone Both Middle Kenai "C" & "D" zones are straddled by production pkrs for proper segregation and isolation as future oil and gas production dictates. / er ~'f /~ 16. I hereby c tJ~y/~#:-the~o~sfl~ t',f IlUl i ~,..tmue and correct SIGNED (This space for State APPROVED BY C~ND~TiONS OF APPROVAL, E Dc TITLE Dist. Drlg. Supt. DATE 8/17/70 See ~nstrucfions On Reverse Side DIV!G!ON OF Off. AND GA~ Approved COpy Returned STATE OF AJ~KA & "~ub~e~ment Reports" in D~lt~mte OI.L AND GAS CO-~RVATION~ C~tTTEE L _ /t , _ " -"- SUNDRY N'OTIC~S AND REPORTS ON WELLS (~l~ not use this form for proposals to drilt or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PEHAV/IT~" for such proposals.) 1. ' "- ' ' ' ' "" '- OI, L.['-'] GA8 Union 0il Company -,o,f, California 3. AD~q.ESS OF OPERATOR ' 6. L~]~ DESIGNATION A2/D SERI.~ REL ~L 18731 Tr~din~ Bay 9. ~L NO, State A-10 ~0~ F~ ~ F~L, OR ~I~CAT ~ TradimK Bay Field-Middle Kemai "C" o~m~i~) Sec. 4, TgN, Ri~W, SM. 67-76 BUB~U~NT R~PO~ O~: FRACTUR~ ~'~A~EN~ ALTERING CASINO 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 4. ~J~CATION. O,F WELL Ats=~ace Conductor #3i, 1609'N & 571'W from SE corner, section 4, T9N, R13W, SM. 13. ELEVATIONs (Show whether DF, RT, GR', etc. 14. 101' RT above MSL Ch~ ApP~ia~ Box To NOTICE 0]~ INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR AC!DIZE A~ANDON' I~lVl~ REPAIR WELL CHANGE PLAN~[! (NOTE: Report results of multiple completion on Well {Other) Com~)letion or Recompletion Re~)ort and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Trading~ Bay State A-10 was producing 1500 BOPD from the Middle Kenai "D" and Middle Kenai "C" Intervals. The well was. producing with a very high gas-oil-ratio approaching the 2000 cu.ft./bbl allwable, and production was being curtailed in an effort to reduce gas production. It was proposed to locate the points of high gas entry in the "D" Zone,squeeze cement as indicated to eliminate excessive entry, and return to production as a single producer from the "C" Zone for further testing. The above remedial was completed as follows: 1. Moved rig over TBS A-10 3/1/70. Ran thermal analysis logs across the Middle Kenai "D" Interval. 2. Killed well with 70# Invermul, pulled dual tbg strings, retrieved pkrs. 3. Ran bit and scraper to clean out to 6525'. 4. Ran Howco E-Z drill BP & .set @ 5634' to isolate Middle Kenai "D" Zone. 5. Ran Howco RTTS tool & set @ 5470' to test perforations from 5532-5592 (51-6 sand). 6. Ran DST on 51-6 sand (5532-5592) to check for excessive gas entry. 3-1/2 hr test, estimated 638 BOPD flow rate, 1423 mcr/day, G0R 2230. 7. Set 9-5/8" cmt retainer @ 5395'. Sqzd 51-6 sand w/200 sx "G" cmt, max press 3000#. 8. Ran single string 2-7/8" 6.4# N-80 tbg w/Baker F-1 hyd pkr @ 4190 & tail pipe to 4202'. 9. Instld B.P.V. in tbg, rmvd BOP's, instld & tstd single xmas tree, chngd over fm Invermul to diesel oil. , & "~bsequent ]Reports" ha Oul~lt~ete STATE OF AL~KA OIL AND GAS CON~ER'VA,TIONi COMMITTEE SUNDRY NOTICES AND-REPORTS ON WELLS not .use this form for proposals to drill or to deepem or plug back to a diffierent reserWtr; Use "APPLICATION I~OR PF~R~IIT--" for such proi~sals.) WELL WELL OTHER ,, 2. NAME OF OPERATOR Union 0il Company- 3. ADgRESS OF OPERATOR 4. LOCATIO~T O,F WELL At surface 13. ELEVATIONS (Show whether DF, i~T, GR, etc. 14. Check Appr~priafe Box To I,~d, ka~ N~iure o~ N~i'ce, K~- }... ~ TWO m APt N~CAL copt. 6:' L~ DEIklGNATION AND S~L NO. 8. UNIT, Fa OR ~SE N~E Xra~ing Bay 9. ~L NO. State. A-10 10. F~ ~ ~L, OR W~T , 11. SEC., T., R., M., (~M O~1~) FRACTU~ TREAT MULTIP~ COMPLETE ~ R -~EATMENT ALTIRIN~ CASING SHOOT OR ACIDIZE ABANDONS OTING:0R IzING ABANDONM~NT* lu r 9iSCRIBE t'~OPOSID OR COMPLi~ID OtIltTIONS (Clearly state all pertinent details, and give ~rtin;ent~dates, including ~timated date 0f starting an}' propo~d work. 10. 11. 12. Set pkr & tstd OK. Returned well to p~oduction as Middle Kenai "C" single oil.prOducer. Released rig @ 7:00 am 3/6/70. This Sundry Notice represents work performed to date which is approximately one-half of the work proposed in the Notice dated 2/19/70. Thermal analysis:logs will be run to determine points of gas entry in the "C" Zone. The Well will be re-entered and zones demonstrating high gas entry will be squeezed. The well will' then be returned to production as a dual oil well in the Middle Kenai"C" and Middle Kenai "D" Intervals. 16. I hereby eertif ~e e and correct SIGNED ~ TITLE Dist. Drlg. SuPt. APPROVED BY ~ TITL~. CONDITI-ONS~ OF APPROVAL, AH: DATE 3/17/70 See 1,nsltu~ions On ReVerse Side Re/ui'n,?j I~np - ad~a HooIq pIIos #000£ - oxoq ,,9I/6-~ :S2A'IVA pz8 aaa :ciO& (IV~IH ol,II~[fl,t Pa8 ,,9/.L-~ gD(I uo~aumD :~t~[O~VH O~I~[fl,.T., 006 ,,0I x 006 ,,EI uoz~m~3 :(IV~tH DI"II~[FI,I,' :"IOOdS DEIISV3 S>lO>I porn. ,,g/g-6 'mou ,,ZI :~)~l~vq$ :H,WONVH D~ISVD 006 ,iZI (l~ ~sJ~[eqs :C[VE[H Ol~IISVD. BIOIEDflC[OI~4 '-J[¥I.LI~I '- UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO. LEASE Trading Bay State . %VELL NO.. A--10 W.(F. IELD Trading Bay DAtE 3/2/70 6 E. T. D. 6525' 6525 6525' 6525' 6526' DETAILS OF OPERATIONS, DESCriPTIONS & RESULTS Rig Released to A-10 W.O. fm A-8 W.O. @ Midnight 3/1/70. Moved rig to A-10 open sleeves in both strings. Circ down tbg w/Invermul. Remove xmas tree. Install BOP's. Cont instlng BOP's. PO short string tbg stand in drk. Pulled hyd pkrs. Layed ~ong string down. RI with 8-1/2" bit & scraper. Washed out bridge @ 6385. RI to 6525'. Circ & cond tnvermul. PO. RI Howco RTTS tool set @ 1900', tstd pipe rams w/1500 psi. Retrieved RTTS tool. PO. Ran Howco Model EZ BP on Lane-Wells wireline. Set pkr @ 5634' isolating Middle Kenai "D" Zone. DST 51-6 sand Middle Kenai Zone: Ran dry 5" ~p on Howco RTTS tool. Pumped in 1550 psi gas cushion. Set pkr 5470. Open tool 3:10 pm for 15 min IF. Closed tool for 90 min ISI. Opened tool @ 3:10 pm, bled off gas cushion to 175 psi, increasing to 350 psi. Fluid to surf in 16 min. IF rate 1559 BOPD, 814 mcf, 522 GOR. Oil rate steadily declined, GOR steadily increased. Last flow rate @ 350 psi 638 bbls/D, 1423 mcf, 2230 GOR. Closed tool 6:35 pm. Backscuttled. RI to 5595'. Circ out gas cut invermul POH w/DST tools. RIH w/Howco EZ -SV- 9-5/8" BP. Set @ 5395'. Brokedown perfs from 5532-5592 w/2700 psi w/30 ft3 diesel & 30 ft3 wtr ahead mixed 200 s~ Class "G" cmt followed by 30 ft3 wtr than 30 ft3diesel. Disp. Sqzd. Could not get build up of pressure. Cleared holes. Job completed 8:30 am. PO of retainer. Backscuttled tool clean. Circ btms up. POH. RU & ran 132 its 2~7'/8" 6.4# N-80 S.L. tbg to a total depth of 4202' w/Baker F-1 pkr @ 4190 (top). Landed tbg w/BPV.instld. Removed BOE. Instld Cameron xmas tree (See Tubing Detail). Instld xmas tree. Tstd to 3000#. Disp annulus & tbg w/diesel using Howco. Set pkr & sheared out w/2800 psi. First pkr test failed. Press annulus on top of pkr. Held 1000 psi. Pressd 1000 psi down'tbg. Held. Turned well to production @ 7:00 am 3/6/70. RIG RELEASED to Move to A-17. 2-7/8". ~ubinR Detail Bo t t om Top LenK t h J t s D e sc rip t ion 4202.35 4201.90 4201.90 4200.55 4200.55 4199.55 4199.55 4190.99 4190.99 4159.79 4159.79 4154.26 4154.26 3904.31 3904.31 3898.78 3898.78 2306.25 2306.25 2300.72 2300.72 298.73 298.73 289.51 289.51 40.68 40.68 38.10 28.10 27.00 27..00 -0- .45 1.35 1.00 8.56 31.20 5.53 249.95 5.53 1589.23 5.53 2001.98 9.22 248.83 2.58 1.10 37.00 132 2-7/8" 8rd collar 2-7/8" Baker hydro trip sub 2-7/8" Otis N Nipple 2-7/8" x 9-5/8" Baker hYd set pkr 1 2-7/8" 6.4'# N-80 ASL tbg 2-7/8" Otis CX Mandrel . 8 2-7/8" 6.4# N-80 ASL tbg 2-7/8" CX Mandrel 5! 2-7/8" 6.4# N-80 ASL tbg 2-7/8" Otis CXMandrel 64 2-7/8" 6.4# N-80 ASL tbg 2-7/8" Otis Ball Valve 8 2-7/8" 6.4# N-80 ASL tbg 2-7/8" ASL - 2-7/8" 8rd pup CIW - Hanger Elevation = tbg hanger to K.B. Joints Total A.P'i. CODE. 50-133=20064 Release Date 2-7-70 State of A)aska ' Department of Natural Resources DIVISION OF MINES AND MINERALS Sec. 4 - ......Petroleum Branch ............ T. 9N INDIVIDUAL WELL RECORD R. !3W < S Meridian Permit No. 67-76 Issued 11-28-67 Operator Union Oil Co. of Calif. Location (Surface) !609' FSL & 571' FEL, Sec. 4 Lease No. A]~iJ" 1~ ~3'i .................. - .... or Owner_ __.T_~a_d_i.n~_Ba~y_St. ate Loc. (Bottom)630' FNL & 2060' FEL) Sec. 4 , . Welt No. A-10 (24-4) Area Trading Bay Field PBD 6525 ' SpUd Date 12-5-67 Dfi ] 1 lng Ceased Total Depth 7073' Suspended _~ -_ ......... ,.; __..Aband°ned Elevation 101 tit .~e-oo.~. ~~-28-68 ,(~S) ~(Z,598< .......... ~S5:~6.~ (L)31.3 (S)0.8 (~)0.~ Comple{ed ~/-GL-~. 1-7-68 120 BID, Gray 29.4 APl Cut 7.7 (S)225 (L)422 -(~)30 "(L)2O'- ~t0 Gas MCF/D, Bean 90 /64 CP 1000 psi, TP 0 · psi 6919 Test wet-squ. 45 sx. 13 3/8"-61ff ' 1095' 1200 6760'-6840'test wet-squ.50 sx. .... (~T4~-~:-6-s_,- s-q: ~1~00' ~i2 ........ ~:_ ...... 9 5/8"-40~3,5f~ 7053Shoe750 ) ~V ~ ~ (~50' :;-5325 ;58 ;- ~-"- 2 7/8~'._tbg. 4206' on~ (5532'-92';5'68:4"-5712'~5787'_~ _:: ' __ . 2 ~/8" tbM. 4945' on~ (~030~-88';6!00'-34';6160'-~ ) -'i~ ..... ~ ~.~- -~ ~ ~ ........ (6245' (Long ~ ~ ~ ' w GEOLOGi C FORMATIONS Surface L~st Tested Na~ Depth Contents WELL STATUS Year Jan Feb : Mar Apr May June July Aug Sept Oct Nov Dec ~_-~:-- '__~ __~.~_<_z_~- _ ~--~7_~--_ __~- ---_-: - - i -]~' .... _ '2~.~ ~: ~.~-, _ .L ' ":' -~.-- c ,' ;~' 'c_c ~ ' ': - . _ :-._- ._: - ~ ]'z '"~ .... _- (Short string) P%r,f. 4262'-88' ;43!6'-54' ;4398'-4430' ;{~498'-4.5!4' 14572'-92' ;4668'-93'.: , ~766' -4864' ' Remrks: .'- . Form P--3 :/'--"~ REV. 9-30-67 . STATE O,F ALASKA Submit "Intentions" in Triplicate & "Subsequer~t Reports" in Duplicate OIL AND GAS CONSERVATIO,N COMMITTEE SUN:DRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a di£fierent reservoir. Use "APPLICATION FOR' PEI~MIT-~" for such proposals.) . wELL WELL OTHER 2. NAblE OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPEtiATOR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 4. LOCATION. O,F WaZLL Atsur~ace Conductor #31, 1609'N & 571'W from SE Corner, Sec. 4, T 9N, R 13W, SM 13. ELEVATIONS (Show whether DF, RT, Gl{, etc. 101'RT above MSL 8. LTNTTrFJ~°,~ OR LEASE NAME FILE Trad±n~ Bay State A-10 10. FIE~D ARNI) i~OOL, Oil WILDCAT TradinK Bay Field - Middle Kenai u. sec., T.. a.. M., (BOTTOM HOL~ "D"&"C" OBJECTIVE) Sec. 4, T 9N, R 13W, SM 12. PEI{1VI/T I~O. ] 67-76 Check Appropriate Box To I~n~i'ca~e Niature of N~oti'ce, Report, or 'Other '[~ta NOTICE OF INTENTION TO: TEST WATER SHUT-0FF ~--~ PULL OR ALTER CASING ~ FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON REPAIR WELL ' CHANOE PLAlV~ I~UBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONNIEN'T$ (Other) (Other) (NOTE.: Report results of multiple completion on Well Coml~letion or Recompletion Report and Log form,) DESCRIBE I'I~OPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. - Trading Bay State A-10 is currently producing 1500 BOPD from the Middle Kenai "D" and Middle Kenai "C" intervals. The well is producing with a very high gas-oil ratio which is approaching the 2000 cu.ft./Bbl allowable, and production is being curtailed in an effort to reduce gas production. It is proposed to run dynamic thermal analysis logs across both the "D" and "C" producing intervals to locate the points of high gas entry, kill the well and squeeze cement as indicated to eliminate excessive entry, reperforate the remaining "C" and "D" zones for increased productivity, and return to production as a dual Middle Kenai producer. , Estimated Startin~ Da. re: 3/1/70' proposed Procedure: 1. Run thermal analysis lOg through the long string across the Middle Kenai "D" interval to determine points of gas entry. 2. Kill well with invermul. Pull tubing strings. 3. Set bridge plug above "D" interval to isolate. 4. Re-run tubing. m¥1SmN oFoa A~ 0~ Return to production temporarily producing from "C" zone only,, (Cont ' d. ) Form REV. 9-30-67 /~' Submit "Intentions'' in Triplicate & "Subsequent Reports" in Duplicate STATE 0,F ALASKA OIL AND GAS CONSERVATION; COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLIC~_TION FOR PERMIT--' for such proposals.) 1. OiL [] GAS [] WELL WELL OTHER 2. NAME OF OPERATOR Union 0il Company of Cal±forn±a 3. ADDRESS OF OPERATOR 4. LOCATION. O,F WELL At surface 13. ELEVATIONS (Show whether DF, RT, GR, etc. 14. Page Two ~. API NUMERICAL CODE 50-133-20064 6. LEASE DESIGNATION AND SERIAL NO. ADL 18731 7, IF IN]DIAN, AJ~LOTTEE OR TRI'BE NA2VLE 8. UNIT, FAR1VI OR LEASE NAME Trading Bay 9. WELL NO. State A-10 10. FIELD AJN-D POOL, OR WILDCAT 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. PERMIT 1~O. Check Appropriate Box To I~ndicate Niature of .N~oti'¢e, Re ~ort, er Other 'Data NOTICE OF INTENTION TO : TEST WATER SHUT-OFF PULL OR ALTER CASINO SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER 8HUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ARANDONMENT* (Other) NOTE: Report results of multiple completion on Well ompletion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. · Proposed Procedure (Cont'd.): _ 5. Run thermal analysis logs across Middle Kenai "C" zone to determine points of gas entry. 6. Kill well with invermul. Pull tubing. Clean out to TD. 7. SqUeeze cement intervals demonstrating high gas entry as indicated by above logs. . 9. Run dual 2-7/8" tubing strings, and return to production. "D" and Short String - Middle Kenai "C". Clean out and reperforate remaining producing intervals for increased productivity. Long String - Middle Kenai DIVISION OF Oil AND_ GA~ 16. I hereby certify true and correct SIGNED __ (This epace for s~/~te' o c u ) APPROVED BY .':.i, , .... TITLE Dist. Drilling Sup' t. DATE 2/19/70 TITLE See lnstrucfiops On R?V~erse Side A.P.|. CODE. 50-133-20064 Re] ease Da te State of Alaska Oep~rtrnent of Natural Resources DIVISION OF MINES AND MINERALS .- . o,_.~, ~;l~.um Branch INDIVIDUAL WELL RECORD 2-7-70 Sec. 4 R. 13.~.y _. S Meridian Permit No. 67-76 Issued 11-28-67 Operator Union Oil Co. of Calif. Lease No. ADL 18731 or Owner _.T_~r_~d~n~_Sa_¥_ St_a,_te Location (Surface)t609' FSL & 571' FEL, Sec. 4 Loc. (Bottom) 630' FNL & 2060' FEL, Sec. 4 Well No. A-10 (24-4) Area Trading Bay Field _~ ..... --~_ .._,_,._ _ ._. .... ._ - _ _~ ............ . _, .... _ · PBD 6525 ' Spud Date 12-5-67 Drilling Ceased Total Depth 7073' : Suspended Abandoned Elevation 101 RT Re-comp. F 3-28-68 (S) 927(L)989 ...... ~S):26.3 (L)31.3 (S)0.8 (L)Oo3 Completed (/F/-GL-~/). 1-7-68 IP 120 B/D, Gray 29.4 APl Cut 7.7 % (S)225 (L)422 -(S)30 (ri)'20'-- ~t0 --~-- .......... Gas MCF/D, Bean 90 /64 CP 1000 psi, TP 0 - psi Casing: Size. ~ SxCm~ ~?f~___6.~99J:,67~q'j6904'- ~lugs .... 6919 Test Wet-squ. 45 sx. t3 3/8"-61f~ ' 1095' 1200 6760'-6840'test wet-squ.50 sx. -- - (~i~4~-Z-g~~'~ S'~ ....... - - ' '-':"~'- 9 5/8;'-40&43.5~ 7053Shoe750 -'~7i00" sx. ) ~V ~ ~50~ ~38~0-60 sq. w/t00 sx'. ) _ --.. --~ 2 7/~'.__t~. 4206' o~ pck~. (5532~-92"5<684,'-571~';5787'~ · 6838' ;5900'-54' ;5985'-6020'; ) ~_ ~/.S'J~..~9~f_o~~ ~os '-~~~.oo'_-sf>'~6z6o'- ) 6245 ' z'~------~ .... {~; .............. -~---'~ ....... Surface L~st Tested Name Depth ~ Contents WELL STATUS Year Jan Feb Mar_, Apr May June July Aug Sept Oct Nov Dec - -' ' -",;,,,_ L--'- :_...: -~- )~-" ~-"_ __;/.._ ; -_. ._" -% :. ':..~'.- ..... ~----: : ' __~ .._. _ I , .__(Short string) Per,f 4262'-88' ;4. 316'-54' ;4398'-4430' ;Z>498'-4.5!4' ;Z~572'-92' ;4668'-93~ - . -~ .... ~- e ~_ i_ _ ,,_ _: --~_ .:' = '_.~. ,- _. _ , _ ....... _._ ..... _-. ,_ __ ,: .,- .. ...... '_-., _. :_. _:__ .. . __.__. .: ...~ Remarks: .a P 7 '~ SUBMIT IN DUPLIC STATE OF ALASKA (See other in- structions on OIL AND GAS CONSERVATION COMMITTEE ~,~v~-~ side) i WELL COMPLETION OR RECOMPLETION REPORT AND LDG* la. TYPE OF WELL: oil, [-~ WELL b. TYPE OF COMPLETION: NEW [] WORK[] WELL OVER EN GAS- [-~ DRY WELL [--~ Othe'r'~ :: PLU(~ ~ Dirt. ~--~ Other:' BACK EESVR. 2. NAME OF OPERATOR Union 0il Company of Cal±fornia 3. ADDRESS OF OPERATOR 507 W. Northern Lights Blvd., Anchorage, Alaska ~995~3 At su~ace 1609'N & 571'W from SE cor. Sec 4, T~9N, ,:R13~~''~ SM At top proa. inter. R1 repor~ea below 528'S & 1407'W of s~face l~cation A~o~a~de~m 542'S & 1617'W of surface locati~n RT, GR. ~)* 17. ~. CASING~AD 3-17-68 3-27-68 3-27-68 10i' RT above M~L ~OW~Y* ' ROTARY TOOLS CABLE TOOLS 7073'~ 6650'~ 6525'~ 6102'VD Dual 0-7073 ~. PRODUCING EV~(S), GF ~S ~OM~TIO~, BOSOM, N~E (~ AND ~)* 23, W~ DIRE~GN~ . ~ SURVEY Top Perfs: 5012'~ 4649'VD : Btm Perfs: 6245'~ 5825'VD ' Yes 24. ~E ~~C ~D OT~ ~GS R~ DILt H~, BHC ~onic w/SP and calipert SNP~ CST~,and~Hud~ Lo~ CAS~G ~ (Re~rt all strips set ~in ~1~~ ~ C~G SIZE WEIGh, LB/FT. DE~ ~T (~) 13-3/8" 61# / J-551 1095'] 17-1/~ ~:[ 1~00 ~x cement Iqone 9-5/8" 140.43.5 j N-80[ 7053~ i22i/&~/~i7~0s~shoe&750s~DVl' None , ,--: ~, ' ~5348 ~. PERORATIONS OP~ TO PRODU~ON (Inte~al, size and number) [~:~, . q%: ~CID, S~IOT, F~CTU~, C'~ENT SQU~ZE, ~C. 5~12; 5~8~-5838; 5900-5954; 5985-6020; [/414~I68~ ] .... Sq w/100 sx neat 6030-60~8; 6~00-5~3~; 6z60-62~5. [3~0~3%0~ [ sq w/~OO ~pe of p~p) [WELL STA~S (~oduc~g or DATE ~RST P~ODU~ON [ ~ODUCTION METHO~ (Flowh~.g gas lift, p~mp~g~size'and ~(' ' 3-27-68 ,~-. [ Flowing '..: ~-, :.. ~.' · , , [ ' Producin8 3-28-68, [ 24: ~-. i. 20/64 ~ ~- I:'~' t,: 989 ~. I ~' ,' :'~. ' 'I~-~UR~ ' :"-, :J' .= ~ [~' ' 31' ~ .... "' ' · DISPOSITIO~:0~ GAS (8old, used for'~uel, vented, etc.) ~.-? ~.c ~-~ ~-. : .... :' ]TEST WITNESSED BY F~el &-~ented ~:' '~': .... ........ , ......: .~ ,- ~ M. Bratcher 32. LIST OF ATTACHMENTS :/ '"'4' '.. ' ..... 7-/: . tt~h ' "' ~3. I hereby cert~y t~at the foregoing and a ed information is complete and~rrec~;as determined from all:available records SIGNED ' ' ' ~ TIT~St DriliinglrSup~rintendent~ - · · PATS 4/3/68 H. D. McMahan : ~: · (S,, ~,,~r,c,io,~ ~,$ S~,~ [or ASdifio,cl D~a o, R,v,,,e Side) 5. AP1 N~CAL CODE 50-133-20064 O. LE~E DESIGNk~6~'~ID SERL~'NO. ADL-18731 ~, IF I~I~, ~~ OR ~IBE N~ 8. UN~,F~ OR ~SE N~E Trading Bay State 9. W~L NO. A-10 (24-4) i0. F~ ~ ~L; Oa W~mT ~'{~ ,, ~r~ -~ , Tra~ing Bay Field ~e¢~ il. 8~C., T., R., ~., (~O~ ~O~ O~E~IVE) Sec 4~ TgN~ R13~, SM ~ 12. P~IT ~O. .. ~iSu..mmary of Formation Test 90 min ~ciP, 8 hr FFP, 4'hr FCIP. No fluid/~t01 sdr'f~ ·~ ~. . !i Reversed 45 bbls Oil, l~%!~tr, 14% emul. ,. 0¥2% snd ~' IHP 2498, ICIP 2199, FFP 301~1234, FCIP 2066, . :"~ ¥ Ge0I~gi Markers Top~ of C Sand 4230'MD '~'~ .i~ %--. ~!!? }!!ToM of' D-:Sand 4950'MD .' - STATE OF ALASKA~. , '~' {Seeother In-L ,, ' structions on- ' OIL AND GAS CONSERVATIoN'~CONIMITTEE~* ~eve,'se side, J ~' *PI N~C. AL I 150-'133-20064 · ~ ~-.~ ....... : ~4 T ~ )" .... ~ ~ ~' ~' 6. 'LEASEDESlGNA, TION A2~D SERIAL NO. WELL cOMPLETION OR RECOMPLETION:: R£ .... ND.}!iL:OG ADL-18731 WV, LL ~ WELL ~,,_ ,. b. TYPE OF COMPLETION: .... ' :' BACK FeESV R. OVER EN WELL lJniog Oil.~¢ompany of Califgrnia ., c ~' 3. ADDRgSS O*~ OPERAT,0R - - ~ " i. 507 W. 'No~the~n .Liahts _Blvd., AnchorageS) Ai~Ska ~;' d 4. LOCATioN OF WEL£-.~.Report location eledrlll and:iin accorda~Oe with any:.~ate:~equire~ea-t,s)* at ,.r~,ce 1609'1q & 5'71'~ from SE cot ::. SecV~, ~; R13~, SM ? - At tOP prod. Interval reported'below 528ts a14o7'wof ti t~tal depth 542'S& 1617"W of Surface Location-:.' .:..~ ' i , /Sea.:' 4. T9N_. R13W. SM 13. DATE Si:~UDDED [li."~DA~T~ ~.D./RE~C~ [~5.' DANTE 'CO'IVLP-sUSP OtR~, ~.-41~i-~V~TIOi~.S_~CD'F, RgB, I~T~ GR, .~'1~C)*]17. ~. CASINGHEAD t ~'~i~ DRILLED BY MD & TVD[I9, PLUG;' BA, CI~I -'MD & ~D~-IF 1VUJL"L' ;J~'~LE%NY* CQ~iJ~PL ..... ~ 21'R RY TOOLS INTERVALS TO~L 'DEPTH SURVEY 1ViAD E Top Perfs 4262:'MD -397LTVD -~ '- ~- -'"' 24. TYPE ELECTRIC A.ND OTHER LOGS!RUN-. ..... :~_.:/! _ fl [ l[ -. CA..~RIG ETZ~ - .WEIGHT, LB/FT. SXZE CF~ .Ir~NTING l~ECOl%D I A3VIOUNT PULLED SIZE TOP. (MD) BOTtI'OM (MD) $~ SIZE DI~I~ SET (iVID) P~CKER SET (IVlD) 4208 28. PERFO1R~TI01WS OP?-/N TO (Interval, size and number).. 29. ACID, SHOT, F~CTURE, CEAIENT SQUEEZE, ETC. 4262.4288'; 4316-4354'; ~;4398-4430'; 44982~"[i~i48L..-.~i:~8_' ! Sq. w/lo0 sx neat 4S14'; ~572-4592'~i 4668'4693'; 4796-4864 1i304°'~86°~.. :: /i:~ ,:/' ]Scl' w/100 sx neat ' PI%ODUCTIO1W ~ DA~E FiRsT-PRoDUCTiON [ pllOf)UCTioN METi{O,D (Flo~vh:.g, gas }lif. t7 pumping__si~ and ~_pe o£ pump) ] VTELL STATUS (Producing or - 7; i,~ sieur-in) Producing ~/27/68 Flowing ,' FLOW, TUBING'-: ~I~G PP,~S~_ D-R~ [CAL~TED OIL~BBL. ' GAS--1V[C~.. WAT]~,,--BBL. IOIL GRAVITY-AP1 31'. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) ]TEST WITNESSmD B '~Uel & Vented t M. Bratcher 8~. I hereb~ ~ertif~ that ttie.':fore~oins and at bed information is complete and correct as determined from allTavallable records It,D r MCMahan. i , · (See Instructions and Spaces for Additional Data on Reverse Side) 8, UNIT,FA/~/I OR LEASE NAME :Trading Bay State 9. WIlL 1~O. A-10 (24-4) 10.: FIELD A~ND POOL; OR WILDCAT Trading Bay Field 11._ SEC., T., R., M., (BO'I'rOM HOLE ~ O~JF_~rlVE) DST #2: ~S' ~N~LUDIN~ INTEI:I. VAf '~T~D, PI:LESSUR'I~- DATA ~ I~COVEI~I~ OF OIL. GAS, :'. -- WATEH AND MUD DS~: #3: . ~ _ ,. :? INSTRUCTIONS General: This form is designed for sui~rd'[tting a complete and correct well cc~:mj~letion report o~d :'Tall t~,'j~es of lanzJs and lease.~ ~n Alaska~'. .:7- .- -:lterm: 16: Indicate whiChspaceselevatiOnon is-:usedandaS reference (where not otherwise shb~m) for depth'"~nea~re- '-ment~ given in cther this form in any attachments. '"~ :~ ''~ .... -- -.. -!. ' .... '' :-'1 ' " ' '~'ltem~ 20~'~,nd 22'..: If this well is comb]eted for Sel~r~af'e production from' mor~'-4Fi'an one interval zone i:(mul~iple"comple'ti0n), so stote in iteH '20, and in ifem 22 show the prc.zlucin~f iinterval or interga~, .Ctop(~)~ bottom(s);~'nd name .(s)(if:~ny)-for only the interval reported in item 30...:~S6'bmit a separate i;(Paoe] .on--:this for'm, adequat'ely identified, for each additional inte, val to be s~perately Produced, showk-I-1 ,.ing 'the ja-CkJitional data pe~finenf't© ~uch inter~;al. ' ...... -"' ":" ' ' ' -" .... L. -_ ~ ' '-c: ? '. ..... '. --Item26: .'fbacks C~ment'q Attached s~'pplement~l records' for-this Well should show-~he details or, any mul-~,~.. _ . . 'f' "<- : --.; · Z'.',. ,,.'_:tiple.stacj'e Cemer~Jing ahd the location &f the cementing tool. i :., ..~ - . ,?em;'28:-Submit"'a separate com~sletion report on this form for each interval to~i~ separately ':(See ]nstr:uction {~r items' 2.0 and"22 above). , .... 41'48-4168:, 5" d.~!~ 4...85./psi:.~gas cushion, 5 min~ IFP, 90 min ICIP, FFP 3' hr :1-5:: min, 90 min FCIP.' No f..!uid to surface. _ra~te, 18/64 bean~:I li~50-jtbg~press. . j.. 35. Well flowed gas @ 2~'96'i~ICF7 ................... .dT~p of'C sand .~. .. Top of D sand -. MEAS. DEPTl~ IFT'. 1206, ICIP 16.9.5,:iFFP 1630, FCIP 16.:95 --. 3840-3860,:. 5" d.p., i.:P0O psi gas cushion,.. 40' min test. No fluid, to surface., 3092 MCF rate, 20/64, tubing press. IHP. 1662, IF? 1239, F 1500, F¢IR. 1532, Flip 1630. · ._ 5. . .. . _ ;~ . - [.'AND DETEC~EI) SHOWS OF OIL, G~ OR WA~. ~.. 5 min IFP, 90'm~n':ICIP, 1 hr." 1300 ps.i [. 4230' · 4950' TT~UE VERT. D~I LEASE' Trading Bay State UNIO OIL CO. Of CAL. IFO NiA WELL RECORD RECOM?LETION RE?ORT WELL NO. i A-10 FIELD RECORD SHEET C /'" No. Trading Bay SIZE' ~ WEIGHT' THREAD . · ' GRADE DEPTH ~ · REMARKS 13'3/8" 61# T.& C Butt 'J-55 ' 1095 ~;I91--5/8" I40," 43.5 I'' --'' J-N '7052 · · - - - 4989 · ' . · [ ' · ' , i' -., · . , . · · ,, , .... ' ' · . , , . PERFORATING RECORD ~,,L . ~ ~ ~ ) ! /~ ~. :... ... 1..~ '' · pRESENTCONDITION . DATE- · ~ INTERVAL E.T.D. . REASON 1-3~67. · 6909-6919 6984 Test' Squeezed .. Retainer 6875' , 1-4267' ' 6760-6840 6875 Test . 'Squeezed - Retainer'6750 '~'6.~68 66,00-6740 6750 ProdUction B.P .6525- Hemlock Zone · 3.20-68. 5330-5350 - 6525. . Test ..' . 3-21-68 4148-4168 " ..Test squemzed 3-23-68 3840-3860 " - ,, Test Squeezed 3-23-68 4240 - ,, .. Block Sqz,' ~eezed , 3~26-68 426.2-4288 " . Production · 4316-4354 ' " , , 'l ' , ,. 4398-4430 "C"Zone : 4498'4514 ' Ii .... ' 4572-4592 · i . · ..... . 4668-4693 . 4766-4864 I ''-- 501215050, 5325-5358, 5532-5592, 5684-571~2, 5787-5838' '~ "D" Zone for :" ' ' 5900-5954, 5985-6020, 6030.~5088, 6100-6130, 6.160-6245 ~ Pr. odu~tion , . , ITIAL P:RODUCTION · DATE ' INTERVAL NET OIL C%T GRAV. C.P.. T.P. CHOKE MCF GOR I REMARKS '~i'6-68. 6600-6740 148 28.9 0 0-200 90/64. NM Ga8 Lift - : ~-28-68 4262/4864 927 0.2 26.3 0 185 30/64 225 240 "C" Zone '3-28-68 5012/6245 989 0.3 31.3 0 610 20/64 422 426 ,,D,, Zone · · . · · . , , . , . , , , ' APR 1 lflSfl "' ..... ' ' DI¥1$1C~N oF MINES & MINER ~L~ I . · - ANCH, DRAGE . , · , , , . . . , , . . · . ., - ~VELL HEAD ASSEMBLY' TYPE: ,, ... .. CAsiNGHEAD.: ' ''' S'haffer"Model KD 12" Series-1900 '2 2" wi - . LP .screwed .~de outlmt~; gnttnm tO----- . -. .~ _ . SOW 13-3/8" Csg. C~LSING HANGER. sh'affer 12" .NOminal9-5/8" Model KOKS. -- : · . · - CASING SPOOL: ' · . TUBING HEAD: Cameron 1'2'-900# x '10".900~; DCB .w/2"-1500~ ~t,,da~H o~,tlets TUBING HANGER: TUBING HEAD TOP' MASTER VALVES: -- UNION OIL CO, OF CALIFORNIA DRILLING RECORD LEASE 'Trading Bay State WELL' NO. A-I.O FIELD SHEET D PAGE NO .... ~ DATE .. 3-17-68 3-18-68 E. T. D. 6750.' 6525' 3-19-68 3-20'68- 6525' 6525' DETAILS OF OPERATIONS, DESCRiPTiONS & RESULTS RECOMPLETION REPORT Moved rig from State A-12.to'State A-10. Rig over hole @ 2:00 PM. While moving rig. attempted to kill well. with Inlet water but unable to circulate .thru gas lift valve @ 6445'. Rigged up wireline unit to pull ball valve @ 299'. Valve very difficult to pull due to paraffin in tbg. Removed ball valve and ran paraffin cutter. RIH with retrieving tool to pull gas lift valve. Tool would not fall due to paraffin. Loaded tbg with diesel oil. Reran retrieving tool and pulled gas lift valve @ 6445 Rigged up to circulate Inlet water to kill well. Circulated 68.5# weighted Inlet water (outside-in) thru mandrel @ 6445' to kill well. Installed tubing back pressure valve and removed Xmas tree. Nippled up riser assembly, installed flow line and BOPE. Released Baker packer @ 6489'. Pulled 208 its 2-7/8" tbg with jewelry and 9-5/8" pkr, Rigged up Lane Wells and.RIH with HOWCO .CIBP and set. same @ 6525'. POH with wireline. Closed blind rams and pressure tested BP to 2000 psi - 10 mins OK, Released pressure and RIH with Lane Wells CBL and G-R Cor- relation logs. Bonding varied from good to poor intermittently throughout interval 3500'-6525'. Removed riser assembly. Removed Shaffer single string tubing head and replaced same with Cameron dual string tubing head. Installed Cameron dual string tubing head. Attemp~ to test to 3000 psi, could not hold pressure. Removed head and found top steel ring of "R" seal bent.. Replaced ring with new one and re-installed head. Attempted to test again but head would not hold pressure. Removed hend and found new ring also-bent as before. Replaced Cameron "R" seal with Cameron "X" seal.. Re-installed head and tested to 3000 psi - OK. Perforated interval 5330-5350' using Lane Wells NCF II'charge on 4" carrier guns. RIH w/ HOWCO DST assembly on DP. PositiOned packer @ 5307' with tail pipe to 5320'. .Pressured drill pipe with 500 psi gas cushion. After shutting off gas supply pressure on d.p. continued to increase and string weight increased, indicating fluid entry. Bled gas cushion off d.p. Closed bag and pumped into drill pipe with 100 psi using kill line. Continued reverse circulating unit, d.p. was full of water and gas cushion worked out of fluid. Broke out DST manifold and POH. Found bar valve in DST assembly had been ruptured. Redressed DST.tools and RIH as before to obtain DST #1. 'Pressured drill pipe to 485.psi with gas cushion. Set packer.@ 5307' and opened tool-@ 11"15 pm. After 5 min IFP increased to 510 psi. Closed tool to obtain ISIP. Obtained 1-1/2 hrs ISIP. Reopened tool @ 12:50 am. -Bled. off' gas cushion. Well continued with strong blow (7 psi TP) throughout.8 hr FFP. Shut test tool @ 8:50 am. NO fluid to surface. Opened 'rever'sing ports. Oil to sur'f, ace after reversing with 12 bbls. (FL apparently 680''from surface). Continued reversing and recovered 45 BO (cut lO%.wtr, 14% emulsion and 0.2% sand). Water cut measured @ 74,000 ppm Cl. First water obtained on-reversing measured @ 79,000 ppm Cl. (wieghted Inlet water). Continued reverse circulating during 4 hr FSIP. Pulled tool loose @ 12:~0 pm and POH. Broke down'test tool and read pressure charts as follows: IHP 2498, IFP 668, IC'IP 2199, FFP 301-1234, FCIP 2066, FHP 2'465. Rigged up Lane Wells and perforated interval 4148-4168' w/4 SPF using NCF II charge on 4" carrier guns.. ,Picked up HOWCO DST.tools w/retrievable BP. RIH for DST #2'. Set BP @ 4202', Pulled up hole one stand. Pressured drill pipe to 485 psi and set pkr @ 4090' w/ tail pipe to 4103'. Opened tool @ 8:25 pm. Pressure increased to 945 psi during 5 min IFP. Closed tool 1-1/2 hrs for ICIP. Reopened tool @ 10:00 pm. Turned well to test trap to establish stabilized flow rate,. · UNION;OIL CO, OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO. 2 LEASE.TradlSngBay Sta~e . . DATE E.T.D. RECOMPLETION REPORT VMELL NO. A-10 FIELD Trading Bay, , DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 3-21-68 6525 3-22-68 6525' 3-23-68 6525 Continued flowing well and obtained gas flow tests as follows: Time Rate, MCFD, Tm ~ Choke 10:4-5 2496 1150 10 18/64 11:00 2179 1150 27 18/64 11:30 i850 1190 27 16/64 12:00 1776 1200 27 16/64 12:30 1698 1200 25 16/64 1:00 AM 1729 1200 26 16/64 1:15 1791 1200 26 16/64 ReCovered 6.5 Bbl water, emulsion, and trace of oil while flowing well. Closed tool @ 1:15 ~M and reverse circulated. Recovered 4 Bbl fluid as above while reversing. Obtained 90 min FCIP while reversing and circulating gas out of drill pipe. pulled tool loose @ 2:45 AM. Retrieved BP @ 4204'. POH and broke down test tools. DST #2 press- ures as follows: IHP 1858, IFP 1206, ICIP 1695, FFP 1565-1630, FCIP 1695, FHP 1858. RIH with wireline to set HOWCO DM plug.. Fired ignitor but tool gave all indications of misrun. Started pulling out of hole when. plug set @ 3845'. Waited on arrival of X-over subs to fish out setting tool prior to drilling out plug. RIH with overshot, found plug @ 5835'. POH with setting tool. RIH with bit and drilled up BP @ 5835'. Chased plug to 6525'. . POH. Rigged up Lane Wells, set HOWCO DM BP @ 4270 - left.setting in hole. RIH with overshot, recovered setting tool. RIH w/ HOWCO RTTS @ 3995' to squeeze perfs 4148-4168'. Mixed and pumped 100 sc class "G" cement mixed with Inlet water - cement on formatio~ @ 1400# @ 16 cu ft/min. Pumped 60 cuft SD 10 mins. Pumped 10 cuft @ 1600# SD 15 mins. Pumped 10 cuft @ 1600# SD 30 mins. Pumped 8 cu.ft @ 1800# SD 1 hr. Pressured to 2500#, no decrease in 5 mins. POH w/ RTTS. CIP @ 1:30 PM 3/22/68. WOC 7 hrs. Rigged up Lane Wells, RIH w/ gun. Tagged top of cement @ 4054'. Perforated 4 HFT 3840-3860. RD Lane Wells. Picked up HOWCO 'test tools. RIH with packer @ 3800' and tail pipe @ 3813'. Pressured pipe to 500# with gas. Opened tool @ 11:30 PM. Surface pressure increased to 1200# during 5 min IFP. Closed in for 90 hrs for ICIP. · .. Tool open 100 mins. Flowed gas at following rates.: MCF~D Choke' Time T.P. 3092 20/64 ~ 70 min 2355 16/64 "15 min 1465 ~ ~ 12/64 15 min No fluid recovered .on test. IHP 1662 IFP 1239 ICIP 1532 IFP (2) 1467 FEP (2) 1500 FCIP (2) 1532 FHP 1630 Inside-,Chart 1300' 1325 1375 Outside Chart 1728 1337 1581 1500 1565 1581 1695 LEASE UNION OIL CO. OF CALiFOrNiA DRiLLiNG RECORD RECOMPLETION REPORT SHEET. D PAGE NOo i Trading Bay.state IYELL NO.. A-10 FIELD . Tralding Bay DATE 3-23-68 (Contd) 3-24-68 3-25-68 3-26-68 E. T. D. 6525' 6525' 6525' 6525' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS POH with test tools, RIH with RTTS to squeeze perfs 3840-3860'. Set packer @ 3700'. Mixed and pumped 100 sx class "G" cement mixed w/ Inlet water. Pumped 75 cuft cement in formation @ 16 cu ft/min @ 1600#. ~ncreased to 2200#. Broke back to 1200# SD 15 mins. Pumped 10 cuft @ 1600# SD 30 mins. Pumped 10 cuft @ 1800#, broke back to 1600# SD 45 mins. Pumped 10 cuft @ 1600#, .cleared perfs. Mixed and pumped 100 sc class "G" with 2% CaC12 and Inlet water. Pumped 75 cuft cement in formation @ 16 cu ft/min @ 2400#, SD 15 mins. Pumped 10 cuft @ 1800#, SD 30 mins. Pumped 10 cuft @ 2000#, SD 45 Wins. Pumped 5 cu ft. Pressure increased to 2500# - no decrease in 5 mins - no back flow.' CIP @ 3:15 PM. POH with RTTS. WOC. RIH with bit and-drilled cement from 3790-3900'. Closed rams.. Pressured up to 1500# - no decrease in 15 mins. Ran bit to 4062' and drilled cmt 4062-4200'. Pressured up to 1500#, no decrease in 15 mins. CO to 4270. POH. Rigged up Lane Wells and perforated 4 holes @ 4240". RD l,~'~e" Wells and ran in hole with HOWCO RTTS @ 4110'. Pumped into formation w/ water @ 14 cu ft/min @ 2400# broke to 1600#. Mixed and pumped 100 sx class "G" cement mixed w/ Inlet water. Pumped 70 cuft in formation @ 1600# SD 15 mins. Pumped in 10 cuft @ 1800# SD 30 mins. Pumped in 10 cuft @ 2000#, SD 45 mins. Pumped in 10 cuft . Pressure incr.eased to 2800# - no decrease - no back flow, CIP 3:00 PM. Released RTTS POH, WOC. WOC total 12 hrs. RIH w/ bit, drilled cement 4170-4275'. Closed rams, pressured up to 1500#, no decrease in 15 mins. Ran bit to 4270', drld on BP. Plug turned loose - pushed plug to 6525'. RU Lane Wells and perforated the following intervals w/4" carrier gun w/NCF II charges: 4262-4288'; 4316-4354'; 4398-4430'; 4.498-4514'; 4572-4592'; 4668- 4693'; 4766-4864'; 5012-5050'; 5325-5330'; 5350r5358'; 5532-5592'; 5684-5592'; 5684-5712'; 5787-5838'; 5900-5954'; 5985~6020'; 6030- 6088'; 6100-6134'; 6160-6245. Rigged down Lane Wells. RIH w/ Baker casing scraper. POH changed rams in BOP. Started to run tubing and found Baker packer Model A-S was in- operative. WO packer 2 hrs. Ran two strings of tubing, w/ jewelry as follows: 2-7/8" Seal Lock Collar Baker Trip Sub 2,7/8" N-80, 6.5#, Seal Lock'Tubing Otis Type X landing Nipple Baker F-1 Packer XO Pub Sub EUEX Seal Lock 2-7/8" N-80, 6,5#, Seal Lock Tubing Otis XO Sleeve 2-7/8" N-80, 6.5#, Seal Lock Tubing Baker Packer A-S Dual XO Pup EUEX-Seal Lock 2-7/8" N-80, 6.5#, Seal Lock Tubing Otis CX Gas Lift Mandril 2-7/8" N-80, 6.5#, Seal Lock Tubing Otis CX Gas Lift Mandril 2-7/8" N-80, 6.5#, Seal Lock Tubing Otis CX Gas Lift Mandril Jts .45' 4989.64.-4989.19 1.50' 4989'.19-4987.69 30.65' 4987.6'9-4957.04 1.00' '4957.04-4956.04 8.05' 4956.~4-4947.99 3.63' 4947.99-4944.36 30.96' '4944.36-4913.40 3.20 22 688.85 12.70 4.18 1 31.61 5.50 4913.40-4910.20 4910.20-4221.35 4221.35-4208.65 4208.65-4204.47' 4204.47-4172.86 4172.86-4167.36 10 308.87' 4167.36-3858.49 5.50' 3858..49~3852.99 56 1735.65' 3852.99-2117.34 5.50' 2117.34-2111.84 UNION OIL CO. OF CALIFORNIA DRILLING RECORD RECOMPLETION REPORT SHEET. D PAGE NO.- 4 LEASE_ 'Trading Bay State DATE 3-26-68 3-27-68 E~T. D. 6525' 6525' VV-ELL NO. A- 10 FIELD'.Trading Bay DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Long~ St.r.ing ~ontinued 2-7/8" N-80, 6.5#, Seal Lock Tubing XO Pup EUEX Seal Lock Otis Ball Valve Nipple Otis Flow Coupling XO Pup EUEX Seal Lock 2-7/8" N-80, 6.5#, Seal-Lock Tubing 2-7/8" N-80, 6.5#, Pup Joint XO Pup EUEX Seal Lock Cameron Split Tubing Hanger Landed below RT Jts __ . 58 1800.40 2111,84- 311,44 3.20 311.44-308.24 2.25 308.24-305.99 3.00 305.99-302.99 3.10 302.99-299.89 251.14 299.89- 48.75 8.15 48,75- 40.60 2.60 40,60- 38.00 1.00 38.00- 37.00 37.00 37.00-00.00 Short String, Baker Trip Sub Otis "N" Nipple Baker Dual Paker A-S Slack on Packer Baker Stinger XO Pup EUE X Seal Lock 2-7/8" N-80 6.5# Seal Lock Tubing 2 Otis CX Gas Lift Mandril 2-7/8", N-80, 6.5#, Seal Lock Tubing 10 Otis CX Gas Lift Mandril 2-7/8" N-80 6 5# Seal Lock Tubing 56 Otis CX Gas Lift Mandril 2-7/8" N-80 6 5# Seal Lock Tubing 57 , ! · , Otis Ball Valve Nipple Otis Flow Coupling XO Collar 2-7/8", N-80;- 6,5#, Seal LOck Tubing 7 2-7/8", N-BO, 6.5#, Sub ,! ,! II !1 II Landed below RT 1.50 4229.11-4227.61 1.20 4227.61-4226.41 10.42 4226.41-4215.99 2.03 4215.99-4213.96 .30 4213.96-4213,66 3.20 4213,66-4210.46 62.13 4210.46-4148.33 5.50 4148.33-4142,83 313.12 4142.83-3829.71 5.50 3829.71-3824.21 1745.63 3824.21-2078.58 5.50 2078.58-2073.08 1785.78 2073.08- 287.30 2.25 287.30 - 285.05 3.00 '285.05- 282,05 .75 282.05- 281.30 215.25 281.30- 66.05 10.20 66,05- 55.85 10,15 55~85~ 45.70 7.70 45.70-'. 38..00 · .1.00 38.00- 37,00 37.00 37.00- 00.00 Nippled down BOP, installed.Cameron dual tree, tested' seal to 3000#. Displaced salt water with diesel. Baker packers. RIG RELEASED @ 9:30 PM 3'27-68' Dropped setting balls and set both Form No. P----4 REV. 9-30-67 STATE O,F ALASKA O~L AND GAS CONSERVATION COMMITTEE SUBMIT IN DEPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · 2. NA1VIE OF OPERATOR Union Oil Company of California 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 LOCATION OF WELL 1609'N & 571'W from SE corner Section 4, T9N, R13W, SM . AP1 NUAIERICAL CODE 50-133-20064 ~ESiG5'AT.ION AXD SERIAL NO. ADL-18~31 /) Trading Bay State A-10 Trading Bay Field -11. SEC., T., R., M., (BO~'POM HOLE OBJECTIVE) Sec. 4, T9N, R13W, SM 12. PEP, iVIIT 1~O. _____ 67-76 REPORT TOTAL DEPTH AT END OF MONTH, CI-L~AIGES IN HOLE SIZE, CASING A/krD CE1VIENTING JOBS INCLUDING DEPTH SET ~ VOLLrMES USED, PERFORATIONS, TESTS .A_ND !~LESULTS, FISHING JOBS, JUNK IN HOLE AND SIDE-T1;L~CKED HOLE AND Ally OTITER SIGNIFICANT CI~I. A3q~ES !Al HOL~ CONDITIONS. TRADING BAY STATE A-IO~ RECOMPLETiON MARCH 1968 Production from Hemlock Zone suspended and Middle Kenai Sands dually completed. Moved rig on to A-10 3/17/68 Set permanent bridge plug @ 6525', above hemlock perforations Ran Lane Wells CBL and Correlation logs DST 5330-5350': No fluid to surface. Recovered 45 bbls in 8 hrs, 10% wtr, 14% emulsion, 0.2% sand. DST 4148-4168: Well flowed gas @ 2496 MCF/D rate, 18/64 choke, 1150# TP. With bridge plug @ 4270' squeezed perfs with 71 sx to formation @ 2500 psi. DST 3840-3860': Well flowed gas @ 3092 MCF/D rate, 20/64 choke, 1300# TP. With bridge plug @ 4270' squeezed perfs with 160 sacks cement @ 2500 psi. Drilled out cement to 4200'. Perforated 4 holes @ 4240' and squeezed with 64 sacks to formation @ 2800 psi. Drilled out cement and bridge plug @ 4270'. Perforated: 4264-4288'; 4316-4354'; 4398-4430'; 4498-4514 '; 4572-4592 '; 4668-4693 '; 4766-4864 '; 5012-5050'; 5325-5330 '; 5350-5592 ' 5684-5712'; 5787-5838'; ,,5900-5954'; 5985-6020'; 6030-6088'; 6160-6245' Ran dual strings of 2-7/8 tubing with production packers set @ 4206' and 4945 '. RIG RELEASED 3/27/68 RECEIVED DIVISION OF MINES a MINERAL~ ANCHORAGE -----..--. ~ 14. I hereby certify~th~t t]~e foregoing i~ true and rrect ' .s~G~_ ~_~.., ~.L/~C~ . ..i3ist. Drilling Superintendent 4/4/68 DAis: NOTE--Report on this form is required for each calendar mont~ns, anO must ~ with the Division of Mines & Minerals by the }Sth of the succeeding month, unless otherwise directed. ~.Tm~tt "Imtentions" in & "Subsequent Reports" in .Dupliimte STATE O,F ALASKA OIL AND GAS CONSERVATION; COAAMITTEE SUNNY NOTICES AND REPORTS ON WELLS (DO not use this form for proposals to drill or to deepen or plug back to a diffiere~t reservoir, Use "APPLICATION FOR PEH~IT~" for such proposals.) ,, 1. 'NAME OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPERATOR 507 W. Northern Lights Blvd· 4. LOCATION O~ WELL Atsumce 1609'N & 571"W from SE corner Section 4, T9N, R13W, SM 13. ELEVATIONS (Show whether DF, BT, GR, etc. 101' R.T. above M.S.L. AP1 NUI~CAL CODE 50-133-20064 6. ~?,ASI~,' DEStGNA~'iON AND SERIAL NO. ADL-18731 ?. IF INDIA.N, ALLOTTEE OR TRIBE 8. UNITr FAR1VI OR LEASE HAME Trading Bay State 9. W~ILL NO. A-10 10. FIELD ,MN-I) FOOL, OR WILDCAT -Trading-'Bay Field _ 11'. SEC., T., R., M., (BOT'INDM HOT-~ OBJECTIVE) Section .4,~ T9N, R13W, SM 12. PEB2VIIT NO. 67-76 14. NOTICE OF INTENTION TO : Check &ppr~ria,~e Box To I,ndicate Nlature of NO!,~c'ei SUBSeqUeNT R~PORT OF: MULTIPLE COMPI,ETE FRACTURE',TREATMENT ABANDONMENT* REPAIR WELL CHANG' PLANS (Other) '* (See Below) (NOTE: ;RePOrt results of multiple completion on Well (Other) Completion or Recompletion Report and LOg form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give perttnent::dates, including estimated date of starting an}' proposed work. Suspended production from Hemlock Zone and dually 'Completed Middle Kenai~Sands TRADING BAY STATE A-10, MARC~ 1968 _ Set permanent bridge plug @ 6525', above Hemlock perforations Ran Lane Wells CBL and Correlation logs. DST 5330-5350': No fluid to surface. Rec. 45 bbls in-8 hrs, 10% water, 14% emulsion, 0.2% sand. DST 4148-4168': Well flowed gas @ 2496 MCF/D rate, 18/64 choke, 1150# TP. With bridge plug @ 4270' squeezed peris w/71 sacks to formation @ 2500 psi. eST 3840-3860': Well flowed gas @ 3092~MCF/D rate, 20/64 choke, 1300# TP. Squeezed peris w/160 sacks cement @ 2500 psi. Drilled o~cement to 4200'. Perforated 4 holes @ 4240' and squeezed w/64 sacks to formation' @i2;80~ psi.' ~Drilled out cement and bridge plug @"4270'. Perforated:' '4262-4288';' '~31~43~-';,. 4398-4430'; 4498-4514'; ~ 45~2-4592'; 4668-4693'; 4766-4864' 5012-5050~f/A:5325-5'336~f 5350-5358'; 5532-5592'; 5684-5712'; 5787-5838'; 5900-5954' 598~920'-; '~6030~8'; 6100-6134'; 6160-6245 Ran dual strings of 2-7/8" tubing w~th production pack~rsset @ 4206' and 4945'. - / 16. I hereby certify that ~h.e for~$oin~ i~J;rue andtcorreet ~ H.D. i'icMahan r · · (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF Alq~: Dist. Drilling Superintendent TITLE DATE 3/27/68 TITLE DATE See 1,nstrucfions On Reverse Side -. F~rm 1~-3 I~EV. Submit "Intentions" in Tr~plica~e & "Subsequent Reports" in Duplicate STATE O,F ALASKA OIL AND GAS CONSER'VATIONi ,COMMITTEE SUNDRY NOTICES AND .REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reserv~ir. Use "APPLICATION FOR PEEA~IT--" for such proposals.) OZL ~ OAS [--] WELL WELL OTHER ~.. NAME OF OPERATOR 3. A~DRESS' OF OPERATOI~ 99503 4. LO'CATION, O~F WELL At surface ~9 ~]~ 13. ELEVATIONS ~ Show whether DF, RT, GR, etc. 14. Check Appropriate Box To I,n~iza~e N~ature of N~oti'ce, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I I PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE I ] ABANDONS REPAIR WELL ~ CHANGE PLANS ~O~.her~ * (~ ~~) 50--Z33-2006-4 6. L~'E DE~IGNATION AND ~a-~L~L NO. ADL*-18731 "~, iF INDt'A~, ALLO'rr~:~: OR TRIBE NAbiE UNIT, FARlVl OR LEASE NAME 9. · V~IELL ~O. ' A-10 11. SEC., T., I~., M., (BOTTOM HOLE OBJECTIVE) .:Sec.. &, T~, RI3~/, S~l 12. P~T NO, 67-76 SUBSEQUENT REPORT OF: WATEa SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTINGi OR ACIDIZINO ABANDONMEN'TS (Other) NoT~: Report results of multiple completion on Well ompletion or Recompl~tion Report and 'Log form.) ,, DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimate.d date of starting any proposed work. * Suspend G~k Zone. eenpl, aCe H.tddle K,ena~. C h D--sando.. 13-3/8" co~S~S ceuen~ e 9.$/8- .~ e~meuted $ 7053' l~od~ £ron ~enloek ~u pe~£ora~no 6760'68~0'' 16. I hereby certify ii,at.)thee.forego_ins i~ tru correct G;L~.o ~..&~6.~/~ State q~ce~se)/~ CONDITIONS OF APPROVAL, ~ A~: ./ DATE DATE 3-17--68 See Instrudions On Reverse Side ]Perm lq'o. P--4 REV. 9-30-6V STATE OF ALASKA SUBMrr IN D~LICA~ O~L AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O:F DRILLING AND WORKOVER OPERATIONS 1. WELL WELL OTHER 2. NA/V~E oF OPERATOR Union 0il Company of California 3. ADDRESS OF OPEI%ATOR 507 Northern Lights Blvd., Anchorage, Alaska 4. LOCATION O'F %VF, LL 1609'N & 571'W from SE corner Section 4, T9N, R13W, SM -5.' APl NU~{ERICAL CODE 50-133-20064 LEASE DESIGNATION AND S~IAL NO. ADL-18731 7. IF INDIAN, ALOTTEE OR TRIBE NA.RIE 8. U/N'IT,F.~P~M OR LEASE Trading Bay State 9. WELL 99503 A-10 (~4-4) 10. FIELD AND POOL, OR WILDCAT trading Bay - Hemlock Pool I1 SEC., T., R., 1%~[., (BOTTOM HOLE OBJECTIVE) Sec. 4, T9N, R13W, SM 12. P~q2VIIT NO. 67-76 ~3. REPORT TOTAL DEPTH AT END OF MONTH, CI~-ANGES IN I~OLE SIZE, CASING A1N-D CE~{ENTING JOBS INCLUDING DEPTH SET A/WI) VOLUNIES USED. PERFORATIONS, TESTS A/WD P~ESULTS. FISHING JOB~. JD-NK IN HOLE A-ND SIDE-TT~ACKED HOLE ANT) ANY OTHER SIGNIFICANT CIiAN~F_,S IN HOI~ CONDITIONS. TRADING BAY STATE A-10, JANUARY 1968 Ran Schlumberger SNP and CST. ". Cemented 9-5/8" 40# and 43.5# N-80 casing @ 7053' w/750 sacks cement. Cemented thru DV collar @ 5350' w/750 sacks cement. Cleaned out to 6984' Ran CBL and Coorelation logs. DST 6904-6919': Fluid surfaced in 1-1/2 hrs. Flowed 55 bbls in 7 hrs.,90-98% water. Set retainer @ 6875' and squeezed 6904-6919' w/45 sacks cement. Perforated with 4/HPF 6760-6840'. DST 6760-6840': Recovered 35 bbls water, 39000 ppm total Cl. Squeezed 50 sacks cement thru retainer set @ 6750. Ran 2-7/8" tubing with packer @ 6489'. Perforated w/ 4/HPF 6670-6740. RIG RELEASED @ 3:00 PM 1-6-68 RECEIVED FEB 1 19 'J DIVISION OF MINES & MINEP. ALS ANCHORAGE ~. I hereby certi the I~or. egoin~is, true SIGNED ~ .... ~~ ~,u% r, Cr.ai~a~l ~T= Dist. Drilling Superinte~gMt February 9, 1968 NOTE--Report on this form is required for each calendar month, regardless ~f '~he status O~~ operations, an~ must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~ise directed. UNION OIL CO. OF CALIFORNIA ALASKA DISTRICT TO: Alaska Transmittal WELL NAME- 'II<3 f,--13 TBD G-4 · Transmitted herewith are the following: Run No, Sepia Blue Scale Induction Electrical Log 1 ea '~'2"~-. Dual-Induction Lat-erolog (Final logs: TB A-10, TBU G-4) BHC Sonic/Caliper Log BHC SoniC/Gamma Ray BHC Sonic/ Caliper/Gamma Ray Log Formation Sonic Log (Fs) Density-Gamma Log Formation Density Log {Fd) Neutron Log Formation Neutron Log {Fn) CDM or High Resolution Dipmeter ~DM'Safety Print CDb! or Printout CD~,! or, Polywog Plot CD~ Polar'-Plots Proximity4iicrolog/Caliper Log Gamma Ray-Neutron Log Gamma Ray Collar Log Cement Bond Log bMdlog Core Descriptions, Conventional, No. Core Descriptions, Sidewall Core Analysis Core Chips Sample Cut Drill Stem Test Directional Surveys Receipt a. cknm~,ledged:~~-? Date' Return receipt to: Union Oil Co. of California, 2805 Denal~ St. Anchorage, Alaska RECEIVED FEB 1 1968 DIVI,SlON OF MINES & MINERAL~ ANCHORAGE 99503 IL c;~ ~ ,~, re~e~se s de) 0 ~NO G~S CO~S~V~YION;~6~YE~ 'WELL cOMPLETION OR REcOMPLETIO~P~T ~lqb~.oa* la. TYPE OF WELL: on, ~ ~t~ ~ d.' ~.. ~ ~ ,,'~ b. TYPE OF COMPLE~ON: ~ ~ c~J ~'~.J NEW WORK DEEP- PLUG ~IFF, r!J ' ~ ~9 - WELL OVER EN ' nick n. zsva. Ot_~ ~.,~ cJ- ~-' 2. NAME OF OPERATOR ' ' ' ~" ~ ~ ~'~' (¢ * · c:J ~;';¢ " . -: Union 0il Company of Galif0}n a' ' 3. ~DDa~SS 0P OPERATOR ~. -_, :.;~ . ' , ,~ ~ a~.. i~. , ;_ ....... r~ern bzehts Boulevard, ;-Ancho~a~e~ as : 3 ~ LOCATION 0~ ~E[L_(Report 'loaat~ cle~ty a~"in accordance' with ~Ya ~t~e ~quire~en~s)~'~ at ~ ec~ ~ 1609'N &':571'W from SE corne~ S ,:.T~N, ~13W; S.M. At tOP prod. interval reported-below (6600) 517' S::; & i~W f~om .:~u~:~ [~oc. At total d~P~ (7073') 515'S a.~20.68'W f~m $d~f~. goca~i, oa2 '*. ~'~ ' · ' ' , ' -~ ,v'", , ¢ ~' ~,,, r ,"1 13. na~~D~ ll4..~.~ T.n, ~.~c~ t:!o..~n~ co~ ~Usr ~-X~ ;$6. ~v~s (DF, RKB, 12-5-67 - -.. I 12.30-67 · ~ [' 1-7-68(;~ ;-'~ ~ ~ I '~ ~ 7073,.- 6652 /:': 6750,.. -6630 1.~ :~ ~ ;-, ~; _ ~ .t ~. PRODUCING, ~V~(S), '~F- ~S OOM~TiO~, gO~M,L~~ A~ ~)~ . ~ ~, W~ DIRE~OH~ 558~ 6600 '__.. ____' :- ' ~. ,~ m ~..: ~-~ 6740 ~,' 6320' VD Hemlock .......... '.;~ ~ ~ , .. Yes _ . CAS~G RE~ (~e~ all St~e~ ~11) ~ ~L: _x3-a/ I ;~_ 6i. ~ / J'r55.[ 10~ ~1 'a~2'[''~ ~ sx cement Nene 140, 43*5 [; .'-80:~[ 70~ ; ~~/~'[~; 7'0 si shoe, 750 sx DV " ~ ' ' ' - ; '~ ,4 ' ' -- : SIZ~ 'l TOP(A~, I BO~,SID, 28. PE~O~TI~NS OP~ TO'~O~ONL' (m{e~0!. size ~d n~be~) 'B '.L~. '" -AC~.' ~',. · ~'-~ . NT i QU .m C 4 h01es/~t 2" scallop guns - ,t~m!~mV~(~) -. 6760-6840 I 50 sx Class'" "G" cement 6600-6740'.. : 6~4-~19.m ~°~ ~; ~*~:"~ [ 45 sx Class "G" cement i i I :11 i ii. i i i i ii II ii i 'i :.1 ]11 ii DAT~ FI~T.P~ODU~OH -[ ~O'DUC~O~ ~'f[~O'D (~'0W~ag, gas;lifL pump~g--siz'~and;: ~, type O' P~D) llWZSnm*~-i-)S*AmS _(~°au~Us-- -°~ : 1-7-68 - - .i Gas Lift~' :: ~:~J ' l~' ~ I Yroouczng ~,~, o, ~,~. .l~o~s ~s~ I~oxz s~Z~ 1~..~ sod O~s~n. '~~cs. Wa~~n. [GaS-Om~O 1-9-68, 4" ' 90/64 I ~ 20. i, - al'DISPOSITION O~ GAS (~01~, used )or ~uel, vented, etc.) : I '' ~ '~"} Used for fuel, vented . . . [ M.L. Bratcher 82. ~i~ Core record " ~8.'I hereb'~ eertff7 that the foregoing and ~aehed' Information 1~ cOmPlete and eo~reet a~ determined from all?available records TITLE Di~t. ',Drilling SuperintendeB[T~ I III · (See InstruOions end S~ces ~or Additional Data on Reverse Side) -- 8. UHIT, FAF. M OK LF_~SE NAME ..Tradin~ Bay State 9. W~L ~o. ~h ~o: r~ ~'~L, oa W~THemlock Trading ,Say F~eld - Pool ~-76 · .INTERVALS D~LLED BY '' CABLE TOOLS Sec. 4~]:;TgN, R13W, S.M. '12, :PEP'MIT 1VO,,& .. INSTRUCTIONS .. ~. .. ~.4 b~ .~ '!:: :.._) ~., ~- General: This form is design~,ed f6~ .sul~'.mi!~.ing .a complet~-:.and correct well cor~pleti~n report end log on ?.;. .~. all types of lands and leases i~ AlaSka._ -- '- ' :.'~ i-~':: z '=: -' '?' · Item:':-::16: Indicate which elevatio~ is 0'sed as ,~eference (where not otherwise-~how,'~) for depth .ri3eas6re- ments::gi.X~- n in other spaces on this form and in-'any attachments. Items'22~.and 22= If this wet-I is comp't:~te:d fo,.:.separatc-*production from m0~e than one interval zone ~ L,'~ --"' '-' .-. 7(mult e,:comple~}:on), s° state in item--"20', and' in item :22 show the prcduci~g interval~ or inter~als, ., ..,...3 -. '/.!op(si7 bo tom(s):and name ( (if'ahy) for.gnly ;~he int01i~v~.l reported in item 30~ ,Submit a separate repo~t '(ioaO~)~ oh':this form, adequa.t~ly j~entified, for'f~ach addi?~onal inte~,al to be ~bperately produced, show- : ~ng th'e'%dlditionYa'l data Pertinent:to such inter'val .,z ~tem26: '~,'Sac.ks Cbment": Attached supplemental records'f°r this well should sl~ow the details of ~"nY.m'UiL · i~iple ~tag!0 ce'.~eh)ing and' the Iocatic)n of.-~}the qementi,n.'g',;tool. ~:i:::)O p~o '* :Jtem'328:2~ub'~it~ra separate.completion r rt %n this":~o:F~n for each interval to be separafely du'~:~! :'L~=~...~...-. ,;~stmct;on.-,.,f'~,r items ..,.,on~ ',q-aa:~ ~ .... "- . ' -e n~_/.._ a..,ove~. - . 34. SUMMARY OF' FORMATION T.E~TS~-JNCLI]DII~I INTERVAL TESTEI~, PRESSURE DATA. A.h'D OF OIL, GA.q, :i ' .. , , ~ . .. : WATER AND MUD ~' ' : · '2',.~ }ST 6904-69i9:* 5" D.P,~ Pa~k~ 6.-83~. 90"min:!iClP, 7 hr ~FP,.3 hr.F. CIP -Gas m ~- ;urface in'5 min., flu~id i~: t..-1/~' ~s. !Flowed 55 bbls flhid tg.~: hrs. 2-10% oil ~0-98% Wa~er, 74000ppm~"~tot~.l ~1 z<i~ 3016::~ IFP 959, ICIp :2801, ?FP 959&2705, ~ ~ ~.~;~Op.: Hemlock 6586 'CIP 2753, ..FHP 3016 Sqzd.~u '~et~iner 0 6875 w/45 sx d~ent ~q~fo~ation. ~ST 6760-6840: 5" D.P. Pac~er:67~05[.~. 90 min ICIP, 8 hr EFP, 3 hr FCIP Gas to .... · mrface in 3 hr ~0 min. ~c~ger~d'..]5 bbls ~r in:D.P., 39000 pPm~ ~o~al c1.-' :HP 3016, IFP 144, ICZP 26:81;'}.FF~ I:46-1102, FCIP,2657, FHP 3016~ u'$~zd:thru 36. CORE DATA, A~ACII BRIE~-D~CRIPI~ONS OF LITfIOLOGY, POROSITY, FRACAS, '.~PP~T DIPS - '¢ ~:~' -~ '-~ " [~ ' ' " ' DE'FE~ED SHOWS OF OIL, G~ OR WA~. _ ,--~ .... ~ · "~ I ~ C ' ", s. :ores: '~69626698 ~6982670 6740267~9 6819-6831 :' x . , . .:.. :T .:: ~'< .:; -. ~..- ,-2.. -..~ : ~ .~ · ~ .... ~ " . 'C ~ ' '.~ ~ .. :' i~ ; t2 .. .- _. .. -~ C , _ : ~ ~' : ~ .~,: "' "~" ' . ~'~'" ' WELL RECORD PAGE NO. i ~ " ' ~ . .. ' - ~_- .u- -_LEASE- "State [3.-3t8" - . 6i' ".:.'Buttress :-: J-55 -:' :"- 1095-.'. cemented Wl1200' Sx "(-last' 200'sx 2% Cadl2)" .. '.' '::" 9-5/8" '40~ 43~5 Buttress · J-55~ t,I-80 7053 - Cemented w/750 sx class "C" plus CFR-2 in 1st stage ' '.'. " .... '"' ' ". · '. ' and'Tqn.~x-__~ _ of same -in 2nd sra~,e._ ~, .." 2 8'i ~ -7/ , ,,,- · '6'"41' Seal-Lock' N".80 · 6560. Set-: w/Baker Model .F-1 Packer@ 6489 ,. , · . . · PERFORATING RECORD '' DATE I~,'' XNTERVAL 'E.T:D.' ' RE~SON ! . :' P~ESENT CONDXTXON ' 1~3-68 [' 6919.6904' 6984' - DST" #1 ~quee.z.ed w/50 cuft Reg. Class "G" cement thru. ' ' · .' '[ ' ' :' · ' · italliburton D. rillable Retainer @ 6875' · . , , , :1-4'68 _'. 6760-6840' . 6875' DST #2. i~queezed w/62.5 cu f't. Reg., Class "Gi' cement. thru ' ' ' · " talliburton Driilable Retainer @ 6750' ~6-68 "/. 6600-6740' . 6750'. PrOduction.- Open for ProduCtion ' ' ' ..... . · , . · · · · . · . · . , . . · . · ,, .. · · . , , . , , , ., · INITIAL PRODUCTION ' ~DATE , INTERVAL NET OIL ,CUT" GRAV. C.P. 'T.P. GHOKE M,~F GOR "REMARKS 1-6-68 I 66'00.6740 148 . 3 28.9 0 0-200 90/64 NM - 'Heading & Dying ,, . . , , · . . , , . . · . . , , , · . · , , . · , , , · · . : . . · , ,, , · , · · , ,, ~ . ' . .... ' ' ~ . . ' 'WELL 'HEAD ASSEMBLY ' TYPE: · · CAsiNG HE~D': :" Sha:ff MOdel KD 900 'w p.w/2-2" LP screwed side outlets. Bottom to er ~. . . ":.....: :..? , -..: -. ~ ~.- .'.-"-:-'. ,--'.: . .. ..... . ..-.. SOW 13-3/8'.' 'casing . CASING HANGER: Shaffe '12" ' 0ael s CASING SPOOL: " : :'' ' '"" "' ' .... '" : i TUBING: HEAD:.: Shaffer'.'TYp~ .~9~' ::L!0. 12,., :'; 3000# x: 10"-3000# w/2-2"~.1500# studded outlets TUBING HANGER: .;-·TUBING HEAD·TOP' Cameroon' Si;n~l~:String Solid Block w/Master Valve and Swab Valve w/o Wing Valve- MASTER'VALVES:' 2-9/1.6" Bore ':i;"' ;',-:i.' uNiOn 'Oil CO.' Of califOrNia SHEET d .. '-;'. , . .. ,-. ' .. :'--... '::-' .:'- DRILLING RECORD ' PAG,E NO, 1 · . . · ..LEASE Trading Bay ,State.; ,:. WELL NO. -'~ A-10 FIELD Trading ,Ba, y DATE 'E. T. D. 12-5-67 300' 1106' 1106 ' 1400' 9 thru 13 14 5394' 5623 ' 15 5693' 16 5765' 17 5827 ' · 21 -- " 6267' : .. . - , DETAILS OF OPERATIONS. DESCRIPTIONS & RESULTS .. Spudded 12-5-67 @ 2:00 PM. Drilled 12-1/4" hole to 300'. Attempted to orient. Dyna Drill, had magnetic interference, waited on'Sperry Sun Gyro Compass to orient. Oriented and Dynadrilled from 300' ~ 526' Pulled out of hole. Ran in'with drilling assembly and drilled 12-i/4" hole from 526' to 1106'. Pulled' out of hole. Picked up 17-1/2" hole opener. OPened 12-1/4" hole to 17-1/2" hole from 300-1106'. Circulated hole clean. Pulled out of hole. Ran and cemented 13-3/8" casing @ 1095' With HOWCO float Shoe @11095' and HOWCO'differential fill collar @ 1048'. Cemented w/1200 sacks class "G" cement mixed'with inlet water, preceeded by 50 cuft water. Bumped plug w/1600#, float held OK. Cement in place @ 7:45 PM. 13-3/8" Casing Detail From 1095' 1092.87' 1051'.56' 1049~39' 42.46' 33.46' To 10-92.87' 2.13 HOWCO Float Shoe 1051.56' 41.31 1 Jt i3-3/8", 61#, J-55, Buttress, new, Smls 1049.39' 2.17 HOWCO Differential Fill Up Collar 42.46' 996.93 24 Jts 13-3/8", 61#, J-55 Buttress, New, Smls 33.46' 9.00 Shaffer Fin Joint 00.00 Below KB 1038.24,25Jts 13-3/8", 61#, J-55, Buttress, New, Smls. Waited on cement. Cut-off 13-3/8", installed Shaffer KD head, tested head to 3000# for 15 mins, held OK. Nippled up BOPs and Hydril, Tested rams to 1500# for 15 mins, held OK. Drilled collar and shoe Drilled 12-1/4" hole from 1400-5394' Drilled 12-1/4" hole to 5623'. Pulled out of hole. Ran in with Dyna Drill to turn hole back to the left. Dyna Drill failed to operate. Pulled out of hole. Ran in hole with another Dyna Drill, oriented D.D. survey instrument-hung up, broke overshot~ - Dynadrilled to 5693' Pulled out of hole. Ran in with drilling assembly. reamed from 5693-5765' Drilled,'surveyed, Ran in hole with'.Dyna Drill. While orienting DD stuck survey inst. in kick sub. Pulled out.of hole to recover inst~'RIH.w/DD, attempted to 6r£ent for 5 hrs without-success°- POH, RIH with' DA. Drilled to 582.7'. Drilled .to' 5910'.'. Tripped for bit change @ 5855' Pulledlout-.-of hole. ~.~-~Ran in' With drilling assembly. 59 7 . ~ -Altered~ target and~dropped..angle. . Driiiedl 'from 5987.6106 ' ,,..- . . ::....! Dri.lled~ from'~6106-6267 ' · Drilled from 591.0- _.:':;.:.::' L' ~:';:'iI. i:i ;':,-:;-:;.'-:,-;::.~:":,i'.-:ii .".-"i :: '-;-..-. :'" DRILLING; REcoRD:: ..~-.-i::~.:. :;.. /. :,' i 'ii: ' PAGE' NO,. ].EASE :-'.= Trading" Bay state- ' .-aLL'NOI A, IO :-'i~ELD Trading Bay - ._ DETAILS OF OPERATIONS, DEscRIPTIONS & RESULTS DATE' '12-22-67 ,~ 24 23 25 26 27 28 29 E. T. D. 6446 Drilled and surveyed 12-1/4"' hole from 6267-6414'. Pulled out of hole picked up Dyna Drill. Ran in hole and oriented same. Dynadril!ed 12-1/4" hole ~from 6414-6446'. · 6590 Dynadrilled6446-6486'. Pulled out of hole and laid down Dyna Drill. Ran in hole, drilled and s~rveYed 12-1/4" hole from 6486-6590'. 6696 Drilled and surveyed 12-1/4" hole from 6590~6696'. Pulled ouff of hole to pick up core barrel, 6716 Made up core barrel and ran in hole. Cut core #1 from 6696-6698' when · barrel jammed. Pulled out of hole with no core recovery. Re-dressed core barrel and ran in hole. Cut core #2 from 6698-6705'. Barrel- jammed'. Pulled. out of'hole and laid down core. Recovered 2'. Made up DA and-ran in hole. Reamed core hole from 6696-6705". Drilled and surveYed 12-1/4" hole from 6705-6716'. 6740 Drilled and surveyed 12-1/4" hole from 6716-6740'. Twisted off while drilling @ .6740 with no indication of torque. Pulled out of hole and found'shock sub had parted at mandrel leaving bit and part of shock sub in hole. Made up fishing assembly with 10" overshot and ran in hole. Circulated over top of fish and pressure indicated fish was caught. Pulled out of hole and found fish was not recovered. Re-dressed over- shot and ran im hole. Ci.rculated over top of fish @ 6736' and pressure increased from 800 psi to 1200 psi. Pressure held with pump shut off. Pulled out of hole and found fish was not recovered, jars were plugged with mud and cuttings. Re-dressed overshot and ran in hole. Circulated to top of fish. Prepared to go down to attempt to latch over fish. 6783 Circulated down and latched onto fish @ 6736'. Gained 20,000# pull when picking up off bottom. Pulled out of hole and recovered fish. Picked up core barrel and ran in hole. Cut core #3 from 6740-6759'. Barrel. jammed, pulled out of hole. Recovered 5' conglomerate and sand oil stained.' Picked up bit and ran in hole. Reamed core hole and drilled and surveyed 12-1/4" hole from 6759'-6783'. 6906 Drilled to 6819'. Pulled out of hole, ran in with core barrel, cored 6819-6831' (12') core #4. Recovered 2' conglomerate and oil sand (core barrel jammed). Ran in hole with Bit #24. Reamed core hole 6819-6831' and drilled to 6906' 7033 ' Drilled and surveyed 12-1/4" hole from 6906-7033' with bit changes @ 6908' and 6970'. ~ . . , 7073 Drilled and surveyed 12-1/4" hole.from 7033-7073'. Circulated for samples.l'l/2'hrs., made short trip. Pulled out of hole to run logs. ..~ Laid down 7,3/41" robe magnafluxed.~ Ran Schlumberger's DILL, HRD, and Sonic Formation FaCtor~ Log. ' 7073 -. -Ran-schlumberger's:BHC'SoniC-.L°g, SNP and Density Tool. Tool failed -~!iwh~ilerunnin~, ~.Ran-sidewall sample guns and rigged down Schlumberger. ... :! 'R~n ?.~. hole With--i'bit and. CirCulated to condition hole for Casing. _UNiON ?OiL-.CO: Of CaliFORNiA · SHEET D (.':'i._...-;¥ ~:..-,:' :-." ':'": ..:: .;.'.:' 'i..-'-/;-;' .'.';;;-::. '.!; i; ;,:!'- DRILLING 'RECORD i. ; ... ~...-.: !.. : ~,A~= 'NO~. 3 I ':'~ ': Trading '.BAY- stAtei!/.'., ;::;-;,-.~ ,::/' ;.!/i.-'._vvq~LL NO-/;;...X.10'-'. FiELD ' '-Trading 'BaY LEASE DATE 1-1-68 , E. T. D. 7073 6984 69.84 6875 -_ . · . - . DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Pulled out of hole and rigged.up to'run-casing. Ran 174 Joints 40# and 43,5# N-80 and J-55 with Baker Model "G" shoe @ 7053' and Baker Model "G" Collar @ 7007'. Halliburton DV Collar located @ 5353'. Mixed and pumped 7'50 sacks class "G" cement with CFR-2 using Inlet water. Displaced 1st stage with 2990~cu ft mud using #2 rig pump. Opened DV Collar and circulated 2 hours. Mixed and pumped 250 sacks Class "G" cement' with CFR-2using Inlet water. Displaced cement with mud and cement in place @ 11:30 PM;i-I-68. 9-5/8" CasinK Detail From TO' 7053.03" 7050,44'. 2.59' 7050.44" 7009.64' 40.80' 7009.64' 7007.74' 1.90' 7007,74' 5600.07'1407.67' 5600.07' 5350.85' 249.22' 5350.85' 5348.65' 2.20' 5348.65' 4110.92'1237.73' 4110.92' 80.31'4030.61' 80.31' 36.98' 43..33' 36.98' ~O.00 7053.03' Baker Model "G" Diff. Fill Shoe 1 Jt 9-5/8, 43,5, N-80 Buttress, Sb~S, New Baker "G" Diff. Fill-Up Collar 34 Jts 9-5/8, 43.5, N-80 Buttress SPAS, New 6 Jts 9-5/8, 40#, N-80 Buttress, SMLS, New HOWCO D.V.~Collar 30 Jts 9-5/8, 40#, N-80, BUttress, S~S-, New 102 Jts 9-5/8, 40#, J-55, Buttress, SMLS, New 1 Jt 9-5/8, 43.5#, N-B0, Buttress, SMLS, New Landed below rotary table 174 Jts Nippled down and set 9-5/8" casing slips. Nippled up and ran in hole with 8-1/2" bit. Drilled out DV collar @ 5353', closed pipe rams, and pressure tested to 1000# - OK. Ran to bottom and displaced mud in hole with weighted Inlet water (68.5#/cu ft) Pulled out and rigged up SChlumberger. Ran Gamma-Ray Correlation Log and Cement Bond Log. CBL indicates no bond. Perforated 'interval 6904-6919' with 4 shots per ft using 4" carrier guns. .Ran in hole with HOWCO DST tool and set packer'. @ 6834'. Opened tool and had gas-.to 'surface in 5 mins. Closed tool for 90 mins. Reopened tool and had fluid to surface in 1-1/2 hours. Flowed 55 BF in 7 hOurs (90-98% oil), surface pressure varying from 0-135 psi. Closed tool in to obtain FCIP. Obtained 3 hour FCIP. Pulled out of hole and broke down test tools. IHP-3033#, IFP-966#, ICIP-2792#, FFP-966-2696#, FCIP-2744#, FHP-3033#. Ran in hole with HOWCO cement retainer and set same @ 6875'. .Mixed and pumped 50'sacks regular class "G"'cement. Pumped 50 cuft cement to form when DP pressure broke from 3200# to 1600#, and bled off to 800#. Maintained 1600# on.annulus. Pulled out of retainer and picked DP up to 6863'.. Backscuttled and-recovered approximately 5 sacks cement. Pulled out'o'f hole. and rigged~up Schlumberger. Ran in hOle with Schlumberger's 4".carrier gun. perfo'rated intervals 6760-6840' with 4 Shots per..foot.~ ~Rigged down'Schlumberger. Ran in hole with HOWCO ~ DST tool; .-Set.packer.@~6705.''. .Opened tool for 5.mins with good blow. '--.Closed tooll for 90'mins '.t° °btain~ICIP..-, Reopened tool with strong blow. "-Had'~!g~s-itd: ~rface in'3 h°ufs-:~iO~/~ins~ 'i ..No fluid to surface in 4-3/4 ~hrs. :-. "' .OIL'.CO. OF CALIFORNIA -'-"-:..- '-' '-;;~,-:"i-;'-::... ,"- -~ -DRILLING RECORD. . PAgE NO.. LEASE:-.. Trading Bay state . :i.: .,-~./-.;'- '~.I~rELL'.NO-' A.~I0 FIELD ..' Trading 'Bay , DATE E.T.D. · DETAILS OF OPERATIONS, DEMCRIPT'IONS & RESULTS I~5-68 6750 5. 6750 6 6750 · .-. . ShEeT D Continued with.second open flow period. Closed tool after total o'f 8 hfs flow. No fluid to surface. Blow continued steady throughout open. period (6-Spsi surface pressure). While obtaining FCIP reversed tool and recovered 35 bbl water (64#/cu ft and 39,000 ppm chloride) Water was slightly gas cut with very faint trace of oil. Obtained 3 hr FCIP, pulled tool loose, and pulled out of hole. Broke do~m test tools. IHP-2985#, IFP-145#, ICIP-2648#, FFP-145-1062~, FCIP-2648#, FHP-2985#. Ran in hole with HOWCO cement retainer and set same @ 6750'. Mixed and pumped 50~sacks regular class "G" cement. Spotted cement to top of retainer and closed tool. Pumped cement to perfs. 6760-6840'.. While displacing cement, pressure.increased from 3750# to 4250# and held @ 425·0# after squeezing 62.5 cuft cement. Pulled. out of retainer and backscuttled with no cement returns. Pulled out of hole, changed to 2-7/8"'tubing rams and rigged up to run tubigg. Began running tubing. · Ran 208 joints 2-7/8" 6.4# N-80 Armco Seal Lock tubing with jewelry. Bottom of tubing @ 6560' with Baker Model F-1 packer @ 6489'. Set tubing hanger and removed BOPE. Installed X-mas tree and tested hanger seal to 3000# for 15 mins. Displaced salt water in hole with diesel using 484 bbls diesel. Dropped ball and set packer with 2000#. Held for 10 mins - OK. Released pressure and rigged up Schlumberger. Perf- orated interval 6600-6740' with 4 shots per foot using 2" scallop guns. Surface pressure to 350 psi @ completion of perf. job. Rigged down Schlumberger and turned well to producing into well-clean fan @ 12:30 PPi. Produced 73 BO, 3% cut with 28.·9°API gravity in first 11-1/2 hrs. 6560;31-6559.86 6559.86-6559.'36 6559.36-6556.19 6556.19-6525~27 6525.27-6524.17 6524.17-6493.20 -0.45 0.50 3.17 30.92 1.10 30.97 7.92' 6493.20-6485.28 3.17 31.04 5.59 1245.81 5.59 1335.85 5.59 . ·1738.21 5.59 1810.15 2.25 3.O0 3.15 249.14 3.15 1,00 6485.28-6482.11 6482.11-6451.07 6451.07-6445.48 6445.48-5199.67 5199.67-5194.08 .5194.08-3858.23 3858.23'3852 ~,4 3852 ~ 4-2114.43 2114.43-2108.84 2108.84- 298.69 298.69- 296.44 296.44- 293.44 294.44- 290.29 290.29- 41.15 41.15- 38.00 38.00- 37.00 37.00- 0.00 RELEASED RIG @' 3:00 PM 1-6-68. 2--7/8" Tubing Detail 2-7/8" 8rd Collar Baker Shear Sub 2-7/8" 8rdx2-7/8" Seal Lock Tubing Pup 1 Jt 2-7/8" 6.4# N-80 Seal Lock Tubing Otis Type X L.N. 2.313 ID 1 Jt 2-7/~" 6.4# N-80 Seal Lock Tubing Baker F-1 H.S. 2-7/8" x' 9-5/8" Packer 2-7/8" 8rd x 2-7/8" Seal Lock Tubing Pup 1 Jt 2-7/8" 6.4# N-80 Seal Lock Tubing Otis CX G.L. Mandrel 40 Jts 2-7/8" 6.4# N-80 Seal Lock Tubing Otis CX G.L, Mandrel 43 Jts 2-7f8" 6.4# N-80 Seal Lock TUbing Otis CX G.L. Mandrel 56 Jts 2-7/8"'6.4# N-80 Seal Lock Tubing Otis CX G.L,. Mandrel ~58Jts-2-7/8" 6,4# N-80 Seal Lock Tubing. - Otis Ball Valve L.N..- Fl°w Coupling .... ':' 217/8".8rd x'-:~'7/8": SeaI LOCk':Tubing Pup -18' jts 2-7/8" 6.4#,..N'80 Seal Lock'-TUbing 2,7/8,8rd. X. 2-7/8'' Seal Lock'Tubing Pup --.-. · ..... Shaffer,.Type 59A Tubing Hanger - · ' Landed belOw zero 208 Jts -~ '.:~ .. "' . · .. , 6560.31 :: ~,,,~,~-u;s'.^. .'.--.-:.~'f:-" ""~ION OIL CO]'fipANY OF CALI~""*"~!A" ~.''...-.':"~... - ...... . '.:..::.-.-.. :.:-' .: ,. .-.- ..... . ,~. :cORE'-RECORD ~:?:' .'v:' ~.:'. :" ::':":" '..:'...~ .", '.. }.' ':'.:. :.:~ ..:"-,':.' '.::: ~.':?::~: :. ? :-::.:":.-.'~ ::"., : .... ~-' .... -.-.. ~ '-.' i'- '~.':' ~ -. ' ' ': .' '~ ' ' . : -:" . - - :"'~.-..'~ - .'-':. ' - :~.... . . :. -':Z- .:'-.- ,' . ~ .' .' - :-' , :' ' .... " ' . ' . . '- - '.~ ' .' ' ' · - - ': ' ' : ':.-' ' . ' , ' ~' ' - ~ ~ .~ ~ .......... ~,'.'... " ~.'.':_-'"':- - "": '"' :" :::~: :."." '~':-e:~.' ~>m~ ' - "' I"~'"1-~*~. / .... . -' . , - ., I I ..... Y/EL ELEVATIO: Z ELEVATiO! ~--A P P 'T ~AN-? ..~' i'": '.;':: ";.'i:-."~ :.." ' ':i.'; '" : ,:..':.'.h.'._ :': .j..;':.~i"; ...... :~ ' ":.':; -:.: :'- ,. ".'" ,' :":i"':.: "]'" :'".: i~.,: ," :;, '.~ : '" "'/ .... /~., . .,.. . ; .. _-, -- ;:.._-.: .,,,:j..'::'. .... "';-':.:i: ~::;.-;.:' · "- -- ~ .... ,-.. ~ . / . · r / . ,;..~ .... .j . / ,_,.,-, ...... .'-"-":-:-' ~" :':'- -.~,L~:.~ % '. :'i~"~"'4"-,': ,~/~.:z~.>'"'.' ' ' :....:.': '-...'--'-..,C0'~^,,o~ ~--:,~ ~- ~,~,,,,~,o~ · · ... ... DESCRIPTION OF CORE. . DRILLER I S!ZE & TYPE FROM BARREL TOTAL OIL SAND .. GRAY' S ' D£ScRIPTIoH OF COR~' ELEVATI O.~ ~(i-.,..~-.'.?. _-.' .-':..:::: :..:':'--:.'.-i-...:.:.',:'::. i':":~: 71 :.'-' %,.i.' ,:: ,'" :c o R . :!""~:"""' :''//"'s~:~,,.,~;"~:': "~'"~,.~ '":'- ." :' -~.//~.,~.o/~..:::":' --;:" '~::: "::: :'"~'~'~":k'~' '''''::~" ':': '-:: '"';~" '" ' 1 ~-.~,~., ,, '~--~. ~~ ;'-:' ''- ~" ~" :" ": "" "'~'"' "'~s~'"'"" ": :'~/-'~':'- ~ ' ' - ' '' ' FIELD ' ' , ~' COMPANY ' E , ,V/ELL ~..."-' :-' ."'"-:-: "· -. '- ~ . '- ' : '-~. : - ~ . .'~ ' .' .' .' .' ".-:~ ~,3 ~ ............. ' GRAY. ' ' ' - · DRILLER ' I TOTAL ' OIL' SHE L DESCRIPTION.' OF CORE ' DATE SIZE e TYPE FROM TO ' REC'RY SHALE SAND S~ND. L ~ . ~A~.~ , - I -" /"° "" ' ' ~~ ' ~~ 'r EcTI NAL D LING. CORP' ,,,,~ ~8 Ne:,.~,,'Street · Santa Ana, California 92701. < SHEET' NO.' ~ COMI~ANY UNION 0IL C0~A]~ .... , ..... , ' _,ADDmESS' ~ ARY 1968 ~,' WELL ~_~ATE ..... A-10, L~ATiON . TRAD!N~.,'BA ', "'CouNT.Y .- ~A~ .. DIPTH ~NGTH, ANGL~ ' COURSE TO AL DEViATIO~ J,~ .... ~~ ~TURE , LATITUDE DEPARTURE 1106 ~26 00, ' 1071~ 98' 65i 32 S 65 W ~ ~ 1318 . ~25 30 . 1262 3~ ~9~ ~: 6~ , , ' ~ ~ ~' 1~0 3~.' , ~ 26~ 20 [8~o ~ ~t 23 30 17~0 ~, 70 9~' S 66 W j 2[~ 8: ~5~ 20 I~39 ..... [23~ ~5 1831 o~ 39 87 s 67 ~ 23~ 3~ ~9 90 2190 J 2~ '2~0 3~ ~08 S 68 W I ~ ~:'- " ' ' ' ~ , ,.' ~C ' ' ' ' ' ...... ' ' '~' ' "' .... " ' ' ' ' '" '; '" "' '" ' '"' ' "' ' ' ' " i~~~~,~_~': ALACAL DIRECTIONAL DRILLING CORP. ~,~~" 888 No. Main Street· Santa Aha, California 92701 COMPANY UNION 0IL CO}~PANY . ADD.ESs_ JOB NO,~ SHEET NO. ~/~ · ANU~RY 1968 ..WELL~q~ A.~FI~ _A:-10 ' , .... LOCATION. I~I]~ATJT~J~_~. ]~ AT, ~EAIU~gD DEVIATION VERTICAL DE~H couRs[ DIRECTION O~ ~P~ ANGLE COURSE TOTAL DEVIATION DEVIATION .... COUNTY~ LATITUDE DI[i~ARTUR£ ' LATITUDE NORTH DEPAR' 2801 2616 2860 35~2 3 ~o05 /*267 /,606 /*688' [911 50O/* 5159 5287 5325 5355 TYPE O!~'. SURVEY:_ ' .... CALCULATED BY · .CHECKED BY,, ..~" ~".-,~ ~.~,~,;:. ' : · . ... ' · ALACAL' DIRECTi AL DRILLI . ORP. . Jcw NO.-' · _ _~ ' ~.".~-~'~:"" '" ' CalifOrnia 92'70[ .. · , . . . 888 No. Main Street · .SantaAna, '~'.. ".'..' - ' . , . WELL ~AT~ A- 10 LOCAT,ON ' ~ADING BAY. COUNTY ' ~NAI '~.., , .. ;. j. ~: - ., ;-, , . , , .... , ~ ~<L , .... , ,~'~ , , r; ..... ,, ~, , ', , , j ·, , , '.~ .... _ MEAIURED[ COURll ~ ~.ViATioN ~' '~ER'T~C'AL DE~H tOuRs. DIRECTION ',,~ . -. '.__ CQ?~SE. '. : .... 'L~' :-: :"~ ' : '. ToTAL ......... -- ' "' DIpTN ~ ~NGTH~ ~ ....... OF ]~ LATITUDE ~ DEPARTURE - " LATIYUOE ' ' DEPARtUrE : ~ ANGLE · . COURSE ~ TOTAL DEVIATION, DEVIATION {~ No.T~'- ~'i ~T '/ ' W~T ~~ ' ............ ~, . ,...j , , , . : . _ _--_ ~ ~ , . , , , . ___ -~ .., : . .- .... , :_ . ORTH ; ~OUTH EAST . j WE~T i 515 78 " ~' 1945 76 5987-:60~ t[1513 15 30' -' '~.5626557I'216~-- !~1331~7 I~883_w85 W' i, ~ _; .[ ~. ':-'~~- ~'~ 516518 ~'20' ~ '~ 1987:67t97~ ~6 ,. ' , ' '~ 518 87 199& 15 610.6 1130. .568? 29.~ 638 S 89 W ~ ~ ~ - ~ 518 98, ' . 200'0.,53 6138.: ' : ~' '10'30:~ ' ' ~ : ' ":8~ 5 83 S 89 ~W . ~ . . ': . "~ ~519'~ 620 5?80 6&2.6, 6 00~. 600& 31 1 518 - ~ - ~ - .. ~ . - . ~ ~ _ , .... 659o.t: 2 0° 6~68 05 1 08 8 68 W: ~ 52O 6623 .1~ ~5; 6201 03 1 O1 S 85... W ~ .520 95 2052 ~9 " . . ' " ::' ' 6683.' J '2~15. 62.60 98 · 2 36 N'.:. :85 jW t' ,, {~ · ;.. -' ' ,,.~' , ~ ,~ ' .... ' ,,'.f" - ' ' .a, . '. - ' .... " -- ~,~, ,' . ' - ,, , ".. , ' ~ .. ' , · , .'~ ~ , - ~ , ' ..... , ~, ., , , , ", ~ : ' ," ," , ' TYPE O'P SURV£Y: CALCULATED 'BY , , CHECKED BY,, ~~.~,~-::(:~;., ALACAL DIRECTIONAL DRILLIN~ CORP. / ".,~' 888 No. Main Street · Santa Aha, California 92701 cO.pANv.... ~ION OIL, 00~~ , M I[~URIO DEVIATION VE~¥1CAL. DEf"TH cou~ DIRECTION OF' DIEPTi. I' ANGI.f COUR~I~ TOTAl. DEVIATION DE,V:IATION 67&0 6317 COURSE "'"' ' ": ' LATI TU Dm' .JOB s.m' .o. ,, · ANI~ART 1968 . - ,,~. _~_ . ,LATITUDE DEPARTUR NORTH IEA~T 69 o 6/,83 6517 6610', .66501 TYPE Olr SURVEY:, ,,?, ,,,,,, :. CALCULATED ,BY '~': CHECKED : ,6£ '890~ ',~ ,£6'i~1S 'S 'G 7~,0Z'0£ 99 '(] 'Pi £ Z0Z t~lSOIt/ ' /ID8 bu!poJ.L 'Jl"l~'0 =10 ~kN~'cllhlOO -IlO NOINfl UNION OIL CO. OF CALIFORNIA ALASKA DISTRICT Transmittal TO: State of Alaska DATE. 1/12/,,,65 FROM: Union Oil CompanM__ .... WELL NAME: . Trading_BaY State Transmitted herewith are the following- Run No. Sepia Blue Scale Induction EleCtrical Log Dual Induction Laterolog BrIC Sonic/Caliper Log BHC Sonic/Gamma Ray BHC Sonic/ Caliper/Gamma Ray Log Formation Sonic Log (Fs) Density-GaMma Log Formation Density Log (Fd) Neutron Log Formation Neutron Log (Fn) CDM or High Resolution Dipmeter CDM Safety Print CDM or Printout CDH or Polywog Plot CDM PolaT'.Plots Proximity-Microlog/Caliper Log Gamma Ray-Neutron Log Gamma Ray Collar Log Cement Bond Log bMdlog Core Descriptions,-Conventional, No. _ Core Descriptions, Sidewall Core Analysis Core Chip% Core #2 (6700), Cor~ #3 {6740, 6741, 6756.S, 6757, 6758) Sample Cut Core #4 (6819, 6820} Drill Stem Test Directional Surveys Receipt acknowledged' ~~ ~ Date: /-'/ ~'~" 'C" Return receipt to- Union Oil Co. Of California, 2805 Denal~ St. Anchorage, Alaska 99503 Ferm No. 1=--4 REV. 9-30-$7 STATE O,F ALASKA O~L AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF ~DRILLING AND WORKOVER OPERATIONS SUBMIT IN DEPLICATE ~. AP~ NUA~ERICAL CODE 50-133-20064 6. LEASE DESIGNATION AND SERIAL NO. ADL-18751 7. IF INDIAN, ALOTTEE OLq TRIBE NAME 0ZL ~ 0*S ,~ WELL WELL 0TriER 507 West Northern Lights Boulevard LOCA~ON OF WELL 1609'N ~ 571'W fr. SE corner, Section 4 T9N,' R13W, SM 2. NA/VIE OF OPERATOR Union Oil Company of California 3. 'AD,DRESS OF OPEI:~ATOR 8. I/NIT,FA/~M OR LEASE NA_ME Trading Bay State 9. WELL NO. A-10 10. FIELD AND POOL, OR WILDCAT Trading Bay, Hemlock Pool 11. SEC., T., R., 1%~., (BO~FOM HOLE OBJECTIVE) Section 4, T9N, R13W, SM 12. PER.MIT NO. 67 -76 13. REPORT TOTAL DKPTH AT END OF MONTH, CI-IA_NGES IN HOLE SI~E, CASING A-ND C~-~ViENTING JOBS INCLUDING DEPTH SET A/VD VOLU1VIES USED, PERFORATIONS, TESTS A!N-D RESULTS. FISHING JOBS, JUNK IN HOLE A/~D SIDE-TRACKED HOLE ANT) A2~Y OTHER SIGNIFICANT CHA/~ES IN HOI~ COI~DITIONS. TRADING BAY STATE A-10, DECEMBER 1967 7075' drilled. Spud 12/5/67 '. Drilled 12-1/4" directional hole to 1106'. Opened hole to 17-1/2'~ Cemented 13-3/8" casing @ 1095' w/1200 sx class "G" cement. Drilled 12-1/4" hole to 6696'. Cored 6696-6698, 6740-6759, 6819-6831. Ran Schlmaberger DiL, ~RD, Sonic, BHC Sonic. Now running SNP RECEIVED ANCHORAGF: smmm ,_,._iD_ MeMahan U~L~ Dist. Dril,,ling. Superinimd~ 1-8-68 ! NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. ~ OXX-~ of c.,aX~ ~~ XS your for r~e ~ e~pt~ ~e Form P--3 "*"AT?'''~; ALASKA SVBMIT (Other lnst~ .on~ r~ OIL AND GAS CONseRVATION COMMITTEE verse ~ide) SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back t° a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) 1. OiL /] GAS [] WELL WELL OTHER 2. NAME OF OPERATOR Union Oil Company of California Effective: July 1, 1964 5. LEASE OESIONATION ANn sE'RIAL NO. ADL 18731 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT.AGREEMENT NAME 8. FARM OR LEASE NAME ADDRESS OF OPERATOR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 Trading Bay state 9. w~ NO. A-10 C24-4) . ,4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surfece 14. PERMIT NO. 67-76 1609' N & 571' W froTM SE corner, Sec. 4, TgN, R13W, SM 15. E~VATIONs (Show whether DF, ST, OE, e~) 101' R.T, above MSLW 10. FIELD AND POOL~ OR WILDCAT ?rading Bay Nield , Hemlock 11. SEC;, ~r.,.S;, M., OR BLK', 'AND RURVE~ .OR AREA Sec.-4, T9N, R13W, SM 12. BOROUGH /18. STATE :enai Peninsul~ ,, "Alaska~ 16. Check Appropriate Box To Indicate Nature o1~ Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBEEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING' WELL FRACTURE TREATMENT ALTERING SHOOTING OR ACIDIZINO ABANDONMENT* (Other) NOTE: Report results of multiple completion on Well ompletton or Recompletion Report and Log form';) ~ 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, Rive subsurface lo~ations and measured and true vertical depths for allmarkers and zones perti- nent to this work,) * The bottom hole location for this well was programmed for a Hemlock CompletiOn -And the SW quarter of Sec. 4, TgN, R13W, SM. The bottom hole is being adjusted to compensate for geologic and mechanical difficulties. This will be the second Hemlock well in the SE quarter of Sec. 4, TgN, R13Wa SM and is consistent with 80 acre spacing. The bottom of the hOle Will be approximately 2060' W and 630' S from the surface location. RECEIVED . DIVISION OF MINES & MINERALB ANCHORAGE- . 18. I hereby certify that the foregoing ~ true and correct SIGNED . D, . fi. U.' ~cManan TITLEDiSt. Drilling SuperintendentvATE Dec. 26, 1967 -, (This space for Federal or Stat~ ofllce_uJe) CONDITIONS OF APPROVAL, IF AH: TITLE *See Instructions on Reverse Side FORM SA - I B · 12$.SM 8J67 "'""~ ~ ,-~"~, ~ /~' ~ ~MEMORANDUM TO: J--~ FROM: state of Alaska DATE : ~jjljljljJllJj~ ~ ~ SUBJECT: 125.5M 8/67 /'~ MEMORANDUM TO:F ~ ~ :~j]jj~ State of Alaska DATE SU BJ ECT :~~JJ~ljjj~ ~ Form P--I REV. 9~30-67 STATE O,F. ALASKA SUBMIT . .,TE (Other instr~ .... s on reverse side) OIL AND GAS CONSERVATION ,COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK 1~[. TYPE OF WORK 2. NAME OF OPEP, akTOR Union 0il Company of California 3.ADDRESS O~ OPERATOR 2805 Denali Street, Anchorage, Alaska 99503 DEEPEN l-1 PLUG BACK J-] ZONE ZONE 4. LOCATION O,F WELL At surface 1609' N & 571' W from SE corner, Sec. 4, T9N, R13W S.M. At propesed prod. zone Top Hemlock - 945' N & 2240' E. from SW'corner Sec. 4, TgN, R13W, S.M. $. 6. LEA~E DESIGNATION ~ SgRIAL NO. ADL 18751 ?. IF INDI~, AJ_J.K)TTE~ OR TRIB~ NAM~ 8. UNIT~ FARlVI OR LEA~E NANiE Trading Bay State 9. WELL NO. A-10 (24-4) 10. FIELD AND POOL, OR WILDCAT - em Trading Bay Field ~oo~°Ck 11. SEC.-, T., R., M., (BOTTO1V[ HOLE OBJECTIVE) Sec. 4, T9N, R13W, S.M. 13. DISTANCE IN MILES AND DIRECTION F.~O:M· NEAREST _TOWN OR.POST OFFICE* 12. Approx. 27 miles NW of Kenai, Alaska 14. BOND INFORMATION: TYPE Statewide Surety and/or No. Bond No. 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPE-~TY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) , 18. DISTANCE FROM PROPOSED LOCATION* United Pacific Insurance Company B-73310 i l6. NO. OF ACRES IN LEASE 000' j 3,840- ' 1, I J lg. PROPOSED DEPTH [: %So, 6 6o, vo TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT, 4,300 ' 21. ELEVATIONS (Show whether DF, R.T, C-R, .etc.) 101' R.T. above M.S.L. 23. ' FItOPOSED CASING AND CEMENTING PROGRAM ,~.mo--~ $150,000.00 '17. NO. ACRES'ASSIGNED TO THiS WELL 80 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START* December 1, 196'7 SIZE OF HOLE [ SIZE OF CASING WEIGH~PER F°OT GRAI~E I{ 'sETTING DEpT~i ' : QUANTITY OF CEMEN~ 17½'" 13-3/8":: ~' 61#' ' ClaSS-G 1080 "" -' [ 1200 Sx. 12~" 9-5/8" .40~ 6 43.5~ " 7850 lSO0 Sx. , . Drill 17½" directional hole to 1100'. Run and cement to surface 15-5/8" 61# casing. Install 12" 3000# double hydraulic gate and-Hydrii. Drill 12¼" direttional hole to 7830'. Run electMic logs. Run: and cement' 9-5/8" casing by electric log determination. Perforate and put well on production. IN ABOVE SPA~C'~ DESCRIBE PROPOSED PROGRA1VI: If proposal is to deepen or plug back, give data on present productive zone and propos~d new productive zo~e. If Pr(~posal is to drill or deepen dire~t~onally, give pertinent data on s~bsurface locations and measured and true vertical depths. Give bl~O~owout preventer program. / ...~ .....<~; ...... c .~< . Landman ~~~,'~--.~ ~c///~~~ November 27, 1967 S!G , _ TITLE (This space for ~tate office Use) ISAMPLES AND CORE CHIPS RF,~UIi~ [] YES ~ NO DIlq. ECTIONAL SURVEY I~EQ~ 5~,YES [] NO CONDITIONS OF APPROVAL, IF Ali-Y: J~ REQUIREMENTS: A.P.I. NYJ1VIERICAL CODE APPROVED By_.[~w ~"? ~~/. ~I 50-133-20064 APPROVAL DATE THOMAS R. MARSHALL, '~1~ Executive Secretary as,, ,~,onservat~on Committee DATE DIVISION OF MINES a MINERALS /~NCHORAGE ,32 J7 9 J~ UNION W.T.B. STATE~ I UNION T.B. :#=2 t A-90 t ' I I I I I A-6 I I O~, % ~A- I \\"~-A / \ I UNION I [O A-5 I I I /---TRADING BAY UNIT I J~ TEXACO T.B. # I .34 .3 JO UNION-MARATHON ADL - 18751 JO J~ T I0 N JJ UNION E.T.B. STATE ~1 T 9 N UNION-MARATHON jj ADL--,759e R 1.3 W UNION OIL COMPANY OF CALIFORNIA ALASKA DISTRICT LOCATION MAP TRADING BAY STATE A-lO (24-4) DATE: SCALE: I"= 2000'
