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100-146
STATE OF ALASKA ALASKA OIL ANn GAS CTINRFR\/ATlnnl rnftAftAICCIn AI �.., k v �✓ r a 'q L- l. SEP 2 C -trig --- --- --..__..-, I—- V.. P..,....,..,,.-... WELL COMPLETION OR RECOMPLETION REPORT ANDa 1a. Well Status: Oil ❑ Gas SPLUG Other Abandoned ❑ ❑ ❑ Suspended❑ 20AAc 25,105 20AAc 25110 GINJ ❑ WINJ ❑ WAG[] WDSPL ❑ No. of Completions: 2. Operator Name: 6. Date Comp., Susp., or Hilcorp Alaska, LLC Abend. 8/26/2019 16. Well Class: Development Q Exploratory ❑ Service ❑ Stratigraphic Test ❑ 14. Permit to Drill Number/ Sundry: - 100-146/319-139 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date -Spudded: 3/29/1959 15. API Number: - 50-133-10145-01-00 4a. Location of Well (Governmental Section): Surface: 150' FSL & 1511' FEL, Sec. 16, T8N, R9W, SM Top of Productive Interval: Total Depth: 150' FSL & 949' FWL, Sec. 15, T8N, Rj9W, SM • 8. Date TD Reached: 6/9/1959 16. Well Name and Number: Swanson River Unit (SRU) 14-15 , 9. Ref Elevations: KB: 15.3' 17. GL: BF: Field / Pool(s): Swanson River Hemlock Oil / Tyonek Gas 10. Plug Back Depth MD/TVD: 18. O' MD / O' TVD Property Designation: FEDA028406 • 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 346160.2 y- 2477488.4 Zone- 4 TPI: x- y- Zone- 4 Total Depth: x- 348662.0 y- 2477419.3 Zone- 4 11. Total Depth MD/TVD: 19. • 11,460' MD / 11,015' TVD DNR Approval Number: N/A 12. SSSV Depth MD/ TVD: 20. N/A 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: 21. N/A (ft MSL) Re-drill/Lateral Top Window MD/TVD: N/A 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 N/A 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT GRADE TOP BOTTOM TOP BOTTOM PULLED 22" Surf 44' Surf 44' 13-3/8" 54.5 J-55 Surf 2,967' S 2,967' 7^ 26 29 32 35 38 N-80 Surf 11,449 Surfurf 11,005' 24. Open to production or injection? Yes ❑ No Q If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): , I ��� VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) N/A N/A N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes D No Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, Date of Test: N/A 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 e Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity- API (corr): Form 10-407 Revised 5/2017�ll ��-/� //ZG �`NTINUED ON PAGE 2 F1BDMS ±OCT 0 91019 Submit ORIGINIAL on ff'r Swanson River Field SCHEMATIC Well #SRU 14-15 Hilrorn Aloxka, LLC. RKB to TBG Head = 15.30' CASING AND TUBING DETAIL Tree connection: TC -3 Uni-bolt SIZE WT GRADE CONN TOP BTM 2600' sgzd holes 3500' 5 shots Boc 3500' CBL 516V Tac @ 3800' ali , C k 1lb q�1,41`t Fish-27'of5 sections ofstnp ,as 1280/15 ,,sd holes 8500' 4 shots Cale TOC in C..aB @ 10574' a Pesch @ 154'-159' 2 307" 3 SZ`I0 4 ?" 618" 5 6 7 8 T 51-0 51-5 L 53 55-5 56-9 59.2 11 12 = 62-5 62-5 = 68-0 13 14 15 28 25 24 27 Cale TOC in Tubing @ 10681' PBTD = 0' / TD = 11,460' MAX HOLE ANGLE =25°, KOP @ 3800' NO. Depth Item 1 160' CIBP w/ 160' cement to surface 4/17/19 22" 3,077' CIBP w/ 35' cement -TOC 3,040' 4/17/19 3 Surf 44' 13-3/8" 54.5 J-55 5 Surf 2,967' 7" 38 N-80 8rd LT&C Surf 34' 7" 32 N-80 8rd LT&C 34' 1,030' 7" 29 N-80 8rd LT&C 1030' 2,276' 7" 26 N-80 8rd LT&C 2276' 5,718' 7" 29 N-80 8rd LT&C 5718' 7,367' 7" 32 N-80 8rd LT&C 7367' 8,789' 7" 35 N-80 I 8rd LT&C 8789' 10,432' 7" 38 1 N-80 I 8rd LT&C 10432' 11,449' Tubing: 10,900' 2-7/8" Baker cmt retainer 2311,096' Camco MM GLM #12 w/dummy 2-3/8" 4.6 N-80 Buttress Surf 5,310' 26 with 3/8" SS methanol injection line Surf 2,506' NO. Depth Item 1 160' CIBP w/ 160' cement to surface 4/17/19 2 3,077' CIBP w/ 35' cement -TOC 3,040' 4/17/19 3 5,240' CIBP w/75'cement -TOC 5,165'4/15/19 4 5,237 Top m 2-3/8" tubing stub 4/12/19 5 5,246' Bake------------ Assy. size 40-26 6 5,250' Baker Model "DB" Retainer Production packer, 7" 29#, DPM 7 5,264' SBE, XO to 2-%", 4.6#, Butt 8 5,310' WLEG 9 6,340' CIBP w/37'cement 11/10/17 -TOC 6,303' 10 6,410' CIBP w/35'cement 09/10/17 -TOC 6,375' 11 6,574' PosiSet Plug w/ 10' of cement 12 6,700' PosiSet Plug w/ 10' of cement 13 8,300' Bridge Plug in 7" casing, 6/20/01 w/ T - OC 8,053' 14 8,313' Milled up pkr fish. 15 8,442' Bridge Plug in 7" casing, 11/8/96 16 9,890' 2-7/8" Tubing cut, 10/21/96 17 1a,00r- 0,012' Holes in tbg 18 10,125' Camco MM GLM 410 w/dummy 19 10,574' Calc TOCin annulus 20 10,594' Camco MM GLM #11 w/dummy 21 10,681' Calc TOC in tbg 22 10,900' 2-7/8" Baker cmt retainer 2311,096' Camco MM GLM #12 w/dummy 24 11,137' 2-7/8" Baker cmt retainer 25 11,148' Brown HS -16-1 retr packer 26 11,212' Camco MM GLM#13 w/CEV 27 11,0' Baker Model packer 28 11,28240' Bridge plug DRAWN BY: TAB Updated by DMA: 09-06-19 28. CORE DATA Conventional Core(s): Yes ❑ No ❑✓ Sidewall Cores: Yes ❑ No 0 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 Q If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation at total depth: 31. List of Attachments: Operations Summary, Schematic, MIT -IA, Photo document casing cut-off/cement top/welded plate. 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. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Bo York 907-777-8345 Contact Name: Ted Kramer, Operations Engineer Authorized Title: Operations Manager Contact Email: tkramerohilcoro com Authorized r-- / Contact Phone: 907-777-8420 Signature: ��a�'/ Date: 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 reportedin 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: core analysis, paleontological report, production or well test results. Form 10-40/ Revised 5/2017 Submit ORIGINAL Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 14-15 50-133-10145-01 100-146 4/11/19 1 8/26/19 Daily Operations: 04/11/2019 - Thursday PTW, hold safety meeting and review 1SA's. Carolina mats arrived on location. Pull up pit liner and lay down matting boards. String pit liner over matting boards. Back in carrier, Koomey, pits, choke skid. Continue to rig up HAK 401. Road and pad only allow one trailer load at a time. 04/12/2019 - Friday PJSM, Start equipment. Location walk around completed. Pollard E -line on location. Spot up to well. CIBP setting tool missing. PESI supervisor headed for shop for tool. Rig up Mud lines to IA and fill back side of tubing. 175 bbls pumped to fluid pack backside. Make up 2.375" CIBP. RIH. Stop at WLEG and log OOH to get CIBP on depth. Attempt to set CIBP at 5239'. After attempted set E -line picked up and RIH for a tag. CIBP was not at set depth. POOH to surface. CIBP firing pin bent. Make up new 2.375" CIBP. RIH and log pass. ON depth. Set CIBP at 5,239'. POOH to surface. Make up 2.375" Tubing jet cutter. RIH . Tag CIBP at 5,239'. Pick up 5,234.3' CCL depth puts tubing cut at 5,237'. POOH . Confirmed jet cutter was spent. Rig down E -line. Circulate down IA and up tubing to fluid pack wellbore. Pressure test 7" casing to 2,500 Dsi for 30 minutes and chart. Good test. Set BPV in tubing hanger. Nipple down production tree. Nipple up 7" BOPE stack, mud lines to choke and kill manifold. Function test all rams and valves. Rig up floor. 04/13/2019 -Saturday PJSM with AAO crew. Location walk around. Fire equipment. Make up test joint to hanger. Install TIW valve and I BOP. Attempt to close annular bag from 7" stack on 2.375" tubing. Have to Cycle bag multiple times to get element to engage pipe. During this cycling annular bag hydraulic valve failed. Opened 2" bull plug on side of hydraulic tank and visually confirmed valve leaking back into tank. Called mechanics. Send hot shot to Farm yard to pick up 4 way valve and top set of 2.375" dies for foster tongs. Mechanic is unsure of status of used valve. Send Hot shot to rig 169 to pick up new valve and rebuild kit. Move on to test pipe rams while awaiting 4 way valve for annular bag. While cycling pipe rams accumulator was running and building pressure as designed. Electric motor on hydraulic pump locked up and started smoking. Crews turned off at control switch on pump. Smoke continued until rig crew member threw the breaker and bang box. Called our rig mechanic. Dispatched Weaver Bros trucking to farm yard to pick up 404 accumulator unit. 404 Koomey unit arrive on location. Spot unit. Run hydraulic hoses. 404 koomey didn't come with Air line and manifold to run remote BOPE controls. Attempted to use 404 Koomey with 401 remote manifold. Air control panels will not match up. Mechanic called into assistant to locate 404 air manifold. Rig crews swapping 404 electric motor into 401 Koomey. Electric motor swap complete. Electricians rebuilding control switch contacts. Test electric motor. New control switch on order for Koomey unit. Prep for BOPE test in the AM. mise Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 14-15 50-133-10145-01 100-146 4/11/19 1 8/26/19 Daily Operations: 04/14/2019 -Sunday PJSM. Fire equipment. Left heater in Koomey unit throughout the night to keep hydraulics warm. Fire equipment. Location walkaround. Fill Pressure control equipment with water. Perform shell test look for leaks. 24 Hr BOPE test witness notification sent 4/10/19 @13:41. Witness waived by Jim Regg via email on 4/11/19 @ 0932. Start BOPE test. Test all rams and valves to 250/2,500 psi for 5 minutes and chart. Perform draw down test. BOPE test completed. Rig up high pressure hoses. Pull test join and BPV from tubing hanger. Close Blind rams. Circulate 200 bbls of 9.8 ppg brine. Make up pulling joint to hanger. Back out hanger lock down bolts. PU on hanger 28K break over. 25K free travel. Break out and lay down hanger and pup joints. Start tripping OOH with 2.375" tubing cut chemical injection line banding and spool on wooden drum. Rack back stands in derrick. 45 stands racked back (2,800'). Close annular bag and install TIW floor valve. Location walkaround complete. SDFN. - 04/15/2019 - Monday PJSM. Fire up rig. Location walkaround completed. WHP 0 psi, IA 0 psi. Lay down TIW valve. Trip OOH with tubing. Halliburton completions hand on location. Make up 7" CIBP and setting tool. Trip in hole with stands. Tag top of Packer at 5250'. Pick up to 5240' with top of CIBP. Rotate 35 times to the right. Pu to 31K and hold. Pick up to 41K and hold pick up to 48k and release from CIBP. RIH and tag CIBP to ensure set. Rig up Halliburton cementing crew. Hold SIMOPS safety meeting with AAO crew and Halliburton cementing crew. Pt cement lines 250/2500 psi. Cement wet at 14:30. Confirm cement 15.8 ppg. Pump 3 bbls of class G cement and chase with 17.5 bbis of water for displacement. Break down cement lines and TIW. Trip OOH 40 seconds per stand. Cement laid in. TOC should be 5165'. Cementers rigging down. Trip 2.375" tubing OOH. 500' racked back. Circulate bottoms up to clean tubing. 225 bbls pumped. Continue to trip tubing ooh rack back 50 stands for next cement job. Rig up Pipe racks, beaver slide and cat walk. 04/16/2019 -Tuesday PJSM. Location walk around. Fire equipment. Trip OOH with 2.375" tubing. Rack back 35 stands. 50 stands total racked back. Make up x over, setting tool and 7" CIBP. Fill 7" casing. Rig up test line and chart recorder. Pressure up 7" casing to CIBP and cement at 5240' and 5165' TOC. Chart Pt 2000 psi for 50 minutes. State witness test. Lou Laubenstien on location. Good PT. Bleed down. TIH with 7" CIBP. 48 stands and 1 single. Rotate 35 turns right to set 7" CIBP at 3,075' 16k free weight. PUII to 26K and wait 3 minutes. PU to 36K wait 3 minutes. PU to 40K and shear off 7" CIBP. Pull in Halliburton cement trucks. Trip OOH 500' above TOC. Circulate bottoms up. Rig up HES cementers. Hold SIMOPS safety meeting. RU cement line to TIW valve. Pump 5 bbls of fresh water ahead. Close in block valve and PT iron 250/3500 psi. Test pump kick outs. Mix up 9 bbls of 15.8 class G cement. Cement weight verified 15.9 ppg. Online with 9 bbls of cement (225' in 7"). Displace cement with 11.89 bbls of fresh water. Shut down, rig down cement trucks. Rig down TIW valve and Trip OOH with 48 stands and a single. Rig down cementers. Lay down tubing. OOH with 2.375" tubing. Prep for E -line in AM. qY Gt�v V- v< - Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Per Number Start Date End Date SRU 14-15 50-133-10145-01 100-146 4/11/19 8/26/19 Daily Operations: 04/17/2019- Wednesday PJSM. Fire equipment. Location walk around. E -line on location. SIMOPS. Rig up E -line. RIH to tag TOC 2,894'. Cement top is 27' low. Wait on cement kits to arrive. Make up dump bailer. RIH 5" x30' dump bailer and set 35' of cement ontop of cement plug. Set 7" CIBP at 160'. PU casing punch. Punch 7" casing from 152.5'-156 6' Attempt to circulate up the 7"x 13 3/8" casing. Pressure up to 800 psi. No communication. Trip in hole with 160' of 2.375" tubing. RU cementers. Safety meeting . Cement wet 1,700 15.8 ppg Pump 6 bbls class G cement. Trip OOH with tubing. Job complete. secure well. Rig down HES. 04/18/2019 - Thursday PJSM safety meeting. Rig down 401. Move rig to SCU 24313-04. 08/26/2019 - Monday BLM/AOGCC Inspectors onsite, upon verification of cured cement to surface the wells abandonment plate was welded in accordance with BLM/State of Alaska requirements. Swanson River Field SCHEMATIC Well #SRU 14-15 }lilrogi M.A., LLC PERFORATION nATA ZONE TOP BTM Top TVD Bottom TVD SPF DATE 3,500' 3,500' 3,500' 3,500' 5 06/20/59 51-0 5,382 5,392 5,347' 5,357' 6 12/30/18 5sqz 51-5 5,467' 5,484' 5,429' 5,445' 6 12/29/18 51-5 5,505' 5,543' 5,466' 5,502' 6 12/29/18 51-5 5,543' 5,550' 5,502' 5,509' 6 12/29/18 Isolated 53 5,907 5551' 5,853 5,896' 6 12/28/18 Isolated 55-5 61200' 6,210' 61135' 61145' 6 11/16/17 Isolated 56-9 61345' 61365' 6,273' 6,292' 6 09/19/17 Isolated 59-2 425' 6U11,224"11,231' 6,445' 6,349' 6,367' 4 08/10/01 Isolated 59-26;459' 6,371' 6,381' 4 08/10/01 Isolated 59-26,502' 6,410' 6,421' 4 07/29/01 Isolated 61-36,582' 6,466' 6,496' 4 07/18/01 Isolated 62-56,758' 6,635' 6,662' 4 070/8/01 Isolated 62-56,796' 6,686' 6,697' 4 07/08/01 Isolated 68-07,577' 7,306' 7,415' 4 07/04/01 Isolated 8,500' 8,260' 8,260' 4 06/17/59 sqz 11,231' 10,794' 10,800' 4 05/29/63 Abdn 11/91 Hemlock 11,262' 11,276 10,829' 10,842' 4 07/59, 02/61 Abdn 11/91 Hemlock 11,290' 1 11,300' 10,856' 10,865' 4 05/63 Abdn 11/91 DRAWN BY: TAB Updated by DMA: 09-06-19 SRU 14-15 Wellhead Removed/Cemented to Surface i dJ. ( JTZ ,t'y ty r( 111 �} 11 ��� � fid' �jr rAu� r �, dl y. c • ; • �� ,5 — 4000 UVB-- _ ? X A) i � A c � 1 CHART N0. MO I t MP-,5OpO-lHR METER f CHART PUT ON I '�� y I� III li' it it I III -. - TAKEN M LOCA TIpNSP(i /��� /— M tf\ REMnNY,; grir ,S�`( .0001' / V 10 m GmwLt Inc t�(ct_4NE Well S.R.U. 14-15 Plug & Abandon Memo Via email Date: 7/16/2019 To: Hilcorp Alaska LLC .................................................... Attn: Cole Bartlewski From: James A. Hall, PLS Project: Swanson River Unit — SRU 1415 Well Plug & Abandon Survey Re: Project Summary This memo represents the plug and abandon survey performed by McLane Consulting Inc. (McLane) for Hilcorp's Swanson River Unit SRU 14-15 well located in Section 16, Township 8 North, Range 9 West, Seward Meridian, Alaska. The survey was performed on July 3, 2019. The scope of work consisted of providing accurate field elevations so the well could be plugged and abandoned per State requirements. Existing survey control was recovered and positional accuracy was confirmed by comparing (2) check shots on hard targets to existing data. To establish original ground elevation near the well casing, (2) original ground survey measurements were observed at the perimeter of the pad in opposite positions from the well location. A prorated original ground elevation at the well was computed from the (2) pad perimeter original ground shots. A top of pad elevation was also recorded on or adjacent to the well casing. A measurement and an "X" to the proposed cutoff elevation was marked on the cellar. Enclosed is Exhibit A which includes well casing cutoff detail with pad, original ground, and proposed casing cutoff elevations. • Mean pad surface grade in vicinity of well casing: 257.4'± (2019) • Original ground elevation in vicinity of well casing: 256.4'± (2019) • Cutoff depth requirement: 3.0' below original ground elevation • Minimum casing cutoff elevation: 253.4 • Casing cutoff elevation as staked in field: 252.4' The cutoff mark elevation of 252.4', as referenced in the field, exceeds the required minimum cutoff elevation of 253.4. Please feel free to contact me if you have any questions or comments. Si n 7 rely, James A. Hall, PLS McLane Consulting, Inc. JAMES A. HALL P.O. Box 468 Soldotna, Alaska 99669 (907) 283-4218 Fax (907) 283-3265 Email jhall@mclanecg.com ORIGINAL GROUND SHOT ELEV.=256.6' (2019)x GRAVEL P Au O SRU 14-15 P&A ASP NAD83 ZONE 4 N: 2477222.5 E: 1486188.4 ELEV.=257.1' JAMES A. HALL 1) BASIS OF HORIZONTAL, NA083 US FEET POSITION (EPOCH 2010) AND VERTICAL CONTROL (NAVD88) IS AN OPUS SOLUTION FROM NGS STATIONS TBON, TSEA, AND ZAN1 TO ESTABLISH CP -15. THE ALASKA STATE PLANE COORDINATES NAD 83 ZONE4 ARE. N = 2480030.714 / E =1488857.995 / ELEV = 318.981 CnnsuLbN Inc NGINE 'W IMA NGI SMPING iTMNO P.0 BG e TN .B 9 vQC JW?, 8 218 FM (90))28]5285 EMAIL 8nMCtPNE@MCLWEC6.GOM GROUND SHOT 51' (2019) GRAPHIC SCALE 0 50 100 200 1 inch = 100 ft. WELL CASING CUT-OFF DETAIL WELL CASING — TO BE REMOVED PAD ELEV = 257.1' f _ __ _ _ O.G. ELEV _256.4' t 4.0' REFERENCED WELL CASING LFV r--_'�E= AT ELEV = 959.4' SWANSON RIVER UNIT a" 7118 19 WELL SRU 14-15 DMWNEY Bae PLUG AND ABANDON EXHIBIT -A 50P1E i- iw NAD 83, ASP ZONE 4 vROJEC�N1ivBOOK 1 NO 19-0] SECTION 16, TOWNSHIP 8 NORTH, RANGE 9 WEST, SEWARD MERIDIAN ALASKA MEMORANDUM TO: FROM: Jim Regg�� illegt`1 P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE Brian Bixby SUBJECT Petroleum Inspector August 281h 2019 Surface Abandon SRU 14-15 Hilcorp Alaska Inc. PTD 1001460; Sundry 319-139 8/26/2019: 1 arrived at Swanson River Field and met up with Mike Erstrom (Hilcorp Construction Foreman). We went to the well location and I verified there was good hard cement to surface and all the correct information was on the marker plate. The cut off is over 4 feet below grade. I also took pictures of the hard cement, marker plate, marker plate after welded on and the depth of the cutoff. Attachments: Photos (4) 2019-0826_Surface_Abandon_SRU_14-15_bb.docx Page 1 of 3 Surface Abandon — SRU 14-15 (PTD 1001460) Photos by AOGCC Inspector B. Bixby 8/26/2019 iht'fi ,gs o yq�Lg4 ♦r yi.,. f s�. t •,:'V, : z v >J n 2019-0826_Surface_Abandon_SRU_14-15_bb.docx Page 2 of 3 2019-0826_Surface_Abandon_SRU_ 14-15_bb. do cx Page 3 of 3 MEMORANDUM Founded on State of Alaska Depth To MW Above Alaska Oil and Gas Conservation Commission TO: Jim Re �J 41t�'1t9 5240 ft MD - DATE: April 16, 2019 p 9.8 ppg P.I. Supervisor 1\ �g 0 0 SUBJECT: Well Bore Plug & Abandonment SRU 14-15 FROM: Lou Laubenstein Hilcorp Alaska LLC Petroleum Inspector PTD 100-146; Sundry 319-139 Section: 16 Township: 8N Range: 9W Meridian: Seward Drilling Rig: N/A Rig Elevation: N/A Total Depth: 11012 ft MD' Lease No.: FEDA028406 Operator Rep: Cole Bartlewski Suspend: P&A: Yes Casing/Tubing Data (depths are MD): Casino Removal: Conductor: 22" O.D. Shoe@ 44 Feet Csg Cut@ Feet Surface: 13-3/8" O.D. Shoe@ 2,967 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 11,449 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: O.D. Tail@ Feet Tbg Cut@ Feet Plugging Data Test Data: Type Plug Founded on Depth Btm Depth To MW Above Verified Fullbore Bridge plug 5240 ft MD - 5165 ft MD 9.8 ppg N/A 0 0 Initial 15 min 30 min 45 min Result Tubing 2460 2460 - 2460 IA 2460 2460 2460 #��j P OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: This was a pressure test on the cement plug #1 for this abandonment. This test was recorded on a Chart. Attachments: none rev. 11-28-18 2019-0416_Plug_Verification_SRU_14-15_11 THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Bo York 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 w .aogcc.olaska.gov Re: Swanson River Field, Tyonek Gas, Beluga Gas Hemlock Oil Pool, SRU 14-15 Permit to Drill Number: 100-146 Sundry Number: 319-139 Dear Mr. York: 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,n CPLI— J ieL. ielowski Commissioner DATED this q day of April, 2019. R8DMS APR 0 g 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED MAR 11 2019 AOGCC 1. Type of Request: Abandon ❑✓ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Venting Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑✓ Stratigraphic ❑ Service ❑ 100-146 ' 3. Address: 3800 Centerpoint Dr, Suite 1400 S. API Number: Anchorage Alaska 99503 50-133-10145-01 —011 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 766 ' Will planned perforations require a spacing exception? Yes ❑ No ❑ Swanson River Unit (SRU) 14-15 9. Property Designation (Lease Number): 10. Field/Pool(s): f(w?r� 41 FEDA028406 • Swanson River / Tyonek Gas & Beluga Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): 6349; 6410 Junk (MD): 11,460' . 11,015' 6,303' 6,233' 2,292 psi 6574'; 6709; 8300' NIA Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 22" 44' 44' Surface 2,96T 13-3/8" 2,96T 2,967' 2,730psi 1,130psi Intermediate Production 11,449' 7" 11,449 11,005' 7,240psi 5,410psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-3/8' 4.6# / N-80 5310 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker DB Pier; N/A 5,25UMD/5,229TVD; N/A 12. Attachments: Proposal Summary ❑ Wellbore schematic ✓ 13. Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 1, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 121- 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: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkralllgll hilcoro.com Contact Phone: 777-8420 Authorized Signature: Date: 2 -,Lt N 1-a 1 5 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �iG- 13G / Plug Integrity u BOP Test 5 Mechanical Integrity Test ❑ Location Clearance ❑ Other: .ZSUO esL 60P AC(- . pin PrE«,. �o.av� 9 ,ems. Zo A4�- z-57lizc�) Post Initial Injection MIT Req'd? Yes ❑ No ❑ I O fl 2g1Q APR p D Spacing Exception Required? Yes ❑ No ❑✓ Subsequent Form Required:^BONS_ �O _ '-I ()-7- APPROVED BY µ I /� I I Approved by: IMV/AJ COMMISSIONER THE COMMISSION Date: l ll// _ L ( 1 �' 0' /� ^^ /� JJ� �rb� $ Lmk Formand Form 10-403 Revised 4/2017 )XI Approved application sOaW.fol Q1h� o t date of approval. A chments in uplicate H Hilcorp Alaska, LL, Well Prognosis Well: SRU 14-15 Date:03/13/2019 Well Name: SRU 14-15 API Number: 50-133-10145-01 Current Status: Shut -In Gas Well Leg: N/A Estimated Start Date: May 1, 2019 Rig: Rig 401 Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 100-146 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Bo York 1 (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: Current Bottom Hole Pressure: Maximum Expected BHP: Max. Potential Surface Pressure: Brief Well Summary: — 2,907 psi @ 6,145' TVD — 2,907 psi @ 6,145' TVD — 2,292 psi (Based upon a 0.473 psi/ft gradient to the deepest open perforation) (Based upon a normal gradient) (Based upon expected max. BHP and a 0.10 psi/ft gas gradient to surface) Swanson River Unit 14-15 was originally drilled and completed as the SRU 34-16 in March 1959. This well was abandoned as a dry hole and re -drilled as SRU 14-15 from 3,800' MD in July 1959. SRU 14-15 was initially completed as a Hemlock oil producer. The Hemlock perforations were abandoned in November 1991 and the well eventually re -completed up -hole, in the Tyonek gas sands, starting in November 1996. The Tyonek 77-3 sands were perforated several times in January 1997, but failed to produce gas. The Tyonek 68-0 through 59-2 sands were perforated in July and August 2001 and also failed to produce gas. Finally, the shallower Tyonek 56-9 up through the 51-0 sands were shot (between September 2017 and December 2018). No gas was produced from any of the Tyonek sand intervals. SRU 14-15 is currently shut-in. The purpose of this Sundry is to permanently P&A SRU 14-15. ✓ Hilcorp asks for a Variance from 20 AAC 25.112 (c) (1) (E) and 43 CFR 3160 G 2. Hilcorp proposes to cut off (& pull) the existing 2-3/8" tubing just above the 7" Baker DB packer (@ 5,250' MD) and set a 7" CIBP w/ 75' of cement on top, to isolate the existing perforations which are just below the tubing tail. This will result in the bridge plug being set approximately 142' above the top perforation. 75' of cement will be displaced through tubing on top of the CIBP, in accordance with 20 AAC 25.112 (c) (1) (E) and 43 CFR 3160 G 2. Pre - Rig Work: 1. Provide 24 hour notice to AOGCC that Plug and Abandonment of well will commence per AOGCC regulations 20 AAC 25.112 (h). Notify BLM of P&A as per 43 CFR 3160 G. 2. RU Pump Truck. RU on tubing and casing and conduct an IA pressure test to 2,500 psi on chart for 30 min. Bleed down pressure. A "Z6 sz�� i�` C�_ 35-6n' ?' c.s 3. Bullhead 9.8 ppg brine down the tubing into the open perforations _ 4 tk I / Workover Rig #401: 4. MIRU Rig 401. 5. Notify AOGCC and BLM 24 hours in advance of test to extend the opportunity to witness. 6. Setback pressure valve. H Hilmro Alaska, LU Well Prognosis Well: SRU 14-15 Date:03/13/2019 ND wellhead, NU BOP and test to 250 psi low & 2,600 psi high, annular to 250 psi low & 2,500 psi high. Record accumulator pre -charge pressures and chart tests. a. Perform Test. b. Test VBR rams on 2-3/8" test joint. c. Submit completed form 10-424 to AOGCC within 5 days of BOPE test. Copy to BLM. 8. MIRU E -line. Pressure test lubricator to 3,000 psi. 9. PU Jet Cutter. RIH and cut tubing @ 5,245' (+/-) MD, lust above the seal assembly on the Baker Model DB Packer. Note the Baker DB packer is set at 5,250'. POOH and RD E -line. 10. PU tubing and circulate the hole with 9.8 ppg kill weight fluid. 11. POOH w/ 2-3/8" tubing, laying down GLM's and racking back pipe. Note: A CBL, dated 5/20/63, indicates that the top of the primary cement in the 7" annulus, is at 3,790' MD. Following the primary cement job, holes were shot in the 7" casing at 3,500' and cement squeezed into the 7" x 13-3/8" annulus, to isolate the 13-3/8" casing shoe. The CBL shows good cement bond below the casing shoe (@ 2,967'), from 3,500' up to 3,100' and also good cement above the casing shoe, from 2,740' up to 2,600'. ✓ The bond log indicates that there is 400' of good cement below and 140' of good cement above the surface casing shoe (behind the 7" casing) �. 12. RIH w/ 7" CIBP on 2-3/8" tubing. 13. Set CIBP @ 5,240' (+/-), /S) 14. PU tubing 5' and place 75' of 15.8 ppg cement on top of the CIBP. a. Top of Cement (TOC) should beat —5,165' MD. t 15. POOH w/ 2-3/8" tubing. WOC. 16. PU 2"d 7" CIBP and RIH on 2-3/8" tubing. 17. Set CIBP @ 3,077' (+/-). '✓ 18. PU tubing 5' and place 225' of 15.8 ppg cement on top of the CIBP. a. Base of Cement on top of CIBP @ 3,077' MD (^'110' below surface casing shoe). ^ b. TOC @ 2,852' MD ( —115' above surface casing shoe) (\/ 19. POOH w/ 2-3/8" tubing. WOC. 20. RU E -line. Test Lubricator to 3,000 psi. RIH and tag cement. Make sure TOC is above 2,867' (should be at ^'2,852'), to ensure at least 100' of cement extends above the surface casing shoe. 21. PU & RIH w/ 3`d CIBP to 160' and set same. POOH. VY 5 22. PU set of casing punches and RIH to 159'. Punch holes from 159' to 154'. POOH and RD E -line. vv-�- 23. Rig up cementers to back side. Establish circulation down the IA through the tubing punches and up the 7" casing. Circulate a 15.8 ppg cement plug from 160' to surface. RD Cementers, WOC. 24. Place dry hole tree on well. 25. RDMO Workover Rig. Post -Post - RigAbandonment Procedures: 26. Excavate cellar, cut off casing 3' below natural GL. w/ 27.Notify and BLM 48hrs in advance. 28. Create well abandonment marker per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10. The following must be bead -welded directly to the marker plate: a. Hilcorp Alaska, LLC b. PTD: 100-146 c. Well Name: SRU 14-15 H FBImrp Alaska. LLI d. API: 50-133-10145-01 Well Prognosis Well: SRU 14-15 Date:03/13/2019 29. Set marker plate per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10, collect GPS coordinates. 30. Photo document casing cut-off and Welded Plate install. 31. Backfill excavation, close out location. Attachments: Actual Schematic Proposed Schematic BOPE Schematic RWO Sundry Revision Change Form Swanson River Field SCHEMATIC Well # SRU 14-15 Hilansp Aturkn. LLC Actual Completion 12/30/18 RKB to TBG Head = 15.30' CASING AND TUBING DETAIL s4zd hal. 3500' 2 5 .hats gjdt� CBL V63 TOC @3800' k 7 4 5 Cak TOC Cak TOC 19 in Tubing @ in Casing17 166811 @ 10574'"�l8 22 23 4 25 -7 N PBTD = 6,303'/ TD - 11,460' MAX HOLE ANGLE = 25°, KOP @ 3800' SIZE WT - 6 7 CONN TOP bt-0 22" 2,109' T 51-5 Fish - um.m T o95 Surf 53 guns lv30n8 54.5 J-55 5 Surf 2,967' 7" A^ N-80 8rd LT&C Surf - 56-9 7" B N-80 8rd LT&C 34' = 59-2 7" 29 N-80 8rd LT&C 1030' 2,276' 7" 26 9 8rd LT&C 2276' - 62-5 7" 29 - 62-5 8rd LT&C 5718' - 68-e 7" 32 0 8rd LT 7367' 12 "M hot. 8500' 35 N-80 4shut, , , Cak TOC Cak TOC 19 in Tubing @ in Casing17 166811 @ 10574'"�l8 22 23 4 25 -7 N PBTD = 6,303'/ TD - 11,460' MAX HOLE ANGLE = 25°, KOP @ 3800' SIZE WT - GRADE CONN TOP BTM 22" 2,109' Macco 2-3/8" SMO -1C3 Chem Inj Mdrl w/1" -1000 psi chem inj valve w/ 6' pup its, top & him 3 Surf 44' 13-3/8" 54.5 J-55 5 Surf 2,967' 7" 38 N-80 8rd LT&C Surf 34' 7" 32 N-80 8rd LT&C 34' 1,030' 7" 29 N-80 8rd LT&C 1030' 2,276' 7" 26 N-80 8rd LT&C 2276' 5,718' 7" 29 N-80 8rd LT&C 5718' 7,367' 7" 32 N-80 8rd LT 7367' 8,789' 7" 35 N-80 8rd LT&C 8789' 10,432' 7" 38 N-80 8rd LT&C 10432' 11,449' Tubing: 11,096' Camco MM GLM #12 w/dummy 21 11,137' 2-7/8" Baker curt retainer 2-3/8" 4.6 N-80 Buttress Surf 5,310' 2411,240' with 3/8" SS methanol injection line Surf 2,506' nanaa�:unwrau NO. Depth Item 1 15.30' 2-7/8" Tbg hgr w/Cameron H BPV profile and 2-7/8" x 2-3/8" buttress xover 2 2,109' Macco 2-3/8" SMO -1C3 Chem Inj Mdrl w/1" -1000 psi chem inj valve w/ 6' pup its, top & him 3 4,910' Macco 2-3/8" D-50 glm w/1" dummy w/ 6' pup Its, top & btm 4 5,246' Baker Locator Seal ASSY. size 40-26 5 5,250' Baker Madel "DB" Retainer Production packer, 7" 29#, DPM 6 5,264' SBE, XO to 2-%", 4.6#, Butt 7 5,310' WLEG 7A 6,340' CIBP w/ 37' cement 11/30/17 -TOC 6,303' 7B 6,410' CIBP w/ 35' cement 09/30/17 -TOC 6,375' 8 6,574' PosiSet Plug w/ 10' of cement 9 6,700' PosiSet Plug w/ 10' of cement 10 8,300' Bridge Plug in 7" casing, 6/20/01 w/ TOC @ 8,053' 11 8,313' Milled up pkr fish. 12 8,442' Bridge Plug in 7" casing, 11/8/96 13 9,890' 2-7/8" Tubing cut, 10/21/96 14 10,00x- 10,012' Holes in tbg 15 10,125' Camco MM GLM #10 w/dummy 16 10,574' Calc TOC in annulus 17 10,594' Camco MM GLM#11 w/dummy 18 10,681' Calc TOC in tbg 19 10,900' 2-7/8" Baker cmt retainer 20 11,096' Camco MM GLM #12 w/dummy 21 11,137' 2-7/8" Baker curt retainer 22 11,148' Brown HS -16-1 retr packer 23 11,212' Camco MM GLM #13 w/CEV 2411,240' Baker Model D packer 25 11,280' Bridge plug DRAWN BY: TAB Updated by PW: 03-13-19 Swanson River Field SCHEMATIC Well # SRU 14-15 Ilil... P AI.ka. LLC Actual Completion 12/30/18 PERFORATION DATA ZONE TOP BTM Top TVD Bottom TVD SPF DATE COMMENTS 3,500' 3,500' 3,500' 3,500' 5 06/20/59 sqz 51-0 5,382 5,392 5,347' 5,357' 6 12/30/18 Open 51-5 5,467' 5,484' 5,429' 5,445' 6 12/29/18 Open 51-5 5,505' 5,543' 5,466' 5,502' 6 12/29/18 Open 51-5 5,543' 5,550' 5,502' 5,509' 6 12/29/18 Open 53 5,907 5,951' 5,853 5,896' 6 12/28/18 Open 55-5 6,200' 6,210' 6,135' 6,145' 6 11/16/17 Open 56-9 6,345' 6,365' 1 6,273' 6,292' 6 09/19/17 1 Isolated 59-2 6,425' 6,445' 6,349' 6,367' 4 08/30/01 Isolated 59-2 6,449' 6,459' 6,371' 6,381' 4 08/10/01 Isolated 59-2 6,490' 6,502' 6,410' 6,421' 4 07/29/01 Isolated 61-3 6,550' 6,582' 6,466' 6,496' 4 07/18/01 Isolated 62-5 6,729' 6,758' 6,635' 6,662' 4 070/8/01 Isolated 62-5 6,784' 6,796' 6,686' 6,697' 4 07/08/01 Isolated 68-0 7,457' 7,577' 7,306' 7,415' 4 07/04/01 Isolated 8,500' 8,500' 8,260' 8,260' 4 06/17/59 sqz 11,224' 11,231' 10,794' 10,800' 4 05/29/63 Abdn 11/91 Hemlock 11,262' 11,276' 10,829' 10,842' 4 07/59, 02/61 Abdn 11/91 Hemlock 11,290' 11,300' 10,856' 10,865' 4 05/63 Abdn 11/91 DRAWN BY: TAB Updated by PW: 03-13-19 Swanson River Field PROPOSED SCHEMATIC Well #SRU 14-15 IBl.tew Aluka, LLC Actual Completion 12/30/18 RKB to TBG Head = 15.30' CASING AND TUBING DETAIL ^, Tree connection: TC -3 Uni-bolt SIZE WT GRADE CONN TOP BTM Depth 7 8 1 ±160' Punch Fish -27'.f5 ±3,077' si54' TOC 2600• Surf 3159 C 54.5 J-55 M sgzd holes 3500' Surf 2,967' 5 shots �� T 38 - 56.9 BOC Surf 34' 500' 32 N-80 CBL 5/63 34' Il - 61-3 roc @' 29 1% 3800' 1030' - 62-5 7" 26 3 8rd LT&C 2276' - 68-0 7" 29 5 0 Cale roc in Casing @ 10574' 28 W, C.TOC in Tubing @ 10681' PBTD = 6,303'/ TO = 11,460' MAX HOLE ANGLE = 25°, KOP @ 3800' Depth 7 8 1 ±160' _ 51.0 = Fish -27'.f5 ±3,077' 51-5 53 sections/3 stop Surf 44' gum Iv312/308a 54.5 J-55 5 Surf 2,967' 7" 38 - 56.9 I0 Surf 34' 7" 32 N-80 8rd LT&C 34' Il - 61-3 7" 29 1% 8rd LT&C 1030' - 62-5 7" 26 - 62.5 8rd LT&C 2276' - 68-0 7" 29 13 8rd LT&C 5718' ]4 P 7" 32 15 sgzd holes 8500' 7367' 8,789' 4 shots 35 Cale roc in Casing @ 10574' 28 W, C.TOC in Tubing @ 10681' PBTD = 6,303'/ TO = 11,460' MAX HOLE ANGLE = 25°, KOP @ 3800' JEWELRY DE IAIL NO. Depth Item 1 ±160' CIBP w/ 160' cement to surface 22" ±3,077' CIBP w/ 225' cement -TOC 2,852' 3 Surf 44' 13-3/8" 54.5 J-55 5 Surf 2,967' 7" 38 N-80 8rd LT&C Surf 34' 7" 32 N-80 8rd LT&C 34' 1,030' 7" 29 N-80 8rd LT&C 1030' 2,276' 7" 26 N-80 8rd LT&C 2276' 5,718' 7" 29 N-80 8rd LT&C 5718' 7,367' 7" 32 N-80 Srd LT&C 7367' 8,789' 7" 35 N-80 Srd LT &C 8789' 10,432' 7" 38 N-80 8rd LT&C 10432' 11,449' Tubing: 10,900' 2-7/8" Baker curt retainer 23 11,096' Carrico MM GLM #12 w/dummy 2-3/8" 4.6 N-80 Buttress Surf 5,310' 26 with 3/8" SS methanol injection line Surf 2,506' JEWELRY DE IAIL NO. Depth Item 1 ±160' CIBP w/ 160' cement to surface 2 ±3,077' CIBP w/ 225' cement -TOC 2,852' 3 ±5,240' CIBP w/75'cement -TOC 5,165' 4 ±5,245' Top of 2-3/8" tubing stub 5 5,246' Baker Locator Seal Assy. size 40-26 6 5,250' Baker Model "DB" Retainer Production packer, 7" 29#, DPM 7 5,264' SBE, XO to 2-%", 4.6#, Butt 8 5,310' WLEG 9 6,340' 1 CIBP w/ 37' cement 11/10/17 -TOC 6,303' 10 6,410' CIBP w/35'cement 09/10/17 -TOC 6,375' 11 6,574' PosiSet Plug w/ 10' of cement 12 6,700' PosiSet Plug w/ 30' of cement 13 8,300' Bridge Plug in 7" casing, 6/20/01 w/ TOC @ 8,053' 14 8,313' Milled up pkr fish. 15 8,442' Bridge Plug in 7" casing, 11/8/96 16 9,890' 2-7/8" Tubing cut, 10/21/96 17 10,002'- 10,012' Holes in tbg 18 10,125' Carrico MM GLM#10 w/dummy 19 10,574' Calc TOC in annulus 20 10,594' Carrico MM GLM#11 w/dummy 21 10,681' Calc TOC in tbg 22 10,900' 2-7/8" Baker curt retainer 23 11,096' Carrico MM GLM #12 w/dummy 24 11,137' 2-7/8" Baker curt retainer 25 11,148' Brown HS -16-1 retr packer 26 11,212' Camco MM GLM#13 w/CEV 27 11,240' Baker Model D packer 28 11,280' Bridge plug DRAWN BY: TAB Updated by DMA: 03-13-19 Swanson River Field PROPOSED SCHEMATIC Well #SRU 14-15 llil ,,,,Al:-kn,ua; Actual Completion 12/30/18 PERFORATION DATA ZONE TOP BTM ToDTVD Bottom TVD SPF DATE COMMENTS 3,500' 3,500' 3,500' 3,500' 5 06/20/59 sqz 51-0 5,382 5,392 5,347' 5,357' 6 12/30/18 Isolated 51-5 5,467' 5,484' 5,429' 5,445' 6 12/29/18 Isolated 51-5 5,505' 5,543' 5,466' 5,502' 6 12/29/18 Isolated 51-5 5,543' 5,550' 5,502' 5,509' 6 12/29/18 Isolated 53 5,907 5,951' 5,853 5,896' 6 12/28/18 Isolated 55-5 6,200' 6,210' 6,135' 6,145' 6 11/16/17 Isolated 56-9 1 6,345' 1 6,365' 6,273' 1 6,292' 6 09/19/17 Isolated 59-2 6,425' 6,445' 6,349' 6,367' 4 08/10/01 Isolated 59-2 6,449' 6,459' 6,371' 6,381' 4 08/10/01 Isolated 59-2 6,490' 6,502' 6,410' 6,421' 4 07/29/01 Isolated 61-3 6,550' 6,582' 6,466' 6,496' 4 07/18/01 Isolated 62-5 6,729' 6,758' 6,635' 6,662' 4 070/8/01 Isolated 62-5 6,784' 6,796' 6,686' 6,697' 4 07/08/01 Isolated 68-0 7,457' 7,577' 7,306' 7,415' 4 07/04/01 Isolated 8,500' 8,500' 8,260' 8,260' 4 06/17/59 sqz 11,224 1 11,231' 10,794' 10,800' 4 05/29/63 Abdn 11/91 Hemlock 11,262' 11,276' 10,829' 10,842' 4 07/59, 02/61 Abdn 11/91 Hemlock 11,290' 11,300' 10,856' 10,865' 4 05/63 Abdn 11/91 DRAWN BY: TAB Updated by DMA: 03-13-19 HILCORP ALASKA 7-1/16" 5M BOPE 7-1/16" 5M HYDRIL GK ANNULAR 32" TALL, FLANGE TO FLANGE 7-1/16" 5M LWS DBL GATE BOP DRESSED W/VARIABLE RAMS IN TOP DRESSED W/BLIND RAMS IN BOTTOM 26-3/4" TALL, FLANGE TO FLANGE 7-1/16" SM DRILLING SPOOL W/2-1/16" SM OUTLETS 18" TALL, FLANGE TO FLANGE ^77" TOTAL STACK HEIGHT ANNULAR STYLE BOP SPECS: - 3.30 gallon open chamber volume - 3.86 gallon close chamber volume GATE STYLE BOP SPECS: -1.45 gallons to close per gate -1.18 gallons to open per gate - 5.45:1 closing ratio -1.93:1 opening ratio ff Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well SRU 14-15 (PTD 100-146) 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 AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. 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 ream Operations Manager Date First call Operations Engineer Date 1,000,000 100,000 10,000 1,000 100 10 HILCORP ALASKA I.I.C. SWANSON RIV UNIT 14-15 (100-146) SWANSON RIVER HEMLOCK OIL A—` I � '�'�'' Monthly Production Rates �y .i 371; • /117 1,000,000 100,000 10,000 1,000 Z V1 O c� G 100 m v m 3 0 10 3 z Jan -1955 Jan -1960 Jan -1965 Jan -1970 Jan -1975 Jan -1980 Jan -1985 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Jan -2020 �- Produced Gas (MCFM) o GOR . Produced Water (BOPM) —. Produced Oil (BOPM) SPREADSHEET_Prod-I nject_Curves_W ell_V 119_1001460_SRU_14-15_20190326.xlsx 3/26/2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED JAN 3 1 2019 1. Operations Abandon Li Plug Perforations LJ Fracture Stimulate 0 Pull Tubing Li Operations shutdown Li Performed: Suspend ❑ Perforate P1 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Flow test & Venting ❑✓ 2. Operator 4. Well Class Before Work: Hilcorp Alaska, LLC 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ 100-146 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, Slratigraphic❑ Service ❑ 6. API Number: AK 99503 50-133-10145-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028406 Swanson River Unit (SRU) 14-15 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River / Tyonek Gas & Beluga Gas 11. Present Well Condition Summary: 6,303; 6,375; 6,564; Total Depth measured 11,460 feet Plugs measured 6,700; 8,300 feet true vertical 11,015 feet Junk measured N/A feet Effective Depth measured 6,303 feet Packer measured 5,250 feet true vertical 6,233 feet true vertical 5,220 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 22" 44' 44, Surface 2,967' 13-3/8" 2,967' 2,967' 2,730psi 1,130psi Intermediate Production 11,449' 7" 11,449' 11,005' 4,240psi 5,410psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 2-3/8" 4.6# / N-80 5,310' MD 5,278' TVD Packers and SSSV (type, measured and true vertical depth) Baker DB Pkr; N/A 5,250' MD 5,220' TVD N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 10 15 120 Subsequent to operation: 0 0 10 10 10 14. Attachments (required per 20 AAc 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory[] Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil LJ Gas WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ sUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 317-546 Authorized Name: Bo York 777-8345 Contact Name: Taylor Nasse Authorized Title: Operations Manager Contact Email: tnasseta�hilcom.com �i Authorized Signature: Date:.? tl M i9 Contact Phone: 777-8354 Form 10-404 Reviled 4/ 7* �6..�, y,�g RBDMCq FF6 0 12019 SCAN N1!`!Yit W`!1y2019 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 14-15 E-Line 50-133-10145-Oi 100-146 12/26/18 1/1/19 Daily Operations: 12/26/2018- Wednesday PTW & JSA. PT 3,000 PSI TP - 0 psi. RIH W/ 1.75" B-BOX TO (SEE FL @ 3,020'KB) 6,303'KB TAG FILL, POOH. POOH, RIG DOWN. PARK UNIT @ P & S. 12/28/2018 - Friday Sign in. Mobe to location. PTW and JSA with AKE-Line and SLB N2. Rig up hard lines and lubricator. PT N2 lines and lubricator to 250 psi low and 4,500 psi high. TP - 0 psi. Started pumping N2 at 800 scf/min (Had approx. 1,000 gal on truck) while waiting on N2 tanker. Tanker showed up around 1115 hrs (suspose to be here at 10 am). Transferred N2 from tanker to pump truck (approx. 2,000 gals) and sent 500 gals to SLB yard to store. Pressure increased to ,4000 psi after we had pump 1050 gals down hole to push fluid away. Figured it would take 950 gals to push all fluid away. We have 1,800 gals of N2 in tank on pump truck. Shut down N2 and rigged SLB N2 down. Tried to run in hole with E-line but could not. Added weight bars. RIH w/ 1-11/16" x 10' Spiral Strip Gun, 6 spf, 60 deg phase and tied into pert log dated 11-16-17. Ran correlation log and send to town. Got ok to perf from 5,907' to 5,917'w/ 2,950 psi on tubing. Spotted and fired gun. Pressure went to 3,000 psi after shot, 5 min - 3,100 psi, 10 min 3,100 psi and 15 min 3,050 psi. Started out of hole and hung up in tubing tail. Worked tools from 5,305' to 4,800' and tools came free. POOH and had left 5' of the spiral strip in hole. Called town and discussed. Ed with AKE-line will meet Pollard SL at their shop at 5:30 in the morning with the strip and I will meet Pollard SL at 7 am to fish the strip out of tubing. If successful will move over to SCU 24313-04 and fish that strip. Rig lubricator off well. Pollard SL will use AKE-line crane. TP - 3,050 psi. 12/29/2018-Saturday ARRIVE @ SR JSA/TGSM. GET UNIT HEAD TO PAD RIG UP WIRE LINE. P/T4,000 PSI FAIL C/O O-RING RE-TEST GOOD. RIH W/ 1.75" LIB TO 5,700'KB. CLEAR DID NOT SEE STRIP GUN. POOH, OOH RIG DOWN. RIG OVER TO SCU 24313-4. PTW and JSA with AK E-Line. Rig up lubricator. PT to 250 psi low and 4,000 psi high.RIH w/ 1-11/16" x 7' Spiral strip gun and tie into yesterday correlation log. Spot gun and fire gun from 5,543' to 5,550' with 2,525 psi on tubing. No pressure change. Had trouble pulling strip gun into tubing tail at 5,305' and pulled heavy to 4,800 and came on out of hole with normal tool wt. Left 4' of strip in hole. Ran 1-11/16" drift to 5,650' and didn't see strip. POOH.RIH w/ 1-11/16" x 10' Spiral strip gun and tie into yesterday correlation log. Spot gun and fire gun from 5,505' to 5,515' with 2,495 psi on tubing. After 5 min - 2,495, 10 min - 2,490 psi and 15 min - 2,490 psi. Had same trouble as last run POOH. Left 8' strip in well. Ran same drift to 5,530' and didn't see strip. POOH.RIH w/ 1-11/16" x 10' Spiral strip gun and tie into yesterday correlation log. Spot gun and fire gun from 5,467' to 5,477' with 2,435 psi on tubing. After 5 min - 2,435, 10 min - 2,435 psi and 15 min - 2,430 psi. Had same problem getting in tubing tail and pulling heavy to 4,800'. At 3,150' tools hung up and pulled out of rope socket. POOH. AK E-Line has to get more tools so we are SDFN and meet back here in the morning at 9 am. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 14-15 E -Line 50-133-10145-01 1 100-146 12/26/18 1 1/1/19 Daily Operations: 12/30/2018 -Sunday Sign in. Mobe AK E -Line to location. PTW and JSA. Re -head wireline. Rig up lubricator. PT to 250 psi low and 4,000 psi high. TP - 2,312 psi. RIH with 1.75" LIB and tag top of fish at 3,155' KB. Tap down to get an impression on the LIB. POOH. LIB had picture of rope socket. Call Pollard Slickline. Rig down E -Line and go get Pollard wireline unit. Bring slick line unit to location. Spot unit and start the rig up while waiting on them. Pollard on location. Have PTW, JSA and SIMOPS with AKE-Line. PT lubricator to 250 psi low and 4,000 psi high. TP 2,235 psi. RIH W/ 2" JDC TO 3,168'KB W/T LATCH E -LINE TS POOH HANGS UP AT 3,071'KB W/T 3,038'KB 2,849'KB. LIGHTLY SJ FREE EACH TIME HANGS UP IN TREE SJ FREE. OOH W/E-LINE TS BRAKE TS DOWN. LEFT 2' of strip from gun. RIH W/ 1.75" LIB TO 5,500'KB CLEAR NO TAG POOH. OOH RIG OFF. RIG UP E -LINE STAND BY FOR E -LINE TO PERF. E -LINE OUT OF HOLE RIG DOWN. RIH w/ 1-11/16" x 10' Spiral Stri Gun, 6 spf, 60 deg phase and tie into correlation log dated 12-28-18. Spot and fire gun from 5,382' to 5,392' with 2,201 psi on tubing. After 5 min - 2,195 psi, 10 min - 2,180 psi and 15 min - 2,170 psi. POOH. Tools pulling 200 to 500 lbs over tool weight after entering tubing at 5,315'. Pull that way until 4,800' and then smoothed out. Left 8' of strip off gun in hole. Ran 1-11/16" drift to 5,400'. to make sure tubing was clear. POOH. Did not see strip. NOTE: Total strips left in casing is: 1st gun - 5', 2d gun - 4', 3d gun - 8', 4th gun - 2' and 5th gun - 8': All total is 27' of 1-11/16" strip off strip guns. Rig down E line and Slickline. Well is ready to blow N2 out of well and see if there is any gas. 12/31/2018 - Monday Begin well testing with 1,950 psig on tubing. Open to tank and blow down N2. Blew down to 2 psig over4 hrs with no fluid to surface. SI for overnight buildup. 01/01/2019 -Tuesday Well built to 133 psig overnight. Open well to tank and blow down to 0.5 psig in 5 minutes. SI for buildup. Built to 20 psig over 2 hrs. Swanson River Field SCHEMATIC Well #SRU 14-15 tlansrp .Alaku, U.f. Actual Completion 06/24/01 RKB to TBG Head = 15.30' CASING AND TUBING DETAIL Tree connection: TC -3 Uni-bolt SIZE WT GRADE CONN TOP BTM sgzd bola 1500' IVI,,,'J Item 1 15.30' 2 5 shots 2,109' Macco 2-3/8" SM0-1C1 Chem Inj Mdrl w/1" -1000 psi chem inj valve w/ 6' pup its, top & btm 3 Surf 44' CBL 5/63 TOC 54.5 J-55 5 1 2,967' @ 38M, 38 N-80 8rd LT&C Surf 34' 3 4 5 6 7 51-0 T 51-5 Fish-27'of5 L53 xcliosu of strip Buns 12/30/18 55-5 56-9 59-2 8 61-3 9 62-5 62-5 68-0 _ --- 10 I1 12 sgzd holes 8500' a sn0u 13 14 Jc,dC roc(v� n T C.TOC 17 10606i 811" In Casing is 10576' 1&18 22 23 24 25 PBTD = 6,303'/ TD = 11,460' MAX HOLE ANGLE = 250, KOP @ 3800' IIas01a11:YP1a IL\IN NO. - Item 1 15.30' 2-7/8" Tbg hgr w/Cameron H BPV profile and 2-7/8" x 2-3/8" buttress xover 22" 2,109' Macco 2-3/8" SM0-1C1 Chem Inj Mdrl w/1" -1000 psi chem inj valve w/ 6' pup its, top & btm 3 Surf 44' 13-3/8" 54.5 J-55 5 Surf 2,967' 7" 38 N-80 8rd LT&C Surf 34' 7" 32 N-80 8rd LT&C 34' 1,030' 7" 29 N-80 8rd LT&C 1030' 2,276' 7" 26 N-80 8rd LT&C 2276' 5,718' 7" 29 N-80 8rd LT&C 5718' 71367' 7"32 10,007- 10,012' N-80 8rd UMC 7367' 8,789' 7" 35 N-80 8rd LT&C 8789' 10,432' 7" 38 N-80 8rd LT&C 10432' 11,449' Tubing: 11,096' Camco MM GLM#12 w/dummy 21 11,137' 2-7/8" Baker cmt retainer 2-3/8" 4.6 N-80 Buttress Surf 5,310' 24 with 3/8" SS methanol injection line I Surf I 2,506' IIas01a11:YP1a IL\IN NO. Depth Item 1 15.30' 2-7/8" Tbg hgr w/Cameron H BPV profile and 2-7/8" x 2-3/8" buttress xover 2 2,109' Macco 2-3/8" SM0-1C1 Chem Inj Mdrl w/1" -1000 psi chem inj valve w/ 6' pup its, top & btm 3 4,910' Macco 2-3/8" D -SO glm w/1" dummy w/ 6' pup its, top & btm 4 5,246' Baker Locator Seal Assy. size 40-26 5 5,250' Baker Model "DB" Retainer Production packer, 7" 29#, DPM 6 5,264' SBE, XO to 2-%', 4.6#, Butt 7 5,3101 WLEG 7A 6,340' CIBP w/ 37' cement 11/10/17 -TOC 6,303' 7B 6,4101 CIBP w/ 35' cement 09/10/17 -TOC 6,375' 8 6,574' PosiSet Plug w/ 10' of cement 9 6,700' PosiSet Plug w/ 10' of cement 10 8,300' Bridge Plug in 7" casing, 6/20/01 w/ TOC @ 8,053' 11 8,313' Milled up pkr fish. 12 8,442' Bridge Plug in 7" casing, 11/8/96 13 9,890' 2-7/8" Tubing cut, 10/21/96 14 10,007- 10,012' Holes in tbg 15 10,125' Camco MM GLM#10 w/dummy 16 10,574' Calc TOC in annulus 17 10,594' 1 Camco MM GLM#11 w/dummy 18 10,681' Calc TOC in tbg 19 10,900' 2-7/8" Baker cmt retainer 20 11,096' Camco MM GLM#12 w/dummy 21 11,137' 2-7/8" Baker cmt retainer 22 11,148' Brown HS -16-1 retr packer 23 11,212' Camco MM GLM #13 w/CEV 24 11,240' Baker Model D packer 25 11,280' Bridge plug DRAWN BY: TAB Updated by DMA: 01-30-19 Swanson River Field Well # SCHEMATIC Well SRU 14-15 Om.,n, AI.A.. LLC Actual Completion 06/24/01 PERFORATION DATA ZONE TOP BTM TODTVD Bottom TVD SPF DATE COMMENTS 3,500' 3,500' 3,500' 3,500' 5 06/20/59 sqz 51-0 5,382 5,392 5,347' 5,357' 6 12/30/18 Open 51-5 5,467' 5,484' 5,429' 5,445' 6 12/29/18 Open 51-5 5,505' 5,543' 5,466' 5,502' 6 12/29/18 Open 51-5 5,543' 5,550' 5,502' 5,509' 6 12/29/18 Open 53 5,907 5,951' 5,853 5,896' 6 12/28/18 Open 55-5 6,200' 6,210' 6,135' 6,145' 6 11/16/17 Open 56-9 6,345' 6,365' 6,273' 6,292' 6 09/19/17 Open 59-2 6,425' 6,445' 6,349' 6,367' 4 08/10/01 Isolated 59-2 6,449' 6,459' 6,371' 6,381' 4 08/10/01 Isolated 59-2 6,490' 6,502' 6,410' 6,421' 4 07/29/01 Isolated 61-3 6,550' 6,582' 6,466' 6,496' 4 07/18/01 Isolated 62-5 6,729' 6,758' 6,635' 6,662' 4 070/8/01 Isolated 62-5 6,784' 6,796' 6,686' 6,697' 4 07/08/01 Isolated 68-0 7,457' 7,577' 7,306' 7,415' 4 07/04/01 Isolated 8,500' 8,500' 1 8,260' 8,260' 4 06/17/59 1 sqz 11,224' 11,231' 10,794' 10,800' 4 05/29/63 Abdn 11/91 Hemlock 11,262' 11,276' 10,829' 10,842' 4 07/59,02/61 Abdn 11/91 Hemlock 11,290' 11,300' 10,856' 10,865' 4 05/63 Abdn 11/91 DRAWN BY: TAB Updated by DMA: 01-30-19 THE STn'1'O 'ff1LASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager 01KO ou Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 • Alaska Oil and Gas Conservation Commission Re: Swanson River Field, Tyonek and Beluga Gas Pools, SRU 14-15 Permit to Drill Number: 100-146 Sundry Number: 318-546 Dear Mr. Helgeson: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov 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, Hollis S. French Chair DATED this QZ day of December, 2018. RBDM�DEC 14 2018 0 9 RaECENED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 DEC 9 20:3 '7-- i Z/ ) 2,( i A6� 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Q • Other Stimulate ❑ Pull Tubing ❑ C>nge_ Approved Program ❑ ��ing Plug for Redrill El Perforate New Pool [IRe-enterSusp Well ElElf GlAlter Casing "`O VentOther: ❑� ' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q. Stratigraphic ❑ Service ❑ 100-146 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-10145-01•-E5d> 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 766 Will planned perforations require a spacing exception? Yes El No Q' Swanson River Unit (SRU) 14-15 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028406 Swanson River / Tyonek Gas & Beluga Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): 6,375'; Junk (MD): 11,460' ` 11,015' 6,375' 6,301' 2,120 psi 6,564'; 6,700'; 8,300' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 22" 44' 44' Surface 2,967' 13-3/8" 2,967' 2,967' 2,730psi 1,130psi Intermediate Production 11,449' 7" 11,449' 11,005' 4,240psi 5,410psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-3/8" 4.6# / N-80 5,863' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker DB Pkr; N/A 5,250'MD/5,220'TVD; N/A 12. Attachments: Proposal Summary ❑ Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑Q BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: December 21, 2018 OIL ❑ WINJ❑ WDSPL❑ Suspended ❑ GAS Q 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: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramera-hilcorp.com p Contact Phone: 777-8420 q,71 Authorized Signature: Date: 1 CJ 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: VeArAJr Ot 12Si �'a�✓d;Gyf nor ro ��¢e� Yo�a1/s D� 1 ��sc %S Q�n{or;s�.� ir,, QcCo �ac� tr%f� 20A9G2S,23SCd�C�- � CC % f Z 1 4 201 Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMDEC Spacing Exception Required? Yes ❑ No © Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: i Z' ► Z t �a - d I V I l AL Form 10-403 Revised 4/20 Approved application i v li r ate of approval.'0001/' Submit Form and Attachment jp Duplicate I R 9 • Ilileurp Alaska, LLI Well Prognosis Well: SRU 14-15 Date: 12/4/2018 Well Name: SRU 14-15 API Number: 50-133-10145-01 Current Status: SI Gas Well Leg: N/A Estimated Start Date: December 21, 2018 Rig: E -line Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: ±5,484' Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 100-146 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Tyonek 53 Current Bottom Hole Pressure: 2,757 psig (Based on 0.433 psi/ft gradient to TVD) Max. Potential Surface Pressure: 2,120 psig (Based on 0.1 psi/ft gradient to TVD) Brief Well Summary Hilcorp Submitted and received an approved Comingling Agreement (Docket Number: CO -18-015, Conservation ✓ Order No. 766) to comingle Beluga and Tyonek Sands in this well bore. . Hilcorp would like to withdraw Sundry 317-512 since it is now expired. This Sundry application is to replace Sundry 317-512. In November 2017 sand 55-5 was perforated and tested for gas production under Sundry number 317-402 but was non-commercial by itself. A comingling application was then submitted and approved by both the AOGCC and the BLM. The remaining intervals to be tested (Beluga and Tyonek), will now be perforated together under this Sundry Application. Note: This sundry application only includes intervals that are below the current packer. A separate Sundry will be filed for intervals above the packer since those intervals will require putting a rig on the well. Notes Reeardine Wellbore Condition • Casing passed MIT to 1,500 psig July 2015. Eline Procedure: 1. MIRU E -line, PT lubricator to 2,500 psi Hi 250 Low. 2. PU wireline guns 3. RIH and perforate the following zones: Zone Sands Top (MD) Btm (MD) FT Beluga 51-0 ±5,382 ±5,392 10 Beluga 51-5 ±5,467' ±5,484' 17 Beluga 51-5 ±5,505 ±5,543 38 Beluga 51-5 ±5,543 ±5,550 7 Tyonek 53 ±5,907' ±5,951' 44 Tyonek 55-4 ±6,199' ±6,226' 27 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Bleed down tubing pressure per Engineer's instructions prior to perforating. d. Correlate using correlation log. Use Gamma/CCL/ to correlate. Well Prognosis Well: SRU 14-15 Hileorp Alaska, LL Date: 12/4/2018 e. Install Crystal gauges before perforating. Record tubing pressures before and after each perforating run. f. All perforations in table above are located in the Tyonek and Beluga Gas Pools based on Conservation Order No. 766 4. RD Eline. 5. Turn well over to production for testing. Note: Flowback- Once the well is perforated, the Nitrogen blanket will be flowed back and vented. Once hydrocarbons are detected, the perforated interval will be vented the shortest amount of time posse 6 le to con irm t at t e interval is capable of producing in economic paying quantities, but no longer than 7 days. This operation will be manned to minimize the amount of vented gas and once a commercial rate is established, the well will be shut in until it can be placed on line through the facilities.. H - anticipates that no more than 900 mcfd_will be vented per day and no more than 2 MMscf total will be vented for this Sundry Application. If well is not producing gas in paying quantities, see remaining procedures below. 6. RU E -line. 7. Pressure up on well with nitrogen to push water away. 8. PU plug, RIH and set same in casing above the top perforation. Place 35' of cement (if room) on top of plug. WOC. 9. PU RIH with Bailer and tag top of cement. 10. Prepare Sundry for additional well work. Attarhmnntc- 1. Actual Schematic 2. Proposed Schematic 0 Swanson River Field SCHEMATIC Well # SRU 14-15 HilcoriiAlaska,LLC Actual Completion 06/24/01 RKB to TBG Head = 15.30' CASING AND TUBING DETAIL Tree connection: TC -3 Uni-bolt 56-9 B n' -59-2 R 61-3 9 i 62-5 62-5 - 68-0 ri ^r 10 11 12 PBTD = 6,375'/ TD = 11,460' MAX HOLE ANGLE = 25°, KOP @ 3800' SIZE WT GRADE CONN TOP BTM 22" 2,109' Macco 2-3/8" SM0-1C1 Chem Inj Mdrl w/1" - 1000 psi chem inj valve w/ 6' pup jts, top & btm 3 Surf 44' 13-3/8" 54.5 1-55 5 Surf 2,967' 7" 38 N-80 8rd LT&C Surf 34' 7" 32 N-80 8rd LT&C 34' 1,030' 7" 29 N-80 8rd LT&C 1030' 2,276' 7" 26 N-80 8rd LT&C 2276' 5,718' 7" 29 N-80 8rd LT&C 5718' 7,367' 7" 32 N-80 8rd LT&C 7367' 8,789' 7" 35 N-80 8rd LT&C 8789' 10,432' 7" 38 N-80 8rd LT&C 10432' 11,449' Tubing: 11,096' Camco MM GLM #12 w/dummy 21 11,137' 2-7/8" Baker cmt retainer 2-3/8" 4.6 N-80 Buttress Surf 5,310' 24 with 3/8" SS methanol injection line Surf 2,506' NO. Depth Item 1 15.30' 2-7/8" Tbg hgr w/Cameron H BPV profile and 2-7/8" x 2-3/8" buttress xover 2 2,109' Macco 2-3/8" SM0-1C1 Chem Inj Mdrl w/1" - 1000 psi chem inj valve w/ 6' pup jts, top & btm 3 4,910' Macco 2-3/8" D -SO glm w/1" dummy w/ 6' pup jts, top & btm 4 5,246' Baker Locator Seal Assy. size 40-26 5 5,250' Baker Model "DB" Retainer Production packer, 7" 29#, DPM 6 5,264' SBE, XO to 2-%", 4.6#, Butt 7 5,310' WLEG 7A 6,340' C I B P w/ 37' cement 11/10/17 -TOC 6,303' 7B 6,410' C I B P w/ 35' cement 09/10/17 -TOC 6,375' 8 6,574' PosiSet Plug w/ 10' of cement 9 6,700' PosiSet Plug w/ 10' of cement 10 8,300' Bridge Plug in 7" casing, 6/20/01 w/ TOC @ 8,053' 11 8,313' Milled up pkr fish. 12 8,442' Bridge Plug in 7" casing, 11/8/96 13 9,890' 2-7/8" Tubing cut, 10/21/96 14 10,002'- 10,012' Holes in tbg 15 10,125' Camco MM GLM #10 w/dummy 16 10,574' Calc TOC in annulus 17 10,594' Camco MM GLM #11 w/dummy 18 10,681' Calc TOC in tbg 19 10,900' 2-7/8" Baker cmt retainer 20 11,096' Camco MM GLM #12 w/dummy 21 11,137' 2-7/8" Baker cmt retainer 22 11,148' Brown HS -16-1 retr packer 23 11,212' Camco MM GLM #13 w/CEV 24 11,240' Baker Model D packer 25 11,280' Bridge plug DRAWN BY: TAB Updated by DMA: 12-04-18 11 0 9 Swanson River Field SCHEMATIC Well # SRU 14-15 lli6mroAl"ka,LLC Actual Completion 06/24/01 PERFORATION DATA ZONE TOP BTM Top TVD Bottom TVD SPF DATE COMMENTS 3,500' 3,500' 3,500' 3,500' 5 06/20/59 sqz 55-5 6,200' 6,210' 6,135' 6,145' 6 11/16/17 Sundry 317-402 56-9 6,345' 6,365' 6,273' 6,292' 6 09/19/17 Sundry 317-402 59-2 6,425' 6,445' 6,349' 6,367' 4 08/10/01 Isolated 59-2 6,449' 6,459' 6,371' 6,381' 4 08/10/01 Isolated 59-2 6,490' 6,502' 6,410' 6,421' 4 07/29/01 Isolated 61-3 6,550' 6,582' 6,466' 6,496' 4 07/18/01 Isolated 62-5 6,729' 6,758' 6,635' 6,662' 4 070/8/01 Isolated 62-5 6,784' 6,796' 6,686' 6,697' 4 07/08/01 Isolated 68-0 7,457' 7,577' 7,306' 7,415' 4 07/04/01 Isolated 8,500' 8,500' 8,260' 8,260' 4 06/17/59 sqz 11,224 11,231' 10,794' 10,800' 4 05/29/63 Abdn 11/91 Hemlock 11,262' 11,276' 10,829' 10,842' 4 07/59,02/61 Abdn 11/91 Hemlock 11,290' 11,300' 10,856' 10,865' 4 05/63 Abdn 11/91 DRAWN BY: TAB Updated by DMA: 12-04-18 0 PROPOSED SCHEMATIC Hileorp Alaska, LLC RKB to TBG Head = 15.30' Tree connection: TC -3 Uni-bolt I C sqzd holes 3500' M 2 5 shots CBL 5/63 TOC n 3800' 3 4 5 22 23 24 25 PBTD = 6,375'/ TD = 11,460' MAX HOLE ANGLE = 25°, KOP @ 3800' DRAWN BY: TAB Swanson River Field Well # SRU 14-15 Actual Completion 06/24/01 CASING AND TUBING DETAIL SIZE WT �6 % 51-0 CONN TOP T 51-5 22" 2,109' i 53 3 Surf = 55-4 55.5 13-3/8" A J-55 5 Surf - 56-9 7" B N-80 8rd LT&C Surf = 59-2 7" 32 8 8rd LT&C 34' 1,030' 7" 29 ,F q 8rd LT&C 1030' - 62-5 7" 26 62-5 8rd LT&C 2276' 5,718' 7" 29 w - 10 11 8rd LT&C 5718' 12 sgzd holes 8500' 32 N-80 8rd LT&C 4 shots 81789' 7" 35 1 14 8rd LT&C 8789' Calc TOC 7" 38 in Tubing @ 19 Calc TOC 10432' 10681' 17 in Casing 11,096' 18 @ 10574' 11,137' 2-7/8" Baker cmt retainer 22 23 24 25 PBTD = 6,375'/ TD = 11,460' MAX HOLE ANGLE = 25°, KOP @ 3800' DRAWN BY: TAB Swanson River Field Well # SRU 14-15 Actual Completion 06/24/01 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BTM 22" 2,109' Macco 2-3/8" SMO -1C1 Chem Inj Mdrl w/1" - 1000 psi chem inj valve w/ 6' pup jts, top & btm 3 Surf 44' 13-3/8" 54.5 J-55 5 Surf 2,967' 7" 38 N-80 8rd LT&C Surf 34' 7" 32 N-80 8rd LT&C 34' 1,030' 7" 29 N-80 8rd LT&C 1030' 2,276' 7" 26 N-80 8rd LT&C 2276' 5,718' 7" 29 N-80 8rd LT&C 5718' 7,367' 7" 32 N-80 8rd LT&C 7367' 81789' 7" 35 N-80 8rd LT&C 8789' 10,432' 7" 38 N-80 8rd LT&C 10432' 11,449' Tubing: 11,096' Camco MM GLM #12 w/dummy 21 11,137' 2-7/8" Baker cmt retainer 2-3/8" 1 4.6 N-80 Buttress Surf 5,310' 24 with 3/8" SS methanol injection line Surf 2,506' JEWELKY DEIAIL NO. Depth Item 1 15.30' 2-7/8" Tbg hgr w/Cameron H BPV profile and 2-7/8" x 2-3/8" buttress xover 2 2,109' Macco 2-3/8" SMO -1C1 Chem Inj Mdrl w/1" - 1000 psi chem inj valve w/ 6' pup jts, top & btm 3 4,910' Macco 2-3/8" D -SO glm w/1" dummy w/ 6' pup jts, top & btm 4 5,246' Baker Locator Seal Assy. size 40-26 5 5,250' Baker Model "DB" Retainer Production packer, 7" 29#, DPM 6 5,264' SBE, XO to 2-%", 4.6#, Butt 7 5,310' WLEG 7A 6,340' CIBP w/ 37' cement 11/10/17 -TOC 6,303' 7B 6,410' C I B P w/ 35' cement 09/10/17 -TOC 6,375' 8 6,574' PosiSet Plug w/ 10' of cement 9 6,700' PosiSet Plug w/ 10' of cement 10 8,300' Bridge Plug in 7" casing, 6/20/01 w/ TOC @ 8,053' 11 8,313' Milled up pkr fish. 12 8,442' Bridge Plug in 7" casing, 11/8/96 13 9,890' 2-7/8" Tubing cut, 10/21/96 14 10,002'- 10,012' Holes in tbg 15 10,125' Camco MM GLM #10 w/dummy 16 10,574' Calc TOC in annulus 17 10,594' Camco MM GLM #11 w/dummy 18 10,681' Calc TOC in tbg 19 10,900' 2-7/8" Baker cmt retainer 20 11,096' Camco MM GLM #12 w/dummy 21 11,137' 2-7/8" Baker cmt retainer 22 11,148' Brown HS -16-1 retr packer 23 11,212' Camco MM GLM #13 w/CEV 24 11,240' Baker Model D packer 25 11,280' Bridge plug Updated by DMA: 12-04/18 0 • Swanson River Field PROPOSED SCHEMATIC Well #SRU 14-15 Iliewp M.A., LLC Actual Completion 06/24/01 PERFORATION DATA ZONE TOP BTM Top TVD Bottom TVD SPF DATE COMMENTS 3,500' 3,500' 3,500' 3,500' 5 06/20/59 sqz 51-0 ±5,382 ±5,392 ±5,347' ±5,357' 6 Proposed TBD 51-5 ±5,467' ±5,484' ±5,429' ±5,445' 6 Proposed TBD 51-5 ±5,505' ±5,543' ±5,466' ±5,502' 6 Proposed TBD 51-5 ±5,543' ±5,550' ±5,502' ±5,509' 6 Proposed TBD 53 ±5,907 ±5,951' ±5,853 ±5,896' 6 Proposed TBD 55-4 ±6,199 ±6,226' ±6,134' ±6,160' 6 Proposed TBD 55-5 6,200' 6,210' 6,135' 6,145' 6 11/16/17 Sundry 317-402 56-9 6,345' 6,365' 6,273' 6,292' 6 09/19/17 Sundry 317-402 59-2 6,425' 6,445' 6,349' 6,367' 4 08/10/01 Isolated 59-2 6,449' 6,459' 6,371' 6,381' 4 08/10/01 Isolated 59-2 6,490' 6,502' 6,410' 6,421' 4 07/29/01 Isolated 61-3 6,550' 6,582' 6,466' 6,496' 4 07/18/01 Isolated 62-5 6,729' 6,758' 6,635' 6,662' 4 070/8/01 Isolated 62-5 6,784' 6,796' 6,686' 6,697' 4 07/08/01 Isolated 68-0 7,457' 7,577' 7,306' 7,415' 4 07/04/01 Isolated 8,500' 8,500' 8,260' 8,260' 4 06/17/59 sqz 11,224' 11,231' 10,794' 10,800' 4 05/29/63 Abdn 11/91 Hemlock 11,262' 11,276' 10,829' 10,842' 4 07/59,02/61 Abdn 11/91 Hemlock 11,290' 11,300' 10,856' 10,865' 4 05/63 Abdn 11/91 DRAWN BY: TAB Updated by DMA: 12-04/18 STATE OF ALASKA OSKA OIL AND GAS CONSERVATION AISSION REPORT OF UN�RY WELL OPERATIONS ., C Y4.SY- q;.iSP iEZ' M1 N. E DE 5 0 j 20" 118 1. Operations Abandon U Plug Perforations hl Fra ture Stimulate U Pull Tubing U A s� u. own Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing ❑ Change Approved rogram ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development Q Stratigraphic ❑ Exploratory ❑ Service ❑ 100-146 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-10145-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028406 Swanson River Unit (SRU) 14-15 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River / Tyonek Gas & Beluga Gas 11. Present Well Condition Summary: 6,474; 6,700; Total Depth measured 11,460 feet Plugs measured 8,300; 8,442 feet true vertical 11,015 feet Junk measured N/A feet Effective Depth measured 6,464 feet Packer measured 5,250 feet true vertical 6,385 feet true vertical 5,220 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 22" 44' 44' Surface 2,967' 13-3/8" 2,967' 2,967' 2,730psi 1,130psi Intermediate Production 11,449' 7" 11,449' 11,005' 4,240psi 5,410psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic p JAN 0 21p19 Tubing (size, grade, measured and true vertical depth) 2-3/8" 4.6# / N-80 5,863' MD 5,811' TVD Packers and SSSV (type, measured and true vertical depth) Baker DB Pkr; N/A 5,250' MD 5,220' TVD N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 150 Subsequent to operation: 0 0 0 2 0 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas WDSPL Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 317-402 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer(&hilcorp.com Authorized Signature: &4mg;� Date: % (8 Contact Phone: 777-8420 Form 10-404 Revised 4/2017/6�/A?///.�;, /l 21, 1 d RBDMSC 0 7 1018 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number I Well Permit Number Start Date End Date SRU 14-15 50-133-10145-01 1 100-146 9/2/17 11/26/18 Dally Operations. 09/02/2017 -Saturday Sign in. Mobe to location. PTW and JSA. Spot trailer mounted wire line unit and crane. Wait on lub, generator and dog house to be trucked from town. Change well head connection to 3" bowen. Unload equipment and use loader to transfer equip to pad. Pad is muddy and ground soft due to rain yesterday. Rig up lubricator and pressure test to 250 psi low and 2,500 psi high. TP - 50 psi. RIH to with SLB PNX tool to 400'. Tool would not power up. POOH. Checked good on surface. Trouble shoot tool. Changed out press/temp section of tool string and RIH to 300'. Tool was working. Ran on in hole with PNX tool and tie into digital log sent from town. Tag at 6,470'. Start logging out of hole at 300' per hour. SLB is at 3,600' as of now and will be logging to 2,500'. 09/03/2017 - Sunday Continue SLB PNX Logging to 2,500'. Run back in hole and do a repeat section from 6,470' to 6,180' and POOH. Rig down lubricator ancle turn well over to field. 09/06/2017- Wednesday Mobe to location. SIMCIPS, PTW and JSA for SLB and Pollard E -Line. Rig up lubricator, hard lines PT hard lines and lubricator to 250 psi low and 4,500 psi high. Start pressuring well up with N2 to push flu.id_back into perfs. Started with 1,800 psi at 1,000 scf/min and pressure went up to 3,950 psi slowly and broke over and down to 3,850 psi at 1,000 scf/min with 97K SCF away. Tried to go in hole with GPT but didn't have enough wt bars. Borrowed some from slickline while regular wt bars brought out from shop. Found fluid level at 6,350' with 3,300 psi on tubing. Brought pressure back up 4,000 psi at 1,200 scf/min and broke over to 3,950 psi at 1,200 scf/min. Check fluid level with GPT tool and fluid had been pushed into perfs at 6,425'. Shut N2 off and pressure went down to 3,250 psi over 30 min and fluid did not enter well bore. Tagged fill at 6,468'. Ran correlation log and send to town. Log was on depth. Pressure up lubricator to 3,900 psi and attempt to run in hole with basket plug. Had to add more wt to buck pressure. RIH and tied into Digital Log sent from town. Set new plug with 3,250 psi on tubing at 6,410'. POOH and looks like good set. Plug was set at 1,945 hrs. Make up 1-11/16"x 20' bailer and load with beads. RIH and dump bail beads in basket at 6,410'. Make 3 runs with cement and dump bail on top of plug at 6,410'. Had to fix or replace blast sub on every run. RIH with last run now. TP - 2,400 psi. Also pressured up lubricator with N2 before we open swab valve on every run. 09/07/2017 - Thursday Continue running in hole with last dump of cement. Dumped cement on top of plug at 6,410'. That gave us 8' of cement on top of plug. Cement in place at 0630 hrs. TP - 2,400 psi. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 14-15 50-133-10145-01 1 100-146 1 9/2/17 11/26/18 Daily Operations: - - 09/08/2017 - Friday Mobe to location. PTW and JSA. SIMOPS with SLB N2 and Pollard E -line. Rig up lubricator. PT to 250 psi low and 2,500 psi high. TP - 2200 psi. RIH w/ 1.75" LIB and closed the vent on the plug at 6,397'. POOH and LIB showed top of vent. MU 1-11/16" x 40' cement dump bailer loaded with 4 gals cement (2.1') and tag TOC on plug at 6,403'. Pick up and dump cement. Made 4 more runs of cement with bailer and dump. Dumped 11' today and 7' yesterday for a total of 18'. Will come back Sunday the 10th and dump 17' more of cement for a total of 35'. Also pressured up lubricator to 2,500 psi before opening swab w/ N2 the first 3 runs today. Then pressured tubing up to 2,350 psi before turning SLB N2 loose. Used 100 gal of N2 today. That leaves us with 3,400 gals left. Cement in place at 1745 hrs. Est TOC 6,392'. Rig down lubricator and WOC. Cement samples are in construction office. 09/10/2017 -Sunday PTW and JSA. Rig up lubricator, PT to 250 psi low and 3,500 psi high. TP - 2,200 psi. RIH w/ 1-11/16" x 40' dump bailer full of 16.9 ppg cement and dump on top earlier cement at 6,392'. Made 6 more runs with bailer (28 gals of cement - 17'). Est TOC at 6,375'. CIP at 1605 hrs. TP - 2,050 psi. Rig down lubricator and WOC. 09/19/2017 -Tuesday PTW and JSA. Rig up lubricator, PT to 250 psi low and 3500 psi high. TP - 1950 psi. RIH with GPT tool and tie into OHL. Tag at 6383'. No fluid level. Worked thru some tight spots until they cleared up. Send log to town. POOH, RIH w/1 - 11/15"x20' Strip, 6 spf, o deg phase and tie into OHL. Run correlation log and send to town. Get ok to..perf from_6345' to 6365'. Spot and fired gun with 1950 psi on well. Pressure went to 1975 psi right away and 2025 psi after 5 minutes. 10 min was 2050 psi. POOH . All shots fired. TP - 2100 psi. Rig down lubricator and turn well over to field. 09/22/2017 - Friday PTW and JSA. Rig up lubricator, PT to 250 psi low and 3500 psi high. TP - 1650 psi. RIH w/GPT tool, tie into OHL and tag fill at 6387'. Found fluid level at 6038'. Tubing pressure was 1650 psi. Send log to town and POOH. Rig down lubricator and turn well over to field. 11/08/2017 - Wednesday Sign in. Mobe to location. PTW and JSA. Spot equipment Rig up lubricator, PT to 250 psi low and 4,500 psi high. TP - 0 psi. Transferred 3,000 gal of N2 from tanker to SLB N2 pump truck. RIH w/ Gamma Ray, 1-11/16" x 20' bailer and sat down at 1,600' and worked bailer to 1,630'. POOH and bailer had a thick slurry of wire line grease in it plus some water. Looks like fluid level is around 1,600'. Add a couple of weight bars and went down and worked thru the spot at 1,600' to 1,630' and tools fell ok. Went down and tagged at 6,380'. Called and talked to town and decided to get N2 pump truck spotted and start first thing in morning. It's going to take about 12 hrs or more to push fluid away, set basket plug and dump beads and 8' of cement with the 1-11/16' dump bailer. Got a fluid sample out of bailer. Rig down lubricator and secure well. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number I Well Permit Number Start Date End Date SRU 14-15 50-133-10145-01 1 100-146 9/2/17 11/26/18 gaily r4ti s" 11/09/2017 -Thursday Sign in. Mobe to location. PTW, JSA and SIMOPS with SLB N/2. Rig up lubricator and N2 hard lines., PT to 250 psi low and 4,500 psi high. TP - 0 psi. Pressure tubing up with N2 from 0 psi to 4,000 psi. Let pressure bleed to 3,200 psi in 30 min. Pressure back up to 4,000 psi and let bleed to 3,200 psi couple more times. RIH and saw FL at 5,170', continue in hole to 6,250'. Pressure tubing back up to 4,000 psi while coming out of hole. Had pumped 110K N2. Bailer full of fluid. Stab back on with lubricator and bailer. Bring pressure back up and pressure broke over at 500 scf/m at 3,950 psi. Kept pushing fluid away at this rate/pressure for approx. 1 hour. Slow rate down to 300 scf/m at 3,250 until SLB pumped 127K scf/approx 1,350 gals of N2. Shut N2 down and RIH with bailer to 6,280'. Sat there for 10 min and pulled out of hole. Bailer was dry. TP - 3,250 psi. Called town and discussed. Decision made to wait until morning to set basket plug. Rig down SLB N2 truck for coil tubing in the AM. Rig down lubricator. TP - 3,250 psi. 11/10/2017 - Friday Sign in. Mobe to location. PTW,JSA. Rig up lubricator, PT to 250 psi low and 4,500 psi high. TP - 2,550 psi. RIH w/ 1- 11/6" x 10' bailer, tie into perf log dated 9-19-17 and stop at 6,330'. Wait 10 min and POOH. Bailer was empty so fluid level was below 6,330'. MU 1-11/16" Neo Basket plug. RIH with plug and tie into perf log dated 9-19-17. Run correlation log and send to town. Get ok to set plug at 6,340'. Spotted basket plug and set plug with 2,500 psi on tubing. POOH. Good set. Had PTW, JSA and SIMOPS with SLB N2 crew that was released from coil job on SRU 241-33. Rig up hard lines and PT lines 250 psi low and 3,500 psi high. RIH with 2 gals of bridging beads and dump in plug basket at 6,340'. POOH. Good dump. Make 3 runs with 1-11/16" x 40' cement dump bailer full of Neo Super Slurry 17# cement (2.66' per bailer/4 gals per bailer equals 8'/12 gals total cement) and dump on top of plug at 6,340'. Est TOC at 6,332' and CIP at 2315 hrs. Good dump on all 3 bailer runs. We pressured lubricator up to 2,550 psi with N2 before opening swab on bead and 2 bailer runs. On the 3d bailer run SLB N2 crew could not get the pump to prime up. Tank showed that there was 10 inches left. SLB said either they were out of N2 or something was wrong with the equipment. Rigged N2 lines down and released crew. They pumped a total of 140 gals. Rick w/SLB said they would check it out and let me know. Rig down lubricator, secure well and WOC. TP - 2,475 psi. 11/12/2017 - Sunday Sign in. Mobe to location. PTW,JSA. Rig up lubricator, PT to 250 psi low and 4,500 psi high. TP - 2,300 psi. RIH w/1.75" LIB centralized and tie into plug log. Tagged at 6,330'. Hit one time down and POOH. Did not have a good impression on the LIB of closing vent. Changed the position of the centralizer. RIH w/1.81" LIB centralized and tie into plug log. Tagged at 6,328'. Hit one time down and closed the plug vent POOH. Had good impression of the plug vent. TP - 2,275 psi. MU 1-11/16" x 40' bailer. RIH with bailer and tie in with plug log. Tagged at 6,330' (Est TOC was 6,332"). Pick up 3' and dump 2.5' of 17# NEO Super Slurry cement. POOH. Good dump. Make 3 more 1-11/16" x 40' cement bailer runs of 17# NEO Super Slurry and dump on top of plug that should put TOC at approx 6,320'. That should leave us with 6 to 7 bailer runs tomorrow depending on where we see TOC. CIP at 1915 hrs. All dumps were good. TP - 2,250 psi. Total cement dumped was 10'. Rig down lubricator and secure well. Will resume dump bailing in the AM. C: Hilcorp Alaska, LLC SIR Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 14-15 50-133-10145-01 1 100-146 9/2/17 11/26/18 Daily Operations: --------------- 11/13/2017 - Monday Sign in. Mobe to location. PTW, JSA. Rig up lubricator, PT to 250 psi low and 4,500 psi high. TP - 2,150 psi. Mix cement. RIH with 1-11/16" x 40' bailer and tie in with plug log. Tagged at 6,331'. Should of tagged at 6,320'. Call town and discussed. Pick up 3' and dump 2.5' of 17# NEO Super Slurry cement at 6,331'. POOH. Good dump. RIH with same bailer loaded with cement and dumped on top at 6,331'. Started out of hole and tool hung up at 5,259' (bottom of bailer). Top of tools are at 5,217'. Work tools but could not get free. We have been having trouble with wireline grease/mud mixture. Called town and discussed. Pumped 1 bbl of diesel and worked tools. Pumped another bbl of diesel and worked tools. Let soak a while but did not come free. Pulled up to max pull. Pumped another bbl of diesel. Will leave tools with a bind on them and have a hand stay out here and pump a bbl of diesel every 4 hours until morning or until tool comes free. Diesel did cut the sample of grease/mud that was taken off bailer but it took 15 to 20 min. Also going to have slickline out here in the morning with E -line to either fish tools, clean up tubing or both. The bottom portion of the bailer is across the packer at 5,250'. Top_of cement est at 6,326'. 11/14/2017 -Tuesday Sign in. Mobe to location. PTW, JSA and SIMOPS with SL. Pumped 3 barrels of diesel last night 4 hours apart. Started with tool wt at 2,100 lbs and worked our weight up to 2,400 lbs at 100 Ib increments. Tools came free at 2,400 Ib tool weight. POOH. Tools were clean. Rig down lubricator. Sign in. Mobe to location. PTW, JSA. Rig up SL lubricator, PT to 250 psi low and 4,500 psi high. TP - 2,150 psi. RIH with 2-3/8" wire line brush and brushed from 5,180' to 5,310' (Tubing Tail) several times. Didn't see any significant trouble. It looks like the diesel pumped cleaned up tubing. POOH. Rig down slickline. Rig up E -line lubricator and 1-11/15" x 40' dump bailer. RIH with 1-11/16" x 40' cement bailer and tie in with plug log. Tagged TOC at 6,326'. Pick up 3' and dump 2.5' of 17# NEO Super Slurry cement at 6,326'. POOH. Good dump. RIH with 1-11/16" x 40' cement bailer and tie in with plug log to 6,323'. Pick up 3' and dump bailer full of water (due to the diesel in well) at 6,323.5'. POOH. Good dump. Wait on Neo casing cleaner. Due to dumping cement in diesel you have to have 10' casing cleaner for 7" casing. Pollard just had 5 gals. Neo sent instructions for a Poor Boy Casing Cleaner. RIH with 1-11/16" x 40' cement bailer and tie in with plug log to 6,323'. Pick up 3' and dump bailer full of Neo Casing Cleaner (due to the diesel in well) at 6,323.5'. POOH. Good dump. TP - 1,900 psi. Rig down lubricator. Pollard is going to mix up 15 gals of Poor Boy Casing Cleaner tonight and will dump it tomorrow. NOTE: Pumped approx. 4-1/2 bbl of diesel/approx. 120' in 7" casing. 11/15/2017 - Wednesday Sign in. Mobe to location. PTW, JSA. Rig up lubricator, PT to 250 psi low and 4,500 psi high. TP - 1,850 psi. Fill lubricator up with 10 gals of Poor Boy Casing Cleaner. Add 3' to bailer. RIH w/ 1-11/16" x 43' dump bailer filled with Poor Boy Casing Cleaner and tie in to plug log. Tag at 6,321'. Pick up 3' and dump 2.66' of cleaner (total of 12' cleaner). POOH. Good dump. Make 6 runs with 1-11/16" x 43' cement bailer and tie in with plug log. Dump 2.66' of 17# NEO Super Slurry cement with each run from 6,321' to 6,305' (total of 35' on top of plug). POOH. Good dump. Rig down lubricator and secure well. Will perf in the morning. TP 1,850 psi. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 14-15 50-133-10145-01 1 100-146 9/2/17 11/26/18 Daily Operations: 11/16/2017 - Thursday Sign in. Mobe to location. PTW, JSA. Rig up lubricator, PT to 250 psi low and 4,500 psi high. TP - 1,800 psi. RIH with CCL/GR, tie into plug log and tag TOC at 6,303'. POOH. RIH w/ 1-11/16" x 10' strip, 0 deg phase, 6 spf and tie into plug log. Run correlation log and send to town. Get ok to perf from 6,200' to 6,210'. Spot and fire gun with 1,800 psi on tubing. Fire gun and saw no change in pressure. POOH. All shots fired. Rig down lubricator and turn well over to field. 11/26/2018 - Monday Received commininglin approval for this well per AOGCC Docket Number: CO-18-015yConservation Order No. 766, dated November 19, 2018 and determined new sundry was needed for additional work. The office work was completed same date Novmeber 26, 2018. • Swanson River Field SCHEMATIC Well # SRU 14-15 L117e-11A[aaka,LLC Actual Completion 06/24/01 RKB to TBG Head =15.30' Tree connection: TC -3 Uni-bolt 1 sqzd holes 3500' 5 shots CBL 5/63 TOC a 3800' 3 4 5 6 7 51-5 55-5 k,.2, 56-9 B dt I 59-2 R 61-3 s2 -s 62-5 - ss -0 NJ-NNN�µ NNNN 11 0 11 12 sqzd holes 8500' 4 shots PBTD = 6,375' / TD = 11,460' MAX HOLE ANGLE = 25°, KOP @ 3800' J CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP Cale TOC 22" 2,109' in Tubing Cale TOC Surf 10681' in Casing J-55 n. 10574' Surf 2,967' 7" 38 N-80 8rd LT&C (210 34' 7" 32 22 8rd LT&C 34' 23 7" 29 24 8rd LT&C 25 2,276' PBTD = 6,375' / TD = 11,460' MAX HOLE ANGLE = 25°, KOP @ 3800' J CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BTM 22" 2,109' Macco 2-3/8" SMO -1C1 Chem Inj Mdrl w/1" - 1000 psi chem inj valve w/ 6' pup jts, top & btm 3 Surf 44' 13-3/8" 54.5 J-55 5 Surf 2,967' 7" 38 N-80 8rd LT&C Surf 34' 7" 32 N-80 8rd LT&C 34' 1,030' 7" 29 N-80 8rd LT&C 1030' 2,276' 7" 26 N-80 8rd LT&C 2276' 5,718' 7" 29 N-80 8rd LT&C 5718' 7,367' 7" 32 N-80 8rd LT&C 7367' 8,789' 7" 35 N-80 8rd LT&C 8789' 10,432' 7" 38 N-80 8rd LT&C 10432' 11,449' Tubing: 11,096' Camco MM GLM #12 w/dummy 21 11,137' 2-7/8" Baker cmt retainer 2-3/8" 4.6 N-80 Buttress Surf 5,310' 24 with 3/8" SS methanol injection line Surf 2,506' JLWLLKY UL IAIL NO. Depth Item 1 15.30' 2-7/8" Tbg hgr w/Cameron H BPV profile and 2-7/8" x 2-3/8" buttress xover 2 2,109' Macco 2-3/8" SMO -1C1 Chem Inj Mdrl w/1" - 1000 psi chem inj valve w/ 6' pup jts, top & btm 3 4,910' Macco 2-3/8" D -SO glm w/1" dummy w/ 6' pup jts, top & btm 4 5,246' Baker Locator Seal Assy. size 40-26 5 5,250' Baker Model "DB" Retainer Production packer, 7" 29#, DPM 6 5,264' SBE, XO to 2-%", 4.6#, Butt 7 5,310' WLEG 7A 6,340' CIBP w/ 37' cement 11/10/17 -TOC 6,303' 7B 6,410' CIBP w/ 35' cement 09/10/17 -TOC 6,375' 8 6,574' PosiSet Plug w/ 10' of cement 9 6,700' PosiSet Plug w/ 10' of cement 10 8,300' Bridge Plug in 7" casing, 6/20/01 w/ TOC @ 8,053' 1i 8,313' Milled up pkr fish. 12 8,442' Bridge Plug in 7" casing, 11/8/96 13 9,890' 2-7/8" Tubing cut, 10/21/96 14 10,002'- 10,012' Holes in tbg 15 10,125' Camco MM GLM #10 w/dummy 16 10,574' Calc TOC in annulus 17 10,594' Camco MM GLM #11 w/dummy 18 10,681' Calc TOC in tbg 19 10,900' 2-7/8" Baker cmt retainer 20 11,096' Camco MM GLM #12 w/dummy 21 11,137' 2-7/8" Baker cmt retainer 22 11,148' Brown HS -16-1 retr packer 23 11,212' Camco MM GLM #13 w/CEV 24 11,240' Baker Model D packer 25 11,280' Bridge plug DRAWN BY: TAB Updated by DMA: 12-04-18 Rile ru Alaska, LLC Swanson River Field SCHEMATIC Well #SRU 14-15 Actual Completion 06/24/01 PERFORATION DATA ZONE TOP BTM Top TVD Bottom TVD SPF DATE COMMENTS 3,500' 3,500' 3,500' 3,500' 5 06/20/59 sqz 55-5 6,200' 6,210' 6,135' 6,145' 6 11/16/17 Sundry 317-402 56-9 6,345' 6,365' 6,273' 6,292' 6 09/19/17 Sundry 317-402 59-2 6,425' 6,445' 6,349' 6,367' 4 08/10/01 Isolated 59-2 6,449' 6,459' 6,371' 6,381' 4 08/10/01 Isolated 59-2 6,490' 6,502' 6,410' 6,421' 4 07/29/01 Isolated 61-3 6,550' 6,582' 6,466' 6,496' 4 07/18/01 Isolated 62-5 6,729' 6,758' 6,635' 6,662' 4 070/8/01 Isolated 62-5 6,784' 6,796' 6,686' 6,697' 4 07/08/01 Isolated 68-0 7,457' 7,577' 7,306' 7,415' 4 07/04/01 Isolated 8,500' 8,500' 8,260' 8,260' 4 06/17/59 sqz 11,224' 11,231' 10,794' 10,800' 4 05/29/63 Abdn 11/91 Hemlock 11,262' 11,276' 10,829' 10,842' 4 07/59,02/61 Abdn 11/91 Hemlock 11,290' 11,300' 10,856' 10,865' 4 05/63 Abdn 11/91 DRAWN BY: TAB Updated by DMA: 12-04-18 OF T7j., � � , s THE STATE •• Alaska Oil and Gas W \may �— LAsKA Conservation Commission oh= ___�=. 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 -41:;:e*?' Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC SCOT=0 NOV 0 9 2017' 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Tyonek Gas & Beluga Gas Pool, SRU 14-15 Permit to Drill Number: 100-146 Sundry Number: 317-512 Dear Mr. Halgeson: 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, Hollis S. French Chair DATED this z day of November, 2017. RDD '1S --- NOV - 2 2017 RECEIVED • • OCT 3 0 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION A Cr'+ APPLICATION FOR SUNDRY APPROVALS /'� 4� 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend El Perforate 0 - Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing ❑ Other: El 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska, LLC Exploratory 0 Development Q • 100-146 ' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-10145-01 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 716.001 ' 1:1Swanson River Unit(SRU)14-15 • Will planned perforations require a spacing exception? Yes ❑ No 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028406 " Swanson River/Tyonek Gas&Beluga Gas - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD):6,375'; Junk(MD): 11,460' ' 11,015' - 6,375' 6,301' 2,120 psi 6,564';6,700';8,300' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 22" 44' 44' Surface 2,967' 13-3/8" 2,967' 2,967' 2,730psi 1,130psi Intermediate Production 11,449' 7" 11,449' 11,005' 4,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-3/8" 4.6#/N-80 5,863' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker DB Pkr; N/A 5,250'MD/5,220'TVD; N/A 12.Attachments: Proposal Summary 0 Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory 0 Stratigraphic 0 Development❑✓ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: November 10,2017 Commencing Operations: OIL ❑ WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS ❑✓ • WAG 0 GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcoro.com '7 Contact Phone: 777-8420 Authorized Signature: Date: /O/IO/( COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: /7 512--• Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0 Other: °,�-m�w�L", i e--1.-�,L, ' 4 c SAS. 5 b j , Ca /r a Post Initial Injection MIT Req'd? Yes 0 No ❑ ,✓a 0 �.f (I .j . Spacing Exception Required? Yes ❑ No Subsequent Form Required: /(j RBB aS 1, -- ' - 2 2017 APPROVED BY Approved by:442 . COMMISSIONER THE COMMISSION Date: I' 14 4( P /, 3,-17 n, R lG1I Submit Form and Form 10-403 Revised 4/2017 pproved application is valid for 12arih! liApLal. �a� ttac mein ua`teplic \\ /t0itt!7 nts sl, /7 • • Well Prognosis Well: SRU 14-15 Hilcorp Alaska,LL Date: 10/27/17 Well Name: SRU 14-15 API Number: 50-133-10145-01 Current Status: SI Gas Well Leg: N/A Estimated Start Date: November 9, 2017 Rig: E-line Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 100-146 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: 2,757 psig (Based on 0.433 psi/ft gradient to TVD) Max. Potential Surface Pressure: 2,120 psig (Based on 0.1 psi/ft gradient to TVD) Brief Well Summary Hilcorp Submitted and received approved Sundry number 317-402 to add perforations in this well. Work from that Sundry is currently being executed. Just prior to filing the Sundry Request, a PNX log was ran to look for by passed pay. Additional intervals were found by using that log and this Sundry application is being filed to be able to perforate and test those additioonaintervals. 1/ • Note: This sundry only includes intervals that are below the current packer. A separate Sundry will be filed for intervals above the packer since those intervals will require putting a rig on the well. Notes Regarding Wellbore Condition • Casing passed MIT to 1,500 psig July 2015. Eline Procedure: 1. MIRU E-line, PT lubricator to 2,500 psi Hi 250 Low. 2. RU Nitrogen. Pressure up on well to push water away. 3. PU RIH with Plug. Set plug above the top perforation. Place 35' of cement on top of plug. WOC. 4. PU RIH with Bailer and tag top of cement. POOH With same. 5. PU wireline guns 6. RIH and perforate the following additional zones individually: (Note:the Beluga Sands must be ✓ isolated from any sands below 5,728' and cannot be comingled.) Zone Sands Top (MD) Btm (MD) FT Beluga 51-0 ±5,382 ±5,392 10 Beluga 51-5 ±5,467' ±5,484' 17 Beluga 51-5 ±5,508 ±5,550 42 Set Isolation Plug ri below Tyonek 53 ±5,907' ±5,951' 44 Tyonek 55-4 ±6,199' ±6,226' 27 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Bleed down tubing pressure per Engineer's instructions prior to perforating. d. Correlate using correlation log. Use Gamma/CCL/to correlate. e. Install Crystal gauges before perforating. Record tubing pressures before and after each perforating run. • • Well Prognosis Well: SRU 14-15 Hilcorp Alaska,LI) Date: 10/27/17 f. All perforations in table above are located in the Tyonek and Beluga Gas Pools based on Conservation Order No. 716.001 7. RD Eline. 8. Turn well over to production for testing. Note: Flowback-Once the well is perforated, the Nitrogen blanket will be flowed back and vented. Once hydrocarbons are detected,the perforated interval will be vented the shortest amount of time possible to confirm that the interval is capable of producing in economic paying quantities. This operation will be manned to minimize the amount of vented gas and once a commercial rate is - established, the well will be either put into the system or shut in until it can be placed on line through the facilities. Hilcorp anticipates that no more than 900 mcfd will be vented per interval and no more than 2 MMscf will be vented for all of the intervals contained in this Sundry Application. If well is not producing gas in paying quantities, see remaining procedures below. 9. RU E-line. 10. Pressure up on well with nitrogen to push water away. 11. PU plug, RIH and same in casing above the top perforation. Place 35' of cement (if room) on top of plug. WOC. 12. PU RIH with Bailer and tag top of cement. 13. Prepare to perforate the next zone following steps 5 through 8. Attachments: 1. Actual Schematic 2. Proposed Schematic • • Swanson River Field SCHEMATIC Well#SRU 14-15 Ilaeor5 Alaeka,LLf, Actual Completion 06/24/01 RKB to TBG Head 15.30' CASING AND TUBING DETAIL Tree connection:TC-3 Uni-bolt SIZE WT GRADE CONN TOP BTM 22" Surf 44' 13-3/8" 54.5 J-55 Surf 2,967' 7" 38 N-80 8rd LT&C Surf 34' 7" 32 N-80 8rd LT&C 34' 1,030' 7" 29 N-80 8rd LT&C 1030' 2,276' _ 7" 26 N-80 8rd LT&C 2276' 5,718' C 7" 29 N-80 8rd LT&C 5718' 7,367' M - -) 7" 32 N-80 8rd LT&C 7367' 8,789' sgzd holes 3500' T 7" 35 N-80 8rd LT&C 8789' 10,432' 5 shots CBL 5/63 TOC - 7" 38 N-80 8rd LT&C 10432' 11,449' @ 3800' Tubing: 2-3/8" 4.6 N-80 Buttress Surf 5,310' with 3/8"SS methanol injection line Surf 2,506' 3 JEWELRY DETAIL >ini 4 NO. Depth Item -I__., I l 1 15.30' 2-7/8"Tbg hgr w/Cameron H BPV profile and 2-7/8"x 2-3/8" buttress xover miis 5 2 2,109' Macco 2-3/8"SMO-1C1 Chem Inj Mdrl w/1"-1000 psi chem inj a valve w/6'pup jts,top&btm 3 4,910' Macco 2-3/8"D-S0 glm w/1"dummy w/6'pup jts,top&btm - 6 4 5,246' Baker Locator Seal Assy.size 40-26 5 5,250' Baker Model"DB"Retainer Production packer,7"29#,DPM 751-5 6 5,264' SBE,XO to 2-%",4.6#,Butt 7 5,310' WLEG T 55-5 7A 6,410' CIBP w/35'cement 09/10/17-TOC 6,375' ___ _ _-56-9 8 6,574' PosiSet Plug w/10'of cement 7A r�____.:�" 9 6,700' PosiSet Plug w/10'of cement 59-2 10 8,300' Bridge Plug in 7"casing,6/20/01 w/TOC @ 8,053' 11 8,313' Milled up pkr fish. .1:"=' 8 12 8,442' Bridge Plug in 7"casing,11/8/96 - 61-3 13 9,890' 2-7/8"Tubing cut,10/21/96 iisie.i 14 10,002'- 10,012' Holes in tbg � 9 T 62-5 15 10,125' Camco MM GLM#10 w/dummy - 68-0 16 10,574' Calc TOC in annulus .7^.-^ : 10 17 10,594' Camco MM GLM#11 w/dummy 11 18 10,681' Calc TOC in tbg ,, 19 10,900' 2-7/8"Baker cmt retainer 12 20 11,096' Camco MM GLM#12 w/dummy sqzd holes 8500' = 21 11,137' 2-7/8"Baker cmt retainer 4 shots 22 11,148' Brown HS-16-1 retr packer 1314 23 11,212' Camco MM GLM#13 w/CEV CaicTOC 24 11,240' Baker Model D packer Calc TOC in Tubing(a3 25 11,280' Bridge plug :::: :>17 10681' in Casing -- iiiii zEEEaI'.€iEiEiiji 18 iiiE??isIis€:€€€is isi i€is 19 !.,_.: .,aii':,ii€iii;;:;20 iiiiiiii iiii is '' .: A 22 23 :: sl 0 24 ilii C = :7125 X PBTD=6,375'/TD=11,460' MAX HOLE ANGLE=25°,KOP @ 3800' DRAWN BY: TAB Updated by DMA: 10/26/17 • • Swanson River Field SCHEMATIC Well#SRU 14-15 Hilcurp Alaska,LLC Actual Completion 06/24/01 PERFORATION DATA ZONE TOP BTM Too TVD Bottom TVD SPF DATE COMMENTS 3,500' 3,500' 3,500' 3,500' 5 06/20/59 sqz 51-5 ±5,505' ±5,543' ±5,466' ±5,502' 6 Proposed Sundry 317-402 55-5 ±6,200' ±6,220' ±6,135' ±6,154' 6 Proposed Sundry 317-402 56-9 6,345' 6,365' 6,273' 6,292' 6 09/19/17 Sundry 317-402 59-2 6,425' 6,445' 6,349' 6,367' 4 08/10/01 Isolated 59-2 6,449' 6,459' 6,371' 6,381' 4 08/10/01 Isolated 59-2 6,490' 6,502' 6,410' 6,421' 4 07/29/01 Isolated 61-3 6,550' 6,582' 6,466' 6,496' 4 07/18/01 Isolated 62-5 6,729' 6,758' 6,635' 6,662' 4 070/8/01 Isolated 62-5 6,784' 6,796' 6,686' 6,697' 4 07/08/01 Isolated 68-0 7;457' 7,577' 7,306' 7,415' 4 07/04/01 Isolated 8,500' 8,500' 8,260' 8,260' 4 06/17/59 sqz 11,224' 11,231' 10,794' 10,800' 4 05/29/63 Abdn 11/91 Hemlock 11,262' 11,276' 10,829' 10,842' 4 07/59,02/61 Abdn 11/91 Hemlock 11,290' 11,300' 10,856' 10,865' 4 05/63 Abdn 11/91 DRAWN BY: TAB Updated by DMA: 10/26/17 • Swanson River Field II 0 PROPOSED SCHEMATIC Well#SRU 14-15 Hilcorp Alaska,LLC Actual Completion 06/24/01 RKB to TBG Head= 15.30' CASING AND TUBING DETAIL Tree connection:TC-3 Uni-bolt SIZE WT GRADE CONN TOP BTM 1 22" Surf 44' 13-3/8" 54.5 J-55 Surf 2,967' 7" 38 N-80 8rd LT&C Surf 34' 7" 32 N-80 8rd LT&C 34' 1,030' 7" 29 N-80 8rd LT&C 1030' 2,276' _ 7" 26 N-80 8rd LT&C 2276' 5,718' C 7" 29 N-80 8rd LT&C 5718' 7,367' M 7" 32 N-80 8rd LT&C 7367' 8,789' sqzd holes 3500' 2 5 shots T 7" 35 N-80 8rd LT&C 8789' 10,432' CBL 5/63 TOC - 7" 38 N-80 8rd LT&C 10432' 11,449' @ 3800' Tubing: 2-3/8" 4.6 N-80 Buttress Surf 5,310' with 3/8"SS methanol injection line Surf 2,506' 3 JEWELRY DETAIL ali 4 NO. Depth Item LII I 1 15.30' 2-7/8"Tbg hgr w/Cameron H BPV profile and 2-7/8"x 2-3/8" 11 E buttress xover iiiiiimoi 5 2 2,109' Macco 2-3/8"SMO-1C1 Chem Inj Mdrl w/1"-1000 psi chem inj 'A E valve w/6'pup jts,top&btm 3 4,910' Macco 2-3/8"D-S0 glm w/1"dummy w/6'pup jts,top&btm 6 4 5,246' Baker Locator Seal Assy.size 40-26 Emit 7 5 5,250' Baker Model"DB"Retainer Production packer,7"29#,DPM 51-0 6 5,264' SBE,XO to 2-%",4.6#,Butt - 51-5 7 5,310' WLEG -r- 55-5 7A 6,410' CIBP w/35'cement 09/10/17-TOC 6,375' -56-9 8 6,574' PosiSet Plug w/10'of cement 7A 9 6,700' PosiSet Plug w/10'of cement 59-2 10 8,300' Bridge Plug in 7"casing,6/20/01 w/TOC @ 8,053' 11 8,313' Milled up pkr fish. � ~~~~N X 12 8,442' Bridge Plug in 7"casing,11/8/96 - 61-3 13 9,890' 2-7/8"Tubing cut,10/21/96 14 10,002'- Holes in tbg _ 62-5 10,012' T 62-5 15 10,125' Camco MM GLM#10 w/dummy - 68-0 16 10,574' CaIcTOC in annulus 10 17 10,594' Camco MM GLM#11 w/dummy 11 18 10,681' Calc TOC in tbg 19 10,900' 2-7/8"Baker cmt retainer 12 20 11,096' Camco MM GLM#12 w/dummy sqzd holes 8500' 21 11,137' 2-7/8"Baker cmt retainer 4 shots 22 11,148' Brown HS-16-1 retr packer 1314 23 11,212' Camco MM GLM#13 w/CEV Calc TOC 24 11,240' Baker Model D packer in Tubing @ 25 11,280' Bridge plug Cale TOCKP g in Casing ... <:::i. 17 10681' Eii Iiiiiiiiis;iillri€€i @ 10574' iiiii t- -�:ii>::>:`p 18 Ii:i:i:i:?e ;a €€ 19 ;.;.. :i•::ii i 20 ::::::::;rA. 23 : ,24 25 t PBTD=6,375'/TD=11,460' MAX HOLE ANGLE=25°,KOP @ 3800' DRAWN BY: TAB Updated by DMA: 10/26/17 • • 11 Swanson River Field PROPOSED SCHEMATIC Well#SRU 14-15 HilcorDAlaska,LLC Actual Completion 06/24/01 'k,,. PERFORATION DATA (/ ZONE TOP BTM Top TVD Bottom TVD SPF DATE COMMENTS 3,500' 3,500' 3,500' 3,500' 5 06/20/59 sqz ,,/ 51-0 ±5,382 ±5,392 ±5,347' ±5,357' 6 Proposed TBD q 51-5 ±5,467' ±5,484' ±5,429' ±5,445' 6 Proposed TBD 51-5 ±5,505' ±5,543' ±5,466' ±5,502' 6 Proposed Sundry 317-402 51-5 ±5,543' ±5,550' ±5,502' ±5,509' 6 Proposed TBD 53 ±5,907 ±5,951' ±5,853 ±5,896' 6 Proposed TBD 55-4 ±6,199 ±6,226' ±6,134' ±6,160' 6 Proposed TBD it 55-5 ±6,200' ±6,220' ±6,135' ±6,154' 6 Proposed Sundry 317-402 56-9 6,345' 6,365' 6,273' 6,292' 6 09/19/17 Sundry 317-402 59-2 6,425' 6,445' 6,349' 6,367' 4 08/10/01 Isolated 59-2 6,449' 6,459' 6,371' 6,381' 4 08/10/01 Isolated "� 59-2 6,490' 6,502' 6,410' 6,421' 4 07/29/01 Isolated /' it 61-3 6,550' 6,582' 6,466' 6,496' 4 07/18/01 Isolated 62-5 6,729' 6,758' 6,635' 6,662' 4 070/8/01 Isolated 62-5 6,784' 6,796' 6,686' 6,697' 4 07/08/01 Isolated 4 ? 68-0 7,457' 7,577' 7,306' 7,415' 4 07/04/01 Isolated // °j/'/ 8,500' 8,500' 8,260' 8,260' 4 06/17/59 sqz /° 11,224' 11,231' 10,794' 10,800' 4 05/29/63 Abdn 11/91 Hemlock 11,262' 11,276' 10,829' 10,842' 4 07/59,02/61 Abdn 11/91 Hemlock 11,290' 11,300' 10,856' 10,865' 4 05/63 Abdn 11/91 DRAWN BY: TAB Updated by DMA: 10/26/17 • v OF Tit, • ti)\��\�7 7s� THE STATE Alaska Oil and Gas il, of®\ T cc T � Conservation Commission ::,,_„€ 1�L�V��lrl Sf �� 333 West Seventh Avenue "-- / GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OAMain: 907.279.1433 S11Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager aleSEP 2 7 2017, Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Tyonek Gas and Beluga Gas Pools, SRU 14-15 Permit to Drill Number: 100-146 Sundry Number: 317-402 Dear Mr. Helgeson: 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. Per 20 AAC 25.215(b), commingling of production from two or more pools is prohibited with an order from the AOGCC. 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, CLOSZE— -- Hollis S. French Chair DATED this 1'4 day of September, 2017. RBDMS 1,, ba' 1 9 2017 • tt r EIV D STATE OF ALASKA U 2 17 ALASKA OIL AND GAS CONSERVATION COMMISSION c l APPLICATION FOR SUNDRY APPROVALS ,O 7 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations Er Fracture Stimulate 0 Repair Well 0 Operations shutdown❑ Suspend ❑ Perforate Q Other Stimulate 0 Pull Tubing ❑ Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Ng- p,7 t, Hilcorp Alaska,LLC Exploratory 0 Development ❑✓ 100-146 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service 0 6.API Number: Anchorage Alaska 99503 50-133-10145-01 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 716.001 Swanson River Unit(SRU)14-15 1=IWill planned perforations require a spacing exception? Yes No ✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028406 • Swanson River/Tyonek Gas 7 ` ��, " ? ii ,�4e',i,(7 11. PRESENT WELL CONDITION SUMMARY !-. Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD):6,474'; Junk(MD): 11,460' 11,015' 6,464' 6,385' 2,120 psi 6,700;8,300';8,442' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 22" 44' 44' Surface 2,967' 13-3/8" 2,967' 2,967' 2,730psi 1,130psi Intermediate Production 11,449' 7" 11,449' 11,005' 4,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: . Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-3/8" 4.6#/N-80 5,863' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker DB Pkr;N/A 5,250'MD/5,220'TVD;N/A 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ElBOP Sketch 0 Exploratory ❑ Stratigraphic 0 Development ❑✓ Service 0 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: September 5,2017 OIL 0 WINJ ❑ WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS ❑✓ WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerehilcora.com Contact Phone: 777-8420 Authorized Signature: `i�jl� Date: Q/ZZ//7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 -7- y02_, Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDIVIS C1uSEP 1 9 2017 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0— &/©LI APPROVED BY Approved by: aLK1 �-- COMMISSIONER THE COMMISSION Date: 1 y' (L1 J( j/ i"/Z - / 4 /i Submit FForm ends'7 Fo0 rm 10-403 Revised 4/2017 pfr9ivalid for 12 months from the date of approval. Attachments in Duplicate • S Well Prognosis Well: SRU 14-15 Hilcorp Alaska,LI) Date:08/22/17 Well Name: SRU 14-15 API Number: 50-133-10145-01 Current Status: SI Gas Well Leg: N/A Estimated Start Date: September 5, 2017 Rig: Moncla 401 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 100-146 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: 2,757 psig (Based on 0.433 psi/ft gradient to TVD) Max. Potential Surface Pressure: 2,120 psig (Based on 0.1 psi/ft gradient to TVD) Brief Well Summary SRU 14-15 was drilled in 1959 as a Hemlock producer and remained active until 1983. It produced a total of 14MBO &62MMCF of gas. In 1991 the Hemlock was abandoned by pumping cement below retainer. Several attempts were made to produce shallow gas without success. The well is currently shut-in. The purpose of this work/sundry is to add perforations in the Lower and Upper Beluga formations and test each interval individually. Notes Regarding Wellbore Condition • Last tag at 6,471' WLM on 7/6/2015 w/a 1.860" GR. • Well will be tested in current open zone (59-2) prior to any procedures below. • Casing passed MIT to 1,500 psig July 2015. Pre-Sundry Work • Run a cased hole PNX log through tubing to look for bypassed pay. Eline Procedure: 1. MIRU Eline, PT lubricator to 2,500 psi Hi 250 Low. 2. RU Nitrogen. Pressure up on well to push water away. 3. PU RIH with Plug. Set plug @ 6,410 feet. Place 35' of cement on top of plug. WOC. 4. PU RIH with Bailer and tag top of cement. POOH With same. 5. PU wireline guns 6. RIH and perforate the following zones individually: Zone Sands Top (MD) Btm (MD) FT sc)f' Beluga LB 51-0 ±5,505' ±5,543' 38 he, teGS Tyonek LB 55-5 ±6200' ±6220' 20 �17:;i4,,e Tyonek LB 56-9 ±6,345 ±6,365 20 0 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. 4fe,s� c. Bleed down tubing pressure per Engineer's instructions prior to perforating. d. Correlate using correlation log. Use Gamma/CCL/to correlate. e. Install Crystal gauges before perforating. Record tubing pressures before and after each perforating run. • • Well Prognosis Well: SRU 14-15 Hileorp Alaska,LLQ (-7"- d Date:08/22/17 f. All perforations in table above are located in the Beluga Pool based on Conservation Order No. 716.001 p ( 7. RD Eline. as1) 8. Turn well over to production for testing. /� g- f(./7 If well is not producing gas in paying quantities,see remaining procedwieA below. 9. RU E-line. Zv 44'—' Zs a )1�'r`•`�ki.,�l' 10. Pressure up on well with nitrogen to push water away. 44' r'-,-'Jt`r717Q„"/ -icw eel-6 11. PU plug, RIH and same in casing above the top perforation. Place 35' of cement(if room) on top of plug. WOC. , GhJ /0411iac 12. PU RIH with Bailer and tag top of cement. �- z 13. Prepare to perforate the next zone following steps 5 through 8. 1,47 Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Current Wellhead Drawing 4. Proposed Wellhead Drawing ••H Swanson River Field SCHEMATIC Well#SRU 14-15 Hilcorp Alaska,LLC Actual Completion 06/24/01 RKB to TBG Head = 15.30' CASING AND TUBING DETAIL Tree connection:TC-3 Uni-bolt SIZE WT GRADE CONN TOP BTM 22" Surf 44' l' 1 13-3/8" 54.5 J-55 Surf 2,967' 7" 38 N-80 8rd LT&C Surf 34' 7" 32 N-80 8rd LT&C 34' 1,030' 7" 29 N-80 8rd LT&C 1030' 2,276' _ 7" 26 N-80 8rd LT&C 2276' 5,718' C 7" 29 N-80 8rd LT&C 5718' 7,367' Z M 7" 32 N-80 8rd LT&C 7367' 8,789' s5 holes 3500' T 2 7" 35 N-80 8rd LT&C 8789' 10,432' 5 shots CSL 5/63 TOC = 7" 385 N-80 8rd LT&C 10432' 11,449' @ 3800• Tubing: 2-3/8" 4.6 N-80 Buttress Surf 5,310' with 3/8"SS methanol injection line Surf 2,506' 3 JEWELRY DETAIL It 4 NO. Depth Item L'I II; I 1 15.30' 2-7/8"Tbg hgr w/Cameron H BPV profile and 2-7/8"x 2-3/8" I JE buttress xover asiamossmso 5 2 2,109' Macco 2-3/8"SMO-1C1 Chem lnj Mdrl w/1"-1000 psi chem inj A E valve w/6'pup jts,top&btm 3 4,910' Macco 2-3/8"D-50 glm w/1"dummy w/6'pup jts,top&btm 6 4 5,246' Baker Locator Seal Assy.size 40-26 5 5,250' Baker Model"DB"Retainer Production packer,7"29#,DPM 7 6 5,264' SBE,XO to 2-%",4.6#,Butt 7 5,310' WLEG - 59-2 8 6,574' PosiSet Plug w/10'of cement - 59-2 9 6,700' PosiSet Plug w/10'of cement R 10 8,300' Bridge Plug in 7"casing,6/20/01 w/TOC @ 8,053' - 59-2 11 8,313' Milled up pkr fish. 12 8,442' Bridge Plug in 7"casing,11/8/96 - 61-3 13 9,890' 2-7/8"Tubing cut,10/21/96 14 10,00T- Holes in tbg - ••- 10,012' - 62-5 15 10,125' Camco MM GLM#10 w/dummy T 62-5 16 10,574' Calc TOC in annulus - 68-0 17 10,594' Camco MM GLM#11 w/dummy .12"---...241.1)" .'^'^•"d'"' w 10 18 10,681' Calc TOC in tbg 11 19 10,900' 2-7/8"Baker cmt retainer 12 20 11,096' Camco MM GLM#12 w/dummy sgzd holes 8500' 21 11,137' 2-7/8"Baker cmt retainer 4 shots 22 11,148' Brown HS-16-1 retr packer 13 23 11,212' Camco MM GLM#13 w/CEV 14 24 11,240' Baker Model D packer igaleTOc 25 11,280' Bridge plug Calc TOC in Tubing in Casing .i.. :..17 10681' PERFORATION DATA @ 10574• �•".•• "`` 18 ZONE TOP BTM Top TVD Bottom TVD SPF DATE COMMENTS `I""'I i.... 19 3,500' 3,500' 3,500' 3,500' 5 06/20/59 sqz `P. :a>.. >:'20 59-2 6,425'• 6,445' 6,349' 6,367' 4 08/10/01 1-11/16 PJ Strip Egg22 59-2 6,449' • 6,459' 6,371' 6,381' 4 08/10/01 1-11/16 PJ Strip 23 59-2 6,490'• 6,502' 6,410' 6,421' 4 07/29/01 Isolated }{ '..;.I -24 61-3 6,550' . 6,582' 6,466' 6,496' 4 07/18/01 Isolated A 62-5 6,729' • 6,758' 6,635' 6,662' 4 070/8/01 Isolated 62-5 6,784' ' 6,796' 6,686' 6,697' 4 07/08/01 Isolated - :725 68-0 7,457' • 7,577' 7,306' 7,415' 4 07/04/01 Isolated 2/ 8,500' 8,500' 8,260' 8,260' 4 06/17/59 sqz L l 11,224'• 11,231' 10,794' 10,800' 4 05/29/63 Abdn 11/91 ,v,*,:' „ _''"1 `, ° , Hemlock 11,262'. 11,276' 10,829' 10,842' 4 07/59,02/61 Abdn 11/91 PBTD=6,464'/TD=11,460' Hemlock 11,290' • 11,300' 10,856' 10,865' 4 05/63 Abdn 11/91 MAX HOLE ANGLE=25°,KOP @ 3800' SRU 14-15 Schematic 08-18-17 Updated by DMA:08/18/17 DRAWN BY:TAB 0 •11 Swanson River Field PROPOSED SCHEMATIC Well#SRU 14-15 Hilcorp Alaska,LLC Actual Completion 06/24/01 RKB to TBG Head=15.30' CASING AND TUBING DETAIL Tree connection:TC-3 Uni-bolt SIZE WT GRADE CONN TOP BTM - 1 22" Surf 44' 13-3/8" 54.5 J-55 Surf 2,967' 7" 38 N-80 8rd LT&C Surf 34' 7" 32 N-80 8rd LT&C 34' 1,030' 7" 29 N-80 8rd LT&C 1030' 2,276' 7" 26 N-80 8rd LT&C 2276' 5,718' _ C 7" 29 N-80 8rd LT&C 5718' 7,367' Z M 7" 32 N-80 8rd LT&C 7367' 8,789' sqzd holes 3500' 2 5 shots T 7" 35 N-80 8rd LT&C 8789' 10,432' CBL 5/63 TOC - 7" 38 N-80 8rd LT&C 10432' 11,449' @3800' Tubing: 2-3/8" 4.6 N-80 Buttress Surf 5,310' with 3/8"SS methanol injection line Surf 2,506' 3 JEWELRY DETAIL 4 NO. Depth Item L:_11111111111111111 1 15.30' 2-7/8"Tbg hgr w/Cameron H BPV profile and 2-7/8"x 2-3/8" �, buttress xover 5 2 2,109' Macco 2-3/8"SMO-1C1 Chem Inj Mdrl w/1"-1000 psi chem inj �� valve w/6'pup jts,top&btm 3 4,910' Macco 2-3/8"D-SO glm w/1"dummy w/6'pup jts,top&btm 6 4 5,246' Baker Locator Seal Assy.size 40-26 5 5,250' Baker Model"DB"Retainer Production packer,7"29#,DPM 6 5,264' SBE,XO to 2-%",4.6#,Butt 510 7 5,310' WLEG = 55-5 8 6,574' PosiSet Plug w/10'of cement E59 2 ' 59-2 9 6,700' PosiSet Plug w/10'of cement c R 10 8,300' Bridge Plug in 7"casing,6/20/01 w/TOC @ 8,053' - 59-2 11 8,313' Milled up pkr fish. 12 8,442' Bridge Plug in 7"casing,11/8/96 = 61-3 13 9,890' 2-7/8"Tubing cut,10/21/96 9 14 10,002•- Holes in tbg 10,012' - 62-6 15 10,125' Camco MM GLM#10 w/dummy 62-5 16 10,574' Calc TOC in annulus T- 68-0 17 10,594' Camco MM GLM#11 w/dummy µ,:,, +r'�r 10 18 10,681' Calc TOC in tbg 11 19 10,900' 2-7/8"Baker cmt retainer 20 11,096' Camco MM GLM#12 w/dummy 12 21 11,137' 2-7/8"Baker cmt retainer sqzd holes 8500' 22 11,148' Brown HS-16-1 retr packer 4 shots 23 11,212' Camco MM GLM#13 w/CEV 1314 24 11,240' Baker Model D packer Cale TOC 25 11,280' Bridge plug Cale Toc1 } in Tubing@ 1068' PERFORATION DATA in Casing €:•<i'iii I" `;18 ZONE TOP BTM Top TVD Bottom TVD SPF DATE COMMENTS @10574' If?€:€:I:I'.1' ;ii: :: 19 3,500' 3,500' 3,500' 3,500' 5 06/20/59 sqz II.::::;:::a:iiiiii i i i 20 LB 51-0 ±5,505' ±5,543' ±5,466' ±5,502' ±38 Proposed TBD _ 22 55-5 ±6,200' ±6,220' ±6,135' ±6,154' ±20 Proposed TBD • !:I iii'"'I�> : :'FA,ri 56-9 ±6,345' ±6,365' ±6,273' ±6,292' ±20 Proposed TBD 23 59-2 6,425' 6,445' 6,349' 6,367' 4 08/10/01 1-11/16 PJ Strip '""""I' / 59-2 6,449' 6,459' 6,371' 6,381' 4 08/10/01 1-11/16 PJ Strip 59-2 6,490' 6,502' 6,410' 6,421' 4 07/29/01 Isolated G -7125 61-3 6,550' 6,582' 6,466' 6,496' 4 07/18/01 Isolated \ 62-5 6,729' 6,758' 6,635' 6,662' 4 070/8/01 Isolated n� 62-5 6,784' 6,796' 6,686' 6,697' 4 07/08/01 Isolated Z , 68-0 7,457' 7,577' 7,306' 7,415' 4 07/04/01 Isolated 8,500' 8,500' 8,260' 8,260' 4 06/17/59 sqz PBTD=6,464'/TD=11,460' 11,224' 11,231' 10,794' 10,800' 4 05/29/63 Abdn 11/91 MAX HOLE ANGLE=25°,KOP @ 3800' Hemlock 11,262' 11,276' 10,829' 10,842' 4 07/59,02/61 Abdn 11/91 Hemlock 11,290' 11,300' 10,856' 10,865' 4 05/63 Abdn 11/91 SRU 14-15 Proposed Schematic 08-22-17 Updated by DMA:08/22/17 DRAWN BY:TAB • • • II Swanson River SRU 14-15 12/22/2016 ttiln.rp AhuLi.t.t.0 Swanson River Tubing hanger,Shaffer T55- SRU 14-15 AJ0,7 X 2 7/8 BTC lift and 133/8 X7 X23/8 susp,w/2%Type H BPV profile,3/8 control line,PN: 421810 BHTA, B-15-A, is • 2 9/16 5M FE mir Valve swab,WKM-L, - . 1r 2 9/16 5M FE HWO AA �, Cross,stdd,2 9/16 5M X 2 1/16 5M II ?lif i. ' Valve upper master,WKM-L, ', 1s ' 2 9/16 5M FE,HWO,AA , • Valve lower master, WKM-L,2 9/16 5M FE,HWO, ; > /„® Adapter,Shaffer A10, AA ` 7 1/16 5M stdd X 2 9/16 5M,IA Void test good 5/27/09 . /, npt control line port 250/5000psi Ground Level Tubing head, Shaffer _ , ` T55-LI, 13 5/8 3M X =•:�i ,- 7 1/16 5M w/2-2 1/16 5M U U I ® ---.viii Valve,WKM-M,2 1/16 5M SSO, 7"Type 1 secondary FE,HWO,AA trim seal in head ;, ° - �, Qty 2 Tubing head 1996 placed in I` *- ' f v®- IIIW11.1 .6.11P1 I Irti, Casing head, Shaffer KD, t 1 t 1 Valve,plug,Rockwell,2" 13 5/8 3M X 13 3/8 SOW, (k LPO, w/2-2" LPO, 7" KD slips Ill1.0, .i.,..,and packoff assy in head a • • Swanson River SRU 14-15-proposed 08/22/2017 aiknrp ‘huka.LIR: Swanson River Tubing hanger,Shaffer T55- SRU 14-15 A10,7 X 2 7/8 BTC lift and 13 3/8 X 7 X 2 3/8 susp,w/2%Type H BPV profile,3/8 control line,PN: 421810 BHTA,Otis,2 9/16 5M FE X 3"Bowen Quick Union a'` EEIEBEEEEEEm •\$ c) "r" Esea c�smt C�` gyp, \Ca,1 e Valve,Swab,WKM-M, r., e. <p" fie' 44\ 2 9/16 5M FE,HWO,DD trim - -. -At' ah • -At' �' yF n [s s. €tetpit 1,,\ \'. O ,,■ a� i w�% glitalAgg INT[ a amea s Valve,Master,WKM-M, °} � a 2 9/16 5M FE,HWO,DD trim .1: iliEd Eat kEEEPEAREP EELEtwili Valve,Master,WKM-M, ` 17 Or.. ''''''QII 2 9/16 5M FE,HWO,DD trim Shaffer-A10, � 7 1/16 5M stdd X 2 9/16 5M,'/: i. :ter + :#21 npt control line port Ground Level Tubing head, Shaffer - 7111 ., T55-LI, 13 5/8 3M X ,NN ® N*�� 7 1/16 5M w/2-2 1/16 5M illi F III - Valve,WKM-M,2 1/16 5M SSO,7"Type 1 secondary - FE,HWO,AA trim seal in head c T - crag Qty 2 Tubing head replaced in 1 �.1� 1 "IIIIIA111 11'11- 1996 ,1996 III ,} Ill Casing head,Shaffer KD, III Ell Valve,plug,Rockwell,2" 13 5/8 3M X 13 3/8 SOW, v�lj LPO, w/2-2" LPO, 7" KD slips lei . I and packoff assy in head3 KR • • Davies, Stephen F (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Thursday, September 7, 2017 3:51 PM To: Davies, Stephen F (DOA) Cc: Donna Ambruz; Chad Helgeson; Schwartz, Guy L (DOA) Subject: RE: SRU 14-15 (Permit 100-146, Sundry Application 317-402) - Question Attachments: Tyonek_Gas_Pool_Cross-Section.pdf Steve, I have requested and obtained from our geologist an updated cross section (see attached). The black line on the cross section indicates the top of the Tyonek Gas Pool. Hilcorp is in agreement with your assessment that the LB 51-0 interval is above the Tyonek Gas Pool and in the Beluga Gas Pool. I suggest we fix this by adding a note that the LB 51-0 interval cannot be comingled with the perforations below it. This should not be an issue in actuality because we have been required by BLM in this field to set plugs and place cement on top of all abandoned zones prior to moving up to the next interval. Please let me know if this is acceptable to the Commission. I do appreciate you catching this error. It is MUCH easier to correct this issue in advance than to go back and try to repair it after it happens. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, September 06, 2017 5:21 PM To:Ted Kramer<tkramer@hilcorp.com> Cc: Donna Ambruz<dambruz@hilcorp.com> Subject: RE: SRU 14-15 (Permit 100-146, Sundry Application 317-402) -Question Hi Ted, I built a cross-section that ties SRU 14-15 to SCU 41-04(the reference log for CO 716.001 that establishes the vertical gas pool boundaries). My quick well log correlations place the top of the Tyonek Gas Pool in SRU 14-15 at about 5725' MD, rather than 5380' MD as you note below. As I currently see it,the LB 51-0 interval lies within the Beluga Gas Pool, not within the Tyonek Gas Pool. So, per 20 AAC 25.215(b), production from Hilcorp's planned perfs between 5505' and 5543' MD can't be commingled with production from any of the underlying perfs without an order issued by the 1 • . AOGCC. Or maybe my correlations are incorrect. Could Hilcorp please provide a cross-section that ties SRU 14-15 to SCU 41-04 and demonstrates the planned LB 51-0 perfs in SRU 14-15 will lie within the Tyonek Gas Pool rather than in the Beluga Gas Pool? Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From:Ted Kramer [mailto:tkramer@hilcorp.com] Sent:Tuesday, September 5, 2017 3:44 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Cc: Donna Ambruz<dambruzPhilcorp.com> Subject: RE: SRU 14-15 (Permit 100-146, Sundry Application 317-402) -Question Steve, SRU 14-15 is correlated for the top of Tyonek Gas Pool at 5,380' MD. Although I called the LB 51-0 interval Beluga, it does fall within the Tyonek Gas Pool as defined above. I hope this helps. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 From: Davies,Stephen F(DOA) [mailto:steve.daviesPalaska.gov] Sent: Monday,August 28, 2017 9:28 AM To:Ted Kramer<tkramer@hilcorp.com> Subject:SRU 14-15 (Permit 100-146, Sundry Application 317-402) -Question Ted, What is Hilcorp's measured depth for the top of the Tyonek Gas Pool in SRU 14-15? 2 • • SRU 14-15 is governed by Conservation Order 716, with pool vertical boundaries revised by Conservation Order 716.001. Neither of these orders address commingling of production. Please be aware that, per 20 AAC 25.215(b), commingling of production within the same wellbore from two or more pools is prohibited without an order issued by the AOGCC. Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.daviesPalaska.gov. 3 • • SCU_341-04 SRU_14-15 (#4) 12/31/1959 3/29/1959 ♦ 0 0' 1' 44 msmolimmamMr.-!=moi Ear iiiiiiiiii..in iaw,----... 1 7 a=[--�03n r■■■ [[[_--�-�� gas■■ Mid: ail=:lss11=111 „;n1■ ... , '-`°6 me -.._ _e .■ ....._ MI 11110iirEll 9111111 i aim II IN . it--- _i`NN ,-- m ,E POOL.PULE _- •— Ir H■IPI i - s 1 ; ■cw=■■ MS z [■ '. Boli-E 0 di- Num no sae - 11-Nall-.. - r EM � ■►--- ■ii_= - sa r s-easB C. +�� lialltarmrial -moi a=cam S ■o---ice1 .pil earee< s io■n■■■[■----- 4 lait.'N ZS II BEIM=MU. ear --- = MEAN MEE — —_-- W • PM �- ...... o see°I ii.cc-E3-�-�� i-; Mr I "-TY-'' rJ a , I i wil MENEM =is a ,5 0) 1 ..........1 ... 1...1 111111111MMINIPM s- ;� �:i ■ tea - - .411.11111 MilliiIIIIII -: II nK���II 1 1 FIE WM. 11111i II MN ina.....0 eA,~6e.e, -4 swim NMI ri inn ' -Mil ill- .711111111.11n ■-- 5,1,65407 _ 7 luf�■�■M LP4 11 ■ ■•5---�FA INN_E■[ 111111. 4■■C:S1S��S- ■iJ :11 1111101111111 MN 11 tea— !)o■■■■ii---�d in 111111110M MOM��__ MEIN”- „ sea �W ri 1iiiiiii=11in=f'I�i K4 ® UU■■aa■ua Ty 6x41!--- MEM MMMIIIIIIIIII MUM C_4111 MEMP9 MN -� MMIME_■ii----W- I1 �■■ --- 51,ry_50.251.W. _.7...3 me 111'.10 MUM ea,v6��e�! ■ca■i"i ■ M L7 Ul�.� 4111 III NtE illtE Ca _ 11.11111E>• MI eo 11i MINI MI IF 1.) -111.4 6141 -�I � 163981 meillE ii mainsiois - Rzeiii a! a tMR= in _■■■----ice91 NM 1111111111111111111112 -n■5141■ 4 SCU_341-04 SRU_114-115(#4) • • • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Wednesday, September 6,2017 5:21 PM To: Ted Kramer Cc: Donna Ambruz Subject: RE: SRU 14-15 (Permit 100-146, Sundry Application 317-402) - Question Hi Ted, I built a cross-section that ties SRU 14-15 to SCU 41-04(the reference log for CO 716.001 that establishes the vertical gas pool boundaries). My quick well log correlations place the top of the Tyonek Gas Pool in SRU 14-15 at about 5725' MD, rather than 5380' MD as you note below. As I currently see it,the LB 51-0 interval lies within the Beluga Gas Pool, not within the Tyonek Gas Pool. So, per 20 AAC 25.215(b), production from Hilcorp's planned perfs between 5505' and 5543' MD can't be commingled with production from any of the underlying perfs without an order issued by the AOGCC. Or maybe my correlations are incorrect. Could Hilcorp please provide a cross-section that ties SRU 14-15 to SCU 41-04 and demonstrates the planned LB 51-0 perfs in SRU 14-15 will lie within the Tyonek Gas Pool rather than in the Beluga Gas Pool? Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies( alaska.gov. From:Ted Kramer[mailto:tkramer@hilcorp.com] Sent:Tuesday, September 5, 2017 3:44 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Cc: Donna Ambruz<dambruz@hilcorp.com> Subject: RE: SRU 14-15 (Permit 100-146, Sundry Application 317-402)-Question Steve, SRU 14-15 is correlated for the top of Tyonek Gas Pool at 5,380' MD. Although I called the LB 51-0 interval Beluga, it does fall within the Tyonek Gas Pool as defined above. I hope this helps. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 1 • • C 985-867-0665 From: Davies,Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday,August 28, 2017 9:28 AM To:Ted Kramer<tkramer@hilcorp.com> Subject:SRU 14-15 (Permit 100-146, Sundry Application 317-402)-Question Ted, What is Hilcorp's measured depth for the top of the Tyonek Gas Pool in SRU 14-15? SRU 14-15 is governed by Conservation Order 716,with pool vertical boundaries revised by Conservation Order 716.001. Neither of these orders address commingling of production. Please be aware that, per 20 AAC 25.215(b), commingling of production within the same wellbore from two or more pools is prohibited without an order issued by the AOGCC. Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 2 • • • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Monday, August 28, 2017 9:28 AM To: Ted Kramer Subject: SRU 14-15 (Permit 100-146, Sundry Application 317-402) - Question Ted, What is Hilcorp's measured depth for the top of the Tyonek Gas Pool in SRU 14-15? SRU 14-15 is governed by Conservation Order 716, with pool vertical boundaries revised by Conservation Order 716.001. Neither of these orders address commingling of production. Please be aware that, per 20 AAC 25.215(b), commingling of production within the same wellbore from two or more pools is prohibited without an order issued by the AOGCC. Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 1 y � • Chevron September 22, 2010 Timothy C Brandenburg Drilling Manager Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Well Status Change Dear Commissioner, • Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com EP 2 4. 2010 Union Oil Company of California would like to report a change of status for well Swanson Riv Unit 114-15 API 50-133-10145-01 PTD 100-146 rom 'SUSP' to 1 -GAS". During a review of the wellbore conditions, it appears this well does not meet the requirements for a suspended well per the revised Suspended Well Regulations 20 AAC 25.110. Please let us know if we can provide any further information by contacting myself at 263-7657 or Larry Greenstein at 263-7661. Sincerely, Timothy C. Brandenburg Drilling Manager Attachments: Form 10-404 in duplicate and Actual Well Schematic. Union Oil Company of California / A Chevron Company STATE OF ALASKA ALASKOL AND GAS CONSERVATION COMMISSIN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Repair Well Lj Plug Perforations Lj Stimulate Li Other [:✓j Well Status Change Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re-enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 15. Permit to Drill Number: Name: Development ✓❑ Exploratory ❑ Stratigraphic❑ Service ❑ 00-146 3. Address: PO Box 196247, Anchorage, AK 99519 . API Number: 50-133-10145-01 00 7. PropertkDesignation (Lease Number): 8. Well time an�Number: FEDA028406 [Swanson River Unit] Swanson Riv Unit 14-15 9. Field/Pool(s): 11-1 Swanson River Field / Hemlock Oil & Tyonek Gas Pool 10. Present Well Condition Summary: 6,474', 6,700', Total Depth measured 11,460 feet Plugs (measured) 8,300', & 8,442' feet true vertical 11,015 feet Junk (measured) N/A feet Effective Depth measured 6,464 feet Packer (measured) 5,250 feet true vertical 6,385 feet (true vertical) 5,220 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 22" 44' 44' Surface 2,967' 13-3/8" 2,967' 2,967' 2,730 psi 1,130 psi Intermediate Production 11,449' 7" 11,449' 11,005' 7,240 psi 5,410 psi Liner _,waft Z;.rA; Perforation depth: Measured depth: 6,425'-6,445', 6,449'-6,459' True Vertical depth: 6,348'-6,367', 6,371'-6,380' Tubing (size, grade, measured and true vertical depth): 2-3/8" 4.6# N-80 5,863' MD AM 5,810'TVD Packers and SSSV (type, measured and true vertical depth): Baker DB Packer 5,250'MD(5,220'TVD) N/A N/A 11. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf I Water -Bbl TCasing Pressure Tubing Pressure Prior to well operation: 0 0 10 1110 psi 110 psi 1110 Subsequent to operation: 0 0 10 1110 psi psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development❑✓ Service ❑ Daily Report of Well Operations N/A 15. Well Status after work: Oil Gas [:✓j WDSPL GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG ❑ 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Chris Kanyer 263-7831 Printed Name T' y . Brandenburg Title Drilling Manager Sigtures Phone 276-7600 Date 9/21/10 �. RBDMS SEP 2 7 2P,'1 AV7-�_' Form 10-404 Revised 7/2009 Submit Original Only 0 Swanson River Field UNOCAL 76 Well # SRU 14-15 Actual Completion 06/24/01 RKB to TBG Head = 15.30' Tree connection: TC -3 Ifni -halt PBTD = 10829' TD =11460' MAX HOLE ANGLE = 25°, KOP @ 3800' Mt mt CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BTM 22" 2109 Macco 2-3/8" SM0-1C1 Chem Inj Mdrl w/1" - 1000 psi chem in' valve w/ 6' pup its, top & btm 2. Surf 44' 13-3/8" 54.5 J-55 4. Surf 2967' 7" 38 N-80 8rd LT&C Surf 34' 7" 32 N-80 8rd LT&C 34' 1030' 7" 29 N-80 8rd LT&C 1030' 2276' 7" 26 N-80 8rd LT&C 2276' 5718' 7" 29 N-80 8rd LT&C 5718' 7367' 7" 32 N-80 8rd LT&C 7367' 8789' 7" 35 N-80 8rd LT&C 8789' 10432' 7" 38 N-80 8rd LT&C 10432' 11449' Tubing: 11212 Camco MM GLM #13 w/CEV 4 11240 Baker Model D packer 2-3/8" 4.6 N-80 Buttress Surf 5863' with 3/8" SS methanol injection line Surf 2506' JEWELRY DETAIL NO. Depth Item SPF 15.30 2-7/8" Tbg hgr w/Cameron H BPV profile and 2-7/8" x 2- 3/8" buttress xover 1. 2109 Macco 2-3/8" SM0-1C1 Chem Inj Mdrl w/1" - 1000 psi chem in' valve w/ 6' pup its, top & btm 2. 4910 Macco 2-3/8" D -SO glm w/1" dummy w/ 6' pup jts, top & btm 3. 5246 Baker Locator Seal Assy. size 40-26 4. 5250 Baker Model "DB" Retainer Production packer, 71129#, DPM 5. 5264 SBE, XO to 2 %" 4.6#, Butt 6. 5310 WLEG 6490 6502 59-2 7. 8300 Brid a Plug in 7" casing, 6/20/01 w/ TOC 8,053' 8. 8313' Milled up pkr fish. 9. 8442 Bridge Plug in 7" casing, 11/8/96 10. 9890 2-7/8" Tubing cut, 10/21/96 4 10002-10012 Holes in tb 6784 10125 Camco MM GLM #10 w/dumm 4 10574 Calc TOC in annulus 7457 10594 Cameo MM GLM #11 w/dumm 4 10681 Calc TOC in tb 8500 10900 2-7/8" Baker cmt retainer 4 11096 Cameo MM GLM #12 w/dumm 11224 11137 2-7/8" Baker cmt retainer 4 11148 Brown HS -16-1 retr packer 11262 11212 Camco MM GLM #13 w/CEV 4 11240 Baker Model D packer 11290 11280 Bride plug PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 3500 3500 5 6/20/59 s z 6425 6445 59-2 4 8/10/01 1-11/16 PJ Strip 6449 6459 59-2 4 8/10/01 1-11/16 PJ Strip 6490 6502 59-2 4 7/29/01 Isolated 6550 6582 61-3 4 7/18/01 Isolated 6729 6758 62-5 4 7/8/01 Isolated 6784 6796 62-5 4 7/8/01 Isolated 7457 7577 68-0 4 7/4/01 Isolated 8500 8500 4 6/17/59 s z 11224 11231 4 5/29/63 Abdn 11/91 11262 11276 Hemlock 4 7/59,2/61 Abdn 11/91 11290 1 11300 Hemlock 4 5/63 Abdo 11/91 SRU 14-15 Schematic 6-24-01.doc REVISED: 9/22/2010 DRAWN BY: TAB Chi ' n Dale Haines Union Oil Company of California Alaska Area Operations P.O. Box 196427 M. Manager Anchorage,AK 99519-6247 Tel 907 263 7951 Fax 907 263 7607 Email Daleah@chevron.com (' March 31, 2009 Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 SCANNED APR 0 1 2D14 Re: Suspended Wells Dear Commissioner Foerster, Please find the attached corrections to the suspended and long term shut in well list as provided in your letter dated January 28, 2009. As per our discussion the submitted list needs to be expanded to include additional wells that may not currently be identified on the list provided by the Commission. We also provide the Commission with an annual shut in well report that is sent to Steve McMains. This report was mailed to the Commission on March 30, 2009. At this time I cannot validate that we have provided the Commission with a comprehensive list of all suspended wells so it is our intention to validate the two lists and to review our records to ensure that we have accurately responded to the request. We will therefore endeavor to provide a comprehensive list to the Commission in the next two weeks. Chris Myers will contact Jim Regg to discuss the scheduling inspections of the suspended wells in 2009. If you have any questions about this submittal, please contact myself. Sincerely, 6.)1c Dale Haines Alaska Area Operations Manager Attachment Cc: Tim Brandenburg Chris Myers Dave Cole Union Oil Company of California/A Chevron Company http://www.chevron.com Corrections for the referenced list of suspended and long-term shut-in wells operated by UNOCAL. Well Name API# PTD Current Listed Status Corrected Status Bruce 18742#40 50-733-20339-00 181-022 Suspended Shut-In SRU 14-15 50-133-10145-01 100-146 Suspended Shut-In SCU 243B-04 50-133-20489-00 199-055 Suspended Shut-In H t. _ _._,_ '.` i -1\ + SARAH PAUN,GOVERNOR ALASKA y�cgg�� OIL AND ALASKA AND =AS 33a W.7th AVENUE.SUITE 100 CONSERVATION COMMISSION ANCHORAGE.ALASKA 995013539 PHONE (907)279-'4a3 January 28, 2009 FAX (907)27675:2 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 6019 Dale l lames UNOCAL, 380( Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut-1n Well Information Dear Mr. I lames: Enclosed arc the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed is a list of suspended and long-term shut-in wells operated by UNOCAL. For each list, please verify the information for each well and provide any corrections by April I, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Rcgg at 907-793-1236 or jim.regg(i,?alaska.gov. I I'you have _vy questions regarding this notice, please CnniPet Tom M_itlnd.^r at 9(17-791- 1250 or tom.maundcr@alaska.gov. Sincerely, 0147,4( (/ Cathy P. Foerster Commissioner l;nclosures L • c. N. NI n A CD CD CO C) v CD O CO CO O CO NV VN' . .. 'N7 N 0 CA Cr) O) 0 O Ll CO 0 _ n n O C- n n n n N. N. n K) CA O W •7 Ni. M M V N 12 f0 CO V O CO CO CO CO CO CD CO n CO CO W N N G) e0 CO v n r N N N N N N N N 'L 5 o 0 0) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 •� ¢ 0 0 0 0 0 0 0 0 0 0 0 0 ¢ ¢ < < < < ¢ < Q W J J J J J J J J J J J J 00000000 Z 1., W W 0 0 0 Q 0 0 0 0 0 Q 0 0 w w W w w w w w %., .r LL IL < < < < < < < < < < < < LL LL LL LL LL LL LL LL Cn (/) N Cn CA to U) Lr) CO 0 cn U) N CJ) 0 0 0 0 U) N U) N \.. 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C� p„ �. rr J W I+ 0 _ ` 9 W o 00 0000000 99A 99999999 `� Q M W in M tO n M CV d L� rt = 0 r O ID CCpp rn CO c n 0 c •a• - Z CJ ' ^ CD N q' r N p CD O O) ••? co O co n E. x 8 t0 O O O O o O O $ ~ O Oi y O e1- 0 0 0 O O ,. (") CO W O Q O) CO O) CD Nt. h. CO CA K) �` O) C7 Z C) 8 N 8 N N N C�) •. y O Ni ct co O) CD CD tO n n Zi-) O) V CO n ' rn r CD`O cD n co N i .. Z c k~ v r. r.4 C ▪ 0 CC C., 0 Q C C co C.) ix z C) r. U sm.t V` MN* � Cs) U) �i) LL O • 0 P-I :J U) J coJ A...1 C s- : CA 0 V) 0)V cd _ cr. Q fcv . V '` MC = MO MI V1 Z o C. N Q I- CO = m 0 Q Z Z U (��[ O ~ O ...4 9 Q L Q - C U N •; p O V N 0 CV Q p z 1 p CO o N. C 0 1-4z, \ 3- g -. zi vp Z ''L' rnrr C V O - ti 20 $.AC 25.1 10. Suspended wells (a) if allowed under 20 AAC 25.105. the commission will, upori application by the operator under(b) of this section, approve the suspension of a well is (1) the well (A) encounters hydrocarbons of sufficient quality and quantity to indicate that the well is capable of producing in paying quantities, as reasonably demonstrated by well tests or interpretive formation evaluation data; for purposes of this paragraph, "paying quantities" means quantities sufficient to yield a return in excess of operating costs; (B) is a candidate for redrilling; (C) has potential value as a service well; or (I)) is located on a pad or platform with active producing or service wells; and (2) the operator justifies to the commission's satisfaction why the well should not he abandoned, and, if the well is not completed, why the well should not be completed; sufficient reasons include the (A) unavailability of surface production or transportation facilities; (B) imprudence of security maintenance of a completed well in a shut-in status; (C) need for pool delineation and evaluation to determine the prudence of pool development. (b) An Application for Sundry Approvals (Form 10-403) must be submitted to and approved by the commission before plugging operations are begun in a well for which suspension is proposed, except that oral approval may be obtained from the commission if it is followed within three days by the submission of an Application for Sundry Approvals for final approval by the commission. Approval will be conditioned as • necessary to protect freshwater and hydrocarbon resources. An Application for Sundry Approvals must include (1) the reason for suspending the well and information showing that the applicable criteria for suspension under(a)of this section have been met; and (2) a statement of proposed work, including (A) information on abnormally geo-pressured strata; (B) the manner of placement, kind, size, and location, by measured depth, of existing and proposed plugs; (C) plans for cementing, shooting, testing, and removing casing; (D) if the Application for Sundry Approvals is submitted alter beginning work, the name of the representative of the commission who provided oral approval, and the date of the approval; and (E) other information pertinent to suspension of the well. (c) At the operator's request accompanying the submission, information submitted to show that the applicable criteria for well suspension under (a) of this section have been met will be kept confidential (1) for the period specified under AS 31.5.035 (c), if the information is described in 20 AAC 25.0710) ; or (2) for the time that the information has value as a trade secret, if tic information is not described in 20 AAC 25.071(h) but is determined by the commission to constitute a trade secret under AS 45.50.940 . (d) A well approved for suspension must be plugged in accordance with the requirements of 20 AAC?S_1 12. except that the requirements of 20 AAC 25.112(d) do not apply if (I) a wellhead is installed or the well is capped with a mechanical device to seal the opening; and (2) a bridge plug capped with 50 feet of cement or a continuous cement plug extending 200 feet within the interior casing string is placed at or above 300 feet below the surface; the commission will waive the requirement of this paragraph for a development well drilled from a pad or platform, if the commission determines that the level of activity on the pad or platform assures adequate surveillance of that development well. (e) Until a suspended well has been abandoned or re-entered, the operator shall maintain the integrity of the location, provide the commission with a well status report every five years, and clear the location in accordance with 20 AAC 25.170(a) (2) or (b) or with 20 AAC 25,172(c) (2) or(d), as applicable. History: Eff. 4/2/86, Register 97; am 11/7/99,Register 152 Authority: AS 31.05.030 1, 0 v _t 4E.(0 • ,\ 1.1 \:..\ _o Iv/ iii.7. iiii [ L! `` / { n E ' I Po 1 r :LI ' / SARAH PALIN,GOVERNOR ALASKA OIL AND GAS / 333 W 7th AVENUE,SUITE 100 CONSERVATION COMMISSION , ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 January 28, 2009 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 6019 Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: Notice of Revised Suspended Wells Regulations lKE1� APR 2014 and Request for Verification of Suspended and Shut-In Well Information Dear Mr. Haines: Enclosed are the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed is a list of suspended and long-term shut-in wells operated by UNOCAL. For each list, please verify the information for each well and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or jim.regg@alaska.gov. If you have any questions regarding this notice, please contact Tom Maunder at 907-793- 1250 or tom.maunder@alaska.gov. Sincerely, a/747, Cathy P. Foerster Commissioner Enclosures U.S. Postal Service, CERTIFIED MAIL, RECEIPT D (Domestic Mail Only;No Insurance Coverage Provided) —u For delivery information visit our website at www.usps.com:. LT" WO IAL. U ;, I1JPostage $ $0.59 I•:44 SPS p�wi, OCertified Fee $2.70 tt c) Dp Return Receipt Fee Z ;f (Endorsement Required) $2.20 9 ? // D Restricted Delivery Fee ru (Endorsement Required) $0.00 CA. c0 AK yScc. rl Total Postage&'--- d $5.49 01/28/ y"- C:1 sant To Dale Haines D UNOCAL N Street,Apt.No.; or PO Box No. 3800 Centerpoint Dr. Ste 100 City State,ZJP+ Anchorage AK 99503 ■ PS Form 3800,' . J SENDER: COMPLETE THIS SECTION COMPLETE THIS SECTION ON DELIVERY ■ Complete items 1,2,and 3.Also complete A. vgnature I Print your name and address one ethe reverse X \ X,vLva--Vi '1 item 4 if Restried Delivery is dsired. \47 ❑SIA nt ddresse so that we can return the card to you. ec Reived b)5(Printed Name) C. a of 1 li ry 111 Attach this card to the back of the mailpiece, 9 /ry or on the front if space permits. ka ;rtt� i " �) ��( +' D. Is delivery address different from item 1? ❑ Yes' i 1. Article Addressed to: If YES,enter delivery address below: 0 No Dale Haines UNOCAL 3 800 Centerpoint Dr. Ste 100 S (vice Type i Anchorage AK 99503 rtified Mail 0 Express Mail 0 Registered c.q eturn Receipt for Merchandise I 0 Insured Mail 0 C.O.D. i 4. Restricted Delivery?(Extra Fee) ❑ Yes 2. Article Number (Transfer from service label) 7005 1820 0001 2499 6019 PS Form 381 1, February 2004 Domestic Return Receipt 102595-02-M-1540, • 0 co (O a 0 a a a a a a (OV Oa) a) On) CD 0 CO O) cod0 a _ n n 0 n N- n n n n n n I O CO O a a M M a ao O O ti O O O O O O O O r N N N N N N N N 10) N v O 00U) 0000000 00 GA Q U 0 0 0 0 0 0 0 0 0 0 0 0 Q .:( < < < < Q Q SI SI 0 W J J J J J J J J J J J J 0 0 0 0 0 0 0 0 y w w 0 0 0 0 0 0 0 0 0 0 0 0 W W W W W W W W .a U. 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REC[:IVED API< 2 n 2.(J05 UNOCALqj) .- Alaska Timothy C. Brandenburg Drilling Manager Unocal Alaska Tel 907.263.7657 Cell 907-3507920 Fax 907-263-7884 E-mail: brandenburgt@unocal.com Alaska Oil f!:J. Gas Cons. Cornrnìssitm Anchorage April 29, 2005 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W. ih Avenue Anchorage. Alaska 99501 Re: Request for Variance-Swanson River Mr. Aubert, We are requesting a variance of 20 MC 25.285 (c) (9) and (10). We are preparing to perform well intervention work with a "well servicing unit" provided by Nabors Alaska Drilling, currently stacked at Swanson River. We augmented the BOP equipment on the unit to satisfy our internal standards. Last year we worked with you to obtain a variance to work over several wells in the Swanson River field. We continue to believe the proposed system is superior in well control capabilities to BOPE configurations that are presently in use in the United States and Canada for wells with equivalent pressure and flow regimes. I L}(P lÆ) 'Ö -' We are greatly appreciative of your consideration of this proposal and look forward to meeting with you to discuss any issues with the proposed configuration. Attached you will find a brief description of the wells to be worked on; the highest maximum anticipated surface pressure (MASP) and the proposed BOP configuration. Additionally you will find a schematic of the proposed BOPE layout. Sincerely, ·-7 ~. ~c<h Timothy C:~ndenbUrg Drilling Manager --~'''<,"'''''/''.'''''- . _.~.........,,.. -" -. ¡(;I\NNEfJ NO\¥ 1 1lD05· Attachments Union Oil Company of California I Unocal Alaska 909 West 9th Avenue. Anchorage. Alaska 99501 http://WINW.unocal.com ) ) Well Descriptions Well Work Inventory SCU 32-08 SRU 23-15 SCU 22-04 SCU 314-04 SRU 14-15 100- (4-b SRU 12-15 Reservoir The highest BHP of any well to be worked on at this time is 3000 psi @ 10,900' TVD (Hemlock) which is equivalent to a .275 psi/ft gradient or a 5.29 ppg EMW. Fully evacuated, the MASP would be as follows: 3000 psi BHP - (10,900' TVD x .1 psi/ft Gas Gradient) = 1,91 Opsi MASP. Proposed ConfiQuration BOP's Annular,5K 7-1/16" or 11" Double gate, 5K, 7-1/16" or 11" Mud Cross, 7-1/16" and 11" (optional based on BOP height) Accumulator 1 - 90 gallon Bounty Accumulator System 9-10 gallon Barksdale Control Valves Marsh Gauges 1 - Pump, Union Pump Comp., Model #BIT-532-55 1 - Newman Electric Motor 4 - 11 Gallon Nitrogen Bottles Pits The pit consists of a 150 bbl tank partitioned into 50 bbl compartments. Pump The pump is an Western Roughrider 1000 Triplex on an independent skid. The pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. Kill Line The Kill Line/Circulating Line will consist of 2", 3000 psi Iron or 2", 5000 psi hoses with integral Fig 1502 hammer Unions. Kill Line Valves The kill line valves will consist of, at a minimum, 2 ea. manually operated, 2-1/16", 5K valves attached to either the mud cross or the tubing spool annulus valve. ) ) , . Choke Line Valves The choke line valves will consist of, at a minimum, 2 ea. manually operated, 2-1/16". 5k valves that will be attached to either the outlet below the lower rams on the double gate or the mud cross. Choke Line The choke line will consist of 2", 5,000 psi hoses with 2-1/16" 5m API Flange. Choke Manifold The choke manifold is 2-1/16", 5K with two manual chokes and four valves. Choke Return Line/Gas Buster Line The gas buster line will consist of 2", 5000 psi hose with 1502 Unions. The line will run from the choke manifold to the gas buster. Gas Buster The gas buster is located in one of the three 50 bbl compartments of the pits. It is constructed with an open bottom that utilizes the hydrostatic level in the tank for the water leg. The gas buster vents vertically. Gas Detection We are proposing that a single gas LEL monitor be placed at the work platform. PVT We are proposing to work with out a PVT system as the wells to be worked will not be capable of circulation at surface or the reservoir will be isolated. UNOCAL SWANSON ------ ............... ~ I ~ ~ ,---- I I I II Pipe Ram " I I " Blinds II I I I ~ps.I~ 2" 5M MGV 2" 5M MGV I m [}] 0]11" or 7-1/16" 5M Annular 5M Studded Top and Flanged Bottom ~11" or 7-1/16" 5M DBL --' ~ Optional 3111" or 7-1/16" 5M Drilling Spool wI 2 ea 4" 5M OTL 12", 5m Hose wI flange connections. 1 11" or 7-1/16" 5M Hydril Annular BOP 2 11" or 7-1/16" 5M Shaffer LWS Double BOP 3 11" or 7-1/16" 5M Drilling Spool w/2 ea 4" 5M OTL (Optional) 4 2 1/16 5M Manual Gate Valve 5 2 1/16 5M Manual Gate Valve 6 2 1/16 5M Manual Gate Valve 7 2 1/16 5M Manual Gate Valve '_/ 2" 5m High Pressure hose. To Flow Back Tank (36) "suspended well" means a well that has been plugged as required by 20 AAC 25.105 and held ia abeyance pending a determination to either complete the well as a service or pro- ducible well or to abandon the well; Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe) Dan Williamson Drilling Manager 9/14/O 1 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Subsequent Well Work Report; SRU 14-15 Workover Swanson River Field, Alaska Dear Commissioner Heusser: Unocal Alaska Resources hereby submits its subsequent report of wellwork operations for the subject well. Please find enclosed a Well Recompletion Report (Form 407), a Workover Summary Report and an updated wellbore schematic. If you have any questions or require additional information, please contaCt Bill Penrose at 258-3446. Dan Williamson Drilling Manager ,~/asks Oil &,~Gas, Cons. -- ~ ~'t°mm':;s'r:'..r~ ,-,nd ioraqe ORIGINAL (. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: X SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Unocal Alaska Resources 100-146 3. Address 8. APl Number 909 W. 9th Avenue, P.O. Box 196247, Anchorage, AK 99519-6247 50- 133-10145-01 4. Location of well at surface 9. Unit or Lease Name X: 346163, Y: 348600 Swanson River Unit At Top Producing Interval (10280' MD top of Hemlock) 10. Well Number SRU #14-15 At Total Depth 10,960' MD 11. Field and Pool X: 348600, Y: 2477348 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Swanson River Field/Hemlock 15' KBI A-028406 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 1 21. Thickness of Permafrost 11460' MD/11016' TVD 8053' MD/7847' TVD Yes: x No:I NA feet MDI NA 22. Type Electric or Other Logs Run None during workover 23. CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 22" 15 44' Cmtd to surface 0 13-3/8" 54.5# J-55 15 2967' 17-1/2" Cmtd to surface 0 7" 38, 32, 29, 26 N-80 15 11,449' 8-1/2" Cmtd f/TD to 3,800' O' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" 5,311' 5,250' 6,425' - 6,445' MD / 6,348' - 6,367'TVD 6,449' - 6,459' MD/6,371' - 3,379'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) N/A I ,, Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD --> Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE => 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. SEP 2 (~ Z001 ,~l~.~s~.30ii & Gas Co~'~s. A,qchor~.~ge Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGINAL Submit in duplicate -29. 3O. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and fime of each phase. F"'~"'ii' ~'~ ................ ,~.. '~,, ~. i~ .... 11, , .~ ~ ,. ~. , SEP Atssk~ Oi~ ~, Gas Oons. Commission 81. LIST OF A~AOHM~NT8 Wellbore schematic, Daily 8umma~ of Rig Opemtion~ Form 10-407 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ORIGINAL Unocal Alaska Drilling Workover Summary Report SRU 14-15 6113101 to 6124/01 6/13/01 6/14/01 6/15/01 6/16/O 1 6/17/01 6/18/01 6/19/01 6/20/01 6/21/01 6/22/01 6/23/01 6/24/01 7/3/01 7/4/01 7/8/01 Accepted H&R Rig #9 at 00:00 hrs. Monitor pressures. Run GR to 5,822'. Set PX plug and prong in x-nipple at 5,822'. Bleed down tbg and monitor. Pressure test annulus to 1,500 psi- OK. Perforate tubing at 5,750'. Mix 15.7 ppg mud. Displace tubing and annulus with 15.7 ppg kill weight mud. Monitor well to ensure dead. Remove tree and N/U BOP stack. Finish installing BOPs. Test BOPE. Pull tbg hanger out of wellhead and tbg seals out of packer. Circulate well. POH w/old completion. R/D GBR and clear floor. Change BOP rams to 3-1/2" and test. Load 3-1/2" drill pipe and BHA. Commence picking up packer milling BHA and RIH. RIH w/packer milling assy on 3-1/2" drill pipe, breaking circulation several times. Mill packer. Circulate out gas. Complete circulating out gas. Finish milling packer. Chase packer to bottom at 8,313'. Circulate hole until mud properties evened out. POH w/packer milling assy. Continue POH. M/U and RIH w/cement retainer on drill pipe. Set retainer at 8,300'. POH w/setting tool. Rig up to cement, hold safety meeting, pressure-test lines. Pump 8 bbls of Class G (w/ additives) cement and spot on top of retainer. Displace with mud and POH. Continue POH and L/D cement retainer running tool. M/U and RIH w/5-3/4" mill and 7" casing scraper to 8,047'. Could not circulate. P/U 5 stands and break circulation. RIH, breaking circ. every stand. Found hard cement at 8,053'. Weight tested w/15,000 lbs w/ pump on - OK. Cmt plug is 247' long. Reduce mud weight to 12.5 ppg and commence cleaning pits. Clean mud pits. Displace mud in well w/lease water and haul off mud for disposal. Displace water in well w/9% KCl brine and haul water off for disposal. POH, L/D BHA. RIH w/production packer on drill pipe and set at 5,250'. POH, L/D drill pipe. Finish L/D drill pipe. RIH w/completion and space out. Circulate inhibited brine into annulus. Land tubing. Pressure test tubing and casing. N/D BOPE, N/U tree. Test tree to 5,000 psi - OK. Clean pits and release rig at 23:59 hrs, 6/24/01. Displace completion fluid with gas lift gas. MIRU wireline. M/U 1-11/16" strip guns and RIH. Tie in and perforate the 68-0 Sand 7,457' - 7,477' with 4 SPF, 0 deg phasing. POH, all shots fired. RDMO wireline. MIRU wireline. M/U 1-11/16" strip guns and RIH. Guns misfired, POH. M/U new 1- 11/16" strip guns and RIH. Tie in and perforate the 62-5 Sand 6,784 - 6,796' with 4 SPF, 0 deg phasing. POH, all shots fired. M/U 1-11/16" strip guns and RIH. Tie in and 7/12/01 7/13/01 7/16/O 1 7/17/01 7/18/01 7/29/01 8/8/01 8/10/01 perforate the 62-5 Sand 6,729 - 6,758' with 4 SPF, 0 deg phasing. POH, all shots fired. RDMO wireline. MIRU wireline. RIH w/Posi-set packer and set at 6,700'. POH. RIH w/dump bailer w/ cement and dump 1 load of cement on plug. Make dump bailer runs #2 through #5. Top of cement at 6,690', 10' above packer. MIRU wireline. M/U 1-11/16" strip guns and RIH. Tie in and perforate 6,542' - 6,574' with 4 SPF, 0 deg phasing. POH, gun stuck at 1,391' Pull loose and POH with wire - guns left in hole. R/D wireline, R/U slickline. Make multiple runs w/varying tools. Push fish from 349' to 1,288'. Continue to work fish down to 6,622' (68' above cement on Posi-set packer). RDMO slickline, R/U wireline. M/U 1-11/16" strip guns and RIH. Tie in and perforate the 61-3 Sand 6,550'- 6,582' with 4 SPF, 0 deg phasing. POH, all shots fired. RDMO wireline. MIRU wireline. M/U 1-11/16" strip guns and RIH. Tie in and perforate the 59-2 Sand 6,490' - 6,502' with 4 SPF, 0 deg phasing. POH, all shots fired. RDMO wireline. MIRU wireline. RIH w/Posi-set packer and set at 6,474'. POH. RIH w/5 dump bailer runs w/cement and dump 10' of cement on plug. TOC at 6,464'. MIRU wireline. M/U 1-11/16" strip guns and RIH. Tie in and perforate the 59-2 Sand 6,425 - 6,445' with 4 SPF, 0 deg phasing. POH, all shots fired. M/U 1-11/16" strip guns and RIH. Tie in and perforate the 59-2 Sand 6,449' - 6,459' with 4 SPF, 0 deg phasing. POH, all shots fired. RDMO wireline. UNOCALe RKB to TBG Head = 15.30' Tree connection: TC-3 Uni-bolt sqzd holes 3500' 5 Shots CBL 5/63 TOC @ 3800' 2 3 6~74' 6700' .qqzd holes 8500' 4 shots Calc TOC in Casing @ 10574' 10 PosiSet Plug w/10' ofcmt 61-3 PosiSet Plug w/10' of cml I -- 68-0 Calc TOC in Tubing 10681' PBTD = 10829' TD = 11460' MAX HOLE ANGLE = 25% KOP @ 3800' 14-15 Dwg 6-24-01 Swanson River Field Well # SRU 14-15 Actual Completion 06/24/01 I1 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BTM 22" Surf 44' 13-318" 54.5 J-SS Surf 2967' 7" 38 N-80 8rd LT&C Surf 34' 7" 32 N-80 8rd LT&C 34' 1030' 7" 29 N-80 8rd LT&C 1030' 2276' 7" 26 N-80 8rd LT&C 2276' 5718' 7" 29 N-80 8rd LT&C 5718' 7367' 7" 32 N-80 8rd LT&C 7367' 8789' 7" 35 N-80 8rd LT&C 8789' 10432' 7" 38 N-80 8rd LT&C 10432' 11449' Tubing: 2-3/8" 14.6 IN-S0 I Buttress Surf 5863' with 3/8" SS methanol injection line Surf 2506' JEWELRY DETAIL NO. Depth Item 15.30 2-7/8" Tbg hgr w/Cameron H BPV profile and 2-7/8" x 2- 318" buttress xover 1. 2109 Macco 2-3/8" SMO-1C1 Chem Inj Mdrl w/l" - 1000 psi chem inj valve wi 6' pup jts~ top & btm 2. 4910 Macco 2-3/8" D-SO giro wll" dummy w/6' pup jts, top & btm 3. 5246 Baker Locator Seal Assy. size 40-26 4. S250 Baiter Model "DB" Retainer Production packer, 7" 29#, DP/VI 5. 5264 SBE~ XO to 2-%'~ 4.6#~ Butt 6. 5310 WLEG 7. 8300 Bridge Plug in 7" casin~ 6/20/01 w/TOC O 8~053' 8. 8313' Milled up pkr f'mh. 9. 8442 Bridge Plug in 7" casing, 11/8/96 10. 9890 2.7/8" Tubing cutp 10/21/96 lO0O2.10o12 Holes in tbfl 10125 Cameo MM GLM #10 w/dnmmy 10574 Calc TOC in annulus 10594 Camco MM GLM #11 w/dummy 10681 Calc TOC in tbg 10900 2-7/8" Baker cmt retainer 11096 Camco MM GLM #12 w/dummy 11137 2-7/8" Baker cmt retainer 11148 Brown HS-16.1 retr packer 11212 Camco MM GLM #13 w/CEV 11240 Baker Model D packer 11280 Bridge plug PERFORATION DATA .TOP BTM ZONE SPF DATE COMMENT.S. 3500 3500 5 6/20/59 sqz 6425 6445 59-2 4 8/10/01 1-11116 PJ Strip 6449 6459 59-2 4 8/10/01 1-11/16 PJ Strip 6490 6502 59.2 4 7/29/01 Isolated 6550 6582 61-3 4 7/18/01 Isolated 6729 6758 62-5 4 7/8/01 Isolated 6784 6796 62-5 4 7/8/01 Isolated 7457 7577 68-0 4 7/4/01 Isolated 8500 8500 4 6/17/59 sqz 11224 11231 4 5/29/63 Abdn 11/91 11262 11276 Hemlock 4 7/59~ 2/61 Abdn 11/91 11290 11300 Hemlock 4 5/63 Abdn 11/91 REVISED: 9/25/2001 DRAWN BY: TAB FW: Swanson Workover Program F~900FOLDEDSHIPMENT. jp,q Name: 900FOLDEDSHIPMENT.jpg'] Type: JPEG Image (image/jpeg) Encoding: base64 ~ Name: 900WEIGHTBOX.jpg [~-~900WEIGHTBOX. ip.q Type: JPEG Image (image/jpeg) I Encoding: base64 I Name: Swanson Gas Anchor. doc ~Swanson Gas Anchor. doc Type: WINWORD File (application/msword) Encoding: base64 4 of 4 513/01 10:05 AM ;'Poor Boy" Gas Anchor Gas breaking out of production LProduction Production Production Casing -- 2-7/8" Tubing RXBC Rod Pump Seating Nipple, 2-7/8" Cup Type w/2.280" ID 2-7/8' Ported Sub 1.660" Dip Tube w/ 10 rd Box x 72 MS btm 3 its of 2-7/8" 'Fail Pipe 2-7/8" ()tis "R" type Profile Nipple w/plug, 2,188" ID -- L 2-7/8" Ported Sub LocSet Packer w/o Element FW: Swanson Workover Program ., Subject: F'W: Swanson Workover Program Date: Thu, 3 May 2001 08:47:11 -0800 From: "Bill Penrose" <bill~fairweather.com> To: "Tom Maunder \(E-mail\)" <tom_maunder@admin.state.ak. us> Tom, For your information and records: This is the same e-mail i sent you on 511101 except that I've changed the discussion of BOPE to be used when running rods in the rod pump conversions. Please dispose of that previous message as the BOP discussion was grieviously in error. Thanks! Bill ---Original Message .... From: Bill Penrose [mailto:bill~,fairweather. com] Sent: Tuesday, May 01, 2001 8:57 AM To: Tom Maunder (E-mail) Subject: RE: Swanson Workover Program Tom, Following each question that you posed is the answer, preceded with an A: One big question. What rig is proposed? A: H&R Rig #9, being imported from Canada. SRU 14.15... -What are the BHPs of the old interval and the new? Unless there is a possibility of a high pressure zone (there are a few out there), 3000 psi sounds appropriate. A: BHP of the old interval is 4,900 psi and will only flow water. The BHP of the new interval is 3,000 psi and is expected to flow gas. The request for testing the BOPs to only 3,000 psi as well as not installing an SSV is an artifact from one of the other programs. Please disregard it. It is our intention to test the BOPs to 5,000 psi. -You request not to have a SSV since the well will not flow unassisted, but this is a gas well. Is the SSV request an artifact from another program? A: Yes, as stated above, the SSV request is an artifact. Please disregard it. -Do you plan to do a casing test in the pre rig work or prior to perfing? A: We will perform a casing test after plugging the presently perforated interval. -How the well will look after workover is not too difficult to imagine, but a drawing will help as I move it up the line. A: I will generate proposal drawings ASAP and get them to you. -What gas rate is expected? Will 2-3/8" tubing limit the production? A: The gas rate is expected to be ~2MMSCFD which will not be limited by the 2-3~8" tubing.. 1 of 4 5/3/01 10:05AM FiN: Swanson Workover Program .. -What zone/sand is the new completion in? A: The Tyonek 62-5 Sand SRU 234-15... -This plan is pretty straight forward. You have the BHP of the intended zone. Are there any others of concern? A: No, we'll just reperf the existing perforated intervals. -The present packer is a fair distance above the PBTD. Fill is mentioned, has it been tagged? A: No tag run has been made since this interval was perforated. However, the well makes sand so there is probably some amount of fill. -Do you plan to do a casing test in the pre rig work or prior to reperfing and gravel packing? A: No. The perforations are open and the producing pressure will be very Iow. -Although you have larger tubing planned for this well, will it limit production? A: No. There will not be enough rate from this well to see the tubing as a limitation. SRU 14A-33... -As I indicate in my comments...is there any intent or need to clean out the deeper intervals? A: No. We'll just acidize the existing perfs. .You are requesting not to have a SSV on a gas lifted completion. As noted above, will adding the G perfs make the well capable of flowing? A: No. The BHP in the G-Zone is 1600 psi and will not allow the well to flow, -If the request for no SSV is approved, is there some shutdown mechanism on the gas lift? A: There are 2 manual valves at the surface for shutting in the gas lift. While discussing this question, the field supervisor and I decided that we are uncomfortable with the possibility of a line leak occuring some time before somebody notices and tums off the gas lift gas supply. We therefore withdraw the request to eliminate the SSV. -What are the BHPs. A: Hemlock BHP =. 1500 psi, G Zone BHP = 1600 psi I would appreciate some detailed information regarding the downhole equipment and the surface pumping unit. A: Photos and diagrams attached to this message. I can provide more technical data if you'd like, SCU 33A-8... How high will the tie back be? A: The casing leak is suspected to be at the port collar at 7,332'. The tie-back liner will extend up to cover it, making the tie-back -2500' long. If the leak is found elsewhere, it will effect the length of the liner as the intent is to tie back from the existing TOL to just above the leak. 2 of 4 5/31Ol 10:o5 AM FW: Swat=on Workover Program Will it be fully cemented? A: Yes. BOP and contingencies when using crane? A: We plan to use a 2-ram stack consisting of: Top: 2-7~8", 1500 psi WP, 0 - 1-112", variable rod rams Btm: 2-112", Model LP-15, 0 - 1-112", variable rod rams Each well will use both rams while running the rods, with the bottom set being left on the well as a permanent part of the wellhead equipment (i.e., when it's all done, each well will have an LP-15 BOP left on it and the top ram will be left over for future use in running and pulling rods.). Is there any iiklihood that the Hemlock could flow after reperfing? A: No, the BHP is only 1500 psi, not enough to lift the oil column. Need BHPs A: BHP = 1500 psi. Will tubing be anchored? A: Yes, see the attached gas anchor schematic. Will gas be produced out of a casing valve? A: Yes. SCU 33-33 Why base oil on this one? A: Base oil is being used because the G-Zone is very water-sensitive. Any plan to test the casing? A: No, the perforations are open and the producing pressure will be very Iow. --~ SCU 13-34 BHP = 1500 psi. Please call or write with any additional questions or comments. Regards, Bill [ Name: 1100SIDE&FRTVIEWBELTOUT.jpg ['~1100SIDE&FRTVIEWBELTOUT. ip,q~ Type: JPEG Image (imageljpeg) ~Encoding: base64 '1 Name: 1100SIDE&FRTVIEWBELTOUT.jpg r~1100SIDE&FRTVIEWBELTOUT.jpg'I Type: JPEG Image (image/jpeg) .I Encoding: base64 [~ 1100SIDEVIEW.jp.qI Name: 1100SIDEVIEW.jpg Type: JPEG Image (image/jpeg) Encoding: base64 3 of 4 5/31Ol 10:05 AM Swanson Workover Program Subject: Swanson Workover Program Date: Wed, 25 Apr 2001 03:02:30 EDT From: STMaunder@aol.com To: bill@fairweather.com CC: tom_maunder@admin.state.ak.us Bill, Doing a little homework. Funny, the phone doesn't ring near as much here. But the new office doesn't have plumbing problems either. But I digress... I have some questions with regard to the programs. I'll start off with my cryptic diary notes and expand on them. One big question. What rig is proposed? ~:~,~.~.~, ~--~ ~ ~ ~ SRU 14-15...(191-237)...(301-106)...proposal is to clean out the well, abandon the existing perforations and recomplete...request to test BOP to 3000 psi and also not to have a SSV...say that the well won't fl0w...plan to recomplete as a gas well...might need proposed drawing -What are the BHPs of the old interval and the new? Unless there is a possibility of a high pressure zone (there are a few out there), 3000 psi sounds appropriate. -You request not to have a SSV since the well will not flow unassisted, but this is a gas well. Is the SSV request an artifact from another program? -Do you plan to do a casing test in the pre rig work or prior to perfing? -How the well will look after workover is not too difficult to imagine, but a drawing will help as I move it up the line. -What gas rate is expected? Will 2-3/8" tubing limit the production? -What zone/sand is the new completion in? ,~ Z.o*~,- ~ SRU 234-15...(160-041)...(301-102)... proposal is to clean out the well, reperf and gravel pack the interval and run tubing.,.BHP stated at 2785 psi...request 3000 psi BOP test...need a new drawing...no mention of deleting SSV -This plan is pretty straight forward. You have the. BHP of the intended ,,~ zone. Are there any others of concern? -The present packer is a fair distance above the PBTD. Fill is mentioned, .~ has it been tagged? u -Do you plan to do a casing test in'the pre rig work or prior to reperfing and gravel packing? -Although you have larger tubing planned for this well, will it limit ~',~,,,,~?, production? ~~ s,u packer and clean out the well, not necessary or possible to clean out ~e.,/~ deeper...run tubing shallower, acidize the existing perfs and add G zone perfs...this is an oil well and presently will not flow unassisted...request is to not have a SSV...how do they propose to Sl...will adding the G perfs make the well flow? 1 of 2 -As I indicate in my comments...is there any intent or need to clean out the deeper intervals? -You are requesting not to have a SSV on a gas lifted completion. As noted S .wanson Workover Program above, will adding the G perfs make the well capable of flowing? -If the request for no SSV is approved, is there some shutdown mechanism on the gas lift? -What are the BHPs. The proposed rod pump wells have similar comments. I did talk with Steve Tyler regarding this proposal some time ago. I would appreciate some detailed information regarding the downhole equipment and the surface pumping unit. I have just copied my notes regarding these wells. I don't think they are too cryptic. If you need further clarification, please call SCU 33A-8...(172-017)...(301-103)...proposal is to clean out the well, repairing a 7-5~8" casing leak by runing a 5" tie back and equipping with a rod pump...makes same request to omit SSV...probably more appropriate on this well type...how high will the tie back be?...will it be fully cemented?...BOP and contingencies when using crane?...is there any liklihood that the Hemlock could flow after reperfing?...need BHPs...will tubing be anchored?...will gas be produced out of a casing valve? SCU 33-33...(176-056)...(301-105)...somewhat similar to 33A-8, plan to clean the well out and complete with red pump...request relief on SSV as before...plan to use base oil for workover fluid...no reperf...why base oil on this one?...Hemlock and G zones already open in this well...any plan to test the casing? SCU 13-34...(unsure of permit number)...(301-104)...cleanout and equip with pump...plan to add G zone perfs...similar requests as before...plan to use 6% KCI for fluid Bill, thanks in advance for looking at these comments/questions. Please call to discuss. Tom 2 of 2 4/25/01 9:49 AM STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: 2. Name of Operator [ ] Abandon [ ] Alter Casing [ ] Change Approved Program UNOCAL ALASKA RESOURCES [ ] Suspend [ ] Plugging [X] Repair Well [X] Pull Tubing [ ] Operation Shutdown (~Re- Enter Suspended Well Address 909 W. 9th Avenue, P.O. Box 196247, Anchorage, AK 99519-6247 4. Location of well at surface Effective depth: X: 346163, Y: 348600 At top of productive interval NIA At effective depth NIA At total depth X: 348600, Y: 2477348 Present well condition summary Total depth: measured true vertical measured Casing Structural Conductor Surface Intermediate Production Liner true vertical 5. Type of well: [X] Development [ ] Exploratory [ ] Stratigraphic [ ] Service 12. ] Time Extension [X] Perforate ] Variance [ ] Other Stimulate 6. Datum Elevation (DF or KB) 15' RKB 7. Unit or Property Name Swanson River Unit 8. Well Number Perforation depth: measured 11,460 feet'/ 11,016 feet ,/ 8,682 feet Plugs (measured) Junk (measured) 14-15 Permit Numb~23,h' t (30 -~ 0. APl Number 501331014501 1. Field and Pool Swanson River. Hemlock & Tyonek Bridge plug at 8,682' Wireline tools lost at 8,428' Length NIA 29' 2,952' NIA 11,434' N/A True vertical 8,685 feet Size 22" 13-3/8" 7" 8,398' - 8,418' Cemented 44'to Suface 2,967' to Surface 11,449' to 3,800' MD TVD 44' 44' 2,967' 2,967' 11,449' 11,004' Tubing (size, grade and measured depth) 8,165' - 8,181' 2-3/8", 4.6 #/ft, N-80, BTC at 5,863' Packers and SSSV (type and measured depth) 2-3/8" X 7" Baker Model D permanent pkr at 5,778' '"13. Attachments i [X] Description of Summary Proposal [ ] Detailed Operations Program [ ] BOP Sketch 14. Estimated date for commencing operation If I~roposal was verbally approved 5115/01 Conditions of Approval: 15. Name of approver Date Approved Contact Eng!neer Name~Numb, et Bill pen rose 258-3446 I herel;~/~ce[tify that the fom~oJne is true and correct to the best of my knowledge -- ' - comEission u~e/only- ~7 - Notify Commission so representative may w_ itness ~;::~ .~'~ ~I?,.~;~W- Plug integrity BOP Test ~ Location Clearance Mechanical Integrity Test Subsequent form required 10-. LI ~ Status of well cla.s~fication as: [ ]Oil .......... ~""~[X] Gas/l [ ]Suspended Service '",...., .... .,.....; ............ "' , Prepared By Name/Number. Bill Penrose 258-3446 Date ~L-/¢"- O / IApproval No. Apl)roved by order of the Commission Commissioner Date Form 10-403 Rev. 06115/88 Submit In Triplicate Unocal Alaska Business Unit Swanson River Field Well SRU 14-15 AFE # Prepared by: WJP Date: 3/01 Estimate for Non-drilling AFEs (Cap Recomp, SWR, Abandonment) UNOCAL No. Preliminary Procedure Time CUM CUM Estimate Time Time __ (Hours) (Hours) (Days) _ Prep Well For Workover L Test Wellhead Use Slickline Unit to Pull Dummy Valve From GLM at 5,726' , Kill Well By Circulating Produced Water Down Tubing, Out Annulus -- Workover _ 1 MIRU Workover Rig ~. 0 0 0.0 _ 2 Set BPV, N/D Tree, N/U BOPE and Test 18 18 0.8 _ 3 M/U Landing Jo!nt, Pull Tbg Hgr to FloOr, Circulate Well 3 21 0.9 4 POH and S/B Tbg and. Jewelry (5,863') 12 33 1.4 _ 5 P/U3'I/2"DPw/PkrMilI.&Prt, RIHtoPkr~5,778' 12 45 1.9 6 Mill Pkr and POIT ~ 12 57 2.4 _ 7 Clean Out Fill and Wireline Fish to 7,100' 24 81 3.4 8 Make 7" Scraper Run to 7,100', POH 12 93 3.9 9 PJH w/7" Bridg© Plug on DP, Set ~ 7,000' 5 98 4.1 10 Place 100' Cmt Plug On Bridge Plug, Reverse Out 3 101 4.2 11 Displace Well to 9% KCL, POH 12 113 4.7 ' 12 RII-I w/2-3/8" Completion to 5,250' 10 123 5.1 13 Land Out, Set Pkr, Pressure Test Completion 4 127 5.3 14 ,Set BPV, N/D BOPE; N/U Tree, Test Tree 12 139 5.8 , 15 RDMO Workover Rig 0 139 5.8 Post-Rig Work 139 5.8 Use Pollark Wireline to Swab 300' Brine f/Tbg 139 5.8 R/U SWS, Perf6733'-6762', 6788'-6800' 139 5.8 , IUD swS, R~ecord Shut-In Tbg and Annulus Pressures 139 5.8 , i i i Subtotal (Days) 5.79 Lossfrrble Time (11%) 0.64' Total Project Days 6.43 . . . Note: Loss, Trouble, Unplanned is based on 11%. "~"" Also, the risked troubled costs were included in the AFE costs. SRU 14-15 AFE Est Page I of I 4/9/01 RKB to ~BG Head--lS~0' Tree connection: TC-3 Uni-bolt sqzd holes 3500' shots CBL S/63.. TOC 3800' 6435 on 7-27-99 sqzd holes 8500' 4 shots Holes in Tubing 0 10002-10012 Cnlc. TOC · 10574' B398'-8418' Swab cups 6 23" long 7 10 11 Cslc T0C h lla 10651' 12b ' 13 14 PBTD = 10829' TD-- 11460' HOLE ANGLE-- 25% KOP 0 3800' SRu_14_15 S'~ _~ River Field ~ SRU 14-1S Actual Completion' 1~9/96 CASING AND I~JBING DETA~ SIZE, WT GRADE CONN. TOP BO,'I~OM -- 22" Surf 44' 13-318"54.5 J-SS Surf 2967' 7" 38 N-80 8rd LT&C Surf 34' 7" 32 . N-80 8rdLT&C ~' 1030' 7" 29 N-gO 8rd LT&C 1030' 2276' 7" 26 N-80 8rd LT&C 2276' $718' 7" 29 N-80' 8rd LT&C 5718' 7367' 7" 32 - N-g0 8rclLT&C 7367' 8789' 7" 35 N-80 ~d LT&C 8789' 10432' 7" 38 N-80 grd LT&C 10432' 11449' Tubing.' 2-3/8" 4.6 N-80 Buttress Surf 5863' with 318" SS mmbanol inj~-ticm lineS.m/ 2506' . . ~RWELRY DETAIL NO. Depth, I~m 15.30 2-7/8" Tbg hgr w/~ H t~PV profile 2506 2 5726 3 5778 4 5830 5 5863 6 8682' · 7 9890 10002-10012 10 10125 10574 1i '10594 10681 lla 10~00 12 11096 12a 11137 12b 11148 13 11212 14 11240 15 11280 TOP BTM 3500 3500 8398 8418 8408. 8418 8500 8500 11224 11231 11262 11276 11290 11300 and 2-718" x 2-318': butU~s xover Macco 2-~8" SMO-1C1 Chem Iai Mdrl w/l"- 1000 psi cheminj valve Macco 2-3/$" D-SO glm w/l" dummy Pmmaeat pack~, 2-3/8" x 7" 29#, DPM X nipple, ID = 1.875" 7"' Bzidgo Plug sot 0 8442' on 11/8/96, but rafted O 8582' on 1/23/97. 2-718" Tubing cut, 10/21~6. Holes in tbg Camco MM GLM #10 ~vldumn~ Calc TOC in anauins. Ca~o TOC in tbg 2-?/8" BL]~ cmt remhu~ Caimo ~ OLM #12 w/dmnmy 2-7/8" Ba]~' cn~ r~tnin~ Brown HS-16-1 retr pack~ Cam~ MM GLM #13 w/CEV Bak~ Model D packm Bridg~ plug PERFORATION DATA ZOI~ SPF DATE COMMENTS · 5 6/20/59 sqz, 6/59 'l~onek 77-3 4 1/1~7 Mud · 4 1/23/97 ~p~, Mud 4 6/17/59 sqz, 6/59 4 5/29163 Abdn 11/91 Hemlock 4 7/$9,2/61 Abdn 11/91 Hemlock 4 5163 Abdn 11/91 IU~~: ~/$/00 DP~WN BY: TAB Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7677 UNOCALe) Dan R. Williamson Drilling Manager Tuesday, April 17, 2001 Ms. Julie Heusser, Commissioner AOGCC 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Application for Sundry Approval; SRU 14-15 Workover, Swanson River Field, Alaska Dear Commissioner Heusser, . Unocal Alaska Resources hereby submits an Application for Sundry Approval for its plan to re- complete Well SRU 14-15 in the Swanson River Field on the Kenai Peninsula. SRU 14-15 is a shut-in gas w~ll that has sand fill and a wireline tool fish. The proposed workover will consist of pulling the old completion, cleaning out the fish and fill to PBTD, abandoning the existing perforations with cement, running a new completion and perforating a new gas sand. Because this well will~'ot flow unassisted~,, Unocal requests approval to re-complete this well without a surface safety valve. For this same reason, we also request approval to test BOPE to a maximum of~.5~0~0 psi. The anticipated commencement of this Workover is approximately May15. Please find enclosed an Application for Sundry Approval (Form 403), a summary workover procedure and a wellbore schematic. If you have any questions or require additional information, please contact Bill Penrose at 258- 3446. Sincerely, Dan Williamson Drilling Manager Enclosures cc: Bill Penrose 14-15 100 ~ Water Cut 80 6O 4O 2O o 100 Cum Oi Prod Mbb Cum Gas Prod MMcf 10 ......... Cum Nater Prod f Mbbl ~ 1 0,1 O.Ol 0.001 105 i Oil Rate PD ~)ou(: ~ Gas Rate rPD~ ( MMcf/d ) - ----- Water Rate (PD~ t bbl/d ~ ~4 Gas / Oil Ratio Vlcf/bbl 1 U 103 10~ 10~ 100 I0- ! ~ lO 10,3 (. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: X Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: x 15 feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Swanson River Unit Anchorage, AK 99519-6247 Service: 4. Location of well at surface 8. Well number 360' FSL & 1680 FEL of Sec. 16, T8N, R9W, SM SRU 14-15 At top of productive interval 9. Permit number NA 91-237 (10-403 for P & A in 1991) At effective depth 10. APl number 2189' FSL& 552' FWL of Sec 15, T8N, R9W, SM (@ 10,681' MD) 50- 133-10145-01 At total depth 11. Field/Pool 352' FSL & 733' FWL of Sec. 15, T8N, R9W, SM Swanson River/Hemlock abandoned & Tyonek 12. Present well condition summary 8,442' cmt retainer in 7" but tagged at 8,682' Total depth: measured 11460 feet Plugs (measured) 10,681' calc TOC in tubing true vertical 11014 feet 10,900' cmt retainer in tubing 11,137' cmt retainer in tubing Effective depth: measured 8682 feet Junk (measured) 11,280' bridge plug in 7" casing true vertical 8436 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 44' 22" 44' 44' Surface 2967' 13-3/8" 2000 sx 2967' 2967' Intermediate 7" 600 ex & 500 ex @ 8500' 10850' 10850' Production 1 1449' Liner Perforation depth: measured 11224'-11231' Plugged 8398'-8418' · . _ _ 11262'-11300' Plugged true vertical 10791 '-10798' 8168'-8188' ~,~ 10827'-10863' ,,i'!j~. "i '17~ ~ '''''~ i'"' Tubing (size, grade, and measured depth) 2-3/8", 4.6 #/ft, N-80 BTC @5863' Z ~' :"~"~ '""' ~; ~'~¢,.~:~, ~ '.:,.;'.i~'!~": ,'"'.?":' '., '"' ~' ~, '.: ..... Packers and SSSV (type and measured depth) Baker Model 'D' Pkr (84-26) 5781' ,~ ,~'' '~""";';:~'.'".' ....... ;";'" 13. Attachments Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 7/31/00 , 16. If proposal well verbally approved: Oil: Gas: Suspended: X Name of approver Date approved Service: 17.I hereby~"et'tify that the fo¢~lO_il~g is true and correct to the best of my knowledge. ,., ', ' Sign ed .' ,~~~'~" ~~So~ Title: Drilling Manager Date: 7"" ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity.~ BOPTest L,,"' Location clearance I :Z O- Mechanical Integrity Test Subsequent form required 10- ~O ~ ORIGINAL SIGNED BY Oo~'t _ x D Ta lot Seamount ,,qo6 _^ Approved by order of the Commissioner ~0~¢~¢~0~ ~ Commissioner Date I ~'~ Form 10-403 Rev 06/15/88 ~ SUBMIT IN TRIPLICATE , UNOCALe) RKB to TBG Head = 15.30' Tree connection: TC-3 Uni-bolt sqzd holes 3500' 5 shots CBL 5/63 TOC @ 3800' Fill tagged at 6435 on 7-27-99 sqzd holes 8500' 4 shots Holes in Tubing @ 10002-10012 Caic TOC in Casing @ 10574' Peffs 2 8398'-8418' Fish, 3 Swab cups 4 6 23" long 5 6 10 11 Calc TOC in Tubing @ 1 la 10681' 12 12a 12b 13 14 15 PBTD = 10829' TD = 11460' MAX HOLE ANGLE = 25°, KOP @ 3800' SRu_14_15 SIZE WT Swanso(n River Field Well # SRU 14-15 Actual Completion 11/9/96 CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 22" Surf 44' 13-3/8" 54.5 J-55 Surf 2967' 7" 38 N-80 8rd LT&C Surf 34' 7" 32 N-80 8rd LT&C 34' 1030' 7" 29 N-80 8rd LT&C 1030' 2276' 7" 26 N-80 8rd LT&C 2276' 5718' 7" 29 N-80 8rd LT&C 5718' 7367' 7" 32 N-80 8rd LT&C 7367' 8789' 7" 35 N-80 8rd LT&C 8789' 10432' 7" 38 N-80 8rd LT&C 10432' 11449' Tubing: 2-3/8" 4.6 N-80 Buttress Surf 5863' with 3/8" SS methanol injection lineSurf 2506' JEWELRY DETAIL Depth Item NO. 15.30 2-7/8" Tbg hgr w/Cameron H BPV profile 2506 5726 5778 5830 5863 8682 7 9890 10002-10012 10 10125 10574 11 10594 10681 lla 10900 12 11096 12a 11137 12b 11148 13 11212 14 11240 15 11280 TOP BTM and 2-7/8" x 2-3/8" buttress xover Macco 2-3/8" SMO-1C1 Chem Inj Mdrl w/l" - 1000 psi chem inj valve Macco 2-3/8" D-SO glm w/l" dummy Permanent packer, 2-3/8" x 7" 29g, DPM X nipple, ID = 1.875" Tbg tail w/wireline guide 7" Bridge Plug set @ 8442' on 11/8/96, but tagged @ 8682' on 1/23/97. 2-7/8" Tubing cut, 10/21/96 Holes in tbg Camco MM GLM gl0 w/dummy Calc TOC in annulus Camco MM GLM gl 1 w/dummy Calc TOC in tbg 2-7/8" Baker cmt retainer ~'~;~'t ?~r~ .~ ~ I~: '.~ ,,'t~,i~t, Camco MM GLM gl2 w/du~[~..,.. ~.~ 2-7/8" Baker cmt retainer BrownHS-16-1 retrpacker d~[. 1~ '~000 Camco MM GLM gl3 w/CEV Baker Model D packer Bridge plug PERFORATION DATA ZONE SPF DATE COMMENTS 3500 3500 8398 8418 8408 8418 8500 8500 11224 11231 11262 11276 11290 11300 5 6/20/59 sqz, 6/59 Tyonek 77-3 4 1/16/97 Mud 4 1123/97 Reperf, Mud 4 6/17/59 sqz, 6/59 4 5/29/63 Abdn 11/91 Hemlock 4 7/59, 2/61 Abdn 11/91 Hemlock 4 5/63 Abdn 11/91 REVISED: 7/10/00 DRAWN BY: TAB UNOCAL ) ,., Swanson River Field Well # SRU 14-15 Proposal RKB to TBG Head = 15.30' Tree connection: TC-3 sqzd holes 3500' 5 shots CBL 5/63 TOC @ 3800' Fish @ 8428' Swab cups 23" long sqzd holes 8500' 4 shots Holes in Tubing @ 10002-10012 Calc TOC in Casing @ 10574' Proposed p_erfs 6733-6762-'~ 6788-68000,' Proposed cmt plug f/7225 - 6925' Perfs 6 8398'-8418' 7 10 11 Calc TOC in Tubing @ 1 la 10681' 12 12a 12b 13 14 15 PBTD = 10829' TD = 11460' MAX HOLE ANGLE = 25% KOP @ 3800' SRu_14_15_Proposal CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 22" Surf 44' 13-3/8" 54.5 J-55 Surf 2967' 7" 38 N-80 8rd LT&C Surf 34' 7" 32 N-80 8rd LT&C 34' 1030' 7" 29 N-80 8rd LT&C 1030' 2276' 7" 26 N-80 8rd LT&C 2276' 5718' 7" 29 N-80 8rd LT&C 5718' 7367' 7" 32 N-80 8rd LT&C 7367' 8789' 7" 35 N-80 8rd LT&C 8789' 10432' 7" 38 N-80 8rd LT&C 10432' 11449' Tubing: 2-3/8" 4.6 NO. 2 7 9890 10002-10012 10 10125 10574 11 10594 10681 lla 10900 12 11096 12a 11137 12b 11148 13 11212 14 11240 15 11280 TOP N-80 Buttress Surf 5863' with 3/8" SS methanol injection lineSurf 2506' JEWELRY DETAIL Depth Item 15.30 2-7/8" Tbg hgr w/Cameron H BPV profile and 2-7/8" x 2-3/8" buttress xover 2506 Macco 2-3/8" SMO-1C1 Chem Inj Mdrl w/l" - 1000 psi chem inj valve 5726 Macco 2-3/8" D-SO glm w/l" dummy 5778 Permanent packer, 2-3/8" x 7" 29#, DPM 5830 X nipple, ID = 1.875" 5863 Tbg tail w/wireline guide 8682 7" Bridge Plug set @ 8442' on 11/8/96, but tagged @ 8682' on 1/23/97. 2-7/8" Tubing cut, 10/21/96 Holes in tbg Camco MM GLM #10 w/dummy Calc TOC in annulus Camco MM GLM #11 w/dummy Calc TOC in tbg 2-7/8" Baker cmt retainer Camco MM GLM #12 w/dumr/I~.~ ,, 2-7/8 Baker cmt retainer Brown HS-16-1 retr packer Camco MM GLM #13 w/CEV Baker Model D packer Bridge plug PERFORATION DATA BTM ZONE SPF DATE COMMENTS 3500 3500 5 6/20/59 sqz, 6/59 8398 8418 Tyonek 77-3 4 1/16/97 Mud 8408 8418 4 1/23/97 Reperf, Mud 8500 8500 4 6/17/59 sqz, 6/59 11224 11231 4 5/29/63 Abdn 11/91 11262 11276 Hemlock 4 7/59, 2/61 Abdn 11/91 11290 11300 Hemlock 4 5/63 Abdn 11/91 REVISED: 7/10/00 DRAWN BY: TAB Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Willlamson Drilling Manager Commissioner Christenson: July 10, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Re: Commissioner Robert N. Christenson Application for Abandonment (Form 10-403) Swanson River Field Swanson River Unit #14-15 Enclosed is the Sundry Notice (Form 10-403) relating to the proposed recompletion of Swanson River Unit Well #14-15. It is proposed to isolate the current Tyonek 77-3 perforations and reperforate the Tyonek 62-5 sand. This well is currently suspended and shut in. The previous recompletion perforations (Tyonek 77-3 Bench, 8398' - 8418') produced only mud. On November 6, 1997, an attempt was made to clean out the well with foam and Coiled Tubing. The Coiled Tubing was worked down to 7400' where it became stuck. The coiled tubing was worked free. Two subsequent wireline operations tagged fill on November 7, 1997 at 6717' and on July 27, 1999 at 6435'. The current well completion schematic is attached. Due to previous stuck pipe problems at 7400', we are requesting an exception to 20 ACC 25. 112 c(1) (C). It is proposed to use Coiled Tubing to clean out fill from 6435' to 7225' with water. Place a cement plug'with Coiled Tubing from 7225' to 6925' and perforate through tubing the Tyonek 62-5 Sands (6788' - 6800' and 6733' - 6762'). The expected start date for this well is July 31, 2000 so your timely consideration for approval is appreciated. If there are any questions, please contact Dan Williamson at 263- 7677 or L. D. Davis at 263-7679. Drilling Manager AOGCC cover letter 14-15 abdn · . ~..., ? ..,,!',i~/;!~.,..-~.i?;::...!:t ~'!~.'". :":!".""~ L. D. Davis Unocal Alaska Business Unit Swanson River Well SRU #14-15 AFE # Prepared by: LDD Date:7/5/00 Estimate for Non-drilling AFEs (Cap Recomp to Tyonek 62-5) UNOCAL ) No. ,Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) 1 MIRU COILED TUBING 2 Pressure Test Coiled Tubing BOPE 4,500 psi 3 SDFN 4 M/U BHA #1. 1.75" mill on 1-11/16" Motor. 5 RIH to 5850. Establish circulation. 6 Wash down F/6435 (top of fill) and mill down to 6900'. Reciprocate & circulate. 7 Circulate while POOH to end of tubing with Coiled Tubing. Continue to POOH. 8 SDFN 9 M/U mule shoe or wash shoe, 10 RIH to 5900. Establish circulation. Wash down F/6435' to 6900'. 11 Wash and reciprocate from 6900' to 7225'. Circulate and reciprocate. 12 Circ while POOH to end of tubing with Coiled tubing. Continue to POOH. 13 SDFN 14 RIH w/CT. Mix and pump appx. 11 bbls of cement. Set cement plug F! 7225' to 6925'. 15 Circulate and rceciprocate Coiled tubing @ 6900' until well clean of cement. 16 POOH with Coiled Tubing. 17 SDFN 18 R/U E-Line 19 Pressure test Lubricator to 3000 psi 20 R/U and swab well down to 700'. 21 M/U 1-11/16 Enerjet guns & RIH. Perforate 6788'-6800' & 6733'-6762'. 22 R/D E-line and Coiled tubing equipment. 14-15 AFE Est Recomplete Tyonek Page 1 of 2 7/10/00 UNOCAL P. O. Box 196247 Anchorage, Ak 99519=6247 907-276-7600 907-263-7884 fax February 5, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Commissioner David Johnston Subject: Swanson River Unit Well #14-15, Approval # 396-210 Recompletion Report Form 10-407 cO Commissioner Johnston: Attached is the Form 10-407 for the recompletion of Swanson River Unit Well #14-15. The Hemlock oil zone was abandoned in 1991 and a workover was performed in November 1996 to recomplete this well as a Tyonek gas producer. The rig workover in November 1996 pulled the old tubing and successfully pressure tested the casing to 1500 psi. Even though the pressure test indicated a competent wellbore, a bridge plug was set at 8442' to insure isolation from old squeeze perforations at 8500'. The rig workover finished on the well by running a 2-3/8" single completion. In January 1997, SRU 14-15 was perforated from 8398'-8418'. No gas flow was established even after swabbing the well. A tag run indicated the bridge plug must have released during the perforating and fallen downhole below the old squeeze perforations. The bottom 10' of the zone was reperforated. Again no gas was observed during swabbing operations but fluid entry was observed. A sample of the wellbore fluids obtained at the perforated interval indicated mud had flowed into the wellbore. An old cement bond Icg (1963) indicated competent cement behind pipe at the new production perforations and at the old squeeze perforations but this is apparently not true. At present, SRU 14-15 is shut-in and future utilization of this wellbore is uncertain. Results from other gas recompletion work at Swanson River will help determine the best course of action on SRU 14-15. ^ sundry application form 10-403 will be submitted for your approval prior to commencing any further work on this well. If there are any questions about this report, please call me at 263-7659. Sincerely, Tim Billingsl~ Drilling Engineer u AOC~OVR.DOC I RECEIVED FEB 14 1997 Alaska 0il & Gas Cons. Commissi°n~/5/97 Anchorage (" STATE OF ALASKA ' ALASKA IL AND GAS CONSERVATION(,.;OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: SUSPENDED X ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Unocal Oil Compeny of California (UNOCAL) -~I-~28~/~-210 3. Address 8. APl Number P. O. Box 196247, Anchorage, Ak 99519 _ _~ ..... 50- 133-10145-01 4. Location of wall at surface,,t ~;f,k,~/~. ~ ~ 9. Unit or Lease Name 360' FSL, 1680' FEL, Sec. 16, T8N, R9W, SBM ,~ W.,~ . .. Swanson River Unit At Top Producing Interval;1 i~.~t._~ ~,:~ 10. Well Number NA :i~~! SRU #14-15 At Tot. al Depth 11. Field and Pool 35Z FSL, 733' FWL, Sec. 15, T8N, R9W, SBM 5. Elevation in feet (indicate KB, DF, etc.) 1 6. Lease Designation and Serial No. Swanson River Field/Tyonek 15' KBI A-028406 12. Date Spuddod 13. Date T.D. Resched I 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 3/29/1959 11 I1011996I I1/28/1997 NA feet MSL ~2. T~ El~tric or Other Lolls Run Plug and Pecker Record-~ 1/9/~, GR/CCL-1/1S~?, Comp Record-ll~ 0/97, 0RICCL-1/2~?, Com~ Record-lIZ'~? 23. CASING, lINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 22" 0 44' To surf 0 13-3/8" 54.5 J-55 0 2967' 17-1/Z' 2000 sx 0 7" :26~-38~ N-80 0 11449' 10-5/8" 600 sx & 500 sx ~ 8500' 0 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" 5863' 5778' 8398'-8418' MD 4 spf, 0.34" dia hole 8160'-8179' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 1116/97 lGas Zone would not flow due to poor cement quality behind casing causing mud to flow into wellbere. . Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO 1116/97 NA TEST PERIOD => .0 0 0 NAI NA Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 0 0 24-HOUR RATE => 0 0 0 NA 28. CORE DATA Brief description of lithology, pemsity, fractures, appemnt dips and presence of oil, gas or water. Submit core chips. ' None Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. [ 30. ~ GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Tyonek 77-3 Bench 8398-8418' 8160'-8179' Recovered only drilling mud due to poor quality cement behind casing. 31. LIST OF A'I'i'ACHMENTS Wellbere schematic, Summary of Rig Workover Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed )~~. fl~~ Title DrilllnnManager Date c""~e~... ~//~/~ "J Form 10-407 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injsction, observation, injection for in-sltu combustion. Item 5: Indicate which elevation is usecl as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), 8o state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Summary of Rig Workover Operations Swanson River Unit Well No. 14-15 10121196- RU E-LINE UNIT. RIH AND JET CUT 2-718" TUBING ~ 9890'. POOH AND RD E-LINE. 11105196- ACCEPT RIG ~ 00:00 1115196. ND TREE, NU BOPE. MAKE RIG REPAIRS TO MUD LINE. TEST BOPE (WITNESS WAIVED BY BLAIR WONDZELL-AOGCC AND JOE RUSSELL-BLM) 11106196- PULL HANGER TO RIG FLOOR. REPAIR MUD LINE AND PITS. CIRC BU. POOH AND STAND BACK 8275' OF 2-718" TBG. LAY DOWN REMAINDER OF TBG, GOOD CUT AT 9858'. MU 5.75" MILL AND 7" 38# CSG SCRAPER. 11107196- RIH WITH CASING SCRAPER TO 8500'. CIRC BU. DISPLACE HOLE TO 6% KCL AND 1% CORROSION INHIBITOR. PRESSURE TEST CASING TO 1500 PSI. POOH AND LD 2-718" TUBING. 11108196- FINISHED LD 2-718" TUBING AND MILL/SCRAPER. RETEST CASING TO 1500 PSI, GOOD. ND BOP STACK, REPLACE PRIMARY SEAL IN CASINGHEAD. COULD NOT REMOVE SECONDARY SEAL FROM TUBING HEAD. NU NEW TBG HEAD WITH SECONDARY SEAL. TEST TBG HEAD AND SEALS TO 3000 PSI, GOOD. NU BOP STACK, TEST SAME. RU SCHLUMBERGER, RIH AND SET 7" BRIDGE PLUG ~ 8442'. 11109196- LOG GAMMA RAY FROM 8442' TO 5400'. RIH WITH BAKER MODEL D PERMANENT PACKER ASSEMBLY ON E-LINE. SET PACKER ~ 5772' ELM. POOH AND RD E-LINE. RIH WITH 2-318' COMPLETION, STING IN TO SEAL BORE, TEST PACKER AND SEALS TO 1500 PSI. MU SPACEOUT PUPS, PUMP TBG VOLUME PLUS 5 BBLS DIESEL, LAND HANGER. 11110196- RUN IN LOCK DOWN SCREWS. TEST PACKER AND CASING TO 1500 PSI. RUN BPV, ND BOPE, NU TREE. PULL BPV, RUN 2-WAY CHECK. TEST TREE, PULL 2-WAY CHECK. RELEASE RIG AT 12:00 ON 11110196. MOVE RIG TO SRU 12-15. 1116197- RU SCHLUMBERGER, LOG GR/CCL CORRELATION LOG FROM BRIDGE PLUG ~ 8442' TO 5700'. RIH WITH PIVOT GUNS, PERFORATE 8408'-8418' AT 4 SPF, 180 DEG PHASING. TUBING PRESSURE INCREASED FROM 0 PSI TO 1100 PSI. POOH WITH GUNS. ATTEMPT TO FLOW WELL, PRESSURE BLED FROM 1100 PSI TO 0 PSI WITH NO FLOW. RIH WITH PIVOT GUNS, PERFORATE 8398'-8408', TUBING PRESSURE INCREASED FROM 300 PSI TO 1200 PSI. ATTEMPT TO FLOW WELL, PRESSURE BLED IMMEDIATELY WITH ONLY 1 BBI_ DIESEL RECOVERED, NO FLOW. POOH WITH GUNS, RD SCHLUMBERGER. 1117-19197- RU SLICKLINE UNIT, SWAB WELL DOWN TO RECOVERED 55 BBL WATER AND 23 BBL OF LOAD DIESEL. FLUID ENTRY BUT NO GAS TO SURFACE. 4060', SOME 1120197- SLICKLINE TAG OF BRIDGE PLUG AT 8687' sim (DEEPER THAN 8442' elm). FLUID LEVEL AT 3665'. 1122197- RU SCHLUMBER, LOG GR/CCL AND CONFIRM THAT BRIDGE PLUG HAS RELEASED AND FELL DOWNHOLE TO 8682' elm. 1123197- RIH WITH PIVOT GUN AND REPERF 8408'-8418' WITH WELL OPEN. NO FLOW, NO PRESSURE AT SURFACE. POOH WITH GUNS, RD E-LINE UNIT. 1124-25197- RU SLICKLINE UNIT. INITIAL FLUID LEVEL AT 1060', SWAB WELL DOWN TO 3650', FLUID KICK BLEW TOOLS UP HOLE (NO GAS WAS EVER OBSERVED AT SURFACE). SWAB TOOLS STUCK AT 3232', PULLED ON FISH AND PARTED WIRE. FISHED WIRE AND ROPE SOCKET ABOVE SWAB TOOLS BUT COULD NOT FISH SWAB CUPS AND BROKEN QUICK CONNECT. 1128197- RU SLICKLINE UNIT, RIH WITH 1-3/4" BLIND BOX AND PUSH FISH BELOW TUBING TAIL AT $863'. RIH AND SET DOWN AT 8428' sim. RIH WITH SAMPLE BAILER AND TAG SOFT FILL AT 8410', WORK DOWN TO 8420' AND RETRIEVE SAMPLE OF MUD AND SAND. RD SLICKLINE UNIT, EVALUATING ALTERNATIVES. UNOCAL ) Swans(off River Field Well # SRU 14=18 Actual Completion 11/9/96 RKB to TBG Head = 15.30' Tree connection: TC-3 Uni=bolt sqzd holes 3S00' 5 shots CBL 5/63 TOC 3800' sqzd holes 8500' 4 shots Perfs 8398'.-8418' Fish, Swab cups 23" long Holes in Tubing (~ 10002-10012 Calc TOC in Casing (~ 10574' 10 11 Calc TOC in Tubing lla 10681' 12 12a 12b 13 14 15 PBTD -- 10829' TD -~ 11460' MAX HOLE ANGLE -- 2S°, KOP ~ 3800' SC1415AC.DOC CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 22" Surf 44' 13-3/8" 54.5 J-55 Surf 2967' 7" 38 N-80 8rd LT&C Surf 34' 7" 32 N-80 8rd LT&C 34' 1030' 7" 29 N-80 8rd LT&C 1030' 2276' 7" 26 N-80 8rd LT&C 2276' 5718' 7" 29 N-80 8rd LT&C 5718' 7367' 7" 32 N-80 8rd LT&C 7367' 8789' 7" 35 N-80 8rd LT&C 8789' 10432' 7" 38 N-80 8rd LT&C 10432' 11449' Tubing: 2-3/8" 4.6 N-80 Buttress Surf 5863' with 3/8" SS methanol injection line Surf 2506' JEWELRY DETAIL NO. Depth Item 15.30 1 2506 2 5726 3 5778 4 5830 5 5863 6 8682 7 9890 10002-10012 10 10125 10574 11 10594 10681 lla 10900 12 11096 12a 11137 12b 11148 13 11212 14 11240 15 11280 TOP BTM 2-7/8" Tbg hgr w/Cameron H BPV profile and 2-7/8" x 2-3/8" buttress xover Macco 2-3/8" SMO-1C1 Chem Inj Mdrl w/l" - 1000 psi chem inj valve Macco 2-3/8" D-SO glm w/l" dummy Permanent packer, 2-3/8" x 7" 29#, DPM X nipple, ID = 1.875" Tbg tail w/wireline guide 7" Bridge Plug set ~ 8442' on 11/8/96, but tagged ~ 8682' on 1/23/97. 2-7/8" Tubing cut, 10/21/96 Holes in tbg Camco MM GLM # 10 w/dummy Calc TOC in annulus Camco MM GLM # 11 w/dummy Calc TOC in tbg 2-7/8' Baker cmt retainer Camco MM GLM #12 w/dummy 2-7/8" Baker cmt retainer Brown HS- 16-1 retr packer Camco MM GLM #13 w/CEV Baker Model D packer Bridge plug PERFORATION DATA ZONE SPF DATE COMMENTS 3500 3500 8398 8418 8408 8418 8500 8500 11224 11231 11262 11276 11290 11300 5 6/20/59 sqz, 6/59 Tyonck 77-3 4 1/16/97 Mud 4 1/23/97 Reperf, Mud 4 6/17/59 sqz, 6/59 4 5/29/63 Abdn 11/91 Hemlock 4 7/59, 2/61 Abdn 11/91 Hemlock 4 5/63 Abdn 11/91 REVISED: 2/3/97 DRAWN BY: TAB (' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: x Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved pr~ram: Pull tubing: x Variance: Perforate: x Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL~ Development: x 15 feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Strut/graphic: Swanson River Unit Anchorage, AK 99519-6247 Service: 4. Location of well at surface 8. Well number 360' FSL & 1680' FEL of Sec. 16, T8N. R9W, SM SRU 14-15 At top of productive interval 9. Permit number ,~) _ NA 91-237 (10-403 for P&A in 1991) At effective depth 10. APl number 2189' FSL & 552' FWL of Sec. 15, TSI~I. R9W, SM ({~ 10,681' MD) 50- 133-10145-01 At total depth 11. Field/Pool 35Z FSL & 733' FVVL of Sec. 15, T8N.. R9W, SM Swanson River/Hemlock abandoned 12. Present well condition summary 10.681' calc TOC in tubing Total depth: measured 11460 feet Plugs (measured) 10,900' cmt retainer in tubing true vertical 11014 feet 11.137' cmt retainer in tubing 11.280' bridge plug in 7" casing Effective depth: measured 10,681' feet Junk (measured) true vertical 10,282' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 44' 22" 44' 44' Surface 2967' 13-3/8" 2000 sx 2967' 2967' Intermediate Production 11449' 7" 600 sx & 500 sx {~ 8500' 11449' 11003' Liner Perforation depth: measured ; 1224'-11231' Plugged RECEIVED 11262'-11300' PluggedORIGINAL true vertical 10791'-~ 0798' 10827'-10863' OCTZ/- 1996 Tubing (size, grade, and measured depth) 2-7/8", 6.5~, N-80 8rd at 11273' (Holes in tubing at 10,002'-10,012') Packers and SSSV (type and measured de.h) Brown HS-16-1 2-7/8" x 7" {~ 11148' j~.$ka 0il & Gas Cons. C0mmissioa Anchorage 13. Attachments Description summary of proposal: Detailed operations program: x BOP sketch: x 14. Estimated date for commencing operation 15. Status of well classification as: 11/6/96 16. If proposal well verbally approved: Oil: Gas: Suspended: x Name of approver Date approved Service: 17. I hereby certify that the foregoing is true anti correct to the best of my knowledge. " Signed: )~.~'] ;1~ DaleHaines Title: Drilling Manager Date: FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApprovaI Plug Integrity / BOP Test ~ Location clearance "' C;~/~ Mechanical Integrity Test Subsequent form required 10-/.~ 7 unginal Signed By 0a. vid W. Johnston ! Approved by order of the Commissioner Commissioner Date' Form 10-403 Rev 06/15/88 Approvecl Uopy Returned SUBMIT IN'TRIPLICATE UNOCAL Swanson River Field SRU 14-15 Workover Program 10114196 Objective: Recomplete SRU 14-15 from an abandoned Hemlock Producer to a Tyonek Gas Producer. Status: Abandoned Hemlock producer. Well design: Based on recompleting the well to a Tyonek gas producer. General Procedure I. Pre-riq prep work: E-line cut tubinq above existinq TOC. 1 RU E-line unit and make 2.25" OD gauge ring run to 9900'. POOH. Note: Calculated TOC in tubing is 10,681' and in annulus is 10,574'. 2 RIH with 2.25" full jet cutter and cut tubing at 9900'. POOH and RD E-line. 3 Circulate hole to lease water. I1. Ri_cl Mobilization and Prepare Well for New Completion Note: Notify BLM and AOGCC 24 hours in advance of BOP tests. 1 MIRU Alaska Well Service RIG 5. 2 ND tree. NU BOPE, choke line, kill line and choke manifold. 3 Pressure test BOPE. -fo 7OOO ~'¢~'- 4 Pull 2-7/8" tubing. 5 RIH with bit and scraper to 8500'. 6 Circ hole to 6% KCI lease water with corrosion inhibitor. Pressure test casing to 1500 psi. Note: Squeeze holes at 8500' may be leaking. Casing integrity test by Chevron in 1986 failed to hold pressure. 7 POOH and LD tubing and bit/scraper. 8 If casing does not pressure test, MU Baker storm packer. Set storm packer in top joint of 7" 38# casing. 9 ND BOPE, ND tubing spool and replace primary casing packoff. U BLMI415P. DOC [ 10/14/96 UNOCAL ) Swanson River Field SRU 14-15 Workover Program 10114196 10 NU tbg spool and pressure test primary packoff to 3000 psi. 11 NU BOP and test. 12 Pull storm packer. II1. Run 2-3~8" Completion: 1 RU E-line unit. 2 RIH and set 7" bridge plug with E-line @ 8450'. (above holes in casing @ 8500'). 3 RIH with permanent packer assembly on E-line. Set packer at 5800'. RD E-line. 4 PU and RIH with new 2-3/8" tubing and methanol injection line: 5 Space out and land tubing hanger. 6 Pressure test tubing to 2000 psi and annulus to 1500 psi. 7 ND BOPE. NU and test tree. 8 RD rig and move to next workover. IV. Perforate Tyonek 1 RU E-line unit. Tie-in Loq: Schlumberger's TDT date 8/15/96. 2 RIH with GR/CCI correlation log. Log from 8450' to 5800'. POOH 3 RIH Schlumberger 1-11/16" pivot guns at 4 spf. Perforate as follows. Top BoEom Footage 1 8372' 8387' 15' 2 8398' 8418' 20' 35' 4 POOH and RD E-line unit. 5 Turn overwell to production. U BLMI415P. DOC 2 10/14/96 UNOCAL RKB to TBG Head = 15.30' Tree connection: TC-3 Uni-bolt sqzd holes 3500' 5 shots CBL 5/63 TOC 3800' Loaded Annulus with Cru(le in 1963 sqzd holes 8500' 4 shots Calc TOC in Casing (.~) 10574' 9 Holes in Tubing (a~ 10002-100 ! 2 10 11 Calc TOC in Tubing I la 10681' 12 12a 12b Swansou River Field Well # SRU 14-15 Actual Completion 5/63 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 22" Surf 44' 13-3/8" 54.5 J-55 Surf 2967' 7" 38 N-80 8rd LT&C Surf 34' 7" 32 N-80 8rd LT&C 34' 1030' 7" 29 N-80 8rd LT&C 1030' 2276' 7" 26 N-80 8rd LT&C 2276' 5718' 7" 29 N-80 8rd LT&C 5718' 7367' 7" 32 N-80 8rd LT&C 7367' 8789' 7" 35 N-80 8rd LT&C 8789' 10432' 7" 38 N-80 8rd LT&C 10432' 11449' Tubing: 2-7/8" 6.5 N-80 8rd Surf l 1,273' ,JEWELRY DETAIL NO. Depth Item 15.30 1-9 10002-10012 10 10125 10574 11 10594 10681 lla 10900 12 11096 12a 11137 12b 11148 13 11212 14 11240 11273 15 11280 Tubing hanger Camco MM GLM w/dumrnv as follows: 1372'. 2736'. 4003'. 5191', 6244'. 7268'. 8007', 8636', 9352' Holes ill tbg Camco MM GLM #10 w/dummy Calc TOC in annulus Camco MM GLM #11 w/dummy Calc TOC ill tbg 2-7/8" Baker cmt retainer Camco MM GLM # 12 xv/dummy 2-7/8" Baker cmt retainer Brown HS- 16-1 retr packer Camco MM GLM #13 w/CEV Baker Model D packer 2-7/8" tubing tail Bridge plug 13 PBTD = 10829' TD = 11460' MAX HOLE ANGLE = 25°. KOP (.~ 3800' SCI415A.DOC TOP PERFORATION DATA BTM ZONE SPF DATE COMMENTS 3500 3500 8500 8500 11224 11231 11255 11255 11262 11276 11290 11300 11312 11340 Hemlock Hemlock 5 6/20/59 sqz 4 6/17/59 sqz 4 5/29/63 Abdn 11/91 5 7/9/59 WSO sqz 4 7/59, 2/61 Abdn 11/91 4 5/63 Abdn 11/91 4 7/15/59 Sqz perfs REVISED: 10/14/96 DRAWN BY: TAB UNOCAL ) '( Swanson River Field Well # SRU 14-15 Proposed Recompletion 10/96 RKB to TBG Head = 15.30' Tree connection: TC-3 Uni-bolt sqzd holes 3500' 5 shots CBL 5/63 TOC 3800' sqzd holes 8500' 4 shots iiiiiiiiiii Prol)ose(J :i:i:::~:~: Perfs ;::.:,:.:.: CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 22" Surf 44' 13-3/8" 54.5 J-55 Surf 2967' 7" 38 N-80 8rd LT&C Surf 34' 7" 32 N-go 8rd LT&C 34' 1030' 7" 29 N-80 8rd LT&C 1030' 2276' 7" 26 N-80 8rd LT&C 2276' 5718' 7" 29 N-80 8rd LT&C 5718' 7367' 7" 32 N-80 8rd LT&C 7367' 8789' 7" 35 N-80 8rd LT&C 8789' 10432' 7" 38 N-80 8rd LT&C 10432' 11449' Tubing: 2-3/8" 4.6 N-80 Buttress Surf 5860' with 3/8" SS methanol injection line Surf 2500' JEWELRY DETAIL Depth Item NO. 15.30 I 2500 2 5770 3 5800 4 5830 5 5860 2-7/8" Tbg hgr w/Cameron H BPV profile and 2-7/8" x 2-3/8" buttress xover Macco 2-3/8" SMO-lC 1 Chem Inj Mdrl w/l"- 1000 psi chem mj valve Macco 2-3/8" D-SO giro w/l" dummy Permanent packer. 2-3/8" x 7" 29# X nipple. ID = 1.875" Tbg tail w/wireline guide Holes in Tubing (~2 1{)0{)2-10012 Calc TOC in Casing (~) 10574' 1o 11 C:ilc TOC in Tubing ../ ! la 10681' 12 12a 12b 13 14 15 PBTD = 10829' TD = 11460' MAX HOLE ANGLE = 25°, KOP (~ 3800' SCI415P.DOC 6 8400 7 9900 10002-10012 10 10125 10574 11 '10594 10681 lla 10900 12 11096 12a 11137 12b 11148 13 11212 14 11240 15 11280 TOP BTM Bridge Plug in 7" casing 2-7/8" Tubing cut Holes in tbg Camco MM GLM #10 w/dummy Caic TOC in annulus Camco MM GLM #Il w/dmmny Calc TOC in tbg 2-7/8" Baker cmt retainer Camco MM GLM #12 w/dummy 2-7/8" Baker cmt retainer Brown HS- 16- l retr packer Camco MM GLM #13 w/CEV Baker Model D packer Bridge plug PERFORATION DATA ZONE SPF DATE COMMENTS 3500 3500 8372 8387 8398 8.418 85O0 8500 11224 11231 11262 11276 11290 11300 5 6/20/59 sqz Tyonek 77-3 4 Proposed Tyonek 77-3 4 Proposed .4 6/17/59 sqz ,4 5/29/63 Abdn 11/91 Hemlock 4 7/59~ 2/61 Abdn 11/91 Hemlock 4 5/63 Abdn 11/91 REVISED: 10/14/96 DRAWN BY: TAB FILL-UP, " ST~ 'r% ~_ LINE'--~~'- '.,ooo p~t FLOW BOP .c'O00 pst PIPE' ~ lo' 50oo !0' 5000 CHOKE 3"'5000 psi PIPE PJ~R~ 1 O' 500o BOP ~TAC.K 107 EO:~: psi .( UNOCALe P. O. Box 196247 Anchorage, Ak 99519-6247 90%276-7600 907-263-7884 fax October 18, 1996 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Commissioner David Johnston Subject: Swanson River Unit Well #14-15 APl #50-133-10145-01 Form 10-403, Proposal to Recomplete Well to Tyonek Dear Commissioner Johnston: Unocal proposes to recomplete the Swanson River Unit Well # 14-15 as a Tyonek gas producer. This well's Hemlock perforations were aoandoned in November 1995 (Approval #91-237). The proposed work will require pulling the existing 2-7/8" tubing and running a single 2- 3/8" completion. The Tyonek gas zone will be perforated with through-tubing guns. Attached in triplicate are the 10-403 form with BOP schematic, detailed operations program and wellbore schematics of before and after the proposed work. Estimated start date is November 6, 1996 so your timely consideration of this proposal would be appreciated. Please direct any questions to Tim Billingsley at 263-7659. Sincerely, Tim Billingsl6y' u AOGCOV.DOC I 10/18/96 Form ~160-5 (JUNE 1990) UNITED ~ rES DEPARTMENT OF i HE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use 'APPMCATION FOR PERMIT-' for such proposals SUBMIT IN TRIPLlCATE 1. Type of Well Oil Gas ~: Well ~ Well [-I Other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchorage, AK 99519 (907) 276-7600 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit -- 14 Wells Soldotna Creek Unit -- 7 Wells FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31, 1993 5. Lease Design~on and Sedal No. 6. If Indian, Nlottee or T~ibe Name 7. If Unit or CA, Agreement Designation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Field and Pool, or Exploratory Area Swanson River Field 11. County or Parish, State Kenai, Alaska 12. CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION Notice of Intent ['-] Subsequent Report r-i Final Abandonment r-] Abandonment I--i Change of Plans I--] Recompletion I--I New Construction r-] Plugging Back E] Non-Routine Fracturing r-I casing Repair r-] WaterShut-Off E:] Altering Casing t'-I Conversion to Injection E~ Other Temporarily Abandon r"l Dispose Water (Note: Rep<xt results of multiple conmpletion on Well Completion or Recompleaon Repo~ and Log form.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details, and give pertinent dates, including estimated date of slatting any Ixoposed work. ff well is directionally ddiled, give subsur'ace locations and measured and true vmlJcai depths for all mad<ers and zone per~nent to this work.)* As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1,1996 to March 31,1997: Soldotna Creek Unit .. ~u 21-8 }ISCU 34-9 212-10 (O! ~SCU34-8 [~SCU41B-9 (.eO-~RU12-15 ~- ! SCU 243-81 ~CU 14-34 OO-~/-J~SRU 14-15 41A-15 3,-..;I _o SRU gO.- I 0 7" ! e SRU "38' ? sRu a-22 * High GOR well that may be produced intermittently Swanson River Unit SRU 2 2-27 SRU 23-27 SRU33 -27 oo-,-o I i Gt:IVED SRU 43-28 0 SBU 21-33WD ~ ~.",~, APR 0 SRU 24-33 -~ ~.,- '7 14. I hereby oalify th~ lie foregoing is trde and oon'ect. .gned / ./~~. _/f/f~f. _~) ~//// (This space for Fedeml aneV~fr~e use) Dennis L. Groboske Petroleum Engineer Date 3/29R6 Approved by T~e Date Conditions of approval, if any: T'~Je 18 U .S.C. Se=lion 1001, maims it a crime for any person knowingly and willfully to make to any deflarlment or agenw of the United States any false, fictil~3us o~ fraudulent statements or relxeaenlations as to am/malta' within its iu~diction. *See Instruction on Reverse Side Attachment No. 1 Swanson River Field Proposed Temporarily Abandoned Wells: Total 21 Wells Twelve Month Period: April 1, 1996 to March 31, 1997 Shut-in Wells under Evaluation for Shut-in Wells during Field Blowdown Rate Potential P&A Shallow Gas Potential and 'Hemlock Only' P&A Hemlock Producers Future Shallow Gas P~oducer with the Hemlock Abandoned SCU 34-8 SCU 243-8 SCU 13-9 SCU 41B-9 SRU 21-33WD SRU 34-28 SRU 43-28 SRU 212-10 SRU 212-27 SRU 12-15 SRU 41A-15 SRU 23-27 SRU 331-27 SCU 14-34 7 Wells 2 Wells 5 Wells ~,~ * '~.~h GOR well that may be produced intermittently SCU 21-8 SCU 34-9' SRU 14-15 SRU 43A-15 SRU 14-22 SRU 23-22 SRU 24-33 2 Wells 5 Wells ATTACHMENT 2 SWANSON RIVER FIELD Wells with Temporarily Abandoned Status Change Removed from 1996 Temporarily Abandoned Status · SCU 34-4 Recompleted in Tyonek Gl and G2 zones · SCU 43A-4 Recompleted in Tyonek G1 and G2 zones · SCU 13-4 Workover to remove tubing fish. Currently producing from Hemlock · SCU 23B-3 Returned to full time production · SCU 314-3 Returned to full time production · SCU 43-9 Returned to full time production · SCU 23-15 Returned to full time production Additions to 1996 Temporarily Abandoned Status · SCU 13-9 Recompleted in Tyonek G2 zone Iow rate oil producer. APR 0 ALASKA OIL AND GAS CONSERVATION COMHISSION WALTER J. HICKEL, GOVERNOR 3OOl PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 August 19, 1994 Kevin Tablet, Land Manager UNOCAL ? O Box 196247 Anchorage, AK 99519-6247 Re: Suspended Wells Compliance with regulations Dear Mr. Tablet: UNOCAL has 15 suspended wells as shown on the attached list: ALASKA SUSPENDED WELLS A~ OF AUGUST 1994. The applicable regulation is as follows: 20 AAC 25.110 SUSPENDED WELLS (a) Upon application by the operator under 20 AAC 25.105(e), the commission will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have future value as a service well. , . For each well on the attached list of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above or advise as to your plans to abandon the well. Wells'that meet the criteria of (a) above that you wish to maintain as suspended, as required by 20 AAC 25.110(e), must have well site inspections as appropriate this year prior to snow covering the locations. · Chairman c: Blair Wondzell encl hew/1 lunsusp PERMIT 00-0146-0 61-0045-0 66-0008-0 66-OO38-O 67-0007-0 67-0042-0 72-0007-0 ?5-000g-0 77-0017-0 78-0096-0 79-0017-0 81-0022-0 90-0041-0 90-0071-0 . - _ 133-10145-01 133-1014¢-01 283-10020-01 283-10021-00 283-20003-00 733-20018-00 733-20032-00 133-20237-00 283-20045-00 733-20300-00 733-20119-00 733-20441-01 733-20339-00 733-20302-01 733-20417-00 . . OPERATOR T31q=ON OIL CO ~ION OIL ~O LT~ION OIL ~O UNION OIL CO UNION OIL CO LT~ION O=L ~ ~ION OiL ~ ~ION OIL ~ ~ION O=L ~ ~ION OIL ~ ~ION OIL ~ ALAS/CA SUSP~qDED W~LLS AS OF AUGUST 1994 WELL NAME SWANSON ~IVUNIT 14-15 SWANSON ~IV~NIT 43-15~D NICOLAI CK ST 1-A NI~OLAI CKT31~IT 2 NI~OLAI ~K~T~IT 3 ~RANITE PT ST 187429 GRANITE PT ST 1874210 SWANSON RIVUNIT 24-33 ~ ~IV~ ~lqIT 14-31 MGS ST 17595 16 G~NITE PT ST 18742 31 GI~A~ITE PT ST 18742 34 GI~NITE PT ST 18742 40 T~ING BAY ST A-20D T~ING BAY~IT M-04 WEL~. C~-ASS D~r D~V D~V DEV D~V D~V D~V D~V DEV DEV D~V D~V WELL STATUS SUSP SUSP STATUS DATE 11/08/91 8/20/91 8/14/91 9/18/91 9/02/91 9/16/89 9/29/88 4/01/93 8/18/75 2/05/92 lO/O7/88 9/2o/91 4/21/82 4/23/90 7/03/90 16 15 29 29 20 12 31 04 01 31 31 31 31 04 33 TWP 08N 08N 11N 11N 11N 10N 11N 13N 09N 11N 11N 11N 09N 09N 009W 009W 012W 012W 012W 012W 011W 009W 009W 012W 011W 011W 011W 013W 013W Unocal North Amq"' -" Oil & Gas Divisiorl, Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Alaska Region March 31, 1994 Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 Re: .1, 994 Sundry Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas' Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 30 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are'requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Thirtieth Plan of Development and Operations for the Swanson River Field; i.e. April 1', 1994 to March 31, 1995. Two information sheets are attached with this Sundry Notice request. Attachment I lists the proposed TA wells using the same. format as submitted last year. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses during field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Three wells SCU 24A-9, SCU 33-5, and SCU 21-3 were removed from the list while two wells SRU 12-15 and SRU 21- 33WD were added to the list. RECEIVED APR - 1 1994. Uii a Gas Cons. Commission Anchorage Mr. Joseph A. Dygas March 31, 1994 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-781 6. DLG:dma ~~'.:Dennis L.' ~~,r~b~ske Petroleum Engineer Attachment cc: L.R. Dartez, Marathon Oil Company O. W. Johnston, Chairman, AOGCC t Form 3160- 5 (JUNE 1990) UNITI( ATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentn/to a different reser~oir. Use 'APPMCATION FOR PERMIT-' for such proposals SUBMIT IN TRIPLlCATE 1. Type of Well Oil Gas ~ Well I~1 Well I'-] Other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchorage~ AK 99519 (907) 276-7600 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit --- 19 wells Soldotna Creek Unit --- 11 wells FORM APPROVED Budget Bureau No. 1004-0135 Extras: March 31~ 1993 5. Lease Oasignation and Sedel No. 6. If Indian, Allottee or Tribe Name ! · . . o, 7. If Unit or CA, Agreement Designation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Reid and Pool, or Exploratory/u'ea Swanson River Field 11. County or Padsh, State Kenal, Alaska 12. CHECK APPROPRIATE BOX(s)TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION ~ Notice of Intent I"'l Abandonment l'"l Subsequent Repo~ r-] Final Abandonment r-] Change of Plans I-] Rscompletion I-] New Conatruction l"] Plugging Back [-1 Non-Routine Fracturing I-I Casing RePai..r I"] Water Shut-Off ["] Altering Casing r"l Conversion to InJec~on ~ Other Temporarily Abandon ~ Dispose Water (No~: Rqxxt ~ of multiple conml~ation on Well 13. Des~q'be r'~-,,,po~,ed or Completed Operations (Clearly slate all pertinent cle/ib, and give pe~inent dates, including eslinaa~ date d siding any proposed wink. If well is cimctional¥ dried, give ,ubauri~ce locations and measured and line verl~ deplh, for all mar~ and zone plllnen~ As described in attached letter, Unocal requests that the folbwing wells have a temporarily abandoned status for the twelve month period, April 1994 to March 31, 1995: Soldotna Creek Unit ,~ !' * SCU 23S-3 8CU 243-8 <~ ! SCU 13-4 ~CU 341-8 <J ~ * SCU 21A-4 8CU 13-9 ~l SCU 34-4 * SCU 34-9 5' i * SCU 43A-4 SCU 14-34 / -o//...* SCU 21-8 *High GOR wells that may be produced Intermittently. Swanson River Unit ~'; SRU 212-10 .,,-"8RU 14-22 $ I 8RU 43-28 ~'~ 8RU 14-15//-~/~oRU 12-15 ~ 1 8RU 14A-33 SRU 23-15 ~J 8RU 23-22Tu~SRU 24-33 ~usI=SRU 34-15 51 SRU 28-27. 'T SRU 32-33WD'S % I. SRU 41A-15}~SRU 212-27 SRU 21-33WD ~t3~o SRU 43A-15G~ SRU 331-27 ' <~ tL~o SRU 432-15 ~! SRU 34-28 (This ,pa~fo~ Fe~i~, and l~;a~ use) Conditions of approval, if any: RECEIVED APR - 1 1994 Tdie 18 U.S.C. SeoUon 1001, makes it a odme for any peraon knowingly and willlully lo make lo any del3arln~ or agency o~ lbo United ~[~~'~ns. C0mmissi0r fraudulent statements or repmsenlaUom as to any miter wilhin ils jurisdlation. *See Instruction on Reverse Side Anoholag8 Attachment No. 1. Swanson River Field Proposed Temporarily Abandoned Wells: Total 30 Wells Twelve Month Period: April 1, 1994 to March 31, 1995 Shut-in Wells under Evaluation for I · Shallow Gas Potential Rate Potential P & A and 'Hemlock Only' P & A Shut-in Wells during Field Blowdown ii Hemlock Future Shallow Gas Producer Producers with the Hemlock Abandoned ~ 5~t~ SCU 13-4 u~-- l~ SRU 212-10 flo-~SCU 34-4 ~[-c~ SRU 23-15 ~-'~.z. SCU 341-8 (~.-~o SRU 41A-15 (~;~-'7 SRU 34-28 uz,-5~ SRU 14-22 ~[-8 SRU 43-28 ~o-[% SRU 23-22 ~o--I.~% SRU 32-33WD t~I-%%SRU 212-27 (~_--bt SCU 243-8 ~o-~I~ SRU 331-27 (02~- Z SRU 21-33WD/~-Z~SRU 12-1 5 Ioo-~&SCU 14-34 ;;0-q~/SRU 23-27 SRU 14A-33 I~-t'l SCU 21-8' B\-~ SCU 13-9 b~-~ cO-I~b SRU 14-15 (t0-uc[ SRU 34-15 SCU 34-9' SRU 43A-15 SCU 23B-3' ~-b~ SRU 432-15 SCU 43A-4' -~.-o-,SRU 24-33 SCU '21A-4* 8 Wells 8 Wells 3 Wells 6 Wells 5 Wells *High GOR wells that may be produced intermittently RECEIVED APR - '1 1994 Alaska Oil & Gas Cons. Commission Anchorage Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change Additions to 1994 Temporarily Abandoned Status · SCU 12-15. Shut-in gas lift producer with casing communication. Evaluate for repair or abandonment. · SCU 21-33WD: Shut-in due to wireline fish in tubing. Workover candidate. Removed from 1994 Temporarily Abandoned Status · SRU 24A-9' · SRU 21-3: Returned to full time production after workover. Returned to full time production due commencement of Blowdown in field. tO · SRU 33-5: Returned to full time production after workover. RECEIVED aPR - 1 1994 u~ & Gas Cons. Commission Anchorage Alaska Region Unocal North America~ ~) Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 COMMcoMM 'RES ENG UNOCAL ) · k.~. · | __ ___ /' ' I -~hG...A.S. ST I C7~,'~' [ re[~ ~ [~EOL ASSTI t ., j~~ ~ ~ i~TAT TECHI I March 24, 1993 '.~" I~ILE ~ · Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 Re: 1993 Sundry Notice Request for TA Wells in S_..wans0n:,LR..iver'~'Field, Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 31 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply With 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Twenty-Ninth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1993 to March 31, 1994. These concurrent time' periods will greatly simplify future TA Sundry Notice and Plan of Development and Operations preparation. Two information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells using the same format as submitted la _t.~ar by ARCO. The two general categories .are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses under field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed'Temporarily Abandoned List. Two wells, SCU 243-8 and SCU 21-8 were added.to .the list while three wells, SRU 21-22, SRU 12A-14 and SRU 211-15 were removed from the list. RE£EIV'ED MAR 2 5 199;5 Alaska 0il & Gas Cons. c0mmissio~ Anchorage Mr. Joseph A. Dygas March 18 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. Yours very truly, Petroleum Engineer DLG:sr Attachment cc: L.C. Smith, Chairman, AOGCC L. R. Dartez, Marathon Oil Company RECEIVED' MAR 2 5 1993 Alaska 0JJ & Gas Coils. C0mmissior~ ;Anchorage Form 3160-5 :June 1990) UNITED STATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals SUBMIT IN TRIPLICATE i. Type of Well 'X']Oil Gas Well ~] O Other Well 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone No. P. O. Box 196247, Anchorage, Alaska 99519 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit 17 wells Soldotna Creek Unit ,- 14 wells (907) 276-7600 FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31,1993 5. i.~ase Designation and Serial No. 6. If Indian, Allonee or Tribe Name 7. If Unit or CA, Agreement Designation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Field and Pool, or Exploratory Area Swanson River Field I 1. County or Parish, State Kenai, A1 as ka CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION ~J Notice of Intent D Subsequent Report O Final Abandonment Notice k=] Abandonment [~] Recompletion D Plugging Back O C. asing Repair [] O~r Temporari 1 y Abandon O Change of Plans O New Construction D Non-Routine Fracturing D Water Shut-Off O Conversion to Injection O Dispose Water (Note: Reponrcsultsof multiplccompletionon Well Completion or Recompietion Report and Loe form.) [3. Describe Pruposed 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, give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.)* As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for 'the twelve month period, April I 1993 to March 31 1994. ~, ~~ C,~ ~., ' ' Swanson River Unit / SCU 21-3 . .SCU 21-8*/°~' SCU 23B-3'.v SCU 243-8 SCU 13-4 ~ SCU 341-8 SCU 21A-4 SCU 13-9/ SCU 34-4 v SCU. 43A-4 y SCU 24A-9 SCU 34-9*~ SCU 33-5~ SCU 14-34 Swanson River Unit SRU 212-10 ~,., 1,4-'! 5., :: ~ SRU 23-i5 SRU 34-15 SRU 41A-15 SRU 43A-1 SRU 432-15 SRU 14-22 SRU 23-22'" SRU 23-27 ~ SRU 212-27 SRU 331-27 SRU 34-28 v SRU 43-28 ~ SRU 14A-33~ SRU 24-33~' SRU 32-33WD RECE)VED * High GOR wells that may be produced intermittently. Signed ~'~ Tide Petrol eum Engi near ~b ~ for ~ ~ S~ o~) Alaska Oil & Gas Cons. Gom~'tss'tor Anchorage Conditions of approval, if any: , . . litle 18 U.S.C. S~.-~os-~ 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent r tcpmsemtiom as many manet within i~ juriedic~na. *~ In~tmotlon on Rmmr~ Side Attachment No. I Swanson River Field ProPosed Temporarily Abandoned Wells: Total 31 Wells Twelve Month Period: April 1, 1993 to March 31, 1994 Shut-in Wells under Evaluation for Shut-in Wells until the Field Blowdown Rate Potential P & A(~ Shallow Gas Potential and 'Hemlock Only' P & A Hemlock Producers Future Shallow Gas Producer with the Hemlock Abandoned SCU 13-4 SCU 21A-4 SCU 34-4 SCU 43A-4 SCU 33-5 SRU 341-8 SRU 34-28 SRU 43-28 SCU 32-33WD SCU 243-8 SCU 21-3 SRU 212-10 SRU 23-15 SRU 41A-15 SRU 14-22 SRU 23-22 SRU 212-27 SRU 331-27 SCU 14-34 SRU 23-27 SRU 14A-33 11 Wells 7 Wells 3 Wells 5 Wells SCU 21-8" SCU 13-9 SCU 24A-9 SCU 34-9' SCU 23B-3' SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 SRU 24-33(2~ 5 Wells Does not include SRU 211-15. Scheduled full P & A in March-April, 1993 Scheduled 'Hemlock Only' P & A in March-April, 1993. High GOR wells that may be produced intermittently. RECEIVED AncJ~0rage Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1992's TA Status - December 27', 1991) Additions to 1993 Temporarily Abandoned Statu-~ · SCU 243-8: · SCU 21-3: Shallow gas producer ('l'yonek). Shut-in due to mechanical problems. Workover candidate. Shut-in due to current high GOR. Mechanical problems. Removed from 1993 Temporarily Abandoned Status · SRU 21-22: · SRU 12A-4: · SRU 211-15 Returned to production after flowline repair. Returned to full time production in 1992. Scheduled for full P & A March-April, 1993. Waiting on personnel and rig. RECEIVED MAR 2 5 ~99;5 Alaska Oil & 6as Cons. GommlSsiui' Anchorage .r ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well A[ OtL !--! GAS I--I 2 Name of Operator ARCO Alaska, Inc 3 Address SUSPENDED.~_.~lt,I. ABANDONED ~ SERVICE P.O. BOX 100360, Anchorage, AK 99510..0360 4 Location of well at surface 360' FSL, 1680' FEL, SEC 16, T8N, R9W, SM At Top Producing Interval At Total Depth 11,460' MD, 11,012' TVD 22 Type Electric or Other Logs Run 352' FSL, 733' FWL, SEC 15, T8N, Rgw, SM 5 Elevation in feet (indiua[u KB, DF, etc.) I 6 Lease Designation and Serial No. 274' KB I A-0_~8384 12 Date Spudded 13 Date T.D. Reached 1114 Date11/08/91.Co,~p., Susp. or Aband. J 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 10,829'MD, 10,426' TVD YES E] NO [] 17 Permit Number : SA(10-403) 91-237 8 APl Number 50-133-10145-01 9 Unit or Lease Name SWANSON RIVER UNIT 10 Well Number SRU 14-15 Field and Pool SWANSON RIVER FIELD HEMLOCK OIL POOL 15 Water Depth, if offshore NA Depth where SSSV set J I NA feet MD MSLJ16 No. of Completio~ feet I 21 Thickness d permafrost NA 23 CASING SIZE 11-3/4" 7II WT. PER FT. 24 Perforations open to Production (MD+TVD of Top and Bc~tom and interval, size and number) lbg perfed f/10,002'-10,012' MD 27 Date First Production Date of Test Row Tubing Press. 28 9647'-9657' TVD CASING, LINER AND CEMENTING RECORD Se i i ~NG DEPTH MD TOP BO'ITOM HOLE SIZE CEMENTING RECORD SURF 23' SURF SURF 11,449' AMOUNT PU~ ~ ~n ~.6 TUBING RECORD SIZE DEPTH SET (MD) 'PACKER SET (MD) 26 ACID, FRACTURE, CEMENT SQUE;7;~ ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED PRODUCTION TEST [Me!~:l of Operation (Flowing, gas lift, etc.) TEST PERIOD ~ ICALCULATED[Casing Pressure ,~,.HOUR RATE.~ iO,,.BBL i~S.MC~ CORE DATA of lithology, porosity, fractures, apparent dips and pr~enca of oil, gas or water. Submit core chips. WATER-BBL WATER-BBL ICHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-APl (corr) r~., 10-407 RECEIVED MAR 1 6 1992 Alaska Oil & Gas Cons. Commission Anchorage Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30 ...... GECLOGIC MARKERS FORMATION TESTS NAME Include intewal tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 31. LIST OF ATTACHMENTS REPORT OF DAILY OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed __ Title AREADRIII'~IGENGINI=FR Date ..... INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit.a separate'.form for each additional interval to be separately produced, showing the data pertinent to such intbrval.; . '~ Item 21' Indicate.w, hether f.ro:m ground level (GL) or other elevation (DF, KB, etc.). , . Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location .Of the.~cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. SRU 14-15 (P & A SUMMARY OF OPERATIONS) Lease Designation/Serial No. A-028406 0700-2000 hrs Rig up Arctic Recoil 1-1/2" CTU, press test bop's, RIH w/ 2" Jet nozzle, unable to get past glm @ 1397', POH, bend tbg, RIH, tag hard btm O 11,206'(CTU measurement)-11,219' tbg detail measurement, wash btm, POH after displacing all crude in tbg w/lease water, MIRU Precision W/L. RIH w/pulling tool, could not get past 6000', inadvertently pulled GLV f/mandrel O 6000', POH, RIH & reset valve, POH, RIH w/p,~lltng tool to attempt to recover G.L. valve lost on 8-13- 91. Unable to locate. POH, RIH w/2-1/4" impression block, apparent collapsed or split tbg ~ 11,220' w/room f/lost GLV to go past. POH & secure well. Will set GLV in mandrel ~ 11,397'(empty glm) & attempt to pump down tbg. 11/02/91 0700-2330 hrs MIRU Precision W/L, attempt to set dummy valve in glm ~ 10,594', misrun, POH, rerun successful, attempt to pump down tbg & bullhead fluid, immediate pressure communication w/2-7/8" x 7" annulus, no fluid injected ~ 2000 psi, open annulus & displaced annulus w/lease H20, lease H20 to surface in calculated depth of-1400'. R/U W/L, RIH & pull 1-1/2" dummy O 1373',. seals gone, set replacement dummy in glm/ continue displacing annulus w/lease H20. returns all fresh H20 until calculated amount to top packer, displacement presumably going around top packer(reportedly'never set) or lower glm, MIRU Atlas W/L, RIH & perf 5' ~ 4 8PF w/2-1/8" JJIII Gun f/11-212-217', POH, immediate press increase of 800 psi f/dead well, pump down TBG & establish injection rate of 1 BPM ~ 1800 psi, R/U Atlas & RIH w/Baker 2-7/8" cmt retainer, set 3' above top packer ~ 11,137', POH, Rig down & secure well f/night. 11/03/91 0700-1700 hrs RU CTU & RIH w/stinger, sting into retainer ~ 11,137' WLM(11,101 CTU measurement, establish injection O 1 BPM ~ 3700# w/lease H20. , batch mix 75 ax Class G(15.6 bbl) w/additives ~ 15.9 p.p.g., pump down CTU tail, sting into retainer w/annulus(csg) closed & squeeze 15 bbl cement into tbg annulus & thru perfs to zone, unsting & circulate 1/2 bbl cmt returns to surface, top of retainer should be clean, POH w/CTU & rig down, will perforate and set retainer this a.m. 11/04/91 0800-1200 hrs Mina Atlas W/L, RIH, 8h,,o?t 5' circ holes f/11,082'-11,087', POH, 2-7/8 retainer @ 10,900, P OH, rig down & move W/L to SRU 432-~ MAR 1 6 199 Alaska Oil & 6as Cons. Commisslen SRU 14-( ~P & A) PAGE 2 Summary of Operations 0700-1400 hrs R/U CTU w/ stinger, RIH, Tag retainer 0 10,854'(10,900' WLM), stab in & establish circ rate thru perforations, batch mix 75 sx class G w/.35% halad 344, .20 % CFR-3 & .25% HR-5, pump 14 bbl thru retainer & ~round ~umulus, unsting & pump I bbl emt in tbg, unsting & POH to 10,666, circ btms up(slight cmt returns), POH & rig down CTU & cmt unit. CIP 0 1200 hrs 11-4-91. wt. 15.9 ppg. Cslc TOC in 2/7/8" x 7" romulus 10, 574' C/ftc TOC in 2-7/8' tbg. 10,681' 11/06/9 0330-1630 hrs Rig up Atlas W/L, RIH w/ 2-1/fi' TBG. perforater-tag solid ~ 10,829'. Pull to 10,002 & perf tbg. w! 40 hole8 f/10,002' 10,012'. POH, Rig down Atlas -all shots fired. Rig up ARCO Triplex pump, pump down annulus HAD communications to TBG. Rig down pump & secure well. 11/06/91 1300-1630 hrs Move flow back choke & tank from 432-15 & rig up- rig up Haliburton, displace well w/ 9.7 ppg brine thru perfs from 10,002'-10,012'. Rig down & release Haliburton 1630-11730 hrs Move in diesel & Triplex pump, freeze protect well by pumping 2 bbls diesel down TBG. & U-TBG to annulus, protected 50' below ground level. Signature ~ _/~ Drilling Superint~ndi~nt Date ~//////fa- RECEIVED ~AR 1 6 199~ Alaska 011 & Gas Cons. Commission Anc/~orage OFliGINAL Form 31~0--5 (November 1983) (Formerly 9.--331) UNITED STATES (Other Inatruetlont aa re. DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS not u~e thio form for pro~o~la to drUt or to deepen or pluf back to · dl~erent reservoir. Ule "APPLICATZON FOR PERMIT--" for suck I. wELL ARCO Alaska, Inc. 3. &DO·S~8 Of' OflB&%"OI P.O.Box 100360 Anchorage, AK 99510 · I. Loc&xtOIi of %q'ELL (Re,oft loc~tioa eleErl~ and in &ecordEflLY* with ·ny State requirement-* SN also slme~ t? below.) At ludace Swanson River Unit ....... 19wells Soldotna Creek Unit ...... 13 wells |4. flied I': IIS. ELBV&~ONB (SM whetJ~er Df. IT. 4m. Form approved. Budlet Bureau No. 1004-0135 E, xptres August 31. 1985 Li&al OUtOXaTZOW &aD EIS'~L I0. ?. WIlT AOIIIviN1 a&idl Soldotna Creek/Swanson Rv I. FAtkl al L~B&·I I&kll 9. WELL lit. 10. FIILO &ND IqOL, OB WILOC&T Swanson River Field 11. ~. ~q Iq M,, 0l iLr~ LID IUIVI! OU &ii& Kenai Alaska 16. Check Appropr, ate Box To IndicaJe Nature of Notice, Report, or Other Data NO~ICB Of INTINTIOM TO: 10·IIGUIII~ IJlq)l~ O/: REPAIR Wl~ CHANGE PLA~8 (Other) (Other) Temporary Abandon (~: Re~rt ~.-D~SCIIBI I'tO~llO 0l COSlPLETED OPEIAYIOX8 (Clearly state nil prtinPilt de~llu, and ~lve ~rtinent pM· worL If ~1 b dl~o~ drill~ sin s~m ~uns And meas,r~ neat m ~ ~L) · As cleon%ed in the attached memo, ARCO Alash, ~¢. m~ests that the following wells have a temporarily abandoned status: Soldotna Creek Unit SCU 23B-3 SCU 21-8 SCU 12A-4 SCU 341-8 SCU 13-4 SCU 13-9 SCU 21A-4 SCU 24A-9 SCU 34-4 SCU 34-9 SCU 43A-4 SCU 14-34 SCU 33-5 Swanson River Unit SRU 212-10 SRU 14-15 SRU 23-15 SRU 34-15 SRU 211-15 SRU 41A-15 SRU 43A-i5 SRU 432-15 SRU 14-22 SRU 21-22 SRU 23-22 SRU 23-27 SRU 212-27 SRU 331-27 SRU 34-28 SRU 43-28 SRU 14A-33 SRU 24-33 SRU 32-33WD * -High GOR wells that may be produced intermittently. 18. I hereby (N~rtlfy-Z~&t .the go, reft ~l~ It trde and eorrect SIGNED -" RECEIVED. DEC 3 7 1991 Alaska 0il & Gas Cons. Commit TITLE Actinq Reqional EnqineerDAxm (Thio il)lee for Federli or APPROVED BT CONDITIONS OF APPROVAL, Z~ L~qr: TITLE DAT~ ~ee Inwucfion, on Reran Side Attachment 1 Swanson River Field Proposed Temporarily Abandon Wells: Total 32 Wells Shut-in Wells under Evaluation for Shallow Gas Potential Rate Potential P & A. and 'Hemlock Only' P & A ' Shut-in Wells until the Field Blowdown Future Shallow Gas Producer Hemlock Producers ' with the Hemlock Abandoned ~~~ $i~:;~ :~. ~ :;:;:.<.: ~.~.:~ ~:!:~:;.:i:i:i:i::;.<.:::; ~.g:~;::i:i gi ~;:; ~ SCU 12A-4 SRU 212-10 SCU 13-4 SRU 211-15 SCU 21A-4 SRU 23-15 SCU 34-4 SRU 41A-15 SCU 43A-4 - SRU 14-22 SCU 33-5 SRU 23-22 SCU 341-8 SRU 212-27 SRO 21-22 SRU 331-27 SRU 34-28 SRU 24-33 SRU 43-28 ~- SRU 32-33WD ~ SCU 14-34 SRU 23-27 SRU 14A-33 11 Wells 9 Well~ 3 Wells SCU 21-8 * SCU 13-9 SCU 24A-9 SCU 34-9 SCU 23B-3 * SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 5 Wells 4 Wells * -High GOR wells that may be produced intermittently. -. For:. Temporarily Abandonment Sundry 12/27/91. Attachment 2 RECEIVED Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1991's TA Status; our letter 12/28/90) DEC Alaska Oil & Gas Cons. Commiss Anchorage Added to 1992 Temporarily Abandoned Status: · SCU 23B-3 & · SCU 21-8: High GOR wells, may be produced intermittently, otherwise shut-in until blowdown. SCU 12A-4: High GOR well, may be. produce 'intermittently, This well is also being considered as a workover candidate. · SCU 43A-4: Shut-in due to mechanical problems. Also being considered as a workover Candidate for shallow gas. · SCU 13-9: High GOR well, shut-in until field blowdown. .. · SRU 212-10 & · SRU 212-27: High water rate shallow fuel gas well, currently not economic to produce based on current fuel gas needs. · SRU 21-22: Well' currently shut-in due to problems with the flowline. Well will be returned to production when repairs have been completed. Removed from 1991 Temporarily Abandoned Status · SRU 21-15 & · SRU 314-27: Wells are scheduled for full P & A in 1st Quarter 1992 as part of the '91-'92 SRF Plan of Development. Note: 'Hemlock Only' abandonments were 'performed on SRU 14-15, SRU 34-15, SRU 43A-15 and SRU 432-15. These wellbores are being maintained'for their future shallow gas potential and remain on the TA List for 1992: '. Attachm~n~ ~ Swanson River Field Shut-in Wells not on the 1992 TA Stares List Wells with planned upcoming work: · SRU 21-15 & SRU 314-27: Wells are scheduled for P & A in first quarter 1992. .. Wells that are used seasonally · SCU 43-4WD: This water/mud disposal well is a standby well and is only used on an 'as needed' basis. DEC ,,z 1'1991 AJaska OjJ & Gas Cons. ~;omrnissio,, Anchoraoe. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook inlet Engineering December 27, 1991 COMM C~ SR . SR Mr. J. A. Dygas Chief Branch of Lease Operations (AK-984) Bureau of Land Management 222 West 7th Avenue Post Office .,Box 13 Anchorage, AK 99513-7599 Subject: 1992 Sundry_ Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 32 wells in the Swanson River Field for a period of 12' months. This Sundry Notice is being submitted to comply with Chapter II, Section 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. All 32 wells are expected 'to be shut-in for a period of at least 30 days during 1992. Several information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells and separates them into the following five categories: Shut-in wells under evaluation for: 1, rate potential, permanent abandonment (P & A), and shallow gas sand potential and 'Hemlock Only 'abandonment. RECEIVED DEC ,5 1 199t Alaska Oil & Gas Cons. Commission Anchorage Mr. J. A. Dy gas Page 2 December 27, 1991 Shut-in wells until field blowdown, including: . Hemlock producers, and wells with future shallow gas potential in which the Hemlock has been abandoned. The fifth category shown above is a new addition to this year's TA listing. This grouping is for the wells in 'which the Hemlock has been abandoned but the wellbore is being maintained for possible future shallow gas production. Four wells from last ye.ar's TA list were moved into this category. Attachment 2 gives a brief explanation for each well that has been added to or removed from the 1991 Temporarily Abandoned List (Ref: our letter of 12/28/90). Eight wells, SCU 12A-4, SCU 21-8, SCU 23B-3, SCU 43A-4, SCU 13-9, SRU 212-10, SRU 21-22 and SRU 212,27, have been added while two wells, SRU 21-15 and SRU 314-27, have been removed from the previous TA List. Attachment 3 is a list of shut-in wells that are not included in the '92 TA listing. Two of the wells mentioned above, SRU 21-15 and SRU 314-27, are not included because they are scheduled for P & A in the first quarter of 1992. This work is being done as part of the '91-'92 Swanson River Plan of Development. Also included in Attachment 3 is SCU 43-4WD, a standby water disposal well which is only used seasonally. If you have any questions Concerning this Sundry Notice request, please call Hyeh- Yeon Hoffer at 265-1355 or Jim Zernell at 263-4107. Sincerely, J~ c. Winn Acting Regional Engineer JTZ:jlg:0025 Attachment CC:. L. C. Smith, Chairman AOGCC A. R. Kukla, Marathon Oil Company B. C. Dehn, UNOCAL Corporation ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging X Time extension _ Stimulate _ Abandon Change approved program _X_ Pull tubing _ Variance _ Perforate Other Hemlock 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development ~ !ARCO Alaska. Inc. Exploratory _ KB 274' feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. BOX 100360, Anchorage, AK 99510 Service _ Swanson River Unit 4. Location of well at surface 8. Well number 360' FSL, 1680' FEL, Sec 16, T8N, Rgw, SM SRU 14-15 At top of productive interval 9. Permit number At effective depth 10. APl number 50-133-10145-01 At total depth 11. Field/Pool Swanson River Field 352' FSL, 733' FWL, Sec 15~ T8N, Rgw~ SM Hemlock Oil Pool 12. Present well condition summary Total Depth: measured 1 1,460' feet Plugs (measured) 11,307'-11,340', 11,425'-11,449' true vertical feet Halliburton Cl bridge plug at 11,280' Effective depth: measured 1 1,280' feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 4 4' 2 2" Yes 23' Surface 2,967' 1 3-3/8" Yes 2,967' Intermediate Production 11,449 7" Yes 11,449' Liner Perforation depth: measured 11,218'; 11,224'-11,231'; 11,268'-11,276'; 11,290'-11,3 true vertical Tubing (size, grade, and measured depth) ' 2-7/8", 6.5# N-80 EUE to 11,275' Packers and SSSV (type and measured depth) Baker Model "D" Pkr @ 11~238', Brown HS-16-1 Pkr @11,148' (never set) 13. Attachments Description summary of proposal X Detailed operation program X BOP sketch_ Wellbore Diagrams, Well History, Area Map 14. Estimated date for commencing operation 15. Status of well classification as: Auoust 10. 1991 Oil ~( Gas m Suspended _ 16. If proposal was verbally approved ~.~...q.... ....... ..... ~"', .^~',,..c.-,,~,,,,o~ Name of approver Date approved Service ,~e~'~ ~117' I'Ii araby c~ f°reg°ing is true and-c°rrect t° the best °f mY knowledge'(' ~ ~ I~.~ /~C~/ ~,~,,~ f ~,i/~O~'~__ _ .~ f'7~J~ . . t~{~_ Title Area Drillinl~ Enl~ineer Date ~.~ ~.~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witnessI o.~1. N_o..~ Plug integrity _ BOP Test_ Location clearance IAppr'~! Mechanical Integrity Test_ Subsequent form r"-~quire 10-~0~ Approved_ bythe order of the Commission Commissioner Date,C~'/7/~/ Form 10-403 Rev 06/15/88 SUBMIT ~IPLICATE ORIGINAL SIGNED B~ RUSSELL A. DOUGLASS Approved Copy ,~RU 14-15 General P&A Procedure 1. MIRU slickline. RIH with gauge ring to PBTD. Confirm PBTD @ 11,280' +. Attempt to close off mandrels at 10125', 10349', and 11096'. RD slickline. 2. RU CTU and MU open ended nozzle. RIH with open ended nozzle to PBTD. Adjust odometer to match slickline depth. POOH w/CTU. 3. RIH w/wireline. Set cement retainer @ 11,235'(below "D" nipple). POOH w/wireline. . RU HOWCO and line cementers to pump down the coiled tubing unit. RIH w/CTU. Sting into retainer at 11,235'. Down squeeze 16 cuft. class "G" cmt. Unsting CTU from retainer. . Down squeeze 21 cuff. class "G" cmt into Tbg.xCsg. annulus through the open Camco gas mandrel @ 11,212'. Be sure to hold pressure to Tbg.xTbg. annulus while performing squeeze. 6. POOH w/CTU while laying 5 cuff. cement in Tubing. RD CTU and HOWCO. . RIH w/wireline and dummy bar and tag cement top. POOH w/wireline and dummy bar. RU Tbg. cutter and RIH to 10,800'. Cut Tbg. @ 10,800'. POOH. 8. RD and secure well. SRU 14-15 Brief Well History SRU 14o 15 was originally drilled and completed as the SRU 34-16 in March 1959. This well was abandoned as a dry hole and redrflled as SRU 14-15 to the east from 3800' MD in July 1959. This wellbore was cored. After a drfllpipe fish was stuck, the well was cemented back to 10,977' MD and redrilled to a total depth of 11,460' MD. The H5 Sand tested wet and the H4 Sand was completed for 85 BOPD. By February 1961, the rate had declined to 21 BOPD. Additional H4 perforations were added as well as reperforating the existing interval. The post-perforation rate was 31 BOPD. In November 1962, the well was shut-in with a last producing rate of 3 BOPD. In May 1963, a workover was performed and the lower H4 tested wet. A cast iron bridge plug was set at 11,280' MD. The upper H4 was reperforated and the H1 was perforated and a selective single completion was run. Initial production after the workover was 14 BOPD declining to 10 BWPD within nine days. In July 1963, the well was shut-in. In June 1983, the well was produced with gas lffi at 1 BOPD x 80 .BWPD. A Chevron casing integrity test was performed in january 1986 and was not successful. Documentation of the CIT is not available. In February 1986, a 2.25" gauge ring could not get past the mandrel at 11,212' MD. The tubing and production casing pressures are currently 450 psi and 540 psi respectively with no pressure on the surface casing. The well records note that four mandrels are open and the top packer was never set. It also indicates that the road is inaccessible. Since the SRU 14-15 produces predominantly water with little off, it offers no future utility in the Hemlock. As uphole gas may be present in this well, only the Hemlock is recommended for abandonment at this time. Tins abandonment will leave SRU 14-15 in a safer condition than its current configuration. The procedure to abandon the Hemlock is identical to that which would be employed if a full P&A were planned. Thus, no incremental costs will be incurred through this piecemeal operation. UNIT BOUNDARY~ ~-~ I I I I i...I ~- I t-o*. I I I I I I------- · I I I I FAULT ILOCK FAULT I I SWANSON RIV'ER FIELD STRUCTURE MAP HEMLOCK FORMATION ~S$' .=. .. .. . . . . · .. · . · ,i el ,fs.M4~&~ ,W',VO Y,~/,,e - /~.~' ,4. Cmt Vol for Hemlock P&A SRU 14-15 Packer @ 11,1 40' never set Packer @ 11,240' Tubing tail @ 11,275' TOO @ 10,100' Open Camco Mandrel Cement Retainer @ 11,235' Plug @ 11,280" 7", 28~, N-80 @ 11,449' Cement to 10,500' Vol-1 = 40'*.1911 = 8 * 200% = 16 cuft. Vol-2 = 135'.03253 = 5 cuft Vol-3 = 140'.1460 = 21 cuff ARCO Alaska, Inc~' Post Off;ce Bux ;00360 Anchorage. 41as~a 99510.0360 1-~ .'3~-~ _ ~ - ' -'~-'~-':'~ ~'3- 2-5 EnD:nee,:ng December 29, 1989 Mr. J'. A. Dygas, Branch Chief Division of Minerals Bureau of Land Management 6881 Abbott Loop Road Anchorage, Alaska 99507 Dear Mr. Dygas: Attached is a Sundry Notice requesting approval to temporarily abandon 31 wells in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.3:4, paragraph C of the Bureau of Land Management Regulations. All 31 wells are expected to be shut-in for a period of at least 30'days. The wells are separated into four categories: 1. Under evaluation for rate potential. 2. Under evaluation for P&A or future utility. 3. Inefficient producers. 4. Shut-in until blowdown. Several other items have .been attached for your information.. Brief explanations are given for each well. that has been added or deleted from the temporarily abandoned status (Ref: your letters of 3/1/89 (3160 (984)) and 3/30/89 (3180 (984)) and our letter 12/28/88). In addition, a list of cun'ently shut-in wells which have planned upcoming work that will enable their return to production is attached. If you have any questions concerning this Sundry Notice request, please call Stacy Strickland at 263-4914. Sincerely, Tom Wellman TW:SLS:jt:0016 Attachment CC: .C.V. Chatterton, Chairman AOGCC A. R. Kulda, Marathon Oil Company S.W. Ohnimus, UNOCAL'Corporation RE'¢EI'VED DEC2 9Lo&9 . alasle 0ii ti Cous. Commissi Anchorage ¢ ~NovemM~ 1983) (Ome~ tnscrueuoel ou (l%rmerty 9-:331) DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT i SUNDRY NOTIC AND ON (~ not ~ thM rom for D~Mts to d~! or to d~ or plus ~ek m i ~nnt ~oir. 1. '~. NAil 01' Ol'lbTOI ARCO Alaska, Inc. 3. ADDUM Of Post Offfce Box 100360 Anchroaqe, AK 99510 4. LOC&TION Of WELL (Re,ri lo~tlon clelrly S~ aim I~ IT ~lov.) At lu~l~ Soldotna Creek Unit - 11 wells Swanson River Unit - 20 wells 14. PIIMIT ~0. jL$. ILBV&T~ON8 (SM whetAer.oF, iT, at, Form approved. Elqdlet Bureau No. 1004--O13S EzDireu Au~uat 31. I~S oldotna_Creek/wanson ~v~r Units 8. ff~M Oa ~&aa 10. b~D &HO POOL, Oa WILDCAT IUuVBT 0a AaA& ~t,n Alaska 16. Check Approoflate Box To Indicate Nature ol Notice, REM,*, or Other Data NO%ilCB Off IBTBliTIOM ~: IUBIBG~B~I'I Nae: · ........-.-. ,..- ..t. ! IOtber) TemDorar i i y abandon o~.:_b,,,_mmm. ~ I~_Um. eutM_euo, o. ,compleuoa or &w-,_m_e~?e_- _~_%~_~ .fid_ r__._.~ ret1.) PROPOSED Ok COMPLk~ED OPII~ATIO.Y~e (Clearly state ~11 ~rtlnenc detalia. Ind ~tve ~rtlnent ~ Jn~lu~.l~td ~l~ of.aW ~ ~ro~:~ worL If w~ b di~o~ d~U~ five ~m ~uns ~nd mellur~ ~nd c~e vertz~ ~ z~ ~ msrEeu'~ MuM ~- As described in thc attached memo, ARCO Alaska, 'Inc. requests' that the following wells have a temporarily abandoned status: Soldotna Creek Unit Swanson River UrliI SCU 13-3 SCU 13-4 SCU 21A-4 SCU 34-4 SCU 24-5 SCU 33-5 SCU 33-8 SCU 341-8 SCU 34-9 SCU 31A-16 SCU 14-34 SRU 34-10. SRU SRU 14-15 SRU SRU 21-15 SRU SRU 211-15 SRU SRU SRU 31-15 SRU SRU 34-15 SRU SRU 41A-15 SRU SRU 43A- 15 SRU SRU SRU 432-15 SRU 23-22 31'2-22 ' 23-27 314-27 331-27 34-28 43-28 14A-33 24-33 RECEIVE[ Alaska 0il & Gas Coos. Comm Anchorage 32-33WD 12-34 · (Thti ipl~tJ for FodereJ or State oMeo mi .. &PPROVBD BT CONDITION8 Of APPROVAL. Lf A.NY: Cook I n I et Eng inerr ing Mnnagm~ma TI'L'T~ DATa '*See Inslmctiom on Return Side Title 18 U.S.C. Section t00t, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any f&lse, fictitious or fraudulent statements or represeflta~ona aa to any matter within its jurisdiction. TEMPORARILY ABANDONED WELLS IN SRF Wells under Wells being Wells SI Evaluation evaluated for for Inefficient Rate Potential .P&A/Future Utility Production - Wells SI until Blowdown 13-4 34-4 24-5 33-8- 341-8 34-9 41A-15 23-22 23-27 13-3 14-15 21-15 211-15 31-15 34-15 432-15 31A-16 312-22 34-28 14A-33 32-33WD 12-34 14-34 21A-4 33-5 34-10 43-28 24-33 43A-15 314-27 331-27 For: Temporarily Abandonment of 12/29/89 SWANSON RIVER FIELD Wells having Changed Temporarily Abandoned Status Added to Temoorarilv Abandoned Status: $CU 21A-4: Well is temporarily abandoned due to inefficient production (high GOR). SRU ~2-$3 W D: Well is temporarily abandoned due to annulus communication problems. Removed from Temnorarilv Abandoned Status: $CU, 243r8: production. This shallow sands gas well has been returned $CU 13-9: A workover is planned for this well which will enable this well to be returned to an active status. SRU 212-10,: This shallow sands gas well has been returned to production. SRU 23-15: This gas-lifted well has been returned to production. A sidetrack is planned which will enable this well to be $,RU 21-~4: returned to an actiVe status. RECEIVED DEC2 1989 Naslm Oil & Gas Cons. Commissiot~ Anchorage For: Temporary Abandonment 'Sundry of 12/29'/89 SWANSON RIVER FIELD WELL STATUS UPDATE Shut-in Wells with Planned Upcoming Work* $CU 32A-9: When on-line, this SI well produces gravel. A sidetrack is planned to return this well to active status. *Will not be placed on temporarily abandoned sta,J 'sCE/VED ~Omge Commi~io~ For: Temporary Abandonment Sundry of 12/29/89 Wel 1 s under Evaluation for Rate Potenti al 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 TABLE I Wells being Evaluated for P&A/Future Uti 1 i ty 212-10 21-15 31-15 34-15 432-15 312=-22 212-27 14A-33 12-34 22-23WD 243-8 14-34 Wells SI for Inefficient Producti on 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until B1 owdown 43A-15 314-27 331-27 343-33 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 12!5 Cook Inlet/New Ventures Engineering August 19, 1987 Joseph A. Dygas, Branch Chief United States Bureau of Land Management Post Office Box 230071 Anchorage,' Alaska 99523 Dear Joseph: Attached is a Sundry NOtice requesting approval to temporarily abandon 39 wells in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.4, paragraph C of the Bureau of Land Management Regulations. All 39 of the wells mentioned in the attached Su'ndry Notice are expected to be shut-in for a period of at least 30 days. The 39 wells listed in Table #1 were identified during our recent review of the status of all wells in the Swanson River Field. These wells have been put into four categories: 1. Evaluate for rate potential 2. Evaluate for plug and abandon/future utility 3. Shut in- inefficient production 4. Shut in - save for blowdown Wells. in Categories #1 and #2 are currently under evaluation to determine their final disposition. Wells in Categories #3 and #4 are wells with little short-term usefulness, but wells that do .have some long-term utility. If you have any questions about this Sundry Notice request, please contact me at 263-4299. Sincerely, H. F. Blacker Regional Engineer Cook Inlet/New Ventures HFB' JWR: ch: 0006 Attachment CC: .C.V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission ARCO Alaska. Inc. ,s ;t Sub.~dia~f of Atlant~cR~chfieldCompany Form 3160--5 (November 1983) (Formerly 9--331) ., . UNITED STATES (Other Instr~etlous on re* DEPARTMENT OF THE INTERIOR ..r.-,d,) BUREAU OF LAND MANAGEMENT SUNDRY NOTICES ,AND REPORTS ON WELLS (Do not ~se this form for props,Als to drill or to deepen or plug back ~o · different reservoir. Use "APPLICATION FOR PERMITs'* for suds I)ropoeML) OIL i~ GAl ~] waLL WELl, OTHER NAMR Or OPERATOB ARCO Alaska, Inc. Soldotn~ 3. ADDI~18 O! OPIIATOI P. O. Box 100360 Anehora~m. AI~ 9qSlf~-fl3fif~ LOCATION Or WELL (Re~rt location clearly and ~ a6cordlnc~ with any 8~ r~uiremen~,e S~ Also opm~ 17 ~low.) At I~l~ Soldotna Creek Unit - 15 Swanson River Unit - 22 wells ' 14. PERMIT NO. 16. mJVATIONS (Show who,her DIP, Form approved, Budget Bureau No. 1004--0135 Expires, August 31, 1985 --miss OSfiONA~Om AmD pULiL mo. 0. !1' ImDIAB, ALLO'I'TBB OR TRill NAME ?. umFE AQIBBJflIIT maul Creek~Swanson River Unit fARM O· LEAS[ NAM· s. will 10. ~i~LD AmD F~L~ OB WILDC&! Swanson River Field Il. Im~q ~fq L, Mq OB ELK. Ails · UI~VBY O· AlJA IS. L'OUI'/! OB filllllI 18. ITA~'II Kenai [ Alaska 16. Check Appropriate Box To Indicate Nature oF Notice, Report, or Other Data NO~lCB SIP INTENTION TO: BUBIB41UBm'f tllq)l'f O~: aRGOT OB &ClDLSI AR&NOONs BEGOT·NO on &CIDmlN· [ . I &BAmD4)NMBBTe REPAIR WELl` CHANGE PLAN8 (Other) .... I I (~To~B: Report results of multiple eomplelJon on Wall (Other) T~_mporar~ly abandon ___ Completion or Reeompletion Report and Lot form.) DE.'qCRIU£ ['IIOPOSED OR CO,%IPLETED OPERATION~*. (Cleat'l~ state all pPrtluPttt detallN, and give pertinent dates, laeludlu~ estimated data of starting proposed work. If well Lu direetionail~ drilled, five oubu~aee locations ~nd measured And true var·tad depths for ~11 markers ·nd fiSheS poru- nent to ,his work.) s As described in the attached memo, ARCO Alaska, Inc. requests the status o~ the £ollo~ing wells be changed to Temporaril~ Abandoned. SOLDOTNA CREEK UNIT SWANSON'RIVER UNIT SCU 13-3 SCU243-8 SRU212-10 SCU12A-4 SCU 13-9 SRU 34-10 SCU 13-4 SCU12A-10 SRU 14-15 SCU323-4 SCU343-33 SRU 21-15 SCU43A-4 SCU 14-34 SRU 31-15 SCU 24-5 SCU 14-3 SRU 432-15 SCU 33-5 SCU23B-3 SRU 34-15 SCU341-8 SCU 34-4 SRU41A-15 SCU2 lA-4 SRU43A- 15 SRU312-22 SRU 21-22 SRU 23-22 SRU 22-23WD SRU212-27 SRU314-27 SRU 23-27 SRU331-27 SRU 34-28 SRU14A-33 SRU 24-33 SRU 12-34 SRU 21-34 (This ap'ce for Faders] or State o~ce use) APPROVED BT COlqDITIOlq8 OF APPROVAL, /]' Alert: TITLm DATR *See Instructions on Reverse Side Title 18 U.S.C. Section 100l, makes it ~ crime for any person knowingly and willfully to make to any department or alenc¥ of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. WELL RECORD INVENTORY Fi e l d: Swansou R£ve]r Loca ti on -- ~ - I ii i i I [ T - - il Opelm&~Ol,' & We'I t Nalllel _ . .qt'=nclard Oil Compau_v l. Drilling Pemit: 2. Survey Plat: 3. Monthly Reports (P-3): 4. Completion Report (P-7):I 5. Well tiistory: 6. Other: 7. Mi s cel 1 aneous: 1 32 i j i . ' Total Pages: 8. Deviation Survey(s): 9. Well Logs: _(1) ~.~. (2) c~ _(4)_ (s) c_~ _(7) .., i _(9) (!0) 35 _ i i ,1 · ii i I i · I I i _ I · · m I i .e Box 937 Rock Springs, Wyo. 82901 Area Code 307 Tel. 362-6488 Producing Formation Elevation (CHF, DF, KB, etc.) Datum Tubing set at Casing set at Production Packer at Perforations ".. -..' C.A. White Wire Line Well Service Box 156 Casper, Wyoming 82601 · . · SUBSURFACE PRESSURE SURVEY .. . .. ~ubsea, or ( ) 274' lib ( ) _ 11271 1-1-225-11~00 Subsurface Controls (Nipples, etc.) Instrument Data Company Running Survey Element - Range & No. Clock - Range & No. Calibration Date Static Pressure Data , . '.Pressure at Datum ~ ) '. Shuit-in Time ) Pi at Datum Shut-in Tubing Pressure Shut-in Casing Pressure Top of Oil Top of Water Temperature at 11180 feet Date of 'Last :Test Pressure @ Datum, Last Test Shut-irt Time, Last Test" . , Flow Test Data Choke Size Stabilized Production Oil Gas ,. Water :. Flowing Tnbing Pressure "' Flowing Casing Pressure C .A. White ~'_*K2 7079 6000psi ~._3 Hre' · ',' :'.~':"'"::' "";k '. . Remarks: Rerun on .4-26-75 psig ' 428 psig psig . 172 °F psig bbis/day MCF/day. bbls/day psig. psig · ,. Operator_._ N.G. Hopper Box 962 Soldotna, Alaska 99669' Area Code 913 Tel. 262-4496 Company Standard Oil Company Lease SRU Wen No. 14- Field Swanson River State_Alaska Test Date Zero Point KB . GRD Press., P, psig 1353 2233 3108 3994 4861 4946, 5025 5127 5209 Static Test Time At hrs. VI31CN led De C adienl 000 415 440 438 443 434 425 395 46O i .... :| --I ........... .,!i i: ....... o. " ? ' '00 N31:IZJ. 310 3N3~rt'~ ~ a3dYd HdV~g N3~)ZJ. 31C] O~-oblOt~e '¢1N ,_i~. .. ~ :.'.' .-: -. ~,,~'. -. ""-"~ PRODUCING DEPARTMENT T£LEPHON£ BR. 7-6201 C. V. CHATTERTON DISTRICT SU PERINTENDEN'r P. O. BOX 7-839 · ANCHORAGE · ALASKA · .~ ..,, ~ ....... , ~. . ..... ~. · ..... _ .....~.,.~.~.~ .~ ,,: RECEIVED' AUG ;~ lgm Petroleum Branch Divislon of Mines and Minera~l Alaska Dept. of Natural Resoura~ ,/ '/ ¥/,....,(/;/.. / / .Oeatleaea~ wen ~~ ~v~ u,~t zb.l~. ' C, V.~~tte~tca' PERFORATING RECORD: Four Four Four ¥.. holes at 11, 218' holes/.foot 11,224'-11,231' Reperforated ~" holes/_foot 11,268'-11,276' Reperforated l" holes/foot 11,290'-11, 300' "holes/foot 11,290' -11, 300' Reperforated DRILL STEM TESTS: HOT ~1, at 11,218' WSO HOT ..~, at 8,500' WSO HOT~3' at 3,500' HOT ~, at 11, 290 ' -11, 300' HOT ~5, at 11,290'-11,300' HOT ~6, at 11, 290.' -11, 300' (B~test ~l) (Retest ~2) COMPLETION REPORT SWANSON RIVER UNIT 14-15 Section 15, T.: 8 N., R 9 W., Seward B &M S~Ammao OIL CO~A~ OF ~Z~O~mA, WOI - O~E~O~ ,Ma~ 18, 1963 Commenced rigging up at 3:00 P.M. Attempted to run Klmley perforating gun. Unseccessful due to wax in tubing. Set tubing p~ug, removed X-mas tree, and installed B~PE. Removed tubing plug. May 19, 1963 Pulled up on Guiberson KV packer and opened bypass. Killed well with 89~ Black Magic Mud, using Halliburton pumps. Pulled 2 7/8" tubing. m:' Z963 Ran 5 5/8" bit and casing.scraper and cleaned out to 11,307'. Circulated and conditioned mud and pulled out. Ran Cement Bond log 11, 298'-100'. Ran a Ealliburton D.M.. bridge plug and set at 11,245' holes at 11, 218'. Shot five ~" ,B'~, ~ ~.1, WSO test at 11,218' Tool Assembly: 2 outside BT recorders, 3' of 2 7/8" perforated tail pipe, 7" type "C" Nookwall packer, VR safety joint, hyda~ulic Jars,. 2 inside ,BT recorders, hydrospring tester, and dual closed in valve. ' Ran on 11,153' of 2 7/8" tubing.. Used 3000' of water cushion.. Set packer at 11,179', with 16' of tail to 11,195'. Opened tester at 12:10 A.M. for 5 min. pressure release. Faint blow of air for 5 minutes. Shut in tester at 12:15 A.M. for 45 min. IsI pressure period. Opened tool to sur- face at 1:00 A.M. for 75 min. flow test. Shut in tool at 2:15 A.M. for 60 min. FSI pressure.. Pulled packer loose at 3:15 A.M. Very faint bubbly blow for 30 min. Dead for balance of test. Recovered 10' net rise of Black Magic drilling fluid. Final Pressure Data :. Depth. C~..u. ge IH_ ISI, TOp inside 11,161' Bottom inside 11,165 ' Top outside 11,187' Bottom outside 11,191' IF FF FSI FIt ,, ~ · _ 6365 5070 1312 1325 ~ 6365 6356 5o61 1283 ]29o ~841 6353 6~o6 5o55 z332 z3~ ~75 6~6 No r~~s. Stylus ~sen~ged. Conclusion: Tool functionedOK. No water entry. COMPLETION REPORT SWANSON RIVER UNIT 14-15 Section, 15~ T. 8 .N...)_ R .9 W._~ Seward B & M STANDARD OIL COMPANY OF CALIFORNIA , W6I - oPERATOR Page 2 ,HCT ~ 2, WSO test o,n,L s, Que.ezed holes at 85,00~,... Tool Assembly: As before. Ran on 8616' of 2 7/8" EUE tubing. Used 480' of water cushion. Set packer at 8442.', with 16' of tail to 8458' at 1:48 P.M. Opened tester at 1:54 P.M. for 6 min. pressure release. Light steady blow of air. Shut in tester at '2:00 P.M. for 65 min. ISI pressure period. Opened tool to surface at 2:45 P.M. for 80 min. flow test. Shut in tool at 4:05 P.M. for 45 min. FSI pressure. PUlled packer loose at 4:50 P.M. Light blow of' air for 20 min., then dead. Dead at 3:05 P.M. Dead for remainder of test. Recovered 360' net rise, all Black MAgic drilling fluid. Final Pressure Data: Depth Gauge IH ISI IF FF FSI FH Top inside Bottom inside Top outside Bottom outside 84~94' 4526 829 369 379 745 4531 8%28' 4531 831 383 383 747 4531 8450 ' 4578 859 ~ 409 779 4578 8454 ' 4570 ~ 417 ~14 763 4570 Conclusion: WSO - OK Attempted to set packer to test holes at 3500'. Unsuccessful. Pulled. HOT ~3, WSO test on squeezed holes at 3500'. ~an on 3409' of 2 7/8" ELE tubing and 33 ' of 4 z,, drill collar. Used no water cushion. Set packer at 3468', with 16'~of tail to 3484 at 2:46 A.M. Opened tester at 2:52 A.M. for 6 min. pressure release. Im- mediate steady moderate blow of air for 6 mins. Shut in tester at 2:58 A.M,. for 62 min. ISI pressure period. Opened tool to surface at 4:00 A.M. for 90 min.. flow test. Shut in tool at 5:30 A.M. for 68 min. FSI press- ure. Pulled packer loose at 6:38 A~M. Immediate' faint blow decreasing to bubble in 12 min. (at 4:12 A.M.) Dead for remainder of test. Recovered 350' net rise, all Black Magic drilling fluid weighing 82-84 pcf. Final Pressure D~ta: _ . ,L, ...... : : . ;~:: zE zsz FF Fsz ~ttom i~i~ 3452' 1~4 29~ 229 216 271 1931 outside 3476' 1969 304 226 226 263 1969 ~ttom outside 3~0' 1990 ~3 247 247 292 1919 Conclusion: WSO - OK COMPLETION REPORT SWANSON RIVER UNIT 14-15 Section l~ T8 N.~ R 9 W.~ Seward B & M STANDARD O~ COMPANY OF CALIFORNIA - WOI Page Ran bit and scraper, drilled out DM plug at 11,245' and cleaned out to 11,307'. Circulated and conditioned mud and pulled out. May 24,_ 196~ Shot four 1/2" holes/foot 11,290'-11,S00'. H_C~_ ~, of the interval, ll, 290',, ,-11, 3,00' __ Tool Assembly: As before. Ran on 11,253' of 2 7/8" E~E tubing (6.5~) Used 3231' of water cushion. Set packer at 11,278', with 16' of tail to 11,294' at 12:43 P.M. Opened tester at 12:45 P.M. for 6 min. pressure release.. Immediate weak blow of air for 6 rains. ' Shut in tester at 12:51 P.M. for 2 hr. 5 min. flow test. Shut in tool at 3:58 P.M. for 52 min. FSI pressure. Pulled packer loose at 4:50 P.M.. Faint bubble and dead. Picked up to wash perfs at 2:25 P.M.. 2-3" fluid drop in annulus (Pipe displacement) Set down at 2:35. Felt like packer was slipping, would not take weight. Picked up and pulled packer loose. Reset packer at 3:52 P.M. Tester reopened at 2:58 P.M. Faint bubble and dead. Dead for remainder of test. Recovered 124' of net rise~ grading from 78 pcf Black Magic at top to 139 pcf Barite and Black Magic.. Final Press.ure .Dar6: Top inside ll, 260' 6327 4902 1397 1409 4964 6263 Bottom inside 11,264 6358 4990 1422 1422 5000 6337 Top outside 11,286' 6403 5036 5041 5053 5053 6394 Bottom out~tde 11,290' 6452 5046 5043 5053 5061 6444 Conclusion: Charts indicate tail pipe perforations plugged. Content of rise indicates Barite settled out frcm Black Magic Mad. Possibly some formation fluid, entry.as s~me sandy particles were in rise. Test incon- clusive. ~Y 25 and 26~ 1963 ___ open ended, drill pipe and conditioned mud at 11~307'. HCT #5, retest of the interval _1172_90'!...1!,300~_. Ran on 11~253' of 2 7/8" EUE tubing. Used 3293' of water cushion. Set packer at 11~278', with 21' of tail to 11~299' at 9:57 P.M. Opened tes- ter at 10:00 P.M, for 30 min. pressure release. Immediate faint blow to dead in 25 minso Shut in tester at 10:30 P.M~ for 55 min. ISI pressure COMPLETION REPORT SWANSON RIVER UNIT 14-15 S,ection 15~ T...8 N.. R. 9 W._~ Seward B & M STANDARD OIL COMPANY OF CALIFORNIA, WOI - OPERATOR Page 4 period. Opened tool to surface at 11:25 P.M. for 65 min. flow test. Shut in tool at 12:30 A.M. for 30 min. FSI pressure. Pulled packer loose at l:O0 A.M. Dead throughout flow test. Recovered 68' net rise grading from cushion contaminated Black Magic Mud to 143~ sandy Barite and Black Magic. Final Pressure Data: Depth Gauge IH ISI IF FF FSI FH Top inside 11~260' 6368 1459 1459 1459 1459 6353 Bottom inside ll~, 264' 6414 1440 1440 1440 1440 6286 Top outside ll~ 291' 6401 5034 5034 5034 5034 6353 Bottomoutside 11,295 6492 5048 5056 5066 5066 6492 Conclusion: Charts indicate tail pipe perforations plugged. Content of rise indicates Barite settled out of Black Magic mud and some sandy fluid entry. Test inconclusive. Pulled tester am~l ran open ended drill pipe. Circulated and conditioned mud. _~__.¥~ 27, 1963 Reperforated with four 1/2" holes/foot 11,290' -11,300'. HOT ~6~ R..et~s.t., of the interval l!~ 290' -Yl~ 309' Tool Assembly: As before. Ran on 11~213' of 2 7/8" EUE tubing. Used.3293' of water cushion. Set packer at 11~249', with 47' of tail to 11,296' at 10:42 A.M. Opened tester at 10:45 for 33 min. pressure release. Immediate weak blow increasing to a moderate steady blow for 10 min.~ then decreasing to weak in 5 min. (at 11:00) then increasing to strong in 5 min. (at 11:05) then heading slightly till when shut in. Shut in tester at 11:18 A.M. for 45 min. ISI pressure period. Opened tool to surface at 12.:03 P.M. for 3 hr. 22 min. flow test. Shut in tool at 8:25 P.M. for 2 hr. 36 min. 'FSI pressure and backscuttled. Sampled backs cuttle . Pulled packer loose at 11:01 P.M. Immediate stro~ steady blow of air. 3/8" Shaffer adjustable bean at s~rface. Cushion. to surface with scum of Black Magic at 1:05 P.M. Opened to 1/2" surface bean at 1:18. No noticeable change. Flow changed to heavy oily mud at 2:48 (Wt. 81~ gritty sandy). Flow changed to water with gritty oil scum. at 2:58P. M. Flow changed to oil at 3:55 P.M. Flow changed to water with oil scum at 4':10. (Estimated 85-90% water) Flow remained un- changed for remainder of test. Flowed at 164 B/D rate. Water tested 900-950 G/G~ 15000-16,500 PPM. Cushion tested 24 G/G. COMPLETION REPORT SWANSON RIVER UNIT 14-15 section 15~ T. 8 N.~ R. 9 W.~. Seward B & M STANDARD OIL COMPAiIY OF CALIFORNIA, W0I - 0PERATO~ Final Pressure Data~: (HCT ~6) Depth Gauge _T_IE~ ISI IF FF FSI FH Top inside 11,235' 6239 4974 Clock failed - Bottom inside 11,239' 6201 4943 .... 4823 4933 6096 Top outside ll~ 284' 6298 5024 3284 4904 5014 6179 Bottom outside ll, 288' 6299 5015 3270 4898 5005 6185 Conclusion: Charts i~ieate partial plugging during pressure release. period. Tool functioned properly. Test diagnostic. Bottom sand wet. Ran open ended drill pipe. Circulated and. conditioned mud. Ran junk basket. Ran a Halliburton cast iron bridge plug and set at 11~280t. ~, 196____~3 Ran Schlumberger carrier gun and reperforated the interval 11~ 268 '-11, 276 ' and perforated 11,224'-11,231' with four ~-" ho]~ s/foot. Ran bit and casing scraper and cleaned out 11,280'. Circulated and pl~,lled out. Ran Baker model "D" packer on wiretine ~%d set at 11,240'. ~ 3o, 1963_ Reran 359 joints 2 7/8", 6.5~, N-80, EUE 8R, Rg 2 tubing with packer and mandrels. TUBING DETAIL E.B. to donut One 2 7/8" pup Joint and Three 2 7/8" pup Joints 44 Joints 2 7/8" tubing Camco MM mandrel with RD 4~ Joints 2 7/8" Camco MM mandrel 41 joints 2 7/8" Camco MM mandrel 39 Joints 2 7/8" Camco MM mandrel 34 joints 2 7/8" Camco MM mandrel SS joints 2 7/8" Camco MM mandrel 24 Joints 2 7/8" Camco MM mandrel 20 Joints 2 7/8" Camco MM mandrel tubing with RD tubing' with RD tubing with RD tubing with RD tubing with RD tubing with RD tubing with RD K. B. Depth 15.30' donut 2.50' 17.80' 24.3o' 42.1o' l, 329.84' l, ]71. valve (1) 12.84' l~ 384.78' 1,350.79' 2,735.57' valve (2) 13.18' 2~ 748.75' 1~254.17' valve (3) 12.80' 4~. 015.72 1~174.78' 5.. 190.50' valve (4) 13.17' 5~203.67' 1~040.82' 6,244.49' valve (5) 13.22' 6.. 257.71' 1~ 009.96' 7,267.67' valve (6) 12.79' 7,280.46' 726.35' 8,o06.81' valve (7) 13.17' 8~019.98' 615.94' 8~635.92' valve (8) 13.o5' 8~,648.97' (Continued) COMPLETION REPORT SWANSON RIVER UNIT 14-15 Section 15~ T. 8 N.~ R. 9 W., Seward B & N STANDARD OIL COMPANY OF CALIFORNIA, WOI "OI~ERATOR Page 6 23 oints 2 7/8" Camco MM mandrel 25 joints 2 7/8" Camco MM mandrel 15 joints 2 7/8" Camco MM mandrel 16 Joints 2 7/8" tubing with RD valve (9) tubing with RD valve (10) tubing with RD valve (ll) tubing Camco MM mandrel with CEV i joint 2 7/8" tubing Brown CC safety Joint One 2 7/8" pup joint Brown 2 7/8" x 7" HS-16-1 packer 2 joints 2 7/8" tubing Camco MM mandrel with CEV One 2 7/8" pup Joint Camco "D" nipple One 2 7/8" pup joint Baker model "D" stop sub Sealing assembly Production tube Tubing landed in Baker model "D" packer at ll~ 240' with tail to 703.24' 9, B52.21' 12.72' 9, B64.93' 760.59' 10,125.52' 12.80' 10~ 138.32' 455.74' lO~ 594.06' 12.77' lO,606.83' 489.31' ll~ 096.14' 12.77' 11~ 108.91' 29.77' 11,138.68' 1.07' 11~ 139.75' 7.93' 11,147.67' 6.00' 11,153.68' 58.44' 11~ 212.12' 1.3.08' 11~225.20' 8..11' 11,233.31' · 95' 11~ 234.26' 4.05' ll, 238. .63 11 238. 3.73' 11,242.67' .30.00' 11,272.67' 11,272.67' Removed BOPE~ installed and tested X-mas tree. Displaced mud with oil. Set plug in D nipple. .MSY..3!, ~.196B Attempted to set CEV valve in mandrel at 11,212'. Unable to get CEV in mandrel. Pulled CEV. Rig released at 7:00 A.M. After rig was moved off location, retrieved Brown plug. Decided not to run CEV and not to set packer. Well was put on production June 3~ 196B~ flowing at a rate of 14 B/D oil on 64/64" bean to a Baker tank. mme 8, 1 3. The production turned to 100% water~ and the well flowed an average of l0 B/D water until July 3, 196S, when the well was shut in. UNITED STATES DEPARTMENT OF THE INTERIOR G£OLOGI¢^L SURVEY- Blidgt. t l~,::,..au N,,. Approval vxpir,'s g~.,o ~.V~.~:: A~pkor. age · 'r.,,~- ~.:,'_~., A.-O284P.6.. u.,-,- .S.~a~Son gi~e~ LESSEE'S, MONTHLY REPORT OF ', Stat,, ..._Alaska ....... Co~nty ..K.e._n..._~_..._P...e_n..i.._n.g.~_l...a ..... t,'ield Swanson River ' ':':.~;['i: : ~.. 77~d follo:rDz,.j. . i.e a corree.~ report we~i:O /'or tt~,' r,~..ont7t, o/' . ........................... May ...... 19~J.. , Swanson ;~&ver,:"ii~'~'":: ""-~.',~ ,-. .. ' , ............ C '~ ' V~;'-'5~rl'ATT ~T-~.i ;: ..................... ..'t¢e.n.t's addr,'.~:~ P. O..Box..7,839. .......................... .Anchorage,..Alaska... ,.~'i~ncd ' ' "' ' '"'- .... .............................................0:~ "~V. ~'-~4.~_~:.~:~_~' ' ' ~ ~ .............. Pho~e .................BR.o.a. dway._.?.-._o..2..0.:l.. ............................................ ~1,_Jcnt's titlc Dis'b ti. ct, S'.a. pe~intendent '15 8N 9W SW~ ~SON RITER UNIT Cu. FT. O~' GAS GALLONS or lqARI~ELS Or REar, AR KS ~ECOVEI/ED ~o~e; so state) da,.~ ~d result con.ut ................... ~ ..................... . . ! Oonmence~ remedial t work iMa¥ 18, 19 BOP E. P~lled tu~iOg ou ~ of hole. ' WSOi [tests at ll, 218 ', 85C0', ahd 3500'. !W'80 ika¥. ' t Sh~ fo~ ~" holes),oo, '11,290'-11,300'. ,An HCT ~.' Recove,ed t2~' ,et/rise. TeSt in~on~lusive,~perfora~&ons pl~ged. Re- te~ted 1~,290'-11~,~OO' ~HC't ~5). Hecovece~ 68' ~t[rise. Test ~n~on~lu~ive, per, StatiOns plugged~. Reper~'orated ~th four ~" no~es/fopt ~o290'~ll,..QO'and ran '.~CT ~6. :t~ened ~r 3 hours 22 ~nu~s fl~ te.~t. ~lowed wate~ with sc~ of o~ at 164 B/D Se~ bridge plug at ll,: ~O' and rep~rforated with tw~ .~" aoles/ fo~t. 11,~68'-11, 27~ '. , a~ ~ ~rforatei with f'~ur ~" holes. /'foot ~1,[224'-~1,231'. ~et ~ M~el "D" packer at ~,240' (top). R~and ~anded 2 7~t8" 'qb~g. Removed BOPS and ~st~led cc:~ U.S~G.S. - M. H. $~ter (2) sta e - T. a. ~chfield - C~ W. ~erry ~. R.R. Ritter ~r~thon - Gesrge ~owards Unibn - H. M./Li~/ / NoTw..~There were ......................................... runs or sales of oil; ...................................................... M cu. ft. of gas sold; .................................... : ......... runs or sales of gasoline during the month. (Write "no" where appliemble.) NoTm.~Report on this form is required for each calend~r month, regardless of the status of oper.-~ions, and must be fried in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise direoted by the supervisor. For~t 9-$29 .(January 1950) 16'-'25756'-8 O. ~. GO¥~'."..~.~' ~nl~rl,G QFgIC~ Euclosed is r~e .ap~'oved Application COHPLETION R.'.~. ~RT PACKER AND GAS LIFT INSTALLATION STAIID~ OIL. CgEP ,,A,~_IY- OF CAL IFOBiIIA - WESTERN, OpE,i~AT!0,NS, , INC ;, - OP,,,ERATOR AREA: Kenai Peninsula, Cook Inlet Area, Alaska PROPERTY: Swanson River Unit LA~ OFFICE: Anchorage ?.EASE NO.: A-028406 WELL NO.: SRU 14-15 ,. Section 15, Township 8 North, ~ange 9 West, Seward LOCATION: Surface: Bottom Hole: 1680' West and S60' North from Southeast Corner of Section 16 2460' due East from surface location (SRU B4-16) ELEVATION: 274' K.B. DATE: August 5, 1963 _ · i 1. i , , K. B. is 15' above ground /-% .... C. V. 0EATTERTON, Dist~ct Superintendent Santa Fe Drilling Compaz~v, Rig ~35 DATE COMMENCED P~DIAL WOP~: May 18, 1963" DATE COMPLETED REMEDIAL .WOE(: May 31, 1963 SUMMARY ~OTAL DEP~E: 11, 460'" PLUGS: Eallib~Aton CI bridge plug at 11,280' 11, 307 ' -11, 340 ' 11, ~25 ' -11, 449 ' ....See Original Completion Report OASING: 22" cemented at 4~' 13 3/8" cemented at 296?' 7" cemented at 11, 449' petroleum JSranch Divlslon of /~in.es and ~ineralS Akmka Dept. o~ t4aturat Resource~ STATE OF ALASKA :Se,'o~hor m- .~t ruct ions on reverst. Side OILAND OAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: on, [~] ' uAs 'l~,] DRY [] Other W~:LL W F,L~- b. TYP~ OF COMPLE~ON: w EI.I. OVER EN ~ BACK RE~VR. Other ~ 2. NAME OF OPERATOR 2. ADDRESR OF OPERATOR 4. ~,OC~T[0.x OF WEL~. IRel)ort location clearly and in accordance with any State requiremet~ts)* At ~urface At top prod. interval reported below At total depth 13. 'DA.TE SPUDD~.'114. DATE T.D'. BF.,ACHED ! ! Ill.' TOTAL DEPTH, 1VLD & TVD[19. pLUG, ! ~-').. PRODUCING !N'T'ERVAL(S), O.F THIS COMt~.,ETION~TOP, BOTTOM, NAME (MD AND TVD)* 5. AP1 NU1VIF-A~CAL CODE 6. LEASE DESIGNATION A-ND SERIAL NO. ~ I~ _~_ 1~'" I,.~' 7. IF INDIAN'. ALLOTTEE OR TRIBE NA.M.E 8. UNIT,FAILIVI OR LI~.A,$E NA~IE 9. WELL NO. 10. FLEI.,D A,ND POOL. OR Vv'ILDCA. T 11. SEC., T., R., M.. (BOTTOM HOLD OBJEC'I'IVE) 12. PERMIT D,~,TE CO,MP SU. SP O~ ABAND. [16' IEL'EVATIONS t DF' RKB' R'£' GR' ETC)* 117' EL'EV' CA'SINGIiEAD~l HOW MA.NY* ROTARY TOOLS '' C'.ABI,E TOOLS ' 23. WAS DIREC"rlONA.L ! SU£t ¥'EY MADE i 24. TYPE ELECTI.{IC AND OTHI~ LOGS RUN CA, SING SIZE WEIGHT, , i CASING RECORD (Report all strings set in well) DEPT~I SET (MD) HOLE sIZE ClaSir..N TING RECOI'LD PULLED 26. LINER I'tEC 0'~- 28. PERFOI%AT£ONS OPEN TO PRODUCTION (IuterVal, size and nurnber~ 27. TUBING RE~OTLD SCI:IF_,EN (MD) SIZE DEPTH SET (MD) ~ PACI{ER SET (MD) 29. ACID, Si:OT, F;.I~CI'LrlIE, CF~,IENT SQU.EEZ.~, ETC. DEPTII IICi'fIRVA.L (MD) AA,iOUN'£ AND I..'!ND OF 1VIAI'E~LIAL USED D~`TEF~cTPf~DUCT~[P~DU~T~NME~£~O~D(F~wh~g~``~aJ~i£~pumping-sizeandtype~pump). ~ . . ] V/ELL STATUS (Producing or snuL-in) DATE OF T~ST, [~OURS TES.T~ ' [~IOI{E SIZE ' ~ROD'N FOR Oi~BEL. G~CF. WATE~BBL. [ OAS-OIL IL%TIO ~ [TEST WITNESSED BY 32. hiST OF ATTACHMENTS 3,2. I hereby certify that the foregoing and attached information is complete and correct as determined from all-available records '-' ?-'~"~T& . *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- meats given in ether spaces on this form and in any attach;.'nenis. Items 20, and 22:: If this well is completed for separate praduction from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prc-Juci,;g interval, or intervals, top(s), bottom(s) and name (s} (if 'any) for only the interval reported in item 30. Submit a separaie report (page) on this form, adequately identified, for each additional inte, val to be seperately produced, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items' 20 and 22 above). 34. SUMMARY OP" I{'O~MATION TES'I'-q INCLUDING INTERVAL TF_,ST£D. PRE.e'~quRE DATA AND '.RF~OVERIF. S. OF OIL. GAS. 35. GEOLOGIC M ARK~,,S WATER AND MUD NAIVI~ MEA$. D~-'PTH !T'RU~ VERT. . .. _ 3~. CORE DATA, Aq'I'ACll ~IE~' D~~O~S 'OF ~IO~GY, POROS~Y~ FRAC~R~. AP~' ~{- AN~ D~ITEC~tEI)- SIIOWS OF' OIL, GO- ~ W~ ' (Fsb. 1MI) '--X 15 (SUBMIT IN TRIPLICATE) UNITED STATES DEPARTMENT Of THE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS NOTICE Of INTENTION TO DRILL . ._ NOTICE OF INTENTION TO CHANGE PLANS ........... I- . NOTICE OF INTENTION TO TEST WATER SHUT-OFF NOTICE OF INTENTION TO RE-DRILL OR REPAIR WELL ........ I .... NOTICE OF INTENTION TO SHOOT OR ACIDIZE ............ NOTICE OF INTENTION TO PULL OR ALTER CASING ........ SUBSEQUENT REPORT OF WATER SHUT-OFF ............ SUBSEQUENT REPORT OF SHOOTING OR ACIDIZING ............ ~ ..... NOTICE OF INTENTION TO ABANDON WELL .............................. .~_O._~.'$..c_.e_...o~. ~.nt_.en.~..i.o_.n, t9 .p~._.r.f_0r.a.t_e.. I:. X SUBSEQUENT REPORT OF ALTERING CASING ................... SUBSEQUENT REPORT OF ABANDONMENT .......... SUPPLEMENTARY WELL HISTORY ................... (INDICATE ABOVE BY CHECK MARK NATURE OF' REP'ORT, NOTICE, OR OTHER DATA) * Surface location: Well No. SgU. ~-15. is located 360 ft. from,_ line and .1690.. ft. from tine Of'sec..'..1(~. ..... ~. ~ ..:=~ ~ '"~ -,~, · ...... ..... (-~ Sec. ~n,i s~. No.) ..... . ..... (g~mge) ..... (Meridian) ._.Sw...a..n.~ .o..n., ..R.i.v..e .r ............. ~e..n~l P.e. nin~_ula .................. (Field) (Co{lnty or 8ubdivision) · The elevation of the derrick floor above sea level is. 27~4 ft. * Subsurface location: 2460' due East of surface location DETAILS OF WORK Pefro~eum Bi'anch Natural Resource~ (State names of and expected depth= to ob~octive -~nd,; show sizes, woi,hta, and lenfth8 o/propouod ca~lrl,s; indicate muddirt~ job, InE poJrtts, and ell othm' important propooo~ work) Present Status: Work Proposed: 1. 2. 3. 4. T.D. 11,460', 7" Csg. emt'd 11,,4.', plug 11,301'. Well shut in, having last produced 3/0 B/D oil/water, November, 1962, from perforated int. ePval 11,262'-11,276'. Move in rig. Pull tubing. Perforate and test interval 11,290'-11~3OO'. Further perforating and testing will depend upon results from test of 11,290'-11,3OO'. Recomplete well on gas lift from perforation based on test results. Address ..... ~,__._0_,.._ ~0_~._7.., .83.? ....................... .................. _8_n..c. ko. r~&e_~._ ~!a. ~ka. .................... I undorutand that this plan oE work must rocoive approval in writirt~ by the ~i~ul ~urvey ~f~o o~ratioM may b cmmo~ ~mp~y _.~ ~r~..., ~!..Oom~._~f_.U_~f~r~.~__~p.~6~__~[~98~x._~U~ ..................... ....................................................................... Title ~.~~..~~A~.~_~_~_~.~_~ ........... GPO 862040 APPLICATION FOR PERMIT TO DRILL, DEEPEN OR PLUG BACK APPLICATION TO DHILL [] DEEPEN [] PLUG BACK [] R~~{, NAME OF COMPANY OR OPERATOR S_~!~a!idk-~l 'Co, of ~tfo~a, Weatern Operat~o~. ~n~.. Address ~ ~ ~-- City ~ ~ho~e DESCRIPTION OF XVELL AND LEASE Name of lease State I ~Vell number I Elevation (~round) Snneon ~Yer unit ~-1~ . J . . ~ec~n~t~nshi~n~ or block & survey Field & reservoir (If wildcat, so state) Swa~sm '~ver Field Distance, in miles, and direction from nearest town or post office County Xenai Nearest distance from proposed location to property or lease line: Distance from proposed location to nearest drilling, completed o~ applied~for well on the same lease: Proposed depth: ~ feet .... ", .... ~ .;::. :.. feet ~ot~ry or cable tools ..... " Number of acres in lease: If lease, purchased with one or more wells drilled, from whom purchased: ,~am e IApprox. dale work will star! Number oi .'ells on lease, including this well, ~,~C~~:( ..... completed in or drilling to this reservoir: Address . Status of bond Remarks: (If this is an application to deepen or plug back, briefly ,describe work to he,done, giving present producing zone and expected new producing zone) ,, .i~reeent. et~tue~ teat CERTIFICATE: Z, the undersigned, state that I am the, of the (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein, are true, correct and complete to the best of my knowledge. Permit Number: _ ./~-~' Notice: Before sending in this torm be sure that you have given all information requested. Much unnecessary correspond. ence will thus be avoided. See Instruction on Reverse Side of Form Signature '. . OltA~.~Aet. ' '. Alaska Off and Gas Conservation Commission 'Application to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. 1 Effective October 1, 1958 . . PRODUCING DEPARTMENT TELEPHONE BR. 7--6201' J. T. CROOKER DISTRICT SUPERINTENDENT ' P. O. BOX 7-839 . ANCHORAGE · ALASKA March 22, 1961 Mr. R. V. Murphy Alaska Oil & Gas Conservation Commission 329 Second Avenue Anchorage, Alaska Dear Sir: Enclosed, herewith, is the Completion Report - Remedial, for Swanson River Unit Well 14-15 (4A), for your information and files. Enclosure Very truly yours, STANDARD OIL COMPANY OF CALIFORNIA Western Operations, Inc. J. T. CROOEER COMPLETION REPORT - REMEDIAL STANDARD OIL COMPANY OF CALIFORNIA - WESTERN OPERATIONS INC. - OPERATOR AREA: Kenai Peninsula, Cook Inlet Area LAND OFFICE: Anchorage PROPERTY: Swanson River Unit LEASE NO.: 0284O6 028077 WELL NO.: SRU 14-15 (4A) Section 15, Township §N, Range 9W, Seward LOCATION: 5130' south & 6791' west from the SE corner Section 10. Surface location in Section 15. At total depth of 11,460' the vertical depth is approximately 11,O20' and coordinates are approximately north O' and east 2460'. ELEVATION: 274' K.B. is 15' above ground DATE: March 20, 1961 , ,. ............. '~. ,..- ......................... COMMENOED OPERATION: 7:30 AM February 10, 1961 COMPLETED OPERATION: 5:30 PM February 10, 1961 PRODUCTION: Flowed well during operation SU~I~RY TOTAL DEPTH: 11,460 ' ~ PLUGS: Dig. hole - see Oompletion Report hole- 11,301' - 11,340'' 11,425, - 14449' JUNK.' Side tracked in or~g~ml hole See original Completion Report GASING: conductor pipe O 44' cemented $ 9' SUNDRY NOTICE~ AND REPORTS ON WELLS ~ OF IN'IIITION 1'O TEST IATTR SflUT-OIqr ............. [ ..... Iii&ilK NATUIIC M NI:II'D~T, N, OT~. ~ ~ DATA) / Wd[ N~ .~=~ ........ k~ ~ .... E. fr~.. line m~ ..~.6~.. k. f~ 1~ a ~. _~ ...... .... ~ j~ ...... ~..~..~,,..~,..~..~. .... ~.~.~.~.~.. A_ :~ ~ ~n - ~.) (~} (M~) ~.~r .~_.~_~ ............ .A~.~ .................. .......................... (~ ~ e~at~ ~ ~e ~ a~ve ~ DETAI~ OF WO~ + ~~s~e ~oM~on: ~' due ~ ~r~ ~3 ~/~, ~ice ~ ~o~ ~e ~rt out.ned ~1o~ is he.by su~t~: 2. ~ ~ ~-~r log ~~ ~i~. ~) ~t ~11 ~11. 3. Jet ~o~ i~~s I1,~2 - ~1, ~o~te im~e~l 11, ~- 11, ~8, ' , umi~ th~ ~u~i~ equi~~., ~. ~ o~ e~i~n~ ~ ~nti~e ~ , .,,,. ... COMPLETION REPORT - PJ~EDIAL SWANSON RIVER UNIT 14-15 Section 15~. T. 8 N.~..R. 9...W..~ S. eward B & M ~TANDARD OIL CO. OF CALIFORNIA, W.O.I. - OPERATOR Page 2. PERFORAT IONS: 4--m~'' 8500' Squeezed holes at with cement Squeezed 5-~" holes at 3500' with cement WNS0 through 5r½" holes at 11,255' WSO through 5-~" holes am -1,344 4-~" holes/.foot 11,312' - 11,340' (Squeezed & Plugged) 4-~" holes/foot 11,268' - 11,276" 5-3/8" holes/foot 11,262' - 11,274' (Perf'd & reperf'd) TUBING: 2~" EUE tubing hung at 11,235½' with a Guiberson KV-30 production packer from 11,167' to 11,173' (according to Gamma Collar Log). 1 blank joint and 1 perforated. Joint belew packer with Venturi shoe on bottom at 11,~35~'. PROBUCTION: Well still flowing. COMPLETION REPORT - RE~DIAL SWANSON RIVER UNIT 14-15 Section 15., T...~ N.,. R. 9 W..~ Seward B & M STANDARD OIL CO. OF CALIFORNIA, W.O.I. -'OPERATb~ Page 3. February 1~O, ..1961 7:30 AM Moved in Weaver Bros. 35 ton crane and Schlumberger truck and rigged up the high pressure lubricator which was 41' long. Ran in with Schlumberger tubing Gamma Ray Collar sonde which consisted of 2' head, 8' weights & 5' gamma ray instrument with the collar locator on bottom (total 15' ), ran on 5/16" mono element cable through the lubricator. All measurements are based on K.B. which was 15' above ground level. Hit a bridge at 11,274' (bo~.~,om 2' of perforation), and spudded the sonde six times in an attempt to go to 11,301' (effective depth). Recorded 11,274' to 10~3OO'. Correlated gamma ray log to I.E.S. and found casing collar at 11,272', the Venturi shoe at 11,235½', and the Guiberson KV-30 production packer between 11,167' to 11,173'. Cut 5' of jet capsules from gun due to inability to get below 11,274' Ran in through lubricator with gun which consisted of (bottom up) 12~' jet ~apsules, 3' collar locator, 8' weights, and 2' head (25' total). Jet perforated %-3/8" holes/foot from 11,262' - 11,274' with reference to casing and tubing collars and gamma ray correlation with the I,E.S. Came out with sonde and ragged insulation on wires indicating that gun had fired. Laid down high pressure lubricator and replaced tubing. Job complete at 5:30 PM. Average production prior to job was 21 B/D, 31.O°, 5% cut, 64/64" bean, 3 MCF/D. Average production after the remedial work was 31 B/D, 31.OO,. 3% cut, 64/64" bean, 5 MCF/D. (See attached production sheet). O. W. Gilbert OWG: arab COMPLETION EPO T - E EDIA5 SWANSON RIVER UNIT 14-15 Section 15, T. 8 N-, R. 9 W., Seward B & M 'S'TANDARD OIL cO~OF CALIFORNIA, W. oiI.- OPERATOR Page 4. PRODUCTION HISTORY SWANSON RIVER UNIT 14-15 (4A) Date February 22 15/0 February 3 15/0 February 4 26~1 February 5 19/1 February 6 19/1 February 7 19/1 February 8 24/1 February 9 27/1 February 10 Remedial February 11 36/1 February 12 38/1 February 13 38/~1 February 14 30/1 February 15 35/~1 February 16 29/1 February 17 29/~1 February 18 29/1 February 19 29/1 February 20 29/1 February 21 29/1 February 22 27/1 Work Hrs . on Prod. 1, , , , . 24 hours 24 hours 24 hours 24 hours 24 hours 24 hours 24 hours 24 hours 24 hours 24 hours 24 hours 24 hours 24 hours 24 hours 24' hours 24 hours 24 hours 24 hours 24 hours 24 hours 24 hours NOTE: Gas: Bean: is estimated at from 3~ to 5 MCF per day Full 64/64 th!s PRODUCING DEPARTMENT TELEPHONE 47001 J. T. CROOKER DISTRICT SUPERINTENDENT P. O. BOX 839 · ANCHORAGE ° ALASKA September 8, 1960 CONFIDENTIAL Mr. R. V. ~urphy Alaska Oil & Gas Conservation Commission 329 Second Avenue, Anchorage, Alaska Dear Sir: Enclosed, herewith, are one field print and one sepia copy of the Composite Induction-Electrical Log for the Swanson River Unit Well No. 14-15 (4A), recorded at intervals as follows: Run No. 1 - 46-3,009 feet Run No. 2- 3009-10,459 feet Run No. 3 - 3636-10,990 feet Run No, 4 - 10,990-11,450 feet for your information and files. Very truly yours, STANDA~ OIL COMPANY' OF CALIFORNIA Western Operations, Inc. Eric lo sures J. T. CROOKER OCT 12 110 Standard Oil Co. of California Permit Noe None Swanson River Unit I -To, 14-15 (") Sfc loc: 150' FSL & 1511' FEL, Sec 16, TBN,R9W, SUM BHL: 150' FSL & 9491 FWL, Sec 15, T8N,R9W, SUM Ele: 274' KB -o 259' grd Contr: Coastal Drl& Co. Spud: 3-29"59 qWltd: POW 7-25-59 TO 11460' IP: 100 B/dq 32*8% AP19 12/64#1 cko GOR 113/19 TP 170 psig Perf: 4-V @ 11268'-11276', 5--3/8" @ 11262'-11274' Plugs: 10978'-11168* & 111751ftII316' orig hole; 11301* -1131401 11425'-11449' R/D hole Csg: 22" conductor @ 44' w/25 9x 13-3/8" @ 2967' w/2940 ox 7" @ 11449' w/600 ex 2% tbj hmg @ 112351 Rewrks: WS out of SRU 34alS @ 3774' · . . .:-'~'~.~ ~ ~ t' '~..~'~,"..:~:.~ :...:~'-'"' .... .:.~,.: ~.-..,,-_~,.~, :;;;. ;-....,r -...~,. .... ., -' ",;:~' -"',:-'" -" -'.- '; :-~.~!".'~-'.~ .'~'"': '' ~"'~f ?.. ,~' ~'~ ~"~ "~."" ~"~'.~."-~i..':,' ::"~':~'~ ~:.:~"."',~'" .'.:"..: '"~.;,~::'?'~'""? .... '~..(.: ..... ...~. .... : ::':....~; ...-,......,...-*-.-~,.. · -,-.,-..-....,... :' ,.. ~.,,'.~....~.,~.-' ;,~'.. ~.~-~ ~..~,~.~-',~';'~~..,.~~ ~ , ~,. ,~..-~ ~.~ ........ ..~. ... ,.. ..... · ,, ..... ~ ~ -:..... - .~.o. , !'c~.~ ~ ..... ~.~.,..~.~.~ ~,. . ,~ .. ,~ . ,':'.,.,,~..,, . .. .- ..,~,.~:,., .. ',., ~ , ~'.. , ~ . ,.' , *...~-." ~,~- . ~, .~ ,',,,......: -...,. ,,,. ~..,~..-f-~.., ,..: . .,~,'..o . .. . .. -: ~?, ..,,~,:.' ,'.. ,,, . ...~ ,,.,.':.. ..,,~, * . .......~,~ . ,~ *~;,~ ',.'.. ,. ,~,, ~.;. ,. ~. :;,.'.. '~'.-~.~' ~;..-...... ..... : ~... .... ... ',~,..' ~ .'.:.~-:.'?..'.....,,. . ,. : ...: ,,...~.. ..... · ..... . ......... .. ; ..., . .....~.. .... .~,._ . _ ~.,.~ ~;~" ~'~ : "~:' "'~ ~"'°""'i'.' " ' " ' ' "" ..... ~ '""* '" '" " '*'~'~':'~'~'~''" ° ~ ' '~'' ' '" "'" '" '~ ' "' :'"'" "'., ' ,~ / ~.'~'': :"~ - :,~,i.U. ~. :'* ' ' :: ''''? ":' ' '"'~" "" ~ ' '"' '°'' ~"~"~ ' ' ';:'~" ''''~'~' ":~"'~' .. ':'' . ..' ~,.: :* . ;. ~ .' . .: . . . . ...~... .. . .: . .. , . . ... :. . . ,...:.. ...,~..,.....-~ ~. ..../. ::. ,,:., .. ,..r . ~ ..~.~ . '~'. ~ .,, , .' ~ ' ~ ~' ' ' . ' ' ' '. ' / · '' ' ' " '.'~' '.~ " ' ' '" · "~. ~-": .' . · ' ' '~' ' ' '~ · "'"' · ': ~ .' ~ " Hr.J,T. Crooker Standard Oil Co. of Cali£. Opt. P. O. Box 839 Anchorage, Alaska Dear Mr, Crooker: Please be advised that this Division luts uot received a directional survey ~or Wsll ~. ~0.~, 8e~. 15 electric los ~ diree~ional 8ur- vet for ~11 ~o. t,~~~), Sec. ' 15, ~d veil hts~or7 and elec~r~e los for "S.R.U." 12-27 (6) Sec. 27, T,8 H., a.9 ~'., S~ard B & H, ~anson R~ver ~ o~1 field. t~e would also apprectace receivtu8 a copy of the mud lo&gins survey for Well No. "$.R.U." 3~-10 (l), Sec. 10. Yours eruly, DDB:bb DOHAI~ D. B~UCE Petroleun Geolosis~ ,, REPORT I .. R~CEIVE~ and PLAN , / / SUB.SURFACE SINGLE- SHOT SURVEY STANDARD OIL OF CALIF. IISWANSON RIVER UNIT KENAI, ALASKA B 5 L DIRECTIONAL CO. SURVEY DATA SHEET CALIFORNIA i COURSE ' !D~V,A~ION' ~01 0 87 7~)' 0 07 )8 1 7.5 ?7 1.31 · ~6 1! 31 6 0~/37 ~5 I 31 '4 1' 31 3 I 31 I I 75 1 31 0 87 I 75 o, 87 1 75 I 31 I 75 I 75 I 75 I 75 1 31 I 31 0 ~7 I~NAI COUNTY _._ DRIFT RECTANGULAR COORDINATES DIRECTION NORTH SOUTH EAST P0lh'l' 50* 00' E 0 56 0 67 75° 00' E 0 ~ I 51 800 ~ ' E 0 I 63 3 23 85~ ~' g 0 52 ~ 54 75~ ~ E 0 ~ 5 O1 75° ~' E 1 ~ 6 ~ 15¢ ~* ~ 2 ~ 6 31 70° ~ ~ 2 80 5 ~ 75° ~W 3 14 3 81 70° ~* ~ 2 54 2 17 70° ~' ~ 2 ~ 0 94 ~o ~' ~ 3 70 0 40 40~ ~' E 5 ~ 1 60 S~°~' E 5~ 222 75° ~' E 5-21 3 91 ~ ~' E 4 ~ 5 10 25° ~' E 3 ~ 5 ~ 60~ ~' N 3 93 5 ~ 70° ~' ~ 3 ~ 3 ~ 75° ~' ~ 2 ~ 1 69 700 ~' W 2 ~ 0 ~ 75° ~' W 2 '~~ 75° ~' W ~ 1 10~ ~' ~ , ' 1 JOB N 0 ............. SHE'ET NO _1 of._.4 ..... . . STATE ~ ~ WEST R E MAR g,~'~ I 0 81 165 B ~ L DIRECTIONAL CO. SURVEY DATA SHEET 5TANDA~ OIL OF CALIFORNIA ~NCHO RAGEs A[~S KA .JOB RIVER UNIT #4 KENAI FT TRUE I : COURSE VERTICAL SLE ' DEPTH iDEVIATIONi : 30' 549q Tg' 2 62 30' 5599 69 2 62, 00' 5699 67 1 75; 30' 5799 64 2 62: 30' 5899 61 2 62' -_ DRIFT DIRECTION N 45° 00' E N 55° 00' E N 60° 00' g F.~T N 7.5° CIO' E 30' 45' 15' 15' .7)! 5' 5999 59 6O99 57 6199 55 6299 53 6399 53 6499. 51 6599 48 6699 46 6799 44 6899 41 699q 36 7O99 35 7199 3~ 7299 27 7399 25 7499 22 7599 19 7699 17 77cY~ 12 7099 O4 2. 18 1 75 1 31 1 73 0 44 2 18 2 62 2 18 I 75 2B2 3O5 1 31 262 305 2 18 262 262 305 3 93 N 75° 00' E N 75c 00' g N &5= ~)' E S 85': 00' E S 60:- (X)'E N 30° 00' I~ N 35° 00' W N 15° 00' W N 0Sa 00' W N 25° 00' g N 20° 00' E N 65° 00' E N /300 00' E S 70~ 00' E S 60~ 00' g 30° 00' E 500 00' g 50° 00' E 85° 00' E 50° 00' E NORTH 0 ~Sfi 2 36 3 24 3 24 3 92 COUNTY · RECTANGULAR COORDINATES SOUTH [ EAST 0O6 Z20 ~ I ~ 3 72 ~ 634 ~ 8 d7 4 40 10 97 4 94 12 65 5 06 13 96 4 9O 15 71 4 68 16 09 6 57 15 CIO 8 72 13 49 1082 12 9,) 12 57 .12 76 14 94 13 87 17 87 14 92 18 32 16 Il 18 78 18 69 17 73 21 62 16 64 23 51 14 37 24 82 12 68 26 82 11 47 2t~ 49 11 73 31 53 14 26 34 54 Di~ILg)N DMPANY ~ STATE REMARKS VCEST B fi L DIRECTIONAL CO. SURVEY DATA SHEET JJJ4 FIEI D JC~I~[ -- COUNTY.. STATE ALASKA jDJVlA[IONi DI~JCTION I ' - J J NORTH SOUTH [AS[ WEST 2 ~ N ~ ~' E 18'~ ' 39 16 95~ 92' , 79 74 52 ?7 .9 ,6 .1 6 3 3 4 . 2~?. 2 18 3 49 2,62 1~ 75 3O5 436 4 80 436 436 3-'05 306 2,62 ! 262 0 87 305 305' 3 93, I 3 93~ 3 931 3 93j 262 , i . S 80° 00' I::. S 70o 00' ii/ N 75° 00' Iii' N 85° O0'g N 85° 00' I~ N 15° 00'# °N 35° 00' E N 40° 00' E N 55° O0~ £ N 55° O0' g N 15° 00' # N 25° 00' W N 80° O0 F. AST FAST N 70° 00' N 65° O0~ E N 500 00' E N 80° O0o E; N 45° 00' E N 55° 00' E 17 59 16 85 17 76 17 98 18 14 21 O9 24 66 28 O0 3O 50 33OO 36'04 3899 41 36 43 89 44 O4 45 39 47 05 49 58 52 99 55 77 57 28 i DRILO~N 41 74 39 69 3632 33 71 31 96 31 17 33 67 36 47 40 O4 43 61 43 ~7 43OO 41 97 41 29 42 15 45 20 48 25 51 94 55 50 58 51 60 48 63 26 65 41 I JOE3 NO $-~;~'T ~,~o __ 3_ Of 4 ...... REMARKS I · , B 5 L DIRECTIONAL CO. SURVEY DATA SHEET w.r-_,. ,._ .SWANSON _RIVER UNIT MEASUREC DEPTH io,5ooioo .... 10)600 10,700 lo, o m 10)900 11,100 ~0 11)200 ' 11,300 ,DO 11,400 ~0 11~500 O0 11,600 03 11,700 O0 11,900 O0 12)000 O0 12~100 O0 12,:*00 12)300 O0 12,400 ~ 12~500 O0 I'Z) $'~Z DRIFT ANGLE O1° 30' O1o 30' 01° 15' Ol° 45' Ol° 30' Ol° 30' 020 15' 02° 30* 02° 45' 02° 30° 012° 30' 02° 1,5 ' 03° 15' 03° 45' 03~ 15' 02o ~.~e 03° 15 ' O0° 15' 02° 15' 03° 45' 04~ 30' ~4o r,o' 10)697 55 10)797. 50 10~097 47 10,997 44 lI~09T 36 11)197' 26 11~297' 14 11 )397- 04 11)496. 94 11~596 06 11,696 70 11)796 49 11,896. 33 11,996, 31 12,0%, 15 11!,195-99 12)295 91 12 ~3~ 70 12 )495 37 VERTICAL I DEPTH {DEVIATION{ ' ! 10,597' 57 2 62 2 305 · 2i 62 3' 93 4~ 4'~ 3 93 5 67 6 54 5 67 4 80 5 67 5 67 3 93 6 54 7~ } { KE,'VAI ADDRESS. _ANCHORAGE, ALAS~ COUNTY . _. STATE DRIFT DIRECTION s5o 50'. .... 65° 00' E 65° 00' E 60° 00' E 15° 00' W 20° 00' E 40~ iX)' E 55° 00' E 500 00' E S 45o 00' E S 45° 00' S 45° 00' S 55° 00' 560000 S 650 00' E S 75° 00' S 70° 00' S 65° 00' S 60000' $ ~LSo 00' E lm w .,r. I - ~ RECTANGULAR COORDINATES _._ NORTH 58 !7,9- 57 68 56 75 55 22 53 71 51 10 47 49 44 15 41 40 ..... 38 60 35 52 32 74 28 '73 24 90 22 '14 20 11 1865 16 71 15 11 78 11 10 (o ~4 IlI ! } SOUTH EAST ............. -r- .......... .... 60 93 i 71 9O 74 .54 76 69 76 77 80 84 87 o] .36 16 10 90 52 93 3O 97 31 102 b6 107 57 111 117 122 126 131 139 I ,41 '74 30 97 79 ~oe ao ..................... $~£E::T ~o _..4_Of..4 ..... WEST REMAR'~'~. 7 8 10 11 12 13 14 15 16 17 18 19 2O 21 22 23 B ~ L DIRECTIONAL CO. SURVEY DATA SHEET 0IL OF CALIFORNIA -- MEASUREC I DEPTH I I 3100 O0 37OO 00 3759 00 3774 00 3794.00 3909'00 4033 O0 4158~00 4405 O0 4519 00 4633'00 4766 00 4887OO 5014 O0 , 5103 O0 5136 o0 5262.00 5452.~00 ~,'~,._~ .... .S#~.SPN_ .~_zV_~ UNIT 1 ! TRUE DRIFT fIELD .. ANGLE I VERTICAL DEPTH GOo GOe 000 30' 00o 30' Ol° (30' (300 45" 00o ~t 000 30' 00o 45' 00o 00' 03°. 15' 030 45e 06° 00' 01'o 15' 08° 15' 10o O0~ 12° 00" Il° 45' 12° 00' 13° 15" 14° 00' 14° 00' 14° 15" 14 ° 15' ! 16 ° 30" i 15 ° 4~ ' I COURSE IDEVIATION I 3100 -00 0 87 3299'98 1 75 3399 ;97 ! 3! 3499 96 3599 :% 3699 95 3758.95 3T73 ;93 i 3T93 189 3908 26 4031,27 4154 '98 4397 142 4620 53 4749:99 4867 40 4900 63 5O'/6.89 ~106 .~7 5229 '68 5412 56 ADDRESS ........... COUNTY. _ DRIFT DIRECTION CAL. AZ' THIS POZN' S 500 000 N 75° 00' $ 80000, N 85° 00' E 1 !31 S 75° 00' 0 187 S 75° 00~ I :31 ! S 15~ 00~ 0,85 ~ N 79~ 00' E; I 31 12:02 15:65 17 ~4 22 -05 24 '95 23 21 23 70 30 48 29 27 3072 21 91 o 12 35 78. 51 57 N 83o 00' E N 82o 00' E N 82° 00' E N 83o 00' E N 89° 00' E 89000 N 84° 00' E N 87o 00' E 87° 00' FAST N 8qo 00' E N 81° 00' N 78° 00" N 79° 00' NORTH 1:81 4OO 4' 39 483 7 '26 8 5O 10'09- 11 11 11 11 11 49 12 76 20 20 30~04 JOB NO SHEET NO __.{_ .Of 3 STATE RECTANGULAR COORDINATES SOUTH 0 ;00 0 56 033 0 63 0 52 0-86 IO9 236 2 ~36 2 ;20 2O4 0 3? EAST 0;00 0 6? 1.51 3 23 4 54 5 81 665 6 31 6 31 7 14 8'44 20' 34 3584 53 65 75 70 10O65 123'73 147 40 177 84 207 09 237 81 259 72 267 74 302 74 353, 36 ~ WEST R E MA R I(-~,~ W.S. No. I #.S. Ne. 2 26 27 28 29 30 31 '3~ 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 4~ 49 50 B 5 L DIRECTIONAL CO. SURVEY DATA SHEET COMPANy _ _._STANDARD 0Il. 0i CALI~IA [ W~'..L SIll .AN~)__N_R.!VER UNIT 4-A MEASURED DEPTH 5601J 00 6oegt oo 6152; O0 fi,275, 00 6~12:O0 64341 O0 6528~ O0 6558~ O0 67701 O0 6901 O0 7O901 00 7154 00 7197 OO 7344 O0 7404 O0 7626- 00 7787 O0 7926 00 ADDR£$5 _. 8100 00 8190 00 8556 00. 8719 00~ . I FIELD .... [~'~i~Z COUNTY. ~ VERTICAL ANGLE i DEPTH DEVIATIONI ].60 is' 60 1 14° 30' j 5812f 15i 66 36 15° 00' ~ 5969 59 DRIFT DIRECTION N 81° 00' E; N (~3o 00" E N 00o 00' E 16° 45'1 6087 37 35 45 18° 00' ! 6204 36 38 01 18° 19° 45* 20° 00' 19° 15' 200 130 * 20° 30~ 22° 220 15' 22° 30' 23° 45 * 24° 30* 24° 15 ' 25° 30' 24° 00' 24° 00' 25° 15' 22° 45' 220 22° 00~ 22° 15' 6239 40 11109 6354 23 41 22 6442 56 32 15 6470 88 9 O9 6568 61; 35 57 · 6669- 77 ~ 37 '82 ~ 49 07 6791 23i 6966 15{ 71 66 7025 28 24 49 7064 64 17 32 7198 41 7253.12 7453 50 7600 58 7727 56 7884 94 7967 94 0105 84 8307 04 8457 90 60 96 24 64 95 57 65 48 56 53 74 23 34 80 56 41 81 29 61 71 $ 88o 00' E S 86o O6' E N 88o 00° E N 88° 00' EAST N 84° 00* N 84o 00" E N B4o 00' E N BSo 00' E N 88o 00' E N 83° 00' E N 80° 00' E N 79° O0' E N 79° 00' g N 79° O0' E N 81° 00' g N 81° 00' E N 82° 00* E N 83° 00' E N 88° 00' E S 89° 00' g $ 89° 00' g RECTANGULAR COORDINATES NORTH ~61 56 46 12 44 88 42 23 4264 44 O6 44 0O 45 11 48 83 52 78 57 06 59 56 62 54 65 55 77 08 81 78 100 02 110 27 119 11 129 44 133 68 135 64 134 22 133. 15 SOUTH · DaILy.. 1~ C EAST 46O 40 , 50~ 55 537 98 575 90 587 78 628' 98 661 13 670 97 7O6 34 743 95 792 83 965 56 909 75 1063 56 1148 23 1204 O6 1277 57 1312 11 1368 49 1449 77 1511 47 , WEST I W.S. Nco 3 No. 4 W.S. No. 5 #. S. ho.'"' -. COMPANY v,';,' SWANSON RIVER UNIT i MEASUREC i DRIFT TRUE ' J VERTICAL i DEPTH ' ANGLE i DEPTH t ....... . ....... . .... 3o' 52 I 8901 i O0 ' 22° 00' 8700 '26 53 9141'00 i 21 ° 45' 8840 87 ' 54 91FJ~S 00. 22° O0° 8090 59 55 9378 O0 ' 23° 15' 9067 O0 56 ~ 9596 O0 21'"'30* 9260 8.3 57 j 9740-O0 22° 15' 9403 10 58 ! .9910 O0 21" 1,5' 9561 54 -59 i 10~229 O0 20'~ 30' 9860 35 bO [ 10~522 O0 22° 00' 10~132.02 I 61 10~706 O0 19° 00' 10~.305 99. 62 i 10~799 O0 19° 30' 10~394 60 63 : 10~977 O0I 22° 15' i0~559 34 64 ~ ~265 i 19° 30' 10~830 81 B ~ L DIRECTIONAL CO. SURVEY DATA SHEET STANDARD 0IL OF CALIFORNIA ................... ADDRESS F IE_l D - ~ COURSE DRIFT DEVIATION DIEECTION 6g-"O~ '* .... -$---~'~0-00, g ..... 34 ,16 S 96° O0* g 59 29 S 83° 00' g 16 86 S 832 00' E 75 79 S 01° tX)' E ANCHORAGE: ~ ALASKA COUNTY .. RECTANGULAR COORDINATES _ . NORTH SOUTH EAST 130188 .... 1576"49 128 48 1610' 87 121 26 ' 1669 72 119 21 1686 45 107 36 1761 31 94 86 03 52 74 95 79 '90 54 52 61 61 S 81° 00' g S 78'~ 00' E S ~d.° 00' E 111 71' 109 76 59 91 31 38 67 39 96 14 S 03° 00' E S 78° 00' g S 81° 00' g S 79° 00' E S 79° 00' E S 79° 00' E 61 33 3851 29 14 23 15 10 3O 1840 23 1(t93 56 1954 57 2065 44 2172 79 226T ?6 2328 91 2423 29 and drille to 11~460 DRILF.~N '~Pj~,N~r ' , CJDSURi~I 2423.90 S 89° 49' E NOTE:- Originsl r~drilled hole pl.~ed ..d W.S. ~t ~ 10~978' faee~ 120° No sur, eys~ taken after sidetr~ckigg. . ' : . ; : i ~ I JOB NO SHEET NC) . 3 of 3 5TAT£ AL~ REMARKS WEST COD~LETION REPORT - EEW WELL S~J~DARD OIL COMP.~ OF CALIFOF~KA - OPERATOR 2~ELD: Ke .~._ Peni~ula, Cook Imlet Area LAND OFFICE: Amchorage,, Lease No. 028077 LOCATION: 5130' South, ~679..1.'. West, of F.~ cqrner Section !O (S~Arfac. e ) j,,,%-7~F,%L~% *Direction Coordinates: ~ 11., 262' TVD 10,.830' N O' E 2420' TD I1,~60' T~ 11,,020' N O' E 2460' *T~rD & coor~Linates ~gpro'z~tmate. DA~:., September 25, 1~.~9 DATE COI.~2~ED DRIr.TJNG: DATE COMPLETED DRILkI~G: SUMMARY ~ DEI'~: 1,1,~60' JU~: Fish 1 1 1 1 Sidetracked in original hole: - d_~iltrols - momel collar - 7-~/~" ~All collars - crossover sub - 10~" ~ashover shoe ~ts. 9" was~i~e (z71.8~') PLU~,: Orig. hole: 10,978-11,168' 11,175-11, 316' R/D hole: 11, 301-11, 3~O' 11, 425-11, 4%9' CASING: 13-3/8" cemented ~ 2~.67' i i 122~ co~d~ctor Pipe .g ~'. '" OCT Oil & Gas Section Division o~ Mines 'and Minerals Alaska Dept. of Natural Resoure~ Operator: STANDARD OIL COMPANY OF CALIFORNIA Well: Swanson River Unit #' 14-15 Completion Date;Mlly 95~ 1959 Release Date: Aug. 2g.- 1961 , The Files contain the following material: 1. Permit to drill and location plat ........... 2. Reports of operations and sundry notices ....... 3. Well history ....... . ............... 4 Completion report . · · · · · · · · · · · · · · · · · · · · 5. Directional survey ..................... Induction and sepia 6. Electrical log, ........... 7. Lithology or mud log and sepia . . .... . .... . . 8. Other log Remedial werk Remedial work Office File 10. 11. 12. 13. 14. 15. Release File Remarks: COMPLETION REPORT SWANSON ~ZW~ ~mT 14-15 (4-A) ._Section .15~ .T. 8 N.~ R..9 W.., Sewa _rd_ B~ STA~D~_~D OIL CO. OF 0AIXF. - GPE~TOR WORK DONE Well dir~ctio~ally drilled from 34-16 (~4) location (abaudoned-dry hole). Same top hole in both wells. Staudiug cemented. Located top cemeut plug @ ~729'. Cleaned out cemeut to 3759'. Conditiomed hole. Ran in with B~L double set removable whipstock with 7-5/8" Bit, 15 foot mouel pup Joint. Set whipstock faced N 74° E. Drilled 15' off whipstock to 3774'. Su~ey g-. ~774' in~licated vertical deviation of 3°15' N 79° E. ~,_!!ed whipstock. R~u 10-5/8" Security hole opener. Opeued hole to ~77~'. ~ole ~ssumed vertical to 3000'° Origi_~_] hole coordiuates ~ ~700' 2.35' S, 6. Bl' E from surface location. 375.9 ' - 3774' 15 ' drilled Drille~ 10-5/8" hole 577~'-4096'. 377~' - 4096' ~22' drilled 80 per mud 3794' 3~°~5' N83°_ E 3~09' 6~ N 82° E' 4033' 7°15' N 82° E, T~D 4031.33', 1.82' 35.83' E March 31 - April 1, ' ,m ' -'~. ,mm mmm~ . m. mm ~mm ...~mm. ~lle~ 10-5/8" hole ~' ~70'. 4096' - 4470' ~74' drilled 80 pcf mud A~ri.1 A 2~' 1959 ' Drille~ 10-5/8" hole ~470'-5014' 4470 ' - 501~' 544' drilled 8(~t pcf mud h.766, 13°15' k887' 14° 501~' zk° 5103' 1~o15 ' N~°E I~e E N 89° E, ~ ~076.95', ll.~' N, ~59.08' E r.' Page 3. 501~' - 530~' 290' drilled 80 pcf mud Set whipstock No. 2 ~ 5103', faced N 15° W. Surveys: 5136' 14°15' 5265' 16o30' N 81° E N 78° E, TVD 5229.74', 20.19' N, 302.10' E April ~, 1959 or~ed ~o-5/8" ~ole 5 3o4' -5786' 5 304' - 5786' ~82' drilled 81 pcf mad ~ 81~ E, T~D 5~5~.65', 36.5~' ~, 393.90! E AD~! f, !9~9 Drilled 10-5/8" hole 5786'-6152' 5786' ' - 6152' 366' ~.rilled 83~ pcf mua 6152' 160~5' 6275' 18° s 88°s, ~ro 6087.~', ~.87' ~, 537.3~' E s 86° E, TVD 620k. %0 ' , ~2.22' E, 575 · 27' E April 6, 19~9 . Drilled 10-5/8" hole 6152'-6310' 6152' - 6310' 158' drilled 83 pcf mud Set whipstock No. 3 @ 6275' , faced 18°, S 86° E A~ril 7, 1959 - ~mm mm m mm mmm m mmm~mmm ~m mmmwemmm m mR ~mmm e e m~mm ~ m mm m mm, m ,m mm em, em, m mm 4em m mm emm m memm mm mm m m m mm ,m mm m 4mm emm, mm m m mmm mm mm mmem Drilled 10-5/8" hole 6310'-6538' 6~10' - 65~8' 228' drilled 83 pcf mad , , 88° Surveys: 63/2 18045 N 88° E 61~34.' 19~°~' ' N E 6~28' 20~ ~e E Set whipstock No. b @ 6528' faced N 20° W, PAGE Dr~n.e~ Z0-.~/8" ~Ze 6,S38' 6538' S~rveys: - 6770' 232' da~Illed 6558' z9,~°15'. ~ 8~° E 6662' 20~ N 84° E 677o' ~o°zo' ~ 84° m, ~ ~69.8~, ~ed 10-5/8" hole 6~0'-69~' 6~0 ' - 69~' 170 ' ~lled ~y: 6~1' 22°N 85° E, ~ 67R1', 57' N, 79~' E , 52.79 N, 7h-3.98' E 82-8~- pcf mud Imm ~ m m mlm m mlm m,/ml, ,Ill m # ~lli) II ill i/ Il Jill II mll m mm m mm mm ~1 m, m, e ~m imm A~ril ~, lyF2 ..................... D~e4 1o*}/8" ~ie T136'-T~3' 7136' - 7~3' l~' ~ll~ 83 pcf ~t ~ps~ NO. 6 ~ 7154', face~ N 25° W. 7~0' ~°15' N~° E 715~' 2~' N 83° E 7197' 23045, N~o E Spotted 50 bbls SRU crude. Moved 21 bbls outsid~ ~P, ~ved balamce ~! 3 bblc au hour while working pipe. WOrked pipe up hole appro~!me:tely 3'. Freed pipe after 5 hrs. Drilled 10-5/8" hole 6940'-7090'. 69~0' - 7090' 150' drilled 80 pcf April ll~ 1959 Drilled 10-5/8" hole 7090'-7136' 7090'- ~i~6'O 46' drilled 80 pcf mud Set whipstock No. 5 ~ 7090' , faced N 20° W. While pulliug from 6940 ~P stu~k ~ 6925'. ~?potted 50 bbls diesel, 21 bbls outside E~. Moved ~esel B bbls ~ hour w~le wor~ pipe. ~1 lO, 1959 s~.,~:,Ns0!~ PawzR U~;5T 14-3.5 Section 15~, T. 8 i~'z H. 9 W., Se~rd ST^NDA..qD OIL CO. OF CALIF~)R~I[;., OPERATOR Pa~e 5. ~1 13, 1959 ......................................... Drilled 10-5/8" hole 7_093'-7570' 7293' - 7570' 276' drilled Surveys: 7344' 24°30' 7570' no good N79° E, TVD 7!98 ~' . , 77.1~' N, 965.38' E A~riZ 14, ~959 Drilled 10-5/8" hole 7570'-7686' 7570' - 7686' 116' drilled 8~ pcf mt~d Pulling from total depth, 7686', to make connection, pipe stuck , 7680'. Spotted 50 bbls SRU crude, pipe loose after 2 hrs. 15 rains. Surveys: 7~Ok' 2~O15' 7626' 25°30' N 79° E, TVD 74~3.50', 100.12' N, 1083.~6' E - 7787' 101' drilled 8~-86 ,pcf mud 7787' 2~°~ 81° E, ~,D 7600.58', LtO.37' ~, L~%8.a3' E 7787' - 8100' 313' drilled 92-95 pcf mud Dri ileal 9" hole 8100' -8190' 8100' - 8190' 90' d_~illed 92-95 pcf mad Surveys: 8100 25°15' 819o ~%5' N 82° E N 83° E, TVD 7967.9%', 133.78' N, 1312.11' E Drilled 10-5/8" hole 8190-8257' 8190' - 8257' 67' drilled 94-95 pef mud Rem electric log 8190'-3500" P~ge 6. Drilled 10-5/8" hole 8257'-8340' 8257' - 83~0' 83' drilled 93 pcf mud DrilLed 9" hole 83)+o' - 8~o3' 63' drilled 93 pcf mud Circulated , 8403' to cv~!u~te gas show 8273'-8300' in SRU 34-16 (~/%). On basis of redrill hole and lira&ted ~gas show, did not test. Drilled 10-5/8" hole 8403'-8694' 8403' - 869%' 291' drilled 95 pcf Drilled 10-5/8" hole 8694' - 8889.' 86~4 '- 8889' iO~.. ' drilled ~-"',.~.~.~: '~,-~. p cf mud Surveys: :, 8719' 22°~15' S 89° E.,'t~WI)8~57.90', 133.2M N, 1511. k7' E 8889, 22~3o, s 8~° w., ~vo 861~.~6,, 131.o~, ~, 1~75.~9' E. 8889' - .cO36' 1%7' drilled 95 pcf mud Sur~e~: 8981' ~o S 86° ~, T~D 87~0.~6', 1R8.63' ~, 1609.87' ~ A~r~_! 23, 19~9 Drilled 10-5/8" 'hole 9036' - 9186' 150' drilled 95 pcf 9141 21%5' S 83° E 9186' 22° S 83° E, TVD 8890.59', 1!9o34' N, 1686.~5' E COMPLETION F~PORT SWANSON RIVER U~T !%- 15 (~-A) se~ion ~.~, ~. ~~ OIL ~0. OF Page ?. Drillea 9186' - 92~8' 9186' - 9248' 62' drilled Pipe stuck ~ 9208' while ~.k~ng connection. loose 10:~5 PM after 12 hrs. 95 pcf m~d Spotted 50 bbls. SRU crude. Pipe A_~ri! 29 to 30, 1959 Drilled 10-5/8" hole 9749'-10,097' 97~9' - 10,097' 348' drilled 95 pcf mud May 1 to 6, 1959 9' drilled ' to 10-5/8". 93 pcf mud Set whipstock No. 7 ~. 9740', 10~O97' - 11,006' 909' drilled 96 pcf mud Surveys: 10,522' 22° S 78° E, TVD 10,132,02', 38.60' N, 2172.79' E 10,706' 19° S 81°E, TVD 10,305.99', 29.23' N, 2231.96' E 10,799' 19°30' S 79° E, TVD 10,393.66', 23.30' N, 2262.%3' E Drille~ 10-5/8" hole 10,097'-11,006' 10,977' 22°15' S 79° E, TV]) 10,558.40' ~q fl, , o' ~,/,q ~ ~ %."'"'",i, ~' '' ~''~I~:'' ~ , 10.45' N, 2328.58' E 9248' - 9740' 492' drilled 9%~' pcf mud Surveys: 9~78' 23°1~' s 81° E 9~96' 21o30' s 81° E, ~;D 9269.83', 9~.95' ~, 18~0.23' E April aS,_ 1959 COMPT~..TION 1t~P01t2 Section 15, _T. ~8 N., R..~ W. ~ Seward B&~ STA2EMM~D OIL CO. OF CALIFORNIA, 0~ERA~OR Page 8. Drilled 10-5/8" hole 11,006'-11,085' ll, 006' - 11,085' 79' drilled 95 pcf mud Lost complete returns ~zile drilling ~ il, 085'. Pulled b~ck to 29~J ', attempted to regain circulation with 200 bbls 85 pcf mud. ~ returns. ~11ed out. ~an in open end ~P to 2980', pumped in 100 bbls 85 pcf mud. Ran Schlumberger temp- erature survey, indicated loss zone 3~0'-3~'. ~,n open end ~P to 3B20'. Placed ~60 sax construction cement with 2~ calcium chloride ~ that point. L~t =ant stand ~ ~rs. ~m 10-5/8" bit. Circulated out soft cement to ~068'. ~an ~P to ~B86'. Drilled out firm cement ~406' -~7~9'. Between 3759' -~769' in- dications bit m~king new hole. Survey ~ 3769' ~/~ . Ran whipstock, faced N 79° E. Drilled off whipstock to 3787'. ~ !0, 19~9 ,mm ,mm ,mini, em~m em, ,mm, ~ mm~ m~, ,mm,. m, ~m, m, em, ~ em, em. ~m ,mm mime, em, em, ,m ~,mm ,m .mm ,mm, m~ m m ~'- mmmm mm m m m ~mm m mm m mmmmm mmm mm m m mmmm mm mmmm m mm m m ,mmm m m m~m* m m m m Pulled ~B_tpstock. Ran 7-5/8" bit. Drilled 3787'-3805' at which .~int pulled out and opened 7-5/8" hole to 10-5/8" to 3805'. Survey @ 3804' 3 30', S 77° E. Pulled out, ran in with whipstock, 7-5/8" bit'faced N 40° E. Drilled off whip- stock to 3813'. Pulled out, opened hole to 9" to 383~'. At 38~+' pulled 9" ran in w/10-5/8" bit. Drilled ahead to ~46'. Cuttings and drill rate indicate crossed red, ill hole between 3875'-~885'. Drill rate, 800-~O0 ~t/hr, cuttings indicated up to 90~ cement through this interval. Surveys: 386h.' ' 76~E" 3892' N 7k~E 3787' - 3846' 59' drilled 80 pcf m~d ~ il, 1959 ~mm, .l$ e,,, mm mil .m. lmm. emm mm, mmm, emm ~. . m ,m. ,mm, .,1.. mm, mm,.. ,mmmm imm, mm, mm . m ~, mm. ,,mm, ~m, ~ ,mm. m mmmm m · m~mm mm m mm m mm.mmm mmm m m m mm mm m m ,mm~ mmm m mmmmmm mm Drilled lO-5/8" hole ~8~6'-~o~,. P~ued out, ran whipstock,7-5/8" ~it, faced S 40° W. Drilled 3' off whipstock to 3907'. Pulled out, ran 9" bit. Drilled B~K)7'-3951'. At 3<)18' cuttings indicatefl 90~ ce~nt ~ appar~ntl7 back in redrill hole. Drilled out cement to 3951'. ~ 12, 19~9 ................... Z;,';;'&H ~. mmmmmmm mm mmmm ,m mmmmm~mmmmmm mmmmmmm mmmm mm m m ~lled out ce~nt to 3~5' at ~ point bit ~ped ~e ~ ~ ~21'~ ci~ted ~ co~ttoned ~d from ~ ~cf to ~ef. ~ or ~n of fled. Ci~ted ~d co~tioned md in s~s ~ ~0', ~' T~', ~00', lO~ 800' ~d ll~ 085' · Co~tioned md ~ ~ lozt cir~tio~ m~~ eons~~ o~ ~be~x ~ ~ea~x. ~ e~~~on ~ ~Og5~. ~n 10-5/8" hole op~_ner thru interval 3700'-4100'. ~ull circulation. Ran 10-5/8" bit to 11,085', broke circulation ~ 6000', 8000' , 10,000' . Only 5C~ returns while ciraulating @ 11,085 '. Rem ope~ e~d E~ a~d equalized 80 sax comstruction cement @ ll, 081'. Partial returns. Pulled to 10,500', could not circulate. Pulled to 3000', circulated with ~ returns Circulated m ~ s~s ~ 6~ , ~,1~ ~ ~ $ 1959 ¢irculate~ an~ cond/tione~ mu~ to 10,531' thru open emi ~P. ~an 10-5/8" bit to 4000' at which time ~Ad dropped in --,~us. Pulled 10,~/8" bit. Ran S-~l,,m~er~er temperature survey, stopped @ 8~8'. Pumped 180 bbls mud in annulus. Reran Schlumberger tempera~ survey, stopped ,% 6700'. Results indieate~ loss below 6700'. ~ 9" bit in sta~es to 10,967'. Broke circulation ~ 3052', 5350', 7~O0', 9157', 10,097'. Full circulation at all depths. Checked cement plug ~ 10,~67'. Drille~ mud with fiber, micatex an~ Sel flake, lost circulation material to 5% by volume. .!7, 1959 ~ 10-~/0" bit ~ ~ctto~ s~bi~zation 'in s~s ~ ~7'. ~ circ. ~ eo~tio~d~~ ~', 57~', ~' 7100' 8~0' 9050' ~1 ~tu~ at ~ ~t~. ~d cont~ 5% lost cir~atiom ~~ eo~isti~ of flor, ~ea~x ~ Jel f~e. ~an to top of cement plug e 10,967'. Drilled out cement plug 10,967'-11,085'. Drilled 10-~/8" hole 11, 085 ' -11,106 ' . L1,085' - 11,106' 21' drilled 91-93 pcf mud 11,106' - 11,26~' 159' drilled 92-93 pef mud 1959 Co~d ~,~5'-~,~9}' w/8-7/8" Chasten ~nd co~d. P~ge i0. · l.{ay 21~_ lO~O~ cont' d. 11, e65, - 11, e77' 277' . 11,F],8, 11,~'8, - 11,281' 11,281' - 11,282' 11,282' - 11,282~' 11, 282~ ' - 11,284' 11,28b' - 11,292' II, 2p2' - 11,293' 11,293' .- 11,295' 11,295' . 11, 296' ~1, e96. - ~, ~e.~., 11, 33-2' . ll, ~l.~" 12' greenish gray siltstone 1' oil stained silty sa~d, firm lime ~-~i~d gray oi! s-~ud, light b~ oil s~i~ 3' oil s~, ~d. ~ i~ ~m~, silty, f~_able, ~ceo~, b~ oil s~d, ~od pet~le~ o~r, ~l~ fluo~scen~, eve~ satu~tioa. l' g~e~sh ~, s~, silts~ -'~-~' silty, oil s~ined s~d . ' sllts~ 8' oil s~, ~d. ~~d, e~n satu~tion i' silts~, ~c~us, ~o~c~us 2' oil s~d, med. $~d l' siltsto~ 1~-' oil $~ ~ to 7' pebb~ oil s~ ~~ ~,s into co~o~~ in ~t~m 3'. ~th oil ~ ~d pebb~ ~ e~y ~~d, good o~r, ~l~n fluo~scen~. mm mmmm "' mmi mm mmmmm m~mmmmmmm mmm m mm, Mm m # mm, ! mw mm m m m mm ~m,mm. mm mmm,m mmm# mmm m, mm mmm~m, mm, mmmmm.mmmmmmmmmm, m,mm,mmm Cored 3_1, 31~.}" - 11, 32-~}-' with 8-5/8" 'Christensen Diamomi Con--head. ~u lo-~/8" ~it, opeaea hole from 8-7/8" to 10-5/8". Drilled one foot' ~lth 10-5/8" .Core ~'3, 11,32~' - n, 348', rec. 23' conglomerate sandstone with oil saturatio~ ~; ~m~y a~,, 1959 ,m.m em, ,m, ,m m mm mm ~ mm.mm.m ~m, m~,m~ .m~,m~ ~,m,~m m.~m .mm ,m mm Ra~ 10-5/_8" bit with directional drilling assembly a~l reamer. Reamed interrals 554o'-5565' ~ 792e'-Sz08'. O~e~ea hoZe from 8-7/$" to zo-5/8" from 11,348'- 1.1.,311-9'. ¢i~te~ hole cle~u. PulJ.e~ bit. Tit~t hole 826~'-7636'. Oore ~4, ll, 349'-11, 35b', rec. 3' conglomerate saz~ls~ with oil satlAratiom rumui~g lO~. Oore bit badly grooved. CO,~PZETION EEPORT s msoa tmrr Page 11. Ran 10-5/8" bit ~,lth directional drilling assembly. Pipe stuck ~ 11, 322' while attempting to clean out to top of 8-7/8" hole ~ 11, 34~'. Spottea 30 bbls SRU crude @ bit. Worked pipe 6 hrs. U~able to free. Circulated SRU crude out of hole. ~r~ ~~r; shot pipe ~ ~ of ~~. T~ of ~sh ~,170'. ~sh co~- sis~d of 166.47' w/10-5/8" bit~ ~lt~l, 7-B/~" ~1 ~ co,r, ~lt~l, ~-" --- ~4" '~ ' 'f ~/ ~ ~~, ~lt~l ~ c~sso~r sub. ~co~d ~ in ~ 10-5/8" bit ~ co~tio~ hole. ~er ~bz ~ ~ ~ ~1~. ~k ~ld of ~sh lo~ 1~,~. ~t Ja~ lo~ ~,~. Ja~~ ~d ~ ~ect on fish. mmmeemm mm m m mm mm#mmm m m m m memmmmemm, mmm m memm me m m m-em mm memm m m mm mm mmemm mm mere mm mm m mae emmmm memm l~shed o~r fish l~om 11,20b'-1_l, ~2'. Wash pipe bec~ stuck ~ 2:30 PM. Jarred - ~ - m , em~m mem mm mm m m mmmmmme em mmm mmm mmm memmmmm mmm mmmme mmmmmmm mmmm mm e m m mmmmmmmmmm m emmm mm mmmmm Spotted 50 bbls SRU crude. 20 bbls around fish, 30 bbls in I~. Continued jarring washover pipe while displacing crude @ 2 bbls/hro, no results. Unable to move wash pipe after 12 hrs. continmous jarring. Cemented thru washpipe. Placed 27 sax thru interval 11,~16'-11,175'. Cementing tools and pipe in hole: z - lO-5/8" COMPLETION REPORT sw~o~ ~Dm~ mw z4-z5 (~-A) Sectiom 15z T. 8 N.; R. 9 !q'l Se. ward $~~D OIL CO~'OF CALZOne' O~E~OR 1 - 10~" washover shoe 5 - ~ts. ~" wa~l~e (z?z.~') Found top firm cement plug ~ I0,957'. Cleaned out ce~amt to 10,977'. Circulm~ed $~%el conditioned mad. ,. ,.. , . mm mm mmmmmmm mm mm m mmmmmmmm emmm m mmm mmmmmmmemmemmmemmm ~t w~ps~ ~ 10,978' fa~d ~ 1~° ~. ~~e~ o~ ~psto~ ~m 10,9~' 10,9~'. .. .. ............. ' ............................. ~lled f~ 10,~'-11,~5' ~ 10-5/8" hole ~ ~metlo~ ~1~ asse~ co~isti~ of bit, ~r abo~ bit, 1~' of ~11 ~1~, ~lt~l 10, 9~' - ~,~5' ~5' ~i~ed '" .. D~ed ~,~5' ~ ~,~' in 10-5/8" ~le 11:115 ' - 11, 221' 106' drilled 92 pcf mad 11, 221' - 11, 382' 161' drilled 9~- per mad svz~so~ ~ u~z l~-15 (~-A) Section 15, ~. 8__N_.~ R. 9 w.~ Seward B~,I STA.NZ~ OIL CO. OF CALIFOPJ~U[A, OPERATOR Page 13. J.ume_. 9, .1959 Drilled 10-5/8" hole ll, 38a'-ll,~' 11,382' - 11,460' 78' drilled 92 pcf mud Ram Schlumberger induction electric log 10,990'-11,~50'. Conditioned and circulated mad. Jume lO, 1959 Laid down drill pipe, ran casing. Cez~_uted 7" casing .¢/ 11,~49' ~,ith 600 s~x construction cement. Cement in place 6:20 ~. Star~ed displacing cemen~ 6:30 .$j,I, bumped plug ~? 7:12 AM. Ran ~emper- ature survey, top cement estimated ~ 10,000'. Top i jt . 4o. 35.' ~otal 278 ~ts Above EM 6 Cemented at 1i,4~9-" ' 7" OD, 38~.", N-80, range 3, misc. mfg.- both domestic and E~sh; 8 R LT&C 7" OD, 32~, same as above 7" OD, 29~, " " " 7" OD, a6S, " " " 7" OD, 29~-, " " " ?" " " " 7" OD, 055, " " " 7" OD, 384/~, " " " Includes Baker~"~ifferential fillup collar and Baker differential shoe Casing equipped with centralizers and reciprocating scratchers. m~ mm w~,,m ,m$~m,~m ~m,~m~m m, mm, m mm m m mmm mmm mm m m m m m m mmm mm m e mm m e m mm m m m m m m m m mm mm m mm m m m m m m m m m em m m $ m m m mm Landed 7" casing w/240,000~ hook load (70,000~. in excess of as cemented load). Installed casing, packing and tubing head. Installed and tested BOPE. Picked up 2-7/8" drill pipe with 5-5/8" bit and 7" casing scraper. June 13, 1959 ~m m~m.-~m, emm mmm m mmmmmm m m mmm mmmem mmm~mmm mm m mm m m m mmmm m m m mm m m m m m m m m mm m m m m m a e m m mm m mem m mm m mmm __ mmm Cleaned ~t c~nt ~ 11, ~5' COMPLETION EEPO~ SWANSON RIVER UNIT 14-15 (4-A) Section S~Ah-~ Oxh CO. OF CALIFORNIA, 0~EBATOR Page 14. ~ ~i~~n tes~r for W~ w/~50' ~ter ~s~on. ~t pa~er ~ ~,282'. ~ened tester ~ 3:lB PM ~th f~nt blow 2 ~ns th~ ~/8" ~ ~ ~:2~ PM - ~ blow. ~n~ ~ for ~st pe~od. Closed tester ~:iB ~. ~ed ~s~r, ~c ~' ~~ fled. C~s ~~te test ok. IH IF FF FH Top Recorder 69~5 1~O0 1~00 6970 Bottom Recorder 7010 1360 1360 6900 WNS..o- 11,255' Jet perforated 11,254'-11,255' w/5 shots. Ban F~lliburtoa tester w/2700' water cushion for WSO. Set packer @ 11,188'. Opened tester ~ 3:~0 AM. Weak blow entire test. Closed tester 4:~O AM for 30 rains final shut ia. Net rise 6760'. Top 2100' all water, 53 G/G showing increasing oil stain tou~ur~ Bottom. Circ. -- -, ,=~ ~F~w~ =v.y .~. ~u ~, ~nen wa~er w~n cn~omnity of 1~40 G/G. Last z*/~ u/u cn~orinity. Ran 2-7/8" ~ open end to 11, 3~,~'. Circulated and conditioned mud. Gas b~ilt up I ~' tt It ~etween 7" ~Lnd 3 3/8 ~t~ng ~usLz~ 13-3/8 ~asJ. n~ he~d to leak. Gas bu/lt up ~ ~0 ~sL Ln 3 ~s. ~e~ ~ off e~ 3 hrs. ~ ~bu~n ~ b~ ~1~ ~ 8~9~'. P~ ~ 3et p~o~ ~ shot~ ~ 8~00' ~a ~nt ~/~00 s= co~t~Lon ce~t in ~ e~o~ to ~ gas beton st~s. - mm ~mme mm m ~ ~ mem emmmm mm emmm mem $ m mmmmemm m m m m m m mmmmmm mmmmmmmm mme S~eeze ..5~ ~ ~ ~.2e~s ~ 85~' Jet pe~omted [ shots ~ 85~'. ~ in w/~ll~~a ~ s~ueoze pa~er '~ ~o~ pa~er ~ 8~0'. O~n~ 500 s~ construction e~nt ~ ~ s~t ~les ~ m m ~mm mmm m mm mm mm mmmm ~m mm mt m mm, mm m,m,m mmm m,mm mmm m mm m m mm mmm m,m,m m mmmmmmm mt mm mmmm m, mm m, mm mmmm mmmem ~mm m mm m m mm mm mm Nan temperature survey which indicated top cement 6' 7170'. Gas continued to build up bet~en strings. Page 15. Oune m., 1959 · ml~ ~m .m, elm m, *mm, ,mmm, ,m mmm. ~. ~m, ,mm m ~m, ~mmm ~e. ,mmm. mm ,mm ~m~ ~.emm mm ,m ~m, ,m emma,m. ,mm, ~m. ,m mm. m, m, .~ ~m m, mmm mmmm ,mm. em m, ~m, m, emi m, mm m ,m, m,,m ~mm ,mm ~m ,m mm mm,m ,m mmm,,m,~ mm~ ~m, ,m, mm, mm immm lmm, ~lm ~mml~,mm, ,m ~m, mmm, ,mmm. emm. mm mm,mm Drilled out cement retainer. Located top cement ~ 3455'. Cleaned out cement. Casing would not hold 1500# on a pressure test of shot holes. I~ Halliburton wall scraper thru 3500', conditioned gas cut nmd. Set Na~ !4_burton cement retainer @ 3400 in 2~ casing. Attempted to break down formation with 2500~, held O.K. Drilled out cement retainer. Pressure tested casing to 1750~ - O.K. June 22, 1959 S~ze 1~ s~ ~t..~ Pete ~' 35~'. Ci~~d~d con~tioned ~ ~t ~d ~ ~0' '~ ~2~'. ~s ent~ i~ca~d-c~~ in ~m ohot ~les ~ 3500'. P~ssu~ ~s~d 7" ~si~, ~d ~t ho~ 1~ psi. ~t ~bu~n c~nt ~t~r ~ 3~', ~d ~t ~1~. Set seco~ ~]~_b~n ~t ~t~r ~ ~350', held. S~zed 1~O s~ ~t~ion c~nt t~ shot ~s ~ ~' . , ~. p~ssu~ 2~ psi. m mm, mm mmmmm m em mmmm m m mm mm m m mm mmm, mm mm mm m mm mm ,mmmmm Squeeze 50 sax cern ~ per~s .~ .3500'. Drilled out cement retainer ~ 34~2'. DriLled Out ha~"cem~n~ 3~2'-35'60', Cleaned out to 3600'. Holes @ 3500' would not hold'750psi. Set HO~I~O DC retainer ~ 3~7'. Squeezed holes ~ 3500 w/50 sex cememt w/~ calcium chloride. Final pressure ~250 psi. 27 sax outside perfs. S~~ ~0 s~ ~ ~ pe~s $ 3~'. ~et ~t ~0 ~nt ~t~r ~ 3%37'. cle~ea 'out-t0-36~,, ~ c~' 3%~-3513,. App~ed p~s~ ~ holes ~d ~t hold a~ ~0 psi. ~t HO~ ~ ~~ ~t~r ~ 3435'. S~eezed w/50 s~ coati,ion ~nt (~ c~ci~ ~o~ ad, a).t~ holes ~ 35~'. S~ed ~~ ~nt ~ ~:35 PM, ~s~d sq~ezi~ ~ 1:50 PM. P~ssu~ b~16 ~ 31~ psi. Esti~d ~ s~ ~tsi~ p.e~s. , mm m ~m m mmm mmmm mmmm m m mm mm mmmm mm mmmm mm ,mm m mmmm m m ~mm.mm mmmmm mm m mm,mm mmmmmmm m m mm m. mm,mm, m m m,m mmm Pressure test Perfs @ ~500' O.K. Drilled out HO~I~O DM cement retainer ~ 3435'. Cl~d out to 3~00";~' .... Nard""~nt 3~35' to 3507'. Pressure tested holes @ 3500' w/1500 psi for ~0 rains. - O.K. June_ .1959 m mm ' m m mm 4mm, mmmm m mmmmmmmm mm mm, mmmmmmmmm mmmmm mm mm mm m mm mm mm mm,mmm m mmm i~m~ m mm mmm mm mmmm mm, mmm mm mm mm ,mmm mm, mm mmmm ,mm mm m mm mmmm mm, mm mm squeeze 50 sax c.ement, thru perfs @ $5.OO'~ Ram DST. ~ tester on 2-7/$" I~, all da~ -set packer @ 3~O2". Tool ~~ '~o~ AM. l~int steady blow, dead in 5 mins. Olose~ tool, rel.~ased pacl~r ~ 6:01, J$1. l~c. 210' 93 ~ mad. Chs~q;s ind.icatecl COMPLETION 14-15 (4-A) STANDARD OIL CO. OF CALIFOi~IIA, June _29, 1959 cont' d. Outside Recorder Inside Recorder IH IF FF Ftt 2185 3950 56o 2185 185 160 23.75 Broke down cement w/cement track. Set HOW~O ~$~ cement retainer ~ 3433'. Squeezed in stages w/50 sax construction cement (2~ calcium chloride added) thru holes ~., 3500'. Started squeezing @ 3:20 PM, Finished ~.' ~:~5 PM v/pressure buildup to 3350 psi. Estimated displaced 26 sam cement outside perfs. 3~0=. ~H~O ~s~=~ set ~es~ere ~35~, ~s~r ~e~a 1 ~., f~= blow 3 ~ ~e~d ~ ~ blow ~ ~, ~ad ~~r of test. ~c. 210' ~i~ fled. 0~s i~~ted pl~~, ho~r, ~tsi~ ~co~r sho~ ~ b~ld ~. ~st co~i~d g~d. Omtside 'recoraer Inside recorder IH IF FF FH 2210 370 370 2185 2175 155 155 2175 mm ' mm ' ~-.-- mm mm m mmmmmmm mm m mmmmm mm mmmmmmmm mmmmmmmmmmmmmmmmmm mmmmmemmmmmmmmmmm mm m m,mmmm me mmmmmmmmmmmmmm mmmm m imm m m mmmmm mmm m mm Pre~sure test perfs '6 8500' O.K. Drilled out cement retainer 5.' 8400'. Nar~ cern to ~507'. Cle~'~' out to 8550", circulated amd coaditioaed mad. Pressure tested holes ~., 8500' w/1500 psi, tested O.K. ~.- Be~cer wall scraper to 8550'. Conditio~ed mu~. i mm ! m m m m e m mmm mmmm m ! mmm m m ! m emmlmlmmm#m mm mmmm mlme#mm m mmmm m mmmm mm mmm mm ! mmm emm e mmm mm m Halliburton tester stopped @ 3457'. Pulled ECT and ran bit an~ wall scraper to 8600'. mm, mm. mm ,mmm ,m ~m. am,mm em mm ~mm ,mmm ~mm m m ~ ~ ~ m~ m m m mm mmmme m m memm mmmmmmm mmm mmmmm mmmmmmmmmmmm~ P~s~ ~ attired to~b~ e~test ~.~ ..~, 2~' set ~m ~t~ner ~ ~, 158', ~fo~ti0 ~ W~ s~ts ~ 11,255'. ~d ~t b~ ~ ~ ~00 poi. D~ed out ~ ~~r ~ ~,158'. ~ ~T, ~ble to set pa~er. SWANSON ~WER U~IT 14-15 (4-A) Section 15, T. ~ N.~ R..~ W.~ Seward ~ OIL CO. OF C~~~, ~~R ............ mmsm m mmm mmmm m m ! m mm mm mm m m mm mm Reran ~T, packer, would not set again. ~an IIP. open ended. Circulated and cond- itione~ mind @ ll, ~00'. ~an ~T. Set packer @ 11,078'. Opened tester for 7 mlns Good Blow. Pulled tester. Recovered approx!-~-tely 180' water, 720' drlg. fluid. ~,-mm~mmmmm,~lm,mmmmm,mmmmmm,mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmemm m m, mmmm mm '~ retainer $ 11,158'. ~ormation broke dow~ O 4~°O0 psi. Pumped 2 Bbls of m~ thru perfs @ 11,256'. pu_l:l ed up out of retainer, mixed 80 sex construction eem. ~et ~ im retainer. ~ormation would not take fluid ~ 6000 psi. DO cern retainer @ 11,150'. Circulated a~d co~titioned ~Ad ~ 11,300'. Jet perforated 5 hole.'".. @ mmmm mmmm mmmmmmmmm mmmm mm mmmm mm .m ~m m m m mmm m~mmm mmm ~t. c~ ~ner at ~, ~8'. At~~ ~ bre~ do~ fo~tton ~u~ s~t holes ~t ~,2~5'. ~tion xo~d ~ b~ do~ w/72~ psi. ~ ~m ~ner ~ ~T w/~"~r ~s~on. ~t tes~r ~ ~,2~'. ~e~d 't~l ~ 10~35 ~ B~w inc~i~ ~ ~d blow ~r 15 ~. ~ol ~ed 75 ~. Closed t~l for l~ ~ ~I. ~ s~tt~ out ~se of ~' ~~ ~is~d of 10~' ~t ~le ~ ~ ~' oil ~sion ~ ~t f~m app~x. ~ ~ ~ ~ter w/~o~ty C~s i~ca~d ~ster~ ~e~d o.k. . . · , Inside recorder Omt. si~e recorder ... mmmm m mmmmmmmm mmmmmm mm mm~ ~Tpe~s ~ ~,255'-~0 tim. ~d ~nd. ~d to ~,335'. ~t ~m mt~r ~ ~,'~" '~ ~T'w/~; ~r ~on. ~t pa~er ~ ~,192'. ~e~ tester 3:ltl ~, ~ ~low t~e~i~ ~ f~r ~w ~r 10 ~ for ~~r of ~st. C~sed t~l ~ 5:1~ ~. ~ene~ ~ ~ ~d ~rse ~r~a~d fluid 9ut. Fi~ ~se oi~ ~r w/~~ty of ~0 to ~30 G/G. IH IF FF SI Outside Recorder 6945 n6~ ~60 5~-~ 69~5 Ap~~~ ~0' ~r. squeeze .~l sex eem thru Derfs $11, ~-55' · Bet cam retainer ~ 11~ ~lO'. Broke ~ formati'0~ w/~ psi, squeezed 71 sax of construction cern thru perfs - m · m .m mmm mmmmmm m mmm mmmmmm mmmmm m m m mmm mmmmmmmmmm m mmmmmmmmm mmmm .memmmm m~ mm m m m mm mm mm m mm mmmm Stood cern 10 hrs. Cleaned out to 11,2_10'. Drille~ out cam retainer ~ ll, 210'. Drilled out cern 11,210'-11,276'. Clesmed out to 11,316', top of bridge plug. n, 19 9 emma, ~m~ ~m ~m, em, emma,.ml mm~ ~ ~-~,2~' S~r~r 3et pe~m~a 5 ~s ~,257'-~,2~'. ~ ~T on 2.7/g--~~ pipe w/~' ~r ~on. ~t pa~r ~,195'. ~e~d t~l 2 ~.{ for 1 ~ ~. ~ ~ ~ ~I. Ve~ ~ B~w 1~ ~ t~ ~ ~~r. Re~~d 5' ~t ~se, ~~ ~d. C~o~ty 50 O/O at ~ols. C~s O.K. Inside reeor~er IH IF F~ FH FSI 698~ 11~] 11~] 6985 1785 Drille~ out bridge plug @ 11, 316'. July 12, 1959 Pe~. i~~ 11, ~'-~, ~' Cle~ out to. 11,~' ~ ~i~ sc~er, sc~~ ~,150'-~,~5'. S~~r~r J~ pe~o~ted ~ ~les per ~. ~,~'- ~!3, 19~9 ' e - e m mmm m mm mmmmm m mm mmmmm mmm mmmmmm mmemmmmm mmmmmm ~T i~~ ~,~'-~,3~'..;...~!~d tes~r ~ tester on 2-~/8" ~ w/~O0' ~~ :~0'n. - ~ ~er ~ '11'~'. ~ ~n i~ti~ shut in, ~ ~. flow. ~~d~ol.to 1/~" ~ 5:~ ~. ~!dblow ~c~as~ ~ ~ in 1 ~. 50 ~. ~r 2 ~. ~ ~ns ~d ~t~m~le ~oke f~ml/W' to 3/8". ~ ~ in blow 1~ ~ f~ s~t in. ~rs~ ~t ~. C~~te less t~ 1~' net ~. Vi~ est~ 5'-15' ~~ ~ ~t ~se ~sti~ 765 G/G. ~1 pipe pe~s pl~~. ~~s in~~ pl~~ of ~1 pipe ~ ~t~ hole ~okes. ~tsi~ ~~r clo~ s~ed. IH FH IF FF ISI FSI Inside recorder pressures: 68b~ 68b~ 136~ 136~ ~610 5610 ..... . .................. 5-5/8" bit. 0irculated ami eon~itioned m~d at 11,4~0'. Ban casing scraper. ~ type C Packer, ~burton jars, DR safety ~oint, TC .valve and 3640' We. Set packer at 11,286' ~ 1:28 AM. Tester opened at 1:30 AM for 90 rain flow test. Closed tester at 3:00 AM. ~ood to strong Blow for entire flow period. Water cushion to surface 35 rains followed by mudd~ water to clear water w/chlorinity averaging 1440 to 1560 G/G NACL. No trace of oil. Charts indicate test conclusive. IH IF FF FSI FH Inside recorder 6930 2915 5400 5665 6900 outside recorder 697O 4615 5335 5765 6945 Page' 19. July ~!~,_ {~W-{~- mdmmm }Nd{ mm m Imm m m m m m m Imm m m m m Imm m S~ze_ ~e~s :,'~ ~,312'-~,3~.' .w/95 sax c~m ~n 5-5/8" bit, ~n~tio~d a ci~. ~d at 11'~i7'. ~t ~bu~on ~i ~ ~~er ~ ~,~9'. $~ezed pe~s ~low ~m ~~r w/9~ s~ co~t~ot~oa ~. Spot~ ~ ~ cern on ~ of ~m ~~r em ~m~m, m *mm, mmm imm ami m m m m ~T 1~~ ~,.~.'-~6' Sc~,m~r~r ~ ~o~d ~~'-~,~6' ~ ~ l' 1/2" ~le ~r foot. ~ ~w/~ C ~k ~~~r, ~ s~ety Joint, HO~O ~ ~ ~' ~ ~ ~' ~r ~on. ~t ~er ~,2~' ~ ~:~ PM for ~ ~n ISI. ~d ~s~r ~ 6 ~ for'f~ test. ~r Blow inc~asl~ to ~o~' ~er 10 ~. ~r ~s~on to su~ 2 ~. ]0 ~, ~te of fl~ 10 to 12 ~H, folded by oil ~ch ~t. ~ fol~s: 11:00 PM 12:00 PM 1:00 A~ 2.:00 hX b:O0 AM 5:00 AM Gravity @ 5:00 A~ 29.3 @ 58 degrees. Shut in well for 30 rain FSI @ 7:05. Estimatea flow rate during last 7 hfs of flow 5 to 7 ~PH. Inside recorder Outside recorder IH ISI 'IF FF FSI FH 7175 561.o 3.970 3520 3555 712o 7055 5b95 '1875 3~00 5~50 7025 367 ~o~t~, ~ o~ ~" ~up jo~, of ~" ~m tub~ w/~berson pro~uction packer, 1 Blank ~t., 1 perf. ~t. of ~aTM E~E tubiag below packer w/Ventur~ shee, @ ll, 250'. Set packer ~. ~,~90' w/12000~. Lauded Insta~e~ Christmas tree. ,mm, m,m m, m~,,m em. m m mm,mm m m mm I,m em m,mmmm emm ,mm, mm mm mm mmm ~m em m, m,mm, m em,mm m m Swabbed. Fluid entry ~ppmx. 2 to ~} ~PH, otl cut appro~,~.tely 2~. Section 15, T. 8 N.~ .R. ~ .W., Se.w~_. BSa~ m, mmm - ' ~mmm m mmm, ,~ ~mm. m,~,m mm m, m. ~m, ,m.. mm ~m,~mm, ,m. ~m.m~ ,m ~m, m ,mm, ,m mm, ,mm ~m, ,mm mm, mm mmmmmm mm m m, .m m,m m-~m. m mm,mm m.mm m mmm m mm m, mm.m m. mmm m m, m mm,mmmmm mm Swabbe~ ~ 2700'. Fluid entry ~ ~H, oil cut 2~. Intermittenly swabbe~ fluid from approx. 1000' to below 5500'. Indicated rate of fluid entry approx. 5 BPH. Fluid oil, ~At 16~ including 8~ mud and 8~ w~ter. m mmm mm m ! mm m ,m m mmmmmmmm mm mm, m, mm. m m m m m-~ m,m m. mm ~m, m m m.m m Swabbed fluid to 69~0'. Stood 4 hrs. ~luid level 1500'. Rate of fluid entry approx. 9 ~N. ~abbed fluid to 3500'. Stood u~til 10:00 A~ at which time fluid surfac~. Flo~ed at e~~~el~:;.~r~",.hundme~ B/D r~te. S~ut in to in~ta~ blow box. Well die~. Resumed sw~bbiu~, swabbed 0~30'. Oravity B2.5 ~ 95 degrees ~0.8 ~ 58'. degrees Cut water, O. 4~ emmlsion ~'"' " water, 1.0~ eunAlsion, trace sediment water, 4.0% emulsioa, 1.1~ sediment rater, 1.0~ emmlsion 11' P~.: 31.8 ~ 6~ degree~ ~~-"~' 19~R/'" ' ": '""' .'" ~be~ at 75~', fled ~1 oil. S~~ ~bbi~ at 3:30 ~ ~il 7:00 ~i, fled ~ ~ 1~'. ~b~ ~ 1575 ~ ~~d ~uid ~se of 7 to 8 ~H ~. ~~.o~ ~~ ~m s ~, 7/~/59 ~~ 3. ~ ~ 7/~/~, ~o ~s. ~~. . fl~~l ~~ 5~0' ~ 3:~ ~. ~~ s~a~d~9:O~ ~. Flo~to ~ ,.,. '"'}")'. ."' ' :4. ". ' ." .... ,. . . .~les:" '''~': ::"~ ....... ' ',: '''~' "~ "~ G~~ "';" '""' . ~ ~ ~ m~ m ~ ~ ~ ~ ~mm~mmm ~ . ~elI shut i~ 1:~0 PM, July 2b, 1959. 7510 751o 76Io ~ut on tem~o~ ~roduction ~.:oo' PM, 9/9/~9. " 12 180 " 5 165 o:~ ~ i~o " 6 175 Corrected ~re.~ averages 3R.8 ~ 60 degrees.
