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Oeth Nolan Hilcorp Alasjkc GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 TTilcurp Almkx,TAX. Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 10/30/18 To: Alaska Oil & Gas Conservation Commission Abby Bell Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 CBL CD1: Elog digital data 05` SCx141B-09 GBL Fnal.pdf LJ SCJ 41B-09 CBL Main Pass AKEAine las SCANNED Nov u h z. u,ta 7/9/2018 12:56 PM Adobe Acrobat Doc... 4,807 KB 7/9/20181259 PM LAS File 2,082 KB Please include current contact information if different from above. RECEIVED OCT 3 12018 AOGCC lo o269 29 93 2 Please acknowledge �ecejpt byAigping andfreturninNne copy of this transmittal or FAX to 907 777.8337 Received By: / j' I I lln L /1/ _ \ I Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑� Suspended E] 20AAC 25.105 20MC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1b. Well Class: Development Q Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6.Date C 'Tip., Susp., or Aban_ 8/31/2018 14. Permit to Drill Number/ Sundry: 100-269/318-266 3. Address: 3800 Centerpcint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: 5/20/1981 15. API Number: 50-133-10129-02-00 4a. Location of Well (Governmental Section): Surface: 710' FNL, 660' FEL, Sec. 9, T7N, R9W, SM Top of Productive Interval: N/A Total Depth: 587' FNL, 599' FEL, Sec. 9, T7N, R9W, SM 8. Date TO Reached: 9/17/1989 16. Well Name and Number: Soldotna Creek Unit (SCU) 41B-09 9. Ref Elevations: KB: 20.42' GL: BF: 17. Field / Pool(s): Swanson River / Hemlock Oil - Tyonek Gas 10. Plug Back Depth MDITVD: O' MD / O' TVD 18. Property Designation: FEDA028997 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 346965.1 y- 2455241.0 Zone- 4 TPI: x- N/A y- N/A Zane- 4 Total Depth: x- 346922.2 y- 2455420.6 Zone- 4 11. Total Depth MD/TVD: 10,928' MD / 10,918' TVD 19. DNR Approval Number: N/A 12. SSSV Depth MD/ VD: N/A 20. Thickness of Permafrost MD/TVD: N/A 5. Directional or Inclination Survey: Yes L (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. 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 GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT FT. TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" Surface 28' Surface 28' DRIVEN To Surface 11-3/4" 47.5 Surface 1,998' Surface 1,998' 15-1/2" 1200 sx T' 23 26 29 Surface 9,923' Surface 9,922' 10-5/8" 1600 sx 5" 18 1,324' 10,926' 1,324' 10,916' 6" 75 sx Class G 24. Open to production or injection? Yes ❑ No 0 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd):q�� N/A -V/A 26171ft'CETtORT• DAT1E' VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDlrVD) 2-7/8" & 2-3/8" 10,488' & 10,487' 10470 10657 10786 MD 10463 10649 10777 TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes No Q Per 20 AAC 25.283 (i)(2) attach electronic and printed information THINTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED rAP 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): 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: Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017 IV—CONTINUED ON PAGE 2 2018 Submit rOR GINIAL on REQS M CJi L401-'�_7z. r3. /9 � 28. CORE DATA Conventional Core(s): Yes ❑ No D 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. N/A 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base 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. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Chad Helgeson Contact Name: Ted Kramer, Operations Engineer Authorized Title: Operations Manager Contact Email: tkramer@hilcoro.com Authorized Contact Phone: 907-777-8420 Signature: Date: 1017d 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 tap and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only SCHEMATIC Swanson River Field SCU 41B-9 Hilmr, AlnAa. LLC API # 50-133-10129-00-00 TD = 10,926'; ETD =10,834' Max hole angle is 100 CASING DETAIL 20" 94 Conduct. Surf. 28' I1-3/4 6/15/05 CIBP, cement to surface 07/11/18 Surf. 1,998- 7" 26-29 N-80 Surf. 2,994' T 23 N-80 2,994' 4,967' 7" 26 N-80 4,967' 6,722' T 29 N-80 6,722' 9,923' 5" 18 N-80 4.276" 9,602' 10,926' Baker SC -IL retrievable gravel pack Packer 9 TUBING DETAIL 2.688" Model S sliding sleeve Abandoned 10,661' 2.688" Seal bore 11 2-7/8" 6.4 L-80 Buttress 2.441" 10,479' 10,488' 2-3/8" 4.7 N-80 1.995" 10,56 10,487' NO Depth ID JEWELRY Item 1 160' 6/15/05 CIBP, cement to surface 07/11/18 2 2,150' 7,395' CIBP w/ 767' of cement @ 1383 07/10/18 3 7,370' 77-3 CIPB w/ 47' of cement @ 7323' 07/09/18 4 10,470' 2.688" Baker 5OA-26 SC -1 Retrievable Packer 5 10,475' 2.992" Baker retrieving extension 6 10,480' 2.313 Baker X -nipple 7 10,488' 2.44" Baker wireline entry guide 8 10,657' 2.688" Baker SC -IL retrievable gravel pack Packer 9 10,660' 2.688" Model S sliding sleeve 10 10,661' 2.688" Seal bore 11 10,678' 2.00" Crossover sub 12 10678' 2.00" 2-3/8" Shear out safety joint (43,000 lbs) 13 10,710' 1.87" Otis X -nipple 14 10,741' 1.95" 2-3/8" x 0.20" gage, screen 10,771' 1.315" 2-3/8" x 1.35" O-ring sub 10,772' 1.95" 2-3/8" x 0.20" gage ,Baker tell tail screen 15 10,785' 2.00" Model S-22 snap latch seal assembly 16 10,786' 2.688" Baker Model -D permanent sump packer Date Zone Top MD PERFORATIONS Top TVD BTM MD BTM TVD Comments 6/15/05 77-3 7,385' 7,384' 7,395' 7,394' 2"HSD PJ 6 SPF 9/15/99 77-3 7,404' 7,403' 7,426' 7,425' 2-1/8" EJ/PJ 6 spf, 0 deg 9-3-95 G-2 10,402' 10,396 10,420' 10,414' Abandoned 6-90 HB -1 10,506' 10,498' 10,520' 10,512' Abandoned 11-90 HB -2 10,539' 10,531' 10,547' 10,539' Abandoned 2-90 HB -8 10,720' 10,711' 10,732' 10,723' Abandoned 9-25-89 HB -8 10,746' 10,737' 10,768' 10,758' Abandoned Fish/Fill Information: A. Abandonment plug tagged with wireline @ 9,358' WLM B. 4-1/8" Mill: top of fish @ 10,518'. C. Cleaned out cement with mill to 10,520' on 8/26/95. Updated by DMA 09-13-18 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Weil Permit Number Start Date End Date SCU 4113-09 50-133-10129-00 100-269 7/3/18 1 8/31/18 Daily Operations: 07/03/2018 -Tuesday Weaver trailers arriving with TK#1 rig items. Pollard SL on location. PTW and JSA. RIH w/ 2-7/8" ok, 1 w/ 1.25" JDS to 5,940'KB, latch bottom GLV, POOH w/valve. RIH w/ 2" JDC to 7,275'KB, latch prong, tubing is fluid packed w/ ^'150# psi, pull prong and see 950# immediately on IA gauge, POOH w/prong. RIH w/ 2.5" GS to same, latch plug. POOH, dragging up to 1000#, hang up @ 3,905'KB, in top of GLM# 2, give one jar lick, set back down in bottom of mandrel, pick back up and have 150# less weight, POOH w/ GS sheared RIH w/same to 3,989'KB, set down on plug, latch and POOH w/plug. RD slickline. Sign -out, turn in permit, depart field. 07/04/2018- Wednesday PTW. JSA. Pull 100 x 100 sheet of pit liner. Unload trailers and set equipment. Vetco Gray Wellhead hand on location. Bleed down IA from 950 psi to zero. Bleed down 200 psi from tubing. Install BPV. Remove wellhead. Nipple up BOPE equipment. Continue to RU. 07/05/2018 - Thursday PTW. Hold safety meeting. Continue to RU KT#1. Call out Weatherford 13-3/8" x 7" xover for casing jacks. 4 pallets of KCL delivered from Baroid. Mix 220 bbls of 9 ppg brine and circulate down tubing and up IA. Lower work platform. Function test BOPE. Shell test BOPE and surface equipment to 3,500 psi. Notified AOGCC for 24 hr. BOPE test witness. 07/06/2018 - Friday PTW. JSA. Review BOPE test procedure. Finish rigging up TK#1. Vetco wellhead hand remove BPV and replace with 2 way check. Dress casing jack slips with 2-7/8" die. Make up slip bowl to top and bottom of casing jacks. Function power tongs. Call State Rep Jim Regg to check on inspector. Mix up 65 bbls of KCL. New IBOP and HCR gate valve arrive on location. State Rep Bob Noble on location. Start BOPE test. Test all rams and valves to 250/3,000 psi for 5 minutes. 24 hr State BOPE test witness notification sent 7/5/18 @ 1530. Accumulator drawn down test completed. Remove 2 way check. Close BOPE blind rams. OA valve closed. Well site secure. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 41B-09 50-133-10129-00 1 100-269 7/3/18 1 8/31/18 Daily Operations: 07/07/2018 -Saturday PTW. Safety meeting. Install 2x 2.375" IBT pup joints 12' long'. Make up to hanger threads. Latch crane and elevators. Back out lock down screws from wellhead. Attempt to pick up with crane to 64,000 lbs. No luck releasing packer with crane. Rig up HAK casing jacks with wellhead x over on top of 7' annular bag. Function test. Redress 1 of 2 slips for 2.375" tubing, install tubing bowls on top of casing bowls. Review calculations with crews. Discuss the abilities of using the casing jacks. 100% tubing yield is 105,600 lbs. Our calculated tubing weight is 46,784 lbs. 30K over to shear is 76,784K. Rounded up to 78,000 lbs. No more than 686 psi on casing jacks. Set casing jack pressure to 600 psi. Slips installed on upper jack assembly. Pick up and stroke casing jacks, set lower slips. Retract jack. Take new bite. PU and heard the packer release land hanger. Pick up 2.375" 0andling equipment. Make up lines to 2.375" tubing. After packer was un set there must have been some trapped gas behind packer. Let tubing bleed down to return tank. Open IA. Still bleeding down. Fire hot oil truck. pump down tubing. 15 bbls pumped before returns caught up from the IA . Total bbls pumped for well circulation 76 Having issues with air slips working. Cleaned and repaired air slips. Start tripping pipe OOH cutting and removing SS control line and banding. 23 joints removed and laid down. Secure well. SDFN. 07/08/2018 -Sunday PTW. Hold safety meeting. Trip 2-7/8" completion out of hole. Lay down GLM's and Baker Packer. 210 joints removed. 07/09/2018 - Monday PTW. Hold safety meeting. Hold safety meeting with pollard E -line. MIRU Pollard E -line. Fire hot oil truck and fill tubing, 12 bbls pumped. Rig up CBL (cement bond log). RIH, log from 7,350' to surface. CBL shows good cement from 7,350'- 2,000' or up to 11-3/4" shoe (cement needs to be at minimum 50' above shop) From 2,000' to surface no indication of bonded cement. OOH with CBL. Standby awaiting Weatherford 7" CIBP to be delivered. CIBP on location. Make up 7" CIBP. RIH with CIBP and log strip. CCL at 7,361'. 9' from CCL to top of CIBP. Set CIBP at 7,370'. Saw 700 Ib weight bobble. Good indication of set. Pick up clean. RIH and tag. CIBP set at 7,370'. POOH to surface. Break down CIBP tools. Make up 4" dump bailer. Mix up cement dump bail kits. 35' of cement in 7" casing requires 3 runs. 1.4 bbls required for 35' of cement in 7" Bailer will hold 20 gallons per run. 3 runs. RIH and dump bail cement from top of CIBP. Cement top (TOC) at 7,335'. POOH to surface. Rig down Pollard E -line. Plan to have E -line back after 12 hrs. 7 am the following morning to pressure test and tag TOC for BLM. 2,000 psi for 30 minutes. Rig baick,P�JESSI. Close Blindramsand secure well. Well site walk around complete. Location secure. SDFN. r� X P� Hilcorp Alaska, LLC Well Operations Summary Well Name Rig AN Number Well Permit Number Start Date End Date SCU 41B-09 50-133-10129-00 1 100-269 7/3/18 8/31/18 Daily Operations: 07/10/2018-Tuesday PTW. Safety meeting. Rig down Hot oil truck from 243-08 and move to SCU 4113-9. PT 7" casing (post CIBP/35' cement dump bail) to 2,000 psi for 30 minutes and chart. RIH tag TOC at 7,323'. Corrected depth. POOH to surface. BLM satisfied with Tag and pressure test. Make up 7" CIBP. RIH Log strip. Place and set WTF 7" CIBP at 2,150'. Pick up and tag CIBP. Confirmed set at 2,150'. POOH to surface. Make up shooting flange and lubricator for casing punch run. 4' tubing punch 6 spf. 2.5' from CCL to top shot. RIH and punch holes in 7" casing from 1,898'-1,902'. Had 11-3/4" x 7" annulus closed to flow lines except 1/4' needle valve. When punches fired OA went fro a vac to a blow. Good indication we have communication between annuli. POOH to surface. Rig back E-line unit. Line up HAK pump truck and come online down 7" casing taking returns up 11-3/4"x7" casing annulus with 9.0 ppg brine, 3.3 bbls/min at 234 psi, returns to surface after 20 bbls pumped. Continue circulating annulus. Pumped annular volume to ensure OA is cleaned up, 135 bbls circulated. Have Vac truck remove fluid from rig pits. HES cementing crew on location. Hold safety meeting. RU. HES having issues with laptop communication to cement acquisition program. Hold pre cement tailgate meeting. Discuss job parameters and deployment methods. Operational change in cement procedure. Confirmed and approved with BLM representative and HAK town engineer. Instead of cementing down the 11-3/4"x7" annuli and taking returns up the 7". We will pump down the 7" with our cement return up the 11-3/4"x 7" annuli. Less displacement fluid gives us less change of having green/contaminated cement. Pressure test cement lines to 3,500 psi. Pump 5 bbl fresh water spacer ahead. cement wet at 16:50. Weight up to 15.8 ppg class G cement. Online with cement down 7" casing. 51.4 bbls of 15.8 ppg cement pumped. Swapped to freshwater for displacement. Returns 1:1. 53 bbls of fresh water pumped. Shut down HES cement truck. Wash up truck. 7" and 11-3/4" open to cement displacement tub. Small flow from 7" casing due to U-tube effect, less than 1 bbl flowed back. TOC in 7" and 11-3/4"x7" annuli calculated to be 1,463' from surface. Manifest cruz vac trucks to G&I facility. Clear surface lines with air. HES cement unit rigged back. HAK hot oil truck rigged down. Ready for E line in the am. Location walk around complete. SDFN. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 416-09 50-133-10129-00 100-269 7/3/18 8/31/18 Daily Operations: 07/11/2018- Wednesday PTW. Hold safety meeting. Review JSA. Fire equipment. Open well and check well conditions. PESI E -line on location. Rigging up. RIH and tag TOC at 1,383'. Make up 7" CIBP. RIH log strip. On depth. CIBP set at 160' top of plug. POOH to surface. RIH with 1-9/16" RTG with 10 shots 6 spf. Shoot holes at 157-'159'. OHH back PESI. Not able to circulate through casing punches. Call Pollard and get another casing punch coming. RU PESI. RIH with casing punch. 20 shots. Punch 152'- 162'. Online with hot oil truck to circulate casings. We have circulation. POOH. Rig down PESI. HES cement crew on location. Cruz Vac Truck on location with 65 bbls of fresh water at 70*F. Pressure test cement lines to 3,500 psi. Cement wet at 15:10. weight up to 15.8 ppg. Online at 3 bbls/min down 7" casing taking displacement up 11-3/4" casing. 17 bbls pumped. Sill watery cement. Mix up 4 more bbls and pump around until good cement seen at suface. Close in 7" and 11- 3/4" wellhead valves. cementjob complete. Clean up cement truck and manifest for G&I. Rig down TK#1. 08/22/2018- Wednesday Meet at office with Cruz super sucker. Hold safety meeting and discuss safety concerns with entering well cellars. Clean well cellars for SRU 213-10, SRU 23-22, SCU 418-09. 08/27/2018 - Monday A&L arrive on location. Permit to work and safety meeting. Remove grading. Sniff wellhead for gas. Start excavating around cellar removing surface rebar and concrete. Dig down and found 3' thick concrete cellar floor. Towards middle of cellar concrete became substantially thicker up to 5'. Not having luck breaking with excavator bucket. Called for jack hammer attachment. Move to SRU 23-22. 08/28/2018 -Tuesday PTW with A&L construction. Hold safety meeting. Arrive on location and continue to jack hammer 5'x 11' of cement cellar floor to obtain our cut depth of 3' below natural ground level. 08/29/2018- Wednesday Continue to jack hammer cement. 08/30/2018 - Thursday Rig up wellhead saw and perform cut. Cement to surface on all strings. Communicate with State Rep Guy Cook for tomorrow's P&A inspection. 08/31/2018 - Friday Guy cook on location inspect cement to surface. Good to weld marker plate. Weld marker plate. Start to backfill hole. Cut and cap existing flow lines. Location is backfilled. Send pictures of P&A work to 0 drive. i SCU 41B-9 Measuring to Cut Off Wellhead r � � i e r � S ./ �- "� r �. _ �� / ,� � , f � :� r :�q� � s �� ��� ���p r� a M �"/ _ i �� .: c xs � !! � n �_ r > Z �3 a�k $ a �i s i �A \c '; 9. f` t S `Y � 'rS g �- ` r � iii / .`.t �l, } ��. .. .iYY __ r. A � s r _ _ a`e r' ¢-V - � �`, ti � � r �y ,., �, ��. 1 ��Y�sy� ^ .•� j 4 f �i ' c r' a. i b ho a �T �•^ �•'.� at � - �..'4. s�..N.a' . ? ? i � � S O � � r " -P,�d� �, ,y� SCU 41B-9 Marker Plate v y:y 'R1 ZIP / _ S:. .. `... ftp � '. .• 95 ' Rim\ • � � Yd�.i..�s/�. �'!�� F . ie\ _ � a -" :off • Y j 480 4200 3600 r - 60 1gp0 O6 6 1 �i C RT N0. MC MP-6000 4H ��\•.rn w (P 2.cODIV-�,� T METER I I o 0 CHART PUT ONTAKEN OFF -� —_M %-fv- &-M -` \ LOCATION �• REMARKS C,'5(-7 F- a � 14 ooa� % OOVZ Consultin Inc IvIcLANE Well S.C.U. 41 B-09 Plug & Abandon Memo Via email Date: 30 August 2018 To: Hilcorp Alaska LLC....................................................Attn: Cole Bartlewski From: M. Scott McLane, PLS Project: Soldotna Creek Unit 41 B-09 Well Plug & Abandon Survey Re: Project Summary This memo represents the plug and abandon survey performed by McLane Consulting Inc. (McLane) for Hilcorp's Soldotna Creek Unit 4113-09 well located in section 9 T7N R9W Seward Meridian, Alaska. The survey was performed on August 23, 2018. 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) survey measurements were observed at the perimeter of the pad in opposite positions from the well location, parallel to the tidal flat gradient. These elevations were averaged and assumed to fairly represent original ground in the absence of historical data. A top of pad elevation was also recorded adjacent to the well casing then (2) reference grade stakes were set with measurements to the proposed cutoff elevation. Enclosed is Exhibit A which includes pad asbuilt data from 2009 and a well casing cutoff detail with pad, original ground and proposed casing cutoff elevations. • Mean pad surface grade in vicinity of well casing: 135.7'± (2018) • Original ground elevation in vicinity of well casing: 134.7' ± (2018) • Cutoff depth requirement: 3.0' below original ground elevation • Minimum casing cutoff elevation: 131.7' • Casing cutoff elevation as staked in field: 130.7' The cutoff mark elevation of 130.7', as referenced in the field, exceeds the required minimum cutoff elevation of 131.7'. P.O. Box 468 Soldotna, Alaska 99669 (907) 283-4218 Fax (907) 283-3265 Email msmclane@mclaneg.com Consulting Inc tvlc�4NE Please feel free to contact me if you have any questions or comments. Sincerely, M. Scott McLane, PLS McLane Consulting, Inc. Page 2 of 2 P.O. Box 468 Soldotna, Alaska 99669 (907) 283-4218 Fax (907) 283-3265 Email msmclane@mclaneg.com PAD SHOT (NEAR WELL) ELEV = 135.7 \ ORIGINAL GROUND SHOT ELEV = 138.9 (2018) ORIGINAL GROUND SHOT ELEV = 130.7 (2018) LIMITS OF GRAVEL PAD ®SCU12A X110 SCU41B-09 P&Aj ASP NAD83, ZONE 4 N: 2, 455, 002.14 E: 1, 486, 987.84 ELEV. 135.9 OF AC�`s�r,�I _49 T -H9* i ................ NORTH % � �_00 �.... ow 000 me :M. SCOTT MELANIE. SCALE I�`"aF�'. 4928—S yg�� 0 200 400 �, Fp gj/301$OI5 P� FEET ,1 ESS IONaL NOTES S4 S3 S9 S10 WELL CASING CUT-OFF DETAIL WELL CASING 'ATO BE REMOVED PAD FI FV = 135 1. BASIS OF HORIZONTAL; NAD83 US FEET POSITION (EPOCH 201 0) AND VERTICAL CONTROL (NAVDBB) IS AN OPUS SOLUTION FROM NGS STATIONS TBON, TSEA AND ANC2 TO ESTABLISH CP -2. THE i ALASKA STATE PLANE COORDINATES NAD 83 ZONE 4 IN FEET ARE: 4. 0' N = 2458384.578 ) E = 1483669.444 I ELEV. = 212.690 (NAVD88) I I I L_ 2. SECTION LINES SHOWN WERE ESTABLISHED FROM SURVEY TIES TO ORIGINAL GLO MONUMENTATION (1987) Co L$ng Inc G VOICE: (807)3834318 FAX: 007)283-3i3 EMAIL SA..E®MUANECG WM I I Hilcorp Alaska, O.G. ELEV = 134.7' t REFERENCED WELL CASING CUTOFF AT ELEV = 130.7' SWANSON RIVER FIELD WELL SCU 41B-09 PLUG AND ABANDON EXHIBIT -A NAD 83, ASP ZONE 4 LO TION SECTION 09 T07N R09W SEWARD MERIDIAN, ALASKA REVISION: - DATe &3013018 DRAWN BY: JAN SCALE: V=200' PRWECTNO. 187030 BOOK NO. 17L883 SHEET • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg`�C� �'�� DATE: 9/07/18 P. I. Supervisor FROM: Guy Cook SUBJECT: Surface Abandonment Petroleum Inspector SCU 41 B-09 Hilcorp Alaska LLC PTD 100-269; Sundry 318-266 8/31/18: 1 traveled to Swanson River Road in Sterling, Alaska and met up with Cole Bartlewski to witness the cement to surface and casing cut-off depth of SCU 41 B-09. The cement was to surface and was good and cured. The casing had been cut off at 3 ft 4 inches below ground surface. The identification plate had all the required information welded on to it and was to be welded on later. I instructed Cole to send me , pictures of the identification plate welded onto the casing when they were done (photos attached). Attachments: Photos (4) SWNEV NOV 2 12m 2018-0831 _Surface_Abandon_SCU_41 B-09_gc. docx Page 1 of 3 Surface Abandonment — SCU 41 B-09 (PTD 1002690) Photos by AOGCC Inspector G. Cook (except as noted) 8/31/2018 2018-0831_Surface_Abandon_SCU_41B-09_gc.docx Page 2 of 3 • n LJ Y - _ _ate .,-Ab,- --'Wpm ,-Ab,- Photo of marker plate installed; courtesy of Hilcorp (9/2/18)--- 2018-083 I—Surface—Abandon—SCU-4 I 9/2/18) 2018-0831_Surface_Abandon_SCU_41 B-09_gc.docx Page 3 of 3 0 � STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPS Test Report for: SOLDOTNA CK UNIT 41B-09 ' Contractor/Rig No.: Hilcorp TK I Operator: HILCORP ALASKA LLC Type Operation: WRKOV ''' Sundry No: Type Test: [NIT 318-266 - PTD#: 1002690 r DATE: 7/6/2018 Operator Rep: Cole Bartlewski Test Pressures: Reviewed By: ? P.I. Supry FE= Comm Inspector Bob Noble ? Insp Source Rig Rep: Gamaliel Sales i Inspector Rams: Annular: Valves: MASP: Inspection No: 250-3000 250-3000 - 250-3000 2922 : Related Insp No: bopRCN 180707200128 ACCUMULATOR SYSTEM: BOP STACK: TEST DATA MISC. INSPECTIONS: System Pressure _3_000 MUD SYSTEM: Pressure After Closure 2700 P/F 200 PSI Attained 4 - Visual Alarm Location Gen.: P _ Trip Tank P NA Housekeeping: P Pit Level Indicators NA NA PTD On Location P Flow Indicator NA NA iding Order Posted P Meth Gas Detector P P Well Sign P _ H2S Gas Detector P P ' Drl. Rig P MS Misc NA NA_ Hazard Sec. P 0 none NA Misc NA #4 Rams bopRCN 180707200128 ACCUMULATOR SYSTEM: BOP STACK: Time/Pressure P/F System Pressure _3_000 _ P Pressure After Closure 2700 P ' 200 PSI Attained 4 - P Full Pressure Attained 16 - P Blind Switch Covers: All Stations • P Nitgn. Bottles (avg): 4 na, 2462 P. ACC Misc 0 NA FLOOR SAFTY VALVES: BOP STACK: Quantity P/F Quantity Size P/F Upper Kelly 0 NA Stripper 0 none NA Lower Kelly 0 NA Annular Preventer 1 " 71/1611 P Ball Type 1 _ P, #1 Rams _ 1 _ 2 3/8" x_3_.5" ' P_ Inside BOP I P #2 Rams _1 Blinds FP FSV Misc 0 NA #3 Rams 0 none NA #4 Rams 0 none NA #5 Rams _ 0 none NA #6 Rams _ 0 none NA Choke Ln. Valves 1- 2 1/16" P - HCR Valves 1- 2 1/16" P Kill Line Valves 2 " 2 1/16" P Check Valve _ 0 none NA_ BOP Misc 0 none NA CHOKE MANIFOLD: Quantity P/F No. Valves 11 P_ Manual - Manual Chokes 2 P Hydraulic Chokes 0 NA CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 NA Number of Failures: I '/ Test Results Test Time 6.0 Remarks: Rig inspection and BOP test went well. They had the crew and all the BOP equ off of Moncla 404. They had to cycle the blinds to get them to hold. - NM-ri Wel fir- qSt,J One For p1,C(i 4%t& Ps ( Z_ )�� SCANNED AUG 0 6 'rota ' 'Y{ACJ 1.r. ,-'q " rpl- �.e 1.2,74"Im S r= ` THE SOE of AI-ILJ J GOVERNOR BILL WALKER Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 • Alaska Oil and'�Gas o #: tO JUL 0 3 Re: Swanson River Field, Tyonek Gas Pool, SCU 41B-09 Permit to Drill Number: 100-269 Sundry Number: 318-266 Dear Mr. Helgeson: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279, .1433 Fax: 907.276.7542 www.aogcc.alaska.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 Z(5 day of June, 2018. RSDMS-d JUN 2 8 2010 1`-,x a r A 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 JUN Z5 r.�jls� 1. Type of Request: Abandon ❑✓ ' Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutd�wn ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: III ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q - Stratigraphic ❑ Service ❑ 100-269 ' 6. API Number: Vs. 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 50-133-1012902-00 , 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes El No ❑ Soldotna Creek Unit (SCU) 41 B-09 . 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028997 Swanson River / Hemlock Oil - Tyonek Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,928' 10,918' - 8,758' 8,758' -2,922 psi 9,358' 8,758' ( ill) Casing Length Size MD TVD Burst Collapse Structural 28' 20" 28' 28' Conductor 1,998' 11-3/4" 1,998' 1,998' Surface 9,923' 7" 9,923' 9,922' 6,340psi 3,830p i Intermediate Production 1,324' 5" 10,926' 10,916' 10,140psi 10,490 si Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" 6.4# / L-80 7,311' Packers and SSSV Type: Baker FH Pkr; Baker 50A-25 SC -1 Pkr; Packers and SSSV MD (ft) and TVD (ft): 5,983' MD/TVD ; 10,470' MD/ 10,463' TVD; Baker SC -1 L Gravel Pkr; Baker Model D Sump Pkr; NA 10,657' MD/ 10,649' TVD; 10,786' MD/ 10,777' TVD; N/A; N/A 12. Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: July 1, 2018 OIL ❑ WINJ ❑ WDSPL ❑ Suspended GAS ❑ WAG ❑ GSTOR ❑ SPLUG ', ❑ ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑✓ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer0hilcorp.com Contact Phone: 777-8420 �y Authorized Signature: Date: Zs ! �/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: AAF V/ Plug Integrity BOP Test M/ Mechanical Integrity Test ❑ Location Clearance ❑ Other: lF D(j C� �� c ,,So c, 6: %-1- I' I ` .5 L 1I V Va ��SF� L.0 -. n J Post Initial Injection Req'd? es ❑ No ❑ GGG/ Spacing Exception Required? Yes ❑ No d Subsequent Form Required: —� T APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: $ 2,5./% RMS -4 JUN 2 8 2018 r" Submit Form and „y{ oYm 10-403 Revised 4/2017 Approved applicat n i fu r 2 o the date of approval. Attach ents in Duplicate Hileorp Alaska, LL' Well Prognosis Well: SCU 4113-9 Date: 6/20/2018 Well Name: SCU 4113-9 API Number: 50-133-10129-02 Current Status: Shut -In Gas Well Leg: N/A Estimated Start Date: July 1, 2018 Rig: Moncla 401 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 100-269 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: — 3,247 psi @ 7,426' TVD (Based on 0.473 psi/ft press. gradient; Maximum Expected BHP: — 3,247 psi @ 7,426' TVD (Based on normal grad of btm interval Max. Potential Surface Pressure: — 2,922 psi (Based on 0.1 psi/ft. gas grad. to Surf. Brief Well Summary The SCU 41B-9 well was drilled and completed as an oil well in October, 1989 as a Hemlock oil well. In September of 1995 the well was completed as a Tyonek oil well by perforating the G2. This completic remained until September of 1999 when the G2 interval was abandoned by setting and pressure testing a cemei plug to 2,500 psi and then perforating the 77-3 sand from 7,426 — 7,404'. In June of 2005, the 7,385' — 7,3S interval was added. By June 2009, the well was added to the Shut in well list. This well has never produced since Hilcorp took over as operator in 2012. /The purpose of this Sundry is to P&A the Well. Notes Regarding Well: • A PX Plug was set in the X nipple @ 7,277' on 8/3/17 to TA the well as per BLM requirements. Pre Rig Slick -line Procedure: 1. Provide 24hr notice to AOGCC that Plug and Abandonment of well will commence per AOGCC regulations 20 AAC 112.(h). 2. MIRU Slickline. PT Lubricator to 2,600 psi Hi 250 Low. 3. PU RIH with retrieving tool and pull PX plug from X -nipple at 7,277'. 4. RD sliicckline. s LV Rig Procedure O 1. MIRU KT# 1 Work Platform. 2. Ensure no pressure is on the well. 3. Set Back pressure valve. ND wellhead, NU BOP and test 250 low 3,000 psi high, annular to 250 psi Low/ 2,500 psi High. Record accumulator pre -charge pressures and chart tests. (Note: Notify AOGCC and BLM 24 hours in advance of test to extend the opportunity to witness). Perform Test. Well Prognosis Well: SCU 41B-9 HilcorpAlaska, LLO,Date: 6/20/2018 b. Test VBR rams on 2-7/8"" test joint. c. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Copy to BLM. 4. PU on tubing 30,000 over string wt to release FH Retrievable Packer. (Note: Casing jacks may be required to unset packer). Circu ate well with 9.5# kill weiht flJ ell - 6. POOH W/ Tubing laying down the capillary line and GLM's and tubing. 7. RU E -line. r---,- Sce . kid. 8. PU 7" CIBP and RIH to 7,370'. Set Same. POH PU Dump Bailer. Dump bail 35' of Cement on topof CIBP. WOC. 9. PU CBL. RIH with Same and lightly tag TOC. (TOC needs to be 7,335' or shallower.) Log 7" casing Pup into the 11-3/4" surface casing looking for TOC. 0. PU RIH W/ 7" CIBP and set at 2,150'. Note: The next steps of the procedure will be determined by the results of the CBL. c7 y If the CBL determines that there is cement behind the 7" to surface then cement plugs will be laced as follows: a. A cement plug will be placed on top of the CIBP @ 2,150' up to 1,900' using 15.8#J gal. cement. b. A second CIBP will be placed @ 160'. 15.8 #/gal. cement will be placed on the CIBP to surface. If the CBL determines that there is cement present behind the 7" casing up past the 11-3/4" surface casing shoe ( 1,998'), but not up to 160' from surface, then cement and plugs will be pla �^ as follows: a. A cement plug from the top of the CIBP at 2,150' up to 1,850'. b. A CIBP will be set at 160'. Holes will be punched in the 7" casing at 150' and circulation established. Cement will then be circulated down the 7" X 11-3/4" annulus, through the holes punched in the 7" and up the 7" casing to surface. If the CBL determines that there is not cement present behind the 7" casing up past the 11-3/4" surface casing shoe( 1,998'), then cement and plugs will be placed as follows: a. Holes will be punched in the 7" casing 100' below the Surface casing shoe ( 2,098' 2,102'). The back side valve will be opened and an attempt to establish circulation down the 11-3/4" X 7" annulus through the punched holes and up the 7" casing to surface. i. If there is circulation to surface, then Hilcorp will circulate cement down the backside, through the casing punches, and up the 7" casing to surface. Down hole plugging operations are complete. b. If there is no circulation to surface, then additional punches will be shot 100' a the surface casing shoe ( 1,898' —1,902'). c. A braden head Squeeze will be conducted by placing cement from the CIBP at 2,150' up to 1,700' (+/-). �rr�( Well Prognosis Well: SCU 41B-9 Hilcorp Alaska, LLi Date: 6/20/2018 d. Pressure will then be applied to the cement to force it into the 11-3/4" X 7" annulus to isolate the surface shoe. WOC. e. RIH and Tag TOC. (TOC must be < 1898'). f. RU E -line. PU RIH with a CIBP and set same at 160'. Holes will be punched in the 7" casing at 150' and cement circulated down the 7" X 11-3/4" annulus, through the holes punched in the 7" and up the 7" casing to surface. 11. Place dry hole tree on well. 12. RDMO KT #1. Post Rig Abandonment Procedures: 13. Excavate cellar, cut off casing 3' below natural GL. X14. N.ptifY AOGCC and BLM 48hrs in advance. 15. 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: 16. Hilcorp Alaska, LLC a. PTD: 100-269 b. Well Name: SCU 416-9 c. API: 50-133-10129-02 17. Set marker plate per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10, collect GPS coordinate 18. Photo document casing cut-off and Welded Plate install. 19. Backfill excavation, close out location. Attachments: Actual Schematic Proposed Schematic Well Head Diagram BOPE Schematic Hilcorp Alaska, LLC Original RKB = 20.42' TD =10,926'; ETD =10,834,' Max hole angle is 10° 0 SCHEMATIC Swanson River Field Well #: SCU 41B-9 Actual Completion: 6/15/05 Date Zone Top MD CASING AND TUBING DETAIL BTM TVD SIZE 6/15/05 WT GRADE CONN ID MD TOP MD BTM. 7,395' 20" 2"HSD PJ 6 SPF 94 Conduct. Surf. 28 7,403' 11-3/4 7,425' 2-1/8" EJ/PJ 6 spf, 0 deg 9-3-95 Surf. 1,998 10,402' 7" 10,420' 26-29 N-80 Surf. 2,994 H13-1 7" 10,498' 23 N-80 2,994' 4,967 11-90 7" 10,539' 26 N-80 4,967' 6,722 Abandoned 7" HB -8 29 N-80 6,722' 9,923 10,723' 5" 9-25-89 18 N-80 4.276" 9,602' 10,926 10,768' Tubing: Abandoned 2-7/8" 6.4 L-80 Buttress 2.992" Surf 7,311 Abandoned 2-7/8" 6.4 L-80 Buttress 2.441" 10,479' 10,488 2-3/8" 4.7 N-80 1.995" 10,56 10,487 JEWELRY NO Depth ID Item 1 42.9' 4.930" 3-1/2" Shaffer Tbg Hanger w/ Type H profile (E UE 8rd) 2a 2,239' 2.347" 2-7/8" McMurry Macco SMO -1 Chemical Inj. Mandrel 2b 2,320' 2.347" Cameo KBMM Gas Lift Mandrel #1 1" valve w K-2 3,917' 2.347" Cameo KBMM Gas Lift Mandrel #2 1" valve w K-2 4,871' 2.347" Cameo KBMM Gas Lift Mandrel 93 1" valve w K-2 5,512' 2.347" Cameo KBMM Gas Lift Mandrel #4 1" valve w K-2 5,934' 2.347" Cameo KBMM Gas Lift Mandrel #5 1" valve w K-2 3 5,983' 2.437" Baker FH Retrievable Packer (30 Kip shear release) 4 7,277' 2.313" Baker X -Nipple, w/ PX Plug 08/03/17 5 7,310' 2.437" Baker wireline entry guide/SOS 6 10,470' 2.688" Baker 50A-26 SC -1 Retrievable Packer 7 10,475' 2.992" Baker retrieving extension 8 10,480' 2.313 Baker X -nipple 9 10,488' 2.44" Baker wireline entry guide 10 10,657' 2.688" Baker SC -1L retrievable gravel pack Packer 11 10,660' 2.688" Model S sliding sleeve 12 10,661' 2.688" Seal bore 13 10,678' 2.00" Crossover sub 14 10678' 2.00" 2-3/8" Shear out safety joint (43,000 lbs) 15 10,710' 1.87" Otis X -nipple 16 10,741' 1.95" 2-3/8" x 0.20" gage, screen 10,771' 1.315" 2-3/8" x 1.35" O-ring sub 10,772' 1.95" 2-3/8" x 0.20" gage ,Baker tell tail screen 17 10,785' 2.00" Model S-22 snap latch seal assembly 20 10,786' 2.688" Baker Model -D permanent sump packer Date Zone Top MD Perforations Top TVD BTM MD BTM TVD Comments 6/15/05 77-3 7,385' 7,384' 7,395' 7,394' 2"HSD PJ 6 SPF 9/15/99 77-3 7,404' 7,403' 7,426' 7,425' 2-1/8" EJ/PJ 6 spf, 0 deg 9-3-95 G-2 10,402' 10,396 10,420' 10,414' Abandoned 6-90 H13-1 10,506' 10,498' 10,520' 10,512' Abandoned 11-90 HB -2 10,539' 10,531' 10,547' 10,539' Abandoned 2-90 HB -8 10,720' 10,711' 10,732' 10,723' Abandoned 9-25-89 HB -8 10,746' 10,737' 10,768' 10,758' Abandoned Fish/Fill Information: A. Abandonment plug tagged with wireline @ 9,358' WLM B. 4-1/8" Mill: top of fish @ 10,518'. C. Cleaned out cement with mill to 10,520' on 8/26/95. Revised by DED Updated by DMA 08-14-17 PROPOSED SCHEMATIC Hileorp Alaska, LLC RKB = 20.42' 9 10 11 12 13 1141 15,16 TD = 10,926'; ETD =10,834' Max hole angle is 10° Swanson River Field SCU 41B-9 Actual Completion: 6/15/05 SIZE WT GRADE CASING DETAIL CONN ID MD TOP MD BTM. 20" 94 Conduct. ±2,150' Surf. 28' 11-3/4 ±7,370' 9/15/99 CIPB w/ 100' of cement Surf. 1,995' 7" 26-29 N-80 10,475' Surf. 2,994' 7" 23 N-80 Baker X -nipple 2,994' 4,967' 7" 26 N-80 10,657' 4,967' 6,722' 7" 29 N-80 Model S sliding sleeve 6,722' 9,923' 5" 18 N-80 4.276" 9,602' 10,926' 12 10678' 2.00" TUBING DETAIL 13 10,710' Abandoned Otis X -nipple 14 10,741' 1.95" 2-3/8" x 0.20" gage, screen 2-7/8" 6.4 L-80 Buttress 2.441" 10,479' 10,488 2-3/8" 4.7 N-80 1.995" 10,56 10,487 NO Depth ID JEWELRY Item 1 ±160' 6/15/05 CIBP, cement to surface 2 ±2,150' 7,395' CIBP w/ 212' of cement 3 ±7,370' 9/15/99 CIPB w/ 100' of cement 4 10,470' 2.688" Baker 50A-26 SC -1 Retrievable Packer 5 10,475' 2.992" Baker retrieving extension 6 10,480' 2.313 Baker X -nipple 7 10,488' 2.44" Baker wireline entry guide 8 10,657' 2.688" Baker SC -1L retrievable gravel pack Packer 9 10,660' 2.688" Model S sliding sleeve 10 10,661' 2.688" Seal bore 11 10,678' 2.00" Crossover sub 12 10678' 2.00" 2-3/8" Shear out safety joint (43,000 lbs) 13 10,710' 1.87" Otis X -nipple 14 10,741' 1.95" 2-3/8" x 0.20" gage, screen Abandoned 10,771' 1.315" 2-3/8" x 1.35" O-ring sub 10,772' 1.95" 2-3/8" x 0.20" gage ,Baker tell tail screen 15 10,785' 2.00" Model S-22 snap latch seal assembly 16 10,786' 2.688" Baker Model -D permanent sump packer Date Zone Top MD PERFORATIONS Top TVD BTM MD BTM TVD Comments 6/15/05 77-3 7,385' 7,384' 7,395' 7,394' 2"HSD PJ 6 SPF 9/15/99 77-3 7,404' 7,403' 7,426' 7,425' 2-1/8" EJ/PJ 6 spf, 0 de 9-3-95 G-2 10,402' 10,396 10,420' 10,414' Abandoned 6-90 HB -1 10,506' 10,498' 10,520' 10,512' Abandoned 11-90 HB -2 10,539' 10,531' 10,547' 10,539' Abandoned 2-90 HB -8 10,720' 10,711' 10,732' 10,723' Abandoned 9-25-89 HB -8 10,746' 10,737' 10,768' 10,758' Abandoned Fish/Fill Information: �. Abandonment plug tagged with wireline @ 9,358' WLM S. 4-1/8" Mill: top of fish @ 10,518'. Cleaned out cement with mill to 10,520' on 8/26/95. Revised by DED Updated by TEK 06-20-18 Swanson River SCU 41B-09 06/20/2018 Hlrnrp :Unrka- l.a'.(: Swanson River SCU 41B-09 113/4X7X27/8 BHTA, B -15-A, 2 9/16 5M FE Valve swab, WKM-L, 2 9/16 5M FE, H W0, AA Cross, stdd, 2 9/16 5M X 2 1/16 5M Valve upper master, WKM-L, 2 9/16 5M FE, H W0, AA Valve lower master, WKM-L, 2 9/16 5M FE, H W O, AA Tubing head, Shaffer T55 -LI, 13 5/8 3M X 7 1/16 5M w/ 2- 2 1/16 5M SSO, 7" Type 1 secondary seal in head Casing head, Shaffer KD, 13 5/8 3M X 11 % SOW, w/ 2- 2" LPO, 7" KD slips and packoff assy in head Tubing hanger, Shaffer T55 - A.10, 7 X 2 7/8 BTC lift and susp, w/ 2'/: Type H BPV profile, 3/8 control line Adapter, Shaffer-AJO, 71/16 5M stdd X 2 9/16 5M,'/: npt control line port Valve, WKM-M, 21/165M FE, HWO, AA trim fb Qty 2 Valve, plug, Rockwell, 2" © LPO, 2ti • • 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" 5M DRILLING SPOOL W/2-1/16" 5M 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 Choke Manifold KT# 1 rig 03/15/2018 To Gas Buster Blooey Line 1 • Unibolt Connection • 10' in length 9' in width 2 1/16 5M Gate Valves • • KT RIG #1 RIG DIAGRAM NORMAL OPERATIONS Crane PANIC LINE l R • Schwartz, Guv L. • From: Ted Kramer <tkramer@hilcorp.com> Sent: Wednesday, June 27, 201811.41 AM To: Schwartz, Guy L (DOA) Subject: RE: [EXTERNAL] RE: KT# 1 Choke manifold drawing Guy, There is a weight indicator (load cell) with a read out in the crane. We also have the given that it is a 70 ton capacity crane. We also know how much boom we have as well as the angle ii and pick radius of the crane. From all of this we can go to the crane charts and determine the max pick at the given sett up. I met with my well site supervisor and crane operator yesterday while on location and we discussed that before every pick, we have to have an established Max pull weight that we will pull with the crane. As far as tubing weight, we have a good handle on what the tubing string weighs (3144' of 2-7/8" 6.5#/ft L-80 =20,43 - in air). What we do not know for sure is how much it will take to unseat the tbg hanger. That is why we have the casing jacks on location. If we pull to our max and it is not moving, we will rig up our casing jacks to unseat. Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, June 27, 201810:55 AM To: Ted Kramer <tkramer@hilcorp.com> Subject: [EXTERNAL] RE: KT# 1 Choke manifold drawing Ted, Is there a load cell to determine how much you are pulling with crane? Also what is the pulling limits of your crane way you will be rigged up and scoped out? 2 7/8" tension is rated at 116K lbs. (80%) Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservaf 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 delewithout first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Ted Kramer fmailto:tkramer@hilcorp.comj Sent: Wednesday, June 27, 201810:25 AM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Subject: RE: KT# 1 Choke manifold drawing Guy, FYI on Gas detectors, we have two heads on the platform floor and two at the pits (similar to the Moncla rig). Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 From: Ted Kramer Sent: Wednesday, June 27, 201810:18 AM To: Schwartz, Guy L (DOA) (guy.schwa rtz@alaska.gov) <guy.schwa rtz@alaska.gov> Subject: KT# 1 Choke manifold drawing Guy, Here is the choke manifold for KT # 1. Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 HILCORP ALASKA LLC, SOLDOTNA CK UNIT 41B-09 (100-269) SWANSON RIVER, HEMLOCK OIL Monthly Production Rates 10,000,000 101000,000 Cum. Prod Oil (bbls): 173,366 Cum. Prod Water (bbis): 38,971 Cum. Prod Gas (mcf): 14,279,147 1,000,000 =` = -• 1,000,000 CTVD R-D,,ILD) RtiOEI(N A'. T. 1 ONMM 1000 .65 .._f�°� H O NPORfN;},) pm p p xI 6� Q ... •y1 ___.___._ t 0 oNMM °�Q ° n p O c SMD Rn9(SFy DTCP(w-A) w O Q. 100,000 _3' t OHMM 100° 70 © 70- v �Q°�' Q _..epye . 100,00 °I 3 U ____ 1102110° e? ° ° O 0 .— 10,000 t ° �n ,o,00 - - 10,000 tC _o ° ° - Ve ._ 10300 I , �; o� ��� 9 WOO N P.ntuoz�t� ri C 1,000 �oaoo1,000 z (D a CPO 0 0 0 °0 0 0 0 --h Vo "� cNi taSaQ. 1a52D 10500 '_ ( .l - O *'o O ��4 �. h H 100 =.+f 10538 - 105-7 .., D _ — 100 0 0 M 0 711 ono„ I 00 0 0 ° ° `b ^ o ® o O 10 0ioo v Produced Gas (MCFM) 10 S 10720 -10732 GOR =.I 1074e 107�8 Produced Water(BOPM) 10e00 0000 o Produced Oil (BOPM) y�lb tidy ,ac SPREADSHEET Production Curve Well V102 1002690 SOLDOTNA CK UNIT 41B-09 20180625.xlsx - - - - - - - - - - 6/26/2018 Chevron r August 3, 2009 Dale A. Haines Manager, Oil & Gas Operations SCANNED APR 0 12014 Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, Union Oil Company of California 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com P;� xu,nF�sGti,�u Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, o "e, 1 � Dale Haines Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 G-8RD 1780450 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 14-42 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 16-42 1670770 Feb -87 Abandoned No Flow Phase I Abandon abandon at end of platform life Br 18-42 1680120 Apr -89 Collapsed Casing 100% water production Phase I Abandon abandon at end of platform Iife P 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubin -to-casin communication Failed MIT Possible restore injection abandon at end of platfnnn life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life n -AAT? l 1 RIAR7n Sen -M Shah,— hnle in tnhin near R') M M Stnnnell nrnAnrina Ph.— r Ah -1— ah. -i— at en 1 of nlatfh_ Iife 9ep-02 E -Line wire in LS.Low oil production from LS. Phase I Abandon abandon at end of platform life I- 7A 17KAV)n I AA..._nl I A.r,. t-.— u:..t, xx/nro. !`..r Dh..— r Al......i.... oMan Ann at —A of ..I atfn..n lif.. G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase I Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known dam a Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 1 Jun -03 INo known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 1 Jun -03 jNo known damage IPlatform shut-in -- uneconomic jPhase I Abandon abandon at end of platform life Ba -31 1 1951990 1 Dec -97 No known damage I Produced water lPhase I Abandon I abandon at end of platform life Di-2RD 1 1750070 1 Dec -02 No known damage IPlatform shut-in -- uneconomic jPhase I Abandon I abandon at end of platform life Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -4 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform Iife Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known dama a Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life ;CU 12A-10 1750570 Jan -97 milled through sg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 13-4 1750150 Jul -03 no known dama a no flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -01 no known damage no flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN SCU 21-8 1620190 Aug -9 parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21A-4 1801050 Dec -0 no known damage no flow Possible shallow gas Remove due to SI date SCU 21B-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 23B-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov -0 no known damage no flow Possible Sidetrack to G-Zone/Hemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 32B-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 44-4 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct -9 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 known dama a no flow Possible shallow as or as stora e 2011-2014 Mono od A-10 1670760 Coll sed casin Producin Coal Phase I Abandon abandon at end of latform life Mono od A-23 1720200Colla NDec-Ono sed casin Producin Coal Phase I Abandon abandon at end of latform life Mono od A-30 1730140No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of platform life \can -2(Q`k SARAH PALIN, GOVERNOR p{/ AL& l SHA011L AND GALS ! 333 W. 7th AVENUE, SUITE 100 CONSERVATION C®�il HSSIOT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 June 22, 2009 Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 ►NNED APR U 12014 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubertnalaska.gov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Company Permit No. Well Name UNOCAL _ _Union Union Oil Company of California Union Oil Company of California Oil Company of California Union Oil Company of California 168-024 194-149 179-033 167-077 Granite Pt St 17587 5 - Granite Pt St 18742 03RD Granite Pt St 18742 14 Granite Pt St 18742 16 - Union Oil Company of California 168-012 _JGranite Union Oil Company of California 100-266 Union Oil Company of California 182-020 Union Oil Company of California 169-004 Union Oil Company of California 188-098 Pt St 18742 18 Granite Pt St 31-14RD2 Trading Bay Unit D-06RD Trading Bay Unit D-18 Trading Bay Unit D-30RD2 Union Oil Company of California 182-083 Trading Bay Unit D-40RD Union Oil Company of California 178-045 Trading Bay Unit G-08RD Union Oil Company of California 176-032 ;Trading Bay Unit G-24 {I :Union Oil Company of California Union Oil Company of California i Union Oil Company of California Union 179-013 188-028 168-038 ITrading Bay Unit D 06RD ITrading Bay Unit G-34RD - - ITrading Bay Unit K-0_6_RD_ _ Union Oil Companyof California I 169-066 ITrading Bay Unit K-09 --- Union Oil Company of California 179-016 Union Oil Company of California 178-004 Trading Bay Unit K-21 RD Trading Bay Unit K-23 Union Oil Company of California 165-038 MGS St 17595 05 Union Oil Company of California 166-003 MGS St 17595 06 Union Oil Company of California 167-017 MGS St 17595 11 Union Oil Company of California 167-049 MGS St 17595 13 Union Oil Company of California 176-075 MGS St 17595 18 ------------ ---- ------ Union Oil Company of California 185-135 ---- MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD Union Oil Company of California 193-119 MGS St 17595 28 Union Oil Company of California 193-118 MGS St 17595 29 Union Oil Company of California 193-120 MGS St 17595 30 Union Oil Company of California 195-199 MGS St 17595 31 _ Union Oil Company of California 175-007 S MGS Unit 02RD Union Oil Company of California 167-028 S MGS Unit 03 Union Oil Company of California 167-058 S MGS Unit 04 Union Oil Company of California 175-044 S MGS Unit 13 Union Oil Company of California 175-066 S MGS Unit 14 _ Union Oil Company of California 176-045 S MGS Unit 15 _ Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 Union Oil Company of California 194-098 S MGS Unit 18 Union Oil Company of California 175-057 Soldotna Ck Unit 12A-10 Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 _ Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 _ Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 _ Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 _ Soldotna Ck Unit 23B-03 _ Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 Union Oil Company of California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 Union Oil Company of California 100-269 Soldotna Ck Unit 41 B-09 Union Oil Company of California Union Oil Company of California Union Oil Company of California 162-031 174-066 160-018 Soldotna Ck Unit 43-09 Soldotna Ck Unit 44-04 Swanson Riv Unit 212-10 Union Oil Company of California 161-033 Swanson Riv Unit 212-27 Union Oil Company of California 160-041 ISwanson Riv Unit 234-15 Union Oil Company of California 167-076 ,Trading Bay St A-10 Union Oil Company of California 172-020 !Trading Bay St A-23DPN Union Oil Company of California 173-014 1 Trading Bay St A-30 Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com UNOCAL Debra Oudean G & G Technician To: AOGCC Helen Warman 333 W. 7tn Ave. Ste#100 Anchorage, AK 99501 Date: June 21, 2005 01 7 WELL VENDOR PERMIT _. API NUMBER LOG TYPE SCALE ... ........ LOG:,..:.:,, INTERVAL.:.:, ..... RUN # B-: FILM NOTE5 -LAS,:.:. # IHSD DATE LOGGED LINE PDS, DLIS SCU Schlumberger 100- 501331012902COMPLETION RECORD 2 5 INCH 6/15/2005 7385-7395 1 ` 1 1 1141B-09 2690 POWERJETS i Ipds Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Received Bv: <l ��� Date: 1 �- o , app STATE OF ALASKA RECEIVED ALAS. ')OIL AND GAS CONSERVATION COMM. )ION JUL 19 2005 REPORT OF SUNDRY WELL OPERATIOMaaska Oil & Gas Cons. Commission 1. Operations Abandon L Repair Well L Plug Perforations LJ Stimulate LJ OtheAghorWperforate Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver E] Time Extension[:] Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re-enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number: Name: Development Q Exploratory❑ Stratigraphic❑ Service❑ 1002690 3. Address: PO Box 196247, Anchorage, AK 99519 6. API Number: 50-133-10129-02-00 7. KB Elevation (ft): 9. Well Name and Number: 20.42 RKB SCU 41 B-09 8. Property Designation: 10. Field/Pool(s): Swanson River Unit Swanson River Field, G -Zone, Hemlock 11. Present Well Condition Summary: Total Depth measured 10,926' feet Plugs (measured) 9,358' true vertical 10,916' feet Junk (measured) 8,758' tagged fill Effective Depth measured 8,758' feet true vertical 8,757' feet Casing Length Size MD TVD Burst Collapse Structural 28' 20" 28' 28' Conductor 1,998' 11-3/4" 1,998' 1,997' Surface 9,923' 7" 9,923' 9,992' 6,340 psi 3,830 psi Intermediate Production 1,324' 5" 10,926' 10,916' 10,140 psi 10,490 psi Liner Perforation depth: Measured depth: see attached True Vertical depth: see attached Tubing: (size, grade, and measured depth) 2-7/8", 6.4#, L-80 @ 7,311' (see schematic for abandoned tubing) Packers and SSSV (type and Baker FH Retrievable Packer @ 5,983'; Baker 50A-26 SC -1 Retrievable Packer @ 10,470'; Baker SCA L retrievable measured depth) gravel pack Packer @ 10,657'; Baker Model -D permanent sump packer @ 10,786' 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a RBM EFL JUL 2 0 7005 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 68 372 n/a 200 Subsequent to operation: 0 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory[] Development 0 Service ❑ Daily Report of Well Operations X 16. Well Status after proposed work: Oil [:1 Gas El WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ 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: n/a Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 907-276-7600 Date 7/12/2005 Form 10-404 Revised 04/2004U KL iF..,1 �Q$� Submit Original Only Swanson River Field ALASKA WRILLING1 Well #: SCU 41B-9 UNOCAUS Actual Completion: 6/15/05 Original RKB = 20.42' TD =10,926'; ETD =10,834,' Max hole angle is 10° Revised by DED SIZE WT CASING AND TUBING DETAIL GRADE CONN ID MD TOP MD BTM. 20" 94 Conduct. 2a Surf. 28' 11-3/4 2b 2,320' 2.347" Surf. 1,998' 7" 26-29 N-80 9-3-95 Surf. 2,994' 7" 23 N-80 2.347" 2,994' 4,967' 7" 26 N-80 3 4,967' 6,722' 7" 29 N-80 2.313" 6,722' 9,923' 5" 18 N-80 4.276" 9,602' 10,926' Tubing: 7 10,475' 2.992" Baker retrieving extension 8 2-7/8" 6.4 L-80 Buttress 2.992" Surf 7,311' Abandoned 10 10,657' 2.688" Baker SC -1L retrievable gravel pack Packer 11 2-7/8" 6.4 L-80 Buttress 2.441" 10,479' 10,488' 2-3/8" 4.7 N-80 1.995" 10,56 10,487' NO Depth ID JEWELRY Item 1 42.9' 4.930" 3-1/2" Shaffer Tbg Hanger w/ Type H profile (EUE 8rd) 2a 29239' 2.347" 2-7/8" McMurry Macco SMO -1 Chemical Inj. Mandrel 2b 2,320' 2.347" Cameo KBMM Gas Lift Mandrel #1 1" valve w/BK-2 7,403' 39917' 2.347" Cameo KBMM Gas Lift Mandrel #2 1" valve w/BK-2 9-3-95 4,871' 2.347" Cameo KBMM Gas Lift Mandrel #3 1" valve w/BK-2 10,420' 5,512' 2.347" Cameo KBMM Gas Lift Mandrel #4 1" valve w/BK-2 HB -1 5,934' 2.347" Cameo KBMM Gas Lift Mandrel #5 1" valve w/BK-2 3 5,983' 2.437" Baker FH Retrievable Packer (30 Kip shear release) 4 7,277' 2.313" Baker X -Nipple 5 7,310' 2.437" Baker wireline entry guide/SOS 6 10,470' 2.688" Baker 50A-26 SC -1 Retrievable Packer 7 10,475' 2.992" Baker retrieving extension 8 10,480' 2.313 Baker X -nipple 9 10,488' 2.44" Baker wireline entry guide 10 10,657' 2.688" Baker SC -1L retrievable gravel pack Packer 11 10,660' 2.688" Model S sliding sleeve 12 10,661' 2.688" Seal bore 13 10,678' 2.00" Crossover sub 14 10678' 2.00" 2-3/8" Shear out safety joint (43,000 lbs) 15 10,710' 1.87" Otis X -nipple 16 10,741' 1.95" 2-3/8" x 0.20" gage, screen 10,771' 1.315" 2-3/8" x 1.35" O-ring sub 10,772' 1.95" 2-3/8" x 0.20" gage ,Baker tell tail screen 17 10,785' 2.00" Model S-22 snap latch seal assembly 20 10,786' 2.688" Baker Model -D permanent sump packer Date Zone Top MD Perforations Top TVD BTM MD BTM TVD Comments 6/15/05 77-3 7,385' 7,384' 7,395' 7,394' 2"HSD PJ 6 SPF 9/15/99 77-3 7,404' 7,403' 7,426' 7,425' 2-1/8" EJ/PJ 6 spf, 0 deg 9-3-95 G-2 10,402' 10,396 10,420' 10,414' Abandoned 6-90 HB -1 10,506' 10,498' 10,520' 10,512' Abandoned 11-90 HB -2 10,539' 10,531' 10,547' 10,539' Abandoned 2-90 HB -8 10,720' 10,711' 10,732' 10,723' Abandoned 9-25-89 HB -8 10,746' 10,737' 10,768' 10,758' Abandoned Fish/Fill Information: A. Abandonment plug tagged with wireline @ 9,358' WLM B. 4-1/8" Mill: top of fish @ 10,518'. C. Cleaned out cement with mill to 10,520' on 8/26/95. Well Name SCU 41B-9 Field Name API/UWI �SWANSON 50-133-10121-02 Lease/Serial Orig KB Elev (ftKB) Water Depth (ft) �Soldotna Creek 20.4 0.00 Primary Job Type Perforating Primary Wellbore Affected Main Hole Jobs AFE No. QC Eng 164038 Daily Operations 6/14/2005 00:00 - 6/15/2005 00:00 Operations Summary Prep for job. Pressure tested lubricator. 1050 psi tbg and fluid to surface. RIH w/2.25"GR and set down at 20' RKB. Pumped water and moved ice plug to 51' RKB. RIH w/ 2.25"GR. Tagged fluid level at 490' w/100psi on tbg. Tagged fill at 8758' RKB. RIH w/ 2" x 10' dummy guns to 7500'. 6/15/2005 00:00 - 6/16/2005 00:00 Operations Summary Spot eline equipment and RU. PJSM. RIH w/ 2"HSD Powerjet 6 SPF, 60 degree phase. Tied in to RST -Sigma log (December 14, 2000). Perforated 10 shots from 7385' W/L to 7395' W/L. POOH all shots fired. RD. ALASKA OIL AND GAS CONSERVATION COMPIMSION December 6, 1999 Dan Williamson Drilling Manager UNOCAL P O Box 196247 Anchorage, Alaska 99519 Re: Permit Number Ltr Dated October 11, 1999 Dear Mr. Williamson: TONYKNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 AOGCC history database had a problem with six duplicate permit numbers that occurred several years ago. The current listed well permits were not issued by AOGCC. We added a seventh digit to the permit number and inturn created a database problem. I corrected this situation by changing the permit number to a new Y2K seven -digit permit number. The new Y2K permit number (first six digits) should be annotated on all reports submitted to AOGCC for these named wells in the future: Current Permit Well name New Y2K Permit Number 66-0056-1 Granite Pt St 31-14RD 1 100-265-0 66-0056-2 Granite Pt St 31-14RD2 100-266-0 74-0026-1 Soldotna Ck Unit 32B-09 100-267-0 72-0017-1 Soldotna Ck Unit 33A-08 100-268-0 80-0107-1 Soldotna Ck Unit 41 B-09 100-269-0 68-0044-1 Trading Bay Unit G-12RD 100-270-0 The permit number changes were made December 5, 1999 by AOGCC. Sincerely, at, Steve McMains Statistical Technician j STATE OF ALASKA ALASKA O -i -L AND GAS CONSERVATION uOMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Oil'*.GAS( SUSPENDED: Classification of Service Well ABANDONED: SERVICE: Q 2. Na,R� )f Operator UNOCAL 7. Permit Number — — 0- 599164 8. API Number 50- 133-10129-02 3. Address PO Box 196247, Anchorage, AK 99519-6247 4. Location of well at surface 710' FNL, 660' FEL, Sec 9, T7N, R9W, SM At Top Producing Interval 710' FNL, 660' FEL, Sec 9, T7N, R9W, SM At Total Depth 587' FNL, 579' FEL, Sec 9, T7N, R9W, SM `'`�"'"'~° 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 41B-9 11. Field and Pool Swanson River Field Hemlock/Tyonek 5. Elevation in feet (indicate KB, DF, etc.) 150' KB/123'GL 6. Lease Designation and Serial No. I A-028384 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 9/1/99 15. Water Depth, if offshore NA feet MSL - 16. No. of Completions 1 17. Total Depth (MD+TVD) 10928/10918 18. Plug Back Depth (MD+TVD) 1 9358-9350 19. Directional Survey Yes: No: 20. Depth where SSSV set NA feet MD 21. Thickness of Permafrost NA 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED NA 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 8,095' to 8,119' MD 8,094' to 8,118' TVD 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 7311 5983 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9358-10470 25 BBLS of Cement 27. PRODUCTION TEST Date First Production 9/16/99 Method of Operation (Flowing, gas lift, etc.) Gas Lift --No Entry Date of Test 9/16/99 Hours Tested 18 PRODUCTION FOR TEST PERIOD => OIL -BBL 0 '0 GAS -MCF WATER -BBL .0 CHOKE SIZE I 2" GAS -OIL RATIO NA Flow Tubing Press. 250 Casing Pressure 1900 CALCULATED 24-HOUR RATE => OIL -BBL 0 GAS -MCF 1 0 1 WATER -BBL 0 INA OIL GRAVITY -API (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NA REC EIVED ORIGINAL NAV 19199AnChomp Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. GEOLOGIC MARKERS 30. FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. MEAS. DEPTH TRUE VERT. DEPTH Tyonek 77-3 Sand 8084 8120 31. LIST OF ATTACHMENTS Operations Summary, Well Diagram 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge I ADMAPIMAAAAW t Signed Title All / / Date ` / / G ( 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". Form 10-407 SCU 41B-9 Operations Summary: 8/2399: RU pump truck and kill well. 8/27-9/2/99: MIRU rig. NU BOPE and test to 250/3000 psi. POOH standing back 2-7/8" tubing. LD GLM's and jewelry. RIH with tubing and tag packer/fill @ 10459'. Pump 25 BBLS of Class G cement. Pull 20 stands and reverse circulate. Displace well to 6% KCI. POOH and LD 107 jts of tubing. RIH with 2-7/8" completion. Land tubing hanger/ Set packer @ 5989'. Pressure test tubing to 3,000 psi and annulus to 2,500 psi. Test abandonment plug to 2,500 psi. ND BOPE and NU tree. Test tree to 5,000 psi. 9/15/99: RU wireline unit. RIH and tag cement @ 9358'. Perforate 7426-7404 with 2-1/8" EJ/PJ 6 SPF 0 deg phasing. Turn well over to production. SCU 41 B-9 Operations Summary.doe 11/17/99--1:05 PM TD =10,926'; ETD =10,834,' Max hole angle is 10° SIZE WT CASING AND TUBING DETAIL GRADE CONN ID MD TOP MD BTM. 20" 94 Conduct. Surf. 28' 11-3/4 2-7/8" McMurry Macco SMO -1 Chemical Inj. Mandrel 2b Surf. 1,998' 7" 26-29 N-80 Surf. 2,994' 7" 23 N-80 2,994' 4,967' 7" 26 N-80 4,967' 6,722' 7" 29 N-80 6,722' 9,923' 5" 18 N-80 4.276" 9,602' 10,926' Tubing: 7,310' 2.437" Baker wireline entry guide/SOS 6 2-7/8" 6.4 L-80 Buttress 2.992" Surf 7,311' Abandoned Baker retrieving extension 8 10,480' 2.313 2-7/8" " 6.4 L-80 Buttress 2.441" 1110,54 10,479' 10,488' 1-01497' NO Depth ID JEWELRY Item 1 42.9' 4.930" 3-1/2" Shaffer Tbg Hanger w/ Type H profile (EUE 8rd) 2a 2,239' 2.347" 2-7/8" McMurry Macco SMO -1 Chemical Inj. Mandrel 2b 2,320' 2.347" Camco KBMM Gas Lift Mandrel #1 1" valve w/BK-2 Fish/Fill Information: 3,917' 2.347" Camco KBMM Gas Lift Mandrel #2 1" valve w/BK-2 B. 4-1/8" Mill: top of fish @ 10,518'. 4,871' 2.347" Camco KBMM Gas Lift Mandrel #3 1" valve w/BK-2 5,512' 2.347" Camco KBMM Gas Lift Mandrel #4 1" valve w/BK-2 5,934' 2.347" Camco KBMM Gas Lift Mandrel #5 1" valve w/BK-2 3 5,983' 2.437" Baker FH Retrievable Packer (30 Kip shear release) 4 7,277' 2.313" Baker X -Nipple 5 7,310' 2.437" Baker wireline entry guide/SOS 6 10,470' 2.688" Baker 50A-26 SC -1 Retrievable Packer 7 10,475' 2.992" Baker retrieving extension 8 10,480' 2.313 Baker X -nipple 9 10,488' 2.44" Baker wireline entry guide 10 10,657' 2.688" Baker SC -11, retrievable gravel pack Packer 11 10,660' 2:688" Model S sliding sleeve 12 10,661' 2.688" Seal bore 13 10,678' 2.00" Crossover sub 14 10678' 2.00" 2-3/8" Shear out safety joint (43,000 lbs) 15 10,710' 1.87" Otis X -nipple 16 10,741' 1.95" 2-3/8" x 0.20" gage, screen 10,771' 1.315" 2-3/8" x 1.35" O-ring sub 10,772' 1.95" 2-3/8" x 0.20" gage ,Baker tell tail screen 17 10,785' 2.00" Model S-22 snap latch seal assembly 20 10,786' 2.688" Baker Model -D permanent sump packer Perforations Date Zone Top BTM Comments ?? 77-3 999 7,404' Proposed 9/15/99 77-3 7,404' 7,426' 2-1/8" EJ/PJ 6 spf, 0 deg 9-3-95 G-2 10,402' 10,420' Abandoned 6-90 HB -1 10,506' 10,520' Abandoned 11-90 HB -2 10,539' 10,547' Abandoned 2-90 HB -8 10,720' 10,732' Abandoned 9-25-89 HB -8 10,746' 10,768' Abandoned Fish/Fill Information: A. Abandonment plug tagged with wireline @ 9,358' WLM B. 4-1/8" Mill: top of fish @ 10,518'. C. Cleaned out cement with mill to 10,520' on 8/26/95. SCU 41B-9 9-1-99.DOC MWD/Revised: 8/26/99 w 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson DATE: August 30, 1999 Chairman THRU: Blair Wondzell, �2 i FILE NO: A99JH4GF.DOC P. I. Supervisor 1201,31191 FROM: Lou Grimaldi y SUBJECT: BOPE Test CC -1 Petroleum Ins ector Unocal SCU 41 B-9 Soldotna Creek Unit PTD #80-0107 Sundry #399-164 Monday, August 30, 1999: 1 witnessed the initial BOPE test on CC -1 which was preparing to work over Unocal well #SCU 41 B-9 in the Soldotna Creek unit. The rig was ready to test when I arrived and we began immediately. All BOPE equipment was tested with no failures observed. The rig was well prepared for this test as was evident by the Four-hour test time. The location was well laid out and orderly. Over the last couple of visits to this rig, I have seen much improvement in not only its performance but its general appearance overall. SUMMARY: I witnessed the initial test of the BOPE on CC -1 working over Unocal well # 41B-9 in the Soldotna Creek Unit. There were No failures observed. Test time 4 hours. Attachments: A99JH4GF.XLS CC: Dan Williamson (Unocal drilling supervisor) NON -CONFIDENTIAL I A99J H4G F STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X DATE: 8/30/99 Drlg Contractor: Inlet Drilling Rig No. CC#1 PTD # 80-107 Rig Ph.# 283-2535 Operator: Unocal Rep.: Nick Scales Well Name: SCU 41 B-9 Rig Rep.: Jerry Sandidge Casing Size: Set @ Location: Sec. 9 T. 7N R. 9W Seward Test: Initial X Weekly Other REMARKS: Good test, Rig coming along nicely. Location orderly and clean. Distribution: STATE WITNESS REQUIRED? orig-Well File YES X NO TEST DATA c - Database 24 HOUR NOTICE GIVEN c - Trip Rpt File Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure P/F Location Gen.: P Well Sign P Upper Kelly/ IBOP 1 250/3,000 P Housekeeping: P (Gen) Drl. Rig P Lower Kelly / IBOP PTD On Location P Hazard Sec. P Ball Type 1 Standing Order Posted P Inside BOP 1 BOP STACK: Quan. Test Press. P/F Test Annular Preventer 1 250/3000 P CHOKE MANIFOLD: Pressure P/F Pipe Rams 1 250/3,000 P No. Valves 11 250/3,000 P Lower Pipe Rams 1 P No. Flanges 32 Blind Rams 1 P Manual Chokes 1 Functioned Choke Ln. Valves 1 P Hydraulic Chokes 1 HCR Valves 1 P Kill Line Valves 2 P ACCUMULATOR SYSTEM: Check Valve 1 1 System Pressure 2,950 P Pressure After Closure 2,400 MUD SYSTEM: Visual Alarm 200 psi Attained After Closure m In S 28 sec. Trip Tank P P System Pressure Attained m in's —4-6— sec. Pit Level Indicators - P P Blind Switch Covers: Master: Remo�P Flow Indicator P P - Nitgn. Btl's: Four bottles @ 2500 Meth Gas Detector P P H2S Gas Detector P P TEST RESULTS Number of Failures: 0 ,Test Time: 4 Hours. Number of valves test 23 Repair or replacement of ailed Equipment will be made within N/A Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission _days. Office at: axNo. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. 1. Supervisor at 279-1433 REMARKS: Good test, Rig coming along nicely. Location orderly and clean. Distribution: STATE WITNESS REQUIRED? orig-Well File YES X NO c - Oper./Rig c - Database 24 HOUR NOTICE GIVEN c - Trip Rpt File YES X NO c - Inspector Page 1 Waived By: Witnessed By: Lou Grimaldi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 4bkilc � APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: X Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: 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 Exploratory: 150'K13 / 123' GL feet 3. Address 7. Unit or Property name P.O. Box 196247 Anchorage, AK 99519 Stratigraphic: Soldotna Creek Unit Service: 4. Location of well at surface 8. Well number 710' FNL, 660' FEL, Sec. 9, T7N, R9W, SM SCU 41 B-9 9. Per it number At top of productive interval 612' FNL, 635' FEL, Sec. 9, T7N, R9W, SM V • /O 10. API number At effective depth 592' FNL, 605' FEL, Sec. 9, T7N, R9W, SM 50- 133-10129-02 11. Field/Pool At total depth 587' FNL, 579' FEL, Sec. 9, T7N, R9W, SM Swanson River/ 12. Present well condition summary Total depth: measured 10928 feet Plugs (measured) true vertical 10918 feet A LIG 2 1999 i Effective depth: measured 10834 feet Junk (measured) true vertical 10825 feet Alaska Oil & Gas (torts. Coni llSSluf Atchora�ge Casing Length Size Cemented Measured depth True vertica depth Structural 28' 20" Yes 28 28 Conductor Surface 1988' 11-3/4" 1200 sx 3161 3161 Intermediate Production 9910' 7" 1600 sx 9910 9909 Liner 1324' 5" 175 sx 10926 10918 Perforation depth: measured 10347-10376; 10402-10420'10506-11520'10538-10547;10720-10732; 10746-10768 true vertical 10340-10360; 10395-10413; 10499-10513; 10530-10539; 10711-10723; 107737-10759 Tubing'(size, grade, and measured depth) ORIGINAL 2-7/ " .4 Ib/ft 9636' 2-3/8" 4.7 Ib/ft N-80 10661-10786. 2-7/8"6.4 Ib/ft 10470-10488 8 6 @ Packers and SSSV (type and measured depth) Baker "FH" @ 9527'; Baker SC -1 @ 10470'; Baker SC1 L @ 10661 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 8/26/99 Oil: X Gas: Suspended: 16. If proposal well verbally approved: Name of ver Date approved 1 Service: 17. 1 hereb ce 'fy What the re i rue and correct to the best of my knowledge. Signed: Title: Drilling Manager Date: 44 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No. Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ti0'7 ropy vg d A pr ev'4 �f ORIGINAL SIGNED BY Robert N. Christenson Commissioner Date Approved by order of the Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Unocal Alaska Bul..ness Unit Swanson River Field Well #SCU 41B-9 Prepared by: MWD Date:8/20/99 Revision #1 ALASKA _., MRILLINCv • 5 No. Preliminary Procedure Kill well prior to moving in rig. Set BPV 1 MIRU rig --turnkey rig move. 2 ND tree and NU BOPE 3 Test BOPE 4 RIH with landing joint and release FH packer. ��✓�- 5 POOH and standback 2-7/8" tubing. Lay down GLM's. 6 RIH with cement retainer and set @ 9,550' 7 Pump cement below retainer and abandon G-2 perforations. 8 Pull stinger out of retainer. 9 Place at least 100 ft of cement on top. 10 POOH above cement and circulate well and tubing clean. 11 POOH with stinger. 12 LD stinger and PU bit and casing scraper. 13 RIH w/ scraper 14 Pit Cleaning 15 Change well over to 6% KCI. 16 POOH with tubing. 17 RIH with GLM's used 2-7/8" tubing, and chemical injection mandrel 18 Set packer @ 6,000' with tubing tail @ 7,300' 19 Release landing joint. 20 Set BPV 21 IND BOPE 22 NU tree 23 Test Tree. 24 Release rig. NU Flowlines Gas lift water from well. RU wireline unit. RIH and perforate 77-3 sand at 7382'-7426. RD wireline unit. SCU 41 B-9 AFE ESTAs Page 1 of 1 8/20/99 Original RKB = 20.42' TD =10,926'; ETD =10,834,' Max hole angle is 10° SCU 41B-9 8-28-95.DOC Swanson liver Field Well #: SCU 41B-9 Actual Completion: 8/28/95 SIZE WT CASING AND TUBING DETAIL GRADE CONN ID MD TOP MD BTM. 20" 94 Conduct. Surf. 28' 11-3/4 3-1/2" Shaffer Tbg Hanger w/ Type H profile (EUE 8rd) 2 Surf. 1,998' 7" 26-29 N-80 Surf. 2,994' 7" 23 N-80 2,994' 4,967' 7" 26 N-80 4,967' 6,722' 7" 29 N-80 6,722' 9,923' 5" 18 N-80 4.276" 9,602' 10,926' Tubing: 7,521' 2.347" Camco KBMM Gas Lift Mandrel #4 2-7/8" 6.4 L-80 Buttress 2.992" Surf 9,635' 2-7/8" 7-31SIl 6.4 L-80 Buttress 2.441" "t 10,479' 10,488' DRAWN BY: MWD 8/20/99 JEWELRY NO Depth ID Item 1 42.9' 4.930" 3-1/2" Shaffer Tbg Hanger w/ Type H profile (EUE 8rd) 2 2,259' 2.347" Camco KBMM Gas Lift Mandrel #11 3,512' Camco KBMM Gas Lift Mandrel #10 4,512' Camco KBMM Gas Lift Mandrel #9 5,101,' 2.347" Camco KBMM Gas Lift Mandrel #8 5,717,' 2.347" Camco KBMM Gas Lift Mandrel #7 6,298,' 2.347" Camco KBMM Gas Lift Mandrel #6 6,909' 2.347" Camco KBMM Gas Lift Mandrel #5 7,521' 2.347" Camco KBMM Gas Lift Mandrel #4 8,099' 2.347" Camco KBMM Gas Lift Mandrel #3 8,711' 2.347" Camco KBMM Gas Lift Mandrel #2 9,322' 2.347" Camco KBMM Gas Lift Mandrel #1 3 9,527' 2.44" Baker FH Retrievable Packer 4 9,540' 2.313" Baker X -Nipple 5 9,635' 2.44" Baker wireline entry guide 6 10,470' 2.688" Baker 50A-26 SC -1 Retrievable Packer and 7 10,475' 2.992" Baker retrieving extension 8 10,480' 2.313 Baker X -nipple 9 10,488' 2.44" Baker wireline entry guide 10 10,657' 2.688" Baker SC -11, retrievable gravel pack Packer 11 10,660' 2.688" Model S sliding sleeve 12 10,661' 2.688" Seal bore 13 10,678' 2.00" Crossover sub 14 10678' 2.00" 2-3/8" Shear out safety joint (43,000 lbs) 15 10,710' 1.87" Otis X -nipple 16 10,741' 1.95" 2-3/8" x 0.20" gage, screen 10,771' 1.315" 2-3/8" x 1.35" O-ring sub 10,772' 1.95" 2-3/8" x 0.20" gage ,Baker tell tail screen 17 10,785' 2.00" Model S-22 snap latch seal assembly Perforations Date Zone Top BTM Comments 9-3-95 G-2 10,402' ' 10,420' 2-1/8" EJ 90 deg 6 SPF 6-90 HB -1 10,506' 10,520' 11-90 HB -2 10,539' 10,547' 2-90 HB -8 10,720' 10,732' 9-25-89 HB -8 10,746' 10,768' - Fish/Fill Information: A. 1-3/4" gauge ring tag fill @ 10,471' on 10/19/95. B. 4-1/8" Mill: top of fish @ 10,518'. C. Cleaned out cement with mill to 10,520' on 8/26/95. ISED: 3/22/99 DRAWN BY: MWD 8/20/99 Inlet Drilling Rig #CC -1 7-1/16" 5000 psi BOP Stack Valve on Koomey Line 3-1/8" Kill Line 7-1/16" Annular Preventer 5k psi Blind Rams 5k psi Pipe Rams Drilling 1 1 Spool 2 5k psi Pipe Rams 7-1/16"" 5M Tubinglhead 7" Casing T 4-1/16" Choke Line 1 = HCR Valve 2 = Gate Valve 0 Blowout Prevention Equipment Inlet Drilling Rig #CC -1 or Equivalent 7-1/16" BOP Equipment 1 ea 7-1/16" x 5000 psi wp single ram type preventer 1 ea 7-1/16" x 5000 psi wp double ram type preventer 1 ea 7-1/1691 x 5000 psi wp annular preventer 1 ea 7-1/1611 x 5000 psi wp drilling spool with 2 ea 4" side outlets (choke and kill), HCR and manual valves on choke line and two manual valves on kill line. Kill line also has a check valve. 1 ea Koomey BOP control unit with 120 gallon volume tank, w/twelve 10 -gallon accumulator bottles and nitrogen back-upsystem. Valve at annular preventer on Koomey line. 1 ea 5 station, remote control panel 1 ea 5,000 psi choke manifold with Cameron automatic hydraulic choke 3' - 10,000 psi with control choke panel. 1 lot Hydraulic pipe and fittings from manifold to BOP stack. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: Other: x 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: Exploratory: x 150' KB 123' GL feet 3. Address 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Soldotna Creek Unit 4. Location of well at surface 8. Well number 710' FNL, 660' FEL, Sec. 9T7N, R9W, SM SCU 41 B-9 At top of productive interval 9. Permit number/approval number 612 FNL, 635' FEL, Sec. 9, T7N, R9W, SM 80-107/95-168 At effective depth 10. API number 592' FNL, 605' FEL, Sec. 9, T7N, R9W, SM 50- 133-10129-02 At total depth 11. Field/Pool 587' FNL, 579' FEL, Sec. 9, T7N, R9W, SM Swanson River/Hemlock 12. Present well condition summary Total depth: measured 10928 feet Plugs (measured) true vertical 10918 feet # � Effective depth: measured 10834 feet Junk (measured) true vertical 10825 feet Casing Length Size Cemented Measured depth True vertical depth Structural 28' 20" Yes 28" 28" Conductor Surface 1988' 11-3/4" 1200 sx 3161' 3161' Intermediate Production 9910' 7" 1600 sx 9910' 9909' Liner 1324' 5" 175 sx 10926' 10918' Perforation depth: measured 10347'-10376'; 10402'-10420'; 10506-11520'; 10538'-10547' r E D true vertical 10340'-10360'; 10395'-10413; 10499'-10513'; 10530'-10539'; 10711'-10723'; 737' 0 59' Tubing (size, grade, and measured depth) N O V 2 0 1996 2-7/8", 6.4# @ 9636' 2-3/8", 4.7# N-80 10661'-10786 2-7/8" 6.4# L-80 10470' -10488 - Packers and SSSV (type and measured depth) Baker "FH" @ 9527'; Baker SCA @ 10470', Baker SCIL @ 10661' Alaska Oil & Gas Cons. Commission Anchareas 13. Stimulation or cement squeeze summary Intervals treated (measured) On October 31, 1996 a step rate water injection test was conducted, please see attachments for details. Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil -BBL Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-in since September 1995 Subsequent to operation 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: x Gas: Suspended: Service: 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: Dale A. Haines CAAj, Title: Drilling Manager Date: ## i Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 40 0 a 0 0) 0 z 00 L) kn N W a 0 0 Jobheport Total Flowrate Wellhead Pressure Messages Recorded Volume (BBL ) WELL 41B-9 FIELD Swanson River CLIENT UNOCAL EXECUTION SUMMARY COUNTRY USA JOB DATE 31 OCT 96 T i me Total Flowrate Wellhead Pressure Messages Recorded Volume (BBL ) 12:00:00 Pressure test 12: 15:00 Begin injection — 5 12:30:00IL - 10 — 15 12:45:00 Pressure annulus — 20 — 25 13:00:00 Begin injection — 30 — 35 Pressure at 4000 psi max 13: 15:00 - 40 — 45 — 50 13:30:00 — 55 — 60 13:45:00 - 65 - 70 14:00:00 — 75 Pressure of 4000 psi max 14:15:00 RECEIVED 14:30:00 - 80 2 Q 1996 ]31Dov — 85 14:45:00 A14414$ Oil & 044 CQAA- COMM'"'" 15:00:00 0.00 BPM 1.25 0 --- PSI 5000 0 100 Schlumberger WELL TREATMENT REPORT . Do�weN os.�w.0 PMM& ih USA. DOWELL SCHLUMBERGER INCORPORA ; WELL. NAME AM NUMBER Sk . B- 9' LOCATION (U!emyDS U. , ,�, � FR TION 4::"* 6 TREATMENT NUMBER d D - 03 - CARBON DK)XIDE POOLJI;IELD lid s&r-fRver,o FOR ION ::r K BOTTOM HOLE TEM /�RATURE N A AGE OF WELL NEW REWORK ❑ TYPE OF WELL OIL GAS WATER ❑ ❑ INJ. ❑ COUyTY/P A// j14 NA -f Af 4 �`l+nJ �y ! l� El f �.54 STA e ALLOWABLE PRESSURE 00 RIR_ 1 '[Etl ll�l"fwwm S TOP TO BOTTOM HM� TYPE OF SERVICE 0 [3 MATRIX TREATMENT ❑ SANQ CONTROL Cl FRACTURING .OTHER ePRIMARY TR ATING FLUI t/ ( kz- fit o—� 4 =SING SIZE DEPTH �Z TO q q / / �� TO THIS/TREATMENT ` .�O eAL OPERATORNAME y / TUBING SIZE WT DEPTH TO ❑ Stabilized 2 G. v 9631�" TO 3Cy6 SERVICE INSTRUCTIONS y �o a 5• PACKER TYPE PACKER DEPTH TO /L) 7o � 9 S 3 �z y�y TO + i •I lee -a ..a �- S : Le 5 O nn . N TUBING VOLUME C-7 ANNULAR VOL 02-1a TO I i a S. PERF. DIAMETER- IN. • OPECASING VOL.PERFORATED I INTERVAL TOTAL- /49 FT. OIL VOLUME FLU N BBL.S r FOR CONVERSION PURPOSES 24 BELS EQUALS 1000 GALLONS DISPLACEMENT C. TBG. TUBING ❑ JOB DONE DOWN CASING I ANNULUS I ❑ ❑ BOTH ❑ ARRIVED ON LOCATION: 10: e) c LEFT LOCATION: 30 , J.0 lie 3 /106 /VUR )420 N� 7 �6 2 FLUID mil X, ;i wl�w nom nim Imm� umm Imm 2 Pre -Job Safety Meeting Pressure Test To Od psi O 16 C BPM AVERAGE INJECTION RATES 6 a.O CARBON DK)XIDE TOT 11-56 (NITROPEN I �NNPROP ( SQ. TREATING TREATING PRESSURE SUMMARY PRESSURE 7 /voo FINAL AVYR`G�v IMrMEE . S.D.P. MIN S.I.P /�/�,tStuv d- i44%X,4,k- I / 115 THIS/TREATMENT 0450 / ❑ Teat (/ �J ❑ Stabilized :NTA V S SUPE -L 36 f6 r 7 3Cy6 Pre -Job Safety Meeting Pressure Test To Od psi O 16 C I h., I , S , e-,Sn+ 6 a.O 0 11-56 r a ` to SQ. ov o 7 /voo Sad o P ,� ;,tic 71 v 96 d Ovd /�/�,tStuv d- i44%X,4,k- 106 0450 �• e66 4L/o46 ,. �v 36 f6 Sj fy-r� 3Cy6 /L) 7o c�a yab I 3wr 4 54 TliPl<tCEIV r -u u *2/00IV WA ACID BBLS OIL VOLUME FLU N BBL.S r TOTAL INJECTED AJ ANTITY PROPPANT PLACED TOTAL ORDER /�`` �pESIGNED Las N TONS PAD VOLUME GALS % PAD FRACTURE-- GRADIENT PAGE OF PAGES OCT -07-96 MON 14:10 UNOCAL� ASSET GAS GRP FAX NO. 9072W874 P,01/02Unocal Energy Resource- .,vision Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7813 UNOCAL0 October 7, 1996 Gary A. Orr Senior Petroleum Engineer Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wondzell: Unocal wishes to conduct a water injectivity step -rate test on Well 41 B-9 in the Tyonek oil zone. The objective of this test is to determine the possibility of using water Injection as a form of pressure maintenance in the Tyonek. The Tyonek oil zone completion in Well 41 B-9 is completed below the oil/water contact. The test will consist of injecting water at various rates and recording the stabilized injection pressure that corresponds to the injection rate. The estimated duration of testing is two hours. Upon completion, results of the step -rate test will be forwarded to you. If you have any questions concerning this work, please feel free to call me at (907) 263- 7813. Sincerely, GarytA.Orr RE C E 11 V E D -T 19 ,, 1 J S UUT-W-96 MON 14:1U UNOCAL ASSET GAS GRP FAX N0. 9072637874 " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS P. 02/02 1. Type of Request Abandon: Suspend: _ Operation shutdown: Re-enter suspended well: Alter casing: _ Repair well: Plugging: Time extension: Stimulate: Chan a ap rovedprogram: Pull tubing., Variance: Perforate: Other: X Water Inject. Test 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or K13) Union Oil Company of California Development: X Exploratory: 150' RKB 123' G.L. feet 3. Address 7. Unit or Property name Stratigraphic: P.O. box 196247, Anchorage, Ak. 99519-6247 Service: Sotdotna Creek Unit 4. Location of well at surface 8. Well number 710' FNL, 660' FEL, Sec. 9, T7N, R9W, SM SC 41B-9 9. Permit number At top of productive Interval 612' FNL, 635' FEL, Sec. 9, T7N, R9W, SM 80-107 At effective depth 10. API number 592' FNL, 605' FEL, Sec. 9, T7N, R9W, SM 50-133-10129.02 11. Field/Pool At total depth 587' FNL, 579' FEL, Sec. 9, T7N, R9W, SM Swanson RiverlT onek Hemlock 12. Present well condition summary Total depth: measured 10928 feet Plugs (measured) 10520'- 10661' C true vertical 10918 feet VNIO180 Effective depth: measured 10834 feet Junk (measured) 10518' - Fish true vertical 10825 feet Casing Length Size Cemented Measured depth True vertical depth Structural 28' 20" Yes 28' 28' Conductor Surface 1988' 11-3/4" 1200 sx 3161' 3161' Intermediate Production 9910' 7" 1600 sx 9910'_ 9909' Liner 1324' 5" 175 sx 10,926' R r r FIVE Perforation depth: measured 10402'-10.420'; 10,506'-11,520; 10,538'- 10,547'; 10,720'- 10,732'; 10,746'- 10,768' true vertical 10,396'- 10,413% 10,499'- 10,513'; 10,630'- 10,639'; 10,71l'- 10,723' 10,737'- 10,759' Tubing (size, grade, and measured depth) 2-7/8"; 6.4#; L-80; 9636' 2-3/8"4.7* N-80; 10,661'- 10,786' 2-7/8" 6.4# L-80; 10,470'- 10,468' Packers and SSSV (type and measured depth) Baker "FH" 0 9527'; Baker SC -1 ® 10,470'; Baker SCIL ® 10,661' 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 10/9/96 Oil: X Gas: Suspended: 16. If proposal well verbally approved: Name of approver Date approved Service: 17. 1 hereby certify that the foregoinng� is true and correct to the best of my knowledge. Signed: i+! Title: Senior Petroleum Engineer Date: 10/06/96 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No. Plug integrity BOP Test Location clearance Mechanical Integrity Test ✓ Subsequent form required 10- If O unginai Signea 6y David W. Johnston ItIaLo) Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Approved COPY Return d -113 Form 3160-5 UNITED` kTES (JUNE 1990) DEPARTMENT 016i -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 Oil Gas Well [ Well ❑ Other Union Oil Companv of California (dba 3. P. 0. Box 196247, Anchorage, AK 99519 (907) 276-7600 . Location of Well (Footage, Sec., T., R., M., or Survey Descrip FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31, 1993 5. Lease Designation and Serial No. 6. If Indian. Allottee or Trine Name 7. If Unit or CA, Agreement Designation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. API Well No. 10. Feld and Pool, or Exploratory Area Swanson River Field Swanson River Unit -- 14 Wells 11. County or Parish, State Soldotna Creek Unit - - 7 Wells Kenai, Alaska 12. CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION [3 Notice of Intent ❑ Subsequent Report ❑ Final Abandonment TYPE OF ACTION ❑ Abandonment ❑ Recompletion ❑ Plugging Back ❑ Casing Repair ❑ Altering Casing E3 Other Temporarily Abandon ❑ Change of Plans ❑ New Construction ❑ Non -Routine Fracturing ❑ Water Shut -Off ❑ Conversion to Injection ❑ Dispose Water (Note: Report results of multiple conmpletion on Well Completion or Recompletion Report and Log form.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zone 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 1, 1996 to March 31,1997: Soldotna Creek Unit Swanson River 6C -);SRU Unit '.33 SRU 212-27 SCU 21-8 SCU 34-9 (p 1 _ y3 SCU 34-8 SCU 41B-9 (p�- j SCU 243-8 U 14-34 212-10 ' SRU 12-15 vo-144SRU 14-15 SRU 23-27 SRU 331-27 v4' S � v _9 $ SCU 13-9 (��-.� t? SRU 41A-15 SRU 34-28 X03-7. •- io i Hq SRU !SRU 14A 225 tom:?1q SRU 21 - SRU 33WD QPR 0 i 1996 $� ..101 7 V-17 SRU 23-22 SRU 24-33 -7 vZ` 7 kowsp * High GOR well that may be produced intermittently 14. 1 hereby certify the the foregoing is true and correct. Dennis L. Groboske signer40;rine Petroleum Engineer Date 3/29/96 __7A tff'r'_"_ - (This space for Federal an ffice use) Approved by roe Date Conditions of approval, if any: ritle 18 U.S.C. Section 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 statements or reoreserrttions as to anv matter within its iurisdiction. *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 Rate Potential P & A Shallow Gas Potential and `Hemlock Only' P&A SCU 34-8 SRU 212-10 SRU 12-15 SCU 243-8 SRU 212-27 SRU 41A-15 SCU 13-9 SRU 23-27 SCU 41 B-9 SRU 331-27 SRU 21-33WD SCU 14-34 SRU 34-28 SRU 43-28 7 Wells 2 Wells 5 Wells *.ugh GOR well that may be produced intermittently ,".I a l� Shut-in Wells during Field Blowdown Hemlock Future Shallow Gas Producer Producers with the Hemlock Abandoned SCU 21-8 SCU 34-9* 2 Wells SRU 14-15 SRU 43A-15 SRU 14-22 SRU 23-22 SRU 24-33 5 Wells ATTACHMENT 2 SWANSON RIVER FIELD r Wells with Temporarily Abandoned Status Change Removed from 1996 Temporarily Abandoned Status • SCU 34-4 Recompleted in Tyonek G1 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 2313-3 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 low rate oil producer. RtuvEDti APR 01 1996 Al ft Ot& Goa C". Cawriwion mdww Alaska Dear Ms. Miller: s Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCALID December 6, 1995 Ms. Joan Miller Statistical Technician Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Re: Soldotna Creek Unit - Well SCU 41 B-9 API Number 50-133-10129-02 On October 23, 1995 the following interval was perforated in Well 4113-9: BENCH TOP MD BOTTOM (MD) FEET G1 10,347 101367 20 Very truly yours, Candace Williams to mE IDcC AjaSka OU!, G25 COM- Anchorage Ot`t:.Anchorage STATE OF ALASKA' ALASKA OIL - ,SND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate PI in Perforate X — Pull tubing After casing Repair well Pull tubing Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development x UNION OIL COMPANY OF CALIFORNIA UNOCAL Exploratory Stratigraphic — 150' KB 123' G.L. feet 3. Address 7. Unit or Property name P.O. BOX 196247 ANCHORAGE AK 99519 - 6247 Service Soldotna Creek Unit 4. Location of well at surface 8. Well number 710' FNL, 660' FEL. Sec. 9, T7N, R9W, SM SCU 41 B-9 9. Permit number At top of productive interval 612' FNL, 635'; FEL, Sec. 9, T7N, R9W, SM 80-107/95-168 10. API number At effective depth 592' FNL, 605' FEL, Sec. 9, T7N, R9W, SM50-133-10129-02 11. Field/Pool At total depth ORIGINAL 587 FNL 579 FEL Sec. 9 WN R9W SM Swanson River/T onek Hemlock 12. Present well condition summary Total depth: measured 10928 feet Plugs (measured) 10520'-10661' CMT true vertical 10918' feet Effective depth: measured 10834 feet Junk (measured) 10518'- Fish true vertical 10825 feet Casing Length Size Cemented Measured depth True vertical depth Structural 28' 20" Yes 28' 28' Conductor Surface 1988' 11-3/4" 1200 sx 3161' 3161' Intermediate Production 9910' T' 1600 sx 9910' 9909' Liner 1324' 5" 175 sx 10926' 10918' Perforation depth: measured 10347-10376'; 10402-10420'; 10506-11,520'; 10538-10547'; 10720-10732'; 10746-10768' 1 true vertical 10340-10360'; 10395-10413'; 10499-10513'; 10530-10539'; 10711-10723'; 10737-10759' Tubing (size, grade, and measured depth) 2-7/8", 6.4# L-80 9636' 2-3/8' 4.7# N-8010661'-10786' 2-7/8" 6.4# L-8010470-10488' Packers and SSSV (type and measured depth) RECEIVE Baker "FH" 9527'• Baker SC -1 10470'• Baker SCIL 66 101' 13. Stimulation or cement squeeze summary Intervals treated (measured) OEC 13 1995 Treatment description including volumes used and final pressure Alaska Oil & G25 Con$. COMmi 14. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Data Tubing Pressure Prior to well operation 10/12/95 0 337 180 900 180 Subsequent to operation Shut In Shut-in 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil X Gas Suspended Service 17. 1 hereby certify that the foregoi g i and correct to e t of my knowledge. Signed G. Russell Schmidt ' itle Drilling Manager Date Form 10-404 Rev 06/15/88 y� SUBMIT IN DUPLICATE Spud: 9 89 ACU 41B-9 fop r"Rmiock:10491 Ft. MD Compleied:10/89 Swanson Riper Field Angie @Hemlock; 9 Deqs. Lasl Workover: 8/28/95 RPI No.: 50-133-10129-01 Hanger: Shaffer 10518.0 -10520.0' FISH 3.75" Mill 10520.0 -10661.0' CEMENT PLUG 10772.7 -10172.1' JOINT Marker 10834.0 -10926.0' CEMENT PLUG 10341.0 -10361.0' PERFS G-1,10/23 f 95,:6HPF, 201, 21/8" Enerjet Guns 10402.0 -10420.0' PERFS_ G-2,_9/�A.5,12HPF,18', 21 /8" Enerjet Guns, 90 Pha 10480.3 -10480.8' PLUG "PX" 10480.3 -10481.6' 2.313" ID IANDING NIPPLE Otis X 10470.0 -10419.6' PACKER Baker SC -1 Pkr, W/Retreiving Ext. 10470.0 -10481.7' 2.815" OD 6.50#/ft 1-80 TBG 10477.0 -10480.3' SAND PLUG Calcium Carbonate 10506.0 -10520.0' PERFS H-1, 4HPF,14', 4/90,10/90 10538.0 -10547.0' PERFS H-2, 4HPF, 9',11/90 10487.7 -10488.3' 2.441" ID REENTRY JOINT Baker WL Entry Guide 10678.0 -10678.0' SHEARSUB 43,0001 10678.0' CROSSOVER 10651.0' RETRV, PACKER Baker SC -11 Gravel Pack Pkr 10660.0' SLEEVE Model S 10185.0' GRAVEL Gravel Pack 10651.0 -10186.0' 2.315" OD 4.70/ff N-80 TBG 10120.0 -10132.0' PERFS MH -8, 4HPF,121, 2/90 10146.0 -10768.0' PERFS 1-1-1-8, 121-11`1`, 221, 9/25/89 10710.0 -10110.0' LANDING NIPPLE Otis X 10741.0 -10141.0' SCREEN 2 3/8" x .020" Gage Screen 10771.0 -10171.0' SEALS O -Ring Seal Sub 10772.0 -10172.0' TELLTALE SCREEN 2 3/8" x .020" Baker Telltale Screen 10785.0 -10785.0' SBA S-22 Snap Latch Seal Assy 10786.0 -10186.0' PACKER Baker D Sump Pkr KB ELEV: 21' Oil Well PBTD:10520' PerN 10/23/95 TD: 10926' REGEIVLU 0[c 13 1995 Alaska Oil & Cpm Cons. CoMirlission Anchorage Spud: 9 89 ,r.� SCU 41B-9 Top C'1-1Qm1ock:10491 Ff. MD Com pleled: 10/89 Swanson River Field Rr�yie @ Hemlock: 9 Degs. Last Workovers 8/28/95 API No.: 50-133-10129-01 Hanger: Shaffer 10518.0 —10520.0' FISH 3.75" Mil 10520.0 —10661:0' CEMENT PLUG 10347.0 —10367.0' PERFS G-1,10/23/95, 6HPF, 201, 21/8" Enerjet Guns 10402.0 —10420.0' PERFS G-2, 9/3/95,12HPF,181, 21 /8" Enerjet Guns, 90 Pha 10470.0 —10479.6' PACKER Baker SC -1 P4. W/Retreiving Ext. 10477.0 —10480.3' SAND PLUG Calcium Carbonate 10470.0 —10487.7' 2.875" OD 6.501/f t 1-80 TBG 10480.3 —10481.6' 2.313" ID IANDING NIPPLE Otis X 10480.3 —10480.8' P[UG "PX" 10487.7 —10488.3' 2.441" ID REENTRY JOINT Baker Wl- Entry Guide 10506.0 —10520.0' PERFS H-1, 4HPF,14', 4/90,10/90 KB EEE: 27' Oil Well PBTD:10520' Perf'd 10/23/95 TD: 10926' REC,E1Vt--U QEC 13 1995 Puska Oil & Gas Corts. Co€ mussion Anchorage STATE OF ALASKA --o ALA OIL AND GAS CONSERVATION COMM `ION REPORT OF SUNDRY WELL OPLHATIONS 1. Operations performed: Operation shutdown — Stimulate _ _ Plugging _ _ Perforate X_ Pull tubing x_ _ Alter casing_ Repair well Pull tubing _ OtherX__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X Union Oil Company of California Unocal Exploratory _ _ Stratigraphic _ 150' RKB 123' G.L. feet 3. Address 7. Unit or Property name P.O. Box 196247 Anchorage, AK 99519 Service Soldotna Creek Unit 4. Location of well at surface 8. Well number 710' FNL, 660' FEL, Sec. 9, T7N, R9W, SM SCU 41 B-9 9. Permit number/approval number 80-107/95-168 At top of productive interval ,. 612' FNL, 635'; FEL, Sec. 9, T7N, R9W, SM # < E r At effective depth 10. API number 592' FNL, 605' FEL, Sec. 9, T7N, R9W, SM 50-133-10129-02 11. Field/Pool At total depth 587' FNL, 579' FEL, Sec. 9, T7N, R9W, SM Swanson River/Tyonek Hemlock 12. Present well condition summary Total depth: measured 10928' feet Plugs (measured) 10520'-10661' CMT true vertical 10918' feet Effective depth: measured 10834' feet Junk (measured) 10518' – Fish true vertical 10825' feet Casing Length Size Cemented Measured depth True vertical depth Structural 28' 20" Yes 28' 28' Conductor Surface 1988' 11-3/4" 1200 sx 3161' 3161' Intermediate Production 9910' 7" 1600 sx 9910' 9909' Liner 1324' 5" 175 sx 10926' 10918' Perforation depth: measured 10,402'– 10,420'; 10,506'– 11,520'; 10,538'– 10,547'; 10,720'-10,732'; 10,746'– 10,768' true vertical 10,395'– 10,413'; 10,499'– 10,513'; 10,530'– 10,539; 10,711'– 10,723' 10,737'– 10,759' Tubing (size, grade, and measured depth) 2-7/8"; 6.4#; L-80; 9636' 2-3/8" 4.7# N-80 10,661'-10786' 2-7/8116.4# L-80 10470'-10488' Packers and SSSV (type and measured depth) Baker "FH" @ 9527' Baker SC -1 @ 10470' Baker SCIL @ 10661'r- r ' 13. Stimulation or cement squeeze summary K Intervals treated (measured) H-1 10506 –10520' and H-2 10539' –10549' OCT 3 Treatment description including volumes used and final pressure None Gil & Gas Cons. CoJiTitnlissIOQ 10 BBLS of 15.8 PPG Premium G cement AnChOM901 14. Representative Daily Average Production or Injection Data Oil–Bbl Gas–Mcf Water–Bbl Casing Pressure Tubing Pressure Prior to well operation 73 15,722 12 1070 2150 Subsequent to operation 0 109 319 920 150 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run__ Daily Report of Well Operations x _ Oil x Gas _ _ Suspended _ _ Service he best of my knowledge. 17. 1 hereby certify that the forg is a=re Signed G. Russell Schmidt Drilling Manager Date 10/05/95 Form 10-404 Rev 06/15/88 1 " SUBMIT IN DUPLICATE Spud: 9 89 SCU 416-9 Top of-�mlo�k:10491 Ff. MD Completed: 10/89 Swanson River Field Ai,y,, @ Hemtoek:9 De s. last Workover. 8/28/95 API No.: 50-1 �3-10129-01 Nagger: Shafer 0.0 - 28.0' 20" OD 94.001/ft CSG 0.0 -1998.0' 113/4" OD 40.50/f t SURF CSG 0.0 - 302:3' 1" 00 29.00/ft N-80 PROD CSG 302.3 -1238.2' 1" 00 26./ft N-80 PROD CSG 1238.2 - 4966.5' 1" OD 23.00/ft N-80 PROD CSG 4966.5 - 6122.0' 1" OD 26.001/ft N-80 PROD CSG 6722.0 - 9923.0' 1" OD 29.001/ft N-80 PROD CSG 9602.0 -10926.0' 5" OD 18.001/ft N-800 LINER 10518.0 -10520.0' f 1SH 3.15" Mill 10520.0 -10661.0' CEMENT PLUG 10834.0 -10926.9 CEMENT PLUG 21.0 - 9635.3' 2.815" OD 6.40111 [-80 TBG 10410.0 -10487.1' 2.815" 00 6.501/ft L-80 TBG 10651.0 -10186.0' 2.315" OD 4.10/ft N-80 TBG 9527.1- 9533.9' 5.697" OD 2.441" ID RETRY. PACKER Baker 4182 Pkr. W/50 Rota -10402:0 -10420.0' PERE G-21 9/3/95,12HPF,18', 21/8" Ener] t Guns, 90 Phc 10470.0 -10419.6' PACKER Baker SC -1 Pkr. W/R* iviq Ext. 10411.0 -10480.3' SAND PLUG Calcium Carbonate 10480.3 -10480.8' PLUG "PX" 10506.0 -10520.0' PERE H-1, 4HPF,14', 4/90,10/90 10538.0 -10541.0' PERFS H-2, 4HPF, 9,11/90 10651.0 -10651.0' RETRV. PACKER Baker SC -1L Gravel Pack Pkr 10120.0 -10132.0' PERE MH -8, 4HPF,121, 2/90 10746.0 -10168.0' PERE 111-8,12HPF, 22', 9/25/89 10786.0 -10186.0' PACKER Baker D Sump Pkr KB ELEV: 27' PUT0:10520' Oil Well 1100 Peq'd 9/3/95 OCT 13 1995 Alaska Oil & Gas Cons. Commission Anchorage Spud: 9 89 Completed: 10/89 last Workover: 8/28/95 0.0 - 28.0' 20" OD 94.001/ft CSG 0.0 -1998.0' 113/4" 0D 40.5q/0 SUS CSG 1998.0 - 199 Y SHOE 0.0 3023 T' OD A-001/4 N-80 PRS} CSG SCV41B9 Swanson River Field PI Na.: 50-1M-10.129-01 Top of 4-mlock:10491 Ft. MD Aiiy,� 0 Hemlok: 9De gs. Hanger: Shaf er 21.0 - 9635.3' 2.815" OD 6.401/ft L-80 TBG 27.0 - 28.9 HANGER Shaffer 302.3 1238.2' 1" OD-26.001/ft N-80 PROD CSG 1238.2 - 4966.5' 7" OD 23.0q/ft N-80 PREF CSG 44512.6 - 4519.3' 2.347" ID Gk%ff VALVE�9, Cama KBKUM W/BK-2 Latch 4966.5 6122.4' 1" OD 26.OQ /ft N-84 PROD CSG 514T 0 - 5107.9 2.341" ID GaffVALVE.18, Camco KB K-2 latch 6122.0 - 9923.4' I" OD 29.001/ft N-80 PROD CSG 5711.4 - 5724.0' 2.341" ID M VALVE 17, Caw KBMM'-U W/BK-2 latch 9; L 6298.0 - 63044.6' 2.347" ID MR VALVE 16, Cam KBIT Gly W/BK-2 Latch �:. 0 C T 13 19'95 6908.8 - 6915.4' 2.347" ID GASUR VALVE 15, Camco KBM M GLIA W/BK-2 Latch Alaska Cit & Gas Cons. Commission Anchorage 1520.9 -1521.5' 2.341" ID GA ff VALVE 14, Cam KBMM GLS W/ BK -2 Latch 1570.0 --15129 STS 8M8.8 - 8105..3' 2.347" ID M VALVE 13, Cavo KBMM . W/BK-2 Lath :x 8711,4 - 8111.8' 2.341" ID G�iJE1 VALVE 2, Camco KB�I GL�1 W BK -2 Latch 9321.8 - 9328.3' 2.347" ID X Ff VALVE 1, Coca KBiN.QkW/BK-2 Latch 9602.4 - 9618.x' H�fVGER Baker 2 W lice__W / 9521.1- 9533.9' 5.697" OD 2441" 1D RETRY. PACKER Baker 47BZ Pkr. W/50 Roto 991.1'2.313'0 UVB NIPPLE. Baker 9 - io 9023.4` SHOE 9636.0' 2.441" D REM JOINT Baker WL *-W.: W10524t: TDrT{2 Pend 93/95 e� • ' Spud: 9 89 SCU 41 B-9 Top 0'400110491 Ff. MD Completed: 10/89 Swanson River Field wiye 0 Hemlock: 9 De s. Last Workover: 8/28/95 API No.: 50-133-10129-01 Hanger: Shaf er 10518.0 -10520.(' FNi 3175" Mill 10520.0 10661.9 CW PLUG 10112.7 -10112.7' fig Marker v� PBT�:=10� Tf 109Y 10402.0 -10420.0' PERFS G-2,9/3/95, 12HPF, 181, 21 /8" hrjet Guns, 90 Pho 10480.3 -10481.6' 2.313" ID LANDING NIPPLE Otis X 10471.0 -10480.3' SAND PLUG Calcium Carbonate 10410.0- 1091.7 2.875" OD 6,501/11 L-80 TBG 10470.0 -10479.6' PACKER Baker SC -1 Pkr. W/Retreiving Ext. 10506.0 -10520.0' PERE H-1, 4HPF,1411 4/90,10/90 106.3- 104@3 PLUG "PX" 10538.0 -.10541.9 PERFS H-2, 4HPF, 9,11/90 10481.7 -10488.3' 2.441" ID REENTRY JOINT Baker WL Entry Guide 10678.0 -10618.0' CROSSOVER 10651.0 -10651.0' RETRY. PACKER Baker SC -1L Gravel Padc.Pkc 10660.0 -10660.0' SLEEVE Model S 10660.5 -10785.0' GRAVEL Gravel Pack 1%61.0- 10661.9 SBA 10651.0 -10186.0' 2.375" OD 4.701/ft N-80 TBG 10720.0 -101319 PERE MH -8, 4HPF,12', 2/90 10678.0 -10618.0' SHEARSUB 43,0001 10746.0 -10768.0' PRE LH-8112HPF, 22', 9/25/89 10110.0- 10710.9 LANDING NIPPLE Otis X 10741-0- 10741.9 SCREEN 2 3/8" x .020" Gage Screen �, 10771.0 -10R[Y SEALS 0 -Ring Seal Sub 10712.0 -10772.1' TELLTALE SCREEN 2 3/8" x .020" Bakery TeRde Screen 10785.0- 10785.9 SBA 5-22. Snap latch Seal Assy 10786.0- 10786.9 PACKER Baker D Sump Pkr L I v 1OCT 'I3 1915 Alaska: Uel & Gas Cons. Commission Anchorage oil Well Ped 9/3e/95 SRU 41 B-9 DAY 1 - 2 (08/19/95 - 08/20/95) COMPLETE RIG MOVE. RIG ACCEPTED AT 00.00 HRS ON 08/19/95. N/D TREE. ANNULUS PRESSURE AT 300 PSI. NIPPLE UP BOP. M/U LANDING JOINT. CIRCULATE AROUND 8.5 PPG LEASE WATER. LOST RIG PUMP AND HAD PROBLEMS WITH THE GAS BUSTER. R/U VECO GAS BUSTER HAUL WATER AND COMPLETE WELL KILL PROCEDURE. LOSSES OF 12 BPM NOTED. SPOTTED A 10 BBL PILL OF LIQUID CASING ON BOTTOM. SQUEEZED PILL INTO PERFS WITH 2000 PSI. CIRCULATE BOTTOMS UP. WELL STATIC. TEST BOP. CHECK WELL PRESSURES OK. BACK OUT LOCK DOWN PINS. PULL HANGER FREE WITH 100 K LBS. STRING WEIGHT OF 86K LBS. P/U 30 FT. SHUT WELL IN AND CIRCULATED THRU' CHOKE BOTTOMS UP. WELL STATIC. L/D HANGER AND LANDING JOINT. POOH WITH COMPLETION STRING. FULL RECOVERY 10,351'. SET WEAR BUSHING. M/U SPEAR ASSEMBLY. DAY 3 (08/21/95) CONTINUE P/U SPEAR ASSEMBLY. RIH PIU 3 1/8" DC AND 2 7/8" PAC DP. RIH WITH 3 1/2" TUBING. BLEW HOSE ON COOLING SYSTEM FOR BRAKE COOLING WATER. REPAIR SAME. CONTINUE RIH WITH SPEAR TO 10,370'. BREAK CIRCULATION, ENGAGE PACKER AT 10,377'. PACKER CAME FREE WITH LIGHT JARRING. CIRCULATE THE WELLBORE. POOH WITH THE PACKER AND TAILPIPE ASSEMBLY. DAY 4 (08/22/95) CONTINUE POOH WITH PACKER AND TAILPIPE ASSEMBLY. L/D TOOLS. P/U 4 1/8" MILL FOR CLEAN OUT ASSEMBLY AND RIH. C/OUT AS REQ'D F/10520'-10663'. CBU. POOH. DAY 5 (08/23/95) POOH W/ 4-1/8" MILL AND 7" CSG SCRAPER. CHANGE LOWER PIPE RAMS AND TEST TO 250/51000 PSI. SET WEAR RING. RACK AND TALLY 2-3/8" TBG. PU MULE SHOE STRINGER AND RIH TO 101661'. CIRC. PUMP 10BBL BALANCED CEMENT JOB. PULL UP TO 9,924'. REVERSE CIRC. L. .- L r OCT 13 191D5 Alaska Oil & Gas Cons. Commission Anchorage DAY 6 (08/24/95) SQZ CEMENT @ 0.5 BBL/MIN WITH 2200 PSI. 5 BBL SQUEEZED IN TOTAL. HELD PRESSURE FOR 1 HOUR PRESSURE BLEED TO 1300 PSI. R/D HALLIBURTON. POOH WITH WORK STRING. P/U CLEAN OUT ASSEMBLY AND RIH TO 10,245'. TAGGED CEMENT STRINGER. CONTINUE RIH. TAGGED FIRM CEMENT AT 10,300'. DRILLED CEMENT TO 10,400'. TESTED CASING TO 3000 PSI FOR 15 MINS. TESTED OK. CONTINUE DRILLING FIRM CEMENT. DAY 6 (08/24/95) CONTINUE DRILLING FIRM CMT TO 10,520'. WORK ON TIGHT SPOT AT 10,520'. HIGH TORQUE AND OVER PULL NOTED. PUMP HI-VISC SWEEP AND CIRC OUT. M/U BHA#5 W/SMALLER MILL (3-3/4"). RIH. MADE APPROX. 1 FT, UNABLE TO MAKE ANY MORE HOLE. PUMP HI -VIS SWEEP AND CIRC OUT. (NO METAL OR FORMATION IN RETURNS). POOH FOR NEW ASSEMBLY. ON SURFACE DISCOVERED THAT JARS HAD PARTED LEAVING 3.5' FISH IN HOLE. M/U BHA #6, OVERSHOT ASSEMBLY AND RIH. TAGGED TOF AT 10,520'. ATTEMPTED TO WORK OVER TOP OF FISH. POOH. NO RECOVERY, DAMAGE NOTED ON OUTSIDE OF OVERSHOT. L/D EXCESS DRILLPIPE FROM DERRICK. R/U SCHLUMBERGER TO RUN GR TO CK DEPTH OF HEMLOCK BENCHES AND TOP OF FISH. RIH W/5" BAKER "SC" PACKER. SET PACKER @ 10470'. RIH W/3-1/8" DC ON 2-7/8" TBG. DAY 10 (08/28/95) RIH 3-1/2" TUBING. L/D 3-1/2" TUBING. PULL WEAR BUSHING. TEST BLIND RAMS. TEST 7" CSG TO 3000 PSI FOR 30 MINUTES. OK. SET TEST PLUG. CHANGE TOP PIPE RAMS. TEST TO 250/5000 PSI. RU AND RUN 2-7/8" COMPLETION. DAY 11 (08/29/95) CONT. RIH W/ 2-7/8" COMPLETION. RUN-IN LOCK DOWNS AND DISPLACE ANNULUS W/CORROSION INHIBITOR. PRESSURE UP ON TBG AND SET PACKER @ 1500 PSI. TEST TBG TO 4000 PSI. RU SLICKLINE AND PULL STANDING VALVE. TEST PACKER TO 3000 PSI FOR 30 MIN. OK. SET BPV. ND BOP NU TREE. TEST TREE TO 5000 PSI. RD AWS RIG 5. OCT 13 19"'3 Alaska Oil & Cas Cons. Commission Anchorage DAY 12 (08/30/95) STACK RIG ON LOCATION AND RELEASE RIG 8/30/95 @ 03:00 HRS. PREPARE LOCATION AND WELL FOR COILED TUBING DISPLACEMENT. DAY 13 (08/31-9/03/95) WAIT ON WELL PREPARATION. RU ARCTIC CTU. PRESS. TEST BOPE. PULL TEST CONNECTOR. RIH W/ CT. DISPLACE WELL WITH 110 BBLS OF DIESEL. POOH W/ CT. RD CTU. MIRU SCHLUMBERGER WIRELINE UNIT. PRESSURE TEST LUB. HOLD SAFETY MTG. PU & RIH W/ 2-1/8" ENERJET 6 SPF 90 PHASED 18' PERF GUN. MAKE TIE-IN PASS AND CORRELATE GUN. PERFORATE TYONEK @ 10,402'-10420'. TBG = 0 PSI BEFORE AND AFTER. PU 18' OF GUN. RIH TBG = 1000 PSI. GUNS ON BTM TBG = 1800 PSI. PERFOATE @ 10,402'-10420'. POOH W/ GUNS TBG = 1600 PSI. TURNED WELL OVER TO PRODUCTION @ 21:30. •k 10 Ralph P. Holman Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-6247 August 31, 1995 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Douglas: This is to inform you of Unocal's intent, upon your approval, to perforate the following intervals in well SCU 4'B-9 (API # 50-133-10129-01) in the Swanson River Field. BENCH TOP (MD) BOTTOM (MD) FEET G2 10,402' 103-420' 18' TOTAL 18' Sincerely, r RE ED SEP 22 1995 x►aska 01 & Gas Cons. Commission Anchorage STATE OF ALASKA ALAS l AND GAS CONSERVATION CC IISSION APPLICATION FOR SUNDRY APeROVALS 1. Type of request: Abandon _ Suspend _ Operations shutdown— Re—enter suspended well_ Alter casing_ Repair well _ Plugging _ 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) Unocal Development X__ RKB: 150' Exploratory _ Stratigraphic _ feet 3. Address 7. Unit or Property name P.O. Box 196247 Anchorage, Alaska 99519-6247 Service Soldotna Creek Unit 4. Location of well at surface 8. Well number 710" FNL, 660' FEL, Sec. 9, T7N, R9W, SM SCU 41B-9 9. Permit number At top of productive interval „ORIGINALO FEL Sec.9 T7N R9W SM 612 FNL, , 8'i'635 i� l 10. API number 0j! At effective depth 592' FNL, 605' FEL, Sec. 9, T7N, R9W, SM 50-133-10129-,4W 11. Field/Pool At total depth 587' FNL, 579' FEL, SEc. 9, T7N, R9W, SM Swanson River/Hemlock 12. Present well condition summary Total depth: measured 10928 feet Plugs (measured) 10480 true vertical 10918 feet Effective depth: measured 10834 feet Junk (measured) true vertical 10825 feet Casing Length Size Cemented Measured depth True vertical depth Structural 28' 20" Yes 28' 28' Conductor Surface 1998' 11-3/4" 1200 sx 3161' 3161' Intermediate Production 9910' 7" 1600 sx 9910' 9909' Liner 1324' 5" 175 sx 10926' 10918' Perforation depth: measured 10746-10768,10720-10732,10506-10520,10538-10547 true vertical 10737-10759,10711-10723,10499-10513,10530-10539,. R,� L l , 'E D Tubing (size, grade, and measured depth) 2-7/8" @ 9636' SEP 22 1995 Packers and SSSV (type and measured depth) Baker FH @ 9527' Alaska Uli & Gas Cons. Commission 13. Attachments Description summary of proposal X_ Detailed operations program_ BOP s orage 14. Estimated date for commencing operation 15. Status of well classification as: 9/1/95 Oil X__ Gas _ Suspended _ 16. If proposal was verbally approved Blair Wondzell 9/5/95 Name of approver Date approved Service 17. 1 her y c rtify th a ew going ' ue and correct to the best of my knowledge. � C 9 Is (C1s Signed Title -`��1� ` t Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness ApprovEll Plug Integrity BOP Test Location clearance _ � 4! _ _ 10 Mechanical Integrity Test_ Subsequent form required — ff O Approved Copy Original Signea By Returned Approved b the order of the Commission David W. Johnston Commission r ate Z - Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ARCO Alaska, Inc. Post Office Bait -.v0360 Anchorage, Alaska 99510-0360 Telephone 907 2761215 Cook Inlet Engineering May 5, 1992 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Submittal of Subsequent Report for SCU 41B-9. Dear Mr. Smith: ORIGI it ,] lor In March 1992 ARCO Alaska, Inc. canceled the perforation of SCU 41B-9 H3 sands from 10571'-10581'. This was due to the communication from a lower gas producing zone. If you require any further information in this regard, please call Jim Zernell at 263-4107. Sincerely, J.C. Winn Acting Regional Engineer JCW:DRH:j1g:0139 RECtEIVEJ) Attachment MA Y ' Alaska Gi/ 2 1992 cc: Mr. W. Watson Marathon Oil Company .& Gas Co Mr. B. C. Dehn UNOCAL Corporation Achol� �omr�j�jp�} 9. ARCO Alaska, Inc. Is a Subsidiary of Atlantic Richfield Company 811611141t STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 . Type of Request: Operation Shutdown Stimulate Plugging Perforate _ X Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator S. Type of Well: 6. Datum elevation (DF or KB) Development X_ ARCO Alaska. Inc. Exploratory _ RK13 150' feet 3. Address Stratigraphic _ 7. Unit or Property name P.O. Box 100360, Anchorage, AK 99510 Service _ Soldotna Creek Unit 4. Location of well at surface 8. Well number 710' FNL, 660' FEL, Sec. 9, T7N, R9W, SM SCU 41 B-9 At top of productive interval 9. Permit number/approval number 612' FNL, 635' FEL, Sec.9, T7N, R9W, SM 92-033 At effective depth 10. API number 592' FNL, 605' FEL, Sec.9, T7N, R9W, SM so -1 33-1 01 29-0x2 At total depth 11. Field/Pool 587' FNL 579' FEL Sec.9 T7N R9W SM Swanson River -Hemlock 12. Present well condition summary Total Depth: measured 10928' feet Plugs (measured) true vertical 10918' feet Effective depth: measured 10834' feet Junk (measured) true vertical 10825 feet Casing Length Size Cemented Measured depth True vertical depth Structural 28' 20 Yes 28' 28' Conductor Surface 1998' 11-3/4" 1200 sx 3161' 2751' Intermediate Production 9910' 7" 1600 sx 9910' 9909' Liner 1324' 5" 175 sx 10926' 10918' Perforation depth: measured 10506'-10520', 10538'-10547', 10720'-10732, 10746'-10768' Proposed perforations true vertical 10571'-10581' 10499'-10513', 10530'-10539', 10711'-10723', 10737'-10759' were canceled Tubing (size, grade, and measured depth) 3-1/2" @9528' MD; 2-3/8" from 9528'-10442' MD Packers and SSSV (type and measured depth) RECEIVED Packers: Baker FH @ 10397' Baker SC IL @ 10651' 13. Stimulation or cement squeeze summary MAY 121992 Intervals treated measured N/A Alaska Oil &Gas Cons. Comate Treatment description including volumes used and final pressure Anchorage] 14. Representative Daily Average Production or Iniection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent tooperation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Y— Oil —2L Gas Suspended Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. `�'`-v� .Signed G Title Acting Regional Engineer Date 'ds 9 L Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE At K di Arco Alaska Inc. -Swanson River BCU 41 B-9 a 133-10129-01 Xll Type: Producer Spud Date: 9/89 Completion Date: 10/89 lust Workover: Original RKB: 27' Hanger Type: Schaffer Hanger: Grace Top of Hemlock: 10,491'MDMax. Hole Angle: 100 Angie @Hemlock : 90 All I Depths are 'A F s "Im LI• RKB I MD to Top of Equipment. Jewelry Data laierval Depth Eauipment LjL 0. D, 1 29' 31/2" X -Over Butt Box x 31/3" EUE 8R Pin 10,538'-10,547' H2 2 1997' 31/2" x 1" Camoo GUM KBUG We Type DV BK -2 latch MH8 3 9528' 31/2" X -Over Butt Box x 2 3/8" EUE 811 Pin 2.00" 4.50" 4 10,344' 2 31W x 1" TMPDX GLM w/CV & BK -2 latch 5 10,385' 2 3/8" X -Over EUE Mod Box x 2 7/8" EUE 8R Pin 1.99" 2.875" 6 10,386' Baker 40-26 P.B.R. 1.99" 4.078" 7 10,397' Baker "FH" Pkr 40,000# Shear 1.99" 4.125" 8 10,434' Otis "X" Nipple (1.875" I.D.) 1.875" 3.078" 9 10,441' Baker W/L Entry Guide 10 10,561' Baker "SC -1 L" Gravel Pack Pkr. 2.688" 4.125" 11 10,660' Model "S" Sliding Sleeve 2.688" 3.93" 12 10,661' Seal Bore 2.688" 3.81" 13 10,678' X -Over Sub 2.00" 3.812" 14 10,678' 2 3/8" Shear Out Safety Jnt. (43,000#) 2.00" 3.00" 15 10,710' Otis "X" Nipple 1.87" 2.70" 16 10,741' 2 3/8" x .020" Gage Screen 1.95" 3.046 17 10,771' 2 3/8" x 1.35" O -Ring Seal Sub 1.315" 2.875" 18 109772' 2 3/8" x .020" Gage Baker Tel Tail Screen 1.95" 3.046" 19 10,785' Model "S-22" Snap Latch Seal Assembly 2.00" 3.375" 20 10,786' Baker Model "D" Sump Pkr. 2.688" 3.937" Casing and Tubing size Weight Grade T= Bottom Desserinti_on_ 20" 94# 0 28' Conductor Pipe 11 3/4" 40.5# 0 1998' Surface Casing 7" 26-29# N-80 0 2994' Production Casing 7" 23# N-80 2994' 4967' Produckon Casing 7" 26# N-80 4967' 6722' Production Casing 7" 29# N-80 6722' 9923' Production Casing 5" 18# N-80 9602' 109926' Liner 31 /2" 9.3# J-55 0 9528' Tubing 2 3/8" 4.7# N-80 9530' 10,442' Tubing Perforation Data laierval Zone EI SPE 10,506'-10,520' 1-11 14' 4 10,538'-10,547' H2 9' 4 10,712'-10,720' MH8 8' 1 10,720'-109732' MHS 12' 4 10,746•.,0,768" RECEIVEb Date 4/90 11/90 3/90 2/90 9/25/89 M.4y 121992 PBTD =10,834' 10,926' �tamissito�► TD = s�ca Oil AL Gas Cans. . Co 1Rn*a_ra9e1 Comments Reperf'd 10/90 Plug covers Plug covers Plug covers �Q(gj j SCU41 B-9 By. JKW 11/21/90 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate Change approved program _ Pull tubing _ Variance _ Perforate _X_ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska. Inc. Exploratory _ RK13 150' f eat 7. Unit or Property name 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service Soldotna Creek Unit 4. Location of well at surface 8. Well number Proposed 710' FNL, 660' FEL, Sec. 9, T7N, R9W, SM SCU 41 B-9 9. Permit number At top of productive interval 612' FNL, 635' FEL, Sec. 9, T7N, R9W, SM 10. API number At effective depth 592' FNL, 605' FEL, Sec. 9, T7N, R9W, SM33-1 0129-01,7= 11. Field/Pool At total depth 587' FNL 579' FEL Sec. 9 T7N R9W SM Swan rLftqUU rglw,,L 12. Present well condition summary P t (. t I V t L) Total Depth: measured 10928' feet Plugs (measured) true vertical 10918' feet �A A R -- 41992 Effective depth: measured 10834' feet Junk (measured) true vertical 10825' feet Alaska Gil & Gas Cons. CoMMISS10"' Casing Length Size Cemented Measured deptlAi nWaN tical depth Structural 28' 20" Yes 2 8' 28' Conductor Surface 1998' 11 3/4" 1200 sx 3161' 2751' Intermediate Production 9910, 7" 1600 sx 9910, 9909, Liner 1324' 591 175 sx 10926' 10918, Perforation depth: measured 10506'-10520',10538'-10547',10720'-10732',10746-10768' MD Proposed: 10571'-10581' true vertical 10499'-10513',10530'-10539',10711'-10723',10737'-10759' TVD Proposed: 10562'-10572' Tubing (size, grade, and measured depth 3 1/2" @ 9528' MD; 2 3/8" from 9528' - 10,442' MD Packers and SSSV (type and measured depth) Packers: Baker FH @ 10,397', Baker SC IL @ 10,651' 13. Attachments Description summary of proposal _ Detailed operation program X BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: March 15. 1992 Oil X Gas _ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service _ 17. 1 hereby ceMfy that the foregoing is true and correct to the best of my knowledge. '} Signed �'��Ll t Title Cook Inlet Regional En r. Date 5 Z FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness (Approval No. Plug integrity _ BOP Test Location clearance _ Mechanical Integrity Test _ Subsequent form require 10- ORIGINAL SIGNED BY ---3_7_l ,Approved by the order of the Commission i nNiNur: r (ut,11T14 Commissioner Date Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE W ftAf fly SCU 41B-9 PERFORATION PROCEDURE Updated: February 24, 1992 PERFORATING PROCEDURE Prior to Perforating 1. Contact Anchorage office to verify sundry approval before proceeding. 2. Shoot fluid level in tubing to verify liquid level is several hundred feet above perforated interval. Load tubing with crude if necessary. E -Line Perforating 1. Conduct safety meeting with appropriate personnel. Obtain diagram of the tool string prior to commencing work. 2. Make-up tool string of adequate weight bars, 10' section of 1-11/16" Expendable Strip Guns @ 4 SPF and 0° phasing, decentralizer, and CCL. 3. RIH with well shut-in, and tie into Atlas Wireline Services PDK-100 Log dated 9/22/89 using CCL. NOTE: PDK-100 Log is on depth with DII.. 4. Position gun section at the PDK-100 depth shown below and fire: Gun No.,Interval (PDK-100) Footage (ft) ,fid 1 10571-10581' 10 H3 5. POOH. Confirm that all shots have fired. Repeat the gun run if necessary. 6. RD E -line unit. 7. Return well to production on current choke setting. Test wells on days 1, 3, and 5 following perforation. M.O. Hamilton Cook Inlet Engineering Ph: 263-4384 RECEIVED 1AAR - 41992 Alaska Oil & Gas Cons. Commissloh Anchorage ARCO Alaska, Inc. Post Office Box . ,0360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering December 12, 1990 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: -� ORIGiNAI 11 OF Attached are Application's for Sundry Approval requesting name changes and new API numbers for the following sidetracked wells as discussed in phone conversations between C. M. Baker and L. C. Smith on 12/3/90: Old SCU 41A-9 SCU 33-8 SCU 32A-9 New SCU 41B-9 SCU 33A-8 SCU 32B-9 If you have any questions or need additional information, please contact C. M. Baker at 263-4643. Sincerely, T. Wellman Regional Engineer TW:jkw:0012 Attachment cc: Mr. A. R. Kukla Marathon Oil Company Mr. B. C. Dehn UNOCAL Corporation RECEIVED DEC 19 1990 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company *b X 11 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown , Re-enter suspended well _ Alter casing _ Repair well _ Plugging , Time extension _ Stimulate _ (Name Change approved program _ Pull tubing _ Variance Perforate — Other-X_Change) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development J„ ARCO Alaska. Inc. Exploratory _ RKB 1500feet 3. Address Stratigraphic _ 7. Unit or Property name P.O. Box 100360, Anchorage, AK 99510 Service Soldotna Creek Unit 4. Location of well at surface S. Well number Proposed 710' FNL, 660' FEL, Sec. 9, T7N, R9W, SM SCU 41 A -9 - At top of productive interval 9. Permit number — Q '� 612' FNL, 635' FEL, Sec. 9, T7N, R9W, SM 10. API number At effective depth 592' FNL, 605' FEL, Sec. 9, T7N, R9W, SM a 3-/012 11. Field/Pool At total depth 587' FNL 579' FEL Sec. 9 T7N, R9W SM Swanson River/Hemlock 12. Present well condition summary Total Depth: measured 10,928' feet Plugs (measured) true vertical 10,918' feet Effective depth: measured 10,834' feet Junk (measured) true vertical 10,825' feet Casing Length Size Cemented Measured depth True vertical depth Structural 28' 20" Yes 2 8' 28' Conductor Surface 1998' 11 3/4" 1200 sx 3 16 1 ' 2751' Intermediate Production 9910, 7" 1600 sx 9910, 9909, Liner 1324' 5N 175 sx 10926' 10918, Perforation depth: measured 10,506'-10,520', 10,538'-10,547, 10,720'-10,732', 10,746-10,768' MD RECEIVED true vertical 10,499'-10,513', 10,530'-10,539', 10,711'-10,723', 10,737'-10,759' TVD Tubing (size, grade, and measured depth DEC 19 1990 3 1/2" ar 9528' M D; 2 3/8" from 9528' - 10,442' MD Alaska Oil & Gas Cons. Comm Packers and SSSV (type and measured depth) Packers: Baker FH C& 10,39T, Baker SC IL 10,651' Anchorage 13. Attachments Description summary of proposal _ Detailed operation program _ BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: Oil X Chas Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service _ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Cook Inlet Regional En r. Date is -/z-9 v FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness (Approval No. Plug integrity BOP Test _ Location clearance _ '- Mechanical Integrity Test _ Subsequent form require 10- /f/ d?" J e- -Tn 9� !� �ti w► 6c.r Gym e ,Approved by the order of the Commission Commissioner Date V Form 10-403 Rev 5/03/89 Approved COPY turn d � 6 ORIGINAL SIGNED BY LONNIE C. SMITH SUBMIT M TRIPLICATE ►sion -7 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering November 15, 1990 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached is an Application for Sundry Approval on SCU 41A-9 (ARCO SCU 4113-9) for perforating the H2 interval. The requested interval is 10,538' - 10,547' MD (10,530' - 10, 539' TVD) . If you have any questions please contact Stacy L. Strickland at 263- 4914. Sincerely, T. Wellman TW jkw:0005 Attachment cc: Mr. A. R. Kukla Marathon Oil Company Mr. B. C. Dehn UNOCAL Corporation NDy 191gg0LOW Alaska9al�,� oca� ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company R9 NO STATE OF ALASKA _. a ALASKA OIL AND GAS CONSERVATION COMMISSION } OPPI (CATION FOR SUNDRY APPROVALS .t 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing ! Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program Pull tubing _ Variance _ Perforate _X Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska. Inc. Exploratory _ Stratigraphic _ feet 3. Address 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Soldotna Creek Unit 4. Location of well at surface 8. Well number 710' FNL, 660' FEL, Sec. 9, WN, R9W, SM SCU 41A -9 - 9. Permit number At top of productive interval 612' FNL, 635' FEL, Sec. 9, WN, R9W, SM 10. API number At effective depth 592' FNL, 605' FEL, Sec. 9, T7N, R9W, SM so -133-10129-01 - - 11. Field/Pool At total depth At 587' FNL 579' FEL Sec. 9 T7N R9W SM Swanson River/Hemlock 12. Present well condition summary Total Depth: measured 10,928' feet Plugs (measured) RECEIVED true vertical 10,918' feet Effective depth: measured 10,834' feet Junk (measured) NOV 19 1990 true vertical 10, 8 2 5' feetW '� & Gas Goes. .iska� Casing Length Size Cemented Nf"as 'rue vertical depth Structural 28' 20" Yes 28' Conductor Surface 1998, 11 3/4" 1200 sx 3161' 2751' Intermediate Production 9910, 7" 1600 sx 9910, 9909, Liner 1324' 5" 175 sx 10926' 10918, Perforation depth: measured 10,746'-10,768', 10,720'-10,732', 10,506'-10,520' MD; Proposed: 10,538'-10,547' MD true vertical 10,737'-10,759', 10,711'-10,723, 10,499'-10,513' TVD; Proposed: 10,530'-10,539' TVD Tubing (size, grade, and measured depth 3 1/2" @ 9528' MD; 2 3/8" from 9528' - 10,442' MD Packers and SSSV (type and measured depth) Packers: Baker FH @ 10,39T, Baker SC IL @ 10,651' 13. Attachments Description summary of proposal _ Detailed operation program , BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: November. 1990 Oil X Gas Suspended _ 16. if proposal was verbally approved Name of approver Date approved Service _ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Si ned 7Xc 1VGffA44)1_ Title Cook Inlet Re ional En r. Date 1/ /s ga FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness (Approval No Plug integrity BOP Test _ Location I� clearance09tIntegrity 4c Test SubsequeAIteEC�- _ ,Approved by the order of the Commission Commissioner Date V Form 10-403 Rev 5/03/89 WK21119M. OUDMI 1 1114 1 niruvM I LONNIE 0• SMITH \� 11 r SCU 41B-9 Perforate H2 Procedure Objective: To add perforations in the H2 interval and increase well production. Well Data: Completion: Tie-in Log: Minimum Restriction: Tubular Capacities: Pressure Data: Procedure: 3-1/2" tbg to 9528' MD, 2-3/8" tbg to 10,441' MD GP pkr, blank pipe & screen from 10, 561' MD PDK 100 (9/22/89) Otis 'X' Nipple @ 10, 434' MD (1.875" ID) 3-1/2" tbg = .0087 Bbl/ft; 2-3/8" tbg = .00387 Bbl/ft Tbg = 2700 psi; PC = 1040 psi; SC = 2 psi Note: Make a 1.75" gauge ring run to 10,580' MD to assure that there is adequate clearance for perf guns prior to RU conductor line. • Assure that Sundry approval has been obtained prior to perforating. 1. Hold safety meeting with all appropriate personnel. 2. MIRU conductor line. Pressure test lubricator to 4000 psi. 3. Shut-in well. RIH with perf gun/CCL. Tie-in to pert interval: PDK 100 (9/22/891 Footage Sand SPF 10,538-10,547' MD 9' MD H2 4 Hole Hole Company Gun Type Qun Sim Depth Diameter Schlumberger Enerj et Strip 1-11 / 16" 7.35" .34" Atlas Silver Jet 1-11/1611 8.09" .33" Halliburton DynaStrip 1-11/1611 7.5 0" .40" NOTE: Gun orientation should be down (at hole bottom) . 4. Perforate interval. POOH ASAP going slowly until through 3-1/2" x 2- 3/8" crossover. 5. Check gun to confirm that all shots have fired. RDMO. 6. Return well to production ASAP in the 900 psi system on current choke. Test on days 1, 3, and 5. ARCO Alaska Inc. is a subsidiary of Atlantic WNW Company AR3B-6001-A 4 A 17 ska Inc. - Swanson SCU 41 B-9 AI•-sif. 133-10129-01 Spud Date: 9/89 Completion Date:10/89 'original RKB: 27' Hanger Type: Schaffer .op of Hemlock: 10,491'M DMax. Hole Angle: 100 All Depths are RKB MD to Top of Equipment. 1- J Ri , .:r ' - old Well Type: Producer Last Workover: Hanger: Grace Angle @Hemlock : 90 Jewelry Dem Equipment LIL 0.D. 1 29' 3 1/2" X -Over Butt Box x 31/3" EUE 813 Pin 2 1997' 31/2" x 1" Camco GLM KBUG WE' Type DV BK -2 latch 3 9528' 31/2" X -Over Butt Box x 2 3/8" EUE 8R Pin 2.00" 4.50" 4 10,344' 2 3/8"x 1" TMPDX GLM w/CV & BK -2 latch 5 10,385' 2 3/8" X -Over EUE Mod Box x 2 7/8" EUE 813 Pin 1.99" 2.875" 6 10,386' Baker 40-26 P.B.R. 1.99" 4.078" 7 10,397' Baker "FH" Pkr 40,000# Shear 1.99" 4.125" 8 10,434' Otis "X" Nipple (1.875" I.D.) 1.875" 3.078" 9 10,441' Baker W/L Entry Guide 10 10,561' Baker "SC -1 L" Gravel Pack Pkr. 2.688" 4.125" 11 10,660' Model "S" Sliding Sleeve 2.688" 3.93" 12 10,661' Seal Bore 2.688" 3.81 " 13 10,678' X -Over Sub 2.00" 3.812" 14 10,678' 2 3/8" Shear Out Safety Jnt. (43,000#) 2.00" 3.00" 15 10,710' Otis "X" Nipple 1.87" 2.70" 16 10,741' 2 3/8" x .020" Gage Screen 1.95" 3.046 17 10,771' 2 3/8" x 1.35" O -Ring Seal Sub 1.315" 2.875" 18 10,772' 2 3/8" x .020" Gage Baker Tell Tail Screen 1.95" 3.046" 19 10,785' Model "S-22" Snap Latch Seal Assembly 2.00" 3.375" 20 10,786' Baker Model "D" Sump Pkr. 2.688" 3.937" Casing and Tubing Size Weight ode TU Bottom Description 20" 94# 0 28' Conductor Pipe 11 3/4" 40.5# 0 1998' Surface Casing 7" 26-29# N-80 0 2994' Production Casing 7" 23# N-80 2994' 4967' Produciton Casing 7" 26# N-80 4967' 6722' Production Casing 7" 29# N-80 6722' 9923' Production Casing 5" 18# N-80 9602' 10,926' Liner 3 1 /2" 9.3# J-55 0 9528' Tubing 2 3/8" 4.7# N-80 9530' 10,442' Tubing Perforation Data Interval Zone EI SPF Date 10,506'-10,520' H1 14' 4 4/90 10,746'-10,768' H8 22' 12 9/25/89 to, -1ZD" -+o,73Z` h4$ 'Z` c� PBTD = 10,834' �� �� ptl GA's e TD = 10,926' & pnch"Cad Plug covers R'n C'> Well SCU41 B-9 By: JLB 9121190 E -L* e BOPE's se Head/ aulic Packoff .tor Extension danual Rams Swab Valve rouble Master ' aloes —Wellhead Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Well SCU 41A-9 Dear Mr. Chatterton: Attached is a Report of Sundry Well Operations on SCU 41A-9 (ARCO SCU 41B-9) for additional perforations in the H1 and H8 intervals. The H8 interval was perforated from 10, 720'-10, 732'MD (10, 711'- 10, 723'TVD) on February 20, 1990 and produced all water. Subsequently, the H1 interval was perforated from 10, 506'- 10, 520'MD (10, 499'-10, 513'TVD) on April 6, 1990 and produced all oil. Due to the undesired H8 production, a retrievable plug has been set to isolate it. If you have any questions please contact Carol Baker at 263-4643. Sincerely, T. Wellman Regional Engineer TW:JLB:ch: 0011 Attachment cc: S. W. Ohnimus UNOCAL Corporation A. R. Kukla Marathon Oil Company RECEIVED J U �S 131999 ,h1a6ka Oil & Gas Cons. COMMISS1011 Anchorage ARCO Ahnka, Inc. Is a Subsidiary of Adwdc RkhIWd Company ARCO Alaska, Inc., Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 2761215 Cook Inlet Engineering June 7, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Well SCU 41A-9 Dear Mr. Chatterton: Attached is a Report of Sundry Well Operations on SCU 41A-9 (ARCO SCU 41B-9) for additional perforations in the H1 and H8 intervals. The H8 interval was perforated from 10, 720'-10, 732'MD (10, 711'- 10, 723'TVD) on February 20, 1990 and produced all water. Subsequently, the H1 interval was perforated from 10, 506'- 10, 520'MD (10, 499'-10, 513'TVD) on April 6, 1990 and produced all oil. Due to the undesired H8 production, a retrievable plug has been set to isolate it. If you have any questions please contact Carol Baker at 263-4643. Sincerely, T. Wellman Regional Engineer TW:JLB:ch: 0011 Attachment cc: S. W. Ohnimus UNOCAL Corporation A. R. Kukla Marathon Oil Company RECEIVED J U �S 131999 ,h1a6ka Oil & Gas Cons. COMMISS1011 Anchorage ARCO Ahnka, Inc. Is a Subsidiary of Adwdc RkhIWd Company 4 STATE OF ALASKA f r ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown _ Stimulate _ Plugging Perforate X Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska. Inc. Exploratory _ ' 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service Soldotna Creek Unit 4. Location of well at surface 8. Well number 710' FNL, 660' FEL, Sec. 9, T7N, R9W, SM SCU 41 A -9 - 9. Permit number/approval number At top of productive interval 612' FNL, 635' FEL, Sec. 9, T7N, R9W, SM -90-084 10. API number At effective depth 592' FNL, 605' FEL, Sec. 9, WN, R9W, SM -133-10129-01 At total depth 11. Field/Pool 58T FNL 579' FEL Sec. 9 WN R9W SM Swanson River -Hemlock 12. Present well condition summary Total Depth: measured 10,928' feet Plugs (measured) true vertical 10,918' feet Effective depth: measured 10,834' feet Junk (measured) true vertical 10,825' feet Casing Length Size Cemented Measured depth True vertical depth Structural 2 8' 20" YES 2 8' 281 Conductor Surface 1998' 11 3/4" 1200 Sx 3161' 275 1 ' Intermediate Production 9910' 7" 1600 Sx 991011 9909' Liner 1324' 5" 175 Sx 10926' 10918' Perforation depth: measured 10,746' -10768' 10,720'-10,732'* 10,506'-10,520' MD* true vertical 10,737' -10759' 10,711'-10,723'* 10,499'-10,513' TVD* Tubing (size, grade, and measured depth) * Add Perfs 3 1/2" @9528' MD; 2 3/8" From 9528' -10,442' MD Packers and SSSV (type and measured depth) Baker FH C@ 10,397", Baker SC IL @ 10,651' RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) JUN 13 1990 H1 10,506'-10,520' MD - H8 10,720'- 10,732' MD Alas{ Otl & Gas Cons. COMMIsS1011 Treatment description including volumes used and final pressure t :; Anchorage Add Perfs ° 14. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure 0 0 0 0 0 Prior to well operation Subsequent to operation 550 1925 450 0 1000 psi 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ I Daily Report of Well Operations _& Oil Gas Suspended Service 17. i hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Cook Inlet Regional Engineer Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE JUN -04-190 15:23 I. JANSON RIVER TEL N0:216S ARCO Alaska, Inc. 4L � WELL SERVICE REPORT 8ubW41ay of Adonae Mchflold Company . t ... .. .� , +fir N —G -J2 L tjucj ka Oil & Gas Cons. o W� © CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK uri-04- , . J0 15: %''�"'",� .�HhiSGhd R I'..ER TEL HO :-E,""�"'�.5 ARCO Alaska, Inc. {, 3ubsidlary of Atlantic Richfield Company WELL PEDT CONTRACTOR i'li� t` rr`U sS a a FIELD - DISTRICT - STATE TION AT REPORT TIME 4,3-- ,, Q „ WELL SERVICE REPORT DAYS DATE U _yz REMARKS MAJUE436 Ab" & ! ,. - DT&11*41C . y k 00 M 1� r• f/ / 4r _* El CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK I&S—OL16— I Tamm ft 1 /%1.111 CAMftr UlsibllNH I Wind Vel. siori�l ' � d El CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK I&S—OL16— I Tamm ft 1 /%1.111 CAMftr UlsibllNH I Wind Vel. siori�l Subject: Swanson River Redrill/Workover Activities As mentioned in my previous letter, ARCO Alaska,Inc. (AAI) plans to perform a redrill of three wells (SCU 32B-9, SCU 33-8, and SRU 21- 34, and a workover on one well - SCU 13-9. This work is planned to commence about May 28, 1990. All activities will be done from existing well pads. The final Plan of Operations and a copy of the "Coastal Project Questionnaire" are provided for your review and authorization of the proposed work. ' If you have any questions or need additional information about these operations, please contact me at 265-1501. Sincerely, RECEIVE -1)a rence L. Bro2wn Permit Coordinator MAY 0 719Q 1 . V �. 1 laska .Oil.& Gas LLB :es Cons. Cormn Anchors isslon LLB/04/031 g enclosure: Plan of Operations ! CZM Questionnaire cc w/o enclosures: J. Dygas, BLM, Anchorage Kenai Borough, Soldotna L. Leatherberry, ADEC, Soldotna P. Miller, DGC, Anchorage L. Smith; AOGCC, Anchorage ARCO Alaska. Inc. is a Subsidiary of A11aMlcAlchileldCompany AR39.6003•C ARCO Alaska, ► Post Office Box 100360 ; Anchorage, Alaska 99510-0360 , COMM Telephone 907 276 1215 COMM May 4 1990 SR EN -a -ASST Mr. Daniel Doshierr�c U.S. Fish and Wildlife Services ��� nssT Kenai National Wildlife Refuge Sri OEOL P. O. Box 2139 GEUL ASS T Soldotna, Alaska 99669 s-rA*r TECH SPAT TECH Dear Mr. Doshier: FILE _ Subject: Swanson River Redrill/Workover Activities As mentioned in my previous letter, ARCO Alaska,Inc. (AAI) plans to perform a redrill of three wells (SCU 32B-9, SCU 33-8, and SRU 21- 34, and a workover on one well - SCU 13-9. This work is planned to commence about May 28, 1990. All activities will be done from existing well pads. The final Plan of Operations and a copy of the "Coastal Project Questionnaire" are provided for your review and authorization of the proposed work. ' If you have any questions or need additional information about these operations, please contact me at 265-1501. Sincerely, RECEIVE -1)a rence L. Bro2wn Permit Coordinator MAY 0 719Q 1 . V �. 1 laska .Oil.& Gas LLB :es Cons. Cormn Anchors isslon LLB/04/031 g enclosure: Plan of Operations ! CZM Questionnaire cc w/o enclosures: J. Dygas, BLM, Anchorage Kenai Borough, Soldotna L. Leatherberry, ADEC, Soldotna P. Miller, DGC, Anchorage L. Smith; AOGCC, Anchorage ARCO Alaska. Inc. is a Subsidiary of A11aMlcAlchileldCompany AR39.6003•C ARCO Alaska:" Post Otl,..x 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 May 1, 1990 Mr. Lester Leatherberry Alaska Department of Environmental Conservation Kenai District Office P.O. BOX 1207 Soldotna, Alaska 99669 Dear Mr. Leatherberry: C01 IN -1 ENG ASST I E ! :; ASST CC.'. E C L Al S 1 STAT TECH F!LE I Subject: Swanson River Redrill/Workover Activities 6 ARCO Alaska, Inc. (AAI) plans to perform a redrill of three wells and workover on one at Swanson River Field beginning about May 28, 1990. All work will be done from existing pads. A copy of the "Coastal Project Questionnaire" and Plan of Operations are .provided for your information. If you have any questions, I can be reached at 265-1501. Sincerely, �f a rence "L.Brown Permit Coordinator LLB -es LLB/04/032 Enclosure: Plan of Operations CZM Questionnaire cc w/o enclosures: J. Dygas, BLM, Anchorage Kenai Borough, Soldotna P. Miller, DGC, Anchorage L. Smith, AOGCC, Anchorage B. Wright, DNR, Anchorage R C -," V �.' MAY 0 7 1590 Alaska oil & Gas Cons. Cammtssjan Anchoraga ARCO Alaska. Inc. is a Subsidiary of AtlanlicRlchlieldCompany AR39•E003-C ARCO Alaska Post Oil& z 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 May 1, 1990 NIr. Bill Wricht Department of Natural Resources Land and Water Management P.O. Box 107-005 Anchorage, Alaska 99510-7005 Dear Mr. Wright: C0lUll I SIR ENG Ef i ASST �zz. _jL ASS f ASST STAT TECH I SIfiT C^� ' ARCO Alaska, Inc. (AAI) is planning redrill operations on three wells in the Swanson River Field and a workover on SCU 13-9 starring about May 28, 1990. The wells involved are SCU 32B-9, SCU 33-8, and SRU 21-34. As part of this activity, we plan to utilize groundwater from nearby water wells, which have been drilled previously. The drilling and testing activities on each well will last less than one month and we anticipate the daily water use to be approximately 10,000 gallons per day for each well. In anticipation of these and future redrill activities at Swanson River this summer,we request that by this application a temporary water use permit be issued for each of these wells. To minimize the administrative workload on AAI and the Division of Land and Water Management, it would be preferred that AAI be issued a permit that would allow temporary use of any installed water well within the field for a period of one year. We feel the single permit would adequately ad%&& tl:e anticipated activities in the field. Periodic reports would be provided to ensure that the State, and Fish and Wildlife Service records are complete. - AAI would, however, continue to obtain USF&WS and BLM authorizations for field operations as needed. I have attached the Plan of Operations that applies to the planned activities and the required check for $100.00. If you have any questions or need additional information about these -drilling - operations, please contact me at 265-1501. I hope to hear from you at your earliest convenience due to the short -time frame before the work is planned to begin. Sincerely, u.t. Lawrence L. Brown Permit Coordinator LLB:es LLB/04/2 8 enclosures: Plan of Operations CZM Questionnaire cc w/o enclosures: D. Doshier, USF&WS, Soldotna J. Dygas, BLM, Anchorage H. Friedman, ADEC, Anchorage Kenai Borough, Soldotna L. Leatherberry, ADEC, Soldotna P. Nliller, DGC Anchorage L. -Smith, AOGCC, Anchorage ��0. . � keb q� as�o .9q� c�ora� VNfss�% ARCO Alaska. Inc. is a Subsidiary of AllanticRichfietdCompany AR3B•6003-C ARCO Alaska, Past Ole,..e —ox 100360 COMM r Anchorage. Alaska 99510-0360 �All��' Telepnone 907 278 1215 iIES SR ENG t May 1, 1990 EN ASST Li SST - ECL GO -LA Mr. Henry Friedman ,T' — _.. A.SI pi Alaska Department of EnvironmentalTECH j1 Conservation s i A7 TEC. 3601 C Street, Suite 1350 1 LC ! Anchorage, Alaska 99503 _i Dear Mr. Friedman: ARCO Alaska, Inc. (AAI) plans to perform a redrill of three wells (SCU 32B-9, SCU 33-8, SRU 21-34), and a workover on SCU 13-9 in order to improve oil production. The drilling activities will begin about May 28, 1990. All work will be done from the existing well pads. The Plan of Operations for these activities is attached for your information. The drilling waste to be generated will consist of used mud and formation cuttings, which will be confined to a metal "cuttings box", for transport to the Swanson River Field Central Disposal Facility that is a lined permitted facility for the disposal of this type of drilling waste. All pumpable liquids generated during the drilling and testing of the=sell :rill b� injected into disposal well SCU 43-4. It is estimated that approximately 3000 barrels of drilling waste fluid will be injected in this manner. If you have any questions concerning this waste disposal notice, please do not hesitate to call me at 265-1501. Sincerely, Qa rence L. rown Permit Coordinator LLB:es LLB/04/029 enclosure: Plan of Operations CZM Questionnaire cc w/o enclosures: D. Doshier, USF&WS, Soldotna J. Dygas, BLM, Anchorage Kenai Borough, Soldotna L. Leatherberry, ADEC, Soldotna P. Miller, DGC, Anchorage L. Smith, AOGCC, Anchorage B. Wright, DNR, Anchorage J'VlAY 0 7 I990 ."aska Oil & Gas Cons, Commisslott Anchoraga ARCO Alaska. Inc. is a Subsidiary of AIlan ticRichfieldCompany AR38-6003-C ARCO Alaska, Inc. 70"-7 Post Office - _ 5 c�360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering April 4, 1990 Mr. C.V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Well SCU 41A-9 Dear Mr. Chatterton: Attached is an Application for Sundry Approval on SCU 41A-9 (ARCO SCU 41B-9) for perforating the H1 interval. The requested interval is 10,506'-10,520' MD (101499'-10,513'TVD). If you have any questions please contact Carol Baker at 263-4643. T. Wellman TW:JLB:ch:0010 Attachment cc: S. W. Ohnimus UNOCAL Corporation A. R. Kukla Marathon Oil Company RECEIVED APR — 51990 Alaska Oil & Gas Cons. Commisslop Anchorage ARCO Alaska, Inc. is a Subsidiary of AtianticRichfieldCompany STATE OF ALASKA Al . OIL AND GAS CONSERVATION COMMIZION » p APPLICATION FOR SUNDRY APPROVALP 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _X Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska, Inc. Exploratory _ Stratigraphic _ RKB 150 feet 3. Address 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Sol�n� CG�L7�� 4. Location of well at surface S. Well number 710' FNL, 660' FEL, Sec. 9, T7N, R9W, SM SQU 416-9 9. Permit number At top of productive interval 612' FNL, 635' FEL, Sec. 9, T7N, R9W, SM 80-107 10. API number At effective depth 592' FNL, 605' FEL, Sec. 9, T7N, R9W, SM 50-1 33-10129-01 - - 11. Field/Pool At total depth At 587' FNL, 579' FEL Sec. 9 T7N R9W SM Swanson iv r- 12. Present well condition summary R t t t I V ' Total Depth: measured 10,928' feet Plugs (measured) true vertical 10,918, feet APR — 5 1990 Effective depth: measured 10,834' feet Junk (measured) �$S�011 Cons. Comm true vertical 10,8251 feet Alaska Oil & Gas Casing Length Size Cemented Measured depthAnfhhWWrtical depth Structural 2 8' 2001 YES 2 8' 28@ Conductor Surface 1998' 11 3/4" 1200 sx 3161' 2751' Intermediate Production 9910, 7" 1600 sx 9910, 9909' Liner 1324' 511 175 sx 10926' 10918' Perforation depth: measured 10,746'-10,768', 10,720'-10,732 MD; Proposed 10,506'-10,520' true vertical 10,737-10,759, 10,711'-10,723 TVD; Proposed 10,499,'-10,513' Tubing (size, grade, and measured depth 3 1/2" @ 9528' MD; 2 3/8" FROM 9528' -10,442' MD Packers and SSSV (type and measured depth) Packers: BAKER FH @ 10,397' BAKER SC IL @ 10,651' 13. Attachments Description summary of proposal _ Detailed operation program BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: April 1 Oil XGas _ Suspended _ 16. If proposal was verbally approved Name of approver Date approved 1 Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ` %� ���--- Title COOK INLET ENGINEERING MANAGER Date -q-V FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness jApproval No. Plug integrity _ BOP Test _ Location clearance _ �� � Mechanical Integrity Test _- Subsequent form require 10-9 ... Approved b the order of the Commission Commissioner Date Form 10-403 Rev 5/03/89 5UbM1 I IN I tilVUL A I t E-Lm*e BOPE's ..__ Grease Head/ Hydraulic Packoff RECEIVED APR — 5 1990 Alaska Oil & Gas Cons. Commission Anchorage �-- Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead SCU 41B-9 Add Perf Procedure SR 149 Objective: To add perforations in the H 1 interval. Well Data: Completion: 3-1/2" tbg to 9528', 2-3/8" tbg to 10,441' MD GP pkr, blank pipe & screen from 10,561' Minimum Restrictions: 1.875" ID Otis W nipple 0 10,434' MD Tie-in Log: PDK100 (9/22/89) Tubular Capacities: 3-1/2" tbg = .0087 Bbl/ft; 2-3/8" tbg = .00387 Bbl/ft Pressure Data: Thg = 1520 psi; PC = 1600 psi; SC = 2 psi PROCEDURE: NOTE: 1. Make a 1.75" gauge ring run to GP to assure adequate clearance for perf guns prior to RU conductor line. 2. Dummy -off bottom GLM prior to RU conductor line. 3. Assure that FL and pressure on tubing are sufficient to enable some drawdown on the formation (est. at 4800 psi at 10,700') when opened to flow while perforating. 4. Assure that Sundry approval has been obtained prior to perforating. 1. MIRU conductor line. Pressure test lubricator to 4000 psi. 2. SI well. RIH with perf gun/CCL. Tie-in to perf interval: PDK (9/22/89) Foo#agg Sand SPF 10506-10520' 14' MD H1 4 Hole Hole Company Gun Type Gun Size Depth* Diameter* Schlumberger Domed Scallop 1-11 / 16" 4.63" .28" Atlas Jumbo Jet III 1-11 / 16" 5.84" .24" * API test data in Berea sandstone. NOTE: Gun orientation should be down (at hole bottom). 3. Open well to flow. immediately perforate interval. 4. Allow well to flow choked -back for at least 20 minutes. 5. POOH ASAP going slowly until through tubing tail. 6. Check gun to confirm that all shots have fired. RECEIVED 7. RDMO. APP - 51990 Alaska Oil & Gas Cons. Gomd,04o ,AnchioragO ARCO Alaska, Inc Post Office t- _A o u0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook inlet/New Ventures Engineering February 14, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Well SCU 41A-9 (ARCO SCU 41B-9) Dear Mr. Chatterton: Attached is an Application for Sundry Approval on SCU 41A-9 for perforating the H8 interval. The requested interval is 10,706'-10,732' MD (10,697'-10,723' TVD, which will be shot and tested in individual 10 to 12' intervals from the bottom up. Pending the resulting production, the previously submitted H1 perforations may be subsequently opened. If you have any questions please contact Carol Baker at 263-4643. Sincerely, T. Wellman Interim Manager TW:JLB:ch:0009 Attachment cc: S. W. Ohnimus UNOCAL Corporation A. R. Kukla Marathon Oil Company FEB 16 10 Vit) A,rias Oil & Gay; Cons. Commission Anchora ARCO Alaska, Inc. is a Subsidiary of AtianticRichfieldCompany STATE OF ALASKA AL,,SM OIL AND GAS CONSERVATION COMMISSION . APPLICATION FOR SUNDRY APPROVALS n i? i 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate - Change approved program _ Pull tubing _ Variance Perforate _X Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska.Exploratory _ Stratigraphic _ RK13 150 feet 7. Unit or Property name 3. Address P. O. Box 100360, Anchorage, AK 99510 Service Swanson River Unit 4. Location of well at surface 8. Well number 710' FNL, 660' FEL, Sec. 9, T7N, R9W, SM 9. Permit number At top of productive interval 612' FNL, 635' FEL, Sec. 9, T7N, R9W, SM --80-107 10. API number At effective depth 592' FNL, 605' FEL, Sec. 9, T7N, R9W, SM - - 50-1 33-10129-01 11. Field/Pool At total depth At 587' FNL 579' FEL Sec. 9 T7N R9W SM Swanson River -Hemlock 12. Present well condition summary Total Depth: measured 10,928' feet Plugs (measured) true vertical 10,918' feet Effective depth: measured 10,834' feet Junk (measured) true vertical 10,825' feet Casing Length Size Cemented Measured depth True vertical depth Structural 2 8' 20" YES 28' 2 8' Conductor Surface 1998' 11 3/4" 1200 sx 3 16 1 ' 2751' Intermediate Production 9910, 7" 1600 sx 9910, 9909, Liner 1324' 5 " 175 sx 10926' 10918, Perforation depth: measured RECEIVED 10,746'-10768' MD; Proposed 10,706'-10,732' true vertical 10,737'-10,759' TVD; Proposed 10,697'-10,723' FEB161000 Tubing (size, grade, and measured depth :h'��Iskd_Cil Gas 3 1/2" @ 9528' MD; 2 3/8" FROM 9528' -10,442' MD Canso Comfrji6�io Packers and SSSV (type and measured depth) Anch®rap Packers: BAKER FH @ 10,397' BAKER SC IL @ 10,651' 13. Attachments Description summary of proposal _ Detailed operation program .X BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: Oil X _-_ Gas _ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Si , COOK INLET ENGINEERING MANAGER Date (4 go FOR COMMISSION USE ONLY 10 Conditions of approval: Notify Commission so representative may witness (Approval No .^ Plug integrity _ BOP Test _ Location clearance _ I_ Mechanical Integrity Test Subsequent form require 10- 4,>, ORIGINAL SIGNED BY Approved by the order of the Commission LONNIE C. SMITH Commissioner Date 20190 o Form 10-403 Rev 5/03/89 Approved Copy R turn d 40 SUBMIT IN TRIPLICATE 0 SCU 41B-9 Add Perf Procedure SR 120 Qbjectiv : To add perforations in the H1 interval. Well Data: Completion: 3-1/2" tbg to 9529', 2-3/8" tbg to 10,443' MD GP pkr, blank pipe & screen from 10,651' Minimum Restrictions: 1.87" ID Otis "X" nipple @ 10, 710' MD Tie-in Log: PDK100 (9/22/89) Tubular Capacities: 3-1/2" tbg = .0087 Bbl/ft: 2-3/8" tbg = .00387 Bbl/ft Pressure Data: Tbg = tr: PC = 480 psi: SC = 62 psi PROCEDURE: Note: 1. Make a 1.75" gauge ring run to 10, 760' MD to assure adequate clearance for perf guns prior to RU conductor line. 2. Assure that FL in the tbg. is sufficient to balance or slightly underbalance (300 psi max.) the formation (est. at 4800 psi at 10,700'). 3. Assure that Sundry approval has been obtained prior to perforating. 1. MIRU conductor line. Pressure test lubricator to 4000 psi. 2. SI well. RIH with pert gun/CCL. Tie-in to perf interval: PDK (9/22/89) Footage, Sand SPF 10720-10732' 12' MD H8 4 Hole Hole COMB= Gun Gun Size Depth* Diameter* Schlumberger Domed Scallop 1-11 / 16" 4.63" .28" Atlas Jumbo Jet III 1-11 / 16" 5.84" .24" * .API test data in Berea sandstone. NOTE: Gun orientation should be down (at hole bottom). 3. Perforate interval. 4. POOH ASAP going slowly until through tubing tail. 5. Allow well to flow choked -back for at least 20 minutes. 6. Check gun to confirm that all shots have fired. RECEIVED 7. RDMO. ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company ARSB -6001-A =s ? Oil & Gas Cons. Cares F Anchoraga E-Lm*e BOPE's Grease Head/ Hydraulic Packoff •— Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead ARCO Alaska, Inc. Post Office Box a 00360 Anchorage, Alaska 995100360 Telephone 907 276 1215 " Cook Inlet/New Ventures Engineering January 10, 1990 Mr. C.V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Well SCU 41A-9 (ARCO 4113-9) Dear Mr. Chatterton: Attached is a Report of Sundry Well Operations in which SCU 41A-9 (ARCO 41B-9) was acidized to remove near wellbore damage in the recently completed gravel pack. The acid job was performed November 14, 1989 and a copy of the well service report is attached. If you have any questions please contact Wes Peirce at 263-4228. Sincerely, T. Wellman TW:DML:ch:0006 Attachment cc: S. W. Ohnimus A. R. Kukla ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieidCompany UNOCAL Corporation Marathon Oil Company Gas Cuns. com+��i: Aiichoratg STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION f REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown _ Stimulate X Plugging Perforate _ Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska, Inc.Exploratory _ ' RKB feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service Soldotna Creek Unit 4. Location of well at surface 8. Well number 710' FNL, 660' FEL, Sec. 9, T7N, R9W, SM - 9. Permit number/approval number At top of productive interval 612' FNL, 635' FEL, Sec. 9, T7N, R9W, SM -1 - 80-107/9-563 10. API number At effective depth At 592' FNL, 605' FEL, Sec. 9, T7N, R9W, SM 0- - 1 - 50-133-10129-01 11. Field/Pool At total depth At 587' FNL, 579' FEL, Sec. 9, T7N, R9W, SM Swanson River -Hemlock 12. Present well condition summary Total Depth: measured 10,928' feet Plugs (measured) true vertical 10, 91 8' feet Effective depth: measured 10,785' feet Junk (measured) true vertical 10,776' feet Casing Length Size Cemented Measured depth True vertical depth Structural 2 8' 2011 YES 2 8' 2 8' Conductor Surface 1998' 11 3/4" 1200 Sx 1998, 1998' Intermediate Production 9910' 7 " 1600 Sx 991001 9909' Liner 1324' 5" 175 Sx 10926' 10916' Perforation depth: measured 10,746 -10768' MD true vertical 10736' -10758' TVD Tubing (size, grade, and measured depth) 3 1/2" @9528' MD; 2 3/8" From 9528' -10,442' MD RECEIVEr") Packers and SSSV (type and measured depth) Baker FH @ 10,397", Baker SC IL @ 10,651' 13. Stimulation or cement squeeze summary FA I I I Intervals treated (measured) 10,741'-10,771'''''°`" Treatment description including volumes used and final pressure 30 bbis xylene, 44 bbis 7 1/2 HCL acid, 20 bbls crude, unload with N2; final pressure 3600 psig. Average Production or Injection Data 14. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 1200 1 1 0 0 Subsequent to operation 3 0 175 975 300 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations X Oil X Gas Suspended Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed j?wH, UlC zu-t4l ---- Title Cook Inlet Engineering Manager Date x-15"-qD AKt;V AWSKIR, mu. V S ot*v of Atto+tic wchfield CWnpony WELL .',Ot CONTRACTOR L2 WMLL C►cnvl%Oc ncrvnI STATE DAYS (DATE 11-144 TION AT REPORT TIME L,.^Ac ut1�Ks / 1 oO A c t b A �-�`N M14�% Aa�6 W'CC1� P+�t„ 4��'SOIJt3�4.. 1 OBD ^ 1 SCS_ A ka.5, Sri R rt -ruaktS 2� - Z-tr SC C �aK� 5'rl �b �, �z •�� i.�,J�� TO � P�1L� . �R'E~s�'R� 't'�S i TO Sa molts, -lCs f 02 L tIPOV S 'CCS SOr� Sr's�t� . 11 � - 1155 _.....�c,.��T �r�,z+o.a� • `T+J3�Nt� 1 \� �� ; �., i ,7..00 ?'� �, � C� d � ��. \kct ►� z� o� � �,� s M,N3 -Qom. PAS. %7160 Sk i 4A C Ir W/ C-7 -m- LC�7.' '3166%*0 d-lZvXG $a a PuMp+� 6 cwr sw - �.� � t `T�t4t�� �2�`rUS�aS V4 GTi•`r''66 AN�.x�Lv� 't'o -�1� .. ��•E.-t'AN4t _ � A O � � u�� To 'S.��f�CE AF'�� �eS TS�-S Av4Ay . Rimp Rtan owl -TO Qt -?S tSPM . 1AVJ ~ 11, ss 41180 6 O C tea �SvRV- '5-tA�bA.E -r'-Ako\.-o,tlo0c Q ZOO Ti It, 0 - UU '2��Pw•t'�JE. M /"` JsT,0 %4.s .4mW % C 1410 1.0 41180 6 O 0 Xyc»4, spar �, Reams 14 3< a w IT Ac.•o *met A4\1> 41300 Bro0 to .t5' C�cw 964AP. C'c' �. ScWW; {4 6,447 AA 30a 350 t600 0.20 4:580 A4cco l�O 31 AC�o '?ftrss. C% Sa _ 15ao 0,;0 . . Sano 35x0 tS 33 Aea S&QwAg. .1► Li CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK W"tlwTir»p. Chill Factor I Visibility Wind VA Signed RaP� +F OF mues I knots i 4 �-1 ARCO Alaska, Inc, �SvWdtn of At1•Mic Richfield C from r WELL CONTRACTOR • STATE TION AT REPORT TIME WELL SERVICE REPORT D - C_or* DATE 11 -14 - t705 .3 3�c� 'M 44A 93 C-���o o �u►�. �� Q09 -0.A1 3Lk00 ILm 0 59 yc.YL646 smwr *4 4�VL F*L�m . 0141r QA 44400 3ram 5' '7� _ ��%JtLs ,wc.6NE; * ggERL c?!A < 0A 5jkoo .ion o cQ,2me - FLQS IA 1-757(o 0.4c 4600 31eo s 179 c1240;a — ASde 0,§:Q Ak$S-0 .0 10 8A CQ -ops tell OA 0 4 (0Sa .15" 8g CF!!W . cgolc?g a SCwe&zS . _ 01 y 4!56 3ib00 Zo 9 Li <ol !Advo *6 CT b!�Sz fg qmg s. 7k 39 &v> -c a •D I Li :. r .' • 1 � � �� • � �,f.,•...�� .rim per M MGA S 11 5,3C� t bo tA tT'. cprrc�o+ -,co -4N�4k . 4a CHECK THIS BLACK IF SUMMARY CONTINUED ON SACK Temp. Chill Wind Y*I. Slptwd Ropm f fir I I mIIM I knots v EMARKS CONTINUED: ♦ • • .• MOM- OWN "�7-i -- "m Malmom- dp HiQ )�,, eye ,�wi � � e , r� �p.�`���� ��► �► i0a� 1Bl�p EFEZ wg� z g# I ---, Wd 4,47 IF rI ,alt��u��i�,�� r„�,t;,,;;;� � n";;,,w���a►�iuN�'��m��ffii��}���� f� �ili�f�11lIIIIlfIlllHUM,nUftu r�urrm w., �u�m���► ����u�p NtMnurttu�um ���i�u���� tm MYNA I -AWN! PI �E82 re LZ ft '� ti ARCO ALASKA INC. Cook Inlet/New Ventures Engineering TRANSMITTAL #375 TO: John Boyle FROM: Tom Wellman COMPANY: AOGCC COMPANY: ARCO Alaska, Inc DATE: NOV 179 1989 WELL NAME: LISTED BELOW Transmitted herewith are the following Blue Sepia Sepia --" Line olded Rolled M lar Tape SCU 41A-9 Gravel Pack Log G 1 1 SCU 243-4 Temperature Log 1 1 Receipt Acknowledgement: Return reciept to ARCO ALASKA, Inc. ATTN: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' Dat 92fC�tdED NOV 2119 Alaska Oil &A�as Co�mmissl0o ARCO Alaska, Inc.' Office Post 13 o O e c.._ t 00360 Anchorage, Alaska 99510-0360 r , Telephone 907 263 4724 T. Stewart McCorkle / Engineering Manager Cook Inlet/New Ventures November 8, 1989 Mr. C.V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Well SCU 41A-9 (ARCO 41B-9) Dear Mr. Chatterton: Attached is an Application for Sundry Approval to acidize the recently completed gravel pack to remove near wellbore damage in SCU 41A-9 (ARCO 41B-9). We propose to perform an acidize job designed in three stages which will utilize coiled tubing for placement. A procedure of the job is attached. With your approval, we would like to begin this work as soon as possible. If you have any questions please contact Wes Peirce at 263-4228. ", �f -Ire �M T. S. McCorkle TSM:DML:ch:0005 Attachment cc: S. W. Ohnimus UNOCAL Corporation A. R. Kukla Marathon Oil Company ME= aiv 0 9 198 C4 `Jsl a Oil & Cas Cone Commi a�� s , Anchor� ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6279 ` STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate X, Change approved program _ Pull tubing _ Variance Perforate Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska. Inc.Exploratory _ Stratigraphic _ RK13 150 feet 3. Address 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service Soldotna Creek Unit 4. Location of well at surface 8. Well number 710' FNL, 660' FEL, Sec. 9, T7N, R9W, SM SQU 41A -9 - 9. Permit number At top of productive interval 612' FNL, 635' FEL, Sec. 9, T7N, R9W, SM 10. API number At effective depth 592' FNL, 605' FEL, Sec. 9, T7N, R9W, SM - - 50-1 33-10129-01 11. Field/Pool At total depth At 587' FNL 579' FEL Sec. 9 WN R9W SM Swanson River -Hemlock 12. Present well condition summary Total Depth: measured 10,928' feet Plugs (measured) true vertical 10,918' feet Effective depth: measured 10,785' feet Junk (measured) true vertical 10,776' feet Casing Length Size Cemented Measured depth True vertical depth Structural 28' 2 0" YES 2 8' 2 8' Conductor Surface 1998' 11 3/4" 1200 sx 1998, 1998' Intermediate Production 9910, 7 " 1600 sx 9910, 9909' Liner 1324' 591 175 sx 10926' 10916' Perforation depth: measured RECEIVEL 10,746'-10768' MD true vertical 10,736'-10,75$' TVD Tubing (size, grade, and measured depth 3 1/2" @ 9528' MD; 2 3/8" FROM 9528' -10,442' MDtfs Oi�, Packers and SSSV (type and measured depth) I TIrn Anchora Packers: BAKER FH @ 10,397' BAKER SC IL @ 10,651' 13. Attachments Description summary of proposal _ Detailed operation program X BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: 1989 Oil ,2L_ Gas Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si ne i�,-rs n.=C�1�.S��,, Title COOK INLET ENGINEERING MANAGER Date I t - 9-64J FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness (Approval No. 9 Plug integrity _ BOP Test _ Location clearance _ I _r..,r �v Mechanical Integrity Test _ Subsequent form require 10-./-/,0Y / -Approved b the order of the Commission Commissioner Date Form 10-403 Rev 5/03/89 " / / SUBMIT IN 11RIPL'ICATE Z/ m SCU 41B-9 CTU Acid Treatment SR 99 Objective: Acidize well to remove damage from drilling mud, emulsion, andiron precipitates. Safety: Have fire extinguishers on location. (Note: Confirm with Engineering that Sundry approval has been received before proceeding with stimulation). Job Preparation: 1. RU choke manifold to take returns from the downstream side of the flowline wing gates and back into the flowline. Use chick-san on all lines. 2. Filter all fluids to 3 microns at pump suction. 3. Nitrogen requires two days notice prior to job. 4. Have service company titrate acid on location to ensure proper acid strength. 5. Shoot PC fluid level and perform packer calculations. Do not exceed 86" tubing movement for PBR. Recommended Procedure: 1. RU slickline and pressure test lubricator. Pull orifice check from 10,344' MD and replace with dummy. RD slickline. 2. Hold safety meeting with all appropriate personnel. 3. RU 1-1/4" CTU with 1.6" Swirl Wash Nozzle and check valve. RU service company to pump acid and nitrogen. Pressure test CTU and surface lines to 5,000 psig. 4. Displace the CTU with lease crude and RIH to 10,771' MD (O-ring sub ID 1.315") while pumping crude at 1/8 to 1/4 BPM. Take returns through choke skid to the gauge tank during this step. Ensure that the Cr X tubing annulus is completely fluid packed. 5. Pump the acid treatment as follows: A. Spot a 15 Bbl xylene pre -flush containing 10% mutual solvent to the end of the CTU. Shut in return line. B. Pump 2,000 gals acid (See attached acid detail) down CT at 1/2 to 1 BPM. Energize acid with 400 SCF/Bbl nitrogen. Do not exceed 3,500 psig on CT X tubing annulus (Approximate frac pressure). C. Overflush acid with 15 Bbls xylene containing 10% mutual solvent. Energize xylene with 400 SCF/Bbl. D. Displace Cr with nitrogen. ARCO Alaska Inc. Is a subsidiary of Atlantic RicMieid Company ARSB -6001-A F SCU 41B-9 CTU Acid Treatment SR 99 - Page Two E. Immediately after displacing CT with nitrogen, open choke to the gauge tank and backflow spent acid. Continue lifting well with nitrogen until treatment volume has been recovered. Collect three fluid samples of acid during flowback (beginning, middle, and end). Analyze samples for acid concentration and Fe content. If acid is not completely spent, dump neutralizing agent in gauge tank. F . If well will not backflow the treatment volume, overflush all treating fluids with 75 Bbls of lease crude. This will displace the acid approximately 5' away from the wellbore. 6. POOH with CT. RD equipment. 7. RU slickline and pull dummy from GLM at 10, 344' MD. Rerun 1" orifice check with 5/16" port. 8. While rigging down service companies, disconnect choke skid and re -install production choke. Initiate production using gas lift as necessary. 9. Test well after 12 hours and daily thereafter for a two week period. MSR -100 7.5% HCl 0.4% A250 Corrosion Inhibitor 0.5% F75N Surfactant 100#/m gals L41 Iron Chelating Agent 0.5% W54 Non -Emulsifying Agent Tubing: 3-1/2" to 9,528' MD; 2-3/8" from 9,528'-10,442' MD. Tubing Volume: 86 Bbls Tbg X CT Vol: 70 Bbls (CT displacement 1.518 Bbls/1,000') Packer Type: Baker FH at 10,397' MD. PBR installed. GP Packer: Baker SC -1L at 10,651' MD. GP Screen: 20 ga. screen from 10,741'-771'MD (1.95" ID). Min Tbg ID: 1.315" O -Ring sub at 10,771' MD Liner Size: 5" X 18 #/ft at Packer GLMM, Locations: GLM #1 1,997' GLM #2 10,344' ARM Alaska Inc. is a subsidiary of Atlarft Rictfmid Company AMB -6001-A OCT -12-'69 16:35 ARCO Alaska, Inc. lub* oq Of 6*ntf9Rk ftk00ompwty I D: SWANSON R I VER TEL N0: 2651,,�'83 42'17 P01 ''"* L7''NG / TUBING / LINER DEIe � - S� I►�l Sen! �t P, E e� DRILL SITE _ 41q_ DATE - _._.�. .-. Page [—of t pages #ITEMS COMPLETE DISCRIPTION OF EOUIPMENT RUN LENGTH DEPTH V+ R 15 q Ta T 6 N _ Zko v ff-f CI , ' ��* `� ".P S zG0T'S y ,5,3 s' " 4v -TT boy.,k �v gue A 14 qt *. fout Mh AA kto O jai&46 3tvvl c SAO A Obb Pup .26 �y �B b 1 q6.5 13PIL"m" Z4 k. F CA r t, 3e`im 3%" .31�6 ue $ D AA MoD r8g, Y 5 _ 94 9' Z API" Cu� Dk 9 ZYx EaffitOPig zbb" S I I 19Z z *'u-10 EL&C09 Ists J,.(_ ZYS" Yu" i-mgtkx- C,,W -wZqiwr-1<9At99: j A&Z LAMd 41 -L � 6S 3 fJ -91 �¢�,LS 3,60„ - (A Alt i&k " x -so a � D "T7 A 3 -. Z9 MoD 31 • Z $so, 46 g-fwq z r 1,17 33,1q Z. sill l 0oN 1.'3y rx(Ldhc 130TTOM OF TUBING TAIL Remarks 'K G 1.17 OPERATOR ��_.�I%ti�ra1'A.._� t�G. ��zt w[j*:W 4EtAM THRuO COMPANY REP. r wC«#-.3_.__.. __. ..... _.,r.. .._.cam. ..A) -.go FIELD LONG j COuNTY.�.�rur STATE - — �-- w DATE -rutlu^. LONG si F111A 6WIT sTRINO 13 Now Comple6-E Ilkm Vlgrkovtr WT. ON , 40. Otmu Le"TNa7i _ i��+ ti, = p6SC�ii:itON ....._.. 1 "o '19- .?'? 3 WELL PROFILE LL f � 1•tijJ. i 4 .• t 1 G 1.17 OPERATOR ��_.�I%ti�ra1'A.._� t�G. ��zt w[j*:W 4EtAM THRuO COMPANY REP. r wC«#-.3_.__.. __. ..... _.,r.. .._.cam. ..A) -.go FIELD LONG j COuNTY.�.�rur STATE - — �-- w DATE -rutlu^. LONG si F111A 6WIT sTRINO 13 Now Comple6-E Ilkm Vlgrkovtr WT. ON , 40. Otmu Le"TNa7i _ i��+ ti, = p6SC�ii:itON ....._.. 1 "o '19- .?'? 3 � WA -45A] 196A 414 k LL qqo 3•- K Iw. Law )) '• Q j (/��� - a� _ Imo} a ' STATE OF ALASKA ORIG, T A .A OIL AND GAS CONSERVATION COMMISSIONy REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown _ Stimulate _ Plugging Perforate _ Alter casing Repair well Pull tubing Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska, Inc. Exploratory _ ' 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 service Soldotna River Unit 4. Location of well at surface 8. Well number 710' FNL, 660' FEL, Sec. 9, T71N, R9E, SM 9. Permit number/approval number At top of productive interval 597' FSL, 611' FEL, Sec. 9, T7N, R9E, SM 80-107/9-653 10. API number At effective depth 590' FSL, 605' FEL, Sec. 9, T7N, R9E, SM50-133-10129 11. Field/Pool At total depth 587' FSL, 599' FEL, Sec. 9, T7N, R9E, SM Swanson River/Hemlock Pool 12. Present well condition summary Total Depth: measured 10928' feet Plugs (measured) original 5" liner & 7" csg cemented true vertical 10918' feet f/td(10847)-9970' and sidetrack window cut f/9921'-9970' for new td & 5" liner. Effective depth: measured 10834' feet Junk (measured) true vertical 10824' feet None Casing Length Size Cemented Measured depth True vertical depth Structural 20" 200 Sx CS II 1 1 0' 1 1 0' Conductor Surface 11 3/4" 1200 sx 1998' 1998' Intermediate Production 7" 1600 sx 9970' 9969' Liner 5" 175 sx Class G 9602'-10926' 9602'-10916' Perforation depth: measured 10746'-10768'md true vertical 10737'-10759'tvd Tubing (size, grade, and measured depth) 3 1/2" 9.3# j-55 x 2 3/8" 4.7# N-80 @ 10443'md Packers and SSSV (type and measured depth) Baker 'FH' Pkr @ 10398'md, Baker 'D' Pkr 13. Stimulation or cement squeeze summary Intervals treated (measured) OCT 2 61989 Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Commission 14. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Water Injector _ Daily Report of Well Operations Oil Gas Suspended Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Area Drilling Engineer Date Form 10-404 Rev 05/17/89 SUBMIT IN DUPLICATE t WWI STATE OF ALASKA ALASKA V L AND GAS CONSERVATION COMMISSION rnnubt-pTinM nn RP -COMPLETION REPORT ORIGIN AND LOO µ 1. Status of Well OIL GAS ❑ SUSPENDED U ABANDONED ❑ SERVICE ❑ Classification of Service Well 2. Name of Operator ARCO Alaska, Inc. 7. Permit Number 80-107/9-653 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 8. API Number 50— 133-10129-01 4. Location of well at surface 710' FNL, 660' FEL, Sec. 9, WN, R9W, SM At Top Producing Interval 597' FNL, 611' FEL, Sec. 9, WN, R9W, SM At Total Depth 587' FNL, 599' FEL, Sec. 9, WN, R9N, SM 9. Unit or Lease Name Sol dotna Creek Unit 10. Well Number SCU 41A-9 (ARCO 41B-9) 11. Field and Pool Swanson River Field/ Hemlock 5. Elevation in feet (indicate KB, DF, etc.)6. RKB 150' Lease Designation and Serial No. A-028997 12. Date Spudded �/�� 13. Date T.D. Reached 04/21/81 09/17/89 14, Date Comp., Susp. or Aband. 10/08/89 15. Water Depth, if offshore feet MSL 16. No. of Completions 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 10928'MD,10918'TV 10834'MD;10824' 19. Directional Survey VVES 10 NO ❑ 20. Depth where SSSV set --- feet MD 21. Thickness of Permafrost --- 22. Type Electric or Other Logs Run DIL-SP-GR, CCL -CBL -GR Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" -- --Surf 281 -- 11-3 4" 47.5# Surf 1998' 15-1/211 1200 Ax nmt 7" 231126029 Surf 99701 -10-5181, 1600 RX cmt 5" 18.0# FL4 -N80 9602' ' 611 175 sx Class G Sidetrack window '- ' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 10746'-10768'MD/10737'-10759'TVD w/12 spf 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3-1_19"&9-U8" 10441, 10398, 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS -OIL RATIO Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY -API (torr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None I V E D RECD OGT 2 61989 .Alaska Oil & Gas Cons Commisslon Anchorage Form 10-407 021 / W C 6Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE n 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. i %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 interval. Item 21: Indicate whether from ground level (G L) or other elevation (DF, K6, 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". Form 10.407 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. None "G" Sands 1031004' Hemlock 10,491' 31. LIST OF ATTACHMENTS Detailed Summary of Operations, Gyro 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Area Drilling Engr. Date 1 a 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. i %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 interval. Item 21: Indicate whether from ground level (G L) or other elevation (DF, K6, 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". Form 10.407 8 7 ARCO Oil and Gas Company Well History - Initial Report - Da= Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. e 3 District County, parish or borough Stat ARCO ALASKA INC. KENAI Field Lease or unit SCU 41 A-9 Ws11 no. SWANSON RIVER ADL: 028997 SCU 41 8-9 Auth. or W.O. no. Title AD6463 WORKOVER & DRILLING Operator AHOY W.I. ARCO 48.0000 Spudded or W.O. begun Date Hour Prior status if a W.O. P&A & SIDETRACK 9/02/89 00:00 Date and depth as of 8:00 a.m. 09/02/89 ( 1) TD:107951(10795 SUPV:BES 09/03/89 ( 2) TD:10795' ( 0) SUPV:BES 09/04/89 ( 3) TD:107951( 0) SUPV:BES 09/05/89 ( 4) TD:105451( 0) SUPV:BES 09/06/89 ( 5) TD: 98001( 0) SUPV:BES 09/07/89 ( 6) TD:100111( 211 SUPV:RWS 09/08/89 ( 7) TD:100111( 0 SUPV:RWS 09/09/89 ( 8) TD:100111( 0 SUPV:RWS The above is correct Complete record for each day reported GRACE 154 KILLING WELL MW: 9.2 VIS: 0 FIN RU. PULL BPV. SITP-3675 PSI, SICP-900 PSI. SET PLUG IN NIPPLE @ 10565. BLEED OFF PRESSURE. PULL DV FROM GLM @ 10528. CIRC 9.2 PPG BRINE TO KILL WELL. DAILY:$63,500 CUM:$63,500 ETD:$63,500 EFC:$1,263,500 TESTING BODE MW: 9.2 VIS: 0 FIN KILLING WELL. SET BPV. ND TREE AND NU BOP'S. TESTING BOPE. DAILY:$46,378 CUM:$109,878 ETD:$109,878 EFC:$1,309,878 MW: 9.2 VIS: 0 FIN TESTING ROPE. PULL SEALS F/ PKR. HOLE TAKING 36 BPH. PUMP HEC PILL AND SLOW LOSS TO 2 BPH. POR W/ TSG. STD BACK 2-3/8" AND LD 3-1/2". RU ATLAS. GIH W/ CMT RETAINER. DAILY:$32,227 CUM:$142,105 ETD:$142,105 EFC:$1,342,105 GIH W/ DP MW: 9.2 VIS: 0 SET RETAINER 10545'. TESTED CSG AND RETAINER TO 1000 PSI. OK. RU ATLAS AND RAN CBL. PU STINGER FOR RETAINER AND GIH WHILE PU 3-1/2" DP. DAILY:$34,738 CUM:$176,843 ETD:$176,843 EFC:$1,376,843 PU DC'S MW: 9.2 VIS: 0 FIN GIH WITH STINGER. BATCH MIXED CMT. DAMAGED STINGER. DUMPED CMT AND POH W/STINGER TO REPLACE SAME. GIH WITH STINGER AND SQZ'D 5.5 BBLS CMT BELOW RETAINER AND SPOTTED 12.5 BBLS ON TOP. TRIPPED FOR 6" BIT AND DC'S. (EST TOC -98001.) DAILY:$42,175 CUM:$219,018 ETD:$219,018 EFC:$1,419,018 POR FOR SECTION MILL MW: 9.0 VIS: 48 FPU BHA. TAG TOC @ 9998'. DRILLED OUT HARD CMT TO 10011'. CLEAN MUD TANKS AND MIX MUD. DISPLACE BRINE WITH MUD. POH FOR SECTION MILL. DAILY:$19,679 CUM:$238,697 ETD:$238,697 EFC:$1,438,697 CUTTING SECTIONIN IN 7" CSG MW: 9.0 VIS: 70 POR AND PU SECTION MILL. GIH. COULD NOT INITIATE CUT IN CSG. TFN MILL. CUT SECTION F/9910-9921'. DAILY:$23,151 CUM:$261,848 ETD:$261,846 EFC:$1,461,848 POR W/ BIT MW: 9.1 VIS: 65 MILLED SECTION TO 9970', (60' TOTAL.) MADE CLEAN UP TRIP PRIOR TO SETTING KO PLUG. DAILY:$30,964 CUM:$292,812 ETD:$292,812 EFC:$1,492,812 9 C) 10 &> 970 OCT2 ti 1 �1 . `-.r Alaska 011C,,41)[1-1qyp� r � r� i r all daily well Macon form are prepared for each welal. consecutively Page Yi'NVry Anchorage, s a 71 ARCO Oil and Gas Company Daily Well History—Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following selling of oil string until completion. District County or Parish State ARCO ALASKA INC. KENAI AK Field lease or Unit Well no. SWANSON RIVER ADL: 028997 SCU 41 B-9 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. GRACE 159 09/10/89 ( 9) WOC MW: 9.1 VIS: 40 TD: 98101( ) SET 11.5 BBLS OF 16.2 PPG CMT ACROSS SECTION. TFB AND TAG SUPV:RWS TOC AT 95481. WASH TO 9810'. CIRC OUT GREEN CMT AND WOC. DAILY:$22,464 CUM:$315,276 ETD:$0 EFC:$1,515,276 09/11/89 ( 10) SIDETRACKING WELL MW: 9.0 VIS: 37 TD: 9923'( 11 1) WOC. WASH CMT TO 98201. DRILLED FIRM AND HARD CMT TO SUPV:RWS 9915'. TRIP FOR KO ASSY. ORIENT W/ GYRO. DRILLED F/9915 — 99231. 7 DAILY:$18,790 CUM:$334,066 ETD:$0 EFC:$1,534,066 11) PERFORMING PIT MW: 9.0 VIS: 40 TD: 99751( 5 ) DRILLED TO PD. TESTED BOPE TO 3000 PSI. MADE 6" HO RUN. SUPV:RWS PERFORMED PIT=14.5 PPG EMW. DAILY:$27,607 CUM:$361,673 ETD:$O EFC:$1,561,673 09/13/89 ( 12) DRILLING MW: 9.6 VIS: 49 TD:103031( 32 1) POH. FIN TESTING BOPE. GIH W/BIT AND DRILLED TO 10268'. SUPV:RWS ST 3 STDS. DRILLED TO PD. DAILY:$21,848 CUM:$383,521 ETD:$0 EFC:$1,583,521 09/14/89 ( 13) DRILLING MW: 9.6 VIS: 46 TD: 0'( ) DRILLING FROM 10303-10386. CBU. DROP SURVEY. POOH, L/D 20 SUPV:B S JTS OF 3-1/2" DP AND 12 4-3/4" COLLARS. P/U 2 MONEL DRILL COLLARS AND 30 HWT DP. SERVICE RIG. TRIP IN HOLE. WASH/REAM 50' TO BOTTOM. DRILLING 10,386-4291. DAILY:$34,754 CUM:$418,275 ETD:$418,275 EFC:$1,200,000 09/15/89 ( 14) CIRCULATING AND RAISING MW MW:10.0 VIS: 44 TD:105391(1053 ) DRILLED TO 10536'. CIRC OUT GAS CUT MUD AND RAISE MW. SUPV:BES DRILLED TO PD. TFNB. REAMED TO BOTTOM. CIRC OUT GAS CUT MUD AND RAISE MW TO 10.0 PPG. DAILY:$33,892 CUM:$452,167 ETD:$452,167 EFC:$1,200,000 09/16/89 ( 15) CIRCULATING MW:10.0 VIS: 48 TD:107521( 21:) DRILLED TO PD. SUPV:BES DAILY:$23,240 CUM:$475,407 ETD:$475,407 EFC:$1,200,000 09/17/89 ( 16) POH FOR LOGS MW:10.0 VIS: 46 TD:10900'( 14 ) TFNB. DRILLED TO 10,900'. ST. POH FOR LOGS. SUPV:BES DAILY:$32,661 CUM:$508,068 ETD:$508,068 EFC:$1,200,000 The above is correct For form preparatfoNand distributic sse Procedures LMual Section 10, Drilling, Pages 88 and 87 Number all daily well history forms consecutively Page no. as they are prepared for each well. AR3B-459-2-B ARCO Oil and Gas Company Daily Well History—Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or per4orating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. t) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. uistnct County or Parish State ARCO ALASKA INC. KENAI 1AK Field Lease or Unit SCU 41 A-9 well no. SWANSON RIVER ADL: 028897 SCU 41 B-9 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. GRACE 154 09/18/89 ( 17) TD:109281( 2 ) SUPV:BES 09/19/89 ( 18) TD: 0 PB:10834 SUPV:BES 09/20/89 ( 19) TD: 0 PB:10834 SUPV:BES 09/21/89 ( 20) TD: 0 PB:10834 SUPV:JC 09/22/89 ( 21) TD: 0 PB:10834• SUPV:JC 09/23/89 ( 22) TD: 0 PB:10834 SUPV:JC The above is correct For form preparation 4(h4 distributi( see Procedures Manua action 10, Drilling, Pages 86 and 87 RU TO RUN 5" LINER MW:10.0 VIS: 46 RU ATLAS. LOG OH W/ DIL—SP—GR—CAL. MADE CONDITIONING TRIP AND DRILLED 28 ADDITIONAL FEET. POH. RU TO RUN 5" LINER. DAILY:$33,960 CUM:$542,028 ETD:$542,028 EFC:$1,200,000 WOC MW: 0.0 WBM RAN 30 JTS OF 5" 18# FL4S N-80 W/ BAKER LINER HGR. RIH Y W/LINER ON 3-1/2" DP. CMT'D LINER W/ 175 SX 'G' CMT W/ ADDITIVES AT 15.8 PPG. SET LINER HGR AND RELEASE F/SAME. POH FOR BIT. GIH TO 85791. CBO. WOC. DAILY:$29,443 CUM:$571,471 ETD:$571,471 EFC:$1,200,000 POH MW: 0.0 WBM FGIH AND TAGGED TOC AT 93951. DRILLED CMT TO TOL AT 9602'. TFNB AND BHA. CLEANED OUT LINER TO LANDING COLLAR AT 10834'. TESTED CSG, LINER AND LAP TO 2860 PSI FOR 1/2 HR. OK. DAILY:$52,872 CUM:$624,343 ETD:$624,343 EFC:$1,200,000 FILL PITS W/ BRINE MW: 0.0 NaCl FINISH POH. TEST BOPE. LD DC AND HWDP. RIH W/ BIT AND SCRAPER. CLEAN MUD FROM PITS. FILL PITS WITH BRINE. DAILY:$17,389 CUM:$641,732 ETD:$641,732 EFC:$1,200,000 CIRC AND FILTER BRINE MW: 0.0 NaCl FILL PITS W/ CLEAN 9.6 PPG BRINE. REV CIRC 60 BBL HEC—FRSH WATER SWEEP FOLLOWED BY 14— BBL FRESH WATER. DISPLACE W/ 9.6 PPG BRINE. PUMP SCOUR PILL, 30 BBL OF 2 PPB XC POLYMER AND 2 PPG 20/40 SAND, 1000 GAL OF 15% HCL, 10 BBL OF 2 PPG SC AND 2 PPG 20/40 SAND AND 20 BBL OF 3 PPG XC POLYMER PILL. CIRC AROUND TO SURF. CIRC AND FILTER BRINE. DAILY:$48,073 CUM:$689,805 ETD:$689,805 EFC:$1,200,000 CASED HOLE LOGGING MW: 0.0 NaCl CIRC. & FILTER BRINE. POOH. RU WESTERN ATLAS. LOG W/ PDK-100 & CBL. POOH W/ CBL AFTER TOOL FAILURE. DAILY:$22,089 CUM:$711,894 ETD:$711,894 EFC:$1,200,000 Number all daily well history forms consecutively Page no. I as they are prepared for each well. AR3B-459-2-B i ARCO Oil and Gas Company „ Daily Well History—Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. I) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday -of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish State ARCO ALASKA INC. KENAI AK Field Lease or Unit Well no. SWANSON RIVER ADL: 028897 SCU 41 B-9 Date and depth as of 6:00 a.m. Complete record for each day while drilling or workover in progress GRACE 154 09/24/89 ( 23) TEST LINER LAP TO 3000PSI MW: 0.0 NaCl TD: 0 RUN CCL/GR/CBL & GYRO SURVEY. RIH W/ MODEL 'D' PACKER AND PB:10834 SET @ 10785'. REPLACE HYDRIL. TEST LINER LAP TO 3000 PSI SUPV:JC FOR 30 MIN. DAILY:$30,514 CUM:$742,408 ETD:$742,408 EFC:$1,200,000 09/25/89 ( 24) TD: 0 HANGING DRILL LINE ON CROWN MW: 0.0 NaCl AP PERFORATE 10746'-10768' @ 12 SPF W/ WESTERN ATLAS. RIH W/ PB:10834 SURGE ASSEMBLY & SURGE PERFS. REVERSE OUT VERY LITTLE OIL SUPV:JC AND GAS. POH W/DP. TOOL JT. HIT PIPE RAMS AND DRILL LINE JUMPED SHIVES AT CROWN. RE -HANGING LINE. DAILY:$65,287 CUM:$807,695 ETD:$807,695 EFC:$1,200,000 09/26/89 ( 25) POH TO INSP. FISHING TOOLS MW: 0.0 NaCl TD: 0 RE -STRING DRILLING LINE. TIH & TAG FISH @ 1046'. RECOVERED PB:10834 APPROX. 9560' OF FISH, TOP OF REMAINING FISH @ 9592'. RIH SUPV:JC AND TAG FISH. NO RECOVERY. POH AND INSPECT FISHING TOOLS. (FISH CONSISTS OF ENTIRE SURGING ASSEMBLY. DRILLSTRING PARTED 1 JT. BELOW RKB.) DAILY:$41,289 CUM:$848,984 ETD:$848,984 EFC:$1,200,000 09/27/89 ( 26) GIH W/FISHING ASSY MW: 0.0 NaCl TD: 0 GIH W/ FISHING ASSY #4 & COULD NOT LATCH FISH. TF FISHING PB:10834 ASSY #5. LATCH FISH AND POH. LOST FISH 25 STDS OUT. FPOH. SUPV:JC GIH W/ FISHING ASSY #6. COULD NOT HOLD FISH. POH. LEFT 5 DOGS F/ ROLLING DOG 0/S IN HOLE. GIH W/ FISHING ASSY V. DAILY:$21,312 CUM:$870,296 ETD:$870,296 EFC:$1,200,000 09/28/89 ( 27) RU FREE POINT MW: 0.0 NaCl TD: 0 FGIH. MADE BLIND B0. REC'D 7 JTS TBG.GIH W/FTA #8. LATCH PB:10834 FISH. POH RECD 6" OF TBG. GIH W/FTA #9. LATCHED FISH. SUPV:BES MOVED FISH UP HOLE 8'. DAILY:$23,450 CUM:$893,746 ETD:$893,746 EFC:$1,200,000 09/29/89 ( 28) POH MW: 0.0 NaCl TD: 0 RAN FP. STUCK AT RTTS. MADE BO BELOW DC'S AND POH. RECD PB:10834 10 JTS TBG AND 16 DC'S W/X0. GIH W/JARRING ASSY. COULD SUPV:BES NOT MOVE FISH. POH. DAILY:$22,450 CUM:$916,196 ETD:$916,196 EFC:$1,200,000 09/30/89 ( 29) POH MW: 0.0 NaCl TD: 0 RECD XO AND BY-PASS TOP SUB. GIH W/BURNING SHOE. BURNED PB:10834 OVER BY-PASS SUB 2'. POH. SUPV:BES DAILY: $ 4 6, 664 CUM:$962,860 ETD:$962,860 EFC:$1,200,000 The above is correct Signature I Date ITitle For form preparation distributic see Procedures Manu Section 10, Drilling, Pages 86 and 87 Number all daily well history forms consecutively Page no. as they are prepared for each well. A83B-459-2-B ARCO Oil and Gas Company „ Daily Well History—Interirr Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim' sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish State ARCO ALASKA INC. KENAI AK Field Lease or Unit SCU 41 A-9 Well no. SWANSON RIVER ADL: 028897 SCU 41 B-9 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. GRACE 154 10/01/89 ( 30) PUMPING HI -VIS SWEEP MW: 0.0 NaCl TD: 0 RECD INNER MANDREL OF BY-PASS. GIN W/ BURNING SHOE. PB:10834 MILLED 1'. POH. RECD PORTED '0' RING BODY. GIH W/BURNING SUPV:BES SHOE. MILLED 1/2'. DAILY:$24,120 CUM:$986,980 ETD:$986,980 EFC:$1,200,000 10/02/89 { 31) GIH MW: 0.0 NaCl TD: 0 POH. GIH W/ JARRING ASSY. LATCH FISH. POH. RECD LOWER PB:10834 BODY OF BY-PASS. GIH W/ 0/S. LATCH FISH. PULLED FREE W/ SUPV:BES 20K PULL. POH. NO RECOVERY. GIH W/ BURNING SHOE. DAILY:$31,645 CUM:$1,018,625 ETD:$1,018,625 EFC:$1,200,000 10/03/89 ( 32) GIH MW: 0.0 NaCl TD: 0 FGIH. MILLED ON RTTS. MADE 2". TF 0/S. LATCH FISH. POH PB:10834 W/SAME. FULL RECOVERY. PU 4-1/8" BIT AND GIH TO CLEAN OUT SUPV:BES WELL BORE. DAILY:$44,277 CUM:$1,062,902 ETD:$1,062,902 EFC:$1,200,000 10/04/89 ( 33) TESTING BOPE MW: 0.0 NaCl TD: 0 CIRCULATE AT TOL. FGIH TO SUMP PACKER. NO INDICATIONS OF PB:10834 JUNK. CIRCULATE AND FILTER FLUID. POH AND PREP TO PU SURGE SUPV:BES ASSY. DAILY:$26,079 CUM:$1,088,981 ETD:$1,088,981 EFC:$1,200,000 10/05/89 ( 34) CIRC & FILTER BRINE MW: 0.0 NaCl TD: 0 FIN TST BOP. PU 2-3/8" TBG & RTTS & RIH W/3-1/2" DP. STAB PB:10834 INTO SEALS & SET RTTS @ 10,620'. TST CSG TO 3000#. PULL SUPV:RWS 37-1/3 STANDS, PU DISC VALVE & RIH. RU FLOW LINES. SET RTTS @ 10,623' W/DISC VALVE @ 3520'. SHEAR DISC, OPEN WELL TO PROD FLOWLINE. RISE IN FLUID LEVEL, APPROX 14.5 BBL IN 1 HOUR 20•MIN. REL RTTS & REV CIRC. MIX & PUMP 30 BBL SCOUR/HI VIS PILL. RIH, TAG FILL @ 10,767'. WASH TO 10,788'. REV OUT SAND (APPEARS TO BE FRAC SAND). RIH, 1-1/2' FILL IN SUMP PACKER. ATTEMPT TO REV OUT PACKER BORE. FILTER BRINE WHILE CIRC. DAILY:$26,280 CUM:$1,115,261 ETD:$1,115,261 EFC:$1,200,000 10/06/89 ( 35) FILTERING BRINE MW: 0.0 NaCl TD: 0 POH W/ SURGE ASSEMBLY. RIH W/ 1" STINGER ON WORKSTRING. PB:10834 REVERSE SAND OUT OF PACKER BORE. CIRC. & FILTER BRINE. SUPV:RWS DAILY:$25,218 CUM:$1,140,479 ETD:$1,140,479 EFC:$1,200,000 The above is Signature For form preparati see Procedures M Drilling, Pages 86 Number all daily well history forms consecutively Page no. as they are prepared for each well. AR38-459-2-B 7) ARCO Oil and Gas Company ;; Daily Well History—Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in descrlbinq Work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim' sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish State ARCO ALASKA INC KENAI 1AK Field Lease or Unit SCU 41 A-9 Well no. SWANSON RIVER ADL: 028897 SCU 41 B-9 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. GRACE 154 10/07/89 ( 36) PREPARE TO LD DRILL PIPE MW: 0.0 NaCl TD: 0 FILTER BRINE. POH. PU GP ASSY. GIH. GRAVEL PACKED WELL PB:10834 W/7 BBLS OF 8 PPG 12/20 SAND. SCREENED OUT W/2000 PSI. SUPV:RWS RETESTED PACK 2 TIMES. REVERSED OUT EXCESS SLURRY. RESTESTED PACK AFTER GEL BROKE. OK. CLOSED SLIDING SLEEVE AND TESTED TO 1000 PSI. OK. BUILD 140 BBLS BRINE FOR TRIP. DAILY:$15,950 CUM:$1,156,429 ETD:$1,156,429 EFC:$1,200,000 1.0/08/89 ( 37) RU SLICKLINE MW: 0.0 NaCl TD: 0 POH AND LD DP. PU 3-1/2" 9.3# J-55 EUE 8RD AB MOD X 2-3/8" PB:10834 4.7# N-80 EUE 8RD AB MOD COMPLETION ASSY. RU SLICKLINE TO SUPV:RWS SET 'PX' PLUG. DAILY:$89,209 CUM:$1,245,638 ETD:$1,245,638 EFC:$1,200,000 rhe above is correct of/ z For form preparationAd-distribution "a Procedures Manttjjggll Section 10, Drilling, Pages 86 and 87 AR38-459-2-B Number all daily well history forms consecutively '.nage no as they are prepared for each well. s ARCO Oil and Gas Company Ai Daily Well History —Final Repor Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish State ARCO ALASKA INC. KENAI AK Field Lease or Unit SCU 41 A-9 Weil no. SWANSON RIVER ADL: 028897 SCU 41 B-9 Auth. or W.O. no. Title AD6463 WORKOVER & DRILLING Operator A.R.Co. W.I. Total number of wells (active or inactive) on this Producing Interval 011 or gas cost center prior to plugging and ARCO 48.0000 abandonment of this well Spudded or W.O. begun Date Hour Prior status If a W.O. P&A & SIDETRACK 9/02/89 00:00 Date and depth Complete record for each day reported as of 8:00 a.m. GRACE 154 10/09/89 ( 38) RIG RELEASED MW: 0.0 NaCl TD: 0 SET 'PX' PLUG IN 'X' NIPPLE. PRESSURE UP TO 2500 PSI AND PB:10834 SET 'FH' PKR AT 10,397'. SHEARED OFF OF PBR. RELANDED TBG SUPV:RWS AND TESTED ANNULUS AND PKR TO 2500 PSI. OK. SET BPV. ND BOP'S AND NU TREE. TEST SAME. OK. CLEAN TANKS AND RR @ 2200 HRS 10-8-89. DAILY:$48,098 CUM:$1,293,736 ETD:$1,293,736 EFC:$1,200,000 Old TD New TO PB Depth Released rig Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) eotenuai test data Well no. Date Reservoir Producing Interval 011 or gas Test time Production Oil on test asit per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity corrected Allowable Effective date .na aQ Vv .a IV -- Signature For form preparation and di ri utio see Procedures Manual, Se . n 10, Drilling, Pages 88 and 87. a Number all daily well history forms consecutively I Page no. as they are prepared for each well. AR38-459-3-C DNINat of AtlanNeRkMINdCanp -11-� tF e-1- F I - ARCO ALASKA INC. Cook Inlet/New Ventures Engineering TRANSMITTAL OM TO: John Boyle FROM: Tom Wellman COMPANY: AOGCC COMPANY: ARCO Alaska, Inc DATE: Oct 20, 1989 WELL NAME: SCU •44iB-9 Transmitted herewith are the following Receipt Acknowledgement: Date: I -f3 -9 Return reciept to ARCO ALASKA, Inc. ATTN: Judy Boegler ATO 0 4 Post Office Box 100360 Anchorage, AK 99510-0 Alaska Oil & Gas Cons, COMMISSIM Anchorage sperrV-sun DRI! -LING SERVICES Mr. Brit Brown Drilling Manager ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 October 18, 1989 Re: Boss Gyroscopic Survey Job No. AK -BO -90103 Well: 41B-9 Field: Swanson River Survey Date: 09-23-89 Operator: D. Harger Mr. Brown: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Please note this is a tie-in survey with Eastman's Survey dated 4-14-75 Job #AM0475. Thank you for giving us this opportunity to be of service. Sincerely, L /'' Ken Broussard District Manager Directional Services Enclosures cc: Judy Boegler, Arco Alaska 1 copy, 1 diskette 8537 Corbin Drive (99507) * P.O. Box 231649 • Anchorage, Alaska 99523 1(907)267-0200 • Fax(907)522-3432 A Baroid Company SPERRY-SUN DRILLING SERVICES PAGE 1 ANCHORAGE ALASKA ARCO ALASKA, INC. DATE OF SURVEY: 09-23-89 SCU 41-B9 BOSS GYROSCOPIC SURVEY SWANSON RIVER JOB NUMBER: AK -BO -90103 ALASKA KELLY BUSHING ELEV. = 150.00 FT. COMPUTATION DATE: 9/24/89 OPERATOR: D. HARGER TRUE SUB -SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 9700 9699.43 9549.43 0 41 N 52.80 W .00 65.21N 54.83W 33.94 9800 9799.42 9649.42 0 29 N 48.30 W .21 65.86N 55.63W 34.17 9900 9899.42 9749.42 0 12 N 88.00 E .66 66.15N 55.76W 34.37 9925 9924.41 9774.41 3 11 N 75.10 E 11.94 66.33N 55.05W 34.85 9950 9949.32 9799.32 6 20 N 76.00 E 12.60 66.84N 53.03W 36.20 10000 9998.91 9848.91 8 12 N 70.70 E 3.97 68.69N 46.99W 40.55 10100 10097.83 9947.83 8 36 N 72.20 E .45 73.34N 33.13W 50.89 10200 10196.67 10046.67 8 54 N 69.90 E .47 78.28N 18.74W 61.73 10300 10295.39 10145.39 9 26 N 67.30 E .67 84.11N 3.90W 73.56 10400 10394.01 10244.01 9 36 N 64.10 E .55 90.92N 11.17E 86.37 10500 10492.74 10342.74 8 41 N 62.60 E .93 98.04N 25.38E 99.08 10600 10591.83 10441.83 6 37 N 58.50 E 2.14 104.54N 37.02E 110.08 10700 10691.24 10541.24 5 46 N 52.00 E 1.10 110.65N 45.91E 119.52 10800 10790.82 10640.82 4 41 N 51.00 E 1.09 116.33N 53.05E 127.78 10900 10890.48 10740.48 4 41 N 51.00 E .02 121.47N 59.41E 135.22 10928 10918.39 10768.39 4 41 N 51.00 E .07 122.91N 61.19E 137.30 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE -DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 137.30 FEET AT NORTH 26 DEG. 27 MIN. EAST AT MD = 10928 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 26.47 DEG. �7 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA► PAGE 2 ARCO ALASKA, INC. DATE OF SURVEY: 09-23-89 SCU 41-B9 SWANSON RIVER JOB NUMBER: AK -BO -90103 ALASKA KELLY BUSHING ELEV. = 150.00 FT. COMPUTATION DATE: 9/24/89 OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB -SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD -TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9700 9699.43 9549.43 65.21 N 54.83 W .57 10700 10691.24 10541.24 110.65 N 45.91 E 8.76 8.19 10928 10918.39 10768.39 122.91 N 61.19 E 9.61 .85 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE -DIMENSION RADIUS OF CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES PAGE 3 ANCHORAGE ALASKA ARCO ALASKA, INC. DATE OF SURVEY: 09-23-89 SCU 41-B9 SWANSON RIVER JOB NUMBER: AK -BO -90103 ALASKA KELLY BUSHING ELEV. = 150.00 FT. COMPUTATION DATE: 9/24/89 OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB -SEA DEPTH TRUE SUB -SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD -TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9700 9699.43 9549.43 65.21 N 54.83 W .57 9750 9750.00 9600.00 65.57 N 55.30 W .57 .00 9850 9850.00 9700.00 66.12 N 55.90 W .58 .00 9950 9950.00 9800.00 66.87 N 52.91 W .69 .11 10051 10050.00 9900.00 71.12 N 39.98 W 1.63 .94 10152 10150.00 10000.00 75.80 N 25.60 W 2.77 1.14 10253 10250.00 10100.00 81.23 N 10.84 W 3.99 1.23 10355 10350.00 10200.00 87.69 N 4.47 E 5.37 1.37 10456 10450.00 10300.00 95.02 N 19.55 E 6.76 1.39 10557 10550.00 10400.00 101.99 N 32.84 E 7.89 1.13 10658 10650.00 10500.00 108.08 N 42.61 E 8.55 .66 10759 10750.00 10600.00 114.21 N 50.44 E 9.05 .50 10859 10850.00 10700.00 119.38 N 56.83 E 9.39 .34 10928 10918.39 10768.39 122.91 N 61.19 E 9.61 .22 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES PAGE 4 ANCHORAGE ALASKA ARCO ALASKA, INC. DATE OF SURVEY: 09-23-89 SCU 41-B9 SWANSON RIVER JOB NUMBER: AK -BO -90103 ALASKA KELLY BUSHING ELEV. = 150.00 FT. COMPUTATION DATE: 9/24/89 OPERATOR: D. HARGER INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS TRUE SUB -SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MARKER 10004 10002.87 9852.87 68.88 N 46.45 W TOP G SAND 10491 10483.84 10333.84 97.41 N 24.17 E TOP HEMLOCK 10800 10790.82 10640.82 116.33 N 53.05 E SURVEY DEPTH 10834 10824.70 10674.70 118.07 N 55.21 E PBTD 10926 10916.39 10766.39 122.81 N 61.06 E 5" LINER BOTTOM 10928 10918.39 10768.39 122.91 N 61.19 E TD T ----------------------------------------------------------------------------- ARCO ALASKA, INC. SCU 41-B9 -- ------------------------------------------------------------------------- STRATIGRAPHIC SUMMARY MEASURED COORDINATES -------MARKER------- DEPTH --------TVD-------- WITH REF. TO WELLHEAD BKB BKB SUB -SEA ORIGIN: 71OFNL 660FEL SEC 09 T07N R09W TOP G SAND 10004 10002.87 9852.87 68.88N 46.45W TOP HEMLOCK 10491 10483.84 10333.84 97.41N 24.17E PBTD 10834 10824.70 10674.70 118.07N 55.21E 5" LINER BOTTOM 10926 10916.39 10766.39 122.81N 61.06E TD 10928 10918.39 10768.39 122.91N 61.19E ---------------------------------------------------------------------------- COMPUTER PROGRAM - SPERRY-SUN THREE DIMENSION RADIUS OF CURVATURE ---------------------------------------------------------------------------- DATE OF SURVEY: 09-23-89 COMPUTATION DATE: 9/24/89 JOB NUMBER: AK -BO -90103 KELLY BUSHING ELEV. = 150.00 FT. SPERRN7-SUN DRLG. oVCS. SCU 41-B9 SWANSON RIVER ALASKA 09-23-89 0 2000 4000 I- CL W C:) 6000 J Q U H 6000 w w 10000 12000 14000 VERTICAL PROJECTION START TVD = 1 FINISH TVD = 10918.39 SCALE IS 2000 FEET/IN 0 2000 4000 6000 5000 10000 12000 VERTICAL SECTION DIRECTION : 65.21 ARCO ALASKA INC. Cook Inlet/New Ventures Engineering TRANSMITTAL #362 M. John Boyle COMPANY: AOGCC DATE: Oct 3,1989 �I �3- C11, FROM: Tom Wellman COMPANY• pis a, WELL N : SCU 4 -9 2,5--6 Receipt Acknowledgement: D --C 36Gz- Date: Return reciept., ARCO ALASKA, Inc. UC VbD a� `ATM: Judy Boegler ATO 1390A CT 4 Post Office Box 100360 Anchorage, AK 99510-0360' Alaft QII & GS ConS. CommiSAR Anchorage MA 2,5--6 Receipt Acknowledgement: D --C 36Gz- Date: Return reciept., ARCO ALASKA, Inc. UC VbD a� `ATM: Judy Boegler ATO 1390A CT 4 Post Office Box 100360 Anchorage, AK 99510-0360' Alaft QII & GS ConS. CommiSAR Anchorage ARCO ALASKA INC. f Cook Inlet/New Ventures Engineering TRANSMITTAL #361 TO: John Boyle COMPANY: AOGCC DATE: Sept. 25, 1989 Transmitted herewith are the following FROM: Tom Wellman COMPANY: ARCO Alaska, Inc WELL NAME: S U 41B-9 150-133- 1B- 10-133- lot -2 -at- e2 Receipt Acknowledgement: D e. fiRm N 2 Return reciept to ARCO ALASKA, Inc. Pjaw Un & Gag On GpMp8*11 ATIN: N: Judy Boegler ATO 1390A Anchorage Post Office Box 100360 C4, Anchorage, AK 99510-0360' �9 i 77Z Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information. of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. PROGRAM40 LISCAN REVISIONS 5.2 PART NUMBER: W5790 -MICRO Start of execution: Thu 21 SEP 89 9:02a ****-'REEL HEADER LIS 89/09/17 ATLAS 01 'LIS CUSTOMER FORMAT TAPE' * * * * TAPE HEADER LIS 89/09/17 3972 01 'OPEN HOLE-DIFL only, MAIN & REPEAT AT 10914 To 9772 FT.f FILE I FILE HEADER MAIN .001 1024 CN ARCO ALASKA, INC WN SCU 41B-9 FN SOLDOTNA CREEK COUN KENAI STAT ALASKA PORMAT RECORD (TYPE# 64). ONE DEPTH PER FRAM TAPE DEPTH UNIT : F 10 CURWS NAME CODE SAMPLE# UNIT BYTES I GR 68 1 API 4 2 CAL 68 1 IN 4 3 RFOC 68 1 OHMM 4 4 RILD 68 1 OHMM 4 5 RiLm 68 1 OHMM, 4 6 SPD 68 1 F/Mm 4 SP 68 1 Mv 4 8 CHT 68 1 LB 4 * DATA RECORD (TYPE# a) 1018 BYTES DEPTH OR CAL RILM. SPD 8P CILA 10908.000 0.00000009+00 4.000000 0.2000000 0.0000000E+00 -80.00000 43.0430443043E+00 10858.000 42.31233 5.713526 5.961510 50, 436943 -53. 0637 173.6710 10808.000 87.57355 5.747289 7.375590 49.407�a --25.68245 147.4097 1.0758.000 57.95021 510750234 5.92591.8 51.95320 �-54.1.7278 180.7556 10708.000 59.47650 5.792333 5.284792 50.588870 --56.89658 223.2334 10658.000 109.1719 , 6.301572 7.627749 48.624641 -12,54729 139.6322 10608.000 52.35408 5.805326 21.71306 48.95941 52.96979 37.35793 10558.000 107. 5264 6.637461 8.202780 49.95930 -»12.12030 1.2.9.5830 10508.000 60.88722 6.488050 19.63976 48.61.871. -21.84076 54.04691 10458.000 44.69081 6.656443 7(f.8(►7299y{7 47.40_150 -5.677419 128-5937 128 . 5 MF 37 10408.000 47.+69229 6.004261. 8.075359 48.40141. -20.02411 1.37.0824 10358-000 64.17801 6.281315 25.71919 47.61880 -3.475440 52.8601,4 10308 * aaa 50.64352 6.459002 4.7291.83 48.801.71 -2.057299 222.2414 10258.000 58.42032 6.517449 4.127276 48.40141 -»3.975286 RFOC CHT RILD WEN 0.2000000 0.24100000 41. aaaaaaOE+00 3000.000 6.514364 5.75801.3 -11498.85 4187.422 9.998182 6.802272 -1.1498.85 41.51.81.6 9.174816 5.532332 --11.498.85 4222.820 84431850 4.47961.6 -11.498.85 41.78.625 10.97402 7.161673 -11.498.85 4103.195 30.69550 26.76808 -11498.85 4072.238 9.573450 7.717061. -1.1498.85 401.3.937 15.72267 18.50244 11.498.85 4029.423 7.946804 7.776432 -1.1498.85 4051.920 9,039600 7.294881 --1.1.498.85 4020.744 1.9.42966 18.91785 -11498.85 4047.848 5.063812 4,499611 -11498.85 3995.711 4.465802 3.553.708 -1.1.498.85 4007.692 1.0208.000 56.67055 6.383917 4.166432 50.4369+ -2.546043 263.5439 101.58.000- 61.31592 6.334046 3.636903 57.95851 -3.214238 31,4.8379 101.08.000 61.1.3844 6.40991.4 1.,434325' 49.03671 --2.965796 849.9534 10058.000 43.96251 6.434821 4.41.451.6 51.9591.1 -0.9807463 248.4,375 10008.000 63.07050 6.423114 2..834349 51.44270 2.7611.67 364.9028 9958.000 46.0+1532 6.930706 4, 341890 52.95901 0.1.62.5894 264.8494 9908.000 55.26483 8.049288 2.5851.08 54.03030 ..9.022427 338.5710 9858*000 23.36691 6.060307 1+f�,t�t�A� 54.55261 47.9301.9 ..QO.00 21.64732 9808.000 0.0000000R+00 64090775 0.2000000 O.00O0000E+00 -80.00000 0.0000000E+00 44874714 3.794434 ..11498.85 4006.826 6.715084 3.176238 -11498.85 4041.492 .2.21.4939 1.176536 11498.85 3980.593 4.563791 4.025157 »11.498.85 3984.766 3.153727 2.740456 -.11498.85 3959.937 5.186780 3.775731 --11498.85 3927.176 3.488448 2.953589 -11.498.85 3805.451 0.2783559 46.19508 --11.498.85 3820.074 0.2000000 0.2000000 0.0004000E+00 3000,000 TOTAL DATA RECORDS • 99 STARTING TAPE DEPTH 10908.00 ENDING TAPE DEPTH * * FILE TRAILER PILE # 2 * PILE HEADER* REPEAT.002 1024 FORMAT RECORD ( TYPE # 6 4 ) ONE DEPTH PER FRAME TAPE DEPTH OMIT : P 10 CURVES NAME CODE SAMPLE# UNIT 1 GR 68 1 API 2 CAL 68 1 IN BYTES 4 4 9772.00 '* 5 41%.L.WAW RILM w %p 68 .r 1 r...rr. .. r OHM 4 6 SPD 68 1 F/MM 4 7 8P 68 1 mv 4 8 CHT 68 1 LR 4 9 TTEH' 68 1 LS 4 10 CILD 68 1 mmso 4 * DATA RECORD ( TYPES# 0) 1018 BYTES * DEPTH OR CAL RILM SPD 8P CILD 1C91�4yj[�.000 O.00DO�►J+Ot�#�.(E{�:+(t�()0 4{�.00tom}](0[/0�0 0.2000000 O.00OOOOOE+M0 -80.0 000 0.00000000+013 10864.000 46.69920 5.596204 6.048190- 45.99532 -43.51204 183.1474 10814.000 -62.89573 5,717825 6.012847 46.99532 -44.97282 175.4317 10764.000 56.86696 5.744225 4.64581"x4 46.99532 --44.53..924 242.1"x997 10714.000 51.76306 5,735010 4.445661 46.99532 -58.05396 257.7585 . 57 i 7585 ' 10664.000 147.9603 60338190 7.3567999 46.99532 -8.137352 146.7886 10614.000 41.67168 5.733779 48.1.1455 47.99519 --50.47589 19.25099 10564.000 101.1272 6.6541[�2�;8 7.654359 47.99,1, 19 -7.3.+.,Jy0106 139.6456 10514.000 0.1}1iO0000E+00 6,835666 0.2000000 0.00OOOOOE+00 -80.00000 0.0000000E+013 :1' POC CHT RILD WEN 0.2000000 0.2000030 Q.000c34OOE+00 3000.000 6.892626 5.460083 -11498.85 4187.459 8.735645 5.713251 -11498.85 4180.516 7.227086 4.120317 11498.85 4166.676 8.551741 3.879600 -11498.85 4110.094 310.5353.5 6.812516 -11498.85 4070.323 45.17824 51.94537 -11498.85 4023.280 8.924831 7.160982 -11498.85 4040.025 0.2000000 0.2000 00 0.00000000+00 3010.000 TOTAL DATA. RECORDS « 38 STARTING TAPE DEPT =i,'-10914.00 ENDING TAPE DEPTH 10482.00 **** FILE VILER **** * * * * TAPE TRAILER * �r LIS 89/09/17 3972 TOTAL RECORDS IN THIS LOGICAL TAPE -0 147 **** REEL TRAILER LIS 89/09/17 ATLAS 01, TOTAL RECORDS IN THIS LOGICAL REEL : 148 TOTAL RECORDS IN THIS PHYSICAL REEL: 148 End of execution: Thu 21 SEP 89 9:02a Elapsed execution time.-- 29.27 seconds. SYSTEM RETURN CODE = 4 PROGRAM: LISCAB` REVISION: 5.2 PART NUMBER: W5790 -MICRO O 0r pa Start of execution: Mon 25 SEP 89 10:25a r **** REEL HEADER LIS 89/09/22 ATLAS 01 "LIS CUSTOMER FORMAT TAPE' * * * * TAPE HEADER LIS 89/99/22 3979 01 R��,�IVED 'PDN -100; 4 PARTS AT 10808-3082 FT, REPEAT*- 10809-10569 FTf FILE # 1 FILE HEADER **** PART 1.001 1024 CN ASKA, STC WN CU 41B-9 FN _ CREED STAT ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FSE TAPE -DEPTH UNIT : F 19 CUR' 'ES z NAME CODE SAMPLE# UNIT BYTES 1 CCL 88 1 VOLT 4 2 SPD 68 1 FT 4 .3 LS 68 1 CTS 4 4'' SS 88 1 CTS 4 .5. C i 68 1 CTS 4 8 CElS 68 1 CTS 4 7. G2 68 1 CTS 4 a CR 68 1' API, 4 11 8GMA 68 1 DIM 4 1.21.929.2 '4788.320 12 CSS 68 1 Cis 4 101.4620 271..6479 I, I'a8 68 1. CTS 4 14.99850 1919.348 14 EKL 68 1 4T8 4 0.2673284 1.6.94791. 15 BKS 68 1 CTS 4 12.83651. 1..734241 16 RATO 66 1 DIM 4 1.29681.1. 1624.463 17 RICE 68 1 D114 4 1.81.7504 31.6.2600 is RIN 68 1 DIM 4 15.99840 2501.439 1.9 RBOR. 68 1 DIM 4 0.1,61.1,617 i4.834�70 * DATA RECORD (TYPE# 0) 968 BYTES 1.5.38 T 85 12.52447 DEPTH 1.758476 CCL O.00OOOOOE+00 8PD 1224.849 LS ss 1 1.272.798 GEIS. 201.1.489 02 25.58382 G'R MCN MSD 269.9360 SGMA 16.04027 Css 1.847514 iss Bn BKS 1850.374 RATO 12743.62 RICS RIN RBOR 1.084 8.000 100.0000 0.00O41OOOE+00 O 0 OOOOOOOE+410 0.00OO OOE+CSO 0.40410000E+041 41. O0O41OOOE+00 O.00OOOOOE+00 O.00 OOOOE+00 O.0Ot1t14' OOE++041 O.00OOOOOE+041 0.0000000E+40 O.041O41414' OE+410 O.00OOOOOE+00 0.00OO OOE+410 O.00OOOOOE+00 O.00OOOOOE+00 -6.000000 5.4 00000 -1..000000 10758.000 0,0000000E+0 ' 0 14.99850 2044.524 35995.1.3 1.386►3.01. 1.21.929.2 '4788.320 48.23741 2009.700 0.1981.404 1.6.43797 24795.58 334423.7 101.4620 271..6479 17.7+0934 13.1.3115 12.76724 1.797458 107084-F000 0.00000000+O 14.99850 1919.348 36495.54 1.3772.29 1.21.292.1 4498.1.1.7 48.20366 2009.458 0.2673284 1.6.94791. 24750.82 32561.3.1 122.9374 322.1.511 19.03000 1.3.11084' 12.83651. 1..734241 10558.000 0.00000,00E+00 40E+00 15;99840 1290.981. 30986.21. 81.32..555 1.29681.1. 1624.463 71.39432 2013.418 002515497 24.22774 213300-32 325533.4 1.81.7504 31.6.2600 23.98509 15.26423 1.2.96829 14811131 10608.000 9-.899998 15.99840 2501.439 38471.58 16287-,74 127970.0 6145.223 400-74641 2009.494 0.1,61.1,617 i4.834�70 27164..46j 338509.2 102.851.0 2614.5291. 1.5.38 T 85 12.52447 12.21987 1.758476 1.0558.000 O.00OOOOOE+00 1.5.99840 1224.849 29463.45 6771..71.5 1.29382.4 1.272.798 6+3.18372 201.1.489 04'43731.86 25.58382 20209.64 3221.48.1 133.8500 269.9360 23.67709' 16.04027 13.34803 1.847514 10508.000 O.00Oi1OOOE+00 1,5.99840 1850.374 3419�4.20 12743.62 114440.6-4282,484 35,45230 200$ . 786+ 0.2293004 1.6.39987 23327,80 302488.0 108.6764 249.9490 18.44923 13.48330 12.6761.6 1.718311. 10458.000. . 0 *- 0000000E+04 1.4.. 99850 1706.405 32192407 W4 4k w`!Wf w 224.1760 .f.f sAf;✓f W,& 18.81.291. 404.4. v4+•wr 13.63509 wwwv- • • +. 1.2.54931 . •••• •••• 1..785719 /04084000 O.00OOOOOE+00 1.4.99854 1717.467 33302.07 1.2124.00 1.1.2598.0 3737.792 30.43892 2008.223 0.83053234-01 1.7, 77036 22596.87 300385.6 65023500 252.5690 1.8P72609 13.32241 12.90231 1.712343 10358.800 0.0000000E+00 14.99850 2234.726 32553.83 11.677.54 124613.6 3772.547 34.90910 1997.790 331 51.41. 17.26520 23081.64 305685.7 94.57701 294.8579 14.50273 13.38486 12.57305 1.735442 1.4308.000 0 P 0000000E+00 1.5 o03420 1397.450 29312%.22 9489.035 104266.6 264.:✓�4.411 31..45718 2005.424 0.2379901 1.9.48303 19716.1.2 276493..2 72.84100 261.2830 24.95476 1.3.9302 12.84828 1.735456 10258.000 t1.00OOO00E+00 15.99840 1364.913 29016.93 919310336 102676.0 2580.205 31.42632 2005.705 0.226 365 19.43301. 19447434 275092.7 107.0100 247.3630 21.22337, 14.61.106 12.86667 1.712033 ,TOTAL DATA RECORDS8 STARTING TAPE DEPTH' = 10808.00 ENDING TAPE DEPTH 14224.00 ** FILE TRAILER **** FILE 2 **** FIDE READER *** PART' 2.002 1024. * FORMAT RECORD ( TYPE# 64 ) N DEPTH PER FSE TAPE DEPTH UNIT a F 19 CURVE a NAME CODE SAMPLE# UNIT BYTES 1. 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X300303 0.0O03OOOOE+00 650.0000 04000000E+00 0E+00 03.030)0303OOOE+00 O a_ 0iOO4O0 OE+0?03 03: 0,030��0003E+0303 0 « vci0r�0O1�E+�?t1 0, o�Ot3�00�+�� 03.0 03000300}E+403 03.01040303030.E+030 0.0303003030348+00 0 ' 0O0'303000tE+00 03.0000000E+00 0.0000000S+00 0038+0303 03. i1O0303OOOE+00 -5.000000 5.000)0030 -1.00300+00 621.3.0300 0.0303003OOOE+00 17.998203 1097.842 26385.6 6475.602 1304290'8 1341.674 33.250318 2019.201 0.471.6573 24:1.9482 1.9403.98 321667.8 11.2.0860 240.95103 24.02576 16.64282 1.1,020494 1.922277 6163.000: 03.013003030303E+003 19.998034 11039.580 25491.. 803 62020'715 1241.91:5 1190.X38 30:47211. 20319.860 0.6400527 24-.99422.18597.62 3122+65.9 55.73599 234.16803 23.03189' 16.56898 1.1.27857 1.948033 6 1.j1�.3+.01pOO+y O.00O{3++�OOE*00 1.9.]998003 1661.804 30047.05 9858. w93 ! 137041' • 9 3140 a O92 303.79826 �r0 0 ♦ 551 0.3247454 17.83504 224033.42 3403944.0 84.40342 230.7980 18,14194' 15.31.325 1.1..32256 2.03035237 6063.000- 0.0000000B+00 0040 B+0303 1,8.99811 1116.093 24735.00 6071 « 81,6 122252.7 1286-« 380 23 � 48413 20321.828 0.3499449 23.76999 181.99.51 306040.1 32.64201 205.29503 22.1.8 1403 16.634903 103.43523 1..939966 6013.0030 03. i30313O40303E+00 1.8.4401.1 1233.979 26461.59 7PI2.992 131652.2 1637.721. 36,41730 2122.2031 0.g359O310 19810.33 318843.7 61.96642 265.4600 .220'10695 21.44353 1.6.39407 1.1.55945 1.9950332 5963.000 Q.0000 OOOE+00 "18.44 311. 1.048.434 24675.86 61.34.375 1.20391.1.2 1.382.302 22.29594 2422 0,516 03.3549893 23,011565 1.8205.20 303851..4 77.98001 238.6760 23-450261 16.91374 1.1.50941 1..957326 5913.000 0 « 030403130303E+003 18.. 404403 16015:1.12 29354.037 1.0 062.23 132274.4 341,1, 567 22.94693 2025.605 0.21.78068 16.69612 22`0}72:67 337165.2 71.25401 21.7.304€3 1.8.30609 15.350129 11..31293 2.03037591 5663M00 0+1.o1!oo'+Vitof * oo 18.99811 165Y .art90 28330-41 1001.9.00 133223.1 3537.304 21..99173 2027.150 01.2925940 1.5.93166 21.937.38 333650;4 61.99001 289*3560 17.01820 15.27897 11.19241 2.022141 5813. X300 0* 0000100E+010 18.4401.1 167E.825 29578.09 1.0491..95 1.35883.6 3473.179 22.44017 2024.954 0.5901870 18.88790 2257,9.47 343146*1 77.83800 218.1240 17.54251. 1.5.63111 11.27778 2.026865 5763.000 0. O13OOOOOE+00 18.99811 1326.21.0 27458.61 $136.074 1.32084.4 2205.836 29.26569 20244719 0.2061461 19.7801.1 20553.23 325345.4 74.34601 1.94.6540 .20.71774- 15.97303 11.50629 1, 981.992 5713.000 0.0000000E+00 18.9981.1. 1257.337 24688.83 75614 352 1.170 33.4 2112#1639 29.15056 2020.502 0.3205333 19.37184 18499.49 294934.4 83.50500 242.5210 19.69040. 1.5.67002 11042802 1.987227 5663.000 0=0000000E+00 18.99811 1507.368 26905.04 9.37.352 1.29084.9 .3001.682 22.97382 2024.604 0.35911.41. 1.7.013055 20717.99 324841.4 6..41699 231..0240 17.92241 15.63471 11,.1.8465 2.049914 561.3.000 O.0000040B+00 1.8.99811. 1109.788 24539.30 633+x.352 1251.21 * 3 1375.948 33.09243 2022.827 0.2494488 23.28928 1.8474.49 308375.9 76.67401 24543030 22.09970 1.6.77608 11.23608 1.991388 5563.000, 0.001000100E+00 18.99811. 1030.324 22253.62 5739.062 105477.9 1.278;686 12.72899 2024.202 0.2478181 22.83209 16135.29 267100:8 44.011.701. 163.31.00 21..67561. 1.6.38486 10.79259 1.955104 5513.000-- 03.0000000E+001 1.8.99811. 1.097.786 244424.37 6033.133 ' ' 1.201458.9 1.1.96.695 .29.62820.. 2024.923 0.3504224 24.42299 1.7906,83. 295069.2 '83.33501. 251.4820 22424695 1.6.28571 11..12524 1.973441 5463.0001 0.OQ.00OOOE+00 18.9981.1 959.3298 21546.37 5866.5/5+ 9 100903.7 1.359y.259 9� i 5�4w1�.302 2019.6{44 0.4615305 2'2.13029 156674.23 253336.4 60.57301 1.75.9250 22.43875 1.6.11.034 10.77587 1.91.7700 541.3.000 0.00010000E+010 0.0000000E+00 0.0000000E+00 01.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 13.0000000E+00 0.000001005+00 0.00000011E+00 -5.000000 650.0000 0.0000000E+001 0.00000008+00 5.0000!0 0.00010000E+00 0.00000010E+00 0.0000000E+00 -1.0000100 TOTAL DATA. RECORDS 1.45 STARTING TAPE DEPTH M 6263.00 ENDING TAPE DEPTH = 5399.00 * FORM&T RECORD ( TYPE# 64 ) OWDEPTH PER FRAM TAPE DEPTH UNIT ' : F :+ CURVES -NAME CODE BALE# UNIT BYTES CCL 68 1 VOLT, 4 2,.' 8P0 68 1 PT 4 .3. LB 68 CTS 4 4 8S 68 1 CTS 4 5 'Ci 68 1 CTB 4 6 GEIS 68 1 CTS 4 7.1 C2 6e 1 CTS,: 4 .. 8 OR 68 1 API 4 9 MON 68 1 CTS 4 10 MSD 68 1 CTS. 4. 11 BCMA 68 1, DIM 4 12 C88' 68 1 CTS 4 13 I88 58. 1 CTB 4 14-113KL 68 1 CTS 4. 15 BKS 68 1 CTS 4. 16 RATO 68 - .1 DIM -.4 17 RICB 8 -1 - DIM = . 4 18 RIN 68 1 DIM 4 19 RBOR 681, 1 DIM 4 DATA RECORD ( T Y'PE # 0) 966 BYTES DEPTH CCL` SPI) LB 8B C1. GE18 02 OR MON MSD SOMA CSB IBs BKL BKS RATO RICE RIAS RB+OR 5452.000 1000.6000 O.00O0000E+00 650.0000 0.0000000E+00 0.0000000E+00 0.0000000E+o0 0.,0000000E+Op 0 w 0000000E+OQ 0.0000000E+000.0000000E+00 OpOOO0000E+00 0.00000bOE+QO 0pOOOOOOOE+00 0.000OOOOE+00 0.+OOO0000E+00 OsOOOOOOOE+00 -5.'000000 50'040000 -1..600000 5402.000 0.000Q000E+00 18.10741 1274.827 27960.72 74691746 133847.9 173.2.150 270.28983 2014«393 0.2399269 22$37474 20585.46 325373.5 78.53600 219.7670 21:92725 15.75939 11.27591 1.929505 5352.000 O.00OOOOOE+00 1.8.23401. 2203.351 26354.54 187.3590 5302.000- 83 14.371 302.X1008314.371 001658832 257.2639 .Lr. a &..Owj w* 21.88666 040000000E+00 a1.35688 ..'" ]6 :.r0.3L73a54 20A,09943 W6 wI A. / F 1.5.99748 1,8.234{11 22x3«194 21193-079 15.84731 11.06428 1409.561 23.99738 334567.4 11.. 32357 1.935792 28342.14 2018:779 58.1.6800 1.963 926 5252.0010 13.01301311134E+1311 23.34837 21131.7.32 28835.78 71.83.691. 1.22995.1 .1814-9981i1204.48.4 1655, 383' 2009.881. 0.3409973 22.34944 15265013; .70250456 298308.4 48.7451111 196.4980 22.06506 25.55842 11,08157 1.893196 52 02.000 7310.547 0.45961.70 249.7634 515�r2. 000.} 7135.852 0.440131.1.8 2;,T7.6821 51.02,000 690}9.926 0.4 w'' 49 0�36 , 265..2070' 5052.000-, 6836.898 0.3611.015 293.6501, 5002-000 .�y ry. 01.2522717 26x2.3521 4952.0010 7773.1.56 0:47841.58 263.6101 O. OOOOt3OOE+00 1.321.95.9 21.36150 2135809 O . 00001100E+ 00 135609.9 22.74886 1.9.75807 is. 99811 1837.122 20225.63 1.6.18849 18.79811. 1766-238 21057. 63 1.4.80223 11.040001008+00 ..18.99811 136775.615117.657 O.00OOOOOE+130 23.34837 21131.7.32 22.66447 1.6.720158 0,0000000E+00, 18.99811 136043.3 1.566.6+91. 22.71017. .20222.59 21.62543 1.6.21.408 13.00OOOOOE+00 1.31,673.4 21.53680 22.25734 O.00000 OOE+0 0 1.37672.9 21.50.88 . 21..03021 18.998.1 1811.785 20089. i5 1.6.93051 18.99811 1974.489 21152.301 16.101324 1269.281 28.14421. 128085.5 11.36545 1414.679 25.54927 327014.0 9.742215 1191.928 28.56122 y{ I+Wy� 3362+�� .8 11,.38570 1249-078 29.91302 3260017.3 1,0.92901 1221.1 68 301.03581 335024.3 1.1.64540 1.362.314 29.49536 336944.8 1.1..06087 27158.65 20107.985 75.07599 1.94211.5 29429.71 2448.983 63.29201 1.871945 27110.81, 2009.3�}5�)8 1.953427 27024��.pr�9ry.5{ 20019.243 88.85201 1.941.394 2111.2.84 2407.029 701.53000 2.022415 28562.67 20)08.216 99.15401, 1.949002 4902.01001 O.00OOOOOE+130 19.88879 1532.487 28970.46 8804.367 134699.7 2660.421. 21.92162 2009.271 €3.,2476696 1.8.45886 21.608.82 326815.0 79.75200 238.82901 18.92239 1.5.19988 10.99684 1.995528 4852.000 6837,367 0.3378949 j� 28.1.425'0'{� O. OOOOOL`VA +00 1,31797.2 23.00479 21..84952 19.65300 1.527.965 19866.017 3.6.17903 4802.000 0.000O0 OOE+0101 19.998110 1231.699 34.51,698 321,688.6 1,1.017327 1251.296 27068.36 2011.569 85.43102 1.996481. 26962.98 V . "w W w/ w "x "u F 239.0660 iAf 4. . V +i V we. ,. 21.58907 +'i+ w r/ w✓ 0 . W w 15.85470 10 * 89009 -------- -_..--T239.0660 1.999290 4752.000 0.00110000E+00 1.9.99800 1683.878 2+458 .14 5736.953 1.24836.1 x.02 ! , 5 30 21'4 29399 ,G010.655 0.3340405 25.68892 18188.85 303495.9 78.68501 274.3901 22.60945- 16.38935 10.97826 1.941313 4702.000 0.0400000E+00 19.88879 1366:095 25038.16 -,571;6.922 133703.3 1065.11.83 33.30751 2009.027 0.713533+5 25.8978"7 18962,.7. 320520.9 100..1190 .264.5251 23.48244 16.76552 1.1.1.2463 1.' 945157 4652.000' 0.0000004E+00 19.99800 11.25.765 25423.41 5885.121. 132189, 0 1207.885 31.07503 2009.725 0.6712725 2+4.61084 1.9053.68 320555.9 64.35800 273.8721 22,'57664" 1.6.74884 101.94118 2.002662 4602.000 00-0003000E+00 19.3431.1 1174.974 25563.55 6092.621 124564.3 1.147.751 31.02182 2008.141 4.4455249 25.27986 1.8607.17 30704643 80.67599 246.2880 21..73361 17.0100 1.1..1.6021. 1.961.489 4552.000 O.00O0000E+00 1.9.99800 1245..11.5 25275.50 7363.219 120372.6 1937=530 20.8661.5 2010.022 13.3706324 .20,,-53198. 18843, . 77 3t007�89}.8 744;00400 4 181. 51170 20. 25031 15.86568 ! 1 w 319856 /41040w0j 2 . 00 0 963 2'.007963 450.:2.00 hP. OOOOOOOL#" +00 19. 9:wr660 1116.646 25451485 6387.914 1.34041.7 1.345.164 26.31734 201.1.. 638 0.5007297 23.72411. 19345.79 3246575 92.49400 273.8271 22.79480' 17.1.9475 11.35884 2.041.841 4452.000 0.00000002+00 1.9.99800 1025.311 23926.35 5465.535 1. 8817.1 1033.551 29.+68221 2012.559 0.5481244 25.85963 18231-55 322200: 4 86.3220 1. 250.0550 }yy( 23.2781.8 17/j .16405 1.1.24330 2.031359 4402.004 0.00000609+00 1.9.99800 1644A03 903 28302.57 897?.349 145352.8 2714.115 1.8.301.88 2012.636 0.3914069 18.13400 22266.93 348443.9 46.90102 257.03 .0 17.22128 15.63335 1.1.401.042 2.020802 4352.+000 O.00OOOOOE+00 1..9.99800 1.564.554 28122.1.9 8875.203 1.44778.2 2650..548 21.46124 201.30-551 0.380241.3 18.54961. 22203.55 343781.2 84.24800 224.6280 18.38426 15.61.354 11..13165 1.999643 43012.000 0.0000003E+4+0 19199800 1.344.640 27137.15 74.5.852 1.41582.4 1776.521 24.33894 2014.434 0.4679465 21.88158 20827.85 337079.7 1.08.3860 275.9990 20 � 14069 16.01.259 1.1..37489 2.04951.2 4252.000 Oa OOOOOOOE+00 20.7621.0 1.491.2.38 26070.38 V. 4403.U,kU 261.6030 ,% f . g,74 / ca 1.8.8321.1 c. „t.yruv. a+�. 15.60973 .+,r.r........... 11.15077 1.987148 4202.000 O.00O0000E+00 20.88876 1408.107 27416.61 8235.258 138076.5 2336.946 21.48720 201.5.1.22 0.4568611. 19.29329 21099.'95 335096:7 67.95601 237.1220 1.9.53403 1.5.77864 11..03376 2.014639 4152.000 O.00OOOOOB+00 1.9, 99800 1453.760 27889.12 7886*199 1421.10.1 2022.399 20.49306 2013.091. 04:4519382 20.53673 21250.94 339252.6 67.54500 253.0920 1.9.21593 15.82377 11421413 2.011909 4162.000 0 *, 600 10009+00 19.99800 1.488.311. 28982.39 O:.53.609 142016.E 198 .029 24.3 026 2013.`701 01.1809564 21..29771. 21634. 86 340014.4 86.74500 308.2681 1.9.51312 15.61647 1.1.13202 1.994420 4052, 000 03.00; OOOOOE+00 20.10721 1.433.740 28201..93 7667.309 141.718.5 1.844.552 24.74947 2014.474 03.1884965 21:80241 21.233.26 330056.7 1032.5060 277.0291 19.61.864 15, 56954 10.96951 1..9451.45 4002.000 0.430300000E+030 20.7621.0 1412.0380 2861.3.77 .77903.699 1389560:2 2054.311. 230'433287 2014.748 0.4601969 20.58057 21.306.64 329958.9 69.5 51.01. 21.7.0190 200-26405 15.61861 11...34070 1.991.015 3952.600 4, 0000000E+00 20.76210 1.281.. 839 27139.34 -" 233.562 1.391.36.7 1.633.607 1.8..18501. 201.5.443 03.4390729 22.74751 205511%'87 331735.9 65.17500 272.3020 21..20332 16.4.3222 11*46992 1.986304 3902.000 0.430003000E+00 20.99791 1415.337 27528.91. 7097.277 1.38184.2 2142.631 16.45226 2015.348 0.4018598 20.22734 203938.-69 333660.8 64.41400 255.8640 1.90'48396 1.5.9031.1. 1.1.42529 2.001795 3852.000 43, OOO0000E+00 20. 888703 1283.363 26768.84 .703314'281 1395011*6 1.722.365 18: 82922 2017.066 03.5229257 21.62274 203437.45 326952.4 76. 53300 221-8640 '20.74557 1.6.04388 11 , 2031.6 1.965389 3802.0W 0.43000000E+00 203.99791 1070.1030 2491.4.65 5997.988 129176.6 1.1850792 24151.099 201.5.688 0.2368852 24> 64331. 18674.43 316444.8 80'.94000 285.0459 23.25192: 1.6.81375 11.47723 1.9941.69 3752.000 0.0000440E+00 20.99791 1.122.301 25256.85 59911914 132140.,'2 11.68.81.1 25.90645 201.5.365 65j0855`46 0.277.6589 25.4f7�569 19y0Q43.54 317314j}'.( 6 77.5710 6 2 7 i . 658:r� 22. 54294 15. 87312 11. 22210 2.022675 3702 0001 0.00000003E+00 20.99791. 1278.265 26451.89 - 'iF a V +✓ .N' 'M/ s4 +F J 299.2700 SIM iw # wi. M/ 1A SIM 1+ 20.62549 w Y w w wJ .. 16.42741 .� � ... � � 11..1.7844 _, — _ _ _ _ - _ ,... 2.015707 3652.000 O « C#OOOOOOE+00 20.99791 1069.587 25021.82 5741..379 130750.2 1036.018 27,15356 201.7.763 0.2878001. 26.10539 1.87'7 , 23 31.7950.2 79.70300 263.71.80 23.423 30 1.7 ».1.8161 1.1.39578 1.955531. TOTAL. DATA RECORDS 306 STARTING TAPE DEPTH = 5452.00 ENDING TAPE DEPTH 3620.00' * * FILE _ TRAILER * * , FILE # 4 FILE ,HEADER PART 410004 1024 * FORMAT RECORD (TY'PE# 64 ONE DEPTH PER FRAME. IT1 E DEPTH UNIT.'' F 19 CURVES � NAME CODE SAMPLE# UNIT BYTES 1 CCL W. 1 VOLT 4. SPD 68 1 PT 4 3 'LS 88 1 CTS 4, 4 SS 8' 1 CTS 4 5 G1 68 1: CTS 4 6 i EAS 68 1 CTS 4 7 G2 883 1 CTS 4- 8 OR .68 1 AP 1 :,4 9 - MON 68 -1 CTS .. -4 20 -MSD 68 CTS :,4 ill SOMA 68 1 DIM � 12 CSS 58 1 CC'S 4 23 ISS 68 1 CTS 4 14.' :. BKL 68 1 CTS 4 15 BKS 68 i CTS l8 IRATC 68- 1 DIM 17 : R,2CS 68 A' . DIM 4 18 RIN 68 1 DIM 4 19 RBOR 68 1 DIM.. 4 * DATA REC ( TYPE# 0) 966 BYTES � ' DEPTH . -CCL SPIE LS $S G 1 GEIS G2 OR ."MON MSD' CSS..' x8$ :BKL. SKS RATO- RICS' RIN RBOR 3670.000 03.03430434,30343E+030 0.13043030003E+443 0.043`000043E+00 3620.000 5427.1.87 0.3996097 266.69039 357000 00 5838.691 03.3 481x,781 268:3911 3520.000 6296.137 0.5947534 232.4580- 34700000.:.. 4976.957 0.5831456-- 281.6379 .5831.456..281.6379 3420-000'' 6926.879 0,-31741364 274.4290 3370.000 8674.559 0.303'9317 31.4.1.37+ 3320.000 5184.1.91. � 6«36 rr.���y81.5 393y E 65043 100.0300303 0 a;loo034104343E+0303 4313130000E+1313 13.4311000430E+00 43.010434303003E+043 130413.6 25.81.129 24.05363 0 430000100E+130 1.34877. 25.130375 23.02673 0.0000000E+00 0.4000000B+00 43.043O143OOOE+1303 -5.000000 1.7.99820 1043.746 1,8592.25 17.035742 1.7.99229 3.207.523 19106.95 16.84238 43.0004303043E+ 0313 1.7.4)3 4013 1.25062.7 1324.021 24.89093 18779.49 23.53506 16.85301. 0.0000000E+00-- .17-99820 130575.8 823.5881 28.27942 1.81.89.81. 24.07491 17.29742 43.001344300E+030 1.30'1321�.6 22.697�y4 22.13307 O. O0043t343V,f�l" +0 132856.7 20.00659 0659 19.51187 01 0030343003E+00 132865.7 ,/p 26.64} j8�15 24.420$8. . 17.40450 1.580.0767 1.981.7 ..Vy�0 1.5.53736 16 99831 2.327.247 21210.68 1.5.31322 17.99820 893.3062 1.8535.26 17.25404 6503.0000 0 ice"' ti✓ 0[Y'+j� 00/'000+ V o 1027.465 27.66664 31.85031.9 1.1.28375 1092.385 32.72011 331359.9 11.29393 1099.1.1.9 20.1.6217 301,331.4 11.. 35426 999.111.1. 32.9196+6 312947.2 11.24'9035 2213.737 27.82690 315496.2 1.1.11335 1469.7701 25.3�6�y960 325566.9 103.94924 1004.700 35.65964 316862.4 11.15860 3270.000 43.003000430E+00 17.99820 1378.837 8070.422 1.29490.9 21035.692 21.29631 0,3968226 200'47856 20361..20 317251,9 285..7590 19.95992. ? 5.55884 10.96294 32203.0003 8523.297 0.5238445 261.6550 Q.4143Ott OOOE+00 135702.7 19.69409 1„9.1.5573 +1.7.998201 2354.446 21.410.21 15.55291 3170,000 O.00o00003E+003 11.998203 80325.883 1.32342.5 1982.053 0.1249668 21.13106 20850.17 278.9470 20.91629 15.44608 1497-822 29.52704 3341.26."9 1.1.032187 1372.786 25.4019,53 317789.4 10.77169 1 0..0O00U003E+1343 43 . C3Q4)4)4300E+0)0 0.443430000E+013 -1..000000 24695.51 2017.063 8611000 2.0330323 25082.18 2016-282 103.6850 2.447'984 25698.8+1+ 21316..625 63.74199 2.0446039 24146.47 2016.793 105.4180 2.015868 26853.89 2018.468 98.49699 1..914577 28727.70 2016.322 83.07602 1.913920 24551.91 2016.8622 99.00700 1.971170 275*1�.3..00 201! .839 59.65800 1..972136 28618.28 2018.1316 80.42041 1..959248 28743.81. 2017.992 76o68500 1.943585 3120.000 0.0000000R+,00 17 * 99820 1337.378 27428.66 7604.531 13+ 401.7 1806.773 33.22345 2019.002 0.277393 22.1.5293 20199.93 317029.9 78.77604 265.5271. 20.55809 15.51.637 14.98536 1..92+9554 070,030 3070,000 0.0000000E+00 O . tO7tOOE+00 650.0000 50.t000 QOOOOOOE+00 4 . O.OOOOOO/E+00 O.OOVOOOOE+00, OsOOOOOOOE+00 O.00OOOOVE+00 /.OVOOOOOE+00 0a000//000E+oo 0.000110/G+oo O.OOOOOOE+00. O.ylOOOOOE+00 O.OOOOOLlr+00 oi,0009000E+00 4.4404000E+44 -5.000000 5.000000 -1.000000 TOTAL D,A,TA, RECORDS 102 STARTING TAPE DEPTH 3674..00 ENDING TAPE DEPTH 3062.44 **** PILE TRAILER **** FILE .# 5 **** PILE HEADER *** REPEAT. 445 1024 * FORMAT'RECORD (TYPE# 64) ONE DEPTH PER. FRAME TACE - bEPTH UNIT F 1:5 CUR17ES NAME CODE SAMPLE# UNIT BYTES 1 . C -CL 68 1 VOLT 4. SPD 68 1 FT 4 .. LS 68 1 OTS � 4 . S .68' 1 CTS 4 5 G1 68' .1. CTS 4 6 GEIS 68 1 CTS 4 028 1 CTS,__ . 4 .7 8 GR 68 API 4 9 MCN 68. - - 1 CTS 4 1.6 MSD 68:. 1 CTS 4° 11 - SGMA 68 1. DIM 4 1.2 CSS 68 1 CTS 4 13 ISS 68 1 CTS 4 14 RRL 68 1 CTS 4 16 R� 68 CTS 4 16 � RATO 68 1 IT DIM- 17 R1CS 17 . 68 1 DIM 4 18 R1N 68 1 DIM 4 19 R.HOR. 68 1 DIM 4 * DATA RECORD (TYPE# 4) 966 BYTE$ D19PTH CCL SPD LS SS TOTAL DATA RECORDS 41 STARTING TAPE DEPTH -^ 1.0809.00 LANDING TAPE DEPTH 10569.00 * PILE TRAILER * * * * **** TAPE TRAILER **** LIS 89/09/22 3979 01 :&ATO Rica AIN RHQR 10809.000 300.0000 0.0000000E+00 0.0000000E+oo 0.0000000E+Oo 0.0000000E+012 0.0000000E+00 0.00000008+00 0.0000000E+00 0.0000000E+00 O.00OOOOOE+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 O.00OOOOOE+00 0.0000000E+00 0.0000000E+00 5.000000 -1..000000 1.075+34,000 0.0000000E+00 1990.847 37137.77 1.4303.83 121325.9 4634.687 54.40454 2009.822 0.2235109 - 1.6.99324 2521.3.82 316048.4 128.2920 31.3.121. 18.62245 1.2.72969 11.74381 1.790152 10700.000'' '' , 2:3.80000 -.15.99840 1.992.762 36621.09 13725.51"- 119328.1 4567.195 59.03178 2009.457 0.3246821'' 16.79285 .24733.67 31.5075.6 93.65700 299.0659 16.38174 38174 12.80754 12.15002 1.710668 1.0659.000. 0 OOOOOOOE+00"11 1.6.76250 1296.248 3021.8.94 7798.098- 126751..1 1644, 637 64.79094 2007.91.1 0.4871.94.:. 21,.67653 20740.89 311430.7 159.5440 352.2861 23.28114 15.08012 12.98088 1.826368 10609x000' 0.0000000E+00 15.99840 2499.593 381.28.87 15529.1.0 . 1.29'205.9 5694.246 38.00592 2006..744 0.1.85861.6+ 15.16158 267` 1.43 325214.5 80.23001. 279.3779 1.5 s 21.162 1.2.10928 11.88686 1.760546 TOTAL DATA RECORDS 41 STARTING TAPE DEPTH -^ 1.0809.00 LANDING TAPE DEPTH 10569.00 * PILE TRAILER * * * * **** TAPE TRAILER **** LIS 89/09/22 3979 01 End of execution: Mon 25 SEP 89 lO t 26a Elapped execution time 1 minute , 12.7 seconds, SYSTEM RETURN CODE = 4
