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Home My WebLink About172-007 • STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM.SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 .• Suspended❑ 1b. Well Class: 20WAC 25.105 20AAC 25.110 Development 0 ' Exploratory ❑ Go WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Hilcorp Alaska, LLC Aband.: 10/11/12 ' 172 -007 / 312 -353 3. Address: 3900 Centerpoint Drive, Suite 100 6. Date Spudded: 13. API Number: Anchorage, Alaska 99503 09/25/72 50- 133 - 20237 -00 • 4a. Location of WeN (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 932' S & 2089' E of NW Comer, Sec. 4, 17N, R9W, SM' 11/30/72 Swanson River Unit (SRU) 24-33 • Top of Productive Horizon: 8. KB (ft above MSL): 183.3. 15. Field/Pool(s): 127' N & 2342' E of SW Corner, Sec. 33, T8N, R9W, SM GL (ft above MSL): 164.6 Total Depth: 9. Plug Back Depth(MD +TVD): Swanson River Field / Hemlock Oil • 271' N & 2399' E of SW Corner, Sec. 33, T8N, R9W, SM 10,821' MD 10,605' TVD 4b. Location of WeN (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 344467 • y- 2460328 ' Zone- 4 . 11,088' MD 10,84T TVD ' FEI3,A028399 , TPI: x- 344722 y- 2481333 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 344787 y- 2461527 Zone- 4 N/A N/A 18. Directional Survey: Yes Ohio 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD+TVD: (Submit electronic and printed information 20 AAC 25.050) WA (ft MSL) N/A ( Pn per ) 21. Logs Obtained (List all logs here and submit electronic and printed 'information per 20AAC25.071): 22.Re- dril/L Top Window MD/TVD: N/A N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING PULLED 20" 94 H-40 Surface 266' Surface 266' 10 - 3/4" 40.5 K -55 Surface 3,408' Surface 3,408' 7 -5/8" 26.4 N-80 Surface 10,635 Surface 10,435 5 -1/2" 23 N-80 10,434' 11,085' 10,252' 10,845 24. Open to production or injection? Yes ❑ No 0 25. TUBING RECORD If Yes, list each interval open (MD+TVD of Top and Bottom; Perforation Size SIZE DEPTH SET (MD) PACKER SET (MD/TVD) and Number): N/A RECEIVED ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 0 FEB 1 203 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 90 . G. P - kr.k.�f / , AO + C ` TOC 10,066' 9 bbls of cement plug 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A N/A Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: N/A Test Period Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate pi. +'` 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. SCANNED MAR 13 2013 RBDMS FEB 12 2O tr Form 10 -407 Revised 10/2012 CONTINUED ON REVERSE Z 'u - 1 ? Submit original only '� ( /3% 'z 11' ' • • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base N/A Formation at total depth: 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Chad Helgeson Email: chelgeson(ilhilcoro.com Printed Name: Chad Helgeson Title: Operations Manager Signature: �1 Phone: 907 - 777 -8405 Date: 2 /11/1 3 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. 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. Item 1b: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level 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 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well 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. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. 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. Form 10 -407 Revised 10/2012 • • Donna Ambruz From: Chad Helgeson Sent: Friday, December 21, 2012 11:33 AM To: Donna Ambruz Subject: FW: SRU 24 -33 ( PTD 172 -007) FYI, we will have to get our 10 -407's modified as per Guy's emails. I think these can wait till after the 1 of the year. Chad From: Schwartz, Guy L (DOA) [ mailto :guy.schwartzOalaska.gov] Sent: Friday, December 21, 2012 11:26 AM To: Chad Helgeson Subject: SRU 24 -33 ( PTD 172 -007) Chad , Same thing on this well. Include the Sidetrack rig operations as far as milling window. In this case I don't see where you pressure tested casing or set a CIBP as the approved sundry outlined. Please explain. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) - 3 �3 add 5tA- /a - �d 3 /6/0 . . Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 24 -33 50- 133 - 20237 -00 172 -007 9/18/12 10/11/12 Daily Operations: 09/18/12 - Wednesday MIRU Williams WOR. Cir well volume from well through rig pits, monitored & weighed fluid to ensure 9.6 brine in hole. ND wellhead. MU 1 jt of 3 -1/2" IBT tbg into hanger. Backed out all lock pins & pulled hanger. Set slips on tbg. NU BOP. Tested pipe rams & annulars on BOP's. SWFN. SD. 09/19/12 - Thursday Started TOOH laying down 342 jts of 3 -1/2" IBT TBG and 7 gas lift mandrels. MIRU SL. RIH w/6.600" GR & Junk Basket to 10,066'. POOH heavy thru 9,800'- 6,700'. RDMO SL. 09/20/12 - Friday MDMO Williams WOR and cleaned location. �-- 10/03/2012 - Wednesday rtik Rack topdrive in cradle, lower bottom torque tube, move frac tanks and pump. RD plumbing between modules. Peak crane and two trucks on location at noon, held PJSM with entire rig team, remove topdrive from rig floor, ship out topdrive gen set, lower centrifuge house and ship out, set down mud lab and ship out, lower roof caps over drawwork ship out cuttings box, remove augers, ship rock washer, lay down degasser swivel standpipe gooseneck, scope down derrick and lower mast. 10/04/2012 - Thursday Secure derrick climber counter weight, secure kelly and cement hoses, chain c- section, disconnect electric lines, secure tong hanging lines, LD tongs, torque tube, trash cans, bails, stairs, install I- beams, LD derrick, unbolt driveline, secure doghouse. ove modules to stage area, move mats to 44 -33. Retract doghouse, lower doghouse, remove handrails, remove mudline, remove beaverslide, remove standpipe manifold, stage degasser, augers, boiler house, fuel tank, boiler house, gen sets 1 & 2, pump houses 1 & 2, stage pipeshed, stage pit modules, 2nd crane on location at 20:00 hrs, prep cellar on 44 -33. Set up light plants on 44 -33, prep to lay liner and felt. 10/05/12 - Friday Lay felt and liner on 44 -33 pad, lay matting, locate crew at 23B -22 to RU and remove derrick, PJSM with Peak operators, set derrick on truck and road to 44 -33. Move pipeshed to 44 -33, move sub base to 44 -33, move remaining mats to 44 -33. Assemble sub base over well, spot pit modules, spot derrick, spot doghouse and water tank, spot pump modules, gen sets, boiler house and fuel tank. Hook up fuel and electric lines. tart gen set, cont RU, prep to raise mast, tie in equalizer lines, suction and discharge lines in pump modules. 10/06/2012 - Saturday Raise mast, string blocks, scope up derrick, spot 4 pipeshed modules, spot degasser, spot rock washer, install augers, spot centrifuge, install lower torque tube, stage topdrive cradle on rig floor, RU topdrive, spot genshack for topdrive, install roof caps over draw - works, spot mud lab, Toad water tank, stage windwall section on pad, spot foreman shacks on pad, install HandyBerm. Clean and organize doghouse, change oil in topdrive, RU lower derrick ladder. Prep pits to take on mud from tank farm, install chains /binders on water tank, unload pipeshed, install choke line from choke house, clean pump rooms. 10/07/2012 - Sunday Spot and level Foreman shacks, spot sewer and water tanks, RU new koomey unit, koomey unit, set windwalls with crane, set cattle chute over beaver slide, hang service loop, load 600 bbls 10.9ppg mud in pits, function check surface lines, RU top drive • gen set, function check topdrive. ND cap on well, NU 11" BOP stack, install steps and landings around rig, spot cuttings box, install koomey lines, bolt up choke and kill lines, install flow nipple, install flow paddle, install saver sub, MU kelly hose, cetrifuge mud from 10.9 to 9.3ppg, cont working on new koomey unit (control box issues). 10/08/12 - Monday Finish up NU BOP, install KatchKan on stack, rebuild 4" standpipe valve, offload mud products, RU test pump and manifold, install test plug, fill stack and choke manifold, MU TIW and dart on test jnt, MU test tool on top drive. Shell test at 250/5000 psi for 10/10 min. Test annular at 250/2500 psi, all other BOPE at 250/5000 psi for 10/10 min, replaced lower IBOP on topdrive, AOGCC Rep Jim Regg waived witness at 9:47 on 10/8/12, BLM Rep Justin Miller waived witness at 11:24 on 10/8/12. Racked and tallied 330 jnts 4" DP. RD test equipment, LD test jnt, pull test plug, stage baker tools on rig floor, MU BHA #1, 6" roller cone bit, bit sub, 6 5/8" string mill, 3 1/2" HWDP flex jnt 6 5/8" upper string mill, XO sub, 18 jnts 4" HWDP. PU 4" DP from pipeshed and single in hole from 567' to 629', wear bushing ID is 6 5/16 ", mills are 6 5/8" so did not set wear bushing in well head. 10/09/2012 - Tuesday Fill hole with 20 bbls w/ produce water. Pick up singles & RIH t/ 700', work mill through spot @ 700' no drag, continue picking up pipe to 9123' circulate bottoms up, pump sweep, circulate sweep out @ 400 GPM, 2270 psi rotate and work pipe while circulating. Monitor well. Circulate and blance out fluid. Trip out of hole standing back. Service rig and topdrive. Trip out of hole @ 1750'. 10/10/2012 - Wednesday Trip out of hole. Wait on Pollard w /line. Rig and run collar Iocatorm gamma and CIBP tools, set CIBP @ 9038', bolt strippe out of lower plate on CIBP instead of shearing test casing @ 2100 pg, test good, Wait on CIBP and E - Line unit, make up upper & lower string mills & mwd. PJSM w/ E - line crew and rig up e- line. RIH with CIBP and set bridge plug @ 9034' wlm, pooh and rig down wire line. P/U MWD, UBHO, xo and shallow test mwd @ 410 gpm. Pick up upper and lower string mill, and whip stock. RIH w/ whip stock assembly, & mills, mwd tools and orient tools to whip stock. Trip in hole w/ whip stock on drill pipe from derrick @ 2 min per stand. 10/11/2012 - Thursday Trip in hole with whip stock to stand 134. M/U top drive on std 134, break circ. orient whip stock @ 80 deg, tag CIBP @ 9019', slack off 20K engauge anchor, P/U 6K to confirm set, slack 40K and shear bolt, whipstock set @ 9001.15. Displace well W/ 352 bbls 9.5 EZ -mud, get drilling perimiters, p/u 150, s/o148. Mill window f/9001 T/ 9015. Monitor well , well flowing, @ 8/9 bbl /hr, shut well in. Shut in psi 1270 on csg 1220 on drill pipe, weight mud system up to 10.2, intial gain = 10 bbls. Pump 10.2 kill weight mud @ 3 bbl /min, ICP 1000 psi, continue pumping kill rate F/ 7800 stks, 30bbI gain while pumping kill wt fluid, continue pump until 10.2 ppg @ surface, monitor well through gas buster slight flow, open well and monitor well, well flowing, shut well in and record pressure, 890 psi on drill pipe, 840 on csg, decission made to increase mud wt to 10.7 build weight in mud pits to 10.7. Pump 10.7 kill weight mud through choke, following pump schedual @ 3 bbl min. Swanson River Unit n • SCHEMATIC Well: SRU 24 -33 Completion Date: 12/23/1972 ua.," p 11.■,1.1. I 11 PTD: 172 -007 API: 50- 133 - 20237 -00 RKB:178'/ GL: 165' AMSL [ I 20° CASING DETAIL Size Type Wt Grade ID Top (MD) Btm (MD) 20" Conductor 94 H -40 19.124" Surface 266' 10 -3/4" Surface 40.5 K -55 10.050" Surface 3,408' 33.7 N -80 6.765" Surface 80' 26.4 N -80 6.969" 80' 3,400' 7 -5/8" Intermediate 29.7 N -80 6.875" 3,400' 5,400' 10-3/4'i , 33.7 N -80 6.765" 5,400' 7,300' 33.7 P -110 6.765" 7,300' 10,635' 5 -1/2" Production 23 N -80 4.670" 10,434' 11,085' JEWELRY DETAIL No. Depth Item 1 10,765' Packer PERFORATION DETAIL Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments 10,644' 10,660' 10,444' 10,458' 14' 6 Cemented 10,676' 10,696' 10,473' 10,491' 18' 6 Cemented 10,704' 10,711' 10,498' 10,505' 7' 4 Cemented 10,721' 10,735' 10,514' 10,527' 13' 6 Cemented 10,740' 10,762' 10,531' 10,551' 20' 4 Open TOC 10,066' , # .4 +y ; :, . - `, 10,770' 10,794' 10,559' 10,581' 22' 4 Open A � �t a.�i 4 j -, . ,,,•+ » p 7-5/82, 4 ii r_gT 1 ` 1 k 5-1/2" , TD: 11,085'/ PBTD: 10,821' Updated by DMA 12/19/12 STATE OF ALASKA ALAtA OIL AND GAS CONSERVATION COMPSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: 011 ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 • Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Ei • Exploratory ❑ GI❑ 1MNJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: HilcorpAlaska, LLC Aband.: 10/11/12 • 172 -007 /•/Z 3 53 3. Address: 3900 Centerpoint Drive, Suite 100 6. Date Spudded: 13. API Number: Anchorage, Alaska 99503 09/25/72 50 -133- 20237 -00 ' 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 932' S & 2089' E of NW Comer, Sec. 4, T7N, R9W, SM • 11/30/72 Swanson River Unit (SRU) 24-33 . Top of Productive Horizon: 8. KB (ft above MSL): 183.3 15. Field/Pool(s): 127' N & 2342' E of SW Comer, Sec. 33, T8N, R9W, SM GL (ft above MSL): 164.6 Total Depth: 9. Plug Back Depth(MD +TVD): Swanson River Field / Hemlock Oil, 271' N & 2399' E of SW Comer, Sec. 33, T8N, R9W, SM 10,821' MD 10,605' TVD 4b. Location n of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD TVD): 16. Property Designation: Surface: x- 344467 _4/0/5/ /5/ � y- 2460328 2 L/6 L7l Zone- 4 - 11,088' MD 10,847' TVD ' FEDA028399 • TPI: x- 344722 y- 2461333 ,/ Z - / 5 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 344787 y- 2461527 2 Zone- 4 N/A N/A 18. Directional Survey: Yes [to 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained (List all Togs here and submit electronic and printed information per 20AAC25.071): 22.Re- drilVLateral Top Window MD/TVD: . N/A N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM PULLED SIZE CEMENTING RECORD PULLED 20" 94 H-40 Surface 266' Surface 266' 10 -3/4" 40.5 K -55 Surface 3,408' Surface 3,408' 7 -5/8" 26.4 N -80 Surface 10,635 Surface 10,435' 5 -1/2" 23 N-80 10,434' 11,085' 10,252' 10,845 24. Open to production or injection? Yes ❑ No El 25. TUBING RECORD If Yes, list each interval open (MD+TVD of Top andliteion Size SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) and Number): N/A ®EC 2 2012 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was 0C 0 hydraulic fracturing (MD) AMOUNT MOUNT completion? D KIND OF MATERIAL USE TOC 10,066' 9 bbls of cement plug 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: N/A Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate — 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No El Sidewall Cores Acquired? Yes ❑ No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. r r" ;`' °LC H j 21 . .. SCANNED FEB 2 8 2093 Form 10 -407 Revised 10/2012 CONTINUED ON REVERSE lZ • z.4 / SU it original only G • • 29. GEOI MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes El No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base N/A Formation at total depth: 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Chad Helgeson Email: chelgeson @hilcoro.com Printed Name: Chad Helgeson Title: Operations Engineer Signature: �" d/ �' " Phone: 907-777 -8405 Date: Zci 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. 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. Item 1b: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level 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 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well 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. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. 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. Form 10-407 Revised 10/2012 • � Swanson River Unit Well: SRU 24 -33 SCHEMATIC Completion Date: 12/23/1972 Hilrnrp Alaska, LLC PTD: 172 -007 API: 50- 133 - 20237 -00 RKB:178'/ GL: 165' AMSL 20' CASING DETAIL Size Type Wt Grade ID Top (MD) Btm (MD) 20" Conductor 94 H -40 19.124" Surface 266' 10 -3/4" Surface 40.5 K -55 10.050" Surface 3,408' 33.7 N -80 6.765" Surface 80' 26.4 N -80 6.969" 80' 3,400' 7 -5/8" Intermediate 29.7 N -80 6.875" 3,400' 5,400' 10 -3/42 , 33.7 N -80 6.765" 5,400' 7,300' 33.7 P -110 6.765" 7,300' 10,635' 5 -1/2" Production 23 N -80 4.670" 10,434' 11,085' JEWELRY DETAIL No. Depth Item 1 10,765' Packer PERFORATION DETAIL Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments 10,644' 10,660' 10,444' 10,458' 14' 6 Cemented 10,676' 10,696' 10,473' 10,491' 18' 6 Cemented 10,704' 10,711' 10,498' 10,505' 7' 4 Cemented 10,721' 10,735' 10,514' 10,527' 13' 6 Cemented 10,740' 10,762' 10,531' 10,551' 20' 4 Open TOC 10,066' 10,770' 10,794' 10,559' 10,581' 22' 4 Open 7 -5/8'L 5 -1/2 TD: 11,085'/ PBTD: 10,821' Updated by DMA 12/19/12 • �� Hilcorp ��U��«�U°�� LLC �~ . ...~~~~" �� Alaska, ~~~~~ ��UU Operations Summary ��.~nn �� ~�.........~. x Well Name API Numbe Well Permit Numbe Start Date End Date SRU 24-33 50-133'30237'00 172'007 9/18/12 9/20/12 � ~ ailY 0 ° 09/18/12 - Wed MIRU Williams WOR. Cir well volume from well through rig pits, monitored & weighed fluid to ensure 9.6 brine in hole. ND wellhead. K8U1jtof3'1/2"|BTtbg into hanger. Backed out all lock pins & pulled hanger. Set slips on tbg. NU BOP. Tested pipe rams & annulars on BOP's. SWFN. SD. 09/19/12 - Thursday Started TOOH laying down 342jtsof3'1/3"|8TT8G and 7 gas lift mandrels. MIRU SL. R|Hw/6.6OO"GR& Junk Basket tm 10,066'. POOH heavy thru 9,800'-6,700'. RDMO SL. 09/20/12 - Friday MDMO Williams WOR and cleaned location. ! • • 0, r,t , THE STATE Alaska Oil and Gas 1 °fAL ASKA __ 4;,; Conservation Commission Witt � *h GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1 433 Fax: 907.276.7542 7: K ; Chad Helgeson -- Operations Engineer Oa? Hilcorp Alaska, Inc. 1 7?" " 3800 Centerpoint Drive Anchorage, AK 99524 Re: Swanson River Field, Hemlock Oil Pool, Swanson River Unit 24 -33 Sundry Number: 312 -353 Dear Mr. Helgeson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission 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, Cathy VFoerster Chair DATED this / % day of September, 2012. Encl. RECEIVED STATE OF ALASKA S EP 1 3 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A�aska Oil & Gas Cons. Commission 20 ARC 25.280 Anchorage 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations Ei Perforate ❑ Pull Tubing 0 - Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well : Stimulate ❑ Alter Casing ❑ Other. ❑ 2. Operator Name: 4. Current Well Gass: 5. Permit to Drill Number. Hilcorp Alaska, LLC Development El Exploratory ❑ 172 -007 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: 3800 Centerpoint Drive, Anchorage AK, 99524 50- 133 - 20237 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number. property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El Swanson River Unit 2433. 9. Property Designation (Lease Number): 10. Field / Pool(s): FEDA028399 (Swanson River Unit) Swanson River Field / Hemlock Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,088 10,845 ' 10,124 9,972 10,120' (Cement) N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 266' 20" 266' 266' Surface 3,408' 10 -3/4" 3,408' 3,408' 3,130 psi 1,580 psi Intermediate Production 10,635' 7 -5/8" 10,635' 10,435' 6,020 psi 3,400 psi Liner 651' 5 -1/2" 11,085' 10,845' 10,560 psi 11,160 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 3 -1/2" 9.3#/N -80 10,120 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A N/A N/A 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch (l Exploratory ❑ Development Q Service ❑ I 14. Estimated Date for 15. Well Status after proposed work: 9/17/2012 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended Q 16. Verbal Approval: Date: / -( CI- WINJ ❑ GINJ ❑ WAG 0 Abandoned ❑ Commission Representative: 44.. Yaw « f GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing 1 i true and correct to the best of my knowledge. Contact Chad Helgeson 907 - 777 -8405 Printed Name /�C�haddHHelgeson 777 -8405 - TTitle > Operations Engineer Signature (i2%"( L� �/ Phone 777 7 -O ® `7d Date 9/13/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 2- 353 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: _ 2 Ooo pS Z. Bo( n (� A /4„, 4 4 4 , /3oP I;: .�c 4roc.J . .p ,0roo J ,cu-1_ Zomc ZS= its( Subsequent Form Required: /0 .. y 0 7 4,,, //,, APPROVED BY Approved by: L f J � (/,-- COMMISSIONER THE COMMISSION Date: i - 7 — / Z_. DMS SE 2 0 ` QRIG1N ' Form 10-403 R vised 1/2 r •r /lc./ / 0 Su in Duplicate `, • Well Prognosis Well: SRU 24 -33 Hilcorp Alaska, LLC Date: 9/13/2012 Well Name: SRU 24 -33 API Number: 50- 133 - 20237 -00 Current Status: Abandoned Oil Producer Leg: N/A Estimated Start Date: Sept. 17, 2012 Rig: Williams 405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: 172 -007 First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second CaII Engineer: Luke Saugier (907) 777 -8395 (0) AFE Number: Current Bottom Hole Pressure: 0 psi Not open to formation Maximum Expected BHP: 0 psi @ 10,400' TVD Cement squeezed Max. Allowable Surface Pressure: 0 psi Brief Well Summary This well was completed in 1972 as an oil well. It was perforated initially in the Hemlock H -1, 2, 3, 4, 5 &8 zone. The H8 was determined wet. Lots of sand production in 1975 and a workover performed and replaced tubing. In 1982 the well was cleaned out with coiled tubing and multiple problems with sand production. In 1993 the Hemlock formation was abandoned for a future sidetrack and left with a 9.7 ppg brine left in the hole. Regarding Wellbore Condition • Well current well status is abandoned oil well, with cut off tubing at 10,120ft. Brief Procedure: • ( 3° " 4 " -•- 1. RU pump unit and pressure test the well tubing /casing to 2000 psi. 2. MIRU Williams Rig 405. Circulate 400 bbls of 9.7 ppg brine through well. 3. Remove tree without BPV in tubing hanger. 4. Pull tubing up and set slips below the tubing hanger. Remove the 9 -5/8" tubing hanger 5. Set BOP stack over the tubing stub, hold the tubing with the blocks from the rig. 6. Notify AOGCC 24hr in advance of BOP testing 7. Remove slips and set 7" BOP stack on the well. 8. Test the BOP stack (Except blind rams) and choke equipment with the tubing in the stack to 2000 psi, against the casing and tubing. 9. Pull tubing out of the well, LD 3 -1/2" tubing and check for NORM. 10. Test BOP Blind Rams, record and chart. 11. R/U slickline. Drift 7 -5/8" casing with 6 -5/8" OD gauge cutter. a. If unable to drift casing: i. M/U 6" taper mill & 6 -5/8" string mill. TIH to top of 3 -1/2" tubing stub @ 10,120'. ii. Wash and ream past obstructions. iii. Circulate hi -vis sweep on bottom. iv. TOH. 12. Test casing to 2100 psi / 30 min. 13. N/D BOP. N/U abandonment cap. • • Well Prognosis Well: SRU 24 -33 Hilcorp Alaska, LLC Date: 9/13/2012 14. RDMO Williams Rig. 15. R/U E -line. Make GR /CBL /CCL logging pass from 10,120' to 8,000'. a. Locate couplings and sand /shale intervals. Determine appropriate setting depth for CIBP. 16. M/U CIBP and set in best shale section from 10,120' to 8,000'. 17. Prepare location /cellar for Doyon Arctic Fox to side track well. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematics , • • Swanson River Unit PROPOSED Well: SRU 24 -33 Hilroro Alaska. LLC Completed: 2/17/1972 RKB:178'/ GL: 165' AMSL Casing Detail i 1 Size Type Wt Grade ID Top (MD) Btm (MD) 20" Conductor H -40 19.124" Surface 266' 10 -3/4" Surface 40.5 K -55 10.050" Surface 3,408' 20" 33.7 94 N -80 6.765" Surface 80' 26.4 N -80 6.969" 80' 3,400' 7 -5/8" Intermediate 29.7 N -80 6.875" 3,400' 5,400' 33.7 N -80 6.765" 5,400' 7,300' 33.7 P -110 6.765" 7,300' 10,635' 5 -1/2" Production 23 N -80 4.670" 10,434' 11,085' 10 -3/4L i JEWELRY DETAIL No. Depth Item 1 10,765' Packer Perforation Detail Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments 10,644' 10,660' 10,444' 10,458' 14' 6 Cemented 10,676' 10,696' 10,473' 10,491' 18' 6 Cemented 10,704' 10,711' 10,498' 10,505' 7' 4 Cemented 10,721' 10,735' 10,514' 10,527' 13' 6 Cemented 10,740' 10,762' 10,531' 10,551' 20' 4 Open C (p„, 10,770' 10,794' 10,559' 10,581' 22' 4 Open 61 E (1 -s4.�� 2 °t S2 ' N.1.„ C 8L EST.TOC 10,124' I 7-5/8"L 5 - 1/2" _ , TD: 11,085'/ PBTD: 10,821' Revised: 9/9/2012 by TDF • • SRU 24 -33 20" @ a66 J NOTE: All depths are KB reference. 9 .7 PPG Original GL -KB is 20 ft. BRINE P &A CEMENT ® FIJI. 1983' CAMCO MM MANDREL 10 -3/4' @ 3408' 3612' CAMCO MM MANDREL 4961' CAMCO MM MANDREL 5028' CAMCO MM MANDREL 6728' CAMCO MM MANDREL 7234' CAMCO MM MANDREL TUBING CUT /0/204 7557' CAMCO MM MANDREL EST TOC /o /.W 10276' 3 -1/2" x 2 -3/8" CROSSOVER J•.. 5 -112" LINER @ 10434' • p CEMENT RETAINER 010580 , ,� •s:.J• � i . ' c= ': ,{ 10590' XA SLEEVE ••: "- " ' • ••{ TUBING PERFORATIONS 10610%10615' CEMENT RETAINER 010620' k " I►� 10624' PACKER 'J '10630 S NIPPLE 7 -5/8" @ 10635 � •w t ' •t t ''• i{•% UNER PERFORATIONS ItJ ;:" :.' ' TUBING PERFORATIONS 10635' - 10640' 10644'- 10660' k, "4. 10676'- 10696' r v�tt v 10704'- 10711' . "{`�•{ t. 10721'- 10735' 1� DECEIVED i t 10733' D NIPPLE MAY - 3 1993 . h t ▪ •• • LJZt. '.s• { j ▪ :� ▪ •• t { ' �" • Alaska Oil &Gas Cons. Commission 2 -3/8" 4.6# @ 10754' "{ 10738' FILL Mchorage . %t:'t: of t::t: J.:t. ti 11 10763' TOP OF FISH • v -0 � 4 10765' PACKER UNER PERFORATIONS 10740' - 10762' 10770'- 10794' • 10821' PBTD 5 -1/2" 23# @ 11085' .. • • Swanson River 2012 Williams Rig BOP tlavorp U.,.k.,. 1.1.1. 07/31/2012 3.07' Hydril ° GK 7 1/16 -5000 l li 1 111111 1 I I 1111l1[ J' d I 7 1 S � clw -u ®0�_ 3.68' • It: 7r H 71/16 -5000 Ill Ill lillii I'i' Choke and Kill Valves 2 1/16 10M s . III III. 1 11 III I Irk, 1/16 i jN� t I 2.00 : 1 � l 1 1 e:: 111 ( i IEI 111 • Page 1 of 2 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, September 17, 2012 11:22 AM To: 'Chad Helgeson' Subject: RE: Swanson River 24 -33, PTD 172 -007 Chad, You have verbal approval to proceed as submitted in your sundry. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Chad Helgeson [mailto:chelgeson @ hilcorp.com] Sent: Monday, September 17, 2012 9:50 AM To: Schwartz, Guy L (DOA) Subject: RE: Swanson River 24 -33, PTD 172 -007 Guy, We submitted the Sundry for the well we discussed below, late last week. We are hoping to move the rig to this location today and start working on the well, testing BOP's tomorrow. Can we get a verbal approval for the work that was proposed, if the Sundry hasn't been approved already? Thanks Chad Helgeson From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, September 12, 2012 4:02 PM To: Chad Helgeson Cc: Clint Chanley Subject: RE: Swanson River 24 -33 Chad, I reviewed your proposal... If you can prove hydraulic isolation to the formation the AOGCC ( see 20 AAC 25.035 (e) ) would approve your approach as outlined below. One change however would be to circulate the well around to a known brine density before pulling the hanger. After 20 yrs it is better to start with a known KWF in the wellbore. (I am assuming 9.7 is KWF density). Can you elaborate on the BOP testing you propose in step 7..... you will not be able to set a test plug or TWC in the wellhead. Testing against cement plug in casing? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Chad Helgeson [mailto:chelgeson @hilcorp.com] Sent: Tuesday, September 11, 2012 10:24 AM To: Schwartz, Guy L (DOA) 9/17/2012 Page 2 of 2 Cc: Clint Chanley Subject: Swanson River 24 -33 Guy, Attached is the current schematic for SRU 24 -33 (PTD- 24 -33). This is a well that we plan to sidetrack with the Doyon Rig. Before we put the Doyon Arctic Fox Rig on the well, we would like to pull tubing and set bridge plugs with the Williams Rig 405 (much cheaper day rate, if there are any problems pulling tubing or running casing scrapers, etc) The problem as I mentioned on the phone is that the current tubing hanger will not fit through BOP stack we have available in Kenai. We can get a 13 -5/8" stack from Prudhoe Bay for this job, but seems like a lot of over kill to pull the hanger from the well. What I would like to propose in my 10 -403 Sundry is to: 1. Rig up on the well with the Williams 405 rig 2. Test casing /tubing to 2000 psi (well already has 9.7 ppg brine in the well) 3. Remove tree without BPV in tubing hanger 4. Pull tubing up and set slips below the tubing hanger. We would remove the 9 -5/8" tubing hanger 5. Set BOP stack over the tubing stub, hold the tubing with the blocks from the rig. 6. Remove slips and set 7" BOP stack on the well. 7. Test the BOP stack (Except blind rams) and choke equipment with the tubing in the stack to 2000 psi. 8. Proceed with the well work, which is to pull the tubing and set bridge plug. Let me know if this would be worth submitting formalin my sundry. Chad Helgeson Operations Engineer Hilcorp Alaska, LLC Office: 907 - 777 -8405 Mobile: 907 - 229 -4824 r _ . X2012 Page 1 of 1 Schwartz, Guy L (DOA) From: Chad Helgeson [chelgeson @hilcorp.com] Sent: Tuesday, September 18, 2012 5:53 PM To: donnierhuffman @yahoo.com; Awhudgens75 @yahoo.in Cc: Schwartz, Guy L (DOA) Subject: 24 -33 tubing Hanger removal ?rip f i " ^ 00 � Donnie, As we discussed on the phone tonight, the AOGCC has some concerns with pulling the cut tubing without a BOP if there is not a clean cut at the bottom and we possibly pull /move the "cement retainer" thus removing one of our 2 safety barriers. They will approve pulling up to 10K over string weight (95,000 #) on the tubing, but no more than that to get the tubing hanger high enough to remove. If the tubing hanger does not release our options will be to make another cut and see if we can get it to release or Rig down and wait for the drilling rig with the bigger BOP's to pull the hanger and tubing. Call me with any questions or if you have any problems with this. Chad Helgeson Operations Engineer Hilcorp Alaska, LLC Office: 907 - 777 -8405 Mobile: 907 - 229 -4824 SCANNED link 0 2 2O13 9/19/2012 L1 � SEAN PARNELL, GOVERNOR M . ALASKA OIL A" GAS 333W. 7th AVENUE, SUITE 100 CONSE RVATION COMMIS ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg Drilling Manager Union Oil Company of California PO Box 196247 e Anchorage, AK 99519 Re: Swanson River Field, Hemlock Oil Pool, SRU 24 -33 Sundry Number: 310 -355 Dear Mr. Brandenburg: SAN NO �t 1 91 � Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission 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. , Ln4cere n Tone DATED this /? day of November, 2010. Encl. • (Ark STATE OF ALASKA OCT 2 S 201 <<t tS� ALASKA OIL AND GAS CONSERVATION COMMISSION astCCRsG�u APPLICATION FOR SUNDRY APPROVAL Anehomp 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Request for Suspended Well Renewal 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development El - Exploratory ❑ 172 -007 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 133 - 20237 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑� Swanson Riv Unit 24 -33 - 9. Property Designation (Lease Number): 10. Field / Pool(s): FEDA028399 [Swanson River Unit] I Swanson River Field / Hemlock Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,088 10,845 10,124 9,972 10,120' (cement) N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 337' 20" 337' 336' Surface 3,408' 10 -3/4" 3,407' 3,407' 3,130 psi 1,580 psi Intermediate Production 10,635' 7 -5/8" 10,635' 1 10,435' 6,020 psi 3,400 psi Liner 651' 5 -1/2" 11,085' 10,844' 10,560 psi 11,160 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 1 3-1/2" 9.3# N -80 10,120' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A / N/A N/A / N/A 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 121 Service ❑ 14. Estimated Date for N/A 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑� - 16. Verbal Approval: Date: N/A WINJ ❑ GINJ F1 WAG ❑ Abandoned El Commission Representative: GSTOR El SPLUG El 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer 263 -7831 Printed Name 7Z Timothy C. Brandenbu Title Drilling Manager Signature Phone 276 -7600 Date l� Z '2 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: � ,AvS14 altf fV Zo AA Z S. It Z C ) / Q ,( K&J e. Ip � pj"a UKVAd IS A"Pp yoLt0-d I Subsequent Form Required: t4d APPROVED BY / Approved by: C MMISSIONER THE COMMISSION Date: Form 10-403 Revised 1/2010 G NA Submit in Duplicate Suspended WeU Data Well: SRU 24 -33 Surface Location: 932' FNL, 2089' FWL, Sec 4, T7N, R9W S.M. Permit to Drill: 172 -007 API: 50- 133 - 20237 -00 AOGCC Inspection Date: 9/27/10 AOGCC Inspector: Bob Noble Size Pressure (psi) Tubing 3 -1/2" 0 Casing 7 -5/8" 0 10 -3/4" 0 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: • There has been no change in the mechanical condition of SRU 24 -33, based on monitored pressure trends. The well was suspended in good mechanical condition in April 1993 with a cement retainer and cement isolating the completion interval. • Formation pressure from surface to the top of the completion interval is a normal . pressure gradient. • The proposed plan for SRU 24 -33 is to maintain suspended status while prioritizing the well with other workover and abandonment candidates. The plan includes a continuation of 2009 and 2010 work programs that returned shut -in wells to production (3 per year) and abandoned shut -in wells with no potential (2 in 2010). Attachments: • Current Well Schematic • 3 Year TIO Plot SRU 24 -33 20" @ 337' L NOTE: All depths are KB reference. 9 7 PPG Original GL -KB is 20 ft. BRINE P &A CEMENT E FILL 10 -3/4' @ 3408' L , CAMCO MM MANDREL 3612' CAMCO MM MANDREL 4961' CAMCO MM MANDREL 5028' CAMCO MM MANDREL 6728' CAMCO MM MANDREL 7234' CAMCO MM MANDREL o' 7557 CAMCO MM MANDREL EST TOC 101.2V 10276' 3 -1/2" x 2 -3/8" CROSSOVER 5 -1/2" LINER @ 10434 CEMENT RETAINER 0 10580' 10590' XA SLEEVE TUBING PERFORATIONS 10610' - 10615 C EMENT RETAINER 010620' 10624' PACKER 7 -5/8" @ 10635' "` ' 10630' S NIPPLE LINER PERFORATIONS `s" " TUBING PERFORATIONS 10635'- 10640 10644'- 10660' 10676'- 10696' 10704'- 10711' . :sr 10721'- EIV ' "'�:r: 10733' D NIPPLE INA 0 3 X993 ti Alaska Oil & Gas Cons. Cammissi 2 -3/8" 4.6# @ 10754' 10738' FILL Anchorage 10763' TOP OF FISH LINER PERFORATIONS 10765' PACKER 10740' -1 0762' 10770'- 10794' 5 -1/2" 23# @ 11085' 10821' PBTD Plot Pressure & Rate vs Time - Well SRU 24 -33 400 350 7 133/8" Tubing 300 250 d L N 200 L a 150 100 50 0 0 o g o 0 0 0 0 0 r n n n r n n n n n n r �ro '- o� .-m '- rn .-m �m �o .-o �o Date 7" 13 3/8" Tubing TIO Report 09/30/10 0 0 0 08/27/10 0 0 0 Data Sheet 07/20/10 0 0 0 06/25/10 0 0 0 05/2/10 0 0 0 SRU 24 -33 04/30/10 0 0 0 03/27/10 0 0 0 02/19/10 0 0 0 FLOWING 01/28/10 0 0 0 12/24/09 0 0 0 11/09/09 0 0 0 Permit # 1720070 10/07/09 0 0 0 08/29/09 0 0 0 08/19/09 0 0 0 API # 50- 133 - 20237 -00 07/31/09 0 0 0 03/29/09 0 0 09/30/08 0 0 10/17/2007 to 10121/2010 01/23/08 0 0 12/20/07 0 0 10/17/07 10/26/2010 4:20 PM - TIO Reports 7e.xls J J Dolan SRU 24 -33 TIO Plot.xls SRU 24 -33 Page 1 of 1 Aubert, Winton G (DOA) From: Kanyer, Christopher V [Chris.Kanyer @chevron.com] Sent: Monday, November 15, 201011:20 AM To: Aubert, Winton G (DOA) Subject: SRU 24-33 (PTD 172 -007) Winton, Per our earlier phone conversation, we request a variance from the suspended well plug placement, regulation 20AAC25.112(c)(3), on our sundry request, for suspended well renewal, for well SRU 24 -33 (PTD 172 -007). Please let me know if you have any questions regarding this request. Thanks. Chris Kanyer Technical Assistant Wellbore Maintenance Team Office: (907) 263 -7831 Cell: (907) 250 -0374 Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 11/15/2010 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS19 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Ll Repair Well Li Plug Perforations Li Stimulate Ll Other � Suspended Well Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Inspection Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re-enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5`Permit to Drill Number: Name: Development ❑.r Exploratory ❑ Stratigraphic❑ Service ❑ 172-007 3. Address: PO Box 196247, Anchorage, AK 99519 6. API Number: 50-133-20237-00 ao 7. PropertkDesignation (Lease Number): 8. Well Name and Number: FEDA028399 [Swanson River Unit] Swanson Riv Unit 24-33 9. Field/Pool(s): Swanson River Field / Hemlock Oil Pool 10. Present Well Condition Summary: Total Depth measured 11,088 feet Plugs (measured) 10,120' (cement) feet true vertical 10,845 feet Junk (measured) N/A feet Effective Depth measured 10,124 feet Packer (measured) N/A feet true vertical 9,972 feet (true vertical) N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 337' 20" 337' 336' Surface 3,408' 10-3/4" 3,408' 3,407' 3,130 psi 1,580 psi Intermediate Production 10,635' 7-5/8" 10,635' 10,435' 6,020 psi 3,400 psi Liner 651' 5-1/2" 11,085' 10,844' 10,560 psi 11,160 psi Perforation depth: Measured depth: N/A True Vertical depth: N/A 0C 2' 2 Tubing (size, grade, measured and true vertical depth): 3-1/2" 9.3# N-80 10,120'MD 9,9697VD Packers and SSSV (type, measured and true vertical depth): N/A N/A N/A N/A 11. Stimulation or cement squeeze summary: Intervals treated (measured): fO T 2 0 2010 t a N/A Treatment descriptions including volumes used and final pressure:% N/A 12. Representative Daily Average Production or Injectio Oil -Bbl Gas-Mcf I Water -Bbl I Casing Pressure Tubing Pressure Prior to well operation: 0 0 10 10 psi 0 psi Subsequent to operation: 0 0 10 10 psi 0 psi 13. Attachments: 14. Well Class after worii Copies of Logs and Surveys Run N/A Exploratory❑ Development❑✓ Service ❑ Daily Report of Well Operations N/A 15. Well Status after work: Oil Gas WDSPL Well Remains in'SUSP' Status ==> GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG ❑ 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Chris Kanyer 263-7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature -' Phone 276-7600 Date 10/11/10 OCT 21106c�� Form 10-404 Revised 7/2009 Submit Original Only Suspended Well Inspection Data Well: SRU 24-33 Surface Location: 932' FNL, 2089' FWL, Sec 4, T7N, R9W S.M. Permit to Drill: 172-007 API: 50-133-20237-00 AOGCC Inspection Date: 9/27/10 AOGCC Inspector: Bob Noble *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: • None. Attachments: • Current Well Schematic • Picture(s) • Plat-1/4mile radius of wellbore Size Pressure (psi) Tubing 3-1/2" 0 Casing 7-5/8" 0 10-3/4" 0 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: • None. Attachments: • Current Well Schematic • Picture(s) • Plat-1/4mile radius of wellbore 20" Qe 33T IF 10-3/4' @ 3408' 5-1/2" LINER @ 10434' 7-5/8" @ 10635' LINER PERFORATIONS 10644'-10660' 10676'-10696' 10704'-10711' 10721'-10735' 2-3/8" 4.6# @ 10754' LINER PERFORATIONS 10740'-10762' 10770'-10794' 5-1/2" 23# @ 11085' • SRU 24-33 IL NOTE: All depths are KB reference. Original GL -KB is 20 ft. P&A CEMENT ® FILL 1983' CAMCO MM MANDREL 3612' CAMCO MM MANDREL 4961' CAMCO MM MANDREL 5028' CAMCO MM MANDREL 6728' CAMCO MM MANDREL 7234' CAMCO MM MANDREL 7557' CAMCO MM MANDREL 10276' 3-1/2" x 2-3/8" CROSSOVER CEMENT RETAINER„ 0-110580 10590' XA SLEEVE TUBING PERFORATIONS 10610'-10615' CEMENT RETAINER 0-10620' 10624' PACKER ,10630' S NIPPLE 31� 10733' D NIPPLE MA`s _ 319 3 10738' FILL Alaska Oil & Gas Cons. Commission Anchorage 10763' TOP OF FISH 10765' PACKER 10821' PBTD SRU 24-33 (114 Mile Radius) 341= 34M 34M mm 340W 34M Us,oa 34= son i vi ♦ee ii♦ m 1 Swanson River Field —SRF secton.bd 0 O ! Scab S*AAM 1.1 mgo Kevin go Lhgm Dok Pro"4M 3012010 NAD27 Aleck a Stat Pleas 4 `F 324-33 33 SCU 3 S 3 ' 1 SCU -33 SW • SCU 14- SR 4-33 N SCA 5 SCU 1-04 t C U 42-04 SC 2-04 Sc lull= SCU ' ,�J 332-04 Y: •� 4 SCU 323-04 SCU 2;b . SCU 43A-04SC 13-03 i vi ♦ee ii♦ m 1 Swanson River Field —SRF secton.bd 0 O ! Scab S*AAM 1.1 mgo Kevin go Lhgm Dok Pro"4M 3012010 NAD27 Aleck a Stat Pleas 4 U ndefined Cas .1:AS1 AM Sts"*-- 271'1'SL v m _ t � _ � r e � , t 4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/27/10 Inspector: Bob Noble Operator: Union Oil Well Name: SRU 24-33 • Oper. Rep: Lee Elliott PTD No.: 172-007 Oper. Phone: 907-398-9992 Location Verified? Yes Oper. Email: If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 04/01/93 Date AOGCC Notified: 09/22/10 . Sundry No.: Sundry Rpt 5/3/93 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 25 " Photos Taken? Yes IA 0 OA 0 " SCANNED AUG 1 4 2015 Condition of Wellhead: The location was verified with the use of a plot plan and a well sign.The wellhead was found to be in good condition with working gauges. The cellar had about 2"of clean water with no sheen.There was no guard rail to protect the wellhead. Condition of Surrounding Surface The location looked good with no sign of old oil staining. Location: Follow Up Actions Well sign is incorrect-shows Soldotna Creek Unit;well file and permits indicate Swanson River Unit 24-33 Needed: Attachments: Photos(3) - REVIEWED BY: Insp.Supry JAW-- Comm PLB 09/2010 2010-0927_Suspend_SRU_24-33_bn.xlsx Suspended Well Inspection—SRU 24-33 PTD 1720070 Photos by AOGCC Inspector B. Noble 9/27/2010 - -,.,.,,,,,.. l• ;,... '-AV4: ''' • '.. 1., „ •';''..1' ,, ' eh'•t 1 r. .. , ^ , 'r , • SOLDOTNA CREEK UNIT. WELL NO $CU 24-33 .. . ........ ....ow 4. L. . •z7/4/0 i i 1 1 \ \ ., • , . .,- .. •*,----s f.i.,* '- ' : --' • - -.. - \ \ \, ,.. ..tr!'; .. /'• f.. fifk' , -.•// / lilt Al \ \ , . • •-•,-;''', . \\'\te V , ' •i , f-1.1 • , ' 1 .r : . . , \ \ ' . . • -1' -- ' , , . Is, '•\ , -rif .... f. , • • 4 --,4,,4 r. itt'" , i ; '• " ."''' ' ' l', 'e.y,A . . 40.10111101014 ""''' r 1044',,, 1 ...', •.`. ...4: - I I 1 \ \\ \ NN, ..,,..„..:,...›..,, N. '`....N.,',....... .....2.7.,,, ."-..,:::.:*,. ( , .. • \s, --...,,, 2010-0927_Suspend_SRU_24-33_photos.docx Page 1 of 2 r , A ,IF. f t� r r //% %//// i .,. 1-4 /Z-14/// / / J / i is \ , \\\\ v/., ,,// 7 / / I I I 1 ei 1 I I ' . \ \ \ 1 f ...'444,11N ' ik ' ,' ' ' .,,,„,„ , , ..,\ \\\\\\ ..� � , -—,447,. \\\\\ \A , i __. . „. ., ._ . .. „ 17 '''' �, Rs' r • : 2010-0927_Suspend_SRU 24-33 photos.docx Page 2 of 2 March 31, 2009 Dale Haines Alaska Area Operations Manager Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7" Avenue Anchorage, Alaska 99501 Re: Suspended Wells Dear Commissioner Foerster, `1 'L- o o -"t Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7951 Fax 907 263 7607 Email Daleah@chevron.com SCANNED X 1 0 7 2 0.1 Please find the attached corrections to the suspended and long term shut in well list as provided in your letter dated January 28, 2009. As per our discussion the submitted list needs to be expanded to include additional wells that may not currently be identified on the list provided by the Commission. We also provide the Commission with an annual shut in well report that is sent to Steve McMains. This report was mailed to the Commission on March 30, 2009. At this time I cannot validate that we have provided the Commission with a comprehensive list of all suspended wells so it is our intention to validate the two lists and to review our records to ensure that we have accurately responded to the request. We will therefore endeavor to provide a comprehensive list to the Commission in the next two weeks. Chris Myers will contact Jim Regg to discuss the scheduling inspections of the suspended wells in 2009. If you have any questions about this submittal, please contact myself. Sincerely, N 66 - Dale Haines Alaska Area Operations Manager Attachment Cc: Tim Brandenburg Chris Myers Dave Cole Union Oil Company of California / A Chevron Company http://www.chevron.com Corrections for the referenced list of suspended and long-term shut-in wells operated by UNOCAL. Well Name API# PTD Current Listed Status Corrected Status Bruce 18742 #40 50-733-20339-00 181-022 Suspended Shut -In SRU 14-15 50-133-10145-01 100-146 Suspended Shut -In SCU 243B-04 50-133-20489-00 199-055 Suspended Shut -In i ,.3 �`�_} SARAH PAUN, GOVERNOR 1 ALASKA OIL AND GAS 333 '✓1/ 7th AVENUE. SUITE 100 CONSERVATION TION COMMISSION ANc;HgFJiGE. ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-75:2 January 28, 2009 CERTIFIED MAIL. RETURN RECEIPT REQUESTED 7005 1820 0001 2499 6019 Dale l laines UNOCAL 3800 Centerpoint I)r. Ste 100 Anchorage AK 99503 Ile: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut -In Well Information i)ear Mr. 1 (sines: Enclosed are the Alaska Oil and Gas Conservation COmn1ISSIOn'S revised re, ulations regarding suspended wells (i.e., 20 AAC 25.110). - Also enclosed is a list of' suspended and long-term shut-in wells operated by UNOCAL. For each list, please verify the information for each well and provide any corrections by April I, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with .lim Regg at 907-793-1236 or jim.rcga@alask<i.gov. hav'_- an}r questions ?'naard)na this notice, t^,Icase _•mast Tom .ut,cwnrirr :tt 907-791- 1250 or tom.maunder(r,}alaska.gov. Sincerely, Cathy P. Foerster Commissioner I;nCIOSUres Operator Suspended and Shuts In Wells UNION OIL CO OF CALIFORNIA Field Current Date of Permit API Number Well Name Stntus titnlus Surface Location .................................................... Leasc(s)........................ BIRCH HILL 165.001-0 50-133-10029-00-00 BIRCH HILL UNIT 22-25 SUSP 3/7/1988 1836 FNL 1954 FWL Sec 25 T 9 N R 9 W SM FEDA028407 DEEP CREEK 207-123-0 50-231-20031-00-00 HAPPY VALLEY 8-12 SUSP 11/25/2007 2908 FNL 293 FEL Sec 21 T 2S R 13 W SM FEE-CIRI 14 V A - 5- GRANITE PT 196-045-0 50-733-20472-00-00 GRANITE POINT 52 SUSP 8/11/1997 2428 FNL 1298 FWL Sec 13 T ION R 12 W SM ADL0018761 196-013-0 50-733-20470-00-00 GRANITE POINT 54 SUSP 4/22/2006 2427 FNL 1303 FWL Sec 13 T ION R 12 W SM ADL0018761 197-145-0 50-733-20479-00.00 GRANITE POINT 55 SUSP 8/26/1997 2437 FNL 1303 FWL Sec 13 T 10 N R 12W SM ADL0374044 167-057-0 50-733-20046-00-00 GRANITE PT ST 11-24 SUSP 9/30/1997 2383 FNL 1368 FWL Sec 13 T ION R 12 W SM ADL0018761 167-023-0 50-733-20018-00-00 GRANITE PT ST 18742 09 SUSP 9/16/1989 834 FNL 676 FEL Sec 12 T ION R 12 W SM ADL0018742 167-042-0 50-733-20032-00-00 GRANITE PT ST 18742 10 SUSP 9/29/1988 1948 FSL 1979 FWL Sec 31 T 11 N R 11 W SM ADL0018742 178-096-0 50-733-20119-00-00 GRANITE PT ST 18742 31 SUSP 10/7/1988 1945 FSL 1982 FWL Sec 31 T 11 N R 11W SM ADL0018742 179.017-0 50-733-20441-01-00 GRANITE PT ST 18742 34 SUSP 9/20/1991 2012 FSL 1945 FWL Sec 31 T 11 N R 11 W SM ADL0018742 181-022-0 50-733-20339-00-00 GRANITE PT ST 18742 40 SUSP 4/21/1982 1948 FSL 1975 FWL Sec 31 T 11N R 11W SM ADL0018742 195-005-0 50-733-20465-00-00 GRANITE PT ST 18742 52 SUSP 7/9/1995 730 FNL 682 FEL Sec 12 T ION R 12 W SM ADL0018742 MCARTHUR RIVER 169.095-0 50-733-20203-00-00 TRADING BAY UNIT D-20 SUSP 1/31/2007 672 FSL 1211 FWL Sec 6 T 8N R 13W SM ADL0018729 173-001-0 50-733-20248-00-00 TRADING BAY UNIT K-17 SUSP 4/20/2002 694 FSL 83 FEL Sec 17 T 9N R 13W SM ADL0017594 SWANSON RIVER 199.055-0 50-133-20489-00-00 SOLDOTNA CK UNIT 2438-04 SUSP 9/22/1999 2003 FSL 575 FEL Sec 4 T 7N R 9W SM FEDA028997 180-106-0 50-133-20232-01-00 SOLDOTNA CK UNIT 42A-05 SUSP 8/9/2006 1879 FSL 498 FEL Sec 5 T 7N R 9W SM FEDA028997 182-199-0 50-133-20363-00-00 SOLDOTNA CK UNIT 428-05 SUSP 6/21/2006 1823 FSL 572 FEL Sec 5 T 7N R 9W SM FEDA028996 100-146-0 50-133.10145-01-00 SWANSON RIV UNIT 14-15 SUSP 1/28/1997 360 FSL 1680 FEL Sec 16 T 8N R 9W SM FEDA028406 162-034-0 50-133-10148-00-00 SWANSON RIV UNIT 14-22 SUSP 10/5/1995 660 FSL 660 FWI. Sec 22 T 8N R 9W SM FEDA028406 172-007-0 50-133-20237-00-00 SWANSON RIV UNIT 24-33 SUSP 4/1/1993 932 FNL 2089 vWL Sec 4 T 7 N R 9W SM FEDA028399 162-030-0 50-133-10143-01-00 SWANSON RIV UNIT 41A-15 SI 8/26/1987 615 FNL 715 FEL Sec 15 T 8N R 9W SM FEDA028384 203-074-0 50-133-20523-00-00 SWANSON RIVER KGSF 3 SUSP 8/22/2007 1754 FNL 4030 FEL Sec 27 T 8 N R 9W SM FEDA028406 11'ednesdit Jonxeq 14, :009 e J "o xr Z — j 'o /�P( – elwp S F 1 Operator Suspended and Shut In Wells UNION OIL CO OF CALIFORNIA Field Current Date of Permit API Number Well hone Status Status Surface Location .................................................... Lease(s)................................... TRADING BAY 190-041.0 50-733-20302-01-00 TRADING BAY ST A-20RD SUSP 4/23/1990 1604 FSL 559 FCL Sec 4 T 9 N R 13 W SM A01-0018731 N?J/'f �: opo /ped 11'ednesdnl-, Janunrr 14, 2009 20 F AC 25.1 10. Suspended «velis (a) ]f �IIIOWULI under 20 AAC 25.105. the COMMISS1011 will, upa:- ahpl:a:ion by t:�� operator under (b) of this section, approve the suspension of a well i (1) the well (A) encounters hydrocarbons of'sufficient quality and quantity to in-dicate that the well is capable of producing in paying quantities, as reasonably demonstrated by well: tests or interpretive formation evaluation data; for purposes of this paragraph, "paying quantities" means quantities sufficient to yield a return in excess of operating costs; (I3) is a candidate for redrilling; (C) has potential value as a service well, or (I)) is located on a pad or platform with active producing or service wells; and (2) the operator justifies to the commission's satisfaction why the well shoule not be abandoned, and, if the well is not completed, why the well should not be completed; sufficient reasons include the (A) unavailability of surface production or transportation facilities; (13) imprudence of security maintenance of a completed well in a shut-in status; (C) need for pool delineation and evaluation to determine the prudence of pool development. (b) An Application for Sundry Approvals (Form 10-403) must be submitted :o and approved by the commission before plugging operations are begun in a well for which suspension is proposed, except that oral approval may be obtained from the commission if it is followed within three days by the submission of an Application for Sundry Approvals for final approval by the commission. Approval will be conditioned as necessary to protect freshwater and hydrocarbon resources. An Application for Sundry Approvals must include (1) the reason for suspending the well and information showing that the applicable criteria for suspension under (a) of this section have been met; and (2) a statement of proposed work, including (A) information on abnon-nally geo-pressured strata; (B) the manner ol' placement, kind, size, and location, by measured depth, of existing and proposed plugs; (C) plans for cementing, shooting, testing, and removing casing; (ll) if thu ;\hlnlicr.tion for Sundry Approvals is submiitcd a(1cr bcsinu:ing work, thO panic of the representative of the commission who provided oral approva, and the date of the approval; and (E) other information pertinent to suspension of the well. (c) At the operator's request accompanying the submission, information subn it.ed to show that the applicable criteria for well suspension under (a) of this section have been met will be kept confidential (1) for the period specified under AS 31-05.035 (c), if the information is describ,.d in 20 AAC 25.071(n) ; or (2) for the time that the infonnation has value as a trade secret, if tac informaticn is not described in 20 AAC 25.071 b) but is determined by the commission. to constitute a trade secret under AS 45.50.940 . (d) A well approved for suspension must be plugged in accordance v"Ith the requi-ements of 20 AAC 25.112. except that the requirements of 20 AAC 25.112(d) do not apply if (1) a wellhead is installed or the well is capped with a mechanical device to seal the opening; and (2) a bridge plug capped with 50 feet of cement or a continuous cement plug ex;cnding 200 feet within the interior casing string is placed at or above 300 feet below the surface-, the commission will waive the requirement of this paragraph for a development well drilled from a pad or platform, if the commission determines that the level of activity on the pad or platforin assures adequate surveillance of that development well. (e) Until a suspended well has been abandoned or re-entered, the operator shall maintain the integrity of the location, provide the commission with a well status report every five years, and clear the location in accordance with 20 AAC 25.170 a (2) or (b) or with 20 AAC 25j 72(c) (2) or (d), as applicable. History: Eff. 4/2/86, Register 97; am 11/7/99, Register 152 Authority: AS 31.05.030 M ~1 2'00`1 a a a 0 SARAH PALIN, GOVERNOR ALASKA 011L AND GAS333 W 7th AVENUE, SUITE 100 CONSERQAIMON COMMISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 January 28, 2009 FAX (907) 276-7542 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 6019 Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut -In Well Information SCANNED OCT 0 7 2014 Dear Mr. Haines: Enclosed are the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed is a list of suspended and long-term shut-in wells operated by UNOCAL. For each list, please verify the information for each well and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or jim.regg@alaska.gov. If you have any questions regarding this notice, please contact Tom Maunder at 907-793- 1250 or tom.maunder@alaska.gov. Enclosures Sincerely, Cathy P. Foerster Commissioner Postal o. CERTIFIED MAIL,. RECEIPT rq c3 (Domestic Mail Only; No Insurance Coverage Provided) MIMI ..n AWJKlRA D' , fU Postage $ $0.59 SQS P0— 9 0 Certified Fee $2.70 N o C3 Return Receipt Fee S ? f (Endorsement Required) X2,20 Q�9 fry Restricted Delivery Fee C� ,QQ rU (Endorsement Required) m AK 5S`O,, r-9 Total Postage 8 $5.49 01128/ Ln M Sent To Dale Haines Cl 1=1UNOCAL t`' Strtief Apt. Wo.; or Po sox No. 3800 Centerpoint Dr. Ste 100 city sieie, z/Pr Anchorage AK 99503 ■ Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. ■ Print your name and address on the reverse so that we can return the card to you. ■ Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 r Anchorage AK 99503 A. gnature Xnt J \> n\( �' p t y�t� A re ssep Received b `(,Printed Name)", C. a of Pli�jry D. Is delivery address different from item 1? ❑ Y 7 If YES, enter delivery address below: ❑ No 3. Service Type -U-Certified Mail ❑ Express Mail ❑ Registered C:fReturn Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number (transfer from service label) 7005 1820 0001 2499 6 019 PS Form 3811, February 2004 Domestic Return Receipt 102595-02•M•1540 Operator Suspended and Shut In Wells UNION OIL CO OF CALIFORNIA Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... BIRCH HILL 165-001-0 50-133-10029-00-00 BIRCH HILL UNIT 22-25 SUSP 3/7/1988 1836 FNL 1954 FWL Sec 25 T 9 N R 9 W SM FEDA028407 DEEP CREEK 207-123-0 50-231-20031-00-00 HAPPY VALLEY B-12 SUSP 11/25/2007 2908 FNL 293 FEL Sec 21 T 2S R 13W SM FEE-CIRI GRANITE PT 196-045-0 50-733-20472-00-00 GRANITE POINT 52 SUSP 8/11/1997 2428 FNL 1298 FWL Sec 13 T 10 N R 12W SM ADLO018761 196-013-0 50-733-20470-00-00 GRANITE POINT 54 SUSP 4/22/2006 2427 FNL 1303 FWL Sec 13 T 10 N R 12 W SM ADL0018761 197-145-0 50-733-20479-00-00 GRANITE POINT 55 SUSP 8/26/1997 2437 FNL 1303 FWL Sec 13 T 10 N R 12W SM ADL0374044 167-057-0 50-733-20046-00-00 GRANITE PT ST 11-24 SUSP 9/30/1997 2383 FNL 1368 FWL Sec 13 T 10 N R 12W SM ADL0018761 167-023-0 50-733-20018-00-00 GRANITE PT ST 18742 09 SUSP 9/16/1989 834 FNL 676 FEL Sec 12 T 10 N R 12W SM ADL0018742 167-042-0 50-733-20032-00-00 GRANITE PT ST 18742 10 SUSP 9/29/1988 1948 FSL 1979 FWL' Sec 31 T 11 N R 11 W SM ADL0018742 178-096-0 50-733-20119-00-00 GRANITE PT ST 18742 31 SUSP 10/7/1988 1945 FSL 1982 FWL Sec 31 T 11 N R 11 W SM ADL0018742 179-017-0 50-733-20441-01-00 GRANITE PT ST 18742 34 SUSP 9/20/1991 2012 FSL 1945 FWL Sec 31 T 11 N R 11 W SM ADLO018742 181-022-0 50-733-20339-00-00 GRANITE PT ST 18742 40 SUSP 4/21/1982 1948 FSL 1975 FWL Sec 31 T 11 N R 11 W SM ADL0018742 195-005-0 50-733-20465-00-00 GRANITE PT ST 18742 52 SUSP 7/9/1995 730 FNL 682 FEL Sec 12 T 10 N R 12W SM ADL0018742 MCARTHUR RIVER 169-095-0 50-733-20203-00-00 TRADING BAY UNIT D-20 SUSP 1/31/2007 672 FSL 1211 FWL Sec 6 T 8 N R 13W SM ADL0018729 173-001-0 50-733-20248-00-00 TRADING BAY UNIT K-17 SUSP 4/20/2002 694 FSL 83 FEL Sec 17 T 9 N R 13W SM ADLO017594 SWANSON RIVER 199-055-0 50-133-20489-00-00 SOLDOTNA CK UNIT 2436-04 SUSP 9/22/1999 2003 FSL 575 FEL Sec 4 T 7 N R 9 W SM FEDA028997 180-106-0 50-133-20232-01-00 SOLDOTNA CK UNIT 42A-05 SUSP 8/9/2006 1879 FSL 498 FEL Sec 5 T 7 N R 9 W SM FEDA028997 182-199-0 50-133-20363-00-00 SOLDOTNA CK UNIT 428-05 SUSP 6/21/2006 1823 FSL 572 FEL Sec 5 T 7 N R 9 W SM FEDA028996 100-146-0 50-133-10145-01-00 SWANSON RIV UNIT 14-15 SUSP 1/28/1997 360 FSL 1680 FEL Sec 16 T 8 N R 9 W SM FEDA028406 162-034-0 50-133-10148-00-00 SWANSON RIV UNIT 14-22 SUSP 10/5/1995 660 FSL 660 FWL Sec 22 T 8 N R 9 W SM FEDA028406 172-007-0 50-133-20237-00-00 SWANSON RIV UNIT 24-33 SUSP 4/1/1993 932 FNL 2089 FWL Sec 4 T 7 N R 9 W SM FEDA028399 162-030-0 50-133-10143-01-00 SWANSON RIV UNIT 41A-15 SI 8/26/1987 615 FNL 715 FEL Sec 15 T 8 N R 9 W SM FEDA028384 203-074-0 50-133-20523-00-00 SWANSON RIVER KGSF 3 SUSP 8/22/2007 1754 FNL 4030 FEL Sec 27 T 8 N R 9 W SM FEDA028406 Wednesday, January 14, 2009 Operator Suspended and Shut In Wells UNION OIL CO OF CALIFORNIA Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... TRADING BAY 190-041-0 50-733-20302-01-00 TRADING BAY STA-20RD SUSP 4/23/1990 1604 FSL 559 FEL Sec 4 T 9 N R 13 W SM ADL0018731 Wednesday, January 14, 2009 Form ~160-5 (JUNE 1990) UNITED STATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reent;y to a different reservoir. Use 'APPMCATION FOR PERMIT-' for such proposaJs SUBMIT IN TRIFLICA TE 1. Type of Well Oil Gas we, we, I-I Other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchoraqe, AK 99519 (907) 276-7600 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit -- 14 Wells Soldotna Creek Unit -- 7 Wells FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31, 1993 5. Lease Designation and Serial No. 6. If Indian, Nlottee or Tribe Name 7. If Unit or CA, Agreement Designation Swanson River/ Soldotna Creek Units 8. We~l Name and No. 9. APl Well No. 10. Field and Pool, or Exploratory Area Swanson River Field 11. County or Parish, State Kenai, Alaska 12. CHECKAPPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION Notice of Intent [] Subsequent Report Final Abandonment {-'] Abandonment r'-] Change of Plans I--] Recompletion [--] New construction 0 Plugging Back r-I Non-Routine Fracturing {'-] Casing Repair ~ Water Shut-Off r'-] Altering Casing ~ Conversion to Injection [~ Other Temporarily Abandon ~ Dispose Water (Note: Report results of multiple conmpletion on Well Completion or Recom~ Report and Log form.) 13. Describe Proposed or Completed Operations (Clearly slate all pertinent details, and give pertinent dates, including estimated date of stmlJng any p~oposed work. If well is directionally drilled, give subsurbce locations and measured and true vertical depths for all mad(ers and zone pertinent to this work.)* As described in attached letter, Unocal requests that the folk)wing wells have a temporarily abandoned status for the twelve month period, April 1,1996 to March 31,1997: Soldotna Creek Unit (o,~.' icj SCU 21-8 ~li SCU 34-9 (~') ~SRU 212-10 (O1' ~SCU34-8 ~scu41a-9 (.~O-~RU12-15 ~,,~.- I SCU 243-8! [.~.~CU 14-3400-~ ~SRU 14-15 SRU 41A-15 gO- 107" J (~)'-I'"~ SRU23-22 * High GOR well that may be produced intermittently Swanson River Unit SRU -27 SRU~-28 ~ /_ SRU43-~ ~1- ~ SRU 21- 3WD 0 SRU 24-33 14. I hereby certify th~ the foregoing is true and correct. Dennis L. Groboske Petroleum Engineer D~, 3/29/96 Approved by Tale Conditions of approval, if any: Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willlully b3 make to any department or agency of the United States any false, fictitious or fraudulert statements or repr~ ~ to any ma~er within its ju~dietion. *See Instruction on Reverse Side Attachment No. 1 Swanson River Field Proposed Temporarily Abandoned Wells: Total 21 Wells Twelve Month Period: April 1, 1996 to March 31, 1997 Shut-in Wells under Evaluation for Shut-in Wells during Field Blowdown Rate Potential P&A Shallow Gas Potential and 'Hemlock Only' P&A Hemlock Producers Future Shallow Gas Producer with the Hemlock Abandoned SCU 34-8 SCU 243-8 SCU 13-9 SCU 41B-9 SRU 21-33WD SRU 34-28 SRU 43-28 SRU 212-10 SRU 212-27 SRU 12-15 SRU 41A-15 SRU 23-27 SRU 331-27 SCU 14-34 SCU 21-8 SCU 34-9* SRU 14-15 SRU 43A-15 SRU 14-22 SRU 23-22 SRU 24-33 7' Wells 2 Wells 5 Wells *.~.h GOR well that may be produced intermittently 2 Wells 5 Wells ATTACHMENT 2 SWANSON RIVER FIELD Wells with Temporarily Abandoned Status Change Removed from 1996 Temporarily Abandoned Status · SCU 34-4 Recompleted in Tyonek 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 23B-3 Returned to full time production · SCU 314-3 Returned to full time production · SCU 43-9 Returned to full time production · SCU 23-15 Returned to full time production Additions to 1996 Temporarily Abandoned Status · SCU 13-9 Recompleted in Tyonek G2 zone Iow rate oil producer. APR 01 1996 ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 August 19, 1994 Kevin Tablet, Land Manager UNOCAL ? O Box 196247 Anchorage, AK 99519-6247 Re: Suspended Wells Compliance with regulations Dear Mr. Tabler: UNOCAL has 15 suspended wells as shown on the attached list: ALASKA SUSPENDED WELLS AS OF AUGUST 1994. The applicable regulation is as follows: 20 AAC 25.110 SUSPENDED WELLS (a) Upon application by the operator under 20 AAC 25.105(e), the commission will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have future value as a service well. For each well on the attached list of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above or advise as to your plans to abandon the well. Wells 'that meet the criteria of (a) above that you wish to maintain as suspended, as required by 20 AAC 25.110(e), must have well site inspections as appropriate this year prior to snow covering the locations. · Chairman c: Blair Wondzell encl hew/llunsusp ALASKA SUSPENDED WELLS AS OF AUGUST 1994 PERMIT API NUMBER OPE~TOR WELL NAME 00-0146-0 133-10145-01 61-0045-0 133-10144-01 66-0008-0 283-10020-01 66-0038-0 283-10021-00 67-0007-0 283-20003-00 67-0023-0 733-20018-00 67'0042-0 733-20032-00 72;-0007-0 133-20237-00 UNION OIL CO SWANSON RIV UNIT 14-15 UNION OIL CO SWANSON RIVUNIT 43-15RD UNION OIL CO NICOLAI C.K ST 1-A ~TNION OIL ~O NIC~DI~AI C~K ~IT 2 ~ION OIL ~ NI~I CK~IT 3 ~ION OIL ~ G~ITE PT ST 18742 9 ~ION OIL =O G~ITE PT ST 18742 10 ~NION OXL CO . ~SWANSON RIV UNXT ~2~:.&~33 . 75-0008'-0 283-20045-00 UNION OIL CO 77'0017'0 733'20300-00 UI~ION O=L CO 78-0096-0 733-20119-00 UNION OIL CO 79-0017-0 733-20441-01 UNION OIL CO 81-0022-0 733-20339-00 LT~ION OIL CO 90-0041-0 733-20302-01 UNION OIL ~O 90-0071-0 733-20417-00 UNION OIL CO IVAN RIVER UNIT 14-31 MOS ST 17595 16 GRANITE PT ST 18742 31 G~/~ITE PT ST 18742 34 GRANITE PT ST 18742 40 T~tDING BAY ST A-20~D T~tDING BAY LT~IT M-04 WELL ~LAS S D~V DEV DEV D~-V DEV DEV SER DEV DEV DEV DEV DEV DEV DEV WELL STATUS SUSP SUSP SUSP SUSP SUSP ~US~ STATUS DATE 11/08/91 8/20/91 8114/91 9118/91 9102/91 9116/89 9/29/88 4101193 8/18/75 2/05/92 10/07/88 9/20/91 4/21/82 4/23/90 7/03/90 SECT 16 15 29 29 2O 12 31 O4 01 31 31 O4 08N 08N 11N 11N 11N 10N 11N 07N 09N 11N 11N 11N 09N 09N 009W 009W 012W 012W 012W 012W 011W 009W 009W 012W 011W 011W 011W 013W 013W Unocal North Amef' '~<,. Oil & Gas Division ~ Unocal Corporation *' ~ 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 Alaska Region UNOCAL ) March 31, 1994 Re: Mr. Joseph A. Dygas .... . Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 · 1994 Sundry_ Notice Reauest for TA Wells in Swanson River Fiel~ Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 30 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are'requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Thirtieth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1994 to March 31, 1995. Two information sheets are attached with this Sundry Notice request. Attachment I lists the proposed TA wells using the same. format as submitted last year. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses during field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Three wells SCU 24A-9, SCU 33-5, and SCU 21-3 were removed from the list while two wells SFIU 12-15 and SRU 21- 33WD were added to the list. RECEIVED APR - 1 1994 Alaska Oil & Gas Cons. Commission .Anchorage Mr. Joseph A. Dygas March 31, 1994 Page 2 · , · o As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-781 6. DLG:dma ~Z.·.Dennis L.' ~~,r(~ske Petroleum Engineer Attachment CC: L. R. Dartez, Marathon Oil Company D. W. Johnston, Chairman, AOGCC Form 3160-5 (JUNE 1990) UNi'r~ ATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reenlry to a different resen~oir. Use 'APPMCATION FOR PERMIT-' for such proposals SUBMIT IN TRIPLlCATE 1. Type of Well Oil Gas we, we, FI or,er 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchorage, AK 99519 (907) 276-7600 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit --- 19 wells Soldotna Creek Unit --- 11 wells FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31~ 1993 , 5. Lease Deeign~on and Serial No. 6. If Indian, Allottee or Tribe Name . . · .· 7. If Unit or CA, Agreement Dedgnation Swanson River/ Soldotna Creek Units 8. Well Name and No. g. APl Well No. 10. Field and Pool, or Exploratory Area Swanson River Field 11. County or Parish, State Kenal, Alaska 12. CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION r~ Change of~'lans Notice of Intent Subsequent Repo~ Final Abandonment ['] Abendonment r"] Recompletion ~ New Construction r-] Plugging Back ~ Non-Routine Fracturing r"i casing Repair r'] Water Shut-Off ~] Altering Casing I-1 Conversion to Injection [~ Other Temporarily Abandon ["J Dispose Water (Note: Report resura d mulliple ~mplelion on Well 13. Desuibe Proposed or COml:~aed Operations (Clearly sate all pertinent detaib, and give patineat dat~, inducing estimated date of ,aning any ixolx~ work. As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1994 to March 31, 1995: Soldotna Creek Unit ,.-% !' * SCU 23B-3 SCU 243-8 ;~ 1 SCu 13-4 SCU 341-8 <J ~ * SCU 21A-4 SCU 13-9 :~1 SCU 34-4 * SCU 34-9 f I * SCU 43A-4 SCU 14-34 / -d//-.* SCU 21-8 *High GOR wells that may be produced Intermittently. Swanson River Unit ~-I SRU 212-10 ./-"SRU 14-22 $ I SRU 43-28 %us SRU 14-15//-~/~RU 12-15 $ ( SRU 14A-33 ~%~' SRU 23-15 ~ SRU 23-22TU.~SRU 24-33 ~u~l=SRU 34-15 :.'51 SRU 23-27; ':'~ SRU 32-33WD % !. SRU 41A-151~SRU 212-27 SRU 21-33WD 5t~sp 8RU 43A-15G~ SRU 331-27 ' ~ u.~ SRU 432-15 ~! SRU 34-28 (This space fo~ F~ and ~te~use) Concrdions of apprm~l, if any: RECEIVED APR - 1 1994 'i"~, 18 U.S.C. Section 1001, makes it, aime for any person knowingly and willfully to make to any department or agency o~ lhe United s~~,~ns. C0mmissi0r *See Instruction on Reverse Side AnGhorage Attachment No, I Swanson River Field Proposed Temporarily Abandoned Wells: Total 30 Wells Twelve Month Period: April 1, 1994 to March 31, 1995 Shut-in Wells under Evaluation for Shallow Gas Potential Rate Potential P & A and 'Hemlock Only' P & A ~o--I~ SRU 212-10 (~[- oS SRU 23-15 SCU 341-8 (~.-~o SRU 41A-15 SRU 34-28 ez~5~ SRU 14-22 SRU 43-28 ~-to~SRU 23-22 SRU 32-33WD/~I-~%SRU 212-27 SCU 243-8 c~-~ SRU 331-27 SRU 21-33WD~Z~SRU 12-15 Io0~&SCU 14-34 &0-qc/SRU 23-27 SRU 14A-33 Shut-in Wells during Field Blowdown Hemlock Future Shallow Gas Producer Producers with the Hemlock Abandoned SCU 21-8' C0-1% SRU 14-15 SCU 13-9 U0-u~t SRU 34-15 SCU 34-9' SRU 43A-15 SCU 23B-3' %5-bb SRU 432-15 SCU 43A-4' -~_-o-~SRU 24-33 SCU 21A-4' 8 Wells 8 Wells 3 Wells 6 Wells 5 Wells *High GOR wells that may be produced intermittently RECEIVED APR - ] 1 94 Alaska Oil & Gas Cons. Commission Anchorage Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change Additions to 1994 Temporarily Abandoned Status · SCU 12-15: Shut-in gas lift producer with casing communication. Evaluate for repair or abandonment. · SCU 21-33WD: Shut-in due to wireline fish in tubing. Workover candidate. Removed from 1994 Temporarily Abandoned Status · SRU 24A-9: · SRU 21-3: · SRU 33-5: Returned to full time production after workover. Returned to full time production due commencement of Blowdown in field. Returned to full time production after workover. tO RECEIVED ~,PR - 1 1994 ~s~ u~l & Gas Cons. Commission Anchorage /' STATE OF ALASKA ~'~ · AL/~ , OIL AND GAS CONSERVATION COMI~ .ION U',~ , , 1. Operations pe~rmed: Operation sh~down __ S~mubte __ gg' g Pull tubi~ ~ter casing Repair well Pull tub,~ ~herX Partia~/ndo~ .... 6. Datum e~mio. (DF or KBb 2. Name of Operat~ Type of Well: Union Oil Company of California (Unocal) 3. Address P.O. Box 196247 Anchorage, AK 99519 Development Exploratory Stratig mphic 4. Location of well at surface 932'S & 2089' E of NW Corner, Sec. 4, T7N, R9W, SB&M At top of productive interval 675'N & 2298' E of SW Corner, Sec. 33, T8N, R9W, SB&M At effective depth 509' N & 2339' E of SW Corner, Sec. 33, T8N, R9W, SB&M At tolal depth 271' N & 2399' E of SW Corner, Sec. 33, T8N, R9W, SB&M 12. Present well condition summary Total depth: measured 11,088' feet true vertical 10,845' feet Effective depth: measured 10,821' feet true vertical 10,599' feet Casing Structural Conductor Surface Intermediate Production Liner ? 7~' ,/-¢'Z~ { feet 7. Unit or Prope_rty name . Swanson R~ver Unit 8. Well number SRU 24- 33 9. Permit number/approval number 72-7 :10. APl number 50-133-20237-00 11. Field/Pool ~,,,~~(im~iver Field LEiVr-F Length Size Plugs (measured) MAY- 5 199~ Junk (measure~Jaska 0il & (~as Cons. C0mmissi0~ Anchorage Cemented Measured depth True vertical depth 266' 20" Yes 266' 266' 3408' 10-3/4" Yes 3408' 3408' 10635' 7- 5/8" Yes 10635' 1031 O' 651' 5-1/2" Yes 11085' 10483'l Perforation depth: measured 10,862'- 10,832' (squeezed); 10,794'- 10,770'; 109,762 '- 10,740' 10,735'-10,721'; 10,711'-10,704'; 10,696'-10,676'; 10,660'-10,644' true vertical 10,641 '- 10,612'(squeezed); 10,574'- 10,551 '; 10,543'- 10,522' 10,517'-10,503'; 10,493'-10,486'; 10,478'-10,459'; 10,443'-10,427' Tubing (size, grade, and measured depth) 3--1/2", 9.3#, N-80 0'-10,275'; 2-3/8" 4.6# EUE 8rd 10,275' Packers and SSSV (type and measured depth) Baker model "FH" Pkr @ 10,624' hen1 13. Stimulation or cement squeeze summary Intervals ~reated (measured) 10,644'- 10,735' Treatment description including volumes used and final pressure 9 bbls Class "G" cmt, FP - 4850 psi 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X_ 16. Status of well classification as: Oil__ Gas __ Suspended X_._ Service 17. I herel~e~rect to the best of my knowledge. Signed G. Russell Schmidt Title Drillincj Manager Form 10-404 Rev 06/15/88 Date 04/22/93 SUBMIT IN DUPLICATE 20" @ 337' 10-3/4' @ 3408' TUBING CUT @/0/;~0, EST TOC /o/.~ 5-1/2" LINER @ 10434' 7-5/8" @ 10635' 9.7 PPG BRINE SRU 24-33 NOTE: All depths are KB reference. Original GL-KB is 20 ft. ~ P&A CEMENT FILL ~_1983' CAMCO MM MANDREL 3612' CAMCO 4961' CAMCO 5028' CAMCO 6728' CAMCO 7234' CAMCO 7557' CAMCO MM MANDREL MM MANDREL MM MANDREL MM MANDREL MM MANDREL MM MANDREL 10276' 3-1/2" x 2-3/8" CROSSOVER ~EMENT RETAINER 6~10580' 10590' XA SLEEVE TUBING PE, RFORATION~; 10610'-10615' CEMENT RETAINER ~10620' 10624' PACKER 10630' S NIPPLE LINER PERFORATIONS 10644'-10660' 10676'-10696' 10704'-10711' 10721'-10735' ' 2-3/8" 4.6# @ 10754' TUBING PERFORATIONS 10635'-10640' RECEIVE ) 10733' D NIPPLE MAY - ~ 199~ A~aska 0il & Gas Cons. Commission Anchorage 10738' FILL LINER PERFORATIONS 10740'-10762' 10770'-10794' 5-1/2" 23# @ 11085' 10763' TOP OF FiSH 10765' PACKER 10821' PBTD SWANSON RIVER SRU 24-33 11,085' TD DAY 2 (3/29/93) RIGGED UP SLICKLINE. PULLED AND VERIFIED THAT THE GLM'S AT 4961' AND 7234' WERE DUMMIES. CLOSED XA SLEEVE AT 10,590'. PRESSURE TESTED ANNULUS TO 300 PSI, OK. BAILED SAND OFF "S" PLUG AT 10,630'. PULLED PRONG AND "S" PLUG. GAUGE RING RUN TO 10,737', OK. SRU 24-33 11,085' TD DAY 3 (3/30/93) RIGGED UP ELECTRIC LINE. PERFED 2-3/8" TUBING FROM 10,640'-10,635'. SET 2-3/8" CEMENT RETAINER AT 10,620'. RIGGED DOWN ELECTRIC LINE. SRU 24-33 11,085' TD DAY 4 (3/31/93) RIGGED UP 1-1/2" COILED TBG. TESTED BOPE TO 5000 PSI, OK. STABBED INTO THE 2-3/8" RETAINER AT 10,620'. SQZ'D 9 BBLS CEMENT BELOW THE RETAINER INTO THE HEMLOCK 'FORMATION. SRU 24-33 11,085' TD DAY 5 (4/01/93) RIGGED UP ELECTRIC LINE. PERFED TBG FROM 10,610'-10,615'. SET 2-3/8" (3MT RETAINER AT 10,580'. RIGGED UP COILED TBG. TESTED BOPE TO 5000 PSI, OK. STABBED INTO RETAINER AT 10,580'. PUMPED 12 BBLS CEMENT THROUGH THE RETAINER. EQUALIZED 2 BBLS ON TOP OF RETAINER. R/D COILED TBG. RIGGED UP ELECTRIC LINE. TAGGED CEMENT AT 10,124'. CUT 3-1/2" TBG AT 10,120'.CHANGED WELL OVER FROM 8.6 PPG TO 9.7 PPG BRINE. FINAL REPORT. Alaska Region Unocal North Americajr Oil & Gas Division [ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 ,...,......~ Telephone (907) 276-7600 COMM I_1 :RES ENG UNOCAL ) ·. SR ENG I I -__.NG ._.ASST I GEOL ASSTI ~.p?(,.-c._-~Z~ fo oz. ~TAT TE~H,~,__~___I March 24, 1993 ~,~: FILE Mr. Joseph A. Dygas Bureau of Land Management . Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 Re: 1993 Sundry Notice Request for TA Wells in ~wanson:,:River;:Fiel~. Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 31 wells in the Swanson River Field for a period of 12 months.. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Twenty-Ninth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1993 to March 31, 1994. These concurrent time periods will greatly simplify future TA Sundry Notice and Plan of Development and Operations preparation. Two information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells using the same format as submitted last year by ARCO. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses under field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Two wells, SCU 243-8 and SCU 21-8 were added to the list while three wells, SRU 21-22, SRU 12A-14 and SRU 211-15 were removed from the list. RECEIVED MAR 2 5 199,~ Alaska 0il & Gas Cons. C0mmissio~ Anchorage Mr. Joseph A. Dygas March 18 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. DLG:sr Yours very truly, Dennis L." Gfoboske Petroleum Engineer Attachment cc: L.C. Smith, Chairman, AOGCC L. R. Dartez, Marathon Oil Company RECEIVED MAR 2 § 1993 Alaska 0il & Gas Cons. Comrnissior~ Anchorage Form 3 i 60-5 (June 1990) UNITED STATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 3 i, 1993 5. Lease Designation and Serial No. 6. If Indian, Alioue~ or Tribe Name Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals SUBMIT IN TRIPLICATE i. Type of Well roil Gas Well ~] O Other Well 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone No. P. O. Box 196247, Anchorage, Alaska 99519 4. Location of Well (Footage, Sec., T., R., M., or Survey De~ription) Swanson River Unit - 17 wells Soldotna Creek Unit .......... 14 wells (907) 276-7600 12. TYPE OF SUBMISSION TYPE OF ACTION 7. If Unit or CA, Agreenu:nt D~ignation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Field and Pool, or Exploratory Ama Swanson River Field I I. County or Parish, State Kenai ~ Alaska CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA ~'~ Notice of Intent F-] Subsequent Report '-={Final Abandonment Notice O Abandonment O Recompletion '-]Plugging Back =-]Casing Repair [~] Omcr Temporari 1 y Abandon [~ Change of Plans O New Construction O Non-Routine Fracturing D Water Shut-Off O Conversion to Injection =-]Dispose Water (Note: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 13. Describe Proposed or Compicted Operations (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.}* As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1, 1993 to March 31, 1994' Swanson River Unit / 21-8*/ SCU 21-3 ~ SCU SRU 212-10 SCU 23B-3'. SCU 243-8~ SRU 14-15' SCU 13-4 ~ SCU 341-8" SRU 23-15/ SCU 21A-4 SCU 13-9/ SRU 34-15 SCU 34-4 ~ 43A_4Y SCU 24A-9 SRU 41A-15w SCU SCU 34-9**' SRU 43A-15 SCU 33-5v SCU 14-34u' SRU 432-15 SRU 14-22~ SwanSon River Unit SRU 23-22~ SRU 23-27 ~ SRU 212-27~ SRU 331-27 SRU 34-28 v SRU 43-28 v SRU 32-33WD ~' * High GOR wells that may be produced intermittently. sig.~ /,V~/x,~ ;,y',~~0~.-- zi,,e Petroleum Engineer RECEIVED Alaska 0ii & Gas Cons. Anchorags Approved by Title. Date Conditions of approval, if any: Fide 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 x ~sas manx manor wiO~in ~ jurisdiction. *See Instruction on Rmmme Side Attachment No. 1 Swanson River Field ProPosed Temporarily Abandoned Wells: Total 31 Wells Twelve Month Period: April 1, 1993 to March 31, 1994 Shut-in Wells under Evaluation for Rate Potential P & A Shallow Gas Potential and 'Hemlock Only' P & A Shut-in Wells until the Field Blowdown Hemlock Future Shallow Gas Producer Producers with the Hemlock Abandoned SCU 13-4 SCU 21A-4 SCU 34-4 SCU 43A-4 SCU 33-5 SRU 341-8 SRU 34-28 SRU 43-28 SCU 32-33WD SCU 243-8 SCU 21-3 SRU 212-10 SRU 23-15 SRU 41A-15 SRU 14-22 SRU 23-22 SRU 212-27 SRU 331-27 SCU 14-34 SRU 23-27 SRU 14A-33 11 Wells 7 Wells 3 Wells 5 Wells SCU 21-8' SCU 13-9 SCU 24A-9 SCU 34-9' SCU 23B-3' SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 SRU 24-33~2~ 5 Wells Does not include SRU 211-15. Scheduled full P & A in March-April, 1993 Scheduled 'Hemlock Only' P & A in March-April, 1993. High GOR wells that may be produced intermittently. RECEIVED AlaSka Oil.& Gas Cons. Commission Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1.992's TA Status -December 27, 1991) Additions to 1993 Temporarily Abandoned Status · SCU 243-8: · SCU 21-3: Shallow gas producer (Tyonek). Shut-in due to mechanical problems. Workover candidate. Shut-in due to current high GOR. Mechanical problems. Removed from 1993 Tempo.rarily Abandoned Status · SRU 21-22: · SRU 12A-4: · 'SRU 211-15 Returned to production after flowline repair. Returned to full time production in 1992. Scheduled for full P & A March-April, 1993. Waiting on personnel and rig. RECEIVED MAR ~ 5 t99;5 Alaska 0il & Gas Cons. (~on~m~ssio~ Anchorage ARCO Alaska, Inc.if~,' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 8, 1992 Commissioner Leigh Grimm Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99510 SR~/::~IG jJ~ SR ENG iENG ASST I ENG ASST I SR GEOL I { GEOL ASSTI !GEOL ASSTI STAT TECHI STAT TE~ FILE Re: Transfer of Pending Sundry Applications to New Operator Dear Commissioner Leigh Griffin, With the transition of operatorship of the Swanson River Field and the King Salmon Platform from ARCO Alaska, Inc. to Unocal we are passing onto Unocal the existing work files of several projects that have Sundry Applications approved by your office. The following approved Sundries are being transferred: SRU 43-28 SRU 331-27 SRU 211-15 SRU 24-33 Convert Well to Water Injection. Convert Well to Water Injection. Plug and Abandonment Hemlock Only Abandonment Unocal, as operator, is assuming the responsibility of carrying out the work as approved by your office or canceling the existing Sundry Application and re-submitting revised work plans. In addition to the above there are pending operations on the King Salmon Platform that Unocal will carry out when they assume operatorship. This includes the 'No Flow Testing' on K-5, It-10rd, K-24 and K21rdS, and an MIT that is due on K-15. This work is currently scheduled to be completed when an inspector from your office is available to witness the testing. If you should have any questions concerning any of this work please do not hesitate to contact me at 263-4304 or you can contact Mr. Martin Morell with Unocal at 263-7805. Sincerely, Tom Wellman Transition Manager, Cook Inlet Engineering cc: Martin Morell Unocal ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED DEC - 9 '1992 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 ORIGI, August 28, 1992 Leigh Griffin State of Alaska Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, AK 99501 ?'7 Dear Mrs. Griffin: Subject' SRU 24-33 Hemlock Plug and Abandonment Attached is a Sundry Notice requesting approval to plug and abandon the Hemlock formation in Swanson River Unit Well 24-33. As the potential for shallow hydrocarbon production exists in SRU 24-33, the well will be secured for possible remedial work by circulating 9.7 ppg brine in the wellbore If I can provide additional information concerning the above mentioned procedure, please feel free to call me at 263-4243. Sincerely .,, .~ Steve Bradley Drilling Engineer CC. A. W. McBride File RECEIVED AU G 2 $1992 Alaska Oil & Gas Cons. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION . APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well _ Change approved program m Operation Shutdown _ Re-enter suspended well_ Plugging ~ Time extension _ Stimulate __ Abandon Pull tubing _ Variance _ Perforate Other _~_ Hemlock 2. Name of Operator ARCO Alaska, loc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 932' S & 2089' E of NW corner, Sec. 4, T7N, RDW, SB&M At top of productive interval 675' N & 2298' E of SW corner, Sec. 33, T8N, RDW, SB&M At effective depth 509' N & 2339' E of SW corner, Sec. 33, T8N, RDW, SB&M At total depth 271' N & 2399' E of SW corner, Sec. 33, T8N, RDW, SB&M 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 11,088' feet 1 0,845' feet 10,821' feet 1 0,599' feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) 20.0' KD 7. Unit or Property name Swanson River Unit leet 8. Well number SRU 24-33 9. Permit number 10. APl number 50-133-20237-00 11. Field/Pool Swanson River Field Hemlock ~:~lil ~'(~ I" ! ~ t ~ ~'~ ~\LL.E! V r'[J AU G 2 $1992 Alaska 0il & Gas Coils. ~,ummissi°n Anchora Length Size Cemented Measured depth True ~le~rtical depth 266' 20" Yes 266' 266' 3408' 1 0-3/4" Yes 3408' 3408' 1 0635' 7-5/8" Yes 1 0635' 1 031 0' 651 ' 5- 1/2" Yes 11 085' 1 0483' Perforation depth' measured 10,862'-10,832' (squeezed); 10,794'-10,770'; 10,762'-10,740'; 10,735'-10,721 '; 10,711 '-10,704'; 10,696'-10,676'; 10,660'-10,644' true vertical 10,641'-10,612' (squeezed); 10,574'-10,551'; 10,543'-10,522'; 10,517'-10,503'; 10,493'-10,4486'; 10,478'-10,459'; 10,443'-10,427' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 0'-10,275'; 2-3/8" 4.6# EUE 8rd 10,275'-10,574' Packers and SSSV (type and measured depth) . Baker model 'FH' Pkr @ 10,624' 13. Attachments Description summary of proposal X Wellbore Schematics, Well Histor7, Area Map 14. Estimated date for commencing operation September 7,1992 16. If proposal was verbally approved Name of approver Date approved Detailed operation program BOP sketch 15. Status of well classification as: Oil Gas Suspended X Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //~ ~,-(.J ~? ~-~i~ ~' Title Area Drillinc~ Encjineer / - FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness ,~pproved C~fl~roval No. Plug integrity /[,_ BOP Test_ Location clearance m Returnedl Mechanical Integrity Test_ Subsequent form require 10-_~L_ Origlnal Signed By f David W. Johnston .Approved by the order of the Commission Commissioner Date /~i / Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE . 3. . . . . . . 10. 11. 12. 13. 14. SRU 24-33 ~r~ GENERAL P&A PROCEDURE Confirm status of GLM @ 1983', 3612', 4961', 5028', 6728', 7234', 7557', dummy as required. Pull plug in S nipple @ 10,630'. Tag fill/bail to at least 10,660'. Make gauge ring run to 10,660'. R/U wireline and perforate 5' of tubing w/4 spf @ 10,635' - 10,640'. Wireline set a 2-3/8" cement retainer (#1) @ 10,620'. RIH w/CTU and sting into retainer. Squeeze 45 sx (9 bbl) of cement below retainer. POOH above retainer and flush CTU. R/U wireline and perforate 5' of tubing w/4 spf @ 10,615'- 10,610'. Wireline set a 2-3/8" cement retainer (#2) @ 10,580'. RIH w/CTU and sting into retainer. Open the 3-1/2" x 7-5/8" annular valve. Pump 60 sx (12 bbl) of cement into 2-3/8" x 5-1/2" and 2-3/8" x 7-5/8" annulus. Top of cement to extend 200' above the top of the 5-1/2" liner lap @ 10,434' (TOC +/-10,200'). Close 2-3/8" x 7-5/8" annular valve. Spot a cementplug of approx 10 sx (2 bbl) above the 2-3/8" retainer. (TOC +/- 10,200'). POOH to above TOC and flush CTU. POOH. R/D CTU. RIH w/wireline and tag cement. Cut tubing @ 10,150'. POOH. R/D wireline. Circulate well w/kill weight brine. Secure the well. Clean and clear' location. REC£1VF-D AU G 2 $1992 Alaska 0il & Gas Cons. Com~'lss'tou Anchorage 20"@ 337' 10-3/4' @ 3408' ~ 5-1/2" LINER @ 10434' 7-5/8" @ 10635' LINER PERFORATIONS 10644'-10660' 1'0676'-1 0696' 10704'-10711' 10721'-10735' 2-3/8" 4.6# @ 10754' LINER PERFORATIONS 10740'-10762' 10770'-10794' 5-1/2" 23# @ L Current Well Status _S R U_.._24-___33_ NOTE: All depths are KB reference. Original GL-KB is 20 ft. ~ FILL 983' CAMCO MM MANDREL 3612' CAMCO MM MANDREL 4961' CAMCO MM MANDREL 5028' CAMCO MM MANDREL 6728' CAMCO MM MANDREL 7234' CAMCO MM MANDREL 7557' CAMCO MM MANDREL 10276' 3-1/2" x 2-3/8" CROSSOVER 10590' XA SLEEVE (OPEN) 0624' PACKER 10630' S NIPPLE PLUG 10733' D NIPPLE RECEIVE 10738' FILL ,AUG 2~ 1992 ~[a8~ ~Jl & Gas Cons. IJommission 10763' TOP OF FISH ' Anchorage 10765' PACKER 10821' PBTD ARCO Alaska Inc. HTE 6/26/92 20"@ 337' 10-3/4' @ 3408' TUBING CUT ~ 10150' EST TOC 10200' 5-1/2" LINER @ 10434' 7-5/8" @ 10635' 9.7 PPG BRINE NOTE' All depths are KB reference. Original GL-KB is 20 ft. ~ P&A CEMENT I FILL 983' CAMCO MM MANDREL 3612' CAMCO MM MANDREL 4961' CAMCO MM MANDREL 5028' CAMCO MM MANDREL 6728' CAMCO MM MANDREL 7234' CAMCO MM MANDREL 7557' CAMCO MM MANDREL 10276' 3-1/2" x 2-3/8" CROSSOVER CEMENT RETAINER @10580' 10590' XA SLEEVE TUBING PERFORATIONS 10610'-10615' CEMENT RETAINER @10620' 10624' PACKER 10630' S NIPPLE LINER PERFORATIONS 10644'-10660' 10676'-10696' 10704'-1071 1' 10721'-10735' 2-3/8" 4.6# @ 10754' LINER PERFORATIONS 10740'-10762' 10770'-10794' /2" 23# @ 11085' TUBING PERFORATIONS 10635'-10640' 10733' D NIPPLE 10738' FILL 10763' TOP OF FISH 10765' PACKER AUG 2 $1992 D. JJ & Gas Cons. ~ummissio~ Anchorage 10821' PBTD ARCO Alaska Inc. HTE 6/16/92 This well is a SI producer. This well has been SI since 1983 because of high (}OR. The well was tested on 9/89, but produced no off. A plug is ~ 10,611' WLM. The fill is ~ 10,363' MD as of 10/89 and it is on the 12/91 T&A list. 12/72: 3/75: 10/75: 1983: 7/83: 9/89: 9/89: 12/89: 1/90: Completed the H1 through H5 Sands; the H8 Sand tested wet and was squeezed. Lost wireline fish and 10,000' of wire {produced around the fish). Worked over, but left 29' of tubing fish in the well. The well died after the workover because of sand and rocks. Resumed production. ~ cleanout. SI the well because of high GOR. C1~ cleanout 5563'-5568' MD (a sand bridge was cleaned) and 10,500'-10,768' MD. Perforated the HI (10,645'-10,665' MD), H2 {10,680'- 10,690' MD), and H5 (10,740'-10,750' MD) Sands. Bailed the fill 10,357'-10,738' and tested the gas with solids production. Set a plug at 10,611' WLM. Circulated the wellbore with a 9.2# brine. Unit Boundary SRU 24-88 I I I I I I · ~ C~ ~ ! Fault BIO~' ! I I I' RECEIVED G 2 8 1992 Gas Cons. L;omlniss'iou ~.nchorag~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engine~tng December 27, 1991 ~OMM Mr. J. A. Dygas Chief Branch of Lease Operations (AK-984) Bureau of Land Management 222 West 7th Avenue Post Office .,Box 13 Anchorage, AK 99513-7599 Subject: 1992 Sundry_ Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas:' Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 32 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with Chapter II, Section 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. All 32 wells are expected 'to be shut-in for a period of at least 30 days during 1992. Several information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells and separates them into the following five categories: Shut-in wells under evaluation for: . rate potential, permanent abandonment (P & A), and shallow gas sand potential and 'Hemlock Only abandonment. RECEIVED DEC 1 199t Alaska Oil & Gas Cons. Commi~ion Anchorage Mr. J. A. Dygas Page 2 December 27, 1991 Shut-in wells until field blowdown, including: 4. Hemlock producers, and 5. wells with future shallow gas potential in. which the Hemlock has been abandoned. The fifth category shown above is a new addition to this year's TA listing. This grouping is for the wells in which the Hemlock has been abandoned but the wellbore is being maintained for possible future shallow gas production. Four wells from last ye,ar's TA list were moved into this category. Attachment 2 gives a brief explanation for each well that has been added to or removed from the 1991 Temporarily Abandoned List (Ref: our letter of 12/28/90). Eight wells, SCU 12A-4, SCU 21-8, SCU 23B-3, SCU 43A-4, SCU 13-9, SRU 212-10, SRU 21-22 and SRU 212-27, have been added while two wells, SRU 21-15 and SRU 314-27, have been removed from the previous TA List. Attachment 3 is a list of shut-in wells that are not included in the '92 TA listing. Two of the wells mentioned above, SRU 21-15 and SRU 314-27, are not included because they are scheduled for P & A in the first quarter of 1992. This work is being done as part of the '91-'92 Swanson River Plan of Development. Also included in Attachment 3 is SCU 43-4WD, a standby water disposal well which is only used seasonally. If you have any questions concerning this Sundry Notice request, please call Hyeh- Yeon Hoffer at 265-1355 or Jim Zernell at 263-4.107. Sincerely, J. c. Winn Acting Regional Engineer JTZ:jlg:0025 Attachment C~ L. C. Smith, Chairman AOGCC A. R. Kukla, Marathon Oil Company B. C. Dehn, UNOCAL Corporation R£C X/[D Alas~ Oit & ~as Cons. Com.~'lss'tor~ Anchorage 16. ield · ~ 21A~ ~ 2~ S~g 211-15 S~U 331-27 ~ ~ ~ ~9 SKU 41A45 SKU 5[U 432-15 SKU 1~'33 ~ ~5 sKU RECEIVED DEC 3 1 1991 Alaska Oil & Gas Cons. Commit Attachment 1 Swanson River Field Proposed Temporarily Abandon Wells: Total 32 Wells Shut-in Wells under Evaluation for Shallow Gas Potential Rate Potential P & A and 'Hemlock Only' P & A Shut-in Wells until the Field Blowdown Future Shallow Gas Producer HemlOck Producers with the Hemlock Abandoned i:i~:i:!:~:i~:i:~:i:i.<.:i:i:~:i:i:i:i:i:~i:i:i:i:i:i:i:i:i:i:i:~::;~:i:i:i:i:i:i:~:i:i:!:i:i:i:i::;i:!~::;:;i:i~:i:i:~`.....:~:i:i:i:i:i:i:i:i:i:i:i:i~:i:!:i:i:i~:!:i~:i:i:i:i:i:i:!:i:i:;;:;!:i:~i:i:i:i:i:i:i:i::;i~:i:;;i:i:!:i:i:i:i:~i:i:i:i:i:i:i:~:i:::::~::i:i:i:i:i::;~i SCU 12A-4 SRU 212-10 SCU 13-4 SRU 211-15 SCU 21A-4 SRU 23-15 SCU 34-4 SRU 4lA-15 SCU 43A-4 SRU 14-22 SCU 33-5 SRU 23-22 SCU 341-8 SRU 212-27 SRU 21-22 SRU 331-27 SRU 34-28 SRU 24-33 SRU 43-28 SRU 32-33WD c) c'~ r'r'l SCU 14-34 SRU 23-27 SRU 14A-33 11 Wells 9 Wel§. 3 Wells SCU 21-8 * SCU 13-9 SCU 24A-9 ' SCU 34-9 SCU 23B-3 * SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 5 Wells · 4 Wells * -High GOR wells that may be produced intermittently. For:. Temporarily Abandonment Sundry 12/27/91. Attachment 2 RECEIVED Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1991's TA Status; our letter 12/28/90) /llaska Oil & 6as Cons. Commissi Anchorage Added to 1992 Temporarily Abandoned Status: · SCU 23B-3 & · SCU 21-8: · SCU 12A-4: High GOR wells, maybe produced intermittently, otherwise shut-in until blowdown. High GOR well, may be produce intermittently, This well is also being considered as a workover candidate. · SCU 43A-4: Shut-in due to mechanical problems. AlsO being considered as a workover candidate for shallow gas. · SCU 13-9: High GOR well, shut-in until field blowdown. · SRU 212-10 & · SRU 212-27: High water rate shallow fuel gas well, currently not economic to produce based on current fuel gas needs. · SRU 21-22: Well currently shut-in due to problems with the flowline. Well will be returned to production when repairs have been completed. Removed from 1991 Temporarily Abandoned Status · SRU 21-15 & · SRU 314-27: Wells are .scheduled for full P & A in 1st Quarter 1992 as part of the '91-'92 SRF Plan of Development. Note: 'Hemlock Only' abandonments were performed on SRU .14-15, SRU 34-15, SRU 43A-15 and SRU 432-15. These wellbores are being maintained for their future shallow gas potential and remain on the TA List for 1992. Attachment 3 Swanson River Field Shut-in Wells not on the 1992 TA Status List Wells with planned upcoming work: · SRU' 21-15 & · -SRU 314-27: Wells are scheduled for P & A in first quarter 1992. Wells that are used seasonally · SCU 43-4WD: This water/mud disposal well is a standby well and is only used on an 'as needed' basis. RECEIVED DEC ~ 1 199! Alaska Oil & Gas Cons. uommissios, Anchoraoe ARCO Alaska, Inc.j~.~' Post Qff;ce B~x !00~,.30 A,~chorage. -' ias~,a 995 '-,.0-0360 December 29, 1989 Mr. J. A. Dygas, Branch Chief Division of Minerals Bureau of Land Management 6881 Abbott Loop Road Anchorage, Alaska 99507 COMM RES SR ENG SR =. ,x, r-_ t Dear Mr. Dygas: Attached is a Sundry Notice requesting approval to temporarily abandon 31 wells in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.3-4, paragraph C of the Bureau of Land Management Regulations. All 31 wells are expected to be shut-in for a period of at least 30 days. The wells are separated into four categories: 1. Under evaluation for rate potential. 2. Under evaluation for P&A or future utility. 3. Inefficient producers. 4. Shut-in until blowdown. Several other items have been attached for your information. Brief explanations are given for each well that has been added or deleted from the temporarily abandoned status (Ref: your letters of 3/1/89 (3160 (984)) and 3/30/89 (3180 (984)) and our letter 12/28/88). In addition, a list of currently shut-in wells which have planned upcoming work that will enable their return to production is attached. If you have any questions concerning this Sundry Notice request, please call Stacy Strickland at 263-4914. Sincerely, Tom Wellman TW:SLS:jt:0016 Attachment cc: -:.C.V. Chatterton, Chairman AOGCC A. R. Kulda, Marathon Oil Company S.W. Ohnimus, UNOCAL Corporation RECEIVED DEC291 I9 Alaska 0il & Gas Cons, Commlssic Anchorage · , Fom~ 3160--S (Nov~mi~P 1983) (Formerly 9--331) , rED STATES DEPARTMENT OF THE INTERIOR ,,--ak) - "' BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not ~ ~ ~of'm tot pro~ta to drill or to dee~ eL* pl~( brock to e dlffiPllt ~r~oir. Um **AJ~PIJCATION FOR PERMFT--" for susa Brolmm~) o.. []- GAO ~] ARCO Alaska, Inc. 3. ADDB, SI8 Of Post Offfce Box 100360 Anchroage, AK 99510 4. I. OC&TIO~ Of WaLL (Re~rt lo. tiaa ctetrll iud tn &ccordin~ with 8Ay S~ iI~ i~ 1~ ~ow.) Soldotna Creek Unit - 11 wells Swanson River Unit - 20 wells 14. PII, M IT jtS. It,BV&~ONS (SM whether of, rt. Form apprQved. 13ud~et Bureau No. tOO4--O13S l~xQtre~, &u~131t 31. tg~S La&BI GG~IGm&'ZlOI &a~ ~ ?. I~lll~ &GB. RmMBiI? N&MI ~Owaldotna-greek/ risen N~ver Units 10. FLILO iHO 14N)L, O! WIL0CiT l:J. ~T ~ flazllJ IL. ITA'gl KenaiI ^laska 16. Box To Indicate Nature of Notice, Rem)fi, or Other Dam IUIII~(JBIrT ~ Q~: ' CHAHGB PLA,n8 REPAII WILL ( 0the~ W~~ (Other) TemDorar i ! y abandon ~: b~fl-~ ~ m~ emCOn om , t'omoletlon or lmm~euon ~fl tn~ [~ ~. UhSCRI~E PROPOSED OB COS/PitTED OPERATIO~ (Clearly state all ~rttnPnC details, end :tva ~rttnenC ~t~ Jn~lud.~_m~at~ ~i~ of_l~ ~t ;ro~=~ worL If w~ b dietary dhfl~ give ~~ ~uns ~fld melltlr~ ~nd t~e vertt~ ~p~ r~ ~ marse~ ~d mum ~. nen~ ,~ ~ia ~rL) · As described in thc attached memo, ARCO Alaska, Inc. requests' that the following wells have a temporarily abandoned status: Soldotna Creek Unit Swanson River Unit SCU 13-3 SCU 13-4 SCU 21A-4 SCU 34-4 SCU 24-5 SCU 33-5 SCU 33-8 SCU 341-8 SCU 34-9 SCU 3 lA-16 SCU 14-34 SRU 34-10 SRU 23-22 SRU 14-15 SRU 312-22 SRU 21-15 SRU 23-27 SRU 211-15 SRU 314-27 SRU 331-27 SRU 31-15 SRU 34-28 SRU 34-15 SRU 43-28 SRU 41A-15 SRU 14A-33 SRU 43A-15 SRU 24-33 SRU 32-33WD SRU 432-15 SRU 12-34 RECEIVEE, Alaska Oil & Gas Cons. C0mmi~ Anchorage 18. t bere0y cer~y tJzat the Eore~oLaf La r~te &nd correct Cook Inlet Enginerring ManagH~l (3?his space for lrederai or Stzto o~e~ ufo) APPROVED BY ¢OZqDITIONS OIP APPROVAL. Lf AA~r: *See Inmvctiom on R~v~w Si~ Title IS U.S.C. Section 1001, makes tt a crime for any person knowingly and willfully to make to any department or agency of the Untied States any false, ~£ctzttous or fraudulent statements or represeflta/.Lona aa to any matter wtthtn tls jurisdiction. TEMPORARILY ABANDONED WELLS IN SRF Wells under Evaluation Rate Poten[i,_a! Wells being Wells SI Wells SI evaluated for for Inefficient until P&A/Future Utility Production Blowdown 13-4 34-4 24-5 33-8 341-8 34-9 41A-15 23-22 23-27 13-3 14-15 21-15 211-15 31-15 34-15 432-15 31A-16 312-22 34-28 14A-33 32-33WD 12-34 14-34 21 A-4 33-5 34-10 43-28 24-33 43A-15 314-27 331-27 For: Temporarily Abandonment of 12/29/89 SWANSON RIVER FIELD Wells having Changed Temporarily Abandoned Status Added to Temoorarilv Abandoned Status: -- - SCU 21A-4: Well is temporarily abandoned due to inefficient production (high GOR). SRU 32-33 W D' Well is temporarily abandoned due to annulus communication problems. R¢lpoved from Temporarily Abandoned Status: $CU 243-8' This shallow sands gas well has been returned production. $CU 13-9' A workover is planned for this well which will enable this well to be returned to an active status. SRU 212-10: This shallow sands gas well has been returned to production. SRU 23-15: This gas-lifted well has been returned to production. SRU 21-3o,: A sidetrack is planned which will enable this well to be returned to an active status. 'RECEIVED D C2 1989 Alaska Oil & Gas Cons. Commissiol~ Anchorage For: Temporary Abandonment Sundry of 12/29/89 SWANSON RIVER FIELD WELL STATUS UPDATE Shut-in Wells with Planned Upcoming Work* SCU 32A-9: When on-line, this SI well produces gravel. A sidetrack is planned to return this well to active status. *Will not be placed on temporarily abandoned ,ta, CEIVED For: Temporary Abandonment Sundry of 12/29/89 ARCO Alaska, Inc.[~, Post Office BOx 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures ORIGIN . August 10, 1989 Mr. C. V. Chatterton, Chairman/ Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Well SRU 24-33 Dear Mr. Chatterton: Attached is an Application for Sundry Approval to perforate the tubing tail in Well SRU 24-33. We propose to perforate the tubing in the intervals from 10,645'-655' (H1), 10,680'-690' (I-I2) and 10,740'-750' (H5) with I 11/16" hollow carrier guns at 4 JSPF. 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. Sincerely, T. S. McCorkle TSM:DML:ch:0004 Attachment CC' S. W. Ohnimus A. R. Kukla UNOCAL Corporation Marathon Oil Company RECEIVED AIaska Oil & Gas Cons, Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6279 A(' ~' STATE OF ALASKA ..,,,A OIL AND GAS cONSERVATION COMIC. .)N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate ~ Other __ 2. Name of Operator 5. Type of Well: ARCO Alaska, I nc. Development X Exploratory __ 3. Address Stratigraphic_ P. O. Box 100360 Anchorage, AK 99510 Service__ 4. Location of well at surface 932' S & 2089' E of NW corner, Sec. 4, T7N, Rgw, SB&M At top of productive interval (SCU 21-4 pad ) 675' N & 2298' E of SW corner, Sec. 33, T8N, R9W, SB&M At effective depth 509' N & 2339' E of SW corner, Sec. 33, T8N, R9W SB&M At total depth 271' N & 2399' E of SW corner, Sec. 33, T8N, Rgw, SB&M 6. Datum elevation (DF or KB) 164.6' GL, 177.1' KB feet 7. Unit or Property name Swanson River Unit 8. Well number SRU 24-33 9. Permit number 10. APl number 50-- 133-20-237 11. Field/Pool Swanson R i ver-Hem Iock 12. Present well condition summary Total depth: measured true vertical 11,088 feet Plugs(measured) 10,845 feet Top of plug ~ 10,808' Effective depth: measured true vertical Casing Conductor Surface Intermediate Production Perforation depth: 10,821 feet Junk (measured) 10,599 feet Length Size Cemented Measured depth 20" H-40 94# To surface , 10-3/4",K-55,40.5~ To surface 7-5/8" P-IlO&N-80 33.7#,~9.7#,&26.4~ 651' 5-1/2" N-80 23~ To 10,434' 11,085' , , 266' 3408' 10,635' measured 10 True vertical depth 266' 266' 3408' 3408' 10,635' 10,310' 10,735-10,721'; 10,711- truevertical10,641-10,612'; 10,574-10,551'; 10,493-10,486'; 10,478-10,459'; 10,443-10,427' ~bing(size, grade, and measureddepth) 3-1/2", 9.3#, N-80, 10,371'; 2-3/8", 4.6~, 10,754' PackersandSSSV(typeand measuredde~h) Brown DBAL~paCker @ 10,765'. Baker FN @ 10,630' 13.~achmen~ Descri~ionsummaryofproposal__ D~ailedoper~ionsprogram,~c.. 10,843' ,862-10,832' squeezed; 10,794-10,770'; 10,762-10,740'; 10,704'; 10,696-10,676'; '10,660-10,644' 10,543-10,522'; 10,517-10,503'; BOP sketch X__ 14. Estimated date for commencing operation 115. Status of well classification as: August, 1989 16. If proposal was verbally approved Oil X Gas ~ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~,~. ~ Title Cook Inlet Engineer lng Manager Date ~.~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- /--I O~ Original Signed By Approved by order of the Commissioner David W. Johnston Suspended ~¢~ i 1~4 '~0~0 -- ~.¢~ [ ~i'.+ ~,~u;** .... '.~k~. O~J & Oas Con I.Approval No. /kt3pro'veCt Oo~3'Y Retur~e~ Commissioner Date Anchorage FOrm 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Tubing Perforation Procedure SRU 24-33 . 2. 3. 4. . . RU slickline and pressure test lubricator. RIH with 1.75" gauge ring and tag PBTD. RD slickline. RU E-line unit and pressure test lubricator. RIH with 1-11/16" hollow steel carrier perforating guns (4 JSPF), weight bars, and CCL. Tie in to robing tally. Perforate the tubing from 10,740'-750' (HS), 10,680'-690' (H2), and 10,645'-655' (HI). RD E-line. Install Willis Rotary choke with loads ranging from 12/64" to 24/64". Return well to production slowly. Watch produced fluid samples closely for sand production. Anchora.o,e E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension L Manual Rams Swab Valve Double Master Valves Wellhead DML 7/22/88 ..¢--4' STATE Of ALASKA ''~[. ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL F-I COMPLETED WELL~i~r, OTHER I--I 2. Name of Operator 7. Permit No. Chevron U. S.A. Inc. 3. Address 8. APl Number P. O. Box 107839, Anchorage, Alaska 99510 50-133-20-237 4. Location of Well 932' S. and 2089' E. of N.W. Corner of Section 4, T7N, R9W, Seward B&M. 5. Elevation in feet (indicate KB, DF, etc.) 177' K.B. 12. I 6. Lease Designation and Serial No. A'028399 9. Unit or Lease Name Swanson River 10. Well Number * SRU 24-33 11. Field and Pool Swanson River Field Hemlock Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing []" Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On 12/1/82, SRU 2.4-33's production tubing was cleaned out.to a depth of 10,384' using 1" coiled tubing with a ijet nozzle end and circulating with crude. On 12/15/83, 1" coiled tubing with a 1 3/4" dyna-drill and a 1 3/4" mill was run in~ hole and the production tubing was cleaned out from 10,384' to 10,770'. The well was placed back on production. 14. I hereby certify/t~t the fo~go~to the best of my knowledge. Signed~o.~r--~, Title Area F. ng±neer The space below for Commission use Date Conditions of Approval, if any: Approved by COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" irt Duplicate STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION C ,IISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER E3 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 3. Address 8. APl Number P. O. Box 107839, Anchorage, Alaska 99510 50-133-20-237 4. Location of Well 932' S. and 2089' E. of N.W. Corner of Section 4, T7N, R9W, Seward B&M. 5. Elevation in feet (indicate KB, DF, etc.) 177' K.B. 6. Lease Designation and Serial No. A-028399 12. 9. Unit or Lease Name Swanson River 10. Well Number SRO 24-33 11. Field and Pool Swanson River Field Hemlock Pool Check AppropriateBoxTolndicate NatureofNotice, Report, orOtherData NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] ~. Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated'date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On 12/1/82, SRU 24-33's production tubing was cleaned out. to a depth of 10,384' using 1" coiled tubing with a ijet nozzle end and circulating with crude. On 12/15/83, 1" coiled tubing with a 1 3/4" dyna-drill and a 1 3/4" mill was run in hole and the production tubing was cleaned out from 10,384' to 10,770'. The well was placed back on production. 14. I hereby certify/t~t the f~r go__to the best of my knowledge. SignedK'~--~- Title Area Enqineer The space below for Commission use Date /'i Conditions of Approval, if any: Approved by. COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 'DEPT..' PLACE: FD- Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. . RECEIVED BY REMARKS ON OTHER SLOE, THIS CttEVRON U.S.A. INC. BOX 7-839 ANCHORAGE, ALASKA 99510 February 16, 1983 Chevron U.S.A. Inc. P.O. Box 7-839 Anchorage, Alaska 99510 Re~. Subsequent Reports, SundrY Notices and Reports on Wells (Form 10-403) For the following lists of "~otice of Intention To~' Sundry }k)tices and Report on Wells (form 10-403) this office does not have on record the 'Subsequent Report of~" defining the action taken on the approved intention. Please advise this office by Subsequent Report of the disposition of the intention. Well ..Chevron Da~9 Brief.. Du..s..cription of Intention Jeanette Is. 1 SRU 23-27 SRU 24-33 SCU 21-4A SCU 13-34 SCU 14-34 SCU 21-9 1/13 / 82 5/7/82 5/7/~2 8/3/82 8/5/82 8/5/82 Brier description Clean out scale plug Clean out scale plug ReperfOrate Isolate leak in H-"3-4" interva Return }il and H2 to production Clean out fill 'in tub!.ng Sin~cerely, : .:/ ' ,,.. I ",' ~ .... '-": /'.,.:' ..... Commissioner LCS/JKT/g lh STATE OF ALASKA ALASK ,LAND GAS CONSERVATION C ~IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 3. Address 8. APl Number P. O. Box 7-839, Anchorage, AK 99510 50-133-20-237 4. Location of Well 932' S. and 2089' E. of the N.W. corner of Section 4, T7N, R9W, Seward B&M. 5. Elevation i0 feet (indicate KB, DF, etc.) 177' K.B. 6. Lease DesiGnation and Serial No. A-028399 9. Unit or Lease Name Swanson River 10. Well Number SRU 24-33 11. Field and Pool Swanson River Field Hemlock Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: , SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Clean out sand and rocks from tubing to ~10,794~ using a coil tubing unit. Nas~ Oil & Gas Cons. Commission ~.uchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title ~ ~lJ~~ The spa~e b~ow for Comm,~:)n use Conditi~of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions'' in Triplicate and "Subsequent Reports" in Duplicate TILANSMITTAL AN!:}, ACItNOWI,EDGI,iMENT OF RECEIPT OF }!.5,,TI_!J!JAI__~- (ALASIIA) TO: DEPT.: Mr, T. R. Marshall State o1' Alaska DDislon of OI! & Gas 3001 Porcupine Drive PLACE: Anchorage, Alaska 99504 FD - Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF ~,hiTERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE Ib~IEDIATELY. COMPANY WELL RECEIVED BY REMARKS N OTHER SIDE, THIS SI-IE'IE'T l~,rm ~To. P--4 I~'V. 3-1-70 STATE OF~' ,'o, LASKA OIL AND GAS CONSERVATION COMMI'I-I'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WKLL OTHER SUBMIT IN DUPL1CAT~ NAME OF OP]~,ATOR Standard Oil Co. of California, WOI 3. ADDRESS OF OPERATOR P. O. Box 7-839, Anchorage, Alaska 99510 4 LOCATION OF WELL Surface: 932' South and 2089' East of NW corner of Sec.4 T7N, R9W, SB&M (Well SCU 21-4 pad) BHL: 271' North and 2399' East of SlI~ corner of Sec.33 T8N, R9W, SB&M 5 AP1 NUQ,.iERICAL CODE 50-133-20237 _ .~NG Swanson River 9 WELL NO Sec. 33, T8N, R9W, SB&M 12. PEP-MIT NO 72-7 13. REPORT TOTAL DEPTH AT END OF MONTH. CH~NGF~ IN HOLE SIZE. CASING AND CL'MF_~NTING JOBS INCLUDING DEPTH SET ~ VOLErNrES USED pF~.FORATIONS. ~'ESTS A_N-D RESUL3~S FISHING JO~ JLq~K [N HOI~E AND SIDE-TI~ACKED HOLE AI~D ANY O~EER SIGNIFICANT CH. ANGES IN HOLE CONDITIONS 12/1 12/2-3 12/4 DECEMBER, 1972 Ran DIL log from 11,073' to 10,622';Borehole Compensated Sonic log from 11,076'-10,620' and Compensated Neutron Log from 11,076'.-10,400 '. Hung 5½", 23#, N-80 liner at 11,085' with top at 10,434'. Cemented liner with 56 sacks class G cement with 3/4% CFR-2. CIP 10:35A.M. 12-3-72. Ran Cement Bond Log from 11,022' to 10,422' and Gamma Ray Neutron log from 11,035' to 10,040'. Pressure tested 7-5/8" casing, liner lap and 5%" liner to 2650 pSi for 10 minutes -.ok. Perforated from 1Q,832' 'to 10,862' with 4-%" holes per foot. 12/5 Ran Formation. Test #1 on interval 10~',~"~'2'-10~'~'~'~ ..... 'Set packer at 10,775'. Used '1150 psi gas cushion. Opened tool at 12:25P.M. for 3 hr. 52 min. flow period. Closed tool for a 4 hr. final SI period. Backscuttled 9854' rise. Recovered 69 bbls. of water testing 775-875 gpg NaC1 with scum of oil. IH 5804 psi, IF 1456 psi, FF 4421-psi, FSI 4470 psi, FH 5804 psi. 12/6 Set retainer at 10,826' . Squeezed perforations from 10,832'-10,862' through retainer. Broke down formation with 5800 psi. Pumped 100 sacks Class "G' cement with 3/4% CFR-2. Displaced. with 436 cu. ft.. mud and squeezed to a final pressure of 7100 psi. Backscuttled approximately 8 sacks of cement. CIP 11:54 PM 12-6-72. 12/7-12 Attempted to pull out.. Found tubing stuck. Backed off at 10,675'. Washed over to 10,816'. Cut at 10,808'. Milled tubing from 10,808' to 1.~0,821'.. 12/13 Perforated the following intervals with 4-1/2" holes per foot: 10,794'-10,770', 10,762'- 10,740', 10.,735'-10,721', 10,711'-10,704', 10,696'-10,676' & 10,660'-10,644' .Ail DIL dept 12/14 Set Brown 5%"., 23# DBLL packer, at 10,765' on wireline. 12/15-20 Ran 3%" tubing, 2-3/8" tubing and production equipment. Stuck top packer at 10,451' in 5%" liner. Jet shot off tubing at 10,162'. 'Pulled and recovered.all tubing to 10,162'. Ran in with wash pipe and outside cutter. Cut and recovered 250.81' of 2-3/8" tubing. Ran 4%" mill. Milled packer. Packer and fish Slid to bottom. Ran in with overshot and recovered entire fish, 12/22 Ran .3%" tubing, 2-3/8" tubing and production equipment to 10,794'. Seal assembly in Brown DBLL packer at 10,765'. 12/23 Installed xmas tree and tested to 5400# - ok. Displaced well with lease crude. Set packers. Released rig at 8:00A.M. 12-23-72. 14. I hereby cer~ify~t tile .fort~goingo i~ true ar;xi s,o~mm ~~/~~~J ~ Area Superintendent mAr~, 1- f -73 Il)IV:SIgN CF OIL AND GAS ANCHORAG{~ Form STATE oF ALASKA OIL AND GAS CONSERVATION COMMITTEE WELL cOMPLETION OR RECOMPLETION REPORT! AND LOG* WELL WELL DRY Other , b. TYPE OF COMPLETION: NEW[] WOnK [] DEEP- ~-'] PLUG [~ WELL OVER EN BACK EESVR. Other ' _ 2. NAME OF OP~RATOI1 Standard .0il Company of Califo.rnia~ W0I / ' 'fr ' ...... ,. P;O;-B°x;i:~?-839, :.~mCh0r~e, AlaSka ~ 99510-" LOcA~ION '0~ ~gLL?(Re~ovt. loeati~n elearlg~ana:.i, accordance with an~';~tate" requireme,~s ) * At s.~ac6: 93e~? SOUth-~a ,~9' ~$ast of ~ eorneg~ of Sec. 4, ~, it t0~,~ mp~.. 2~1';. North and ~3~'fEast of SW~:aorher of Sec. B ~ ' ... I ~' '72-T ~' ~V '~'~ ' ~V, ~ '~ ...... ~ "; .? . (~z ' ' " : L1 Borehol.e CompenSate¢ Sonic Log,-Comp'eft- Log, Ray ;ron and 4-Arm DiPme.t~r 25. ~,, ,-~. ,,. ?~, :. REC,'OP, D (Rel set : .' ' · , C'ASmG HOLE~ ~tZE C~N'TING R~COP~D I ~OUNT PULLED~ ~ ,, 5: ?::' 26~'' See --- ,, ~, ~ --- 5~;" "' .'~::'~ [ lO.~a~' ::,:~ / i'~.~8S::, [ ~6 ~ I . l~Z~/8' ' "mi' 10,79k'~:;' ~: '. 1'~0,604', ~!664' 4 ' ! ' ' .......... t '¢' ! ,.., L. I l' ~ ~ , 10,71~', 765' 28. PE~FOrRATIONS OPEN TO PRO~U~O~'.'.:' (inte~l, size and humber) [ 29. ACID, S~iOT, FRACTURE, C~ENT SQUEEZE, ETC. ~:~:r 7~ ~' ~ ~n70li'''' ,,.,:, ,:?" ,';'~ ..... ~ ~ &0832' -10662' [ 92 sacks or cemen~ avo}/j/ ,..~v~ I.~ "J "~ ~!I ' ~'~ ;: '" ..... lO:': 711' ~10,704 ~'; ',':~ ~ holes per foot ' ~ l ~.~= ov T=~T, I~0~S TES,~ 'l~oxE SZZE I PR~'z~ FdR OI~BBn. '"-~A~~M ~E~.B4 _.J GAS-OIL RATIO ' S2 LIST OF ATTACHMENTS ~ ' ! : ~ '~:: 1,~ ' I '' Logs. (Item ~24)~ Directional sur~ev~: F~tion Test Results SS. ~ here~y c~~~~nd at~ached ~nformat~on~, ~ c6~p~ete~L~ :,: and correct as ....... determined from aHVavaHab~e records / '~~-~' ' ~ ?~ ~ea ~Pe~'intehdent D~TE 1-~ ~ -73 T~TLE y"~ . ,.; _ INSTRUCTIONS -~.~C~n'eral: This fb'rm .isI designed~'~6'~',,submitting:~a complete and correct" well conNoletion'.report and log-on .' :all ty:pes of ]an.ds and,leases, in Alaska .... ' Item:' 16: Indicate Which elevat'i'o~ is us'bd aS:i'ireference (Where not otherwi~-e~h-ow:n)-:f(~.r depth'imeasure- .., ments gi:ven.' in c, ther spaces on t~i~: fo;'m'and in any attachments. · , · . , :: ~ .- ., (, ~ ~:_: ....... Items 20,:-and 22:: I-f.this well is com~ie'[~d fo~: seParate production frOm more it:han one interval zone '.'(mull]plo .qompletion), so state in item 20, aha in item 22" show the. prc.::iu~:it~g i.nterval, or intervals, ii:"top(s), bottom(s)':and name (s) (if .any) .for- onJy "the interval reported in item 30. Submit a separate report ~.?(pag'~) o'n:i this for. m, adequately~-i, dentified, for/leach adcti'tiO'nal inte~ val to be seperately produced, show- 'lng' the '~'c]iaitiorl,a:t: data pertinent to ,such' inte~v:al. I¢®m~26: .'!Secks'.i-~,ment": Attached s~.pp)brn~r~tal records for,this welll should show'the details of any mul- ,.;tipl~':stage'~:em;~nting and the I°~tion of the"-cementm'g .tool: .. .... '::. '.- ;.i.. '~ ' .:~ ' "'Item-28J' S~J:bmit 'a . separate, completion report 'on this'-form :for each 5nterval to be separately produc~i. .. .'.(See,..~nstr'uction f~r items 20'and 22 ab°ve)'i " .." .,. , ' .; '.L.. · , .... ~-'~,' ~UJvJI~JIAJ:I,Y Or Ji~OJ:I,I~A'FION T~"-~T$"JI~CI',UDII'~(~ INTE~VA~ T~TED, PB~-~UHE~D~A ~ ~V~ OF OIL.: G~, -: .. ... ~ :':. .~ ~ 35. G~GIC M~RK~ _" .: WA~ AND MUD . · ' C' , Test ~ ~. ~ '" ,, Backscuttled appro~i~-tel~ 9854' rise' and recovered 69-bb. ls of D 5~677' '" 5~677' Water testing 775-875 ~g NaC1 with sc~ of oil. ~ ' El0 8~280', 8~270' .. ~ .... . Pressure data atta~he~. .'~'~' H1 -~, ' ~. "--~ .., . ' .... ~~,~ " '-' : ..... :., ~:-- - 10,798' ' · . . ~ . -- .~., . ~: ~.:-, . ... .~ . ~ .. -,.~; ~. . '. _ , ~.~ ~;:~'~ ~::"":..., '" ~ " '.~, 3B.. CORE DATA. A~ACI[ BRIE~ D~CRIPI~ONS OF LITHOLOGY, POROSIT~ .,.., AND DE'I'EC~'EI) SHOWS OF O1~. O~ OR ~. ', ~ ) :: ': ' ' i . ~" ~ · . . , '" ~ "" ":~ ' ' ' ' ~ - '.; '- C: ' .... ,.. C. ' ":' ' ' ' "~" .' · · . L, ' e.,, .. -'~ :.4 : ~ ~ :~:, . . :; ~ ,,.t ~_.:.',,~: " m ..-, i ~,, '. · Attachment CEMENTING RECORD OF CASING casing cemented with 424 sacks Class "G" cement mixed with 2.4~ Gel by weight of water. 10-3/4" casing cemented with 1660 sacks Class "G" cement mixed ~ith 2.4~ Gel by weight of water followed by 200 sacks neat Class "G%' cement. 7-5/8" casing cemented around shoe with 260 s~cks Class "G" cement mixed with. 2.1% Gel by weight of ~ater followed by 100 sacks of neat Class "G" cement. Cemented through stage collar with 460 sacks of Class "G" cement mixed with 2.1~'Gel by weight of water. Jki4 t 73 DIVISION OF OIL AND 'OAS ANCHORAGE COMPLETION REPORT- Remed~a£ STANDARD OIL COMPANY OF CALIFO1LNIA, WESTERN OPERATIONS, INC. · AREA: SWANSON RIVER FIELD LAND OFFICE: ANCHORAGE · · PROPERTY: SWANSON RIVER UNIT LEASE NO: A-028399 WELL NO: SRU 24-33 API NO: 50-133-20237 LOCATION AT SURFACE: 932' South and 2089' East of NW corner of Sec. 4, T. 7N., R. 9W., SB&M (Well SCU 21-4 Pad). ELEVATION: 164.6' groun~ level, KB to GL is 12.5'. DATE: October 20, 1975 LOCATION AT DEPTH: 271' North and 2399' East of SW corner of Sec.33, T'; 8N., R. 9W, SB&M. · R. J. McKinley / Area Engineer DRILLED BY: Nabors Drilling Company Rig #5 DATE CObD~NCED DRILLING: September 20, 1975 RIG RELEASE: October 16, 1975 October 16, 1975 DATE OF INITIAL PRODUCTION: SU~fARY TOTAL DEPTH: 11,088' PLUGS: EZ drill cement retainer at 10,826' with cement to 10,821'. EFFECTIVE DEPTH: 10,765' Original CASING: 20", H-40, 94#, Buttress cemented at 266'. 10 3/4", K-55, 40.5#, Buttress cemented at 3408'. 7 5/4", P-il0 & N-80, 33.7#, 29.7# and 26-4#. Buttress cemented at 10,635', CP'd at 7404'. 5 1/2", N-80, 23#, Buttress liner from 10,434 - 11,085', cemented at 11,085'. JUNK: 27' of 2 3/8" tubing including Otis XA sleeve and Brown packer ass. (ORIGIN/~) · PF-RFORATIONS: S _UMMARY (CONT' D) 1/2" jet holes per foot 10,862'-~.0,832' (squeezed) 1/2" jet holes per foot 10,794'-i0,770'- 1/2" jet holes per foot 10,762'-10,740' 1/2" jet holes per foot 10,735'-10,721' 1/2" jet. holes per foot 10,711'-10,704' 1/2" jet holes per foot 10,696'-10,676' 1/2" jet holes per foot 10,660'-10,644' ' ,.? Dual Induction - laterolog 9,240'-3,405';.10,362'-7,500,; 10,588'-10,000'; 11,073'-10,622'. Four-ArmHigh Resolution Continuous Dipmeter 9,240'-3,405'; 10,590'-7,500'. Cement Bond Log 10,606'-4,200'; 11,022'-10,422'. Compensated Neutron Log 11,076'-10,400' Borehole Com~Densated Sonic Log 11,076'-10,620' Gamma Ray Neutron Log 11,035'-10,040'. Casing Collar Log and Perforating Record 10,980'-10,400'. INITIAL PRODUCTION: .(30 days) ~D -- Flowing OIL - 2,287 B/D WATER ~%S - 3,249 MCF/D GOR. - 704 API GRAVITY - 33.4 T.P - 400 FORMATION TESTS: Formation Test ~1 - %0,832'-10,862, September 20; 1975 Commenced operations rigging up at 4:00 AM. Prepared gel water and 85 pcf mud. September 21~ 1975 Pulled tubing and installed raised face flange with API 3000 ring joint flange. Killed well with 74-70 pcf mud. Circulated and install cosasco plug. Removed x-mas tree and nipple up B.O.P.E. 70-74 pcf mud September 22~. 1975 Tested pipe rams, stand pipe and choke manifold to 3000 psi. Repaired 10" ring gasket on r~s. · - 70 pcf mud · September 23~ 1975 Tested B.O.P.E. Circulated and worked packer loose. Pulled out of hole with 101 stands of 3 1/2" tubing along with 4 joints of 2 3/8" tubing plus 25' of wire line, top of fish at 10,469'. 70 pcf mud September 24~, 1975 Circulated above fish, could not get into 5 1/2 liner at 10,434', pulled out. .. 74 pcf mud September 25, 1975 Ran in and cleaned out to top of liner at 10,434' and washed over liner to 10,507'. Unable to get below this point, pulled out. 74 pcf mud September 26~. 1975 Fishing at 10,434' no recovery. Shut down to repair Hydra-matic. - 74 pcf mud September 27, 1975 Completed repairs, and went in with overshot assembly. Work over fish at 10,434' to 10,482' could not recover fish. 73 pcf mud September 28~ 1975 Re-entered hole hooked into fish at 10,434' and recovered (207') to 10,639'. Attempted recovery of cc safety joint at 10,639' but could not break loose. Pulled out leaving top of fish at 10,639'. 72 pcf mud September 29~ 1975 Ran in and milled 6"; located top of packer at 10,645' and circulated out, no ~e.covery. 72 pcf mud September 30~ 1975 Ran in found top of fish at 10,667', ~elieved to be lead seal of packer. With washover pipe and one joint of washpipe made one foot to 10,668'. 72 pcf mud October 1, 1975 Milled on fish to 10,678', mill wore out. Pulled and checked B.O.P.E. Made up new mill. 71 pcf mud October 2~ 1975 Re-entered and milled over Brown packer at 10,669. Mill stopped, made repairs and continued mi. lling at 10,669'. 71 pcf mud October 3, 1975 Milling October 4~ 1975 Milling and fish recovery attempt at 10,677' with no success. 74 pcf mud October 5 ~ 1975 Milled from 10,677' to 10,678'. 74 pcf mud October 6~ 1975 Milled out packer at 10,664' and recovered otis "S" nipple at 10,668'. · 74 pcf mud October 7~ 1975 Re-entered and recovered 49' of fish, leaving 79' of fish, top of fish at 10,717'. 74 pcf mud October 8, 1975 -. Ran in hole and recovered 46' of fish, leaving 29' top at 10,763' , 72 pcf mud October 9.~ 1975 Fishing, could not get below 10,756' on return. 72 pcf mud October 10~ 1975 Fishing at 10,763'. O. ctober 11, 1975 Fishing, pulled out leaving 29' of fish including packer. Top fish at 10,763'. Circulated out. Rigged up, ran 2 3/8" and 3 1/2" tubing and Hydro-tested to 5000 psi. 72 pcf mud October 12~ 1975 Completed production tubing run with tail at 10,755'. Set packer at 10,624' to 10,631'. Installed Cosasco plug and tested to 3000 psi. Nipple down B.O.P.E. Installed x-mas tree and tested to 5000 psi, OK. Pull Cosasco plug. Rigged up C.A. White. Ran in hole to check "D" nipple at 10,734', could not get wire below 10,650'. October 13~ 1975 Pulled and checked Brown plug. Re-entered hole and attempted to close sliding sleeve at 10,622', unable to close. Pumped 450 bbls. of clean lease crude along with 50 bbls. BJ mud sweep followed by 100 bbls. of hot fresh water. Circulated out mud sWeep at 6.5 bbls. per minute. 72 pcf mud · .October 14.~. 1975 Condition mud and changed to 68-72 pcf mud. Installed Cosasco plug, nipple down x-mas tree and installed Class 111 B.O.P.E. Tested all rams-choke manifold to 3000 psi and Hydril to 2500 psi. Ail tubing recovered to 10,765' leaving 27' feet including Brown packer in hole. October 15~ 1975 " Drifted all Blast joints. Made up Baker "FH" Packer. Ran in hole and moved Otis sleeve up on single joint. Install Cosasco plug and tested to 3000 psi. Landed tubing and nipple down B.O.P.E. Install x-mas tree and tested to 5000 psi. Pumped clear lease crude down annulus out tubing at two barrels per minute. Closed annulus and pumped down tubing with 2500 psi., (See attachment for tubing detail.) OCtober 16~ 1975 Pressure test annulus to 1000 psi for 30 min. OK. Clean rig site and released rig at 3:00 PM, October 16, 1975. J. W. Wilson Ticket : F L U i D S A M P L E D A T A Dote 12-4-72 Number 308592 Sampler Pressure. .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. C.~3s of Job HOOK WALL District ANC~IORAGE cc. Oil '' ce. Water Tester Co Ko JONI~.S Witness M . BLAIR WONDZj', cc. Mud Drilling Tot. Liquid cc. Contractor R, B, MONTGOMERY DRILLING. COMPANY SM Gravity ° AP! @ °F. EQU I PM E NT & H O L E DA TA Gas/Oil Ratio ,. cu. ft./bbl. Formation Tested HemLock Zone Elevation 177 ' KB Ft. RESISTIVITY CHLORIDE Net Productive Interval. 30 ~ Ft. CONTENT All Depths Measured From Kelly bushing Recovery Wate:r __ @ °F. ppm Total Depth 11,088' Ft. Recovery Mud .. @ °F. /v~ain Hole/Casing Size. Recovery Mud Filtrate __ @ °F. ppm Drill Collar Length .. 10 Mud Pit Sample . @ -- 'F. Drill Pipe Length 465.74t I.D. 2. 441" Tub Mud Pit 5ample Filtrate @ "F. ppm Packer Depth(s) 10,775 ~ Ft. Mud Weight vis cp Depth Tester Valve 10 ~ 756 ~ Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion gas 1200f/~ Ft. Pres. Valve 10,751' Choke~-½-1" Choke 5/8" Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of J ~ Remarks Filled drill pipe with 1200~ gas cushion.., set packer and opened at 12:25 for 233 minute flow period. Closed tool for 239 minute closed in pressure period. Reversed drillpipe of formation fluid at 6:13 PM. Pulled packer , loose at 8:17 PM , Gauge No. 3382 Gauge No. 3381 Gouge 'No. 2857 TIME TEMPERATURE 10760 10764 Depth: 10789 Ft. Depth: Ft. Depth: Ft. 12 Hour Clock 24 Hour Clock 24 Hour Clock Tool A.M. Est. "F. ' Blanked Off no Blanked Off No Blanked Of~'es Opened P.M. 1079b ' Tool A.M~ ,, Actual 183 OF. Pressures Pressures Pressures Closed P.M._ Field Office Field Office Field Office . . Reported Computed , Initial Hydrostatic 5790 5807 5794 579_9 _ 5804 5826 Minutes Minutes '~C:-: Flow' Initial 1377 2211 1081 2179 1456 2333 - - ~.~.. Final 4281 4281 4420 4265 4421 4267 232 233 C~osed in 4447 4454* 4494 4511 4470 4512 240 239 '~ Initial ~ ' - : o Flow ' or. ,, ~, Final Closed in ~ Flow - Initial . ~, Final Closed in F~.~ o__l Hydrostatic - - 5794 5799 5804 5826 - *Read at 115 minuteS'when chaz~' time e~pired. m--- , , '"'""°'""'"" FORMATION TEST DATA //t FLUID SAMPLE I~^TA Sampler Pressure Recovery: Cu. Ft. Gas cc. Oil cc. Water cc. Mud Tot. Liquid cc. Gravity Gas/Oil Ratio P.S.I.G. at Surface ° APl @ °F. . cu. ft./bbl. RESISTIVITY CHLORIDE CONTENT Recovery Water" ~ @ 'F. .ppm Recovery Mud .. @ °F. Recovery Mud Filtrate ~ @ ~ °F. ppm Mud Pit Sample ~ @ ~ °F. Mud Pit Sample Filtrate ~ @ °F. ppm Mud Weight vis cp Ticket Date 12-4-72 Number 308592 Kind Halliburton of Job HOOK WAL~, District ANCHORAGE Tester Co Ko JON~S Witness MR, B, Drilling Contractor R, B, MONTGOMERY DRILLING COMPANY SM EQUIPMENT & HOLE DATA Formation Tested Elevation Ft. Ft. Net Productive Interval All Depths Measured From Total Depth Main Hole/Casing Size Drill Collar Length -I.D. Drill Pipe Length, I.D.. Packer Depth(s) Depth Tester Valve Ft. Ft. Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of Recovered Feet of Recovered Feet of · .~ ............. Recovered Feet of Fourth Gauge Remarks ,, TEMPERATURE Est. °F. Actual ° F. In._iitiol Hydrostatic Initial Flow Final ClOsed in o Initial c Flow ~.~. Final Closed in Initial Flow _, Final Closed in .~Final Hydrostatic .Gauge No. 2856 Depth: 10 7 9 3 Ft, 24 Hour Clock BlankedOff yes Pressures Field 5807 1459 Office 5831 2351 Gauge No. Depth: Ft. Hour Clock Blanked Off Pressures Field Office Gauge No. Depth: Ft. Hour Clock Blanked Off Field Pressures Office Tool Opened Tool Closed Reported Minutes 4436 4279 4510 4529 , DATA 5831 FORMATION TEST 5807 TIME A.M. P.M. A.M. Computed Minutes LITTLE'Ii ~OZ17 told i/lZ //~ Gauge No. 3382 Depth 10,760' First Il First Flow Period Closed In Pressure Time D~fl. .000" .0000 1563- 3601 5639 7677 9715 1.1753 1.3792 1.5830 7 PS1G Temp. Corr. 2211 2582 Time Deft. .000" ,0000 Log-~ PSIG Temp. Corr. 4281 4329 3402 .2106 4359 3752 .3193 4385 3940 4061 4156 4222 4281 · 4280 .5367 .6454 .7541 .(. 7830'~-~'* .8628 .9715 1.0802 1.1889 1.2976 1. 4063 44OO 16 ' Gauge No.3381 oI .0000 2179 11 .0784' 2570 .1806 .2828 4418 4440 4454 4454) Ii 1,51501 I - , 1.6240 - Depth ·3851 .4873 .5895 15 Reading Interval REMARKS: 3386 3735 3924 4049 4140 .0000 · 0512': .1058 · 1604 · 2150 .2696 .3243 4265 4319 4346 4369 4388 4405 4423 .6918 4209 .3788 4437 .7940 4265 ·4334 4445 · 4880 4459 .5426 .5972 · 6518 !-,7064 .... 7610 4469 4482 4489 4494 &504 &~11 Second Flow Period Time Deft. .000" PSIG Temp. Corr. Cloc'!c No. 4~85 ,,, Second CloSed in Pressure Time )eft. Log-~ .ac :l" PSIG Temp. Corr. ITicket 12 hour N°. Third Flow Period" Time Defi. PSIG Temo. .000" Corr. 308592 Third Closed in Pressure Time Deft. .000" LogZ-- - 10.764' Clock No. 8737 24 hour ,,, 30 16 *First interval is equal to 23 minutes, *'15 mi~t.tes. ***Read at t~e end of approximately 115 minutes when chart time expired. pc. IG Temp. Corr. Minutes RPFGIAL PRE'-Z;SURE DATA Gauge N°. , 2857 j Depth First Flow Period Time Deft. .000" _~o.0000 .0768, J PSIG Temp. Corr. 2333 2771 .3773 4775 5777 First Closed in Pressure Time Defi. .000" 7 12 13 .6778 .0000 7780 L t+~ og~ Gauge NoJ , .0773* 2l .1781 31 .2789 al ·3797 sj .4806 .5814 ..Ti .6822 PSIG Temp. Corr. 4267 2603 .0505~* 4321 3412 .1043 4348 3745 3932 4054 4145 .1581 .2119 .2657 · 3195 .3733 .4271 ,4809 .5347 .5885 .6423 .69611 .749g 4211 4267 4370 ~615 4390 44O4 4422 4439 4449 4461 4471 4483 4490 4495 145!2 , , 10,789' Second Flow Period Time Deft. .000" PSIG Temp. Corr. m ,,, Clock No. 8422 Second Closed In Pressure .0505~ Time ::)~ fl. .0C )" PSIG Temp. Corr. r I Ticket 24 hoU No. Third Flow Period" Time Deft. .000" 2856 Depth 10793 Clocb, No. 8420 24 hour %351 .0000 4279 . 4236 4363 4387 4404 '4422 PSIG Temp. Corr. 4439 4453 4461 4475 4485 4498 3403 3751 3939 m 4064 ,, 4154 4223 4279 ,. Reading Interval '30 .1044 .1583 .2122 ,2661 .3200 ,3739 .4278 · 4817 .5356 .sgg5 .64~4 _fig7~ :7517 _8050 4505 4515 16 4522. 4529 I~EMARKS: *First inCerval is equal to 23 minutes. *'15 minutes, , 308592 'rhird Closed In Pressure Time Deft. L.Og~ Temp. .000" rg Corr. Minutes SPECIAL PRESSURE DATA . . Reversing Sub Water Cushion Valve ........... Oo O. 3.75'1 2 7/8II Drill Pipe ...................... Drill Callers ...................... Handling SUb & Choke AssemblY ...... Dual CIP Valve ................... Dual CIP Sampler Hydro-Spring Tester ................ 2.875" 3.88" 3.90" Multiple CIP Sampler ............... Extension Joint .................... AP Running Case .................. II II Hydraulic Jar ................ · ..... VR Safety Joint ................. Pressure Equalizing Crossover ......... Packer Assembly ..... H.°.°.k. ?.~.~?'... 3.87" . 3.87" 3.88" 3.88" 4.50" Distributor Packer Assembly Flush Joint Anchor ................. Flush it. Perf. Blanked-Off B.T. Running Case ....... 2.87" 2.87" 3.87" ~k~b'm BT- 3.87". Anchor Pipe Safety Joint ........... 1.75" 2.441" 2. 764" ' 2.4~1" .87" .62" 3.00" 3.00" 1.00" · 75" 1.25" · . 3,00? 308592 LENGTH 2.48~ DEPTH 465.74' Tubing 10,279~-58' Weight Pipe 6.05' 6.02' 5.10'' ' 10,756' 4.25J' 10,760' 4.58' 10,764q 2.77' 2.55' 5.53; 10,775' 3.55' 5.25' 4.03' 10~789' 4.03' 10,793' 1.05' 10,796' 3.87" 3II Packer Assembly ... ~ ............... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars Flush Joint Anchor ................. Blanked-Off B.T. Running Case ........ SYMBOL OF SERVICE REPORT of SUB-SURFACE DIR.ECTIONAL . SURVEY STf~2~DARD 0IL OP CALT~3RNTA CONIPANY ?FELL 24-73 'WELL NANIE SWANSON RI~?.R bTTiT LOCATION JOB NUMBER AI~I 1-972 TYPE OF SURVEY !.gJ-LTISHOT A.~YD SII[GLE SHOT DATE 12/08/?2 SURVEY BY !mRICE ~ PATTERSON 075 ALAS.VA ! N REPORT DECEMBER 7, 1972 /~DARD OIL COMPANY SWANSON RIVER UNIT .L 24-~3 EASTMAN MULTISHOT AND SINGLE SHOT MAGNETIC SURVEYS K,B. F. LEVATION 177.! FT. MAGNETIC DECLINATION 25 DEG. TANGENTIAL METHOD OF COMPUTATIONS BY f. M. LINDSEY AND ASSOC. RECORD OF SURVEY ALL CALCULATIONS PERFOR~IED BY I B M ELECTRONIC CO~iPUTER TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. EASTMAN MtJLTISHOT SURVEY 0 0 0 0.00 -2~2.~5 N 55 E 225 0 15 224.99 -17.~5 N 55 E 447 I 30 ~46.92 20~,~7 S 55 E 665 0 45 664.90 422.45 5 37 E 850 0 45 849.88 607.43 S ~4 E 1137 0 ~5 1136,86 89~,~1 S 51E 1379 0 30 137B.85 1136.~0 S 55 E 1640 0 30 1639.8~ '1397.39 S 5 W 1922 0 30 19~1.83 1679.38 S 83 W 22~1 0 ~5 2240.80 I998.35 S 35 E 2556 0 45 2555.7T 2313.32 S 87 E 28~ 0 30 28~0,76 2598.31 S 65 E 3156 0 0 3~55.76 2913.~1 S 65 E 3q20 0 15 3~19.76 3177.31 S 53 W 3500 0 15 3499.76 3257.31 S 52 W 3~95 0 15 3594,76 3352.3I N ~3 W 3689 0 45 3688,75 3q~6.30 S 82 W 3784 ! 0 3783.74 35~1.2g N ~3 W 3878 ! 0 3877.72 3635.27 N ~7 W 3973 ! 0 3972.7! 3730.26 N 44 W TOTAL COORDINATES 0.00 S 0.00 W 0.56 N 0.80 E 2.77 S 5.56 E 5.0~ S 7.28 E 6.79 S 8-96 E 9.15 S 11.88 E 10.36 S 1~.61 E 12,63 S 13,~1 E 12.9~ S 10.97 E 16.35 S 13,36 E 16.57 S 17.~8 E 17.62 S 19.73 E 17.62 S 19.73 E 18,31 S 18.81 E 18.53 S 18.54 E 18,22 S 18.26 E 18.~9 S 17.04 E 17.18 S 15.91 E 16.06 S 1~.71 E 14.87 S 1.3-56 E C L 0 S U R E S DISTANCE ANGLE D M $ 0,00 5 0 0 0 W 0.98 N 55 0 0 E 6,21 $ 63 32 6 E 8.86 S ~5 15 48 E 11.2~ $ 52 51 l0 E 15o00 $ 52 23 20 E 17.11S 52 ~2 40 E 18.42 5 46 42 50 E 16.96 S 40 18 22 E 21.12 S 39 1~ ~1E 24,09 S 46 32 10 E 26,~6 $ 48 14 31 E 26.46 $ 48 14 31E 26.26 S 45 46 ]~ E 26,21 $ 45 I 13 E 25.80 S 45 3 10 E 25o07 S 42 48 31E 23.42 S 42 47 4~ E 21,78 S 42 28 44 E 20,12 S 42 21 13 E DOG LEG .SEVERITY DEG/IOOFT SECT IoN ' .DI.STAN¢ . .. .. 0,000 ........... 0,00 0,111 0,741 0,646 -1.'2~ 0,~76 ..... -3,07" 0. 049 O. 105 <.. 0.192 -8,8t~ 0,223 78' 0.338 ....... 0,209 -11.&8 0,120 ' -12,13 0.159 "12, lg. 0,095 ....... '13,0~'~ 0.00,5 -13.31. 0.356 .... -13,09'; 0,681 -13.56. 0,882 -12,67 0,074 ' ' -'-11,88- 0,0.55 .... " -11, .0.2,,~ .-. , RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY ! B M ELECTRONIC COMPUTER TRUE ME'AS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT · SEA DIREC DEG. ~067 1 15 4066.68 5824.23 N 19 W 4162 1 0 4161.67 5919.22 N 23 W 4257 1 0 4256.66 4014.21 N 20 w 4551 1 0 4350.64 4108.19 N 6 W 4446 1 0 4445,63 .~4203.18 N 19 E 4541 0 45 4540.62 4298.17 N 33 E 4635 0 45 4634,61 4392.16 N 33 E 4729 0 45 4728,60 4486.15 N 55 E 4824 1 0 4823,59 4581.14 N 55 E 4919 1 0 4918,57 4676.12 N 55 E 5014 045 50~3,57 4771.12 N 58 E 5108 1 0 5107,55 4865.10 N 82 E 5202 0 30 5201,55 4959,10 $ 62 E 5297 0 15 5296.55 5054.10 S 80 w 5591 0 15 5390,55 5148,10 N 11W 5486 0 15 5485.55 5243.10 N 23 E 5580 0 45 5579,54 5337.09 N 16 E 5675 1 0 5674,52 5432.07 N 12 E 5770 0 45 5769,51 5527.06 N 5 E 5865 0 30 5864,51 5622,06 N 23 W 5959 0 45 5958,50 5716.05 N 18 E 6053 0 15 6052.50 5810.05 N 18 W 6147 0 45 6146.49 5904.04 N 27 W 6242 1 0 6241.48 5999.0~ N 35 E 6~67 0 45 6366,47 612~.02 N 28 E 64~0 1 O 6~2ge46 6187.01 N a9 E 6525 0 30 6524.46 6282.01 N 42 E 6620 0 45 6619,45 6377,00 N 38 E 6715 1 0 6714.43 6471,98 N 19 E TOTAL COORDINATES 12.93 S 12.89 E 11.40 S 12.24 E 9.85 S 11.67 E 8.22 S 11.50 E 6,65 S 12.04 E 5.60 S 12.72 E 4.57 S 13.39 E 3.85 5 14.37 E 2,88 S 15,7~ E 1.93 S 17.09 E 1.27 S 18.14 E 1.04 S I9.77 E 1.45 S 20.~9 E 1,50 S 20.08 E 1.10 S ZO.O0 E 0.72 S 20,17 E 0.46 N 20.51E 2.08 N 20,85 E 3,32 N 20.96 E 4.08 N 20.63 E 5.25 N 21.02 E 5.64 N 20.89 E 6.74 N 20,53 E 8.10 N 21.28 E 9.5~ N 22.05 E 10.26 N 22.88 E 10.88 N 23~43 E 11.86 N 24.20 E 13.42 N 24.74 E CLOSURES DISTANCE ANGLE D M S 18.26 S ~4 54 '16 16.73 S ~1 1 21 15.27 $ 49 50 55 14.14 S 5~ 27 29 13.76 $ 61 5 25 13,90 S 66 12 28 1~,15 S 71 ? 49 14,87 $ 75 ~ 19 15.99 S 79 36 19 17.20 $ 83 32 2~ 18.19 $ 85 58 36 19,79 S 86 57 56 20,54 $ 86 0 ~ 20,14 S 8~ 42 54 2U.03 S 86 50 46 2~.18 S 87 57 ~1 20.51N 88 42 36 20·,95 N 84 17'41 2~,22 N 80 59 40 2~.04 N 78 48 12 2~-66 N 75 57 43 21.64 N 74 52 43 2~,42 N 71 39 24 22.77 N 69 9 57 2~,03 N 66 35 49 25.08 N 65 50 15 25.84 N 65 5 41 26,95 N 6~. 53 27 28,~5 N 61 30'3~ DOG LEG SEVERITY DEG/IOOFT 0.57.9 0.276 0.055 0,259 0.456 0.344 0,000 0.277 ISECT [ D I S T .......... -'lo 99 -2,25 -1.09:~ -0,12: 0,000 0.267 0.466' 0,706 0.751 0,373 0,15W 0,535 0.271 0,286 0,408 0.528 0.603 0.537 0.975 0,217 0,639 0,534 0,267 0.½00 0,265 1,13 2,39' 3,29. 3,9i' 3,72 3,55 3,92 4,33 8.4¢. 9,10" 10.337 11,60 13'15 - 15,65 j _....'.}7, 52i-' 9 17'.:' ./. REcoRD OF SURVEY · ALL CALCULATIONS PERFORMED BY ! B ~ ELECTRONIC 'COMPUTER TRUE NEAs. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DR I FT SEA DIREC DEG. 6809 0 45 .6808,42 6565,97 N 29 E 6904 0 0 6903,42 6660,97 N 29 E 6998 0 15 6997,42 6754,97 S 32 E 7092 0 15 7091,42' 6848.97 N 25 E 7185 0 30 7184,42 .6941,97 N 5 E 7279 1 0 .7278,41 7035,96 N 12 W 7374 0 0 7373,41 7130,96 N 12 W 7469. 0 30 7468,40 7225,95 N 57 W 7562 0 15 7561,40 7318.95 N 37 W EASTMAN SINGLE SHOT MAGNETIC SURVEY 7670 3 15 7669,23 7426.78 N 18 E 7704 4 15 7703,13 7460,68 N 10 E 7764 5 0 7762,91 7520,46 N 5 E 7825 5 15 7823,65 7581.20 N 7 E .7890. 6 15 7888,26 7645,81 N 10 E 7952 7 15 7969.77 7707,32 N 13 E 8046 9 15 8062,54 7800,09 N 16 E 8172 11 45 8165.90 7923,45 N 16 E 8269 14 30 8259,81 8017.36 N 18 E 8311 15 0 8300,38 8057,93 N 18 E 8372 15 0 8359.31 8116.86 N 7 E 8497 17 0 8478,84 8236.39 N 5 E 8621 19 30 8595,73 8353,28 N 5 E 8734 19 45 8702,08 8459,63 N 8 E 8875 23 15 8831,63 8589.18 N 8 E 8974 25 15 8921,17 8678,72 N 8 E 9169 26 0 9096.44 8853.99 N 9 E TOTAL COORDINATES 14.50 N 25.34.E 14.50 N 25.34 E 14,15 N 25.55 E 14.52 N. 25.73 E 15.33 N 25,80 E 16.9~ N 25.46 E 16.94 N 25.46 E 17.39 N 24.76 E 17.71N 24.52 E 23.5~ N 26.41E 26,02 N 26.85 E ]1.23 N 27.30 E 36.77 N 27.98 E 4~,7~ N 29,21 E 51.36 N 30.97 E 65-88 N 35,14 E 90.55 N 42.21 E 113.65 N 49.71 E 123.99 N 53.07 E 139,66 N 55.00 E 176.06 N 58.18 E 217.30 N 61.79 E 255.11N 67,10 E 310.23 N 74.85 E 352,05 N 80.73 E 436.48 N 94.10 E CLOSURES DISTANCE ANGLE O M S 29.19 N 60 12 39 E 29.19 N 60 12 39 E 29,21N 61 0.53.E 29.54 N 60 32 50 E 30.01N 59 16 11E 30.58 N 56 21 28 E 30*58 N 56 21 28 E 30,26 N 54 55 0 E 30,25 N 54 8 55 E 35,38 N 48 17 23 E 37,39 N 45 53 48 E 41,48 N 41 9 46 E 46,21 N 37 16 25 E 52.60 N 33 44 22 E 59.98 N 31 5 30 E 76.67 N 28 4 19 E 99,91N 26 59 35 E 124,05 N 23 37 38 E 13~,87 N 23 10 27 E 150,10 N 21 29 63 E 185,43 N 18 17 14 E 225,91 N 15 52 26 E 263,79 N 1~ ~4.15 E 319,13 N 13 33'55 E 361.19 N 12 5~ 56 E ~4b,51N 12 9 59 E DOG 'LEG SEVERITY DEG/IOOFT 0.311 0.789 0.266 '0.467 0,299 0.577 0,526 0.299 2,883 3,313 '1,418 0,504" 1,606 1.710 2,176 1.986 2.873 1.190 6,661 1,659 2,016 0,919 2,482 2,020 0,~4 SECTION' D 15, J 20,0'8": 20./+9: "21.2 22,76? 23.02:~, 23,27· . _ ;.;..~ :~, .. 29.38' 31.90 · . 72,57 :_ 98.22" 122.46. 133,31 1~8.96' "185.01 225,84' 263,79' '319,0~~ ":~ 36!, 06~: RECORD OF SURVEY ALL CALCULATIONS PERFORatED BY I B ~ ELECTRONIC COMPUTER .TRUE MEAS, DRIFT VERTICAL DEPTFI ANGLE DEPTH D H SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M DOG LEG SEVERITY DEG/[OOFT SECT I Ohjfi. DISTAN¢i . . 9421 24 0 9326.65 9084,20 N 11 E .9551 22 0 944'1,19 9204-74 N 15 E 9662 23 0 9549,36 9306.91 N 13 E 9874 25 30 9740,71 9498.26 N 14 'E 10095 25 15 9940,60 9698,15 N 17 E 10373 25 45 10190,99 9948.54 N 17 E 10520 24 15 10325,02 10082.57 N 16 E 10600 24 0 10398,10 10155.65 N 18 E 10682 24 0 10473,01 10230.56 N 17 E 10781 24 0 10563,45 10321.00 N 18 E 10929 25 0 10697,59 10455.14 N 18 E 11088 25 0 10841,69 10599.2g N 18 ~ 537.09 N 113.66 E 584.13 N 126.26 E 626.39 N 136.02 E 714,95 N 158,I0 E 805.10 N 185,66 E 920.60 .N 220.97 E 978.6~ N 237.61 E 1009.58 N 247.67 E 1041.48 N 257.42 E 1079.77 N 269.86 E 1139.26 N 289.19 E 1203.17 N 309.96 E BOTTOM HOLE CLOSURE 1242.45 FEET AT N 1~ 26 46 E 548,99 N 11 56 55 E 597,62 N 12 11 50 E 640,99 N 12 15 5 E 732,22 N 12 28 10 E 826,23 N 12 59 9 E 946.75 N 13 29 51E 1007,07 N 13 38 51 E 1039.52 N 13 47 1 E 1072.82 N 13 53 0 E 1112,99 N 14 1 56 E 1175.~9 N 14 14 ~6 E 1242.45 N 14 26 46 E 0.862 1.952 1.1~4 1,195 0.593 0,180 1.060 1,068 0,496 '0,411 0,676 0,000 INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR 'G~:IVEN DEPTHS · · TRUE CODE MEASURED VERTICAL TOTAL COORDINATES NAM~ DEPTH DEPTH H1 PT 10643 10653 10663 10673 10683 10693 10703 10713 10723 10733 10743 .. 10753 10763 10773 10783 10793 H4 PT 10798 TOP 8 SAND 10825 BASE 8 SAN 10920 TOP lO SAN 10935 BASE 10 SA 11032 10437.38 1026.31N 252.78 E 10446.52 1030.20 N 253.97 E 10455.66 1034.09 N 255.16 E 10464.79 1037.98 N 256.35 E 10473.93 I0~1.86 N 257.54 E 10483.06 1045.73 N 258.80 E 10492.20 1049.60 N 260.06 E 10501,33 1053,47 N 261.32 E 10510,47 1057,34 N 262,57 E 10519.60 1061.21N 263.83 'E 10528.74 1065.07 N 265.09 E 10537.87 1068.94 N 266.34 E 10547,01 1{)72.81N 267.60 E 10556,15 1076,68 N 268,86 E 10565.27 1080.58 N 270.12 E 10574.33 1084.60 N 271,43 E 10578.86 1086.61N 272.08 E 10603,33 1097.46 N 275,61E '10689,43 1135.64 N 288,02 E 10703.03 1141.67 N 289.97 E 10790.94 1180.66 N 302,64 E ' CLOSURE DISTANCE ANGLE D.M S 1056.98 N 13 50 12 E 10194.93 1061.04 N 13 50 56 E 10204,07 1065.10 N 13.51 39 E 1021~,21 1069.16 N 13 52 22 E 10222,34 1073.23 N 13 53 6 E 10231,48 1077.28 N 1~ 5~ 2 E 10240.61 1081.34 N 1~ 54 57 E 10249,75 1085.40 N 13 55 52 E 10258,88 108~,45 N 13 56 47 E 10268,02 .... SUB ............................. ...... .. .... ,.~ 1093,51 N 13 57 41E 10277,15 1097,57 N 13 58 35 E 10286,29 ..................... 1101,63 N 13 59 28 E 10295,42 ' '~: 1105,68 N 14 0 22 E 10304,56 ........ 1109.74 N 14 1 14 E 10313.70 :' 1~13,83 N 14 2 7 E 10~22.82 ' 1118.05 N 14 3' I E 10~31.88 '" 1120.15 N 14 ~ 28 E '10~36.41 1131.~4 N 14 5 ~1E 10~60.88 1171.60 N 14 13 52 E 10~6.9~ 1177.92 N 14 15 5 E 10460.58 1218.83 N 14 ZZ ~8 E ~0548,49 ........ . . · ............... ........ -.. . MEASURED D~PTH. AND OTHER DATA FOR EVERY EVEN , . TRUE MEASlIRED VERTICAL SUB MD-TVD DEPTH DEPTH SEA DIFFERENCE 342 342. 100. 0 443 442. 200. 0 543 542, 300. 0 643 642, 400. 0 743 742, 500. 0 843 842, 600. 0 943 942, 700. 0 1043 1042, 800. 0 1143 1142, 900. 0 1243 1242. 1000- 0 1343 1342. 1100. 0 1443 1442, 1200. 0 1543 1542, 1300. 0 1643 1642, 1400, 0 1743 1742, 1500, 0 1843 1842. 1600, 0 1943 1942, 1700. 0 2043 2042, 1800. 0 2143 2142, 1900. 0 2243 2242, 2000. 0 2343 2342, 2100, 0 2443 2442, 2200. 0 2543 2542, 2300, 0 2643 2642, 2400, 0 2743 2742, 2500, 0 2843 2842, 2600. 0 .2943 2942, 2700, 0 3043 3042, 2800. 0 3143 3142. 2900, O 3243 3242, 3000. 0 3343 3342, 3100, 0 3443 3442. 3200. 0 3543 3542, 3300, 0 3643 3642, 3400. O 3743 3742. 3500. 0 100 FEET OF VERTICAL CORRECTION D 0 0 0 0 0 0 0 0 0 ,0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O SUB SEA DEPTH, TOTAL COORDINATES 1,20 S 3-32 E 2,70 S 5,46 E 3,76 S 6,31.E 4,81 5 7,10 E 5.77 $ 7,98 E' 6.72 5 8,89 E 7.55 S 9,90 E 8.37 S 10,92 E 9.18 S 11,92 E 9.68 S 12,63 E 10,18 $ ~3.35 E 10.91S i3.56 E 11,78 5 13,48 f 12,63 S 13,39 E 12,74 S 12,52 E 12,85 S 11,65 E 13,15 S 11,12 E 14.22 5 11,87 E 15-30 S 12,62 E 16,35 5 13.38 E 16,42 S 14,69 E 16.49 5 16,00 E 16,56 S 17,31E 16,89 S 18,17 E 17,26 S 18,96 E 17,62 S 19,73 E 17,62 S 19.73 E 17.62 S 19.73 E 17.62 S 19.73 E 17.85 S 19,43 E 18,11 S 19,08 E 18.37 S 18,74 E 18.39 S 18.61 E 18,31 S 17,66 E 17.71 S 16,60 E . , ~4~ASURED DEPTH AND OTHER DATA FOR ·EVERY EVEN 100 FEET OF SUB SEA DEPTH. TRUE ~l~. ASURED VERTICAL SUB IHD- TVD VERTICAL DEPTH DEPTH SEA' DIFFERENCF CORRECTION TOTAL COORDINATES 3843 3842, 3600, 0 3943 3942. 3700. O' 4043 4042,. 3800. 0 4143 4142. 3900, O. 4243 4242, 4000, 0 4343 4342.' 4100, 0 4443 4442. 4200. 0 4543 4542' 4300, 0 4643 4642, 44.00. 0 4743 4742. 4500. 0 4843 4842, 4600, 0 4943 4942. 4700, 0 5043 5042, 4800, 0 5143 5142, 4900, 0 5243 5242, 5000. 0 5343 5342, 5100, 0 5443 5442. 5200. 0 5543 5542, 5300. 0 5643 5642, 5400, 0 5743 5742, 5500. 0 5843 5842. 5600. 0 5943 5942, 5700. 0 6043 6042, 5800, 0 6143 6142. 5900, 1 6243 6242, 6000. 1 6343 6342, 6100, 1 6443 6442, 6200. 1 6543 6542, 6300, 1 6643 6642, 6400. 1 6?43 6742, 6500, 1 6843 6842, 6600. 6943 6942, 6700, 1 7043 7042. 6800. 1 7143 7142, 6900, 1 7243 '7242. ?000, 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 0 0 0 0 0 0 0 1 0 0 0 0 0 0 0 o 0 0 0 16,48 15.25 5 13,43 S 11.71 S 10.08 S 8.36 5 6.70 $ 5,58 S 4.51 S 3.69 2.69 S 1.76 1,20 S 1.19 1.46 S 1,30 S 0,89 S 0.00 S 1.53 N 2.96 N 3,90 N 5,05 N 5,60 N 6,69 N 8,11 N 9,26 N 10.35 N I1,06 N 12,24 N 13,75 N' 14.50 N 14.36 N 14,33 N 14.97 N 16,32 N 13.92 E 12,37 E 11.76 E 11.52 E 12,02 E '~; 12.7:3 E 1~,4'? E __ 1A.57 E ....... 16.00 E 20,04 E 20,32 E 20,04 E 20.09 E 20,37 E 20.73 E 20.93 E 20.71E 20.95 E 20,90 E 20,35 E 21.29 E 21,90 E 22,95 E 2~,58 E 24.33 E 24,92 E 25,34 E 25,43 E 25,64 E 25,76 E 25,59 E MEASURED DEPTH '~.IEAsuRED .DEPTH 7343 744~ 754D 7643 7743 7844 7945 8046 8251 8355.. 8459 8564 8671 8778 8887 8998 9109 9219 9329. 9~38 9546 9654 9765 9876 9986 10097 10208 10319 10429 10539 10649 10758 10868 AND.OTt-tER DATA TRUE VERTICAL SUB DEPTH SEA 7342. 7100. 7442. 72O0. 7542. 7300. 7652. 7400. 7742. 7500, 7842. 7600. 7942- 7700. 8042, 7800. 8142, 7900e 8242. 8000o 8342. BlO0. 8442. 8200. 8542. 8300. 8642, 8400. 8742. 8500. 8842. 8600. 89420 8700. 9042. 8800, 9142. 8900. 924-2. 9000, 9342, 9100. 9442, 9200, 9542. 9300, 9642. 9400, 9742. 9500. 9842. 9600. 9942. 9700. lC)042. 9800. 10142, 9900, 10242, 10000, 10342, 10100, 10442. 10200. 10§42. 10300. 10642, 10400. FOR EVERY EVEN MD-TVD DIFFERENCF 1 1 1 1 1 1 2 3 6 9 12 16 22 28 35 ~5 55 66 77 86 96 103 112 123 155 166 177 187 ]97 206 216 226 100 FEET OF SUB VERTICAL CORRECT I ON 0 o 0 0 0 0 1 ! 3 3 4 '6 6 7 10 10 11 11 9 10 7 9 11 lO Il 11 1! Il 10 10 9 10 10 SEA DEPTH. TOTAL COORDINATES 16.94 N 25.46' 17.27 N 24.95 17.65 N 24,57 22.09 N 25.94 29.44 N 27.15 38.79 N 28,34 50.45 N 30.76 65.87 N 35.13 85.86 N 40.86 109.38 N 48,32 135,17 N 54,45 164,98 N 57e2! 198.90 N 60,14 233,91 N 64.12 272,28 N '69,52 315.28 N 75.56 362,29 N 82e35 410.47 N 8~,98 45~.58 N 98,01 500.29 N 106,50 543,26 N 115.31 582.28 N 125,77 623.53 N 135,36 669,47 N 146.76 715.73 N 158,34 760.83 N 172.13 805,95 N 185,92 852.08 N 200.02 898.21 N 214.13 942.88 N 227,36 986.02 N 2~0.01 1028.~+6 N 253 1070.88 N 266,97 1114,81 N 281,24 E E E E E E E E E E E E E E E E E E E E E E E E E E E E E E E E E E .. TRUE MEASURED VETRT ICAL SUB DEPTH DEPTH SEA 1000 2000 3000 AO00 5000 6000 7O0O 8O00 9000 lO000 999, 757. 1999, 1757. 2999, 2757. 3999, 3757. 4999, 4757. 5999, 5757. 6999, 6756. 7997. 7754.- 89~4, 8702, 985A,. 9612, TOTAL COORDINATES 8.02 S 17.62 S 1.~7 $ 5°42 N 14,16 N 58,78 N 363,91 N 766.35 N 10.48 E 11.55 E 19.73 E 13,36 E 17.99 E 20.96 E 25.56 E 33.10 E 82.51 £ 173.81E I ! i i- L_.L ~ i' i Form No, P--4 l~'V. ~- I-?0 STATE OF ALASKA SUBMIT ]lq 'DtTPLICAT~ OIL AND GAS CONSERVATION CO/V~I~EE 50-133-20-237 ...... i~-~ A-028399 ~IT F~ OR LEASE N~E Swanson River SRU 24-33 '~-~FEi," - ~ ~w~ ,~g. om wmmc~'-'~lt~ ' ' ' .... S~nson River ' o~ Sec 33, T8N, R9W, SB&M , , MONTHLY REPORT OF DRILLIN_~ ~ ~ I~D V ~ AND WORKoVER OPERATIONS~ I, NAM-~- OF OPerATOR Standard Oil Company of California, ~. ADDREss OF' oPerATOR P.O. Box 7-839, Anchorage, Alaska 4 LOCATION OF WFJ..L SURFACE: 935' south and 3065' west of the northeast corner of Section 4, T7N, R9W, SB&M (Well SCU 21-4 pad) APPROX BHL: 200' north and 3000' west of southeast corner of Section 33, T8N, R9W, SB&M PERMIT NO 72-7 13. REPORT TOTAL DEPTH AT END OF MONTH. CHA.NGES IN HOLE SIZE. CASING AND CL-MENTING JOBS INCLUDING D~P'IH SET ~ VOLLrI~ USED, PFJ~FOP~%TIONS, TESTS A.I%rD F~ESULTS FISHING JO~ JL~TK LN HOLE AND $IDE-/'P~ACKED ItOL~E A3~D ~NY OTHER SIGNIFICA/%TT CI~A3~GES IN I{OL~ CONDITIONS 'November 197 2 November 1-2, 1972 - Ran open ended drill pipe to 7943' and equalized 200 sacks of Class G cement. Located cement plug at 7670' and drilled out to 7675~. November 3-4, 1972 -Ran turbodrills #1 and 2 to sidetrack original hole. Drilled with turbodrills to 7887'. UDmble to sidetrack. Equalized 200 sacks of Class G cement at 7867'. November 5-6, 1972 - Located top of plug #2 at 7618'. Cleaned out cement to 7624'. November 7-10,1972 - Ran torbodrill #3 and sidetracked original hole at 7624'. Ran turbo- drill #4 and drilled to 7668'. Directionally redrilled ahead in 9-7/8" hole to 8311'. November 10, 1972 - Ran turbodrill #5 and drilled to 8329'. November 11-20,1972 - Directionally drilled ahead in 9-7/8" to 10373'. Ran Schlumberger DIL log from 7500' to 10373'. November 20-22,1972 - Directiona!ly drilled 'ahead in 9-7/8" hole to 10600'. Ran Schlumberger DIL log from 10635' to 10373'. Ran 4 arm dipmeter from 10600' to 7500'. Drilled ahead to 10635' and conditioned hole for casing. November 23-24,1972 - Ran 10,635' of 7-5/8" P-110 and N-80, 33.7, #29.7# and 26.4# casing. Cemented through shoe with 260 sacks of cement Gel mix (2.1% Gel by weight of water) followed by 100 sacks of neat cement. Opened stage collar at 7404' and cemented through collar with 460 sacks cement- Gel mix (2.1% Gel by weight of water). CIP 2:30 p.m. 11-24-72. November 25-27,1972 - Landed 7-5/8" casing. Installed tubing head. Tested secondary seal to 5000 psig - O.K. Nippled up 10"-5000# BOPE. Cleaned out stage collar and 7-5/8" casing to 10618'. Ran Cement Bond Log from 10618' to 4200'. Test BOPE and 7-5/8" casing - O.K. to 2500 psig surface pressure. November 28-30,1972 - Directionally drilled ahead in 6-5/8" hole to 11,088'. NOTE~Report on this f~m il required for .~Ch colefldar ~thl regordiesl of lhe Itotus of operotiofls, Qnd must~ filed In dupll~te with the oil and gas conservatbn commiflee by the 15~ of the suec~ding mn~, ~le~ otherwis~ d~r4cted. Form P--3 ~ Stat)mit "Intentions" in Triplicate - '" i -- P~EV. 9-30-69 & "Subsequent Reports" in Duplicate STATE O,F ALASKA ' OIL AND GAS CONSERVATIO, N COMMITTEE 50-i33-20-237 ,, --- ' 6. LEASE DESIGNATION A.N¢, ~,~ SUNDRY NOTICES AND REPORTS ON WELLS .. :,,.._,_~_.~N,_ I (DonotusethisformforproposalsbodriHor'odecpen use "^~¢'.~C.~TION'EOR ¢'E~rr~" '~o. ~.ch'.~o¢o~:) A-028399 . , 1. ?. IF INDIA.N, Ai~Ou-r~E O 'RIB 2. NAME OF OPERJ~TOR 8. UNITl FA~h~[ OR I.~YJ~SE NA Standard 0il Company of California Swanson River 2 3. ADDRESS OF OPERATOR 9. W~LL NO, 1). 0. Box 7-839~ Anchorage~ Alaska 99510 SRU 24-33 ,, _ ~Ev ..... _ At surface 932' south and 2089' east of N~ corner of Sec. 4~ Swanson River SrC - _ T7N, Rgw, SB&M (Well, SCU 21-4 Pad) Approx BHL: u. s~.c., r., a.. ~., (SOTTO~ . · OBJECTIVE) 200' north and 3000' west of SE corner of Sec. 33, T8N, R9W~ SB&M Sec. 33, TSN, RgW, SB&M' 13. ELEVATIONS (Show whether DF, ET, OR, e%c. 19.. P~q~%~LIT NO. 164.6' GR, 177.1' KB 72-7 ! ,4. Ch~ck Appropriate Box To I,ndicate N3t'ure of N~tice, Re )ort, or Other D~t~ NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~] I PULL OR ALTER CASINO I I FRACTURE TREAT MULTIPLJ COMPI,ETE J I SHOOT OR ACZDIZE [ J ABANDON* REPAIR WELL ] [ CHANGE PLANS ~Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF I j FRACTURE TREATMENT Z1 SHOOTINO OR ACIDIZlNO (Other) REPAIRINO WELL ALTERING CASINO ABANDONMENT* (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Change the original drilling program to eliminate the stage cementing collar in the 7 5/8" casing string scheduled at 36'00'. Well SCU 21-4 located 100' due east does not have ~ement tying the surface and productive strings. 30 PSIG pressure noted previously in the casing string annulus resulted from a leak in the secondary packing in the tubing head, and has now been corrected. It was checked on 11/7/72 and no pressure found. The above change is proposed to preclude possible mechanical problems. NOV 2 4 197P D1ViSICJ'4 CF OIL AND GAS ANCHORAG~ J. W. ~-IGNED ,/~1 (This space for State offic~ u~ // ~ co~vmo~s oi-iP~ao~A~, ~ ~: ~ ' Area Superintendent TITLE TXTLE 'ghiSf Pe~r0!eum Engineer DATE //~ '**~ - See Instructions On Reverse Side lvorm No. 1:'---4 P,,EV. STATE OF ALA~SKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY REPORT O:F 'DRILLING AND WORKOVER OPERATIONS WI~LL WELL OTHER 2. NA_I~E OF OPElq.~TOR 8. UNIT,FAP~M OR LEASE NAME Standard 0il Company of California, W0I Swanson River 3, ADbRr~SS OF OPm~TOR P. O. Box 7-839, Anchorage, Alaska 99510 4. lOCATION OF WgLL SURFACE: 935' South & 3065' West of the North- east corner of Sec. 4, T7N, R9W, SB&M. (Well ~C~-~21-4 Pad). APPROX. BHL: 200' North & 3000' West of South- east forner of Sec. 33, TSN, R9W, SB&M. ~5. AP1 NU~iERICAL CODE T ~ 50-133-20-237 ~ 6, LEASE DESIGNATION AN'D SERIAL NO. A-028399 ?. IF INDI^~', AL~DT'I'EE OR TRIBE N~ME 9. WELL NO. SRU 24-33 10. FIEI.D AND POOL. OR WILDCAT Swanson River 11. SEC.. T., R., M,, (BO~'POM HOIE o~ Sec. 33, T8N, R9W, SB&M 1~.. PERMIT 172-7 L 13, REPORT TOTAL DEPTH AT F2qD OF MONTH, CI-IA~'GF_~S IN HOLE SIZE, CASING A_ND CE1VIF_~TTING JOBS INCLUDING DEPTH SET AlTO VOLTJiVIE~ USED, PEi~FOI:L~TIONS, TF_~Ts AN'D 1RESULTS. FISHING JOB&. JUI~K IN HOI~E AND SIDE-TYLACICED HOLE AND A~Y O~FA:~ SIGNIFICA-NT CI-LM~G~ IN HOI~ CONDITIONS. OCTOBER 1972 October 1-2, 1972 Drille'd 15" hole to 3415'. Ran 3408' of 10 3/4", 40.5 lb/ft, K-55 buttress casing. Cemented with 1660 sacks of Class G cement mixed with 2.4% gel by weight of water followed by 200 sacks of neat Class G cement. Good re- turns through out cement job. Cement in place by 8:15 PM, 10-2-72. October 3-6, 59_72 Cut 10 3/4" casing. Installed 10"-5000 psig 10 3/4" SOW casing head. Tested casing head and weld lap to 2000 psig. Installed Class III, 10"-5000 psig BOPE. Pressure tested CSO, Hydrill and pipe rams, 2500 psig - ok. Drilled out cement in 10 3/4" casing with 9 7/8" bit. October 7-%0t~_~72 Drilled ahead in 9 7/8" hole to 7950'. Well kicked off at 7950' and directionally dri'lled to bottom hole location- 170' N, 105' W at a depth of 9256' (9232' TYD). o c t o b er Ran Eastman multishot directional survey. Ran Schlumberger Dual Induction-Laterolog and Continuous Dipmeter from 3405' to 9256'. NO;t 7 i§77 DIVI$1C;.N 'F OIL AND GAS 14. I he.by S'G~~--~'~//]t~~J ~ AREA SUPERINTENDENToA~ 11/ ~/72 , .~ ~.- ~.~15 .......... TE~Report on t~is form is req~lred for each calendar too,th, ~egard[ess of the stat~s of operation% soo must ~ fi]e~ i~ d~plicate witb~be Division of Mi~es & Minerals by the lSth o{ the s~cceedi~9 month, ~nless othe~ise directed. REV. 9-30-6 9 ~bmtt "Intentions" in Triplicate "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION: COMMII-rEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION'Foi~ ~'EHi~i']?-L~' ~for such 'Pr'o~osal~) 1. 0IL [] OAS [] WELL WELL OTHER 2. NAME OF OPERATOR Standard Oil Company of California ~. ADDRESS OF OPEq{ATOR P. O. Box 7-839, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 935' South and 3065' West of NE corner of Sec.4 T7N, Rgw, SB&M (well SCU 21-4 pad) Approx. BHL: 200' North and 3000' West of SE corner of Sec. 33, T8N, R9W, SB&M 13. ELEVATIONS (Show whether DF, RT, Gl{, etc. 164.6' GR, 177.1' KB 50-133-20-237 6. "i2EASE DES/~NATION A.ND SEI; A-028399 8. UNIT, F~ OR ~SE NAME Swanson River 9. ~L NO. SRU 24-33 , 11. SEC,, T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 33, TBN, R9W, SB&M 12. PER2VLIT NO. 72-7 Check Appr~riate Box To I,nd~cate N, ature of N~)ti'ce, Re tort, or Other Dat~ NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPI.ETE SHOOT OR ACtDIZE ABANDON$ REPAIR WELL CHANOE PLANS tother) SUBSEQUENT REPORT OF: FRACTURE TREATMENT 8HOOTING 0R ACIDIZINO , I ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPO//IED OR C0.'4PLETED OPERATION'S (Clearly state all pertinent details, and g'ive pertinent dates, including estimated date of starting any proposed work. Plugback, sidetrack well and directionally drill according to original program. Well reached 9256' on 10/30/72 at a location 170' N and 105' W of the surface iocation. Evaluation indicates proposed target can no longer be intersected from this point. A multishot survey was made, and DIL and dipmeter logs were run. Operator Proposes to equalize an approximate 350' Class G, neat cement plug, with top at 7620', sidetrack and directionally redrill to the original target location.. ProPoSed Plug will isolate all potential water sands. // (Thi, space for Stat~%ofltct.u~/ ~. ~ CONDITIONS 0F ~PPROVAL, IF A~: ~ OV DIVI~ICN ~.F OIL AND GAS ANCHORAGE AREA SUPERINTENDENT TITLE DATE 11- / -72 See Instructions On Reverse Side Approved Copy Form No. P---4 REV. 9-30-67 STATE OF ALASKA SUBMIT liN DUPLICATE OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF D-RILLING AND WORKOVER OPERATIONS NA/~E OF OP~I~%TOR Standard Oil Company of California, WOI ~. API NUMERICAL ~ODE 50-133-20-237 8. LEASE DESIGNATION AND SERIAL NO. A-028399 T. IF INDIAN, AL~DTT~E OR TRIBE NAME 8. LrNIT,FA/~ OR LEASE NA]~E Swanson River 3. ADDRESS OF OPERATOR 9. WELL NO. . P. O. BOx 7-839, Anchorage, Alaska 99510 SRU 24-33 LOCATION OF WF_J~L SURFACE: 935' South & 3065' West of the North- east forner of Sec. 4, TTN, Rgw, SB&M. (Well SCU 21-4 pad). APPROX. BHL: 200' North & 3000' West of South- east corner of Sec. 33, TaN, Rgw, SB&M. 10. FIELD AND POOL. OR WILDCAT Swanson River ll. SEC., T., R., M., (BO1~I'OM HOLE OB.r~CTn~ Sec. 33, TaN, Rgw, SB&M 12. PElq~/IIT NO. 72-7 13. REPORT TOTAL DEP/~H AT END OF MON//{, CI~NGF~ IN HOLE SIZE, CASING ~ CEMENTING JOBS INCLUDING DEPTH SET ~%rD VOLLrlVI~ USED, PEi~ORATIONS. T~TS ~ i~SULTS, FISHING JOBS, JI/NK IN HOL4g A_ND SIDE-TRACKED HOLE ANT) A_NY O~{ER SIGNIFIC~NT C~G~ IN HOLE CONDITIONS. --September 25-27, 1972 September 28-29, 1972 ~September 30, 1972 SEPTEMBER 1972 Well spudded 9-25-72. Drilled 17 1/2" hole to 410'. OPen&~. 17 1/2" hole to 26" from ~ to 400' (30" conductor pipe through 52') Ran 20" buttress, welded casing to 266' casing with 424 sacks Class G with 2.4% Gel by weight of water. II B BOPE on 20" casing and tested 266'. Cemented Cement mixed Nippled up Class same. Drilled out cement and shoe at 266'. Drilled 15" hole to 1483'. Drilling ahead 9-30-72. OlVI~ION OI~ OIL AND G4.~ 14. I hereby frtt~//h~or~ ~~ ~r SmN~D~V~X/.ZXl~~ =~DISTRICT SUPERINTENDE~T~ 10/ff /72 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filect in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. S~abn~t "Intentions" in Triplicate g.r.v. ~o.su-o~ & "Subsequent Reports" in Duplicate · '~ -L STATE OF ALASKA ~. API NUiVLF~CAL CODE ' .... j' 'C. ENG. OIL AND GAS CONSERVATION CO,~I~EE, , , 50-i33-20237 .... ~r'~ ~,~"'~;~ SUNNY NOTICES AND REPORTS ~ W~ (Do not use this fo~ for proposals ~ drill or to de~en ...... i'" ~ [~N~ , , . . . ,, W~LL ~ ....r'.. G20[" ~7 ~*M~ or o~'~o~ ~. U~~ O~ ~s~ ~*~S f. A~zss o~ o¢~.~o~ ~. ~ ~o, ~. O. Box 7-839, ~cbotase, AZaska 995Z0 S~O 24-33 o~ Sect~o~ 4, ~7~, ~9~, S~ & ~ ~, s~c., ~., ~,, ~,, (~0~o~ ~o~ C0NFER~' ' .... O~E~IVE) Sec. 33, TSN, :'RgW, SB & M 1~. ELEVATIONS (Show whether DF, RT, GE, etc. 12. P~T ~O. 164~ 6' GR 72-7 ~'~' Check Appropriate Box To I, nd',i,cate Nmture of N~>ti'ce, Re, ~ort, or Other Data NOTICE OF INTENTION TO : FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONS REPAIR ',','ELL CHANGE PLANS ~Other) SUBSEQUENT RIPOET OF: WATER SHUT-OFF J REPAIRINO W,LL J SHOOTING OR ACIDIZING J [ ABANDONMEN'T* (Otheri Spuc well , (NOT~: Report results of multipls completion om ~ell Completion or Reeompletion Report and Log form.) 15. DESCRIBEproposedPROPOSEDwork. OR CO.MPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting an}' Re. conversation between Mr. O. K. Gilbreth and Mr. Wesley R. Tinker III of September 22, 1972. Spudded subject well at 9:30 A,M. on September. 25, 1972. OCT 2- DIVISION OF OIL ANCHO'IA~ certify a '~ '~r oin )! ~'-- d rect SIGNED C~-. VJ CHATTERTON / TITLE District Superintendent DATE 9-- 29--72 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Approved Copy Returned Form REV. 9-30-6 9 Submit "Intentions" in Triplicate & "Subsequent l~eports" in Duplicate STATE O'F AI.ASKA OIL AND GAS CONSERVATIO,N COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APP-L1CATION'Fo~ P'EP~iT-L~' 'for such 'p~osal~) 5. AP1 N~CAL CODE 50-133-20-237 6. LEASE DESIGNATION A_ND SERIAL NO. A-028399 7. IF INDIAN, ALLOTTEE OR TRIBE NA2VI~ OIL ~. GAS [] WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT, FARNI OR LEASE NAME Standard Oil Company of California, WOI Swanson River 3. ADDRESS OF OPERATOR P. O. Box 7-839, Anchorage, Alaska 99510 4. LOCATION OF WEI~L 935' South & 3,065' West of the Northeast corner 9. WELL NO. SRU 24-33 10. FIELD A~D POOL, OR WILDCAT Swanson River At surface of Section 4; T7N, R9W, SB&M. Approx. BHL: 200' North & 3000' West of Southeast corner of Section 33, TSN, R9W, SB&M. (Well SCU 21-4 pad)', n. s~.c., T., R., M.. (BOTTOM OBJE~TIVE)A A Section ~, T8N, R9W, SB&M 13. ELEVATIONS (Show whether DF, RT, GR, etc. 12. PE'I~lVI~T NO. Approx. 165' gr, 179' KB 72-7 14. Check Appropriate Box To I,nd~cate Nature of N~tice, Re ~ort, or Other D~t~ NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI,ETE REPAIR WELL CHANGE PLANS ~ Other), ,. SUBSEQUENT REPORT OF: FRACTURE TREATMENT Z ALTERING CASING SHOOTING OR ACIDIZING ABANDON MEIqT$ (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETZD OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an)' proposed work. The following changes have been made in the drilling program: 1. Drive a 30" conductor to 80' +. . Cement 20" 94#/ft., H-40 casing at 3. Nipple up and test 20" - 2000 psig BOPE. 4. Drill ahead to 10-3/4" casing point. NOTE: This notice supplements Sundry Notice dated 4-10-72. The between casing string annulus at SCU 21-4 (11 3/4" x 7") was checked on 9-6-72 and found to have 30 psig pressure. Annulus was' ~led to 0 psig. A 20"-2000 psig BOPE stack has been included in the drilling program as a safety measure, SEP 2 2 1972 eer y - re~oi ~ d re? SIGNED C. ¥. TITLE DIVISION OF OIL AND GA3 . ! DISTRICT SUPERINTENDENT DATE, .9-~a/~72 (This space for Sta~filce u~e.) ~,,*'~' APPROVED BY / See Instructions On Reverse Side .o~'ra r--~ ~bmlt "Intentions" I~ Triplicate ~. 9-30~,7 ~ ~ "~u~quent ~e~" ~ ~uptj~te STATE O ~KA ~ ~U C'~ COD~ OIL AND GAS CONS[~VAT[ON CO~IWSE - ' ..................... ~ ~-- --- -- --- ~ ~. ~ ~u~'rt~ ~ s~ NO. SUNDRY NOTiCSS AND R~ORTS O~ 2. H~2,1E OF OPERATOK ~ ~~}'~5I OR ~L%S~ N~IE Standard 0il Company of California ~O7~ Swanson Ri~r . P. O. Box 7=839 AnehoraEe, Alas~ .... OF O~L '"" ~ 2&'33 t. ~ATIOK OF WZLL :~>lgl~ ...... i~'~D ~ND 1~'OOL, O1( WIDCAT ~'~935' SoUth and 3,065' West of Northeast c~rner~:~ Swanson R~v~r , , Section 4, T7N, R9W, SB & M (Well SCU 21-4 pad)' ~' u. s~c..~.. ~..~.. -- O~E~CiVE) Approx. BHL: 200' North and 3~000' West of South~. Section ·33, TSN, RPW, SB & M east corner of Section 33, TSN, RPW, SB. & M. 13. ~VATIONS IShow whe:her DF, HT, GE. etc. 12. PEa%liT . _ Apurox. 165' G%~ 179' KB -"" 72-7' " ~' Check Appropriate Box To Indicate Nature o{ Notice, Re to., or Off, er NOTIC~ OF INTENTION TO: ~- ' j' ~''''' ' C [U~SEQUENT REPORT OF ~gST WATE~ 8H['T~FF PCLL OR ALTER CASINO WATER SlIUT-OFF " ". REPAIRINO W~LL F~ACTL'HE TREAT MCLTIPLE COMPLETE FRA~L'~ TBEAT~ENT "~ ~ ALTERINO 8HOOT OR lClDg/ ABANDON* gHOOTINO O~ ACIDIZINO ~ZPAIR WELL CHANG~ PLANB (Other) (NOTE: Report r~sults of multiple completion on Well {O~her) Compl.tion or Recompletion ~eport and Lo~ form.) DESCRIBE PROPOSED OP. CO.%IPLETED OPERATIONS (Clearly state all pertinent detail~, and give pertinent dates, Including estimated date of starting any proPOsed work ....... .. ' ..... ~ ~., ~.~ ~./ The following plans have been changed: --'. ~:..; -~, ~) ~u~ ~ bottom ho~ ~o~tZo~ ~ ~o~m~'~4~='200=~ ~o~t~:"a~d ~."~000' ~..~ o~ the SE corner of Section 33; T8N, R9W, SB'j& M. Thisvloe~ti0n has been changed from 100' North and 3,200' West of the So~theast%c~r~er 6~.Section 33, T8H, R9W, SB & M, Slight adjustments in the directi0nal'"pPogram hhve; been made =o reflect this new bottom hole location. K" b :~- ~:~-'- ~ :Q.. -- :~ -" ~ ,:v 2) The ~s~ ~ro~ram nas ~ee~ rev~se4 ~s fo~o~s:.: 'i ~ ~''[~ ~' .. - . a) The 7" casing has been changed to 7-5/8'i-- and the" ':;:-casmng.. ... C' ' ~ 11,075') to the top of the H~lo~k [.(~:10,.5'38'). u. - - ' A~deta~ed drillin~ _pro~ram is attached. ., ~ //,. -~.;--~ [~IGNED~ ( /~//'~/ (-~4"~~"-~-TITLm District Superintendent ...... V.'J__Uha_t_~r3~an___i ' - The well will be completed with a S:l/~''' liner.· '.=:." ...." ~.i:: ~ o :;:.-..: ~ ::.: .:~ .¢~ rTM' ',.' ~ r ~ · ,,' :)~ -- .. . ~,, .,.= ~'] :', .~ ~: C . · 1 ~ '. DATE point Changed from T.D. (This tpace for State otlice usel _ _. TITLE See qnstructlons On Reverse Side DRILLING PROGRAM REVISED 4/5/72 TO REFLECT CHANGE OF 7-5/8'~ASING POINT FROM T.D. TO ABOVE THE HI POINT PROPOSAL FOR WELL OPERATIONS PRO 316 - 1 DRILLING PROGRAM FIELD: SWANSON RIVER PROPERTY AND WELL NO: SWANSON RIVER UNIT 24-33 SURFACE LOCATION: Approximately 935' South and 3,065' West of the Northeast corner of Section 4, T7N, R9W, SB & M. ~CU 21-4 pa~.. BOTTOM HOLE LOCATION: Target Base of Hemlock #10 sand. Location approximately 200' North and 3,000' West of Southeast corner of Section 33, T8N, R9W, SB & M. ELEVATION: Approximately 165' ground level, 179' KB BLOWOI~ PREVENTION CONSIDERATIONS: 1. Potential Problems: G.a.s: Gas sands may be jencountered at any depth below the shoe of the surface casing. No gas entries were reported while drilling Wells SCU 21-4, 34-33, 13-34 and SRU 14-33 with 95-97 pcf mud. Gas entries can be a problem on trips and bottoms up must be carefully watched. Care must also be exercised while drilling coal beds. If thick beds are penetrated, reduce the drilling rate and circulate bottoms to remove the gas. Lost Circulation: No lost circulation occurred while drilling Wells SCU 34-33, 21-4 and SRU 14-33. The above wells were drilled with 97-98 pcf mud. While shut-in after a Kick, lost circula- tion occurred at SCU 13-34 in the interval from 3,100' to 4,400'. The point of major loss at SCU 13-34 is believed to have been in the more permeable sands from 3,100' to 3,400'. This interval will be cased off while drilling SRU 24-33. While drilling the Hemlock&ands at SCU 42-5, lost circulation occurred with 98 pcf mud in the hole. At SCU 24-33 7-5/8" casinm will be set above the Hemlock and the interval penetrated with lower weight mud. Water Entries: A major water entry occurred while drilling well $CU 13-34 at 11,014' with 97-98 pcf mud. After the kick was controlled, the well was redrilled through the zone of entry with 98+ pcf mud with no probl, em. Drilling crews should be alert at all times for any indication of fluid entry. Precautions: Any kicks should be handled by our normal procedures. Drilling crews should be made aware of these methods. Care should be exercised at a~.times, but expecially not to hydrau- lic the formation and lose circulation while running in the hole nor swab the hole while pulling. Hole must be kept full at all times. PROPOSAL FOR WELL OPERATIONS PRO 316 - 1 DRILLING PROGRAM -2- SRU 24-33 April 5, 1972 2. Maximum Anticipated Formation Pressure: 4,900 psig. 3. Maximum Anticipated Surface Pressure: 2,500 psig. BLOWOUT PREVENTION EQUIPMENT: 1. As per" Operating Instructions D-IT" 2. Class III on the 10 3/4" and 7-5/8" casing (10" - 5,000 psig). See ,Well head and BOPE hookup on attached sheet. OBJECTIVES: Based on an estimated K.B. elevation of 179'. Hemlock Sands 1-5, 8, 9, and 10; #10 sand. Target base of Hemlock Markers Drilled Depth-ESt. Vertical Depth-Est. Sub-Sea Depth-Est. Fault - E 8,180' 8,179' -8,000' H - 1 10,538' 10,375' -10,200' H - 4 10,695' 10,559' -10,380' H - 8 (top) 10,725' 10,569' -10,390' H - 10 (top) 10,840' 10~669' -10,490' H - 10 (base) 10,975' .10,740' -10,561' T.D. 11,075' 10,840' L10,661' DRILLING PROGRAM Prior to spud, run Gyroscopic Survey in SCU 21-4. Also check 11 3/4" x 7" annulus for pressure. 1. Drive 18" conductor pipe to ~ 80'or as deep as possible during rig up. _ 2. Drill a 15" hole to 3,425'. Maintain drilling fluid as per the attached Drilling Fluid Program. Specify 75 pcf mud maximum. 3. Run 3,425' of, 10 3/4" O.D., 40.5#/ft., K-55, Buttress casing and cement as follows ( have stage collar on location in case lost circulation occurs while drilling the top hole and single stage cementing is therefore not feasible): a. Use differential fill-up Shoe and differential fill-up collar one joint up. b. Lock bottom five joints of casing including Mill collars. c. Centralize the casing above the shoe. Cement through the shoe in one stag~ as follows ( use bottom wiper plug): 1. Use 1,150 sacks of Class "G" cement premixed with 8% gel. Follow 1,150 sacks of gel cement with 40~ sacks of neat cement pre-mixed with 3/4% CFR-2 and treated with 3% calcium chloride. (total excess 29%) PROPOSAL FOR WELL OPERATIONS PRO 316 ' 1 DRILLING PROGRAM -3- SRU 24-33 April 5, 1972 Basis: Yield Class "G" - 1.15 ft3/sk Yield Class "G" + 8% gel - 1.89 ft3/sk 2. If cement returns are not received at the surface, do a top Job. Cut off 10 3/4", 40.5#/ft K-55 casing 36" below the top of the cellar (ground level) to allow the top flange of the tubing head to be above ground level after completion. ® Install. 10" - 5,000 psig 10 3/4" SOW casing head. Test welded lap to 2,500 psig. . Install class III 10" - 5,000# BOPE as per attachment. Test BOPE and Kill manifolds etc. to 2,500 psig with clear water per "Operating Instructions D-17". Drill out cement in the 10 3/4" casing with a 9 7/8" bit to within 10' of the shoe. Pressure test the 10 3/4" casing to not over 2,500 psig. If test is okay, drill out the shoe. . Drill a 9 7/8" hole to a vertical depth of 10,375', estimated'top of the Hemlock sands, as follows :- Follow mud specifications as on the attached mud program. b. Take single shot surveys from 300' to the estimated KOP a minimum of every 480'.. Should conditions warrant, reduce the survey interval to every 240' or less. Always take 'a survey on a dull bit. c. Beginning at approximately 7'~800', KOP, build 2-1/2°/100' hole to a maximum of 25°. Lead well for a right hand turn. Along course N8°E 'deviation is approximately 1.100' TarRet is the base of the Hemlock #10 sand at a location 200'N and ~,000' W of the southeast corner of Section 33; T8N, R9W. A final directional program will be furnished, Vertical depth of the target 'base H-10 sand; is +_. 10,740'. Drilled depth is approximately 10,975'. . At a vertical depth of 10,375', condition hole for logs. Take a 1/2 gallon sample of mud prior to pulling for logs. Run and tape the following Schlum- berger log: a. Dual Induction-Laterolog from drilled depth to the Shoe of the 10 3/4" casing. Use linear scale for the 2"-100' and logarithmic scale for the 5"-100'. b. Have 4-arm High Resolution Dipmeter on location. 10. Drill ahead and log as indicated by log run to set 7-5/8" c~sing shoe at the top of the Hemlock (H1). 11. Run 7~ casing and cement at the top of the Hemlock as follows: a. Bottom :3,238' (10,538' - 7,..300'). 33.7~P-110 Exl:rome Line Next 1,900% ~7,300% - 5,400') 33.7# N-80 Extreme line PROPOSAL FOR WELL OPERATIONS PRO 316 - 1 DRILLING PROGRAM -4- SRU 24-33 April 5, 1972 Next 2,000' (5,400' - 3,400') 29.~# N-80 Extreme Line Next 3,320' (3,400 - 80') 26.4# N-80 Extreme Line Top 80' (80' - surface) 33.7# N-80 Extreme Line Total 10,538' b. Run float shoe, float collar and stage collar at approximately 7,400'& 3600'. c. Have triplex shoe on location in case it is necessary to set 7-5/8" above the drilled depth. d. Centralized bottom 700' and above the stage collar. e. Cement in 2 stages with sufficient cement through the shoe to reach 8,700' and through the stage collars to reach 5200' and the surface. Do a top j. ob if .required. 12. Remove BOPE and land the 7-5/8" casing. Install 10" - 5,000# bottom flange x 6" - 5,000# top flange tubing head. Test secondary pack off to 5,000 psig. Install i0" - 5,000# BOPE and test to 2,500 psig. per "Operating Instructions D-17". 13. Drill out cement to below the stage collar and pressure test the 7-5/8" casing to 2,500 psig to ensure closure of stage collar. Clean out to within 10' of the 7-5/8" casing shoe. Pressure test 7-5/8" casing to 2,500 psig. 14. Run .Variable Density Cement Bond Log from the effective depth to above the top of the shoe job. Also log CBL from below, the-stage collar at 7,400' to above the top of the cement. 15. Based on CBL, test WSO above the Hemlock zone as required. 16. Condition mud weight to 74-76 pcf (provides a hydrostatic pressure of 5,300 - 5,425 psig at 10,300' vertical depth). 17. Drill 6-5/8" hole to 11,075' T.D. (Total Depth to be 100' below the base of the Hemlock #10 sand target). 18. Condition hole for logs. Take a 1/2 gallon sample of mud prior to pulling for logs. Run and tape the following Schlumberger logs: a. Dual Induction - Laterolog from T.D. to the shoe of the 7-5/8" casing. Run same scales as before. b. S.P. - BHC Sonic from T.D. to the shoe of the 7-5/8" casing. 19. Condition hole for 5-1/2", 20# N-80 Buttress liner. 20. Run 5-1/2" liner with Buttress and special clearance couplings and cement as follows: · a. Run float shoe and float collar. b. Allow for approximately 200' of special clearance couplings in the liner lap below liner hanger. c. Cement with sufficient class "G" cement with 3/4% CFR-2 to reach the top of the liner. Mix a heavy slurry (118-122 pcf) and displace slowly to avoid turbulent flow. d. Disconnect from liner hanger, pull up + 10' , close rams and downsqueeze liner lap. Backscuttle out excess cement from near the top of the hanger. PROPOSAL FOR WELL OPERATIONS PRO 316-1 DRILLING PROGRAM SRU 24-33 -5- April 5, 1972 21. After drilling out cement, run retrievable retainer t° near the top of the liner and pressure test theliner and liner lap. Squeeze lap if necessary. 22. Clean out inside 5-1/2" liner and run Schlumberger Variable Density Cement Bond log from T.D. to above top of liner hanger. .Test WSO's as required. 5-1/2" liner and 7-5/8" casing. Top completion fluid to 'be approximatel~'' ~000' above 5-1/2" liner top. Use + 10 bbls. of diesel as a spacer. 24. Jet perforate with centralized guns selected intervals for production. Leave blanks to ensure minimum segregation interval for packer setting of 10'. Run casing scraper and scrape the perforated interval. Perforate with 4 hyperjet holes per foot using 4" O.D. carrier gun. 25. Run and hydrotest to 5,000 psig approximately 10,300' of 3-1/2" O.D. 9.2# ft. Buttress tubing. Run 2-3/8" O.D. tubing and jewelry in 5-1/2" liner. Run gas lift mandrels at approximately 1,800', 3,300', 4,650' 5,800, 6,800', 7,625' and 8,300'. A detailed completion program will be furnished after the T.D. logs have · been run. 26. Remove BOPE and install X-mas tree. Test tree to 5,000 psig. Displace drilling fluid down the annulus and out the tubing with lease crude oil. 27. Set the packers and release the rig. Place well on production as directed by the Production Foreman. o/s W. R. TINKER III B. E. WONDZELL ~6LJ' DRILLING FLUID PROGRAM SRU 24-33 SWANSON RIVER UNIT SWANSON RIVER FIELD BASIC DRILLING FLUID SYSTEM Medium treated lignosulfonate mud. OPT//.~UM DRILLING FLUID PROPERTIES Mud Property ..(Ver ti ca 1...pep ths) 1 0 - 3.~425' 2 3 4 3,42,5.' r 6,000' .6.,0.00.'.--.!0,53~' ~~ weight - pcf Viscosity - sec/qt., API Fluid loss - CC, API Plastic Viscosity ~ CPS Yield Point - lb/100 ft2 Gel- lb/100 ft2 - 10 min PH Calcium- PPM Solids Content - % Vol. Diesel Content - % Vol. Max. 75 pcf 72-80 t~-60 7-10 10-20 5-10 10 max. 8.5-9.0 8-12 5-8 93-99 74-76 43.-48 43-47 7-i0 4-7 20-30 10-14 8-12 8-12 . 10 max. 0-5 ' 8.5-10 9.5 50 max. 50 max. 10-18 6-10 6-8 6-8 REMARKS' 1. Drill top hole to 3,425' ~ with salvaged mud, if available. Run centrifuge backwards to reduce mud weight as required. 2. Convert top hole mud to gel mud while drilling from 3,425' to 6,000' At 6,000', increase weight and have mud properties as listed in Column ~3 at 7,000'. Run centrifuge normally below 6,000'. 3. Use medium treated lignosulfonate mud below 6,000'. 4. Limit dry job to 20 sacks of barite or as directed by Drilling Foreman. 5. Maintain an adequate supply of lost circulation material at the rig. 6. Make a High Pressure - High Temperature Fluid Loss determination every third day. Make fluid loss tests at estimated bottom hole temperature of 170° F. 7. Maintain total hardness under 100 ppm and report all versenate titration as (ppm) CaCO3. 8. After cementing 5-1/2" liner and before perforating, spot on bottom 95 bbls. of oil base fluid. Fluid to have the following properties: Water Weight - pcf Viscosity - sec/qt., Fluid Loss - CC, API Gel Strength - lb/100 ft. 4-6% 75 45-55 0 7-12 · ,,~ 5pod _ J 9,.ood ! 09oo to 20 DAYS RIG RELEASE CONTRACTOR o. ,1 ...... 47 ....... _t.. ~: 0' 6' ~ /0' ~K -0~'~'~ 6'000~' $, ',~. U. P4-$5 ~'I~VAN SOA/ ~l V~R F/EL O PROPOSAL FOR WELL O',"ERATIONS PRO. 316-A {TO BE USED AS A GO-I II) · ' CASING P't 'JIREMENTS AND EOUIPMENT · . . WELL/LOCATION N . SRU 24-.33 FIELD_ Swanson River DATF A~ri! 5 1972 FOP`WARD BUYING NO eSTIMATED SPUD DATF TOTAL DEPTH 11,075 METHOD OF PRODUCI'ION FD3, o~__~L MAX.-ESTIMAI'ED SURF. PRESSURF- . .25Q.0_~_PSI ESTIMATED O/W/G llC0/ 200~ 385EOUIP. FOP, STF_AM_ No ' IN J: No PRODUCER . Yes CASING Gros~ F0otago APl Size Weight Grade 'Threads' Coupling Computer Design For: Conductor + 80' Heavy wall line pipe ' ' Surface 3425 ' 10-3/4" 40.5 K-55 Buttress .~equires'5 - 10-3/4" x 15" O.D. Lace over the collar centralizers and a2n~' 10-3/.~ stop ring~._ ~ake~ 10-3/4" Buttress flexiflow collar z£exi~£ow shoe an~ ~a~er ~.oc~. V/a~er Sking: Design based on mud density~ 98 lbs./cu, ff. and above max. surf. prossure -- Top 3400' 7-5/8" 26.4~ N-80 Extreme Line Next 2000' 7-5~8','. 29.7# N-80 Extreme Line Next 200,0 ' 7-5/8 33.7# N-80 Extreme Line Bottom 3600 ' 7-5/8" 33.7# P- 110 Extreme Line Total 11,000' Cemen~in~Acce~ories Baker 7-5/8" Extreme Line' model "G" shoe and model "G" Collar (Differential ~ill-up) · '' Maker 7-5/8" Extreme Line 33.7# N-80- Model "G" Stage.collar-and c'ementing plugs. L~ner 200' 5-1/2" 20# N-80 Buttress -- SPecial Clearance' -600' ' 5-1/2" ' 20# N-80 Buttress Regular Requires float ~h.~ landing collar and wiper ~lugs. . - Brown Oil To~l ~" - 20# x 7-5/8" 33.7# Boll Weevil hanger and' PP, L liner packe~..' . ~ CASING UNITiZED,f This Well !-I S~andard Desicja For Field [l Well No. r'l 25 - 9'7/8" x' 7-5/8" LOC Centralizers and 2 stop rings. HEAD: 5000 PSI CWP. BoH. ornConnl .. 10-.3/4" sow, Type KD Top Ccnn- 10" 5000# API RJ Fig__, 2 2 ~. ~;++i~ i ........... ~ .... V 1 a bull plug.and I sco~ch -~--~= ..................... uureweu ouuu~r -~ _a_v~ _ .................. . .. Screwed _ _oufb; TUBING HEAD__ TUBING . BoHom 250 Ne~ 400 ' :, 10,450 ' . .R.eq,~ires: 7 - 3-1/2" 1 - 2-3/8" 4- 2-3/8" · 5- 2-3/.8" 2 2-3/8" ~''~ '~' .1 -.~2-3/8" ~ -. ! - Otis 3- . . XMAS TREF_~-----' ~ . . Arm ;uomg Beans __ Casing Boahs i-:cadet 1. S,uf, mg Box PUNP: : -. 10" 5000 ._PSI CWP. Bo,,om Corm .... -5000# AP1 RJ Planed, Type 55L .... , ..... O'J ,~'~ Top Conn, 6" 5000# AP1 RJ Fi~. '__ W/Otis Control ,, 2 - 2" studded +'' Type Suspension Shaffer 55L, .3.-_1/.2" Buttress up & down,_ B~red for 3-1/2" cosasco plu_g~ -and for Otis control. . Feel AP! Size We;ghf Grade Threads Typ~ RODS: Grade ..... PUMPING UNIT. APl Size_ Engino 2-3/8" Baker Blast Joints 8rd EUE 2-3/8" 4.70# ' N-80 8rd EUE 3-1/2" -9.3# N-80 Buttress Camco M}~ mandrels and 7 R 20 gas lift valves x 5-1/2" 20# Baker model "F" wireline set packer x 5-1/2" 20# Brown HS-16-1 or Baker "FH" hydrauli Camco "C" sleeves or Otis "XA" Sleeves Otis "S" position nipples Camco "D" nipple" --- ":' '" ' Rema f~s {Cross-over% etc.) .-- packers 1/2" tubing removable ball valve ........... :...: ............. . :.:.. · ........ ::._ _ PSI CWP. Uwg. No--A~P'C-126-O & ~P-C-127-.~.A 'Type_ 1.- 2 ,, 5000# Willis T~Ipe I Flow Bean __,Type " . "__ Arm PS! CWP. Dwg. No__ __' Typo. Polis~,ed Eod 'x ' Lof "x. ' Type at ' oF_ "' ' o;- - "' ' o F. i -- ! -- Iype Max. Skoke .... "Sol at_ "Stroke an~ _Motor._.~ HP _ Remarks Prep,ared By ~'Zor B. E. Wondzell Field Foreman c~,~ b~ z~l~o~, 9/ro/z~ ~ Approvedby / ~~~~' Dist. Supt._ ~~~~t~ C. V. C~TTER'fON ' ' p,o.~,~..~ ~,,.o.~, J : I 1 i ' ii :. i . - . t · , · . . · · · .- · t ,. .;~.;.:,': ,...... . .. .,,,.. . . ,--.,,, ~ ,.' !/,' .. , , · ,~ , . : . ,l.,?. ;. "" "' "'" '" .......... '""'""' " '"' ~,,.~ ~.,. :" '- :"~t ;....~:.' · . .' .; ..: ~ ,. ,:/. :.,:';'. ,-. , .;., .~.,.-;'.,,; .. ,ff ,;,.,,. ~ ". o,. .. · .. .. · STANDARD 0IL CO~; ~','~' OF CALIFORNIA. WESTERN ¢,PLRAi~IONS, INC A,I. dT'&-R/.~Z ~/~ ~'OR 7'~'A~/C~q~- ,D ~HRIS~?MIlS TREE IIV,.qZ34L L I~ T/ON G~VAtlSON RI V£R £1£~ ~ ~ ,dZ,ZSR',4 ' -j!i !:i. ....... .['.d~ , c.- /. z. - ~ . Iribri~ t7, .StIedir. d Ol I Co. ~tNe. 72-7 ~ 0tt (Wlpm~ M CltlMrala P. O. Blt ?-ll~ SBMo llll i --ill# Id ~ ~ll'll~l[ i:ln ll~ ~I~. A dl~lml ~ Is llcilM. A 11111~ illrlalli':$ lelltll lililf Ii 'llqulrld llrl~r fa 1tm ,~d rd afl i i llg' I~, the ~ at ~lll cr lb~, pteell gl:iq) thls office .. STATE OF ALASKA APPLICAtiON FOR PERM!1' 1'O DRILL, DEEPEN, OR OiL AND GAS CONSER\/ATtON ,COMM1TTE DEEPEN [] P 2. NALiE OF OPEH. ATDR 8tapAard 051 Company of Ca2±£ornSa 5. P.0. Box 7-839, Anchorage, Alaska LOCA'rlo× or ',VEL~.. .~t.,,~e 935' South and. 3,06,5' West of No~thea~ Section 4; T-7-N;' R-9-W; SB&M (Well SCU 21-4 Pad) ._- At p,-opo~a ~:o~. ~.o=~ Approx. 100' North and 3200' West of Soutbe~'t Corner of Section 33: T-8-Ni R-9-W: SB&M 13, DIST.AI','CE IN MILES AND DIRECTW)N F.~.OM NEAREST TOWN OR POST OFFIC]~' Approximately 17 miles from Kenai~ Alaska 6. L~ASE DI~;IGNA'.m. ON ~d'fD .~.~-tI~L Nc~. A-028399 7. IF INDIAN, A~E Swanson River Unit 9. WELL SRU 24-33 !fi. FIELD AND }'(iDb. OR WIL!JCA. T Swanson River I ll..SEC.. T.. R.. M., ~BOR~FO.M ~OL~ O~CTn'~, Section 33; T-8-iq; R-9-W; SB & M i. Tw~ENation Wid~,~¢ty ~,,d,o,.- No. SL 6205862 15. DISTANCE FRO,Vi PHC, POSED' PROPERTY OR I:I~;ASE LINE, FT. ,A,~o ~o ~ ..... t ~,~. ~t. ~ ~,,y) Unitized lg.' DiSTA. NCE FROM PROPOSED ~CATION* TO NEAREST ~VELL DRILLING, COMPLETED. OR APPLIED FOE. FT. __&P~ox, 1:050" from 21-4 * ~1. ELEVATIONS {Show whether DF, RT, CR, etc.~ i_6. NO. OF ACRES IN LEASE 1760 ,AC. 0~5' $150,000 17. NO. ACRES' ASSIGNED TO q.w-IiS WELL 40 * 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK !,VILL START' c~,'~'~ .... '--- Y'T;;~ ....... C~Y .... GRADE K-55 o.¢ We propose to drill SRU 24-3.3 a.s per attached program. Section 2060 (1)(B) Reason for deviation. To avoid disturbing ad~o~,_~a~0~r~ ~:,e~t~ures k tr:~ ~ i ~! in the Kenai Moose Range. ~ ~ k.~: [J ~"' "~""~ *Well 1.ocation has been approved by Division of Oil and Gas. F'~7~ i ST, [~/d ' DIVISION OF OIL ~,; ....... ~'- ~ ABO~ SPA~ DB~IBE ~OPOS}~ PP.~R~: If p~ml Is to dee~m or plug ~ck, give ~ on present pmduaive zone and p~ new produ~ive ~ne. If propel ts %0 drill or d~n d~ect .oi~lly, give pert~en~ ~ on subsu~a~ ~%~ ~d meas~d ~d ~ue recital ~ep~s. Give b!ovmout prevan~er program. (This space fo/' STate ofhce use} ISAMPLF~ AND CORE CHIPS YES RECTIONAL SURVEY RI~PQUI'!~,_ETO YF~ NO 24 I hereby cert~y S~G~ ' ' ~NSMI ~AL LETTER A.P.L ~C~ CODE District Superintend~ . . P~OPOSAL FOR WELL OI~TIONS PRO 316-1 DRILLING PROGRAM swANSoN RIVER PRO~RT~ AND UELL NO: SWANSON RIVER UNIT 24-33 SURFACE LOCATION: Approximately 935' South and 3,06'5' West of the Northeast corner of Section 4; T-7-N; R-9-W; SB&M BOTTOi~I I{OLE LOCATION: Target Ease of Hemlock ~.~!0 sand. Location approximately · 100' North and 3,200' West of Southeast corner of · Section 33; T-8-N; R-9-W; SB&/t ; .. -.-;'~. ~ATION: Approx~tely '~65!- ~Und level, 179' ~ ~.,::.,.... -..:. :::.:.;.~:?...-..'.~.:..:._ ~-." ..-_ . .::..~;."- . ).,::.~..,,::.::,:.;:.:,.',...~.., '-(~ · . 'B~O~ P~~ION CONSIDE~TIONS: .~.-.... '-..-... --, ' ~encOUntere.d~ at.'.a~'d~th bel~ the shoe . of '.. ~, ":-'*,..;.. · the surface casing, NOgas entries .were reported while .... '::...-:.-."J:.~:'~t :::.,?' ~.'...:. "drilli~ Wells S~'21-4, 34-33,~. 13-34. and SRU 14-33 with '.' ~-- ' ' ~ ".'-~5;"~7 pcf. mud....GaS,-e-t~ies, can be..a :.problem.,on trips an4 ~' .' .. . ~enet.rated, reduce the drilling~ rate and circulate bottoms .- -.- -.." '.:- .':'-'- . m~ ~ remove the gas.,. ':':: . ~ . . .... . . ... ' ' .... ' .. ~eSt Cir ulatto and ':~. '.. Nater Entries: No lost circulation)or water.entries occurred wh~le . drilling Wells SCU 34-33, 21-4' and SRU 14-33. The above wells Nere drilled with 97-98 pcf mud. A'major water ent~ occurred " . '_ Nhil'e drilling Well SCU 13-34 at 11,014' with 97-98 pcf mud. - . " .It was necessa~ to shut Well S~ 13-34 in. While shut-in lost -- · :. ~rculation occurred in sand inte~als from 3,100' to 4 400' - . - . ~,.... '... - ~ ' .. Well SCU 13-34 was subsequently redrilled through the zone ---- ~f water ent~ with 9~ pcf mud with no problem. .... "' ~recaut~ons: A~ kicks shouid~.be ha~dled' by :our no~al procedures. ' -- '~'ri[ling crews should be made. aware, of these methods. Care ~-- ' ~should be exercised at all times,.' but e~ecially not to hydrau- ..~ ~. ~C the fo~ation and lose circulation while ~nning in the - - - hole nor ~ab the hole while pulling,. Hole must be kept full · - . at 'all times. . - . .. '. 3' M~tmum Anticipated Surface Pressure:... 2,500 )s · .... .. . ~ ' ' ~' ~ ~ ~'~j. ' ' ' " g,f.' 2 . '. :. , . .... " <" : DIVISION 0~: 'O:i ,':'.b:-:) ,.[. .. .,' . . . ,- _.... :-. · , ,~..'~ ~ . ..~ - - ' : ' ' '" '" ' ' ' A ~'J?:~,4('~ [~' '.:..,. .:"...).. .... :. :'.) .- .... '.. ., . .. , :,...' . . ...- . . , . :.., .... . ,.... . . . ... . . . .. , .- . . - . .'.- , .. . ~, . . - ..... · -' ";" Vrop°sal For Well ( ;rations PRO 316-1 - - '"' Drilling Program -2-' "~'' "'- ":.'-' : '.ii'):.":./ :. -' BL(I~OUT PREVENTION EqDTP}fl~NT: -¢ - : -.~ - i " ' .; 1~ As per "Operating Instructions . . , January, 24, 1972 Class II! on the 10 3/6" and 7" casing (10"-5,000 pstg). See Well head & BOPE hookup on attached figure 13. · OBJE~!J~p: Based-on an estimated K.B. elevation of 179' tlemlock Sands 1-5, 8, 9. and 10; Ta_r.~.e.~ .~..a. se of Hemlock ~10 sand. -: Harker~ Drilled Depth Vertical Depth Sub-Sea Depth (Estimated) (Estimated) . (Estimated) :'.:.!'.i.:.::...-'~' ' Fault E ' . .... ' 8'180' ...!"."-: .'/" '8,179 '~ ' 08,000 ::-~!'?:i"::':': ""H 4 '"'i. :'"/:..:~'i'!':: 10,695. :.::"":':::'.:.: ''/:':::' 10,614' ,."~::.ff:'."',.:ff..ff, ff · r'~'"-10,235' -: - - 10,566'"' ' . ' ~ o10,385' ... ' ' 2 I' ' ,' '"::~' · ~.:"... - H-- 8'(top) .'? ': ':':-'/.10 , 7 5. :,i ,..':~::: 10,589 ' - - o10,410' · S - 10... (cop) '": :.:;:-.:. 10,840 :. ::!i ' :. L '. : ./. ' 10,699' ::"':' ' T.D, · ' ' .... , ' - 8 " ' ~- .. '..".':.....~.-:'!." 10,945!'..:..:' 10,799. :' ""' ..:". ":. '~' ~':' ':' :.'".:<: ... "': ':" ..... '-~.: ': ..... '.':, ,~l.~"I~.' ·-I.L..-':~! .. :.:~...l~, -. : ". '. " .. ' .... :':':.":::.";;~".'~:' :.'i'~.:'':.':'''i.<:,''': '~ ';/::' : : : :' " <? .:.' i': .-: ..:/:-"':.. ,.. .: .::.<!....:,: .:'.:..'"......,.:i:'.,.._. ' ,'., ':. : '.-,.-',. "" ;-.' .-.:.:'..'.'?.':".-';: :..-. " -..f': -- , .... ' DWelt .: "-'~ :...,:... ::..::::: . /: ~... :. :~...'.-.: .......... ..:.:.. . .....; . . : · .. - ..:: . . - . . . ..... - ...... ~rtor to spud, run CTrOSCOpiC survey in SCl' 21~t, '~lso check-11 3/6" x 7" annulus :' for pressure. · . . . , .... l. Drive 18" conductor pipe to · 80 or as deep as possible.during rig up. '- 2' Drill a 15" hole to 3,.425' Maintain drilling fluid as per the attached ' Drilling Fluid Program. Specify. 75'pcf mud maximum. . .. .. 3. Run 3,425' of, 10 3/4" O.D.,. 40.5~/ft,.'K-55, Buttress casing and cemen~ as folla~s ( have stage collar on loCation in case lost circulation occurs while drilling the top hole and single stage cementing is therefore not --'~eastble): '"- ~" ~-: ! - . . - · .:.. .. - .:" .......... ~,'::::'U~e differential fill-up-shoe and differential fill-up collar one .. .- .b Joint up. ..., , Lock bottom five joints of. casing fncluding }fill collars. " :. .' c.' Centralize the casing above the shoe. ,, d. Cement through the shoe in one stage as follows ( use bottom wiper · .. - ...~.plug): - -- 1, Use 1,150 sacks (35% excesS) of class: "G" cement premtxed with 87. gel. Follow 1,150 sacks of gel cement with 400 - sacks of neat cement pre-mixed wi.th 3/4% CFR-2. and treated" with .3% calcium chloride. (total excess 27%) - · .. -.- Basis: Yield Class "C" = 1.15 ft3/sk Yield Class "G" + 8% gel - 1.89 ft3/sk' Proposal For Well Operations PRO 316,1 "- -:.: · Drilling Program .;.-3''-" '--" - - '" . 3anuary 2t~, 197:2 .- 2, If~ cenent returns ar~ not-received at the surface, do a top . . . &. Cut off 10 3/4", ~.5~/ft K-55 casing 36" bel~ the t~ of the cellar (ground level) to all~ the t~ fla~e of the tubing head to be above ground level after collation.' 5. Install 10"-5,000 psig 10 3/4" SOW cas'in~ head. Test welded lap to 2,500 psig. 6. Install class III 10"-5,000f/ BOPE as per attached figure 13. Test ~PE and Kill manifolds etc. to 2,500 psig with Clear water per ... : '.. "Operating Instructions D-17". ' - . .,~ ?;i'.;.'Drtll out cement in the lO'3/4"::casingl/~ith-a 9 7/8" bit to'..%rithin ' ' ':'. 'i.-:"lOT of 'the shoe. -Pressure test":the 10::3/4'' casin~ to not over 2,500" ,. '~ .'ii.i-'"i<psig-' If test ts okay, drtll'.,out~"the, shoe -;. . .. . - .- ........ .. . - . ..: ....... -... ...; ..'.- .... , . :-..... ::- .; -.,. ~ ,/ i . '. ' "-'* * *'' *"' ! · ..-~ ~ ...... :1.8.*Drill a'9 7/8" hole to'10,945.' :: .... ~ .,'-.,." ". . ~.....;...~. F°llo~' mud' specifications" as."~ ned.' .,on',' the attached mud program. Take single shot surveys from 300~.:?~to '8,000~, KOP~ a minimum of ~:i*..;.~:i~:??.' ever~ 480', Should conditions warrant .. reduce survey interval to every 240. ' 'or less.: .~. Always i. take ;a:~: sUrveY On. a dull bit. - .' ":".!'.(C'"il.-:::Be~imai~ at approximately ,000., ,....KOr, 'bUild 2 1/2:'/I00 hole angle to a maximum of 25'. ConSider. 'leading veil. AlOng course -i..i:i!.~i'i:'/" 1t 8°, W deviation is approximately. 1,'050'. Target is the base of :'":';'-"' ". the Hemlock ~/10 sand at a 'location.:-100' '.N and 3,200' W of the .-.:.-.., ' . : .'. G.:.' Southeast corner of Section 331:T-8-N; "R-9-Wi SB&/t. I final -; -- - .-" .,-":.directional survey will be fUrnished.' Vertical depth at the .. ',. ~arget is 10,764'. Sub-sea depth .i...S..:.~. i_0__~585'. 9.- At T.D. condition hole for final.'.lo§s.-''Take a 112 gallon sample of mud prior to pullin~ for logs.'-.: Run~ and tape the following Schlumberger logs. ' ~ " ' '..i:i. :'4,-":? ~ ' a. Dual Induction - Laterolog'from T.D, to the shoe of the 10' 3/4" . " '"-.. casing. Use linear scale for the: 2,'-100' and logarithmic scale ' ,. for the 5"=100'. ' :.:: ..... ~ ..- .... b. '~' SP - Bottom hole compensated'Sonic from.T.D, to 'the shoe of the -' '- " .... " 10 3/4" casing. · - e, Four arm high resolution dtpmeter from T'D. to the shoe of the . 10 3/4" casin~. :.,. ,..~. ~i..:..:... .- --. .- - . ... . ;10- '.Run 7" casin§ as follows.: -- "'-' : :......'. · : . . . ; a" Bottom 2,945' (10,945'-8,000')29# P-Il0 ~8i~-LT &C i'ncludinE Marker ~ . - .. Joint ~ 10.' long. ' - Hext 900' (8,000'. - 7,100'). '26#. P-110 .8R Next 2,000' (7,100'-5,I00') 26# N-80 8R LT llext 5,020' (5 100'-80') 23~/ N-80 Buttress~ i!j.i. '. 80' (80'-surface)29~ N-80 Buttress -~ ·Total i0,945' . ,'~ ..,,. : , . . ,..: . :, . . ,. . · . 'prOPosal For Well O~erations PRO 316-1 :'...:: ?' . Drilling Program .: .-.....:..--~ ~ii':il;i.ii~!i~ . .- ;% bo RUn 7" Cloat shoe, float 'collar and. stage cementing collar at .. approximately 7,500' (determine after log. run). '-' Co Centralize bottom 700' and above stage collar. . .-...> .'~: 'd. Run marker joint near the top of the Hemlock. e, Cement in 2 stages as follows (use bottom wiper plug): 3anuary 24, 1972 ...... 1. Through the shoe with' sufficient cement pre-mixed with 3/4% CFR-2 to reach 8,700' (510 sacks of class "G" cement - no " excess) 2. ThrouEh. the staEe collar with sufficient cement to reach -.- 5,200' (520 sacks of class "G" cement - no excess). ll.i Remove BOPE and land 7" casing?c: lnstali'lO,,.5,000# bottom, flange x~-6"'5,000#'".;'.- : ~ ~.. -.'!"-- tOp flange tubing head.· . Test secondary~pack off to 5,000 psig. ' " ~.'"; "' 8,. J - , .-. .-..:~....10 5,000~ BOPE and test to 2' 500 si ' ' a · ' · . ~...-...::.. :.~. .. .. .. .~, . p ..g.per Oper ting Instructions D-17" -.I .' Drzll out cement to below stage collar..' at ;. i 7,~00-~ 'and pressure tes~ ' ~:'..;;..;7~ castn~ to 2,500 psig 'to ensure.closUre, of' stage collar. '"' 13? :ciean 'out cement to b rye' sands. Run Gatma Ray - ~eutron .';!~:~.i. collar' log ~ 1,O00'~ .,from.. the effective depth t.o above the top of the -)'~ '-"-.";.. "llemlOck .zone. .Run varlable.density-.CBL..fro~ the effective depth to ..-;...:. ['..i~.;:~ :above the top of the shoe'cement jOb-'.?~>LOg variable density. CBL from -'.~ -_ ~":'.~.. belov the stage collar at i 7, 500 '-":.'to above the top of the cement. i~'I. ?fiL.:'Run cemen~ quality curve with. CBL. i':...-~!.i~i -~ 14' 'Based' on CBL, test WSO above Hemlock~.-zone:;tf required;. -15. .Jet perforate with centralized guns':, selected intervals for production. ... Leave blanks to ensure minimum .'segregation interval for paCker setting- of 10'. Run casing scraper and scrape.the'perforated interval. Set · izeline packer above lower most. productive sand. -- _: _..:. 16.' Run and hydro,est to 5,000 pstg.approxtmately 10'800' of .2 7/8" O.D. ... 6.5~/ft EUE tubing with je~.~elry and, hydraulic packers. Run gas lift .. :-.: mandrels at approximately 1,800.', 3,300', 4,650'.,' $,800', 6,800', · '."~ '.-:'.'.' 7,625' and 8,300". A detailed' completion program will be furnished -"-...'c.'~;;'~;. after the T. D. logs have 'been run.. ~7*...:_Remove BOPE and install X-mas tree.' TeSt tree tO' $,000 psig. Displace · ' drilling fluid down the annulus and out the tubing with lease crude - *":".~.. oil. ..:., . . · 18. Set the packers and release the rig-::; Place well on production as directed by the Production Foreman. . .¢ ]~AS~C DRI'LL17~ FLID~D S~STEM - Medium treated lignosulfonate mud. . · OPTiMO!.! DRTLLINC- FLUID PROPERT.TES . -- . .. - -_-'~ANSON RIVER FIELD Mud Property (Vertical. Depths) 3,4.-25' .3~,425' - 6,000' 6,000' - T.D. * .. ..... l/eight - pcf -.-':['"' ' . 72-80 93-99 [ :.['. Fluid 'loss - CC, APl "::" ::~i.~ mUd with~ gel and 7-10 /+-7 Plastic Viscositny - CP$2."(~;'~i!i.-~:~ cellex.~ as.:..requtred 10.-20 20-30 '.- Gel- lb/100 ft - 10 mtn":.~ 10 ~. IO ~..'.-'.~':~' -." 50 . Solids Content - Z Vol; . . ~X2 ..' ..... Diesel Content - ~ Vol .~8 _?...~.:: ...... ,..,, ... :.,;:[:'~, ". - .' [:,.: ,':~":,.".. .,'~7 ' .... .: . ._ . . . ,::,,,;,). ,~._' :::-.~: .... .. - .... . . .. J;:."L'[::' "/?'?'".'"~: "' ' ...... ' ..... :::-..;:/: ~'. ,:.. ',.,. : ;. '[ ... . .' .- . [ . - . :.[.': ... . . ' . "' ' '. ': "I,-..".~il1 t~ hole to 3,425~-i with.:': ;ed md, if available, Run - .. ' · ,, .-.: .; [, .... '-:.:... :...centrifuge bac~ards ~o reduce mUd::veight as required, .. . [-' .. '... '"'~ ----:'.-:'[ l, C°nver~ t~ hole ~fl to gel ile drtilt~ from 3,425" to 6,000', ~ '"":.. ' At 6,000~, increase ~eight ~d have mud properties as listed fn right · ..~. - .'.-: -' h~d col~n aC 7,000~. ~un centrifuge nomatly, bel~ 6,000~. .., .' .. ..:,~.. -- ... '....".~.' 3, Use. medi~ treated'.lt~osulfonate ~d bel~ 6,000~. '-. '.' . '- -- .: . . . "'""~' " /~'.::: ~, L~Xt d~ ~°b to 20 sac~ of barite, or a~ directed by Drilling Forem~, . .~(:~ -. :: .:-. [::: :: "-"/~: S. ~tntain an adequate ,~plyOf?lost circulation material at the rig. , .,. :, . /. ~' ': . . -.; . . . .· . . . "-' ::."" ~. .~e a High Pressure' - ~gh T~erature Fluid Loss dete~ination " '. "~ eve~ third, day. ~e flui.d loss tests .at esti~ted .bottom hole ":..".-/~-'... . .- ?.~..t~erature. of 170° F. ;; ~. -.-.. :.. . . _ .. - · .... , :.-.. ~, ~intain total hardness under' 100 ppm and r~.ort all versenate , ...:, ..,, ~ . .',.,'- ,::....::-_ titration as (ppm) Cat03* " , ;. "[,'. ; .. ' ,, ',[' . ~ '. . .. . : . ~' .:." '~'~, Bel~ 8,000' (vertical d~th)'.' ke~ mud ~eight be~een 98 ~d 99 pc~, . c. . ..... ~' . · : ':~" "'.~"'". .... . :' " ' ." .. ' ' ..- . ' ~.~=~'t' -:.. .. ._ . . . . . . . . . -. . ·:. .. . . "' t : ' ''-". , , ' . -. . . : .. . . -. ,.. . . · . , . ...... =' .... """'"' "~ ' "~' ":-:"' '~: "::i:/--:' " ":~' .. .. · ..":!:'~.~.:.:,:.i;,:.'..:~:::" '"-I :-':': :" '" ,"':'""- "-":":'" ' -.:' ""' :-"'" ' '! : "'"'"' " ' '" ": . . :~ ' < ' ',~sm'¢",'s~'l~-""~n~"~ . -~ , . ' ,d' ...- . .. · .. :, ~ . :- . ... "" "' ' :'"' '¢ ' t ' ' ' " ' · ' .: -. ' .... :. '"' · * t4 ;.-'". - *' - ~ '. -"- / "..i4 ' ' ' ' ' ,. - '". 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": _. ,... :.--',,=---:::'"....:;. ':-';x--.,"' '.. ..~. "..":~...-"' .'.: ":,-...i.~:'h-I~: ~ -...--:.-. .:...-.- x ..:.i.- t (-.. '" :'"' -' .-'.! ' "' '. I - !4~,~ ~.-~'~,.~1~.~ : " .... ' '";' ' ''. ' "',"' ' ':" ' '! " · ~1- ' ' .... !~---,"~--,-------~T~,----------T--~--~ ::". :---:-,1: -II\~_ J ..... , ..... ~. : ~="., .. '-' '.~'. f ., ' . ~*..' ~.. ,' 4,' .t. ',' "' ; ":~.'~ -~t'::ili 'i-"~" '~'C!'77 ' :. ' ... I '. =, ' . . :_ -'. ~' '.'.:./ · ' '. · -'. .... ~ -"!. ; ' - I .... · I " .'"'" .... ._ :.t:.":. ' -:'." "': ", ""-.-I'.: ' ' '. '"~ ' T ' .' - ' · . · . . . · .. ..:. .~'-. . . · . ... .- . f...;, · . . . . . ..... ~ .... ~ · . · '.'.':t '.'? ': ' '. '.. . ' '~ t %.. / ...... ~,,'~,'~.~'~= ~'"~',"~ ~'~:~,D. ~-:.~"~"' - .... - - ~ , · ' , ' --'-- .' ' . ~ - . ' , ~.'~.~*-~7~ *~ ,"7" · - · I' 1' -' ' ....-:' ! .,"' . ' . . '. . -! I - · .... .; ...' ' ' '."'...- ' '. . : .. I' ' .' . . ' ...-.- !-. ~ .... ,, :"..:'.~i'.- : ~'~ ' '~I I' ~o '!'.'"'." I ,, 0 " , " .I. · · i". ..- 'i ; ~ -:", ':,~ ,";-' .. :'..: '"'l."-: --~ -' t.'...'_._-. - -_ , , ...'.- .. : .- .. ~. · - i *~4 = · / .....', i · . ! · i' .:..:.. ~ -',1,'4 "' ' ' . oF 1' I " ":'?"i.' \ " i STANDARD OIL CO CALIF WO' ; .... .'' "-'.'/. ".'.. ..--.....-~' - OP]:.;~ATO~ - .,,,, I. . . s ~' SRU 24-33 LOCATION "-i .~, I :- '- . ' i SWANSON IVER FIELD " " ' '-' '' L.-;, ''~ · , KENAI ALASK, '"" ' "' '7' :" !--"--'--~ Date: January 1972 · "' ! I t. ~cale. None · i o Yes Nn Remar~t 1. Is wel"l to be 'located in a defined ~oo~ ................. t " i 2. Do statewide rules apply ....................... ~, 3. Is a register*d, survey plat attached . . . . . : ........... . , · · ty 4. Is well located proper alstance from proper line ............ Is well located proper dista~:e from other wells ............ 6 Is su¢~i¢~uni, undedicated acreage available in this pool ........ ~< 7. Is well to be deviated ......................... x~y~ 8. Is operator the only affected party ...................... ~ r 9.: Can.::pemtt .... be approved before ten-day wait .: :..:: ::::, ~ .; ~:~.:.., 10~ Does operator, have a bond in force .................. 1'~ ~ ls~ conducto~ string provided ...................... :/~) ---- i-~:. Is"enough cement used to circulate on conductor and surface . . . 13. wi1't cement tie i~ sur~a~;~,- and intermediate or production strings l!~ Wi!' :.~ent cover all possible productive horizons ............ I:5. Will surface casin, cover all fresh water zones ............ ~ ,. : Will surface csg. interna'; :~"~'~:t equal .5 psi/f!~ to next string .... - 17. Will all casing give adequate safety in collapse and tension ...... lq. Does BOPE have sufficient pressu~- ra*ing ........... ·