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Home My WebLink About159-014& L0C_%TION CLE.~ R~ ~CE Sta~a cf Alaska ALAS~ 0iL a GAS C-'~SERFATION COMMISSION .Aev'Lew ~ .... ~--e well =:~o, an~-¢ommen: on pluqcj~_ng, well hea~ s=a:us, an~ !o~a=i:n clearance - :rcvi~e loc. :lear. : -- Conclusions: Core ' ~ - ~ro o -o 7 !~~ tc')~o,~-Ol .... " "STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP/ETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: SUSPENDED: ABANDONED: X SERVICE: 2. Name of Operator 7. Permit Number Unocal Oil Company of California (UNOCAL) 59/14/300-148 I 3. Address 8. APl Number P. O. Box 196247, Anchorage, Ak 99519 50- 133-10109-00 4. Location of well at surface ~,,tlll,'l~ON~ " 9. Unit or Lease Name 1,000' FNL, 1,170 FEL, Sec. 4, T7N, R9W, SM ~ ~' Soldotna Creek Unit AtTop Producing Interval '~~;~ ~ 10. Well Number SAME~ [ SCU #341-4 At Total Depth 11. Field and Pool SAME 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Swanson River Field/Hemlock and Tyonek 180' KBI A-28997 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore i 16. No. of Completions 12/31/59 3/20/60 7/25/00I NA feet MSLI 1 11,315'MD/11,315'TVD 10,192'MD/10,192'TVD Yes: No: X NA feet MD NA 22. Type Electric or Other Logs Run CBL/GR/CCL ran from 10,190' to 8,000'. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 22" 0 22' To surf 0 13-3/8" 54.50# J-55 0 3000' 17-1/2" 2200 sx 0 7" 23-29# N-80 / P- 110 0 10992' 9-7/8" 1692 sx 0 '"24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 10207 -10225' 7" Baker SABL @ 10202 10147'-10167' MD & 10177' - 10184' MD 6 spf, 0.34" dia hole 7" Baker Mod"F" @ 10485' 10147'-10167' TVD & 10177'- 10184' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED cement retainer @ 10192' cmt plug 10197' - 10585' 269 sx class "G" (50 bbls) mixed to 15.8 ppg. Squeezed 263 sx (49 bbls) of of 15.8 #/gal below cement retainer. 27. PRODUCTION TEST Date First ProductiOn I Method of Operation (Flowing, gas lift, etc.) I flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE [ GAS-OIL RATIO I TEST PERIOD => Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) =ress. 24-HOUR RATE => 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None , 000 0 R IGINAL A~obor~§e Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 31. LIST OF ATTACHMENTS Wellbore schematic, Summary of Daily Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signe .,,.v_ ~ ....... Title___DrillinqManaqer Date..~'"~ ~")_ Form 10-407 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Perforation Data Sheet After Abandonment (7-25-00) SCU 341-4 APl No. 50-133-10109-00 zon'e ,_ "" Measured Depth (feet) True Verl;.!cal Deptl~ (feet) , ' "Status G-2 10147 - 10167 10147 - 10167 Open ,L S-2 10177- 10184 10177- 10184 Open H-1 10230 - 10265 " 10230 - i'0265 Abandon'ned H-2' 10275 - 10285 10275 - 10285 "' Aband°ned ...... H-3/4/5 10310 - 10394 10310 - 10394 Abandoned H-8 10409 - 10478 10409 - 10478 Abandoned H-10 10508 - 10585 10508 - 10585 Abandoned Cement retainer set at 10192' and 263 sx (49 bbls) of 15.8 ppg cement squeezed below retainer. Description of Activities SCU 341-4 Abandonment Summary Operations commenced on SCU 341-4 on 13 July 2000. Alaska Pipe Recovery Service rigged up and cut the 4-1/2" tubing at 10,195. While pulling out of the hole with the chemical cutter the wireline tools became stuck at 3,345' and left the tools in the hole. Attempts were made to fish out the chemical cutter but failed. Moved in and rigged up Inlet Drilling Rig CC #1. Tested the BOPE and screwed into the hanger. Made a blind back off on the 4-1/2" tubing at 9864. Did not recover the wireline chemical cutter. Ran in the hole with slick line to 10,202' with no obstructions. Ran 4-1/2" tubing and made a chemical cut at 9,950'. Milled over packer Baker SB-3 packer at 9,956'. Fished out packer and tail assembly to 10,202'. Ran mill and clean out assembly to 10,199'. Rigged up and ran Schlumberger CBL/GR/CCI from 10,190 to 8,000. Set cement retainer at 10,192'. Established an injection rate of 1690 psi at 5 BPM. Batch mixed and pumped 269 sx (50 bbls) of Class G cement mixed at 15.8 ppg. Squeezed 263 sx (49 bbls) of 15.8 ppg below cement retainer. Final pump pressure 2000 psi. Prior to stinging out of retainer pressure was holding at 1500 psi. Reversed out 1 bbl of cement. The original plan was to abandon the well with coiled tubing. The decision to request a change of plans was based on the loss circulation problems using coiled tubing on well SCU 323-9. An E- Mail from Blair Wondzell (AOGCC dated 21 June 2000) approved the abandonment using the rig and squeezing below the cement retainer. (See attached Abandonment Schematic) Unocal Alaska Drilling Drilling Summary Report SCU #341-4 Well Abandonment 7/13/00 to 7/25/00 ,,..'.,(~b 2.. 0 · Anchora§e 7/13/00 7/14/00 7/15/00 7/16/00 7/17/00 7/18/00 7/19/00 7/20/00 7/21/00 Rig up lubricator and APRS wireline and test to 2800 psi-Ok. Make up 3.625" chemical cutter and run in hole. Tie in and locate packer. Make chemical cut at 10,195'. Pull out of hole. Chemical cutter slips start hitting tubing collars at 6800' to 6600' then every other collar to 3800'. Worked free to 3345'. Stuck cutter and failed to work free. Pull out of rope socket. Left 15.91' of wireline tools in the hole. Move in Pollard Wireline. Make up lubricator and test to 2800 psi. Make up Pollard Wireline tools and run in hole to fish. Latch onto fish and hit jars with 800#. Broke overshot and left part of over shot and guide ring in hole. Make up new overshot and run in hole. Engaged fish and sheared off tool. Pull out of hole and left overshot in the hole. Make up new Bowen overshot and run in the hole. Engage fish and jar on fish w/1000g. Jar on fish five times, sheared pins and left Bowen overshot in the hole. Rig down Pollard Wireline and install back pressure valve. Move in and rig up Inland Drilling Rig CC #1. Continue to move in and rig up Inland Drilling Rig CC 01. Continue to move in and rig up Inland Drilling CC 01. Nipple up BOPE, weld koll line and picture nipple to fit well head height. Hook up BOPE control lines. Change out 3-1/2" pipe rams to 4-1/2" rams. R/U test chart recorder, pull back pressure valve and set TWC. Rig up to test top drive, both kelly valves leaked. Service top drive valves and test choke manifold. Finished testing choke manifold, outside check valve, full opening safety valve, pipe rams, blind rams, HCR, dart valve to 250 psi low and 5000 psi high. Re- tested top drive kelly valves-OK. Tested annular to 250/3500 psi-OK. Make up landing joint and engage tubing hanger. Pick up tubing string. Worked string to 160 Klbs. Make blind back off. Backed off after 22 turns. Puli out of hole looking for wireline fish. Finish pulling out of hole with 4-1/2" tubing (314 jts). Top of fish at 9883'. Did not see wireline fish. Rig up Pollard Wireline and run in hole making a feeler run to 10202'. No sign of wireline fish. Lay down wireline tools and lubricator. Run in the hole drifting 4-1/2" tubing to 3.75". Continue to run 4-1/2" tubing. Screw into fish at 9883'. Rig up APRS. Run in hole with 3.625" chemical cutter. Make chemical cut at 9950'. R/D APRS. Pull out of hole laying down 4-1/2" tubing. Finish laying down 316 jts of 4-1/2" tubing + 4.45' cut off. Change out 4-1/2" rams t o 3-1/2"rams. Test to 250 psi/5000 psi-OK. Make up milling assembly. Pick up 3-1/2" drill pipe and drift while running in the hole. 7/22/00 7/23/00 7/24/00 7/25/00 Finish picking up 3-1/2" drill pipe. Slip and cut drilling line. Tag 4-1/2" stub at 9949'. Mill over packer at 9954 to 9957'. Pull out of hole and lay down mill. Make up 5-7/8" overshot with 4-1/2" grapple. Finish making up fishing bottom hole assembly. Run in hole and work over the top of the fish at 9949'. Work fish and pull out of hole with the fish. Lay down tubing fish and found that K-22 anchor seal released from lower packer. Make up junk mill and string mill. Run into hole to 10199'. Pull out of hole. Finish pulling out of hole and lay down string mill and junk mill. Nipple down flow line and rig up lubricator. R/U Schlumberger and run CBL/GR/CCL from 10,190 to 8,000'. Lay down logging tools. Make up Baker mocel K-1 Cement retainer. Run in the hole and set at 10,195'. Rig down Schlumberger. Nipple up flow nipple and flow line. Finish nippling up flow line and flow nipple. Make up Baker Model B snap latch stinger and run in hole on 3-1/2" drill pipe. Make up cement line and test to 4000 psi. Slab into packer and establish injection at 1690 psi w/5 bpm. Batch mix 15.8 ppg cement. Pump 50 bbls of cement and squeeze 49 bbls of cement below cement retainer. Final pump pressure 2000 psi @ 5 bpm. Static surface pressure holding at 1500 psi prior to stinging out of retainer. Reverse out 1 bbi of cement. Pull out of hole and lay down cement stinger. UNOCAL ) RKB to Tbg. Spool = 17.10' window 10167 - 10182' Ia G-2 TOC approx. 10,195' Wireline fish j (chemical cutter) SCU 341-4 Abandon_ SIZE WT Swal~ 'River Soldotna Creek Unit Well No. 341-4 Workover (Plug Back Prior to KO) CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 22" 13-3/8" 54.5 7" 29 26 23 26 29 26 7" 29 22' J-55 8rd/ST&C 12.615 Surface 3,000' N-80 Buttress 6.184 Surface 304' N-80 Buttress 6.184 304' 1,235' N-80 Buttress 6.184 1,235' 4,229' N-80 Buttress 6.184 4,229' 4,527' N-80 8rd LT&C 6.184 4,527' 6,489' P-110 8rd LT&C 6.184 6,489' 9,346' P-110 8rd LT&C 6.184 9,344' 10,992' NO, Depth ID JEWELRY DETAIL OD Item 1 17.10' Tubing Hanger, 4-1/2" EUE 8rd Lift Thread x 4-1/2" Buttress Suspension Thread, Type 'H' BPYP 4 10,192 5 10,202' 3.875 5.970 6 10,207' 3.958 5.20 7 10,217' 3.725 5.20 8 10218' 3.958 5.20 9 10,225' 3.958 5.20 Baker "K" Cement Retainer Packer, Permanent, 7" x 4" Baker SABL-3 1 ea. Pup, 4-1/2", 12.6g, L-80 Modified Buttress 'XN' Nipple, 4-1/2" Buttress (3.725" I.D.) 1 ea. Pup, 4-1/2", 12.6#, L-80 Modified Buttress WLEG NO. Depth Item Notes A 2,002' 13-3/8" Stage Collar B 6,944' 7" Stage Collar C 10,485' Packer, 7" x 4", Baker Model 'F' PERFORATION HISTORY Interval Accu_m. Date Zone Top Btm Amt spf Comments 5/30/96 G-2 10,147' 10,167' 20' 6 Isolated By Scab 5/30/96 G-2 10,177' 10,1842 __7'~ ....... 6 3/11/60 H- 1 10,226' 10,227' l' 11/13/77 H- 1 10,230' 10,265' _3_5'~ 11/13/77 H-2 10,275' 10,285' 10' 8 11/13/77 H-3/4/5 10,310' 10,394' ____ 84'_ ......... .4/~88 3/11/60 10,402' 10,403' ____!'_ .......... _5 3/17/60 H-8 10,409' 10,478' _ 69~' ...... _4 3/17/60 H-10 10,508' 10,585' 77' _ 3/11/60 10,598' 10,590' ___L'_ ......... 3/11/60 10,600' 10,601' 1' _ .... _5_ ..... Squeezed 3/11/60 WF 10,965' 10.966' 1' PBTD = 10,850' TD = 11,315' ~-.,U b 2. 7_~ ~:.~..~ ~',) MAX HOLE ANGLE = Vertical Alaska Oi-': Anchorage CO~CTgD 8~: sl~ldd ~VISED: 8115100 STATE OF ALASKA ALASKA O -AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: X Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 180' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Soldotna Creek Unit 4. Location of well at surface 8. Well number ....... ~ ~. ...... ~.~ ..... ~ - SCU341-4 1,000' S, 1,170' W of NE Corner, Sec. 4, T7N, R9W, SM ~.,~ ''~ ~; "~ ;~ ';' ;: ": ~ At top of productive interval 9. Permit number Same 59114 At effective depth ' .;~', i ,~ '] r_~U00 10. APl number Same 50- 133-10109-00 At total depth ~a~ka 0~ & ~ C0~;~ C0~'~missi0n ~ 1. Field/Pool Same ~j~C~f~9 Swnason River Field / Hemlock 12. Present well condition summary Total depth: measured 11,315' feet Plugs (measured) true ve,ical ~ 1'315' feetORIGINAL Effective depth: measured 10,580' feet Junk (measured) true veAical 10,580' feet Casing Length Size Cemented Measured depth True vedical depth Structural Conductor 22' 22" Yes 22' 22' Sufiace 3,000' 13-3/8" I stg 450 sx, 1,750 sx ~ DV 3,000' 3,000' Intermediate Production 10,992' 7" 1 stg 1,000 sx, 692 sx ~ DV 10,992' 10,992' Liner Pefioration depth: measured 10,230'-10,265'; 10,275'-10,285'; 10,310'-10,3~'; 10,409'-10,478'; 10,508'-10,585' (10,147'-10,167'; 10,177-10,1 ~' Isolated by Straddle Packer) true veAical Same 10,230'-10,265'; 10,275'-10,285'; 10,3~ 0'-10,3~'; 10,409'-10,478'; 10,508'-10,585' (10,147'-10,167'; 10,177-10,1 ~' Isolated by Straddle Packer) Tubing (size, grade, and measured depth) 4-1/2", 12.~, L-80, Modified Buttress, 10,225' MD Packers and SSSV (~pe and measured depth) Baker SABL-3 Permanent ~ 10,202', Baker SB-3 Permanent (Straddle Packer) ~ 9,956' MD 13. Attachements Description summa~ of proposal: X Detailed operations program: X BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 6/21/00 16. If proposal well verbally approved: Oil: Gas: X Suspended: Name of approver Date approved Se~ice: 17. I hereby ce~i~ that the foregoing is true and correct to the best of my knowledge. Signed:~~ ~ ~Williamson Title: Drilling Manager Date: ~j~'' t~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness lApproval No. Plug integri~. ~ BOP Test ~ Location clearance I -~ ~ /~ Mechanical Integrity Test Subsequent form required 10- ~ 0 ~ Approved by orderofthe Commissioner I_/_~ Commissioner Date ~ '~ ~~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE R~: Well' SCU 341-4 (Approved Sundry Approval #300-148 dated 6/5/00) Subject: Re: Well: SCU 341-4 (Approved Sundry Approval #300-148 dated 6/$/00) Date: Wed, 21 Jun 2000 16:19:36 -0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: "Davis, LD" <lddavis~unocal.com> CC: Tom Maunder <tom maunder@admin.state.ak.us> LD Davis, We agree that your proposed change should result in an equal or better abandoned then was originally proposed. The operations are nearly identical except you are now planning to use the rig to do the abandonment versus coil tubing. We agree that this change is within the scope of the original approval and therefore no further approval is need from the AOGCC. Sincerely, Blair Wondzell, 6/21/00. "Davis, LD" wrote: Blair, Thank you for taking speaking with Tim and I. As per our conversation'. The change in the procedure was based on the problems associated with SCU 323-9. Attached is the new general procedures and the well schematics with the~ rig for the abandonment of SCU 341-4 prior to side tracking the well. > The rig will set a 7" cement retainer below the proposed sidetrack point and > pump more cement through the retainer than was originally planned with the > coiled tubing. > Then the whipstock will be set on top of the retainer and the sidetrack will > be drilled. Please let me know if this is acceptable. Thanks and Regards, LD Davis Alaska Drilling Ops. Office no.: 907-263-7679 Cell no.: 907-250-2711 > > <<SCU-341-4 General Abandonment Procedure.doc>> <<SCU 341-4 Draw Prop -- > Sidetrack a.doc>> <<SCU 341-4 Draw 8-12-98.doc>> > Abandonment Procedure.doc > SCU-341-4 General Abandonment Procedure.doc Type: Microsoft Word -- Document (application/msword) > Encoding: base64 Name: SCU-341-4 General > Name: SCU 341-4 Draw Prop Sidetrack a. doc > SCU 741-4 Draw Prop Sidetrack_a. doc Type: Microsoft Word Document ( app l i ca t i on/msword ) > Encoding: base64 > > Name: SCU 341-4 Draw'8-12-98.doc > SCU 341-4 Draw 8-12-98.doc Type: Microsoft Word Document ( app l i ca t i on/msword ) > Encoding: base64 I of 2 6/21/00 4:20 PM General Abandonment Procedure SCU 341-4 1) 2) 3) 4) 5) 6) 7) 8) 9) MIRU Inlet Drilling Rig #CC-1. NU and Test BOPE. R/U e-line and cut tubing at 9,953'. Pull 4-1/2" completion tubing. Mill packer at 9,956' and retrieve. RU e-line and run cement evaluation log. Run and set 7" cement retainer @ 9,991' RIH w/DP to 9,991. Sting into retainer and establish injection. Based on injection, mix and pump cement. Approximate cement volume = (10,580- 10,225) x .0371 bbls/ft for 7" 29# = 13.17 bbls Squeeze approximately 13.2 bbls + 7 bbls of additional cement (approx. 20.2 bbls) below the cement retainer and Baker SABL-3 packer. RIH with 7" whipstoCk on drill pipe and set whipstock on top of cement retainer at 9,991' 10) Mill window at 10,170' and commence horizontal re-drill of SCU No. 42-4. General Abandonment Procedure SCU 341-4 1) 2) 3) 4) 5) 6) 7) 8) 9) 10) 11) 12) 13) 14) 15) 16) 17) RU coil tubing, RIH and tag fill at 10,580'. Mix and cement volume to cover from PBTD to tubing tail. Appx cmt volume = (10,580'-10,225') x .0371 bbl ft for 7" 29# = 13.17 bbl Total cmt volume = 13.17 bbl. Once cement ~ched end of Coiled Tubing, extract coil at a 1:1 ratio pulling one foot for every foot of displacement. Once cement volume been pumped, displace with water. While pumping water, extraction of CT 9,000'. Circulate coil clean. Shut in on well and squeeze 5 bbls. RIH to tubing tail and circulate. POOH and rig down coil tubin Set plug in XN Nipple at 7'. Cut tubing at 10,195' tubing at Move in Inlet Dri Rig #CC-1. NU and Tes/g(3PE. /.. Pull completion tubing. / / Mill pa~ker at 9,956' and retrieve. / RU o/line and set 7" bridge plug at approximately 10,170'. / / RL~ w' 7" whipstock on drill pipe and set whipstock on top of bridge plug at 10,~ Mill window at 10,170' and commence horizontal redrill of SCU No. 41A-4. UNOCAL$ RKB to Tbg. Spool = 17.10' A SIZE 22" 13-3/8" 7" Tubing 4-1/2" Swa~ River Sold h Creek Unit Well No. 341-4 Actual Completion 8/12/98 CASING AND TUBING DETAIL WT GRADE CONN ID TOP BTM. 54.5 J-55 8rd/ST&C 12.615 Surface 29,26,23# N-80/P-110 BTC/8rd LT 6.184 Surface 12.6 L-80 Mod. Butt. 3.958 17.10' 22' 3,000' 10,992' 10,190' 341-4 Act Draw 3 NO. Depth 1D 1 17.10' 9,956' 3.875 5.970 9,969' 3.958 5.20 10,199' 3.875 5.850 10,202' 3.875 5.970 10,207' 3.958 5.20 10,217' 3.725 5.20 10218' 3.958 5.20 10,225' 3.958 5.20 JEWELRY DETAIL OD Item Tubing Hanger, 4-1/2" EUE 8rd Lift Thread x 4-1/2" Buttress Suspension Thread, Type 'H' BPVP Scab Liner/Tubing Assembly Packer, Permanent 7" x 4" Baker SB-3 7 its. Tubing, 4-1/2", 12.6#, L-80, Modified Buttress Traveling Anchor Seal Assembly, Baker Packer, Permanent, 7" x 4" Baker SABL-3 1 ea. Pup, 4-1/2", 12.6#, L-80 Modified Buttress 'XN' Nipple, 4-1/2" Buttress (3.725" I.D.) 1 ea. Pup, 4-1/2", 12.6#, L-80 Modified Buttress WLEG NO. Depth Item Notes A 2,002' 13-3/8" Stage Collar B 6,944' 7" Stage Collar C 10,485' Packer, 7" x 4", Baker Model 'F' PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments 5/30/96 G-2 10,147' 10,167' 20' 6 Isolated By Scab 5/30/96 G-2 10,177' 10,184' 7' 6 Isolated By Scab 3/11/60 H-1 10,226' 10,227' 1' 5 Squeezed wso 11/13/77 H-1 10,230' 10,265' 35' 8 11/13/77 H-2 10,275' 10,285' 10' 8 11/13/77 H-3/4/5 10,310' 10,394' 84' 4/8 3/11/60 - 10,402' 10,403' 1' 5 Squeezed 3/17/60 H-8 10,409' 10,478' 69' 4 3/17/60 H-10 10,508' 10,585' 77' 4 -- 3/11/60 10,598' 10,599' 1' 5 Squeezed WSO 3/11/60 10,600' 10,601' 1' 5 Squeezed 3/11/60 WF 10,965' 10,966' 1' 5 Squeezed PBTD = 10,850' TD = 11,315' MAX HOLE ANGLE = Vertical CORRECTED BY: sit REVISED: 3/15/00 UNOCAL ...... RKB to Tbg. Spool = 17.10' A SIZE 22" 13-3/8" 7" ,, Tubing 4-1/2" WT 54.5 29 26 23 26 29 26 29 12.6 Swa!?~u~n River Sold a Creek Unit Well No. 341-4 Actual Completion 8/12/98 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. NO. Depth ID 1 17.10' 22' J-55 8rd/ST&C 12.615 Surface 3,000' N-80 Buttress 6.184 Surface 304' N-80 Buttress 6.184 304' 1,235' N-80 Buttress 6.184 1,235' 4,229' N-80 Buttress 6.184 4,229' 4,527' N-80 8rd LT&C 6.184 4,527' 6,489' P-110 8rd LT&C 6.184 6,489' 9,346' P- 110 8rd LT&C 6.184 9,344' 10,992' L-80 Mod. Butt. 3.958 17.10' 10,190' JEWELRY DETAIL OD Item -- Tubing Hanger, 4-1/2" EUE 8rd Lift Thread x 4-1/2" Buttress Suspension Thread, Type 'H' BPVP 2 9,956' 3.875 5.970 3 9,969' 3.958 5.20 4 10,199' 3.875 5.850 5 10,202' 3.875 5.970 6 10,207' 3.958 5.20 7 10,217' 3.725 5.20 8 10218' 3.958 5.20 9 10,225' 3.958 5.20 Scab Liner/Tubing Assembly Packer, Permanent 7" x 4" Baker SB-3 7 its. Tubing, 4-1/2", 12.6#, L-80, Modified Buttress Traveling Anchor Seal Assembly, Baker Packer, Permanent, 7" x 4" Baker SABL-3 1 ea. Pup, 4-1/2", 12.6#, L-80 Modified Buttress 'XN' Nipple, 4-1/2" Buttress (3.725" I.D.) 1 ea. Pup, 4-1/2", 12.60, L-80 Modified Buttress WLEG TOC approx. 10,350' SCU 341-4 Draw G-2 Notes NO~. Depth Item A 2,002' 13-3/8" Stage Collar B 6,944' 7" Stage Collar C 10,485' Packer, 7" x 4", Baker Model 'F' PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments 5/30/96 G-2 10,147' 10,167' 20' 6 Isolated By Scab 5/30/96 G-2 10,177' 10,184' 7' 6 Isolated By Scab 3/11/60 H-1 10,226' 10,227' 1' 5 Squeezed wso 11/13/77 H-1 10,230' 10,265' 35' 8 11/13/77 H-2 10,275' 10,285' 10' 8 11/13/77 H-3/4/5 10,310' 10,394' 84' 4/8 3/11/60 - 10,402' 10,403' 1' 5 Squeezed 3/17/60 H-8 10,409' 10,478' 69' 4 3/17/60 H-10 10,508' 10,585' 77' 4 3/11/60 - 10,598' 10,599' 1' 5 Squeezed wso 3/11/60 - 10,600' 10,601' 1' 5 Squeezed 3/11/60 WF 10,965' 10,966' 1' 5 Squeezed PBTD = 10,850' TD = 11,315' MAX HOLE ANGLE = Vertical CORRECTED BY: sit REVISED: 3/15/00 UNOCAL Swanson River Soldotna Creek Ut ,Veil No. 41A-4 (Formerly 341-4) Proposed Sidetrack, June 2000 RKB to Tbg. Spool = 17.10' TOC approx. 10,350' LA G-2 SIZE CASING AND TUBING DETAIL WT GRADE CONN ID TOP BTM. 22" 13-3/8" 7" 7" Tubing 54.5 29 26 23 26 29 26 29 22' J-55 8rd/ST&C 12.615 Surface 3,000' N-80 Buttress 6.184 Surface 304' N'86 Buttress 6.184 304' 1,235' N-80 Buttress 6.184 1,235' 4,229' N-80 Buttress 6.184 4,229' 4,527' N-80 8rd LT&C ' 6.184 4~527' 6,489' P-110 8rd LT&C 6.184 6,489' 9,346' P-110 8rd LT&C 6.184 9,344' 10,992' NO. Depth ID JEWELRY DETAIL OD Item 2 10,166' 3 10,166' 4 10,199' 3.875 5.850 5 10,202' 3.875 5.970 6 10,207' 3.958 5.20 7 10,217' 3.725 5.20 8 10218' 3.958 5.20 9 10,225' 3.958 5.20 7", 29//, Whipstock 7" Bridge Plug Traveling Anchor Seal Assembly, Baker Packer, Permanent, 7" x 4" Baker SABL-3 1 ea. Pup, 4-1/2", 12.6#, L-80 Modified Buttress 'XN' Nipple, 4-1/2" Buttress (3.725" I.D.) 1 ea. Pup, 4-1/2", 12.6#, L-80 Modified Buttress WLEG NO. Depth Item Notes A 2,002' 13-3/8" Stage Collar B 6,944' 7" Stage Collar C 10,485' Packer, 7" x 4", Baker Model 'F' PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments 5/30/96 G-2 10,147' 10,167' 20' 6 Isolated By Scab 5/30/96 G-2 10,177' 10,184' 7' 6 Isolated By Scab 3/11/60 H-1 10,226' 10,227' 1' 5 Squeezed wso 11/13/77 H-1 10,230' 10,265' 35' 8 11/13/77 H-2 10,275' 10,285' 10' 8 11/13/77 H-3/4/5 ~0,310' 10,394' 84' 4/8 / 3/11~60 ,~10,402' 10,40Y 1' 5 Squeezed 3/17/60 H-8 /.10,409' 10,478' 69' 4 3/17/60 H- 10 10,508' 10,585' 77' 4 3/11/60 10,598' 10,599' 1' 5 Squeezed WSO 3/11/60 10,600' 10,601' 1' 5 Squeezed 3/11/60 WF 10,965' 10,966' 1' 5 Squeezed ................ ,'~ / ~'~ ........ ii'~'""~ SCU 341-4 Draw PBTD = 10,850' TD = 11,315' ,5 2000 MAX HOLE ANGLE = Vertical CO~C~D BY: slt ~VISED: 3/15/00 17 Swanson River Field Kenai Peninsula, Alaska I I I ~o ! ! ! I ! I ! I I I I I 31 32 I 8N-9W 18 33 -! 33-1 8 34 -8 80LDOTHA . CREEl( UMI' · I. I 17 I I ol I 44L-,.I I SWANSON RIVER uNrr 33-~3 14A-33 23-33 13 34 -33 '1-4 I 34, DISPOSAl, 32A-I ]8 4a-~a ,WAREHOUSE b'3'ORAGE 43-8 EQUIPMENT i I L4-34 - 4- - _4..4.-.4 _. 10 26 L, ANDIHG 8'IIliP I I I I I I I I I ! / / / / I I I I I I \ I I \ 11 / / I I I ,/ 14 ' ' "'"" STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: X Alter casing: Repair well: Other: 'Converted to Gas Prod. 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF orKB) Union Oil Company of California (UNOCAL) Development: X 167' RKB MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic~.,~r P.O. Box 196247, Anchorage, AK 99519 Service:~ Soldotna Creek Unit 4. Location of well at surface '" 8. Well number 1,000' S, 1,170' W of NE comer, Sec 4, T7N, R9W, SM SCU 341-4 At top of productive interval 9. Permit number/approval number Same 59/14 At effective depth 10. APl number Same 50- 133-10109-00 At total depth 11. Field/Pool Same Swanson River Field/Hemlock 12. Present well condition summary Total depth: measured 11,315' feet Plugs (measured) true vertical 11,315' feet 0i Effective depth: measured 10,850' feet Junk (measured) ~ , true vertical 10,850' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 22' 22" Yes 22' 22' Surface 3,100' 13-3/8" 1 stg. 450 ex, 1,750 sx @DV 3,000' 3,000' Intermediate Production 10,992' 7" 1 stg. 1,000 ex, 692 sx @DV 10,992' 10,992' Liner /~' Scab Liner Perforation depth: measured 10,230'-10,265'; 10,275'-10,285'; 10,310'-10,394'; 10,409'-10,478'; 10,508'-10,585' (10,147'-10,167'; 10,177-10,184' Isolated by Straddle Packer) true vertical Same Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, Modified Buttress, 10,225' MD Pack_.ers and SSSV (type and measured depth) R [ C Baker SABL-3 Permanent @ 10,202', Baker SB-3 Permanent (Straddle Packer)@ 9,956' MD .- 13. Stimulation or cement squeeze summary N/A z', "' Intervals treated (measured) ' '*[¢ t' N/A Treatment description including volumes used and final pressure Al~t~¢~. 0ii & ~3~ 14. Representative Daily Avera.qe Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 7-20-98 ......... 0 2,550 Subsequent to operation 9-15-98 0 14.3 mmcfd 0 0 1,650 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: Gas: X Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed.~l ~~i ~~/~ /~.~/~/~¢~ Dan Williamson Title: Drilling Manager Date: . . . Form 10-404 Rev 06/15/88 SUB~ PLICATE UNOCAL RKB to Tbg. Spool = 17.10' A 341-4 Act Draw.doc G-1 G-2 C SIZE WT Swv'~'~n River Sola,,~aa Creek Unit Well No. 341-4 Actual Completion 8/12/98 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 22" 13-3/8" 54.5 7" 29,26,23# Tubing 4-1/2" 12.6 J-55 8rd/ST&C 12.615 Surface N-80/P- 110 BTC/8rd LT 6.184 Surface L-80 Mod. Butt. 3.958 17.10' 22' 3,000' 10,992' 10,190' NO. Depth ID JEWELRY DETAIL OD Item 1 17.10' 2 9,956' 3.875 5.970 3 9,969' 3.958 5.20 4 10,199' 3.875 5.850 5 10,202' 3.875 5.970 6 10,207' 3.958 5.20 7 10,217' 3.813 3.725 8 10218' 3.725 5.20 9 10,225' 3.958 5.20 Tubing Hanger, 4-1/2" EUE 8rd Lift Thread x 4-1/2" Buttress Suspension Thread, Type 'H' BPVP Scab Liner/Tubing Assembly Packer, Permanent 7" x 4" Baker SB-3 7 jts. Tubing, 4-1/2", 12.6#, L-80, Modified Buttress Traveling Anchor Seal Assembly, Baker Packer, Permanent, 7" x 4" Baker SABL-3 1 ea. Pup, 4-1/2", 12.6#, L-80 Modified Buttress 'XN' Nipple, 4-1/2" Buttress (3.725" I.D.) 1 ea. Pup, 4-1/2", 12.6#, L-80 Modified Buttress WLEG NO. Depth Item Notes A 2,002' B 6,944' C 10,485' 13-3/8" Stage Collar 9-5/8" Stage Collar Packer, 7" x 4", Baker Model 'F' PERFORATION HISTORY Interval Accum. Date Zone Top Btm 3unt spf Comments 5/30/96 G-1 10,147' 10,167' 20' 6 Isolated By Scab 5/30/96 G-2 10,177' 10,184' 7' 6 Isolated By Scab 3/11/60 H-1 10,226' 10,227' 1' 5 Squeezed WSO 11/13/77 H-1 10,230' 10,265' 35' 8 11/13/77 H-2 10,275' 10,285' 10' 8 11/13/77 H-3/4/5 10,310' 10,394' 84' 4/8 3/11/60 10,402' 10,403' 1' 5 Squeezed 3/17/60 H-8 10,409' 10,478' 69' 4 3/17/60 H-10 10,508' 10,585' 77' 4 3/11/60 10,598' 10,599' 1' 5 Squeezed WSO 3/11/60 10,600' 10,601' 1' 5 Squeezed 3/11/60 WF 10,965' 10,966' 1' 5 Squeezed PBTD = 10,850' TD = 11,315' MAX HOLE ANGLE -- Vertical DRAWN BY: tcb REVISED: 8/14/98 Workover Summary Soldotna Creek Unit, Well 341-4 7/19/98 - 8/12/98 DAY 1 (7/19/98) BLEED TUBING FROM 2,550 PSI TO 0. ANNULUS 0. RIG UP APRS E-LINE. PRESSURE TEST LUBRICATOR TO 2,500 PSI. OK. RIH W/2-1/8" CHEMICAL CUTTER. SET DOWN AT 10,153'. LOCATE AND CUT TUBING BETWEEN NO. 1 AND NO. 2 PACKERS AT 10,137'. POOH. DAY 2 (7/20/98) FILL ANNULUS WITH 250 BBLS LEASE WATER. PRESSURE TEST 7" X TUBING ANNULUS TO 2,500 PSI FOR 30 MIN. GOOD TEST. BLEED PRESSURE. RU SLICKLINE. PRESSURE TEST LUBRICATOR. RIH AND ATTEMPT TO SHIFT SLIDING SLEEVE AT 9,953'. ATTEMPT TWO TIMES. NO GO. POTENTIALLY TO MUCH DIFFERENTIAL PRESSURE BETWEEN TUBING AND ANNULUS. POOH. SECURE WELL SHUT DOWN FOR NIGHT. DAY 3 (7/21198) RU SLICKLINE. TEST LUBRICATOR. PUMP 40 BBLS LEASE WATER DOWN TUBING. RIH AND SHIFT SLIDING SLEEVE AT 9,953'. POOH. RD SLICKLINE. SET BPV. MOVE IN RIG UP NORDIC RIG NO. 5. DAY 4 (7122/98) CONT. MIRU NORDIC RIG NO. 5. CIRCULATE WELL WITH A TOTAL OF 440 BBLS LEASE WATER. DAY 5 (7123/98) CONT. RU NORDIC RIG 5. ACCEPT RIG AT 8:30 HOURS. NIPPLE DOWN TREE. NIPPLE UP 7-1/16", 5M, BOPE. ANNULAR, DOUBLE GATE, MUD CROSS, SINGLE GATE. PULL BPV AND INSTALL TWO WAY CHECK. TEST ALL BOPE 250/3,000 PSI. OK. WITNESS WAIVED BY AOGCC AND BLM. PULL TWO WAY CHECK. MU LANDING JOINT INTO HANGER. PULL HANGER OFF SEAT WITH NO OVERPULL AT 90K. PULL HANGER TO FLOOR AND CIRCULATE BOTTOMS UP. SLIGHT GAS ROLL AT PITCHER NIPPLE. CIRCULATE ADDITIONAL HOLE VOLUME. WELL DEAD. DAY 6 (7124/98) POOH LAYING DOWN 3-1/2" X 2-7/8" COMPLETION. RECOVER 9,981' 3-1/2" AND 2 JOINTS OF 2-7/8", NO. 1 PACKER, 5 JOINTS 2-7/8" TUBING AND CHEMICAL CUT. MU BHA NO. 1, 6" SHOE, 2 JTS. 5-1/2" WASH PIPE. RIH PU 3-1/2" DRILL PIPE. DAY 7 (7~25~98) CONT. PU. DRILL PIPE. CHANGE TURBO ON DRAWWORKS ENGINE. CONT. RIH. TAG FISH AT 10,177' ROTATE OVER AND WASH DOWN TO NO. 2 PACKER AT 10,216' DPM. PUMP 35 BBL HIGH VIS SWEEP. NO SIGNIFICANT SOLIDS RETURNED. DAY 8 (7126198) POOH. PULL TIGHT THROUGH PERFORATIONS AT 10,155'. POOH TO 6,228'. SHUT DOWN TO REPAIR HYDRAULIC PUMP ON RIG. CONT. POOH. LAY DOWN BHA NO. 1. MU BHA NO. 2.5-3/4" OVERSHOT W/2-7/8" MILL. RIH. DAY 9 (7127/98) CONT. TIH W/BHA NO. 2. TAG FISH AT 10,177' DPM. LIGHTLY DRESS AND ATTEMPT TO SWALLOW. TORQING UP AT 10,183'. UNABLE TO ENGAGE FISH. POOH. RECOVER WADDED UP TUBING IN OVERSHOT. LD BHA. DAY 10 (7128198) MU BHA NO. 3, 6" CONCAVE MILL. REPLACE TURBO ON DRAWWORKS ENGINE. RIH. TAG TOF AT 10,183'. MILL 2-7/8" TUBING STUB TO 10,185'. PUMP 10 BBL HIGH-VIS SWEEP. ATTEMPT TO MILL BELOW 10,185' W/NO SUCCESS. POOH. LD CONCAVE MILL. DAY 11 (7/29198) CONT. POOH W/BHA NO. 3. MU BHA NO.4, SKIRTED MILL W/CUT LIP GUIDE. RIH W/BHA NO 4. FAST LINE SHEAVE BEARING OUT. WAIT ON REPLACEMENT. DAY 12 (7130/98) WAITING ON FASTLINE BEARING. REPAIR SAME. CONT. RIH. DAY 13 (7131198) CONT. RIH BHA NO. 4. BREAK CIRC. AND TAG FISH AT 10,182'. MILL 2-7/8" TUBING STUB FROM 10,182' TO 10,206' LEAVING APPROX. 10' OF STUB ABOVE NO. 2 PACKER. PUMP 20 BBL HIGH VIS SWEEP. POOH. LD BHA. TEST BOPE 250/3,000 PSI DAY 14 (8/1/98) COMPLETE TEST BOPE. OK. MAKE UP BHA NO. 5, CRIPPLE MILL W/WASH PIPE EXTENSION AND FINGER BASKET. RIH. BREAK CIRCULATION AND SWALLOW FISH AT 10,206' WASH DOWN. HIGH TORQUE AT 10,214' (2' ABOVE PACKER). REVERSE CIRC. 40 BBLS. AT 1,500 PSI. ATTEMPTING TO CATCH JUNK IN FINGERS. HIGH TORQUE AT 10,214'. POOH. DAY 15 (812/98) CONT. POOH. SCALE RECOVERED IN FINGERS. ~ CUP METAL RECOVERED IN JUNK BASKETS. MU BHA NO. 6.5-3/4" OVERSHOT DRESSED WITH 2-7/8" GRAPPLE. RIH. BREAK CIRCULATION AND TAG STUB AT 10,206'. WORK OVER FISH TO 10,211'. JAR ON PACKER 10 TIMES WITH 210K. ATTEMPT TO RELEASE PACKER WITH RIGHT HAND ROTATION. PACKER MOVED DOWN HOLE 10'. CBU. PU W/250K. SOME UPWARD MOVEMENT. REPAIR DRAWORKS CLUTCH. DAY 16 (813198) CONT. REPAIR CLUTCH. WORK PIPE WITH 330K. WORK UP HOLE ADDITIONAL 15'.POOH. PACKER SWABBING WELL. SHIFT OPEN CIRCULATING SUB. CIRC. POOH SLOW. WELL SWABBING. BREAK CIRC. AT 9,345'. CONT. POOH. WELL TAKING FLUID AT 50 BBL/HR. MIX 50 BBL. SIZED SALT PILL. PUMP SAME. DAY 17 (814198) COMPLETE PUMPING SIZED SALT PILL. LOSSES DOWN TO 3 BBLS/HR. CONT. POOH. RECOVER NO. 2 PACKER, 1 JT. 2-7/8" TUBING, CAMCO INJECTION MANDREL, CUT JT. TUBING. MU BHA NO. 7, 5-3/4" OVERSHOT W/2-7/8" GRAPPLE. RIH. DAY 18 (815/98) CONT. RIH. ENGAGE FISH AT 10,283'. BREAK CIRCULATION. MILL OVER TO ENGAGE FISH. PU WEIGHT INCRESE OF 2-3K. NO INDICATION OF PACKERS UNSEATING. CIRCULTE OUT GAS BUBBLE. POOH. RECOVER 2.5' AND 3.5' PIECES OF TUBING FROM OVERSHOT. REDRESS OVERSHOT WITH NEW MILL AND ADDITIONAL EXTENSIONS. RIH W/BHA NO. 8. DAY 19 (816198) CONT. RIH. BREAK CIRCULATION AND FIND TOP OF FISH AT 10,287'.ENGAGE FISH AND PU 6'. 8-10K ADDITIONAL WEIGHT. CIRCULATE OUT GAS BUBBLE. WELL TAKING FLUID. LOSSES AT 60 BBLS/HR. PUMP 35 BBL SIZED SALT PILL. POOH PULLING 60-110K OVER. JARRING FIRST THREE STANDS. LOSSES DOWN TO 3BBLS/HR. POOH. FULL RECOVERY, NO. 3 AND NO. 4 PACKER AND JEWLERY. DAY 20 (8/7198) CONT. LAYING DOWN FISH. MU 2-3/8" TAILPIPE AND 7" CASING SCRAPER FOR CLEAN OUT RUN. RIH. TAG TOP OF NO. 5 (PERMANENT) PACKER AT 10,485'. WASH DOWN TO 10,542'. CIRCULATE WELL CLEAN. POOH TO 10,042'. SPOT 35 BBL SIZED SALT PILL IN ANNULUS. POOH LAYING DOWN DRILL PIPE. DAY 21 (8~8~98) CONT. POOH LAYING DOWN DRILL PIPE. MU HOWCO 7" RTTS. RIH TO 61' AND SET. ATTEMPT TO TEST. NO-GO. LEAKING AT SURFACE. PRESSURE TEST RTTS TO 1,500 PSI. GOOD TEST. ND. 7-1/16" BOP'S. REMOVE TUBING SPOOL. INSTALL NEW PACKOFF. INSTALL 1' STUB EXTENSION ON TO 7" CASING. INSTALL NEW TUBING SPOOL. TEST TO, 3,000PSI FOR 30 MIN. GOOD TEST. NIPPLE UP 7-1/16" BOP'S. SET TEST PLUG AND TEST. GRAYLOCK CLAMP ON CHOKE LINE LEAKING. CHANGE SEAL RING AND RE-TEST. TEST 250/3,000 PSI. GOOD TEST. LAY DOWN TEST PLUG. RIH W/RTTS RETRIEVING TOOL. DAY 22 (819198) SCREW INTO RTTS. UNABLE TO SCREW IN COMPLETELY. PUMP 10 BBLS. DOWN TUBING. PICK UP AND RELEASE RTTS. PUMP 61 BBLS AND FILL HOLE. OPEN WELL. POOH WTH RTTS, REMAINING DRILL PIPE. RTTS FOUND TO HAVE PIECES OF METAL IN CONNECTION. WELL TAKING 20 BBLS/HR. BHA BACKED OFF AT BIT SUB LEAVING SUB, SCRAPER, SUB AND 2 JTS. 2-3/8" TUBING IN HOLE. CHANGE RAMS TO 4-1/2". TEST TO 250/3,000 PSI. GOOD TEST. MU FISHING ASSEMBLY, 3-1/2" REG SCREW IN SUB. RIH PU 4-1/2" TUBING. DAY 23 (8110/98) CONT. RIH PU 4-1/2" TUBING. BREAK CIRC. AND ATTEMT TO SCREW INTO FISH AT 10,485'. PRESSURE INCREASED FROM 300 PSI TO 500 PSI. POOH TO 10, 020'. PUMP 45 BBL SIZED SALT PILL. CONT. POOH STANDING BACK 4-1/2" TUBING. LAY DOW FISHING ASSEMBLY AND RECOVERED SCRAPER ASSEMBLY. PREP. TO RUN COMPLETION. DAY 24 (8111198) MAKE UP STRADDLE PACKER ASSEMBLY. RIH W/COMPLETION. MU HANGER AND LAND COMPLETION. RU SWS E-LINE. RIH WITH GR/CCL TO CORRELLATE PACKERS ON DEPTH. PACKERS ON CORRECT DEPTH.POOH. RD E-LINE. RU SLICKLINE. RIH WITH 3.83" GAGE RING. WORK THROUGH TIGHT SPOTS 1,019', 3,035',3,518'. CONT. RIH TO "XN" NIPPLE AT 10,216'. DISPLACE ANNULUS WITH CORROSION INHIBITOR AND DIESEL FOR FREEZE PROTECTION. DROP BALL AND ALLOW TO FALL TO RHC PLUG SET IN "XN" NIPPLE. PRESSURE UP ON TUBING TO 2,950 PSI FOR 10 MIN. AND SET PACKERS. PRESSURE TEST ANNULUS TO 2,500 PSI. HOLD FOR 15. MIN. NO BLEED OFF. GOOD TEST. RU SLICKLINE. RIH AND ATTEMPT TO EQUALIZE RHC PLUG. DAY 25 (8112198) POOH. EQUALIZING PRONG TO LARGE. MODIFY AND RIH. EQUALIZE RHC PLUG. POOH. MU AND RIH WITH GS PULLING TOOL. LATCH RHC. POOH. RD SLICKLINE. INSTALL TWO WAY CHECK. ND BOPE. NIPPLE UP SEAL FLANGE TREE AND TEST TO 5,000 PSI. OK. RELEASE RIG AT 24:00 HOURS. Unoeml Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-26~-7660 UNOCAL ) July 17, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Blair Wondzell Subject: Soldotna Creek Unit Well No. 341-4 .~.~P~-- "[(l'~t~ APl #50-133-10109-00 Amendment to Form t0-403, Proposal to Convert from Gas injector to Gas Producer Mr, Wondzell: As discussed this morning, please insert these amendments to the Form 10-403 for Solclotna Creek Unit Well No. 341-4 conversion from gas injector to Hemlock gas producer. 'The10-403 was originally submitted with the intention of setting a single peeker above the Tyonek "G". These attachments now include a straddle packer assembly set at approximately 9.930' to 10,200' to isolate the Tyonek "G" Zone. Anticipated start date is July 23, 1996. Please direct any questions to Tim Brandenburg at 263-7657. Sincerely, Tim Brandenburg JUL 1 7 199B ,~;Z 'd ege~'ON 'd~lO0 -IVOONn ~vgz'6 866[ ' LINOCAL ) RItB to Tbg. Spool = 17.10' 10 14 -_ G-1 G-2 .C SIZE gwallson River Well SCU 341-4 Proposed Completion CASING AND TUBING DETAIL WT GRADI~ CONN ID TOP aTM. 13-3/8" 54.5 J-55 8rddST&G 12.615 Surface 7' 29,26,23# N-80/P-I I0 BTC/grd LT 6.184 Surfaco Tubing 4-1/2" 12.6~ L-80 Mod. Butt 3.958 17.10' 3-112" 9.2 L-80 Mod. Butt 2.992 10,194' 22' 3,000' 10,99;2' 9,930' 10,219' JEWELRY DETAIL , ,NO. Depth ID OD Item _ ! ! 7. ! O' Tubing Hanger 2 9,930' 3.875 Anchor, Seal Assembly Scab Liner/Tubing Auembly 3 9,930' 4.000 - Pa~ker, 7" x 4" 4 9,934' 5.000 - l~Lillout Extension 5 9,944' 3,958 - Tubing Adapt~ 6 9,946' 3.958 - Tubing, 4-1f2", 12.6~, L-go, Modified Buttress 7 10,194' 2.992 - Crossover, 4-1/2" Buttress Bo~ x 3-11T' Buttre~ Pin 8 10,195' 2.982 - Seal Assembly 9 1 O, 195' 4.000 - Packer, 7" x 4" Peimanent I 0 10,200' $.000 - Mfllout Extension I 1 I0,206' 2,992 - I ca.6' pup, 3-1/2", 9.2#, L-80 Modified Buttress 12 10,212' 2.813 - 'X' Nippl,, 3-1/2" Buttress (2.813" I.D.) 13 10213' 2.992 - 1 ca, 6' Pup, 3-1/2", 9.2#, L-gO Modifiexl Buttress I4 10,219' 2-992 - WLEO/Sheatout Sub Note~ · NO..__ Depth Item A 2,002' 13-3/8" Stage Collar B 6,944' 9-$/8" Stage Collar C 10,485' Packer, 7" x 4", Baker Model 'F' PERFORATION HISTORY Interval ' ~ccnm. ...... ..... 5/30/9~ ~1 10,147' ~ 10,167' 20"-' 2 ~~ ....... 5~0/96 0-2 10,1~ "~,1~, 7' 2 3/11/60 H-1 ..... ~26' 10,227' I' 5 s~o ~1/13~7 H-1 - 10~20' ~ ~0~65' 35' 8 1 ~/13m H-~ ' t0~75' ~0~85' 11/13~ ' H-~/~/5 10Jl0' 10~' 84" 3/11/60 * ' ........ 10,402' 10,40~' 1' 3/17/60 H-8 "' 10,409' 10,47g' 69' 3/17/60 H-10 '"T0;508' 10~8Y 77' '4' 3/11/60 - '" ~'0,598' 10,599' 1' 3/II/60 - "i~;$00'" 10,60I' 1' ..... 3/11/60 ~ 10,965' 10,966' 1' ,, , ..,, ., PBTD = 10,850' TI) = 11,315' MAX HOLE ANGLE = Vertical DRAWN BY: tcb REVISED: 7/16/98 'd~O0 -IVooNn I,,1V9~'6 866 l ' / i'ln? ,It) 1 7 199B -~o. Preliminary ProcedUre Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) Prep Well for Workover Test Wel'~aead .... . . R.u slick ii~e, RIH and shift open '~' Sleeve at 9,953' .......... ..... :{rqorko~r ................ 1"' MIRU Nordic Rig No. 5 0'0 ................ 0 .......... 0.:0 ....... 2 ND Tree, NU BOP and Test 24.0 24 1.0 3 Engage ha~ger with Landing ?;i~t ........ 1.0 25' 1:0 4 to ZO ' 5 'RIIt, Free Point, Make chemical cut at 9,940' (above No. 1 Packer). 6.0 33 1.4 -'6 POOH laying down robing. 20.0 53 2.2 1.0 54 ' '2.3 7 Install Wear Bushin.,g_. ,. 8 MU Fishing BHA No. 1 3.0 57 2.4 9 t'U 3-1/2' Drill Pipe R.IH 22.0 79 3.3 10 !E~'~ag. e2-7/8'I Fish. ,~,tiempt to jar No. 1 and 2 Packer ~ee ........... 3.0 82 3.4 l i'1I~U/R~ with chemical cutter, cut at 10,177'.Below No. 1 Packer' ' 4.0 86 3.6 12 2~ No. 1 Pa~ker free. 3.0 89 3.7 13 cirCUlate. ' ........ 2.~ ....... 91, 3.8 14 ]POOH. 12.0 103 4.3 15 :LD Fish. , .....................310 106 4.4' 16 MI~ Fi$~.Bg'I~314_.A N~'['2, .W..a. shpipe .. ' ............... , .......... 4'0 110 4.6 .-- 17 ~d/--I. " 10.0 120 S.0 .................... ,,, . 18 Washover. Cleanout to fish. 4,0 124 5.2 19 POOH. I[2.0 136 5.7 20 ..:MU Fishing:_ .B...HA No. 3, Over~I~ot..... .."'-... 4.0 140 ....... 5.8 21 ltlFI 10.0 150 6.3 22 F. ngag¢ fish. 1.0 151 6'.3 23' Jar No. 2 Packer'~ree.' ................. 3.0 154 '6.~ ;24 Circulate gas eom ~;ii ....... , ........... 4.0 l SS ~'.16 2--5 ~oou ............. 12'.0 170 7.1 26 Install W'e~r Bushing. 1.0 1~71 7.1 ;27 Test BOPE.I.......... ' ................ 4--0 i-75 7.3 ~-g ~tstall W~ar'Bushing. " 1..6- 176 7.3 ' Page 1 of 3 9/~ 'd $886'oN 'd~JOO 'IVOONFI ~V/~'6 866L 'Ll'Jn? Unocal Alaska Business Unit Swallsoll River Well No. SCU 341-4 Prepared by: Tim Brandenburg Date: 7/16/98 Unocal Alaska Business Unit Swanson River Well No. SCU 341-4 Prepared by: Tim Brandenburg Date: 7/16/98 i"~o. Preliminary Procedure ' Time CUM CUM Estimate Time Thne (Hours) (Hours) (Days) 29 !MU Fishing Assembly BHA No. 3., (~'~:~;i~ot. 2.0 178 7.4' , ,.,,, .......... 30 RtH 1.0.0 188 7.8 31 Retrieve Packer. " " 3.0 191 8.0 .............. 32 POOtL 12.0 203 8.5 .. ,..,., .... 33 LD Fish. 1.0 204 8.5 ................................ 34 M:~"~ishing BH.A No. 3, Overshot. 3.0 207 8.6 35 RIH. ' .... 10.0 217 '~'~t~ 36 Engage 2-7/8" Fish. ~'ttempt to jar No. '3 and 4 Packers fi-ce. ' .............. ].0 220 9.2 ...,. ..... 37 KU, Make chemical cut above No. 4 Packer. 4.0 224 9.3 ,..,.,... ,, ,, ,,,.,,., ,., 38 Jar No. 3 Packer fi-ce. 3,0 227 9,5 ,,, ,,.., 39 Ckculate. 2.0 229 9.5 , - - ,,.,,,,. ~,m., . 40 POOH. 12.0 241 I0,0 41 LD Fish. 1.0 242 10.1 42 ~J:!, Fishing Assembly No. 3. I0.0 252 10.5 43 Eng"ge 2-7/8" Fish. Attempt to jar N;.'~-Pacl~er free. - ........ 3.0 25'5 10.6 44 RU Rrm Fr;~"i~oint, Make chemical cut ai~o¢~ 1~, 5 Packer 4,0 259 10.8 45 Jar No. 4 Packer free. 3.0 262 10.9 , .,,, ,., ., , ,. ,,,,.,,. 46 Circulate 2.0 ' 264 11.0 ,.. , . ,,,,, 47 'POOH. 12.0 276 11.5 ...... , .... ,.. '~8' !LD Fish. 1.0 277 11.5 ,, ,,! .,,,- _49 RIH, Fistfing Assembly..N.o.. ,..3... ' 10.0 287 12.0 50 Ea.g...ag.e 2-7/8" Fish, jar seals fr..o..m packer. '" . .... 3.0 29~ 12.1 .. 51 Circulate. · 2.0 292 12.2 ,. , .,.,,, ,,,, 52 POOH. 12.0 304 12.7 .......... ----- ,,, _ . 53 '.LD Fish. 1.0 305 12.7 ....... ,,,. ................... · ,,, ,., ,,, _ ..,., . :, Clean out Fill --_ 54 ~ Cleanout Assembly No. 1, 3.5" Mill 2.0 _30_7_ ..... 12.8 ..... ,,, 55 ]RIH. PU 7" Casing.Scrapper 10.0' 317 13.2 $~- iClean out (Reverse) fill fi.om lO,51I'to 10,68~' ..... 8.0 325 13.5 57 i]POOH Laying down 3-1/2" Drill Pipe. 14.0 339 14.1 .,. ,,- , ...... Page 2 of 3 g?g 'd ~8~6'0N 'd~0O ]¥00Nfl ¢tYZg'G 866[ 'Z['in? Unocal Alaska Business Unit Swanson River Well No. SCU 341-4 Prepared by: Tim Brandenburg Date: 7/16/98 UNOCAL ) '"'N~' Preliminary Pr~;edure ........... Ti~; ..... CUM CUM Estimate Time Time (Hours) (Hours) (Days) ~_ II IIIII Ill i IIIII II II Chang~ Out Tubing Spool 58 MU 7" KTTS/Stonn Valve 2.0 341 14.2 59 iRIH, set I~TS at'200', 13OOH, Test. ' ................ 2.0 ..... 343 ' 14.3 60 '~)ick .u..p..stack.' ................. 4.0 ' .... 3'47 i4.5 '" o ,t. ... "" 353 4.7 ..........., lmm ,, 62 Land stack, test. 4.0 357 14.9 63 R~, retreive RTTS. 3.0 360 15.0 6~ POOH Layi~.g. down 3-I/2" Drill Pipe.. .......... 9.0 369 15.4 65 Pull Wea~ Bushing. 1.0" 370 1~14 66 -T'est BOPE. ' ............ 4.0 .... 374 15.6'" ...... Run '~omPietion ..................... 67- Kua and set isolatiox~' ~acker at 101200' ' ......... 8 ...... 3~'2 1519 68 Run 4-1/2,".~ompletion: ..... '~4.0 393 .. 16.4 ~ 69 Displace annulus to inhibited fluid. ' ....... 2.0 395 16.5 70 Stab into !,owcr packer: .test seals. , ........ 1.0 ..396 16.5 71 Set Packer at 9,930'. 2.0' 398 'i6.6 '~2 Land cor~,p.'.lefion. ' ........ ; ..... -' .',, 2.0 ..... 400 --i6.7.' 73 Prcsssure test annulus. 1.0 401 i6.7 74 'ND BOP ,' 12.0 4i3 17.2 ' 75 N~ and Test tr;;. ' ............... ' ..... 3.0 .... -4-16 I7.3 76 '-'-RD Workovar'Rig 0.0 416 17.3 ~_ i i i il ,,lllllll I II III a mflal,m a I I I II ~ i~,mm .. II II _1. I1[ ...... I iiimll .. iii I Subtotal (Days) 17.3 Loss/Trble Time (11'%) 1.9 '~otal Project Days 19.2 .... I _111 IIII r · --.. ' Page 3 of 3 R/~ 'H ~R~R'oN 'd~OO ]VOONn ~VtZ'6 966L 'ZL'ino IUNOCAL .J UNOCAL Alaska Drilling Department To: Mr. Blair WondzeI1 A.O.G.C.C. From: Tim Brandenburg SCU No. 341-4 Form 10-403 Amendments Pages including cover sheet: 6 1998 Alaska ~ & ~as Cms. C,(wMik~ Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7660 UNOCAL ) July 9, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Commissioner David Johnston Subject: Soldotna Creek Unit Well No. 341-4 APl #50-133-10109-00 Form 10-403, Proposal to Convert from Gas injector to Gas Producer Dear Commissioner Johnston: Unocal proposes to re-complete Soldotna Creek Unit Well No. 341-4 converting it from a gas injection well to a~Hemlock/T~/onek gas producer. The well is currently shut in after a 1996 tests to inject gas into the Tyonek G Zone. The proposed work will require the removal of the current completion and to re-complete with a 4-1/2" Tubing String with a packer set at approximately 9,930'. Attached in triplicate are the 10-403 form with BOP schematics, detailed operations program and schematics of the existing wellbore, and the proposed re-completion. Estimated start date is July 23, 1998. Please direct any questions to Tim Brandenburg at 263-7657. Sincerely, Tim Brandenburg STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: X Variance: Perforate: Other: Convert to Gas Prod. 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: 167' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: X Soldotna Creek Unit 4. Location of well at surface 8. Well number 1,000' S, 1,170' W of NE Corner, Sec. 4, T7N, R9W, SM SCU 341-4 At top of productive interval 9. Permit number Same 59/14 At effective depth 10. APl number Same 50- 133-10109-00 At total depth 11. Field/Pool Same Swnason River Field / Hemlock 12. Present well condition summaryRE£EIVEI Total depth: measured 11,315' feet Plugs (measured) ,rue vertical 11'315' feetORIGINAL Effective depth: measured 10,850' feet Junk (measured) true vertical 10,850' feet ~,t~tSKa 011 & Gas Coils, casing Length Size Cemented Measured depth True vertica~o[i~lep[~ra~ Structural Conductor 22' 22" Yes 22' 22' Surface 3,000' 13-3/8" 1 stg 450 ex, 1,750 sx @ DV 3,000' 3,000' Intermediate Production 10,992' 7" 1 stg 1,000 ex, 692 sx @ DV 10,992' 10,992' Liner Perforation depth: measured 10,147'-10,167'; 10,177-10,184'; 10,230'-10,265'; 10,275'-10,285'; 10,310'-10,394'; 10,409'-10,478'; 10,508'-10,585' true vertical Same 10,147'-10,167'; 10,177-10,184'; 10,230'-10,265'; 10,275'-10,285'; 10,310'-10,394'; 10,409'-10,478'; 10,508'-10,585' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80, @ 9,892'; 2-7/8", 6.5~, N-80, EUE 8rd @ 9,892' to 10,557' Packers and SSSV (type and measured depth) Baker Mod. "FH" @ 9,958', 10,215', 10,295', 10,394'; Baker Mod. "F" @ 10,465' 13. Attachements Description summary of proposal: X Detailed operations program: X BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 6/29/1998 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: ,,~'~..,~ f__.... ~,~-.,~ f Dale Haines Title: Drilling Manager D ate :--~'" / ~-~ "-~' FOR COMMISSION USE ONLY Plug integrity BOP Test ~ Location clearance I Mechanical Integrity Test Subsequent form required 10- ~¢~) ~r o,,le(~ ¢,.~ Original S~gnuu u,~ ,'~~ David W. Johnston Approved by order of the Commissioner Commissioner Date ?--~,~ 0 -'" ~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Unocal Alaska Business Unit Swanson River Well No. SCU 341-4 Prepared by: Tim Brandenburg Date: 6/18/98 UNOCAL ) No. Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) Prep Well for Workover Test Wellhead Ru slick line, RIH and shift open 'XA' Sleeve at 9,953' Workover 1 MIRU Nordic Rig No. 5 0.0 0 0.0 2 ND Tree, NU BOP and Test 24.0 24 1.0 3 Engage hanger with Landing Joint 1.0 25 1.0 4 Attempt to Unseat No. 1 and 2 Packers 2.0 27 1.1 5 RIH, Free Point, Make chemical cut at 9,940' (above No. 1 Packer). 6.0 33 1.4 6 POOH laying down tubing. 20.0 53 2.2 7 Install Wear Bushing. 1.0 54 2.3 8 MU Fishing BI-IA No. ! 3.0 57 2.4 9 PU 3-1/2" Drill Pipe RIH 22.0 79 3.3 10 Engage 2-7/8" Fish. Attempt to jar No. 1 and 2 Packer free 3.0 82 3.4 11 RU/RIH with chemical cutter, cut at 10,177' Below No.1 Packer 4.0 86 3.6 12 Jar No. 1 Packer free. 3.0 89 3.7 13 Circulate. 2.0 91 3.8 14 POOH. 12.0 103 4.3 15 LD Fish. 3.0 106 4.4 16 MU Fishing, BHA No. 2, Washpipe 4.0 110 4.6 17 RIH. 10.0 120 5.0 18 Washover. Cleanout to fish. 4.0 124 5.2 19 POOH. . ,~"~ 12.0 136 5.7 20 MU Fishing, BHA No. 3, Overshot.t. ~\N~~,''' 4.0 140 5.8 21 R IH ~,~M, ,~% 10.0 150 6.3 22 Engage fish. '- . ,~ ~nO ~- ~\~..~ 1.0 151 6.3 23 Jar No. 2 Packer free. ~x39- - ~.~.e,b~,,-- 3.0 154 6.4 24 Circulate gas from well -~,~.~*%~ 4.0 158 6.6 25 POOH ~1,,,-~ v*.- 12.0 170 7.1 26 Install Wear Bushing. 1.0 171 7.1 27 Test BOPE. 4.0 175 7.3 28 Install Wear Bushing. 1.0 176 7.3 Page 1 of 3 Unocal Alaska Business Unit Swanson River Well No. SCU 341-4 Prepared by: Tim Brandenburg Date: 6/18/98 UNOCALO No. Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) 29 MU Fishing Assembly BHA No. 3., Overshot. 2.0 178 7.4 30 RIH 10.0 188 7.8 31 Retrieve Packer. 3.0 191 8.0 32 POOH. 12.0 203 8.5 33 LD Fish. 1.0 204 8.5 34 MU Fishing BI-IA No. 3, Overshot. 3.0 207 8.6 35 RIH. 10.0 217 9.0 36 Engage 2-7/8" Fish. Attempt to jar No. 3 and 4 Packers flee. 3.0 220 9.2 37 RU, Make chemical cut above No. 4 Packer. 4.0 224 9.3 38 Jar No. 3 Packer free. 3.0 227 9.5 39 Circulate. 2.0 229 9.5 40 POOH. 12.0 241 10.0 41 LD Fish. 1.0 242 10.1 42 RIH, Fishing Assembly No. 3. 10.0 252 10.5 43 Engage 2-7/8" Fish. Attempt to jar No. 4 Packer free. 3.0 255 10.6 44 RU Run Free Point, Make chemical cut above No. 5 Packer 4.0 259 10.8 45 Jar No. 4 Packer free. 3.0 262 10.9 46 Circulate 2.0 264 11.0 47 POOH. 12.0 276 11.5 48 LD Fish. 1.0 277 11.5 49 RIH, Fishing Assembly No. 3. 10.0 287 12.0 50 Engage 2-7/8" Fish, jar seals from packer. 3.0 290 12.1 51 Circulate. 2.0 292 12.2 52 POOH. 12.0 304 12.7 53 LD Fish. 1.0 305 12.7 Clean Out Fill 54 MU Cleanout Assembly No. 1, 3.5" Mill 2.0 307 12.8 55 RIH. PU 7" Casing Scrapper 10.0 317 13.2 56 Clean out (Reverse) fill from 10,511' to 10,685' 8.0 325 13.5 57 POOH Laying down 3-1/2" Drill Pipe. 14.0 339 14.1 Page 2 of 3 Unocal Alaska Business Unit Swanson River Well No. SCU 341-4 Prepared by: Tim Brandenburg Date: 6/18/98 UNOCAL ) No. Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) Change Out Tubing Spool 58 MU 7" RTTS/Storm Valve 2.0 341 14.2 59 R]H, set RTTS at 200', POOH, Test. 2.0 343 14.3 60 Pick up stack. 4.0 347 14.5 61 Change out tubing spool. 6.0 353 14.7 62 Land stack, test. 4.0 357 14.9 63 RIH, retreive RTTS. 3.0 360 15.0 64 POOH Laying down 3-1/2" Drill Pipe. 9.0 369 15.4 65 Pull Wear Bushing. 1.0 370 15.4 66 Test BOPE. 4.0 374 15.6 Run Completion 67 Run 4-1/2" Completion. 24.0 393 16.4 68 Displace annulus to inhibited fluid. 2.0 395 16.5 69 Set Packer at 9,930'. 2.0 397 16.5 70 Land completion. 2.0 399 16.6 71 Presssure test annulus. 1.0 400 16.7 72 ND BOP 12.0 412 17.2 73 NU and Test Tree. 3.0 415 17.3 74 RD Workover Rig 0.0 415 17.3 Subtotal (Days) ' 17.3 I Loss/Trble Time (11%) 1.9 I Total Project Days 19.2 Page 3 of 3 UNOCAL ) RKB to Tbg. Spool -- 17.10' A 10 11 12 13 ! C D E 14 15 16 Fin Tagged 10,511' w/ Z3'GR I/8/90. SIZE Swanson River Well SCU 341-4 Actual Completion 11/7/77 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 22" 13-3/8" 7" Tubing 3-1/2" 2-7/8" 54.5 29,26,23# 9.3 6.5 J-55 8rd/ST&C 12.615 Surface N-80/P-110 BTC/Srd LT 6.184 Surface N-80 8rd 2.992 17.10' N-80 8rd 2.441 9,819' 22' 3,000' 10,992' 9,891' 10,556' NO. Depth JEWELRY DETAIL OD Item 1 17.10' 2 9,891' 3 9,953' 4 9,957' 5 10,214' 6 10,221' 7 10,254' 8 10,294' 9 10,300' 10 10,354' 11 10,394' 12 10,400' 13 10,444' 14 10,485' 15 10,526' 16 10,556' Tubing Hanger Crossover, 2-7/8" 8rd Pin x 3-1/2" 8rd Box Otis "XA" Sleeve (Closed 7/11/97) Baker 2-7/8" x 7 .... FH" Retrievable Packer Baker 2-7/8" x 7 .... FH" Retrievable Packer Otis "S" Nipple, Position No. 3 with "S" Plug Camco, "MM" Mandrel Baker 2-7/8" x 7 .... FH" Retrievable Packer Otis "S" Nipple, Position No. 2 Camco, "MM" Mandrel Baker 2-7/8" x 7 .... Fid" Retrievable Packer Otis "S" Nipple, Position No. 1 Camco, "MM" Mandrel Baker "F" Packer with Stop Sub "D" Nipple Mule Shoe NO. Depth Item Notes A 2,002' B 6,944' C 10,177' D 10,221' E 10,280' 13-3/8" Stage Collar 9-5/8" Stage Collar Fill in Tubing (Perf Debris/Mud) and in Annulus. In 1977 well displaced from 10 ppg Baroid Ligno. Mud to lease crude oil before setting packers.. Otis "S" Plug, Position No. 3. Unable to retrieve due to fill in tubing. Tubing Cut, Schlumberger 2-1/8" Chemical Cutter, 5/11/97 PERFORATION HISTORY Interval Accum. Date Zone Top .... Btm 'Amt spf Comments 5/30/96 G-1 10,147' 10,167' 20' 2 5130196 G-2 10,177' 10,184' 7' 2 3/11/60 H-1 10,226' 10,227' 1' 5 Squeezed WSO 11/13/'77 H-1 10,230' 10,265' 35' 8 11/13/77 H-2 10,275' 10285' 10' 8 11/13/77 H-31415 10,310' 10,394' 84' 4/8 3/11/60 10,402' 10,403' 1' 5 Squeezed 3/17/60 H-8 10,409' 10,478' 69' 4 3/17/60 H-10 10,508' 10,585' 77' 4 3/11/60 10,598' 10,599' 1' 5 Squeezea Wso 3/11/60 10,600' 10,601' 1' 5 Squeezed 3/11/60 WF 10,965' 10,966' 1' 5 Squeezed PBTD = 10,850' TD = 11,315' MAX HOLE ANGLE = Vertical 341-4Draw.doc DRAWN BY: tcb REVISED: 4/30/98 UNOCAL RKB to Tbg. Spool = 17.10' A 3 4 5 6 7 _- G-1 - G-2 Fill C/O 10,685' 341-4PropDraw2.doc SIZE Swanson River Well SCU 341-4 Proposed Completion CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 22" 13-3/8' 7" Tubing 4-1/2" 54,5 29,26,23# 12,6 J-55 8rd/ST&C 12.615 Surface N-80/P-I 10 BTC/8rd LT 6.184 Surface L-80 Mod. Butt. 3.958 17.10' 22' 3,000' 10,992' 9,929' NO. Depth JEWELRY DETAIL OD Item 1 17.10' 2 9,929' 3.875 3 9,930' 4.000 4 9,930' 4.000 5 9,960' 3.810 6 9,961' 3.957 7 9,991' 3.958 Tubing Hanger - Anchor, Seal Assembly - Packer, 7" x 4" Permanent - Tubing, 4-1/2", 12.6~, L-80, Modified Buttress - "X" Nipple Tubing, 4-1/2", 12.60, L-80, Modified Buttress - Mule Shoe , J NO. Depth Item Notes A 2,002' 13-3/8" Stage Collar B 6,944' 9-5/8" Stage Collar C 10,485' Packer, 7" x 4", Baker Model 'F' PERFORATION HISTORY Interval Accun~ Date Zone Top Btm Amt spf Comments 5/30/96 G-1 10,147' 10,167' 20' 2 ~so~ea Sy Scab 5/30/96 G-2 10,177' 10,184' 7' 2 Isolated By Scab 3/11/60 H-1 10,226' 10,227' 1' 5 Squeezed WSO 11/13/77 H-1 10,230' 10"265' 35' 8 11/13/77 H-2 10,275' 10.285' 10' 8 11/13/77 H~3/4/5 10,310' 10,394' 84' 4/8 3/11/60 10,402' 10,403' 1' 5 Squeezed 3/17/60 H-8 10,409' 10,478' 69' 4 3/17/60 H-10 10,508' 10.585' 77' 4 3/11/60 - 10,598' 10,599' 1' 5 Squeezed WSO 3/11/60 - 10,600' 10,601' 1' 5 Squeezed 3/11/60 WF 10,965' 10,966' 1' 5 Squeezed PBTD = 10,850' TD = 11,315' MAX HOLE ANGLE = Vertical DRAWN BY: tcb REVISED: 4/30/98 SWANSON i..VER BOP/WELLHEAD HOOKUP SCU 341-4 F~ow HYDRIL "GK" 7 ~ "5000~ ANNULAR HYDRIL 5000# DOUBLE GATE UUUUU "5000~ CROSS HYDRIL 7 ~ "5000~ SINGLE GATE 61" o000o 24" I I I I 4 24 ~" - Gn:f. /.eve/ SCHAFFER TBG. HEAD (7T55L1) 13 s~ ' 3000~ 13 ~" 3000~ 13 ~" K.D. HEAD 22" L:~DrafUng~WANSON-BOP.Dwg WELL 46 1 ~./16' MANIFOLD. IS D~SIGNED WITH 3 1/8" x 5000 SHA?FER TYPE S T}]ROUGH LINE AND 'SHAF~.~R. 2 1/16" x 5000 TYPE B SIDES. THE CHOKES ARE TRI PLO 3" x 10,O00 2" ORIFICE HYD. 2" X 5,000 1" OR~FICE MAN· ¥1E~ AA DRWB, NO. NWS- 1/87 REI:'. DT. NO. 5~4§ flUG-26-97 TUE 07:47 UNOOhL ~qSSET GRS GR? I*RX N(J. 8u (zu~ (u tq r, u ~ _F"~ - ~> / ~ RECEIVED Pressure Record for MIT on Shut-in Injection Wells -~'~.q 2 G 1997 41as~ .Oil & Gas Cons..Co. mmis~, C( To: From: Larry P. Greenstein @ Unocal (263-7661 or fax 263-7874) , ' "Tubing ....... d'asi.n.g".'] '" outm:Casing ) ' "' Date .... PresSure Pressure Surface PresSure II I III I II III 7/24 2950 1950 0 '" 7'/25 .... 2950 ....... ;1'950 "0 .....7126 ..... 2~00 ..... 1'6:40 I '" 0 " 7/27 ' 2950 ....... 194~ ........ 0 .... 7/28 2940 1940 0 ............ 7/29 2940 1940 0 7~30 2940 1940 0 _ 7/3';I .... 2940 ..... 1~'40 .... 6 ....... 8/1 ' ''2iaoo .... ~95o ' o 8/2 ..... 2900 1950 ' 0 8/3 2900 " 19,~b ............ 0 "' ' 8/4 .... 2875 ........... 1950 ......... 0 8/5 2850 1956 0 8']'16 ............. 2850 ........ 1950 ......... 0 ....... ' ,. ,. ,. i i,, .... .. i , 8/17 2775 1650 0 8/18 ............. 27f~ 1650 ..... 0 .... 8/19 .... ~'~75 ......... 1650 8/20 ' 2790 ..... 1650 ...... 0 8/21 2790 ,1650 0 ' Po;'t-it'X~'a~ ~°te '.'76~ ...... MMENTS: ~o .... l~.,)'/~'~.~, .... C Blair Wondzell ;Phone. ~I~"~ ¢ ~'"'/ Please review these pressures for SCU 341-4 at Swanson River Field. Per your request, a pressure change was generated and then monitored for a few mom days. For our records, could you please sign off on the concurrence line and fax back to me. Thanks for all the patience. As a shut-in injection well, it appears that this well does not pose a significant threat to the USDWs~ · o o.cu : .... Biair i;~'ondzell @ AOGCC /,~-- URUURL Mbb~l ~Hb To: Blair Wonzell From: Larry P, Greenstein Unocal t'H~ RU, ~Uf,'"O31OIq F, Ut Please take a look at these pressures for SCU 341-4 at Swanson River Field. As a shut-in injection well, it appears that this well does not pose a significant threat to the USDWs. If this meets with your approval, can this well be the first of the Swanson wells to complete the State MIT requirements? Please call me with any questions or concerns, t', U~ /24 BI2 BI4 940 0 0 0 0 0 0 0 0 0 0 0 0 0 cOMMENTS: RE' EIVED ~.LI6 ] b 1997 Alas~._Oil .& Gas Cons. C. ommis~ ' ~' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: x Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Unocal Development: 180' RKB feet 3. Address Exploratory: 7. Unit or Property name PO Box 196247 Anchorage, Alaska, 99519-6247 Stratigraphic: Service: x Swanson River Field 4. Location of well at surface 8. Well number 1,000' S, 1,170' WofNE Comer, Sec. 4, T7N, R9W, SM SCU 341-4 At top of productive interval 9. Permit number/approval number Straight Hole 59-14 At effective depth 10. APl number 50- 133-10109-00 At total depth 11. Field/Pool Swanson River/Hemlock 12. Present well condition summary Total depth: measured 11,315 feet Plugs (measured) true vertical 11,315 feet Effective depth: measured 10,850 feet Junk (measured) true vertical 10,850 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 22' 22' Yes 22' 22' Surface 3,000' 13-3/8" 450 sx {~ shoe 3,200' 3,200' ;,,~..; ;..~_';.~'.~, 1750 sx @ DV 2,~~2' Production 10,922' 7" 1,000 sx @ shoe 1,992' 10,992' ,L,4Re~ 692 sx {~ DV 6,944' Perforation depth: measured 10,147'-10,167'; 10,177'-10,184'; 10,230'-10,265';10,275'-10,285';10,310'-10,394';10,409'- 10,478';10,508'-10,585' true vertical 1~~147'-1~~167';1~~177'-1~~184~;1~~23~~-1~~265~;1~~275~-1~~285~;1~~31~~-1~~394~;1~~4~9~-1~~478~; 10,508'-10,585' Tubing (size, grade, and measured depth) 3-1/2" 9.3~ N-80 to 9,892'; 2-7/8" 6.5~ N-80 from 9,892' to 10,557' Packers and SSSV (type and measured depth) 2-7~8 x7" 29~ Baker "FH" packers {~ 9,985'; 10,215'; 10,295'; & 10,394' 2-7/8"x7"29~ Baker "F" packer {~ 10,465 13. Stimulation or cement squeeze summary Intervals treated (meaSured) N/A IntervNal//~ treated (measured) O IGI L Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation ~/~o ~¥§. 16,837 - 3,410 Subsequent to operat!on 6 / 9 6 _~¥~;. . 35 - 1,010 15. Attachments: 16. Status of weli classification as: Copies of Logs and Surveys run: Daily Report of ,Well Operations: X Oil: Gas: Suspended: Service: Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: RECEIVED AUG 2 1 1996 Alaska 0il & Gas Cons. Commission Signed: /r~ ~ ~ ~c~... Title: Drilling Manager Date: 5{~l~J'~8 Form 10'404 Rev 06/15/88 SUBMIT IN DUPLICATE ATTACHMENT #1 WELL SCU 341-4 PERFORATION INTERVALS New Perforations: Bench G-2 Bench G-1 10,147'- 10,167' MD 10,177,- 10,184' MD 10,147'- 10,167' TVD 10,177' - 10,184' TVD RECEIVED OiJ & 8~s Con~. ~ommi~ion Anchorage ATTACHMENT #1 WELL SCU 341-4 PERFORATION INTERVALS New Perforations: Bench G-2 Bench G-1 10,147'- 10,167' MD 10,177'- 10,184' MD 10,147' - 10,167' TVD 10,177' - 10,184' TVD RECEIVED AUG 2 1 1996 Alaska Oil & Gas Cons. I.,~.~t'it'm~mu~, Anchorage Unocal Energy Resources Di' ',n 909 West 9th, P.O. BOX 1962.. Anchorage, AK 99519.-6247 Telephone (909) 276-7600 · ~: .-~...::.~-.: ~:. Fax (907) 263-7828 · . Debra Childers Clerk DATA TRANSmiTTAL 96-13 June 6, 1996 Howard Oakland 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items. -. 0"l'~; Granite Point 1 Anna-21 filer? blackline'" Completion Record 4/01/96 -~'~ Granite Point / Anna-26 ~m / blackline ~' Tubing Packer Setting Record 4/20/96 .... ,2. t~"' Granite Point / Anna-36 ~ blackline,"' Completion' Record 5/20/96 1,~ Granite Point/42-23 RD~m/ blaCkline? Perforating Depth Control 2/17/96 0;~r~ Trading Bay Unit K-26 RD film,-/'blackline~' Main Pass (Collar Locator) , 3/23/96 /'~_ Trading Bay Unit M-5 ~ / blackline~.,' Completion Record -,- 2/14!96 Trading Bay Unit M-25 ¢i~ / blackline,----Completion Record ..... -4/24/96 '0 Ct~Trading .Bay Unit' M-25 1~fl"/blackline~..--l::;ompletion Record 4/30/96 Trading Bay' Unit G-21 ¢ib~1'~,.blackline,.-- CCL/Gamma Ray 4/03/96 .. Trading Bay Unit G'21 f~ blackline--' Cement Retainer .......... 4~08~96 Trading Bay Unit G-21 .fll'm / blackline,-" Completion Record 4/13t96 A;b Trading Bay Unit G-21 ~ / blackline~.-, Completion Record 4/18/96 Trading ,Bay Unit G-21 ~ / blackline--' Completion Record 4/22/96 Trad, ing Bay Unit G-21 [4'ilm / blackline~- Completion Record 4/25/96 , Tradin§ Bay..Unit .G-21 ~/blackline-/ Completion Record/2 118 Energet 3SPF 4/15/96 Trading Bay Unit G-21 ~ / blackline,--- Gamma Ray/Temperature 4/10/96 T~r,.,ading Bay Unit G-21 ¢if"rp / blackline,-" Tubing Cutter ~ 4108196 ~ "'"'"-~'/~c~ 3'.f,[--'4 d~l'm/blackline,-- Completion Record ........... 5117196 -? ,., .. ,.,, . .,.,, , , " 7~ RECEIVED Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 9O7-263-7676 UNOCAL G. Russell Schmidt Drilling Manager Friday, May 10, 1996 Mr. Blair Wondzell AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wondzell: _Gas Injection Test on scu 34.1-~ UNOCAL is proposing to initiate a gas injection test into the Tyonek G-2 interval in SCU well 341-4. The work will ultimately decide the nature of the workover program slated for this year. SCU well 341-4 is an ideal candidate for a gas injection test into the Tyonek G-2 interval. Them is an isolation packer above and below the G-2 interval allowing for complete isolation. The Hemlock interval will be isolated with a tubing plug. As noted on the attached procedure, several steps will be taken to ensure mechanical integrity of the isolation packers. If you have any questions, please contact the undersigned at 263-7676 or Dan Williamson at 263~7677. Drilling Manager GRS/leg RECEIVED MAY 1 4 1996 Naska 011 & Ga. Cons, commiss~ Anchorage ~" STATE OF ALASKA ~'-~' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS "i. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair Well: Plugging: "' Time extension: Stimulatel Change approved program: Pull tubing: Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Unocal Development: 180' RKB feet 3. Address Exploratory: 7. Unit or Property name PO Box 196247 Anchorage, Alaska, 99519-6247 Stratigraphic: Service: X Swanson River Field 4. Location of well at surface 8. Well number 1,000' S, 1,170' W of NE Corner, Sec. 4, TTN, R9W, SM ecu 341-4 At top of productive interval 9,~it numar Straight Hole --- At effective depthORI61N'AL 10. APl number 60-133-10109-00 At total depth 11. Field/Pool Swanson River I Hemlock "12.' Present well condition summary Total depth: measured 11,315 feet Plugs (measured) true vertical 11,315 feetRECEIVED Effective depth: measured 10,850' feet Junk (measured) true vertical 10,850' feetMAY 1 4 1996 Casing Length Size Cemented ~{t~l~lll C01111. C0ffli111~[~/ertical depth Anchorage Conductor 22' 22" Yes 22' 22' Surface 3,000' 13-318" 450 sx ~ shoe 3,200' 3,200' 1750 sx ~ DV 2,002' production 10,992' 7" 1,000 sx ~ shoe 10,992' 10,992' 692 sx ~ DV 6,944' Perforation depth: measured 10,230'-10,265'; 10,275'-10,285'; 10,310'-10,394';10,409'-10,478'; 10,$08'-10,$85' true vertical 10,230'-10,265'; 10,275'-10,285'; 10,310'-10,394';10,409'-10,478'; 10,608'-10,686' Tubing (size, grade, and measured depth) 3-112" 9.3# N-60 to 9,892'; 2-7/8" 6.6# N-80 from 9,892' to 10,557' Packers and SSSV (type and measured depth) 2-?18" x 7" 29# Baker "FH" packers (~ 9,985'; 10,215'; 10,295'; & 10,394' 2-?18" x 7" 29# Baker "F" packer ~ 10,466' 13. Attachements Description summary' of' proposal: X Detailed operations program: X BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: May 14, 1996 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: Gas Injector 17. I hereby~ ~~,~~~~~ct to the best of my knowledge. Signed: Title: Drilling Manager Date: 16-May-96 FOR COMMISSION USE ONLY , , Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity BOP Test Location clearanceI Mechanical Integrity Test ~ Subsequent form required 10- ~ ~ ~ -'~ ~ .n, ,-'~ved Copy Returned Original Signed By - ~//'7. 0avid W. Johnston// /~ Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Soldotna Creek Unit Well 341-4 Isolate Hemlock Injection intervals and Open the Tyonek G-2 for Injection By: S.S. Lambe Date: May 6, 1996 Revision #: Final AFE #: 121985-0-00 Objective: 1) 2) NOTE: SCU 341-4 is currently injecting into the Hemlock intervals. The well has been proposed for a recompletion in the Tyonek G-2 interval. Due to the low pressure of the Tyonek reservoir, a Tyonek gas injection test has been proposed. Well 341-4 is a top structure well for both Hemlock and Tyonek zones. The current completion is set up to allow for injection into the Tyonek below a packer without requiring a rig workover. Pressure test casing by tubing annulus by pressuring annulus to 1,500 psi. Monitor pressure for bleed off?for 15 minutes. Bleed pressure back to 250 psi. Rig up slicldine unit, lubricator and BOPs. Pressure test to 5000 psi against swab valve. Bleed pressure to shut in tubing pressure. MU 2.305" gauge ring and RIH to 10,300'. POOH with slickline. Rig aside slickline. Prior to arming explosives and until explosives are 500' in hole, establish all safeguards for handling explosives. Re- establish safeguards when POOH from 500'. 3) 4) 5) 6) 7) 8) RU APRS unit, lubricator, and BOP's. Pressure test to 5,000 psi against swab valve. Bleed pressure to shut in tubing pressure. RIH with chemical cutter dressed for 2-7/8", 6.5# N-80 tubing. Correlate depth of jewelry per attached tubing tally and fire jet cutter 15' above the packer set at 10,295'. Ensure tubing cut is in the middle of a tubing joint. POOH with E-line & RD. Rig up slickline unit, lubricator and BOPs. MU OTIS S-3 lock and plug profile. Pressure test to 5,000 psi against swab valve. Bleed pressure to shut in tubing pressure. RIH and set assembly in position #3 "S" nipple at 10,221'. POOH. MU PS-3 prong for tubing plug assembly. Note and record SITP prior to setting prong. RIH and set prong in plug profile set in position #3 "S" nipple. POOH with slickline. Pressure tubing to 5,000 psi with injection gas to test plug. Monitor pressure with strip chart for 15 minutes. Bleed pressure to 1,500 psi below SITP and monitor pressure for 15 minutes. Ensure plug is holding. Note: Monitor casing pressure to ensure tubing integrity. Pressure tubing to original SITP with injection gas. MU Kinley tubing punch dressed for 2-7/8", 6.5#, N-80 tubing. RIH and punch two (2) circulating holes at 10,205' and two (2) holes at 9,975'. Monitor tubing and casing pressure for communication. Pressure test tubing to 5,000 psi with injection gas and ensure the packers at 9,958' and 10,215' are holding. If the pressure leaks off?, retest the casing by tubing annulus to 1,500 psi as noted in step # 1. If the pressure test holds, proceed to step # 9. RECEIVED MAY 1 4 1995 Aim~ka 011 & ~aa Cons. Commiuion 9) lO) 11) The tubing pressure leaks off and the casing by tubing annulus holds, the packer at 10,215' is not holding. Pull prong and plug from position 03 and resume injection of gas into the Hemlock formation. The tubing pressure leaks off and the casing by tubing annulus fails, the packer at 9,957' is not holding. MU shifting tool and open XA sleeve at 9,954'. Leave plug in position 03 nipple and leave well shut in. Bleed tubing pressure to original SITP. RIH and recover PS-3 prong from position #3 at 10,221'. MU "W" circulating plug dressed for 2-7/8", 6.5#, N-gO tubing. RIH and set tubing plug at 10,100'. Start injecting gas down tubing to displace the fluid in the 2-7/8" tubing by 7" casing annulus from 9,975' to 10,205'. SI injection gas and allow tubing pressure to fall offto original SITP. RIH and recover "W" circulating plug set at 10,100'. Reset PS-3 prong in position #3 at 10,221'. Pressure test tubing plug to 5,000 psi to ensure prong is set. Bleed tubing pressure to 1,500 psi for negative test on plug. RD Slickline. NOTE: 12) 13) Prior to arming explosives and until explosives are 500' in hole, establish all SCHLUMBERGER safeguards for handling explosives. Re-establish safeguards when POOH from 500'. RU E-Line unit, lubricator, and BOPs. Pressure test to 5000 psi. MU 1-11/16" CCL, GR, and 20' 2" Domed Scallop, O-phase, 4 SPF, 6.5 gram charge. NOTE: 2' DS gun requires a BHP of 3,000 psi while shooting in gas to prevent splitting of the carrier. Maximum gun swell is 2.18" and minimum ID requirements of 2.25". RIH with perforating gun. Lightly tag tubing plug set in position #3 nipple at 10,221'. Pull correlation log from 10,221' up to 9,960'. Correlate depths to DIL log dated 04-Mar-60. Pressure the tubing to 2,450 psi with injection gas (equivalent 3,000 psi BHP ~ 10,000'). Perforate Tyonek G-2 interval from 10,165' - 10,185' DIL Record SITP. MU 2nd 20' gun as noted. RIH and correlate to DIL. Crack well to flow for underbalance & Perforate Tyonek G-2 interval from 10,145' - 10,165' DIL SI well after perforating. POOH with perforating guns and ensure all shots fired. RD E-line and clean up site. Turn well over to production. Start injecting gas into the Tyonek G-2 interval recording pressure and rates every 6 hours for first 72 hours. 17 · 4~26' 6488' 9 345' C.R 2002' 694 4' ,a, 9~7.76' .,,J. · 4bJ~I · '"""'/-' '"' I~<l ' :, . , ~ 6 ~. ~,~ii~' f --: I ' : RePf~ l maes' ........ / ~ - · 40 IG~355.07 -~ ] [ ~,~ [ ~e · ~ l' ~: !1 : . / Ee I! ' / ~ [ :,osea'wso -~ IIO~o~' ~ --~ ' ' ~ ?.:L ll,3~' PUP dT':. · J .,% ~; RECEIVED MAY 1 4 199G Naeka 0il & Gas Cons· Commission Anchorage R. =c :~ x-o;'~. 2 dl'S. 2&" 6.5# K-SO TU3Z:.'O 2~' X 7" B,~-.~. K.-I PAClCt.~R 6.65. 6.10 ' X dr. 2&. 6oSf ll-oO lqJSlKO (v/Pups IO. JI:JO. IS'J ~x.c~, CAM. CO 194 Ik'.A~DRJ.2, Z d.P. 2~f, 6..~f It-IX) 2~g' x ?" DA. lEt ltd PACKgK OH~ "S" I;IPPIZ~ Poaif, lon , II I I II I 31.20 6.6,:1 1.57 b. b3 9.6~ .~, [ SCU 341-4 CASING 8 TUBING DETAIL SECTION 4 T. 7N.,R. DW. FIELD_ _~,..~ ",ZE-~ ~PLINGS: TYPE.~ ~ ..... DELIVERED: JT~ ~OE: DEPTH FLOAT COLLAR: DEPTH, AUXILIARY EOUIPMENT & DEPTHS PROPERTY ~C.:., ..~ , THREADS ~ r-..-! GRADE J"J" ~o . . MAX. O.D ..... USED ..:,',2. JTS.: MAKE & TYPE MAKE & TYPE PAGE_ / OF, _PAGES { WELL NO.~-,:''/' ~'' ~ -! RANGE JOINTS LEFT ON RACK- _~, LENGTH LENGTH L ii i i il i ~ i i i i i · - MEASUREMENTS REMARKS MEASUREMENTS REMARKS ' SHOW ........... SHOW JOINT RACK-LENGTH MADE UP-LENGTH * CENTRALIZER JOINT RACK.LENGTH MADE UP-LENGTH CENTRALIZER ...... & SCRATCHER I ' & SCRATCHER liTEr TENTHS FEET TENTHI 0 EPTHS IrEEr TENTHS FEET TENTH8 0 E PT HS · i i ii ii i i i iiii i ii i i. , ~q / 0 p~. ~ 5~,~ , ~/ ~5' .... ,9 z "rD", ,i~~,,, /~o ~o~,~. ~ "/ ? C~- ,,"~,~-, ~°- ~ ,.~6, .... s G [D~...;~ ~r~, ~z ,_,.,:.:..~,..~'~. , , , , , .,.. .6 ~ ~,,~.. ~.~.~, .., .,,.el s ~3.s~. .~'r'oP ;uG ... s _?/ '70 .... , '~/~'7,6 ....... o $~'~ ·. ~ ~ 85 )-.'/k~ o~c. ~*$/~o .... · /oos-' . .,,~'~ 9~ · . ~/~/ .. ,$/~? o... /5f..R~.~/ ... o,.3/ .?/ ToT~ A /.5;T' 5-Z- TO~'^,. C .2.4 7..q .... 10,393, '35 ....... ' " "1~"~"' ' ' , ~, ~.~ ,~,%.~,... , , .~ /¢ "~" ~,z-.~-~ ,, , · ,~_ ~, .... ,.../~. I,¢ PuP , , ~o GG ........ · /o/~ P~P . .,~¢l ot¢. .... , , , '.., ~1~ . , / /o ~ /~Z'~. :.';," , / ~ ~?~ , ~,~ ?~ , , · ' ~ z~'~, ~ ' ..... ,. ~ /~ P~c~:¢,~ e ,oz~.~o , ~/ ~ ? .... ,.~/~.9 .t~ ~3 ,-- .., .... ~ ~ Ft,~ ~ o 2o ~ ,'-.- . I I I &ill I I I I I ] I I TOT~ B ./~' ' ~/ TOTAL D ~-.~.~D, :? '~ j i , , , i il i i i ill,U i TOTAL THIS ~PE CASING TOTAL ALL CASING ADDED , , , J' TOTA~ ~CK MADE UP REMARKS TOTAL RACK MADE UP , ,, ~ ,, ,, , iii i i i i ~' " r " ,o,~, ~'"'/~. ~ ' ,~ ,o,,~J ..... '~C,, ~'~?.' ~' :. ' . ,, ~.. To~L .... ~K~!%~ ......... ,~, ~ ~ , , ~ · PAGE TOTAL ~;Y: ~ · :j ~ . ~L I ~ ' I , i , I , p~X.,,~D., .......... ~'~V ~ 4 1996 T°TAL .......... , , _ ~ml~t ..... NOTE~: STAIrr Nfl SHEET FOR EACH DIFFERENT GIt&DE O1~ WEIGHT OIr CASUJG Naska 0it & Gas ConG.<)~i .,, , . Ll~irttod im U.:;. A.' Anch0rag ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering September 16, 1992 Commissioner Leigh Griffin Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for SCU 341-4 Mechanical Integrity Test. Dear Commissioner Griffin: Attached is a Report of Sundry Well Operations for a successful, state witnessed, Mechanical Integrity Test on SCU 341-4. The Well Service Report is included for reference. If you require further information, please call Jim Zernell at 263 4107. Sincerely, J. C. Winn Acting Regional Engineer JCW:JLB:0183 Attachment CC: Mr. L. R. Dartez, Jr. Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation RECEIVED S E P ~ 1 1992 Alaska Oil & Gas Cons. Commissto" Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ORIGINAL 1. Type of Request: Operation Shutdown ~ Stimulate Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other X MIT Z. Name of Operator ARCO Alaska, Inc, 3. Address P. O. Box 100360, Anchoral~e, AK 99510 4. Location of well at surface 5. Type of Well: Development Exploratory Stratigraphic Service 1000' N, 2070' E, SE comer, Sec. 4, T7N, R9W, SM At top of productive interval Straight Hole At effective depth At total depth 1 Z. Present well condition summary Total Depth: measured true vertical 11315' feet 11315' feet Plugs (measured) 6. Datum elevation (DF or KB) 167' KB 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 341-4 9. Permit number/approval number 59-14 / 92-081 10. APl number so-133-10109-00 1 1. Field/Pool Swanson River-Hemlock feet Effective depth: measured true vertical Casing Length Structural Conductor 22' Surface 3000' Intermediate Production 10992' Liner Perforation depth: measured Current: 10,850' 10,850' Size 22" 13-3/8" feet Junk (measured) feet Cemented Measured depth Yes 22'MD Yes 3000' MD ,! Yes 10992' MD Yes 10230' - 10375' True vertical depth 22' TVD 3000' TVD 10992' TVD 13. true vertical Current: 10230' - 10375' Tubing (size, grade, and measured depth) 3-1/2" 9.3# N-80 to 9892' MD; 2-7/8" 6.5# N-80 from 9892'-10557' MD Packers and SSSV (type and measured depth) Baker "FH" Pkr @ 9958', 10215', 10295', 10394",: Baker "F" @ 10465' MD Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure RECEIVED S EP ~: 1 Alaska Oil & Gas Cons. 14. Representative Daily Averaae Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 33000P/D 0 2000* 5600 Subsequent to operation 0 33000P/D 0 2000* 5600 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X_._ Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned //c.~..~_~/~~ Title Cook Inlet Regional Engineer Form 10-404 Rev 06/15/88 Service Gas Injector Date SUBMIT IN DUPLICATE * Note: Pressure is being maintained on production casing to assist in "seating" the sealant material. The pressure will be bled off after an indeterminent period of time. WELL WELL Bi;RVICE REPORT iPBDT IFIELD - DISTRICT - STATE OPERA-'I;ION AT R~EPOI=IT TIME ii i · KI-L.F'! V El.) [] CHECK THIB BLOCK IF SUMMARY CONTINUED ON BACK W"thlr ITMn,. l Chill Plat~ , Vl.lblllty iWlnd ~.1. AW _ OF' 'FI mli~ "'-"' "I ~mm,~ AlaSka OJi & Gau Oon~. GOF,;~.,t?in~ A~nhnrnn_n HAHE Ceatpony TYPE OF PIS ,P, ItPJLUS TVD FLUID N) )0 o CASII, K~ TBG REG $tZE/WI/(ZAI~ SlZ[ 'IT. ST PR[SS PRETEST 5TART 15 KIl~ 3,0 _Il_IN TBG 'TIE TIE IlHE CSG I'BG TBG 18G F1~55 CSG CSG CSG p_nE_s~ PRESS PRF~S COl~prt$: CII~IIIS: ~lU..AB P,,.UI D: i I, IF.~L GLYCQL SAU VAIDI qUIING INJEClIQII fLUIDI P - I'BglI/CE BI'Et II'lJ S - SALT WATEII IS - HISCIBLE IHJECIlOH I ' IAJECTIHG N - mT INJECTIPG olm cfn C.O~ {rev QS/IOIR] IIELL TEST: Initial · floyear._~_~.~' Irorkover F. xplatp Al)GCC Ill II'SS S I OIAILF~ COlfNtY ~ $1(A, IATUIRE: o~ Z O~ fll ARCO A~aska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering April 3, 1992 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Submittal of Application for Sundry Approval for SCU 341-4 Mechanical Integrity Test Dear Mr. Smith: Attached is an Application for Sundry Approval for a Mechanical Integrity Test on SCU 341-4, to comply with UIC Rule No. 6, to test tubing-production casing integrity. Also a proposed operations plan and well schematic for SCU 341-4 are included for reference. If you require any further information in this regard, please do not hesitate to call Jim Zemell at 263-4107. Sincerely, J. C. Winn Acting Regional Engineer TW:DRH:czm:0129 Attachment CC: Mr. W. Watson Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation RECEIVED Alaska Oil & Gas Cons. Comm'tss'ton Anchorage ARCO ~ Inc. is a Sul~dlary of Allantic Richfield Company STATEOFAIASKA0 R 1 6 1 N A !. ALASKA OIL AND GAS CONSERVATION ~MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well _ AIt~r easing _ Repah' well_ Plugging _ Time extension _ Stimulate ._. Change approved program _ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1000' S, 1170' W of NE Corner, Sec. 4, T7N, Rgw, SM At top of productive Interval Straight Hole At effective depth Pull tubing _ 5. Type of Well: Development Exploratory Stratigraphio Service Variance Perforate Other X {MIT1 6. Datum elevation (DF or KB) 180' KB 7. Unit or Property name Swanson River Field 8. Well number feet 9. Permit number 10. APl number At total depth 12. Present well condition summary Total Depth: measured true vertical 11315 feet Plugs (measured) 11315 feet 11. Field/Pool Swanson River / Hemlock 13. Effective depth: measured 10850' feet Junk (measured) true vertical 1 0850' feet Casing Length Size Cemented Structural Conductor 2 2' 2 2" Yes Surface 3000' 1 3-3/8" Yes Intermediate Production 1 0992' 7" Yes Liner Perforation depth: measured Current: 10230' - 10375' true vertical Current: 10230' - 10375' Tubing (size, grade, and measured depth) 3-1/2" 9.3# N-80 to 9892'; 2-7/8" 6.5# N-80 from 9892' - 10557' Packers and SSSV ( type and measured depth ) Baker "FH" - 9958' Baker "F" - 10465' Attachments Description summary of proposal _ Measured depth True vertical depth 22' 22' 3000 3000' 10992' 1O992' RECEIVED APR - 6 1992 Alaska 0il & Gas Cons, Commission Detailed operation program ~( BOP sketch _ 14. Estimated date for commencing operation Mav. 1992 16. If proposal was verbally approved 15. Status of well classification as: Oil __ Gas _ Suspended Name of approver Date approved Service 17. I hereb<b.y_ca~ify that the foregoing is true and correct to the best of my knowledge. ned ~;~--~,.~,--~~--~ Title Cook Inlet Regional En~r. FOR COMMISSION USE ONLY Conditions of approval: Notify COmmission so representative may witness Plug integrity_ @O~P Test_ Location clearance__ Mechanical Integrity Test/~ Subsequent form require 10- /--~ Approved by the order of the Commission Form 10-403 Rev 5/03/89 IApproval N~:~,2 ,-~ ~7 , ORIGINAL SIGNED BY LONNIE C S~,~ITH Commissioner Date SUBMIT IN TRIPLICATE ARCO Alaska, Inc. Internal Correspondence D a t e: March 31, 1992 File Code: SCU 341-4 (WS) SCU 312-9 (WS) Subject: MIT on SCU 341-4 and SCU 312-9 From/Location: Hyeh-Yeon Hoffer ATO- 1388 Telephone: x1355 To/Location: S. DeJamett KI Please perform Mechanical Integrity Tests (MIT) on Wells SCU 341-1 and SCU 312-9. These two gas injectors are 1992 MIT candidates. The tests are required to comply with Rule 6 of the Swanson River Field Area Injection Order No. 13. The last tests were performed on 6/30/88 for both wells. Pre-test these wells to detect any leakages. If excessive pressure loss greater than 10% in 30 minutes is detected, notify Anchorage office for diagnostic procedure. To allow time for possible delay, please plan to complete the tests by May 31, 1992. The attached procedure outlines the MIT for SCU 341-4 and SCU 312-9. The procedure includes loading the tubing by production casing annulus (TbgxPC) and the production casing by surface casing annulus (PCxSC) with inhibited lease water before the actual MIT on TbgxPC. The well locations are shown in Attactment I and the schematics of these wells are also included. The AOGCC and BLM must be notified at least 24 hours in advance to witness the test. Please call me at the above extension or Jim Zernell at extension 4107 if you have any questions regarding the procedure. ' / . : ~ ") Hyeh-Yeon H6ffer Cook Inlet Engineering Attachments CC: V. L. Ferguson Baker/Brown Rugen/O'Dell J.T. Zernel~ ARCO Alaska Inc. is a sti~dia~ o/Agantio RbhCmkl Company AR31~I-A ATO- 1396 ATO- 1370 SRF SRF ATO- 1366 RECEiyrcO Alaska Oil & Gas Oons. oomm'~s¢Or~ Anchorage s. Veaarne~t March 31, 1992 Page 2 SCU 341-4 Objective: To load TbgxPC and PCxSC and to verify the mechanical integrity of the TbgxPC prior to the AOGCC witnessed MIT. Well data: A vertical well; a gas injector Capacities: Top pkr. depth: Current Pressure: Injection Rate: SC testing Pressure: 3-1/2" to 9892' MD; 2-?/8"to 9958' MD 7"; N-80 and P-110; 23, 26 and 29 lbs/ft to 11,315' MD; wall thickness = 0.317" 13-3/8"; 54.5 lbs/ft to 4228' MD TbgxPC= 0.0265 bbl/ft PCxSC= 0.1070 bbl/ft 9958' MD Tbg = 5570 psi; PC = 900 psi; SC = 65 psi 37 MMSCFPD 2500 psi Procedure: . . . . . . . . Load TbgxPC and PCxSC with lease water Install a two-pen recorder to monitor SC and PC pressures. Shoot fluid levels on TbgxPC and PCxSC. Calculate needed load volumes and prepare the fluid. If no loading is needed, skip to step 1 Y. Monitor Tbg, PC and SC pressures throughout the Job. Hold a safety meeting. RU choke and gas buster to SC, as needed. Blow down SC pressure without allowing fluid production. Hook up the pump truck to SC and pressure test lines to 4500 psi. Load PCxSC with lease water containing 0.25% WR676 corrosion inhibitor and a 5 bbl crude cap. Do not exceed SC pressure of 300 psi when pumping. RECEIVED APR - 6 199~ Alaska Oil & Gas Cons. 6omm'tss~On S. DeJarnett Mm'ch ~1, !992 Pa~e 3 SCU 341-4 (continued) . 10. Repeat steps 5 through 8 for the PC, as needed. Do not exceed the injection pressure of 3000 psi for PC in Step 8. Contact the Anchorage office to verify that sundry approval has been obtained before proceeding with the MIT. 11. 12. 13. 14. 15. 16. 17. Pressure test TbgxPC Record the pressure of Tbg, PC, and SC. Leave well on normal, lnJec on. Pressure TbgxPC in steps up to 2500 psi. Hold for 5 minutes in each step, observing pressures on Tbg, PC, and SC. Limit the SC pressure to 300 psi. Hold the final testing pressure of 2500 psi for 30 minutes. Observe the initial and final pressures on TbgxPC. Pressure decline should be less than 10%. Notify the AOGCC and BLM at least 24 hours in advance. Repeat the test for AOGCC and BLM. Alaska Oil & Gas Cons. Anchorage March 31, 1992 Page 4 $CU 312-9 Obiective: To load PCxSC annulus and TbgxPC annulus and to verify mechanical integrity of TbgxPC. Well data: A vertical well; a gas injector SC: Capacities: Top pkr. depth: Current Pressure: Injection Rate: SC testing Pressure: 4" to 9236' MD; 3-1/2" to 10,053' MD; 2-7/8" to 10,150' MD 7"; N-80 and P-110; 23, 26 and 29 lbs/ft to 10,785' MD; wa_Il thickness=0.317" 13-3/8" 54.5 lbs/ft to 2998' MD TbgxPC= 0.0238 bbl/ft PCxSC= 0.1070 bbl/ft 10,150' MD Tbg= 5350 psi; PC = 2250 psi; SC = 10 psi 46 MMSCFPD 2600 psi Procedure: . . . . . . . . Loading of TbgxPC and PCxSC with lease water Install a two-pen recorder to monitor SC and PC pressures. Shoot fluid levels on TbgxPC and PCxSC. Calculate needed load volumes and prepare the fluid. If no loading is needed, skip to step 11. Monitor Tbg, PC and SC pressures throughout the job. Hold a safety meeting. choke and gas buster to SC, as needed. Blow down SC pressure without allowing fluid production. Hook up the pump truck to SC and pressure test lines to 4500 psi. Load PCxSC with lease water containing 0.25% WR676 corrosion inhibitor and a 5 bbl crude cap. Do not exceed SC pressure of 300 psi when pumping. RECEiVeD s. D~Jarn~tt Mm'ch ~1, 1992 Page 5 8CU .~12-9 (co~,,t,l~ued) , 10. Repeat steps 5 through 8 for the PC, as needed. Do not exceed the injection pressure of 3000 psi for PC in Step 8. Contact the Anchorage office to verify that sundry approval has been obtained before proceeding with the MIT. 11. 12. 13. 14. 15. 16. 17. Pressure test TbgxPC Record the pressure of Tbg, PC, and SC. Leave well on normal.injection. Pressure TbgxPC in steps up to 2600 psi. Hold for 5 minutes in each step, observing pressures on Tbg, PC, and SC. Limit the SC pressure to 300 psi. Hold the final testing pressure of 2600 psi for 30 minutes. Observe the initial and final pressures on TbgxPC. Pressure decline should be less than 10%. RDMO. Notify the AOGCC and BLM at least 24 hours in advance. Repeat the test for AOGCC and BLM. RECEIVED APR - 6 I~92 Alaska.Oil & Gas Cons. Comm~ssio'r~ Anchorage Attachment I SCU 312-9 ! I I I I~__, I~__. 34-10 I Unit Boundary I ~---~ .~~ ( .~ ~ Cen~ SCU 341-4 ! I r--J I I · I ~ J r-J J ' I Falult Block RECEIV[D Alaska Oil & 6as Oons. Anchorage Swanson River Field Structure Map Hemlock Formation ¢.P. 2002° CP. 694 4' 2 PuP · .RECEIVED .Alaska Oil & 6as 6ohs. Commission . ~1059~'W$0 'ii I~°a°q' li~,o,~ o,' a.~ ~o,~, - ' ~ ~.:~, 11,~1~ Anchorage ~,ue~'eY-' - 2~,,x ~ x-o;~ 2 J?So 2,~" 6..~# t;-80 TUDZ::O 9,95~.57' OTIS "IA" 2}~" x 7" IIAKgR FII PACKI~R Oi'I:~ "~,". IIZPPI.~, Position I Jr. 2~,, 6..~ CA~CO ~L~ ~A~D~gL · J?. 2~. 6..~ 'M..~O rU."ING BA~[R YH PACKE.:i OTX~ "~" NIPPLg, Position t2 I J/'. 2~. 6..~ g-~ TUBIgO (./Pups 10.1¢'.I0.1Y) ~l..~;a, .2~' x 7" DAX~ V~ PACKF, R O.r~; "S" NXPPI..-'., Posit.ton #1 · · 1 Jr. 2,~" 6.5t R-,O TI~. i~l~t "1m PACI~r.'R ~/ STOP SUD ~ '3" I:XPPI. g · Jr. '~* 6o.g.~ ::-~,0 T'J31::G I I II 6.63, Jl. Tu' · · il.67' .~2 2Y.]C SCU :541-4 CASING 8~ TUBING DETAIL SECTION 4 T. TN.,R. 9W. .i 1(.9. 17o20 ~ Top o£ Ce3J. ez' Top oZ' Coller ~ KB Tub.t~ Ha.,~er · 29~ Jts &a O,D. 18.60' 9199.22 9235.57' - · )-- X-OV"g~o 3~?EUE 8rd F /," O.:3./Z.D. 2.5' 1,10" ...... 2l 2'/ Jt. 3~" L"d~ 8rd Tbg, 816.65' · ~u~.j -1~- x-cv~ 2A" x 3~," o.~o' 30,08A.74*-A ,, . 10,116.51 e . ~ 1 P~, 2, x? 2~ $.~ lO,29~.~,~ [ t ;t ~. E~ ~ ~. · 29.~'. 10t3~7t ~ · .v~mm ow . ~ ~ S" ~~, ~mit~n t3 (~v) t.~' ~/~ ~ ~' ~t. ;~ S~ ~ Tbf, ~,98' ~"~ " '- a~ P~ . ' ~0,~.~' ~ STOP ~ ~0.~' 10,~9.~t[ m ST~ SU3 ~ ~ for B~'rM. .2 ~m ;~, ;;; ~ TrW, v/au ~' ~=p o~ Plug 10,700' · RECEIVED : . APR-61~92 · T,D. 10,?S5, Alaska Oil & 6as Cons. CommissiOn · : ..... ............ Anchorage S;C U 312-9 CA;SIN & TUBING DETAIL SECTION 9 T.7N.R.9W. -" STATE OF ALASKA '~ '. ALAS/--"iOIL AND GAS CONSERVATION COM"*'~SION ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other I~ Mechanical Integrity Test 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 180' KB Feet 3. Address 6. Unit or Prop...e. rty narj3e Post Office Box 100360 Anchorage, AK 99510 Swanson I~ver ~eld 4. Location of well at surface 1,000' S and 1,170' W of NE corner, Sec. 4, T7N, R9W 7. Well number $CU 341-4 At top of productive interval Straight Hole At effective depth At total depth 8. Approvalnumber 8-489 9. APInumber 50-- 133-10109-00 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 22.' Surface 3,000 ' Production 10,992' Perforation depth: 10,230 - 10,375' 11,315' feet 11,315' feet 10,850' feet 10,850' feet Plugs (measured) Junk (measured) Size Cemented Measured depth True Vertical depth 22" Yes 13-3/8" Yes 22' 3,000' 22' 3,000' 7" Yes 10,992' 10,992' Tubing (size, grade and measured depth) A'mg~a 0[~ 3-1/2" 9.3# N-80 to 9,892'; 2-7/8" 6.5// N-80 from 9,892 - 10,~5~'' Packers and SSSV (type and measured depth) Baker "FH" - 9,958', 10,215', 10,295', 10,394'; Baker "F" - 10,465' 12. Stimulation or cement squeeze summary Intervals treated (meaSured) N / A Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average 17,~Xl~ll~l~(~X)~Xlnjection Data OiI-Bbl Gas-Mcf Water-Bbl 40,501 38,501 Casing Pressure ~bing Pressure 2,300 5,350 2,300 5,450 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~//.~. Signed Title Senior Area Engineer Date Form 10-404 Rev. 12-1-85 Submit in Duplicate , . . JUL-OI-'~ 07:S3 ID~ 'ARCO Alaska, Inc: {) 8ul~dl~ of AtWnttc I~hfleld Oomp~my CONTRACTOR · h.o.s.~. /.~.L..,v, REMARKS TEL NO: 1 :~B~ ~'x '] FIELD' DISTFIIOI' - STAT,~ IOPEFIATION AT REPORT TIME #62? P01 - "· WELL SERVICE REPORT l OA,,~,~ IDATE !--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK W#th~r I Tmmr~. 1 Chill Factor--I VIIIbililv l Wind Vel, ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering June 21, 1988 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: 1987-88 UIC Pressure Testing - Swanson River Field Wells SCU 312-9, SCU 341-4, and SCU 323-4 Dear Mr. Chatterton: Attached are Application for Sundry Approvals to pressure test three subject injection wells in compliance with the Swanson River Field Area Injection Order No. 13. These three pressure tests comply with the requirement to test 25 percent of the gas injection/water disposal wells each year. All efforts will be made to complete testing by June 30, 1988. Sincerely, Tom Wellman Senior Area Engineer TW:MLE:ch:0009 Attachments CC: J. A. Dygas, Bureau of Land Management J. Coltart, Chevron USA D. Jones, Marathon G. Graham, UNOCAL 'RECEIVED JUN 2 3 1988 Naska 0il & Gas tens. Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI~$1ON APPLICATION FOR SUNDRY APPROVALS I Type of Request: Abandon E3 Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing ~ Pressur, Time extension [] Change approved program [] Plugging [] Stimulate I-I. Pull tubing ~ Amend order [] Perforate [] Other [~ Test 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360 Anchorage, AK 99510 4. Location of well at surface 1,000' S & 1,170' W of NE corner, Sec. 4, T7N, RDW At top of productive interval 5. Datum elevation(DF or KB) KB 180' 6. Unit or Property name Swanson River Field feet 7. Well number SCU 341-4 8. Permit number Straight Hole At effective depth At total depth 9. APl number 50-- 1 ~- 10109-00 10. Pool Hem Iock 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 22 ' Surface 3,000 ' Production 10,992' Liner Perforation depth: 10,230 - 10,265'; 10~275'- 11,315' feet 11,315' feet 10,850' feet feet 10,850' Size Plugs (measured) 10,285'; Junk (measured) Cemented Measured depth True Vertical depth 22" yes 22' 22' 13-3/8" yes 3,000' 3,000' 7" yes 10,992' 10,992' 10,320 - 10,332'; 10,340 - 10,375' RECEIVE JUN 2 3 ]988 Tubing (size, grade and measured depth) 3-1/2", 9.3#, N-80 to 9,892'; 2-7/8". 6.5#, N-80 from 9 892- 10,557'Alaska0tl&$asc°ns' Packers and SSSV (type and measured depth) , · Anchorage 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch - 13. Estimated date for commencing operation Testing to be completed by 7/1/88 14. If proposal was verbally approved Name of approver Form No. ~Dated ff-//~5'~ Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed -'7'~-~ ~ ~ Title Senior Area Engineer Date Conditions of approval Approved by Form 10403 Rev 124-85 Commission Use Only Notify commission so representative may witness r-I Plug integrity [] BOP Test [] Location clearance ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned Commissioner _ IApproval No..~...~ by order of the commission Date Submit in triplicate SCU 341-4 LOAD PRODUCTION AND SURFACE CASING AND PRESSURE TEST PRODUCTION CASING Loading 1. 2. 3. 4. . . PC and SC Annulus Record pressures on the tubing, production casing and surface casing. Blow down PC to 1,000 psi, recording all pressures. Blow down SC, recording all pressures. Shoot fluid levels for pump-in volumetrics. (Annular capacity (Bbl/ft.): SC = 0.1070, PC = 0.0264). Load SC with lease water containing 10 gal./100 Bbls WT 676 corrosion inhibitor and a 5 Bbl crude cap. Do not exceed 300 psi surface pressure during pump-in. Monitor all pressures. Load PC with lease crude. Do not exceed 2,500 psi during pump-in. Do not bleed PC below 1,000 psi during pump-in. Pressure Testing Production Casing NOTE: 24 hours prior to initiating pressure testing procedure, contact the Alaska Oil and Gas Conservation Commission at 279-1433 and the BLM at 267-1240, and inform them that a pressure test will be conducted as per Rule 6 of Swanson River Field Injection Order No. 13. NOTE: During pressure tests of production casing, closely monitor PC/SC packoff to insure no communication to the surface casing. If any communication is noted, cease pressure test and notify Engineering in town. . Install two pen chart recorder for tubing and production casing. Inject into tubing at usual rate. 8. Pressure test PC/SC packoff to 3,000 psi. . Pressure production casing to 2,000 psi. Hold for five minutes, observing pressures on tubing, production casing and surface casing. If initial pressure is already at or above 2,000 psi, proceed to Step 10. 10. If no significant pressure changes occur within five minutes (>50 psi), increase production casing pressure by 500 psi. Hold pressure for five minutes. 11. Repeat Step 10 until a pressure of 3,630 psi is reached. minutes, noting initial and final pressure on all strings. · KI: I:/V I:U JUN 2 1988 Alaska 011 & Gas Cons. Commission Anchorage 422C' 4526' 6488' 17. ~c C.P. C.P. 694 4' 9,953.57" 324 JT$. 3~' 9.3~ N-~)TU.31EO RECEIVED JUN 2 3 ]988 Alas~.Oll & Gas Cons. Commission ' ~ohorage ~" ~ ~ x-orr,. OTIS ~'_.' eL~ "REPERF / ~ ~ I.I :10275'--p--F 10285' K~ ~ . . ' ,32' ~~oI 10394' 10,39~.23' ~ .1040~' IO,~CC'.~, ~ . 10508' ~0, 5~ .~ '" . ~:~: ~: II : II ~ t ~,os~a'wso · i IlOSOq' 1o]0' 60.~ J.lY' b.Oa ' 6.65, 1.uO' 6.92' 6.10' 1o~0' 0 rJ5 "S" I~IP?4~,, Position #1 I J'J. CAY. CO A~2:, · 1 dP. 2~" 6.5# t;-~O Tm. i3AK~t "Y" PACKgR #/ StOP SOB x ,~?. a ~, I:IPPLE · Jr. II I1! II III I · CASING 8~ TUBING DETAIL SECTION 4 T. 7 N.,R. gW. SCU 541-4 b.b] 31.7u' 9.69 · · 31.67 .92' I ~1.20' 6.63' I 59-o/,-/ SWANSON RIVER WELL ~1~ .__ SRU --SRU ~ SRU ~'~CU tSCU ~ SCU ~ SCU ~ SCU .SCU ~ SCU 5 1 / ~/"r~ - SRU 312-2~ 314-27 331-2-7 323-4 332-4 341-4 341-8 312-9 321-g 323-9 432-15 TYPE Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Water Injector STATUS AS OF 1/1/88 Shut-in Shut-in Shut-in Injecting Injecting Injecting Shut-in Injecting Injecting Injecting Shut-in GRU13/2c RECEIVED Alaska Oil & Gas Cona. Commission TABLE I Wells under Evaluation for Rate Potenti al 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 Wells being Evaluated for P&A/Future Util i ty 212-10 21-15 31-15 34-15 432-15 312-22 212-27 14A-33 12-34 22-23WD 243-8 14-34 Wells SI for Inefficient Producti on 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until B1 owdown 43A-15 314-27 331-27 '"343-33 ARCO Alaaka, Inc.~ Post Office B~^ 100360 Anchorage, Alaska 99510-0360 Telephone 907 265 6369 John C. Havard Engineering Manager Cook Inlet/New Ventures July 14, 1987 Mr. C. V. Chatterton Alaska Oil.& Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Re-. Swanson River Unit: Gas Injection Well Production Casing Pressure Tests Dear Mr. Chatterton- Attached are seven (7) Well Service Reports documenting the results of the recent pressure tests conducted on Wells SCU 314-4, SCU 323-4, SCU 332-4, SCU 341-4, SCU 312-9, SCU 321-9, and SCU 323-9. The other active gas injection well, Well SCU 341-8, is currently loaded with kill weight fluid in anticipation of a late-September workover to repair a packer leak. Of the seven gas injection wells tested, only one (Well SCU 323-4) did not meet the criteria stated in Rule 6 of the AOGCC Area Injection Order No. 13. The remaining six wells held their calcu- lated test pressure (within 10%) for 30 minutes. The test pressure for each well was calculated to generate a differential pressure gradient across the casing of 0.25 psi/ft at the vertical depth of the uppermost packer. The surface pressures in Well SCU 323-4 have stabilized at acceptable levels (PC +_1500 psig, SC +_I00 psig). We will be retesting this well for integrity in the near future. AOGCC and BLM representatives will be notified 24 hours in advance of this test, should they wish to be onsite. Until that time, we propose to continue injection into this well. If you need additional information, please contact H. F. Blacker at 263-4299. Very truly yours, JCH:JWR'cI:0004 Attachments cc: Mr. Joseph A. Dygas - Bureau of Land Management ARCO Alaska. lnc ,S a Subs~d~ar'y of AllanlicRichfieldCompan¥ .... _. ARCO Alaska, Inc. 4~ WELl. II~I~T ~,,/,/- .¢ I REMARKS ..... IFIELD · DISTRIGT · $'fAT~,: OPERATION AT "EPO~T TIGE WELL SERVICE REPOR [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeJther Tirol). J Chill Flctm J Vlllbllity Wind Vel. ATTACHMENT E-I Injection Well Data Water Disposal, Avg. Max. Avg. Wells Rate(BPD) Rate(BPD) Press(ps!) SRU 31-33W 327/+ SRU 32-33W 651 SRU 4I=33W 125 SRU 2t-33W < 2S05 scu/+3-/+w. 5' .... /+500 /+500 /+500 8500 /+500 769 778 913 735 Shut In Max. Press(psi) 1000 1000 1000 1000 1000 Depth of Inj,(ft,) 2100 2100 .2.~.s2 2.1.2_.0 3100 Depth of Well(ft.) 2/+61 2520 3000 38O. 5.. 6660 Gas Injection Ave. Wells Rate(MCFD) Max. Rate(MCFD) SCU 31-/+-2 .39,950 SCU 323-/+ 35,680 SCU 332-/+ · 27,6/+0 3/+1-/+ 37,6/+0 3/+1-8 30,300 ;U 31'2-9 /+/+, 000 SCU 321-9 29,940 scU 323-9.... ~ 35,920 SCU 3#3-33 0 SRU 332-1.5 0 SRU 312-22 0 SRU 31/+-27 0 SRU 331-2~7 Is 0 /+5000 45000 45000 /+5000 /+5000 /+5000 /+5000 /+5000 /+5000 /+5000 /+5000 /+5000 /+5000 f_/.,e o,v, o¥ 0,7 e/[s ' - 5075 5370 5095 5355 5160 5270 5155 5105 Shut In Shut In Shut In Shut In Shut In 5800 '5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 10291 1039/+ 10470 10226 10256 10183 1029/+ 10280 10695 11388 1075/+ 111/+6 1080/+ 11520 10775 11119 10850 1081/+ 10785 10745 10750 10995 11982 11000 1143/+ 11620 ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAO 25.2.52 09-Sep-87 ARCO Alaska, Inc. 110500 Name of Operator SWANSON RIVER FIELD - UNIT 051950 Field and Pool August 1987 Month and Year of Injection 11. WELLI2. API NUMBERI.5. C~4. FIELD~5. DAYSI TUBING PRESSURE ~ CASING PRESSURE 50- ~ LI & POOL ! IN ~ I ~ Al CODE I OPER 16. MAXI7. AVERAGE~8. MAX 9. AVERAGE NO. I I I .514-4 525-4 .5.52-4 541-4 541-8 .512-9 52.5-9 ._'-'.43-55 1412-10 .521-9 4.5-4WD I SI I I PSIG I PSIG I___SI I I 155-10104-00 IG I 772100 I .50 15,450 I 4,958 1.55-10106-00 18 I 772100 I 0 I 0 I 0 1.5.5-10107-00 IO I 772100 I .50 15,500 I 5,005 155-10109-00 IG I 772100 I 30 15,550 I 5,141 155-10120-00 IG I 772100 I 0 I 0 I 0 155-1012.5-00 IG I 772100 I 54) 15,.550 I 4,945 135-10126-00 18 I 772100 I .50 15,300 I 4,928 155-101&8-00 IG I 772104) I 0 I 0 I 0 155-20206-00 IG I 772100 I 0 I 0 I 0 15.5-10125-00 IG I 772100 I 50 15,450 I 4,991 155-10111-00 ID I 772056 ~ 0 '1 '0 I 0 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 PSIG 5,500 0 1,040 2,860 0 1,240 2,600 0 0 1,960 0 PSIG 2,559 0 656 0 1,109 2,568 0 0 1,815 0 DAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION. 1 10. LIQUID Ill. GAS I 15, LIQUID I 14. GAS (BBL) (MCF) I (BBL) I (MCF) I I I 1,177,165 I 0 I 948,955 I I I I I I I I I I I I 0 1 I I I I I I I I I t I I I II hereby certify that the foregoing is true and correct to the best o~ my knowledge 1 l ISigned I 1 I ITitle I Form 10-405 Rev. 12-1-85 INSTRUCT IONS ON REVERSE SIDE 59,259 Ol 51,632 57,120 OI 40,48.5 35,148 Ol 0 25,706 115. TOTAL 113,609 I 0 1 ,~14,475 I 054,428 I I I I 0 1 I I I I I I I I 0 0 771,182 I l I I I I I I I l I I I I I I I I 0 I 6,279,814 I Submit in Duplicate I I I I I' I I I I I | ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTIONREPORT 20 AAC 25.232 ARCO Alaska, Inc. 110500 Name of Operator SWANSON RIVER FIELD - UNIT 051994 Fi eld and Pool August 1987 Month and Year o~ Injection NO. | 50- I :512-22 :153-10147-00 :G 1514-27 1153-10154-00 ~G 1531-27 1155-1015&-00 :G :1. WELL:2. APl NUMBER:5. CI4. FIELD L~ & POOL A~ CODE S~ :452-15 ~21-35WD ~51-55WD :52-35WD :41-53WD ~ 772100 I 772100 I 772100 155-10141-00 IG I 772100 133-101&2-00 ID ~ 77203& 133-20356-00 ID I 77203& .133-10164-00 ID ~ 772036 153-10167-00 ID I 772036 I I I I : IN ~ I ~ OPER 16. MAXI7. AVERAGEI8. MAXI9. AVERAGEIIO. LIQUID Ill. GAS (MCF~ 5. DAYSI TUBING PRESSURE I CASING PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION I 13. LIQUID I 14. GAS I PSIG : PSIG I PSIG - I I ~ - I I I - I I : - I I I I 29 I 875 I 754 I I 29 I 820 I 746 I 0 I 30 I 875 I 759 I 0 1 30 I 850 I 751 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 l 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 II hereby certify that the foregoing is true and correct to the best o{ my knowledge I I I Si gned I I I ITitle I Form 10-405 Rev. 12-1-85 .ate ?' INSTRUCT IONS ON REVERSE SIDE (BBL) I I (BBL) I I I I I I I I I I 2,675 I I 77,581 2,770 I I 80,318 2~071 I I 62,119 145 I I 4,352 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 l I I I I- I15. I I I I I I I I I I I I l ITOTAL I 224,370 I I Submit in Duplicate PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUOHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUOHOE PRUDHOE PRUDHOE .. UN UN UN UN BAY UN BAY UN BAY UN BAY UN BAY UN BAY UN BAYUN BAY UN BAY UN 'BAY bN BAY UN BAY UN BAY UN BAY UN BAY UN T S-11 T S-14 T T-1 T T-7 T T U-~ T T U-9 T U-.lO T X-6 T X-11 T X-23 T X-2q T X-26 T Y-3 T T Y-6 T Y-7 IT Y-11RD BAY UNIT Y-18 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL SNANSON RIVER, HEMLOCK OIL POOL ARCO ALASKA INC SOLDOTNA CK UN SOLDOTNA CK UN SOLDOTNA CK UN SOLDOTNA CK UN SOLDOTNA CK UN SOLDOTNA CK UN SOLDOTNA CK UN SOLDOTNA CK UN ........... SOLDOTNA CK UN SOLDOTNA CK UN UNI T 314-4 T . 323-h T 332-~ T 341-4 T 341-8 T 312-9 T 321-9 T 323-9 T 412-10 T 343-33 T OR LEASE TOTAL 3o9;53 264,~25 , 174,~67 380,162 602,357 515,072 264,751 183,322 244,173 294,661 149,980 173,544 262,057' 282,344 76,492 49,131 84,323 22,223 43,679 306,429 14,519,526 39,536,156 39,536,156 88,810,1~0 SOLDOTNA cREEK UNIT 1,148,650 1,080,598 871,402 1,090,670 153,799 1,246,967 749,378 1,089,518 SHUT-IN SHUT-IN 7,430,982 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 6 30 31 31 6,975,040 7,115,160 1,241,472 2,275,741 2,727,957 2,791,~76 2,551,632 1,790,980. 1,767,557 6,174,166 . 5,618,096 3,530,342 5,273,083 3,169,181 3,942,403 1,968,753 2,653,403 102,640 597,32.1 6,409,296 1,388,876 294,742,915 233,327,280 207,759,340 231,764,932 218,694,647 304,044,302 33,033,842 170,911,513 111,~13,676 - - ENHANCED RECOVERY - - ALASKA INDIVIDUAL NELL PRODUCTION FOR MARCH, 1987 NELL NAME AND NUMBER ARCO ALASKA INC SNANSON RIV UNIT 331-27 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL TRADING BAY, MICDLE KENAI C OIL POOL UNION OIL CO OF CALIFORNIA AOL-18731 TRADING BAY ST. A~SRD-2 TRADING BAY ST A-12RD TRADING BAY ST A-26 TRADING BAY ST A-29 UNIT OR LEASE TOTAL POOL TOTAL TRADING BAY, MICDLE KENAI O OIL POOL UNION OIL CO OF CALIFORNIA ADL-18731 TRADING BAY ST A-SRO-2 TRADING BAY ST A-19 UNIT OR LEASE TOTAL POOL TOTAL FIELD.TOTAL Gl L(BBL) NTR(BBL) GAS(MCF) DAYS SI4ANSON RIVER UNIT SHUT-IN SHUT-IN-"'~. SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN T,~30,982 7,430,982 CUH. OIL CUM. MATER 413,93~ 15,582,616 4,498,822 6,267,061 7,3~8,68~ 21,618,136 CUM. GAS 28,263,659 ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.252 ARCO Alaska, Inc. 110500 Name of Operator SWANSON RIVER FIELD - UNIT 051~4 Fi eld and Pool December 1~86 Month and Year of Injection I1. WELL NO. I 1312-22 -J514-27 $51-27 '~1432-15 I I I I · 1 2. API NUMBERIS. C;4. FIELDIS. DAYS: .TUBING PRESSURE I CASING PRESSURE ~DAILY AVERAGE INJECTION~TOTAL MONTHLY INJECTION 50- I LI & POOL I IN I I ~ I I Al CODE I OPER 16. MAXIT, AVERAGEIG. MAXI~. AVERAGE:IO. LIQUID 111. GAS I 15. LIQUID ~ 14. OAS I SI 155-10147-00 I G I 772100 155-10154-00 I G I 772100 155-10156-00 I G I 772100 155-10141-00 I G I 772100 I 1 I I I I PSIG I PSIG I PSIG I PSIG I (BBL) ~ (MCF) I (BBL) 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 r 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 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 II II 11 I I I I ~'~~ ,"' ~ ! ~ :1..- I I I I I I I .. I I I I I I I I I (MCF) I I ' I I I I I I I I I I I II hereby certif)6 that the forego~'ng I Si gned _ I I Supervi~ New Ventures Compliance and Revenue ITi~le Form 10-405 Rev. 12-1-85 is true and correct to the best of my knowledge 115. I : ~las~a Oil & Gas : : - An=t:,om~--: 1 TOTAL I 0 Date __~_/_~_~ INSTRUCTIONS ON REVERSE SIDE 0 Submit in Duplicate ARCO Alaska, Inc. 110500 ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.232 SWANSON RIVER FIELD - UNIT 051950 December 1986 il. WELL I NO. I. : I I 314-4 I 323-4 -I 532-4 :-~.-~' t 34 1 '4 ~ / ~, *~**~ 541-8 I 312-9 I 323-9 1412-10 ~ 321-9 I I I I I I I I I I I I I ..-'. Name of Operator Fi eld and Pool Month and Year of Injection 2. API NUMBERIS. Ct4. FIELDIS. DAYSI TUBING PRESSURE I CASING PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION 50- I LI & POOL I IN I I I I I S'I I__.SI 133-10104-00 lB I 772100 1555-10106-00 IG I 772100 1 133-10107-00 IG I 772100 15555-10109-00 IG I 772100 153-10120-00 IG I 772100 153-10125-00 IG .I 772100 135-10126-00 IG I 772100 155-10168-00 IG ~ 772100 1355-20206-00 IG ~ 772100 1553-10125-00 IG I 772100 I I I I I I I I I I I I I t I I I t I I I I I I I I I I I I I I I I I I I I AI CODE I OPER 16. MAXI7. AVERAGEI8. MAXIg. AVERAGEIIO. LIQUID Ill. GAS I PSIG I PSIG I PSIG I PSIG I (BBL) I I ...... I I ...... I I I 550 15,5500 I 5,013 12,500 I 1,560 I I 50 15,650 I ' 5,278 1,3,250 I 1,976 I I 30 15,500 I 5,071 I 700 I 594 I I 50 15,550 I 5,1,57 11,200 I 849 I I 30 15,;300 I 4,882 11,400 I 1,5548 50 15,000 I 4,697 12,850 I 1,267 I I 17 15,200 I 5,140 11,600 I 1,388 0 I 0 I 0 I 0 I 0 I I 0 I 0 I 0 I 0 I 0 I I 30 15,5540 I 5,130 11,600 I 1,089 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 I I I I I I I I I I I I (MCF) 552,501 29,526 24,038 29,951 25,121 55,165 25,550 0 0 20,970 15. 'LIQUID I 14~ GAS I (BBL) I I (MCF) I 975,018 I 885,785 I 721,155 I 898,524 I 695,626 I I 1,054,878 I 450,602 I 0 1 0 1 629,091 I I I I I I I I I I I I I I ) I I I I I I I I I .I f I ~ ! I I I I I II hereby certify that thee for~~ is true.and correct to the best of my knowledge ', - 1Signed ....... -__ I I Super , New Ventures Compliance and Revenue / ~. ~__~___~_~_~ ITitle Date -_ Form 10-405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE I15. TOTAL I p' .......~ I I I I' I I I I I I I I 0 I ~288~&55 I I Submit in Duplicate LEASE NO. I ENHANCED RECOVERYI COHP. DATE 4 ~ STATU~ PRODUCT JAN FEB MAR ALASKA INDIVIDUAL HELL%ODUCTION FOR 1986 YEAR APR MAY JUN JUl AUI~ ~EP OCT NOV DEC TOTAl_ CUM. ~~ SHANSON RIVER, HEHLOCK ARCO ALASKA INC SOLDOTNA CK UNiT ~Z~-~ APT UNIT051950 OIL '08/15/60 NTR l$INJ GAS 1055857 1026590 1189909 1165806 1228646 1211657 1257286 1288552 1305704 1~25075 1022955 975018 15808655 2917855~5 SOLDOTNA C~ UNIT ~2~-6 APT ~-~n~n¢-nn UNIT051950 0IL 06/01/61 HTR GINJ GAS 926806 895795 101~89 1021515 1095847 109595~ ~110742 ~160265 1~65222 986857 950909 885785 125059~2 250~68775 SnlnOTNA CE UNiT ~2-6 API Z~-~n~n7-oo UNIT051950 0IL 06/05/60 HTR 1GINJ GAS 729520 694699 694207 ?68554 848986 808659 855?55 906429 908925 775879 755048 721155 9465572 205554815 UNIT051950 0IL 05/21/60 HTR 1GINJ GAS 96q~82 95989? 11055~0 100q702 1191630 1125q55 115189~ 1167267 1142665 98956? 10q7597 89852~ ~2728~66 2288q5715 $OL~OTNA CK UNiT ~61-R AP! ~-~n~?n-nn UNIT051950 0IL 07/~/61 HTR 1GINJ GAS 772050 72~011 855765 795562 858795 85180! 877~66 885419 86145~ 802085 790782 695626 976~772 _~0LnOTNA .C[ UNIT 5~?-q AP! UNIT051950 0IL ~0/09/60 HTR 1GINJ GAS 1150860 11052q6 1275~68 1219~5~ 1266~62 124282! 1268188 1518592 1512222 ~120~5 1~59677 ~05~878 [qqSqZS! 50078q5~5 SOLDOTNA CK UNIT 52~-q AP! UNIT051950 0IL 07/~9/61 HTR 1GINJ GAS 787999 770786 9~1516 857121 859651 824009 859794 852q54 865q41 701058 65788~ 629091 95~656q 51111755 SOLDOTNA CK UNIT 323-q APT UNIT051950 0IL 07/17/61 HTR 1GINJ GAS 868162 887705 1057~0~ 1002092 1041454 1027008 105~526 1105448 1110180 1002927 967125 ~50602 11552~55 1681~5955 SOLDOTNA CK UNYT 412-10 UNIT051950 Oil 06/11/72 HTR ° 1HINJ GAS SOLDOTNA CK UNiT 5~-55 UNIT051950 OIL 05/08/61 HTR ' 1GINJ GAS --. SHAN$ON RZV UNIT ~2-15 UNIT051994 0IL 10/2~/$9 HTR ' 1GINJ GAS SHANSON RZV UNIT 54-15 UNIT051994 0IL 08/04/6! HTR 1G~NJ GAS AP! l~-lOl&~-O0 API l~-ZOl~l-O0 AP! 155-10142-00 13888. 111415676 q018206 9029559 2056925 4645530 III 4 + LEASE ND. IENHANCED RECOVERYI COMP.DATE + ................. + STATUS PRODUCT JAN FFR HAR ~~ SWANSON RIVER, HEMLOCK SHANSON RIV UNIT 312-22 API UNI'TO51qg4 OIL ALASKA INDIVIDUAL HELL~ODUCTION FOR APR MAY JUN JUL AU~ 133-10147-00 1986 SEP OCT NOV YEAR TOTAl. CUM. 08/11/62 HTR 1GINJ GAS SWANSON RIV UNIT UNITOS]qg40TL 514-27 API 135-10154-00 s7 gss 24017269 06/14/60 HTR 1GINJ GAS SWANSON RIV UNIT UNITOBlqg~ OIL 331-27 API 153-10156-00 78332178 02/17/58 HTR 1GINJ GAS , , --- ARCO ALASKA 28265( OPERATOR TOTALS OIL HATER 8,337,995 POOL TOTALS GAS 7,0~1,527 7,852,406 8,187,302 8,680,226 7,499,819 6,288,655 1,929,187,012 7,215,396 8,113,868 8,369,449 8,393,451 8,667,789 7,311,775 93,601,663 SHANSON RTVER. HEMLOCK OIL HATER 8,557,995 FIELD OAS 7,041,527 7,852,406 8,187,502 8,680,226 7,499,819 6,288,655 1,929,187,012 7,215,396 8,113,868 8,569,449 8,393,451 8,667,789 7,511,775 93,601,663 SWANSON RIVER TOTALS OIL HATER 8,337,995 GAS 7,0~1,527 7,832,406 8,187,$02 8,680,226 7,499,819 6,288,655 1,929,187,0'- 7,215,396 8,113,868 8,369,449 8,393,451 ~,667,789 7,311,775 93,601,665 __ ~ - OHEOK THIS BLOCK IF SUMMARY C, ONTINUED ON BACK W, ithw J T,m~.l chin F,eto~-lW~ibmty lWl,d V,I. :::; "iS~O~KJ~ ..,,, ~orm 3160--5 (November 1983) (Formerly 9--331) U, ,'ED STATES (Other lustruetb, sa DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~e this form for proposals to drill or to deepen or plug back to g ail[stent reservoir. Use .'APPLICATION FOR PERMIT--" for such Form approved. Budget Bureau No. 1004-0135 Expires. August 31, 1985 5. LEASE DBIIONATiON AND INIIAL NO, 6. Ir INDIAN, ALLOTTBN ON TIIBB NAME ?. UNIT AORBBMBNT i. Soldotna Creek Unit WELL WEI. L 8. rA~M OI LBAIB NAMB 2.NAMB OF OPESATOI ~CO Alaska, Inc. o. 3. ADDalISa or OPERATOR P.O. Box 100360, Anchorage, AK 99510 4. LOC&TIO~ OF WELL (Report location clearly and tn accordance with any State requirements.° Se~ also space 17 below.) At surface Soldotna Creek Unit - 7 wells 14. PERMIT 16. EleVATIONS (Show whether or, RT, 10. FIBLD AND POOL; OB WILDCAT Swanson River Fimld NUBVN! OI ABJIA Sec. 4, 9, T7N, R9W Kenai ] Alaska 10. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICB Or INTENTION TO: FRACTURE TREAT MULTIPLE COMPI.ETE SHOOT OR ACIDIZB ABANDONS RF. PAIR WELL CHANGE PLAN~ WATaR SHUT-Or# : amramzwo WaLL FRACTURB TIIATMgNT . ALTBRINO CASINO 8H~TINO OR ACIDIZINO ABAN~NMBHTO (Other) (NOTS: Re.ri resulm of multiple ~mpleflon on W~ Completion or aecompletlon Re.ri tod ~f form.) (Other) X PresSure Test ~,~," ',E.%('R:IIX I'ROI'OSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including ~flmate5 date of starting an. proposed work. If well is directionally drilled, give subsurface Ioeatlons and mens. red and true vertical depth~ for all markers and son~s p~rtl- nent to this wor~) * The AOGCC has issued Area Injection Order No. 13, applicable to Swanson River Field, effec- tive March 16, 1987. To comply with Rule No. 6 - Demonstration of Tubing/Casing Annulus Mechanical Integrity, ARCO Alaska, Inc. is planning on pressure testing the production casing annulus of each active gas injection well at Swanson River to a surface pressure sufficient to generate a differential pressure of 0.25 psi/ft between the uppermost packer and the formation. The wells included in the program are wells 314-4, 341-4, 312-9, 323-9, 321-9, 323-4, and 332-4. The attached procedures outline the steps that will be taken to conduct the test. The wells are currently being loaded with fluid in the production casing and surface casing annuli. The pressure testing is expected to occur in the last two weeks of June, 1987. RECEIVED .J U N -'- ?, !.9~:7 Ataska 0il & Gas Co.s. Commission Anchorage 1.~. I hereby certlfy~-hat the forel~gng is tr~e and correct SlOHED~ Regional Engineer TITLE (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, LP ANY: TITLE DA~ *See Inmuctions on Reverie Side Title 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 [Ini~cl ,~t~t~'~ any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. SCU 341--4 LOAD PRODUCTION AND SURFACE CASING AND PRESSURE TEST PRODUCTION CASING Lo.a..d.ing PC and SC Annulus 1. Record pressures on the tubing, production casing and surface casing. 2. Blow down PC .to 1000 psi, recording all pressures. 3. Blow down SC, recording all pressures. . Shoot fluid levels for pump-in volumetrics. Estimated volumes from most recent fluid level data are noted below. . Load SC with lease water containing l0 gal/lO00 gal WT 676 corrosion inhibitor and a 5 bbl crude cap. Do not exceed 300 psi surface pressure during pump-in. Monitor all pressures. . Load PC with lease crude. Do not exceed 2500 psi during pump-in. Do not bleed PC below lO00 psi during pump-in. Pressure Testing Production Casing Note: 24 hours prior to initiating pressure testing procedure, contact the Alaska Oil and Gas Conservation Commission at 279-1433 and the BLM at 267-1240, and inform them that a pressure test will be conducted as per Rule 6 of Swanson River Field Area Injection Order No. 13. Note: During pressure tests of production casing, closely monitor PC/SC packoff to insure no communication to the surface casing. If any communica- tion is noted, cease pressure test and notify Engineering in town. 7. Pressure test PC/SC packoff to 3000 psi. Be Pressure production casing to 2000 psi. Hold for five minutes, observ- ing pressures on tubing, production casing and surface casing. If initial pressure is already at or above 2000 psi, proceed to Stepq. . If no significant pressure changes occur within five minutes (~50 psi), increase production casing pressure by five hundred psi. Hold pressure for five minutes. 10. Repeat Step 9 until a pressure of 3630 psi is reached. Hold pressure for 30 minutes, noting initial and final pressure on all strings. Volumetrics Fluid Level (3/11/87) Annular Capacity (bbls/ft) Estimated Fluid to surface .(bbls Surface Casing 335' .1070 36 Production Casing 3844' .0264 1 O1 TRANSMITTAV'-'~ND ACKNOWLEDGEblENT OF RECEIPT r"',~b\TERIAL - (ALASKA) .- DATE 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. . _ JqZ -3~ _q , q ii i ii i i i i -- ii - i i i · _ BOX 7-839 REMARKS O,N OTHER SIDE, THIS SHE'ET ANIOHORAGE, ALASKA 99510 ,, CHEVRO.N.U.S.A. TRANSbIITTAL ~D ACKNOWL.EDGEbIENT OF RECEIPT ~. MATERIAL - (ALASKA) TO: DATE STATE OF ALASK. A -'. "' '"' ~ OIL .o $001 PORCUPINE DRIVE .." ANCHOR'AGE,ALAsI~A 99504 -.-----,?-r ?.,' ~ ....... -o ..... . "'THE FOLLOWING ISA LIST OF MATERIAL ENCLOSED HEREIN. INDUCTION ELECTRICAL LOG DUAL INDUCTION LATEROLOG BOREHOLE CO~'~ENSATED SONIC BOREHOLE CObhP. SONIC ;.:/caliper BOREHOLE COMP. SONIC w/gamma BOREHOLE TELEVIE~rER CONTINUOUS DIPbfETER. High ,Res. CDM - POLYWOG PLOT CEMENT BOND LOG C.A.$!yC. CO!.T.AR I.N~ -- P~r£. Re~'. COI~PENSATED FOR>~TION DEN. COMPENSATED NEUTRON FOR~LATION ~NALYSIS LOG FO~'~TION DENSITY LOG F F FO~TION TESTER FO~TION FACTOR F F G~ =Y - NEUTRON ~"~ [~ C~ 'O~ ~Y COLL~ LOG ~- M~CAO LOG MI CROLATEROLOG A ,0 ~,p ~ ~D LOG NEUTRON LOG DJ;qs/0o c~ t~,. ~.:,,'~'. ' ....... '"':'" '~"'~,',':;iio~: -- '- PROXIbIITY MICROLOG ~,[:c:'hOl RWA COP~ARISON PLOT .. S~DSTONE ~YSIS SA~D SIDEW~L NEUTRON .POROSITY SONIC ' TEb~E~TU~ LOG 4/-/7 PLEASE CHECK AND' ADVISE I,~DfEDIATELY. I I I0O 2oo DIRECTIONAL SURVEY CORE DATA SARABAND TABULAR LISTING Received and checked by: ~.~.'-,"-t'v~. ~. ~.L~~_.~./-' By: cx-mw, O.s.A. BOX 7.839 ANCTIORAGE, ALASKA 99510 CHEVRON U.S.A. INC. C O~,~?LETION REPORT Remedial Work AREA: Swanson River Kenai Peninsula Alaska PROPERTY: Soldotna Cree~.~ Unit WELL NO: SCU LAND OFFICE: Anchorage LEASE NO: A-028997 LOCATION AT SURFACE: 1000' So. and 1170' West of NE CORNER Section 4, TTN, RgW LOCATION AT DEPTH: Straight Hole ELEVATION: 180' KB DATE ,--,,-,__BY:' · Area Engi4~eer DRILLED BY: Brinkerhoff Rig #31 DATE WORK COMMENCED: November 7, 1977 DATE WORK COMPLETED: November 17, 1977 S~Y TOTAL DEPTH: 11,315' PLUGS: 10,850' EFFECTIVE DEPTH: 10,850' cASING: 22" cemented at 22'. 1B-3/8" cemented at 3000'. D.V. collar cemented at 2002'. 7" cemented at 10,992' · Cemented through perforations at 10,965', 10660' and 10,226'. Water shut off on holes at 10,598' and 10,226'. PERFORATIONS-CURRENT WELL STATUS 10,230' - 10,265' l0,275' - l0,285' 10,310' - 10,39~' 10,h09' - 10,h78' 10,508' - 10,585' lO,2B0' - 10,265' ) Reperforated 10,275' - 10,285' ). Reperforated 10,320' - 10,332' ) Reperforated 10,3~0' - 10,375' ) Reperforated LOGS:-THIS REMEDIAL WORK Dresser Atlas G~mma Ray-Neutron with Collar Locator 10,15~'-10,512' i Run ~ovember 7, 1977 Accepted rig at 5:00 a.m. Conditioning and building mud weight and volume. 7~ pcf mud _N_ovember 8, 1977 Using Byron-Jackson pump truck pumped ~02 barrels of 73-7h pcf mud to kill well. Cut mud to 69 pcf. Circulated and built mud to 71+ pcf. With rig pumps circulated, built volume and weight to 73+ pcf. Flowed tubing. Possible heavy spot on annulus - circulated - no heavy spot located. Flowed tubing. 7~ pcf mud November 9, 1977 Circulated, built mud to 75~76 pcf. Killed well and pulled lines. 75+ pcf mud November 10, 1977 Rigged up and tested B.O.P.E. to 5000 psi per Spec. D-17. Opened ports and released from packers. Pulled out of Baker Model F packer at 10,485'. Circulated and conditioned mud. Nov. e~ber..ll, 1977 Recovered 3~", 2-7/8" tubing and production jewelry including split mandrel at 10,131'. 75 pcf mud November 12,..1977 Ran in hole with 2-3/8" and B~" tubing string. Stabbed thru Baker Model F packer at 10,485' and ran tubing to 10,560'. Circulated' and conditioned with gas cut mud. 75+ pcf mud / · November 13, !9!7 Reperforated intervals lO,2BO' - 10,265' 10 275' - 10 285' lO,B20' lO,B~O' and 10,375' - 10,B75' with h - ~" jet cut holes per foot. Circulated and cleaned hole with 7" casing scraper. 75+ pcf mud November _lb, and 15, 1977 Hydro-tested and ran 2-7/8" and B~" production string in hole. Stabbed into Baker Model F packer at 10,h85'. (See attached) Rigged up Dresser Atlas and ran in hole. Short circuit in line - pulled out and repaired. 75+ Pcf mud November 16, 1977 Ran Gamma Ray-Neutron Log with Collar Locator interval lO,15~' - 10,512' to orientate packers. Landed tubing with 4000 psi on stop sub. Installed Cosaco plug. Removed B.O.P.E. Installed tree and tested to 6500 psi. Displaced with 400 barrels lease crude. November 17, 19.77 Closed "XA" sleeve at 995B' . Set Brown plug in "D" nipple at 10,526'. Rig released at 6:00 p.m. S. S. SHIPPY 'C.P. 2OO2' C,P. 6944' 9,953.57 ' ' ~, 957.76' <,,...- 2 PUP ,ITS, 3~' 9.3// (10.[~5' - 5.~0') .- 324 JTS. 3~' 9.3# N-80 TUBING 2%. x' x-orca 2 JTS. 2~" 5o5# N-80 TUBING OTIS "IA" SLEEVE 2~' x 7" BAKER FH PACKER 1,].0 60. 3.19' 6.O'~ ' · il 11o6oo' ~ i'~p or Plug 1o,85o, 8-J~. 2~" 6°5// N-80 TUBING 2~" x 7" BAKER Fit PACKER O?IS "S't NIPPLE, Position #3 z Jr. 2~,, 6.~// ~-~o TOSING · . CAMCO MM t/~NDREL 250.25' 1 JT. 2¥ 6.5~ N-~JO 'tUBING 6.65' 1o60' 31.2~' ~o92' 31°h~' 6~10' OTIS "S" NIPPM'~, Position #2 1o50' 1 JT. 2~" 6o~# N-OO TUB'~r¢G (w/Pups JO.l{'.JO.l~') 1 Jr. 2,~." 6.5# N-DO TOBIHO 2~" x 7" BAKER Fi{ PACKER OTiS "S" N1PPLE, Position #1 1 J~. 2~" 6°5// N-50 TBO. (w/Pup BAKER "P' PACKCR W/ STOP SUB 1 JT. 2~" 6.5f N-60 TO:lING "D" NIPP~ 1 J'~. .~" 6.5,~ N-hO TUBINO , , 8.08, 31.20, 6.63' 41. % ' b.b3' 31.7o' 9.6;~' 31.67 ' .92, 29.]~' SCU 341-4 CASING TUBING DETAIL SECTION 4 T. 7N.,R.9W. CHEVRON U.S.A. INC. COMPLETION REPORT Remedial Work AREA: Swanson River Kenai Peninsula Alaska I2%ND OFFICE: Anchorage LEASE NO: A-028997 PROPERTY: Soldotna Cree~. Unit WELL NO: SCU 3~1-. ~ LOCATION AT SURFACE: 1000' So. and llT0 ' West of NE CORNER Section ~, TTN, RgW LOCATION AT DEPTH: Straight Hole .~..~ ELEVATION: 180' KB DATE~-/~/-~BY~ ', .,~.' Mat Auk7 Area Engi4~eer DRILLED BY: Brinkerhoff Rig #31 DATE WORK CON~4~2~CED: November 7, 1977 DATE WORK COMPLETED: November 17, 1977 SUMMARY TOTAL DEPTH: 11,315' PLUGS: 10,850' EFFECTIVE DEPTH: 10,850' cASING: 22" cemented at 22'. 13-3/8" cemented at 3000'. D.V. collar cemented at 2002'. 7" cemented at 10,992'. Cemented through perforations at 10,965', 10660' and 10,226'. Water shut off on holes at 10,598' and 10,226'. PERFORATIONS-CURRENT WELL STATUS 10,230' - 10,265' 10,275' - 10,285' l0,310 ' - l0,39~ ' 10,bO9' - 10,h78' 10,508' - 10,585' PERFORATIONS-THIS R~DIAL WORK 10,230' - 10,265' ) Reperforated 10,275' - 10,285' )~ Reperforated 10,320' - l0,332' ) Reperforated 10,3b0' - 10,375' ) Reperforated LOGS:-THIS REMEDIAL WORK Dresser Atlas Gamma Ray-Neutron with Collar Locator 10,154'-10,512' 1 Run ,, November 7, 1977 Accepted rig at 5:00 a.m. Conditioning and building mud weight and volume. 74 pcf mud ~pvember 8, 1977 Using Byron-Jackson pump truck pumped 402 barrels of 7B-7~ pcf mud to kill well. Cut mud to 69 pcf. Circulated and built mud to 71+ pcf. With rig pumps circulated, built volume and weight to 73+ pcf. Flowed tubing. Possible heavy spot on annulus - circulated - no heavy spot located. Flowed tubing. 74 pcf mud November 9., 1.977 Circulated, built mud to 75~76 pcf. Killed well and pulled lines. 75+ pcf mud November 10, 1977 Rigged up and tested B.O.P.E. to 5000 psi per Spec. D-17. Opened ports and released from packers. Pulled out of Baker Model F packer at 10,485'. Circulated and conditioned mud. 75+ pcf mud November ll, .1977 Recovered 3~", 2-7/8" tubing and production jewelry including split mandrel at 10,131'. 75 pcf mud N?,vember 12, ,1,977 Ran in hole with 2-3/8" and 3~" tubing string. Stabbed thru Baker Model F packer at 10,485' and ran tubing to 10,560'. Circulated and conditioned with gas cut mud. 75+ pcf mud November. 13,'1977 Reperforated intervals' 10,230' - 10,265', 10,275' - 10,285', 10,320' - 10,340' and 10,375' - 10,375' with 4 - ~" jet cut holes per foot. Circulated and cleaned hole with 7" casing scraper. 75+ pcf mud ~ovember 14, and 15, 1977 Hydro-tested and ran 2-7/8" and 3~" production string in hole. Stabbed into Baker Model F packer at 10,485'. (See attached) Rigged up Dresser Atlas and ran in hole. Short circuit in line - pulled out and repaired. 75+ pcf mud November 16, 1977 Ran Gamma Ray-Neutron Log with Collar Locator interval 10,154' - 10,512' to orientate packers. Landed tubing with 4000 psi on stop sub. Installed Cosaco plug. Removed B.O.P.E. Installed tree and tested to 6500 psi. Displaced with 400 barrels lease crude. November 17, 1977 Closed "XA" sleeve at 9953'. Set Brown plug in "D" nipple at 10,526'. Rig released at 6:00 p.m. S. S. SHIPPY 302 · ~ 6488' -C.R 2002' 6944' '- 9,953.57' f 102~0' ' / nE PERF l ~ ~,o~' 40' 10,35h.O7 '~ / 10394' 10~39~.23~ 10409' -: 10,1~)~ .39 ' / / 10 r ,,.~ l :loses' 10, ~)0.3~ IO598'wso i'Jp or Plul~ 10 850' .......... T.P. 1!,315' 2 PUP JTg. 3~'' 9.3// (lO.hS;' - 5..q;O') 324 JTS. 3~' 9.3# N-80 TUBING 2 JTS. 2~" 6.5~/ N-80 TUBING OTIS "×A" SLeeVE 2~' x 7" BAKER FH PACKER ,3'IS. ~" 6.5# N-80 TUBING 2~" x ?" BAKER Fit PACKER Otis "S'~ NIPPLE, Position #3 · . CAMCO MM BAKgA FH PACKg~ OTiS "S" 1 JT. 2~" 6.~# N-~O TUBING (~/Pups lO.i~'-lO,l~'} CA~CO P~ ~NDAgL 1 aL 2~'. 6.5// N-~O TUBING 2%" ~ 7" ~K~. FH PACKER OTIS "S" NIPPY, Position #1 CAMCO 1,~ MAND~EL BAKEt{ "~' PACK~ w/ STOP SU~ 1 JT. 25" 6.~# ~ O" NIPP~ 1 JT. ~" 6.~// N-hO T,,B,.,,O _ _ -, ,, _ , m mm .......... SCU 1o10' 60.55 ' 3.1~' 6,0'4 ' 6.65' 1.60' 31- 2 ~ ' ~.92' 31oh~ ' 6.10 ' 105o ' 51o iJh ' 8. b8' 31.2~' 6.63 ' 1.57 ' 41. gi~ ' ~.03' 31.70' R.62' 31.67 ' .92' 29° 341-4 CASING TUBING DETAIl_ SECTION 4 T. 7N.,R.9W. Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE 'SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use ',APPLICATION FOR PERMIT--" for such proposals.) WELL NAME OF OPERATOR C'nevzon U 3. ADDRESS OF OPERATOR ?. o. ~d:)x 7-839, ~her&ge, /slC-99510 4. LOCATION OF WELL At surface ~.000' S ~ 1170' W Of ~ ~~ O~ 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 166' G.L 14. CheCk Appropriate BOx To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 133-10109-00 6. LEASE DESIGNATION AND SERIAL NO. &-028997 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME l~l.{lotaa Creek 9. WELL NO. SCU 341-4 10, FIELD AND POOL, OR WILDCAT S~anson River t~eld 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 4, TTR, Rgw, SB~d4 12. PERMIT NO. 3ort, or Other Data NOTICE OF INTENTION TO; TEST WATER SHUT~)FF L---J FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL _ (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE.. Report results of multiple completion on Well . Completion or Recompletion Report and Log form.) i5. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. a.nd ~etu~n troll to gas t,n~lon as per the &t~&che~ px~am. 16. I hereby certify that the foregoing is t~ CONDITIONS OF APPROVAL,-~F ANY:~ Petroleum Engineer DATE. See Instructions On Reverse Side October 20, 1977 DATE Approwd ~ ..... Returned / /ton · CHEVRON U.S.A. INC. TRJ~NSbIITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF MATERIAL - (ALASKA) PLACE:' ATT. DATE THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. · PLEASE CHECK AND ADVISE IMMEDIATELY. i ii RECEIVED 8Y TRANSMITTAL ~' 'CKNOWLEDGEMENT OF RECEIPT OF ~ ]RIAL - (ALASKA) DEPT.: FD - Folded PLACE_ .~~: O .... :/~ . . RS _- Rolled Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. COMPANY ~,C- ~dCai L , ,.~ ,, , , WELL HISTORY LOG 2" 5" ! - ' .., ,,, I00 200 e4-9 ~p.~-IS', , 'I2!~R&K,.N. C'F OIL AND GAS 'ED BY REMARKS 0 THEE SLOE, THIS SHE'ET STANDARD OIL' COMP.'~LNY OF 'CALIF. SCU- Field SWANSON RIVER 'Form ti n HEMLOCK : .......... ~. ................ __ ..... . ........ fl 0 : ............................ .Well" · 341-4 ! ', 0 ................. } L~I~ .o,,. tx 'F OiL AND GAS ANCHORAGE 4.871 SOUTHAMI:'ION DR ANCHORAGE., ALASKA 99503 TEL .5r'7,- P72 596( NORTH STAR ENGINEERING, JHC. RF.$F:RVOIR PRESSURE ~k TEMP..DA-Fa C~;4C'') '~tL!': 4 NC) : ,~. I A i .~ ' .\', .: I 1 , · : NORTH STAR ENGINEERING, INC. 100 W. INT'L. AIRPORT RD.. STE. 205 RESERVOIR PRESS. AND TEMP. DATA ANCHORAGE. ALASKA 99502 RESERVOIR fLUID samPLINg TELEPHONE {907) 272-5966 OILAND GAS WELL TESTING Company. STANDARD OIL COMPANY. OF CALIF. Location Well ...... SCU 341--4 Field SWANOSN RIVER State ....... ALASKA Borough, . KENAI Formation HEMI/DCK Date 10 APRIL 1975 DATE TIME CHRONOLOGICAL DATA REMARKS ELAPSED GAS TIME. VOL HR.MIN MCFD TBG CSG PRESS PRESS PSIG PSIG GAUGE #33496-N BHP@ R.D. 10330' 10330' -10150 BHP@ DATUM .-10300 09:00 11:00 11:30 11:40 12:00 12:05 12:15 12:15 12:16 12:17 12:18 12:19 12:20 12:21 12:22 12:23 12:24 12:25 12:26 12:27 12:28 12:29 12:30 12:31 12:32 12:33 12:34 12:35 12:36 12:37 12:38 12:39 INJECTING GAS RIGGING UP GAUGES IN LUBR. START IN HOT.R GAUGES HUNG UP @ 10330' GAUGES STUCK, WENT AHEAD WITH TEST INJECTING GAS INJECTION AVERAGE SHUT INJECTION OFF FALL OFF Ii !! II !! I! II I! !! DAYS 00:00 00:01 00:02 00:03 00:04 00:05 00:06 00:07 00:08 00:09 00:10 00:11 00:12 00:13 00:14 00:15 00:16 00:17 00:18 00:19 00:20 00:21 00:22 00:23 00:24 4577 4508 2000 28000 4508 2000 3610 5322 5322 5322 5322 5322 4988 4963 4950 4940 4934 4928 4922 4917 4913 4909 4904 4900 4897 4894 4892 4890 4888 4886 4884 4882 4880 4878 4876 4875 5337 5337 5337 5337 5337 5003 4978 4965 4955 4949 4943 4937 4932 4928 4924 4919 4915 4912 4909 4907 4905 4903 4901 4899 4897 4895 4893 4891 4890 Corn P~,ny~ i,., STANDARD Well .... scu 341-4 OIL NORTH STAR ENGINEERING, INC. 1OO W. INT'L. AIRPORT RD.. STE. 205 RESERVOIR PRESS. AND TEMP. DATA ANCHORAGE. ALASKA 99502 RESERVOIR fLUID SAMPLINg TELEPHONE {907) 272'5966 OILAND GAS WELL tESTING COMPANY OF ,CALIF .... Location Field SWANSON RIVER I I State .... J~SI~ Borough ...... KENAI ..... Formation HEMLOCK Dote,,, 10 APRIL 1975 CHRONOLOGICAL DATA ELAPSED GAS DATE TIME VOL TIME REMARKS HR.MIN MCFD TBG CSG PRESS PRESS PSIG PSIG GAUGE #33496-N BHP@ R.D. 10330' 10330' -10150 BHP@ DATUM -10300 12:40 FALL OFF 12:41 " 12:42 " 12:43 " 12:44 " 12:45 " 12:50 " 12:55 " 13:00 " 13:05 " 13:10 " 13:15 " 13:20 " 13:25 " 13:30 " 13:35 " 13:40 " 13:45 " 13:55 " 14:05 " 14:15 " 14:25 " 14:35 " 14:45 14:55 " 15:05 " 15:15 " 15:25 " 15:35 " 15:45 " 15:55 " 16:05 " 16:15 " 16:25 " 16:35 CLOCK RAN OUT 00:25 00:'26 00:27 00:28 00:29 00:30 00:35 00:40 00:45 00:50 00:55 01:00 01:05 01:10 01:15 01:20 01:25 01:30 01:40 01:50 02:00 02:10 02:20 02:30 02:40 02:50 03:00 03:10 03:20 03:30 03:40 03:50 04:00 04:10 04:20 3595 3583 3564 3552 3545 3542 4874 4873 4872 4871 4870 4869 4866 4861 4857 4853 4850 4848 4846 4844 4841 4839 4837 4836 4835 4834 4833 4832 4830 4828 4825 4825 4824 4823 4822 4821 4820 4819 4818 4817 4816 4889 4888 4887 4886 4885 4884 4881 4876 4872 4868 4865 4863 4861 4859 4856 4854 4852 4851 4850 4849 4848 4847 4845 4843 4840 4840 4839 4838 483% 4836 4835 4834 4833 4832 4831 FISHED GAUGES OUT Company~ Well Borough NORTH STAR ENGINEERING, INC. 100 W. INT'L. AIRPORT RD., STE. 205 RESERVOIR PRESS. AND TEMP. DATA ANCHORAGE, ALASKA 99502 RESERVOIR flUID SAMPLING TELEPHONE {907) 272-5966 OilAND GAS WELL TESTING .c:,I'ANr)ARD' OIL cOMPANY OF CALIF ....... Location $CU 3.41-...4 Field. SWANSON RIVER State_ ALASKA KENAI Formation HEMLOCK .Date 10 APRIL 1975 T + ~ T DATA ~T CUMULATIVE PRODUCTION 70,298,911 MCF INJECTION RATE PRIOR TO SHUT IN 28,000 T= 70,298,911 MCF/ 28,000 MCFPD 2511 MCFPD DAYS X 1440= 3,615,372 43T T +(ST (MINS.) ~3 T BHP@ -10300 1 3,615,373 2 1,807,687 3 1,205,125 4. 903,844 5 723,075 6 602,563 7 516,483 8 451,923 9 401,709 10 361,538 11 328,671 12 301,282 13. 278,107 14 258,242 15 241,026 16 225,962 17 212,670 18 200,855 19 190,284 20 180,770 21 172,162 22 164,336 23 157,191 24 150,642 25' 144,616 26 139,054 27 133,904 28 129,121 29 124,669 30 120,513 35 103,297 40 90,385 45 80,343 50 72,308 55 65,735 60 60,257 5O03 4978 4965 4955 4949 4943 4937 4932 4928 4924 4919 4915 4912 4909 4907 4905 4903 4901 4899 4897 4895 4893 4891 4890 4889 4888 4887 4886 4885 4884 4881 4876 4872 4868 4865 4863 -NORTH STAR ENGINEERING, INC. Company: STANDARD OIL COMPANY OF CALIF location 100 W. INT'L. AIRPORT RD.. STE. 205 RESERVOIR PRESS. AND TEMP. DATA ANCHORAGE, ALASKA 99502 RESERVOIR fLUID SAMPLING TELEPHONE {907) 272-5966 OIL AND GAS WELl TESTING Well SCU 341-4 Field. SWANSON RIVER Borough KENAI Formation I I ~]EMLOCK State __Date , A~S~ 10 APRIL 1975 BHP@ -10300 65 55,622 4861 70 51,649 4859 75 48,206 4856 80 45,193 4854. 85 42,535 4852 90 40,172 4851 100 36,155 4850 110 32,868 4849 120 30,129 4848 130 27,812 4847 140 25,825 4845 150 24,103 4843 160 22,597 4841 170 21,268' 4840 180 20,086 4839 190 19,029 4838 200 18,078 4837 210 17,217 4836 220 16,435 4835 230 15,720 4834 240 15,065 4833 250 14,462 4832 260 13,906 4831 SEMI-LOGARITHMIC 5 CYCLES X 70 DIVISIONS KEU~EL ~ ~SS~, CO. ,A~,, U.,.,. 46 6213 I I I I I I I I .L~' +.t, 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 t I I Iol tl I I I I I i.,I I I I I I I I I I O~ 9 · ~Ol gO~ ~0~ ~0~ £0~ l~onn (Feb. 1061) I ..... : ..... ! --: ..... ' (SUBMIT IN TRIPLICATE) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY BudS, or Buremu No. 4S-R~M.4. Approval expires 12-.31--80. Land O~l~ee Anc. hol~s, ge ....... t....o. A_-_0_2..899[[, ........... .~, ___ ..~....~_a..?.~ ~__.c. ~.e.~_. SUNDRY NOTICES AND REPORTS ON 'WELLS I NOTICE OF INTENTION TO DRILl_ .................. ....... NOTICE OF INTENTION TO CHANGE PLANS ........ = ._~ NOTICE OF INTENTION TO TEST WATER SHUT-OF;F .............. NOTICE OF INTENTION TO RE-DRILL OR REPAIRiWI~I.L ........t~ ...... NOTICE OF INTENTION TO S~K)OT OR ACIDIZE__J[ .................. NOTICE OF INTENTION TO PULl, OR ALTER CASING ............ I ..... 1 NOTICE OF INTENTION TO ABANDON WEU. ...................... SUBSEQUENT REPORT OF WATER SHUT,OFF ........... ', ~ . SUBsEoUENT REPORT OF SHOOTING OR ACIDIZING, ................ t ..... SUBSEQUENT REPORT OF ALTERING CASING .................... I ..... SUBSEOUENT REPORT OF RE-DRILMN~ OR REPAIR ............. ] ..... SUBSEQUENT REPORT OF ABANDONMENT ............... I ..... SUPPLEMENTARY WEll HISTORY -- V~' *'S ...... ~ ..... S'Pl~lement, a._~ ReI)o~''1; ~_o._._o~._ s__._.!:n_ je. ct,.! on. ............................. ~ ..... (INDICAT~ A~OVE I~ CHECK MARK NATURE Of' REPORT NOTICE. OR OTHER DATA) ................................... _A~_r~.~. 2.~...__~9_ ...... 19.~3. WellNo. _~U._~_is '--a,~ ~,__.ft. from__ {~ ,ineand.~75.._ft. from[~} line of ,~ ...... ~ ..... (~ ~. ~d ~. No.) ~WP.) '-- (M~ldl~) S~ns~p ~r_ ............... Ke~i_ ~enln~u~ .............................. ~ ..........~~--- ............... ~) ..... : (~unty or 8ubdlvl~n) (B~ ~ Te~t~ry) K. B. ~e ~evation of the ~ a~ve s~ level DETAi~ OF WORK (~a~ n~ ~ mhd ez~t~ ~pth~ to ~tlve ~st ~ew ~m~ ~lhts~n~ inI ~int~ n~ nil ot~ Im~nt 2. Initial injection z~te 4. 7010 N/D rate. I uadts~tiad that thio pla d wedl mM toelivo aplmpeud In wrltlnf I~ dis Geolefiell e-uruy befoto oporatlone ma), be oommen#d. C. V. O[A~N Title I);t a.t,,r:L~,...~Ul~t,.,...:...A~,a~,.D~MLt ot ep0 Itl0d0 / ..... ~ SUBMIT IN DT3,...~i~ATE* STATE OF ALASKA (See ()thor In- st ructions on OIL AND GAS CONSERVATION coMMITTEE II III I I WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* %%' ELI. W ELL Other ' b. TYPE OF COMPLETION: w E L I. OV ER E N B AC K RESV R. Other __ 2. NAME OF OPERATOR 3. ADDRESS OF OPERATOR ........... ' ' '' ' 4. t, OCaTION Ob' wELL -(-Report location clearly and in accordance with any State requirements)* At surface At top prod. interval reported below At total depth 5. APX NLSW. EKICAL CODE 6, LEA.SE DESIGNATION AND SERIAL NO. 7. IF INDIAN, ,/kI~OTTEE OR TRIBE NA1VIE 8. UNIT,FArM OR L~kSE NAME 9, WELL NO. 10. FIELD AND POOL, OR WILDCA. T ll. SEC,, T,, R., M., (BOTTOM HOLE OBJECTIVE) 12. PEI~IT NO. I~OW1VIANY* ROTARY TOOLS CABLE TOOI, S l a~t~'a 22. PRODUCING !NI~EEVAL(S). OF ~I~IIS COMPLETIOn--TOP, BOTTOM, NAME 0VID AND TV~)* 23. WAS DIRECTIONAL : SURVEY MADE 24. TYPE ELECTRIC AND OTHER LOGS RUN CASING REC:ORD (Report all strings set in well) CA~SLNG SiZE WEIGHT, DEI::~['H SET (M.D) HOLE SIZE ~;~ Z'~ -- CEMLNTING RECOt~ I A~OUNT PULLED : 26. LINER .II 1 PERFORATIONS OPFiN TO PRODUCTION (interval, si~e and number) I I I I I III 30. P~ODUCTION DATE FZ~ST Pl%ODUC~ION ~ ~oDucT1oN ME1.HOD (Clowh}c, g~s liiL pumping~size and t~pe of pump~ C}!OXE SiZE {P~OD~N FO'~ OI~EBL. GA~CF. ruow, TUmNS C~S P~ss~z CA~T~ m~L. ' s~r~cr. 2]. DISPOSITION OF GAS (~O~g, ~8~ ~OW ]~e}, w6~ted, etc.) : 27. TUBING REC OP~D SCi~EEN (~ffD) SIZE DEPTH SET (R~D) ~ PACKER SET (MD) ~.. , ,,,,, . II I I ] IIII I I 29, ACID, SHOT, F;IAC~L'LYRE. CF~',IENT SQUE-~Z~, ETC. DEPT~i 1NTE~V.A~L (MD) AS'iOUNF z'~D I'2tND OF MAI'E?dAL USED [ V(ELL STATUS (Producing or ! VCATER--BBL. ] GAS-OIL IL,TIO WA~BBL. ] OIL GRAVITY-API (CORR.) I TE~/IT WITNESSED BY 82. LiST 0~" ATTkCH~i"~-NTS ' ..... ~3."I hereby certify that the foregoing and attached information is complete and correct as determined from 'all-ivallabl"e recor'~s SIGNED TITLE *(See Instructions and Spaces ICor Additional Data on Reverse Side) INSTRUCTIONS Generel: This form is designed for submitting e complete end correct well completion report end log on ell types of lends end leeses in Alaske. Item: 16: Indicete which elevetion is used es reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attach:.~en~s. Items :20, and :2:2:: If this well is completed for seperatc prcduction from more than one interval zone (multiple completion), so state in item 20, end in item 22 show the prcJuciag intcrYal, or intervals, top(s), bottom(s) and neme (s) (if eny) for only the interv,~l reported in item 30. Submit a separate report (pege) on this form, edequately identified, for e~ch additional interval to be seperately produce,J, show- ing the aciditionel data pertinent to such intervel. It. m2~: "Sacks Cement": Atteched supplemental records for this well shoulJ show the deteils of eny mul- tiple stege cementing end the ]ocetion of the cementing tool. Item :21/1: Submit ~ seperete completion report on this form for each interval to be separetely produc,cl. (See instruction for items 20 ~nd 22 above). 34. SUMMIA. RY OF' F'O~MATION TES'I':5 INCLUDIN(; INTERVAl., TESTED. PH~_~UH.E DATA..AND REC'0VERIES' OF OILi GAS. · . 35. GEOLOGIC MARKERS WATER AND MUD MEA$. Db-'~T~[ 'T'HU~VERT.'D~rI~li ., ., . , , PROPOSAL FOR WELL OPERATIONS, PRO 316-1 SCU 341-4 RE.~EDIAL DISCUSSION PROPOSAL: Pull tubing, re-perforate the H3-5 sands, replace damaged jewelry and return well to injection. Injectivity is badly needed at this point to'balance withdrawals and to increase reservoir pressure. WELL HISTORY AND CURRENT STATUS: SCU 41-4 was originally completed in Hemlock 1-10 sands on March 21, 1960, with an I.P. of 438/4/120 (O/W/G). This well was converted to Hemlock 1-10 sand gas injection in December, 1962. Last production was 967/10/220 (O/W/G) with cumulative oil pro- duction of 679,800 bbls. Figure 1 .depicts the'geological structure and the current production of surroundin9 wells. In September, 1969, the 2 7/8" tubing was replaced with 3 1/2" tubing in order to increase injection capacity. Mud weights of. 82-84 pcf were used to kill and control the well. The 2 7/8" tubinq showed severe pitting fr~m 10,140' to 9,400.' + and the possibility exists that the casing in this interval is also pi--tted. Figure 2 presents a schematic of the tubing and Figure 3 presents the E-log through the Hemlock. In March, 1975, the H10 sand was excluded from.injection by setting a "CA" plug in the "D" nipple at 10,534'. In July, 1977, a spinner survey was run which showed that the "CA" plug was gone from the "D" nipple and stuck at the bottom of the tubing. Of the 30,500 MCF/D being injected into SCU 341-4, 5,600 MCF/D exiting through the mandrel at 10,243', of which 4,200 MCF/D was returning to the tubing through the mandrel at 10,357'. A total of 29,100 MCF/D was then being injected into the H10 sand (see Figure 3). A plug was then set in the position 1 nipple at 10,437'. Injection was then only 5000 MCF/D. Solvent stimulation attempts were unsuccessful in increasing injectivity. A tubing-casing leak at 10,136' + developed about 8-11-77. On September 1, 1977, a pack-off was set from 10,147.5' to 10,125'. This pack-off failed almost immediately. On September 23-28, 1977, the pack-off was pulled and the H1-5 perforations were acidized. On 10/1/77, a new pack-off was set, but the tubing-casing annular pressure built-up as soon as injection was started. Either the second pack-off is leaking or there are additional tubing leaks. ALTERNATIVES: le Continued wireline attempts have a very low probability of success. Even if all the tubing leaks could be found and packed-off, it is %mlikely that effective injectivity can be attained even with acid stimulations. 2. There is no other well available that is satisfactory for conversion to gas injection. Replacing SCU 341-4 with a new well is not justified due to the substantially higher costs. RISKS: Ail risks are felt to be normal. IJE :draw I. J. EPPERSON J e L£1GE ND CHEVRON USVt INC. Id[¢~i&m~C~L [~CT4,L ~k Contours on 1t.4 Point SWA,NSO N RIVE' R FIELD ENO.: I.J,E, I~- sc, ~ [-I"-- ~000' ICJ I1~ F' L I il i I i -ii SCU 341-4 REMEDIAL I. ,--, WELL LANDING' MAI' :EL TO KB I~,.-ro · ,, '. - . H Bc~e F "F" Pa cke~r at i0,49:5' - I0, I 01.87 --'10,130.84' ---- -- lO, t43.~0' --- 10,172.B8' ~ '-- 10,179.30' } 30' ~" 10,243..~ --!0,256.15' - - S.C.U. 341-4 TUBING DETAIL CSG. 9345'-T.D. IS 7" 2~:Vp II iii i I ill I I i i LANDING MANDREL . . ' 350 dts. ;~'-EUE TUBING 2~'X ~Ya' X-OVER __ __ I Jt 2Ya~ EUE TUBING >~ - CI~MC'O MM Naadrel -~.--- I Jr ~'EUE Tubing >-.- .BAKER FH 7"x 2~" Packer _ ..... I Jf ~' EUE Tubing ~ Otis 5 Nipple Position~_ _ >- CA MCO 65' .. 85~ -- '---- 10,287.'42'-- 10,293:45' i0' ' : --10,323:85'-- - - _ 10,325.4S'-.----.~'.., :--10,$56.'97" : -' 10,570.13 ----'~ ' . -- . im -- --10,400'. 58" -'- · -- -10,437.21 ,-- 10,43~.81 . ~""' - - - 10,'448.41', --- >__.. -- 10,461.15 ..'""- 1'8,' --,o."9~o~' - - ..__ _o~W--10,501.90' .~ . IO.~.~4'.--L_ 10,5;54.56 _ ,- _ : 10,85Cc 0.35' 10,066.87' __ .I. 20' : 28.97' I~ :o6' .2 8.78' G' '.62' m.6o' "3'1.29' I dt ~ro,wn I JF · Offs $ . CAMCO MM Mandrel · · . · MM Mend,et _ _ 'mz.8,' -- ~ : 2~"EUE Tubing._ _ 31.29' . HS-16-1 7" x 2¥ Pc~cker 6.03' ;E.~' EU E T.~ ~':'},: _ _' 30.40' ,. Nipple Posit~on ~2_ _ '"1.60 .. '.1 ... at' 2,%~ EUE Tubing_ 7· ,. Brown H'S-16-1' 7" x2~'?dcker- . I df 2~" EUE Tnbin9_ _ Offs S' Nipple Positional Pup Jt 2~' E~E Tubin'~__ _. CAMCO M~ Mandrel ___ _._. I ds gT~" ~U~ Tubing __ __ '-si .52' .-.m3.~e' .. 30.45' · .. · :30.65' __..I.~0' ., ~.:.~,6o' Ik.74' · 31.os' Baker Stop Sub _ · .80' Baker Seal Assembly - 8.90' · . o I dt 2¥EUE Tubln'g ' ."Z. 31.74' CAMCO D Nipple ~_~/c~ /~/y~.3_ .92' I dt 2~a' EUE Tubing - 31.74' Porf. Pup__ __ :4,22' Top of PJ~9 · ., ' To+a I Oepf h · . mi i J Ill- --- III I - -- o. o- (Z) o , o, PROPOSAL FOR WELL OPERATIONS, PRO 316-1 SCU 341-4 REMEDIAL LOCATION: · SCU 341-4 FIELD: Swanson River At surface: 1000' S and 1170' W of the NE corner of Section . 4, T7N, R9W, SB&M. At T.D.: Same, straight hole. ELEVATION: 166' G.L.; 180' K.B. T.D..- 11,315' PLUGS: 11,300-10,850', cmt. CASING: 22" cemented at 22' 13 3/8", 54.55, J-55, 8R, ST&C cemented at 3000'. DV collar at 2002'. 7" cemented at 10,992'. Bottom 4560' is 265-295, P-110, 8R LT&C; next 1962' is 295, N-80, 8R, LT&C; remainder is 23#-29~, N-80, buttress. PERFORATIONS: 5 5 5 5 5 5 4 1/2" holes 10,226' squeezed with cement. 1/2" holes 10,402' pressure tested to 530Opsi. 1/2" holes 10,600' squeezed with cement. '1/2" holes 10,965' squeezed with cement. 1/2" holes 10,226' WSO. (Reperf) 1/2" holes 10,598' WSO · 1/2" JHPF: 10,585 - 10,508" 10,478 - 10,409' · 10,394 - 10,310' 10,285 - 10,275' 10,265 - 10,234' 10,250 - 10,234' reperforated with 4-1/2" k~oles/ft. TUBING: See attached schematic (Figure 2) "CA" plug at 10,566' + with CEV prong on top; pack-off 10,148- 10,128'. BLOWOUT PREVENTION: Gas: This well' isa gas injector. Ail sands will flow gas. Care must be exercised at all times not to swab well. Lost Circulation: During remedial work in September, 1969, 200 bbls of 82-84 pcf mud were lost during the work. No major problems are anticipated during this work, but LCM should be kept-on hand at all times. Precautions: Any kicks should be handled by normal procedures'. Drilling crews should be made aware of those methods and and Care must be exercised at all times. The hole must be kept full. Program: 1. Maximum Anticipated Formation Pressure: H2-5: 4400 psi H8-10:5000 psi Programmed mud weight of 72-75 pCf will .provide a 750-970 psi overbalance through the H2-5 sands (10,230'-10,394') and 290-505 psi overbalance through the H8-10 sands (10,409-10,571') . Maximum Anticipated Surface Pressure: 4063 psi Blowout Prevention Equipment: Class III-5000 psi, as per "Operating Instructions D-17" · ~ove in rig and kill well with 72-75 pcf mud. 2. Install Cosaco plug and remove tree. 3. Install Class III BOPE and test to 5000 psi. DOG and/or USGS to witness test. Remove Cosasco plug. 4. Pull 3 1/2" and 2 7/8" tubing, mandrels, packers and jewelry. Note depths of any holes and damaged equipment. Pull all tubing slowly to minimize swabbing. Do not drill out Baker "F" packer @ i0,493'. 5. Clean out to top of Baker "F" packer @ 10,493' 'and condition mud. 6. Jet perforate 10,230' - 10,265', 10,275' - 10,285', 10,320' - 10,332' and 10,340' - 10,375' with four 1/2" JHPF '" 7. Run tandem scrapers (7", 29#) to 10,490'. Pull scrapers slowly to minimize swabbing. 8. Run 3 1/2" x 2 7/8" tubin§ and jewelry as per attached tubing detail (Figure 4). Hydrotest all tubing and equipment to 6500 psi. Run Gamma-Ray-Neutron-CCL Log through tubing for depth control. Engineering to witness. 9. Install Cosasco plug, remove BOPE, install and test tree to 6500 psi. 10. Remove Cosasco plug and displace mud with lease crude oil. ll. Set wireline plug in "D" nipple and pressure up tubing to set hydraulic packers. Release rig. 12. Recover plug from "D" nipple and back' flow lower zone only. until the zone cleans up. Re-set plug in "D" nipple. 13. Back flow all upper zones separately until clean. 14. Return well to injection at maximum rates into the H1-5 sands. ~ o~8: c. F. K/rkvold W. D. Sauer G. Matiuk I. J. EPPERSON DRILLING FLUID PROGRAM SCU 341-4, SRF Basic System: Medium treated Lignosulfonate mud. Fluid Properties: Weight - pcf.. Viscosity- sec./qt. API Fluid Loss - cc API Plastic Viscosity - CPS ~Yield Point - lbs./100 ft.2 Gel - tbs./100 ft.2 - 10 Min. pH Solids - Vol. % * or as required 72-75* 40-70 less than 7 · '22 'maximum 10-20 5-15 9.0- 9.5 8-12% Remarks: Limit dry jobs to 20 sacks of barite or as~'directed by Drilling Foreman. 2. Maintain adequate supply of lost circulation material. C Z6~ 6488' 934.5' 22' DV 20OZ ' 10,146.7- 327 Jts. 3 1/2" tubing X-over 2 7/8" x 3 1/2" CASING N-80 N .80 N.80 N-80 2 Jts 2'7/8" tubing · .7 ' ,208 ~ 10,211.6 OTIS "XA" sleeve Baker packer .... 10,218.3 ,o..a.z,..~10,219.8 ~ -OTIS !'S" nipple, pos ~~Z 1 Jt 2 7/8" tubing ~o,2~o' 10,250. ~ Camco MM Mandrel ' ' 10,259 i ~ ~,o.=,s' 1 Jt 2 7/8" tubing , ~ ~ . /10,290 ~ ,292. ~, Bro~ CC safety joint to.z,~ ~10 .9-- ~, - .- ~'~o;~o' ~ ~0,299.1~ -Baker packer ~ ~ .. 10,300.6~0~S "S" nipple, pos. ~2 1 Jt~ + 20' pup 2 7/8" tubing ~. ~ ~10,351.6~ . Camco ~ ~ndrel ' ~ ,~ ~o.,~o.~ ~ ~. ~ ~/~,, ~u~g '--: = 0,391 7 ' ,- H- ~ ' ~ Bro~ CC safety joint. .~ ,~.,,,' ~10,39 3.2-~ Baker Packer ' ~,o 4o, 10,399.9~ , ,, "- ~~ ' ' 10,401 4~OTIS s nipple' p°s'~I '1 i Jt.* 20' pup 2 7/8" t~bing ':E ~~10,452 l~C e ~ ~ ' -- ' ~ - amco ~ ~ndr 1 -~.~ 10,461. Z~ 1 Jt 2 7/8" tubing "~' E . 10,492 2.~ · ~ ,~:~'- _ ~_~u,~. ~ Baker Model "F" packer ~ - IAi ~ , lA ~01 9 J ~ ~ -.-- 1 Jt 2 3/8" t~bing %~ ~ ~.o.,., ~o,~ ~'~ BI - 10,8~.00~ TOP of ~UG ~ 11~15.00' TD 302' 302'- 1234' 123,}- 4526 4526 -6488 62.0' 2.9' 6.7' 1.5' 31.0' 9.1' 31.0' 1.5' 6.7' 1.5' 51.0 9.1' 31.0' 1.5' 6.7' 1.5' 50.7' 31.0' 0..8~ 8.9~ 0.9' 31.0' I III I I pRoPOSED SCU CASING & SECTION iii 341-4 TUBING DETAIL ~ T.? ~L,R. 9W. FIGURE 4 Form P--3 S JE OF ALASKA ' SUS~YT I~T r' ~,[,ICATS. (Other lnstru, s on re- OIL AND GAS ~*~NSERVATI0N COMMITTEE .verse etde) ~ · '., SUNDRY NOTICES AND REPORTS ON WELLS .(Do not use this form for proposals to drill or to deepen or plug back to a. different resertotr. Use "APPLICATION FOR PERMIT--" for such proposals.) -> ' GAS ' [---1 ' : ' oil ~] WELL ' ' _OT~R . lnJ~' ~n ~ W~LL C'n_~ 4_ _ W 11 . Standard Oi1 Comp~any'nr'gnl!"f., W:O !; - Operat'or ~. ADDR~ OF OPERATOR 4. ~OC*~tOf O~ ~C~-iRebort~c~tt~n a~}~'i~d3~d~an~ ih~ state Fe~u~ements.' S~ also space 17 below.) Atsurtoce 1175* West and 1000' South from N.E. corne of Section 4, T7N, R9W., S.M. 15. EUSVArIO~,'S (Show whether DF, aT, aa, etc.) Effective: July 1, 1964 LEASE DI~S[GNATION AND SERIAL NO. A-o?gq97 IF INDIAN, ALLOTTEE OR TRIBE NAME t4. PER.%IIT NO. ?. UNITAOREEMENT NAME o. w~ ~.oldo rna 8U~VEJ OR ARiA Sec. 4, TTN, 12. BOROUGH 18. STATE Creek'Unit ~20' K B, Kenai ChecE AppropriateBoxTolndicate Natureo~Notice, Repod, or OtherData NOTICE OF INTENTION TO: .%1ULTIPLE COMPLETE ABANDONs CHANGE PLANS TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACID!ZE REPAIR WELL SUBSEQUENT REPORT OF: WATER SHUT-OFF __~~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING Ga ACIDIZING ABANDONMENTs (Other) S ', w ' t l- -~ (NOTE: Repor~alts o'~' mtfltip%%~t~i~tion on Well Completion or Recompletton Report and Log form.) 16. (Other) Creek Unit R8W. A1 -oka 17. DESCRI~Z I,ROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of startln~ any proposed work. If well is directi0nally drilled, give subsurface locations and measured and true vertical depths for all markers and zones perti- nent t~ this work.) * · On 7-13-67 gas injection into SCU 341-4 was discontinued. The well was killed with produced water a~d water injection was started on 7-13-67. 2. On 8-14-67 tee water injection was discontinued after injecting approximately 86,2505bls. of produced water· e Gas injection was reinitiated 8-14-67 18. I hereby certes'that tho foregoiu{ is true a~d correct / - ~ , ../~' .. . ' SIG~D ~ ~ ~ /' ~' TITLE ~ , . '-~ . . . ~- . . , ,. , . *See ln,tt.uction~ on Reveme Side ANCHORAGE F~rm P--3 STATe--'OF ALASKA SVBMIT IN TRIPI~ATE* (Other instructior~ re- OIL AND GAS CO~-.5ERVATION COMMITTEE verse side) SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) Effective: July 1, 1964 LEASE DESIGNATION'AND SERIAL NO, A-028997 6. IF INDIAN, ALLOTTEE OR TRIBE OILw~LL ~ GASWEL~. [~ OTH~-R Soldotna Creek NAME OF OPERATOR 8. FAR.%! OR LEASE NAME Standard 0il Company of Cal±f. W.O.I. - Operator Soldotna Creek ADDRESS OF OPERATOR 9. W~LL NO. P. O. Box 7-839, Anchorage, Alaska SCU 341-4 LOCATION OF WELL (Report location clearly and in accordance with any State requirements.' See also sp. ac_e At surfocell)~5b~l°~)est & 1000' South from N.E. corner of Sec. 4, T7N, R9W, S.M. 15. ELEVATIONS (Show whether DF, RT, OR, e~?~) 180' K.B. 14. PER.~IIT NO. 10. FIELD AND POOL~ OR WII, DCAT Swanson River SEC., T., R., M, OR BLEo AND SURVEY OR AREA Sec. 4, T7N, R8W. 12, BOROUGH J 18. STATE Kenai [ Alaska 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO : TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON' REPAIR IA'ELL CHANGE PLANS (Other) Inject slug_of water SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ASANDONMENT' (Other) ~N~OTE: Report results of multiple completion on Well vompletion or Recompletion Report and Log form.) 17. DESCRIBE PROPOSED OR COMPLETED OPE...-TI ,va I L~at'..~ u~&~u ail : = ...=.. '~.~alls, and give pertinent dates, including estimated dat~. of starting an)- proposed work. If well ia dir~ctioa~, ~' drilled, k"-,~ uub~'.wfsce loc~t~o.' and measured and true vertical depths for all markers and zones perti- nent to this work.) * 1. Discontinue gas injection into SCU 341-4 2. Kill well with lease waste water 3. Inject approximately 100,000 barrefs of produced water into well. 4. Re-establish gas injection into well. 5. Obtain periodic gas gauges on producers in fault block to determine effect of water slug. Confirming conversation N. J. Hildebrand - K. L. Vander Ahe. 7-17-67 certlfy~that the ,~'orei[olu~ is. t~e and~ correct SuperintendmntDATm 7/?F/67 TITLE District (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE *See Inltructions on Rever:e Side RECEIVED AUG .1967 " DIVISION OF ~ilJ~.S._~_~ L'4L~.~_.; ...... c~I(m I~PORT CONVERSION TO GAS INJECTION _S.TA~_~DARD 0IL COMPANY~OF C_ALIFQRNIA~.~,~WEST.~ OP.Ep~.._TIONS, INC, -OPE~RATOR~_ AREA: Kenai Peninsula, Cook Inlet Area, Alaska PROPERTY: SOLDOTNA CREEK UNIT LAND OFFICE: Anchorage Lease No.: A-O28997 SECTION 4 (Projected) T. 7 N., R. 9 W., Seward B & M LOCATION: 1000' south and 1170' west of the northeast corner of Section 4 ELEVATION: 180' K. B. DATE: April 2, 1963 :C~. V-. 'c~AT~ERTON, Distr:" Lc~ Su~'e~inten ,n~ CONTRACTOR: Santa Fe Drilling Company (Rig #35) DATE COMMENCED RE~,~_,DIAL WORK: September 15, 1962 DATE COMPLETED REMEDIAL WORK: September 22, 1962 SUMMARY TOTAL DEPTH: 11,315 ' PLUGS: 11,300- 10,850' CASING: -"~ 22"'cemented'at 22' 13 3/8" cemented at 3000' 7" cemented at 10,992' PERFORATIONS: As before COMPLETION REPORT .- CONVERSION TO GAS INJECTION SOLDOTNA CREEK UNIT WELL NO. 41-4 s~jected) T. 7 N., R. 9 W., Seward B & M ' O ATOR Page 2 Commenced remedial work at 11:00 P.M. Moved rig. ~SePtember !6, 1962 Rigged up and conditioned Black Magic m~d.i: ~'" ~_eptember 17.,. 1962 Killed well with 82# pcf Black ~gic mud, using Halliburton. tree and installed BOPE. Removed X-mas ~ept.ember_ ~8, 1962 ., ~ ~ ~ · ..... Pulled 2 7/8" tubing out of hole. out and changed collars on tubing. Ran 7" casing scraper to 10,585~ Pulled September 19,.,. 19~2~ Changed collars on tubing. ~eptember 20~ 1~62' Ran Agnew & Sweet wireline before rerunning tubing. Hole OK. Reran 2 7/8" tubing equipped with packers and mandrels to lO,O18'. Ran Sckl.umberger Depth Determination Log inside 2 7/8" tubing. Sept.ember .21~. 1962 Ran remainder of tubing and landed same at 10,594'. COMPLETION REPORT - CONVERSION TO GAS INJECTION SOLDOTNA CRKKE UNIT ~ELL NO. 41-4 Section 4 (Projected)T. 7 N., R. 9 W., Seward B & M STEWARD OI~ CO, OF:OA~ORNIA"-' W'o.I. ,OPERATOR ~ Page 3 TUBING DETAIL (BASED ON TALLY) K' B. to landing flange 2 7/8" pup joint with 2 7/8" Shaffer Donut with Cosasco tread 2 joints 2 7/8" tubing 2 7/8" Otis "S" landing nipple in position #4 322 joints 2 7/8" tubing 2 7/8" Otis Sleeve valve (closed)' I joint 2 7/8" tubing 2 7/8" Brown CC safwt¥ joint 2 7/8" pup joint ~2 7/8" x 7" Brown HS-16-1 packer I joint 2 7/8" tubing 2 7/8" Otis "S" landing nipple in position #3 i joint 2 7/8" tubing 2 7/8" Brown expansion joint I joint 2 7/8" tubing 2 7/8" Camco MM mandrel 2 7/8" pup j. oint 2 joint 2 7/8" tubing 2 7/8" Brown CC safety joint 2 7/8" pup'joint ~2 7/8" x 7" Brown HS-16-1 packer 2 7/8" pup joint 2 7/8" Otis "S" landing nipple in position #2 2 7/8" pup joint 2 7/8" pup Joint 2 7/8" Brown expansion joint 2 7/8" pup joint 2 7/8" Camco MM mandrel with CEV valve 2 7/8" pup joint 2 7/8" pup Joint 2 7/8" Brown CC safety joint 27/8" pup joint 7/8" x 7-" Brown HS-16-1 packer 1 joint 27/8" tubing 2 7/8" Otis "S" landing nipple in position #1 2 joints 2 7/8" tubing 2 7/8" Venturi shoe 13.45 1.90 60.41 1.60 10074.40 2.43 31.58 1. O3 10.10 6.00 31.56 1.60 31.58 3.80 31.38 13.15 10.10 63.18 1.O9 10.2O 6.OO 10.08 1.60 10.15 10.13 3.78 10.11 13.30 lO.15 10.19 1.04 lO. 25 6.00 31.28 1.61 61.92 .67 K.B. Depth 15.35 75.76 77.36 10151.76 lO154.19 1o185.77 10186.80 10196.90 1O2O2.9o 1o234.46 10236.06 10267.64 10271.44 10302.82 10315.97 10326.07 10389.25 10390.34 lO4OO..54 104o6.54 1o416.62 10418.22 10428.37 10438.50 10~2.28 10452.39 10465.69 10475.84 lO48~.03 10487.o? 10497.32 lO5O~,32 ~oS3h.~ 10~36.21 ~0S98.~3 10598.80 Tubing landed at 1~' ~ ..... '~"-~ ..... Ail tubing is2 7/8", 6.5#, 8R, N-80 with Hardy Griffin 6. T. AP~~~~ Base Venturi shoe on Depth Log dated 9-20-62 10,O18' Tubing ran in hole after depth log 563 K. B. to landing head 13.55 Tubing landed at (based on log) io;594'~5' COMPLETION REPORT- CONVERSION TO GAS INJECTION SOLDOTNA CREEK UNIT ~ELL NO. 41-4 Section 4 (Projected) T, 7 N., R, 9 W', Seward B & M ~T~~ 0IL~'~C~' 'OF "CA~6RNIA~ --W.'0~i,"~ O?~T'O~" ~ $~tember 21, 1962. (con%inued~ Removed BOPE and installed a 10, OOO~ W.P. Injection Head. 88OO~ psi: OK. Displaced ~ud with oil and flowed well~ Tested head with September .22, .1962 Ran Agnew & Sweet wireline tools and set packers at 10,197', 10,401", and 10,497'. (Top of packers, based on tally) Rig released at 10:OO A.M., September 22,1962. SRH:psm UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. Approval expires 12-ai-60, LA.o Omc~ .... ~~r.~e ......... LESSEE'S MONTHLY REPORT OF OPERATIONS The followi~ is a correct report of operations and prod~otio~ (i~,cludb,,J drilli~ and prod~ein~ ,~lts) for t.~e mont~ of _____.~~~r ................... ~S_~ ....... _~.~_~..gr~k .U~t -. .............................. ......._~ OX~.LO~S or o~ ' '--~ ..... ~ i CU. FT. OF OAS [ ~ ..... ] BAitRE~q } REMARKS [ · · ~ ~ ~%h ~k l~gto ~e ~~ed~x-m~ t~ee ~d tns~~ ~ ' tubal eq~pped ~ D~pl~ed ~ wi~io~. Set ~kere ~t 10191', 10381', ~ 10%~'. ~~ we~ a~ re~u~ te ~ ~ucti~ ~ releas~ 5ep~er 22, ~ , oo, S~g'~'~'s'-~o' ~o~o ffo~mo,_S~2s~er 0CT ~2 1962 ~field - C, ~ W. ~ D~v~on o~ M~n~s a~d M~=~r~ t I. ' BioTa.--Them were ...................................... runs or sales of off; .............................................. M cu. ft. of gas sold; ......................................... runs or sales of gasoline during the month. (Write "no" where applioable.) Nown.---l~eport on this form is required for each calendar month, regardless of the status of operations, and must be filed in dup!ica~ with tthe supervisor by the 6th of the su0coeding month, unless otherwise directed by the supervisor. '. ~i'~ ~1~n.es and h\!nerats ' ON AI~~ Na:u,'ai Resourc. · . JUL 1.6 1962 Division' of Mines and' h6!~erals ,adg~ka Dopt, of Neterel ResoOt~&J test O~m III B~ut - ; · ~p, .Xmo Tree. Of ihs In~ection f~cilittem, APPLICATION FOR PERMIT TO DRILL, DEEPEN OR PLUG BACK -. NAME OF ~(~MPANY OR OPERATOR Address : · ~- ...... ' ...... " - '~ ' Cit~ '~ .- ,: State ..... -~ ..... D~scRIPTION OF WEI~ AND LE~SE Nameof lease ]~Vell number I Elevation (ground) Well location (give footage from section lines) ....... ~ec~ion--townshig--range or block &' survey Distance, in miles, and direction from nearest town or post off~ee ~earest distance from proposed locaLJon Distance from proposed location to nearest drilling, to proper~7 o~ lease Hne: completed or applied--for well on the same leR~e: feet Proposed depth: Rotary or cable tools Approx. date work will start Number of wells on lease, includin~nfg~llT''?'~--~-'- Number of acres in lease: completed in or drilling to this reservoir: If lease, purchased with one or more wells drilled, from whom purchased: Name Address JUL 16 ]962 Status of bond Remarks: (If this is an application to deepen or plug back, briefly describe Work to be done, giving present producing zone and expected new producing zone) P~sroleum Branch D1.yb~¢~. Of Mino~. and Minerals__ Alaska Dept, of Nalurai Resource~ CERTIFICATE: I, the undersigned, state that I am the e of the (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are tr/}ae, correct and complete to the best of my knowledge. ~/~r~/, ~ Permit Number: ~** Approval Date: ' ~l~W '~ t~ ~ Notice: Before sending in this form be sure that you have given all information requested. Much unnecessary correspond- ence will titus be avoided. See Instruction on Reverse Side of Form Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. 1 " Effective October 1, 1958 'b Hr. C. V. Cb~ter~, DfJtrLc~ Supertutenden~ S~andard Oil C~spa~y o~ Cattfornta P. O, Box 7-829 Anchorage., &l~ PLease refer ~o my l~tt~r, da:ted April ~eh to ~tse t~t tht~ D~vi~n ~s ~t yet r~etv~ the requeoced m~rtal. ~11.1 ~ plea~ [tie the ubJec't Very truly yours Donald D. Bruce ~£. Petroleum Branch cot g. 1~. b~tt~ey, Jr. ~pril 5, 1962 Dear Hr. Chatty: In teviewin8 ou~ well rece~ds ! Find that thio Division baa never receive1 a copy o~ the mud lo~ ~or 7out ~el! ~o. "Solaotna Creek ~tt** a~-&, S~c. ~, ~.7N. ~, $ ~. ~ ~ill ~u pl~se ~ile a blue li~ ~y ~ s~la o~ t~ ~ 1o8 ~or ~e ~e Donald O. Bru~e Chief, Petzoleum Branch P. O. BOX 8 3 9 · A N C H O R A G E · A LA S KA PRODUCING DEPARTMENT TELEPHONE 47001 J. T. CROOKER DISTRICT SUPERINTENDENT September 8, 1960 OCT 12 19 0 Aiasha Dept. Mr. R. V. Murphy Alaska 011 & Gas Conservation Commission 329 Second Avenue Anchorage, Alaska Dear Sir: Enclosed, herewith, are one (1) copy and one (1) sepia copy of the Composite Induction-Electrical Log~ Runs one through six, inclusive with recorded interval from 60 to ll, 313 feet~ for the Soldotna Creek Unit Well 41-4 (1), for your infor- mation and files. Very truly yours~ STANDARD OIL COMPANY OF CALIFORNIA Western Operations, Inc. Enclosures J. T. C ROOKER PRODUCING DEPARTMENT TELIZPHON£ 47001 d. T. CROOKER o [STRILCT SUPERINTENDENT P. O. BOX 839 ' ANCHORAGE ' ALASKA 'September 21~ 1960 Mr. R. V. Murphy Alasks 0il & Gas Conservation Commission 329 Second Avenue Anehorage~ Alaska Dear Sir: Enclosed~ hereWith~ are Revised Pages one (1) and eleven (11) to be inserted in your copy of the Com- pletion Report for Sold°rna Creek Unit 41-4 (1) Well. Very truly yours~ STAMDARD OIL CON. ANY OF CALIFORNIA Western Operations~ Inc. J. T. CROOKER Enclosure · CONPLETION ~EPORT - NEW WELL OIL CONPANY O~ CALIFORNIA - AREA: Kenai Pemimsula, ~ook Imlet Area PROPE~: Soldotna Creek Unit Lease No.: 028997 W LL _ SECTION 4 (Projected) T, 7 N., R. 9 W., 8e~r~ ~M LOOATION: Approximately lO00' south and 1175' west of the corner of Section 4. ELEVATION: 166' Ground, 180' K.B. DRIL!~n BY: DATE CO~EN~ED DRILLING: December 31, DATE COMPLETED DP~LI~INO: March 21, 1960 No production to ~te other than that obtained duri~ fl~w tests and pipeline facilities are belag imstalled. I II II I I I I III II II II _. I I I II I . _ . S~Y TOTAL E~PTH: 11, 315' PLU~S: 11, ~00 - 10,8~0' CASING: 22" eem ~2' 13 3/8" cern 3000' with 1000 sacks constr~ction cement &~und m ~nd lO00 sachs construction cement thr~t~h eoll~ ~t 2002 '. 7" cern 10,992' ~b 1OOO sacks co~struetioa eememt ar~mm~-s~e and 1692 sacks construction cement through eell~ at 69~'. PERFO~ONS: hOles 5 !!h°les holes boles boxes holes Per i~. 10,229' squeeze~ w~th cement. 10,402' pressure tested to ]300 psi. 10,600' squeezed wi~b cement. 10,965 ' squeezed wt~b cement. 10,226' 10, 5~$' WSO. lo, - lo, 5o8' 10, 3~ - 10, 310' 10,285- 10,~7~' t0,2~ - 10,250 - !0,2~$' reperforated with ~ -~" holes/ft. ?~ 7779 ~75 ~ ~ 3o o0 ~ ~ ~ ~0 O0 10. o0 ~ 10 ~ 1~ OO oo oo oo ~ No produetio~ reeo~l. ~ell shut in easter ec~l~toa of i~t~ flow tests pesdi~ eeas~ion of teak settl~ tut pipeliae f~eil/ties. Pa~2 ~cem~er 31, Spudded 10 AM Drilled 12}" hole 2~' - 403" 378' ~ri lled 80 pcf mad J_aauary 1, 1969~ ~O3" - 1088' 685' drilled 8O - 8B Drilled 11 3/~" .hole 1085' - 2722' 163~' drilled 2722' - 3000' drilled 78 - 83 per ~ Schlumberger I-ES L~ 60 - 3001' Micro caliper log 60 300~', Sonic log 60 - 3OO3' · 25' - 1000' 975' opened Opened hole to 17½" 1000' - 1~:~5' 368' opened Opeaed hole 'to 17½" 136:~' - 2761' 1393' opened 80 - 85 per opeaed hole to 3.7½"' ' 8~ per 2761' - 3000' 239' opened Cemented 3.3 B/8" ~sg. @ 3o00' in a sta~e._s ~ ' ' _ .... ~1, , -. ,~'~, ,, _. _~ *---_ B0t~. St~.: Usecl HOt/CO ,eem trUc~ to mix ~}O sax perm constr., tYPe cern w/2~ CACL2- ad&ed te avg 116 pcf slurry. PreeeAed cern w/30 bbl. water. Displaced cement with rig pump. secon~ S.,~e: Cemanted through DV collar at 2002'. Used HOWCO cern truck to mix' i750 sacks Perm~aw construction tyFe cement with 2~ CAOL~ added to average slurry. Preceied cement wi~h 30 bbl. water. Displaced cement with rig pump. Close~ D~ collar with 1500 psi using HOWCO Truck. ~oc~l cement returns. Cement in piaee at 6:20 AM., ~: I~ collar programmed for 1~00', Erroneously installed lower, then umable t° pull casing to recover collar. ~e~te~ at Cut & Reec~ere~ fleet ~e equlp]~ed w~th J~ eentrall~zer8: (1) on shoe ~oint, (~) on eeco~l (3) on ~o~nt belov !)V eolls~, (~) on ~o~nt above Le~b~ c~8~u~b ~nstslle~ end tested Blov Out Prevention ]tqu~pnent v~th ~0 ~st - CK. out cemnt to ~) per 3~1' dfl~d Lost 2b bbls. hud at 70~'. 71.1.6 - ~ pump pressure to 1000 psi. No further CONPLETION REPORT S~ImA.~ 0:1:I, CO.. Oi~--CAI,I~i~iA', O1~"01~ Dr~.lled 9 7/8" hole 9k - 99 pcf 7998 - I0,110 211~' drilled ~a~ ..cut mad from 9~ pcf to 92 per 8929'. Circulated and increased nmd weight to 98 pcf. Continued to have ~s cut mud after round trips. ~ Schlumberger X-ES ~O01' - 10,106' Sonic log 3OO3' - 10,105' · , Micro-caliper log Drilled 9 7/8" hole 10,1~8' - lq551' ~3' 4xilled 98 - 99~ pcf Rea Schlumberger I-ES, 10,106' - 10,553' an~ Micro-caliper log, 10,130' - 10,555' m-~Ued 9 ?/8" ho~e 10,~Sl' - 10,993' drilled 98 - 99 per Lost %0 bbls. of mud while drilling at 10, 58~'. Reduced p;,~ pressure to 1250 psi ~nd recovered circulation. February 20, 1960 _ Ran Schlumberger I-ES, interval 10,553' - lO,gg~', Micro-caliper log 10,555' - 10,92~', Sonic log 10,105' - 10,99~' and Dipmeter 5,000' - 10,994'. Cireulated an~ conditione~ hole ~ hours. FeBruary 22, 1960 Cemented 7" casing at 10,992' in two sta~es using ~lliburton Cementer Equipment. Bottom Stage: Mixe~ 1000 sacksBsmm~e~e construction cement with 0.~ HR-4 ~e~arderAd~ed to avera4~e 11~ - 116 pc~ elurry. Preceded cement with %0 bbls. of water. Displaced cement with rig pumps. Working pressure ~00 - 600 psi, final pressure 1250 psi. Full circulation throughout ~oB. Casing stuck at 10,992'. Could not reciprocate pipe. Cement in place at 5:07 AM. Did n~ ~umpplug. Second Sta~e: Druppe~ ~lliburton DV ~~ ~b. ~d ~ bbls. of ~d ~~ ~ ~l~r at 69~' ~ 15~ psi p~s~ ~thout ~~s. ~xed 692 sacks p.e~~~t~ion ~nt p~s. Pl~ ~ ~. ~~ p~ss~ 1~ psi. Close~ ~ ~1~ ~th 2~0 psi. ~ ~~ ~~out Job. ~ ~nt ~ ~ bbls. cf ~r. TOp 7 Joints ~)~. q'3' Next 22 Joints 931.22 ' Next 69 Joints 2~94.35' Next 7 Joi~ts 297.90 ' Next ~7 Joints 1961.72' Next 68 Jeints 2856.93 ' Bottom 41 Joints 1~. 8~' .00' TO AL Joints 1099 . 39 ' Above K.B. 2.00 7", 29~, N-80, Buttress, R- 3 7", 26~, N-80, Buttress, R- 3 7", 2~, N-SO, Buttress, R- 3 7" 26~, N-80, Buttress, R- 3 7", 29~, N-S0, 82, LT~C, R- 3 7", 26~P-l10, 8 R, LTa,C, R- 3 7", 29~, P-110, 82, L~, R- 3 Cement collar, shoe, and DV collar Cemented at Shoe Joint equipped with B~ker Flexi-Flow cement shoe and Ba~er Flexl-l~. w cement collar on tc~ of shoe Joint. Baker centralizers on all casing collars from 10,992' - 10,100' an~ between DF collar at 69~J+'. Baker reciprocating type scratchers placed on 5' intervals at the following intervals 10,210' - 10,2~0'; 10,280' - 10,3~0'; 10,380' - 10,~20'; 10,470' - 10,5~0'; 10,S80' - 10,650'; 10,7~O' - 10,800'. ~lliburton D~ collar located at 69~.30'. , l~n temperature Schlumberger temperature survey to 5450' where tool stopped. No i~dieation of to~ of cement. Leaded easimg with 200,000~ hook load. Installed Blow Out Prevention Equ/pment~ and tested. Held 0~. ~brua 2~t 196o Drilled out cement 6932 - 694~'. out cement 69~5 - 8577'. Drilled out D7 collar at 69~'. Drilled Fe~ruar~ ~-~, ~60 _ Drilled out cement $577 - 10, 2~0'. Schlumberger Gamma I~ -Neutron collar log surface - 10,229'. Per- ~orated 7" easing at 10,226' with 5 ½" holes using Schlumberger equipment and c~sln6 collmr~ for reference. so~ clm~ um:T Seetiou k(Pro~ected. ), T. _7 li., R..9 W.,.. se~e, rd....~ ~T~ OiLCO.'0F CA~~, OFEPATOR Squeezed holes at 10,226' using /alliburton cementing equipment. Set I1/ retainer at 10,126' and squeeze~l, shot holes with 50 sacks cement, l~rmation Breakdown pressure ~500 psi. Working pressure tncrease~ from 2/~X) ~pt to ~700 psi fixm,1 pressure. Estimated 35 sacks cement put away. Drille~ out retainer mt 10,126'. Drille~l out cement DrAlled out ~t 10,2~0 - 10,~10'. Schlumberger Jet perforated holes lO, hO2' using ea~in~ collars for reference. Attempted to squeeze holes at 10,~02' using ~alliburton equipment. Set DM retainer mt Pressure tested holes with 5~O0 psi maximin pressure. Held ~ psi for 5 mtmtes with 2000 psi on ~nnulus. No breakdown obtained. Drille~ ~ut re- tainer mt 10,278'. Drilled out co, ant lO,~lO - 10,610'. Schlumberger Jet perforates 5 ½" holes at 10,6OO' using c~sing collars for reference. Squeezed holes at 10,6OO' using Halliburton cementing equipment. ~et retrievable retainer at 10,~O' a~l squeeze~ shot holes with 100 saeEs ce- ~ treated with O. ~ ~R.~. Preceded cement with 10 bbls. water and followe~ cement by 1 bbl. water and 52 Bbls. drilling fluid. Formation breakdown pressure ~)00 psi. Working pressure increased from 3000 psi to 5000 psi final pressure. Estimated 77 sacks c~ put away. While m~ng in to ~rill out cement dropped slip handle into hole. ma~met with no recovery. Drille~ out cement 10,~81 - 10,595'. ~o cement 10,595 - 10,610'. Pressure teste~ caS. lng to Z~OO psi. Drilled out cement 10,~10 - 10,975'. Using casing collars for reference, ran Schlumberger equilment aad Jet perforate~ 5 ~" holes at 10,965'. ~lli- burton DM retainer aeclde~.~lly set at 7070' while running in hole. Drilled cut retainer at 7070' and cleaned out to 10,97~. ~queeze~ holes at 10,~5' using Halliburton cementing equipment. Set re- trievable retai~er at 10,~' an~ squeezed shot holes with 100 sacks cement treated wl~h O. ~ ~R-~. Used hesitation technique. Formation breakdown pressure ~O00 psi. Working pressure deerease~ from 3000 psi to 1~00 psi final pressure. Drilled out cement 10,SA~- 1089~', ~nd 10,930 - 10,993'. ~8 ~ore .$2 - 11,295 - 11,315' 17' Fine gra~, silty, glauconite lithic feldspathAe sandstone. Fine, fairly well sorte~ quartz, plagioclase, and, lithie grains in a silty to clayey matrix. Chert am~ chert-like grains are comaon; volcanic (flew) graime are rare. Eormblem&e grains seen on thin section. recovery. Mareh 10 - 11, 1960 l~n Schlumberger logs am~ recorded I-ES log over interval 11,072 - 11,313', Mterolog 10,996- 11,316', Sonic log 10,995 - 11,~13', Dipmeter 10,983 - 11,31~', Gamma ~ay - Neutron log 10,229 - 11,317'. Displaced 77 saeks eonstruetion cement treated with 0.~ ~l:l-ll. threu~ 2" tubing and ~" ~mill pipe hung at 11, 300'. Drill~l out cement 10, 99~ ' 10, 999 ' · Displaced 50 sacks construetion cement treated with O. ~ NR-4 through 2" tubing and ~" drill pipe hung at 10,997'. Schlumberger Jet perforated 5 ~" holes at 10,225 - 10,~26' using casiag collars for reference. WBO at 10,~26' - ~an R~CO tester on ~" ~rill pipe with 2993' ~C, 1~' ~t pa~er at 10,17~'. ~~r ~ ~ = 2 ~tsi~ BT's, 8' ~il, ~~r ~fety ~oint, ~c J~,l i~i~ ~, ~-~~ ~s~r,_~'., ~H pi~e) ~ ~lw, ~93' ~, ~ s~ ~ 13.~ ~ pipe. ~s~r for ~ ~~ i~ti~ s~utia at 1:~ ~. ~e~ ~ ~ b~at 1:~ for 1~o~~, ~. ~~~ 3/8" ~at 1:~, Olos~ ~ ~ for ~ ~~ ~1 s~utia at 2: ~ ~. ~~ ~~r 1~ ~:~~. ~~~' ~ ~se 9~~. (90' ~ ia fl~~~se of air P~ESSURES: Inside BT Outside BT Outside BT IH ISI IF FF FSI FH 6598 7~ 1339 13~1 1509 6557 6657 191 1453 1~ 16/~0 65~ 6567 1~ 1~5 13~ 1550 65~ Schlumberger jet pe'rforate~ 5 ½" holes at 10,597 - 10,598'uslag easing collars for reference. page 9 ~O at 10,598' - ~ HO~O tester on ~" drill pipe with 2993' ~C, 90' AC. Set packer at 10,5~3'. Teeter ~e up - 2 outsi~ BT's, one i~~ ~eker ~fety Joint, ~~~c $~, l~i~ BT, -s ~ tea 1 s " ,,. ~ ~ ~ re r, ~' AC ~f ~ ~~ ~" ~11 pipe 13.~. ~en~ for ~ ~nute i~tial shut- ~m?~ ~.~ ~. ~d ~ v~ ~ ~ ~ ~o~',~ o~ o~ ~ur new rot ~ ~te ~~ shutlm at 5:~ PM. Packer ~oae at 5:~. ~' ~t ~ae. 91~ pc~d $0' ~ in fl~ ~~e of AC). P~ESSU~ES: I~ 7SI IF FF FSI FH Xnside BT 68o~. 53 299 13Ol 1682 68o~ Outside BT 6812 109 1360 13~7 1733 6~12 Outside BT 6819 2123 13~6 13~ 172~ 68o6 Schlumberger Jet perforate~ ~ ~" holes per foot 10,230 - 10,250' using collars for refereaee. ~an R~T 10,2~0 - 10,250' on ~" drill pipe with ~er at 10,176'. ~s~r ~e ~ eo~is~of 2 ~tsi~ BT's, o~ i~i~ BT, ~s~r, 1~' AC (~t~m s~ ~ ~/~ OD X 2~",~ ~, ~ s~ ~" 13.~ ~~ ~e), ~ ~, ~s' ~ (~ s~ ~, ~.~ ~r at ~:~ ~ ~r ~5 ~~ l~ttal s~tln. ~ b~w ~en-d~. ~" ~ ~e~d 10 ~tes. ~ened ~at bl~w inc~si~ to at~ tn 5 ~nutes. Shut ~11 in at su~ee at 7:0~ ~, for 52 '~~s ~ cl~r su~ flow ~. ~en~ t~l at 7:55 ~. ~s~on ~ s~ce 7:~ A~. ~ ~ oil ~ su~ ~~u~s ~ter. ~ tu~ ~ trap at 8:25 ~ f~r ~ ~te ~,~st. A~~ ~ psi su~ee p~ss~. Shut ~11 in at ~~ at ~ cl~ t~p ~ei~es. ~~ ~11 at 10:~ ~ for ~tio~ 11~ ~~ flow ~st. A~~ ~ ~w ~ 1~ B/D oil, ~u~ ~ ~/8"-~ (~~), 6~ psi suite p~s~. ~1 e~sed at ~:2~ ~ ~r ~ ~te ~ shu~n. ~~ttled ~se. A~~ oil ~t O. ~ ~r ~d ~A. A~m~ ~e~d oil ~ty ~.0 ~es. SABLE CO~ (~WITY ~ OUT ~TER S~ COMPLETION I~PORT SOLD~ CREEK ~I~IT ~1-~ ~ion 4 (PreJected), T. ? N., R. 9 W., Se~rd m~ S~ OiL Co-."0~ c~o~, '~m~o~ ....... Page 10 March 14, 1960 (Continued) PRESSURES: IH ISI'- IF FF 'FSI Inside BT Outside BT Outside BT 6612 - - clock stopped ................... 6~ ~ 3701 ~259 5267 ~92 ~9 5196 ~78 ~195 51~ ~33 Drilled out cement 10~810.- 10,850'. Schlumberger Jet perforated 4 ½" holes per foot 10,~6~ - 10,58~' using casing collars for reference. ~CT 10,565 - 10, 58~ ' · ~ls failed. ~T 10,~6~ - 10,58~'. Ran R~T on 3~" drill pipe with 2993' WC, 180' AC. Set packer at 10~13'. Tester makeup consisted of 2 outside BT, inside PP~, 8' perfs., packer, safety joint, hydraulic Jars, inside _BT, hydro-spring tester, 180' AC (bottom stand 4 ~/4" OD X 2~" ID DC, top stand ~ 13.30~ drill pipe) TC valve, 2993' ~C (~2 stands ~ 13.30~ drill pipe). Opened tester at 4:26 PM for 60 minutes initial shutin. Opened ~1., bean at }:26 PM for 87 mimmtes. Immediate wemk blow increasing to medium strong blow in twe minutes. Steady medium strong blow thereafter. Opened 3/8" bean at 6:~3 PM for 8 heurs 22 minu~es. Medium strong blow decreasing to medium blow in 15 minutes. Cushion to surface 8:47 PM, 3 hours 21 minutes after opening tool. Unloaded cushion and emulsion 2 hours 8 minutes. Well turned to trap 11:17 ~M. Well flowed at average rate of 340 B/D oil' ~0 - 100 ~F ~s on ~-" surface bean, 12~ psi suri~ce pressure for 3 hours 58 minutes. Trap pressure 11~. Tool closed 'at 3:15 A~ for 1 hour 29 minutes final shutino Backscuttled rise. Pulled packer loos® at 4:~4 AM. 11:~5 PM 31'1 12:15 AM 34.7 m:45 AM 36.9 l:~-~ Aa 36.7 :1.:4~ AM 36.9 ~:~o Aa ~6.9 a:~ m ~. ~ ~ATER 17.~ 8.2 6.~ W 2.8 6.8 3.a 3.a w o.~ 2.8 0.8 ~.8 ~. 0.2 2.6 0.~ 2.2 ::1.6 o. 2 1. ~ e~l. - 2.2 0.7 1.~ e~l. 0.1 ~.7 L6 o.9 w 0.2 ~.3 ~.~ ~- 0.5 w o.~ PRS~UI~8: Inside BT Outside Bt Outside BT IH 66~o ISI IF FF FSI FH - a0a~ 36a3 55a~ 6~82 - 190~ 3~ 5518 65~ - 1899 3~6 5~33 650~ Sehlumber~er J~ perforate~ ~ ~" holes per foot through following interm!e u~in~ e~si~ eo~ f~r refe~ee~ 10,565 - 10,508', 10, I~78 ~o,~o~', lo,~.- lo,~ao', z~,23~ - ~o,~5', lO,~65 - ~o, 2s4'. ~ost Co~ez~d carrier g~u in hole during operatAon. (Interval 10,250 - 10,234' d~mestic, 8 R, ~, 2.1" ID ve~turi Eaa~ at 1% 577' . ,. X~lle~ chrlst~ms tree a~ ~es~e~ to $~000 psi. ~ld ~. ~c~t~led '~ ~ c~ oil usi~ ~b~n p~i~ e~p~t. CI~ oil ~ .sure at 9:15 ~. ~~ ~ at fo~~ rotes: 10:~ ~ tC..!2:.O~ _PM' 1 hour.20 minutes, 3~/6~ ~ean, representative mate 1~05 ~ ..__to 1:0~.I~, i hour, S~/6~, representatXve rate 1020, CP--~O, 117 psi trap pressure. ~-:.o~.....~..to 1:3o_._~g 2~ minute, sm, ~ ~, ~ k~3o 1:_~ PMto 2:05 ~ ~ ~tes, ~/~ ~, ~ ~ B~, 10E0 ~F, ~ 6~, 2:0~ pM ~o 2:35 PM, 30 ~~s, ~/~ ~, ~ ~350 B/D, 1150 ~, ~ ~90, ~ ~70, trap p~ssu~ 117.- ~ RECEIVED Oil & Gas Set-tim, Division of M;~,*'~: a?.d )~;~i:..c:-als Alaska Dept. o[ Natural B. csources COMPI~TION S0LDel~ C~ U~I~ ~,~rch m~, 1960 (Cont~n~ed) _ 10:~0 11:~0 12:BO 1:0~ 1:30 2:00 2:30 Rig released at 6:00 PM M~rch 21, 1960. 6.7 .8 .2 .2 0 .2 .0 .2 Page 12 .2 .6 .6 SaM T T T T T 0 PRoDuCING DE:PARTM £NT T£LI~PHONI~ 47001 J. T. CROOK£R DISTRICT SUPERINTENDE:NT P. O. BOX 839 ° ANCHORAGE ° ALASKA June 27, 1960 RECEIVED JUN 29 1960 CONFIDENTIAL Oil & Cas Section Division of M/r,e's and Minerals Alaska Dept. of Natural ltesources Mr. Richard Murphy Al~sk~ Oil & Gas Conservation Commission 329 2nd Avenue, Anchorage, Alaska Dear Sir: Attached, hereto, i$ the Completion Report for Soldotna Creek. Unit Well No. 41-4 (1) for your information and files. Very truly yours, STANDARD OIL COMPANY OF CALIFORNIA Western Operations, Inc. Attachment UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42-R356,5. Approval expires 12-31-60. ...;qO OFFICE ~.~ ................ u.,~- .,~0..1~_._ ~r,q~ __~_ _t .... LESSEE'S MONTHLY REPORT OF OPERATIONS The followin~ is a correct report of operations and prod~etion (inel~din~ drillin~ and prod~ein~ wells) for the month o£'_~~ ............................ ,1~__., __..8~._~__~ ........ /l~ent' s address .... ~-.---0.--]~--'~-~} ......................................Company ~~~ ....... .............................. ~--~ ............................ ~i~ned ................... LI,._L..C2,~;/:.~(,~'~..':. :::~ .................. e~o~ .................... ~,._~: ................................................ ~'~ ~i~.~_.___~_-~~___ , , SEC. AND GALLONS OF BARRELS or RE1VIARKS ~ OF ~ TWP. RANGE WELL DAY8 CU. FT. OF GAS NO. Paoo~cmr BARRE~ OF OIL ~RAVITY (~ tho~ds) ~ASOLINE WATER (If (If drilling, depth; tf shut down, educe; ~ECOVERED none, so state) date ~d r~ult of t~t for g~ol~e content of , ,, , NoTE.--There were ']{0 ...................... runs or sales of oil; ............... ~ .......................... M cu. f~. of gas sold; ................... ~ ..................... runs or sales of gasoline during the month. (Write "no" where applicable.) NowE.--Rd~5~Yrt on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-329 · (January 1950) 16~2§706-8 U. $. GoYERNM£NT PRINTINO orrtc£ ._~' UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY ' Bud~ BuFeau No. 42-RSfM, S. Approval expiFes 12-31-~L* LESSEE'S MONTHLY REPORT OF OPERATIONS .. 8tare ...... ~ ................ &o~tyK~.~ Field ~~ ~ ]Jl~t ~-~-v~?-.--.-. ~- ........ ~----7--~ ......................................................................... TI~e foltowi~ is a correct report of operations a~d prod~etio~ (i~el~di~ drilli~ and prod~ei~ ~.~ ~o~ ~lt~~~.~.~_~ .......... , ~_, ~ ~.~ -~:. .__:_-:_,~._'~_~:~~ , ............... : .... - ........ ~~~.-~.-~-~-~ f?~T~~~~~. ............. ............................... ' ........ '~~":~- ........ ' ..... ~'~ ......... : .......... -~;-:r-c~oo~sg ............... Pko~e ................ : .............. ~:~~.., .......................... ~ ..... J~e~t s title ~..~~~~~ SEC. AND (]AS ~ OF ~ TWP. RANGE WELL D*~s GALLONS OF BARRELS OF NO. PROnUCBn BARRELS OF OIL GRAViTY CU. FT. OF (In thousands) GAsoLn~E WA?~.R (If RECOYERED none, so state) ~,, . __ _ REMARKS content of gao) (I! drilling, d~l~th; ff shut down, eau.e; date aud result of test i'or ge~oline : NoTE.--There were ~ ........... .~ ....................... runs or sales of oil; .................. ~ ......................... M cu. ft. of gas sold; .................................... ~ ...... runs,or sales of gasoline during the month. (Write "no" where applicable.) No~E.--Report on this form is required for each calendar month, regardless of the s~atus of operations, and must be filed in .duplicate with tho ~upervisor by the §th of the succeeding mo~th, unle;~ ?e~/~ff directed by the supervisor. · .o= ,,-,,.,,,,,...,..r:,,. ,,,...,, "" ...... -.-.-:/ ,,.,.,, ,,. ,,., ............... R~ V' ~~ ' ' .. ]~~ ~ :~ ~)ggO-~ v/..~ mix ee v/o.~ ]m.,~. Z,3NmeM4 v/zu o~. , 10~.~, m~ ~1~ ~, ~ ~m. tree RECEIVED MAR 28 J960 Oil & Cas Sect;on Division oc ~ '. ,.'.: .~" ';l-..erals UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. Approval axpLms 1~-31-60. . LAND OFFICE LESSEE'S MONTHLY REPORT OF OPERATIONS The following is a eorreet report of op'eratior~s and prod~otior~ (ir~ol~dtng drilli{~ a~ prodding ................................................ ........... ............. ..................... ~o~ .......................... ~ .......... ~,~~ ............................. ~'~ ~ ~~~.~~~~ SEC. Ah-D BAP~B~T~q OF OIL i ORAVXTY GASOLFNE WATIgB (~ (H ~Hng. d~; If shut down, ~ OF ~ TWP. RANGB W~ D&~ OU. FT. OF GAS o~Ns OF BARRB~ Or REMARK8 ~0. PnOD~BD ~ th~) ~ ~d ~t of ~t f~ ~BCOVEEED none, so s~) ~, ~ ~) psi. NoT~--There were ............. .0 ..... , ................ runs or sales-of oil; ............................ ~) .............. M cu. ft. of gas sold; -.'_, ................................. ~_ .... runs or sales of gasoline during the month. (Write "no" where applie~ble.) NoT,n.--Report on this form is required for e~ch c&lendsr month, regardless of the status of operations, and must be filed in duplleats with the supervisor by the 6th of the suoceeding month, unless otherwise directed by the supervisor. Form 9-829 ~ ~..... ,,--~,~-, ,. ,. ,0,,,,,,, ,,,,,,, o,,,, R. ¥. .5i . UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. A~proval expires 1~-81-~0. LAND OFFICE ................................. u.-,- ........... ..sg...z..~...c.~.e.L LESSEE'S MONTHLY REPORT OF OPERATIONS , , SEc. AND oo. FT. OF OAS }'~ Or ~ Twr. RANOE WELL D~x~ GA~ONS Or BA~Rz~ o~ R'EMARK8 NO. P~ucm~ B~R~ OF O~ GRA~TY GA~E WATER (~ ~ th~&) ~EcOYERED none, so 8~) , , , ~n~t ~ ~-7/~" ~s 10, ~'-X0,~72~'. ........ EEC Di~ /s/on o1: ~i~. :'~; NoT~.--There were ............ ..". ........................ runs or sales-of oil; .................. ..~_ ....................... M cu. ft. of gas sold; ..................................... -0 .... runs or sales of gasoline during the month. (Write "no" where applicable.) NoTn.--l~eport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding'month, unless otherwise directed by the supervisor. Fornx 9-~29 (J'atmary 1950) 1e-.--~67~ ti. I. IOYIR#IItNT PRI#TIIffl O~elCl UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 4~-R~.~. Approval exph~. 1~1-60. ~E NUMB~ u.~ ....... ~~.A~ ....... LESSEE'S MONTHLY REPORT OF OPERATIONS Tl~e followi~5 is a correct report of operatior&s arid prod~ctior~ (i~clmti~ dHlli~d a~ prod~ci~5 J~e~' s address ............ ~--0~.~--~~ ........................ ....................................... ~~,._~ .................... ~~ .................. _Q~J~.~i:~4 .................... ............................ .................................. , , , WELL DAYs BARRELS Or OIL GRAWTY GU, FT. or (]AS GALtONS Or BARRE~ OF RE~ARKS SEC. A~ ~WP, RANGE ~0. PaO~VOm~ ~ECOVERED none, ~ state) &~ ~d r~Mt of ~t for ~ OF ~ (~ tho~&) GAS0Lm~ WA~ (H (If drlll~z, d~th; if shut down, ~t ~ ~) I .... [.ECFIV[¢' ~ ~ H. ~~ .... NoTE.--There were ........ O ........................... runs or sales of oil; '-"0 ..................................... M GU. ft. of gas sold; ................................ O ..... ~ .... runs or sales of gasoline during the month. (Write "no" where applicable.) Nor-.--Eeport on thia form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the suoceeding month, unless otherwise directed by the supervisor. FOF]]I3. 0'~'~9 10--..'~S760-8 u.s. GOVERNMENT PRINTII~ OFIrlCE (lanuary 1050) UNITED STATES 'DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42-R0~6.§. Approval expires 1,~1-430. · ~.~ omc~ _~ .................... ~ ,u~m~--C~ .... u., .................................. ~ ........ LESSEE'S MONTHLY REPORT OF OPERATIONS T]~e followi~ is a oorreot report of operatioz~s az~d prodz~otio~ (iz~olz~diz~ drilliz~ anal prodz~5 ~,~t' ~ ~aa~,8, ................. .~;_..9.;.____~__,_1_~__~ ................... '~.~ .......................................... ~.~Mll~_,__~~ ............... si ~ea ............... r_~,.._~.,~ .~._,...,~:~ ....................... r~,~ ....... · "~ ~_~ "~' "':~"" " .......................................................................... .~,~t'~ utz~_i~::;.~~ ............ , ......... ,, AND BARI~L9 OF OIL (~RAVITY GASOLINE WATER (~ (H d~l~g, d~th; ff shut down, O~ ~ ~P. RINOE WE~ D~.z Or. FT. O~ GA8 OA~oN8 O* BARSI~ O~ RE~ARKS NO. P~DUOED ~ tho~&) RECOVERED none, ~ s~te) ~ ~d r~ult of t~t for ~n~t d ~) : ce; L, H ~~ .... NoT~.mThere were ........... .Q ........................ runs or s~les of oil; ................... 0. ...................... M ou. ft. of gas sold; ............................ ~ ............. runs or sales of gasoline during the month. (Write "no" where applieable.) No?n.mReport on this form is required for e~ch c~londar month, rogardle~ of tho status of operations, and must bo filed in duplicate with tho supervisor by the 6th of the succeeding'month, unless otherwise direct~cl by the supervisor. FOrth 9-B29 (January 1950) lO.--~?oe~ u.m. ~OVwRHMENT PRI#rI#O OfFICe UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY 'LESSEE'S MONTHLY REPORT OF OPERATIONS TAe followin~ is a oorreot report of operations and prod~otion (gnoludtnl~ d~in~ a~ prods~ng ..... ~ ................ ~f~t'~ ~. .......... ~...~...~..z~ ........................ ~,omp~y..~.~~~~, .......... · ~ed ................... ~---~--~~E~ ............... P~o~ .......................... .~..~~ ........................................ ~,~ ,,~ AND WELL D&~s OU. FT. Or O~ or ~ ~. RAhaB GAiNs ~EMARKS' NO. ~ P~DUOnD BARR~ OF O~ GRA~ GASO~NE WATER (~ ~ tho~&) ~ECOVERED none, so s~) oon~t d m) . , .. ,~--.,--..~ ..eL~ ....... u R CEIVED R, ~'. ~ Z ~ FEB 4 1960" Oil:~ Gas Section Division o[ Mi~es and Minerals ~ ~aa~ Del>~. o[ Natural Remurces : . : NoTn.--There were ........ ..0. ........................... runs or sales-of oil; ........................... _0_ ............... M ou. ft. of gas sold; .............. L ................... ~.l ...... runs or sales of gasoline during the month. (Write "no" where applisable.) NoT~.--Report on this form is required for each calendar month, regardless of tho status of operations, and must bo filed in duplicate with the supervisor by the 6th of tho succeeding'month, unless otherwise dire&ed by tho supervisor. Forln 9=$29 (January lOS0) 10---267~J-8 u.I. GOVLPRNMENT PIIIHTIK 0~WICg UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS ,The foltowi~,~ is a correct report of operatior~s and prod~ctior~ (ir~ol~din~ drilli/~ a~d prod~oin~ r ~ ......= r ~~ ~ ' ' ~ ~ ............. '~g~m ~gnuu ......... ; ............................. ~~¢_~~ ................... ~f~¢~ ........... .~_..~_..¢~r.,:~ ........................ ~~ ............................. ~._~~ ..................................... ~e~,', u,t~..~.~"'" ~~"~" .................... SEc. AND CU. FT. or GAS ~ or ~ Twr. RANOE WELL DATS GALLONS Or BA~R~ O~ REMARKS ~O. Pao~woe~ BABBE~ OF OIL ORAVITY (In thous~ds) GASOL~E WATER (If (If da~drffitue'sad r~t d~th;oflf~t shut f~d°wn' ~ECOVERED none, 80 8~RtO) ~n~nt ~ ~) ............. Now~..--There were ....... ,0.:- .......................... runs or sales of. oil;: ........ '0 ..... : ............................ M cu. ft. of gas sold; ................ !~[ ............ - ............. runs or sales of gasoline during the month. (Write "no" where applicable.) l~lo?~..---Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-829 (~Ianuary 1950) 16--25766-8 u. $. OOV£RNMZNI' PRINTINm OFF~C£ PRODUCING DEPARTMENT TELEPHONE 47001 J. T. CROOKER DISTRICT SUPERINTENDENT P. O. BOX 839 · ANCHORAGE · ALASKA November !0, 1959 Mr. R. V. Murphy State O&G Conservation Comm~_ssion 329 Second Avenue Anchorages Alaska Dear Mr. Murphy: Please refer to our exchange of conversation regarding additional details you require on our submission o£ permit to drill Soldatna Creek Unit Well 41-4 (~l). The follow,lng should furnish you the details you requested: Blowout Prevention Equipment: 3000~ working pressure double ram for complete shut. off and ram for shut off around drill pipe, casing Or tubings with a 300~0~ hydril GK mounted on. top of ram. Program: Cement 20'' ID conductor pipe 5-10' below cellar floor. Drill to approximately 3000'. Cement~13-3/8'' casing with 2000 sacks or sufficient cement to fill to surface. Drill full hole for 7" casing (10-5/8" - 9-5/8") to total depth estimated at 12, 400'. Run Schlumberger IES to total depth. Core and test as conditions warrant. Complete with 7" casing or abandon on basis of tests and cores obtained. We shall add the above information in the remarks section of the Permit to Drill format we will submit to you on future wells. Your early approval and return of the permit on Soldotna Creek Unit Well 41-4 (~l) will be appreciated. Oil & Gas Sectio~ Division oF Mines and MincvdS Yours very truly, STANDARD OIL COMPANY OF CALIFORNIA WESTERN OPERATIONS, INC. J. T.40~KER Soldotus Creek lthtt lb. ~1.4 (1) Permtt Bo. 1~ Issued ll-l&-JS~ Lout gle~ Pet f 1~' ~, 1~~ ~d ~trt ~tol ~1~ ~. 12-31-~ ~ltd{ ~ 3-21-~ ~ 1111~e i350 B~, It.i' ~I. ~ t~1, 3~i~ ck, ~ i~ PSi8 10~5'-i0275~ , 10265 *-10~*. 11~'-1~~ ~" ~ 2~" 2 2' 7" 9 I~2~ v/l~ ~ ~ ~ & 692 ,x thru ~11~ ~ 69~e 2-7/8~ Cbs ~ O 10577* ~rmuo~ l~lver Oil field is ~proved subject: t:o the £ollcqrl. n8 p~-ovtsious: indicate p~ck~r se.~L~ depths ~nd tuJect~u ta~ervalo. A co~1e~'' Fo~ ~. ~-13~ lepor~ of Injection ~roJec~ shall be filed no hte~ tha~ the IO~h' dsy of ~he nouth ~ollo~ ~he uon~h reported. ten (I0) Very ~ruly ~ours, ~ R. Soyster Donald D. Bruce Ch~e£, ~e~roleum Branch PRODUCING D£PARTMENT TELEPHONE 47001 J. T, CROOKER DISTRICT SUPERINTENDENT P. O. BOX 8 3 9 ° A N C H O R A G E ° A LA S K A November 3, 1959 Mr. Richard Murphy Petroleum Engineer Alaska O&G Conservation CommSssion 329 Second Avenue Anchorage~ Alaska Dear Sir: We enclose herewith Alaska. O&G Conservation Comm~ ssion Form, P-l~ Application for Permit to Drill, covering Soldatna Creek U~t 41-4 (~l), with check in the amount of ~50.00 to cover pe~t fee. Please return the yellow copy indicating the permit number and approval date for our files. Yours very truly, STANDARD OIL COMPANY OF CALIFORNIA WESTERN OPERATIONS, INC. J. T.~C O0~R attachments NOV 4 1959 Oil & Cvs Sc', ;;~: Division ot: l~,~!t.~,s a~,',[ Mi~erais ,'[laska Dept. of ~&turai Resources =~ .- APPLICAT~ION TO DRI~.I~.~.-.-, I~.EEP~..N E] PLUG BACK DATE Address : ,',._ - .....~-:. : ..... ~:-~; ~-:~ :?::,~ .... r :: -~ ~x_. ':Clt? v~'m~:-: State ~Vell location (~[ve footage from section Distance,~in miles,. _and direction from nearest town or post office ~ ~ ~'i.~_~ h-,~ :..:. - ...... - L .~: ..... ~..' : .... Nearest distance from proposed location Distance from proposed location to nearest drilling, to property or lease line: completed or applied--for well on the same lease: ~ ~ feet feet Proposed depth: Nui~ber of acres in lease: {Rotary or cable tools [ Approx. date work will stare Number of.wells on lease, including this well. completed in or drilling to this r~ervoir: If lease, purchased wi.th- one or more Name wells drilled, from whom purchased~ - Address Status of bond Remarks: (If this is an application to deepen or plug back, briefly describe work to be done, giving present producing zone and expected new producing zone) NOTED CERTIFICATE: I, the undersigned, state that I am the ~~ of ~e ~ ~ ~ ¢1~ (company), and that I am authorized by said company to make this report; and that th s report was pre- pared under my supervision and direction and that the facts stated therein are true, correct and complete to the best of my knowledge. Permit Number: Approved By' ~U~~~'~'"~ '-' --' ' ~-~-~I~-r~i¥, Petro~um 'g.~dneer '~ Notice: Before s~4~di~g in tl~I~, ~orm be I~ur~e~thali/~ou have given all infor~laltl~l~lae~te~l~tl;tqlllu~l~Ciml~Y~L[~llgr correspond- ence will. thus be. avoide~l.~ . _~ Alaska Dept. or mammz Resource~ See Instruction on Reverse Side of Form Signature Alaska 0fl and Gas Conservation Commission AppLication to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. 1 Effective October 1, 1958 Form 9-~1a (Feb. 1051) ..... ! ...... , ...... t ! ! ! ..... ~ ...... ! ..... : ...... (SUBMIT IN TRIPLICATE) UNITED STATE~ DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42-R358.4. / Approval expires 12-31-60. tend Offico ~ i.,ea~e No.._~ .............. SUNDRY NOTICES AND REPORTS ON WELLS ,, .o~-,o= o,: ,.~-?o. -to .,~-o.,'- o..~.^,, w~ ............... II ~u,~ou..~- ..,,o.~- o,~ ,~.o.,~.,,,~ o..~.~,. ............... '1 ..... NOTICE OF INTENTION TO ABANDON WELL ........................... ]1 ............................ (INDICATE ABOVE BY CHECK MARK NATURE OF REPORT, NOTICE, OR OTHER DATA) Well No. ~:~:: is located :~'_;__ ft. from__ line and ~___ ft. fro line o .- ........ ~_~_:~ ............... ~_r~__~_~:_:~_~_~_~, ..... ~ ............... (~ Sec. an~t SeC. N'o.) ..... -(-~.) (Range) (Meridian) ~-~~ ~ ~_~~ .................. ~ ................ .................. ~'i~a5 ........................ (county or Subdivision) .......... DETAILS OF WORK (State names of and expected depths to objective sands; show slz~s, welght~and lengths of propom~! eamings~ indictor® muddinl jobs, c~ment- lng points, and all othar important pro~msad work) I understand that this plan of work must receive approval in writing by the Geological Survey before operations may be commenced. Company __~_~_~:_~:_~~___~_~_.L*:~-~__-=_.===:'-.-= ............................. Address .... ~_~:i~_~ ........................ By ........... ~--~i--~ ....................., Title ................. .~ ........... ~. ..... -2 ...... ::--::::::::: ..... GPO ~ 18 507 ? 4 1 I0 2,020,'000 ~ev~$ed Pla ~ 155 ', ..... .r! .J Well LocaHon Pla~' Zbo~v~n~ 3ur Loc. 3CUdI' ~ ~ 3~-~ d~o/tam Hole Loc. 3 C ~ 3Z-4 I[ ~ II II I ' II IIII NOTICE The following well logs and oversized documents have been placed in offsite storage. If you would like to view the original documents, please contact the AOGCC librarian. AOGCC 3/4/2005 :~ ;ç¡fJ ~ i , t! ~ Ii . .: ¡ ,I , .~¡:. :~.""'~, - ~" S UH iùiì BÈ Ìlc ER' wILÌ~ š ùR'VÈrÌN G" Ù Ò RPÒ ÌlÀ'Tì Ò N "~ ~" """"""""" HOUSTON, TKXlS """"""""""~ 1. ' . , _I _. ..--- . llcrals ~ùurC{ z >-, 0 ....L.._ 01- ZO<-I =>-IU-I OwOw UU:-I3 RUN No. Date First Reading Last Reading Feet Measured Csg. Schlum. CS9. Driller Depth Reached Bottom Driller Depth Datum Mud Nat. Dens. I Visco Mud Resist. " Res. BHT Rmf Rmc " pH " Wtr. Loss Bit Size Spcgs.-AM MN IND. Opr, Rig Time \- TrucK No. Recorded By Witness cl~- ¿;/ed;im/oØcf ~ ! J ¿ - :ã1_ -'_ _ ~ all CO. -=lr~ - -¡ "'- ~ -~r"' - II - -,-_t - -'- -... ~ríDt:NllJ\\:-='- :--: ¡ :-1 I : 1_; '_, I - r-,.., k. Elevation: D.F.: .. i /80 ,I K.B.: - -,_.... or G.l.: /fi'ô -- - '-,~~ ! Other Surveys AIL -J'¿ - liRN Dip. S~V€. Location of Well , . >- z ~ Q.. ~ o u /' COUNTY Kenai STATE Alaska -, '-' FlUNG No. - ~ - ~ , -2 - -3- -4- -5_d__-~.J.- 2 -/2 -60 ¿- I...cj- fin 2.: ~o -60 .J - 4- - 60 -'_ ¡- If'¿ / ù ô ' IO} 5~.. 'J I 10, .9.94 J 1/) 0 7 Z I -, ~:-/- ..3,()O/' IOJ I(){;' 1(),S..")..9' /0/.994' ,~,~,._.i1 7 / ():'i ' 45 7 I 44/ I 78' ~':~; 3}000' /0;1984' ~I ,-.-, r P?' .J,fJon~/.:¡·h/' 3)OQ() I 3~OOO' IOJ983' -~-,.J~ \-10n..~' lo,/In' IO,.5..í.7' /()J,Q,98' /1)077' - ..,goon' I()}I/O' IOr¿;Ji/ ' /0, .9.95 I II) () 72.'. )r~~:... K,R. ..J . G PI. -. 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M~HI\MA~ f· ¡ I' t ~~HR 1A~ . ~ ~~ ? ~ ~ ~. ~~ ~ ~ ,'~, ~ ~ , f~\ I ¡ ¡ I . ¡ ~. ·~.orf,Höle '~ecþrd . '1· . t " l':"~':'! '.,'1,1 .¡, . :' Tubing Recor~.\ ~.>~'~ 1'- ~~ ~ ~.~, ';.... ,: {~;:I" ¡RUnt' ~Ol: . ¡. Bih " t . ì~ ;....."F,~.o ~,rn . L, ':;Q - fa ¡I . I ~ !3·s~zel ;:g3't,· SUo FRrFoAmCJ ~ ;~: ;)18,1 °9';1! ¡. 'I}.i 1" . . ~;:.I>., ~ .. . I r-.:: . "'~ ~ ';). i ;... ¡..,' .? ¡' D. I:;j' ~.. D :-, ~~ ~, : ~ . ~ ", ~~\,'.~': I ::.. : h ! ~'I '" I I ~ , '.J ..... i ~ 1..... ¡ ..... \ ~. _ ~: ?7(:P1 '!6... 5 .9891 J ~:~ ~: ~- ~1 O.~.!)6 t. i;-J. ..' : X:· . I t è ~ .~. ~ t: t ~ I'Ll :~ I ~! ~ 1. I ~ I ~~ I ~ I ~:' t; . ~\ 1. ~. . _ .' ~ " J i' j :: '.~ ;! ~~ ;- @ ~ _" ~ J; '.'- .~"/ I;.;; I ~ I ::J 1_· I ?: t CåS1f1ÇER¡EJ,~Or~ l? ~ 'I ¡ø ¡(.) I:, ~ l..u, c'. i liner ~'þ;, -:'.. --: ~ ~ f ~ \ q-: 1 . ~:. ' . C'~ ,. .f} ,-) - ";¿ -;¡. L ... ." . " . 'J..:t. _. :::. ¡ I ." ... . ." ~ If' . pi,;.... I~I~~;~....=; ~9yl.,·,:g~t~~~lg.:Ÿ..r(:~¡~\í8·, ~~~~~":. ~Wgt· From / To {"'h' l\;'~' '~'I(¿ ¡"~ ,~t ~.¡:~. ~flRffAÇEëiU~" '·:11n9~tt}& "0 ío 17i I· ~ .... j ~ C I !:;: II'" :n',,"..·..f . '1' ..-r,....,. .~. l, ,.. T, ,. ·'¡l~· ., .,- .Ã.. ,.....'..".. . ····1 . . . ... i ~ . ~ .~.. <::"~'~~, ;'~;_ _:.t~,'~.~,< .:,~ ~'~~\f:t,P~!;~: ?:"':';'!~"",':;::' ':'~:,'<i .~. . ~J.·::r;:·· !~-"'.c:',...n."...~.,."......."...,' - ."..."",:-.Þ....·..:..... .'., ",,-, ,'.' .,....'~,. 1':\ ....' ..,.. . :··t'\~ ..I~,r2~L_,.·,~;'::,i0~)I~.'rt~:i~'2~!~L;.~'~,~.. ':~~,..:.. . .... ,_:i~~ . ," -,..'.:, . '," . , . . I ,"'~~ .~........u.... a' ..... ,..........,1......' '. ...1." ,'" , '. ," ""67"'7;'" () I,r¡, . . .. ' ',; \',-: :.'.,', " ,-;':,' . ,> --:--:--," , .,,' .., .' I"~ . . . , .' ~' " ',' 'I' ' . , .. -: ." ".' " " ',t ',:: '. ." . .' '. . . , , " . :1,"&",""'··""" " , rJPlr . ' . ~ ' WIRE LINE SERVICES GEARHART-OWEN "'."fA";'· '........,,:.,.......,....' .'..~'......."..'...".".....'.... . '," . , , , " , ", I , ' , . , .~,."'_...:.,,.......,. , :~ ',..' '.~.., \,IQ,~"'''. J. ,"~ FilING NO. COMPANY CHEVRON U.S.A. , I ;--- . r-~ Cí.~ "/";" WE(L S. C aU. 341,-4 f. .~ ..I I,,, ) L:' ~ (','.'..;~. ' , .'" C;) ...-.f c.0 -\ FIELD 5WANSON RIVFR KF NAJ 'COUNTY 4:. LOCATION. L see; TWP. ROE. PERMANENT DATUM. LOG MEASURED fROM DRIUING MEASUIED FlOM (; R (] UN) I F V F I \.4.0 . ELEV. fT. ABOVE 'ERM. DATUM c;AMF . , Date Run No. Type log Depth· Dri Iler Depth-logger Bottom logged interval Top logged interval Type fluid in hole Max rec. temp., deg. F. Operating rig time Recorded by Wi tneued by ? HR. ROI 7 r.1R. FPPFRSON 7-?n-77 ONF 5PTNNFR 1 0 RS 0 10Sh5 10S&O 10100 GAS Run No. Bore-Hole Record From To Size WRt. 3-1/? ' )-7/ ~ ' )-3JR' Bit ",:~RM 110H '. . \/\ ---- - - - -. .... STATE AI AS KA OTHER SERVICES: !:LEV. I K.I. D.F. G.l. . Casing Record From o 100Rfi 10493 To lOORó 104q~ lOli70 .: .' ,':. \' " '::ï. .': I, ..:ç \~ '::,,~ , \ 'of( p ~ " C ~ .....~ . . .' . . ~\-~'- rn'",... "7" "'-;'1 IC·!:I~097) PRINTED IN U. S. A. ~ -" \:- '¡ , . ..' ". .. - . ~rsèìì ìùlùßRCE R'wÈìL'š ùÌlvÈrÌÑè'èò RPÒ ÌtÀTÌôÑ ~;.. . ~"""""""""" HOUnOl, TEXAS """""''''''''''''~~!:'\::' -'- SIMULTANEOUS" ~-;' ~.~1!~ rflunma I[a¡ -/(eutwz ~,~t:. COMPANySt'an dard 0 i J Other Survey~ Comt')arr'~' '~a J i forn i a ¡e.s-.ML-~L-~DM, Location·, of Well - " i: · ,t.fJ:f_.- GIU .4J::4 ~,~ , , l~l;1J~~f:¡ Idea t· LOCA 11L.\~"IiiI:m:m CO~~V.~ STATE 1\'1 ~..S ka :::<;,..", Log De'pths Measured From '-Ku·, -q- .l- J ø-F.O I~:~H . I . 08 8 Elevation: D.F.: . K.B.: '~. 0.: c;»r G.L.:~ 6, FILING,No. 14 Ft. above··,iil.···, ..' . " ,', RUN NO. Oat. " :. First .ReodinQ Last Readina _FootºQe Measured Ma~._º~pth Reached -cBottQJ" Driller . ~ilD..!lm Temp. of. JI uid" NaJu re Jlu.lli Level { Casln"~ize CasinaWeiaht {Casino Size Casing Weight Bit Size Bit Size . No. Counters Used Type Eauipment Tyrp Pnnllll Opr. Rig Time Truck No. Observer Witness 2~~!=f, 0 I 0,229 "' 00 10. . 24 ;, ll. ;:>.1 I . lO.231 . I~? v I B 2~ jb:¡ "s g to I nqq;>, ?~ m. , lb. ' to 9k in. '7-998 to I 099 b £ in. "ema r k~ I -2 .,', ~ N ,\.<,J"1 ¢ S. . ,,~p -Iv . , . '~ h rs ... 2.5h~ ' ',' MJI rDh. v. H oaq I a na-r'rn Iln ey " . J~'! 1 . .~ ~ ~ ~A I ~. r IJ I I in. } ..lb. in.} , lb. . in. in~ to to ·~u to 2 \JNi-\M-~ vN~-~ 2 tl r 5 ~' 2~62 .)now ti yer' '.' :..:~"".l~:'''"i.'''' '<";":'~'~~"" 1<-1",' ":"'1~'V"'-;"",'~ '~~''"'-,]c't h~'~~~<6'~ :-t ,:' ~~. ;.:'F. '\ ;", ..;;....''W ,:.:, . r-~r ". COMPANY -St a nda rd IÚl , O,th~r SUirveys . ~ ç,'ompanv of Cal ifornia 'I;;~-ML ... ¡ (01 . location of Well ~ ..! 'i SCU -.- 41-4 c:: ...; c WELL ~'- )...)/~ P2 ' ~ 0 1; ~ ~ct- c... c' L...- '1. .)~ 1'0- FIELD ~~ i Ide at ~ I "Ora: 'õ -- C} .- "t ro. LOCATION 4-8N.-9vi c: .. +-- c.,.. .. .., :) 1')0 ¿ .) z,., >- ?::: ~O z 8~g~ ~ COUNTY Kenai ~ rac', net Elevation: K.B.: 180 a. ~ , : D.F.: 0 v¡¡:.....~ u STATE i-iJaska or G.L.: Ihþ l~g De~ths Measured From K,(;1, .BUN No. . ()Q t.Y .. ~ ~s'f. Rcuçfing ~,.';'~' II. ..·,I"':T R, "', , "',d.. . ;L'" : . ep!!!!9 " " ," 'M~9sured . ,) '~. S('hJ~_m. ,,~ ~ ~~ Q~'Jle~ . ~~r j)J!f.!.h~.~ached ';~i iet-om. priller 'ij \'1JtII,.l No t . ''''~~1' " Dens. ¡ Vise. Mud' R~·~ist. - ì¡-R'e~: BHT . -,"~.~~.·-~H· ...;.; . rr-'Wtr. Loss --'''-Rm'f ~¡t sizë =$p-an::', --_.- S'pr. Rig-rime Truck No. lecorded By : ~ Witness .. ,I -::::: . ~ '. .. . ';~'~~\~"~.."';'~T(~'~(;.""~"~ I.~...· 1',' 14:' Ft. above bL. " .' .,¡, -, I - - 2- '-2-6U l-t~-6n .1. OU.1 . I~. I u~ 2 . 9~g . "c~ y,g? . -22 / . ~~..~~ .1. 008 "fn. II'd 3, uno / >'1 Ü:~llq\ (J e I j,. ,/ \~ f·il'''''''.,\ 83 I 7 U I;"';":<';~)R \l'i,::.·.~~ ~: i : ~~ ':~' ::f'~~?:~ :: J 41 :~ @ 0 F 9 . 5 @' 7? 0 F ~ . CC 30 min 6 . , CC 30 rTlin 7 . 1m ,@ 6q OF 2. 8m @ 68 Of . '--·.-(::~l @ ___ ' I'e mâ r k ~ l J) - 9'¡' . . i.!.. r" 1ft". .1 ft. .1 ft _ i§mt-:" h l j To] . () 0.1 .3. u O.1f 0.. I o. 1 I 0 9 (3 00 To i U9 9 :;) : -.-J, ~ ~;: fu ~. \~ ' r :~ J h r s . 3 h r 5 . 2 h r 5 . ~ ~"'OR;I'.:~/"I:'~ '- ,..., 2 ~ 62 ? ~'1()? __ ? ~16? - Tru:'~1 \; ''i ~ J I 8 r ¡~ i I ll~ r 6"¡! I I e r _ Rec r:": Ullh~rt Vj JhBrt V1lhert Wíïr,,;!' ~ -~~ ,- - ;,'~ 1', J,' "~ f' ":~~' I -3- ?-~ U-6() lu,9YS. J t).. I U~ - 89'U - "._"'.I".\,~~~~~,,~~,~ .,I··~\.."II" \; ':"~¡"'.' ~_"U~,!\",,,,'~IÞ~'-~":,"" i~~'I',,,,,~~.~,, ~..~~'~;'" ~.f-~~J·..i./.wt,¡,~t:~.. __ ~,..A~r-.~-,~' -3- 2-1!i-&l), I O. b~::> IO.,I.1q . 425 I O··f)~1 . 0, bb U~I I 00 J, 5~ i:2 :, ~f" :~, q ~..Q @ '7?:' ðF '5'.2. CC 30 mi."· . 2:1 @ 6 8m: olF ~ _.6. @ EiOm' o'F 1_6' i I O. ~. 00 : qý , r' .v¡:i -~ ; H ? hrs ?t)h~ i _ .111 j , fa r: .~ 'b','~ ~er~;'.-""~.~lJ ¡L' I, , ~ , " Elevation: D.F.: I .' . K.B.:' 180 ,or ,G.L!' t r;;(.. . i ; COMPANY .$t~·ndarQ o¡ I " , , 3" ·~ompanv..of ~a I ifornia . : ¡rQ ,=~, WELL $~.U 4,1-4 ¡<,Icl. ~¡~~ .; ·~L.o' :'Llt ,,' .'. Q"" , -......- . .it,;, . .... '.' . "\, :......,...., I\!~' '(,+0-"" ' ~ i- 'ì/~'iU.;rtf'- ' rn 4 ~../ .--1·:,:~: :-016: fiELD W i Ide rt t .~ "'~'"'' .. "",... I c:'J ' ' iii"" .." ':'~~ ' : ¡ , \' ~l . ~.. .~>,.'~ . i ro I,' (, '0"" ~··TI.O"'I 4"'1N -a ~~ .'..'.'1' ,.'",...1,.......,.',.'... "l,..... .,.,' .. ~, .' I') ......,.... , I.: \"JI\..., I:" -;¡ , ,..,,,\ .. "." .i ~~' ";'~~\~ ~I) ¡o ' ,~.: "oIf'!. .' . , " ,:, ."~ .! ~.. ;' I¡)~\~I: "':.~ " < Z ! ,:> 'f' ..: .,. . ~'. i '" ., '~'~". . .~. "'". ' '.' .. ," I P i 't ~If::··): .... ...', - :' '~'. :'~~~!~, ~A'~.~ ""i. 'I r~:y n~, ,1.~,Æ .,.,~ .'. .. '!,~ ;·,:,>·",·~:,:,'i.,<,:;}l,i.,:". .~ '. I'·'i";'" :.' ....,'.; , .' ,; :":"'.;.: . ..~~.' ~;~. .,'. . .... .... . ,~" .' ." , ': . ,i,,;,:" '. ' t Measured from' ¡~ ;, 4 Ft. above ûL ,"; ~~:::c;;;,: li:.-· ;:,:':¡t:· ~}. . :~" , . ~\ ~.'.:,".'....' ,:~., é .' ~~ ~1Y'. ,.'1. c:. '.. . , 2 ~ 11/,::' ,·,'WJII'rtO. :. .: -1-' .~ - ~.~.~,..,!..\..,;.'.¡~.;. ..' " -I·~;rj·~,_~:' , . !'~ ,,1-, ~-6¡O f '?~.:I, ?-68 .. kif./.i,'''''.[,\,: ',:' . ;;reåêftna. .: . '. ]'OOk.' . ", O~'I 0. :~ 1¥j,' .' '!... ~ Jt. ,.. 'ttf. t. .' , ~.J ·.,r.".'.':..,: i<"f ". '.ÍtoaII". ng":.. h Q ¡' .'¡ ~ ()/)I:. , ..,:.....'.'.,.".,.', I .."-'. ..,' '.''''. ". " ~.' ."~ ,I ,~ Ii c, ;' 4ft_lUred '2.' 5· : I ·.,i.;:,~o.',..:f .:'. . ·~..iiachtd' ,3 :'o~7 '1 1:-1 n 1~,~î' ,',i) " . ~ T rlUer'.. ;i ,000 '\ I 0. J I 0 í~r; . JoIOI. . bfil t . . . ue I ...,~;.~.:,..(.'.:.(' .:,;., ... .' ~ '¡¡.·..-.e~, Is~.iSC. ..~a.3 4 @. ..~~ of. .l :81·@.'. ' ~~.¡. Øf, .J., "-'t.. ~..'. .,. 0 - :~i' .~ 1I.""es.8HT .1 q!>' 89 . of: I.? @ 141 F; '.il: ~': ij' ..~.. 'H. ,@ ,. of 'q f.;;. '@7 ? of : ,\ L·~ . t" , "\ ,.. . ~ . ,_. ~¡:L . . t,", I'. loss 5 . CC 30 min " t, . (! CC 30 min· !¡{. ~ft.Jm\ @ hq; of; ~ .8@ ';Rm' of' ".J:~" . H.q~ @' 69' OF. 1.I,5@.14f,CoF, "1/ .~ud~\oQ~ _m . ~, ' I~. ~ " . ',~:: I·':,· ." .,Dept. ,q .UPp :¡!:." ~lt:H~.· - ~,., "'. '-\.)) .' .. \1,) ~: : $ondì Type PM:'-~ - t'.v'~-t\ ~' . ad ~ '" ; '" .. . 'tt ".~/ ~tr....: . ·~~~2S. '1~2~s. i,¿\ '(~Iy .-~-~II'ar.' ',' Mj liar . ,<,~~, ~', .. ' b ¡ bert" .\1, bart ~,.......... 10' ~, \""~' .>"1,: '., " ;." ' t; tJ""','i'l9' .. 'I' , ~¡;.. . ~' ,.,.:·::1::'1:, (,:,f,o!.' . . ~~' , ' :4:~l4" ~:'I. ,. tJJ~~ I 'I) . ' ;,r,:¡~J f;,. 4' 8 . ~{" ~ '¡ '~,f~;' ~~~;ll J; ~: I It:) - ::>L Location of Well . i 1 ! I ? .~ ., i .'1 , ! .,