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161-020
_~hu~=,_%~ = LOCg. TION CLE~-Rg~CE R~PORT State of ..!&..~= . ~~ o~-.~ ~ ¢~-~s~xvx~z~ ¢~mss:~ 2er_~ i~-ca_--rais - =~p.s: Review ~he well file, an~-cement cum plu%mj~.ng, well hea~ Well head cnn .Har~'cer pos= or place: · Si~ne~ STATE OF ALASKA t-. ALASKA AND GAS CONSERVATION boMMISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: SUSPENDED: ABANDONED: X SERVICE: 2. Name of Operator 7. Permit Number Union Oil Company Of Califonia (UNOCAL) 61-20/95-120 3. Address 8. APl Number P.O. Box 196247, Anchorage, AK 99519 50-133-10125-00 4. Location of well at surface 530 'FNL, 1890' FWL,Sec 9,T7N, R9W,SM At Top Producing Interval Same as above At Total Depth Same as above 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 124' GL I A-028996 12. Date Spudded I 13. Date T.D. Reached I 14. Date_Como., Susp. or Aband. , I7/19/1961 I ~Jl/~/~'~(~ndon ed) I 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Su~ey 10,745' MD~VD 19,415' MD/~D (EZSV) J Yes: No: 22. Type Electric or Other Logs Run GR/CCL (Set EZSV to abandon) 9. Unit or Lease Name Soldatna Creek Unit 10. Well Number SCU 321-9 11. Field and Pool Swanson River Hemlock Tyonek 15. Water Depth, if offshore I 16. No. of Completions feet MSLI Abandoned 20. Depth where SSSV set I 21. Thickness of Permafrost N/A feet MDI N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" Drive Pipe 0 37' Driven 0 11-3/4" 47 J-55 0 2010' 16" Yes 0 7" 20/23/26/29 N-80 0 10,272' 8-1/2" 550/1275 sx 0 5-1/2" liner I20 N-80 9,713' 10,743' 6" 100 sx 0 I 25. TUBING RECORD 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) None SIZE DEPTH SET (MD) PACKER SET (MD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9415' MD (EZSV) 130 Sx Class G at 15.8 ppg (Squeezed below EZSV) 27. Date First Production 7/22/1961 Date of Test 7/21/1961 Hours Tested 24 PRODUCTION TEST I Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR TEST PERIOD => OIL-BBL 784 GAS-MCF 175 WATER-BBL 8 CHOKE SIZE I GAS-OIL RATIO 11/64" J 223 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 1670 0 24-HOUR RATE--> 784 175 8 36 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No cores taken. RECEIVED OCT 1119 ORIGINAL Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. i 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 directional survey, completion drawing, summary history 32. I hereby certify that the fore~joing is true and correct to the best of my knowledge Signed ~J~.~. ,A,~ ~~'/)'J~ Title J~il~l~J/ /[~l~J/'l~ Date /~;~'"'~ ~-~? INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Description of Activities Swanson River SCU 321-9 Abandonment Operations commenced on SCU 321-9 on 29 July 1999. The well was killed with lease water and the rig was rigged up. After screwing into the landing joint the tubing was pulled free from a cut previously made at 9616'. The 2-7/8" tubing was pulled from the well and laid down. Schlumberger wireline was rigged up and a 7" EZSV was run in the hole and set at 9415'. Afterwards a cementing stinger made up to 3-1/2" drillpipe was picked up and mn in the hole. A 25 bbl slurry of 15.8 ppg cement was mixed up, and after stabbing the stinger into the EZSV, the slurry was squeezed below the packer abandoning the "G" and Hemlock below. (See attached Schematic) The drillpipe was pulled from the well and preparations were underway to perform the sidetrack of the well on 1 August 1999. UNOCAL RKB = 18.5' "Abandonment Plug" 130 sx "G" at 15.8 ppg squeezed below EZSV at 9415' 3 5 "Fish" Rotary shoe over tbg stub ~ 10322' "Fish" 22' wireline tool string @ 10540' 10 11 12 G1 ~G2 H1 H3 H4&5 H8&9 Swanson River Well SCU 321-9 Abandonment Detail CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 11-3/4" 47 J-55 11.000 Surface 7" 29 N-80 BT 6.184 Surface 7" 26 N-80 BT 6.276 281' 7" 23 N-80 BT 6.366 1,090' 7" 26 N-80 BT 6.276 4,783' 7" 29 N-80 BT 6.184 6,591' 7" 29 P-110 BT 6.184 8,466' 5-1/2" 20 N-80 BT 4.778 9,713' 27' 2,010' 281' 1,090' 4,783' 6,591' 8,466' 10,272' 10,587' JEWELRY DETAIL NO. Depth ID OD Item 1 9,415' 5.950 2 9,616' 5.983 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 10.282' 10.287' 10.299' 10.316' 10.364' 10.374' 10.378' 10.409' 10,442' 10,453' 10,456' 10,492' 10,540' 10,584' 10,587' 10,592' 2.416 4.50 3.50 3.100 4.50 - - 2.688 2.992 1.870 2.437 - 7" EZSV Baker Model "FH" Packer 2-7/8" x 7" with tubing tail below and 2-7/8" tubing stub above. Baker SC-2P Ret Pkr, with packer plug Baker millout Ext w 2-3/8" crossover "X" nipple High pressure tubing paekoff, swallowed 4.26' tbg stub 2-3/8" GLM, KBMG with EK valve Brown CC safety jt Baker FH retr packer Otis S nipple, position 2 2-3/8" GLM, KBMG with EK valve Brown CC safety jt Baker FH packer Otis S nipple, position 1 2-3/8" GLM, KBMG with EK valve Camco D nipple Baker Model D perm packer set on E-line Shear sub with 1" hole in center, wireline fish PERFORATION HISTORY (DIL) Interval Accum. Zone Top Btm Amt spf Comments G1 10,159' 10,172' 13' 6 Abandoned G2 10,197' 10,229' 32' 4 Abandoned G2 10,204' 10,27Y 69' 12 Abandoned H-1 10,294' 10,304' 10' 4 Abandoned H3 10,324' 10,352' 28' 4 Abandoned H5 10,364' 10,375' 11' 4 Abandoned H4&5 10,388' 10,450' 62' 4 Abandoned H8&9 10,474' 10,582' 108' 4 Abandoned H10 10,598' 10,659' 61' 4 Abandoned H10 PBTTD = 9,415', TD = 10,745' MAX HOLE ANGLE = vertical 321-9 Well Schematic (Modified Abandonment).docDrawn by: NM 10/07/99 PERFORATION DATA SHEET AFTER ABANDONMENT SCU 321-9 9/1/1999 Zone Measured Depth (Feet) Status G-1 10159-10172 Abandoned G-2 10197-10229 Ab an doned G-2 10204-10273 Abandoned HB- 1 10294-10304 Ab an don ed HB-3 10324-1-352 Abandoned HB-4/5 10388-10450 Abandoned HB-5 10364-10375 Abandoned HB-8/9 10474-10582 Ab andoned HB-10 10598-10659 Abandoned STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: X Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Rep~i'~ well: Plugging: Time extension: Stimulate: Change approved program: Pull tt~bing: variance: Perfor~'te: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of Califonia (UNOCAL) Development: X RKB = 142' GL = 124' feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Soldatna Creek Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: 4. Location of well at surface 8. Well number 530' FNL, 1890' FWL, Sec 9, T7N, R9W, SM SCU 321-9 At top of productive interval 9. Permit number Same as above 61-20/95-120 At effective depth 10. APl number Same as above 50-133-10125-00 At total depth 11. Field/Pool Same as above Swanson River/Tyonek/Hemlock 12. Present well condition summary Total depth: measured 10,745' feet Plugs (measured) true vertical 10,745' feet Effective depth: measured 10,700' feet Junk (measured) true vertical 10,700' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 37' 20" Yes 37' 37' Surface 2,010' 11-3/4" 1275sx 2,010' 2,010' Intermediate 10,272' 7" 550/1250 sx 10,272' 10,272' Production 1,032' 5-1/2" 100ax 9713-10743' 9713-10743' Liner Perforation depth: measured (See attachment) RECEiVeD true vertical O~: ~-~ ~:::~/c~.~. Tubing (size, grade, and measured depth) 2-7/8" 6.4#, L-80 at 9742' 2-3/8" 4.6#, L-80 at 10282-t0587' Packers and SSSV (type and measured depth) Baker Model FH @ 9,638', Baker Model SC-2 @ 10,282' Anchorage Baker Model FH @ 10,378' and 10,456' and Baker Model D @ 10,587' 13. Attachments Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 7/5/1999 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I hereby certify that the foregoirkg is true and correct to the best of my knowledge. Signed: Title: Drilling Manager Date: FOR COMMISSION USE ONLY Conditions of Plugappr°val:integrity.N°tify. ~C°mmissi°nBopS° representatiVeTest ¢ may witneSSLocation clearance IApproval No. Mechanical Integrity Test Subsequent form required 10- ORIGINAL SIGNED-BY Robert i,~ Christen$Of~ Approved by order of the Commissioner Commissioner Date , Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager May 21, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Johnston: Attn: Re: David Johnston Application for Abandonment Swanson River Field Soldatna Creek Unit #321-9 Enclosed is the Sundry Notice (Form 403) relating to the abandonment of Swanson River Unit Well #321-9. This well is currently producing from the Tyonek G zone at 50 BOPD, 70 BWPD. A Baker "F" Packer plug was placed in the well during the last workover in June 1995 to suspend production from the Hemlock intervals below. Subsequent to placing the packer plug, the Tyonek G-1 and G-2 sand intervals were perforated with 1034 each, 2-1/8" enerjet charges. It has been our experience that approximately 70% of these disks are left in the hole after firing the guns. A slickline tag on 3 March 1999 confirmed that approximately 58' of perf debris and disks are on top of this packer plug making recovery of the plug very difficult. In addition to the debris left on top of the packer plug a 22' wireline fish was left in the hole at 10540' preventing access to the Hemlock Bench 8 and 9. Attempts to recover this fish in the past have failed. It is proposed to set a squeeze retainer at 9650', above the open G-1 and G-2 perforations. The zones would be abandoned by down squeezing enough cement to fill the wellbore and perforations below. The Hemlock intervals are commingled throughout the field and abandonment of individual zones is not required from a reservoir management standpoint. The placement of this squeeze packer will facilitate subsequent sidetrack operations for this well. The well is slated to become a Hemlock Bench 1-5 commingled producer via a long reach horizontal sidetrack. The expected start date for this well is July 7, 1999 so your timely consideration for approval is appreciated. If there are any questions, please contact Dan Williamson at 263-7677 or Nell Magee at 263-7671. /~cerely,/}. f)~/1/~, ~"~) ~C ~iV Drilling Manager A~aslm Oil & Gas Cons. Comm~ssm~' Anchorage Perforation Intervals SCU 321-9 Perforation Interval MD/TVD 10159-10172' 10197-10229' 10204-10273' 10294-10304' 10324-10352' 10364-10375' 10388-10450' 10474-10582' 10598-10659' Length 13' 32' 69' 10' 28' 11' 62' 108' 61' Zone G-1 G-2 G-2 H-1 H-3 H-5 H-4/5 H-8/9 H-10 General Abandonment Procedure SCU 321-9 1) Move in Inlet Drilling Rig #CC-1. 2) NU and Test BOPE to 5000/250 psi. 3) Circulate well to 8.6 ppg lease water and ensure well is dead. 4) Unseat packer at 9638' and recover completion tubing. 5) RU e-line and set 7" EZSV squeeze retainer at approximately 9,650'. 6) 7) RIH pick up drill pipe and sting into EZSV. Establish injection rate. Mix and pump sufficient cement to squbeze the open Tyonek G perforations and fill the annular volume below the EZSV to an ETD of 10,222'. 8) Sting out of retainer and pressure test retainer and production casing to 3000 psi. 9) POOH and prepare for sidetrack operations. UNOCAL ) Stage Collar @ 7480' Fill Tagged ~ 10,222' WLM 4/3/99 "Fish" Rotary shoe over tbg stub ~ 10322' "Fish" 22' wireline tools @ 10540' 10 15 16 22 G1 G2 H1 H3 H4&5 H8&9 H10 SIZE WT Swanson River Well SCU 321-9 Actual Completion 6/16/95 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 20" - 27' 11-3/4" 47 J-55 11.000 Surface 2,010' 7" 29 N-80 BT 6.184 Surface 281' 7" 26 N-80 BT 6.276 281' 1,090' 7" 23 N-80 BT 6.366 1,090' 4,783' 7" 26 N-80 BT 6.276 4,783' 6,591' 7" 29 N-80 BT 6.184 6,591' 8,466' 7" 29 P-110 BT 6.184 8,466' 10,272' 5-1/2" 20 N-80 BT 4.778 9,713' 10,743' Tubing 2-7/8" 6.4 L-80 Butt 2.441 surf 9,742' 2-3/8" 4.6 N-80 Butt 1.995 10,282' 10,587' JEWELRY DETAIL NO___:. Depth ID O___~D Item 1 15' - - 2 See Item 2.347 5.500 3 9,638' 2.416 5.983 4 9,707' 2.313 3.500 5 9,740' 2.441 3.700 6 10,280' 2.65 0 7 10,282' 4.50 2.688 8 10,287' 3.50 2.992 9 10,299' 3.100 1.870 10 10,316' 4.50 2.437 11 10,364' 12 10,374' 13 10,378' 14 10,409' 15 10,442' 16 10,453' 17 10,456' 18 10,492' 19 10,540' 20 10,584' 21 10,587' Tubing Hanger, 2-7/8", P/N: 421738, Type H BPVP GLM, Camco, MMG, 2-7/8" x 1-1/2", 05321-000-2400 Eleven GLMs at 2265',3669', 4611', 5298', 5922', 6511', 7098', 7719', 8312', 8904', 9523' Packer, Retrievable, Baker Mod. "FH" 2-7/8"x7", 50k pull or rotate to release Nipple, 'X', 2.313 I.D. WLEG (down in 5-1/2" liner) Baker "F" Latching Packer Plug w/Eqsub 2.5 sx caCO3 on top (4') Baker SC-2P Ret Pkr, pull w/retrieving tool to release Baker millout Ext w 2-3/8" crossover "X" nipple High pressure tubing packoff, swallowed 4.26' oftbg st~ No slips, pushed rotary shoe down tubing stub 2-3/8" GLM, KBMG with EK valve Brown CC safety jt Baker FH retr packer Otis S nipple, position 2 2-3/8" GLM, KBMG with EK valve Brown CC safety jt Baker FH retr packer Otis S nipple, position 1 2~3/8" GLM, KBMG with EK valve Camco D nipple Baker Model D perm packer set on E-line PERFORATION HISTORY (DIL) Interval Accum. Date Zone Top Btm Amt spf Comments 12/21/95 G1 10,159' 10,172' 13' 6 2-1/8", EJ,0 deg. 10/4/96 G2 10,197' 10,229' 32' 4 2-1/8", EJ, 0 deg. 6/20/95 G2 10,204' 10,273' 69' 12 2-1/8", EJ, 90 deg. H-1 10,294' 10,304' 10' 4 Isolated By F plug in pkr H5 10,324' 10,352' 28' 4 Isolated By F plug in pkr H3 10,364' 10,375' 11' 4 Isolated By F plug in pkr H4&5 10,388' 10,450' 62' 4 Isolated By F plug in pkr H8&9 10,474' 10,582' 108' 4 Isolated By F plug in pkr H10 10,598' 10,659' 61' 4 Isolated By F plug in pkr Last Workover 6/16/95 PBTTD = 10,700', TD = 10,745' MAX HOLE ANGLE = vertical 321-9 Well Schematic Drawn by: NM 05/20/99 ~[4rN J,..l I!!lil~l~ UNOCAL$ Volume below packer squeeze cemented. ,Gl G2 H1 SIZE WT Swanson River Well SCU 321-9 Proposed Abandonment CASING AND TUBING DETAIL GRADE CONN ID 11-3/4" 47 J-55 7" 29 N-80 lIT 7" 26 N-80 BT 7" 23 N-80 lIT 7" 26 N-80 BT 7" 29 N-80 BT 7" 29 P-1 l0 BT 5-1/2" 20 N-80 BT JEWELRY DETAIL NO. Depth ID OD Item 9650' 10,282' 10,287' 10,299' 10,316' 10 364' 10 374' 10 378' 10 409' 10 442' 10 453' 10 456' 10 492' 10 540' 10 584' 10 587' 10 592' 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 TOP BTM. 27' 11.000 Surface 2,010' 6.184 Surface 281' 6.276 281' 1,090' 6.366 1,090' 4,783' 6.276 4,783' 6,591' 6.184 6,591' 8,466' 6.184 8,466' 10,272' 4.778 9,713' 10,587' 5.95 4.50 2.688 3.50 2.992 3.100 1.870 4.50 2.437 7" EZSV Baker SC-2P Ret Pkr, with packer plug Baker millout Ext w 2-3/8" crossover "X" nipple High pressure tubing packoff, swallowed 4.26' tbg stub 2-3/8" GLM, KBMG with EK valve Brown CC safety jt Baker FH retr packer Otis S nipple, position 2 2-3/8" GLM, KBMG with EK valve Brown CC safety jt Baker FH packer Otis S nipple, position 1 2-3/8" GLM, KBMG with EK valve Camco D nipple Baker Model D perm packer set on E-line Shear sub with 1" hole in center, wireline fish "Fish" Rotary shoe over tbg stub @ 10322' "Fish" 22' wireline tool string @ 10540' 9 10 11 H3 H4&5 H8&9 PERFORATION HISTORY (DIL) Interval /-~ccunl. Date Zone Top Bim Ami spf Comments 12/21/95 G1 10,159' 10,172' 13' 6 2-1/8", F_J,0 deg. 10/4/96 G2 10,197' 10,229' 32' 4 2-1/8", El, 0 deg. 6/20/95 G2 10,204' 10,273' 69' 12 2-1/8", El, 90 deg. H-1 10,294' 10,304' 10' 4 Isolated By F plug in pkr H5 10,324' 10,352' 28' 4 Isolated By F plug in pkr H3 10,364' 10,375' 11' 4 Isolated By F plug in pkr H4&5 10,388' 10,450' 62' 4 Isolated By F plug in pkr H8&9 10,474' 10,582' 108' 4 Isolated By F plug in pkr H10 10,598' 10,659' 61' 4 Isolated By F plug in pkr H10 Last Workover 6/16/95 PBTTD = 10,700', TD = 10,745' MAX HOLE ANGLE = vertical 321-9 Well Schematic (Abandoment) Drawn by: NM 05/20/99 Inlet Drilling Rig #CC-1 7-1/16" 5000 psi BOP Stack 7-1/16" Annular Preventer 3-1/8" Kill Line 1 = HCR Valve 2 = Gate Valve 5k psi Blind Rams 5k psi Pipe Rams Drilling Spool 5k psi Pipe Rams 7-1/16"" 5M ~ Tubinglhead[--~ ''' Casing 4-1/16" Choke Line Blowout Prevention Equipment Inlet Drilling Rig #CC-1 7-1/16" BOP Equipment ea 7-1/16" x 5000 psi wp single ram type preventer ea 7-1/16" x 5000 psi wp double ram type preventer ea 7-1/16" x 5000 psi wp annular preventer ea 7-1/16" x 5000 psi wp drilling spool with 2 ea 4" side outlets (choke and kill), HCR and manual valves on choke line and two manual valves on kill line. ea Koomey BOP control unit with 120 gallon volume tank, w/twelve 10-gallon accumulator bottles and nitrogen back-upsystem. ea 5 station, remote control panel ea 5,000 psi choke manifold with Cameron automatic hydraulic choke 3" - 10,000 psi with control choke panel. lot Hydraulic pipe and fittings from manifold to BOP stack. 17o~ ~'~ ~'?~ + f I iI WAR~HOUSE ~ I ~-~'~/7~ %_/ -<)~}~--:-f d / ~ .~ ~:':, i .::: ............ ......: KE~ ~NINS~ ~ R~R FIELD , , ,., . OIL SPILL ...... '. ' ........ '~"'~' , ..... "";~'~"" RESPONSE P~N MAP / ~ I I . ~ Anchora~:, STATE OF ALASKA ALASKA O;-AND GAS CONSERVATION (.;OMMISSION 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) Union Oil Company of California (Unocal) Development: x RKB 142' FL=125' 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 530' FNL, 1890' FWL, Sec. 9, T7N, R9W, SM SCU 321-9 At top of productive interval 9. Permit number/approval number 61-20 Same as above 0 R I Gl NAL lO. APInumber At effective depth Same as above 50- t 33-t0125-00 At total depth t 1. Field/Pool Same as above Swanson River/Tyonek-Hemlock 12. Present well condition summary Total depth: measured 10745 feet Plugs (measured) 10700 true vertical 10745 feet Effective depth: measured 10700 feet Junk (measured) true vertical 10700 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 37' 20" Yes 37' 37' Surface 2010' 11-3/4" 1275 sx 2010' 2010' Intermediate 10272' 7" 550 sx 1 st stage 10272' 10272' 1250 sx 2nd stage Production 1032' 5-1/2" 100 sx 9713'-10245' Liner Perforation depth: measured 10197'-10273'; 10294'-10304'; 10324'-10352'; 10364'-10375'; 10388'-10450'; 10474'-10582'; 10598'-10659' true vertical Same as above Tubing (size, grade, and measured depth) 2-7~8" 6.4~ L-80 @9740 2-3/8" 4.6~ L-80 10202'-10324' 2-3/8" 4.7# N-80 10,324'-10,591' Packers and SSSV (type and measured depth) Baker FH 9637'; Baker SC-2P @ 10282'; Baker FH 10,383'RECEIVED Baker FH 10462'; Baker D Perm 10587' 13. Stimulation or cement squeeze summary '7r° Intervals treated (measured) "G" zone was reperforated on 10/4/96. See attachment for details. Treatment description including volumes used and final pressure N/A Alaska 0il & Gas Cons. commission Anchor~.ge 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well'operation 9/15/96 187 74 84 820 300 Subsequent to operation 10/7/96 120 102 111 1100 150 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: x Oil: x Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: Dale Haines Title: Drilling Manager Date: Dec. 09, 1996 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 10253.( !02¥57 FIi 9/50/96 'c!g W/2.25' i:'ulrp Bc'b:r '0i9'.0 '(}2290' ::'~Ff;C i020,'i0 '02.;50' ?SFS (3 2 6;'20/95, ibP? 69 2 '/'8' reiei O~s 90 P~' }02/99 0282a >~',]OSeke~ FLo%.2~ :>k. Ph.{ W/q{oCO3o~op 102950 01'935' CROS',OV ? Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL ) February 9, 1996 Alaska Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Commissioner: OhlGINAL Re: Soldotna Creek Unit - Well SCU 321-9 APl Number 50-133-10129-02 On December 21, 1995, the following interval was perforated in Well SCU 321-9: BENCH TOP (MD) BOTTOM (MD) FEET G-1 10,159 10,172 13 TOTAL 13 Attachment Very truly yours,/ / Candace Williams STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing After casing Repair well 2. Name of Operator 5. Type of Well: Development x UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Exploratory 3. Address Stratigraphic P.O. BOX 196247 ANCHORAGE, AK 99519 - 6247 Service X Return to Prod. Plug~ ~ Perforate Pull tubin9 Other 6. Datum elevation (DF or KB) Location of well at surface 530' FNL, 1890' FWL Sec. 9, T7N, R9W, SM At top of productive interval Same as above At effective depth Straight Hole At total depth Same as above ORIGINAL RKB 142' GL=125' feet 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 321-9 109.~n'~number 5-120 umber 50-133-10125-00 11. Field/Pool Swanson River/T¥onek/Hemlock 12. Present well condition summary Total depth: measured true vertical 10,745 feet Plugs (measured) 10,745 feet Effective depth: measured true vertical 10,700 feet Junk (measured) 10,700 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 37 20" Yes 37' 37' Surface 2010' 11-3/4" 1275 sx 2010' 2010' Intermediate Production 10,272' 7" 550 sx 1st stage 10,272' 10272' 1250 sx 2nd stage 1,032 5-1/2" 100 sx 9713'-10245' Liner Perforation depth: measured true vertical 10159'-10172';10204'-10273';10294'-10304';10324'-10352';10364'-10375' 10388'-10450';10474'-10582";10598'-10659' Straight Hole Tubing (size, grade, and measured depth) 2-7/8", 6.4#, L-80 to 9740' MD 2-318" 4.6# L-80 10,202'-10,324' 2-3~8" 4.7# N-80 10,324'-10,591' Packers and SSSV (type and measured depth) Baker FH 9637'; Baker SC-2P ~) 10282'; Baker FH 10,383' Baker FH 10,462'; Baker D Perm 101587' ,,^n F1 R lq 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Data Alaska 0il & Gas Cons, Anchorage Tubing Pressure Prior to well operation 12/16/95 532 262 5 1375 380 Subsequent to operation 1/14/96 176 135 358 1425 215 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run *See Below Daily Report of Well Operations Oil X Gas Suspended Service 17. I hereby certify that the fd~i~l is t~~e best of my knowledge. Signed G. Russell Schmidt ~ Title Drilling Manager Date 2/9/96 Form 10-404 Rev06/15/88 '~ ~ ' SUBMIT IN DUPLICATE ;ommission Unocal Energy Resourr 'ivi~'~' 909 West 9th, P.O. BO; J24. Anchorage, AK 99519-6247 Telephone (909) 276-7600 Fax (907) 263-7828 UNOCAL( Debra Childers Clerk DATA TRANSMITTAL 96-4 February 13, 1996 To: Larry Grant 3001 Porcupine Anchorage. AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items. SRU 32A-33 ,.//BLUELINE / SEPIA 12/5/95 PERFORATING RECORD SMGS #3 BLACKLINE / SEPIA 12/28/95 COMPLETION RECORD .SMGS #3 ~,49LUELINE / FILM 1/9/96 COMPLETION RECORD GP 42-23 RD o,/BLUELINE / SEPIA 12/27/95 BRIDGE PLUG SETTING RECORD GP 42-23 RD BLUELINE / SEPIA 12/29/95 MUDLOG - FORMATION , , SCU 43-4 ,/BLUELINE/SEPIA 12/21/95 PERFORATING RECORD scU 343-33 ~4BLUELINE / SEPIA 12/5/95 COMPLETION RECORD SCU 321-9 ~/BLUELINE / SEPIA 12/21/95 PERFORATING RECORD I I 1996 Please acknowledge receipt by signing and returning one copy of this transmittal or~_.~_._~~~ I Received by: /Date: Nldlorage I '-'""- STATE OF ALASKA AI~ A OIL AND GAS CONSERVATION COMi, SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Pull tubing x _ Alter casing 2. Name of Operator Union Oil Company of California (Unocal) 3. Address P.O. Box 196247 Anchorage, AK 99519 , Location of well at surface 530' FNL, 1890' FWL Sec. 9, T7N, R9W, SM At top of productive interval Same as above At effective depth Same as above At total depth Same as above Stimulate __ Plugging ._ _ Repair well 5. Type of Well: Development X Exploratory __ Stratigraphic__ Service _ _ 12. Present well condition summary Total depth: measured true vertical 10,745 feet Plugs (measured) 10,745' feet Perforate X Pull tubing _ _ OtherX_ Effective depth: measured 10,700' feet Junk (measured) true vertical 10,700 feet 10,700 6. Datum elevation (DF or KB) RKB 142' GL = 125' 7. Unit or Property name I?'"~3pldotna Creek Unit (8:.~e'~l number 9. P errr~it~ d~gr/approval 10. APInumber ~' /' 50-133-10125'~'00 number 11 .~jetd/Poet, ~ ~ lC, r'~ ~v~~l/eeq'~ll~/He mlock S EP 12 1995 Al~ l~il & Gas Cons. C0mniissl.0.n Casing Length Size Cemented Measured depth Structural Conductor 37' 20" Yes 37' Surface 2010' 11-3/4" 1275 sx 2010' 10,272' feet Intermediate 10,272' 7" 550 sx 1 st stage 1250 sx 2nd stage Production 1,032' 5-1/2" 100 sx True vertical depth 37' 2010' 1 O272' 9713'- 10245' Liner Perforation depth: measured 10204'-10273'; 10294'-10304'; 10324'-10352'; 10364'-10375'; 10388'-10450' 10474' - 10582'; 10598'- 10659' true vertical Same as above Tubing (size, grade, and measured depth) 2-7/8" 6.4# L-80 @ 9740' 2-3/8" 4.6# L-80 10,202'-10,324' 2-3/8" 4.7# N-80 10,324'-10,591' Packers and SSSV (type and measured depth) Baker FH 9637'; Baker SC-2P @ 10282'; Baker FH 10,383' Baker FH 10,462'; Baker D Perm 10,587' 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A 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 Prior to well operation (GAS INJECTOR) 26,592 1000 Tubing Pressure 5200 Subsequent to operation (OIL PRODUCER) 668 2400 700 1300 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations x _ 17. I hereby certify that the fo~Jg~ng is~'~ ~n~to the best of my knowledge. !1 !/ %1 Ii I--'I-T ' ~ Signed G. Russell Schmidt,f~J~~./'~itle Drilling Manager Form 10-404 Rev 06/15/88 16. Status of well classification as: Oil x_ Gas _ _ Suspended _ _ Service Date 9/06/95 SUBMIT IN DUPLICATE SCU 32!-9 Sfi~anson Riverrlet,a'-'" AP! No,: 50-!33-!0!25-00 top of fyone,k: 10,238' ,,~ngte @ fyoneK: 0 Deqs. Hanger: Shaffer 0,0 - 2!8' 20"® CS6 65.~,5 - ~66,,~' 7" Of] ~,~J,/ft. N-~ P~. CSG 8466.3 - 10272.0' ?'OD 2g.~/ft P-I!O PROD CSG tt3275,0 ~r? 106.~.0 10661,0 KBFJ_FV: 1.7 T.D; 10745' !95 - 9740.2' 2.875" C~ 6.401/ft L-~ f~ 102~,L~ !o~.:~' "~'~" i/ft - ~.~,~ ~ 4,70 L-80 PS 1036].,] - 10520.6' 2.375" ~ 4.7O~/ft L-~ TBC t~.7 - 1~91.~ 2.675" OB ~.70J/fl L-80 ~G 9637.8 - .9645.1' 2.416" ID RETRV. PACKER Baker 7"B R¢lr Pkr 10204.0-I02710' 1O294.O- 1~4.0- I~2.0' 10~.0-I04~0' lO,~.O- IOYS.~ I¢775 - I/~.t8' R~. PACKER Baker FH Pkr lO,I.~,? - !04~.17 EI~. P/~GKER I~ke.r FI~ FV 10474.0 ~ 11]~.0' P[I~ I.Fi~, 41fl", l~ 1(~0 - 1~.0' l~S H-lO, 4~, 72' j' C.I. IV S EP 1 2 1995 ~il, & Gas Cone, Commi,~kln Smnson River Field No.: 50-!~5-!0125-00 Anqi~ L~ i!oneK: 0 Deqs. ' ~anqer: Shaffer 0,0- ~7.0' 20" 01) CS~ KB ELE~. 17 1~: 10745' 19.3 - §740,2' 2,875" ~ 6.~/ft L,-80 [BG tTJ) - '18,0' 2,437" ID ~ Shoffe~/~ t't ~ Prof~ Ef'l.f - ~.1,t0' 5,5" gl/2.~1" ID ~ ¥~V[ ;~11, Cam i~t~ t;~ 366.93 - ,~677,7 5b" OD 2,F ID Gk.~lJ~ ¥~ ~10. Cram ~G GI~ 4610.9 - .~19.7 5.5" OB 2.347" ID GkSUFT ~'AI.~ ~, Camco 7097,5 - 710.5.9' 5.5" OD 2.547" D ['-,ASJ~ VAL~ iS, C~O I~ ~ Dtt.8 &LOZ 5,5" OD ~347" ID C~ V~L~ J~, C~o ~ C, LM 95212 9¢,aI8 - ~q5,I' 231¢ !O !;LrTI~. ~ Bai~' S~anson River Field 0 ,IoneK: 0 Begs, ~' ~onger: ShWfer 10272.0 - 10272.0' SHOE 10°~~. - 102g~.O' 2.~" ~ ~RV. P~CK~. ~ker SC-2P i0~.5 - 10,~.8' ~t-~. P,~ER ~er FH Pkr I04~5:7 --!04~2.0' REtt~( PACKER ~k~ FH ~ t(YaB7.0 ~ I0589.~Y PACKER .Boker F F, iv, r PSltt. 10700' ~ t074,5' PL~ Baker F La[ch Pkr, Plug W/Eq CaC~ on top PERB H-l, ~, 10' C~V~ ~E To F~m"S mS, ~, 28' ON ~ ~, High P~. Ttx;. C~S~q VALVE t2, C,]rr~,o KI~ L~ ~ ~sS !0~.8 - 10591.0' SB,~ Baker Seal Assy 10584.3 - I0~,2' tANDiI~ NIPPLE Camco D 10586.0 - !0586.8' i0591.0- t05gl.7' i.ggl" ID AP! No,: 50-!55-!0!25-00 Angtl Tyone!: !0,238' !ioneK: 0 Deqs. ~anger: Shaffer 8466.3 - 10272.0' 7" OD 29.00!/ft P-110 P~ CS6 ~n~n I02~0' I UL~ LM - T~ 102/$.9-10282.4' 10282.4-tO~)' 10293.0-10293.5' I0~.0- lO:lO4.0' PLUG ~er F Lotch Pkr. Plug fiFq COCO5 on top 2,6,50" ID R~. P^C~ B~ker SC-2P ~. ~/~ Ext. SEP 12 1995 Alasl~ t;)il .& Gas Cons, Commission · , ~orage !0-~43.5 - !0374.Y ,~UF'f ¥~YE !2, Can~o ,K.~g g~ t0~.0-10~,1~ ~IiB 1+-3, 41fi, 11' lO~4.b - i03~.8' J'OiNI B~ CC ~eiy dj. SCU 321-9 DAY 1-2 (06/03-04/95) 7" ¢__.. 10,287' 5-1/2" @ 9713'-10,743' ACCEPT RIG 6/04/95 ¢__.. 04:00 HRS. MOVE AWS RIG #5 TO SCU 321-9 ON TURNKEY RIG MOB. SET BPV 6/4/95 @ 04:00. ATTEMPT TO PULL BPV. CANNOT PULL BPV. TBG=450 PSI ANN=450 PSI. CIRC DOWN TBG THRU GLM @ 10,200' W/9.4 PPG NACL. SHUT DOWN FOR 1/2 HR. TBG = 100 PSI. BLEED OFF GAS. PULL BPV. SPOT XANVIS PILL ACROSS PERFS. TBG=0 PSI CSG=0 PSI. SET BPV. ND TREE. NU BOP'S. DAY 3 (06/05/95) 7"@ 10,287' 5-1/2" @ 9713'-10,743' ACCEPT RIG 6~04~95 @ 04:00 HRS. MONITOR WELL. NO FLOW. ND TREE. NU BOPE. C/OUT RAMS. PULL BPV. ,SET 2-WAY CHECK. MU TEST JT. TEST BOP'S TO 250 PSI/5000 PSi. PULL 2-WAY CHECK. RU PULL HGR LOOSE @ 140K. WORK TBG & RELEASE BAKER CH PACKER @ 10,237'. SLIGHT FLOW. CIRC 9.4 PPG NACL UNTIL DEAD. NO FLOW. POOH W/3- 1/2" TBG. CHECKING FOR NORM. DAY 4 (06/06/95) 7"@ 10,287' 5-1/2" @ 9713'-10,743' CONT POOH W/3-1/2" TBG & 8 JTS OF 2-3/8" TBG. 2-3/8" TBG PARTED @ 9921'. (MIDDLE OF JT). DID NOT RETRIEVE FH PACKER. RIH W/O/SHOT & JARS. LATCH FISH @ 9921' DAY 5 (06~07~95) 7"@ 10,287' 5-1/2" @ 9713'-10,743' RIH W/FREE POINT TO 10,242'. PIPE STUCK @ 10,242' WLM. POOH W/FREEPOINT. RIH W/l" STRING SHOT & BACKED OFF 2-3/8" TBG @ 20,200'. CIRC & COND SPOT XANVIS PILL ON THE BTM. POOH W/FISH. RECOVERED ENTIRE 2-3/8" TBG & GLM FISH. DAY 6 (06/08/95) 5-1/2' @ 9713'-10,743' RIH W/WASH PIPE. WASH 15' OF FILL FROM ON TOP OF PACKER. POOH RIH W/SCREW IN COLLAR AND JARRING ASSEMBLY. DAY 7-9 (06/09-11/95) 7"@ 10,287' 5-1/2" @ 9713'-10,743' CONT POOH W/WASH PIPE & 3-1/2" TBG. PU GUIDE, SCREW-IN SUB. RIH. TAG FISH @ 10,195' SCREW INTO FISH. WORKED TOP BAKER FH PACKER LOOSE. POOH W/FiSH. RECOVERED 3-1/2" JTS OF 2-3~8" TBG. FH PACKER & S-NIPPLE. PU DRESSING TOOL ASSY. RIH. ATTEMPT TO WASHOVER TBG STUB W/DRESSING TOOL (T.O.F. IS @ 10,316'). TAG @ 10,301' ATTEMPT TO WASH & REAM. P/U KELLY & WASH TO 10,307', COULD MAKE NO PROGRESS (APPEAR TO HANGING UP IN PERFS). POOH. LEFT DRESSING TOOL SHOE IN THE HOLE. P/U SPEAR & RIH @ TAG T.O.F. @ 10,322'. NO SIGN OF TIGHT SPOT IN CASING. POOH W/SPEAR RECOVERED FISH. P/U #2 DRESSING TOOL ASSEMBLY & 7" SCRAPER. DAY 10 (06/12/95) 7"@ 10,287' 5-1/2" @ 9713'-10,743' FINISH RIH W/DRESSING TOOL #2. WASH & REAM AND TAG FISH @ 10,302'. ATTEMPT TO WORK THRU BAD SPOT IN CSG F/10,302'- 10,330'. LOST TORQUE. ROTATE THRU 10,302'-10,308'. PULLED 8000# THRU TITE SPOT. PUMP 17 BBL XANVIS SWEEP. POOH W/DRESSING TOOL. LEFT GUIDE SHOE IN HOLE. DRESSING TOOL WAS OVER TUBING STUB @ 10,322'. MILL ON DRESSING TOOL INDICATES T.O.F. WAS DRESSED OFF. P/U 4-5~8" O.D. STRING MILL & RIH. SEP 1 2 1995 A~aska Oil & Gas Cons. Commission Anchorage DAY 11 (06/13/95) 7"@ 10,287' 5-1/2" @ 9713'-10,743' FINISH RIH WI4-518" OD STRING MILL. P/U KELLY @ 10,298'. TAG BAD SPOT IN CSG @ 10,303'. MILLED F/10,303'-10,311'. WORKED THRU TITE SPOT SEVERAL TIMES. PUMP DRY JOB & POOH W/STRING MILL. L/D 2-7~8" PAC DP & 3-1/8' DRILL COLLARS. P/U OVER-SHOT PACKOFF ASS¥' & BAKER SC2P ISOLATION PACKER & RIH Wi3-112" TBG. DAY 12 (06/14/95) 7"@ 10,287' 5-1/2" @ 9713'-10,743' FINISH RIH W/BAKER SC-2P ISOLATION PACKER. WORK THRU TITE SPOT @ 10,303'-10,311'. WASH DOWN TO TOF @ 10,323'. SET PACKER @ 10,287'. POOH LD RUNNING TOOL. RU & MU BAKER TYPE F PKR PLUG. RIH AND SET F PLUG IN BAKER SC-2P PKR @ 10,287'. TEST TO 2500 PSI, OK. CHANGE OUT CSG PLUG VALVE & TEST CASING TO 3000 PSI FOR 30 MINS (OK). SURF CSG OK. DAY 13 (06/15/95) 7"@ 10,287' 5-1/2" @ 9713'-10,743' POOH L/D 3-1/2" & 2-3/8" EUE WORK STRING. RIH W/NEW 2-7/8" COMPLETION., DAY 14-15 (06/16-18/95) 7"@ 10,287' 5-1/2" ¢___., 9713'-10,743' RIH W/NEW 2-7/8" TBG. LAND TBG TAIL @ 9741'. REV CIRCULATE NALCO CORROSION INHIBITOR. TEST TBG TO 500 PSI. SET BAKER FH PACKER @ 9633'. TEST CSG TO 3000 PSI FOR 30 MINUTES. ND BOP. NU TREE & TEST TO 250~5000 PSI. RELEASE RIG 6/16/95 @ 16:00 HRS. DE-MOB RIG ON TURN-KEY MOVE. RU SLICKLINE. RIH & RETRIEVE STANDING VALVE. POOH. RD SLICKLINE. RU ARCTIC RECOIL. TEST BOPE. RIH W/1.5" COIL TBG & NO77LE. REVERSE CIRCULATE WELL W/DIESEL. PUMPED'TOTAL OF 84 BBLS OF DIESEL. RELEASE WELL TO PRODUCTION. DAY 16 (06/19/95) 7"@ 10,287' 5-1/2" @ 9713'-10,743' RU SCHLUMBERGER. FLOWLINE WAS NOT HOOKED UP. RIH W/GRJCCL AND MAKE TIE-IN RUN. PERFORATED TYONEK @ 10,205'-10,273' VV/2-1/8" ENERJETS TBG INCREASED F/O TO 2650 PSI DAY 17 (06/20/95) 7" @ 10,287' 5-1/2" @ 9713'-10,743' INITIAL 4 HOUR TEST: 961 BOPD, 40 BWPD, 3144 MCFPD DAY 17 (06/20/95) 7"@ 10,287' 5-1/2" ¢___. 9713'-10,743' LAST REPORT. STATE OF ALASKA , ,~_-~SKA OIL AND GAS CONSERVATION CO .... /IISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ _ Suspend __ Operations shutdown __ Re-enter suspended well__ Alter casingm Repair well__ Plugging __ Time extension __ Stimulate m Change approved Program Pull tubing X_ Varianoe __ Perforate X_ Other_ _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Exp~)ratory __ 123' RKB feet 3. Address Stmagraphk= __ 7. Unit or Property name P.O. BOX 196247 ANCHORAGE, AK 99519 se~e ~ Soldotna Creek Unit 4. Location of well at surface 8. Well number 530' FNL, 1890' FWL, Sec. 9, 'ITN, R9W, SM SCU 321-9 At top of productive interval 9. Permit number Same as above ~'/-- ~ ~z ~> At effective depth 10. APl number Same as above 50-133-10125-00 At total depth 11. Field/Pool Same as above Swanson River/Hemlock 12. Present well condition summary Total depth: measured 10.745' feet Plugs (measured)r.,~ I.~ ! f..~ ~ !~ I ~' true vertical 10,745' feet__..---.. __ ~U~'~L~~,/~'~,~- Effective depth: measured 10,700' feet Junk (measured) None true vertical 10,700' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 37' 20" Yes 37' 37' Surface 2010' 11-3/4" 1275 sx 2010' 2010' Intermediate Production 10,272' 7" 550 sx I st Stage 10,272' 10,272' 1250 sx 2ncl stage Liner 1,032' 5-1/2" 100 sx 9713'- 10745' 9713'- 10745' Perforation depth: measured 10294'- 10304', 10324'- 10352', 10364'- 10375', 10388'- 10450', 10474'- 10582', 10598'- 10659' true vertical Same as above ~ ECEI V~ Tubing (size, grade, and measured depth) 3-1/2", 93# to 9658, 2-3/8" 4.7# 9658-10,592' JUN Packers and SSSV (type and measured depth) Baker FH pkr @ 10,237', Baker FH pkr @ 10,383' .,,~$t(~ U/l & ~a$ Co~is, Baker FH pkr @ 10,462', Baker P pkr @ 10,587' AncOt,.., Corn~ 13. Attachments Description summary of proposal x _ Detailed operations program_ _ BOP sketch _ _ 14. Estimated date for commencing operation ~ 5. Status of well classification as: June 3, 1995 16. If proposal was verbally approved Oil_ _ Gas __ Suspended _ x 5~24/95 Name of approver Blair Wonzell Date approved Service _ Gas Injector 17. I hereby~ ~'~e fo,[.e~l~ing ~ true and correct to the best of my knowledge. Signed G.'Ru~--'e]~~v[/'~/-~'~~ Title Drilling Manager Date 06/15/95 · '"FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApprRva. l.,blo., ,.~ ,~ Plug Integrity ~ BOP Test~ v'" Location clearance ~I ~,,~- '"/C7((..~ "' Mechanical Integrity Test__~ __~_O_r.[ Approved Copy Returned Approved by the order of the Commission ~_~ -'~~.~ '~Cu~m/~m~s~//n~er~-- Date Form 10-403 Rev 06/15/88 ~ ~ ~ :{IPLICATE Swanson River Field SCU 321-9 Preliminary Procedure Work-over: Convert Gas Injector into a Tyonek OH Producer . . . o 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. Prepare Location ND flowlinc Kill well by bullhcading 9.0 PPG NaCI brine and p~ well for workovcr. Cut TBG at 10,320' w/chcmic~ cutter. Mov~ in rig up Alaska W~ S~vic~ Rig #5 as a mmk~ ~ ND ~ and NU BOPE and t~t BOPE to 250 psi and f~00 psi. Ci~flat~ 9.0 PPG brino. R¢leas~ top FH packer and POOH w/3-1/2" T13G. RIH w/workstring, casing scrap~ and drying tool Dross off TBG stub. RIH w/Bake~ SC2P paci~r and s~t isolation ~ at 10,275. RE-I w/Bai~ F parlor plug and install in SC2P pa~. Rill w/new 2-?/g" TBG and 12 gas lift mandr~ and Bak~ FH ~. Land TBG and set Packer ~ 9633'. ~o~ 7~ ~-- Rcmov~ BOPE and ~ and t~st tr~ to f~00 psi. NU flowlin~ m~d gas ~ lin~. RDMO AWS Rig ~ as a turni~ rig move. MIRU Dowell coiled tubing unit TEST BOPE RIH w/1.5" coiled tubing a~l displao~ 9.0 PPG bri~ ~ th~ ~asing and tubing with RDMO coiled TBO unit. lvflRU Schlumberger wircline unit. NU lubricator and test to ~ psi. , RIH w/GR/CCL and 2-1/2' RET Enerjet perf guns. Perforate Tyonck (3-2 sands ~ 10198'-10262' and 10158%10173'. RD wirclinc unit Turn well over to production. RECEIVED JUN 22 199,5 Alaska 0il & Gas Cons. Commission Anchon, p MWD 321.gPR2.DOC :~t3 10,474' 10,611' IO, d!94' 10,$04' 10,3SZ' 10,,,175' 10,388' L -- 9,657,54' "' --- 9,656.04'-' -- 9,715.00'-..- · '-- lOt 189.40'--' · '-- I0,200.06"-- · "' fOt2$1 .41'-' i0,257.6 6'--' '-' t0,268.25'"- ---tO,3 65.5/S -- --- t0,374.$4"~ -'?'. 10,375.76"- ---t0,377.54'-- --- 10,383.T9'-- ---- 90,408.74' --,, '"'- t0,410.27' --' '-' 10,4 41.97' '- ---' 10,4 52.80'--' -"- t0,45421 ' '"' -"' 40,455,71 ' "-" --,- 10,462.01' --.- '"--' t0,491.99' "- "-- to,4g3.51' --' --- tO, S 08.83' -- -'-' t0,S40.82' '"" -" tO,SSSJB'"' ---- t0,584 29'-- --- t0,58521 ',-. --- lO, 586.00'-- · "-- t0,567.0~' '- --- t0,591.00',~- --t0,$91.66'--' · , PUP JT. 3 I,t' AB NOOIFIEO 8i10 l-~ jiT JTS. 3}~' A8 HOOlfiEO 8~ 939FT I-~ I80 T~ ~ LIX[I IT JT$. Z~'k8 H~l[O 8~ fl-K 4~ CANTO 2 ~' ~ NOOlF~O ~G ~REL W ~ ~E. I JT 2~' AB GIRO 8~ K-80 4]?F[ I J'[ 2~1' AB HOOIFIEO 8RO N-80 4~7~[ TBG. OTiS S KI~LE POSITION J J JTS. 2}8' AB N~lFiO 8~0 K-BO 4.T1~ TBG. CAHCO Z}I' kB HOOIFI[O KBH~ HAN~EL , kITH EK VAWE ' I SFTY. JT. Z}I' A8 HOOIFIED 8~0 CL I ~P J[ Zllr A8 NOOlFIEO 8~ fl-lO 8A~R 5~'Z Z~I' F.K PACKER OTIS S'.NIPKE POSITIO~ I JT. 2}1 A6 MODifiED I~ N-80 L~F[ CALCO 2~1' A8 HOOtFIEO tBNG HANME L~ WITH El VAWE I~ETY JT. 2~ k8 NODIFIED BROIl CC i PUP Jt 2}(MODIFIED 8 aD K-A0 4./~fT. BA~ER 5~'x2~1' F.H. PACKER I IT. Z}I' A8 NODtFIEO 8~0 K-80 4.rT~. TBG ', OTIS 'S' NIP~E POSITION I ~ P~ ITS. Z}l' A8 NOOIFIED 8U i-80 4.TTFT I IT. 2~8' AB NOOIFIEO 8nO a-80 4.~FT.TBG CAMCO 2}8' AB NOOIFIEO. &Blt WlTU Et VALVE lit. 2}; AB XOOlFIEO 8ti HO 4.~ TOG. CAK~'D'NI~LE 2~1' BAtER SUB slop Z~0' l~ 8At(R 5'/~':~O~FT NOOEL'D' PACK[RI.L.S[T ( i SEAL ASS[KBLY Z~l' ~ ~8 N~E~E B~LK~O WITH I' H~E IN I !,~, -- , -- W.L,S~fO)C[ UA S~AL ASSL'KILT riSK -..-tO,tO0 10P OF PLUG S ' ~ 2Z OF' I'.L. FISN LAST TA, CGID Kilt(...J'Jl'14 ~--t0145' TOTAL Ol fTK $CU 321'9 NOTE: TUBING I'ARTIALLT DAMAGED WHILE 'ScoW, T?N, RSW, 8.M. RUNNING IN HOLE. CONSULT WELL HISTORI' BEFORE WORKING ON WELL. TUTING RUN .T'27-84 CASINO 8~ TUBING DETAIL NP8 , ,, 1-.~ ,,. ,.~TATE OF ALASKA ALASK,,-~.,..OIL AND GAS CONSERVATION C~"%IMISSION REPOR. OF SUNDRY WELL OF RATIONS 1. Operations performed: Oper&tion shutdown __ Stimulate Pull tubing _ Alter ceding__ __ Plugging __ Perforate __ Repair well __ Pull tubing __ Other__ 2. Name of Operator Unocal 3. Address . 12. P.O. Box 196247 Anchorage, Alaska 99519-6247 Location of well at surface 530' FNL, 1890' FWL, Sec. 9, TTN, R9W, SM At top of productive Interval 530' FNL, 1890' FWL, Sec. 9, 'ITN, R9W, SM At effective depth 530' FNL, 1890' FWL, Sec. 9, T7N, Rgw, SM At total depth 530' FNL, 1890' FWL, Sec. 9, TTN, R9W, SM Present well condition summary Total depth: measured true vertical 10745 feet 10745 feet Effective depth: measured 10700 true vertical 10700 5. Type of Well: RECEIVED APR 22 1994 Aiaska Oil & Gas Cons. Commission ~u,u.orage Plugs (measured) feet Junk (measured) feet 6. Datum elevation (DF or KB) KB: 142' 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 321-9 9. Permit number/approval number 61-20 10. APl number 50-133-10125-00 11. Field/Pool Swanson River/Hemlock Ot I6INAL feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth True vertical depth 37' 20" Yes 37' 37' 2010' 11-3/4" 1275 sx 2010' 2010' 10272' 7" 1800 sx 1027Z 10272' 1032' 5-1/2' 100 sx 9713'-10745' 9713'-10745' 10294-10304, 10324-10352, 10364-10375, 10388-10050, 10474-10582, 10598-10659 true vertical 10294-10304, 10324-10352, 10364-10375, 10388-10450, 10474-10582, 10598-10659 Tubing (size, grade, and measured depth) 2-7/8', 6.5# to 9687' and 2-3/8', N-80 to 10653'. Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Baker seal assbly. @ 10587'. Baker F1 pkr. @ 10259', Brown HS-16-1 pkr. @ 10376'. Brown HS-16-1 pkr. @ 10456'. 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injeclion Data OiI-Bbl Gas,Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X_ 16. Status of well classtr=ation as: Oil __ Gas __ Suspended Sen4ce Water injector 17'lher~yc~.' .ti~(~ef~°~u!)andc°rrectt°thebest°fmykn°wledge~k~. . ,,, '~. Signed J'~-- l'~'~,,lt%Y-v~ ./~ Title Date Form 10-400 Rev 06/15/88 SUBMIT IN DUPLICATE UNOCAL WELL SE ~"' RV ,.,E REPORT FOREMAN CONTRA~R OPERATION Al; TIME OF REPORT:. REMARKS: _ ii , ii i _ . _ ,. ADD q~ .__ Alaska 0ii & Gas Cons. 4nchorage ........ IWEATHER ~rEMP. REPORT F i~HILL FACTOR V e plSIBlUW [NIND EL/NfflALS. Fi mi. kts.~W_~ I PAGE. OF ._._._ STATE OF N. ASKA ALASKA OIL AND GAS CONSERVATION ~SSION Mecflanlcal Integrity Test OPERATOR: ...... p,~ START '~= U~' ..... ~,U~. "' TI~ TIUE TIUE TIUE "P TYPE PA~ R~ ~ME ~ ~UID MD 8~,,1~1~ 8~ P~ PRE~ P~ P~ TIME , ~MMENTS: i i i i ' '*~'~ , ,, '/~"~ 14~o~&° 0 13~ o V ~MME~ 3 .... ....... ~MMENTS: II ~ I I,, ~ "'1 i ...... ~rLI~II~IG IWE~"TION FLUID: JIIkNNUL4R FLUID: ~k~J&J~ENI': ~'1~: = PROCI. IC~DWATER INJ. IDIESE[. Il'dUal , = ?0,ALT WATER INJ :. GI.~ ,, , . 4 - Year "MISCIBLE INJ. :~ SAlT WATER WorklwJr a~JE~ ~ ORI~ MUD OUta' . .. = NOT INJECTING ~' ~ ,,-E'A~;: OTHER ~ ~ OTH~ Database ,~, =~ ...., .c~ OPBRATOR REP SI c-,,l~pec~t'M'c'TrJpRi'tRle ~ ,.o r t'l.~. ~ * FI.051.Xt.T (Rev. 12/92) (~~~ ._ ,~,~ ..... 1. Type of request: STATE OF ALASKA ALASKA./'"-. AND GAS CONSERVATION COM~SSION /-~ APPLICA. FOR SUNDRY AP, AOVALS Abandon __ ' Suspend m OperMiom shutdown m Re-enter 8uepended well__ Alterouing Repakwell Plugging Timee:xten~ion S.muhte (MIT) f~/'///.--// m m Pull tubing -- Varlar~e Perforate __ OtherX Change approved program 2. Name of Operator Union Oil Company of California (Ur~ 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at sul'ace 530' FNL, 1890' FWL, Sec. 9, 'I7N, R9W, SM At top of productive Interval At effective depth At total depth StaTue as above Type of Wel: Expk)mto~ ~ 6. Datum elevation ~ or KB) feet4 7. Unit or Property name Soldolna Creel< Unl 8. Well number SCU321-9 g. Permit number 10. APl number 50-133-10125-00 11. Field/Pool Swanson River/Hemlock 12. Present well condition summary Total depth: measu'ed true vertical Effective depth: meastxed 10700 true vertical 10700 Casing Length Structural Conductor 37' 20' Surface 2010' 11-314" Intermediate Production 10272' 7' Uner 1032' 5-1/2' Perforation depth: meas~xed true vertical 10745 feet Plugs (measured) 10745 feet feet Junk (measured) feet Size Cemented Measured depth True vertical depth Yes 37' 37' 1275 sx 2010' 2010' 550 sx let stage 10272' 10272' 125o sx 2n(I stage 100 sx 9713' - 10745' 9713' - 10745' 10294-10304, 10324-1~, 10364-10375, 10388-10450, 10474-10582, 10598-10659 10294-10304, 10324-10,3,52, 10364-10375, 10388-10450, 10474-10582, 10598-10659 Tubing (size. grade, and measured deplh) 2-7/a', 6.$# to 9687' and 2-3/8", 4.7# N-80 to 10eSe'. Baker seal asbly. ~ 1068i Packers and SSSV (type and rneas~xed depth) Baker 'Fl" packer@ 10259', Brown H8-16-1 pla'. @ 10376' Brown H8-16-1 I pkr. @ 10456' 13, Attechments Description summary of proposal __ Deteiled operations progmmX__ BOP 14. Estimated date for commencing operation 115. July 20, 1993 / 161 If proposal was verbally approved Oil m Gas ~ Name of approver Date approved Service Inlector,, 17. I here(~ cer~ that i~e~l~coff~ ~ the best of'~,, ___1vi_.,, my knowledge. Condltk3m ot approval: Notify Commission so representative may witness Status of well classh~ation as: D--, g.3 93 Plug Integrity _ BOP Test Mechanical Integrity Test~./' Appro'..'ed by the order of the Commission Form 10-403 Rev 06/15/88 Location clearance ,~-ubsequent form required 1"~- Original Signed By David W. Johnston Approved Copy Returned ~/~/~ '-~ _ C~mn~ieaio'ner' Date ~//,,g'/77 *~ SUBMIT IN ~ HiPLICAt E E-Line' BOPE's Grease Head/ Hydraulic Packoff ~-- Lubricator Extension Manual Rams UUN 15 1989 Alaska 011 & Gas Con~. Commission Anchorag~ _ Double Maste~ Valves -Wellhead RECEIVED d u L 2 0 199;5 Alaska Oil & Gas Cons. Commission Anchorage PC & SC Loading and PC Pressure Test SCU 321-9, SR 47 ~0~ectlve: To load the PC and SC and verify mechanical integrity on the PC per the AOGCC requirements. This testing must be witnessed by the AOGCC prior to July 1, 1989. Well Data: PC: SC: Top pkr. depth: Capacities: Current Pressures: 2-7/8" EUE tbg. to 9,647' MD 7" N-80; 23, 26 and 29# to 10,272' MD 11-3/4" 47# J-55 to 2,010' MD 10,259' MD 'Fog x PC = .0302 Bbls/ft. PC x SC = .0699 Bbls/ft. Tbg= 5550 psi; PC= 1700psi; SC =30psi procc, dure: Load PC and ~ . Install a two-pen recorder on the well to monitor the SC and PC pressures. . Shoot fluid levels on the SC and PC. (Skip to step #10 if no load is needed on the SC or PC). Calculate needed load volumes to fill SC and PC. Assure that this fluid is on location for load. 3. Monitor tbg., PC and SC pressures throughout the Job. 4. Hold safety meeting. 5. RU choke and gas buster to SC, as needed. 6. Blow down SC pressure without allowing fluid production. 7. Hook up pump truck to SC and pressure test lines to 4500 psi. . Load SC with lease water containing .25% WIB76 corrosion inhibitor finishing with a 5 Bbl crude cap. Do not exceed 300 psi during pump-in. . Repeat steps #5-8 for the PC, as needed, using a 3000 psi maximum injection pressure for step #8. (Several 1,000 psi blowdown/loads may be required). RECEIVED d U L ~ 0 ~995 Alaska Oil & 6as Cons. Anchorage PC & SC Loading and PC Pressure Test $CU 321-9, SR47 Page Two Contact the AOGCC (279-1433) and BLM (267-1243) at least 24 hours prior to testing the PC so that an agency witness can verify the test results. Pressure Test _ 10. Pressure up PC to 500 psi over current pressure (2,000 psi minimum). Hold for five minutes (observing tbg., PC and SC pressures). 11. 12. If less than 50 psi is lost in five minutes, increase pressure by 500 psi. Hold for five minutes. Repeat step # 11 until 3610 psi is reached. Hold pressure for 30 minutes, noting initial and final pressures on all strings. 13. RDMO. RECEIVED d U L ~ 0 Alaska Oil & Gas CoDs. Commiss~o~ Anchorage T. --. /. 7/0. · ~o0. CASING CA~CO ~M M~D~ /3.20' 071~ ~ NI~PL~ POSITION uN ..... ~ ~0' ~0~ ~X~A~S/O~ J~ ...... ~.7~' P~P d~ ~' EMI ~U~I~ ..... /0.1~' CAMCO PUP ~ ~ ~' ~ ~1~$ ...... ~. 00' ~ PU~ ~ / PUP JZ 2~" · JUL Oii& 6as Cons. ;Anchorage ARCO Alaska, Incf Post Office , ,o0360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures July 31, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: 1988-89 UIC Pressure Testing - Swanson River Field Wells SCU 314-4, SCU 332-4, and SCU 321-9 Dear Mr. Chatterton: Attached are Sundry Notices and Well Service Reports which document the production casing pressure tests on gas injection wells SCU 314-4, SCU 332-4, and SCU 321-9. The wells were tested in accordance with Rule 6 of the AOGCC Area Injection Order No. 13. All wells held their required test pressure (within 10%) for 30 minutes. These pressure tests satisfy the requirement to test 25 percent of our Class II wells per year. Please contact Stacy Strickland at 263-4914 if you have any questions concerning this matter. Sincerely, T. S. McCorkle TSM:DML:ch:0003 Attachments CC; G. A. Graham A. R. Kukla UNOCAL Corporation Marathon Oil Company RECEIVED AUG o 7 t989 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlantlcRichlleldCompany AR3B--6279 ADsTATEN OF ALASKA OIL GAS CONSERVATION COM,. ,.SION REPOFir OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __ Stimulate __ Plugging __ Pedorate __ Pull tubing -- Alter casing __ Repair well __ Pull tubing __ Other.~X M I T 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360 Anchorage, AK 99510 5. TyPe of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 530' FNL, 1890' FWL, Sec. 9, T7N, R9W, SM 6. Datum elevation (DF or KB) 142' RKB 7. Unit or Property name Soldotna Creek Unit At top of productive interval Same as above, At effective depth Same as above, At total depth Same as above. 9. Permit number/approval number lO. APInumber 50-- 133-10125-00 11. Field/Pool Swanson River-Hemlock feet 12. Present well condition summary Total depth: measured Effective depth: Casing Conductor 37 ' Surface 2,010 ' Production 1 O, 272 ' Liner 1,032 ' Perforation depth: measured 1 O, 745 feet true vertical 1 O, 745 feet measured 1 O, 700 feet true vertical feet 10,700 Length Size Plugs (measured) Junk(measured) Cemented Measured depth 20" yes 37' 11-3/4" 1275 sx 2,010' 7" 550 sx 1st stage 1250 sx 2nd stage 10,272' 5-1/2" 100 sx 9,713-10,745' I,294-10,304'; 10,324-10,352'; ,598-10,659 ' . true vertical Same as above. Tubing (size, grade, and measured depth) 2-7/8" 6 5# to 9 687' and 2-3/8,.'., 4.7# N-80 to 10~653'; , , , Packers and SSSV (type and measured depth) Baker ' F 1 ' Pkr e 1 O, 259'. Brown HS-16-1 Dkr @ 10.456'. 13. Stimulation or cement squeeze summary 10,364-10,375'; 10,388-10,450'; ~ueverticaldepth 37' 2,010' 10,272' 9,713-10,745' 10,474-10,582'; Brown HS-16-1 pkr ~ 10,376'. Baker Seal ina_ Ass. ¢ 10.;587' . is,.r~ Et,~'E J. ~V' E []t 14. Intervals treated (measured) N/A AUG o 7 1989 Treatment description including volumes used and final pressure ..-~,.¢,,- ..... ~,~,-~ 0il & Gas Cons. C0mmissl0n Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 25,759 -- 1,750 5,1 O0 Subsequent to operation -- 31,214 -- 15. Attachments 116. S~atus of well' classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations __ Oil __ Gas __ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1,500 5,240 Service Gas Injector Signed ~,,,~, ~ Title Cook INlet Engineering Manager Date ' : " , SUBMIT IN DUPLICATE Form 10-404 Rev 06/15/88 Il I Jl · I I llIl IIII pR,,:;~,.~.;:~.c, ....... ~,_~ 15 ~ .-tO'It:IN ........ - ,, , ' ,~-~:/.t: oo ~._ ,, ..... _, , ......... ,~ ,~ ,, ,,,,, , .... " ' 7'~ ~ '~ ~ - -- - · ...... - .... i . ,, II Ii ii , II ....... I i iii i i i i i ii ..... ~ ____ ii i , , III iiii iiii i [ I [ iiiiiii · i i .... iii i I ~ I ii ......... i i i i ii I i ii ...... ....... I1~11 i ...... ~. _ I I i , .. ...... ~ - II lu ~,, - _ i ii I I I I iii _ I I 20 ~C 25.030(a1 ~0 ~C 25.612(c) 20 P,P,C 25.2b'2(d) ARCO Alaska, Inc. Post Office 8ox 100360 Anchorage, Alaska 99510-036C Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures OiIIGIN June 14, 1989 Mr. C. V. Chatterton, chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: ARCO Alaska, Inc. requests approval to perform the attached mechanical integrity tests on $CU 314-4, $CU 332-4, and SCU 321-9,: This testing is designed to demonstrate tubing and production casing integrity in accordance with the AOGCC Injection Order No. 13, Rule 6. It is being done to satisfy the requirement to test 25% of our Class II wells per year. Plans are to perform the MIT's as soon as possible as the testing deadline for the 1988-89 program is June 30, 1989. Please contact Carol Baker at 263-4643 if you have any questions concerning this matter. Sincerely, T. S. McCorkle TSM:CMB:ch:0017 Attachment RECEIVED )UN 15 1989 Alaska Oil & Gas Cons. Commission Anchorage cc' G.A. Graham ,~ 1~ Kukla UNOCAL Corporation Marathon Oil Company ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6279 STATE OF ALASKA '"-'" OIL AND GAS CONSERVATION COMMI~..,,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend .__ Alter casing ~ Repair well Change approved program __ Operation shutdown ~ Re-enter suspended well ~ Plugging ~ Time extension ~ Stim utate __ Pulltubing ~ Variance ~ Perforate ~ Other .Z_ tv11T Test ing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510 4. Location of well at surface 530' FNL, 1890' At top of productive interval Same as above. At effective depth Same as above. At total depth Same as above. .5. Type of Well: Development ExplOratory Stratigraphic Service FWL, Sec. 9, T7N, R9W, SM 6. Datumelevation(DForKB) 142' RKB ~ UnitorPrope~yname Soldotna Creek Unit 8. Wellnumber SCU 321-9 9. Permit number 10. APl number 50-- 133-10125-00 11. Field/Pool Swanson River-Hemlock feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Production Liner 10,745 feet 10,745 feet 10,700 ~m 10,700 ~et Perforation depth: Length Size Plugs (measured) Junk (measured) Cemented RECEIVED 3UN t t9 9 N°r~Jaska 0ii & Gas Cons, Commission Measured depth .Artchol~ vertical depth 37' 20" yes 37' 37' 2,010' 11-3/4" 1275 sx 2,010' 2,010' 55O 10,272' 7" 1250 1,032' 5-1/2" measured 10,294-10,304'; 10,324-10,352; true vertical Same as above. Tubing (size, grade, and measured depth) 2-7/8", 6.5// to 9,687' and 2-3/8", Packers and SSSV (type and measUred depth) Baker 'FI' packer @ 10,259'. Brown sx 1st stage 10,272' 10,272' sx 2nd stage 100 sx 9,713-10,745' 9,713-10,745' 10,364-10,375'; 10,388-10,450'; 10,474-10,582'; 10,598-10,659'. 4.7//, N-80 to 10,653'. Baker Sealing Ass. HS-16-1 pkr e 10,376', Brown HS-16-1 pkr 10,587'. 10,456', 13. Attachments Description summary of proposal __ Detailed operations program X' BOP sketch 14. Estimated date for commencing oPeration ! 15. Status of well classification as: 16. If proposal was verbally approved I 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 ~ i,,t)~,E,~z..... ~ 'l'~/~c~r.,,Jr-~ Title Cook Inlet Engineering Mgr. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ B.OP..Test __ Location clearance ~ Mechanical Integrity Test '~, Subsequent form required 10- /, ORIGINAL SI6NED BY LONNIE C. SMITH Approved by order of the Commissioner I Approval NO. ¢-"~'c:~ ¢ Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead PC & SC Loading and PC Pressure Test SCU 321-9, SR 47 Objective: To load the PC and SC and verify mechanical integrity on the PC per the AOGCC requirements. This testing must be witnessed by the AOGCC prior to July 1, 1989. Well Data: PC: SC: Top pkr. depth: Capacities: Current Pressures: 2-7/8" EUE tbg. to 9,647' MD 7" N-80; 23, 26 and 29# to 10,272' MD 11-3/4" 47# J-55 to 2,010' MD 10,259' MD Tbg x PC = .0302 Bbls/ft. PC x SC = .0699 Bbls/ft. Tbg=5550psi; PC = 1700psi; SC =30psi Procedure' Load PC and SC . Install a two-pen recorder on the well to monitor the SC and PC pressures. e Shoot fluid levels on the SC and PC. (Skip to step # 10 if no load is needed on the SC or PC). Calculate needed load volumes to fill SC and PC. Assure that this fluid is on location for load. , , . 1 Monitor tbg., PC and SC pressures throUghout the job. [~ ~_ C ~ [V '~ D Hold safety meeting. [JlJ~ 1 5 1989 RU choke and gas buster to SC, as needed. Alaska 0il & Gas Cons. Commission Anchorage Blow down SC pressure without allowing fluid production. 7. Hook up pump truck to SC and pressure test lines to 4500 psi. . Load SC with lease water containing .25% wr676 corrosion inhibitor finishing with a 5 Bbl crude cap. Do not exceed 300 psi during pump-in. 0 Repeat steps #5-8 for the PC, as needed, using a 3000 psi maximum injection pressure for step #8. (Several 1,000 psi blowdown/loads may be required). PC & SC Loading and PC Pressure Test SCU 321-9, SR47 Page Two Contact the AOGCC (279-1433) and BLM (267-1243) at least 24 hours prior to testing the PC so that an agency witness can verify the test results. 10. 11. 12. 13. .PC pres.sure Test Pressure up PC to 500 psi over current pressure (2,000 psi minimum). Hold for five minutes (observing tbg., PC and SC pressures). If less than 50 psi is lost in five minutes, increase pressure by 500 psi. Hold for five minutes. Repeat step # 11 until 3610 psi is reached. Hold pressure for 30 minutes, noting initial and final pressures on all strings. RDMO. ~,laska Oil & Gas Co~s. commisslog Anchorage CA$1/VG ~"'%'U~i/V~ ~£T4/L ~.~.~ ~ -- 251 J T4. ~ ~" £UE TI.18/NG_ ,' - ~"~ 2~~ X ovf~ ~ I8 JT'a. ~~ £(.1£ 71./8/N$_ J Wel 1 s under Evaluation for Rate Potential 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 TABLE Wells being Evaluated for P&A/Future Uti 1 i ty 212-10 21-15 31-15 34-15 432-15 312-22 212-27 14A-33 12-34 22-23WD 243-8 14-34 Wells SI for Inefficient Producti on 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until B1 owdown 43A-15 314-27 331-27 ~'343-33 ARCO Alaska, Inc. Post Office 00360 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 work0ver 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. l~he 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 _+100 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 ,,:, .' 1987 Alaska 0ii & Gas Cons. Oommissiofl Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanficRichfieldCompany ~,~/'- '~ ~'1 ...... / ~,~'" ? CONTRACTOR IOPERATION AT REPORT TIME REMARKS [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ATTACHMENT E-I Injection Well Data Water Disposal Wells SRU 31-33W SRU 32-33W SRU 1+1-33W SRU 21-33W scu 1+3-1+w.; Av§. Rate(BPD) 3271+ 651 125 2805 Max. Rate(BPD) 4500 1+500 1+500 1+500 1+500 Avg. PreSs(psi) 769 778 913 735 Shut In Max. Press(psi) 1000 1000 1000 1000 1000 Depth of ,,, bj.(tt.) 2100 2100 3100 Depth of Well(ft.) 21+61 2520 3000 6660 Gas Injection Ave. Wells Rate(MCFD) Max, Rate(MCFD) SCU 314-2 39,950 SCU 323-1+ 35,680 SCU 332-1+ 27,61+0 ~jCl~! 3#l-t+ 37,61+0 31+ 1-8 30,300 31'2-9 I+1+ ,000 SCU 321-9 29,91+0 SCU 323-9..- ~ 35,920 SCU 3/33-33 0 SRU 332-15 0 SRU 312-22 0 SRU 311+-27 0 SRU 331-2~ ~ 0 1+5000 1+S000 45000 45000 1+5000 1+5000 45000 1+5000 45000 1+5000 1+5000 1+5000 1+5000 5075 5370 5095 5355 5160 5270 5155 5105 Shut In Shut In Shut In Shut In Shut In c~ 7 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 10291 10390 101+70 10226 10256 10183 10291+ 10280 10695 11388 10754 1111+6 10801+ 11520 10775 11119 10850 10814 10785 1071+5 10750 10995 11982 11000 1i620 -8- ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.252 0~-Sep-87 ARCO Alaska, Inc. 110500 Name of Operator SWANSON RIVER FIELD - UNIT 051950 Fi eld and Pool August 1987 Month and Year of Injection 1. WELL NO. ! ' .314-4 ' 52.3-4 3.32-4 541-4 ' ' 541-8 312-cp 323-9 ' 343-35 '412-10 ' .521 43-4WD , 2. API NUMBERI3. C[4. FIELD:5. DAYSI TUBING PRESSURE 50- : LI & POOL I IN ~ ~ Al CODE [ OPER 1&. MAXI7. AVERAGE I SI I___SI 133-10104-00 IG 133-10106-00 155-10107-00 133-10109-4)0 153-101.20-00 133-10123-00 133-1012&-00 133-101&8-00 155-2020&-00 IG 135-10125-00 155-10111-00 ID I I l I I I I I l I I I I I I I I I I I I I I PSIG I PSIG I I I 772100 I 30 15,450 I 772100 I 0 I 0 I 0 772100 I 30 15,500 I 5,005 772100 I 50 15,550 I 5,141 772100 I 0 I 0 I 0 772100 I 30 15,350 I 772100 I 30 15,300 I 4,928 772100 I 0 I 0 I 0 772100 I 0 I 0 I 0 772100 I 30 15,450 I 77205& I 0 'I '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 CASING PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION. I I I I 8. MAX 9. AVERAGEIIO. LIQUID 111. GAS I 15. LIQUID I 14. GAS I PSIG 5,500 0 1,040 2,8&0 0 17240 2~&O0 0 0 l~&O 0 PSIG I (BBL) I (MCF) I (BBL) I (MCF) I I 2,359 I I ~9,2-59 I I 1,177,1&5 ~... 0 I I 0 I I 0 &5& I I 31~&52 I I 948,c255 ... 2,376 I I 37,120 I I l,l13~&O~ I 0 I I 0 I I 0 1 1,109 I I 40,483 I I 17214,475 1 2,368 I I 35,148 I I 1,054~428 I 0 I I 0 I I 0 I 0 I I 0 I I 0 1 1~815 I I -'~5~706 I I 771~182 I 0 I 0 I 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 , 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 I Signed 'I hereby certify that the foregoing is true and correct to the best of my knowledge Title Form 10-44)5 Rev. 12-1-85 Date INSTRUCT IONS ON REVERSE SIDE I15. I I I I I I I I I I I' I I I I I I I I ITOTAL I 0 I &,279,814 I I Submit in Duplicate ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC-'-~5. 252 ARCO Alaska, Inc. 110500 Name of Operator SWANSON RIVER FIELD - UNIT 051994 Field and Pool August 1987 Month and Year of Injection :1. WELL:2. APl NUMBERIS. CI4. FIELD : NO. | 50- ~ L~ & POOL I I I Al CODE I I I SI I I I___SI 1512-22 1135-10147-00 18 I 772100. 1514-27 1153-10154-00 IG I 772100 1551-27 1155-1015&-00 18 I 772100 1452-15 1153-10141-00 IG' I 772100 5. DAYSI TUBING PRESSURE IN I OPER l&. MAXI7. AVERAGE PSIG PSI8 l I 121-55WDI155-101&2-O0 ID 151-33WD1155-20556-00 ID 132-33WDI.133-10164-00 ID 141-35WDI155-10167-00 ID I I I I I ' I I I I I I I I I I I 1 I I I t I I I I I I I I I I I I I I I 1 I I I I I I I I I I I : I | I I I I I I I I I 772036 I 772056 I 772056 I 772056 I I I I I I I I I I I I I I 'I I I I I I I I i - I - I . I - I 29 875 1 29 820 I 50 875 I 50 850 I I I I ' I I ' t I ' I ' I I ~ I ' I I ' I ° I ' I I ° I ' I ~ I ~ I I ' I 754 746 759 751 CASING PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION 8. MAX PSIG I I I 9. AVERAGEIIO. LIQUID 111. GAS I 15. LIQUID I 14. GAS I PSIG I (BBL) I (MCF) I (BBL) I (MCF) I 1 I I I I I I 77,581 I I 80,518 I I 62,119 I I 4,352 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 I I I' I I I I I I I I 2,675 I I 2,770 I I 2,071 I I 145 ] I I I I I I I I I I I I I I I I I 1 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 of my knowledge I I l Si gned I I. I ITitle I Form 10-~05 Rev. 12-1-85 Date ~ /~ ~--'~/~ 7 INSTRUCT IONS ON REVERSE SIDE -115. I I I I I I' I I I I I I I I I I I I I I I I 1 I I I I ITOTAL I 224~570 I 0 I I I I Submit in Duplicate 'x PRUDHOE B~ UNIT S-11 PRUDHOE B~UNIT S-14 PRUDHOE UNIT T-1 PRUDHOE UNIT T-7 PRUDHOE BAY UNIT U-3 PRUDHOE BAY UNIT PRUDHOE BAY UNIT PRUDHOE BAY UNIT U-9 PRUDHOE BAY UNIT U-lO PRUOHOE BAY UNIT X-6 PRUDHOE BAY UNIT X-11 PRUDHOE BAY UNIT X-23 PRUOHOE BAY UNIT PRUOHOE BAY bNIT X-26 PRUDHOE BAY UNIT Y-3 PRUDHOE BAY UNIT PRUDHOE BAY UNIT Y-6 PRUDHOE BAY UNIT Y-7 PRUDHOE BAY UNIT Y-11RD PRUDHOE BAY UNIT Y-18 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL SWANSON RIVER, HEHLOCK 0 ARCO ALASKA INC SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT ............. SOLDOTNA CK UNIT SOLDOTNA CK UNIT IL POOL 314-4 323-4 332-4 341-4. 341-8 312-9 321-9 323-9 412-10 343-33 UNIT OR LEASE TOTAL 309:534 264,425 174,467 380,162 602,357 515,072 264,751 183,322 244,173 294,661 149,980 173,544 262,057 282,344 76,492 49,131 84,323 22,223 43,679 306,429 1~,519,526 39,536,156 84,445,002 39,536,156 88,810,140 SOLDOTNA CREEK UNIT SHUT-IN SHUT-IN 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 1,148,650 31 1,080,598 31 871,402 31 1,090,670 31 153,799 6 1,246,967 3O 749,378 31 1,089,518 31 7,430,982 7,115,160 1,2~1,472 2,275,741 2,727,957 2,791,476 2,551,632 1,790,980 1,767,557 6,174,166 5,618,096 3,53O,342 5,273,083 3,169,181 3,942,403 1,968,753 2,653,403 102,640 597,32'1 6,409,296 1,388,876 294,742,9'15 233,327,280 207,759,340 231,764,932 218,694,647 304,044,302 33,033,842 170,911,513 111,413,676 - - ENHANCED RECOVERY - - WELL NAME AND NUMBER ARCO ALASKA INC SWANSON RIV UNIT 331-27 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL TRADING BAY, MICDLE KENAI C OIL POOL UNION OIL CO CF CALIFORNIA ADL-18751 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, MIDDLE KENAI O OIL POOL UNION OIL CO GF CALIFORNIA ADL-18731 TRADING BAY ST A-SRD-2 TRADING BAY ST A-19 UNIT OR LEASE TOTAL POOL TOTAL FIELD.TOTAL ALASKA INDIVIDUAL NELL PRODUCTION FOR MARCH, 1987 OIL(BBC} NTR(BBL) GAS(MCF} DAYS SWANSON RIVER UNIT SHUT-IN SHUT_iN-'"~. SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN 7,~30,982 7,430,982 CUM. OIL CUM. WATER b13,93~ 15,582,616 #,~98,82Z 6,267,061 7,3a8,684 21,618,136 CUM. GAS 28,263,659 ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.232 ARCO Alaska, Inc. 110500 SWANSON RIVER FIELD - UNIT 0519~4 December 1~86 I I1. WELL NO. I 1312-22 -J314-27 I I I I I' I · I Name of Operator Field and Pool Month and Year of Injection 2. API NUMBERI3. C14. FIELD~5. DAYS~ TUBING PRESSURE I CASING PRESSURE :DAILY AVERAGE IN~ECTIO~TOTAL MONTHLY INJECTION 50- I L~ & POOL I IN I ~ ~ I I Al CODE I OPER 16. MAXI7. AVERAGE:8. MAX;~. AVERAGE:lO. LIQUID Ill. GAS I SI I ~ PSI~ I PSIG ~ PSIG I PSIG I (BBL) ~ (MCF) ;___S~ 153-10147-00 I G I 772100 153-10154-00 I G I 772100 I - 133-101~6-00 I 0 I 772100 I - I I I I I I 133-10141-00 I 8 I 772100 I - I , I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 'I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 13. LIQUID I 14. GAS 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 1 ( MCF ) I · I I I I I I l I l .... | I I I I ...... I I II hereby certify~ that the forego~i:ng is true and correct to the best of my knowledge Si gned ......... Title --.Supervi~/New VentureS Compliance and Revenue Date Form 10-405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE I15. I I ' : Alasia Oil & Gas C I I I I I I I I ' I I I ' I TOTAL I 0 I 0 I I I 8ubmit in Dupli[ate ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.252 ARCO Alaska, Inc. 110500 Name o4 Operator 1. WELL NO. 514-4 525-4 -: 552-4 ~...~:~) 541-4 541-8 512-9 525-9 1412-10 J 521-9 I J I I I I I I SWANSON RIVER FIELD - UNIT 051950 Fi eld and Pool December 1986 Month and Year o4 Injection 2. API NUMBERIS. CI4. FIELD:5. DAYSJ TUBING PRESSURE I CASING PRESSURE JDAILY AVERAGE INJECTION 50- I LI & POOL I IN I I I I Al CODE I OPER 16. MAXi7. AVERAGE~8. MAXig. AVERAGEJlO. LIQUID J11. GAS I SI I I PSIG I. PSIG I PSIG I PSIG J (BBL) J (MCF) l___SI I J ...... i I ...... J i I 155-10104-00 lB I 772100 I 50 J5,500 I 5,015 12,500 I 1,560 I J 52,501 155-10106-00 IG I 772100 J 50 15,650 I '5,278 J5,250 I 1,976 I I 29,526 155-10107-00 IG I 772100 I 50 15,500 I 5,071 i 700 I 594 I I 24,058 155-10109-00 IG I 772100 I 50 :5,550 I 5,157 il,200 I 849 I I 29,951 155-I0120-00 IG I 772100 J 50 i5,500 I 4,882 11,400 I 1,548 I I 25,121 155-10125-00 IG .I 772100 J 50 iS,000 I 4,697 J2,850 i 1,267 I J 55,165 155-1'0126-00 iG I 772100 J 17 15,200 I 5,140 Jl,600 i 1,588 I I 25,550 155-10168-00 IG I 772100 J 0 I 0 I 0 J 0 I 0 J I 0 155-20206-00 IG I 772100 I 0 I 0 I 0 I 0 J 0 | I 0 155-10125-00 IG I 772100 I 50 15,540 I 5,150 ll,600 I 1,089 I I 20,970 I I I I I I I l 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 I I I I 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 I I I I I I I I I I I I I I I I I I I I ' I 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 l ' I I I I I I I I l I I I I I I I l ' I I I I I I I I I TOTAL MONTHLY INJECTION I I 15. LIQUID I 14, GAS I (BBL) I I (MCF) 975,018 885,785 721,155 898,524 695,626 I 1,054,878 I I 450,602 I I 0 1 I 0 1 I 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 I I I I I I I I I I I , , , , , , j J J i ! i I I i II hereby certify that thee 4or~~ is true and correct to the best of my knowledge i Sighid --~--~__~. '~ ...................... Z Super , New Ventures ~ompliance and Revenue ITi~le Date ........ Form 10-405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE 115. l I I I I ITOTAL I i I A .....,~,-' ~.~ l I I I- I I I I I I 0 I 6,288,655 I I Submit in Duplicate LEASE NO. I ENHANCED RECOVERYI COHP. DATE + ~- STATUS PRODUCT JAN FEB MAR ALASKA INDIVIDUAL WELL%0DUCTION FOR 1986 YEAR APR MAY JUN JUL AUI~ SEP OCT NOV TJFC TOTAL. ~,~~ SWANSON RIVER, HEHLOCK ARCO ALASKA INC SOLDOTNA CK UNIT ~14-4 AP[ 1~-10104-00 UNIT051950 0IL 08/15/60 HTR 1GINJ GAS 1055837 1026390 1189909 1165806 1228646 1211657 1237286 1288352 1303704 1123075 1022953 975018 13808633 291785545 SOLDOTNA CK UNIT ~2~-6 API l~-1010~-00 UNIT051950 0IL 06/01/61 NTR GINJ GAS 926806 895793 1014~89 1021315 1093847 1095934 1110742 1160265 1163222 986837 950909 885785 123059~2 2301687?5 SOLBOTNA ~[ UNiT 55P-~ API UNIT051950 0IL 06/05/60 NTR 1GINJ GAS 729520 694699 694'207 768554 848986 808639 853755 906429 908923 773879 755048 721133 9463572 205534815 AOLDOTNA CK UNIT . ~1-~ APT UNIT051950 OIL 0~/21/60 HTR 1GINJ GAS 964182 939897 1105310 1004702 1191630 1125433 1151894 1167267 1142663 989567 1047397 SOL~OTNA CK UNTT ~61-8 API UNIT051950 0IL 07/14/61 NTR 1GINJ GAS 772030 721011 855765 793562 858793 851801 877466 883419 861434 802083 790782 693626 9761772 217114264 SOLBOTNA CK UNIT ~]2-~' .APT UNIT051950 0IL 10/09/60 NTR 1GINJ GAS 1130860 1105246 1275468 1219~54 1266462 1242821 1268188 1~18592 1312222 1120413 1159677 105~878 1~45~281 3007843~5 SOL~OTNA CK UNIT 321-9 AP! 133-10125-00 UNIT051950 0IL 07/19/61 NTR 1GINJ GAS 787999 770786 941316 857121 839631 824009 839794 852454 865441 701038 637884 629091 9546564 31111753 SOLDOTNA CK UNIT 323-9 AP! 133-1012&-00 UNIT051950 0IL 07/17/61 HTR 1GINJ OAS 868162 887705 1037404 1002092 1041454 1027008 1054326 1103448 1110180 1002927 967125 430602 11532433 168143953 SOLOOTNA CK UNIT 412-10 AP! 133-2o20~-no 343-33 ~32-15 138887e.') AP1 133-10141-00 54-15 APl 133-10142-00 111415676 UNIT051950 OIL 06/11/72 HTR 1NINJ GAS SOLDOTNA CK UNIT UNIT051950 OIL 03/08/61 HTR IGINJ GAS SWANSON RIV UNIT UNIT051994 OIL 10/24/59 HTR 1GINJ GAS SWANSON R[V UNIT UNIT051994 0IL 08/04/61 HTR 1GINJ GAS q018Z06 9029539 2056925 ~643530 III 4 + LEASE NO. I ENHANCED RECOVERYI COMP.DATE ~ + STATUS PRODUCT JAN FER MAR ~~ SHANSON RIVER, HEMLOCK SHANSON RIV UNIT 512-22 API UN~TOSlgg~ O~L ALASKA INDIVIDUAL HELL~ODUCTION FOR 1986 'APR MAY JUN JUL AUfi SEP OCT NOV DFC 15~-101~7-00 YEAR TOTA[ CUM_ 08/11/62 HTR 1GINJ GAS SWANSON RIV UNIT UNITOSIgg4 OIL 514-27 API 155-10154-00 873988 24017269 06/14/60 HTR 1GINJ GAS SWANSON RIV UNIT UNIT051994 OIL 531-27 API 155-10156-00 7855117S 02/17/58 HTR 1GINJ GAS - ARCO ALASKA TNC OPERATOR 0IL 28265( TOTALS WATER 8,557,995 POOL TOTALS GAS 7,0ql,527 7,852,406 8,187,302 8,680,226 7,q99,819 6,288,655 1,gzg,I87,01Z 7,215,596 8,115,868 8,$69,q49 8,595,451 8,667,789 7,511,775 95,601,665 SWANSON RIVFR. HEMLOCK OIL HATER 8,537,995 FIELD GAS 7,041,527 7,652,~06 8,187,502 8,680,226 7,499,819 6,288,655 1,929,187,012 7,215,596 8,115,868 8,569,449 8,$95,45! 8,667,789 7,511,775 95,601,665 SWANSON RIVER TOTALS OIL HATER 8,557,995 GAS 7,0~1,527 7,852,406 ~,187,502 8,680,226 7,499,819 6,288,655 1,929,187,0)' 7,215,596 8,115,868 8,$69,q49 8,$95,451 8,667,789 7,511,775 95,601,665 SWANSON RIVER WELL TYPE ~l I~JBo ___ SRU 312-22 Gas Injector _-~ 81 --SRU 314-27 Gas Injector 5~ 'r/Sf ~.~ SRU 331-2-7 Gas Injector ~S-CU 323-4 Gas Injector ..SCU 332-4 Gas Injector ~SCU 341-4 Gas Injector ~ SCU 341-8 Gas Injector ~SCU 312-9 Gas Injector ,SCU 321-9 Gas Injector ~ SCU 323-9 Gas Injector 5I /~/~ -SRU 432-1.5 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 Cons. Commission Anchorage t"l CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, Inc. :l Post Office BOx 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 $CU 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 +100 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. Inc ~s a Subsidiary of AtlantlcRichfieldCompaf~y Form 3160--5 (November 1983) (Formerly 9--331) U' lED STATES sUm.,T m Ta~'~'~&~· (Other Instruetio. ,n re- DEPARTMENT OF THE INTERIOR ,erse.~d,) 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 a did, rent reservoir. Us~ ,'APPLICATION FOR PERMIT--*' for ouch propo~alt) WELL WELL OTHER 2. NAME OF OPERATES ARCO Alaska, Inc. 3. ADDaEBB Or OPmRATOu P.O. Box 100360, Anchorage, AK 99510 4. LOCATION Or %VELL (Report location clearly and In accordance with any 8tote requirement].* See also space 17 below.) At surface Soldotna Creek Unit - 7 wells 14. PZitMIT t~o. ELEVATIONS (Show whether DF, R,. OR. etc.) Form approved. Budget Bureau No, 1004-0135 Expires August 31, 1985 5. LSABB DSSIONATION AND IlltiL I~O. 6. Ir INDIAN, ALLOt'TaB OR T~IBB NAME UNIT AORBBMSHT NA~fB Soldotna Creek Unit 8. fAIM OR LSAeB NAMR g. WBLL l(O. 10. fIELD AND POOL; OI WILDCAT Swanson Rivmr Fimld mUBVBY OB AIBA Sec. 4, 9, T7N, R9W Kenai I Alaska 1§. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICB OF INTaNTION TO: FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZm ABANDON* REPAIR WELL CHANGE PLAN~ RUBRB(JUBNT uulq)u~ O~: WATER SHUT-OFf ~ RmI~AIRINO WaLL IPBACTUEB TUgATMBNT . ALTERINO CASINO 8HOOTINO OR ACIDlZlNO ABANDONMBNT® (Other) (NOTE: Report results of multiple eompleUon on Well (Other) X Pressure Test Completion or Recompletion Report and Log form.) lT. ~ES¢'it'.l;~ I'ROPOSED OB COMPLETED 0PERATION~ (Clearly state all pertine,t details, and give pertinent dates. Including estimated date of starting an$ proposed work. If well is directionally drilled, giVe subsurface locations and measured and true vertical depths for all markers and stones peril- neat to ~is 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 JUN-'-'":,..., !9~."/' Alaska Oil & Gas Cons, Commission Anchorage, 1 .~. I hereby certify ,~.hat the foregf~ng is tr~e and correct Regional Engineer TITLE (This space for Federal or State office use) APPROVED BY CONDITIONI!t OlV APPROVAL, IF ANY: TITLE DA~A *See Instructions on Reverse 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 ~_:.~a c,o,o. .... f.l~o_ .qctitious or fraudulent statements or representations as to any matter within its jurisdiction. SCU 332-4 LOAD PRODUCTION AND SURFACE CASIN.~!,:~ Oii& Oas C(~s. AND PRESSURE TEST PRODUCTION CASING Loadin9 PC and SC Annulus 1. Record pressures on the tubing, production casing and surface casing. 2. Blow down PC to'lO00 psi, recording all pressures. 3. Blow down SC, recording all pressures. 4~ Shoot fluid levels for pump-in volumetrics. Estimated volumes from most recent fluid level data are noted below. Be 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. e Load PC with lease crude. Do not exceed 2500 psi during pump-in. Do not bleed PC below lO00 psi during pump-in. Pressure Testin0 Production CasinO 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. e ge 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 Step i. 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 3800 psi is reached. Hold pressure for 30 minutes, noting initial and final pressure on all strings. Volumetrics Surface Casing Production Casing Fluid Level (3/11/87) Annular Capacity (bbls/ft) Estimated Fluid to surface (bbls 4572' .0103 47 56' .0464 3 CHLVI'(LIi~I U.S.A. INt~. · TRANSMXTTA'/"~"x) ACKNOI~rLEDGEMENT OF RECEIPT "'~'J~TER~AL - (ALASKA) DATE THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. FD- Folded R - Rolled S - Sepia - Film X - Xerox B - Blueline PLEASE CHECK ANDADVISE IMMEDIATELY. glq-q ,-/ ! RECEIVED 8Y Chevron Chevron U.S.A. Inc. July 20, ]984 Alaska Oil & Gas Consv. Comm. 3001 Porcupine Drive Anchorage, AK. 99501 Gentlemen: Enclosed for your records are well histories for SCU 12A-3 and SCU 2~9/321-9. Sincerely, 100 Years Helping to Create the Future STATE OF ALASKA ~ ALASKA . AND GAS CONSERVATION cO,,.MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. CHEVRON U.S.A., Inc. 61-020 3. Address 8. APl Number P.O. Box 107839 Anchorage, Alaska 99510 50- 133-10125-00 4. Location of Well OTHER [] 9. Unit or Lease Name Soldotna Creek Unit 530' S & 1890' E of the N.W. corner Section 9, T7N, R9W, S. B & M 5. Elevation in feet (indicate KB, DF, etc.) 142' KB 6. Lease Designation and Serial No. A-028997 10. Well Number SCU 21-9/SCU 321-9 11. Field and Pool Swanson River-Hemlock 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing r-~ Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other J~ Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Convert to gas injector 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See attached RECEIVED MAY 1 5 1984 Cid ~ ~.;:~ Cons. Commission Ancl~,or~g9 14. I hereby ce~,~y that~he~rrect to the best of my knowledge. SignedK(~, ~ Title Area F. ng±neer The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 Rev. 7-1-80 1. Pulled gas lift dummy valve at 10217'. Filled annulus with produced water. 2. Moved in and rigged up Brinkerhoff Signal rig #58 on 3/15/84. 3. Killed well with 10.1 ppg lignosulfonate mud. Set BPV. 4. Removed tree. Installed and tested Class III BOPE to 5,000 psi. 5. Recovered 2 7/8" X 2 3/8" production string and packers. 6. Ran 7" casing scraper. Pressure tested 7" casing to 3,000 psi. 7. Ran Gearhart GR/CCL log from 10601' to 9713'. 8. Set Baker model "D" packer with drillpipe at 10587'. 9. Ran in hole and landed 3½" X 2 3/8" injection string and packers. 10. Removed BOPE and found worn tubing head. 11. Installed and tested Class III BOPE to 5,000 psi. 12. Pulled up on tubing and replaced one joint of tubing with Baker retrievematic packer and "F" nipple with plug in place. 13. Set packer at 25'. Backed out of packer and removed BOPE and damaged tubing head. 14. Installed and tested new tubing head to 3,000 psi. Installed and tested BOPE to 5,000 psi. 15. Released and pulled packer, reinstalled one joint of tubing and landed tubing. 16. Changed over hole fluid to lease crude. 17. Ran and set Otis pos. 1 plug in "S" nipple at 10493. Pressured up tubing and set packers. Removed plug. 18. Released rig 4/1/84. 19. Placed well on continuous gas injection 4/17/84 (SCU 21-9 - redesignated as SCU 321-9)~ R C IVED MAY 1 5 1984 - "r" ~,9 ~~, ~ t~ /~cr/o~ ~~A~ ~_ ~ ~-~ : .... .. ~(~ ~.~ ., - . ..... ~ .~...~/ . e I ..~/ eeel · · ~I ....-'~'. . ~ .....;~ ..;.~[~~ ~ 0 7 1084 "~>' Alaska Oil & Gaa Cons, Commission ~" ' ~ Anchorag~ ! REVS~ ~ SCALE ~"~ ~' DATE ~'~' ~ ~~~~ ~~~ ~~~ DR ~ CH . DR,APP .. EN6 OPR6, D(PT, ~ APPROVED GO*580-A (2M-CD-Il-70) TRANSMIT: .AD ACKNO~qLEDGEMENT OF RECEIP _ MATERIAL- (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. -- . ' Ill I I I / · , ,' .-' x~::.~¢:..;V%~~u: ti~': , ..:::'~,:,-x:..,' "~' :; ~. . . ~k]~iJ?~ ::; Oz-4 ~'~'?~[[' ~ S~:~>~[ ~ ":~'~L~ ~H(.~-'~, ~' ,~}-:;3: '" ~:'..,.:', '~'~; :, ':{5 TRANSMITT,,~ ,~ND ACKNONqoEDGEMENT OF RECEIP~ ,,, ~bNTERI~ - (AL~) ~~z~ ~~~ DATE ~~: ~~~(- ~~ ~- Blueline ~.. Sepia ~ FOL~WING IS A LIST OF ~TER$~ ENCLOS~ HE~IN. PL~E CHECK ~D ~VISE I~DIATELY. ..~ RUNS ~.[. F ,FILM S,SEPIA ' I ' I 2 · 4 S.e* .WELL .LOGS ~" S' 2"., lDO II~. 200: =.. )UAL INDUCT,O. ,T. [;~ ~ ~ ...... [OVAL INOUCTION FOCUS[O LOG .' ...... I "' WEL~U~- ( D..~ ,.~.c,,.. L,,,,,~o~ ............. ~UAL DETECTOR N[UTROm qW ,L ' ............ ': ........... SEC 'T ,R. :so,,.ot~ co,,,,,,~o s.,,~ ' ~O~EHOL[ COM~. SONIC ~DM POLYWO. P,.OT... - -- -- i , BONO boo · ~A~NO CO~AN P~nrORAtlNO ~o~c~N ~oG ........ :o~a oe';JA'b~A&*~A~ ................. L TIE IN roi GyRO ......... [~SATED D[NSl/NEUTNON/GR .......... :OM~E NIATEO OINIIkOG~ ................ *COMPENSATED FOaMATION DENSITY... COMPENSATED ~EUT~ON FOaMATION OEN.I .... ~ ~ " ; C~PUT/N PROCESSED · OMF~EN PnOCESS~D LDO (CYOERLOOK)~ 'DSTNDT . . ~. ,, ~ ~ ,! . Il ! I · I i · ! · I ! e ! ! ..I I ! Ii iIle ii FLOMgT[N ...... .. , .......... ... ........ FO~AT,O~ T.T~ ....................... - ' ~ ,, FORMATION ANALYSIS LDO , LOCATIOH PLAT ;GAMMA RAY PERMIT TO-DRILL I~O1 AMMA ~AY ~~ '" ~$UNORY NOTICE 10~4.. I,OUCTIO, [~ICTRICAL 'LOrn ...... MONTHLY NOTICE P,4 ~ATEROkOg ''~ -- ,, i ! II e e, e cl..lee eee ee e · · . MICRO LOI ..... CO~E OA~A .' M~cNo~xr[N~gj ...... ................... " "-~,,~ '~:o~' 'L'; , SARABAND LISTIflG NEUTROH c~$~ ~ BOT. HOLE PRESS ' ~o.ol~ [~'" ...................... APPUfl DPN. or ABAN PnO~tL[ CALIPER. ' . D~ SU~.GYRO MU~ PRO~MITY MICROL~ .................. '" . ~ ~w. Co.N.,.o. p~-:::':: DRC. ~UR. GYRO SAnAIANO .. ' _co.ouc~o~ ,.,~,: iso... L.. :: 7: :: :'. :.:.:.:.. :.:: :"~~ ~1N G'~:~: SONIC . ..... CLusT~ U - ~,,=(~F44;G; ~/'" ........ PRO~ED PROGRAM ISID[WAk~ N~uT~oNPo~oslTY -- ~---- .il m m ~ , m '~PECTRAkOG ._.~ ~ ~. ,. ~[MPERATURE ' ' · ·-COMPLETION REPORT .TDT'M - :, ~vo o,j ~'~W~';~';;~.% ......... ~ ~' ..... ~WLS - '-- Loos ~ BH~ FO CNFO i RECEIVED BY ~O~ ~.S~ ~C. - ~x 7~3g ~EMARKS A~a~~ G~.~sT~~ A~ORAGE, A~SKA ~5~0 Anchorage Chevron .o. o U.SA Inc..-: _ 107839, Anchorage, AK 99510. Phone(g07)786-6600 ~~tion PRODUCTION ANCHORAGE' Swanson River Field Mr. Bob Delany Refuge Manager Kenai National Moose Range U.S. Department of Interior Fish and Wildlife Service P. O. Box 2139 Soldotna, Alaska 99669 Dear Mr. Delaney: Chevron U.S.A. Inc., as operator of the Swanson River Field, proposes to convert well SCU 21-9 to gas injection service. This requires the installation of approximately 500u of high pressure injection lateral from the main injection line to the edge of the existing well location. The proposed routing is thru the burn area so the clearing of trees will not be required. Please refer to the attached drawing AP-A-238. Mr. Richey of your office and our Mr. C. W. Wilson discussed the following items in a telephone conversation on March 19, 1984: . . . Ac,ess to the main line tie-in point shall be along the main pipeline right-of-way from the south road only. Pipe shall have a minimum of 42" cover. Disturbance shall be kept to a minimum. Work between main line and edge of location shall be completed' before the ground thaws. Work is scheduled to begin on March 26 and should be completed in three days. Pipeline route to follow ridge. We request your early approval for this project. Very truly yours, T. L. Perryman :WFS:eh Attachment By: Date: RECEIVED 0 ]984 Alaska 0il & ~as Cons, Commission Ancf~oragt~, ,.~ STATE OF ALASKA ~ ALASK IL AND GAS CONSERVATION c..MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 61-020 3. Address' 8. APl Number P. O. Box 107839, Anchorage, Alaska 99510 50-133-10125-00 4. Location of Well OTHER [] 530' S & 1890' E of the N.W. Cor., Sec. 9, T7N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) _ 142' K.B. 6. Lease Designation and Serial No. A-028997 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 21-9/SClJ 321-9 11. Field and Pool Swanson River - Hemlock 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] '- Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] ~] Other :~] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all Pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See attached procedure. Subsequ~t Work Bevortecl . ., This work will be done on or about March 1, 1984 J ECEIVED FEB 2 i i984 Alacka 0ii & Gas Cons. Commission A Signed ;~' ~~ Title Area Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by. Returne~t 8¥ Order of CO~ ISSIONI::R the Commission Form 10-403 Rev. 7-1-80 Submit "1 ntentions" in Triplicate and "Subsequent Reports" in Duplicate SCU 21-9 CONVERSION PROGRAM . 3. 4. 5. ® ® . . 10. 11. 12. 13. 14. 15. 16. 17. Prior to moving in workover rig fill annulus with produced water and pull dummy out of the mandrel at 10217'. Move in and rig up workover rig. Kill well using 72-73 pcf mud as detailed in attached workover fluid program. Install Cossasco plug and remove tree. Install Class ~I BOPE and test to 5000 psi. Remove Cossasco plug. Recover 2 7/8" x 2 3/8" tubing and production equipment as per attached tubing detail. Visually inspect all tubing and equipment for damage and note any erosion or irregularities. Pull tubing slowly to minimize swabbing. Clean and test all mandrels and install CEV valves in all mandrels. Run 7" esg. scraper to top of liner. Run 7" 29# packer and set just above liner. psi. Pressure test 7" easing to 3000 Clean out well to 10,700' or as deep as possible. Run tandem 5~" 20# casing scrapers to 10660'. Circulate well clean. Run gamma ray - collar log from PBTD to top of liner. Run 5~" Baker model "D" packer on wireline and set in blank between 10582' and 10598'. Tie into collars correlated between GR-CCL and original DIL. Setting depth is critical. Run 33" x 2 3/8" tubing with Atlas Bradford Modified ABC couplings as per the attached "Proposed tubing detail." Hydrotest all tubing and couplings to 5000 psi. Note: the original 2 3/8" Camco MM mandrels will be used if they tested good, otherwise run 2 3/8" Camco KBUG mandrels in their place. Ail mandrels except the lower most at +10550' to have CEV's in place. Mandrel at +10550' to be run empty. Stab tubing into Baker model "D" packer and land tubing using modified hanger as shown in attached wellhead diagram (figure 4). Install Cossasco plug and remove BOPE. Install 10,000 psi injection tree as shown in attached wellhead dlagrarfl~.; (figure 4). Test tree to 6500 psi. Remove Cossasco plug and displace mud with lease etude through mandrel a~ ~-~ +10550'. · SCU 21-~ Conversion Program 18. 19. 20. 21. 22. Place a CEV in mandrel at +10550'. Run and set a C.A. plug in Cameo "D" nipple at +10590'. Pressure up tubing and set hydraulic packers. Remove C.A. plUg and release rig. Produce well from lower zone as directed by area foreman until the well cleans up. Supplementary program will be written if well will not flow. Pull valves from mandrels at +10550', +10420, and +10335' one at a time and clean up each zone separately. =~edesignate Well as $CU 321-9.1 Place well on injection as directed by area foreman. Advise Anchorage engineering of injection rates. Flow meter and injeetivity test to be run after injection has stabilized. J. B. LOGAN RECEIVED FEB 2 1 1984 AI~c~ Oil & Gas Cons. Commi~ion SCU 21-9 CONVERSION PROGRAM e 3. 4. 5. 6. . . . 11. 12. 13. 14. Prior to moving in workover rig fill annulus with produced water and pull dummy out of the mandrel at 10217'. Move in and rig up workover rig. Kill well using 72-73 pef mud as detailed in attached workover fluid program. Install Cossaseo plug and remove tree. Install Class III BOPE and test to 5000 psi. Remove Cossaseo plug. Recover 2 7/8" x 2 3/8" tubing and production equipment as per attached tubing detail. Visually inspect all tubing and equipment for damage and note any erosion or irregularities. Pull tubing slowly to minimize swabbing. Clean and test all mandrels and install CEV valves in all mandrels. Run 7" csg. scraper to top of liner. Run 7" 29# packer and set just above liner. Pressure test 7" easing to 3000 psi. Clean out well to 10,700' or as deep as possible. Run tandem 53" 20# easing scrapers to 10660'. Circulate well clean. Run gamma ray - collar log from PBTD to top of liner. Run 5~" Baker model "D" packer on wireline and set in blank between 10582' and 10598'. Tie into collars correlated between GR-CCL and original DIL. · Setting depth is critical. Run 3~" x 2 3/8" tubing with Atlas Bradford Modified ABC couplings as per the attached "Proposed tubing detail." Hydrotest all tubing and couplings to 5000 psi. Note.- the original 2 3/8" Cameo MM mandrels will be used if they tested good, otherwise run 2 3/8" Cameo KBUG mandrels in their place. All mandrels except the lower most at +10550' to have CEV's in place. Mandrel at +10550' to be run empty. Stab tubing into Baker model "D" packer and land tubing using modified hanger as shown in attached wellhead diagram (figure 4). 15. Install Cossaseo plug and remove BOPE. 16. 17. InstaU 10,000 psi injection tree as shown in attached wellhead diagram (figure 4). Test tree to 6500 psi. Remove Cossaseo plug and displace mud with lease crude through mandrel at +10550'. SCU 21-9 Conversion Program 18. 19. 20. 21. 22. Place a CEV in mandrel at _+10550'. Run and set a C.A. plug in Cameo "D" nipple at +_10590'. Pressure up tubing and set hydraulic packers. Remove C.A. plug and release rig. Produce well from lower zone as directed by area foreman until the well cleans up. Supplementary program will be written if well will not flow. PuU valves from mandrels at +10550', +10420, and +_10335' one at a time and clean up each zone separately. Redesignate well as SCU 321~9. Place well on injection as directed by area foreman. AdviSe Anchorage engineering of injection rates. Flow meter and injectivity test to be run after injection has stabilized. J. B. LOGAN February 16, 19 83 Chevron U.S.A. Inc. P.O. Box 7-839 .Anchorage, Alaska 99510' . . Re:. ~ubsequent Reports, Sundry Notices and Reports on Wells (Form 10-403 } For the following lists of "Notice of Intention Tot" Sundry }~otices and Report on Wells (form I0-403} this office does not have on record the "Subsequent Report of:" defining the -action taken on the approved intention. Please advise this office by Subsequent Report of the disposition of the intention. Well '-,': Chevron Date Brief DescriPtion of Inte_ntion Jeanette Is. 1 SRU 23-27 · · SRU 24-33 . . SCU 21-4A ~. SCU 13-34 SCU 14-34 SCU 21-9 1/13/82 5/7/82 5/'7/~2 8/5/82 8/5/8,2 8/5/82 Brier description Clean out scale plug Clean out scale plug Reperforate Isolate leak in H-"3-4#. interval Return H1 and H2 to production ~ Clean out.. fill in tub!~ng LCS lJKT Ig lh T~RANSMITTAL , ACKNOWLEDGEMENT OF RECEIPT 0 kTERIAL -'(ALASKA) THE FOLLOWING IS A. LIST .OF MATERIAL ENCLOSED HEREIN. FD - Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline PLEASE CHECK AND ADVISE IMMEDIATELY. _ :,¥:..? ~.- .. : (?_. -~':,.:'RECEIVED BY ~ON U.S.A. INC. BOX 7.839 REMARKS ON OTHER SIDE, THIS SHE'ET ANCHORAGE, ALASKA 99510 STATE OF ALASKA .~ ALASKA OIL AND GAS CONSERVATION CC,,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 3. Address - P. O. Box 107839, Anchorage, Alaska 99510 4. Location of Well 660' S & 1980' E of the NE Cor., Sec. 9, T7N, R9W, S. B&M 5. Elevation in feet (indicate KB, DF, etc.) I6, Lease Designation and Serial No. 142 ' KB A-028997 8. APl Number 50- OTHER 9. UnitorLeaseName Soldotna Creek Un±t 12. 10. Well Number SCU 21-9 11. Field and Pool Swanson River Field Check Appropriate Box To IndiCate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 1. Coiled tubing unit cleaned out tubing to the top of the plug at 10584'. 2. Several attempts were made to pull the plug at 10584'. All attempts failed. This job was suspended on 12-21-82. No further work is planned. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of Approval, if any: Date Date By Order of Approved by COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA '~ ALASK/~OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S,A. Inc. 3. Address 8. APl Number P. O. Box 107839, Anchorage, Alaska 99510 50- 4. Location of Well 660' S & 1980' E of the NE Cor., Sec. 9, T7N, R9W, S. B&M 5. Elevation in feet (indicate KB, DF, etc.) 142 ' KB 6. Lease Designation and Serial No. A-028997 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 21-9 11. Field and Pool Swanson River Field 12. (Submit in Triplicate) Perforate [] Alter Casing [] , Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 1. Coiled tubing unit cleaned out tubing to the top of the plug at 10584'. 2. Several attempts were made to pull the plug at 10584'. All attempts failed. This job was suspended on 12-21-82. No further work is planned. 14. I hereby certify that the foregoing is true and correct to the best 'of my knowledge. The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate /",.? STATE OF ALASKA ~ ALASKA ~,,L AND GAS CONSERVATION cC,,IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Chevron U. S.A. Inc. 3. Address 8. APl Number P. O. Box 7-839, Anch, Ak. 99510 50- 4. Location of Well 660'S 1980'E of the N.E. Cor., Sec. 9, T7N,R9W,S.M. 5. Elevation in feet (indicate KB, DF, etc.) -- 19'KB 12. I 6. Lease Designation and Serial No, A-028997 9, Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 21-9 11. Field and Pool Swanson River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ', Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] ' Repairs Made [] Other Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed to perform the attached procedure on Well SCU 21-9. RECEIVED AUG - 6 1982 Alaska 0il & (;as Cons. Commission Anchorage 14' I hereb~~t~t~i )re, g°ing is true and c°rrect t° the best °f mY kn°w-ledge' Signed /~ Iyv- V ~,/~ Title Area Engineer The space jbe~w for Comm ission/se Condition!~df Approval, if any: ~ Approved Copy Returned By Order of A..ro~ BY LO~IIE ~. S~IT8 COmMiSSiONER th~ Date 8/5/82 Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate CHEVRON U.S.A. INC. WESTERN REGION ALASKA AREA WELLWORK PROCEDURE SUMMARY WELL' -~ - FIELD' .~ co~,.~_~ ~,~ JOB NO' ORIGINAL SUMMARY OBJECTIVE' ~ ~'e~ ~ ~-~. ~~..,~.~.. TYPE WELL' ~ro~., ce r~ - O,'{ TYPE JOB' SUPPLEMENTAL SUMMARY O NO. WELL DATA' PROGRAM K.B. /~ CASING' "7 ee,,,r~ ~7 PERFORATIONS' ECEiVE] DETAILS ATTACHED Dist,ributlon: Original to Well File W.D. Sauer (3) Field Offlce(I) Preparer (I) D.M. Wilson(I) AUG - 6 i982 Alaska 0ii & Gas Cons. Commission - Prepored by~nchorape Dete ., ,,e_ .. ,~~Pr,0ved, ~y __ /0,522.44 --/0,$4-4. ~$ . ,~,,,a, ~ ~2~ --lO,~ZO. 19 - CA S/Na ' TUX3//F~ O~TAIZ /~'z~ ~ ~ 8~o~vN ~x~~/~ _ . o, I~424~9 - ~ 'BROWW CC 6'APETY J~ .... ' ~ /o,~o~.~ ~ :'-' 745' TO T~ Z 251 JTd. I8 JT'.. 2:~" ,~'(_./z' 7z,.',~//vG. OT/S s H/PPL~ PO~lT/O~ *~_ L ~0' PUP d~ 2~b"~UE T~/~/~G /O. fS' ~MP JT Z~5' ~ME TU~/~G ..... fO./2' CAMCO ~A~ ~HD, qE~ ....... /5. 24' PUp J~ Z ~b" ~ TU~I~G _ _ ~. 0 O' I d~ 2~b" ZUE TU~t~Q 5L ~' ~ PUP J T~. ~6" ~U~ T~lNG 12. ~ 7523. I, 52' ~ ?,9~' 15.20' 29. lO' G. I~" ,_ KB. TO ZAA/DilV~ F£ANGE /9. ZO' L AA/OI,'VG' FL A zVG,E' 2:40' 5'..~ *,JT~,. Z ~.,~" £U£ T(./,,~/,'VG .... ,. t.'.r,.u P. 7 ~ '~ SUBMIT IN D~ .,. !CATE* STATE OF ALASKA '~See other st ructions on OIL AND GAS CONSERVATION COMMITTEE ~,,~,.~ ii i i i i i WEL~ cOMPLETION OR RECOMPLETION REPORT AND LOG* ii i ~ ii Other WELL WELL b, TYPE OF COMPLE~ON: XV ELI. OVER EN BACK nESVR. Other ~ ,, 2. NAME OF OPERATOR 3. ADDRESS OF OPERATOR ..... ' 4. LOC^'rION Or WELL -('Report location clearly and in accordance with a~.y State requirements)* At surface At top prod. interval reported below At total depth ]-]~O~,V MANY* ROTARY TOOLS {0700 22. PRODUCING !NT~ERVAL(S), OF ~-IIS COMPLETIOn--TOP, BOTTOM, NAME (MD AND r -s. API NUMERICA~ CODE 6. LEASE DESIGNATION AND SERIAL NO. 7, IF INDIA.N, ALLOTTEE OR TRIBE NA_IVL~ 8. UNIT,FAH.M OR LEASE NAME 9, WI~LL NO. 10. FIELD AND POOL, OR WILDCA. T 11. SEC., T., R., M., (BOTTOM HOLE OJaJECTIVE) 12. PEHaMIT NO. ! RT, GR, ETC)* ]17. EL`EV. CASINGHEAD ! INTERVALS DRILLED BY CABI,E TOOLS 23. WAS DIRECTIONAL SURVEY MADE 24. TYPE ELECTRIC AND OTHIEi~ LOGS ;RUN __ CASING RECORD (Report all strings set in we'll) CASI~4G SIZE WEIGHT, LB/FT, ,,,,, , , 28'. '~E~O~.ATIO~S ~P~ TO P~O~U~O~ ' (interval, Si~ze and ..... ~;r) ii iiiii i ii i 27. ~UBING HECO?,~D SCi~EEN (A~.D) SIZE DEPTH SET (IV~D) ~ PACKER SET (MD) } 29. 'ACID, si:aT, I.;'i~ACX ORE, CF.'",IENT SQUEEZe, T ', DEPTIi I~TF_~V.~L (MD) £~M©UN£ ~'~ND I(!ND OF MATE~.IAL USED 30. PRODUCTION DATE FIRST Pt%ODUCTION [ ~ODUCT1ON MEIIiOD (Flowii]g, [las lif~, pamping--size and type of pump~ CttOXE SIZE ]PEOD'N FO,~ OI~BBL. G~k~CF. 31. DISPOSXTION Or GAS (SOld, u$ed Ior fueZ, vented, etc.) [ 32~ LiST 0~" AT~kCHMENTS ' A)/IOUNT PULLED "' [Iq'ELL STATUS (Producing or :3nuL-in) ] VtATER--BBL. ] GAS-OIL II.%-TIO WATER--BBL. I O1L GRAVITY-A/~I (CO1R. R. ) I ,, , ~ .: ..... ITEST WITNESS~-D BY 33. I hereby certify that the'foregoing and attached information is comPlete and correct as determined fror6 all-available records ' 7;t'?fe ..... *(See Instructions and Spaces for Additional Data on Reverse S/de) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end Io9 on all types of lan:Is and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- mentsgiven in ether spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate, production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prcJucir~g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interv~l reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additior~al interval to be seperately produceJ, show- ing the ackjitional data pertinent to s. Uch interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location, of the cementing tool. Item 28: Submit a separate complelion report on this forrn for each interval to be separately produced. (See instruction for items 20 and 22 above). U~MAI{Y OF PORMATION TESTS INCLUI)IN(: 'INTEFCVAL, T~'TED, PRE~URE DATA ~'~COVERI~ OF O1~'. GAS, a~. G~GIC MA~K~ WAT~ AND MUD '}:O~E DATA. Aq'I*AcI'I. ..... , ..... COMPLETION REPORT - NEW WELL STA~NDARD 0IL cOMPANY OF CALIF.O. RNIA.. -...WES. TE..RN .OPERATIONS,. INC. - OpF_~.. TOR AREA: Kenai Peninsula, Cook Inlet Area, Alaska PROPERTY: Soldotna Creek Unit LAND OFFICE: Anchorage T,W~SE NO.: A-028997 WELL NO.: SCU 21-9 SECTION: 9, T. 7 N., R. 9 W., Seward B & M. LOCATION: Surface: 530' south and 1890' east from northwest corner Section 9 (P~roJ.) T. 7 N., R. 9 W., Seward B & M. ELEVATION: 142' K.B. K.B. is 19.2' above ground. October 19, 1961 BY: C,.V, C.HATTERTON C. V. CHATTERTON, District Superintendent DRILLED BY: Rowan Drilling COmpany (Rig ~29) DATE COMMENCED DRILI~NG: May 18, 1961 DATE COMPLETED DRILLING: July 19, 1961 DATE OF INITIAL PRODUCTION: July 22' 1961 Daily Average ?84 B/,D Flowing Oil .......... 776 B/_D Gravity ....... 36.3° Water ....... . 8 B/D TP, ........... 1670~ Gas 175 MCF/D Bean 11/64" . e.e.e., e. PRODUCTION: SUMMARY TOTAL DEPTH: 10,745' PLUGS: 10,700- 10,745' JUNK: NONE CASING: 20" conductor pipe cemented at 37'. 11 3/4" casing Cemented at 2,010' w/1275 sacks cement. 7" casing cemented at 10,272' in two stages w/1800 sacks 1,030' of 5~" liner '.hung at 10,743'· Top at 9713' , cemented w/lO0 sacks in single stage around shoe and 50 sacks squeezed from above lap. COMPLETION REPORT o PACKER INSTALIATION il il i .... _ ~ , .... ,,,, i , STANDARD OIL COMPANY OF cALIFORNIA - ~STERN.~ OPEPA...TIONS. ~ INC. AREA: Keuai Peninsula, Cook Inlet Area, Alaska PROPERTY: Soldotna Creek Unit LAND OFFICE: Anchorage LEASE NO.: A-O289gl WELL NO.: SCU 21-9 Section 9, Township 7 North, Range 9 West Seward B&M. LOCATION: Surface: 530' South and 1890' East from Northwest Corner of Section 9 (ProJ.)T. 7 N., R. 9 W., Seward B & M. ELEVATION: 142' K.B. DATE: April 2, 1963 CONTRACTOR: Santa Fe Drilling Company, Rig DATE COMMENC~ REMED~ WOt~f: October 13, 1962 DATE COMPLETED REMEDIAL WO~: October 17, 1962 , , i · "'11 ",,i ' 11 i , ,,1 , , TOTAL DEPTH: 10,745 ' PLUGS: 10,700- 10,745' CASING: 20" cemented at 37' 11 3/4" cemented at 2010' 7" cemented at 10,272' 1,030' of 5½" liner cemented at 10,743'. Top at 9713'. PERFOPATIONS: As before. AREAs Svanson River Field COMPLE'TION REPGRT LANO OFFICE: Anchorage PROPERTY.' Soldol:na Creek Unit LEASE NO~ A-028997 WELL NO~ scu 2l-9/scu 321-9 AP! NOI 50-133-10125-00 LOCATION AT SURFACE= S30' S & 1890' E from ~he Nt~ Cor., Section 9, TTN, '" R9'~, S.N. LOCATION AT TOTAL DEPTH= Same ELEVATION; 142' K.B. DATE: 4/8~ WORK PERFORMED BY., Brinkerhoff signal Inc., DATE COMMENCED WORKs /.. DATE COMPLETED WORKs ~/]./8~ ~(~laCed on gas injection as SCU 321-9 on (See attached Su~at-y.) ,RECEIVED WELL SCU 21-9/SCU 321-9 SUMMARY TOTAL DEPTH: 10,745' CASING: 20" at 37' 11 3/4" at 2010' 7" at 10272' 5~" 9713' - 10743' PERFORATIONS: 10,294'- 10,304' 10,324'- 10,352' 10,364'- 10,375' 10,388'- 10,450' 10,474'- 10,582' 10,598'- 10,659' 'JUNK: WSO 10,288' (squeezed) WSO 10,294' WSO 10,659' WSO 10,661' 21.75' of W.L. fish last tagged in mandrel at 10541'. However, fish may have been blown out bottom of tubing. 12' of 1~" W.L. tools previously lost in hole below tubing. Rope socket, 2 - 3' long stems, I - 2' long stem, knuckle it., oil jars, + 20" stroke, spang jars. 6.71' 4 3/8" swage and extension 6' seal assembly PLUG: 10,745'- 10,700' RECEIVED JUL 2 0 1984 Alaska Oil & Gas Cons. Commission Anchorage 3/15/8¢ Accepted Brinkerhoff Signal Inc. Rig #58 at 10:30 a.m. Rigged up to circulate through X-mas tree. Initial tubing pressure was 3700 psi and casing pressure was 1800 psi. After bleeding the well down for three hours the casing pressure was 2200 psi and the tubing pressure was 3700 psi. Rigged up HOWCO and killed the well with one circulation of the hole volume. 3/16/84 Nippled down tree. Nippled up Class III BOP. Tested all choke and kill valves, check valve, blind rams, pipe rams, floor valves and lower kelly cock to 5000 psi. Tested annular preventer to 2500 psi. Released top packer with 60,000# overpull. ~. 3/17/84 Recovered 2 7/8" x 2 3/8" tubing to ce joint at 10,344' (top of fish). 3/18/84 Swaged tight spot at 10,294'. Tagged fish at 10,325' (19' higher than previous run). 3/19/84 Swaged tight spot at 10,292', hit restriction at 10,325' but moved through to 10,328' (fish now 3' deeper). RIH with 4~" shoe and washpipe extension. Backed off at 10,242' and left shoe and extension in hole. 3/~0/84 Recovered shoe and washpipe extension with 4 1/8" taper tap. Engaged cc sub fish at 10,328' with retrieving tool. Recovered tubing fish. Had tight spot at 10,294'. Jarred and worked 10' before pulling free to ce safety joint at 10,423'. RIH with ce retrieving tool to 10,423' and recovered HS-16 packer and complete tubing assembly. Left 6' of seal assembly in hole. Had tight spot at 10,327'. 3/Z1/84 Milled 2' of model D packer assembly at 10,588'. Packer came free. Circulated bottoms up at the liner top and recovered entire packer assembly. Swaged and milled at 10,294' for one hour without results. 3/ /84 RIH with 4 3/8" swage, 4 5/8" string mill assembly to 10,294'. Rotated swage and mill 2'. Rotary torque dropped off - could not go deeper. POOH. Left 4 3/8" swage and extension in the hole (6.71'). RIH to 10,601' and tagged three strings wireline tools, 6' seal assembly and 6.71' swage and extension. Milled from 10,292' - 10,601'. RECEIVED 'JUL 2 0 1984 ~Jaska Oil & Gas Cons. Commission Anchorage 3/ 3/84 RIH with scraper assembly to 9700'. Circulated bottoms up. Set 7" Baker retrievamatic packer at 9703'. Pressure tested annulus to 3000 psi for five minutes - o.k. POOH with packer. Gearhart ran GR/CCL from + 10,600' to 9713'. RIH with 5~" model "D" packer - wireline setting assembly stopped at 10,305' - could not get through tight spot. 3/24/84 Added weight bars to tool configuration - could not get past tight spot at 10,305'. RIH with packer on D.P. and set at 10,587'. Ran Neutron/CCL log to correlate packer depth. 3/25/84 Tested choke manifold to 5000 psi. · Tested hydril to 2500 psi. and 3 t" tubing. Started running 2 3/8'' 3/26/84 Completed running tubing. (See tubing detail.) Removed BOP stack- tubing head worn almost to the API ring. Nippled up BOP and tested to 5000 psi. TUBING DETAIL Item Length Top Tubing Tail at 10,591.66' 1- 2 3/8" Shear Sub (Muleshoe Bullnosed with 1" original I.D., sheared I.D. 1.991") 1- 2 3/8" Seal Assembly (6-10" segments) 5~", 20# Baker Model D Packer (W.L. Set) 2 3/8", 8rd Baker Stop Sub 2 3/8", 8rd Camco D Nipple .66' 10,591.66' 51 2.8' .79' .92' Joint 2 3/8" AB modified, N-80, 8rd, 4.7# tubing 30.93' 2 3/8", AB modified Camco KBMG Mandrel with EK valve 12.74' Joint 2 3/8" AB modified, N-80, 8rd, 4.7# tubing 31.79' 2 3/8", AB modified, 8rd, N-80, 4.7# PUP 7.75' 2 3/8", AB modified, 8rd, N-80, 4.7# PUP 7.57' 2 3/8", 8rd, Otis S Nipple, Position i 1.52' Joint 2 3/8" AB modified, N-80, 8rd, 4.7# tubing 29.98' Baker 5~" x 2 3/8" FH packer 6.30' 2 3/8", AB modified, 8rd, N-80, 4.7# PUP 1.50' 1.41' 2 3/8", AB modified, Brown CC safety joint 2 3/8", AB modified Camco KBMG mandrel with EK valve 10.83' Joint 2 3/8" AB modified, N-80, 8rd, 4.7# tubing 31.70' 2 3/8", 8rd Otis S nipple position 2 1.53' 2 3/8", AB modified, 8rd, N-80, 4.7# PUP 9.59' 2 3/8", AB modified, 8rd, N-80, 4.7# PUP 9.7' 2 3/8" AB modified, 8rd, N-80, 4.7# PUP 5.66' 5~" x 2 3/8" Baker FH packer 6.25' 10,591' 10,587' 10,586' 10,585.21' 10,584.29' 10,553.36' 10,540.62' 10,508.83' 10,501.08' 10,493.99' 10,491.99' 10,462.01' 10,455.71' 10,454.21' 10,452.80' 10,441.97' 10,410.27' 10,408.74' 10,399.15' 10,389.45' 10,383.79' RECEIVED 'J U L 2 0 1984 Alaska Oil & Gas Cons. Commission Anchorage Rem Len~ 1- 2 3/8" AB modified, 8rd, N-80, 4.7# PUP 1- 2 3/8", AB modified, 8rd, CC Safety Joint 1- 2 3/8", AB modified, Camco KBMG mandrel with EK valvel 1- Joint 2 3/8", AB modified, 8rd, N-80, 4.7# tubing 3 1- Joint 2 3/8", AB modified, 8rd, N-80, 4.7# tubing 3 1- Joint 2 3/8", AB modified, 8rd, N-80, 4.7# tubing 3 1- 2 3/8", 8rd, Otis S Nipple Position 3 1- Joint 2 3/8", AB modified, 8rd, N-80, 4.7# tubing 1- 5~" x 2 3/8" Baker FH packer 1- Joint 2 3/8", AB modified, 8rd, N-80, 4.7# tubing 3 1- 2 3/8", AB modified, Camco KBMG mandrel with EK valvel 17- Joints 2 3/8", AB modified, 8rd, N-80, 4.7# tubing 1- 3~", 8rd, AB modified, Box x 2 3/8", 8rd, AB modified P 317- Joints 3~", AB modified, N-80,' 8rd, 9.3# tubing 1- 3~", AB modified 8rd, N-80 PUP Joint 1- Tubing Hanger - 3~", 8rd on bottom; 2 7/8", 8rd, on top; bored for a Cossasco BPV; equipped with special long neck 9,6~ 3/27/84 Pulled BPV and hanger to rig floor. Backed out landing joint ~ Set Baker retrievamatic packer with "F" nipple on top at ~ place. Backed out landing joint. Nippled down BOP. Replace pack-off to 3000 psi. Nippled up'BOP. POOH with tubing packer. Landed tubing per original detail with BPV in plac Nippled u[~X-mas tree. Reverse circulated out mud with lease 3/28/84 Top [.78' 10,377.54' 1.42' 10,375.76' ~.79' 10,374.34' 1.60' 10,363.55' ~.52' 10,331.95' 1.64' 10,301.43' 1.54' 10,269.79' §.59' 10,268.25' ~.25' 10,237.66' ..35' 10,231.41' 0.66' 10,200.06' [.36' 10,189.40' .50' 9,658.04' ].39' 9,657.54' 2.15' 19.15' 17' 17' nd first joint of tubing. 5' with tubing plug in d tubing spool. Tested )lug and retrievamatic ~. Nippled down BOP. crude. Attempted to set 1" EK valve in gaslift mandrel at 10,541'. ~ )uld not release setting tool from valve. Set plug in mandrel. Could not puI1 up. Jarred on fish unsuccessfully. Cut wireline at the top of the fishing neck. (W.L. fish #1 consisting of 21.75' of 1~" rope socket, 7' of 1~" stem, 1~" knuckle jr., 1~" manual jars, 1~" knuckle jt., 1~" hydro jars, L kick-over tool, 1" EK valve.) 3/29/84 Rigged up Gearhart. Latched fish -jarred for 2~ hours with 1200# overpull. POOH. RIH with new jars and rope socket. Latched fish - jarred once with 1200# overpull. Pulled out of rope socket. Attempted to retrieve W.L.fish # 2 but could not get past 3~"x 2 3/8" XO at 9658'. Flowed well - could not get past 9658'. Ran impression block with inconclusive results. Flowed well. Worked through XO at 9658' with 1 3/4" fishing assembly. RECEIVED :J U L 2 0 1984 Alaska Oil & 6as Cons. Commission Anchorage 3/30/84 Recovered W.L. fish #2 from gas lift mandrel at 10,442'. Had to jar fish through mandrels at 10,442', 10,364' and 10,189'. Ran fishing tools to gas lift mandrel at 10,541' - did not recover fish #1. Note: Although fish #1 was last tagged at 10,541', it may have been blown to the bo o{~-~-of the hole. Note: Tubing may be plugged below bottom gaslift mandrel. The EK valve is not in the mandrel at 10,541'. The four mandrels and the tubing just below the 3i" x 2 3/8" XO are bent. 3/31/84 Ran a 1.85" gauge ring to 10,520' without encountering obstruction. Set Otis "S" position I plug at 10,493'. Pressured up tubing to 3000 psi to set packers. Bled annulus to 0 psi. Top packer held. Recovered equalizing prong from "S" plug. Also recovered one of three 3~" metal strips lost when retrieving fish #2. Could not get.. over fishing neck to pull "S" plug.. Attached CCL to wireline. Could not get past 10,442' because of asphaltine. 4/1/84 Pumped 40 bbls. of solvent followed by 70 bbls. of lease crude down the tubing at 1 BPM and 3600 psi. Pulled "S" plug. Jarred out dummy valve from* mandrel at 10,442'. Pulled gaslift valve from mandrel at 10,442'. Pulled gaslift valve from mandrel at 10,364'. Flowed well for three hours. Unloaded fluid. Well flowed gas with crude mist. Released rig at 9:00 p.m. 4/17/84 Well SCU 21-9 placed on gas injection as SCU 321-9. RECEIVED J U L 2 0 1984 Alaska Oil & G~s Cons, Commission Anchorage COMPLETION REPORT - PACKER INST~TION SOLDOT~ CHEEK UNIT 21-9 Section 9., To 7 N.~LR. 9 W.,~ Seward B & M STANDARD oIL cOMPANY OF CALIFOPdIIA, W.O.I. - OPERkT~ Page October 13~ 1962. Remedial work commenced at 3:00 P.M. Rigged up and conditioned Black Magic mud. October 14.,. 1962 Killed well with Black Magic mud using Nalliburton. installed and tested BOPE. Removed x-mas tree and ,O. ctober .15 ~ 1952 Pulled donut loose and pulled 2 7/8" and 2 3/8" tubing out of hole. scraper to bottom. Ran casing 09tqber 16, 1962 ~Reran tubing equipped with packer. TUBING DETAIL K.B. to landing flange Landing flange 306 joints 2 7/8" 6.5~ N-80 EUE 8R 2 3/8" X 2 7/8" crossover 16 joints 2 3/8" 4.7~ N-80 EUE 8R 2 3/8" Camco sleeve valve i joint 2 3/8" 4.7~ N-80 E~E 8R Brown CC safety joint i - 2 3/8" pup joint Brown 2 3/8" X 5½" _HS-16-1 packer 2 joints 2 3/8" 4.7~ N-80 EUE 8R, Camco D nipple ll joints 2 3/8" 4.7~ N-80 EUE 8R Venturi shoe tubing landed at K.B.. Depth 19.20 .50 19.70 9667.78 9687.48 1. 82 9689.30 503.99 10193.29 2.7O 10195.99 28.15 10224.14 · 94 10225.08 lO.18 10235.26 3.93 102 39.19 63.52 lO 3o2.71 .90 lO3O3.61 348.72 lO652.30 · 5~ 10652.92 Removed BOPE and reinstalled and tested x-m~s tree. October 17,_ 1962 Displaced Black Magic mud with oil and flowed well clean. Set packer at 10,235' Rig released at l:O0 P.M., October 17, 1962. Returned well to production Rj RC£W SRH:pb COMPLETION REPORT Soldotna Creek Unit 21-9 Section ..9.~... T' ? N., R'...9 W.~ S~ewa~d B ~ M STANDA~ OIL CO.. OF CALIFORNIA, W.O.I. - OPERATOR Page 2. PERFORATION RECORDS: 5- 5- 5- 4- 4- 4- 4- ~ii holes at lO, 288'(squeezed) holes at 10,294' _ holes at 10,659'. "holes at 10,661' ?' holes/ft., interval 10,294 - 10, 304' i" holes/ft., interval 10,324 10,352' ?' holes/ft., interval lO~ 364 10, 375 ' ?' holes/~ft., interval 10,388 10,450' · " holes/,ft., interval 10,474 10,582' _." holes/ft., interval 10, 598 10,659' WELL SURVEYS: 5. 6. 7. 8. 9. 10. Schlumberger schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Continuous Dipmeter, interval 9, 957 - 2, OlO' Baroid Mud Log, interval 10, 270 - 9, 000'. Induction-Electrical Log, interval 10,272 - 2, OlO'. Sonic Log w/Caliper interval 9,748 - 2, OlO'. Microlog-Oaliper interval 7, 510 - 2, OlO'. Induction-Electrical Log, interval 10,745 - 10,272' Sonic Log interval 10,742 - 10,272' · Cement Bond Log, interval 10,270 - l, 880'. Cement Bond LOg, interval 10,690 - 9, 700'. Neutron-Collar Log, interval 10,697 - 9,000'. DRILL STEM TESTS- HCT WSO - Test ~1 on 7 HCT WSO - Test ~2 on 5 HCT WSO - Test ~3 on 5 HCT WSO - Test ~4 on 5 HCT WSO - Test ~5 on 5 X 5½" liner lap at 9,713'. - OK. ¥.. holes at 10,288' ~~ WNSO. ~_,. holes at 10,294' - OK. holes at 10,659' - OK. ~'" holes at 10,661' - OK, COMPLETION REPORT Soldotna Creek Unit 21-9 Section 9, T. 7~N-~ .. R:. .9 .W...~ S~wa. rd.~B & M STAN~RD OIL CO. OF CALIFORi~A - W.O.I. - OPERATOR Spudded at 9:00 AM, 5-18-61. Drilled 16" hole 0 - 1,235' Drilled 16" hole 1, 235 - 2, 040' 235' drilled 805' drilled 76 pcf mud 77 pcf mud 2,010' May 21~ 1961 Drilled l0 5/8" hole 2,040 - ~, 465 ' Drilled 9 7/8" hole 3, 465 - 3, 904' 1, 425' drilled 107' drilled ll 3/~", ~?#, 8rd.-Z. Youngstown. Equipped with Baker g~ide shoe and flexiflow float collar. 77 pcf mud 66 pcf mud Casing cemented at joints or Below K.B. 1,978.73' 21.27 ' Ran ll 3/4" easing and cemented as follows: CEME~K~ING DETAIL: Cemented ll 3/4" casing at 2,010' in one stage with 1275 sacks of cement using Halliburton power equipment. Used one top plug. Pumped 40 bbls. of water ahead, mixed 1275 sacks of cement in 70 mins. using Halliburton truck~ dis- placed in 15 ming. using rig pumps. Average slurry weight ll6~. Bumped plug with 1400 psi. F~ll circulation. Cement in place at 9:30 AM~ 5-20-61. Hookload weight of casing before cementing~ 80,000~. CASING DETAIL: 48 COMPLETION REPORT Soldotna Creek Unit 21-9 Sect~ion .9.,.. T:. 7 .N:~, R. 9 ~.~ s~w~.rd B & M STANDARD OIL CO. OF C~LIFORNIA, W.O.I. - OPERATOR Page May O lled 9 7/8" hole 3,904 3, 941' 37' drilled Twisted at 3,941' due to crossover sub failure. Left 9 7~/8" bit, bit sub, ten 7" drill collars and crossover sub. Ran in with 8 5/8" Bowen releasing overshot with 7" spiral grapple. Took hold of fish. Top of fish at 3,633'. Recovered fish. Drilled 9 7/8" hole 3,941 - 4,245' 304' drilled 70 per mud 23, 196z Drilled 9 7/8" hole ~, 245 - 4, 292' 47' drilled l1 pcf mud Twisted off at 4,292' due to failure of bumDer sub. Left 9 7/8" bit, bit sub, ten 7" drill collars, crossover sub, lower section and mandrel of bum~er sub. Ran 8 5/8" Bowen releasing overshot with 6" basket type grapple. Took hold of fish. Recovered fish. Drilled 9 7/8" hole 4, 292 - ~, 747' 455 ' drilled 72 per mud May 24 ~. 26,.. !961 Drilled 9 7/8" hole 4,747 - 6,683'. 1,936' drilled 70 - 77 pcf mud May 27 - June 8, 1961 Drillca 9 7/8" hole 6,683 - 6,718' 35' drilled 76 pcf mud Hole flowing at 6,718', built mud weight to 8~. Drilled 9 7/8" hole 6,718 9,22 ' 2,506' drilled 85 - 96 per mud Baroid Mud Logging Unit started logging at 9,000' June 8th. COMPLE~ION REPORT , Soldotna Creek Unit 21-9 S. ection _9~ T~. 7_ N., R. 9 .W...~ Seward B & ~ STANDARD OIL CO. OF CALIFORNIA, W. 0. I . - 0PEF~TOR Page 5. ,,une 9 - l 61 Drilled 9 7/8" hole 9,224 - 10,207' 983' drilled 96 - 97 pcf mud June 14, 1961 Drilled 9 7/8" hole 10,207 - 10,272' 65' drilled Circulated hole. 2, OlO'. Ran Schlumberger Induction-Electrical Log, interval 10,272 - 96 pcf mud Ran SOnic Log w/Caliper, interval 9,748 - 2,010' Unable to reach bottom. Ran Micro Log w/caliper, interval 7~510 2,010' ~ Ran Dipmeter, 9~957 - 2,010'. Went in hole with drill pipe to condition hole for 7" casing. Laid down 4½" drill pipe. 97 pcf mud Ran 7" casing to lO, 272'. Circulated hole. CEMENTING DETAIL: Cemented 7" casing at 10,272' in two stages with 1800 sacks of cement treated with O. 3% HR-4 using Halliburton power equipment. Used one top and one bottom rubber plug. 1st Stage around shoe with 550 sacks of cement. Pumped 50 bbls. of water ahead, mixed 18 sacks of cement using Halliburton truck and displaced in 36 mins. using rig pumps. Average slurry weight ll6~. Bumped plug with 200~ psi. Full circulation. 2nd Stage through DV at 7517'. Dropped DV bomb, opened DV ports in 45 rains. Pumped 50 bbls. of water ahead, mixed 1250 sacks of cement in 28 mins. using Halliburton truck, displaced in 28 rains, using rig pumps. Average slurry weight ll6~. Closed DV ports with 2500~ psi. Full circulation. Cement in place at 12:57 PM, June 16. Hookload weight of casing before cementing, 200,000; after cementing before landing casing, 194,000; and at time of landing casing, 202,000. Section 9, T. ? N., R. 9 W-, Seward B & M Page CASING DETAIL: Bottom .. 7 Jnts. 296.26' 19 Jnts. 809.18' 87 Jnts. 3,693.46' 43 Jnts. l, 807..21' 21 Jnt s. 880.02 ' i X-over 6.78' DV Collar ~ 7, 480' 2.00' i X-over 6.66 ' 23 Jnts. 973.69' I X-over 6.64' 34 Jnts. l, 414.93' i Marker Jnt. 12.64' .(Top of Marker at 9892' ) 9 Jnts. 378.16' Above K.B. 10,287.63' - Casing landed at lO~ 272.00' 29~, BT, N 80 26~, BT, N 80 BT, N 8O 26~, BT, N 80 29~, BT, N 80 29~, BT, N 80 29~, 8rnd., P-110 29~ BT, P-110 Flanged up and tested primary and second~rypackoffwith 3500~psi - OK. Picked up 3½" drill pipe. Drilled out DV Collar at 7,480'. Tested BOPE~ Hydril, Kelly Cock and DV Collar with 2500~ psi. Drilled out Baffle plate and float collar and 72' cement. Displaced lime base mud with Macco Perm Base Oil drilling fluid. 80 pcf mud June 18, ,,,!961 DrilIed 6 1/8" ho!e 10,272 - lC, 277' 5' drilled Started coring at lC, 277' with 6" Core Head. 76 pcf mud Cored 6" hole 10,277 - 10,286' 9' cored 90 pcf mud COMPLETION REPORT Soldotna Creek Unit 21-9 Section STANDARD OIL CO. OF CALIFORNIA, W.O.I. - OPERATOR June 19, 1961 , Cored 6" hole 10,286 - 10,316' Core ~l 10,277 - 10,305' June 20, 1961 Cored 6" hole 10,316 - 10,351' 10, 305 - 10,.333' Cored 6" hole 10,351 - 10,380' Core~ ~3 '10~333 - 10~361' June 22,. 1961. Cored 6" hole 10,380 - 10,413' Core ~4 10,361 - 10~389' 10~389 - 10,413' 30' cored 28' cut & recovered 35 ' cored 28' cut & recovered cored 28' cut & recovered ~8' cored 28' cut & recovered 24, cut & recovered Page 7. 90 pcf mud 88 pcf mud 90 pcf mud C O~J~TIOif REPORT Soldotna Creek Unit 21-9 S~e_ction 9, T. ? N., R. 9 W.&..S~ward..B & M STANDARD 0IL CO. OF CALIFORNIA, W.O.I. - OPERATOR Page June 23~ 196! Cored 5 7/8" hole 10,413 - 10,419' 6' cored 90 pcf mud Cut on Core ~6 for l0 hours. Pulled out of hole with core barrel. Core head had grove around inner face. Core 10,413 - 10,419' 6' cut 4' recovered Reamed hole with 6" bit down to lC, 419'. 89 pcf mud Drilled 6" hole lC, 419 - lC, 424' 5 ' drilled 90 pcf mud Went in hole with 6" bit and junk basket, pulled out. No metal in junk basket. Cored 5 7/8" hole 10~424 - lC, 437' June. 25, 1961 Cored 5 7/8" hole 10,437 - 10,~68' Core, ~7 10,424 - 10,452' June' 26, .1961 Cored 5 ?/8" hole 10,468 - 10,503' Core ~8 10,452 - 10~480' 13' cored 31' cored 28' cut 25' recovered 35' cored 28' cut 25~' recovered 90 pcf mud 90 - 91 pcf mud 90 - 91 pcf mud Soldotna Creek Unit 21-9 Section 9~ T. ? N., R.. 9 W., Seward B & M STANDARD OIL CO, OF CALIFORNIA' W.O.I. - OPERATOR Cored 5 7/8" hole 10,503 - 10,536' 10,480 - 10,508' Core ~. 10,508 - 10,536' Cored 5 7/8" hole 10,536 - 10,553' Core,. ~1,1 10,536 - 10,553' 33' cored 28' cUt & recovered 28' cut & recovered 17' cored 17' cut 16' recovered grooved core head. Pulled out. 38' opened 25 ' oper~ed 5 ' drilled Core barrel blocked at 10,553', hole with 6" bit and opened core hole. Opened 5 7/8" hole to 6" 10,390 - 10,428' June 29, , ,96! Opened 5 7/8" hole to 6" 10,428 - 10,553' Drilled 6" hole 10,553 - 10,558' Cored 5 7/8" hole 10,558 - 10,574' 16' cored Page 9. 90 pcf mud 90 pcf mud Went in 90 pcf mud 91 pcf mud 92 pcf mud 91 - 92 pcf mud COMPLETION REPORT Soldotna Creek Unit R1-9 Section 9~ T. ? N., R. 9 W., Seward B'& M S~ANDA~D OiL 'CO. OF CA~6~A~" W.0.~, - O~.~OR Page 10. june 30, ..1961. Cored 5 7/8" hole 10, 574 - lO, 599' ~Core ~12 10,558 - lO, 586' july ~, 196~_ Cored 5 7/8" hole lO, 599 - lO, 642' Core ~13 lO, 586 - 10,614' 10,614 - 10,6~2' Cored 5 7/8" hole 10,642 - 10,670' co~e lO, 642 - 10,67o' ju~ 3, %96~ Cored 5 7/8" hole lO, 670 - 10,697' core 10,670 - 10,697' ~ened core hole f~m 6" to 6 1/8" 10,277 25' cored 28' cut & recovered 43' cored 28' cut & recovered 28' cut & recovered 28' cored 28' cut & recovered cored 27' cut & recovered 95 ' opened 90 - 92 pcf mud 91 pcf mud 91 pcf md 91 - 92 pcf mud 92 - 93 pcf mud COMPLETION REPORT Soldotna Creek Uni~ 21-9 Section 9~ T. 7 N., R~. 9 W~, ~S~Ward B & M STANDARD 0IL CO. OF CALIFORNIA, W.0.I. - OPERATOR Page 11. July 4, 1961 Opened 6" hole to 6~z~'' 10,372 - 10,413' .41' opened 92 - 93 pcf mud Opened 5 7/8" hole to 6 1/8" 10, .413 - 10, 697' 284' opened 92 pcf mud Drilled 6 1/8" hole lO, 697 - 10,702' 5' drilled 92 pcf mud Reamed tight spots with 6" bit 10,640 - 10,670' 30' reamed 92 pcf mud july 5, 1961 Reamed tight spots with 6" bit lO, 670 - 10,702' 32' reamed 92 pcf mud Drilled 6" hole lO, 702 - 10,745' T.D. 43' drilled 92 - 94 pcf mud Ju!w. 5, 1961 Circulated hole. Ran Schlumberger Induction Electrical Log, interval 10, 745 - 10,272'; Sonic Log, interval 10,745 - 10,272'; and Cement Bond Log, interval 10,270 - l, 880'. 93 pcf mud july, 7, 196 Circulated hole. Picked up and ran 27 joints of ~", 20~, N 80 liner; total 1,030' w/Burns Liner Hanger. Liner l~nded at 10,743'. Baker Float shoe and baffle plate one joint above shoe. Unable to circulate due to well tak~ing fluid. Took fluid at 1200 to 2000 psi. Built up 100 bbls. more volume. Annulus would stand full at times, 5 - 10~ circulation. Pumped 17 bbls. diesel ahead of 100 sacks construction cement treated with 0.4~ HR-4. Dis- placed cement with 520 cu. ft. oil base and mud. 92 pcf mud COMPLETION EEPORT Soldotna Creek Unit 21-9 Section 9~ T. 7 N.,~ R. 9 W., Seward B & M ETANI~ 0IL C'OY- OF CALIFORNIA~- -~. O. I. - OPERATOR July 8, 1961 Pulled 5~2" liner hanger out of hole. Ran in with 6~" bit and 7" casing scraper to top of liner at 9,71~'. Conditioned mud and built up volume. Pulled out and ran in with 7" Halliburton Hookwall packer. 87 pcf mud J~u%y 9, 1961 Set packer at 9, 500'. Broke down formation with 2000 psi. Mixed 50 sacks of construction cement treated with O. S~ HR-4. Pumped 30 cu. ft. diesel oil ahead and l0 cu. ft. behind cement. Followed cement with 402 cu. ft. drilling fluid. Final pressure 2000~ psi. Tripped out and laid down squeeze tools. Went in hole with 6 1/8" bit and 7" casing scraper to top of cement at 9,5BS'. Drilled out cement to top of liner at 9,71S'. Tested with SO00~. Pressure decreased to 2700~ over a period of l0 minutes. - OK. Picked up 1085' of 2 7/8" drill pipe with 4~2" bit and 4~z" casing .scraper. 88 pcf mud Drilled out cement in 5~" liner from 9,713 to 10,700'. Circulated and ran Neutron Collar Log 10,697 - 9,000'. Ran Cement Bond Log 10,690 - 9,700'. Ran WSO Test ~l on 7" X 5~" liner lap at 9,714'. Tool Assembly: i outside BT recorder, 6' of 2 7/8" perf'd, tail pipe, 7" type "C" Hookwall packer, VR safety joint, hydraulic Jars, 2 inside BT recorders, hydrospring tester, 90' of drill pipe and T.C. valve. Used 1650' of W.C. Ran on 9,617' of 2 7/8" EUE tubing. Set packer at 9646' with 13' of tail to 9,659'. No ISI pressure. Opened tool to surface at lO:21 PM for 65 min. flow test. Shut in tool at 11:26 PM for 30 min. FSI pressure. Pulled packer loose at 11:56 PM. Recovered gO' net rise, all drilling fluid. (Oil Base) PRESSURE DATA: IH ISI IF FF FSI FH Top Inside 6057 - 780 780 837 6050 Bottom Inside 6094 - 802 802 813 6075 Outside 6085 - 776 776 807 6086 Set packer at 9,646' test. Opened tester and received a puff blow, dead balance of 90 pcf mud COMPLETION REPORT Soldotna Creek Unit 21-9 Section 9~ T. 7 N., R. 9 Wi, seward B & M STANDARD OIL CO. OF CALIFOP~A, W.O.I. - OPERATOR Page 13. Shot 5 ½" holes at 10,288' for WSO ~2. Tool Assembly: i outside BT recorder, 6' of 2 7/8" perf'd, tail pipe, type "C" Hookwall packer, VR safety joint, hydraulic Jars, '2 inside BT re- corders, hydrospring tester, 9' drill pipe and TC valve. Used 2300' of W.C. Ran on 9192' of ~" drill pipe. Set packer at 10,241' with 13' of tail to 10,254'. Opened tool and received a weak blow, increasing slightly throughout the test. Water cushion to the sur- face in 130 minutes. Flowed water at the rate of 400 barrels per day. Took a 70 min. final closed in pressure· Opened tool to surface at 12:38 PM for 2 hr. l0 min. flow test· Shut in tool at 6:15 PM for 30 min. FSI Pressure. PRESS~ ~ATA: IH ISI IF FF FSI FH Top Inside 6418 - 1084 4390 Bottom Inside 6491 - 1162 4424 Top Outside 6458 - 1056 4427 5107 Chart time expired 5134 " " " Chart time expired July 12, 1961 WNSO Went in hole with 5~z" D~ Halliburton cement retainer. Set retainer at 10,003' Broke down formation with 2600 spi. Squeezed holes at 10,288' with 100 sacks construction cement. Tested with 1500~ psi. Held OK. Went in hole with ~" bit and drilled out soft cement from 10,230 - 10,250', firm cement 10,250 to 10,268'. Tripped out, and went back in with 4½" cement scraper. july lB, !96~ 90 pcf mud Drilled cement 10,268 - 10~288', washed 10,288 - 10,700'. Tripped out and ran perf. g~n. Perf'd. 5 -~" holes at 10,294' for WSO ~3. Tool Assembly: 2 outside BT recorders, 5'of perf'd, tail pipe, 5~TM type "C" hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders, and T.C. ~" valve Used 2278' of W.C Ran on 1059' of 2 7/8" Hydril and 9lO1' 2 · · drill pipe. Set packer at 10,182' with 18' of tail to 10,200'. Opened tool to surface at 2:45 PM for 7 hrs. 55 min. flow test· Weak blow of air throughout test. Cushion to surface at 7:15 PM. Oil to surface at 8:30 PM at estimated rate of 800 B/D. ~ SFC. Bean~400 psi SFC pressure for i hour. 3/8" bean at 175~ psi for i hr. t0 ~li~. ~/8" SFC. Bean. Oil wins cuttin~ 3.2~. (0.3~ H20, O~ emulsion, 2.9~ mud. Shut in tool at 10:40 PM for 70 min. FSI pressure· Pulled packer loose at ll:50 PM. Backscuttled rise during final shut in. COMPLETION REPORT Soldotna Creek Unit 21-9 Section 9, T. ? N., R. 9 W., S?wa.rd B & M STANDARD OIL CO. OF CALIFORNIA, W.O.I. - OPERATOR Page 14. July 13, 1961 C. gn_t_i._nu_e._d PRESSURE DATA: IH ISI IF FF FSI FH Top Inside 6332 - 1191 3402 Chart time expired Bottom Inside 6298 - 1219 2853 4818 6284 Top Outside 6413 - 1048 3262 Chart time expired Bottom Outside 6372 - 1023 2857 4842 6307 July 14,. 196! Went in with drill pipe and backscuttled at 10, 700'. Pulled out. Perforated 5 ½" holes at 10,659' for WS0 Tool Assembly: 2 outside BT recorders, 6 feet of perf'd, tail pipe, 5~" type "C" hookwall packer, VR safety joint, hydraulic Jars, 2 inside BT re- corders, and T.C. valve. Used 2700' of W.C. Ran on 1059' of 2 7/8" Hydril, 9556' - 3~" D.P. + 2875' tools. Set packer at 10,606' with 18' of tail to 10,624'. Opened tool to surface at 7:45 PM for ll0 min. flow test. Faint blow for i hour (8:45), dead 8:58 PM. Pulled packer, opened bypass. Reset packer at 9:05 PM. Faint blow to dead in 2 mins. Pulled packer at 9:10 PM. Purged perfs. 5 times. Reopened 9:18 PM, very faint blow. Shut in tool at 9:50 PM for 30 min. FSI pressure. Pulled packer loose at 10:20 PM. Recovered 40' net rise. PRESSURE DATA: IH ISI IF FF FSI FH Top Inside 6542 - 1205 1222 2998 6542 Bottom Inside 6609 - 1208 1216 3005 6609 Top Outside 6618 - 1198 1198 Chart time expired Bottom Outside 6593 - ll81 1202 3111 6593 Charts show tester open. No plugging. Casing perfs, probably not plugged due to FSI buildup formation too tight to produce. Perforated 5 ½" holes at 10,661' for ;~0 ~5. Tool Assembly: 2 outside BT recorders, 6' of perf' d. tail pipe, 5~" type "C" hookwall packer, VR safety Joint, hydraulic jars, 2 inside BT recorders, hydrospring tester, and T.C. valve. Used 2700' of W.C. Ran on 1059' of 2 7/8" Hydril D.P. and 9556' - 3½" D.P. + 28.75' tools. COMPLETION REPORT Soldotna Creek Unit 21-9 se.c, tion,.9~ T,:,, .7 ~N.. R- 9 w.~,, ,S. ewa.~,d B,~& M STANDARD OIL CO.. OF CALIFORNIA~ W.O.I. - OPERATOR Page 15. Set packer at 10,606' with 18' of tail to 10,624'. Opened tool to surface at 9:12 PM for 8 hrs. 18 min. flow test. Light blow of air until 5:30 PM. Started backscuttle while shut in at 5:40 PM. Cushion to surface at 5:43 PM. Gassy oil to surface at 6:00 PM.. ' 30.40 API cutting, O. 4~ mud. No water. Shut in tool at 5:30 PM for 90 min. FSI pressure. Pulled packer loose at 7:00 PM. Recovered 7300' net rise oil - 64 bbls. or 192 B/D rate. PRESSURE DATA: IH ISI IF FF FSI FH Top Inside 6544 - 1248 2446 Chart time expired Bottom Inside 6568 - 1290 2809 430.8 6568 Top Outside 6632 - 1243 2514 Chart time expired Bottom Outside 6595 - 1299 2794 5304 6595 Conditioned hole to perforate for production. July 16- .17., 1961 Perforated 4 ½" holes/ft, using carrier gun over following intervals: 10,659- 10,598', 10,582- 10,474', 10,450- 10,388', 10,375 - 10,364', 10,352 - 10,324', 10,304- 10,294'. Circulated hole. Laid down ~" and 2 7/8" drill pipe. Picked up and ran 2 3/8" and 2 7/8" tubing. TUBING DETAIL: Venturi shoe & 27 jnts. 2 3/8" tubing 2 3/8" X 2 7/8" crossover 306 jnts. 2 7/8" tubing i ~ 2 7/8" tubing sub K.B. to tubing head 825.04' 1.15' 9,661.03' 2.00' 21.65' Tubing landed at 10,510.87' Bottom of 2 7/8" tubing at 9,684.68' Removed BOPE and. installed X-mas tree. Tested tubing head with 4000~- psi. Held OK. Flow tested well. COMPLETION REPORT Soldotna Creek Unit Pl-9 Section 9, T'...7 N., R. 9 W.~ Seward B & ~4 STANDARD OIL CO. OF CALIFORNIA~ ~Y. O.I. - OPERATOR Page 16. july 19~ 1961 COMPLETION DETAIL: Installed X-mas tree and tested with 3700 psi for l0 rains. Held OK. Com- menced displacing mud with oil at 6 PM. Pumped 40 bbls. of stove oil~ fol- lowed by 360 bbls. of crude oil. Stopped circulating at 8 PM. Formation oil to surface at 9 PM. Flowed oil to sump until 8:20 PM. Started flowing to trap at 9:15 PM. Representative flow rate and cuts as follows: Flow Rates Bean Tubing Casing Trap Flow. Period 0il Gas Size press. Press. Press. 2. ½ hr~ 475 94 MCF/D 8/64 ltl0 1510 80 ~ Total Cut ~ .Water ~ Emulsion ~ Sand & Mud Corr. Gravity 1. o.4 o 0.2 0.2 36.9 2. 0.2 0 0.2 O. 36.8 Shut well in at l:O0 AM. Shut in pressures~ Tubing pressure 1730 psi~ casing pressure 1525 psi. Produced estimated 220 bbls. formation oil. Flowed 270 bbls. to tank and estimated 60 bbls. to sump. Installed Cosasco plug. Rig released 2 AM 7-19-61. SRH:EPW: lo S .~.,-~SEN COMPLETION REPORT Soldotna Creek Unit 21-9 Section ~, T_?_.7..N.~ R.. 9 W., Seward B & M ETANDARD OiL CO. OF CALIFOP~, W.0.I. - OPERATOR Page DEVIATION DATA 0e~t~ 100 ' 820 ' 2,000 ' 3,755' 4, 000' 4,467' 4,930' 5,736' 5,950' 6,:1.66. 6,4-53' 6,693' 7,000 ' 7, 345' 7,675' 8, 148' 8, 364' 8,725' 9, 256' 9, 560' 9, 900 ' Degrees 0O 15 ' 1° 00' 0° 15' 10 30' :L° 30' 2° 00' :Lo 45' 2° 00' 3° oo' 2° 00' :Lo 30' :Lo 30' 1° 00' :Lo :Lo 00' 0° 1° 00' 1° 1° 15 ' 0° 15 ' 0° 30' 0° 15' 1° 00' ~ ~ Approv~} ~.~pi~ 1~-.:~1~. ~.~.~ o~.c~ _.~0hor~m -.~ UNITED ~ATES DEPARTMENT OF THE INTERIOR L~,~ t~. A-028997 6EOLO61CAL SURVEY ONTHLY REPO T OF OPERATIONS LE SEE'S The followit~ is a correc~ rcpor~ o/ operation, s and productio~ (~;nclu,lind dril/in.~ a~d l.,rod~ci~ we~ls) for the mon. tk, of ...... _~.0~.~ ................. ;9..62 ............. ~9~dog~ Creek U~ AND ~P. RANGE [ ~AR'gE~ Or (.ILL ] G/L~VII'Y (}ASr)LINE, ~',xlER (If I fl~i~ ~ork ~o~nenced ~lobe~ ~, ~62~ Kited ~el1 ~h ~k ~ie "~4' ~oved x-me ~e ~d installed ~ed ~bi~ ~n casing scraper. ~r~ 2 3/8" X 2 7/8" co~i~t~on tu~i~ eq~pp~ ~th packer. L~ded tuoi~ at 1~53~. ~oved BO~ ~ ~sta~ed x-~s tree. Displaced ~.~"~th ~. ~Se~ packe~ at 1023~'. ~tur~d ~11 to product- ~ released ~:tober 17, U,SoG. ~ M~ ~. Soyster State !. D. Bruce Richfieldl- C. W. Perry , R.g. Ritter 1962o NOV 8 1962 · 1~ BYancfi, i~ision o~ Mines and ~a,~ka D.9~I,.~ Natural NoT~..--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,) tNToT~.--R, eporg on ~his term is requir~ for each oalendar month, regardless of the sLat, us of operations, and mus~ be filed in duphcate with the su~rv~or by the 6th of the succeeding month, unless otherwise directed by the supervisor, (Jan~y lg~) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bure~a No. ,t2-R356o5. Approval expires 12-31-60. LESSEE'$ .MONTHLY REPORT OF OPERATIONS T],e followi~g is a correct report of operatio;~s and produ, ction (in cl~din.¢ drillin¢ and produ, ci~ wells) for the mo,,t,h o/ ................. ~7 ................... l,~ .............. ~:P~_(lO~Pa._~rgf~__~4P~ · ,~ ~T,~'~ , ~ AL~.~ dg'en?s a4dress ..... P._.~o Box 7-839 , o ~, ~ _ ................................................... ~..ompa,.. ~ ....D~~~ ................................. ~ho~g~,_ AZ~, .............. ~'~:,,.,,~ __ / .?~ ~~ ~~..,. . ....................... SCU 2Z-9 (20) i : .... ~ 10, ¢!h ', 9 7N ~ Co~d: Core [~13, 10,~88' - cut ~ .rec. i Core ~lh, i0,6~'- lO,oh2', cut & rec. 28 NE~ ~ Core ~15, lO,6h~' - 10,670~, cut & rec , ~ore fi!6, 10,67O~ - 10,677", cut & rec~ 27' hM~ ~ Oo~?d h le to 6 1/8" f~om !0,277~ - 10,67~ Drilled 6 1/8" hole zo,~7~, ~ ~o,7~5' · ' '~ , ~ ' '~ '~' "~-~ t.Do R~ ~,L 10,2(O - t.~8. o Sodic-Ca!ioer Log !O,74~' - 10,272'¢ r' ' ~ -,1/2" liner ~e.~eqted zo~, W5o ~o:~s ~na ~oue~z~ ~ne~ ~ */5o ~o,.~ cement. ~o~ l~r' ¢ at~ O714'.., T'~9. cer~nt, . at 9' ' '.53~ Orilled out oement to 9714' . - ~ clewed out ce$~ent ~o 1~,700~. R~oNe'~tron-Co~lar Log 9,~0 - 10j697 ~d_ cement ~;o~ :o: :,700 -[ 10,6: Oo ~ Sat p~.ker at 9646 for WS~ Test on 7" x 5~1/2" lJ'ner lao~ Test 0~. Perforated 5 1/2" . ho~es at 10,2;:8'. ~Set Oacker at 1~,24].~ for SqUeeze& bole~ at ~O,20~~ w/lO0 s~ks ce:~e~t. ~in~ pr. ess~e 1500 ' , ~ T' ~ ~ . I ' $ psi. -D~ll~d.out ~-etaider. ~ ~.~1/2" sc~ao~r ; lO~700'd ?eriorat~d ~ i/2" hole~t 10,2:~ Set "~acker at 10,182' ~ and rsn WSO .est. JLest '.uK. ~dSO t~st '::.. ~3~'.:':,9'. ~ncouclusive. 10,~598' ~ 10.659'.]10.4~4~ - 10,~82~.. IO.~GS~ - 1.O,450~ 10,364' - co~bination t~ing~ Landed ~ lO,5~l'. InStal!ed ~-~s tree ~d ~- te~ted ~].l~ R.ep?$sent~ttve rate:~ 1774 D/D oil, %27 NCF/D gas, 16/64" b~, 1580~]T.~ 14.7~'~ C.M. 87~ trio ~r,ss. ~.4% tot~ cut, ~}Al~ska 0 & 0 ~C - ~.D. 3ruce ] '~io~fieid Oili Cor?;- C, W. O~rry- iii R. E~!or ~tion I ', NoT~,.--There were ...................................... runs or sales of oil; ............................................... M cu. ft. of gas sold; ............................................. r,.n;s or sales of gasoline during the month. (Write "r.o" where applicable.) Noxg.~Report on ~his form is required for each cMend&r month, regardless of the status of opemt, ions, ~nd must be filed in duplicate wi~h the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. ~or~t 9-329 UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42-R356.5. Approval expires 12--31-60. LESSEE'S MONTHLY REPORT OF OPERATIONS State ............ .A__!_e~_ _ ~a_ ........... County __K_.e__n. a__i____P._e__.~.'__n_ ._~__~__ _ ~ .... Field ............ _$.~n._s._.o_.n.._~_i.y_ .e_r_ _ ............................ The foH, owi~ is a correct repor* of operatio~es and production (in. cludin5 drillin,~ and producin~ mells) for ~he m.o,,f:I, of .............. ~.UBO .................. 1~!_ ............ ~O_~_~ot~__9_r~__Ti~!~ .............................. Asen~'s addre's P.o. Sox 7-837 ........................ ' ....................~--- ' .... ~ - Western ~at~ons,/In~ ............ ; ........: ........................................ I .......... ' ..... I scu 2:- 9 (2o~ 7N ~ Drilled 9 7/8" hole 78].6~ - 922h~. B~oid ~nd io~ loggi~ ~ 9000~. Drilled 9 7/8" ho].e 922h~ - 10~207 ~ Sc~amberger I-~ Lo~, in~al 10,207~ - 2C10~. Unable %o ge% below 9980~ with~ Sonic Log sonde. ~rilled 9 7/8" hole , 10,207' = 10,272~. R~ I-ES Log over ~terval 10,190~ - 10,272', ~ and Sclc Log 6ver interval 9748' - 20~O~. Unable to reach ' bottom. Ran Micro L~g over inServal 7510~ - 2010~. ~ continu- ~ cue Dip~tero~ Cemented 7" ca~ing at 10,272' iu two stages. ~ Used~ 550 sacks ~aroun~ shoe ~d 1250 sacks through D.V. color at 7~17'. Tested pr!~r~ ~d ~econda~ packoff.w/3500~ - OK. Drilled out DV coll~ ~ested BOPE, Hydrill, K$~y Cock and ~ DV c$11ar w/2500 psi~o 'Drilled out Barf el plate~ and ~oat ~ collar and 72'~ce~n$. D~lle~ 6 1/8" hole 10,~72' - 10,277 ~ ~ Core ~1, ~O,~7~' -~0,30f~', cut ~ rec. Core ~2, !0,30~' - 10,]~$',~ cut &. rec. 28' ' · : Core ~3, 10,]3~' - 10,~oi', cut & rec. 28~ " Core ~4, 10,36~~ - 10,38~~, cut & rec. Core ~5, 10,38~' - lO,41J', cut & rec. 24~ Boyster ~ Co~e ~6, 10,41~~- 10,~', cut 6' rec. 4~ ~d 6" hole %o 10~.419-~. D~lled 10,~19~ - 10,424~. Co~d ~ore ~7~ lO~h2h~ - lO~h~,~J~ cut ~8~ tee. Core ~10 lO~OS~ - lO~::6J~ eu~ ~ tee, / cc: USGS-MSrwi~ H. (2) Alaskai O&G C',C - D .D - ~Richfield ~il C C.W. Perry R.R. Ritter File: Producing! Exploratie~n Land Core #11 10~536' - 10,5~;3', cut ~7~ rec. il6' drilled~ ~ 10,558'. Reamed to 10,~i 3' W/~" bit and ~0,553' Core #17 10,5~8' - 10,5fl6', cut ~ rec. 2 ' , Core #13~ 10,5~6' - inco~leteo NoTE.--There were ....................................... runs or sales of oil; .............................................. M cu. ft. of gas sold; ............................................. runs er sales of gasoline during the month. (Write 'no" where applicable.) NoTz.--t~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 Otb of the succe~ing month, unless otherwise directed by the supervisor. ~rm 9-329 . ~ ~ 16--25766-8 U.S. GOVCRa~ENT PRiNTiNG O~FICZ (J~n~y 19~) -- UN]TED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Butlgc£ Bur,-:u )~'o. ,12- R.:lSb,5, Approval cxpirt's 12"3t-6o. LESSEE'S MONTHLY REPORT OF OPERATgONS State ........ The followDzg~ is a correct report of opc~'ations and productio~ (inchtdin&~ drillind, and producin~ wells) for the mo~tI; of ........... Hax ............. ~9__~, _ ................ J~ent's address .................. F._ Oo_ Pox 7-63~ ............... Company _~~~,_.I~~-/ ............................................ 48cb0r.~a, _A!]ska ......... Sg~ned ........... ~/~f ...... (~U. FT. OI' (]A~ ~ GAI;LONS OF ]~AItRELS ([I1 tholl~3hdS){ (~ASOLINE hVAqER (][ . (If drilling, d('p;h: if Mint down, catme: t ~OF~ TWP. RANGE[ NO. ~ : ~ARRE~ oF OIL ~,]RAV'TY 7N 9~ squ pl-S (2o) S udded at 9:00 A~ May 1~, lPC!. Drilled 16" hole 0 - 2040'. C~mented !1 3/4" 6,~sing at 2010' with 1275 sacks Installed. and tested DOPE. Drilled I0 5/~" hole 2040' - 3797'~ ~isted off sub. pi~n below bumper ~ub. Took hold of fish at 3633~ ~nd recovered same. Drilled 9 ?/~q" hole 3797' - 4292'. ~isted off 6" ~mper sub. ~qan B~en releasing overshot with 6" ~'r~pp!e. Took bold of £~sh and ~-ecovere~ s~m~e. Drilled 9 7/~" hole 4292.~ - 7816'. NoTr...--Thcrc were ....................................... run;; ,;r s,qh:,; of o:/.' _ ..................................... 5i cu. ff. ~;f :.,.,'as .sold; i;.' . .,,..'S 0~ ll, -.',;: ;' I ~, ' duplicate with thc supcrvi,;or t,y the 6ih of 1 .ue(.:.,lh~:.~ ~:~<'~::¢h. :~ .... !,,:ru ;::o ~'. ," },, ' 1 .... ', (January 1950) ~ ~.~1~ (~e~. lgSD (SUBMIT IN TRIPLICATe) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS NOTICE OF INTENTION TO CHANG~ PLANS ....................... NOTICE OF INTENTION TO TEST WATER ~HLIT-OFF .............. NOTICE O~' INTENTION TO RE-DRILL OR REPAIR WELL .......... NOTICE OF INTENTION TO ~-iOOT OR ACIDIZE .................. NOTICE OF INTENTION TO PULL OR ALTER CASING NOTICE OF INTENTION TO ABANDON WELL SUBSEQUENT REPORT OF' WATER 5HUT-Of'F SUBSEQUENT REI~)RT OF SHOOTING OR ACIDIZiNG SUBSEQUENT REI~RT O~ ALTERING CA~NG ~JBS~QUENT REPORT OF RE-D~ILLING OR REPAIR ~UB~EQUENT REPORT OF ABANDONMEI~r .......................... SUPI~_EMENTARY WELL HISTORY (INDICATE AIOVE BY CHECK MARK NATURE OF REPORT, NOTICE, OR OTHi]~ DATA) Well No. _.~__2~ is l~ated / ~__ ft. from. Iii - ~ p~J. Sec. 9 7~ 9w se~ .......... <-~--~:~-~: ~:~ .......... ~:~ ............. <-~ ............... ~-~a~ ........ ~~_~_.~_~_~ ............ ~.__~~ ............................ ~~ ......................... (Field) (County or 8ubdiv~n) (8~ ~ T~) K.B. The elevation of the '~_~ gq~ a~ve s~ level is DETAILS OF WORK lng ~nt~, ~ all other im~ant p~ 5 5 6. 7. 8. Drill to 2OO0' and cement ll 3/4" casing. Iastall a~i test Cla~s III blowout prevention equipment. Drill ahead to 8~rproxlmately lO, 250', log and ce~nt 7" casing in a single s~ag~. Chan~e ~o oil beJe drilling fluid aud aor~ e~ead ~o penetrate t~e productive interval. R~u~ logs. Cemen% 5 1/2e ]PJ liner at estimated T.D. of lo, Slo'. Obtain :~quired water shut-offs. Selectively Je~ perforate attractive sands and test as m~cessary, Run 2 7/8"-2 3/8" combination ~ubiag string ami complete. APPLICATION FOR PERMIT TO DRILL, DEEPEN OR PLUG BACK APPLICATION TO DRILL NAME OF COMPANY OR OPERATOR DEEPEN [] PLUG BACK C1 DATE St~udard 0il Company of Califoruia, Western 0~, erationst Inc. Address Cit~ P. 0. Box 7-839 Anchorage State DESCRIPTION OF %VELL AND LEASE Name of lease Soldotna Creek Unit 1%Vell number SCU 21-9 Elevation (ground) 145 ~ approximately X, Vell location (give footage from section lines) Section--township--rang'e or block & survey ApDroXl, ,1980'E.& 660'S at right angles from NW cot. proj. Sec. 9~ TTN~. R~, Seined Field & reservoir (If w'ildcat, so state) I County Swanson River Field Hemlock ReservoirI K®nai Peninsula Distance, in miles, and direction from nearest town or post office _Approx~te ,ly t4__miles north of ,sterlinb, Alaska 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: 1980 feet 1~,0 fee~ Proposed depth: _10~8" '+ Number of acres in lease: Rot~try or cable tools Apl)rex. date work will start ~7 1~, 1961 Number of wells on lease, including this well, completed in or drilling to this reservoir: 1,2t If lease, purchased with one or more wells drilled, from whom purchased: Name Address Status of bond none required 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) CERTIFICATE: I, the undersigned, state that I am theDiSt.$~a~t, of th$~,~ 0il ~o. of Calif. Western 0pe.l'ati,ons, (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 tll~e~n ~are ~,true, corr,~ct and complete to q~,?:Tc~:~t'? !2.. ~":., ,~":..~. .... ". '"',, the best of my ~owledge. C. Permit Number: 20-61 Approval Date: M~17, 1~61 Approved By: R..fMu2~tr~p e~ Engineer Notice: Before sending in this form bg sure tsar you have given all information requested. Much unnecessary correspond- ence will thus be avoided. See Instruction on Reverse Side of Form Signature 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 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 ~~~~~"ì~:":~ . ~-.~...~,~ k::2': . ~'" '" .' r~~, ~ ...: ~.:,;,I,., ... .' CEMENT,BUN,D'lOG SCHLUMBERGER WELL SURVEYING CORPORATION Houston, Texas , " \ . ~:~;" ..;~' ~·?,~t·:·;s.:·:~':<::: . ,.,'", . .' , ...... .:... -'. ,,:~, ~: ,~"",¡;,~.'.:.~';...:.. ~ 'Y-:""'~"1..::.:_._ ". ....'..16. ..'..... _'........1_--' r._._........~\. .' .-'. '" IL..~_.._ ... ;-.~.._-:: _~.-"~.-.. ....;.:..;'~.,..¡...,.'!"'-.. "·7;, , . . . . ,. ì~ . . .,.........._-"~ . ..___~~":---.~-__~-~:..__ ~:~:.~~~::"1:~::~5':."1~~~~ -'-'''''''-.-' --. '---:"~-_. . .,,-:~." '-H..~';..;.~.....IQ.';.;..""""...;...~.~.~... ~~·,!"';";',:.u:...~_~~·'="'~-·---- .-..-- ¡ ·1 "~ ............... ......P._.~__ ____~""'_'.......--.~.. ....-.~ ...,~....~... "'~'L··'· .....--........... . . .._ .______......-...:' _...... -.I. ..' I ¡ I ~III ..'I....'.,·,,···--,· t ...........-.....:.......... f·.... ~ u. ~ '.. "of .......,....:.L·..I..J,.~ 'k;);, i';.':::'~ - · N:¿jimí..'lí:1iW.1i.... 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"t~7 ~1-,li}.""":J'·'"...,r~,:" -.P'L,-r~~~I"li:~~,i,o~ ¡;~Å1!1\~: *',. r1~,¥".L" ~""lf.~~:-:'''''-T'''I·.:a..,'''~''· \"..~:..IJ'~ "!.' ~J.I"·" ~'. _ Il,," l) tJlI JJU1U Dßllb ßIL n ßLJj L) U Itl ßJ 11' ti UU ttrOllllflUl' ~~ ~ 1 ~'\." '\.,,"""" '\""" " '\. '\. '\. \. '\.,,"'" HODS TON, TEXAS,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,, ~ ~ . ;. ~.1. . .. ø/.,,-'O~J. ~ -'O/W/ /1 . . .. r.t.. Q ~ -. fOO~i:Ij. C/Jtrúæ/lim - 6tecl/aaa ci{)# "_ Q)o .: COMPANY·i ,".. :;.,J.... (\ !.. - Other sur~ey: f ... . ~' ':; t ~ ? ' ,J;f ", [~, j·L 1 F· (j~,;. ~,,: I /\ ..II!BJI8IL.1.,..L.~~ " 'Location of Well ._,.!-," WELL~('ir.,<.!(:T:·:/\ /~~:~:, K :,~~; ~ T S·c::;;(..1/'Q- ~... ~- -:.-.J .'. .,......' ',¡ ,.' / "-) .:'( -tt 11 t·- ,,,.... 'J I'.,~ ... ~ '" .,' - . " r:.~C".. .~ I '" :-: '...~~' 8 ;"..-LL ~.-""~ - .~~.~ ....-..) --. ~.."" ~..."~.1 ...~ ::', . :: I~=" ..,~' ~~: '" '. C ~~, ': ~,~c::: ~r,·'"",",:" :...,¡... (' Z ~ >-,~ O· Z!"'" , ~ 0 i= :.1'" «."..- Zo-<.....I a... =>.....IU.....I :E OwOw 0 Ui:i:.....I?!: U RUN No. Date First Reading Last Reading Feet Measured Csg. Schlum. Csg. Driller Depth Reached Bottom Driller Depth Datum Mud Not. Dens. , Vise. Mud Resist. " Res. BHT Rmf Rmc " pH " Wtr. Loss Bit Size Spcgs.- AM MN IND. Opr. Rig Time Truck No. Recorded By I 'w"Jtness REMARKS Cartridge No. Panel No. Sonde No. FIELn 1·~ a C!'a CJ ~ '-, ... ".'.,! /\~ 1 .~:; ;,' " ~OCA TION ':;:': .~9 COUNTY STATE K'. ?~ ,: \ J ¡:>\';, /. ¡! L'~' \I~; }~ / ',~, c; 1,..] ':, T':' i () {-I,~:-[ , ! CO (ì J 2 ('}' r \ . '-' ~ "'~,; ~l .)(',1 ,( ..·'·i::..... ":'UIU ;::,' ~~) ¡ fJ? ~ ¡'''~ ~ l:::': <} ~' ) .' (':.' ..~ ~ 'I' ~ -' ....... - t \1 '- ' T F <at ~ c~ _,; ~ ~ U ':' 7 ? ~ 1'(..2 UC) .-- ., b...:> :2 u! u ~ u.:! 73 ~ ¡"..~~ ( i~ j 1 ~îr _:; <.i.? þ..I. ..... .... ~.' T ~ì ". :" . ,. n :~ I q -. 'J ~ ...J L. :j C~) I SPONT AN EO US-POTENTIAL millivolts K r.': ;.~;. ~ ',~- .' : " : c -7 I '''' '.... I-~-~i I ~.. '_ I , ....J. ' ~ 'I. 1....3...) , I It G @ 8 U ° F ! 0 C@::;:j 0 F :,).. '~.;@i :)~) OF U. C!@ I ~:.,0F r,O> . i' @ {' t· OF ~ '"@ ,- ""OF "".", I.~' '...'. .e, ',~~":: > q '" @ r. ( of ~:j 0-:3@ l; tPF .", ,~~.~. @ °Ff.1 @ OF .'~ ~3 . : XC 30 min.1. U CC 30 min. ". .. 7 q ." f (." ~ ~:.'S ~'~/~ '...:,- . ..~( '.."~,, ~I r:~ ! ,~ ; '.. .'~ . ,,:"', {~':' t ~: i1 ,~~, ... :..... ',.~ C.D. I (,...l~-d 1 ; < :) -l.r~ I ~:~~-K : . ~ ,t,~ ", r~~ J 'I... . ,j ® T71 ':;')"~)'" J ~, )' Elevation: D.F.: KB. rt~(2 . .. /22' or G.L.:_,_,._._ ~. ',: ~ ~, : (.~ ':- ~ FILING No. . I 7-h-hl 10, 745 10,272 4;7~ 10')72 r 0272 I (}74t; I 0746 K~ o II .,:,,, I ~'.. @"'" OF @..... of @,... of @ ..."' of @ ,- of CC30min. ñ~ I @ of @ of @ of @ of @ of CC 30 min. I I @ of @ of @ of @ of @ of CC30min. 6FF40 2 hrs 2662 M L~.~_~ R ~'ALL FOLD HERE ; 5.0.= I :!=- II 'c m -a -t % .~ RESISTIVITY nhm~ m2/m CON millim~ '," ' ',",j ,," :",' {"",~ "'U "!::;i",tII;lf!"li/I'¡;~;:"'~ltK:;II::l4-t~""I,·.··'II.F;IÜ"i;1'µWI'JìIU':ill~;DiiD' :!"!(lIÙ~I' 'lil' ItO· \!:III!.lfi~~' J{II:~;J1.tlûdUiili!1fJ~Ij¡\Iî.I;~!:i,lí,,;)¡1{ili~"', /~I1['I1:~;;;j4lIUlli;'U:'~:!', ':ill',::)~. .(".:)gJ~J1,,~f ',' !l,~I, ",~',~\., }J~:!~¡~ :A;I¡" ,,~~:<il~ ~~'- ,,'- ""."""">-. " '80 U 811:1, TEXAS '."'\.),~""'''11;",.::",,,,,,,, ,"X,,, ,""\ œ~~ - ;/ jJ/l/Ú/dÚh - rf/eet4iud/4? t,,_~T~,=:~ RECEIVED- ,'0 "-- ~~ ,...." '- -' ~.' ~'::WELLS9Li:()º!~NÀ)<ê~Ë~"i~t,1' î ~i . ..i::·i~íi19 f~~ ':FI~~I) ~~~k~rJ RIVER f]~I.~þC"'rIONSEG9 T7NR9W~ ~, .".,:.~.,,:'. ~ - ">-,~ ":Z""'" t: «~~ "'. ·',',·~COUNTY~ MAl p~ E"(;.lNCT ::f" ',:;E ~;, '0 ',5,,'1', .,A,T'E. >µ !- 2' N.o~ Idirfg ding :Jsured I urn. Iler !!åch ed )tiller åfûrri ll:s:ð::' ';' ¡ist ¡.BHT f c r. Los;~ -AM MN JND. Time Þ. ~ By \ ~ .- ( '-- ::: COMPANY S1ANJJARbOlL--" Other surveysf C.OMPANY OF CALI FORNI A . 5i,.,-C. GDt'--'. ",'1L-C Location of Well S'G{.. \I'-Q- OEe '7 1961 Petroleum Branch Division of Mines O~(': .'A:.,erals Alaska Dept. of Natural Ke::.J,uces ® Elevation: D.F.: K.B.: 142 orG.L: /22' ~ " ~ , ~ ÄJJAS(A FltINGNo. --- -.- - TWO "TH·REE &;-14-'; I 7~~...;.~' 1027' ----/1 O. 745 I 02 09 10, 272 ""63 47~ , n '72- 10272 I (}74t; fl1746 :K,~ 01] Ö"G h-I'4-~,',1 JO~09 '101£ !~Ýo 2Q to 2010 10210 f 0213 10201 IOGT2 Kß I(ß t.~M£ , ",l'llME ",'.',.,',"""'7"'-'é. ,',',,{;.. "0'7, ,·",I&:t,', 'j", J~'::)..;':":~; [' ·"·-":'h,'·..~ ", ".;' ~'7"" ~ 1..,~: ',,' .', ,'_: I ,~'::D f.6@,8ú qFl ø t@ijU OF ,;~ ·oJ.. 9@{ ':) ~'::¡ of U. ~ I ~5°F t,C;> ¡ "c.. @ ,C; ò':. of 1 6@ ::::{,OF "<.'> ,~" ".~" @ 'i~ C' OF 3- ."~ t:: ;¿°F ~",' '.~."I) ~~'~ r.,~ ",,:: 'o.-J~ \r~ ""--J i 3. @ OF 1.1' @ OF .~ -'3. :.."CC 30 min3 It 0 CC 30 min. ." : 7: q '". t r," ti ~ ¿: ~:~ ¡ .. 14 .:....1 34- I - ;''',. ,~ ,10:::.1 · ..... ~'} 0$ ,; ~:-:: :~ ,~:: ~: ~:é1 U ,@ OF @ of @ of @ OF @ OF CC 30 min. @ ()F @ of @ of @ of @ of CC 30 min. @ <I.... of @... of @ -""" of @, - of @ "-a OF CC 30 min. h~ ,j"' r ,;: ~\~..~ r 6F-F40 2 hrs 2662 ~LLLER , __J ., ..... i 1 3':)~r¿ ~~ -" ~),? , ~ ,.I _ ~ T ~~-. . .- , ".~. :\ - ~ to ; ~ t~ N ~ N 0 0 , -- r )
