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161-021
PLuG=ING & R~PORT Sta~a of Alaska ALA~Z~0iL & GA~ C~'~S~TION C~SSI~ ~, 13~ Io ! aA :.o, o ~'ei! }~ame Opera,or Lcca=iun ~ we~ ~ .=:" ~, an~- c-"""-~: on plu~=jinq, well Review ~-e ...... sca:us, ,an~ !oca=i:n c!eax-~nca - provide loc. clear., co~e., ~ell hea~ o~_: I~ .. , , -- Locan!cn CLe~ca: C~nc!usions: Coda .~~ · . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: SUSPENDED: ABANDONED: X SERVICE: 2. Name of Operator 7. Permit Number Unocal Oil Company of California (UNOCAL) -L~-6-1./300-131 j (~ ! --- ~ ~-~ 3. Address 8. APl Number P. O. Box 196247, Anchorage, Ak 99519 50- 133-10126-00 4. Location of well at surface 9. Unit or Lease Name 1 Soldotna Creek Unit 2520' FSL, 1970' FWL, Sec. 9, T7N, R9W, SM AtTOPsAMEPrOducing Interval i i/~~~i' 10.scuWell Number#323.9 At Total Depth~.~~ ' 11. Field and Pool SAME 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Swanson River Field/Hemlock and Tyonek 135' KB A-028997 12. Date Spuddeds/30/61 13' Date T'D' Reached I 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °fish°re I 16' N°' °f C°mpleti°ns7/8/61 6/27/00 "" NA foot MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10750'MD/10750'TVD 10216'MD/10216'TVD Yes: No: XI NA feet MD NA 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 0 32' To surf 0 11-3/4" 47# J-55 0 2009' 17-1/2" 1800 sx 0 7" 23-29# N-80 0 10748' 9-7/8" 1500 sx 0 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 10150'-10168' MD 6 spf, 0.34" dia hole 10150'-10168' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) ,~ I flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD => Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE => 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ,,: '::? 0 RI G INA L ,_ooo Alaska 0ii & Gas C0~s, Commission Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ,JUL 0 3 2000 Alaska Oil & G~s Co~s. Commissior~ 31. LIST OF ATTACHMENTS Wellbore schematic, Summary of Daily Operations 32. I hereby ~-~~~c~fY that the foreg,~ir~li~true and correct toiJ~/l/~].~~//i' ~ ~ ~ ~ ~1/~/I/I the best of my knowledge ~;~/~i~,/ Signed ~(/[J~V~"~J~"'~ Title Drilling Manager Date , Form 10-407 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". UNOCAL Alaska Drilling Drilling Summary Report SCU SCU #323-9 Abandonment 6/1/00 to 6/26/00 6/1/00 6/2/00 6/3/00 6/4/00 6/7/00 6/8/00 6/14-18/00 6/19-21/00 6/22/00 6/23/00 6~24~OO Pump 65 bbl water in tubing to kill well, tbg pressure fell from 1420 psi to vacuum. RU APRS. Set 2-7/8" bridge plug at 10,600'. Punch tubing with 8 holes from 10,437'-10,439'. Set 2-7/8" cement retainer at 10,400'. RD APRS. RU coil tubing unit. RIH with 1-3/4" coil and stinger with 6' of 1-3/4" straight bar. Could not penetrate SC-2P packer top at 10,260' ctm. POOH. Add 2-1/8" weight bars to eliminate coil memory problems. RIH and still could not pass through packer top at 10,260'. POOH. RU slickline and RIH with CT BHA, small bobble at 10,258' wlm but able to pass through to retainer at 10,406' wlm. POOH. Add one jt of 1-1/4' CS Hydril tubing to coil tubing BHA and round off stinger. RIH and made it through packer at 10,260' with no problem. Sting into retainer at 10,406'. Establish injection rate of 2.5 BPM at 1520 psi. Mix and pump 14.5 bbl of 15.8 ppg cement at 2 to 1.4 bpm and 2800 psi. Unsting and lay in last 0.8 bbl of cement on top of retainer while POH to 10,100'. Circ coil clean. POOH and RD CTU. RU slickline. RIH with 2.25" gauge ring. Tag top of cement at 10,390' wlm. Pull gas lift valve from lowest GLM at 9934'. RD slickline. Pump 220 bbl water into tUbing, no returns seen on annulus. Shut down. No further work on well until Permit to Drill approved and rig moves on. well. Turn-key rig move from SCU 22-4 location to 323-9. ND tree, NU BOPE. Repair choke manifold, general rig up. Test BOPE to 250 psi/4200 psi witnessed by Bo Brown-BLM. (Initial BOPE test to 5000 psi was waived and reduced to 4200 psi as per Bo Brown-BLM and Blair WondzelI-AOGCC). Accept rig at 06:00 hr on 6/23/00. Engage tubing hanger and pull packer free with 94K pull. Circ until well stable. Lay down tubing and packer. RU Schlumberger. Set 7" retainer at 10,216' elm. POOH and RD Schlumberger. RIH with cement stinger on 3-1/2" drill pipe.~~.~[ .~-~ ,JUL 03 2000 Alaska 0~t & Gas Co, is. Commission 6/25/00 6/26/00 Stab in to retainer at 10,214' dpm. Perform injectivity test at 2.6 BPM @ 1900 psi. Decide to increase cmt volume from 20 bbls to 30 bbls due to good injectivity, Mix and pump 30 bbls of 15.8 ppg cement with pressure increasing from 1800 psi to 2500 psi at 2.8 bpm, left 5 bbl on top of retainer. Unsting and POH 10 stands. Circ drill pipe clean with no cmt returns. POOH with drill pipe and stinger. RIH with two 6" mills. Tag cement at 10,155', drill firm cement from 10,155' to top of retainer at 10,214' dpm. Circ hole clean and prepare for oil-based mud changeover and setting of whipstock On top of retainer. 0 5 2000 Alaska Oi~ & Gas Cons. Oommission A. nchor~le UNOCAL RKB to TBG Hanger = 14.65' Tree connection = 2'7/8" 8rd DV @ 6,796' SIZE WT Swanson River Field Well # SCU 323-9 Abandonment as of 6/26/00 CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 20" Surf 32 11-3/4" 47 8rd Surf 2,009 7 29 N-80 Buttress Surf 288 7 26 N-80 Buttress 288 1,048 7 23 N-80 Buttress 1,048 4,715 7 26 N-80 Buttress 4,715 6,543 7 29 N-80 Buttress 6,543 8,369 7 29 · N-80/P-110 LSR 8,369 10,748 Tubing: G-1 G-2 Hemlock HB-1, HB-2, HB-3 HemlOck HB-5 Hemlock HB-8, HB-9, HB-10' aa 9 10 11 12 13 ¸15 16 17 18 19 TBG Cut @ Cmt Retainer @ 10,400' Tubing Punch @ 10,437' Bridge Plug @ 10,600' PBTD = 10,652' TD = 10,750' MAX HOLE ANGLE = Straight SCU 323-9 actual abdn 6-27-00.doc JEWELRY DETAIL NO. Top Depth Item 5 10216' 7" retainer 6 10,259 7 10,263 8a 10,310 8b 10,351 8c 10,359 9 10,364 10 10,371 11 10,379 12 10,419 13 10,436 14 10,441 15 10,448 16 10,557 17 10,576 18 10,583 19 10,589 20 10,624 Baker SC-2P Retrievable Packer Baker retrieving extension Baker CMU sliding sleeve (ID = 2.313") Baker X-nipple (ID = 2.313") Baker Telescoping Joint Bowen Series 150 Overshot Guide w/grapple Baker FH Packer Otis S nipple Position g2 ID = 2.313" Camco MM Gas Lift Mandrel Brown CC Safety Joint Baker FH Packer, Otis S nipple Position #1 ID = 2.313" Camco MM Gas Lift Mandrel Brown CC Safety Joint Baker FH'Packer Camco D Nipple ID -- 2.25" Baker Shear-out Sub TOP BTM ,,, 1, 0.3 2000 Alaska 0~t & Gas Cons. Commission PERFORATION DATA ,~chor~e .. ZONE SPF DATE COMMENTS 10,150 10,168 G-1 10,226 10,246 G-2 10,280 10,300 H-1 10,317' 10,343 H-2 10,351 10,364 H-3 10,388 10,434 H-5 10,455 10,545 H-8 10,554 10,580 H-9 10,592 10,620 H-10 W.S.'O @ 10,276' and 10,625' 2/7/98 Existing 9/17/96 Existing Existing Existing Existing Existing Existing Existing Existing REVISED: 06/27/00 DRAWN BY: TAB UNOCAL Alaska Drilling Drilling Summary Report SCU #323-9 Abandonment 611/00 to 6~26~00 6/1/00 Pump 65 bbl water in tubing to kill well, tbg pressure fell from 1420 psi to vacuum. RU APRS. Set 2-718" bridge plug at 10,600'. Punch tubing with 8 holes from 10,437'-10,439'. Set 2-718" cement retainer at 10,400'. RD APRS. 6~2~00 RU coil tubing unit. RIH with 1-314" coil and stinger with 6' of 1-314" straight bar. Could not penetrate SC-2P packer top at 10,260' ctm. POOH. 6~3~00 Add 2-118" weight bars to eliminate coil memory problems. RIH and still could not pass through packer top at 10,260'. POOH. RU slickline and RIH with CT BHA, small bobble at 10,258' wlm but able to pass through to retainer at 10,406' wlm. POOH. 6~4~OO Add one jt of 1-114' CS Hydril tubing to coil tubing BHA and round off stinger. RIH and made it through packer at 10,260' with no problem. Sting into retainer at 10,406'. Establish injection rate of 2.5 BPM at 1520 psi. Mix and pump 14.5 bbl of 15.8 ppg cement at 2 to 1.4 bpm and 2800 psi. Unsting and lay in last 0.8 bbl of cement on top of retainer while POH to 10,100'. Circ coil clean. POOH and RD CTU. 6/7100 RU slickline. RIH with 2.25" gauge ring. Tag top of cement at 10,390' wlm. Pull gas lift valve from lowest GLM at 9934'. RD slickline. 6~8~00 Pump 220 bbl water into tubing, no returns seen on annulus. Shut down. No further work on well until Permit to Drill approved and rig moves on well. 6/14-18/00 Turn-key rig move from SCU 22-4 location to 323-9. 6/19-21/00 ND tree, NU BOPE. Repair choke manifold, general rig up. UNOCAL Alaska Drilling Weekly Drilling Summary Report SCU #323-9 Abandonment and SCU #23A-9 Redrill 6~22~00 to 712100 6122/00 Test BOPE to 250 psil4200 psi witnessed by Bo Brown-BLM. (Initial BOPE test to 5000 psi was reduced to 4200 psi as per Bo Brown-BLM and Blair WondzelI-AOGCC). 6~23~00 Engage tubing hanger and pull FH packer at 9987' free with 94K pull. Circ until well stable. Lay down tubing and packer. 6/24/00 RU Schlumberger. Set 7" retainer at 10,216' elm. RIH with cement stinger on 3-112" drill pipe. 6~25~00 Stab in to retainer at 10,214' dpm. Perform injectivity test at 2.6 BPM @ 1900 psi. Decide to increase cmt volume from 20 bbls to 30 bbls due to good injectivity. Mix and pump 30 bbls of 15.8 ppg cement with pressure increasing from 1800 psi to 2500 psi at 2.8 bpm, left 5 bbl cmt on top of retainer. Unsting and POH 10 stands. Circ drill pipe clean with no cmt returns. 6~26~00 POOH with drill pipe. RIH with two 6"mills. Clean up tight spots at 5775' and 6236'. Tag cement at 10,155', drill firm cement from 10,155' to top of retainer at 10,214' dpm. Circ hole clean. 6~27~00 Change over well from water to 8.4 ppg oil-based mud. 6~28~00 POH with mills, observed 20k overpull at 6237'. Rotate and work pipe up to 5700' and back down to 6250' with no further signs of overpull. POOH and lay down mills. 6/29/00 RIH with whipstock milling assembly to 10198'. RU Schlumberger and Gryrodata. RIH with gyrO on E-line and orient whipstock face to 284 deg. POOH and RD wireline. Set down with whipstock on retainer at 10214' to set anchor. Shear off bolt with 35k down. Start milling window at 10,192'. 6/30~00 Mill window from 10192' to 10216' with 8.4 ppg mud. POOH with mills. Test BOPE to 3000 psi, witness waived by AOGCC and BLM. 711100 7~2~00 RIH with 6" Bit #1 on 3.06° Short-Pac motor. RU side entry sub and gyro on E- line. Drill from 10216' to 10306'. Pull Gyro and RD E-line. Continue drilling with MWD to 10418' with 8.4 ppg mud. Circ BU and POOH for new bit and BHA. RIH with Ultraslow motor at 1.5° ABH. Slide drill from 10418' to 10452' with 8.4 ppg mud at report time. FW: SCU 323-9 abandonment Version #2 Subject: FW: SCU 323-9 abandonment Version//2 Date: Fri, 9 Jun 2000 18:18:27 -0700 From: "Billingsley, Tim-Contract" <billita~unocal.com> To: "'Wondzell'" <blair_wondzell~admin. state.ak.us> > > From: Billingsley, Tim -Contract > Sent: Friday, June 09, 2000 5:17 PM > To: 'Maunder, Tom' > Subject: SCU 323-9 abandonment Version #2 > > Blair/Tom, (Approved Sundry Appr #300-131 5/18/00) > Due to the low tag of cement after the coil tubing abandonment, Unocal > proposes the revised abandonment procedure with the rig prior to >.sidetracking the well. > The rig will set a 7" cement retainer at the proposed sidetrack point and > pump more cement through the retainer. > Then the whipstock will be set on top of the retainer and the sidetrack > will be drilled. > (the first two files are schematics of the well as is today and with the > prOpOsed 7" retainer, the 3rd file is the proposed procedure with > additions/revisions from the already approved procedure in bold.) > <<SCU 323-9 proposed abdn as of 6-8-00. doc>> <<SCU 23A-9 proposed abdn > ver 2.doc>> > > <<General Abandonment Procedure 323-9 Ver 2.doc>> > > This last file is a daily summary of work done on the well to date. > <<SCU 23A-9 daily summary, doc>> > > Please let me know if this is acceptable before we commence rig operations > next Wednesday June 14. Name: SCU 323-9 proposed abdn as of 6-8-00.doc ~SCU 323-9 proposed abdn as of 6-8-00.doc Type: Microsoft Word Document - - (application/msword) Encoding: base64 ~SCU 23A-9 prop ,0,.sed abdn ver 2.d0c] Type: Microsoft Word Doctunent (application/msword) ~Encoding: base64 Name: General Abandonment Procedure 323-9 Ver 2.doc ~,General Abandonment Procedure 323-9 Ver 2.doc TyPe: Microsoft Word Document (application/msword) Encoding: base64 ~=. ] Name: SCU 23A-9 daily summary.doc I ~SCU 23A-9 daily summary.doc] Type: Microsoft Word Document (application/msword)i Encoding' base64 6/12/00 7:38 AM UNOCAL Alaska Drilling Drilling Summary Report SCU 23A-9 (Formerly SCU #323-9) 611/00 to 618100 6/1100 6~2~00 6~3~00 6/4/00 617100 618100 Pump 65 bbl water in tubing to kill well, tbg pressure fell from 1420 psi to vacuum. RU APRS. Set 2-718" bridge plug at 10,600'. Punch tubing with 8 holes from 10,437'-10,439'. Set 2-7/8" cement retainer at 10,400'. RD APRS. RU coil tubing unit. RIH with 1-3/4" coil and stinger with 6' of 1-314" straight bar. Could not penetrate SC-2P packer top at 10,260' ctm. POOH. Add 2-118" weight bars to eliminate coil memory problems. RIH and still could not pass through packer top at 10,260'. POOH. RU slickline and RIH with CT BHA, small bobble at t0,258' wlm but able to pass through to retainer at 10,406' wlm. POOH. Add one jt of 1-114' CS Hydril tubing to coil tubing BHA and round off stinger. RIH and made it through packer at 10,260' with no problem. Sting into retainer at 10,406'. Establish injection rate of 2.5 BPM at 1520 psi. Mix and pump 14.5 bbl of 15.8 ppg cement at 2 to 1.4 bpm and 2800 psi. Unsting and lay in last 0.8 bbl of cement on top of retainer while POH to 10,100'. Circ coil clean. POOH and RD CTU. RU slickline. RIH with 2.25" gauge ring. Tag top of cement at 10,390' wlm. Pull gas lift valve from lowest GLM at 9934'. RD slickline. Pump 220 bbl water into tubing, no returns seen on annulus. Shut down. No further work on well until Permit to Drill approved and rig moves on well. General Abandonment Procedure SCU 323-9 Version #2 6/9/00 1) 2) 3) 4) 5) 6) 7) 8) RU E-line. Set 2-7/8" bridge plug at 10,600', punch holes in tubing at 10,437'-10,439', and set cement retainer in 2-7/8" tubing at 10,400'. RU coil tubing, RIH and sting into cement retainer at 10,400'. Mix and pump cement to abandon Hemlock HB-8, HB-9 and HB-10 perforations. Appx cmt volume -- (10652'-10441 ') x .0371 bbl ft for 7" 29# = 7.8 bbl (10441'-10259') x .00579 bbl ft for 2-7/8" tbg = 1.1 bbl Total cmt volume = 8.9 bbl. Actual cement pumped = 14.5 bbl Displace cement with water, leaving appx 0.8 bbl of cement above retainer at 10,400'. Unsting from retainer and PU to 10259', circ out any excess cement. POOH and rig down coil tubing unit. Tag top of cement (tagged at 10,390' wlm on 6/7/00). Pull lowest GLV at 9934'. Check injectivity into well, pumped 220 bbl water down tubing with no returns up annulus. Well on vacuum. Shut down operations on well on 6/8/00. Proposed Additional Abandonment as of 6/9/00 9) 10) 11) 12) Move in Inlet Drilling Rig #CC-1. NU and Test BOPE. Pull completion tubing and retrievable packer at 9987'. RU e-line and set 7" cement retainer at 10,218'. 13) RIH with drill pipe and sting into retainer at 10,218'. 14) Establish injection rate through retainer. 15) Mix and pump appx 21 bbls of cement through retainer. Volume of cmt = .0371 bbl/ft 7" csg cap x (10583' packer -10,218')= 14 bbls. Use 50% excess for 21 bbls. Appx 14 bbls have already been pumped below the 2-7/8" retainer at 10,400' 16) Displace cement to retainer at 10,218'. Unsting drill pipe and circulate drill pipe and top of retainer clean of cement. POOH with drill pipe and stinger. RIH with 7" whipstock on drill pipe and set whipstock on top of retainer at 10,218'. 18) Mill window at 10,218' and commence horizontal redrill of SCU #23A-9. RKB to TBG Hanger = 14.65' Tree connection = 2-7/8" 8rd DV ~ 6,796' SIZE WT Swanson ~,~ver Field Well # SCU 23A-9 (Formerly 323-9) Proposed Retainer CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 20" 11-3/4" 47 7 29 7 26 7 23 7 26 7 29 7 29 Tubing: Surf 32 8rd Surf 2,009 N-80 Buttress Surf 288 N-80 Buttress 288 1,048 N-80 Buttress 1,048 4,715 N-80 Buttress 4,715 6,543 N-80 Buttress 6,543 8,369 N-80/P-110 L8R 8,369 10,748 Proposed Retainer ~ 10,218' 6 7 8a 8b 9 10 11 12 13 14 15 TBG Cut 10,366' Cmt Retainer ~ 10,400' Tubing Punch ~ 10,437' Hemloek,/~ 16 HB-8, HB-9? 17 18 HB-10 'x~ 19 20 Bridge lO,6OO' PBTD -- 10,652' TD = 13,821' MAX HOLE ANGLE = Straight SCU 23A-9 proposed abdn ver 2 NO. Top Depth 5 10218' 6 10,259 7 10,263 8a 10,310 8b 10,351 8c 10,359 9 10,364 10 10,371 11 10,379 12 10,419 13 10,436 14 10,441 15 10,448 16 10,557 17 10,576 18 10,583 19 10,589 20 10,624 JEWELRY DETAIL Item 7" retainer Baker SC-2P Retrievable Packer Baker retrieving extension Baker CMU sliding sleeve (ID = 2.313") Baker X-nipple (ID = 2.313") Baker Telescoping Joint Bowen Series 150 Overshot Guide w/grapple Baker FH Packer Otis S nipple Position #2 ID = 2.313" Cameo MM Gas Lit~ Mandrel Brown CC Safety Joint Baker FH Packer, Otis S nipple Position #1 ID = 2.313" Camco MM Gas Lit~ Mandrel Brown CC Safety Joint Baker FH Packer Camco D Nipple ID = 2.25" Baker Shear-out Sub PERFORATION DATA TOP BTM ZONE 10,150 10,168 G-1 10,226 10,246 G-2 10,280 10,300 H-1 10,317 10,343 H-2 10,351 10,364 H-3 10,388 10,434 H-5 10,455 10,545 H-8 10,554 10,580 H-9 10,592 10,620 H-10 W.S.O~10,276'and 10,625' SPF DATE COMMENT.,S 2/7/98 Existing 9/17/96 Existing Existing Existing Existing Existing Existing Existing Existing REVISED: 06/12/00 DRAWN BY: TAB RKB to TBG Hanger = 14.65' Tree connection -- 2-7/8" 8rd DV ~ 6,796' 3 4 5 Tag TOC 10,390' wlm 6/7/00 Retainer @ 10,400' 6/1/00 HB-5 Tbg Punch @ 10,437'- 10439' 6/1/00 HB-8 HB-9 HB-10 Bridge plug @ 10,600' 6/1/00 8a TBG Cut @ 366' 10 11 12 13 14 15 16 17 18 19 20 Top of fill @ 10,624' WLM 5/11/00 PBTD = 10,652' TD = 13,821' MAX HOLE ANGLE = Straight SCU 323-9 proposed abdn as of 6-8-00 SIZE WT Swanson ~uver Field Well # SCU 323-9 Proposed Abandonment, As of 6/7/00 CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 20" 11-3/4" 47 7 29 7 26 7 23 7 26 7 29 7 29 Tubing: 2-7/8" 6.5 2-7/8" 6.5 2-7/8" 6.5 NO. Top Depth 1 14.65 2 3 9,987 4 10,033 5 10,065 6 10,259 7 10,263 8a 10,310 8b 10,351 8c 10,359 9 10,364 10 10,371 11 10,379 12 10,419 13 10,436 14 10,441 15 10,448 16 10,557 17 10,576 18 10,583 19 10,589 20 10,624 Surf 32 8rd Surf 2,009 N-80 Buttress Surf 288 N-80 Buttress 288 1,048 N-80 Buttress 1,048 4,715 N-80 Buttress 4,715 6,543 N-80 Buttress 6,543 8,369 N-80/P-110 L8R 8,369 10,748 L-80 Buttress Surf L-80 Buttress 10,259 N-80 EUE 8rd ABC 10,366 JEWELRY DETAIL Item 10,065 10,365 10,623 Tubing hanger with Cameron BPV profile Camco MMM Gas-Lift Mandrels with 10' pups @ 1,640', 2,669', 3,662', 4,657', 5,429', 6,046', 6693', 7,373', 8,017', 8670', 9,318', 9,934' with live gas lift valves Baker FH (50K) Retrievable Packer Baker X-Nipple profile (ID = 2.313") Baker Wireline Re-entry guide Baker SC-2P Retrievable Packer Baker retrieving extension Baker CMU sliding sleeve (ID = 2.31Y') Baker X-nipple (ID = 2.313") Baker Telescoping Joint Bowen Series 150 Overshot Guide w/grapple Baker FH Packer Otis S nipple Position #2 ID = 2.313" Camco MM Gas Lift Mandrel Brown CC Safety Joint Baker FH Packer, Otis S nipple Position # 1 ID = 2.313" Camco MM Gas Lift Mandrel Brown CC Safety Joint Baker FH Packer Camco D Nipple ID = 2.25" Baker Shear-out Sub PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 10,150 10,168 G-1 10,226 10,246 G-2 10,280 10,300 H-1 10,317 10,343 H-2 10,351 10,364 H-3 10,388 10,434 H-5 10,455 10,545 H-8 10,554 10,580 H-9 10,592 10,620 H-10 W.S.O@10,276'and 10,625' 2/7/98 Existing 9/17/96 Existing Existing Existing Existing Existing Existing Existing Existing REVISED: 06/12/00 DRAWN BY: TAB Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager May 15, 2000 ,~:.,~.~ ~ & Gas Co~,,.'s. Anchorage Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Re: Commissioner Robert N. Christenson Application for Abandonment (Form 10-403) Swanson River Field Soldotna Creek Unit #323-9 Commissioner Christenson: Enclosed is the Sundry Notice (Form 10-403) relating to the abandonment of Soldotna Creek Unit Well #323-9. It is proposed to abandon the current SCU #323-9 wellbore in order to sidetrack the well and drill a horizontal gas producer in the Hemlock Bench 5 interval which will be named SCU #23A-9. This well is currently a vertical well producing from commingled open perforations in the G-l, G-2 and Hemlock Benches 1 through 10 as shown on the attached schematic. It is proposed to set a cement retainer in the 2-7/8" tubing at 10425' (below the Hemlock Bench 5 perforations). Then sting into the retainer with coil tubing and pump cement to abandon the HB-8 through HB-10 perforations. More cement will be left inside the 2-7/8" tubing on top of the retainer. The objective is to isolate the HB-8 through HB-10 intervals in the old Wellbore because of possible future water production. The new sidetrack well will be relatively close to the old wellbore and will be drawing down the HB-5 reservoir pressure. If sufficient isolation in the old SCU 323-9 wellbore is not present, water production from HB-8 through HB-10 may be drawn up through the old wellbore and crossflow through the HB-5 reservoir into the new horizontal wellbore. A cement bond log indicates good cement isolation between all zones outside the 7" casing in SCU #323-9. The Hemlock and G zone intervals are commingled throughout the field and abandonment of individual zones is not required from a reservoir management standpoint except for the possibility of water production from the lower Hemlock as mentioned above. After the coil tubing cement placement is completed, the drilling rig will move in and pull the 2-7/8" tubing and top packer. A bridge plug will be set between the G-1 and G-2 perforations and a whipstock will be set on top of the bridge plug to sidetrack the well. The expected start date for this well is June 10, 2000 so your timely consideration for approval is appreciated. If there are any questions, please contact Dan Williamson at 263- 7677 or Tim Billingsley at 263-7659. Dan Williamson Drilling Manager AOGCC cover letter 323-9 abdn.doc Tim Billingsley 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: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: x Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: x 135 feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Soldotna Creek Unit Anchorage, AK 99519-6247 Service: 4. Location of well at surface 8. Well number 2520' FSL & 1970' FWL of Sec. 9, T7N, R9W, SBM SCU 323-9 At top of productive interval 9. Permit number Same 21-61 1{~ I"' C,~' At effective depth 10. APl number Same 50- 133-10126-00 At total depth 11. Field/Pool Same Swanson River/Tyonek 12. Present well condition summary Total depth: measured 13821 feet Plugs (measured) true vertical 13821 feet Effective depth: true verticalmeasured 10652 10652 feet feet Junk(measured) 0 IRGI NAL Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 32' 20" 32' 32' Surface 2009' 11-3/4" 1800 sx 2009' 2009' Intermediate Production 10748' 7" 1500 sx 10748' 10748' Liner .... Perforation depth: measured See schematic .~ true vertical Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 at 10065' f, AAY ~ 5 200 . Packers and SSSV (type and measured depth) Baker Model FH @ 9987' ':13. Attachments Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 6/10/00 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I herelg~f,~ertify t .~i'~regoing is true and correct to the best of my knowledge. Signe~(- 1~' ~"~ Williamson Title: Drilling Manager 5"' 15 "'~ Date: FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative~ may witnessIlAppr°~al Plug integrity... ~ BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- /~ '1 ORIGINAL StGNEb b'~'" 'Approved by order of the Commissioner ~ Taylor Seamoum ' Commissioner Date '~'d ¢'-"~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE General Abandonment Procedure SCU 323-9 ) 2) 3) ) 5) 6) 7) 8) 9) 10) 11) 12) RU E-line and set cement retainer in 2-7/8" tubing at 10,425'. RU coil tubing, RIH and sting into cement retainer at 10,425'. Mix and pump cement to abandon Hemlock HB-8, HB-9 and HB-10 perforations. Appx cmt volume = (10652'-10441') x .0371 bbl ft for 7" 29# = 7.8 bbl (10441'-10259') x .00579 bbl ft for 2-7/8" tbg = 1.1 bbl Total cmt volume = 8.9 bbl. Displace cement with water, leaving appx 1 bbl of cement above retainer at 10,425'. Unsting from retainer and PU to 10259', circ out any excess cement. POOH and rig down coil tubing unit. Move in Inlet Drilling Rig #CC-1. NU and Test BOPE. Pull completion tubing and retrievable packer at 9987'. RU e'line and set 7" bridge plug at approximately 10,177'. RIH with 7" whipstock on drill pipe and set whipstock on top of bridge plug at 10,177', Mill window at 10,177' and commence horizontal redrill of SCU #23A-9. UNOCALe RKB to TBG Hanger = 14.65' Tree connection = 2-7/8" 8rd DV @ 6,796' 3 q 4 5 6 lO, 'z.~'/ 7 TBG Cut @ 10,366' 8b 9 10 11 Px-Plug Pulled 9/6/99 12 13 14 tO, t~ ~, 15 16 17 18 19 20 PBTD = 10,652' TD = 13,821' MAX HOLE ANGLE = Straight SCU 323-9 schematic.doc SIZE. WT Swanson River Field Well # SCU 323-9 Actual Completion 9/11/96 CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 20" 11-3/4" 47 7 29 7 26 7 23 7 26 7 29 7 29 Tubing: 2-7/8" 6.5 2-7/8" 6.5 2-7/8" 6.5 NO. Top Depth 1 14.65 2 3 9,987 4 10,033 5 10,065 6 10,259 7 10,263 8a 10,310 8b 10,351 8c 10,359 9 10,364 10 10,371 11 10,379 12 10,419 13 10,436 14 10,441 15 10,448 16 10,557 17 10,576 18 10,583 19 10,589 20 10,624 Surf 32 8rd Surf 2,009 N-80 Buttress Surf 288 N-80 Buttress 288 1,048 N-80 Buttress 1,048 4,715 N-80 Buttress 4,715 6,543 N-80 Buttress 6,543 8,369 N-80/P-110 L8R 8,369 10,748 L-80 Buttress Surf 10,065 L-80 Buttress 10,259 10,365 N-80 EUE 8rd ABC 10,366 10,623 JEWELRY DETAIL Item Tubing hanger with Cameron BPV profile Camco MMM Gas-Lift Madnrels with 10' pups @ 1,640', 2,669', 3,662', 4,657', 5,429', 6,046', 6693', 7,373', 8,017', 8670', 9,318', 9,934' with live gas lift valves Baker FH (50K) Retrievable Packer Baker X-Nipple profile (ID = 2.313") Baker Wireline Re-entry guide Baker SC-2P Retrievable Packer Baker retrieving extension Baker CMU sliding sleeve (ID = 2.313") Baker X-nipple (ID = 2.313") Baker Telescoping Joint Bowen Series 150 Overshot Guide w/grapple Baker FH Packer Otis S nipple Position g2 ID = 2.313" Camco MM Gas Lift Mandrel Brown CC Safety Joint Baker FH Packer, Otis S nipple Position # 1 ID = 2.313" Camco MM Gas Lift Mandrel Brown CC Safety Joint Baker FH Packer Camco D Nipple ID = 2.25" Baker Shear-out Sub PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 10,150 10,168 G-1 6 2/7/98 Existing 10,226 10,246 G-2 4 9/17/96 Existing 10,280 10,300 H-1 Existing 10,317 10,343 H-2 Existing 10,351 10,364 H-3 Existing 10,388 10,434._.. H-5 Existing 10,455 10,545 H-8 Existing 10,554 10,580 H-9 Existing 10,592 10,620 H-10 Existing W.S.O @ 10,276' and 10,625' REVISED: 05/14/00 DRAWN BY: TAB UNOCAL ) Swanson River Field Well # SCU 323-9 Proposed Abandonment, 6/2000 RKB to TBG Hanger = 14.65' Tree connection = 2-7/8" 8rd DV @ 6,796' 3 4 5 TBG Cut 10,366' Proposed Cmt @ 10,425' aa 8b 9 10 11 12 13 14 15 ' Hemlock/~ 16 HB-8? 17 HB-9 18 HB-10 X~ 19 20 PBTD = 10,652' TD = 13,821' MAX HOLE ANGLE = Straight SCU 323-9 proposed abdn.doc CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 20" 11-3/4" 47 7 29 7 26 7 23 7 26 7 29 7 29 Tubing: 2-7/8" 6.5 2-7/8" 6.5 2-7/8" 6.5 NO. Top Depth 1 14.65 2 3 9,987 4 10,033 5 10,065 6 10,259 7 10,263 8a 10,310 8b 10,351 8c 10,359 9 10,364 10 10,371 11 10,379 12 10,419 I3 10,436 14 10,441 15 10,448 16 10,557 17 10,576 18 10,583 19 10,589 20 10.624 Surf 32 8rd Surf 2,009 N-80 Buttress Surf 288 N-80 Buttress 288 1,048 N-80 Buttress 1,048 4,715 N-80 Buttress 4,715 6,543 N-80 Buttress 6,543 8,369 N-80/P-110 L8R 8,369 10,748 L-80 Buttress Surf L-80 Buttress 10,259 N-80 EUE 8rd ABC 10,366 JEWELRY DETAIL Item 10,065 10,365 10,623 Tubing hanger with Cameron BPV profile Camco MMM Gas-Lift Madnrels with 10' pups @ 1,640', 2,669', 3,662', 4,657', 5,429', 6,046', 6693', 7,373', 8,017', 8670', 9,318', 9,934' with live gas lift valves Baker FH (50K) Retrievable Packer Baker X-Nipple profile (ID = 2.313") Baker Wireline Re-entry guide Baker SC-2P Retrievable Packer Baker retrieving extension Baker CMU sliding sleeve (ID = 2.313") Baker X-nipple (ID = 2.313") Baker Telescoping Joint Bowen Series 150 Overshot Guide w/grapple Baker FH Packer Otis S nipple Position g2 ID = 2.313" Camco MM Gas Lift Mandrel Brown CC Safety Joint Baker FH Packer, Otis S nipple Position #1 ID = 2.313" Camco MM Gas Lift Mandrel Brown CC Safety Joint Baker FH Packer Camco D Nipple ID = 2.25" Baker ,qhear-nnt ,Ri]]') PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 10,150 10,168 G-1 6 2/7/98 Existing 10,226 10,246 G-2 4 9/17/96 Existing 10,280 10,300 H-1 Existing 10,317 10,343 H-2 Existing 10,351 10,364 H-3 Existing 10,388 10,434 H-5 Existing 10,455 10,545 H-8 Existing 10,554 10,580 H-9 Existing 10,592 10,620 H-10 Existing W.S.O @ 10,276' and 10,625' REVISED: 05114/00 DRAWN BY: TAB AIqD P&S STORAGE Equ*mJd~:~rr) f~* 46' 2~70000 ROAD . PIT SHOP .-.. WASTE DIS~POSAL 11oll ., · ! / ! I I / / I · i UNOCAi. O KENN PENINSULA SWANSON RIVER FIELD nil .qPll I 24~000 $0' 42'~/ 1RY-2;798 FRI 11:13 1. Type of Request: z N,m~"of O~or Unocal 3. Address UNOCFtL RSSET GRS GRP FRX NO. 9072637874 F. U1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION ~,OMMISSION APPLICATION FOR SUNDRY APPROVALS iii .liar :--: PO Box 198247 Anchorage, Alaska, 0519-6247 . Slretlgraphio: -.--. S?ce:. X ,, 4. Locatie~ of well at surface 2620' FNL, lgT0' FEI., Sec. 0, TTN, R~W, SM At top of Productive interval ~traJgh( Hole At effective depth At total depth i~ Preset Well"cend'ition surnma~ Total depth: measured trna. vertical Effective depth: measured true vertical 10,3'60' feet 10,760' feet 10.662' feet 10,662' feet Soldotna Creek Unit 8. Well number $¢U 323-I 10. APl number 60.133-t0128.00 11. Field/Peel Swanson,, ,RI, ,ve,r / H..amlock Plugs (measured) 10,662' Junk (measured) Cor~Jotor 32' Surfae.,e 2,009' Production 10,748' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Size Cemented 20" yes t1-3/4" 60 sx 7" 6005x 900sx Measured depth 2,008' 10,74~' OV ~ ~,7~ True vertical depth 32' 2,000' 10,748' RECEIVED 10,388' - 10~134'; 10,466' - 10,680; 10J92' - 10,620' 10,388' - 10.434'; 10,466' . 10,680; 10,692' - 10,620' 3-1/2" 8.2~, N-~O ~ 8,388'; 2.?/8", 6.8 #. N-BO ~ 10,$24' Packers and SSSV (type and measured del~h) 1:3: Attm~ementa .... DeScfipfion'~ry of I~r~i x Detailed operatlona program: '~' Jr'. Estimated'date fir commencing opemtton I 15. Status of well olass'i~ May 8, 16, if proposal welt v'~rbally approved: ....... i Oi1:~ Oas: I Name of a~.,Qv~ ....... Date ~ I Sen, ice: Oas In,actor 17. I hereby certify that the foregoing hi true and correct to the best of my ImoMedge. i. ~: ~/'~z_...~_. O~O..L_. Title: DrimngManager ! i:i/ ..... .,. ' .... FSR. COMMiss~o'.Us~ 0.'~Y'" ICond'~lone of approval: Notify Commission so representative may witness Plug integrity BOP Test.~__. Location clearance . Mechanical Integrity Test_ ....... :: Su__hsequ_~ ent form requtrod 10-~ . ..................... · :Post-it' Fax Note 7/671 ^p ,~eved Form t0-4o3 Rev 06/1.~88 AUG 1 3 1996 Naska Oil & Gas Cons. Commission Anchorage 2-Z/8" x 7' 29 # Baker "FH' packer~ ~ 10,285', 10,372', 10,442', & 10,663' BOP sket©h: x Suspemled: ...... Date: 13-A,ug-~6 rv ,AY 2 2 1998 Aia$~ ~)Jl & Gas .Cons. ~ctiorage MAY-22-98 FRI 11:14 UNOCflL ASSET GAS GRP FAX NO, 9072637874 V. U2 Soldotna Creek Unit Well 323-9 Workover: Reeomplete Hemlock C-as Injector to Tyonek Oil Producer Procedure Status:Draft #2 Date: 06-May-96 By: S.S. Lambe Facilities Improvement: 14~t~or..k.. 1) Lay inflowline 0600') and header valves, l:~,esmre test to 80% ofyield. SI injection gas one week prior to sta~dng ~rkover. 3) Convert existing blow downlines to lank battery to production lines. Prepare and Kill Well for Workover Rig: 4) Rigup slicldinc. Pressure test BOP's and lubricator to 5000 psi. MU 2.3" Gauge ting. RIH and gauge tubing to 'D' nipple at 10,589'. ?OON. RD slickline. RU E-Line unit. Pressure test to 5000 psi. Establish Safeguards for handling perforating guns. MU APRS's chemical curer dressed for 2-7/8", 6.5 # tubing on SCHLUMBBRGER's N-line. RIH and cut the tubing at 10,366'. RD E-Line. RU pump/ng equipment. Pressure test hardlines to 6000 psi. Bull head 30 bbb xylcne down tubing displaces with 80 bbls produced water at 2 bpm. SI well and let xylene soak around 7) Bleed casing pressure. Fill annulus with produced wnter. As pressure incre~es, Meed off. RU slicklinc unit. Pressure test lubricaton MU dual pressure and single tcmp bombs. RIH and obtain pressure and temperature ~ 10,300'. POOH and read charts. MU 2-7/8" nominal shifting tool dressed bt OTIS XA sleeve ~ 10,217', RIH and shift sleeve up to open. Monitor casing pressure for communicaQon response. RD slickline. IO) Circulate kill weight fluid down tubing taking returns from 3-I/2" x 7" annulus to remove any residual gas. Spot salt based LCM's as required to control fluid loss. Ensure well is dead and holds a column of fluid, Rig Workover: 11) M1RU workover rig. RU lines ~o pump down tubing and take annular returns. Bleed any gas pressure and circulate down tubing ~_king returns up casing. Spot salt based LCM's as required. Ensure well is dead, Set a back pres,mm valve in hang~r profile or plug in the tubing for well control, Nipple down tree and nipple up BOP stack. Function and presswe stack to 250 psi an Pul! back pressure valve or tubing plug as noted in step #12. R J]IVE, D MAY 22 1998 A~aska Oil & Gas Cons. uo~ Anchorage tihY-22-98 FRI 11:14 , / UNOOhL flSSET GhS GRP FflX NO. STATE OF ALASKA AI..~SKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1, Operations performed: Operation shutdmvn: Stimulate: Pull tubing: X Alter c'~,~,i,n,g,i,,' 2. Name of Operator Union Oil Company of Calilomla (Uno. al) 3, A~ldress P.O, Box 196247 Anchorage, AK 99519 4:-L'~)c~'tion of well at surface 2520' FNL, 1970' FEL, Sec. 9, T7N, Rgw, SM At top of produotive interval Straight hole At effective depth At total depth i2. Pr, s,m w,, co..~uon '"mm,,~ ........... Total dapt~: measured true vertical Plugging: Repair well: 6. Type of Well: Development: I Exploratory:. Stratigraphio: ~ Servia; ..... 10750 feet Plugs (measured) 1035Z 10750 feet 1065Z Perforate: X Other: ~. Datum elevati~'(DF or KB) ' 14.65 KB feet 7. Unit or Property name Soldo~ne Creek Unit . .,m : ::_ ..... :: r : : Well number eCU 323,9 614301/96~169 '~ 0:"~,'PI' n'~mber ' ' 5O- 133-I012~,00 Swanson River/Tyonek .-Hemlock : Effective depth: measured 10652 feet Junl< (measured) true vertical 10652 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conduotor 32' 20' Yes 32' 3Z Surface 2009' 11-3/4" 60 sx 2009' 200g' Intermediate 600 sx 10748' Produotion 10748' 7" 90{3 sx DV {~ 6796 10748' Liner Perforation depth: measured 10,388'.10,434': 10,455'-10,580'; 10,59Z-10,620'; 10,226'-10,246' true vertical 10,388'-10,434'; 10,455'-10,580'; 10,592'-10,620'; 10,226'-10,246' Tubing (size, grade, and measured depth) 2-7/8". 6.~ L-8010,065'; 2-718" 6.5~ L-80 10,264'-10,372'; 2-7/8" 6.5~ 10,371'.10,624' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Baker FH ~ gg8T; Baker $C-2P ~ 1025g'; Baker FH ~ 10371'; Baker FH 10,441'; Baker FH 10,583' . ..-._ ........... . Intervals treated (measured) NIA Treatment description including volumes used and final pressure NIA ............ iii i1[ 14. R~presentative Daily Avemae Pr~=tion or Inieotlon Data OiI-BBL Gas-Mcf Wataf-Bbl Casing Pressure Tubing Pressure Prior to well operation Inject 0 23,748 0 2200 4280 483 328 5 550 280 '~ ~'.' 'Status of welt clarification as; _ Subsequent t_o O,l~,ra, ti~ ...... Pr~uce ..... 15. Attachments: Copies of Log~ end Surveys run; ~ Dai.ly Report of Well Operations; x Gas: suape~: ., S ,er~ce: 17:! hereby <~,rtify that the foregoing Is true and correct to the best of my know~edge: Form 10-404 Rev 06/15/88 Alaska 0il & Gas Cons. Anchora.Qe Date: Oct. 10, 1998 SUBMIT IN DUPLICATE STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: X 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 14.65 KB 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 2520' FNL, 1970' FEL, Sec. 9, T7N, R9W, SM SCU 323-9 At top of productive interval 9. Permit number/approval number Straight hole ORIGINAL At effective depth 10. APl number 50- 133-10126-00 At total depth 11. Field/Pool Swanson River/Tyonek-Hemlock 12. Present well condition summary Total depth: measured 10750 feet Plugs (measured) 10352' true vertical 10750 feet 10652' Effective depth: measured 10652 feet Junk (measured) true vertical 10652 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 32' 20" Yes 32' 32' Surface 2009' t 1-3/4" 60 sx 2009' 2009' Intermediate 600 sx 10748' Production 10748' 7" 900 sx DV @ 6796 10748' Liner Perforation depth: measured 10,388'-10,434'; 10,455'-10,580'; 10,592'-10,620'; 10,226'-10,246' true vertical 10,388'-10,434'; 10,455'-10,580'; 10,592'-10,620'; 10,226'-10,246' Tubing (size, grade, and measured depth) 2-7/8", 6.5~ L-80 10,065'; 2-7/8" 6.5¢f L-80 10,264'-10,372'; 2-7/8" 6.5~ 10,371'-10,624' Packers and SSSV (type and measured depth) Baker FH @ 9987'; Baker SC-2P @ 10259'; Baker FH @ 10371'; Baker FH 10,441'; Baker FH 10,583' ~ · p, ~ 13. Stimulation or cement squeeze summary R[~CEiV ~l) Intervals treated (measured) N/A 0C T ?- ?- 1996 Treatment description including volumes used and final pressure N/A .... ,,. n. · ~.~.~ cons. Commission 14. Representative Daily Average Production or Injection Data ~'~ ...... ARchorag6 OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Inject 0 23,746 0 2200 4280 Subsequent to operation Produce 483 328 5 550 260 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 /~.~,~ ~ ~ cl,/~ Title: Drilling Manager Date: Oct. 10,1996 Form 1~)-404 Rev 06/15/88 SUBMIT IN DUPLICATE UNOCAL ) Swanson River Field Well # SCU 323-9 Actual Completion 9/11/96 TBG Cut 10,366' RKB to TBG Hanger = 14.65' Tree connection = 2-7/8" 8rd 1 2 ... ! ::::::: X DV ~ 6,796' 3 4 5 6 7 CaCo3 Px-Plug 8b 9 10 11 12 13 14 15 16 17 18 19 20 PBTD = 10,652' TI) = 13,821' MAX HOLE ANGLE = Straight SIZE WT 20" 11-3/4" 47 7 29 7 26 7 23 7 26 7 29 7 29 Tubing: 2-7/8" 6.5 2-7/8" 6.5 2-7/8" 6.5 NO. Top Depth 1 14.65 2 3 9,987 4 10,033 5 10,065 6 10,259 7 10,263 8a 10,310 8b 10,351 8c 10,359 9 10,364 10 10,371 11 10,379 12 10,419 13 10,436 14 10,441 15 10,448 16 10,557 17 10,576 18 10,583 19 10,589 20 10,624 TOP BTM CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM Surf 32 8rd Surf 2,009 N-80 Buttress Surf 288 N-80 Buttress 288 1,048 N-80 Buttress 1,048 4,715 N-80 Buttress 4,715 6,543 N-80 Buttress 6,543 8,369 N-80/P-110 L8R 8,369 10,750 L-80 Buttress Surf L-80 Buttress 10,259 N-80 EUE 8rd ABC 10,366 JEWELRY DETAIL Item 10,065 10,365 10,623 Tubing hanger with Cameron BPV profile Gas-Lift Madmels with 10' pups ~ 1,640', 2,669', 3,662', 4,657', 5,429', 6,046', 6693', 7,373', 8,017', 8670', 9,318', 9,934', Baker FH (50K) Retrievable Packer Baker X-Nipple profile (ID = 2.313") Baker Wireline Re-entry guide Baker SC-2P Retrievable Packer Baker retrieving extension Baker CMU sliding sleeve (ID = 2.313") Baker X-nipple OD = 2.313") Baker Telescoping Joint Bowen Series 150 Overshot Guide w/grapple Baker FH Packer Otis S nipple Position #2 ID = 2.313" Camco MM Gas Lift Mandrel Brown CC Safety Joint Baker FH Packer, Otis S nipple Position #1 ID = 2.313" Camco MM Gas Lift Mandrel Brown CC Safety Joint Baker FI-I Packer Camco D Nipple ID = 2.25" ZONE SPF DATE COMMENTS 10,150 10,170 G-1 10,226 10,246 G-2 10,280 10,300 10,317 10,343 10,351 10,364 10,388 10,434 10,.455 10,545 10,554 10,580 10,592 10,620 W.S.O~10,276' and 10,625' O ?ff)RILL1NG\SCHEMATIC\GP\GPP\SC3239A2.DOC Proposed Existing Existing Existing Existing Existing Existing Existing Existing REVISED: 9/24/96 DRAWN BY: MWD Sheet1 Well 8/8/96 8/9/96 8/13/96 8/14/96 8/15/96 8/16/96 8/16/96 Unocal Corporation Well History Report Swanson River-SCU--323-9 Page: 1 Pressure tested tubing shanger seals to 5000 psi. for 10 minutes with no bleed off, bled to 0 psi.. Pressure tested hanger and seals between surface and production casings to 3000 psi. for 10 minutes with no bleed off. Began bleeding gas from surface casing past seals while bleeding off test pressure, bled to 0 psi. Attempted to pressure seal between surface and production casing with negative results, would not hold pressure. Would pressure to 1800 psi. while pumping with hand pump and bled to 800 psi. in 5 m/ns. 2600 psi. on production casing with no communication past seals. Installed 2 pen recorder on tubing and production casing. Shut well in @ 1600 hrs., 3100 psi. tbg., 2600 psi. pc.. TRAVEL TO SWANSON RIVER / SCU 323-9, TBG = 3200 PSI, PC = 1750 PSI / R/UP DOWELL BLENDER & VECO PUMP TRK / BLEED PC T/1500 PSI (ALL GAS) SHUT IN FOR 10 MIN (NO BUILD UP) / BLEED PC T/1300 PSI (ALL GAS) SHUT IN FOR 10 MIN (NO BUILD UP / BLEED PC T/1250 PSI & WELL BEGAN TO FLOW OIL, SHUT IN / TBG 3175 PSI / PC 1250 PSI @ 0800 HRS / COMPLETED R/UP OF PUMP EQUIP & MIXED SIZED SALT PILL / HELD SAFTY MEETING / PUMPED 30 BBLS SIZED SALT PILL W/25PPB BRIDGESAL, 16PPB PLUG SAL REG & 12PPB PLUG SALX & DISPLACED W/88 BBLS OF LEASE H20 / SHUT DN / TBG = 775 PSI, PC = 1375 PSI / R/UP HOWCO SLICKLINE & TESTED LUB. T/4000 PSi (OK) / RIH WI 2.3" GUAGE RING TO "D" NIPPLE @ 10589' W/NO PROBLEMS/POOH & SECURE WELL & SHUT DN FOR THE NIGHT, TBG =190 PSI , PC = 1490 PSI, SC = 30 PSI R/UP SWS & TESTED LUB. T/4000 PSI RIH W/GR-CCL / BLEED PC F/1490 PSI T/ 950 PSI IN 50 PSI INCREMENTS (ALL GAS) / LOGGED INTERVAL F/10450' T/9300' W/GR-CCL / HELD SAFTY MEETING / M/UP APRS 2-1/8" CHEMICAL CUTTER & RIH / MADE TIE-IN PASS & FIRED CUTTER (~ 10366' (1' BELOW "CC" JT & LOGGED CUT / POOH (CUTTER HAD FIRED) (CCL CHARACTER CHG BUT NOT DEFINTE) / BLEED SC TO 0 PSI (FAINT BLOW & BLED OFF IN LESS THAN I MIN) / BLED PC IN 100 PSI INC. F/ 1090 PSI T/550 PSI & STARTED GETTING OIL / PUMPED 20 BBLS LEASE H20 INTO PC & PRESSURE UP T/2900 PSI / BLED T/2725 PSI IN 30 MIN ( LOOKED STABLE (~ 2725 PSI / BLED PC T/600 PSI & STARTED GETTING OIL / R/UP HOWCO SLICKLINE / RIH W/SHIFTING TOOL & LOCATED SLEEVE @ 10216' / PRESSURED TBG TO 400 PSI / JARRED UP 5-6 TIMES & SLEEVE SHIFTED / TBG 0 PSI, PC =720 PSI & BUILDING / R/ DN HOWCO / ClRC WELL W/LEASE H20 W/RETURNS THRU CHOKE T/GAGE TANK / BEGAN PUMP W/860N PSI ON PC, 275 PSI @ 2 BPM MAINTAIN 275 PSI (~ 2 BPM / PC PRESSURE CAME DN TO 300 PSI / H20 RETURNS W/222 BBLS PUMPED REMAINDER OF VOL WAS OIL / SHUT DN TBG = 240 PSI, PC = 300 PSI / SECURE WELL & SHUT DN FOR THE NIGHT TBG = 190 PSI, PC = 325 PSI / BLEED PC IN 50 PSI INC. W/NO BUILD UP T/50 PSI TBG DEAD / RAN TAP & CLEANED UP THREADS FOR COSSASCO 2-1/2" BPV, (13 ROUNDS W/NO PROBLUMS / SET COSASCO 2-1/2" 2-WAY CHK & TESTED T/5000 PSI (OK) / PULLED CHK & RAN LOCK DN IN & OUT W/NO PROBLUMS / R/UP HOWCO SLICKLINE & TEST LUB. T/4000 PSI / RIH & CLOSE SLEEVE @ 10216' & POOH / TEST SC T/500 PSI (OK) / TESTED PC T/2750 PSI FOR 20 MIN (OK) / R/DN HOWCO & MOVE EQUIP T/332-4 ............... SUSPEND WELL OPERATION TEL 8-24-96 ....................... TRAVEL TO SWANSON RIVER / CHK PRESSURES ON WELLS 332-4, TBG = VAC, PC = DEAD, PC = 90 PSI / 323-9 = VAC, PC = 50 PSI, SC = 25 PSI / OPEN UP TBG & PC & LET EQULIZE / TBG = DEAD, PC = DEAD, SC = 25 PSI (~ 1100 HRS & SHUT IN SAME & MONITOR (LOCATION READY FOR RIG, CLEAN GRADED & INJECTION LINE REMOVED) / CHK/OUT MUD MATEARILS & EQUIP / ATTEMPT TO LOCATE USEABUL ANN. VALVES (~ SWANSON RIVER (FOUND 3 REBUILT WKM 2-1/16" 5K GATE VALVES & TALK WI SAMMEY BAKER,& WE ARE ABLE TO USE THEM) & HAVE VECO IN STALL BULL RAIL AROUND WELL 24A-9 & 341-4 CHK PRESSURES ON WELLS / 323-9, TBG = VAC, PC = SLITE BLOW, SC = 25 PSI / OPEN UP TBG & PC & LET EQULIZE / SHUT IN SAME & MOINTOR / 332-4, TBG = VAC, PC -- DEAD, PC = 90 PSI / CLEAN LEASE HOUSE / MOVE DRLG SUPPLYS FRM DRLG TRAILER T/LEASE HOUSE / SET UP CO MAN RIG DESK / ORGANIZE FILES / M/UP START Page 1 Sheet1 Well Unocal Corporation Well History Report Swanson River-SCU--323-9 Page: 2 UP & SHUT DN PROCEEDURE ! GO THRU RIG CONTRACT / AWS HANDS SHOWED UP & WORKED ON EQUIPMENT ! TALK W/LANCE & CHK/OUT BOTH PADS / VAC OUT PITS & PREP FOR TURNKEY RIG MOBE (~ 0:600 HRS 8/26/96 8/26/96 8/27/96 CHK PRESSURES ON WELLS / 323-9, TBG = VAC, PC = SLITE BLOW (WILL QUIT IN 15 SEC), SC = 25 PSI / 332-4, TBG = VAC, PC = DEAD, SC = 90 PSI / HELD SAFTY MEETING W/HANDS / LAY OUT LINER (ONE SOILD LINER) & INSTALL RIG MATS, MOVE IN RIG / RAISE DERRICK (NOTICE CRACKED LEVIS GROVING ON DRUM, DID NOT RAISE SUB) CALL IN WELDER / MISC R/UP CONTINUE TURNKEY MOBE / WELD UP CRACK IN LIVIS GROVING / RAISE SUB / SET BEAVER SLIDE, CATWALK, PIPE RACKS & MISC R/UP / TOTCO R/UP PVTS / T.I.A OUT & MAG PARTICLE INSPECTION OF INTIRE GROVING (FOUND HIRELINE CRACK @ BEGINING OF REPAIR WELD) / REPAIR SAME / REINSPECT (OK) 8/28196 8129/96 8/30/96 CONTINUE TURNKEY MOBE / RIG INSPICTION & ACCEPT RIG (~ 0600 HRS & HOLD SAFTY MEETING / CHK PRESSURE ON WELL & MOINTOR, TBG -- VAC, PC = SLITE BLOW THEN DIE (IN 15 SEC), SC = 25 PSI / INSTALL BPV & NIP/DN TREE / NIP/UP B.O.P. Nippled up 7" x 11" 5M x-over spool and 11" 5M BOP (RSRdA). Installed 2 7/8" rams in bottom, CSO, 3 1/2". Function tested gates. Picked up 3 1/2" test joint and pumped thru stack (~ 2400 hrs.. Nordic motorman Ed Edgar fell while stepping off lower subbase beam and injured left wrist and scratched forehead, went in for x-ray of wrist Pressure testing BOPE. Choke line leaked, changed ring gasket. Floor valve leaked, replaced. 3" standpipe valve leaked, rebuilt. Mud pump bleeder valve leaked, replaced. Flange between mud cross and single gate leaked, retightened. HCR valve stem packing leaked, serviced. X-over to safety valve leaked, replaced, flange between mud cross and double gate leaked, retightened. Tested top rams, floor valve, choke and kill valves to 250 & 5000 psi.. Tested annular preventer to 250 & 3500 psi.. Changed test joint to 2 7/8" and tested bottom pipe rams to 250 & 5000 psi., bottom pipe ram control @ rig floor did not work. Pulled test joint, pulled back pressure valve, and set two way check. Pressure tested CSO rams and remaining choke manifold valves to 250 & 5000 psi.. Repaired remote control for bottom pipe rams. Made up landing joint, backed out hanger hold downs and attempted to release Baker ,'FH" packer @ 10,256' with negative results. Pulling 125-130K indicated weight, 82% off 2 7/8" joint stength. Rigged up APRS and tested lubricator to 1500 psi.. Ran in hole with 2 1/8" chemical cutter and cut tubing @ 10,230' with 115K indicated pull, weight dropped off to 88K. POH with APRS wireline @ 2400 hrs.. POH with chemical cutter and rigged down APRS. Circulated well one circulation through tubing cut at 10,230', went through gas buster for bottoms up, moderate bubbling. Observed well, some bubbling, very slow fluid drop. POH with completion tubing. Layed down 843' 2 7/8" tubing. Recovered a total of 10,215' of tubing and jewelry, original KB= 14.56', top of tubing @ 10,230'. Function tested BOP's and set wear bushing. Made up BHA #1, 5 3/4" Bowen series 150 overshot with 2 7/8" basket grapple, drain sub, bumper Page 2 Sheet1 Well 8/31/96 9/1/96 9/2/96 9/3/96 9/4196 Unocal Corporation Well History Report Swanson River-SCU--323-9 Page: sub-jars, (6) 4 3/4" drill collars, accelerator,x-over to 3 1/2" CS Hydril tubing. RIH with BHA #1 @ 2400 hrs.. Continued to RIH with BHA #1, overshot assembly on 3 1/2" CS Hydril tubing, to 9494'. Broke circulation and continued RIH picking up 3 1/2" 15.5# X-95 drill pipe to 10,200'. Circulated down and worked over fish @ 10,232°(dpm). Engaged fish and pulled loose with 55K overpull. Circulated bottom up through gas buster. POH, dragging 20-30K and trying to swab. Completed POH slow and laid down packer and tail cut off, heavy tar build up on fishing tools and packer. Recovered 136' of tubing and jewelry, top of tubing @ 10,366'. Broke down fishing tools and cleared floor. Functioned BOP's. Made up BHA #2, Baker OD/ID dressing mill, (2) 4 3/4" drill collars, x-over, 7" casing scraper, x-over, bumper sub, jars, (4) 4 3/4" drill collars and RIH @ 2400 hrs.. Walkabout-Light Plant/Breaker panel door open, not all breakers labeled. Closed door, advised tool pusher to label breakers. Continue to RIH with BHA #2, dressing mill and 7" casing scraper assembly to 5000'. Circulated bottom up, considerable amount of tar balls on bottom up. Continued RIH to 10,230'. Circulated clean, moderate gas bubbling. Picked up kelly and pressure tested upper and lower kelly cocks to 250 & 5000 psi.. Washed down and cleaned out to 10,372'(dpm), saw indication of entering tubing stub. Pumped 30 bbl. sweep with 3.33 #/bbl. FIo-vis. Circulated and treated system with .25% Nalco 3900, scale and corrosion inhibitor. Checked flow, neg.. Lay down kelly and POH. Continuing to POH with BHA #2 @ 2400 hrs.. Serviced rig. Continued to POH with BHA #2, dressing/scraper assembly. Laid down BHA. Made up tubing tie back overshot and Baker 7" SC2-P packer assembly and RIH on work string to 10,300'. Washed down from 10,300'-10,366'. Engaged tubing stub and confirmed with 15K overpull. Dropped setting ball. Set Baker SC2-P packer @ 10,260'. Pressure tested back side to 1500 psi. for 15 minutes with no bleed off. Rotated off packer and attempted to shear out setting ball by pumping down tubing. Pumping past ball with 4000 psi. @ 3.5 bbl./min.. Pressure up several times and could not shear ball completely. Rigged up and attempted to reverse out ball with negative results. POH laying down work string, wet, @ 2400 hrs.. Daylight crew held weekly safety meeting. Pumped 5 bbls. lease water onto pump room floor thru open line, .5-1 bbl. leaked through containment liner onto location gravel. Vaccumed up standing water from ground and containment and shoveled affected gravel into cuttings bin. Continued to attempt to reverse out setting ball from Baker running tool with negative results. POH and layed down 3 1/2" CS Hydril work string and Baker setting tool. Ball seat piston was partially shifted. Rigged up Halliburton slickline and RIH with 2.3" gage ring, setting down @ 10,367'(wlm), unable to work deeper. POH, heavy tar on tool string. Made up "px" plug body and RIH, set down @ 10,327', unable to work deeper. POH, still had plug, again heavy tar on tool string and plug. Made up 2.29" gage cutter and RIH, stopped @ 10,374'(wlm). POH, rigging down Halliburton @ 2400 hrs.. Night crew held weekly safety meeting, discussed Ed Edgar accident, Iockout/tagout, and pre job safety planning. R/DN SLICK LINE & PULL WEAR RING (PACKED W/PARAFFIN) / M/UP SEAL ASSY,PREPARE & RUN 2-7/8" TBG / (3412 WENT DN ON LOW OIL) Page 3 Sheet1 Well Unocal Corporation Well History Report Swanson River-SCU--323-9 Page: 4 CARRIER) / REINSTALL DRAIN LINE & FILL W/OIL / CONTINUE P/UP & RIH W/2-7/8" TBG T/4903' (3412 WENT DN AGAIN) / SECURE WELL & MOINTOR (CALL IN CAT MECHANIC & PULL PAN, CRANK OK, NEED TO CHG/OUT,ONE PISTON & LINER & CYL. HEADS & BERRINGS) / REPAIR SAME 9/5/96 9/6/96 9/7/96 9/8/96 CONTINUE REPAIR ON CAT 3412 / BTM END REPAIRED / WAIT ON HEADS & PARTS FRM LOWER 48 / ALL PARTS ON LOCATION @ 2300 HRS / ASSEMBLE TOP END 0001 - 0600 HRS: CONTINUE ASSEMBLING TOP END CONTINUE REPAIR ON CAT 3412 / FINISH ASSEMBLING TOP END & FIRE UP & ADJUST SAME / RIG BACK ON DAY RATE @ 12:00 HRS (50 HRS TOTAL DN TIME) / POOH & STAND BACK TBG / CHG/OIL & FILTERS ON CAT 3412 / CONTINUE POOH & STANDING BACK 2-7/8" TBG T/2079' / WAIT ON CHAMP PRK (1) HR / M/UP SAME / RIH OUT OF DERRICK & P/UP 2-7/8" TBG & RABBIT @ MIDNITE 0001 - 0600 HRS: CONTINUE T/P/UP 2-7/8" TBG & RABBIT T/10239' / CIRC HOLE VOL OF WARM LEASE H20 (SURFACE TEMP 150 DEGS, @ SHUT DN FLOW LINE TEMP @ 112 DEGS) /WASH DN F/10239' T/10260' & STAB INTO PRK @ 0600 HRS CONTINUE T/P/UP 2-7/8" TBG & RABBIT T/10239' / ClRC HOLE VOL OF WARM LEASE H20 (SURFACE TEMP 150 DEGS, @ SHUT DN FLOW LINE TEMP @ 112 DEGS) / WASH DN F/10239' T/10260' & STAB INTO PRK / R/UP SLICKLINE & TEST LUB T/3500 PSI (OK) / RIH W/2.3" GUAGE RING TAG @ 10374' (WLM)(UNABLE TO WORK ANY DEEPER) / POOH (SM AMOUNT OF TAR ON TOOLS) / P/UP PX PLUG BODY & RIH & SET IN "X" NPPLE @ 10352' / POOH & P/UP EQULIZING PRONG / RIH & SET PRONG IN IN PLUG BODY / POOH / R.UP & TEST TBG, SEALS & PLUG T/3500 PSI FOR 10 MIN (JUGED UP, GOOD TEST) / TEST 7" X 2-7/8" ANN. T/2750 PSI (LOCK DN SCREW PACKING (LEEKING) / TIGHTEN PACKING & RETEST (OK) / RIH W/DUMP BAILER LOADED W/CACO3 & CHG/OUT BOTH ANN VALVES / TAG PRONG @ 10349' & ATTEMPT T/DUMP BAILER / POOH (CACO3 GUMED UP & ONLY 1/4 OF BAILER DUMPED) / SIFT FINES OUT OF CACO3 & RELOAD BAILER & RIH & ATTEMPT T/DUMP @ 10349' / POOH (SPRING STUCK CLOSED & ONLY 1/4 BAILER DUMPED) / REBUILD BAILER & RELOAD & TEST 7" X 2-7/8" ANN. & NEW ANN VALVES T/2750 PSI (OK) ! RIH & DUMP @ 10349' / POOH FULL DUMP ( CAL TOTAL CACO3 FILL = 2.8') / R/DN SLICKLINE @ MIDNITE 0001 - 0600 HRS:CONTINUE R/DN SLICKLINE & FINISH R/UP OF CHICKSANS & TEST 250 PSI & 2500 PSI (OK) / HELD PREJOB SAFTY MEETING & WENT OVER GAME PLAN & REVEIWED & COMPLETED UNOCAL'S" PUMPING OF FLAMMABLE OR COMBUSTIBLE FLDS, SAFTY CHKLIST" W/ALL PARTYS INVOLED / UNSTING FRM SC-2P PRK & SET CHAMP PRK. @ 8176' W/TAIL @ 10255' & OPEN BYPASS & SHUT IN WELL & BRK CIRC. THRU CHOKE (OK) / PUMP 50 BBLS XYLENE OUT OF 1st TRK, TAKING RETURNS THRU CHOKE T/PIT / SHUT DN & SWAP TRKS & TAKING RETURNS THRU CHOKE T/PROD. FLOW LINE / PUMP 70 BBLS XYLENE & CHASED W/3 BBLS LEASE H20 (T/FLUSH SURFACE LINES) / CLOSE BYPASS & LET XYLENE SOAK W/820 PSI ON TBG FOR ONE HR @ 0600 HRS **** ASK aogcc TO WAIVE B.O.P.E TEST & JACK HARTZ WAIVED B.O.P.E TEST .... CONTINUE R/DN SLICKLINE & FINISH R/UP OF CHICKSANS & TEST 250 PSI & 2500 PSI (OK) / HELD PRE JOB SAFTY MTG & WENT OVER GAME PLAN & REVIEWED & CMPLTED UNOCAL'S" PUMPING OF FLAMMABLE OR COMBUSTIBLE FLUIDS, SAFTY CHKLIST" W/ALL PARTYS INVOLED / UNSTING FRM SC-2P PRK & SET CHAMP PRK. @ 8176' W/TAIL @ 10255' & OPEN BYPASS & SHUT IN WELL & BRK CIRC. THRU CHOKE (OK) I PUMP 50 Page 4 Sheet1 Well Unocal Corporation Well History Report Swanson River-SCU--323-9 Page: 5 BBLS XYLENE OUT OF 1st TRK, TAKING RETURNS THRU CHOKE T/PIT / SHUT DN & SWAP TRKS & TAKING RETURNS THRU CHOKE T/PROD. FLOW LINE ! PUMP 70 BBLS XYLENE & CHASED W/3 BBLS LEASE H20 (T/FLUSH SURFACE LINES) / CLOSE BYPASS & LET XYLENE SOAK W/820 PSI ON TBG FOR ONE HR / BLEED PRESSURE T/PROD. & OPEN BYPASS & REV/CIRC. 250 BBLS T/PROD. / RELEASE PRK & CHK/FLOW (OK) / CIRC HOLE VOL W/WARM H20 (BTM/UP BLK W/NO SOILDS) / MONITOR WELL & R/DN XYLENE LINES & R/UP CHOKE & KILL LINES & TEST (LEEK ON CHOKE. RETITEN GRAYLOCK & RETEST OK) / CUT & SLIP 50' DRLG LINE / POOH (2) STD (OFF DRILLERS SIDE TURBO ON CAT 3412 FAILED) / SECURE WELL (RIG ON DN TIME (~ 1500 HRS) / WAIT ON TURBO FRM. ANCHORAGE & PREP TURBO FOR REPAIR (FOUND PIECES OF VALVE IN TURBO) / REMOVE EXHAUST MANAFOLD & INSPECT, WHILE WAITING / INSTALL NEW TURBO @ MIDNITE 0001 - 0600 HRS: CONTINUE INSTALL OF NEW TURBO (RIG BACK ON DAY RATE (~ 0200 HRS, TOTAL DN TIME = 11 HRS) / POOH & STD BACK TBG / LAYING DN CHAMP PRK @ 0600 HRS 9/9/96 CONTINUE INSTALL OF NEW TURBO (RIG BACK ON DAY RATE @ 0200 HRS, TOTAL DN TIME = 11 HRS) / POOH & STD BACK TBG & L/DN PRK & SEALS (SM AMOUNT TAR ON TOOLS) / M/UP 6" BIT + 7" SCPAPER + BS + 1 JT 3-1/2" DP + BS + JARS + XO = 59.97' / RIH T/10202' (WI NO PROBLUM) / CIRC. BTM'S/UP (WI NOTHING SIGNIFICANT IN BTM'S UP) / POOH @ MIDNITE 0001 - 0600 HRS: CONTINUE POOH & LJDN BHA (TOOLS HAD SM AMOUNT OF GREESE LIKE COATING) / PULL WERE RING / PREP T/RUN COMPLETION & RUN 2-7/8" COMPLETION @ 0600 HRS 9/10/96 CONTINUE POOh & I. JDN BHA (TOOLS HAD SM AMOUNT OF GREESE LIKE COATING) / PULL WERE RING / PREP T/RUN COMPLETION & RUN 2-7/8" COMPLETION ((~ CREW CHG DRILLING SUPERINIENDANT NOTICE POSSABULE UNOCAL SUBSTANCE ABUSE POLICY BROKEN, SEE ATTATCHED MEMO) / WELL WAS SECURED & RIG SHUT DN (RIG ON DN TIME @ 13:30 HRS) ** REKILL SCU 332-4, TBG = 800 PSI, PC = VAC SC = 90 PSI / R/UP VECO PUMP TRK, CHOKE MANAFOLD, & DOWELL BLENDER / TEST LINES T/3000 PSi (OK) / FILL PC W/16 BBLS / BLEED 800 PSI (GAS) T/PROD. & MIX & BULL HEAD 30 BBL SIZED SALT PILL (~ 10 PPG W/26.6 PPB BRIDGE SAL, 18.3 PPB PLUG SAL REG, 18.3 PPB PLUG SAL-X & DISPLACED W/70 BBLS LEASE H20 & SECURE WELL & MONITOR** 0001 - 0600 HRS: (RIG BACK ON DAY RATE (~ MIDNITE) FULL NIGHT CREW SHOWED & TOOK U.A'S & HELD SAFTY MEETING ON UNOCAL POLICYS / CHK/FLOW (OK) / CONTINUE RIH W/2-7/8" COMPLETION / SPACE OUT & LAND HANGER / RUN IN LOCK DN SCREWS / R/UP SLICK LINE & TEST LUB. T/3000 PSI (OK) / M/UP PX PLUG BODY RIH & SET (~ 10033" POOH & P/UP EQUILIZEING PRONG & RIH & SET DN IN GLM (~ 1640' POOH TO CHK TOOL @ 0600 HRS 9/11/96 Held safety meeting. Continued to RIH with 2 7/8" gas lift completion. Spaced out and landed hanger with bottom of reentry guide @ 10,066', "FH" packer (~ 9987'. Rigged up Halliburton slickline and RIH with "px"plug body and set in x-nipple @ 10,032'. Pulled setting tool and RIH with prong, 'set down in gas lift mandrel (~ 1640'. Pulled out and repinned running tool. RIH and set prong in "px" plug. Pressured up and set Baker "FH" packer @ 9987'. Pressure tested tubing to 3000 psi.. POH with prong. RIH and pulled "px" plug body. Pressure tested packer to 2750 psi. for 30 minutes. Layed down landing joint and set back pressure valve. Nippled down BOPE. Installed 7" 5M x 2 Page 5 Sheet1 Well Unocal Corporation Well History Report Swanson River-SCU--323-9 Page: 9/16" 5M seal flange. Installed 2 9/16" 5M x-tree. Pulled back pressure valve. Attempted to set two way check, had problem screwing in plug. Tried a second plug and also had some problems setting. Testing x-mas tree ~ 2400 hrs.. 9/12/96 9/16/96 Pressure tested 2 9/16" 5M x-mas tree to 250 & 5000 psi.. Pressure tested 7" x 11 3/4" casing packoff to 3000 psi.. Released rig for move to SCU 332-4 @ 0100 hrs.. Tore out and moved dg off location. Veco crew began installing flow and gas lift lines. Rigged up Schlumberger lubricator and pressure tested to 4000 psi.. Made up gun #1, 1' 2 1/8" Enerjet retrievable strip gun with GR-CCL and RIH. Made tie in pass from 10,250'-9300'. Put gun on depth, tubing pressure 2275 psi., PC 2000 psi.. 2100 hrs.. Perforated interval from 10,246'-10,245' with 4 jspf 14 grm charges @ 0 deg.. POH. Tubing pressure built to 2310 psi. while POH @ 2205 hrs.. Rigged down Schlumberger, all shots fired, and released well to production @ 2230 hrs.. 9/17/96 Rigged up Schlumberger. Held safety meeting and confirmed radio silence with production personel. Pressure tested lubricator to 4000 psi.. Made up gun #2, 20' 2 1/8" Enerjet retrievable strip gun and RIH. Made tie in pass and placed gun on depth. 525 psi. on tubing and PC. Perforated interval from 10,246'-10,226' with 4 jspf 14 grm. charges @ 0 deg.. POH, all shots fired. Tubing pressure had increased to 550 psi. after perforating and POH. Rigged down Schlumberger and released well to production @ 2200 hrs.. Page 6 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: Workover 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Unocal Development: KB: 135' feet 3. Address Exploratory: 7. Unit or Property name PO Box 196247 Anchorage, Alaska, 9519-6247 Stratigraphic: Service: X Soldotna Creek Unit 4. Location of well at surface 8. Well number 2520' FNL, 1970' FEL, Sec. 9, T7N, R9W, SM SCU 323-9 At top of productive interval 9. Permit number Straight Hole ~- I ~' C~O,~. ~ At effective depth 10. APl number $0-133-10125-00 At total depth 11. Field/Pool Swanson River / Hemlock 12. Present well condition summary Total depth: measured 10,750' feet Plugs (measured) 10,652' true vertical 10,750' feet .ORIGINAL Effective depth: measured 10,652' feet Junk (measured) true vertical 10,652' feet Casing Length Size Cemented Measured depth True vertical depth Conductor 32' 20" yes 32' 32' Surface 2,009' 11-314" 60 sx 2,009' 2,009' Production 10,748' 7" 600sx 10,748' 10,748' 900sx DV (~ 6,796 Perforation depth: measured 10,388'-10,434'; 10,455'-10,$80; 10,$92'-10,$20'RECEIVED true vertical 10,388'-10,434'; 10,455'-10,$80; 10,$92'-10,620' AUG 1 1996 Tubing (size, grade, and measured depth) 3-112" 9.2#, N-80 {~ 9,388'; 2-718", $.5 #, N-80 ~_. 10,$24' Alaska 0il & Gas Cons. Commission Packers and SSSV (type and measured depth) 2-7/8" x ?" 29 # Baker "FH" packers (~ 10,255', 10,312', 10,442', & 10,683~nch°rage 13. Attachements Description summary of proposal: x Detailed operations program: x BOP sketch: x 14. Estimated date for commencing operation 15. Status of well classification as: May 8, 1996 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: ,~&~ 0~t ~,2~ Title: Drilling Manager Date: 13-Aug-96 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witneSSplug integrity BOP Test ~ Location clearance IAppr°val N°' ~- / ~C) Mechanical Integrity Test Subsequent form required lO- Original Signed By Tuckerman Babcock Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 Approved Copy Returned SUBMIT IN TRIPLICATE Soldotna Creek Unit Well 323-9 Workover: Recomplete Hemlock Gas Injector to Tyonek Oil Producer Procedure Status: Draft #2 Date: 06-May-96 By: S.S. Lambe Facilities Improvement: MD 1) Lay in flowline (3600') and header valves. Pressure test to 80% of yield. 2) SI injection gas one week prior to starting workover. 3) Convert existing blow down lines to tank battery to production lines. Prepare and Kill Well for Workover Rig: 4) Rig up slickline. Pressure test BOP's and lubricator to 5000 psi. MU 2.3" Gauge ring. Rltt and gauge robing to 'D' nipple at 10,589'. POOH. RD slickline. 5) RU E-Line unit. Pressure test to 5000 psi. Establish Safeguards for handling perforating guns. MU APRS's chemical cutter dressed for 2-7/8", 6.5 # tubing on SCHLUMBERGER's E-line. RIH and cut the tubing at 10,366'. RD E-Line. 6) RU pumping equipment. Pressure test hardlines to 6000 psi. Bull head 30 bbls xylene down tubing displaces with 80 bbls produced water at 2 bpm. SI well and let xylene soak around packers. 7) Bleed casing pressure. Fill annulus with produced water. As pressure increases, bleed off. 8) RU slickline unit. Pressure test lubricator. MU dual pressure and single temp bombs. RIH and obtain pressure and temperature @ 10,300'. POOH and read charts. MU 2-7/8" nominal shiffing tool dressed for OTIS XA sleeve ~ 10,217'. RIH and shift sleeve up to open. Monitor casing pressure for communication response. RD slickline. 10) Circulate kill weight fluid down tubing taking returns from 3-1/2" x 7" annulus to remove any residual gas. Spot salt based LCM's as required to control fluid loss. Ensure well is dead and holds a column of fluid. Rig Workover: 11) 12) 13) MIRU workover rig. RU lines to pump down tubing and take annular returns. Bleed any gas pressure and circulate down tubing taking returns up casing. Spot salt based LCM's as required. Ensure well is dead. Set a back pressure valve in hanger profile or plug in the tubing for well control. Nipple down tree and nipple up BOP stack. Function and pressure stack to 250 psi and~3L~'ps~. Pull back pressure valve or tubing plug as noted in step #12. 14) Call out APRS and have them on location for making a tubing cut in 2-7/8", 6.5 # tubing. 15) MU pulling sub and engage tubing hanger. Back out tubing hanger hold downs. Attempt straight pull release of Baker FI-I retrievable packer at 10,265'. If the packer at 10,265' doesn't release, make a tubing cut above the top packer at 10,241'. 16) POOH and lay down 3-1/2" x 2-7/8" injection string and BI-IA. Install wear bushing. PU drill pipe and fishing assembly to recover jewelry in the 7" casing to a depth a minimum depth of 10,365'. 17) MU casing scraper dressed for 7" 29# casing. RIH to 10,365' and circulate bottoms up. POOH. Pull wear bushing. 18) MIRU E-Line unit with .38" cable. MU 6" gauge ring with GR & CCL. RIH to 10,365' gauging the casing. Tag top of 2-7/8" tubing previously left in hole. Pull a correlation log from 10,365' to 9,800'. POOH. Fax logs to town to verify GR depths are correctly tied in. Space out isolation packer assembly for top of packer at 10,270'. NOTE: GR & CCL log to be used for setting of isolation packer and perforating. 19) MU DP setting tool and Baker "SC-2P" retrievable packer assembly (see attached tubing detail). RIH and engauge tubing stub with 5-3/4" OD x 3" ID cut lip overshot. Set top of packer at 10,270'. POOH. 20) Pressure test packer and casing to 2500 psi. Monitor pressure for 15 minutes on a strip chart. 21) PU a storm packer dressed for 7", 29# casing. RIH and set at 180'. POOH. ND BOPs. Inspect tubing spool. ND Tubing spool and replace if required. Pressure test to 80% working pressure. NU BOP's. 22) Install wear bushing. RIH and retrieve storm packer. POOH. Pull wear bushing. 23) PU and RIH with BHA as noted on attached proposed well completion schedule. Set retrievable packer at 9,883'. Land tubing hanger and secure with hold downs. Pressure test body and neck seals. 24) Set BPV. ND BOP stack. NU tree and pressure test to 5000 psi. Pull BPV. 25) Release rig. NU towlines and pressure test. Unload Well and Flow Back Hemlock: 26) Unload well to lifting orifice at 1 bpm. Gas lift representative be on location to prevent flow cutting of gas lift valves. 27) RU slickline. Pressure test lubricator to 5000 psi. RIH and equalize plug in lower isolation packer. POOH with plug. Record any pressure changes on surface. Open well to production and allow Hemlock zones to clean up and unload water from workover. Isolate 28) 29) Hemlock and Complete Tyonek G-2 Interval: SI well. Reset isolation plug in profile. Bleed off gas pressure and monitor for pressure build up. Ensure plug is holding. Dump bail 15' of CaCO3 or sand on top of plug. RD slickline. RU E-Line unit. Pressure test to 5000 psi. Establish Safeguards for handling perforating guns. MU 2-1/8" EJ III strip guns, 6-SPF, O-Phase guns as noted below. Stack 2000 psi lffi gas on tubing. RIH and perforate the following interval. Note initial pressure increase from perforating. 30) 31) 32) Tyonek G- 1: 10,151' - 10,170' 2-1/8", EJ III, 6 HPF, O-Phase * Allow well to flow to production unassisted for 48 hours obtaining water cuts every 4 hours. Consult with SRT prior to completing the G-2 interval. Tyonek G-2: 10,228' - 10,248' 2-1/8", EJ III, 6 HPF, O-Phase · RD E-line. Allow well to flow to low pressure system unassisted obtaining water cuts and rates for 48 hours. RU slickline unit. Pressure test lubricator. MU dual pressure and single temp bombs. Shut in well and RIH and obtain pressure and temperature @ 10,200'. POOH and read charts. RD slickline. Turn well over to production. Clean up site. UNOCAL RKB to TBG Hanger = 14.65' Tree connection: 4" 10M Uni-bolt DV @ 6,796' 9 10 11 12 13 14 15 16 17 18 19 PBTD = 10,652' TD = 13,821' MAX HOLE ANGLE = Straight SIZE WT Swanson River Field Well # SCU 323-9 Actual Completion 10/1973 CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 20" 11-3/4" 47 7 29 7 26 7 23 7 26 7 29 7 29 Tubing: 3-1/2 9.3 3-1/2" 9.2 2-7/8" 6.5 2-7/8' 6.4 Surf 32 8rd Surf 2,009 N-80 Buttress Surf 288 N-80 Buttress 288 1,008 N-80 Buttress 1,048 4,715 N-80 Buttress 4,715 6,543 N-80 Buttress 6,543 8,369 N-80/P- 110 L8R 8,369 10,750 N-80 ELrE 8rd ABC 15.4 103 N-80 CS Hydril 103 9,268 N-80 ELrE 8rd ABC 9,269 10,623 N-80 EU 8rd 37 11,350 JEWELRY DETAIL NO. Depth Item 1 14.65 2 118.5 3 9,388 4 10,217 5 10,256 6 10,262 7 10,343 8 10,365 9 10,371 10 10,379 11 10,419 12 10,436 13 10,441 14 10,448 15 10,557 16 10,576 17 10,583 18 10,589 19 10,624 TOP BTM Tubing hanger with Cassasco BPV profile Crossover 3-1/2" X 2-7/8" Crossover Otis XA sleeve ID = 2.31Y' Baker FH Packer Otis S nipple Position #3 ID = 2.31Y' Camco MM Gas Lift Mandrel Brown CC Safety Joint Baker FH Packer Otis S nipple Position #2 ID = 2.31Y' Camco MM Gas Lift Mandrel Brown CC Safety Joint Baker FH Packer, Otis S nipple Position # 1 ID = 2.313" Camco MM Gas Lift Mandrel Brown CC Safety Joint Baker Fl{ Packer Camco D Nipple ID = 2.25" Baker Shear-out Sub PERFORATION DATA ZONE SPF DATE COMMENTS 10,280 10,300 10,317 10,343 10,351 10,364 10,388 10,434 10,455 10,545 10,554 10,580 10,592 10,620 W.S.O @ 10,276' and 10,625' Existing Existing Exisung Existing Existing Existing Existing O:LDRILLING\SCHEMATIC\GP\GPP\SC3239A.DOC REVISED: 8/7/95 DRAWN B Y: MWD UNOCAL Swanson River Field Well # SCU 323-9 Proposed Completion 1996 RKB to TBG Hanger = 14.65' Tree connection = 2-7/8" 8rd Proposed DV @ 6,796' 3 4 5 Tubing Cut @ 10,366' 8b 9 10 11 12 13 14 15 16 17 18 19 20 PBTD = 10,652' TD = 13,821' MAX HOLE ANGLE = Straight PX-Plug O:kDRILLING\SCHEMATIC\GP\GPP\SC3239P. DOC CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 20" 11-3/4" 47 7 29 7 26 7 23 7 26 7 29 7 29 Tubing: 2-7/8" 6.5 2-7/8" 6.5 2-7/8" 6.4 N~O. Surf 32 8rd Surf 2,009 N-80 Buttress Surf 288 N-80 Buttress 288 1048 N-80 Buttress 1,048 4,715 N-80 Buttress 4,715 6,543 N-80 Buttress 6,543 8,369 N-80/P-110 L8R 8,369 10,750 L-80 Buttress Surf 9,900 N-80 EUE 8rd ABC 9,269 N-80 EU 8rd 37 JEWELRY DETAIL Depth Item 10,623 11,350 1 14.65 2 3 9,983 4 9,995 5 10,002 6 10270 7 10277 8a 10312 8b 10347 9 10364 Existing Jewelry 10 10,371 11 10,379 12 10,419 13 10,436 14 10,441 15 10,448 16 10,557 17 10,576 18 10,583 19 10,589 TOP BTM Tubing hanger with Cameron BPV profile Gas-Lift Madnrels with 10' pups @ 1,663', 2,681', 3,669', 4,657', 5,435', 6,063', 6721', 7,379', 8,037', 8695', 9,353', 10,011' Baker FH Retrievable Packer Baker X-Nipple profile (ID = 2.313") Baker Wireline Re-entry guide Baker SC-2P Retrievable Packer Baker retrieving extension Baker CMU sliding sleeve (ID = 2.313") Baker X-nipple (ID = 2.313") Baker Cut-lip Overshot Guide Baker FH Packer Otis S nipple Position #2 ID = 2.313" Camco MM Gas Lift Mandrel Brown CC Safety Joint Baker FH Packer, Otis S nipple Position #1 ID = 2.313" Camco MM Gas Lift Mandrel Brown CC Safety Joint Baker FH Packer Camco D Nipple ID -- 2.25" PERFORATION DATA ZONE SPF DATE COMMENTS 10,150 10,170 G-1 10,228 10,248 G-2 10,280 10,300 10,317 10,343 10,351 10,364 10,388 10,434 10,455 10,545 10,554 10,580 10,592 10,620 W.S.O@10,276'and 10,625' Proposed Proposed Existing Existing Existing Existing Existing Existing Existing REVISED: 8/7/95 DRAWN BY: MWD FILL-UP KILL LINE 5000 psi ANNULAR BOP 10" $000 psi PIPE RAMS 10" BLIND RAMS 10" 5000 DRILLING OOL 5000 CHOKE 3'.' 5000 psi PIPE .RAMS 0" 5000 LINE--D> BOP STACK 10" 5000 psi Unocal North American Oil & Gas Division Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL May 5, 1994 Alaska Region Commissioner Russ Douglas Alaska Oil and Gas Conservation Commission 3~01 Porcupine Drive Anchorage, Ak. 99501 Dear Commissioner Douglas: Application for Sundry Approvals Mechanical Inteqrity Tests Swanson River Field Union Oil Company of California (dba Unocal) requests approval to perform the attached Mechanical Integrity Tests on the following wells in the Swanson River Field: ~-~\~, SRU 31-33WD L0\- ~-9 SCU 43-4MD L~t-Z\ SCU 323-9 ~0~.~\ SCU 314-4 The last well listed above, SCU 314-4, was scheduled for an M.I.T. in 1993, but due to tubing to casing communication, this well could not be tested in 1993. The tubing was pulled from this well and replaced in December, 1993 and the well is now ready to be / tested. / The above proposed M.I.T. tests are being done to satisfy the requirement to test 25% ' of our Class II Injection wells per year. If you have any questions, please contact me at 263-7816. Very truly yours, Dennis L. ~r(~l~ske Petroleum Engineer Gas Cons. Commission Anchorage ~ STATE OF ALASKA -~,. ALASF_ .3IL AND GAS CONSERVATION CL ,'MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon m Suspend __ Alter casing__ Repair well Change approved program m 2. Name of Operator Operations shutdown __ Re-enter suspended well__ Plugging ~ Time extension Stimulate -- Pull tubing __ Vadanoe Pe"~orate Othe-"rX (MIT) 5. Type of Well: ~ 6. Datum elevation (DF or KB) Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface 2520' FNL, 1970' FEL, Sec. 9, 'ITN, R9W, SM RECEIVED KB: 135' 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 323-9 At top of productive interval Straight hole At effective depth At total depth MAY 1 2 1994 Alaska 0il & Gas Cons. Commission Anchorage feet 9. Permit number 10. APl number 50-133-10126-00 11. Field/Pool Swanson River/Hemlock 12. Present well condition summary Total depth: measured true vertical 10750 10750 feet Plugs (measured) 10652 feet Effective depth: measured 10652 true vertical 10652 feet Junk (measured) feet Casing Length Structural Conductor 32' Surface 2009' Intermediate Production 10748' Liner Perforation depth: measured Size Cemented Measured depth True vertical depth 20' Yes 32' 32' 11-3/4" Yes 2009' 2009' 7' Yes 10748' 10748' 10388-10434,10455-10580,10592-10620 truevertical 10388-10434,10455-10580,10592-10620 Tubing (siZe, grade, and measured depth) 3-1/2', 9.2#, N-80 @ 9388'; 2-7/8", 6.5#, N-80 @ 10624' Packers and SSSV (type and measured depth) 2-7/8', 29# Baker FH pkr. @ 10256' 13. Attachments Description summary of proposal Detailed op~irations prograrnX__ BOP sketch Approved 14. Estimated date for commencing operation 115. 5/94 16. If proposal was verbally approved Oil ~ Gas t Name of approver Date approved Service Gas Injector ,7., horeb~er~th?the fo/r~oin~ is~rue~l~ec, ,o ,h~best of my knowl~ge. Si~ned..~/~,-.~~ Title ~,~)[Lt~Lu~G, I~t~.~p~ 'l~. FOR COMMISSION USE ONLY Conditions Of approval: Notify CommiSSion so representative may witness Plug Integrity m BOP Test Mechanical Integrity Test_~''~ Location clearance ~'~bsequent form required ~- ~O~ Status of well classification as: Suspended m IApproval NO~ V "/.2. ~ dng~nai ,Signed By bY the order of the Oommissie3avid W. d0hnston Commissioner Form 10-403 Rev 06/15/88 · ..~:., oved Copy. Returned SUBMIT IN TRIPUCATE PC & SC Loading and PC pressure Test SCU 323-9 Ob_iective: To load the PC and SC and verify mechanical integrity on the PC. Well Da.ta;. Tubing: 3-1/2' to 9388' MD, 2-7/8' to 10,624' MD PC: 7" 23#, 26//and 29# N-80 to 10,750' MD SC: 11-3/4' 47#, N-80 to 2009' MD Top packer depth: 10,256' MD Capacities: Tog. x PC = .0264 Bbls./Ft. PC x SC = .0699 Bbls./Ft. Current Pressures: Tog. = 5300 psi, PC = 2150 psi, SC = 60 psi Procedure; Load PC and SC le 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 robing, 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. e . Hook up pump track to SC and pressure test lines to 4500 Psi. Load SC with lease water containing .25 % WT676 corrosion inhibitor finishing with a 5 Bbl. crude cap. Do not exceed 300 psi during pump- in. e Repeat steps 5-8 for the PC, as needed, using a 3000 psi maximum injection pressure for step #8. (Several 1000 psi blowdown/loads may be required). RECEIVED MAY 1 2 1994 ult & Gas Cons. Commission Anchorage NOTE: Contact the AOGCC (279-1433) and BLM (271-4417, 248-3010) at least 24 hours prior to testing the PC so that an agency wimess can verify the test results. PC Pressure Test 10. Pressure up PC to 500 psi over current pressure (2000 psi minimum). Hold for five minutes (observing tubing, PC and SC pressures). 11. If less that 50 psi is lost in five minutes, increase pressure by 500 psi. Hold for five minutes. 12. Repeat step #11 until 3600 psi is reached. Hold pressure for 30 minutes, noting initial and final pressures on all strings. 13. Rig down. RECEIVED M~ 1 2 1994 ~.~,sV,~ uti & Gas Cons. Commission Anchorage J 6543' 0.0 20' e 32' · ' 118.~6' 2009f Cl'e 6996' ----- 9,388.22' TUBR:O I.LA.r(C~R ( 8.10' ,300 JT$. ~,J' 9.2# r~-.80 .X.G~ 2t" x ~ 26 3'~. 2{. 6..',~ I~,.,80 £UE 8:nl AJaC C?LS. 1~ .,~, ,,~,., ?UP JT. 2i" 6.5/N-80 D,~ 8rd ~ C~. -,---.-, i~ "~. ~~~) I I I ~. ~" 6.~ ~ Z~ 8~ Am C~. I ~. ~. 6.~ ~ ~ 8~ I ~. 2~. 6.~ ~ ~ 8~ 1 ~. 2~" 6,~ ~ ~ 8~ ~ C~ ~ ~L(F~ ) I'O'P J'l'.2{" 6.~# N-80 ~Z~ 8rd /'U? JT. 2~, 6.h~ N-.80 F,~8 8'rd ,3 3'TS, 2i" 6.5# H-.~O F,~ b~ ------' TOP oL* PLUG 10,6,$2.00" · T.D. IO.?~.(X)' ~.~,, ,ds c~' I-&-~,~ 1/,.6S .?5' 103.06' ,c)o' 9263.86' .60 8;,2.07 6.10 3.15 .31.75' 'I.60' 10o0 31.~' 31.~)' 13.06' 8.08" 1.03 6.13 6.~ 1.60 8.0~ 31.~2 12.72 4.10 1.OSt 6,65 1.60' 10.19' 2.10 12.91 6.09 1.06 6.10' 6.57' .91~ 31.?/.' MAY ] 2 1994 ! II I II I I I I CASING & TUBING DETAIL SECTION T. 7 N..R. 9 W. STANOARD OIL COMPANY OF r'., '~.""~"' ARCO Alaska, Inc. Post Office Box-,u0360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering October 17, 1990 Mr. L. Smith Alaska Off and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached are Sundry Notices and Well Service Reports which document the production casing pressure tests performed on SCU 323-9, $CU 43-4WD and SRU 31-33WD. 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 serve to partially satisfy the requirement to test 25 percent of our Class II wells per year. Please contact Carol Baker at 263-4643 if you haVe any questions concerning this matter. Sincerely, T. Wellman TW:JKW:ch:0001 Attachment cc: Mr. ~ R. Kukla Mr.B.C. Dehn Marathon Oil Company UNOCAL Corporation ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company , 1. Type of Request: Operation Shutdown .. Pull tubing 2. Name of Operator ' STATE OF ALASKA :~' ~ ,' ALASKA OIL AND GAS CONSERVATION COMMISSION ' REPORT OF SUNDRY WELL OPERATIONS Plugging Perforate Pull tubing Othe,,r X 6. Datum elevation (DF or KB) Stimulate Alter casing ~ Repair well 5. TyPe of 'Well: ' Development Exploratory __ I Stratigraphic Service X ~RCO Alaska. I nc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2520' North, 1970' East of SW corner, Sec. 9, T7N, R9W, SM At top of productive interval Straight Hole At effective depth At total depth 135' KB 12. Present well condition summary Total Depth: measured true vertical 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 323-9 9. Permit number/approval number ,21-61 10. APl number so- 133-10126-00 11. Field/Pool Swanson River-Hemlock 10,750' feet Plugs (measured) 10,652' 10,750' feet MIT feet Effective depth: measured 10,652' feet true vertical 10,652' feet Junk (measured) 13. Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 32' 20" Yes 0-32' 0-32' Surface 2009' 11-3/4" Yes 0-2009' 0-2009' Intermediate Production 10,748 7" Yes O- 10,748' O- 10,748' Liner Perforation depth: measured 10280'- 10300' MD; 10317'- 10343' MD; 10351 '- 10364' MD; 10388'-10434' MD; 10455'-10545' MD; 10554'-10580' MD; 10592'-10620' MD true vertical 10280'- 10300' TVD; 10317'- 10343' TVD; 10351 '- 10364' TVD; 10388'-10434' TVD; 10455'-10545' TVD; 10554'-10580' TVD; 10592'-10620' TVD Tubing (size, grade, and measured depth) 3-1/2" 9.2~, N-80, to 9388' MD; 2-7/8", 6.5~, N-80, EUE, 8rd to 10,624' MD Packers and SSSV (type and measured depth) 2-7/8",29~,Baker "FH" Pkr,@l 0256';2-7/8",29~, Baker "FH" Pkr @10~372'~ 2-7/8"~29~Baker "FH" Pkr.@10442'~2-7/8"~29~ Baker "FH" Pkr.@ 10583' Stimulation or cement squeeze summary RECEIVED Intervals treated (measured) N/A 14. Treatment description including volumes used and final pressure ',~' I ! J i'lll ReDresentative Daily Averaoe Production or Ini~~ & Oil-Bbl Gas-Mcf Water-Bbl Casing p~aga Tubing Pressure Prior to well operation 0 37038 0 2318 5453 Subsequent to operation 0 37038 0 2318 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run~ , Daily Re,port of Well Operations Oil __ Gas Suspen, ded 17. I hereby certify t'l~at 'the foregoing is true 'and correct to the best of my k'nov~iedge. 5453 Service Gas In!ector,, Signed ~ ~~'1,,,_~ Form 10-404 Rev 06/15/88 Title Cook Inlet Reqional En,clineer Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. WELL SERVICE REPORT D CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK *"i-hei;'' '~ T. mP,Report ~ 'Fll Chill FIct°r l VbibllltY'F mll.s 1WInd Vel' Anchoraq~ ¢.41111pll, ly 0tl. AIO GAS ~Ol~"llf&ll~ ~1~15S1(~1 "~'~ '""~'" '"~ 5~,,,~~,' ~~~ .Pil~t ST__~ lS Illlt )0 NiH C,',StNG Tm; ILrl) TK TIK TiI~ TINE SI'AlIT stF./vt'/mmE stz~ TESt CS~ Tt~ ',m~ ~m TK ~ : P "~ lATER $ - SdI~T ~1~1~11 fig II · NISCl~I~ INJECTION I - lll~lllJ It - NOt. ii. IlK AJdl~l FLUID: DIi~EL - GLYL'OL ~IIILLIll~ ..I~:LL TES[: Initial__ ~-yeer ~ lorl~o~er Exptlln ~RCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering June 13, 1990 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 SCU 323-9, SCU 243-4MD, and SRU 31-33WD. 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 1989-90 program is June 30, 1990. Please contact Carol Baker at 263-4643 if you have any questions concerning this matter. Sincerely, T. Wellman Regional Engineer TW:CMB:ch:0030 Attachment cc' A. 1~ Kukla S. W. Ohnimus Marathon Oil Company UNOCAL Corporation RECEIVED JUN 1 9 1990 Alas~ Oil.& Gas Cons. Commission Anchorage ARCO Abmlm, Inc. Is a SubMdimy of Atlantic Richfield Company STATE OF ~ ALASKA OIL AND G/~ CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well 2. Name of Operator AR(~O Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK, 99510 4. Location of well at surface Alter casing _ Repair well _ Plugging Change approved program_ Pull tubing _ 5. Type of Well: Development Exploratory Stratigraphic Service 2520' FNL, 1970' FEL, SEC. 9, T7N, ROW, SM At top of productive interval Straight Hole At effective depth At total depth rlrl Ir, IN I Time extension Stimulate Variance _ Perforate _ Other _~. MIT 6. Datum elevation (DF or KB) 12. Present well condition summary Total Depth: measured 10,750' feet Plugs (measured) 135' KB 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 323-9 9. Permit number ~ ~/-~,~.Z/--~ 10. APl number 5o-1 33-1 01 26-00 11. Field/Pool Swanson_ ~River/Hemlock feet Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 10,280'-10,364' true vertical 10,750' measured 10,652' true vertical 10,652' Length Size feet feet feet Junk (measured) Cemented JUN ] 9 1990 Alaska 011 & Gas Cons. Commission Measured dept~nc~ill~t[~prtical depth 32' 2 0" yes 0- 3 2' 0- 3 2' 2009' 1 I -3/4" yes 0-2009' 0-2009' 10,748' 7" yes 0-10,748' 0-10,748' 10,455'- 10,580' 10,455'-10,580' MD; 10,592'-10,620' MD TVD; 10,592'-10,620' TVD measured MD; 10,388'-10,434' MD; true vertical 10,280'-10,364' TVD; 10,388'-10,434' TVD; Tubing (size, grade, and measured depth 3-1/2", 9.2#, N-80, to 9388' MD 2-7/8", 6.5#, N-80, EUE, 8rd to 10,624' MD Packers and SSSV (type and measured depth) 2-7/8"~ 29#~ Baker "FH" .Pkr. @ 10~256' MD Attachments Description summary of proposal _ Detailed operation program X BOP sketch 14. Estimated date for commencing operation June 1990 16. If proposal was verbally approved Name of approver Date approved Status of well classification as: Oil Gas Service Gas Iniector & 15. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sicjned ~x/~,x.__.__ Title Cook Inlet Regional Engr. FOR COMMISSION USE ONLY Suspended Date Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP.. Test Mechanical Integrity Test/ Approved by the order of the Commission Form 10-403 Rev 5/03/89 Location clearance Subsequent form require 10-/~3~ ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner Approved Copy Returned I IAppro_val No. . ,,~,_ I .... c~ 0. -- ~,~r / SUBMIT I~1TI~IPLICATE PC & SC Loading and PC Pressure Test SCU 323-9, SR 160 Objective: To load the PC and SC and verify mechanical integrity on the PC. Well Data: Tbg: PC: SC: Top pkr. depth: Capacities: Current Pressures: 3-1/2" tbg. to 9388' MD, 2-7/8" to 10,624' 7" N-80; 23, 26 and 29# to 10,750' MD 11-3/4" 47# to 2009' MD 10,256' MD Tbg x PC = .0264 Bbls/ft. PC x SC = .0699 Bbls/ft. Tbg=5300psi; PC = 2000 psi; SC=41psi Procedure: Loo_d/~ and SC Xe Install a two-pen recorder on the well to monitor the SC and PC pressures. 0 Shoot fluid levels on the SC and PC. (Skip to step #10 ff 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. 8. Load SC with lease water containing .25% WT676 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). RE .EIVEL1 J UN 1 9 '1990 Alaska Oil & Gas Cons. Com~SSlon Anchorage PC & SC Loading and PC Pressure Test SCU 323-9, SR 160 Page Two ..NOTE: 10. 11. 12. 13. 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. PC Pressure 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 3600 psi is reached. Hold pressure for 30 minutes, noting initial and final pressures on all strings. RDMO. RE .EIVED ,JUN 1 9 1990 Alaska Oil & Oas Cons. Commission Anchorage e,,£1048. . ,.. 471~' 6S45' OPe 6?96' 213T. + ~ 9.3~/s. go ( 8.10' & 1.77' ~00 3~$. ~,~ 9.2# ti-80 CS IIYDRIL 9265.86' 822.07 6.10 3.15 O.0 31.75 1.60 '1 10o05,q 6.05' 31.60' 31,~' 13.06' 8,08' 1.03 6.13 6.?0 1.60' 8.05' A. IO 1.05 /..00 ' 6.65 1.60 10.19 2.10 I~ ?'* -10,~56.~" ). ~ la( }~Vo~L (~ ~-r (-~.-.,) ~ 12.91 ~-- ~ ~..~t' ~.~ .~ ~ 8~ ~.o~ ~ '~ 2i" ~ "CC" ~. 1.06 - II : ~P ~. 2~. 6.~ N~ ~g 8~ 6,10 ~. c~o .~..~ <~ R F P F I V E ~ '?',.. ~o.~2.~2'L .~o,~.~,~ ~ ~ ow a~ ~ suB. JUN 1 9 ~990 ~.~5 · ,o ,o,,, Alaska 0il & Gas Cona Commission CASING ~ TUBING DETAIL ~ ~ ~.v. ~o,7~.~, SECTION T. 7 N.,R. 9 W. SM ~6 J~) ~.3~ ,'~,%,~ ~ai.~ A~ ~- I'~-~ STANDARD OIL COMPANY OF : . . . . . TABLE I Wells under Evaluation for Rate Potenti al 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 Wells being Evaluated for P&A/Future UtilitS 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 ., _~/~ .~.:rt E I~ r~f_ ~ ........ - ~ Jl ! .. ,._ ' ~'1' ~7~ ~ ~1 7r~! , , -~~- , ...... ........ r ~ -~ ~ ....................... I.~ .... [_{~.~'_:~'~ e ~ ~_ ~.l~/'m,'es.,~ r.~ t~'~,~.~ ........ ~ b-~ , ~', : .... ........... ..... , , , ., , ATTACHMENT E-I Injection Well Data Water Disposal Wells SRU 31-33W SRU 32-33W SRU 01-33W SRU 21=33W scu F Avg. Rate(BPD) 3270 651 125 2805 Max, Rate(BPD) 0500 0500 0500 0500 t+500 Avg. Press(psi) 769 778 913 735 Shut In Press(psi) 1000 1000 1000 1000 1000 Depth of Inj.(ft.) 2100 2100 23.2_0 3100 Depth of Well(ft.) 2061 2520 3000 6660 Gas Injection Wells Rate(MCFD) Max. Rate(MCFD) SCU SCU SCU SCU scU SCU SRU SRU SRU 31-0-2 323-0 332-0 3t~l-t~ 3151-8 312-9 321-9 323-9_~ 303-33 332-i5 312-22 310-27 SRU 331-2z 39~950 35,680 27,600 37,600 30,300 00,000 29,900 35,920 0 0 0 0 0 05000 05000 05000 05000 05000 05000 05000 ' 05000 05000 05000 05000 · 05000 #5000 toe/ts- · 5075 5370 . 5095 5355 5160 5270 5155 5105 Shut In Shut In Shut In Shut In Shut In 7 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 10291 10390 10070 10226 10256 10183 10290 10280 10695 11388 10750 11106 10800 11520 10775 11119 10850 10810 10785 10705 10750 10995 11982 11000 11030 11620 -8- ARCO A!aska, Inc. 110500 ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.252 SWANSON RIVER FIELD - UNIT 051950 August 1987 09-Sep-87 Name of Operator Fi eld and Pool Month and Year of Injection WELL NO. 514--4 523--4 332-4 541--4 541-8 512--9 323--9 1345-33 1412-I0 521-9 t45-4WD 2. API NUMBERI3. C 50- I L I A I S I___S 133-10104-00 153-10106-00 155-10107-00 155-10109-00 155-10120-00 155-1'0125-00 153-1012&-00 155-101&8-00 155-20206-00 155-10125-00 155-10111-00 ID I I 1 I I I I I I I I I I I I I 4. FIELDIS. DAYSI TUBING PRESSURE & POOL I IN I CODE I OPER l&. MAXI7. AVERAGE I I PSIS I PSIS I I 772100 I 50 15,450 I 4,958 772100 ! 0 I 0 I 0 772100 I 50 15,500 I 5,005 772100 I 50 15,550 I 5,141 772100 I 0 I 0 I 0 772100 I 50 15,550 I 4,945 772100 I 50 15,500 I 4,928 772100 I 0 I 0 I 0 772100 I 0 I 0 I 0 772100 I 30 15,450 I 4,991 77205& I 0 '1 '0 I 0 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I | I CASING PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INflECTION I I 8. MAXIg. AVERASEI10. LIQUID III. GAS I 15. LIQUID I 14. GAS PSIS I PSIS I (BBL) I CMCF) I (BBL) I (MCF) ...... I I I I I 5,300 I 2,559 I I .591259 I I 1,177,165 0 I 0 I I 0 I I " 1,040 I 656 I I 51,632 I I 948,95 2,860 I 2,576 I I 57,120 I I 1,113, 01 0 I I 0 I I 0 1 1,240 I 1,109 I I 40,485 I I 1,214,475 2~600 I 2~568 I I 55,148 I I 1,054,428 0 I 0 I I 0 I I 0 0 I 0 I I 0 I ~ 0 1 1,9&O I 1~815 I I 25,70& I I 771~182 0 I 0 I 0 I I 0 1 I I I I I I I I I I I I I I I I I I I I I I I I I .I I I I : I 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 II hereby certify that the foregoing is true and correct to the best o{ my knowledge 1 I ISigned l I I ITitle t Form 10-405 Rev. 12-1-85 Date ~ //J- ~x$;z INSTRUCTIONS ON REVERSE SIDE I15. I I I I I I I I' I I I I I I TOTAL I 0 I 6,279,814 I Submit in Duplicate ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTIONREPORT 20 AAC 25.232 ARCO Alaska, Inc. 110500 Name o{ Operator SWANSON RIVER FIELD - UNIT 051994 Field and Pool August 1987 Month and Year of Injection 11. WELLI2. APl NUMBERI3. CI4. FIELDI5. DAYSI TUBING PRESSURE I CASING PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION I NO. I 50- I L| & POOL I IN I I I : CODE ~ OPER ~&. MAXI7. AVERAGE:8. MAXIg. AVERAGEIIO. LIOUID Ill. GAS I ; SI I ; PSIG : PSIG I PSIG : PSIG ; (BBL) ; (MCF) I. ~512-22 1133-10147-00 IG ~ 772100 :514-27 1133-10154-00 ~G I 772100 1551-27 :133-10156-00 :G I 772100 f432-15 ;1.33-10141-00 :G I 772100 121-33WD1133-10162-00 :D ~ 772036 131-33WD1133-20336-00 ID I 77203& |32-35WDI133-101&4-O0 ID I 77203& 141-33WD1133-10167-00 ID I 772036 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 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 I I I I I I I I I I I I I I I : : : i II hereby certify that the ~oregoing is true and co~ect to the best of my knowledge I 13. LIQUID I 14. GAS I I lSigned I I I ITitle I Form 10-405 Rev. 12-1-85 I ...... I I ...... I I I I - I I I I I I I - I I t I I I 1 - I I I I I I I - I I I I I I 29 I 875 I 734 I I I 2,675 I I 77,581 29 I 820 I 746 I 0 I 0 I 2,770 I I 80,31S 30 I 875 I 759 I 0 I 0 I 2,071 I I 62,119 30 I 850 I 731 I I I 145 I I 4,352 I I I I I t I 1 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 I I I I I I I I I I I I I I I I I I I 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 I I I I I I I 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 l I I I I I I I I I I I I ...... I I I I. 115. I I I I I I I I I I I I I Date V/,~'-'/* 7 ITOTAL I 224,370 I INSTRUCTIONS ON REVERSE SIDE (BBL) I (MCF) I I I I I I l 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 0 1 I Submit in Duplicate PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY UNIT S-ll UNIT UNIT T-1 UNIT T-7 UNIT U-3 UNIT UNIT UNIT U-9 UNIT U-lO UNIT X-6 UNIT X-11 UNIT X-23 UNIT .NIT X-26 UNIT Y-3 UNIT Y-5 UNIT Y-6 UNIT Y-7 UNIT Y-11RD BAY UNIT Y-18 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL SWANSON RIVER, HEMLOCK OIL POOL · ARCO ALASKA lNG SOLDOTNA CK UNIT SOLDOTNA CK UNIT ~ 323-. SOLDOTNA CK UNIT 332-~ SOLDOTNA CK UNIT SOLDOTNA CK UNIT 3~1-8 SOLDOTNA CK UNIT 312-9 SOLDOTNA CK UNIT 321-9 SOLDOTNA CK UNIT 323-9 ........... SOLDOTNA CK UNIT 412-10 SOLDOTNA CK UNIT 3.3-33' UNIT OR LEASE TOTAL 3o9;~3. 17h, 380,162 602,357 515,072 26/4,751 183,322 2.4,173 29.,661 1.9,980 173.544 262,057 282,3,, 76.,92 /49,131 8".323 22,223 "3,679 306,.29 1",519,526 39,536,156 8",""5,002 39,536,156 88,810,1.0 SOLDOTNA CREEK UNIT SHUT-IN SHUT-IN 3'1 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 1,148,650 31 1,080.598 31 871,ll. 02 31 1,090,670 31 153,799 6 1,2.6,967 30 749,378 31 1,089,518 31 7,,30,982 - . . 6,975,0.0 7,115,160 1,2.1,.72 2,275,741 2,727,957 2,791,.76 2,551,632 1,790,980 1,767,557 6,17.,166 5,618,096 3,530,3.2 5,273,083 3,169,181 3,9~2,.03 1,968,753 2,653,403 102,6.0 597,32~ 6,.09,296 1,388,876 29/4,7,2.9'1 233,327,280 207,759, 231,764,932 218,694,647 30., 0.4,302 33,033,8.2 170,911,513 111,"13,676 - - ENHANCED RECOVERY - - WELL NAME AND NUMBER ARCO ALASKA lNG SWANSON RIV UNIT 331-27 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL TRADING BAY, MIDDLE KENAI C 0IL POOL UNION OIL CO CF CALIFORNIA ADL-18731 TRADING BAY ST. A-SRD-2 TRADING BAY ST A-12RD TRADING BAY ST A-26 TRADING BAY ST A-29 UNIT OR LEASE TOTAL POOL TOTAL TRADING BAY, MIEDLE KENAI D 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 FIEL0 TOTAL ALASKA INDIVIDUAL WELL PRODUCTION FOR MARCH, 1987 OIL(BBL) WTR(BBL) GAS(MCF) DAYS S14ANSON RIVER UNIT SHUT-IN T,,30,982 7,,30,982 SHUT- SHUT- SHUT- SHUT- SHUT-IN SHUT-IN CUM. OIL CUM. WATER 413,93. 15,582,616 ~,"98,822 6,267,061 7,3h8,684 21,618,136 CUM. OAS 28,263,659 ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.252 ARCO Alaska, Inc. 110500 Name of Operator SWANSON RIVER FIELD - UNIT 051~4 Fi eld and Pool December 1~8& Month and Year of Injection 1. WELL NO. 512-22 -~' 514-27 .~51-27 4;~2-15 I' "~ 2. AF'I NUMBER~5. C:4. FIELD:5. DAYSI TUBING PRESSURE I CASING PRESSURE ~DAILY AVERAGE INJECTION:TOTAL MONTHLY INJECTION 50- ILI & POOL I IN I I I I I Al :ODE ' OPER '&. MAXI7. AVERAGE,8. MAX,~. AVERAGE,lO. LIQUID ,11. 8AS , 1~. LIQUID | 14. GAS , ' SI I I PSIG I PSIG I PSIG I PSIG, (BBL) I (MCF) I (BBL) I (MCF) ~ l___SI I I I I ...... l I I I l 1~-10147-00 I G I 772100 I - , I I I I I I 155-10141-00 I G I 772100 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 I I 'I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ~ I I I I 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 l I I I I I I I I I I l 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-.- r-,. 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 : : ,, : : ......: : : JAN 2 0 II hereby certi~ that the ~orego~:n9 is true and correct to the best o{ my knowledge 115. ' I ? ,' I I ~ _~__~ I l- Anoho~S-I ISigned ..... ~.,,~._ _ __~ ............. _ ...... I I I ' ..z/,/_ I I I ' I Sup~rvi~ Ne~ Ventures ~ompliance and Revenue I I I ' ITitle Date ............. :TOTAL : 0 I 0 ' Form 10-405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate I z~t~s~a Oil & Gas Cc;..i ..... ~ssion i ARCO Alaska, Inc. 110500 ALASKA OIL AND SAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.252 SWANSON RIVER FIELD - UNIT 051950 December 1986. I ~ Name of Operator Field and Pool Month and Year of Injection ~1. WELL 2. API NUMBERI5. C14. FIELDI5. DAYSI TUBING PRESSURE I CASINS PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION I NO. 50- I LI & POOL I IN I I I I I ' I Al CODE I OPER 16. MAXI7. AVERAGEI8. MAXIg. AVERAGEIIO. LIQUID Ill. GAS I 15. LIQUID I 14~ GAS I ~ 81 I I PSIS I PSI8 I PSIO I PSIO I (BBL) I (MCF) ! (BBL) I (MCF) 514-4 155-10104-00 18 I 772100 525-4 155-10106-00 IS I 772100.I 552-4 155-10107-00 18 I 772100 541-4 155-10109-00 IG I 772100 541-8 512-9 525-9 1412-10 521-9 ~ ...... ~ l ...... l ~ I I ~ 50 15~500 I ,5,015 12,~500 I 1,~560 I ~ ,52,~501 I 50 15,650 I ' 5,278 ~,2~0 I 1,97& I I 29,526 I ~ 885,785 50 15,500 I 5,071 I 700 I 594 I I 24,058 ~0 15,550 I 5,1~7 11,200 I 849 I I 29,951 155-1012(}-00 IG I 772100 I 50 15,500 I 4,882 11,400 I 1,548 I I 25,121 155-10125-00 IG .I 772100 ! 50 15,000 I 4,697 12,850 I 1,267 I I 55,165 I I 1,054,878 155-10126-00 IG I 772100 I 17 15,200 I 5,140 11,600 I 1,588 I I 25,550 I I 450,602 155-10168-00 I G I 7721(}0 I 0 t 0 I 0 I 0 I 0 I I 0 155-20206-00 I G I 772100 I 0 I 0 I 0 I 0 I 0 I I 0 155-10125-00 IS I 772100 I 50 15,540 I 5~150 11,600 I 1~08~ I I 20,970 I 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 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ' I I I I I I I I I I' I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I' I I I I I I I I I I I I I I I I I I I I I -~'~ ~?i. ~ I.. I I I I I I I I I I I -,,...~c I i I I i ! I I hereby certify that thee for~?~ is true and correct to the best'of my knowledge l~igned .... Supervisor, New Ventures Compliance and Revenue ITitle Date -_ Fo~m 10-405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE I15. I I I I I I ITOTAL I I A .....~" ~,~' I I I I' I I I I I I I I 0 I 6,288,655 I I Submit in Duplicate LEASE ND. I ENHANCED RECOVERYI COMP. DATE .4 4- STATUS PRODUCT JAN FEB MAR ALASKA ZNDZVZDUAL NELL%0DUCT[0N FOR 1986 YEAR APR MAY JUN JHL AU~ ~EP OCT NOV . DEC TOTAl_ CUM. ~~ SHANSON RIVER, HEMLOCK ARCO ALASKA ZNC SflLDOTNA CK UNIT ~14-4 APT UNIT051950 08/15/60 HTR 1GINJ GAS 1055857 1026590 1189909 1165806 1228666 1211657 1257286 1288352 1505704 1125075 1022955 975018 15808655 291785545 SOLDOTNA CK UNIT 523-4 AP1 155-1010~-00 UNIT051950 0IL 0'6/01/61 NTR GINJ GAS 926806 895795 1014~89 1021515 1095847 1095954 1110742 1160265 1165222 986857 950909 885785 12505942 250168775 $0LDOTNA CK UNIT 552-4 APl 135-18107-00 UNIT051950 0IL 06/05/60 ~TR 1GINJ GAS 729520 696699 696'207 768556 848986 808659 855755 906629 908925 775879 755068 721155 9665572 20555681 sn~nnTNA CK HN~T 561-6 APl UN[T051950 05/21/60 HTR 1G[NJ GAS 966182 959897 1105510 1004702 1191650 1125655 1151894 1167267 1142665 989567 1047597 898524 12728466 228845715 SOLDOTNA CK .UNIT 561-~ APT ~RR-~n~?n-nn · UNIT051950 07/14/61 HTR lO[NJ GAS 772050 721011 855765 795562 858795 851801 877666 885419 861454 802085 790782 695626 9761772 217114264 ~nLnnTNA C[ UNIT 512-q' APl UNIT051950 10/09/60 HTR lO[NJ GAS 1150860 1105246 1275468 1219454 1266462 12~2821 1268188 1518592 1512222 1120415 1159677 1056878 1445~281 50078~545 SOLOOTNA C[ UNIT 52]-q APl UN[T051950 0IL 07/19/61 HTR 1. G[NJ GAS 787999 770786 941516 857121 859651 824009 859794 852654 865441 701058 657884 629091 95~6566 51111755 SOLDOTNA C[ UNIT 525-9 API 153-lO]?~-OO UNIT051950 0IL 07/17/61 NTR 1GINJ GAS 868162 887705 1057404 1002092 1041654 1027008 1054526 1105448 1110180 1002927 967125 650602 11552455 168165955 SOLDOTNA CK UNIT 612-10 UNIT051950 OIL 06/11/72 HTR ' 1NINJ GAS SOLDOTNA CK UNIT 343-53 UNIT051950 OIL 05/08/61 HTR ' 1G[NJ GAS .... SNANSON RIV UNIT 652-1~ UN]T051996 10/26/59 HTR ' 1GINJ GAS SHANSON RIV UNIT 36-15 UNIT05199~ OIL 08/04/61 HTR ' 1GINJ GAS m m AP1 155-2020~-00 AP] 155-10168-00 AP1 133-10161-00 API 155-10162-00 1558~ ...... ) 111415676 6018206 9029559 2056925 4643550 III {11 LEASE NO. IENNANCE9 RECOVERYI COHP.DATE + STATUS PRODUCT JAN FE~ · MAR ~~ SHANSON RIVER, HEHLOCK SHANSON RIV UNIT 312-Z2 APl ALASKA INDIVIDUAL HELL~ODUC'TION FOR 1986 APR MAY JUN JUL AUn SEP I]~T NI]V 135-101~7-00 YEAR TI]TAt CUM. 08/11/62 HTR 1GINJ GAS SHANSON ~ZV UNIT 51~-27 API 133-1015~-00 875988 2~017269 06/14/60 HTR 1GINJ GAS SHANSON RIV UNIT UN']T051994 III[ 331-27 133-10156-00 78352178 02/17/58 HTR 1GINJ GAS --.~---~.r ARCI] ALASKA TN~ 2826~ OPERATOR 0IL TOTALS HATER 8,337.995 POOL TOTALS GAS 7,041,527 7,852,~06 8,187,502 8,680,226 7,499,819 6,288,655 1,929,187,012 7,215,396 8,113,868 8,369.449 8,393,~51 8,667,789 7,511.775 93,601,663 SHANSDN RIVER. HEMLI]CK OIL HATER 8,337,995 FIELD OAS 7,041.527 7,832.~06 8,187,302 8,680,226 7,~99,819 6,288,655 1.929,187.012 7,215,596 8,115,868 8,369,449 8,393,~51 8,667,789 7,311,775 93,601,663 SNANSON RIVER TOTALS OIL HATER 8,357,995 7,215,.596 8,115,868 8,$69,~49 8,393,451 8.667,789 7,511,775 95,601,6 SWANSON RIVER WELL SRU 312-22 --SRU 314-27 SRU 331-2.7 S~CU 323-4 .SCU 332-4 SCU 341-4 SCU 341-8 SCU 312-9 SCU 321-9 SCU 323-.9 SRU 432-15 TYPE Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Water Injector STATUS AS OF 1/1/88 Shut-in Shut-in' ..- .... -Shut-in . , Injecting Injecting' Injecting Shut-in Injecting Injecting Inject_lng Shut-in GRU13/2c RECEIVED_ FEB 2 Alaska Oil & Gas Cons. Commission' Anchorage ARCO Alaska, Inc. Post Office ~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 265 6369 John C. Havard Engineering Manager Cook Inlet/New Ventures July 14, 1987 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Re.. Swanson River Unit: Gas Injection Well Production Casing Pressure Tests Dear Mr. Chatterton: Attached are seven (7) Well Service Reports documenting the results of the recent pressure tests conducted on Wells SCU 314-4, SCU 323-4, SCU 332-4, SCU 341-4, SCU 312-9, SCU 321-9, and SCU 323-9. The other active gas injection well, Well SCU 341-8, is currently loaded with kill weight fluid in anticipation of a late-September workover to repair a packer leak. Of the seven gas injection wells tested, only one (Well SCU 323-4) did not meet the criteria stated in Rule 6 of the AOGCC Area Injection Order No. 13. The remaining six wells held their calcu- lated test pressure (within 10%) for 30 minutes. The test pressure for each well was calculated to generate a differential pressure gradient across the casing of 0.25 psi/ft at the vertical depth of the uppermost packer. The surface pressures in Well SCU 323-4 have stabilized at acceptable levels (PC _+1500 psig, SC _+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.' cl: 0004 Attachments cc: Mr. Joseph A. Dygas- Bureau of Land Management ARCO Alaska, Inc. Is a Subsidiary of AtlanticRIchfieldCornpany - CHECK THIS BLOCK IF SUMMARY (~ONTINUED ON BACK Wel~therReporl J Temp. / ! CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Chili Fiotor ' I WInd Vel. · liigned~ Weither {NOvember 1983) (Formerly 9--331) U ,'E STATES (Other lustruetl~ ~n re- DEPARTMENT OF THE INTERIOR ,er,,-'de) BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not U~e this form for proposals to drUI or to deepen or plug back to a different r~rvolr. Us~ ,,APPLICATION FOR PERMIT--" for such proposals.) i. OiL C] ,A. 2. NAME OF OPERATOR ARCO Alaska, Inc. 3. ADDRERR Or 0PB,RATOR P.O. Box 100360, Anchorage, AK 99510 4. LOCATION OF WaLL (Report location clearly and tn accordance with any State requirements,e See also space 17 below.) At surface Soldotna Creek Unit - 7 wells 14. PgRMIT 1~0. 15. ELEVATIONS (Show whether or, Fr. o~. et~) Form approved. Budget Bureau No, 1004-0135 Expires, August 31, 1985 5. LBAOB DBsIONATION AND IIIIIL IlO. O. IF INDIAN, ALLO~FmB OR TBIBI NAMR ?. UNIT AORRBMRNT NAMe Soldotna Creek Unit 8. FARM OR LBAeB NAMR ~. weLL NO. 10. FIELD AND POOL; OR WILDCAT Swanson River Fi.ld mUUVm! OR AIBA Sec. 4, 9, T7N, Rgw 1~. COUNT! OR ]PAIleHj 18. fJTATR Kenai [ Alaska 10. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICe or INTENTION TO: FRACTURE TREAT MULTIPLB, COMPI,ETE SHOOT OB, ACIDIZB, ABANDONe REPAIR WELL CHANGE, PLANS IUBI~UILqT UNIT O!: 8HOOTING OR ACIDlZlNG ABAN~NMBBTO (Other) (NOTe: Report results of multiple eompieUon on Weft (Other) X Pressure Test Completion or Reeompletion Report and Log form.) ,.~ES('it:B~ I'ROPOSED OR COMPLETED 0PERATION~ (Clearly state all pertlnet~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 sones perU- nent 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/fi between the uppermost packer and the formation. The wells incl.uded 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 Commission Oil & Gas Cons. Anchorage hereby certLfy~that the foreglxtng ts tr~e and correct Regional Enaineer TITLE (This space for Federal or State office use) APPROVED BY CONDITIONS Olv APPROVAL, Ii* AN~: TITLE DATE *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 United States anv false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. SCU 323-9 LOAD PRODUCTION AND SURFACE CASING AND PRESSURE TEST PRODUCTION CASING Loadin0 PC and SC Annulus 1. Record pressures on the tubing, production casing and surface casing. 2. Blow down PC' to 1000 psi, recording all pressures. . Blow down SC, recording all pressures. Shoot fluid levels for pump-in volumetrics. Estimated volumes from most recent fluid level data are noted below. 0 . Load SC with lease water containing l0 gal/lO00 gal WT 676 corrosion inhibitor and a 5 bbl crude cap. Do not exceed 300 psi surface pressure during pump-in. Monitor all pressures. Load PC with lease crude. Do not exceed 2500 psi during pump-in. Do not bleed PC below 1000 psi during pump-in. Pressure Testing) Production Casing Note' 24 hours prior to initiating pressure testing procedure, contact the Alaska Oil and Gas Conservation Commission at 279-1433 and the BLM at 267-1240, and inform them that a pressure test will be conducted as per Rule 6 of Swanson River Field Area Injection Order No. 13. Note: During pressure tests of production casing, closely monitor PC/SC packoff to insure no communication to the surface casing. If any communica- tion is noted, cease pressure test and notify Engineering in town. 7. Pressure test PC/SC packoff to 3000 psi. . 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'). e 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 3730 psi' is reached. Hold pressure for 30 minutes, noting initial and final pressure on all strings. Vol umetri cs Surface Casing Production Casing Fluid Level (3/12/87) Annular Capacity (bbls/ft) Estimated Fluid to surface (bbls).. 6488' .0264 171 O' .0699 0 TRANsMXTT,.~ND ACKNOWLEDGEHENT OF RECEIPT~. MATERIAL - (ALASKA) qqso - THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEP. EIN. ED- Folded H - Rolled S - Sepia F - Film X - Xerox B - Blueline PLEASE CHECK AND ADVISE IMMEDIATELY. NEUL ~ ,., __ i- i · iii RECEIVED BY i, ,, REMARKS ON OTHER SIDE, THIS SHE'E'T C~ON U. SJu INC. BOX 7.839 'ANO, IORAGE, ALASKA 99510 TRANSMITTAIF-hND ACKNO~q~EDCEMENT OF RECEIPT '~'~M~\TERIAL - (ALASKA) - DATE FD- Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline ........ THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. -- -- .. I/ -- I i i _ "// ,' r 9 · , i11 i , ~11 i i vi iii -- i - iii II · L il" __ . I' - ......... I I ~' ~ ,~ -- I -- _ ~ I_'_ _ _ ~1~ ii1~ RECEIVED ~x 7~39 REMARKS O~ OTHER SIDE, THIS SH~T ,~,F~OPAGE, A~SKA 99510 '·e .- . . · ,,i · ~'~.e · · " eee * e,, /P, ANSmTTAL AND ACK'F"~rLEDGMENT OF KECEIPT OF MATERIZ Mr. T. R. Marshall State of Alaska Division of Oil & Oas 3001 Porcupine Drive Anchorage, Alaska 99504 · . DATE: THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREWITH. · CHEC~ AND ADVISE IMMEDIATELY. PLEASE -o · . . - . . o · . : · .o . · o : . .o / Remarks: · · ~ SUBMIT IN DUI'~ ~CATE* STATE OF ALASKA (soo other structions on reverse side OIL AND GAS CONSERVATION COMMITTEE ~. iii i ii i i i i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* i i i ii la, TYPE OF WELL; OIL ~] GAS ~ ' WELl. WELL DRY Other b. TYPE OF COMPLETION: WELL OVER EN BACK RESVR. Other __ 2. NAME OF OPERATOR ADDRESS OF OPERATOR 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface At top prod. interval reported below At total depth 13. DA. TE SPUDDED' 114. DATE T;D. REA. CHED 18 TOTAL DEPTH, NIX) & TVD i9. PLUG, BA,~K 22. PI%eDUCING !i'¢TERVAL(S). OF THIS COMPLETION~TOP, BOTTOM, NAME (NIT) AND TVD)* 15. DATE CO,NiP SUSP O1% ABAN'D. i16. MD & 'rv~[20, IF 1WJLTI~:'LE COMPS.,., /-IOW MA.NY* 7. 1F IND1A~I, ALLOTTEE OR TRIBE NA_IVIE 8. UNIT,FAAllVI OR LEASE NAME 9. WEI.L NO. 10. FIELD A~qD POOL, OR WILDCkT 11. SEC., T., R,, M., (BOTTOM HOLE OBJECTIVE) 12. PER,MIT NO. i E~EVATIONS (DF, RKB, R'¥, GR, ~CPC)*I17. ELEV. CASINGtIEAD ! 21. INTERVALS DRILLED BY ROTARY TOOLS '~ '" CABI,E TOOLS 23. WAS DIRECTIONAL SUR, VEY MADE · 24. TY~PE ELECTF, IC AND eTHEl% LOGS RUN CA. SIi4G SiZE \V_EIGHT LB/FT. ",: ,, , 7 ,. /°~','t~ , 26. LIN~'R E,ECOH.D SIZE '[ TOP (5'ID) ' [ BOTTO)~ (MD) SACKS CEA'I~T* [ 28. PEteR.ATheNS OP~ TO PRODU ON (interval, size and number) I~- ~ _ i iii i i CASI/qG RECORD (Report ~'11 strings set in wdll) HOLE SIZE CEM[LNTING RECOtLD A. MOUNT PULLED /~ i i 27. TUBING RECOF~ SCiLE~ (~(D) [ SIZE ~' DEPTH SET (MD) r PACKER SET (},iD) 1 ~ I /~a~ ~ ....... ,, I ..... I ...... 29. -ACID, SiiOT, FiIAC~ URE, C~',IENT SQUEEZe, ETC. D------------------I~I'Ii INTt!IRV.~j~ (MD) AMOUN£ Z~ND I'2!ND OF MA'IE?,.IAL USED PRODUCTION DATE FIRST Pi-~OIDUCTION I I:~KoDucTION 1V[EI[{O'D (Flowing, g~ia3 1i£L, p~mping--size and type of pump~ FLOW, TLTBINCe CASLNG PRESSURE [CAL~TED OIL--BBL. OAS--?~C~. 31. DISPOSITIONOF GAS (Sold, used for fuel, vented, etc.) [V~ELL 2~'FATUS ( Producing or l VCATEI-t--B BL. 1 GAS-OIL ILkTIO IWA~BBL. I OIL GRAVITY-APl (CORR.) frOST W,T~SS~ u~ 32.LIST OF ATTACHMENTS ..... 33. I hereby certify that the foregoing and attached information ts complete and correct as determined from all-available records SIGNED DO~/; /~,~ d~H TITLE DATE _~'-~..~_-~-- ..... .............. 7,-l"~, ...... *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correc~ well completion report end log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- merits given in ether spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate, prc~duction from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the p~cJuci~:g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interv~l ret~orted i~ ite,~ 30. Submit a sep~'~rate report (page) on this form, adequately identified, for each addi~ior~at interval to be seperately produce.J, show- ing the ack:litional data pertinent to such interval. It, m26: "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 completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). ~JMMARY OF' FORMATION TESTS INCLUDIN(; INT'~IZVAL T~TED. PHE~URE DAT~ ~'~COVERI~ oF OIL, GAS. 35. G~GIC MARK~ WAT~ AND MUD · ~ . ...................... , - N~ VELL COMP~T!ON F~EPORT ~:r'~- STANDARD OIL COI~PA~Z OF. C.~L L~Oi~IA -I~STE~ OPE~TIONS, INC.-OPERATOR A~A: Kenai Pe~nsula, Cook Inlet Area, Alaska L~ O~ICE Anchorage ~ase No. A-028997 PRO~RTy: Soldotna Creek U~t WELL NO~ S. CU.2..3-9 ___ Section 9 T... 7 N R. 9 W , Seward B & M LOCATION: Surface: 2~20' North and i970' East from SW corner of SectiOn 9 ELEVATION: 135 ' K,B. DATE: October 26, 1961 K~ B. is 15' above ground C. V. CHATTEI~TON'~ DIST.~ S'~RINT'EN-~ENT DRILLED BY: Reading & Bates Drilling Company DATE COmmENCED DRILLING: May 30, 1961 DATE CO~PLETED DRILLING: July 17, 1961 DATE OF INITIAL PRODUCTION: July 19, 1961 PRODUCTION: Daily Avera§e 669 B/D F~owing Oil 662 B/D Gravity Water 7 B/D TP Gas 167 MCF/D Bean 370 . 1680 psi 10/64" TOTAL DEPTH: 10,750 ' SUMMARY PLUGS: 10,652-10,748 ~ JUNK: None CASING: 20'" conductor pi~ cemented @ 32~ 11-3/4" casing cemented @ 2009~ w/18OO sacks. 7" casing cemented @ 10748' w/6OO sacks around shoe and 900 sacks through DV @ 6796~ REPORT - PACKER .INSTALLATION .... , ,, ,. , , . , , , j, - ~ AREA: Kenai Peninsula, Cook Inlet Area, Alaska LAND OFFICE: Anchorage A-028997 PROPER2Y: Soldotna Creek Unit WELL NO.: SCU 23'9 Section 9, Township 7~ North, .Range 9 West, Seward B~ LOCATION: Surface: 2520' North and 1970' East from Southwest Corner of Section-9, Seward B & M. ELEVATION: 135 DATE: April 2, 1963 C. V. ~NATTE~TON, District supe~lnt-endent CONTRACTOR: Santa Fe Drilling Company, Rig ~35 .. DATE COMMENCED REMEDIAL WOI~: October 17, 1962 DATE COMPLETED REMEDIAL WOt~: OctOber 20, 1962 S~ TOTAL DEPTE: 10,750' PLUG~: 10,652 - 10,748' CASING: 20" cemented at ~2' 11 3/4" cemented at 2009' 7" cemented at 10, 748' PERFORATIONS: As before PRODUCING DEPARTMENT TELEPHONE BR. 7--6201 C. V. CHATTERTON D ISTRI(~T SUPERINTENDENT P. O. BOX 7-839 ° ANCHORAGE ° ALASKA November 1, 1961 Mr. D. D. Bruce State Department of Natural Resources 329 Second Avenue Anchorage, Alaska Dear Sir: Enclesed herewith is Completion Report for the well, Soldotna Creek Unit 23-9, for your information and files. Yours very truly, encl. ¢O L TZON SoLDOTNA CREEK UNIT #23-9. ...... ~'e?a~'°, ,B. & M Section:9, T. 7 N,.R. 9 ?Y~,~.,. c ~ ...... Standard Oil Co. of C~if~ ~.O.I. - ~erator Page 2. PERFORATION RECORDS: 4 ' 1/2" holes Per fo°t over following intervalS: lO62O-lO592 10580~i0554 ' lO5H5 1o455 10434A!0388 10364--10351 10343-10317 10300-10280 '~ELL SURVEYS: 1. Schlumberger Induction-El~ ctrical Log, interval 10754-2012 ' 2. Schlumberger Sonic Log, interval 10742-2012 '. 3. Schlumberger Micro-Caliper Log, interval 10752-9300', 6800-5700 4. Schlumberger Continuous Dipmeter Log, interval 10755-2012 '. 5.' Schlumberger Neutron Collar Log, interval 10652-90oOt. 6. Schlumberger Cement Bond Log, interval 10647-1450'. DRILL STEM TESTS: WSO Test #1 on 5 - 1/2" holes @ 10276' - OK. WSO Test #2 on 5 - 1/2" holes @ 10625' - OK. Schlumberger Wireline Formation Tests at following depths: 10600 '; 10560'; 10503 '; 10464'; 10400 '; 10358 '; 10326 '; 10290 '. COMPLETION REPORT SOLDOTNA CREEK UNIT #23-9 Se.qt~on..9,, .T, .7 N., ..R.. ? w..,. S~ew.a. rd B & ~ ~tandard Oil Co. of Calif., W.O.I. , Operator May 30,_...~196.1_ '~ Spudded at 8:0OPM, 5/30/61-' Drilled 17-1/2" hole. 0 ~ - 100 ~ 100 ~ drilled Drilled 12-1/~" hole. 1001 . 151' 51 ' drilled Page 3. Drilled 12-1%" hole 151' - 20281 1877 ~ drilled Opened 12-1/4" hole to 17-1/2" hole 100 ~ - 10001 900' opened 82 pcf mud J, un, e, !, 196! Opened 12-1/4" hole to 17-1/2" hole. 1000' - 2028~ 1028~ opened. Circulated and conditioned hole to run casing. Ran 11-3/4" casing and cemented @ 2009~ as follows. Cemented 11-~/4" casing at 2009' in 1 stage with 1800 sacks of cement, using Halliburton power equipment. Used I top plug. 1st Stag~ around shoe with 1800 sacks of cement. Pumped 40 bbls of wa~er ahead, mixed 1800 sacks of cement in ~3 mins. using 2 Halliburton trucks, displaced in 13 mins. using rig pumps. Average slurry weight llT#. Bumped plug with 1600 psi. Full circulation. TOP JOB: Cemented between conductor pipe and ll-3/h" casingwith 60 sacks Of'cement. Cement in place at 5:15 6/1/ l. Hookload weight of casing before cementing 7800# after cementing before landing csg 6100# . . . · Cas_Lug Detail:. 47 jts or 1991.~' ll-3/~" 47# 8Rd. Equipped with ~ ' Flexiflow float collar and guide shoe. Below K.B. 18.00~ Casing cemente~ 20~9.'~4' COMPLETION REPORT SOLDOTNACREEK UNIT #23-9 Section 9~ T. 7 N.~._ R. 9 W._a Seward ~1 Standard Oil Co. of Calif., W.O.I. - Operator Page 4 June l, 1961 conttd. Installed BOPE.. June 2 - June 6,,, 1961~ Tested BOPE. Drilled 9-7/8" hole. 2028' - 6580' 4552 ' drilled Well ~bI~w in w/83# per cu ft. mud in hole. Shut in and increased mud weight to 95#. Circulated and conditioned mud for 4-1/2 hours. Circ. all gas out of mud. Drilled 9-7/8" hole. 6580' '~ 6737' 157 ' drilled June 7 June 8~.. 1961~ Drilled 9-7/8" hole. 6737' - 7365' 628' drilled 97 pcf mud June 9, 1961 Gained 100 bbls water drilling through coal seam (7350-77~2). Gas cut mud weight from 96# to 89#. Increased weight to 99#. Drilled 9-7/8" hole. 7365' - 7708' 343' drilled 97.5 pcf mud June 10, 1961 - June 18, l?6_~l Drilled 9-7/8" hole. 7708' - lOl08' 2400' drilled 96.5 - 98 pcf mud ~J~ne 19~ .176! Drilled 9-7/8" hole. 10,108 '-10,245 ~ 138' drilled Circulated hole and started coring @ 10245' with 8-7/8" core head and 6-3/4" core barrel. 97.5 pcf mui COMPLETION REPORT SOLDOTNA CREEK UNIT #23-9 Section ._9~ :~., ...7 N-, R~_m_- 9 W., Seward Standard Oil Cq, of Calif., W.O,I~ - Operator Page 5 June ~, 196! Cored 8-7~8" hole 10245-10289'. Cut Core #1 10245-10275'. Cut, & recovered 30 '. 97o 5 pcf mud .June 21,.~, 1961 Cored 8-7/8" hole 10289-10329'. Cut Core #2 10275-10305'. Cut & recovered 30'. 97 pcf mud. Cored 8-7/8" hole 10329-10344'. Cut Core #3, 10305-10330'. Cut & recovered 25'. Cut Core #4, 10330-10344'. Cut & recovered 14'. 97.5 pcf mud Cored 8-7/8" hole 10344-10372'. Stuck pipe @ 6650' while pulling core barrel. Worked pipe loose after 3 hrs. Finished pulling core #5. Well flowed approximately 2 bbls/min. Recovered 281 of core #5 10344-10372'. Ran in with 9-7/8" bit. Circulated and in- creased mud weight to 98.5#. Conditioned mud for three hours. Reamed 8-7/8" hole to 9-7/8" hole from 10245-10372'. Drilled 10,372'-10,374'. Circulated I hour on bottom after reaming. 98.6 pcf mud .J~ne ,25,, 1961. Coring ahead w/8-7/8" bit. Core #6, 10374-10398'. Cut & recovered 24'. 99.5 pcf mud Core #7, 10398-10410'. Cut and recovered 12'. Circulated on bottom one-half hour. 99.5 pcf mud June 27, 1961 Core #8, 10410-10,440'. Cut and recovered 30'. 99.5 pcf mud COMPLETION P..W.P CRT SOIDOTNA CREEK UNIT #23-9 Section .9~,_.To 7 N., R. 9 Wo, Seward ~ Standard Oil Co. of Calif., W.O~I. - Operator Page 6 Core #9, 10440-10,470'. Cut & recovered 30'. 99 pcf mud J,, ,une ,,~., 1961 Core #10, 10470-10495 '. Cut & recovered 25 '. 99 pcf mud · J..u_ne ~30, 1961 Core #11, 10495-10525'. Cut 30', recovered 28'. 100 pcf mud Reamed with 9-7/8" bit 10374-10525'. Cored with 8-7/8" core head 10525-10528'. 99.5 pcf mud Coring 10528-10559 '. Core #12, 10525-10555'. Cut 30', recovered 29'. 99.5 pc f mud Cored ahead 10559-10593 '. Core #13, 10555-10585'. Cut & recovered 30'. 99.5 pcf mud Ju._ly 4, 19.6_1.. Cored ahead 10593-10629'. 99.5 pcf mud Cored ahead 10,629-10,657'. Recovered core #14, 10585-10630'. Cut & recovered July 6, 1961 Cored ahead 10657-10685'. Core #15, 10630-10669 '. Out & recovered 39 ~. 99.5 pcf mud COMPLETION REPORT SOLDOTNA CREEK WMIT #23-9 SeCtion 9, T. 7 N., R. 9 W., Seward B&M Standard Oil Co. of Calif., W.O.i. - Operator Page 7 July 7, 196~ Cored ahead 10685-10703 '. Core #16, 10669-10703'. Cut 3h', recovered 33'. Measured out hole. Pipe Tally 10703~ Strap.Tally 10696' Correction 7~ Returned 10~20-10525.'. Opened 8-7/8" hole to 9-7/8" 10525-10530'. 99.5 pcf mud July 8, 1961 'Opened 8-7/8" hole to 9-7/8" 10530-10703'. Drilled 9-7/8,, hole 10703' - 10~30'TD bT' drilled Circulated and conditioned mud. Ran Induction Electrical log, interval 10750-2OO9'~ Sonic log over interval 107h2-2009'. ,J,,,ul, y 9, 1961 Ran Micro Caliper Log over interval IO750,9300' and 6800-5700'; Continuous Dipmeter, interval 10750-2010'. Reran Dipmeter. Layed down 6-3/4" core barrel. Went in hole with 9-7/8" bit. Circulated and conditioned mud for 3-1/2 hours. Laid'-down drill pipe. J, uly 10, 1961 Rigged up and ran 7" casing. Cemented 7" casing at 107h81. in 2 stages with l~O0 sacks of cement treated with 0.3% HR-4 using Halliburton power equip- ment. Used I top and I bottom rubber plug. 1st Stage around shoe with 600 sacks of cement. Pumped 50 bbls of water ahead, mixed 600 sacks of cement in 20 mins using Halliburton truck, displaced in 33 mins. using rig pumps. Average slurry weight llT#. Bumped plug with 1800 psi. 'Full circulation. 2nd Stage through DV at 6796I. Dropped DV bomb, opened DV ports in 31 minsT.L~ Pumped ~0 bbls of water ahead, mixed 900 sacks of cement in hO mins using Halliburton truck~ dis- placed in 19 mins using rig pumps. Averags slurry weight llT#. Closed DV ports with 2hO0' psi. Full circulation. Cement in ~ulace at h:O0 PM. Hookload weight of casing before cementing 208,000# after cementing before land casing 19~,000# at time of landing casing l?O,O00# COMPEETION EEPORT SOLDOTNA CREEK UNIT #23-9 Section 9,. T~. 7'N.~, R. 9 W., Seward BUM Standard Oil Co. of Calif., W.O.I. - Operator Page 8 Ju.u.ly i,lo, 1961 cont'd. 7 jts 29# BT-N-80 19 jts 26# BT, N-80' 86 jts 23# BT, N-80 44 jts 26#, BT, N-80 6 jts 29#, BT, 'N-80 1 X-over 1 DV collar 1 X-over 36 jts 29# BT, N-80 1 X-over 29# P-110 38 jts 29#, L8R, P-110 295.00' 759.71' 3667.23' 1827.80 ' ~ 247.39' 6.66 ' 2.00' 6.83' 1563.96' 6.65' 1600.28 ~ 1 pup marker 29#, P-110 14.O8' Bottom 18 its 29#, L8R, P-110 758.98~ Total 259 jts or 10,756.57 ' Above K ~ B. Csg. landed @ -8.00 -i6,'748.57'~ Removed BOPE and set casing slios. Set secondary packer and tested to 3500 psi, Held OK. Reinstalled BOPE~ 99.5 pcf mud Tested BOPE to 2000~ psi. Held OK. Picked ~'~p 212 jts 2-7/8" tubing. Found top of cement @ 6770~. Drilled out cement and DV collsr. Finished picking up 2-7/8" tubing and cleaned out to baffle collar at 10657'. Tested DV collar to 2300# psi. 90.5 pcf mud , Circulated and conditioned mud. Ran Neutron Collar Log over interval 10652-9000'. Ran Cement Bond Log over interval 10647-1450'. Shot 5 - 1/2" holes @ 10,276' for WSO test #1. WSO Test #1, 10,276' Tool Assembly: 2 outside BT recorders, 4 ft perf'd tail pipe, 7"' type "C" hookwall packer,VR safety joint, hydraulic jars, 2 inside BT recorders, hydrospring tester and dual closed in valve. Used 2461' of W.C, Ran on 10,185' of 2-7/8" EUE tubing. Set packer at 10213~ with 17' of tail to 10230'. No ~ISI ~ressura. Opened tool to surface at 4:27 AM for 60 rain flow test. Faint blow 8 m_in, dead balance of test. COMPLETION REPORT SOLDOTNA CREEK UNIT #23-9 Sect~on~.._9,~T. 7 N., R.?W.~,_ Se._ward_Rg~ Standard Oil Co. of Calif., W.0.I. - Operator Gul 1961 cont' Shut in tool at '5:27 AM for 35 rain FSI pressure. Pulled packer loose at ~6:O3 AM.. Recovered 101 net rise.. Pressure Data: IH IF FF FSI FH Top inside 6329 ll41 ll41 1182 6246 Bottom inside ~6334 1131 1143 1178 6258 Top outside 6430 ll~5 1164 1199 6290 Bottom outside 6355 1124 1148 ll60 6278 Jul~ 13,~. 1961 Shot 5- 1/2" holes @ 10625' for WSO #2 WSO #2, 10,625' Tool assembly: 2 outside BT recorders, 4' perf'd tail pipe, 7" type -"C" hookwall~.~packer, VR safety joint, hydraulic jars, 2 inside BT 'recorders, hydrospring tester, and dual closed in valve. Used 2726~ W.C. Ran on 10,532~, 2-7/8" EUE tubing. Set packer at 10,560', 17' of tail to 10'577'. No ISI pressure. Opened tool to surface at 5:30 PM for 5 hr 25 min flow test. Strong blow decreasing to medium blow in 30 min. Dead in 55 min. Opened bypass. Purged perfs. Reopened to surface @ 6:54 PM. Strong blow air. Cushion to surface @ 7:34 PM. Mud and oil to surface 7:55, oil to surface 8:03 PM @ estimated 1500-2000 B/D rate+ , 36 1.2%: 0.6% water, 0.6% S &~ M! , trace mud. Shut in tool at 10:55 PM for 122rain FSI pressure. Pulled packer loose at 12:57 PM and backscuttled. Pressure Data: (Final Pressures) TOp Inside Bottom Inside IH IF FF FSI FH Stylus disengaged 6613 1438 4340 5316 6564 Top Outside Bottom Outside 6732 1460 4365 5394 6732 6621 1441 4306 5283 6615 Tool perfs not plugged. Casing perfs plugged. Considered clean test, WSO. COMPLETION REPORT SOLDOTNA CREEK UNIT #23-9 Section~9~...T..:~ 7.N-, R' 9 W..~ Seward Standard Oil Co. of Calif., W. Ooi. - .Operator Page 10 July 14, 1961 · Ran Schlumberger Wireline Formation Test #l, 10,600'. Tool open 23 minutes. -No recovery. Pressures: ICIP - None, IF - 1489, FF- 1479, FCIP- 1521, FH -6588 psig Ran Schlumberger Wireline Formation Test #2, 10,560:o Tool Open 17 mins + 2 ICIP. Recovered: 0.36 cu. ft. gas, 10,200 cc. water, 50 cc. sand. R~ = 2.5 ohms/meter @ 72° F (Schlumberger) Rmf = 5.82 ohms/meter @ 57° F (Schlumberger) 'Pressures: ICIP - 4923, IF - 4763, FF - 4763, FCIP - 5373, FH - 6604 psig Ran Schlumberger Wireline Formation Test #3, 10,503 '. Tool open 20 rains. + I ICIP. Recovered: O.21 cu. ft gas, 10,100 cc water, 100 cc sand. RN = 3.5 ohms/meter @ 72° F Rmf -- 5.82 ohms/meter @ 57° F Pressures: ICIP - 5200, IF - 5100, FF - 5200 FCIP- 5250, FH -6400 psig Ran Schlumberger Wireline Formation Test #4, 10,464'. Tool open 51 rains. +.4 ICIP. Recovered: 0.40 cu. ft. gas, 125 cc water, trace sm~d RW = 3.3 ohms~meter @ 72° F ~mf = 5.82 ohms/meter @ 57° F Pressures: ICIP- 5000, IF- 208, FF- 604 FCIP- 5300, FH- 6426 psig Ran Schlumberger Wire!ine Formation Test #5, 10,400'. Tool open 13 rains. + 5 ICIP Recovered: 0.25 cu. ft. gas, trace water Rmf = 5.82 ohms/meter @ 57°F Pressures: ICIP - 161, IF - 99~ FF - 99, FCIP- 99, FH -6374 psig Ran Schlumberger Wireiine Formation Test #6 - M.~srun Ran Schlumberger Wireline FormatiOn Test #7,10,358 ~. Tool open 16 rains + 6 ICIP Recovered: 0.27 cu. ft. gas, trace water Rmf -- 5.82 ohms nueter @ 57° F Pressures: ICIP- 166, IF - 88, FF - 88, FCIP - 182, FH - 6350 psig COMPLETION REPORT SOLDOTNA CREEK UNIT #23-9 Section ..9~. T. 7 ..N,, R. 9 W_,~ Seward B&3~ Standard Oil Co. of Calif., W.O.I. - Operator Page 11 Ran Schlumberger Wireline Formation Test #8, 10,326t Tool open 20 mins. Recovered: 0.25 cu. ft. gas, 10,250 cc water Rm_f = 5.82 ohms/meter @ 57° F Pressures: ICIP- None, IF- 493h, FF- 5336, FCIP- 5409, EH- 6796 psig Ran Schlumberger Wireline Formation Test #9, 10,290'. Tool open 18 mins + 5 ICIP Recovered: 0.4 cu. ft. gas, trace water Rmf = 5.82 ohms/meter @ 57° F Pressures: ICIP - 125, IF - 94, FF- 62, FCIP - 62, FH - 6218 psig Picked up 4-1/2" DC and 6-1/8" bit and ran in to 7500'. Circulated and conditioned mud for I hr. Ran to bottom, circulated and conditioned mud 4-1/2 hrs. Pulled out to perforate for production. Perforated 4 - 1/2" holes per ft. over following intervals: 10,620-10,592'; 10,580-10554'; 10,545-10,455'; 10,434-10,388~; 10,364-10,351'; 10,3h3-10,317'; 10,300-10,280' Ran and hung 2-7/8" 8R EUE Range 2 tubing @ 10,508' K.B. Removed BOPE..<' ~"Ins%.a~.led ~ :Xm~a. utree .-amd ~ested .witha3~O0 '~ps~:'.'..f.~r ~[~ rains. - .H~ld OK-~2.'.Co~manced displacing.~mudd~ith oil at 6:00 PM. Pumped 50 bbls of water ahead, followed by 396 bbls. of crude oil. Stopped circulating at 9:00 Pm, Formation oil to surface at 9:00 PM. Flowed mud to sump until 9:30. Started flowing to trap at lO:O0 PM. Representative flow rate and cuts as follows: FLOW RATES ~ ' - BEAN TBG. CSG. TRAP FLOW PERIOD OIL GAS SIZE PRESS. PRESS PRESS 1 hr. 1632 B/D 260 mcf 16/64 1560 1390 75 1/2 hr. 792 B/D 106 mcf 10/64 1680 1475 75 % TOTAL CUT % WATER % EI~JLSION % SAm & I~D CORR. GRAVI, T,,Y o.8 34.9 0.9% 0.2 0.7 35.2 co~PL~. T~:ON ~PO~? soLDOTNA CREEK UNYT Section 9, T,7 ~d~d' ~i% Co~ Page 12 July 16 Shut well in at 6:30 AM. Shut in pressures: Tbg. press. - 1790 psi, Csg. press. - 1570 psi. Produced estimated 707 bbls. formation oil. Flowed 667 bbls to tank and estimated ~O bbls to sump. Installed cosasco plug.. Rig released 7 :O0 AM, July 16, 1961 CO~L!~TION REPORT SOLDOTNA CREEK UNIT #23-9 SectiOn 9, To 7 N.~ R, 9 W., Seward B~ Standard-Oil Co, of C~i±~'~Wj0.I~ - ~erator Page 13 D~YIATION DATA 2028a 373O' 4163 ' 4553' 5454' 6054' 6377' 6714 ' 6880 ' 7095' 7270' 7520' 7708' 8071' 8267' 8487' 8702 ' 8878' 9000 ' 9170 ' 9331' 9450' 9676" 9833' 10000 ' 10182 ' 0o30, no recording 4o00, 4o45' lO00, 2 °00 ' 2 °00 ' 3o45, 3°30' 3000' 2o30, 2o30, 2o30, 2 °00 ' lO30, 4o30' 2°00, 3°00' no recording 2000' 2o08, 2 °00 ' 2 °00 ' 2 °00 ' lO30, 3000 ~ REPORT of SUB-SURFACE DIRECTIONAL SURVEY Standard Oil Company of California SCU 323-9 COMPANY Swanson River WELL NAME -- LOCATION JOB NUMBER AMO375G-06 SURVEY BY Shya'm Talwar TYPE OF SURVEY DATE, Gyroscopic · March 10, OFFICE Alaska 1975 CO..M~LETION REPORT AMO~75-G6 ........... MARCH 18~1975 ,_STANDARD OIL CO. 'OF CALIFORNIA . SWA,NSOh{- RIVER FIELD SCU 32B-9~ GYROSCOPIC SURVEY . . .............. KB_ .ELEV._._13_5_ FI' ' - TANGENTIAL ~E THOO ' '::-- · . ..................... :tCO(~u~[o_fo~. [,s ~.~:~.~;.'~-~.~S'tOC~..~'.~.'..;:F;--.t~.,--: cz~s~Y-~,'- ....... ASsoc. ... .................................. - ........ - ................ RECOR~ OF SUrVeY ..... '-. '.. -.- '..' - : - '-: . ~_ ~._ff~.[.. '/~17~.~[~':~'_~.~_ _CA'~_CUL'~:T [ ON5 -P ERF ORME~. BY_' .l .__B N E L ECTROB!_~'-:-~C'OMPg TLR . ........ , , TRUE - - ' -.: _. ..... : ............. : ......... :__: ................ DOG LEG MEAS'~' DR'[FT'"'VERTiCAL SUB DR~FT TOTAL-COORDiNATES C L 0 S U R E 5 .... SEVERITY DEPT~..:ANGLE[.::"_OEPTH 'L~.._~._.SEA'~:~'_~. DIREC ......................... - ' ~ ........ ~'[S~ANC~:~._.:'~._'[: .'ANGLE.' ...... D_EG(.1.~.OFT 0 N . DEG, - D M S . ...... 115"'0 30'--114,99 .... ~20,00 ' 5'88--W ...... 0,03 5 ....... 1,00 W 1,00 5 88 0 0 W 0,435._ .... ~5 ..... 055 .... 2~'~.98 ....... 79.98. "N 8o--w ...... o.2~-~ ...... ~.~o'w:';~_~ ...... ...................... m .... 4%5--- 0--30 ....... 414.97 .... 279.97 S 75 W' 0.28 N .......... 4.43 W 4.44 N 86_ 17 40 W 0.295 ....... ~'- o'-2o ..... ~4,~ ........ ~,~ '~'~2-w'~ .........o,~ N 4,~-w ............ ~,s~.]N..so 33.~'.z?.._A .... o,~ ........... . ..................... . ...... ..... 615 0'- 5 .... 614,97 .... 479.97 S 4 E ........... 0.63 N 4.74 W .............. 4.78_~. 82 23 6 w 0.422 .... 715 0 '30 ......... 7~4.96 579.96 ..... S ' 8'w 0.23 S ....... 4.8'6__.W ............ ........ 4,86 $ 87-17 27 w 0.412 ...... 8!5---0-'30 ....... 814.96-'---679.96 ....... ~l'6-'W ............ 1.06 s 5.10 W ' ~.21 s 78 10 18 W 0.070 ~"--1115 0 0 1114.96---- 979.96 .... S'- O'-E~ ....... 1.10 S 4,95 W 5,07 S 77 :22__17 W ~1215'-0 .... 0 ....1214'96'~-1079,9'6' --S'" O"E 1.10"S .......... 4,95 'W 5,07 .... S' 77 22 17 W --- 1315 --0 25 -'1314.96 '1179.96'- 'S-i'7- W--~' .......... 1,82 'S ........... 5.17 W --~'a15 0--0 '14!4'.'96 .... 1-279,96. s ....O-'-W ..... 1,82'--S 5,17 W 5,~8~S-'-70 32 28 w 0.430 ---!51'5-"%-20--1514'95 .... 1379.95 S 51 W 2,20-"S 5.-63-W 6;04-~-~'-6~-~39-38 W -' '1615-"0' 10 .... 1'614.95--- !479.95---S-'-'~1'-W ..... 2,42 ~S .......... 5"82 W 6,31---S-67-24~-36--w. 0,175 .... 1715 .... 0-30 .... 1714.95 .... 1579.95 "S 59_W ........ 2.87 S .... 6.57- W' ~ ......... 7.17 5._66 23 28 W 0"~42 -- i815 ....... 0-30 ..... 1814.95 ..... 1679.95'--S"'65 W 3,2~ S 7.36~'W-- 8,04 S 66'-14 .... 25'-W ...... 0,052 -"z~5 0 ~0 .... t~4,94-'~779.s~+ s 57 w 3,7~ S ........ 8'09 w s,9~ s 6~ 20 2~ w 0,070 - z2~-o 25-2~4.~ .... 20v~,~-"s 5s._-w .... -~'..~f_~ 5,20'-s~ ....... ~.~-W ....... ~.~--'s's2 ~o-~s w 0.~ . . 0,500 - 0,090 0,090 0,000 0,~30 SECZ!O TAN 0',0 3,2 3,8 3,9 3.6 3.6 3e5' .... . 3,5~ 3o2~, ' _. __ ALL_¢ALCPLATIONS_..PERFORMED_BY .... I ,.B.M ELECTRONIC_COMPUTER.. .- - .. . ...................... Yi~ gE .... .iii:J! L'-. ~;.:;~'-'_~ilm- '] ":'~L.' '.-.'.'_i. ............... ' ...... : ............. ~' .................. ~ ............... ................ ~b'~ LE ~ MEA'SFDR'I'FT VERTICAL SUB DRIFT TOTAL COORDINATES' C L 0 S U R E S SEVERITY DEP_T_H..ANGLE ..... DE.PT~ .............. SEA..... DIREC ............................................................. DISTANCE ...... ANGL E~' ~-]i'._~ DEG / 100FT ~' _ ........ ~ ..... ~ ...................................... ~E~._._ ,: ..... : .........-:__. ' ................ ':~ ..... ~ s .............. 2~5 0 ~5 ~,9~ 2279,92 S 87 W 5,06 S ~,96 W ~,99 ..... S 67 2,_~7 W ......... ................................................ ,...._ _.__25!5 __l_..ZO .... 2514,89L__Z~79,89 ..... S 83 W ............ 5,35..S ........ !4,28 W ...... 15,25. .S__ 69 "~7..41.W ........ .... 2615__ 1 _10 .... 2614,87 ..... 2'479,87. ..S'.~-7~""~ 5,9~ S 16,24 W 17,29 S 69 59 48 W 0,260 2715 1 30 27!~,84 2579,84 S 70 W - ... 2815 1 50 2814.79 2679,79 S :70 W s E c_%.~_.o_~ ...... D.I_S.T. AB _( 7 ,.1 1._0,25 6,81 S ...... 18,70 W 19,90 S 69 59 50". W ....... 0,343 ........ 11,8( 7,90 S 21,72 W 23,11 S 69 59 51 W 0,340 2915 .... '.2 30. .2914,69 2779,69 'S 80 W 8,66 S 26,02 W .......... 27,42 S 71 34 50 W 0,758 .... 3015 2 55 301~.56 .... 2879,56 S 81 W 9.46 S 31.06 W 32,47 S 73 3 23.,~ ...... 0,433 __31.15 .......2 A5 ....... 3114,a5i_.2979,~5 S 81_W .............i0,21S ...... 35,80 W 37,23 S 74 4 36 W 0,180 3215 3 25 32!4.27 3079.27 S 83 W 10,94 S 41.74 W ....... 43.15-'5' 75 18 32 W 0,688 ...................... _ ........................................ .... 3315 ........ 3_,30 _.33!4,08.,.13179,08. .... S 89 W. ........ . ....... 11,05 S . ........ 47.85 W ._,. 49.10S 76 59 41 ~ ......... 0,369 3415 4 !0 3413,82 3278,82 S 91W 10,92 S 55,12 W 56,19 S 78 47 22 W 0.683 .... ss15-'4-'soi~3~.51s.51 '-'ss78.51 ..... s92 w ........... 10.~ s ...... ~2.96 w .......... 6s.85 s~o"-zs 5,'-~ ....... o.ss9 ._ -"36!5 ..... 4 25 36!3,21 ......... 3~.78.21 ..... N--82-W ................ 9,57 S .... 70.61 w ............. 71 25--'$-'82'16'-'37"-%~- 0,472 ....... 3715 3 3~--3'713;02 .... 3578.0f N'"72-W ............... 7,68--S 76,41 .... W ........... 76,80-~ 8~"!5"'14"W ..... ~,156 ~i 38~5 3 55 3812,79 .... 3677.79 .... N'--'~2-'~ ............. 4,47 'S .......... 82,A6"~'"'-: ..... 82,58 S'-'86 53"4'~'-W-'"- 0.776 391'~ '~---'0 3~'i'2";-54--3777,5~ .... -N--64 w. --i-,~i- s ...... 88,7-3 w--88'7~'-S 89 5 14 w--0,155 40!5 4 20 4012,26 3877,26 N 65 W 1.78 N 95.59 W 95,61 N 88 55 50 W ............................ . al!5 a 10 ...... A!1!,99___,3_976.99 ..... ~ 51'-W-''¥ .............6.36 N 101,24 W 101,44 N 86 24 19 W 1,050 ....... ........ 42!'5 a 10 ~211,73 4076.73 N 53 W 10,73'N ........ 107.05-~ ...... 107,5-'9-h-"-84--i'~-22 W 0.1~5 .... .................. ~s ~ ~ .... s'-~ ~ ..... ~ ~ ~. ~ .... ~'~ ~.. ~ .... ~N--~.~""iW__-'..i~'~L'~'~; ~'-'~ .......... . ................. ~ ~ ~. ~e W ......... ~ ~ s. o'~.~"~'i~ Z~i"Z~-.~.~._..~ _. o.jg, 4415 3 30 4411,31 4276,31 N 47 W 19,66 N 116.44 W 118.09 N 80 24 59 W 0,435 4515-'-~-25 45!~s ..................................... .... 4376.1s ...... h .... ~7 w 2~.7~"-N .... lzo,e2'-'-W ............... i2~.13 N-'TS-'sz~..5~_~ii.~_ Q.bTo ---~'615 .... 3-"-5--k610,98 4~75,98 N 49 W 27,27 N 12&,89 W 127,83 N 77 40 46 W 0,~58 47!5 3 0 4710,84 ..... 4575-,84 ..... N .... 5~'-'~ ...........30.~42"N ...... 129,07''W .......... 1~2,61" ~ '~6 4~ 7-'-~_._~j._0.231 &S!5 2 ~0 a810,75 ~675,75 N 55 W '--~ .... 32,92 N 132,64 W 136,&7 N 76 3 29 W 0,509 4915 2 25 _..49!0,66 ~775,66 N 53 W 35,48 N 136,0~ W 1~0,58 N 75 22 52 W 0,111 5015 2 5 5010,59 4875,59 N 48 W 37e92 N 1~8,74 W 143.8~ N 74 - ~ ~'~ ~- ~ ..... o ..... ~ ~ ~ P. ~ ~'-~i'-3 ~. 7 ~..,. ~ ~ i. ~'~ ~"i' ~ ~..'~i '~.'-'-_'~.~ 0 ? ~ ~ ...... ~..3"f-..i..~ ~ ~. 9.~..7 w ~S ...... ~. ~ ~ .. ? ~ .... ~... 16.$~ 20,6~ __ 2~,.I.~ 28,6c, __33,72 53,4~ 59e3~ 66.1~ 73,1~ 80.5~ 87,82 95.0~ 101.82 107.., 8_4_ 1!3,75 .. · 124 · 3_2 !2~,6E 132,9] o _ 136,5~ RECORD OF SURVEY-' -A_-_L-I,~,"_-_C'-.A~'_CcJE'A-T'IoN's--PERFORMED BY I' 'B M' 'EL'ECTR'~)NI C '-coMPUTER -~EAs~"-DRIFT""VERTICA'I~- ...... SUB ......... DRIFT ................. TOTAL.'-'COORD'INATEs C L 0 S U R E S SEVERITY _s EC_'I'. I ON __..5~1'5 1--'Z~5 ....5310,42 .... 9i75,42 N 39 W 45,48 N 145,33 W 152,28 N 72 37._21_W.. ........ 0,268 ..... 5615 _1. 4~._.5610,29~. 5~T5,29.'.T..]N' .2~-W"~[__~_.~..~_'53,~3 N ......l~9,28'-'W"~Z'_].]]][" 1SS,SD N .70 ....! 8..'.'21.. ..W __.D71D __!_50 ..... 5710,2~ 5575,24 ............ N'21 W 56,~S N 150,4S W .. ..160,66 N 69 26 .16.._W ......... O,lSO ___5815 1 50 58!0,19 5675,19 N 12 W 59,57 N 151,09 W 162,41 N 68 28 59 W 0,289 ............ . ..................................... 5915 ! SO 5910,15 5775,15 N 14 W 62,11 N 151,73 W 163,95 N 67 44 18 W 0,3a5" ..... 6p15__1_.40 6010,1I _ 5875,11 ..... N_.29.._W 64,65 N 153,14 W". ......... 166,23 N 67 6 ~6 W 0,447 ............. . 6115 1 45 6110,07 5975,07 N 48 W 66,70 N 155,41 W ......... 169,i2 N 66"~6 .... 16 W 0,570 .... 6215 . ..... 1 55 .... 6210,01._6075e0i. ..... N 5~ W ..........68,7~ N ......158,10 W. ......... 172,39 N 66 .30 17...w ........ 0,241 6~15 2 10 6309,94 617z~,94 N ~7 w ?0,79 N 161,28 W 176,1B N 66 _<]61 S 55 6609,21 6474,21 N ~S W 84,92 N 176,11 W 195,51 N 64 15 22 W 1,SO1 68~D ~ !0 6808~68 667D~68 N ~1 W- '97,18 N 18D,92 W ...... 208,02 N ~2 8 5~ W 0,2!8. ---6'915 6 5 6908,42 ..... 6773,~2 .... N-"DO: W IOD,~G-'N .... 187,~8 W 2~,09 N 61 7 57 W 0,!08 ...... . --7115 2 ~0 7108,10 697~',-!0 ...... N""4~ W 111,96 N 194.40 W 224.~4 N 60 ~ ~B W !,~92 --7215 ...... 2-~'25---7208~01-7073.01 ....... N 41 ..... W ..... 115.16'N ......... 197.18'-w '~1'5 2-~25----7~07,92 -'-7172,92 ..... N'41'-W ........ 118,36- N ...... 199,96-W ....... 232,~7 N~'59 22-~5 w 0.-00-0~ - ~ ~ ~ ~ -'~ 2 0 .... ? 4 o 7. ~ 4'71 v 2 7 2. ~ 41]~"~'],],4 2 7 W"]]-.]"f -'z 2 ~. ~ O.-'N 11-] 2 o 2. ~ 9 1 _~_~.._2 8_ 146:%9_ 1_4_8, ._4 5_ !.5 ! ,3.0_ .__153,88_ 156,50._ 158,80 160,73 163,32_ 166,34 173,49 179,59 187,37 - 1.~_~ 200.39 206,96 213,35 219,63 223.87 227,96 232,05 236,00 '--7515 2 35 .... 7507,74 7372,74 N 37 W 125.01 N 205,41 W 7615__.2_.30 ..... 7607,64 7472,64 N 44 W 128,14 N 7715 2 15 7707,57 7572,57 N 45 W "130,92 N "17815ff'.1.'_30_~i17807,5S .... 7672,53 N 44'-w-' 132,80 N ___7915 .1.__45 .... 7907,~8 7772,48 N 31 W 135,42 N ..... 8015_._1__25 800?,45 ..... 7872,45 ..... N 23.__W ........ 137,72 N 208,44 W 211,22 W 213,04 W 214,61 W 215,58 W 240,46 N 58 40 33 W 0,330 244e68 N 58 25 2 W 0,323 248,50 N 58 12 26 W 0.253 251.04 N 58__3 .... 38_.W ........ 0..75_1 253,76 N..57 4.4.._49_.W ..... 0,444 255,82_N._57 25. 42 ~ ........ 0.389 240,27 · 244,53 248,38 _253,69_ 2~5.,/~L OF SU V -Y . . -. ~IE~S. DR], T VERTICALs.. SUB ......... DRZFT .......... T.QTAL._COORDINA~ES ....... :, C L 0 S U R E' S ........ SEVERITY .. DEPTH__ANGLE ...... DEPTH ...........SEA ...... D]REC ..................... DISTANCE ....... ANGLE- ..... DEG/~OOFT 8215 ~ 30 ..8207,D9 ....... 8072,39 N 22.W ....... ~fi2,~6 N. 2~7,50 W ..... 260,00...N 56 fi6 30...W ........ 0,07~ .._8315__1 20 8.307,~5 _.8~72,36 N 19.W ........ ~,67 .N .... 2~8,25 W ... 261,86 N 56 27 ~2._N. ............ 0,176 .......... $ _E. C T_ [O.N D ]: S.TANC 257_,89 8415 .... ! 30 8407,33 ._8272,33 N 38 W 85!5.~~1 25 .... 8507,29 ..... 8372,29._ N 36 W 8615 1 !0 8607,27 8472,27 N 47 W -. 8715 ..1 10_ 8707,25 8572.25 N 62 W 8815 1 !0... 8807.23 8672,23 N 56 W 152,25 N 260,00 146,73 N .... 219,87 W ......... 264,34 N_..56. 16.5p..~.~ .......... 0,495_ 148,75 N .... 221,34.W ......... 266,68 N 56 5 ~6 W ..... 0,087 265,68 150,15 N 222,83 W ...... 268,70 N 56 I 38 W ...... 0,359 268_,6~ 151,10.N ......... 224,63 W ........... 270,73 N 55 ..4.~20.W .......... 0,305 270,7~ ._ 226,33 W 272,77 N 56 4 18 W 0,122 272,_~7 ....... 8915 I_.!5._ 8907,21 8772,21 N 43 W 153,84 N ..... 9015 _.1 20 9007.18 8872,18 N 41-W ...... 155,61 N .... 9115 1 0 ..... 9107,17 8972.17 N 33 W 157,07 N 9215 1"25 9207,13 '"9072,13 N 30 W ....... 159,2~ N 9315 1 30 9307,10 9172,10 N 30 W 161,50 N 227.82 W 229,35 W 230,30 W 231,55 W 232,86 W 27~,90.N__55..58... 8._W ........ 0,285 ...... 274,_8~ 277,16 N 55_.50 38 ~ ...... 0,101 277,14 . __ 278,77 N 55 42._~17__W ....... 0,376 278,75 281,02 N 55_29 ..... 3..W .... 0,435 280,98 283,38 N 55 15 23 W ...... 0,070 283,.3.~ .... 94!5--'1"'20 .... 9407,07--9272,07 .... N-29-W' '- 163,54 N - 233,99 W ....... 285,48 N 55 2-'55 W 0,152 .._'615. _ ~0 ........ 9607.0 _.9472'04'.'-"~Ni_~611W...'--;-'._ '_~66;32_ ....... ............ 236,34 W 289.00"-N _ 9715 0 55 9707,03 9572,03 N 61 W. . 167,11 N 237,76 W 290,52 N 5~ 53 54 W 0,363 ~815 1 0 9807,0! 9672,01 N 68 W 167,76 N 239,38 W 292,32' N 54 58 ~4 W 0,137 ......... . ............... . ...... 9915 1 20 9906,98 9771,98 N 78 w 168.25 N 241,67 w 294,47 N 55 9.!4..W ..... 0,395 .......... . 10015 1 25 10006,95 9871,95 S 74-'~ ........... 167,55 N 24~,07 W 296,05.~_..5.5 .... ~.1_~...~ '_0,.576 ~ .... . .............. ~ ~ .................................. 10115 1 30 10106,92 997!,92 $ 76 W 16',93 N 246,61 W 297,79 N 55 54 BOTTOU-'fiO~E ,LO~UR£ 299;'I'5""'FE~T"AT'"N"5'6" 22 15 W 28 5,3.0 286,8.9 28 8 ~_90 2.90,52 292,23 _ _ 294__ ,__4_Q 29 6., __ 2_9 299, 15 .... MEASURED ........ VERTICAL SUB HD-TVD VERTICAL'; ..................................... DEPTH. .......... 7' 42 7342 7442 7542 7642 7742 7842 ................... 7 7943 . 7 8043 8 8143 .................. 8 8243 8 8343 8 8~43 8 8543 ............. 86/+3 8743 8843 8943 .............. 9043 91'43 --9243 934'3 8 DEP_TH__.SEA_ DIFFERENCE'.- _._CORRECTION ' TOTAL... COORDINATES . .... 235. 7100, 7 0 1 335, 7200, 7 0 1 435, 7300. 7 0 1 ._ 535, 7400, ................ 7 ......................... 0 - ' 1 635. __7500. .......... 7 .............................. 0 ........................ 1 735. ..... 7600. ............. ~ · .0 ...................... = .............. 1 835, ..7700, .............. 7 ............................. 0 ................................... 935, 7800, 8 1 l 035, .... 7900. ............ 8 .................... ..__..0 ............................... 1 135. 8000. 8 0 1 235. .... 8100. .i 8 0 ..................... : ............. 1 335, 8200, 8 0 ! 435, ..... 8300, ............. 8 ........................................ 0 I 1 535, 8400, 8 0 1 635.' 8500, 8 0 1 735, 8600, 8 O. 1 835, 8700, 8 0 1 935, 8800. 8 0 1 9443 9 9543 9535. 9643 9635. 9743 9735" 9843 9835. 9943 9935. 10043 10035. z6.6 97.93_ w .__ 19,19 N 200,70 W 22,38 N 203,43 W 25~86 N ........... 206,24..W 28,90 N 209,20 W 31.44 N 211,72 W 33,52 N 213,47 W 36,05 N 214.88 W 38.36 N 215,84 W 40,70 N ........ 216,79'."W' 43,07 N 217.71 W 45.24 N 218,71 W 47,29 N ......... 220,28 w ........ m 49,14 N 221,75 W 50,41 N 223,33 W 51,42 N 225,10 W 52e69 N 226,74 W 54,33 N ....... 228,'2~"W 035, 8900, 8 0 9'135, .... 9000'; ..........8 ............................ 0 9235. 9100.' 8 0 9335; .... 9200; ...... 8- 0 435, ...... 930'0" ....... ~ 8 ........... -- ......... ; ............ 0 ...... 1 9400, 8 : 0 1 9500, 8 0 1 9600. 8 0 1 9700, 8 0 1 9800; ............... 8 0 1 9900, 8 0 I 156,01 N 229.61 W '1'57,67 N 230,65 W 159,86 N 231.91 W 62,07 N 233,17 W 63,92 N 234,24 W 65.30 N 235,28 W 66,54.._~_.. ...... 236,74. W 67,29 N 238,22 W 67,90"N ........ 240,02-'W .... 68.06 N 242,34 W 67,38 N 244.78 W ]_~'~EA_Su~ED_-~DEP..T_H_-AND~.OTiLIER DA_TA_.FO_R.].EVERY-.EVEN IO0..F.EET OF SUB 5EA..DEP"~H";' ......... - - 'T R-O E ~EASURED ........ VERTICAL ,SUB - ' M,D-TVD ........ VERTICAl- DEPTH .......... DEPTH '-SEA DIFFERENCE ....... CORRECTION ..... ; .... TOTAL -COORDINATES ... ~837 3835, 3700, 2 0 :3,79 S 83,86 W 3938 ............ 3935, 3800, 3 1 0,69 S 90,28 W . ........... ..... .:":"'o . . .. N ..... w ............. 4138 .............. 4!35, 4000, 3 0 - 7,36 N 102,58 W 4238 ................ 4235, 4100, . _ 3 ......... 0 - 1!,84 N ._. 108,20..W ................ 4339 4335, 4200, ' 4 1 16,47 N 113,03 W ~z+39.- 4~+35. ~300, 4 0 20,62 N 117,48 W 4&39 4635, ..... 4500,._. ..... ~. ....................... 0 ......... 28,03 N 125,89:'~~ · ~600 4 0 , 4700 4 0 4.739 4735 4-839 ............... 4.835 ..... : ...... 4939.. ............. -4935 5039 5035 5!39 5135 ......................... 52.40 5235 5340 5335 5~40 5435 5540 5535 5640 5635 5_7.40 5735 5840 5835 5940 5935 6040 6035 6!40 6135 6240 6235 6340 6335 6~a~ 6~35 · aSO0 · 4900 · 5000 . .- , 5100 · 5200 6541 ' 6535 664! 6635 , , ......... _.4 ........................... 0 ............. , ........... · 4 0 , 4 0 , 5 , ~ 0 5300, 5 0 5400' ........... 5 ................................ 0 ....................... 5500· 5 0 5600, 5 0 5700· 5 0 59oo, .......... 5 ...... : ...................... 0 ................................ 6000, 5 ' 0 .... 6100, 5 0 , 6200 .... · 6300 · 6400 · 6500 6741 6735. 6600 6841 6835, 6700 5942 '6935e 6800 7042 .. 7035, 6900 ...... 7142 ........ . 7135, 7000 31,03 N . 33,54 N 36,07 N 38.55 N 41,14 N 43,69 N ......... 46,06 N 48,52 N 51,33 N 54.17 N 57,20- N 60,20 N . . 62.74 65.16 67,20 69,24 71,60 75.33 129,93 W 133,46 W .... !36,69 W- 139,31 W 141,64 W 143,88 W 145.61W 146,86 W ..................... 148,34 W 149,56 W 150,59 W ... 151,25 W N !52,08 W N 153,71 W N 156,08 W N 158,89 W N 162,58 W N !67,95-'w · 7 1 80,64 N 173·33 W 86,48 N 177,16 W 92,57 N 181,15 W 98,81N 18a,86 W 104,80 N 188,53 W . 7 0 · 7 0 109.63 N 192,22 W 112.83 N 195,14. W MEA.$URE_D_DEP_TH_~AND_O_THER .... DATA_,FOR.. EVERY_ EV. EN ~100 FEET_ OF. 5uB"'$~'~'-DEPT'H';'- _ ........... - · ..... TRUE ............. ...... DERTH DEPTH. SEA DIFFERENCE'".;...;;'.. CORI~ECTION ......... TOTAL ..... COORDINATES · .. · 335 .... 335, 200, · 0 ": ...................... 0 .................................... 0,46 N 3,76 W . . /*35 435, 300, 0 ~3~ ~35, 400, 0 635 635, 500. O 735 735. 600.' 0 835 835, 700. 0 93_.5; .............935, ..... 800. .......... 0 ........................ 0 1035 '1035, 900. ...........0 ............. . ..- 0 1135 ...............1135, .... 1"0 O0 · 0 0 1235 1235,_ 1100,.. .. _0 ................................ 0 1335 1335, 1200, 0 0 !435 1~. 35,. _ 1300. 0 . 0 1535 1535, 1400, 0 0 1635 1735 1835 1935 2035 2135 ............................. 1,07 1,10 ._ 1,10 1,25 . . . 1,82 1.90 2,24 0 .............................. 0,38 N ........ 4,50 W 0.. .................. 0,75 N ...... 0 0,46 N 4,76 W 0 .... 0,39 .$ .... . ......... 4,91 W 0 1,06 S 5.1ow 1635. 1500, 0 0 2,51 1735, 1600, 0 0 2,94 .. 1835, .... 1700, ............ 0 .................................. 0 . . ............. 3,33 1935, 1800. 0 0 3,81 2035. ..... 1900', ............. 0 ........................... · ......... 0 ............................ 2135, 2000. 0 0 4,88 5,07 W 4,95 W .--4.95'-~W' -- 4,99 W 5.17 W 5,26 W 5,67 W 5,97 W ......... 6,73'" W 7,51 W 8,80 W 9,42 W 10,08 W lO;92 w 12,43 W 14,67--W 16,74 W S 19,31 W 2235 2235. 2100. 0 0 5.16 2335 2335. 2200, 0 0 5,01 2435 2~35;-' 230b~ .......~-'0 ....... 0 5,12 2535 2535, 2400, O : ............. = ........... 0 5,46 2635 2635, .... 2 5 0 0 ; ........ 0 ................................ 0 ................ 6.09 2735 2735. 2600, 0 0 7,03 2835 2835. .... 2700. ........... 0 ........................... 0'-'-= ..... : ....................... 8.06'S ........ 22,59 W 293-5 2935' ......2800, 0 O- 8,82 S 27,0~--W 3035 ' 3035. 2900e 0 0 9,61 S 32.03 W 3136 "3!35;- 3000. ........ 1 ........................... 1 ................................ 10.35-5 ........... 37.03-W 3236 .................. 3235, -3100' ............ 1 .......... ~ .............. 0 ........................... 10.96 S ...... 43,01 W. 3336 3335; 3200, .......... 1 ............................ ' ..... 0 ............ 11,02'"$ 49.37'W 3z, 36 3537 3637 3~35, 3300; ......... 1 .......... --T-. ................ 0 ............................ 10',86--5 ........ 56:78 W 3535. .... 3400, .......... 2 1 ............................ 10.41-'$ .......... 64,'6~- W 3635' ..... 3500' ....... 2 ......... ~ ................0 ............................... 9,15 S ........ 71.87 W INTERPOEATED-9'ALUE$' FOR EVEN ].000 FEET Of MEASURED---DEPTH'; TRUE ...... ' ME-ASORED ........ VEqTICAL ....... SUB DEPTH DEPTH .............. ,SEA ............ TOTAL" COOR D-INA'TE$ .-- 2000 1999-'-- '186~+, . a,ll ,S 8,59 W ' -' 3000 ...............2999, ' 2862+, 4000 .............. 3997, 3862.. 1. 5000 ~995, 4860, 37. .......... 6000 5995, 5860, ............ 64, 7000 6993, 6858, 107. 8000 7992, 7857, 137, 9000 8992, 8857, 155, 10000 9991, .......9855-, -167, 55 N 27 N-. 95 N . _. 37 N 66 N 138,33 W 152,93 -W 190.83 W 215o44-'W 229,12 -W 243t71 .~_ .............................. ..._ ~ . ! " t': ...... ~ ' ' ' . ' , "' . ..... I .... ' ~ :' ' ;" ' ! . ' ] ~, " ~. ' ~ I : I I , ........ J' ............ ] ............. ] ........... [' [' [ I ~ I ' [ : ..... L~..... L ..... HORIZONTAL VIEW . .... : :~ -:l ~ - 1-, ._ :'. ._,~ : ..... ;: ' "~ :" " 0 ' .......... ] ............................................... ; . ;. ,_ ~ , .. ~ ......... :., , ' : STANDARD OIL COMPANY OF CALIFORNIA ' { , i , ~ ......... ; -. ~ SCU. 523-9 ~ - . ~., .... . ,-. , ,¢~. : ; -, .-~ ...... ..[ .;' ~; . ~ . , , ............. ....... ~ ..... ~ ..... '.~ "";". ! ~''.": : ,' * ' ~ ' ~ , ' ~ ; · : ~ " ;' '. ' . i ' ',' ' · '- ~ ~';-~ , ~ ~,~, , , ' I~ ~ , ...... · ) ~ ~ ' ' ' : ' ~ : : ~ ~o .; ' ' : ' . ' · .............. /.:- ..... .~ .''-, ~ '; :'. it t; . ~-~':-~I '-:': ~' , ..... ,';[ , : ' ;. · ' '~ ~ : ....... { ...... , " , -: ; · 6~ ~ .1 ......... . ~ .... . . . f . : ~. - .. . . , . . - ~ ~ . ; - i · . ; -. ; ~-- ~ : -.,; -.-~ ....... " ..... ' 4400 ...... .~ ~ .... '~.:.... ~'.' ~': ..:':.':'! '-:i : j. ~, '' ;': -'~ ";':' ' '.' '~ · ,., . - .,.~ ~'. ;' .~/. "-r'~, : ..... ' :'-.,- .""~: .... ~l, :.:' ~''~''~: ..... ~"[, ....... - -' :"J< ....... '-;':-':"i,-'~;-. ...... :-. ~-:,'.' .......... .... :" "" ............. ...... ,.._, ...... , .... , ...... ................. I .... { .' ' ' ' ...... ' ~' ~ '' ' , ' t 1 [ · .. ~ i ~ - . , I i ......................... ~ ~. ;, ,~ , . , : .... t .... .. ] :.: j .:. .................... . .- ~[ ...... .... m-:._ :'~-"":' ..... .... :- ...... ~"~,: ........................................ ] ..... ' - , ........ " '::";"'::"i -'~ :' : - [-.. :, ......... , - ' . . ...... ........... . ......... '..: ...... ~.: ...... - ............. ~ ..................... ALL DEPTH8 SHOWN ...................... ~ ......... ._.. " ; .... l' ~ ;. ' [ - - . · ---'- ARE TVD ' : , ........... . :;'i :;T.-;:' ' ~ . :..'~ .i.-'~-:'. ~ -~ ", : . '; ' ',," ,' - ', ~:~ ':: "' ~ · ~. · ~ .I ' ;.:: . .'i ~-:-2''~' ' '! ~.' .'. ~.:' : ......... .t':'." ..... ~1 . '~, ' '' ' ' ~ ..... ;' ~, .... : ' ' ~ ~ ....... ~ , .... t" · ;' ; '": "i ' ~ ........ . I ' ' , ' ....... t ' : ' : , ~.'. ::i ..... ~ : : ......~.. :.' ' - .... :'.. ' - -! ' ' - ....... I ! ~ ~ '" 1 ' :'-~ '".' ~.~,~i"~'~ ~'.;'"~'~ '"-,1"; .....!~-~'-. ,i": '.~:., ':.~.'i''':'~ ''~:."f.,: -';,': '-;-. " : - ' ' i ' ~ ":' [ : J' I J "~ ............ : · ' I . } · SCALE I"=i000' I : - i ' STANDARD OIL COMPANY OF CALIFORNIA , t , i ' SCU 525-9 , 24~ ' : I :TANGENTIAL' METHOD ~ ........ ."; .............: ...... , : u. . . _ . , . . -~. .,~ , ~ , ~ ! -- . t . ~ j I [ "; ! · 2800- ' ~ ; .... i ' '' ~"'; ' ' ' , . J . ~ : ! ; ~ ........... , .................. ~. ~ ............................. . .......................... ., .t , , . ; , . . .. .; , ~ , , .... !. ~ "i : - ~ '; : L -. ..:. ..... j . ! !. ' : .. .~ . . . i! i i " '" '""' ' '-" :" ";' --. ................ ,": .... { ................ I ............ i .................................... ~, .... ' ........ . ...... : .... i ..... ; .... ' ' i ' I .... ; ' "· . --~ ...... ~- - -' - 3600 ..... ...... : .-; .- ~ ' ;- -: ' - -- i - ' L ! .......................... ! ........., ..... ;~..._'_' ....... :... ....... i . . . !. ., ~ .... - ................. ', : -.. ........ ~., ........................ 4000 ......................... ,' ............................................. ~ i ' ....... ~ ] ~ ..... ' !' ._ ; .. - .. ; ' i : "' .:,-- i~',' i, ! .... ,, , ,' ! : .; ; - ..: :. _ . . [ . - ~. ! · . ..... ! - . . . -_ . , ; . .... ? -- -... ~ ..... ! .~ ..... ............................ ; .................................... !-'?T'~ ............ ~ ...... ~'~"~"": ...... : ....................... '""~ .............. ~ ............. " ................................... · : . - ' : i · ::' : ' 5~oo. ' ' , · · . . i . i -- ; ,.. ~ ,- : ~- I~ .-. --~- -~ . ..................... ~ ............. ....... ~ ........... ! -- ~ ..... ' ..... , ...... ' ....... '- · ' ' i - ' - _.. ": ' ALL DEPTHS SHOWN ! ' ! ' ' { "' '!" ' ' ,' .............. i ........... ! r~x)o ................ , ..................................... --- j ARE TVD : i . i - " 'i : i ' - , ............ ,'' , ' i. ; --- ~ ..-, ... : ..... ~ 6400 ..... · - .............................. i- ': ' .... "- .................. , ............... ' ..... ' ; .... ' Iii'' :' '=~ ............ i .... - .... ~ ..... " "' ' : ~ . .~:. : ............. ;. ...... ~ ......... . .. , i ~ '~' ~ I ..... i 6800, : , .' :, .i~"i :,!~ -i, ......... , ' .... ' - " ,, ' ~"-' ', ' ~ " ~': "i'"'"'- i' .... .. 7eoo ·. . t. , ~. ; -. ; _ ; ! . . : . . . · I ' i - ~ : {. .... ': :. i- - ~'- . .... ~ ' ; · ... · -' ! ' i ........ ; ................... ' ............ i .............................. , ~ ' "I' ~. 'i,.- : .' ....... ~ ...... ?~oo. ' t' ....... : .......... 6000 ........................... ! ................ ' - { '. ....... : ..... ? ............. ........ , ..... , ............... ""'~ ~ ~"~" ..... ' " ' ~ i ....N, ',', : " 'il . ~ ' ' ' ; .-.,, I .... -' ... [ ........ , .. t ;' ~'" '] .... i-+' , " ~' ....l : "~'' t" '- .......! · · ! ~eO0 ..... ~ ' ' ' "'~ ' I . i ' t , ; '! ' ' ~ ' ' ..... , ..... = ..... L.:--& ..... ~ .................... ' ' ' I ................... ,, ..................... ............. ~ ....... '-': ........................: ~ ..... , !.i ..... I ...... eeoo ...... ..l : '" i ' ' : ' ~ [ · ' i~; ~ ;-f~ ' ~.i'i ..... ~'~'~ i .~ - , · : ' ~ · t · ' TVD = 10,205, .... i : · , ~ TMD=IO.21 REV. 9-30-67 & ".~l~eqt~t Reports" in Duplicate ' --- STATE OF ALASKA` ' IIc.'m OIL AND'GAS' CON~,~VATION ,COMA'tJTTEE ' SUN:DRY NOTICES AND REPORTS ON WELLS 1-'4 ~.,:~ (Do not use this form for proposals ~o drill .or. to 'deepen or. plug back t~ a diffierent reservoir. , ,. · ,,,, ...... ! 1. ' 7. IF INDIAN, ALLOTteE OR TRIBE N~ M.E 1 OIL ~'~ OAS j - -- .-, WELL' ~--~ OTHER GaS, Tn ection Well ' i : WELL ,, ..... ~ . _ 2. HANIE OF OPEt~ATOR 8. UNIT, FAitH OR LE~SE HAME I 3 GEOL Standard. 0il Company ,..°~ California,. . , WOI .. , Sold~tna Creek ...'1 .... REV P.O. Box 7-839 Anchorage, Alaska 99510 SCU 323-9 - J ~['~' j 4. LOCATI'ON O'F WELL 10. FIELD ~ POOL, OR WILDCAT At surface ~anson Riyal7 FII.F. 2520~ North and 1970~ East o~ SW corner II. SEC.,T.,R.,M.,(BOTTOMHOLE · OBJECTIVE) of Section 9, T-7N, R-DW~ S B & Mo Section 9: T-7N, R-DWi" , SB & M 1:{ I~.T.F. VATTC)N.~ (Show whet. h~r DF. RT. GR. etc. 12. PER1VIIT NO. 135' K B Check App~priate ~ox To Itndicate N~ture of N~fice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ] [ PULL OS ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE -- ABANDONs REPAIR WELL CHANGE PLAlVS 21 -61 ~, or Other 'Data EUB~EQUENT REPORT OF: FRACTURE TREATMENT ALTERINO CASING SHOOTING OR ACIDIZINO ABANDONMENTs (Other) Initiate gas injection (NOTE: Report results of multiple completion on Well (Other) Completion or Recompletion Report and Log form.) 1'5. DESCRIBE PROPOSED OR CO~tPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an}' proposed work. Gas injection was initiated in SCV 323-9 on December 20, 1973 at a rate of 35,000 MCF/~ ~t 4900 PSIG. certify, a' he f o: true and correct ' - J.W. ' W~£K~r (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF AN~: TITLE Area Supervisor DATE 12-21-73 DATE See Instructions On Reverse Side Form No. 1:'--4 STATE OF ALASKA SUBM~ IN DtmLICA~'~- OIL AND GAS CONSERVATION COMMII-[EE MONTHLY REPORT O:F :DRILLING AND WORKOVER OPE:RATIONS 5. APl NUMERICAL CODE 3. ADDaESS OF OPERATOR P. O. BOX 7-839 Anchorage, Alaska 99510 LEASE DESIGNATION AND SERIAL NO. A-028997 7. IF INDIA]~, AI_,OTIEE OR TRIBE NAME 1. 0IL [] ~,s [--~ oTaz~ Gas Injection Well ........ Wr. LL WELL 2.NAME OF OPERATOR 8.UNIT,FA/~I OR LEASE NAME Standard Oil Company of California, WOI Soldotna Creek 9. W~..I,L NO. SCU 323-9 4. ~CA~ON OF WELL 2520' North and 1970' Section 9, T-7N, R-9W, East of SW corner of SB&M. 10. FI~,T .r~ AND POOL. OR WILDCAT swanson River 11. SEC., T., R., M.. ~O~OM HO~ o~ Section 9 T-7N, R-9W,SB&M 12. PERNIIT NO. 21-61 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA_NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLU'NiES USED, PEP~OB. ATIONS, TESTS AND R~ESULTS, FISHING JOB,S, JUNK IN HOLE AND SIDE-TIkACI{ED HOLE ANT) A_NY OTI~ER SIGNIFICANT CI{A/~GES IN HOL~ CONDITIONS. October, 1973 Commenced operation at 6:00 p.m., October 11, 1973. Killed well with 77 pef mud. Removed xmas tree and installed 5000 psi Class 111 BOPE. Pulled and recovered 2 7/8" tubing and jewelry leaving bottom packer and tubing tail in the hole. Recovered packer with packer retrieving tool. Ran overshot and recovered all tubing below packer. Cleaned out to 10,654' with 6" bit. Landed 2 7/8" x 3 1/2" tubing string at 10,624' with packers at 10,583'; 10,441'; 10,372' and 10,256'. Removed Class 111 BOPE and installed 10,000 psi injection tree. Tested tree to 6500 psi. Displaced drilling fluid with lease crude oil and set packers. Released rig at 1:00 a.m., October 24, 1973. N O'J '5 1973 Note: Original well designation was SCU 23-9 14. I hereby ce fy ~ h ~ rego is ~ and correc~ SmNEO T~TLE Area Supervisor N0~--~eport on this form J~ refl~Jred for each calendar month, regardless of the stat~s of operations, a,~ m~st ~ filed in duplicate with the Division of Mines A Minerals by the 15th of the succeeding month, unless othe~ise directed. · ' Form i~--3 ~. 9-~.- STATE ' ' 5. AP1 N~C~ CODE OIL AND ~S CON~VATIO~ SUNDRY NOTI~S AND R~oRTs ON WEL~ (DO not use this ~o~ ~o~ p~o~l~ 1. ' .... "" o~ ~ ~ ~ ot.~' Gas WELL WELL Standard 0il Company ' 3. ADD.SS OF OP~TOR 9. ~L NO. P. O. Box 7-839 Anchorage~ Alaska 99510 SCU 323-9 Ats~face 2520' North-and 1970' East of SW corner ,~ of Section 9, T-7N, R-9W, SB&M U. SmC.,T..a..m..(S~MKO~_~ ~ O~E~IVE) Section 9 T-7N, R-9W, SB&M 1R RI.EVATIONR (Rhnw whpt. h~ DF_ HT_ OH. etc. ~ 12. P~T NO. 135 ' KB 21-61 Check Appropriate Box To Imiic~te Nmt'ure o~ I~otice, Re ~or~, or Other 'Data NOTICE OF INTENTION TO; TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASINO MULTIPLE COMPLETE ABANDONs CHANO~ PLANS (Other) e~OOTtNO OR ACIDIZINO J _ J ABANDONM~T* Gas Inaction Conver- NOTJ: Report results of multiple completion on Well ompletlon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR CO.MPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an}' proposed work. Commenced operation at 6:00 p.m., October 11, 1973. Killed well with 77 pef mud. Removed xmas tree and installed 5000 psi Class 111' BOPE. Pulled and recovered 2 7/8" tubing and jewelry leaving bottom packer and tubing tail in the hole. Recovered packer with packer retrieving tool. Ran overshot and recovered all tubing below packer. Cleaned out to 10,654' with 6" bit. Ran and landed 2 7/8" x 3 1/2" tubing string at 10,69-4' with packers at 10,583', 10,441', 10,372' and .t0,256'. Removed Class 111 BOPE ~ installed 10,000 psi in~ection tree. Tested tree to 6500 psi. Displaced drilling f~uid with lease crude oil and set packer. Released rig at 1:00 a.m., October 24, 1973. NOV "5 1973 Note: ;O~iginal well desisnation was SCU 23-9. ~0. I he~e~y ~e~"} mat ~th~ torrens is true ~ cor,eet SIGNED TITLE Area Supervisor DATE 11//$ /73 (This spaCe/~or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY; TITLE DATE See ~nstrucfions On Reverse Side Form REV. 9-30-6 9 ' ' ~ '~ Smbmit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE O'F ALASKA OIL AND GAS CONSERVATIO'N COMMIYI'EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION 'FOR ~'EY~V~r['-L~' 'for such'p~o~osal~') · O,L ~ OAS [~ OT.ER Gas In~ection WELL WELL 2. NAME OF OPERATOR Standard Oil Company of California, WOI 3. ADDRESS OF OPERATOR P. 0. Box 7-839, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 2520' N~ amd ~970' E. from SW Corner, Section 9, T. 7 N., R. 9 W., SB&M 13. ELEVATIONS (Show whether DF, RT, GR, etc. 135 ' lib '~. AP1 N~CAL CODE 6. I.I~.A~E DESIGNATION A.ND SERIAL NO, A-028997 7. IF INDIA.N, ,AT.I'.O'i"r,i~E OR TRIBE NA/VLE -- 8. UNIT, FAB.M OR T.F.~kSE NAME Soldotna Creek Unit 9. WELL NO. SCU 23-9 10. FI~.r.r) A2qD POOL, OR WILDCAT Swanson River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 9, T. 7 N., R. 9 W., SB&M 12. PERMIT NO. 21-61 Check Appropriate Box To I,ndicate Nature of NOtice, Re~ort, or G~her D~ta NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASINO FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANGE PLAN~ ~Other) Convert to Gas Injection SUBSEQUENT REPOBT OF: SHOOTING OR ACIDIZINO ABANDONMENTS (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting an)' proposed work. Commence operations 6:00 PM, October 11, 1973. Redesignate as SCU 323-9. 100T '! 8 ig?3 DIV!SION OF OIL AND GAS A, ,CHOR.AGE I I I ' 3 GEOL ~ -- '~NFER, - 16. I hereby certify~~7~y~the fo, re oing ue and SIGNED // Wf (This epace for }~'ate office use) correct TITLE Area Supervisor APPROVED BY CONDITION~ OF APPROVAL, IF ANY: TITLE See Instructions On Reverse Side DATE · .~l:~roved. ~ppy ~,eturned Form P--3 R~EV. 9-30-69 S~bn%tt "Intentions" in Trtplioate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATIO.N CO,MMrrrEE SUNDRY NOTICES AND REPORTS ON WELLS (DO not use this forlTl for proposals to drill or to deepen Use "APPLICATION'FoR ~'Et%~ViiT~J' 'for such 'p~o~iosal~) WELL WELL OTHER 2. NAi~,fE OF OPERATOR Standard Oil Company of California~ WOI 3.ADDRESS OF OPERATOR P. O. Box 7-839 Anchoraget Alaska 99510 4. LOCATION OF WELL At surface 2520' North and 1970' East Corner Section 9, T7N,R9W, from Southwest SB&M. 13. ELEVATIONS (Show whether DF, RT, GR, etc. 135' K.~B. Check Appropriate Box To [nd~icate Nmt'ure ,of NOtice, Re 5. APl N~CA3~ CODE 6. LEASE DE&IGNATION A.ND SERIAL NO. A-028997 7. IF INDIAN. ALLO'I-r~ OR TRIBE NA1VIE 8. UNIT~ FARA'f OR LEASE NAME SoI~otna Creek 9. W~L NO. SCU 23-9 10. FIELD A2qD POOL, OR WILDCAT Swanson River 11. SEC., T., R., M., (BOTTOM HOLE OB~.CTIVE) S e c'. 9 T-7-N, R-9-W SB&M 12. PERMIT NO. 21-61 ~ort, or Other NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON' REPAIR WELL CHANGE PLAN~ ,Other) Convert to gas in~~ ~-, EUBSEQUENT REPORT OF: WATER SHUT-OFF -- REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING J, j ABANDONMEIqT' (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) t5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (~qe~ll'ly state all pertinent details, and give pertinent dates, including estimated date of starting proposed work. We propose to convert SCU 23-9 to gas injection per the ---~:'~..~-~¥--~ 'L attached program. Well will be redesignated SCU 323-9 :---J-- ~ "i~ N~'-~ I gIVi,51Ot4 Or': OIL AND GA.5 ANcHORAG5 5ENG 2 GEOL 3 GEOL I I t ._.sEc I_C_C~FER' · J FILE: . ..i ...... .... SIGNED CONDITION! 0F AP~B0VAL~ A~: TITLE Area Supervisor DaTE 8/~z/73 · See Instructions On Reverse Side Approved Copy ..:.. -. .' . ...: .' :: · ... .- .- _.... .... ?.!:. .- '-' - .... :: ".' ':" ' i'"-'-: '- :. ': .... i :-PROPOSED CONVERSION OF SCU 23-9 ........ ' ~ ' ::"-':'."-i'-' ' :.'" i ::: ' ..' ' . . p_roposal. ' ~ : ......-:.':"'.'' '"'!.':". :;~/"':'-).':?!::-i.': '.:/':?i:i'I'' :' :'::': "'"" '. ''''''? ":' '""' . - Convert an idle high GOR producer, to gas injection. Install 3 1/2" tubing ~ and use packers to segregate the Hemlock zone into three intervals, H 1-5 - sands, H 8-9 sands and H 10 sand. ~. ' .- _ ..... . DiscusSion ':'.::...:.:~ .... :: ..::~ .:....::. .. . .:. , _.- :.'. :.~ . -,:.- .-..- .-. ,_-;.'~. ;... : A field-wide reservoir pressure Survey'was run in May 1973. Reservoir pressure in the southern portion of the SCU Fault Block was 400-500 psi less ,'.than desired. Average pressure at the most northerly injector SCU 341-4 was ~-6ut. 5400 psi and was about 4900 psi at the southerly injector SCU 312-9. Average pressure -in the peripheral producing wells ranged from 4300 psi to " "''--.-~.. 4500 psi except in .the producers on the southe:.:n plunge of the structure. - .-:-: The pressure at SCU 21-16 .was about.. 3800 psi. ' Displacement pressure in the high.: pressure gas injection project must be - . . ..: maintained above 4200 psi in the peripheral wells or oil recovery will be -reduced. The conversion of SCU 23-9 is required so that a greater volume .. . . of gas can be injected into the underpressured southern portion of the . .. 'SCU Fault Block. In' this way, displacement pressure to the peripheral wells can be increased to and maintained above 4200 psi. The conversion ii' : will have the additional benefit of reducing plant output pressure which increases overall injection rate-and will provide additional flexibility . "'' in the gas injection system so that .compressors will not have to be shut down in the event an injector is shut in. . ·.. sCu 23-9 has been produced only' periodically for several years becauSe of ' ' .., ..its very high GOR, It has little current value in the gas injection project. .- · -...: The well is structurally high and is located relatively far from the producing - · wells to the south so resultant areal sweep will be good. Other wells in the · '_. southern portion of the field are not suitable for injection because of their -. proximity to good producers or because they are good producers themselves. · '" - "'i .....:: ': - :' "' ':'~: ': ::'"-:" ' :' :':: '~': -'-'- -' ' "' . ..,... -. . . ..... . ........ ..~.,.... ~:. · ........ ~.t:~,~..'~,-.©l.:..©lC .. · :-. .. ./. ~--.: - :, .- - '_:..". :-..::._: - :,' * '' - - . :: .... : "':-i','~- :-' ' '-"'- PROPOSAL FOR WELL OPERATIONS - PRO 316-1 CONVERSION PROGRAM .. Field: Swanson River 'P~ro~erty 9nd Well No.: SCU 23-9 surface Location: 2520' North and 1970' East from SW corner of Section 9, T7N, R9W, SB&M. Elevation: 120' ground level - original K.B. was 15' above ground level. All measurements based on original K.B. PRESENT CONDITIONS': Total Depth: 10,750 ' Effective Depth: 10,652' Plugs: 10,652' - 10,748' Casing: 20" conductor pipe set at 32' 11-3/4" 47#/ft. casing cemented at 2009' 7" casing detail as follows (from tallY): Bottom 759' (10,749'-9,990') 29# P-110 L8R Next 14' (9,990'-9,976') 29# P-110 L8R Market Jt. Next 1600' (9,976'-8,376') 29# P-110 L8R Next 7" (8,376,-8,369') 29# P-110 BT x-over Next 1564' ( 8,369'-6,805') 29# N-80 BT .Next 15' (6,805'-6,.790') DV collar and x-overs Next 247' (6,790!-6,543') 2'9# N-80 BT ~Next 1828' (6,543'-4,715') 26# N-80 BT Next 3667' (4,715'-1,048') 23# N-80 BT Next 760' ( 1,048'- 288') 26# N-80 BT Top 288' ( 288'- Surf.) 29# N-80 BT Total 10749' - Ail K.B. Depths Perforations :. 'Four 1/2" jet holes per foot as follows: ....... ,,-.,;4 0;.: O!L A!qD GAS ANCHORA~..-,5 10,620'-10,592'', 10,580'-10,554'; 10,545'-10,455'; 10,434'-10,388'; 10,364'-10,351';410,343'-10,317'; -10,300'-10,280'. WSO's thru five 1/2" holes at 10,625' and 10,276' · , All perforation depths are IES. Tub.lng Detail: Per attached detail dated 6-12-68. Datum:- Take all measurements-'from a point 15' above the ground level. _. Proposal for Well OperatiOns - PRO 316-1 Conversion Program -2- 7" Casing Collar Location - IES Depth 9897'; 9931'; 9971'-9985' marker joint; 10,026%'; 10,069'; 10,108'; 10.,148'; 10,193'; 10,228'; 10,272'; 10,310'; 10,354'; 10,398'; 10,441'- 10,'483'- 10 527'; 10,569' , · , · · BloWout Prevention Considerations-: 1. Potential Problems a. Gas Gas may be encountered after packers are released and while clean- ing.out 7" casing. Gas entries into the mud column can cause serious p~oblems. Care must be exercised at all times to avoid swabbing the well during trips Or when pulling production equipment. b. Precautions Any kicks should be handled by our normal procedures. Drilling crews should be made aware of these methods and care should be exercised at all times by every member of the crew. The hole must be kept full at all times. 2. Maximum Anticipated Formation Pressure: 4700 psi 3. Maximum Possible SurfacePressure: 3200 psi 4. Blowout Prevention.E~ui~ment: - a. As per "Operating Instructions D-17." b. Class III, 10"-5000 psi for all work. AUG D"'~c~'~'~' ~ AND .., ,.:,,...,-, Ok O~L GAS ANCHORAGE PROGRAM 1. -Prior to rig move in, pull CEV. from' mandrel at 10,159'. Install Cosasco plug. 2. Move in contract rig. Remove Cosasco plug and kill well with 72-74 pcf clay base mud (73 pcf mud will provide a 500 psi overbalance at 10,280', top of the perforations). 3. Install Cosas¢o plug and remove xmas tree. Install and test to 5000~psi a Class III BOPE. Test blow and kill line manifolds to 5000 psi. Remove Cosasco plug. 4. Pull and lay down tubing and packers. Have a "CC" Retrieving tool on hand in case the "CC" safety joints at 10,342' and 10,412' release. Proposal for Well Operations - PRO 316-1 Conversion'Program -3- 5. Mill over and recover Baker Model "D" packer at 10,585'. Clean out 7" casing to 10,652'. Drill out cement Plug to 10,670'. Circulate hole clean. · Scrape perforations using tandem7" casing scrapers. Circulate hole clean (attempt to find a positive displacement scraper). Set Baker Model "F" packer on wire line at 10,585'. Measure from reference collars. 8. Run 2 7/8" x 3 1/2" tubing and jewelry. Tubing detail to follow. Hydrotest tubing to 6500 psi. 9. Stab through Baker Model "F" packer and land tubing. Install Cosasco plug. Remove ~OPE and install 10,000 psi injection'tree. Test tree to 6500 psi with clean water. I0. Remove Cosasco plug and displace drilling fluid with crude oil. 11. Set Packers and release rig. 12. Well clean up and injection program to be-provided. B. Berget // .~ubnatt "lntenttor,~" tn 'i'ripltcata STATE O:F ALASKA AND GAS CONS:ERVAT'r'~,,~,,-¢ COMMIT-lEE U~e "AI?i-'LICA'FION FOR P~i{Mi'F-.-" for ~uch proposaI~.) W~LL _~ ~ELL ~ OT~ER 2, ~AYdIS OF OP~.V:ATOI~ 8, UNI~ FAI~,I O~ I,~A~ NA.MrJ Standazd Oil ~.~ompany of Ca~ifornia,~ W.O.I. Soldotna Cree~ P. O. ~ox 7-839, Anchorage, Alaska 99510 SCU 23-9 4. LC'CATfOZq C,F WELL 2520' North and 1970' East from of Section 9.~ T7N~ Rgw, SB&M SW corner 10. ]FLkZLD AJqD POOl,, 011 'V/I!~CA]' Swanson Rive~ I1. SEC., T., R., ]%I., (P, OTTO~[ }tOI~q I DRAFT J CONFER: FILE: OBJECTIVE) ~ _ Section 9 T7N, R9W, SB&M (Show whether DF, ~T, GI:I, e%c. 12. PER?,!IT NO. 135' KB 21-61 Check Appropriate .Box To [nc[ic~?e Nature of Notice, P.e :orf, or Other Data NOTIC~ OF INT~NTION TO: i 'VT ,% T 'D, ~. [~,HUT-OFF PL'LL OR ALTEB CASINO GR ACIDIZ~ L -J ABANDON* WELL .__ C14 AX(; E PLANB tO~he~ Convert to Gas Injection (NOTS: Report results of multiple compl,-tlo'n on Well Completion or Rccompletion Report ~prl Log for:n,) i'RO. POSED OR COMPLgT~D GFI~RATION8 (Cle&rly state all pertinent details, and g!ve pertinent dates, including estimated dat~ of etartlng any work. We propose to convert SCU 23-9 as per attached program. to a gas injectoz RECEIVED JUL 2'6 I'971 DIVI~iON OF OIL AND OAS ANC~O~A~I lO. t hereby certify O~at the foregoing~L~ true ., , /" ,/L'~.,,:A,.;,,f:, ~ / g, O' ; TITL~ Dist. Superintendent DATE 7-2.~- 7 1 TITL~ /J~ ' e ~eo '~nM'rucl{~ns On Reverse Sido Approved Copy · Eeturned ,,, WELL SCU SWANSON July 1 , 23-9 RIVER FIELD 1971 REMEDIAL PROGRAM PROPOSED WORK: Convert Well' to-gas-injection. Recomplete well with a String of 4" tubing. PRESENT CONDITIONS: T o~t a~l D_epth: 10',750' ..... --'~ : 10,652'-10,748' _C-~'Sin__g: 20" ....... conductor pipe_ set at 32" 11r3/4', 47#/ft. casing cemented at 2009' 7"_ .... casing detail as follows: (from tally): Bottom 759' (10,749'-9,990') 290 P-110 L8R' Next 14' (9,990'-9,976') 29# P-110 L8R Market Jt. Next 1600' (9,976'-8,376') 29# P-110 LSR ...... Next 7' ( 8,376'-8,369') 29# P-110 BT x-over -:.Next 1564' (8,369'-6,805') 29# N-80 BT . Next 15' ( 6,805'-6,790') DV collar and x-overs Next 247' ( 6,790'-6,543') 29# N-80 BT Next 1828' (6,543'-4,715') 26# N-80 BT Next 3667' (4,715'-1',.048') ~3# N-80 BT Next 760' ( 1,048'- 288') 26# N-80 BT Top 288' ( 288'- Surf.) 29# N-80 BT Total 10749' - Ail K.B. Depths Elevation- 135' K.B. K.B. is 15' above G.L. Perforations: 4-1/2" jet holes per foot as follows: DI¥1$10N OF OII. AND GAS ANCHORAG8 10,626'-10,592' ; 10,545'-10,455'7 10,364'-10,351~ ; 10,300'-10,280'.' · 10,580'-10,554'; 10,434'-10,388'; 10,343'-10,317'' , WSO's thru 5-1/2" holes at 10,625' and 10,276'o. Ail perforation depths are IES. ' 7" Casing Collar Location - IES Depth 9897'-, 9931'-, 9971'-9985' marker joint; 10,026%'', 10,069'; 10,108'; 10,148'; 10,193'; 10,228'; ].0,272'; 10,310';. 10,354'; 10,398'; 10,441'; 10,483'; 10,527'; 10,569'. Tub ing: 2-7/8" EUE tubing with jewelry and packers per the attached Casing and Tubing aetails dated 6-12-68. as WELL SCU 23-9 - REMEDIAL PROGRAM July 1, 1971 Page two Junk and Condition of Casing.: During remedial work in June, 1968 no bad pipe or j'~nk reported. Effective depth was 10,652' . BOPE Considerations: This is a high gas-oil ratio well. On 5-28-71 the reservoir pressure at the top of the perforations at 10,280, was approximately 4900 psig. Class III BOPE will be'used and hole must be kept full at all times. A 75 pcf mud will provide an overbalance of 450 psig at the top of the perforations or 10,280'. ~ · 8~ 9~ SCU 23- 9 GAS INJECTION CONVER~I~IN~. P R o c A M .I tL2 1971 DIVIEION Of O1[ AND GAS P~iO~ ~O r~g move ~n, puZZ C~V from mandreZ a~ ~0,~59'. Fi1~ tubing and tubing-casLng annulus ~th e~ude o~Z. Znsta11 Cosasoo ~Zug. Move in contract rig. Remove Cosasco plug and kill well with 76-77 pcf clay base mud (76 pcf mud~will provide 500 psig overbalance at 10,280', top of the perforations) as directed by the Production Foreman. Install Cosasco plug and remove xmas tree. Install and test to 5000 psig a Class III BOPE consisting of a 10" Shaffer LWS Series 1500 double gate and 10" Hydril GK series 1500 bag preventer. Test blow and kill line. manifolds to 5000 psig as directed by Production Foreman. Remove Cosasco plug. Work tubing to free packers at (top) 10,190', 10,375' and 10,445'. Pull and lay down tubing and packers. Have a "CC" Retrieving tool on hand in case the "CC" Safety joints at 10,342' and 10,412' release. Pick up 2-7/8" drill pipe and mill over and recover Baker Model "D" packer at 10,585'. Run 2-7/8" drill pipe with saw toothed collar on bottom and clean out 7" casing to 10,652'-. Circulate hole clean. Run open ended tandem 7" casing scrapers. Thoroughly scrape and re-scrape perforations. Circulate hole clean. Pull laying down 2-7/8" drill pipe. Run a 5-7/8" O.D. gauge ring on a junk basket and casing collar locator to the effective depth and log to above the marker joint at 9971'-9985' (IES depth). Set Baker Model "F" wire line packer using Schlumberger equipment at an IES depth of 10,585'. Measure from collars and marker joint. Make up hydraulic packers and jewelry on 2-7/8" tubing to above the top packer. Above the top packer cross over from 2-7/8" EUE tubing to 4", 11.0#, N-80, EUE tubing with ABC couplings. Tubing detail to be furnished, but set hydraulic packers at 10,445', 10,375' and 10;200'. }tydrotest tubing to 6500 psig. Stab through Baker Model "F" packer. When the locator stop contacts the packer, pick up one foot and land the tubing. Install Cosasco plug. Remove BOPE and install 10,000 psig injection xmas tree. $CU 23-9 GAS INJECTION CONVERSION July 1, 1971 Page two 10. 11. Test tree to 6500 psig with clean water. Remove Cosasco plug and displace clay base drilling fluid with crude oil as directed by the Production Foreman. 12 14. Set packers,install Cosasco back pressure valve and release rig. Back flow from lower zone only initially until the well cleans up' Check with Engineering prior to back flowing the upper zones. Inject into all zones when well is cleaned up. -. /W. Ro TINKER III O/S W. H. Fairfield JIlL 19/l DI¥1$1ON OF OIL AND GAS ANCHORAGB, } . ~":'~'~e'~-,~L~-~ ........ DlVIglOiq OF OIL ,.;,;'iD i AN. CH O RAG E ' ALASKA P. O. BOX :-839A~r~ i$, -~:)3 mr. ~4. H. Soyst~r Regional Oil & G~s Supervisor United ,%tares (~ologlcal Su~ey P. O. ~x 259 ~~i:'nch°~ge';'~as~'.. C'hlet'~ Petr~_eum B~aneh ~p~meo.% of i~tux'al ~sou~es 329 Y, econd :~venue /~.nchora ge ~ GentlemeG: We enclose her~wltB for your files and Information, completion -.,:.~po~%s of remm..cllel work on wells Soldot~a Creek 25-9, ~2-8, and ~ery truly yours, , C. V. CHA~'XI~RTON COMPLETION REPORT - PACKER INSTALLATION SOLDOTNA CREEK UNIT 23-9 SECTION 9~, T. ? N:, R.._9 W.., Seward B & M S~q~A~ OIL C~A~Z Or CA~Zma~; W, O~ I'." """" OP~.~0i~ Page 2. Octob.~er 17... ,!96~ Remedial work commenced at 1:00 P.M. Rigged up and conditioned Black Magic mud. 0cto..,ber,, 18~ ,,1,962 Killed well with 80~ pcf Black Magic mud using Halliburton. tree and installed BOPE. Pulled 2 7/8" tubing out of hole. Removed x-mas Oc~ ober 19~ 1962 Ran casing scraper to 10,600'. Pulled scraper. Reran 2 7/8" tubing. TUBING DETAIL K.B. to landing flange Landing flange 2 - 2 7/8" pup Joints 322 joints 2 7/8" 6.5~ N-80 EUE 8R Camco Sleeve valve i Joint 2 7/8" 6.5~ n-80 EUE 8R Brown CC safety joint i joint 2 7/8" 6.5~ N'80 EUE 8R Brown 7" X 2 7/8" HS-16-1 packer 2 Joints 2 7/8" 6.5~ N-80 EUE 8R Camco D nipple l0 Joints 2 7/8" 6.5~ N-80 EUE 8R Venturi shoe Tubing landed at I,B. Oe~th 1~.22 .35 l~. 57 16.17 30.74 10135.81 10166.55 3.02 10169.57 31.25 10200.82 1.06 lO201.88 lo.oo 10211.88 5.97 10217.85 63.26 10281.11 · 92 10282.03 315.63 lO597.66 ,66 10598.32 ~0", 598; 32 Ocgober 2.0.., 1962_2 Removed BOPE and reinstalled x-mas tree and tested with 4500~ psi. mud with oil and flowed well· Set packer at 10,212'. Displaced Rig released at 9:00 P.M., October 20, 1962. S. R. NANSEN SRN:pb UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS State ..... _A_~.a.s_ka ................ Co**nt~j ____K~n_a~ P_oni,,mu~a._. Field __ Swax~on River. _ . 9 The followin.¢~ is a correct re]~ort of opera~io;,,s and productiot~ (ir~eh~cti~i:i ,?:i/[inE atilt prodttcin~ wells) for the 2~onth o/_._ ~O~r .................. :~_62 ................... ~oldot~ Creek_ Unit .l~ent's ad.~rcss ........ Po. o. B~ 7-839 ......... c(,,.~,o,,~/ $rA~_ O!L C0~. ~ ...... ~-[ ........................................................... Rem~ Wo~ ~CU 23-9 i(21) Remed~sl 7N ~ :ommenced Qctober 17, 19620 Killed well wi~h Black Ma~ic mudo Removed x-mas tree and installed BOPE. Pulled tu~,~ingo Ran casi~ e~raper. R~ram 2 7/~" tubing equipped .~rith Oacker. Landed tubing at 10598'° A~aoved BOPE and ~eins[alled x-rays ~ree. ~ Displaced ~d with oil. Set packer at 10212~o Rig released October 20, U.S.G M.H. Soyster $ta~e D Bruce Richfield - C. W. Perry Ro 'R. Ritter Files - P~oducing i R~turned well to productiono 1962, RECEIVED .. NOV 8 1962 Petroleu~ Branch D~v~sion of Min~s and MineraJs · NoTE.--There were ....................................... runs or sales of off; ................................................ M cu. ft. of gaa sold; ............................................... runs or sales of gasoline during the month. (Write "no" where applicable.) Nom~.--Report on this form is required for each calendar month, regardless of the status of ~peraHons, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise ,ih'ectc,'l bv the supervisor. UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS State .......... Al~$kg .............. County .......~e___~__.& _~O_.z~..g_~___l~__Field ..... ~n~ pg____R~._ 7.e__r___ F~ld ....................... Tt~e /~Nc, u.,i~ is a correct report of operatio~,s' and product, ion ('incl~din~ drillin~ and produ, cing we~s) for thc monna o/ ...... ~ ......................... ~-, _ ........... ~l~o~__~ek ~t ......... ,. s~ o~~o~~~~ ~Ao,~ ................... ~aa~ 7-629~ ................................... ..z,,~.t.'~ lit/,, ~is~ct S~e~nten~nt ,Core ( '1 r~ . FT. OF (iAS d. Core $12, 10,525' 10,555' cut 30' Tee ~-9' _ -- $ , · · Core ~13~ iO,~S' 10,~6~' cut & rec 30' . · Core ~ , 10,585' - 10~6~O', cut & rec 45' Core #15, lO,6SG' - 10,669', cut & rec. ~9'. Core ~16, 10,669'- 10,703'. Out 34' U.S.G~S. Alaska 0 ~ a C~ - D. D. Bruce! , ~tchfield, .-C.i.W. Pgrry, R. R, Ritt~er, iR, dined with 9 7/8" ~it 10,525 - 10,703' and'drilled hole 10,703 - 10~7~0' TD. Ran I-ES 10,754 - 2,012'. Sonic 10,7~2 - 2,012'. Mlcr~-Oalll~r 10,752 - 9~300' and 6,800 - 5~700'. Dlpmeter 10,750 - 2, Oi0'. ~emented 7' cas~ng at 10~7~8' in tWO s~ages wi~h 1500 sacks· 10ne ptage around ~hOw wX~h 600 and 2nd throtigh nV collar at 6,796' iwith 900 ~acks. InStallod and tested BOPE ~o 20OO p~i. Ee:ML GE. Top ,Of c~ent aD 6,770'. i Drilled oDt DV collar and ~ement to top of Baff~. e collar at 10,.657'.~ Tested DM collar lto 2 ~1 ~ $ i $ Held OK. aah ~eut.~.,n,-col~,-' ~o~ l?,?~0 - 9, o0o' and CBL ZO,?~O - 1,$~0'. Shot~, 5 - ~ ho~es aS 10,~76' for WSO~st #~. WSO ~ezt 0~. PerfOrated 5 - ~" h$1es ~t 10,625' for WSO Test ~2. WBO GE. R~n WiT, line formation tests on following d~pths: lO,~00', 10,503', ~O, 464', 15,400', 10,358', 10~B26', 10,290'. Circulated and condi'~xoned m~d. P~rfor~ted $ ~ hOles/foo$ over following inter~als: i10,620- 10,592', 1~,580 - 10,554', 10,54.5 - 10,455', 10~4~$- 10,~88' ~o, %~ - ~o, ~5~', 10, ~$~ - ~0, ~7',' ',¢'; Soo ' ~o, sSo,. ~n and .2 7/8 tubing w/yen%uTi ~hoe at 10~08 . I~stalled .E-n~s tree and ~low tested ~li. RepresentatiMe rate: 16~2 B/D oil, 260 MCF/D g~s,' 16/6~" beam, 1560~ T.P., 1~90~ C.P. 7~ trap p~ess., 0.8~ total !cut, O.l~ water, 0.7~ sand and nmd, 35.$° corr. gravity. Ri~ re.l. ease~ ,-~. ~. So,SteT I Files: ,Produc£nE _Explorat~Lon NOTE. There were ....................................... runs or sales of oil; ............................................... M cu. ft. of gas sold; .............................................. runs or sales of gasoline during ~he month. (Write "no" where applicable.) NoTE.--Repor; on this form ~s required for each calendar mon;h, reg:m!lcss of the s~atus o~ opera[ions, and mus[ be filed in duplicate with the supervisor by ~he 6;h of ~he succeeding month, unle~:s oCherwise directed by ~he supervisor. (January 1930) UNITED STATES DEPARTMENT Of THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS 9 The followi~L~ is a correct report of operations and prod,ection (ineludin~ drillin~ and producin~ wells)/'or the ,zen. th of ............. ~ .......................... 1.~_~_., ................. ~-~_~_P_~_~_r~_k_.~ ..................... ~ent's address ........P.~.._~_,__~gX__7~.~3~. Company STANDA~ 0~L 00, OF ............ .................................. ' ~,~ent'~~~O~'~ I'fl'~CAL~0~IA 7N ~ SDu~ded ~ay 30, 1961o Dpi~ed 17-}. hole ~ - 2028'~ Cement 1i-3/4" 6~ing at 2009~ b/1800 sacks. Installed ~ tested BOPE. Dri~ied ~-7/8" hole 20285' -6580'. Well started to fl~ w/83~ ~d~ in h*le. Shut in a~ increased mud weikht to 9~, cim~ated gas out Sf hole. Dr~le~ 9-7/8" h$1e 6580'; 10 24~. Cored Co~ ~1, 10,~45~ - 10,275', eut& rec~. 30' ~ cor~ ~, ~o,~, .~ ~o,~os,, ~ut ~ ~o. ~o, ~ Co~e ~3, 10,305' -~ 10,330~, ~ut & req. 25~ Core ~4, 10,~30' - 10~344', eu5 & re~. ~ out' hole ]~d drilled hol~ 10,372' $ 10.374~. coV~ ~7, ~o,~, .~ ~o,~o,, ~ a =e~. x2~ ,~ Core~ ~8, lO,qiO, -]10,~0,, ~ut & rec'.l 30' Core ~9, 10,~40'~ -~, 10,470',~, ~ut & rec. 30' ~ Core ~lO, lO,~TD - 10,49p , ~ut & rec. 2%~ Re.ed 1(~,375' - 1~,525'~ . Rtc~}field Otl lCo~.'-C. ~. : I R.R. ~t~r I Fil~: Produc~ ~ ~loration ~ ," La~ ~ ~ NoTE.--There were ...................................... runs or sales of oil; .............................................. M cu. ft. of gas sold; ............................................. runs or sales of gasoline during the month. (Write "no" where applicable.) NoT~.~Repor: on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of t, he succeeding month, unless otherwise directed by ghe supervisor. Form 9-329 (J~uuary 1950) ~ 16--25766-8 U.S. OO¥~.SM{~ENT PRINTINa OFFICE 'ii (SUBMIT IN TRIPLICATe) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS NOT~ M mTEXrK)N TO caA~ ~LA.S ........................ ! .... MOTlC[ OF INTENTION TO TEST WATER SIMJT-43FF .............. NOTK:£ O~ INTENTION TO I~-D~ILL Off RI~AIN ~ .......... I ..... NOTICE OF INTENTION TO SHOOT OR AClDIZ[ .................... I ..... NOTIC[ O~ INTENTION TO Ii'ULt. OR AZ.TE:N CASIN6 ............ ; ....... NOTIC[ OF INTIENTION TO AIANDON WILL ...................... SUPPI.~~Y WE~t. HISTORY .................................. '~--'l .... (INDICATI[ &~OV[ BY CIMK:K MARK NATURE o/r RI]K)NT. NOTIC~ ON ~ E)ATA) agp ..to--rely, S.~ ~,. ~c~.,_ .~ ....~,_.h~,__~._~__~., ............ ~~_~.A..~ ......... ~ ~. ~ ~. No.) ....... ~wp.) (~) (M~dl~) S~o~ ~ve~ [e~ ..~~ ........... A.~ .................... .................. ~-~ ...................... ~~ ,,b~t,~Y ............... ~e elevation of the ~ a~ve ~ level 6. 7. 8. DETAII~ OF WORK Dwli' to 2,0fX)' a~od cement 11 3/k" casin~ to su.rface. Install aM test CJ.as~. [.ii B!o~ut P~ventlon Equi-p~nt. Dri.L1 ~ead to '~p~,:~'~x~m-~'~" 10, ~'. Co~ ~ead to pe~t:m~e the p~d~ctive C~nt 7" ~sl~ at .-t' JUN 5 196'1 C'."! & Division of Company __. _S.._~... ~._ ...OIL.._ _¢ . .Olt~__ ___A~._.__ _.O_~. _~ ,+~. __- _~__. ~.S. ~_ _ _Q~j~.~Qj~. _ _ ~_L .................. c. v. i APPLICATION FOR PERMIT TO DRILL, DEEPEN OR PLUG BACK APPLICATION TO DRILL NAIVlP] OF COMPANY OR OPERATOR DEEPEN PLUG BACK [-1 DATE ~ 29, 1961 S~ 0IL C(]IPAI~ OF CAI,IF~'tlI, ~~qN (a~Et~0t~S, 1~. Address City State DESCRIPTION OF IVELL AND LEASE Name of lease IWell number IElevation (ground) Sol~k~t~a C'rmek U~tt ] ~ 23-~ [ 130'~ Well location (give footage from section lines) Section--township--range or 1)lock & .~urvey App~~l~ 1980' east Field & reservoir (If wildcat, so state) ] County S~~ '~r ~,~e,~l H~~ ~se~!r .................... Distance, in miles, and direction from nearest town or post office Nearest distance from proposed location Distance from proposed location to nearest drilling, to property or lease line: completed or al)plied--for well on the same lease: '~ feet ~ feet Proposed depth'. Rotary or cable tools Number of acres in lease: [Approx. date work will star! Number of wells on lease, including this well, completed in or drilling to ,this reservoir: If lease, purchased with one or more wells drilled, from whom purchased: Name Address Status of bond Remarks: (If this is au 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 the ~].S~.~'~. of the ~T'I~ : . ' 'OFitSt~,~I[iC. ' (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are true, correct and complete to the best of my knowledge. Permit Number: 21-61 Jur~e 1, 1961 /,, ~ Approval Date: _ , ~, £ ..~/ Chic'f} Petroleum Branch NotiCe: Before sending in this form be sure that you have given all information requested. ~uch 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 ~idot~a Creek I~it 23-g (21) t'erud, t Bo. ZJ,~ Xosued 6-1--61 \ PRODUCING DEPARTMENT TELEPHONE BR. 7.-6201 C. V. CHATTERTON DISTRICT SUPERINTENDENT ~9, Z,~6z Please re£er ~ ~ ~,e~~e conversation 0t' Hay 1,, 1961~ with our l~r. W. E. ~~ re~n~ $o~tna Creek Unit well 23-9. We have reviewed ~ ~~n ~h 1~. So~ter of the U.S.G.S. and ~$h ~o sub~t ~u e&~e~te lo~t~on a~ ~ on the attaeJae6 elteteh flyer 8nd are pro~ %o ~t~.~ ~t ~r ~ v~ml~ ~usl~et&~n. We therefore requeet ~ ~roval ~or an alternate location for 8Ctl 23~) spprox~nate~ l~lO' east e~l ~:)' north of the soutlmeat corner of Oect:Lon ~.. (~h:[s ]~cat~on efllou~ be app~tel~r ~0~ from Eman~n l~ver. ) Rec'd 5/10/61 APPROVED: /s/John B. Hakala Refuge Manager - 5/10/61 · Ve~? t~ml~ S~tt~ OIL CO~tl~ OF l~rn Operations, Inc. Orig.[ual signed C. V. CI-IATTEBTO~ Attache~nt ce: Nr. M. Ih 8o~er~ C. V. CItA~N 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 ~ q~' ~"·'~'1wI,.fJ!i<~":W~/~~~~b¡,.~{'1Pòf.' $'70>.~~<::l~~'ff<~r~~~ì.l<I~1~~fl:C¡I\¡;i.toIl:ijfl;l.~~~~'~~~ J '.. ,'. ~,:', '.' "" ", ':,;'::'"'-~,"':!":~J;:J/:';JJ~~~/"":":\"'" l1_ O· ~o'~Q:J\~'ë~"II:" ..-; :' ]1' "Œ@Œ~WŒ:~~~~:~[)~~~nM;''-;o II('~~::,;',,:,,': " ' l!:; IW ~ tJ\ï·;·~ "',,;',' ".", '.j \ ~,;' \ì __.~' _: ....:.;-' ~ __._ ,_. _ ~ ,,' _, ~'. _ .: '".> ~~?y~,'::~~ .:. ;" ':;:"" :~,,;:: ~r',.'~ .<.....;. 1-.* )~ ::',1,'- _ .~:.~ ~ ;:~ ! "'," . AUG \5".',19-14,' ,\ ,- .... ' ,., ,\ ,," "./ 1-,' . ,. . ¡: I ! Allr '. ......,.. . I :1, ,~ ¡ 1\ ' . ~ f ! ,); ! ' .:r , ~ ( ,:) , f ~, ,', , . I ' ! i , .. " r~':""" - - ------'. ."',,'."',,'".., ..~." 'liO IN~EJ;iIIAtJ;~ ~QþJ ¡/)l;~~]~:w(£)rJ1?i)' ,', · "':V¡if!J~r~1 ~lr/~'~I'~ v,,~.··,..,ødL-;·iI~~~~~~' PRODUCTION LOGGING STATE' ,LOCATION: ' AKA~KA , .,,", ."~- . ~., "" ... . . COMPANY" STANDARD 01. "COMPANY WEllSCU~&q .'.' f9f1Yl~J3-q FIELD '.. SWANSON R I VFR . . BOROUGH ' KFNAT '. 1:w;:¡-4 ·.RG~.~· "'........,j ¡ .\. ~ ,',. 1 CCL-SPI NNER ,~,' . j RIA TRACER ,;::':.: ~::>i SERVICES INCLUDE: 'Í SEC 9 PERMANENT DATUM: LOG MEASURED. FROM DRILLING MEASURED~R.OM (; ~I . K.R~ K.R. ",,' .:.:.:::j , ELEV~" 0 . HEV: K.B.· 1 S 15 ., FT. ~BOVEPERM ,DATUM D.F. :':':' ~).,,.~,:.,,. ;;~~ .'":j DATE: 6 - 2 0 - 7 4 MECHANICAL DATA :'¡:"7'~"!I....:t,:'~ SIZE 7" TUBING RECORD" ""'~'"j FROM .... TO": :\1 ..':~ SURFA~E lO~7.48 3 1/2~S_URFACE' _~--.9J..iã_'·'-<../':,. . 2 7 I 8' . 9_3 8 8 1 0 ~ 6 2 3'i'!'::~ CASING· RECORD TO" WEIGHT FROM SIZE 29B , . PERFORA nONS ' ... MANDRELS PACKERS NIPPLES :c,..·.· '!": SLEEVES . \.-:'1 ·lO~280 1 0, ~1 7 10,351 10,388 10,455 10~594 10,592 10,300 . .10,'343 10,364 10,434 10,545 10,580 . 10,620 OTHER .,..:, -.-e...b PLUG ca 10,589~~ '. 10,34.3 10,41Q 10,'i56 _.XA: lO.(~l ~ 10,25L~lQ,~2_ 1 0 ~ 3 7.1 ...5=.l43J-A- ..1 0, 441, S~...lJl..,.-.!t.!t.8- 1 0 , 5. ~ 3-' 0 -1 0 , 5 ¡~9_ . ~ . . ". " ~.. .' .. J '.~. '. ".,... ,.' -;';'..:. .. . ~, " '", _of .. . .' J -.......---.---. ~ ( o~ I, :"." , :'::;-'.. .': " . '.i ,J" ..:';.;;~/i.·.'~::;,>-l::~:>~~:::;;'-\ , .. ~~."~'; :;'~·é'.'· ','~', . c0MÞANy~~.' .~·CHEVRON ·¡U·. ~.,A.;'" '., .; ~ . " ,',~::_;,;,X '. .... " ·,~,~tt.'; ·,··,~~{ß~'~l!~;ti\':'.,·:,;~i~i.; , ':S~.~.S~ß14 ,J~l ~FR '.: .... ."; ~, '\' :'" ··::~NÄ'l'. ~,~~~-~':':CQ. :::·:..i:, :·.:~::~H(~:~:·.?; \ ,. . ~\~r;';':,~:~~;,:::ë~;,'82~(.::1:~{:s:'::;;r:;'lr~7?f1;0f·:;T(.': :~~ ;:.:'.-::; . "'.'.. !:~ !0~~ ,,~ ·;O<,,·t:J ~; !'~..j~ W] '..'~ ::; 'Õ~;:; t:: '.~§ :~~~.~ ·:l·,·~ ~~;:Q _!,!:~:; ·s 'i¡~ . .·T·' ;" "g'¿GJ ;;;;'::i:?'f ~. !!I .t ,;:." Other, Servicøs', O~'C .....'= ,:a..~ .~~':~)~ ..~$ :ü.:'t: · Qk'e: :Q).;~ E:'U: circ ..... c .~.' '.';,\,~ '~~f¢ ,. ,,~ . crJ: . ' " .<.~': : ~ :" ~ ~:' .,:, ' '';' , ~ ,; ',ã: .~ ~',. \~:"':"~':~~""'..",. 'r., I.. . 1<»"":1: ~ - ;'~';' ~:- D thO II .. '.' '!.:" ,"",.", .... ~ :> . '. êp.\.,~ n . at' -~.'. ....._'.':. ,".' . ^ " ':'1..... .;;:~~ . DePtli-.1.ogger·:' ¿-':,- . . . . . ." .,. ..'".' ,; , ,.", ~.~.;,~.~ 0' . 'Bott~iniogged Int~fV'al' , - :,::] 0'600,. ~,". , . ). ,~..~ , _ ',. t ": ,:g:~~ " ., Top 'Logged Interval" >101 on'·. 1.: \.::.....'.-.. . ...»~' ."- '< 'f·· ~.; cI . .,.:. TY~.Flulèqn,·H~I~ ':" ':., ·:'·'.IN:(,~~·G~~;;:-' .' ~';::.; !.; ;~> . , "'<7 ';'. ..o.~."'.'~~ ~':, ·M R T 'OF> ...::,..'.......... ,., . ;......., . <,~.,' c. .... ~ '. ax; .' ec.;emp. ".'"'' ~ ~ " .: ~.. ...:.:.,;.:.~~~.~~ l .:~ '.~ :.::~.~.'~').... ~.I:QUIP...N,o~·anr:t lOc~\Ìjóri/.,.~~..· .' . , :':ISTÈRLX"G "~,r·:'.'~,.:.·:·:·",~ '~ .\ " . :·::~eco.r~eø·ay·.:.·,::~':! -:'::~::"~'><', ,·~·:·'tASHJEY':':~·' ::. .... . ,. .', '·,r .;"" ..'!:'~~ ".: ~.:.. ;'¥'iI.tnef?sØd.};JY···:·'.':\<'. ...,~.." .MFH~Â'('/"·· r,. - .. t co ~ ,..'".... ·'BORE.HQ,LE;RECORD >,c:, , .. ," " " : r~BI'tiG R,E~0f.lD~' .·::..X: ';.~ ',;";~ :;~ ~~ ~;' :... ..'...,.:.;9.,...:-....,..:.:,......·.:~·'.I~:.:~'.·.;....~~..:.:. :.;.r...;:..:.~,.:.·.:..~:..~. ..~.'......~::;:....'.'...'.:._.~~....r::.,"·" ,..... ....~..> ;' 2f ~.:.'. , 3S~;' t '~:. ~g~i ·:?:t :, :, ,::; ~8' ~:. ;!l~ ,<.:. ',:,: ': " '.' .,,)'; "~ .~;:l{~.:;:·~:~:i£:~f.I~:: ;;';~::'?~~?}~ ;i;f~ "~'r:, ··~"~SING·REGORD:.: ........~::.."...:....:,.::.< :.~'..'.\.. LINER ; " ~ . ~·':.'''···:I '.~i'~" ". Site.'. ·..Wgt·,' .~: From· . ~..,.""" To'··.." :·"Slze·, ,·::wg,l.' -. '"'' 'From ·'rô·,>"·:·:X: '~';1 20.·' ..,~~,.' ·su.oc.Acr:; .'.~. ~"""" ".... . . .'/', c w·..·'::.: .,' li3J 4· ... ,. :" ..~ SURFACE "! :'2009' - . ~. .\ .-..'-., ., .,,~". .... " ~o:,~~. ., <, ~O:~V11~H.~". ~> ' , S~:~C.E.: .'.:1, 07 ~O .:., ~~ .,' '_".' . ,'., .." ~" ....':'~; '.': .,..~.~ ~.".'" ':'....:_...:..,~.... ;...:.~.'..,:.~,.._,',:~'~:..'.'....;'.:...~;.....:...'b.:...._...'.':..:....,:.~,_,~....~.,:.:..,~~....~,:::~......:...::..:_':'._... . ,.~,'~'.'.~' . c:,.,·..·.,:'_,.~...:'.·"....·-.:· ~....,~.. ."¥:~...: ..~..:.;.:~_...:.'::..._..~~_-....'I'~.:_:..-...,.'-...~_..,...~.c..:.:~..~....._.~._". .,·..:,...,..r.~::_¡>:.:..,.:·.,"..:...<:.~."'...:......,'.:.."..:f,·.'_'.~:,',.." "" .:7 . , " ... .. -....., - . ..·:..:_·...:..·~:5-~.'...:_.·........:-..:....'.-..:_.....:..'.........,.:.'.......'..,..,_.,.,.,...J, ..,,...:.'..,.-...;....':....,"..\......_._. .- L~';: ·<:i~:.~' ;...:::...;:,..__>~I.<>..,':.:.-;¿..:::~· .:' T .' '. ,.... _. -"~:: ,.~.::."~~;r:>: '.', ... ,I~'.',' ~ ç: --. I ',\ ~~t: ~'. ' ',. ..~ ': ','..:,~' '~ 'p'" ~··~~\f~ ~., , It, ~ '" .' . i..·..¿ .'.'-1.. .~' ,\ I .F1E~D^ (. .. ','- .", " '., , "côÚNTX·'·:··'· :·.~9G~TI()J\4,,\ . "..' ,'.' "."', . , ~. . .-.'...... '.. ,,', ., , .. ~ . . . I ., ~SEG. : :'1tt:::, . <,-R.ßS:· ·.~W.;":·'''· . .,j, ~ " .~ -l, 'r' ,~ ,...' ,,'Á.o,; "',' '" ..;-..:,..;<',.~~. ,:,! ". p,ørmá",ent 'bðtu'n'I~;;:: .. ~. . . ... ...l" ',. " ..' ·oc.· .._ ·.lO~·M~~~u'red..'·'t~~~~·, . ~. \., I~"¡'.'" ~;.' ',. ¡." ," "AI. (~B.~. '" , I ~ ' ~': '."':''' ~i. .;. " '~" ~ . "~. '. ~ .~ "1 : .~' ...:;:' ( .' ./ &1 .-rQ"J¡/" Perforatin'g Record 2 1/811 Enerjets 0¡ CL~ J Schlumbetger 0" -oC -oCJ æ~ I: c5, I:: æ~ 0« (. ~ Q)Q ~..c E -0.... .8 æ'~ (/) :J (/)1: 0 .......Q Q) 1::(. :5 Q» EQ >. Q) .a :Jê -g æe ..c: Q)= ,~ Ea E ..c ....CJ .2 WQ W :§3 (¡) ....1: ~ Oe as _a ãi as -0 .g CJ Q) .......e °c 0 ~+= I:: ~ Q)a ~ E~ ~ OC ~Q Q) (/)ê 0 W·- ..c: 0::= W I::e 0 Q)a .a ~ê -0 I:: I:: .- CJ as I::U I:: 0Q. e 0 -at ~ Q)G: 0 (/)... .Q ~~ ai (/)... E I::C as .Q ::= I:: 1::<.; Q) 'õ.. ~ 0= ~ Q)t Q) (ija ..c: I- (/)Q. I::ot: 0.... ~a "a)ê ....« Q.... ....a Q)- ....... - .5 c ='ê <t:c COMPANY Union Oil Company of California '" ~ ,2 ;; u Õ >- i:: '" Q. '" ~ E > <C 0 ä: ;: ~ U i:: rJ' Õ ~ ~ ~ i:: ;; i:: i:: '" ~ 0 ~ :: w u ~ rJ' z rJ' ~ WELL SCU 23-09A FIELD BOROUGH Swanson River Kenai STATE Alaska Other Services: None ~ NE 1/4 SW 1/4 ~ ~ ~ ~ § At Surface ~ 9 ~ ::J ~ API SERIAL NO. ß ~ ~ ~ 8 50-133-1 0126-00 Permanent Datum MSL Log Measured From RKB Drilling Measured From RKB Date 07 -F EB-1998 Run No. 1 Depth Driller Depth Logger (Schl.) Btm. Log Interval Top Log Interval Type Fluid in Hole Salinity NaCI Density Fluid Level Max. Rec. Temp. Deviation Logger on Bottom Equip. I Location Recorde,~ By Witnessed By lWP. 7N 0.0 F above Perm. Datum SECT. 9 Elev. 135,0 F RANGE 9W Elev.: K.B.135.0 F D.F. G.L.120.0 F 10200,0 F 9800.0 F Produced Fluids 13:20 8257 Rachel Walsh Mr. Larry McAllister I Kenai, Alaska BOREHOLE RECORD Bit Size Depth CASING & TUBING RECORD 27/8- 6.4000 LB/F 0.0 F 11 3/4- 47.0000 LB/F 0.0 F Size Weight Casing Top-Driller Casing Top-Logger Casing Shoe-Driller Casi ng-Logger -,. 29.0000 LB/F 0.0 F 10750.0 F 10623.0 F 2009.0 F -----~----- .. _0>=----",- _:...;..,'--o------........-~ -",- - .";or·'. -,..--, REMARKS . _-. _ _ .} ,'.- ·r - -. '--; . Witness' ï I, ! Date . :,'RUNNo.'·": : ,¿ :t û..... ',' ~ L-: ,... ., r- .-. , .... .: ,,~. çz.: z c,· '~~ , !-U ;::), .~ >,,' ,'-2 _.~ ·.:::x ~~ 0" " ':lJ -::-w... , ,'.':~ œ: ¿¿- - .'" 0 û ' :t .....J ,~ - ,;.I) cr. ~ '.t , Z' -Z'::t:., I ::= :..) '. ::.,JJ .:: <~ z ('\"') -:t - ~ . ,~..... 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'- . . _ ..1-:.-: ; _ . _', _ ".-< -.-' _ _ '"r- - .' -. , -. _ "-" 5:. ~ ".- -.-~ J }.,&.~~~~k·'~f~:··t··-t .-.,,-. £ I 10 38~10 434 '~L ,t_ .g :-~~-iö 'L~5S=iô~-345 ~'J~~'~~' / ~: g t-:et01'S5lt=1{f-$80 - " ~ ., ,,-,--:' ,,-'-., '--< " ,. ~_ <:!"to:592..::-10 --620 ->-~T~-~t-, '.' ·,·.),·jt:1:t~j~t't=t~·~tf-' ,[ ,dJ ~., ."'-~.--"-_._--':~---~ 5id' , - ., - -" - - - . - ..' -.' - -- "':;Œ.,~;i;:~~TX¿'tJ~~;:~f;tf&~£ff£·~~i"f2i:;~i~f£~~~1tj~~ ¡COMPANY i- ' "- (WEll ~f=IËÜ)_ CHEVRONU.S.A.L INC. .,... .;.- .. - , ~ ,SOLDOTNA,CREEK UNIT 323-9 SWANSON RIVER COUNTY KENAI t-- ' .- - --~..'.,.."'-"" ..~~ _.~_.. _ ,\PI Seriol No. 1 locoiion: STATF ALASKA "L _ ~.~ _ ..... -- ---'-.......,...--. H..-I' .- i - TEMP,_ " SPIN'NER ¡See. 9 Twp. 7N _, \ __,_.. 1\,,'." __.. ' , ____ftge, .. 9W'- ..:.g.......:..~~,_.. ...A.;;;..~;..... -_: ~ ,.....'.....-. - -..'.... ~ , " . .~.:~...¿ ..:_~.:i.*."':~. Permonent Datum' -(;..1 Log Measured From: KB Drilling MeO'>ur",¿ From:~Iš. B . --r_,....,¡-t:'ø..-~~._;: t:~>·:,~j.:-~J --i~ I ,- - ~ - _ __._.....__\'"-. ___.__},., . .[--~r.:¿_j. ..... ~_,'-.J.8 ...~\"___L....:.. .A.,":- 'ii, .. _-".:...AiI:'?a, .,-, ~Depthn)rthese re~ord,~ re , ' . - ~ 10-12-84, Eq~jpment 8257 - ~",,' ~_- QCõn--etQféd.by-2Cl ONE Locotion KENAI ,.-:~t:,;" '''-' -:-'--'- .':,'.,' , lÕ~ 75..0 . 00 ' _Rec.o'rded By F _ ~ ,lKNOWLE, ,SlT,INK,·' H,At1--", .",_ffi: =, Indkdte,"_~_ :~<)Je d,_ f!V, ;011, .N I A. W¡tneo;š By Mr, _ _ LOGAN -:' _ "'~:, '_ '.' >:- ~-~_.' ",.:' , ~-O.~~,~ .~~I,e' 10,600 -..'" ,. ,,' ,/' It .', ,,:~;:;f¿n·i~j . ..L_ J..Q:A4.Q",Q" _/if 'fI-" JIi.~ ,_ ..L___'~~~L~~.b.Jo..-'~LWõ.,~ , ,~LdL...--' ~~...... .. ~~~' Ii ~4~1""_', ~"",..;.Ai.... 'lit:'~ ',--~ ~"ì Elev.: 15Ft, Above Perm, Datum 15 Ft. A~'ove Perm. Dotum 'KEL OF GL- -- ;"""..-:. .; '" ~ "'- -.......,.,.........',-- Dote Run No. Depth-Driller Depth-5chl. Btm. log í~tervol I Top log Intervol ,.-, _-,,- 'JelL ~__. I....., ,- ','," ,', 1"...,""",;....\.0'..,..........·1....'......"'.·....',·,...',· ,Retarder Retarder by,,!?;;: . Wt.of slurry Water' 10$s Drill. mud type' Drilling mudwt~ " I, ¡ l i~ " i'. 1", v!''''· ¡ .,,\ C EM E. NT 80 N 0 lOG SCHLUMBERGER WELL SURVEYING CORPORATION' Houston, Texas, :",\i':',¡\',I;,,~"'¡)'m"'-.:i' ""¡' "~~,I;,..,~''''''·;\:'',r,"If'r',.\'~''', ''I).' '.:' ,:','~' ", ')"\' ~:¡v:~ ",' """:~!i\"/ />"~:,·,"J;~:,'?{~,,)R "'S'" ,'" " E I',·, , '~i(' '. ,C":'i":tU" ,,~,..:' ,:,;I,:ER;~::,,: "~ ,'':1~ì' '}~"/'~'; ..: .~.,',,':,,,J.:,,... (..L,~:~:t,!~'"'~'~,~;"i~~:,,d'¿' :.... ,.:,~,;.~'>~J\"~" f\··~~~,~';:; ,t.:).~.~,:::; , ....' "~, ".... '''\'~''''::.'1':': ~!ß/:':":':::b~ ',' ,.", ,.' r "I'/~,Cc;l',:i ~_rnml ;'(',:'il' ~l~·RI~ i ,I I II ¡ '.,"'1 ~,I'.~ , 'o,,~r ~1I&,b," . ~¡';" " ' ',. · - I I I '...'C,;~15\' ."',:~.~ '~, i ð~ð~ . ,I,' ...~ I J , ~I ::,) ¡ !: ' I I' ?" I I' '" -. !,' L', IÞ. 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