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Home My WebLink About161-013 STATE OF ALASKA RECEIVED • AL/-‘,DKA OIL AND GAS CONSERVATION COMMISSION !I IN i 1 1(115 WELOil ❑L COMGas PLETION SPLUGe ON OR RECOMPLETION REPORT AND LOG.. .. 1a.Well Statu ❑ ❑ Abandoned 0 - Suspended❑ l b.Well Class: AnCiCorta 20AAC 25.105 20AAC 25.110 Development [✓] - Exploratory n GINJ❑ WINJ n WAGE WDSPL❑ No. of Completions: _0 Service ❑ Stratigraphic Test n 2.Operator Name: 6. Date Comp., Susp.,or 14. Permit to Drill Number/ Sundry: Unocal Oil Company of California(UNOCAL) Aband. 9/13/1999 161-013 ' 3.Address: I- Spudded: 15.API Number: P.O. Box 196247,Anchorage,AK 99519 4/12/1961 50-133-10106-00-00 - 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2015'FSL, 2070'FWL,Sec 4,T7N, R9W,SM,AK • 5/22/1961 Soldotna Creek Unit(SCU)323-04 • J Top of Productive Interval: 9. KB(ft above MSL): 167 • 17. Field/Pool(s): , ,v2rn„`g;ve( del., 2015'FSL,2070'FWL, Sec 4,T7N, R9W, SM,AK GL(ft above MSL): 125 • Hemlock Oil Pool . Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2015'FSL,2070'FWL,Sec 4,T7N, R9W, SM,AK 10,276'MD/10,276'TVD • FEDA-028997 ' 4b. Location of Well(State Base Plane Coordinates, NAD 27): '11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 344442.005 y- 2457991.129 Zone- 4 10,775'MD/10,775'TVD • N/A TPI: x- 344442.005 y- 2457991.129 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 344442.005 y- 2457991.129 Zone- 4 N/A/N/A N/A 5. Directional or Inclination Survey: Yes ✓❑attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 r N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to:mud log, spontaneous potential, gamma ray, caliper, resistivity,porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation, casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary % O® SEP 1 7 2015 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 22" - - 0 43' 0 43' - Construction Cement 11-3/4" 47 J-55 0 1,413' 0 1,413' 16" 1000 sx Class G 7-5/8" 39/33.7/29.7 N-80 0 10,375' 0 10,375' 10-5/8" 1500 sx Class G 5-1/2" 20 N-80 9,693' 10,770' 9,693' 10,770' 6-1/2" 150 sx Class G 24. Open to production or injection? Yes ❑ No 0 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation Size SIZE DEPTH SET(MD) PACKER SET(MD/TVD) and Number): 2-3/8" 10,392'-10,700' 10,392/10,525/10,661 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑✓ Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period —*-• Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): of 0-407 apvkec 5/7015 24-Hour Rate —► - CQJt ITINUED ON clr Submit ORIGINIAL only 28. CORE DATA Conventional Lore(s): Yes ❑ No ❑✓ Sidewall Cores: Yes ❑ No E If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ Permafrost-Top If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. Formation at total depth: 31. List of Attachments: Well Schematic, Daily Report Information to be attached includes,but is not limited to: summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Stan Porhola Email: sporhola@hilcorp.com Printed Name: Stan Porhola Title: Operations Engineer • Signature: j1C Phone: 907-777-8412 Date: VI0/1 S0::11111 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection, Gas Injection, Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form:well schematic diagram, summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only UNOCAL Alaska Drilling Drilling Progress Report SCU #323-04 9/2/99 to 9/13/99 9/2/99 RU E-line unit to cut tubing. RIH with chemical cutter and set down in bottom GLM at 9428'.' PU and cut 2-7/8" tubing at 9425' with good surface indications of cutter function. POOH and RD E-line. 9/3/99 Move rig from SCU #41B-9 to SCU 22-4. Dropped sub base when choker line broke. Delay in rig move to inspect and repair sub base beams. 9/4/99 Inspect and repair sub base beams 9/5/99 Continue sub base repairs. Circ 500 bbls lease water down tbg and up annulus at 2.5 BPM/300 psi. Took 125 bbl to fill well and then full returns thereafter. 9/6/99 Finished repairs on sub base and inspected same. Resume rigging up on SCU 22-4 (formerly SCU 323-4). 9/7/99 Rigging up Inlet Drilling Rig #CC-1 on SCU 323-4 for sidetrack operations. RU top drive. 9/8/99 Accept rig at 12:00 hrs on 9/8/99. ND tree, NU 7" BOP stack. 9/9/99 Test BOPE. Witness waived by AOGCC and BLM. MU landing joint and pull tubing, lay down 292 jts of 2-7/8" tbg. 9/10/99 MU BHA #1: 2-7/8" tubing overshot plus 6.5" string mill combo. RIH and tag tight spots in 7-5/8" casing at 6563'-6567', 6731'-6733', and 6777'. Ream thru all tight spots with no problem and PU and fall through tight spots with no problem after reaming. RIH and engage tubing stub at 9633' (packer had fallen to top of 5-1/2" liner). POOH with packer and 9 jts of tubing. No problem at tight areas. 9/11/99 RIH with 4.5" mill assy to 10343' to clean out 5-1/2" liner. Circ BU and POH to 5590'. MU 7-5/8" Baker storm packer, RIH one stand and set storm packer. Test packer to 2500 psi. ND BOP stack and tubing head. NU new tbg head. 9/12/99 Pressure test new tubing head and BOPE. Retrieve storm packer and drill pipe. RU E-line and set Baker DW-1 whipstock packer at 10,276'. 9/13/99 RIH with gyro on E-line and measure orienting slot in DW-1 packer at 305.5 deg. POOH and RD E-line. Orient whipstock face at surface at 18.7 deg. RIH with .?°.< whipstock/window mill assy. Latch into packer at 10270' dpm. Shear up mill assembly from whipstock. Change over to 8.4 ppg Flo-Pro mud system. Mill window from 0255' to 10282'. •14 Swanson River Well SCU 323-4 Actual Abandonment 9/13/99 ' Ililcora Alaska,LLC CASING AND TUBING DETAIL RKB= 18.5' SIZE WT GRADE CONN ID TOP BTM. 22" - - - 28' 11-3/4" 47 J-55 8R 11.000 Surface 1,413' 7-5/8" 39 N-80 Speed Tite 6.625 Surface 131' 7-5/8" 33.7 N-80 X-Line 6.765 131' 3,623' - - 7-5/8" 29.7 N-80 Speed Tite 6.875 3,623' 5,654' 7-5/8" 33.7 N-80 Speed Tite 6.765 5,654' 6,552' 7-5/8" 39 N-80 Speed Tite 6.625 6552' 10,375' 5-1/2" 20 N-80 Hydril 4.778 9,693' 10,770' Tubing 2-3/8" 4.6 L/N-80 Butt 1.995 10,392' 10,700' 1)V Collar: 6,983' U I JEWELRY DETAIL NO. Depth ID OD Item EST TOC: 1 10,255' NA 4.500 Baker Whipstock 7-5/8" 2 10,276' NA 4.500 Baker DW-1 whipstock packer 8,514' 3 10,388' NA 2.65 Baker"F'Latching packer plug with 5 sx CaCO3 on toii $ $ 4 10,392' 2.68 4.500 Packer,Baker SC-2 5-1/2" 5 10,398' 2.99 3.500 Baker Millout Extension 5.60' CBL TOC: 6 10,403' 1.87 3.100 Sliding Sleeve,Baker CMU Window 7 10,489' 1.87 3.100 Baker"X"nipple 5-1/2"x7- 8 10,496' 1.99 4.500 Baker High Pressure tubing pack-off 5/8" milled 10,498' 1.99 2.375 Top Stub of Original tubing 10,255' 9 10,525' Packer,Backer FH to 10 10,562' Otis"S" nipple 1 10,282' 11 10,594' Brown"CC safety Joint 12 10,627' Otis"XA"sleeve 13 10,661' - - Packer,Baker FH 2 t,2 Fish: Fill Lost Gaslift ° Tagged at Dummy . • 3 10,357' Valve 7.n r•';•:4 f' (ELM) tiK•1 11:•{f ti�1fti 4 XI H2 5 _ 6 ,> _ H3 H4 7 = 145 8 ® PERFORATION HISTORY 9 Xt DC Interval Accum. Date Zone Top Btm Amt spf Comments 118 7/13/1995 G2 10,272' 10,332' 60' 12 2-1/8",EJ 10 0 _ 5/25/1995 G2 10,322' 10,332' 10' 4 2-1/8",EJ H9 7/12/1995 G2 10,350' 10,367' 17' 12 2-1/8",EJ 1 I OM 4/1/1961 H2 10,394' 10,406' 12' 4 Casing gun 4/1/1961 113 10,426' 10,434' 8' 4 Casing gun 12 4/1/1961 H4/5 10,454' 10,510' 56' 4 Casing gun 13 DC 15:‹ 4/1/1961 H8 10,539' 10,621' 82' 4 Casing gun 4/1/1961 H9 10,633' 10,648' 15' 4 Casing gun 4/1/1961 1110 10,670' 10,714' 44' 4 Casing gun - = 1110 r Last Workover=7/95 ETD=10,740' ,TD=10,775' MAX HOLE ANGLE= 2 deg. DRAWN BY: STP REVISED: 6/10/15 a From: Davies, Stephen F(DOA) Sent: Wednesday, November 19, 2014 10:39 AM To: Brooks, Phoebe L(DOA) Subject: SCU 323-4 (PTD #161-013): P&A Documentation Phoebe, Unocal's cover letter for the Permit to Drill application for SCU 22-4(PDT#199-083) indicates that cement plugs were not placed in the original SCU 323-4 wellbore prior to the SCU 22-4 redrill. Please ask Hilcorp to submit a completion report for SCU 323-4 with a current well diagram. That completion report and diagram must explain/display the current status of the SCU 323-4 wellbore and how the whipstock used to kick-off the subsequent SCU 22-4 redrill isolates the original SCU 323-4 wellbore from the SCU 22-4 redrill, effectively P&A'ing the original SCU 323-4 wellbore. The effective date for the P&A of SCU 323-4 will be the date that the window was milled in the SCU 323-4 casing. Please let me know if you have any questions or if this isn't clear. Thanks, Steve D. CONFIDENTIALITY NOTICE: This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 1 RE..CE/.VED ................. Alaska Oi-~&-G.asGons:,Commission Anchorage FO~M 1-0[11 {~[~. 11-85) ~I~I[D /_.~UHX T]r,D STATE8 //~¢ DE$'~ ENT OF THE Z~4TERZOR, SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to s different reservoir. Use **APPLICATION FOR PERMIT-" for such ~ol:x~sals , SUBMIT IN TRIPLICATE P.O. Ba~ 196247 Anchom~, ~ 995196247 4. ~ e~Well (Fool. s. 8es., T., R., ¥., M 8un~/ , ,,i 12. CHECK APPROPRIATE BOX(8) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION ,. ~] Other__lr~ Tm It i~ proposed to conduct a test on SCU Well No, 323-4 to evaluate gas injectivtty into the existJng producing horizon. Surface injection pressure and rate will be measured dudng the test. The test is expected to start aPProximately two days after Sundry approval and,last approximately 7 days. For any questions concerning the proposed test, oail Dave Wl~itacr, at 263-76'6. R ~ C ~- I V ~ ~ ('!1~ .Imce for FederM m 8~e dlice u.e) ,Fc~m 2~)-~ UNITED STATES (June 1000) DEPAR'I/~"~'I'I' OF THE TNTERIOR BUREAU OF LAND ~~EMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use "APPLICATION FOR PERMIT-" for such proposais , , ,, ' ' ' ' ' " 'SUBMIT IN TRIPLICATE 'T i Tvp, o, wd ............... X,~ __o~ __o~ ,, 2. N~nm M Opermr UnoM 3, Addrou md Tolephofl, No. P.O. Box 196247 Aflch~.. Absks 09~19.e247 ~ o~w,, ¢oo~.. ~.. T.. ,.:',,.. o, ~ ~) ' 2015" FSL & 2070' FWL, ~<:=. 4, TTN, RgW. SW III I CHECK APPROPRIATE BOX(S) TO INDICATE NATURE OF NOTICE. REPORT, OR OTHER OATA TYPE OF SUBMISSION TYPE OF ACTION FORM APPROVED Budg~ Bureau No. 10040135 Explm~: Mimh 31, 1993 5. Lea~e DeligfM~lon and 6edll No. A-028997 6. If Indian, Allo~ or Tdbe ~ 7. If ~ or CA, Agreement De~natlon Soldotn~ Creek ecu 323-4 / , ~PPW.,~. 50-133-10108-00 10. FioM and Pool, or Explomtofy ~ ~VlnlOn ~i~-?~H~, ....... ,K~I, ,~, .... [] NoUce ~ Interl~ [] Re=~e~n !-'1 ~~ [] ~ Repmr Water Shul-4:~f (NO~e: Report remJ~ ~ multiple ~ompleUon on Well Complea~ ~' R~.~AT, plelJ~ Repot1 lind Log foml.) It is proposed to conduct a test on SCU Well No. 323-4 to evaluate gas injectivity into the existing producing horizon. Surface injection pressure and rate will be measured during the test. The test is expected to start approximately two days after Sundry approval and last approximately 7 days. R E C E IV E D For any questions concerning the proposed test, call Dave Whitacre at 263-7616. APR 1 8 1995 Alaska 0il & Gas Cons. Commissi0fl Anchorage (This space far Federal m' 81ale ol~,¢e use) I ~ II I I I Title Dete Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL December 6, 1995 Alaska Ms. Joan Miller Statistical Technician Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Ms. Miller: Re: Soldotna Creek Unit - Well SCU 323-4 APl Number $0-133-10106-00 On May 25, 1995 gas injection was stopped, a PX plug was in X-nipple at 10361' and the following Tyonek interval was perforated in Well SCU 323-4: BENCH TOP (MD) BOTTOM (MD) FEET G-2 10,322 10,332 10 TOTAL 10 Attachment Very truly yours, Candace Williams STATE OF ALASKA '~"~ , ALASKA C.. AND GAS CONSERVATION L ~MMISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well Oil i~ Gas r'l Suspended r'l Abandonment [] Service [] ~~~?~//j_ . 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 61-13 / 3. Address 8. APl Number P.O. BOX 196247 ANCHORAGEr AK 99519 50-133-10106-00 4. Location of well at surface , ----~-,~-,, ~ 9. Unit or Lease Name 2015' FSL, 2070' FWL, Sec. 4, T7N, R9W, SW~: .tOQ~K)HS~~i Soldotna Creek Unit At Top Producing Interval ~ ~ I 10. Well Number Same as Above ~ ~~! SCU 323-4 At total depth~l ~, ,~~~ 11. Field and Pool Same as Above ~'?'?'~ ' Swanson River - Tyoneld 5. RKBElevMicnlnfeM(indica~ KB. DF, Mc.)167' I s. A-028997Lease DeMgnatio~and84HM No. Hemlock I 22. Type of Electric or O~hor Logs Run lES, Sonic, DIL, Cal, CBL, GR/Neutron. CCL 23. CASING, LINER AND CEMENTING RECORD I SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 22' -- -- Surf 43' -- Construction Cmt. 11-3/4' 47.0~ J-55 Surf 1413' 18' 1000 ax Cla,~ G 7-5/8' 39.0/33.?/29.7# N-80 Surf 10375' 10-5/8' 1500 ax Cla,~ G 5-1/2' 20.0~ N-80 9693' 10770' 6-1/2' 150 ax ~ G 24. Perforations open to Production (MD + TVD of Top and Boltom and 25. TUBING RECORD intewal, size and nurnbet) Size 'Dep01 BM VD) Packer 8~ 10426 - 10434' MQfTVD DepIh IntewM ~dD) 10454-10510' MDrrVD 1C~5L'39 - 10621' MD/TVD 105~ - 10648' MDCTVD 1067'0 - 107'14' MD/TVD 27. PRODUCTION TEST DMe Flint Pmducfiem I ~ of Test Heum TesI~I PRODUCTION FOR OIL-BBL ~F WATER-BBL, CHOKE.,~IZE! G~OIL I~A,TIO 10/15/95 24 TEST PERIOD -,~ 190 2 87 I Flew Tubing Casing Pre~m~re CALCULATED OIL-BSL J' ~F WATER-BBLi OIL GRAVITY-APl Pm~. 180 600 24-HOUR RATE ,-~ 190 / 2 ~/' 28. CORE DATA 0EC 1 1 1995 Alaska 0il ~, ~as k;ons, [.;ommission Anchorage Form 10-407 Sulxn# in duplkm~ Rev. 7-1-80 CONTINUTED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TEST NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH ... 31. LIST OF ATTACHMENTS 32. I hereby ~tify that the foregoing is ~ and correct to the best of my knowledge ·" G. R,._~_~JI_ Schmidt INSTRUCTIONS Item 5 Indicate which elevation is used as reference (where not otherwise shown) for depth rneasuremenm given in other spaces ~ ~ ~ and in any attachments. Item 16 and 24: If this well is completed for separate ;xoductJon from mom than one intarvaJ (~ complete), so ~tata in itam 16, and in it~n 24 stx~ the producing ~ fo~' onty the intarval ~ Item 21: Indicate whether from ground level (GL) o~ othe~ elevation (DF, KB, etc.) Item 23: Attached su~:~le~nental records for this we41 should show the details of any multiple stage Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Ga~ injection, Shut-in, Other.explain. Item 28: If not cores taken, indicate "none". , Spud: 412 6t Competed: 6/:i/6'~ Last Workovei: SCU 323-4 Swanson River Fled AP No.' 50-133- 0106-00 Lip . Top..~,,.,mlocL 10,364 Ft. MD ,,,,qie @ Hem ock:l Deg, ~ Hanger: Shaffer 6552,0 - 0575.0' 7 5/8" {.} 59.00t/fl N-80 PROD CSC 10575.0- 10375.0' SHOE 10770.0 - 10770.0' SHOE 9693.0 - 10770.0'5 ~.,: OD 20100~/fl N-80 LINER 10740.0 - 10775.0' CEMENT PLUG Oil ~ell Peffd 5/25/95 KB ELL-V: 167' PBTD: 10740' -rD: 10175' ",5-9634.0' 3.500" OD 9.30!/fi J-55 TEIG _ _. ._ - . . --' 'Y i:r,!f i 72',0- 962if I.!77 ID LANDING NIPPLE Otis X ~¢.4.0 - 9654,0' ON OFF Otis Over Shot & Pockoff ~;':; 0 9666,0' "' ~"-'"" .... :. - ~LU-Vr_ Otis XA Installed Upside Down ...,i ,.-,,, n._ '-.i"%'pr [b DEC 1 1 1995 Atmk~ Oil & Ga'. ........ :?;!4.0- 10700.0' 2.375" OD 4.70t/fl N-80 TBC , '7/"t 'ii.i- I',354.0 - '755.0 - ![~9.0 - i~3.0 - i;$20.0 - i~¢0.0 - ~52.0 - ~C594.0 - 'i:7.0 - 10,~61.01 PLUG PX t0,56i.0' .~NDING NIPPLE OIs S Posilion tS ld52.0' PERB 0-2, 5/25/95, 4HPF, 10', 111/16" Silverjei C:';, 0 10406.0' PERFS H-2, 4HPF, 17, 4/61 10434.0' PERFS H-5, 4HPF, 8', 4/61 10510.0' PERB H-4,5, 4HPF, 56', 4/61 10455.0' SLEEVE Otis XA Installed Ups de Down 10621.0' PERFS H-8, 4HPF, 82', 4/61 10648.0' PERFS H-9, 4HPF, 15', 4/61 10520.0' JOINI Brown CC Sdy dl 10714.0' PERB H-la, 4HPF, 44', 4/61 10562,0' ~NDNG NIPPLE Otis S Poston ~2 10594.0' JOIN{ Brown CC Saf{y dt 10627.0' SLEDE O[is ~ nsta d Upsde ,,~'*"',o ,,u ~:~V, PAOKER Baker FH 10667,0' ~NBING NIPPLE Camco D ~,~"- STATE OF ALASKA ALA, , OIL AND GAS CONSERVATION COMtv, ~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate Pull tubing _ _ Alter casing 2. Name of Operator Union Oil Company of California (Unocal) 3. Address P.O. Box 196247 Anchorage, AK 99519 . Location of well at surface 2015' N, 2070' E, SE Corner, Sec. 4, T7N, R9W, SM At top of productive interval Same as above At effective depth Same as above At total depth Same as above __ Plugging _ _ Perforate X__ Repair well _ _ Pull tubing X__ Other X 5. Type of Well: Development X Exploratory __ Stratigraphic__ Service _ _ 6. Datum elevation (DF or KB) 12. Present well condition summary Total depth: measured true vertical 10,775 feet 10,775 feet Plugs (measured) Effective depth: measured 10,740' feet true vertical 10,740' feet Junk (measured) Casing Length Size Cemented Structural Conductor 28' 22" Yes Surface 1413' 11-3/4" 1000 sx Measured depth Intermediate 10,375' 7-5/8" 1500 sx RKB = 167' GL-- 125' 7. Unit or Property name Soldotna Creek Unit feet 8. Well number SCU 323-4 9. Permit number/apProval number 61 - 13/95-122 10. APl number 50-133-10106-00 11. Field/Pool Swanson ~iye, r~or~/Hemlock 10,740' SEP 1995 N~ ~ & ~as Cons. C0~10~ True vertical depth 28' '~/T~ 1 ,~ 28' 1413 ~?/'~/ ~,1413 Production 1,077' 5-1/2" 150 sx 10,740' 10,740' Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 2-7/8" 6.5# L-80 @ 9733' 2-3/8" 4.6# L-80 10,392'-10,498' 2-3/8" 4.7# N-80 10,498'-10,700' Packers and SSSV (type and measured depth) Baker FH 9496'; Baker SC-2P @ 10393'; Baker FH 10,525' Baker FH 10~661' * 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation (GAS INJECTOR) 29,755 1300 Tubing Pressure 4950 Subsequent to operation (OIL PRODUCER) 152 22 179 850 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run_, Daily Report of Well Operations x _ I Oil x _ Gas _ _ Suspended _ _ Signed G. Russell Schmidt ~,~,~t~;~Title Drilling Manager I. i/ H~,,'-~ I ~ Form 10-404 Rev 06/15/88 2OO Service - Date 9/08/95 SUBMIT IN DUPLICATE ~,,,U 323-4 S~anson River Field AP! No.: 50- ! t~-10106-00 Top of l~,-.,, n'~a Ft. MD Angle ¢ Hemiock: ~ :~'.,,,, %¢. Hanger: bnarer _ ~0740.0 - t0T&0' CBENT L 15.O - ?128.5',2.875" OD 2.44-1" ID B.¢~/ft L-80 § Rd. IBG USED 1TOG. 71283 - 97e.0"" 2.875'00 6.40t/fi L-~ Buttress TIg 94-96.5 - lO'//~O - 1~.0 - 10,~58.0 - I0426.0 - t04~.0' ~ H4, 4/61, ¢ltT, I~ ~.o - ~o5to. o' P~S H-4,5, ¢], ~, 56' te5;~5.0 - 10525.0' R~. ~ B~er C,.I ~ I05~9.0 - t~2I.¢ ~ H-e, 4/6t, ~, ~ tef~,~.O -~ 1~.i~ PI~ H-& ¢I, ilt~, t5' 1.01;61,0 - 10661.0' Eli:ff. PAl;KB l~er F:,t ~ ]OK/O,O- ]O/KO' ~ HqO, 4/61, 4itT, ~' BE 107~ J.< .- . ._ ::.,,.;: j SCU ~:' ' ,.,.,..J-ff I't' I-'° S,onson rover rdd No..: 50-135-!0!06-00 Top o! Hemlock: !0,,364 Ft, MD An<lie @ Hemlock: i Deg, ' Hanger. Shoffer 14110 l~z~' SHOE - Ct I.JA/ 1~1.~ - ~23.0' ? 5/8" OD tt?O//lt ~-~ ~1) C$~ II m f.l); lO?~' I5.0- Z128.5' 2.875" ~ 2.44.1" ID 6.~/fl L-80 8 I~L ~ U~ TSO. 7128.3 - 9740.0' 2.875" OD 6.40J/fl L-80 Buttr~ BG NB ~. 15.0- t§.2' KAI¢~ Sh~tb DSR Hgt. ~f/Cm'mron Type -'"2246..8 - 2~5.5' 2.~Y B-C~SL!Fi', "I,~iE itt, Camco. KI~ 5292.5 - 52E0' OASlJFI' V~tV[ #, C,~ ~I,{ ff~8.J - 5~4.8' ~'d,q' V~,{ Il, ~ I~ ~ 6~6.4 - 6502.8' C,E~,, ¥~VE !6; C<~ KBMM G~ 76§6~ - 7705.4.' 6ASUFf V,~E ~4, C~o ~M GLM uomp~e~.~: ~)/ Lost'Workovei: 7/7/95 i~7'5.0 - 10b75.0~ IOT/O.O - 107/0,0' ~anson River " Field APt ~.: J . !. l(IbSO.O 1OHS&8 ll~.O I04AO Top of Hemt~k: t0,$64 Ft. MD Anclle @ Hemlock: i Deg, ' Hanger: Shaf[er - I0:~2.0' ~rs c-2, ~/~2/~.s, ~2~, t~', 90 ~ - t040;~.b' RE11~. PACI(ER Boker SC-2P Pkr. ~/~.~ ~ - t~.o' ~B H4, ¢, ~r, 12' - t~7.g' ~,~7o" ~ ~ ~k. ~u 10495.9 - 10502.1' 1,995" ID ON OFF Beker i-fqh Pr, llx]. Pockofl 10520,0 - 105~.0' JOINT Bro~ CC Saf~ J~ I0525.0 - 10525,0" ETRV. PACI~ Nker F}t Pkr I0,~0 - 10B2.0' ~ ~ Otis S ~ t2 101~t.0 '-IOBI.O' ~",/. PACKER Baker m67o. o- ~OTttO' Pin's H--m, ,~1~, er, BID: 10383.8 - 10588.8' F~ CalciUm C~nate SCU:¢ AP! No.: .. Top of Hemlock: 10,364 Ft, MD Anqle @ Hemlock: ! Deg. ' Hanger: Shoffer 10388.8 - 10392.8' PLUC, Boker "P' Mching Pkr. Plug 1039Z8 - I04015' ~/. PACKER ~ ~¢-~ Pb. ]/[~ ~ EEY:.. !67 r~]D: I01~ 10775' 10594~- 10~.¢' PB~ I~2, 4/61, 4Hff, 12' I0~,8 - M07.9' 1.870" iD 5LL~ C~er sEP 12 1995 Alas~ OB & Gas Cons. Commi~mn , ~omgo 10434.0' SCU 323-4 DAY 1-7 (06/06-12/95) 7-5/8' @ 10,375' 5-1/2" @ 9693'-10,770' RU HALLIBURTON SLU. RIH W/BAILER & BAIL PERF DEBRIS & CACO3. RIH AND RETRIEVE PX PLUG FROM S-NIPPLE @ 10,361' RU VECO BULLHEAD LEASE WATER DOWN TBG. SPOT XANVIS PILL ACROSS PERFS. RIH AND PULL GLV FROM GLM @ 9534'. CIRC LEASE WATER THRU GLM AND KILL WELL TBG = 0 PSI, CSG = 0 PSI. RU SCHLUMBERGER & APRS. NU LUB & TEST TO 1000 PSI OK. RIH W/1-11/16" CUTTER. MADE CUTS @ 10,483', 10,309' AND 9670'. TBG = 0 PSI CSG = 0 PSI. TBG PRESSURE BUILT TO 900 PSI. RU VECO AND PUP XANVIS/CACO3 PILL ACROSS PERFS. TBG = 0, CSG = O PSI. RU IISCO & INSTALL 3" CAMERON TYPE H 2-WAY CHECK. TEST TO 5000 PSI FOR 30 MINUTES. BLEED OFF TO 4800 PSI. REMOVE 2-WAY CHECK. LUB. LOCK DOWN SCREWS. DAY 9 (06/14/95) 7-5/8"@ 10,375' 5-1/2" @ 9693'-10,770' CIRC. 8.5+ PPG LEASE WATER. DAY 10-12 (06/15-18/95) 7-5/8" @ 10,375' 5-1/2" @ 9693'-10,770' MIRU AWS RIG #5 ON TURNKEY-RIG MOVE. ACCEPT RIG 6/17/95 @ 14:00 HRS. CIRC WELL W/9.4 PPG BRINE. SPOT XANVIS/LIQUID CASING PILL ON BOTTOM. ND TREE. NU & TEST BOPE. MU LANDING JT. PULL HGR LOOSE. POOH W/3-1/2' TBG. DAY 13 (06/19/95) 7-5/8' @ 10,375' 5-1/2" @ 9693'-10,770' CONT POOH & LD 3-1/2" TBG CHECK FOR NORM. PULLED 9510'. PU 3-1/2" DP & 4-3/4" DC'S. PU 7-5/8" CSG SCRAPER & RIH. DAY 14 (06/20/95) CONT RIH W/3-1/2" DP. TAG BAD SPOT IN CSG @ 6759'. WORK THRU RIH & TAG MODEL D PACKER @ 9577'. CBU. POOH W/MILL & SCRAPER. RU SCHLUMBERGER. RIH W/USIT, CSG INSPECTION TOOL. TOOL FAILED. SEND TOOL TO TOWN FOR REPAIRS. WAIT ON TOOL. DAY 15 (06/21/95) WAITING ON SCHLUMBERGER LOGGING TOOL TO BE FIXED. RUN USIT TOOL F/7100'-6500'. SHOWED WORN SPATS IN CASING @ 6958', 6726' & 6780'. ALSO P/U DV COLLAR ON LOG. RIH AND LOG CASING F/9540'-6970'. RUN BOND LOG F/7100'-6500'. DAY 8-10 (06/23-25/95) RIH W/MILLING ASSY BHA #1. TAG DB PACKER @ 9577'. (WORK THRU TITE SPOT @ 6755'). MILL DB PACKER F/9577'-9579'. POOH. MILL APPEARS NOT TAKE OVER PACKER. P/U BHA #2 (SHOE #2). RIH. TAG PACKER @ 9577'. REVERSE CIRCULATE UP DP. SUBSTANTIAL AMOUNT OF RETURNS (METAL, RUBBER & SCALE). MILL PACKER F/9579'- 9581'. GAS TO SURFACE. SHUT-IN WELL. CIRCULATE KICK THRU CHOKE. CHECK FOR FLOW. NO FLOW. MONITOR WELL. NO FLOW. POOH W/BHA #2. RIH Wl4-112" OVERSHOT. TAG PACKER @ 9577'. ATTEMPT TO PULL BAKER MODEL DB PACKER. POOH. NO PACKER. RIH W/4-1/8" O/SHOT. TAG PACKER. ATTEMPT TO PULL PACKER. P/U WT INCREASED GOOD INDICATION PACKER RELEASED. DAY 11 (06/26/95) POOH W/4-1/8" OVERSHOT. NO PACKER. LD 4-1/8" OVERSHOT. COMPLETE BOP TEST IN 2.5 HOURS. NOTIFIED AOGCC OF TEST. DECLINED WITNESSING TEST. P/U 6-1/2" MILL W/3-1/8" EXTENSION & 3 BOOT BASKETS. RIH. SCDL. SET DOWN @ 9428'. ATTEMPT TO WORK THROUGH W/BUMPER SUB. NO GO. WORK THROUGH BY ROTATING (TITE SPOT CORRELATES TO COLLAR & USIT LOG). TAG T.O.F. @ 9578'. MILL T.O.F. CBU. DAY 12 (06/27/95) FINISH CBU. POOH W/3-1/8" EXTENTION AND MILL. MARKS INDICATE THAT EXTENSION WAS INSIDE FISH. PU SPEAR LOADED W/3.308" GRAPPLE AND RIH. SET DWN AND USE BUMPER SUB TO WORKTO 9,587'. POOH WITH FISH. PULLED TIGHT @ 9492'. PULLED 20 KIP OVER TO WORK THROUGH TIGHT SPOT. POOH WITH NO FISH RECOVERY. LD BHA. MARKS ON SPEAR INDICATE WAS LATCHED. DaY 13 (06~28~95) PU 7-5/8" CASING SWEDGE (6.5" OD) AND RIH AND TAG UP @ 6551'. JAR 20 KIP UP TO FREE. POOH W/SWEDGE. PU SPEAR WITH 3.308" GRAPPLE (BULL NOSE CUT OFF 2" FROM GRAPPLE). RIH TO 9465'. BREAK CIRC. TAG FISH @ 9579'. LATCH FISH. POOH TITE @ 9507'. WORK THROUGH. CHECK IF FISH IS STILL ENGAGED. PUMP PRESSURE STILL READING 1000 PSI. DROP SHEAR-OUT PUMP SUB DART. CBU. POOH W/FISH. DAY 14 (06/29/95) SERVICE RIG. POH W/FISH. L/D FISH RECOVERED 87.40'. P/U 6.375" CSG. SWEDGE. CUT DRLG. LINE. FINISH BHA AND RIH TO TOF 9664'. REVERSE CIRC. POOH W/CASING SWEDGE. REPAIR HYDROMATIC CLUTCH. POOH W/CSG. SWEDGE. DAY 15 - 17 (06/30/95 - 07/02/95) CONTINUE POOH WITH CASING SWEDGE. A NUMBER OF SMALL MARKS ON OD OF SWEDGE. M/U FISHING ASSEMBLY AND RIH. HOLD SAFETY MEETING. FINISH RIH. ROTATE OVER FISH AND ENGAGE FISH. REVERSE CIRCULATE JUNK INTO REVERSING BASKET. POOH. L/D TOOLS. NO RECOVERY IN REVERSING BASKET. P/U GUIDE AND OVERSHOT. RIH TO GRAB XA SLIDING SLEEVE AND PULL PACKER FREE. ENGAGE FISH AT 9,664' AND PULL PACKER FREE. CIRCULATE BOTTOMS UP THRU CHOKE. NO GAS. POOH WITH PACKER. PACKER HUNG UP AT 9,622'. JARRED FREE WITH 50K LBS. APPEAR TO HAVE LOST PACKER. POOH. RECOVERED PART OF XA SLEEVE. M/U NEW GRAPPLE IN OVERSHOT AND RIH. CIRCULATE AND ENGAGE FISH AT 9,678'. CIRCULATE BOTTOMS UP. NO GAS. POOH WITH FISH. JAR FREE AT 9,636', 9595' AND AT 9553'. CONTINUE POOH. L/D FISH. CHANGE LOWER RAMS TO 2 7/8" PIPE RAMS. TEST BOP'S. P/U FISHING BHA NO. 14 AND RIH. DAY 18 - 19 (07~03~95 - 07~04~95) CIRCULATE DOWN OVER FISH AND ENGAGE OVERSHOT AT 10,311'. PULL PACKER FREE WITH 30K LBS OVERPULL. PULL FISH UP 15' AND LINE UP TO CIRCULATE BOTTOMS UP THRU' THE CHOKE. POOH WITH FISH. L/D FISH, RECOVERED PACKER OK. TUBING CUT ON BOTTOM OF FISH WAS NOTED TO BE SLIGHTLY BELLED. P/U TAPERED MILL AND CASING SCRAPERS TO DRESS OFF TOP OF TUBING ASSEMBLY AND TO CLEAN OUT CASING. RIH. WASH AND DRESS OFF TOP OF TUBING. CIRCULATE A HI-VlSC SWEEP. POOH WITH BHA AND L/D. P/U STRING MILL ASSEMBLY TO CLEAN OUT TIGHT SPOTS BETWEEN 6517' TO 6773'. RIH AND WORK STRING, NO TIGHT SPOTS OBSERVED. DAY 20 (07/05/95) POOH WITH STRING MILL ASSEMBLY. L/D. P/U 5 1/2" SC-2P PACKER ASSEMBLY AND RIH. CUT AND SLIP DRILLING LINE. CONTINUE RIH WITH PACKER. WORK PACK OFF OVER TUBING STUB 3 FOOT. DROP BALL. PRESSURE UP TUBING TO 3000 PSI. ROTATED 15 TURNS TO BACK OUT SETTING TOOL. SHEAR OUT BALL SEAT AT 5000 PSI. PACKER SET AT 10375'. POOH WITH SETTING TOOL. DAY 21 (07/06/95) CONTINUE POOH WITH SETTING TOOL. P/U F-PLUG AND RIH TO TOP OF SC2P PACKER AT 10,379'. SET F-PLUG IN PACKER AND TEST CASING TO 3000 PSI. PRESSURE AGAIN BLEED BACK TO 2200 PSI AND STABILIZED AT 2200 PSI. MIX AND PUMP 10 BBLS OF CACO3. SPOT PILL ON TOP OF THE F-PLUG. POOH LAYING DOWN 3 1/2" DRILLPIPE. DAY 22-24 (07/07/95- 07/09/95) CONTINUE LID DRILLPIPE WHILE POOH. SET BOP TEST PLUG, CHANGE TOP RAMS AND TEST SAME. R/U TO RUN THE COMPLETION. RUN THE 2 7~8" COMPLETION. HAD TO WORK PACKER PAST A TIGHT SPOT AT 6763' WITH 15 KLBS. WORK OUT SPACE OUT AND PICK UP NECESSARY PUP JOINTS. TOTAL NO. OF JOINTS RUN WAS 221. RIG UP ON ANNULUS AND DISPLACE 9.4 PPG BRINE WITH 8.7 PPG LEASE WATER. MIXED WITH NALCO 3900 CORROSION INHIBITOR. DISPLACED 350 BBLS. ATTEMPTED TO TEST TUBING. STANDING VALVE WILL NOT SEAT. ATTEMPT TO CLEAN OUT STANDING VALVE, CIRCULATE DOWN TUBING AND DOWN ANNULUS WOULD NOT TEST. WAIT ON PRECISION WlRELINE TO ARRIVE ON LOCATION. R/U PRECISION. PULL STANDING VALVE FROM X NIPPLE. RIH WITH PX PLUG. SET PLUG AND POOH. RIH WITH PRONG AND SET IN PLUG. TESTED LINES AND LUBRICATOR TO 4000 PSI. TESTED TUBING TO 1500 PSI SET PACKER WITH 1500 PSI. TESTED TUBING TO 4000 PSI. TESTED OK. POOH WITH WIRELINE. RIH WITH PRONG LATCH. POOH WITH PRONG. RIH AND LATCH PX PLUG. POOH . R/D PRECISION WIRELINE. R/U AND TEST 7 5/8" CASING AND PACKER TO 3000 PSI. TESTED OK. PULL LANDING JOINT. SET BACK PRESSURE VALVE AND NIPPLE DOWN BOPS. CONTINUE NIPPLING DOWN BOP'S. NIPPLE UP TREE TO PRODUCTION SPECS. TEST TREE TO 250 AND 5000 PSI. RELEASE RIG AT 06.00 HRS 07/09/95. MOVE RIG TO 242 - 16. DAY 1 (07/10/95) PREPARE LOCATION FOR COILED TUBING. RIG UP COILED TUBING. HAD TO REBUILD SHEAR RAMS. TEST COILED TUBING BOPS. RIG UP INJECTOR ON BOPS. TEST COILAND STRIPPER TO 5000 PSI. RIH WITH WASH NOZZLE TO 10373'. PICK UP 5FT AND REVERSE CIRCULATE THE 5 1/2" CASING AND 2 7/8" TUBING TO DIESEL. POOH. RIG DOWN THE COILED TUBING UNIT. DAY 2-3 (7/12-7/13/95) IRU SCHLUMBERGER WIRELINE. NU LUBRICATOR AND TEST. OK. IH WI 2-1/8" ENERJET STRIP GUN AND PERFORATE TYONEK: 10,272'-10,298'; 10,298'10,332'; AND 10,350'-10367'. SHOT EACH INTERVAL TWICE = 12 SPF. RD WLU. TURN WELL OVER TO PRODUCTION. M~Ill er prwY11nl:ur I~! IMI rem. 1111 11~ v~lvm~ ~k va lye JUM Z6 ' 95 08: 46PM ~ TeI~ R~rt JUN 27 !~95 _ __ Nail s t g~._._.__._ __ Press altec el P~ t~r clot Re,e~e~ 911M witch eo~r~ _FLOOR ~ v&L,~.S: / T,. Lewm' Kelly 8411 type Inlidt ~w~dntfold F.t lur-s., j~' Test tt~e ~, ~" hfs ' ReI~IIr or r~iK~ ~ filled equi~t tm ~ mdt within d4yt. ~tlfy ~ ln~tort ~ fo~m wf~ wt~t~gfl/FAXed [276-?~k2] vetiflca~m t0 C~tlilm office. · m __ · I I . m ~-hj - MGOC e - S~plrvtsor C.tli (rev 07/921 I - ' AOGCX: ~,~,~.-,,e 270-1433 - IrAx JTG-7~Aa STATE OF ALASKA ~"~ ~ .~SKA OIL AND GAS CONSERVATION CC, .... ,,fiSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ _ Suspend __ Operations shutdown __ Re-enter suspended well__ Alter casing__ Repair well _ _ Plugging __ Time extension __ Stimulate ~ Change approved program ~ Pull tubing X_ Variance __ Perforate X_ Other X_ 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 5. Type of Well: Development Exploratory Slrafigraphio Location of well at surface 2015' N, 2070' E, SE corner. Sec. 4, '[7N, RDW, SM At top of productive interval Straight hole At effective depth At total depth ORIGINAL 6. Datum elevation (DF or KB) 167' KB 7. Unit or Property name Swanson River Unit ,~jell number 323 -4 9. Permit number ~ ~;/-/~ 10. APl number 50-133-10106-00 11. Field/Pool Swanson River- Hemlock feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface 10775' feet Plugs (measured) 10775' feet Intermediate 10740' feet Junk (measured) 10740' feet Length Size Cemented 28' 22" Yes 1413' 11-3/4" Yes REdE!VEt., JUN 22- 199b ~aska U~l .& Gas Corl~, Measured depth ~lC~Ql~rue vertical depth 28' MD 28' TVD 1413' MD 1413' TVD Production Liner Perforation depth: 10375' 7-5/8" Yes 10375' MD 10375' TVD 1077' 5-1/2" Yes 10740' MD 10740' TVD measured 10394'-10406'; 10426'-10434'; 10454'-10510'; 10539'-10621'; 10633'-10648'; 10670'-10714' true vertical Same as above Tubing (size, grade, and measured depth) 3-1/2". 9.3# 9622, 2-3/8" 4.7# 9581 '- 10700' Packers and SSSV (type and measured depth) Baker DB @ 9577', Baker FH @ 9669', Baker FH @ 10325' Baker FH @ 10~525'~ Baker FH Packer @ 10661' 13. Attachments Description summary of proposal x _ Detailed operations program_ _ BOP sketch 14. Estimated date for commencing operation 6/17/95 16. If proposal was verbally approved Name of approver Blair Wonzell Date approved 5. Status of well classification as: Oil Gas Service Gas Injector Suspended __ 17' I hereby c~~~ is ~Td~;ct t° the~,,,/ i~ best of my knowledge. Signed G. Rb~e'11S~i(~r"" v ~ ,,,,-, ~'/'l'itle Drilling Manager FOR COMMISSION USE ONLY Date 03/07/95 Conditions of approval: Notify Commission so representative may witness Plug Integrity ~ BOP Test ~ Location clearance Mechanical Integrity Test__ Subsequent form required 10- ____ Approved by the order of the Commission driglnal Signed By David W. Johnston 'Approved Copy Returned Commissioner Date .~'/~, ~'G~' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Arco Alaska Inc.- Swanson APl#: 133-10106-00 Completion Date: 6/1/61 Hanger Type: Shaffer of Hemlock:10,364'MDMex. Hole Angle: 2° Well- SCU 323-4 Spud Deta: 4/12/61 Original RKB: 15' Top River Field Wall Type: Injector Leet Werkever: 10/87 Henger:Shaffer Angle @Hemlock :1 ° All D HIO 9 10 11 12 13 15 16 2 3 4 5 6 'D to Top of Equipment. Jewelry 1 9534' 2 9577' 3 9621' 4 9654' 5 9666' ; 9669' 7 10,325' 8 10,361' 9 10,455' 10 10,520' 11 10,525' 12 10,562' 13 10,594' 14 10,627' 15 10,661' 16 10,667' OtLS 'LBX' GLM Baker 'DB" Packer OILs "X" Nipple (I.D. 1.875') OILs Overshot & Packoff OILs "XA' Sleeve (installed upside down) t'~aker "FH" Packer Baker 'FH' packer Otis "S' Nipple, Position ~J Otis 'XA' Steeve (installed upside down) Brown "CC' Safely Joint Baker 'FH' Packer OILS "S' Nipple, Position #4 Brown 'CC' Safely Joint OIls 'XA' Sleeve (installed upside down) Baker'FH' Packer Camco 'D' Nipple Caalng and Tubing 22' 0 28' 11-3/4' 47# J-55 0 1413' 7-5/8' 39# N-80 0 131' 7-5/8' 33.7# N-80 131' 3623' 7-518" 29.7# N-80 3623' 5654' 7-5/8' 33.7# N-80 5654' 6552' 7-5/8' 39# N-80 6552' 10,375' E-~/2' g'~# N-e0 9693' 1¢,770' 3-1/2' 9.3# J-55 0 9622' 2-3~8' 4.7# N-80 9581' 10,700' Perforation Data 10,394'-10,406' H2 12' 4 4/61 10,426'-10,434' H3 8' 4 4/61 10,454'-10,510' H4,5 56' 4 4/61 10,539'-10,621' H8 82' 4 4/61 10,633'- 10,648' H9 15' 4 4/61 10,670'-10,714' H10 44' 4 4/61 Del~rlntlon Conductor Pipe Surface Casing Production Casi; Liner Tubing Tubing PBTD = 10,740' TD = 10,775' RECEIVED JUN 22 1995 Well 0il & Gas Cons. Commission ~ Anchor;~? SCU 323-4 By: JLB 4/12/90 Swanson River Field SCU 323-4 Preliminary Procedure Work-over: Convert Gas Injector into a Tyonek Oil Producer 1. Prepare Location. 2. RU SLU. R1H w/bailer and remove perf debris and CaCo3 on top of PX plug. 3. RHt and retrieve PX plug from X- nipple @ 10,361'. 4 ND flowline. 5. IfPX plug cannot be retri~ MIRU AP1 C'I~. 6. RIH w/1.5" CT and cleanout debris above PX plug. 7. R1H w/sliddine and retrieve PX plug. 8. Kill well w/ 10.2 PPG brine and prepare well for workovcr 9. RUAPRS. Tie-into Pedlog run on May 12, 1995. Cut 2-3/8' TBGat 10,485', 10,320', and 9,670'. 10. Move in rig up Alaska Well 5on/lee Rig #5 as a turnkey move. 11. ND tree and NU BOPE and test BOPE to 250 psi and 5000 psi. 12. ~,rculat¢ 10.2 PPG NaCI brine. Spot Xanvis pill across perfs. 13. POOH w/3-1/2" and 2-3/~" TI3O and Otis overshot. 14. RIH and fish Baker DB packer @ 9,577'. 15. RRt and fish Baker FH packer ~ 9,669'. 16. RIH w/overshot and fish Baker FH packer ~ 10,325'. 17. RIH w/wodcming, casing scraper and dressing tool. Dress off TI3O stub. lg. RIH w/Baker SC2P packer and set isolation packer at 10,350'.. 19. R1H w/Baker F packer plug and install in SC2P pac~.. 20. RHt w/nc-w 2-7/8" TBO and 12 gas lift mandrels and Baker FH packer. 21. Land TI3G and set Packer ~ 9,600'. 22. Remove BOPE and install and test tree to 5000 psi. NU flowlin¢ and gas lift line. 23. RDMO AWS Rig 5 as a turnkey rig move. RU SLU and RIlL Pull standing valve from X-nipple. 24. MWD 323-4PR2.1X~ RECEIVED dUN 22 1995 A[aska Oil & Gas Cons. Commission Anchor~,~ Page: 2 25. 26. 27. 28. 29. 30. 31. 32. 33. Swanson River Field SCU 323-4 Preliminary Procedure Work-over: Convert Gas Injector into a Tyonek Oil Producer MIRU DoweH coiled tubing unit TEST BOPE RIH w/1.5' coiled tubing and displace 10.2 PPG brine inside the casing and tubing with die, el. RDMO coiled TBG unit. MIRU Schlumberger wirelinc unit NU lubricator and test to 5000 psi. RIH w/GR/CCL and 2-1/2' RET Enerjet perf guns. Perforate Tyonek G-2 sands (~ 10267'-10327' and 10342%10357'. RD wireline unit Turn well over to production. MWD 323-4PR2.DOC 6/Xt95 ARCO Alaska, Inc. ~ Post Office Box ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering February 13, 1992 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: From 10/1/91 through 10/9/91 ARCO Alaska Inc. commenced to seal a minor production casing leak and perform a MIT on SCU 323- 4. The operation consisted of filling the PC with inhibited lease water and pressured up with gas until the location of the leak was found. Once this was accomplished a pill was mixed and pumped consisting of two 50# pails of Hypo-Seal. A second pill of 2 drums of ARCO graphite oil was pumped after letting the well stabilize from the first pill. The leak was successfully sealed and the MIT was satisfactorly performed. On 1/14/92 the final testing was witnessed by your State Inspector, Mr. Grimaldi. Please refer to the enclosed attachments for further details of this operation. If you have any questions on this matter, please contact Jim Zernell at 263-4107. Sincerely, d.C. Winn Acting Regional Engineer Attachment cc: Mr. W. Watson Mr.B.C. Dehn Marathon Oil Company UNOCAL Corporation ARCO Alaska, lng. is a SubMdlaw of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ORIGINAL 1. Type of Request: Operation Shutdown ~ Stimulate Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska, Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development __ Exploratory Stratigraphic __ Service X_ Plugging Perforate __ Pull tubing Other X __ MIT 6. Datum elevation (DF or KB) 167' KB 7. Unit or Property name Soldotna Creek Unit feet 4. Location of well at surface 2015' N, 2070' E, SE corner, Sec. 4, T7N, R9W, SM At top of productive interval Straight Hole At effective depth At total depth 8. Well number SCU 323-4 9. Permit number/approval number 91-195 G, I --- O(Y L-3 10. APl number s0-133-10106-00 1 1. Field/Pool Swanson River-Hemlock 12. Present well condition summary Total Depth: measured true vertical 10,775' feet Plugs (measured) 10,775' feet Effective depth: measured 10,740' feet Junk (measured) true vertical 10,740' feet Casing Length Size Cemented Measured depth Structural Conductor 28' 22" Yes 28'MD Surface 1413' 11-3/4" Yes 1413' MD Intermediate Production 10375' 7-5/8" Yes 10375' MD Liner 1077' 5-1/2" Yes 10740' MD True vertical depth 28' TVD 1413' TVD 10375' TVD 10740' TVD Perforation depth: measured 10394'- 10406'; 10426'- 10434'; 10454'- 10510'; 10539'-10621'; 10633'-10648'; 10670'-10714' MD. true vertical 10394'-10406'; 10426'-10434'; 10454'-10510'; 10539'-10621'; 10633'-10648'; 10670'-10714' TVD. Tubing (size, grade, and measured depth) 3-1/2" EUE, 8RD @ 9633' MD; 2-3/8" EUE 8RD from 963Y-10,700' MD Packers and SSSV (type and measured depth) Baker "FH" Baker "FH" Pkr @ 9669', 10324', 10525', 10661' MD RECEIVED FEB " '""" L ~1 IgOc 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure N/A Alaska Oil & Gas Cons. Commission Anchorage 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 33000P/D 0 2000* 5600 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 0 33000P/D 0 2000* 16. Status of well classification as: 5600 Oil Gas Suspended Service Gas Iniector~ · 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title Cook Inlet Regional Engineer Date 'L1//~ -~ )--- * Note: Pressure is being maintained on production casing to assist in" seating" the sealant material. The pressure will be bled off after an indeterminent period of time. ARCO Alaska, In,,. ~ I~l)BldlJy of &tlINIQ IIIl~bftlid SWANSON RI · PRODUCTION P.OI/Oi WELL SERVICE REPOI: " ' IOPEIqATION AT REIN:)IqT TIME ............ 39.5-; -- / ~0, i D OHEoK~H'$ BI. OC~K IF SUMMA~IY GONTINUEO ON' BAOK ,i ~U Oil & Gas Cons. Co[l:~sion Anchorage .,~- . .. HECHANICAL ' 'GRI'IY 1EST Date //--/~-- 9C:~ Company /~Rc O Fie`id · , PRETEST STAR.___[ 15 HIN 30 HIN *P * I TYPE OF PKR CAS I NG TBG REQ TBG T I HE T I HE T I HE START WELL *S - ANNULUS IVD S I ZE/#T/GRADE S I ZE TEST CSG IBG TBG IBG I I HE P F - NNtE *14 *N FLU ID MD : PRESS PRESS CSG CSG CSG PRESS PRESS PRESS 3 ~..oo , 95'7 05'0 o ,5" oo 5'700 5'700 COHHENIS: T"ua, O'P,,a& / Co..t, s. ................................ ,,, . ,, , ,., , . ,, ,., , , ,, ,, , , . , ..... . ,,,, ,.,,,,, . _. ~ ...... , ., ,,., CO~tENI S: ,, , ,, ,, m, ,, , , ,, ..... ,,, , ,, ,, , ,, COIffiENIS: , , . ,. ,,. , *IUBING INJEC11ON FLUIQ4 P = PRODUCE WATER IflJ S = SAL1 WATER INJ H = HISCIBLE INJECllON I = ItlJECTING N = IiOT INJECTIIIG C.O~G (rev 05/10/90] ANNULAR FLUID: GRADIENT: NELL TEST~ DIESEL GLYCOL SALT WATER DRILLING HUD AOGCC WITNESS SIGNATURE COHPANY REP SIGNATURE 1,0-0~-1~1 05:55 00'7 ~ 10BO SW~q$ON RIVER ~JCTION ~. 01/0~ ARCO Alaska, Inc. ~ WELL SERVICE REPORT 8u~tdl~ M AtlBnIIQ Rla~fleld ~Y WELL _ ' IPBDT -- ' I FIELD- OtOT~tC;Y- 8TATL [DAY8 I DATE GONTHAGTOR . --- q IOPEII~TION AT REP08¥ TIME ? ~,L~ .... L "-~_ "-"rue. u't,,~ _ ! ,. RI=MARKS ,FI CHEO'K T~I$ Bk.I~.K IF SUMMARY CONTINUED ON BACK 10-O~-l~l OB: ~ gO? /~-~. 10~0 ARCO Alaska, Ino. ~ 8uOlldllr/of Atllntlo FIIol~fllld ~,OmlDl,'ty WELL IPBDT CONTRACTOR REMARK; BWAN$ON RIVER ~DUCTION P.O1/O1 IFIELD. DI~¥~iOT* STATE " IOPERATION AT REPORT TIME WELL SERVICE REPORT ~;0o -'/78&, · .., ,4.0o lt'oO q. oo r'l oo - i F"] GHEGK THIS BLOCK IF SUMMARY CONTINUED ON BAOK ...... dl · ,- w...-r I,-.,,~ I ,,,,,,...r I V,.,.,,,, ]W,,Vo,. RelX~ ,11 ,Il' mllN I ~0-0~-19~1 0?:0? 90~ ~ 5 10~0 ARCO Alaska, Inc. g) Sul~ldl&ry of Atl~fltto Rlol~flold CA)mpaJ~y WELL ti=BDT CONTRjACTOR SWANSON RIVER ~ODUCTZON P.Oi/O1 WELL SERVICE REPORT OPEflATI~N AT REPORT TIME IDAYB DATE / Z I"1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK _Weelher J Temp. J CNII FJ~ter ] Vlmlblllly I WInd Vel. ~-~, ~.0;~0 SWANSON ~blmlmmml? of Atlmntio Rl~flm~l ~mPmm~ CONTI4AOTOR ~ , ' - IOPEP. AllOjI AT 14F. F(~Rr'i:WE' ,. = ' ,lm , Il i I Ii i i iii n ii iiiii i llUl mi -- - m~ i ii - i i ) i _ i _ II.,_L... , m lU , mi . , __. mm _ i mill, ....... ! , , I 1,1 mt I p u p I I _ 1l _ _1 : -~_-,~-z_ . i mm i ..... Jl CHECK THIS BLOCK, IF SUMMARY CONTINUED ON BACK _W~_thy l l'~p. ~ ~lll Fmdior_) Vl,lbllliy .. I Wlnd Vel: A-05-~ggl 09:42 907 /'-'~ 1030 ~U AIBIK~, lnG' ~ul~Mdllry of Alllntlo PIIohfMld WELL tOPERATION AT REPORT TIME - ., . ~/ ,., ..,..,./,,,,/6,,,, Z /~/~ /'.. ~: ...,- ,.. ~: ,,,~ ._ AI-,,-A ,-,--~ ,~t ~/ .,~_~. ,0,,,,,,,,,,,~ ..... ...... j - ~,~,,.,~__. .-~-0- ' .,"'' - ...... I I .... -~ .,,..,-. /F,--,~:;~ ,z,, x,,.,.,~,~. · - r ' . ~/- I - . .... - ..... W~b: . ~aor~ p .,~. r~l~,,l7 ~ p ' ~ ~t~ ~.e ~.' . ........... r"] GHEGK THIS BLOCK IF SUMMARY CONTINUED ON BACK / / ~ i030 8ul~l(llaq, df~tl&ntlo Rlahfleid WELL ,NTRA~OR IqJjMAFIK8 SWANSON ;~ l VER "DUCT [ ON ;~. 04 [-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK J I 10-~4-$991 1~: ~1 907 ~'"~[)0~0 ARCO AlaSKa, Inc 8ublldllry of Atl&ntl= Rlohfleld ¢a=mpifly WELL ~TRACTOR IPBDT SWANSON R I VER ~OUCT ! ON P. 05 ' 1 FIELD - DISTRICT · STATE IOPE~ATION AT R£PO~i TIME IDA,S I DATE , .... . [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather.___.. !, Temp. I, Chill Faator. I Visibility .. I Wlnd VeL ARCO Alaska, InC. WELL ~ERVICE REPORT DISTRICT-STATE O..AT,O~ AT ~E~T T~M~' /3: 4~) L'"I CHECK THIS BLOCK IF 5UMMAIRY CONTINUED ON BACK wo.,,., t~.m,, lo"'""°'°' I<~"'""tYi w,.~'v.,, I,~.., ,~ RllN~rt ,~ ,e I _,,.. , . I / ' ,., . 10-10-1g@l 0~:01 gO? ~B~ 10~0 ARCO Alask-, Inc. 8ul~ldl-~y of Atlantic Ri~fleld ¢a~ml~m/ WELL CONTRACTOR IPBDT SWANSON R ! VER PRODUCT ! ON JFIELD · DISTRICT, BTATE OPERATION AT REPORT TIME P.O./ii WELL SERVICE REPORT , · _ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ,., i 'lnn,u' , ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering July 5, 1991 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Request for Waiver for Operating SCU 323-4 Gas Injector. Dear Mr. Smith: Please find the attached Sundry Notice requesting approval for ARCO to operate the subject well outside of .the Area Injection Order (AIO) for the Swanson River Field. The production casing on $CU 323-4 was recently tested prior to the scheduled routine MIT according to AIO # 13, Rule #6. The results of the preliminary testing indicated that the well would likely not pass the MIT, or if it did pass, it would be only marginally acceptable. On June 28, as per Rule #7 of the AIO, ARCO contacted Mr. Minder of your office informing him of the condition of the well and requesting verbal approval for continued operations pending the submittal of our proposed plan of corrective action. Mr. Minder allowed one week for ARCO to follow up with our plan. In our plan ARCO is requesting that the well be kept on injection while diagnostics are performed to locate and attempt to seal the leak. Since the leak is very small, and there is no communication with the surface casing which may place the shallow fresh water formations at risk, ARCO feels confident that the well can be operated prudently in its current condition. A procedure has already been implemented in the field whereas the well is monitored continuously via a chart recorder and is checked at least four times per day by field production personnel. RECEIVED J U L - 5 t99t Alaska.Oil .& Gas Cons. Commission Anchorage ARCO Ala~a, lng. is a Sul~dlary of Atla~ttc Richfield Company Mr. L. Smith July 5, 1991 Page 2 The attached Proposed Operations Plan for SCU 323-4 outlines the intended methods for determining the location of the leak, and probable means of sealing it off. In the event the problem cannot be resolved to the point where a satisfactory MIT can be attained a workover will be scheduled and performed as soon as possible to correct the problem. Your office will be contacted in the event that there are any changes in the status of the well. Should you have any questions concerning the proposed operations contact Jim Zernell at 263-4107. Sincerely, T. Wellman Regional Engineer TW:dTZ:czm:0097 Attachment cc: Mr. J. Dygas Bureau of Land Management JUL - 5 1!Ifil Oil & Gas Cons. Commissio~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abando'n _ "" suspend__ "Oporatio'n S~utdown __ Re-enter suspended well __ Alter casing m Repair well _ Plugging_ Time extension _ Stimulate--_ , Change,.aPPr0,ve,d pr,ogra..m __ Pu,!.!. tubin, g =- variance _ Perforate .._ Other X 2. Name of Operator ' 5. Type of Well: 6. Datum elevation (DF or KB) Development ARCO Alaska,, Inq ...... Exploratory _ 167' KB fe~t 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anch..orage,,AK 9951.0 .... Se, rvice _~X Soldotna Creek Unit 4. Location of well at surface 8. Well number 2015' N and 2070' E from SE corner, Sec. 4, T7N, RDW SCI, I 323-4 At top of productive interval 9. Permit number Straight Hole At effective depth 10. APl number 50-133-1 0106-00 At total depth 11. Field/Pool ~,~li~N~r~~ck 12. Present well condition summary K'~ ~ E I VE Total Depth: measured 10,775 feet Plugs (measured) true vertical 10,775 feet JUL - 5 1991 Effective depth: measured 10,740 feet Junk (measured) true vertical 1 0,74 0 feet ~!a,~g~ 0Ii & Gas .Cons. C0mm'tss't0~ ncti0rage Casing Length Size Cemented Measurecr~l~pth True vertical depth Structural Conductor 28' 22" yes 28' MD 28' TVD Surface 1,41 3' 1 1 -3/4" yes 1,413' MD 1,413' TVD Intermediate Production 10,375' 7-5/8" yes 10,375' MD 10,375' TVD Liner 1,077' 5- 1/2" yes 10,740' MD 10,740' TVD Perforation depth: measured 10,394'-10,406'; 10,426'-10,434'; 10,454'-10,510'; 10,539'-10,621'; 10,633'-10,648'; 10,670"10,714' MD true vertical 10,394'-10,406'; 10,426'-10,434'; 10,454'-10,510'; 10,539'-10,621'; 10,633'-10,648'; 10,670'-10,714' TVD Tubing (size, grade, and measured depth 3-1/2" DUE 8RD @ 9,633' MD; 2-3/8" DUE 8RD from 9,633'-10,700' MD Packers and SSSV (type and measured depth) Baker "FH~ 9,669'~ 10~324',. 10~52,5', 10,661'' MD 13. Attachments Description summary of proposal ~ Detailed operation program _. BOP sketch _ 14. Estimated date for commencing Operation 15. 'status of well classification as: July, 1991 Oil __ Gas Suspended m 16. If proposal was verbally approved Name of approver Date,appr. oved Service -X ~(Gas Injector) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~tned '"T"[,U~~ , T. itle Co.ok In.!et..Regional Engr. Date FOR COMMISSION USE ONLY Conditions oi approval: Notify commission 'so r'~Pmsentative may witness IApproval No. Plug integrity BOP Test _ Location clearance I ¢3'! - ! Mechanical Integrity Test _ Subsequent form require 10- "-"" / ! ORIGINAL SIGNED BY~.1/~,7/ Approved by the order of the Commission : .. LONNIE C, SMITH Commissioner Date -] Form 10-403 Rev 5/03/8'9 ' App_r0.v_e~ ~upy ' SUBMIT II ~ TFTIPLICATE PROPOSED OPERATIONS PLAN FOR CONTINUED OPERATION OF SCU 323-4 .purpose: The purpose of this plan is to: 1- Outline a procedure for continued gas injection, 2- Discuss diagnostics procedures for locating the leak, and 3- Consider methods for sealing off the leak. Histo~ry: SCU 323-4, a gas injector, was worked over in 1987 to correct a production casing leak which, at the time, was believed to be at the packer. Following the workover the well was returned to service. In June of 1988, the well marginally passed a MIT with a pressure drop of just less than the permitted maximum of 10% in 30 minutes. In June 1991 a test was performed on the production casing in preparation for a routine MIT on the well. The test showed that the pressure drop after 30 minutes was 10% of the test pressure indicating that well would either fail the test, or if it did pass the MIT, it would only be marginally acceptable. Plan for Continued Operation: The well will be kept on gas injection under the following criteria. , A chart recorder will be placed on the production casing and tubing to provide for continuous monitoring. , The well will be checked and pressures recorded at least four times per day (twice per shift). , Any changes in the well operating conditions will be reported immediately to the Production Supervisor, the AOGCC, and the BLM. e _. In the event that tubing to production casing communication is detected the well will be shut in immediately and the Production SUpervisor, the AOGCC and the BLM notified. RE'¢EIVED JUL - § 1991 Alasf~.Off ,& Gas Cons. Commission Anchorage SCU 323-4 Page 2 II. III. Diagnostic Procedures: Procedures will be under taken to determine the source of the leak in the production casing. A temperature survey in combination with a noise log will be used in attempt to determine the location of the leak. Preliminary procedure- 1. Set plug in 'X' nipple below the top packer @ 9,621'. . Load the tubing with lease water. Allow the well to remain static for 24 hours for the temperature to stabilize. 3. Run a base line temperature survey to 9,600'. . Bleed off the production casing (PC) pressure to determine if it results in continuous flow from the PC. e If the PC flows a reasonable amount of fluid, re-run the temperature log to determine the location of the leak. . If the PC does not flow, rig up to pump down the PC while running the noise log to determine the location of the leak. Maintain a constant positive pressure on the PC to provide a continuous movement of fluid through the leak. . Re-run the temperature survey to confirm the findings of the noise log. . Report the findings to the Production Supervisor, the AOGCC, and the BLM. Remedial Procedure to Seal Leak: Procedures will be undertaken using proven techniques to attempt to seal the leak. The procedure will be dependent on the results of the Noise and Temperature Logs. The following represents a possible means of sealing the leak. RECEIVED d U L - § 199] ~a~rgi,.oil & Gas Cons. commission 'Anchorage SCU 323-4 Page 3 Preliminary procedure- , With a plug set in 'X' nipple below the top packer @ 9,621', pull the DV from the GLM @ 9,534' and replace it with an orifice with the check valve removed. Load the well with lease water. e Mix up a pill using lease water with 20 to 30#/bbl Litesal. Actual volume to be determined by the depth of the leak. 3, Pump the pill into the production casing taking returns out of the tubing. , Pump down the tubing and take returns out of the PC. Choke back the returns on the PC to maintain 3,500 psi of surface pressure to squeeze off the leak. 5. Repeat steps 3 and 4 as required. , Perform the MIT as required in the AIO # 13 and return the well to routine service. , If the well does not pass the MIT begin planning a rig workover to repair the well. Injection operations will continue until the workover is commenced unless the condition of the well has changed requiring it to be shut-in. RI]'¢EIVED JUL - 5 t991 ,Oil & Gas Cons. Comrnissiol/ ~nchorage UNIT BOUNDARY-~ r---~ I I I I t--.J I I I I I I--.----1 I I I I I o o _1 CENTER 1 FAULT .LOCK./ o '"1 I I I I I I I 8CU I IFAULT BLOCK1 r-J I I I I I I I SWANSON RIVER FIELD STRUCTURE MAP HEMLOCK FORMATION RECEIVED UL - 5 199! Gas Cons. Commission Anchorag~ Well- sou 323-4 Spud Date: 4/12/61 Original RKB: 15' Top of Hemlock:10,364'UDMax. Hole Angle: Arcc - ,laska Inc.- Swanson RivE ield APl#' 133-10106-00 Well Type' Injector Completion Date' 6/1/61 Last Workover: 10/87 Hanger Type' Shaffer Hanger:Shaffer 2° Angle @Hemlock :1° All D, RKB I~ H2,$ H8 HIO 2 3 4 5 6 9 10 11 12 13 14 15 16 ID to Top of Equipment. Jewelry I 9534' 2 9577' 3 9621' 4 9654' 5 9666' 6 9669' 7 10,325' 8 10,361' 9 10,455' 10 10,520' 11 10,525' 12 10,562' 13 10,594' 14 10,627' 15 10,661' 16 10,667' Otis "LBX" GLM Baker "DB" Packer Otis "X" Nipple (I.D. 1.875") Otis Overshot & Packoff Otis "XA" Sleeve (installed upside down) Baker "FH" Packer Baker "FH" Packer Otis "S" Nipple, Position ~5 Otis "XA" Steeve (installed upside down) Brown "CC" Safety Joint Baker "FH" Packer Otis "S" Nipple, Position #4 Brown "CC" Safety Joint Otis "XA" Sleeve (installed upside down) Baker "FH" Packer Camco "D" Nipple Casing and Tubing 22" 0 28' 11-3/4" 47# J-55 0 1413' 7-5/8" 39# N-80 0 131' 7-5/8" 33.7# N-80 131' 3623' 7-5/8" 29.7# N-80 3623' 5654' 7-5/8" 33.7# N-80 5654' 6552' 7-5/8" 39# N-80 6552' 10,375' 5-1/2" 20# N-80 9693' 10,770' 3-1/2" 9.3# J-55 0 9622' 2-3/8" 4.7# N-80 9581' 10,700' Perforation Data Interval Zone FT SPF Date 10,394'-10,406' H2 12' 4 4/61 10,426'-10,434' H3 8' 4 4/61 10,454'-10,510' H4,5 56' 4 4/61 10,539'-10,621' H8 82' 4 4/61 10,633'- 10,648' H9 15' 4 4/61 10,670'-10,714' H10 44' 4 4/61 RECEIVED Descri~3tion Conductor Pipe Surface Casing Production Casing Liner Tubing Tubing PBTD = 10,740' ,JUL -§ 1991 Well SCU 323-4 TD = 10,775' ~0JJ& Gas Cons. Cemmissiu, By: JLB 4/12/90 ~ N~chorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering May 29, 1991 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached is an Application for Sundry Approval :$ur-;cy on SCU 323-4 to comply with UIC Rule No. 6 to test tubing- production casi~g .,integrity. '~"-':-~--------:-:--:-.--,----.---i_T'~*--~"m~'-.~_::.-.:.~::-.'~ .-.~::-.'.-.~ .~..~.~::~_.~ ~ ............... ,___ a3_atyressures~in'-trle-t-uDing/proouction, - casing annulus candid-be obtained. If you have any questions on this matter, please contact David A. Pursell at 263-4258. Sincerely, T. Wellman Regional Engineer TW:JKW:czm:0070 RECEIVED MAY 1 1991 Alaska Oil & Gas Cons. Commission Anchorage Attachment cc' Mr. W. Watson Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ~ " 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 __ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 99510 Pull tubing __ Variance _ 5. Type of Well: Development ~ Exploratory _ Stratigraphic _ Service _ 2015' N and 2070' E from SE corner, Sec. 4, T7N, Rgw At top of productive interval Straight Hole At effective depth At total depth 12. Present well condition summery Total Depth: measured 10,775 true vertical 1 0,775 Effective depth: measured 10,740 feet Junk (measured) true vertical 1 0,7 40 feet Casing Length Size Cemented Structural Conductor 2 8' 2 2" yes Surface 1,413' 1 1-3/4" yes Intermediate Production 1 0,375' 7-5/8" yes Uner 1,077' 5-1/2" yes Perforate __ Other X I M I T ~ 6. Datum elevation (DF or KB) 167' KB 7. Unit or Property name Soldotna Creek Unit 8. Well number ~CU 323-4 9. Permit number feet RECEIVED 10. APl number J~0-133-10106-00 MAY ;5 1 t99t '~'~. Field/Pool Swanson River/Hemlock Alaska 0il & Gas Cons. Co[nm'ts ~tu~'~lr /~o~J,~ oi< feet P~red) ~~, feet Measured depth True vertical depth 28' MD 28' TVD 1,413' MD 1,413' TVD 10,375' MD 10,375' TVD 10,740' MD 10,740' TVD measured 10,394'-10,406'; 10,426'-10,434'; Perforation depth: 10,539'-10,621'; 10,633'-10,648'; 10,670'-10,714' MD true vertical 10,394'-10,406'; 10,426'-10,434'; 10,539'-10,621'; 10,633'-10,648'; 10,670'-10,714' TVD Tubing (size, grade, and measured depth 3-1/2" EUE 8RD @ 9,633' MD; 2-3/8" EUE 8RD from 9,633'-10,700' MD Packers and SSSV (type and measured depth) Baker "FH" 9,669'~ 10~324'~ 10,525'~ 10~661' MD 13. Attachments 10,454'-10,510'; 10,454'-10,510'; Description summary of proposal _ Detailed operation program X BOP sketch 14. Estimated date for commencing operation J 15. Status of well classification as: June. 1991 I Oil __ Gas Suspended 16. If proposal was verbally approved Name of approver Date approved Service X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance . 7 - Mechanical Integrity Test Subsequent form require 10- + /14 7- . Approved bi/the order of the Commission 0RII31NAL SIGNE0 BY Fnrm 1n-4n.3 R.v .~/n.3/R.cl LONNI~: C. SMITH Title Cook Inlet Regional En~ir. IApproval No. /~pproveCt CoPY Returned Commissioner Date (~ '- j g-9'l RI IRMIT IN TRIPl IC. ATF Well SCU 323-4 MIT. SR 244 Ob_tective Load SCxPC annulus & PCxtbg annulus and verify mechanical integrity. Current Status SRU 323-4 is on gas injection. Pressures: TP 5680 psi PC 280 psi SC 7 psi Procedure Load SC and PC RECEIVED MAT 1 t999 Alaska OJJ & Gas Cons. t;ommissiori Anchorage 1. Record pressures on the tubing, production casing, and surface casing. 2. Shoot fluid levels on PC and SC. . Bleed and Load SC and PC with lease water containing 0.25% WT676 corrosion inhibitor and a 5 bbl crude cap. Do not exceed 300 psi on the SC when pumping. NOTE · The PCxtbg annulus was full (WSR 1-5-91) and should not require much loading. The annulus is loaded with 10.1 ppg brine with a crude cap (WSR 7-19-87). Also, the SCxPC annulus should be full (WSR 11-28-88). 4. Contact the Anchorage office to verify that sundry approval has been obtained before proceeding. . 24 hours prior to initiating testing procedure, contact the AOGCC and the BLM to inform them that a pressure test will be conducted as per Rule 6 of Swanson River Field Area Injection Order No. 13. Pressure Test Production Casing 1. Install a 2 pen chart recorder to monitor tubing and tubing x production casing pressure. Inject into tubing at usual rate. 2. Pressure production casing to 2000 psi. Hold for 5 minutes, observing pressures on the tubing, production casing, and surface casing. 3. If no significant pressure change (>50 psi) within 5 minutes, increase production casing pressure by 500 psi. Hold for 5 minutes. . Repeat Step #3 until a pressure of 3525 psi is reached. Hold pressure for 30 minutes, noting initial/and final pressure on all strings. '. Arco Alaska Inc. -Swanson River Field Well- $¢u 323-4 APl#: 133-10106-00 Well Type'lnjector Spud Date: 4/12/61 Completion Date' 6/1/61 Last Workover' 10/67 Original RKB: 15' Hanger Type: Shaffer Hanger:Shaffer Top of Hemlock:10,364'MD Max. Hole Angle: 2° Angle @Hemlock '1 ° Ail D, RKB I~ . H2.3 H4,5 H8 H9 H10 2 3 4 9 10 11 12 13 14 15 16 ID to Top of Equipment. Jewelry I 9534' 2 9577' 3 9621' 4 9654' 5 9666' 6 9669' 7 10,325' 8 10,361' 9 10,455' 10 10,520' 11 10,525' 12 10,562' 13 10,594' 14 10,627' 15 10,661' 16 10,667' Otis "LBX" GLM Baker "DB" Packer Otis "X" Nipple (I.D. 1.875") Otis Overshot & Packoff Otis "XA" Sleeve (installed upside down) Baker "FH" Packer Baker "FH" Packer Otis "S" Nipple, Position ~ Otis "XA" Steeve (installed upside down) Brown "CC" Safety Joint Baker "FH" Packer Otis "S" Nipple, Position #4 Brown "CC" Safety Joint Otis "XA" Sleeve (installed upside down) Baker "FH" Packer Camco "D" Nipple Casing and Tubing 22" 0 28' 11-3/4" 47# J-55 0 1413' 7-5/8" 39# N-80 0 131' 7-5/8" 33.7# N-80 131' 3623' 7-5/8" 29.7# N-80 3623' 5654' 7-5/8" 33.7# N-80 5654' 6552' 7-5/8" 39# N-80 6552' 10,375' 5-1/2" 20# N-80 9693' 10,770' 3-1/2" 9.3# J-55 0 9622' 2-3/8" 4.7# N-80 9581' 10,700' Perforation Data Interval Zone FT SPF Date 10,394'-10,406' H2 12' 4 4/61 10,426'-10,434' H3 8' 4 4/61 10,454'- 10,510° H4,5 56' 4 4/61 10,539'-10,621' H8 82' 4 4/61 10,633'- 10,648' H9 15' 4 4/61 10,670'-10,714' H10 44' 4 4/61 Descrir~tion Conductor Pipe Surface Casing Production Casing Liner Tubing Tubing MAY ) 1 t99t Alaska Oil & Gas Cons. Core.ss'tot 'Anchorage PBTD -- 10,740' TD = 10,775' Well scu 323-4 By: JLB 4/12/90 STATE OF ALASKA ALASKA OIL AND GAS cONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOCi 1. Status of Well Classification of Service Well OIL ~ GAS [~ SUSPENDED ~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 3. Address 8. APl Number P.0. Box 100360, Anchorage, AK 99510-0360 50- 133-10106 4. Location of well at surface 9. Unit or Lease Name 2015' FSL, 2070' FWL, Sec. 4, T7N, RgW, SW Soldotna Creek Unit At Top Producing Interval 10. Well Number 2015' FSL, 2070' FWL, Sec. 4, T7N, Rgw, SW SCU 323-4 At Total Depth 11. Field and Pool 2015' FSL, 2070' FWL, Sec. 4, T7N, Rgw, SW Swanson River - Hemlock 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 167 'I A-028997 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 04/12/61 05/22/61 06/01/61' N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. DirectionalSurvey ! 20. Depth where SSSV set I21.Thickness°fPermafr°st 10775'MD/TVD 10740'MD/TVD YES [] NO [] Nonefeet MD --- _ 22. Type Electric or Other Logs Run lES, Sonic, DIL, Cal, CBL, GR/Neutron, CCL 23. CASING, LINER AND CEMENTING RECORD . .. SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 22- .... Surf 43, __ C. nn.~r,.q~on C_mt. .... 11-3/4" 47.0# J-55 Surf 1413' 16" 7-5/8" 3 .0/33.7/29.7# N-80 Surf 10375' 10-5/8" 1_~{3o _~x £]m~ c. .... 5-1/2" 20.0# N-80 9693' 10770' 6-1/2" 150 sx Class 24. Perforations open to Production IMD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/4 spf 3-1/2"/2-7/8" 9658' 9577 10394'-10406'MD/TVD 10426'-10434'MD/TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 1 0454 '-10510'MD/TVD ,DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10539' -10621 'MD/TVD N/A 10633 ' -10648'MD/TVD 10670 ' -10714 'MD/TVD 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 6/6/61I F1 owing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 6/1/61 2 TEST PERIOD I~ 1608 250 0 16/64"I 6.4 Flow Tubing Casing Pressure CALCULATED Jl~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 1600 1550 24-HOUR RATE 847 190 9 36.1 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core data previously submittedJ E EJVE ) * WorkoVers performed 11/24/62 & 10/23/87 ;~iaska,.Oil & Gas Cons. C0mmissim~ ' ;a~ch0rage Form 10-407 012/WC6 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. N/A NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, OOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS None I hereOy certify that the foregoing is true and correct to the best of my knowledge Titl~rea Drilling Engr. Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. !tern 16 and :24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (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. ~':~:~- ~ 'i-?-i?· ~"~.,'~e-! ~r~.i _:,~ ~;': ,~r~!~: .~i~' !::!~;,.vi~',?, ~;~:~..:; !..i~';.', i:~,'-.-'~:i .,"':~!'~, ~"i',~.'d:' ~.~'.'.: ~.:~:~-~, !~.:.~,;:.,"..,'~-',i~! ', ,;! ~:.~:' ADDENDUM WELL: SCU 323-4 (SWANSON RIVER) 10/24/87 10/25/87 RU wireline, tested lubricator to 4000 psi. RIH and open XA sleeves. Pulled dummy valve f/GLM. Bail fill from top of plug in D nipple. Pulled prong and plug. RD wireline. RU Halliburton and tested lines to 2000 psi. Displaced well to crude in reverse circulation. RD. Shut well in w/1500 psi. Installed dummy valve in GLM. RU wireline, test lubricator to 300 psi, RIH and set dummy in GLM, POOH. RD. Cleaned up well pad and storing equipment. Well shut-in w/1200 psi. ' ' DriVing Super~-lF~r Date ADDENDUM WELL' 10/16/87 SCU 323-4 Attempt to pressure test casing, test failed. RU WL. Test · lubricator to 3500 psi, ok. RIH & pull prong f/plug in S-5 nipple @ 10357'. RIH & pulled plug f/S-5 nipple @ 10357'. GIH & close XA sleeves @ 10627', 10455, & 9666'. POOH. RIH w/CA plug, got stuck in sleeve @ 9666'. POOH. Running tool swiveled off. Fished running tool and pulled plug. GIH and open XA sleeve @ 9666. POOH. RIH w/CA plug & set same in "D" nipple @ 10667'. POOH. RD WL. Secure well. Rig up Gearhart. Test lubricator to 1000 psi w/well pressure, ok. GIH w/1-11/16" chemical ~cutter. Cut 2-3/8" tubing @ 9644'. POOH. RD Gearhart. Secure well. D~ 1 i ng Sqg__~vi sor / D6te STATE OF ALASKA ' "~ ALAS/-'~'OIL AND GAS CONSERVATION COM ~%,SION REPORT IJF SUNDRY WELL OPERATIONS ~ , 1. Operations performed: Operation shutdOwn [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other ~ Mechanica I Integrity Test 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 157' KB Feet , '3. Address 6. Unit or Property name Post Office Box 100360 Anchorage, AK 99510 Swanson River Field 4. Location of well at surface 2,0t5' N and 2,070' E frOm SE corner, Sec. 4, T7N, R9W 7. Well number SCU 323-4 At top of productive interval Straight Hole At effective depth At total depth 8. Approval number 8-490 9. APl number 50-- 133-10106-00 10. Pool Hem lock 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 28 ' Surface 1,413 ' Production 10,375 ' Liner 1,077 ' Perforation depth: 10,394- 10,714' 10,775' 10,775' 10,740' 10,740' Size 22" 11-3/4" 7-5/8" 5-1/2" feet feet feet feet Plugs (measured) Junk (measured) Cemented Measured depth True Vertical depth Yes 28' 28' Yes 1,413' 1,413' Yes 10,375' 10,375' Yes 10,740' 10,740' Tubing (size, grade and measured depth) 3-1/2 EUE 8RD 9,633'; 2-3/8 EUE 8RD 9,633 - Packers and SSSV (type and measured depth) Baker "FH" 9r669'r 10,324', 10,525', 10,661' 12. Stimulation or cement squeeze summary Intervals treated (measured) N/A 10,700' Treatment description including volumes used and final pressure 13. Representative Daily Average~i~YOt Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 38,162 250 5,400 Subsequent to operation 36,494 400 5,400 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ,:~¢~.¢' ~ ~;~:,.~ Signed .~ bJ~z----- Title Sen i or Area Eng i neet Date Form 10-404 Rev. 124'-85 Submit in Duplicate JUL-01-'88 0?:53 ID~ ARCO Alaska, Inc. 8ul~lgJiary of Atlantic I~chfield Ccmp~my W~..LL PBDT .ZZ~- '/ COI~TRACTOR REMARKS TEL i~IE'I.D - DISTRIG'T- 6'TATE OPERATION AT REPORT TIME ~627 P02 ~ WELL SERVICE REPORT 7.E.s. = ~¢,~o'~ [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK M/,,,,Ath~H, ITel'lift I ~hill Kmnlfl4, I Villbllilv l Wifld Vii. ARCO A~aSka, Ir~c. Post Office Bo:< !00360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering June 21, 1988 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: 1987,88 UIC Pressure Testing - Swanson River Field Wells SCU 312-9, SCU 341-4, and SCU 323-4 Dear Mr. Chatterton: Attached are Application for Sundry Approvals to pressure test three subject injection wells in compliance with the Swanson River Field Area Injection Order No. 13. These three pressure tests comply with the requirement to test 25 percent of the gas injection/water disposal wells each year. All efforts will be made to complete testing by June 30, 1988. Sincerely, Tom Wellman Senior Area Engineer TW:MLE:ch:0009 Attachmems cc: J.A. Dygas, Bureau of Land Management J. Coltart, Chevron USA D. Jones, Marathon G. Graham, UNOCAL 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 [] PressL Time extensiOn [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other ~ Test 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360 . Anchorage, AK 99510 Location of wellatsurface 2015' N & 2070' E from SE corner, Sec. 4, T7N, R9W 5. Datum elevation(DF or KB) KB 167' 6. UnitorProperty name Swanson River Field 7. Wellnumber SCU 323-4 feet At top of productive interval Straight Hole At effective depth At total depth 8. Permit number 9. APl number 50-- 133- 10106-00 10. Pool Hemlock · Present well condition summary Total depth: measured true vertical 1 O, 775 ' feet Plugs (measured) 10,775 ' feet Effective depth: measured true vertical Casing Conductor Surface Production Liner Perforation depth: 10,394 - 10,406'; 1-,648'; 10,670 - 1 O, 740 ' feet Junk (measured) 1 O, 740 ' feet Length Size Cemented Measured depth True Vertical depth 28' 22" yes 28' 28' 1,413' 11-3/4" yes 1,413' 1,413' 10,375' 7-5/8" yes 10,375' 10,375' 1,077' 5-1/2" yes 10,740' 10,740' 10,426 - 10,434'; 10,454 - 10,510'; 10,539 - 10,621'; 10,633 - 10,714'. RECEIVED ~bing(size, grade and measured depth) 3-1/2 EUE 8RD 9,633'; 2-3/8 EUE 8RD Packers and SSSV(type and measured depth) Baker "FH" 9,669' 10 324' 10 525' ' , , , , 12.Attachments 9,633 - 10,700'. JUN 2 3 988 10,661 '. Alaska 011 & Gas Cons. Commission Description summary of proposal [] Detailed operations program II'Ill, ketch [] 13. Estimated date for commencing operation TestinB to be completed by. 7/1/88. 14. If proposal was verbally approved SuT)soque~ ~Vo~'~,~ ~,,e~o~ed on _ ~ Name of approver ~o~o/~~te~~~ Date approved 15, I hereby certify that the foregoing is true and oorrect to the best of my knowledge Signed ~ ~~' Title Senior Area Engineer Date Commission Use Only Conditions of approval Approved by so representative may witness Notify commission [] Plug integrity [] BOP Test [] Locatjo_n clearance Approved Dopy Returned LONNIE C. SMITH Oommissioner Approval NO. ~;~-3._/_/,~ ¢ by order of the commission Date ~'] ,~- )~:~:::~z~ re Form 10-403 Rev 12-1-85 Submit in triplicately' SCU 323-4 Loading . 2. 3. 4. . , LOAD PRODUCTION AND SURFACE CASING AND PRESSURE TEST PRODUCTION CASING RECEIVED PC and SC Annulus JUI~ 2 25 1988 Alaska .Oil & Gas Cons. Commission Record pressams on thc tubing, production casing and sm'~acc casing. Anchorage Blow down PC to 1,000 psi, recording all pressures. Blow down SC, recording all pressures. Shoot fluid levels for pump-in volumetrics. (Annular capacity (Bbl/ft.): SC = 0.0699, PC = 0.0326). Load SC with lease water containing 10 gal./100 Bbls WT 676 corrosion inhibitor and a 5 Bbl crude cap. Do not exceed 300 psi surface pressure during pump-in. Monitor all pressures. Load PC with lease crude. Do not exceed 2,500 psi during pump-in. Do not bleed PC below 1,000 psi during pump-in. Pressure NOTE: NOTE: . . 10. 11. Testing Production Casing 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. During pressure tests of production casing, closely monitor PC/SC packoff to insure no communication to the surface casing. If any communication is noted, cease pressure test and notify Engineering in town. Install two pen chart recorder for tubing and production casing. Inject into tubing at usual rate. Pressure test PC/SC packoff to 3,000 psi. Pressure production casing to 2,000 psi. Hold for five minutes, observing pressures on tubing, production casing and surface casing. If initial pressure is already at or above 2,000 psi, proceed to Step 10. If no significant pressure changes occur within five minutes (>50 psi), increase production casing pressure by 500 psi. Hold pressure for five minutes. Repeat Step 10 until a pressure of 3,525 psi is reached. Hold pressure for 30 minutes, noting initial and final pressure on all strings. ii K.B. TO ¢~OU~O LEYE~ ,i,4 Il' 0~.-6,96J' 356 JTS. J'/a* EUE 8,,0 TUBING .~669.ZT._~OTIS"XA" SLEEVE UPSIOE OO~VN BAKER FH PACKER STRAIGHT PULL 9;Zl .$1 ~ .96~.T'TCPLiNER 21 JTS. Z~' EUE 8no T:JBlltC ;48.63 ~ ~ ---10,3~4.e2'~ BAKER'FH"PAC~ER STRAIGHT PULL 5~00 ~.Oa' j ., / I JT. Z~' EU[ 8.o TualrtC ~ ~: ---10,]61.23'~ OTIS "S" rIIPPLE ~5(~ I.SZ': : ~ j -10,4~5.20 ~OTtS'XA' SLEEVE UPSidE O0',v~ ~0~) 2.aT' I /~5 ~ / Z jTs. 2~ EUE 8,o TUBING ol I I '10'5' 9'67' ~ 6RO'~N "CC" SAFETY JOINT 1.4t' -~ _,[ PUP JT Z~" EUE 8.0 TU91~IC 4.07' I ~ I,oe., / ;~?~ ~ ~ ~" 'IO,594-52'~RO'WN'CC'SAFETY JOINT 1.41' ; I I l,oea,' I ~ .,. ~ : . ~ ~ ~ .... ~,~-~,~9AKER 'FN" PACF, ER STRAIGHT ;~LL 5C,000 ._ ~ [ ] -- ' ,u,~,.o3 ~CA:4CO 'O" ~tlPPLE (~M~) nr~cl~lC~ ( ~g g,o.o.. ....... ,1 , jT~"EUE8~TBG 9AKERSHE~RS'~9 3l" ". ,o,,o I Gas ns Commission ~ - ,o T75 o~' Z 0 ~ ~ "' ' '' I SECTION 4,T. 7".,".~ W. I / I Chevron U.S.A. Inc. Wells under Evaluation for Rate Potential 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 TABLE I Wells being Evaluated for P&A/Future Uti 1 i ty 212-10 21-15 31-15 34-15 432-15 312-22 212-27 14A-33 12-34 22-23WD 243-8 14-34 Wells SI for Inefficient Producti on 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until B1 owdown 43A-15 314-27 331-27 ~'343-33 ARCO Alaska, Inc.t 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 work'over to repair a packer leak. Of the seven gas injection wells tested, only one (Well SCU 323-4) did not meet the criteria stated in Rule 6 of the AOGCC Area Injection Order No. 13. the remaining six wells held their calcu- lated test pressure (within 10%) for 30 minutes. The test pressure for each well was calculated to generate a differential pressure gradient across the casing of 0.25 psi/ft at the vertical depth of the uppermost packer. The surface pressures in Well SCU 323-4 have stabilized at acceptable levels (PC +1500 psig, SC +100 psig). We will be retesting this well for integrity in the near future. AOGCC and BLM representatives will be notified 24 hours in advance of this test, should they wish to be onsite. Until that time, we propose to continue injection into this well. If you need additional information, please contact H. F. Blacker at 263-4299. Very truly yours, JCH:JWR:cI:0004 Attachments cc: Mr. Joseph A. Dygas - Bureau of Land Management ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. ~ WELL SERVICE REPORT /~o / ~,~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~)o~ ATTACHMENT E=I Injection Well Data Water Disposal. Wells SRU 31-33W SRU 32-33W SRU t+1-33W SRU 21-33W scu/+3- w ¢ Avg. Rate(BPD) 3278 651 125 2805 Max. Rate(BPD) 8500 #500 8500 85'00 8500 Avg. Press(psi) 769 778 913 735 Shut In Max. Press(psi), 1000 1000 1000 1000 1000 Depth of Inj.(tt.) 2100 2100 2- 82 2.1.2_.0 3100 Depth of Well(ft.) 2~61 2520 3000 ' 3_~0.5~ 6660 Gas Injection Wells Ave. Rate(MCFD) Max. Rate(MCFD) SCU 31-/+-2 SCU 32-3-Q 'SCU 332-t+ 3/+1-8 U 31-2-9 SCU 321-9 scU 323-9~ SCU 3~$3-33 SRU 332-15 SRU 312-22 SRU 31/+-27 SRU 331-2_7 l~ 39,950 35,680 27,6/+0 37,6#0 30,300 29,9/+0 35,920 0 0 0 0 0 /+5000 /+5000 /+5000 /+5000 ~5000 /+5000 ~5000 #5000 ~5000 /+5000 ~5000 /+5000 /+5000 e otc 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 1039~ 10/+70 10226 10256 10183 1029~ 10280 10695 11388 1075~ 111~6 1080~ 11520 10775 11119 10850 1081# 10785 107/+5 10750 10995 11982 11000 11~3~ 11620 -R- ARCO Alaska, Inc. 110500 ALASKA OIL AND SAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAO 25.252 SWANSON RIVER FIELD - UNIT 051950 August 1987 o9-Sep-87 Name of Operator Field and Pool Month and Year of Injection ~1. WELL NO. 514-4 525-4 352-4 341-4 541-8 312-~ 323-~ 1545-53 1412-I0 321-~ 143-4WD 2. API NUMBERIS. 50- 153-10104-00 133-10106-00 155-10107-00 155-10109-00 155-10120-00 155-1'0125-00 135-10126-00 135-10168-00 153-20206-00 135-10125-00 135-16)111-00 4. FIELD & POOL CODE 772100 772100 772100 772100 772100 772100 772100 772100 772100 772100 5. DAYSI TUBING PRESSURE I CASING PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION IN I I I 1 OPER 16. MAXI7. AVERAGEI8. MAXIg. AVERABEI10. LIQUID Ill. BAS I 13. LIQUID I 14. GAS 772056 I PSIS I PSIB I I · 50 15,450 I 0 I 0 1 30 15,500 I 5,005 50 15,550 I 5,141 0 I 0 I 0 50 15,550 I 4,945 50 15,500 I 4,928 0 I 0 I 0 0 I 0 I 0 .50 15,450 I 4,991 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 PSIB I PSIB I (BBL) I CMCF) I (BBL) I (MCF) I I I I ~ I I I 4,958 15,300 0 0 1,040 2,8&0 0 I , 240 2,&O0 0 0 I, 960 0 ' ' . , . . , ' ' 2,559 I I 39,239 I I 1,177,1&5 0 I I 0 I I 65& I I .51,632 I I 948,955 2,376 I I 37,120 I I 1,1 0 I I 0 I I 0 1 lv109 I I 40,485 I I 1,214,475 2~.5~B I I .55~14B I I 1,054~42B 0 I I 0 I I 0 0 I I 0 I I 0 1 1~815 I I 25~706 I I 771,182 0 I 0 I I I I I I I I I I I I I I I I I I I I I I .I I I I I I I I I | I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I l I I I II hereby certify that the foregoing is true and correct to the best of my knowledge I I I Date 115. I I I I I I I I I I I' I I I I I I I I ITOTAL I 0 I 6,279,814 I I Submit in Duplicate Form 10-405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION .REPORT 20 AAC-~5. 252 ARCO Alaska, Inc. 110500 Name o{ Operator SWANSON RIVER FIELD - UNIT 051994 Field and Pool August 1987 Month and Year of Injection WELLI2. API NUMBERI5. CI4. FIELDI5. DAYS1 TUBING PRESSURE ! CASING PRESSURE IDAILY AVERAGE INQECTIONITOTAL MONTHLY INJECTION 1 NO. ~ 50- I LI & POOL I IN ~ ~ ~ I 1512-22 1155-10147-00 IG ~ 772100 1514-27 1155-10154-00 ~G I 772100 1551-27 I135-10156-00 :G I 772100 1432-15 |155-10141-00 IG I 772100 I - I I ~ I 1 ~21-55WD~155-101&2-00 ID I 77205& 151-53WD1135-20556-00 ID I 772056 ~52-55.WD1155-10164-00 ID I 772056 141-55WD1155-10167-00 ID I 772056 I 50 I 850 I 751 I I I 145 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ~ I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I i I I I I ...... I I Al CODE I OPER 16. MAXI7. AVERAGE18. MAXI9. AVERAGEIIO. LIOUID Ill. GAS SI I I PSIG I F'SIG I PSIG I PSIG I (BBL) I (MCF) SI I___ I I I I I II hereby certify that the ~oregoing is true and correct to the best of my knowledge 115. I I lSigned '~¥~2, 2~ I I I I I ITitle ~'~£ ~'~ ~,~¢~...~.~ Date ~/,~'"/'7 ITOTAL I INSTRUCTIONS ON REVERSE SIDE Form 10-405 Rev. 12-1-85 15. LIQUID I 14. GAS I (BBL) I (MCF) I I I 77,581 80,518 62,119 4,552 224,570 Submit in Duplicate PRUDHOE .B~ UN I T S- 11 PRUDHOE ~UNIT S-14 PRUDHOE ~' UN IT T-1 PRUDHOE B'A'Y UN I T T'7 PRUDHOE BAY UNIT U-3 PRUDHOE BAY UNIT U-4 PRUDHOE BAY UNIT PRUDHOE BAY UNIT U-9 PRUDHOE BAY UN I T U-.lO PRUDHOE BAY UNIT X-6 PRUDHOE BAY UNIT X-11 PRUDHOE BAY UN I T X-23 PRUDHOE BAY UNIT X-24 PRUDHOE BAY bNIT X-26 PRUDHOE BAY UNIT Y-3 PRUDHOE BAY UNIT PRUDHOE BAY UN IT Y-6 PRUOHOE BAY UNIT Y'7 PRUDHOE BAY UN I T Y- 11RD PRUDHOE BAY UN I T Y-18 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL SNANSON RIVER, HEHLOCK O ARCO ALASKA INC SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK'UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT .......... SOLDOTNA CK UNIT SOLDOTNA CK UNIT I L POOL 323-4 332-4 341-4 341-8 312-9 321-9 323-9 412,10 343-33 UNIT OR LEASE TOTAL 264,425 174,467 380,162 602,357 515,072 264,751 183,322 244,173 294,661 149,980 173,544 262,057' 282,344 76,492 49,131 84,323 22,223 43,679 306,429 14,519,526 39,536,156 84,445,002 39,536,156 88,810,140 SOLDOTNA CREEK UNIT SHUT-IN SHUT-IN 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 1,148,650 31 1,080,598 31 871,402 31 1,090,670 31 153,799 6 1,246,967 30 749,378 31 1,089,518 31 7,430,982 7,115,160 1,241,472 2,275,741 2,727,957 2,791,476 2,551,632 1,790,980 1,767,557 6,174,166 5,618,096 3,530,342 5,273,083 3,169,181 3,942,403 1,968,753 2,653,403 102,640 597,32t 6,4O9,296 1,388,876 294,742,9'15 233,327,280 207,759,340 231,764,932 218,694,647 304,044,302 33.033,842 170,911,513 111,413,676 ALASKA INDIVIDUAL NELL PRODUCTION FOR HARCH, 1987 - - ENHANCED RECOVERY - - NELL NAM[ AND NUMBER ARCO ALASKA INC SNANSON RIV UNIT 331-27 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL TRADING BAY, MICDLE KENAI C OIL POOL UNION OIL CO CF CALIFORNIA AOL-18731 TRADING BAY ST. A-SRO-2 TRADING BAY ST A-12RD TRADING BAY ST A-26 TRADING BAY ST A-29 UNIT OR LEASE TOTAL POOL TOTAL TRADING BAY, MICDLE KENAI 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 FIELD.TOTAL OIL(BBL) ~rl'R|BBL) S~/ANSON RIVER UNIT SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN GAS(MCF) DAYS 7,430,982 7,430,982 CUM. OIL CUM. WATER 15.582,616 4,498,822 6,267,061 7,3~8,68~ 21,618,136 CUM. GAS 28,263,659 ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.252 ARCO Alaska, Inc. 110500 Name of Operator SWANSON RIVER FIELD - UNIT 051~4 Field and Pool December 1~8& Month and Year of Injection 11. WELL:2. API NUMBERI5. C~4. FIELD:5. DAYS~ TUBING PRESSURE I CASING PRESSURE :DAILY AVERAGE INJECTION~TOTAL MONTHLY INJECTION : I NO. I 50- I LI & POOL I IN I I I I I I I I Al CODE I OPER I&. MAXI7. AVERAGE!8. MAXI~. AVERAGE!lO. LIQUID Ill. GAS I 13. LIQUID I 14. GAS I I I SI I I !___SI I I~12-22 11~-10147-00 I G I 772100 I 314-27 1135-10154-00 I G I 772100 I ~i:~i.:~,~1-27 115~-1015&-00 I G I 772100 I '.~:1452-15 1155-1014.1-00 I G I 772100 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 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 t I I l I I I I I I I I I I I I I I I I I I I I I PSIS I PSIS I PSIS I PSIS I (BBL) I (MCF) I (BBL) I ...... I I ...... I I I I - I I I I I I I I - I I I I I I t I - I I I I I I I I .- I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I. I I .I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I . I I I I I I I I I I I I I I I I t I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I Ir~. ~'~I~1-'- I I II I I I I I I II I I I I I I II I I I ...... , : , :. jAN20 ;'I I I I I Alasi~a Oil & Gas C .... . ...... ~mssion II hereby certif~ that the forego~i~ng is true and correct to the best of my knowledge ! ¢ .' I Si gned - --'~"~"- - --~-X- ................... i SupI, vi.~~e. Ventures Compliance and ~evenue ~~, I Title .... Da~e ............. I ~orm 10-405 Rev. 12-1-85 INSTRUCTIONS ON ~EVE~SE SIDE (MCF) I I15. I ! :. Anct:,ora?-: ! I I I I I I I I I I I I I I I TOTAL I 0 I 0 I I I I I Submit in Duplicate I I I I I I I I I t I I I I I ! ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAO 25.252 ARCO Alaska, Inc. 110500 Name of Operator SWANSON RIVER FIELD - UNIT 051950 Fi eld and Pool December 198& Month and Year of Injection :1. WELL NO. ! I 514-4 : 525-4 *-1 532-4 ::~?L') 341-4 541-8 312-9 323-9 t412-10 I 321-9 I I I I I I I I I I I I ..-'. _.. I I I I 2. API NUMBERIS. CI4. FIELDIS. DAYSI TUBING PRESSURE I CASING PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION 50- I LI & POOL I IN I I I I S'I l___SI 133-1.0104-00 IG I 772100 I 155-10106-00 IG I 772100 1 153-10107-00 IG I 772100 1 155-10109-00 IG I 772100 I 153-10120-00 IG. I 772100 1 153-10125-00 135-1012&-00 155-10168-00 155-20206-00 155-10125-00 18 I I I I I I I Al CODE I OPER 16. MAXI7. AVERAGEI8. MAXIg. AVERAGEIIO. LIQUID 111. GAS I (BBL) I (MCF) I .... I PSIG I. PSIG I PSIG I PSIG I I I ...... I 50 15,500 I 5,013 12,500 I 1,560 I I 32,501 30 15,650 I '5,278 15,250 I 1,976 I I 29,526 30 15,500 I 5,071 I 700 i 594 I I 24,058 50 15,550 I 5,137 11,200 I 849 I I 29,951 30 15,500 I 4,882 11,400 I 1,548 I I 23,121 I 772100 I 30 15,000 I 4,697 12,850 I 1,267 I I 55,165 772100 I 17 15,200 I 5,140 11,600 I 1,388 I I 25,530 772100 I 0 I 0 I 0 I 0 I 0 I I 0 772100 I 0 I 0 I 0 I 0 I 0 I I 0 772100 I 50 15,540 I 5,150 11,600 I 1,¢)89 I I 20,970 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I · I I I I I I I I I I l I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 15. LIQUID I 14, GAS I (BBL) I I (MCF) 975,018 885,785 721,153 898,524 695,626 054,878 I 430,602 I 0 1 0 1 629 ~091 I I I I I I I I I I I I I I I I I I I I I I ' ' ' ' ' I I I I I ~ I I I II hereby certify that ttL~ :or,going is true.and correct to the best of my knowledge ,, ISigned . , I I per ITitle Date .... I Yo~m 10-405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE I 115. I I I I I I I TOTAL I I A .....~'~ I I I' I I I I I I I I 0 I 6,288,655 I I Submit in Duplicate LEASE NO. JENHANCED RECOVERYJ COHP.DATE + + STATUS PRODUCT JAN FEB HAR ~~ SHANSON RIVER, HEHLOCK ARCO ALASKA INC $OLOOTNA CK UNTT 514-4 UNIT051950 0IL ALASKA INDIVIDUAL HELL%ODUCTION FOR 1986 YEAR APR HAY JUN JUL AUI~ SEP OCT NOV I}FC TOTA[ CHH. 08/15/60 HTR i$INJ GAS 1055857 1026590 1189909 1165806 1228646 1211657 1257286 1288552 1505704 1125075 1022955 975018 15808655 291785545 SOLDOTNA CE UNYT 923-4 AP! UNZT051950 OI'L 06/01/61 HTR GINJ. OAS 9'26806 895793 1014489 1021515 1093847 1095954 1110742 1160265 1163222 986837 950909 885783 12305942 230168773 SOL~OTNA C[ UNTT ' ~2-4 APT ]~-]n~n7-no UNIT051950 OIL 06/05/60 HTR -' iOINJ OAS 729520 694699 694'207 SOLDnTNA CK UNTT ~41-6 APT l~-~n]nq-nn r UNIT051950 OIL ' 05/21/60 HTR 1GINJ GAS 964182 959897 1105510 1004702 1191650 1125433 1151894 1167267 1142665 989567 1047597 898524 12728466 228845715 SOL~OTNA CK UNTT ~41-g APT 1~-1017n-~ · UNIT051950 OIL 07/14/61 HTR 1OINJ GAS 772050 721011 855765 795562 858795 851801 877466 885~19 861~54 802085 790782 695626 9761772 21711~26~ $OL~OTNA CK UNiT ~l?-q AP! UN[T051950 0IL 10/09/60 HTR 1GINJ GAS 1130860 1105246 1275~68 1219454 1266462 1242821 1268188 1318592 1312222 1120413 1139677 105~878 14454281 30078~345 $OLDOTNA CK UNTT 521-q AP~ 1~3-10125-0§ UNIT051950 OIL 07/19/61 HTR 1GINJ GAS 787999 770786 941516 857121 859651 824009 859794 852454 865441 701058 657884 629091 9546564 51111753 SOLDOTNA CE UNiT 325-9 APT 1~-1012~-00 UNIT051950 0IL 07/17/61 HTR 1GINJ GAS 868162 887705 1057404 1002092 SOLDOTNA CK UNIT ~]2-10 APT UNIT051950 OIL 06/11/72 HTR ° 1HINJ GAS SOLDOTNA CK UNIT UNIT051950 OIL 03/08/61 HTR 1GINJ GAS · ., SNANSON R~V.UN[T UNIT051994 OIL 10/2~/59 HTR ' 1GZNJ GAS SHANSON RZV UNIT UNIT051994 OIL 08/04/6! HTR 1GZNJ GAS m im 432-]5 34-15 AP! 133-1016~-00 API 133-10141-00 AP! 133-10142-00 138887~,~) 111413676 6018206 9029539 2056925 4643530 II! !!1 LEASE NO.. IENHANCED RECOVERYI COMP.DATE + + STATUS PRODUCT JAN FER MAR ALASKA INDIVIDUAL HELL~ODUCTION FOR 1986 ~~ SWANSON RIVER, HEMLOCK SWANSON RIV UNIT 512-22 UN~.TOB]99~ OIL YEAR · APR MAY JUN JUL AUg REP OCT NOV DEC TOTAL CUM. API 135-10147-00 08/11/62 HTR 873988 1GINJ .GAS 24017269 SWANSON RIV UNIT 514-27 API 153~10154-00 UNITOS]Og40~L 06/lq/60 HTR 1GINJ GAS 78332178 SWANSON RIV UNIT 551-27 API 133-10156-00 UN']T051gg~ OIL 02/17/58 HTR - 1GINJ GAS 28265~ ,~/ · - ARCO ALASKA INC -oPERATOR 0IL TOTALS HATER 8,337,995 GAS 7,041,527 7,852,406 8,187,302 8,680,226 7,499,819 6,288,655 1,929,187,012 7,215,396 8,113,868 8,369,~49 8,393,451 8,667,789 7,311,775 93,601,663 POOL SWANSON RIVER, HEMLOCK TOTALS OIL , HATER 8,357,995 OAS 7,041,527 7,852,406 8,187,502 8,680,226 7,499,819 6,288,655 1,929,187,012 7,215,396 8,115,868 8,569,449 8,393,451 8,667,789 7,511,775 95,601,665 FIELD SWANSON RTVER TOTALS OIL . HATER 8,337,995 ~ ,, OAS 7,041,527 7,832,q06 8,187,302 8,680,226 7,499,819 6,288,655 1,929,187,07 ~ 7,215,396 8,113,868 8,369,449 8,393,451 8,667,789 7,311,775 95,601,663 .,~ SWANSON RIVER WELL ~ I~/Bo __ SRU 312-2~ ~'~ 8'~ -- SRU 314-2-7 51 ~]Sf <_~._ SRU 331-2'7 ~ S~CU 323-4 iSCU 332-4 ~ SCU 341-4 ~ SCU 341-8 .~ SCU 312-9 - SCU 321-9 ~ SCU 323-.9 5~ /~/~ -SRU 432-1.5 TYPE GaS Inj Gas Inj Gas Inj Gas Inj Gas Inj Gas Inj Gas Inj Gas Inj Gas Inj Gas Inj Water I ector ector ector ector ector ector ector ector ector ector njector STATUS AS OF 1/1/88 Shut-in Shut-in '-' Shut-in Injecting Injecting Injecting Shut-in Injecting Injecting Injecting Shut-in GRU13/2c RECEIVED F E ~ 2 5 "'~'.'.' ?. Alaska Oil & Gas Con~. Commission Anchorage ~ A_RCOAlask~, Inc. ARCO Alaska, Inc.: Post Office Bu^ 100360 Anchorage. Alaska 99510-0360 Telephone 907 265 6369 John C. Havard Engineering Manager Cook Inlet/New Ventures July 14, 1987 Mr. C. V. Chatterton Alaska Oil& Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Re: Swanson River Unit: Gas Injection Well Production Casing Pressure Tests Dear Mr. Chatterton.' Attached are seven (7) Well Service Reports documenting the results of the recent pressure tests conducted on Wells SCU 314-4, SCU 323-4, SCU 332-4, SCU 341-4, SCU 312-9, SCU 321-9, and SCU 323-9. The other active gas injection well, Well SCU 341-8, is currently loaded with kill weight fluid in anticipation of a late-September workover to repair a packer leak. Of the seven gas injection wells tested, only one (Well SCU 323-4) did not meet the criteria stated in Rule 6 of the AOGCC Area Injection Order No. 13. The remaining six wells held their calcu- lated test pressure (within 10%) for 30 minutes. The test pressure for each well was calculated to generate a differential pressure gradient across the casing of 0.25 psi/ft at the vertical depth of the uppermost packer. The surface pressures in Well SCU 323-4 have stabilized at acceptable levels (PC +_1500 psig, SC +_I00 psig). We will be retesting this well for integrity in the near future. AOGCC and BLM representatives will be notified 24 hours in advance of this test, should they wish to be onsite. Until that time, we propose to continue injection into this well. If you need additional information, please contact H. F. Blacker at 263-4299. Very truly yours, JCH:JWR:cI:0004 Attachments cc: Mr. Joseph A. Dygas - Bureau of Land Management ARCO Alaska. Inc ~s a Subs~dlar~ of AtlantlcRichfieldComloar~y SWANSON RIVER INJECTION 7-27-87 Results of Casing Integrity Testing Status of SCU 323-4 Current Gas Injection Surveillance Program Discussion of Rule 5 - Reporting the Tubing/Casing Annulus Pressure Variations Water Injection Well Testing SWANSON RIVER UNIT GAS INJECTION WELL CASING INTEGRITY TESTS Date Well 6/20/87 SCU 314-4 6/24/87 SCU 323-4 7/20/87 SCU 323-4 6/24/87 SCU 332-4 6/20/87 SCU 341-4 6/20/87 SCU 312-9 6/20/87 SCU 321-9 6/24/87 SCU 323-9 * 20-minute bleedoff ** Well loaded with lO.1 ppg brine *** Tubing SI and loaded with lO.1 brine Production Casing Test Pressure Production Casing 30-Minute Bleedoff 3750 3520 8ooC ) 3790 3630 3700 3700 3715 0 psi (0%) 360 psi (10.2%)* 305 psi (16.9%)** llO psi (2.9%) 170 psi (4.7%) 150 psi (4.1%) 100 psi (2.8%) 255 psi (6.9%) Tubing Injection Pressure 5550 psi 5260 psi 1800 psi***~' 5200 psi 5150 psi 5425 psi 5425 psi 5200 psi (JWR: cl: 0005) Well 323-4 Recent History Comments 2/12/87 Packoff Integrity Test Tested TBG Hanger PO to 2500 psi for 15 min. OK. Tested PC/SC PO to 1500 psi for 15 min. OK. 3/11/87 Fluid Level 4/8/87 Packoff Integrity Test Tested TBG Hanger PO to 6000 psi for 15 min. OK. 6/24/87 State Integrity Test 7/1/87 SC Bleed 7/10/87 SC Bleed 7/11/87 Fluid Level 7/16/87 Set Plug in TBG 7/17/87 Circ. 10 ppg brine 7/18/87 Set Plug in ~ 7/18/87 Circ. 10 ppg brine 7/19/87 PT PC & TBG 7/19/87 PT TBG Pressured PC to 3525 psi. Bled off 360 psi in 20 min. TBG Hanger PO increased from '0' to 2850 pal. SC pressure increased from '0' to 190 psi. Bleed off all pressures after test. Bleed SC from 150 to '0' psi. Bleed SC from 100'to '0' psi. PC - 3658' wi 1580 psi. sc- O'w/25p~. Attempt to set plug in Nipple at 10,361 ', no good. Set TBG plug at 10,120'. Could not circulate well. Suspect 'I'BG plug leak. Close 'XA' Sleeve and PT tubing. No good. Pull plug from 10,120. Set plug in Nipple at 10,361' (schematic shows pos. #3, really pos. #5). Total of 345 bids used. Final Pressure: PC- O, SC- O. Pressured PC to 1850. Bled off 250 psi in 20 min. Repeat test, Bleed off 355 psi in 30 minutes. Close 'XA' Sleeve. Pressure TBG to 2500 psi. Bleed off '0' psi in 30 minutes --> Plug set. RECOMMENDATION; Leave well shut in with 10 ppg bdne in the TBG and the PC annulus. Monitor fluid levels and surface pressures until workover economics can be completed. Notify State with appropriate Sundry Notices. Estimated rate loss from lack of injection in this well is about 375 BOPD. 7/21/87 JWR 1 114. l Il' ~.fili.dO' -- ---oJJlS.II' -- .t111' Ill LIIII ItlIIG IAISIIL -- -il.iii.it' - I .' ! ~ l IS. SI I.tl' I " i =:%t% i ,, -~.so4Jl'- SSG JIG. $¥ CUE I,o TUliKG ~-(z'6' I~') l&'t0x ,z%'ltlJz I JT. I~j" CUE leo filling - IriS'lA" SLEEVE tPSIOE 11 JtS. I~' lie to~ Tiling ---Il.Iii. il'---) IAt~I'FN'PACIE! StlalGllt PILL / .I JO. liE' lUE leo tiling --*!O.3Gl J5'-.~,. OTIS So UlfPL[ fei,oPen J(~K Il.ltl' I JTS. 1¥I~il I~ tJlllC I Jtl. I~'IUl I~ TUIIK .JlJll 'CC' li~jtt JEllS I JT. 2~ E~E IN Tiling O%IS ~' IIPPL[ PostS,on 4 I JT. Z~'EUE Iff TOtinG ~ II011 'CC' SAFETY JOINT I JT. ZYEUE I# Tiling -IS,SILl/'- ~OTIS *lA' SLEEVE UPSIO[ SOWN tlllJl I.IS I.I1 G4I.G.~ lO.l! l · Gl.It 1.4I 4.0~ I.l! 30.4:_ i.S.~ 31.~2 1.4 3f 3! Z.12 i ess, o' I JT. IS' Ell[ IN TJttlIG t~ -IS.fit.IS'- ~IAKER 'F#' PACKER STRAIC~T PULL ~,~O ~o ~. j -- -so.ils.si' ~ I Jl. I~' EWE k TK lull SNE:I , '".'"' * S.C.U. - ' ' --~. CASING & TUBING DET~L ~ --lt. tl~.l~' T.I. J Cherts, U.S.A. Inc./t SWANSON RIVER GAS INJECTION SURVEILLANCE Monitor and record daily tubing pressure, production casing pressure and surface casing pressure on all gas injection wells. Weekly verify accurate pressure readings on all strings with calibrated pressure gauges.. Shoot fluid levels as necessary to determine downhole pressures in the production casing and surface casing annulus. Weekly verify fully functional and non-leaking tree valves. Actively evaluate data on a daily basis to insure continuous safe operations. Perform diagnostics as appropriate to insure sufficient understanding of well bore condition. Respond to unsatisfactory conditions by taking immediate remedial action. Area In~ection Order No. 13 Hatch 16, 1987 Page 3 Rule 2 Authorized Injection Stra,~a for Disposal Within the affected area non-hazardous oil field fluids may be injected for the purpose of disposal into strata defined as those strata which correlate with strata found in the Swanson River Unit well SRU 32-33 between the measured depths of 2100 feet and 3460 feet. Rule 3 Fluid In_iection Wells The underground injection of fluids must be: 1) through a well permitted for drilling as a service well for injection in conformance with 20 AAC 25.005; 2) through a well approved for conversion to a service well for injection in conformance with 20 AAC 25.280; or 3) through a well that existed as a service well for injection purposes on the date of this order. Rule 4 MonitorinK.the Tubin$/Casin~ Annulus Pressures, The tubing/casing annulus pressure of each injection well must be checked weekly to ensure there is no leakage, and that it does not exceed a pressure which will subject the casing to a hoop stress greater than 70I of the casing's minimum yield strength. 'Rule 5 Reportin~ the Tubing/Casin~ Annulus Pressur.e Vartat,ions Tubing/casing annulus Pressure va~iations _of more than 200 psi between consecutive pressure read~ngs madW when in~ecting under steady state conditions of fluid temperature, rate, and pressure must be reported to the Commission on the first working day folloWing the observation. Rule 6 Demonstration of Tubing/Casing Annulus Mechanica,.!,, A schedule must be developed and coordinated with the Commission which ensures that the tubing/casing annulus for each injection well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi, or, assuming a 0.465 psi/ft geo-pressure gradien:, a surface pressure that imposes a differential pressure gradient acress the casing of 0.25 psi/ft at the vertical depth of the packer, whichever is greater; but not to exceed a hoop stress greater than 70Z of the casing's minimum yield strength. The test pressure must be held on the tubing/casing for 30 minutes with no more than a 10Z decline. The Commission must be notified SWANSON RIVER FIELD DISPOSAL WELLS WELL SRU 21-33 WD SRU 31-33 WD ~ SRU 32-33 WD SRU 41-33 WD SRU 43-4 MD TYPE Water Disposal Water Disposal Water Disposal Water Disposal Mud Disposal EXPECTED TEST COMPLETION DATE 9-1-87 9-1-87 9-1-87 9-1-87 9-1-87 (WMP:cl :0026) STATE OF ALASKA AL, ~A OIL AND GAS CONSERVATION CO. ,IISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other j~ WORKOVER 2. Name of Operator ARCO Alaska, Inc; 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2015' FSL, 2070' FWL, Sec. 4,. T7N, At top of productive interval 2015' FSL, 2070' FWL, Sec. 4, T7N, At effective depth 2015' FSL, 2070' FWL, Sec. 4, T7N, At total depth 2015' FSL~ 2070' FWL~ Sec. 4~ T7N~ R9W~ SM 11. Present well condition summary Total depth: measured 10775'MD true vertical 10775'TVD Effective depth: measured 10740'MD true vertical 10740'TVD Rgw, SM Rgw, SM R9W, SM feet feet feet feet Datum elevation (DF or KB) RKI~ 167' Feet Unit or Property name Soldotna Creek Unit 7. Well number SCU 323-4 8. Approval number 7-560 9. APl number 50-- 133-10106 10. Pool Swanson Ri vet Fi el d-Heml ock Plugs (measured) None Junk (measured) None Casing Length Size Conductor 28' 22" Surface 1398' 11-3/4" Production 10360' 7-5/8" Liner 1077' 5-1/2" Cemented Measured depth Constructi on cmt 43'MD 1000 sx Class G 1413'MD 1500 sx Class G 10375 'MD 150 sx Class G 9693'-10770'MD True Vertical depth 43 'TVD 1413 ' TVD 10375 'TVD 9693 ' -10770'TVD Perforation depth: measured true vertical 10394'-10406' 10633'-10648' 10394'-10406' 10633'-10648' , 10426'-10434', 10454'-10510' , 10670'-10714' , 10426 ' -10434 ', 10454 ' -1051 O' , 10670'-10714' , 10539'-10621', , 10539'-10621 ', Tubing (size, grade and measured depth) 3-1/2"/2-7/8", N-80/J-55, tbg w/tail @ 9658' Packers and SSSV (type and measured depth) DB pkr @ 9577' & SSSV: none 12. Stimulation or cement squeeze summary RECEIVED NOV 2 N/A Intervals treated (measured) Treatment description including volumes used and final pressure. Alaska 0il & Gas Cons. Commission Anchorage 13. Representative Daily-Average Production or Inj, ection Data N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Wor~kover Wel 1 History) Daily Report of Well Operations _~ Copies of Logs and Surveys Run [] that the foregoing is true and correct to the best of my knowledge 15.1 hereby certify Signed ~o~ ~~.)~.." Title Associate Engineer Date (Dani) SW03/13 Form 10-404 Re~ 12-1-85 Submit in Duplicate ~.~ a as Compan Well History - Initial Report- Dally · f ratl Instmotlefls: Prepare and submit the "Initial Reps "o Wednesday after a well is spudded or workover operations are started. Dally work prior to sPudding should be summarized on the form giving inclusive dates only. North Slope Borough [ Alaska Alaska Lea~e or Unit Well no. Field Swanson Creek ADL #028997 323-4 Auth. or W.O. no, [Title AD6056 ! Recompletion R011'n: 5.,: ":~' · Operator IARCO W.I, Prior statue If a W.O. 0830 Hfs. ,_ [0/21/87 [0/22/87 [0/23/87 '10~.667 '.D-Nip,e, WaiC on adapter-flange PPg N~'::::jl.;~' ~ ~cep,t,~r!l:,@i (1830 hfs, 10/18/87. Kill well. BO~.' Wa~t on flanse. ND tree. ACc to 5½" @ I0,770" 10,667' D'Nipple, POOH. w/3~" cbg 9.:7 ppg NaCZ ND tree', NU & tst NOPE. Pull tbg hgr to flr, circ hole & POOH w/3~' tbs. 5½" @ 10,770' 10,667' D Nipple, NU. BOPE 9.7+pp$ NsC1 Fin POH. RU WL, rn GR/JB to 96~', POH, RD Gearhart. ;IH, sat BP @ 9607', tst csg. PU RTTS, set RTTS & scorn vlv 2' below wellhead, ND NOPE. Chg out wellhead. NU BOPE. 5½" @ 10,770' 10,667' D Nip~li~P~, 9.7+ ppg NsC1 NU & tst ~OPE,~?~:~ll SS$?'&':RTTS, circ, POOH, LD BP. RIH w/OS, latch onto.tbsstub'~ set pkr & tst to 2000 psi. Rel E/pkr, POOH, LD 3~" 5½" @ 10,770' .... 10,667* D Nipple, ND NOPE 9.7+ ppg NsC1 POOH, LD 3~" tbg. RU & RI~ w/LBX GLH on 3½" tbg, locate in pkr. PU hsr& lnd tbg. Tst pkr to 2200 psi f/30 sin; OK. BOPE. IDate 11/12/87 ITM Drilling Supervisor ' · ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District ]County or Parish /State Alaska North Slope Borough Alaska Field ILoase or Unit I Woll no. Swanson Creek ADL ti028997 323-4 Auth. or W.O. no. ~Title AD6056 [ Recompletion Roll'n 5 API Operator I A.R.Co. W.I. ARCO Alaska, Inc. 12% Spudded or W.O. begun Date Workover 10/18/87 Iotal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I our [Prior status If a W.O, 0830 Hrs. [ Date and depth Complete record for each day reported as of 8:00 a.m. 10/24/87 5½" @ 10,770' 10,667' D Nipple, RR 9.7+ ppg NaC1 ND BOPE. NU &tst tree to 8000 psi. RR @ 1815 hfs, 10/23/87. RECEIVED ?,!?-%?, Oil & ~as Cons. Commissi(:,i~ Anchoraqe Old TD New TD I PB Depth I Released rig Date ~Kind of rig 1815 Hrs. 10/23/87 I Rotary Classifications (oil, gas, etc.) i Type complet on (single, dual, etc.) Oil Single Producing method Official reservoir name(s) FlOwing Swanson Creek Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oi'l on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct 11/12/87 Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, ARCO Alaska, Inc. Post Office Box 100360 Ar~chorage, Alaska 99510-0360 Telephone 907 276 12!5 Cook Inlet/New Ventures Engineering "August 19, 1987 Joseph A. Dygas, Branch Chief United States Bureau of Land Management Post Office Box 230071 Anchorage, Alaska 99523 Dear Joseph: Attached is a Sundry Notice requesting approval to temporarily abandon 39 wells in the Swanson River Field for'a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.4, paragraph C of the Bureau of Land Management Regulations. All 39 of the wells mentioned in the attached Sundry Notice are expected to be shut-in for a period of at least 30 days. The 39 wells listed in Table #1 were identified during our recent review of the status of all wells in the Swanson River Field. These wells have been put into four categories- 1. Evaluate for rate potential 2. Evaluate for plug and abandon/future utility 3. Shut in - inefficient production 4. Shut in - save for blowdown Wells. in Categories #1 and #2 are currently under evaluation to determine their final disposition. Wells in Categories #3 and #4 are wells with little short-term usefulness, but wells that do have some long-term utility. If you have any questions about this Sundry Notice request, please contact me at 263-4299. Sincerely, H. F. Blacker Regional Engineer Cook Inlet/New Ventures HFB: JWR' ch' 0006 Attachment cc: C.V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission Form 3160--5 {November 1983) (Formerly 9--331) UNITED STATES susm? (Other lustraetloua au re- DEPARTMENT OF THE INTERIOR BUREAU OF LAHD MANAGEMEIqT~ SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~e this form for proposals to drill or to deepen or plug back to I difEerent reservoir. Use "APPLiCATION FOR PERMITs" for such pr~iMMML) OIL ~ GAS ~ OTHBa WELL waLL ._. Soldotn~ 2. lq&MB Or oPaaAToa ARCO Alaska, Inc. 3. ADDIgaa Ol' OI~IIATOI P. 0. Box 100360 Anchorage. AK 4. LOCATIO~ Or WeLL (Report location clearly and ~ a~eordanee with any State requtrements, e See also space 17 b~low.) Form approved. Budget l~uteau No. 1004--0135 Expires August 31, 1985 §. LI&II DlllON&?lOll AND IIllIL IIO. O. Ir llll)lAIl. ALLOt'rS! Oil TtlBB llAMa 7. Ulll~ AOIIBMaMT llAMa , Creek%Swanson River Unit 0. w~..r. 10. fieLD illD POOL. OI WILDCAT Swanson River Field At sq~a~ Soldotna Creek Unit - 15 Swanson River Unit - 22 wells 14. Fan,sT ~0. [ 16. a~VA~O~a (S~w whether D~. ~. ~ cie.) i ~enai I Alaska 16. Check Appropriate Box To Indicate Nature o[ Notice, Report, or Other Data NO'rlCB o~' INTBNTIOlq TO: iBUBIBiJUBJl~ BBI~O~ O~ e. FRACTURe` TREAT MULTIPLB COMPI.ET~ rBAC'TUBB TRBATMIlll~ . ~RINO 8ROOT OR ACID~B ABAN~Ne SHYING OR ACIDI~I~O REPAIR WaLL CHANGE PLAN8 (Other) (N~B: Re,ri resul~ of m~ttplo ~mpleUon on W~ (Other) Temporarily a~andon .~. Completion or R~mpsetton Rein and ~W tom.) ~7. DESCRIUE pROPOSED OR CO~IPLETED 0PERATIO~ (Clenrl7 state ~11 pertlneltt details, and ~ive ~rttnent dateL Ineludl~ Hflmat~ da~ of o~W an~ propos~ work. ~f w~l h di~tion~y driH~, five s~e l~tions and mensur~ and true vertl~ dept~ for ~1 markeu and Mn~ neat ~ ~is wor~) * As desc:~bed ~n the attac~ed memo, ~C0 A~aska, ~nc. :squeals the status o~ the fo[~ow~ng we~s be changed to Tempo:a:~[~ Abandoned. SOLDOTNA CREEK UNIT SWANSON RIVER UNIT SCU 13-3 SCU243-8 SRU212-10 SRU 23-22 SCU12A-4 SCU 13-9 SRU 34-10 SRU 22-23WD SCU 13-4 SCU12A-IO SRU 14-15 SRU212-27 SCU323-4 SCU343-33 SRU 21-15 SRU314-27 SCU43A-4 SCU 14-34 SRU 31-15 SRU 23-27 SCU 24-5 SCU 14-3 SRU 432-15 SRU331-27 SCU 33-5 SCU23B-3 SRU 34-15 SRU 34-28 SCU341-8 SCU 34-4 SRU41A-15 SRU14A-33 SCU21A-4 SRU43A-15 SRU 24-33 SRU312-22 SRU 12-34 SRU 21-22 SRU 21-34 18. [ hereby certif~y._tb, at the for. fwotng~/$/~te and correct ~ IG 1%~1~ ' .// .,~ -. ~ - ................... (This space for Federal or State office use) APPROVED BI' CONDITION8 OF APPROVAl,, LF ~: TITLm DATB *See InMn~'tions on Revere Side Title 18 U.S.C. Section t00t, makes it a crime for any person knowingly and willfully to make to any department or agency of the .......... t ___d..t ...................... *.,,6;..e me t~ m,qu mmttme within its Jurisdiction. TABLE 1 Wells under Evaluation for Rate Potential 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 Wells being Evaluated for P&A/Future Uti 1 i t~ 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 Production 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI unti 1 B1 owdown 43A-15 314-27 331-27 343-33 %. . STATE OF ALASKA ALA,,,~A OIL AND GAS CONSERVATION CO~,..alSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate [] Other [] 2. Name of Operator ARCO Alaska, Inc 3. Address P. 0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2015' FSL, 2070' FWL, Sec. 4, T7N, Rgw, SM At top of productive interval 2015' FSL, 2070' FWL, Sec. 4, T7N, Rgw, SM At effective depth 2015' FSL, 2070' FWL, Sec. 4, T7N, RgW, SM At total depth 2015' 5. Datum elevation (DF or KB) RKB 167' 6. Unit or Property name Soldotna Creek Unit 7. Well number SCU 323-4 8. Permit number N/A 9. APl number 50-- N/A 10. Pool FSL, 2070' FWL, Sec. 4, T7N, RDW, SM Swanson River Fi eld-Hemlock 11. Present well condition summary Total depth: measured 10775 'MD feet true vertical 1 0775 ' TVD feet Plugs (measured) None Effective depth: measured 1 0740'MD feet true vertical 1 0740 ' TVD feet Casing Length Size Junk (measured) None Cemented Measured depth True Vertical depth Conductor 28 ' 22" Surface 1398 ' 11 -3/4" Producti on 1 0360 ' 7-5/8" Liner 1077 ' 5-1/2" Construction cmt 43 'MD 43'TVD 1000 sx C1.G 1413'MD 1413'TVD 1st stage 500 sx Cl.G 2nd stage 1000 sx Cl .G 10375'MD 10375'TVD 150 sx C1.G 9693'-10770'MD 969~'-10770'TVD Perforation depth: measured 10394'-104.06', 10426'-10434', 10454'-10510' true vertical 10394'-10406', 10426'-10434', 10454'-10510' Tubing (size, grade and measured depth) 3-1/2" N-80 to 9634'; 2-7/8" N-80 to 10700' Packers and SSSV (type and measured depth) Baker FH's ~ 9669'~. 10325'; 10525'. 12.Attachments Description summary of proposal 13. Estimated date for commencing operation September 16, 1987 , 10539'-10621 ' , 10539'-10621 ' 10633'-10648', 10670'-10714 0633 ' -10648 ' 10670 ' -10714 RECEIVED Deta i I e ~j~¢~ i(Jn ~.~,0~ ram [] Alaska 0i', & Cas UUl uUlillillO~lUll Anohora~e BOP sketch 14. If proposal'was verbally approved Name of approver' __ _ Date approved , ,c , , ~ , ~- ",[ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed . ' k,~,,.yTitle Regional Drilling Engineer Commission Use Only (TJB) 5A2/89 Date Conditions of approval Approved by Form 10-403 Rev 12-1-85 x' Notify commission so representative may witness ! Approval [] Plug integrity [] BOP Test [] Location clearanceI · NO. by order of ' the commission Date ~- ~/~7~ Submit in tripiicate ~ SCU 323-4 WORKOVER GENERAL DISCUSSION SCU 323-4 was completed as a producer in the H2-10 in April, 1961. It was converted to a gas injector in June, 1968 and used for that purpose since that time. The tubing was pulled in April, 1981 and the completion arrangement changed from a 3 to 4 packer design. While testing the tubing/casing annulus on 6/24/87 in compliance with Area Injection Order No. 13, the tubing/production casing annulus showed a 10.2% pressure decline in 20 minutes. This gas injection well was subsequently killed with 10.1 ppg brine and further pressure tests conducted to determine mechanical integrity. These additional tests indicate a potential packer or casing leak. The tubing hanger packoff is also leaking. During the forthcoming workover, the existing tubing string will be cut above the top packer and pulled. The casing will be tested for integrity and the appropriate remedial measures taken if required. A new tubing string will be run with an overshot packoff sub and a new packer. The packoff sub will be stabbed over the existing tubing stub and a new packer set above the packoff to guarantee annulus isolation. Please see the attached procedure for more specific information. Anticipated bottomhole pressure: 5139 psi Workover fluid: 9.7 ppg NaC1 brine SA2/89a 8/20/87 RECEIVED AUG 2 .i I }g7 Alaska 0ii & 6as Cons. Commissior~ SCU 323-4 Gas Injector Swanson River 3½" Tubing Change Out Procedure Prior To MIRU Workover Rig 1. RU slickline and pull tubing plug from Otis "S" nipple @ 10,361'. 2. Close X A sleeves @ 10,455' and 10,627'. 3. Set tubing plug in "D" nipple at 10,667'. Rig down slickline. 4. Circulate well with NaC1/CaC12 brine & pump kill pill if required. 5. RU electric line and cut tubing with chemical cutter above top packer. 6. Check surface casing pressure and bleed if necessary. Workover Ri~ ....... 1% MIRU. ND tree. NU BOPE and test. 2.~tubing. Circulate and condition brine. 3. POOH with existing completion string. 4. RU and make junk basket/gauge ring run. RIH to top of tubing stub. POOH. 5. RIH w/retrievable bridge plug and set above tubing stub. Set storm choke. 6. ND stack and change out tubing head and 7" secondary seal unit. Make sure all pressure is bled off SC annulus. NU stack and retest. 7. Pull storm choke. Pressure test production Casing. Isolate leak as required. Squeeze leak or set internal casing patch. Retest production casing. 8. RIH with dress-off mill to tubing stub. 9. Dress-off tubing stUb, circulate hole clean. POOH. 10. PU packoff assy., nipple, space out tubing, and permanent packer with hydraulic setting tool. RIH. Swallow stub. Set packer. 11. POOH laying down. 12. PU 3½'! completion string with seal assembly. Stab into permanent packer, test packer, space out, land tubing. 13. Set BPV, ND stack. NU Tree. Test tree. Release rig. 14. Pull BPV. RU WL unit. Pull dummy and set circulation valve in GLM. Displace well with lease crude. Record SITP. 15. Release well to Production. SR/80 ~,}aska 0il & Gas Cons Co~ ~,~,,o--., 000 0 ZZZ Z C .iV D ~,~il CASING & TUBING DETAIL SECTION 4. ,T. ? N., R. 9 W. ~ ,'~ . -~,-n.? Chevron U,S.A. Inc.' Oil & Gas 'Cons, Gommission K.B. TO GROUND LEVEL I I.26' L 1t.2G' IUI]INC ~AN~ER O't-6, Se3' 356 JTS. ~Fa" EUE 8.0 TUaiNC 9f~1,51 -9666,40'--,~ OTI$ "XA" SLEEVE UPSIDE OOWN 2.87 ,-9669.Z~'~ BAKER FH PACKER STRAIGHT P'JLL 50,00~~ 6.92' / . · 9695' TOP LINER 21 JTS, Z~'EUE 8,o T~ING I ) ~AKER"FH PACKER STRAIGHT PULL 5g~OO~ ~.08' I I I JT. 2~" EUE 8.o TUBIHG 30.33' -10,361.23' '~OTIS "S" tlIPPLE Po~Tfo, 3 -10,375' 0194' 0406' ] JTS. 2~"E~JE 8~oTUBI~C ~2.45' 0426' 04~4' --10,455.20'~ OTIS 'XA" SLEEVE UPSIDE BOURN 10454' Z JTS. Z~'EUE 8No..TUBINC 81.84' 10510' -10,519.67' ~BROWN "C~" SAFETY JOINT 1.41' PUP JT. 2D~" EUE 8,0 TU81~tC 4.07' -~0,525.~9' 9AKER FH PACKER STRAIGHT PULL 50,000~ 8.10' I JT, 2~"EUE 8,o TUBING ~0.¢8' -10,561.71' OIlS "5" NIPPLE PoS~TIo. 4 1.53' -~0,594.5~'~ GRO'~N 'CC" SAFET~ JOINT 1.41 10621' ,os~' i JT. 2~"EUE 8.0 TU~IRG 31,5~ -~O,627.~2'--~OTIS-XA- SLEEVE UPSIOE DOWN ,o~4e' I JT. ~"EUE 8,0 TUGINC 51.25' -----10,661.25' AKER 'FH" PACKER STRAIGHT PULL 5~,000 10,667.~5' A~.~CO "O" NIPPLE . ~o~o' ~ I JT. 2~"EUE 8noTB~. BAKER SHEARS'J9 -- -10,699,5 I' General Purpose Worksheet ISubject IPage No.(~ //% e.. /w~~ RECEIVED Alaska Oil a Gas Cons. Oon'm',issios Anshor329 ANNULAR PREYENTER 7 PIPE RAMS 6 !' ! 1. 1 1-$/4" SURFACE CASINO 2, ? s/~ASI NO HEAD 1 2" - 3000 PS1 FLANGE 3. 12" - 3000 PS1X8"- 5000 PSI TUBING HEAD 4. 8"-5000PSIX I I" - 5000 PSI CROSS-OVER SPOOL. 5, 11" - 5000 PSI BLIND RAMS 6, 11" - 5000 PSI PIPE RAMS 7. 11"- 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST I. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. A,5~URE THAT A(~UMULATOR PRE~.~URE 13 3000 PSI WITH 1500 PSI DOWNSTREAM OF' THE REOULATOR. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAININO AFTER ALL UNITS ARE CLOSED WITH CHAROINO PUMP OFF. RECORD ON THE IADC REPORT. THE ~PTABLE LOWER LIMIT IS 4.5 SECONDS CLOSING TIME AND 1200 PS1 REMAININO PRESSURE. 11, 12. 13. BOP ST~CK TEST 1. FILL BOP STACK AND MANIFOLD WITH BRINE. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN ,.SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPA&S VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSi. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAH5. ?. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES, 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PS1 TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAHS, BACKOFF RUNNING,JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAHS AND TEST TO 5000 PSI FOR 10 MINUTE5. BLEED TO ZERO P 10. OPEN BLIND RAMS AND RECOVER TEST PLUG, MAKE SURE MANIFOLD AND LINES ARE FULL OF BRINE AND ALL VALVES ARE ,,SET IN THE DRILLING POSITION. TEST STANDPIPE VALVES TO 5000 PSI, TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SENO TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. DM MARCH 9, 1987 (November 1983) (Formerly 9--331) U, STATES su.--IT (Other Instruetl~ ;n re- DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug baek to n different reservoir. Use ,,APPLICATION FOR PERMIT--" for such propomalL) Form approved. Budget Bureau No. 1004-0135 Expires. August 31, 1985 LEASh DEEIONATION AND IBIIAL NO. INDIAN, AI, LOT'rBB OB Tilt! NAME 7. ONIT AOIREMBNT NAMR ~' Soldotna Creek Unit WELL wELL 8. II*ARM OB LBAEE NAMB 2.NAME OF OPERATOR ARCO Alaska, Inc. 0. WBLL mo. 3. ADDmERB OF OPBRATOR P.O. Box 100360, Anchorage, AK 99510 4. LOCATION OF WELL (Report location clearly and In accordance with any State requlrementR*e See also space 17 below.) At surface Soldotna Creek Unit - 7 wells · 14. ria~t IT 15. sAlVATIONS (Show whether Dr, BT, OR, ets.) 10. I*IBLD AND POOL, OI WILDCAT Swanson RivEr Fiold 11. mr., T., a., M, OB mK. LAm aumym! OR A~iA Sec. 4, 9, T7N, R9W 12. ~uwxT OB rARmHI 18. STATS Kenai I Alaska 10. Check Appropriate Box To Indicate Nature of Notice, Reporl, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPI.ETE flHOOT OR ACIDIZB ABANDON' REPAIR WELL CHANGE PLAN~ aUBEBQUBN~ mul"Ol~ OB': WATER SHUT-Or~ ~ allsllall~O WELL IPRACTURB TREATMENT . ALTEBIN0 CASINO 8HOOTING OR ACIDlSlNO ABANDONMBNTO (Other) (NOTE: Report results of multiple completion on Well (Other) X Pressure Test Completion or Reeompletion Report and Log form.) ~.,~, ~E.%('it*,lSM :'ROPOSED OR COMPLETED 0PERATION~ (Clearly state all pertinent details, and give pertinent dates, lneludtnw estimated date of startlnw an. orop~ed work. If well is directionally drilled, give subsurface loe~tions and measured and true vertical deptlm for all markers and r, ones perU- neat to ~is wor~) * The AOGCC has issued Area Injection Order No. 13, applicable to Swanson River Field, effec- tive March 16, 1987. To comply with Rule No. 6 - Demonstration of Tubing/Casing Annulus Mechanical Integrity, ARCO Alaska, Inc. is planning on pressure testing the production casing annulus of each active gas injection well at Swanson River to a surface pressure sufficient to generate a differential pressure of 0.25 psi/ft between the uppermost packer and the formation. The wells included in the program are wells 314-4, 341-4, 312-9, 323-9, 321-9, 323-4, and 332-4. The attached procedures outline the steps that will be taken to conduct the test. The wells are currently being loaded with fluid in the production casing and surface casing annuli. The pressure testing is expected to occur in the last two weeks of June, 1987. RECEIVED Ataska Oil & Bas Cons. Commission Anchorage lg. I hereby certlfy~at the foreKpJng is tr'ge and correct / .=-~ , Regional Engineer DAT~ TITLE (This space for Federal or State sics use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DAT~ *See Inmuctions on Reverie Side Title 18 U.S.C. Section 100l, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. SCU 321-9 LOAD PRODUCTION AND SURFACE CASING AND PRESSURE TEST PRODUCTION CASING Loadin.!) PC and SC Annulus · Record pressures on the tubing, production casing and surface casing. Blow down PC' to lO00 psi, recording all pressures. 3. Blow down SC, recording all pressures. . Shoot fluid levels for pump-in volumetrics. Estimated volumes from most recent fluid level data are noted below. . Load SC with lease water containing l0 gal/lO00 gal WT 676 corrosion inhibitor and a 5 bbl crude cap. Do not exceed 300 psi surface pressure during pump-in. Monitor all pressures. . Load PC with lease crude. Do not exceed 2500 psi during pump-in. Do not bleed PC below lO00 psi during pump-in. Pressure Testin9 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 b 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 ~1. 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. Volumetrics Fluid Level Annular Capacity (bbls/ft) Estimated Fluid to surface (bbls) Surface Casing Recent ly 1 oaded .0699 Production Casing Recently 1 oaded .0264 I~H t:.V i'{U N U..~. A. TRANSMXTT~'A__ND ACKNOWLEDGEMENT OF RECEIPI~. P~TERIAL - (ALASKA) THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. /EA. _ i i L , , RECEIVED BY REMARKS ON OTHER SIDE, THIS SHE'E'T CItL'VIION U.S.A. IN~ BOX 7-839 'ANO'IORAGE, ALASKA 99510 : ' STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION CO,v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~3 7. Permit No. OTHER [] ' 2. Name of Operator Chevron U.S.A. :[nc. 3. Address P.O. Box 7~839, Anchorage, AK 99510 4. Location of Well 2051' N & 2070' E. From the S.W. corner, Sec. 4, T7N, R9W, 8. APl Number 50- 9. Unit or Lease Name 50] dotna Creek S.M. 5. Elevation in feet (indicate KB, DF, etc.) 167' K.B. I 6 .' Lease Designation and Serial No. A-028997 10. Well Number SCU 323-4 11. Field and Pool Swanson River Hemlock 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] . Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation I~ Abandonment Repair Well [] Change Plans [-] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On July 29, 1982, the H-lO sand was matrix acidized as follows- 1) 30 bbls. 5% HC1 2) 105 bbls. 12-10% mud acid 3) 30 bbls 5% HCl RECEIVED AUG 2 ? 1982 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoin~g )~s true and correct to the best of my knowledge. Signed . ~. '~~~,c,.~-.:;~"~,~~ Title Area Enqi neer ~ I ~ /."~ - ~ - The space belo~ for Commission use ~ Date 8/26/82 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Form 10-403 Date Submit "Intentions'' in Triplic~'t~' Rev. 7-1-80 and "Subsequent Reports" in Duplicate WELL HISTORY SCU 323-4 April 20, 1981 Rig Up Brinkerhoff Signal Drilling Company's Rig ~60. April 21, 1981 70 PCF Rig Up - mix brine water to 70 PCF. April 22, 1981 70 PCF Circulate well with 420 barrels of 70 PCF brine, lost 150 barrels of brine at 7.5 BBH, mud gas cut A~ril 23, 1981 70 PCF Continued circulating well With 70 PCF - still losing fluid at 7.5 BPH reduced weight to 67 PCF. Mix brine polymer in mud - still losing mud at 4.5 BPH. Well. dead. Set BPV and remove tree. April 24, 1981 67 PCF Nippled up BOPE and kill lines - tested to 5,000 psi April 25, 1981 67 PCF Pull BPV and tubing hanger, release packers with 130,000~ over pull, circulate out gas cut mud. Pull out of hole laying down 160 joints of ~3 1/2 tubing. A~pril 26, 1981 68 PCF Continued pulling out of hole laying down 314 joints 3 1/2" tubing, 28 joints 2 3/8" tubing, two mandrels, 1 packer, Otis "S" Nipple and top part of BOT CC joint. Left fish in hole: Fish - bottom CC joint looking up at 10,526' and two packers with jeWelery. Picked up fishing tools and .'run~in hole on 2 7/8" and 3 1/2" drill pipe. Packers in hole BOT HS 16-1 at 10,526' and Baker model packer (wireline set) at 10,659'. A_~ril 27, 1981 72 PCF Continued picking up drill pipe and running in hole - screwed into fish with CC safety joint box at 10,517'. Circulated with partial returns. Pull out of hole to 9,445', drill pipe plugged. Pulled out of hole - well kicked with -~2000,of 2 27/" drill pipe in hole. 600 psi casing pressure - pressure increased to 1450 psi - bled off pressure to 1800 psi every 20 minutes. April 28, 1981 72 PCF Nippled up". choke line to production flow line, rigged up BJ Hughes to kill well. Raised mud to 80 PCF with bar. Attempted to kill well at 1/2BPM '2500 psi. c.p. Washed out choke line, Shut Well In (Shut in pressure 3,490 psi). Repaired line, attempted to kill, washout out choke line. Raised mud weight to 94 PCF. April 29, 1981 108 PCF Repaired line, mixed mud to 108 PCF. Raised mud weight to 135 PCF. Pumped 200 barrels - lost some mud to formation. Shut Well In to build Mud. Shut in pressure 50 psi drill pipe,. 1200 psi. casing, built mud weight to 108 PCF.~ ' ...... 109 PCF April 30, 1981 Pumped 100 barrels of 109 PCF mud - well dead. Run in hole with 1 joint 3 1/2" drill pipe, well started flowing, Shut in Well - casing pressure increasing, drill pipe pressure zero. Built mud weight and volume. .~ay 1, 1981 126 PCF · Pump 150 barrels of 126 PCF mud, Bled well off thru choke to product-~.on line. . . May 2, 1981 109 PCF Killed well with 109 PCF. Run in hole to 4804'. Circulate up bubble. Run in hole to 6295'. Circulate up bubble. Run in hole t6 9599'. Lost circulation. Shut in and mix mud. May 3, 1981 103 PCF Pumped'180 barrels of 103 PCF mud..~ Bled~off casing. PumPed 455 barrels formation water. Shut well in - mixing and keepinghole_full with formation waster (casing pressure 100 psi). ~a~ 4, 1981 67 PCF P~mp 34 barrels of 67 PCF mud - lost returns. C~ntinued pumping total 54 barrels. Shut well in and filled annulus. Bled off 400 psi casing pressure. filled annulus. May 5, 1981 67 PCF Run in hole 8 stands, released fish on bottom, circulate at 1055', kill well with 1350 barrels of 67 PCF mud, Pulled out of hole keeping hole full. May 6, 19 81 68 PCF Continued pulling ~ut of hole. Run in hole - screw into fish and release packer, circulate. May 7, 1981 68 PCF Continued circulating out gas. Pulled out of hole to 8033'. Circulate out gas . Pooh - recovered Brown HS packer, 4 joints tubing and 1 mandrel. Picked up packer retrieving tools. Run in hole to 10, 484'. Circulated out ! gas. M~y 8, 1981 68 PCF Run in hole to 10,585'. Milled over last packer. Pulled out of hole to top of liner, circulate~bottoms up. Pulled out of hole slowly. May 9, 1981 69 PCF Pulled out of hole. Recoverd Baker packer, layed down fishing tools. Picked up 4 5/8" mill 8 - 3 1/2" drill collars and run in hole and cleaned out fill to 10,740'. Pulled out of hole. May 10, 1981 Layed down mill, picked up 6" bit and 7 5/8" casing scraper. Run in hole to 9693'. Circulate and pUlled out of hole. Picked up 4 5~i,' mill and 5 1/2" scraper and run in hole to 10,740'.. Circulated. ~ May 11, 1981 70 PCF Short trip to 9693' and back. Circulated bottoms up. Pulled out of hole laying down drill pipe. i Picked up and started in hole with production tubing and packers. - hydroteSted to 6500 psi. May 12,' 1981 Continued hydrotesting in tubing, lost 2 x 3/4" x 3~8" pieces of hydrotest tool in hole. Rigged up CA White solid wire line. ~ May 13, 1981 70 PCF Run in hole with impression bi~ock to 6887'. Rkn in hole with mag. to 6885'. Rec0vered~piece of junk. Reran mag. to 6917 - no recovery. Run in hole with spear - could not push below 6917'. Run in hole with 1 5/8" blank box and pushed junk to shear sub. Continued hydrotesting 3 1/2" tubing in hole. May 14, 1981 70 PCF Rigged up Dresser Atlas, Ran Gamma Ray log and landed tubing at -1.0i~99.51' · . Set BP valve, Nippled down BOPE, Nu tree and tested to 6500 psi. .May 15, 1981 Ri,gged up CA White and cles~...XA.sleeves at 10,627', 10,455' and 9669'. Nippled up BJ hughes and pumped 519 barrels of lease crude down annulus. Dropped ball to set hyd. packers - unable to set packer.~ Rigged up CA White and attempted to set plug in "D" nipple - run sinker bar to clean out junk· May 16, 1981 Attempted to set plug in "D" Nipple, would ~ot seal. Checked XA sleeves - all closed, run sinker bars and magnet to remove junk. RIH with plug.. Did not set. Made clean out sinker bar run, made two more attempts to set plug and two clean out runs. Rigged up BJ and pumped 20 bbls. of chemical...asphalt cleaner. Run in hole with plug - did not set.. Run in hole with swivel sinker bar for clean out, May 17, 1981 Run in hole with XA sleeve shifting tool upside down. Closed XA sleeves (,XA sleeves upside down). Set packers and tested annulus - packers held o.k. May 18, 1981 Clean pits and released rig at 6:00 a.m. JAC 11;26' D.Y.-6, 98.1' K,B. TO GROUND LEVEL TUBING HANGER 356 ITS. 3~a' EUE 8,o TUBING ....... 96~33.92'-- .... 9GGG,40° -- .~--9669.Z 7' -- ,969.1'10P LINER (2¥' ~*') ~'*B0x ,(Z~,"BR BOX I IT. 2~ £UE 8*D, TUBING OTIS ~XA" SLEEVE'UPSIDE OOV/N BAKER FH PACKER STRAIGHT PULL 21 ITS. Z¥ EUE 8.D TUBING ii II .26' 'L_~ &-1o.775,.oo. I.D. 9(;21.51 I,',1 $' 3 1 ..,33' 2.8'/' 6.92' ---10,324.82' BAKER 'FH" PACKER STRAIGHT PULL 50pOO" I IT. 2¥EUE 8.0 TUBING -10,361.23'--- OTIS'"S" NIPPLE Pos,Tio, 3 i lO4O6' ITS. 2¥EUE 8,o TUBING ~)2.45' 10425' ' 10454' I .-:10,455.20' OTIS'XA" SLEEVE UPSIDE DOWN .10454 ' . : : 2 ITS. 2~'EUE 8pDTUBING 10510' ' -10,519.6T' -- _ BROWN "CC" SAFETY JOINT PUP IT. 2~" EUE 8,~ TUBING '10,525.19'_3_ BAKER FH PACKER STRAIGHT PULL 50900* 10539' : I IT. 2¥EUE 8.0 TUBING 30.48' i ' ' ~10,561.71' - ~-OTLS "S' NIPPLE POSITION 4 1.55' : I iT. 2¥'EUE 8,0 TUBING 31.02' !~o$~1 -10,594..t2'- · . /-BROWN "CC' SAFETY JOIItT 1.41' 10635' , / · I.JT. 2~e' EUE / , i'-.,O,62T. IZ'--~OTIS'XA'.SLEE'V..EUPSIDE DOWN ". 2.88' i,o,,,8' / I JT. ~ EUE '8~o TUBING 31.2,~ ] ---_ -J~0,6~6~1,.,2~5, :::::~BAI~ER "FH" PACKER STRAIGHT PULL 50,000 G.I_O: I - - ' ,~,o~,.~o ,~:-CANCO 'O" NIPPLE 110670' i 10,699.51' !'.. I JT~ 2& EUE 8~TB,.G. 8AKER,.SHEARStJ6,,31.23' .. TOp' S'o C.U, 3'23' 4 -. CASING 1~ TUBING DETAIL SECTION 4~T.? N,~ R. 9 W. Chevron U.S.A. Inc. 08' o52° 2.~T' Gl .64' i.4i' 4.0T' STATE OF ALASKA r~. ALASKA O.,.. AND GAS CONSERVATION COIv, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator 7, Permit No. Chevron U.S.A. Inc. 3. Address P. O. Box 7-839, Anchoraqe, Alaska 99510 4. Location of Well 2051' N and 2070' E from the SW corner of Section 4, T7N, R9W, SB&M. 5. Elevation in feet (indicate KB, DF, etc.) 167' K-B.. 12. 6. Lease Designation and Serial No. A-028997 8. APl Number 50- 133-10106 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 323-4 11. Field and Pool Swanson River Field Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) [] [] [] 13. Describe PropOsed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Chevron plans to acidiZe well SCU 323-4 as described in the attached program. bse trent-Work Reported Xo./ 14. I herebyT;.~io;y;g i~true and correct to the best of my ~no~edge. Si~neO ~~~ Title e ~ons Super~ntendeng RECEIVED J U £ 2 1982 A!aska 0il & Gas Cons. Commiscior~ An~'l~nr~ n Date July 21, 1982 The space below for Commission use Conditions of Approval, if any: Approved by ORIGINAL SIGNED BY LONHIE C. SMITII COMMISSIONER [.Approved Copy ,, Returned By Order of the Commission Date Form 10-403 Rev, 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate CHEVRON U,$.A. INC. WESTERN RE GION ALASKA AREA WELLWORK ~DURE. SUM,MARY .. .,- - .~, ...... ._ 'LOC.: .S':~ .ff.....TTA2~ ,~¢~ ~B.~ TYPE WELL:'. ~,,,5 I/I/JEC. T/ON , _ ......... TYPE JOB' ORIGINAL SUMMARY BI SUPPLEMENTAL SUMMARY C) NO, -- _ OBJECTIVE' /NC~EiqS[' I0 ..... ,~/~ND,,,,, I/U,.).t.~C 7'/I/ /~, ............. WELL DATA' K.B. 1/. CASING' 5E~: /q-77'P(,H~ D£T/:t-IL. . LINER' ~BING: - ~E~ A ~C/Y ~D , ....... ~R. ~RFORATIONS': ~ ' NOTES:., PROGRAH /) ...~IC. Op ~__~.,l~/4r7'E. Czosz,-- "X/~ ._gZ_c'Tt./,r~ ,h,,T 70,¥.5:5- ~/~O iUOTE",. £I..E~-L)t:-_5 . .. AE., E /_)/05!DE Z ') R' /~ DP DDI/I/ELL , Z/MIT £URF, OCL-- ..... DETAILS ATTACHED JUL 2 ~ i982 Gas Cons. Commis~red Distribution: -Orlgin. I to Well File N3ska Oit & Anchorage " W.D. ~ (~) R~ Offlc,(I) P~~ (I) ~wed D.M. Wils~(I) .... "'~ _ , CHEVRON U,S,A, INC. WESTERN' REGION _ ALASKA AREA WEL.I,.WOI:~... PROCEDURE. SUMMARY .. · · OF PROGRAM (03NT1NUED): ., ii i i i /z ii ii! i i _ i ii _ __ DETAILS ATTACHED Distribution: · 'Original to Well File W.O. Souer (3) Field Office(I) Preparer (I) D.M. Wilson(I) Alaska Oil & ~a~ Cons, Commission -nchorape Dale Prepared ~ .~ed ' · ! -// 0000 . · -.' ' 11.26' ,- ,_ K.B. TO GROUNb ~.EVEL ' "" I JT. 2~ EUE 8.0. TUBt,C -9666.40'-- - --9669.Z1'-- ~ OTIS 'XA" SLEEVE UPSIDE DOWN BAKER FH PACKER STRAIGHT PULL 50.,000 · 9693'~0P LINER * 21 .JTS. Z~' EUE 6~o TUBING ---I0,324.8~' BAKER 'FH" PACkER.STRAIGHT PULL I 'JT Z~'EUE 8.0 TUBIflC ---10,]61.2~' . - OTIS'"S" NIPPLE POS,T~.. ~ - lO,iTS'. ' / 10394~ ~ " I ~o4oe' t JTS. 2~'EU[ 8poTUBIKC . 10426' . . ' I I :10,455.20' ~OTiS-XA- SLEEVE UPSIbE DOWN .i04s4 ' . : , ., : : .' : " 2 JTS. 2~'EUE 8~oTUBING --10,5~9.6T' - ~8ROWN 'CC" SAFETY JOINT 1.41' PUP JT. ~" EUE' 8,~ TU'91flC 4.07' -10~525.19' -BkKER FH PACKER~STRAI~NT PULL 50'~00~ G.lO' ". . : ~ 0 539~ : I JT. Z~EUE 8~o TUelflG 30.48' : ~ :lO,56i. Tl" ~OTtS "S' HJPPLE PosiTeD, 4 ~ ' · ' I JT. Z~'EUE 8nD TUBING 31.02' ~ I~;;~'er~-A°'59'~' :" eROWN 'CC' SAF~TYl 3~IHT ' ' '3i.39' 1.4r i'°6~8'; l* ' IjT. ~'EUE 8P~ TUBING ! -'~,~'~. ~BAKER 'FN"'PACKER STRAIGHT PULL 50,000 G./~ ~,o67o' ~0,69951'~ ! ~ I JT: 2% EUE'8AoTBG.; BAKER SHEAR SU9 31.23 _,_?~4' -.10,740'. TBp E IV E D JUL 2 3 i982 Aia§ka Oil &-Gas Cons. Commission Anchor~q,.~ S.C.U. 52.5- 4 CASING 8~ TUBING DETAIL SECTION 4,T.? N., R. 9 W. Chevron U.S.A. Inc. 11.25' 1.15' 3 I..33' 2 G. 92' G48.G3 ]0.33' .52' ~2.45' 2.aT' $t.64' HYDROFLUORIC ACID SAFETY PRECAUTIONS · . ALL CHEVRON U.S.A. INC. PERSONNEL MUST ABIDE BY THE FOLLOWING SAFETY PRECAUTIONS' .. NOTE: 1. These safety precautions have been adopted by ~hevron u.S.A. Inc. .. and are recommended to the Service Companies. Dowell, B. J. Service, and Halliburton sell hydrochloric - hYdrofluoric acid mix for well stimulation. All but the Halliburton Company call this mix "Mud Acid", The' Halliburton Company has a "Mud Acid" consisting of Hydrochloric Acid and surfactants and contains no Hydrofluoric Acid. Their Hydrofluoric -. Hydrochloric Acid combination is known as "H. F. Acid". Be 1 le The current trend is to increase HF acid concentrations from the 3% - 5% formerly used, to 10% - 15% in addition to the normal 10% to 15% hydrochloric acid. While these higher concentrations are more hazardous, the safety precautions outlined below apply to all mixes containing less than 20% HF. Special additional precautions should be added for concentrations above 20% HF. The acid is less dangerous after expending in the well but can still cause serious injury. HF acid mixtures will b~Fn the skin. Both HCL and HF acids can serevely damage eyes. HF acid fumes can cause eye damage, and the. liquid HF can cause immediate blindness. SAFETY PRECAUTIONS The Production Foreman is to hold safety meetings with 'all personnel prior to start of the work and acquaint all .with these precautions and with the attached First Aid measures. e Service Company people may be required near the acid piping while pumping, §ut these should be kept to an absolute minimum. There is normally no reason for our Company' personnel to get closer than fifty feet to the acid piping. : An adequate supply of f~esh water must be immediately available for emergencies and for washi'ng tubing. Protective Equipment' (a) Eyes - Protective goggles shall be worn by all personnel within fifty feet of.equipment or lines containing HF acid.' Face shields should be used with goggles but are not adequate protection used alone. Face shields do not protect against acid vapors or splashing around edges of the shield. Alaska Area June, 1982 ., .Page 1 of 3 0 e e (b) Skin "Normal clothing is adequate protection from acid vapors. ' 'C'~l-6-~hing provides some immediate protection against liquid but should be lipped off and"the skin flooded with water if saturated with liquid acid. Wet or sweaty areas'will absorb HF vapors. Attached to the~e safety precautions are the First Aid measures drawn up by our Company doctors. IMPORTANT " The-attached are First Aid measures only, The patient must be rushed to. a qualified physician immediately after administering First Aid by -...- flushing with water for a minimum of 20 minutes. The physician must be called and advised of the emergency and the type of chemical con- tacted concurrently while administering First Aid. . On wells which have had W-41 treatment, toxic arsine gas (AsH~) may be generated when contacted with HF acid. The Foreman is responsible for checking these wells with a DRAEGER detector as outlined in Chevron Practice No. 89. On wells which have some-hydrogen sulfide production, additional amounts of this extremely dangerous gas may be released when acidizing. The Foreman is responsible for proper precautions and detection of H2S gas as outlined in Chevron Practice 77. · · .o Alaska Area 'June, 1982 AI2ska Oil & Gas Cons. Co~?mission 'Anchorage Page 2 Of 3 · FIRST AID TREATMENT OF HYDROFLUORIC ACID INJURIES Contact With Skin .,.. .. 1. Put patient under S~ower at once - remove contaminated clothing while under shower. Wash area 20 minutes. Inhalation 1.. Remove the patient to fresh air, free from drafts. 2. Apply artificial respiration, if necessary. 3. Reassure the patient and discourage him from coughing. 4. Keep patient warm, because he will be suffering from shock. 5. Make-patient rest. 6. Take patient to emergency hospital. Contact With Eyes_ 1, Irrigate eyes freely with clean Water for 15 to 20 minutes, holding eyelids apart during irrigation to insure contact of water with all of the tissues of the surface, of the eyes and lids. e Take patient to a physician, preferably an eye specialist or emergency hOspital. NOTE'- .. ,, ,, 1. !MPORTANT " · The above'are First Aid measures only. The patient must be rushed to a qualified physician immediately after administeri.ng First Aid. 2. In the Alaska Area the following doctors and/or hospitals have been' contacted and are equipped for emergency treatment. SOLDOTNA/KENAI Paul G. Isaak, M. D. "Peninsula Mcdical Clinic 1 block off Kenai Spur Road Soldotna, Alaska 262-4401 (8:00 a.m. until..5:00 p.m.) weekdays only) 262-4404 or 262-4407 (after hours, weekends and 'holidays) ANCHORAGE Dale J. Trombley, M. D. 4001 Dale street Anchorage, Alaska 99504 (907) 276-0500 - Office (907) 272-5777 - Home Peter' O~ ltansen, M,D. Medical Center, Inc. Benco Building Kenai Spur Road Kenai, Alaska 99611 283-4611 Alaska Area June, 1982 JUL 2_ 3 8,.2 A!aska Oil & Gas Cons. Commiss/on Anchora.~e Page 3 of 3 -r Chevron Chevron U.S.A. Inc. P.O. Box 7-839, Anchorage, AK: 99510 · Phone (907) 279-9666 T. L. Perryman Area Operations Superintendent Production Department May 25, 1982 WELL COMPLETION INFORMATION State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. Kugler Dear Mr. Kugler: Enclosed is the material requested in your April 21st correspondence. Also included with tI~s transraittal is information on Soldotna Creek Not included are mechanical drawings for wells SCU 42-5A, SCU 44-8A and SCU 41-9A. Our drafting department is presently overloaded. I will forward these drawings to you when they have been completed. Also missing are the requested samples and core chips from Beluga River Unit well ~214-35. There were no core samples taken from this well. Should there be any questions contact this office. Very truly yo,~, . L. PerrTm~',f DMW:dmw Enclosure t?E CEIVED · aska Oi~ & Gas Cor~s. ~chorage COMPLETION REPORT - RE~EDIAL~ WELL CHEVRON U.S.A. INC. AREA: Kenai Peninsula Cook Inlet Area, Alaska LAND OFFICE: Anchorage PRDPERTY: Soldotna Creek Unit LEASE NO: A-028997 WELL NO: SCU 323-4 API NO: 50-133-10106 LOCATION AT SURFACE: 2051' north & 2070' E. from the S. W. cot., section 4, T7N , R9W, S.M. LOCATION AT TOTAL DEPTH: same ELEVATION: K.B. 167' 12/81 DATE: AREA SUPERVISOR DRILLED BY: Brinkerhoff Signal Drilling Company Rig #60 DATE COMMENCED REMEDIAL WORK: 4/20/81 DATE COMPLETED REMEDIAL WORK: 5/18/81 RETURNED TO PRODUCTION: SUMMARY TOTAL DEPTH: 10,775' PLUGS: 10,740'-10,770' EFFECTIVE DEPTH: 'i0,740' (cmt.) CASING: 22" conductor at 28' 11 3/4" CSG. at 1413' 7 5/8" CSG. at 10,375' 5~" liner 10,770' - 9693' LOGS: Dresser Atlas Neutron log 9550' - 10,623' 5/13/81 ccl $ Z$-~ COMPOSITE PRODUCTi~t~ ffRoF:IL.E_ :SP/,',J,~/'~ - T=--m P - ~SAT5 I~J ~C1"ioAJ ,PRO~:I L.~ ,SOR. vE Y CC/.. + p~R.F:OP,,AT~I, JC~ REco~D IIoJEC T?Oa} PR, o?~Lt=_ C~ r~ M A tP~ ¥ - N £. u'c t~ o ~ Loc=. l/UuEcrz okl [:'R o ,C/ LF--· ,5o /o i c. L.O C., COMPOS 17'~ eW, oDUCTIOU. 1__06 C~ mEIOr ~3o~o b Co 6 ~ATE .SD. PI,~, B ~u~ Clho_~ d?-18-80 ~-- ~" ,5'-2.7-01 ,--'-' '-"" 3-30' 70 '-"'- '"' 3-I - 75 "'" "" 7-Z0-77 ~ ~" /~ecze ved .ha+ e_ .~laska Oil & C~as Con,:,. ltnchora.ue cr~c lox e d o~ ve.{ op e_. . c..c c,e no w l e,:,t, y e rn e ~:t' COMPOSITE. Pt~)DtJC TIOtd I t, JJ Z C__ T'I o,cJ CC/... + pt~RFO,'tAT;k,tG REColD l tuJ. Ec T'/ O AJ NF__.u~£oAJ LoC) ,5O /U l C. COMPOS/T'E. PI~.OOUC. TIO~J Lu~ C~mEIOT E~o~b Log 8-/8-8o /Z - z.8-81 (,,-z4-~,$ ~-3o ' 70 3-1-25 3 -Z&,-'7~ 7-Z0-77 ~ LOE L,I~J.E Alaska Oil &' L~as Cony,. L;ommissiLm -Jw~c AJ~- '. ~cu .Acous-nc C~mP_~r ~o~J) DAT'~ 7-Z/- 8/ ?- Z/- 8~ Oil 8, Gas cons. Commission ih ~'fAC e~c!o~e~ eM uel. OlOC SE.?I,~ ~gU L14-¢5, LoG Z::),,a-z'~ ,5'F_..PJA BLuEurcE /-7-81 u.-. ~ blt- 'TUb ,.~ Id l C L,o c~ 1-17-81 Acoustic C~,m'r~¢r ~o~Jz~ -LOC,- vol . , . ~ ti~e cnc /~ed e~ue Loc, .D~SCF,,~PTtot,,J . . . t°Roxtt'qtl-'"/ LoG- /VI~cRoLoG Acou .ST't c, C ~_r4 ¢_..~'r C ¥t~t= f..LO6 r__" J-DF, FDC, C~t., Dic ~)gAb. I Fo DUC TI O IkJ - Do~ob /..-o~,- VDb L. oc~ /-/-81 c- 1-26-81 1-2_.7-t5l t-7-~/ I-t7-St th ~he e.~cl~~ enae_.lo?¢. ~Cb~ 4/- 9A buAL. OF__..Tt~¢ TO~. I ....... D,a+c Ple~e. s~dn ~n~ ~ . Almsi(.a Uii & Gas Cons. 4--Z3-7 Z 4-Z7-72_ 4-11-72 4-Zo-FZ PlA BCU~UN£ buA. c ../~u OucF~ ~J - 5F L. Plc~ s ~ 5 ~3 ~ ~ nrJ . re. wcr¢n ¢h ~ s in ~1~ e~c~os~l ~nuc[ ope, ?-(¢ -gl ~ -8/ 5'-zz,-8/ ,-..--- DuAt. { ~ DUCFlo~" eof c Corn P~.A...qATE, D NJ E, u TP,.O IO ll-t-~l T~l m ¢_. I I-,P-~ l jl-~-81 DE-AJ~ tTy I1-1 -$1 Fei-urn ~rht~ -Vran$ m: kt~ ! aL b~ou~le r-,L..) em e ~ 4- f ' STATEOF ALASKA ~- , ALASKA t.~L AND GAS CONSERVATION Q._ ~MISSION WELL coMpLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1: Status of Well CoiF OIL[~ GAS [] SUSPENDED [] · ABANDONED [] SERVICE [] :2, Name of Operator 7, Permit Number Chevron USA ]:nc, 13-61 3, Address 8. APl Number P,0, Box 7-839 Anchorage, AK 99510 ~o~3-10106 4. Location of well at surface 9. Unit or Lease Name 2051'N, 2070'E, from SW corn Sec. 4, T7N, R9W, SB+M Soldotna Creek Unit At Top Producing Interval Same 10. Well Number SCU 323-4 At Total Depth Same 1t. Field and Pool Swanson River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Hem1 ock 167'KB] A-028997 i 2. Date Spudded4_ 20-81 13. Date T.D. R eacheds_9, 81 ' 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°nSS- 18-81 feet MSL 17. Total Depth (MD+TVD). 18. Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost ~ 10,775' 10,740'I None YES [] NO~] feet MD 22. Type Electric or Other Logs Run Space Out, Log 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 22" 133# N-80 S'urtace 2~J' 11 3/4~ 4~ NN80 Surface 1413' "7 5/8 29,7,33 7,39# N-lO Surfac.: 10375' 5½" N-80 9693' 10770' 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) 10394'- 10406' 3½" 9633.92' ,. 10426'- 10434' ' 2 3/8" 10,699.51' 9669.27' * 10454'- 10510' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL(MD) AMOUNT& KIND OF MATERIAL USED i0539'- 10621' : 10633'- 10648' 10670' - 10714' N~iNF None · , . ,, 27. PRoDUcTIoN TEST Date IA rstProduc:tion · ' ' I Method,, of-Operation (Flowing, gas lift, etc.) NoneJ None~ Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL cHOKE SIZE GAS-OIL RATIO ,;-. '. -r. : TESTPERIOD J~. , Flow-TubiDg Casing Pressure ., CALCULATED; I~ OIL-BeE GAS-MCF WATER-eeL OIL GRAVITY-APl (co'r) Press. 24-HOUR' RATI~:'-~' ' · . 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · Packer Set Cont'd ' · : -'. 10,324.82' EEC VED · ' 10,525.19' " .... ' - '~' - : '" " 10,661.25' JUN - 4 1981 · Alaska 0il & Gas Cons. Commission : Anchorage Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE __ 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing i~true and correct to the best of my knowledge Sign~;~" Title Area Oper. Supt. Date ~ "' 3- ~/ T.! . Per~Lvman INSTRUCTIONS General' This form is'designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached o,~,._~,~,.o lemental records .... for this ,',..; ~:. .~.~,, ..:., ~,._~ .~hnv: the de,.'.,~ ils of any multiple stage cement- STATE OF ALASKA , ALASKA ~ ~aUD GAS CONSERVATION C('~MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS,<: · Drilling well [] Workover operation [~ 2· Name of operator 7. Permit No. Chevron USA Inc. 13-61 3. Address 8. APl Number P.O. Box 7-839 Anchorage, AK 99510 so- 133-10106 9. Unit or Lease Name SB+M. Soldotna Creek Unit 4. Location of Well atsurface 2501'N.+2070'E. from SW corner Sec.4, TTN, R9W, 5. Elevation in feet (indicate KB, DFI etc.) 6. Lease_ Desi_g_na_ti_o_n and Serial No. 167' KB - A 028997 10. Well No. SCU 323-4 11. Field and Pool Swanson Hemlock River Field For the Month of. May ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 10,775 T.D. killed well, R1H w/circ'~ sub, engaged fish at 10,478', POH and circ'd, Ran casing scraper to bottom, cond. hole for tubing, ran 33 Jts 2 3/8" tubing w/Jewelry, Ran 356 Jts 3½" tubing, Hydro-test tubing to 6500 P.S.I., removed B.O.P.E. + installed 10,000 PSI'xmas tree tested to 6500 PSI, Set Packers and released Rig 5-18-81 13. Casing or liner run and quantities of cement, results of pressur9 tests 14. Coring resume and brief description 15. Logs run and depth where run 16. DST data, perforating data, shows of H2S, miscellaneous data RECEIVED JUN - 4 1,981 Alaska Oil & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ../-~' Area ~- Supt. ,~ - ' ~,/ ' 'SIGNED TITLE vper. DATE ~- NOtE--Rel~o'r~On tl~'r~l~r~equired for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Chevron , · . CHEVRON .U.S.A. [ C. TRANSMITTAL AND ACKNOWLEDGEbfENT OF RECEIPT OF MATERIAL - (ALASKA) DATE Rolled Sepia .'- F - Film X '- Xerox - ~ - Blueline · THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IbD~DIATELY. . STATE OF ALASKA ALASKA/-XL AND GAS CONSERVATION C~MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1~ Drilling well~I ~o--~er ~ i____ 2. Name of oPerator ~. Permit ~o. CHEVRON U.S.A. INC. 3. Address P. O. Box 7-839 Anchorage, AK 99510 4. Location of Well atsurface 2051' North and 2070' East from the Southwest corner of Section 4, TTN, R9W, SB&M 8. APl Number '! '! 50- 133-10106 9. Unit or Lease Name So]dotna Creek Unit 10. Well No. SCU 323-4 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 1671 KBI A-028997 11. Field and Pool Swanson River Field Hemlock For the Month of Ap ri 1 , 19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks ' Commence~operations 0700 hours, April 20, 1981. Killed well with 70 pcf mud. Lost 150 bbls. mud. Reduce mud weight to 67 pcf. Lost 210 bbls. Install and test 5,000 psi BOPE. Pulled and recovered 314 jts 3 1/2" tbg 28 its 2 3/8" tbg. 2 Camco MM mandrils, nipple and Baker 5 1/2" x 2 3/8" packer. Top of remaining fish at 10,526'. Took kick while coming out of hole with Brown FIS16-1 packer. Killing well at month end. 13. Casing or liner run and quantities of cement, results of pressure tests N/ A 14. Coring resume and brief description N/A 15. Logs run and depth where run N/ A 1 6. DST data, perforating data, shows of H2S, miscellaneous data N/A MAY 1 1981 Nask~ 0il & Gas Cons. Commission Anchorage 17. I hereby certify that ~is true and correct to the best of my knowledge. DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate ~-~ _.. STATE OF ALASKA ~ ALASKA L~L AND GAS CONSERVATION C(~,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name 'of Operator CHEVRON U.S.A. INC. 3. Address P.O. Box 7-839, Anchora~, Alaska 99510 4. Location of Well , Surface' 2,051' North and 2,070' corner of Sec. 4, T7N, R9W, SB&M. East from the Southwest 5. Elevation in feet (indicate KB, DF, etc.) _ 167' KB 12. I 6. Lease Designation and Serial No. 7. Permit No. 8. APl Number 50- 9. Unit or Lease Name Soldotna Creek unit 10. Well Number SCU 323-4 11. Field and Pool Swanson River Hemlock Check Appropriate Box To Indicate NatUre of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing ~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) [] o [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We propose to pull and repair the tubing in SCU 323-4 per the attached program.. We anticipate this work to begin in December, 1980 'RECEIVED NOV 7 AIm~la Oil & earn Oon~, Comml~m~ Am~orage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~~~~ Title A~P_a EnainPPr The space below for Commission u~ · Date Conditions of Approval, if any: Approved by COMMISSION ER Form 10-403 Rev. 7-1-80 By Order of the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate PROPOSAL FOR WELL OPERATIONS PR0-316-1 Field : Swanson River _Property. and Well No.: Sol dotna Creek Unit 323-4 Surface Location: 2,051' North and 2,070' East from the Southwest corner of Section 4, T7N, R9W, SB&M. Straight hole. Total Dep,th: 10,775 feet. _Plug.~_: 10,740 feet.. £a.sing: 22". Conductor ~ cemented at 28 feet. 11-3/4" 47# J-55 cemented at 1,413 feet. 7-5/8" 29.7 #. 33.7#. 39 # N-80 cemented at 10,375 feet. D. V. collar at 6,983 feet. 5½" 20 # N-80 liner cemented at 10,770 feet, top at 9,693 feet. Perforations: Tubing: See attached See attached. Junk: 18" Go-devil in mandrel at 10,611 feet. No report of bad casing. Datum: 15' above ground level at original KB elevation of 167'. BOPE Considerations: Gas injection well. A, Maximum anticipated formation pressure is 4600 psi in the Hemlock at 10,400'. A 70 pcf mud will overbalance formation pressure by 450 psi. Be Maximum possible surface pressure: 3500 psi. Care must be exercised to avoid swabbing the well when pulling injection string. C, Any kicks should be handled by normal procedures. All personnel should be made aware of these methods. The hole is to be kept full at all times. D. Blowout prevention equipment: Class III - 5000 psi for all work. 'RECEIVED NOV 7 1.%,0 ~.laska 011 & Gas Cons, Commission PROGRAM 1. Pull CEV at 10,257 feet. e Move in contract rig and kill well with 70 pcf clay base drilling fluid as directed by Production Foreman. 3. Install safety plug in do-nut, remove xmas tree. e Install and test Class III, 5000 psi BOPE, including 5000 psi blow and kill lines. Alaska Oil & Gas Conservation Commission and U.S.G.S. to witness test. Remove plug. Be Release packers. Uppermost packer is 2-3/8" x 5½" Baker "FH-I" at 10,302 feet. Remaining hydraulic packer is a 2-3/8" x 5½" Brown HS-16-1 Model at 10,526 feet, with "CC" safety joint at 10,517 feet 6. Pull tubing and production equipment. 7. RIH with packer mill and retrieve Baker Model "D" at 10,659 feet. 8. RIH with 4,5/8" bit and clean out to 10,740 feet or as deep as possible. ge Make up hydraulic packers and jewelry on 2-3/8" tubing; run 2-3/8" x 3½" string per supplementary program to be furnished. Hydrotest tubing to 6500 psi. 10. Set hydraulic-packers. 11. Install plug in do-nut. Remove BOPE and install 10,000 psi injection tree. Test tree to 6500 psi with clean water. 12. Remove plug, release rig. 13. Backflow intervals separately to clean up well. Return to injection in selected intervals per supplementary program. RECEIVED NOV 7 1980 ~,laska Oil & t3as Cons, Commission Anchorage LEI~K A1 Z2. V. @ 69o°Z' .. /0, '$06' i ~042~' /o. 4s4' t lo, s/o' . · · Lq. SO' ~. L~ . 7-0 ~ $/4,4.j7 TO~ OFz/N~ ~ 21 JT~. ~UE TU~/~G _ _ 66~.93' 9695 ' --/0, p57.07 --/0,270.22' ~ C~MCO I dT /0,302 00' ~ ' ' [ - I d T 2~" fUI 7~/~G ..... JI. 62' 9~' j . e JTS. 2~" EU~ TU*/NG .... - ...... 83.81 H --/0,404. . ,'~ 4~. 66 ,~ ~0~ ~XPA~IOM JT ~.76' H 5' ' ' / u~ ~" ~u~ ~/~G -z/.78 c4~co H a UTS. '~ : PUP JT ~" E~ T~/MG_. ~ ~ 2 + JTS. Z~b" ~'U~m TU/911VG : : , ,, ~ ...... ~-' ~ ~ --/0. 659.00~ ~ ~ ~. 2S ~B ~ --I~664.25' ~ 8A~ER PIALING ASSeMbLY .... I : ,HtO /~. ~ ~"c~. ~ ~.[- /o, ~o' · . Top OF m/¢~o ~~~ NOV 7 1980 ~. : .... . .........· .. . ---~-: ': ' - ...... ,' -: .... ~ ' ~ ~ ............. - : , ~liGIIUla~ ·-... :..:. :. . -,============================== ..... . - ' .' : . . .z. ' ". . . . .... : . 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'. :..':~ ::-: :~::::::::,~ ::::.'..':- ":..'?:~..'..": . .:..::-::..::-, .'-.:...' _::::-:,: .,-'-:J '-:::-:':,::::::~'~::::,,:~A:::..::vo,~.:.:o~ ::::::: :- :,': ..':...... :......:......:...,..:..:.>: :-::.-.'...'.. : . -' :. : · - 2~:~:::5_~I' : ' ~ ' :.::5-::::~0.25.~ ..... :Zi:,/:~':2L2T"'X.:"W"~~ :..':'..::, :'-;;.'.:...'.. ...::::: :..:::-. :: :...-....:"-.::-.:-:-..~: ...:-.....-~ :: :" ,:-:: ~:,:,..:-'.' :~.:-.............. :.:. ::..:...~.:. ========================================================================= : ~ . ~, .~ , -:6._:?~000 .......... ~, : ~ ~ . . ....~ ~ . ...:...... ~ .. .. .. <..~. . ~,,~~.~ ~7~: ~ 7 :. "" ' I : .~ ~:~:~ r~ ~o -- '. ~'..~: . . .. . ...,, ~...~ ............. ~. :~.j . - ~ ~" ~ E C E 'i. V ~ 2 ~ ~-". ' NOV 7kV~ .' .- ~ _.. :. ~; ?,~ ,. ., ,_'~-":'~., . ;kB 03^13::)3B 'XI~ZVIGENNI NSIAGV GNV NDNHD NSV.WqE 'NI.q~NH -G~SO~DN3 ~VINN3.VN ~0 .I. SII V SI ONIMOq90'4 . o -. . 7RA, NS~aTTAL AND ACKN~"._EDGm~NT_ 0F.RE~CEIpT OF MATERIA :ALASKA) ~;ta~ of Alaska Division of OII & Gas ~1 Porcupine Drive Anchorage. Alaska 99504 . . ~ FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREWITH. . C]~ECK AND ADVISE IMLMEDIATELY. .'. PLEASE / Form Submit "IntEntions" tn Trtplh~tat & "Subsequenl l~ports" in Duplicnte STATE OF ALASKA 0IL AND' GAS CONSERVATIO. N ,COMMII'I'EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to decpen or plug back to a diffierent.reservoir. Use "APPLLCATION FOR PERMIT--" for such proposals.) OIL [---{ OAS W-.LL WELL [-~ OT,ER Gas Injecti.on 2. NAt~IE OF OPERATOR Standard 0il Company oF s. ^DDRESS OF OPERATOR P. O. Box 7-839~. Anchorage Alaska. qgqol 4. LOCATION OF WELL Ats~m~, 2051' North & 2070' East from Southwest corner of Section 4, T7N, R9W, SB& M 13. ELEVATIONS (Show whether DF, RT, GR, etc. .KB 167' Check Appropriate Box To Indicate Nature of Notice, Re 6. LEASE DESIGNA~'ION A-ND SF.~IAL NO. A-028997 7. IF INDIAN, A.LLOTTEE OR TRIBE NA1W.~ 8. UmT, ~m-~Z OR ~.s.s~. ' Soldo~qo Creek 9. %VELL NO. SCU 23-4 · 10. F~ ~D ~OOL, OR WI~CAT ~wmng~n R~V~r u. sic.. ~., m., ~., (mo~o~ ~o~ O~EC~IVE) 4~ T7N, R9W, SB & M 12. PEP~.IT NO. }ort, or O'ther Data NOTICE OF INTENTION TO : TEST WATER 8HUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASINO MULTIPLE COMPI.ETE ABANDONs CHANGE PLAN8 SUBSEQUENT REPORT OF: WATER ShUT-Orr ! REPAIRINO WELL PRACTUR" TRE~T'~ENT *LTERZNo c~szso SHOOTZNO OR *Cm~ZZ~O j J <Oth~O Conversion co Gas Inj. {No~: Report re~ult~ of multtpl~ eomplotton on Well (Other) , , J Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated, date of starting any proposed, work. Gas injection initiated 8/12/68. Initial gas inject, ion rate 44,079 MCF/D RECEIVED DIVISION OF MINES & MINERALS ANCHORAGE .. 16. I hereby certify [hat t~he foregoing la ~us and correct District / / .- / 8IOl'{~]D C" '-V. C'HATTV, RT'0N TITLE Superintendent DATE 8/ (Thin space for State office use) CONDITIONS OF APPROVAL, IF A~: DATE See Instructions On Reverse Side Form P~3 REV. ~T>-,~ E %,~F ALASKA OIL AND GAS CONSERVATION ,CO/v'~AITTEE l~ubn~At "Intentions" in Triplieat~ _ & "Sub~equent.H~ports" in DupUca~-'% ~' 5. APl NLF~'IJSiiIICAL CODE SUNDRY NOTICES AND REPORTS ON (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoLr Use "APPLICATION FOR PE£1MIT--" for such proposals.) WELL WELL OTHER 6. LEASE DESIGNATION A.ND SERIAL NO. 2. NA~ME OF OPERATOR Standard Oil Comp_a_By of Californin WOT- 3. ADDRESS OF OPERATOR P.O. Box 7-839, Anchorage: ~ qqsD] 4. LOCATION OF 'WELL At~urfac~ 2051' North and 2070' East from west corner Section 4, T?N, R9W, SB & M A-028997 7. IF INDIA.N, A-LLOTTEE OR 'i'~,iBE NA_M_E 8. UNIT, FA_R2Vi OR LEASE NAME Soldotna Creek 9. WELL NO. SCU 23-4 ]0. FIELD A2qD POOL, OR %VILDCAT · South- Swanson River 11. SEC., T., R., l~I., (I~OTTOM HOL~ OBIECTIVE) 4, T7N, R9W, SB & M 13. ELEVATIONS (Showy whether DF, RT, GR, etc. 12. PERSIIT I~O. KB 167 ' 14. Check Appropriate Box To Ind.[cate NaWre of Notice, Re ~ort, or Other Data NOTICE OF INTENTION TO : FRACTURE TREAT .%! ULTIPLE COMPI,ETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Convert to Gas Inj. ~_x:'. SUBSEQUENT REPORT OF: WATER SIIUT-OFF J ' REPAIRING WELL 8HOOTING OR ACIDIZING ABANDONME~'T* (Other) OTE: Report results of multiple completion on Well ompletion or Recompletton Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. 1. Kill well and pull tubing. 2. Run new tubing with packers and injection. 3. Install 10,000 psi X-mas tree. 4. Return well to production. 5. Your division to be notified upon August 15, 1968. accessories suitable for selective commencement of injection, about RECEIVED MAY 7 !968 DIVISION OF MINES & MINEEAI.~ ANCHOEAGE 16. I hereby certify that thee foregoing i,, true and correct SIGNED. ~.~. ~,- ?",L,,~,' ;~: ~' (Thi~ ~pace for State o~ce use) CONDITIONS OF APPROVAL, IF District ~ri-"cndent DATE ~/__:~ / 6 8 · See Instructions On Reverse Side OIL AND GAS CONSERVATION COMMITTEE i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* ,.. TYr~. oF w~,.L: o,I. ~ -'u-~s' ,~ ' ?~-~-'. ' .... W ELL[__J W ELLL~ DR YL.__J Other b. TYPE OF COMPLETION: NEW [] WORK ~--] DEEP-[] PLUG ~] DIFF.[---] %V ELI, OVER EN BACK nESVR. Other __ , SUBMIT IN DUt :%TE* STATE OF ALASKA i'S& other sl ructions on reverse shte; 2. NAME OF OPERATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL-(-Report location clearly and in accordance with any S'tate requirements)* At surface At top prod. interval reported below At total depth 5. AP1 NU1VIEHJCAL CODE z-o-/x, ?-- ,2~>/o ¢ 6. LEASE DESIGNATION AND SER~L NO. 8. UNIT,FJ~I2vI OR LEASE NAME 9. WE~L NO. 10. FIELD AND POOL, OR WILDC&T i1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO, ] / 22, PRODUCING INTERVAL(S), OF THIS COMPLETION--TOP, BOTTOM, NAME (MD AND TVD)* 24. TY~PE ELECTRIC AND OTHEI% LOGS RU~ R'r, GR, ETC)*I17. ELEV. CASINGttEAD ';.~'~ERV ~:.S'~ I)R ii, LED BY l " c^sl,s TO0r,S 23. WAS D~RECTIONAL SURVEY MADE ! ,1 CA, SLNG SIZE Im mi : CASING RECORD (Report all strings set in w~ll) \VEIGI-IT, LB~'I~T. DEl'TH SET (1VID) HOLE SiZE i~ 26. 11,TY 7, 6 2. ;~7 LINER ~ C O ~I I ~ CEMLNTING RECOILD 20/[OUNT PULLED ~8. PERFORATiON'~ OP~.-~I TO PRODUCTION (interval, size and number) : i DATE FIRST PI%ODUCTIOlq [ I ! 21. mS?OS~T~ON or ~as (Sold, u, ed Ior.fuei, vented, ¢~c.) 27. TUBING RECO1TD SCZEEN (R~.D) SIZE [ DEPTH SET (MD) ~ PACKER SET (MD) ACID, Si:OT, FilAC~i 0'R~, CF-,2,IENT ~QUF'EZ~, ~.Tc. DE~YIi 1NTEiRVAL (MD) AMOUNI' 2~D 1-21ND OF' MA'IEZIAL USED 32. LIST OF ATTACHMENT~ PF~ODUCTION FP~DUCTION MEI[-[OD (Flowii~g, gas lift, pumping--size and type of pumpi OIL-~BBL. I I } V/ELL GTATUS (Producing or [ %VATEI{--BBL. l GAS.OIL ILkTIO WATER--BBL. ] OIL GRAVITY-~I (CORR.) 1 TEST WITNESSED BY 1 .... 33.'I hereby certify that the foregoing and attached information is complete and corre6t as determined from"all-avallab'le records SIGNED _~ ~r'. b~.~ ~'. 6. t~ (,,-~:,o o'-/~. TITLE *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachments. Items :20, and 22:: If this well is completed for separate production fror',': T~OTt' than one interval zone (multiple completion), so state ~n item 20, and in iteq~ 22 show the p~cJuci:~,._q interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, show- ing the acf, ditional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoul:J 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). 34. IgUI'91MAIt¥ OF' F'OHMATION TESTS IN('LUI)IN(; INTEII. V^L TF_..~TED. F'lt'E.~,-c;uIrl£ DATA AND P..F_.COVEIIIF-...¢; OY ()IL, GAS, WATEFL AND MUD 35. NAME GEOLOGIC M ARKEiI~?, MEAS. DE~S'l'~t ': ;~ ~ ~ '-" :~'"'~ UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY The follo~.,i~,~ is a correc~ report of operotio~.~ and prod~ctio~'~ (D.'.ch~dit~ Jrilli~.~ and produci~ weH.~)for the ~o~,t!~ of_ ............. ~_~v~r ......... ;9.6.2. . So~otna Cre~ Unt~ d~ent:'s add,'es.~ P O. ~x 7-839 d/om, p~,,~,$T~~ OIL ~0;~ CALIFo W.O.I. ......... : $ ............ : ' . ~ - -_- ~ .. . ~{ OF ~ TWP. RANGE NO. PRoovo~n BARREI~ O~ OIL GRAVITY (In thou.q~mds) }~ECO5 ;.;REI) ll01le, ad still,e) date and t~ult of ~ content , . ~ ~ic mudo Killed we~ ~h Black Marc mUdo R~oved x-~s I 1~78~ e~pped ~th 5~" :Br~ ~1~1 pa~ker at 10323~, } ' ~m~ed BO~ a~ i~tall~ x~s ~ree. Di$placed mud with Set packer at 10323'. ~ i , ~t~d ~ell to productio~ ~g release~ Nov~ber 24, 1962~ U.SoG.So ? Mo g. Soyster State - ~. R. Rarshall Richfiel~- C. W. Psrry } Ro ! R. RAtter Files - ?roduc~ng NoTE.--,There were ........................................ runs or sales of oil; .............................................. M cu. ft. of gas sold; .............................................. runs or sales of gasoline during the month. (Write "no" whcre applicable.) NOTE. Report on this form is required for each calendar month, regardless of thc status of operations, and intmt be filed in duplicate with the supervisor by the 0th o~ the succeeding month, unless otherwise dh'cried by thc supervisor. ~rm 9-899 P. O. BOX 7-839 · ANCHORAGE · ALASKA PRODUCING DEPARTMENT TELEPHONE BR. 7--6201 C. V. CHATTERTON DISTRICT SU PER INT~,~*~ ................... '~ ....... ,~ ~,,.,.,. ~ ~. F~D~:TiALf ) Augast 2!, 1961 Mr. D. D. Br~ac e State Department of Natural Resources ~2~ Second Avenue Anchorage, Alaska Enclosed, herewith, is the Completion Report for oo!do~na Creek Unit :':;~e~z~ 23-~ (~7~- ,~, for yo~ur information, ant~. ~]ss. Eric! osure ORIGINAL COMPLETION REPORT - NE& WELL STANDARD OIL COMPANY OF CALIFORNIA -%~TERN OPERATIONS INC. - OPERATOR Kenai Peninsula, Cook Inlet Area, Alaska LAND (FFICE: Anchorage LEASE NO. A-028997 PROPERTY: Soldotna Creek Unit WELL NO.: $C~~ SEC. 4 T. 7 N., R. 9 W., Seward B & M. LOCATION: Surface: 2015' North and 2070' East from southwest corner Section 4. ELEVATI~I: 167 K.B. DATE: August 16, 1961 DRILLED BY: Reading & Bates Drilling Company DATE COmmENCED DRiLLING: April 12, 1961 DATE COMPLETED DRILLING: June 1, 1961 DATE OF INITIAL PRODUCTION: 6-6-61 PRODUCTION: Daily Average 856 Flowing Oil 847 Gravity Water 9 TP Gas 190 MCF Bean 36.1 162~ 11/64" summay TOTAL DEPTH: 10775 ' PLUGS: 10740' J~NK: None CASING: ' 22" Conductor cemented at 28'. 11 3/4" casing cemented at 1413' in one stage around shoe with 10OO sacks. 7 5/8" casing cemented at 10,37%' in two stages. First stage around shoe with 500 sacks. D.V. collar at 6983'. Second stage through D.V. with i~ sacks, 1 ~o COMPLETION REPORT SOLDOTNA CREEK UNIT WELL 23-4 s~c.t,!o~, 4, T. 7 N., !~..9.. W.,. Sew.ard B ~ ~M Standard Oil Company of 'California -WOI - Operator Page 2 PERFORATION RECORDS: Perforated 4 - ½" holes/foot over intervals: 10714' -- 10670' 10648' -- 10633' 10621' -- 10539' 10510' -- 10454' 10434' -- 10426' 10406' -- 10394' WELL SURVEYS: 1. Schlumberger I-ES Log, interval 1413' - 10314', & 10100' - 10364'. 2. Schlumberger Sonic Log, interval 1413 ' - 10363 '. 3. Schlumberger Induction Log, interval 10370' - 10770'. 4. Schlumberger Sonic Caliper Log, interval 10765' - 10370 '. 5. Schlumberger Cement Bond Log, interval 9716' - 10737'. 6. Schlumberger Gamma Ray Neutron Log, interval 10762' - 5000'. 7. Schlumberger, Collar Location Log, interval 10762 ' - 5000 '. DRILL STEM TESTS: WSO -'Test on 7 5/8" x 5 1/2" liner lap at 9693'. COMPLETION REPORT SOLDOTNA CREEK UNIT WELL 23,4 STANDARD OIL COMPANY OF 'CALIFORNIA, W, 'O. I. - OPERATOR Page 3 SpUdded at 2.~OO PM, April 12, 1961. Drilled 16,, hoie~ O ' 600' Drilie~ 16,, hole. 600' Drilled 76 pcf mud 600' - 2025' 1425 ' Drilled 78 pcf mud Prepared to run casing. Cemented 11 3/4" casing at 1413' in one stage with 1OO0 sacks of cement using Halliburton power equipment. Used one bottom rubber olug. First stage around shoe with 1000 sacks of 'cement. Pumped 50 bbls. of water ahead, mixed 1000 sacks of cement in 56 mins. using Halliburton truck, dis- placed in 13 mins. using rig pumps. Average slurry weight 116~. Bumped Plug with 1750 psi. Full circulation. Hookload weight of casing before cementing 65,000 after cementing before landing casing 65,000 at time of landing casing 65,000 CASING DETAIL 34 joints or Above K.B. 1417.06' 11 3/4", 47#. J-55, 8 R .. ,00' Landed casing at 1413..O6' Equipped with Baker guide shoe and float collar. Installed and tested BO.WE and Kelly cock to 15OO .osi. OK. Located top of cement at 1134'. Drilled out cement to 1443'. Drilled out shoe at 1413'. Pressure tested 225 psi, bled to 1~0 psi. OK. Drilled 10 5/8" hole 2025' - 3914' 1889' Drilled 70 pcf mud CoMpLETION REPORT SOLDOTNA CREEK UNIT WELL 23-4 section ~4;.~ T~..~ .? N~,:~ R.,~: 9 W,., Seward .B:& .M STANDARD OiL COMpANY OF CALIFORNIA, WAO,I. - OPERATOR Page 4 rilled lO 5/8" hole. 3914' - 10262' 6348' Drilled 71-95 Dcf mud Baroid Mud Logging Unit commenced logging on April 30, 1961 at 9520'. Ran I~ES LOg, interval 1413' 10314' interval 1413 ' - 10363 '. Drilled l0 5/8~' hole. , & 10314' - 10364' , and Sonic Log, 10262 i . 10,370' 108 ' Drilled 94.5 pcf mud May 6, .1961 CEMENTING DETAIL: Cemented 7 5/8" casing at 10375 in 2 stages with 15OO sacks of cement treated with 0.3% HR-4 using Halliburton power equipment. Used one (1) top plug. First stage around shoe with 500 sacks of cement. Pumped 50 bbls. of water ahead, mixed 500 sacks of cement in 14 mins. using Halliburton truck, displaced in 33 mins. using rig pumps. Average slurry weight 116~. Bumped plug with 14OO psi. Full circulation. . Second stage through DV at 6983. Dropped DV bomb, ports failed to op. en. Ran Schlumberger empty carrier gun and chased D.V. Plug to the 6983' and opened D.V. Oollar. Pumped 50 bbls. of water ahead, mixed 1000 sacks of cement in 16 rains, using Halliburton truck, displaced in 24 rains, using rig pumps. Average slurry weight 116~. Closed DV ports with 2500 psi. Full circulation. Cement in place at 11:41 AM. Hookload weight of casing before cementing 203,000 after cementing before landing casing 202,500 at time of landing casing 202,500 S0~TNA CREEK uNIT ~ELL 23.~4 STAND~ 0iL COMPANY ~J~ CALIFORNIA,' ~.6.~. - OPt~ATOR Page CASING DETAIL Top 3 ~otnts or 13o-62 7 5/8", 39# N-80, Speed Tit~ N~Xt 83 jOints or 3491.57 7 5/8", 33.7#, N-80, X-line Next 48 JOints or 2030.64 7 5/8", 29.7#, N-80, Speed Tite Next 21 joints or 898..02 7 5/8", 33.7#, N-80, Speed Tire B~ttom 89 Joints or 3829.44 7 5/8", 39#, N-80, Speed Tite All 244 joints or 10,380.29 Above K.B. ~ _ %.,,2,9 Landed Casing at 10,375. Equipped with Baker shoe and differential float collar. DV collar at 6983'. Changing gel mud to perm base mud. 88 pcf mud May 9,_ _1961 Drilled out cement and shoe. Drilled 6 5/8" hole. 10,370 - 10,384 14' Drilled Drilled additional footage because measured pipe tally did not equal pick-up tally. Double measurement taken, with both tallies checking. Prepared to run core barrel. May 10 - May 11, 1961 Cut Core #1-- 10,384' - 10,414' 31' recovered. Cut Core #2 -- 10,414' - 10,439'. Cut and recovered 25' May 13, 1961 Cut Core ~3-- 10,439' - 10,466' Cut Core #4-- 10,466' - 10,491' 30' Cored Cut & Recovered 27' Cut & Recovered 25' 89.5 pcf mud 89.5 mud 86 pcf mud 88 pcf mud cOMPLETiON REpoRT SOLDOTNA CREEK UNIT WELL 23-4 Sectign~ T. 7 N., hR. 9 W., Sew _ar_d B & M STAND~ ~IL dOMPANY OF CALIFORNIA, W'O,~i. - OPERATOR Page 6 i4, 1961 CUt Core #5 -- 10,491 - 10,519 Cut Core ~6 -- 10,519 ' - 10,547 ' May~16,,, 1961 cut core #7 -- lO,547' - 10,575' coring ahead on Core #8. Cut Core #8 -- 10,575 - 10,603 Cut Core #9 -- 10,603' - 10,631' Cut Core #10-- 10,631- 10,659 Cut Core #11 -- 10,659 - 10,688 May 20, 1961 Cut Core #12 -- 10,688' - 10,717 ' Cut Core #13-- 10,717' - 10,746 ' Cut 28' , Recovered 26.5' 87 pcf mud Cut 28' , Recovered 30' 87 pcf mud Cut and Recovered 28'. 89 pcf mud Cut and recovered 28' 88 pcf mud Cut and Recovered 28' 88 pcf mud Cut and Recovered 28' Cut and Recovered 29' 88 pcf mad Cut and Recovered 29' 88 ocf mud Cut and Recovered 29' 88 pcf mud SO~OTNA.OREEK UNIT WELL 23-4 section 4~. T, 7 N., R. ?W:, Seward B & M ST)4NDARD ~i~' c~M~A~Y 'OF CALiFORNiA., w'O,:i. _ OPERATC~ Page 7 Cut core ~lh -- lO, 746' - lO, 775 ' Cut and Recovered 29' Ran Induction Log, interval 10370' - 10770'. Ran Sonic Caliper Log, interval 10765' - 10370'. 88 pcf mud M..ay 23, 1961 Reamed 6~', hole 10,644' - 10,674'. Reamed6~' hole 10,674' 10,775' 30i reamed. 101' reamed. May. 24, 1961 Circulated, conditioned hole. Pulled up to 7 5/8" casing. Checked hole for fill up. OK. Ran 28 Joints 5~" liner, 20~, hydril thread, Range 3, N-80. Liner length = 1077 ft. Liner Landed at 10770', including float shoe and Burns liner hange~ top of liner 9693'. Cemented with 150 sacks of construc- tion cement 116~ slurry treatedwith 0.3% HR-4~Retarde~Preceded cement with 82 cu. ft. of Diesel Oil. Displaced with 290 cu. ft. of oil base drilling fluid in 24 minutes. May 2~, !~! Cement equalized in liner. Cleaned out 7 5/8" casing to top of liner at 9693'. Ran in with 4~" bit and hit top of cement at 9949'. May 26, 1961 Drilled cement out of 5~" liner to 10,740' with 4½" bit. May .27, 1961 Pressure tested lap on 7 5/8" x 5½" casing with 2550 osi. OK. Ran Schlumberger Cement Bond Log, 9716' - 10,737'. Ran Schlumberger Gamma Ray Neutron and Collar Location Log over interval 10,762' - 5,000'. 1961 W~O - Test on 7 5/8" x 5½" Lap at 9693: Ran 2 outside BT Recorders, 4 2 7/8" perforated tailpipe. 7 5/8" Type C Packer, VR safety joint, Jar~s, inside BT Recorder, Hydrospring tester dual TC valve on 119 stands 2 7/8" Drill pipe. Set packer at 9647. Used 1672' water cushion. Opened tester for flow period at ~:4~ AM, open one hour.. 3/8" bean -- weak blow declining to dead in ten minutes. Dead for remainder of test. Shut tool in for 1/2 hour. Final shut in pressure at 6:45 AM. Pulled and recovered 150' net rise normal drilling fluid. COMPLETION REPORT $OLDOTNA CREEK UNIT WELL 23~4 Tection 4'~- T.~ _7 _N, ~. Ri 9 .W~ ~ Seward B & M vOA O Page 8 Pressure Data: IH ISI IF FF FSI FH Top inside ............ Bottom inside 6222 -- 869 869 969 6222 Top Outside 6291 -- 849 851 9%7 6291 Bott°m outside 6200 -- 788 792 884 6200 wso - OK May,~ 29, 1961 Per~orated 4 - 1/2" holes per foot using carrier guns in the following intervals: 10,714' 10,670', 10,648' -10,633', 10,621' -10,539', 10,510'- pipe. Cleaned out li~r from 10,054' - 10,094' and 10,680' - 10,740'. Circulated.2 7/8" drill pipe and layed down same. Picked up amd landed 2 3/8" and 2 7/8" tubing at 10,637'. TUBING DETAIL 1017.13' 1. 7' 9600.32 ' 2.00' 16.OO' 2 3/8" EVE tubing (32 joints) Cross over 2 7/8" EVE tubing (303 Joints) 2 7/8" EVE tubing Pup joint for doughnut KB to ground Dropped BOPE when removing BOPE. Cleaned up cellar and repaired damage. Installed X-mas tree and pressure tested X-mas tree and ca~ing pack-off's with 4000 psi. OK. May 31, 1961 Displaced mud with 35 barrels diesel and balance with crude oil. Flow tested well. Leak at top of tubing hanger. Attempted to kill well. Pumped 62 barrels of oil base drilling mud down tubing at maximum psi of 1800~. A~temp~ed to set Oosasco plug. Could not seat Cosasco Plug. Pumped 3~O barrels of oil base mud used for displacement. Used oil base mud recovered from drilling. Weight approximately 90 lbs. Went to 5500 psi to displace fluid. When finished, 3300 psi on casing and tubing. Bleading well down to see if dead. COMPLETION REPORT SOLDOTNA CREEK UNIT WELL 23-4 Section 4, T, 7_N.,' R. 9 W..~ Seward B & M STANDARD OIL COMPANY C~ CALIFORNIA, W.O.I. - OPERATOR Page 9 ..June 1,p 1961 Eight (8) hours attempting to kill well with Halliburton power equipment. Flowed and tested well in 12 hours.. COMPLETION DETAIL Installed X-mas tree and tested with '4000~ psi for 45 minutes. Held OK. Commenced displacing mud with oil at 12:00 MN. Pumped 35 barrels of Fuel Oil ahead, followed by 350 barrels of crude oil. Stopped circulating at 3:15 AM. Formation oil to surface at 4:30 AM. Flowed oil to sump until 4:00 AM. Started flowing to trap at 4:30 AM. Representative flow rate and cuts as follows: FLOW RATES BEAN TBG. CSG. TRAP FLO~ PERIOD OIL GAS SIZE PRESS. PRESS. PRESS. __ _ 1. 2 Hrs. 1608 B/D 250 MCF/D 16/64 1600 1550 73# 2. 3/4 Hrs. 630 B/D 72 MCF/D 10/64 1720 1625 70~ % TOTAL OUT % WATER % EMULSION % SAND & MUD CORR. GRAVITY 1. 0.1 0.0 0.O 0.1 36.7 2. O.1 0.O 0.1 0.O 36.8 Shut well in at 8:30 AM. Shut in pressures; Tbg.. pressure 1780~ psi, Casing pressure 1650~psi. Produced estimated 200barrels formation oil. Flowed 250 barrels to tank and estimated 150 barrels to sump. Installed cosasco plug. Rig released at 8:00 PM, June 1, 1961. SRH:jm S. R. HANSEN $oLDoTNA CREEK UNIT WELL 23-4 eCtion 4~ T'.~?~N~. R. 9 W., Sewar~ B & M TAND~ ~XL' c6MPA~Y~oF' CALIFORNI~,"¥~'-0]I. - OPERATOR Page 10 DEPTH 1063' 2025 ' 3914' 4276 ' 4525' 4920' 5413 ' 5775' 6109' 6526' 6713 ' 6.884 ' 7063 ' 7262 ' 7478' 7680' 7837' 8042' 8556' 8854' 9186 ' 9674 ' 10212 ' 10300' 10370' DEVIATION DATA DEGREES O°- 40' 1° lO - OO' - 7.5' 1°- 15' 10 - OO ' 1° - OO' 1° - 45' 1° - OO' 1° - 30' 1° - OO' O° - 30' 5°- OO' 4° - 15' OO - 45' 1° - 30' 1O- 45' O° - 30' Missing 1° - 30' 1° - 45' 1° - OO' 1° - OO' 1° - OO' Io- 15' 1° - 00' COP~PLETION REPORT - PACKER INSTALLATION STANDARD OIL COI-~PANY OF CALIFORNIA -~ST~N OPERATIONS INC. - OPERATOR AREA: Kenai Peninsula, Cook Inlet Area, Alaska LAND OFFICE: Anchorage LEASE NO.: A-028997 PROPERTY: Soldotna Creek Unit ~LL NO.: SCU 23-4 Section 4 T 7 N., R. 9 W., Seward B&M LOCATION: Surface: 2015' North and 2070' East from Southwest corner Section 4 ELEVATION: 167 K.B. K.B. is 15' above ground. DATE: June I9, 1963. ~ . ~~ C'V. CHATTERTON' ~ist~ict SUperintendent CONTRACTOR: Santa Fe Drilling Company Rig #35 DATE COMMENCED REMEDIAL WORK: November 8, 1962 DATE COMPLETF~D REMEDIAL WORK: November 24, 1962 SUMMARY TOTAL DEPTH: 10775 ' PLUGS: 10740' - 10770' CASING: 22" cemented at 28'. 11 3/4" cemented at 1413, 7 5/8" cemented at 10,375' 1077' of 5½" liner cemented at 10,770' top at 9693' ~ · COMPLETION REPORT - PACKER INSTALLATION SOLDOTNA CREEK UNIT 23-4 Page 2 Section 4 T. 7 N.~ R. 9 W., Seward B&M STANDARD OIL CGMPANY OF CALIFORNIA - %'3estern Operations, Inc. -'0PERATCR .... November ,8,~, 1962 Commenced rigging up at 4:00 AM. November 9-11~ 1,962 Conditioned Black Magic Mud and waited on new spool for rig. November 12, 1962 Attempted to kill well. Fluid bypassed around tubing landing mandrel. Attempted to set Coasco plug in tubing landing mandrel. Retriever failed. Flowed well to tank while cleaning rig. November. 13, 1962 Flowed well to tank and circulated Black Magic. Recovered Cosasco plug and s oclat adapter. November 14, 1962 Conditioned Black Magic Mud. Killed well with 80 pcf mud using Halliburton pump truck. Novembe. r 15, 1962 Removed x-mas tree and installed BOPE. Pulled 2 7/8" tubing out of hole and ran 5 ½" casing scraper. November 16, .1962 Worked casing scraper through perforations 10454' - 10714'. Circulated and conditioned hole. Ran in and set Howco RTTS packer. Removed rotary table, BOPE and landing flange. November 17 ~,,, ,1,962,. Removed secondary packoff. Installed new packoff scal and installed new landing flange. Pressure tested with 3500 psi. OK. Reinstalled BOPE and pulled packer. November 18, 1962. Reran 2 7/8" X 2 3/8" tubing equipped with packer. COMPLETION REPORT - PAC ~KER INSTALLATION Page 3 SOLDOTNA CREEK UNIT 23-4 Section 4 T. 7, N.,,,R. 9, W,.~ Seward B&M STANDARD OIL COMPAMY OF CALIFORNIA, WESTLRN OP!,RATIONS, INC. - OPERATOR Nove.mb.er' 19.~ 196.2. Ran and landed tubing. Removed BOPE and installed x-mas tree. Attempted to break circulation. Ran Agnew & Sweet wireline, stopped at 9682'. Removed x-mas tree and reinstalled BOPE. Pulled tubing out of hole. ,N~o~,eber 2,0~ 1962 Ran open ended tubing to top of liner at 9693'. Circulated. Hit hard bridge at 10,697'. WAshed out bridge to 10712'. Ran to bottom at 10,759'. Pulled up 5' and circulated.. Circulated out pieces of rubber and cuttings. Nqvember 21~ 1962 Pulled open ended tubing and ran back in with 4 5/8" bit. Hit small bridge at 10609'. Ran to 10754' and circulated. ~o~vembe,r, ,2.2,: 1962 Pulled bit and ran casing scraper. Circulated hole clean and pulled out. November 2.3.~ 1962 Reran 2 7/8" X 2 3/8" tubing. TUBING DETAIL K.B. to tubing hanger Donut and pup joint 304 joints, 2 7/8", 6.5~,N-80 8R EUE R2 2 7/8" X 2 3/8" crossover 21 joints 2 3/8", 4.7#, N-80 8R EUE R2 Camco Sleeve Valve i joint 2 3/8", 4.7#, N-80, 8R EUE R2 Brown CC Safety joint Pup joint Brown 5 ½" X 2 3/8" HS-16-1 packer 2 joints 2 3/8", 4.7#, N-80, 8R EUE R2 Camco ~'D" Nipple 9 joints 2 3/8", 4.7#, N-80 8R EUE R2, Beveled collar on bottom Tubing Landed at K.B. Depth 15.68' 2.40' 18.08 9591-70' 9609.78 1.57' 9611.35 666.21' 10,277.56 2.55 ' 10, 2 80.11 31.65' 10,311.76 · 95 ' 10,312.71 10.08' 10,322 · 79 3.94' 10,326.73 63.72' 10,390.45 · 87' 10,391.32 286.48' 10,677.80 · 25' 10,678.05 Removed BOPE and installed x-mas tree. Displaced mud with oil and set packer at 10, 32.3 ' · November 24~ 1962 Returned well to production. Rig released at 1:00 A~M. S.R. HANSEN 'UNITED STATES DEPARTMENT OF THE iNTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42d~.356.5. Appruval expir,.~ Anchorage, LESSEE'S MONTHLY REPORT OF OPERATIONS Alaska ........ .7'1~' t'~:.glo;cin. 2 is a corzv'ct: repot!, o/' oparatAwz, s at:d prodtectio~z. (izzchtdi~t~ drillin.,j a~ed produ.,/in~' ~v'c/fs)/br th, c ,,~,o,,[h. o/ ....... ga7 ....... /2.6~, So!dotna Creek Unit .................... ,h '~"{/'-~ ....... - ......... : .~f,,,,,~'s ~dJr~,~.~. . P. O. Box 7-839 ......... ~:',,ml,,~,~/. ' c. 7N 9W Drilled 1,3 5/8" hole '?~[.3' - 10,370'. Ran induction, electrical and sonic lo~s. C~mented ?" casi~ a t 10,375' in two stages with ~00 sacl{s around shoe, and 100~ sacks thromgb D.V. collar at 6982'. Changed ~ " ~r'o~, Oc.i oil base drilli~f flui~. Drilled out cement and shoe. Drilled 6 3/q" hole !0,37a' .- ~O~ .,32~'. Cored 6 3/8" hole ' '-" .... n .... ~ ,, ' ~ ~' /~'31' - 10,77~' R~ Induction~ 10,3.'~h' lO,631 ~ ~.,¢c 6 aole .~,.. . Eleetrie¢.l, end Sonic ~;'aliper Lo~,s. 0oene¢ 6 3./q'' ia.nd 6" hole to 6}:" 3~a to 1, ,- . , 'ac o,d, 1. 7 or : lin r ~/shoe at ~.;,'~ ~'"¢'~.¢ ¢,.¢ T:? of ce,tent ~ Fg~hg'. "~-~eme~~~~~~%¢ 99h9' -~i0,Th0'. Cested lap on 7 ~/8" x ~-" casing w/2~¢O psi. ~ ........... , Collar Log Held 0F. Ran Co. eDt BoCd !,o~ and '¢¢ut-on-¢sm~a r;'~Y - ........ . ,{~;ld OK .... r d ~ .. ~.:" holes ., over in~ervals 10~7!~~ - ]0,670~ I0~6~8' - 10~63~', 10,6~~ - /?' R~ tubing and hung at ~0,6,7'. ~emov~ BCPE. Drdpped Clea~ed up cellar Pqnd r~paired d~ge. ZnStal~ed x-mas tree. Tested with' 1~000 r,~5. ~ispla. ced ~e~ra bsse~drill, ing .fluid with Flo,~-tested ~el~. ~oosa~co plug v{lve failed to held. Attempted to kilt ,~el.1 to deter~&ne ~h7 CosascO seat ineffective. Determined that tubing ~tmn:k~ei se~ OK. Did not ~ttemf,t t~ repair Cosasco seat. Fl~d ~mll to cle~n u~j Represe~,stive ~ow r~te::, 16OO B/D, MCF/D, 16/6h" bean; 160~ tubing Tessure, ~; ~o~_~ ?,._ -~sin%~. 735 trao. ores~. Corr. ',grm.~ty ]6j.?o APi.~ Totr~ qut O.].~. Shut in pressures iT]0/l~h~ tbg,/csg..%%6 release~. 2.: 2:00 i.PM ,~ne 1, 1961. '~ CC: U.S.G.S. - Mean ~. Soyster (2) ' ' ~'~ld ~ a · , ,~i~ Cord W. R~ch~ z .... ~ _rry Fifo: Producing ; Explore[ion '~d NOTE. Thcr~ were .................................... rdns er sales of o~1; ...................................... M cu. fg. of gas sold; .............................................. ru.s r,r ,-:alc.s ~:;f ~asoline during thc mo~,th. (Write "n,,," ,,vi.'rc. atq)licaldt;.) NoT~:.--!teport on this form i~ .rc(l,tirc,! fl]r ~ach ca.lendar month, regnrdh'~s n[ thc .q:t',~q ,~f o}>cr;~tign;% gn(l l]l!lSt bo liied in duplicate with the supervisor by the 6th of the succeeding month, unloss otherwise ,iireetcd by thc ;¢ulmrvisor. 1;'orn~ 9-329 MIY !o !96'1 ....... ~ ...... '-~ q'~' ~ ~'~ ~ R .... F~'~' "' ~ .~ ' ~ ' .... ~., No'r~.---Repor~ ori '~hi.~ f'm:m i~ ',requital for earl ~:'~aie~.da~.- nuont, l;q reg~rd!es~ of ¢~e ~t,;~tus of operations, a~td mus~ b~'<. ~i~c! in (b~J~MIT IN TPJPL~ATE) UNI'rED STATE~ DEPARTM£NT OF' TH£ INTERIOR G~.OG IGAI. ~JRVKY SUNDRY NOTICES AND REPORTS ON WELLS II L III III I 111 llll Il Il I · I I I~I I II II II The elevation of th~~ ~bove n level is ..... ~§_. Pc (~:pprox:L~.lo') DETAILS OF WORK Tkle ~~.__S.._upertntendent-Alask~ APPLICATION ~ ~;:': ::'~ i~'~'-' '~" ' FOR PERMIT TO DRILL,' DEEPEN OR PLUG BACK ' '.--.Lc- , ...... - ;: · AP~P_.:I~JC4T[-Q~N .TO DRIL~L;~ DEEPEN ~ PLUG BACK ~ Address [?::, ~" . ':~; - : .~ /-: :-':~'~ ~: ' ,. - -- ~ -: . City. ,~:~-: _ -'.-. -: : State ~ :-': ::': .... . )':'' -.-' :-'--'' '' -~ ~ DESCRI-PTION"~OF::~WELL~ AND ~EASE Name ~f lease '~ [ Well number : ~ Elevation (ground) 5Vell location (~ive footage from section lines) 8eetion~township~ran~o 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 applied~for well on the same lease: feet ( ~ feet Proposed depth: Number of acres in lease: - {Rot~ary or cable tools 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 an application to deepen or plug'back, briefly describe work to be done, giving present producing zone and expected new producing zone) APR 1 106! CERTIFICATE: I, the undersigned, state that I am the ~-~~*of the~~ (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated~j~ereip a~e ~rue, oq~rect and complete to ~,.~rigma/ signea the best of my knowledge. J.T. CROOKER Permit Number: 1~"' ~l Approval Date: A~rnva~ , PR. 1 1961 Approved By: .L __ Notice: Before s~ i~~PmP~ have Wen Intr ~ O~ ~atur~ ~e~ces See s ~~verse Side of Form Signature Alaska Off and Gas Conservation Commission Application to Dr/Il, Deepen or Plug Back Form No. P-1 Authorized by Order No. I Effective October 1, 1958