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Home My WebLink About160-042 Perf Sundries ( ¡l 0 - (7 4- ~ / (to .. 0 L/ ::z.. Subject: Perf Sundries From: "Eynon, Don" <DEEynon@MarathonOiLeom> Date: Tue, 23 Dee 2003 15:20: 15 -0900 r 9:;:"Vy irtphßA U:9~r"t(~~rn,~JI)n<::WirÎtpn.£å ubect@~ dlTlin. §tat e,- åW~ U§»-., 9~:r"Titu §;"."[)~ Qi §~ ..'~M'.~'. ~I:.~ Øify1JEiil;j$@Ma£f!lþ()n(2)i 1"~.p()rT1>-, :'¡!:\Nå 1~~)'I<E3r1I'.\, ',,' <KDWalsh@MarathonOiLcom> ' ,""""""',....> ',:""'". ,:,'" , , .. , , """',' , , , , , ' , , , ,.., ',', ',. " "," , .'" ..".. ,.. "'" Winton; , Ut, V\ CJ-- Please ~he first Falls Creek # 1 rd Sundry application with approval number 303-383. The perforation interval was changed after discussions with the geology department. I apologize for the additional paperwork. Thank you for the quick response and verbal approval to do the Falls Creek 1 rd and GO # 1 perforating. Thanks, Don Eynon Production Engineer Marathon Oil Company Alaska Business Unit Telephone 907-564-6318 «Eynon, D E (Don).vcf» Eynon, D E (Don) <DEEynon@MarathonOil.com> ENGR II PROD Alaska Production Region ALASKA REGN-OPERA TIONS (3086) I~ ~ er:., v Ii " , (} , -~ (" .tol ,t (tJ fîC cfX CfJ-A ./r, () , ", '/1 \ '-1' (I" pf ~tANNE[)) DEC ~ 1 2003 1 of 1 12/23/2003 3:24 PM .' +9155646489 T-345 P.O1 F-384 Jun,,20-02 08:45am From-MARATHON Marathon OilCompany June 20, 2002 Steve McMain AOGCC 333 West 7~ Ave Suite 100 Anchorage, AK 99501 Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 9071564-6305 Fax 9071564-6489 Dear Mr. McMain: Please find faxed with this cover letter, a copy of McLane's Surveying report for the proper offset information for the Falls Creek #1 original wellbore and the Falls Creek #1 RD sidetrack located in the Falls Creek Unit. The proper offset for the identical surface location of these two wells is as follows: 1898' FSL, 2885' FEL, Section 6, TIN, R12W, S.M. Also faxed, is a copy of the directional survey for the Falls Creek #1RD per your request. You will note on the 10-407 submitted for this well's completion on 04/22/02 that the location data for the top of the producing interval at 7850' MD is correct at 1821' FSL, 5013' FEL, Sec. 6, T1N, R12W SM. The offset data at the 8900' MD TD is no._.~t correct due to a typographical error in the E/W desoription. The corre~ offset at TD should mad 1830' FSL, 5025' FEL, Sec. 6, TIN, R12W SM. A 10-407 page #1 which includes the offset TD correction for the Falls Creek #1 RD has also been included with this cover letter. Please accept our apologies for any confusion associated with this matter. If you would like any other information, please contact me at 564-6305 or kdwalsh@marathonoil.com. Sincerely, Ken D. W alsh Advanced Production Engineer RECEIVED JUN. 2 0 200~. AlaskaOil&GasConi.~n +9165646489 F,~LL,5 ORE EK NO. 1 28,8,5' FEL SECTION ~, TIN, t~121,~, 5.1"1., A~ N 22~45~2 T-345 P.02 F-384 TI. 24~.1 1'15" C:I'"IF:'- \ (' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OILJ~J GAsJ~J SUSPENDEDJ---1 ABANDONEDJ~J SERVICEJ~J 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 Classification of Service Well 4. Location of Well at Surface · _ 1899' N &"2ra,~ ~ from southeast corner, sec. 6, T1 N, R12W, SM ~ of '~~ At top Producing Interval At Total Depth 442' N & 2952' W of surface location. 5. Elevation in feet (indicate KB, DF, etc.) 276' RKB 12. Date Spudded 12/7/1960 17. Total Depth (MD+TVD) 13795'MD/13382q'VD 7. Permit Number 60-42 8. APl Number 50- 133-10005-00 9. Unit or Lease Name Falls Creek Unit 10. Well Number Falls Creek #1 11. Field and Pool 6. Lease Designation and Serial No. Falls Creek/Tyonek ADL-00590 13. Date T.D. Reached 14. D o Susp.~_ r A~b.a~ 15. Water Depth, if offshore 16. No. of Completions 4/4/1961 ~'~~~ I N/A feet MSL I one 18. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 3151'MD/3088'TVD IYesr~N° D I N/A feet MDI N/A 22. Type Electric or Other Logs Run I-ES, Sonic, Micro, Continuous Dipmeter, CBL, Neutron Collar, GR 23 CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE Not Reported HOLE SIZE SEI-FING DEPTH MD TOP BOTTOM 0 248' 0 2468' 0 8600' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) CEMENTING RECORD AMOUNT PULLED 20" 97 26" in place, 480Ex N/A 13-3/8' 54.5 J-55 18-5/8" in place, 16605x N/A 9-5/8" 40 N-80 12-1/4" in place, 18845x N/A 25. TUBING RECORD Perforation depths: (All isolated) MD 3900'-3911'; 5290'-5315'; 5442'-5470'; 7562'-7583'; 7585'-7600' TVD 3819'-3830'; 5158'-5181 '; 5302'-5329'; 7324'-7344'; 7346'-7360' RECEIVED JUN 1 8 2002 Anchomoe SIZE J DEPTH SET (MD) PACKER SET (MD) 2-7/8", e.5#, N-SO J7545' (Pulled 5881') 9-5/8", 40# J Baker Model 'D' 7545' 9-5/8', 40# J Cement Retainer 5225' 9-5/8", 40# J Cement Retainer 3850' 9-5/8", 40# JCIBP 3151' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13250'-13050' 12100'-11850' 10100'-9900' 8700'-8500' 7641'-7562' 5991'-5200' 4011'-3850' 27. PRODUCTION TEST Date First Production Date of Test 5/21/1961 J Method of Operation (Flowing, gas lift, etc.) N/A Hours Tested J PRODUCTION FOR 1.5o ITEST PERIOD J CALCULATED J24-HOUR RATE 85 sks. Construction cement 140 sks. Construction cement 85 sks. Construction cement 35 sks. Construction cement 30 sks. Class "G" cement w/additives 340 sks. Class "G" cement w/additives 71 sks. Class "G" cement w/additives OIL-BBL 0 GAS-MCF 118 WATER-BBL 0 CHOKE SIZE J GAS-OIL RATIO 2O/64 J N/A Flow Tubing Pres. Casing Pressure OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) 1435 N/A 0 1880 0 N/A 28. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Interbedded sandstone, shale and coal. Sandstone contains methane with porosity ranges from 5-18%. Form 10-407 Rev. 7-1-80 N:~ddg~kghwells~(BU 33-6~OGCCABDNFC#1 .xl$ CONT" 4F ' AL RBDNS BFL Submit in Triplicate 29. 80. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered NAME MEAS. DEPTH TRUE VERT. DEPTH and gravity, GOR, and time of each phase. Beluga 2077 2057 Tyonek 5120 4995 Tyonek T3 7227 7008 Hemlock 11605 11236 West Foreland 12569 12172 RECEIVED JUN 1 8 2002 81. LIST OF ATTACHMENTS Daily operations summary, wellbore schematic, directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed I~1~--~ , ~~n Walsh Title Advanced Pro, duction Eng. Date 5/30/2002 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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), sc 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 cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other- explain. ' Item 28: If no cores taken, indicate "none". Form 10-407 N:\drlg~sterllng~u32-9~AOG CCABDNFC#1 .xls Well: FALLS CREEK #1 RD Well Operations Summary Date DFS Ftg MD TVD Operations Summary MW i 06/22/01 06/23/01 06/24/01 .06/26/01 0 0 8,395 0 0 8,395 0 8,395 06/26/01 0 0 8~395 06/27101 0 8,395 06/28/01 0 0 8,395 06/26/01 0 8,395 06/30/01 0 0 8,395 07/01/01 07/02/01 07/03/01 0 8,395 0 8,395 07104/Ol 07/O5/Ol 0 8,395 0 0 8,395 0 8,395 07106/01 0 0 8,395 07107/Ol 0 8,395 07106/01 0 0 8,395 07/09/01 / 07/10/01 0 8,395 0 0 8,395 BEGIN TO PJD RIG AND PREPARE TO MOVE. . 0 PJD RIG ON KBU 23X-6 LOCATION AND MOVE TO FALLS CREEK#1 LOCATION AND BEGIN PJU. 0 CONT. R/U GLACIER#1 RIG. 0 COMPLETE RIGGING UP RIG. RAJ AND TEST CHOKE LINE AND CHOKE MANIFOLD. BLEED DOWN CSG PRESSURE WITH NO CHANGE IN TUBING PRESSURE. R/U SLICK LINE AND TEST LUBRICATOR. RIH W/SLICKLINE TOOLS AND ATTEMPT TO PULL 2 7/8' OTIS "D' PLUG. COULD NOT LATCH PLUG. AI'rEMPT TO RUN 2 1/4" BAILER. COULD NOT PASS 36'. POOH AND FIND HYDRATE IN BAILER. 0 BREAK UP HYDRATE IN TUBING. RETRIEVE OTIS "D' PLUG O . 502' AND OTIS "D' PLUG O 7441'. RUN 2.31' GAUGE TO BOTTOM OF TUBING ~ 7640'. ATTEMPT TO PUNCH A HOLE IN 2 7/8' TUBING ~ 7506'. RIH TO RETRIEVE COLLAR STOP. 0 RETRIEVE COLLAR STOP. RAJ TO RUN APRS EL TUBING . PUNCHER. EL BOP WOULD NOT TEST. R/D APRS EQUIPMENT. MOBILIZE AND R/U SCHLUMBERGER TUBING PUNCHER EQUIPMENT. RIH AND PUNCH TUBING 7500' TO 7502'. NO CHANGE IN TBG OR CSG PRESSURE. ATTEMPT TO CIRCULATE TUBING W/2980 PSI. 0 SHOOT TUBING PUNCHER GUNS: 7300' TO 7302' 8 HOLES. . 7000' TO 7002' 8 HOLES. 6492'-6493.5' 7 HOLES. NO COMMUNICATION BETWEEN TBG AND CSG. 0 PUNCH TUBING 6006'-6008', 6494'-5496', 5006'-5008',4492'-4494', . 3989'-3991'(4SPF). NO INDICATION OF COMUNICATION BETWEEN TUBING AND CASING. BULLHEAD 65BBLS 6%KCL DOWN TUBING. BLEED OFF CASING PRESSURE THROUGH CHOKE. MONITOR TUBING AND CASING PRESSURE. 0 MONITOR TUBING AND CASING. BLEED ANNULUS OFF AND '. FILL. MONITOR TUBING AND CASING. SET BPV. N/D TREE. N/U BOP. 0 TESTING BOPE. · · , 0 FINISH BOP TEST. PULL BPV. WORK STUCK TUBING AND · ATTEMPT TO CIRC. MONITOR WELL AND MOBILIZE SCHLUMBERGER. PJU SCHLUMBERGER EL. 0 PUNCH TUBING AND CIRCULATE. RIH AND CUT TUBING ~ 8.67 7538' AND 3500'. POOH W/3500' OF 2 7/8" TUBING AND IJD. CHANGE UPPER PIPE RAMS TO 4" . TEST PIPE RAMS. 0 COMPLETE BOP TEST. PAJ DP. RIH W/INFLATABLE PACKER 8.7 AND SET ~' 2952'. DUMP 8' SAND ON TOP AND PLACE A 100' CEMENT PLUG ON TOP OF SAND. POOH WI SETTING TOOL. WU AND RACK BACK COLLARS AND HWDP WHILE WOC. 0 TEST CSG. N/D BOP. N/D WELLHEAD. FABRICATE 8.67 EXTENSION TO 9 5/8" STUB AND WELD ON. N/U WELLHEAD AND TEST. N/U BOP. 0 N/U BOP AND TEST. TEST 9 6/8" CSG. RIH W/8.5' BIT AND 8.7 BHA AND DRILL CEMENT. POOH. RIH AND RETRIEVE TAM INFLATABLE PACKER. 0 RIH W/8 1/8" WASH SHOE AND 7 5/B" WASHPIPE. WASH OVER' 8.7 2 7/8" TUBING F/3500' TO 3910. TORQUE INCREASED AND COULD.NOT WASH PAST 3910'. POOH. IJD DRAG TYPE SHOE AND P/U WAVE TYPE SHOE. 0 RIH W/7 5/8" WASHPIPE W/8 1/8" WAVE TYPE SHOE. MILL 6". 8.72 APPEARS TO BE MILLING METAL. POOH. RIH W/OVERSHOT BHA AND LATCH FISH. POOH. 0 POOH W/2 7/8" TBG FISH. L/D 12 JOINTS, 406' OF 2 7/8" TBG. 8.7 TEST BOPE. RIH W/5 3/4" OVERSHOT BHA. LATCH FISH AND ' CIRCULATE. MAKE 2 1/8" GAUGE RUN TO 4139'. 0 MAKE GAUGE RUNS W/WIRELINE. RELEASE FROM FISH AND 8.8 POOH W/OVERSHOT. RIH W/WASHOVER ASSY. CAN NOT PASS 3910'. POOH. RIH W/OVERSHOT ASSY AND LATCH FISH. RAJ SCHLUMBERGER AND RIH AND FIRE JET CUTTER @ 3988'. POOH AND R/D SCHLUMBERGER. Well: FALLS CREEK #1 RD Well Operations Summary Date DFS Ftg MD TVD Operations Summary MW 07/11/01 I 8,395 07/12/01 2 8,395 07/13/01 8,395 07/14/01 8,395 07/15/01 8,395 07/16/01 8,395 07/17/01 8,395 07/18/01. 8,395 07/19/01 8,395 07/20/01 ' 8,395 07/21/01 8,395 07/22/01 8,395 07/23/01 5,458 07/24/01 5,488 07/25/01 5,496 07/26101 5,496 0 P.O.H. / LAY DOWN 82' FISH / RUN 8 1/2" TAPERED MILL THRU 8.8 PERFS O 3910' -3914' ! WASHING OVER FISH O 4000' O 200-300' PER HR. / MODERATE AMOUNTS OF GAS PRESENT 0 WASH-OVER TUBING TO 4600' / LAY DOWN WASHPIPE AND 8.8 RUN IN WITH OVERSHOT/WORK OVER TOP OF FISH - PULL 50000 OVER STRING WT. / LOST FISH / COULD NOT RE- ENGAGE / POH/PICK UP NEW EXT. AND. GRAPPLE/R.I.H. 0 LATCH FISH, PULL AND JAR WITH 120,000# OVERPULL / RUN 8.8 JET CUTTER TO TOP OF FISH / SAT DOWN SOLID I ATTEMPT TO RELEASE OVERSHOT (TIGHT) / P.O.H. - HAD TWISTED 2 7/8" OFF O 4519' LAYED DOWN 531.59' 2 7/8" TBG. (SPLIT COLLAR ON LAST JT. LEAVING 2 7/8" THREAD LOOKING UP) PICK UP WASHPIPE / WASHING FROM 4600' 0 WASH TO 5129' i P.O.H. AND P/U 2 7/8" OUTSIDE CUTTER 8.7 -R.I.HJ CUT 04557' AND LAY DOWN 32.30 2 7/8' I GOOD CUT / RUNNING IN WI OVERSHOTTO NEW TOP OF FISH 04557' / WILL FOLLOW WITH JET CUT O 5129' 0 R.I.H. W/OVERSHOT AND ENGAGE FISH I RUN GUAGE RING 8.7 TO BTM.; RUN JET CUTTER AND CUT 05126' (3' ABOVE FILL) LAY DOWN 571' 2 7/8" TBG. RUNNING IN W/ WASHPIPE RIGGED WI PILOT MILL IN DRIVE BUSHING TO DRESS OFF T.O.F. O END OF EA. W.P. RUN 0 WASH OVER 2 7/8'" TBG. FROM 5129' TO 5308' I P.O.H. TO 8.7 INSPECT SHOE (INSIDE -BOI'rOM OF SHOE CUT SMOOTH 045-60 DEGREES) TEST B.O.P.S I WAIT ON TOOLS FROM BAKER I 0 RUN IN WI 6 1/2' X 4 7/8' SHOE ON 5 3/4' WASHPIPE I WORK 8.8 OVER TOP OF FISH 05126'; WASH DOWN TO. 5308' WASH WITH SHOE 5308' TO 5311' I POH (SMALL CHUNK OF 9 5/8"COUPLING WEDGED IN SHOE ) I RUN IN WI OVERSHOT - CHASE FISH 5126' TO 5220' I POH WET 0 LAY DOWN 99.14' 2 7/8" TBG. I RuN IN WI 5 3/4" SHOE , "T' ' 8.8 DOG, AND 6 JTS. 5 '3/4" WASHPIPE I RECOVER 74.75' 2 7/8' TBG. I RUN IN WI TAPERED MILL AND STRING MILL 0 LAY DOWN TAPERED MILL AND STRING MILL I R.I.H. AND MILL 8.8 WI 5 3/4" SHOE (SHOE WAS COMPLETELY WORN OUT, JUNK BASKET FULL OF CASING PIECES AND CEMENT CHUNKS) /RUNNING IN WITH (SMALL) TAPERED MILL 0 MILL'TO 5314' I LAY DOWN MILL AND PAJ JET BASKET - 8.8 JET/WASH 5267' TO 5315' I RECOVER FIST SIZE CHUNK OF CEMENT FROM BASKET (NO METAL) .RUN IN WITH JUNK MILL AND (3) JUNK BASKETS I MILLED OR DRILLED 5312' TO 5323'ITORQUEY i PUMP SWEEP//NO METAL cu'n'INGS SEEN I P.O.H. 0. P.O.H. I CLEAN FULL JUNK BASKETS/MAKE UP BHA AND SET 8.8 ON JUNK 028' (BELOW WEAR RING) ATTEMPT TO FISH - KNOCKED DOWNHOLE I R.I.H. WI SHOE AND SINGLE JT. WASHPIPE / WASH 5322' TO' 5340 I ' P.O.H. 0 LAY DOWN WASHPIPE / PICK UP MILL AND MILLING W/ 8.8 LESS THAN 100l)~ TO ATTEMPT TO GET INTO CASING ' 0 MILLING TO 5363' I LAY DOWN MILLING ASS'Y. AND PICK UP 8.75 SHOE AND WASHPIPE / WASHING OVER TUBING O 40' - 50' PER HR. TO PERFS O 5442' I WASHING O 2' TO 5' PER HR. THRU PERFS 0 WASH-OVER TUBING TO 5468' I POH / TEST BOP'S / RIH I 8.7 WASHOVER TO5488' 0 WASH OVER TBG~ 5468' TO 5496' / RETRIEVE 95.77' BADLY 8.7 SCARRED ,WRAPPED UP TBG. / R.I.H. WITH NEW SHOE / WASH OVERTBG. FROM 5496' TO 5911'( 415' ) P.O.H. 0 RUN IN TO CUT TBG. WITH OUTSIDE CUTTER / CUT O 5881' ( 8.7 30' UP FROM BTM. OF WASH)'. P.O.H. NO RECOVERY I REMOVED 18" X 2" FLAT CUT PIECE OF TBG. FROM CUI'FER / R.I.H. WITH NEW CUTTER Well: FALLS CREEK #1 RD Well operations Summary Date DFS Ftg MD 'I'VD Operations Summary MW 07/27/01 5,881 0 07/28/01 5,881 0 07/29/01 3,151 0 07/30/01 3,109 '0 07/31/01 I 20 3,130 3,074 08/01/01 2 4 3,134 3,078 08/02/01 '3 173 3,307 3,237 08/03/01 4 358 ' 3,605 3,526 08/04/01 5 631 4,296 3,985 08/05/01 6 579 4,875 4,428 08/06/01 7 365 5,240 4,737 08/07/01 8 .435 5,675 5,131 08/08/01 9 6,029 5,480. 08/09/01 10 6,650 6,078 08/10/01 11 6,905 6,335 08/11/01 12 7,430 08/12/01 13 7,815 . 08/13/01 14 8,125 08/14/01 15 8,800 08/15/01 16 8,900 08/18/01 17 8,900 6,955 7,242 7,402 8,227 8,323 8,323 · ' 8.7 CUT TBG. @ 5881' / P.O.H. / LAY DOWN 388.40' 2 7/8" TBG. / R.I.H. WI NEW SHOE / MILLNG OVER PIPE O 5991 O 0600 WASH OVER FISH TO 5992' / P.O.H. / MILL WAS DESTROYED / ' 8.7 /PREPARE TO PLUG BACK / RIH W/ RETAINER TO 5225' / TEST LINES / ESTABLISH INJECTION RATES I MIX AND PUMP CMT. I SPOT 13 CU. FT. ON TOP REVERSING OUT O 6 AM SET RETAINER O 3850' / SQUEEZED CMT. UNDER AND SPOT 8.7 CMT. ON TOP OF RETAINER / R.I.H. W/ CASING SCRAPER TO 3300' / RIG UP WIREMNE AND SET BRIDGE PLUG O 3151' / TEST CASING AND BRIDGE PLUG TO 2500 PSI FOR 30 MIN .-O.K. / START PICKING UP WHIPSTOCK, MILLS, AND BHA RUN IN WITH WHIPSTOCK / SET ON BAKER BRIDGE PLUG / 8.7 PUSHED PLUG DOWNHOLE TO 3159' - (5) FT. BELOW 9 5/8' COUPLING I P.O.H AND PICK UP MILLING ASS'Y. / PUSH PLUG TO TOP OF CEMENT ON RETAINER O 3815' / P.O.H. I RUN HOWCO E-Z DRILL / SET 03109' / RUNNING IN TO SET 30000~ ON E-Z DRILL O 0600 SET 30000~ DRILLSTRING ON E-Z DRILL / TEST CASING AND 8.8 E-Z DRILL TO 2500 PSI ) P.O.HJ S.L.M. LAY DOWN BHA I TEST B.O.P. 'S I PICK UP WHIPSTOCK I R.I.H. I ORIENTATE 20 DEGREES RIGHT OF HIGH SIDE I CUTTING WINDOW AND OPEN HOL. E FROM 3103' TO 3130' DRILL NEW HOLE F/3130' TO 3134'. PUMP SWEEP AND CIRC. .8.8 CLEAN. MIX NEW MUD. DISPLACE WELL TO NEW MUD. PERFORM LOT. POOH. POOH W/MILL ASSY AND L/D. P/U 6 3/4" BIT AND STEERABLE 8.9 ASSY AND RIH. DIR DRILL AND SURVEY F/3134' TO 3307'. TROUBLE SHOOT MUD PUMP#2. WORK ON'MUD PUMP#2 AND R/U BJ UNIT. CHANGE LINERS 9.1 IN PUMP#1. RIH AND TEST BJ UNIT. DIR DRILL.AND SURVEY F/3307' TO 3542'. CBUX2'W/BJ UNIT. DIR DRILL AND SURVEY F/3542' TO 3565'. .- DIR DRILL AND SURVEY F/3665' TO' 3979'. CBUX2. POOH TO 9.3 3130'. CBU. SLUG PIPE AND POOH. C/O BIT. RIH DIR DRILL AND SURVEY F/3979' TO 4296. CBUX3. DIR DRILL AND SURVEY FI4296' TO 4610'. CBUX3. 9.2 POOH TO 3110. CBU. SERVICE RIG. 'RIH. DIR DRILL AND SURVEY F/4610' TO 4875. DRILL F/4875' TO 4923'. CBUX3. POOH. C/O BIT. RIH. DRILL 9.3 F/4623' TO 5240'. CBUX2. CBU. DRILL F/5246' TO 5365'. CBUX3. DRILL F/5365' TO 5675'. 9.4 CBUX3. POOH. ~'EST BOP"S / R.I.H. W/BIT #6 /'SLIP AND CUT DRILL LINE / 9.4 R.I.H. / DRILLING-SLIDING 5675'- 6029' , DRILL / SLIDE TO DROP ANGLE / DRILL TO 6650' 9.3 9.4 DRILL TO 6698' / TRIP FOR BIT , BRAKE REPAIR , AND M.W.D. BATTERY / WORKING TO REPAIR GEAR END OF #2 PUMP AND DRILLING 06905' DRILL/SLIDE / DRILL FROM 6905' TO 7430' DRILL ; SHOR~"TRIPTO 6550' ; DRILL AND SLIDE TO 7815 '/ CIRCULATING SAMPLES FOR LOGGERS; PREPARE TO P.O.H. P.O.H. FROM 7815' / CHANGE OUT BIT AND REPLACE MOTOR / PICK UP (11) HEAVI -WATE R.I.H. AND DRILL DRILLING FROM 8125' TO '8800' DRILL TO 8900 (TD) / CBU AND SWEEP / SHORT TRIP TO WINDOW / CBU AND HIGH VISC SWEEP / P.O.H. AND RIG UP FOR LOGS LOG WELL / TEST B O P' S / R.I.H. FOR LAST CLEANOUT BEFORE CASING 9.3 9.3 9.3 9.2 9.2 9.3 Jul-ZO-01 04:4epm From-~ARATHffi OI L +9166646480 STATE OF A~OKA A~S~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS P.O~/03 F-066 1. Type of Request: Abandon X__ Suspend_ Operation Shutclown __ Re-enter suspended well - Alter casing _ Change app¢oved program 2, Name of Operator .Marathon Oil Company 8. Address PO Box 196168 Anchorage, AK 99519 4. Location of well at surface Repair well_ Pluggin9_ Pull tubing_ -- 5. Type of Well: Developme~lt _ Exploratory X Stmtlgraphle _ Service Time extension_ Stimulate_ Variance ~ Perlorata _ Other_ At effeotive depth 6. Datum elevation (DF or KB) 276 RKB . 7. Unit or Property flame Falls Creek 6. Well number Falls Cree~ #1 9, Permit number 60-42 .. 10. APl number .. 50-183-1000,5-00 11. Field/Pool Folio Creek Unit At total depth ~' ,. .,, . , .... 44P-' Nortl~ ~ 2__2' west of surfaoe location ~-2. P~e~e~ well condition summary ....... Total Depth: measured clfllllng 13,795 feet (approx) tree vertical 13,382 feet Effective depth: measured 8395 feet (approx) true vertlcal 8128 feet Casing Length Sl~,e Struofu~l 28' ' 36" Conductor 248' 20' Surfe0e 2468' 13,375" Intennecliate 8e00' 9.625" Produo'don Liner Plugs (meaeured) 13,260'-13,050'; 12,1 10,100'-9,g00'; 8,700'.8,395' dunk(measumd), Oenq~ted Measured depth Tree vertical depth 28' 28' ~80 sx 248' 248' 1660 ax 2458' 2440' 1884 sx 8600' 8327' ' Pef~omtion de~: measured 3900'-3911'; 52g0-~;5316': 544~.L5470'; 7562'-7583'; T586'-7600' Vue vertical 361g'-3830'; G 168'-5181 '; 5~02',6329'; 7324'-7344';' 7346'.7360' Tul31ng (size, grade, and measured depth) 2,875", 6.6#, N-80 ~ 7614' Peat<era and SSSV (type and measurea depth) Model D peel<er ~1 ?542/, No SSSV ,. .. 13. Attaohme~Its Description summa~/of propoeal _ Detailed operation program X_ ._ BOP sketoh _ 14, Estimated date for oemmencing operation . Oil.._. Nanl~Bf ~l~5'h3~er(~&~'"'' ~ ~,e,~,,~{~:b Date app~ved '17.1 hereby c~rtify~.ha_t?_~oing is trna and corre~ to tho boat of my ,m:ededga.. Signed ~J~.- ~J~_~ Title PmaucdonEngineer Date Iw' Denise M. Titus ..... .......... FOR COMM!.$SlON ,USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integdty.~ BOP Teat_ Location olearance Mechenioal Integrity Test ._. Subsequent form require I i'" 15, status of wetl Maselficatlon as: Gas ~x Suspended ~ 7120/2001 ORIGINAL SIGNED BY AOl~rOved by tile artier of the Commission .. D Taylor Seamount comrn~sla~r ' Data _ _ ... t , Form 10-403 Rev 06115/88 SUBMIT IN TRIPLICATE ORIGINAl. Jul-ZO-01 04:4Spm From-MArATHON OIL .... -~. .~°~. +9166646480 T-762 P.03/03 F-955 ~ J Marathon Oil Company Alaska Region Falls Creek #1 Abandon Prior to Sidetrack History: Falls Creek #1 was drilled to a total depth of 13,795' in 1961. The well has since been plugged back. At present, PBTD =8395' (see attached wellbore diagram). The current wellbore configuration consists of a single 2 7/8" string of production tubing cut at 5323', and a Baker Model "D" permanent packer located at 7545'. There are open perfs both above and below the packer (see attached wellbore schematic). Due to damaged casing, zones below 5315' must be reached by sidetrack. Existing zones must be abandoned prior to exiting the casing. Objective: Cement will be squeezed below a retainer set just above the cut tubing and damaged casing. Another retainer will be placed at 3870' to squeeze the topmost set ofperfs. Procedure: 1. MU Baker 9 5/8" cement retainer to workstring. Set retainer at approx. 5225'. 2. MIRU BJ Services squeeze 97ft3 oS' cement through retainer (see attached cement volumes). Rig back BJ. '~. 3. MIRU Schlumberger. Set cement retainer 3' above coll~ nearest 3850'. '" RDMO Schlumberger. 4. TIH, sting into cement retainer. RU BJ Services to pump 69i~3 bbl. cement through retainer. 5. Proceed to sidetrack. 7/20/2001; 4:41 PM Attachment Cement Volumes: Top Cement Plug: Bottom of retainer: 3850' 100' below base of perforated interval: 4011' Casing volume in 9 5/8", 40ppf: 69 it3 Density: 15.8ppg, Yield: 1.15ft3/sx Cement: 60sx Middle Cement Plug: Bottom ofpacker: 5225' Top ofbackside fill: 5315' Casing volume in 9 5/8", 40ppf: 39 fr3 Density: 15.8 ppg, Yield: 1.15 tt3/sx Cement: 33 sx Lower Cement Plug: Bottom of packer: 7562' 100' below base of perforated interval: 7700' Casing volume in 9 5/8", 40ppf: 58 il3 Density: 15.8 ppg, Yield: 1.15 f~3/sx Cement: 50 sx Total Cement: Volume: 166ft~ Cement: 143sx 7/20/2001; 4:41 PM Creek #1 Proposed Abandonment Cement Retainer @ 3850' Cement Plug 3850'-4011 ' 69 ft3, 60sx Cement Retainer @ 5200' Cement Plug: 5200'-5315' (top of fill) 39 ft3 33sx Backside fill 5315'-top of packer Casing Damage @ 5315' Cement Plug: 7562'-7641' 58 ft3 50sx Open Hole TD 13,795' 36" conductor @ 28' 20" Surface casing @ 248' 13 3/8" @ 2468' Sqz Holes: 3884'-3886' Open Perfs: 3900'-3911 ' Sqz Holes: 5275',5326',5419',5490' Open Perfs: 5290'-5315' 5442'-5470' Baker Model D @ 7545' Szq Holes: ] 7550', 7615' Open Perfs: 7562'-7600' 27/8", 6.5ppf, N-80 8rd @ 7641' 9 5/8", 40 ppf, casing Shoe @ 8600'MD/8327'TVD Marathon Oil Company Alaska Region Domestic Produ~tion DATE: P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 9071561-5311 FAX COVER LETTER PLEASE DELIVER THE FOLLOWING TO: Name: Company: Fax,o.:' _ . ll.?~m~,er Of-pag. ,r'~,~''~'~,. ..m.': .... ,, ..z/ f FROM: Name: ' IILocation/Extension: ..."' _ . T,,,, ,1 mT/SS4-s4~ , iii i iiiii" ii i i . . NOTE: · If transmission is not complete, please call 907/561-5311. A subsidiary of USX Corporation ).~O-d (;O/lO'd ~).,/.-/ Environmentally aware for the long run. 110 IdOH/¥1dWt=uioJ::l mdt, t:tO tO=g~-Inl' Marathon Oil Company Alaska Region Falls Creek #1 Abandon Prior to Sidetrack R£C£1v£D History: Falls Creek #1 was drilled to a total depth of 13,795' in 1961, The well has since been plugged back~ At present, PBTD -8395' (see attached wellbore diagram). The current wellbore configuration consists of a single 2 7~8" string of production tubing cut at 5323', and a Baker Model "D" permanent packer located at 7545', There are open perfs both above and below the packer (see attached wellbore schematic). Due to damaged casing, zones below 5315' must be 'reached by sidetrack, Existing zones must be abandoned prior to exiting the casing, Objective: Cement will be squeezed below a retainer set just above the cut tubing and damaged casing. Another retainer will be placed at 3870' to Squeeze the topmost sci of peris. Procedure: 1. MU Baker 9 518" cement retainer to workstring. TIH. Set r~tainer at approx, 5225'. 1 MIRU BJ Services squeeze 169ft3 of cement through retainer (see attached cement volumes). Sting out of retainer and cap w/--13ftz cement. Reverse , circulate out at low rates/pressures (be cautious of open peffs at 3900'). Rig back BI'. 1 MU second 9 5/8" cement retainer to workstring. TIH. Set retainer at approx. 3850'. RU B~' Services to pump 69ft3 bbl, cement through retainer, Sting out of retainer and cap w/~13ft~ cement. Reverse ckculate out of hole. RDMO 4. MU casing scraper and bit. TIH ,to 3200'. TOH. MIRU Schlumberger. Set CIBP 3' above collar nearest 3150'. RDMO Schlumberger. 6. Pressure test casing to 2500psi for '30 minutes. 7. Prepare to run whipstock for sidetrack per procedure. 7/25/2001; 10:32 AM l~O=d ~O/ZO'd ZZZ=1 110 MOHlWVfl-modd mdVt:tO tO=i~-In¢ Attachment Cement Volumes: First Retainer Volumes: Lower Cement Plug: Bottom of packer: 7562' 100' below base of perforated interval: 7700' Casing volume in 9 5/8", 40ppf: 58 ft___~~ Density: _1.5.8 ppi, Yield: 1_..15 fta/sx Cement: .5.0 sx Tubing Cement Volume: Tubing tail: 7562' Top of robing: 5340.__.~' Tubing volume in 2 7/$", 6.4ppf: 72 ft3 Density: 15.8 opg, Yield: 1.15 ft3/sx Cement: 63 s__~x Middle Cement Plug: Bottom of packer: 5225_' Top of backside fill: 5315.___[' Casing volume in 9 5/8", 40ppf: 39. fta Density: ~, Yield: 1.15 ft~/sx Cement: 33 s.__.~x Cement Cap on Retainer (30'): Casing volume in 9 5/8", 40ppf: 13 ft_._2~ Cement: 11 sx, Total Volume:,182 ft~ Cement: !.58 sx Second Retain, ~r Volumes: Top Cement Plug: Bottom of retainer: 3850' 100' below base of perforated interval: 4011~' Casing volume in 9 5/8", 40ppf: 6_.9 ft3 Density: 1,5.8o_og, Yield: 1.15fta/sx Cement: ,,60sx Cement Cap on Retainer (30'): Casing volume in 9 5/8", 40ppf: 13 ft3.. Cement: 11 sx Total Volume:82 ft~ Cement: 71:'sx Final Cement: Volume: _2.~4ftz Cement: 229 sx 7/25/2001:10:32 AM l~O=d ~O/~O'd ~1.~=~ 68~gvgGGt6+ 110 NOHlWVlfl=moJd md~t:tO tOqg=lnr i ., Falls Creek #1 Proposed Abandonment conductor @ 2.8' CIBP @ +/1 3150' Cement Retainer @ 35S0' Oement Plug: 3650'-4011' Cement Retainer 0 5200' Cement Plug: 5200'-5315' (top of fill) GqZ Holes; $864'-,9886' Open Perfs: 3900'-,.~911' SqZ Holes'. 527~', 5a2S', 541$', S490' Open Perfs: 5290'-5315' 5442'.5470' Bedside fill' 531s',top of peeker Caslr~g Damage @ 531S' Baker Model D @ 7646' Cement Plug: 7562'-7641' Holes: 7550', 7615' ..~ Oper~ Perfs: : 7582'-7600' 2 7t8", 6,Sppf, N-80 ~ 0 7641' g ~", 40 ppf, =aelng Shoe @ 8600~MD/8327'TVD Open Hole TD I ALASKA OiL & GAS. CONSERVATION COMMISSION 333 W. 7TH AVE, SUITE 100 ANCHORAGE, AK 99501-3539 FACSIMILE TRANSMITTAL SHEET FROM: FAX NUMBEI~ " TOTAL NO. OF PAGr~ I~,ICI.UDING (~OVER: PHONE NUMBV-I~ SENDER'S REI~ERI!NCE NUMBER: "YOUR REFERI~NCE NL1MBEI~ , ' [] URGENT ~ FOR REVIEW., . .. ·., ,. [] PLEASE REPLY · · NOTES/COMMENTS: PHONE NO. (907) 279-'1433 , FAX NO. (907) 276~.7542 Falls Creek #1 {" Subject: Falls Creek #1 Date: Mort, 18 Jun 2001 15:47:07 -0800 From: "Titus, Denise M." <DMTitus@MarathonOil.com> To: "Tom Maunder (E-mail)" <tom_rnaunder@admin.state.ak. us> Hi Tom, The recompletion proposal for Falls Creek #1 is a compromise of many requirement& The main objective is to isolate surface pressure (per AOGCC request). Additionally, it remains a goal that the wellbore maintain adequate future utility, In cementing all open perfs (intervals as shallow as 3900' or as deep as 7600') behind 4 1/2" pipe, we remedy the entire problem of pressure to surface. This completion also leaves the wellbore large enough (rs through tubing methods) to be accessible to perforating with large guns, or fracture stimulation at a later date if desired. If you have any further questions regarding the proposed completion. Feel free to call or email. Thanks; Denise M. Titus Marathon Oil Company Alaska Region (907) 564-6317 1 of I 6119101 12:15 PM Marathon OilCompany June 7, 2001 Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 9071561-5311 Fax 9071564-6489 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Suite 100 Anchorage, Alaska 99501 Reference: Falls Creek #1 Dear Mr. Maunder: Enclosed is the APPLICATION FOR SUNDRY APPROVALS form for Marathon well Falls Creek #1. The scope of this workover is to repair the wellbore to alleviate pressure on the annulus. If you need any additional information, I can be reached at 907-564-6317 or by e-mail at dmtitus@marathonoil.com. Sincerely, Denise M. Titus Production Engineer ORIGINAL {'" STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend _ Operation Shutdown __ Re-enter suspended well _ Alter casing _ Repair well ~ Plugging __ Time extension _ Stimulate _ Change approved program _ Pull tubing ~ Variance __ Perforate__ Other _ 2. Name of Operator .Marathon Oil Company 3. Address PO Box 196168 Anchorage, AK 99519 4. Location of well at surface 1899' N & 252' West from southeast corner. Sec 6, T1N, R12W ~% At top of productive interval 6. Datum elevation (DF or KB) 276 RKB 7. Unit or Property name Falls Creek 8. Well number At effective depth At total depth 442' North & 2952' west of surface location 5. Type of Well: Development _ Exploratory X Stratigraphic __ Service Falls Creek #1 feet 9. Permit number 60-42 ~ 10. APl number 50-133-10005-00 11. Field/Pool Falls Creek Unit 12. Present well condition summary Total Depth: measured drilling (approx) true vertical Effective depth: measured (approx) true vertical Casing Length Structural 28' Conductor 248' Surface 2468' Intermediate 8600' Production Liner 13,795 feet 13,382 feet Plugs (measured) 13,250'-13,050'; 12,100'-11850'; 10,100'-9,900'; 8,700'-8,395' 8395 feet Junk (measured) 8128 feet Size Cemented Measured depth True vertical depth 36" 28' 28' 20" 480 sx 248' 248' 13.375" 1660 sx 2458' 2440' 9.625" 1884 sx 8600' 8327' Perforation depth: measured true vertical 3900'-3911'; 5290'-5315'; 5442'-5470'; 7562'-7583'; 7585'-7600'_. ... (, 3819'-3830'; 5158'-5181'; 5302'-5329'; 7324'-7344'; 7346'-7360t'~ F -. ~ E ! V E D Tubing (size, grade, and measured depth) 2.875", 6.5#, N-80 @ 7614' Packers and SSSV (type and measured depth) Model D packer @ 7542', No SSSV 13. Attachments Description summary of proposal _ Detailed operation program X__ BOP sketch 14. Estimated date for commencing operation 6/25/01 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas ~ Suspended 17. I hereby certi~/that the foreg.oi~ng~ue Signed ~ ~s~e and correct to the best of my knowledge. Title Production Engineer Date couu,ss,o. ConditiOnSplugOf approval:integrity Notify Commission. Bops°Test ~[,repre§entatiVeLocationmay witneSSclearanceS~ Mechanical In~gri~Test~ Subsequentfo~ require 10-~~ Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED J. M. Heu~, Commissioner Date ~./~/q/0 /'1 SUBMIT IN/TRIPLICATE ORIGINAL Marathon Oil Company Alaska Region Falls Creek #1 Workover Procedure History: Falls Creek #1 was drilled to a total depth of 13,795' in 1961. The well has since been plugged back. At present, PBTD =8395' (see attached wellbore diagram). The current wellbore configuration consists of a single 2 7/8" string of production tubing w/a Baker Model "D" permanent packer. There are open peris both above and below the packer. A tubing or packer leak is suspected as the surface annulus pressure builds to 2600 psi (most plausibly originating, below the packer, but possibly from open peris on the annulus). Objective: The primary objective of this workover is to remedy the pressure on the tubing x casing annulus as requested by the AOGCC. This will be achieved by pulling the existing packer/tubing completion. Followed by a wellbore clean.ut to 8550'. Existing perforations at 3900'-3911',, and 5290'-5315', 5442'-5470', and 7562'-7600' will be isolated behind a cemented string of 4V2" pipe. An additional objective of this well will be to open and stimulate zones from 6920'- .. 7020', 7562'-7600', and 6920'-7020' at a later date. Prior to any work. vet events, the pad and access road will require dirt work. Procedure: 1. Call out Vetco remove 2 7/8" BPV . MIRU Pollard Wireline. RIH and retrieve Otis "D" lock plugs w/H equalizing sub at 505' and 7420'. (*Use caution when pulling plugs as 2600 psi is expected below top plug. Also, lower plug is thought to be leaking. Hydrates will likely be an issue.) RIH w/2.25" gauge ring to tubing tail at 7641' POOH. RIH w/mechanical tubing punch. Punch holes in tubing at 7500'. POOH. RDMO Pollard. . MIRU BI pumping services. Tie in to pump down tubing. Rig up flowback iron, choke, and gas buster from the annulus to a 340 bbl tank. Commence pumping kill weight fluid (6% KC1) down 2 7/8" tubing, circulating existing wellbore fluids and gas out annulus. Close annulus and continue pumping (in attempt to bullhead into peris below packer). Max pressure, 3000psi. Note volume pumped and volume displaced. RDMO BJ Services. 4. Call out Vet6o to replace tubing BPV for rig mobilization. 5. MIRU Glacier Drilling #1 rig. NU BOPs and test to 250/5000 psi. 6. RU and pull on tubing. If tubing and seals come free, proceed to step 8. (NOTE: be sure to cheek OD of SEALS to confirm ID of packer.) 7. If pipe cannot be pulled free: MIRU APRS. Run free point. RIH w/chemical cutter. Cut pipe above stuck spot or at 7535' (-¥2 joint above seals). RDMO APRS. 8. Circulate well, expect some gas. TOH LD 2 7/8" pipe. . MIRU PES. Prepare to run TAM International inflatable bridge plug. MU bridge plug and setting tool to workstring. RI/-I to 3850'. Establish up and down weights. Circulate if needed (do not rotate). Drop 15/16" setting ball. Pressure up on workstring until 200 psi differential. Hold for 5 minutes. Increase pressure to 400 psi and hold for 2 minutes. Increase pressure in 400 psi increments until setting sleeve shears (+/- 1875 psi). Watch for pressure fluctuation to confirm sleeve shift. 10. Pull 5000 lbs over string weight and slack off 5000 lbs below string weight to confirm bridge plug is set. Maintain set down weight. Torque workstring to left while simultaneously picking up to release from bridge plug. POOH w/workstring and running tool, spotting 10' of sand and 10' of cement on top of bridge plug. 11. Pressure test plug and casing to 1000 psi. Hold at least 15 minutes. Bleed off pressure. 12. ND BOP Stack. 13. MI ABB Vetco. Remove existing 7 tubing hea6.. Replace w/1 l"3m x 9 5/8"5m tubing head. 14. Pressure test new tubing head to 250/5000 psi. 15. NU BOPs and pressure test to 250/5000 psi. 16. RIH w/cement mill. Drill out cement and wash sand as required. POOH 17. MU TAMCON Overshot and jars to workstring. RII-I to bridge plug and tag. Overshot will auto latch onto fishing neck. 18. Pull up to +/- 5000 lbs to confirm latch. Pressure up annulus to balance any potential pressure that might be below bridge plug. Maintain applied pressure and workstring tension. Slowly rotate workstring to the right +/- 8 rounds to release bridge plug assembly. Watch for pressure drop and workstring weight decrease to indicate bridge plug release. Allow at least 15 minutes for element to deflate. Circulate gas out if necessary. POOH w/tools (take care not to let workstring rotate). LD workstring and inflatable packer and retrieval tool. RDMO PES. 19. MU Baker BHA#1 as follows to retrieve seals if necessary (skip to step #20 if seals came with tubing): 8 1/8" 8 1/8" 8 1/8" 6 1/4" 6 1/4" 12-6 1/4" HMC w/2 7/8" Superloy Insert (If required) 150 Overshot w/2 7/8" Basket Grapple w/MCP Top Extension OD Bumper Jar OD Oil Jar Drill Collars T.I.H. to top of chemical cut tubing. Establish all up, down, and rotating weights. Engage fish with overshot. Take overpull to pull seals lose. POOH w/seals (NOTE: be sure to check OD of SEALS to confirm ID of packer.) 20. MU Baker BHA #2 as follows to retrieve permanent packer: 12-18 8 1/2" MM Mill w/4 ~A PRT Spear w/4 aA Grapple w/5.5' of Ext. Tripple Conn. Sub 7" OD Boot Collar Baskets 4 1/2" Reg Box x 4 1/2" IF Box Sub 6 1/4" OD Bumper Jar 6 1/4" OD Oil Jar 6 1/4" OD Drill Collars T.I.H to top of packer, establish all string weights before milling packer. Mill packer per standard BOT packer milling procedures. After packer drops, circulate bottoms up to remove any trapped gas. POOH w/packer. 21. If unable to fish OD of packer, make up BHA#3: Itco Spear to catch 4.750" ID of the packer (correct ID if necessary) Spear Stop sub 6 1/4" OD Bumper Jar 6 1/4" OD Oil Jar 12-6 1/4" Drill Collars T.I.H. to top packer. Establish all up, down, and rotating weights. Engage fish with spears. POOH with packer. 22. TIH w/casing scraper and 8 V2" tri-cone bit. Clean out to 8550'. TOH laying down scraper, mill, and drillpipe. 23. MIRU Schlumberger wireline. Run RST and CBL logs. RDMO Schlumberger 24. Make up float equipment to 4 V2" casing l~as follows: a. Float shoe b. One joint 4 W', 11.6ppf, L-80 LTC (tubing thread) c. Float Collar d. One joint 4 W' 11.6ppf, L-80 LTC e. Landing Collar f. 57 jts 4 W', 11.6 ppf, L-80 LTC g. 4 W' "X" nipple (to sit at approx 6820'). h. 161 jts 4 W', 11.6ppf, L-80 i. MIRU Pollard control line banding equipment. Install side pocket man&el with chemical injection valve. (:for' ~b:15~4 i~-~/'r.m ~ 'Ox~ ~.~d~ j. 66 jts 4 u,, y2,11.6ppf, L-80 spaced out to surface '~ ~~' k. 4 V2" fluted tubing hanger t~[~'-o 25. Run injection line to surface, banding along side of tubing. Space out and land fluted tubing hanger. Terminate and pressure test injection line. RDMO Pollard. 26. MU joint of drill pipe w/cement head (pre-loaded w/wiper plug) 27. Commence pumping cement, taking returns out annulus via fluted mandrel hanger. 28. 29. Drop plug and pump 6% KC1 displacement. Be certain to bump plug. Top of cement should be 3400'. WOC 12 hrs. Pressure test ljae~ to 3500-psi for 30 minutes. Bleed off pressure and test backside to 1000 psi for 30 minutes. Bleed off pressure. Install BPV. ND BOPs. 30. Install packoff and tree. Swap BPV for dual check and pressure test tree to 5000 psi. Pull check valve and install BPV. 31. RDMO GD#1 32. Secure and lock tree as necessary. ,,o 764! ' Falls Creek #1 Proposed Workover Liner Completion TOC @ 3400' Open Hole TO 13,795' 36" conductor @ 28' 133/8" @ 2468' 1660 sx 4 i/2" Liner, 11.6 ppf, L-80 LTC Surface-8550' Existing Perfs: 3900'-391 1 ' Existing Perfs: 5290'-5315' 5442'-5470' Potential Perfs: 6920'-7020' Existing Perfs: 7562'-7600' Potential Perfs: 8390'-8440' 95/8",40 ppf, casing Shoe @ 860Q'MO/8327'TVO Marathon OilCompany Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 995194}168 Telephone 9071561-5311 Fax 9071564-6489 May 31,2001 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Suite 100 Anchorage, Alaska 99501 Reference: Falls Creek #1 Dear Mr. Maunder: Enclosed is the APPLICATION FOR Creek #1. The scope of this workover the annulus. If you need any or by e-mail at dmtitus~marathonoil Sincerely, Denise M. Titus Production Engineer APPROVALS form for Marathon well Falls to repair the wellbore to alleviate pressure on information, I can be reached at 907-564-6317 OP, IGINAL STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well ~ Plugging _ Time extension _ Stimulate _ Change approved program __ Pull tubing ~ Variance _ Perforate _ Other _ 2. Name of Operator .Marathon Oil Company 3. Address PO Box 196168 Anchorage, AK 99519 5. Type of Well: Development _ Exploratory X Stratigraphic _ Service . 4. Location of well at surface 1899' N & 252' West from southeast corner. Sec 6, T1 N, R12W At top of productive interval At effective depth At total depth 442' North & 2952' west of surface location 12. Present well condition summary Total Depth: measured drilling (approx) true vertical 13,795 feet 13,382 feet 6. Datum elevation (DF or KB) 276 RKB 7. Unit or Property name Falls Creek 8. Well number Falls Creek #1 9. Permit number 60-42 10. APl number 50-133-10005-00 11. Field/Pool Falls Creek Unit Plugs(measured) 13,250'-13,050'; 12,100'-11850'; 10,100'-9,900'; 8,700'-8,395' Effective depth: measured 8395 feet Junk (measured) (approx) true vertical 8128 feet feet Casing Length Size Cemented Measured depth Structural 28' 36" 28' Conductor 248' 20" 480 sx 248' Surface 2468' 13.375" 1660 sx 2458' Intermediate 8600' 9.625" 1884 sx 8600' Production Liner True vertical depth 28' 248' 2440' 8327' Perforation depth: measured 3900'-3911'; 5290'-5315'; 5442'-5470'; 7562'-7583'; 7585'-7600' true vertical 3819'-3830'; 5158'-5181 '; 5302'-5329'; 7324'-7344'; 7346'-7360' Tubing (size, grade, and measured depth) 2.875", 6.5#, N-80 @ 7614' Packers and SSSV (type and measured depth) Model D packer @ 7542', No SSSV 13. Attachments Description summary of proposal _ Detailed operation program X__ BOP sketch 14. Estimated date for commencing operation 6/25/01 Oil 16. If proposal was verbally approved Name of approver Date approved 17. I hereby cer~fy that the for?go')~i~/is true and correct to the best of my knowledge. Signed ~~r ~ Title Production Engineer Date Dehise M. Titus ~/~'Y"~,.~I '7 15. Status of well classification as: Gas X 5/30/2001 Suspended FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test_ Location clearance_ Mechanical Integrity Test_ Subsequent form require 10- ]Approval No. I Approved by the order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Marathon Oil Company Alaska Region Falls Creek #1 Workover Procedure History: Falls Creek #1 was drilled to a total depth of 13,795' in 1961. The well has since been plugged back. At present, PBTD =8395' (see attached wellbore diagram). The current wellbore configuration consists of a single 2 7/8" string of production tubing w/a Baker Model "D" permanent packer. There are open perfs both above and below the packer. A tubing or packer leak is suspected as the surface annulus pressure builds to 2600 psi (most plausibly originating below the packer, but possibly from open peffs on the annulus). Objective: The primary objective of this workover is to remedy the pressure on the tubing x casing annulus as requested by the AOGCC. This will be achieved by pulling the existing packer/tubing completion. Followed by a wellbore cleanout to 8500'. Existing perforations at 3900'-3911', and 5290'-5315', and 5442'-5470' will be isolated between two packers. The well will be recompleted with 3 W' pipe. The pipe between the packers will be P-110 to allow fracture stimulation at a later date if desired. Prior to any workover events, the pad and access road will require dirt work. Procedure: 1. Call out Vetco remove 2 7/8" BPV . MIRU Pollard Wireline. RIH and retrieve Otis "D" lock plugs w/H equalizing sub at 505' and 7420'. (*Use caution when pulling plugs as 2600 psi is expected below top plug. Also, lower plug is thought to be leaking. Hydrates will likely be an issue.) RIH w/2.25" gauge ring to tubing tail at 7641' POOH. RIH w/mechanical tubing punch. Punch holes in tubing at 7500'. POOH. RDMO Pollard. . MIRU BJ pumping services. Tie in to pump down tubing. Rig up flowback iron on annulus to tank. Pump kill weight fluid (6% KC1) down 2 7/8" tubing, circulating existing wellbore fluids and gas out annulus. Close annulus and continue pumping (in attempt to bullhead into perfs below packer). Max pressure, 3000psi. Note volume pumped and volume displaced. RDMO BJ Services. 4. Call out Vetco to replace tubing BPV for rig mobilization. 5. MIRU Glacier Drilling #1 rig. NU BOPs and test to 250/5000 psi. 6. RU and pull on tubing. If tubing and seals come free, proceed to step 8. (NOTE: be sure to check OD of SEALS to confirm ID of packer.) 7. If pipe cannot be pulled free: MIRU APRS w/chemical cutter. Cut pipe at 7535' (-¥,- joint above seals). RDMO APRS. 8. Circulate well, expect some gas. TOH LD 2 7/8" pipe. . MIRU PES. Prepare to run TAM International inflatable packer. MU packer and setting tool to workstring. RIH to 3850'. Establish up and down weights. Circulate if needed (do not rotate). Drop 15/16" setting ball. Pressure up on workstring until 200 psi differential. Hold for 5 minutes. Increase pressure to 400 psi and hold for 2 minutes. Increase pressure in 400 psi increments until setting sleeve shears (+/- 1875 psi). Watch for pressure fluctuation to confirm sleeve shift. 10. Pull 5000 lbs over string weight and slack off 5000 lbs below string weight to confirm bridge plug is set. Maintain set down weight. Torque workstring to left while simultaneously picking up to release from bridge plug. POOH w/workstring and running tool, spotting 10' of sand and 10' of cement on top of bridge plug. 11. Pressure test plug and casing to 1000 psi. Hold at least 15 minutes. Bleed off pressure. 12. ND BOP Stack. 13. MI ABB Vetco. Remove existing 7" tubing head. Replace w/1 l"3m x 9 5/8"5m tubing head. 14. Pressure test new tubing head to 250/5000 psi. 15. NU BOPs and pressure test to 250/5000 psi. 16. RIH w/cement mill. Drill out cement and wash sand as required. POOH 17. MU TAMCON Overshot and jars to workstring. RIH to bridge plug and tag. Overshot will auto latch onto fishing neck. 18. Pull up to +/- 5000 lbs to confirm latch. Pressure up annulus to balance any potential pressure that might be below bridge plug. Maintain applied pressure and workstring tension. Slowly rotate workstring to the right +/- 8 rounds to release bridge plug assembly. Watch for pressure drop and workstring weight decrease to indicate bridge plug release. Allow at least 15 minutes for element to deflate. Circulate gas out if necessary. POOH w/tools (take care not to let workstring rotate). LD workstring and inflatable packer and retrieval tool. RDMO PES. 19. MU Baker BHA#1 as follows to retrieve seals if necessary (skip to step #20 if seals came with tubing): 8 1/8" 8 1/8" 8 1/8" 6 1/4" 6 1/4" 12-6 1/4" HMC w/2 7/8" Superloy Insert (If required) 150 Overshot w/2 7/8" Basket Grapple w/MCP Top Extension OD Bumper Jar OD Oil Jar Drill Collars T.I.H. to top of chemical cut tubing. Establish all up, down, and rotating weights. Engage fish with overshot. Take overpull to pull seals lose. POOH w/seals (NOTE: be sure to check OD of SEALS to confirm ID of packer.) 20. MU Baker BHA #2 as follows to retrieve permanent packer: 12-18 8 1/2" MM Mill w/4 ¼ PRT Spear w/4 ~A Grapple w/5.5' of Ext. Tripple Conn. Sub 7" OD Boot Collar Baskets 4 1/2" Reg Box x 4 1/2" IF Box Sub 6 1/4" OD Bumper Jar 6 1/4" OD Oil Jar 6 1/4" OD Drill Collars T.I.H to top of packer, establish all string weights before milling packer. Mill packer per standard BOT packer milling procedures. After packer drops, circulate bottoms up to remove any trapped gas. POOH w/packer. 21. If unable to fish OD of packer, make up BHA#3: Itco Spear to catch 4.750" ID of the packer (correct ID if necessary) Spear Stop sub 6 1/4" OD Bumper Jar 6 1/4" OD Oil Jar 12-6 1/4" Drill Collars T.I.H. to top packer. Establish all up, down, and rotating weights. Engage fish with spears. POOH with packer. 22. TIH w/casing scraper and 8 Va" th-cone bit. Clean out to 8550'. TOH laying down scraper, mill, and drillpipe. 23. MIRU Schlumberger wireline. Run RST and CBL logs. RDMO Schlumberger 24. Make up the the bottom packer/tailpipe assembly to workstring, including wireline reentry guide, and x nipple with PX plug in place. 25. RIH w/lower packer and tailpipe assembly. Set packer at -5550' and POOH. 26. MU upper packer w/spaced out P-110 tailpipe and seals. RIH and sting seals into lower packer. Set packer and POOH. 27. Pressure test casing, tubing, and seals to 1000 psi for 30 minutes. 28. Change out pipe rams for 3 a/2" tubing. Pressure test to 250/5000 psi. 29. RIH w/3V2" tubing and seals. Sting into packer and mark pipe. Space out and land tubing hanger. 30. Pressure test backside to 2000 psi for 30 minutes. 31. Install and pressure test tree to 5000 psi. Install BPV. 32. RDMO GD#1 IIII II _ -- ~e, too' Methanol Injection Mandrel @ 2000' Permanent Packer wI sealbore extension @ 3870' Permanent Packer wI sealbore extension @ 5550' EOT @ 6850' Cleaned out to 8500' Proposed Workover Open Hole TD 13,795' 36" conductor @ 28' 20" Surface casing @ 248' 133/8" @ 2468' Isolated Perfs: 3900'-3911 ' Section of31/2", 9.2ppf, P-110 (burst 13,340 psi) Isolated Perfs: 5290'-5315' 5442'-5470' 31/2", 9.3ppf, L-80 production tubing (P-110 between packers) Potential Perfs: 6920'-7020' Primary Producing Perfs: 7562'-7600' Potential Perfs: 8390'-8440' 95/8", Shoe @ 8600'MD/8327'TVD · ~. ~e:· Falls Creek # 1 -Reply ) ) \ ') IbÓ ~o4-e- Subject: Re: Falls Creek #1 -Reply Date: Fri, 06 Oct 2000 15:48:36 -0500 From: "Denise M Titus" <DMTitus@MarathonOi1.com> To: blair _ wondzell@admin.state.ak.us, CEY oung@MarathonOil.com, JBRiddle@MarathonOil.com, J GEller@MarathonOil.com, PKBerga@MarathonOil.com, RJ Affinito@MarathonOil.com, WECissell@MarathonOil.com Blair, Ultimately, the plan for Falls Creek #1 will be a workover sometime next year. In the meantime, we will regularly monitor and bleed the annulus pressure as needed. I recognize the need to relieve wellhead pressure as a matter of public safety. This is a condition we are working toward. Achieving this will be a somewhat tricky process as we have a limited and conflicting history for this well. I will continue to keep you posted with our progress and plans (and sundries where needed) . Thanks Denise Titus Marathon Oil Company 3201 C Street, Suite 800 Anchorage, AK 99503 (907) 564-6317 " "'liI.n~'. [,.~., J~JL "1'1 ·l·'~ LaOS '¡'''Q'''' ¡oj¡. \\..,~,(;.' ~ \. ~Vln!"\ 1 of 1 10/9/008:14 AM MARATHON OIL COMPANY " ) \ DAILY WELL OPERATIONS REPORT ') /60 - 04 e... PAGE 1 OF 1 DATE: 10/4/00 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: N/A FIELD: TUBING: Falls Creek Unit WELL #: FC#1 9 5/8" 31/2" 2 7/8" CASING: TREE CONDITION: BENCHES OPEN: Bleed pressure from annulus Monitoring Pressure Hrs. SUMMARY OF OPERATIONS 10/3 Pumped -- 25 bbl runoff water from cellar Checked pressures: Ptubing = Opsi Pannulus = 2750psi P13 3/8 = Opsi Bled annulus to drum. Pressure declined to -700psi in 12 minutes. Recovered about 1 + 1/4 drum diesel. Continue to bleed well to 400 psi. 51 well to watch build up. Pressure climbed to 550 psi after 1 hr. Secure well and leave Slover night to observe BU. 10/4 Pressure on well after 15 hours: 1375 psi Vendor Equipment Daily Cost Cumulative Cost DAILY COST: CUM: REPORTED BY: Titus Falls Creek" # 1 ~ ) ') Subject: Falls Creek #1 Date: Mon, 02 Oct 2000 18:11 :55 -0500 From: "Denise M Titus" <DMTitus@MarathonOi1.com> To: blair _ wondzell@admin.state.ak.us, CEY oung@MarathonOil.com, DRErwin@MarathonOil.com, JGEller@MarathonOil.com, PKBerga@MarathonOil.com, RJAffinito@MarathonOil.com, WECissel1@MarathonOil.com Just to keep you updated on the process of bleeding the pressure off of Falls Creek # 1 we II. . . Pete Berga and I took a trip out to the location Friday to observe the present state of the well. The location looks as follows: The gate has a couple pad locks. These can be removed with a bolt cutter and should be replaced with one of our own locks. The road in is fairly overgrown with brush and limbs. The wellhead sits near the entrance of a fairly small, overgrown pad. It looks as though maneuvering equipment on the pad could be somewhat tricky due to the size and layout of the pad. I did not inspect the wellhead as it is covered with a tarp and enclosed by a chainlink fence. As it sits, a couple inches of location runoff water cover the grate over the cellar and the valves appear to be below the grate. There is no sheen to the water. Tom Coursen of Weaver Bros. Trucking was asked to inspect the site and offer some insight on the road condition and layout with respect to maneuvering equipment. He suggested that some tree limbs be removed. Also, it appears as though a small tank could be bobtailed onto the pad. He thought scraping or otherwise disturbing the road would do more harm than good. Tom suggested waiting until the ground freezes up some to provide additional stability if possible. Before initiating the move of any large equipment, Wayne Cissell plans to pump the cellar and get a preliminary look at the project. This will probably include some stainless steel tubing, a pressure recorder, and small scale containment. This work will probably be done tomorrow, 10/3/00, and should give a good indication of the scope of the flowback and the necessary equipment. Once this preliminary information is obtained, a course of action will be provided in advance so that the AOGCC may be scheduled to witness. If there are any further questions, feel free to contact me. Thanks, Denise Titus Marathon Oil Company 3201 C Street, Suite 800 Anchorage, AK 99503 (907) 564-6317 1 of 1 10/2/003:16 PM STATE OF ALASKA t' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS '1~ Type Of request: Abandon _ Suspend _ Operational shl~tdown _ Re-enter suspended well_ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _X Change approved program _ Pull tubing _ Variance _ Perforate _ Test 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_ 276 RKB feet 3. Address Exploratory_X 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 sen/ice_ Falls Creek 4. Location of well at surface 8. Well number 1899' North & 252' West from southeast corner Sec. 6, T1 N, R12W, SM Falls Creek At top of productive interval 9. Permit number / approval number At effective depth ORIGINAL 10. AGp?'n4u2mber 50-133-10005-00 At total depth 11. Field / Pool 442' North & 2952' West of surface location Falls Creek Unit 12. Present well condition summary Total depth: measured 13795 feet Plugs (measured) 13250'-13050', 12100'-11850', true vertical 13382 feet 10100'-9900', 8700'-8395' Effective depth: measured 8395 feet Junk (measured) true vertical 8128 feet Casing Length Size Cemented Measured Depth True vertical Depth Structural 28' 36" 28' 28' Conductor 248' 20" 480 sx 248' 248' Surface 2468' 13.375" 1660 sx 2468' 2440' Intermediate 8600' 9.625" 1884 sx 8600' 8327' Production Liner Perforation depth: measured 7562'-7583', 7585'-7600' true vertical 7324'-7344', 7346'-7360' Tubing (size, grade, and measured depth 2.875", 6.5#, N-80 @ 7614' Aiaska 0i'i & Gas L;on~. C0mmissi0~, Packers & SSSV (type & measured depth) Model D packer @ 7542', No SSSV 13. Attachments Description summary of proposal__ Detailed operations program 14. Estimated date for commencing operation 15. Status of well classification as: August 15, 2000 16. If proposal was verbally approved Oil__ Gas Name of approver Date approved Service ~ ~the~g, is ~best of mY knowledge.,~ ,,,,~ Ouestions? CallPaulMazzolini263.4603 _ Sighed Paul Mazzolinl ~"--~. Title: Drilling Team Leader Date -- ~;;~'-"' Prepared by Sharon AIIsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness J Approval no. Plug integrity _ BOP Test ~ Location clearance -- Mechanical Integrity Test ~ Subsequent form required 10- -- Appr°ved bY °rder °f the C°mmissi°n ~'; ~" ~ ~: ~.- ~/~'_ I~ i L ...... Commissioner Date ~//~' 1 ~0 Form 10-403 Rev 06/15/88 · Ii=L) uY D Taylor Seamount Approved Copy Retumel:l SUBMIT IN TRIPLICATE Anadarko Petroleum Corporation Falls Creek Well 13-6 Casing Integrity Test August 2000 See attached wellbore and wellhead schematic 1) Clear/repair road and location as required to allow tanks and a cement pumping unit to be rigged up. Some tanks will be for diesel to load the 2 7/8" X 9 5/8" annulus. The other will be set away from the wellhead so that gas and fluids can be bled off the 2 7/8" X 9 5/8" annulus thru a choke manifold. Set all tanks in accordance with regulations and safe practice. 2) Clean out cellar as required. Install a second 2" 3M valve on the existing2" 3M side outlet valve on the 2 7/8" X 9 5/8" annulus and 9 5/8" X 13 3/8" annulus. Inspect tree and wellheads for any visual leaks, verify/bleed off any pressure in tree. Verify pressure on the 2 7/8'"X 9 5'8" annulus (2,600 psi on 9-22-99). Check the pressure on the 9 5/8" x 13 3/8" annulus. 3) Rig up manual choke manifold to the new valve in 2) above(2 7/8" X 9 5/8" annulus) a safe distance from the wellhead and mn to one tank set safely away from the wellhead. Conduct safety meeting. Attempt to slowly bleed off existing 2,600 psi trapped in the 2 7/8" X 9 5/8" annulus. Monitor wind direction to insure safe operations. Methanol/Glycol injection upstream of the choke manifold may be required to avoid 'freezing problems. Monitor pressures in the 9 5/8" X 13 3/8" annulus and any other pertinent cavities while bleeding. 4) If pressure does not decline significantly, terminate operations. Prepare P'& A plan. ,. 5). If pressure declines, bleed to nil and load annulus with diesel( 570 BBLS annular volume). Limit surface pumping pressure to 500 psi. Take precautions while pumping . diesel under pressure. Bleed any pressure from' the 9 5/8".x 13 3/8" annulus recorded in 2) above. 6) Bleed pressure thru ½" NPT test port from the 9 5/8" casing primary/secondary seal and ring gasket cavity. (unable to bleed on 9-22-99). Re-energize seals and pressure. test to 2,000 psi. 7) Service all valves. ' '8) Attempt to pressure test 2 7/8" X 9 5/8" annulus loaded in 5) above to 1000 psi for 30 minutes and record on a chart. 9) RD equipment and secure well. List of equipment/services required for Falls Creek 13-6 Integrity Test 1) Contractor to prepare access road and location as required. 2) Cameron wellhead technician with tools. 3) Roustabout crew 4) Two inch 3 M flanged valve, studs, nuts and ring gasket. 5) Dowell/BJ/Howco cementing unit with pressure recorder with sufficient Chicksans. 6) Storage tanks as required. Large opening for the vent tank. 7) Sufficient surface lines and fittings 8) Choke Manifold 9) Glycol injection pump and glycol 10) Fire Extinguishers 11) 600 +- BBIs diesel · CHE.YRON FALLS CREEi,' CLAM GULCH AS OF 09124199 .tELL# 13-6 " (' 2..91't6" 5M TREE CAP WI 2-?18 INTERNAL UFT THREAD - - PN: Y22342-00100251 ~,~;~ C'~l PN: K036070 .... .-...: ' '~/ : SN' 179440.2 ~ / 2-9/16" 5M WKM MODEL 'M' GATE I-- I ' VALVE. , 2.9'16" 5M WKM MODEL 'M' GATE / ~'.~,. 2-9116' 5M WKM MODEL 'M' GATE ' / ' VALVE. ' . Pi':: K041443 ' [~_"..': ( ~G't } :~ ] PN: K36070 ' SN: 79575' 1 ~J;~:"~.~[~/.,4~""SN: 179435-2 q'-lrt6 x 2.718, TUBING 5HAFFER TUBING HANGER. 7-1118 5M X 2-g116 SM TBG. HD, I ' ~ --'1 ~ ' -- ADAPTER, W/OUT TEST PORT , .. 11 3M X ?-,1/16 5M 'EIIAFFER TUBIN SPOOL WI 6-3/8 BORE 12 X g-5/8 SECONDARY SEA ; 5M ROCKWELL PLUG 2' VALVE 12 X 9-~.8 CASING SLIPS 13-31B &RD BTM X 11 3M STARTING HEAD, SN: 9883 2" 3M ROCKWELL PLUG VALVE Falls Creek Well 13-6 Wellbore Schematic 36' @ 28' Block Sqz's @ · 3484'-3927' 5275'-5326' ~ 5419'-5490' 2 MMCF/D @ 430 FTP FSIP - 3385 psi 20" (97# Grade B) @ 248' Otis "D' tbg. plug @ 500' DVT @ 1518' 13-3/8' (54.5# J-55) @ 2468' ~ Perfs @ 3900-3911 (sqz'd) -<~--'"'Peds @ 5290-5315(sqz'd) -~---~Peds @ 5442-5470(sqz'd) Otis"D"tbg. plug@ 7402' Model"D'pkr @ 7542', 2-7/8'tbg (6.5# N-80) @ 7614' ~ Perfs @ 7562- 7600 PBTD @ 8395' 9-5~8' (40# N-80) @ 8600' Lont Creek #2, et al • • Subject: RE: Lone Creek #2, et al Date: Thu, 27 Jul 2000 10:33:02 -0500 From: Tommy Thompson <tommy_thompson @anadarko.COM> To: "'Tom Maunder "' <tom_maunder @admin.state.ak.us> Tom, (0ROLA I apologize if there has been any confusion regarding the Falls Creek Well. I have been discussing the issue with Paul and had assumed since our last discussions that you and Blair wished to receive correspondence from Phillips (Arco) as they are operator of record. As such I have relied on Paul to handle. I am in Anchorage right now and will be in town for the next week or so. I had hoped to meet with Blair and yourself early next week, but should your schedule allow we can get together earlier. My schedule today is already spoken for, could we meet some time Friday? You can reach me by phone at 713 -819 -1796 (mobile). _ Tommy T i APR 0 5 2411, > Original Message > From: Tom Maunder fSMTP: tom maunder@admin. state. ak. us] > Sent: Wednesday, July 26, 2000 PM > To: Tommy Thompson > Cc: Blair Wondzell > The last item is the et al...Falis Creek. I have talked with Paul > Mazzolini a couple of times and sent emails to both him and yourself. > To date, I have only been received replies from Paul. I am disappointed > that neither Blair nor I hate received any communication from you > regarding this well. Even a short note acknowledging receipt of my > messages and that you or your staff were working on the plans would have > been appreciated. > In the last message (which I think you got a copy of) Paul indicated > that the land people were getting things sorted out with regard to the > operatorship and that non -rig and rig options were being prepared. I > sincerely hope that at this late date plans are well beyond being > prepared and that sorting out the land situation hasn't severely > impacted your ability to accomplish work on that well this season. The > beginning of August is fast approaching and / believe we have been most > clear in our expectation that we expect work to be done soon on the > Falls Creek well to eliminate the surface pressures. > I will attempt to call you about 11 am your time on 7/27. Feel free to > pop an email back so I can have it in hand when I call. > Tom Maunder > Petroleum Engineer > AOGCC « File: Card for Tom Maunder >> ALASIIA OIL AND GAS / t t / / / TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 12, 2000 Todd Liebl Manager, Land Alaska Anadarko Petroleum Corporation 17001 Northchase Drive Houston, TX 77060 Re: Anadarko Alaska Operations Dear Mr. Liebl: Thank you for the prompt response to my initial inquiry. Unfortunately, Commission records are somewhat incomplete, and changes of ownership throughout the state have ot'ten gone unreported. A Notice of Change of Ownership (form 10-417) should be filed whenever oil and gas leases change ownership. A Designation of Operator (form 10-411) should also be timely filed. Enclosed are copies of our regulations and the appropriate forms. The Commission would like a complete list of all leases that Anadarko holds an interest in. The list should include state and federal leases as well as any private fee mineral leases statewide. -- The Commission is also trying to get th~# 13-06)~vell/~"~'~operly plugged and abandoned, since it has been sl~ut in ~and has~h casing pressure. Although Phillips Alaska, Inc. is currently drafting a plan to plug the well, they have indicated that the well may be Anadarko's responsibility. Who is the operator of this property? The Alaska Division of Governmental Coordination has also recently reported that Anadarko is in the pre-application stage for the Lone Creek #2 and #3 wells. A Designation of Operator (form 10-411) must be submitted and approved by the Commission prior to the commencement of drilling operations. Please call me at 907-793-1236 if you require fm~er clarification. Sincerely, Wendy Mahan Natural' Resource Manager Enclosures ( ANADA~KO PETROLEUM CORPORATION 17001 NORTHCHASE DRIVE · P.O. SOX 1330 TEL. (281) S75-1101 · HOUSTON, TEXAS 7'7251-1330 nadaH July 6, 2000 Ms. Wendy Mahan Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Alaska Lease List Dear Ms. Mahan: We received your letter of June 29, 2000 wherein you requested a list of our Alaska leases. Prior to providing you with the information, we have several questions to assist us in clarifying your request. One, are you interested only in Anadarko's state leases, or are you also interested in BLM, MMS and private fee mineral leases? Two, are you interested in leases covering lands on the North Slope, the Cook Inlet basin, or both? And three, are you interested only in producing leases? As I'm sure you are aware, any list we provide you will only be a "snapshot" of our leasehold and will be subject to change without notice. We look forward to your response. Yours very truly, Anadarko Petroleum Corporation Todd L. Liebl Manager, Land Alaska TLL:dd Alaska Oi~ ' '' ~. · ," · - & Ga., Con.,. Commission A~chorarje Falls Creek Subject: Re: Falls Creek ] '3'-~ (~6 Date: Thu, 13 Jul 2000 15:43:24-0800 From: Tom Maunder <tom_maunder~admin.state.ak.us> Internal To: Paul Mazzolini <PMAZZOL~ppco.com> CC: blair_wondzell~admin.state.ak.us, tommy_thompson~anadarko.com, Dora I Sofia <DSORIA~ppco.com> /60- Thanks Paul. We look forward to seeing the program. Tom Maunder Paul Mazzolini wrote: Blair, This is a status update on the proposed work on Falls Creek Well #13-6 to enhance present well integrity. A well plan has been developed and approved by Anadarko and Phillips for this well. The Phillips Land department has been working with Anadarko and will be sending the AOGCC a letter designating Anadarko to perform work on Well #13-6. You should be receiving this letter within the next week followed closely by the well work procedure and sundry notice. It is the intent of Phillips and Anadarko to expedite the field operations after the sundry has been approved. Please contact myself at 263-4603 or Tommy Thompson at 281-874-3262 with any questions. Regards, Paul Mazzolini Drilling Team Leader Tom Maunder <tom maunder~admin.state.ak.us> ] Petroleum Engineer . Alaska Oil and Gas Conservation Commission 1 of 1 7/18/00 10:43 AM ."' file:lllUntitled Thanks for the reply. I'm glad you appreciate our position with regard to the well's condition and will welcome seeing the work proposal. Ge~ing the ~rk going after the 4th holiday makes sense. Based on the information I have ~en I ~n appreciate the di~culties you are en~untering ~th all the intere~ owners. Regarding operator~ip, I don't ~ow what if any council I ~n offer. It appears kind of late in the game to be doing any designating. From ~at I understand in your voi~ mail message, such designation may not be Anadarko's preference. However, I do think that this designation pro,ss is outside the scope of the real matter ~ are ~ncerned with. The well needs work and we do expe~ that work to be done this summer. Plea~ get back to me or Blair to di~uss fu~her. We look fo~ard to seeing the work program Paul Mazzolini wrote: Tom, Phillips and Anadarko have been working through their land departments to pass operatorship of the Falls Creek Unit from Phillips to Anadarko but still have not completed this due to the number of small interest owners and getting their approvals. However, Phillips is looking to designate Anadarko as the entity to perform work required to bring the Falls Creek well in line with the AOGCC requirements this summer. Any comment on this proposal from the AOGCC? I have also been in discussion with Tommy Thompson with Anadarko on what work and how it can be accomplished this summer. We want to work toward improving well integrity without utilizing a drilling rig first. However, discusions have been started with Drilling Contractors to make sure that a rig could be obtained if needed. I am out of town but will be back on 6~30 and will contact you then. Regards, Paul Tom Maunder <tom_maunder@admin.state.ak. us> on 06/13/2000 02:02:26 PM To: Tommy Thompson <tommy_thompson@anadarko.com>, Paul Mazzolini/AAI/^RCO@Arco cc: Blair Wondzell <blair_wondzell@admin.state.ak. us> Subject: Fall Creek Unit #13-6 (PTD 60-0042) Gentlemen, We met in early February and discussed the Commission's concerns with regard to the reported surface pressures on the subject well. It is my recollection that you committed to preparing a work plan for execution this summer to address those concerns. To date, we have not received any work proposal. Please advise us of the status of any work planned to address the concerns discussed in the meeting. As we indicated at the meeting, it is our expectation that the work necessary to eliminate the well's surface pressures will be completed this summer. We look forward to your reply. Thomas E. Maunder Petroleum Engineer AOGCC I of 1 6/27/00 3:21 PM Re: Falls Creek Well Integrity PERMIT TO DRILL ~-942 Subject: Re: Falls Creek Well Integrity PERMIT TO DRILL 60-042~__ Date: Fri, 11 Feb 2000 08:25:13 -0900 -~ From: Blair Wondzell <blair_wondzell~admin. state, ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Paul Mazzolini <PMAZZOL@mail.aai.areo.eom> CC: tommy_thompson@anadarko.eom, Dora I Sofia <DSORIA~maail.aai.areo.eom>, Robert F Swenson <RSWENSON~mail.aai.arco.eom>, Tom Maunder <tom_maunder~admin. state, ak.us> Good Morning, Paul, Thanks for getting together with us on the 10 th. We appreciate the unknowns. If you find some information on the 1983 work, please send a copy our way. We agree with and accept your repair procedure as stated below. Thanks for moving this problem up on your priority list. Sincerely, Blair Wondzell Paul Mazzolini wrote: > Blair, Thanks for meeting with Tommy Thompson and I this morning concerning the > Falls Creek well integrity issue. Both Anadarko and ARCO are very interested in > resolving the well's integrity issue and plan to begin actual well work in June > 2000. The work performed in September 1999, reconfirmed the integrity of the > back pressure valve set in the tubing hanger and of the X-mas tree itself. > Cooper-Cameron technical representatives are presently researching what might be > done to re-energize the casing hanger seals as part of the work which will need > to be completed. > > Once the scenarios for re-energizing the seals have been developed a detailed > procedure will be written which will re-establish the wellbore's integrity and > isolate bottomhole pressure from the casing strings. In addition to questions > concerning the wellhead equipment, little information concerning the last well > work performed in 1983 is in the well files. Because of this we are presently > unsure what was left in the tubing below the back pressure valve. There could > possibly be a D lock plug at about 506' WLM, an ice plug at about 705' WLM and a > deeper D lock plug set at about 7420' WLM. The tubing would be cleared of these > obstructions, if required and then we would determine the source(s) of pressure > communication and perform remedial wellwork to isolate the bottomhole pressure > from the casing strings. > > Tommy and I will continue working on this procedure and will submit with the > required sundry notice to the AOGCC as we get closer to June. Please call me at > 263-4603 or Tommy at 281-874-3262 with any questions or comments. > > Regards, > > Paul t 1 of 1 2/11/00 8:25 AM General Purpose Worksheet Fe IPage No. By Of IDate AR3B-6287 • • General Purpose Worksheet A. Nr Subject Page No. Of C CIA \ 5 C co \c File By Date /a-' 3000 VD • 3c7 1( / ?\ MuZ 1 ()c1 Voc-. 16� S �sdr --J.)\jQL " I k\ ©v�s ■ a � S ANNED APR 0 5 20l ca ar 'c CTGC O r� O � S c.\ ‘Gti �4 N+O1*`- * VCs\ . V QCS'� s, 5 A -‘c),\ \\ 11- Q • AR3B -6287 Falls Creek (PTD 60-42) • • Subject: Falls Creek (PTD 60 -42) Date: Thu, 27 Jul 2000 08:25:17 -0800 From: Tom Maunder <tom_maunder @admin.state.ak.us> To: Paul Mazzolini <pmazzol @ppco.com> Paul, Good to talk to you. I wanted to send this note to document our call. Please email me back a reply. The issues regarding the integrity of this well have still not been resolved. Throughout our meetings and correspondence I believe we were clear of our expectation that wellsite work to eliminate the well pressure would be undertaken this summer. August is fast approaching and we have not received a sundry application requesting approval to begin work. Various internal issues have been indicated as ongoing, particularly the land situation and operatorship. Regardless of your internal discussions with Anadarko, our records indicate that ARCO Alaska was the operator for the Falls Creek well. With the purchase of all assets of ARCO Alaska, Phillips now has the responsibility for the well. You indicated in our discussion that you are ready to go to work. If that is the case, not later than August 3 please submit the appropriate sundry request to begin work. If the sundry and work plan are not received by the 3rd, we will refer the matter to the Commissioners. I look forward to seeing the work documents. Please call me if you would like to discuss. Tom Maunder Petroleum Engineer AOGCC Torn Maunder <torn maunderadmin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 7/27/00 8:30 AM • 6 9-- ) PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P. O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 Dora I. Soria Land Department, ATO 1360 Telephone 907- 265 -6297 Facsimile 907- 265 -1608 E -mail dsoria @ppco.com July 17, 2000 Mr. Steve McMains Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Re: Designation of Operator Falls Creek Field Cook Inlet, Alaska Dear Mr. McMains: In accordance with my letter dated February 22, 2000, and as we discussed recently, Anadarko Petroleum Corporation ( "Anadarko') is now contractually the operator of the Fall Creek Field. However, the execution by all parties to legally accomplish such designation is still underway. As you are aware, I am still missing confirmations from three of the working interest owners. Once those are in hand, we hope to submit the complete paperwork to the various agencies. I have enclosed advance copies of the documents, as executed to date, for your information. Anadarko has developed a well plan to enhance the present integrity of the Falls Creek Well #13 -6 and will be performing the related work. Anadarko will shortly be sending AOGCC a well work procedure and sundry notice for such well. Once the sundry is approved, Anadarko intends to perform the operations diligently. Please do not hesitate to contact me with any questions you may have. You may also contact Tommy Thompson at (281) 874 -3262 regarding the impending operations. Very truly yours, 42 I Dora I. Soria RF V D Senior Landman JUL 19 2000 Alaska Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRlchfleldCompany • • DIS (cov) enclosures cc: (cover only) Todd Liebl, Anadarko Petroleum Corporation Tommy Thompson, Anadarko Petroleum Corporation Paul Mazzolini, PAI Blair Wondzell, AOGCC Tom Muander, AOGCC ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany From - Fri Jan 21 15:28:41 2000 X-Mozilla-Status: 0001 X-Mozilla-Status2:00000000 Message-ID: <3888E93B.36CF9DB2@admin.state.ak.us> Date: Fri, 21 Jan 2000 14:18:19 -0900 From: Blair Wondzell <blair wondzell@admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Marlo Garza <mario_garza@anadarko. COM>, Paul Mazzolini <pmazzol~mail.arco.com> Subject: Re: Falls Creek Integrity Test PTD 60-042 References: <71EBC27C874CDl11B13600805F8506B204D26939~mai101> Content-Type: text/plain; charset=us-ascii Content-Transfer-Encoding: 7bit Mario, Sounds good. We'll look forward to discussing the situation with Mr. Ford.. Sincerely, Blair Wondzell Marlo Garza wrote: Dear Mr. Wondzell: If my messages have been preceived as portraying insensitivity to the problem, I sincerely apologize. That was/is certainly not my intent, nor of Anadarko. Gary Ford, our project manager, will be in attendance at the Monday meeting. From: Blair Wondzell[SMTP:blair wondzell@admin.state.ak.us] Sent: Friday, January 21, 2000 11:43 AM To: Marlo Garza; Paul Mazzolini Subject: Re: Falls Creek Integrity Test PTD 60-042 Mario, Your 3Nov99 e-mail demonstrated your insensitivity to the seriousness of the situation. Your memo below continues to convey that message. Incidently, measurements from our map indicates that FC 13-6 is approximately 900 feet from Alaska Highway 1. As far as the Commission is concerned, ARCO is the responsible operator and therefore is the company I want to talk to. I would be receptive to one of your engineers joining us. Please have one give me a call at 793-1226. Sincerely, Blair Wondzell r. Marlo Garza wrote: Dear Mr. Wondzell: Sorry if I caught you by surprise. Anadarko is a 25% WI owner in the well. Under the terms a contractual assigment, ARCO granted us technical operatorship of a number of wells, including this one, even though they continue to be operator of record. We would like to be present for the meeting. As I indicated, several from our engineering staff will be up in Anchorage during the week of February '8. If the informal meeting can not be rescheduled for those dates, we would still like to be present and have one of ourAnchorage based persons attend (and conference -in Houston by phone...if possible). We will do whatever best suits your wishes. Please advise. Thanks. ..... Original Message ..... From: Blair Wondzell [SMTP:blair wondzell@admin.state.ak.us] Sent: Thursday, January 20, 2000 6:17 PM To: Marlo Garza; Paul Mazzolini Subject: Re: Falls Creek Integrity Test Mario, Your e-mail caught me by surprise for a couple of reasons: 1. Our records show ARCO is the responsible party; and 2. I was proposing an informal engineering meeting prior to putting them on notice. If Paul has changed his mind about the engineering meeting, we'll proceed to issue a notice to repair or abandon the well. One of the points I wanted to discuss with Paul was the time frame for compliance (we are contemplating 3-6 months). I am trying to contact Paul to see if he wants to help formulate the notice or just wants to receive it. ARCO and Anadarko have known about the situation at Falls Creek 13-6 since at least November 3, 1999 (your E-mail to me) and must have developed plans to make the well safe, to comply with AOGCC regulations. As you should know, that well appears to have 2600 psig on a casing that had a burst rating of 2730 psig in 1962 and the well is very near a major State highway. Please send me a copy of your plans so that we can consider your ideas as we formulate the notice. Sincerely, Blair Wondzell Marlo Garza wrote: Dear Mr. Wondzell: Dora Sofia of ARCO has called informing us (Anadarko) of your desiire to meet to discuss the results of the recent Falls Creek #1 Well integrity test. She indicated you were proposing to have such meeting next Monday. We would like to be present at the meeting and can have arrangements to do so with our Anchorage Staff but would likely need assistance via telephone conference call to our Houston Engineering Group. If possible, we request that the meeting be postponed until February 8 or 9, during which time, some members of the Houston Engineering Group would be in Anchorage. Please advise by e-mail or call me by phone at 281/873-1271. Very truly yours, Mario M. Garza Project Landman Anadark0 Petroleum Corporation Legal Requirement To Repair Well · Falls Creek Well 13-06 PTD 60-042 Statutes Sec. 31.05.030 Powers and duties of commission. (a) The commission has jurisdiction and authority over all persons and property, public and private, necessary to carry out the purposes and intent of this chapter. (b) The commission shall investigate to determine whether or not waste exists or is imminent, or whether or not other facts exist which justify or require action by it. (d) The commission may require (3) the drilling, casing and plugging of wells in a manner that will prevent the escape of oil or gas out of one stratum into another, the intrusion of water into an oil or gas stratum, the pollution of fresh water supplies by oil, gas or salt water, and prevent blowouts, cavings, seepages and fires. (e) The commission may regulate, for conservation purposes (1) the drilling, producing and plugging of wells; Regulations 20 AAC 25.105. ABANDONMENT OF WELLS. (b) A well drilled onshore or from a fixed offshore platform must be abandoned before removal of the drill rig unless the well is completed as an oil, gas, or service well or is suspended, or unless well operations are shut down in accordance with 20 AAC 25.072. Each well drilled from a fixed offshore platform must be abandoned before the platform is removed or dismantled. The above three possibilities are: 1. 25.072. Temporary Shutdown of Drilling and Completion Operations. Does not apply, well has been completed. 2. 25.110. Suspended Wells· Does not apply, no down hole plugs. 3._25.115. Shut-in Wells· Falls Creek Unit Well No. 13-6 is a completed (oil,) gas (or service) well. The annual report must cover (1) the current known mechanical condition, (2) the date and circumstances when the well was shut-in and (3) an analysis of the future utility of the well. 20 AAC 25.200 PRODUCTION EQUIPMENT (c) Wellhead equipment must include appropriate gauges and valves installed on the tubing, casing-tubing annulus and casing-casing annuli to show surface pressures and to control the well flow for the range of condition expected. Other alternatives will, in the commission's discretion, be approved for subsea completions. (d) All producing wells capable of unassisted flow must be completed with downhole production equipment consisting of suitable tubing and a packer that effectively isolate the tubi ng-casing annulus from fluids being produced, unless the commission specifically approves production through the annulus to increase flow rate without jeopardizing ultimate recovery from the well. 20 AAC 25.526 CONDUCT OF OPERATIONS An operator shall carry on all operations and maintain the property at all time in a safe and skillful manner in accordance with good oil field engineering practices and having due regard for the preservation and conservation of the property and protection of freshwater 20 AAC 25.534 TESTS, SURVEYS AND INSPECTIONS (a) As the commission considers necessary or advisable to carry out the purposes of AS 31.05 (Alaska Oil and Gas Conservation Act) and this chapter, the commission will require that tests or surveys be made to determine the (1) quality of oil and gas produced; (2) formation, casing, tubing or other pressures; (b) The commission will, in its discretion exercise its statutory power to enter and conduct onsite investigations and inspections at reasonable times of facilities, equipment, practice, records, or operations for the purpose of ensuring compliance with the requirements of this chapter. 20 AAC 25.535. ENFORCEMENT (a) If the commission, as the result of an investigation or otherwise, considers that a person may have violated or failed to comply with a provision of AS 31.05, this chapter or a commission order, permit, or other approval, the commission will, in its discretion, take enforcement action under this section against the person. Review of Current Well Condition Falls Creek Unit #13-6 PTD: 60-0042-0 Location: S01-T01N-R013W (SM) Kenai Borough, Alaska Introduction: This report reviews the well history for the Falls Creek Unit #13-6 (formerly Falls Creek Unit #1) in light of a recently completed well inspection and provides recommendations for future well work. The Falls Creek Unit #13-6 (formerly Falls Creek Unit #1) is located on the Kenai Peninsula immediately adjacent to the Sterling Highway near Clam Gulch. The well was drilled, completed and tested by Chevron in 1960/1961. After testing, the well was shut-in and has remained so for nearly 40 years. In the annual (potential) development plans submitted through the years, any work on or production of the well has been deferred "pending shooting/evaluating new seismic information that will positively affect the ability to exploit and produce the Unit economically." In mid 1999, the well site was visited by ARCO 'Alaska representatives (Note: Although some correspondence shows Anadarko to be the operator per some agreement with ARCO, all official records available indicate ARCO is the operator of record) t,? perform "an [well] integrity test. This test was a condition for approval of the 38'" plan of development submitted in late 1998. The site visit/inspection was performed in September 1999. At that time, the tree was serviced and successfully pressure tested. 2600 psi was found on the tubing x casing annulus and the 13~3/8" x 9-5~8" hanger and packoff assembly were found to be leaking. No pressure value for the outer annulus was reported. Unsuccessful attempts were made to bleed off both pressures with no observed pressure reduction noted after ten minutes. Following the attempted bleedoff, the tree valves were secured and the operation terminated. A copy ot: ARCO's inspection report is attached. Following staff review of the information reported for September 1999, concerns were raised due to the reported annulus pressure and casing hanger leaks. This concern was communicated to ARCO requesting they evaluate the situation and propose remedies. A reply was received from Anadarko indicating their opinion that the well is secure and they do not 'propose any work at this time. . It is the professional opinion of the AOGCC Petroleum Engineering Staff that it is not prudent to indefinitely maintain the Falls Creek Unit #13-6 well in its reported condition. FallsCreek.doc Page 1 of 6 January 14, 2000 Operating History: Drilling operations began December 7, 1960. During the course of the operations, the following casings were set: 20", 97#, grade B 13-3/8", 54.5#, J-55, 8rd 9-5~8", 40#, N-80, 8rd 248' cemented to surface with 480 sx 2468' cemented to surface with 1660 sx in 2 stages 8600' cemented with 1884 sx, partial lost returns while cementing, unable to reciprocate. Pipe was set 300' off bottom and cemented. Drilled hard cement in open hole below shoe. The well was ultimately drilled to nearly 14000'. After running open hole logs, the open hole section was abandoned with 4 cement plugs to 8454' (about 150' above the casing shoe) and testing commenced in the 9-5/8" casing. A series of drill stem tests (DSTs) were conducted working sequentially shallower in the well. .The usual technique employed was to perform block squeezes above and below a prospective testing interval, perforate the interval, test it and then set 'an isolation plug above the interval. It is important to note that the isolation plugs were set above the perforated intervals and no attempt was made to squeeze cement into the intervals. When the DSTs were completed, all isolation plugs were drilled out to allow the permanent completion to be run. Please reference the attached completion drawing for the following discussion. For purposes of this discussion the wellbore will be divided into four sections defined as follows: Section 1: 9-5/8" casing from 8395' (PBTD) to 8600' (casing shoe).' Section 2: 2-7~8" tubing from surface to 7542' (packer) and 9-5/8" casing from 7542' to 8395'. Section 3: 9-5~8" casing x 2-7/8" annulus from 7542' (packer) to surface. Section 4: 13-3/8" x 9-5~8" annulus from 2468' (13-3/8" shoe) to surface. Section 1: A single production test was performed in this section of the wellbore. Test ~articulars are: Squeeze Perforations: Perforated Interval: Gas Rate: Isolation Plug Depth: None 8395'-8415' 20 - 30 Mcf/d 8325'-8454' .w/50 sx FallsCreek.doc Page 2 of 6 January 14, 2000 Section 2: A single production test was performed in this section of the wellbore. Test particulars are: Squeeze Perforations: Perforated Interval: Gas Rate: Isolation Plug Depth: 7615' w/25 sx, 7550' w/ 100 sx, no cleanout depth specified 7562'-7600' 2000 Mcf/d, 2600-psi shut-in surface pressure 7100'-7250' w/60 sx Section 3: Three intervals and 6 production tests were performed in this wellbore section. Test particulars are: Squeeze Perforations: Perforated Interval: Gas Rate: Isolation Plug Depth: 5490' w/115 sx, 5419'w/115 sx, cleaned out to 5490' 5442'-5470' 335-400 Mcf/d and fluid spray sufficient to snuff flare 5362'-5440' w/30 sx Squeeze Perforations: Perforated Interval: Gas Rate: Isolation Plug Depth: 5326' w/40 sx, 5275' w/ 50 sx, no cleanout depth specified 5290'-5315' 680 Mcf/d and fluid spray sufficient to snuff flare 4097'-4297' w/77 sx Squeeze Perforations: Perforated Interval: Gas Rate: Squeeze Perforations: Perforated Interval: Gas Rate: 3927' w/135 sx with circulation to surface via 13-3/8" x 9-5/8" annulus. 45 sx placed circulating. 3884' w/50 sx, no clean0ut depth specified 3900'-3911'- perforated twice tested interval 3 times with minor recovery, tool often plugged On 3rd test 13-3/8" x 9-5~8" annulus pressure declined from 22 psi. to slight vacuum during test. 3922' wi .52 sx, 3886' w/ 100 sx, cleanout to 3915' 3900'-3911 '.re perforated tool partially plugged Temporary testing was concluded and the interval isolation plugs were drilled out. Hard cement intervals were reported drilled at the following depths: 3918'-3969' 4140'-4360' 5380'-5460' 7580'-8395' FallsCreek.doc Page 3 of 6 January 14, 2000 It is noted that gas cut mud was circulated at 5340'. Following cleanout, 7562'- 7600' was reperforated, a permanent packer was set at 7545'+, 2-7/8" 8rd tubing was run, stung into the packer, landed and the rig was released April 24, 1961. The well was production tested beginning June 21, 1961. An AOF of 2900 Mcf/d was determined for the interval below the packer. Stabilized flow rate was 1980/Mcfd and 2.2 bwpd. Shut-in tubing pressure was noted at 2540 psi with a static pressure at mid perfs of 3404 psi at 7342' tvd. Analysis: Based on the well file information and the conditions reported following the September 1999 site visit, the following can be determined for the wellbore sections previously described: Section I 1. The perforations tested in Section 1 are plugged and abandoned. Section 2 2. The perforations in Section 2 are open to the wellbore and gas is likely present in the tubing, below the backpressure valve in the tubing hanger. Section 3 3. Three intervals were tested in Section 3. None of these intervals were squeezed following testing and all are open to the 9-5~8" x tubing annulus. 4. The presently reported 9-5/8" x 2-7~8." annulus pressure is very nearly the reported shut-in tubing pressure reported when the Section 2 zone was. tested. 5. The source of the annulus pressure is likely the Section 2 zone, although the communication method is not clear. Since no pressure was found 'within the tree, the backpressure valve is holding. A leak through the packer is possible as are leaks through the 8rd tubing threads or a hole in the tubing. It is also possible that one of the open annulus zones is contributing to the pressure. 6. Gas and foamy diesel were bled from the 9-5/8" x tubing annulus. Diesel was reported used when the well was completed. The well file does not have any clear information what fluid weight was in the well when the tubing was run. Based on the hydrostatic pressures from the final shallow test, 11.5 ppg mud was in the hole at that time and is likely the fluid left in the 9-5~8" casing x tubing annulus. FallsCreek.doc Page 4 of 6 January 14, 2000 Section 4 . No pressure value is given for the 13-3/8" x 9-5/8" annulus, although the hanger seals were reported to be leaking with flow from the inspection port. Gas and foamy diesel were bled from this annulus as well. If the hanger seals are leaking, it is likely that 2600 psi also exists on that annulus as well. 8. The published burst pressure of new 13-3/8", 54.5#, J-55 casing is 2730 psi which is just slightly greater than the reported surface pressure. . When the initial squeeze was attempted above the top test interval, a portion of the cement volume was circulated up the hole x casing annulus with the remainder being squeezed. The circulated volume was not sufficient to fill up into the 13-3/8" casing. It is likely that the 13-3/8" x 9-5/8" annulus is open at the shoe. This conclusion is further supported when it is reported that on one of the shallow tests, the' pressure on the 13-3/8" x 9-5/8". annulus declined while flowing the well. Conclusions: From analysis of the historic information regarding the well and 'the recently provided inspection information, the following conclusions are made: Historic Information 1. The Falls Creek well is located quite near the Sterling Highway near Clam. Gulch. 2. The well was drilled in 1960/1961 and has never been commercially produced. 3. It is likely that' the well will, for the foreseeable future, remain uneconomic. 1 One (1) perforated interval is open to the wellbore below the permanent packer. Three (3) perforated intervals are open'to the 9-5/8" x tubing annulus. September 1999 5. The mechanical integrity of the tubulars and wellhead seals have deteriorated since .installed and 2600 psi is present at surface in the tubing and the 9-5/8" casing x tubing annulus. It is possible that this same pressure exists on the 13-3/8" x 9-5/8" annulus as well. 6. The published burst pressure of new 13-3/8" casing is 2730 psi. 7. It is unacceptable to allow the well to remain in the condition reported. FallsCreek.doc Page 5 of 6 January 14, 2000 Recommendation: Based on the conclusions, the following recommendations are made. 1. ARCO Alaska, as operator of record, should be directed to prepare a plan to eliminate the reported annulus pressures present on Falls Creek Unit #13-6 in compliance with AOGCC regulations. 2. The necessary operations should be completed not later than August 31, 2000. FallsCreek.doc Page 6 of 6 January 14, 2000 Falls Creek Unit #13.6 PTD: 60-0042-0 SHL: S01-T01N-R13W SM Kenai Borough, Alaska 36" conductor at 28' Cemented to surface 20" casing at 248' Cemented to surface 13-3/8" casing at 2468' Cemented to surface Squeeze Peris 3884' & 3886' Test Interval 3900'-3911' Squeeze Peris 3922' & 3927' Interval tested 4 times. Tool plugging problems, no real gas. 45 sx of cement circulated up hole from squeeze at 3884'. Squeeze Peris 5275' Test Interval 5290'-5315' Squeeze Peris 5326' Squeeze Peris 5419' Test Interval 5442'-5470' Squeeze Peris 5490' Upper interval made 680 Mcfld. Lower interval made -350 Mcf/d. Both intervals made sufficient water to extinguishflare. Squeeze Peris 7550' Test Interval 7562'-7600' Squeeze Peris 7615' ITest Interval 8395'-8415' FallsCreekdrwg.doc 'i.:' at :.:':.:': I9-5/8" x 2-7/8" packer at 7542' I2-718" tubing tail at 7614' I Upper interval made 2000 Mcf/d. AOF 2900 Mcf/d w! 2.2 bw/d. Lower interval made-30 Mcf/d. I9-5/8" casing set at 8600' 8-5/8" hole drilled to 13795'. Plugged solidly back to 8454'. TEM-01-14-00 ALASKA OIL AND GAS CONSERVATION COMMISSION Meeting Subject --~ Date/Time NAME - AFFILIATION (PLEASE PRINT) TELEPHONE { . United States Department of the Interior BUREAU OF LAND MANAGEMENT ANCHORAGE FIELD OFFICE 6881 ABBOTT LOOP ROAD ANCHORAGE, ALASKA 99507 Mr. Blair Wondzell: State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear Mr. Wondzell: 3160 (040) January 13, 2000 It is the Bureau of Land Management policy to defer well regulations to the appropriate state agency when a well drilled on federal lands reaches a productive horizon or bottom hole location off of the federal mineral estate. The Falls Creek Unit well is located in the federally managed Falls Creek Unit, but is located on the State of Alaska oil and gas lease ADL 00590. Therefore, we believe the State of Alaska Oil and Gas Conservation Commission is the agency with primary regulatory authority. We are aware of the apparent pressure communication between the tubing and annulus in the Falls Creek well. We strongly encourage and support actions to correct this problem. Should you have any further questions regarding this matter, please contact Peter Ditton at 267-1429. Sincerely, Michael Alcom Acting Group Manager, Energy and Mineral RECEIVED r_' uuu An0h0rag0 01/13/2000 14:36 FAX 907 269 8939 ROYALTY ACCT. RUN DATE:01/13/2000 DEPARTMENT OF NATURAL RESOURCES RUN TIME:14:25 OIL & GAS/MINING OWNERSHIP INFORMATION ~ OOl NRB7800P-07 PAGE: 1 ADL NUMBER: ADL 590 AGREEMENT TYPE: OIL AND GAS LF3~SE NOTIFICATION CID: 106539 NOTIFICATION NAME: CHEVRON U.S.A. INC TOTAL ACRES ACRES ACRES ONSHORE OFFSHORE 3,660.000 0.000 3,660.000 RECEIVED Alaska Oil & ~as Co~s. Gomml~lon SEG SEGMENTED ACRES CDE ONSHORE OFFSHORE Q 0.000 564.450 OWNER CID 2176 106346 4742 131220 142132 2354 3753 131216 131215 1958 1951 20642 NAME BURGLIN, BRIAN ARCO ALASKA, INC. , SALE 1, BURGLIN, CLIFFORD LUNDGREN (ESTATE OF), JAMES GUSTAFSON, MARY SEXTON, MICHAEL R BURGLIN, BRUCE RIMA, BARBARA C BURGLIN, JOSEPH BLTRGLIN, DAVID ANADARKO PETROLEUM CORPORATI WORKING ROYALTY INTEREST INTEREST 1.5000000 1.3125000 25.0000000 21.8750000 0.0000000 12,5000000 22.0000000 ~9.2500000 15..0000000 13.1250000 3.0000000 2.6250000 2.5000000 2.1875000 1.5000000 1.3125000 1.5000000 1.3125000 1.5000000 1.3125000 1.5000000 1.3125000 25.0000000 21.8750000 SEG SEGMENTED ACRES CDE ONSHORE OFFSHORE 2 0.000 3,095.550 OWNER CID NAME 2176 BLTRGLIN, BRIAN 4742 SALE 1, 131220 BURGLIN, CLIFFORD 142132 LUNDGREN (ESTATE OF), 2354 GUSTAFSON, MARY 3753 SEXTON, MICHAEL R 131216 BURGLIN, BRUCE 131215 RIMA, BARBARA C 1958 BURGLIN, JOSEPH 1951 BURGLIN, DAVID JAMES WORKING ROYALTY INTEREST INTEREST 3.0000000 2.6250000 0.0000000 12.5000000 44.0000000 38.5000000 30.0000000 26.2500000 6.0000000 5.2500000 5.0000000 4.3750000 3.0000000 2.6250000 3.0000000' 2.6250000 3.0000000. 2.6250000 3.0000000 2.6250000 Post-it' Fax Note 7671 ITM f I OoJDepl*, IPh~ne # , I a Falls Creek Well Subject: Falls Creek Well Date: Tue, 4 Jan 2000 16:01:08 -0900 From: "William Van Dyke" <wdv~dnr. state.ak.us> To: "Blair Wondzell" <Blair_Wondzell@admin.state.ak.us> As a follow up to our conversation last week we have reviewed the integrity test for the Falls Creek well that was performed in September, 1999. It appears that there is a communication problem in the wellbore. We recommend that the Commission work with the operator to determine the problem and then implement an acceptable remedy. While the communication problem does not have to be solved tomorrow, it should be addressed sooner rather than later. I do not believe that it is in our interest to let the well sit in its current condition for years to come. It is mY understanding that the well is on a state lease, although the Falls Creek unit officially is managed by BLM. of 1 1/$/00 8:11 AM ., ~'Re: [Fwd: FW: Falls Creek Integrity Test] Subject: Re: [Fwd: FW: Falls Creek Integrity Test] Date: Wed, 03 Nov 1999 08:37:55-0800 From: "John H. Spaulding" <trapper~rnatnet.eom> To: Blair Wondzell <blair_wondzell~admin.state.ak.us> Tom, As Lou is in sunny Mex. I am your only hope for a response. One of my questions is that he keeps mentioning development dates, what kind of time frame are we talking about. If we are looking at a long term type of shut-in situation, then I feel that the well should have some repairs made to bring it in line with the regs. and EPA guidelines. Will be talking to you later today, js Blair Wondzell wrote: Guys, Thought I would forward this to you and solicit your comments. As noted, when the well was inspected earlier this year 2600 psi was noted on the tbg x csg annulus. I suggested to Blair that we should probably check and see what (if anything) Anadarko/ARCO thought about the situation. Let me know what you think. Thanks. \ Tom 793-1225 Subject: FW: Falls Creek Integrity Test Date: Wed, 3 Nov 1999 10:10:17 -0600 From: Mario Garza <mario_garza~anadarko. COM> To: "'blair_wondzell~admin. state, ak. us '" <blair_wondzell~admin. state, ak. us> CC: "'dsoria~mail.aa/.arco.com," <dsoria~mail.aa/.arco.com> > Dear Mr. Wondzell: > Pursuant to your recent telephone inquiry regarding > the presence of annular pressure in the recent integrity test of the Falls > Creek Unit #1 well, a review of the data has been conducted by Anadarko's > Enginering Department and the following is submitted: > Recommendation: > * Anadarko proposes to continue monitoring the subject well into > the future for changes in pressure in lieu of pulling tubing at this time > due to logistic and cost constraints contrasted with the marginal benefits > to be derived from taking immediate action. > > * Pulling of tubing would be deferred until such time that > development plans are initiated. > > > Basis For Recommendation: > * Anadarko observed pressure ( +/- 2600 psi ) on the 2-7/8"tbg x > 9-5/8"csg annulus. Anadarko is of the opinion that the pressure anomaly > is most likely the result of a minor tubing leak. > * Surface wellhead and production tree were inspected and pressure > tested and found to be in mechanically sound condition. > > * Review of well records indicates that shallow intervals are > protected by 13-3/8" casing string set at 2468' MD (2440'TVD) and cemented > to Surface. > > * It is Anadarko's opinion that minimal risk to surface or shallow 1 of 2 11/18/99 8:24 AM Re: [Fwd: FW: Falls Creek Integrity Test] strata exists under current "as is" conditions. As such Anadarko recommends continued monitoring of the situation and undertaking a course of action at such time as development plans are set in motion. Should you have further questions or require additional information, please do not hesitate to call me at 281-873-1271. Thank you. Respectfully submitted, Mario M. Garza Project Landman Anadarko Petroleum Corporation PO Box 1330 Houston Texas 77251. 2 of 2 11/18/99 8:24 AM FW: Falls Creek hl~ity Test Subject.: FW: Falls Creek Integrity Test Date: Wed, 3 Nov 1999 10:10:17 -0600 From: Marlo Garza <mario_garz~adarko. COM> To: *~lair_wondzell~in.state.ak.us'" <blair_wondze11~admin. state.ak, us> CC: "'dsoria~_,mail.aai.arco.com'" ~lsoria(~mail.aai.arco.com> Dear Mr. Wondzell : Pursuant to your recent telephone inquiry regarding the presence of annular pressure in the recent integrity test of the Falls Creek Unit #1 well, a review of the data has been conducted'by Anadarko's Enginering Department and the following is submitted: Recommendation: * Anadarko proposes to continue monitoring the subject well into the future for changes in pressure in lieu of pulling tubing at this time due to logistic and cost constraints contrasted with the marginal benefits to be derived from taking immediate action. * Pulling of tubing would be deferred until such time that development plans are initiated. Basis For Recommendation: * Anadarko observed pressure ( +/- 2600 psi ) on the 2-7/8"tbg x 9-5/8"c~g annulus. Anadarko is of the opinion that the pressure anomaly is most likely th~ result of a minor tubing leak. * Surface wellhead and production tree were inspected and pressure res,ted and found to be in mechanically sound condition. * .. Review of well records indicates that shallow intervals are protected by 13-3/8" casing string set at 2468' MD (2440'TVD) and cemented to surface. * It is Anadarko's opinion that minimal risk to surface or shallow > strata exists under current "as is" conditions. > > As such Anadarko recommends continued monitoring .of~ > the situation and undertaking a course of action at. such time as > ~development plans are set in motion. .> > > Should you have further questions or require .> additional information, please do not hesitate to call me at 281-873-1271. > Thank you. > > > > > > > > Respectfully submitted, Marlo M. Garza Project Landman Anadarko Petroleum Corporation PO Box 1330 Houston Texas 77251. 1 of I 11/18/99 8:24 AM · ', .,. . . ': .. "'~'""'?""~"'"'"~,%,.~"'"'~'~'.".'~ ~%.~;~...~"~' 'J'q '"~:~<? '"~'~'~'~"~'~':'"~'~"~'7~"~'~"'~'~i?'~?'~'~.; ~ "~ ~'~'~":~"~-~'~v.~'~ ~' ' ' ~ ~,~-~~ 20: 58 9875823888 CAMERDN PASE 05 WELL ~R,l'rY ~ 'T'hl roTIowkllf I;G'oaod%l~ Wilt ' 1) b) 3 Y/B" tubi~ above the be,ak ~ plug' 4l. Ran, iL bottom hole ststb ~ eur~ with the fo~wi~ 1'015 10/20/1999 · 20:50 9075523880 CAMERON ... PAGE · mmm .., ~;~lr0 " BoRon lJo:b PressL~e , tt MP_P(?SiX') ~ TOTi4L ~'J-'CiE.IO,~ ~ STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _X Test 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development .~ 276' RKB 3. Address: Exploratory .X 7. Unit or Property: P.O. Box 100360 Stratagrapic ___, Anchorage, AK 99510-0360 Service. Falls Creek 4. Location of well at surface: 8. Well number: 1899' North & 252' West from southeast corner Sec. 6, T1 N, R12W, SI~ Falls Creek i~~,~-~ 6 ~/~ At top of productive interval: 9. Permit number/alSproval number: 60-42 At effective depth: 10. APl number: 50-133-10005-00 At total depth: 11. Field/Pool: 442' North & 2952' West of surface Iocatior Falls Creek Unit 12. Present well condition summary Total Depth: measured 13795' Plugs (measured) 13250'-13050', 12100'-11850 true vertical 13382' 10100'-9900', 8700'-839,~ Effective Deptt measured 8395' Junk (measured) true vertical 8128' Casing Length Size Cemented Measured depth True vertical depth Structural 28' 36" 28' 28' Conductor 248' 20" 480 sx 248' 248' Surface 2468' 13.375" 1660 sx 2468' 2440' Intermediate 8600' 9.625" 1884 sx 8600' 8327' Production Liner Perforation Depth measured 7562'-7583', 7585'-7600' true vertical 7824'-7344', 7346'-73D0'ORJGJNAL Tubing (size, grade, and measured depth) 2.875", 6.5/l, N-80 @ 7614' Packers and SSSV (type and measured depth) RECEIVED Model D packer @ 7542', No SSSV 13, Stimulation or cement squeeze summary OCT J I'JlB Intervals treated (measured: N/A ~~ ~~~~. Intervals treated (measured) 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~ Oil _ Gas _ Suspended __X Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed. ._ <~~~~._. _ _. Title',"~l~.l/.L./ld~'T'/~irn L.F_~I~-R. Date 'O/~1~ Form 1 0-404 Rev 06/15/88 SUBMIT IN DUPLICATE Falls Creek Integrity Test The goal of the well work was to inspect and service the production tree and perform a pressure integrity test on the tree, wellhead and the 9 5/8"x 2 7/8" annulus. The work was performed on 9/22/99 with Paul Mazzolini onsite to witness the servicing and testing for ARCO. The well cellar needed to be cleared of gravel and debris so that the casinghead, surface casing annulus valve and production casing annulus valves could be inspected, serviced and tested. Cameron service personnel inspected the production tree and wellhead equipment and found no leaks or damaged equipment. All tree valves (WKM 2 9/16" 5000 psi), swab, master and 2 each wing valves were serviced and actuated. The back pressure valve which is set in the tubing hanger is holding, as no pressure was found in the tree. A Cameron 2 9/16" 5000 psi tree cap was installed to facilitate any future well work. A nipple with a needle valve on a Rockwell 2" 5000 psi plug valve on the 9 5/8"x 2 7/8" annulus was connect to a gauge and found to have 1100 psi. The valve was opened slowly and found to contain trapped gas, which quickly bled off to 0 psi. This pressure was monitored and did not change..The 2" olue valve on the annulus w,,as opened and 2600 psi was shown on the gauge. An attempt W~s made to bleed this pressure down so a pressure test of the annulus could be performed. When the valve was opened to bleed pressure immediately got gas and foamy diesel. T~he ~annulus was bled for 10 minutes with no decrease in pressure indi~.cating po. ssible 9communic,ation between the tubi,ng and. t,h,,e,an,nulus~ The 2" plug valve was then-shut in and pressure bled to 0 PSi indicating that the plUg valve has good integrity. It was then decided on location not to attempt a pressure test of the annulus at this time. The seals on t. he Shaffer 13 3/8"x 9 5/8" casing hanger and pack-off assembly.were also found to be leaking as foamy., diesel was noted coming from the inspection port on the 1~3 ~/8i' s~ai flange and did not bleed down after monitoring, for 3-5 minutes. This ai~o ~'~ indicates possible communication with the formation p'ressure in"the tub'ing. A pump truck was then rigged up to thee production tree and the tree was pressured to 2500 psi with diesel and pressure momtored and recorded. The pressure in the tree decreased to 2297 psi in 38 minutes and was recorded on a pressure vs. time graph. The main cause of this thought to be air entrained in the diesel from the triplex pump. After the pressure test was completed a visual inspection of the diesel standing in the production tree showed no sign of pressure or gas leaking from the well. The tree cap was installed with a pressure gauge and was monitored for 20 minutes with no pressure build up. Equipment rig down was completed. The master and swab valves were then shut in and the well secured. CHE~/RON FALLS CREEK CLAM GULCH AS OF 09124/99 DRAWN BY PETE THOENI 0W24,99 LL# 13-6 ~ ~ 2-9/16" 5M TREE CAP W/2-7/8 INTERNAL LIFT THREAD I I PN: Y22342-00100251 I I 2-9/16" 5M WKM MODEL 'M' GATE ~ SN' 179440-2 ~ 2-9/16" 5M WKM MODEL 'M' GATE · I I VALVE. 2 9/16" 5M WKM MODEL M' GATE ~ ] Il I ~ .. - ' / .,,,~.~ ~---w~ 2-9/16 5M WKM MODEL 'M' GATE SN: 79579-1 ~~~SN: 179435-2 I I I I 7-1/16 5M x 2-9/16 5M TaG. HD. 7-1/16 X 2-7/8 TUBING SHAFFER TUBING HANGER. 11 3M X 7-1/16 5M SHAFFER TUBIN SPOOL W/6-3~8 BORE PN: 7T55L1 12 X 9-5/8 SECONDARY SEA 0 0 0 2" 5M ROCKWELL PLUG VALVE 12 X 9-5/8 CASING SLIPS 13-3/8 8-RD BTM X 11 3M SHAFFER 'KD' STARTING HEAD· SN: 9883 2" 3M ROCKWELL PLUG VALVE i " ttenting Job Report (~ 'RISM* V2.2 Well FALLS CREEK 13-06 J Client Arco Alaska Field WILDCAT SIR No. 20125234 Country USA Job Date 9/22/99 4:46:22 PM i i i i i i i i Time o9~22/99 16:46:22 ..... T,otF'lov,,~'ate Messages Cl~nVo~ -- De. U1 I=l~sslxe U1 16:48:00 . 16:52:30 - 16:57:00 . 17:01:30 . 17:06:00 - 17:10:30 -. 17:15:00 - 17:1~.30 --- 17:24:00 - : -- '~'OP ACQUI~fflON 17:28:~0 . · l"l"l''l"'l'l'll'l,l',' ,i,'ll,l'*'i','i'.l~l~.~l.'l. ll,l,l,li~l,l,l,l,i, ' ........ hh:mm:ss 0 - - b~ I 5 -- P~I e 0 ' pu 3ooo 09/22/99 17:26:19 ' ii i i i iiii i i iiiii i i ii i .i i i iii i [i i i i i i i i 'Mar~ of Scha~eerger ARCO Calculations Cha Subject File Sheet number I L E+,5# ,.T-5'5' 8~b QUALITY LITHO PRINTING, ANCHORAGE, AK (907) 563-4743 159-5881 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ " Alter casing _ Repair well_ Pluggir~ _ Time extension _ Stimulate _ Other _X Change approved program _ Pull tubing ,. Variance _ Perforate _ Test 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development_ 276 RKB feet 3. Address Exploratory_X 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchora~le, AK 99510-0360 service_ Falls Creek 4. Location of well at surface 8. Well number 1899' North & 252' West from southeast corner Sec. 6, T1 N, R12W, SM Falls Creek At top of productive interval 9. Permit number / approval number 60-42 At effective depth 10. APl number 50-133-10005-00 At total depth 11. Field / Pool 442' North & 2952' West of surface location Fall Creek Unit 12. Present well condition summar Total depth: measured 13795 feet Plugs (measured) 13250'-13050', 12100'-11850', true vertical 13382 feet 10100'-9900', 8700'-8395' Effective depth: measured 8395 feet Junk (measured) true vertical 8128 feet Casing Length Size Cemented Measured Depth True vertical Depth Structural 28' 36" 28' 28' Conductor 248' 20" 480 sX 248' 248' Surface 2468' 13.375" 1660 sx 2468' 2440' Intermediate 8600' 9.625" 1884 sx 8600' 8327' Production Liner measured 7562'-7583', 7585'-7600' Perforation depth: true vertical 7324'-7344', 7346'-7360' "~'~;/' Tubing (size, grade, and measured depth 2.875", 6.5#, N-80 @ 7614' I ~ t .. ..... .~-,~ ..... AiTChorage C°~lr~is~ior., Packers & SSSV (type & measured depth) Model D packer @ 7542', No 8SSV 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __X 14. Estimated date for commencing operation 15. Status of well classification as: August 24, 1999 16. If proposal was verbally approved Oil__ Gas ~ Suspended ~X Name of approver Date approved Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Paul Mazzolini 263'4603 Signed ---- Title: Drilling Team Leader Date Paul Mazzollnl Prepared by Sharon AIIsup. Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witnessI Appr°va'' Plug integrity _ BOP Test _ Location clearance _ Mechanical Integrity Test_ Subsequent form required 10- ___Approved by order of the Commission ....... · Commissioner Date '~ '-- Form 10-403 Rev 06/15/88 · nnstenson SUBMIT IN TRIPLICATE Falls Creek ]:ntegrity Test . Test integrity of all x-mas tree valves prior to pulling BPV. Note: BPV run in 9/83 and pressure in tree bled to 0 psi. . Service and repair tree valves as required. Valves are to be pressure tested to 2500 psi. . Swap out Thornhill-Craver tree cap w/Cameron 2-9/16", 5000 psi tree cap. Press test to 2500 psi. . RU and pressure test lubricator. Pull Cosasco BPV from TBG hanger. . Install Cosasco 2-1/2" two-way check valve in TBG hanger. Bleed off pressure in x-mas tree to test two-way check valve. 1 Rig up pump to pressure tree to 2500 psi. Stage pressure up in 500 psi increments and monitor for leaks. Hold test for 30 minutes once pressure stabilizes. Record test on a chart. . After successful test rig up lubricator and pull Cosasco two-way check from TBG hanger. At this point will have TBG pressure shut in at the x-mas tree. . RU and test 13-3/8" x 9-5/8" wellhead seal assemblies, both primary and secondary seals. Test to 2000 psi, this is less than 80% of collapse pressure of 9-5/8", 40#, N-80. Re-energize seals as necessary to get positive test. 1 RU and test 20" x 13-3/8" wellhead seal assemblies, both primary and secondary seals. Test to 500 psi. Re-energize seals as necessary to get positive test. 10. RU and test 9-5/8" x 2-7/8" annulus to 1000 psi. Hold pressure for 30 minutes and record test on a chart. Note annulus pressure prior to test. 11. RU lubricator and install Cosasco 2-1/2" BPV. Bled x-mas tree pressure to 0 psi and monitor for 30 minutes test for positive set of BPV. 12. RD test equipment and secure well. P. Mazzolini, 7/19/99 ARCO Subject ~"~-/..-S C.~'/..~ File Calculations Char Sheet number of Oate ~/~/e e QUALITY LITHO PRINTING, ANCHORAGE, AK (907) 563-4743 L ,7'-5'5' .8~ · . 2.0 M/4CFb e 159- 5881 CHEVRON Clam Gulch as of 6-16-99 Falls Creek We~, 13-6 Thornhill-Craver type TC-3 Unibolt Tree Cap WKM model M gate valve 2 9/16" 5000~ pin BM 36070 sin 179440-2 WKM model L gate vah?e 2" 5000~ x 1 518" bore pin BM41443 sin 79579-1 .,. WKM model M gate valve 2 9116" 5000~ pin BM36070 s/n1'79435-2 gravel & water from this point down J, WKM model L gate valve 2" 5000# x 1 518" bore pin BM41443 s/n 177402-1 Shaffer Seal Flange 6" 5000~ x 2 9/16" 5000# NO EXTERNAL TEST PORT ARCO Calculations Char OUALnY LITHO PRINTING, ANCHORAGE, AK (~07) S&.3-4743 159-5881 ARCO Calculations Char Subject J~/,-L..S C~'/,.~ K-- File Sheet number Date L 40 ~, /v , QUALITY I~ITHO PRINTING, ANCHORAGE, AK (907) 563-4743 CHEVRON Clam Gulch as of 6-16-99 Falls Creek Wel~'. ,3-6 Thornhill-Craver type TC-3 Unibolt Tree Cap WKM model M gate valve 2 9/16" 5000# pin BM 36070 sin 179440-2 WKM model L gate valve 2" 5000~ x 1 5/8" bore pin BM41443 sin 79579-1 WKM model M gate valve 2 9/16" 5000~ pin BM36070 s/n179435-2 gravel & water from this point down WKM model L gate valve 2" 5000# x 1 5/8" bore pin BM41443 sin 177402-1 Shaffer Seal Flange 6" 5000~ x 2 9/16" 5000# NO EXTERNAL TEST PORT COMIVi IRES E.NG SE ENG NRC SR GEOL GEOL ASSr" ' STAT TECH · STAT TECH FILE , DEPARTMRNT OY NATU'RAL RF.,SOUR :: 360I'-"C~" ST~ET. SU1TE 138;0. / ANCHORAGE, ALASKA 99503-5948 D/VISION OF OIL AI fD GAS PHONE: (907) 269-88( ....... November 9, 1998 Mr. J. David Dorris, Group Manager Bureau of Land Management Anchorage Field Office 6881 Abbott Loop Road Anchorage, AK 99507 RE: Falls Creek Unit Thirty-eighth Plan of Development Dear Mr. Dorris: The Department of Natural Resources, Division of Oil and Gas (DNR) received your November 3 1998 letter approving Arco Alaska Inc.'s 384 Plan of Development (POD) for the Falls Creek Unit. DNR concurs with the decision to conditionally approve the POD and require a well bore integrity test. However, DNR is concerned that the Falls Creek Unit has remained shut-in for nearly 40 years. The Unites Sates Department of the Interior, Minerals Management Service (MMS) published a Federal Register notice on October 15, 1998, with Guidelines for Suspension of Production Due to Uneconomic Market Conditions. (See Attached) DNR agrees with the notice, which sates in part: We expect lessees to diligently manage their leases by exploring, developing, and commencing production within the primary term. We will only grant SOPs for a lease when a lessee commits to production and provides a reasonable schedule of activities including measurable milestones. We will not grant suspensions for nonproducing leases solely to wait for uncertain economic or technological conditions to improve. BLM's policy on the Suspension of Production appears to be different from MMS. Please explain B,LaM's policy on lease extensions and Suspensions of'Production. Sincerely, Kenneth A. Boyd Director Enclosure: Federal Register Notice cc: Dept. of Law ~tO ~' AOGCC Arco Alaska, Inc. KAB/CL/cdl C:\USER~CDL\Units~FaIIs Creek~C38thPOD concur.doc "Develop, Conserve and Enhance Natural Resoun~ for Present and Future Alaskans :: .... ' ~ prmteo on recycieO pal~e~ 0 y ~1, ,,~ ( (' United States Department of the Interior BUREAU OF LAND MANAGEMENT ANCHORAGE FIELD OFFICE 6881 ABBOTT LOOP ROAD ANCHORAGE, ALASKA 99507 Ms. Dora I. Soria ARCO Alaska, Inc. P.O. Box I00360 Anchorage, Alaska 99510-0360 3160 (AK040) Dear Ms. Sofia: Enclosed is an approved copy of the 38th plan of development (POD) for the Falls Creek Unit, Kenai Borough, Alaska. This approval is.subject to the concurrence by the State of Alaska, Department of Natural Resources, and is only for the general plan of development. Specific field operations will require additional approval. As you know, this Unit has remained in effect without production since completion of the FCU #1 well in 1961. In 1983 a successful well bore integrity test was performed to satisfy the requirements of the 22"d POD. However, since it has been 16 years since the last integrity test and it is likely the well will remain shut-in fo~ at least three additional years, we believe a new test is necessary. We have contacted the Alaska Oil and Gas Conservation Commission (AOGCC) and they are in agreement that some form of well bore integrity test should be performed. Accordingly, in addition to the commitments identified in the POD, we are requiring that ARCO schedule and perform an integrity test on the FCU #1 well. Details of the test should be submitted to the BLM and AOGCC for review and approval. Should you have any questions regarding this matter please contact Peter Ditton at 267-1429. Sincerely, , ager 1 enclosure Approved 38th POD for Falls Creek Unit (lp) CC: Blair Wondzell AOGCC 3001 Porcupine Drive Anchorage, AK 99501-3192 w/enclosure Kenneth A. Boyd Department of Natural Resources, Division of Oil and Gas 3601 C Street, Suite 1380 Anchorage AK 99503-5948 w/enclosure RECt:IVED 1998 Naska Oil & Gas Cons. Commission Anchorage 38~. ~'LAN OF DEVELOPMENT AND OPERAt .~NS FALLS CREEK UNIT STATE OF ALASKA NO. 14-08-001-732 I. PERIOD This plan of development shall cover the period from December 24, 1998 to December 24, 1999. II. DRILLING PROGRAM The feasibility of a Drilling Program is being evaluated within the Falls Creek Unit based on the new seismic program discussed below. The Unit Owners continue to assess the potential for the discovered gas. III. LONG-RANGE DEVELOPMENT ACTIVITIES Historically, the lack of pipeline and gas market has restricted production from the Falls Creek Unit. The estimated investment for the construction and operation of a line to the existing gas transportation system exceeds the projected revenues generated from such operation. However, the Unit Owners diligently continue to evaluate and explore for additional reserves in the unit area. In 1996 the Unit Operator entered into an Exploration Agreement with Anadarko Petroleum Corporation CAnadarko") to evaluate the South Cook Inlet Area. Anadarko begun a 2-D acquisition program along the Kenai Peninsula in October 1997 that extended into early summer of 1998. Approximately 54 miles of new seismic data were acquired to further assess the Falls Creek Unit proper. The cost of the acquisition was approximately $250,000. This program involved a transition zone approach to seismic acquisition that consisted of tying both marine acquired seismic data and land acquired seismic data into one data'set. Initial processing has .been completed and Anadarko anticipates the interpretation of the 2-D seismic data covering the Falls Creek Unit will be completed by the end of 1998. Anadarko will make a presentation to BLM and DNR with its interpretation in the first quarter of 1999. Results of the new 2-D seismic data should provide Anadarko and the Unit Operator with information to determine the feasibility of further exploration and/or development operations in the Falls Creek Unit. A successful drilling program based on the new data could warrant the construction and operation of a pipeline that may potentially enable the development and production of the Falls Creek Unit Leases. IV. STATEMENT OF OPERATOR'S REPRESENTATIVE I hereby certify that the statements made in this plan are, to the best of my knowledge, tree and correct, and that the work associated with the operations proposed herein will be performed or caused to be performed by ARCO Alaska, Inc., its Operator and contractors in conformity with the plan and the ten~s and conditions under whi/c~it is approved. AGREED TO AND ACCEPTED THIS ~ DAY OF ,1998 DEPARTMENT OF NATURAL RESOURCES BY: TITLE: AGREED TO AND ACCEPTED THIS ,~¢a DAY OF ~, 1998 BUREAU O~~/D MANAGEMENT - SE]~IT BY: 7-2-59 ; 8:06.~ ; ) · ..,ARCO Alaska, Inc..~~ .~: ' .-'p. ~::'o.,~ .,,' , ,, Phone: ~b3 ::~Go.3 _ Lo=tion: ~~. ,~ ARCO 307 276 7342;# 1/ 6 ., III · jj Kup~ruk Developmenl P. O, BOX 100360 ANCHORAGE, AK 99510-0360 , FAX,~Y 907 265-6E24 Commenl$: ./ .. t ~.d J-131 · I,,y 1863) ._. · U' -'.D STATES sr.M:~ m ?.' TE* (Other I,lalruetl .. I~- DEPARTMb,~, OF THE INTERIOR -.-.,,.~ GEOLOGICAL SURVEY ' SUNDRY NOTICES AND REPORTS ON WELLS IJn "APPLICATION FOR PERMIT--" for such Gmpo-~l&) Standard Oil Company sE California~ WOI ~. O. Box 7-839,. Anchor{gej.~laska 4~ "L[,,:.t~i~';%;'~ [fM[('l[~'port location clearly anti tn ac~rdance with any State reqttlremeatl.® ~ee al~ ~l'u~ IT below.) ~899' North Had 2~2' ~est ~rom Sou~heas~ corneF of Section ~.IN., R~2 ~. Seward n & ~. Bottom hole: ~2' North and · 2952~ ~es~ ~rom surface location. eleVATiOn (Show wbedur Dr..~. --k et&) 276' l& '6, Fails Creek Unit ['Fall- C~eek U~t .... I ...~:r 6 (.~t) "-~" Falls Creek Unit Il. tBS.. ~.. It.. If., On BLt. AND ~JUIVI! O! aBA .. Sec. 6 - T, IN. ,R12W___SB_.SM 12. uou..r ;;;:;;i :a. Kenat Alaska Check Appropriate Box To Indicate Nature of Notice, Repod, or Other Data, :..' II~lllqlJEIl tlFOl~ O!: ~ . -,-...--.. ~'"""'"""'" I--I ..' '.""'"" ~'"'"° I--I j ..~,. o. Ac.,,.o .,., . ::.. :...A..o....-- I--J' . '(Other) ~ ti . ' (NO~B: Report results o! multiple ~ompletton on Well C,mpletiou or Rpeompletl, n Report and'f, olF fprm.) ' 1~. pEf,Cttlnt I,RiJlqml~l~ Oil CO.~II'M~TED OP~RATfOXt (Cle#rlj, store nil perrins,it detalia, and giTe pertinent dates, Including estimated date of .tatting IJsojnmed work. If wt4! il diruUonaiW drilled, giro aulmu~nor iomtion# .nd ,u(qm.red and true Tertleal depthN rot ail marten and sones perU- nmi to ~hia work.) · . :, ." '.: ' .=. ' . ~; .: - · ' .... .' · ~ _' . .... ~ * . · t~' '-:7"..- "- . °'.? v -. ..... ? ': ..... 1. Hove in necessary equtpuent (beaters trap, meter Fun, fla~e lV~ne)' £o~* ? '-' .: :~. ~' ,, .*~ prolonged production test o£ well.. ~-~. ~.'" :....-,-. - 2. Retrieve tubing, plugs and run static pressure survey,. ..-,. ;.: ..~ '.;: % .- . 3. Flo~ veil at approximately 2000 - 3o00 MCF/D for 7' to 10 da~:, 'p~.r'iod. Run flaying pressure surveys during flow period. Shut well in and run static build up pressure suryey Run tubing plugs and return veil to shut in status. TZTLn District Superintendent APPROVED BT CONDITIONS OF APPROVAL, Tm 'See Instructions on Reverse Side /,.o,; z SENT BY: · I 7-2-§9; B:O6Ai~I; ARCO ALASKA~ 907 276 7~42;# 3/ 6 ; .=. '"" "" ' U' TO STATES DEPARTME., OF THE INTERIOR vwr~ddr) GEOL~ IGAk ~RVEY ' SUNDRY NOTICES AND REPORTS ON WELLS Standa&'d Ott Company of CaltfornLa~ ~0! P. O. Box 7-839, Anchoraqe; Alo~kn 18~9~ ~or~h wad 252' Vest from Southeast corner of Section'6, ~.ZY., RI~ ~. Sevard g & ~. ' Bottom hotel 4420 North and 'Z95~ ~aet ~ro~ surface location. - J 276' il V, u#lf A~i#)IllI! #m)li ~Palis Creek Un:ti :lF'IIs creek"nSf L .-oL.~-~z' ~,~. ........ ~.'t · .I- Fa%to Creek Unit ~iUliYliW OB &ABA Sec. 6 = T. IN, ,RIi~T/ SB&,~I 't~':"'~'*~,?',~' ,~i;.'ii'i T~.'i~;~ii ..... I tCen.a t BorouRlj ..... A%.a~ka Check Appropriate Bo-, To Indicate Nalum el Notice, REM,, m OlheF DaM itl ,O~ ii ,tCMdlg AI&~#~ Jms'm Wll~ C#~Sll /~A#i IOl~t,) ., .-~ ................... ~, ~e in neaessa~ equt~ne (heater, ~rep, prolo~ed prod,mOron te~t o~ veil. ~,~ ; . ~.. -- Z, Retrieve tub/n& pleas and tun Fto~ vet1 at approximately ZOO0 - 3000 mF/D for 7' Run fto~tn~ preoeuEe surveys deltas [1o~ petted. ~ut ~11 In mad ~n static build up pressure su~ey ~un tub~n8 pTuBo end return welt to shut tn status, q4 · , ..... / ./" _____._ .:c_..v=., ~,RAI'~. I~O~ ,,,, ~rTtl DisCFtCt Superintende._n,~ ~'~., ., .-..~, · _, ~ .-- · .~ , ,,:2~ ,. ,; ' : %;..~. .... -..'., ,, ~ . ,~." _· ', ., .. ~.~,i,~., '. :' "': ' , .,,,.: ...~ · ~'~:~ ~",. ~. .':. .,.~,;. .,., -tv,,. . -- ,,& ~ '. SENT BY: I I 27, ' .5800. AOI.- $058! ~4 oO - ~'~' wt~otv r ,, $$0.,~ J 15 Gpt. 14 W ~'A t.t. $ '~.D, t/2/.! l~Ooc 7- 2-59 ; 8: 07A~I ' ARCO ALASKA- 1-75 j TIPCO J1-31-B4 J19 -: - ZO $OCAI. 1-31-84 · 25C0t 086 30 NEWMONr CLARK APACHE ~l aND ' ~0L-630~5 E~qer ,. 6-30-?~ U ! ,, SOt"IlL urv ' 10,fi-60 Exr $0 ~il , ~r. rEc ' n',,', ],,~' i $OCAL Sfote [A 0~3~9 907 276 7542 ;# 51 6 L._' It3 -- . ~'F--~ / ~OL- 60504 I I 30CA& ,."~' O. ~' S E OPHI[II$ $1@.41 State " NEWM(~ " , ' I SOCZ~ SENT BY: 7-2-89 ; 8:07A1~1 ' ARCO ALASKA-,. \\ 'L-' :. ° * . ~'g-' I "-"C" ~ / %% .. \ .I , ,~ ! * INL 907 276 7842;# 6/ 6 ' I ,', / ',,~.;: t I ~' ,.:, .,;,' ~i' /, .~,.' ,~ ....,, ;... , I ; ~... ,!: .... .. l.'- , .... u~.~. ~..)p .~ . . ' ,?'...,.,! "'" :~9'.) ' I .... ~"-!:' I.' "~' & ....:.:..? I .o ,' . ., ...... . .... I " ! /'7 ?". "',.-, .... '"' ;",-,:' r~ ~.., ~'! ' '"' ':-.-".:i', ..... o ~d a,f.n / AtlanticRichli3{dCompany SOU']"/-! ALASNA FgLLS C~EEK UNIT SEISMIC'MAP BY S~CAL ON , TOP OF PAY ZONE SCALE,' I" c, 3tO00' approx. ' ~,, l~t J. CViT~$H .,, .... t'll Illl-II I PLAT 3L/RFAC£ AND ~UB~URFACE LOCATION ~ WELL App~xima~e Scale AOL 00590 APPROXIMATE [4 / / ! / 'r I ~.,R.13W./ ., Z lAl~o~imate su~'£ace Ioe~/~/~ · /' 12 /'1 / / // · 18 S~T ~: 7- 2-59 ; §: 06A~I ' ARCO AI_A.~KA-, -- - ~ -: -'''~ := :'~ ': --= ~':' · APPLICATION FOR PERMIT TO DRILL, DEEPEN OR vLUG BACK · APPL,ICATION TO DltlLl~ ~ " D~]SP]~N ~ I:'I,UO BACIK ~ - NAMF. OF COMI"&NY Ol~ OI'~.IIA. TOI1 " , I 907 276 7§42;# 2/ 6 Box ._7.._~J._'~9. .............................. Anaho~ ............... VA~"' Hovenber 9, 196) Onshore; Ha~Zd A, ~edernon ~e ~aee Well l~r.~n~J~v~ (~Jve {oot~.~e fr~ sectJo~ litter} ~tlu..t.w.~hlp-.~.n~e Or ldoch & ~urvey ~e~...~pp~x. 3~0..'._.S0_~t~_and 2800, vest from ~ Comer 5cc, 6, T. ~ H,, R, ~ ~.,Se~.. Wildcat[ Ke~ Pe~nsu~a ....................................................................................................................................... t.)tgta~c., lu toilet, an4 dll'enEl,~ll ft'0tR nearest t~n or Dost ~lce Distance from proposed Ioca%ioa itl nel~re~t eomuleted or al)Plied--tm' welt on the same tense: IA.vro~. date work will et.r! ~ovenbe r ~, ,, , Number af wOll~ .n lease, lncludii,~ tide well completed in or drilling Io t.hT~ o i)roperty or tease linn: Approxi~te~ 550 ~ro~o..d de.th: ............................ '~';';;~;~OnshOreoffffshom~r ~,r-leaSe[ease~[(i,;',;;: _~660ac~s' ......................................... acres rf h'O~, J)iirc~hEuicd with (;n~ or morc ...$_l.0..s_0_Q~....;___]~._L~:l v21~ ~ ~2~ ~s ~~eO b~ 8t&~e goue~oa ~ew~~e .................................... l~rndttcl~g ~o~e ~lld ~l, eete~ new ~rofluc~ sone~ ~ttom hole loeat~on~ south an~ ~' east ~st be ~rec%~o~ d~l~a f~m onaho~ sur~ce ~cat~on to teat for ~oonib~e ~earBon ~se~rs ~h~eh ~y ~r~e offaho~ l~se ~o-~o ~L 00~, ~TANDARD OXI, COMPANY OF CAI,IF, CERTIFICAI'~,: I, the understgned, state tl~t I nm ~D.$~_~._ Of ~e..~S~e~ ~e~t~o~ ln~, (com~n~), and ~at I nm nuth0~ed ~ s~ld e~p~n~ to ma~e btl~ ~eport~ ~nd mat ~g r~zt wn~ pre, pared under 2n~ su~crvlel,~ al)d dh'eetlo~ and ~at the facts stated therebt ere true, eo~eet nnd complete ~ the best o! my knowledge. Permit Number: ^.,.., ,, App~ovul Det, e:~ ~'=3.t'~, ................. - ............... , D. I). ]?,,,('e, l"e.'¢,leu,m Notice: Berm'., ~e.m{J.~ h%, fbl~ f~rm ~ q~a ~ ~ have ~ven ail Jnf&fl~t~5 t~d~fe~ ~Uh~~arF ~er~d- eneo I ~ ~; be avoidS. See l~truol~n ~ Reverse Side cf FOrm -qlgna~.ure Original s;gned ~J. T. CROO:.'.SR J. T. CR(~I~R Ala~k,'l Off Omi GaS Conservation Commieskm AppllcntLon to Drill, Deepen or Plug 9ack Authorized by Order No. I · :tleettve October 1, 198B OCT 10 '95 0~:51PM ARCO AK LRHD DEPT ARCO Alaska, Ino- Date: Company: Fax #: Pages following cover: P. 1/1 Fax No. (907) 263-4966 P.O. Box 100360 Anchorage, Alaska 99510-0360 Company: Verify No: 0.2 ,. o,t~ ,! · .0. i~7 o.o~) o. o.~? OCT 'i ].'1995 Nasga .0it & Gas I~ons. Commission Ntohorage ARCO Alaska, Inc. {" Post Office B~^ ,b0260 Anchorage Alaska 99510-0360 Telephone 907 276 1215 March 31, 1995 Mr. David W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Johnston, Re: Suspended Well Update ARCO Alaska Inc. ("ARCO") has compiled data pertaining to the 25 suspended wells described in your August 19, 1994, letter. Any additional suspended wells which were discovered during our research are also included in this update. I have attached an update on each well and grouped the wells by geographic area. ,If you have any questions, please call the ARCO Contact indicated for each geographical area or me at 265-6914. Sincerely, ' //'SeniorLand~ , / JRW:hb Enclosures CC: M. L. Bill. L. D. Brown H. R. Engel R. M. Lance T. W. McKay G. K. Phillips M. J. Reisterer ATO 1528 LAO 466 ATO 1918 ATO 1420 ATO 1202 ATO 496 ATO 1439 RECEIVED APR 1 4 1995 Alask~ Oil & Gas Cons. Commission Anchora.'"., ARCO Alaska, Inc. Is a Subsidiary of Atlanll~: Richfield Company Exploration Wells (ARCO Contact: Tom McKay 265-6890) ARCO hereby requests extensions of "suspended" status for the following wells. West Mikkelsen State #1, APl # 50-029-20278-00, Permit # 78-0017-0 This well was Certified Capable of Producing in Paying Quantities on February 15, 1979. Hemi Springs State #1, APl # 50-029-21056-00, Permit # 83-0181-0 This well was Certified Capable of Producing in Paying Quantities on June 4, 1984. Birch Hill 22-25, Permit # 65-1 This well was Certified Capable of Producing in Paying Quantities. .Falls Creek #1, . .~,,~...-...4/.'?_ ' This well was CertTfied Ca~-bl.e of Producing in Paying Quantities on February 18, --1944. The following wells are scheduled to be plugged and abandoned: Delta State #1, APl # 50-029-20004-00, Permit # 68-0095-0 Delta State #2, APl # 50-029-20150-00, Permit # 74-0056-0 .Put River State #1, APl # 50-029-20017-00, Permit # 69-0036-0 Kavik Unit #3, APl # 50-179-20004-00, Permit # 73-0027-0 Highland State #1, APl'# 50-029-20199-00, Permit # 76-0017-0 Ravik State #1, APl # 50-029-20888-00, Permit # 82-0218-0 .Sag River State #1, APl # 50-029-20002-00, Permit # ? .Northwest Eileen State #1, APl # 50-029-20013-00, Permit # ? RE£EIVED APR 1 4 1995 Naska (Jif & Gas Cons. Commission Anchora, ~' The following well is no longer operated by ARCO: Swanson River Unit #34-15, APl # 50-133-10142-00, Permit # 60-0041-0 'lOP ~~oo FALLS CREEK U51 ~1 APRIL 12~ 1966' STATUS Production Status: Shut-in gas well Total Depth: 13,800 Casing: 13 3/8" cemented at 2468' 9 5/8" cemented at 8600' Perforations: 8395'-8415' 7615' squeezed 7550' squeezed 7600'-7562~ 7600'-7585' 7583'-7565' ...... -~90' squeezed 5442'-5470' 5430' squeezed Top Plug.: 8325' 5326' squeezed 5290'-5315' 5275' squeezed ~3927' squeezed / ; 3922' squeezed / 3900'-3911 perf. & reperf I · 3886' squeezed · -3884' squeezed Tubing: 2 7/8" EU~ landed in Model "D" retainer at 7542' with stinger to 7614' (See attached diagram) Rig Released: April 24, 196i RESERVOIR LIMIT TEST , 1.. Move in and install equipment for prolonged production test. a. High pressure heater (200,000 BTU minimum capacity) b. 4" meter run and Barton meter. c. Suitable stack linc. 2. Make wireline static gradient pressure survey. (MP static approxi- mately 3400 psi) (Use 2 bombs in tandem) 3. Run wireline pressure bombs with 100 hour clock and hang at mid point of perforation (7581'). (Use 2 bombs in tandem) 4. Place well on production at constant producing rate of 3000 MCF/D, for 7 day flow period. Rerun wireline pressure bombs as required to provide continuous pressure recording. 5. Rerun wireline pressure bombs as required and obtain 200 hour shut-in pressure build-up. 6. Depending on the results leave well shut-in or return to,production for additional time period. 7. Investigate reservoir limits by both material balance and flowing bottom hole pressure methods. ,4.. , &,'.," W. E. WHITNEY COMPIETiON REPORT N.,~', WELL STANDARD OIL COMPANY OF CALIFORNi& -'~-~'?'~ ' ~ .~ __ ~-:r~o.,.~.~ OPERATIONS .~q~ - OP~TOK Kenai Peninsula, Cook Iulet A~-ea, .tiaska LAND OFFICE: Anchorage PROPERTY: Falls Creek Unit WELL NO.: LOCATION: Fa~ls Creek #1 Sec. 6, T. 1 N., R. 12 W., Seward B & M. Surface: 1899' North .and 252' West from South 1/4 Corner Sec. 6. Bottom Hole: 442' North and 2952.5' West from surface location. ELEVATION: 276 ' K.B. DATE: October 13, 1961 DRILLED BY: DATE COMMENCED DRILLING: DATE RIG ~MLMASED: Coastal Drilling Company December 7, 1960 April 24, 1961 DATE OF COMPLETION: June 25, 1961 DATE OF 'INITiAL PRODUCTION: None, Moll Shut In . PRODUCT ION: SU~.~RY TOTAL DM~'~H: 13,795 D.D. PLUGS: 13,250 - 13'050 12,1OO - 11,850 10,100 - 9,900 8,700 - 8,454 8,454- 8,325 Cleaned out to 8,395 (Eff::~c'~i~c' Depth) Cores: 13,779- 13,789 13,789 - 13,795 COMPLETION REPORT FALLS CREEK UNIT %~ELL #1 Section 6, T 1 N., R. 12 W., Seward B &M Standard Oil Co. of Calif., ~'~.O.I., -~erator Page 2 S.U.~.~ARY~ Conti~.n.u~ed CASING: 36" Conductor cemented at ~:. 20" Conductor cemented at 248' with 480 sacks 13 3/8" casing cemented at 2468: in 2 stages: let stage around shoe ~,ith 550 sacks. 2nd stage through D.V. at 1518' with lllO Sacks. 9 5/8" casing cemented at 8600' around shoe ~nkth 1884 sacks. PERFORATION RECG{DS: i. 5- 1/2" holes at 388~' ~SO (Squeezed) 2, 5 - 1/2" holes at 3886' WSO (Squeezed) 3. 5 - 1/2" holes at 3922' %~S0 (Squeezed) 4'~ 5 - 1/2" holes at 3927' ~0 (Squeezed) 5'. 5 - 1/2" holes at 5275' WSO (squeezed) 6, 5 - 1/.2" holes at 5326' '~NSO (Squeezed) 7. 5 - 1/2" holes at 5419' '~SO (Squeezed) 8. 5 - 1/2" holes at 5490' %;S0 (Squeezed) 9. 5 - 1/2" holes at 7550' %~S0, k~.~O (Squeezed) 1~. 5 - 1/2" holes at 7615' ~S0 (Squeezed) . ll, 6 -' 1/2" holes/ft, at 3900 - 3911' (3 perforating jobs) 12. 2 - 1/.2" holes/.ft, at 5290 5315' 13~ 2 1/2" holes/ft, at 5442 ~470' 14. 4- 1/2" holes/ft, at 7562- 7600'. 15. 2 - 1/2" holes/ft, at 8395 - 8415' 1. Schlumberger I-ES Log, intez'val 24~%3 ' - 248 ' 2. Schlumberger Sonic Log~ interval 24~0' - 248' 3. Schlumberger Micro Log, interval 2433' - 248' 4. Schlumberger Continuous Dipmeter~ interval 2!~33 ' - 2~8 ' 5. Schlumberger I-ES Log, interval 6676' - 2~2' 6. Schlumberger Sonic Log, interval 6672 ' - 2452 ' 7. Schlumberger !,'~icro Log, interval 6676: - 2452' 8. Schlumberger Continuous Dipmeter, interval 6676' - 2452 ' 9. Schlumberger I-.ES Log~ intervs.1 8614' -6677' 10. Schlumberger Sonic Log, interval 8610', - 6672' ll. Schlumberger F~cro' Log, intervs1 8615' - 6676 ' 12. Schlumberger Continuous Dipmeter, interval 8598' - 5600 ' 13. Schlumberger I-ES Log, interval 10,367' - 8,594' 14. Schlumberger Micro Log, interval 10,367' - 8,594' 15. Schlumberger I-ES Log, interval 11,729' - 10,367' 16. Schlumberger Sonic Log, interval 11,723' - 10,364' 17. Schlumberger Cement Bond Log, interval' 8,594' - 4,560' 18. Schlumberger I-ES Log, intern, al 12,698 ' - ll,~ 729' COMPLETION P~E PORT FALLS CREEK U~IT ~.~ELL #1 ~ection _6_, .T. 1 N.~ R. 12 W., Seward B & M Standard Oil Co. of Calif., W.O.I., - Op. erator Page 3 su mmR. Y, Con. t. in ued %~L SURVEYS: Continued 19. Schlumberger Sonic Log, interval 12,5}%2 ' - ll, 724 ' 20. Schlumberger Micro Log, interval 12,696' - 10,367' 21. Schlumberger Continuous Dipmeter, interval 12,698' - 8,600' 22. Schlumberger I-ES Log, interval 13,783 ' - 12,698 ' 23. Schlumberger Sonic Log, interval 13,770' - 12,542' 24.. Schlumberger Micro Log, interval 1.~, 771 ' - 12~598 ' 25. Schlumberger Dipmeter Log, interval 13,000' - 12,500' 26. Schlumberger Neutron Collar Log, interval 8,460' - 3,000' 2?. Schlumberger Gamma Ray Collar Log, interval 8,460' - 500' DRILL STEM TESTS: 1. HCT #1 on perforated interval 8,395' - 8,415' 2. HCT #2 on perforated interval 7,562' - 7,600' 3. HCT #3 on perforated interval 5,442' - 5,47o' 4. HCT #4. on perforated interval 5,290' - 5,315' 5. HCT #5 on perforated interval 3,900' - 3,911' 6. HCT #6 on perforated interval 3,900' - 3,911' 7. HCT #7 on perforated interval 3,900' - 3,911' 8. HCT #8 on perforated interval 3,900' - 3,9].1' 9. HCT ~9 on perforated interval 3,900' - 3,911' COMPLETION REPORT FALLS CREEK UNIT ~LL #1 Section 6~ T. I N.~ R. 12 W.~ Seward B & M Standard Oil Co. of Calif., W,O.I., - Operabo~ Page 4 D. ecember 7~ 196.0 Spudded at 4:00 p.m., December 7, 1960. Drilled 12¼" hole 0 - 251 ' 251 ' Drilled Opened 12~" hole to 26" hole 0 - 58' 58 ' Opened 78 pcf Mud December 8, .!960. Opened 12-~-" hole to 26" hole 58' - 251 ' 193 Opened Ran 248' of 20" Conductor Pipe. Cemented 20" conductor pipe at 248' in single stage with 480 sacks of cement treated with 2% Calcium Chloride, using Halliburton power equipment. Cemented around shoe with 480 sacks of cement, hnmped 20 barrels of water ahead, mixed 480 sacks of cement in 15 minutes using Halliburton truck, displaced in 20 minutes using rig pumps. .Average slurry weight ll6#. Displaced cement through 236' of 2 7/8" t~bing hung inside of 20" conductor. Cement in place at 4:00 p.m. Conductor Detail 248' - 20" 97# Grade B. Seamless Range 3 Stood cemented 2 1/2 hrs. Released pressure on tubing at 6:30 p.m. Pulled out tubing. Commenced flanging up. 78 pcfmud ~ec,ember 9, ,1960 Completed flanging up. Drilled m~use hole. Checked BOPE, Kelly Stop, Hydril and pipe rams with 1500 psi. OK. Drilled out cement 225' - 248'. Drilled 12 1/4" hole. 251' - 456 ' 205 ' Drilled 75 pcf Mud COMPLETION REPORT FALLS CREEK UNIT WELL #1 Section 6~ T. 1 N.~ R... 12 .~'~..~ Seward B & M Standard Oil Co. of Calif., ~.LO.I., - Operator Page 5 December lO~ 196.0. Drilled 12 1/4" hole. 456 ' - 1382 ' 926 ' Drilled Directionaliy drilled 12 1/4" hole. (Using jetting method) 1382' - 1630' 248' Drilled Kickoff point at 1346'. 77 pcf Mud December ll,. 1960 Directionally drilled 12 1/4" hole 16 30' - 1814 ' 184 ' Drilled Set Whipstock #1 at 1814' faced N. 25' W. Drilled off whipstock with 7 5/8" bit. 1814' - 1829 ' 15 ' Drilled Opened .7 5/8" hole to 12 1/4" hole 1814 ' - 1829' 15 ' Opened Directionally drilled 12 1/4" hole 1829' - 1850' 21' Drilled 78 pcf Mud ~e.c~mber 12, 1960 Directionally drilled 12 1/4" hole 1850' - 2468' 618' Drilled Circulated and conditioned mud 1 hour. Ran Schlumberger I-ES Log, interval 2443' - 248'; Sonic Log, interval 2430 ' - 248 '. 75 pcf Mud ~ece~b~..r ..!3, 19~60 Ran Schlumberger ~licro Log, interval 2433' - 248'; Dipmeter Log, interval 2433' - 284'. Pulled BOPE welded on conductor pipe. Nippled up conductor pipe. Opened 12 1/4" hole to 18 5/8" hole 251' - 1332 ' 1081' Opened 75 pcf Mud COMPLETION REPORT FALLS CREEK UNIT WELL #1 Section 6~ T. 1 N.~ R. 1.2 W., Seward B & M Stmdard Oil Co. of Calif., %.~Y.O.I., - Operator Page 6 December 14, 1960 Opened 12 1/4" hole to 18 5/8" hole. 1332 ' - 2468' 1136 ' Opened Pulled out. Checked Bit. Ran in, circulating s_nd conditioning mud for 4 hours. 82 pcf Mud De.cember 1.5.,...1.9.60 Ran 59 joints of 13 3/8" casing. Cemented 13 3/8" casing at 2468' in 2 stages with 1660 sacks of cement treated with 0.3% HR-4 using Halliburton power equipment. Used 1 top and 1 bottom rubber plug. 1st Stage around shoe with 550 sacks of cement. Pum~. ed 50 barrels of water ahead, mixed 550 sacks of cement in 45 minutes using Halliburton truck, dis- placed in 35 minutes using rig pumps. Average slurry weight 116#.. Bumped plug with 1200 psi. Full circulation. 2nd Sta~ through DV at 1518'. Dropped DV bo~o, opened DV ports with 500 psi. .~p~'~ 50 barrels of water ahead, mixed 1110 sacks of cement in 70 minutes using Halliburton truck, displaced ~n 25 minutes using ~rig pumps. Average slurry weight 116~. Closed ~V porto with 2000 psi. 3/4 to full circulation, with cement returns to surface. Cement in place at 10:15 A.M. All 59 Joints or Landing Nipple CASING DETAIL 2432.71 ' 18.60' 13 3/8" 54.5# J-55, R-3, 8RD Equipped with Baker Shoe, Baker fillup Collar, Centralizers and Scratchers. 2451.31' Ail 2451.31 ' Bel~ K.B. - 16769' Landed at 2468.00 ' Flanged up. Installed BOPE and tested with 1500 psi. OK. Checked C.S.O., 30 minutes. OK. COMPLETION P~EPORT FALLS CREEK UNIT h~LL #1 Section 6, T.. 1 N., R. 12 W.,. Seward B. & M Standard Oil C°. of Calif,, W~OAI., - Operator Page 7 December.. 16~ 1960 Drilled out D.V. Checked pipe rams, hydril, kelly stop and D.V. with 1500 psi. for 30 minutes. OK. D.O. cemented at 2377' - 2468'. Directionally Drilled 12 1/4" hole. 2468' - 2769' 301' Drilled Set whipstock #2 at 2769'. Drilled off whipstock with 7 5/8" bit. 2769 ' - 2784' 15 ' Drilled 78 pcf Mud Dec.embe. r 1.7. ~ 1~96~ Opened 7 5/8" hole to 12 1/4" hole. 2769 ' - 2784' 15 ' Opened Directionaily drilled 12 1/4" hole 2784' - 3152' 368' Drilled 85 pcf Mud Decembe. r.18 - 24,~ 196O Directionally drilled 12 1/4" hole. 3152' - 5286' 2134 ' Drilled 85-96 pcf Mud D.e. cember .25, 1960 Directionally drilled 12 1/4" hole. 5286' - 5436' 150 ' Drilled Stuck pipe while taking survey at 5424'. Spotted 50 barrels of Lube 90 distillate, displaced with 57 barrels mud, leaving 30 barrels outside and 20 barrels inside D.?. Oil in place at 9:45 p.m. Circulated oil at 1 bbl. per hour rate. '~orked Bumper sub. 96 pcf Mud COMPLETION REPORT FALLS CREEK UNIT WELL #1 S. ection 6~ T.. 1 N., R. 12 W., Seward B & M Standard Oil Co. of Calif., ~.O.I., - Ooerator Page 8 December 2.6, 1961 Worked stuck pipe. Moved oil at 1 barrel per hour rate until 8:00 A.M. Moved oil at 2 bbls. per hour until 12 Noon. 48 bbls. out at 12 Noon. Started circulating at 12 Noon, added 2 barrels of bit lube, 23 - 50 lbs~ sacks of Carbonox and 35 sacks of Baroid. Spotted 75 barrels of SCU Crude Oil, 30 barrels outside m~d 45 barrels inside D.P., mixed 2 barrels of N.I.O. with crude. Followed crude with 32 barrels of mud. 27 barrels left in pipe at 12 Midnight. Moved oil at 3 barrels per hour rate. 93 pcf Mud December 2.?~ 1960 Worked stuck pipe loose at 1:30 A.M. Circulated oil out. Added 8 barrels of Trimulsion and 26 - 50 lb. sacks of Carbonox. Pulled out and laid down 17 joints of crooked pipe. Directionally drilled 12 1/4" hole. 5436' - 5625' 189 ' Drilled 96 pcf Mud December .28,, 196~ -- Janu. a~y_~, 1961 Directionally drilled 12 1/4" hole. 5625' - 6619' 984' Drilled 97 pcf Mud Directionally drilled 12 1/4" hole. 6619' - 6685' 66' Drilled Ran Schlumberger I-ES Log interval 6676' - 2452'; Sonic Log interval 6672' - 2452'; Micro Log interval 6676' - 2452'; Dipmeter Log interval 6676' - 2452'. 98 pcf Mud J..~anuary 3 -- ll, 1961 Directionally drilled 12 1/4" hole. 6685' - 7885' 1200' Drilled 95-97 pcf Mud COMPLETION REPORT FALLS CREEK UNIT k~LL #1 Section 6z.T_._i_._N_..,.._R:. 12 ~'L~ Seward B & M Standard Oil Co. of Calif., '~.~.O.I., - Operator Page 9 January. 12, 1961 Directionally drilled 12 1/4" hole. 7885' - 8007' 122' Drilled Twisted off at 8007'. Left 12 l/k:' bit, 12 1/4" D.T., 7 _3/4" Monel D.C., 12 1/4" O.T., ? 3/4" B.S., 2 - 7 3/4" D.C., ? 3/4" B.S., 12 1/4" O.T. B.S. length is 126'. Top of fish at 7881'. 96 pcf Mud Janu.a~.y 13~ 1961 Ran in with Bowen 9 1/2" overshot with 7 !/2" grapple and 6" B.$., Crossover, and 2 - 7 3/4" D.C. Circulated 1/2 hour. ~.Torked over fish. Chained out, recovered fish. Directionally drilled 12 1/4" hole.. 8OO7' - 8036' 29' Drilled 95 pcf Mud j .anuary 14....~ 19, 1961 Directionally drilled 12 1/4" hole. 8036' - 8591'. 555' Drilled 95-96 pcf Mud Directionally drilled 12 1/4" hole. 8591' - 8608' 17 ' Drilled Twisted off at 8608' due to Bumper sub failure. Left 12 1/4" bit, 12 1/4" DT, 1 - 7 5/8" Monel D.C., 10 5/8" D.T., 2 - 7 3/4" D.C., 12 1/4" D.T., 2 - 7 3/4" D.C., 12 1/4" D.T., Crossover, and 1/2 of 7" bumper sub. Length of fish 229'. Top of fish at 8379'. Ran in with 8 5/8" Bowen overshot with 5 3/4" basket grapple and 6" Bumper sub, 6" B~en jars, crossover, 2 - 7 3/4" D.C., Crossover, 2 - 6" D.C. ~orked over fish. Slipped off t~ce. Circulated in 5 barrels of bit lube. Pulled out, ran in with 8 1/2" Bowen socket extension, 5 3/4" basket grapple, crossover, 7" bumper sub, 7" Shaffer jars, 2 - 7 3/4" D.C., crossover sub, 2 - 6" D.C. on 4 1~2" D.P. 95 pcf Mud COMPLETION ~ZPORT FALLS CREEK UNIT I~,~ELL #1 Section 6~ T. 1 N.~. R- 12 ~.',.~.~ Seward ~ & M_ Standard Oil Co. of Calif., W.O.I., - Opsrs.tor Page 10 J, anuary 21~ 1961 Worked over fish. Circulated and worked pipe. Spotted 60 barrels oil (30 bbls. Pacific Base and 30 bbls. Diesel). Oil in place at 5:00 A.M. 30 bbls. inside and 30 bbls. outside. Moved oil at 3 bbls./hr, rate. Little or no action on tool. Pipe stuck up hole after tying onto fish. Circulated oil out. Circulated and worked stuck drill pipe. Could not get free of fish. Rigged up and ran Ford Alexander free point indicator and string shot on Schlumberger wire line. Free ooint at 3220'. Fired string shot at 3159' and backed off. Left 8 1/2" Bowen'socket extension, 5 3/4" basket grapple, crossover, 7" bumper sub, 7" Shaffer jars, 2 - 7 3/4" D.C., crossover sub, 2 - 6,' D.C. and 4 1/2" D.P, Total length of fish #2 is 5222'. Top of fish #2 3159'. 95 pcf Mud January 22, 196~ Ran in with 2 Shaffer Bumper subs, 4 - 7 3/4" D.C., Crossover sub, on 4 1/2" D.P. Screwed into fish. Bumped down and worked fish. Ran Ford Alexander free point indicator a~ shot string on Schl'~mberger wire line to 7500'. Free point at 7300'. While locating collars preparatory to backing off, pipe stuck. No action on bumper subs. Circulated and worked pipe. Ran Ford Alexander free point indict, tot and shot string on Schlumberger wire line. Free point at 2933'. Fired string shot at 2933' and backed off. Left fish #3 in hole. Fish consists of 4 - 7 3/4" D.C., Crossover sub and 4 1/2" D.P. Length of fish #3 is 226'. Too of fish now 2933'. ?icked up 6 joints of 9 7/8" wash oipe, Bowen jars, ~. Bumper subs and Shaffer Bmmper safety, 5 - 6" D.C. on 4 1/2 D.P. ~ashed over fish 2933' - 2967'. 94.5 pcf Mud J_anuar3r 23, 196~1 Washed over fish 2967' - 3174'. Pulled out, laid down wash pipe. Ran in with 4 1/2" D.P. open ended. Screwed into fish. Ran Ford Alexander free poimb indicator and shot string on Schlumberger wire line. Free at 8510' and 8145', stuck at 8169'. Fired shot string at 8139' and attempted to back off. Pipe didn't torque up. Ran Ford Alexander free point indicator and shot string on Schlumberger wire line. Free at 8370'. Pipe stuck uo hole. Pulled free point indicator to work pipe free. Ran Ford Alexander free point indicator and shot string on Schlumberger wire line. Ran to 8170'. Free at 5165'. Fired shot string at 5074' and backed off. Recovered fish #3 plus 1815' of 4 1/2" D.P. off of fish #2. Top of fish n~ 5074'. 94.5 pcf Mud COMPLETION REPORT FALLS CREEK UNIT ~.~LL #1 Section 6~ .T. 1 N..~ R. 12 ~.'.~.~ Seward '73 & M Standard Oil Co. of Calif., k~.O.I., - Operator Page ll J. anuary 2~, 1.961 Ran in with 8 5/8" bit, 6" D.C., 8 3/4" D.T., 2 - 6" D.C., 8 3/4" D.T., B.S., lO 5/8" D.T. on 4 1/2" D.TM. Reamed hole 2490' - 5024'. Circulated and conditioned mud. Pulled out. Ran in with 4 1/2" D.P., 6" B.S., 3 - 6" D.C., 4 1/2" D.P. and 4 - 7 3/4" D.C. at 2433' and 4 1/2" D.P. 92 pcf Mud January 25~. 1.9~! Screwed into fish, worked fish. Ran Ford [!.lexander free ooint indicator and string shot on Schlumberger wire line to 5500'. Free at 5160', fired shot string at 5136', and backed off. Recovered 2 singles of 4 1/2" D.P. length 62'; Ran 'in with 4.1/2" Saver sub, 2 - 6" B.S., 8 - 6" D.C. on 4 1/2" D.P. Screwed into fish, worked fish. Ran Ford Alexander free .ooint indicator, and shot string on Schlumberger wire line to 6000'. Free at 5585'. Fired shot string at 5574' and backed off. Recovered 14 singles of 4 1/2" D.P. (13 of which were crooked), length 435'. Ran in with 4 1/2" saver sub, 2 - 6" B.S., 8 -. 6" D.C. on 4 1/2" D.P. Screwed into fish, worked fish. Ran Ford Alexander free point indicator and shot string on Schlumberger wire line to 8187', free at 8177'. Fired shot string at 8147' and backed off. Commenced pulling OUt. 91 pcf Mud Januar~ 26, 1961 Recovered 27 2/3 stands of 4 1/2" D.P., length 2572.82'. Ran in with 7 joints of 9" wash pipe with 9 5/8" shoe, drive sub, crossover, Shaffer Bumper sub, Bowen jars and 3 - 6" D.C. on h' 1/2" D.P. Circulated and conditioned mud at 8142'. Worked over fish. Washed over fish 81~4.7~ 8377' Pulled out and laid down wash pipe, Ran in with Saver sub,o~,pe~ sub, ~ - 6" D.C. on 4 1/2" D.~. Screwed into fish. Ran Ford Alexander free point and shot string on Schlumberger wire line. Fired shot string at 8379'. Commenced pulling out ~ 91 pcf Mud anuary !9 1 Recovered 1 single of 4 1/2" D.P., 3 - 6" D.C., Crossover, 2 - 7 3/4" D.C., 2 short subs, Bowen jars, bumDer sub, 2 short subs, and Bowen socket. Length 205'. Ran in with wash pipe. Worked over fish. Washed over fish 8379' - 8607'. Circulated 1 hour. Pulled out. Ran in with 8 1/2" Bowen socket with 5 3/4" grapple, worked over fish. Screwed into ~ish, commenced pulling out. 91 pcf Mud COMPLETION REPORT FALLS CREEK UNIT ~ELL #1 Section 6~ T. 1.N., R. 12 kT., Seward B &M Standard Oil Co. of CaLif., k~.O.I., - Operator Page 12 January 28, 1961 Recovered 12 1/4" bit, 12 1/4" D.T., 1 - 7 5/8" Monel D.C., 10 5/8': D.T., 2 - 7 3/4" D.C., 12 1~4" D.T., 2 - 7 3/4" D.C., 12 1/4" D.T., Crossover and bottom half of 7" Bumper sub. Directionally drilled 12 1/4" hole. 8608' - 8612' 4 ' Drilled Circulated and conditioned mud 1 hour'. Ran Schlumberger I-ES Log, interval 8614' -6677', Sonic Log, interval 8610' -6672', Micro Log, interval 8615' - 6676 '. 91 pcfMud ~anuary 2L9, ..19~1 Circulated and conditioned mud 2 hours. Ran Schlumberger .Dipmeter Log, interval 8598' - 5600'. Pulled up to 5370' and Dipmeter stuck. Stripper Dulled loose and worked line off of sheave. Made up Schlumberger 4 1/2''° junk basket with grapples. Ran in. Caught fish, pulled up lO,O00~ and released pull. Pulled up lO, O00~ again, wire line came loose, recovered wire line and 10" of rubber and 12" steel top of dipmeter (fishing head). 91 pcf Mud Ran in with Bowen 8 5/8" socket with 3 1/2" basket grapple, 4 1/2" guide and 6 1/2" B.S.. on 4 1/2" D.P. Found top of fish at 8594,'~ fish had fallen back down hole from 5370'. Worked over fish. Amp pressure went from 250~ to 750~., shut pump down. Chained out. N~,,recover¥. Ran back in with B~en 8 5/8" socket, 3 1/2,' basket grapple, B.S. on 4 1/2" D.P. Circulated 30 minutes. Worked over fish, packed off over fish. Chained out recovered fish (Dipmeter). Ran in,drilled up junk. Directionally drilled 12 1/4" hole. 8612' - 8623' 11' Drilled 93 pcf Mud January 3!,. 1961 Directionally drilled 12 1/4" hole. 8623 '-. 8633' 10' drilled COMPLETION REPORT Page 13 FALLS CREEK U~iT ~LL #~ Section 6~ T. 1 N., R. 12 W., Seward B & M · '" - Ooerator Standard Oil Co of Calif., ~.~.0.i., January 31, 1961, Continued Had washout at the string reamer, through ~,,lng slot, left wing in hole. Worked by wing. ~lled out and installed new bit. Directionally drilled 12 1/4" hole. 8633 ' - 8724' 91' Drilled 94 pcf Mud Febru. a..ry l, i961 Directionally drilled 12 1/4" hole. 8724' - 8836' ll2' Drilled Feb ~rua~y....2, 1961 Directionally drilled 12 1/4" hole. 8836 ' - 8909' 73 ' Drilled Circulated 3 hours, Laid down D.P. and drilling set up. Commenced running 9 5/8" casing at 11~00 'P.M. 96 pcf Mud February. 3,_ 196_1 Finished running 9 5/8" casing. Lauded 9 5/8" casing at 8600'. .~--~, CEMENTING DETAIL Cemented 9 5/8" casing at 86OO' in a single stage with 1884 sacks of cement treated with 0.3% HR-4 using Halliburton power equipment. Used 1 top and 1 bottom rubber plug. Cemented around shoe ~gth 1884 sacks of cement· Pumped 50 barrels of water ahead, mixed 1884 sacks of cement in 60 minutes using Halliburton truck, displaced in 55 minutes using rig pumps, Average slurry weight 117#. Bumped plug with 2000 .osi. Cement in place at 2:10 p.m. Had 2/3 lost circulation during last 5 minu~es of ~isplacin~. Estimate 150 barrels lost. Circulating pressure dropped from~ 1600 psi to 14OO psi. Drilling fluid left behind casing treated with hydrazine. Casing froze at 8600' unable to reciprocate. 190,0OO~ hookloadbefore cementing 170,OO0~ hookload after cementing and before landing casing COMPLETION REPORT FALLSCREN( UNIT k~LL #1 Section 6~,.T.. 1 N., R. 12 :":,~..~ Seward B & M Standard Oil Co. of Calif., l.~.O.I., - Operator Page 14 Fe, b, ruary ,3,, 1961~ Continued Ail 256 joints or 256 joints or 1 joint recovered 255 joints or Recovered Below K.B. Casing Landed @ 8600' CAS ~NG DETAIL 8620.89 ' 8621 ' 31' 8590' 9 5/8" 40~ N-80 Youngstown Casing equipped with Bs_~er differential fill up shoe with whirler ports, Baker cement baffle 2 joints up and central- izers at 8580', 8500', 8400 ', 7660 ' and 7600 '. 8583' 17' Commenced flanging UP. Februa~r~.....4, !9~! Completed flanging up. Installed and tested BOPE with 15OO psi. OK. Tested C.S.O. with 1800 psi. for 15 minutes. OK. Tested GK hydril, pipe rams and kelly cock with 16OO psi. OK. Tested oack off with 1800 psi. OK. Picked up 8 3/4" bit and direction drilling setup. Ran in, stopped~ at 848'.. Could not work through tight spot. Ran in with 8 1/2" Security bull nose hole opener w~th 8 3/4" Driltrols in directional setu~o. Could not get driltrols through tight spot. Ran in with 8 3/4" 3-point reamer with 8 5/8" bit, on single D.C. and B.S. Reamed casing 848' - 870'. Top 5' re~med hard. Rereamed several times, still unable to wcrk through tight spot without rotating. Ran in with 8 5/8" bit and directional drilling setup with all 8 5/8" driltrols. 93 pcf Mud Fe,br,u,ar¥ 5~. ,!9.6.1 Found top of cement at 8504'. Drilled out cement from 8504' - 8531'. Drilled out bard cement 8531' - 8595'. Drilled out shoe at 8595'. Drilled out hard cement to 8718'. C.O. bridges 8718' - 8800'. C.O. hard mud ao~ bridges 8800 ' - 8909 '. Directionally drilled 8 5/8" hole. 8909' - 8929' 20' Drilled 94 pcf Mud COMPLETION REPORT FALLS CREEK UNIT #1 S~ecti. 9. n 6~. T. 1 .N.~ R. 12 !~J..~ Seward B & N Standard Oil Co. of Calif., W.O.I., - Operation Page 15 Febru .ary 6 - 19~ 1961 Directionally drilled 8 5/8" hole. 8929 ' - 10, 355 ' 1426 ' Drilled 91-92 pcf Mud February ,20~ 1961 -- Directionally drilled 8 5/8" hole. 10,355' - 10,367' 12' drilled Circulated and conditioned mud 2 hours. Pulled out. Ran Schlumberger I-ES Log interval 10,367' - 8,594' Sonic Log interval 10,364' - 8,594' Micro Log interval 10,367' - 8,594'. ' Directionally drilled 8 5/8" hole. 10,367 ' - 10,400 ' 33 ' Drilled 93 pcf Mud F_e ruarT: 21 -4, 196] Dire¢~ionallydrilled 8 5/8" hole.. 10,400' 11,'706, ': - 1306' .,."lied ,. 91-93 pcf Mud March 5~ ..1961 Directionaliy drilled 8 5/8" hole. 11,706 ' ' 11, 727 ' 2'1 ' Drilled Circulated and conditioned mud. Ran Schlumberger I-ES Log interval 11,729' - 10,367' Sonic Log interval 11,723' 10,364' Cement Bond Log interval 8,594' - 4,560'. ' Directionally drilled 8 5/8" hole. 11,727' - 11,757" 30 ' Drilled 91.5 pcf Mud .March. 6 - 16, 196~1 Directionally drilled 8 5/8" hole. 11,757 ' - 12,654' 897' Drilled 90-92 pcf Mud COMPLETION REPORT FALIS CREEK UNiT #1 Section 6~ T 1 N.~ ~...1~ ¥.~ Sew~rd. B & M Standard Oil Co. of Calif., W'.O~I;, - Operator Page 16 March 17~ 1961 Directionally drilled 8-5/8" hole.. 12,654' - 12, 700' 46 ' drilled 92 pcf mud Circulated and conditioned mud. Ran Schlumberger I-ES log interval 12,698'- 11,627', Sonic log interval 12,698'-11,698', Micro log interval ]2,696'- 10,367', Continuous Dipmeter interval 12,698'-8,600'. March..1.8. - Mar~h 31, 1961 Directionally drilled 8-5/8" hole. 12,700' - 13,741' 1,041' drilled 90.5-92,5 pcf mud April 1, 1961~ Ran I-ES log, interval 13,783-12,698, Sonic log and Dipmeter sondes would not go below 11,778'. Directionally drilled 8-5/8" hole. 13,741' - 13,779' 35' drilled 91 pcf mud Cleaned out to 13,779'. Ran velocity survey, interval 13,000' to surface. Reamed 8-5/8" hole. 13,759' - 13,779' 20' reamed 91 pcf mud Ran Sonic log, interval 12,542-13,780', Micro log, interval 12,696-13,780, Dipmeter, interval 12,500'-13,000'. A~.ril 3, 1961~ Ran in with core barrel, 8½" Reese rock head core bit. Core #1. Cored 10' interval 13,779' - 13,789' 4' core recovered. 92 pcf muc C O~tWLET ION REPORT FALLS CREE{ UNIT #1 Section 6~ T. i ~!.~ R. 12 :~.,. Seward B & M Standard Oil Co. of Calif., ~.~. O. I., - Operator Page 17 April .h~ 1961. Core #2. Cored 6'. 13,789' - 13,795' T.D. 6' core recovered 92 pcf mud A. pril ,5, 1961 Commenced abandonment of lower portion o f hole. Circulated, ran to 13,250~ with ~½" drill pipe. Plug .~.__~l - Plugged from 13,250' to 13,050 ' with 85 sks construction cement @ 2 :~5 AM. Pumped 20 bbls water ahead. Ce~nt mixed in 12 rain, ll6# slurry. In place @ 3:35 ~.M. P.!'~g #2 - Plugged from 12,1OO'- 11,850' with l~O sks. construction cement. Started @ ~:~5 ~. Pumped 20 bbls. water ahead. Mixed cement in l? min, ll6# slurry. Displaced in 25 min. In place at 5:05 ~2~. Pulled up, circulated. Feeling for top of 2nd plug. April 6, 1961 Located top of Plug #2 at 11,866~ after 6 hrs. Plug #3 - Plugged from 10~100'- 9900~ with 85 sks construction cement. Mixed in lO m in, llT# slurry, dis- placed in 25 min. In place 2;35 ~4. Plug #k - Plugged from 8700'-8500' with 135 sks construction cement. Mixed in l0 min, llT# slurry, displaced in 25 min. Located. top of plug at 8~5h'. Scraped 9-~/8" casing in I hr. Rigged up Schlumberger. Ran Schlumberger Neutron log interval 8h60-3000' and Gamma log interval 8~60'-500'. Jet perforated 2 - ½" holes/ft. 8395'-8h.15'. H~CT #1, (8395-8415~ '~)~ Testor assembly as follows: 2 outside BT recorders, lO~ of 2-7/8" perf'd tail pipe, 9-5/8" type "C" hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders, hydrospring tester and TC valve above 93' of 6" drill collars on 8211' of ~'~" drill pipe. Used 186~ of W.C. Set packer at 8333', 22' of tail to 8355~. Opened tool at 12:35 PM for 30 rain ISI pressure. Opened tool to surfs, ce at l:O~ ~ for 2 hr ~ rain flow test. 1/~" bean open 50 min. Immediate blow and steady medium blow during entire period. 3/8" bean open I hr l[[ min. Slight increase in blow.. Blow remained steady during entire period. Gas to surface I hr 28 rain after opening tool for flow period. Flow estimated 20-30 mcf/day. Shut in tool at 3:09 PM for 35 rain FSI p':.~ess. ?ulled packer loose at 3 :[~ ~:~. P~covered 1~0' net rise, slightly gassy and watery drilling fluid. No trace of oil or t.ar. COmPLETiON REPORT FALLS CP~E~ ~iT #1 Section 6~ T. I N.~. R. 12 W., Seaward c~ Standard Oil Co. of Calif., W.O.i., - Ooerator Page 18 April 7 ~ 1961 cont ' d Resistivity of fluid recovered: 2.2 ohm m2~m at 49° F, equivalent to 200 g/g NaC1 Resistivity of normal drlg fluid: 1.5 ohm m~/m at 61° F, equivalent to 250 g/g NaC1. Pressure Data: IH ISI IF FF FSI FH Top inside 5228 1074 330 163 1793 5199 Bottom inside 5356 1103 243 170 1836 5252 Pulled out, ran in for plug. Plug #5 - Plugged 8454'-8325' thru 4½" drill pipe hung at 8454' with 50 sks 'c°nst~. ce~nent, 117# slurry. Took 118 bbls water to displace. Ce~.'mnt in place at 9:00 ~:I. April 8~.. 1961 Jet perf'd 5 - ½" holest at 7615'. Ran squeeze tool, set packer with 25 sks cement. Set retrievable retainer at 7562', broke down with 2000 psi. Top away at 1500 psi. Mixed 50 sks constr, cement, llS# slurry @ 6:05 AM. Dis- placed at 6:15 AM with l0 bbls water ahead, followed by 2 bbls water ao~ 85 bbls mud. Closed tool. Displaced 15 bbls, I bbl cmt (5 sks) thru holes @ 7615', continued 'displacing in stages for 50 min. Squeezed 25 sks cement thru holes at 7615'. Final press. 5000 psi. Max. back up annular press in- creased to 2000 psi during displacement. Cement in place at 7:40 AM. Jet perf'd 5 - ½" holes at 7550'. Set retrievable retainer at 7463'. Packer failed during displacement and back scuttled cement. Pulled retainer - replaced slips, rubbers. Reran retainer, set at 7460'. Packer f~iled during displacement, back scuttled cement. ~pril 9~ %96,% Pulled, ran scraper and 8-5/8" bit. Scraped 7450'-7560'. Circulated, pulled out. Squeezed hole~ at 7550'. 200 bbls water ~ead, 100 sks constr cement, 117# slurry, 2 bbls water behind. Displaced 64 bbls drilling fluid. Pumped out 10 bbl cement, waited 4 rain, pumped 2 bbls, then 1 bbl every 4 min for a total of 18 bbl. In 15 rain opened, breather, cement flowed back. Pumped cement back, held another 15 min. Held OK. In place at 3:25 PM. · Working press. 1100 psi, Final press.1500 psi. Drilled out cement, scraped, circulated. Pulled for Schlumberger. COMPLETION i~P ORT FALLS CREEK b~IT #1 Section 6~ T..1 N.~ R. 12 W.~ Seward B & M Standard Oil Co. of Calif., W.O.I. - Operator Page 19 April lO~ .1961.. Jet perf'd 2 - 1/2" holes/ft 7562-7600'. HgT #2 (75 2.76o0'), Tool assembly as follows: 2 outside BT recorders, 10' of 2-7/8" perf'd tail pipe, 9-5/8" type "C" hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders, hydrpspring tester, 90' drill collars and TC valve. No W.C. Ran on 7405' of 4~" drill pipe, 126' drill collars and tools to packer. Set packer at 7526 with 21' of tail to 7547. Opened tester at 7:27 AM for 32 rain ISI pressure. Opened tool to s~rface at 7:59 AM for 9 hr 41 rain flow test. I~unediate strong blow of air. Gas to surface at 8:20 AM in 21 min. Took pressures during flow period. l~e. presentative Flow Rates Time T.P. SS Bean .S ~Bea,n. Orifi. c__._~e COEFF SP.GR. Abs. Temp.. Press~. Flow Rate 1:45 P 510 1/4" 3/8" 1.25" 657.5 0.6 520° 2:00 P 510 " " " " " " 4:45 P 600 3/8" " " " " " 35.0 1830 mcf/d 11 42.5 2100 mcf/d Shut in tool at 5:40 PM for 2 hr FSI press. Pulled packer loose at 7:40 PM. Recovered 210' net rise. Ail gassy, watery drilling fluid. Tested 48.6 g/g equivalent NaC1. Pressure Data :. IH ISI IF FF FSI FH Top.inside 4724 ' 3301 921 1670 chart time expired Bottom inside 4709 3281 841 1146 3302 4626 Top outside 4628 3287 838 1205 3385 4620 Bottom outside 4736 3392 1067 1156 3310 4626 Ran in with 4½" open end drill pipe to plug. Plug #6 - Plugged 7250'-7100~ with 60 sks. construction cement. Cement in place at 1:15 AM. ~ April 11,...1961 Ran in, scraped casing 5330'-5450'. Pulled, jet perf'd 5 - ½" holes at 5490'. Ran HRC tool, stopped at 842'. Pulled out, worked over tool. Ran in, broke formation down with 3600 psi, 1500 psi on annulus. Formation took fluid at 4 bbl/min, 2400 psi. Pumped 20 bbls water ahead, 50 sks cement, 6 rain mix., .,. C OMPL!'T ION '~ PCET FALLS CREEK UNiT #1 Section 6~ T. 1 N.~ R. 1~2 W., Seward B & M Standard Oil Co, of Calif.~ W.O.I. - 'Z~erator Page 20 April 11~ 1961 cont'd. 115# slurry, followed by 2 bbl water and 54 bbl mud. Closed tool, ~rapped 10 bbls water in drill pioe. Squeezed 50 sks constr, cement thru holes @ 5490' followed by 4 bbls water to clear holes. Final press. $O0 psi. Pulled l0 stands, reset retainer at 5390'. Broke formation down with 1000 psi. Form- ation took fluid at 2 bbl/min, ~ ' 2~'~.O psm. Mixed additional 75 sks cement, 9 rain mix, ll6# slurry. Squeezed ~9 sks thru holes at 5490'. Cemented at 8:05 PM, in place 10:05 M~. Final press. 1900 psi. April..12, 1~61 Jet perf'd 5 - ½" holes at 5419'. Puil~d, set packer at 5340'. Broke form- ation down with 3800 psi, 1500 pgi on annulus. Formation took fluid at 3 bbl/min, 2100 psi. Pumped 20 bbls water ahead, trapped l0 bbl in drill pipe. Mixed 50 sks constr, cement, 5 rain mix, ll6# slurry. Squeezed 5..0 sks cement away follm~ed by 2 bbls water and 54 bbls mud, with 28 bbls mud thru holes @ 5340', 4 more bbls mud to close holes. Final press. 1300 psi. Cemented at 6:05 AM, in place 8:10 ~M. Pulled 6 stands, circulated, set pkr at 5346~. Packer failed. Pulled out, ran in DM retaher. Set packer ab 5340~. 1800 psi. Formation took fluid at 3½ bbl/min, 20 bbl total. Closed tool on l0 bbl water. Mixed and pumped 75 sacks constr, cement, 7 rain mix, ll6~ slurry, followed by 2 bbls water and 49 bbls mud. Squeezed away 65 sks cement with 29 bbls mud. l0 sks cement left inside drill pioe. Final press 12OO psi. Cemented at 5:40 PM in place 6:25 PM. Pulled out. Ran in with bit and 9-5/8" Baker scraper. Bit plugged. April 13, 1961 DO retainer at 5340'-5342'. Dropped to 5354'. Cement med. hard from 5354- 5490'. Used 3OOO~ .weight to drill. Circulated. Jet perf'd 2 - ½" holes/ft 5442-5470. HCT #3 HCT #3 - (5442-5470') Testor assembly as fol~lows: 2 outside BT recorders, 10' - 2-7/8" perf'dtailpipe, 'type C.hookwall ~kr~ VR safety Jt., hydrau~lfc ..Jaor~' 2 ~bnside ~ ~.ecer~ hydro- spring tester, and 96.~ of 6" drill collars in TC valve. Used no W.C. Ran on 5265' 4½" drill pipe. Set oacker at 5389' with tail to 5411'. Opened testor at 9:03 AM for 30 ~in ISI pressure. Opened tool to surface at 9:33 AM for 3 hr 47 min flow test. 1/4" bean open 2 hr 29 min. Light blow in- creasing to medium in 6 min. Gas to surface in 20 min. Representative Flow rates as follows: 3/8" surface bean 400 mcf/d 90 psi tubing press 1" surface bean 335 mcf/d -0- psi " " 3/8" bean open at 12:02 PM for 45 rain COMPLETION .REPORT FALIS CRE~X ~tIT ~1 Section 6~ T. 1 N~, R, 12 W,, Seward B ~ M 11 , i 11 ~ '' .... : : ~ Standard Oil Co. of Calif., W. O. I. - ¢~erator Page 21 April 13.~. 1961 cont'd Representative flow rate: 1" surface bean, 350 mcf/d, 15 psi tubing ore~s~ Heavy fluid spray to surface at 12:O3 PM. Normal drilling fluid~ Flame extinguished. Attempted to reduce fluid spray by reducing surface bem~ size~ Unable to keep flame lit~ No increase in blowA Shut in tool at 12:47 PM.foP 2 hr. FSi press~ Pulled packer loose. I~covered 1ilO' net rise. Top 360~ thick gassy drilling fluid, next 720' watery mud grading to muddy water Which blew out in stages. Bottom 30' above TC valve fine clayey sand~ Resistitivy of water sample: 4.7 ohm m2/meter at 53°F equivalent to 90 g/g NaC1. Pressure Data: IH ISI IF FF FSI FH t,~,' Top inside 31,14 2144 61,9 1215 2149 3256 Bottom inside Clock stopped Top outside 3477 2189 712 1242 2189 3261 Bottom outside 3453 --- 466 1160 2170 3257 P~ug #? - Plugged 5362-5440', with 30 sks cement, mixed to 117# slurry. 4~" dr-ill pipe hung at 5440'. 10 bbls water ahead, followed by 2 bbls water and 74 bbls drilling fluid. Cement in place 9:15 PM. Pulled to 5432, reversed circulation. Jet perf'd 5 ~" holes at 5326'. Ran in, scraped casing 5120-5300'. Ran in . 4~" drill pipe with packer set at 5266~. Formation broke do~en at 2000 psi taking water at 4 bbl/min. Pumped in ~ bbls water, followed by 50 sks cement, 5 m. in mix, ll7# slurry, followed by 2 bbl water, 53 bbl mud. Trapped l0 bbls water and 25 bbl mud in drill pipe. 40 sacks cement squeezed away, l0 sks left in casing. Working press. 12OOp. si, final press. 1700 psi. Cement in place 8:10 AM. Held 15 min. Opened bleeder pump, 38 sks cement flowed back into casing. Pulled, Jet ~erf'd 5 ~'" holes at 5275'. Set retainer at 5275'. Formation broke do~n witl~ 3200 psi, took fluid at 4 bbl/ rain with 2200 psi. Opened tool, p~nped in 20 bbl water, 60 sks cement, 2 bbl water, then 20 bbl mud. 50 sks squeezed away. Working press. 2000 psi. Final press. 2200 psi. In place 3:20 PM, held for 15 min. Opened'bleeder pump, cement flowed back. Pumped back 50 sks behind casing, lO sks left in casing~ COMPLETION REPORT FALLS CREEK UNIT #1 Section 6, .T. 1 .N.~ .~. 12 W.~ Seward B&~:i Standard Oil Co. of Calif., %.~.O.I. - C~erator Page 22 ~pril !5~. 196--1 Jet perf'd 2 - ~" holes/ft 5290-53!5.b'. Ran HOT #4. HOT, Testor assembly as fo!lows: Two outsid~"'~T, reSo~'d'ers, 10' -. 2~7/8" perforated t~il pipe, t.~pe C hook, ail~ pkr., VR safety joint, hydraulic j~'s, 2 inside BT recorders, hyd~ospring tester, and 88~ of 6" drill collars and TC valve. Used no W.C. Inadvertently set packer at 5346', 22~ of tail ~o 5372~. Opened testor at 6:10 AM fo2 8 rain ISI press. Lost fluid. Opened 1/4" bean for 16 min. Weak blow. Pulled up and reset packer at 5253~. Reopened tool to surface at' 6:47 AM for 4 hr 53 rain flow test. 1/4" bean open 1 hr 58 m~n. Ligh~ blow increasing to medium in 4 min. Gas to surface 18 min after reopening tool. Stabilized flow rate ~th 1/4" subsurface bean and 1" surface bean., 680 mcf/d with 100 psi tubing press. 3/8" bean opened 8:45 AM for 2 hr 55 rain flow period. Stabilized flow rate with 3/8" subsurface bean ~.nd $" surface bean, 680 mcf/d with 100 psi tubing press. Light fluid spray to surface at 8:55 AM increasing to heavy spray at 10:47 AM. Flame extinguished at 10:47 AM. Heavy fl~id spra~M continued until tool shut in at 11:40 AM for 2 ~r 4 min FSI press. Pulled. Recovered 500' net rise muddy water testing 1.9 ohm m~/m equivalent to 225 g/g NaC1. Pressure Data: IH ISI IF FF FSI FH Top inside 3313 -- 236 818 2168 3148 Bottom inside 3339 -- 241 803 2159 3171 Top outside 3285 -- 420 790 2186 3127 Bottom outside 3328 -- 437 799 2164 3124 P!._ug ~8 - Plugged 4097-4297'. Ran 4'½" drill pipe to 4297'. Mixed 77 sks Cement, 10 min mix, 117// slurry, squeezed away in 10 rain with 10 bbls water, then 2 bbl water and 56 bbl mud. Cement in place 5:30 PM. Jet perf'd 5 1/2" holes at 3927'. Ran in, scraped 3820-3940'. April 16,.. 1961 Set DM retaher at 3908'. Squeezed holes at 3927'. Formation broke down with 1800 psi, taking fluid at 4 bbl/min. Opened 9-5/8" X 13-3/8" annulus at surface, established circulation to surface. Pumped in 50 bbls water, 100 sks cement, mixed to 117# s lu~,ry, 2 bblw ater and. displaced with 43 bbl drilling fluid. Closed 9-5/8" X 13-3/8" annulus at surface and displaced with add- itional 9 bbl d~illing fluid. 'Displaced 45 sks cemen'o thru holes at 3927 ', while dirculating through annulus at 500 psi and displaced 45 sks through holes at COMPLETION REPORT FALLS CREEK UNIT Section 6. T. 1 N., R. 12 W Seward ..... ,~-T~anda'~'d' Oil C6. of Calif.,'l~: O.I. - t'p~'ator Page 23 3927~ with annulus closed at 12OO psi final press. Pulled out of retainer, backscuttled 3 sks cement.~ 7 rain mix, 15 rain displacing, cement in place at 7:50 AM. Jet perf'd 5 - :~" holes at 3884'. Set DM retainer at 3823'. Form- ation broke down with 2100 psi, taking fluid at 3 bbl/min. Pumped in 20 bbl water, 60 sks cement, 2 bbl water and 31 bbl drilling fluid. Closed tool, trapped l0 bbl water in tool. Pmmped in 24 bbl drilli~ fluid, placing lO bbl water and 50 sks cement through holes at 3884, leaving lO sks in casing 6 rain mix, 15 rain displacing, llT# slurry. Working press. 1200 psi, final press. 1900 psi. Cement in place at 340 Ri. Jet perf'd 2 - ~" holes/ft 3900-3911. (390o-3 n,) Testor assembly as follows: Two outside BT recorders, 10' '- 2-8%8" perforated ta.i! pipe, %ype "C" heo.kwa.ll. p~r.~ VR safety joint, hydraulic jars, 2 inside BT recorders, hydrospring tester, and 88' of 6" drill collars on TC valve. Used no W.C. Ran on 3747' 4~" drill pipe. Set packer at 3866', 22' of tail to 3888'. Opened testor at 3:15 AM for 34 rain ISI pressure. Ooened tool to surface at 3:49 AM for I hr 6 rain flow test. 1/4" bean open ~l min. No blow. 3/8" bean open 55 rain. No. blow. Picked up and reset tool 4:10-4:12 AM. Very faint blow declining to dead in 18 min. Picked up and reset tool 4:45-4:51 AM. No blow. Shut in tool at 4:55 AM for 30 rain FSI press. Pulled. Recovered 88~ net rise gassy drilling fluid below TC valve. Charts and tool overhaul indicated TC valve' plugged during test. Test no good. April 17, 1961 Ran HCT Testor assembly as f°ilows: Two outside BT recorders, lO' of 2-7/.~'~'~erforated. tail p~pe, t.~pe ,,C".h..ookwall packer~ 1 VR s~ety joint, hydraulic jars, 2 ins'~.de BT recorders, hydro- spring tester, anddual closed in valve. ~;sed no W.C. Set packer at 3866', 22' of tail to 3888'. Opened testor at ll:50 ;24 for 30 rain ISI pressure. Opened tool to surface at 12:~9 PM for I hr flow test. l~" bean open 37 mira.. Immediate medium blow declining to weak in 37 min. 3/8" bean open 23 min. Weak blow declining to dead in 10 min. Picked up and reset tool l:lO-l:12 PM. No blow. Shut in tool at I:20.PM. No Final shut in as tool plugged during test. Recovered 350~ net rise. Top 170' normal drilling fluid. Bottom 180' heavy thick cement cut mud. Pressu'~e data indicates tool and possibly 9-5/8" perforations plugged. Test inconclusive. Pressure Data: IH IS I IF FF FSI FH Top inside 2338 1684 686 1440 -- 2288 Bottom inside 2287 1666 650 1420 -- 2261 Top outside 2329 1701 695 1558 -- 2291 Bottom outside 2311 1695 708 1551 -- 2305 COMPLETION REPORT FALLS CRE~K UNIT ~1 Section .6~ .T. 1 N_~ ~ 1.2 ..W.~. Seward B~. ~t~ndard Oil Co. of CalifA, W.O.I~ - Operator Page 24 Apr. il ,!7, 1961 c0nt'd. Ran in, Conditioned mud. HOT #7' HcT #7 .(3900-3911 Jet re-perf'd 2 - -~-" holes/ft 3900-39.11~, ,,~ · ., ,. · Ran . Testor assembly as follows: .o ~ Two. outside' BT Yecorders,~,lO' .of.~-7/8" perforat~-tail pipe, type C hookwail pkr~ VR safety joint, hydraulic Jars, 2'.inside BT recorders, hydrosprmng ~es~er, and 88' of 6" drill collars. Used no ~.C. Ran on 3747' 4½" .drill Pipe~ Set packer at 3858', .22' of tail to 3880'. Opened tester at 11:37 PM. Opened tool at surface for 1~ hr 5 min flow test. Gas to surface 27 min after Opening tool. Measured pressure on 9-5/8" X 13-3 ~" annulus during flm¢ period. Initial pressure of 22 psi declined to slight vacuum in 20 rains, then dead. Shut in tool at surface for.1 hr. PUlled packer loose at 1:42 PM. Recovered . 2970' net rise. Top 2~.70'· gass~' slightly ~water.~drilling ~fluid grading to 900' muddy water. ·. ·" Pressure Da~ta: IH ISI IF FF FSI FH Top i~ide 2300 -- 336 1524 -- 2299 Be%tom inside 2240 -- 316 1504 -- 2240 Top outside 2335 -- 389 1555 -- 2335 Bottom outside 2296 -- 385 1510 -- 2295 Drilled out retainer at 3909!, cement 3912-3922'. Cond. mud. Jet perf'd 5 - ½" holes at 3922'. Set BM retainer at 3915'. Closed tool, broke formation down with 2200 psi. Took fluid at 3 bbl/min. Pumped in 20 bbl water, mixed 60 ~sk~ cement followed by 2 bbl water, displaced with 52 bbl mud, 2 bbl water. Left 8 sks inside pipe, 52 sks through holes at 3922 '. Cementing started at 4:20 PM. Mixed in 5 min, in place at 4:45 PM. Working press. 1100 psi, final press. 1900 psi. Ran in, scraped 3816-3890'. Apri.1 1..9, 1961 Jet perf'd 5 - ½" holes at 3886'. Set DM retainer at 3846'. Formation broke down with 1900 psi, took fluid at 3 bbl/min. Pumped in 20 bbl~ter. Closed tool on 10 bbl water. Mixed 100 sks cement in 9 min., followed by 2 bbl water and 22b~l mud. Closed tool. Unable to pump cement out. Backscuttled, pulled out. Stinger on tool bent. Drill~ d out retainer, c lesned out 3846- 3890'. Set retainer at 3846' with new tool. Formation broke down with 4200 COMPLETION REPORT FALLS CRE.~IK ~'~IT #1 Section 6~ T. 1 N~, R, 12 W., Sew~urd B & M $'6anda~d O~l co. of-cs!if., l~.o,'i. , operator Page 25 April 19, 1961 cont'dA psi with 2000 psi on annulus, took fluid at 3~- bbl/min. Pumped in 2 0 bbls water closed tool on l0 bbl~ Mixed 1OO sks cement, ll6# slurry, 8 rain mix, followed by 2 bbl water and 22 bbl mud. Squeezed holes with 39 bbl mud. Cleared holes with 6 bbl.lO0 sks cement squeezed away. Started cementing at 3:05 PM, in place at 3:30 PM~ h~orkin~ press. 2400 psi. Final press. 2400 psi. Pressure on annulus, llOOpsi. Backscuttled, set DM retainer at 3846 '. Broke formation down ~th 2400 psi. Took fluid at 3 ½ bbl/min. Pumped in 20 bbl water. Closed tool on l0 bbl. Mixed 100 sks cement in 8 rain, f oIhwed by 2 bbl water and 22 bbl mud. Closed tool, squeezed with 30 bbl mud. 85 sks cement through holes at 3886', 15 sks left inside casing. Started cement job at 4:45 PM~ in place 5:15 PM. Working !tess. 2000 psi. Final Pressure 2000 psi. Backscuttled. Drilled out retainer 3846-3848~. Drilled out med. hard cement 3848-3890, hard cement 3890-3915'. Jet reperf'd 2 - ~-" ho!es/ft 3900-3911~. Ran HCT #8. Testor assembly as follows: · TWo outside~,~BT r~cprders,".'lO? ?f 2r?~8" p~rf?A~e.d.~ta~i~ pipe,_t~e C.hookwall ~ .~ w~ sa~-e~v join~,, n~lrau~mc jars, '~ inside ~'~ recorcer~, hy~ospring aCK er ~ ' ~ ' . ~. · · ~ster, ~nd TC valve. Used no W.C. Rsn on 3837~ 4~' dr~ll p:=pe. Set p~ker at 3866', 22' of tail to 3888'. Opened testor at 8:48 ~ for 30 ISI p~ss~e. ~ened tool to surface at 9:18 ~ for 3 hr 8 ~n fl~ test. 1/4" bean (subsurface), light bl~ of ~r. ~ened 3/8" subsurface bean lO:21 ~. Light bl~ increasing to medimu b~ of air at 1.1 mcf/d rate. Turned to prover at ll:15 ~. Graduall7 decreasing to dead at 12:30 M~.. Shut in tool at 12:45 ~ for 2 hr 8 ~n FSI press. ~ll~ packer loose at 2:50 Recovered 988' net rise of gassy drlg~ mud. Very thick mud on top of ~ valve. Pressure Data: IH ISI IF FF FSI FH Top inside 2259 1563 120 604 712 2259 Bottom inside 2379 1541 112 588 696 2243 Top outside 2402 1569 121 1248 1550 2151 Bottom outside 2370 1551 120 1235 1521 2129 Charts indicate perf. tail was partially plugged during test. Spril. 2.1~ 1961 Ran HCT #9, 39OO'-3911 COMP!ETION REPORT FALLS CREEK UNIT #1 Section 6.,; T. 1 N,.~ R. 12 w.,.. Seward B & M Standard Oil Co, of Calif., W.O.I. - Operator Page 26 April 21, 1961 cont'd~ ~CT #9,, 3900' -3~91~1 ' ~.eS.tor assembly as follows: Type "C" hookwall pack~r, VR safety joint, hydraulic jars, 2 inside BT recorders, hydrospring tester. Used no W.C. Ran on 3837' of 4½" drill pipe. Set Lcacker at 3860, 4' of tail to 3864' Opened testor at 12:19 AM. No ISI. 5/8" subsurface choke. Opened tool to surface at ~ :19 AM for 2 hr 43 flow test. Medit~n blow of air would not ignite. Gradually decreasing to dead at 2:20 AM. P~lled packer loose at 3:02 AM. Recovered 470' net rise. Slightly gas cut mud.. Would not burn. Pressure Data: IH IBI Top Inside 2307 · Bottom inside 2342 IF FF FSI FH .. 231 285 285 2283 181 (?) 294 294 2272 Drilled out retainer at 3915'. Drilled out cement to 7384'. Hard cement 3918-3969, 4140-4360, 5380-5460. Gas cut mud circulated out at 5340'. Scraped 7500-7580'. Drilled out cement 7580-8~12', Drilled out hard cement 8312-8395'. Circulated, conditioned mud. Backscuttled. Jet perf~d 2 - ~" holes/ft 7562-7583' and 7585-7600'. Ran junk catcher and set Model "D" packer at 7,545~. Landed tubing on packer with no weight at 7545. Tub~g Det'ail Below K.B. 16.20' Tubing hanger .82' 1-2-7/8" pup jt. 2.00' 239 jts 2-7~8'" tubing (6.5#, N-80, 8R) 7520.98 Tbg measurement to packer Baker locator tbg seal below packer 2 jts 2-7/8" 'tubing tail 7541.8'O' 3.50 63.70' Baker locator tbg.seal above packer 1.80 Production tube 7641.00" Tbg measurement to packer 7541.80' ~.,,!ire line .measurement to top of packer = 7545'. OC~PLETI ON P3]P ORT FALLS CRE'fK UNIT #1 ___~.c_%_.i_on 6, T. 1 N., R. 12 W., Seward Standard .Oil Co. of Calif., W.O.I. '- Page 27 ~pri~l ~3., 196.1 cont'd. Rigged up and pumped in 50 bbl diesel oil. Removed BOPE. Installed ~mas tree. _April 2}~ 1961 Started flowing diesel oil at 1._o:02 PM. Gas to surface at 1:28 PM. Flowed well at varying rates to clean un. Some water to surface at higher flow rates. Stabilized flow rate from 2:10-2:25 PM at 1930 mcf/d, 32/64" bean, 430 psi tubing pressure. 2-3 slugs water surfaced during flow period. Shut in pressure 2750 psi. Wire line pressure surve, y indicated gas gradient to productive interval. _ '... ' . Rig released midnight, EXPLORATION DEPARTMENT ANCHORAGE DISTRICT E. $. PARKER DISTRICT SUPERINTENDENT P. O. BOX 7-8 3 9 · ANCHORAGE · ALASKA June 27, 1963 Mr. Thomas R. Marshall Petroleum Geologist State Division of Mines and ¥~nerals 329 Second Avenue Anchorage, ~Llaska Dear Mr. Marshall: Please refer to your letter of June 14, 1963 indicating that the State had not been furnished a set of d~samples on the Falls Creek No. i well. A set of di~samples was taken On this we~-the-~ate.~In view of the fact that the State had no facilities for storing such material, these samples have been retained in our Core storage facility and at our expense awaiting the State's notification that the samples were wanted. The Falls Creek samples are still in storage at our sample facility and may be obtained by .contacting Nr. A. B. Scouler in our Cordova Buildi~ offices. Very truly yours, Dear l~r, P~rker: In ,a le,£~er ~.rc~ ehia o,if£ce addressed ~'o ~..J.T. ~~r, dated N~~r 1.5, I~60., aec~p~y,.in~. sti.~lG,~n ~s ~de '~,ha~ ~s D~vis~o~ ~ ~i8~ a se~ o,f ditch s~ple.s o,f chis '~1. '~ daze , . Pl~ase ~ ,~h~.m ~ter ~' ~d'~a~e Very tt*ul.y yo.ur$~ TheWs R. Fmrshall., Jr'. Pet~l,emn Geolog~$~ PRODUCING DEPARTMENT TELEPHONE BR. 7--6201 C. V. CHATTERTON DtSTRICT SUPERtN'I'ENDENT P. O. BOX 7-839 · ANCHORAGE · ALASKA October 30, 1961 CONFm ENTIAL ~ Mre De D. Bruce State Department of Natural Resources 329 Second Avenue Anchorage, Alaska Dear Sir: Enclosed herewith is Completion Report for the well~ Falls Creek Unit ~1, for your information and files. encl. Yours very truly, P. O. BOX 7-839 · ANCHORAGE · ALASKA EXPLORATION DEPARTMENT ANCHORAGE DISTRICT E. S. PARKER DISTRICT SUPERINTENDENT December 4, 1961 'RECEIVED' OEC 14 ll~J. ~..~. Richard B. Murphy, Division Engineer State of Alaska, Division of [tines and ~nerals Oil and Gas Section 329 Second Avenue Anchorage, Alaska Petroleum Branch Division of Mines and Minerals Alaska Dept. of Natural Resource~ Dear Mr. ~&~rphy: Enclosed is a copy of the Report and Plan of Sub-Surface .Survey for the Standard Oil Company of California "Falls Creek" Unit No. i 'Well~ Clam Gulch, Alaska. Please hold information confidential. Yours very truly, ' E.S. PAR~GER ABS: ven e nc i. REPORT and PLAN of L RECEIVED DEC 14 196'1 Petroleum Branch Division of Mines and Minerals Alaska Dept, of Natural Resource~ SUB-SURFACE SURVEY STANDARD OIL OF CALIF. FALLS 'CREEK'UNIT Nt I CLAM GULCH, ALASKA JOB NO ....... DATE APRIL 1961 il RiI~i~I~II~ CONTR, tlI~ CtlI{PItRATIlIN 3327 LIME AVENUE LONG BEACH 7. 'CALIFORNIA II COMPANY . I WELL .... FA[J.S Ci~J~l(' [,1']~ N0 I FIELD ___CL~ ~ COUNTY .... STATE ......... A_.L'A_$ _KA ........... TRUE RECTANGULAR COORDINATES MEASURED DRIFT DEVIATION DRIFT VERTICAL REMARKS DEPTH ANGLE COURSE DIRECTION DEPTH NORTH SOUTH EAST WEST 1346 134(:, O0 a)l~. ;IDK {J~D VERTICAL TO ~ HIS Di~ [] 1~'1~: 1382 0° 30" 1382 O0 31 S 65° # 13 28 DECLINAI'IC.. 1412 0° 45" 1412 O0 39 S 70° # 26 65 OF 26° 1503 1° 45° 1502 96 2 78 S 55°# I 85 2 93 USED IN 1598 4' 30~ 1597 67 7 45 S 52° W 6 44 8 80 a)IIPUTING 1111S SUli!fk"T~ 1660 6o 45~ 1659 24 7 29 S 53° W 10 83 14 62 1690 7° 45° 1688 97 4 05 S 54° W 13 21 17 90 1752 9o 15° , 1750 16 9 97 S 54° # 19 07 25 97 1813 I1o 300 1809 94 12 16 S 55' W 26 04 35 93 1844 12° 15° 1840 23 6 '58 S 55° W 29 BI 41 32 1880 14° O0° 1875 16 8 71 S 61° W 34 03 48 94 1930 16' O0° 1923 22 13 78 S ~0° W 40 92 ~K) 87 2036 16o 45 o 2024 73 30 55 S 60° W 56 20 87 33 2159 16° 30° 2142 66 ' 34 93 S 61° # 73 13 117 88 2314 16° 15° 2291 46 43 37 S 62° W 93 49 ' 156 17 2468 15° 30° 2439 85 41 15 S 63° W 112 [7 192 83 2666 17° 30 o 2628 68 59 54 S 62° W 140 12 245 40 2760 18° 15o 2717 95 29 44 S 62° W 153 94 271 39 2810 16° 45~ 27651 83 14 41 S 71° W 158 $3 285 O1 2850 16° 30° 2804 18 II 36 S 77° W 161 19 296 08 3109 17° 00' 30511 86 75 73 S 88° W 163 83 371 76 3297 15° O0° 3233 45 48 65 WES! 163 B3 420 41 3539 14° 15o 3468 O0 59 58 S 89° W 164 B7 479 98 3692 13° 30' 3616 78 35 71 WEST 164 ~7 515 69 3~7 14° O0° 3805 99 47 17 N 89° W 164 ~4 562 85 · ['~ .i-.'-::~b :'-', -'.' ~-: ,:] :~-~ ~'~ .'-c~ .,'-~ ~- :~ COMPANY ~~OIL~~ ~F ~~A~ ~ ~ ~ L DATE JOB NO. SHEET NO.. WELL F~L.LS CBEI~_UNZT N° I FIELD COUNTY____ ~ STATE TRUE RECTANGULAR COORDINATES MEASURED DRIFT DEVIATION DRIFT VERTICAL ~ REMARKS DEPTH ANGLE COURSE DIRECTION DEPTH NORTH SOUTH EAST WEST 3999 14° 150 3914 54 27 57 N 69° # [ 163 56 590 41 4136 14° 300 4047 17 34 30 N 89° # 162 96 624 70 4294 15° 15' 4199 bi 41 55 N 89° · 162 23 666 24 4546 15° 45" 4442 16 68 39 N 87° # 158 65 734 53 4716 15° 45 o 4605 79 46 14 N 86° ti 155 43 780 56 4909 lb° 300 4790 84 54 81 N 85° # 150 65 855 16 5247 17° 00' 5114 07 98 83 N 86° # 143 75 933 75 5436 16° 450 5295 06 54 47 N 86° ti 139 95 988 09 5644 17° 150 5493 70 61 67 N 84° ti 133 50 1049 42 5944 17° 45o 5779 42 91 47 N 80° Ii 117 62 1139 50 6084 17° 45o 5912 76 42 69 N 80° ti 110 21 1181 59 6244 17° 300 6065 35 48 11 N 80° # 101 86 1228 97 6444 17° 300 6256 09 60 14 N 77° W 88 33 1287 57 6544 17° 450 6351 33 30 49 N 77° Ii 81 47 1317 128 6644 17° 15' 6446 83 29 65 N 73° # 72 80 1345 163 6894 16° 450 6686 23 72 05 N 77° # 56 59 1415 184 7034 16° 150 6820 63 39 17 R 770 Ii 47 78 1454 O1 7234 17° 000 7011 89 58 48 N 75° Ii 32 65 1510 50 7414 17° 450 7183 32 54 88 N 75° Ii 18 45 1563 51 7614 18° 150 7373 26 62 64 N 75° Ii 2 24 1624 O1 7814 _ 17o 150 7564 26 59 30 N 76° Ii 12 10 1681 55 8084 15° 000 7825 05 69 88 N 76° # 29 O0 1749 35 8344 13° 30~ 8077 87 60 60 N 74° Il 4.572 1607 68 -' 8724 13° O0° 6448 14 ~5 50 N 76° ti (:~40 1890 64 71 79 1915 99 ~55 13* 300 1~S& O0 25 91 N 78° ti COMPANY WELL STANDARD OIL COI~ANY OF C, ALIFOIINIA FAU,~ C~[. ~I~IT N° I F I E L D.___ CLA~ SHEET NO._ DATE APRIL 1961 JOB COUNTY__ [~d~]' STATE TRUE RECTANGULAR COORDINATES MEASURED DRIFT DEVIATION DRIFT VERTICAL REMARKS DEPTH ANGLE COURSE DIRECTION DEPTH NORTH SOUTH EAST WEST 9153 13~ 30~ 8665 30 74 22 N 75° W 91 00 1987 68 9357 14° 00~ 9063 24 49 35 N 76° t~ 102 94 2035 56 9484 14° 45~ 9186 O~ 32.33 N 73° # 112 39 2066 48 9620 15° O0 ~ 9317 41 35 20 N 70° W 124 43 2099 56 9734 15° 15° 9427 40 29 98 N 71° W 134 19 2127 91 9819 14° 45~' 9509 60 21 64 Pi 66° W 142 99 2147 68 9927 14° 15' 9614 27 26 ,59 N 68° # 152 95 2172 33 10t013 14° 15' 9697 62 21 17 g 680 # 16C 88 2191 96 10t200 13° 45* 9879 25 44 45 N 68° # 171 53 2233!17 10~324 15° 009 9999 02 32 09 g 69° ~ 1~ 03 2263:13 10~435 15° 00' 10,106 23 28 73 N 67° # 20g 25 2289 58 10t486 14° 30~ 10t155 61 12 77 N 67° I~ 205 24 2301 33 10,556 14° 30~ 10~223 38 17 53 N 65° # 212 65 2317 22 10~630 15° 15 9 10t294 77 19 146 N 62° · 221 79 2334 40 10~768 15° 009 10~428 06 35 71 N 65° ti 23~ 88 2366 76 ~_ 10~877 15° 00' 10~533 34 28 ~21 N 63° ti 24~ 69 2391 90 11~005 15° 45~ 10t656 54 34 '74 N 63° # 26~ 46 2422 85 11~098 15° O0* 10~746 37 24 07 N 62° # 27~ 76 2444 10 11~184 15° 009 10,829 44 22 26 N 64~ W 28~ 52 2464 11 11~287 14° 30* 10~929 15 25 79 N 64e g 29'/83 2487 29 11~420 16° 009 11~057 O0 36:65 N 61° # 315 60 2519 34 11,563 16° 30* 11~194 11 40 61 N 63° ti 334 04 2555 52 11~659 15° 30' 11~286 62 25 65 N 62° W 34~ 08 2578 IT 11t727 15° 45' 11~352 07 18 46 W 62" ti 354 75 2594 41' 11~,811 15° 00' 11t433 21 21 74 N 63° W 364 62 2613 84 COMPANY ~.~;~ ~--~-.--~ ,,:-~~ ~ |:~ ~-i ~:: :..:, ?. ~.~ . SHEET NO., 0IL ~~ 0F ~~~ DATE ~L 1961 ~os No._ WELL FAL~ ~ ~T H0 1 I='.IELD~ CL~ ~IILC~ COUNTY ~ STATE TRUE RECTANGULAR COORDINATES MEASURED DRIFT DEVIATIOI~ DRIFT DEPTH ANGLE VERTICAL COURSE---- DIRECTION - . REMARKS DEPTH NORq'H SOUTH EAST WEST 11,916 13° 45* 11,535 20 24 96 N 64° 1~ 37~ 56 2636 27 11,968 14° 00.' 11,585 66 12 58 N 62° W 381 47 2647 38 SPF~I~! SUN 12,106 13° 45* 11,719 70 32 80 N 600 ti 391 87 2675 78 SII~LE $1iOl 12,193 13° 30." 11~804 30 20 31 N 6T° W 405 81 2694 48 .... 12,450 11~ 00' 12,056 57 49 04 , N 80~ ti 414 32 2742 77 DlFl~"r~B . 12,520 12° 00-' 12,125 04 14 55 N 85° ti 41~ 59 2757 26 12~700 12° O0° 12,301 10 37 42 N 85~ ti 418 85 2794 54 12,850 13° 15' 12,447 11 34 38 N 85~ · 421 85 2828 79 12,940 12° 00' 12,535 14 . 18 71 N 85° # 422 48 2847 43 13,000 11° 150 12,593 99 11 71 N 80° # 425 51 2858 96 13~320 9° 00' 12,910 05 50 05' N 80° ti -43420 2908 25 PBOJECl'ED 13,420 7° 45* 15,009 14 13 49 N O0° W 436 54 2921 53 ASSUMING 13,520 6° 30' 15,108 50 11 32 N ~0° # 4~ 51 2932 !68 lo15°/100 13,620 5° 15' 13,208 08 9 15 N ~0° # 44C 10 2941 69 DIg)P Lq 13,720 4° 00' 13,307 84 6 98 N 80° # 441 31 2948 56 DRIFT 13,795 3° 00' 13,382 74 3 93 N 800 tl 441 99 2952 43 CLOSURE 2984, 88' N 81° 29 0 W (' P. O. Box 7-839, .Anchorage, Alaska September 28, 1961 REGISTERED MAIL State of Alaska Division of Nines and M~nerals Oil and Gas Section Attn: Mr. R. B. Nnrphy, Division Engineer Dear Sir: Enclosed is a sepia of the complete Core Laboratories Grapholog for the Standard Oil Company of California, Operator, well "Falls Creek" Unit No l, Sec- tion 6, T. 1 N., R. 12 ~.L, S.M., Kenai Peninsula, Alaska. Please hold the above log in a confidential status for the maximum prescribed period of time. Very. truly yours, ABS: ab encl E. S. Parker MEMOE.A ND UM i A ........... .t. FALLS C~K U~'~T NO. 1 OPEN FLOW POTENTiAL TEST INTRODUCTION It is the purpose of this memorandum to present the results of the Open Flow Potential Test performed on well Falls Creek Unit No. 1 from June 21 through 25, 1961. The test was performed in five parts: 1. Static Pressure Gradient Survey 2. Open Flow Potential Test 3. Forty-eight Hour Flow Test 4. Flowing Pressure Gradient Survey 5. Twenty-four Hour Pressure Build-up & Static Pressure Gradient Survey RESULTS 1. An Open Flow Potential was determined to be 2900 M~F/D. (See Attach- ment 4). 2. A stabilized flow rate of 1980 MOF/D was obtained during the forty- eight hour flow period following the Open Flow Potential Test. Considerable icing occurred during the forty-eight hour flow period. The icing was not confined to the flow line but was found in the tubing to a depth of 145'. After the well cleaned up, stabilized water production was indicated to be approximately 2.2 BBL. water per day at the 1980 MCF/D rate. Salinity of the water gradually increased throughout %he test, varying from 2~O G/G to 320 G/G. (See Attachment No.. 8 - Salinities. ) DE~IL Test equipment was moved in on June 21, 1961 to perform an Open Flow Potential 'Test of the interval 7562 - 7600'. The procedure followed during this test is outlined as follows: 1. Static Pressure Gradient Survey ;.~ ~ ,.,~ ., i : t .' 1' 7 ~ ~_z:..-. c _ : .: Prior to commencing the Open Flow Potential Test a static depth ressure survey was run. The information obtained was: Fluid level 260'±, Static Pressure at Mid-point of Perforations, 3404 psi, Tub- ing Pressure, ~.540 psi. (See Attachment No. 2 for Operator's report of survey). , FALLS ~REEX U~-/T NO. 1 OPEN FLO~ PO~NTIAL TEST 2. Open Flow Potential Test Five stabilized n-~tes were obtained from observed data; 2020 MCF/D ~ 1450 psia T~bing Pressure, 1655 MCF/D ~ 1885 psia, 1135 MCF/D $ 2285 psia, 1035 MSF/D @ 2325 psia, and 560 M~F/D ~ 2595 psia. (See Attachment No. 3 for Potential Test calculations and No. 5 for summary of observed field data. ) The Open Flow Potential was determined to be 2900 MOF/D. (See Attachment No. 4, Open Flow Potential. ) ~he well was opened up for a forty-eight hour flow period at approxi- mately 2000 MCF/D. During this time, the flow line and well head froze up intermittently and the well had to be shut-in five times for a total of sixteen hours to thaw the lines and X-mas tree. One stabilized flow rate was established over a nine hour period with the well producing at a 1980 NOF/D rate. The well head was thawed by the use of a steam boiler and alcohol injection equipment. (See Attachment No. 6 for Observed Data - Flow Period. ) 4. Flo~wing. press=~e Gradient ~he well was shut-in to install the depth pressure e~uipm~nt. On running in, ice was found at 13' to a depth of 145'. The ice was cleaned out by injecting alcohol and chipping the ice with a dewaxing tool attached to a wire line. (See Attachment No. 7A - Service Report. ) ~he depth pressure instrument was run in while the well was flowing to obtain a flowing gradient. (See Attachment No. 7B - Survey Report. ) Twenty,four Hour Pressure Build-up & Static Pressure Gradient.~.urve. y The well was shut-in with the instrument opposite the Mid-point of the perforations to obtain a twenty-four hour pressure build-up curve. (See Attachment No. 70 - ~urvey Report . ) After the t~nty-four hour build-up period, a static pressure gradient survey was obtained while the instrument was being pulled from the well. (See Attachment No. 7D - Survey Report. ) Upon completion of the pressure surveys at 7:30 PM, JUne 2~, 1961, the well was shut-in and the test equipment removed. R. G. WALL\ APPROVED: o/s W.E. WNI~¥ RGW: lo P. O. BOX 7-8 3 9 · ANCHORAGE · A LA'SKA EXPI. ORATION DEPARTMENT ANCHORAGE DISTRICT E. S. PARKER DISTRICT SUPERINTENDENT September 5, 1961 State of .Alaska Division of ~nes & Minerals Oil and Gas Section 329 Second Avenue Anchorage, Alaska Attn: Mr. Richard V. Murphy Gentlemen: Enclosed are two copies o£ the £ollowingreport for the Standard Oil Compan~ of Callfornia~ Operator~ Falls Creek Unit No. I well, Section 6, T. i N.~ R. 12 W., S.H.: 'rOpen Flow Potential Test". Very truly yours, E. S. Parker ........ ~~*' ABS: ab encls , . .. ELL OPEN TEST InitfaI :['e~t k~ ., lq :'dl$,_i C~t' ORT gpec;al il-leservotr · Fa:!s .7 r.-~.~k · t Standard Oil C,--~ma=.y of California I ('ount¥ } Lot'lttio~ K~aai Pen, ~ C2am 3ulch, Alaska X I~2 '~' - '~ i9 8n ;C~ 2-7/8" 6.~¢-~ ) 2-7/8", Pip, line Conne¢tlon 2" Pioe ~o Meter' Run Multiple Completion (Dual or Triple) Time of Flow Hours Falls 3ree. k U::it .761h ~ (Prover) (Line) Size 4~ Coeffl- { .... .' JIM Hr.) { &o.~4.~ 'l -- 60,367' '{ -. G,', ¢-Liq',dd -- . £ronl each zone Gas (Choke) (Orifice) Size 2.7~" _ 8__8_8 --~-. 7-~~ ....... .... ~ ............................... FLOW ('AL('UI,ATIO~S Pressure psis Casi nil; Press. lmig Oacker ~ack~r Packer , -- ,Wack~r I L!uuid 4 Apt ' Pw P (Imia) t Absolute Potential Z P~cker ; -- " IkSo 2285 ..... Cal. Rato of Flow Q MCF/D Compress. Factor F Flow Temp. Gravity I Fact or Factor -'1---6-;~ .... ----ff;-¢'~9 .......... I, 2'9! ......... 149; .......... i 1!;35 ........ P P -- i PRESSU TIE CALOULATIONS (F q), CERTIFICATE: It, me underst~, state mat I ~ th~k~;' ~q~ t~ 2ta~;dard ~. Cot of Californ~ a ~~mn [~.a~iSns, Inc. (~D~). ~d ~at I am a~or~ed by said par~ ~ my ~r~sion ~d direc~ and ~at ~.e fac~ sta~ the be~t a/ my knowledge. A2saka Oil ~md Gas Conservation Commission Gas Well Open Flow Potential Test Report (4-Point Test) Form No. AuthO~d by O~ No. ~ Attachment Ne. 1 S~TUS TOTAL I~PTE: 13, 800' CASING: 13 3/8" cem. 2468' 95/8" cem. 8600' PFAtFOPATIONS: 8395 - 8415' 7615' squeezed 7550' squeezed 7600 - 7562' 7600 - 7585', 7583 - 5~90' squeezed 5430' squeezed 5326' squeezed 5275' squeezed 5~9o - 5315' 3927' squeezed 3884' squeezed 3900- 39!1' perf. & re-perf.. 3922' squeezed 3886' squeezed 3900- ~911' perf again TOP PLUG: 8395' TUBING': ~ 7/8" E~E laaded in Model D retainer at 7542' with stingor to 761~'. PRODUCTION ~EST P~0GPAMS 1. Move in an.~. install portable gas trap ~ith gas flow meter ~un. Twenty four hour before starting production test program, notify Engineer- ing so that necessary contacts with Exploration, Participants, and governmental authorities may be made. Make wireline static gradient pressure survey. ~. Y~ke production flow test of interval 7600 - 7562'. Stabilize flow rate at approximately 1500 ~ 2000 mcf/d. (On initial flow test well stabilized at 1930 mcf/d with $35 psi tubiD~ pressure and 32./6~" bean. ) If spray of formation fluid develops and persists reduce flow rate. b~ Flow well at foregoing stabilized flow rate for approximately ~ hours. Flare gas during entire flow period. Obtain surface pressure and temperature data. - 2 - June 13, 1961 Reduce a~ stabilize flow rates at approximately 1500, 1000, and 500 mcf/d. Obtain surface flow, pressure and temperature data at each level of flow to establish open flow potential. d. Increase well flow rate to approximately 2000 mcf/d and flow for 48 hours. e.. Shut well in and run wireline static buildup pressure survey. Obtain ~8 hour buildup. Based on flow rate and pressure survey results further program will be furnished. Distribution: ESe - 3 SOW - 3 JJD PRO 562 Book Duty Engineer Prod~ction ~?~' c,'ah'sts COMPANY WELL NO. ... PURPOSE OF SERVICE' TOOLS USED' COMMENTS' Att.aci~:~ont ?,TOo ?A AGNEW AND SWEET ~,%':~E L.NE SER',iCE REPORT SE. RVICE'S DYNAMOMETE'R PRE SSdRE StJ RV E"~ S TF MPFRATt:R~ SURVFYS PIANO ~F L_~NF SERVICE ACCL. ST.CAL WELL SOUND)NG SERV'CE SPECIAL SERVICES FAIRV~EW '7 226.~ Of ~' FIELD ..0..~ll: ~r'll~.a .................................. Falls Creek __g-7/8" tub~n~ iced. __ Retake ice to p~it ru~t~ pressure b~b. i-I/A- O.D. B~iler, 1-1/2" ~re lt~ ~ols wi~ wtg~12 tool~ a~ ~est T~as ,araffin knife and alcohol. 7:00 AM to 8:00 Al:! crew moved equt~_m~_nt to allow ua to i _~et to well,._ Well flowing and [_ '~ell .lub~oated ~ ~ever~ g~lons alcohol lub~cated ~ [ i i In ~ tubing.__ 8~00 ~ start In hole ~ 1-1/4" ba!!er . ~u~ t0s fro~ 14 feet to 29 m additi.~l foetal, O~dered 2 d_r~a alo0hol. lltgi~d., uJ! wire line tools w/2" Texas scraper, spudded from 18' '~a¥~.2_' qu_l_t_e ha_rd' Alcohol arrived, lubricated in 2 gallonsj_ put on wir~ line wiggely tool, contt~v_ed apud~ing. ltard~l~lm ~2'__jlo ~7'.L.a!~p__roximatel.v 20 ~llons of alcohol used to aid removal. Put 0n__~"__We_~t_Texas _~araffin knife:_._.spudded 65 feet to 134 feet then tools ~ro~ped free, ice re_moved at 4:00 PM Pre_narej_q run preseure bomb for producing a~d 24 hour ~__jtatic BY__ ~[gJlew ,& Bruton/AI DATE June 24, 1961 Productio~ Spec~algsts Atta¢.~nt ~.To. ?~ A~NEW AND .~WE~' 3914 GILMORE AVENUE _~AKERSF'~ELD. CALIFORNIA SUBSURFACE PRESSURE SURVEY FA;Rv..~",v 7--~6T 2000 &000 T~.'.,.~a ~.~.'.~ 2--7/8"_~. ~mded in model "D" retainer ~th_.~.tt_..n~_ er ~ 7614'. GATE. ~Tum ~, 1961 ~EPTH 8~95' plug ZONE SHOE GAS ANCHOR ....... INT_AKE PURPOSE l~o~ol~,,z~. Pre._ssure Sur~m~ _. ;E-~A'RKs-I~r _o8_I~CS...n_~...~t.. a~r~. 20~ NCF/D, tubl~ p~eeg. ~~t~ fr~. ~680' 'a~' eta~iliZi~... .,c. u~ ~ ....... ~x,~u~ r~.~.~.~ ........ 1~._'~ ~ ...... ?~ ........ a~u~ 1800 PSI. ~ Prodact- PRESSURE ~0~ ~00 ~000 1000 1500 6000 . "' . . ~PP STABILIZATION PERIOD GROSS OIL.. RATE B./D 'NET OIL RATE B/D FORMATION GAS MCF/D GOR CFT/BBL. CIRCULATED GAS MCF/D ... Oil DRY GRAVITY °APl BEAN SIZE CASING PRESSURE ............... TUBING PRESSURE .. .... ~ 0 0 "2010 74~2 .. PRESSURE GRADI EN' 1802 - 2000 19~6 0.077 4,000 2043 0.053 6000 2128 0.042 7000 2174 0.04,6 7200 2188 O. 070 7342 2199 0.078 8000 , On bottom 5:48 .. ,. ..... ., . . .: .... .... . Agaew/AI P ,8 AND SWEE~ MOR£ AV;:'4t.E EAi",b ~,~SF'IEL['), CA[_.IFORNIA 5UBSURFACE PRESSURE SURVEY Falls_ Creek T',;,:..~O S~T.~',.-i'2~718" EUE ~mafl®fl tn model "D" retat~er ~754~' with. sti ..:~e.~ to 7614'. PU~P SHOE ~.u.~. p.o_s?.. Sra...ti.C__Pre slur ® Build-Up o zo .O- l0 3~00 al00' ~000' 2800: ff/O0'" .' 2600 ~00 2100 ........ :..:, .:,' .......... ,, j ........ '..j ...... FA~Rv.F',v 7-" .? 67 ~FLL ',4AME ?~g ~. 1 r_,A-~.JU~ ~ & 25, z_~RO .O,NT M~t + 15' o~P~. 8395' pl=g . .. ZONE INTAKE- ........ · _ STABll,:'AT,ON P~RIOO ~ h0.ur! .... GROSS OIL. RATE B/D ....... '1[' .... NET OIL "ATE. B,/D X FORMATION (;AS MCF/D ~ GOR CF'T/BBL. CIRCULATED GAS MCF./D OIL DRY GRAVITY '~API . .. BEAN SIZE ......................... c^s,N~ .RESS,~RE 1800 TUBING PR ~.S$ U R ~.. 2805 ~[mZr I ... PRESSURE 23,99 [/2 3256 1 3315 1-1/2 3~29 3 8 3~A4 12 3~47 16 33~1 :.. ,, ...: .... : ...... :-:.: ..... .~ "' . ' ' .... On bottom 6~00 PM 6-?,4. · . Of~' bOttOm 6:00 1~ 6-25. · . . ...... ...... ,. . . . , ., . . · , ., ,. ..... .'. ...... .' '_'i';'i'Y.-.",':.-'.':'7'l" .4 .... i ..... ~ ." · "' }":"' :'T :'": ...... SpedalLsts ~ ,.,.,tackw~.t No. 7D AGNEW AND SWEET, ,i 7~14 (.~,t MOrF AVE,NL;E ' E;AK ERSFIEL_D. CALIFORNIA SUBSURFACE PRESSURE SURVEY F A i RV, .'-'W ow:.,~tandard Oil Co_mloa..n2 Of California .~,~L~ Falls Creek LIN.~ :?-. DESCRIPTION DAr? JU~e ~ 1961 z~.Ro PO,N~. Mat + 15' 8~5' plu~ DEPTH ZONE ~..uf._~.! p s?or ............................. PuRPoSE St.a__t.i_c__P_r._.e~iurl .~urve~ REMARKS p,c~ u~ ~ __,^x,MuM T~ER^T~,E ...... ~__2.. ....... °f c~-:---'-?~' ....... INTAKE .. . ._ .... PRESSURE ~:)00 2.500 ,'7,F:~t0 4000 0 6000 :" · . , , 8OO0 . ' .... o ~000 s~-~ zn 'e:oo '~ e,-~-el ....... ............ .'.. STABILIZATION PERIOD 2~4 . ~.. GROSS OIL RATE' B./D Z NET OIL RATE B,/D FORMATION CAS MCF,/D i GOR CFT/BBL. Z ''' CIRCULATF. D GAS MCF,/D X ........... OIL DRY GRAVITY °APl BEAN SIZE . . . ' CAS,NG PR~-~S,.,RE 1800 · ' : "~ TU~,N~PR~SS~,RE 2805 Approx. ~luid .... Level 717B' D ~h ! V DEPTH PRESSURE GRADI ENl . 0 ' 0 2805 - "' ~o"' ~ooo ~9.~ o.oTz '~087 ' 4000 ~o9~ o. oe9 ~ ' ~ooo aze6 o. o6~ ~..~ v~oo ~ Piano line frozen solid in alcohol lubricated in to fIOO line, WI.I fr~sen high tn tubing, ~etermined b~t etretch. · Attach:~nt ~?Oo 8 FALLS CREEK ?~'~ ~ NO. 1 ~ ~.~ SALI?iITIES Sample No. 1 2 , 3 4 5 Time 6,45 PM (6-22-61) 6,00 PM (6-23-61) 9:00 PM 12:OO M 7:00 ~.M Resistivity Te:"..merature Salinity P.D. ~'{eter Ohms/M 2/M Degrees F. Grains/Gallon Bblso 1.435 55° 280 - - 1.48 55° 290 49643.9 1.68 55° 240 49644.3 1.47 55° 290 49644.5 1.32 %5° 320 49645.1 Volume Bbls. -- m . em, ,4 T TA O /q M £1V T iVo. zi FA~S C~E~,c Ll~wr tVo. l ~P£At /c'LOW ]:~OT£NTIA~_ TES~T I0 · ~, .::: u;:;::;::';: ::::::::::::::::::::::::::::::: :-h ':':"-; ';:::: :; ...... i ...... ::::::.: :: ~ ..... ; ''.;.; ;, :- :.;;;:.'-f:':::.":':.%'~:T---.'-:-~. :-~-~-'-'..-:F.' :' .; ",~-*':".'1 .... ~,,.'Trd-,, .............. ~ ............................. i .............~ ........... ,-..;',.'..~'*.-'.:, :''I ....................... ~'-" '.. '-'~i~iil -:-'.~: "!: ' ': ":! ':'!' 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':" · .... .. , .;:,:;~.; .... . .... . . . ........ ~ :,, -~:~,.. . : ...... ~ '~. 6 · - · ..... · · · . .:. } . I (~ ' ': '' ' '::. '' : ' ~ ~ ~ ......... . , , · ~ ,':'.I .... · !. ~ ...... Z ~ zl . .--.. -- ; . .; ~ ,~ ~.~' c-.H-t. · ' ' ''T ' ' ~ ~i' ~ :.-',:. i-hi.::-.,':;-~ ....... · .. ' ._ i ! '"I Ir.. ~ 'i'-' ' ..... 0 a. 4 ~r:';'~:':;:~: '.I':: ;:: :':::"!'i!'::.., ~ ~ ................. ' ' ' ...... ' :':':I 'i. '.i~:~..~..~.l,~!l~': '. i. . . · .1.;; · . .-.L.L ;- . · · · ,; .: , , -,. i; ,~ f ' '" * ' ' ' ," i · · ! ]...~i;,,. ,, ii 'I.; ~',: ::;'il 1 .1.1 ..... - ......... ~ "_.t;_L.. .......... 1 2 3 4 ~.i '7 iii 9 1 ,".] .?. 3 4 5 6 / :i ' ~'"~'--:) /ou /~oo /o, 0 0 o FALLS CREEK. ~!IT ~' .0. 1 OPEN FLOW POTEkWPIAL TEST FIELD DATA Attac~ent No. 5 Time 6-21-61 7:30 PM 7:45 PM 8:00 PM 8:15 PM 8:30 PM 8:45 9:00 PM 10:30 PM 10:45 PM 1i:00 PM 11:15 PM 6-22-61 12:30 AM 12:45 MM 1:00 M4 l: 15 AM 1:30 AM 1:45 AM 2:00 AM 2:15 AM 2:30 AM 3:15 AM 3:30 AM 3:45 AM 4:00 AM 4:15 AM 4:30 AM 4:45 AM Tbg. Press Psig Trap Press. Surface Psig Bean In. FIHST STABILIZED FLOW PJ~TE, -. 144o 14.35 1435 ~35 ~35 -- 93 93 88 88 88 88 88 SECOI~D ST~iLiZW~D RATE 1870 ~ . 90 1870 90 ..1870. 90 1875 90 TMiHD STABILiZED · '?J;~E , 228O ' 2285 -.2300 2310 2310- 9O 9o 9O 9O 90 FOUF~H STABILIZED RATE 229O 90 2275 90 227O · ~ 9O 227O. 90 FIF'MI STABILIZED RATE 20/64" I! II 20/64" t! 20/64. I! fl l! 2580 90 20/64. 2575 9o " 2580 90 " 2580 90 " 2580 90 " 2580 90 " 2580 90 l ' ' Meter Pressure ~ifferential Static IN~.H20 ~ Psia 5.50 :5°50 5.40 15.40 '5°40 15.40 5.40 4.40 4.40 4.40 4.38 6.35 6.35 6.40 6.40 6.40 6.4O 6.40 ' .... . . · '6.45 6.45 6°45 l 6.45 2.90 2.80 2.~ 2.70 2.80 6.42 6.40 6.42 6.40 6.40 3.00 3.00 3.~ 3.00 6.50 6.50 6.50 6°50 1.50 1.50 1.50 1.50 ~.5o 1,50 6e50 6,50 6.50 6,5o 6,50 6.~o 6o50 OrLfice hx 2.7~ f! 4x 2.75 4 x 2.75 4x 2°75 4 x 2.75 Orifice Coefficient 54o233 54.233 54.233 54.233 54.233 T emp er atur e Meter Run o Fo 71° 75° 72° 75° 80° Il Soecific Gravity 0..6 i! Il o.6 I! Il fl 0.6 i! l! o.6 fl fl fl I! l! Rate MCF/Day 1390 1390 1880 ].880 1880 1880 1880 151o i5io 15~o iSio 975 970 978 945 970 1260 1260 1260 1260 5~5 5~5 525 5~.5 525 525 TbgoPress. Trap Press° Surface TL,~e P$ig P~ig Bean Ino 6-23-61 5: 30 PM 1750 90 4 8/64" 6: OO PM 1800 90 " 7:00 PM 1800 90 " 8:00 PM 1800 ~O " 9: O0 PM 18OO 90 " 10: OO PM 18OO 90 " 11:00 PM 1775 90 " FALLS CREEK NO. 1 FORTY-EIGHT HOUR FIDW PERIOD FIE, ID DATA - STABILIZED RATE Meter Pressure Differential Static Orifice ~ ]]~.H20 ~ Psia In. 5.60 6.40 4 x 2.75 5.70 6.40 It 5.70 6.40 " 5.70 6.40 ti 5.70 6.40 " 5.60 6 °40 " 5.70 6.40 Orifice Coefficient Attachment No° 6 Temperature Meter Run SDecific o F. Gravity 54.233 57° 0.6 ti II I! . 58° ,, IT Il II It I! f! II 11 II Flow Rate ~CF/Day 1778 1980 1980 1980 ~78o 1940 1980 ,,' ABNEW. AND SWEE~' ,'¢ ~ N .."5~1~ OII..MORE AVENUE BAKERSFIELD. CAL.I~ORNIA SUBSURFACE PRESSURE SURVEY , c~.~___.~-?/8~_..to 86~' ?~,~, 276' O~*~ J~ne 21, 19~ LIN~.R DESCRIPTION ................ ZONE .. PU~4P SHOE GAS ANCHOR REMARKS ,.,~ ~ ~. .~x,~,~ ~-~,,~,~ ...................... ~ o~ ~__.'...."_~-:.-,.-"- .... INTAKE PRESSURE ooo ooo ~000 4000 6000 800O ,. D Depth I '~0 . ~lut~ Lev.i '6~0~ . 6176 · ,. .................... , ,., .. . , . . ...................... , ' '. ...J ....... .. . . . .. ..... . . . . ........... ..... . ... . . . ... . .. ,, . . .,. ............... . .~.'~ ..' . ..' , ......... , .... . .~ ...... ..... STABILIZATION P~.R,OD 21..days ........ ~ROSS o.~_ RAT~ ~/o x NET OIL RATE B/D .~ FORMATION GAS MCF/D ' GOR CFT/BBL. X CIRCULATED GAS MCF/D X ....... ~' Oil DRY GRAVITY °APl .EAN S,ZE . .: .. CASING PRESSURE rU~,N~ PRESSU.~. * ?..SA0''~'' · No V DEPTH PRESSURE GRAD! EN1 2.000 2680 0.07,?. 4000 28 04, 0.062 6000 2929 0.062 7000 5254 0.32,5 7200 ~:~44 0,400 7342 3404 0.423 On ~ottcn 10:27 All (2)' Tubt,z~ Pressure .(~s~h,) '~ lk35 1870 · :~70 2310 2580 1885 "- ~ · ~85 90 ' ~ 2595. · , . Con'ec~on: .. = .i . . ._ 9o 9o (b) Tear. 71 75 (5) Meter __ Static ,, 6.50 6.qo 6.50 FAM~ ~ UN/T NO. 1 OPEN FLOW GAS POg~NTIAL (6) 3:~. B~. ~r. .~ -' m 5.~,o '. 0.6 . . ~.~o '-" 0.6 . .. .3.00 '0.6 ~.8o 0.6 ~(~r ( 9 ) ____ (~'/])) . 60.307 171o 60.367 ~78 00. ~u53 1083 1.5o o.6 6o.o96 (~o) (sa.) (a_~,) Ps Pf~ ps2 +, b-'3 ._ _.. 1890 11,6B9,600 3,572,100 ~ ~ ~ " 5, ~ ~, 600 ~5 " 7, ~5, ~0 ~65 " 7,6~,2~ ~35 " 9,~,~ pf~ . ps2 (~z) - (~) 8,117,500 6,284,0~ ~, ~6%, 000 2, ~78, ZK)O (Feb. 1~1) (SUBM~ iN TRIPLICATE) UNITED STATES DEPArTMEnT OF ThE ~NTErIOR GEOLOGiCAL SURVEY Bt,Ak-et B~au No. AppwvaJ expi,.~ 12-31-~0. SUNDRY NOTICES AND REPORTS ON WELLS D ~ SUBSEQUENT REPORT OF WA'ffJ~ mUT-O,F~,__~_.]~a NOTICE 'OF IN~TiON TO RILL ........................... ~ .... SU~ENT REPORT OF S~TING OR ~IDIZIN~ ................ ~e~ENT aE~RT OF AL~ING ~S~ NOTICE OF INTENTION TO CHANGE PLANS ................... NOTICE OF INTENTION TO TEST WATER SHUT-OFF ........... , NOTICE OF INTENTION TO RE-DRILL OR REPAIR WL:'LL ......... SUBSEQUENT REPORT OF RE-DRILLING OR REPAIR ............... 1 ......[ NOTICE OF INTENTION TO SHOOT OR ACIDIZE ............. SUBSEQUENT REPORT OF ABANDONMENT ..................... I ......~ NOTICE OF INTENTION TO PULL OR ALTER CASING ........... ~ .... SUPPLEMENTARY WELL HISTORY .................................. l ....... ~ NOTICE OF INTENTION TO ABANDON ~ ],.0~'~ i / [ ao~cloa of well ......... '"'X / ...... ! (INDICATE ABOVE BY CHECK MARK NATURE OIr REPORT, NOTICE, OR OTHER DATA) Surface location of approxlmate!y,,~ /WellNo. ba:3U.~! .... isiocatcd/l'~OO.ft, from..~ ]ineand.~C~:~ .... ft. from l~} line of ~ .... ~ (~ ~. ~a ~. No.) (Twp.) (Range) (Meridian) W~ldeat Ke~l A~a A~s~ (Yl~ld) (County or Subdivl~u} (~ta~ ~ Tertiary) ~e eleva6on of the ~ a~ve s~ level is .... ~7~_~, ffL DETAILS OF WORK 1. Plug interval 13.,250 - 1.3,050' solidly wit& cement. Hole to be filled with heavy mud between plugged 2. Plug interval iP_~I.C~O - 1.i,850' solidly with cement. 'l%hese two plu~shou!d effectively Isolate the Ne~loc[ Zone from adjacent intervals. 3- Plt~ interval 10,i00 - 9~900' solidly wi. th cement. 4. Plug in~er-~al 8,700 - 8~500' solidly 'with ce~nt. These two plugs should effectively prevent fluid migration in above HemlocE. 5. Sele. ctively evaluate intervals behind 9 5/8" casing which is cemented at 8~ 6G0'. ...................... AgCE0gAGt~._ALA~KA ..................... UN!TED STATES DEPARTMENT OF THE iNTERIOR GEOLOGICAL SURVEY B~,dget }lur,,,gtl ,x,'b. 42-11350.5. Approval e~plre'~ 12.-3!-~. ~ND OFFICE ..................................... ~,~E NUMBER .................................. UNIT ............................................ LESSEE'S MONTHLY REPORI' OF OPERA. TION , State .................................. County_ ........................................ ?Yeld ................................................................... The [ollowit~,~ is a corr~.:c~ report of ope. rations and production (ir, c~din.~ driliir...~ and pvodz~ci'~g wells) for ~he .'1,o~l,t,I~ o/. .................................... /9 ....... , ....................................................................................... address .................................................................... Cor~epa~y .................................................................... ............................................................................................ Siffn, ed, ....................................................................... Pgor~e ..................................................................................................... ~cnt' s ti~le .................................................................... ] su~surf~e and 1" surf~:e' beans. ~stabili~ed flow ~ate at 680 ~f/d~ l~)t p~t, R. ecovere~ 500~I n.et rise ~f ~lddy ~ater, Tested 225 g/g NmC~. PLug ~8 ... h&97' 4 h297~ wit~ 77 sacl4s, Perf'd 5,-~' hol~s at )927' Squeezed wit~ '1]~ sack's~ Perf'd, 2-.'~'" hOles/ft, ]9~' - HCT #5 - 39OO' - 3 II I. Tool Plug, ed. Test inconc3nsive. HCT #6 .~ 39OO' - 3~].1'~ i Weak blow~ Recovered 350'i net ri.~e, rop 170~ drilling fl'uid,~ ne'~t 180~ h~a~y.thic, k cement ~'ight,,ed Too'. part. ia'il7 plu.~ed, Ae-pe~f'dF 2-~" hcles/ft, HCT fi7 - 39~~ - 3~11~, We~ blow~ Gas tc surfacej 27 ~i,n, after too~ ope',;l~d,, RecoVered j2970~' net ~ise, Top ~070~ ~a~sy, alightly wat~ d'iiling fl~id g~ading to 9~~ of m~,ddy ~ate~'~ Test indicated 9~ ~ac~ Perf do~5~ ~oles at 3 ~86 ~ S~eezed l~ sacks through hol~s. ~e-perf~d ~-~ ~oles/ft~ 3~~ - 35~11~. HCT~ ~8 - ~9OO~ - ~5'11~.~Wsak bl~ No gas to surface. Recovered HC~ ~9 - }900~ - 3~'lt',jWeak blow No ga4 to surf~ce~. Recovered [~70~ rise~, dri] fluid~ To 'ed. ' net lng ,1 parti~2Ly plug Drilled ou~ cemmt 71OO~ ~ 7~8h~. Cleane( o~t~ dqilled ou cement to 8~9~ let re~pert d 2-~" holes/f~ ~}~62~ j- 76OO~, ran M~el wire line ez~d, set at 79[~. j pa¢ler oi No'r~:.--Therc were ........................................................runs or sales of oH; .......................................................... M cu. ft. of gas sold; ....................................................................... runs or sa'les o£ gasoline during the mouth. (WrRe "no" where appHcai:)~c.) NOT~:.---Rel)ort on t;his form is required for each calendar month, regard]ess of the status of operations, a~)d must be filed in duplicate with thc supervisor by the 6th of the succeeding utoutb, unless othcrwi, s~) directed by 't,[;e ~:upervisor. (January UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42- 1{356.5, Approval expima LAND OFF~CE LE~E NUMBER ................................ UNIT .............................................. LESSEE'S MONTHLY REPORT OF OPERATIONS ,,State ...........................................................................Co'tzn. ty ~'ie~d ......................................................................... TY~e ,follo~in~ i~ a correo~ report of opcra~io~ and prod~ctio'~ (incl~di~ d~ill~ and prod~c~n~ weil~) flor the moz~$]~ of d~em, t:' s address ............................................................................................................ Sign, ed P~o~e d~er~t' s tig:le .............................................................. Installs[ tubing h~ad, Ran 2 ?/8~]tubing. Stabbed M~e! "D" pac~r ~d landed iubing ~i'bh 'tail.~to 7610~:. P'u~m~e~ in ~0 bbl. sur~c~., ~l~ed di~,s~l ~il~ gas to~ surface ~1 hr, 26 ~dn, Flied ~k varying .,'ates to clem u~. Stabilized fl,}~ for at ~930 ~cf/d, 32/~1.," b~an, h30 ps':. tubing ~press. >hut in pressu~, 27~D psi~ ~grel~ased ~dnight h A!akka 0 & O (C - g. D. Bruce.! Richfield Oil Corp,,I- Co Wo ObiI, Oil Co. ~ George So~.'d~l Unign Oil Co.~- C~ ~. Smith Fil~- Pr~uc~ng E~!orAtion La~ No~:.~There were .................................................... runs or sales o'f oil; ............................................................. M cu. ft. of gas sold; ............................................................. runs or sales of gasoline dur.[ng the month. (Write "no" where applicable.) NoT~..--(~eport on this form is required for each ca. lendar month, regardless of the status of operations, and must be filed in duplicate with the sttper¥i:~or ?)y the 6t;h of the succeeding month, uniess otherwise directed by the supervisor. UNITED STATES DEPARTMENT OF' THE iNTERIOR GEOLOGICAL SURVEY Budget Bureau No..12--]~356.5. Approval e::pirtxs !2-3!-80. LE$SEE;S MONTHLY REPORT CF OPERATIONS ~e /ollou;i7',g~ is a, correcL report, o/ opera;ion,s and prod~ct~o~ (ir~ci't&¢~n,~ drilJi~f a~d produ, e~n$ wells) for/:h.e mo~th of April 1~__, Fall~ Creek Unit ffl Wildcat d~ t' d ese P, 0 Box '-8'~9 ', -. ~ .. ' " ,~e~, s a dr ....................... ~ ............ ~.., _ ............................. Eom,pan& ~as~,_rn..~_t~.~-:.~a ............. . BRoadway 7-6,_01 ~, ~ ,b,~. H ~. ~.~0~ ~. ~e'k ~tt j 6 t~ i?W 8 5/8" hole 13,741' ~ 13,779' R~ Velocity ~ Rea~d 8 "~le 13~759~ - 13~7~9~,~ Ran Son~.c, ~cro ~ ~d Dipmeter~ Cor~ 13~779"~'$ 13,789~. Cored 1.3~89" SW~' Pl~.gged to a ~ando~ lower portion'of ~ole~ Pl~ g ~1 - ' O' '~'ith 85 ~a('.ks~ Plug ~2 - t1,~ -~12~l~~ With lbo $3 ~9~~ ~ 1.O~lOO ~th' 85 sac~s~ Plu~ ~ ~ 8h~4' ,~ 87(O~ ~.th .ac'k~,~ Ran Ne{~tron and Ga~a ~ogs, J~t perf'd 2,-~'" holes .~te~ at 20 - ~0 mc~d. Recovered h0' inet rise; slightly g~sy ~y d~illing flqid. Fested ~Jg/g Nat'S. Plug ~S - 8320' - saek~j, through ~"olesJ'~ Perf'~d. ~ ~-.};~ ~ol s/ft, 7~,~"~ ",- 7600', ~!CT ~2 7~o2' - 7600~, (~ened t. oolj9 hr, hl.J ~n~ a~p, f3.~ rate~ ~" mb-s~rf, bean.,JlS'~Ohcf/day'. ~/8' s'obqsnrf, beth 71.OO Rec ,vere~ 210' n.e~]rise.~ Gassy., wSter, ~].ing f~. Tested h8., g/g~NaC!. P14g ~6 p~iOO~ ]~' 7250' wit, h~60 sacks~ 'Perf~d. ~-2 ho'l~k at 9h!91. S~.eezed hol{s with ~l~ saek~ Drilled out j Recbvere~ 1110' neq riselo Top' 360~ thick ~,ssy drlk. m'uid, 7~oJ' wat,,r~ mud: ~es~edJgo g/g ~a¢l~ Pl'u~ ~7 - 5362' - 9h40', with 30 ~ack}}_ Perf d ~-} h~les at 53~6 . SqUeezed hOJsacks through hole~ petted >.{~ he,es ~t 5~7p' %ueeked 50 s~ek:s ~ay¢ Jet pert'd. No'r~,---There were ................................................ runs or sales of oil; ....................................................... M cu. fi. of gas sold; ......................................................... runs or sales of gasoline during the mon%l'l. (Write "no" where applicable.) No'r~.--.-Report GU this form is required for each calendar month, regardless of t;he stratus of operations, and must 'be filed in dupticabe with the supo.rvi;~or by the 0th of the succeed ng IllOl'ttl'l, unless; otherwise directed bv the supervisor. (~ntmry 1~) ,fC~ONTk~LY REP~A~. ~, OF Ot ERA I Ohi, > Oil o~l )n Ff.. :b ;s: Co, ,-.' C~ to~t±or. , )No~:~,?--.-There we.re ................................................ mas or ~a!es of oil; .......................................................... M ................................................................. ~t,ns )r 13~es oi g~aohm¢ dui.,ng the month. (Wm~8 no where No~,--ILepo~% on thi~ form is requir~ for each calendar moiith, reg~d]e~ of the status of operations, ~upli~ with the supe~Mor by the 5th of the suceeedk~g month, u~ess o~he~-i~ di~c'~d by ~:he supervisor. UNITED STATES DEPARTMENT OF TH~,_ INTERIOR GEOLOGICAL SURVFY ]iud,'-',et I ;u:'v;U! >.'., .I:: ApproYtd ~'Xl,iri's 1:2-31-t;',), LAND O FFI£'-' .... A 21~._O A.Q ?."'~,, -~ .......... ~,s~. ~,,,,~?.__ ADL 0059_0. .......... u,~-r .... .Pa, i.:Ls___ ¢ :re ek ................. LESSEE'S MONTHLY REPORT OF OPERATIONS 6 ~,e following' is a correct report of t:,p,'rali¢~,¢s a~td procluction (i~,.clu. dDt~ drillin~ an, d prodztcin~ wells) for the mon, tl~ o/ ..... ~b;~a~y ',9 ~_~ ........ ~.. Creek U~t ~l iiil~g~g .............. ~ S ' .0- C . T ~ ~ent's address .... ~ O. ~X T-8;~ ....... Co,,,pa,q/~~~ ~~~~ ......... ................................. ~~ge, A~ska .......... Si~ncd ........ i_,:.. ....... : ".'L ;.~ ............................... P~on, e ...................... ~9~_~5~X. T,~20~ ........................ ,i?c¢¢. t'.~ tit/,, ~sgrio~ S~ge.z~-ge~i.-A~ak~ ri'WP.IqANGE ~','~' [ ,> ' BAItKEI.S O~' OIL (]R.tVITY -" ' · ', ' ,' (1' tS(l] IN},' ~VAT[,']~ (It' (If drilli.a d~ ~th if ~ L <2 w ~ eau*e; }~ OF ~ *~ ~. z no~ut:,.;~ (III LII,>I.IS:IlI(IS) [ ~f ~ '>~ '. i~ n } .... ~ ,. ~ . ~ date ;.nd renu t >f te~t f,r g,soline I .... ' .... '', ~.,.~t}t~.n[ of Emi) .... i ................. i .................................. ~1 s Creek U~t ~3 Wfficat ' ~ ~ ' ~t 12W Dir$ctio~l~ drilled 12~" hole 81a4 - 8909'. Cemented 9 5/8~,,casing at_86~ ~th l~, isacks. D.O.C. Di~ctio~lly drilled 3 5/0 hole ~909 - 10~38~'. ~n ~S~ $o~c and ~dc.~o logs. Di~ctio~!~ trilled 8 5/8" hole 10,~67 11,184'. At ~illed ~pth ll~lS~' (V.D. 10~829.~') Coo~'~%es. 2~.5~ no~h, 2~64.1~' west ~ ...... cc U.S Riel Uni · --, >n 0il :.,o. - Co 'E, Sr0ith NorE.--q:'tmrc wore ............................................. run:< or s::l<:s of oil; ...................................................... M cu. fi,. of gs, s sold; ..................................................... nIns:¢r ~::h:,sof ~a, solil:i~ri~n'::br tho~nont, h. (Writo NOTn.--l{cl)or~ on this :orn~ :~ r(,qtiit'cd for c;N:]l (::~l(~i',~:' i~t<)::t,]t, ro,;:t'$,rdle::,,: of i,he Forth LESSF~'$ MON~~¥ REPORT OF OP~TIONS the saeeeedl~ moetl~, ealees ot, hel, wi~ ~ b~ t;~ aitpe~vtaor. UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget llur,,au Nh. 42 Approval expires 1'2- ~ omc~ .... Anc~o.~ge ....... UNIT _ _~.+ ~ ~.~ ........ LESSEE'S MONTHLY REPORT OF OPERATIONS The followi~g ix a correct: report of opcrutiou,s and production (i'nclz.~dD,~ drillin~ and prodz, cin~ wells) for the mon. tt~ of ~ce~e~' 19 ~_, - = '~ " .............. ~, Cx ~X .................. ,,. ....... .dgc~t'saddre,,'s ....... t). O. ~ox ~-03~ ............... Company .... .hccte:'n uoez~:zzouF,¢ _ 6 }iN lfiW ~'¢d.c.e&'~at k PM 1~/7/o0: Dri.~led _~.~ · · , ' /~ ' , · -~o.U, hole to 251' ~ened hole Ce~:~en.ted 20" ea~"Jng at 2~' with l~[}O sachs of cement. Zur:.tallcd 1.~'~- an~ tea;ted BOPE. D.O,C. D!r'ectio:p~l!y dx~iL!ed 12{-" hole 251 - S4~ ].81~', Set ~,~Ips'bopk //1. ~,t ].8].k,. ~. D~ :~cticr~].ly. drilled ~:.~o~l,, hole 3.~[31)4. - 2~8'. Rru~ T.,E,,~ ~ Sonic, ~.'~a:'o, an~. Diometer logso ~,ened ho[e~ Cemented :~] 3/8"~ casing at ,2>.[68~ with'1660 s~ekc~ ~r'eetloml!y d. ri.~.led 1~.:w ho._e ,2 r68 - 2 r6, , ,Se .m~p~tc ck. ~,. ~t, ~769 · Direction,ally drilled !=,, hole ,:-769 - 5h.~6 · ~,,uck p.~e at ~ >tte&~oi]. ~d. w~rked loose. Digeetionally cl.:ii, lc& 12~" hole 5[~ 16 - 6474'. At drilled Oepth ~M[' (V.D~. 6255.54') Coordinates: 83 '7T~ $o~t.h, ~88 71.~ west.' ' ' .,' ',:, ~ ,, Rl~hfie.ld Oil Co~ - C. g. ~.ez't~ M. L. till , W. Co Bishop I R.Z. sbeek E~!o mtlo~ NOTCh:.--There woro ................................................. runs or ~ales of oi!; ........................................................ M cu. ft. of gas ........................................................ ruu~ or ~m,]e, of ?ia~'<fllm~ dnrh~ the n'm~t]~. (Wrl~e "no" where No'r~:.---l~,(.l)~ rt on l. his form is re(tuire~t for (tacit ('a.]c:~dar month, ,~'""~ ~ t' ~ ' t',,.'~ duplicate with thc s~q)ervh-.or :,y tlm 6th of tl~o ,m(:c(;,~di~U.; m<,nt}~, unless othm'wiso (.~roc,..c,l ho su])m'vis~,r. (January 1950) APPLICATION FOR PERMIT TO DRILL, DEEPEN O,. _.dG BACK APPLICATION TO DRILL NAME OF COMPANY OR OPERATOR DEEPEN [] PLUG BACK [] DATE November 9, 1960 __~_0IL_C_0~AN~_0~RNIA,_Western 0perations~ Inc. Address City w. o. sox 7-839 Anchorage State DESCRIPTION OF %VELL AND LEASE Name of lease I lVell number Elevation (ground) Onshore: Earold A. Pederson Fee Lease -Gf~~Co.--ROCo_ADL 00590 Falls Creek ~1 Approx. 250' Well location ~' (g'ive footage from section lines) Section--township--range or block & survey Surface approx. 3~00' south and 2800' west from NE Corner Sec. 6, T. 1 N.~ R. ]2 W. ~Seward Field & reservoir (If wildcat, so state) County Wildcat Kenai Peninsula Distance, in miles, and direction from nearest town or post office 1 3/~ southwest along Sterling Highw~_x...from Clam Gulch~ Alaska Nearest distance from proposed location Distance from proposed location to nearest drilling'. to property or lease line: completed or applied--for well on the same lease: Approximately 550 ~eet .... feet Proposed depth: Rot6u-y or cable tools 11~ 465± ' Rotary Ai)prox. date work will star! November 20, 19(D Number of acres in lease: Onshore lease 108 acres Offshore lease 25660 acres (ADL 00590) Number of wells on lease, including this well, completed in or drilling to this reservoir: First Well If lease, purchased with one or more wells drilled, from whom purchased: Nam e Address Status of bond $10,000. Bond will be filed as required by State Conservation Regulations Remarks: (If this is an application to deepen or plug back, briefly describe work to be done, giving present producing- zone and expected new producing zone) * Bottom hole location: At estimated top of objective sand approxtm~.tely 3000' south and 300' east of northwest corner of Section 6, T. i N., R. 12 W. Hole must be directionally drilled from onsho~ surface location to test for possible hydrocarbon reservoirs which may underlie offshore lease SOCo-ROCo ADL 00590. STANDARD 0IL COMPANY OF CALIF. CERTIFICATE: I, the undersigned, state that I am theDist. Supt. of the Western Op_erations~ Inc. (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are true, correct and complete to the best of my knowledge, iOFi~lrla] s~gned Permit Number: Approval z~am.~ Approved By:_ ~'~'~ D. D, Br'acc, Petroleum Geologist Notice: Befor~.en~ng i~. tgia form be ~.e th~ you have given all inf~E~D~ ~-eqd'e~eo$ ~h~$ary correspond- ence W~I! thus,.be avoided, See Instruction on Reverse Side of Form J. 'r. Signature J.T. CR00KER Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form Ho. P-1 Authorized by Order No. 1 Effective October 1, 1958 (Feb. 1~51) (SUBMIT IN TRIPLICATE) UNITED STATES ~-eo,,[ DEPARTMENT OF THE INTERIOR GEOLOGICAL SUI~VEY Budge[ Bureau No. 42-R35&4. Approval expires 12~31-~. SUNDR'Y NOTICES AND REPORTS oN WELLS t-- NOTICE OF INTENTION TO DRILL ........................ i.~[,. SUBSEQUENT REPORT O~ WATF,,R ~'iUT-OFF_. NOTICE OF INTENTION TO CHANGE PLANS SUBSEQUENT REPORT Otr ~4OOTING OR ACIDIZING NOTICE OF INTENTION TO TEST WATER SHUT-OFF ........ i ..... SUBSEQUENT REPORT OF ALTERING CASING NOTICE OF INTENTION TO RE-DRILL OR REPAIR WELL ..... ! SUBSEQUENT REPORT OF I~I[-DRILLING OR REPAIR NOTICE OF INTENTION TO SHOOT OR ACIDIZE ............ i ........ SUBSEQUENT REPORT OF ABANDONMENT NOTICE OF INTENTION TO PULL OR ALTER CASING .......... [: ...... SUPPLEMENTARY WELL HISTORY _- ..................................... NOTICE OF INTENTION TO ABANDON WELL ........................ ~l ................................................................................ (iNDICATE ABOVE BY CHECK MARK NATURE OF REPORT, NOTICE. OR OTHER DATA) ............................. ..l!q._~e__r__? .......................... 19_~_ * ~ ~ar~ee ~oe~tion or ~~x~te~N~ _ } / Well No. _~..~l ..... is l~ated/3~, ft. from__ .[~ ~ line and __~__ ft. fr~ ~E/~ line of sec .............. __ ~._~c~__6 ~ ........... ~.__L.I. .... ~,._~....~,_. ' ..~~..~._~.~_ (~ ~. ~d ~c. No.) (Twp.) (Range) (Meridl~) (County or Subdivision) (~tsie ~ ~erri~ry) ~ devotion o~ the derric~ fl~r above sea level i~/. ~ ~5... ft. DETAILS OF WORK in[ ~lnts, and all other [m~rtaot ~ work). 1. ~ ~ 250' ~ ~~ ~" co~c~r pi~. 2. ~~ ~ ~at O~s III ~o~u~ P~~oa ~~. ~i~~ C~aa III ~o~t P~mti~ ~~mt ~ ~ctio~ ~ a. ~~ 9 5/8" p~tecti~ ~al~ a~ ~~~~ ~' If ~ces~. 6. ~ 2 7/8" ~u~ a~ ~le~ or a~m, ~ ~~~ ~ s~. * ~t~ ~ ~~om a~ est~d ~ of objective ~ a~ oa at~~ P~. Company .... S~__0~, C~ANY_OF.. CAI~,.FDRg~,_._I~s1~ex~_i~xl,.~IO~,...IGc_~ ................... A&tr~ ...... ~.__o ..................... 1960 tt~. J. T. C~oo.ker Standard Oil Co, o.f California, Oper. i~or P, O. Box ?=839 Anchorage, Alaska Dear ~. Crooker:. ~dd fluid of sutftcient veliht and proper' consistency to prevent blou~uts shell be used in drill'iq the yell and the: column o£ umd fluid shall be maiutaine~l to the .surface at all 'tiros, particularly while pulling the drill pipe. . Adequate bloat prevention equipment shell be provided and tested testy for use at all times, The character of the £1uid content of, each porous £ormation, shall be determined tu 8o. far es possible and, if o£ commorclsl value, shall be protected in a manner approved by this Division. Thio Division shall be nott£1ed as £ollows: (a) O[ any oil and gaa shoviu~s encountered. (b) Before runnius casin8 ocher chert surface casing in the hole. Ocher requirements may be outlined at that tinm~-. ~.J.T. Croober lfowaber 15, 1960 PoSe 2 Upon tim coupletiou or sbsndomm~ of said ~11, thL8 DLv~%~ shall quired, ~ dtroctiomLt surv~ ~nd .& collmcttou o~ dit~ ~lem ~ you. ~ m~y queer.tons plea~ do not he~Ltste to c811 on me. Yours ver~ Cruly, i / APPt~OXINAT£ ,,/ I ~ UBZU~FA CE ..' ,.. Ct~EEt~ ..; 4 i !/ 13