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Il!1age oject Well History File Cover e XHVZE This page identifies those items that were not scanned during the initial production ,scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 1 CQCi - Cf12 ~ Well History File1dentifier Organizing (done) ... RESCAN o Two-Sided 1111111111111111111 DIGITAL DA T A~ o Rescan Needed .1111111111111111111 . OVERSIZED (Scannable) o Color items: o Diskettes, No. o Maps: o Grayscale items: Poor Quality Originals: o Other, NofType o Other items scannable by large scanner o . , OVERSIZED (Non-Scannablèj o Other: o Logs of various kinds NOTES: BY: BEVERLY ROBIN VINCENT SHERYL MARIA ~;':DY . o Other \ -fJi) -()3 f . '"~ n DATE: Is/~" Project-Proofing 1111111111111111111 Scanning Preparation cJ x 30 = loO DATE: tJ~0.3SI + -B-- = TOTALPAGES I 6 BY: BEVERLY ROBIN VINCENT SHERY~WINDY BY: DATE: 1 ""Z.3 Ci3IS1 4JQ- Production Scanning Stage 1 PAGE COUNTFROM SCANNED FILE: -=:z5 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ß YES.. I ~ NO BY: BEVERLY ROBIN VINCENT SHERYl MARIA 8 DAT.L. -63 êY:g;il~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: _ YES _ NO BY: ~;ìROBIN VINCENT SHERYl MARIA WINDY DATE:)- 3-P3 151 ~ 1111111111111111111 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCAlE OR COLOR IMAGES) ReScan ned (individual page [specialattOlJtlon] scanning completed) 1111111111111 mil RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked (done) 1111111111111111 ~I 12/1 O/02Rev3NOTScanned. wpd Well Name Pre 2008 Survey Location NAD27 ASP 4 Northing Easting Post 2008 Survey Location NAD27 ASP4 Northing Easting Distance Moved NCI A-01 2,586,726.69 332,100.19 . 2,586,726.40 332,102.26 2.09 NCI A-02 2,586,722.85 332,108.29 2,586,721.16 --- 332,111.27 ____3.43 _ NCI A-03 _ 2,586,728.60 ___ _ 332,106.22 2,586,728.31 332,109.43 _ _ __ 3.22 _ NCI A-04 2,586,719.62 332,105.09 2,586,718.58 _ __ 332,108.09 3.18 ____ _ NCI A-05 ___ 2,586,725.55 332,110.17 ____ 2,586,725.14 332,111.79 1.67 NCI A-06 2,586,719.66 332,102.09 2,586,719.22 332,104.19 2.15 NCI A-07 2,586,727.79 332,103.73 2,586,728.78 332,105.40 1.94 NCI A-08 2,586,720.56 332,098.31 2,586,722.44 332,101.65 _ 3.83 NCI A-09 2,586,666.58 332,039.08 2,586,667.35 332,040.44 1.56 NCI A-10 2,586,670.21 332,040.91 ; 2,586,673.71 332,044.17 _ _ 4.78 ~ _ NCI A-10A 2,586,670.21 332,040.91 _ 2,586,673.71 332,044.17 4.78 NCI A-11 2,586,670.23 332,039.14 2,586,677.01 332,041.75 __ __ 7.27 NCI A-12 2,586,722.73 331,947.80 2,586,723.59 _ _ 331,994.15 _ 46.36 NCI A-13 2,586,734.88 331,993.50 __ 2,586,733.15 331,995.48 2.63 NCI B-01 2,586,730.03 331,999.80 2,586,723.04 331,998.16 . 7.18 NCI B-01A 2,586,730.03 331,999.80 2,586,723.04 331,998.16 7.18 NCI B-02 2,586,731.14 331,999.29 2,586,729.60 332,001.86 3.00 NCI B-03 2,586,731.69 331,986.37 2,586,726.81 331,991.70 7.23 NCI B-03PB1 2,586,731.69 331,986.37 2,586,726.81 331,991.70 7.23 ~~ ~1~ APR 4 4 2008 /~~ -6~5~ REV DATE BY CK APP ESCRIPTION REV DATE BY C P DESCRIPTION I 2/29/08 SAS K WA MODIFY WELL HOUSE SCHEMA TIC, SH T.2 ADD MUD LINE ELEV., SHT.3 g ~ ~ 36 31 T 12 1~l 31 32 ~{, 1~s ~~ 1 6 ~ T ll N 6 5 N ,., Ro s. isvs• SEC. b 1206' SCALE: 1"_1320' ---6- ~ ~ o ~ ~ 1 6 6 5 12 7 7 8 GENERAL NOTES: ~~~~ ~F ~ ~\~, I. SEE SHEET 3 FOR COORDINATE TABLE i '~P'' ~~ ~~''%9S/~-~1~ ~~•. 1 .. ~ 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND ':,9 ~j ~ ~ '~ ~ ~ ' ~ VERTICAL SURVEY DATA 49th ~ : • ~j 3. SECTION LINES AND TIES ARE BASED ON PROTRACTED ~ ""'`"""""""""""""""""'"""' j ~ VALUES. ~• ~, '; KENNETH W. AYERS ~~ moo: • ~ ~ ~s 8535 •1 ~ SURVEYOR'S CERTIFICATE •••~o - „ ~ ~~FOp~. ~ I HEREBY CERTIFY THAT 1 AM PROPERLY REGISTERED AND ~~~~ii~ ~=~~.•~~ LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY ME OR UNDER MY DIRECT SUPERVISION AND THAT AL DONE BY L LOUNSBURY DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF & ASSOCIATES, INC. FEBRUARY 28, 2008. SURVEYORS ENGINEERS PLANNERS ~ PHONE: (9071 272-5451 AREA: MODULE: UNIT: Conoco hilli S NORTH COOK INLET TYONEK PLATFORM Alaska, Inc. W ELL CONDUCTOR AS BUILT CADD FILE N0. 08-005 AS BUILT 02/27/08 DRAWING N0: 08-005 AS BUILT PART: 1 of 3 REV: 1 REV DATE BY CK APP DESCRIPTION REV DATE BY C PP DESCRIPTION I 2/29/08 SAS KWA MODIFY WELL HOUSE SCHEMATIC, SHT.2 ADD MUD LINE ELEV., SHT.3 v T ~` ¢ ~~ ~ ~ .f~$ AA 99 TtlN R! ~~ s. ~s'u' sc e `SiS ~~ ~~ O ~~ ~~ SCALE: 1"=30' a9 kp. O ESD 600 50 - ESD 600-51 •10 IQ •B2 3 A8 A•A• : •O5 B A6. A3. A12 BI 5 • • • A4 AZ WELL HOUSE 2 O~ • Zp A:o LEGEND: O ' AB • WELL ~ WELL CONDUCTOR 0 ESD (EMERGENCY SHUT OFF VAL VEl GENERAL NOTES: 1. SEE SHEET 3 FOR COORDINATE TABLE 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND VERTICAL SURVEY DATA LOUNSBURY 3. NO WELLS EXIST IN WELL HOUSE NO. 4 , AND IT WAS NOT & nssoc>aTES, INC. A S B UIL T SURVEYORS ENGINEERS PLANNERS 907 272 P E 545 1 HON - 1 : ( AREA: MODULE: UNIT: ConocoPhilli s NORTH COOK INLET p TYONEK PLATFORM Alaska, Inc. WEEL CONDUCTOR AS BUILT CADD FILE N0. DRAWING N0: PART: REV: 08-005 AS BUILT 02/27/08 08 -005 AS BUILT 2 of 3 1 1 12/29/OBI SAS I KWA I I MODIFY WELL HOUSE SCHEMATIC, SHT.2 ADD MUD LINE ELEV., SHT.3 ASP ZONE 4, NAD83, FEET NAD63 GEOGRAPHIC MLLW DESCRIPTION (POINT NO.) NORTHING FASTING LATITUDE LONGITUDE ELEVATION NqU WELL TAG NO. WELL HOUSE NO. 1 1001 2586492 1472018 61 04 34.38 150 57 03.71 72.0 Conductor 1 1002 2586489 1472017 61 04 34.34 150 57 03.72 73.9 B3 1003 2586485 1472019 61 04 34.31 150 57 03.67 74.1 A12 1004 2586485 1472023 61 04 34.31 150 57 03.59 73.8 B1 1005 2586487 1472027 61 04 34.33 150 57 03.52 72.0 Conductor 5 1006 2586491 1472027 61 04 34.37 150 57 03.52 73.7 B2 1007 2586495 1472025 61 04 34.41 150 57 03.57 72.1 Conductor 7 1008 2586495 1472021 61 04 34.41 150 57 03.65 73.7 A13 WELL HOUSE N0.2 2001 2586437 1472060 61 04 33.84 150 57 02.83 71.9 Conductor 1 2002 2586433 1472059 61 04 03.38 150 57 02.84 71.9 Conductor 2 2003 2586430 1472062 61 04 33.77 150 57 02.79 71.8 Conductor 3 2004 2586429 1472066 61 04 33.77 150 57 02.71 73.4 A9 2005 2586431 1472069 61 04 33.79 150 57 02.65 71.9 Conductor 5 2006 2586435 1472069 61 04 33.83 150 57 02.64 73.3 A10 2007 2586439 1472067 61 04 33.86 150 57 02.69 73.3 A11 2008 2586439 1472063 61 04 33.87 150 57 02.77 71.9 Conductor 8 WELL HOUSE N0.3 3001 2586488 1472128 61 04 34.36 150 57 01.47 73.0 Al 3002 2586484 1472127 61 04 34.32 150 57 01.48 73.1 A8 3003 2586481 1472130 61 04 34.29 150 57 01.43 73.1 A6 3004 2586480 1472133 61 04 34.28 150 57 01.35 73.0 A4 3005 2586483 1472137 61 04 34.31 150 57 01.29 73.0 A2 3006 2586487 1472137 61 04 34.34 150 57 01.28 73.0 A5 3007 2586490 1472135 61 04 34.38 150 57 01.33 73.0 A3 3008 2586490 1472131 61 04 34.38 150 57 01.41 73.3 A7 50 2586540 1472069 61 04 34.86 150 57 02.69 72.7 ESD Valve 600-50 51 2586501 1472011 61 04 34.46 150 57 03.86 72.6 ESD Valve 600-51 100 2586572 1472123 61 04 35.18 150 57 01.58 115.3 Top center helipad -101' MUD LINE SURVEY NOTES: 1. ALL COORDINATES ARE ASP ZONE 4, NAD83, US SURVEY FEET. GEOGRAPHIC COORDINATES ARE NAD83. 2. ELEVATIONS ARE IN FEET, BASED ON MLLW, REFERENCED TO DRAWING NO. MPD- TY04-2021, SHEET I OF 1, REV. 2 3. ALL AS BUILTS ARE TO THE CENTER OF EXISTING STRUCTURE. 4. WELL CONDUCTOR ARE VERTICALLY AS BUILT TO THE TOP OF A 1/4" STEEL LID, TACK WELDED TO THE TOP OF THE CONDUCTOR. 5. WELLS ARE VERTICALLY AS BUILT TO THE TOP OF THE LOUNSBURY LOWEST HORIZONTAL FLANGE ON THE WELL. & ASSOCIATES, Irrc. ConocoPhilli s p Alaska, Inc. CADD FILE N0. DRAWING N0: 08-005 AS BUILT 02/27/08 AREA: SURVEYORS ENGINEERS PLANNERS ~ ~ PHONE: (907j 272-5451 MODULE: UNIT: NORTH COOK INLET TYONEK PLATFORM WELL CONDUCTOR AS BUILT 08-005 AS BUILT PART: 3 of 3 REV: 1 ( ( Paul Mazzolini Exploration/Cook Inlet Drilling T earn Leader Drilling & Wells Conoc~hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4603 August 12, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 ^ I!~ "\1 ': ,HIJ.J .:". ..;, 2083 Subject: Well Completion Report for NCI A-10 (APD # 69-88/302-237/303-129) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the North Cook Inlet well A-1 O. This report is for the recent plug and abandonment procedures on this well. If you have any questions regarding this matter, please contact me at 263-4603. Sincerely, ?~ fY/~ P. Mazzolini Exploration/Cook Inlet Drilling Team Leader CPAI Drilling PM/skad AUG 1 3 2003 SCANNED AUG 2 1 2003 ( (" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil D Gas D Plugged D Abandoned ~ Suspended D WAGD 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory D GINJ D WINJ D WDSPL D No. of Completions _ Other - Service D Stratigraphic Test D 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. J 69-88 1 302-237 I 303-129 or Aband.: July 29, 2003 3. Address: 6. Date Spudded: 13. API Number. P. O. Box 100360, Anchorage, AK 99510-0360 August 22, 1969 50-883-20030-00 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number. Surface: 1304' FNL, 1023' FWL, Sec. 6, T11 N, R9W, SM September 27, 1969 NCIU A-10 At Top Productive 8. KB Elevation (ft): 15. Field/Pool(s): Horizon: 812' FSL, 2425' FWL, Sec. 31, T12N, R9W, SM RKB 116' North Cook Inlet Field Total Depth: 9. Plug Back Depth (MD + TVD): Beluga Pool 2505' FSL, 4115' FWL, Sec. 31, T12N, R9W, SM 1941' MD 11866' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 332040.92 y- 2586670.21 Zone-4 8250' MD 1 6240' ADL 17589 TPI: x- y- Zone-4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- y- Zone-4 N/A ALK 2916 18. Directional Survey: Yes D NoL::J 19. Water Depth, if Offshore: 20. Thickness of 130' feet MSL Permafrost: N/A 21. Logs Run: N/A 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Surface 366' Driven 16" 65# H-40 Surface 631' 22" 610 sx Class G 10-3/4" 40.5 1 45# J-55 Surface 2782' 15" 737 sx Class G 7" 23# / 26# J-55 1950' 8228' 9-5/8" 1210 sx Class G cement plug @ 4771' 10-3/4" bridge plug @ 1900' 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; jf none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 2250' - 6550' 4833',5243',5571', 5636', 5737', 5846' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. perfs abandoned, 4890' - 7765' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Plugged and Abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF W A TER-BBL CHOKE SIZE GAS-OIL RATIO Test Period n> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF W A TER-BBL OIL GRAVITY - API (corr) press. psi 24-Hour Rate -> 27. CORE DATA Brief ~escriPtio~ of ~ithOI09y, por~,sity, f~actures, apparent dips and pr~ of oil, gas or water (attach separate sheet, if necessary). Submit core chips; If none, state none. ~ ~\¡'-<f:. A6~./- \ \ ø. a..-. !-_._.._~,!L nt~ ..,.J<I, ~ ~..- 01 .f1J¡(PLET:QN~ o::ft.9.¿ið ~ DA TE ~ ~ E \ --Z~?li~ RBDMS 8Fl NJ614 2m ~ 'l\f\ Çc .0"7 I ~D I AUG 11, /003 It 'þCf I;p I :J -""",-....-..--.- ....-.......... ,,.,·...,'"·,,·,·.".~.:.,\i:'r·~ I, ~j (IT' ~~~ '1,1 ~,~Il, \11 II; 'I f";¡ I," ~\ ,,' ,I, \~ :.,1, I.. . . Fo~~1!4tw Rl!vlse~I~~~~~~ANNEb AUG 2 1 20;NTINUED ON REVERSE ðER I GIN A I "!'IIÞ Submit In duplicate .:r~,\!:i r 28. (" 29. nil '- GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NIA NIA 30. LIST OF ATTACHMENTS Summary of Daily Operations, Abandonment Schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Billingsley @ 265-6531 ::~::~ "1~ Title: Phone Cook Inlet Drillina Team Leader Date C>ßlll..!tJ:!J Prepared by Tim Billingsley INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1 a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 .( !¡( North Cook Inlet Unit No. A-I0 Daily Summary 6/22/03 Accept rig at 12:00 on 6/22/03. ND tree, set blanking plug and NU BOPE. Pressure test BOPE to 250 psi/3000 psi. 6/23/03 RllI w/APRS wireline to 2250', cut 4 1/2" tbg @ 2250'. Pull hanger, circ to 8.4 ppg water. Pull and lay down 2250' of 4 1/2" tbg. PU 3 1/2" drill pipe. 6/24/03 MU Baker 7" CIBP on drill pipe, RllI, set CIBP @ 2245'- 2247'. POOH wi running tool, change top pipe rams to 7", test bridge plug to 1500 psi fl 10 min. Nipple down of BOP stack to remove FMC 4 1/2" tubing spool. 6/25/03 PU stack, weld slips to casing, remove 4 1/2" tbg spool. Set BOP's on 7" casing spool, test to 1500 psi, install bell nipple. RllI with 7" casing cutter on drill pipe. Wait to cut casing until LEL gas detector calibrated. 6/26/03 PU 4 1/2" DP, stand back in derrick. Calibrate LEL gas detector at shaker. Cut 7" casing @ 2100', attempt to eirc, no circ at 800 psi. POOH, LD cutter. MU 7" Spear assembly, attempt to pull casing. 6/27/03 Pulling on 7" casing (cut @ 2100'), no success, release spear. MUI RIH wi cutter, cut 7" @ 800', POOH. MU/BHA, RIH engage casing wi spear, Pull up to 270k, slight movement, Release, LID spear. PU cutter, RIH to cut @ 310'. 6/28/03 Cut 7" casing @ 310', POOH LID cutter. MU spear assembly, RIH, engage fish, pull to 95K to free, eirc. Pull hanger to floor, RU & lay down 310' of 7" casing. Test BOPE, upper & lower IBOP leaking. Wait for mop parts. 6/29103 Set wear bushing, PU 6 1/2" drill collars, RU epoch mud logging equipment on rig floor, Spot BJ injection pump in dry sack area, Parts arrived, installl top drive IBOP and test to 240 and 3000 psi (OK). 6/30103 RllI with spear on 3-1/2" drill pipe. Spear into 7" casing @ 310', jar on fish, jars quit, working wi torque to free fish. Service rig, unable to release fl fish, slip and cut drilling line. 7/1/03 RU APRS, fire 360 gram/ft string shot at 306.5' to 310', release grapple. POOH, LID fishing assembly, change over top drive saver sub to 4 1/2" XH, PU spear wi jars, RIH with spear on 4-1/2" drill pipe and engage fish. Jar on fish, jars quit, release spear with no problem, POOH. Change jars, RIH wi jars, engage fish. 7/2/03 Grapple slipped on spear, could not re-engage, POOH. MU spear assembly with added extension, RIH spear fish, jar on fish @ 301 " good jar action but could not move fish. Release spear, POOH, LID spear. MU casing cutter ( ( assembly, cut 7" @ 465', POOH. MU spear, Rill, engage fish @ 301', pull 80k, pull fish free. 7/3/03 POOH wi spear & fish, LID 164' csg (301'-465'). Rill cut @ 635', POOH, MU spear, circ prior to engage fish, jar and pull free, recovered 170' of fish (465'-635'). Rill with spear, tag fill at 617' (18' above top of sih at 635'). Wash down 18' with spear from 617' to top of fish at 635'. (Circ out large chunks of dried mud material, dice sized) 7/4/03 Engage fish, jarring on fish for 17.5 hrs with only 2.5' of progress, release fl fish with difficulty (needed top drive max torque plus rotary table), circulate across shakers to super sack. 7/5/03 Circ, break TD conn, derrick inspection -post jarring, POOH LID spear. PU & MU cutter assembly, RIH to TOP at 635', could not get inside--fill, POOH LID cutter. RIH 6" mill BHA fl cleanout, tag & wash 632' to 850', RIH tag 1926'. 7/6/03 Work on standpipe leak, wash fl 2034' to 2098', weld threads on union wi circ slow wi head pin, con't washing to 2230', POOH to 1528', change 55, MU 9 3/4" stab, Rill 4 1/2" DP to 1596, ream to 2160', sweep, POOH, RIH cut @ 712', POOH f/spear. 7/7/03 Rill with 7" spear, engage fish @ 632', Pull free, POOH, LID fish. MU spear, Rill wash 650' to top of fish @ 712', engage fish, jar on fish, moved about 1 foot up, release fl fish, derrick inspection, POOH. 7/8/03 POOH wi 7" spear and lay down BHA, Tested BOPE, RIH and washed down to 903' with 6' mill and 9-1/2" stabilizer cleanout BHA. 7/9/03 Rill and washed down to 1097', CBU, POOH and lay down BHA. Picked up fishing BHA (drilling jars) and RIH. Engage fish at 712', jar up and down, jarred fish free after 9 hrs and circulated. POOH with fish. 7/10103 POOH and laid down fish. PU clean out BHA and RIH to tag top of fish with 9-1/2" stabilizer at 798', Circulated hole clean, POOH. RIH with casing cutter, would not enter fish at 799', POOH and modified guide, Rlli and through top of fish at 799', cut casing @ 934', POOH with casing cutter. PU fishing BHA including rattler vibrating jar. 7/11/03 Rill, Engaged fish, Vibrated and jarred fish, Repaired standpipe leak. Continued vibrating and jarring on fish, no movement. POOH, LD fishing BHA. ( (" 7/12/03 Picked up milling BHA with pilot mill (8-5/32" OD blades, 6" pilot nose) and tightened clamps on standpipe. RIH, tagged fish, circ with some viscosity and recovered large amount of solids. Milled on fish from 798' to 810', PU and could not slack off back to 810'. Circ and work pipe, punched through and passed through top of fish at 810'. POOH, pilot mill blades were wore down to 6" OD. Rill with 6.25" clean out mill to 2193'. Change over hole to hi-vis fluid and POOH. Made up pilot mill BHA and RIH (7-7/8" OD blades). 7/13/03 Milled on fish and circulated as needed to keep hole clean from 810' to 860'. 7/14/03 Milled on fish and circulated as needed to keep hole clean from 860' to 961'. (Modified cuttings chute.) 7/15/03 Mill wore down and slipped inside 7" casing, CBU. POOH and tested BOP. Rill and reamed to 961'. Milled on fish to 995'. 7/16/03 Milled on 7" casing from 995' to 1181'. 7/17/03 Milled on 7" casing from 1181' to 1190'. Made clean out run with 9 7/8" mill. Cleaned out to 1182'. 7/18/03 Cleaned out to 1185', POOH with 9-7/8" mill and changed to Pilot mill, RIH, Milled on fish to 1256'. 7/19/03 Milled on fish to 1263'. POOH, some 7" casing junk wrapped around pilot mill. Changed to 9 7/8" Junk mill, Rill and milled from 1259' to 1268'. Made trip and changed to 6" mill, RIH, Cleaned out to 1331'. 7/20/03 Cleaned out 7" to 1905', CBU, POOH and laid down 6" mill. Changed to 9 7/8" Junk mill and 9-3/4" stab, Rill and milled from 1268' to 1272'. Made trip and changed to Pilot mill, Rill, Milled on fish from 1272' to 1336'. 7/21/03 Milled on fish from 1336' to 1547'. 7/22/03 Milled on fish f/ 1547'-1676', clean flow line, eirc, POOH w/ pilot mill, MU 9 7/8" mill, RIH, tag @ 1608', attempt to circ, plugged string, POOH, clean iron f/ mill, MU wash tool to clean iron f/ BOP stack, wash stack, attempt to pull wear bushing, no go. 7/23/03 Attempt to pull wear bushing, wash around WB lockdown screws, RID test equip. Obtain waiver from Chuck Scheve-AOGCC to continue with 9-7/8" mill cleanout run while developing plan for pulling wear bushing and performing BOP test. MU BHA, serv rig, RIH w/9 7/8" mill to 1200', wash to 1608', ream to 1675', mill to 1676', CBU, POOH. RIH with pilot mill to 1620', plugged string, attempt to unplug, POOH. ( (' 7/24/03 Con't POOH wet, unplug metal fl pilot mill, Rlli with pilot mill to 1000', CBUx3, Rlli to 1500', wash to bottom @ 1676', mill 7" csg fl 1676' to 1829', sweep hole every 2 hrs. 7/25/03 Mill 7" csg fl 1829' to 1880', hole packing off, work up to 1676', normal circulation, circ, POOH. MU 9 1/2" c1eanout assembly, Rlli, wash & ream, dress off top off fish to 1883', POOH wI pumps to 1169', circ, POOH, LID BHA, MU 7-7/8" pilot mill, Rlli. 7/26/03 Wash fl 1700' to 1883', mill fl 1883' to 1950' with pilot mill, circ, pump out to 1770', wash BOP stack. MU 9-1/2" mill c1eanout BHA, RIH, circ, ream 1880' to 1947'. 7/27/03 Mill on junk fl 1947' to 1950', circ, pump out to 1770', POOH, wash stack. PU c1eanout assembly #2 wI csg scraper, RIH, wash to 1950, circ, pump out to 1770', POOH. Wash BOP stack, MU tri-mill assembly wI 9.794" upper mill, RIH to 1945', circ & sweep hole. 7/28/03 Circ @ 1945', POOH wI tri-mill assembly (9.794" OD), LID BHA. RU Schlum WL, Gauge ring JB CCL run 9.45" OD to 1940' (could not see collars), Run CCL by itself, still could not see collars. PT csg to 500 psi, RU/run USIT fl 1935' to 200' (collars successfully logged), RU/Run Baker CIBP & set top @ 1941', POOH WL, RID, LD 3-1/2" drill pipe. 7/29/03 Flush BOP stack wlwash tool, N/D BOP, cut wear bushing fl csg spool, NU BOP, test 103/4" csg to 1300 psi for 30 min with no leaks. End of A-10 Abandonment Sleeve - ~ - m - FISH @ 6008' - leaking - XX Plug - "XA. 0000 4 - - - - - - - - - - 2 "XN· - PBm 6619' EZSV 06619' - - - - - - - - - - - - - - - TD m 8,250' Updated bv: Osborn 1012612002 PBID: 6,619' ISupv: Well: North Cook Inlet Unit No. A-tO Location: T~nek P1atfonn, Cook Inlet, Alaska 4 U2 12.6 & 12.75 1bfft = INovember 16, Field: North Cook Inlet Unit MPG 7 6694-6716 e-8 6755 - 6765 f-1.1 6919 - 6926 g-1 7030 - 7050 h-1 7085 - 7090 h-3 7224 - 7234 h-9 7294 - 7296 i-3.1 7329 - 7339 i-7 7361 - 7366 i-8 7463 - 7466 k-1 7541 - 7547 k-4.1 7628 - 7668 m-1,m-2,m-3,m-4 7762 - 7765 m-11 6424 - 6430 6462 - 6477 6508 - 6548 d-4 & d-5 DV collar @ 65115' @ 8228' * May,1997 Top of Fill 5342' February, 1998 Well started making 2000 BWPD and died October, 1999 - Set Side Bore Separation Tool with plug on bottom in Sliding Sleeve at 5207' Well would not flow, pressure up with gas, still no flow January 13-15, 2000· Found fill at 5116' RKB, bail drilling mud and sand from 5116' to 5147' RKB, SD for weekend January 18-20, 2000· Bail drilling mud and sand from 5103' SLM to 5120' SLM Nov. 25, 2001 FCO 5150' - 5212' Nov. 26, 2001 Tag silt @ 5161' - FCO 5150 - 5212' - post FCO tag @ 5158' Nov. 28, 2001 Set SCSSV Sept, 12, 2002· Pull SSSV & Tag fill @ 5150 WLM Oct. 5, 2002 Pull SBST Oct. 6, 2002 Pull PX plug; obstruction noted @ 5578' Oct. 7, 2002 Open sleeves at 5534' & 5207', Set 4-1/2' cmt retainer at 4856'. Oct. 8, 2002 Pump 35 bbl of 15.8 ppg cmt thru retainer and lay in 5 bbbl on top of retainer Oct 9, 2002 Tag TOC @4771', Pressure test cmt to 2100 psi, lost 100 psi in 30 min, good test. Squeeze Perforations Original Completion Perforations Added during 1994 W orkover ~¡!;Wl: 970) 994 5933 5942 5949 6055 6129 6158 6181 6210 6228 6272 d-2 d-3 6225 c-0.5 6234 c-1 6275 c-2.5 sand had cut tubing opposite perforations 7030'-7050' Beluga a-7 to d-5 test 4.8 MMCFD & 3000 BWPD October, 1994 - Set PX plug in XD sleeve at 5534' (5514' WIM). Open CI 1-3 XD sleeve at 5207' Well completed in CI 1-3, test 14.7 MMCFD, FrP 900 psi Note: Fish left on top of plug @ 6008': spang jars, knuckle joint, x-line setting tool 6139 b-6 6163 b-7 6186 b-8 5937 a-7 5944 a-7 5959 a-7 6088 b-3, b-4, &b-5 Notes - Well History May, 1970 - Original Completion in Beluga a-7 thru m-4, Beluga pressure monitor well July, 1975 - Added CI 1-4.1, 6.0 & 9.0 May, 1994 Workover - Commingled CI 1.0 - 6.0, 8.0 -11.0, & Beluga a-7 thru m-ll June, 1994 - Production Test 13 MMCFD & 62 BWPD, Well died August 1994 Reperforateladd perforations in Beluga, Flow Test Beluga 5933'-7765' : 9.7 MMCFD & 25 BWPD (9500 Cl) 255 psi FTP Reperforateladd perforations in Cook Inlet from 4890'-5810' September, 1994 - Set BP at 6691' and abandon Beluga e-8 to m-11 without testing, Beluga Sands 5912 - 5913 (sqz) 5744 5800 5814 - 5815 (sqz) packer @ 5846 5756 5810 CI-10.0 CI-11.0 6 5 .i l ~ 1 ~ ~ 6008.64 6012.82 ili2.:22 §.lli:i2 6552.34 ~ 51.35 4.18 537.14 gQ 0.88 Halliburton "A WR" Permanent Packer & Th¡!;. Adapter 4 U2" 12.61b/tt J-55 Mod EVE 8rd Tubing Halliburton 4 U2" "XA" Sliding Sleeve 4 U2" 12.61b/tt J-55 Mod EVE 8rd Tubin..!.. Halliburton 4 1/2" "XN" ~e Re-Entry Guide End of Tubin\!: ~ ~ 3.813 3.958 3.725 3.99 5.982 5563 5.475 5563 5.:ill. 556 I packer @ 5637 Sleeve c.", J" 5650 - 5651 (,," "XD" 0000 14 5677 - 5702 CI-9.0 . 5702 - 5723 CI-9.0 1 packer @ 5737 1 o 9 ~ 7 ~ 5747.81 ~ 5813.93 5844.88 .29 61.90 4.22 30.~ 12 Halliburton "A WR" Permanent Packer & Thg. Adapter 4 1/2" 12.61b/ft J-55 Mod EVE 8rd Tubing Halliburton 4 U2" "){D" Sliding Sleeve 4 U2" 12.6 Th/tt J-55 Mod EVE 8rd TubinZ Halliburt~n "No-Go" Seal Unit 3.880 3.958 3.813 3.958 3.900 5.982 5563 5.475 5563 4.000 37 ·z· - - - - - - - - - - "XD" 0000 - "XD" 0000 19 - ~ 5647.81 5725.07 5729.29 5735.40 ~ 77.26 4.22 6.:!! .12 Halliburton "A WR" Permanent Packer & Thg. Ada...£.ter 4 1/2" 12.6 Th/ft J-55 Mod EVE 8rd Tubin\!: Halliburton 4 U2" ")(D" Slidin¡!; Sleeve 4 U2" 12.61b/ft J-55 Mod EVE 8rd TnbinL Halliburton "No-Go" Seal Unit 3.880 3.958 3.813 3.958 3.900 5.982 5563 1:ill. 5563 4.000 5587 - 5602 5608 - 5618 packer @ 5571 CI-8.0 CI-8.1 l! 20 .2 ! 7 5571.08 5583.45 5621.91 ~ 5634.39 12.37 3~ 4.22 ~ 2.12 Halliburton "A WR" Permanent Packer & Th\!:. Ada~ter 4 U2" 12.6 Th/ft J-55 Mod EVE 8rd Tubing Halliburton 4 U2" "){D" Slidin\!: Sleeve 4 U2" 12.61b/tt J-55 Mod EVE 8rd TubinL Halliburton "No-Go" Seal Unit 3.880 ~ ~ 3.958 3.900 5.982 5563 5.475 5563 4.000 5557 - 5558 5482 - 5483 5360 5392 5365 5417 sqz) sqz) CI-5.1 CI-6.0 26 25 24 ~ 22 5243.27 ~ 5534.48 ~ 5569.96 1.24 279.97 4.22 31.26 .12 Halliburton "A WR" Permanent Packer & Thg. Adapter 4 1/2" 12.61b/ft J-55 Mod EVE 8rd Tubing Halliburton 4 U2" "){D" Sliding Sleeve 4 W" 12.61b/tt J-55 Mod EVE 8rd Tubin..!.. Halliburton "No-Go" Seal Unit 3.880 3.958 3.813 3.958 3.900 -- 5.982 5563 5.475 5563 4.000 5270 - 5280 5313-5318 5324 - 5327 5337 - 5343 5352 - 5355 CI-4.1 CI-5.0 CI-5.0 CI-5.0 CI-5.1 II ,g 31 30 29 28 27 illill ill2&.Q ~ 4874.31 ~ ~ 5242.15 ~ 33.07 1.44 33350 ~ 30.12 2 Halliburton 4 U2" "){D" Sliding Sleeve 4 1/2" 12.61blft J-55 Mod EVE 8rd TUbin....K. Halliburton "No-Go" Seal Unit Otis "VSR" Hvdraulic Set Retrievable Packer 4 U2" 12.61b/tt J-55 Mod EVE 8rd Tubin\!: !.lalliburton "X" ~~_ 4 U2" '2.6Th/ft J-55 Mod EVE 8rd Tubin..!.. n .- packer @ 5243 Cook Inlet Sands 4890 - 4990 CI-1.0 5008 - 5088 CI-2.0 5111 - 5151 CI-3.0 5163 - 5193 CI-3.1 38 37 ~ ~ 34 2250.00 ~ 4784.91 4819.94 4832.20 35.03 2.26 2 4 U2" 12.6Th/ft J-55 Mod EVE Halliburton "X" landing Nipple 4 U2" 12.61b/ft J-55 Mod EVE Halliburton Tubing Seal Divider Otis Ralch-Lalch Seal Unit 8rd Tubing 8rd Tub~ 3.958 ~ 3.958 3.958 3.955 '- . 5563 4.998 5563 5.969 5.627 2533.47 1.44 CMT retainer @ 4856' om02 Otis ·VSR' packer @ 4833' Tubing Seal Divider @ 4820' "4815-4816 (sqz) 1 38.90 38.90 Elevation 1.950 7.296 7,296 8,228 Tubin ( Siring: 2.250 f - 6,550 Htålli.lillH J-55 M2!!EUE 8r<! HtiiisHffiIiihn '"'' g¡:¡¡¡:¡¡¡ PRODUCTION TUBING STRING ,.~!3.~ ~::~~¡ 134 :Dnm:::¡: 4 /2" .2.:!S..~~/fl NCIU A-10 Actual Abandonment BPV(Make.Tvpe,OD) FMC OCT Tbl!ll2dMake.TvDe) FMC TC·lA 4112" 8rd X 4112" Annulus Fluid: 8.5 lb/e:al comptetion fluid with 30 % methanol TOC: WATER DEPTH: 120' HóiJ. ::LH:¡ ¥QJ1 H:V:::fu!ffi!iiF4HHm:Wí:::mm:::H:::Hö.fi(i¡WHH ~¡¡iïj _ _ Production Casin....&L..- 1Q...:. ....±! ...122_ 1&...:. ....±! -ill_ Q.lli ....±! 1.695 ~ o 3/4 ,695 2.782 455#/ft :::! '--- - 4-1/2" tbg cut at 2250 Tag cmt above ret @ 4771 0/9/02 1 7 ll.!M! 261blfl J-55 J-55 BT&C BT&C 4360 4980 3270 4370 366 415 ~ 7" milled to 1950' r-- 7" BP at 2245' 103/4' @ 2782 J-55 J-55 ~ BT&C 3130 3580 580 2090 .@2 715 -~ I'" ,.-10-314" BP at 1941 631 366 '- '-- T BT&C mïtiïi£: MEMORANDUM ~n1D3 TO: Randy Ruedrich Commissioner ~\ \~) /Ì íl~l\ 1 THRU: Jim Regg "«' P.I. Supervisor FROM: John Crisp Petroleum Inspector Operator Rep.: Mike Winfree Contractor Rep.: Otto/Pull ia/Peters Test Pressures Rams: 250/3000 MISC. INSPECTIONS: P/F Location Gen.: Good Housekeeping: V. Good PTD On Location Yes Standing Order: Yes BOP STACK: Quantity 1 1 1 1 1 1 2 P/F Sign: N/A Rig cond: ~ Hazard: P Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Size 135/8 4.5 27/8x5.5 13 5/8 3 1/8 3 1/8 3 1/8 N/A \ State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 22,2003 SUBJECT: Blowout Preventer Test New Contractor 5 Conoeo/Phillips Tyonek PIt. A-10 Ptd 169-088 Sundry 302-237 N. Cook Inlet/Beluga Pool NON· CONFIDENTIAL Op. phone: 907776-2350 Op. E-Mail: Rig phone: 907776-2350 Rig E-Mail: Annular: 250/3000 Choke: 250/3000 TEST DATA FLOOR VALVES: Quantity P/F Upper Kelly 1 P Lower Kelly 1 Ball Type 1 I nside BOP 1 P/F P P P P P P P ~ CHOKE MANIFOLD: Quantity P/F 16 P 1 P ! P No. Valves Man. Chokes Hyd. Chokes P MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector AI arm P P P <0 P Visual P P P Tested Tested ACCUMULATOR SYSTEM: Time/Psi P/F System Pressure 3000 After Closure 1650 200 psi Attained 18 sec. Full Pressure 2 min. 11 sec. Blind Covers (All Stations): Yes N2 Bottles (avg): 4 @ 2500 psi. Test's Details I traveled to C/P Tyonek PIt. to witness the initial BOP test on the de completion of well A-I O. The application for sundry approval number for de complete is 303-129. The PTD for the sidetrack of A-lOA is 203-075.5 failures were witnessed on initial BOP test. Flange to W/H would not hold test pressure, this was seen leaking to atmosphere. There was no working gauge @ Drillers console or choke panel to show casing pressure. Floor safety valve leaked@ keyhole. Li.e;hter than air .e;as detector @ the shale shakers failed to test. Gas detectors did not co~y wi AOGCC Regulation 20 AAC 25.066 (6). ------.. Withe amount of cased hole work to be performed before wellbore pressure or fluids could be encountered @ surface, & wi the on duty AOGCC Engineer contacted for support, the cased hole operations were allowed to continue wi Rig out of compliance. The Rig must be in full compliance wi AOGCC regulations before pressure tested 7" casing is cut. v/ /J -t1 ~ Attatehments: none ,-:-/ ~ ~ ~ ¡ ~,;!. ~ L ¡v-~ ~ W f4-. ¡(..~ Tv-.-:, <::. '\ "::> ù-.. ~Q~ '" ~"\ù ~\().~ ~< ær~ Iv 2003-0622_BOP _Kuukpik5_NCIU_A-10jc.xls Total Test Time: 10 hrs. cc: Number of failures: BOP Test (for inspectors) BFL OS/29/03 SC Ai\~NED I\UG 0 4 2003 ,( NeJ .J~,- ,D \<cS .-Cf6~ ~-\a~ ~.()~-O'5 Variance Request ~c..\ \J ç.'<L\0 ~\\~ Kuupkik Rig 5 North Cook Inlet Platform ConocoPhillips Alaska ConocoPhillips Alaska (CPA) has moved Kuupkik Rig 5 to North Cook Inlet Platform to perform drilling and completion operations on the platform. Inspector John Crisp witnessed the initial BOP test on June 22 and noted 5 discrepancies. Preparatory operations were allowed to continue, however CPA was required to remedy the discrepancies before conducting what would be considered "open hole" activities. As of the afternoon of June 25, 2003, CPA had completely remedied 3 of the discrepancies. The 4th discrepancy was expected to be remedied following arrival of the necessary LEL calibration gas on the evening of June 25. The final discrepancy, distinct audio alarms for H2S and methane, is not expected to be remedied until sometime Friday June 26. CPA has requested a variance to the requirements of 20 MC 25.066(6) so operations might proceed. In support of their request, CPA stipulates that 1-AII required gas detection sensors are in place and functional. 2--There are functioning, individual, visual indicators for H2S and methane. 3-- The 7" casing will not be cut until the LEL detectors have been properly calibrated. 4- The gas on North Cook Inlet does not contain H2S. 5- The recognized risk of H2S lies in cutting the 7" casing and circulating the "fluids" that have been in place for some 35 years. 6-CPA has hand held detectors available. Regulation 20 MC 25.066(d)(3) allows the Commission to approve a variance from the requirements of this section [.066] if the variance provides at least an equally effective means of gas detection. The ability to detect either gas is not compromised by granting CPA's request. If either H2S or methane were detected, the individual visual indicators would signal appropriately. If high detection limit were exceeded for either gas, the single audio alarm would sound. I recommend approval of CPA's variance request. This approval is only for the time necessary for CPA to obtain the necessary "horn" parts. As noted in CPA's variance request, they expect to remedy the 5th discrepancy on June 26,2003. ~~?~ Tom Maunder, PE Sr. Petroleum Engineer SCANNED JUL ø 3 2003 Wwd: Kuupik Rig 5 BOP test compliance issue~ Subject: [Fwd: Kuupik Rig 5 BOP test compliance issues] Date: Wed, 25 Jun 2003 16:54:42 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Randy Ruedrich <randy_ruedrich@admin.state.ak.us>, Dan T Seamount <dan_seamount@admin.state.ak.us>, Sarah Palin <sarah.JJalin@admin.state.ak.us> cc: Jim Regg <jim_regg@admin.state.ak.us>, Winton GAubert <winton_aubert@admin.state.ak.us> All, Enclosed is a response to CPA with regard to a H2S gas alarm variance request. I discussed this matter with Randy and he gave his approval to send the response. The analysis note is attached. Tom ~._.,.."...."..,.,.",..",,,,.. ", ···.·......··"·,.......w··,··,.....·,.......,·.·"...,'...,......,,..··,···"·,,.,·"'...·,·.,·,···..·,·,··,·.··'w...,·.·"-'....,.·..···w·..,"........·....,·,·.,..,··.....,y·,.,··........."·,···w.·,..··"'.............'....,.,.... .,.."..........."...."'..""'.........,.".......",.,,.,."'.....,.,.....,.,.,..,........,·,..,·,···,··,··,·,.w·...,·,"w.·,...·..·,···,···".....·....·.··....",'....,·...·.,."........·,....."......,'..'w........,.",.,.· Subject: Re: Kuupik Rig 5 BOP test compliance issues Date: Wed, 25 Jun 2003 16:52:38 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Tim A Billingsley <Tim.A.Billingsley@conocophillips.com> CC: Kuupik 5 Company Man <Kuupik5CompanyMan@conocophillips.com>, Kuupik 5 Tool Pusher <Kuupik5TooIPusher@conocophillips.com>, Larry Ross <Iarry@kuukpik-drlg.com>, Paul Mazzolini <PauI.Mazzolini@conocophillips.com>, AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> Tim et ai, An evaluation has been made of your request for a variance to the requirements to have separate audio alarms for the H2S and methane detectors on board the Kuupkik 5 rig on NCIU platform. Your request for variance has been approved. This approval is for roughly the next 24 - 30 hours to allow ConocoPhillips to obtain the necessary parts to allow the separate audio alarms. As you indicated in your request, the LEL detectors must be satisfactorily calibrated before any operations to cut the 7" casing may be undertaken. Both the H2S and methane detectors and the associated visual alarms must be operational. You correctly identify the H2S risk as being from the "fluids" in the 10-3/4" x 7" annulus that will be circulated from the well bore following the cut. You are urged to take prudent precautions when circulating that annulus. Please keep us informed as to the status of finally remedying the audible alarm discrepancy. Tom Maunder, PE Sr. Petroleum Engineer Tim A Billingsley wrote: > Tom, > (See attached file: 1_BOP Kuukpik 5 06-22-03 JC1.xls) > The BOP test of 6/22/03 on Tyonek Well A-1 0 witnessed by John Crisp had the > following 5 failures (see attachment above). > These failures are all corrected or will be corrected before cutting the 7" > casing as shown below except for #5. > > 1) Floor valve - New floor valve has been obtained. > 2) LEL gas detector at shale shakers not working. New detector has been > installed. Calibration gas will be on the platform this evening to verify > detector operates correctly. > 3) Casing pressure gauge not working at choke panel next to driller's > console. This gauge has been repaired. > 4) Wellhead flange leaked. This has been fixed and pressure tested to 1500 > psi after NU the BOPs on the casing head. 1 of 3 6/26/2003 8:19 AI ~ {Fwd: Kuupik Rig 5 BOP test compliance iSsu,' ~ > 5) Gas detectors did not comply with 20 MC 25.066(6), H2S and Methane > alarm systems need to be different from each other, both visual and audio > alarms need to be different from one another. This problem has not been > fully corrected yet. There is distinctly different visual alarms (Amber > for H2S and Red for LEL) but there is presently not distinct audio alarms > for H2S and LEL. There is only one alarm sound for both. A new audio > alarm is arriving and should be working by Friday. We do have handheld H2S > monitors which will be present when we circulate up the 7" x 10-3/4" > annulus. None of the wells at Tyonek platform produce H2s but there is a > possibility of H2S being present in the old annulus fluids that will be > circulated up the 7" x 10-3/4" annulus. If there is a release of H2S gas, > all of the detectors have been calibrated and will detect the H2S but the > audio alarm will not be distinguishable between H2S or LEL. > > Therefore, ConocoPhil/ips proposes: > ConocoPhil/ips will not cut the 7" casing until the calibration gas has > been transported to the platform and the LEL detectors checked. (item #2 > above). > ConocoPhillips requests permission to proceed with the 7" casing cut > tonight after the LEL detectors have been calibrated but before the > distinct H2S vs LEL audio alarm has been installed which will occur on > Friday. > > Thank you for your consideration. > > Tim Billingsley > 265-6531 > > ----------------------------------------------------------------------- > > > Name: 1_BOP Kuukpik 5 06-22-03 JC1.xls 1_BOP Kuukpik 5 06-22-03 JC1.xls Type: EXCEL File (application/msexcel) Encoding: base64 ..,...."",...".. ".".',',..',' ,',·"'W',','.,',',wu.',w.',',',"",,·,,', ',',' ".',',','.',"," '......',.,"",.,','..... ,',',',',',',',',",'.,"",',W.W 'w·...'",'.',.",.·..",·,w,w."" .,'.'...',.....",'.' '.w,'.'." ,',',',' "",..,. , ".'" "',' ,,".'.",',',",',' ',' ,...."'.,,.. ',','.', ,',·,'."",,'.','.',,',·',',',','.'.'.',W.",'H '.'.',., ,'.' ',',' ...., '."'.'.'" '01",'.'," ',',' 'I Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission I,... Name: 030625-gasdetVariance Request.doc 0030625-qaSdetVariance Request.doc Type: WINWORD File (application/msword) : Encoding: base64 Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission ~:.:...;,;",..:..:..;,.~_......_---.........._.. .,_...........................u:.:...¡,.,..........---..:..o..... 2of3 6/26/20038:19 AI '. { MEMORANDUM TO: Randy Ruedrich Commissioner THRU: Jim Regg P.I. Supervisor FROM: John Crisp Petroleum Inspector Operator Rep.: Mike Winfree Contractor Rep.: OUo/Pullia/Peters Test Pressures Rams: 250/3000 MISC. INSPECTIONS: P/F Location Gen.: Good Housekeeping: V. Good PTO On Location Yes Standing Order: Yes BOP S1 ACK: Quantity 1 1 1 1 1 1 2 P/F Sign: N/A Rig cond: ~ Hazard: P Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Size 135/8 4.5 27/8x5.5 135/8 31/8 31/8 31/8 N/A State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 22, 2003 SUBJECT: Blowout Preventer Test New Contractor 5 Conoco/Phillips Tyonek PIt. A-10 Ptd 169-088 Sundry 302-237 N. Cook Inlet/Beluga Pool NON· CONFIDENTIAL Op. phone: 907776-2350 Op. E-Mail: Rig phone: 907776-2350 Rig E-Mail: P/F P P P P P P P Annular: 250/3000 Choke: 250/3000 TEST DATA FLOOR VALVES: Quantity P/F Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 F Inside BOP 1 P CHOKE MANIFOLD: Quantity P/F 16 P 1 P ! P No. Valves Man. Chokes Hyd. Chokes MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector Visual P P P Tested Tested Alarm P P P F P ACCUMULATOR SYSTEM: Time/Psi P/F System Pressure 3000 After Closure 1650 200 psi Attained 18 sec. Full Pressure 2 min. 11 sec. Blind Covers (All Stations): Yes N2 BoUles (avg): 4 @ 2500 psi. Test's Details I traveled to C/P Tyonek PIt. to witness the initial BOP test on the de completion of well A-IO. The application for sundry approval number for de complete is 303-129. The PTD for the sidetrack of A-lOA is 203-075. 5 failures were witnessed on initial BOP test. Flange to W /H would not hold test pressure, this was seen leaking to atmosphere. There was no working gauge @ Drillers console or choke panel to show casing pressure. Floor safety valve leaked '@ keyhole. Lighter than air gas detector @ the shale shakers failed to test. Gas detectors did not comply wI AOGCC Regulation 20 AAC 25.066 (6). WIthe amount of cased hole work to be performed before wellbore pressure or fluids could be encountered .@ surface, & wi the on duty AOGCC Engineer contacted for support, the cased hole operations were allowed to continue wi Rig out of compliance. The Rig must be in full compliance wi AOGCC regulations before pressure tested 7" casing is cut. Total Test Time: 10 hrs. Number of failures: ~ BOP Test (for inspectors) BFL OS/29/03 ª Attatchments: !1QJ]! 1_BOP Kuukpik 506-22-03 JC1.xls Re: Tyonek A-10 7" ram test ~ ~~ dO ~ -é)'( ~ Subject: Re: Tyonek A-10 7" ram test Date: Tue, 24 Jun 2003 09:25:22 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Tim A Billingsley <Tim.A.Billingsley@conocophillips.com> cc: AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> Tim, Thanks for the email, I don't see what other option you will have. Has there been any pressure noted on the 10-3/4" x 7" annulus?? That would be you <- greatest risk. Your proposal to test prior to ND against a BP in the casing was what I was thinking of after listening to your message. By copy of this email, your proposal is accepted. Good luck. Tom Maunder, PE AOGCC Tim A Billingsley wrote: > Tom, > As we discussed on the phone today, 6/24/03, the upcoming cut and pull of > the 7" casing on Tyonek A-1 0 is presenting difficulties in obtaining a > conventional 3000 psi test of the 7" rams. > Step #4 of the approved Permit to drill says "ND BOPs and ND tubing head. > Tack weld slips to 7" casing. NU BOPE to casing head. Test BOPE to 3000 > psi." > > The problem is that a test plug can not be run in the casinghead with the > slips and 7" stub in the way. Also, the 10-3/4" x 7" annulus will be in > communication with any BOP test pressure so the test pressure can not be > contained. So a BOP test after the BOPs are nippled up to the casinghead > can not be accomplished. > > ConocoPhillips proposes to: > 1) Set a 7" bridge plug at 2100'. > 2) Change the top pipe rams to 7". > 3) Pressure test to 1500 psi, a shell test on the 7" rams against the 7" > bridge plug. > 4) Nipple down the BOPs. > 5) Remove the tbg head. > 6) Tack weld the 7" slips to 7" casing stub. > 7) NU the BOPs to the casing head. > 8) Proceed with the 7" cut at 2100' and pull 7" casing. > 9) After the 7" casing has been pulled, set test plug in the casing head > bowl. > 10) Change 7" rams to 4-1/2" rams. > 11) Pressure test BOPs to 3000 psi. > 12) Proceed with step 7, preparing to sidetrack 10-3/4" casing at 2000'. > > Please let me know if the revised plan above meets with your approval. > > Also, the rig is working on the deficiencies that John Crisp noted. The > gas alarms are being corrected and will be done before the 7" casing is cut > and pulled. > > Tim Billingsley > 265-6531 r:::::::::::::::::::~::::::::::::::~:::::::~::':::::::::::::::::~::::::::::::~:::::~:~::::::::::::::,~:~::::::::::::::::::::::~::::::::::::::::::::::::::=:::::::=:::::::::::::::::::::=:::::::::::::::::::::::::::::::::::=.=:::=::.::::::::::::::::::::::::::::::::::,::::::::::::::::::::::::::: ¡CANNED JUl 0 3 2003 1 of 2 7/24/2003 11 :46 AM ',,-, '-" A~s- ~ y k'1l\03 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 Perforate 0 Variance 0 Annular Dispos.D Alter casing 0 Aepair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Ae-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to 9PM Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 69-88/302-237 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Ak 99510-0360 50-833-20030-00'/ 7. KB Elevation (ft): 9. Well Name and Number: 116' RKB NCIU A-10 8. Property Designation: 10. FieldlPools(s): ADL 17589 / ALK 2916 N. Cook Inlet Field/ Beluga Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured) Junk (measured): 8250' 6240' 6619' 5100' 4771' Casing Length Size MD TVD Burst Collapse Structural 366' 30" 366' 366' Conductor 6311 16" 631' 631' 1640 670 Surface 27821 10-3/4" 2782' 25181 3130 1580 Intermediate Production 8228' 7" 8228' 62251 4360 3270 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 48901-77651 39051-59121 4-1/2" J-55 65501 Packers and SSSV Type: Halliburton SSSV nipple @ 279' Packers and SSSV MD (ft): Halliburton VSR and AWR pkrs SSSV @ 279', pkrs at 4833, 5243', 5571', 5636', 5737', 5846' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/1/2003 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJD WINJD WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tim Billinaslev @ 265-6531 ' Printed Name Paul Mazzolini Title Cook Inlet Drilling Team Leader Signature ?~fY/t-A;(.V'ß, '- , Phone 263-4603 Date 04-/ ~5' I Zoo3 ... .. COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3p3 -/~ Plug Integrity 0 BOP Test D Mechanical Integrity Test D Location Clearance 0 RECEIVl:::u Other: ~~QO~';\ ~V ~3ç-I£,'WI APR 2 5 2003 Subsequent Form Required: lc)-'\"tl, 5CìANNED APR 3 0 2003 Alaska Oil & Gas Cons. Commission Anchorage ~ BY ORDER OF ~/<.elÞ3 Approved by: /Zø /- COMMISSIONER THE COMMISSION Date: ---- " / Form 10-403 Revised 2/2003 ORIGINAL SUBMIT IN DUPLICATE "-" ldry Application for Abdn, Well A-1 0 '-"" Saved: 25-Apr-03 1. Proposed Abandonment Program Please refer to Attachment 2, A-l0 Well Schematic. 1. MIRU Kuukpik #5 on the Tyonek platform. 2. Install and test BOPE to 3000 psi. (Note: 5,000 psi BOP equipment will be rigged up on A-lOa but the tubing head is only rated to 3000 psi so the max test pressure is requested to be only 3000 psi. The maximum anticipated surface pressure is only 2347 psi as noted above in Section 4 so a 3000 psi test is appropriate.) 3. Cut and pull 4-1/2" tbg from 2100'. (Note: tbg plug was tagged at 4771' on 10/9/02 to abandon perfs in A-l0.) 4. Observe that 7" casing and 7" x 10-3/4" annulus is stable. ND BOPs and ND tubing head. Tack weld slips to 7" casing. NU BOPE to casing head. Test BOPE to 3000 psi. (Note: 5,000 psi BOP equipment will be rigged up on A-lOa but the casinghead is only rated to 3000 psi so the max test pressure is requested to be only 3000 psi. The maximum anticipated surface pressure is only 2347 psi as noted above in Section 4 so a 3000 psi test is appropriate.) 5. RIH with hydraulic casing cutter on drill pipe. Cut 7" casing at 2050'. Circulate up 7" x 10-3/4" annulus via casing cut. POOH with casing cutter. 6. Spear 7" casing, pull and lay down 2050' of 7" casing. 7. RIH with 9-1/2" tri-mill clean out assy to 2050'. Circ hole clean, POOH with mill assy. 8. RU E-line, set 10-3/4" 45.5# bridge plug at 2000' (KOP). POOH and RD E-line. 9. Pressure test 10-3/4" casing to 1500 psi. 10. Prepare to drill A-lOa sidetrack well at 2000'. (see previously submitted APD for A-lOa) 2. Attachments Attachment 1 Kuukpik Rig #5 BOP and choke manifold drawings Attachment 2 A-10 Well Schematic. 6CANNED APR 3 0 2003 A-10 403 abdn proc.DOC Printed: 25-Apr-03 , 45" Annular 13 5/8" cJ & (" Double Gate 34" 13 5/8" 13.400 9.800 , Choke· ,Line ,Outlet 3" 5,000 PSI M'ud, Cross 20" .... Kill Line Inlet 3" 5,000 PSI , ( 13 5/8n Singl·e Gate 18" 1.3 5/8" 5,000 PSI Shaffer BOP Stack Kuukpik Drilling Rig 5 + + o pres~re Sensa 0 CÐCÐ. CÐ CÐ, CÐJ t Automatic Choke -- To Shaker o CB 3" Panic o CÐ , 0 CÐ' 101 ICÐI - I I I o CÐ o CÐ let> ICÐ t Manual Choke D t Inlet ¡~ T-o Gasbuster o CÐ r- 3" 5,000 PSI Choke Manifold Kuukpik Drilling ~~D APR 3 () 2003 ~ANNEJ) APR 3 0 2003 "-" ~ NCIU A-10 WELL COMPLETION DIAGRAM IRPVIM.k.............OD\ FMC OCT IIIIœ.DrUIDook: ~ Tb ) FMC TC-JA 4m"8ldX4m"BT&C IIIKB-'DIB: 3'04' 41 lADnaladllalth 1.51..,...1 lXIamlellon Dald with 30... methanol JKKB.& . U6' 366 TOC. 2.710' ftom CBL dated 4IJ2f10 WATBRDBP'DI: 120' Imœ..ML. ¡¡¡¡¡m~~¡¡¡¡¡¡¡¡¡p¡¡¡¡¡,1.i§¡F-~~I~~="æjæiil;¡¡¡¡jjfæiæE;¡;¡¡~jæ=ã¡;'3ïf¡¡¡':¡¡¡;;;¡¡¡Ê=-'¡¡¡'ïïr";;¡¡I¡;;:~ l'IotIaclloa CUm. 631 30· 41 366 16· 41 cal 10 3/4 . 41 1695 405#Jft 1-55 BT&C 3130 1510 629 10 3/4 " 169S 2782 4S5#Jft I~S BT&:C 3580 2090 715 103/4· 0 2782 7· 39 70 261h1R I~S BT&C 4910 4370 415 TOO 0 2780' 7· 70 61S1 231h1ft I~S BT&:C 4360 3270 366 * 7" 68SI 1228 261h1ft MS BT&:C 4910 4370 41S Tag cmt above ret 0 4771',1019/02 TabllU! 8Id1U!' 4 lfl· 39 311 12.60 IhIft 1..55 MocIBT&C 4730 4910 ill Tlbing Seal Divider 4 lfl" 311 6.550 12.751h1R 1..55 Mod BlE IIrd 4730 4980 134 o 4820' c~= "';;,"''''.....=.Iª:;¡;¡;¡¡¡¡¡Iiï1ê-~ ;;'==-=:0-:;"",:.::" -_¡¡¡¡m¡¡t - -.-. - . .--- .¡¡:~~if.=- __Ë'.!!IÐf.,.¡¡..;;; .. 4815 - 4816 (sqz) P:R.ODUCTIONTVBJNGBl':R.ING Otis "VSR· packer 44 0.00 31.90 Blevalion o 4833' 43 31.90 0.66 FMC/OCTlI'aM 4112"1Irdx4112"BT&C Tutin._.... 3.9SI 6.000 42 39.56 239.53 4lfl" 12.61h1ft I~S MocIBT&:C Tabin~ 3.9S1 S.563 CMT retainer 0 4856' 1017/02 41 279.D9 2.46 Otis 4 1/2. SC88VLaodill2 NiDoIe - - ooIlSSSV 9/J2/02 3.813 S.566 - 40 2815S 29.21 4lfl" 12.61h1R MS MocIBT&:C Tabin~ 3.9S8 5.5ca 31 ....:J!:.... 39 310.76 0.7S X..ova, 4 lfl· BT&C1o 4lfl" Mod BUBIrd 3.953 4.919 Side - Cook Inlet Sands 31 31151 4471.96 4 lfl· 12.61h1R 1-55 Mod BUB Ird Tabing 3.951 S.5ca 11«. 4890 - 4990 CI·I.0 37 4713A7 1M Halliburton "X" LoadiD2 NiÐD1e 3.813 4.991 ii' - 5008 - 5088 CI-2.0 36 4784.91 3S.03 4lfl· 12.61h1R MS MocIBUBIrd Tabin [ 3.958 S.563 Tool - 5111 -5151 CI-3.0 3S 4819.94 12.26 HaDib_ Tabing Seal DiYide:c 3.9SI 5.969 "XI)' r 0000 29 : 5163-5193 CI-3.1 34 4832.20 1.12 Otis RaIdl·LaJdI Seal Unit 3.95S S.627 33 483332 6A1 Otis "VSll" HvchaulicSctRe~ Padœr 3.880 S.982 - · . ~ packer 0 5243 32 4839.80 33.D7 4lfl" 12.61h1ft I~S ModEUE Ird Tabinlt 3.9S8 S.5ca - 31 4812.87 1M HaDiburton "X" Loadin [ NiÐD1e 3.813 4.991 - 5270 - 5280 CI-4.1 30 487431 333.50 4lfl" 12.61h1R I~S Mod EUE Ird Tabin [ 3.958 S.5ca 5313 -5318 CI-5.0 29 S207.81 4.22 HaDib_ 4lfl· "XI)" Sliding Sleeve 3.813 5A75 - 5324 - 5327 CI-5.0 28 S212.03 3D.12 4lfl" 12.61h1R 1-55 ModEUE Ird Tabinlt 3.9S1 S.5ca - 5337 - 5343 CI-5.0 27 5242.15 1.12 HaDibmlon "No-Go" Seal Unit 3.900 4.000 - 5352 - 5355 CI-5.1 - - 26 S243.27 11.24 HaIIib_ "AWR.·PamaacntPadœr&<Tb~.AdanIcr 3.880 5.982 2S S2S4.51 279.97 4lfl" 12.6_ I~S MocIEUE Ird Tabialt 3.9S8 S.5ca - 5380 - 5365 CI-5.1 24 SS34A8 4.22 Hallibmlon41n· "XI)'SIidin~SIeeve 3.813 SA7S - 5392 - 5417 CI-6.0 23 5538.70 31.26 4lfl· 12.61h1ft I~S ModEUE Ird Tabin [ 3.9S8 S.5ca - 22 5569.96 1.12 Hallib_ ·No-6o· Seal Unit 3.900 4.000 - m .. 5482 - 5463 (sqz) "XI)' 2!!2!- 24 m 21 SS71.08 1237 Hallibmlon "A WR.. Pamanent PacIœr knit. Adanlcr 3.880 S.982 r~l .. 5557 - 5558 (sqz 20 5583AS 38M 4lfl· 12.6_ 1-55 ModBUBIrd Tabin [ 3.9S8 S.5ca 19 S621.91 4.22 Helhòmlon 4 lfl" "XI)" Slidinlt SkcYc 3.813 SA7S ~ · . ~ packer 0 5571 18 5626.13 8.26 4lfl" 12.6_ 1~5 ModEUE81d Tabin~ 3.9S8 5.563 Sleeve - 17 S63439 2.12 HaIIib_ ·No-6o· Seal Unit 3.900 4.DOO ~ 19 : 5587 . 5602 CI-6.0 "XI)' ~ 5808 - 5618 CI-8.1 16 5ca6.51 1130 HaIIib_ ·AWR.· PamanentPadœr &< nlt.AdanIcr 3.880 5.982 IS 5647.81 Tl.26 4lfl" 12.6_ 1-55 Mod EUE Ird Tabin. 3.9S1 S563 14 S72S.D7 4.22 Halhòmlon 4 lfl· "XI)" Slidin.. Sleeve 3.813 SA7S r-l 13 S729.29 6.11 4lfl" 12.6_ MS ModEUEIId Tabin.. 3.9S1 S.5ca 12 573SAO 1.12 HaIIib_ "No-Oo" Seal Unit 3.900 4.000 - · . - packer. 5637 -.. 14 m 11 S736.52 11.29 Hallibmlon "AWR." Pamancnt PacIœr &: Tb [. Adaplcr 3.810 S.9I2 ~ ." 5650 - 5651 (sqz) 10 S747.81 61.90 41n· 12.61bift I~S ModBUBIId TabiRlt 3.9S8 S.5ca "XO' ~ 5677 - 5702 CI-&.O 9 S809.71 4.22 Halliburton 4 lfl· "XI). SIidin~ Sleeve 3.813 SA7S - · 5702 - 5723 CI-&.O 8 5813.93 30.9S 4 lfl· 12.6_ I~S Mod BUB lid Tabin~ 3.9S8 S.563 r-l - 7 5144.81 1.12 HaIIib_ "No-Go" Seal Unit 3.900 4.000 - !...~ - packer 0 5737 - 6 S846.OO 11.29 HaDibmlon "A WR.. Pamanent PacIœr &: Tb [. Adapter 3.880 S.982 ~ 9 - · 5744 - 5758 CI-10.0 5 S857.29 15135 4 lfl· 12.61h1ft I-SS Mod BUB Ird Tabin~ 3.9S8 S.563 "XI)' ~ " 5100-5810 CI·11.0 4 6008.64 4.18 Hallibmloa 4 lfl" "XA" Slidinlt Sleeve 3.813 SA7S - 3 6012.82 537.14 4lfl" 12.6_ 1-55 ModBUBIrd Tabin [ 3.958 S.5ca r-'1 III - 5814 - 5815 (sqz 2 6549.96 1.50 HaDibarloa 4lfl· "XN" NiDnJc 3.725 S.5ca - · . - packer 0 5846 1 65S1A6 0.88 Rc-EnIIv Guide 3.99 S56 DV collar. 5821' 65S2.34 End ofTabinlt m Beluga Sands - 5912 - 5913 (sqz) Notes - Well History - May, 1970 - Original Completion in Beluga a-7 thru m-4, Beluga presSUIe 11IOJ1itor well FISH 0 6008' _ · 5933 - 5937 a-7 July, 1975 - Added CI 1-4.1, 6.0 &: 9.0 eoIIIng - · 5942 - 5944 a-7 May, 1994 Workovec- CommingledCI 1.0- 6.0, 8.0 -1l.0,&:Belugaa-7 thrum-ll ~ - 5949 - 5959 a-7 June, 1994 - Production Test 13 MMCFD &: 62 BWPD, Well died August 1994 "XA' ~ 4 _ · 6055 - 6088 b-3, b-4, & b-5 Reperforatc/add perforations in Beluga, - 6129 - 6139 b-6 Flow Test B eluga 5933'-7765' : 9.7 MMCFD &: 2S BWPD (9500 Cl) 2S5 psi FIP - 6158-6163 b-7 Reperforatc/add perforations in Cook Inlet from 4890'-5810' - 6181 -6188 b-6 September, 1994 - Set BP at 6691' and abandon Beluga 0-8 to m-l1 without testing, - 6210 - 6225 c-D.5 sand had cut tubing opposite perforations 7030'-7050' - 6228 - 6234 0-1 Beluga a-71o d-5 test 4.8 MMCFD &: 3000 BWPD - " 6272 - 6275 0-2.5 Oetober, 1994 - Set PXplug inXD slccvcat5534' (5514'WIM). OpenCI 1-3 XD slccvc at 5207', - Well compIeœd iu CI 1-3. test 14.7 MMCFD. FfP 900 psi - 6424 - 6430 d-2 Note: Fish left on lop of plug @ 6008': spang jars, knuckle joint. x-line setting tool - - 6462 - 6477 d-3 May, 1997 Top 01 F115342' 2 ..2!.. - 6508 - 6548 d-4 & d-5 February, 1998 We. starf8d making 2000 BWPDand died PB1D .19' October, 1999 - Set Side Bore Separation Tool wi1h plug on bottom in Sliding Sleeve at 5207' wen would not flow, pressU18 I.p with gas, stiR no flow F1J!iV o .'9' - January 13-15, 2000· Found flU at 5116' RKB, ball drilling mud and sand - 6694-6716 e-8 from5116'105147'RKB, SDforweekend - 6755 - 6765 1-1.1 January 18-20, 2000 - Ball drilling mud and sand from 5103' SLM to 5120' SLM - 6919 - 6926 g-1 Nov. 2&, 2001 FCO 5150' -'5212' - 7030 - 7050 11-1 Nov. 26, 2001 Tag sin 0 5161' - FC05150 - 5212'-postFCOtag 0 5158' - 7085 - 7090 h-3 Nov. 28, 2001 Se1 SCSSV - 7224 . 7234 11-9 Sept. 12, 2002 - pun SSSV & Tag fill 0 5150 WLM - 7294 . 7296 i-3.1 Oct. 5, 2002 PuU SBar - 7329 . 7339 i-7 Oct. 6, 2002 pun PX plug; obstruction noled 0 5578' - 7361 - 7366 i-8 Oct. 7, 2002 Open sleeves at 5534' & 5207', Set 4-112' emt retainer at 4856'. - 7463 - 7466 k-1 Oct. 8, 2002 Pump 35 bbl of 15.8 ppg cmt Ihru retainer and lay in 5 bbbl on top 01 retainer - 7541 -7547 k-4.1 Oct 8, 2002 Tag TOO 04771', PressUl81estemtto 2100 psi, lost 100 psi in 30 min, good1est. - 7628 - 7688 m-I,m-2,m-3,m-4 - " 7762-7765 m·11 - Squeeze Perforations Original Completion (1970) * Potf0J81ÏoasAddedduring 1994 WoJIrovcr UÞdatecl bv . O.born 1012m002 7· 0 8228' PB1D: 6619' ISoov: rn,ltWI: 4 lfl· - 12.6 &: 12.7S IhIR Well: North Cook Inlet Unit No. A·10 Ncwember 16 1994 TD = 6 250' Localion: Tvonek P1aIfOllll, Cook InIo:l. AIasJœ. Fidd: NarIb Cook Inlet Unit MPG " \'~ fh ) PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 A. Worthington Phone (907) 265-6802 Fax: (907) 265-6224 October 22, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations NCIU A-10 (69-88 / 302-237) Dear Commissioner: ) Phillips Alaska~ Inc. submits the attached Well Completion Report for the recent P&A operations on the Tyonek well NCIU A-10. If there are any questions, please contact me at 907-265-6802. Sincerely, L~~ A. Worthington Wells Engineer Phillips Alaska Inc. A W/skad ""'"'0 g 4 l RECEIVED OCT 2 9 2002 AlasKa Oi~& Gas Gons. Commtsslon Anchorage '... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ') ) 1. Status of well Classification of Service Well Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 0 2. Name of Operator 7. Permit Number ConocoPhillips Alaska, Inc. 69-88 1 302-237 3. Address 8. API Number P. O. Box 100360, Anchorage, AK 99510-0360 50-883-20030-00 4. Location of well at surface r"êoMPLETIOII 9. Unit or Lease Name 1304' FNL, 1023' FWL, Sec. 6, T11N, R9W, SM œJ North Cook Inlet Unit . , At Top Producing Interval j W\"11" I: 10. Well Number 812' FSL, 2425' FWL, Sec. 31, T12N, R9W, SM ~~- A-10 At Total Depth $11,'" .. '., ,< 11. Field and Pool 2505' FSL, 4115'PwL, Sec. 31, T12N, R9W, SM r. -4 ,B. .....' Cook Inlet Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Beluga Pool RKB 116' feet ADL 17589 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore 16. No. of Completions August 22, 1969 September 27, 1969 May 3, 1970 N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8250' MD I 6240' TVD 4771' MD YES 0 No 0 SSSV @ 279' 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Surface 366' Driven 16" 65# H-40 Surface 631' 22" 610 sx Class G 10-314" 40.5#, 45.5# J-55 Surface 2782' 15" 737 sx Class G 7" 23# & 26# J-55 Surface 8228' 9-5/8 · 1210 sx Class G cement plug @ 4771', top of junk @ 5554' 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 311' & 6550' 5243', 5571', 5637', 5737', 5846' all perfs P&A'd 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4771' - 5554' Class G cement plug 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) not applicable P&A Date of Test Hours Tested Production for OIL -BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO N/A Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. psi 24-Hour Rate> 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. ...~~~'7 RE€EIVED ~~~~'\ ~ N/A ~'o \.<U ~,-\4 ~ . OCT 292002 >; - ~ '7 fil-~ .;ó-Y ~ <:<L~ \~\- AlasKa OD·& Gas Oons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE \ RBDMS 8Ft Submit in duplicate NO\! 1 2002 ~9. ,. / 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data. all fluids recovered and gravity. GOR, and time of each phase. N/A RI€EIVED OCT 2 92002 Alaska Oil& Gas Gons. Commission Anchorage 31. LIST OF ATTACHMENTS Summary of Daily Operations 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Aras Worthington 265-6802 Signed Lø# Aras Worlhin n Title Wells Enaineer Date /Þ~~ Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for 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 r·.,...... 1 ¡ ì j 1· \.. ' ! Date 10/07/02 10/08/02 10/09/02 ) ) NCI A-10 C t Event History ommen TAGGED OBSTRUCTION AT 5554' CTM W/JSN, WASHED TOP OF SAME. RD CT, RU SL. RUN LlB(S), INDICATIONS OF POSSIBLE COLLAPSED PIPE OR SIMILAR OBSTRUCTION. DECIDE TO ABANDON WELL ABOVE OBSTRUCTION. OPEN SLEEVES AT 55341 MD AND 52071 MD. SET 4.5" CMT RETAINER AT 48561 RKB (MID 1ST JT BELOW PKR) BUT COULD NOT SHEAR OFF, DISCONNECT & POOH W/O SETTING TOOL. ATTEMPT TO PUMP THRU SETTING TOOL & RETAINER, NO LUCK. SHUT DOWN DUE TO HIGH WINDS RESTRICTING CRANE OPERATIONS. WAITING ON WIND UNTIL 6 A.M. RIG UP 3-1/81' FISHING TOOLS WITH 3" GS AND PULL CMT RETAINER SETTING TOOL AFTER 48 JAR LICKS. ESTABLISH INJECTION THRU CMT RETAINER AT 1 BPM, 400 PSI. RIH WITH STINGER ASSEMBLY, CIRC 40 BBL SW THRU CT, UP BACKSIDE. STING INTO RETAINER AND ESTABLISH INJECTION. PUMP 40 BBL 15.8 CLASS G CEMENT & LAY LAST 5 BBL ON RETAINER. PERFORM HESITATION SQUEEZE. PUMPED 4.75 BBLS OF CEMENT AWAY THEN BUILT 280 PSI ON WELLHEAD AND PRESSURE REMAINED STABLE. COMPLETE POST-CEMENTING CLEANUP CIRCULATION. PRESSURE UP WELL TO 500 PSI TO TEST CEMENT SQUEEZE. DID NOT SEE ANY PRESSURE DECLINE IN 5 MINUTES. FREEZE PROTECT WELL WITH 12 BBLS OF DIESEL. RD CTU, RU SL. RIH W/2.4" GR AND TAG CEMENT AT 4771' RKB, EST 941 CEMENT ABOVE RETAINER. PT CEMENT PLUG TO 2100 PSI, LOST 100 PSI IN 30 MIN, GOOD TEST. SECURE WELL FOR L TSI. Page 1 of 1 10/22/2002 .,. ) ) MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Camille Taylor, uf 'fl1C~ DATE: October 11, 2002 Commissioner Tom Maunder, h~~ P. I. Supervisor \0 ( \ 5-07; THRU: FROM: John Spaulding, Petroleum Inspector SUBJECT: Plug and Abandonments PAl Tyonek Platform Wells Non Confidential October 11. ~002: I traveled to PAl's Tyonek platform to witness the plug and abandonments of the bottom hole locations in preparation for eventual sidetracking and workovers of the following wells. ~\~ In previous conversations PAl's rep. Jack Kralik asked how much pressure I wanted to see on the well upon my arrival, I requested that 500psi or at a min a positive pressure be displayed. All well were in the near area of 500psi. '<O"-Ofs~ 'A"':~Ð;was pressured from 500 psi to 1150 psi and held for 30 min. with no bleed down. The well was then de pressured to 0 psi and observed for 15 min. with no build up. \bG-a<zs, , ,A",,1'1'was pressured up from 500 psi to 1100 psi and held for 30 min with no bleed down. The well was then de pressured to 0 psi and observed for 15 min. with no build up. \ <; <6-oa ~_. ~... was pressured up from 420 psi to 2200 psi and. held for 30 min. with no bleed down. The well was then de pressured to 0 psi and observed for 15 min. with no build up. \'1~-~\D B-2 was pressured up from 500 psi to 2400 psi and held for 30 min. with no bleed down. The well was then de pressured to 0 psi and observed for 15 min. with no build up. SUMMARY: I witnessed 4 successful plug and abandonment pressure tests. Attachments: None P&A·s Tyonek Plat 10-11-02js.doc ,.. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ) ') ~I Ð?J ~~ ~7 APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_X Suspend_ Alter casing _ Repair well _ Change approved program _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora e, AK 99510-0360 4. Location of well at surface 1304' FNL, 1023' FWL, Sec. 6, T11 N, R9W, SM At top of productive interval 812' FSL, 2425' FWL, Sec. 31, T12N, R9W, SM At effective depth Operational shutdown _ Plugging _X Pull tubing _ 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service Re-enter suspended well _ Time extension Stimulate Variance Perforate 6. Datum elevation (DF or KB feet) RKB 116 feet 7. Unit or Property name Other At total depth 2505' FSL, 4115' FWL, Sec. 31, T12N, R9W, SM 12. Present well condition summary Total depth: measured true vertical North Cook Inlet Unit 8. Well number A-10 9. Permit number 1 approval number 69-88 '\1" 10. API number / 50-883-20030 11. Field 1 Pool Cook Inlet / Beluga / 8250 feet./' Plugs (measured) 6619' 6240 feet Effective depth: measured 6619 feet Junk (measured) true vertical 5100 feet Casing Length Size Cemented Measured Depth True vertical Depth Structural 30" Driven 366' 366' Conductor 16" 610 sx Class G 631' 631' Surface 10-3/4" 737 sx Class G 2782' 2518' Production 7" 1210 sx Class G 8228' 6225' Perforation depth: measured 4890' - 7765' RECEIVED true vertical 3905' - 5912' JUL 252002 Tubing (size, grade, and measured depth 45" 126# J-55 Mod BT&C @ 311' 45" 1275# J-55 Mod-EUE @ 6~~Ska Oil & Gas Gons. CommlSSlor: . , . , , . , . , Anchorage Packers & SSSV (type & measured depth) Halliburton "AWR" pkr @ 5243',5571',5637',5737',5846' MD. SSSV @ 279' MD, "VSR" pkr @ 4833' 13. Attachments Description summary of proposal _X Detailed operations program _ 14. Estimated date for commencing operation 15. Status of well classification as: August 1, 2002 16. If proposal was verbally approved Oil Gas _XX BOP sketch Suspended _ Date approved ect to the best of my knowledge. Service Title: Wells Engineer Approval no. 2. 3OZ- I~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness .!>S~t:) ~~\ ~\~\"",,"..;)'Cv\. ~~, Plug integrity ~ BOP Test ~ Location clearance _ . \. ~ (' Mechanical Integrity..... Test _ ~ Su~equent form required 10- 4.t\ ~ f"\.()~~.., ~~"""~~"\~~ \..ç ~~O~~ ,,(..~c:) ~ (3.~'i. u...~\.<:...~~", ØngInaI SIgned By Approved by order of the Commission Oechsli T Commissioner Date Form 10-403 Rev 06/15/88 · OF<IGINAL SUBMIT IN TRIPLICATE ) ') NCIU A-tO Intended P&A Procedure for rig Sidetrack Objective: Permanent Plug and Abandonment of all zones that are currently perforated for rig sidetrack next Spring. Intended Procedure: Clean-out sand to top ofCffiP @ 6619'_ T~\.....>~,,> \> ,-..;¡S'-~ 5 dO'\ i 55SL.\ Shift all sliding sleeves open. Set Cement Retainer near packer @ 5737'. Pump cement through CT & cement retainer to P&A all perfs below. Lay 10~ ~ ~'-=> \ of cement on top of retainer. \'"3>~ L\ -\ \~~ -~ ~.~S b b \ ~ · Set Cement Retainer near packer @ 5571'. Pump cement through CT & cement retainer to P&A all perfs below. Lay 10' ,;) b~\ of cement on top of retainer. \ <0 ~ \ S b b \ ~ Set Cement Retainer near packer @ 4833'. Pump cement through CT & cement retainer to P&A all perfs below. Lay 10' ..'~ b~\ of cement on top of retainer. \~ ~ \ \, ~ 'b ~ «> Tag TOe with slickline & Pressure-Test tbg to 2000 psi WHP. 1. 2. 3. 4. ( 5. 6. 7. 8. 9. 366 J 10:h' 37 =x::: TO<\ @ 2780' Tlbing Seal Divider @ 4820' ··4815 - 4816 (sqz) I-I' ~ r - ì ~ otis "VSR· packer _. .-iê @4833' 31 ~ ~ Cook Inlet Sands ~ I kIe _I Bot. _ ... ij,""....jon _ ~ 001 _~ 'xO' 0000 29 _ ~ r Open ~ -. .-¡ -~ -~. -~. -I, -F- -I' :E _ ~. 5360 - 5365 CI-6.1 -I::§ 5392 - 5417 CI-6.0 , !III!!! ¡¡¡¡ 5482 - 5483 (sqz) "Xo' ~ 24 r ~ ì ¡¡¡¡ _ 5557 - 5558 (sqz) _.-._= -.. -~ ~ _ i: 5587 - 5602 CI-8.0 'XO' ~ 19 _=. 5608-5618 CI-B.1 I r-ì ~ _ LI --= I.. packer @ 5637 ~ ;¡¡¡;¡ 5650-5651 (sqz) 'XO' ~ 14 _ ¡¡¡¡ 5677 - 5702 CI-9.0 r - l -I' 5702 - 5723 CI·9.0 -L·-~ -.i, 57 57 CI ~ _~ 44- 56 -10.0 'XO. ~ 9 _~' 5800-5810 CI-11.0 r-l !!!~ ª' §" 5814 - 5815 (sqz) _I I_~ packer@5846 ï Beluga Sands i!·· 5912 - 5913 (sqz) -i. 69 5 7· 7 _I 33- 93 ... _~ . 5942-5944...7 ~ _~ 6949-5959...7 ·X,,· ~ 4 _ II ' 60!_5 - 6088 b-3, b-4, & b-5 _I 6129 - 6139 b-6 _I 6158 - 6163 b-7 _I 6181-6186 b-8 _~ 6210-6225 0-0.5 _II 6228 . 6234 0-1 _ i . 6272 - 6275 0-2.5 -I _ ~ 6424 - 6430 d-2 _ ~ 6462 - 6477 d-3 _I 6508 - 6548 d-4 & d-5 4890 - 4990 5008 - 5088 5111-5151 5163 - 5193 CI-I.0 CI-2.0 CI-3.0 CI-3.1 packer @ 5243 5270 - 5280 5313 - 5318 5324 - 5327 6337 - 5343 5352 - 6355 CI-4.1 CI-5.0 CI-5.0 CI-5.0 CI-5.1 packer@5571 packer @ 5737 leaking 2 - "XII- - PBTO O8Ir EZSV . ee.s· E ~i _ ~ 6694-6716...8 _ II 6755 - 6766 1-1.1 Iæ -,ª -! - ;. - ~. .¡¡¡¡ -I :1 -~ _ ~ 7628 - 7668 m-1,""2,1I\o3,""4 _ª . 7762-7766 ",.11 ¡g ~ 6919-6926 g..1 703Ð - 7050 ~1 7086 - 7090 ~3 7224 - 7234 ~9 7294 - 7296 1-3.1 7329 - 7339 H 7361 - 7366 HI 7463-7466 k-1 7641 - 7547 k-4.1 7· @ 8228' ... TO . 8,250' -----------.'-- ,1:- -.-. j.t .. .i :;t,: . '.:': ;..',' BTà.·C ·h'.- :., '., 7 - 6,858 ¡ 8,:¡:;S i 261blft I J-55 BT"€: 4660 4080 377 T.bl~ Slrlu: I I 4 In' 391 3111 12.60 Iblft I 1-55 Mod BT&C 4730 4980 135 4 In. 3111 6,5501 12.75 lblll I 1-55 Mod EUE erd 4730 4980 134 --. , - PRODUCTION TUBING STRING 44 0.00 38.90 lBevalion 43 38.90 0.66 FIoIO f COT S' OM .. 1/2" erd . . 112" Bno Tubing HMgof 3.958 6.000 42 39.56 239.53 4 In· 12.61b1ft I-55 Mod BT&C 'Iùbûu!: 3.958 5.563 41 279.09 2.46 Ods 4112· SCSSII'Lendlnt N;ppIo -....ISCSSV 1V28/01 3.813 5.566 40 281.55 29.21 4 In· 12.6 lb'ftl-55 Mod BT&C Thbing 3.958 5.563 39 310.76 0.75 X-Over 4In·BT&C104IIT ModEUESrd 3.953 4.919 38 311.51 4471.96 4 In· 12.6lblft 1-55 Mod EUE Sed 'lUbin£ 3.958 5.S63 37 4783047. 1.44 Halliburton "X. Landing Nipple 3.813 4.998 36 4784.91 35.03 4 In" 12.611>'ft I-55 Mod EUE Sed Thbiug 3.958 5.S63 35 4819.94 12.26 Halliburton Tubing Seal Divider 3.958 5.969 34 4832.20 1.12 Otis Ratclí'Latch Seal Unit 3.955 5.627 33 4833.32 6.48 Otis "VSR" HydraUlic Set ~evable Packer 3.880 5.982 32 4839.80 33.07 4 In" 12.61b1ftl-55 Mod EUE Srd Thbin.c: 3.958 5563 31 4872.87 1.44 Halliburton ·X"LandinIz Nwde 3.813 4.998 30 4874.31 333.50 4 In· 12.61I>'ftl-55 Mod EUE Srd Tubing 3.958 5.S63 29 5207.81 4.22 Halliburton 4 tn· "XD· Slicing Sleeve 3.813 5.475 28 5212.03 30.12 4 In·, 12.6,Ib/ft<J-55Mod EUE Srd Tubing 3.958 5563 27 5242.15 1.12 Halliburton "No,Oo" Seal Unit 3.900 4.000 26 5243.27 11.24 Halliburton "AWR·l'ennanent Pack"" & Tbg. Adapter 3.880 5.982 25 52S4.51 7:19.97 4 tn· 12.61b1ft 1-55 Mod EUE Srd Tubing 3.958 5.563 24 5534.48 4.22 Halliburton 4.tn· "XD· Slicing Sleeve 3.813 5.475 23 5538.70 31.26 4 In· 12.61blft'I-55 Mod EUE Srd 'lùbing 3.958 5.563 22 5569.96 1.12 Halüburton ·No,<;o· Seal Unit 3.900 4.000 21 5571.08 12.37 HalJiburtOll'AWR· P~aneJlt Packer & Tbg. Adapter 3.880 5.982 20 5583.45 38.46 4112' 12.6lMI·I-55 Mod EUE Srd Tubirut 3.958 5563 19 5621.91 4.22 HaIlibtirtáo.4.ln· 'XD· Sliding Sleeve 3.813 5.475 18 5626.13 826 4 In" 12.61b1ft 1-55 Mod EUE Srd Thbin.c: 3.958 5.563 17 5634.39 2.12 HaUiburlÒlÍ"No-Go", Seal Unit 3.900 4;000 16 563651 11.30 Hallibtirton ·AWR· Permanent Packer & Tbg. Adapter 3.880 5.982 15 5647.81 77.26 4 In· 12.61b1t! 1-55 Mod EUE Srd Thbing 3.958 5.563 14 5725.07 4.22 Halliburton 4.ln· "XD· SIi<i= Sleeve 3.813 5.475 13 5729.29 6.11 4 In" 12.61blft 1-55 Mod EUE Srd Tubiwr 3.958 5563 12 5735.40 1.12 Halliburton ·No,<;o" Seal Unit 3.900 4.000 11 5736.52 11.29 HaUiburton ·AWR" Permanent Pack"" & Tbg. Adapter 3.880 5.982 10 5747.81 61.90 4 In· 12.6lblft 1-55 Mod EUE 8cd Tubing 3.958 5563 9 5809.71 4.22 HaUiburton 4 In" ·XD· Sliding Sleeve 3.813 5.475 8 5813.93 30.95 4 In" 12.61b1t! J-55 Mod EUE Srd Thbing 3.958 5.S63 7 5844.88 1.12 Halliburton ·No-Go· Seal Unit 3.900 4.000 6 5846.00 11.29 Halliburton "AWR·l'ermanent Packer & Tbg. AdaPter 3.880 5.982 5 5857.29 151.35 4 tn- 12.61b1ft 1-55 Mod EUE Srd Tubing 3.958 5.563 4 6008.64 4.18 Halliburton 4 ,112· "XA. Sliding Sleeve 3.813 5.475 3 6012.82 537.14 4 tn· 12.61b1t! 1-55 Mod EUE Brd Tubing 3.958 5.S63 2 6549.96 1.50 Halliburton 4 In" "XN" Nipple 3.725 5.S63 1 6551.46 0.88 Re-EnIrV Guide 3.99 5.56 6552.34 End of Tubing Noles - we:n Histol)' ·:no - Original Complc:tion in Beluga a- 7 then m-4. Beluga pressure monitor well 7n5 - Added CI 1-4.1, 6.0 & 9.0 5/94 Workovc:c- Commingled CI 1.0 - 6.0. 8.0 - 11.0, & Beluga a-7 tlun moll 6/94 Production Test 13 Ml\.fCFD & 62 BWPD. we:n died August 1994 ReperforaWadd pcrlorations in Beluga, Flow Test Beluga 5933'-7765' : 9.7 MMCFD & 25 BWPD (9500 CI) 255 psi FrP Rc:perforaWadd perlorations in Cook Inlet from 4890'-5810' 9/94 !"SctBP ài~ll'and abandon Bc:luga c:-8 to moll without testing, sand had cut tubing opposite: perlorations 7030'-7050' Beluga 8-7 to d-5 Ic:st 4_8 MMCFD & 3000 BWPD . Set1"Xplurin·XD·steeve·tt5534\.{5514' WLM). Üpc'JI CI 1-3 XD sle:e:ve: 815207', We:D complc:tc:d in CI 1-3, test 14.7 MMCFD, FrP 900 psi f6¡97 - 2/98 - 10/99 - Top of Fl. 5342' We' started making 2000 6WPD and died Set Side Bore Separation Tool wtIh plug on bo\l~~ We. would not 1Iaw, preesure up with gas, slil no flow 1/13100 10 1/15100 - Found fill at 5116' RKB, baR driaing mud and sand from 5f 16'to 514T RKB, SO for weekend 1/18100 10 112~OO - Bail drilling mud and sand from 5103' SLM 10 5120' SLM Nov. 26. 2001 FCC 5160' - 5212' Nov, 26, 2001 ~1:~..!~.':",.f'C06160~82ft!~~~.616'C1Ue Nov, 28, 2001 Set SCSSV .. Squeeze Perforations Original CorI¥>IetIon (1970) Pedonliœs Added œriD¡ 1994 Wortover Uodated bv : ImO 1/6102 I PBTD: 6.61'l 1Snuv: Well: Nord. Cook laid U.IINo. A.l0 Location: Tyoock Platfonu. Coot IDle!, Aluka trbg Wt: 4 112" - 12.6 a. 12.75 Iblft INovember 16, 1994 Fidd: North Cod: lDlet Unit MPG -, ) I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate Pull Tubing X Alter Casing 2. Name of Operator: Phillips Petroleum Co. 3. Address: P.O. Box 1967 Houston, Texas 77251-1967 Plugging Repair Well 5. Type of Well Development _X_ Exploratory Stratigraphic Service 4. Location of well at surface: Leg 2, Slot 6 PPCo. Tyonek Platform 1304' FNL & 1023' FWL Sec 6 - T 11 N - R9W North Cook Inlet, Ak. At top of productive interval: 4890' MD 3889' TVD 812' FSL & 2425' FWL Sec 31 - T12N - R09W At effective depth: 4890' MD 3889' TVD 812' FSL & 2425' FWL Sec 31 - T12N - R09W A t total depth: 6619' MD 5100' TVD 1744' FSL & 3228' FWL Sec 31 - T12N - R09W 12. Present well condition summary: Total Depth: measured true vertical Effective Depth: Casing: Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured true vertical Length measured true vertical Tubing (size, grade and measured depth) 8,183 feet Plugs (measured) 6,194 feet 4,890 feet Junk (measured) 3,889 feet Size Cemented 30 " Driven 16 610 sx CI "G" 1 0 3/4" 737 sx CI "G" 7" 1210sxCI"G 4890' - 7765' 3905' - 5912' Perforate _X_ Other 6. Datum elevation (DF or RKB) RKB 116 Feet 7. Unit or Property Name North Cook Inlet Unit 8. Well Number A-10 9. Permit Number / Approval Number 69-88 94-261 10. API Number 50-883-20030 11. Field / Pool Cook Inlet I Beluga PBTD: 6,619' ORIGINAL Measured Depth 366 631 2,782 True Vertical Depth 366 631 2,518 8.228 6,225 Packers and SSSV ( type and measured depth) 4 1/2" 12.6 Iblft J-55 Mod-BT&C Tubing 39 - 311' 4 1/2" 12.75 Ib/tt J-55 Mod-EUE Tubing 311 - 6550' Halliburton "SSSV" at 279', Halliburton "VSR" packer at 4833' Halliburton "AWR" packers at 5243', 557 '.., 6' 13. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 14. Prior to well operation: Subsequent to operation 15. Attachments: JAN 2 7 1995 Alas~ Oil .& Gas Cons. Commission ·-........1.. r Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure o 13000 61.96 360 o 12700 34.06 16. Status of Well Classification as: Service Copies of Logs and Surveys Run Daily Report of Well Operations X Oil Gas X 15. I hereby certify that the foregoing is true and correct to the best of my knowledge: Form 10-404 Rev. 06/15/88 Title Principle Engineer Date 19-Jan-95 SUBMIT IN DUPLICATE ¡ ~ Tubing Pressure 918 06/08/94 145 953 1 2/06/94 Suspended · , ) ') ( PHILLIPS PETROLEUM DAILY REPORT SUMMARY PAGE: 1 WELL:North Cook Inlet unit No. A-l0 RIG:Pool Arctic Alaska/Pool Arctic Alaska FIELD:COOK INLET NORTH AFE#:P-V129 CNTY/STATE:TYONEK OFFSHORE/ALASKA AUTH COST:$827,OOO DATE DEPTH RPT NO MW OPERATIONS SUMMARY DAILY COST CUM COST ------------------------------------------------------------------------------------------------------------------------- ------------------------------------------------------------------------------------------------------------------------- EVENT TYPE:Workover 09/24/94 8,228 8.5 SKID RIG FROM LEG 3 TO LEG 2.HooK UP UTILITIES.POSITION PIPE $37,566 $37,566 RACK, INSTALL BEAVER SLIDE, HAND RAILS & RELATED EQUIPMENT. 09/25/94 8,228 2 8.5 R/U ON A-10.PULL SCSSV.SET PX PLUG & PRONG 24886.SET SCSSV. $31,092 $68,658 FILL TBG.SET BPV.N/D TREE & N/U & TEST BOPS. 09/26/94 8,228 3 8.5 PULL BPV,SSSV,& PX PRONG/PLUG. FILL TBG & ANNULUS W/160 BBLS. $43,446 $112,104 P/U TBG ABOVE SEAL DIVIDER.CIRC OUT PACKER FLUID.TOH W/TBG. TlH.RET RATCH LATCH.CBU.TOH.TlH.UNSEAT PKR.CIRC OUT GAS.TOH. 09/27/94 8,228 4 8.5 TOH.L/D PKR & TAILPIPE.e22 BENT JTS).BIT,SCRAPER TO 6700.TlH $45,490 $157,594 & SET EZSV Q6619.TOH.P/U & RUN PACKER ASS #1.R/U W/L & CORRELATE DEPTH.SET PACKER TOP AT 5846.TUBING TAIL ~ 6552. 09/28/94 8,228 5 8.5 RIH WITH & SET PACKER ASSEMBLIES # 2, # 3, # 4. RIH WITH $33,417 $191,011 PKR ASSEMBLY # 5 AT REPORT TIME. 09/29/94 8,228 6 8.5 RUN & SET PACKER ASSEMBLIES # 5, # 6, & PRODUCTION ASSEMBLY/ $38,938 $229,948 RUN SSSV/SPACED OUT/PUMPED PACKER fLUID/PULLED SSSV/RUN PLUG TO TEST SSSV 09/30/94 8,228 7 8.5 FINISH SETTING & TESTING SSSV/ND BOpIS/NU & TEST TREE/PULL $207,220 $437,168 PLUG/RD WL/RU COIL TBG/RIH WITH COIL TBG JETTING IN WELL WITH N ITROGEN/ 10/01/94 8,228 8 0.0 FINISH JETTING IN & FLOW TESTING WELL/LOADED TBG WITH N2/ $65,748 $502,916 RIG DOWN & LOAD OUT TEST EQUIPMENT/LAY DOWN DP FROM DERRICK 10/02/94 8,228 9 0.0 LD DRILLPIPE/OFFLOAO ON BOAT/REELEASE RIG 1200 HRS 10/01/94 $49,826 $552,742 ****RELEASED RIG TO DEMOBILIZATION**** 10/19/94 8,228 10 0.0 RU TEST EQUIPMENT & COIL TBG TO JET IN WELL $28,034 $580,776 10/21/94 8,228 11 0.0 RU TEST EQUIP/OPEN WELL DIED/RU COIL TBG TlH JETTING OUT WTR $35,123 $615,899 & SAND/POOH/CHECK FO~ WASHOUTS MAKE REPAIRS/SION 10/22/94 8,228 12 0.0 PRES TEST LINES/SITP 125# BLEED OFF GAS/TIH W/COIL TBG JET $38,146 $654,045 TOTAL 414 BBLS/PooH RD COIL TBG/RU SLICKLINE/TIH PULL SSSV GUAGE RING RUN SET ~25001 POOH/SO FOR NIGHT 10/23/94 8,228 13 0.0 RD WL/RU HOWCO PUMP LOAD TBG W/39 BBLS PRES INC TBG PLUG $37,569 $691,614 TIH W/COIL TBG CLEANOUT TBG/TIH W/WL SET DOWN 240831 POOH WL/SION 10/24/94 8,228 14 0.0 LOAD TBG W/WTR/ATTEMPTING WORK BAILER DOWN THRU TBG/RD WIRE $30,120 $721,734 LINE/RU COIL TBG CLEANOUT THRU END OF TBG/SPOT VISCOUS PILL IN TBG/TIH Wl ATTEMPT SET PLUG FAIL TO GET DOWN/POOH 10/25/94 8,228 15 0.0 RU WIRELINE RUN VARIOUS TOOLS IN ATTEMPT TO GO THRU TBG SEAL $42,725 $764,459 DIVIDER a4790'/IMPRESSION BLOCK INDICATES TOP OF TBG DAMAGED SION 10/26/94 8,228 16 0.0 RU WL TlH W/3.75" TAPERED MILL TO 4790 FOR GUAGE RUN/POOH $32,429 $796,888 RD WL/RU COIL TBG TIH W/3.75" MILL+DRLG MOTOR/DRESS OFF TBG SEAL DIVIDERa4790/PooH RD/RU WL TIH CHECK SLIDING SLEEVES 10/27/94 8,228 17 0.0 TIH W/COIL TBG JET IN WELL/FLOW TESTING WELL STARTED MAKING $31,501 $828,389 MUD & WASHED OUT FLOWLINE/PUMP 150BBLS DOWN TBG/RU WL TIH SET PLUG IN SLEEVE @6008 10/28/94 8,228 18 0.0 LOAD TBG W/100 BBLS W/O#/RU WL TIH FIND DRLG MUD TO 5778 $28,163 $856,552 SET PLUG IN SLEEVE .5534/TEST PLUG TO 1000#/OPEN SLEEVE .CI ZONES 1,2,3,4/PooH RD WIRELINE 10/29/94 8,228 19 0.0 OPEN WELL FAIL TO FLOW/RU COIL TBG JET IN WELL/WELL FLOWING $10,863 $867,415 SI INSTALL SSSV/OPEN WELL TO FLOW/TURN INTO PRODUCTION DAYSUM.RP1 12/07/94 REGEIVED JAW 2 7 19S;~ Alaska on & Ga~ Cnn~.r.nmmission ^~n:::~'~;,~'; :¡¡If 1:1 · m "" æE ~ ilJ ; : ,; ~,¡:.:i.~.!:,.1 ;::::B2 ::::: ! III ~I ::=~) o 4833' I c_ ,"'.. ...... .,~ :d ::::: Jill! ¡¡¡¡¡ - ~ I'""~ 1 ¡,¡.:¡.:II_ -Ii packer@5243 .- I ~ I I : ~:~ ~ ~,[.¡.L.I.¡ .~ ~ f ~~~~;:c~ ~ .. 5587 - 5602 CI-8 I'~~ '" _-~18 c~ i¡j- _I packer @ 5637 ..;¡:~ I ~ !j¡j _ m " 5650 - 5651 (lqz) ~j~ "XC" ~ =m 5877 - 5702 CI-9 ;i;i) :m .. 5702 - 5723 CI-9 ~:¡: I I E¡~ ~¡¡¡_ ,packer @ 5737 I'~~ ~: :=::: ~:~ :.::. I ] " 5814 - 5815 (sqz) I~- .. packer @ 5846 ::::: J~:~ ]1jjj @ Beluga Sande :::¡: =m " 5912 - 5913 (sqz) ¡jjj¡ ]I ::::: =m .. ¡¡m ]I .. ~::: _ =m "XA" 0000 ]I .. ::::: - =m ::::: " ::::: ~ :::¡¡ =m ::::: ]I ::::: =m ::::: ]I .. ::::: =m .. =m ¡.:·.~,:1.:¡:¡¡.¡ ]I =m" ::::: ]I .. 1¡.::.i:.¡:.¡ =m ]I =m ]I .. 7463 - 7466 =m ]I =m EZSV Q 6619' TD = 8.250' 4890 . 4990 5008 - 5088 5111·5151 5163 - 5193 5933 - 5937 5942 . 5944 5949 - 5959 6055 - 6088 6129·6139 6158 - 6163 6181 - 6186 6210 - 6225 6228 - 6234 6272 - 6275 6424 - 6430 6462 - 6477 6508 - 6548 6694 - 6716 6755 - 6765 6919 - 6926 7030 - 7050 7085 - 7090 7224 - 7234 7294 . 7296 7329 - 7339 7361·7366 7541·7547 7628 . 7668 .. 7762 - 7765 7" @ 8228' I FINAL WELL COMPL TION DIAGRAM ~.pV(M.ke, Type,OD) FMC OCT \..,) Tbg.Hgr.(Make,Type) FMC TC-IA 4 111" 8n1 X 4 lI.1" BT&C Annulus Fluid: 8.5 Ib/gal completion Ruid with 30 0/0 methanol TOC: 2,780' from CBL dated 4/12nO WATER DEPTII: 120' . '>ODk><'tô¡:« <1?>SøûOííf:{ '::/W1\':::J<:Giáciéf{:?J??:ø>'u.t?:::) ::'::::);l\.\1'''(::::: Production Casing: 41 366 41 631 41 2, 782 45.5 & 511b/ft 39 70 26 Ib/ft 70 6,158 23 lblft 6,858 8,221 26lb/ft rubing Strin : 4 112" 39 311 12.60 lb/ft J-55 Mod BT&C 4730 4980 135 4 1/2" 311 6,550 12.75Ib/ft J-55 Mod EUE 8rd 4730 4910 134 ,'.. "·<NØ;:::..·:·:··:Jöjt:.:·:::. }):~ngtW:>¡:: .. :···\.·::¡>~riP~«:¡:::::'::··· ....-.::..........:..........:........:. < {In}:::{< ¡:¡:.:::::OD'::=::': PRODUCTION TUBING STRING RKB-Drill Deck: RKB-11IF: 39.40 RKB-SL : 116.00 RKB-ML : :::::?:Ø?tF:?? : ?rrømn:::: 30" 16 " 10 3/4 " 7" 7" 7" J-55 J-55 J-55 J-55 BT&C BT&C BT&C BT&C 3350 4660 4010 4660 1970 4080 3080 4080 531 327 288 327 CI-1 CI-2 CI-3 CI-4 44 ..().OO 38.90 Elevation 43 38.90 0.66 FMC' OCT 6" 3M 4 112" 8rd x 4 112" BT&C Tubing Hanger 3.958 6.000 42 39.56 239.53 4 l/2" 12.6Ib/ft J-55 Mod BT&C Tubing 3.958 5.563 41 279.09 2.46 Otis 4 1/2" SCSSV Landing Nipple 3.813 5.566 40 28l.S5 29.21 4 1/2" 12.6 lb/ft J-55 Mod BT &C Tubing 3.958 5.563 39 310.76 0.75 X-Over 41/2"BT&Cto41/2"ModEUE8rd 3.953 4.919 38 31l.S1 4471.96 4 1/2" 12.6Ib/ft J·55 Mod EUE Ird Tubing 3.951 5.563 37 4783.47 1.44 Ha1liburton "X" Landing Nipple 3.813 4.998 36 4784.91 35.03 41/2" 12.61b/ft J·55 Mod EUE 8rd Tubing 3.958 5.563 35 4819.94 12.26 Ha1liburton Tubing Seal Divider 3.958 5.969 34 4832.20 1.12 Otis Ratch-Latch Seal Unit 3.955 5.627 33 4833.32 6.48 Otis "VSR" Hydraulic Set Retrievable Packer 3.880 5.982 32 4839.80 33.07 4 112" 12.6Ib/ft J-55 Mod EUE 8rd Tubing 3.958 5.563 31 4872.87 1.44 HallibW10n "X" Landing Nipple 3.813 4.998 30 4874.31 333.50 4 1/2" 12.61b/ft J-55 Mod EUE 8rd Tubing 3.958 5.563 29 5207.81 4.22 Halliburton 4 1/2" "XD" Sliding Sleeve 3.813 5.475 28 5212.03 30.12 4 1/2" 12.6Ib/ft J-55 Mod EUE 8rd Tubing 3.958 5.563 27 5242.15 1.12 HallibW10n "No-Go" Seal Unit 3.900 4.000 26 5243.27 11.24 Halliburton "A WR" Permanent Packer & Tbg. Adapter 3.880 5.982 25 5254.51 279.97 41/2" 12.6Ib/ft J-55 Mod EUE 8rd Tubing 3.958 5.563 24 5534.48 4.22 HallibW10n 4 1/2" "XD" Sliding Sleeve 3.813 5.475 23 5538.70 31.26 4 1/2" 12.61blft J-55 Mod EUE 8rd Tubing 3.951 5.563 22 5569.96 1.12 Ha1liburton "No-Go" Seal Unit 3.900 4.000 21 5571.08 12.37 Ha1liburton "A WR" Pennanent Packer & Tbg. Adapter 3.880 5.982 20 5583.45 38.46 4 l/2" 12.6Ib/ft J-55 Mod EUE 8rd Tubing 3.958 5.563 19 5621.91 4.22 Halliburton 4 112" "XD" Sliding Sleeve 3.813 5.475 18 5626.13 8.26 4 l/2" 12.6Ib/ft J-55 Mod EUE 8rd Tubing 3.958 5.563 17 5634.39 2.12 Halliburton "No-Go" Seal Unit 3.900 4.000 16 5636.51 11.30 HallibW10n "A WR" Pennanent Packer & Tbg. Adapter 3.880 5.982 15 5647.81 77.26 41/2" 12.6Ib/ft J·55 Mod EUE 8rd Tubing 3.958 5.563 14 5725.07 4.22 HallibW10n 4 112" "XD" Sliding Sleeve 3.813 5.475 13 5729.29 6.11 4 1/2" 12.6Ib/ft J-55 Mod EUE 8rd Tubing 3.958 5.563 12 5735.40 1.12 Ha1liburton "No-Go" Seal Unit 3.900 4.000 11 5736.52 11.29 Halliburton "A WR" Permanent Packer & Tbg. Adapter 3.810 5.982 10 5747.81 61.90 4 1/2" 12.6Ib/ft J-55 Mod EUE 8rd Tubing 3.958 5.563 9 5809.71 4.22 HallibW10n 4 1/2" "XD" Sliding Sleeve 3.813 5.475 8 5813.93 30.95 4 1/2" 12.6Ib/ft J-55 Mod EUE 8rd Tubing 3.958 5.563 7 5844.88 1.12 Ha1liburton "No-Go" Seal Unit 3.900 4.000 6 5846.00 11.29 Halliburton "A WR" Pennanent Packer & Tbg. Adapter 3.880 5.982 5 5857.29 151.35 4 1/2" 12.61blft J-55 Mod EUE 8rd Tubing 3.958 5.563 4 6008.64 4.18 HallibW10n 4 l/2" "X A" Sliding Sleeve 3.113 5.475 3 6012.82 537.14 4 1/2" 12.61b/ft J-55 Mod EUE 8rd Tubing 3.958 5.563 2 6549.96 l.S0 Halliburton 4 1/2" "XN" Nipple 3.725 5.563 I 6551.46 0.88 Re-Entry Guide 3.99 5.56 6552.34 End of Tubing PRODUCTION PERFORATION INTERVALS COOK INLET SANDS BELUGA SANDS .. *"* 4815 - 4816 Block Squeezed CI-1 4890 - 4990 CI-2 5008 - 5088 CI-3 5111-5151 CI-4 5163 . 5193 CI-5 5270 - 5280 CI-5 5313 - 5318 CI-5 5324 - 5327 CI-5 5337 - 5343 CI-5 5352 - 5355 CI-5 5360 - 5365 CI-6 5392 - 5417 *"* 5482 - 5483 Block Squeezed *"" 5557 - 5558 Block Squeezed CI-8 5587 - 5602 CI-8 5608 - 5618 *,," 5650 - 5651 Block Squeezed CI-9 5677 - 5702 CI-9 5702 - 5723 CI-10 5744 - 5756 CI-11 5800 - 5810 *** 5814 - 5815 Block Squeezed *** 5912 - 5913 Block SqueeZed .. New Perforations c· "gj ~I "š¡: ei o:!c 0; 0) 't. g'~!' Q¡sæ: VJ~ (tJ "'=.'U' .! Ø'!!;¡; I ~:fJ¡ ãi" ~ ;¡ --;:. "Upper" .. 5933 - 5937 5942 - 5944 5949 - 5959 6055 - 6088 6129 - 6139 6158 - 6163 6181 - 6186 6210 - 6225 6228 - 6234 6272 - 6275 ~.j <[ 1 '"'7i .. ~ LU >: 1.(') Cfì ~ .. -' î- ." u.;J ~, ~ ~ ~.¡¡ .. .. .. .. ·Middle" 6424 - 6430 6462 - 6477 .. 6508 - 6548 6694 - 6716 6755 - 6765 6919 - 6926 7030 - 7050 7085 - 7090 7224 - 7234 7294 - 7296 7329 - 7339 Perfs below isolated with cmp .. .. .. .. .. 7361 - 7366 7463 - 7466 .. .. "Lower" .. 7541 - 7547 7628 - 7668 7762 - 7765 PBTD: 6,619' Supv: WeD: North Cook Inlet Unit No. A-tO Location: Lower Cook Inlet, Alaska IThgWt: 41/2" - 12.6 & 12.75 lb/ft I Nowm~I~I994 Field: Cook Inlet Unit MPG S;P-2Ø~1994 16:47 FROM '~F'H I LL I PS DR I LL I ~~G ) TO 89072767542 P.0Øl/0Ø8 ~ ') ) ,. , , PHILLIPS PETROLEUM COMPANY P.O. Box 1967 Houston~ Texas 77251..1967 6330 West Loop South Bell.ire, Texas 77401 Nurd. Amodco E&P Septernbei" 20. 1994 North Cook Inlet Unit A·10 Permit NUt 69-88 TO: Mr. Blair WOnd2GII State of Alaska on 4'ntl Gas Conservation Commission 0 R I G I N A' L Fax No. 907·276·7542 FROM: Paul R. Dean Philips Petraleum Co. (713) 659·3b02 (713) 669·3754 (fax) As pel' our oonversation of Friday, Sept. 16, 1994. enclosed Î$ a. r:opy of the letter reQuest for the upcoming re-work proposed for the North Cook Inlet Unit No. A.. 1 O. The original letter will be sent via OVArnight mall tDday. n will make a note on it that it has been faxed as of this date). If the program meets your requirements and is approved, please Fax a COpy of the apøtoved Permit to my attention at the Fax number stated above. Your assistance in this matter will be appreciated. ReOê'rd~. Paul R. Dean OR\G\NAL RECEIVED SEP 20 1994 . SS\\J\' Alaska Oil & Gas \"ons. liun\\1\\ Anchorage SEP-20-1994 16:47 FROM rHILLIPS DRILLING ) TO 89072767542 P.002/00S ) . PHILLIPS PETROLEUM COMPANY ~ HOUSTON, TEXAS 77251·1967 BOX 1967 NORTH AMERICA EXPLORATION AND PRODUCTION BELLAIRE, TEXAS 6330 WEST lOOP SOUTH PHILLIPS BUILDING September 19. 1994 North Cook Inlet Unit "A~10" Phillips Tyonek Platform" A" North Cook Inlet, Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: North Cook Inlet Unit A- 10 Workover Program Attached are three copies of the Application for Sundry Approvals, form 10-403, and three copies of the tentative workover program for the workover of the A-10 well on the North Cook Inlet Unit. Included in the program are the BOP sChematic and the well control policy for the workover. If you have any questions concerning this workover or need any additional information please contact Paul R. Dean at (713) 669-3502. Regards, ¿tþ D. C.' Gill, Manager Drilling and Production Engineering cc (w/enc): J. A. Landrum J. W. Konst (r) P. R.~ J. F. Mitchell 'Ð Central files RECE\VE() SEP 20 1994 Alaska Oil & Gas l.Jons. I.JVil\Hì\SSIV\' Anchorage SFP- 20-1994 16: 4 7 FRO~1 ',' ''!I'?H), I LL I PS DR I LL I NG 1"w;l8-'?# ~#~ .;(7~C71.3J ¿¿9"··..3óð:¿ STATE OF ALASKA ~ /e' -~~ ~~¿ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION /I-~31 /I-:ð"";:a. 98<~¿99 LIGATION FOR SUNDRY APPROVALS ~~~ TO 89072767542 P.003/00S ) Q AbGI1d9n _ G~o~"d _ Operation Ðhytclown _ AQQntol' êucpondod W.II _ Altlilr C~u¡jn9 _RèpalrWell_Plugging __ Time Exten8ion_ Stlmulate_ Cha., 0 A rovoC; Pro rAm)( F"yll Tybin X Vl lr¡*n~è rerforate Othor X 5. Type of Well 6. Datum elevation (OF or RKB) Phllli Petroleum Oe. Oevelopment_X nl<S 1'6 Feet S. Address: Exploratory ........... 7. Unit or Propenv Name 6330 W. LOOp SOUÜ1 Stratigraphic _ North Cook Inlet Unit Bellaire Te (8S 77401 Service 4. Looi:itJon of wvll illt :,:;u,f~w; Leg 2, Slot e PPCo. Tyonek Platform 1304' FNL & 1023' FWL Sec 6 - T11N - R9W North Cook Inlet, Ak. At tV J or productive intervaL 4890' MD G08S' TV!:) 812' FSL & 2425' FWL Sec31 - T12N - R09W At "rrf¡tr,.;livtllJliilpth; 4890' MD 3889' TVD 812' FSL & 2425' FWL $eo 31 - T12N - R09W At totj:j depth: 8250' MO 8240' TVD 2505' FSl & 4115' FWL Sec 31 - T12N - A09W 1 Z. Present well condition t:iurnrl1i:l.ry: Total Depth: measured 8,183 feet true vertical 6,194 feet ~ 8. Well Number A-10 9. I"'ermlt Number I Approval Numbør 69....88 10. API Number 50-883....20030 11, Field I pooj Cook Inlèt Belu a Plugs (measured) PBTD: 7,429' EffeCtiVe Deptn: measured 4,890 fel:lt Junk (rntl.~ull:lu) true vertieal 3,889 feet Casing: Length Size Cemented Measured Depth True Vertical Depth StrUCtural 30 II Dr IVtUl 388 3E30 Conductor 16 II 610 sx o "G" 631 631 Surface to 3/4" 737 t:iX 01 "G" 2,782 2,018 I ntermed ¡ate foI roo UCtlOn 7" 1210 ax CI"G" 8,228 8,225 Liner RECEIVED Perforation Depth: measured 4890' - 7668' true vertical 3905' - 5858' Tubing (sizEI, grade and measured depth) 4 1/211 12.60 Ib)ft J-5S Mod BT&C Packers and SSSV ( type and measured depth) Oil Gas..x Suspended _ Name of A rOYer Date A rOWld Service 17. I hereby certify that the fcreilolng IS true and correct to the þest or my knowledge: D.C. Gill Title Drl. & Proo. ~n r. Mana er FOR COMMISSION use ONLY Conditions of Approval: Notify Commission SO RepresentatIve may witness Plug Intègrity .......-- BOP Test ~ Location Clearance Mechanical Integrity Test _ Subsequent Form Required 10 - H0'1 Origìnal Signed By David W. Johnston Commissioner Date 1'(?- 3/~ SUBMIT IN TRtPUCATE Approved Copy Returned 9 .- 2.. C. ~ ? C( ~ SEP-20-1994 16:48 FROM i?HILLIPS DRILLING !") TO 89072767542 P.004/008 ) September 19, 1994 Houston, Texas North Cook Inlet unit '1AIt-10 North Cook Inlet Unit Tyonek County, Alaska Tentative Procedure 1. Skid rig OVA,... WAll Nö.. 10 ~lot. in LeI] 2. Kill well with 8.5 Ib/gal KCl water I XanVis polymer. Fill tubing and annulus with 2 , kcl wa~~r. Bl@~d off pressures and monitor same. Close SSSV¿ 2. Install 8PV, remove XMAS tree, NU and test 13 5/8" 10M BOP equipment. utilize a 16 3/4" 5M x 13 5/8" 10M DSA. Test the BOP equipment as per t.he attached "Well Control" program. 3. Rig up to pull tubinq. RélQa~Q ~éals from Halliburton Ratoh-A-Latch Seal Assembly. Pull 4 1/2" tUbing, SSSV and seal assembly. TIH with rQ't:.rioving tool and 1:'àOOVer the Halliburton "VSR" retrievable packa:r at 4,847 i and tailpipe. circulate out any gas from below the packér. 4 _ TIH with 6 l/S" bit and casinq scraper for 7 it 23 and 26 lb/ft casinq_ Cloan out oacing to a minimum of 6,700t (P8TD ic 8,183t). Ciroulate hole clean and POOH. 5. TIM with EZSV cement retainer and set same at 6,600t to isolate the lcwér Bélu9a pe~fo~ationa (6,694' - 7,76St). (j. TIII with permanent packer assemblies as outlined on the "Propoøeà Well Completion Diagram". Set packer isolation asse1'l1blies at 5,850', 5,730', 5,635', 5,570', and 5,230'. Get Halliburton 7" retrievable "VSR" packer at 4,847'. 7. Make up Halliburton paoker seal assembly onto the 4 1/2" tubing. TIH with 4 1/2" tubins l1nd SCSSV landing nipple. Lelnå seal a5sembly into isolation packer. Test annulus, then pullout of seal assembly and (,;l.r;uulåL~ 70/30 mathò.nol I RCl packer fluid into annulus. Space out tubing. S. Close SCSSV, install BPV, ND BOP equipment and NU and test 7 1/16" x 4 1/2" xmas Tree. Remove BPV·s. ~. use coiled tUb1nq (it necessary) and nitrogen to lower fluld l~vl;)l ëtUd get well kicked off. Unload well and allow clean up through the proãuction testing equipment. Release workover rig to next well. NOTE: BHP at 3880 TVD is approx 1400 psi (7.0 lb/gal equivalent), sorne~hat less than the 8.~ lb/qal equivalent Wh1cn will Þe used to kill the well during the recompletion phase. RECEIVED SEP 20 1994 Alaska Od & Gas LaOS. Lülì\fIll5Slu' I Anchorage SEP-20-1994 16:49 FROM ~HILLIPS DRILLING i~) TO 89072767542 P.005/008 ) SECTION A WELL CONTROL PROCEDURES This well is a category 3 well, as defined in Phillips Completion Workover and Woll control polioy~ As èuoh two ba~~ièro muat bo in plaoo during nipple up and nipple down operations. For all other operations, two barriers, e.q. the BO~ts, fluid oolumn, eto. must be in plaoe in order to conduct simultaneous operations. The BOP equipment is 10000 psi WP Class 4 as per Phillips Well control manual. The bottom set of rams should be ~ 1/2" pipe ra'lltS, the tniddlè set ~ill be blind rams and the top set should be variable rams. Although the BOP is rateå to 10000 psi, the ri~er ~nd the wellhead are rated to ~ooo psi. The BOP and choke manifold should be stump tested to 3000 psi. The BOP tdl\)~lù bt;: L.~tiLf;1d tv 3000 !J~i upun nippla up ànd to 1500 psi on a weekly basis. The Alaska Oil and Gas Conservation Commission (AOGCC) should be notit1ed prior to conductinq BOP tests. The nQt¡f¡ç~t¡cn tu AOGCC should be made early enouqh for them to witness the test if they desire. The maximum surface pressure for the well is 1090 psi. This pressure was obtained during the BHP testing in June, 1994. The well Ci:i11 ,be killaå and stability maintained ~ith 8.5 Ih/gal fluid. Well control drills are to be conducted with each crew as per Phillips well control manual. Drills shoulð be reported on the IAPC daily drilling report and on Phillips Daily Drilling Report. This well produces from a series of very permeable sands. A small decrease in pressure at the perforations can result in very large flowrates. It is vital that good 'Well control practices be followed during the course of this workoVer. Trip spee~ wnile POOH should be kept relatively slow to avoid any tendency to swaD. Before any trip is made swab and surge calculations should be made based on the properties of the flUid in the hole. DO NOT exceed the running speed determined by the caloulations. A detailed trip book comparinq measured fill up requirements to the calculated requirements should be maintained for each trip. The cause for any discrepency between the actual and required fill up volume must be determined before cont.inuing with the trip, XAIN'rAI!lIIlG CONTROL OF THE WILL IS OF THE UPMOST IMPORTANCE, TRIP SPEED IS SECONDARY. There are 43 perforated intervals below the Halliburton uVSR" packer that are effectively commingled at the present time anã cannot be isolateã. All of the zones presently perforated in this well can be killeã with water. As a precautionary measure, a line should be ran from the annulus valves on the tUbing head to supply workover fluid, drillwater, or seawater. This line can be used to supply workover fluid as discussed above or as a last resort can be used to kill the well with drillwater or seawater. pu~ping drillwater or seawater through the annulus valves should be considered only in an emerqency situation as these fluids could result in formation damaqe. RECEIVED SEP 20 1994 ~/llkl 011 \\ Gas ÍJons. (,iornmISS\(JII Anchorage SEP-20-1994 16:49 FROM . - RHILLIPS DRILLING '~~") TO 89072767542 P.006/008 ) NCIU A·10 RISER AND BOP ARRANGEMENT 5M ANNULAR PREVENTER 10M VARIABLE BORE PIPE RAMS 10M BLIND RAMS DRILLING SPOOL 3 1/2- 10M PIPE RAMS RISER 13 5/811 10M X 13 5/811 5M ADAPTER 13 5/8ft 8M X 18 3/411 SM CLAMP RISER 16 3/4H 5M X 183/411 5M ADAPTER 16 314M 5M CLAMP X r 3M TUBING HEAD 9" 3M X 11" 3M RECEIVED SEP 20 1994 A/,,_ Oil, . _, AGI8 l.Ions, (ic.nurnIS8I\,1i, nChOfaQø ". , SEP-2Ø-1994 16: 5Ø FROt'1 .... ~~ I ~: ~: I·:: .:: ~ 7 ~ , , 5 -i ·XIl,=,. " ,I I I ., , ' , , ~ . l ~ ' \ r 3 . I W f'elTO IIIN' H~ f Ø;j;W.'. ¡'~ì~\'~\ \i1~ ~ "i TO ... . 280' ~~~ · "I1I1!!i -41115 ¡~4<-) :m ~ :i .Jj¡ :J! ~ _Ii ::u ~ .: ::,.~- II · .~~~7 - !!1I!'I1I <""II) ! :::JI ¡-'~"~-..- ..1l w. ::¡:¡O7' - ;01)£ -¡¡ .W &BOt llie1. ïI 001 ~"'!oI.' - 0:1....1· r~'17) :s .J~ ~Q1i' - ;702 :JI .. 1700 1i7:!1 :II .. 1S7.... &7'&8 ..!Vi .. !IIIOD - ;110 j:.tX. .!: .. "&1)1.. ... &ð11i (~J !II $Ih~ -IiO'~ (..qItJ "'"hl~jI¡,,"l!.. :E ...Ii ~ :œ ::m: :N ..¡ j ...I! ~A - 1'\1.\iI :D .. "'17; - /\¡>"r.! j i ß1 ]I 'ï"'i'õV OM' !. ~ , í. , ~ ·1 , , ¡ ¡ ¡ TM G "FIn' T....¡"II Caal DividDr 1111 "I\.~d· Oil ~ ·\lon· .I(Iç k.r @ 4&47' (lMI¡ Inl.' o...l¡ f -40;0 - '111\1)0 ~Ot;l4l"Rn IiH 1 fit51 !'11ft;, -!'III!;' !'I;TO - !l.'PlO ... ~o,o - .!!Ð'~ .. nå~ - U~~· ** 6337 &348 .. !Io3:IJI! - ::I~:!:! .. !lUG - .!J:!III:j ::;&:)o-::;&:)j' &04:J 6~ :¡"~-;r.l1I ""'IM .. \fIM "'~-1I1:\ Ot~ - "'00 "'1 .- $'~ e~10 iC!œ ''I:¡1 ... 81:M;1 $4M: .. &471 h....... -/l."IIUI ."..,.. _I\TII'\ 07::¡::i - 070:1 SOlD 600i 7000 - ,* Tnft!! - TQIIQ n¡lIÓ-T~ n:"4 - '* 7UO - ~* 7Q~' - ,. "''' 7M.." _ r.-w. 7&41 7U' 1020 - 7aGO 771\> - 774111 I· (!!J ~J' ' PHILLIPS DRILLII-IG TO 89072767542 P.OO7/0ØS WELL COMP' "FMÇ OCT FMC J-$$ ~...i.s )-$~ .1-"P' 1'-;0 .......·m 4Wi,i .. ..··..·:'iii ;::IW(.f ¡¡:~ 4Mó ""', BT4C ,lI,tA!...: 8')' .!kG 'RTA.~ ?? 21 . .. '~iJ i9 ",··'··.......11:1 17 16 1~ 11 1'\ 12 U 1~ I f\ 7. 6' $' l' ~. -'~lÌõo ~. M) j9,S4i 296.26 29ft 72 g3?43 .i;¿K. JfI -183199 4A4fL~~ ....iÃ41.oo "... 4~$2.ZI 4855.8.4 "188tj,;1~ .. .... 4M?!!'> 5071.21 5()1S~9 , sn2.i.2 5776:5J 791:\.71 791 S.:i? 1916.05 2 ~.........,... .......-.. \. I', , --................·"1...·..- I PP.ODUÇ'"IlQ II 'Ii~POR.A'tIÓN INTDR.VÁLS COOK INLET SANDS BELUGAShNPS **. 40U¡ .. -4j IS [ I....I~ E:/ >Mi<llllll!ld C~ . 1 4600 4000 (,:I-~ MM-!It 1I1I CI-¡) :)1 ¡ . ~1!l1 01 4 618a &103 CI-5 5270 - 5:280 \:'1 " &a1~ Ale ~I-' QU4 ..!lazt 1:1-' ~:!I,;,~~ CI IS 63fro AM CI-5 5360 - 5'95 CI 8 1:100· '~17 'UPJIOP" .... 5"33 -!õIiI!97 ';1:1 - Q~~ liW - :ïa::ill 00:;:; - GOOO st. - $1U ~1':111 . "1I~:1 !In' _Ij1 1 0I:1C11 - g¡:t$ ~ÌII-m::04 6272 - r.l75 'Mlrk'tl.' ~4òt4 .. ...~, ... ,0141. .. _ 81....." a.._~¡J !S6' . 15660 Dlool( eli_lOll ~ - 04" 0;\111 - ç$4Q IIII~ -11'11 111..... - II It«... ~~, ~ _ ÞlW..¡M 70aa 7060 701& 7000 122. - 7234 ;: : ;:: AI.. (hI , Gi nel 7.8' A 741J.'!- . '4AJiI o 1994 01 . 01-1 IN? - "QII :iDOB - ;010 ... 6110 ".' ; 191' k Ç~.....d CI 0 t: w CI-,C CI 11 1877 - m:g M'Ct - Ii'~ liN4 - !i7jO &800 "'0 ., ðllM" ... &114 111" It KII! òIi ~ liel! - ::'8'3 DllÄok ::kIWoIez~ 73111 _ J(I&1 18:!8 7811 77t:! 7711 N~w Perfor tions WI: iéld! eMk Inlet link PRD SEP-20-1994 16:51 FROI'II I' I I ) I ~ , 'II> , : Sl:i6 I:. I OOi I' , '-tBl.¡ t} ~ F~~· ;. ..l.-L :' '........- I --. OX' 52JO - "'Ii 'r~ - ~ 'XD'.!!!IRQ.. llii I' r-l 1'-- I~ f ~ , ~ ~.'\ ~ !:~ 1i :·1 ,¡ ~ ~ ~ ii '¡¡ r-ì ~ .~ .~:_. .-: . . 'XP' .!!æ.. 5570 5b37 ~-7 }c:) 58>?::> f--- 'XI:)' IUUW .: ~ , \ ~ (, ~, I11III1I0Il ClIP j b'WW roTlJ 61e:r Tn _ III !OII""" 10 '3/4" @ 2782 TO¡; @ r.!/W' TllbJna ~I Olvtœr B4U4· *4ðHJ - 4010 (:l.q1) n,r~ 'VM' 'IIIr.'" 'lI/411"1" C/jlll~ 1" 1fI1t1'U\~9 4I!CIC 400{¡ CI j 5e.)l .. t.at!o, QI-£ $\1 j - ;1~1 ¢j-Q :;1 aa - :;183 OH rli4l'.kt1tr ~ ~'YI ,\,)7(1 ... /I) A" .·.b..~ o. !>'' 1;.s-~:n~ I::~_~ .. !I:I¡ 4 - !:I:I:.If r.:1-!:I n 1!1.i13'1' '~3 ÇI . .. 5361! 1i361i CI Ii .. $;lOg - *$ ~-$ :¡ge~ - ~f7 OI-g · :;.¡et - c.qa (.~..¡ .. !R'IIIT - :'I~/I ("'I'¡ 1'òll:Þ.It, 0 ."",TO .. 11111117 - _II ~,-. .. 56011 ii1S CI ø ... 5033 lOCI'/' .. ~.. 41W4 :llM9 - ~ - 000:; - OOÐG S1Ü - elM III!\II-tlltI;\ "'.AI.AIM ~1IJ - Itf"'" 11".-.01 - 4I:ÞI .. e:!72 . WO 9*t - V'IDÔ (MOE - 0477 OOOI!I - 0:..8 .-m 1: ~ "11 ::B ::J... ...ü J;t ~ _-/\1111 "'7M _ A~'\ 11111111-W..... I /rjJfJ - f'h'J I ,. /1M! - IIIW I .. 7.DoI - 1Ð11 7:!004 .. 7:lIi r,¡œ 7a3O 1001 - 7OCIO ... T4IIi1 . t4ei .. .. 1"'" .71'<1.7 rt-:ð' - )...... : .. ,'rs;;. - ff~ 7" {W 112æ' PHILLIPS DRILLING TO 89072767542 P,008,'OO8 PROPOSED WELL COM~TION DIAGRAM np'v, Willi 1.'1'vP.!...UU} . ...~.¡¡i:i OCT _... '.1 RIm-n.1I1 T.'å!\"': J:.I!~.{MAII:C l'yoa=\ I:M~ TC- tit "iT!:&·ø..1 X" If).· ~'r"' RIO.'I"THfI "'.40 A'i.i.-..a;J.'lu;,I. ~.ql coan:tlc.tion 'lid.! ..¡Lt. ~... llar-Ihoul IlU-ilL: LLð.OO :::;~~~;gb::.;..: r::~~~o~~~' ~~~~~;~~:::r~;;.iZ:ål~: ::::r.t·¡:'¡;"';::.::.ilr,.~;\~~:~~~~.~~Jí:ç~·f, ::~;~;tJWt.~¡¡:; ... ~: -'--~r ~~ __...... . ... ........ -.... .. I ~~.t;.... 41 2, 7&:2 45.S &£ SI lb/ii J- 5~ BT ~ .... ....... J~:t\) 7· ~ 7O'¡1j IbIn J-55 DT&C 1bOU 7" 10 ........~.t!IS8 331Þ1fi ... ·j·=Šš· H'!~ 4UW 7" Q.Uts liI;.rjls ilQ RlIlt J-~!I I HT&C 4ð6IJ Il"lIbt". lit.., ..' .1 4 liP Wi . ,....:~ l:it,{ ) Ibtl\ J S5 I Mod I3T a:C 47.10 oI9At'I 1:'\': ...,,,..~ 3Z1!.. 65.50 12.7Slblfa J-55 I Mu, !'t"'"rll .4f.V1 ___ ~ ¡ ~ ~,::¡'¡:~¡:::.::.~ : .. ~ ::::l¡:::rð-ð~·:n:::::: :i " '::(::ëliirttr. ::,:::: ,.::'.. ",. . I,.:..,:" ~u d' .,1\ f)~..ir'ihn.. :', 'I: .:.:: ~ .. .:.:::.:. ~ ; "::":':': ~ D ':;:::'::,~ ~ c: :¡:::: ',::.. .. ;:,:i:¡: I,F:I:~... I .')0 ~ r,;oall¡ ~;. P"R.nJ')ul"1:.."{l~ 'rmUNA :rITR 'NO .... . . . 'VI , ··,··.._....~7 36 3' 31 jJ ...,. "''''''''-j[ ·n 3LI I 29 i 11847.00 S.on Oili. "VAR" "w!'.I..I;(,~t RrJI;"~,,I,k. "P""L.,. M' '"..¿~..Mo':-~'_' ?~...Mno 4 Y1.~ I" (, Il1l'l T-'ì'~ M,.I F.1.'f..IJ ",I T'I~III! 17 """ r. fi:,lIiI.Rll1i.'TI '''''.. Lam.jDII. tl (ltll~ ?~ 4314.on ''''.00 41n" t2.61Mt ]-S, Mud BtTE 8rd Tublnll. 'Ii ';?,tIII.(\I') .. on H¡IIIIi\I\'rC'.'" .tfl." "XD"SIi..IiDII.SIf'tw 24 52(1*.~_..........~Q¡.~...i.~::...1.~,~..IM.\..]7"~~..M~.;aµE &rd TlblDI 23 '221.00 i 2.00 "1lIlbunaD "No-Go" SCII Unit ¡ ." ," ':~; ",.. Si3i:1~ÒÜ"'" 'IU:oo' "~iïïJ~ÞW10ïï''';ÄWR'~'1)(;iTiaDóiiriiå-iko¡:ã 'fbl:. AdRDL '~I i>:.!AUlJU ~~lJIl 4 II.!" r..!.6Iho/1t J ..~~ I\A,," 1o'111oI.)lN! TUI"lII\,. .,.~......,,;; 'Y. ..,......a~.__.._.....t!m. J.ii.I!¡~~U<)· seal Unil 19 5570.00 lC.OO rIallibwtcn MAWR" rcrn"lneull'.,ier& Thl:!. Ad.1r..tJ 3.BBO 5.9112 1£1 ~!'oAn.oo 41.00 4 112" 1~.(, U"rIft :J-!l!: MI',d mmA,d TII ,:II~. ' :'1.9:"18 !I.!:/i."I 1'1 .O¡(o'-tM 4.00 ITllm"", 11111 .. 11!" "XT'I" :Cötl&li,",_ ~....~" :'-fn:'t :;.4"'-" 1ft W'ì'M II m 41~ t'Uilh/fl ,..H M.ul F.TlP.KII -rullir,1I. '\~"i.'I HIi' 15 '6S~.OO 2.00 liatllburl(' D MN...-G...·!4!1I1 trnll :UOO, 4.000 . I 10.00' ···H~ii¡¡:wïi··;;\w'/p_i¡;-.ñtP~~tr" n~, AœP;- UI() i---¡¡&¡ !"Il.OO ~ 1·"" 12.01tWlt J-SS Mod-ªJIi..!!g,.J..!.l!.in!:............... .... .... .. .1.~.! ~.~~~ ·too HIIU,bul'to1'l ·No·· tj". ~III Un,t . J.!.'OO I ~.wu ,.... ~ S l:' 7QIO-~ CJP 778£ - 11ØI ¡ .. Nl'w p",r.UI;',"1o "'''Ira 0/1 ~_ ~BTD: ',1&.1" ... 1511!IV: J 'nlll. WI' " In.· - 11.t'1t\ '2.'~ IMt "".~ V/ì" W..t ..lConÙ:oot ...1$1 U.h Mo. A.7" to I '9-~-94 A -. '!)n~' (.,(JUlf1JI:lSlvI ~t.d! .JeWer"'OQ ¡ ÙlJet. /\Jail¡¡¡ f'io:a 4: C~k taTet~lIlr .. ..:_'!!'IU t~øv nM ,*.fII) :ki.$iS -~jo m,i''} S);¡.·1J :.f~.lb 41ß:l'JlJ ~.u.."5 1'II't"'&.JJI ~!If:! Ell:'v;a li,.ID 0.66 ~r;'; I U'; I ~. ~M .., 1 1!:.."}1..~!I,,,1(:.1· ~.I M.: I utllng M¡;¡;;'"'' ,. 2~.7ó 4 1/2" I:!.I! Ib/fl J-5S MOI1 IIT4;Ç T\1\\iftA ~,"G Oils -1 L/~" SC:SSV Låtláint: NiøPli U,7l 1 if:!;' 1·3..Clla!t1 J-SS Mod 8·~·&.C hIUM' IJ.ïJ X-Uvor 4 11,¿'; ·ï;j~'j:¡L:ïã4 11"" Mad I-iUI-oI!I\II. 4M1.'>JI:J 4 It"'" IJ.f> Ibn't J 55 U,..4 :III.. ".... TubilU! 1:' 16 Job,l1iburt.,. .,...... 1'.1"':' 0.71; Uti.. Iht"h . Latdl Sc..,1 Unit '........'.,....L. r-- ,~ _. ~¡~ p.ac.kll'f@ jO:Jó ! m * II':'N,I - Mil I \"""1 I .Jt ....ff - ~'u;,¡ Çl-" ..... ..l.. æ·· ~'11<1 - ~r...:¡ WI-II ... I~ i'>~kC»' @ 4Io/.:N .~ n ~ ~... $i'+4-~r:;o ~-~~ ,)(D'io""" ~··5aOg-~10 ¢ -~. r ="-1 ]... I · !1ft ItIo - :'III I!! I"'I'~ _. . ~¡ p..d.... 0 ""-<'on ..m tI"ufA nll.:!t J *l1li1.:2 - 111111:> li"lllj "l». ~ :::m :JI :::m :J« ...æ I~ J ~ 3iLJ :]I 3 .. 11 u l:' 5(iJ i,OQ SI>1~.( ( Si:i~.UU 11 1(\ Q 3- 1 $1.'18.00 'I'I'4A.M '¡1\l4m 5318.00 ~U&.OO . .---ïjj]¡õ· ..i¡;\mb'ii'¡.~ñ··-¡rÂWR~ ~~~·;i;~t·~;\~k,;;;¡TbI:. AœDi4 (,(,.00 ¡ 41J2" 12,(, II....". :r-~!: MI·"Httm ß 'd Tllhh\9 4 no, H:llH1I1I1I '" 4 1/1.0 h~n· ~Hd:lI;:' :ltrr.vr: ---1. ~¡;oo 41¡Z" 1Z." IW{( :r.!i:ïÑ7.:.jBr.iBt':j"~¡,¡;;;- ...... 1.00 I HillUb\lrlw ·N...-rJ'J· !eill tlnll i . ............ "."-.'-'---'.... . 10.00 I Hà\li'-"lll'IOtI "AU/R" P.~IIt;n~"'411:II:.ta n.. A.dspaJ l~O,OO! ~ 1/"J." t'I..ti Ib/tt J-$S Mðd SUE 81'd Tubin~ ! . ·1.UU I Halllbllrtan., lfJ" "AU" ~lldlDm9.!,{!........... .. ¡ ::j·H.UU I 11"J" UoOltlilt ')-SS ModlWi ¡rd Tllain!! . I,OO ~{~'··XN· NIDDlo 1 nnd of Tubilll! -- Ij 585Ci,OO S S~(¡.O( 4 ·····~iiü:ïïü .. .~ 1IW-tJ)( 2 6s-4t!.IJO I 6:'iSQ.DQ PNC1n1"~'Ir1N pp..f.'è'i'IiAT1õN rNTr..RVÁ1.::1 coos: INLET St\N['I' KP',jIAA !lcANM .. ... ~1jI~' - ~II; olIGo. lòqu...... 01 1 4&00 4000 01-£ S'* - $OW) CI-O :¡1~I-ml CI... OIU-:i11t.) (,;I-!I ~;;on - ~o r:1.II !\.',;\-II:\III (,':1_1) ,>~0j4 - ,):"~ì t.:1-!:I !I;' ~f - ':t~u ellS IS_-_~ CI 6 U80 "" Ct·· e ~ 6417 ... Go;U - ~ Bk,.{,k 3Q_d ... !)2 Y . 2101 Bki""3o.¡1ICa.I.II~ C'".I-A !I.'tI!t - ~ ~-:¡.M MtIA -"III ~ ... -.. - !IIo" &Ioi:\($qu~ CI 0 &877 f7O:! QI-O 6~ 51Q3 OHI! ~++ - ~7$11 C;I-11 :;eoo - :;010 ..f 31~ R ~10 B1uo.II3q"eue1l ... !\II17 - !l13 !!I1uW. a_...J .......... "Vp~" .. .3:1-!llI:It lIeoIiiI - lIiM~ 1IÐ40 1161S0 110&& as Qtto - e,:!ð IU:ïfI - 010:1 lI,a, . i1M "'IO-~ Þ,Ofj'j¡$. ~ ~,¡ - I$~" ~. .. .. .. .. .. o. 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'..-9r.1 .......- RfC flVEC ~) 0 ]994 TOTAL p, Ø08 / ",- \~- ), QS Þ ) PHILLIPS PETROLEUM COMPANY HOUSTON, TEXAS 77251-1967 BOX 1967 BEllAIRE, TEXAS 6330 WEST lOOP SOUTH PHilLIPS BUilDING EXPLORATION AND PRODUCTION GROUP October 29, 1 993 p\/ c£6 \9 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: North Cook Inlet Unit A-10 Workover Phillips and Arco are presently evaluating the results of the Sunfish No.2 well drilled from the Tyonek platform. Plans to spud the Sunfish No.3 have been delayed to permit incorporating the results of the Sunfish No.2 into the delineation program. Rather than have the drilling rig remain idle while the evaluation is completed, we propose to perform workovers on the NCIU gas wells. The first of these workovers is the NCIU A-1 O. Attached are three copies of the Application for Sundry Approvals, form 10-403, and three copies of the detailed workover program for the workover of the A-10 well on the North Cook Inlet Unit. Included in the detailed program are BOP schematics and the workover fluid program. If you have any questions concerning this workover or need any additional information, please contact Dennis Morgan at (713) 669-2173. Regards, ¡;.~ /17~ ~r D.C.GiII Drilling and Production Engineering Manager DCG:DRM/bcf cc: A. R. Lyons Central files J. F. Mitchell RECEiVED NOV - .\ 1993 ,- '\0;-: Alaska Oil & Gas Cons. (;0\1\1'(\\55 Anchorage --......---.- --. "'.- ">.'-'..-'-"- .., ...-.......-.-.-..---..-..-..-.--.---.--..----........"- .___.__._._ __...._...m______." ._..._ .__,,'''_.. ..________..._ ._ -. ...--.--._~-------_._.._---_.._--._.'-_._"---_._._..__. _._~._-_._-_..>. .- ._- - '---"'---'-~ ~..- . , STATE OF ALASKA ALASK..~IL AND GAS CONSERVATION COMM,JION APPLICATION FOR SUNDRY APPROVALS I¡ ~ 1. Type of Request: Abandon Suspend ~: Operation Shutdown l J Re-enter suspended well n Alter casing C ~ Time extension Change approved program Plugging:J Stimulate :x Pull tubing. Amend order r Perforate !X Other ~J 5. Datum elevation (OF or KB) 116 2. Name of Operator Phillips Petroleum Company 3. Address 6330 W. Loop South, Bellaire, TX 77401 4. Location of well at surface Platform "A", leg 2, slot 6 1304' FNL, 1023' FWL, Sec. 6-T11N-R9W At top of productive interval 812' FSL, 2425' FWL, Sec. 3I-T12N- R9W @4890' MD, 3889' TVD At effective depth 812' FSL, 2425' FWL, See 31-T12N-R9W @4890' MD, 3889' TVD At total depth 2505' FSL, 4115' FWL, Sec. 31-T12N-R9W @8250' MD 6240' TVD 11. Present well condition summary Total depth: measured true vertical 6. Unit or Property name North Cook Inlet Unit 7. Well number A-10 8. Permit number b Y-9l? 9. API number '50- 10. pool Cook Inlet 8183 6194 feet feet Plugs (measured) Effective depth: measured true vertical 4890 3889 feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True Vertical depth 16" 10-3/4" 610 sks 737 sks 631 2,782 631 2,517 7" 1,210 sks 8,228 6,225 measured 4890-7668 RECEIVED true vertical 3905-5858 NOV - 11993 Tubing (size, grade and measured depth) 4", 11 ppf J-55 Packers and SSSV (type and measured depth) RH -ç:, Description summary of proposal !Xl Alaska OiJ & Gas Cons. CommisSIon Anchorage and 3-1/2" 9.2 ppf J-55 @7,691 Detailed operations program ~ BOP sketch ~ 12.Attachments 13. Estimated date for commencing operation November 10, 1993 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ....D. C. Gill .(l, 71''' Title D&P Engineering }tanager Date 10/26/93 Commission Use Only Conditions of approval Notify commission so representative may witness Approval No. ...3 _ I) Cf Q o Plug integrity ~ BOP Test 0 Location clearance I" I I ~ / ¿J -~t>~ ,r,? U ;'" e d Retumed - «-\.f-?~ Originð1 SJgned By by order of Approved by D,,\dQ '·â .....,)1') Commissioner the commission Date II Form 10.403 Rev 12-1-85 Submit in triplicate ~ :/. ", -) ) WORKOVER OBJECTIVES: 1. Pull tubing to replace subsurface safety valve. 2. Reperforate productive intervals to improve bottomhole deliverability. 3. Recomplete well with 4 1/2 It tubing to maximize deli verabili ty. WELL HISTORY AND CURRENT CONDITION: The well was drilled in 1968 and completed as a Beluga formation monitoring well in 1970. The well was worked over in 1975 during which time the Cook Inlet sands were perforated and the well completed as a commingled Cook Inlet and Beluga producer. The well was completed with an otis RH retrievable packer set at 4884' and tailpipe extending to 7691'. A schematic drawing and detailed description of the current completion is attached. The well is equipped wi.th an FMC-OCT wellhead and X-mas tree. A drawing of the tree is attached. Back pressure valves, test plugs, wear bushings and any required wellhead service will be supplied by FMC. Seven of the 14 Cook Inlet sands and 18 intervals in the Upper, Middle and Lower Beluga are perforated. The well is currently producing 10.7 MMCFD and has shut in pressure of 1090 psi. The reservoir pressure of the sands perforated in this well will vary between a 5. 0 ppg mud weight equi vilant and a 7.5 ppg equivilant. There are several intervals in the Cook Inlet sands that have been identified as pay but have not been perforated. These intervals may be perforated during the course of this workover. These intervals are expected to have reservoir pressures less than 7.5 ppg emw. The SCSSV on this well failed in 1990. Attempts to repair the safety valve problem were unsllccessful. To resume production a dummy was set in the safety valve nipple and a velocity valve was set in the XA sleeve at 48/7'. There are indications of tubing annulus communication, probably through at the safety valve nipple. A wireline fish was lost in the attempts to repair the safety valve and open a sliding sleeve. The fish should be in the Q nipple near the bottom of the tubing. RECEIVED 2 NOV - 11993 Alaska Oil & Gas Cons. Comm\ss\ùí\ Anchorage ) ) The sands in this well are highly permeable. A small reduction in the pressure at the perforations can result in very high flowrates. Be sure that all personnel are aware of this and understand the importance of following good well control practices. Crews should be alert for any indications of flow and prepared to shut in the well and circulate through the choke at any time. PROCEDURE Establish barriers, install BOPs and kill well: This well is a cateqory three well. A variance to Phillips Well Control Manual has been requested to permit nipplinq down the X-mas tree with 1 tested barrier and 2 untested barriers. Al. Fill tubing with workover fluid as needed to kill well. See attached workover fluid program. A2. Bleed off pressure from tubing x casing annulus and fill annulus. A3. Monitor well for at least 30 minutes. A4. RU wireline lubricator and test to 1500 psi. AS. Pull dummy from DHSV nipple. A6. Pull velocity valve. Valve is set in XA sleeve at 4877' A7. Install plug in profile at XA sleeve. AS. Install BPV A9. ND tree. Note: Tree should be sent to FMC for inspection, repair, and addition of a second master valve. A10. NU and test riser and BOP to 3000 psi. See the well control section of this procedure for additional details concerning BOP tests and well control requirements. All. Retrieve BPV and plug from XA sleeve. Pull existinq completion, clean out to TD: B1. Screw DP into tubing hanger and pull on DP to release otis RH packer. Limit pull to 170,000 lbs hookload. The otis RH packer is a pull to release packer, rotation is not needed. Note: Be prepared for gas bubbles anytime, but especially when a packer is released. 3 RECE\VED NOV - 11993 Alaska on & Gas Cons. LO\ì\Ù\\SS\ij\\ Anchorage ) ~) B2. If pipe does not come free, take free point measurements to determine stuck point. Cut tUbing above stuck point. B3. Circulate at least one full hole volume before POOH. Be prepared to shut well in and circulate through choke as there may be significant volumes of gas trapped below the packer. B4. POOH wltubing, packer and tailpipe. Pull slow to avoid any tendency to swab. Note: Tubing is to be checked for NORM contamination Note: A detailed description of the completion equipment presently in this well is found in section o. The tubing in the well includes 4" and 3 1/2" as well as several blast joints and other tools. Have handling tools available to cover all sizes of tubing in the well. B5. If necessary, RIH wI an overshot, jars, 4 3/4" drillcollars and 3 1/2" drillpipe to recover remainder of tubing. B6. After all tubing has been recovered, RIH wI 6" bit and clean out to PBTD at 8120'. B7. Circulate well with clean completion fluid. POOH REPERFORATE Cl. Make up TCP perforating guns and DST string per attached schematic and RIH. C2. RU Schlumberger and run GR correlation log to locate perforating guns to perforate desired interval. C3. Set packer and open tester valve. C4. RU nitrogen unit and pressure up on tubing to actuate firing head and open pressure operated vent. C6. Bleed off pressure to initiate flow. Flow well to clean up new perforations. Kill well with work over fluid. C5. C7. ca. POOH wI perforating guns.- C9. Repeat steps 1 - a until all intervals have been perforated. Run New completion D1. RIH wI 6" bit to TD. Circulate well with clean completion fluid. POOH. 4 RECEIVED NOV - 11993 Alaska Oìl & Gas Cons. LornrnISS¡(J1l Anchorage -) ") Note: Leave pipe stood back if the rig is to be skidded to the A-ll well to continue the workover program. Lay down the drillpipe if the well is to be skidded to Sunfish J to begin drilling. D2. RIH wI 4 1/2" tubing, blast joints, packer and related tools per attached schematic. DJ. RU Schlumberger to locate packer so that blast joints are opposite perforations. D4. Space out as needed. D5. Reverse circulate to packer fluid with glycol into annulus D6. Set packer D7. Install DHSV and BPV DB. ND BOP and NU X-mas tree D9. Retrive BPV and DHSV. D1D. RU coiled and jet well in. D11. Turn well over to production. 5 RECE\VED NOV - 11993 ro\SS\UI" Alaska on & Gas Cons. (;om Anchorage ) '') Well Control This well is a category 3 well, as defined in Phillips Completion Workover and Well Control Policy. For all operations two barriers, e.g. the BOP's, fluid column, etc. must be in place in order to conduct simultaneous operations. The BOP equipment is 10000 psi WP Class 4 as per Phillips Well Control manual. The bottom set of rams should be 3 1/2" pipe rams, the nïiddle set will be blind rams and the top set should be variable rams. Although the BOP is rated to 10000 psi, the riser and the wellhead are rated to 3000 psi. The BOP and choke manifold should be stump tested to 3000 psi. The BOP should be tested to 3000 psi upon nipple up and to 1500 psi on a weekly basis. The Alaska oil and Gas Conservation commission (AOGCC) should be notified prior to conducting BOP tests. The notification to AOGCC should be made early enough for them to witness the test if they desire. Well control drills are to be conducted with each crew as per Phillips well control manual. Drills should be reported on the IADC daily drilling report and on Phillips Daily Drilling Report. This well produces from a series of very permeable sands. A small decrease in pressure at the perforations can result in very large flowrates. A large number of trips can be expected during the course of this workover. It is vital that good well control practices be followed during the course of these trips. Trip speed while POOH should be kept relatively slow to avoid any tendency to swab. Before any trip is made swab and surge calculations should be made based on the properties of the fluid in the hole. DO NOT exceed the running speed determined by the calculations. A detailed trip book comparing measured fill up requirements to the calculated requirements should be maintained for each trip. The cause for any discrepency between the actual and required fill up volume must be determined before continuing with the trip. MAINTAINING CONTROL OF THE WELL IS OF THE UPMOST IMPORTANCE, TRIP SPEED IS SECONDARY. All of the producing sands, 25 different intervals between 3905' and 5858' TVD (4890' - 7668' MD), are commingled at the present time. The pore pressures in the various sands will range from 5.0 ppg EMW to 7.5 ppg EMW. The variations in gradient will make it difficult to kill the well and could create well control problems throughout the workover. There is a possibility that the lower pressured intervals will not support a fluid column adequate to control the higher pressured intervals without addition of a bridging agent to the workover fluid. A premixed pill designed to bridge off the lower pressured 1 RECEIVED NOV - 11993 Alaska Oil & Gas Cons. commlsS\Vi\ Anchorage 2 NOV - 11993 Alaska DH& Gas Cons. Commission Anchorage RECEIVED All of the zones presently perforated in this well can be killed with water. As a precautionary measure, a line should be ran from the annulus valves on the tUbing head to supply work over fluid, drill water, 'or seawater. This line can be used to supply workover fluid as discussed above or as a last resort can be used to kill the well with drillwater or seawater. Pumping drillwater or seawater through the annulus valves should be considered only in an emergency situation as these fluids could result in formation damage. zones should be maintained in one of the mud pits until the well has been cleaned out to TD. If the well cannot be made to stand full, then well control can be maintained by constantly pumping workover fluid. ) ) ) NCIU A-10 ) RISER AND BOP ARRANGEMENT 5M ANNULAR PREVENTER 10M VARIABLE BORE PIPE RAMS 10M BLIND RAMS DRILLING SPOOL 3 1/2" 10M PIPE RAMS RISER 13 5/8" 10M X 13 5/8" 5M ADAPTER 13 5/8" 5M X 16 3/4" 5M CLAMP RISER 16 3/4" 5M X 16 3/4" 5M ADAPTER 16 3/4" 5M CLAMP X 9" 3M TUBING HEAD 9" 3M X 11" 3M RECE\V£D NOV - "\ 1993 . . \1\m\SS\U\' k OU & Gas Cons. liO Alas a Anchorage , , ) ') Workover Fluid program The base fluid for the workover is a 2% KCL brine. Fluid density will be 8.4 ppg. Kill fluid: This fluid will be used for the initial kill operations and will be used while cleaning out the existing completion and circulating out any sand that has accumulated in the wellbore. Fluid Properties: Weight: Total hardness: KCl concentration: 8.4 ppg less than 100 ppm 7 ppb For additional fluid loss control use pills of workover fluid containing 3 ppb Xanvis (XC polymer). The polymer should be hydrated and sheared properly to obtain the maximum low shear rheology. If additional fluid loss is required LCM pills of Litesal XCP pill will be used, The volume of the pill and the amount of bridgeing agent to be used will be determined based on the rate of loss. Saturate the system with LiteSal (borate salts) and add 2 - 3 ppb Liteplug fine to the circulating system. Then spot the LCM pill across the thief zone. Should additonal fluid loss control be needed for seepage control while working with the thief zones open, add 15 ppb LiteSal XCP and 5 ppb pH-6. This will viscosify the system to suspend additional bridging agent. Then add 5 - 10 ppb Liteplug if needed. Sweeps containing 3 PPB Xanvis should be used as needed for hole cleaning while circulating out the sand. Screens on the shaker should be as fine as possible without blinding. Sand that is circulated out should be sampled to insure it complies with the NPDES permit and diposed of overboard. If the sand cannot be disharged overboard it will be collected in bins and sent to shore for disposition. RECEIVED 2 NOV - 11993 Alaska Oil & Gas Cons. Comm\SSlOP Anchorage NOV - 11993 Alaska Oil & Gas Cons. commiS5\O¡ Anchorage 3. 4- 3M Studded Tee ® RECEIVED 9. 16- 3M x 16- SOW Casing Head 8. 10- 3M x 16- 3M Casing Spool 7. 2- 3M FE Gate Valves 6. 8- 3M x 10· 3M Tubing Head, equipped with OCT Type Tc-1A-EN Tubing Hanger bored for Otis TSV Uns (4-112- EU Brd Hanger UftThread) 5. 4- 3M x 8- 3M Studded Tubing Head Adapter, bored for Otis TSV Une. 4. 4- 3M FE Gate Valve with -Fail Close- Pneumatic Actuator 2. 4- 3M FE Gate Valve 1. 4- 3M Tree cap with Needle Valve and Gauge ) North Cook Inlet Unit Wellhead Arrangement PROPOSED ) 1 ~ .., '"""-,, I '-"" North Cook Inlet Unit Wellhead Arrangement CURRENT 1. Hammer Union 2. 4- 3M Orbit Ball Valve 3. 4· 3M Studded Tee 4 4. 48 3M Æ Gate Valve with 8Fail Close- Pneumatic Actuator 5. 48 3M Gate Valve 6.48 3M x 883M Studded Tubing Head Adapter, bored for Otis TSV Une 7. 883M x 10· 3M Tubing Head, equipped with OCT Type TC-1A-EN Tubing Hanger bored for Otis TSV Une (4-112· EU Srd Hanger lift Thread) 8. 2- 3M FE Gate Valves 9. 108 3M x 16· 3M Casing Spool 10. 16· 3M x 168 SOW Casing Head RECEIVED NOV - 11993 Alaska OU & Gas Lons. lÏommiS5\\) Anchorage ~J 1, sv KBM - ~~~ xo DVTOO @eeeI5 Q l~ L.^IV' I.,.'-A '-''-'''''LlII ,'-',... "-'''''. .~,..." "'" .~""'-" ,., . '" BPV M4ke.T~ I tbO.Har.lMake tVÞeï: Cl -1A Annulus Fluid: INHIB~A1ER WITH tÆTHANOl. FOR FÆE2E PR01ECTION TOC: AKB-DRILL DEO<: 24.5' AKB- THF: 38.9' RKB-SL: 118 RKB-ML : }'GIådØ::::::::::" ':"':':'J}'"Ii~}}:}}::ÐU"f:'. ,',}}:,COIL:::"", :,:::::::-rèliiífå,f::: . ., ........ - .i:::;:::;:i:;:::;:;:;:;:;:;:::;:;::: ... ., },:()O:::,::::::: 30 16 10 :fI4 7' 7' 7' 4" 3 1t.!' ... : ':PERFS::::::::::::::: ....'.:-:-;.:.:.;.:.:...;.......:. . , .. SQlEEZE 48115-4818 SQlEE2E SQlEE2E SQlEE2E 01 488D-4890 02 !5OOB -!5088 03 0.. 5111 -5151 15183-5193 o 15 5270-152ØO 08 5392-5417 15482 -15483 5eI51-55e8 eeeo-15EI51 08 f!J871-5702 SQlEE2E 5814-5815 SOlEE2E !!e12-!!e13 U BELUCJA l1848-eeee U BELUCJA 8128-8138 U BELUGA 8158-8183 U BELUGA 8181-8188 U BELUGA 8210-8225 U BELUGA 8228-8234 M BELUGA 8424-8430 M BELUGA 8482-8477 M BELUGA eeoø-eð48 M BELUGA 8894-8118 M BELUGA 815!5-8185 M BELUGA 8919-8928 M BELUGA 703O-7œO M BELUGA 7œ5-7090 M BELUGA 7329-7339 M BELUGA 7381-7388 LBELUGA 7541-7547 L BELUGA 7828-7868 ,:,::;::}fciD:::::::,:: SLfFAC SlIFAQ SI.R=AC SLfFAC +/-7C 7298 SLfFAŒ 4872 .. tit::::::: 4872 4873 4877 4881 4884 4889 4897 4801 5009 5019 5107 5121 5212 I52ØO 5300 5438 5452 5891 15720 158!58 !!eN 8140 8180 8171 6161 6195 620!5 8223 8253 8438 8441 8477 8481 8521 8510 8705 8135 8165 8165 8189 8933 8942 7038 7OEI8 i'CSG 7108 7341 7381 7375 7385 7555 7565 7839 7688 7690 7891 8183 .. :':eoüOiÝi}:: 388 631 2782 +/-10 8858 8228 4872 7891 ,. :;:::,Wt:::::::::: ....... Ø5.CX 45.50 26.00 23.00 26.00 10.90 8.30 H-40 J-55 J-55 J-55 J-55 J-55 J-55 BUTT BUTT BUTT BUTT BUTT .... 38 40 272 273 278 277 3t17 308 313 314 1 OCTTC-1A TUBING HAftGER 239 4" BUTTÆSS TUBING 1 X-OVER 3 1~ 8FÐ X.." BUTTÆSS 3 OTIS TYPE B BAlL VALVE NIPPlE 1 X-OVER"" BUTTÆSS X 3 112" 8FÐ 30 .." BUTTÆSS TUBING 1 X-OVER 3 1~ 8FÐ X.." BUTTÆSS 15 CAMCx:> KBM MANDÆL (WITH DUMMY) 1 X-OVER 4" BlJT1ÆSS X 3 112" 8FÐ 4558 4" BVT1ÆSS TUBING ''"-- -/ 1 X-OVER 3 1~ BUT1ÆSS X.." BUT1ÆSS .. 3 1~ PlP JOINT 4 OTIS XA SOOING SŒEVE nNiTH VELOOTY VALVEI 3 OTIS SŒEVE FELEAŒ seAL DIVIDER fON-OFF TOOU 5 OTIS RH PACKER 8 3 1~ PlP JOINT 4 OTIS XO SOOINB SLEEVE ~NI 108 3 112' BLAST JOINTS 10 3 1~ PlP JOINTS eø 3 1~ BLAST JOINTS 14 3 1~ PlP JOINTS 81 3 112' BLAST JOINTS 88 31~ BUTTÆSS TUBING AND PlP JOINTS 20 3 1~ BLAST JOINTS 138 3 1~ TUBING AND PlP JOINTS 16 3 1~ BLAST JOINTS 239 3 1~ TUBING AND PlP JOINTS 28 3 1~ BLAST JOINTS 239 3 112' BUTT'FESS TUBING AND PlP JOINTS 10 3 1~ BLAST JOINTS 181 3 112' BUTTÆSS TUBING AND PlP JOINTS 20 3 1~ BlAST JOINTS 11 3 1~ TUBING AND PlP JOINTS 10 3 1~ BLAST JOINTS 14 3 1~ TUBING AND PlP JOINTS 10 3 1~ BLAST JOINTS 18 3 1~ TUBING AND PlP JOINTS 30 3 1~ BlAST JOINTS 185 3 1~ BUTTÆSS TUBING AND PlP JOINTS 9 3 1~ BLAST JOINTS 30 3 1~ TUBING AND PIP JOINTS 20 3 1~ B~ST JOINTS 24 3 112' TUBING AND PlP JOINTS 49 3 1~ BLAST JOINTS 135 3 1~ TUBING AND PlP JOINTS 30 3 1~ BLAST JOINTS 30 3 1~ TUBING AND PIP JOINTS 20 3 1~ BLAST JOINTS 4 OTIS XO SOOING SLEEVE (OPEN) 144 3 1~ TUBING AND PlP JOINTS 9 3 112' BLAST JOINTS 96 3 1~ TUBING AND PlP JOINTS 30 3 1.2" BLAST JOINTS 30 3 11'2" TUBING AND PlP JOINTS ".. : t':!- DI Aa~ ~!(\!~ 233 3 1~ PlP :JOINTS 20 3 1~ BLAST JOINTS 1.. 3 1~ PlP JOINTS 10 3 1~ BLAST JOINTS 170 3 1~ TUBING AND PlP JOINTS 10 3 1~ B~ST JOINTS 74 3 1~ TUBING AND PlP JOINTS 49 3 1~ BlAST JOINTS 2 OTIS Q NIPPlE - WÆUNE FISH SHOUlD BE HEFE 1 MULE SHOE END OF TUBING DRILLED IN 1969, COWlE1ED IN 1875 DEVIATION 151 DEG PBTD 5690 4980 5890 7210 79ØO 3.476 2.992 2.875 2.992 3.476 2.992 2.813 2.992 3.476 2.992 2.992 2.813 2.750 2. 780 2.992 2.813 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.992 2.882 2.992 2.882 2.813 2.992 2.882 2.992 2.882 2.992 2.882. 2.992 2.882 2.992 2.882 2.992 4330 3270 4330 8590 1400 415000 368000 415000 189200 142500 ':'::::::::::::00: ::::'{{:(lM}}} 4.000 4.000 4.280 4.000 4.000 4.000 4.500 4.000 4.000 4.000 3.500 4.280 5.750 6.000 3.500 4,280 4.500 3.500 4.500 3.500 4.500 3.500 4.500 3.500 4.500 3.500 4.500 3.500 4.500 3.500 4.500 3.500 4.500 3.500 4.500 3.500 4.500 3.500 4.500 3.500 4.1500 3.500 4.500 3.500 4.500 3.500 4.500 4.280 3.500 4.500 3.500 4.500 3.500 4.500 3.500 4.500 3.500 4.500 3.500 2.882 4.500 2.992 3.500 2.882 4.500 2.625 4.500 .2.øø r \:1500 _ ii"7 L \ \.B ¡ V It!' I""'{C v. .. \I' - L..ft"l t\\O\J - -, 1':J~\I . \'4 c. mtn 55\0\\ ~.' n e.o::\c, Cons. vO A\aSKa uu \To Anchorage · JJ sv Ll- t'U'\l'U'-U::U vVIVlrLI:; Ilvn ~VII'-IYIM I IV "'_1_ "'-- I V BPV(MakeTYP8.0D). Tba.Har.IMake.TYP8,," .ITC-1A Annulu. fluid: INHBiT"ED WATER WITH METHANOL FOR FREEZE PROTECTION TOC: .","" \ " "-'" RKB-DRILL DECK: 24.5' RKB- THF: 38.9' RKB-SL : 116 RKB-ML : CÔnn. ". . ::}}]~(;'$f}} }}}:::(;:Qt{{::: :{{t_n$iØ6{:: ......................... ......................... ......................... ............,........... ......................... . . . . . . . . . . . . . . . . . . . . . . . . . ::::::::QO:: 30:::::: ::;::~:}::::roíf{:? ::::{]~Qttôm386:'>}~ }::::::::::wt}}}: ~::{{{{{Ör.¡:iif}}}}: SURFAC 18' SURFAC 631 65.0( H-40 10314 SURFAC 2782 45.50 J-55 7' SURFAC +/-70 28.00 J-55 BUTT 5690 4330 415000 7' +/-7 8858 23.00 J-55 BUTT 4980 3270 386000 7' 7298 8228 28.00 J-55 BUTT 5690 4330 415000 41/2' SURFAC 400 12.60 J-55 BUTT -MOr 6620 5730 198000 4 112 400 7900 12.75 J-55 8RD - MOD 8820 5730 198000 :Þeæš::::~:::::::::::::::~:~::::ëe~:~:~:::::: :::::::::~tê6âtii::::~_~::::::::::::::O'b:::~:::::::~ '. :::::::::::::::::::::::::::::::::::~:::::::::::::rtof.iS:::::~:::::::::::::::::~Œtf::::::::_:mEtiHmIE:::::::::::::(iNi::::::::::~:: - - F,QAMÄllö",,:::::::: , . . . . . . . . . . . . . . . .,................... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 39 1 OCT TC-1A TUBING HANGER 40 380 4 112 BUTTRESS MODIFIED TUBING 3.478 4.000 400 3 OTIS sessv NIPPLE 2.875 4.280 403 4447 4 1/2' 8RD MODIFIED TUBING 3.478 4.000 SQUEEZE 4815-4818 2.992 3.500 4850 12 OTIS OVERSHOT TUBING SEAL DIVIDER 2.813 4.280 4882 3 RATCH LATCH 2.750 5.750 4883 5 OTIS VSR PACKER 2.780 6.000 4888 3 OTIS X NIPPLE 4871 229 4 112' TUBING 2.992 3.500 2.813 4.280 Cl1 4890-4890 2.992 4.500 2.992 3.500 Cl2 5008-15088 2.992 4.500 XD 5100 4 OTIS XC SLIDING SLEEVE ;CLOSEm 2.992 3.500 013 5111-"181 2.. 4.1100 Cl4 5183-5183 5104 798 4 1/2' TUBING 2.992 3.500 CI5 5270-e28Q 2.992 4.500 2.992 3.500 CI8 5392-5417 2.992 4.500 2.992 3.500 SQUEEZE 5482-5483 SQUEEze 5557 -5558 SQUEEZE 5850-5851 OIl 5177-1702 2.. ".!IM 2.992 1.1500 SQUEEze 5814-5815 SQUEEZE 5912-5913 XA !5900 4 OTIS XA SLIDING SLEEVE 'CLOSED' U BELUGA 5948-5959 2.992 4.500 5904 1998 4 1/2' TUBING 2.992 3.500 U BELUGA 6129-8139 2.992 4.500 U BELUGA 8158-8163 2.992 3.500 2.992 4.500 U BELUGA 6181-8188 2.992 3.500 2.992 4.500 U BELUGA 6210-6225 2.992 3.500 U BELUGA U21-e234 , 2.992 4.500 2.992 1.1500 M BELUCIA 1424-1430 2.992 4.500 2.992 3.500 M BELUGA 8482-8477 2.992 4.500 2.992 3.500 M BELUGA 8508-1548 2.992 4.500 CV TOO 2.. 3.500 0_5 M BELUCIA 8884-1711 2.882 4.500 2.992 3.500 M BELUGA 6755-8765 2.882 4.500 - 2.813 4.280 2.992 3.500 M BELUGA 8919-6828 2.882 4.500 2.992 3.500 M BELUGA 7030-7_ 2.882 4.500 2.. 3.500 M BELUGA 7085-7080 2.882 4.500 2.992 3.500 M BE:'UßA 73-"!- 7'1'19 _. ...._-~/.";:_.-; 2.&ü2 4.òOO 2.992 3.500 M BELUGA 7381-7388 2.882 4.500 2.992 3.500 L BELUGA 7541-7547 2.882 4.500 2.992 3.500 L BELUGA 7828-7668 2.882 4.500 XN 7900 1 OTIS XN NIPPLE 7901 10 PUP JOINT 2.625 4.500 7911 1 WIÆLlNE REENTRY GUIDE 2.992 3.500 7912 END OF TUBING -' - 8163 PBTD u~r LT\/LI"\ n·~L I V LLk' DRILLED IN 1989, COMPLETED IN 1975 DEVIATION 51 DEG NOV - 1 1993 Alaska Oil & Gas Cons. liommisS1li Anchorage .. P:lJirm 10-403 REV. 1-10-73 ''\ ) Subml t "I ntentlons" In Triplicate & "Subsequent Reports" In Duplicate ') STATE OF ALASKA 5. API NUMERICAL CODE OIL AND GAS CONSERVATION COMMITTEE 50-283-20030 6. LEASE DESIGNATION AND SERIAL NO. SUNDRY NOTICES AND REPORTS ON WELLS ADL - 17589 (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT-" for such proposals.) 1. GAS [!] 7. IF INDIAN, ALLOTTEE OR TRIBE NAME OIL D WELL WELL. OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Phillips Petr91eum Compaqy NCIU 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Drawer 66 - Kenai, AI{ 99611 A-I0 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT At surface Leg 2, Slot 6, 1304.2' FNL, 1022.7 FWL, Sec. 6, TIIN, R9W, S.M. 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) BHL 2505' FSL & 4115' FWL, Sec. 31, 12N, R9W, S.M. See Item 4BHL 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 12. PERMIT NO. RKB 116' from MLLW 69-88 14. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: TEST WATER SHUT-OFF ~ FRACTURE TREAT SHOOT OR ACIDIZE REPAI R WELL (Other) PU,LL OR ALTER CASING ~ MULTIPLE COMPLETE ABANDON* CHANGE PLANS WATER SHUT-OFF ~ FRACTURE TREATMENT SHOOTING OR ACIDIZING ' (Other) Clean out & erf REPAI RING WELL ALTERING CASING ABANDONMENT* ~ (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCR IBEPROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. SEE ATTACHED "DAILY REPORT DETAILED" ~~©Œ~WŒ~ tJOV 1 71975 E'!'/:S1(~ ¡" ~ - ,~:!L AND G,,\ê3 SIGNE-d("'~:-óz~-v L~ ....L _- Porter (This space for State office use) TITLE Sr. Pet,:rolelJm ti~rH"; nee". DATE {~1iJ APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side SHEET NO. ~ Present Operation: Nipple up BOP 10 hrs.testWellA-ll. 16 mmcf a day production 61/2 hrs.skidrigfrom A-II to A-IO end rig up. 4 hra. circulate 11.3 mud a.round A-IO to kill well 1/2 hr. move Christme.stree and nipple .' up BOP August 2 ,1975 COOR wi.th tbg, finish NU BOP tested to 2500 lba,O.I. Remove baek pressure valve and ball valve WIH with Otis wire line with latching toolt could not close Otis XAsleeve at 4881. Shear loose and COOH. Circulate out, COOR with tbg, left dogs on, sepa.rat1.on tool in hole. 'vfIH wi th2 7/8 inch spea.r catch packer and pulled. loose, circulate 2 hrs. start out of hole. August 3, 1975 NiPPle döwn BOP. Finish COOHwith tbg,lq down Otis sleeve release seal divi"der, replace shear through sub packer t top XO and XA sliding sleeves, move XA sa 1 joint aboye packer~ Space out , go in hole. Now nipple down BOP and nipp1eup Christmas tree. August 4, 1975 PresentC)peration: Prepare the test 't;,Tel1 Displace mud out of easing and tbg withws.ter, spot atlO.5 PH water in casing, drop balls to set pa.cker, pressure tbg to 500 Ibs, lOOOlbs casing to 800 Ibs t thentbg to 1200 Iba, 1500 Ibs 9 Ballsàeared at 2100 Ibs. Bleed tbgto zero, pressureennulus <to 100Qlbs for 15 min. to check packer-it was O.K. Rig up Otis pull ball va-lve end shift. sleeves to flow water out of well.. Well cleaned , ..prepare.. to test. August 5 ,'·1975 Present Operation : Moving . Rig lO.hoursflowing well and clean up. 12hours '. testing well 14 mmcfgd. 2 hours rig' down to skid to well A-9. g)ÆÐ~/;~0 æø'p~~/ -c:A/tZ// ·CPn?/ì.L<L7(,') D Œ©{EU~Œ\lli Wl NO\) 11\975 - .. ~- /- II ,I·N)' GAS I"" .-. . L. .¡-.., D\'/:$:,.... ¡" '- I '-'" - . ,-. ~ I.' !.."......qrIR,~:\ ~ j[ Ml~'.:í.._~~L'I.::,'~:·..· ~ Form 911 1-69 Printed in U.S.A. . . , .. ,. ¡ ·f'·': ') DAILY REPORT DETAILED ) LEASE NCIU WELL NO. A-I0 SHEET NO. TOT AL DATE DEPTH NATURE OF WORK PERFORMED 6/24/75 PTD':'~'-8120 Mud Data: 11.5 /44 Da.ys FR Spud: 6 Finish GOOH. Tag bottom at 7756'. Cj.rc bottoms up BIldeond m.ud to 11.5 ppg. vlashed rat hole to 8120 old RKB. Could not wash deeper. Recov cmt part in mud return. Cire out. COŒ! nu Schlumberger. Testd shorting nipple to 1000 psi - o.k. Perf as follows: 5677 to 5702 rES 5392 to 5417 rES 5270 to 5280 lES 5163 to 5193 rES 5111 to 5151 IES ContinuiùB to perf. §125/75_ Mud Data.: 11.5/43/7.5/2/18/26/8.0/440 Finished pE:rf 5008 to 5088'. h890 to 4990 rES. All perf wI 411 Hyperjet wI four holfsper ft. RD ;3chlumberger. WIH w/bit. Cire & CM. COOH. Now running completion string. §126/75 PTD: 8120 Mud Data: 8.5 I Sea Water Cire out w/sea water. Ran completion string to 7342'. Ne,,, HT measurement. liU Schlumberger. Ran GRN correlation log. End of tbg location at "(333' rES. RD Sehlumberger. Finished GOOHw/co:mpletion string for 342 additional feet and landed tbg w/backpressure valve in place. ND BOP. Pull back press valve. UU XT. tstd XT to 3000 psi. RU to Circ out mud. Now Circ out. Have tsted SCSSV I/J~n line and dummy to 5000 psi. Have tstd KBM ~,1Mdril to 2000 psi. 6/~.IL12 FINAL REPORT Final tbg setting - 7691' oldFXG (7675 lEG). Fin circ aut w/mud w/bay water. Spotted fresh caustic wa.ter in 4H x 7" anulus. BU Otis. Pulled dummy 8esSV. Set circ valve in Q nipple i'T 17683' old RKB. Set Otis PH pkr at 4884 r old RKB w/3000 psi. Tstd 4;; x 7!! anulus and pIer to 1000 psi - o.k. Pulled circ valve. Set Otis SCSSV at 272'. Tstd opening. To skid. rir to ~1ell A-II. Form 911 1-69 Printed in U.S.A. :~~ fõJ IE © Œ U ~~ ill) ~ NO\l1 '7 \975 C\L ;~.ND Ù, D\V~S'C ¡, c ¡:: .¡r. " <', ~. Form No. G·t REVISED: JAN. 5T ATE OF AlASKA OIL AND GAS CON5ERV AnON COMMITIEE SUBMIT IN mJPLlCA'I'E [~r Test Annual '0 SpecIal ~Œa;~~WfEH :)t.~ : 9 1975 DIVlSlù~ "~/ OiL AND GJ Jr. .""IJ },) A. (t~ [J .' ¡"f.)~.il.iJiVU"II;o }¿'Pf-8'8 S WELL OPEN FLOW POTENTIAL TEST REPORT 4-POIXT TEST /~ .1 . ~ t. tJ r;.?~, ",<... --.0/),_) JA. 7' t'omÞletlon Date. ¿' ~ I ',/u..1 ,d. -'IL- "/. _6 ,.c1,.:J¡~ ..J/ C 31- ,I? ,y-.", D I . ,L/ /: ,. 7- I Total Depth (5'/ ~ () I Test Date ~J _ ..I í'.....- ". ...~., (..o '. ,.... I Well Xo. .' /:) .-,,/. I. T/Pay .l'rnl1u..¡r;;. .. I nlerval I ,.t/.ß'I'l/\ ""''''' ,,-l ~ , ç,. (. ".J " / c-;) neserv{1 . Dr./ --.~;-...<\ ,'" . ..' c· ./, -- . "', Leatle ~ ~. r....;--.," /V~,r, ~ ' ';if) ." L ~ ,IC.. -t_ ......" ("~/-~ Set @ B228 GL I ~() Ga~· Liquid IIrdrorarlJon Ratio :llfFper Bbl. Gra\;ty of Liquid (Api) , ",; ',',: /"*'i \.;,..\ , , OBSERVED DATA Flow Data Casing Press. psiS' Plowing' Temp. 'I<' ~;íh; ~ .5'3 $1- 5ð 494; 8 Rate of Flow Q.1\ICF/D I, the-undersigned. state that I am th" r. is ':;y' '-:- of the f.~· \. \' , r;:> .~~ --;-:: r(-.:.r)t....C..I~). ~- , "" /' " ,,~ and that I am authorized by said company to mak~~<this report; a?~~jbat...t.his report was pre- pared under my supervisJon and direction an~that the" f,a 15 at..~d. ther.:~...~~. t.__~.~. ,tr.. ue>. carr.. ..~i .and ....comPlete ,.0 the best of my knowledge. / /7 . (/\ .. /" I ":'"J.-.-::.... I / ./ ' . , I ,c',...1',?"," ¿.....,__ ..:or ,O~..·~¿.//t.- ; \ " Ignature f - \Tbc¡.l-)L'(e..(.5~'i:IK,,(~)) :-ro4-&13\MO :: a(:\',-o. ~~'1a,~O '.4e.1·~/ . ~Q~lo~1 "A\) =-3<b'1ß 10 5B'6ß 1"- 0 ~Œ@œllWJ ~tf 1 9 1975 DIVJSiJN OF OAt Ai~J J1 [M'd i}ú A £In \! L. -. A\jthl!. \\)C:tu ~ ~-W ì)A'- ·A.L¡\(.K...~ . ·.--J Form'''1Q.403 REV. 1-10-73 ) Subml t "I ntentlons" In Triplicate & "Subsequent Reports" In Duplicate ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE 5. API NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT-" for such proposals.) ADL - 17539 1. 7. IF INDIAN, ALLOTTEE OR TRIBE NAME OIL D GAS Ç::1 WELL WELL~ OTHER 2. NAME OF OPERATOR A1··'" fI 3. ADDRESS OF OPERATOR 8. UNIT, FARM OR LEASE NAME HCIU 9. WELL NO. P.O. 4. LOCATION OF WELL Alaska 99611 At surface 6, T11,1 2, Dlot '71 . ì 3f3C. Ä.-, 10 10. FIELD AND POOL, OR WILDCAT North Cook Inlet 11. SEC.,T., R., M., (BOTTOM HOLE OBJECTIVE) Bee Item ~, BHL ~.s ,. }/[. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) BICB 116 i from. M.LIJl 12. PERMIT NO. 14. 69ß.. 88 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPO RT OF: WATER SHUT-OFF § FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) REPAI RING WELL ~ TEST WATE R S H. U,T_OF,F.~ ' " P,ULL OR AL TE, R CASING ~ FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAI R WELL CHANGE PLANS (Other) Cleanout/Perf mere X... ALTERING CASING ABANDONMENT* (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. SEE ATTACHED HDATI..IY REPORT D:h1TAILEDI! ~ Œ ~ ~ ~W ,Œ W ,I I I. I . I~ I DfV:SfON Of OIL AND GA~ A~CHORAGE Sr. Petroleum Engineer DATE 7/01/75 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Form 911 "1·69 Printed in U.S.A. /-:--..., GIll "II 3 1/2 DP. 13 hra nipple' up l'ØJ! riser and BOP. Tee t BOP and choke end kill linea to 3000. Teat Hydril 1500 psi. lIt hrs PU 6ft bit. Jilt casing scraper and 3 1/2 DP and GIR" 6/2 3/7'~ Nippling up BOP. 1 hrfinish LD TBG and PKR. 19 hra testing BOP t leaking. change out ring:) retighten, 'Would not hold. Nipple d.own BOP loca.te 8..'lother riser borrowed 12" 900 riser from Union. l¡. hrs l·lD riser. §.!22/1r¿ PTD<~'S183 4 hr'RUÐchlumberger. Let preas down on tbg. GOOR. w.tbg gun. Perf tbgfour 1/4" shots at 4790. caOH. RD Schlumberger. 1 hr RU. Circ downtbg. ,Displaqewatel"w/csg. Condmudin pit,s 1 hr. Circ short t1mev Ill. 3 mud. Well dead. 12 hr nipple up BOP ~ , LDtbg. 4 hra nipple up BOP. 2 hra test BOP to 1500 psi.. 9 hrs pullpnckerloose and C t"4 CGrn~. 1 hour RU, Otis and pull BPV. 8 hra RU pmrer,tongs Ðnd 1.1) hn tbg. RUOtlsto pull ball valVe. PTÐ 8183. 14 hra finished movingrlg to Well 10. 1 hrboltdown aub1ncse 9 'hrslRU belplns'Welder~. PTD-.8183. RU Schlumberger to perf tbgto It!ll well." 8 hr$ RU Otis. ,Pull ball veJ.ve snd runbaek press valve. Bleed Qff presse.l1d RD Otis. 14 hra pumplo4bbl mud down tbg to kill well. Bleed off 450 lb. press tbf; . would bleed to 0 11). press but cont flow in g.- Bled 1400 psi off cag. .. Cae: 'Would contAnueflowing gas cut water. 2 hr RD Otis. RU Schlumberger to pUtlchholea in thg above PKR to circ and kill well. _. TQTAL .Q.AI..E .. ,', ... > D EJ'S T H NATURE OF WORK PERFORMED ) SHEET NO. WELL NO. A-IO ". DIViSION OF ·.OIL AND GAS. A~,,'CHOJV\GE Form 911 1-69 Printed in U.S.A. {R{œ@ŒIWŒ~ ) ¡ ¡ ¡; C. í6: FINAL REPORT Final tbg setting - 7691' old RKð (7675 rES). Fin cire aut w/mud w/bay. water. Spotted fresh caustiJcwater in 4" x 7" anulus. RU Otis. Pulled dummy sesSV. Set cire valve in Q n1pplevr/7688' old RKB. Set Otis RH pkr at 4884' old RKB w/3000 psi. Tstd 4" x 7" anulus and pkr to 1000 psi - o.k. Pulled cire valve. Set Otis sessv at 272'. Tstd opening. To skid rig to Well A-II. 6/27/75 Mud Date: 8.5 I Sea. Water Cire out w/seawa.ter. completion string to 7342'. New RTmeasurement. RU , Schlumberger. Ran GRNcorrele.tion log. End of tbg location at 7333' tES. RD Schlumberger. Finished GOOH w/completion string for 342 add! tional feet and landed tbg ",/back pressure valve in place. ND BOP. Pull back press va.lve. UU XT. tstdXT to 3000 psi. RU to Circout mud. Now Cire out. Ha.ve tsted SCSSV 1/4" line and dumrl\V to 5000 psi. Have tstd KBM Mandril to 2000 psi. Finish GOOH. Tag bottom a.t, 7756'. Circf bQttoms up a.nd cond mud to 11.5 ppg. .' vlsahed rat hole to 812Go1d RKB. Could not wash deeper. Reeov cmt part in mud return. Cire out. eaOH RU Sehlumbarger. Testd sho~ing nipple to 1000 psi -o.k. Perf e.s follows: 5677 to 5702IES 5392 to 54l7IES 5270 to 5280 IES 5163 to 5193 rES 5111 to 5151IES Mud Data: 11..5/43 I 7.5/ 2/ 18 /261 8.0 /440 Finishedpe.rf 5008 to 5088' . 4890 to 4990 ¡ES. All perf 'w/.4HHyperjet w/four holthperft..RD Sehlumberger. WTI:I w/bi t. Clrc& CM. caDH. Now r1.111ning completion string.. ,', b')'¡ô/2'41'7'~;" ¡:!,{::'~:J.;':}i';i' PTD: 8120,: Mud Dat a: ·····.'11.5/44 D8¥s ·.·Fe Spud.: , 6, TOT AL MI.E. DEPTH NATURE OF WORK PERFORMED 11.-10 SHEET NO. WELL NO. " ~) DAILY REPORT DETAILED I~: For:~ i 403 ',Rff'" .1-10-73 Submit "I ntentlons" In Triplicate & "Subsequent Reports" In Duplicate ') ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE 5. API NUMERICAL CODE 50-283-20030 6. LEASE DESIGNATION AND SERIAL NO. ADL - 17589 SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to d rill or to deepen Use "APPLICATION FOR PERMIT-" for such proposals.) 1. 7. IF INDIAN, ALLOTTEE OR TRIBE NAME OIL D GAS C1 WELL WELL~ OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Philli s Petroleum Com an 3. ADDRESS OF OPERATOR P.O. Drawer 66 - Kenai Alaska 4. LOCATION OF WELL At surface Leg 2, Slot 6,1304.2' FNL, 1022.7' FWL, Sec. 6, TllN, R9W, S.M. BHL 2505' FSL & 4115' FWL, Sec. 31, R9W, S.M. 9. WELL NO. 611 A-IO 10. FIELD AND POOL, OR WILDCAT North Cook Inlet 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) See Item 4 BHL 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 12. PERMIT NO. RKB 116' from MLLW 14. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: TEST WATER SHUT-OFF ~ FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING ~ MULTIPLE COMPLETE- ABANDON* CHANGE PLANS WATER SHUT-OFF § FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) Cle an out &. Perf (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertInent details, and give pertinent dates, Including estimated date of starting any proposed work. REPAIRING WELL ALTERING CASING ABANDONMENT* t;/2-? /)5 f"\ 1...../ ¿ I SEE ATTACJED "DAILY REPORT DETAILED" oJ ¡'S <)0 {R{~©~~WŒ~ dUL 1 b I~; ~j DIVISION OF G L n"¡,, U,1J AN'HO~';~ Sr. Petr DATE ?ð/ß TITLE APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side <::¡~ IL v '-fè~ ~ ~ ~ y GIll v/ 3 1/2 DP. 13 hrs nipple up 10" riser and BOP. Test BOP and choke and kill lines to 3000. 'I'eat IIydri1 1500 psi. Ii hra PU 6° bit, Jilt casing scraper end. 3 1/2 DP and GIE" Nipp11ng up BOP. 1 hrt"inish LD TBG and PKR. 19 hra testing BOP, leeking, change out ring, retighten t would not hold. Uipple down BOP locate another riser borrowed 12lf 900 rIser from Union. l~ hI's l.fD riser. PTD..:: 8183~' RU SChlurnberger to pe·rftbgto kill veil. . 8 hra RU Otis. Pull 'bnll v81V(¡) sndrunbackpx-essyalve oÞ ,Bl.,~d Qffpress a11d RD otis" 14 hra pumpl04bbl'mud down tbg<to kill w611. Bleed.. off 450 lb. press tbg would·Þleed. toO .lb.pressbutcont flow1ng.Bled1400 psi off csg. Csgvouldcoutinueflowing gas cut wa.ter. 2,hr RD otis. RU Sèhlumberger to punCh bolesi~ tbg above PKR tocirca.ndkill well. PTD ......"81;83 '!ì hr RU .Schlurnberger. Letpresa ~ontbg... GOOH.w..tbg gun Perf tbgfoUr 1/41' shots at 4790. COOH~, RDSehlUTJiberger. 1 hrRU. Cire ~owntbg. Displace waterv/cs(l,.Condmudll1 pits 1 hr. Circshort time v/ll.3 mud. Welldend. 12hr nipple up BOP. LD tbg. 4 hrs nipple up BOP. 2 hra ··te$t BOP to 1500 psi. 9 hra pull packer loose and C g~CGCM. 1 hour RU Otis and pull BPV.8 hra RU power tongs and IJJ l~H tbg. Ihrboltdownsuõ be_sa ¡tU Otl'>to~U11b~lve.lye.·. "1>8183. 1~,~~EJ·.fin1$h~dmQ,!ing rig. to Well 10. .9h~øRUbelp1ngWelder.s. ^,. .', .... .~,t:' ' . , ~ '''''', ' '< .~. ~. Form 91 1":':" ~9 .Î . 6/23/75_ £L22/72 9 L2J./Ti ¡;I, TOT AL DATE DEPTH NATUREOFWORK PERFORMED '. ,tff· . WELL NO. A-lO SHEET NO. DAIL '{REPORT DETAILED 1 "," '",. 6[241.12.. .' . i,'"j,., PTD: 8120"..:'" ,.. ........... MudDate.~ 11.5.]44 Days FRSpud :,' :: "',.<';/,«:,~:, -/ -":),,:,¡:,;;"""" Finish QOOH. ..Tag 'bot~om at 7756'¡, . C:trcbo~torna uþandcend ;rn.ud. to 11.5 ppe;,"V1 a.shed rat heleto 8120 old RKB. Cou1d not wash. deeper. '. Recovcmtpa~~nroudreturl1'" Circ out . '. COOH RU SChlUt!l"erger. Testd shorting nipple to 1000 psi - o.k. Perf .8S....follows ~ : ..567Tto5702 IES ::'(:5:392 to5 417 ..XES 5270'to5280IES' 5163 to '5193 lES 5111·.tO 5151' rES Mud De.ta: 11.5 /43/7.5'/ 2'/1812()I8.Q/ 440:: finished p6rf5008 to5088t. ..4890 to 4990IES. j\llperf w{4H.HyperJet w/fourho14sperft. F.D Sch'1umberger. ~¡IHw/bit. C1rc& CM:. COOR. Now runningcoIDpletionstring. Mu.d Data: 8.5fSeaWater Cire out w/sea water. Ran completion strine; to 7342'. New HT measurement. RU . Sehlumberger. Ran GRNcorrelation log. End of tbg location at r(333'IES. RD Schlumberger. Finished GOOH vlcor.npletion string for 342 ad.di tional feet and landed tbgw /back pressure valve in place. ND BOP. Pullback press valve. NUXT. tstd XT to 3000 psi. RU to Cire out mud. Now CiTe out. Have tsted sæsv 1/4" line and dlmunyto 5000 psi. Ha.ve tstd KBM Mandril to 2000 psi. 6/27/75 FINAL REPORT Final tbg setting - 7691 told RKG (7675 rES). Fin cire aut wlmudwlbay water. Spotted fresh caustfc water in 4" x 7" anulus. BU Otis. Pulled dummy Sq3SV. Set cire va.lve in Q nipple 'Vi /7688' old R.ìŒ. Set "Otis RH pkr at 4884 told RKB w/3000 psi. Tstd 4". x 7:1 anulus and pkr to 1000 psi - o.k. Pulled cire valve. Set Otis sæsv at 272'. Tstd opening. To skid rig to -í1ell A-l.l.. r Ô 1"( , . ; :;.. . > -f ...... !rorm P-3 ¡U;V. 9-3Q-6.7 '_\ Subnùt "In. tentlons" in Triplicate & "Sub.se<¡uent Reports" in Duplicate STATE . lASKA Oil AND GAS CONSERVATION COMMITTEE ) 5. .~:r>l NUMERICAL CODE 50-283-20030 6. LEASE DESIGNATION AND SERIAL NO. SUNDRY NOTICES AND REPORTS C'N \VELLS (Do not use thi$ form for proposals to ddll Ol~ to deepen or plug back to a diff'ierent reserV'Oi:r. Use "APPLICATION FOR PER¡vllT-" for such proposa1s.) ADL - 17589 Wli r.~ ~ { 1. 7. IF INDIAN, ALLOTTEE OR TRIBE NAJ."V1E OIL 0 GAS 1::1 W&LL WEL.L tXJ OTHER 2. NA.l'I.IE OF OPERATOR . Philli. s Petroleum Com 3. ADDRESS OF OPERATOR P. O. Drawer 66, Kenai, Alaska 8. UNIT FARM OR LEASE NAME NOm 996n 9. WELL NO. A-IO 4. LOCATION_OF WELL At surface Leg 2, Slot 6,· 1304.2' FNL, 1022.7' FWL, TllN, R 9W, SoMe ...:!3.HI. 2~05 ,- FSt & 4ll.5' FWL, Sec. 3:1., ,+l2Nj R 9W, S.M. 10. FIELD ANt> POOL, OR WILDCAT North Cook Inlet 11. SEC., T., R., M., (BO'ITOM HOLE ' OBJECTIVE) :- See Itém;4 BHL "~-I 13.EI.EV ATIONS"(Show whether DF, RT,GR, etc. ~. 12. PERMIT NO, RKB 116, ·fromMLLW., . ." ~-' . t -6~$$ ;:,~:';\{ : 14. . Check AppropriattJ- Box 1'0 'indicate N~ture of ~t¡~e,.Re~, ~ ~~ fata ~-:. ~ ;7~ ,:,":;::-,"::,'~' . : ~;. '-:L TO" w.....aOM:·r r-a:: : "LTCa m"il w...j~~~~ ~ .~a~NT_~~' :::.raINOWaLL I~ J'RAC'tCBJ: TaUT. '. . . )tULTIPLJI COMPUTE . J'RACTUÙ TaJl.U:XJlÑT:·:; , ALTZIUNG CASING 8. H. 00. T,.oa Å, C..IDII1II_. ÅBÂNDON~ ,.. .BOO"~ o~, 'CIDl:,"f --; ....OON".a.·_ REPAIR WI1LL CHANGII, PLAloJ&, (Other). ' - (NoTII: Report reøult. of multiple completion on Well (Other) Cleanout Perf more x Com letion or Recompletlon Report and Log form.) IS. DESCRIBE PROPOSED OR CO~IPL¡¡:TJ:D OP!JRA'tIO:SS (Clell1"l1 8tate aU petthieut detaUs, and:;tve pert1.nent dates, Including estimated datI! of starting an>' proposed work. ,..., ":::" ." _:;¡ 10 Rig up. Kill well with 1103 ppg nIlld. Removetreè.~-I:ri1t~16:jJ4-5ºÛO# WP riser and 12't..3QOO# WP double gate preventer and:,RYdril. .: Test BOP and'. riser. 20 Pull 4" tbg and retrievable packer. 3. Perforate Cook Inlet Pay 4890'- 5704 'MD RKB overall. 40 Run combination 4" X 3 J./2~t-tubing string with otis' subsurface~afety valve set about 270' RKB and Ot,is retrievable packer set about 4$.70' MDRKB, anct'tubing set 7677' MD RKB. ;,. ' . .','--::: 5. Install tree and displace mud with ·:water. Set :t:w~aulic pac:kere:'Test packoff. 6. Glean. up well and conduct 4 Point BPr. 7.· Ut.µ'ize as a producer commingled in"90ok, Inlet and Beluga.Pays..~ . , "lRl [E,~,,~ ~. ~Œ ~ _. ::..: U f'¡ .:. 6 :,'7/ >;) ':,: d1V~SI()I\r Of C?1L' AND GAS :~ ~'AlXCHORAGE' . ~t:i.mated start of operations is. 6/16/75 DAn; 6¿:~-1< APPROVED BY CONDITIONS· 0:5' TITL1D ?j;" £~. DATm 'f¡'/~r See-'~dions On ,. Reverse- Side Approved Copy f:~t¡.:rn(;(3 ·'117/~ --_..-~" .._. ---.' -. . :\ " ') ') I D_IR ..-trt, . I C. GEOL l-é~ENGT ¡f"ENG-1 I 2 -ENÖ- I :fE'NG ~r4-ËNG-T -fTENGl- -f1'GEOll~ -'--¡-2 'GEOL---' /! -\---3' GEOCî--- I REV -, -r-' r[5ì~AFT1-- I -SEC --r---- C6ÑFER~----- FILE: <=t ~ PHilliPS PETROLEUM COMPANY ANCHORAGE. ALASKA 99501 __ 515 ··D" STREET EXPLORATION AND PRODUCTION DEPARTMENT August 25, 1970 Division of Mines & Minerals Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. T. R. Marshall, Jr. Gentlemen: Attached, please find the original and two copies of Form P-7, Well Completion or Recompletion Report and Log, Chronological Well History from date of re-entry to final suspension, and Perforating & Squeeze Record for NCIU Well #A-IO. Yours truly, JBG: jo Attachments PHILLIPS PETROLEUM COMPANY //'1 & Alt' -:- ~ I / /£ ~' "-J I /onn . i 0 U District Ofn e Manager RECE!VfD f\u'r: 2 (>! ~I07CJ r~ u I ,Jf ' ) DIVISION OF OIL AND GAS ,ANCHQRAQI!! - ." 1 " "',~ ~orm P"""::7 J ); """D'~,,, . . SUBMIT' IN DUPLi ) /V ~IATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE (Sl'l' other in- structions on reverse side) 5. API NUMERICAL CODE WELL COMPLETION ORRECOMPLETION REPORT AND LOG * API 50-2B3-20030 6. LEASE DESIGNATION AND SERIAL NO. la. TYPE 011, 0 WELL b. TYPE OF COMPLETION: NEW {; wOnK 0 DEEP- 0 WELL U OnJR EN 2. N.Ur(~ OF OPERATOR GAS GiI WELL ~ DRY 0 Other ADL-l 589 7. IF INDIAN, ALLoTTEE OR TRIBE NAME PLUG 0 DACK DIFF. 0 ' nESVR. Othl'r 8. UNIT,FARM OR LEASE NAME Phillips P~troleum Company 3. ADDRESS OF OPERATOR North Cook Inlet Unit 9. WELL NO. 515 IID!I Street, Anchorage, Alaska 99501 4. LOCATION OF WELL (Report location clearly and in accordance with anll Bt te requirementø). At surface Leg 2, Slot 6, 1304.2 I FNL, 1022 .7' . F'ttJL, Sec. 6, TIIN, RQW S.M. No~·h (!ook- Inlet Plàtform "Ty:onekf' F~~:~i~;';te~~po;: ~ê!;~:o¥J~, Pi~, 5g<:~: MD, 3925 I TVD, 3501 2505' FSL & 4115' FWL, Sec. 31, T12N, R9W, S.M. A-IO 10. FIELD A4ND POOL; OR WILDCAT Se c . 31 12. PERMIT NO. S.M. 13. DATE SPUDDED 14. I)ATE T.D. REACHED 15. DATE COMP,SUSP.OR ABAND. 16. ELEVATIONS (DF, RKB, RTf GR, !:I'C). 17. ELEv. CASINGHEAD 69-8B B-22-69 RKR 116 I from M1L~l 73 t from MLLW . IF MULT:EPLE COMPL., 21. INTERV ALS DRILLED BY HOW MANY· ROTARY TOOLS CABLE TOOLS 18. TOTAL DEPTH,MD & TVD 9. PLUGBA.CK DEPTH B2 0' MD 6240 'T B183t MD 6194' TV 22. PRODUCING INTERVAL(S), OF THIS COMPLETIOiN"--TOiP, BOTTOM, NAME (MD; AN 23. WAS DIRECTION AI:. SURVEY MADE Beluga Sands 5949' - 766B' M.D. 24. TYPE ELECTRIC AND OTHER LOGS RUN AUG.2 7. .197Q Yes IES, FD C & SNP 25. CASING SIZE DIViSION OF Oil AND GA~ CASING RECORD (Report all strings set in well) ANCHORAGI WEIGHT, LB/FT. GRADE DEPTH SET. (Mt» CEl\iLNTING RECORD AMOUNT PULLED 26. SIZE LINER RECORD TOP (MD) 27. BOTI'OM (MD) SACKS CEMENT* SCREEN (MD) 0' 28. PERFORATIONS OPEN TO PRODU 0 (Interval, size and number) 2V. ACID, SHOT, F.aAC"I'URE, CEMENT SQUEEZE, ETC. SEE ATTACHED PERFORATING & SQUEEZE RECORD DEPTH INTERVAL (MD) AMOUNT I~,KIND OF MATERIAL USED 30. DATE FIRST PRODUCTION NOT PRODUCED PRODUCTION DATIC OF TEST. HOURS TESTED CHOKE SIZE FLOW TUBING ING PRESSURE CALCULATED PREss. 24-ROUR RATE . 1. DISPOSITION OF GAS (Sold, tued lor tiel, 'Vented, etc.) Record TITLE District Office Iv1anager ~, DATE August 25, 1970 *(See Instructions and Spaces for Additional Data on Reverse Side) .. " and log orY completi,on II INSTRUCTIONS a complete and Genera This form is designed for submitting all types of Jands and leases in ~,Iaska J .J " ~J 'j , . rj report depth measurel , 1 '11 for show,n) we otherwise correct referer:.ce (where not n any attachments. is used:as form and which elevation ef'spaces 'ont'Ìhis D , ) ) . zon~' nterval~ a sepa,rate report seperåtely produced. show" - '~ 0 'J the details of any mul- ~ervå at ( '1 . 1 separately produced. - ) , 1 from more fhan one the prcducing int,erva n item 30. Subri1it to be be show shou 1d D interva production 22 show ') to î 1 r ) . GEOLOGIC MARKERS ) VNAME 35. AND .RECOVERIES OF OIL, GAS. TESTEn, ,PRESSURE DA TÀ šWATER AND.J\fUD ~'"TS , ) ~J ) , , - , - :-J - } ) , =¡ , J ) . »" '-" ..J '" ') " j ) :Item: 16: Indicat+ me..,ts givepjrrc1J1 Items 20, '!"~~i~: Y~this. wèìl is completed for separate (multiple co:mpletjo'ñ), 'so state in 'ite"l 2Q", and in itèm top(s), bott~(s), ;nçi~ame (s) (itanYl.for. qnfy ¡the. ihterva (reported (page) on Cft1ß ~forn<P,J'àdequately'vi~entified,_f.òr 'each additional ¡ntel vß ingthe a~~~~a.t :~1a pertinent" to such fn~r~al.) I T.I!,"""I J,' -". 1,. I - 1t8m26: "Sacks,cément":. Attached suppIEtftl~nt~1 i'e(:ords for thiswel tiple stage ~me'1ti99.anddhelocation of -th~ fementing toot - '- -", ",.' , ~ - ..,¿ - Item 28: Submit a ~eParðte' completion repé>rfon thi~ form for eaëh (See instruction for items 20 and 22 above): ...... - - -- ......-- ) ,f) ~ ~¡ -~-1 U'fcltUI1It'fG ~"' l"ERV AL 1 ~ , ) L ì J- :) " .J APPARSNT OIPS , ) BRIEFOESq\IPITlONS OF LITHOLOGY. POROSITY.::YRActUJtES. AND DE'I'ECTE.IJ 'SHOWS 'oF OIL. qAS On. ~ATER. j' ~ ATTACII '-:) NGm WELL HA-IO 8-22-6' 8-23-6' 8-24/~1-6' '-1/11-6' '-12/16-6' '-17-6' '-18/27-6' '-28-6' '-2'/30-6' ) ) CHRONOLOGICAL WELL HISTORY Spudded 15" hele & drld to 650' & r.md. to 22ft. Ran 16't e.g. Set @ 631'. Gmtd w/440 ax Type "GU cm.t mxd. in 220 bb1s ,rehydrated 4% Gel wtr. Gmt ciro. Tailed in w/170 ax Type "Gft omt mxd in 20 bbl. FW w/2% co wtr. 650' WOR. Temporarily suspended. 2805 ' Dr1d 15ft hole t. 2805'. Ran 10-3/4ft oag. Set @ 2783 t. Cmtd .",/6]2 sx Class IIGtl cmt mxd in 257 bbl. 4% prehydrated Gel wtr. Tailed in .",/125 sx Glass "Gft cmt mxd in 15 bb18 2% 00 wtr. Drld '-518u hole to 8250'. Ran IES, SNP & FDC Log.. Ran 7ft csg. Set @ 8228 t. Cm.td w /320 ax Cla88 "G" cmt mxd in 103 bb18 20% Diace1 nDft in FW. 2nd. stage omtd w/89O ax Class UGU omt mxd in no bbls 2% cc wtr. Temporarily-suspended. TIds well has been logged and esg run. The tubing will net be run in this well and the well win Bet be perforated. until. some later date when the well is needed. 8250. t 82 50 t ,,~t~~'4 fa ~.Ü! 13\969 ÐiVI$lON Of Oil AND GAS ANCHOII\GI NCIU ilJELL # A -10 4-11/21-70 4-22-70 4-23/30-70 5-1/3-70 \ ) 51 3/70 CHRONOLOGICAL lißLL HISTORY \fiH & drld cmt 6405' - 6604'. vITH to float collar. Tested casing, O.K. Ran CBL to 8164'. Perf 5912' - 5913' w/4 ~!I shots. Squeezed 126 sx Type 'G' cement thru perfs into formation. Hax. holding press., 3,000#. Perf casing 58JA.' - 5815' s/4 ~II shots. Squeezed 116 sx Type 'G' cement into formation thru perfs. Max. holding press., 3,000#. Perf 5650' - 5651' w/ 5 !II holes. Squeezed 115 sx Type 'G' cement into formation thru perfs. Max. holding press., 300011. Perf casing 5557' - 5558' w/4 ~I! shots. Squeezed 121 sx Type 'G' cement into formation thru perfs. Max. holding press., 3000#. Perf csg 5582' - 5583' w/4 ~II shots. Squeezed 122 sx into formation thru perfs. Max. holding press., 3,000#. Perf 4814' - 4815' w/ 4 ~!I holes. Squeezed 123 sx Type 'G' cement into formation thru perfs. Max. holding press., 2650#. Drld out cement & tested perfs. Squeezed 86 ax Type 'G' cement thru perfs 5650' - 5651'. Max. holding press., 3000#. Drld out cement to float, tested casing to 2000#, O.K. Ran 4" tbg string. Set at 4840'. Ball Valve set at 276.79' & tested control line to 5000#, O.K. Packer leaking. Temporarily Suspended. RU. Pulled tubing. Dressed packer. Retested to 2000#, O.K. Pulled Ball Valve dummy. Perforated as follows in Beluga Sands w/4 .36n hole/ft w/ No Plug Jets thru tubing. Reran durrony in Ball Valve & tested. Temporarily Suspended. IES Measurements RKB: 5949' - 5959',6129' - 6139',6158' - 6163', 6181' - 6186',6210' - 6225',6228' - 6234',6424' - 6430',6462' - 6477',6508' - 6548',6694' - 6716',6755' - 6765',6919' - 6926', 7030' - 7050',7085' - 7090',7329' - 7339',7361' - 7366',7541' - 7547',7628' - 7668'. Q ;!"W- E \/ F /\ t 'i l' ; : ,r: ') ~'i f-\Uf.) ¡,." i DIVISiON Of' C¡L .<\\'0 GAS ANCl-IORAG~ ¡)\\f\:)\C:N Of C¡t ,t..':"<D GAS ANGiORAGi!: r " t:) ¿ ~,)r (~f, \,/ r f'\c.,. \".t" ,ri~ :' '1:1_, .. ._~ 'u,- ~ ).~.J Sltst - Gy, mod hd, calc; w/interbedded clyst, coal, and sand. Sand - Lt gy, fg, SA. Sltst - Gy, soft, 5li sdy; wjinterbedded sand & clyst. Sand - Lt gy, fg, SA; wjinterbedded clyst, sltst & 55. Sand - Lt gy, fg, SA; w/interbedded clyst. Clyst - Gy, soft, slty; w/interbedded sand & sltst. Sand - Med gy, fg, SA-SR. ClY5t - Gy, mod hd. Sand - Med gy, f-mg, SA-SR; w/interbedded clyst, sltst, and coal. Clyst - Gy, brn, buff, soft to mod hd, bentonitic; w/interbedded sand, coal, and sltst. Sand - Med gy, f-mg, SA-SR. Clyst - Gy, soft, slty, carb; w/interbedded sand & coal. Sand & gravel. SAMPLE DESCRIPTION PHILLIPS PETROLEUM COMPANY #A-10 N.C. I. Unit North Cook Inlet Field Cook Inlet, Alaska ) ) 6650 - 6770 6770 - 7030 7030 - 7060 7060 - 7415 7415 - 7545 7545 - 8250 o - 4000 4000 - 4290 4290 - 4515 4515 - 4800 4800 - 4880 4880 - 5800 5800 - 6650 , ;~t , *". BJ. Schlumberger " " .If " n " " II ft~- " " If " fI " " " " If II " II If 1\ " " II fI II 1\ It fI 1\ 1\ II " 'q. Schlumberger It " n . " n fI, n ", II " ,DJVJSION OF OIL AND G..S ANCHOR/ .:)E ç:~' 2.1969 ~'i,~~~ ' "Î ....1 HlB~ TRM " OKG /1' ;:" , ~_;._~_i. KL V -/-/',- HWK /1'-_" ~!iit:. JBG: jo Attachments (2) PHILLIPS PETROLEUM COMPANY ~~ ¿~~.~7y~;,....t-) Ihn B. Gipson,.,/, District Office Manager Sincerely, Enclosed, please find two copies each of Report of Sub-Surface Directional Survey, Phillips Petroleum Company, Platform "Aff, WellI/A-lO, North Cook Inlet, Alaska. Dear Mr. Marshall: Mr. T. R. Marshall, Jr. Division of Mines and Minerals Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 October 1, 1969 FILE EXPLORATION AND PRODUCTION DEPARTMENT PHILLIPS PETROLEUM COMPANY ANCHORAGE, ALASKA 99501 __ 515 "D" STREET ') ) / i- l 4 I¡. SYMBOL OF SERVICE 11 REPORT of SUB-SURFACE DIRECTIONAL SURVEY ( \ PHILLIPS PETROLEUM COMPANY COMPANY PLATFORM A A-IO WEU NAME NORTH COOK INLET ALASKA LOCATION 'I 1 , JOB NUMBER AM9-2869 TYPE OF SURVEY SINGLE SHOT DATE SEPT 1969. SURVEY IY onchoroge OFACE ..- o._aa UNO rf fAStCO IN U.s..... bL El L C C M P L ETIO_N_.___._JLf__e_'-'O__.R_T__d_____~_._.__:_ ____Ì'-AGJ; ___J. ,., ~---- ---- --~-----_.--_.----_._-. --....-~--.._.__..,,- PHILLIPS ~ LTR 0 L ~ U~ [0 M PAN Y ¡¡~ ELL A -10 PREPA_RE QBY_£C~__QiL~QL 6~___.____,-___T AN~NJJ~L.._M'EJHOPd·";;':'i .:11. ^~Ulli D., U_ .E__.'i___l___~_I__1...Q.li__.__~_..__._.__~__ U E P r H AN C L [ 0 1 i~, L. C TIC N T va S U ß '; E A U¡'~IGlr-~ LUCATCU AT ~/D:::; 650.00, TVù = 1 32 : 3 0 ' :~ 41il 73 1 . 62 762 t 45' N 3~~ 761.41 79:3 ... . I _A5-..!______Î''I ,,2_iL_______.__l_'l2.....1 J U¿4 ~ JO' ~ 23~ 022.70 \;~ 0 6 ') 4 5 ' ¡\! 3 5 L '1 0 3 . 5 2 LJ61.J It ü' N 36E ')65.36 1 Ù 2 9 1 j J · 1\1 3 1 !~ 1 J ¿ 3 . t.3 2 1 u 91 14 45' 1'1 361: 1 np,3. 7 e _.115.. 5.. . ,lÇ:_l.:3_!__~_j13~_.__lift 5 .2L...__. 1 2 it 6 1 9 0 ' 1'\ 3 2 i; 1 ? :3 1 . l. 6 1340 21 is' N 30t 13i8.87 l't.:L? 23 45' :1 321..: 1403.08 1 5 2 ') 26 0 · f; 35 é 1 4 8 6. 6 7 1617 26 . JO' _I 2j;~ 1 Ó)Ó9. 00 _._ll.1 ¿..__ _ __ __LQ_.__..Q.!____l:{_flL______ 1 6 :; 4 . j j 1 U 0 "7 2 (t 3 0 · 1'1 3 2 L 1 I L ü. ~2 j 1 (} 0 1 . ¿ ") 0 ' 1\] 3 -¿ ~~ 1. ~~2 6 .. 0 3 1993 ,2r 30' N 3221901.63 2086 2) 45' N 32L 1988.38 2178 32 O' N 33E 2066.40 ,-_2 21L._,.__...3 2..._..J.t!.. .___..1 L-3.1 L.____.2lih5 J.t.._ . 2365 31 30' N 31E 2211.15 245~ 40 0' N 31C 2289.16 . 2:3 53 it j 0 · f... 3 1 ':: . 2 j~) 7 . ':Ì 1 2647 46 U' ~ 31E 2423.21 2 H \.) 5 It (; 0 ' ì\J 32 L 2 ~}3 Z .-) 6 _,2 {Hi <1._ .___ .!tC.._'t2'_.__ ...i\_32..L___-.2.23 0..52 2)82 47 0' N 32E 2653.44 3101 47 30' N 34t 2138.39 3231 4U 30' N 32[ 2820.56 3 31) 6 It 9 0 · i~ 3 j I.: 2:1 C 2. 56 -------~.~.,'~-~.~----~~~~_..~ _._. ~---_..- ._--~--_._--------_#__.- ~.----"'-~"-'.~-'._-' ._~_._. ~ .U·_~.______···_____ ~___"~__ ._______~_. _____._~__..___,__._____~_.____.__ _~_.____ _ , 650.00, 631.62 66l.41 .Q9.:L. 13 7~~240 70 803.52 86).36 9:?.34082 9ß3.78 l.iJ '! ;:L.. 2_< 1131.26 121B.87 1303.C8 1386.6" 1469.0 () 15 .? ~... 3 1640.83 1726.03 1801.63 18;j~~.38 1966.40 2Q!:tf_..5.~ ZIlI.IS 21D9.16 2257.91 2323.21 24'32.96 _ n 24.9_º,! 5 2__ .,_ ,. 2 553 . 9 it 2638.39 2 7 ¿. o. 5 6 28Q?..56 -------->.-<--- -~--~~--,---~-----~_..~._---.----- _..._._---~..~--,-- ---., ~ l.OTAL COORDINATES C LOS U R. E S LATITUDE CEP ARIU.B~_,.J1LST AN~c...E___,AJiGlE DOG LEG SECTIÓN-~, ----.-----....-.--...., ...." SEY_ERIIY.DlSIANÇ(: , - - _. -~---_..-----..._--._--- _.'~---------------- --.--- L, A T I <rue E = 3__~__1_1_J ____~DdE_P-"_RI_!LR_f__~_~ ~_~ ~.7 8 . 92N 11 . :3QE ... _.._.1_~_~!tº.___ti__.5.1~.69 E.____º~O.ºO 14 . 05 11. a 1 N 13. :3 ZE ,.. __.___lI~S_<L.r( ._.~a~_~_~ E:_.__n__6~~63 _.__17 ~ ~ 1 ....j,,2~N ._I~.OC1E 21.70 .N 44.04E __~_182 .___~1-!.~4 20 . 31N 11 . 08 E___ _____Z 6 ~5_4 _~._4.0_~Q7 _E.__ ___ _:..5.126 Z º . 54 . J 31 .68 N 2 5 ~ 05f . . . 4Q~_9__N._3.8~3~r;__ . .2..461 40. 3 9 .~ 41.41N 32.12E . 52~4 J N..~I.J9E __~ .004 52. 39,,~ 1J2.98N 39.01.1; 65",63. 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Q Ü 24 6,} . 16 N ~64d 4400.UO 4300.00 2547.45N ~190 4500.00 4400.00 26¿3.0JN ~92 _"1._,____.. _ On.. __4.óilll.OO________ _L.LíOil__...G.o..._ '"_. 2691. 91N 606ß. 4700.00 4600.00 2111.11N 6¿D6 48UO.00 4100.00 2842.91N 6344 4900.00 4800~GQ 2912.81N 6481 ~OOU.OO ~900.QO 2980.49N 661D 5100.00 5DOO.00 3041.dON ___ 61.5 6-__._________ ~) ? 0 oLO"O"__-5.lo..tl...il..Q_____3li~ __9Q!'~L .... 6B9~ 5300.0D 52QQ.00 3180.96N 7034 ~4CO.00 53UO.GO 3246.ci4N 1175 5500.00 5400.00 3313.17N 1311 5600.00 5500.00 3379.41N 1460 5700.00 56CO.üU 3445.39N _....___1.6Q5_.. .no__ d_'"__.___ .5.HÜll..ÜQ ______3.1.CJl...c.Q 3512_eleN 7152 590D.00 5800.00 3579.67N JU9a 6000.00 jYOO.OO 3646.¿3N 0045 6100.00 6000.00 3J12.25N 6192 6200.00 6100.00 3778.21N .--- ,-~_..~_..----,_..'-"-- --~-.- »"-- - --'---~"--"--'--"--<"'-"--""""'~~ ~"-- '-"~-""-'- -._>. -, ,.-,-",-.-< -_--.--~----------,~---._. --...--- ,.-~~.-~.~.-"~""""'-~--'--------"'_._'- --..,.- ---------~. .-.-----.--------.... .__._-y.._~~_.._.- --,- ---~--.>--- 1334.95E 1410.8lE l483..~t6 E 1554.71E 1624.96E 1692.70E I1j8.40E 1822.51E .. 1 9 e4,..Q.5E.. 1 941 .6 2E_ _ __ 2010.83E 2013.77E 2139.11E 2205..58E . . 22.12.1J. 2E- 2342.73E 2413.49£ 2481.16E 2562.24E 2640.87£ ~2 122... 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"- - ..- ----~-----~.._-------~- ---_..._~........--_.__. ------.- .~-_.-----'-.- -- --~- - -.---- --~_. -. ,~---_.._-- --,-~-,~- ----.-- _._,---~~-~.- __'"> ..~.__.,___..._.._ __._ F·__'_. ___._~_____._._.._ _..__-------.._____.. ___. ._~,,~_.,~ .________....,.----c-___ . ____ -__~~.___ -- ._ .__.___. ___.___<_ -- -- .-.------------. "--~" ....-.-. --~-- :Þ ¡ t t - I ¡ . _: i ' ., ; ¡....:--~·--t.;...MF -( >- ~ f f = ~£)()f; - i ¡ 1- j --'---,-- ,--.- --+- -- - - ¡ ~. i I _u___._ i~----;-----. i- . ! -¡ ¡ - --- ----- .--.- i f -t j ! -.-.. I . A-IILLIP5 I'-'t-I t'ð . F1 t.A (IU='~ WELL' ^- W í- -- -----! ---1 . . ! PREPARED BY:.5CS .09/30/69 1 ~+~.:.~~-~---~-_.,._~ -~_.~:_--¡---~ ---~------_tt;~----~-~---r---=--- ~---- ---t~-_· ¡ I - I . , I- f -'-1 I --~ .~- . ----..-.-'---- ~f.~T~:F~~T'r~=-;~~~;::~·-:~-~~-r:~ ';": : $ , ~ 1 0,,-' ,.. ~- --~ ! . - . ; ,. ~ - , I ~E - " -', ..~ :'[~Cr..=-=:;+=:=T-:: :T===::!~ ?: k:-::-l-- ! ~-;i".," ~·-t ··:~tffl~;)?'¡r.f~1~-~=ttf~~::"1;C~t r - -. ¡ - ~ ~ - -. F~ -- -r - ~- ~--= - - ¡ 5cALE -~ - - L' - - ~- : - t ~ - - i -~ -' - -- ¡ -, : - - t : ¡ - - - ¡ -~-T~--;--:---t1. t7 = 6OO<t-~~-;---~~-;---:-T~o ~- -- ~-r=:=-:-':. 4 r - . - . -, t -- . , ..! i j - ~. -. - ! -, . 1- -- ; 1 - f ! A-iILLIPS --PETRCLE1.J..A -~ANY WElL A-:lO PREPARED BY! sc5 OS/ E !~T------Ti· ~-:-:-r:-o-~--:-r----~- ¡ -0 -I· I ¡ r ¡ 1 ¡ ! ._+_____.-.,-----.--.--I-----.---n _n -- _____1____.___._ ------..~---.-- :----J . ! i ~ .! I ! ----·,-~~···,·····-·'·~T"·-··· ·---f--- t I I -.--~j-- ! t 1 -i· ! ~ ¡ . I ~ - ....---.. --.,. '. -... ._~ , , ,....~. _.-. ---.....--- 0". ...~_.'...:._ , - . . -..... -.............- -. '.--- ....., --~.._.... ..~. ~...,._.,....- ..._..'--..._~'-.... ---~, , ~ ---.--..¡---.:---.'"""'-- "":' ...------·-··'r" --.. --_...~ --,~_. -----¡-----'- " <- t " ---.---...- .~- --'.. - -----...,.~--~ tn .~.. .-......---- .- ..__...;-,- -, -_._- ~ - '-f --.. --- ------, .- -~----_.._---_.. "-- .- ----- . ~ -'- --- ....- '--. '-~.--- - - - --.. -".- .--(...------ !----.... --" ~-.._----.. - - ---~ _.__.~. --- - .- -- ---""'1'-'- ----- --- ---- _.- --- ._~.__________.-L-..__._ -.:..,_____. __._~_______.___.___ __L-_ TVO= TM:J = ~:f Form P-3 REV. 9-30-67 SubmIt "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALA~KA OIL AND GAS CONSERVATION COMMITTEE , 5Ap! N5Q:2å3-20030 6. LEASE DESIGNATION AND SERIAL NO. SUNDRY NOTIC'ES AND REPORTS ON WELLS (Do not use this form for proposals to driJl or to deepen or plug back to a diffierent reservoir Use "APPLiCATION FOR PEPw.ìŒlT-" for such proposals.) ADL-17589 7. IF INDIAN, ALLOTTEE OR TRIBE NA.lYIE ~iLL 0 ;AESLL [] 2. NAME OF OPERATOR Philli 3. ADDRESS OF OPERATOR OTHER 8. UNIT, FARM OR LEASE N AlVIE North Cook Inlet Unit Petroleum Com 9. WELL NO. HA-JD 515 "D" Street, Anchorage, Alaska 99501 4. LOCATION OF WELL At surface leg 2, Slot 6, 1304.2' FNL, 1022.7' FWL, Sec. 6, TUN I R9W, S.M., North Cook Inlet, Platform HTyonek't To» of Pa.v~ 5000' MD, 3925' TVD, 350' FSL, 2550' FWL, See 1T td 3M 13. ELEVATIONS (Show whether DF. RT, GR, etc. RICB116t 14. 10. FIELD AND POOL, OR WILDCAT North Cook Inlet 11. SEC., T" R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31 T12N 12. PERMIT NO. I F-Pom MIJ..W 169-88 Check Appropriate Box To I!ndi'cate Nature of Nloti'ce, Report, or O,ther Data S.M. NOTICE OF INTENTION TO: SUBSEQUENT REPORT 01': TEST WATER RBUT·O" ~ PCCL OR ALTER C,"," § WATER SHUT-OFF § REPAIRING WELL ~ FRACTVRE TREAT MVLTIPLE COMPLETE = FRACTU.RE TREATM. ENT = ALTERING CASING = SHOOT OR ACIDIZE ABANDON- SHOOTING OR ACIDIZING ABANDON MENT- REPAIR WELL CHANGE PLAl'S =J (Other) Se.. Below - (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. D¡';~~~~~~e~n~~rs:.D OR CO~!PLETED OPERATIONS (Clearly state all pertinent detall¡,¡, and goh'e pertinent dates, Including estimated dat'i! of startIng anr Temporarily' Suapmded. WIHIe drJd CIIt 640St - 6601,.'. WIH to t10at colla~.'feate4 cuing, O.tc.. Ran OIL to 83.64'. Pert 5912' - 5913' w/4 tn_bote. . Squeezed 150 ax r,pe. !tan. __nt thrn perfs' into . to:nation. Max... holdiDI preaa,' ,(X)O/J. Pel'f .sine SEn4t... SSl5'w/A if' shote. Squ.e_ed n6_ ,...". UC)"oement into formation thru. perte. Max. holdine pre.., 3,tXJOI1. 'err ,650t -56511 wI ; in hole.. Squ..Iêd.US ax T1Pct !taft __rat iDtotoration thN perfs. Max. bolding preu., 3OOOfI. Pert .sing 5557' .. ;;S8' w/l:t.ln shota.SqWlØJØd 121 ex·T1Pct U(JH_at into toratiœ th'rUperre. Max. holding preu, )000#. Pert ·08.S582' - ssa,- W/4 in ehotlt. SqUHHd l22ø into' fo"..tion 'thru. pert.. 'Max. holding· pre., 3,tXJOI1. Pert 4834' - 4815 t wl,. iu 110188.SqueeHd. 12'_ T1Pct t1Gn oeman\ intotoration thru perle. Max. holdins pres., 26S01. Drld out caent It teeted perta. !que.Ad. 100 IX T1Pct tfG"cement thru perts 5650'- 5651', Max. bold1:ng pre., 30()01. Drld out ·c_nt to tloat,teated casing to 2fXJO/) t O.X. lW!..~nt~~_.... Se~,at ~,.Ba..n Valve .t at 276.79' &: tested control 11_ to . .'. , O.K. Paoker akins. 'r81ftPO_rily SU;8p8D!ed. RO. Pulled. tub1._ Dre_ød packer. Retested .to 2000', O.K. . Pulled. Ban Valve dUIIV. Perforated. ... toUowa inBel'up Sande v/4 .36ft hole/rt w/Ho Plug Jete 16. I hereby cert~ý that the ~Ore&Ó1n~ II tr~e ~~d correct SIGNED ,;/¡}.-/..,-. /";. ,,~/·-1) ;·{;ii'.....-.. i 5-3-70 4-11/21-70 4-22-7D A.-2,/'JO-70 ;-1/3-70 TITLE n1 At, 'tn~P. . M;v * May J2 ~ 1<170 DATE (Thil Ipace for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See 1!n·strucfions On ReveÁ~~F¡~'~~i~d RctuI nee! J'orm P-3 REV. 9-30-67 Subnút "Intentions" in Triplicate & "Subsequent Reports" in Duplicate PA.GE 2 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE , 5. APÌs0:2â3~20030 6. LEASE DESIGNATION AND SERIAL NO. SUNDRY NOTIC'ES AND REPORTS ON WELLS (Do not use this form for proposals to dÙll or to deepen or plug back to a diffierent reservoir Use "APPLICATION :FOR PER:.'\IIT-" for such proposals.) ADL-17589 1. 7. IF INDIA..'\f, ALLOTTEE OR TRIBE NAl\-1E OIL 0 GAS Cl WELL I WELL ~ OTH£R 2. NAME OF OPERATOR 8. UNIT, FARM: OR LE..'\SE NAME North Cook Inlet Unit 9. WELL NO. f11!~l'b!~F~~'. f!~1"~ IIA-lO 10. FIELD A..'\fD POOL, OR WILDCAT At surface Leg 2, Slot 6, ]3()A..2' FNL, 1022.7' FWL, Sec. TllN, R9W, S.M., North Cook Inlet, Platform UTyonektf TOt) or ra~: 5000' MD, 3925' TVD, 350' FSL, 2550t FWL, ~. ~l T]?U R9W S ~M.. 1'. :E:v IëmS (Show ~hether !>F. R'T, GR, etc. 6, North Cook Inlet 11. SEC., T., R., M.. (BOTTOM HOLE OBJECTIVE) 14. R9W I 69-88 Cht,c;k Appropriate Box To ¡'ndi'cate Nature of Nlotice, Report, or OltherD1ata S.M. ~OTICBl OF YiNTENTION ~O: SUBSEQUENT REPORT OF: TEST WATE. R .1!..."UT-OFr I. ·1 PCLL OR ALTER CAS". II WATOR snUT-O" § REPAIRING WEILL I i FRACTURE 'l'R'AT E I MVLTIPL!!I COMPJ.E1'E _ FRAC1'URE TREATMENT ALTERING CASING § SHOOT 0 R "C..I..:DIZE _I. ABANDON. _, SHOOTING OR ACIDIZING ABANDONMEN'T* = REPAIr., WELL J CHANGE PLAJIlS (Other) See Below (OU..\er) I (NOTE: Report results of multiple completion on Well _ . . ..' . ..... .....--J Completion or Recompletion Report and Log form.) 15. VES CRraE Id'IWPOSkED OR CO~! PI;Ji:TED OPERATIONS (Clell rly state all pf'rtinen t details, and "'I"e pertinent dates, Including astlma ted da t" of starting an ,- propose wor '. ... . "" 5-1/3-70 (Con' t ) tbru. t.Ubinli.Remn d'UllJW' in Ball Valve Ie teated. Teaporari~ SwIpInded. ms Keaøure..t. RKB:S'49'.-S"9t. '129'- 613", 6158' - 6163', 6161 t ... 6~t J 621Ø J -6225 t, 6228' .. 6234', 6Ul.. ,- .64)0-, 6462' - 6477', 'SOl.. 6548ft 6694' - 6716',6755'· 6765', 6919' - 6926', 7030' -70'" t f 7045 t - 7090', 73'29'- "'9', 7361 t_ 7366', 751+1 t - 7')4'1', 762$\' - 1668t. 16. I hereby certity' tha t the forel91nl '-18 true 'ani:fcorrect SIGNED ,/.. .('::,;../ "f ?" j. 7/,::;;;1" TITLE Met .oro P Mv· DATE May 12. 1970 (Thill IIPace/'for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY; TITLE DATE See 1!nstructions O'n Reverse S,ide Form P-3 'REV. 9-30-67 ) STATE O>F ALASKA OIL AND GAS CONSERVATION COMMITTEE Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate ) SUNDRY NOTIC'ES AND RE'PORTS O·N WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir, Use "APPLICATION FOR PERMIT .. for such proposals.) - 5. API NUMERICAL CODE API 50-283-20030 1. OIL 0 GAS m WELL WELL t:e:J OTHER 2. NAME OF OPERATOR Phillips Petroleum Company 3. ADDRESS OF OPERATOR 8. UNIT,FARM OR LEASE NAME PILI North Cook Inlet Unit 9. ~L NO. -... 515 liD!! Street, Anchorage, Alaska 99501 4. LOCATION. OF WELL Atsurface Leg 2, Slot 6, 1304.2' FNL, 1022.7' FWL, Sec. 6, TIIN, R9vv, S .~1., North Cook Inlet, Platform tlTyonekll Top of Pay: 5000' ~ID, 3925' TVD, 350' FSL, 2550' ~~) Sec. 31 Tl2N R9W S.M. See 1 S IV! 13. ELEVATIONS (Show whether DF. RT, GR, etc. 12.. PERMIT NO. RKB 116' From MLLW .' '. I' 69-$8 14. Check Appropriate Box To I!ndi'ca,te Nlature of Nlqt~'ce; Re'port,or,Oitber 'Data }-10 lQ. F~ AND,¡>00L. OR WILDCAT NOTICBI OJ' INTBlNTION TO: 8UBSEQUBlNT aBl~oaT 0.: PULL OR ALTER CAS DIG ~ WATER SHUT-o'l!'l' § REPAIRING WELL ~ MULTIPLE COMPLETE· FRACTURE TREATMENT ALTERING CASING ABANDON· X. saOOT,". ?S ACID"". = AS"008MO'T' CHANGE PLAJIIS (Other)' (Non: Report "results 'of multiple completion on Well (Other) See Below Completion or Recompletion Report and Dog form.) 15. D¡';SCRIBE PROPOSED OR CO~IPLICTED OPERATIO~S (Clearly state all pI'rtinellt details, and give pertinent da~es,lncludtJ'lg ,èstima~~ :I dat~ of starting an>' proposed work. ,. '. .....;". TEST WATO. SaOT·on ~ FRACTURE TREAT _ SHOOT OR ACIDIZE _ REPAIR WELL Re-enter ~^jell Il:A-10. Run Cement Bond L::>g, perforateandsq~e;~z~ anY~one~.· where cement no good, run tubing string, perforate Beluga Sands, .4' shots/rt â.t tne')~ntê'h-als listed below. Run 4-point test and complete to produce. . '." IES Measurements RKB:- 6225',6228' 6234', 6765',6919' - 6926', 7547',7628' - 7668'. 6179' 6184',6210' 6694' 6716',6755' 7362' 7367',7543' 5949' - 5959', 6129' - 6139' , 6158 , - 6163' ,6181' - 6186', 62101 - 6424' - 6430', 6462' - 6477', 6508' -6548',. l>694' - 6716', 6755' - 7030' - 7050', 7085' - 7090', 7329' - 7339', 73g1' - 7366', 7541' - SNP Measurements RKB: 5947' - 5957', 6127' ;;;;'6137', 6156' - 6161' 6225', 6228' 6234', 6421' 6427.'" 6459' 6474', 6505' 6545', 6765', 6918' 6923', 7030' -705Ò',' 7085' ..:.. 7Q90', 7330' - 7340', 7549',7628' 7668'. . f-- t: ,,-' I:"'" t i.~ P\P¡~ íJ / I \)",T::>C.;·,~ " C?AS IIN ç;.¡ Ç¡ J{AG ~ ~ITLE District Ofc. Mgr. DATE April 21, 1970 (:rhta 00 co Jor Sta to ,.,... P"") ';J 7j) APPRO D BY Lt, 4~/!-t<-<.. TITLE CONDITIONS OF APPROVAL, IF ANY: 11/7 DATE 4/ z:. t- íù ~ See 'nstructions On Reverse Side Approved -cop~ Returned - 4-0(>.:¿ -7 Q ;"10VO!(:1)or t I) ¡ 196':; ;;:'r. ,,john :.:. Gipson D i s tr i ct ()ff i ce f'~¡ana9ûr Ph i t tIps P~~t,..o I eWr~ Gornpany 5 t:j ,:, Lr I StieG t AI'K::hora~1t}7 p..fsSkrj 995()t Dear ,'·¡r. G t pson ~ kbÐ have racelved y(~ur mat'øriats on the ¡,,¡efU !i~edls Nos ...J\.-9~ f\'- f Olt A-It.. \~e ,arE! n];1turn t nqw I th thi s I attar approved cop i ~Ft$ of Forni f)·~3 for each o'f the we f is.. These af)proved co !)ies of Form P- :3 are cQnd i··· tt oned Oln the $ubmi 5S ton of Form P,,·7 or tl"eCÖHlp 1£3ti Q!'l report for (~ach of thê threø "",,9:1 ¡ s showfoq theJi1 to be SU5p~)nded. i~ Itof tt'"le f i 1 (;;~S?Jlppeer cOfnþlet(i~ ~!xcept for these F orn¡ P-7 1$. \fJhen thEa we t f S ,are f t nail y put on p rodu ct ion, we~ \'IOU t (/ 81'P rec J rJ! te neJ~' p.,,, 7 ts sho~J i"'9 th6~ I ni -t I a I product T on data.. Yours \t(..~ry tru ty, .-.¡.~~....' Harry ~~\ 1<&9 I€~r Petroleum Geofo9ist Hlr,¡ K ~ f#~Y En(~ I osures ) ) (I PHILLIPS PETROLEUM COMPANY ~ ANCHORAGE, ALASKA 99501 _ 515 ·'D" STREET - HlB ~:\. TRM . /Z; 0Jm #'~ Kt V ____ ____.,.. t'J\\/:( ~. 'l': EXPLORATION AND PRODUCTION DEPARTMENT ¡i.E" November 12, 1969 Division of Mines & Minerals Department of Na.tural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. T. R. Marshall, Jr. Gentlemen: Attached, please find original and two copies of Form P-3, Sundry Notices and Reports on Wells, Chronological Well History, Sepia and Blue Line IES Log for NCIU Well #A-IO. Yours truly, PHILUPS PETROLEUM COMPANY ~/ / \ / L? f .' //).~ / J..., . . .A.-J I John B. GiP~ {/ District Office Manager JBG: jo Attachments ~~.t'~~ t,O',} 131969 _n&&eaIM.I Of CI\- GAS 1iM.Y~AtIQtCIÅGI ,. ...' 't .., ,- --;~ i(' '(.' .- . .' Form V-3 REV. 9-30-67 ~ STATE Ù'F ALASKA OIL AND GAS CONSERVATION COMMITTEE Subl1Ùt "I51tentions" -in Triplicate & "Subsequent Reports" in Puplicate ) 5. API NUMERICAL CODE SUN'DRY NOTIC'ES AND REPORTS O'N WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PERMIT-" for such proposals.) ADL-l S 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. OIL 0 GAS IV1 WELL WELL ~ OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME North Cook Inlet Unit 9. WELL NO. Philli a Petroleum Co 3. ADDRESS OF OPERATOR 515 UD" Street, AnohGrage, Alaska 4. LOCATION. OF WELL <99501 At surface Leg 2, S1.øt 6, 11Q4.21 FNL, 1022.7t FWL, Sec. l>, TllN,RW, S.M...t....North Ceok Inlet,Platf$z,n.ttTyenektt ~::.O!lPa:., ~N~O~~,~. :¿,25f TVD, 3501 FiL, 2;;°,.01 Ft,lL, Oð...,.. '1!l.", .,I , 7" UV'\,¡jo,¡¡J TJ.2N, R'JW, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc. 12. PERMIT NO: RKB 116' From MLLW I ,. ' 6'-88 Check Appropriate Box To I!ndi(;ate Nlature of Nloti'ce,Report, QrOther :Data 14. NOTICID OF INTIINTION TO : SUBSIIQUIINT RIIPQaT 0.: :::::::::::~:T.orr B ::::::::·~::P~;::Y. § :::::::,.:::.'.:::'.:.. R.·.·.., ." ..... :::.::::~::::;. ~ REPAIR W'LL B CRAN.' PLA'S (Olh..>·· ... 5uePen12 Well Y (Other) (NOTE'.: Rèport rß8ults of m.U.IUPJe com.PleUon on Well Complètion or Recompletion.Report and Log form.) 15. D£SCRIBE PROPOSED OR CO~fPLETED OPERATIO~S (Clearly state 0.11 pprtinellt details, and give pertinent dates, includiniir estimated dat~ of starting anr propo8ed work. ..' This well has been drilled. to a TVD of 6241.', MD ofS2;Qt., BHL: 2;05' F~L, 4ll,1 FWL, Sec. 31, T1.2N, R9W, S.M. The well was then legged. ..~ 8&S~:~s::MUl. Geee Chronolegical Well Histø:ry attached). The well will not be perferateduntil søme lat~r date when well is needed (Est. 4-5 years). Also attached, please find. Sepia and m.ue Line !IS Log. ¡ßtr.!vta f' U-·~ I 1 ~ 1969 \;"t \j U , '. DIYII&~OAI SIGNED Dist. Ola. Manager DATE November 12. 1969 e or State omc;..~) APPROV D BY (fKðl..aÀc:rÆ·· ~ CONDITlONB OF APPROV AL, IF ANY: TITLE a, 7 ß..hltu- ~,¿"" l ~ DATE / / -/ý-¿' Ý See 'nstrudÎons On Reverse Side Form No. P-4 REV. 9-30-67 ) '> ~~~ -Wi.. OKG --"1' 5. API NU:VIERICAL CODE KL V -' jf G,. API 50-283-20030 H\VK -- " 6. LEASE DESIGNA !ION AXD SER\t'ft, NO " ~ _ . I rtl:l. ADL-l7589 .._ 7. IF INDIAN', ALOTTEE OR TRIBE mlE ¡,;; -- STATE OF ALASKA SUBMIT IN DUPLICATE OIL AND GAS CONSERVATION COMMITTEE MONT'HL Y RE;PORT OF DRILLING AND WORKOVER OPE;RATIONS 1. OIL 0 GAS r:ü=\ WELL WELL L.6J OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME #A-10 10. FIELDA..~D POOL, OR WILDCAT Surface: Leg 2, Slot 6, 1304.2' FNL, 1022.7' FWL, Seo. 6, TllN, R9f¡f" S.M., North C00k Inlet, Platførm u'I'yoneku Tom of Pay: 5000' MD, .3925' TVD, 350' FSL, 25501 FWL, Seo. 31, TUN, R9W,S.M. North COQk Inlet 11. SEC.. T., R., M.. (BOTI'OlVI HOLE OBJECTIVE) S.M. 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS. TESTS AND RESULTS. FISHING JOBS. JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HO~ CONDITIONS. 6 -SS 9-.30-69 S250 f 9-1/11-69 9-12/16-69 9-17-69 280 5 t 9-1S/27-69 9-28-69 9-29/30-69 82501 SIGNED This well has been logged and csg run. The tubing will not be run in this well and the well will not be perforated until some later date when the well is needed. Temporarily suspended. Drld 15'1 hele to 28051. Ran 10-3/4" e.g. Set @ 2783'. Cmtd w/612 ax Cl.... ftGU cmt mxd in 257 bbls 4% prehydrated Gel wtr. Táiled in w/U5 ax Class UGH omt mx.:d in 15 bbls 2% co wtr. Drld 9-5/8" hole to 82501. Ran lES, SNP & FDC Logs. Ran 7'1 csg. Set <t S22SI. Cmtd w/320 ex Class fiG" cm.t mxd in 103 bbls 20% Diaoel ItDtt in fresh wtr. 2nd stage cmtd w/S90 sx Class ItGn cmt mxd in 110 bbls 2% co wtr. Temporarily suspended. ItEtt~VtJ OCT 1 f, 1969 PIVISlON OF Oil AND GAS -. - - ANCHORAGE District Oft\- Mg'r_ DA~ October lS, 196Q OTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicatt with the Division of Mines & Minerals by the 15th of the succeeding mo nth, unless otherwise directed. Form No. P-4 REV. 9-30-67 '- ) STATE OF ALASKA SUBMIT IN DUPLICATE OIL AND GAS CONSERVATION COMMITTEE MONT'HL Y RE!PO'RT OF DRILLING AND WORKOVER OPE;RATIONS ~ ........... 5. API NUMERiCAL CODE 1. '!V API 0-283-20030 " '~:: DE:GNAnON m SERtAL NO. 1; ~ 7. IF INDIAN', ALOTTEE OR TRIBE NAME L- OIL 0 GAS r::l WELL WELL 6ð.J OTHER 2. NAME OF OPERATOR Philli s Petroleum Compan 3. A DRESS OF OPERATOR ~- '-',""""",~ 8. UNIT, FARM OR LEASE NAME North Cook Inlet Unit 9. WELL NO. 515 IfDf1 Street Anchora,p'e 4. LOCATION O'F WELL 99501 A-10 10. FIELD A......D POOL, OR WILDCAT Surface: Leg 2, Slot 6, 1304.2' FNL, 1022.7' FWL, Sec. TllN, R9W, S.M., North Cook Inlet, Platform. uTyonek11 Top of Pa.y: 5000' MD, 3925' TVD, 350' FSL, 2550' FWL, Sec. 31, T12N, Ro/w, S.M. 6, North Cook Inlet 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIvE) Sec. 31, T12N, R9W, S.M. 12. PERMIT NO. 69-8£5 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS. TESTS AND RESULTS, FISHING JOBS, JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOU¡: CONDITIONS. 8-31-69 8-22-69 $-23-69 6501 WOR. 8-24/31-69 650' Spudded 15ft hole & drilled to 650' & rmd to 2211. Ran 16n csg, set @ 631', cmtd w/MO sx Type UGH cmt mxd in 220 bb1s pre hydrated 4% Gel wtr. Cmt circa Tailed in w/170 ex Type nGtt cmt mxd in 20 bbla ~v w/2% cc wtr. WOR. IUt~!4\iJ ~.J ~. r.-~: 1 ¡:'; 1969 J ~IVJSION OF OIL AND GAS ANCHORAGE TITLE District Ofc. Manager DATE September 12. 1969 NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding mo nth, unless otherwise directed. ') (("\\ ¡ ¡ ¡ ! Ii ¡ ¡ \ \j :' '-......./ n j! ! ¡ L~J \1 ! ! I í . ( I I / / 10/8 filmiiiAT/DNA[ AIRPûi!T RD,1B<.... .~V) .,' " .'; r: if (V{t¡I;:: 9 q;:; fJ?: '1J1oH) ., H¡I~~,~V~. iIo4l... ",-Jv~_ ,. ~=~ H\~K ~ ~~ Iff/Ti1 No !iI/iLEU, GD~!£aliDR September 9, 1969 - mE .. _,1Jt'li Mr. John B. Gipson District Office Manager Phillips Petroleum Crnnpany 5"J 5 [) Street Anchorage, Alaska 99501 Dear Sir: 'Re: North Cook Inlet Unit, #A-10 Phillips Petl'oleum Company, operator In reference to the subject offshore drill-site the following stipulations are required to protect fish and game resources: 1. No material foreign to the environment will be discharged from ·Uris platform. Th'js "includes garbage, ty'ash, refuse, petroleum B.nd/or its pr-oducts, dr"¡ 11 i ng mud, and debY"¡ s. 2. Drilling operations are not to interfere with commercial fishing" 3. The Habitat Biologistls Office, 1018 West International Airport Road, Anchoraaea Alas 99502 will be notified priot' to abandonment of this loc~t~o~" Statement: The foregoing provisions do not relieve the lessee and/or his contt¿~cto\"':; or ëJ.sS"jgne0s of a.ny respons'¡bï -¡-tics or prov'jsìons y'eqtrired by -Jri'l! (¡'r '·'-·'-::ill"j--t-"Jo"'" C'c "'e,IOta S-!''''':-r'\ O'f" lila-:-k-' Oì" + 'le ,r:pr!,::It-'l CíO\fe-,,.,,·~·I,":':·"I+ c.>, ., 1'--:::_. (.I. ,,¡}I I;t,.., l,O.\...·_ I', ~~, ,,(.\ v 1_~c..\,. o. ~.\ ¡ "'i~' "'" /.J ./ . ~..;d? S í rf ¿ ere 1 y .,r ",' (;J: c: c : B" ri'; '11 i k [~ i" H, BUì'T211 P. D2í¡tr);! RECEIVED (- --, 111969 DJYJSION OF OIL AND GAS ANCfIORAGE J! .1~·,l rl <? Robett Habitat Bio f: ~ ') ) PHilLIPS PETROLEUM COMPANY ANCHORAGE, ALASKA 99501 ___ 515 "D" STREET EXPLORATION AND PRODUCTION DEPARTMENT IICEiV£i} "IIG2 ~;1969 QIVISION OF OILANQOAS ANCHORAGE--" August 22, 1969 Re: Spud New Well - Nem #A-10 Director, Division of Lands Sta.te of Alaska 306 W. Fifth Avenue Anchorage, Alaska. 99501 Dear Sir: This is to notify you tha.t the subject well was spudded on State Lea.se ADL-17589 at 2:00 A.M., August 22, 1969. The surface loca- tion of this well is ;i.t 1304.2' FNL, 1022.71 FWL, Sec. 6, TllN, R9ì¡I, S.M. lie plan to drill this well directional1y to a. bottom hole location of 21001 FSL, 10001 FEL, Sec. 31, T12N, R9W, S.M. Yours truly, PS PETROLEUM COMPANY Offièe Manager JBG: jo cc: l1r. T. R. Þ~rshall, Jr. (1) Division of Mines & Minerals Department of Natural Resources state of Alaska 3001 Porcupine Drive Anchora.ge, Alaska 99504 fIfJ!:::.- HLB 4. . ".' TRM.' . ~fvG ~!,: HWK I~ REL -£ r,-t.--1 f'" ..,., ~-~ r-iil1er$ Governor Division of Oil and Gas 22, John Be Gipson District Office Ua:s.'ulger Phil 1 ip s 'Petroleum Con,uitt"tY 515 o Street Anchorage" 4\1a8k&99501 lte: ltort.h Coolt Inlet Th:d.t, IJ:A....1.0 Pbtl1ipsPet.roleu:m Cot~any, operator Dear :i.1t t.he .approv*!(lappltc.4tkn'ì for permit to referenced we 11 J 00 or about ,August 22. 1969"ft'œttbe North Inlet P latfornl,at a 6, Townsbip will be required. I'mit Ia.(~b electric, 101., septa and print, filed purSU8tJft to tbeapp,11cable regulations inel,wø1e the calibration ~Aro pos.it.tofts béfore s~ (1) t~e ~1 type (3) (5) suøpeftswnot: -- ec: 50-283-20030 Porm P-l REV. 9-30-67 SUBMIT IN TI-U (Other instructio reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE" ... 5. í.. la. TYPE OF WORK APPLICATION FOR PERMIT TO DRill, DEEPEN, OR PLUG BACK DRILL [I1 b. TYPE OF WELL OIL 0 GAS rVI WELL WELL L.lt.I 2. NAME OF OPERATOR 6. LEASE DESIGNATION A.1'\ID SERIAL NO. DEEPEN 0 PLUG BACK 0 OTHER ~b::'~LE 0 ~f¿:'iIPLE D 8_ UNIT,FAR:vI OR LEASE NA.1\¡IE Cook Inlet Unit 'P'hi"ins Petm1eum CO-rqpA-ny 3. ADDRESS ðF OPERATOR 9. WELL NO. 4. L2tá.I~'J>~F ~~Reet J' An~h()ragp. J A 1 a~kA 9950J At surface Leg 2, Slot 6, 1304.21 FNL, 1022.71 FWL, Sec. 6, TllN R9W, S.M., North Cook Inlet, Platform. nTyonekH At propt?sed prod. zone 50001 MD, 39251 TVD, 3501 FSL, 25501 FWL, Sec. 31, -0 10. FIELD AND POOL, OR WILDCAT ok Inlet 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 13. DIRECT,ON F _'-OM NEAREST TOWN OR POST OFFICE" Se S.M. 12. 10.5 miles East of Tyonek, Alaska 14. BOND INFORMATION: M-ML-IV State Wide Bond Rl-l _ TYPE Surety and/or No. 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 18. DISTANCE PROM PROPOSED LOCATION· TO NEAREST WELL D::tILLING, COMPLETED, OR APPLIED FOR, FT. nool 21. ELEVATIONS (Show whether DF, RT, GR, etc.) 2550' 5002 Amount 17. NO. ACRES ASSIGNED TO THiS WELL * 16. NO. OP ACRES IN LEASE 19. PROPOSED DEPTH 83001 MD 620() 1 TVD 20. ROTARY OR CABLE TOOLS Retarv 22. APPROX. DATE WORK WILL START" 23. me! n6 t from ML'LW PROPOSED CASING AND CEMENTING PROGRAM S-22-69 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH QUANTITY OF CEMEN~ --- 1. Deviation required to reaoh BHL from permanent platform. 2. There are no etfected operators. 3. BOP Specification attached. 4. Intervals of interest win be perforated and may be stimulated. * Refer to State of Alaska, Alaska Oil & Gas Conservation Committee, Conservation Order H~.o, dated 6-8-67 and #68, dated 12-7-68. NOTE: BHL: 2100' FSL, 1000' FEL, Seo. 31, TUN, R9W, S.M. IN ABOVE ACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and propose ew roductive zone. If proposal' to drill or deepen dire cLonally , give pertinent data on subsurface 1ocations and measured and .' rtical depths. Give blowout pre enter program. 24. I Jc~vlTE Au.gust 19. 1969 TITLE Dist. Ofe. MRr. CONDITIONS OF APPROVAL, IF ANY: OTHER REQUIREl\1ENTS: See Transmittal Letter A.P.I. NUMERICAL CODE ~YES 0 NO P~T NO & 4 ft:; AP~VAL DAn APPROVEDB~' -~ Chairman TI~a~~:ß~~:~:~:~ *See Instructions On Reverse Side August 22, 1969 Ga.s Cornm; rtE:'liATE AnSI ";. 1969 31 PROP. B.H.L. A-IO X Sec.31-12N-9W S . \ , 2100' FSL,.IOOO'F. \ I 0 \ ' ""'- " ..." \ I '.... \ I '.... \ I ...., \ I " \ ~ A-5 ....... \ AI W '........¡ A-a -,' PHILL~"'@""" \ r/ /<PHILLlPS (G-128113) ....... \ -co II (G-1I3òOO}Ä-2 -J( " 'Of)' .--...--...--- '... \ -. I ., /!}:)}......-- "'''... \ ¡ I' ........-W ~'..., '....... '4' .-" ':-"97~'~ ~...... ~..., . ;( ':X' oÞ I' . ........... _.. . ~ A-v ......,...... .~ ." -.-.. - .... W'........- ", ...." - I ...... I. , , ... / "', A-4 ¿ A-6 @.. ~. " , " I " / , , . I I /~ I l 36 - PROPOSED B.H.LA-9 Sec.l-ílN-IOWS.M. 1200' F.S.L-:2500'F.E.L. .. 0. AOL 3783/ 12 13 TOP qF PAY , 2650 F.S.L:675 F. o ~~~ o~t ~ ~ ,,~~ . ~~ r:- ~., iV~") of,) ~~f:Þ"" ..,.."'........,_...,;....,...,.~....J,.~...",~.,....,..r ~.-...Ì'~..~ ..... -4....--.,.,.··'-·~···, ') ) 89 X A..7 ' AOL /7589 ~ I,( ·7 " (', 1 c ;..l .... ';Vi.:'JOi',{ OFC\~ , ANCt~CrJ3?'~ 32, 5 8 J PHILLIPS PETROLEUM COMPANY 515 "ò' STREET ANCHORAGE ,ALASKA PLAT OF NORTH COOK INLET UNIT TYONEK PLATFORM 18 ORWN. N. J. Powell ./ AOL /874/ SCALE: I ,,~OOO DATE: 6-20-69 J 12 r~ J 11 r~ ~~ ~".i.,,'.~, ~'?j ~ßt !¡"~ ~ GRID .....,.'....,"..,..._,--._...,~..'-'".. -'--'!\"~""'" ,.-....- , ~_.._,.....,.'...__'M~~ ~...,.....__'.',...... --) ") f' d; C ¡'~r~"Oþt A:.'¡Cl,.¡"t; :',~":', ;?,,:,l,~~':,',~ .! ·N. C.!. Un. A-7 N.C.I.Un.A-1 '; N.C.I. Un. A-a N.C. I. Un. A-6 .... PHILLIPS PETROLEUM COMPANY 515 "d' STREET ANCHORAGE,ALASKA NORTH COOK INLET TYONEK PLATFORM COOK INLET ALASKA NOTE: Using PLATFORM NORTH, Slot No.! will be The - furthest platform North slot in platform North- west quadrant of any leg; Slots are numbered I thru 8 in a counter-clock-wise direction. PLATFORM LOCATION~ Sec.6-IIN-9W DATE: 6-20'69 ORWN. N. J. Powell NOT TO SCALE "---;;~;:TYPE OOP SERIES'1500 (BLIND RAMS) Þ<] I':OTE: Double Preventers are used with flanged side outlets for choke manifold. and fillup line connections.. ~ . -~-...._......._----~- HOO!{UP FOR " < . '. 1 ." ~ o Q~}13J. E P.REVENTER~ .N.!£Ll!.=. PJ:=.BJJ:Q..R M ø ® o " G G) 0). ". 4" SERIES_ 1500 VALVE J" 2" SERIES 1500 VALVE " .r 2" MUD PRESSURE GAUGE ON 4"x 4'X~' ~ SERIES 1500 STEEL TEE 4" SERIES ISOC> X 2" SERI!;S 1500 STEEL CROSS 2" SERIES 15~O POSITI VE CHOKE 2" SERIES 1500 ADJUSTABLE CHOKE " ,) ~J .-.-r.'7~~~~"'~_-'~--.---_....x.~_......~~_ PH ILLiPS PETROlEUt'/t COiv~Pl\NY PRODUCTION DEPARTMENT 5000 PSI V/ORi(It\G PRESSURE . BLO\'lOUT PREVENTfJ\ ~;OOì<-UP (SERIES IS,OO FL/\NGC:S OR BETTER) R EV. ~'/II/GS . . SÇHEOULE E -..--_---_._---_._------....-.......-........__.._~........ 2SJ'~-~ì~~) ! ~ 6 .' . I > ~3: - I º ~(J) 31 aT I/' II. m~~~; ,<v:>,<:;) 'v C>~ \)4- ij ~~<v A,.~ 1'1 ~~*¡i<V , ,~ / P ~ ------~-_.- ~ 1; I I ~ 1 l' ~ . f~¡ . ti£ , ¡:r1 1 ¡,;'~ ~ KJ r--~ GR;ID i¿~1 ~!!ì r;1 ¡';ij I..··~· i i i ¡ ¡ ¡ i I I ! ! I ì ¡ ! I· ! ¡L -1 12; 7 LEG NQ. I LÞ.T. 6 ¡ 0 04' 36.38" LONG.150o 56' 55.63" y= 2,586)731 x= 331,995 FRO M N.W COR. 1,250' SOUT H a 975' EAST. )..l.L? N , T 11 N ~I '~.~ ,.... 31 !32 :IIR\I'¡vtJU!'!æ!!,'f'I"1",,;¡¡¡m 6!5 , --r ¡ I I I I I . I I I . j'. - J ~'. . @----------- , I I I I I I I I I I I I I ~\~::.~ '~¡'~.~,:.~~'~: NOTE: Plat amended 7 AUG.68· to show , revised leg numbering. SCALE I II = 1,000-' 615 718 LEG N2. 4 LAT. 610 04' LONG. 1500 56' y= 2.,586,781 x=· 332p63 . FROM N.W. COR. 1,198' SOUTH a 1,043' EAST. LEG N.Q.. 2 LAT. 610 04' LONG. 15cP 56' y= 2)586) 674 x= 332,036 FROM NW. COR. 1,305 I SOUTH a 1,018' EAST. LEG N2 .3 LAT, 61u 041 36,34'" LONG.15cP 56' 53.3911 Y=2,586)724 x= 332,105 FROM N W. COR. 1,2541 SOUTH a· 1,085' EAST. 36.89" 54.2511 35.83" 54.7711 ~~;t~t;'I ¿ '-' ell /?i, l \;L \)¿¿S>.. '''¿¡¡:"'';J ~,""" L-':¡''''~~1 ~ ~~,i'~ 0.. "It 'Ii.... ~~f;<>e '"\',,\ 11 ~"" ,~ " yo ff' ('" 0., ..........;. '<I,. 4,' '-'. G', ~..,. tJ ~. ,-.) i)~ <.::~: . y o~"'9' ð;-, $' ~.: ,,; .. ~'~d 2·····.i Å *- ~'~ 1J;( ~ ß~,,(¡ r;;;7');;c:;;: ::c.~'.~" 0 p I ~~~-,1~,~...¿~;/ ¿~;:J'¿;'.~ :. ¡O-"'þJ¡;";' ··...-,'~e 7-..I"".....Q..·."',,,p t;? ..-..~ ~.~ -t-"""'P'~""":' ¡ . ,~') .Q ~~ ¥".~. ~,...:.;:} ,..<iw~ Ii- '\~;E:i~~~x;:~y < .\...~ . J (," ~,,' '\;;\'" '/ '(:'::::::z~~~2:;;;::':> CERTI FICATE OF SURVEYOR I hereby· certify that I am properly registered and licensed to practice land surveying in the State of Alaska and ... that this plat represents a location survey made by me or under my supervision and that 0'\\ dimensions and other details are correct. /:/ -~/Í Z. /9~8 ~~~ DArE ~I YOR NOTE ___,~,_h\""'_~Y___'__ I NOR-¡ H coro-';,~ "1 ".P ;::--\- ';'\"T ¡ 1\ . I'1ILL I \..','~ ¡ ~ PLATFORM Iltlll ----.------- _._....~ FOR PHilLIPS PETROLEUi,'i Cû -.- ! ¡ DATE: 21 . J U ~JE .s--:..8 ! F. M. Ll1'\ J~)EY 8. ,~::: ~-:: O( SCAL~' I" I 0 .~ ~.-. I ; t.. = VV ¡ Lo¡.ù ';;'ì F:r("'~1 'C'c'<c I FB.11374 PP. 11-15 j . Š-:'fV~'y;~~ - " rRWN.----rcH;Ö,--rc-c-:---¡· 25.92 W NOKTilt:.F.NLIGH)':; 8LV I I SPiNAR:) '0< 4- 06¡ ALASK, JHG. ¡ 111374! .0· The ¡ ocat ion of the platform legs was accompl ¡shed by usi ng triangulation stations BELUGA,TERRACE,and TYONEK which .ore all U.S.C.ß G.S. stations. Arl coordinates are Alaska State Plane, Zone 4. L>"!t /f!<~-- (/i .'l.7~·:> I\.{ ?}¡/(rJ Lease & Well No.. /I~;¡: U~7'¿!~""/O " 1. Is well to be located , 2. Do statewide rules apply e . e. .~. e 3. Additional Requirements: NOTICE The following well logs and oversized documents have been placed in offsite storage. If you would like to view the original documents, please contact the AOGCC librarian. AOGCC 3/4/2005 ~()1 "'" 0 u COMP ANY PHilliPS PETROLEUM COMPANY I L'J t- =:) W 0 a.... a: NORTH COOK I N lET UNIT A - 10 0 V) WEll co a.... z I::) _J FIELD NOR T H COOK INLET < t- -' Z 0:::- W au I COUNTY KENAI BOROUGH STATE ALASKA ;:¿ zz a.... Z >- lEG .' 2 SLOT 6 >-a..O Z LOCATION Other Services: '-0- < PLATFORM TYONEK SNP. FDC ZC~...J 0.. ::)...JU...J ~ OwOw 0 Sec. 6 Twp. 1 1 N Rge. 9W UÜ:...J~ V Permanent Datum: M L L it) , Elev. 0 Elev.: K.B.~~~ log Measured From KB ,1,1 5. 9 Ft. Above Perm. Datum A1/ D.F. .1 1 5 Drilling Measured From KB G.l. 82 @ @ @ RESH GEL. ml ml ml OF @ of @ of @ OF of @ of @ of @ of of @ of· @ of (rìt of @ of @ . of @ of of of of
