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Home My WebLink About193-089 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I~""0~ File Number of Well History File PAGES TO DELETE RESCAN Color items - Pages: ~ -- J ~ Grayscale, halftones, pictures, graphs, charts - Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [3 Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of vadous kinds [] Other Complete COMMENTS: Scanned by: Bevedy ~ncent TO RE-SCAN Notes: Nathan Lowell Re-Scanned by: Bevedy Dianna Vincent'-~ Date: ~ -C~ Lowell Date: ~- ? WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 1Y-28 Run Date: 5/21 /2010 June 25, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1Y-28 Digital Data in LAS format, Digital Log Image file, Interpretation Report 50-029-223 80-00 Production Profile Log 50-029-22380-00 tlrto~~~xa~ ~ H V is ~t 'i, r~ ~ ~! ,' 1 CD Rom 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.b Date: ~~~a ~~ ~~1 t ~i3-fl~ ~ ~ ~ ~~ 1 Signed: 1'~ • ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri123, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7s' Avenue, Suite 100 Anchorage, AK 99501 ~,g ~ .k~f} ~ i .~W .. .. Dear Mr. Dan Seamount: LJ ~~~~ APR 2.7 2010 ~~ ,~ ~i~ ~ has tons. ~;ommissior: ~11CI'K~aQF' . E~3-O`d~~5 ~~ a Enclosed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRL~.. Each of these wells. was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering.the annular space. As per previous agreement with the: AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 1 Q-404, Report of Sundry Operations. The cement was pumped March 21, 2010. The corrosion inhibitor/sealant was pumped April 1 thru April 17, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Since ~.._ ~- Perry ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 4/23/10 10. 1F_ 1(1 R 1Y POD'c Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off da#e Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-01 50029205900000 1810590 SF n/a 4" n/a 2.55 4/5/2010 1A-02 50029205990000 1810710 SF n/a 9" n/a 4.25 4/6/2010 1A-05 50029206270000 1811040 SF n/a 6" Na 4.25 4/7/2010 1A-08 50029203130000 1780400 SF n/a 10" Na 13.7 4/17/2010 1A-09 50029206690000 1811520 SF n/a 4" Na 2.55 4/2/2010 1A-15 50029207110000 1820170 SF n/a 4" Na 2.55 4/4/2010 1F-15 50029210250000 1831490 21" Na 21" Na 4.25 4/1/2010 1Q-02 50029212480200 2051420 22" n/a 22" Na 7.2 4/6/2010 1Q-03 50029212490200 1842330 27" n/a 27" n/a 3.4 4/6/2010 1 Q-05 50029212330000 1842170 32" n/a 32" n/a 3.4 4/1/2010 1 Q-06 50029212240000 1842080 32" n/a 32" n/a 2.12 4/1/2010 1Q-10 50029212150000 1841980 32" n/a 32" n/a 3.82 4/1/2010 1 Q-15 50029213080000 1850460 22" n/a 22" n/a 2.97 471 /2010 1Q-16 50029213090000 1850470 25" n/a 25" n/a 3.82 4/1/2010 1Y 21 50029223870000 1931020 23" n/a 23" n/a 3.82 4/1/2010 1 Y 24A 50029223717100 2041250 26" n/a 26" n/a 3.82 4/1 /2010 1Y28 50029223800000 .1.930890 28" Na 28" Na 5.52 4/1/2010 1Y 31 50029223810000 1930900 6'8" 0.65 24" 3/21!2010 5.52 4/1/2010 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 1Y-28 Run Date: 8/1/2009 December 1, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1Y-28 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22380-00 ~~~ ~A-~ ~ ~ ; ~is4 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 ~t'3 -~~? Fax: 907-273-3535 rafael.barret ~ alhb~urton.com.,~ Date: DEC 0 ~ ~pJg ~ 011 Signed: ,i~sk~ Oil ~ c~~~ a~e~Ets ~;(?"ti~~ic~!, '~~~~nr~c~~ • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ RepBir Well ^ Plug Perforations ~ Stimul8te ^ Othe~ Q install patch Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, If1C. Development ^~ Exploratory ~ ~ 193-089 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 ~" 50-029-22380-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 106', Pad 65' GL ~~ 1Y-28 8. Property Designation: 10. Field/Pool(s): '"~ ADL 25640 Kuparuk River Fie-d / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured ~`~ 8285' feet true vertical ~ 6521' feet Plugs (measured) Effective Depth measured 8182' feet Junk (measured) 8280' true vertical 6440' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURFACE 5507' 9-5/8" 5507' 4430' PRODUCTION 8267' 7" _ 8267' 6507~ RECEIVED OCT092009 Perforation depth: Measured depth: 7690'-7754', 7797'-7825', 7996'-8015', 8030'-8050' Aleska Oil & Gas Cons. Commission true vertical depth: 6062'-6111', 6144'-6165', 6296'-6310', 6322'-6337~ Anchorage Tubing (size, grade, and measured depth) 4" x 3.5" x 2.875" , J-55, L-80 , 4998', 7917', 7946' -•-._- -.-_. -. .. Packers & SSSV (type & measured depth) Otis'HV1' retriev pkr @ 7614', Otis'HV1' retriev pkr @ 7781', Baker'D' perm. Pkr @ 7919' otis sssv @ ~ ao2~ 12. Stimulation or cement squeeze summary: Intervals treated (measured) not a licable ~y PP ~~~z~ix~~ ~~C~:~ ~~ ~ Za~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 227 1183 3707 -- 170 Subsequent to operation 296 3052 3877 -- 193 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Developm\ ~ Service ^ Daily Report of Well Operations _X 46. Welt Status after work: Oi10 Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact John Peirce @ 26 5-6471 ~ Printed Name John Peirce Title Wells Engineer Signature ~~ ,~ Phone: 265-6471 Date ~, d~$ ~ O~ Pre ared b Sharon Alls Drake 263-4 12 ~ Form 10-404 Revised 04/2006 ~~~~~ ~ ~'~ ~ 1 ° ~ ~~ Submit Original Only ~G'~•Ol . 1Y-28 Well Events Summary DATE SUMMARY 7/29/09 BRUSH & FLUSH 7750' - 7910' R . PULLED CV AND SET 1.5" DMY w/ RK• LATCH @ 7875' RKB. IN PROGRESS. 7/30/09 CLOSED CB-1 (SLIDING SLEEVE) @ 7899' RKB. SET ISO SLEEVE(2.31" ID) IN CB-1 @ 7899' RKB. CLOSED AND REOPENED CSW(SLIDING SLEEVE) @ 7770' RKB. COMPLETE. / 8/1/09 SET 3.5" BAKER KB PACKER (2.78" OD) MID ELEMENT @ 7832' RKB. WELL / READY SLICKLINE TO RUN UPPER PATCH ASSEMBLY, IN PROGRESS. 8/12/09 STUNG MIDDLE SECTION OF STRADDLE PATCH ASS'Y (34' 2" OAL, MIN ID 1.62") INTO LOWER PKR @ 7832' RKB. ATTEMPTED SET UPPER SECTION OF PATCH WITH 35 KB PKR @ 7772' RKB (28' 11" OAL, MIN. ID 1.62") ENGAGING SNAP LATCH BAIT PROFILE @ 7799' RKB. ETD SETfING TOOL FAILED TO '~ RELEASE FROM PKR. LEFT ETD SHEAR SUB, GO ADAPTER, FIRING HEAD, SHORTY, AND BAKER 10 (68-1/2" OAL) IN HOLE. IN PROGRESS. 8/13/09 PULLED ETD TOOLS WITH BAKER 10 @ 7737' SLM. ALL PARTS RECOVERED; ETD FAILED TO FIRE. TAGGED KB PACKER @ 7778' RKB; ATTEMPTED SET PKR BY JARRING DOWN. IN PROGRESS. / 8/14/09 CLOSED CSW-1U SLIDING SLEEVE @ 7770' RKB. UNABLE TO CONFIRM PATCH INTERGITY DUE TO APPARENT TBG LEAK INTO C SAND BETWEEN PKR @ 7614' RKB AND 7625' RKB. SUSPF~IDED. _ - ~.. ~ KUP ~ ~ ~(~jx~~~~~~p5 Well Attributes A,~'„.. I ~ Wellbore APVUWI I Field N 500292238000 IKUPA comment ~~~ ~SSSV: TRDP ~ _ _ ___ WeG Cmf~l _ 1Y;~@. 1N] LO .. . _.. Scner_ne(k_.Attu~ , ... : .,. - u~~ ~n, . ..i ~,i .. .Annotation ~Depth(flK6) '~ Last Tag~ 8,039.0 ' Casing Strings sc.~~9 Lasing Description ' ; (~~1 CONDUCTOR,~ CONDUCTOR 111 SURFACE 9 snFENV~V, i.sos SURFACE 9 PRODUCTION ~ cnsuFT, -- Tubing Strings "" s.se, , str~o9 ~ Tubing Description (~~; SURFACE, __ ~TUBING 3,038 i ~TUBING '', 3 ~~TUBING ' 3 GnSUFT, TUBING ~ 2 5,006 ' Other In Hole { All Jev SURFACE, Top Dapih ~ `'.`'~~ (TUD) ~' ~ Top Incl ftK6) ~.Top(kK6) ( (°) ~~~~~.-- 5.992 '" ~ ~1.802 1.675.9~ 41.66 2,961 2.5242~ 44J6 5 006 4,043.1 39.91 GAS LIFT, ~ s.755 5.992 4.798.3 4120 - I 6,755 5,365.5 41.97 GAS LIFT, 7,546 5,952 8 41.25 ],566 i _ 7,590 5,986.0 40.80 i 7,598 5,992.1 40 61 NIPPLE.],590 _ ],614 6,~~.2 .. 4~.$3 i I.. .7.631 6.077.7 ..~ 40.39 PBR.].598- ~ ~ 7.770 6.123.1 40.41 ~ 7.772 6.124.9 40.42 , . _ . _ _ ' . . 7.777 6.1285 ~ 40.46 PACKER,].610- ~ ~ - ~ 7.781 6.131.S~j 40.48 ~ ~ 7,834 6,177.51 4Q50 `~,~ 7,875 6,203.OI 40.43 aROOUCraN, - 7,899 6,221.3~ 4028 ~.s3i -- 7.899 6.227.3 I 4028 IPERF. - ~.ssoa.~s/ ~ i " 7.917 6.235.OI . 40.13 I 7.919 6,236.5 40.72 s~E~vE-o. ..__ ~ ~ I 7.936 6.249.5 39.98 ~ ~~o I 7.945 6.256.4 ~ 39.91 PACKER,7,I12 PACKER, 7,]81 Q I PATCM.] ]]] IPERF,~-~ - 7.]97-].825 . : PACKER. 7.83/- PRODUCTION, ] e]5 SLEEVEC. ],899 \ ISOSLEEVE-C, 7.899 PBR.I.91]- t.. ~ PACKER. ],919 ' i ' NI?, 7,936- SOS, ].965 - TTL.7.966 - IPERF, - -- 7.996-B.O15 ~"'- IPERF ,_ 8,030-8.050 , PRODUCTION, fl,Ifi7 FISH.8280-~~- ~ TD,8,285 1 Y-28 600 I 8/1 812 0 0 8 ILast W0~ '~, 822/ ia Dale Mnotation ~~ L- -t MoA ey EnE Data 3BI2008 IRev Reason- SHOW STRADDLE PATCH .~~.~.i.~~~ 10/7/: 36.00 4" Series 10 self equalizing SSSV !LA/TMPD/1lGLV/8K/_788/1281/ Comment: ; ICO/MMG2lLS/OVlRK/25// Commeni~ STA Otis wl 10' Siroke 10/12/7993 2.97U Otis'HVT' Retrievable packer 10112/1993 2.972 CAMCO/MMG-2/1.5/DMYlRK/// CommenC STA 6 CLOSED 10/12/1993 2.920 Camco CSW-1U: CLOSED 8/74I2009 4l2"//1996 2.812 'KB' UPPER STRADDLE PACKER 8/13/2009 1.810 'KB' SNAP LATCH PATCH ASSEMBLY 8113/2009 1.620 Otis'HVT' Retr. w/'SAN' anchor assy 8 running to 10112/1993 2 972 'KB' LOWER STRADDLE PACKER 8/ V2009 '~ L810 CAMCO/MMG-Z7.5/DMY;RK///CommentSTA7 CLOSED 7I292009 2.920 Camco C&1; CLOSED 7/292009 4/17/1996 2J50 AVA ISO SLEEVE SET ACROSS CB-1 SLEEVE 7/302009 2.310 Baker'GBH-22'LSA 10112/1993 2438 Baker'D' Perm. w/ 5' Seal Bore ext. i W 72/1993 3250 Camco'D' Nipple NO GO 10112/1993 2250 Otis . .. 10/12/1993 2.441 ELMD 7TL @ 7940' during PPROF on 3/102008 10/12/1993 2.441 GLV 1" GW LOST IN RAT HOLE 3/5/2003 3/5/2003 shot Dans Zone Dafe (sh~~~ Typa CommeM 4, C-3, 1V-28 10/1 V7993 12.0 IPERF 4.5" SWS guns, Spiral Ph I, UNIT B, 10/11/1993'~~ 12.0 IPERF 4.5" SWS guns, Spiral Ph pg I 1,1Y-28 1l28i1994 ~~ 6.O~~~IPERf 2.125"SWSguns.904egPh I, A-3, 1Y-28 10l1111993 4.0'~ IPERF 4.5" SWS guns, 180 deg Ph 03/ 12/08 ~~lt~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # 1 s.-- i .o~~ ~~~ Log Description NO. 4624 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1 A-12 11964583 LDL (J'~ (®(~- 02!28/08 1 1E-112B SAND LATERAL 11978443 MEM INJECTION PROFILE 03/03/08 1 iR-04 11964585 USIT j. - 03/02/08 1 2L-330 11837544 OH EDIT (SONIC SCANNER) ''}~ ~ 11/27/07 1 1 31-01 11994626 LDL 03/06/08 1 2N-327 11994628 PRODUCTION PROFILE ~d'~--. 03/08/08 1 1Y-28 11994629 PRODUCTION PROFILE .~ - 03/10/08 1 3S-08C 40016310 OH MWD EDIT VISION SERVICE tea- ~' ~/ 01/17/08 1 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Dethlefs Phone (907) 263-4364 Fax: (907) 265-6224 November 14, 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 1Y-28 (193-089) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the tubing patch operations on the KRU well 1Y-28. If there are any questions, please contact me at 263-4364. Sincerely, J. Dethlefs Kuparuk Problem Well Supervisor JD/skad RECEIVED NOV 1 4 2002 Naska 0il & Gas Cons. C0mmtsslo~ Anchoraoe STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at sur[ace 209' FNL, 3333' FEL, Sec. 1, TllN, R9E, UM At top of productive interval 2700' FSL, 106' FWL, Sec. 31, T12N, R10E, UM At effective depth At total depth 2403' FNL, 4481' FEL, Sec. 31, T12N, R10E, UM 5. Type of Well: Development __ X Exploratory __ Stratigraphic __ Service__ (asp's 531612, 5975115) (asp's 535321, 5978218) 6. Datum elevation (DF or KB feet) RKB 106 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1Y-28 9. Permit number/approval number 193-089 / 10. APl number 50-029-22380 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 8285 feet Plugs (measured) 6521 feet Effective depth: measured true vertical 8006 feet Junk (measured) 6303 feet Casing Length CONDUCTOR 121' SUR. CASING 2997' SUR. CASING 2469' PROD. CASING 8228' Size Cemented Measured Depth True vertical Depth 16" 235 sx PFC 121' 121' 9-5/8" 850 sx PF E, 800 sx Class G 3038' 2579' 9-5/8" (see above) 5507' 4430' 7" 270 sx Class G 8267' 6507' PROD. CASING Perforation depth: measured 7690' -7754', 7797' - 7825', 7996' - 8015', 8030' - 8050' true vertical 6062' - 6111', 6t44' - 6165', 6296' - 6310', 6322' - 6337' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) RECEIVED NOV 1,4 2002 Alaska 0il & Gas Cons. C0mmissio~ 4', 11#, J-55 Tbg @ 4998' MD; 3-1/2", 9.3#, J-55 Tbg @ 7621' MD; 3-1/2", 9.3~, L-80, Tbg @ 79,~~[6", 6.5# Tbg @ 7946' I I OTIS 'HV'r' RETR. PKR @ 7614' MD; OTIS 'HVT' RETR. @ 7781' MD; ECLIPSE PKR @ 7840' MD; BAKER 'D' PERM. @ 7919' MD OTIS 4" SERIES 10 SELF EQUALIZING @ 1802' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation :: : 1217 : : :,: ::: i: 170 15. Attachments I I Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ X Gas __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /s~~''''~'~ ~-~ ~ Title: Kuparuk Problem Well Supervisor Jerry, Deth Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl i:: : 13 : : i:I : 227 5021 4052 Suspended__ · ,S BFL Casing Pressure Tubing Pressure - 158 Service 190 Questions? Call Jerry Dethlefs 263-4364 Date /,/,/~j~ ,P Prepared b~/ Sharon Al~sup-Drake 263-4612 ,. Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 1Y-28 Event History Date Comment 08/30/02 PULLED SLIP STOP, PT TBG ABOVE PACK OFF- HELD, FOUND LEAK @ 7589' WLM, PULLED K-3 PACK OFF & EXTENTION [LEAK DETECT-PATCH] 09/09/02 RECOVERED APPROX. 70% OF ELEMENT LOST 05/14/02. SET & TESTED (FAILED) PULLED & RESET 8' 5" X 3" BAKER K3 PACK OFF ASS'Y @ 7620' RKB. IN PROGRESS. [LEAK DETECT-PATCH, PT TBG-CSG] 09/10/O2 09/11/02 09/12/O2 09/26/02 PACK OFF TESTED @ 7621' RKB FAILED, PULLED PACK OFF & RESET NEW 13' 4" PACK OFF ASS'Y @ 7616' RKB. TEST FAILED, POSSIBLE BAD TEST TOOL? IN PROGRESS. [LEAK DETECT-PATCH, PT TBG- CSG] TESTED PACK Off @ 7616' RKB, FAILED. PULLED & REPLACED W/NEW 8' 5" PACK OFF ASS'Y @ 7621' RKB, TEST FAILED, LEAK RATE 100 PSI PER MIN. IN PROGRESS.[LEAK DETECT-PATCH, PT TBG- CSG] SET 3" TBG STOP @ 7621' RKB. [LEAK DETECT-PATCH] PULL SLIP STOP @ 7579' SLM. PULL 3"X 8' K-3 PACK OFF @ 7580' SEM. JOB IN PROGRESS. [LEAK DETECT-PATCH] 09/27/02 SET 3" PACK OFF & SPACER PIPE( 24' TL) TOP OF K-3 @ 7566' SLM.GOOD PT ON K-3 ELEMENT. SET SLIP STOP ON TOP OF K-3 @ 7564' SLM. [LEAK DETECT-PATCH] Page 1 of I 11/12/2002 PhiLLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 April 24, 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 1Y~28 (193-89) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent wellwork operations on the KRU well 1Y-28. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _XX Patch 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 209' FNL, 3333' FEL, Sec. 1, T11N, R9E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service__ (asp's 531612, 5975115) 6. Datum elevation (DF or KB feet) RKB 106 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 Y-28 At top of productive interval 2700' FSL, 106' FWL, Sec. 31, T12N, R10E, UM At effective depth At total depth 2403' FNL, 4481' FFL, Sec. 31, T12N, R10E, UM (asp's 535321, 5978218) 9. Permit number / approval number 193-089 / 10. APl number 50-029-22380 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 8285 feet Plugs (measured) 6521 feet Effective depth: measured true vertical 8006 feet Junk (measured) 6303 feet Casing Length CONDUCTOR 121' SUR. CASING 2997' SUR. CASING 2469' PROD. CASING 8228' PROD. CASING Perforation depth: Size Cemented 16" 235 sx PFC 9-5/8" 85O sx PF E, 800 sx Class G 9-5/8" (see above) 7" 270 sx Class G Measured Depth 121' 3038' 5507' 8267' measured 7690'-7754',7797'-7825',7996'-8015',8030'-8050' True vertical Depth 121' 2579' 4430' 6507' true vertical 6062' - 6111' 6144'- 6165', 6296' - 6310', 6322' - 6337' .~,.,~,.~ ..... ~,i .... i,.. ,i.:: .J '. ............ ]-ubing (size, grade, and measured depth) 4", 11#, J-55 Tbg @ 4998' MD; 3-1/2", 9.3#, J-55 Tbg @ 7621' MD; 3-1/2", 9.3#, L-80, ~bg!,~.,~79.17' MD, 2.875", 6.5#, Tbg @ 7946' Packers & SSSV (type & measured depth) OTIS 'HVT' RETR. @ 7614' MD; OTIS 'HVT' RETR. @ 7781' MD; ECLIPSE PKR @ 7840' MD; BAKER 'D' PERM. @ 7919' MD; 'OTIS 4" SERIES 10 SELF EQUALIZING @ 1802' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Oil-Bbl Shut-In Shut-In Representative Daily Avera.qe Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil__ X Gas__ Suspended__ Service · _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Michael Mooney Form 10-404 Rev 06/15/88 · Title: Wells Team Leader Questions? Carl Mike Mooney 263-4574 Dpar te:aredb~~~~iC~rake 263-4612 SUBMIT IN DUPLICATE 1Y-28 Event History Date Comment 10/16/01 TAGGED @ 8028' RKB, EST. 22' FILL. [TAG, PATCH] 10/17/01 DRIFTED TBG W/23' 6" MOCK PATCH ASSY (2.74"OD TOP 12" & 2.725" BTM 10" ) TO 7911' RKB. 10/29/01 SET ECLIPSE PACKER. BO-I-TOM ELEMENT AT 7840' ELM- TOP OF PACKER AT 7838'. CCL STOPPED AT 7826.3 FT. CCL TO ELEMENT 13.7 FT (SE-I-TING ELEMENT-TOP OF PACKER: 2.35 FT). GOOD SURFACE INDICATION OF FIRING. RAN BOTTOM SECTION OF TUBING PATCH. PACKER MOVED UP HOLE. PULLED PACKER. [LEAK DETECT-PATCH] DRIFTED TBG W/2.75" X 11' DUMMY TO 7866' SLM. [LEAK DETECT-PATCH] INSTALLED ECLIPSE PKR (2.75" X 32") W/SHEAROUT DISK (1500 DPSI) IN PLACE, LOADED TUBING W/ 87 BBLS DIESEL, SET TOP OF PKR @ 7840' AND ELEMENT @ 7842' (NOTE THIS IS 2' BELOW THE PRIOR SET PKR), LEFT WELL SI. [LEAK DETECT-PATCH] SET 5 SECTION TBG PATCH @ 7840' ELM, (TOTAL LENGTH FROM TOP OF ECLIPSE TO TOP OF K-3 PACK-OFF: 115 FEET), UNABLE TO PT TBG. IN PROGRESS. [LEAK DETECT-PATCH] 11/02/01 03/01/02 03/02/02 03/06/02 03/07/02 POSSIBLE LEAK FOUND ABOVE NEW PATCH, UNABLE TO DETERMINE DEPTH. [LEAK DETECT- PATCH] Page I of 5 5/9/2002 Memory Multi-Finger Caliper Log Results Summary Company: PHILLIPS ALASKA Log Date: July 17, 2001 Log No.: 4377 Run No.: 1 Pipe1 Desc.: 4" 11 lb. BTC-Mod Pipe1 Use: Tubing Pipe2 Desc: 3.5" 9.3 lb EUE Pipe2 Use: Tubing Well: 1Y-28 Field: Kuparuk River Unit State: Alaska APl No.: 50-029-22380-00 Top Log Intvll.: Surface Bot. Log Intvll.: 4,991 Ft. (MD) Top Log Intvl2.: 4,991 Ft. (MD) Bot. Log Intvl2.: 7,915 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the 4" tubing is in good condition, with no penetrations in excess of 20% wall thickness recorded. The minor damage recorded appears mostly in the form of shallow isolated pitting, with no areas of significant cross-sectional wall loss recorded. Scattered light deposts, as thick as 0.17", are recorded throughout the 4" tubing. The distribution of the damage recorded throughout the tubing string is illustrated in the Caliper Region Analysis page of this report. The 3.5" tubing appears to be in good condition, with the exception of the HOLE recorded in Jt. 86 @ 7,834'. The hole is located near the connection between Jts. 86 and 87 (below packer no. 2), with at least a full joint of tubing both above and below the location of the hole. A cross-sectional drawing of the tubing, at the location of this hole is included in this report. Minor damage, in the forms of Isolated Pitting and General Corrosion, is recorded throughout the 3.5" tubing logged. No significant ID restrictions or areas of significant cross-sectional wall loss are recorded throughout the interval of 3.5" tubing logged. 4" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: No penetrations in excess of 20% wall thickness are recorded throughout the interval logged. 4" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional metal loss (> 5%) are recorded throughout the 4" tubing logged. 4" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant ID restrictions (>0.17")due to deposits or pipe deformity are recorded throughout the 4" tubing inspected. 3.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: HOLE (100%) Jt. 86 @ 7,834' MD Isloated Pit (24%) Jt. 87 @ 7,851' MD PERFORATION (23%) Jt. 46 @ 6,620' MD ProActive Diagnostic Services, :[nc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@rnemorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 3.5" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS · No areas of cross-sectional wall loss (>7%) are recorded throughout the interval of 3.5" tubing logged, except at the location of the recorded hole & erosion @ 7,834', where the cross-sectional wall loss is measured at 17%. 3.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS ' No significant ID restrictions, in excess of 0.07 inches, are recorded in the interval of 5" liner logged. (intentionally left biank,) [Field Engineer' S. Adcock Analyst: J. Burton Witness: T. Johns ProActive Diagnostic Services, [nc. / P,O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565~9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Well: 1Y-28 Field: Kuparuk River Unit Company: PHILLIPS ALASKA Country: USA PDS Caliper Overview Body Region Analysis Survey Date: ~uly 17, 2001 Tool Type: MFC24 No99628 Tool Size: 1.69" No. of Fingers: 24 Analysed: J. Burton Tubing: Size Weight Grade & Thread Nom.OD NomJD Nora. Upset 4 ins 11 ppf BTC-Mod 4 ins 3.476 ins 4 ins P~etr~ion and Meal toss (% wall) penetration body ~ metal loss body 0to 1 to 10to 20to 40to above 1% 10% 20% 40% 85% 85% Number ~f j~ints ~n~iy~d itoi~i ~ ~65i Pene 6 119 37 0 0 0 Loss 40 122 0 0 0 0 D~m~ge Configuration ( body ) Number ofjoh~ts c]~m~d iiot~i = ~) Damage Pro~e (% wall) penetration body 0 48 GLM 1 142 metal Koss body 50 Bottom of Survey = 155.1 100 Analysis Overview page 2 PDS JOINT TABULATION SHEEl Pipe;4ins 11 ppf BTCMod Wall thickness. Body: 0.262ins Upset = 0.262ins Nominal ID: 3.476 ins Well: 1Y-28 Field: Kuparuk River Unit Company: PHILLIPS ALASKA Country: USA Datp: July 17, 2001 penetration body metal loss body oint Penetration Metal No. Upset Body Loss inches inches [ % % 1 0 .01 4j 2 1.1 0 .01 [ 4 2 1.3 0 .01 i 4 2 2 0 .01 4[ 2 3 0 .02 6 [ 2 4 0 .01 5 [ 2 5 0 .01 4] 2 B 0 .01 4[ 1 . L o ~ _:92._.5!2 8 0 .01 6 1 9 0 .01 5 I 10 0 .01_, 5 1 11 0 .02 6 12 0 .02 6 [ 13 0 .01 5 1 ] 14 0 .01 5 1 15 0 .01 5 1 17 0 ,01 5 1 18 0 .01 5 1 Upset ]Body inches inches 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o i o Minimum ID Comments inches 3.42 3.46 PUP 3.43 PUP 3.43 PUP 3.44 3.45 3.41 3.41 3.45 3.43 3.43 I 3.45 0 [ 0 [ 3.40 0 i 0 i 3.41 0 [ 0 [ 3.40 0 [ 0 i 3.43 0 [ 0 3.42 0 0 0 0 0 0 0 0 20 0 .01 5 1 0 0 21 0 [ ,01 6[ 1 0 0 i 22 0 [ .02 7 [ 0 0 0 · 23 L 0 [ .0~. Z,- 2 ._._9 0 24 0 i .02 6 [ 2 0 0 25 0 i .02 [ 8[ 26 0 .01 5 i 27 0 .01 5 ] 28 i 0 .02 6 29 0 .01 5 30 0 .02 6 2 '0 0 2 0 0 I 0 0 2 0 0 I 0 0 2 0 0 2 0 0 2 0 0 2 0 0 1 0 0 3.42 3.43 3.41 3.42 3.42 3.41 3.44 3.43 3,45 3.44 [ 3.43 [ .43 3.43 3.41 3.44 31 , 0 ~ .01 3 3.43 32 0 .01 4 3.43 33 0 .01 S 3.43 34 0 .01 5 3.43 0 .05 0 0 0 0 35 0 .01 4 [ 36 0 .01 4 37 0 .01 5 38 0 .01 39 0 .02 6 41 0 .01 [ 5 42 0 .01 [ 4 43 0 .01 [ 5 44 0 .01 [ 4 1 0 2 0 2 2 1 0 [ 0 45 3.41 3.43 3.42 3.43 3.43 2 0 0 3.44 2 0 [ 0 3.45 3 3,43 ~ 0 0 i 0 i 0 3.43 3.41 .01 5 46 0 .01 4 47 0 .02 71 2 [ 0 0 i 3.41 3.44 Damage profile (% walt) SO I00 Pipe Tabulations page 1 PDS Pipe: 4ins 11 ppf BTC-Mod Wall thickness. Body: 0.262ins Upset: 0.262ins Nominal ID: 3.476 ins JOINT TABULATION SHEE-[ Well: 1Y-28 Field: Kuparuk River Unit Company: PHILLIPS ALASKA Country: USA Date: July 17~ 2001 penetration body metal loss body Joint Penetration [ Metal j Projection No. Upset Body [ Loss [Upset Body inches inches [ % i % [ inches inches 48[ o 49 [ 0 i 5i 1 0 o .01 j 3 2 0 0 .01 [ 4 1 0 0 .01 5 2 0 0 53 [ 0 54 ~i 0 55 [ 0 J Minimum ID incites 3.44 3.43 50 [ 0 3.41 51 0 3.44 [ 52 [ 0 3.42 3.42 3.44 55.1 [ 0 55.2 [ 0 57 [ 0 58 [ 0 .01 3 1 0 0 .01 4 2 0 0 .01 4 2 0 0 ~.ff2 7 ~ o o .02 6 1 0 0 0 0 0 0 0 .01 5 2 0 .01 2 [ 2 0 .Ol 4 [ ! 9 .00 I ] 2 0 .01 6 2 0 3.40 3.40 3.32 PUP SSSV Assv. 55.3[ 0 .05 3.41 PUP 56 [ 0 0 3.42 .05 3.40 0 3.39 .02 7 .Ol 3 59 0 ,04 3.39~ 3~42 61 0 0 .01 5 2 0 j 0 3.42 62 0 2 0 I 0 3.40 63 0 3.41 2 j 0 0 .01 5 j 64 0 .01 4 3.42 65 0 .01 5 2 [ 0 0 3.39 66 0 2 [ 0 0 3.41 .02 6 i .01 5 [ 67 0 2 0 0 3.43 68 0 2 0 0 3.43 69 0 .01 4 j I 0 0 3.40 70 0 .01 5 1 0 j 0 3,40 71 0 .01 4 2 0 L 0 3.43 72 .02 7~ 2 0 [ .04 j 0 0 3.39 73 0 .02 71 2 3.40 74 0 .01 5i 2 0 i 0 3.43 75 0 .01 3.41 76 77 78 79 .01 .01 80 5j i 5i 2 5~ 2 0 0 0 0 0 0 [ 0 0 [ 0 s 2 j o j 3.42 3.42 82 3.40 .02 0 .02 81 .01 5 .02 6 .02 7 [ .0~ Si .Ol 5 j .02 7l .02 8 0 0 .05 18 j .05 3.41 0 j 3.42 0 j 3,41 2 0 0 [ 3.40 o ~ 83 0 2 0 [ 3.40 84 0 3 0 .06 3.40 Lt. Deposits. 85 0 2 j 0 [ .05 3.40 86 0 2 .04 ] 3,42 0 J .06 [ 3.38 87 88 2 J 0 0 89 .o7 j 0 [ 90 .O3 i 0 3.42 0 3.42 0 ! 3.42 .04 [ 3,43 , L~..~eposits. o 2 o 91.1[ 0 0 0 .10[ 3.38 PUP 91,2 0 I 0 0 0 3.39 GLM I (Latch @ 2;30) 91.3 0 .11 3.39 PUP Damage profile (% wall) 50 !00 Pipe Tabulations page 2 PDS JOINT TABULATION SHEE-f Pipe:4ins 11 ppf BTC~Mod Wall thickness. Body: 0.262ins Upset: 0.262ins Nominal iD: 3.476 ins Well: 1Y-28 Field: Kuparuk River Unit Company: PHiLLiPS ALASKA CoLIntty: USA Date: July 17, 2001 ~enetration body metal loss body Joint i Penetration No, [ Upset 8ody inches inc6es i % 92 0 .02 8 [ 93 0 .02 7 i 94 0 .01 4 95 0 .01 5 2 96 0 .01 3 2 97 0 0 0 2 98 0 .02 6 1 Metal[ Projection Minimum Loss [Upset iBody ID % I inches inches inches 2 [ 0 0 3.43 2 I 0 _0_. L 3.42 1 [ 0 ~0~_L 3.41 0 .04 i 3,41 0 0 ] 3.40 .05 [ .04[ 3,40 0 .04i 3.42 99 0 .01 5 2 [100 0 .02 6 2 101 0 0 0 2 102 0 .01 4 2 103 0 .01 4 2 104 0 .01 6 2 105 0 .02 , 9 2 [~106 0 .01 5 2 107 0 0 0 2 [108 0 .02 7 2 [109 0 .02[ 8 2 [110 0 .01[ 5 2 [111 0 .01 [ 4 2 i112 0 .02i 8 3 i 113 ] 0 ~ · [114 0 .02 9 2 115 0 ~ .03 10 2 ]116 0 .02 8 1 i [117 0 ,03 10 2 118 o .03 lO 2i [ 119 _.~ _ .04 ~ [120 0 .04 15 2 [121 0 .03 11 2 [122 0 .04 1Si 3 [123 0 .03 121 2 i124 0 .04 16! 2 j125 0 .03 10i 2 [126 .04 .04 13i 0 .03 [ 3.43 ]128 0 .04 17i 2 i129 0 .03 11 2 o i .05i 3.41 ,0S i .0S [ 3.39 0 i .05 [ 3.39 0 i 0 i 3.40 0 [ ,05 [ 3.40 l Lt. Deposits. 0 i .06 i 3,39 Lt Depos ts 0 -L .04[ 3.41 .06[ .03[ 3.39 0 0 ] 3.39 0 .05[ 3.40 0 0 3.41 0 0 3.39 0 [ .04[ 3.39 0 i .03 i 3.42 .03[ 3.38 0 04 i 3.38 0 .04 i 3.42 0 .06 i 3.41 kt. Deposits. 0 .04 i 3.43 3.40 ShaJlow pitting, 0 0 3.40 _ Shallow pitting. 0 .05 [ 3.38 0 .07 .04 ~ 0 .05 i 0 .06 i 0 0 .03i [127 0 .04 131 2 0 .06i 0 .041 0 i130 0 .04 16i 2 !131 ,04 .04 13 2 i132 ,03 .05 19i 2 i133 0 .05 18i 2 i134 .03 .04 14[ 2 i135 0 i .04 14[ 1 i136 [ 0 i .04 15[ 2 139 i .02i .04i15i 2 140 [ .05 [ .03 I 13l .O4 ~ 3.40 Shallow pj~a~gg:_~t._p~posits. 3.39 Shallow pitting. 3.41 Shallow pitting. Lt. Deposits. 3.40 3.40 Shallow 3.42 Shallow pitting. LL Deposits, 3.41 Shallow .O9 i 0 3.39 .06 .05i 3.39 .03 .06i 3.42 [Shallow pitting. Lt. Deposits. ]Shallow pitting. Lt. Deposits, Line shallow corrosion. Lt, Deposits. .07 3.40 ]Shallow pitting. LL Deposits. .09 3.39 [Shallow pittin~ LL Deposits. .07 3.41 Shallow pitting. LL Deposits. .:10 ..)m~ ~[Shal]ow pitting, Lt. Deposits. .12 3.38 Shallow pitting. Lt_ Deposits, .13 3.39 Shallow pit fin g~_DeJ?osits. .07 3.40 Shallow pitting. Lt. Deposits. i 137 i 0 i .03 13 3 0 .04 141 i 0 [ .03 i 12i 2 .10 3 0 .14 ] 3,38 [Shallow pitting. Deposits. .17 i 3.35 [Shallow ]Damage profile (% wall) 50 100 Pipe Tabulations page 3 PDS CALI~ JOINT TABULATION SHEE] Pipe: 4ins 11 ppf BTC-Mod Wall thickness. Body: 0.262ins Upset = 0.262ins Nominal ID: 3.476 ins Well: 1Y-28 Field: Kuparuk River Unit Company: PHILLIPS ALASKA Country: USA Date: July 17, 2001 penetration body metal loss body Joint i142 i143 Metal [ Pro ection i Minimum i Loss ]Upset ]Body [ ID Comments Yo ] roches roches i inches .13 Upset Body inches inches L_~ 0 .03 13i 0 .03 13i .04 .03 13 0 .O4 15! ~07 .03 11 0 .04 161 0 .04 14i 0 .03 0 .03 13i 0 .04 14i 0 .04 14[ 0 .04 16i .O6 .o9 ] .14 ] 2 .06 i147 2 0 .17[ [148 2 0 .17[ l~J~. ~ 2 0 .09] i150 2 0 .17] [151 2 0 .05i ~5-2 2 j 0 .04 i i155 2 i .05 .05 ]154 0 .03 12i 3 j 0 .04i 2j o 0 .03 11j 0 0 0[ j155 155.1] 3.39 l Shallow pi~n~..L, lDeposits. 3.41 3.40 ]Shallow piing. LL Deposits. 3.34 Shallow pitting. Deposits. 3.42 p~(~ups~ 3.30 iSha[lowpi~ng. Deposits. 3.31 Shallow pitting. Deposits. 3.39 Shallow ~m~_ng:_Lt ~posits. 3.32 Shallow pitling. Deposits. 3.41 Shallow 3~42 Shallow 3.41 Shallow pitting. Lt. Deposits. 3.40 Shallow 3.43 0 [ X-Over to 3.5" Damage Classifications Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 75% of drcumference, but depth range does not exceed 1 * pipe ID Line damage depth range exceeds 5 * pipe ID, but extends [ess than 20% of drcumference General - damage depth range exceeds 1 * pipe ID and/or extends more thaa~ 20% of drcumference Isolated - damage depth range does not exceed 5 * pipe ID or extend more than 20% of circumference Damage reporting threshold = 30 thou inches deviation in body, 50 thou in upset. Modal line length = 0.220 feet. Damage profile (% wall) 50 100 Pipe Tabulations page 4 ~LLIPS ~,~SK^ PDS Caliper Sections Survey Date: July 17, 2001 Tool Type: MFC24 No99628 Tool Size: 1.69'i No. of Fingers: 24 Analysed: ). Burton ;joint 1 41 Nominal ID ~ 3.476 Ndminal OD -- 4,000 Remaining wall area = 98 % Tool deviation = 42 ° at depth 4537.5 ft Finger 19 Projection = -0.1 7 ins Isolated Deposit Cross~Sections page 1 PDS C, . IPER JOINT TALLY SHEET Pipe: 4ins 11 ppf BTC-Mod Wall thickness. Body: 0.262ins Upset = 0.262ins Nominal ID: 3.476 ins Joint No. 1.1 Depth feet 23.74 55.37 1.2[ 65.45 1.3 i 71.44 2 i 73.06 3! 104.81 4 i 136.51 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 168.20 6 i 199.91 7! 231.62 8 i 263.31 295.08 326.80 358.47 390.20 421.91 453.66 485.36 517.05 548.74 580.45 612.18 643.87 675.59 707.29 739.03 770.68 802.37 834.15 865.82 897.48 929.17 960.91 992.60 1024.29 1056.00 1087.68 1119.42 1149.76 1181.45 1213.17 1244.84 1276.49 1308.20 1339.91 1371.65 1403.37 Len~h feet 31.63 10.08 5.99 1.62 31.75 31.70 31.69 31.71 31.71 31.69 31.77 31.72 31.67 31.73 31.71 31.75 31.70 31.69 31.69 31.71 31.73 31.69 31.72 31.70 31.74 31.65 31.69 31.78 31.67 31.66 31.69 31.74 31.69 31.69 31.71 31.68 31.74 30.34 31.69 31.72 31.67 31.65 31.71 31.71 31.74 31.72 31.61 Measured ID inches nominal 3.497 3.483 3.459 3.483 3.484 3.483 3.478 nominal 3.485 3.479 3.478 nominal 3.474 3.474 nominal 3.470 3.471 nominal 3.471 3.469 3.474 3.471 3.472 3.464 3.466 3.470 3.465 3.460 3.467 3.462 3.467 3.466 3.468 3.475 3.468 3.459 3.468 3.466 3.462 3.466 3.474 3.468 3.471 3.470 3.469 3.461 ~ 45 1434.98 31.71 3.471 ! 46 1466.69 31.72 3.468 ! 47 1498.41 31.80 nominal Type Pup Pup , Pup Well: 1 Y-28 Field: Kuparuk River Unit Company: PHILLI PS ALASKA Country: USA Date: July 17, 2001 Joint Depth !Length No. i feet ! feet 48 1530.21 31.30 49 1561.51 31.92 50 1593.43 31.68 51 1625.11 31.75 52 1656.86 31.63 53 1688.49 31.77 54 1720.26 31.54 55 1751.80 31.79 55.1 1783.59 6.19 55.2 1789.78 8.76 55.3 1798.54 4.13 56 1802.67 31.82 57 1834.49 31.66 58 1866.15 31.56 59 1897.71 31.69 60 1929.40 31.70 61 1961.10 31.69 62 1992.79 31.74 63 2024.53 31.76 64 2056.29 31.71 65 2088.00 31.64 66 2119.64 31.67 67 2151.31 31.71 68 2183.02 31.76 69 2214.78 31.71 70 2246.49 31.66 71 2278.15 31.68 72 2309.83 31.74 73 2341.57 31.62 74 2373.19 31.67 75 2404.86 31.73 2436.59 76 31.77 77 2468.36 31.67 78 2500.03 31.71 79 2531.74 31.74 80 2563.48 31.62 81 2595.10 31.69 82 2626.79 31.70 83 2658.49 31.75 84 2690.24 31.71 85 2721.95 31.69 86 2753.64 31.70 87 2785.34 31.67 88 2817.01 31.84 89 2848.85 31.57 90 2880.42 31.62 91 2912.04 31.90 91.1i 2943.94 6.60 91.2] 2950.54 5.82 91.31 2956.36 6.48 Measured ID inches _ 3.466 3.465 3.472 3.470 3.472 3.469 . 3.465 3.472 3.458 nominal _ 3.463 3.467 3.467 3.466 3.464 Type pup Sssv Pup 3.464 3.466 _ 3.468 3.471 · 3.473 . 3.468 nominal _ 3.466 3.470 3.470 " 31466 .. 3.469 _3.472 3.474 3.468 3.474 3.465 3.462 3.473 ' 3.468 · 3.474 · 3.470 3.472 [ 3.473 3.472 nominal 3.473 3.470 3.467 3.469 3.481 3.471 3.474 Pup nominal -' Glml 3.474 !Pup Joint Tally page I PDS C, .-IPER JOINT TALLY SHEET Pipe:4ins 11 ppf BTC-Mod Wall thickness. Body: 0.262ins Upset = 0.262ins Nominal ID: 3.476 ins Joint No. 92 93 94 95 96 97 Depth feet 2962.84 2994.50 3026.20 3057.61 3089.66 3121.18 Length feet 31.66 31.70 31.41 32.05 31.52 Measured ID inches 3.468 3.463 3.471 3.463 3.469 .470 Type 31.74 98 3152.92 31.74 i 3.462 99 3184.66 31.66 3.466 100 3216.32 31.75 i 3.464 101 3248.07 31.64 i 3.469 102 3279.71 31.68 i 3.467 103 3311.39 31.63 i 3.469 104 3343.02 31.64 ] 3.460 105 3374.66 31.82 3.468 106 3406.48 31.67 3.469 107 3438.15 31.58 3.471 108 3469.73 31.80 3.459 109 3501.53 31.70 3.472 110 3533.23 31.59 3.470 111 3564.82 31.63 3.465 112 3596.45 31.88 3.471 113 114 3628.33 31.59 3.467 3659.92 31.83 3.480 115 3691.75 31.54 3.474 116 3723.29 31.84 3.469 117 3755.13 31.71 3.475 118 3786.84 31.66 3.470 119 3818.50 31.59 3.480 120 3850.09 31.57 3.473 121 3881.66 31.84 nominal 122 3913.50 31.66 3.480 123 3945.16 31.50 3.482 124 3976.66 31.96 3.474 125 4008.62 31.56 3.478 126 4040.18 31.65 3.472 127 4071.83 31.81 3.478 128 i 4103.64 31.65 nominal 129 i 4135.29 130 T 4166.93 31.64 nominal 3.480 31.74 131 ] 4198.67 31.69 3.482 132 i 4230.36 31.82 3.481 133 i 4262.18 31.67 3.481 134 i 4293.85 31.52 3.473 ~135 i 4325.37 31.69 3.471 136 i 4357.06 31.72 nominal 137 4388.78 31.72 3.475 138 4420.50 31.89 3.479 139 4452.39 31.72 3.480 - 140 4484.11 31.64 3.479 141 4515.75 31.69 3.483 Well: Field: Company: Country: Date: Joint No. 1 Y-28 Kuparuk River Unit PHILLIPS ALASKA USA July 17, 2001 Depth feet Length feet 142 4547.44 31.81 143 4579.25 31.67 144 4610.92 31.42 145 4642.34 31.89 146 4674.23 31.72 147 4705.95 31.63 148 4737.58 31.72 149 4769.30 31.58 150 4800.88 31.74 151 4832.62 31.68 152 4864.30 153 4895.94 154 4927.63 155 4959.48 Measured ID inches · 3.478 155.1 Type · 3.474 _ 3.485 3.483 3.483 __ 3.483 · 3.475 3.482 3.482 . 3.484 31.64 ! nominal 31.69 ] 3.484 31.85 '. 3.479 _ 31.52 3.483 unknown; 3.483 4991.00 _ X-Ovr Joint Tally page 2 Well: 1Y-28 Field: Kuparuk River Unit Company: PHILLIPS KUPARUK Country: USA PDS Caliper Overview Body Region Analysis Survey Date: July 17, 2001 Tool Type: MFC24 No99628 Tool Size: 1.69" No. of Fingers: 24 Analysed: J. Burton Tubing: Size Weight Grade & Thread Nora.OD Nom. ID Nom. Upset 3.5 ins 9.3 ppf EUE 3.5 ins 2.992 ins 3.5 ins Penetration and Metal Loss (% wall) ~ penetration body ~ metal loss body 100 0 0to 1 to 10to 20 to 40 to above 1% 10% 20% 40% 85% 85% Pene 1 36 67 2 0 1 Loss 17 89 1 0 0 0 Damage Configuration ( body 50 Number of joints damaged {total = 56) 43 12 0 0 Damage Prot'de (% wall) penetration body ~ metal loss body 0 50 100 GLM 2 GLM 3 45 GLM 4 GLM 5 GLM 6 83 GLM 7 Bottom of Survey = 87.9 AnaJysis Overview page 2 PDS Pipe: 3.5 ins 9.3 ppf EUE Wall thickness. Body: 0~254ins Upset = 0.254ins Nominal ID: 2,992 ins JOINT TABULATION SHEET Well: 1Y-28 Field: Kuparuk River Unit Company: PHILLIPS KUPARUK Countp/: USA Date: July 17, 2001 penetralion body metal loss body Ioint Penetration No. Upset Body inches 45 46 47 48 49 5O 0 .04 0 .05 0 .03 0 .04 0 .03 0 .04 Metal Projection Loss Upset Body % inches inches Minimum ID Comments inches 2.91 Shallow pitting. L}~ Deposits. 2.91 Shallow corrosion. Lt. Deposits. 2.91 15 4 0 .05 20 5 0 ~06 10 2 0 .04 15 6 0 .12 13 4 0 .04 14 7 0 .05 23 6 0 .05 13 4 0 .05 14 [ 2 0 .05 2.84 2.91 [Shallow 2.90 Shallow corrosion. Lt. Deposits. 51 0 .06 2.90 Corrosion. 52 0 .03 0 .04 .02 6 ] 1 0 0 .03 , 13 3 0 .04 .03 [ 11 I 0 .04 o o o o i o 53 54 0 55 0 55.1] 0 i 55.2i 0 0 .04 15 0 .02 9 0 .04 16i 0 .04 17[ 0 .05 19[ 55.3[ i 57 i 59 4 0 [ .09[ 2 0 J .04 [ 6 0 J .06 j 6 0 .04 4 0 .07 2 0 04 6 0 .06 j 2 ~ 0 .05 [ 3 0 0 2 0 .05 [ 5 0 .04 [ 2 0 o4 4 0 :26 4 0 .05 1 0 .03 3 0 .04 [ 4 0 .04 ] 6 0 .04 [ 6 0 .05 [ i 6O 0 .02[ 8[ 61 0 .0S]2O] 62 p .03 i 12i 63 - 0 .92 [ 8 i 64 0 .041 14i 65 0 .05 18! 66 0 .03 13! 67 0 .05 18i 68 0 .03 13i 69 0 .01 6i 70 0 .02 9i 71 0 .02 72 0 .04 73 0 .05 19i .O4 i .04 ~ .05 i 74 75 76 .03 10 3 .03 13 [ 2 .03 10[ 4 .03 13 3 77 0 0 .06i 78 0 79 0 80 0 80.1 0 80.2i 0 .04 14[ 2 0 .06] .04 16j 3 0 ,07l .03 121 4 [ 0 .05[ .03 I0 i I i 0 i .04i 0 6 i -~6--'--b--'~ i 0 .02, 7i..1 0 .04i .03 10[ 3 0 .05i 0 O[ 0 0 0 .03 10[ 2 0 0 0 0[ 0 0 0 .03 10i 2 0 .04i 0 Oi 0 ~ 0 0 .01 6i 1 0 .03i .03 ll 4 0 8o.3i 0 81 0 2.92 ~ha!!2~ pi~!n$. 2.92 Shallow pitting. 2.93 2.89 l Shallow pitting. 2.89 ] PUP 2.90 [ GL_M~ (Latch@6:00 2,90 PUP Shallow pit~l)g... 2.90 2.91 Shallow 2.92 Shallow pitt!9~. 2.91 Shallow pitting. LL Dep..osits. 2.93 2.92 Corrosion. Lt. Deposits. 2.92 2.91 2.92 [ Shallow pitting:_ 2.89 Shallow corrosion. 2.93 2.90 Shallow pitting. LL ~e~osits. 2.93 Shallow pitting. 2.95 2.91 2.95i 2.91 l Shallow corrosion. 2.91 J Shallow pitting, 2.90 2.90 i Shallo~w~pittip3: 2.93 Lt. Deposits. 2.94 l Shallow pitting. Lt. Deposits. 2.89 2.91 l Shallow pilling. L&.Deposits. 2.90 2.90 PUP 2.89 GLM 5 (Latch @ 8:30) 2~89 PUP 2.92 [Lt. Deposits. 2.81 [ W-1 Nipple 2.97 [ PUP 81.3 0 2.93 [ PACKER 81.4i 0 2.93 LPUP 81.5 0 2.95 i GLM6 (Latch@l:00) 81.6 0 2.95 PUP 82 0 2.94 Damage profile (% wall) 50 100 Pipe Tabulations page 2 PDS CALI~ JOINT TABULATION SHEEI Pipe: 3.5 ins 9.3 ppf EUE Wall thickness. Body: 0.254ins Upset = 0.254ins Nominal ID: 2.992 ins Well: IY-28 Field: Kuparuk River Unit Company: PHILLIPS KUPARUK Country: USA Date: Itdy 17, 2001 Joil'~t No. Upset Body inches inch~s..~(o [ % 83 0 .02 9! 2 84 0 .02 9 [ 2 [~85 ..... .02 [ 9] 1 85.~ o .o2 [ ~[ 1 85.2] 0 0 i 0[ 0 85.3 0 .01 i 5[ Penetration Metali Projection Minimum 8S~4[ 0 0 [ 0 0 85.5 o .ol i ~'~ 1 Loss iUpset Body iD inches inches inches 0 .04 2.92 0 .04 2.94 0 [ .04 2.95 0 [ 0 2.95 PUP 0 [ ~ -.-L 2.81 [ SLIDING SLEEVE 0 [ 0 [ 2.96_ [PUP 0 ~ 0 [ 2.95 [PACKER 0 I 0 [ 2.95 [ PUP .17 ] 0 [ 2.96 0 .04 0 0 0 0 86 [ 0 .52 100 17 87 [ 0 .06 24 1 87.1 0 .02 7 2 87.2 0 .01 6 2 87.3 0 0 O] 0 87.4 0 .04 14 4 87.5 .00 .02 8 1 2.96 2.91 [ Larse HOLE l! isolated pitting. PUP 2.92 PUP 2.95 GLM 7 (Latch @ 2:30) 2.95 0 0 0 .04 2.92 PUP Shallow PUP 0 .06 87.6 0 0 0 [ 0 0 0 2.75 SLIDING SLEEVE 87.7 0 .00 2 [ 2 0 0 2.95 PUP 87.8 0 .02 8 i 1 0 0 2,95 PUP 87.9 0 0 0[ 0 0 i 0 .47 PACKER penetration body metal loss body Damage profile 50 100 Damage Classifications Penetra6on / projecflon class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thicka~ess Ring- damage area exceeds 75% of circumference, but depth range does not exceed 1 * pipe [D Line - damage depth range exceeds 5 * pipe ID, but extends less than 20% of circumference General - damage depth range exceeds 1 * pipe ID and/or extends more than 20°/° of circumference isolated damage depth range does not exceed 5 * pipe ID or extend more than 20% of drcumference Damage reporting threshold = 30 thou inches deviation in body, 50 thou in upset. Modal line length 0.208 feet. Pipe Tabulations page 3 1 Y-28 d: Kuoaruk River Unit Company: PHILLIPS KUPARUK Country: USA Tubing: 3.5 ins 9.3 ppf EUE PDS Caliper Sections Survey Date: July 17~ 2001 Tool Type: MFC24 No99628 Tool Size: 1 ~69~ No, of Fingers: 24 Analysed: I. Burton Cross section for Joint 86 Tool speed = 53 Nominal ID ~ 2.992 Nominal OD = 3,500 Remaining wail area = 64 % Tool deviation = 41 ° at depth 7833.82 ft Finger 1 Radius = 1,522 ins HOLE with Associated Erosional Damage HIGH SIDE = UP Cross*Sections page '1 PDS C, . iPER JOINT TALLY SHEET Pipe: 3.5 ins 9.3 ppf EUE Wall thickness. Body: 0.254ins Upset = 0.254ins Nominal ID: 2.992 ins Joint No. Depth feet 4990.79 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 .2! 4998.73 5007.05 5012.64 5042.43 5073.44 5105.05 5136.64 5167.95 5199.21 5230.51 5261.66 5293.08 5324.85 5356.50 5387.99 5419.60 5451.30 5482.68 5513.68 5544.19 5575.37 5604.16 5635.31 5667.02 5698.21 5729.94 25 t 5759.66 26 ~ 5791.43 27 i 5822.62 28 i 5854.20 29! 5885.62 30 ! 5917.22 31 31.1 31.2 31.3 32 5948.32 5980.00 5987.71 5996.05 6000.25 Length feet 7.94 8.32 5.59 29.79 31.01 31.61 31.59 31.31 31.26 31.30 31.15 31.42 31.77 31.65 31.49 31.61 31.70 31.38 31.00 30.51 31.18 28.79 31.15 31.71 31.19 31.73 29.72 31.77 31.19 31.58 31.42 31.60 31.10 31.68 7.71 8.34 4.20 32.05 Measured ID inches 2.990 nominal 2.977 nominal 2.982 2.996 nominal 2.984 2.970 2.986 2,975 3.000 2.984 2.980 2.989 2.999 3.002 2.989 2.985 3.042 2.982 2.969 2.994 nominal 2.983 2.997 2.982 2.996 2.983 2,988 2.980 2.972 2.988 2,998 2.986 nominal 2,963 2.984 Type Pup GIm2 Pup Pup GIm3 Pup _ 33 6032.30 30.64 3,007 34 6062.94 31.67 2.987 35 6094.61 30.89 nominal 36 6125.50 32.24 2,994 37 6157.74 30.53 2,988 38 6188.27 32.25 2.990 39 6220.52 i 30.46 2,984 40 6250.98! 31.91 2,988 41 6282.891 30.83 3.005 42 6313.72 i 29.96 3.000 43 6343.68 '~ 32.11 2.990 44 6375.79! 30.35 2.984 Well: Field: Company: Country: Date: Joint No. 45 1Y-28 Kuparuk River Unit PHILLIPS KUPARUK USA July 17, 2001 Depth feet 6406.14 Length feet 30.83 46 6436.97 32.18 47 6469.15 28.38 48 6497.53 30.63 49 6528.16 32.42 50 6560.58 31.19 51 6591.77 31.11 52 6622.88 31.32 53 6654.20 31.29 54 6685.49 28.78 55 6714.27 32.49 55.1 6746.76 7.86 55.2 6754.62 7.82 55.3 6762.44 3.68 56 6766.12 30.53 57 6796.65 31.08 58 6827.73 30.99 59 6858.72 31.94 60 6890.66 29.79 61 6920.45 31.65 62 6952.10 30.50 63 6982.60 28.73 64 7011.33 28.18 65 7039.51 32.12 66 7071.63 30.55 7102.18 7133.21 67 68 31.03 30.90 69 7164.11 31.12 70 7195.23 30.41 71 7225.64 31.50 72 7257.14 30.35 73 7287.49 31.50 74 7318.99 32.37 75 7351.36 30.93 76 7382.29 30.52 77 7412.81 32.80 78 7445.61 30.98 79 7476.59 30.93 80 7507.52 31.36 80.1 7538.88 7.62 80.2 7546.50 7.52 80.3 7554.02 5.57 81 7559.59 30.04 [81.1 7589.63 3.04 181.2 7592.67 4.62 ~ 81.3 7597.29 27.75 i 81.4 7625.04 4.47 i , i 81,5 7629.51 9.89 [81.6 7639.40 5.36 / 82 7644.76 32.53 Measured jType ID inches _ 2.979 . _2.987 2.998 2.975 2.982 nominal 2.994 3.001 2.986 . 2.984 2.996 nominal _Pup nominal GIm4 2.964 Pup nominal 2.985 2.979 2.999 2.982! . 2.986 I nominal t 2.977 2.988 2.974 2.995 2.977 2.991 · 2.996 . 2.986 _ 2.991 2.996 2.996 nominal · 2.990 2.989 2.999 . 2.983 nominal nominal 2.979 Pup nominal GIm5 2.985 Pup 2.988 nominal Wl~Nip 2.994 Pup nominal PKR _ _ . nominal , Pup nominal GIm6 2.990 Pup 3.006 ' Joint Tally page I PDS C, .riPER JOINT TALLY SHEET Pipe: 3.5 ins 9.3 ppf EUE Wall thickness. Body: 0.254ins Upset = 0.254ins Nominal ID: 2.992 ins Joint No. 83 84 85 85.1 85.2 85.3 85.4 85.5 86 87 87.1 87.2 87.3 87.41 87.5i 87.6 87.7 87.8 Depth feet 7677.29 7707.99 7735.58 7763.82 7770.55 7774.68 7781.66 7793.75 7807.12 7834.07 7866.04 7869.21 7875.79 7883.26 7890.34 7899.75 7903.62 Length feet 30.70 27.59 28.24 6.73 4.13 6.98 12.09 13.37 26.95 31.97 3.17 6.58 7.47 7.08 9.41 3.87 8.11 Measured ID inches 2.996 2.996 3.008 2.988 nominal 2.987 nominal 3.006 3.006 3.012 2.939 2.991 nominal nominal 3.020 nominal 2.989 Type Pup SLD-SL~ Pup___ PKR Pup HOLE Pup ~ Pup~i GIm7 Pup Pup SLD-SLV 7911.73 3.77 2.985 ~ 87.9 7915.50 unknown 2.975 PKR ~ Pup _ Pup Well: Field: Company: Country: Date: Joint No. 1Y-28 Kuparuk River Unit PHILLIPS KUPARUK USA July 17, 2001 Depth Length feet feet Measu'~'ed iType ID inches · · _ · · _ . Joint Tally page 2 93-089 DAILY WELL OP 12/03/1993 93-089 CDR-E/LWD/DC b~- 7650-8250 i 10/25/1993 93-089 CDR-LWD/DC '~ 7280-8250 93-089 CET b~6700-8172 1 10/25/1993 09/07/1993 Are Was the well cored? yes ~ Are well tests required?~t yes Well is in compliance Initial COMHENT8 dry ditch samples required? yes (~ And received? ~ Analysis & description ~~ yes % Received? ~o no ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 17, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION gS--I~q 1F-15 ¢J5-''~ro 1 Y-22 ff~-~s' 1 Y-27 Y-28 STIMULATE PERFORATE PERFORATE STIMULATE PERFORATE If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (atch only) FTR031796 (w/o atch) RECEIVED MAR 2 3 1994 Alaska 0il & Gas Cons. Commission Anchorage AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate Plugging __ Repair well Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 211' FNL, 1944' FWL, Sec 1, T11N, R9E, UM At top of productive interval 2700' FSL, 106' FWL, Sec 31, T12N, R10E, UM At effective depth 2835' FSL, 332' FWL, Sec 31, T12N, R10E, UM At total depth 2867' FSL, 387' FWL, Sec 31, T12N, R10E, UM 12. Present well condition summary Total Depth: 6. Datum elevation (DF or KB) RKB 1 O6 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1Y-28 9. Permit number/approval number 93-89 10. APl number s o-029-22380 11. Field/Pool Kuparuk River Field/Oil Pool measured 8 2 8 5 feet true vertical 6521 feet Plugs (measured) None Effective depth: measured 8182 feet Junk (measured) None true vertical 6440 feet Casing Length Size Cemented Structural Conductor 1 21 ' 1 6" 235 Sx PFC CMT Surface 54 6 6' 9.62 5" 850 SX Perm. E & Intermediate 800 Sx Class G Production 8228' 7" 270 Sx Class G Liner Perforation depth: measured 7690'-7754', 7797'-7825', 7996'-8016' true vertical 6062'-6111', 6144'-6165', 6296'-6311' Measureddepth 121' 5507' 8267' True vertical depth 121' 4430' 6507' 8030'-8050' 6322'-6338' Tubing (size, grade, and measured depth) 4", 11#/ft., J-55 @ 4994', 3.5', 9.3#/ft., J-55 @ 4994'-7912', 2.875, 6.5#/ft., L-80 @ 7912'-7942' Packers and SSSV (type and measured depth) PKRs: Otis 'HTV' Retr. @ 7610' & 7777', Baker 'D' Perm @ 6999'; SSSV: Otis Series 10 SE @ 1798' 13. Stimulation or cement squeeze summary Perforated "A4" Sand on 1/28/94 @ 6 SPF, 90° Phasing. Intervals treated (measured) 7996'-8016' Treatment description including volumes used and final pressure N/A. RECEIVED MAR 2 5 1994 0il & Gas Cons. C0mmissic Representative Daily Averaqe Production or Injection Data Anchorage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsecluent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 160 // 494 5493 1360 250 / 217 123 662 1360 250 16. Status of wellclassification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. ~} Subsidiary of Atlantic Richfield Company WELL DESCRIPTION OF WORK 1Y-28 PERF 'A' SAND (PROCEDURE DATED 1/19/94) DATE ' 1/28/94 DAY 1 TIME O7OO O9OO 1130 CONTRACTOR / KEY PERSON SWS /RATHERT COMPLETION UNIT PBTD (RKB) ILAST TAG (RKB) - DATE 8,182'I 8,122' ON 1/26/94 LOG ENTRY KUPARUK RIVER UNIT WELL SERVICE REPORT }AFC/CC# - SCA# [ 998065 / 80223 [FIELD COST EST. IACCUMULATED COST I$5,006 I $5,006 ISSSV TYPE / STATUS 14" OTIS SERIES 10 SELF EQUALIZING MIRU SWS. Held safety meeting. MU gun and PU in lubricator. Pressure test lubricator. RIH 2-1/8" Enerjet with BH EJ charges 90° phasing @ 6 SPF. Tie in to CET dated 8/24/93. Perforate A4 sand from 7,996' to 8,016'. Log up through jewerly. POH. RDMO SWS. KUPARUK PETROLEUM ENGINEERING Stmnnary: · Perforate A4 sand from 7,996' to 8,016' with 2-1/8" Enerjet with BH EJ charges 90° phasing @ 6 SPF. Tie in to CET dated 8/24193. ~LCc .Alaska (.iii & 6as Cons. 6ommission Anchorage CHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK Report I -18 °F ! Good miles mph[ COMPLETE ~3(.arla J2 enz INCOMPLETE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate X Plugging_ Repair well Perforate Other 2. Name of Operator ARCO Alaska, In.c. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 211' FNL, 1944' FWL, Sec 1, T11N, R9E, UM At top of productive interval 2700' FSL, 106' FWL, Sec 31, T12N, R10E, U At effective depth 2835' FSL, 332' FWL, Sec 31, T12N, R10E, UM At total depth 2867' FSL, 387' FWL, Sec 31, T12N, R10E, UM 12. Present well condition summary Total Depth: measured 8 2 8 5 feet true vertical 652 1 feet 6. Datum elevation (DF or KB) RKB 106 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1Y-28 9. Permit number/approval number 93-89 10. APl number 5O-029-22380 '11. Field/Pool Kuparuk River Field/Oil Pool Plugs(measured) NoDe RECElVED Effective depth: measured 8 1 82 feet Junk (measured) None true vertical 6440 feet Measureddepth 121' 121' 5507' 4430' 8267' 6507' J~.~:SK~ uH & Gas Cons. Commis~ Anchorage True vertical depth Casing Length Size Cemented Structural Conductor 1 2 1 ' I 6" 235 Sx PFC CMT Surface 54 6 6' 9.625" 850 Sx Perm. E & Intermediate 800 Sx Class G Production 822 8' 7" 270 Sx Class G Liner Perforation depth: measured 7690'-7754', 7797'-7825', 7996'-8016', 8030'-8050' true vertical 6062'-6111', 6144'-6165', 6296'-6311', 6322'-6338' Tubing (size, grade, and measured depth) 4", 11#/ft., J-55 @ 4994', 3.5", 9.3#/ft., J-55 @ 4994'-7912', 2.875, 6.5#/ft., L-80 @ 7912'-7942' Packers and $SSV (type and measured depth) PKRs: Otis 'HTV' Retr. @ 7610' & 7777', Baker 'D' Perm @ 6999'; SSSV: Otis Series 10 SE @ 1798' 13. Stimulation or cement squeeze summary Fracture stimulation of "A" Sands on 2/6/94. Intervals treated (measured) 7996'-8016', 8030'-8050' Treatment description including volumes used and final pressure Pumped 208.5 Mlbs of 16/20 & 12/18 ceramic proppant into form., fp was 5250 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 160 494 5493 1360 250 217 123 662 1360 250 16. Status of well classification as: Oil X Gas Suspended . Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned Title Senior Engineer Form 10-404 Rev 06/15/88 Date 3-/~'' ~ SUBMIT IN DUPLICATE K~,'-\RUK WELL: / Y- '2-~' SERVICE CO: HOLE ANGLE @ PERFS: PERFORATED INTERVAL: FRICTION CORRELATIONS: (PSI/FT vs. BPM) STIMULATION ~UMM~' Y DATE: 2 ARCO REPS: AFE #: ORIENTATION COMMENTS/OTHER RATE XLGW GW SLK WTR SLK DSL .--) TVD TOP PERF: MD TOP PERF: MD TBG TAIL: MD TBG HANGER: FORMATION FRAC GRADIENT: FRAC FLUID GRA[~ENT: pRE-TREATMENT CALCULATIONS ///%' EXPECTED TREATING PRESSURE = (FORM FRAC GRAD X TVD TOP PERF) + (TBG FRIC X MD 'I'BG TAIL) ._ - (FLUID GRAD X TVD TOP PERF) = ~ 7_ ~ 2.- ~7. g 2~', $ ~ ~ / ,.- ... FLUSH VOLUME = (MD TBG TAIL - MD TBG HGR) X ('rBG BBLS/FT) + (MD TOP PERF- MD TBG TAIL) . R E C E IV E D PRESSURE ANALYSIS ~¢_~ .,¢,¢~ M~R 2 $ 1994 ACTUAL FRAC GRADIENT = ISIP / TVD TOP PERF + FRAC FLUID GRADIENT ~ '754- c~ 19O(o x~ w /~i~sk~ U~I & Gas Cons. C0mmissio~ EXCESS FRICTION = FWHTP - ISIP - (TBG FRIC X MD 'T'BG TAIL) d-,',c~L '2'7 $ 7. Anchorage 'C Lo6 c~ STEP VOLUME RATE FWHTP ISIP FG XS FRIC CL~)SURE PRESS EFF. T-/~¢'- 6oO EFFECTIVE PAD: TREATMENT TOTAL JOB: EFFECTIVE SLURRY: .. ~I, IMMARY (5 o~r PAD/TOTAL JOB RATIO: II ozt- PAD/SLURRY RATIO: PROP PUMPED: PPA@ PERFS: I¥ 16/20o°~OO 12/18124'j"{-3,0r- 10/14 PROP IN WELLBORE:/,5"30 PROP IN FORMATION: SEAWATER USED: / ~50 DIESEL USED: ?C) NOTES' /~-4-..C ..'-,"_--,,-,k<<r .-/5>. ~,r../,,~.LT el,2 ADDITIVES USED: ARCO Alaska, Inc. Post Office Bo.. ,00360 Anchorage, Alaska 99510-0360 Telephone 907 278 1215 February 1 4, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. . WELL ACTION ~.5 --Iqfl 1F-15 Perforate ¢i~-i ~o1 H-1 7 Perforate ~.k-tq'51Q-12 Stimulate c/~_uCj 1Y-17 Stimulate ~>~q 1Y-28 Stimulate ¢/o~ i-~,~ 3G-04 Perforate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECEIVED FEB I 6 1994 Oil & Gas Cons. Commission Anchorage AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,blON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing __ Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 211' FNL, 1944' FWL, Sec 1, T11N, R9E, UM At top of productive interval 2700' FSL, 106' FWL, Sec 31, T12N, R10E, UM At effective depth 2835' FSL, 332' FWL, Sec 31, T12N, R10E, UM At total depth 2867' FSL, 387' FWL, Sec 31, T12N, R10E, UM Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 1 2 1 ' Surface 5 4 6 6' Intermediate Production 8 2 2 8' Liner Perforation depth: 12. 8 2 8 5 feet 6 5 2 1 feet Plugs (measured) None 6. Datum elevation (DF or KB) RKB 106 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-28 9. Permit number/approval number 93-8~) 10. APl number 50r.029-22380 11. Field/Pool Kuparuk River Field/Oil Pool RECEIVED 81 82 feet Junk (measured) None 6 4 4 0 feet Measured depth Size Cemented 1 6" 235 Sx PFC CMT 9.625" 850 Sx Perm. E & 800 Sx Class G 7" 270 Sx Class G feet FEB 1 6 1994- Ai~tska Oil & Gas Cans, Oommissio~ Anchorage True vertical depth 121' 121' 5507' 4430' 13. 14. 8267' 6507' measured 7690'-7754', 7797'-7825', 8030'-8050' true vertical 6062'-6111', 61 44'-61 65', 6322'-6338' Tubing (size, grade, and measured depth) 4", 11#/ft., J-55 @ 4994', 3.5", 9.3#/ft., J-55 @ 4994'-7912', 2.875, 6.5#/ft., L-80 @ 7912'-7942' Packers and SSSV (type and measured depth) PKRs: Otis 'HTV' Retr. @ 7610' & 7777', Baker 'D' Perm @ 6999'; SSSV' Otis Series 10 SE @ 1798' Stimulation or cement squeeze summary Fractured "A3" Sand on 12/26/93. Intervals treated (measured) 8O3O'-8O5O' Treatment description including volumes used and final pressure Pumped 22.5 Mlbs 16/20 & 12/18 ceramic proppant into formation, fp was 6800 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas~Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 160 494 5493 1360 250 160 /'/ 494 5493 1360 250 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed¢~/~'' ~ Title Senior Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE . ,_ I:l:lA(3/_S_'TIMULATION ~Ul~ .~. WELl. NO: /_ Y- P_.~ AFC: ,olCl [~'"~t~ DATE: PROCEDURE DATE: ~LP..-~ -~. BEOIN EFIAC: SEFtVlOE CO: ~-~' .- ZONE: ANNULUS PRESS: _%'5~ _ ~al, PSI TEST LINE8 TO: PSi '$T~,GE'VOL. FLUID PROP CONC.PRbp size R'ATE (BPM) PRESSURE ' NII~ '" '"'" "'" '"'"'" ?.~ / ......... ~ 7 ~1 " " ~ Igll~. ~-~ ~ ~ /~ ..... ,. ~ ..... _ _ / .... '" k / ~ II / ,m, i , . .................. / i / / i i / a I ...... I i / I / ........... ii I lSIP: PSI 15 MIN. PSI AVG. PRE88: PSI FLUID ~ RECOVER~- I PJ~ BBL -- ~B COMP~-TE: I ~/,~ __HP.4 8AND IN ZONE: ~_ ~~ ITEMIZED 005~: ' FRAO: ROUSTABOUTS: . DIE~EL: LB 8ANO IN CASING: J ./.. 9~': 5'0 7 HOT OIL SERVICE: _ ~. ~9 ,"'5 ,-"'5 T"R~KINQ: ,~t-'"~ · - · _l JO -~_'~1 8UPEIRVISION:~~ RECEIVED RIG SUPERVISOR · l:0'd ~:O0'ON OZ::2.. £6,Z~ 33d 6£ZZ-6S9-Z06:0I ' ' STATE OF ALASKA ALA~r~ OIL AND GAS CONSERVATION COMM~oSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL F-~ GAS r~ SUSPENDED E~ ABANDONED E~ SERVICE E~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 93-89(..~/~ ! _ 3 Address 8 APl Number / P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22380 4 Location of well at surface [ ...... 9 Unit or Lease Name 211' FNL, 1944' FWL, SEC 1, T 11N, R 9E, UM. '.Z.'/(~ ~~:,~.. lO Well NumberKUPARUK RIVER At Top Producing Interval .. ~ ~,.~,~ F£~.;, 2700' FSL, 106' FWL, SEC 31, T 12N, R 10E, UM ~-.': :!:;-'i:.;,.:, , {f ~ 1Y-28 At Total Depth ~ ~4::~ ~ .. : ~,...~-.--~.'''~c-"L .-__.- J~~_ . 11 Field and Pool 2876' FSL, 387' FWL, SEC 31, T 12N, R 10E, UM :-::.:-'~'~~,_..~.? KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER RKB 106', PAD 65' GLI ADL 25640 ALK 2571 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 14-Aug-93 20-Aug'93 10/14/93(Comp)I NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 8285' MD, 6521' TVD 8182' MD, 6440' TVD YES X~ NO L_]I 1802' feet MDI 1500' APPROX 22 Type Electric or Other Logs Run CDR, CDN, CET, CBT, GCT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VVT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF 121' 24" 235 SX PFC CMT 9.625" 36# L-80/J-55 SURF 5507' 12.25" 850 SX PERM E, 800 SX CLASS G 7" 26# J-55 SURF 8267' 8.5" 270 SX CLASS G CMT 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE IDEPTH SET (MD) IPACKER SET (MD) 4'/3.5"/2.875' 11#/9.3#/6.5# J-55/L-80 7946' 7781', 7919' GUN @ 12 SPF 7690'- 7754' MD 6062'-6111' TVD I 4-1/2 CSG 4-1/2 CSG GUN @ 12 SPF 7797'- 7825' MD 6144'-6165' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4-1/2 CSG GUN @ 4 SPF 8030'- 8050' MD 6322'-6338' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OILoBBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I~ FlowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE I~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. REE£1VED DEC -3 1995 Alask& f¢~i & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP OF KUPARUK C 7764' 6119' 31. LIST OF A-I-rACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEY(GCT) 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed _ .~~~"7~ Title ~/,~ ~,~'/_~ ~1~' DATE _~~. . .. ! / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1Y-28 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25640 ALK 2571 50-029-22380 93-89 ACCEPT: 08/13/93 11:00 SPUD: 08/14/93 03:30 RELEASE: 10/14/93 12:00 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 08/14/93 (1) PARKER 245 TD: 475'( 475) 08/15/93 (2) PARKER 245 TD: 4275' (3800) 08/16/93 (3) PARKER 245 TD: 5245' ( 970) 08/17/93 (4) PARKER 245 TD: 5525'( 280) 08/18/93 (5) PARKER 245 TD: 7400' (1875) DRILLING 16"@ 121' MW: 9.0 VIS: 63 MOVE RIG F/1Y-19 TO 1Y-28. ACCEPT RIG @ 2300 HRS ON 08/13/93. NU 20" DIVERTER. BOBBY FOSTER W/AOGCC WAIVED WITNESSING TEST. PU BHA. CLEAN OUT COND F/58'-121'. SPUD @ 0330 HRS ON 08/14/93. DRILL F/121'-475'. DRILLING 16"@ 121' MW: 9.9 VIS: 48 DRILL F/475'-3063'. SHORT TRIP TO HWDP. TIH-REAM TIGHT HOLE F/1800'-1924'. NO FILL. DRILL F/3063'-4275'. DRILLING 16"@ 121' MW: 9.8 VIS: 44 DRILL F/4275'-4657'. CBU. POOH. CLEAN BHA. MU NEW BIT & TIH. DRILL F/4657'-5209'. PENETRATION RATE DECREASED & COULD NOT SLIDE. PMP PILL & POOH. LD MOTOR & CLEAN UP BIT. MU BIT, NEW MOTOR, ORIENT & TEST MWD & TIH. TIGHT SPOT @ 1800'-1950'. DRILL F/5209'-5245'. ND DIVERTER 9-5/8"@ 5507' MW: 9.8 VIS: 42 DRILL F/5245'-5525'. CBU. POH. LD BHA. RU CSG EQUIP & HOLD SAFETY MEETING. RUN 9-5/8" CSG. TOTAL OF 132 JTS RUN. SHOE @ 5507'. CIRC & COND MUD. RU DOWELL. TEST LINES TO 3000 PSI. MIX & PMP 850 SX LEAD CMT @ 12 PPG. PMP 800 SX TAIL @ 15.8 PPG. DISPLACE W/RIG PMP & BMP PLUG TO 2000 PSI. FLOATS HELD. LOST ALL RETURNS 345 BBLS INTO DISPLACEMENT. LD LANDING JT & ND 20" DIVERTER. CBU 9-5/8~'@ 5507' MW: 9.8 VIS: 35 DOWELL DID TOP JOB PMP 25 BBLS WATER & 120 SX AS1 PF CMT. SCREW ON 11"-3000 BRADEN HEAD. TORQUE 18K. 37.6' RT TO HEAD. NU 13-5/8"-5000 BOPS. TEST BOPE TO 300 & 3000 PSI-OK. TESTED WITNESSED BY BOBBY FOSTER OF AOGCC. PU TURBINE & BHA, ORIENT TOOLS, TEST MWD. RIH. CIRC & COND MUD. TEST 9-5/8" CSG TO 2000 PSI. DRILL OUT CMT, PLUGS, FC @ 5421', CMT, & SHOE @ 5507'. DRILL 10' NEW FORMATION F/5525'-5535'. RAN EMW TEST @ 4400' TVD W/8.8+ PPG. PRESS UP TO 900 PSI FOR 10 MIN. HELD. EMW=12.7 PPG. DRILL 8.5" HOLE F/5535'-7400'. RAISED MUD WT TO 10.3 PPG. START CBU. WELL: 1Y-28 API: 50-029-22380 PERMIT: 93-89 PAGE: 2 08/19/93 (6) PARKER 245 TD: 7445'( 45) 08/20/93 (7) PARKER 245 TD: 8133'( 688) 08/21/93 (8) PARKER 245 TD: 8285' ( 152) 08/22/93 (9) PARKER 245 TD: 8285'( o) 08/26/93 (13) DOWELL TD: 8285 DRILLING 9-5/8"@ 5507' MW:ll.7 VIS: 52 CBU. POH. HOLE IN GOOD SHAPE. LD TURBINE & BHA. PU BHA. RIH. CIRC & COND MUD @ 7400'_ MIXED 30 PPB LCM IN MUD SYSTEM. RAISED MUD WT TO 11.2 PPG. SLUG DP. TRIP OUT TO 9-5/8" SHOE. RAN EMW TEST @ 5827' TVD W/ll.2 PPG MUD. PRESS UP TO 255 PSI FOR 10 MIN. LEAKED OFF 19 PSI TO 236 PSI. EMW=ll.98 PPG. RIH SLOW. WASHED 46' TO BTM-NO FILL. CIRC & COND MUD-RAISED MUD WT TO 11.7 PPG. NO MUD LOSS. DRILLING 8.5" HOLE F/7400'-7445'. DRILLING 9-5/8"@ 5507' MW:ll.7 VIS: 47 DRILL 8.5" HOLE F/7445'-7628'. SERVICE RIG. DRILL 8.5" HOLE F/7628'-8133'. RUNNING 7" CSG 9-5/8"@ 5507' MW:ll.7 VIS: 51 DRILL 8.5" HOLE F/8133'-8285'. CBU. POH W/27 STD. HOLE TIGHT F/8200'-7900'. RIH-TIGHT F/7380'-7440'. NO FILL. CBU. MUD GAS CUT TO 11.4 PPG. DROP SURV & SLUG DP. POH-LD LWD TOOLS. PULLED WEAR BUSHING. RU CASERS-SAFETY MEETING. RUNNING 7" 26# L-80 CSG @ RPT TIME. RIG RELEASED 7"@ 8267' MW:ll.7 VIS: 53 RAN 195 JTS 7" CSG. BROKE CIRC @ 2900' & 5430'. NO MUD LOSS. CIRC & COND MUD & HOLE W/CSG ON BTM J@ 8267'. PMP 650 BBLS-800 PSI @ 6 BPM. FULL RETURNS. SET & CMT'D 7" CSG W/SHOE @ 8267' & FC @ 8181'. DOWELL CMT'D W/ 270 SX PREM G CMT. BMP PLUG. TEST CSG TO 3500 PSI-7" COLLAR LEAKING-TEST INCOMPLETE. PU STACK. LANDED CSG. CUT OFF 7". ND & SET OUT STACK. FINAL CUT 7" NU 11"-3000 X 7-1/16" 5000 TBG HEAD & TREE. TEST TB~ HEAD TO 3000 PSI. FREEZE PROTECT ANN W/150 BBLS WATER & 70 BBLS DIESEL. LD 5" DP. FIN CLEANING PIT & INJ MUD-FREEZE PROTECT INJ WELL. RELEASED RIG @ 0500 HRS 08/22/93. 7"@ 8267' 10/12/93 (10) NORDIC 1 TD: 8285 PB: 8182 PERFORATING 7"@ 8267' MW:ll.7 NaC1/Br MOVE RIG F/1Y-18 TO 1Y-28. ACCEPT RIG @ 1900 HRS 10/11/93. ND DRY HOLE TREE. NU BOP. TEST BLIND RAMS, BROKEN FLANGE & 7" CSG TO 3500 PSI. OK. SET TEST PLUG & TESTED 3-1/2" PIPE RAMS TO 3500 PSI. PULLED TEST PLUG. RU SCHLUMBERGER & TEST LUB TO 1000 PSI & PERF. PERF F/8030'-8050' @ 4 SPF. PERF F/7730'-7825' @ 12 SPF. DEC AJ~Ska 0i~ & Gas Cons. Gommisslon Anchorage WELL: 1Y-28 API: 50-029-22380 PERMIT: 93-89 PAGE: 3 10/13/93 (11) NORDIC 1 TD: 8285 PB: 8182 10/14/93 (12) NORDIC 1 TD: 8285 PB: 8182 RUNNING TBG 7"@ 8267' MW:ll.7 NaCl/Br CONT PERF F/7710'-7730' @ 12 SPF, 7690'-7710' @ 12 SPF. ASF. POOH & LD GUNS. RIH W/GAUGE RING/JB. MU BAKER PKR ASSY & RIH ON E-LINE. SET PKR @ 7915' WLM W/TBG TAIL @ 7942', TIED INTO FINAL CET LOG OF 08/24/93. POOH. RD SWS. RU FLOW NIPPLE & FLOOR TO RUN TBG. MU CARBIDE BLAST RING. MU BAKER SEAL ASSY, CAMCO SS, BLAST RINGS, & OTIS PKR. RIH. CONT RIH W/3-1/2" 9.3# EUE J-55 TBG W/GAS LIFT MANDREL, & OTIS SSSV. MU OTIS 4" SERIES 10' SSSV & ATTACH 1/4" CONTROL LINE. PRESS CONTROL LINE TO 5000 PSI. HOLD F/10 MIN. CONT RIH W/4" TBG & CONTROL LINE. ATTACH SS BANDS EVERY OTHER JT. RELEASED RIG 7"@ 8267' MW:ll.7 NaCl/Br SERV RIG. FUNCTION TEST BOP. CONT RIH W/4" TBG & CONTROL LINE, ATTACH SS BANDS EVERY OTHER JT TO SURF. SPACE OUT TBG. MU FMC HGR. MU CONTROL LINE & TEST TO 5000 PSI. DRAIN STACK. STING INTO PERM PKR & VERIFY SEALS ARE IN. LAND TBG. RILDS. PRESS UP TBG TO 3000 PSI TO SET OTIS PKRS. SHEAR OUT BALL SET @ 3000 PSI. WAIT ON OTIS SL UNIT. RU OTIS SL & RIH. SET STANDING VALVE IN CAMCO D NIPPLE. POH & RIG BACK. PRESS TBG TO 3000 PSI TO SET PKRS F/30 MIN-OK. PRESS ANN & TBG TO 1000 PSI, CLOSED SSSV & BLEED TBG PRESS TO 500 PSI. HOLD F/15 MIN. BOLDS. PRESS TBG TO 2000 PSI & PU TO SHEAR PBR @ 93K. LAND TBG. RILDS. TESTED ANN TO 2500 PSI. INCREASE PRESS ON TBG TO 3000 PSI. RU OTIS SL. RIH & PULL STANDING VALVE. POH. RD OTIS. ND BOP. NU FMC TREE. TEST FLANGE & PACKOFF TO 5000 PSI. OPEN SSSV. PMP 11 BBLS DIESEL IN ANN. BULLHEAD 5 BBLS DIESEL DN TBG. SECURE WELL. RELEASED RIG @ 2400 HRS 10/13/93. SIGNATURE: (Rrilli~g su--perinten~ent)' RECEIVED DEC - 199, Alaska 0il & Gas Cons. Commission Anchorage SUB - SURFA CE DIRECTIONAL SURVEY Company ARCO ALASKA, INC. Well Name 1Y-28 (211.' FNL, 1944' Fid., SEC 1, TllN, RgE, UN) Field/Location KUPARUK, NORTH SLOPE, ALASI~ Job Reference No. 93395 Logaed Bv: RATHERT RECEIVED DEC - 3 199,:3 Pil.& Gas Cons. Commission "'Anchorage Date 24-AUG-93 Computed By: SINES SCHLUMBERGER OCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO A~SKA INC. 1 Y - 28 KUPARUK RIVER NORTH SLOPE, A~SKA SURVEY DATE: 24-AUG-g3 ENGINEER: JACK RATHERT METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION' HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 49 DEG 44 MIN EAST COMPUTATION DATE' 30-AUG-93 PAGE I ARCO ALASKA INC. 1Y - 28 Kt..F'ARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 24-AUG-93 KELLY BUSHING ELEVATION: 106.00 FT ENGINEER: JACK RATHERT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG 0 O0 100 O0 200 O0 300 O0 40O O0 500 O0 600 O0 7OO O0 800 O0 900 O0 0 O0 -106.00 100 O0 200 O0 299 99 399 86 499 29 597 81 694 94 790 77 885 72 0 0 N 0 0 E -6.00 0 24 N 29 59 E 94.00 0 26 N 34 28 E 193.99 I 23 N 55 17 E 293.86 4 29 N 56 I E 393.29 7 50 N 53 59 E 491.81 11 54 N 54 53 E 588.94 15 26 N 54 33 E 684.77 17 31 N 54 54 E 779.72 18 59 N 54 44 E 1000.00 979.92 873.92 20 23 1100.00 1073.06 967.06 22 13 1200.00 1165.33 1059.33 23 0 1300 O0 1256.87 1150.87 24 49 1400 O0 1346.44 1240.44 27 46 1500 O0 1434.07 1328.07 30 18 1600 O0 1518.45 1412,45 34 41 1700 O0 1598.45 1492.45 39 2 1800 O0 1674.41 1568.41 41 34 1900 O0 1749.10 1643.10 41 35 N 54 6 E N 54 15 E N 54 46 E N 54 42 E N 53 32 E N 52 28 E N 51 7 E N 5O 4O E N 50 42 E N 51 15 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET FEET FEET FEET DEG MIN 0.00 0.17 0.84 2.22 6.96 17.47 34.44 '58.07 86.51 117.73 151 18 187 47 225 88 265 97 310 28 358 35 411 92 471 87 536 88 603 36 DEG/IO0 0 O0 0 O0 0 O0 1 76 3 96 4 66 4 12 2 94 1 6O 1 28 1 6O 0 74 3 12 1 4 4 4 0 0 74 26 84 35 85 72 0 O0 N 0 16 N 0 76 N 1 70 N 4 29 N 10 38 N 20 36 N 34 03 N 50 52 N 68 57 N 0 O0 E 0 09 E 0 45 E 1 47 E 5 49 E 14 10 E 27 89 E 47 27 E 70 58 E 96 0 O0 N 0 0 E 0 0 2 6 17 34 58 86 21 E 118 18 N 30 11E 89 N 30 50 E 25 N 40 43 E 97 N 52 1E 51 N 53 38 E 53 N 53 52 E 25 N 54 15 E 8O N 54 24 E 15 N 54 31E 88 10 N 123 51 E 151 71 N 54 30 E 109 131 154 181 209 243 281 322 364 45 N 152 81N 184 99 N 217 06 N 253 97 N 291 15 N 333 05 N 38O 22 N 430 15 N 482 97 E 188 38 E 226 27 E 266 26 E 311 77 E 359 88 E 413 33 E 472 65 E 537 27 E 604 10 N 54 25 E 64 N 54 26 E 89 N 54 3O E 32 N 54 26 E 47 N 54 16 E O3 N 53 56 E 90 N 53 32 E 85 N 53 12 E 31 N 52 57 E 2000 O0 1823 96 1717.96 41 39 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 1898 O0 1972 O0 2046 O0 2120 O0 2193 O0 2265 O0 2337 O0 2409 O0 2480 42 1792.42 42 0 70 1866.70 42 8 71 1940 71 42 24 38 2014 38 42 46 22 2087 22 43 45 30 2159 30 43 51 38 2231 38 43 58 27 2303 27 44 8 82 2374 82 44 30 N 52 5 E 669.63 N 52 33 E 736.31 N 53 6 E 803.17 N 53 22 E 870.28 N 53 16 E 937.77 N 51 42 E 1006.21 N 52 1E 1075.47 N 52 21 E 1144.72 N 50 49 E 1214.19 N 50 59 E 1284.04 0 73 0 58 0 36 0 31 0 77 1 O1 0 36 0 51 0 42 0 48 405 26 N 534 29 E 670 60 N 52 49 E 446 486 526 567 608 651 694 737 781 08 N 587 51N 64O 73 N 694 09 N 748 83 N 8O2 68 N 857 13 N 912 36 N 966 45 N 1020 10 E 737 47 E 804 36 E 871 62 E 939 95 E 1007 42 E 1076 22 E 1146 65 E 1215 84 E 1285 34 N 52 46 E 30 N 52 47 E 54 N 52 49 E 16 N 52 51E 67 N 52 50 E 97 N 52 46 E 29 N 52 44 E 78 N 52 4O E 61 N 52 34 E 3000 O0 2551 92 2445 92 44 54 3100 3200 3300 3400 35OO 3600 3700 3800 O0 2622 O0 2694 O0 2766 O0 2838 O0 2912 O0 2985 O0 3059 O0 3133 70 2516 24 2588 35 266O 87 2732 16 2806 69 2879 40 2953 35 3027 3900.00 3207.71 3101 70 44 50 24 44 4 35 43 41 87 43 10 16 42 45 69 42 36 40 42 29 35 42 6 71 41 47 N 51 17 E 1354 34 N 50 29 E 1424 N 48 25 E 1494 N 48 41E 1564 N 47 2O E 1632 N 46 0 E 1700 N 45 55 E 1768 N 45 57 E 1835 N 45 56 E 1903 N 45 51E 1969 96 82 09 91 83 46 88 06 76 0 4O 2 82 0 25 0 31 3 O3 0 17 0 26 0 31 0 35 0 O2 825 56 N 1075 60 E 1355 90 N 52 30 E 869 915 961 1007 1054 1101 1148 1195 1241 89 N 1130 62 N 1183 48 N 1235 19 N 1286 18 N 1336 26 N 1384 27 N 1433 09 N 1481 61N 1529 61E 1426 43 E 1496 35 E 1565 83 E 1634 04 E 1701 79 E 1769 34 E 1836 71E 1903 72 E 1970 53 N 52 26 E 28 N 52 16 E 42 N 52 6 E 13 N 51 57 E 85 N 51 44 E 30 N 51 30 E 57 N 51 18 E 60 N 51 7 E 19 N 50 56 E COMPUTATION DATE' 30-AUG-93 PAGE 2 ARCO ALASKA INC. i Y - 28 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 24-AUG-93 KELLY BUSHING ELEVATION' 106.00 FT ENGINEER' JACK RATHERT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEQ MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEO/IO0 FEET FEET FEET DEG MIN 4000 O0 3282 38 3176 38 41 34 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3357 O0 3433 O0 3508 O0 3584 O0 3659 O0 3735 O0 3810 O0 3886 O0 3962 48 3251 23 3327 78 3402 03 3478 68 3553 17 3629 54 3704 12 3780 48 41 3 23 40 33 78 41 17 03 41 3 68 40 45 17 41 10 54 41 1 12 40 48 07 3856.07 40 24 N 45 49 E 2036 12 N 45 56 E 2102 N 46 11E 2167 N 46 34 E 2232 N 46 33 E 2298 N 47 2 E 2363 N 48 52 E 2429 N 49 0 E 2494 N 49 16 E 2560 N 49 39 E 2625 O0 15 55 31 61 17 89 36 41 0 38 0 93 0 01 0 66 0 33 I 20 0.40 0.20 O. 50 O. 67 1287 96 N 1577,43 E 2036 45 N 50 46 E 1333 1379 27 N 1671 1424 5O N 1719 1469 73 N 1767 1514 61N 1814 1558 38 n 1863 1601 54 N 1913 1644.41N 1962 1686.72 N 2011 95 N 1624 81E 2102 81E 2167 20 E 2232 07 E 2298 64 E 2363 48 E 2429 O4 E 2494 54 E 2560 95 E 2625 25 N 50 37 E 33 N 50 29 E 68 N 50 21E 40 N 50 15 E 68 N 50 9 E 22 N 50 6 E 93 N 50 4 E 4O N 5O 2 E 45 N 50 2 E 5000 O0 4038 47 3932.47 39 56 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4115 O0 4192 O0 4270 O0 4347 O0 4424 O0 4502 O0 4579 O0 4654 00 4729 42 4009.42 39 29 83 4086.83 39 9 05 4164.05 39 41 04 4241.04 39 34 57 4318.57 38 59 36 4396.36 39 0 16 4473.16 41 7 18 4548.18 41 24 20 4623.20 41 21 N 50 9 E 2689 93 N 50 39 E 2753 80 N 50 55 E 2817 09 N 50 7 E 2880 62 N 50 9 E 2944 43 N 50 40 E 3007 59 N 50 14 E 3070 42 N 49 54 E 3134.46 N 49 47 E 3200.57 N 49 38 E 3266.70 0 19 0 28 0 43 0 74 1 05 1 29 0 52 1 80 0 22 0 69 1728.27 N 2061 31 E 2689 97 N 50 1 E 1768 99 N 2110 1809 1849 1890 1930 1970 2011 2054 2097 O1N 2159 43 N 2208 36 N 2257 55 N 2306 68 N 2354 81N 2403 46 N 2454 27 N 2504 51E 2753 56 E 2817 58 E 2880 55 E 2944 27 E 3007 61E 3070 70 E 3134 22 E 3200 62 E 3266 83 N 5O 2 E 13 N 5O 3 E 66 N 5O 3 E 48 N 50 4 E 64 N 50 4 E 47 N 5O 4 E 51 N 50 4 E 62 N 50 4 E 75 N 50 4 E 6000 O0 4804 38 4698 38 41 14 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 4879 O0 4954 O0 5027 O0 5101 O0 5175 O0 5250 O0 5324 O0 5398 00. 5473 53 4773 15 4848 84 4921 68 4995 89 5069 34 5144 61 5218 95 5292 49 5367 53 41 19 15 42 22 84 42 33 68 42 15 89 41 53 34 41 57 61 42 5 95 41 53 49 41 46 N 49 34 E 3332 63 N 49 33 E 3398 N 48 42 E 3465 N 48 20 E 3532 N 48 25 E 3600 N 48 12 E 3667 N 48 5 E 3733 N 47 59 E 3800 N 48 I E 3867 N 48 0 E 3934 6O 17 75 18 18 92 85 7O 34 0 16 0 38 1 53 0 35 0 45 0 38 0 17 0 23 0 21 0 26 2139 99 N 2554 84 E 3332 68 N 50 3 E 2182 2226 2271 2315 2360 2405 2449 2494 2539 78 N 2605 21N 2655 09 N 2706 91N 2756 48 N 2806 04 N 2856 82 N 2906 59 N 2955 19 N 3005 05 E 3398 50 E 3465 O6 e 3532 46 E 3600 51E 3667 23 E 3733 O1E 3800 70 E 3867 26 E 3934 65 N 5O 2 E 22 N 5O 2 E 79 N 5O 0 E 21 N 49 58 E 2O N 49 56 E 93 N 49 54 E 86 N 49 52 E 71 N 49 5O E 34 N 49 48 E 7000 O0 5548.05 5442 05 41 48 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 5622.56 5516 O0 5697.12 5591 O0 5771.23 5665 O0 5844.34 5738 O0 5918.37 5812 O0 5993.62 5887 O0 6069.76 5963 O0 6145.92 6039 O0 6222.04 6116 56 41 50 12 41 43 23 42 56 34 42 49 37 41 38 62 40 42 76 40 21 92 40 33 04 40 15 N 47 57 E 4000.94 N 47 53 E 4067.60 N 47 41 E 4134.21 N 46 10 E 4201 28 N 45 59 E 4269 34 N 49 50 E 4336 50 N 54 15 E 4402 30 N 57 2 E 4466 72 N 56 16 E 4531 04 N 56 39 E 4595 47 0 16 0 08 0 24 2 20 1 44 2 55 3 58 0 85 0 71 0 78 2583 80 N 3054 75 E 4000 94 N 49 46 E 2628 48 N 3104 2673 24 N 3153 2718 89 N 3202 2766 47 N 3251 2811 59 N 3301 2852 21N 3353 2888 38 N 3407 2923.95 N 3461 2959.90 N 3515 27 E 4067 65 E 4134 87 E 4201 77 E 4269 57 E 4336 39 E 4402 18 E 4466 35 E 4531 32 E 4595 60 N 49 45 E 21 N 49 43 E 28 N 49 4O E 35 N 49 37 E 52 N 49 35 E 31 N 49 37 E 72 N 49 43 E O5 N 49 49 E 49 N 49 54 E COMPUTATION DATE: 30-AUG-93 PAGE 3 ARCO ALASKA INC. 1Y - 28 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 24-AUG-93 KELLY BUSHING ELEVATION: 106.00 FT ENGINEER: JACK RATHERT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPAR-rURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DE~ MIN FEET DEG/IO0 FEET FEET FEET DEG ~IN 8000.00 6298.75 6192.75 39 38 N 57 45 E 4659.07 8100.00 6376.18 6270.18 38 47 N 58 45 E 4721.68 8200.00 6454.32 6348.32 38 34 N 59 40 E 4783.38 8285.00 6520.77 6414.77 38 34 N 59 40 E 4835.58 0.64 2994.62 N 3569.27 E 4659.12 N 50 0 E 1.86 3028.05 N 3623.00 E 4721.78 N 50 7 E 0.00 3059.92 N 3676.86 E 4783.55 N 50 14 E 0.00 3086.68 N 3722.60 E 4835.84 N 50 20 E COMPUTATION DATE: 30-AUG-93 PAGE 4 ARCO A~SKA INC. I Y - 28 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 24-AUG-g3 KELLY BUSHING ELEVATION: 106.00 ET ENGINEER: JACK RATHERT INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 8285 0 O0 -106 O0 O0 979 O0 1823 O0 2551 O0 3282 O0 4038 O0 4804 O0 5548 O0 6298 O0 6520 0 0 92 873 96 1717 92 2445 38 3176 47 3932 38 4698 05 5442 75 6192 77 6414 92 20 23 96 41 39 92 44 54 38 41 34 47 39 56 38 41 14 05 41 48 75 39 38 77 38 34 N 0 0 E N 54 6 E 151 N 52 5 E 669 N 51 17 E 1354 N 45 49 E 2O36 N 50 9 E 2689 N 49 34 E 3332 N 47 57 E 4000 N 57 45 E 4659 N 59 4O E 4835 0 O0 18 63 34 12 93 63 94 O7 58 0 O0 I 89 0 73 0 40 0 38 0 19 0 16 0 16 0 64 0 O0 0 O0 N 88 4O5 825 1287 1728 2139 2583 2994 3086 10 N 123 26 N 534 56 N 1075 96 N 1577 27 N 2061 99 N 2554 80 N 3054 62 N 3569 68 N 3722 51E 151 29 E 670 60 E 1355 43 E 2036 31E 2689 84 E 3332 75 E 4000 27 E 4659 60 E 4835 0 O0 E 0 O0 N 0 0 E 71 N 54 3O E 6O N 52 49 E 90 N 5230 E 45 N 5O 46 E 97 N 50 I E 68 N 50 3 E 94 N 49 46 E 12 N 50 0 E 84 N 5O 2O E COMPUTATION DATE' 30-AUG-93 PAGE 5 ARCO ALASKA INC. I Y - 28 KUPARUK RIVER NORTH SLOPE, ALASKA DATE Of SURVEY' 24-AUG-93 KELLY BUSHING ELEVATION' 106.00 FT ENGINEER' JACK RATHERT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMLFFH FEET DEG/IO0 FEET FEET FEET DEG 0 O0 106 O0 206 O0 306 02 406 16 506 78 608 38 711 50 815 97 921.46 0 O0 -106.00 106 O0 206 O0 306 O0 406 O0 506 O0 606 O0 7O6 O0 806 O0 906 O0 0 0 N 0 0 E 0.00 0 24 N 29 53 E 100.00 0 27 N 35 29 E 200.00 I 29 N 56 28 E 300.00 4 43 N 55 44 E 400.00 8 7 N 53 51 E 500.00 12 14 N 55 0 E 600,00 15 44 N 54 32 E 700,00 17 47 N 54 54 E 800,00 19 15 N 54 36 E 0.00 0.21 0.88 2.37 7.46 18.41 36.18 61.18 91.30 124.73 0 O0 0 O0 0 19 1 79 3 87 4 26 3 69 2 61 1 56 1 13 0 O0 N 0 19 N 0 80 N 1 79 N 4 57 N 10 94 N 21 37 N 35 84 N 53 29 N 72 0 O0 E 0 0 1 5 14 29 49 74 63 N 101 0.00 N 0 0 E 11 E 0.22 N 30 8 E 48 e 0.93 N 31 4 E 59 E 2.39 N 41 36 E 91 E 7.47 N 52 16 E 86 E 18.45 N 53 39 E 32 E 36.28 N 53 55 E 82 E 61.38 N 54 16 E 51 E 91.61 N 54 26 E 94 E 125.17 N 54 32 E 1027 88 1006 O0 1135 1244 1354 1467 1584 1709 1842 1975 2110 64 1106 26 1206 52 1306 69 1406 97 1506 76 1606 29 1706 99 1806 20 1906 O0 1000 O0 1100 O0 1200 O0 1300 O0 1400 O0 1500 O0 1600 O0 1700 O0 1800 900 O0 20 56 O0 22 37 O0 23 31 O0 26 36 O0 29 6 O0 33 59 O0 39 25 O0 41 46 O0 41 32 O0 41 59 N 54 1E N 54 31E N 54 52 E n 54 2 E N 52 58 E N 51 19 E N 50 41E N 5O 50 E N 51 55 E N 52 37 E 161 O0 201 03 243 28 289 51 342 36 403 51 478 05 564 99 653 71 743 12 2 12 0 73 1 53 3 38 3 35 4 83 3 87 0 42 0 63 0 51 93 88 N 131.48 E 161 55 N 54 28 E 117 141 168 200 237 284 340 395 450 37 N 164.03 E 201 87 N 198.65 E 244 75 N 236.47 E 290 28 N 279 03 E 343 88 N 327 31 E 404 96 N 385 12 E 479 O1 N 452 43 E 565 45 N 521 74 E 654 22 N 592 52 E 744 7O N 54 25 E 11 N 54 28 E 5O N 54 29 E 47 N 54 20 E 62 N 53 59 E 08 N 53 30 E 95 N 53 4 E 67 N 52 5O E 17 N 52 46 E 2244.94 2006 O0 1900 O0 42 14 2380.44 2106 2517.71 2206 2656 44 2306 2795 45 2406 2935 34 2506 3076 43 2606 3216 35 2706 3354 78 '2806 3491 61 2906 O0 2000 O0 42 39 O0 2100 O0 43 52 O0 2200 O0 43 53 O0 2300 O0 44 8 O0 2400 O0 44 37 O0 2500 O0 45 1 O0 2600.00 43 59 O0 2700.00 43 35 03 2800.00 42 46 N 53 17 E N 53 19 E 924 N 51 41E 1018 n 52 18 E 1114 N 50 51E 1211 N 51 7 E 1308 N 51 7 E 1408 N 48 27 E 1506 N 48 41E 1601 N 46 0 E 1695 833 29 54 46 54 O3 83 33 18 87 15 0 47 0 50 0 71 0 36 0 53 0 44 0 74 0 46 0 65 0 24 504 59 N 664 63 E 834 47 N 52 48 E 559 616 675 735 797 859 923 986 1050 17 N 737 44 N 812 67 N 888 36 N 964 04 N 1040 35 N 1117 16 N 1191 42 N 1263 22 N 1331 99 E 925 57 E 1019 30 E 1116 19 E 1212 12 E 1310 73 E 1409 93 E 1507 75 E 1603 95 E 1696 90 N 52 51E 93 N 52 49 E 07 N 52 45 E 61 N 52 40 E 39 N 52 32 E 9O N 52 27 E 62 N 52 15 E 15 N 52 2 E 19 N 51 45 E 3627.58 ~ 3006 O0 2900.00 42 32 3763 09 3106 O0 3000 O0 42 16 3897 4031 4164 4296 4429 4561 4693 4826 70 3206 O0 3100 53 3306 O0 3200 13 .3406 O0 3300 30 3506 O0 3400 10 3606 O0 3500 28 3706.00 3600 99 3806.00 3700 23 3906.00 3800 O0 41 48 O0 41 25 O0 40 40 O0 41 17 O0 40 55 O0 41 5 O0 41 2 O0 40 41 N 45 54 E 1787 07 N 45 55 E 1878 N 45 52 E 1968 N 45 51E 2056 N 46 4 E 2143 N 46 33 E 2230 N 46 34 E 2317 N 48 30 E 2403 N 48 59 E 2490 N 49 2O E 2577 33 23 96 85 11 36 71 94 48 0.21 O. 52 0.07 O. 57 0.61 O. 73 0.60 1 . 22 0.15 O. 65 1114 24 N 1398 19 E 1787 87 N 51 27 E 1177 1240 1302 1363 1422 1482 1541 1598 85 N 1463 54 N 1528 52 N 1592 08 N 1654 83 N 1717 86 N 1780 56 N 1844 95 N 1910 90 E 1878 62 E 1968 41E 2057 98 E 2144 42 E 2230 92 E 2317 35 E 2403 07 E 2490 1655.57 N 1975.52 E 2577 92 N 51 11E 66 N 50 56 E 26 N 50 43 E 05 N 50 31E 24 N 50 22 E 45 N 50 13 E 76 N 50 7 E 99 N 50 4 E 52 N 50 2 E COMPUTATION DATE' 30-AUG-93 PAGE 6 ARCO ALASKA INC. 1Y - 28 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 24-AUG-g3 KELLY BUSHING ELEVATION: 106.00 FT ENGINEER: JACK RATHERT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4957 58 4006.00 3900 O0 40 9 5087 5216 5346 5476 5604 5735 5869 6002 6135 80 4106.00 4000 99 4206.00 4100 70 4306.00 4200 10 4406.00 4300 68 4506.00 4400 75 4606.00 4500 07 4706.00 4600 15 4806.00 4700 28 4906.00 4800 O0 39 31 O0 39 13 O0 39 39 O0 39 6 O0 39 1 O0 41 27 O0 41 27 O0 41 14 O0 41 3O N 49 58 E 2662 64 N 50 37 E 2746 N 5O 5O E 2827 N 50 6 E 2910 N 50 43 E 2992 N 50 12 E 3073 N 49 49 E 3158 N 49 36 E 3246 N 49 34 E 3334 N 49 30 E 3421 O3 81 42 54 36 O6 24 05 94 0 67 0 36 I O0 0 34 0 32 0 61 0 35 0 29 0 18 0 72 1710 75 N 2040.39 E 2662.67 N 50 1 E 1764 1815 1868 1921 1972 2027 2084 2140 2197 07 N 2104.51 E 2746.07 N 50 2 E 77 N 2167.88 E 2827.85 N 50 3 E 54 N 2231.45 E 2910.47 N 50 3 E O1 N 2294 62 E 2992 59 N 50 4 E 57 N 2356 87 E 3073 41 N 50 4 E 03 N 2421 75 E 3158 12 N 50 4 E O1N 2489 04 E 3246 29 N 50 4 E 91 N 2555 92 E 3334 10 N 50 3 E 92 N 2622 80 E 3421 98 N 50 2 E 6270 35 5006 O0 4900 O0 42 34 6405 6540 6674 6809 6943 7077 7211 7347 84 5106 43 5206 92 5306 47 5406 59 5506 77 5606 90 5706 60 5806 7483.44 5906 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 42 14 O0 41 51 O0 42 5 O0 41 52 O0 41 46 O0 41 51 O0 41 44 O0 43 8 O0 41 46 N 48 19 E 3512 7O N 48 25 E 36O4 N 48 8 E 3694 N 48 0 E 3784 N 48 1E 3874 N 47 58 E 3963 N 47 55 E 4052 N 47 40 E 4142 N 45 37 E 4233 N 49 13 E 4325 11 15 O5 02 37 78 13 71 49 0 2i 0 47 0 i7 0 22 0 24 0 i9 0 07 0 43 0 74 2 72 2257 75 N 2691 08 E 3512 74 N 50 0 E 2318 2378 2438 2498 2558 2618 2678 2741 51N 2759 47 N 2826 57 N 2893 82 N 2960 62 N 3026 54 N 3093 58 N 3159 54 N 3226 2804.46 N 3293 40 E 3604 62 E 3694 52 E 3784 40 E 3874 83 E 3963 26 E 4052 50 E 4142 20 E 4233 17 E 4325 13 N 49 58 E 17 N 49 55 E 06 N 49 53 E 03 N 49 50 E 37 N 49 48 E 78 N 49 45 E 13 N 49 43 E 72 N 49 39 E 51 N 49 35 E 7616 31 6006.00 5900.00 40 32 7747 55 6106.00 6000.00 40 20 7878 97 6206.00 6100.00 40 21 8009 41 6306.00 6200.00 39 35 8138 20 6406.00 6300.00 38 34 8266 11 6506.00 6400.00 38 34 8285 O0 6520.77 6414.77 38 34 N 55 4 E 4412 88 N 56 48 E 4497 26 N 56 28 E 4581 96 N 57 48 E 4665 O1 N 59 40 E 4745 42 N 59 40 E 4823 98 N 59 40 E 4835 58 3 20 0 9O 0 63 0 65 0 O0 0 O0 0 O0 2858 36 N 3362.05 E 4412.89 N 49 38 E 2905 18 N 3432.97 E 4497,26 N 49 46 E 2952 40 N 3503.97 E 4581.97 N 49 53 E 2997 81 N 3574.34 E 4665.06 N SO 1 E 3040 45 N 3643.60 E 4745.54 N 50 9 E 3080 74 N 3712.43 E 4824.22 N 50 19 E 3086 68 N 3722.60 E 4835.84 N 50 20 E COMPUTATION DATE: 30-AUG-93 PAGE 7 ARCO ALASKA INC. 1Y - 28 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C GCT LAST READING PBTD 7" CASING DATE Of SURVEY: 24-AUG-93 KELLY BUSHING ELEVATION: 106.00 FT ENGINEER: JACK RATHERT INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 211' FNL, 1944 FWL, SECO1 Tll R09 E MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOLFFH EAST/WEST 5507 O0 7764 O0 8130 O0 8182 O0 8267 O0 8285 O0 4430.01 6118.54 6399.60 6440.24 6506.70 6520.77 4324 O1 6012 54 6293 60 6334 24 6400 70 6414 77 1933 34 N 2911 03 N 3037 69 N 3054 25 N 3081 02 N 3086 68 N 2309 67 E 3441 88 E 3639 08 E 3667 17 E 3712 91E 3722 60 E ARCO ALASKA INC. 1Y - 28 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER TOP KUPARUK C PBTD TD COMPUTATION DATE: 30-AUG-93 PAGE 8 DATE OF SURVEY: 24-AUG-93 KELLY BUSHINg ELEVATION: 106.00 FT ENGINEER: JACK RATHERT ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 211' FNL, 1944' FWL, SEC01 Tll R09 E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 7764.00 6118.54 6012.54, 2911.03 N 3441.88 E 8182.00 6440.24 6334.24 3054.25 N 3667.17 E 8285.00 6520.77 6414.77 3086.68 N 3722.60 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 8285.00 6520.77 6414.77 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 4835.84 N 50 20 E DIRECTIONAL SURVEY COMPANY ARCO ALASKA INC. FIELD KUPARUK RIVER WELL I Y - 28 COUNTRY USA RUN I DATE LOGGED 24 - AUG - 93 DEPTH UNIT FEET REFERENCE 93395 AJI Interpretations are opinions based on Inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or ccrrectness of any Interpretations. and we shall not. except In tl~ ca~e of gross or wllfull negligence on our part. be liable or responsible for any loss. costs, damages or expenses incurred or sustained by anyone resulting from any interpretation made by any of our officem, agents or employees. These interpretations are also subject to our General Terms and Conditions as set out In our current price bELL: 1Y-28 · (211' FNL, 1944' FI,IL, SEC 1, T11N, RgE, UI~) HORIZONTAL PROgECTION NORTH 6000 RBF 9339,5 SCALE = I / 1000 IN/FT 5000 4O0O 3000 2000 IOO0 SOUTH -2000 -2000 -1000 0 1000 ......................................... ........ :::' ......................................... · -i''i'i!J"'i'"i--'i'-'i ...... ?-'?'!--~ ..... ?"?!! ...... !-!"-!--?-:'-!--?'!---! ...... !'~--!--! ..... !'-~"~ !-'-!---!-**!--'~---!'--~--? .... ?'!'-~-'! .... i.;...[...i .... ~ ...... !..~ ~.!~ :::: :::: :~:: :::: :::::::: :::: :::: ~:::~:::: :::: :::: :::: :::. !~:!' ~!!'! !*!'!i' !''~!!' !*'!!'! "!'!'["!i!!"!! '!"~!"!' !-7!! ..... !'!'!"!"I"!"!'F'!'"~'!"F'!*''i'i'!! :!!! ..!!!i .~!.!.X ..... 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F~--~--~ .... ~--~ ~-~-~'.~.--~-~'.~'~ ...... ..i.~.~_~ ...... ?.-?.?~ ...... ?..¢...?:.?}..~ .... ??.-.?.~ ..... ?~-..? .... ~}..?..~ .... :..?:~.~ .... ~..~..~..~ ..... ?}...~.} ........ }~.~ ...... ~ ?: ...... ~...:.~ .... ~.~ ...: .... .::::.::.:_.; .... :_.:...:_: .... :::.:.. ::..::. ::.:..: ::::::::::::::::::::::::::::::::::::: ..... ;. .:.: ..:. :. ~:i ~: !~i~!~:~ ::~ ~:~ ~i~ii~ ::~ i~: ::~: ;~: .,:. .;.: . ~-~.-~?.-~--~---?h-?-~. ~-~--~--!~-~-~ .... ~..~..~ .... ~..?.~.~..~.D.~..~.~.~,.~ ~.~...~.~-'..~.~..! :~:~ ~;,: .;~: -~-~--( -~-f~--'~ ...... ~ ~ ~ ~..i ~ ~-.~-~ .... ~..~...f ~ ...~.~ ~..~ .~.~.(-.~ ..~-.~ ~ ~ ~--~.~ ~ ~ ~ ~.~ ..~ ~.~ ~ i.~ ~ ~...~ ~.! ~.~. ~ ~ ~..~. ~.,~ ~ ~ : : ~ ~ : ; . · .... 50.00 PROJECTION ON VERTICAL PLANE 230.00 $0.00 ~CALED IN VERTICAL DEPTHS I-K~RIZ E~CALE = 1 / 1000 IN/FT ARCO Alaska, Inc. qb-7 Date: October 22, 1993 'Transmittal #: 8904 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO- 1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1Y-27a: 5~:g LIS Tape and Listing: 9-13-93 93327 o ~--~-v~'W CD R/CD N/RAB Data 1Yr18~Sr:~ LIS Tape and Listing: 9-13-93. 93362 c~-'CDR/CDN, 1 Bit Run with QRO Processing 1Y-28A:~o LIS Tape and Listing: 9-14-93 93391 ow-CDR/CDN, 1 Bit Run with QRO Processing 1Y-21-+~51 LIS Tape and Listing: 9-08-93 93347 ~--CDR/CDN/RAB in 1 Bit Run and QRO Processing 1Y-19~5~z LIS Tape and Listing: 9-13-93 93380 o~ CDR/CDN, 1 Bit Run with QRO Processing 1Y-34~--~-~5 LIS Tape and Listing: 9-24-93 93296 ~- CDR/CDN, 2 Bit Runs, QR0 Processed ~, ~-r~ 1Y-24~sss~( LIS Tape and Listing: 8-24-93 93319 c.~ - 3 Passes TDTP, LDWG Format 75~S ---- ~_-'z_, 1Y-31-~5~5~' LIS Tape and Usting: 9-13-93 93362 -~- CDR in 1 Bit Run, QRO Processed u ~5o- 1Y-31-~.5~ LIS Tape and Usting: 10-08-93-93 93430 C_.~ 3 Passes, Averaged and Reprocessed HLDT Receipt Acknowledged: ..DISTRIBUTION: Bob Ocanas ARCO Alaska, Inc. Date: October 22, 1993 Transmittal #: 8903 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items, please acknowledge receipt and return one signed copy of this transmittal. I Y-27 c['5-'3'~' Y-27 Y-27 f Y-18 ~ ~ ~-~,o~ Y- 18 Y-18 IY-31 c~..qO Y-31 Y-31 IY-28 - Y-28 Y-28 IiY'21 0[-5 .-~o'L Y-21 Y-21 Y-19 Y-19 c1'5 "t °'~" Y-19 cl ~5-'77- ~1Y-24 Il Y-34 c~..q \ Y-34 ,/CDR Enhancement s' 8-23-93 LWD/Depth Corrected v'CDN LWD/Depth Corrected~.-~¢~"8-23-93 ,/CDR LWD/Depth Corrected a'rs"8-23-93 ¢-CDN LWD/Depth Corrected z,rs"9-08-93 cE;DR Enhancement s~ 9-08-93 LWD/Depth Corrected ¢'CDR LWD/Depth Corrected ~.~"9-08-93 -/CDR LWD/Depth Corrected ~,s" 8-26-28-93 ¢'CDR Enhancement 5" 8-26-28-93 LWD/Depth Corrected v~HLDT Corrected Casedhole ~" 10-08-93 Density ¢'CDR Enhancement .¢ 9-08-93 LWD/Depth Corrected ¢'CDR LWD/Depth Corrected .~-t~ 9-08-93 ¢CDN LWD/Depth Corrected ;~ 9-08-93 ¢CDR Enhancement : ~ 9-08-93 LWD/Depth Corrected ~'CDR LWD/Depth Corrected .~-~ 9-08-93 ¢'CDN LWD/Depth Corrected ~. s 9-08-93 ,/CDN LWD/Depth Corrected .2. t5 9-09-93 ~CDR LWD/Depth Corrected ='~ 9-09-93 ,/'CDR Enhancement .5' 9-09-93 LWD/Depth Corrected ¢q'DTP Depth Corrected ~ 8-24-93 /CDN LWD/Depth Corrected 2'¢:~ 7-2-5-93 · ~:~DR LWD/Depth Corrected zk-~ 7-2-5-93 8858-10012 8850-10018 8870-9990 8280-9180 8500-9150 8290-9160 6910-7830 7100-7700 7000-7700 7650-8250 7280-8250 7260-8250 6900-7450 6670-7640 6650-7590 6900-7610 6900-7660 7050-7500 7450-8220 6250-8640 6250-8640 c~5.q.\ 1Y-34 ,-//CDR Enhanced LWD/Depth' Corrected ~' 7-2-5-93 7200-8600 Receipt Acknowledged' DISTRIBUTION: D&M Date' Drilling Catherine Worley(Geology) NSK State of Alaska (+Sepia) Bob Ocanas ARCO Alaska, Inc. Date: september 10, 1993 Transmittal #' 8860 RETURN TO' ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1Y-18 6{'~"¢ 1Y-28 ~'~ Directional Survey ~ Directional Survey 8-17-93 93388 8-24-93 93395 Receipt Acknowledged' DISTRIBUTION: Date' D&M ':'_S.t~t.e.. of 'Alaska.(2 copies) ARCO Alaska, Inc. Date: September 3, 1993 Transmittal #: 8857 RETURN TO: ARCO Alaska, Inc. AT'i'N: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the .following ~ased Ho[.e)items. receipt and return one signed copy of this tran§mittal. 1Y-28 Cement Bond Tool CBT 8-24-93 1Y-28 Cement Evaluation Tool ~E:i' 8-24-93 Receipt ~~ ~ Date Acknowledge' · Drilling staie~"°f Alaska(+~epia) Please acknowledge 6700-81 50 6700-8172 NSK , IEMORANDUM TO: David John~~ Chairman' THRU: Blair Wondzell P.I. Supervisor FROM: Bobby Fosl~e"~~ Petroleum Inspector TUESDAY, AUGUST 17, 199,3 STATE ALASKA ALASKA OIL AND GAS CONSER VA TION COMMISSION DA TE: AUGUST 17 , 1993 FILE NO: AAXIHQAB .DOC PHONE NO.: 279-1433 SUBJECT: BOP TEST - PARKER 245 ARCO - CPF 1 - 1Y - 28 PTD # 93 - 89 KUPARUK RIVER FIELD I traveled this date to ARCO,s 1Y - 28 and witnessed the BOP test on Parker rig 245. As the attached AOGCC BOP Test Report shows there were no failures. SUMMARY: BOP test on Parker rig 245 - Test time 2 hours - No failures. ATTACHMENT: AAXIHQAB.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drig Contractor: Operator: Well Name: Casing Size: g 5/8 Test: Initial X Workover: DATE: 8/f 7/93 PARKER Rig No. 245 PTD # 93 - 89 Rig Ph.# 65g - 7670 ARCO Rep.: MIKE WHITEL Y ~ Y-28 Rig Rep.: DEARL GLADDEN Set @ 5,507 Location: Sec. 1 T. .1.N. R. g E Meridian Weekly Other Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Ouan. Pressure P/F Location Gen.' OK Well Sign OK Upper Kelly / IBOP 1 300 ~ 3000 I P Housekeeping: OK- (Gen) Drl. Rig OK Lower Kelly / IBOP ' I" 30013000 ~ P Reserve Pit 'NtA " Ball Type I 300 i 3000 ! i~ ' Inside BOP ' '1.; 300 ~ 3000' Test BOP STACK: Quan. Pressure P/F Test Annular Preventer 1 300 ! 3000 P CHOKE MANIFOLD: Pressure P/F Pipe Rams I 300 ~ 3000 P No. Valves 14. J 300 - 3000 P Pipe Rams 1" 300 ~ 3000 P No. Flanges 34 ..Ii300 t3000 P Blind Rams ' I 300 t 3000 P Manual Chokes 1 P Choke Ln. Valves f 300 t 3000 P Hydraulic Chokes I P HCR Valves 1 300 t 3000 P Kill Line Valves 2 300 ~ 3000 P ACCUMULATOR SYSTEM: Check Valve "N ~ A '" System Pressure 3,050 Pressure After Closure .. ,1,800 .... MUD SYSTEM: Visual Alarm 200 psi Attained After Closure .-_._ minutes 37' sec. Tdp Tank YES YES System Pressure Attained 2 minutes 37' sec. Pit Level Indicators '~'ES 'YES Blind Switch Covers: Master: ' YES Remote: YES _ Flow Indicator YES YES Nitgn. Btl's: 6 @ 2400 Gas Detectors YES ' YES" ' "~ Psig. . ~ Number of Failures: 0 ,Test T~rne: 2.0 Hours. Number of valves tested 2~ Repair or Replacement of Failed Equipment will be made within O da~/s. Notify the Inspector and follow with Wri~en or Faxed verification to the AOGCC Commission Office at: Fax N 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 if your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279.1433 I. I II II I . I J . I . .I I I I I I I I I I I IlJlll II I I I[ I I IIII REMARKS: GOOD TEST Distribution: orig-Well File c- Oper./Rig c - Database c - Trip Rpt File c - Inspector ' ~A'TI~ WITNESS R~QUI'RED~ I YES X NO 24 HOUR NOTICE GIVEN YES X NO II I I I I I I I I I III Waived By: Witnessed By: FI-O21L (Rev. 7/1g) AAXIHQAB.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Ddg: x Workover: Drlg Contractor: PN=,KF_R Operator: ARCO ALASKA, INC. Well Name: 1 Y-28 Casing Size: 9 5/8 Set ~ Test: Initial X Weekly DATE: 8/1 7/93 93-89 Rig Ph.# 659-7670 Rig No. 245 PTD # Rep.: Rig Rep.: D. GLADDEN 5507' Location: Sec. 1 T. 11N R. 9E Merd. U Other MISC. INSPECTIONS: FLOOR SAFETY VALVES: Location Gen.: X Well Sign X Upper Kelly/IBOP Housekeeping: X (Gen) Drl. Rig X Lower Kelly/IBOP Reserve Pit NA Ball Type Inside BOP BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure P/F I 300/3000 P 1 300/3000 P 1 300/3000 P 1 300/3000 P 1 3OO/3OOO P 1 300/3000 P 1 300/3000 P NA MUD SYSTEM: Visual Alarm Trip Tank X X Pit Level Indicators X X Flow Indicator X X Gas Detectors X X Test Quan. Pressure P/F 1 300/3000 P 1 300/3000 P 1 3OO/3OOO P 1 300/3000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 1 6 300/3000 P 38 3O0/3O00 P 2 FUNCTION P 1 FUNCTION P ACCUMULATOR SYSTEM: System Pressure 3,050 P Pressure After Closure 1,800 P 200 psi Attained After Closure minutes 31 System Pressure Attained 2 minutes 3 7 Blind Switch Covers: Master: X Remote: Nitgn. Btl's: 2400/2400/2400 2400/2400/2400 Psig. sec. sec, X Number of Failures 0 Test Time 2 Hours Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector Norl~ Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: GOOD TEST. H2S AND COMBUSTIBLE WERE TESTED 8/2/93 Distribution: orig-Well File c - Oper./Rig c- Database c- Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FI-021L (Rev. 2/93) PARKER 245 TESTS STATE OF ALASKA ALA~dr,,A OIL AND GAS CONSERVATION COMMIS,biON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown Re-enter suspended well Alter casing _ Repair well _ Plugging _ Tim~' extension _ Stimulate _ Change approved program X (SEE A'r-TACHED SUMMARY - ) Pull tubing _ Variance _ Perforate _ Other 5. Type of Well: 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 211' FNL, 1944' FWL, SEC. 1, T11N, R9E, UM At top of productive interval 2619' FSL, 6' FWL, SEC 31, T12N, R10E, UM At effective depth At total depth 2911' FSL, 351' FWL, SEC. 31, T12N, R10E, UM 12. Present well condition summary Total Depth: measured Development Exploratory Stratigraphic Service feet Plugs (measured) 6. Datum elevation (DF or KB) ~' RKB 106', Pad 65' feet 7. Unit or Property name Kuparuk River Unit 8. Well number KRU 1Y-28 9. Permit number 93-89 10. APl number 50-029-22380 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 80' Size 16" feet feet feet Junk (measured) Cemented 200 CF Measured depth True vertical depth 80' 80' measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Alaska. Oil & Gas Cons. 'Anchorage 13. Attachments Description summary of proposal __X Detailed operation program __ BOP sketch _ 14. Estimated date for commencing operation 8-12-93 15. 16. If proposal was verbally approved Name of approver Date approved Status of well classification as: Oil X Gas Service Suspended 17. I here~/ certify that the fo. regoing is true and correct to the best of my knowledge. Signed U~,,¢,~~.~~ ~--¢g ,~/,~',,'V/ Title FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require Original Signed By Approved by order of the Commission David W. Johnston Form 10-403 Rev 06/15/88 IAppro._~val.. No._ Approved 10- H 0'7 Returned _ Commissioner Date r~//f/ SUBMIT IN TRIPLICATE Kuparuk River Unit Well 1Y-28 Application For Sundry Approvals Description of Proposed Change to Plan Planned Spud Date of 8-12-93 KRU Well 1Y-28 was granted permit approval on 6-25-93 to set surface casing (9-5/8", 36 Ib/ft, J-55 BTC) to a depth of 4,506' MD (3,676' TVD). Since the permit approval, a change in surface casing setting depths on 1Y pad has occurred. It is now planned to set surface casing (9-5/8", 361b/ft, J-55 BTC) to a depth of 5,500' MD (4419' TVD) in well 1Y-28. This deeper setting depth has been approved by and is in accordance with Administrative Approval 190.15. Attached is a revised casing design spread sheet, general procedure, and fluid program which incorporates the new setting depth. Casing Design/Cement Calculations 11-Aug-93 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg A MD: Production Csg A TVD: Production Csg B MD: Production Csg B TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Mud Weight: Surface Casing Choice: Production Csg A Choice: Production Csg B Choice: Production Casing Frac. Pressure 1Y-28 5,5OO ft 4,419 ft 4,506 ft 3,676 ft 8,237 ft 6,467 ft 3,65O ft 7,557 ft 5,958 ft 10.7 ppg [~ !!i!!!!i!!!!!!!!! !! !!!!!i! !! !!!!! !!i!! ii !!i !1'* See Page 4 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 4,419 ft {(13.5'0.052)-0.11}*TVDshoe =1 2,616 psiJ Estimated BH pressure at top of target zone Anticipated Mud Weight = Top of Target Zone, TVD = 100 psi Overbalance = :l 10.7 ppg 5,958 ft 3,315 psi 3215 psiI Surface lead: Top West Sak, TMD = 3,650 ft Design lead bottom 500 ft above the Top of West Sak = 3,150 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 987 cf Excess factor = 15% Cement volume required = 1,135 cf Yield for Permafrost Cmt = 2.17 Cement volume required =1 520 sxJ Surface tail' TMD shoe = (surface TD - 500' above West Sak) * (Annulus area) = Length of cmt inside csg = Internal csg volume = Cmt required in casing = ~',~-) ~-~ ~.~ -- Excess factor = Cement volume required = A~J G ] ~ ,¢9~ Yield for Class G cmt = volume required Aiaska 0~ & Gas ,¢~n~. .- Anch0r~ge 5,500 ft 736 cf 8O ft 0.4340 cf/If 35 cf 771 cf 15% 886 cf 1.15 770 sxJ Casing Design/Cement Calculations 11-Aug-93 Production tail: TMD = 8,237 fi Top of Target, TMD = 7,557 fi Want TOC 500' above top of target = 7,057 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 206 cf Length of cmt wanted in csg = 80 fi Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 223 cf Excess factor = 15% Cement volume required = 257 cf Yield for Class G cmt = 1.23 Cement volume required =[ 210 sx] TENSION - Minimum Design Factors are: T(pb)=l.5 and T(js)=l.8 Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =1 564000 lb 5,500 fi 36.00 lb/fi 198000.0 lb 29296.4 lb 168703.6 lb Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =l 639000 lb 5,500 fi 36.00 Ib/ft 198000.0 lb 29296.4 lb 168703.6 lb 3.8] Production A (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =1 415000 lb 8,237 fi 26.00 lb/fi 214162.0 lb 34561.1 lb 179600.9 lb Production A (Joint Strength): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Length = Dead Wt in Air = Length * (Wt/ft) Casing Wt (lb/fi) = Buoyancy = Weight of displaced mud Dead Wt in Air = ,~ ~ ~ ~ ~: Buoyancy = .~.. ~ ~ ~ _ . ~..: ~ Tension (Joint Strength) = Design Factor =[ Ai~sk~ Oii& Gas Cons. to fi, nchof~ge 2 490000 lb 8,237 fi 26.00 lb/fi 214162.0 lb 34561.1 lb 179600.9 lb 2.7J Casing Design / Cement Calculations Production B (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =1 Production B (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 BURST-Minimum Design Factor Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = ;,la.s?,;.?, 0ii & Gas 0OHS. Production Csg A: Anchorage 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure - Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Design Factor =[ Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor Production Csg B: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =[ COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Production Csg A 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Production Csg B 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ 11-Aug-93 415000 lb 3,731 ft 26.00 Ib/ft 97006.0 lb 15654.7 lb 81351.3 lb 490000 lb 3,731 ft 26.OO Ib/ft 97OO6.O lb 15654.7 lb 81351.3 lb 6.01 3520 psi 2616.0 psi 1.3J 4980 psi 5545 psi 1701 psi 3844 psi 1.31 4980 psi 7098 psi 2993 psi 4105 psi 1.2J 2020 psi 0.556 Ib/ft 1523 psi 1.31 4320 psi '0.556 Ib/ft 2045 psi 2.11 4320 psi 0.556 Ib/ft 3598 psi 1.2J Casing Design / Cement Calculations 11-Aug-93 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb 2090 psi Burst 6870 psi 5750 psi 3520 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 5410 psi 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb 4320 psi Burst 7240 psi 4980 psi , , , 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1Y-28 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (5,500')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (8,237') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. I I V Created by : jones For: D STOLTZ Dote plotted : 13-May-93 Plot Reference is 28 Version #2. Coordinates are in feet reference slot #28. True Vertical Depths are reference wellhead. Baker Hughes INTEQ 0 250 _ 500_ 750 · 1000. _ 1250_ _ 1500_ 175O 2OO0 _ 2250 _ _ 2500_ _ 2750 _ 30O0 325O 5500 _ 5750_ 4000_ _ 4250 _ _ 4500_ 475O 5000 _ 5250 _ _ 5500_ _ 5750_ _ 6000_ _ 6250 _ _ 6500_ ARCO ALASKA, Inc. Structure : Pad 1Y Well : 28 Field : Kuparuk River Unlt Location : North Slope, Alaska East '--> 550 0 350 700 1050 1400 1750 2100 2450 2800 31,503500 ,38150 RKB ELEVATION: 106' 6.00 ] SEC 12.00 BUILO 3 DEG / 100' 18.00 24.00 X 30-00 '~ 36.00B/ PERMAFROST TVD=1406 TblD= 1480 DEP=553 / I TARGET LOCATION: TVD=1568 TMD=1687 DEP=482 / J 2619' FSL. 6' F'WL // TAROET ./ T~=5~58 /,"' TMD=7557 DEP=4379 T/ UGNU SNOS ' 'rVD=2656 TMD=3142 DEP=1448 T/ W SAK SNDS TVD=303B TMD=3650 DEP=1785 N 49.74 DEG taT0'(TO TARGET) B/ W SAK SNDS TVD=3476 TMD=4238 DEP=2176 3150 2800 :2450 - _2100 K-lO TVD=5936 TMD=4853 DEP=2584 AVERAGE ANGLE 41.6 DEG :..? i.,:i':' ;'. ; ',,:" ~ .~ ': K-5 TVD=5081 TMD=6384 DEP=360 'J'~'b- ..... KUP SNDS TYD=595§ TMD=?557 I)EP=4379 TARGET-T/ T/ ZONE C rv9=5978 T~D=7584 DEP=4397 B/ KUP SNDS TVD=6317 TMD=8037 DE,P~:~9_8~ 2., .............. 0 250 500 750 1000 1250 150{) 1 2 22 O 2500 27 3000 ,:3 35 .3 4000 4500 47 5000 Scale 1 : 125.00 Vertical Section on 49.74 azimuth wifh reference 0.00 N, 0.00 E from slot #28 DRILLING FLUID PROGRAM Well 1Y-28 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-9.6 15-25 15-35 45-75* 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.7 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 2,616 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1Y-28 is 1Y-04. As designed, the minimum distance between the two wells would be 20.2' @ 600' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 55-75 sec/qt to drill gravel beds. Adjust FV to 45-55 sec/qt below gravel beds. ALASKA OIL AND GAS CONSERVATION COMMISSION ' WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 June 24,1993 A W McBride, Area Drlg Engr ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 1Y-28 ARCO Alaska Inc 93-89 211'FNL, 1944'FWL, Sec 1, T11N, R9E, UM 291 I'FSL, 351'FWL, Sec 31, T12N, R10E, UM Dear Mr McBride: Enclosed is the approved application for permit to ddll the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOpE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be g!ven by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W John~ Chairman BY ORDER OF THE COMMISSION jo/enci c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMMISSIOi PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Drill X Reddll g] lb Type of Well Exploratory [~ Stratigraphic Test r'l Development Oil X Re-Entry E] Deepen [-'] Service r-~ Development Gas [~ Single Zone r"] Multiple Zone X 2.. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 106', Pad 65' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchora~]e, AK 99510-0360 ADL 25640, ALK 2571 4. Location of well at sudace 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 211' FNL,1944' FWL, Sec. 1, T11N, RDE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2619' FSL, 6' FWL, Sec. 31, T12N, R10E, UM 1Y-28 #U-630610 At total depth 9. Approximate spud date Amount 2911' FSL, 351' FWL, Sec. 31, T12N, R10E, UM 6/24/93 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1Y-04 8,237' MD 351' @ TD feet 20.2' @ 600' MD feet 2459 6,467' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 3 0 0' feet Maximum hole angle 41.6 o MaxJmurn surface 2,1 76 psig At total depth (TVD) 3,215 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Wei~lht Grade Coupling Len~lth MD TVD MD TVD /include stage datat 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" 36.0# J-55 BTC 4,465' 41' 41' 4,506' 3,676' 520 Sx Permafrost E & HF-ERW 460 Sx Class G 8.5" 7" 26.0# J-55 BTCMOD 4,465' 41' 41' 4,506' 3,676' HF-ERW 8.5" 7" 26.0# J-55 BTC 3,731' 4,506' 3,676' 8,237' 6,467' 210SxClassG HF-ERW Top 500' above Kuparuk 1 9. To be completed for Reddll, Re-entry, and Deepen Operations· Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~ .';-~' .... Conductor Surface Intermediate · . ~ :'-, ..~ ? Production !~ !:~;i ,~ '~ ..,..,:.;.~... Liner " · , ¢~ ,.~ ..... · Perforation depth: measured ~:.i,.., ~,ilj ,,~ ~?:~ !~,;'~JF, .~,gi~;i'~'~'i.!? true vertical ' - ..... · 20. Attachments Filing fee X Property plat ~] BOPSketch X Diverter Sketch X Ddlling program X Ddlling fluid program X Time vs depth plot [~ Refraction analysis [~ Seabed report [~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ///~/~/~ ~ Title Area Drilling] En~]ineer Date ~'/~.~ - ~/ "' Commission Use Onl~ Permit Number I APl number I Approval date I See cover letter for r~'~ -<~' '~ 50-<:3 ~. ,~- ~- :2_. ~ oOO other requirements Conditions of approval Samples required E] Yes ~;~ No Mud logrequired E] Yes J[~ No Hydrogen sulfidemeasures E] Yes ,~ No Directional survey required 'J~ Yes E] No Required working pressure for BOPE [] 2M .~ 3M E] 5M [] 10M [] 15M ~pproved Copy Other: Returned Original Signed By David V,,~. Johnston by order of Approved by Commissioner the commission Date~'// '~'~//7 Fnrm IF)-4CI1 I~l~.v 7-P4-R.q .q~lhrf~it in trinlinntc~ I I V '!Created by ' jones For: D STOLTZ !iDote plotted ' 15-May-9.3 ?lot Reference is 28 Version #2. !Coordinates ore in feet reference slot #28. ~,True Ve¢.icol Depths ore reference wellhead. I Baker i Hughes INTEQ 0 250 _ 500_ _ 750 _ _ - 125O_ _ 1750 .~ 20o02 -- 2250_ _ 2500_ - 2750_ _ 3C~0_ _ _ _ 3750 _ _ 4250_ _ 4.500_ _ 4750_ 50~XI_ _ 5250 _ . 551XL 5750. _ 6500_ I I I I 0 250 500 Scale 1 : 125.00 ARCO ALASKA, Inc. Structure : Pod 1Y Well : 28 Field : Kuparuk River Unit Location : North Slope, Alaska RKB ELEVATION: 106' Scale 1:17.5.00 E a st - - > 3500 550 700 1050 1400 1750 2100 24502800 I I I I I I I I I I I I I I I I [ I I I 3150 550O 5850 I I I I I TD LOCATION: ~ KOP TVD=300 TMD=300 DEP=O 2911' FSL, 55~' FWL ~ 6.00 SE6~ 12.00 BUILD 3DEG/ 100' 18.00 24.00 30.00 B/ PERMAFROST TVD=1406 TMD=1480 DEP=353 / J TARGET LOCATION: 36.00 ./' TVD=5958 /' TMD=7557 OEP=4379_ / NORTH 2830 EAST 3342 T/ UGNU SNDS SURFACE LOCATION: J TVD=2656 TMD=3142 DEP=1448 211' FNL, 1944' FWL J I SEC. 1, T11N, R9E J T/ W SAK SNDS TVD=3036 TMD=3650 DEP=1785 N 49.74 DEG 4379'(T0 TARGET) 8/ W SAK SNDS TVD=3476 TMD=4238 DEP=2176 9 5/8" CSG PT TVD=.3676 TMD=4506 DEP=2353 K-la TVD=3936 TMD=485.3 0EP=2584 AVERAGE ANGLE 41.6 DEG K-5 TVD=5081 TMD=6384 DEP=3601 TARGET - T/ I{UP SNDS TVD=5958 TMD=7557 DEP=4379 . T/ ZONE C TVD=5978 TMD=7584 DEP=4597%xNxx '~ Xx~ T/ ZONE A TVD=6198 TMD=7878 DEP=47_92. _~'~ ~ ~ B/ KUP SNDS 'rVD=6517 TMD=8037 DEP=4698~ TD - 7" CSG PT TVD=8467 TMD=8237 DEP=4831 Vertical Section on 49.74 azimuth with reference 0.00 N, 0.00 E from slot #28 2450 _ 350 o 0 .. ~,~ I I I 10100 I5/ I I I I I 20100 I I I I I I I I I I I I I I i I I I I I I I i I 750 12 0 1500 1750 2250 2500 2750 3000 3250 3500 3750 40'00 4250 4500 4750 5000 ARCO AI ASXA Inc Structure · Pad 1Y Field · Kuparuk River Unit Well · 27 / 28 Location · North Slope, Alaska Scale 1 : 20.00 E a s± -- > 1840 1880 1920 1960 2000 20~,02080 2120 2160 2200 2240 2280 2520 2360 2400 2440 2480 2520 2560 2600 2640 2680 720 IItlIIIIIIIB ~o $4o _ 560 _ - 3~0 _ 100 1300 900 700 3OO 1500 lO0 9160 120001 32O A 280 I 200 ~ 160 0 Z 120 80 2500 0 - _ 4O 300 120 { 300 16o 2oo - ~ 240_ ., ,..., _ ~ 280 _ o I18180 I I I 1840 1920 Scale 1 : 20.00 1700/ 1500 1700 5500 110¢ 100 ~900 i1~11 2040 2080 2120 2100 640 560 52O 1900 100 19o0 1700 3900 3700 300 i i i I i i / i i i 2160 2200 2240 2280 2320 East --> 2360 2400 2440 2480 2520 2560 2600 2640 ,~20 2~ A I 120 ~ ARCO ALASKA Structure · Pad 1Y Field · Kuparul< River Unit Well · 27 / 28 Location · North Slope, Alaska ~oo,~ ~: ~o.oo E a s f - - > 1520 1560 1600 1640 1680 1720 1760 1800 1840 18~0 1920 1960 20~0 2040 2080 2120 2160 220,02240 2280 2320 A I I 5100 560 _ 0 _ 400_ 280 240 2300 200 2100 1900 300 100 160 1500 4.0 8O 120 160 0 o. 2oo_ o ,. ~ 240 _ co 280 1500 1700 1900 430C 5900 2300 1300 1100 410~ 1500 ~500 1300 700 3700 300 9OO 700 r3oo 1500 3go0 370 lOO 1300 ;lOO :900 , ~ ,~ 1.500 2700 ~- , "" ~ '~'~ 150 _~300 ;' %' ' ' ' ' ;' ' ' ;' %' '~' ' ' '2' ' ' ' ' %' ' ......... ' ' ' 1 0 15 1600 164.0 16 1720 17 18 18 0 1880 19 0 1960 2000 20 2080 2120 2160 220,0 2240 2280 2320 Scole1 :20.00 E a st - - > 520 48O - 120 A I I Z 0 2~o 8 . . . 10 11 12 13 14 15 16. 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1Y-28 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,506')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (8,237') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. DRILLING FLUID PROGRAM Well 1Y-28 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-9.6 15-25 15-35 45-75* 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.7 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,176 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1Y-28 is 1Y-04. As designed, the minimum distance between the two wells would be 20.2' @ 600' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 55-75 sec/qt to drill gravel beds. Adjust FV to 45-55 sec/qt below gravel beds. ,, Casing Design / Cement Calculations 26-May-93 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg A MD: Production Csg A TVD: Production Csg B MD: Production Csg B TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Mud Weight: Surface Casing Choice: Production Csg A Choice: Production Csg B Choice: Production Casing Frac. Pressure 1Y-28 4,506 ft 3,676 ft 4,506 ft 3,676 ft 8,237 ft 6,467 ft 3,650 ft 7,557 ft 5,958 ft 10.7 ppg I~iiiiiiiiiiiiiiiiiiiiiiii ii iii i i !** See Page 4 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 3,676 ft {(13.5'0.052)-0.11}*TVDshoe =1 2,176 psiI Estimated BH pressure at top of target zone Anticipated Mud Weight = Top of Target Zone, TVD = 100 psi Overbalance = :1 10.7 ppg 5,958 ft 3,315 psi 3215 psiI Surface lead: Top West Sak, TMD = 3,650 ft Design lead bottom 500 ft above the Top of West Sak = 3,150 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 987 cf Excess factor = 15% Cement volume required = 1,135 cf Yield for Permafrost Cmt = 2.17 Cement volume required =[ 520 sxJ Surface tail: TMD shoe = 4,506 ft (surface TD - 500' above West Sak) * (Annulus area) = 425 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4340 cf/If Cmt required in casing = 35 cf Total cmt = 459 cf Excess factor = 15% Cement volume required = 528 cf Yield for Class G cmt = 1.15 Cement volU~":ir(~qui~ed...=l'~:-~ 460 sx Casing Design/Cement Calculations 26-May-93 Production tail: TMD = 8,237 fi Top of Target, TMD = 7,557 fi Want TOC 500' above top of target = 7,057 fi Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 206 cf Length of cmt wanted in csg = 80 fi Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 223 cf Excess factor = 15% Cement volume required = 257 cf Yield for Class (3 cmt = 1.23 Cement volume required =1 210 sxJ TENSION - Minimum Desitin Factors are: T(pb)=1.5 and Tl'_is)=1.8 Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/fi) Buoyancy = Weight of displaced mud Length Casing Wt (lb/fi) Dead Wt in Air Buoyancy = Tension (Pipe Body) Design Factor 56400O lb 4,506 fi 36.00 lb/fi 162216.0 lb 24001.8 lb 138214.2 lb 4.1] Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =l 639000 lb 4,506 fi 36.00 lb/fi 162216.0 lb 24001.8 lb 138214.2 lb 4.61 Production A (Pipe Body): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ 415000 lb 8,237 fi 26.00 lb/fi 214162.0 lb 34561.1 lb 179600.9 lb 2 Production A (Joint Strength): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 49OO0O lb 8,237 ft 26.00 lb/fi 214162.0 lb 34561.1 lb 179600.9 lb 2.71 Casing Design / Cement Calculations Production B (Pipe Body): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =[ Production B (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/fi) Buoyancy = Weight of displaced mud BURST- Minimum Design Factor Surface Casing: Burst = Maximum surface pressure Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 Casing Rated For: Max Shut-in Pres = .... · "' ..... ?,~;'-"-'~ :~'~ Design Factor Production Csg A: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =[ Production Csg B: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =1 COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2, Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ Production Csg A 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =~ Production Csg B 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 26-May-93 415000 lb 3,731 fi 26.00 lb/fi 97006.0 lb 15654.7 lb 81351.3 lb 490000 lb 3,731 fi 26.00 lb/fi 97006.0 lb 15654.7 lb 81351.3 lb 3520 psi 2176.2 psi 1 .Si 4980 psi 5545 psi 1701 psi 3844 psi 1.3J 4980 psi 7098 psi 2993 psi 4105 psi 1.21 2020 psi 0.556 lb/fi 1109 psi 1 .si 4320 psi 0.556 lb/fi 2045 psi 2.1J 4320 psi O.556 lb/fi 3598 psi 1.21 Casing Design / Cement Calculations 26-May-93 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse Burst I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 6870 psi 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 5750 psi 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 3520 psi 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb 2090 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 5410 psi 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb 4320 psi Burst 7240 psi 4980 psi KJPARUK RIVER UNIT 21-1/4" DIVERTER SCHEMATIC I 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER ~'~ EDF 3/10~J2 7 13 5/8" 5000 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY 8. CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST Boq-rOM 9. RAMS TO 250 PSI AND 3000 PSI. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10 CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD 11. AND 12. LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE 13. DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16"-2000 PSI STARTING HEAD 2- 11" - 3000 PSI CASING HEAD 3. 11"- 3(:x:x) PSI X 13-5/8" -5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8"-5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 State: Alaska Borough: Well: 1Y-28 Field: Kuparuk River St. Perm # 93-89 1Y-28.×LS Date 6/10/93 Engr: M. Minder Casing Interval Interval Size Bottom Top Length IA 9.625 9676 41 4465 2_A 7 6467 41 8196 3A 0 0 0 0 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Description Description Description Tension Lbs Grade Thread Lbs 36 J-55 BTC 0 26 J-55 TC MOD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 lb 219 3B 4B 5B 6B 7B 8B 9B 10B Mud Hydraulic Collapse Weight Gradient Gradient ppg psi/ft psi/ft 9.6 0.499 0.399 10.7 0.556 0.456 0.0 0.000 -0.100 0.0 0.000 -0.100 0,0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 Maximum Minimum Pressure Yield psi psi BDF 2176 3520 1.6 2176 4980 0 0 #1)iVl0! 0 0 #DIM/O! 0 0 #1)lV/O~ 0 0 #1)IV/O! 0 0 #DIVI0~ 0 0 #DIV/O! 0 0 #DIV/O! 0 0 # DIV/O.I Tension Strength K/Lbs 1 C 160.74 2C 213.096 3C 0 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 K/Lbs TDF 564 3.,51 415 1.95 0 #DlV/0.1 0 #DIV/0! 0 #DIV/0! 0 #DIV/O! o #DIV/O! 0 #DIV/0! 0 #DIV/O! 0 #DIV/O! Collapse Collapse Pr-Bot-Psi 1467 2952 0 0 0 0 0 0 0 0 Resist. CDF 2020 1.377 4320 1.464 0 #DNiO! 0 #DIVIO! 0 #DlVlO! 0 #DIV/O! 0 #DIV/O! 0 #DIV/Oi 0 #DIV/0! 0 #DIV/0! 1Y-28CIvIT.×LS State; Well: Field: State Permit 11: 1Y-28 Kuparuk River 98-89 Engineer: Work Sheet Date: ¢/10/,,°3 Casing Type Casing Size -Inches Cuing Length - Feet Hole Diameter-Inches Cement- Sacks1:I1 Cement-"F~td 111 Cement- Cubic t't 111 Cement- Cubic tt 111 Cement- Sacks1:I2 Cement- Yield112 Cement- Cubic ft 11:I2 Cement- Cubic it 112 Cement- Sacks113 Cement-Yield 113 Cement-Cubic tt 11:t3 Cement-Cubic ft 113 Cement -. Cubic ft / Vol Cement- Fill Factor Conductor 16.000 80.000 24.000 0.000 0.000 0.000 200.000 0.000 0.000 0.000 0.000 200.000 1.432 Surface 9.625 4,485.000 12.250 520.000 2.170 1,128.400 1,128.400 460.000 1.150 529.000 529.000 0.000 0.000 0.000 0.000 1,657.400 1.185 Line~ 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 I~DIV/O! Casing Type Casing Size -Inches Casing Del,th- Feet Hole Diamete~-inch~ Cement-Sacks 111 Cement-Yield 111 Cement-Cubic ft 111 Cement-Cubic tt 111 Cement- Sacks112 Cement- Yield112 Cement- Cubic It II2 Cement-Cubic It 1:12 Cement-Sacks 113 Cement-Y'~:I 113 Cement- Cubic It 113 Cement-Cubic tt :!I3 Cement- Cubic ft / Vol Cement-Interval It Top of Cement'- Feet Intermediate 111 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 I:tDIV/O! I:I:DIV/O! Intermediate 1:I2 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 I~DIV/O! Production 7.000 8,237.000 8.500 210.00 1.23 258.30 258.30 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 258.30 2,036.96 6,200.0 Measured Depth ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (2) Loc ~ ~./~./~ [2 thru [~J thru 1]~] [10 & 13] (4) Casg ~</.~ ~-I~- P~ [14 thru 22] [23 thru 28] Company Lease & Well YES . 1. Is permit fee attached ............................................... ../( 2. Is well to be located in a defined pool .............................. ~ 3. Is well located proper distance from property line ................... ~ 4. Is well located proper distance from other wells ..................... ~ 5. Is sufficient undedicated acreage available in this pool ............. /~ 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ 1 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~nber appropriate .......................................... ~ Does well have a unique name & n~nber ................................ z~ Is conductor string provided ......................................... ~ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. ~ Is enough cement used to circulate on conductor & surface ............ ~¢~ Will cement tie in surface & intermediate or production strings ...... ~ Will cement cover all known productive horizons ..................... ~.~, Will all casing give adequate safety in collapse, tension, and burst. ~ Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate well bore separation proposed ............................. ~ Is a diverter system required ........................................ ~ Is drilling fluid program schematic & list of equipment adequate ..... ~ Are necessary diagrams & descriptions of diverter & BOPE attached .... ~.~ Does BOPE have sufficient pressure rating -- test to ~o psig ..... ~ Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... NO ~EMARKS ( 6 ) 0 t h e r ~./~_ ~/~-/~.~ ~29 thru 31] (7) Contact ~ [32] (8) Add l ~4~.~,~-~', /~ -~-~ rev 6/93 jo/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone n~nber of contact to supply weekly progress data ...... Additional requirements ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE MERIDIAN' remarks' UM 2< SM WELL TYPE' Exp/~) Redri 11 , , Inj Rev 0 --I "rZ ,--,0 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASICA, INC. WELL NAME : 1Y-28 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22380-00 REFERENCE NO : 93391 Alaska Oil & Gas Go~s. Gommission - AnChorag~ LIS Tape Verification Listing Schlumoerger Alaska Computing Center 14-SEP-1993 16:21 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 93/09/14 ORIGIN : FLIC REEL NAME : 93391 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, INC.,KUPARUK RIVER UNIT, 1Y-28,50-029-22380-00 PAGE: **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 93/09/14 ORIGIN : FLIC TAPE NAME : 93391 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA, INC.,KUPARUK RIVER UNIT, 1Y-28,50-029-22380-00 TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD BIT RUN 1 93391 ST.AMOUR 1ST STRING 2ND STRING 1Y-28 500292238000 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 14-SEP-93 BIT RUN 2 BIT RUN 3 1 11N 9E 211 1944 106.00 106.00 65.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ........ .... LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1993 16:21 3RD STRING PRODUCTION STRING # REMARKS: FIELD ENGINEER'S REMARKS: ********** RUN I ********** CDR RP TP BIT: 28.56 FT. CDN RP TO BIT: 51.05 FT. BIT TO RES 25.4', BIT TO GR 35.8', BIT TO DEN 52.4' BIT TO NEUT 59.3'. DRILLED INTERVAL 7400' TO 8285' WASHDOWN INTERVAL 7315' TO 7400'. TD @13:49 ON 20-AUG-93. MATRIX DENSITY 2.65 (GM/CC), FLUID DENSITY 1.0 (GM/CC) ROTATIONAL BULK DENSITY PROCESSING USED. BARITE ADDED TO MUD SYSTEM. DATA FROM DOWNHOLE MEMORY. DOWNHOLE NO SLIDING THIS RUN (ROTARY ASSEMBLY). **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 93/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves~ all bit runs merged. DEPTH INCREMENT 0.5000 FILE SUMMARY KRU TOOL CODE START DEPTH STOP DEPTH CDN 7265.0 8285.0 CDR 7282.0 8285.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH MWD 88888.0 88887.5 8073.0 8072.5 8048.0 8047.0 7970.5 7970.0 7940.5 7940.0 7922.0 7921.0 7857.0 7856.5 7832.0 7831.0 7783.5 7783.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1993 16:21 7781.0 7780.5 7775.5 7775.0 7711.0 7710.5 7677.5 7677.0 7671.0 7671.0 7609.0 7608.5 7603.0 7602.0 7595.5 7596.5 7591.0 7591.5 7571.5 7571.0 7568.5 7568.0 7549.0 7548.5 7513.0 7513.0 7487.5 7487.5 7475.5 7475.0 7445.0 7444.5 7422.5 7423.5 7394.0 7394.5 7383.0 7384.0 7358.0 7359.0 7342.0 7343.5 7290.0 7291.5 100.0 101.5 $ MERGED DATA SOURCE KRU TOOL CODE $ REMARKS: BIT RUN NO. MERGE TOP MERGE BASE THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT MWD GR TO WIRELINE CET/GR OF 24-AUG-93. ALL OTHER CURVES WERE CARRIED WITH THE GR SHIFT. UNSHIFTED DATA IS IN FILE #2, AND THIS FILE ALSO CONTAINS VERY ENHANCED QRO PROCESSED RESISTIVITY DATA WITH A 2' AVERAGE. $ LIS FORMAT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 ~LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1993 16:21 PAGE: 9 65 FT 11 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 RHOB MWD G/C3 O0 000 O0 0 I i 1 4 68 0000000000 DRHO MWD G/C3 O0 000 O0 0 i 1 1 4 68 0000000000 PEF MWD BN/E O0 000 O0 0 1 1 1 4 68 0000000000 CALN MWD IN O0 000 O0 0 I 1 1 4 68 0000000000 NPHI MWD PU-S O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OHMM O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OHMM O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OHMM O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OHMM O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OHMM O0 000 O0 0 i 1 1 4 68 0000000000 ROP MWD FPHR O0 000 O0 0 i 1 1 4 68 0000000000 GR MWD GAPI O0 000 O0 0 1 1 1 4 68 0000000000 NCNT MWD CPS O0 000 O0 0 1 1 1 4 68 0000000000 FCNT MWD CPS O0 000 O0 0 i 1 1 4 68 0000000000 FET MWD HR O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CET GAPI O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 8284.500 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.MWD -999.250 RA.MWD -999.250 RP.MWD DER.MWD -999.250 VRP.MWD -999.250 VRA.MWD -999.250 ROP.MWD GR.MWD -999.250 NCNT.MWD -999.250 FCNT.MWD -999.250 FET.MWD GRCH.CET -999.250 DEPT. 8000.000 RHOB.MWD 2.198 DRHO.MWD -0.011 PEF.MWD CALN.MWD 0.076 NPHI,MWD 27.656 RA.MWD 9.715 RP.MWD DER.MWD 9.254 VRP.MWD 10.163 VRA.MWD 9.210 ROP.MWD GR.MWD 43.266 NCNT.MWD 331.473 FCNT.MWD 8.801 FET.MWD GRCH.CET 24.375 -999.250 -999.250 20.134 -999.250 2.551 9.080 40.528 0.821 LIS Tape Verification Listing Schlumberger Alaska Computing Center DEPT. 7500.000 RHOB.MWD CALN.MWD 0.243 NPHI.MWD DER.MWD 2.229 VRP.MWD GR.MWD 127.218 NCNT.MWD GRCH.CET 70.500 14-SEP-1993 16:21 2.460 DRHO.MWD 40.200 RA.MWD -999.250 VRA.MWD 280.150 FCNT.MWD DEPT. 7000.000 RHOB.MWD -999.250 DRHO.MWD CALN.MWD -999.250 NPHI.MWD -999.250 RA.MWD DER.MWD -999.250 VRP.MWD -999.250 VRA.MWD GR.MWD -999.250 NCNT.MWD -999.250 FCNT.MWD GRCH.CET 56.594 DEPT. 6696.500 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DER.MWD -999.250 VRP.MWD GR.MWD -999.250 NCNT.MWD GRCH.CET 73.875 -999.250 DRNO.MWD -999.250 RA.MWD -999.250 VRA.MWD -999.250 FCNT.MWD 0.011 2.174 -999.250 5.661 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 PEF.MWD RP.MWD ROP.MWD FET.MWD PEF.MWD RP.MWD ROP.MWD FET.MWD PEF.MWD RP.MWD ROP.MWD FET.MWD PAGE: 4.701 2.265 26.906 0.933 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 93/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 93/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH files. LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1993 16:21 PAGE: CDR 7265.0 CDN 7282.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): . BOTTOM LOG INTERVAL (FT]: BIT ROTATING SPEED (RPM] HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDN NEUTRON/POROSITY CDR RESISTIVITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (Fl): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L~/~): MUD VISCOSITY (SI: MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (~3): RESISTIVITY (OHMM AT TEMPERATURE DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 8285.0 8285.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF /IN/: EWR FREQUENCY HZ # REMARKS: FIELD ENGINEER'S REMARKS: ********** RUN i ********** BIT TO RES 25.40', BIT TO GR 35.80' BIT TO DEN 52.4', BIT TO NEUT 59.3' DRILLED INTERVAL 7400' TO 8285' 17-AUG-93 FAST 2.4 V4.0¢ MEMORY 8182.0 6700.0 8185.0 TOOL NUMBER NDS049 RGS022 8.500 5507.0 11.70 2.140 85.0 1.870 65.0 SANDSTONE 2.65 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1993 16:21 WASHDOWN INTERVAL 7315' TO 7400' NO SLIDING (ROTARY ASSEMBLY) $ LIS FORMAT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** ..... ..... i 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 ! 4 68 0000000000 RHOB LW1 G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 DPHI LW1 PU O0 000 O0 0 2 1 DRHO LW1 G/C3 O0 000 O0 0 2 1 PEF LW1 BN/E O0 000 O0 0 2 1 DCAL LW1 IN O0 000 O0 0 2 1 TNPH LW1 PU O0 000 O0 0 2 1 ATR LW1 OHHM O0 000 O0 0 2 1 PSR LW1 OHMM O0 000 O0 0 2 1 DER LW1 OHMM O0 000 O0 0 2 1 ROPE LW1 F/HR O0 000 O0 0 2 1 GR LW1 GAPI O0 000 O0 0 2 1 HENA LW1 CPS O0 000 O0 0 2 1 HEFA LW1 CPS O0 000 O0 0 2 1 TAB LW1 HR O0 000 O0 0 2 1 TABD LW1 HR O0 000 O0 0 2 1 68 68 68 68 68 68 68 68 68 68 68 68 68 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1993 16:21 PAGE: ** DATA ** DEPT. 8285.000 RHOB.LW1 -999.250 DPHI.LW1 -999.250 DRHO.LW1 PEF.LW1 -999.250 DCAL. LW1 -999.250 TNPH.LW1 -999.250 ATR. LW1 PSR. LW1 -999.250 DER.LW1 -999.250 ROPE.LW1 20.134 GR.LW1 HENA.LW1 -999.250 HEFA.LW1 -999.250 TAB.LW1 -999.250 TABD.LW1 DEPT. 8000.000 RHOB.LW1 2.226 DPHI.LW1 25.700 DRHO.LW1 PEF. LW1 2.911 DCAL. LW1 0.140 TNPH.LW1 27.500 ATR. LW1 PSR.LW1 9.215 DER. LW1 9.253 ROPE.LW1 37.672 GR.LW1 HENA.LW1 333.500 HEFA.LW1 9.096 TAB.LW1 0.826 TABD.LW1 DEPT. 7500.000 RHOB.LW1 2.460 DPHI.LW1 11.500 DRHO.LW1 PEF. LW1 4.701 DCAL.LW1 0.243 TNPH.LW1 40.200 ATR. LW1 PSR. LW1 2.265 DER.LW1 2.229 ROPE.LW1 26.906 GR. LW1 HENA.LW1 280.150 HEFA. LW1 5.661 TAB.LW1 0.933 TABD.LW1 DEPT. 7256.000 RHOB.LW1 -999.250 DPHI.LW1 -999.250 DRHO.LW1 PEF.LW1 -999.250 DCAL. LW1 -999.250 TNPH.LW1 -999.250 ATR. LW1 PSR.LW1 -999.250 DER. LW1 -999.250 ROPE.LW1 -999.250 GR.LW1 HENA. LW1 -999.250 HEFA.LW1 5.648 TAB.LW1 -999.250 TABD.LW1 -999.250 -999.250 -999.250 -999.250 -0.013 9.362 44.534 1.319 0.011 2.174 127.218 1.915 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 93/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 93/09/14 ORIGIN : FLIC TAPE NAME : 93391 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA, INC.,KUPARUK RIVER UNIT, 1Y-28,50-029-22380-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1993 16:21 PAGE: **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 93/09/14 ORIGIN : FLIC REEL NAME : 93391 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, INC.,KUPARUK RIVER UNIT, 1Y-28,50-029-22380-00