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MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3Q-08A KUPARUK RIV UNIT 3Q-08A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 3Q-08A 50-029-21681-01-00 197-193-0 W SPT 5410 1971930 1500 2220 2220 2220 2220 100 100 100 100 REQVAR P Josh Hunt 8/28/2024 Operator wanted to test to 2900 on this well. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3Q-08A Inspection Date: Tubing OA Packer Depth 190 2900 2740 2720IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240828161854 BBL Pumped:3 BBL Returned:2.8 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 99 9 999 99 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 14:15:45 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Tuesday, August 18, 2020 �� % P.I. Supervisor ��+�� �1 ��?Zti SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3Q -08A FROM: Brian Bixby KUPARUK RIV UNIT 3Q -08A Petroleum Inspector Src: Inspector Reviewed By P.1. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q -08A Insp Num: mitBDB200816080301 Rel Insp Num: API Well Number 50-029-21681-01-00 Inspector Name: Brian Bixby Permit Number: 197-193-0 Inspection Date: 8/15/2020 ' Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min .. , ' — 5410-- - � - -- 2675Type InI W TUbing 265 2675 2675Well 3Q -08A PTD 1971930 Isoo IA 830 Isoo 1730 1720 BBL Pumped: 16 '11313L Returned: 1.4 OA 220 240 240 240 - - - Interval 4YRTST iPIF P ' I Notes: Tuesday, August 18, 2020 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,April 04,2017 TO: Jim Regg P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1- a``ir(1 3Q-08A FROM: Adam Earl 1 KUPARUK RIV UNIT 3Q-08A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-08A API Well Number 50-029-21681-01-00 Inspector Name: Adam Earl Permit Number: 197-193-0 Inspection Date: 4/1/2017 Insp Num: mitAGE170401145755 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3Q-08A Type Inj W TVD 5410 Tubing 1300 1300 I 1300 1300 PTD 1971930 Type Test' SPT Test psi 1500 IA 490 2200 2150 2130 BBL Pumped: 1.7 BBL Returned: 1.2 OA 240 1 295 295 295 Interval 4YRTST Notes: MIT-IA test %ANNE® AUG 1 5 2017 Tuesday,April 04,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO. Jim Regg DATE: Monday,August 08,2016 �z P.I.Supervisor �Cdt V�€I(I SUBJECT: Mechanical Integrity Tests (( CONOCOPHILLIPS ALASKA INC 3Q-08A FROM: Bob Noble KUPARUK RIV UNIT 3Q-08A Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-08A API Well Number 50-029-21681-01-00 Inspector Name: Bob Noble Permit Number: 197-193-0 Inspection Date: 8/2/2016 Insp Num: mitRCN160804104110 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3Q-08A , Type Inj N 'TVD 5410 Tubing 370 376 372 372 PTD 1971930 - Type Test SPT Test psi I 1500 - IA 410 1800 - 1730 - 1720 - Interval 4YRTST PAF P ,; OA 45 50 50 50 Notes: - ----- ------ Monday,August 08,2016 Page 1 of 1 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 qr'/- I~) File Number of Well History File PAGES TO DELETE RESCAN r~ [] DIGITAL DATA E] 'OVERSIZED Color items - Pages: Grayscale, halftqnes, pictures, graphs, charts - · Pages:'/ Poor Quality Odginal- Pages: Other- Pages: Diskettes, No. Other, No/Type .Logs of various kinds Other Complete COMMENI~: n Scanned b :~M~red D~U~ Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: E~ver~ M~red Daretha Nathan Lowell Date: /s/ • • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,September 11,2013 TO: gg Jim Regg P.I.Supervisor I��l%i l!� _` c�f Z , 13 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-08A FROM: Lou Grimaldi KUPARUK RIV UNIT 3Q-08A Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv�)�� NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-08A API Well Number 50-029-21681-01-00 Inspector Name: Lou Grimaldi Permit Number: 197-193-0 Inspection Date: 8/23/2013 Insp Num: mitLGl30825170042 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3Q-08A - Type Inj W TVD 5410 IA 1393 2100 - 2044 - ! 2038 PTD1 1971930 - Type Test SPT Test psi 1500 - ' OA 357 423 415 L 413 • Interval 4YRTST P/F P ' I Tubin g r 2660 • 2651 2654 2678 Notes: I bbl diesel pumped, 1 bbl returned.Good solid test.Pertinent paperwork supplied for test. zv pre 5 9,,,e5 pto4 et-4AL,if • SCANNED ire i; 20Q Wednesday,September 11,2013 Page 1 of 1 . • • dtuaijamogo 0 in T- N ' '..c. •C . I, if • I. I. •I i I. I .ly li .1 . I. i 0 . I. / ,t , 1. . • 1. = 4 - - - i • • • . •••;-' r•--. _ . . . , : C\I -- • • • • . . . . 7,- • . • . . . I''' '3,,,.,:Jj . • . c.\ • . .-• C-- 6) tr , . • • . --- ---1:: , , . . . -4.--\ • • co '-.. - ±) . . • • :K • .,--- - • . • . . . ......... • • • . ? • -4 . • . co - • • .. • I N'—'" . + • . . • I •-- 1 . . • • --,, • / • -.7.., C,A3 • • . . . . . . . •.,., . . . • c\I 4_, . . • . : . • • ) . . . . . , ••• • . • • • • co • . • . • .o . . . . a . - - . . . . • --) (4) . . • - • : 1 , . • . . . . 4., - • • . . co 0 . • . . . . • . . • • • • • • :. 1 • . • . • m ....... . . . —• , 1 i ......, . • . • . • . • . : i , o I Cr) - . • . • . • • ' " 0 : I CO • • • - • • • • . ' . . • • • - I 7 . . . . . . . . 4 • • • • 4 : •,••. . • . • • • I ci, . . . • . • • • • • : t • , n_ • • • i 1 . . . ■ g , . . . . . I-- • • • ■ - i --, • • • • - ! 0 II . . . . . I 1 • • • • • • ' • • ' • • • . 01 ■ 1 • • • L.L.1 I .1 i I 1 1 I I I 1• I 1 il 1 '1 --7-4- i i r I i r i •1 ,L0 Y Z 0 0 F. fl. 0 0 0 0 I I.- < 0 0 0 0 0 0 (NI -r 0- ---,. — 0 Li- 0 LO N 0 N tO 41.-- 0 1- LO •F N .1) -----. H I ISd Q-- en f ... 0.... , • • • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 26, 2011 Commissioner Dan Seamount n Alaska Oil and Gas Commission r,,. , 333 West 7 Avenue, Suite 100 ' "' t� ►SSipn Anchorage, AK 99501 t9 t7 / 7 3 Commissioner Dan Seamount: 3 g - - M Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with 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 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped 10/18, 10/19 and, 10/21, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, r i4 }E ` i 3 2U u t&4 Martin Walters ConocoPhillips Well Integrity Projects Supervisor • 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 10/26/11 2L, 3K, 3M & 3Q PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 2L -301 50103205880000 2081920 10" N/A 10" N/A 1.7 10/18/2011 3K -20 50029230190000 2010880 SF N/A 14" N/A 1.7 10/19/2011 3K -24 50029229350000 1982490 SF N/A 24" N/A 3.5 10/19/2011 3M -01 50029216600000 1870120 SF N/A 12" N/A 5.95 10/21/2011 3M -03A 50029216960100 2081790 SF N/A 18" N/A 5.1 10/21/2011 3M -08 50029217090000 1870280 SF N/A 17" N/A 2.85 10/21/2011 3M -11 50029217180000 1870380 SF N/A 26" N/A 4.25 10/21/2011 3M -21 50029217390000 1870660 SF N/A 15" N/A 3.4 10/21/2011 3Q -03 50029222210000 1911260 SF N/A 18" N/A 3.45 10/19/2011 3Q -07 50029216820000 1861940 SF N/A 17" N/A 4.68 10/21/2011 r> 3Q -08A 50029216810100 1971930 SF N/A 15" N/A 3.55 10/21/2011 3Q -09 50029216740000 1861860 SF N/A 13" N/A 4.4 10/21/2011 ~ ~ s • ConocoPh i I i i ps A~aska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 18, 2009 Mr. Tom Maunder Alaska. Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: r ~1~;~ ~a r ; ~s . ~} m ~~ a~~ ~'t`~~.~.f~ ~:~4~. ~ ~ ~~-- i~ ~ ~3 ~ --- D~B~,~ Enclosed please find 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 10-404, Report of Sundry Operations. The cement was pumped June 26~', 2009. The corrosion inhibitor/sealant was pumped June 30~' & July 16~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. - Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. 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 Date 7/18/09 3H, 318~ 3Q PAD Well Name API # PTD # Initial top o eement Vol. of cement um d Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitoN sealant date ft bbls ft ~ al 31-07 500292154900 1860390 3' NA 3' NA 8.92 7/16/2009 3H-04 501032007600 1870760 30" NA 30" NA 13.6 7/16/2009 3H-08 501032008000 1870800 17" NA 17" NA 3.4 7/16/2009 3H-11 501032009100 1871240 27'.' NA 2T' NA 6.37 7/16/2009 3H-19 501032009000 1871330 17" NA 17" NA 5.95 7/16/2009 3H-21 501032009400 1880080 8" NA 8" NA 1.27 7/16/2009 3H-23A 501032020401 1961860 6" NA 6" NA 1.27 , 7/16/2009 3H-24 50103202350U 1960150 6" NA 6" NA 1.27 7/16/2009 3H-31 501032020500 1940190 13" NA 13" NA ~ 2.97 7/16/2009 3H-33 501032057800 2081130 19" NA 19" NA 5.52 7/16/2009 3Q-03 500292222100 1911260 SF NA 5" NA 0.9 6/30/2009 3Q-06 500292168300 1861950 43' 6.30 26" 6/26/2009 6.8 6/30/2009 3Q-08A 500292168101 1971930 SF NA 6" NA 1 6/30/2009 3Q-09 500292167400 1861860 SF NA 6" NA 1 6/90/2009 3Q-10 500292167500 1861870 15' 2.50 18" 6/26/2009 6.8 6/30/2009 3Q-11 500292167600 1861880 37' 4.30 23" 6/26/2009 7 6/30/2009 3Q-14 500292166500 1867770 46' 5.10 23" 6/26/2009 7 6/30/2009 3Q-22 500292262500 1951860 SF NA 19" 6/26/2009 6 6/30/2009 MEMORANDUM To~ Jim Regg '],~~, P.I. Supervisor I ~'~aj la` ~~~ J FRONT: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October Ol, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-08A KUPARUK RIV LIMIT 3Q-08A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ ('~ Comm Well Name: KUPARUK RIV UNIT 3Q-08A Insp Num: mitRCN080927181726 Rel Insp Num: API Well Number: 50-029-21681-01-00 Permit Number: 197-193-0 ~ Inspector Name: Bob Noble Inspection Date: 9/25/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3Q-08A Type Inj. ~ w TVD ~ s3sa j IA gas 1860 nao 17ao p.T 1971930 TypeTest SPT Test psi 1s6o pA ~ 70 70 ~ 70 7o I Interval aYRTST p~F P -~ Tubing I z6oo z6oo z6oo ~ z6oo Notes: ~~n_ ~~~- l~2~~a, ._ f ~rrrer Wednesday, October O1, 2008 Page 1 of 1 ~~~~~~ Schiumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # C/ ~__ s~zri9~ t~vu .~ 1 ~~~ Log Description 08/06/08 N0.4803 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1A-22 12097412 GLS - (p 07/22/08 1 1 2G-04 12096519 PROD PROFILE - 07/23/08 1 1 1A-22 12097413 PROD PROFILE - ~ 07/23/08 1 1 1A-28 11996647 PROD PROFILE - / 07/24/08 1 1 1A-25 11996648 PROD PROFILE % - 07/25/08 1 1 2A-08 11996649 INJECTION PROFILE 07/26/08 1 1 1 E-112 12080408 INJECTION PROFILE .. 07/27/08 1 1 2W-05 12080409 INJECTION PROFILE - 07/28!08 1 1 3J-10 12097408 SBHP SURVEY 07/20/08 1 1 3M-28 12097411 SBHP SURVEY L .- (}( 07/21/08 1 1 1 L-15 11982443 PROD PROFILE '~ ~ 07/06/08 1 1 30-08A 12080407 SBHP SURVEY ~L°. i(~~ - l93 ((p'a- 07/26/08 1 1 30-09 12080406 SBHP SURVEY /(p °.~-(p~ 07/26/08 1 1 1 L-24 11978468 PRODUCTION PROFILE 07/26/08 1 1 1 F-17 12080410 PRODUCTION PROFILE ~( ~ (p 07/29/08 1 1 30-11 12100430 SBHP SURVEY -p~/ 07/31/08 1 1 2M-06 12100433 INJECTION PROFILE 08/02/08 1 1 i H--~. 12100434 INJECTION PROFILE U ZC. 6 '3 {0 08/03/08 1 1 UGNU DS2-OBI 11996650 TEMPERATURE LOG ~ - 07/27/08 1 1 2X-14 12100432 LDL ~ 08/01/08 1 1 i F-20 12100435 PRODUCTION P OFILE / 08/04/08 1 1 iH-09 12100436 INJECTION PROFILE U 08/05!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. ~J ~~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission FROM: John Crisp Petroleum Inspector DATE: Wednesday, August 11,2004 SUBJECT: Mechanical Integrity Tests eONOeOPHILLIPS ALASKA INe 3Q-O8A KUPARUK RIV UNIT 3Q-O8A TO: Jim Regg Qp-, ø'I 2klù~ P.I. Supervisor 1') 11 V Src: Inspector Reviewed By: P.I. Suprv ,'1ßt2-- Comm NON-CONFIDENTIAL Well Na~e: KUPARUKRIVUNIT3Q-08A API Well Number: 50-029-21681-01-00 Inspector Name: John Crisp Insp Num: mitJCrO40810172725 Permit Number: 197~193-O Inspection Date: 8/8/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3Q-O8A Type Inj. S TVD 6468 IA 1250 3020 2950 2910 P.T. 1971930 TypeTest SPT Test psi 1347 OA 125 150 150 150 Interval 4YRTST P/F p Tubing 2250 2250 2250 2250 Notes: Wednesday, August 11,2004 Page I of I 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_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 60' feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Kuparuk River Unit 4. Location of well at surface 8. Well number 2241' FNL, 2207' FEL, Sec. 17, T13N, R9E, UM 3Q-08A At top of productive interval 9. Permit number / approval number 279' FSL, 1817' FEL, Sec. 7, T13N, R9E, UM 197-193 / At effective depth 10. APl number 50-029-21681-01 At total depth 11. Field / Pool 117' FSL, 2021' FEL, Sec. 7, T13N, R9E, UM Kuparuk River Unit Field/Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured 9634 feet Plugs (measured) true vertical 6468 feet Effective depth: measured 8425 feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 16" 1875# Poleset 80' 115' Surface 4898' 9.625" 1200 sx AS IV, 325 sx Class G 4935' 3727' Production 7831' 7" 630 sx Class G, 175 sx AS 1 7866' 5509' Liner 1953' 3.5" 359 sx Class G 9632' 6467' · . ; ,, ,. , Perforation depth: measured 9346' - 9376' true vertical 6324' - 6339' '..: . Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 tubing @ 7721' -!~'¢:'i' ,, ¢'; Packers & SSSV (type & measured depth) No packer No SSSV 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 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 Oil_ Gas __ Suspended _ Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Carl Peter Nezaticky 659-7224 Signed ~~'~~ .~ Title: Wells Team Leader Date ~::~,~//~,~.. Peter Nezaticky .~./ ..('// Prepared b~/ Sharon Allsup-Drake 263-4612 Form 10-404 Rev 06/15/88 · SCANNED AUG 0 5) 200 SUBMIT IN DUPLICATE PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(3Q-08 (W4-6)) WELL JOB SCOPE JOB NUMBER 3Q-08 ANN-COM M 0625020835.4 DATE DAILY WORK UNIT NUMBER 07/28/02 CEMENT TOP JOB DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 YESI YES DS-CULPEPPER NEZATICKY FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTIMATE WCW.K02.KR9 $6,400.00 $6,550.00 9.3Q Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSIII0 PSI 0 PSI DAILY SUMMARY PUMPED 7 BBL OF ARTIC SET 1 CEMENT INTO THE SURFACE X CONDUCTOR ANNULUS.[WH Maintenance] TIME LOG ENTRY 13:10 ON LOC. MIRU 13:20 START MIXING ARTIC SET 1 CEMENT @ 15.8 PPG. 13:30 START PUMPING CEMENT. 13:40 PUMPED 7 BBL OF CEMENT INTO THE SURFACE X CONDUCTOR ANNULUS. 13:50 WASH UP RIG DOWN 14:15 RDMO LIPS AlaSka, Inc. u i 'ary of PHILLIPs PETROLEUM coMR&NY (2982-2983, Valve 2 (5016.5020, OD:5620) lar~rei/Dummy Valve 3 (65156516, 0D:5 620) NIF (7607-7608, OD:3 500) SBE (7624-7625, OD:3500) NiF (7657-7658, 0D:3.500) 3Q,08A 500292168101 Annular Fluid: Last Tag 8425 Date: 110/11/99 Size 16.000 0 Size 9.625 0 Last W/O: 1/25/98 9634 6KB !4994 115 115 4935 3724 AngLe~ TS 160 dap @ 9334__ Angle ¢. TD 160 deg~ 9634 Rev Reason; IELV desigo, Water Thread Thread Size Top Bottom TVD 7.000 25 7866 5509 Size Bottom TVD 3.500 7679 Size Top 3,500 0 Interval TVD 9346-9376 6324-6339 Mfr 9632 6467 Bottom TVD 7721 i Wt Thread Wt Grade Thread Glade Thread 5411 ! 9.30 i L-80 EUE ABM 8RD Comment 2 1/2" HSD, 180 deg. phasing; No Orientation due to use of Petroline VIv 2. Extended Packin< 5/25/2000 Description Camco 'DS' Nipple pp[e 2.813" PKG BORE NO GO 5404] SEAL Baker GBH-22 Locator Seal Ass}, w/10' stroke Muleshoe Description iD 2.750 2.750 2.750 3.000 2.984 Comment ~e Lost in Hole ROPE Note BELLY DOWN 1.5" GLM @ 7615' RKB, SUGGEST SPANNING GLM W/TOOLS TO GET X PLUG THROUGH SBE 7" x 9 5/8" communication, lots of gas, both sides; suspect collar leak or hanger leak. SEAL (7710-7711, 0D:3500) TUBING 0D:3.500, TTL (772I -7722, 00:3500) ROPE (79197920, OD:I.00O) (9346-9376) SUNDRY NOTICE 10-404 Phillips Kuparuk Well 3Q-08A Annular Cement "Top-Job" July 28, 2002 Phillips Alaska, Inc., Kuparuk well 3Q-08A top of cement between the surface pipe and conductor (9 5/8" x 16") was measured at 42 feet below grade. Arctic Set I cement (15.8 ppg) was pumped into the annular void (7 bbl) via a hose, filling from the bottom-up. The cement top was brought to the surface of the conductor casing. The State Inspector was notified of the cement job and waived attendance, but will inspect the wellhead post cementing. The field Well Service Report is attached. SCANNED AUG 0 9 2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdo~ Stimulate__ Pull tubing _ Alter casing _ J5.Type of Well: Development? Exploratory ~ Stratagrapic ~. Service ~. 2. Name of Operator: Phillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: Plugging _ Perforate _ Repair well_ Other X Datum of elavation (DF or KB feet): 60' RKE 7. Unit or Property: Kuparuk River Unit 8. Well number: 224t' FNL, 2207' FEL, Sec 17, T13N, R9E, UM At top of productive interval: 279' FSL, 1817' FEL, Sec 7, T13N, R9E, UM At effective depth: 171' FSL, 1953' FEL, Sec 7, T13N, R9E, UM At total depth: 117' FSL, 2021' FEL, Sec 7, T13N, R9E, UM 3Q-08A 9. Permit number/a~b~e~ .~.~i~-_. '.~ 10. APl ~umber: 50-029-21681-01 11. Field/Pool: Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured 9634 feet true vertical 6468 feet Effective Depfl measured 9533 feet true vertical 6417 feet Casing Conductor Surface Plugs(measured) None Junk (measured) Piece of rope @ 7919 feet Production Liner Length Size Cemented 80' 16" 1875# Poleset 4898' 9-5/8" 1200 Sx AS IV & 325 Sx Class G 9326' 7" 630 Sx Class G & 175 Sx AS I 1953' 3.3" 359 Sx Class G Measured depth True verticaldepth 115' 115' 4935' 3727' 9361' 6551' 9632' 6467' Perforation Depth measured 9346' - 9376 true vertical 6324' - 6339 Tubing (size, grade, and measured~l~/~r~~ MAY ,?, 9 2~02 3.5,,, 9,3 #/ff., 1_-80 @ 7721. Packers and SSSV (type and measured depth) Pkr: Baker GBH-22 Locator Seal Assy @ 7710': SSSV: None, nipple @ 512 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 249 749 1461 0 0 1300 Casing Pressure Tubing Pressure 991 195 2000 2540 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _ 16. Status of well classification as: Oil _ Gas _ 17. I hereby certify fhaf fhe foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06'/15/88~ -'' Suspended _ Service _WAG_ Date SUBMIT IN DUPLICAT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon Alter casing __ Change approved program X Suspend__ Operation Shutdown __ Reenter suspended well __ Repair well__ Plugging_ Time extension __ Pull tubing __ Variance__ Perforate __ Stimulate __ Other __ 2. Name of Operator: ARCO Alaska, Inc. 5. Type of Well: Development X. Exploratory _...=. Stratagrapic ~ Service __ 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 2241' FNL, 2207' FEL, Sec 17, T13N, R9E, UM. At top of productive interval: 279' FSL, 1817' FEL, Sec 7, T13N, R9E, UM. At effective depth: 171' FSL, 1953' FEL, Sec 7, T13N, R9E, UM. At total depth: 117' FSL, 2021' FEL, Sec 7, T13N, R9E, UM. 8. Well number: 3Q-08A 6. Datum of elevation (DF or KB) 6O' RKB 7. Unit or Property: Kuparuk R ver Unit 9. Permit number/approval number: 10. APl number: 50-029-21681-01 11. Field/Pool: Kuparuk River Field/Oil Pool feet 12. Present Well condition summary Total Depth: measured 9634 feet true vertical 6468 feet Effective Depth: measured 9533 feet true vertical 6417 feet Casing Length Size Conductor 80' 16" Surface 4898' 9-5/8" Production 9326' 7" Liner 1953' 3.3" Plugs (measured) Junk (measured) Cemented 1875# Poleset 1200 SxAS IV & 325 Sx Class G 630 Sx Class G & 175 Sx AS I 359 Sx Class G None Piece of rope @ 7919 feet Measured depth 115' 4935' 9361' 9632' True vedicaldepth 115' 3727' 6551' 6467' Perforation Depth measured 9346'-9376' true vertical 6324' - 6339' Tubing (size, grade, and measured depth) 3.5", 9.3 #/ft., L-80 @ 7721' ORIGINAL Packers and SSSV (type and measured depth) Pkr: Baker GBH-22 Locatcr Seal Assy @ 7710'; SSSV: None, nipple ~ 512' 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch _ 14. Estimated date for commencing operation Convert Oil Producer to WI- Sept, 1999 16. If proposal was verbally approved Name of approver 15. Status of well classification as: Oil _X Gas __ Date approvedI Service Suspended__ 17. I hereby certify that the forgoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Comission so representitive may witness Plug integrety __/,- BOP test __ Location clearance __ Mechanical integrety te~t__Il' Subsequent form required 10- lltl)y Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY Robert N. Christenson IAppr°val N°',.j~ ~ F _ Commissioner,.,, Date -,,,~ .... Co'ct ,~opy SUBMIT IN TRIPLICATE :),:"[u rned Attachment 1 Conversion to Water Injection Kuparuk Well 3Q-08A ARCO Alaska requests approval to convert Well 3Q-08A from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 6324' and 6339'. This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdo~ Stimulate Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ~ ARCO Alaska~ Inc. Development X 60' RKE 3. Address: Exploratory__ 7. Unit or Property: P.O. Box 10036D Stratagrapic__ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 2241' FNL, 2207' FEL, Sec 17, T13N, R9E, UM 3Q-08A At top of productive interval: 9. Permit number/approval number: 279' FSL, 1817' FEL, Sec 7, T13N, R9E, UM 86-193 / 97-193 At effective depth: 10. APl number: 171' FSL, 1953' FEL, Sec 7, T13N, R9E, UM 50-029-21681-01 At total depth: 11. Field/Pool: 117' FSL, 2021' FEL, Sec 7, T13N, R9E, UM Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured 9634 feet Plugs (measured) None true vertical 6468 feet Effective Deptt measured 9533 feet Junk (measured) Piece of rope @ 7919 feet true vertical 6417 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 1875# Poleset 115' 115' Surface 4898' 9-5/8" 1200 Sx AS IV & 4935' 3727' 325 Sx Class G Production 9326' 7" 630 Sx Class G & 9361' 6551' 175 Sx AS I Liner 1953' 3.3" 359 Sx Class G 9632' 6467' Perforation Depth measured 9346'-9376 Oi L i ATE· ,"-. true vertical 6324' - 6339 .: . ,, Tubing (size, grade, and measured depth) 3.5", 9.3 #/ft., L-80 @ 7721' :i: :,i.:'.: .~!. ::. :7.71:: ': Packers and SSSV (type and measured depth) "': ': ": Pkr: Baker GBH-22 Locator Seal Assy @ 7710'; SSSV: None, nipple @ 512 13. Stimulation or cement squeeze summary Perforated A & C sands on 2/13/98. Intervals treated (measured) 9346' - 9376' Treatment description including volumes used and final pressure Perforated using 2.5" HSD guns w/BH charges @ 4 SPF, 180 deg phasing, final pressure = 270 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 976 245 Subsequent to operation 249 749 1461 991 195 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ZX Oil _ZX Gas Suspended Service . ;i~ n le;e~' re c 'Tilt ,°~'.h eWbe;,$; so~ prr~ r% nkt~%~leenlg e ' Date Form 10-404 ¢:v 06/15/88 / SUBI~ IN DUPLICA~ '"ARC. O Alaska, Inc. A KUPARUK RIVER UNIT Kl(3Q-08A(W4-6)) WELL SERVICE REPORT WEI J, JOB SCOPE JOB NUMBER 3Q-08A PERFORATE, PERF SUPPORT 0130980822.2 DATE DALLY WORK UNIT NUMBER 02/13/98 PERFORATE, PERF SUPPORT DAY OPERATION COMPLETE ] SUCCESSFUL KEY PERSON SUPERVISOR 5 YES] YES SWS-ELMORE BLACK FIEI.D AFC# CC# DAILY COST ACCUM COST Signed ESTIMATE 998767 230DS36QO $16,000.00 $48,527.00 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 320 PSI 270 PSI 125 PSI 125 PSII 0 PSI 0 PSI DAILY SUMMARY ROLLERS). PERFORATE "A" SAND F/9346 - 9376' ELM W/2.5" HSD BH @ 4 SPF & 180 DEG PHASED (NO ORIENTATION DUE TO USE OF PETROLINE TIME LOG ENTRY 15:00 MIRU SWS (ELMORE & CREW). TGSM & JOB OVERVIEW. MU GUN ASSEMBLY#1 (10' X 2.5" HSD/MPD/CCL/GR) TL-24'. GUN @ 4 SPF, 180 PHASED & ORIENTED 31 DEG CCW. 15:45 RIH TO 8675' ELM. UNABLE TO MOVE FURTHER (OPEN GLM @ +/- 7650' ELM). WORK UP & DOWN. POOH TO INSTALL PETRO IN ROI.I.ERS. t 8:00 AT SURFACE. BD LUBRICATOR & RD GUN. WORK ON DAMAGED XOVER CONNECTION. MU GUN ASSEMBLY#lA (ROLLER/10' X 2.5" HSD/ROLLER/CCL/GR) TL-29'. NOTE: DUE TO USE OF ROLLERS WILL BE UNABLE TO ORIENT. 20:30 RIH TO 9490' ELM. TIE IN W/10/20/97 SPERRY ROP/GR. MOVE INTO POSITION & PERFORATE F/9366 - 9376' ELM W/ 2.5" HSD BH @ 4 SPF & 180 DEG PHASED (NO ORIENTATION DUE TO ROLLERS). GOOD SURFACE INDICATIONS. LOG UP&POOH. 22:45 AT SURFACE. ALL SHOTS FIRED. MU GUN ASSEMBLY #2 (ROLLER/20' X 2.5" HSD/ROLLER/CCL) TL-36'. PT & RIH TO 9490' ELM. TIE IN & PERFORATE F/9346 - 9366' ELM W/SAME GUNS AS ABOVE. GOOD SURFACE INDICATIONS. LOG UP &POOH. 01:00 AT SURFACE. ALL SHOTS FIRED. BEGIN RD. 02: 00 RD COMPLETE. LEAVE WEI J. SI AWAITING SL TO DUMMY OFF LOWER GLM. · . SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $500.00 $15,000.00 ARCO $0.00 $500.00 DOWEl J, $0.00 $11,142.00 HAl JJBURTON $0.00 $4,865.00 LrYFLE RED $0.00 $1,520.00 SCHLUMBERGER $15,500.00 $15,500.00 TOTAL FIELD ESTIMATE I $16~000'001 $48~527.00 STATE OF ALASKA · ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdo~ Stimulate X Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other _ 12. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 60' RKE 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Stratagrapic ~ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 2241' FNL, 2207' FEL, Sec 17, T13N, R9E, UM 3Q-08A At top of productive interval: 9. Permit number/approval number: 279' FSL, 1817' FEU Sec 7, T13N, R9E, UM ~(~I.~/97-193 At effective depth: 10. APl number: 171' FSL 1953' FEL, Sec 7, T13N, R9E, UM 50-029-21681-01 At total depth: 11. Field/Pool: 117' FSL, 2021' FEL, Sec 7, T13N, R9E, UM Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured 9634 feet Plugs (measured) None true vertical 6468 feet Effective Deptt measured 9533 feet Junk (measured) Piece of rope @ 7919 feet true vertical 6417 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 1875# Poleset 115' 115' Surface 4898' 9-5/8" 1200 Sx AS IV & 4935' 3727' 325 Sx Class G Production 9326' 7" 630 Sx Class G & 9361' 6551' 175 Sx AS I Liner 1953' 3.3" 359 Sx Class G 9632' 6467' Perforation DepthORIGINAL measured 9346' - 9376 true vertical 6324'-6339 ' "- ' ' Tubing (size, grade, and measured depth) .":. ' ' 3.5", 9.3 #/ft., L-80 @ 7721' ~ ,, .,, :,- ~,:.. , . ! ,. .,, , Packers and SSSV (type and measured depth) "~ -~: ::" .... . TM ' ..... ~ ............ Pkr: Baker GBH-22 Locator Seal Assy @ 7710'; SSSV: None, nipple @ 512 '~ '~ i' .'. ~..: 13. Stimulation or cement squeeze summary Fracture stimulate A & C sands on 3/9/98. Intervals treated (measured) 9346' - 9376' Treatment description including volumes used and final pressure Pumped 141,515 lbs of 20/40 and 12/18 ceramic proppant into formation, final pressure = 8500 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 976 245 Subsequent to operation 249 749 1461 991 195 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations_~X Oil X Gas Suspended Service 17. , he,eby certify~tha~oing is tru, e.4t~nd correct to the best of my knowledge. Signe~~~~~,~~-~//~ ~'~'/ '///// Title: Wells Superintendent Date Form 10-40~ SUBMIT IN DUPLICATE~ ARCO Alaska, Inc. KUPARUK RIVER UNIT ~'A K1 (Q-08A(W4-6)) WELL JOB SCOPE JOB NUMBER 3Q-08A FRAC, FRAC SUPPORT 0309982044.4 'DATE DAILY WORK UNIT NUMBER 03/09/98 PUMP "A &C" SANDS FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes O NoI (~ Yes O No DS-YOKUM JOHNS FIELD AFC# CC# DAILY COST ACCUM COST Sig/~e~ ESTIMATE 998767 230 DS36QO $123,201 $123,201 /~.~,~.¥.~_.¢,-.-.~~---._._~ Initial Tbg Press Final Tbg Press 'Initial Inner Ann Final Inner Ann I Initial Outer-Ann I Final Odter Ann 0 PSi 2000 PSI 100 PSI 500 PSII 100 PSII 50 PSI DALLY SUMMARY PUMPED "A &C" SANDS FRAC. , PRESSURED OUT WITH 141,515# OF UP TO 10 PPA 12/18 PROPPANT AT PERFS . LEFT 23802 # PROPPANT IN PIPE. TIME LOG ENTRY 11:00 MIRU DOWELL FRAC EQUIP., LITTLE RED PUMP AND APC SUPPORT. 13:09 HELD JOB SITE SAFETY MEETING. 13:45 PRESSURE TEST TREATING LINE TO 9400 PSI. 14:17 PUMP BREAKDOWN TO 25 BPM AND 8200 PSI, PUMP SCOUR STAGE WITH 1 PPA 20/40 PROPPANT, PUMP FLUSH WITH 93 BBLS STRIAGHT SEAWATER. SHUTDOWN FOR ISIP 195 PSI. 15:08 PUMP DISPLACE, DATA FRAC AND FLUSH. 100 BBLS 50# GEL AND 93 BBLS SEAWATER. 5 TO 15 BPM AND 5462 PSI. SHUTDOWN FOR ISIP AND CLOSURE CALCULATION. 16:15 PUMP 290 BBLS PAD, 5 TO 15 BPM AND 4885 PSI. .. 16:44 PUMP 15439# 20/40 PROPPANT AT 2PPA, 15 BPM AND 4687 PSI. 16:59 PUMP 147867# OF 12/18 PROPPANT TO 10 PPA, SCREENED OUT WITH 8500 MAX PSI. 17:44 SHUTDOWN WITH 141,515# PROPPANT IN PERFS AND 23,802# IN PIPE. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $7,500.00 $7,500.00 ARCO $600.00 $600.00 DOWELL $112,501.00 $112,501.00 LI-FI'LE RED $2,600.00 $2,600.00 TOTAL FIELD ESTIMATE $123,201.00 $123,201.00 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 30, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3Q-08A (Permit No. 97-193) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report to cover any changes made to the completion during the recent operations to sidetrack KRU 3Q-08. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad )nch0rage ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~] GAS [~ SUSPENDED [~ ABANDONED~] SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 97-193 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-21681-01 4 Location of well at surface 9 Unit or Lease Name ..... ~ Kuparuk River Unit 2241' FNL, 2207' FEL, Sec. 17, T13N, R9E, UM / At Top Producing Interval ! ': :: [ ~-~ 10 Well Number 276' FSL, 1808' FEL, Sec. 7, T13N, R9E, UMi~ '~-"~-' -~-~' ........ ~ i ~~ 3Q-08A ;' ~ ~ 11 Field and Pool At Total Depth · 114' FNL, 2012' FEL, Sec. 7, T13N, R9E, UM .............. ~;.:-~' KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. Kuparuk River Oil Pool RKB 54', Pad 22'I ADL 355024 ALK 3574 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 17-Oct-97 19-Oct-97 25-Jan-98I NA feet MSL 1 17 Total Depth (MD+'I-VD) 18 Plug Back Depth (MD+'I-VD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 9634' MD & 6468' TVD 9533' MD & 6417' TVD YES X~ NO U NA feet MD 1600' APPROX 22 Type Electdc or Other Logs Run GR/Res 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT i?ECOI?D 16' 62.5# H-40 SURF. 115' 24' 1875# Poleset 9.625' 36.0# J-55 SURF. 4935' 12.25' 1200 sx AS IV & 325 sx Class G 7' 26.0# J-55 SURF. 7866' 8.5' 630 sx Class G & 175 sx AS I 3.5' 9.3# L-80 7679' 9632' 6.125' 359 sx Class G 24 Perforations open to Production (MD+'I-VD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5' 7721' 7687' 9346'-9376' MD 6324'-6339' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4 spf 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 FO OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOI: Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BB[ OIL GRAVITY-APl (corr) Press. 24-HOUR RATE: 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL N/A Form 10-407 Submit in du .p,J[~]~0[ag~ Rev. 7-]-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 Kuparuk C 9334' 6318' Annulus freeze protected with diesel. Bottom Kuparuk C 9353' 6328' Top Kuparuk A 9353' 6328' Boftom Kuparuk A 9461' 6382' 31. LIST OF AI-rACHMENTS Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 7,J ,~. ~. ~,, ,~..___.__ Title ~'~,T~I.1.T.~ (, E ~-T.,E. Ef, DATE Prepared by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repod 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 Date: 3/26/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:3Q-08A RIG:NORDIC WELL_ID: 998767 TYPE: AFC: 998767 AFC EST/UL:$ 855M/ 995M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:10/16/97 START COMP:01/23/98 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21681-01 10/13/97 (D1) TD: 0'( SUPV:DLW 10/14/97 (D2) TD: 0'( SUPV:DLW 10/15/97 (D3) Tm: 0'( SUPV:RLM 0) 0) 0) 10/16/97 (D4) TD: 7896' (7896) SUPV:RLM 10/17/97 (D5) TD: 8297' (401) SUPV:RLM 10/18/97 (D6) TD: 9061' (764) SUPV:RLM 10/19/97 (D7) TD: 9634' (573) SUPV:RLM 10/20/97 (D8) TD: 9634'( SUPV:RLM o) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 KILL WELL Move rig from 3I to 3Q. Prep well site and spot rig over well. Accept rig @ 22:00 hrs. MW: 9.6 VISC: 52 PV/YP: 11/23 APIWL: 10.0 LAY DOWN TUBING AND JEWELRY Pumped fresh water and mud to kill well. ND tree, NU BOP, test to 300/3500 psi. Pull tubing hanger to floor. Lay balanced plug with OET at 8882' Calculated top of cement at 8529' MW: 9.6 VISC: 96 PV/YP: 12/47 APIWL: 9.0 PICK UP DP AND RIH W/WS POOH laying down 2-7/8" tubing and jewelry. Made gauge ring and junk basket run to 8038'. Run Baker N-1 BP on WL set with top at 7896' MW: 9.7 VISC: 67 PV/YP: 14/44 APIWL: 7.0 RIH W/DRILLING BHA RIH with Baker window master whipstock and milling ~ assembly. Set whipstock with top at 7865'. Mill window fro 7866' to 7879' Milled in open hole from 7879' to 7896' Perform FIT, 12.4 EMW. MW: 9.6 VISC: 56 PV/YP: 16/31 APIWL: 5.0 DIRECTIONAL DRILLING Safety meeting and fire drill. Wash through window and onto bottom at 7896' Drill and survey with MWD from 7896' to 8297' MW: 10.4 VISC: 50 PV/YP: 17/29 DIRECTIONAL DRILLING @ 9231' Drill and survey with MWD from 8279' to 9061' APIWL: 4.5 MW: 10.6 VISC: 51 PV/YP: 21/30 APIWL: 4.0 POOH FOR LINER Directional drill and survey with MWD from 9061' to 9634' MW: 10.6 VISC: 52 PV/YP: 21/26 APIWL: 4.0 LAY DOWN DP Had a sudden 60k overpull at 7840', jars tripped and stuck Date: 3/26/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 10/21/97 (D9) TD: 9634'( SUPV:RLM o) 10/22/97 (D10) TD: 9634' ( 0) SUPV:RLM pipe in casing. Jars would not trip down. Spud on drill pipe, pipe came free and restuck at 7852' Slowly spudded pipe down until stabilizer was out of window, pipe came free. Ream and work pipe from 7955' to 7915'. Pull up to 7284' free through window and in casing. Run 3.5" liner to 9634' TD. MW: 10.6 VISC: 52 PV/YP: 21/26 APIWL: 4.0 RUNNING COMPLETION Cement 3.5" liner with shoe at 9632' Rig up to run completion. Held pre-job safety meeting. MW: 8.4 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG TO 1E-31 RIH with completion string to 9632' NU tree and test 250/5000 psi. Release rig @ 2400 hrs. 10/22/97. Date: 3/26/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 REMEDIAL AND COMPLETION OPERATIONS WELL:3Q-08A RIG:NORDIC WELL_ID: 998767 TYPE: AFC: 998767 AFC EST/UL:$ 855M/ 995M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:10/16/97 START COMP:01/23/98 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21681-01 01/23/98 (Cji) TD: 9636' PB: 9533' SUPV:DLW 01/24/98 (C12) TD: 9636' PB: 9533' SUPV:DLW 01/25/98 (C13) TD: 9636' PB: 9533' SUPV:DLW BLEED ANNULUS PRESSURE MW: 8.5 Turn key rig move from lC to 3Q pad. Accept rig for operations @ 2200 hrs. 1/23/98. SW FREEZE PROTECT MW: 0.0 N/D tree, N/U BOPE and function test. Test BOPE to 300/3500 psi. Pull 3.5" tubing. R/U new seal assembly and re-run. MW: 0.0 Continue to run completion string. N/D BOPE, NU and test. Release rig @ 1630 hrs. 1/25/98. End of WellSummary for We11:998767 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(3Q-08A(W4-6)) WELL JOB SCOPE JOB NUMBER 3Q-08A PERFORATE, PERF SUPPORT 0130980822.2 UNIT NUMBER DATE DAILY WORK 02/13/98 PERFORATE, PERF SUPPORT DAY OPERATION COMPLETE I SUCCESSFUL 5 YES I ___ YES Initial Tbg Press I Final Tbg Press Initial Inner Ann 320 PSII 270 PSI 125 PSI DAILY SUMMARY KEY PERSON SWS-ELMORE Final Inner Ann I I 125 PSI SUPERVISOR BLACK Initial Outer Ann J Final Outer Ann 0 PSII 0 PSI PERFORATE 4 SPF & 180 DEG PHASED (NO ORIENTATION DUE TO USE OF SAND F/ 9346 9376' ELM W/2.5" HSD BH PETROLINE ROLLERS). TIME 15:00 LOG ENTRY MIRU SWS (ELMORE & CREW). TGSM & JOB OVERVIEW. MU GUN ASSEMBLY#1 (10'X 2.5" HSD/MPD/CCL/GR) 15:45 TL-24'. GUN @ 4 SPF, 180 PHASED & ORIENTED 31 DEG COW. RIH TO 8675' ELM. UNABLE TO MOVE FURTHER (OPEN GLM @ +/- 7650' ELM). WORK UP & DOWN. POOH TO 18:00 INSTALL PETROLINE ROLLERS. AT SURFACE. BD LUBRICATOR & RD GUN. WORK ON DAMAGED XOVER CONNECTION. MU GUN 20:30 ASSEMBLY#IA (ROLLER/10' X 2.5" HSD/ROLLER/CCL/GR) TL-29'. NOTE: DUE TO USE OF ROLLERS WILL BE UNABLE TO ORIENT. RIH TO 9490' ELM. TIE IN W/10/20/97 SPERRY ROP/GR. MOVE INTO POSITION & PERFORATE F/9366 - 9376' 22:45 ELM W/2.5" HSD BH @ 4 SPF & 180 DEG PHASED (NO ORIENTATION DUE TO ROLLERS). GOOD SURFACE INDICATIONS. LOG UP & POOH. AT SURFACE. ALL SHOTS FIRED. MU GUN ASSEMBLY #2 (ROLLER/20' X 2.5" HSD/ROLLER/CCL) TL-36'. PT & 01:00 02:00 RIH TO 9490' ELM. TIE IN & PERFORATE F/9346 - 9366' ELM W/SAME GUNS AS ABOVE. GOOD SURFACE INDICATIONS. LOG UP & POOH. AT SURFACE. ALL SHOTS FIRED. BEGIN RD. RD COMPLETE. LEAVE WELL SI AWAITING SL TO DUMMY OFF LOWER GLM. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(3Q-08A(W4-6)) WELL 3Q-08A JOB SCOPE FRAC, FRAC SUPPORT DAY OPERATION COMPLETE SUCCESSFUL 1 YES YES · Initial Tbg Press I Final Tbg Press Initial Inner Ann 0 PSII 2000 PSI 100 PSI DAILY SUMMARY r# PROPPANT IN PIPE. JOB NUMBER 0309982044.4 KEY PERSON DS-YOKUM Final Inner Ann I Initial Outer Ann I 500 PSI DATE DALLY WORK UNIT NUMBER 03/09/98 PUMP "A &C" SANDS FRAC SUPERVISOR JOHNS Final Outer Ann 100 PSI 50 PSI PUMPED "A &C" SANDS FRAC. , PRESSURED OUT WITH 141,515# OF UP TO 10 PPA 12/18 PROPPANT AT PERFS . LEFT 23802 TIME 11:00 13:09 13:45 14:17 15:08 LOG ENTRY MIRU DOWELL FRAC EQUIP., LITTLE RED PUMP AND APC SUPPORT. HELD JOB SITE SAFETY MEETING. PRESSURE TEST TREATING LINE TO 9400 PSI. PUMP BREAKDOWN TO 25 BPM AND 8200 PSI , PUMP SCOUR STAGE WITH 1 PPA 20/40 PROPPANT , PUMP FLUSH WITH 93 BBLS STRIAGHT SEAWATER. SHUTDOWN FOR ISIP 195 PSI. PUMP DISPLACE , DATA FRAC AND FLUSH. 100 BBLS 50# GEL AND 93 BBLS SEAWATER. 5 TO 15 BPM AND 5462 PSI. SHUTDOWN FOR ISIP AND CLOSURE CALCULATION. 16:15 PUMP 290 BBLS PAD, 5 TO 15 BPM AND 4885 PSI. 16:44 PUMP 15439# 20/40 PROPPANT AT 2PPA, 15 BPM AND 4687 PSI. 16:59 PUMP 147867# OF 12/18 PROPPANT TO 10 PPA, SCREENED OUT WITH 8500 MAX PSI. 17:44 SHUTDOWN WITH 141,515# PROPPANT IN PERFS AND 23,802# IN PIPE. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA INC KRU / 3Q-08A 500292168101 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/10/97 DATE OF SURVEY: 101997 MWD SURVEY JOB NUMBER: AKMM70303 KELLY BUSHING ELEV. = 54.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 7794.00 5460.71 5406.71 47 31 N 64.73 W .00 3038.41N 3818.82W 1277.27 7866.00 5509.30 5455.30 47 35 N 65.23 W .52 3060.88N 3866.97W 1302.75 8111.36 5672.68 5618.68 49 56 S 87.95 W 8.24 3095.84N 4044.91W 1425.42 8206.09 5732.36 5678.36 52 9 S 76.09 W 10.00 3085.53N 4117.61W 1490.10 8303.20 5791.09 5737.09 53 37 S 64.28 W 9.81 3059.29N 4190.21W 1564.14 8399.01 5845.69 5791.69 56 58 S 55.47 W 8.33 3019.72N 4258.16W 1642.32 8493.57 5897.93 5843.93 55 57 S 57.17 W 1.85 2976.01N 4323.74W 1721.05 8587.47 5948.85 5894.85 58 32 S 45.73 W 10.60 2926.84N 4385.26W 1799.74 8683.83 5997.53 5943.53 60 49 S 51.67 W 5.82 2872.02N 4447.73W 1882.55 8776.69 6042.59 5988.59 61 6 S 54.47 W 2.65 2823.26N 4512.62W 1963.71 8875.29 6089.72 6035.72 61 47 S 52.46 W 1.92 2771.70N 4582.19W 2050.31 8970.78 6135.25 6081.25 61 15 S 51.93 W .75 2720.25N 4648.51W 2134.21 9063.76 6181.02 6127.02 59 46 S 50.13 W 2.32 2669.37N 4711.42W 2215.04 9159.71 6229.62 6175.62 59 21 S 49.68 W .59 2616.09N 4774.71W 2297.59 9254.34 6277.87 6223.87 59 19 S 50.56 W .80 2563.90N 4837.18W 2378.83 9347.42 6325.01 6271.01 59 49 S 50.85 W .59 2513.07N 4899.29W 2458.99 9442.43 6372.37 6318.37 60 22 S 52.14 W 1.32 2461.79N 4963.74W 2541.29 9534.26 6417.94 6363.94 60 7 S 51.38 W .77 2412.45N 5026.36W 2620.97 9634.00 6467.63 6413.63 60 7 S 51.38 W .00 2358.47N 5093.93W 2707.38 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5613.42 FEET AT NORTH 65 DEG. 9 MIN. WEST AT MD = 9634 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 233.68 DEG. TIE-IN SURVEY AT 7,794.00' MD WINDOW POINT AT 7,866.00' MD PROJECTED SURVEY AT 9, 634.00' MD ' r~ !.)f:'C 2 4 ~997 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC KRU / 3Q-08A 500292168101 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/10/97 DATE OF SURVEY: 101997 JOB NUMBER: AKMM70303 KELLY BUSHING ELEV. = 54.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 7794.00 5460.71 5406.71 8794.00 6050.96 5996.96 9634.00 6467.63 6413.63 3038.41 N 3818.82 W 2814.45 N 4524.95 W 2358.47 N 5093.93 W 2333.29 2743.04 409.75 3166.38 423.33 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA INC KRU / 3Q-08A 500292168101 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/10/97 DATE OF SURVEY: 101997 JOB NUMBER: AKMM70303 KELLY BUSHING ELEV. = 54.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 7794.00 5460.71 5406.71 7932.25 5554.00 5500.00 8082.54 5654.00 5600.00 8241.52 5754.00 5700.00 3038.41 N 3818.82 W 3078.43 N 3912.57 W 3095.99 N 4022.97 W 3077.68 N 4144.54 W 2333.29 2378.25 44.96 2428.54 50.29 2487.52 58.98 8414.25 5854.00 5800.00 8597.39 5954.00 5900.00 8800.30 6054.00 6000.00 9009.76 6154.00 6100.00 9207.54 6254.00 6200.00 3012.48 N 4268.69 W 2920.98 N 4391.38 W 2811.24 N 4529.44 W 2699.18 N 4675.41 W 2589.51 N 4806.12 W 2560.25 72.73 2643.39 83.13 2746.30 102.91 2855.76 109.46 2953.54 97.78 9405.27 6354.00 6300.00 9606.65 6454.00 6400.00 9634.00 6467.63 6413.63 2481.62 N 4938.25 W 2373.27 N 5075.40 W 2358.47 N 5093.93 W 3051.27 97.74 3152.65 101.38 3166.38 13.73 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 197-193-0 KUPARUK RIV UNIT 3Q-08A 50- 029-21681-01 ARCO MD 09634 TVD 06468 o~ommpletion Date: T/~5/98 Completed Status: 1-OIL Current: Name Interval Sent Received T/C/D 8200 ~ SPERRY GR/EWR4 OH 12/17/97 12/17/97 ! :' B~CE~'LuO ~ ~ 6800-8030 /0//%..~7 CH 5 12/10/97 12/18/97 DGR/EWR4-MD ~N~ 7898-9634 OH 12/23/97 12/24/97 L DGR/EWR4-TVD t,~qAL 5530-6568 OH 12/23/97 12/24/97 R MWD SRVY f_~I~RRY 7794 -9634.. OH 12/17/97 12/24/97 Daily Well Ops !c~//~/~?-- ~/~/~ Are Dry Ditch Samples Required? yes ~And Received?~,~yes no ~.~. Was the well cored? yes n(.o,~)~_: Analysis Description Ree~wedq~rt~ffo~-~ Sample Comments: Thursday, February 03, 2000 Page 1 of 1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs December 23, 1997 3Q-08A, AK-MW-70303 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of~ Jim Gal~ Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 3Q-O8A: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-21681-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-21681-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company D Ft I I_1_1 ~ 13 SEI:I~ICE S 17-Dec-97 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 q7-/ 5 Re: Distribution of Survey Data for Well 3Q-08A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,794.00' MD 7,866.00' MD 9,634.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 · Fax (907) 563~7252 A Dresser Industries, Inc, Company WELL LOG TRANSMITTAL To: State of Alaska .Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 3Q-08A, AK-MW-70303 December 17, 1997 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-21681-01 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 , Fax (907) 563-7252 A Dresser Industries, Ino. Company 12/10/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11632 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 3 F-5 ~ ~ - c~c] ~ PRODUCTION PROFILE 9 71 1 2 4 I 1 3F-10 --,~ ~ c:~l PRODUCTION PROFILE 971119 I 1 .... 3 F- 15:2 z~ ~ ~ ~. I C._.. INJECTION PROFILE 9 71 01 4 I 1 3G-03 ~:~- I,-~- PRODUCTION PROFILE 971016 I 1 3G-03 ~,~' PRODUCTION PROFILE 971 026 I 1 3H-01 '~'~-- I~ O PRODUCTION PROFILEW/DEFT 971030 I 1 3K-22 ~] - O ~.<~ [_~ [ C_~ PRODUCTION PROFILE 971 1 26 I 1 3 K-23 ~ "~ - O~/~ PRODUCTION PROFILE 9 71 1 2 7 I 1 30-20 C~- C~c/~'- GAS LIFTSURVEY 971026 I 1 3Q-08A ~ -- {c~ -~ BRIDGE PLUG SETT1NG RECORD 971015 I 1 3 R-18 ~ ~. - (~ I -~ GAS LIFT SURVEY 9 71 02 5 I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONS E RVATI ON COMMISS I ON 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 6, 1997 Michael Zanghi Drilling Superintendent ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3Q-08A ARCO Alaska, Inc. Permit No. 97- 193 Sur. Loc. 2241'FNL, 2207'FEL, Sec. 17, T13N, R9E, UM Btmnhole Loc. 131'FSL, 2057'FEL, Sec. 07, T13N, R9E, UM Dear Mr. Christenson: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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. Blo~vout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling nexv hole. Notice mav be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson Commissioner BY ORDER OF THE COMMISSION dlffEnclosures cc; Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA OIL AND GAS CONSERVATION OOMMIS,b,~N PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill Redrill X I b Type of Well Exploratory I--I Stratigraphic Test [] Development Oil X Re-Entry ~1 Deepen D Service D Development Gas r"l Single Zone X Multiple Zone D 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 54', Pad 22' feet Kuparuk River Field 3. Address 6. Prope_rty_Designatio_n. Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL~, ALK 3574 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 2241' FNL, 2207' FEL, Sec. 17, T13N, RDE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 287' FSL, 1845' FEL, Sec. 07, T13N, RDE, UM 3Q-08A #U-630610 At total depth 9. Approximate spud date Amount 131' FSL, 2057' FEL~ Sec. 07~ T13N~ RDE~ UM 10/07/97 $200~000 1 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) properly line 3Q-09 9651' MD 287' @ Tar~let feet 25' @ surface feet 5580 6474' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 7870' feet Maximum hole angle 59.9° Maximum surface 2555 psig At total depth (TVD) 3250 pslg 18. Casing program Settinc, I Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length IVlD TVD 1~3 'I-VD (include stage data) 6-1/8' 3-1/2' 9.3# L-80 BTC-mo¢ 1931' 7720' 5410' 9651' 6474' 359 sxs Class G 1 g. To be completed for Reddll, Re-entry, and Deepen Operations. [ ~ '~ Present well condition summary Total depth: measured 9 40 0 feet Plugs (measured) ~..~ ~)~.;; [ ., true vertical 657g feet ~,.- -~. Effective depth: Iruemeasuredvertica 92816493 feetfeet Junk (measured) I:~S~ casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 8 0' 1 6 ' 1875# Poleset 1 15' 1 15' Surface 4898' 9-5/8' 1200 sx ASIII, 325 sx AS I 4935' 3726' Intermediate Production 9326' 7 ' 175 sx AS I, 630 sx Class G 9361 ' 6551' Liner Perforation depth: measured 9084'-9116' MD true vertical 6349'-6373' TVD 20. Attachments Filing fee X Property plat [] BOP Sketch X Diverter Sketch [~ Drilling program X Ddlling fluid program X Time vs depth plot ~ Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21. I here~y certify that the foregoing is true and correct to the best of my knowledge (Contact William Isaacson at 263-4622 with questions.) // "Title Drillin~ Superintendent Date ~ Commission Use Only' Perm, Number I APl number I Approval date I See cover letter for <~'7 -~//?,~ 50-d~2_,,~--- ~.,/~ ~,/- O~ /~--~'"'~"Z other requirements Conditions of approval Samples required r'~ Yes J~] No Mud iog required r-~ Yes ,,~ No Hydrogen sulfide measures ~ Yes D No Directional survey required ~ Yes E] No Required working pressure forBOPE r'l 2M ~ 3M D 5M [~ 10M [-1 15M Other: by order of Approved by Commissioner the commission Date Fnrrn 10-401 R~.v 7-24-R.q trinlic.~t~. REDRILL PLAN SUMMARY Well 3Q-08A Type of well (producer/injector): Surface Location: Target Location- Bottom Hole Location- MD- TVD: Rig: Estimated Start Date- Operation Days to Complete: Producer 2241' FNL, 2207' FEL, SEC 17, T13N, R9E, UM 287' FSL, 1845' FEL, SEC 07, T13N, R9E, UM 131' FSL, 2057' FEL, SEC 07, T13N, R9E, UM 9651' 6474' Nordic Rig 2 10-07-97 11 Drill Fluids Program: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Milling Window in 7" casin~] 9.6 >25 15-35 85-95 20-30 30-40 .. 8.5-9.5 Kick off to weight up 9.6-9.7 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.2 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Swaco Geolograph Adjustable Linear Shaker Brandt SMC-10 Mud Cleaner Triflow 600 vacuum Degasser, Poor Boy Degasser Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators and Jetting Guns Notes: 'Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Page 1 Casing/Tubing Hole size 6-1/8" Program: Csa/Tba -- -- 3-1/2", g.3#, L-80, BTC-Mod Tubing $-1/2", 9.3~, I.-80, EUE-Mod Length Too (MD/TVD) Btm (MD/I'VD 1931' 7720'/5410' 9651 '/6474' 7691' 29Y 29' 7720Y 5410' Cement Calculations: Casina to be cemented: 3-1/2" in 6-1/8" open hole Volume = 359 sxs of class G Blend @ 1.19 cu ft/sx Based on: Shoe volume, open hole volume + 53%, & 150' liner lap. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated surface pressure is estimated at 2,555 psi and is calculated using a gas column to surface. The expected leak-off at the window cut in the 7" casing is estimated at 14.0 ppg EMW. With an expected formation pressure in the Kuparuk of 3250 psi and a gas gradient of 0,11 psi/fi, this shows that formation breakdown would not occur before a surface pressure of 2,555 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3500 psi. See attached BOPE schematic. Drilling Hazards: Lost Circulation: Overpressured Intervals: Other Hazards: The suspect lost circulation zones throughout the Kuparuk field are the K- 10 and the K-5 intervals. The sidetrack 3Q-08A, will kick off out of the 7" casing below both the K-10 and K-5 intervals. The 7" casing has good quality cement up to and above the planned kick-off window, which should isolate the K-10 and K-5 from the sidetrack operations. If the Formation Integrity Test shows that the K-10 and K-5 intervals are not isolated and will not hold the desired equivalent mud weight, a cement squeeze at the window could be performed to help isolate these intervals. Off-set ddlling data shows that wells in the area of 3Q-08A have been ddlled to TD with 12.0 ppg mud and no loses. The kick-off point in 3Q-08A is below any zones which would be of pressure concem prior to weighting up for the Kuparuk interval. None Directional- KOP: Max hole angle: Close approach: 7870' MD / 5512' TVD 59.9° (in sidetrack portion) No Hazards Page 2 62.25° (in original portion) Loqqinq Program: Open Hole Logs: GR/Resistivity Cased Hole Logs: GR/CCL Notes- All drill solids generated from the 3Q-08A sidetrack will be hauled to CC-2A in Prudhoe Bay for gdnd and inject. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or to Parker 245 to be disposed by annular pumping into the permitted annulus Parker is connected to at that time. The permitted well will be within the Kuparuk River Unit. Page 3 KRU 3Q-08A GENERAL SIDETRACK PROCEDURE PRE-RIG WORK: . RU CTU. RIH with inflatable cement retainer on CTU. Set inflatable in 2-7/8" tubing tail immediately below production packer. Mix cement. Circulate the cement down coil to immediately above circulating valve on top of retainer. Close circulation valve and down-squeeze cement below retainer into A Sand perfs. Use sufficient volume to fill tubing down through tubing tail and 7" casing from top of fill to tubing tail, plus excess to squeeze away into perfs if possible. Unsting from retainer and circulate well clean on top of inflatable retainer. RDMO CTU. 2. RU slickline unit. Pull dummy valve from bottom GLM at 8873' MD RKB, leaving an open pocket. WO . 10. 11. 12. RKOVER RIG WORK: 1. MIRU Nordic Rig. Lay hard-line to tree. 2. Vedfy well is dead. Load pits w/water. Circulate well to water. 3. Pressure test wellbore to 2500 psi testing cement squeeze and retainer, to ensure isolation from perforations. Set BPV. 4. ND tree. NU and test BOPE. 5. Screw in landing joint. Pull tubing hanger to dg floor. POOH laying down all 2-7/8" tubing. 6. RU E-line unit. Run gauge dng through bddge plug setting depth. RIH and set permanent bridge plug at 7896' MD-RKB. Test 7" casing above bridge plug to 3500 psi. 7. MU and RIH with bottom trip whipstock and window milling assembly. Tag bddge plug and set down weight to set whipstock. Shear free with milling assembly, circulate well to milling fluid, and mill window in 7" casing. POOH LD milling assembly. 8. RIH w/6-1/8" bit, mud motor, MWD / LWD, and steerable drilling assembly. Slide out window, kick-off well, and directionally ddll to total depth as per directional plan. Short tdp to window in casing. POOH. Run 3-1/2" liner to TD w/150' of ovedap to top of milled window. Cement liner. Set liner hanger and liner top packer. POOH w/DP. Pressure test casing and liner lap to 3500 psi for state test. RIH w/completion assembly and sting into polished bore receptacle at top of liner. Space out. Displace well to sea water at max rate. Test tubing and annulus. 13. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic. 14. Clean out well to PBTD w/coiled tubing. Perforate through tubing. Lower Limit: 9 days Expected Case: 11 days Upper Limit: 17 days No problems milling window, ddlling new hole, or running completion. Difficulties encountered milling window, or drilling new hole. WSI 7/8/97 Page 4 Greeted by finch For: B ISAACSON D~te plotted: 2-Oct-97 Plot Reference is 8A Version ¢6. 5550 5700 5850 6000 6150 6300 Structure : Pod 5Q : gA Field : Kuporuk River Unif h Slope, AloskoI <- West (feet) 5250 51 O0 4950 4800 4650 4500 4350 4200 4050 3900 3750 3600 { I t I I I I I I I I I I I ] I I I I I [ I 233.68 AZIMUTH 2465' (TO TARGET) ***Plone of Proposol*** TARGET LOCATION: 287' FSL, 1845' FEL SEC. 7, T15N, RgE TARGET TVD=6322 TMD=9347 DEP=2465 NORTH 287 WEST 71 25 ./ K-1 Morker.-/ / /- T/ Unit D /'/' T/ Unit C4,~-~'Terget - T/ A1 Intervol ./ B/ Kuporuk./ TD LOCATION: 1.31' FSL, 2057' FEL SEC. 7, T13N, R9E 5250 ~ 5400 K0P - SIDETRACK PT TVD=5512 TMD=?870 I)EP=1304 k 47.35 47.35 ,... 48.64 DLS: 9.00 deg per 100 ft kk"--%. 51.11 "-,~ 54 60 ~ ""-. 'sas9 AVERAGE ANGLE . -......' EOC TVO=5~s T~0=~42~ 0~=16~4 59.93 DEG '""-~. B/ HRZ TVD=6098 TMD=8900 DEP=2078 '""-.~ K-1 MARKER TVD=6197 TMD=g098 DEP=2249 ~ ""'-.. T/ UNIT D TVD=6298 TMD=9299 DEP=2424 -. T/ UNIT C4 TVD=651 6 TMD=9335 DEP=2455 TARGET -T/ A1 INT'kTVD=6322 TMD=9347 DEP=2465 '~. '"-... B/ KUP TV0=6374 TMD=9451 0EP=2555 6450 ~ '"'%~ TD - CSG PT T'CD=6474 TMD=965t DEP=2728 6600 [ t , , , , ~ , ] ~ , , [ , ] , , ~ , ~ , , , , , 1050 1200 1350 1500 1650 1800 1950 2100 2250 2400 2550 2700 2850 Vertical Section (feet) -> Azimuth 2.55.68 wffh reference 0.00 N, 0.00 E from slot #8 3450 3300 3150 3000 Z 0 --i- 2850 2700 --I-- v 2550 2400 2250 7-1/16" i . 5000 PSI BOP STACK ~ 6 PIPE RAM ~, I I · I F-- ~ 5 BLINDRAM~ I b I ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURETHAT 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. BO P STACK T EST 1. FILL BOP STACK AND MANIFOLD WITH WATER 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THATTEST 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 5 MINUTES. INCREASE PRESSURE TO 3500 PSI AND HOLD FOR 5 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND INSIDE MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS, HCR VALVE ON CHOKE LINE, AND OUTSIDE MANUAL VALVE ON KILL LINE. 6. TEST TO 250 PSI AND 3500 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3500 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'I-I'OM PIPE RAMS. TEST BO'I I'OM RAMS TO 250 PSI AND 3500 PSI. 9. OPEN PiPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10. CLOSE BLIND RAMS AND TESTTO 3500 PSI FOR 5 MINUTES. BLEED TO ZERO PSI. 11. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 12. TEST STANDPIPE VALVES TO 3500 PSI. 13. TEST KELLY COCKS AND INSIDE BOP TO 3500 PSI WITH KOOMEY PUMP. 14. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 15. PERFORM COMPLETE B©PE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1.11" - 3000 PSI CASING HEAD 2.11"- 3000 PSI x 7-1/16" 5000 PSI TUBING HEAD 3.7-1/16" o 5000PSI SINGLE GATE W/PIPE RAMS 4. 7-1/16"- 5000 PSI DRLG SPOOL W/CHOKE & KILL LINES 5.7-1/16"- 5000 PSI SINGLE GATE W/ BLIND RAMS 6. 7-1/16"- 5000 PSI SINGLE GATE W/PIPE RAMS 7.7-1/16"- 5000 PSI ANNULAR PREVENTER NORDIC RIG ~ LEVEL I z 73'-0' 25'-0' STAIRS EMSCO F-800 (~.j TRIPLED( MUD z LiJ 12'-4.' -- 28'-6" ~TIRES: 40-57 I EMSCO f-800 I (~ TRIPLEX MUD PUMP SPIRAL . STAIRS CONTROL JCONSOLE 53'--0' .d REMOVABLE BOP ENCLOSURE 1NORDIC RIG g2 LEVEL 2 HOiSt NORDIC RIG g2 LEVEL 3 UN~' SPOOL USq'ER AIR HEATER MUD TANK 750 BBLS HYDRAUUC CHOKE MANIFOLD OF~CE WATER TANK /GLYCOL TANK 24.--G~ 84'-0' 12Y 1 · WELL PERMIT CHECKLIST COMPANY, .~L.-,,~ FIELD & POOL c.//74:~/~>(;::) INIT CLASS / --o,,',/) GEOL AREA o¢/~_,) UNIT# .////~_-.) ON/OFF SHORE ADMINISTRATION . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11 ~3. Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. · Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Y N N N N N N N N N N N N ENGINEERING 14. Conductor string provided .................. Y N 15. Surface casing protects all I~nown USDWs ........... Y N ~ 6,~~.. 16. CMT vol adequate to circulate on conductor & surf csg ..... Y N 17. CMT vol adequate to tie-in long string to surf csg ........ ,.~ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... ~ '- 24. Drilling fluid program schematic & equip list adequate ..... (_~ N 25. BOPEs, do they meet regulation ......... .~ ...... (~ N 26. BOPE press rating appropriate; test to '~~ psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ ,.,. N 28. Work will occur without operation shutdown ........... ~ N 29. Is presence of H2S gas probable ................. ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... y N_~ ,4/~, ,¢¢ 31. Data presented on potential overpressure zones ....... ~N ./~ .,,7-/ ~ 32. Seismic analysis of shallow gas zones ............. . 33. Seabed condition survey (if off-shore) ............ ./Y N 34. Contact name/phone for we.ekly Droaress reports ...... /. Y N lexplora'tory only] / REMARKS GEOLOGY: ENGINEERING' COMMISSION: JDH ~ RNC~ co Comments/Instructions' HOW,'ljt- A:\FORMS\cheklist rev 09/97 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. Sperry-Sun Drilling Services LIS Scan Utility Thu Dec 11 12:50:45 1997 Reel Header Service name ............. LISTPE Date ..................... 97/12/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/12/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record 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 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 2 AK-MW-70303 T. FLYNN B. MORRI SON 3Q-08A 500292168101 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES il-DEC-97 10 13N 2241 54.00 52.60 24.00 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 7.000 7866.0 3.500 9634.0 7896.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND BILL ISAACSON OF ARCO ALASKA, INC. ON 28 OCTOBER, 1997. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9634'MD, 6468'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 7845.0 9581.5 FET 7865.0 9588.5 RPD 7865.0 9588.5 RPM 7865.0 9588.5 RPS 7865.0 9588.5 RPX 7865.0 9588.5 ROP 7898.0 9633.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 7898.0 9634.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD AAPI 4 1 RPM MWD OHMM 4 1 ROP MWD FT/H 4 1 RPX MWD OH/~M 4 1 RPS MWD OHMM 4 1 RPD MWD OH/~M 4 1 FET MWD HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 7845 9633.5 8739.25 GR 39.6495 524.444 134.687 RPM 1.205 26.4124 4.62407 ROP 2.3886 270.703 81.9254 RPX 1.3744 26.3359 4.32366 RPS 1.3562 26.6841 4.48285 RPD 0.5245 28.3524 4.79897 FET 0.5977 24 1.81754 First Last Nsam Reading Reading 3578 7845 9633.5 3474 7845 9581.5 3448 7865 9588.5 3472 7898 9633.5 3448 7865 9588.5 3448 7865 9588.5 3448 7865 9588.5 3448 7865 9588.5 First Reading For Entire File .......... 7845 Last Reading For Entire File ........... 9633.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7845 . 0 9581 . 5 FET 7865 . 0 9588 . 5 RPD 7865 . 0 9588 . 5 RPM 7865 . 0 9588 . 5 RPS 7865 . 0 9588 . 5 RPX 7865 . 0 9588 . 5 ROP 7898 . 0 9633 . 5 $ LOG HEADER DATA DATE LOGGED: 20-OCT-97 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: DEPII 2.17F DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : ~9634.0 TOP LOG INTERVAL (FT): 7898.0 BOTTOM LOG INTERVAL (FT): 9634.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 49.9 MAXIMI/M ANGLE: 61.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): TOOL NUMBER P0717SP4 P0717SP4 6.000 6.0 LSND-HT 9.60 56.0 MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHM/4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9.0 1900 5.0 1.600 .000 1.200 2.100 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHMM 4 ! 68 12 4 RPM MWD 2 OHMM 4 1 68 16 5 RPD MWD 2 OHMM 4 1 68 20 6 ROP MWD 2 FT/H 4 1 68 24 7 FET MWD 2 HOUR 4 '1 68 28 8 142.0 First Name Min Max Mean Nsam Reading DEPT 7845 9633.5 8739.25 3578 7845 GR 39.6495 524.444 134.687 3474 7845 RPX 1.3744 26.3359 4.32366 3448 7865 RPS 1.3562 26.6841 4.48285 3448 7865 RPM 1.205 26.4124 4.62407 3448 7865 RPD 0.5245 28.3524 4.79897 3448 7865 ROP 2.3886 270.703 81.9254 3472 7898 FET 0.5977 24 1.81754 3448 7865 Last Reading 9633.5 9581.5 9588.5 9588.5 9588.5 9588.5 9633.5 9588.5 First Reading For Entire File .......... 7845 Last Reading For Entire File ........... 9633.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/11 Maximum Physical Record..65535 File Type ........... ~ ..... LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/12/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/12/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
