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184-194
ect Well History File Coverage XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J 4~y- J ¢ y Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [:3 Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [3 Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: NOTES: D : Logs of various kinds BY: ~EN Project Proofing BY: VINCENT SHERYL MARIA LOWELL BEVERLY BRE~ SHERYL MARIA LOWELl_ Scanning Preparation BY: BEVERLY BREN~~SHERYL MARIA LOWELL [] Other DATE: 7" ~ /SI DATE: r DATE: Isl~ TOTAL PAGES //~-'~7 Production Scanning f Stage I PAGE COUNT FROM SCANN ED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~z~"~ES NO BY: ~BREN VINCENT SHERYL MARI~ LOWELL Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: BEVERLY BREN VINCENT~ARIA LOWELL DATEW/~! (SCANNING IS COM~E~ AT ~IS ~ U~ S~C~ A~ENT~N ~ REQUIRED ~ ~ ~D~UAL PAGE BAS~ DUE TO ~, I ReScanned (individual page [special attention] scanning completed) RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ISl General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd KRU 2W-06 (PTD# 184-194) R~rt of TxIA Communication • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Wednesday, June 24, 2009 9:32 AM To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Jackson, Darron B. Subject: KRU 2W-06 (PTD# 184-194) Report of TxlA Communication Attachments: 2W-06 Wellbore Schematic.pdf; 2W-06 TIO Plot.pdf Jim/Tom, Kuparuk gaslifted producer 2W-06 (PTD# 184-194) is suspected of having TxIA communication based upon a failed TIFL. A leaking gaslift valve is sus ected so slickline will troubleshoot and repair if possible. The well is currently shut in due to t e CPF2 shutdown and will remain so until the TxIA communication can be repaired. The well will also be add to the SCP report. Attached are a wellbore schematic and 90 day TIO plot. «2W-06 Welibore Schematic.pdf» «2W-06 TIO Plot.pdf» `~ Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Weils Supenrisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 RI1~' ^~s~ 2 6.~~> ... ~'y'k~~~~P hl ~ l v _ / 4 V'.'f 8/31 /2009 Date 7/1 /2009 ~ 90 : Date 4!2/2009 ,soo 1400 1200 1000 ~Q 800 soo 400 200 0 Annular Communicaton Surveillance WHP ~ -- - IAP OAP _ - - - _. WHT Apr-09 May-09 Jun-09 ------, ~ooo ~DGI sooo ~MGI 0 5~ ~PWI m aooo ~SWI ' d 3~ ~BLPD U f 2000 1000 - 0 iso 140 120 100 LL 80 y a so 40 20 0 • • Apr-09 May-09 Jun-09 Date ~ ~~ ~ Cc~~~~~P~il~i~+;s ~-~~~~c~, ~~~. KRU 2W-06 ~uu=t~~. ~, , ~ ~~, ~ ~~:, . ~~~~ ,. ~ = ~~ ._ ~ ~~ r~ ~ ~ : ~,~~ ___ API: 500292121100 Well T e: PROD An le TS: 39 de 6802 SSSV Type: LOCKED OUT Orig 11/8/1984 Angle @ TD: 37 deg @ 7400 sssv ~~aoaiaoi, Com letion: OD:3.500) Annular Fluid: Last W/O: 11/21/1987 Rev Reason: TAG, OPEN SLEEVE, set OV Reference Lo : Ref Lo Date: Last U ate: 10/13/2007 Last Ta : 7234 SLM TD 7400 ftK6 ~ Last Ta Date: 9/7/2007 Max Hole An le 44 de 4800 ~ ~r~~_:_. ~"_ ~~~ ~ ~. ~ ~~~ '~°~,~ ~:~ ~t~~ Ia ~~ ' ~: N~~~~ ~ E~i~ ~' ~".~ ~a'~" ~ ~ '~`~ ~w.:: Descri tion Siz e To Bottom N D Wt Grade Thread CONDUCTOR 16.000 0 92 92 62.50 H-40 SUR. CASING 9.625 0 3796 3555 36.00 J-55 ~ PROD. CASING 7.000 0 7393 6259 26.00 J-55 °`fu~}iFt, ,~St~`~k~# =;`~'l1~IN~'`a i ,~' ~; - '~ ° ~,~ ~ ,t '_~~~ _ ,;;~ ~~ Size To Grede Bottom ND Wt Thread ~~ 3.500 0 6955 5911 9.30 J-55 EUE 8RD AB MOD ~ ~ ~ ~~, ~ r~ ~ ~, ~ ~i~TB S'*~~~ ~ E : ~r -- ~it:~~~E, ~ _~., ~,~-~i ~ n~~ ' ~ ra.,..E,~I =~ _ - _ _ ,~ , ~n ~~ 4~ ~ ~ ' _ Interval TVD Zone Status Ft SPF Date T e Comment 6803 - 6897 5793 - 5866 -4 C-3 C-1 94 12 12/16/1984 IPERF 5.5" SOS HJ II, 120 de . h I 7063 - 7074 5996 - 6005 A-4 11 4 12/16/1984 IPERF 4" SOS HJ II 90 de . h 7085 - 7112 6013 - 6035 A-3 27 4 12/16/1984 IPERF 4" SOS HJ II 90 de . h 7114 - 7118 6036 - 6039 A-3 4 4 12/16/1984 IPERF 4" SOS HJ II 90 de . h 7193 - 719 6 6099 - 6101 A-2 3 4 12/16/1984 IPERF 4" SOS HJ II 90 de . h ~ ~I~t ~ ~ ,: ,~,~ ~, , ~ . -_ ~ r ~~ ~ ~ v, ~~r~l~~l~i~s=° = t,~. _ fi r .~. ° a~~ ~ ~.~ rya. .. ~ ~ __ ~ ,. .. ~_ ~ ~ ~ ~ .__ r ~~~~ .,~ ~ . , ~' ~ St MD TVD Man Mfr Man Type V Mfr V Type V OD tatch Port TRO Date Run Vlv Cmnt 1 1875 1875 Camco KBUG GLV 1.0 BK 0.156 1255 9/6/2005 1 ~.` 2 2834 2808 Camco KBUG GLV 1.0 BK 0.188 1285 9/6/2005 ' 3 3421 3282 Camco MMG-2 GLV 1.5 RK 0.188 1205 9/6/2005 4 3945 3663 Camco KBUG OV 1.0 BK 0.250 0 9/8/2007 5 4420 4010 Camco KBUG DMY 1.0 BK 0.000 0 12/16/198 ~_ _~ - 6 4924 4378 Camco KBUG DMY 1.0 BK 0.000 0 8/2/2003 7 5546 4833 Camco MMG-2 DMY 1.5 RK 0.000 0 7/12/1997 pgR 8 6047 5210 Camco KBUG DMY 1.0 BK 0.000 0 8/4/2003 (6591-6592, 9 6547 5594 Camco MMG-2 DMY 1.5 RK 0.000 0 8/2/2003 OD3.5oo) 1. NOTED HEAW SCALE _. ~ ~ ~~~, ,' ~, ,~ :~ ~~~~ ~q~ , ~ ~ ~ ~ ~~,~ F~~'oCl~~~~n 1s~1~` d~'~~11/atu~~ ~ ~ . ~= ? ~~~d ~ ' PKR (sso5~sos, . St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv OD:6.151) Cm nt 10 6643 5668 Camco KBUG DMY 1.0 BK 0.000 0 7/20/1997 Closed 11 6712 5722 Camco KBUG MACCO DMY 1.0 BK 0.000 0 2/16/2001 Closed " t~ ~'1` Il~ ~ _ ~ : ~ -;~~ . ~ G ; ~.- , ~ ~j ~ ~ ~ ~~ aj ~ue ~~`~ ~y , _ 4 ~ De th TVD T e . D . escrl tion ID ~ 1800 1800 SSSV Baker'FVL' Locked Out 10/21/94 2.812 6591 5628 PBR Baker 2.992 6605 5639 PKR Baker'FHL' 3.000 - -- 6915 5880 SLEEVE-O Otis'XA' Slidin Sleeve w/'X' Profile. 11/14/99 - OPEN 9/8/2007 2J50 ----- - --- 6928 5890 NIP Otis'XN' Ni le w/ NO GO 2.635 6935 5896 PKR B k 'FB 1' 3 000 SLEEVE-O er - a . (6915-6916 6Q4J 5907 NIP o'D' Ni le NO GO C 2 750 , o~:a.aao~ 6954 5910 SOS amc Baker . 2.992 NiP 6955 5911 TTL TTL ELMD 6950' ON SWS PPROF 1/8/2007 2.992 cssza-sszs, ~i~~ ,: FIS~ F~ = ~ ~ ~~;-. r 4~," ~ ' ,~ ,4~~~ .,.'~ ~ ~y~~ , ~ =- ~ ,,,~~ ~ ~~ oo:s.5oo) ~ De th ~ Descri Comment tion I PKR 7125 Latch Parts f/ DMY Lost in Well 7/15/1994 ~ssse~sas, = 7265 1.5" DMY w/ RK Latch Dro ed in rathole 8/2/2003 OD:6.151 ~ ;€z ~y #~ ~. .` r , = i ~ ~~ > A n- r~ ~ ~ a .~-~ i = 7 ~" rP ~ ~ ~.'.. ~~SF.~~~~Y~~ :~~"' '~ ... ;- .-` I, ~ ~~ `'~»:. ~ ~ ~ ~ ~ - Date Note NiP (ssas-ss5o 5/9/2004 NOTE: WAIVERED WELL: IAx OA COMMUNICATION , OD3.500) BI G TU N - (0-6955, - OD3.50Q ID2.992) ___.._ Perf .... - --- ...._.__.. (7063-7074) .._ .. _._-_ I PeR ~ (7085-7112) I Pert -........ - - -- (7114-7118) ~ Pert (7193-7196) ..__.._..._. _ _ __..__. i ~ 05/12/09 .~ ~r~~llf~~i!- Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~, ,$ rin• ~~j~~, Well Job # ~ ~ ~~~ ~~. ' n -~ ' .~ MAY ~ ~ ~OG9 ~la~~a iii ~ has ~Oh~. ~rr~s~~~~r~d ~~~hvr~~~ Log Description NO. 5228 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 3A-18 AYS4-00069 PERF/SBHP SURVEY 6 04/26/09 1 1 3C-08 6148-00033 GLS s ! 04/21/09 1 1 2M-25 6148-00034 GR/TEMPLOG 19/- 04/22/09 1 1 1R-19A AYS4-00065 SBHP SURVEY -r C', `~ 3fo 04/23/09 1 1 3G-13 AYS4-00067 SBHP SURVEY - ( 04/24/09 1 1 3G-05 AYS4-00066 SBHP SURVEY 04/24/09 1 1 3F-07 8146-00038 SBHP SURVEY - ~ 04/24/09 1 1 3F-08 6148-00037 SBHP SURVEY 04/24/09 1 1 3M-25A 6146-00040 SBHP SURVEY 3 04/25/09 1 1 3K-08 B14B-00039 SBHP SURVEY C/ 04/25/09 1 1 2N-318A AWJI-00026 MEM BHP SURVEY -(~ 04/27/09 1 1 2Z-07 6148-00045 SBHP SURVEY L 04/29/09 1 1 2Z-01A B14B-00044 SBHP SURVEY ~-~ ~ 04/29/09 1 1 3K-102 ANHY-00080 GLS 04/30/09 1 1 2W-06 B04C-00036 PRODUCTION PROFILE 05!02/09 1 1 2W-12 604C-00037 PRODUCTION PROFILE - p 05!03/09 1 1 3C-02 B04C-00045 POWERCUTTER W/SBHP SURVEY- 05/09/09 1 1 1 J-120 B04C-00043 GLS - ~ Q O 05/08/09 1 1 31-11 B04C-00044 SMALL TBG PUNCH W/SBHP 05/08/09 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. r: ~~~ • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 5, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~. L{~~~~ MAR ~ ~.~ 2UG ~: -. - ~~_; , _, .~~~~ ~~~ ~ ~ ~,~ Dear Mr. Maunder: 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 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 January 18th and January 24th, 2009. The corrosion inhibitor/sealant was pumped February 21St through February 23rd , 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. Sincerely, ii ~%~~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/5/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2U-01 185-004 50' 5.90 3'1" 1/18/2009 9.2 2/22/2009 2U-02 185-005 6' 1.20 22" 1/18/2009 3.4 2/22/2009 2U-03 185-006 34' 7.90 2' 1/18/2009 7.4 2/22/2009 2U-05 185-018 40' 6.50 3'5" 1/18/2009 9.4 2/23/2009 2U-06 185-019 54' 7.00 2' 1/18/2009 7.1 2/23/2009 2U-07A 185-091 6' 0.70 2'2" 1/18/2009 4.5 2/23/2009 2U-08 185-021 80' 11.40 2'10" 1/18/2009 5.2 2/23/2009 2U-09 185-038 12' 1.50 22" 1/18/2009 3.6 2/23/2009 2U-10 185-039 6' 0.80 22" 1/18/2009 3.5 2/23/2009 2U-12 185-041 18'6" 2.70 22" 1/18/2009 3.1 2/23/2009 2U-13 184-246 45' 6.50 2' 1/18/2009 5.9 2/23/2009 2U-14 184-247 22' 4.20 22" 1/18/2009 6.1 2/23/2009 2U-15 184-248 26' 3.90 2'2" 1/18/2009 3.6 2/23/2009 2U-16 184-249 64' 8.40 5'2" 1/18/2009 14.8 2/23/2009 2W-01 185-010 27' 3.50 3'9" 1/18/2009 5.2 2/21/2009 2W-02 185-016 12' 6.50 5'9" 1/18/2009 12.3 2/21/2009 2W-04 185-012 55' 8.10 5'4" 1/18/2009 15.1 2/21/2009 2W-05 184-191 22' 2.90 2'3" 1/18/2009 7.6 2/21/2009 2W-06 184-194 16" NA 16" NA 1.4 2/22/2009 2W-07 184-204 56' 6.60 21" 1/24/2009 5.6 2/22/2009 2W-09 184-219 16" NA 16" NA 3.4 2/22/2009 2W-11 184-222 49' 6.00 4'3" 1/18/2009 10.5 2/22/2009 2W-12 184-224 64' 10.00 22" 1 /24/2009 2.1 2/22/2009 2W-13 184-236 6'6" 6.00 23" 1/18/2009 5.2 2/22/2009 2W-14 184-237 20'4" 3.30 22" 1/18/2009 3.7 2/22/2009 2W-15 184-238 41' 7.10 2'10" 1/18/2009 3.9 2/22/2009 2W-17 207-135 8" NA 8" NA 1.1 2/22/2009 SCANNED Jt\N 3 () 2007 01/24/07 Schfumbel'gel' NO. 4121 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ~I/\N 2'. 9 ZOO7 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 r1.1, Field: Kuparuk I~LI- / ~ [( Well Job# Log Description Date BL Color CD 1 C-111 11415647 RST WFL 10/29/06 1 2B-01 11536780 PROD PROFILE 01/04/07 1 2H-11 11539477 PROD PROFILE 01/04/07 1 2B-02 11538781 PROD PROFILE 01/05/07 1 3N-19 11538782 PROD PROFILE 01/06/07 1 2W-06 11538784 PROD PROFILE 01/08/07 1 1C-28 L 1 N/A GLS 01/16/07 1 2M-06 11628958 INJECTION PROFILE 01/20/07 1 1 C-117 11628954 INJECTION PROFILE 01/18/07 1 2K-16 11638814 PRODUCTION PROFILE 01/22/07 1 1Y·22 11638815 PRODUCTION PROFILE 01/23/07 1 2N-337A N/A SBHP SURVEY 01/21/07 1 2M-26 NIA SBHP SURVEY 01121107 1 2M-03 NIA INJECTION PROFILE 01/22107 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . ) ¡'re~ ~"I,"·J I ' L~ FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GJ\S CONSERVATION COMMISSION 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276·7542 November 9, 2005 Mr, Paul Dubuisson Kuparuk Field Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 \'6lþ-1Q'f Qw-oh Dear Mr. Dubuisson: The Alaska Oil and Gas Conservation Commission ("Commission") performed an inspection of your well safety valve system (SYS) at Kuparuk'River Unit 2W ("KRU 2W") pad on October 2, 2005. Attached is a copy of the Inspection Report. Regulation at 20 AAC 25.265 in conjunction with Conservation Order 348 requires all wells in the Kuparuk River field to be equipped with a Commission approved fail-safe automatic surtàce SYS capable of preventing uncontrolled flow by shutting ofT flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS con1ponent failure rate of 15 percent was identified during the above-noted inspection. Commission test interval requirements provide that the testing frequency will be increased when a tàilure rate exceeds 10 percent. Eflective October 2, 2005 and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2W must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector (907-659-2714) at least 24 hours in advance to provide an opportunity to witness the SVS test. Sincerely, ,--;-' ,-¡ ,--; ~'111(!.¡ b. 1\ "1°(, ' James B. Regg , Petroleum Inspection Supervisor Attachment cc: AOGCC Inspectors ,',' 1 ')IJG~ ,. "\("0\) t '- ~~f:J/ \~ . - Safety Valve & Well Pressures Test Report Reviewed By: P.I. Suprv Comm Pad: KRU_2W Insp Dt 10/2/2005 Inspected by John Crisp Interval 90 Days InspNo svsJCrû510042û4247 Field Name KUPARUK RlVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Bob Noble Related Insp: Reason 180-Day Src: Inspector [~-----jJ-;eITD~-'~--- -'-l- - - -P/ìoïs---------l--SSV~I'SSSJl-Sh~ff;D'r---H/~i¡i)p;-l'-~ -- Jr;¡ip;;s~~re~--l-Gas-iif¡r;J>llit;~~¡-'~'-' c--COi!!;~/__;Ú- Well Permit Separ Set LIP Test Test Test Date Sl Oil, WAG,GINJ, Inner Outer Tubing Number Number PSI PSI Trip Code Code Code GAS,CYCLE,5I PSI PSI PSI YeslNo Yes/No - ---i~OI------ --1850Úio'-9s----70--- -6S-----P-'--p-,------ -- -------T:ÜÍC--- 14ÒÜ-u 720---23-0- --U-yes-----~s-rIA~OA- _u_______ ~--_~\V~ --- -i850IIÕ-- - _i5~~_~7~ _~____~ ~-==-p~:=-_-=-=_-u_=---=-__I-C?I£~__-_T~~--_-=~-~-_=~_-=-=-~=~:~~~_=~=-=-_:-=_~~=--~=-_=-=-=~=-= -=-_~=u= 2W-05 1841910 2650 2000 2000 P P WAGJN - _._---~-- ---. --- ~--------- ------ ----~---_._--~---~--~---- -.--- --- _._---_._--~--------_.._-------- ~-- .-- -------_.------ ------~- -------------------- --- ----._--_. - -- ---- r- - 2W-06 1841940 95 70 65 P P ¡ I-OIL 1250 i 1000 230. Yes , Yes IA x OA ¡ 'i~~¡I-n_- - ~:iiió ___n_:~__ -~6------~}--_I; ~ -~-------- ---u~~âit--- - _30_~__~~_~___,_25~+--NO-~-j--ì'~- ~A_~~A_ ,--- --,--------! - ~~:: ~ ~_ ¡ :~~j:t~F ~E ~F-}~ -~ _ ~~n~ :-::~lt:_:-- -. - -- _--- I=- -.. ~:-1: - - -::~~-:--------J 2W-J4 1842370 2650 2000 0 10 4 WAGlN ! --- ------. - ------ ._----, -- ~._----------- -._---- --. -- ---.----------------.----- -------------- - ----------,~--- ------_._-~--_._-----_._- ----~. ---- ~---~---- _.-----------~_.- -- --------- ~. _2~?___ _J~~2~~_ __95 __ _~~___~g___P ____ ~_______________~ ______!-OIL__nL~40~____~~__~____2~___ :(es ~~~<?~__ _______ _______~ .~ Comments Performance -~-- .----- ----- -------- -- ---_.~-- ---------- Wells Components Failures Failure Rate __J9___ __ _,_2º-__ __ _..~ __________~'Yº_____ - - ---~----~ -. -- ----- .----- ---- - --. ---- ---- ._- - - -- -- ------. ~' if" t! ~ f\ U P ti 'Iã" f Wednesday, October 05,2005 Kuparuk Well Pressure Report Well ? ~)- ~.0 Date ////]///~ ~ Key Well ~ Satisfies / t ~h State r-I Yes U].Yes [-I No '-' ~ . . :~: ~ .::~,..,:-: ~.. Requirement :?:..s®rvio. Company ~ '~ [] No Pressure Measurement Device: ~:~?E]HP i~,AMERADA t-ILYNES F'lTorque Turn Instrument Identification No.: (Upper Bomb) -- (Lower Bomb) .~"o~.~i Type of Test: !~Static r-I PBU TVD- SS. Calibration Date: '~-' ..... . - ' .")~: . , . Datum 'l'imed .~. Pressure ~¢: TVD-S.S. "~"~ '~" 6200' start .~'~.'End · r. - WL MD- RKB 70~7 sand: ~'A E] C F-] Both Final Pressure Upper 'Lower Bomb Bomb Maximum Recorded Temperature: .:.~ ~,., · 'r, .?" Well S! Prior to Pressure Measurement (Date/Time): ~/~. -',. Cha~ Ouali~: ~~[ Operations/Engineering.,.. Representative _ , ~ :.- _..:..,::~:: ARCO Alaska, Inc. Date: December27, 1995 RETURN TO: ARCO Alaska, Inc. At'tn: Julie Nash Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 rTRANSMITTAL #9313 Transmitted below are the following pressure items. Please acknowledge receipt and return one signed copy of this transmittal. 2W-05 ~: (~''1 r--I( Well Pressure Report 2X-08 I~--II ~J Well Pressure Report 2T-38 Well Pressure Report 2W-06 ~q-I~i~ Well Pressure Report 2T-37'~Jol Well Pressure Report 2T-31 ~T-q~ Well Pressure Report 2T-30,~"'-5'7 Well Pressure Report 1 1/09/95 AMERADA 1 1/09/95 AMERADA 1 1/11/95 AMERADA 1 1/1 1/95 AMERADA 1 1/11/95 AMERADA 1 1/12/95 AMERADA 1 1/13/95 AMERADA 2T-38 Well Pre~o.~ 11/26/95 AMERADA Receipt Acknowlegedp,/~~v~~Date: ~ ~ ,.. _ DISTRIBUTION: DEC. Petrotechnical Data Center BP Exploration (Alaska) Inc. MB 3-3 P.O. Box 196612 Anchorage, AK 99519-6612 Fuller 41~#I~ Oil & Gas Cons. Commission Holly c/o Chevron U.S.A., Inc Ar~chorage P.O. Box 1635, Rm 3008 Houston, TX 77251 Barbara Sullivan Mobil Oil Corporation 12450 Greenspoint Drive Houston, TX 77060 Mr. Vernon E. Pringle, Jr. DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 Debm Childers UNOCAL P.O. Box 196247 Anchorage, AK 99519-6247 3001 Porcupine Drive Anchorage, AK 99501 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 12-2-93 REFERENCE: ARCO CASED HOLE FINALS 7/)-~,.,_._.~ 1-3 10-31-93 '7~_~_~_1-4 11-5-93 ?~0~ 1-16 11-5-93 ~-~?~ 1-22 11-7-93 -24A 10-14-93 -26 10-31-93 _~..~.~., _1-28 11-6-93 10-31-93 ~--~ ~~-32 10-31-93 ~ 10-17-03 ~~3-30 11-2-93 ~C~ 1~4-4 11-4-93 11-s-93 10-18-93 ~_~"'~'~ _4--~,~, ~-~ 23A 11-2-93 ~7o29 11-4-03 9-6 11-1-93 · 9-7 ~-~ 9-7 10-20-93 10-25-95 ~.~_1~ 9-49 11-1 '~~--50 11-1-93 1-12 11-9-93 1-16ST 11-8-93 .... 'b} ~t/12-161 10-26-93 12-161 11-8-93 ?.~.~.~ ~14-2 11-7-93 ~ ~i~L_ i 4-4 11-6-93 10-19-93 and return the attached copy. as Have A Nice Day! Sonya Wallace ATO-1529 # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA Perf Record 10t{~{ ?_ -HD07. Run 1, ~' Sch Perf Record ~ ~{ Run 1. 5" Sch ~od ~offie ~t~o~~/~R~' 1,~' ,o-I~ Sch D~ B~t T~P ]1~0--]160~ R~ 1, ~' Sch ~od ~offie~f~l~c~¢t~~R~ 1, ~' ~7oo-l~o Sch Peff Record ~9 ~ 0_~¢~ R~ 1, ~' 8ch Pe~ Record 5~0 R~ 1, ~' 8ch Completion Record ~O~t~ i~ 1, ~' ich USIT(~im~(~m~ Color R~1,~'~90o~0toO Sch Pe~ Record ~S~ ~;~ R~ 1, ~' Sch TBG Patch Record R~ 1, ~' '~0DO-7;~ Sch ~od ~o~e~tN;~m~[i~/~ R~ 1, 1"~" 0-~0~ Sch Collar (Packer ~t) . R~ 1, ~' ~O~-{0q~ Atlas D~ B~st TDTP i~O~{~0aO R~ 1, ~' Sch Pe~ Record ~t~0~q~0 R~ 1, ~' Sch Pe~ Record i~~tl~ R~ 1, ~' Sch ~od ~offie 1Stoa IYgWp~}i~R~ 1, 1"~" ~l~'~ Sch IBP Set ~00~o R~ 1, ~' Sch Pe~ Record :[ 0~ ~~ R~ 1, ~' Sch CNL IZ100 - ~9 ~ R~ 1, ~' Sch Pe~ Record I [~ ~0 ~ 1~ R~ 2, ~' Sch ~ Detect I~0~[~O R~ 1, 1"~" Sch USIT/~aT~~]Color R~ 1, ~' ~O ~[ ~ Sch Pe~ Record ~ ~9 ~ R~ 1, ~' Sch L~er/Jewe~/~~ R~ 1, ~' ~0-~50~ Sch ~ Detect(~[~alP~ ,.~ 1, ~'~" 0'-~o Sch ~od ~offie ~ ~e)e~~ 1, 1"~" o-[~ Sch TBG ~cher Z~-a~5o R~ 1, ~' Sch Pe~ Record ~0~01~ R~ 1, ~' Sch D ~ B ~st ~%5 ~ ~ R~ 1, ~' S c h receipt of data. ~ MOBIL The correct APl# for 3-20A is 50-029-20980-01. This log was ran on 4-11 not the sidetrack and the correct API# is 50-029-20286-00. The correct API# for g-7 is 50-02g-20223-00. This log was ran on 12-16A and the correct API# is 50-029-20899-01. he correct API# for 18-29A is 50-029-22316-01. STATE OF ALASKA ALASKA OIL AND ~ ~RVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Pull tubing Alter casing 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 Exploratory Stratigraphic 4. Location of well at surface 1420' FNL, 2017' FEL, Sec. 26, T12N, R9E, UM At top of productive interval 1254' FNL, 1424' FWL, Sec. 26, T12N, R9E, UM At effective depth 1238' FNL, 1179' FWL, Sec. 26, T12N, R9E, UM At total depth 1234' FNL, 1128' FWL, Sec. 26, T12N, R9E, UM 12. Present well condition summary Total Depth: measured 7050 feet true vertical 6447 feet 6. Datum elevation (DF or KB) RKB 94 7. Unit or Property name Kuparuk River Unit 8. Well number 1Q-12 9. Permit number/approval number 84-193 10. APl number so-029-21210 11. Field/Pool Kuparuk River Oil Pool teet Plugs (measured) None Effective depth: measured 6 9 4 9 feet true vertical 6360 feet Junk (measured) Fish in Rathole. Casing Lenglh Size Cemented Structural Conductor 9 8' I 6" 240 Sx CS II Surface 3532 9 5/8" 502 Sx CS III & Intermediate 594 Sx CS II Production 6 99 6' 7" 336 Sx Class G & Liner 250 Sx CS I Perforation depth: measured Measured depth True vertical depth 98' 98' 3570' 3506' 7031' 6430' 651 4'-6576',6574'-6576',6658'-66 true vertical 5984'-6038',6062'-6077',61 09'-611 Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 6748' Packers and SSSV (type and measured depth) PKR's: Baker FHL ~ 6398'~ Baker FB-1 ~ 6727'; SSSV: Baker FVL 13. Stimulation or cement squeeze summary Reperforated "A" sands on 6/24/93. Intervals treated (measured) 6800'-6820' & 6770'-6790' Treatment description including volumes used and final pressure N/A 65',6770'-6790',6800'-6820',6846'-6854' 5', 6205'-6223',6231'-6248',6271'6278' /~,laska Oil & Gas Cons, ~.nr;hrlr~ga 14. Prior to well operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure - 0 - -0: 3600 400 Tubing Pressure 2300 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X - 0 - -0- 3600 400 16. Status of well classification as: Oil c'_~$ Suspended Service 23OO H20 Iniector 17. I hereby_certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 08/15/88 Date ~"4'~-~ SUBMIT IN DUPLICATE ARco Alaska, Inc. ,~ Subsidiary o! Atlantic Richfield Company .L ACTOR lARKS IPBDT , -m- WELL SERVICE REPORT FIELD.DISTRICT.STATE IOAYS IDATE OPERATION AT REPORT TIME . - /_fi. Jo _ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK : ............ ~'~ STATE OF N.ASi(A ALASKA OIL AND GAS ~ATK~ ~ Bi=POFIT OF SUNDFIY WELL OPEFIATION$ OR IG IN/ L. 1. Type of Request: 2. Name of Operator ARCO Alaska. lng, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development Exploratory Stratigraphic Service Operation Shutdown Stimulate X Pull tubing Alter casing Repair well X 1199' FNL, 558' FEL, Sec. 33, T12N, R9E, UM At top of productive interval 1400' FSL, 1269' FEL, Sec. 33, T12N, R9E, UM At effective depth 1094' FSL, 1347' FEL, Sec. 33, T12N, R9E, UM At total depth 044' FSL~ 1360' FEL~ Sec. 33~ T12N~ R9E~ UM "~ 2 Present well condition summery Total Depth: measured 7400 feet true vertical 6 2 64 feet Plugs (measured) Cement: 7314'-7400 Plugging Perforate _ Other 6. Datum elevation (DF or KB) Effective depth: measured 7 31 4' feet Junk (measured) true vertical 61 94' feet Norle 95' RK~ 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2W-06 9. Permit number/approval number 84-194 10. APl number 50-029-21211 11. Field/Pool Kuparuk Ri,4ar ~ii,.P~o.I ..... t:LI:IVi-D DEC 1 6 1992 .Alaska 0il & Gas Cons. Commissio chorage Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 9 6' 1 6" 260 Sx Cold Set II 9 6' 96' Surface 31 9 6 9 5/8' 870 Sx AS III & 31 9 6' 31 1 0' Intermediate 790 Sx Class G Production 7393' 7" 325 Sx Class G & 7393' 6257' liner 250 SX AS I Perforation depth: measured 7063'-7074', 7085'-7112', 7114'-7118', 7193-7196' 4 SPF 90 degree phasing 6803'-6897 12 SPF 120 degree phasing true vertical 5901'-5910', 5918'-5940', 5941'-5944'; 6004'-6006'; 5698-5771' TVD Tubing (size, grade, and measured depth) 3.5" J-55,set at 6955' Packers and SSSV (type and measured depth) Baker FHL ~ 6605'~ Baker FB-1 ~ 6935'; Baker FVL SSSV {i~ 1800' 13. Stimulation or cement squeeze summary Hydraulically fractured the A Sand with crosslinked gelled water and 12/18 Mesh LDC proppant. Intervals treated (measured) Treatment description including volumes used and final pressure Placed 91452# 12/18 Mesh LDC and 1229 bbl ~3elled water in formation. Final pressure=5146 psi. Renresentaflve Daily Averaae Production or Inlection Data - OiI-Bbi Cas. Md 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 _ 17. I hereby certify that the foregoing. Form 10-404 Rev 0W12/g0 1 145 883 3 1849 d'~2133 41 16. Status of well classification as: Water Injector__ Oil X Gas Suspended is true and correct to the best of my knowledge. Title Engineer 1400 201 1550 206 Date )Z./II/~Z- SUBMIT IN DUPLICATE WELL 'ARCO Alaska, Inc~ Subsidiary of Atlantic Richfield Company ~ ~./- 0(~ iPsDT ~ITRACTOR REMARKS - -' FIELD- DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT DAYS DATE //¢~ ' /0 ' -£ J K THIS BLOCK IF SUMMARY CO'"-'"~TINUED ON BACK ' WeIther [Temp- lChill Flctor Vilibillty ]WindVel. I Signed,, /,; . ,k /~ Report 'r 'F milesI knot81 _ q/"~ .N/J~.z-""k'. "z. ~' ., REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON '~, IC~ ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts --Diesel ~ O~ J.-- ~'~ tZ.. Z., Methanol Supervision Pre-Job Safety Meeting 'Ix j~ ~. [~ J V [' L~ AFL . DE O ! 6 A~a-~ m.~)ii ~ ~as Cons, Anchora~le TOTAL FIELD ESTIMATE STATE OF ALASKA ALA,SKA OIL AND GAS CONSERVATION COMMI~51ON REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown __ Stimulate X Plugging Perforate _ Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 199' FNL, 558' FEL, Sec. 33, T12N, R9E, UM At top of productive interval 1400' FSL, 1269' FEL, Sec. 33, T12N, At effective depth 1094' FSL, 1347' FEL, Sec. 33, T12N, At total depth 1044' FSL, 1360' FEL, Sec. 33, T12N, 12. R9E, UM R9E, UM R9E, UM Present well condition summary Total Depth: measured 7 4 0 0 true vertical 6264 6. Datum elevation (DF or KB) 95' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2W-06 9. Permit number/approval number 84-194 10. APl number 50-029-21211 11. Field/Pool Kuparuk River Oil Pool feet Plugs (measured) feet Cement: 7314'-7400 feet Effective depth: measured 731 4' feet Junk (measured) true vertical 6194' feet None Casing Length Size Cemented Measured depth Structural Conductor 96' 1 6" 260 Sx Cold Set II 96' Surface 31 96 9 5/8' 870 Sx AS III & 31 96' Intermediate 790 Sx Class G Production 73 9 3' 7" 325 Sx Class G & 73 93' Liner 250 Sx AS I Perforation depth: measured 7063'-7074', 7085'-7112', 7114'-7118', 7193-7196' 4 SPF 6803'-6897 12 SPF 120 degree phasing true vertical 5901'-5910', 5918'-5940', 5941'-5944'; 6004'-6006'; 5698-5771' Tubing (size, grade, and measured depth) 3.5" J-55,set at 6955' Packers and SSSV (type and measured depth) Baker FHL @ 6605', Baker FB-1 @ 6935'; Baker FVL SSSV ~ 1800' True vertical depth 96' 3110' 6257' 90 degree phasing 13. Stimulation or cement squeeze summary ~-,..-~t~ r~,,, ;~-~'", · '~ " .._ '- Hydraulically fractured the A Sand with crosslinked gelled water and 12/18 Mesh CarbOlE~:h0'"~® Intervals treated (measured) 14. Treatment description including volumes used and final pressure Pumped 64218 # 12/18 Mesh Carbolite and 907 bbl gelled water. Final treating pressure = 3910 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 356 1 20 0 1450 222 701 / 480 0 750 213 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector __ Oil X Gas Suspended Service 17. I here)~ certify that the foregoing is true and correct to the best of my knowledge. Si~ned4J, ~~). ~ Title Senior Operations Engineer Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE 'ARCO Alaska, Subsidla~ of Atlantic Richfield Compari, WELL _ .CONTRACTOR REMARKS IPBDT IFIELD - DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT JDAY/S ]DATE Jo/g' ~C r-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK 1. Type of Request: Abandon STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION OOMMI~I~ ..~. APPLICATION FOR SUNDRY APPROVALS , Suspend _ Operation Shutdown Alter casing _ Repair well Change approved program _ _ Re-enter suspended well~ _ Plugging _ Time extension _ Stimulate X Pull tubing_ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1199' FNL, 558' FEL, Sec. 33, T12N, R9E, UM At top of productive interval 1400' FSL, 1269' FEL, Sec. 33, T12N, R9E, UM At effective depth 1094' FSL, 1347' FEL, Sec. 33, T12N, R9E, UM At total depth 1044' FSL, 1360' FEL, Sec. 33, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 740 0' feet Plugs (measured) 6264' feet Cement' 6. Datum elevation (DF or KB) 95' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2W-06 /~/-~ .L,.. ~ .-~ 9. Permit number 84-1 94 10. APl number 5o-029-2121 1 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 7314'-7400' Effective depth' measured 7314' feet Junk (measured) true vertical 61 9 4' feet Norle 13. 14. 16. Casing Length Size Cemented Structural Conductor 96' 1 6" 260 Sx Cold Set II Surface 31 9 6' 9 5/8" 870 Sx AS III & Intermediate 790 Sx Class G Production 7393' 7" 325 Sx Class G & Liner 250 Sx AS I Perforation depth: measured 7063'-7074'; 7085'-7112'; 7114'-7118'; 7193-7196'-6135' 5928'-5990 12SPF 120 degree phasing true vertical 5901 '-5910'; 5918'-5940'; 5941'-5944'; 6004'-6006'; Tubing (size, grade, and measured depflq 3.5" J-55 set at 6955' Packers and SSSV (type and measured depth) Baker FHL @ 6605'~ Baker FB-1 ~ 6935'; Baker FVL SSSV @ 1800' 4 SPF Measured depth True vertical depth 96' 96' 3196' 31 1 0' 7393' 6257' 90 degree phasing 5698'-5771' TVD Attachments Description summary of proposal ~ Detailed operation program _ BOP sketch Bottomhole pressure 8000 psi~ No BOP - a tree saver will be used~ No workover fluid will be u;ed Estimated date for commencing operation 15. Status of well classification as: August 1.19~) Oil ;~ Gas __ Suspended _ If proposal was verbally approved Name of approver Date approved Service P r o d u c e r 7. I hereby certify that t_he foregoing is true and correct to tjX, best of my knowledge. Date ~.~/~.,, JO/~ ? Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test_ Subsequent form require Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY LONNIE C. SMITH 10-/~Z) Commissioner IApproval Approved Copy Returne~ ."'/. --7'- Date SUBMIT IN TRIPLICATE Messrs Harvey and Kr~. , June 26, 1989 Page 3 Kuparuk Well 2W-06 'A' Sand Re-Fracture Procedure Charge Code: AFE No. K?????? 1. Obtain a 24 hour well test. . MIRU Slickline Unit. Tag bottom. Close OTIS XA sliding sleeve at 6915'. Pull OV at 3421' and replace with DV. . RIH with Standing Valve and set in CAMCO 'D' nipple at 6948'. Pressure test tubing to 4500 psi. RIH and pull SV. 4. RDMO Slickline Unit. NOTE: Fill was last tagged on 05/01/88 at 7161' - covering the A2 perforations with 35' of fill. Consult with Operations Engineering if fill is tagged any higher than 7161' to evaluate if a pre-refrac CTU cleanout is required. 5. Obtain a 24 hour well test. 6, RU fracture equipment. Install "Tree Saver". Pressure up 7" annulus to 3500 psi. 7. Carry out all fluid quality control procedures (Onsite Operations Engineer). Obtain samples of: - Clean proppant - Pre-pad, pad, 2, 6, 10, & 15 ppg stages, flush Record proppant weight before and after the frac. . Pump the 150 bbl pre-pad. Shut down for ISIP and 10 minute pressure fall-off. Calculate tubing and perforation friction from step rate data. 9. Pump fracture treatment per the attached schedule: WHTPE = 4000 psi Fracture Gradient = 0.70 - 5930' TVD Tubing Friction = 160 to 250 psi/1000' - 6950' MD (Dependent on vendor selected) If treating pressure during the job exceeds 6000 psi, reduce the rate to 15 bpm. The treatment is designed such that the slurry stages could be pumped at 15 bpm without a screenout. 10. Rig down fmc equipment. Follow attached flowback schedule. 11. After well has completed flowback, obtain a 24 hour test. The well should be left on 'A' Sand only production for about 3 weeks. Obtain a 24 hour well test at one week intervals. Contact Operations Engineering for a new gas lift design following evaluation of the increased productivity. KUPARUK WELL 2W-06 'A' SAND REFRACTURE PUMP SCHEDULE GELLED WATER FRACTURE TREATMENT 6~28/89 ST/~C~ FLUID DESCRIPTION CLEAN VOLUME PUMP RATE PROP. ~. PROPPANT PROPPANT WT DIRTY VOLUME HIT PERFS BBLS BPM PPG DESCRIPTION LBS STG/CUM BBLS 1 GW PRE-PAD 2 GW PAD 3 GW w/2 PPG 4 GW w/4 PPG 5 GW w/6 PPG 6 GW w/8 PPG 7 GW w/lO PPG 8 GW w/12 PPG 9 GW w/15 PPG 1 0 SLICK DIESEL FLUSH 1 50.0 2 0 0 - - 0 SHUT DOWN FOR ISIP 250.0 20 0 18.4 20 2 20/40 M CARBO-LITE 25.5 20 4 20/40 M CARBO-LITE 31.6 20 6 20/40 M CARBO-LITE 37.0 20 8 16/20 M CARBO-LITE 41.6 20 1 0 16/20 M CARBO-LITE 19.6 20 I 2 16/20 M CARBO-LITE 12.0 20 I 5 16/20 M CARBO-LITE 64.0 +SV 20 0 - - 1 50/ 1 50 6 5 0 250/ 400 21 5 1544 20/ 420 465 4285 30/ 450 485 7972 40/ 490 515 12421 50/ 540 555 17491 60/ 600 605 9890 30/ 630 665 7585 20/ 650 695 0 64/ 71 4 71 5 TOTAL GELLED WATER TOTAL CLEAN DIESEL TOTAL SLICK DIESEL 563.6 BBLS 22.2 BBLS 64.0 BBLS +SV 20/40 M CARBO-LITE = 16/20 M CARBO-LITE = 13801 LBS 47387 LBS Stages 1 through 9 are Gelled Water. Stages 1&2 are Gelled Water with 40 lbs/1000 gal silica flour and enough breaker for a 6 hour break. ...... ~Stages 3 through 9 are Gelled Water with 6 hour breaker and without silica flour. ..? Stages I through 4 will also contain 5% Arctic Diesel by volume for additional fluid loss control. Stage 10 should include a volume adjustment for surface equipment between the wellhead and densitorneter. The rate during the final 30 bbl of the flush (i.e. after 15ppg stage has hit formation) should be gradually reduced to zero. This job is intenlJonally underflushed by 1.5 bbl. The blender tub should be bypassed at flush. All fluids should be maintained at 70° to 90° F on the surface. '"-" STATE OF ALASKA ~-'". ALASK.. OIL AND GAS CONSERVATION COMN. 31ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate'~ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska: Inc. 3. Address P.O. Box 100360~ Anchoracle~ Alaska 99510 4. Location of well at surface 1199' FNL, 558' FEL, Sec. 33, T12N, R9E, UM 5. Datum elevation (DF or KB) RKB 95 Feet 6. Unit or Property name Kuparuk River Unit 7. Well number 2W-6 At top of productive interval 1400' FSL, 1269' FEL, Sec. 33. T12N, R9E At effective depth 1094' FSL, 1347' FEL, Sec. 33, T12N, R9E At total depth 1044' FSL~ 1360' FEL~ Sec. 33~ T12N~ R9E 11. Present well condition summary 7400' Total depth: measured true vertical 6264' feetfeet Effective depth: measured 7314' feet true vertical 6195' feet Casing Length Structural Conductor 80' Size 8. Approval number UM UM UM Plugs (measured) Junk(measured) Cemented 7-779 9. APl number 50-- 029-21211-00 10. Pool Kuparuk River 0il ' C'EiVED Pool ~aska Oil ~ Gas Cons. C0[[]r~Jssj0r~ Anchorarj. e Measured depth True Vertical depth 16" 260 Sx C.S. II 92' 92' Surface Intermediate Production Liner Perforation depth: 3167' 7369' 9-5/8" 870 Sx A.S. III & 3196' 3111' 790 Sx Class "G" 7" 325 Sx Class "G" 7393' 6257' measured true vertical 250 Sx 6803' -6897' 7063' -7074' 5792' -5865' 5995' -6004' A.S. I 7085'-7112' 7114'-7118' 7193'-7196' 6013'-6034' 6035'-6039' 6098'-6100' Tubing (size, grade and measured depth) 3 1/2", 9.3 lb/ft, J-55 tubing w/tail @ 6955' Packers and SSSV (type and measured depth) Baker FVL SSSV 1800' FHL PKR ¢ 6605' FB-1 PKR ¢ 6935' 12. Stimulation or cement squeeze summary 274 BBL of gelled diesel w/16652# 20/40 Mesh Sand. Intervals treated (measured) 7063'-7074'. 7085'-7112' 7114'-7118' 7193'-7196' MD Treatment description including volumes used and final pressure ' ' 13. (A Sand Only Tests) Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 555 251 0 1100# 160# 893 372 0 1425# 150# 14. Attachments Daily Report of Well Operations '1~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ./,~ ~ Form 10-404 Rev. 12~.12'85 ID FVD Date ~'//.~ 5'/<i ~t .. Submit i~ Duplicate,,_.~' ARCO Alaska, ~nc. ~ Subsidiary of Atlantic Richfield Company~.~. WELL ~DT CONTRACTOR · REMARKS IFIELD - DISTRICT- STATE OPERATION AT REPORT TIME VVf'LI. OC, l~Vlbr, n~;r~,n i I [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemp. { Chill Factor I Visibility Report °F °F miles JWind Vel. ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION ~(JMMISSION ~,/~ ~ WELL COMPLETIO# OR RECOMPLETIO# REPORT Al,ID LO 1, Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-194 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21211 4. Location of well at surface ' 9. Unit or Lease Name 1199' FNL, 558' FEL, Sec.33, T12N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1400' FSL, 1269' FEL, 5ec.33, T12N, R9E, UM 2W-6 At Total Depth 11. Field and Pool 1044' FSL, 1360' FEL, Sec.33, T12N, R9E, UM Kuparuk River Fie,ld 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool RKB 95' ADL 25642 ALK 2573 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 11/02/84 11/07/84 1 2/1 6/84*J N/A feet MSLI 1 17. Total DePth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey [ 20. Depth where SSSV set 1 21. Thickness of Permafrost 7400'MD, 6264'TVD 7314'MD, 6195'TVD YES~] NO [] 1800' feet MD 1450' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/Cal/FDC/CNL, RFT, Gyro (CCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT, PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 92' 24" 260 sx CS II 9-5/8" 36.0# J-55 Surf 3196' 12-1/4" 870 sx AS Ill & 790 st Class G 7" 26.0# J-55 Surf 7393' 8-1/2" 325 sx Class G & 250 ~x AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/4 spf, 90° phasing 3-1/2" 6955' 6605' & 6935' 7063 ' -7074 'MD 5995 ' -6004 'TVD 7085'-7112'MD 6013'-6034'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7114'-7118'MD 6035'-6039'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7193'-7196'MD 6098'-6100'TVD N/A Perforated w/12 spf, 120° phasing .. 6803 ' -6897 'HD 5792 ' -5865 'TVD .... 27. N/A PRODUCTION TEST Date First Production [ Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF 'WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ · oIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED 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. None DEC *Note: Dri.l.led RR 11/8/84. Perforated wel,l & tubing run 12/16/84 Workover ,",!351,--.'.A0 performed 11/22/87. ' -""" , , Form 10-407 Rev. 7-1-80 WC4/15: DAN I CONTINUED ON REVERSE SIDE Submit in duplicate~,~ GEOLOGic;MARKERs .... ! : .?_ ': .... · FOHMATIONTESTS : ~ ' ' ~ ' 'I i' - -~ 'I . .:. '?:' :.- .' ~ ": :_ ' ': ' . : · -. : ' '. - ' ....... NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 6801' 5790' DEPTH (HD) BUILD-UP HYDR05TATIC Base Upper Sand 6899' 5867' Press Press Top Lower Sand 7044' 5980' 6828' ~ 2791 psi 3164 psi Base Lower Sand 7201' 6104' 6835' 2791 psi 3164 psi - 6849' 2795 psi 3170 psi 6856' 2832 psi 3169 psi 6891' 2794 psi 3182 psi 6938' 2841 psi 3201 psi -~- '"~ 7067' 2994 psi 3262 psi 7091' 2998 psi 3264 psi - 7097' 2999 psi 3259 psi _. 3 i. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correc't to the best of my knowledge . Signed ~ ~ ~~ ~/ Title Associate Engineer Date [~-.'2~'~7 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 ~-----.. STATE OF ALASKA AL. .-~ OIL AND GAS CONSERVATION CC ..~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate~ Plugging © Perforate ~ Pull tubing WORKOVER Alter Casing ~ Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1199' FNL, 558' FEL, 5ec.33, T12N, RDE, UM At top of productive interval 1400' FSL, 1269' FEL, Sec.33, T12N, RDE, UM At effective depth 1094' FSL, 1347' FEL, Sec.33, T12N, RDE, UM At total depth 1044' FSL~ 1360' FEL~ Sec.33~ T12N~ RDE, UM 11. Present well condition summary Total depth: measured 7400'MD true vertical 6264 'TVD feet Plugs (measured) feet 5. Datum elevation (DF or KB) RKB 95 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 2W-6 8. Approval number 7-779 9. APl number 50-- 029-21211 10. Pool Kuparuk River Oil Pool P1 ug set @ 6927' Effective depth: measured 7314 'MD feet Junk (measured) true vertical 6195 'TVD feet None Casing Length Size Cemented Conductor 80' 16" 260 sx CS II Surface 3167' 9-5/8" 870 sx AS III & 790 sx Class G Production 7369' 7" 325 sx Class G & 250 sx AS I Measured depth 92'MD 3196'MD 7393'MD Feet Date/~2.~2~ Submit in Duplicate~/ True Vertical depth 92 ' TVD 3111 'TVD 6257'TVD 12. Perforation depth: measured 6803'-6897', 7063'-7074', 7085'-7112', 7114'-7118', 7193'-7196' true vertical 5792 ' -5865 ', 5995 ' -6004', 6013 ' -6034 ', 6035 ' -6039', 6098 ' -6100' Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail ~ 6955' Packers and SSSV (type and measured depth) FHL pkr ~ 6605', FB-1 pkr ¢ 6935' & FVL SSSV (~ 1800' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED ~r-~ r--- ,.,,.- ur..~ ~ 4 1~81 Alaslm Oil & G~ Cons. C0mmissi0~ ~ch0r~e, ' 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Wel 1 History) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge 2~7~//(~ O'~"-~"U Form 10-404 Rev. 12-1-85 Title Associate Engineer (Dani) SW03/18 11/'t 6/87 ( TD: 7400 PB: 7314 SUPV:DJ 11/17/87 ( TD: 7400 PB: 7314 SUPV:DJ 11/18/87 ( TD: 7400 PB: 7314 SUPV:DJ 11/19/87 ( TD: 7400 PB: 7314 SUPV:JE/RB The :~w~/ti:oorl~ot: : ~,: ':TREE, N/U BOP, TEST. pULL HG~ CIR~ WELL. POOH W/ TBO. ~ DAILY:S40,572 CUM:$82,284 ETD:S82,284 EFC:$665,000 RELEASE PKR MW: 9.2 NaClNaBr SERVICE RIG. FINISH POOH W/ TBG. L/D DAMAGED TBG. R/D, R/U, M/U BHA. RIH W/ D.P. FINISH LOAD SHED W/ D.P. FINISH RIH. TAG AND RELEASE PKR. DAILY:S55,248 CUM:$137,532 ETD:S137,532 EFC:$665,000 RIH W/ WASH PIPE MW: 9.2 NaCl/NaBr WORK PACKER, REVERSE CIRC. CIRC. LONG WAY WITH 9.1 PPG. SHUT DOWN UNTIL WELL FLOWING. CIRC. WELL ON CHOKE. RAISED BRINE WT. SPOT PILL. POOH. RECOVERED FISH. RU TO RUN WASHPIPE. RIH WITH WASHPIPE. CIRC. RIH. DAILY:S45,406 CUM:$182,938 ETD:S182,938 EFC:$665,000 RIH W/ OVERSHOT ON TBG MW: 9.2 NaCl/NaBr INISH RIH. WASHOVER FISH. CIRC WELL F/ WASHOVER FISH. CIRC. BUILD SURFACE VOLUME. CIRC. POOH. LD WASHPIPE. PU OVERSHOT. RIH W/ TBG. DAILY:S34,118 CUM:$217,056 ETD:S217,056 EFC:$665,000 RIH W/ OVERSHOT AND 3-1/2 MW: 9.2 NaCl/NaBr RIH W/ 3-1/2" TBG. TAG FISH @ 6776'. CIRC TBG VOL AND LATCH ONTO FISH. PU WT 52 K. SET STRING ON SLIPS W. 55K. Ru GE . T ./L. RiH TO 7029,, TOP OF FI L. EC 2 i987 RIH W/ 2-§/8" CHEM CUTTER. CUT TBG @ 6906'. R/D W/L. POOH W/ FISH AND LD SAME. BLAST RINGS DAMAGED AND 3/4 OF--,1 RInG Nnn~ ~nmmi~Rin~ UISSING IN ~ #2. HOLE IN ,~ # 2, 4. PU OVER SHOT ',,F/ms~a0il & Gas 3-1/2- m~,PLE AN~ RIH U/ 3-1/2" ~ AND DP. SLId/CUt DR~G LINE. RIH SLO~. DAILY:S52,808 CU~:$269,864 ETD:$26D,864 EF¢:$665,000 Date I Title IZ-I I..-,~7 Associate Engineer "!~:'i., AtlanticRichfieldC°mpany ,~," Da.y Well History-Interim 'it Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reporled on "interim" sheets until final In~l/la,--lil~'ls: This form is used during drilling or workover operations. If testing, coring, pr pedorating, show formation name in describing work performed. completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and de~h as of 8:00 a.m. i county or Parish ARCO Alaska, Inc. I NORTH SLOPE I Leass or Unit KUPARUK RIVER UNIT I ADL: 25642 Complete record for each day while drilling or workover in progress NORDIC i 11/20/87 ( TD: 7400 PB: 7314 SUPV:JE/RB 11/21/87 ( TD: 7400 PB: 7314 SUPV:JE/RB 11/22/87 ( TD: 7400 PB: 7314 SUPV:JE/RB I Stat~%i( 2W-6 Iwell no. POH. LD DRILL PIPE MW: 9.2 NRC1 RIH W/OVERSHOT. LATCH FISH @ 6903'. PULLED FREE AND POH. L/D 3-1/2" GLM, PUPS, & SEAL ASSY. PU 1-1/4" STINGER & SHORT SEAL ASSY; RIH & WASHED OUT TAIL PIPE. PRESS. UP SEAL ASSY TO 500 PSI-OK. PULLED OUT OF PKR & CBU. POH & LD 3-1/2" DP. PULLED 36 JTS. HOLE TOOK 2 BBLS INSTEAD OF 6 BBLS. AT 61 JTS, MONITORED WELL; WELL FLOWING. INCREASED WT TO 9.3+ PPG. CIRC. @ 5040'. MONITORED WELL-HIGH FLUID LOSS. CUT WT BACK TO 9.2+ PPG. FILLED HOLE & LOSS SLOWED. CONTINUED POH & LD DP. DAILY:S29,995 CUM:$299,859 ETD:S299,859 EFC:$665,000 LOADING PIPE SHED WITH TB MW: 9.2 NRC1 LDDP. RIH WITH 100 STDS OF 3-1/2" TUBING. CBU. POOH WITH 3-1/2" TUBING. LOAD PIPE SHED WITH 3-1/2" TUBING, DRIFT AND STRAP AND INSTALLING SEAL RINGS. DAILY:S35,626 CUM:$335,485 ETD:S335,485 EFC:$665,000 DISPLACING BRINE WITH DIE MW: 9.2 NRC1 RUN 215 JTS. OF 3-1/2" 9.3# J-55 EUE 8RD AB-MOD TUBING. ~ Set plug @ 6927' 5000# TREE. DISPLACING BRINE WITH DIESEL. (FVL SSSV @ 1~00,, ~L ~<~ @ 6605', ~B-1 PACr~ @ ~935', ~D T~IL @ DAILY:SI77,472 CUM:$512,957 ETD:$512,957 EFC:$665,000 · NU The above is correct For form preparation and,f~istribution see Procedures Manualj~ection 10, Drilling, Pages 86 and 8T IDate ITitle iZ-//~7 Associate Engineer Oil'and:Gas Com ,dny" Daily We,m History-F!nal Report I~: prepare and submit the "Final Reflerl" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Ff~at_R~ert" should be submitted also when operations are suspended for an Indefinite or appreciable length of time. On workovers when an official test la not requli'ed:~upon completion, report completion and representative test data in blocks provided. The 'Final Report" form may be used for reporting the entire operetlorf if space is available. District ARCO Alaske, Inc. Field KOPARUK Rt~ER UNIT Auth. or W.O. no. . Operator. ~,c~ Spudded or W.O. begun Date:and de~: : ' Cemplete-record for_each day reported a~ o~.s:~o'.~m. - ~IC- 1 . r ~" '- ' 11/23'/~7 ( 1~ RIG RELEASED PB:: 7314-' ICounty or Palish - NORTH SLOPE Lease or Unit N)L: 25642 Ti~la Old TD IAccounting Stst~K coat center code 2W-6 IWell no. A.R.Co.W.I. 56.0000 11/14/87 I otal number of wells (active or Inactive) on thl~ Dst center prior to plugging and bandonment of this well our IPriOr statue if a W.O, 0330 MW: 6.9 DIESEL DISPLACE BRINE WITH 226 BBL OF DIESEL. RELEASE RIG 0 0900. HRS 11/22/87. DAILY:S11,700 CUM:$524,657 ETD:S524,657 EFC:$665,000 Released rig Classifications (oil, gas, etc.) INew TD PB Depth Date I K nd of r g Type completion (single, dual, etc.) Producing method Olficial reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature ] Date ITitle d~rib~./~ ~ /Z-//~"~ Associate Engineer For form preparation and ution, see Procedures Manual, Se~Stion 10, Drilling, Pages 86 and 87. STATE OF ALASKA ~' AL/-,....~A OIL AND GAS CONSERVATION CO, .... ,ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend © Operation Shutdown [] Re-enter suspended well ~ Alter casing ~Z Time extension ~ Change approved program '.~ Plugging E3 Stimulate ~Pull tubing~,~Amend order ~ Perforate ~ Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc RKB 95' feet 3. Address 6. Unit or Property name P. 0. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit of well at surface FNL, 558' FEL, Sec.33, T12N, R9E, UM productive interval FSL, 1269' FEL, Sec.33, T12N, R9E, UM 7. Well number 2W-6 8. Permit number 4. Location 1199' Attop of 1400' 9. APl number 50-- 029-21211 10. Pool Kuparuk River Oil Pool Plugs (measured) None At effective depth 1094' FSL, 1347' FEL, Sec.33, T12N, RgE, UM At total depth 1044' FSL, 1360' FEL, Sec.33, T12N, RgE~ UM 11. Present well condition summary Total depth: measured 7400 ' MD feet true vertical 6264 ' TVD feet Effective depth: measured 731 4 ' MD feet true vertical feet 6195 ' TVD Casing Length Size Conductor 80' Surface 3167' Junk (measured) None Cemented Measured depth Rue Verticaldepth 16" 260 sx CS I I 92'MD 92'TVD 9-5/8" 870 sx AS Ill & 3196'MD 3111'TVD 790 sx Class G 7" 325 sx Class G & 7393'MD 6257'TVD 250 sx AS I Production 7369' 6803'-6897' 7063'-7074', 7085'-7112', 7114'-7118', 7193'-7196' Perforation depth: measured ' true vertical 5792'-5865', 5995'-6004', 6013'-6034', 6035'-6039', 6098'-6100' Tubing (size, grade and measured depth) 3-1/2", 9.3#/ft, J-55 tubing w/tail. (~ 6955' Baker FB-1 pkr @ 6935' Packers and SSSV(Wpe and measured depth) Baker FVL SSSV ~ 1827'; Baker FHL pkr ~ 6651' BOP sketch ~L' 12.Attachments Description summary of proposal ~ Detailed operations program [] 13. Estimated date for commencing operation R E E E I V E I) October 25, 1987 14. If proposal was verbally approved Name of approver ~_l~tm Ilii ~, R~.~ Con~. C0mmJ~.~i0n Date approved 15. I hereby certify that the foregoing is true and correct to th~a~l~my knowledge C~) ~?/' ,~ TitleAssociate Enqi n~r Signed )~,}(.~ ~ ]./).f,~ ,. / Commission Use Only 8 (J~) SA2/1 1 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Date /~.. 7-Z5'7 .......... by order of Commissioner the commission Date /~)-0 - Approved by 7 Form 10-403 Rev 12-1-85 Submit in triplicate 2W-6 Preliminary Workover Procedure Pre-Rig Operations 1. MIRU slickline unit. 2. Pull gas lift valve from GLM @ 6594'. Set dummy valves in all other GLM' s. 3. RD slickline unit. 4. Load-tubing and annulus with diesel. 5. RU E-line unit. 6. Cut tubing below retrievable packer and above blast rings. RD E-line. ~' 7. Set BPV. Rig Operations 1. MIRU workover rig. 2. Pull BPV. 3. Circulate kill weight fluid down tubing taking returns through the annulus. 4. Set BPV. 5. ND tree. NU and test BOPE. 6. Pull tubing string changing out couplings to AB MOD couplings. 7. RIH with drill pipe and packer retrieving tool. 8. Latch onto packer and release same. CBU. ~/~ ~bd loss.[ Pump pill if fluid loss is excessive. 9. POOH. LD packer. 0''~¥''~',,., i ~'" f~ !i':i~ 10. RIH and retrieve FL4S tubing with blast ri~§~,a0i] & aas Cons. Anch0ra90 11. Make clean out run to top of permanent packer. Filter brine clean. POOH. 12. Re-run completion assembly with AB MOD GLM's, packer, and SSSV. 13. ND BOPE. NU tree and test. 14. Displace well to diesel. 15. Set BPV. Secure well. 16. Release workover rig. 17. HIRU CTU. Clean out to PBTD. 18. Frac 'A' sand. WPAD/2W'6 ih ANNULAR PREVENTER 6 PIPE RAMS 4 BLIND RAHS 5 TUBING HEAD 1. 16" CONDUCTOR SWAGED TO 9-5/8" 2. 11"-3000 PSI STARTING HEAD :3, 11 "-:3000 PSI X 7-1 / 16"-5000 PSI TUBING HEAD 4, 7-1/16" - 5000 PSI PIPE RAMS 5. 7-1/16" - $000 PSI BLIND RAMS 6. 7-1/16" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1 . CHECK AND FILL ACCUMULATOP RESEP. VOIR 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 ARCTIC DIESEL. 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. $, CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD, 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5, INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI, 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS, 7, INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM 'PRESSURE TO ZERO PSI TO TEST VALVES, TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH :3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI, 9, OPEN PIPE RAMS, BACKOFF RUNNING JOINT AND PULL OUT OF HOLE, CLOSE BLIND RAMS AND TEST TO :3000 PSI FOR 10 MINUTES, BLEED TO ZERO PSI. 10. 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, 11 . TEST STANDPIPE VALVES TO :3000 PSI. 12. TEST KELLY COCKS AND INSIDE 60P TO 3000 PSI WITH KOOIJEY PUMP, 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM, SIGN AND SEND TO DRILLING SUPERVISOR, 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BORE DAILY, JO JULY 28, 1986 (NORDIC RIO 9-5/8") ARCO Alaska, In~ Post Office r~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: August 11, 1987 Transmittal # 6020 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2Z-4 Dual-Zone PBU ~A'-Sand 7-14-87 2Z-4 Dual-Zone PBU 'C' Sand 7-14-87 2Z-12 Dual-Zone PBU 'CT Sand 7-2-87 2Z-12 Dual-Zone PBU 'A' Sand 7-2-87 2U-15 Pressure Buildup 5-28-87 2W-6 Dual-Zone PBU 'C' Sand 7-15-87 2W-6 Dual-Zone PBU 'A"Sand 7-15-87 3M-9 Static Well Pressure Report 7-26-87 3M-3 Static Well Pressure Report 7-17-87 3M-8 Static Well Pressure Report 7-28-87 2Z-6 Static Well Pressure Report 7-21-87 2Z-8 Static Well Pressure Report 7-25-87 2U-6 Static Well Pressure Report 7-19-87 3I-9 BHP Report 7-16-87 2W-7 Static Well Pressure Report 7-21-87 2X-lO Static Well'Pressure Report 7-17-87 2X-14 Static Well Pressure Report 7-17-87 2X-12 Static Well Pressure Report 7-17-87 2W-3 Pressure.Buildup Test 7-4-87 2Z-2 Static Well Pressure Report 7-17-87 2Z-6 Static Well Pressure Report 7-13-87 2Z-2 Static Well Pressure Report 7-9-87 2Z-8 Static Well Pressure Report 7-13-87 3M-i Static Well Pressure Report 7-13-87 3M-2 Static Well Pressure Report 7-13-87 1Y-lO Static Well Pressure Report 4-23-87 1Y-4 Static Well Pressure Report 4-21-87 1Y-4 Static Well Pressure Report 3-3-87 Receipt AcknoWledged: EV AUG 1 3 1987 Alaska 0il & Mas Cons. Commission Anchorage Date: DISTRIBUTION: BP Chevron Mobil SAPC Unocal State of Alaska D&H ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany ARCO Alaska, Inc~, Post Offic( ,x 100360 Anchorage, Alaska 99510-0360 Telephone 907' 276 1215 DATE: 10-22-85 TRANSMITTAL NO: 5410 RETURN TO: RECEIPT AND FINAL PRINTS/ SCHL/ ONE * CEMENT. BOND LOG/ VARIABLE -~ 42X-15 "~2X- 1--3 ~ 2X- 12 ~2X-ll ~x-10 w2X-9 2W-6 '~2V-16 '~ 2V-15" ~2V-13 ~. ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEEP~ING RECORDS CLERK ATO-1115B : - P.O, mOX 100360.'. ANCHORAGE, AK 99510' HEREWITH AFd~ Tri~: FOLLOWING ITh~lS. RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. OF EACH DENSITY '. RUN RUN RUN RUN #1 RUN #1 RUN 91 RUN RUN RUN RUN RUN #1 RUN~#i~ RUN 06-06-85 11-07-.84- 11-17-84 12-08-84 12-08-84 12-21-84 12-20-84 11-25-85 06-0'6-85 06-07-85 - 06-03-85 04-02-85 04-01-~5 03-31-85 04-01-85:- 03-02-85' '-~ PL~AS~ ACKN~4LEDGE 2D-16 - 12-19-84- RUN 2D-15-!~-i 12-18-84 RUN OW2D-1 ~'~' 11-03-84 RUN . '~iR-8 06-17-85 RUN ~wlR-7 06-08-~5 - RUN "~JiR-5 - ' 06-08-85 RUN ~'~lL-15 11-05-84 RUN ,~ lQ- 15 -~ 05-27-85 RUN lQ-3 i.i~.i 04-17-85 RUN ' %CPF-1A -. 12-21-84 ~<UN 5850-8369 5900-8258 5896-8410 3050-7215 310U-6370 3350-6973 5100-8338 5700-7290 4550-710~ 4650-6428 · 6590-8553 . 4970-693~~ -. .~. . . - .. 0070-~122~ -i -/:: .~i- "" 5600-8107~.i-i::~:'..:.-/'.: ".. . '. 5200-74~9- 3285-6454'- 5693-6652 5987-8324 4302-7028 6950-8628 4883-6600 6490-7566 897~-10744- 2200-3856 CEMENT EVALUATION WOOL 1F-'16 - 03-12-85 'RUN. ~%'*iR-57:.?-~I 06-26-85 RUN #1 ~,lR-5.'/~i'i~. 06-27-85- RUN _#2 ~2U-2~.i~!!:::. 03-25-85 -RUN . . ~'2U-15 03-07-85 RUN '~3B-9 '. ~06-30-85 RUN . ~3C-11~. 06-29~85 RUN ~3C~12'~-/. 06-29-85- RUN ~1 · . - _ - -. KECEIPT ACKNOWLEDGED:'. ' BPAE_ -" .... ~ - DRILLIN~*BL B. 'CURRIER. ' L. JOHNSTON_ CHEVRON-' t~BIL~' - D & M ' · "NSK CLE~K*~L -. . LUGS/_.C~MENT EVALUATION LOGS #1- 8269-8712 6974-8~44 8254-8532 5790-9450' ' 6400-7002 6000-8246 · 6500-8726 5400-7457 W. PAShEK EXXON PnILLIPS OIL J. RATH~IELL" ARCO Alaska. inc. is a Subsidiary of AtlanticRichfieldCompany ''STATE OF~ AL~%nS~)A~L: ' S Oh IO .............. "":"~S E~).'' · UNION VAULT/ANO* FIL~ ~7 ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 14, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SLIBJECT: Conductor As-Built Location Plats - 2W Pad Wells 1-8, 9-16 Dear Elaine' Enclosed are as-built location plats for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer ,. JG/tw GRU2/L93 Enclosures If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompan¥ .~ 'PHASE 33: AS-BUILT WELLS 9 Thru 16 28 (NSK 9. O5.223d 2 } 27 34 PHASE 'r AS-BUILT WELLS I Thru 8 WELL ! Y - 5,979,335.00 LAT. 70°2['t~.9905" X - 51~,909.82 LO#6. 169°$0'~7.193t" PAD ELEV. 55.1 0.G. ELEV. 50.3 [79 ~£L 1,22~ FNL $[C. 33 ~£LL 2 Y - 5,979,253.3g LAT. X ~ 518,987.&~ LONG. lkg°~0'k7.85[k'' PAD EL£V. 65.3 0.G. /LEV. 50.5 202 TEL' 1,279 ¢NL 5£C. 33 JELL 3 Y - 5,979,Z27.a0 Lit. 70°21'15.3978" X - 518,eG~.a9 L0~G. 1~g°50'~8.51~7" PAD [LEV. 65.3 0.a. £LEV. ~0.7 225 FEL 1,335 FNL S[C. 33 YELL ~ ¥ - 5,979,172,09 Lit.' X , 518,~2.35 LONG. 2u8 F~L 1,331FNL SEC. 33 ~ELL 5 Y - 5,979,307. t7 L~T. ?0°21'1~,6873" X , 518,508.68 LONG. ~9°50t58.$221" PAD ELEV. 5~.7 0.5. ELEV. 581 ~EL 1,~55 FNL SEC, 33 ~¢LL 6 Y - 5,979,352.79 L~T. 70a21'lT.~33a. x = 518,531.1~ LONG. PAD EL£V. ~.~ 0.G. ELE¥. 59.3 558 FEL l,[;g FqL $[C. 33 e£LE 7 Y - 5og?go~xS.39 LAT. X , $J8,553.57 LONG. 535 ~£L [,Z~ F~L S£C. 33 ~ELL a Y - 5,g?9,G73.sg ~AT. X - 518,575.15 LCNG. I*gc50'ES.9375" 512 F[L ~,G88 FNL S£C. 33 · LOCATED IN PROTRACTED SECTIONS :5;5 8, 34 TOWNSHIP 12 N.~ RANGE 9 E.~ UMIAT MER. NO SCALE NOTE' BASIS OF POSITION iS MONUMENTATION A/ask 2W NORTH AND P.W SOUTH PER LHD ~ ASSOCIATES. LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF OCTOBER 14, 1984. ARCO Aiesko, Inc. Kuooruk Project North Slooe Drilling DRILL SITE 2W CONDUCTOR AS-BUILT LOCATIONS Dote: Oct. 23, 1984 Scole: AS SHOWN Dr~swn Rv' HZ r~w~- P~Jn ~Ck' q 05 ??.~,~ ~ Z, ~ L jr./z, , HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND / THIS SURVEY~~. 3 ALASKA OIL AND ~A$ OOfiSERFATION.f, Of~f~I$$10N Bill Sheflleld, Gm, etnor .. 300f POI1CUPIHE DRIVE ANCHOFI&OE,ALAgKA IgeOl.l-Sfg! TEL £PHONE tOOl! l ;'g,.- f433 REs hte wish to brlng to your attention that the Uommission has hOE" yet received the following required items on the subject well ~hich our records indicated was completed /r~-/~--g>~f' - , · Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled.well. Please submit the above missing material. · · Chairman lc~C.024 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 15, 1985 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2W-6 Dear Mr. Chatterton' Enclosed is a copy of the 2W-6 Well History (Completion Details) to include with the Well Completion Report, dated 01/21/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L157 Enclosure xc' 2W-6 Well File F'E J. 9 Alaska Oil & Gas Con,';. Commission Anchora.,~e ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Post Office Box 360 Anchorage,/--"~ska 99510 Telephone 5_. 277 5637 Date: ±/31/85 Transmittal No: 5014 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 PAGE 2 of 3 Transm±tted herew±th are the follow±rig items. ?lease acknowledge r~ceipt and return one signed copy of th±s transmittal. 1L-1wz CPL Cyberlook 10/08/84 Run 1 '" 2"/5" DIL-SFL/GR 10/08/84 " 2359 - 7470 " 2"/5" Density Neutron. "Para" 10/08/84 " 2359 - 7447 " 2"/5" " " "Raw" 10/08/84 " 2359 - 7447 " 2"/5".BHCS/GR 10/08/84 " 6750 - 7473 2W-6/ CPL Cyberlook 11/06/84 Run 1 3198 - 7286 " 2"/5" DIL-SFL/GR 11/06/84 .... 3198 - 7286 "' 2"/5" Density Neutron "Para" 11/06/84 " 6600 - 7261 " 2"/5" " " "Raw" 11/06/84 " 5600- 7261 " RFT "DIL-SFL/GR, FDC-CNL/GR" 11107/84 , 2W-5/ CPL Cyberlook 10/31/84 Run 1 7350 -.8050 " 2"/5" Density Neutron "Para" 10/31/84 " 3757 - 8080 " 2"/5" " " 2"/5" DIL-SFL/GR /cat Receipt Acknowledged: B. Currier BPAE Chevron t tl~awl ! 10/31/84 10/31/84 DISTRIBUTION .. Drilling i ~Geology ~---~ Mobil W. Pasher '~ 3557 - 8050 "~- ~~:~5:,'~'080 Date: State of AK G. Phillips Sohio Phillips Oil Union D&M NSK Ops. : J. Rathmell Well Files ARCO Alaska. Inc. is a subsidiary of AllanllcRich'lieldCompany ARCO Alaska, Inc. Post Offic~ ,x 360 Anchorage, ~laska 99510 Telephone 907 277 5637 Date: 1/30/85 Transmittal No: 5013 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B T/ra~s~.O. Box 100360 chorage, AK 99510 itted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. BHP REPORTS & .SEQUENCE QF EVENTS 10-4.- 9/30/84 9/04/84 1G-I"~ 11/24/8~ 11/24/84 in-8 10/05/8~ 1L-7 10/19/8~ 1L-6 10/18/84 . 1L-5 10/18/84 1L-4 10/19/84 : 2W-7'j' 1/07/85 .1/07/84 2W-6 ? 1/07/85 1/07/84 2W-5.: 1/07/85 1/07/84 2w-s~ 1/os/s5 1/os/s4 1E-5-" 11/25/84 11/26/84 "BHP" "SBHP" "SBHP" "Initial" "SBHP" "Initial" "SBHP"-"Initial" "SBHP" "Initial" ,,sBHP,, /cat Receipt Acknowledgad: DISTRIBUTION B. Currier Drilling W. Pasher BPAE Geology G. Phillips Chevron Mobil Phillips Oil D & M NSK Ops. J. Rathmell State of AK Sohio Union Well Files ARCO Aiesk&. Inc. is · subsicliary of AllanhcRichfielclCompany ARCO Alaska, Inc. Post Office x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/31/85 Transmittal No: 5014 RETURN TO: PAGE 1 of 3 ARCO ALASKA, INC. ATTN: Records Clerk ATO-11t5B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. -OH FINALs Schlumberger 0~ensity Neutron "Poro" 10/16/84 Run 1 10/16/84 " 7100 - 7733 2"/5" · 7100- 7733 2"/5" ,, DILJSFL/GR 10/16/84 " 3276 - 7758' 2"/5" " BHCS/GR 10/16/84 " 7100- 7759 2"/5" " CPL Cyberlook 10/16/84 " 7100 - 7700 CPL Cyberlook " Density Neutron "Poro" 10/03/84 Run 1 _. -- - 10/03/84 " 6400 - 7050 6400 - 7048 2"/5" 11 II '" "Raw" 10/03/84 " 6400.,- 7048 2"/5" ,, Dz _sm /OR 1'0/03/84 "' 2805- 7074 2"/5" CPL Cyberlook Density Neutron "Poro" 10/07/84 lO/O7/84 Run 1 7200 - 7710 " 7200 - 7878 2"/5" 11 !! " "Raw" 10/07/84 " 7200- 7878 2"/5" " DIL-SFL/GR /cat Receipt Acknowledged: B. Currier BPAE Chevron 10108184 ;, DISTRIBUTION Drilling W. Pasher fOeology~ ' G. Phillips Mobil Phillips Oil 3624 - 7910 2"/5" Alaska Oil & Gas Cons, Commissio~ State of Sohio Union D&M NSK Ops. J. Rathmell Well Files ARCO Alaska. Inc. is a subsidiary ol AtlanticRich'fieloCompany ARCO Alaska, Inc~.. Post Offic~ x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 RETURN TO: Date: 1/31/85 Transmittal No: 5014 PAGE 2 of 3 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ¢~[~'" 1L-1 CPL Cyberlook 10/08/84 Run 1 --- ~ · '" 2"/5" DIL-SFL/GR 10/08/84 " 2359- 7470 " 2"/5" Density Neutron "Poro" 10/08/84 " 2359 - 744Y " 2"/5" " " "Raw" 10/08/84 " 2359- 7447 " 2"/5" BHCS/GR 10/08/84 " 6750 - 7473 __ ~::'~: CPL Cyberlook "- 11/06/84 Run 1 3198 - 7286 2"/5" DIL-SFL/GR 2"/5" Density Neutron "Poro" 11/06/84 " 3198 - 7286 _ 11/06/84 " '6600 - 7261 " 2"/5" " " "Raw" 11/06/84 i, RFT "DIL-SFL/GR, FOC-CNL/GR" /,~xJ~-?W=3 CPL Cyber loo--~~ ~" 2"/5" Density Neutron "Poro" · ' ( , ~ II 11 1! , l~aw! ! /cat -- Receipt Acknowledged: 11/07/84 10/31/84 10/31/84 10/31/84 10/31/84 DISTRIBUTION B. Currier DYilling W. Pasher BPAE ~Geology ~----~ G. Phillips Chevron Mobil Phillips Oil " 5600 - 7261 Run 1 7350 -'.8050 " 3757 - 8080 " 3557 - 8050 " 3757 - 8080 Alaska Oil & Gas C. ons, Commissior~ State of ' ' -~::¢/3 Sohio Union D & M NSK Ops. J. Rathmell Well Files ARCO Alaska. Inc. is a subsidiary of AtlanlicRich'lieldCompany ARCO Alaska, Inc. Post Office/--",x 360 Anchorage, ..,aska 99510 Telephone 907 277 5637 Date: 1/31/85 Transmittal No: 5014 RETURN TO: PAGE 3 of 3 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. <2G-15 IT CPL Cyberi0ok 2"/5" DIL-SFL/GR 2"/5" Density Neutron "Raw" 2"/5" " ' " "P.oro" CPL CYberlook · 2"/5" FDC-CNL/GR "Poro" 2"/5" " "Raw" "2"/5" DILLSFL/GR Str.atigraphic Dipmeter SHDT : 10/01/84 ' RUn 2 6050 - 6520 10/01/84 " '3200 - 6626 10/01/84 " 6050 - 6600 10/01/84 " 6050 - 6600 10/15/84 Run 1 6350 - 6894 '10/15/84 " 6350 - 6894 10/15'/84 " 6350 - 6894 10/15/84 " 2728 - 6934 .. 10/15/84 " 6350- 6940 /cat Receipt Acknowledged: B. Currier BPAE Chevron DISTRIBUTION .. Drilling Geology'~~ Mobil W. Pasher G. Phillips Phillips Oil ~.¢~chcrage State of AK ~ · Sohio Union D&M NSK Ops. J. Rathmell Well Files ARCO Alaska. Inc. ia a subsidiary of AtlanhcRichfieldCompany ARCO Alaska, Inc. Post Office B~.. ,00360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 29, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2W-6 Dear Mr. Chatterton: Enclosed is a copy of the 2W-6 RFT data to include with the Well Completion Report, dated 01/21/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L89 Enclosure xc: 2W-6 Well File 0 4 1985 Alaska OJ~ & Gas Cons. commissior~ Anchom. ge ARCO Alaska, inc. is a Subsidiary o! AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 22, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2W-6 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not received the portion of the 2W-6 Well History covering the completion details. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L65 Enclosures Alaska OJj & Gas Con:~. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ,~---~ STATE OF ALASKA ALASKA ,AND GAS CONSERVATION CL. AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-194 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21211 4. Location of well at surface 9. Unit or Lease Name T ~ .......... _ ~ 1199' FNL, 558' FEL, 5ec.33, T12N, R9E, UN L©C/'~rlC'N3i Kuparuk River Unit At Top Producing Interval I VEP,!FiFD I 10. Well Number 1400' FSL, 1269' FEL, 5ec.33, T12N, RgE, UN ISurf. ~ I 2W-6 ! At Total Depth I B. H. ~ ~.2 11.Field and Pool 1044' FSL, 1360' FEL, Sec.33, T12N, RgE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 95' RKBJ ADL 25642, ALK 2573 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J15. Water Depth, if offshore ]16. No. of Completions 11/02/84 11/07/84 12/16/84I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I-VD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7400'MD,G264'TVD 7314'MD,G195'TVD YES [] NO []I 1827 feet MD 1450' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR/Cal/FDC/CNL, RFT, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD .._ SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 92' 24" 260 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3196' 12-1/4" 870 sx AS III & 790 sx Class G 7" 26.0# J-55 Surf 7393' 8-1/2" 325 sx Class G & 250 s~ AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7193' - 7196' 3-1/2" 6955' 6651' & 6935' 7114' - 7118' w/4 spf, 90° phasing 711 2' - 7085' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 6897' - 6803' w/12 spf, 120° phasing ,. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO · : TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL 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. NONE · -~t_,,.. 2 9 !985 Ataska 0il & G~s Cons, C:J~urljs.sj~,~ Form 10-407 GRU3/~C40 ~ Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~. --:::-,~.~,-~;: ~-~ ~.~.. ~ ,.:.' ~ ,-.- ~ ~_;._ ,~,.~- ~ ~ .... · ~,~. ~:?'~ ~. , . ..:.. ~ . . ~., ~ .~, .. . . . NAME Include interval tested, pressure data, all fluids recover~ and.gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of. each phase. _ . _ . Top Upper Sand 6801~ 5790~ See attached sheet for RFT results, Base Upper Sand 6899'~ 5867~ (EFT results wi]] be forwarded when Top Lower Sand ' 70~~ -~ 5980~ they are received,) . ~se Lower Sand 7201~ 610~~ . . _ . . . . . 3'1. LIST OF ATTACHMENTS . . 32;-' ..... I' h~ce~i~- ~ ~ f~r~~'~r~e~ corre~ ~o ~he be~ ~f my ~nowl~dge Signed ~ ~. ~ Title Associate Engineer 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), s° 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 (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. 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". ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Rel~rt" on the first Wednesday after e well is spudded or workover operations are started, Daily work prior to sPudding should be summarized on the form giving inclusive dates only. District County, parish or borough I State Alaska North Slope Borough I Alaska Field Lease or Unit ~Well no. Kuparuk River ADL 25642 ALE 2573 2W-6 Auth. or W.O. no. T t e AFE 203599 Drilled PARKER #141 APl: 50-029-21211 Operator ARCO W.I ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date ]Hour Pr or status if a W.O. Spud 11/2/84 I 1200 Hrs. Date and depth as of 8:00 a.m. RECEIVED 1985 Complete record for each day reported 11/02/84 11/05/84 11/06/84 11/07/84 16" @ 92' Moving rig. 16" @ 92' 4145', (4053'), Drlg Wt. 8.6, PV 6, YP 9, PH 10, WL 18, Sol 4 : Accept ri~ @ 0500 hrs, 11/2/84. NU diverter sys. Spud well @ ~ 1200 hrs, 11/2/84. Drl 92'-1496', TOH & PU bent sub & mtr, TIH drl 1496'-3205', short trip, POH to rn csg. Rn 80 jts, 9-5/8" J-55 butt w/shoe @ 3196', FC @ 3115' Circ & prep to cmt. Ctm 9-5/8" csg w/35 bbls wtr & 870 sx AS III w/ l/2#/sx D-29 @ 12.2 ppg. Tail in w/790 sx C1 "G" w/2% S-1 & .2% D-46 @ 15.8 ppg. Displ w/10 bbl wtr & 231 bbls, 9.4# mud. Bump plug w/1500 psi f/15 min; OK. Lost rtns w/131 bbls displm't left. ND 20" diverter & rn 1" tbg in ann. Pmp 200 sx AS I cmt mx'd to 15.8 ppg; good rtns. NU BOP & tst per ARCO specs. PU BHA & TIH. Tst csg to 1500 psi f/15 min; OK. DO. Perform leak-off tst to 12.5 ppg EMW. Drl to 3408' TOH, PU mtr, TIH & drl 3408'-4145' 1490', Assumed vertical 1900' 2241' 2683' 2903' 3119' 3278' 3997' , 3.7°, N52E, 1899 TVD, 2 VS, 1M, 2E , 52.° S75W, 2240 TVD, 5 VS, 4S, 6W , 21.3~, S18W, 2670 TVD, 104 VS, 100S, 30W , 29.1°, S145W, 2869 TVD, 198 VS, 189S, 56W , 37.1°, S16W, 3050 TVD, 316 VS, 303S, 88W , 39.8°, S15W, 3174 TVD, 414 V$, 398S, l14W , 43.1°, SllW, 3702 TVD, 902 VS, 874S, 223W 9-5/8" @ 3196' 6857', (2712'), TIH Wt. 10.3, PV 13, YP 8, PH 10, W-L 7.1, Sol 11 Drl & surv 8½" hole 4145'-6857', TOH, chg BHA, TIH. 4369', 42.7°, S10W, 3975 TVD, 1154 VS, 1123S, 270W 5087', 43.2°, S16.5W, 4499 TVD, 1645 VS, 1595S, 402W 6148', 40.1°, S16.5W, 5292 TVD, 2349 VS, 2271S, 602W 6782', 38.9°, S15W, 5781TVD, 2752 VS, 2658S, 712W 9-5/8" @ 3196' 7310', (453'), POH Wt. 10.2, PV 15, YP 17, PH 9, WL 6.3, Sol 12 Wsh & rm 6800'-6815' Drl 8½" hole 6857'-7310', circ & sweep hole, POH. RU Schl, rn DIL/SFL/SP/GR/CAL/FDC/CNL f/7295'-3196' Rn RFT & tl stopped @ 4621' on ledge or tight spot; unable to wrk thru same. RD Schl. RIH, no bridge, circ & sweep hole w/hi-vis pill, POH. 7240', 38°, S14W, 6140.55 TVD, 3037.21VS, 2934.39S, 784.21W The above is correc, t Alaska 0il & Gas Co~g..g~,ih~issw, n For form preparatig'j~ and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date Title 11/21/84 Drillin~ Superintendent AR3B-459-1-D Number all daily well histo~' forms consecutively as they are prepared for each well. iPagle no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report complelion and representative test data in blocks provided. The "Final Report" lorn may be used for reporting the entire operation if space is avadable. Accounting cost center code District JCounty or Parish State Alaska I North Slope Borough Alaska Field IL ...... Unit IWell no. Kuparuk River ADL 25642 2W-6 Auth. or W.O. no. ITitle AYE 203599 I Drill~ Parker 141 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spud Date and depth Complete record for each day reported as of 8 00 a.m. API 50-029-21211 11/08/84 11/09/84 JA.R.Co. W.I. 56.24% IDate 11/2/84 Iotal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our ~ Prior status if a W.O. 1200 hrs 9-5/8" @ 3196' 7400' (90'), Rn'g 7" csg Wt. 10.3, PV 12, YP 10, PH 9.0, WL 6.4, Sol 11 Fin POH, RU Schl. RIH w/RFT tool to 7298', took 19 RFT's, POH,' RD Schl. RIH to csg shoe, break circ, cut DL, RIH, broke circ @ 6000', rm to btm; hole tight & packing off. Drl to 7400'. Circ hi-vis pill. POH 20 stands (normal drag). POH, LD DP. RIH w/20 stands & LD same. LD BHA. Changed top rams to 7" tested to 3000' psi. Run 7", 26 ppf J-55 BTC csg. 86 jts in hole @ 0600 hrs. 7314' PBTD, (0), RR Wt. 10.2 brine Finished rn'g 188 jts + 2 marker jts, 7", 26#, J-55 BTC csg to 7393' Circ for cement. Pmp 45 bbls of Spacer 3000 @ 11.0 ppg. M&P 325 sx of class "G" & .3% KC1 & .8% D-60 & .2% D-46 @ 15.8 ppg. Dropped top plug & displaced w/brine. Bumped plug to 3000 psi. Good reciprocation throughout job. Held pressure for 15 mins. Bled off pressure = floats held. Blew out brine in 7" Changed rams. Picked up stack & set slips. Made rough cut, set back BOP's & make final cut. Installed pack-off & tubinghead & tested to 3000 psi. RR @ 1700 hrs, 11/08/84. Float collar @ 7314' (top), Shoe @ 7393' OIdTD I New TD I I PB Depth Released r~g Date ~Kind of rig 1700 hrs 11/08/84 Classifications (oil. gas, etc.) Type completion (single. dual. etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 7314' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gasTest t~me Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected Signature For form preparation and distdP0[ion, see Procedures Manual, Section t0. Drilling, Pages 86 and 87. AR3B-459-3-C correct Date 1 Dril ling Superintendent -il~ED Alaska 0il & Gas Cons. C~.ffg,.~.~ii~.iy we,, .~.,o~ fo .......... tively Pag .... 2W-6 Arctic pak w/250 sx AS I, followed w/54 bbls Arctic pak. Date ARCO Oil and Gas Company Well History - Initial Report- Daily Inetn~cUone: Prepare and submit the "lnltlM Refl~rt" on the first Wednesday after a well is spudded or workover operations are stmled. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 203599 ICounty. parish or borough North Slope Borough ILease or Unit ADL 25642 ALK 2573 ITitle Completion IState Alaska IWell no. 2W-6 ROLL'N 4 API: 50-029-21211 Operator ARCO Alaska, Inc. Spudded or W.O. begun Completion Date 12/14/84 IH°ur Date and depth aa of 8:00 a.m. 12/14/84 Complete record for each day reported / / 0030 Hrs. ARCO w.I. Pr or status if a W.O. 7" @ 7393' 7314' PBTD, Prep to Perf 10.2 NaC1/NaBr Move rig f/2W-8 to 2W-6. tree, NU BOPE & tst same. perf. Accept ri~ @ 0030 hrs, 12/14/84. RU Schl & tst lub, ok. Prep to ND RECEIVED Alaska Oil & Gas Cons. Cornrnissior~ Anchorage 56.24% The above is correct Signature For form preparation and diatrij~tlo~,- -- see Procedures Manual, Sectioft 10, Drilling, Pages 86 and 87. IDat, 12/31/84 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when ol3erations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative lest data in blocks provided. The "Final Reporl" form may be used for reporting the entire operation if space is available. I Accounting cost center code District County or Parish State Alaska Alaska North Slope Borough Field Lease or Unil Well no. Kuparuk River ADL 25642 ALK 2573 2W-6 Auth. or W.O. no. T tie AFE 203599 Completion ROLL'N 4 API: 50-029-21211 OperatorARCO Alaska, Inc. A.R.Co. W. k56,24% Iaband°nmentlc°st[T°tal centernumberprior°fof wellSthistO pluggingwell(active and°r inactive) on this Spudded or W.O. begun Date IHour Prior status if a W.O. Completion 12/14/84 / 0030 Hrs. Date and depth as of 8:00 a.m. 12/17/84 Complete record for each day reported 7" @ 7393' 7314' PBTD, 7400' TD, RR Kup Crude Perf "A" sand 4" guns @ 4 SPF, 90° phasing f/7193'-7196' & 7118'-7114' & 7112'-7085' & 7074'-7063' w/Hyperjt II charge. Perf "C" sand w/ 5-1/2" scalloped guns @ 12 SPF, 120° phasing f/6897'-6803'. PU 6.125" gauge ring &jnk bskt. RIH t/7050', POOH. MU Bkr FB-1 perm pkr & TP assy. TIH. Set @ 6933'. MU 3-1/2" comp string & RIH. Rn 12 GLM's & 157 jts 3-1/2" 9.3# J-55 8RD EUE, 1PC, tbg. PU & MU Bkr FVL SSSV. Tst same t/5000 psi, ok. Fin RIH w/total of 216 jts 3-1/2" tbg, sting into SBR & space out. Drop ball. MU FMC Gen III tbg hgr & 6' pup & ind. Press up t/2500 psi & set pkr. Press tst top of pkr w/2500 psi, ok. ND BOP stack. NU FMC Gen III tree & tst t/5000 psi, ok. 35 bbls diesl ahead. Displ well w/196 bbls crude. Tst SSSV, ok. Press tbg orifice tst, ok. Press tbg t/3700 psi & shear ball. Set BPV. Bkr FVL SSSV 1826.63', Bkr FHL pkr 6650.53'. Bkr FB-1 perm pkr set @ 6933' WLM 6935.01'. 12/18/84 'D' nipple @ 6949' ReleaSed Rig @ 1300 hfs 12/16/84. RECEIVED Alaska Oil & Gas Cons. C0rr~mJss/or~ Old TD Released rig 1300 Hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data INew TD Date PB Depth ...... 7400' 73t4' 12/16/84 K nd of Hg Rotary Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test lime Production Oil on test Gas per day Pump size, spa X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective data corrected The above is correct Signature~7~I~ ~~J ' I Date For form pre-par%t~ .... d d;s;ri~j~l;on, - see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 12/31/84 ITM Drilling Superintendent 2W-6 RFT Data DEPTH (MD) 6828 6835 6849 6856 6891 6938 7067 7091 7097 BUILD-UP PRESSURE 2791 )sia 2791 osia 2795 ~sia 2832 ~sia 2794 ~sia 2841 ~sia 2994 ~sia 2998 ~sia 2999 )sia HYDROSTATIC PRESSURE 3164 )sia 3164 )sia 3170 ~sia 3169 ~sia 3182 ~sia 3201 ~sia 3262 ~sia 3264 ~sia 3259 )sia DRN/110:tw 01/25/85 RECEIVED r~B 0 4 1985 Alaska Oil & Gas Cons. Commission Anchorage SUB.$URFA CE DIRECTIONAL SURVEY n'~ UIDANCE F~ONTINUOUS Fl] COL Company ATLANTIC RICHFIELD COMPANY · m mm Well Name 2W-6 (1199' FNL~,558' FEL~ S33~ T12N~ R9E~ UM) Field/Location KUPARUK, NORTH SLOPE, ALASKA ...... Job-Reference No. 69862 Lodged By: D. BARBA GCT DIRECTIONAL SURVEY CUSTOMER LISTIN~ F:gR ARCO ALASKA, INC. 2W-6 ~UPARU~ NORTH ~LOP~, ALASKA SURVS¥ 2ATE: ZO-NOV-8~ METHODS DF COMPUTATION TOJL L'OCATIGN: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LI,~EAR V~RTiCA~ SECTIGN: HOR[Z. L)IST. PR,OJ.~CTED ONTO A TARGET AZZMUT~ ~F S~UTH 15 OEG 32 MTN i SCHLUMBERGER ARCO ALASKA. INC. KUPARUK NORTH SLOPE, ALASKA NOVEMBER 2S, !984 TVkl PLOT FROM OCT DATA JOB REFERENCE 6986:2 SURFACE LOCATION' 1199' FNL, 558' FEL, S33, T12N, .R9E, UM VER?~CGL PROJECTION PROJECTION ON vERTICAL PLANE OF AZIMUTH 1~6 $CAt. EO IN VERTICAl. OEPTHS HORIZ SCALE = I/I000 IN/FT WELL' 2W-6 SURFACE LOCATION' 1199' FNL, 558' FEL, S33, T12N, R9E, UM HoRIZONTAL PROJECTION ~R'rH ~EF 69862. 6CI:~.E -- 1 ! 1~ N/FT · o .... ~--.._~..~...: .......... , .............. ?..e ........ ~.-.t ............. ~_,;.._: ......... p ,..,...:.-.:.f ................ h ............... ~ .............. i ............................... ~ ......................... , ..................... ................ ............. ~.- .,L .:..:.._z...L.L ..... :..,. i...:..._. ~ ...... -lggg · ; - · i ~ . : . ~ . .~........ . ................. ~ .................. ~ ................. i ................. i ................ ~ ....... : ........... ¢. ----~ ........................................................................... ~ ................................. ";-"~'-'t-"T"T''~''':'''? -~--'t--'t--'~- -T -:-' t": ............ r ............. t ............. :-":- t"t ............. t ............. :' t ............ ,'"t .................. f ..................... t ...... t' "' ~' '" ' ~"t ............. ............... · ............. ~ ..................... t ~ ................... t ......... : ~, ...........f .... ' ............ ~, ................... * ~, ...................... ~ f ................~' ': ...... ;"T'~"~'"T'T 7 ~ ...... T'7''-'''~ ................ : ......... :'"-"" ............. ~ .............. :'": ................ ~ .................. ' ............... ~ .................... ~ .............. ~:Z':L.~: .................... ..... . · i , . i . , . . i . ~ . ~-~ .~..4 ............ -- t'-'----- ............ - ............... t ...... · ......... ~ ........................ · ...... -'""-'?' ~"~-*- j ........... 4-'* ..... - ................................ · ....................... ' ..................... ......... :.-.:.-- ; ~;' ,] .:.' : ' , [ '' ! ~' ] '~ ~ ~ I ...... ...... ......... ........... ........ ......................... ....... ........... :--t ............... .... I I . :, ~. .......... t~ j ' .......................................................... , ............. ...... .;;~:.i~;.:.:', ...... L:.._~.: ...... '-.: ..... ~..:.; .......... l ............ ~ ......... l..: ...... : .....1..:.-:~ .... ;1 ..... ~ ......~ ..... ; . .......... ~--~ ................ ; -- L ..... i ........ t ..........; ........ ; ........ ~ ........ : - - ~ ........... ; .... , ........... .... ...... ~' :"~ ........... ...1 .......... -4000 , - ~ . : . . . ...... .......... -r*-: : ....... ~ ...... ~ ..... ~ ..........+ ........ : ................... ~ .... ; ........... ~ ........ : ; [ ......... · ~-:-~ ..... ~ ..........f ....... ~ .... : ........ ~ ......... : ..... t ....... : ........ : ......... ~ ........ 1. ' ;'7':':"'~ ............... r .............. :'- ~ ....... ~ ..........~ ............. ~ ............. t ..... :---~ ..... ~ .........; ......... ~ ......... , ..... : .... t ............... -BOO0 .................. ~ .......................... t ................ : ........... f .................. ~ ..................... ' ............ ~ ......... t ........................ ....... ~..; ...... ; ........ + ~ ......................... ~ ..... ~ ....................... . ...... .... ~---: - .... .............. .................................................... -60~0 ...........: .................................................................................. ~ ............... . .... :....: ...... ......... ........ ~ ..... + .............. ~..~ ......... ~ ................ ~ ..................................... ~ .............. ~ ........ ,~ ~.~ ,-~ ......... ~ ....... ~ ............. ~ ................ ~ ................ ~ ........................ ~ .... , - . ~ ' . ~ ........... ~ ..... : - . . ~T EAST GCT DIRECTIONAL SURVEY CUSTOMER LISTING F~R ARCO ALASKA~ INC. ZW -6 KUPARUK NORTH SL~PE~ ALASKA SURVEY DATE: 2o-NOV-8~ 2N$INE~R: 0. BAR~A METHODS 2F C~MPUTATI3N TO3L LOC&TION: TANGENTIAL- AVERAGED Dc¥IATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HSRiZ. giST. PR]JECTEg ONTO A TARGET AZIMUTm OF SOUTH 1S gE~ 32 MIN WEST COMPUTATZ3N OATE: 17-DEC-84 PAGE RCO ALASI(.A, [NC. W-6 ~JPAR;JK DRTH SLI3PE~ ALASKA DATE OF SURVEY: 26-N3V-84 KELLY BUSHINS ELEVAT£ON:' ENGINEER: D. 5ARBA INTERPOLATEO VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUb-SEA COURSE ASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG HIN OEG MTN 0.00 0.00 -95.00 0 0 N 0 0 ~ 100.00 100.00 5.00 0 10 S 73 35 e 200.00 200.00 105.00 0 '7 N 82 4~ ~ 300.00 300.00 205.00 0 3 N 66 ? E ~00.00 400.00 30J.O0 0 11 S I 35 W 500.00 500.00 405.00 0 10 S 28 28 E 600.00 600.00 505.00 0 9 S 79 ZO E 700o00 700.00 605.00 0 7 a 79 50 E $00.30 800.00 705.00 0 L N 41 [ ~ 900°00 900.00 805.00 0 6 S 65 35 W VERTICAL OOGLEG RECTANGULAR COORDINATES H,1R:Z. DE,PARTUR~ SECTION SEVERITY NORTH/SOUTH EASTYWEST DIST. AZ, JMUT~ FEET bEG/lO0 FEET FEET FEET 0.00 0.00 0.00 N 0.00 0.0! 0.22 0.06 S 0.10 -0.12 0.11 0.02 N 0.3~ -0.22 0.36 0.08 N 0.50 -0.05 O.Oa 0.08 S 0.46 0.24 0.29 0.39 S 0.52. 0.35 0.21 0.57 S 0.75 0.2.9 0.16 0.58 S 1.01 0.20 0.16 0..52 S 1.13 0.24 0.17 0.55 S 1.08 ,, 0 11 S ~ · 6B~I9 E 0.35 N, 0 E 0.51 Ni8'O ,i;19 E 0.47 S"' 80',,i!3 9 E 0.65 S '52 '33 E 0.94 S 52..'~48 E 1.17 S 60" 4 E 1.23 S 6S 20 E 1.22 S 63 4 E 000.00 LO00.O0 100.00 LlO0.O0 1005.00 ZOO. O0 1199.99 110~. ~9 300°00 /299.99 1ZOO. 99 400o~0 1399.99 1306.99 500.00 14.99.99 1404o')9 bOO.DO /599.98 1504.')8 700.00 /699.98 1604.98 800.00 L799.97 1704.97 900.~0 /899.95 1804.95 0.,:,4 0.05 0.69 S 0.84 E 0.55 0.16 1.00 S 0.45 ~. 1.36 0.33 1.42 S 0.02 6. 1.92 0.15 1.86 S 0.49 W Z.55 0.16 2.36 S 1.01 W 3.33 0.05 2.99 S 1.65 W 4.21 0.49 3.71 S 2.30 W ,~.$6 0.1,4 4.28 S 2.76 W 5.38 0.25 4.68 S 3.2% WI ~.~6 4.34 4.11 S 1.86 W 1.09 S 50 Jl E l.lO S Z~ 17 E 1.42 'S 0 40 E 1.92 S 1,~ 37 W 2.57 S 23 12 W 3.42 S 28 S3 W 4.40 S 32 24 W 5.09 S 3l 49 W 5.69 S 3½ ~1 W 4.51 S 2~ 20 W 000.00 1999.81 1904.82 1 3.1 100.00 Z099.81 200~.81 1 16 200.00 2199.69 210~o69 4 Z 300.30 Z299.23 2204.13 6 59 400.00 ?.3 ~)8 . 07 230~.07 I0 2~ 500.00 2495.79 2400.79 14 7 600.00 2591.73 2~95.73 18 ~'~ 700.00 2685.61 2590.61 21 48 800.00 2777.29 2682.29 25 16 900.00 2866.2~ 2771.25 28 5~ 0.71 2.42 1.31 S 0.32 3.70 0.94 S 4.95 3.31 5.08 S 1,~. 36 3.43 14.36 S 29.60 3.19 29.12 S 50.34 4.19 49.78 S 78.62 4.1~ 76.85 S 113.01 3.58 109.57 S 152.85 3.78 1~7.45 S 198.~5 3.9d 190.9~ S 2.03 E 2.42 S 57 19 E 2.15 E 2.36 S 66 33 E 0.20 W 5.08 S 2 16 W 1.96 . 14.49 S '? e6 W 4.98 w 19.5~ S 9 42 W 9.63 w 50.70 S 10 56 W 17.09 ~ 78.75 S 12 32 W 27.77 ~ 113.04 S 1~ L~ W 60.30 ~ ~2.85 S ~5 ~ ~ 53.95 d ~98.45 S ~5 ~6 ~ 000.00 2952.21 2857.21 32 30 100.00 3034.89 2939.89 35 52. 200.00 3113.87 3019.87 38 53 300.00 3191.05 3095.05 40 30 400.00 3265.70 3170.?0 42. 39 500.00 3338.76 3243.16 ~,3 15 500.00 3411.60 3316.o0 4,3 1~ 700.00 3484.42 3389.42 ~+3 2.0 800.00 3556.92 3~,61.~2 43 3,~ 900.00 3619.43 353+.~+3 ~+3 29 S 15 45 W 24::~o:~C) 3.70 S 15 50 W 305.74 3.82 S 15 ZZ W 367.04 0.51 S 15 3 W ~,30.61 2.55 S 14 58 W ~97.14 1.22 S 14 41 W 565.42 0.26 S I.~+ 2 W 633.92 0.46 S 13 wi W ?02.43 0.34 S 13 31 W ~71.2~ 0.33 S 13 1Z W 840.07 0.31 240.03 S $8.11 W 2~9.51 S 1.,5 50 W 294.17 S 83.32. W 305.74 S 15 ,~8 W 353.19 S 99.89 W 367.05 S 15 47 W 414.55 S 116.51 W 430.~b1 S 15 41 W 478.82 S 133.74 W 497.14 S 15 36 W 544.83 S 151.21 W 555.42. S 15 30 W 611.18 $ 168.27 w 633.92 S 15 23 w 677.74 S 1~4.63 w 702.4~+ S 15 ~4 W 744.62' S 200.85 W 771.28 S 15 5 W 811.67 S 21.6.75 d 840.12 S 1~+ 57 W ARCO &LAS(.A~m INC. 2W-6 KUPARLJK NORTH SLOPEr ALAS<A C~MPUTATI3N DATk: 17-91C-84 PA~E DATE OF SURVEY: 26-N3V-8¢ KELLY ~USHIN2 ELEVATION: ENGINEER: D. 6ARBA [NT2RPOLATED VALUES FDR EVEN lO0 FEE'T OF MEASURED DEPTH TRUE ~UO-SEA COURSE IEASURED VERTICAL VERT[CAL DEVIATION AZIMU[H DEPTH DEPTh DEPTm DEG MIN DEG M£N 95.00 FT 4000.00 3702.16 3b07.18 4.3 12 4100.00 3775.13 3680.13 ~3 6 4200.00 35~8.23 37~3.Z3 ~2 58 4300.00 3921.43 3826.~3 42 55 4400.00 3994.71 3899.71 ~2 48 4500.~0 ~068.28 3973.~ 4~ 25 4600o~0 ~141.98 4046.98 ~2 55 4700.00 ~2[~.68 4119.58 43 33 4800.00 ~287o06 419g.06 ~3 39 4900.00 ~359.40 4~6~o~0 43 36 S 13 3 m S 12 57 a 976.96 S 12 51 w 104~.12 S 12 ~3 m 1113.17 S 12 32 W 1181..14 S 12 11 W 12~8.76 S 14 35 W 1315.27 S 16 13 W 138~.94 S 16 I W S 16 0 W 152Z.~7 0.19 0.17 0.20 0.1~ 0.3i 0.40 2.50 0.26 0.23 0.23 878.'*5 $ 232.36 d 908.69 $ 16 ~,8 W g~,5o12 S 2¢7.78 W 977.06 ~Si''I¢ ~1 W 1011.6~ S 163.00 W 1045.Z~ ,S 16 34 W L078.08 S 218.09 W 11/3.3~ S 16 t7 W 1166.47 S 292.99 W 1181.38 S 16 Zl W [110.63 S 397.51 W 11~9.07 S 16 15 W 1276.48 S 322.6~ W ~316.63 S ,~ ~1 W ~3~2.56 S 3~1.38 W 1385.28 S ~ ~5 W Z~08.83 S 3~0.56 W 14S~.2~ S I~ Zl W 1475.21 S 379.55 W 1523.26 S 14 15 W 5000.00 t~431.95 &336. :)5 ~3 22 5100.00 ~504.68 4409.68 43 19 5200.00 ~577.48 4~8Z.~8 43 7 5300°00 %650.67 4555.67 ~ 49 5~00.00 ~724.15 4619.15 ~2 29 5500.00 ~798.14 6103.1~ ~2 5 5600,00 ~871.60 4777.50 ~1 ~3 5700.~0 ~9~7.52 ~8S~.52 ~1 ga 5800.00 5022.52 4927.~2 al 13 5900.00 ~O~a. OZ 5003.01 ~0 56 $ 16 5 W 1.591.79 S 16 5 ~ 1660.62 S 16 12. d 171U.97 S 16 13 W 1797.12 S 16 1Z W 186~.83 S 16 3 W 1932.20 S 15 59 W 199~.95 S L5 ~7 W 2065..18 S 15 4L W 2131.32 S 15 3~ W 219~.89 0.17 0.11 0.24 0.7~ 1 0 1541.3~. S 398.59 W 1592.05 S 1~ 29 W 1607.29 S 417.62. W 1660.66 S 14 33 W 1673.13 S 436.72 W 1719.19 S 14 37 W 1738.57 S ~5.7~ W 1797.31 S 1~ ~1 W 1803.60 S 474.6Z W 1885.0i S 1~ ~4 W 1868.31 S 493.41 W 1931.36 S 1~ ~7 W 1932.45 S 511.86 W 1999.09 S 16 ~0 W 19'96.15 S 530.0~ d 2055.32 S 16 52 W 2059.80 S 5~6.00 ~ 2131.~5 S 1~ ~3 W 2122.93 S 565.72 w 21~7.01 S ~ 55 W 6000°00 5173.83 5078.83 ~0 23 6100.00 5250.10 5155.10 WO 17 6ZOO.DO 5316.44 5231.,i, 4 4.0 9 6300.00 540Z.96 530 7. :)6 39 55 61*00. 00 5½79.82 538~.82 39 45 6500.00 5556.81 5~,6 1.81 39 2.3 6600.~0 5634.27 5539.£7 39 13 6700.00 5711.75 5615.75 39 7 6800.00 5789.50 5594.50 38 50 6900.00 5867.63 577Z.63 38 4.0 S 15 2.7 W Z262..11 $ 15 2.1 W 2326.79 S 1~, 55 W 2391.38 S 14 36 W 2,~55.76 S 14 19 W 2519.72 S 1~, I W 2563.51 S 13 53 W 2646.73 S 13 53 W 2709.91 ~ 14 19 ~ 2771.79 0.47 0.17 0.41 0.85 0 0 0.16 0 0 0.70 2185.75 S 583.1,~ W 2262.23 S 14. 56 W 22/,8.1,1 $ 600.40 W 2326.91 S 14 57 W 2310.45 S 617.31 d 2391.50 S 1½ 57 W 2372.71 $ 633.7~ W Z455.88 S 1~ 57 W 2434.6~ 5 6~9.74 W 2519.85 S 16 ~6 W Z496.51 S 665.36 W 2583.65 S 1~ 55 W 255~.90 S 680.58 W 26~6.89 S ~ 53 W 2619.Z8 S 6~5.70 W Z7~0.09 S ~ 5Z W 2680.2~ S 7~0.g8 W Z7~2.99 S 1~ 51 W 27~0.70 S 726.6~ W 2835.39 S X~ 50 W 7OO0..qO 5945.77 5850.77 38 24 71.00. O0 ~024.35 5929.35 37 58 72.00.00 5103.41 6,)0 ~3.41 37 21 7300.00 $183.40 6088.'*0 36 44, 7½00.00 5263.53 6168.53 36 4.4. S 14 3 w 2897.58 S 13 5) w 3020.bl S 14 53 W 3080.62 S 14 53 W 3140.44 0 0.50 1.38 O.OO 0.00 2801.20 S 741.93 a Z897.79 S 1,~ 50 W Z861.19 S 757.01 W 2959.64 S 1~ 49 W 2920.63 S 7?1.70 W 3020.86 S 14 ~8 W 2978.70 S 786.85 W 3080.81 S 14 e7 W 3036.52 S 802.22 W 31~0.70 S 16 ~7 W VERTICAL DDGLEG RECTANGULAR C30RDINAT6S HDRIZ. DEPARTURE SECTION SEVERITY NDRTH/'SOUTH E~ST/WEST DIST. ~'Z~MUT~ FEET DEG/IO0 FEET FEET FE~T D:EG MIN CDMPUTATIDN DATE: PAGE ARCO ALAS~A~ INC. 2~-6 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: Z6-NDV-8~ KELL~ 6USHIN~ ELEVATION: ENG£N~ER: D. ~ARBA '9 5,.,0 Cl F! ZNTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT TRUE SU~-SEA COURSE IEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPT~ DEPTH ~)EPTN DEG MIN DEG M[N 0.00 0.00 -95.00 0 0 1000o00 1000.00 905.00 0 14 2000.00 i999.82 1904.~2 1 31 3000.00 Z952.2,1 2857.2i 32 30 4000.00 3102.18 3607.L8 43 12 5000.00 ~431.95 4336.95 43 22 6000.30 5113.8~ 5078.83 4,0 23 7000.00 5945.77 5850.77 38 24 N 0 ~ E 0.00 N %8 13 f 0.71 S 15 45 ~ 249.50 S 13 3 ~ 908.52 S 16 5 ~ 1591.79 S 15 £? ~ 2262.I1 S 14 ~ a 2ag~.~a VERT:CAL DOGLEG RECTANGULAR CDORD[NATES H2RIZ, S.:CTI~N SEVERITY NDRTH/SOUTH EAST/~EST 0.00 0.00 a 0.00 0.05 0.6~ S 0.8~ E 1.09 2.42 [.31 S 2.03 E 2.42 3.70 240.03 S 58.1[ '0.19 878.48 S 232.36 W 908.69 0.15 1541.34 S 398.59 ~ 1592.05 0.~7 21~5.75 5 5a3.2~ 0.32 2801.20 S 76L.93 COMPUTATION DATE: 17-0EC-84 ARCO ALASKA, INC. 2W-6 KUPAR~K NORTH SLOPE, ALASKA DATE OF SURVEY: 26-NOV-84 KELLY &USH[N~ ELEVATION:' ENGINEER: O. 6ARBA 95.00 FT INTERPDgATEO VALU'~S FOR EVEN 100 FE~T OF SU~-SEA DEPTH TRUE SUS-SEA COURSE E&SURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG NIN DEG MIN 0o00 0.00 ,-95-00 0 0 N 0 0 ~ 95.00 95.00 0.00 0 10 S 12 53 ~ 195.00 1~5.00 lO0.O0 0 7 N 82 3~ E 295.00 295.00 200.00 0 3 N b7 30 E 395.00 395.00 300.00 0 11 S 2 17 W ~95.00 495.00 400.00 0 10 S 2.3 45 Y. 595.00 595.00 500.00 0 9 S 75 ~ 5 699.00 695.00 600.00 0 I N 82 3 E 795.00 795.00 700.00 0 Z N 32 12 E 895.00 895.00 800.00 0 5 S 65 ~7 W VERTICAL DOGLEG RECTANGULAR C80RDINATES H3RIZ. DEPARTURE SECTION .SEVERITY NORTH/SOUTH EAST/WEST DIST ,' FEET DE&/IO0 FEET FEET FEET '~,~G 0.00 0.00 0.00 N 0.00 0.01 0.22 0.0~ S 0.09 -D.ll O.1l 0.02 N 0.3~ -0.21 0.27 0.0~ N 0.49 -0.07 0.08 0.06 S 0.47 0.23 0.25 0.38 S 0.51 ~.35 0.26 0.57 S 0.7~ 0.30 0.15 0.58 S 1.00 O.ZO 0.16 0.52 S 1.13 0.24 0.20 0.55 S 1.0'~ 0.00 N" O, 0 E 0.10," $ 6'1:16 E 0.3~ # 86 20 E 0.50 ,'N 80 29 E 0.41" S 82 39 E 0.64 S 5:~ 6 E 0.93 S 5'2 27 E 1.16 ,S 5'9 ~ E 1.25 S 65 1Z E 1.22 S 63 22 E 995.00 995.00 ~00.00 1095.00 1095.00 1000.00 1195.01 1195.00 1100.00 1295.01 1295.00 1200.00 1395.0! 1395.00 1300.00 1,~95.01 1495.00 1400.00 1595.0l 1595.00 1500.00 1695.02 1695.00 1~00.00 1795.~2 /795.00 1700.00 1895,.05 {.8~5.00 1800.00 0 14 S 56 3a W 0 19 S *7 30 W 0 23 S ~2 57 W 0 23 S ~,7 35 W 0 2.6 S 47 21 W 0 33 S ~+5 3 W 0 32 S ,+3 55 w 0 20 S 46 2~, W 0 17 S 53 2Z w 2 43 N O0 55 -: 0 .,,V3 0.10 0.68 3 0.86 0.82. 0.13 0.9':) S 0.47 1.33 0.2.8 1.39 S 0.04 1.89 0.15 1.84 $ 0.46 Z.51 O.Z~ 2.3~ S 0.9~ 3.28 0.06 2.96 S 1.62 ~.17 0.53 3.6a S 2.32 *.84 0.28 4.26 S 2.74 5.36 0.31 4.6T S 3.2Z 4.63 4.61 4.23 S 2.07 1.10 S 51 34 E 1.09 S 25 38 E 1.39 S 1 37 E 1.89 S 14 3 W 2.,53 S 22. 51 W 3.31 S 2.8 39 W 4.35 S 3l 17 W 5.06 S 32 44 W 5.6'{' S 34 36 W 4.71 S 2& 4 W 1995-.17 1995.00 1'900.00 I 39 2095.19 2095.00 2000.00 1 7 2195.30 2195.00 2100.00 3 54 2295.74 Z295.00 ZZOO.O0 6 51 2396.88 2395.00 2300.00 10 19 2499.19 2495.00 2400.00 14 5 2603.½4 2595.00 2500.00 18 38 2110.12 Z695.00 2600.00 22 10 2819.65 Z795.00 2700.00 26 3 2933.03 Z8E, 5.00 2800.00 30 7 N 49 0 E S $5 S 17 27 w S 11 56 W S il S 13 41 W SI7 ~ W S 18 50 W S 17 5k w S 16 13 W 0.82 2.90 1.39 0.24 3.51 0.8? 4.62. 3.30 4.71 13.63 3.68 13.84 28.84 3.18 18.58 50.35 4.18 49.59 79.70 4.05 77.89 116.77 3.39 113.14 161.35 4.19 155.54 214.71 3.20 206.59 1.94 E 2.39 S 54. 18 E 2.2..4 E 2.41 S 68 41 E 0.1! W 4.77 S 1 17 W 1.8:5 W 13.97 S I 36 W 4.88 W 18.99 S 9 40 W 9.5~ W 50.51 S 10 56 W 17.41 W 79.81 S 12 35 W Z8.99 d 116.79 S 14 12 W '~2.92 W 161.35 S 15 2.5 W 58.51 W 214.71 S 15 48 W 3051.Z7 2995.00 2900.00 34 3175.78 3095.00 3000.00 38 41 3305.19 3195.00 3100.00 40 38 3439.99 3295.00 3200.00 ~'3 3 3577.Z3 3395.00 3300.00 43 12 3714.58 3495.00 3400.00 43 28 3852.56 3595.00 3500.00 43 31 3990.1~ 3695.00 3600.00 43 13 4127.2..1 37-)5. O0 3700.00 '~3 3 4263.90 3895.00 3800.00 S 15 3~ w 277.75 3.27 S 15 33 W 351.85 1.34 S 15 7. W 433.~8 2.55 S 14 51 W 524.36 0.84 S 14 11 w 61~.34 S 13 3) w 712.45 0.27 S 13 27. , 807.47 0.60 S 13 ~ W -)01.87 0.20 S IZ 5~ w 993.52 0.27 S IZ ~l w 1088.61 0.10 267.2.3 S 75.72 w 277.75 S 15 ~.9 W 338.55 S 75.84 W 351.86 S 15 48 W 417.80 $ 117.38 W 433.98 S 15 41 W 505.11 S 140.76 W 524.36 S 15 34 W 596.06 S 154.47 W 618.34 S 15 Z5 W 687.48 S 187.00 . 712.46 S 15 13 N 779.91 S 209.2~ ~ 807.50 S 15 1 W 871.90 S 230.83 ~ 901.94 S 1~ ~9 ~ 963.2~ S 251.94 ~ 995.6~ S 14 39 ~ 1054.10 S 272.6b ~ 1088.79 S 14 30 ~ COMPUTATI2N DATE: PAGE 5 ~CO *LASKA, INC. JPARUK 3RTH SLOaE, ALASKA DATE OF SURVEY: 2b-N3V-8½ KELLY 8USHIN~ ELEVATION: ENGINEER: D. BARBA 95.0'0 FT INTERPOLATED VALUES FOR EVEN I02 FEET OF SUB-SEA DEPTH TRUE SU2-SEA COURSE *SURED VERTICAL VERTICAL DEVIATION AZIMUTH 2EPTH DEPTH OEPTH DEG MIN DEG MiN' VERTICAL DOGLEG RECTANGULAR C~20ROINATE$ HDRIZ,. SECTION SEVERITY Ni]RTH/SOUTH EAST/WEST OIST. FEET ~EG/iO0 FE~T FEET FEET DEG' ~00o39 3995.00 3900.00 ~+2 48 536.17 %035.00 4000.00 42. 23 :~71.86 6135.00 4100.00 ,:i, 3 30 ~10.98 ½295.00 4100.00 ~3 40 ~49.13 %395.00 4300.00 43 19 086.59 %495.00 4400.00 43 19 223.98 6595.00 4500.00 43 1 360.33 6695.00 4600.00 42 33 ~95.76 6795.00 4700.00 ~,2 7 52.9.92 6895.00 4800.00 *1 25 S £2 32 W 1181.40 S 12 22 w 1273.10 S 16 1L W 136~.25 S 16 3 W 1556.83 S 16 5 ~ 1651.Z9 S 16 11 ~ 17~5.34 S 16 10 W 1838.03 S i6 ~ W 1929.36 S 15 59 W 2018.7~ 0.3'~ 1.13 0.30 0 0.35 O. 1:5 0.26 0.38 0.63 0.0~ 11~+4.74 S 2-33.05 W 1181.65 S 1~,,21 W 1234.4~ S .312.65 w 11~3.4~ S~:.::I~=..1,?. W 13Z~.61 S 336.15 W 1366.60 .S:'l:4 J~ W 1416.11 S 352.65 W 1461.81 S I.& ll W 1507.75 S 3a8.91 W 1557.10 'S 1% Z7 W 15~8.51 S ~15.0) W 1651.53 S ~ )3 W 1688.85 S 4~1.29 W 17~5.55 S ~. 38 W 17~.8~ S i~.li w 1838.22 S ~ 4~ w 1865.58 S ~92.62 w 1929.52 S 1~ i) W 1951.53 S 51~.3~ W 2018.9~ S 1~ 50 W 763.33 %995.00 4900.00 '~1 2~+ 895.99 5095.00 5000.00 40 56 027.78 5195.00 5100.00 40 17 158.85 52.95.00 5ZO0.O0 40 13 Z89.$2 5395.00 5300.00 39 59 ~,19o 74 5495.00 5%00.00 39 45 $49.32 .~ 595.00 5500.00 39 11 678.60 5695.00 5600.00 39 11 807.06 5795.00 570:).00 38 49 -)35.07 58~5.00 5800.00 38 41 S i5 45 w 2107.10 S 15 39 w 219~+.26 S 15 25 W 2280.10 S 15 8 w 2364.82 S 1~ 33 W 2~49.06 S 1~ 15 W 2532.33 S 13 55 W S 13 51 W 2696. Z~ S I~ Z3 W 277~.Z2 S ~ 1~ w 285).k2 0.51 0.5'~ 0.31 0.23 0.59 0 0.25 0.41 0 1036.48 S 5:il.43 W 2.107.23 S 1/+ 53 W 211ZO.~l.O S 555,,,0~. W 119~.38 S Ii 55 W 2203.10 S 5B8.03 w 2280.22 S 1~ 56 W 2284.81 S 610.41 W 2304.94 S 1~ 51 W 2366.25 S 632.06 W 1449.21 S 1~ 5~ W Z446.87 S 652.85 W Z53,2.~) S 1~ 56 W Z526.79 S 6)2.90 W 2614.85 S 16 54 W Z606.0~ S 692.43 W 2696.~6 S 14 32 W 2684.58 S 712.01 W 2777.4l S 14 51 W 2761.96 S 731.05 W 1857.33 S 1~ 50 W 061.13 5995.00 5900.00 36 `3 189.%1 6095.00 6000.00 37 28 314.½8 5195.00 6100.00 36 4~ ~O0.O0 6263.53 6168.~3 36 44 S 14 8 W 2`33b.~4 S 13 53 W 3014.18 S 14 53 W 3089.Z8 S 14 53 W 0.49 1.18 0.00 0.00 2838.91 S 7~1.40 W Z936.6? S 1~ 49 W Z91~.38 S 770.15 W 3014.42 S 14 68 W 2987.07 S 789.05 W 3089.53 S 14 47 W 3036.52. S 802-22 W 31~0.70 S 14 ~7 W ~RCO ALASKAt lNg. ~.a-6 ~UPARL,IK ,~ORTH SLOPEr ALASKA HARKER TOP UPPER SAND BASE UP PER SAND TOP UPPER SANO BASE LOWER SAND PAT,3 TOTAL DEPTH COMPUTATION DATE: 1Z-OEC-84 I~TERPOLATEO VALUES FOR CHOSEN MEASURED OEPTH BELOW KB FROM 6801.00 5190.28 6899.00 5865.85 70~4..00 5980.28 7201.00 7400.00 6Z63.53 PAGE OATE OF SURVEY: Z6-N~V-8~ KELLY BUSHING ELEVATION: ENGINEER: O. BARBA 'iS. OO FT SURFACE AT ,ORIGIN= 1199' FNL, 5.~B' FEL, SEC TVD RECTANGULAR C ~'0 RD,,I'NAT E S SUB-SEA NORTHtSOUTfl E~SJ~JE'ST 5695.28 2680.90 S ~1,1.[3 W 57?1.85 274,0.09 5 ~26,",',,419. W 5885.28 282.7.68 S ~'4,8-5~7 W 6009.Z1 2~21.ZI S ~'7['85 W bogg.6z 2~86.79 S ~.89.0~ g 51,58.53 3036.~Z S 802'Z2 ~ ~M ,RCO ALASI(At [NC,. ,W-6 UPARdK I~RTH SLOPEr ALASKA TOP UPPER SAND BASE UPPER SANE) TOP UPPER SAND BASE LOdER SAND PBTD T~3TAL D:_PTH COMPUTATI3N DATE: HEASURED DEATH 6899.02 7201.00 7314.00 7400.00 17-D EC-.~4 SdMMAR¥ FROM KB 5790.28 5866.85 5'980.28 619%.62 6163.53 PA~E DATE OF SURVEY: Z6-NDV-8¢ KELLY 8USHING EL~¥ATION: ENGINEER: D. 5ARBA po 3RIGIN= Ling' TVD SUB-SEA 5695.28 5771.85 5885.28 6099.62 ~168.53 FNL, 558' REC SURFACE LOCATION'. AT FEL. SEC 3.3, TJ2'#, R~Et TANGLJLAR COORDT. N:ATES RTH/S~UT?t EAST/WEST 2580.'~0 S 711.13 W 27~*0.09 S 726..¢g W 2.827.68 S T4.8.51 W 2921.21 S TTZ,.,B5 W 2)86.79 S ~89,.,,'01 W .3036.51 S 802,.12 W UM FINAL dELL L3CATiON AT TD: TRU~ SUS-SEA M~ASURED V~RTICAL VERTICAL DEPTH DEPTH DEPTH 7400.0~ 6Z63.53 6168.53 ~ORIZ~NTAL DEPARTURE DISTANCE AZIMUTH FE~T O~G MIN 3140.10 S 1~ ~7 W Suggest~ form to be inserted in each "Actzve" well folder to d:eck £;:-:_ timoly cca~liance with our' rc<julations. - Operato~, %~11' Nameg~nd Number Reports and Materials to be received by: Required Date Received Remarks . Completion Report Yes .Well. History.. Yes / __~:f _ ~, .~-- " .~~ Samples I~) . · :. , / --: v? ..... · Core Description Inclination Survey -~. , ~/< /!/,,----? · ARCO Alaska, Post Offic o~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/17/85 Transmittal No: 4981 RETURN TO: ARCO ALASKA, INC. ATT/q: Records Clerk ATO-1115B P.0.~'100360 y orage, AK 99510 ' . ~ /T/v~nsmitted herewith are the following items. Please acknowledge receipt ~'and return one signed copy of this transmittal. OTIS PBU SURVEYS 2W-8?~: 1/08/85 lB-7 ...... 12/14/84 2F-12_~. 1/06/85 2F-5- 1/02/85 2W-5 jr 1/07/85 ~W-6 ..... 1107185- i2W-7 ' 11O7185 ilA-l:" 12/31/84 1A-11~ .... 12/15/84 1A-l- 12/23/84 G-5 .... 12/25/84 2F-3~- '12/31/84 2V-8A~ 12/16/84 2B-10 ' 12/17/84 1Y-9~' 12/20/84 ~--lC-..~ 12/10/84 2F-2~ 12/29/84 2F-15 ...... 1/05/85 2F-14- 1/04/85 2F-9 ~- 1/02/85 2F-8-- 1101/85 API 02 9-21228 '029-2D616 029-21097 029-21073 -- 029-21220' 029-05900 029-20908 029-21128. 029-21084 029-20935 f_ ,, ~ 029-21 063 029-21048 /~_-~/~ 02 9-21048 029-21 090 029-21077 CAMCO PBU SURVEYS 1E-12 ~' 12/14, 16/84 /cat Receipt Acknowledged: B. Currier DISTRIBUTION Drilling W. Pasher State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D&M NSK Ops. J. Rathmell Well Files ARt'I1 ,tl.~i~, I.~ *~ a sub-idiarv ol Atl-nlicRichfieldComDanv ARCO Alaska, I'~'-~' Post Offk.. Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 11, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are the November monthly reports for the following wells' 2D-14 2W-5 2X-11 2D-15 2W-6 2X-12 2D-16 2W-7 2X-13 2E-14 2W-8 15-9 2E-15 2W-9 Also enclosed is a Well Completion Report for 2B-]4. any questions, please call me at 263-4944. Sincerely, D. Gruber Associate Engineer JG/tw If you have GRU3/L03 Enclosures RECEIVED AJaska Oil 8, Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanficRichfleldCompany .,~--,, STATE OF ALASKA ~-, ALASKA G_ . AND GAS CONSERVATION COk :ISSION M NTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [XlX Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-194 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21211 9. Unit or Lease Name UM Kuparuk River Unit 4. Location of Well at surface 1199' FNL, 558' FEL, Sec.33, T12N, RgE, 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 95' RKB ADL 25642 10. Well No. 2W-6 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. November , 19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1200 hrs, 11/02/84. Drld 12-1/4" hole to 3205', Ran 9-5/8" csg. 8-1/2" hole to 7310'. Ran OH logs. Drld 8-1/2" hole to 7400'TD, as of 11/07/84. csg. PBTD = 7314'. Secured well & RR ~ 1700 hrs, 11/08/84. Drld Ran 7" 13. Casing or liner ru.n and quantities of cement, results of pressure tests 9-5/8" 36.0#/ft, J-55, HF-ERW BTC csg w/FS ~ 3196'. Cmtd w/870 sx AS II I & 790 sx Class "G" cmt. Top job w/200 sx AS Io 7" 26.0#/ft, J-55, HF-ERW BTC csg w/FS ~ 7393'. Cmtd w/325 sx Class "G" cmt and 41 bbls AS I & 54 bbls Arctic pack. 4. Coring resume and brief description NONE 15. Logs run and depth where run DIL/SFL/SP/GR/Cal/FDC/CNL f/7295' - 3196' RFT f/7298' - surface (19 pressure surveys). Resu'lts to follow on Completion Report. 16. DST data, perforating data, shows of H2S, miscellaneous data NONE Alaska 0ii & Gas C0r, s. g0mmissi0n Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE Associate Engineer DATE NOTE--Repo on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 .... ~ .... ~, Submit in duplicate ARCO Alaska, Inc. Post Office ~'~'< 360 Anchorege,, _aska 99510 Telephone 907 277' 5637 Date: 11/20/84 Transmitt-al No: 4864 TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 //~~am~it~ed herewith are the following items. Please acknowledge receipt and return one signed copy of this tramsmittal. OH LIS TAPES/Schlumberger #69731 2W-6 11/06/84 #69270 2H-3 6/04/84 Run 1 3149 - 7313.5 Runs 1,2 1998 - 6803 (Recomputed 11/18/84) /cat Receipt Acknowledged: B. Currier BPAE Chevron D & M Drilling · Geology Mobil NSK Ops. Date: DISTRIBUTION W. Pasher Phillips Oil J. Rathmell Sohio Union Well Files 'MEMORANDUM State of Alaska TO: THRU: FROM: ALASKA~OIL AND GAS CONSERVATION COM14ISSION C. rton ~ November 6, Cha£,z~fKn~ . j ~ FILE NO: Lonnie C. Smith~.m~~__,~~ C~ssioner ~PHON5 NO~ 102/W Ban LeNo~n ~ SUBJECT: Petroleum Inspector 1984 Witness BOPE Test On ARCO's Kuparuk 2W-6, Sec. 33, T12N, RgE, bM. Kuparuk River Unit Thursday, November 1, 1984: I departed my home at 1:50 p.m. ~0r a 2~.20 p.-m-, sh0wuP ann 3:20 p.m. departure via Alaska Airlines Fl$ght #57 for Deadhorse arriving at 5:00 p.m. Weather: -8 F, clear, light wind. F~riday, November 2,.1984: BOPE tests on ARCO's Kuparuk 2D-i~ Were-compleCted, the subject on a separate report. Saturday, November 3, 1984: BOPE tests on ARCO's Kuparuk 2E-15 were comple~ed~ th&"Subject of a separate report. Sunday, November 4, 1984: BOPE tests on 2W-6 began at i~:30~,m. and Wer~ C~pleted at 2:30 p.m. BOPE inspec- tion report is attached. Monday, November 5. 1984: I departed Deadhorse via Alaska AirI'i~es Flight' ~ a~"' 10:25 a.m. arriving in Anchorage at 12:00 noon and at my home at 12:30 p.m. In summary, I witnessed successful BOPE tests on ARCO's Kuparuk 2W-6. 02-00IA(Rev. 10/79) _ .___ O&G #4 .. 5~4 ' STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Ins~ection Report Date ~~ ~'~ ~~,~ ~' Location: Sec~T/~R~ M (;F~ "' Drillin~ Contractor P~F~ I<~-~ Rig #/~// Representative Location, General ~Q~ Well Sign~;/~ General Housekeeping Z%)~Rig ~ Reserve Pit {D/~ Mud SYstems Visual Audio Trip Tank Pit Gauge Flow Monitor Test Pressure Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: Failures Representative Permit ii ~ .~- ~ ~asing Set ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: psig ~ ~;~ psig /~r-~ 0 rain ~gsec. ~ min ~7 sec. Controls: Master O~ Remote ~Blinds switch cover~~- Kelly and Floor Safety Valves Upper Kellz Lower Kelly Ball Type Inside BOP Choke Manifold No. Valves ~ No. flanges ~ Adjustable Chokes / Hydrauically operated choke Test Time / hrs. Repair or Replacement of failed equipment to be made within Commission office notified. Remarks:' Test Pressure Test Pressure Test Pressure Test Pressure Test Pressure days and Inspector/ Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector October 29, 1984 M-~. J. B, Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re ~ Kuparuk River Unit 2W-6 ARCO Alaska, Inc. Permit No. 84-194 Sur. Loc. l199'FNL, 558'FEL, Sec. 33, T12N, RgE, Btmhole Loc. 1073'FSL, 1394'FEL, Sec. 33, T]2N, R9E, UM. Dear Mr Kewin.. Enclosed is the approved application = r ~ zo_ permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified a-s important for the spa%~ing or migration of anadromous fish. Operations ~in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department or.Fish and Game. Pollution of-any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Mr. Jeffrey B. Ke~n Kuparuk River Unit 2W-6 -2- October 29, 1984 equipment so that a representatiVe of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a d!verter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very trU!TM yours, / it_/// ,,,/..-~ / ./ :? h.- ,-. ~ ~'~ V. 'C__atterton Chat~an of Alaska Oil and Gas Comservation Cool,sion BY ORDER OF TME CO~MISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. · " Post Office B(.,~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 26, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2W-6 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2W-6, along with a $100 application fee ° Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat o A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment Since we estimate spudding this well on November 2, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. .S~n~erel y, /' Area Dril ling Engineer JBK/JG/tw GRU2/L41 Attachments RE'C 'iVED OCT 2 6 984 Alaska 0ii & Gas Cons. C0mmJssiori Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. 2. Name of operator STATE OF ALASKA "'" ALASKA U,L AND GAS CONSERVATION CO,,,MlSSlON PERMIT TO DRILL 2O AAC 25.005 DRILL [~]X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY i--] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC I--I SINGLE ZONE [] MULTIPLE ZON E)~ ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1199' FNL, 558' FEL, Sec.33, T12N, RgE, UM (Approx.) At top of proposed producing interval 1442' FSL, 1292' FEL, Sec.33, T12N, R9E, UM At total depth 1073' FSL, 1394' FEL, Sec.33, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 95', PAD 65' ADL 25642 ALK 2573 Federal Insurance Company 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 1073' ~ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7309' MD, 6212' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 1870 feet. MAXIMUM HOLE ANGLE 41 oI (see 20 AAC 25.035 (c) (2) 9. Unit or lease name ~.~ Kuparuk River Unit 10. Well number 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 276~ psig@ 80°F Surface 31~b, psig@ 6060 ft. TD (TVD) 21 SIZE Hole Casing i24" i12-1/4" 8-1/2" 7" 26.0# 16" 9-5/8" Weight 62.5# 36.0# 22. Describe proposed program: :ASING AND LINER Grade I Coupling H-40 I Weld J-55 I BTC HF-ERW J-55 / BTC HF-ERW ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7309' MD (6212' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak sands at approximately 3226' MD(3115' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2766 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed by the workover rig with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) Proposed Casing, Liner and Cementing Program Length MD TOP TVD 80' 29' I 29' 3197' 29' I 29' 7281' 28' I I I SETTING DEPTH 28' MD BOTTOM TVD 109' 109' 3226'I 3115' I 7309'1 6212' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 870 sx AS III & 790 sx Class G 400 sx Class G blend -23. I hereby certify that the foregoing is true and correct to the best of my knowledge CONDITIONS OF APPROVAL Samples required I~lY ES Permit number APPROVED BY Form 10-401 G~3'~/PD 14 Mud log required I--lYES ~10 Approval date Directional Survey required I APl number I ~YES •NO I 50-- O -b~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE October 29, 1984 by order of the Commission Submit in triplicate Amount $500,000 15. Distance to nearest drilling or completed 2W-5 well 60' @ surface feet 18. Approximate spud date 11/02/84 PERMIT TO DRILL 2W-6 installed and tested upon completion of the job. 2W-6 will be 60' away from 2W-5 at the surface. There are no other close wellbores or crossings anywhere downhole. Top of cement for the production string will be placed at 5720'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the workover rig has moved off location, this well will be fracture stimulated. i 4QQQ~ .5QOQ_ BASE PERpAFROST' ._& .................. , KOP! TvD~'187'Oi THD- 87'0 EP,,O~ z~ K~2 TVD=29~ T.0~2976 DEP=3~ j ~b-~~ T V D L~T ~~b~ 3~ ~b~P = 4 6 2: ' . ~AVE'h'A'GEi' XNGLE ] ' : :. ~OP UPPR SNDS TVD=ST65 T,D=6720 DEP=2739 ~'~. ~ ~,TARGET CNFR TVD=5908 TMD=6909 DEP=2861- ......................... + ........ ~~~~-- TVDm5920 T~=6924 DEP=2872 ~ ~ ~% BASE KUP SNDS TVD=6060 TMD=7109 DEP=2992 ~ ~ TD (LOG PT). TVD-6212 TMD=T309 DEP=3122 ;1000 2000 ' vERT'ICALi SECTION" :~ooo , 4ooo RFC,_i'VED.:: Alaska Oil & Gas Cons. Commiss-~io Anc',~ ..... ! : 1 ~000 ~ ~ ~1000 ' CIE I. OC,~ rio#, ........ 4000____ ,0 pr) iS-15 DE TARGET iCEMTER{ TVD,.Sg<8 TMD-69C9 SOUTH ; Z$? SEC!- 33. TI 2N. RgE WEST 766 TO T,.' ARG !T C £: i ; E D lllaska Oil & Gas Cons. Corrtm[ssion An~/~or,~ge IIII Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" X 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/10" side outlets. 5. 10" ball valves, hydraulically actuated, w/10" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 6. 20" 2000 psi annular preventer. 7. 20" bell nipple. Maintenance & Operati. on 1. Upon initial installation close annular preventer and verify ~hat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor I ANNUL~ 9 BLIND ' ~.~ 3 DIAGRAM ~1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/B" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams g. 13-5/8" - 5000 psi annular 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 NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAJ3. 3. CLOSE ANNULAR PREVENTER AND 'g'JlJ~V~]~S JJ~DSTJ~]~j1J~[ OF C~-tOKES. DON-~T TEST 'AGAINST CLOSED CHOKES 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD 'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 30DO PSI AND HOLD FOR 10 8. ~.~'PRBSSD]tE DOWNS%RBAM OF CHOKE ISOLATION ~fAL.'v']~S, TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTRF.~M~i OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 1D MINUTES BLEED TO ZERO PSi. 11. OPEN BOt'FOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND ItAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. OCT 2 6 1984 Alaska Oil & Gas ¢oas. OommWsion CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc (9 thru 11) 10. '(10-and 12) ' 12. YES NO · 1. Is the 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 pooll... 6. Is well to be deviated and is well bore plat included ........... 7. Is operator the only affected party ................... 8. Can permit be approved before ten-day wait .............. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ REMARKS (4) Cas~ ~ tP-~?-,~ (13 thru 21) 13. 14. 15. 16. 17. 18. 19. 20. 21. Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... (5) BOPE ~/ /~-~.? -~(/ (22 thru 26) (6) Add: 22. 23. 24. 25. 26. 27. Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ..... Does BOPE have sufficient pressure rating- Test to ~ ~ psi~ Does the choke manifold comply w/API RP-53 (Feb. 78) .................. Is the presence of H2S gas probable ................................. 31o f Additional requirements ............................................. Additional Remarks ~J o ~ 0 Geology: Engineering: w _kL .cs ./__ rev: 12/08/83 6. CKLT POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/O~ SHORE 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 effod has been made to chronologically organize this category of information. bI5 TAPE VERI~:'IC,ATION L LVP OIO,H02 VER1FiCAWlflN LISTING PAGE DATE :~qll,l/i9 ORIGIN : REEL NAME : CONTINUATION PREVIOI)S R~EL COMMEhTS : '7 TAPE HEADER SERVICE NAME :EPlI DATE :~4/1~/19 ORIGI~ :0000 TAPE NAME ;9731 CONTINUATION # :01 PRE¥IOIIS TAPF : COMMENTS : ** FILE HE~i)ER FILE N~E :EDIT ,OOl SERVICE NAME : VERSION DATE : MAX%MUM LENGT~ : 1024 FILE TYPE : PREVIOUS FILE : ** INFORMATION RECORDS ** CONTENTS TYPE CATE SIZE CDDE CN : ARCO ALASKA IMC WN : FN ~: KUPARUK RANG: gE TgWN: 12N SECT: 33 A:~ASKA 000 000 018 065 000 000 004 065 000 000 008 065 000 000 002 065 000 000 004 065 000 000 002 065 000 000 O~2 065 000 000 006 065 000 000 003 U65 LVP 010,~02 VERIFICAq.'iON [.,ISTiNG PAGE 2 ALASKA DIVISION COMPUTING CE~T~R : COMPANY = ARCO ALASKA INC WELL : 2W-6 FIELD = gUPARUK COUNTY = N.SLOPE STATE = ALASK SECTION : 33 TOWNSHIP : RANGE : 9E TAPE DENSITY : ~00 SPI JOB # 69731 BASf bOG: DiL , RUN # 1 DATE ~OGGED 6 NOV 84 BOTTOM bOG INTE~{VAL : 7286 FT, TOP bOG INTERVAL : 3198 FT, CASING-bOGGER : 9,625 IN, ~ 3198 FT BlT SiZE : 8,500 IN. DENSITY : 10.20 VISCOSITY : 38.00 LYP 010,~02 VERIFICATION LISTING PAGE 3 Pti FLIIID LOSS RM 0 MEAS, TEMF, RMF @ ~£AS. TEMP, RMC 0 SEAS, TEMP. MATRIX = 9 O0 = 7~1.0 = 4,260 @ 72 f = 6,120 @ 72 F = 2.340 ~ 72 F - 2,2~ @ 145 F : SANDSTONE LDP: T HALSTEAO ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SiZE REPR CODE ENTRY 2 I 66 0 4 1 ~6 1 8 4 73 60 !6 1 66 1 0 i 66 0 DATUM SPECIFICATIOM BLOCK6 ~NEM SERVICE SERVICE UNIT APl API API API FiLE SIZE SPb REPR ID ORDEk ~ bOG TYPE CLASS MOD NO. DEPT FT O0 000 O0 0 0 4 SFLU DIL 0t{~ 00 220 O1 0 0 4 ILD DIL OH~M O0 ~20 46 0 0 4 !bM DIL OHM~i 00 120 44 0 0 4 SP DIb ~V O0 0 10 O1 0 0 4 GR DIL GAPi O0 310 Ol 0 0 4 GR ~DN GAPi O0 310 Ol 0 O 4 AL~ FON IN OU 2~0 O l 0 0 4 .o ~o~ c/ca oo ~o o2 o o 4 :DRMO FDN G/C3 O0 356 O1 0 0 4 .~Ar' ~ oo 4,2o oi o o 4 R.~ ~o.' oo ooo oo o o 4 N~.i ~D~ po oo ~o oo o o 4 NCNb FDN CPS 00 330 31 0 0 4 · FCNL FDN CPS O0 330 30 0 0 4 PROCESS CODE (OCTAL) 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 O00000000000uO 68 OOOO0000000000 68 00000000000000 68 00000000000000 6~ 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 ** DATA *~ DEPT 7313.5000 SFLU 2,9121 lad 3. 0527 2,4043 LVP OlO.H02 VERIFICATION LISTING PAGE 4 SP RHOs NPHi DEPT SP RHOB NPHI DEPT SP RHOB NPHI DEPT SP DEPT RHOS NPMi $P RHOB DEPT SP RHOB NPHI -7 625U Ga 2:4102 DRHO 48.5352 ~ICNb 9570 GR 2,4102 DRHO 49,3164 NCb'b '1200.000(} SFLU -15.7500 GR 2,3867 DRHO 31.3477 NCNb '1100 0000 SFLU -44:5313 GR 2,2324 DRHO 29.~969 NCNb 7000 0000 -143,0000 GR 2,4160 32.2266 NCNb ~900,0000 SFLU 156.5000 GR 2,4023 DR}tO 32,4219 NCNIa 6800.0000 SFLU C '134,8750 2.4629 DRHO 31,8359 NCNb 24. 425, 2 0, 4'~5o 2270, 57, 56, 0, 2740. . 90, O, 24'18, 9 87' O, 2580. 0 12~, 2218, DEPW b700,O000 SFLU 2, SP -56,2187' GR 128' ~ ,, NPHi 43 664 CNI,, 186 DEPT NPHi DEPT SP RHOB NPH! 6600,0000 SFLO -10,6 "19 '1 G R '2 ' 3'730 D R H 0 40,7 '115 NCN~ 05~g,oo00 8FLU ' , 3125 G R -999,2500 DRHO -999.2500 NCNb 6400. 0000 SFbO .'3°'~'zb° G~ 999," .... ~Lt}O DRMO -999.2500 NCNb DEPT SP RHO~ NPH~ 2 120, O, 1842, , '999 ,, -999o 14'1 . 999, 4219 4O97 5000 8867 4219 409't 5000 7266 3125 0264 0000 1~75 8750 0249 0000 7227 8125 0249 0000 1'197 9375 0293 0000 0977 0625 0474 0000 1 0190 0000 4121 8750 0381 0000 921.9 5000 soo 2500 4863 375O 2500 25OO ILL GR NRAT FCNb NR~T FCNb GR NRAT FCML FCNL IbD GR NRAT FCNL IbD GR NRAT FCNL ILD G R NRAT FCNL ILD NRAT FCNL IbD GR NRAT FCNL lbo GR NRAT FCNL 24 4219 3:7930 103,562b 2,4121 24,4219 3,7930 103.5625 3.7559 88.3125 2.8398 789,5000 37.2500 56'8750 2,6738 950,0000 5,2109 90,8125 2,9004 740.0000 8,0313 87,9375 2,9238 7'~8,50OO 2,g590 121,0625 3,029:3 655.5000 1,,8066 128.8750 3'5996 475.7500 2,5625 ,8750 12~.4668 486.5000 ,6~26 21 .5000 -999,2500 -999.2500 ].1,660 1.47,3'150 '999.2500 -999.2500 CALl RNRA IbM CALl RNRA Ib~ CALl RNRA IbM CALl RhRA IbM CALl RNRA IbM CALI RNRA CABI RNRA IbM CADI RNRA IbM CALl RNRA IbM CALl RaR. A IbM CAhI RNRA 8.5000 4,1(,)55 2 3906 8~0000 4,1055 3.8086 8,6250 2,8750 38,5313 8.2500 2,8828 5,382~ 8,6172 3,3477 8,1562 8.'1734 3.3125 2.8125 3,3828 1,8740 9,7891 3,9121 2.5820 9,6953 3.7852 2.073~ 9.0'181 -999,2500 .$,2090 9.9844 -999,2500 LVP OlO,H02 VERIFICATION [,ISTING PAGE b DEPT b300,OOOO Sb'I.,O SP -18,4844 GR RHOb -999 2500 DRH[) NPHI -999~2500 NCNb DEPT 6200,00u0 Sf'LU SP 17,6250 GR RHOB -~99,2500. DRHO NPHI -999.250U NCNb DEPT 6100,0000 8FI.,O SP 19 7031 GR RHOB -~99 ! 2500 DRHO NPHI -999 2500 NCNb DEPT 6000,0000 SKt. U SP -8,101o G~ RHOB -999,2500 DRHO NpHI -999,2~00 NCNb DEPT 5900 0000 SFLO SP -11~9219 GR RHOB -999,25o0 DRH~ NPHi -999.2500 NCNb DEPT 5800 0000 SFLU SP -5,1~30 GA RHOB -999,25o0 DRHO NPHI -999.2500 NCNb DEPT 5700,0000 SFI.,U SP -19,6875 GR RHOf3 -.999,2500 NPHI -999.2500 NCNL DEPT 5600 SPO RH B -999 NPHI -q99 0000 SFIiU 9531 GR 250(.) DRHO 25 00 N C N b 0000 SFI, O DEPT 550 , SP ,1406 RHO~ -999, ~5C 0 DRHO NPHI -999.2500 NCN5 DEPI '~ 54 ,,,0000 ~. ~ I.,O SP .~,9~39 RHOB -999,2500 DRMO NPHI -999,2500 NCNL D:~PT 5~.00(,0 SFLO SP ~.,2969 R, HO~ -99~,~500 NPHI -999..500 NCNb 4,4141 136,1250 -999.2500 -999.2500 7,1523 108 1250 -999:2500 -999,2500 4.7891 108 6250 -999:2500 -999,2500 2.9355 111,6250 -999,2500 -999,2500 ~40,6250 '999.2500 '999,2500 2 7793 115,0000 -~99,~50'0 -999.2500 134, -999,2500 '999,2500 4,1953 '~9 , O0 . 999,2 500 1 4072 ' 2500 1 '14 , g~ O0 3.88~8 ~63,0000 -999. 2500 -999,.2500 4,7583 ~ 92,5000 -999 250Q -999' .250O N~AT FCNL GR NRAT FCNL IbD GR N~A~ FCNL GR NRA~' FCNL NRA1 FCNb IhD GR NRAT FCNL GR N'RA~ FCNb GR FCNb I GR FCNL GR NRAT FCNb GR NRAI' FCNb 2.6191 136,1250 -999.2500 -999,2500 4.1328 108,1250 '999,2500 '999,2500 4,1002 108.6250 -999.2500 -999,2500 2.2480 111,6250 -999,2500 -999.2500 3.2754 140.6250 -999,2500 -999.2500 2,7012 115,0000 -999.2500 -999.2500 3,8984 134.1250 '99g,2500 '999,2500 3,9~68 143,1250 '99g, 500 '999,2500 1,~809 174;.500 -999,~b00 -999. 500 3,3164 163,0000 '999,2500 -999,2500 4,4609 -999,2500 '999,2500 '999,~500 CA£,I RNRA IbM CALl RNRA IbM CAbI RNRA CALl RNRA IbM CALl RNRA IbM CALl RNRA CALl R NRA IbM CALl RNRA (2 A bi R NRA CALl RNRA CALi RNRA 2,b621 9,4609 -N9~,2500 4.3945 9,6875 -999.2500 10,0313 '999,2500 2.3633 9,4609 '999,2500 3,246~ 10,554 '999,2b00 2,7461 9,6797 -999.2500 3,9102 10,6406 -999,2500 3.8S48 10,1010 -999,2500 1,4S68 9,0469 -999,2500 3.4590 9,4375 -999,2500 4,7617 -999,2500 -999.2500 LVP OIO,H02 VERIFICATION LISTING PAGE b DEPT 5~00 0000 SF[,U SP ll:lOlb G~ RHOB -999,2500 DRHO NPHl -999,2500 NCNb 5~O0,O00O SFLU 15.8359 GR 999,2500 DRHU :999,2500 NCNb DEPT 5000.0000 SFLU NPHI -999,2500 NCNL DEPT 4900,0000 SFLU SP -12,3594 GR RHOB 999,2500 ORHO NPHI ~999,2500 NCN[~ SP 36,6563 GR RHOB 999.2500 DRHO NPHi -999,2500 NCNb DEPT 4!00,0000 SFLU SP 24.07BI R. HOB -999,2500 DRHO ~ ' NPHI -999,2500 . CNL DEPT NPHI DEPT 8P DEPT NPHi RHOD NPHI DE,,T RHOB ~600,0000 SFLU 164,8750 GR -999,250'0 DRHO -99g.~500 NCNb ~500,o000 172,5000 GR -999,2500 DR:HO -999.2500 NCnb 4400,O0008FL0 -175,3"/50 GR -999,2500 DRHO -999,2500 NCNb 00~0 SFLU ' 8125 GR -999, -999,2 O0 NCNb 200,0000 8FI.iO .124;3125 GR 999,2500 ORHU 1..8887 ILD 114,7500 GR -999'2500 NRAI -999.2500 YCNb 2,5898 IbD 108,7500 GR '999.2500 NRAT '999,2500 FCND 2.4727 80.0000 GR 'q99,2500 NRA2~ '999,2500 FCNb 2 4668 I.bD 90i8125 GR -999 2500 NRAT -999 250(; FCNL 2.4668 87,~75 GR '999. O0 NRAT -999.2500 FCN~ 2,5801 ILD 92,I875 GR '999 .~500 NRAT '999: 500 FCNL 5,4492 '15,5~25 GR -999;2500 NRAT -999.2500 FCNL 2 7'193 82,3750 GR -999,2500 NRA'I -999.25'00 FCNL 3.4238 I~D 108,937~ GR: -99'9,250 NRAT -999,2500 FCN~ 2,5410 ILO ~00,1875 GR -999,2500 HAI -999,2500 FCNL 2.5098 ILD 86,5000 Gl{ '99912500 NRAT 2.1543 -999,2500 -999.2500 -999,2500 2.5840 '999.2500 '999.2500 '999.2500 2.6543 -999,2500 -999.2500 -999,2500 2.7637 -999.2500 -999,2500 -g99,2500 2,7500 -999,2500 -999.2500 -999,2500 ,9375 -99 .2500 -999,2500 'g99;2500 4,1953 '99~'2500 '99 '2500 '999.2500 2,9258 '999.2500 -999,250 -999.2500 3. 6758 '999,25(0 999'2500 .99g '8555 .2500 -999,2500 -999.2500 2.~125 '999,2500 '999.,~500 CALl RNRA IbM CALI RNRA IbM CALl RNRA IbM CALl R NRA CALl RNRA IbM CALl RNRA CALl RNRA ibm CALi RNRA IbM CAbI, R NRA RNRA I,~M CAD~ RNRA 2.1465 -999.2500 -999.2500 2.5918 '999.2500 '999,2500 2,6504 ~999,2500 999,2500 2.7227 -999,2500 '999,2500 ~.7109 999,2500 ~999,2500 2,8086 -999.2500 2 -999, 500 4.6758 -999 '~500 -999:500 2,8633 -999,2500 -999~2500 -999.2500 -999,2500 2,7095 -999,2500 -999,2500 Z,"1344 -999,2~00 LVP 010.H02 VERiYICATIDN LISTING PAGE ] NpHI -999,2bou NCNb DEPI 4100,00o0 SFLU SP -86,3125 GR RHGB -999.2500 ORHO NpHI -q99.2500 NCNb DEPT 4~00,0000 SFLU SP 53,25o0 GR RHOB -999.2500 DRHO NPHi -999,2500 NCNb DEPI 3900.0000 SFLU SP -115.6250 GR RHO~ -999,2500 D~HO NpH! -999,2500 NCNb DEPT 3800. 0000 SFLU SP -122 8125 GR RHOB -999:2500 DRHO NPHi -999,2500 ..~CNb DEPI ~700 OOUO SFLU SP -129:0000 GR RHO~ -999,2500 DRHO NpHi -999.2§00 NCNb DEPT !600,00(.)0 SFLU SP 125,1250 GR RHOB 999,2500 DRHO NPHI -999,2500 NCNb DEPT ~400,0000 SFLU SP 141'~750 G~ RM(3B '999,2500 DRHO NPHI -999,2500 NCNL DEPT 'ii]00, OO{)O Sf'bu SP 13:2'8750 GR 999 ~ ~500 DNHO 999 ~ 2500 NCNb ~! 0000 SFLU DEPT Sp 139,7500 GR RHOB 999.2500 DRH~ NPHI -999.2500 NCNb DEPT jlR9 O0oo SFLo SP -33'8437 -999.2500 2,~89b lO0,Ob2b -999,2500 -999.2500 3.3242 94.3125 -999,2500 -999,2500 3,8J20 120,1875 -999,2500 -999,2500 3,0957 110,0625 -999,~500 -999,2500 3,2383 123.31~5 -999,2500 -999.2500 2.4570 106,1250 -999,2500 -999,2500 3,2402 105,6250 -999,2500 -999,2500 4,0078 111,8125 '999,2500 '999,2500 4,~094 -999,2~(.0 -999.2500 0.4907 47,3125 '999,2500 -999.2500 5 ~477 ~.438 NRAT FCNb GR NRA~ FCNL GR N~A'f FCN~ NRAT FCNL GR NRA~ FCNL ILD GR NRAT FCNb GR NRA~ FCNL ILO RAT FCNL ILO GR NRA~I FCNb NRAT FCNL GR -999,2500 2 9492 -999:2500 -999,2500 -999,2500 3.9004 -999.2500 '999.2500 -999,2500 4,0234 -999,2500 -999.2500 -999.2500 3,71B8 -999,2500 -999,2500 -999,~500 3,4902 '999,2500 '999,2500 '999.2500 3.0742 '999 ~$00 -999i 500 -999 500 3,726~ '999,2500 '999,2500 '999,2500 4,5234 -999~2500 '999.2500 '999.2500 4,~5~ -999,2500 -999, ~00 -999,~ O0 2000,0000 -999.2500 -999.2500 -999,2500 13 -g99[ _ 500 CAbI RNRA IbM CALl RNRA ibm CALl RmRA CALl RNRA RNRA CALl RNRA Ib~ CALl RNRA CAbI RNRA CABI RNRA II, M CALf RNRA CALI 2.~92~ '999,2500 '999,2500 J.'1422 :~9u,25oo ~.'1930 -999,2500 3.~805 -999,2b00 -99~,2500 ~,431b -999,2500 -999.2500 2.8613 :999,250o 999,2500 3,5215 -999.2500 -999.2500 ~,2930 -999,2500 -999.2500 -999, O0 -999,2500 200o, 0000 -999,2500 -999,2500 99.2500 DVP 010,H02 VERIF'ICATiON LISTING PAGh; 8 RHO~ NPHI -999,2b~00 DRHO -999. 2500 NCNb -999.2500 NRA'I' -999. 250{) FCNL -999,2500 RNRA -999.2500 -W99,2500 ** FILM TRAILER ** FILE NAME :EDIT SERVICE NAME ; VERSION # DATE : MAXIMU~ LENGT).t ; 1024 FIDE TYPE NEXT FILE NA~E ; EOf ** TAPE TRAILER SERVICE NAME :EDIT DATE :B4/11/19 ORIGIN :0000 TAPE NAME :9731 CONTINUATION # :01 NEX~ TAPE NAME COMMENTS : ** RE~L TRAILER ** SERVICE NAME :EOIT ORIGINDAT~ 18~/11/19 REED NAME CONTINUATIO~ ~ NEXT REEL NA~E : COMMENTS :
