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181-116
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 5, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1A-06 KUPARUK RIV UNIT 1A-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/05/2025 1A-06 50-029-20638-00-00 181-116-0 W SPT 6034 1811160 3000 2560 2560 2565 2560 150 150 150 150 REQVAR P Josh Hunt 7/8/2025 2-year MIT-IA Required by AIO 2C.031 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1A-06 Inspection Date: Tubing OA Packer Depth 600 3280 3150 3130IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250709090547 BBL Pumped:5 BBL Returned:4.7 Tuesday, August 5, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1A-06 KUPARUK RIV UNIT 1A-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/01/2023 1A-06 50-029-20638-00-00 181-116-0 W SPT 6034 1811160 3000 2294 2302 2307 2302 150 150 150 150 REQVAR P Adam Earl 7/12/2023 MIT-IA tested as per AIO 2C.031 to max ant.inj. Psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1A-06 Inspection Date: Tubing OA Packer Depth 570 3300 3190 3170IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230714090142 BBL Pumped:4 BBL Returned:4 Friday, September 1, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 AIO 2C.031 MIT-IA James B. Regg Digitally signed by James B. Regg Date: 2023.09.01 15:55:50 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor—71, t FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 14, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1 A-06 KUPARUK RIV UNIT 1A-06 Src: Inspector Reviewed By: P.I. SuprvL Comm Well Name KUPARUK RIV UNIT IA -06 API Well Number 50-029-20638-00-00 Inspector Name: Austin McLeod Permit Number: 181-116-0 Inspection Date: 7/3/2021 Insp Num: mitSAM210704163322 Rcl Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IA -o6 Type Inj W 'TVD 6034 - Tubing 2630 _ 2635 2635 - 2635 ' PTD 1811160 - Type Test sPT Test psi 3000 IA 590 3400 3280 3240 BBL Pumped: 5 .''BBL Returned: 4.9 _ OA 140 - 140- 140 Interval REQVAR Notes: MITIA to MAIP. AIO 2C.031 Wednesday, July 14, 2021 Page 1 of 1 MEMORANDUM To: Pim Regg P.I. Supperve" isor Ie (l 91.7 tq FROM: Matt Herrera Petroleum Inspector Well Name KUPARUK RIV UNIT IA -06 Insp Num: mitMFH190723094419 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 24, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1A-06 KUPARUK RIV UNIT IA -06 Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm API Well Number 50-029-20638-00-00 Inspector Name: Matt Herrera Permit Number: 181-116-0 Inspection Date: 7/21/2019 , Wednesday, July 24, 2019 Page I of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IA -OG e In' w ITVD YP J -. r 603�in 1.. 227x S -so 229, 2291 - PTD 1811160 I I'1'_ Type Test SF''I Test psi 3000 IA 0 ,� - 3140 - �- BBL Pumped: T 4.9 - BBL Returned: 4.7 OA ai - 245 — - - -- -- - Interval' REQVAR P/F 11 Notes: MIT -IA every 2 years to MAIP per AIO 2C.031 ✓ Wednesday, July 24, 2019 Page I of 1 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ( DATE: Tuesday,July 11,2017 P.I.Supervisor \ ell 1,tB f 1 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1A-06 FROM: Adam Earl KUPARUK RIV UNIT 1A-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-06 API Well Number 50-029-20638-00-00 Inspector Name: Adam Earl Permit Number: 181-116-0 Inspection Date: 7/7/2017 Insp Num: mitAGE170708071405 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1A-06 ' Type Inj W 'TVD 6034 ' Tubing 2290 2270 2310 ' 2300 PTD 1811160 Type Test SPT Test psi 3000 IA 930 3260 3195 3170 BBL Pumped: 4 3 BBL Returned: 4 OA 250 250 240 - 240 Interval REQVAR P/F P ✓ Notes: MIT IA as per AIO 2C.031 SGM4NED SEP 2 5 2017 Tuesday,July 11,2017 Page 1 of 1 (9 r- 0 0 r ) ro .� 00 r o F4 v o L. y °o o W D + - h 1 I Q�ma � Y O NE vU + > • Q�Y O ,c e- .- .- '- cO O ate+ a) O 0 U a a C C — (o y,, L y' as 0 � > a m' o s-' E a Cr m CI J w N N N N N N N <: 0 r e- N N N N N N O L J a 0 T T T T T T T T 7 7 E t -o O V F 9 O m co co co m co r6 c C C C F w . . . . . . . . 7 7 7 7c ay C � L v I— N N N N N M M M N M e} O @ ti_ C N Z a U O U Z pC > 2 a L . 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L'.1 N C " fO vi Z co F •i = D f0 .i 0) r0 0 c/a a S a 0� F a a Q • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg kDATE: Wednesday,February 10,2016 P.I.Supervisor \ �e( Z I I t I I SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A-06 FROM: Lou Grimaldi KUPARUK RIV UNIT 1A-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 3R- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-06 API Well Number 50-029-20638-00-00 Inspector Name: Lou Grimaldi Permit Number: 181-116-0 Inspection Date: 2/4/2016 Insp Num: mitLG160205074551 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1A-06 - Type Inj W'TVD 6034 Tubing 1654 - 1657 - 1658 - 1661 PTD 18n160 - Type Test SPT Test psi 1508 - IA 850 3000 2900- 2890 Interval 4YRTST P/F P OA 220 230 230 230 Notes: 3.8 bbl's diesel pumped,3.7 returned.Good test.All pertinent documentation provided by Roger Mouser(DHD Lead). Al4a(444,, ?dem',t pec- �LC z� d --wet( s(--t = %7).` suktiNED SEP 2 7 2016 Wednesday,February 10,2016 Page 1 of 1 1,4eck I A--C- , i • i. ( 1160 Mr-r- z1 4 1)4, A-06c( .►,.x kk.'tLC-i IG zo e745s1 dwajjejoyo N r o 9 . 1 .1 , 1. / . 1. .1. 1 .1 I. 1 . 1. ( .1 , P .1 II. J I. . : 1:_k______',.._______,. . .....— C m • T O ' `. N : : t0 7 . h • o • • . 1 N w 0 o i •• � z T > O F a Z 4 co . . I:j 1— • • Y11 1' I '1 I' 11i I I' i 9 1' I '1 1 1 •1 I 1' 1 r 1' { •1 I'' '1 i 0 Q 0 0 0 0 Q O O 0o N ,-- r- N 1 1 1 ISd III 0 KUP IN.! • -QB ConocoPhillips - Welt Attributes 4/13x Angle 8 MD' : .1 341 ka,hu:, Weebar APlTl6 mme Fl. NaW5511800 ,', 9 8rI DID(1102O• 500292063800 KUPARUK RIVER UFBT 'Welt,. l'I, i t..11:1: 3.600.00 9.1.- , •r. Cal.mell .,.. h23(ppm) lade. Ananiaflon Pod aV 1 .r 1�'. Rg R.*aso Data 1406118@010 ice 33 Pu 1SSSV:IMP I �. LO2IW0. [ 2/24)1987 3901 0)2611981 Anna/awn I Depth(C.KB) I Ead DaleAanalellon �L..l904 S% IL-4 L.,. 3 1 14 J '/20(2015 Rev RI2SOR PGLI PD VJt! IA), pen:N.n i.•.10,0,115 NANGEA,27 0 .-iT . 1 Catilug SCnngs .� I Gaelb..crt Iee 00 0.) .(,,; Tap OMB) Set Depth NB seep 1h INPLen Mode TopThread AD NM ) BP (IVO)- 0. I °CONDUCTOR 16 16.002 32 9 01,1 :G: 71.49 WELDED 6.809 PaawtpinO 00(h4 a On) Top DUB) Sot Depth(1168) Bel Depth(TVD)_WYL (L.Grad* Top Thread • SURFACE 17.014 9950 x1.0 2,791 2,' 2,513.8 45.50 K-55 I/IL Cleft D..olpllen_ OD(.) V) "Set Depth ORD) Set Depth(i in :0eoAe TdprAnad PRODUCTION 7 6276 28.9 9030 3, 6,761.6 711 CG 0-55 BTC 1Tubing Strings T9Diq 0esalpllan sIBnR Na ID"M2 lnl Top(Rt16) kl 88,9.14 sr'-".;-V...,; :('r r Dade as:0;l.rlplj..- TIRING36^x2826' 3 V2� 2.992 27.0 8,901.0 6,2937 1/: _ JBTC AB.MOD I ',NAAE:0NC111cinA;326Br10' .1 '7Comp(6I(DnDeteltl8 Nan00.110 SAFETYVLY,1,214.7 Tap(11103) Top(IVO)pare) Top Ind bm baa 10„ Ned •....-.-�, 'V 11 0;.0 6.07 RAWER TMC HANGER 3.500 1,784.7 1.739.9 28.02 :7r Y .7117 CO -e•-1A-SSA F£TY VALVE 8,0031 8,015.' 42.51. 58) BAKER SBR 2.813 O'4NFAC6 71.`.','4!;- i 8.929.3 1:.71 "` -4Y6-7 � PACJ((R BAKER H.4.1.401)RETRILIi ABLE PACKER I7)10 8238.4'- 61888 a`7.18 tt(i•7'" JAVA BPL NIPPLE 2.897 0,221.0 6,211.8 ,111 at,.91i1,1' SEAL ASSEMBLY WI LOCATOR 2882 6272 6) 6212 5 71117 PACKER BAKER DB PACKER -ENT Dee tGT,J.Mi9- _ 8,200`8°- 6,218.4 43.05 XO Reducing CROSSOVER 3 1)2 x 27182.076 828-..7 6,224,8 O,08 Nil,:;, CAMCODNPPLE NO GO 8,300.3 6,2322 63.96 S0I 01)11811EAR OUT SUB-ITL ELA1D X18300 ON PROF -die 82422007 Other to Hole(Wlrellne retrievable plugs,valves,pumps,Ilse,etc.) O.8 51'1;44981 Top(TVD) Top lnei 10P 1100,81 111681 PI WI. e'_n, Ron bale DA9LIPr;6021.t 8,221.0 6,175.3 43.20PATCH PATCFI:SET 77S PARAGON 26'TOP PACKER, 8221/200/1 1.620 SPACER,SPACER STINGER ASSEMBLY(260.5) IN LOWER ITS PAcI R LOWER PACKER MID GASL;Fr 6,465 t ELEMENT SET 6q 8247 RKB. 6,579. 6,337.7 4239 FISH 6'54n1i00036148'19719 /12611981 •1::1 OAS LIFT, PeA/xetlpns 4 Slnis _ GALS Ahw 0.8751/6,10.3 �Ie trn,IlYul Bus(TYCO (shako" IP . Tap01481 01m t11101) 11111511 1111191 Zorn eels 0 1y7.1 ::D- DABLFTer4ad ... e:1Ce.0 8,1290 6,0928 0,1118.3 LOi112,GA, 203/1987 120,RPE RF 120 deg.Phasing Er IA-08 Casino 8.1080 9,1760 6,092.8 6,1498 UNIT O.C.-4, 9)2611981 ' 170 7:311 Squeezed(2119187T5- :,k';1 2119187 '::.4':1 Ir r;al,; IA-08 SUI. Vann Guns $.1;51.0 6.6112) 6,1 7 ,ta'5. t''..,i `1A2,Y321997 f2b)P1:R1 120 deg.Phasing,5"11As0Fr.7,607.7 00 Casing ----8,3600 8,5720 8,276.2 6,285.1 A 5,IA-6 9!2811981 170 PESO 5'Vann Guns GAS LIT,72688.- --_ 8,383.0 0.424.6 6.2937 0.323.7 A 4,IA OO 942811981 '2.0'IPLRF 5'Vans Galls Cement Squeezes Sell 8.6031 lop(TAR Bu I1VD1 ■■yz„ 1 aP 1116111 81rr 011981 111681 47186) 14, Stn Dale Com PeCT3ER,90193 8,108.0 8,186.0 6,092.8 6,157.7 Cement Squeeze 2/1911987 UPPER PERF SQUEEZED OFF Mandrel Inserts At INJECTION,20722- all Oft top(001 Vale. Leith P871 SW 190 lb. N Tap(9611) 90,1 9Me Dod.l rm Ile) ton: T.p. Type Orr) 18.1) RU.Delle Oslo 1 3,196.0 2.7700 CAMCO KBUG t GA5LIFT 11411' BK 0.043 0.0 2'7')11502 2 4,580.1 9,652.9 68A520 KBUG 1 GAS LIFT (8/1' BK 94000 9.9 3,19:1300 RPBRF,8,10609.1790 7 3 6.:1,1.1 -3,845.8' (I -FON7G l" 'LIFT' COSY bK 0.000 0.0 2124.4967 SII Celt 501.6.111B0B.189.0 4 6,405.1 4.2425 CAMCO 6& 0-0 2/ 16 1 GA5 LIFT 094Y BK 0.000 /9'1 '' s. s. ,PERF,6,16508.1100 5 5,0515 4,524.9 CAACCO ICBM 1 GAS LIFT £61Y BK 0.000 e0 27611982 8 8310.3 ...4.527.0 TJ 9CO KBUG 1 GM LIFT 0100 -OK - 'EA' 0.8 3119219110 f 7 8.71=.4 5,1206 CAMCO KDUG I GAS LIFT Okra' BK 0.000 00 2"2&1992 t 8 7,178.8 5,419.7 CAMCO OW 1 OAS LIFT MY BK 6.000 00.'19/15000 PAID/1,8,2210 9 7,687.1 6,7100 CArt0 KBUG I GA§LIFT £8.14 BK 0.000 0.0 2224/1687 , NIPPI.2 97184 1 7,0®0:6 5,9644 0115 LOX 1122 GAS LIFT OW BK 0.000 00°112611992 D { 1 8,0722 8,0665 1'4.)2/;0 KBUG 1 IW 0074 BK 4.000' OW 141/1007 SEAL ASSY,8,2710 +Y I. PACKFR.II 21711 '+.• N n!ex;Gcn9l'at ft Sahty 4 44 4 _..___. Ead Dale 8800151168 2123)1998 4DT5enMdan1n Tbg®8289'WLMs79dkrtlwn 190`. ft 7/30)2010 NOTE:View Bdre8911c w/Alaete Sdonidie9A NIPPLE,e2ed 7 ......_._ - - II 203,8 3003 IPERr:321190-B.5t20- IPE RF.85690-84240- 1,81 aa/Ba... .-... I PRODUCTION;20011,0299- • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday,January 25, 2016 7:26 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: 1A-06 (PTD 181-116) return to injection for 30 day monitor period 1-25-16 Attachments: MIT KRU 1A-06 diagnostic MITIA 1-24-16.xls Chris, Kuparuk WAG injector 1A-06(PTD 181-116) has been shut in since August 9, 2009 due to surface flowline issues. While shut in, evidence of possible TxIA communication was identified and reported to the AOGCC on November 29, 2012. It is now believed that while the well was shut in, a gas slug migrated through the reservoir, which filled the tubing and near wellbore area with gas. A gas thread leak in the tubing is believed to be the cause of the IA pressurization first identified in 2012. Multiple attempts to bleed the IA proved unsuccessful until a tubing plug was set in March 2014 and a passing MITT achieved. There was some slight buildup of the IA following the tubing plug set due to the residual gas still in the tubing which took several more bleeds to remove. The IA has now remained steady at 450-500psi for nearly a year now. The well line repair work was completed earlier this month and the tubing plug pulled. A passing non-witnessed MITIA to 3000psi was performed on January 24, 2015 demonstrating continued integrity. It is ConocoPhillips intention to return this well to water injection for a 30 day monitor period to confirm the hypothesis that this is a gas-only thread leak. It is also overdue for its 4 yr pad testing so we will be obtaining that after stabilization is achieved. Appropriate paperwork will be filed at the conclusion of the monitor. Please let me know if you disagree with the plan forward. Attached are the MIT data and TIO plots (both 90 day and 1000 day). SCANNED MAY 2 6 2016 Well Name 1A-06 Notes: Sfart Date 10/27/2015 Days 90 End Date 1/25/2016 3000 - WHP Annular Communication Surveillance OAP — 2E00 —WHT — 1: — 1: ROC — 1' 1E00 1( — 9( a1C0C � — 3( — 7( `CG — r( 0 l 5( Oct-1E Oct-1E Nov-1G Plc'-1E Nov-1E Ceo-1S Ceo-1E Cec-1S Jan-1E Jan-12 Jan-1S Jan-16. P =e Oct-15 Oct-15 Nov-1= Nov-1E Nov-1E Dec-1E Dec-15 Dec-15. Jan-1v Jan-16 Jan-16 Jan-1E Date 2 'r ¸ ImacJ' ~roject Well History File Coveri .Age 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. // ~ /- _/ // _~ Well History File Identifier Organizing ~o,~i RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type BY: BEVERLY ROBIN VINCENT S~ MARIA WINDY [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project proofing BY: BEVERLY ROBIh~ INC_~ SHERYL MARIA WINDY Scanning Preparation' . = TOTAL PAGES BY: OB!N VINCENT SHERYL MARIA WINDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: ,~-~'"~ ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION:' _.~ YES BY: BEVERLY'ROBIN~VINCENT SHERYL MARIA WINDY DATE:/ ' /S NO Stage 2 IF NO IN STAGE '~, PAGE(S) DISCREPANCIES WERE FOUND: .. ' YES , . NO II I RESCANNED BY[ BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or .Comments about this file: Quality' Checked 12/10/02Rev3NOTScanned.wpd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 27, 2011 TO: Jim Regg P.I. Supervisor e-ele/ C I ((a'1 { SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A-06 FROM: Chuck Scheve KUPARUK RIV UNIT IA -06 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1A - 06 API Well Number: 50 029 - 20638 - 00 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS110727065544 Permit Number: 181 - 116 - Inspection Date: 7/26/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 1A -06 , IType Inj. N ' TVD I 6034 % IA 1580 2380 2340 2340 P.T.D 1811160 1TypeTest I SPT Test psi 1508 = OA 270 —_ 270 270 270 Interval 4YRTST p/F P ' Tubing L 600 600 600 I 600 � Notes: ) d Wednesday, July 27, 2011 Page 1 of 1 • ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, AIASKA 99510-0360 June 9, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~ JUN 1 1 2009 Alaska Oi9 & Gas Cons. Comrn~s~cr~ Anchoca~a ~~l+~~~ ~ ~ ---D Cv Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRin. 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 May 27~', 2009. The corrosion inhibitor/sealant was pumped May 31St and June 1St, 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, ,.'"j~~% MJ Loveland ConocoPhillips Well Integrity Projects Supervisor _ _ . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 6/9/2009 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 1 A-06 181-116 Na 0.25 22" 5/27/2009 1.70 5/31 /2009 1 C-08 181-052 9`6" 3.50 20" 5/27/2009 1.30 5/31/2009 1C-15 198-229 4'10" 1.00 25" 5/27/2009 3.40 5/31/2009 1D-125A 200-044 4'9" 1.00 10" 5/27/2009 4.50 6/1/2009 1H-03 182-115 15'10" 2.00 24" 5/27/2009 2.60 5/31/2009 Page 1 of 2 • • Maunder, Thomas E (DOA) From: Peirce, John W [John.W.Peirce@conocophillips.com] Sent: Wednesday, August Ofi, 2008 3:22 PM To: Maunder, Thomas E (DOA) Subject: FW: 1F-15 and 1A-06 Questions Tom, Mark Kovar's response is forwarded below re: 1A-06 and 1 F-15 possibilities to receive future Ml. Regards, John Peirce From: Peirce, John W Sent: Wednesday, August 06, 2008 3:19 PM v~~~~~r AQQ ~ ZQQ$ To: Kovar, Mark Subject: RE: 1F-15 and LA-06 Questions Mark, I'il forward your response on to Tom Maunder. If we don't think we'll have any more MI in the future put into 1A- 06, perhaps we should consider a status change for the well from WINJ. I'm not sure what the status acronym is for a water only injector. Maybe PWI? I don't know for sure if we need a Sundry or not for injection status changes on a well, but we would want to request a status change be made on the well schematic and in the Well Status table in our database (Oracle). Thanks, John Peirce From: Kovar, Mark Sent: Wednesday, August 06, 2008 3:10 PM To: Peirce, John W Cc: Versteeg, Joseph R Subject: RE: iF-15 and 1A-06 Questions 1A-06 is a mature MI pattern, so no additional MI is planned here. 1 F-15 is a target for additional MI injection in both the A and C sands with 4% and 7% HCPV of MI injected respectively. 1 discussed this with Joe Versteeg and he will schedule MI as necessary. I should point out that 1 F-15 was shut in due to flowline problems from May, 2002 until December, 2005. Mark Kovar Drillsite Petroleum Engineer CPF 1-A,F,G,Y Conocophillips Alaska Inc North Slope Operations & Development Anchorage, Alaska ATO 1280 Phone: 907 265-6097 8/6/2008 Page 2 of 2 • • From: Peirce, John W Sent: Wednesday, August 06, 2008 1:5$ PM To: 'Maunder, Thomas E (DOA ' Cc: Kovar, Mark Subject: Re: iF-15 an 1A-06 Questions Hi Tom, Re: 1 F-15, I agree the monthly injection data report shows no downtime during May and June 2008. This is because 1 F-15 was only shut-in for part of the day on the days when it was worked on during wellwork operations. The monthly injection data report counts any day that had any injection (even if it was only for an hour) as a day on injection. The monthly injection data report data derivation logic does not sum up total hours for a well on injection during the month then report the total hours on injection as an equivalent total days on injection value for the month. Note, the daily injection data report (copy attached for 1 F-15) shows hours on injection for every day. Also note, per the well event history report (also attached for 1 F-15), that the dates where well work was done, the hours shown on injection on the daily injection report is always something less than 24 hours, but not zero. The difference between 24 hours and the hours reported on injection on any particular day is attributable to the hours it took to complete well work that day on the well. Anyway, this explains why you don't see the well reported with any downtime on the monthly injection data report. A similar explanation for 1A-06 applies re: downtime. On your question suggesting need for a possible status change from 'WIND' or not based on the fact that we have not injected MI in a long time in 1 F-15 or 1A-06, I had to pass that question on to the 1A / 1 F Drillsite Engineer (Mark Kovar), since he has a better crystal ball than I to answer the questions. When I get a response back, I'll forward it to you ASAP. Regards, John Peirce Wells Engineer CPAI Drilling & Wells (907)-265-6471 office Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, August 06, 2008 11:05 AM To: 'Peirce, John W Cc: 'NSK Well Integrity Proj' Subject: KRU 1A-06 (181-116) John, Sort of the same question for this well. I note from the injection report that it has been some time since gas/MI has been injected into this weft (July 2005). Are there any plans to inject gas/MI in the future? You show the status to be "WIND". Just trying to have the status recorded correctly. Look forward to your reply. Tom Maunder, PE AOGCC STATE OF ALASKA ;~.o~' JUG 1 J 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIOI~~~~ ~~# ~~~~ ~`~~~' ~~~~"'`'''~"' 1. Operations Performed: Abandon ^ Repair Well Q ~ Plug Perforations ^ Stimulate ^ Other Q Set patch Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 181-116 / 3. Address: Stratigraphic ^ Service Q ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20638-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 93' ~ 1 A-06 ~ 8. Property Designation: 10. Field/Pool(s): ADL 25647; ALK 465 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9159' ~ feet true vertical 6852'- feet Plugs (measured) Effective Depth measured 8509' feet Junk (measured) 8579' true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SURFACE 2691' 10-3/4" 2791' 2513' PRODUCTION 8930' 7" 9030' 6761' Perforation depth: Measured depth: 8108'-8129', 8153'-8186', 8359'-8372', 8383'-8424' true vertical depth: 6093'-6108', 6126'-6150', 6276'-6286', 6294'-6324' Tubing (size, grade, and measured depth) 3-1/2", 2.875", 3-1/2", K-55, J-55, 8280', 8299', 8301' MD. Packers &SSSV (type & measured depth) pkr- BAKER 'FHL' HYD. SET RETR. ; BAKER 'DB' pkr- 8029' ; 8272' Camco TRDP-1A-SSA SSSV= 1785' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 2161 Subsequent to operation 2881 -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ ^~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-094 contact John Peirce @ 26 5-6471 Printed Name John Peirce Title Wells Group Engineer Signature .~" J""~ --_. Phone: 265-6471 ~~~~/© Date (~'~"/ • Pre b Sha n Allsu -Drake 263-4612 Form 10-404 Revised 04/2006 ~ ~ ~ ~ Submit Original Only ~~~ L Well History 1A-06 50029200 ~~~. Well History 1A-06:500292063800:8/6/2008 Date Event Page 1 of 8 07/06/2008 RAN IPROF WITH LEE TOOLS. RESULTS: TTS PATCH IS HOLDING. 100% OF INJECTION EXITING TUBING TAIL AND ENTERING A-4 SANDS. NO CROSSFLOW DETECTED WITH WELL SHUT IN. 06/21/2008 SET TTS PARAGON 26' PACKER, SPACER STINGER ASSEMBLY(26' OAL} IN LOWER PACKER @ 8247 RKB. RUN TEST TOOL TO TOP PACKER TEST 2000# (GOOD) 06/20/2008 SETA 3.5" TTS 350 PARAGON-2 PATCH LOWER PACKER WITH MID-ELEMENT AT DEPTH 8247. DURING TIE-IN, COULD NOT PULL PACKER UP THROUGH NIPPLE AT 8236' AFTER DROPPING DOWN THROUGH IT. SET DOWN AT PKR AT 8272' WHILE TRYING TO TIE IN. STILL ABLE TO SEE NIPPLE ON COLLAR LOCATOR BEFORE BEING STOPPED. TIED INTO NIPPLE AND SET TTS PATCH LOWER ELEMENT. ABLE TO PULL THROUGH RESTRICTION AFTER SETTING. 02/18/2008 RUN 2.735" GAUGE RING TO 2.75" AVA BPL @ 8236' RKB.RUN 2.688" GAUGE RING 30' BELOW AVA BPL BRUSHING AND FLUSHING WITH 60 BBL'S DIESEL.IN PROGRESS 02/17/2008 PULLED 2.75" AVA TPI (OLD STYLE) FROM 8236' RKB.TAGGED @ 8509' SLM.IN PROGRESS. 11/22/2007 RAN RST WFL WITH FULLBORE SPINNER. TOOL CONFIGURED FOR UP FLOW. FIRST RATE 2050 BPD/1050 PSI SPLITS: 43% A-SANDS / 57% C-SANDS, WFL CHANNELING, SECOND RATE PRESSURE 1280 PSI -RATE UNAVAILABLE DUE TO GAUGE MALFUNCTION USED HISTORICAL PRESSURE FOR 3300 BPD, SPLITS: 42% A-SANDS / 58% C-SANDS, WFL STATIONS AGAIN DO NOT SHOW PACKER LEAK, STATION 8310' SHOWS POSSIBLE CHANNELING 09/20/2007 OC POT-(PASSED); OC PPPOT-(PASSED}; INSTALLED 600 PSI. GAUGE ON CONDUCTOR. 08/04/2007 MULTI-RATE INJECTION PROFILE. RATE 1 AT 2458 BWPD/100 PSU147 DEG F. RESULTS: LEAK AT AVA SLEEVE ALLOWING FOR C SAND INJECTION. RESULTS: UNIT-D, C-4,3,2,1=47%. A-5=18%, A-4=35%. RATE 2=3500 BWPD AT 1200 PSI. RESULTS: UNIT-D, C-4,3,2,1=45%. A-5=5%, A-4=50%. RATE 3=5100 BWPD AT 1400 PSI. RESULTS: UNIT-D,C-4,3,2,1=41%, A-5=0%, A-4=59%. SHUT IN WELL FOR CROSSFLOW. WELL IS CROSSFLOWING FROM A TO C SANDS WITH WELL SHUT IN. 08/02/2007 SET CAT SV IN "D" NIPPLE @ 8280', RE-ATTEMPTED PT TBG- FAILED. POOH W/ SV. NOTE: D NIPPLE POSSIBLY DAMAGED. 08/01/2007 SWAGED TIGHT SPOT IN TBG HANGER & GAUGED TBG TO TOP OF AVA @ 8236' RKB W/ 2.79" GAUGE, PT TBG BELOW AVA FAILED, PT TBG TO 2000# ABOVE AVA W/ D&D TEST TOOL, REPLACED AVA W/ OLD STYLE 2.75" AVA TPI, IN PROGRESS 07/31/2007 SET 2.25" CAT SV @ 8289' RKB, TBG FAILED PRESSURE TEST, IN PROGRESS 07/24/2007 GAUGED TBG TO 2.80" TO AVA NIPPLE @ 8236' RKB. TOOLS HUNG UP @ 1702' http:/lbiz.ak.ppco.com/webbert/Well/Repart/rptWellTable.aspx?REPORT=..%2f. %2fiJser... 8/6/2008 -° Cono~vt~illips (" /~1a5~~. -__.. hr i~3 .1A-O6 I ~UP 1A-06 WDII Attributes wmiwrn wruum 500292063800 view acme KUPARUK RIVER UNIT Iwmi swius rnu.~mum mcLnu~~n INJ 54.00 1'1 lorai uepm ptne~ 9,159.0 Comment F1Y3 (ppm) Dats Annotaton End Data KB-Grd (ft) Rig Release Date SSSV: TRDP Last WO: 7!24/1987 39.01 9126/1981 Annotadon Depth (ftl(B) End Date Annotation End Date L: Est Taa: 8.509.0 12118/2008 Rev Reason: SET TBG PATCH FROM 8221 TO 8247 7l4@006 Casing Strings _ _.._ _ -1 ~~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~~~~~ ~U~7 ~ ~ ~~~~ ATTN: Beth i Well Job # Log Description / I/ ~-_ ., NO.4792 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnke~n 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 07/24/08 1A-06 12080402 INJECTION PROFILE ~ - ( 07/06/08 1 1 3C-17 11964626 SFRT (~~- 07/12/08 1 1 1Y-04 12096505 INJECTION PROFILE '- - b 07/13/08 1 1 1G-O6 12061729 INJECTION PROFILE a ~ 07/13/08 1 1 i F-06 12096506 PRODUCTION PROFILE - ~ 07/14/08 1 1 3M-08 12096516 SBHP SURVEY 07/21/08 1 1 3M-09 12096515 SBHP SURVEY (o (p 07/21/08 1 1 3N-13 12096517 SBHP SURVEY v C Co - 07/22/08 1 1 2W-01 12096508 PRODUCTION PROFILE ~ 07/16/08 1 1 1F-06 12096510 PRODUCTION PROFILE ~ -/C/ 07/17/08 1 1 2A-02 12096511 INJECTION PROFILE = 07/18/08 1 1 3J-17 12096514 SBHP SURVEY g I~~ ~- 07/20/08 1 1 3J-07A 12097409 ~ SBHP SURVEY (' ~_~~~ ®(~~~~ 07/20/08 1 1 3C-15A 12097406 USIT ( / '~ 07/17/08 1 1 2A-05 12096512 SCMT ~(- 07/19/08 1 1 J Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • ._ ~ ~ ~ d ~" ~ ~ ~ SARAH PALIN, GOVERNOR railta-78A OII/ ~ ~~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA7`IO1~T COI~IMISSIOIQ ANCHORAGE,AIP,SKA 99501-3539 PHONE (907) 279-1433 - FAX (907) 276-7542 John Peirce Wells Group Ehgineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: s~°~.~M~~ M,~R ~ ~ 200 Kuparuk River Field, Kuparuk River Oil Pool, 1A-06 Sundry Number: 308-094 Dear Mr. Peirce: Enclosed is the above referenced enclosed form. 1~1 ~" ~` approved Application for Sundry Approval relating to the well. Please note the conditions of approval set out in the When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided iri AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount, Jr. Chair DATED this ?~ day of March, 2008 Encl. ~ C~.3•ti~.~ i~ECEIVE® ~, .e STATE OF ALASKA ~~~ MAR 2 t~'~C ALASKA OIL AND GAS CONSERVATION COMMISSION ~ APPLICATION FOR SUNDRY APPROVA1laska oil ~ Gas Cons. issior~ 20 AAC 25.2so Anchorage 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^/ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 181-116 3. Address: Stratigraphic ^ Service Q ~ 6. API Number: P. O. Box 100360, Anchors e, Alaska 99510 50-029-20638-00 7. If perforating, c{osest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS ^ NO Q 1A-06 9. Property Designation: X10. KB Elevation (ft): 11. FieldfPool(s): °'J ADL 25647, ALK 465 RKB 93' L Kuparuk River Field /Kuparuk Oil Pool , 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9159' 6852' 8509' 8579' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 80' 80' SURFACE 2691' 10-3/4" 2791' 2513' PRODUCTION 8930' 7" 9030' 6761' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8108'-8129', 8153'-8186', 8359'-8372', 8383'-8424' 6093'-6108', 6126'-6150', 6276'-6286', 6294'-6324' 3-1/2", 2.875", 3-1/2" K-55, J-55 8280', 8299', 8301' Packers and SSSV Type: Packers and SSSV MD (ft) pkr- BAKER'FHL' HYD. SET RETR. ; BAKER'DB' pkr= 8029' ; 8272' Camco TRDP-1A-SSA SSSV= 1785' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: April 4, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ 0 ~ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Printed Name John Peirce Title: Wells Group Engineer Signature ,~ ~ "'- Phone 265-6471 Date 3/Z~ Q Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test^ Location Clearance ^ Other: ~`~ C_~3ti~, ~~~~~'~"~~~~ '~~ c~-V ~~-~r~~a~ Subsequent Form Required: ~~~1 C- APPROVED BY Approved b "~ MM SIONER THE OMMISSION Date: Form 1~~2e~ed 06/20 ~~ ~' ~ t j"~ ~ "~ ~ Submit in plicate ~~~~ ~_ • Well 1 A-06 Proposed Tubing Patch Install for Injection Profile Modification 1A-06 is a selective injector with 3.5" tubing. An IPROF ran on 8/4/07 indicated 45% of PWI enters the C sand through a washed out AVA BPL ported nipple with TPI at 8246' RKB. TPI change outs have failed to stop PWI from entering the C sand. An RST log ran on 11/22/07 showed 58% of PWI entering the leaky TPI at 8246' RKB, and verified no packer leak exists from the A to C sand. A 20' retrievable tubing patch will be set over the AVA BPL to halt all injection to the C sand, and 1A-06 will be returned to injection as an `A sand only' injector. Recent Work Completed: 2-17-08: pulled leaky TPI from AVA BPL; tagged 8509' SLM (85' RH below A Sd perfs). 2-18-08: ran 2.688" gauge through AVA BPL; verified AVA BPL has 2.697" ID (No-Go); completed the brush and flush in area to be patched. Proposed Tubing Patch Install Procedure: E-line: RU E-line. RIH with a lower straddle packer with a 2.68" reduced running OD. Set the packer with the element at 8247' RKB in the 3.5" full joint just below the washed out AVA BPL Ported Nipple at 8236' RKB. This will place the lower patch packer 9' below the AVA BPL. POOH with running tools. Slickline: 2. RIH with a standard 2.72" run OD straddle packer, 20' spacer pipe, and an Anchor Seal assembly. Sting and latch into the lower packer at 8247' RKB. Set the top packer at 8227' RKB in the 3.5" full joint just above the leaky AVA BPL. This places the upper packer ~9' above the AVA BPL to complete the patch at 8227 - 8247' RKB (seal to seal). RD E-line. Return the well to `A sand only' injection and obtain valid injection test. 1A-06 Tubing Patch: 10-403 attachment 3/25/08 - J.Peirce ~C~I~~II~~~'~I' Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description N0.4532 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 12/20/07 1J-105 11837540 INJECTION PROFILE ~'a'1'~-C~''~-- 11/20/07 1 1A-06 11837542 _ RST WFL ~'j -/I ` 1. 11/22/07 1 1 Q-05 11837537 _ LDL ~ - ( 11/17/07 1 1B-12 11970607 INJECTION PROFILE vT 12/04/07 1 2N-327 11996582 OILPHASE SAMPLER Q~- (a 12/15/07 1 1D-132 11994588 SBHP SURVEY ~}~' o(. - ~ 12/17/07 1 3H-10B 11996580 PATCH EVALUATION 12N3I07 1 3N-02A 11970609 LDL $ - 12/05107 1 1C-125 11964553 INJECTION PROFILE 12/01/07 1 2M-15 NIA PRODUCTION PROFILE ( ~ 12/10/07 1 2M-11 NIA PRODUCTION PROFILE '(q .- I 12/08/07 1 3A-03B 11970604 SCMT ''-~- / 12/01/07 1 2T-217A 11978431 SCMT 12/15/07 1 2L-330 11837544 FULLBORE MICRO SCANNER ~ 11/27/07 1 2L-330 11837544 SONIC SCANNER 11/27107 1 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Schlumbergør û, NO. 4384 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 2 '7 Z007 commlssion n.. ..4 .... . 'lJ.\v I ~\}\1 ~ 1 S'G~~t.O Company: P, ,.J!, Field: Well Job# Log Description Date BL 1 R-27 11850425 FPIT ¡q / -/0:;). 08/18/07 1 31-08 11839638 LDL ).¡ç{A -r#l\ 07/28/07 1 2M-19 11813070 INJECTION PROFILE / 1'"\1' I~ 1-12-:1 07/29/07 1 3G-26 11813071 LDL )o'O¡-r-.";}:....- 07/30/07 1 1R-18 11837482 SBHP/DDL )C>¡ I -' ^ fS'1 07/31/07 1 1Y-01 11813072 INJECTION PROFILE U-r:t' - ¡'5<3~ó 07/31/07 1 2C-08 11813073 INJECTION PROFILE"/1TI' l'fr~ -(-(:1<", 08/01/07 1 3H-32 11837483 LDL ..:-'W") _"q." 08/01/07 1 1Y-10 11837485 INJECTION PROFILE " U:t.(\ J ~7.. - t'"'fÇ""' ì 08/03/07 1 3G-08 11813075 PRODUCTION PROFILE" 1~/) - () ~fr 08/04/07 1 1A-06 11837486 INJECTION PROFILE i ,,-,, /-;cI-I1l- 08/04/07 1 2N-337B 11837489 PRODUCTION PROFILE ",q/,-.( _ - If A ~ 08/06/07 1 2U-08 11813076 LDL WI7\: ,~-~( 08/06/07 1 1G-12 11837490 PRODUCTION PROFILE 1f5~ - "~~ 08/07/07 1 2N-343 11745232 MEM INJECTION PROFILE" ()î"(' IC;~-~~ 08/08/07 1 2N-327 11837491 SONIC SCANNER ~"'i-~&>'¡ 08/08/07 2N·327 11837491 SONIC SCANNER-FMI ........."'"1 ~F~ 08/08/07 3K-01 11632749 PRODUCTION PROFILE " IfrtD ~ 1,)/ 08/12/07 1 2X-04 11846430 INJECTION PROFILE ( ¡""L{\ )~~ -1t*' 08/13/07 1 2Z-29 11850419 SBHP SURVEY I~~J::JCJ 08/13/07 1 2X-19 11850420 SBHP SURVEY I C} Õ - J/,J.,<,- 08/13/07 1 1A-20 11850421 SBHP SURVEY J ~() - IC:) 08/14/07 1 1F-13 11850422 SBHP SURVEY () 'TI '\ J~~"2., -WI.J 08/14/07 1 1H-10 11846432 SBHP SURVEY ¡Oi -:;. - ^-:q-..., 08/14/07 1 1Q-10 11846431 SBHP SURVEY I ';r¿ - 1(:1?r 08/14/07 1 2U-05 11846433 INJECTION PROFILE / ''T '" J!kC\ - rv< 08/15/07 1 2D-12 11846434 PRODUCTION PROFILE 1*4 -I"A'-I 08/16/07 1 2H-06 11846435 LDL J1r~ -II..&:{ 08/17/07 1 Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color CD 1 1 ';)71" Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 08/22/07 . . MEMORANDUM TO: FROM: Jim Regg P.I. Supervisor Bob Noble Petroleum Inspector . Rqq 7(ti-i/ù7 Well Name: KUPARUK RIV UNIT IA-06 Insp Num: mitR(;¡<;070719124903 Rei Insp Num: Well: 1A-06 iType Inj. I N I I P.T.D! 1811160 ¡TypeTest I SPT 4YRTST Interval Notes: P/F Friday, July 20, 2007 Packer TVD Test psi P /' State of Alaska . Alaska Oil and Gas Conservation Commission DATE: Friday, July 20, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lA-06 KUPARUK RIV UNIT lA-06 S rc: Inspector NON-CONFIDENTIAL API Well Number: 50-029-20638-00-00 Permit Number: 181-116-0 >s\\VJ \LC Reviewed By: P.I. Suprv,.~~ Comm Inspector Name: Bob Noble Inspection Date: 7/15/2007 600 2260 15 Min. 30 Min. 45 Min. 60 Min. IJ,,~th -yL 6035 ,/: IA ! 1680 ¡ OA Tubing Pretest Initial 300 660 300 660 SCANNED AUG 06 2007 I 2240 ¡ 2230 I i , i .---- 300 i 300! i ----+--~~._J__.---,. 660 ¡ 660! ' I J-! Page I of I RECEIVED Scbbnbel'gel' MAY 2 4 2006 ~ Oif & Gas Gens. CQmrr~ ,~mg~ NO. 3808 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 \ \ø Anchorage, AK 99501 , \ \Cb'\ ''f'ß¡.i\ìÌ;,IFC '.:h.J·'\"L;1- - ~) Field: Kuparuk Well Log Description Date Color CD Job # BL 1 G-01 (REDO) 11213744 INJECTION PROFILE ¡if d - ï3ò 05/03/06 1 1 Q-26 11258706 PRODUCTION LOG W/DEFT ì c, '" - I ~ ';) 05/06/06 1 1A-03 11258708 PRODUCTION LOG W/DEFT I "6 ì - 0 ~1r 05/07/06 1 1 Y -15A 11216294 PRODUCTION LOG W/DEFT 1<; ?( _ I qfA 05/08/06 1 1 A-02 11258709 SBHP SURVEY V :r c. I ~ I - ()~ I 05/09/06 1 1 R-13 11258711 INJECTION PROFILE (' :l e.. \ 'i-¡i,\, - ¡,,--{' 05/10/06 1 2M-34 11216296 INJECTION PROFILE 1Jì:-~ IQ(:~- ,,~~ 05/11/06 1 2F-03 11216298 SBHP SURVEY ì ' '"," ,. \ "'ir ~ - ¡.;,-1- 05/14/06 1 2F-14 11216299 SBHP SURVEY U'tf' 11I-~-' ~ 05/14/06 1 1A-06 11258712 INJECTION PROFILE ~ J '¡- Q. i';:'; I - I J (.,. 05/14/06 1 3Q-11 11216301 LDL ¡ 'tG, -/7<;'- 05/16/06 1 1J-184 11216297 USIT () .,. (' .:::1..-,,', n¿¡¿t 05/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~.lt--- ~!Ð~!o(; 9 05/18/06 e e Schlumbergel' Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth Well 4 DJ' ¡5~2P447 (/\. ~ 2P-447 18/"'/117 1A-06 Rt:Jb,z'3J 3F-21 ~of~W 1H-05A Job # 10709677 10696820 10942812 10942813 10687716 USIT USIT INJECTION PROFILE INJECTION PROFILE MDT 4¡£~ SIG~: Log Description Date 12/30/04 NO. 3297 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk -,' BL Color CD 1 1 1 ./ 12/24/03 01/07/04 12/21/04 01/07/04 12/13/04 ,...-...CA" NN" E~" ¡1DR 1 5, LOU;) ~" L" ,C U .-d ,. """ ~ 1 1 ~ DATE: /f3¡:~ Please sign and retur one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ARCO Alaska, Inc.,[ Post Office Bbx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 23, 1992 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr Johnston' Attached in duplicate are multiple Report of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below WELL ACTION WELL ACTION 1A-06 Co nye rs~o n 1 C-06 Waive r 1 C-06 Conve rs~on 1E-03 Stimulate 1G-02 Perforate 1G-03 St~ m u late 1G-14 Perforate 1G-14 Stimulate 1 L-25 Perforate 1 L-25 St,mu late 1Q-13 Perforate 1Q-13 Stimulate 1R-09 Stimulate 1 R-21 Stimulate 1Y-04 Perforate 1Y-04 Stimulate 1Y-07 Co nve rs~o n 1Y-09 Waive r 1Y-09 Conversion 1Y-29 Other 3R-18 Stimulate If you have any questions, please call me at 263-4281. Sincerely, C W. Strickland Sr Engineer Kuparuk Petroleum Eng~neenng Alaska 0ii & 6as Cons. oomm'tss'~or~ ARCO Alaska, Inc ~s a Subsidiary of AtlanbcR~chfleldCompany AR3B-6003-C Report of Well Sutl~ Page 2 ~ Operabons bxc: V. L Ferguson P. A. Lindberg Well Files FTR062395 ATO-1228 ATO-1431 (w/o attachments) (w/c) attachments) (Form 10-404 only) (w/o attachments) Subject: Report of Sundry Well Operations, 1A-06, 1C-06, 1E-03, 1Go 02, 1G-03, 1G-14, 1L-25, 1Q-13, 1R-09, 1R-21, 1Y-04, 1Y-07, 1Y-09, 1Y-29 3R-18 Original + one copy to AOGCC (one -sided copy) RECEIVED JUN 2 5 1995 Alaska Oil & Gas Cons. uumrmsslon Anchorage AL~ STATE OF ~ ~ OIL AND GAS ~RVATION COM REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 779' FSL, 310' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1349' FSL, 1254' FWL, Sec. 8, T11N, R10E, UM At effective depth 770' FSL, 1340' FWL, Sec. 8, T11N, R10E, UM At total depth 614' FSL~ 1345' FWL~ Sec. 8~ T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 91 5 9 feet true vertical 6 85 2 feet 5. Type of Well: Development Exploratory Stratigraphic I Plugs (measured) 6. Datum elevation (DF or KB) RKB 100 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1A-06 9. Permit nuj;nber/approval number 81-116 I10. APl number so-029-20638 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool \1 Effective depth: measured 8 9 4 0 feet true vertical 6698 feet Junk (measured) Vann Gun @ 8579' Casing Length Size Structural Conductor 8 0' 1 6" Surface 2791' 10 Intermediate Production 902 9' 7" Liner Perforation depth: measured 8108'-8129', true vertical 6093'-6108', Tubing (size, grade, and measured depth) Cemented Measured depth True vertical depth 200 SX PF 8 0' 8 0' 3/4" 1100 SX Fondu & 2791' 2513' 250 SX AS II 850 SX Class G & 9029' 6760' 250 SX AS II 8153'-8186', 8359'-8372' 6126'-6150', 6276'-6285' 8383'-8424' 6293'-6323' 3.5", 9.3#, J-55 @ 8280', 2.875, 6.5#, J-55 @ 8280'-8301' Packers and SSSV (type and measured depth) PKR: Baker FHL @ 8029' & Baker DB ~ 8272'; SSSV: Camco TRDP-1A-SSA@ 1785' 13. Stimulation or cement squeeze summary REr(~EIVED Converted well from water injection to MWAG injection on 4/11/93. Intervals treated (measured) N/A JUN 2 5 1993 Treatment description including volumes used and final pressure N/A Alaska 0~1 & Gas Cons. bun~rnission 14. Reoresentative Daily Average Production or In!action Data Anchorage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation -0- 0 - 6200 1300 2450 Subsequent to operation - 0 - 9 0 0 0 -0- 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ~ Oil _ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1600 3900 Service MW^G In!ector Fnrrn 1ll-404 RAv rIR/1R/RR RI IRMIT IN I~1 IPl I~ATF P~'3D,.:~..:,: I [ON WELL :"'l? "TUS. ii:-.,: ~I~ 5_' 0 i- CHOI/,E OR WC F!2S CSg CSg % FTP F'TT % PPM PSi PSI 176 411 121 84 100 i700 176 282 1.20 70 176 222 90 26 17& 300 &O 37 50 l'7& 343 122 73 175 176 249 ti2 ~4 200 176 315 t37 85 400 176 205 87 5 50 176 297 !23 66 790 176 281 140 80 800 · . 176 ~71 118 66 200 " 0 OM OM 19 0 176 251 i17 70 176 278 77 24 gAS LIFT STATUS IOOR = 15000 SI OAT; gAS gAS INd OPT OPT METER VOL RATE OL READiNg , MSCF MSCFD ROOTS 680 0 693 810 ~0 !600 !200R 0 564 475 50 1000 I 150W 0 105 1588 10 I000 3094 328M 534 75 2000 0 2681 1996 80 1410 0 114 719 20 1500 0 2016 2000 !0 1325 0 1307 1811 20 !300 0 1135 !303 20 !675 0 1728 1738 25 1450 0 1479 I500 10 1360 0 0 0 15 1700 0 459 508 20 '1425 ~5' 0 1325 1256 ( H M ( R I I S N ~ 4. 2 0000 ( 2. 1 0000 ( 9. 1 2030 6( 0.0 0000 7.3 0000 4.3 0000 ( 8.7 0000 ( 9.0 0000 9.5 0000 7.6 0000 ( 4.1~ 0000-( 0.07 2400 1. 2.2 0000 ( 5.5 0000 (OTALS' 13934 16238 ~NJECTION WELL STATUS INdECTION VOLUMES SI DATA W Z S WATER RECMD gAS C E 0 T CHO½E 7" 10" INO INO INO H M 0 !.. N A OR iNO CSO CSO METER VOL RATE VOL R I D :__ E T % PSI FTT PSI PSI READINg BBLS BW:PD MMSCF S N E ,i B .~I 100 3802 96 2350 340 0 0 0 5. 698 0000 0 ':,5 A SW !00 2436 ,79. ,. 2000* ~oo o 2441 6923 O- ooo 0o00 o '7 B SW 9 B SW L2 B PW [3 t3 PW '.4 B. PW 5 B PW ,.o B OI 100 2420 .... .",..75'2200R 75 0 4174 554.4 0.000 66 2~27 ]~,~[ 500 225 0 3033 4677 0:000 176 2298 1325 1250- 0 8024 6932 0.000 .176 2321 .... 900 725 0 5619 ........ 0 0.000 176 2369 145 625 225 O' 2935 3890 0.000 176 2319 146 t000 775 0 5~36 5103 0.000 100 3000 96 1575 17~ 0 0 0 6.254 0000 0 0000 0 0000' 0 0000 0 0000 0 0000 0 0000 0 0000 0 "OTALS' SWI' 11399 + PWI- 24629 = 36028 37108 14.434 ._ RECE'IVED jU'.N'2 § 199 Anchorage ( STATE OF~couu, ,o,f 0 I{ I G IN ALASKA OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Suspend Operation Shutdown_ Re-enter suspended well_ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) Abandon Alter casing _ Repair well _ Change approved program X 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 779' FSL, 310' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1349' FSL, 1254' FWL, Sec. 8, T11N, R10E, UM At effective depth 770' FSL, 1340' FWL, Sec. 8, T11N, R10E, UM At total depth 6!4' FSLr 1345' FWL~ Sec. 8r T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 91 5 9' feet true vertical 6852' feet measured 8 9 4 0' fe et true vertical 6 6 9 8' feet Length Size 8O' 16" 2791' 1 0-3/4" 9029' 7" Effective depth: Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: lOO 7. Unit or Property name Kuparuk River Unit 13. feet 8. Well number 1A-06 9. Permit number 81-116 10. APl number so-029-20638-00 11. Field/Pool Kuparuk River Field/ Kuparuk River Oil Pool Junk (measured) Vann Gun @ 8579' MD-RKB Cemented Measured depth True vertical depth 200 sx PF cmt 80' 8 0' 1100 sx Fondu & 2791' 2513' 250 sx AS II 850 sx Class G & 9029' 6760' 250 sx AS II measured 8108'-8129', 8153'-8186', 8359'-8372', 8383'-8424' true vertical 6093'-6108', 6126'-6150', 6276'-6285', 6293'-6323' Tubing (size, grade, and measured depth) 3-1/2", 9.3# K-55 to 8280'; Packers and SSSV (type and measured depth) RECEIVE MAR - 4 1992 2-7/8", 6.5# J-55 from 8280' to 8301' Alaska 0ii & Gas Cons. Co~ Anchorage Baker DB pkr @ 8272'; Baker FHL pkr @ 8029'; Camco TRDP-1A-SSA SSSV ~ 1785' Attachments Description summary of proposal .~_ Detailed operation program _ BOP sketch _ Convert well from oil producer to WAG injector 14. Estimated date for commencing operation Februarv 1992 16. If p~posal wal~verba~ly approved Name or approver ~J Date approved 15. Status of well classification as: Oil __ Gas _ Suspended _ Service WAG injector 17. I hereby certify that the foregoing~ Signed C-[~J, ~ is true and correct to the best of my knowledge. Title Operations Engineer FOR COMMISSION USE ONLY Date Conditions of approval' Plug integrity _ ,BC~P Test Mechanical Integrity Test Notify Commission so representative may witness Location clearance Subsequent form require Approved by order of the Commission Form 10-403 Rev 06/15/88 IApproval_No. / ORIGINAL SIGNED BY '3 -to - ~1'3 Commissioner Date ~ - c] _ cj ~ SUBMIT IN TRIPLICATE ~m'tssi( KRU Well 1A-06 Conversion to Water Injection ARCO Alaska requests approval to convert Well 1A-06 from an oil producer to a water-alternating-gas (WAG) injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water will be injected alternately with gas for the purpose of enhanced recovery into the Kuparuk interval between the depths of 8108' and 8424'. This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. RECEIVED MAR - 4 t992 Alaska Oil & Gas Cons. Commissio[~ Anchorage OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown Pull tubing Alter casing 2. Name of Operator I I ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 779' FSL, 310' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1351' FSL, 1254' FWL, Sec. 8, T11N, R10E, UM At effective depth 770' FSL, 1340' FWL, Sec. 8, T11N, R10E, UM At total depth 614' FSL~ 1345' FWL~ Sec. 8~ T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 91 5 9' true vertical 6852' Stimulate X Repair well 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service feet Plugs (measured) feet 111' Plugging Perforate _ Other 6. Datum elevation (DF or KB) RKB 93 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1A-06 9. Permit number 81-116/90-§~1 10. APl number s0-029-2063800 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 823 6' feet true vertical 61 84' feet Length Size Junk (measured) Vann Gun 361' MD Cemented Measured depth 8 0' 1 6" Surf-80' 80' 3409' 1 0-3/4" Surf-2791' 2791' 7954' 7" Surf-9030' 9030' measured 8108'-8196', 8359'-8372', 8383'-8424' MD 13. true vertical 6093'-6157', 6276'-6286', 6294'-6325' TVD Tubing (size, grade, and measured depth 3-1/2", J-55, BTC, 9.3 #/ft set at 8301' Packers and SSSV (type and measured depth) Baker DB @ 8272'; Baker FHL ~ 8029': Camco TRDP 1A-SSA SSSV ~ 1785'. Stimulation or cement squeeze summary A Sand Re-frac Intervals treated (measured) 8359'-8372', 8383'-8424' Treatment description including volumes used and final pressure See Attached WSR True vertical depth 80 2512' 6760 14. Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 880 470 50 1000 140 Subsequent to operation 1 6 3 0 1 4 9 0 9 0 1 2 0 0 15. Attachments 16, Status of well classification as: Copies of Logs and Surveys run__ Water Injector __ Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 200 Form 10-404 Rev 09/12/90 Title Date //~' - ~/''' ? ~j SUBMIT IN DUPLICATE ARCO Alaska, Ir~ Subsidiary of Atlantic Richfield Company CONTRACTOR REMARKS FIELD - DISTRICT- STATE K'. ~. ~,. WELL SERVICE REPOR'I IOPERA;rlON AT REIK:)Ri-TIME 10/t> ~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK REMARKS CONTINUED. DESCRIPTION DAILY ACCUM. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ~r/~,~./) (__)C_), ARCTIC COIL TUBING · FRACMASTER Roustabouts D,esel l,.,,,~d3 $3L Methanol Superv,s,on · Pre-Job Safety MeetIng AFE ~ ~/-,~/ ARCO Alaska, Inc. ~ Post Ofhce Box*' ,~J0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 23, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action Anticipated Start Date 1A-06 Stimulate August, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J.R. Brandstetter ATO 1120 w/o attachments L. Perini ATO 1130 KOE1.4-9 ARCO Alaska, Inc is a Subsidiary of AtlanhcRIchheidCon~p~'ay , ( STATE OFALASKA ( 0 ~ I~1~! ~'~ OIL AND GAS CONSERVA13ON COMk~ ON ' APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well_ Plugging _ Change approved program _ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Pull tubing _ 5. Type of Well: Development X Exploratory _ Stratigraphic _ 4. Location of well at surface 779' FSL, 310' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1351' FSL, 1254' FWL, Sec. 8, T11N, R10E, UM At effective depth 770' FSL, 1340' FWL, Sec.8, T11N, R10E, UM At total depth 614-FSL, 1345' FWL~ Sec. 8~ T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 91 5 9' feet true vertical 6 8 5 2 feet Plugs (measured) Time extension _ Stimulate X Variance Perforate Other 6. Datum elevation (DF or KB) RKB 93 7. Unit or Property name Kuparuk River Unit 8. Well number 1A-06 9. Permit number 81-116 10. APl number so-029-20§38 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 823 6' feet Junk (measured) 61 8 4' feet None Casing Length Structural Conductor 8 0' Surface 3 4 0 9' Intermediate Production 79 5 4' Liner Perforation depth: measured 8108'-8196', true vertical 6093'-6157', Size Cemented 1 6" Surf-80' 10 3/4" Surf-2791" 7" Surf-9030' 8359'-8372', 6276'-6286', 8383'-8424' 6294'-6325' Measured depth True vertical depth 80' 80' 2791' 2152' 9030' 6760' Tubing (size, grade, and measured depth 3 1/2", J-55, BTC, 9.3#/ft set @ 8301' Packers and SSSV (type and measured depth) Baker DB @ 8272'; Baker FHL @ 8029', Camco TRDP 1A-SSA SSSV @ 1785' ' ' 13. Attachments Description summary of proposal X Detailed operation program _ Refrac A Sands with 72,000 Carbo-Lite proppant. (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: September. 1990 oil ~[ Gas _ 16 If proposal was verbally approved Name of approver Date approved S e r vi ce RECEIVED AUG 2 8 ,~J,~:,a Oil & Gas Col~s. BOP sketch Suspended _ S~gned17 I he,~~ t~the foregoing is true and correct to the best of my knowledge., ~ Title FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance Mechanical Integrity Test_ -- Subsequent form require 10-~L°~' IApprov o. Approved by the order Commission Form 10-403 Rev 5/03/89 Approved Copy ... R~turged : Commissioner Date ~'/~ ~0 SUBMIT IN TRIPLICATE ORIGINAL SIGNED BY LONNIE C. SMITH ¢ Messrs.Gibbs and Hutchins 8/23/90 Page 2 Kuparuk Well 1A-06 'A' Sand Re-Fracture Procedure Charge Code: AFE No. K81581 PRE-FRAC SLICKLINE 1. Obtain a 24 hour well test. 2. 3. 4. . 10. MIRU Slickline Unit. RIH with 2" gauge ring and tag bottom. RIH with 2.79" gauge ring to check for scale. NOTE: If scale is found consult with Operations Engineering. RIH and pull GLV's and OV at 3196', 5853', 6746', 7961' MD RKB. Replace with DV's. RIH with Standing Valve and set in CAMCO 'D' nipple at 8289' RKB. Pressure test tubing to 4500 psi. Pull SV. RDMO Slickline Unit. NOTE: Fill was last tagged on 04/30/89 at 8468' MD RKB'. Consult with Operations Engineering if fill is tagged any higher to evaluate if a pre-refrac CTU cleanout is required. PROPPANT FRACTURE TREATMENT 12. RU fracture equipment. Install "Tree Saver". Pressure up 7" annulus to 3500 psi. 13. Carry out all fluid quality control procedures (On-site Operations Engineer). Obtain samples of: Clean proppant - Pre-pad, pad, 2, 6, 10, & 12 ppa stages, and flush 14. Pump the 150 bbl pre-pad. Calculate perforation friction. Operations Engineer. Shut down for ISIP and 10 minute pressure fall-off. If perf friction is greater thatn 1500 psi Contact RECEIVED MessrS Gibbs and Hutchins 8/23/90 Page 3 1 5. Pump fracture treatment per the attached schedule: WHTPE = 4300 psi Fracture Gradient = 0.77 - 6276' TVD Tubing Friction = 180 to 280 psi/1000' - 8300' MD (Dependent on vendor selected) Recommended Max. WHP = 6300 psi 16. If treating pressure during the job exceeds 5500 psi, reduce the rate to 20 bpm. Rig down frac equipment. POST FRAC 1 7. RU Slickline Unit and pull Petredat gauges and Tag fill. 18. If perforations are not covered and after the gel has fully broken, proceed with fiowback per accepted guidelines. 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. Messrs Gibbs and Hutchins 8/23/90 Page 4 1A-06 REFRACTURE TREATMENT AFE #K81581 WELL SPECIFICATIONS Wellhead (FMC Gen I Retro) SSSV (Baker FVL) GLM's (CAMCO KBUG 1") GLM's (Otis 1.5") Packer (Baker FHL) Packer (Baker DB) "NC)GO" (CAMCO 'D') Tubing Tail A Sand Perforations 12 SPF Tagged Fill PBTD Maximum Hole Angle Hole Angle Across Perfs Tubing Casing Flush to top of A Sand Perfs TVD Depth to Top A Sand Perf NOTE: All Depths are MD-RKB 5000 psi MAWHP 1785' 3196',4589', 5021', 5455', 5853', 6310', 6746', 7177', 7587', 8072' 7961' 8003' 8272' 8289' 8301' 8359-8372', 8383-8424' 8468' 8940' 54° at 3600' 43° 3 1/2", 9.3 Ib/ft 7", 26.0 Ib/ft 74 bbl 6276' (1) (2) FRACTURING FLUID SPECIFICATIONS Base fluid to be clean fresh water with 2% KCl and Biocide added. - water samples to be taken from each tank prior to job and checked (actual tests will be worked out with vendor once selected) A 40# HPG fluid with a non-delayed Borate crosslinker is recommended. Options include: DS YF240 Halliburton Bora-Gel BJ Titan Terra Frac RXL II B or Terra Frac II R-4 STAGE FLUID DESCRIPTION KUPARUK WELL 1A-06 'A' SAND REFRACTURE PUMP SCHEDULE GELLED WATER FRACTURE TREATMENT 8/23/90 CLEAN VOLUME PUMP RATE PROP ~. PROPPANT PROPPANT WT BBLS BPM PPG DESCRIPTION LBS DIRTY VOLUME STG/CUM HIT PERFS BBLS GW PRE-PAD 150 0 25 0 - - 0 --- SHUT DOWN 10 MINS FOR ISIP; FRACTURE CLOSURE PRESSURE MEASUREMENT 25 0 -- 0 25 2 12/18 M CARBO-LITE 4632 25 4 12/18 M CARBO-LITE 5713 25 6 12/18 M CARBO-LITE 9965 25 8 12/18 M CARBO-LITE 14905 2 5 10 12/18 M CARBO-LITE 17491 25 1 2 12/18 M CARBO-LITE 19779 25 0 -- 0 GW PAD 7OO 0 GW w/2 PPG 55 1 GW wi4 PPG 34 0 GW wi6 PPG 39 5 GW w/8 PPG 44 4 GW wi10 PPG 41 6 GW w/12 PPG 39 2 SUCK DIESEL FLUSH 72 0 +SV TOTAL GELLED WATER = 1061 4 BBLS TOTAL CLEAN DIESEL = 42 5 BBLS TOTAL SLICK DIESEL = 72 0 BBLS +SV 1501 150 7001 850 601 910 401 950 501 1000 601 1060 601 1120 601 1180 721 1252 16/20 M CARBO-LITE 72485 LBS Stages I through 8 are Gelled Water Stages 1&2 are Gelled Water with 5% Arctic Diesel, 40 lbs/1000 gal silica flour and enough breaker for a 4 hour break. Stage 2 should be Increased to 750 bbl if on-site personnel decide to pump a diesel or non-cro~slinked flush after Stage 1. Stages 3 through 8 are Gelled Water with 4 hour breaker and without diesel or silica flour. Stage 9 (flush) should include a volume adjustment for surface equipment between lite wellhead and densimeter. This job is ~ntentlonally underflushed by 2 bbl The blender tub should be bypassed at flush. All fluids should be maintained at + 90° F on the surface 74 148 848 908 948 998 1058 1118 ¢ KUPARUK WELL 1A-06 APl It: SPUD DATE: ORIGINAL RKB: 09/05/81 ADL LEASE: 25647 COMPLETION DATE: 02/24/87 PERMIT It: WORKOVER DATE: SURFACE LOCATION: 7"/9'FSL,310'FWI,,SECS,T11 N,R10E TOP OF KUPARUK: 1351'FSL,1254'FWI.,SECS,T11N,R10E 'ID LOCATION: 614'FSL,134~FWL. SECa,T11FLR10E 100 TUBING SPOOL: 27 PAD ELEVATION: WELLTYPE: Ft~ GENI RETRO 1~' ~ H.40 ~0 10.7S' 48.~ K-68 2791 7' ~ K-SE 9030 3.5' 9.3~ J-E8 B'rC 8301 BTM UNER DETAIL.~ SIZE WEIGHT GRADE TOP TUBING JEWELRY ITEM TYPE ID DEPTH Sssv CAMCO TRDP 1A-SSA 1785 SOR BAKER 6003 PKR BAKER I=H 8029 AVA AVA 'BPL' NIPPLE 8236 PKR BAKER DB 8272 NOGO CAMCO 2 25' 8289 SHROUT VANN 8300 DEPTH 1200 36OO k MISC. DATA DESCRIPTION KICK OFF POINT. MAX HOLE ANGLE: 54 HOLE ANGLE THRU KUP: 43 LAST TAG DATE: ~ RATHOLE: 44 FISH/OBSTRUCTION: VANN GUN ~61.43'LONG 8TN 1 2 3 mail 4 $ 7 8 9 10 11 12 81-116 02/24/87 GA8 LIFT lad FLOW INFORMA11ON VALVE DEPTH MAN~ SIZE 3166 CAM(X) ~ 1' 4600 ~KBU~ 1" 6021 CAMCO KBUG 1" 6466 CAM(X) KBUG 1" __r.e~_~ C, AMCO ~ 1" 6310 CAM(X) KBUG 1" 71~ ~~ 1' 7~1 O~ ~X 1 5' ~ AVA 3 5' PERFORATION DATA INTERVAL ZONE FT SPF PHASE 8108-8129 C 21 12 120 8153..8186 C 33 12 120 8359-8372 A 13 4 120 8353-8424 A 41 4 120 REVISION DATE: 06/29~ REASON: 0.1~$ .DY .DV .DV 0.25 .DV 0.~ .DV DV 0.25 DV lSD COMMENTS SQUEEZED REPERFED @ W 5" VANN GUNS 5" VANN GUNS STATE OF ALASKA ALA ~ OIL AND GAS CONSERVATION COM ,,SSION REPORT OF SUNDRY WELL OPERATIONS I Operations performed: Operation shutdown [] Stimulate ~ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2 Name of Operator AI:~C.I') /11~1~_ Thc 3 Address P,0. BOX 100360, Anchorage, Alaska 99510-0360 4 Locahon of well at surface 779' FSL, 310' FWL, Sec. 5 T11N RIOE UM At top of proc~uchve ~nterval ' ' ' 1351' FSL, 1254' FWL, Sec. 8, T11N, RIOE, UN At effective depth 770' FSL, 1340' FWL, Sec. 8, T11N, RIOE, UM At total depth 614' FSL, 1345' FWL, Sec. 8, T11N, RIOE, UM 11. Present well condition summary Total depth' measured 9].59' MD feet Plugs (measured) true verhcal 6852' TVD feet 5. Datum elevation (DF or KB) R~B q3' Feet 6 Unit or Property name Kuparuk River Unit 7 Well number 1A-6 8 Approval number 7_~RQ 9 APl number 50-- i3?q- ?r~R.~RI3r) 10 P°°lKuparuk River 0il Pool 111' Effective depth measured 8236' MD feet Junk (measured) true vertical 6184' TVD feet Vann Gun 361' MD Casing Length S~ze Cemented Measured depth Structural Conductor 80' 16" Surf-80' 80' MD Surface 279].' 10.75" Surf-2791' 2791' MD Intermediate Production 9030' 7" Surf-9030' 9030' MD Liner Perforation depth, measured True Verhcal depth 80' TVD 2512' TVD 6760' TVD 8108'-8196' 8359'-8372' 8383'-8424' MD true vertical 6093'-6157' 6276'-6286' 6294' -6325' TVD Tubing (size, grade and measured depth) 3½" J-55 BTC 9 2# @ 8301' MD Packers and SSSV (type and measured depth) Baker DB ~ 8272': Baker FHL 0 R02c~'; £amcn TRllP 1A-SSA RRRV 0 1_785' 12 Stimulation or cement squeeze summary See Attachment Intervals treated (measured) 11r08.'-8196' IVJD. ea~ment description including volumes used and hnal pressure See Attachment 13 Prior to well operation Subsequent to operahon Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1353 465 1589 1270 1368 797 22].8 1270 Tubing Pressure 275 300 14 Attachments Da~ly Report of Well Operations Cop~es of Logs and Surveys Run [] 15 I hereby cerhfy that the foregoing is true and correct to the best of my knowledge Sign ed.~,~/~'~/l~.t,/.,~.~~_~~,t le Form 10-404 Rev. 12~5-- /'Submit in - Dupl~cate~./' ARCO Alaska, Inc.( Subsl~ar~ of Atlantic R~cnheicl COral>any WELL SERVICE REPORT WELL 'NTRACTOR REMARKS IOPERA~ON AT REPORT TIME ~. ~,T.. ~o ~'T'. P, ~ e. o.~ .~,'c". Iq, 70 ~. Il I 0o0- /Boo,~. I'-I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK W#ther ITemP'Report 'F Chill Fact°r I VisibilityI'F miles Wind Vel. ARCO Alaska, In~ Post Office Bo~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 2, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton- Attached in triplicate is an intent notice on Kuparuk Well 1A-6 listed below: Well Action Anticipated Start Date 1A-6 Stimulate September 8, 1987 as If you have any questions, please call me at 265-6840. Sincerely, Senior Operations Engineer GBS: pg: 0109 Attachments cc: File KOE1.4-9 RECEIVED SEP 0 Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc ~s a Subsidiary of AtlanhcR~chfleldCompany A( STATE OF ALASKA ~ AL ,.A OIL AND GAS CONSERVATION CO ,,,~SSION APPLICATION FOR SUNDRY APPROVALS I Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] T~me extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order [] Perforate [] Other E] 2 Name of Operator ARCO Alaska, Inc 3 Address PO Box 100360. Anchoraae. Al( 99510 4 Locahon of well at surface 779' J~SL,. 3.10' FWL. Sec. 5, T11N, R10E, UM Attop ofproaucz~ve interv~il 1351' FSL, 1254' FWL, Sec. 8, T11N, RIOE, UM At effechve depth 770' FSL, 1340' FWL, Sec. 8, T11N, RIOE, UM At total depth 614' FSL, 1345' FWL: Sec. 8. TllN. RIOE. UM 11 Present well cond~hon summary Total depth- measured 9159' MD feet true vertical6852, TVD feet 5. Datum elevation (DF or KB) RKB 93 6. Unit or Property name Kuparuk River Unit 7. Well number 1A-6 8 Permit number Permit #81-116 9. APl number 50-- 029-2063800 10 Pool Kunaruk RivPr Ril Pnnl , Plugs (measured)]. 11 ' feet Effective depth measured 8236' MD feet true verhcal feet 6184' TVD Casing Structural Conductor Surface X X X ~rxt~'3~te Produchon xxxx~e,~xxxx Perforahon depth' Junk (measured)vann Gun 361' MD Length S~ze Cemented Measured depth 80' 16" Surf-80' 80' MD 2791' 10.75" Surf-2791' 2791' MD 9030' 7" measured 8108' -8196' Surf-9030' 9030' MD , 8359' -8372' 8383' -8424' MD True Vertical depth 80' TVD 2512' TVD 6760' TVD true vertical6093'-6157' 6276'-6286' 6294'-6325' TVD Tubing (s~ze, grade and measured depth) 3½" J-55 BTC 9 3# @ 8301' MD , , ~ · ~ Packersand SSSV (type and measured depth) Baker DB @ 8272'; Baker FHL @ 8029'; Camco TRDP 1A-SSA SSSV @ 1785' 12~tt,acbmen.t,s .D.¢sq.ri.p~i..on sq,m. mary of proposal [] Detailed operahons program [] ~clalze ~ Sand wl~n ~uu gallons of 12% HCl RECEIIfEI S£P 0 8 Jga? Alaska 011 & gas Oons. Cam BOP sketch [] 13. Est~r~l~ceedmdD~tt~ f~r, C~T~encing operation 14. If proposal was verbally approved Name of approver Subsequent Work Reported on Form No./~' qOt'/Dated ff---~~ Date approved 15 I hereby certify that the f~egoing is true and_correct to the best of my knowledge .., J} ~/ ~ Sr. Operations Engineer Signed ..~(~..~ ,¢f~'J ~7.z~' Title i~' ' - ' Commission Use Only Conditions of approval Approved by Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI 9/2/87 Date No. 7 ~.....~..-,~~ Commissioner by order of the commission Date ~'_ ?.- ~;i~I Submit in icate Form 10-403 Rev 12-1-85 AC STATE Of ALASKA (~' ~ ALASK ~L AND GAS CONSERVATION C ,vlMISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOCI 1 Status of Well Classification of Serwce Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 81-116 3 Address 8 APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20638 4 Location of well at surface 9 Umt or Lease Name 779' FSL, 310' FWL, Sec. 8, Tl lN, RIOE, UM Kuparuk River Unit At Top Producing Interval 10 Well Number 1349' FSL, 1254' FWL, Sec.17, T11N, R10E, UN 1A-6 At Total Depth 11 F~eld and Pool 614' FSL, 1345' FWL, Sec.17, TllN, R10E, UN Kuparuk River Field 5 Elevation m feet (md~cate KB, DF, etc ) I 6 Lease Designation and Serial No Kuparuk River 0i 1 Pool RKB 100'I ADL 25647 ALK 465 12 Date Spudded 13 DateTD Reached 14 DateComp,Susp orAband 115 Water Depth. ,f offshore 116 No of Completions 09/05/81 09/20/81 09/26/81'I N/A feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 DlrectlonalSurvey I 20 Depth where SSSV set ] 21 Thlckness of Permafrost 9159'MD 6852'TVD 8940'HD 6698'TVD YES IX NO []I 1785 feet MDI 1700' (Approx) 22 Type Electrm or Other Logs Run D IL/GR/SP/BHCS, FDC/CNL/CBL/Ca], CBL/VDL/GR/CCL, Gyro 23 CASING. LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT PER FT GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 65.0# H-40 Surf 80' 24" 200 sx PF cmt 10-3/4" 45.5# K-55 Surf 2791' 13-3/4" 1100 sx Fondu & 250 sx AS II 7" 26.0# K-55 Surf 9029' 8-3/4" 850 sx Class G & 250 si( AS II 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, s~ze and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8108'-8129'MD 6093'-6108'TVD 3-1/2" 8066' 8029' 8153'-8186'MD 6126 ' -6150 'TVD 8359'-8372'MD 6276'-6285'TVD 26 ACID, FRACTURE, CEMENT SOUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8383 ' -8424 'MD 6293 ' -6323 'TVD Perfs f/8108'-81~(' 100 sx Class C, w/12 spf, 120° phasing 27 N/A PRODUCTION TEST Date F~rst Production I Method of Operation (Flowing. gas I~ft, etc ) I Date of Test Hours Tested ~PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ 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 I~thology, porosity, fractures, apparent d~ps and presence of od, gas or water Submit core ch,ps NoneRECEIVED MAR 2 4 L987 *NOTE: Workover performed & well perforated 02/24/87. Alaska Oil & Gas Cons, Cornmissiop Anchorage Form 10-407 Rev 7-1-80 WC2:30:DANI CONTINUED ON REVERSE SIDE Submit ~n duphcatel~. -. .. 29 30 GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUEVERT DEPTH GOR, and t~me of each phase Top Kuparuk 8082' 6073' N/A Top Upper Sand 8114' 6098' Base Upper Sand 8149' 6124' Top Lower Sand 8348' 6269' Base Lower Sand 8423' 6323' Base Kuparuk 8492' 6373' 31 LIST OF ATTACHMENTS None 32 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S,gned (]~/?/X ./ . X.~,~/~'~ _/ T,tleAs$Oci ate Engi Ileer Date ~ ' ~;~-d'~' 7 INSTRUCTIONS General' Th~s form is demgned for submitting a complete and correct well completion report and log on all types of lands and leases ~n Alaska. Item 1. Classification of Serwce Wells: Gas ~nject~on, water injection, steam ~nject~on, a~r injection, salt water d~sposal, water supply for ~nject~on, observation, ~nject~on for in-situ combustion Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given ~n other spaces on th~s form and in any attachments. Item 16 and 24. If th~s well ~s completed for separate production from more than one ~nterval (multiple completion), so state in ~tem 16, and in item 24 show the producing intervals for only the interval reported in ~tem 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- ing and the location of the cementing tool f' STATE OF ALASKA I~ ALA , OIL AND GAS CONSERVATION CO .SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Shmulate [] Plugging [] Perforate ~ Pull tub~ng~ Alter Casing [] Other I~ WORKOVER 2. Name of Operator 5. Datum elevahon (DF or KB) ARCO Alaska, Inc. RKB 100' Feet 3. Address 6 Unit or Property name P.0. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4 Locahon of well at surface 779' FSL, 310' FWL, Sec. 8, T11N, R10E, UM At top of productive ~nterval 1349' FSL, 1254' FWL, Sec.17, TllN, RIOE, UM At effechve depth 770' FSL, 1340' FWL, 5ec.17, T11N, R10E, UN At total depth 614' FSL, 1345' FWL, Sec.17, TllN, RIOE, UN 7. Well number 1A-6 8. Approval number 539 9. APl number 50-- 029-20638 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effechve depth: measured true vertical Casing Length Conductor 80 ' Surface 2791 ' Production 9029' 9159 'MD 6852'TVD 8940'TVD 6698'TVD Size 16" 10-3/4" 7I, feet feet feet feet Plugs (measured) None Junk (measured) Vann Gun ~ 8579' Cemented Measured depth 200 sx PF 80 'MD 1100 sx Fondu & 2791 'MD 250 sx AS II 850 sx Class G & 9029'MD 250 sx AS II True Vertical depth 80 'TVD 2513 ' TVD 6760 ' TVD Perforation depth: measured 8108 ' -8129 ' , 8153 ' -8186 ', 8359 ' -8372, 8383 ' -8424 ' true verhcal 6093'-6108, 6126'-6150', 6276'-6285' Tubing (size, grade and measured depth) 3-1/2", K-55 tbgw/tail ~ 8066' Packers and SSSV (type and measured depth) FHL pkr @ 8029', DB pkr (~ 8272' & TRDP-1A-SSA SSSV ~ 1785' , 6293'-6323' RECEIVED MAR 2 4 ]987 12. Stimulation or cement squeeze summary Intervals treated (measured) Squeezed perfs f/8108'-8196' Treatment description including volumes used and final pressure 100 sx Class G Alaska 0il & Gas Cons. Commission Anchorage 13. Representative Daily Average Produchon or Infection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (WorKover wel I H1 st. ory) Daily Report of Well Operations I~ Cop~es of Logs and Surveys,,.x LRun [] 15. I hereby certify that the foregoing ,s true and correct to the best of my knowledge ~>~ /~_ ~.~ ~.1~ Signed (~) (~/~</~~,~ Title Associate Engineer Date S"/~Z)"'~'7 Form 10-404 Rev. 12-1-85 (~ (DANI) SW02/2 Submit in Duplicate ARCO Oil and Gas Company Well History - Initial Report- Daily Instructlona: Prepare and submit the "Initial Rel3oll" on the first Wednesday after a well is spudded or workover operations are started Daily work prior to spudding should be summarized on the form giving reclusive dates only DlStrlct Alaska Field Kuparuk River Auth or W O no AFE 603040 Nordic 1 ICounty paros, or borough North Slope Borough ILeaseorUn,t ADL 25647 IT,tie Recompletion/Workover IState AP1 50-029-20638 Operator ARCO Alaska, Inc. Spudded or W O begun Date [Hour 2/12/87 Workover Date and depth as of 800 am 2/13/87 2/14/87 thru 2/17/87 2/18/87 2/19/87 2/20/87 Complete record for each day reported 1700 hrs. IARCO W I Prior status ~f a W O 7" @ 9030' 8579' Van gun fsh, Displ ann w/brine 8.6 ppg NaC1 Accept rig @ 1700 hrs, 2/12/87. Pmp 40 bbls BridgeSal pill & displ ann w/8.6 ppg brine. Alaska 7" @ 9030' 8579' Van gun fsh, Circulate bottoms up 9.4 NACL Cont displace w/8.6 brine, monitor, well flowing. Wt up & pump 9.0 ppg. Bullhead 31 bbls LiteSal pill into formation. Circ 9.0 ppg brine around. Monitor well; no flow. Set BPV. N/U & tst BOPE. Pull tbg hanger. Monitor well, circ hole vol. POOH & chg collars to AB Mod. Cont POOH, well flowing up tbg. Pump 7 bbls brine dn tbg & cont POOH. Well flowing, SI & monitor well. Pump 52 bbls LiteSal pill, bullhead into formation. Circulate w/9.2 ppg brine & increase brine wt to 9.4 and circ. POOH. Pull 258 its tbg.~ RIH w/3-1/2 DP, wsh over and shear FHL pkr. CBU. (Total fluid loss = 1318 bbls). 7" @ 9030' 8579' Vann gun fsh, POOH w/WL 9.4 ppg NaC1 Att to CBU; hole taking fluid, POOH. Pmp 60 bbls LiteSal pill, POH w/FHL pkr. RU WL, RIH w/6" GR/JB; unable to get below 8176'. RIH w/5.90" GR/JB to 8330'. RIH w/EZSV, set @ 8210' WLM. POOH w/WL. 7" @ 9030' 8210' EZSV 9.4 ppg NaC1 POOH & RD wireline, RIH w/DP. Tag BP @ 8212'. Squeeze 100 sx Class G cmt. Hold pressure, monitor well. POOH w/DP. RIH Set~ BP, @ 6555'. Set RTTS & storm valve @ 40'. ND BOPE. NU 5000# K tree. 7" @ 9030' 8210' EZSV 9.4 ppg NaC1 Test tbg, spool, NU BOPE & test same, Pull TP & set wear ring, RIH & ret. RTTS & storm valve, LD same, RIH & ret. BP, POOH w/DP & BP. MU BHA, RIH to 7835' (tag cmt). Clean out cmt to 7865'. Replace leaking swivel packing, drill out firm cmt. IWell no lA-6 56.24% ECEIVED MAR 2 4 1987 Naska Oil & Gas Cons. Commission Anchorage The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilhng, Pages 86 and 87 Drilling Supervisor ARCO Oil and Gas Company , ii Well History- Final Report Instruct,one Prepare and submit the "Final Report" on the hrst Wednesday after allowable has been assigned or well ~s Plugged, Abandoned, or Sold "Final Report" should be submitted also when operahons are suspended for an ~ndeflmte or appreciable length of time On workovers when an offimal test ~s not required upon completion, report completion and representahve test data m blocks provided The "Final Report" form may be used for reporhng the entire operation if space ~s evadable I 'Accountlng cost center code District County or Parish ~ State Alaska North Slope BoroughI Alaska Field Kuparuk River Auth or W O no AFE 60340 Lease or Unit T~tle J Well no ADL 25647 lA-6 Recomple t ion/Workover Nordic 1 AP1 50-029-20638 Operator ARCO Alaska, Inc. Spudded or W O begun Workover ARCo WI 56.24% Date 2/12/87 Date and depth as of 8 O0 a m 2/21/87 thru 2/23/87 2/24/87 Complete record for each day reported Old TD Released ng 0200 hrs. Clasmhcat~ons (mi, gas, etc ) Oil Produmng method Potenhal test data Flowing Iotal number of wells (active or ~nact~ve) on th~s ost center prior to plugging and J bandonment of th~s well I our J Prior status ~f a W O I 1700 hrs. 7" @ 9030' 9.6 NaC1 Drl out cmt to BP @ 8214'. Test squeeze to 1000 PSI. Drl out BP f/8214' - 8217'. Clean out fill to 8569'. RIH w/R3, test pkr. Set pkr @ 8040'. Test 7" csg to 3000#. POOH & LD PKR. RIH w/csg scraper. POOH LDDP. Slight flow, RIH to 8440. Wt up to 9.6, monitor well. POOH LDDP. RU Dresser. Test Lub, perf 8108' - 8128', 8128' - 8129', 8153' - 8173', 8173' - 8186' w/12 SPF. RIH w/6.125 GR&JB to 7855', (could not get down). RIH w/6.0 GR&JB to 8320'. RIH w/Baker DB pkr and set @ 8272' WLM. 7" @ 9030' RR @ 0200 2/24/87 Set DB pkr @ 8272' WLM, RD wireline, service Rig, NU riser. RIH w/completion assy stab into DB pkr, space out, land tbg, set FHL pkr @ 8029', DB pkr @ 8272', SSSV @ 1785', & TT 8301'. Test tbg, shear SBR, reland tbg, test top of pkr, test SSSV, shear out ball w/3700 psi, close SSSV, pull landing it. Set BPV ND stack, NU tree & test, displace well w/diesel, SITP lO0_psi__ Set BPV. Release Ri~ @ 0200 2/24/87. REC EIVED JNew TD Date 2/24/87 PB Depth K~nd of ng Type completion (s~ngle, dual, etc ) Single MAR 2 4 1987 Alaska 0il & Gas Cons. Commission Armhnr,~n Rotar~ Ofhclal resewmr name(s) Kuparuk Sands Well no Date Reservoir Producing Interval Od or gas Test time Production Od on test Gas per day Pump raze, SPM X length Choke raze T P C P Water % GOR Gravity Allowable Effective date corrected The above is correct _ , , Drilling Supervisor For form preparation and d~strlbuhon, see Procedures Manual, Section 10, Dnlhng, Pages 86 and 87 /~ STATE OF ALASKA ALASK .~IL AND GAS CONSERVATION COMMI ,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operahon Shutdown [] Re-enter suspended well C Alter casIng ~ T~me extension [] Change approved program ~ Plugging [] Stimulate [] Pull tubing [~ Amend order ~ Perforate m. Other 2. Name of Operator ARCO Alaska, Inco 3. Address Po 0 Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 779' FSL, 310' FWL, Sec.8, T11N, R10E, UN At top of productive ~nterval 1349' FSL, 1254' FWL, Sec.17, T11N, R10E, UM At effective depth 770' FSL, 1340' FWL, Sec.17, T11N, R10E, UN At total depth 614' FSL, 1345' FWL, Sec.17, T11N, RIOE, UM 5. Datum elevabon (DF or KB) IO0'RKB 6 Umt or Property name Kuparuk River Unit 7. Well number 1A-G 8 Permit number 81 -116 9. APl number 50-- 029-20638 10 Pool Kuparuk River Oil Pool feet 11 Present well condlbon summary Total depth, measured true vertical Effechve depth. 91 59 ' M D feet 6852 ' TVD feet Casing Conductor Surface measured feet true vertical 8940 'ND feet 6698 ' TVD Length S~ze 80 ' I 6" 2791 ' 10-3/4" Production 9029' 7" Plugs (measured) No ne Junk (measured) Vann Gun ~ 8579' Cemented Measured depth ~ue Verticaldepth 200 sx Permafrost 80'ND 80'TVD 1100 sx Fondu & 2791'HD 2513'TVD 250 sx AS II 850 sx Class G 9029'MD 6760'TVD Perforation depth measured true vertical 81 08 ' -81 96 ', 8359 ' -8372 ' , 8383 ' -8424 ' 6093'-6157' 6276'-6285' 6293'-6323' RECEIVED Tubing (s,ze, grade and measured depth) oc'r ~ 1 1986 3-1/2" K-55 ~ 8066' Packers and SSSV (type and measured depth) ~ 0il & Gas Cons. Commission FHL pkr ~ 7989' & WRDP ~ 1639' ~l~l~JlOi'a~~ 12 Attachments Description summary of proposal ~k~Deta~led operations program ~ BOP sketch ~ 13. Estimated date for commencing operabon December 1, 1986 14 If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (¢0~ .%L/)./A_ Title Associate Engineer -- Commission Use Only ( JWR ) SA/136 Date Conditions of approval Not~fy commission so representative may witness [] Plug ~ntegrity [] BOP Test [] Location clearance Form 10-403 Rev 12-1-85 KUPARUK WELL 1A-6 CONVERSION TO SELECTIVE SINGLE PRELIMINARY PROCEDURE 1. Move in and rig up workover rig. Kill well. 2. Nipple down tree. Nipple up and test BOPE. 3. Shear out of SBR. POOH and stand tubing in derrick. 4. Pick up 3-1/2" drill pipe and retrieve packer. POOH. 5. Run CET. Perform cement squeeze between "A" and "C" sands if required. 6. Run in hole and set retrievable bridge plug. Remove 3M tubing head and install 5M head. Test casing to 3500 psi. Retrieve RBP. 7. RIH with casing scrapers and 6-1/8" bit to PBTD. Circulate and condition brine. POOH. 8. Re-perforate "C" sand if well is squeezed. Run GR/JB to PBTD. RIH and set permanent packer between "A" and "C" sands. 9. Run 3-1/2" single selective completion assembly. 10. ND BOPE. NU tree and test. 11. Displace well to diesel by reverse circulation. 12. Test annulus and tubing. 13. Secure well and release rig. 14. The well will be acidized and/or fracture stimulated after rig release. (Workover Fluid: NaCl/NaBr) BHP = 3200 psi @ 6123'TVD(8150'MD) SA/136a: dmr 10-30-86 p, EF, EI /EI) kt~ Oii& Gas Cons. commission ~ct~omge ( ANNULAR PREVENTER § BLIND RAIIS PIPE RAI*IS 4 TUBIN6 HEAD 2 16" CONDUCTOP SWAGED TO 10-3/4" 11"-3000 PS! STARTING HEAD 11 "-.'5.000 PSI X 7-1 / 16"-5000 PSi TUBING HEAD 7-1/16" - 5000 PSi PiPE RAMS 7-1/16" - 5000 PSi BLIND RAMS ?- 1 / 16" - 5000 PSi ANNULAR ACCUHULATOR CAPACITY TES 1. CHECK ANO FILL ACCUtlULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAH OF THE REGULATOR. :5. OBSERVE TII'qE. THEN CLOSE ALL UNITS SIMULTANEOUSLY ANO RECORD THE TII'IE ANO PRESSURE REI'IAINING AFTER ALL UNITS ARE CLOSEO WITH CHARGING PUI'lP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIHIT IS 45 SECONDS CLOSIN6 Title ANO 1200 PSI REHAINtN6 PRESSURE. RECEIVED BOP STACK TEST OCT 1 1986 1, FILL BOP STACK AND VIANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN 'SCREt,~ ARE FLILla,~a~l~raJcons. C, ummlssion PREDETERMINE DEPTH THAT TEST PLUG WILL SE"A'T~,ND SJe, tlhorage IN ~/~LLHEAD. RUN IN LOCK--DOWN SCREWS IN HEAD. :5. CLOSE ANNULAR PREVENTER AND CHOKES ANO BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COI'lPONENTS TO 250 PSi AND HOLD FOR 10 I'IlNUTES. 5. INCREASE PRESSURE TO 1800 PSI ANO HOLO FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7. INCREASE PRESSURE TO :5000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAFI OF CHOKES. BLEED DCR/VNSTREAM PRESSURE TO ZERO PSi TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAI"I OF VALVE AND WITH ZERO PSi DOWNSTREAM, BLEED SYSTEM TO ZERO PSI. 9. OPEN PiPE RAHS. 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 :5000 PSI. 12 TEST KELLY COCKS AND INSIDE BOP TO ~000 PSI WITH KOOHEY PUFlP, 1:5. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COHPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY dO dUNE 16, 1986 (NORDIC RIG 10-:~/4") ARCO Alaska, Inc. _ ,. - Post Office ~' 0360 Anchorage, Asas~ 90510-0360 Telephone 907 276 1215 September 2, 1986 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive 4. Anchorage, Alaska 99501 Subject- Kuparuk River Field _ Production Surveys Dear Mr. Chatterton: In compliance with Rule 9 of Conservation Order Number 173, Kuparuk River Field Rules, we are hereby submitting production survey informa- tion for the second quarter of 1986. Production survey information consists of production logs and production tests as identified in Attachment 1. Production logs {spinners} identified in this attachment will be sent under separate cover. Note that several initial spinners not previously submitted to the State are being submitted at this time. If you have any questions concerning the information reported, please contact me at {907) 263-4935. Sincerely, Senior Operations Engineer ~y ~~ d VLF:pg'O074 ~ -/-'.' ""'SEP 0 8'198 - "-"' - ARCO Alaska, Inc Post Off,ce box 100360 Ancf~orago. AJaska 99510-0360 Te'eDhone o~--, ~u, 276 1215 DATE' 05-2 9-'3 5 TI~ANS. II.~.~ NO:5203 }{ET URN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-11!LB P.O. BOX 100360 ANCHORAGE, AI( 99510 T · lC.,V RAN.~,~ITTED I!EREW1T}[ ARE 'fiie FOLLOWING ITEHS. PLEASE A,.~,~,OWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF TIIiS TF~%NSMITTAL. SEQUENCE OF EVENTS PRESSURh' DATA -2A-3 PBU- '~' SAND 03-16-85 2A-5 SBHP 11-21-84 -2B-1 PBU 04-01-85 2B-2 PBU 04-02-85 2B-15 PBU- POST FRAC 04-09-85 - 2B-16 PBU 04-1 0-85 2F-7 PBU- STATE 04-14-85 - -. -_ 2F-8 PBU- 'A' SAND 04-20 85 2 F__-_9;~./PB U- STATE 04 -13- 85 /2G-_7--~-'~ PBU 04-11-8 5 2G-!2 PBU- 'A' SAND POST F~'~C 03-23-85 2H-!5 ISBHP 04-10-85 _%,-13 PBU- 'C' SAND 04-21-85 2X-13 PBU 03-3 0-8 5 BAKER/ LYNES PRESSURE REPORTS (ONE COPY OF EACH) SET DEPTH lA-1 PBU 04-23-85 7187 ' lA-2 PBU 04-23-85 7476 ' lA-2 PBU 04-23-85 7476 ' lA-5 BUILD-UP 04-23-~5 6957' 1A~6 PBU 04-23-85 8300 ' 1 ~'~-~6' BUiLD-UP 04-23-05 8300' lA-10 BUILD-UP 04-23-85 8415' lA-10 BUILD-UP 04-23-83 8415' TOOL NO. 1722 1302 1512 1734 1719 2062 1508 1299 RECEIPT ACKNOWLEDGED: DT'~T~;a o~, ~, t~.~= Cor, s Commission Anc,orage S.A_E OF ALASKA'~ ARCO Alaska, Inc. Post Ofhce Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 I;K, TF Ob-i 5 ""- I't<Ai~SMJTTAL N0 5t,S4 i<E'FURN lO: 'Tl<AiqS'Mll i[ I) IIFRF'N] 111 AI<L. IIIE I()I.LC]WINu F:ECL-Ir'F ANI) i,;LILJI~N DNF. III.iH/;. ."~1'1 FhX'[" hCI<NLJWLEI,~(;L [;~)I"Y L)F TI IlS [I<ANSH.I'FIhL. I. YNE$ F'I(U -i 04-23--8', A-P 04- iA-2 04-25-85 A-5 04-'2S- A-6 o4-2~-I~5 A-6 04--2~- ~)5 A- i 0 04--2S-~5 i ,h'-I ~ 04-2T~-~5 lC--6 tC-6 04--2J-~)5 --5 0,1- PL~- ~'3 - 5 0,1-23-05 I'--7 04- 2T5- 8_5 G-4 04--mm. ,~ - o("- g-,1 0,1-23- I' [JOI. COI'Y L)F' [,ACII,,) S~ F DFI'FII 7 i 87 ',:'1 ? 6 7476 03 C) 0 0500 ~.; 4 i r> F_) 4 t L; 5' 2 ,?.1 L) 61'~'~ ,"'0 ?b 70 '~'- '," '~ i P '? 512 670t 670 i c: :r ,-. ':- ............................. I) 1 S' 11711~ kIT ] [.) N.~' B. CLll;:Rlr'R~ L, JOllNST(JN £XXON $0~1[0~ aa..., Cons. L,o, Jm:ss,,or, CIII-:VRON* i'iClBJ L-x Pill I. Lli'S Oll..x LIN] ON>' I) & M~( NSI< CI_[.i.:I( d, RAFIIFilTLL.* I(,'FLJL-N/VAULT ARCO Alaska, Inc. ~. Post Ofhce Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 I<b IUl~:N TLJ: At<CO AL_A.?i<A, INC ATTN. R[COi~I)5; CL. EI'<I< A'I' 0-1 t 1 '.~B I'.0. I~OX t00360 ANCI.IOI,:At;E, ~1( 995 li<AN.S'MII1ED ilER["W]lll ~;i(E 111[. r01 LOW]Nb [,:ECEIF"F Al,ID RE'tURN ONE SIGNED COPY (Jr- ( D,"~T E · 0.5-t b-OD 'I'RAN2F..[TTAL NO ] ] l..i'i3' .~ACI( NOWLLDGE I-I I 1 ..9 I'I~AN~MIT I AL. W..¥1</SL'qtJENCIZ JIF lEVI"illS (ONE COPY OF EACil) 04-2t -'0'~ CAMCO 04- '"' ''~ "~ ": ..,.-,,.J CAMCO 04-21 - {15 [;AHCO 04-25-0'5 CAHCO 04- t 9- ~.~> CAHCO 04-t 9- I]'..~ CAFiCO 04-21 -85 CAHCO (~4-22-85 CAMCO 04-2t-.U5 O1 15 (,,4-2t -8"> OT 1.S' 0,1-22-05 OT.[ S 0 ,,I - 2 t -- O b C A M C [) 04-22/23-85 CAHCO 04-2t-05 CAHCO 04-22-115 CAMCO 04-.2¢,-85 CAMCO 04 -25-85 CAMCO 04-2i-.O5 OTIS' 04-23-85 0TI3 '" ',..> CAHCO 04-2o-~~'- 04 - 26 - 0 :> C A ri C 0 04-t 9-U5 04-20-8'.> ARCO 04-22-05 Al<CO 04--2'7-05 OTZS 04-2i-85 OTIS 0,1 - '23 - 05 0 T 15' 0,1-2t -85 Ol IS 04-'2'2-05 Orl3 t A-t r'I;LI t ,h- 1 F'BU i(l-° I<UN LYN['S f<FCJIi'.,I)L.i,~.., t A.-2 IZND I"~U/RUN WI<DF' t A-3 SI:! IF' t A-5 ['BU IA-5 ['UI_I_ F'BU t ~-6 J A-6 i lANG OFF LYNI.X i"i<i_XXUI<E I;IJiiB~' FOR PBU t ~.-6 I'.! N.I..S'H I-'BLJ i¢,-t0 RUN LtNKS RL.COICD[R.? t¢,-t0 F'LILL LYNES I(ECORDEitS 1 B-3 t B-3 F'Btl t C-4 SBi I1" t C-4 XBI IF' lC-6 I4UN LYNEX RE[;Oi~I>EI4S tC-6 RETR1EVlE LYNEX RL[COI4I>ER7 1 ~---4 RUN S['].NNER/T[ H['Ei<~TtlI<E SURVEY---LI~?~K I)U FECTION tE-5 RUN F'BU 3'UI~Vi:Y tE.-~6 1NJFCI [VITY TE;¢T tE-t6 ]NJECT1VITY TEST tE-27 IN,Jb-CTION 'fEST/'A ~ E-27 ~FHF'ERATURE/3'F'] NNER-- L~hI{ DETFCTi(IN tF'-3 RUN LTNES TthNI>EM I-'I<E3'3'UI<E BOHDX F'OR F'Btl ti:'-3 REiI4IFVE LYNFS I<LCd[<I)ER3' ~F-S I<UN LYNES I(ECOI<DEI<X ..... 'C' 3'ANI> ONLY t i'-[> RILTI<I I{VIZ I_YNI::.~ I<ECOi'<I)LI<S I ILl< xI'Ii].L.L ] I IS · x,l. RF,I'I litI-L.L ARCO Alaska, Inc. Post Oftice P '0 Anchorage, · ~..a 99S10 Telephone 907 :.77 5637 RETURN TO: ARCO ALASKA, INC. ATTN: Records Cler~ 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. - CAMCO BHP REPORT~/~MU , TORQUE TURN PBU & TEMP SURVEYS 12/02, 03~84 12/10,11/84 11/26/84 / 12/08/84 12/12,13/84 10/21,22/84 10/12,14/84 o 10/10,12/84 10115184 10/19/84 10/19/84 10115184 /cat Receipt Acknowledged: B. Currier BPAE Chevron D&M Drilling Geology' Mobil NSK Ops. /~-4 12/12, 13/84 Gauge (/64009 DISTRIBUTION RECEIVED Cc ..... W. Pasher G. Phillips Phillips Oil J. Rathmell State of AK Sohio Union Well Files ARCO Alaska, Inc. Post Office, 360 Anchorage .... ska 99510 Telephone 907 277 5637 Date: 1/07/85 Transmittal No: 4942 RETURN TO: ARCO ALASKA, INC. ATTN: Records Cler~ ATO-1115B Box 100360 orage, AK 99510 ed herewith are the following items. Please acknowledge receipt n one signed copy of this transmittal. CAMCO BHP REPORT~/.~BU 1F-7~-~ 12/02, 03/84 10-4 ~ 12/10,11/84 lB-3 11/26/84 10-2~ 12/08/84 1E-8 12/12,13/84 lA-6 ~' 10/21,22/84 1C-9-' '10/12,14/84 -. 1B-ii 10/10,12/84 1E-3 10/15/84 2B-4 10/19/84 2B-3 10/19/84 1E-2 ' 10/15/84 _TORQUE TURN PBU & TEMP SURVEYS t 1F-4 12/12, 13/84 Gauge ~'164009 /cat Receipt Acknowledged: B. Currier BPAE DISTRIBUTION Date: D..rilling W. Pasher State of AK Geology' G. Phillips Sohio ~ t Return To: ARCO Alaska, Inc. , ;' c",~..o;,- 277 5[37 ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 10/08/84 Transmittal No: 4759 PAGE 1 of 2 ,/aT%ansmitted herewith are the following items. d return one signed copy of this transmittal. Please acknowledge receipt ~PJtU SURVEYS/PRESSURE ANALYSIS ~-Z!A-2 5/11,12/84 Torque Turn [Pressure & Temp Surveys) ..... -~r~_--6... 7/06/84 Camco /1B-Il ~ 7/10,12/84 ~-/lA-10 5/10/84 /lC-1 12/17/83 /1C-6 8/04/84 /!G-lO- 12/2!/83 /~_t,1 12/23/83 8/11/84 5/21/84 5/13,14/84 /1G_~3 6/26/84 ~,?~2, 6/30/84 ¢G~5~ 5/26/83 .4'~--z~'' 8/11/84 .-'<liG~-i~. 6/28/84 5/ 8/83 /¢~J 7/07~84 /13-4 12/27/83 .1Y-5 12/14/83 .-1Y-7 12/15/83 /WSW¢;1 7/03/84 /kMW¢;1 4/10/84 CMn']co Otis Otis Otis Camco Cam~o Otis Camco Static Torque Turn (Pressure & Temp Surveys) Cam~o Static Static C~nco Camco Camco Camco Otis Otis Otis Otis Otis Camco ReceipT~ac~nowledged: B. Adams · F.G. Baker P. B~ter Chevron Date: DISTRIBUTION D & M Drilling Geology Mobil NSK Operations W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell R&D C. R. Smith Sohio Enion Well Files Return To: , ;. e~.c 77 5~37 Date: 10/08/84 Transmittal No: 4759 PAGE 2 of 2 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. ~L~9' 5/28184 2c-1 11/09/83 2C-2 11/09/83 2C-6 11/08/83 2C-7 11/08/83 '~--~ 4/18/83 "' ~ 4/24/83 C ' ~Cr4> 4/22/83 4/30/83 4/28/84 "~? 4/29/84 f2V-35 5/04/84 '~V~ 5/06/84 2X-5 8/12/84 Otis Lynes Lynes Lynes Lynes Camco Camco Camco Otis C_mrnco Camco Dresser PBU Flow Survey (Gradient) Otis Static Gradient Otis Cam~o 3C-6 f/19/84 3C-6 5/17/84 Dr~s s er Dresser Mini Drawdown & Buildup Survey /cat Receipt Acknowledged: B. Adams · F.G. Baker P. Baxter BP;£ Chevron Date: DISTRIBUTION D & M Drilling Geology Mobil NSK Operations W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell R&D C. R. Smith Sohio Union Well Yiles KUP~K ENG ! NEER I NG ~i T1'AL #~ TO: William VanA!en FRQVI: D.W. Bose/Shelby J. Matthews Transmitted herewith are the fol Iowincj. PLEASE NOTE: BL - BLUELi NE, S - SEPIA, F - F I LM, ~ PC - PHOTOCOPY AR(33 ALASKA, iN~. ~,~,~ ATTN: SHEU3Y J. iVlATq-tB~- ATO/1115-B P. O. BOX 100360 ~e~ ?~,~. ANCH~E , AK. 99510 KUPARUK ENGINEERING TRANSMITTAL TO' William Van Allen FROM- D.W. Bose/ShelbS J. Matthews Transmitted herewith are the following' PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PHOTOCOP~7~ pRE~I PT ACKNOWLEDGED: LEASE RETURN RECEIPT TO: · ARCO ALASKA, INC. ATTN' SHELBY J. MATTHEWS - AFA/3!I P~Oo BOX 360 DATE' ARCO Alaska, Inc. Post Office B' Anchorage, A,..~.<a 99510 Telephone 907 277 5637 July 21, 1982 C. V. Chatterton State of Alaska Oil and Gas Conservation Con~. 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Chatterton: Enclosed are subsequent reports for Kuparuk Wells LA-5, ~lA-6~, 1D-2, iD-3, 1D-4, and 1D-5 covering acid stimulations. Sincerely, ms/er cc: L. K. Blacker - AFA 330 w/o Attachment L. B. Kelly - AST 306 w/Attachment L. M. Sellers - ANO 332 w/Attachment H. C. Vickers - AFA 326 w/o Attachment J EC, EIVED AC STATE OF ALASKA ~ ALASK IL AND GAS CONSERVATION C MMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL~ OTHER [] 2 Name of Operator ARCO Alaska, Inc. 3 Address P.0.Box 360, Anchorage, AK 99510 4 Location of Well SL: 779' FSL, 310' FWL. Sec 5, T11N, RIOE, UM BHL: 770' FSL, 1340' FWL, Sec 8, T11N, RIOE, UM 7 Permit No 81-116 8 APl Number 50- 029-20638 9 Unit or Lease Name Kuparuk River Unit 10 Well Number 1A-6 5 Elevation ~n feet (~nd~cate KB, DF, etc ) / 6 Lease Designation and Serial No RKB-100' ~DL 25647 12 Check Appropriate Box To Indmate Nature of Not~ce, Report, or Other Data 11 F~eld and Pool Kuparuk River Kuparuk River NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit m Triplicate) (Submit ~n Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation )~ Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion ) Fzeld Oil Pool 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~ncludmg estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) On 3uly 9, 1982, Kuparuk Well 1A-6 was stimulated in the Upper, Mzddle and Lower Sands with 12,% HC1. A coiled tubing unit was used to place and squeeze a total of 150 bbls (6300 gals) of 12°' ,o HC1 with MSR across the perforated zntervals of 8108 8196' 8359 8372' . - , - , and 8383-8424' Nitrogen was circulated alternately with diesel during the cleanup operations to . help lift the spent acid from the well. A total of 1192.5 gal of N2 and 91.5 bbls (3843 gals) of diesel were pumped during the job. A production test of the well following stimulation showed a rate of 3449 STBD as opposed to a rate of 2707 STBD before stimulation. A total of 250 bbls were flowed into separate tankage before the was returned to produciton. This volume included all previously circulated fluids. RECEIVED well 2B4 JUL 3 0 ]982 Alaska Oil & Gas Cons. Commission Anchorage 14 I hereby cert~y that the foregoing ~s true and correct to the best of my knowledge ~ ~ Regional 0peratzons S~gned . ~. _ T~tle Thespace e~wforCommlsslo~se Conditions of Approval, ~f any ~ EngineerDate By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" in Duplicate KUPARUK ENGINEERING TO: Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE RECEIPT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO: RECEIVED J U L 2 6 1982 ~~---~ DATE: Alaska 0i~ & G~ ~,or,~. Commission ARCO ALASKA, INC. Anchorage ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 'ANCHORAGE, AK 99510 ~ STATE OF ALASKA ~ ALASKA 0IL AND GAS CONSERVATION C(~M MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL []X OTHER [] 2 Name of Operator ARCO Alaska, Inc. 3 Address P.0.Box 360, Anchorage, AK 99510 4 Location of Well SL: 779'FSL, 310'FWL, Sec 5, T11N, BHL: 614'FSL, 1345'FWL, Sec 5, T11N, RIOE, UM RIOE, UM 7 Permit No 81-116 8 APl Number 5o- 029-20638 9 Unit or Lease Name Kuparuk River Unit 10. Well Number 1A-6 11 Field and Pool Poo~ Kuparuk River Field 5 Elevation In feet (mdmate KB, DF, etc ) I 6 Lease Designation and Serial No K u p a 100' RKB I ADL 25647 12 Check Appropriate Box To Indmate Nature of Notme, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit in Triplicate) (Submit ~n Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate ~ Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, including estimated date of startlr,~g any' proposed work, for Abandonment see 20 AAC 25 105-170) ARCO Alaska, Inc. proposes to stimulate the Kuparuk Sands with aci/d. Acid wiiI be spotted with a coiied tubing unit with BOP assembIy tested to 4000 psi. Ali circuiated and fiowed fiuids wiii be di~./erted to tankage on iocation. The weii wiii be tested subsequent to t~e stimuIation. Expected start date is May 31, 1982. / . REfCEIVED A-2 0 MAY 2 81982 lliil & Gas Cons. Alaska Commissior~ Anchorage 14 I hereby certlf~hat t~o,ng ls true and correct to the best of mv knowlodge ~ ~ Area Operations Enginee~ 7 S~gned . ~. "~ _ T~tle _ Date The space I~ow for Commission us/~ / Conditions of Approval, if any Approved Copy Returned Approved by. ¢~ "' ' ' COMMISSIONER the Comm~sslor~,_ Date Form 10-403 Submit "Intentions" in Triplicate Rev 7-1-80 and "Subsequent Reports" ~n Duplmate . STATE OF ALASKA C~' ALASKA( .L AND GAS CONSERVATION C ...MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Class~hcat~on of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 81-116 3 Address 8 APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20638 4 Locatlon of well at surface 779' FSL, 310'F~L, .Sec b, IllN, ltl0E, UM 9 Un,t or Lease Name Kuparuk 25647 AtTopProduc,nglnterval 1349'FSL, 1254'FW1_, Sec 8, TllN, RIOE UM lO WelI Number 1A-6 At Total Depth 614'FSL, 1345'F~L, Sec 8, TllN, R10E UM 11 Fleld and Pool Kuparuk River Field 5 Elevat~onlnfeet (~nd~cate KB, DF, etc) I 6 LeaseDes~gnat~onandSenal No 100' RKB I ADL 25647 ALK 465 Kupa~uk River 011 PooI 12 Date Spudded 13 Date T,D Reached 14 Date Comp , Susp or Aband ] 15 Water Depth, ~f offshore { 16 No of Completions ¢/5/81 9/20/81 ¢/2~/81 I -- feetMSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (M~D} 19 D~rect~onal Survey ~ 20 Depth where SSSV set 21 Thickness of Permafrost 9159! 6852' 89401 6698' YE~ NO D I 1639 feetMD 1700' (approx) 22 Type Electric or Other Logs Run D~L / GR/SP/BHCS. FDC/CNL/CBL/CAL, CBL/VDL / GB/CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-40 Surf 80' 24" 200sx Permafrost in ~/~,, ~_~ K-SS Surf 2791' 13/3/4 1100 sx & 250 sx AS II ?,, ~K~ g-55 Surf 9029' 8 3/4" 850sx Class G cmt 24 Perforations ope~ tO ProCuctmon (MD+TVD of Top and Bottom and 25 TUBING RECORD ~nterval, s~ze and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3 1/2" 8067' 7989' 8108'-8196' 835~'-83~Z' W/12 SPF 2~ ACID, FRACTURE, CEMENT SOUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT~ KINDOF MATERIAL USED 8383' -8424' ..... N/A 27 PRODUCTION TEST Date F~rst Production I Method of Operation (Flowing, gas lift, etc ) 12/~/~ 1 I Flowint Date0f~est ' Hours Tested PRODUCTION FOR' OIL-BBL 'GAs-~'CF 'WATER-BBL CHOKESIZE ~GAS-OILRATIO ~/~/~ !2.75 TESTPERIOD ~ 1~73 ,704 -- 176/64I 478 ,., Fl~'~u~ Casing Pressure CALCULATED_ ~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) -Press !50 24-HOUR RA~ ~ ]258 1557 -- 28 COP E DATA Brief description of I~thology, porosity, fractures, apparent dips and presence of o~1, gas or water Submit core ch~ps ~kF~rm 10-407 Submit mn duplicate Rev 7-1-80 CONTINUED ON REVERSE SIDE 29 3O GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT DEPTH GOR, and t.me of each phase Top Kuparuk River Form. 8082' " 6075' N/A Base Kuparuk River Form. 8492' 6375' 31 LIST OF ATTACHMENTS 32 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S,gned l~.//1 (~' (~ ~ T,tleArea 0ps. E rl.q['.. Date I~R 10 1987 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 ~njection, water ~njection, steam ~njection, a~r injection, salt water disposal, water supply for injection, observation, injection for in-sltu combustion. Item 5 Indicate which elevation is used as reference (where not otherwise shown) for depth measurements g~ven in other spaces on th~s form and in any attachments Item 16 and 24. If this well is completed for separate production from more than one ~nterval (multiple completion), so state in item 16, and in item 24 show the producing Intervals for only the ~nterval 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 th~s well should show the details of any multiple stage cement- lng and the location of the cementing tool. HORTIi ~LOPE E;IGIiIEERIi;G J. J. Pa,.:elek/Pnn Simonsen TFans.m~t~ed here:.:i~n are the following' PL~:,S- I:OTE' BL - BLUEL!HE, S - SEPT', F - FILM, T - TAPE P.L-~. . :; !)G . ', --~t,A,_ . ATE' L,/[FL--;.~-' ['//~' SETU,R~i P, ECEZ2T TO'ARCC ALASKA, IHC. ATTiI' Allll S Il':O~iq~'~_~,, - AFA/311 P.O. COX .560 ?Z;C:iO2ACT_, ~K 99510 ARCO Alaska, Inc Posl OIf~c · 360 Anchorage ,I,t',ka 9951P Telephone 9')7 277 563? January 20, 1982 ~. Lonnie Smith State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- Updated Well Completion Reports Dear Sir' Enclosed please find the updated Well Completion Reports for the following wells' DS 11-2 DS 14-16 DS' 12-13 DS DS 13-5 DS A-5 DS 13-7 DS A-6 DS14-15 DS B- 7 Sincerely, G. L. Alvord Associate Engineer Enclosures GUt:ss RECEIVEI) JAN2 1982 " A[,'L STATE OF ALASKA ~( ALASK - AND GAS CONSERVATION C ,,~'MlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Class~hcat~on of Serwce Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 81-116 3 Address 8 APl Number P.O. Box 360, Anchorage. Alaska 99510 50-029-20638 4 Location of well at surface ~ ~ 9 Unit or Lease Name 779' FSL, 310' FWL, Sec. TllN, RIOE, UM I VERIF~D 1 Kuparuk 25647 At Top Producing Interval fZ¢ .Surf. ~ . ' 10 Well Number 1349' FSL, 1254' FWL, Sec.'.l~7', TllN, RIOE, UM B.H. ~ ~_! A-6 At Total Depth 11 F~eld and Pool 614' FSL, 1345' FWL, Sec. Z.1-7', TllN, RIOE, UM Kuparuk River Field 5 Elevat,on ,n feet (md,cate KB, DF, etc ) 6 Lease Des,gnat,on and Ser,al No Kuparuk River 0i 1 7ool 100'RKB ADL 25647 ALK 465 , 12 Date Spudded 13 Date T D Reached 14 Date Comp, Susp or Aband 115 Water Depth, ,f offshore l~6 No of ComCe~,o.s 9/5/81 9/20/81 9/26/81I -- feet MSLI 1 17 T~-~ Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 D~rect~onal Survey I 20 Depth where SSSV set 21 Thickness of Permafrost ~ MD 6852' TVD 8940'MD 6698' TVD YES ~ NO []I 1659 'feet MD 1Z00 ~lDp_l~OX,__~ ... 22 Type Electric or Other Logs Run DIL/GR/SP/BHCS. FDC/CNL/CBL/Cal, CBL/VDL/GB/CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ,, 16" 65# H-40 Surf 80' 24" 200 sx Permafrost 10-3/4" 45.5# K-55 Surf 27,91' 13-3/4" 1100 sx Fond~ & 25( sx AS II 7"" 26# K-55 surf 9029' 8-3/4" 850 sx Class "G" cn~t 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD m,terval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3½" 8067' 7989' 8108' - 8196' 8359' - 8372' 12 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC , 8383 - 8424' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27 PRODUCTION TEST N/A I N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-~CF WATER-DEL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I Flow Tubing Casing Pressure CALC,ULATEp OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (corr) Press i24-HOUR RATE I~ 28 CORE DATA Brief description of I~thology, poros~ty, fractures, apparent d~ps and presence of od, gasorwater Subm~tcorech~ps JAN2 o 1982 ' ,~ias~ Oil & Gas Cons. Commissim~ t,.qchorage Form 10-407 Submit ~n duphcate Rev 7-1-80 CONTINUED ON REVERSE SIDE 29 30 GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUEVERT DEPTH GOR, and tlme of each phase Top Kuparuk 8082' 6073' Top Upper Sand 8] ]4' 6098' Base Upper Sand 8149' 6] 24' Top Lower Sand 8348' 6269' Base Lower Sand 8423' 6323' Base Kuparuk 8492' 6373' -- 31 LIST OF ATTACHMENTS 32 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S.gned ~, ~. -~~ ~-~'~'~'V'/~'~'~')T,tle Dist. Drl.cj En§r. Date l-/~)-~'2..- INSTRUCTIONS General. This form ~s designed for submitting a complete and correct well completion report and log on all types of lands and leases ~n Alaska. Item 1 Classification of Service Wells. Gas ~nject~on, water ~njection, steam ~nject~on, a~r injection, salt water d~sposal, water supply for ~nject~on, observation, injection for ~n-sltu combustion. Item 5 Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given ~n other spaces on th~s form and ~n any attachments Item 16 and 24 If th~s well is completed for separate production from more than one interval (multiple completion), so state in ~tem 16, and ~n 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.). I t,,~ 23 Attached supplemental ~ th;s well shot.~ld shq~, ~'" ' '"' Form 10-407 T3' HO:xT,~ [LOPE~:,GI}IEER!i,G TRAilSHITTAL ~ /F/C' J. J. Pa,.~elek/Ann Simonsen DAT-7_ , / /Z"~Z~ WELL '"" · -- h~,.:E' Transmit~ad herewith are tha following' .. PLEASE I~OTE' BL - BLUEL!HE, S - SEPIA, F - FILM, T - TAPE . r, ....... ' DATE: F. ErE~.PT ,.C,,,,O,,LED,.,E¢:C./L..' ./L.,/_..¢/~. ¢ . ,;~,LR,~ P. EC=~,FT TO' £CEIVED Alaska ARCO ALASKA, I,,~. ATTrI' A~;;~ SI;.iO:ISE~! - AF~/311 P.O. BOX 360 A:IC~iO2ACT_, AK 9951 J. J. Pe':elek/;tnn S~,T. onsen ....... ,~n ~:~ the follc..:in=' S - SEPIA, F - FILM, ~ TAPE Apchola.gg NORTH ~LOPE E:IGIiIEEP,!i;G ( J. J. Pa',~etek/Ann Simonsen I~ATE - //~ '"~ Z.-' ~ t WELL Trar, s..m~;;ed here,..;l tn are the following' ~=~.~ HOTE - BLUELT~E, SEPIA, F - FILM, T - TAPE '- "ETIj'~'' P. ECE'?T TO' RE£EIVEI) RECE!?T ACr,,:C:L[DG DATE' CCI' 2 3 lBS1 'Al3ska Oil & Gas Cons. Commission ~chorage ARCO ALAS~tA, INC. ATT~I: A:i~i StTO;iSE:! - AF$/3tl P.O. BOX 360 A;iC:~n~,Pr ~" CQ~lO ( NORTtt SLOPE ~_~,GI~,E~'RI~:G TRAfISHtTTAL =~ ~?.~/ J. J. Pawelek/Ann Simonsen Transmit:ed herewitn are the following' '" HOTE~ ~L .;~ EASE - BLUELT,,E, ~__~ SEPIA, F- FILM, T - TAPE REC~iPT ,~C~,,,O,,LEuu[ DATE ~2~?T TO S: ,,~lU,.,I RE~- ARCO ALAS:~A, I !~C. _ Alaska 0il & Gas Cons. ..... ,- ~'~ Anchorage ATTH' A;;;l SI~'~u,~:~, AFA/311 P.O. BOX 360 A~CHO2AGE, AK 99510 NORTtt SLOPE E:~GIHEERIi:G ( TRAi~SH!TTAL ~ ~'~' ~ TO- ~/'/~ , ~ ~~,,,,Z FROM: J. J. Pawelek/Ann Simonsen WELL Transmitted herewith are the fol'lowing F - FILM, T - TAPE ...... DATE: RECEIPT ACm,O,.,LEDG[ _ _ .~ ~PL :=~lLR,t [,Eu~:?T TO' EASE ~- ...... ARCO ALASKA, INC. ATT[]: A;i;l SIMONSE~t - AFA/311 P.O. BOX 360 A;]CHOEAGE, AK 99510 OCT 2 ~. 1981 Bit & Gas Cons. Commission ~chorage ARCO Alaska, Inc. Post Office B o0 Anchorage, Alask3 99510 Telephone 907 277 5637 October 9, 1981 Mr. Hoyle Hamilton State of Alaska Alaska O~l and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject' Completion Gyroscopic Surveys Dear Si r' Enclosed please find the co.m]~letion Gyroscopi?/Surv~ey for the following/wells- DS 12-12,vDS 17-7~ DS 17-9, A-5~&.~6, q~-67 and B-7.w Sincerely, P. A. VanDusen District Drilling Engineer PAV:cm Enclosures ARCO Alaska', Inc. North Slope , ,~ct Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 907 263 4274 Les M Sellers D~stHct Drilling Manager October 5, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Comml ssion 3001 Porcupine Drive Anchorage, AK 99501 Subject' DS 14-11 Kuparuk A-4 DS 14-16 Kuparuk A-5 DS 17-10 -KQ~,~["'~'~ 'A-6 Kuparuk B-6 Kuparuk B-7 Kuparuk B-8 Dear Sir' Enclosed please find the following' 1) The Completed Well Reports for DS 14-11, DS 14-16; Kuparuk A-4, A-5, A-6, B-6, & B-7. 2) The Monthly Report for Kuparuk B-8. 3) The completed Gyroscopic Survey for DS 17-10. Sincerely, P. A. VanDusen District Drilling Engineer PAV'cm Enclosures RECEIVED 0RIGIN,&.L AI_A KA ,,.... A~ ~A$ ~OI',,ISEF:tYATI~N ~ wli$$iO1',,I WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well ClassificatIon of Serwce Well OIL)~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 81-116 3 Address 8 APl Number P.O. Box 360 Anchorage, AK 99510 50-029-20638 4 Location of well at surface ~ 9 Unit or Lease Name 779' FSL, 310' FWL, Sec zB', T11N, RIOE, UM Kuparuk 25647 At Top Producing Interval 10 Well Number To be Submitted A-6 At Total Depth 11 F~eldand Pool To be Submitted (~/ff, fFS~_., /~u/5/ Fuu/./ ,S-~c ~/ 'r'l//v/£/O.F,~, Kuparuk River Field 5 Elevation ,n feet (,nd~cate KB, DF, etc ) I 6 Lease Des,gnat,on and Ser,al No Kuparuk River 0i 1 P0ol 100' RKBI ADL 25647 ALK 465 12 Date Spudded 13 Date T D Reached 14 Date Comp, Susp or Aband 15 Water Depth, ,f offshore 116 No of Completions 9/5/81 9/20/81 9/26/81 -- feet MSLI 1 17 Total Depth (MD+TVD)18 Plug Back Depth (MD+TVD, 19 Directional Survey I 20 Depth where SSSV set I 21 Th'ck'ess of Permafrost ~159'MD, 6714'TVD 8940'MD, 6553'TV[ YES[~]X NO[] 1639 feetMD 1700' (appr0x) 22 Type Electric or Other- Logs Run DIL/GR/SP/BHCS, FDC/CNL/CBL/Cal, CBL/VDL/GB/CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT PER FT GRADE :TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-40 Surf 80' 24" 200 sx Permafrost 10 3/4" 45.5# K-55 Surf 2791' 13 3/4" '1100 sx Fondu & 250 sx AS II 7" 26# K-55 Surf 9029' 8 3/4" 850 sx Class "G" cmt 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, s~ze and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3 1/2" 8067' 7989' 8108' - 8196' 8359' - 8372' 12 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 8383' - 8424' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL US.Eh N/A 27 PRODUCTION TEST Date F~rst Production I Method of Operation (Flowing, gas I,ft, etc ) N/AI N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ 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 I~thology, porosity, fractures, apparent d~ps and presence of o~1, gas or water Submit core ch~ps ~lCl~ora'~ uOa~ra/$8/oa Form 10-407 Submit in duphcate Rev 7-1-80 CONTINUED ON REVERSE SIDE 29 30 GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluIds recovered and gravIty, MEAS DEPTH TRUEVERT DEPTH GOR, and t~me of each phase To be Submitted N/A 31 LIST OF ATTACHMENTS , 32 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S,gned ~~, ~~ T,tleDist' Drlg Engr'Date 10/5/81 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 Serwce Wells. Gas injection, water injection, steam ~njection, a~r ~njection, salt water d~sposal, 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 g~ven in other spaces on th~s form and in any attachments. Item 16 and 24. If th~s well is completed for separate production from more than one interval (multiple completion), so state in ~tem 16, and ~n item 24 show the producing intervals for only the ~nterval reported in item 27. Submit a separate form for each additional interval to be separately produced, show~ng 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. Form 10-407 KUPARUK A-6 DRILLING HISTORY NU hydrill & diverter. Spudded well @ 0615 hrs, 9/5/81. Drld 13 3/4" hole to 2811' Ran multishot. Ran 68 jts 10 3/4" 45.5#/ft csg w/shoe @ 2791'. Cmtd 10 3/~1" csg w/1100 sx Fondu & 250 sx AS II. ND hydrill & diverter. Instld 10 3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8 3/4" hole to 8657'. Ran DIL/GR/SP/BHCS, FDC/CNL/GB/Cal. Ran 198 jts 7" 26# csg w/shoe @ 9029'. Cmtd 7" csg w/850 sx Class "G" cmt. Instld 7" packoff & tstd to 3000 psi - okKA Ran CBL/VDL/GB/CCL Arctic packed 7" x 10 3/4" annulus w/300 bbls H20, 2~v sx Arctic Set II & 9~1 bbls Arctic Pak. Displaced well to NaC1. Tstd csg to 3000 psi - ok. Drld cmt to 8940' PBTD. Ran 3 1/2" perf completion assy w/tail @ 8067' & pkr @ 7989'. Tstd tbg hanger & packoff to 3000 psi - ok. ND BOPE. NU tree & tst to 3000 psi - ok. Displaced NaC1 brine to diesel. Set pkr. Dropped perf bar & perf'd f/8108'-8196', 8359'-8372', 8383'-8424'; 12 spf. Flowed well to tst tanks. SI well. Released perf guns. Pulled dummy valve. Closed SSSV. Instld tree cap & tstd 3000 psi - ok. Secured well & released rig 0600 hrs 9/26/81. OCr o 8 1981 0i~ 8, Gas Cor~s. Oommissior~ A~c~orage Eastman/ Whipstock A PETROLANE COMPANY .,,-REPORT of SUB-SURFACE DIREC TIONA L SURVEY ARCO ALASKA~ INC. COMPANY 'Pad A, Well NUmber: 6 WELLNAME Kuparuk Field, North Slope, Alaska LOCATION , JOB NUMBER A951G0023 TYPE OF SURVEY REI;EI~EI) Gyro-Multi Shot OCT l ~ 1981 ~as~ 0il & Gas Cons, Commission A~chorage DATE 08-Sep-81 SURVEY BY D. Pefferkorn OFFICE Alaska Eastman P. O. Box 4-1970~Anchorage, Alaska 99509/(907) 349-4617 October 7, 1981 ARCO ALASKA, INC. P.O. Box 1479 Anchorage, Alaska 99510 Well Number: A-6 Location: Kupaurk Field, North Slope, Alaska Type of Survey: Gyro-Multi Shot Date: 08-Sep-81 Method of Computation: Radius of Curvature Surveyor: D. Pefferkorn Job Number: A981G0023 Attn: Bob Hines Dear Mr. Hines, I am enclosing the original and one copy of the Gyro-Multi Shot Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continUe to serve you in the future. Si~el~ .... / TOM J~NE S// Dist~t/ Technical Coordinator TJ/bb cc: file enclosure Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide .i-,.L-u P~LA'3KA: T_ NC ,. ," ,.,:[-', "A'~,' WELL .dU · o 'GMS/GMS -" ............. JU~::" ,xu~':~ + + ,* o,-,;, o ' Q"'~'~'"'~~. ~. ,,...... L_Orr_ ALASKA ~..:i"Ah:~-.K F]~EL.,-q~ ~::URTi"i S tli~L::; ~. C.'-2-'''=n "' ' ,' ,.., ,., fib, SURV~-YC, R,._ ,~ T.~ ,r':"r"FF~F~KOt:;,'N= BATE F<UN: ,~ '"'-..,o--o,".,'~"r' ..... ~=:I- ,... , '"-R C;AMERA NOt J. 4z,~ C~YRO NO ** ..396 90 B-E:G F;/U.:NO:, II'~1.- ,,~,~ .::.u.t~,,c_,~;,':; LUNt-',:HILLER, [!ATE RUN: '-'"' ~:E,~ ..... rd1 CAHERA NOS F<259,... GYRO NOS .--..~.....S~,~'~ ,'-7'0 BEG A/U ,~.,~0~ 1121 --'.:' !3 F.'. F'.: S :[ G I"! T ,' N 0 IR E: C 0 R Z N T E: R SURV a[ A., WEL. L NO: 6U~,:::,, ;:.,r~c., .lOB. NO:A98].G,~,02~, J PA R U K F I E L D Nt".) R T H' c. · r', .:, · .," ~,L.~.,F E'. ~ AEA'SI'(A FEET FEEl' FEET FEET FEET TOP KUF' SANDS 80E;L--""· 00 6078,85 ,-°OOR.. ,. 7' ._,'-"'-'"'-", S.=;.-.- ,-- ..,. ,. 4/u.,'., ~.,2 S 945+69 E t'OF' UF:'PER SANDS 8114,00 6096,.88 2017,2 5996+83, 4728,96 S 9.4'7,26 E F.~ASE :'~" '~ ",".-' a9 -~O 6i .... '~ "'"'-" - ,~,'F,"R S Sl + 4 ~-:0~o 6 60v? 43 '4'?=;'-~ ~"'; *0 ~;.~.Ic., ._, . ~ 47 S 9 I., -,- - E TOP LOWER._.°ANDS 8..~4:3,,~,'''',''' .., ,, 6267+8'-~... 2080,2 6167~ 8?,_ 4886,45 S 97'*--, + 1-~',:, E DA'Si::.-' LOWER SANDS' E:.42.3,00.. 6.322,74. ,.? 100, ,:,-' 6 2,:,::, ...... 74 -,4 956 ,.. ~6, . S_ 98'-',~, 83' E F' E E 1' D 4P.C,I,17 :_3 11 2C", ii: 4822,':?0 S :L1 '20 E 4846,76 S 11 19 '[': 4982 · =' ~; S .I. 1 ._,o I 6 E 50.-43~64 "--'~1 I,'4 E Bi':'.'t"..!F KUP SANDS 8492, O0 6373,, 41 2118+6 6';?.'"~::'; ,..,. ai~ 4982,SI S 991,~''''.-,,., E 5080,47o'-' 11 15 E ARCO ALASKA, INC,~. PAD 'A~' WELL 'NO ,~ ¢.,; b;gc,,"' '"' """oMo'"' ........................... ;..:'OB NO ~ A981U 0'.., 2 ~;""" KUFARJK FIELO, r',~t.gR,,.~ SLOF'E, ALASKA GMS, u"~-'~- '"' "': ,'~.- .. .... i"iD , :-:u?,.Vu.' 'I ..... '~' I..,,E~" .~ D PEFFERKOF.:N Zi¢.,TE. RUN .: 08.. --c¢.r-'-"~'~'-..~.--~'-' I · CAMERA NO~ 1478 GYRO NO; 37& FORESIGHT: N 0 E, JOB NO: A?81G0008 2800-8?00 MT_~, ._,.~,,.-~.,~,,~ LU~'D/hiILEER~ DATE r'..~N; ..'.-'-'oEP-UI CAMERA NO; o.-'~,, GYRO NO~ 306 90 DEG A/U ~'~0~ :[121 ¢ORES]:GHT~ N 0 E VI-'i:RTICAL SECTION CAL. CULATE[t .IN F'L. ANE;,:~f.~ F'ROF'OSAL D'IREL. I luN..,~,, S;,~1'2 i. EL~,,:.,~;~..~ H:~INi E r',Epn'::'q.,...,.,.,.. OF' SURVEY RADIUS uF' CURVATUF~E rir:.:nu.~. :',}D A, ~EL..L NO: 6 Gf'~/GMS JF'ARUK' FIELD, ...... NORTH' JOB NO ~ A981G0023 ..~ 4 07 - 0 C T -- 81 i::'AG'"' :ASUREB DRIFT ...... [IRIFT ]EF"['H ANGLE BIR~..CTION FEET D N I] M O, 0 0 0 0 lO0,~ 0 1=~, N -"~;o 0 E 200, 0 15 S 81 0 E: SO0, 0 15 S 62 0 E 400, 0 15 N 0 0 E COURSE'VERTICAL VERTICAL 'SUBSEA R E LENGTH DEF"TH SECTION TVD C 0 FEET FEET FEET FEET -"] ~ _ 1 {;, 0 1~ S 4 0 E 00, O, 0 15 S 39 0 W 100, 700~ 1 0 S 44 ~0 'E !00, P;',-~.,,.,.,, 3 4~',_, ,..~ 34 0 E 100, °rhO~.. . 6 15 S 17 0 E 100 ', C T A ~;: G U 0 R D i N A FEET O, O, O0 O, 00 ---100, O0 O, O0 100, 1 O0, O0 ~,,. r'~n.. ,, -0,, O0 0,0~'-,., N 100 ',, ............. ~,..,~'-,r,'t'~ ,-~,~.,~ 0 + 08' 1 O0 ,'00 0,.. 06 N !00, SO0,O0 O,SO 200~00 0,08 S 100, 400~00 0,18 300,00 0,11 N ~00~ '~'~ ~:~ ~ uu 0,~.. 400,00 ~"? 60 499 ~ 99 :'c'9 ~, O~ . . 6?9;99 ............... 1,='9 79~,"9. o 5,27. 699,8~.. . 8'?9,50 13,7~ 799, 5'0 _ r', ,-- L 0 T E S~..""tSTANCE FEET n,O0,, O+ O-v'~'" 0,2:1. 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'51 2,!3 · .3, .~ I 0 i., :ii:8 ~, ~.~'..7 1,50 fib A, WELL NO; 6 GMS/GMS JOB N(D~A981G002S JF'ARUK' FiELD~' NORTH,.~'LOPE:' ALASKA TRUE '" ~'~1 I ,~r-- -,.,, ,::~'O,:.-C:' "" ASURED BRIFT DRIF'T ,...L:UR,::.c. VE:F,'TiU~..~L VEF..'Ti""AL,.., ,,,_,,...._,,_.A R E C': T A N U U L A R C L 0:5 t',..,, R E ]]OGLES [)E:F'TH ANGLE_ DIRECTION LENGTH f_~FF'TH SECTION TV'Ii C 0 0 ?( ]J :[ i"4 A T E R_. DISTANCE '"',...,iR'-r.c. CTION .:.:,,-.""~L,'--':'...,--,-,.I~""' FEET D M f_l M FEET FEET FEET FEET FEET FEET _0 M [~G.,'" I OO F-" '-' ..-'~19, I , ~, 1° '~ ~800 · 49 0~.q 10 0 E 50, '~ .-"~ 908,_.c"~ ~'~ a , ,~1 ,-,°°~,-,'~ ,34 ~R ":"~ 2483 99 959 '~' '-'eO0.,., 50 1~..., S 10 0 E 100. ,.:.:.,o,.t,'"=""-',, '~ , '-7'84 ,,eS ,,.. ,, ,.;.. c:, S 3000, 50 45 S 10 0 E: .....100,.. 2647,,60 ......1062,10 25.47~60 I035,,35 S ¥1o0,, 51 lo S 10 0 E: 100. ~'10 ~- -- . ." .../ ,~,3 1139~7'6 26!0~ 1111 ~'~'~o. S z':.'O0, .=,9 30 S 9 0 E 100 · '~.' 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S 297'" ~0 'E 1'-*'=:°.,..~.._,,.., · O0 ._,:-':: :L1 46 E 3600, ~4 0 S 6 0 E: 100,, 301.0..q~' I"'=:'-'''' -' ' ....... · ,.,..t,o, ~8 'Pq:'10.,.89 1.b07,6'.~ .'=; 30..":.,,45 E lbYU,,-4='._., S 11 29 E 3700,, 53 '" ~'" ......... o~ ......... .,..~.._,,.R ._~ 0 E :i. 00. 3069,85 16""',o.,. 65 2'y69,,.::,.,_, 15U8.0.''z,..., S 314.,,19 E 1618.81 5 It 1'~..,. ~-' 2,00 0-,50 ..-: ! ,-48 · ..:.,800.53 45 S 8 0 E 3900,, 50 1~',.., S 13 0 r.:',.._ 4000, 47 30 S 1'7 0 E -4100, 48 0 S 1.6 0 E: 4200,,. 48 0 S 16 0 E 4500.:. 48 0 S :1.6 0 E 4400, 47 ..'5.0 S 15 0 E 4500, 47" 15 S 1.6 0 E7 .4600, 47 30 S 14 0 E 4700. , 47 1~., ~' S .1.1 0 El . ~-~:, .... 4~;.0. 47 S0 S 12 0 E · 4 ~, 00.,~,.,-" 1 ._.,"" S_ 1 ,..'.~ 0 E 5000, .47' 0 S 1.3 0 E 5100, 47 _1.5 S 1.3 0 E ~,~,:00, 47 i~,.., S13 0 57,00, 46 45 S 12 0 E: 5400,, 46 `1.5 S 14 0 E: 5500'., 45 45''S-'-13 0 E 5600, 44 SO S 14 0 E 5';-:'00, 4."'4._ 45 ,..¢..', 1°.,.:. 0 E 100., 31'""8,98 1698 .,. "'"" ~ ;" "':' ,"~ '' 32:3 3q ~' '::" ~...,'....," · 98 '~ o~:,8 · t. 4 S . ,,. E: 1699,1 o .'.-:;, ]. 0 ,.,,,... E . ..'4..., 5'? o ........... , 100.,, ;5190,54 :5090.,,54 .. :: I -" ':' , ._, .:,,.~/..,67 E !77"7 95 S 10 57 E ~ ~. '" n :'"" :': ~'" ' ..... ;" ':' "' 07 'I 100, ,~.,.56,.:~,; .,::,'1o~,30 I~'.:.::,t8,33.:.,S:;,: ,~57, I.,:5 F:.~o,_,..:.. S .. ! 7 E 100", ,~...,,~S., 54 19,..6,63 3223,'":....;4 1 ~::.:u9, xO .'=; · r,n $390~ 45 2000 ,:/:'.-. · 4 1. ~,,, ,-~ · '"' 10'"",,,, 103, 35':24 100,, 359'" 32 '"':' ":" ~ "'" 24 3.,~92,."'42 7174.,,4i S .,&~ -.,1. ~".. ~,".. ,¢. t,:..i, . .. -,.. ~... .1.00, x6,z,r, O4 -:,90,:; 71 3560.04 2245.48 S !00 3727,76 .-:,-;,,zo 28 3627,76 2317,zI S ... ...., .'. ,....~. ,t..¢ .~' 4- ..... 3,~-,].~.:: E 17~:,.:.~. S I 1 .1.9 i::. 67 E' 2000,86 S 11 30 E 419,15 iS 2;7."74,9:3 S :1. I 39 i-'i: 4:58,93 E: 2!48,81 S 1,1.47 iE 458,60 E 2222.24 S !I 5.'-"; E 4'7"~', 64 E ~'-' 95 ~' '-':~ i o i E · .. ~:;..~'-'- · ..' ," ... .~.. a 9:5 ~'; '" E 2:5.49 "7":::' · , , ........ ,,., S _I.:: i E: 'x -:, o,:.~ ..... =: '::' -" ~:.'; " .,.'~ O0 ......... 48 2442,8~4 3695. ,48 .~":'..t:89 .,. 4 .1. S ...:"'".., ,.., ,, 23 E 2a42.., U,;::, `1. 2 0 E ":,':~ 'x ..... 52:5,573 E 1 ,44 S I"2 0 b. I 00, .....'"4 ,...,~-:' ,....': .....".", ~."" 0 ,:. ,. 16 .,...r',., 4 ,.. 76:5 ., 20 2.": ,:.t./:-_. 1, ,51::~ ,..'::"; .... ,...'::',-~':",..."~ -' I00. 3.:93t.,2'4 2589.72 :58:5:[,24 25:52.93 S 5:Z9.,.S? E' 25Ei',9,72 S :k2 .1. E: .1.00.,. :5'?':79,28 .-,,.'.z-.~' O03'--'°9 ":'q "~"04,. 55 '"""'" '-,4,': ...... ......~,....,... ..... ,....;. .,.,.:.,.. ...-..,:'.:, ;55 S 5, o o E ,.:. ._ ._, :'.~ ., ,'",. 0 ~" :L 2 :"~_ E: .1.00, .4067.1'"' .............. .,~:~'¢ .':':,....,72,40 E ,.,:,'._,,:::,, ,.,-.. S I 4 E o :,-.!/,::,d~ · 4:..! ,:~967,16 2675. ....... 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[_ ,:. t,< t.: T ,d DEF'TH ION 'f'VD C 0 0 R D I r4 A 'l- E .,...,.'.q i)ISTA L., t-,:: v'..'- h.: 1 'ri M B id FEET FEET FEET ,- ,.:..bT FEET FEET g..~ M 'fJF~/~ u..._,r 5900+ 6000. 6100. 6200. 44 45 R~ 11 0 E 100. 4487.6.3 3164,20 4~'''~'~o/,63 3n'~3.02.,, ~ . S o~, . ,., E: 3164~1 46 SO o 10 0 E 100 "~ ...... o ~/+56 3235+ 65 4'*~ , --,~,/+~, 3163.S0 S 680,47 E '47 ' 15 S '9 O. E 100; 4624 ;'6~.~ ..... ~X~n<".~,, · 744~24 ~'65~, ~Z'?S6.44,. ~R- 6"'". 717.~ :'~ ..... '='"~¢)c, .74 S 1'~ :: c 2. 85 50 0 S 9 0 E 100. 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"-7' 0 -' '" 764 ":' '<: R =: ..... ...':, ¢ :. c: 5..., 72 S,' '.:.8,.: E ..,,., ...,,., ,,' ',:.-:,':,' S -1.:I. 5:3 E ,'",,, .,. 50 ¥677~56 S 780:96 E 3759,56 S I! 59 E 0.,00 · 3749.7'~, S 7'::'Fi ~ 66 E S:.3SS + ,--'-'8 S 1 i '::'""..: 7 i:i: 2.~ 2 ~ 6800. 6900, 70000 7100. 7200. 47 0 S 10 0 EE 46 OS 9 0 E 45 45 S 9 0 E 45 OS 9 0 E 46 45 S 8 0 E 100 100 100 100 100. 5156,'~''' ""'~' '' 5 ,78 5365.48 41~1,88 =;765.48 5435.10 419 7300. 45 15 S 8 0 E 100. 5504.56 4265.28 540 ~,56 863.36 E: 7400. 44 45 S 8 0 E: 100. 5575.27 4335.81 5475.27 87.S.21 E · ' =' ' '"' '""~ ......... ~"" 54 ....... 88.S ,54 '7500 44 0 S 9 0 E .1.00. ~64,.,.,..,-,.,4--,05,6'1 5 /,,,.7.% 7600. 43 15 S 8 0 E: 100. 5719.,14 4474,,47 56:[9,14 89J.{,..74 E 7700. 4.S 0 S 8 0 E: .i. 00., 5792.,.12 4542.,67 5692.,12 90:."<.,25 3822~11S 808,41 ','$893.65 S 820,38 4034.85 S 842~74 ,,:4105,84 35 4177.07 8 4247~09 S 4:16 4384~49 S 4452,i9 S E: ....' 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"' ' ........... 50 ' ',': ................ = ....... 5 () 85..; 90 S 1 ! 15 E 0 {::.', 4 ,:::, ..., ..... ,, :,,42" :.)3. 0 S"' 11 ¢) E: ' .i. 0'0., ,2, ..t, / y .:, z U .. 85 ..,, 4 6279 .,..,,: :::: 4 v ,'.::: :._.: .;......., S 9 <;;' 2; .-':, :5 E ,, 8600 · 49 45 S 9 O, E: '! """'; .,. 64 ~"; -. R ": =: i -' "'" -' "004 ,.i. "'; ...... ':::; ............ .,... .......... 'o ..3., i,,- 6 S ::, 2,,.:°/,., ._=; ...... (":, F:. ;"., , ,...,'::' 4 S .:. ,, 1 E ,. I .%..;; ., ,_.!:, ,:..~ ... 1 .,.'l _1. 4 S Y' C: 0 47, 0 .':_".", 8 :'" E:: i. 00 65 '--"/: i '":; F; 92 .i. r-, i6426., i. ';:' ~:: '- ...., ,, ., .,. .... , .,. .... . ,, ., ,, -1. ,,..'::' ,.._':., 1 S .':::; l 0 :[ .4 ., .'~. '"',. E: 522 :[ ,, ._:'=7 S. 1 :[ .1. .-..'c' E: 0 .,, 72 JOB ~';'; ................... .-~,.., .l A Y :::: 1 U C'O 2.Z, 9';0. - ?1=''~,.~ ND ARE F'ROJECTED SURVEY STATIONS ,',=, '- PL,...,G BACK TD 8940. 4F;_ 15'S "'2 0 _.F 40'* 669,'?' +'7! ........ F, Z87 .._,~'""',.', 6597,,/1"" 5289,08 S ~. 0:,!'?., ,'.:'," ".' ~ ..... E =; '~',..-,,.,, S8 ''':~° ' 'R.. :".'1 i E ] 59 ,,D .... q"D F ]; ?'-,~ A i.. C.L. 0 S'U R E "- D .T. R !"": C 1' T_ 0 N ~ ~,:: ~ B I STANCE ~ 0,00 t [ ' . - .-. . ' . ,.:.?::-:..,ii:-.. , '" / j - , . . ir · i Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Operator, W~i i/Name and Numt~r Reports and Materials to be received by: /~--~ ~) K - ~ ~'' ~ ~ Date /a/19 -/-~ ~e/r W~,, ~/~ ~-I Required ~te Received .... C~letion Re~rt Yes Wel 1 Histo~ Yes Mud L~ WO --F/ ~ , , ,.. .~re ~ips Core ~scription ~e~stered Su~ey Inclination Su~ey ,, , ~s R~'"'~ Yes ) Digitiz~ rata ALASKA OIL AND GAS CONSERVATION COMMISSION Thru~ Hoyle H. Ramilton~ Chairman Lonnie C. Smith C~missioner Harold R. Hawkins Petroleum Inspector September 14, 1981 To Witness BOPE Test ARCO Alaska Inc. K.R.F. Well No. A-6 Sec. 5, TllN, R10E, OM Permit No. 81-116 Sept_ember_ ~, 1981 I left DS 14-15 at 9~00 a.m. where I finished wi~e~sl'~g a 'BOPE test, to Arcots Kuparuk field, to witness another BOPE test on well No. A-6. SeDtember 8, 1981 I witnessed the BOPE test on Ku~aruk A-6 well. ~h~'e was~ One fa-ilure, the master control valve to the annular preventer. This valve was repaired and tested okay. filled out an A.O.G.C.C. report (attached). In summary: I witnessed the BOPE test on Arco's K.R.F. well No. A-6. Tests were satisfactory. O&G II 4 4/80 STATE OF ALASKA ( ALASKA OIL & GAS CONSERVATION COIdMISSION B.O.P.E. Inspection Report Inspector Operator ~ R :."r) la A/! f/(,~ Well ,~.-/__ /fJ./2,~J/', Location: Sec , T//,~/R,,pF ,C, ) ,, '//~' Drilling Contractor Rzg # .... . Representative /.-),/2/' )~'~'~ ?~ '.-=Z Permit # / / - // /,~ 7. Casing Set 0 /~[:'/~/" ft. _ _ Representative..~"',/", ' /' "v~ Location, General \ Well Sign .. General Housekeeping Reserve pit ~,_,f/-r' Rig 0~// BOPE Stack Annular Preventer P~pe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: Fazlures ACCUMULATOR SYSTEM Full Charge Pressure ~,/~/ ~. psig Pressure After Closure / z,.' /).p pszg 200 pszg Above Precharge Attained: ./ Full Charge Pressure Attained: · N2 /~(,'? ~ ', '~ ~ .?. ~ ~slg Controls: Master ~ Remote ~ [ B1znds swztch cover Kelly.. and Floor Safet3. Valves Repair or Replacement of fazled equipment to be made wzthzn Inspector/Comm. lssion office notified. Remarks: ~;/%/7-t.-'z? ~nzZZ/?z~Z t/~Z~,<'. D// A/.,/,..:,/,~,~ ~ >.f~,,~._' / _~A:: l-F_'; Z-~~z) r'/¢~Z. 7. f~-/t.- ~,2 _.,n /,~,,~, c.'~' ' '~,' t~,? ~-';. ~' ',,'?.. , .' Upper Kelly. Test Pressure Lower Kelly Test Pressure Ball Type Test Pressure · Inszde BOP Test Pres sure.... / Choke Manifold Test Pressure No. Valves / f'-' No. flanges Adjustable Chokes l[ydraulcally operated choke. Test Time ~ h r~ %'~ -- - days and min -- mln -- se~ sec Dzstrzbution ormg~ - AO&GCC cc - Operator cc - Supervisor Inspector ..... ~ July 30, 1981 Mr. P. A. VanDusen District Dri!ling Engineer ARCO Alaska, Inc. P. O, BC~ 360 Anchorage, Alaska 99510 Res Kuparuk 25647 A-6 ARCO Alaska, Inc. Permit No. 81-116 Sur. Loc.l 779tFSL, 310eFWL, Sec 8, TllN, R10E, UM. Botto~ole Lo~.I 468'FSL, 1502'FWL, Sec 8, TI1N, R10E, UM. Dear Mr. VanDusen ~ Enclosed is the approved application for permit to drill the above referenced wel 1. / Well samples and a mud log are not required. A directional ~rve,f is required. If available, a tape containing the digitized log information shall be submitted on all logs ~for copying ex=apt experimental logs, velocity surveys and dipmeter surveys. ~lany rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title Alaska Ad~nistrative Code ). Prior to commencing operations you may be contacted by the Habitat Coordinator,s office, Department of 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 Adm~nistrative Code, Chapter 70} and t~f the Federal Water Pollution Control Act, as amended. Prior to pr. P. A. Vantmsen l~up~ruk 25647 A-6 -2- July 30~ 1981 ccmmencing operations you may be contacted by a representative of the Department of Environmental Conservation, To aid u~ in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. #e would also like to be notified so that a repre~ sentative of the ccmm~ssion may be present to ~,ttness ~esting of blowout preventer equipment before surface casing shoe is in the event of nspension o,r abandonment, please give this office adequate advance notification so that we may have a witness p~resent, Very truly yours., Chairsmn of ~I _O~D.Ea .0~ m2 CO~issto~ Alash Otl i Gas ~o~~atlon '~~lon Eno lo sure ccz IMpartment of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. ARCO Alaska, Inc.~ Post Office 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 27, 1981 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Kuparuk A-6 Dear Sir: Enclosed please find the following: · 2. 3. 4. 5. 6. 7. The application for Permit to Drill Kuparuk A-6 and a $100.00 check for the application fee. A diagram showing the proposed horizontal and vertical projections of the wellbore. An as-built drawing of "A" pad indicating the proposed surface location. A proximity map indicating the relative locations of Kuparuk wells A-5, A-6, and A-8 (West Sak #12). A determination of maximum pressure to which BOP equip- ment could be subjected. A diagram and description of the surface hole diverter system. A diagram and description of the BOP equipment. In addition, please note that this well is subject to letters of Non-Objection from BP Alaska Exploration Inc. and Sohio Alaska Petroleum Company. These letters should be on file with your office. Please contact me at 263-4270 if your records indicate otherwise. Sincerely yours, P. A. VanDusen District Drilling Engineer PAV/DSS:sp Enclosures ARCO Alaska, Inc ss a subsidiary ot AtlanhcRichheldCompany STATE OF ALASKA ALASKA (_AND GAS CONSERVATION CC("-' /IlSSION PERMIT TO DRILL 20 AAC 25 005 la Type of work DRILL ~(~ lb Typeof well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL C~ SINGLE ZONE [~ DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2 Name of operator ARCO Alaska, Inc. 3 Address JU~ P.O. Box 360, Anchorage, AK 99510 4 Location of well at surface 9 Un,t or le eo[/ ~ 779'FSL, 310'FWL, Sec 5, TllN, RIOE, UM KuDaruk 25647 At top of proposed producmg ~nterval 10 Well number - 1320'FSL, 1320'FWL, Sec 8, TllN, R10E, UM A-6 At total depth 11 F~eld and pool 468'FSL, 1502'FWL, Sec 8, TllN, RIOE, UN Kuparuk River Field 5 Elevat,on ,n feet (,nd,cate KB. DF etc ) I 6 Lease des,gnat,on and ser,al no Kuparuk River 0i 1 Pool 61' GL, 66' Pad, 100'RKBI ADL 25647 ALK 465 12 Bond mformat~on (see 20 AAC 25 025) Type Statewide Surety and/or number Fed Zns Co 8088-26-27 Amount $500,000 13 D~stance and d~rect~on from nearest town 14 D~stance to nearest property or lease Ime 15 D~stance to nearest drmlllng or completed 30 mi NW of Deadhorse mdes (at TD) 468' feet well (@ +1673'MD) 50 feet 16 Proposed depth (MD & TVD) 17 Number of acres m lease 18 Approximate spud date 9159' MD/6714' TVD feet 2469 9-12-81 19 If deviated (see 20 AAC 25 050) 120 Anticipated pressures 2579 ps,g@. 60OF Surface KICK OFF POINT719feet MAXIMUM HOLE ANGLE48oI (see 20 AAC 25 035 (c) (2) 3078 ps,g@ 5930 ft. TD (TVD) 21 Proposed Casing, L~ner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casmg Weight Grade Couplmg Length MD TOP TVD MD BOTTOM TVD (mctude stage data) 24" 16" 65# H-40 Welded 80' Pad I Pad ll4' ~ 114' + 200 CF 13-3/4 10-3/4' 45.5# K-55 BTC 3125' Pad ~ I _ ~ Pad 3159' 12700' 1200 sx Fondu + 250sx 8-3/4 7" 26# K-55 BTC 9125' Pad ~ Pad 9159' 16714' 875 sx Class "G" ~ I I t 22 Describe proposed program ARCO Alaska, Inc. proposes to drill a Kuparuk River Field, Kuparuk River Oil Pool devel- opment well to approximately 9153'MD, 6714'TVD. Selected intervals will be logged. A 20" x 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8" 5000 psi 'RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. Expected maximum surface pressure will be 2579 psig based on cooling of a gas bubble rising at constant volume. The well will be completed with 3½" 9.3# J-55 buttress tubing. Non-freezing fluids will be left on uncemented annuli thru the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon conclusion of job. 23 I hereby certify that the foreg~the best of my knowledge SIGNED 7~,/~, TITLE Dist. Drilling Engineer DATE The space below for CommisSion use CONDITIONS OF APPROVAL Samples required Mud log required D~recttonal Survey required I APl number []YES (~O []YES [~,1:~10 RYES I--lNG) 50- 0Z-~-2.0 -- Permit number Approval date ~J"// [~ 07/30/8]. I SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY _,' ~ .COMMISSIONER DATE 30. 1981 by order of the Commtss~on ASII Form 10-401 Submit mn trlphcate Rev 7-1-80 TVi~=,5930 TI'ID='7987 t WELL A1 Y = 5,971,467.25 " X = 540,'"178.17 LAT = 7~I°19'58.741'r 'I~ ~ ~ o , LONG =_ 1 49°40'26.679'' i ' ~!4' Al WELL 'A2 ~Y .5,971,346 82 .......... X = 540,178.32 " LAT = 70°19' 57.557'' ~ > < ~,. LONG = 149°40'26.693'' . ~1%I A~ -'.: WELL A3 Y = 5,971,227,31 ........ ~i~! X = 540,178.51 LAT = 70o19' 56. 381" ~1~I ~A~(~ ~: 4x)LONG = 149°40'26'707" WELL A Y 5,971,\106.83 > ! '1~ : X = 540,178,52 --mL LAT = 70°19'55. 196" I Iii AZ~(~ LONG = 149°40'26 725" I ~~l ~ WELL A5 Y = 5,970,986.86 ~ X = 5'40,178.61 ,ii __ __ ~!____~1'. A~(~....~ LAT = 70°19'54.016'' ) - ] LONG = 149o40'26.741'' / ~ WELL A6 Y = 5,970,866,70 ~10' ~A__~ ,, X = 540 178 71 " -' 1 LAm = 70°19' 52.834'' ~ ] " I LONG = 149°40'26.757' .... ! ,~o~' i r-. ....... ~A'/O) : WELL A7 Y = 5,970,746.73 ~ ' ~ X = 540,178.55 I ~ ? ~I. LAT = 70°19'51.654'' = . ,~ , LONG = 149o40' 26 781" I ~O7~ AIb(9_ . WP. eT ' ~ '~ ~-,~[;1~ WELL ~8 Y = '.5,970,626.78 I X 540, 1 78.59 i i LAT = = 70°19' 50. 475" i ~ ~ ~ /~ ' LO~IG = 149040'26.798' , '"'o 7 ' ~ .~.~ '.-"-~l/,.~, .t,. I HEREB~fq/~.TIFY THAT I AH -g/,"¢' "' · " '.,~¢~.' PROPERLY REGISTERED AND LICENSED -='~'-"' --"- "-';~' ".'-~',. TO PRACTI CE LAND SURVEY I NG IN , "-. < ' "'-', -', THE STATE OF ALASKA AND THAT / ~. ........ .,'T.'~. . TH IS PLAT REPRESENTS AN AS- ~ ~",."" ~, t..~.~.~', .:~ .,-;' THAT ALL DIMENSIONS AND OTHER ,.....",'..,'-~'.,. ~,'7,-~ ,,$ ,.~ DETAILS ARE CORRECT, .AS OF: ; : "',-" ...... .'"' AtlanticRichfieldCompany O DATE: DRAWING No: NORTH AMERICAN PRODUCING DIVISION ALASKA DISTRICT-'- KUPARUK iii FIEL~i:I.- ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3078 psig from RFT & pressure buildup date. This pressure @ 5830' SS = 5930' TVD will be balanced by 10.0 ppg mud wt. Normal drilling practice will call for a 10.5 ppg wt prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 156 psi over- balance. It is anticipated the surface BOPE equipment could be subjected to a max- imum of 2579 psi during drilling operations. Derivation assumes a gas kick at reservoir temperature and pressure (160°F, 3078 psi), gas migration to the surface w/o expansion, and cooling to 60OF summer cellar temperature. This is well below the 5000 psig BOPE working pressure and less than the 3000 psi weekly test pressure. Pi = pressure initial (reservoir) Ti = temperature initial (reservoir) Vi : volume initial (reservoir) = pressure final (surface) = temperature final (surface) Vf = volume final (surface) P_~ = PfVf_ Ti Tf Since Vi = Vf ie no expansion Pi = Pf ,. ~T Tf Then Pf : PiTf = (3093_ psia)(60°F + 460) Ti (160bF + 460) .i Pf = 2594 psia = 2579 psig Surface Div~ ~.r System 1. 16" Bradenhead. 2. 16" x 20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell nipple. 16" Conductor Maintenance & Operation ~ 1. Upon initial installation close annular I preventer and veri fy that bal 1 valves ! have opened properly. i 2. Close annular preventer and blow air ~__ through diverter lines every 12 hours. t 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not shut in well under any circumstances. ('~-5/8" 5000 PSI RSRRA BOP STACk' PIPE RRHS TBG HD 3 CSG RD 1. 16" Bradenhead 2. 16" 2000 PSI x 10" 3000 PSI casing head 3. 10" 3000 PSI tubing head 4. 10" 3000 PSI x 13-5/8" 5000 PSI adapter spool 5. 13-5/8" 5000 PSI 6. 13-5/8" 5000 PSI and kill lines 7. 13-5/8" 5000 PSI 8. 13-5/8" 5000 PSI 9. 13-5/8" 5000 PSI pipe rams drilling spool w/choke pipe rams bl i nd rams annular ACCUHULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUHULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAH OF THE REGULATOR. 3. OBSERVE TIME THEN CLOSE ALL UNITS SIMULTANE- OUSLY AND RECORD THE TIME AND PRESSURE REMAIN- ING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC 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 RE- TRACTED. PREDETE~,tINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR l0 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR l0 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR l0 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTRE~I PRESSURE TO ZERO PSI TO TEST VALVES. TEST R~IAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAbl 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 l0 MINUTES. BLEED TO ZERO PSI. ll. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUN- NING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 IIINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAHS 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 KOOHEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVE~ITER TEST FORM SIGN AND SEND TO DRILLING SUPER- VISOR. 16. PERFO~4 C~IPLETE BOPE TEST ONCE A WEEK A~ID FUNCTIONALLY OPERATE BOPE DAILY. B P Alaska Explo ratio n ! nc. ~55 Cal,[ornia SI,eet. $~n Francisco, Calilornia 94111. Telephone (4 ~5) 445-9211 October 8~ 1~80 A~O Oil & C~as ~any North Slope District P.O. Box 360 Anchorage, Al,~qka 99510 Attention' ~. S.R. Jaime Letter of Non-Objection ' AROD Oil '~nd C~s Le.~.se ADL 25651 Cent] emen' %%'e x~fer to your .letter of 23 ~3pta~oor ]980, in ~h4ch you ad%~ised us of your intention ~o dr~]l the £o]]owing development %%~11s' Bott~n Hole Ir~:ntion E-~ A-3 ~ A-6 [tho' b,~L, 26~o 'k'R~.q',, ~.~C. 16, T1LN, R]OE, UM 1S~O' ~;~, 1320' k%%L, Sec. 9, ~IN, R]OE, o~ S[ffL= '1320' ~, Sec. 6, ~.].N, R].~, 3R20' NSL, 1320' A%~, Sec. ] '?'~' ~, ]320' %%~, Sec. ?.' "~'rL. ]320' ~%L, Sec. 8, TI~.~, RI~, ~ ' '...' '~, ..~TqO' k~, ~c. 7, T1LN, RiOE, F.~ ~'. ~. ~o.~oz" "" ;c.," nn affected Lessee of Recmrd, hereby ~.'f.~ <~ .... , ...... ~ w: .~s ~]is ~tt, er of Non~ection is, ;'t';~,vc'-, %:;'" +" ,-'- ~- '-c~rs~snd lug that t~ly ~d ~nafide ~u~es to thu~c~e ~ne Kup, "- ',ervo~r ~n a fair ~md c~uit~le ~er ~ adopted by tho p~d," ,]volv~], ~l~ch *.hat said p~ics ~y aL~ee u~n the te~ of such unit~tion ~d their I'e~ctive rights ~d obligations therein, prior %o the r~nc~nt of ~y pr~ucution fr~ tho Kup~ ~~ir. c~' Mr. G. Abrnham, ~hio, SF Y¢~urs very truly, . :i:CLiV SOHIO ALASKA PETROLEUM COMPANY 100 PINE STREET, SAN FRANCISCO, CA 9411 1 October 17, 1980 ARCo Oil and Gas Company North Slope District P. O. Box 360 Anchorage, Alaska 99510 Attention: Mr. S. R. Jaime 'LAND OCT 27 ],980 .,, NOItTI-! .AI2_S KA. ARCo Oil and Gas Company, by letter of September 23, 1980, has requested a letter of non-objection by Sohio Alaska Petroleum to the drilling of the following development wells: Well No. Bottom Hole Location E-6 B-3 A-1 A-2 A-3 ~ A-6 A-7 500' NSL, 2640' EWL, Sec. 16, TllN, R10E, UM 1320' NSL, 1320' EWL, Sec. 9, TllN, R10E, UM 1320' SNL, 1320' WEL, Sec. 6, TllN, R10E, UM 1320' NSL, 1320' EWL, Sec. 6, TllN, R10E, UM 1320' SNL, 1320' WEL, Sec. 5, TllN, R10E, UM 1320' NSL, 1320' EWL, Sec. 8, TllN, R10E, UM 1320' NSL, 1320' EWL, Sec. 7, TllN, R10E, UM Please be advised that Sohio Alaska Petroleum Company does not object to the drilling of the proposed wells. For your information consent to E-6 was previously forwarded by Sohio to the Conservation Commission at the request of P. A. Van Dusen of your office. Sohio's concurrence to the drilling of the listed wells is with the understanding that ARCo, Sohio and other affected working interest owners will proceed in good faith toward an equitable unitization of the Kupar~ Reservoir and that such unitization is achieved prior to the commencement of production from the wells. GJA:c cc: P. Hardwick, BPAE P. Rumley, Anchorage Yours very truly, CHECK LIST FOR NEW WELL PERMITS Company ITEM APPROVE DATE ,,, (1) Fee (2) Loc thru 8) ' ' (3) Admin ~~ ~-'L~ (9 ~ thr:u 11) (4) _Casg ~~ 7.~o-g / -~i~ {6ru 20)' (5) BOPE ~-~- P~a-~/ [21 thru 24) 2. Is well to be located in a f e o 3. Is well located proper distance from pr p n '' ... 4. Is well located proper distance from other wells ........... . 5. Is sufficient undedicated acreage available in this pool.. ' 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 .............. ' 9~ 10. 11. 12. 13. 14. 15. 16. 17. i8. 19. 20. 21. 22. 23. 24. ( 6 ) Ad d:~,~ 7-'/0 ,-,~ ,,/ 2 5. Lease & Well No. _~.,b~'~t.. '~ YES NO REMARKS 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 ................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... · 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 .......................... Is a diverter system required ...................................... ~ Are necessary diagrams of diverter and BOP equipment attached ...... . ~_. Does BOPE have sufficient pressure rating'- Test to ~OO psig .~__ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: Geology: ~ Eng i~e.r ing: HWK ._j~x LC$ ~'B-EW ~ rev :/03/10/81 INITIAL ' GEo'. UN£T ON/OFF POOL CLASS STATUS AREA NO. 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 effort has been made to chronologically organize this category of information. LIS TAPE LVP 009,H05 VERIFICATION LISTING PAGE $, REEL HEADER SERVICE NAME :SERVIC DATE :81/10/27 ORIGIN : REEL NAME ~REEL ID CONTINUATION # PREVIOUS REEL COMMENTS :REEL COMMENTS ** TAPE HEADER SERVICE NAME ~SERVIC DATE ~81/10/27 ORIGIN :1070 TAPE NAME :62177 CONTINUATION # PREVIOUS TAPE COMMENTS :TAPE COMMENTS $$ FILE HEADER FILE NAME ~SERVIC,O0! SERVICE NAME VERSION # DATE : MAXIMUM LENGTH : 1024 FILE TYPE PREVIOUS FILE INFORMATION RECORDS MNEM CONTENTS CN WN FN RANG: TOWN: SECT: COUN: STAT: CTRY: MNEM ATLANTIC RICHFIELD CUMPANY A-6 KUPARUK IOE 5 NORTH SLOPE ALASKA CONTENTS PRES: NEDIT4F RECORD TYPE 047 UNIT TYPE CATE SIZE CODE 000 000 026 065 000 000 004 065 000 000 008 065 000 000 003 065 000 000 003 065 000 000 001 065 000 000 012 065 000 000 006 065 000 000 004 065 UNIT TYPE CATE SIZE CODE 000 000 007 065 LVP 009.H05 VERIFICATION LISTING RECORD TYPE 047 ** RECORD TYPE 047 ** DATA FORMAT ENTRY BbOCFS RECORD TgPE 4 8 9 0 SIZE REPR CODE 4 73 4 65 DATUM SPECIFICATION BLOCKS MNEM SERVICE ERVICE UNIT API AP1 ID ORDER # bOG TYPE DEPT SFbU IS IbD IbM IS GR SP DT NPHI IS GR FDN NCNb IS FCNb DRHO IS CAbI FDN RHOB NRAT IS FT 0 0 OHMM 0 0 OHMM 0 12 OHMM 0 0 GAP1 7 3! MV 7 US/F 0 52 PU 0 68 GAPI 42 31 0 0 34 G/C3 0 44 IN 42 28 G/C3 0 35 0 42 API API FILE CLASS MOD NO, 0 0 0 0 0 0 46 0 0 0 0 0 32 0 0 0 0 0 32 0 0 2 0 0 32 0 0 92 0 0 93 0 0 0 0 0 3 0 0 I 0 0 1 0 0 DATA DEPT GR GR CALI 8648,000 SFbU -99 -999.250 SP =99 109.500 NCNb 198 8,750 RHOB 9.250 9,250 9.000 2,293 IbD DT FCNL NRAT DEPT GR GR CALI 8600.000 70,063 112,938 11.609 SFbU 1.914 SP -6,219 DT NCNb 1984.000 FCNb RHOB 2,287 NRAT DEPT GR GR CAbI BSO0,O00 87 188 oo:.TS 10,344 SFbU 3,436 SP -7,441 DT NCNb 1996.000 FCNL RHOB 2.484 NRAT DEPT GR GR CAbI 8aO0.O00 49.813 64,188 7.973 SFbU 2~.625 IbD SP -3 ,688 DT NCNb 3240.000 FCNb RHOB 2,260 NRAT ENTRY 1 60 ,lIN 0 SIZE PROCESS SAMPLE bEVEL 4 0 4 0 1 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 1 4 0 1 4 0 4 0 -999,250 -999.250 481.500 4,008 1,603 92,000 504,750 3,914 2.885 92.750 588.000 3,252 16,906 93,563 1115.000 2,783 IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO PAGE REPR CODE 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 =999.250 49 072 0:000 1.742 0[0 3,072 Oo 7 18,875 31.299 0.014 bVP 009.M05 VERIFICATION LISTING , PAGE 3 DEPT GR CALI DEPT GR CALl DEPT CALI DEPT GR GR CALI DEPT GR CALl DEPT GR GR CALl DEPT GR GR CAbI DEPT GE CALI DEPT GR GR CAbI DEPT GR GR CALI DEPT GR GR CAbI 8300,000 SFLU 79.938 SP 83,125 NCNb 8.727 RHOB 8200 000 SFLU sP 81,625 NCNb 8.352 RHOB 8100.000 SFbU 67.000 SP 60.312 NCNb 9.570 RHOB 8000,000 SrbU 104.438 SP 121.750 NCNb 9.125 RHOB 7900.000 SFbU i08.688 SP 119.188 NCNb 10.258 RHOB 7800.000 SFbU 205.000 SP -999.250 NCNb -999,250 RHOB 7700.000 SFUU 223.750 SP -999,250 NCNb -999,250 RHOB 7600.000 SFLU 122.000 SP -999.250 NCNb -999.250 RHOB 7500 000 SFbU 90:125 SP -999.250 NCNb -999.250 RHOB 7400.000 8FLU 135,625 SP -999,250 NCNb -999,250 RHOB 7300.000 SFbU 115,563 SP -999,250 NCNb -999.250 RHOB 5 -17 2662 2 7 3~ 12 24 2 22 -6 4512 2 1 -0 1983 2 ! -15 1846 2 2 -14 999 3 -12 -999 -999 3 -12 -999 -999 6 4 -999 -999 3 5 -999 -999 2 9 -999 -999 .527 .938 .000 .438 .605 .180 .000 ,412 . 77 ,000 .506 .854 .932 ~000 436 .788 .055 .000 .410 .742 .859 o~50 , 50 .699 ,969 .250 .250 .043 .805 .250 .250 ,559 .570 .250 .250 .219 ,609 .250 .250 .262 ,461 ,250 .250 ILD DT FCNL NRAT DT FCNb NEAT DT FCNb NRAT IbD DT rCNb NRAT DT FCNb NRAT DT rCNb NEAT IbD DT FCNb NRAT DT FCNL NRAT DT FCNL NEAT ILD DT rCNb NRAT DT FCNL NRAT 4 88 923 2 6 8 1O57O 2 2248 2 2 102 518 3 1 2 -9 9 -999 999 -'999 3 108 -999 -999 3 99 -999 -999 2 115 -999 -999 1 110 :999 999 .801 ,750 ,000 ,813 .641 .563 .000 .764 ,000 ,059 ,035 .188 ,500 .832 .653 .563 ,000 ,781 .199 ,375 ,250 ,250 .154 .000 ,250 .250 .180 .750 .250 .250 ,842 ,375 ,250 ,250 ,660 .750 ,250 .250 ,250 .250 IbM NPHI DRHO IbM NPHZ DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPH! DRHO IbM DRHO IbM NPHI DRHO 4,973 30.811 -0.001 6 824 0.013 0,154 1,939 48.535 -0.005 1.746 45.996 0.034 2 311 999:250 3.084 -999.250 -999.250 3,195 .-999.250 999,250 4.020 .-999.250 999.250 2.709 -999. 1.807 999.250 -'999.250 LVP DEPT GR CALI DEPT GR CALl DEPT GR CALf DEPT GR CALI DEPT OR CAbI DEPT GR CALI DEPT CALf DEPT GR CALI DEPT OR CALl DEPT GR DEPT GR 009.H05 VERIFICATION 7200.000 SFLU 148,625 SP -999.250 NCNb -999.250 RHOB 7100,000 SFLU 142,875 SP -999.250 NCNb -999.250 RHOB 7000,000 SFLU 177.750 SP -999,250 NCNb '999,250 RHOB 6900,000 SFLU 171,625 SP -999.250 NCNb -999.250 RHOB 6800.000 SFLU 134.125 SP -999.250 NCNb -999,250 RHOB 6700.000 SFLU 185,750 SP -999,250 NCNb -999,250 RHOB 6bO0,O00 SFLU 104.438 SP .-999,250 NCNL 999,250 RHOB 6500,000 SFLU 99,125 '999.250 NCNb '999,250 RHOB 6400,000 8FLU 101.625 SP -999,250 NCNb -999.250 RHOB 6300,000 SFbU 102,000 -999.250 NCNb -999.250 RHOB 6200,000 SFLU 87,813 SP -999.250 NCNb LISTING . -999. -999. . -11. -999. -999. . 4, -999. -999. . -999, -999. . -999. '999, -11, -999. -999. . -999. -999. . -999. -999. 1 -999. '999. . -999. -999. . 885 949 250 250 480 055 250 250 846 25O 582 457 25O 25O 662 438 250 25O 180 320 25O 25O 066 969 250 250 045 119 25O 250 127 445 250 25O 5O4 710 25O 25O !82 090 250 DT FCNb NRAT DT FCNL NRAT ILD DT FCNL NRAT DT FCNb NRAT ILD DT FCNL NRAT DT rCNb NRAT ILD FCNL NRAT DT FCNL NRAT ILD DT FCNb NRAT ILD DT FCNL NRAT DT FCNL 2.957 - .250 -999,250 !,279 1 ,563 '9 ,250 '999,250 2.293 105,563 999~250 2,508 101,553 -999.250 -999.250 1,980 - ,250 -999.250 106. -999,250 -999,250 2.318 -999, 0 -999,250 ~2,359 10 .000 -999.250 -999,250 2 3 -999,250 -999,250 2,572 10 .563 -999,250 -999.250 2.436 104.750 -999,250 IbM NPH! DRHO NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPhl DRHO PAGE 2 904 999i250 :999 250 9,297 .25o 999.250 2 203 :999:250 999,250 99~'480 -.250 -999.250 2.199 9,250 3,736 -999.250 -999.250 2,309 -999.250 -999.250 2.355 -999.250 -999,250 2.277 -999.250 -999.250 2.553 -gg9.250 -999,250 2,400 -999,250 -999.250 LVP 009,H05 VERIFICATfON LISTING PAGE 5 CALl DEPT GR CALI DEPT GR GR CALl DEPT GR GR CALI DEPT GR CALI DEPT CALI DEPT GR CALf GR GR CALI DEPT GR CALl DEPT GR GR CALI DEPT GR GR CALl DEPT GR -999,250 RHOB 6100,000 SFbU 99.312 SP -999,250 NCNb -999,250 RHOB 6000,000 &FLU 75,438 SP -999,250 NCNb -999.250 RHOB 5900 000 SFLU 83:063 sP -999,250 NCNb -999,250 RHOB 5800.000 SFLU -9 .250 NCNb -999,250 RHOB 0 000 8FLU 5600.000 8FbU 89.625 SP -999.250 NCNb -999.250 RHOB 5500.000 SFLU 98.063 SP -999 250 NCNb -999:250 RHOB 5400.000 SFbU 105,43B SP -999,250 NCNb -999.250 RHOB 5300.000 SFLU 77.063 SP -999.250 NCNb -999.250 RHOB 5200,000 SFLU 80 813 SP -999:250 NCNb -999,250 RHOB 5100.000 SFLU 93,750 SP -999 2 -5 -999 -999 2 -4 -999 -999 2 -6 -999 -999 2 -5 -999 -999 2 -6 '999 '999 2 '5 '999 '999 2 '8 2 -6 -999 -999 3 -9 -999 -999 7 -8 -999 -999 3 -8 .250 504 '418 . ,250 .250 .412 .547 25O :250 836 :805 .250 ,250 .352 .223 .250 .250 .479 .117 ,250 .250 .563 .105 ,250 .250 ,563 .469 .250 .250 .846 .949 .250 .250 ,381 ,203 ,250 ,250 .578 :250 .250 .254 .359 NRAT DT rCNb NRAT DT NRA? DT FCNb NRAT IbD DT FCNb NRAT ILD DT FCNL NRA? lbo DT FCNb NRAT ILD DT rCNb NRAT lED FCNb NRAT IbD D~ rCNb NRAT DT FCNb NRAT DT -999, 1 -999, -999, t 100 -999: -999. 993* -999. -999. 1 99, -999, -999, 1 107. -999. -999. . 104 -999. . 102, 9 9, . -999. . 107, -999, -999, , 99, -999. -999, , 114, 250 807 563 250 250 705 188 25O 250 277 563 250 250 559 750 250 250 676 750 250 250 018 563 250 250 943 000 25O 250 949 375 250 250 9 0 250 25O 125 375 250 250 689 563 IbM NPHI DRHO NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO NPHI DRHO ZbM NPHI DRHO NPH! DRHO NPHI DRHO IbM NPH! DRHO IbM NPHI DRHO NPHI 2.764 999.250 2,656 999,250 :999.250 3 .1.91 999 250 2.551 999,250 -"999.250 2 613 -999,2,5O 2,928 -999,250 -999,250 2.980 .~999,250 999,250 2 873 :999:250 999.250 .645 .25o 999,250 6 469 :9 i25o 999 250 3,523 -999.250 LVP 009.h05 GR CALl DEPT GR GR CALl DEPT GR GR CALl DEPT GR GR CALl DEPT GE GR CALl DEPT GR GR CALI DEPT GR GR CAbI DEPT GR CALI DEPT GR GR CALl DEPT GR CALl DEPT GR GR CALl DEPT VERIFICATION LISTING 999.250 NCNb -'999,250 RHOB -999.250 -999.250 5000,000 SFLU 94.563 SP 111.125 NCNb 8,750 RHOB 1.664 383 2,285 4900.000 SFLU 107,813 109.688 NCNb 13.055 RHOB 2.!21 -8, 19 2176, O0 2.264 4800.000 SFbU 85,250 SP 90.000 NCNb 13.039 RHOB 2.895 2.270 4700,000 SFLU 75,500 SP 78,250 NCNb 13.445 RHOB 5,~20 -16. 19 2456 000 4600,000 SFLU 90,938 SP 97.938 NCNb 12,383 RHOB 7.559 ,984 ; g.ooo 2.268 4500.000 8FLU 91.000 SP 88.250 NCNb 13.672 RHOB 3.~62 -11. 84 20628.000 ,221 4400,000 SFLU 81.g50 SP 87. O0 NCNb 13.055 RHOB 3.182 2100, 2,229 4300,000 SFLU 80,125 SP 86,188 NCNb 14,406 RHOB 4.238 -18.203 2300.000 2.293 4200.000 SFLU 69.250 $P 66.500 NCNb 13.188 RHOB 7,176 -18.563 2270,000 2,314 4100,000 $FbU 61.125 SP 64.500 NCNb 10.273 RHOB 8.992 -40.656 2366.000 2.168 4000.000 SFLU 19,813 FCNL NRAT DT FCNL NRAT ILD DT FCNb NEAT DT FCNL NRAT DT FCNL NEAT DT FCNL NRA? ILD DT FCNL NRAT ILD DT FCNb NEAT DT FCNL NEAT D? FCNL NRAT IbD DT FCNb NEAT ILD '999,250 '999,250 2.482 116,750 54~,000 ,809 3,580 117,188 610,500 3,525 ,000 9 ,750 647,000 3,766 0 663.500 3.496 6.953 7 .000 2,996 4,520 116.563 57~,500 ,445 4,035 8 3.498 , O0 625,500 3,594 7.840 .000 3,580 7.734 124,563 716,500 3.443 18.016 DRHO IbM NPHI DRHO IbM NPHI DRHO NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO NPHI DRHO NPHI DRHO Ibm PAGE -999.250 2,189 44.531 0,026 .385 3 .600 0.032 3.885 43.896 0.022 6.031 38.867 0.047 6 453 0.037 0,045 3.680 4,801 40.186 0,039 7,648 40.527 0.024 7.609 39.844 0.004 17.906 LVP GR GR CALI DEPT CALl DEPT GR GR CALI DEPT CALI DEPT GR GR CALl DEPT GR CALl DEPT CALI DEPT GR GR CALI DEPT GR CALf DEPT GR CALI DEPT CALI oOg,H05 VERIFICATION 47.156 SP 52.844 NCNb 10.891 RHOB 3900,000 &FLU 84.938 SP 91,500 NCNb 21,781 RHOB 3800,000 SFLU 66.625 SP 65,938 NCNb 16,156 RHOB 3700.000 SFLU 37,188 SP 36.406 NCNb 14.266 RHOB 3600.000 SFLU 45,281 SP 57,094 NCNb 12.305 RHOB 3500,000 SFLU 83,938 SP 83.750 NCNb 13,391 RHOB 3400.000 SFLU 66,000 67,125 NCNL 12.945 RHOB 3300,000 SFLU 57.b56 SP 58,094 NCNb 10,789 RHOB 3200,000 SFLU 63.281 SP 64.625 NCNb 11,188 RHOB 3100,000 SFLU 63,250 SP 67.688 NCNb 13,148 RHOB 3000,000 SFbU 49.188 SP 47.250 NCNb 11,789 RHOB 5ISTING 2~39 781 :ooo 2.064 7,988 -24.359 2552.000 2,203 6,180 8.000 2.229 il.594 = ,156 1729.000 2.109 8,430 =26.891 2042,000 2,172 7,55t -1~,70 197~,000 ,1~I 10,578 2.148 . 84 2~42,000 10.180 -23 781 282:ooo 2.168 10,953 -22.828 000 11 945 2616.000 2.064 DT FCNb NRAT ILD DT FCNb NRAT ILD DT FCNb NRAT DT FCNb NRAT DT FCNb NRAT DT FCNL NRAT DT FCNb NRAT ILD DT FCNb NRAT IbD DT FCNb NRAT DT FCNL NRAT DT FCNL NRAT 140 637 3 8 124 775 3 7 124 593 3 430 3 8 134 567 3 10 124 466 4 16 128 6O5 3 7O5 3 tl 127 553 3 12 569 3 13 {.3O 689 3 ,500 ,500 ,64! ,688 ,563 ,500 ,332 ,918 ,000 ,500 ,590 .078 ,500 ,250 ,928 ,492 ,750 ,500 ,584 ,125 ,188 .000 ,105 .3~5 .500 ,906 · $0 ,000 ,426 ,109 ,750 .500 .938 ,445 ,375 ,500 .873 ,758 ,500 .500 ,537 NPHI DRHO IbM NPHZ DRHO IbM NPHI DRHO IbM NPHI DRHO NPH! DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPH! DRHO PAGE 42.676 -0.004 8,352 31.836 0.065 7,348 307 3~*038 . 11,758 4 ,240 0.001 7,996 40.967 0,015 O55 4 : o2 0,02! 16,391 46.484 -0,005 . 7 -0.002 10,086 4~,900 .005 11.625 45,801 0.002 13,180 40.3(~I -0.0 9 LVP 009,H05 VERIFICATION LISTING DEPT 2900.000 SFLU 10,914 ILD 12.242 IbM GR 46.781 SP -18,078 DT 123,000 NPHI GR 59.625 NCNb 2610,000 FCNb 726,000 DRHO CALI 13.070 RHOE 2,11! NRAT 3,297 DEPT 2800.000 SFLU 12.531 IbD GR 40.000 SP -8.922 DT GR 44,219 NCNb 2396.000 FCNL CALl 14.828 RHOB 2.074 NRAT DEPT 2775.500 SFLU -999.250 ILD GR -999,250 SP -999.250 DT GR 42.312 NCNb 1425.000 FCNL C~bI 10.250 RHOB 2.033 NRAT ** FILE TRAILER FILE NAME :SERVIC.O01 SERVICE NAME VERSION # : DATE : MAXIMUM LENGTH I 1024 FILE TYPE NEXT FILE NAME ** TAPE TRAILER SERVICE NAME :$ERVIC DATE :81/10/27 ORIGIN 11070 TAPE NAME 162177 CONTINUATION # :01 NEXT TAPE NAME COMMENTS :TAPE COMMENTS ** REEL TRAILER SERVICE NAME :SERVIC DATE :81/10/27 ORIGIN : REEL NAME :REEL ID CONTINUATION # NEXT REEL NAME COMMENTS :REEL COMMENTS 28,859 IbM 140,000 NPHI 629.000 DRHO 3.559 :999,250 IbM 999,250 NPHI 315,750 DRHO 4.137 PAGE 12.031 ,003 13.766 39.355 -0.023 250 -0.564 LVP OlO,H02 VERIFICATION LISTING SERVICE NAME :SERVIC DATE :8]/06/11 ORIGEN : REEL NAME :REEL 1P CONTINUATION # :01 PREVIOUS REEL : ~OMMEN?$ :REEL COMMENTS #~ YAPE HEADER #* SERVICE NAME :SERVIC DATE :83/0§/17 ORIGIN :6217 YAPE NAME ~ CONIINUATIDN # ~01 P~EVIOUS ~APE : ~OMMENTS :TAPE COMMENTS ~ FIbE HEADER ~ FIbE NAME {$ERV]C,301 SERVICE NAME : VERSION# : DATE : MAXi~U~ LENGTH : 1024 FILE TYPE : PREVIOUS FIbE = ~# INFORMATION RECORDS MNEM 2N : WN : F',{ : RANG: SECT: CONTENTS A-$ ..... 000 000 K U PAR U K ~,::::.: ::. '? :: :::J~i,:':. ::~ :/.::': :: :!:.:: "':::. ':::. ::: O00:: O00 10~ 1 i N .:: ::: <:: ~i:: ::: ::; :? :::::; :: : ::: ::..: 7:0:O:~: O OO' 0~0 :000 N O R'Y H ~ bOP E :::::. ::: :::: .:::: :::' ::: ::':~ :? O:O.000 .... ~0::0 0 O: ALASKA : ::: OeO O O O :. :: '0 2 065 )1. ;}: 0:6::~ 06 O65 00~ 065: : < · bYP OlO,H02 VERIF'ICATiO~ LISTING PAG~ ,]38 # 10707~,62177 RUN #1, bO~GED 1 BOTTOM ~OG INTERVAL YDP bOG INTERVAL CASING-LOGGeR B,IT SIZE ~YPE HOLE FLUID DENSITY VISCOSITY PH FbUtD bOSS RM ~ MEAS, TEMP, RMF ~ M~AS. TBMP, RM: ~ MEAS, TEMP, RM ~ BHT MATRIX SANDSTONE 2791 FT," 2::7'91: 8.75 iN, X:C'::,: ~O~,, 10.4 LB/C 9.5 2.88 bYP 010oH02 VERIFICATION LISTING .:.:::' :::::::::::::::::::::::: ?J?iL: ::~:.::' ':~:;...:;: :i.~::.:::: .:.:::?:::' .': '::~":: ':::: .:':' : ., :: :;... ............. ::~:...::<:;:..: :::::::::::::::::::::::::::::::::: :.:::" ::~.: :'::::....::::~::. ::]!:::. f::.:::~. D JAb [NDUCTIO~ SPHERICALLY FOCU~[D LO. (DIL] BOREHO~E CDM~ G~:..'::': ';: ::"~ . FoRMA[ION D~NSX'T~ CO~'PE~SA'TED G'DG (FDC) GAMMA RAY bOG (GD) ~.:::. ; : .:.: ::~::::..: ::~: .'.~ :~:.:. :~ :: ~:'~ ~ · ~-DATA FORMAT RECORD ENTRY BbDCK$ T bVP OIO,H02 VgRIFICATION ID ORDER DBPT IbM ILD DIL SP GR DT BHC GR B~C NPHI FDN DRHD FDN EHDB FDN NCNL FDN FCNb FDN DALI FDN GR FDN NRAT FDN RNRA ## DA~A #~ DBP? SP NPH! FCNL RNRA 8648. -999 481. 4, 0000 2500 0723 5000 1308 SP NPHI FCNB RiRA 8600. 47. 504, 4, 0000 2187 O0 0030 DEP~ SP NPH! RNRA 8500, 588, 3, 0000 4414 3281 0000 2807 DEPI SP NPHI FCNL RNRA 8400, .-34, 1067, 2. 0000 6875 O0 9421 DEP~ SP NPHI 8~00, 17. 0000 9375 8105 LISTING BbOCK~ [JN1T API FT OHMH MV GAP ! US/F GAP! PO 0 0 0 G/C3~ · 4Z G/C 42 APl R RHO AL1 SFbU GR DRHO CALl GR CALl SFbU GR DRHU CALl SFLU GR DRHO -999'2500 DT O:i*:~ ,:::::: 8;7 500 Gi . 9;'81 25 DT ....................93'?:25625 8';'03] 3 G'~ 5'5::; 8 ~'37' 79;93'7'5 D'T 7500 -o. OOl ~ ~::O~ ::::~, :2,.4 3:75 PAGE t I:~: I coo. i,; .::: : 6~8.. ..: '9:~9, 2 500 -9 g O'; 2 SOO i':989,00:00 :.::I ,.b025 : 7:0 ;0625 19 ~4:..00:00 .... ':'3 9 i"41 1.9 ~b.,: ..... 3; 2520 l:b:::, 90~ 2 317:8,00 O0 2; 8262 79; 9:37S~ 26 62, O000:: bVP 010.H02 VERi~/CA~iOh LISTI~S FCNb DEP~ SP NPHI FCNb RNRA DEPT SP NPH1 RNRA DEP~ NPH1 RNRA DEP~ SP NPHI RNRA NP~I RNRA DEPt SP NPHI RNRA DEPT SP NPH1 RNRA DEP~ SP NPH! RNRA DEP~ 923,0000 CALl 2,B934 8200.0000 SFLU '~2,17g? GR 30.5J76 DRHO 1050,0000 CAbI 2.8494 8100.0000 SFLU -6,9766 GR I 0645 DRHU o. :oooo 1.94~6 8000,0000 SFL, U 8.5 DRHU 518 5000 CAbI 3:854 7900.0000 SFLU o15,0547 OR 45.9961 ORHO 468.0000 CAb1 3,8539 7800.0000 SFL, U · ,14.8594 GR -999,2500 ORHU 7700,0000 SFGU '12.9687 G~ -999.2500 DRHO °999 2'500 CAb! -999:2500 7600.0000 SFLU '12,8047 GR -999.2500 DRHO -999.2500 CAbl -999.2500 7500,0300 SFLU 4 703 OR -999,~500 CAbi '999 , 500 400. oooo -999 500 ORHO 8,35i6 <' :GE :'~.. ~ 81, ~2i50 l I,D CNL NRAT 0.]' 8 'A~OB 2;51'3~ NCNL 91:,:656.3 ..GBi.,,,:: ?1:i'i~62!50 ,NRA ="999';:25'~00 RROB :?::::: ::"~9'99"~; 26~0'0:: NCN L .999 ;':2:50:0 R'HDB 999::~ 2:500 NCNL 999 ;2500 R HOB 999:'; 2'5'0'0 N CN ~L -999'::,.:i25,0~0~ ~::R .:.;;- :i~: 0 NRA~ 99; 2 500 'PRO:B .... ::: ::99q:;' 2:500 NCNL ,;PAGE` 2,81:25 6.6406 7~:2,2'500 302~:; 0000 6. 1094 6.7, '00:0:0 '. 390'2'; 00'00 ::1,90'~ 2 2.0352' 10~4,4.37 98'3; 0000 6533 4::'6; 000 - 9 99; 2500 ': -:9 ~9 ~ ~5oo :: :3. is 4'j' .2:~:~3:;. 7:5:::00 -0%9::, 250o ,:::.: .12.2:, 00::00 ~ .9 99; 25'00' :' ~0,12::5:0 -9q9;2 0 -99.v, ~500 ~2.6 6'0 2 t: 35,6250 99:9; 2500 b~P OI0.H02 VER]FICATIUN FCNL -999.2500 CAb! RNRA -999,2500 DEPT 7300,0000 SFLO SP 9,4609 GR NPHI :999,2500 DRHO FCNL 999.2500 CAbl RNRA -999.2500 DEPT 7200 0300 SFLU $P 1; 9492 GR NPHI 999.2500 ORHU FC~NL ~999.2500 CAb! RNRA '999.2500 DEPT 7100.0000 SFbU BP -11,0547 GR NPHI -999,2500 ORHO F:NL -999,2500 CADI RNRA -999.2500 DEPT 7000,0000 SFLU Sp 4.7773 GR NPHI -999.2500 ORHO FCNL -999.2500 C~I RNRA '999.2500 DEP~ 6900.0000 SFbU SP '2,4570 GR NPH1 :999,2500 DRHU FCNb 999,2500 RNRA -999.2500 OgPl 6800.0000 SFbO 5P -4,4375 GR NPSI -999.2500 ORHO FCNL -999,2500 CAbl RNRA -999.2500 DEP~ 6700,0000 SFbU SP -11.3203 GR NP,I 999 2500 DRHO 999,2500 CAbI RNRA -999.2500 DEPT 66D0,0000 SFLU SP -2. 9687 GR NPH1 999,2500 DRHO F~NL :999.2500 'CALl RNRA -999.2500 DEPT 6500,0000 SFLU SP 2,1191 OR NPHI -9~9.2500 ORHO LISTING -999 ;2500 ~HOB ...... 999';:":~"5'0 0 NCNI, -999;2500 ~H:OB 9:9:9 ~;2:5 0::0 ::'GR :~:: ".':9 2500: ,NRAT -999~500 RHOB ~9:99"~ ~ S:O:O NCNt. ! 77:,)7: ::, -999'2500 R~OB ~999:;2500 185::':: :::::::::::::::::::::::::: ::..,::::. :::.. -999; 250'0 ......g'HOB .............. 99g~; 2'5~0'0 NCNL .: ~ :: . ILD N'CNL PAGE 6 5625 5oo '2. 957'0 -148,6 .99 25'00 999,25'00 I &2, 87:!50 -ggg; 2500 ":' 2.29:30 77.7500 .'999', 2500 500: '9 99; 2 50'0 ,,:9 ~'9,, ~:5,0,0 2,3184 4375 ': 2500 9:9.~ 1250 -999; 250:0 :, bVP 010,H02 VgRIFICATiDN FCNb -999,2500 RNRA -'999.2500 DEPT 6400.0000 SFLU SP °4,4453 O~ NPHI '999,2500 ORHO FCNb '999.2500 CAbI RNRA '999,2500 DEPT 6300.0D00 sP -1,71oo GR NPHI -'999,2500 DRHO FDN[., -999,2500 CAb1 RNRA '999,2500 ~EPT b200,O000 SFLU SP '4,0898 GR NPH1 '999.2500 DRHO FCNb '999.2500 :ALI RNRA -999,2500 DEPT 6100.ODO0 SFLU SP '5,4180 GE NPHI -999,2500 DRHO FCNL '999,2500 CAL! RNRA '999,2500 DEPT 6000 0000 SFLO SP '4:5469 GR NPHI -999,2500 DRHO F~Nb -999.~500 C'AbI RNRA -999. 500 NPHI .,.99 500 DRHO FCNb -999, 500 :Ab-I RNRA -999,22500 DEPT 5800.0000 SFLU SP ~5,~227 GR NPHI '9~9. 500 DRHO F~NL '999,2500 CAbl RNRA '999,2500 DEPT 5700,0000 SFLU SP '6,~172 GR NPHI -999, 500 DRHO FCNb -999,2500 CAb! RNRA -999,2500 DEPT 5600.0000 SFLU SP '5,1055 OR NPHi '999,2500 DRHO LISTING '9.99:,2500 :G.~. ':. :: "..:.'99.91': 0 N~A,T 999 ;2500 R~OB 999:, 25:00 ::99"9~:2:50'0 NC N I. :999:~::2 ~ 0 N ~ a T -999 ;2500 ~OB .......... 9'9g:, 250 0 N'C~ L -9'99; 2500 ~HO'B :'ggg"~' 2 500 NCNI. ~:999:"::.2:$00 .:: :::G~:~::::.: ",:: ::: .:::::!!19 N:~A::~ - 999; 2500 '~'OS 9gg;250~0 -999',~2 ::"' :::: ;':: .'.:. ::::.: ::":~9 .2500 :NRAT ?:99}:-:}:}00: ,::: ::!:' .':.::: :.,::::!!~: 2::}~0::0. :. 'N:H4T 2,2832 ! O 1., 6250 999; 2500 999,2500 ::2.5723 102.00:00 -99g; 2500 -999,.2500 2.4355 8V,812~ -999;25:00 9. ~ 50:0 · :::2,8066 99. 3125 -909225:00 -999., 25'00 2. ? 05 - g gg ;250'0 ::::3.2773 8 3, .0'625 - 25'0'0 :%3.01. '7:6' 89,6 250 -9g:9; 2500 DVP OlO,H02 VERIFICATION FCNb °999,2500 CAb1 RNRA -999.2500 DEP~ 5500,0000 SFbU FCNb '999,2500 CAb! RNRA '999,2500 OgPT 5400.0D00 SFbO SP '7,1~75 GR NPHI '999,2500 DRHO FC~L -999,2500 CAbl RNRA -999,2500 DE;PT 5300.0000 SFbU SP -II,4766 OR NPHI =999 2500 DRHO FCN5 -999~2500 CAbI RNRA -999,2500 DEPT 5200,OOO0 SFLO SP o10,6652 OR NPHI -999~2500 DRH0 FCNL -999.2500 CAbI RNRA -999,2500 DgPr 5100.0000 SFLU SP °8,8013 GR NPHI -999.2500 ORHO FCNL '999,2500 CAb1 RNRA '999,2500 DEPT 5000.0000 SFLU NPHI , { 3 ORHO 000 CAbl FCNL 541.~671 R~RA 3, DEPT 4900.0000 SFLU SP 'I1,5796 GR NPHI 39,5996 0RH0 FCNb 610.5000 Cibl RNRA ' 3,5698 DEPT 4800.0000 SFLU NPHI 4 . 44 DRH0 FCNb 5~5,0000 CAbl RqRA 3,7140 OEPT 4700.0000 SFLU SP '16.6922 GR NPHI ]8.8672 DRHO LISTING -999 ~,.:~00: '= :': i~.: :. ::= = ~.99.9!~.~,.:2500 NRAT 98 ~'0.625.~;:. :?D:T~':~::~:; :: ::' O00:0 G~ :999;'2500 ~HOB ~.9-104:'999 ~ 25795~00 .~. ~OT':J~::: .: =99 g'22500 ~C ~ L - 9'99 ;'2500 ~HOB ~gg'q" 2 $00 :N:C N [, .999 . 2500 RHOG ~:'99:'9": 2500 NCNI. :99 ~:.::{:<:' :.::: '~:~: :~:..::,~ ~O0:: NR~T :999;"~5oo ~o'~ "' ::'99'9"2:~s~oo ~C~L :?: 0 ';03"t7 R HOB 2:: 2637 ..... 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NRA T 0 ;'6 f'] "7 ~ROB 2;179? 0 ~"0 0 i 'D ...... ~ H O"B 2'; I8'75 N:C Ni ' O','D I 07 ......... AH'OB 2::~ 0625 NCNL Jl-5:23~:'.:: :~:..: ':::,,.,:'~ ' ::::: :.:::, :.:::, ~2~ ?:` ":: ::' PAGB 988 10 i:].1495 1729:' 0000 3,92'7.7 · 8 , 5 ]5'8 219'2- O 000 80,64:2:6 1~O22000'o ,:4,4023 2-1 9'2:::2 0OO0 ======:===9=====:=?: 2 i 9:42000 0 .... 2198:2000 O t3, ~:7:, ~ 1,5=0 2 J 7'~::20000 :'.3:, ~7::5:::0 bVP 0i0,H02 YERIP'ICAT[O~ bls~ING FCN5 ?25.5000 CALl RgRA 3,5630 DEP~ 2~00,0000 SFLI! SP 10.1606 OR NPHI 41,4063 DRHO FCNL 601,0000 CALl RNRA 3,7824 DEPT 2762,0000 SFLU Sp °8,6508 GR NPH! '999o2500 DRHU FCNL -999,2500 CALl RNRA -999,2500 ,# FILE TRAILER FILE NAME :SERVIC.O01 SERVICE NAME VERSION # : DATE l MAXIMUM LENGTH : 1024 FILE TYPE NEXT FILE NAME : ~# TAPB TRAILER SERVICE NAME :SERVIC DATE {83/06/17 ORIGIN {6217 ~kPE NAME CONTINUATION # :01 NEXT TAPE NAME ~OMMENTS :TAPE COMMENTS .... ~';064:5 ~CNL SERVICE NAME :$ERVIC ORIGIN : R g EL N A M E $ R gE b I O '. 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