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Home My WebLink About190-123 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 3G-10 50-103-20134-00 190084_3G-10_IPROF_08Jan2023 3G-13 50-103-20137-00 190116_3G-13_Puncher_03Oct2022 3G-20 50-103-20141-00 190123_3G-20_IPROF_28Apr2022 3H-35 50-103-20805-00 219064_3H-35_IPROF_03Aug2023 3I-11A 50-029-21932-01 210074_3I-11A_SBHPS-PLUG_25Jul2023 3M-05 50-029-21706-00 187025_3M-05_TBG_09Jan2022 3O-04 50-029-21826-00 188062_3O-04_CBL Post BiSN_24Aug2023 188062_3O-04_LDL_04Jan2022 3O-06 50-029-21824-00 188060_3O-06_CBL Pre-BiSN_24Aug23 3R-18 50-029-22249-00 192017_3R-18_LDL_21Feb2022 192017_3R-18_PressTemp_22Mar2022 3S-03 50-103-20458-00 203091_3S-03_IBC-CBL_04Sep2023 203091_3S-03_MechCut_14Jul2023 9of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38395 T38396 T38397 T38398 T38399 T38400 T38401 T38402 T38403 T38404 2/29/2024 3G-20 50-103-20141-00 190123_3G-20_IPROF_28Apr2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 12:12:37 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, September 20, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3G-20 KUPARUK RIV UNIT 3G-20 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/20/2023 3G-20 50-103-20141-00-00 190-123-0 G SPT 5796 1901230 1500 3282 3283 3284 3284 190 190 190 190 4YRTST P Adam Earl 8/1/2023 MIT IA 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 3G-20 Inspection Date: Tubing OA Packer Depth 1080 1810 1800 1800IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230802195119 BBL Pumped:0.9 BBL Returned:0.8 Wednesday, September 20, 2023 Page 1 of 1           MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, January 3, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3G-20 KUPARUK RIV UNIT 3G-20 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/03/2023 3G-20 50-103-20141-00-00 190-123-0 W SPT 5796 1901230 1500 2787 2787 2789 2789 310 440 440 440 OTHER P Austin McLeod 11/20/2022 MITIA post coil tubing lateral drilling 30 MinPretest Initial 15 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 3G-20 Inspection Date: Tubing OA Packer Depth 660 2010 1970 1970IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM221121142300 BBL Pumped:1.4 BBL Returned:1.4 Tuesday, January 3, 2023 Page 1 of 1 By Samantha Carlisle at 2:11 pm, Sep 26, 2022 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-07-04_20218_KRU_3G-20_StaticSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 20218 KRU 3G-120 50-103-20141-00 Static Survey 04-Jul-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:190-123 T36804 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.19 09:11:06 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-07-04_20218_KRU_3G-20_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 20218 KRU 3G-20 50-103-20141-00 Caliper Survey w/ Log Data 04-Jul-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:190-123 T36804 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.19 09:14:06 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-12_21075_KRU_3G-02_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21075 KRU 3G-02 50-103-20141-00 Caliper Survey w/ Log Data 12-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:190-123 T36665 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.27 09:49:05 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor 2efl (o�15�7,01q FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 9, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3G-20 KUPARUK RIV UNIT 3G-20 Sre: Inspector Reviewed By: P.I. Suprvzuic— Comm Well Name KUPARUK RIV UNIT 3G-20 API Well Number 50-103-20141-00-00 Inspector Name: Jeff Jones Permit Number: 190-123-0 Inspection Date: 9/16/2019 - Insp Num: mitJJ 191009075940 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 3G-2o Type Inj w 'TVD 5796 ` Tubing 1832 1837 1835 1836 1901230 ' Type Test sPT rte�rval Test psi 1500 - IA 780 2600 2550 - 2540 ' BBL z.] BBL Returned: z OA 340 - 500 slo 4r P Notes: I well inspected, no exceptions noted. Wednesday, October 9, 2019 Page I of 1 IGut 5 q- ZG Pb 1'7017-30 Regg, James B (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Saturday, August 17, 2019 10:11 AM To: Wallace, Chris D (CED); Brooks, Phoebe L (CED); Regg, James B (CED); DOA AOGCC Prudhoe Bay Cc: NSK DHD Field Supervisor fi� l��Zr/I' Subject: KRU 3G Pad SI MIT's Attachments: MIT KRU 3G PAD SI TESTS 08-15-19.xlsx 0 Please see the attached MIT test forms for shut in wells 3G-15, 3G-20, & 3G-23 in Kuparuk on 3G pad. Sincerely, Sara) Ca.rUg& / 2acheL Kau tk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 ( n2549@cop,com Cell: 907-331-7514 1 sara.e.carlisle@col2.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.repnla)alaska.aov: AOGCCInsoectors(cIxalaska.aov: Phoebe. brooks(MalaskaAOV OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc Kuparuk / KRU / 3G Pad Duffy / Caudle chris wallace(Malaska.aov Well 3G-16 INTERVAL Codes Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1= Initial Test P=P... PTD 1901210 TyH1njN 4=Four Year Cycle Tubing 1560 1560 1560 1560 I = Industrial Wastewater Type Test P Packer TVD 5727 BBL2.8 1 IA 200 3300 3260 3250 Interval V Test psi 3000 1 BBL Return 1 2.7 OA 20 20 20 20 Result P Notes: MITIA to maximum anticipated injection pressure per A10 2C011 Well 3G20 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1901230 Type Inj N Tubing 1245 - 1260 '1245 1245 - Type Test P Packer TVD 5796 BBL Pump 2.0 IA280 2225 2160 2160 Interval 4 Test psi 1500 BBL Retum 2.0 - OA 0 0 - 0 0 Result P Notes: Well 3G-23 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1901320 Type Inj N Tubing 1810 1810 1810 1810 Type Test P Packer TVD 5745 BBL Pump 3.6 IA 260 3300 3195 3175 Interval V Test psi 3000 BBL Return 3.6 OA 150 575 600 600 Result P Notes: MITIA to maximum anticipated injection pressure per A102C.004 Well 3G-23 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1901320 Type Inj N Tubing 7870 1810 1810 1810 Type Test P Packer TVD 5745 BBL Pump 1.0 IA 260 260 260 260 Interval V Test psi 1800 BBL Return 1.0 OA 150 2000 1960 1940 Result P Notes: MITOA to 1800 psi per AIO 2C.004 Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: INTERVAL Codes Result Codes TYPE INJ Godes TYPE TEST Codes W = Water P = Pressure Test 1= Initial Test P=P... G=Gas O= Other(descdbe in Notes) 4=Four Year Cycle F=Fall S=Slung V= Required by Variance 1=Inconclusive I = Industrial Wastewater O = Other (describe In notes) N = Not Injecting Form 10-426 (Revised 01/2017) 2019-0815 MIT KRU_3G-usJ 3wel1s � r ! • a c-i � cE N K f0 t aW�W • > E VI L �o O 0 0 v O (J (1 Q N W CD 0 a--� /1—' aY C 9 . . . . . . . r r r r r N U N +O-' > CL v c c >. LOJ • 73 L Q ❑ L MS Q Q p Q n n n n n n n n n n n n * v p Q m d r > T i, i, >, i, i, >.o co co co co co co co co c c c c + - a o W C u 4J N Z 2 41 a N N N N N I") C) M r N M 0 i Z 22 < CI QJ• 4i C \ u 0 N O C ,_ 0 ❑ 00000 000000 n:,Q �J v ^ L C' J J J J J J J J J J J J bA ;F, ❑ O W W W W W W W W W W W W 'N- aJ L U w F- LL LL LL LL LL LL LL LL LL LL LL LL i., aJ aJ aJ 'O C < J J J J J J J J J J J J a > 4., 0.) 0 CP f•' Q Q Q Q Q Q Q Q Q Q Q Q a)- 0 C `(- 0) a Z Z Z Z Z Z Z Z Z Z Z Z u (a (1) 0 a p LL LI. LL LL LL LL LL LL LL LL LI. LL cc -0 c > F _ C > C 00 au, > +v.+ CU .. u -. 0 z Z N a v u > O c o O —r C O a `L° a Y u L c C 1_ v > u . U C (o a o 0 u j Q a0.) a LA cc a LL LL LL LL L. o ❑ a a o 0 a 0 E a a 0 0 a C'.i W 10 a. J (6 o_ V A A fy to .) ? co O O a O a (1) O O a a O c cv 44 z � x il � `� w0 C' CO VC J J J J J J J J J J J J US W, v, o43 Z it' i)lirplYriP p v P CLIXCLX X CL CeCtiXCLCGCL E W W W W W W W W W W W W 3 W > > > > > > > > > > > > L QR' ced' R' x Q' w Q' w Q' a' ct in z Y Y Y Y Y Y Y Y Y NCY Y ❑ > > > > > > > > > > > O J X CLLYW d' a' CLCCQ: X 2 CL 4-4W Q Q Q Q Q Q Q Q Q Q Q Q v >. LT_ a a a a a a a a a a a a c a DMDM Y Y Y Y Y Y Y Y Y Y Y Y 0 W r,. Uat)W co n o O CO Q) N C') M In Cn D X In G CO CO CO CO 0) O) 0) 0) O) O) 0) 0) N U O 0 0 0 0 0 0 0 0 0 0 0 E O 0 0 0 0 0 0 0 0 0 0 0 0 W O 0 u - 0 0 0 0 0 0 0 0 0 0 0 0 03 r r 1-'4. CO CO 03 n r CO r n 'o 03 CO 03 CO CO CO 03 00 03 CO CO CO C j Z >VI 2 2 2 2 E E E E 2 2 2 2 (o ♦.j W ❑ ❑ ❑ ❑ ❑ ❑ ❑ p ❑ ❑ ❑ ❑ C w -0 gco O 0 O 0 0 N 0 O 0 O 0 0 C O 0 0 0 0 0 O 0 O O 0 O to � 0) U) Il) CO O CO Q) O) COU)M •L E LT( ,-CC S 07 Cr) T N- f- O O r y Co In L 0 IIN M N N 010x-r O O O N O O Q u N N NNNNN NNNNNN I. -0 cs O O O O) O O O M M M M LA RO N N N N N N N O O O N N O •` 0 0 0 0 0 0 — r r O 0 r L m n u)0 0 0 0 0 0 0 0 0 0 0 0 „ 0 v e� C IIn In In N In In In In In u') a U + e� co N a) � C L E a > U CO u .r Q $ W Y C c m 9 H y v ,i Q O 0 m 0) ID m v v o In u, 0 N v 7 a d e=It z b d0 Z r r r r co O O N O O N L.Y E N a Q G J-( r ❑ ❑ W W ❑ N N M N th L12 a E (0 N I. CO S _� �..( L ^ N C Z H Y in 1- a a Q • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday,August 21,2015 P.I.Supervisor 's.l _`r(31 fS SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G-20 FROM: John Crisp KUPARUK RIV UNIT 3G-20 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-20 API Well Number 50-103-20141-00-00 Inspector Name: John Crisp Permit Number: 190-123-0 Inspection Date: 8/15/2015 Insp Num: mitJCr150821101701 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3G-20 Type Inj W'TVD 5796 Tubing 2697 - 2698 2702 - 2698 1901230 SPT 1500 1120 F 2010 1975 - I- 1970 - PTD Type Test Test psi IA Interval 4YRTST P/F PEr✓ OA 220 320 - 320 - 320 Notes: 1.4 bbls pumped for test. SCANNED Friday,August 21,2015 Page 1 of 1 ¸ ..*-* Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not.scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED .[] ' Logs 'of various .kinds . Other COMMENTS: Scanned by: ianna Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: /si • • 10- Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 — ---- ,,,.) 6--- r-,, ,r7vN u March 9, 2012 ---- ;.--- , ,,ds .,,, . L • 4r.= - i- _', r i V f__,:- L) tik (, @ zu Commissioner Dan Seamount ;_ , 7..112 , ,?2 , Cciu 0 Alaska Oil & Gas Commission Aillangs 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 /go- i g -73 Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement 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 in the fall of 2011. The corrosion inhibitor/sealant was pumped on various days in January and February 2012. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. .7-7,/ ,. / ......,..............„.„„ , MJ veland Z ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 3-09 -2012 3A,3G,3H,3K PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 3A -17A 50029226910100 2101130 3'6" NA 13" NA 5.95 2/14/2012 3G-20 50103201410000 1901230 SF NA 24" NA 3.83 2/14/2012 3H-17 50103200810000 1870990 19" NA 19" NA 3H -21 50103200940000 1880080 8" NA 15" NA 4.25 2/14/2012 3H -23A 50103202040100 1961860 6" NA 12" NA 6.38 2/14/2012 3K- 102 50029233780000 2071650 SF NA 16" NA 6.8 2/14/2012 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, September 07, 2011 TO: Jim 1 P.I. Sup 1 ( 1 ∎ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G -20 FROM: Jeff Jones KUPARUK RIV UNIT 3G -20 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3G -20 API Well Number: 50- 103 - 20141 -00 -00 Inspector Name: Jeff Jones Insp Num: mitJJ110906083844 Permit Number: 190 -123 -0 Inspection Date: 8/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. WellI 30-20 , Type Inj. G TVD 5796 ,1 IA 1310 2206 2167 2164 P.T.D 1901230 •TypeTest SPT Test psi 1500 OA 200 300 300 300 Interval 4YRTST P/F P ' Tubing 3612 _ 3611 3613 3618 Notes: I BBL diesel pumped. 1 well inspected; 2 exceptions noted: test port plug on well head and pressure guage on A/L line leaking. Mr. Mouser to initiate repair. Wednesday, September 07, 2011 Page 1 of 1 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~er1 ß!3D/07 DATE: Wednesday, August 22, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPIDLLIPS ALASKA INC 3G-20 KUPARUK RIV UNIT 3G-20 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~.G/2- Camm NON-CONFIDENTIAL Well Name: KUPARUK RN UNIT 3G-20 API Well Number: 50-103-20141-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070820 173000 Permit Number: 190-123-0 / Inspection Date: 8/20/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3G-20 Type Inj. I G TVD 5796 v- IA 750 2460 2420 2420 P.T. IWLt~U TypeTest I SPT Test psi 1500 OA 320 520 520 520 Interval 4YRTST ./ P/F P v / Tubing 3630 3630 3630 3630 Notes: Pretest pressures observed for 30+ minutes and found stable. / SCANNED SEP 1 02007 Wednesday, August 22, 2007 Page I of I Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska,lnc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 90' 1. Operations Performed: I. Kt:.lJt:.IV.....u MAY 0 7 7!W7 . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Abandon 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Operat. ShutdownD Anchorage o WINJ to WAG ,/ Time Extension 0 o Stimulate 0 Waiver 0 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Other Re-enter Suspended Well 5. Permit to Drill Number: 190-1231 ,/ 6. API Number: 50-103-20141-00 r Exploratory Sérviee o 0/ 9. Well Name and Number: 3G-20 /' 8. Property Designation: Kuparuk River Unit .,A Pi.. :.t;ç.f 'ó jil> ,;.z,ç.()1 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool ... Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: measured 10100' " feet true vertical 6075' / feet measured 10016 feet true vertical , 5985 feet Length Size MD 115' 16" 115' 4586' 9-5/8" 4676' 1 0010' 7" 10100' Plugs (measured) Junk (measured) lVD Burst Collapse 115' 3220' 6075' Measured depth: 9686' - 9820' $CANNED JUN 1 4 2007 true vertical depth: 5855'· 5926' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 9602' MD. Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-1-SP' pkr= 9575' SSSV= SSSV SSSV= 1804' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ 908 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: OilO GasO WAG 0 GINJD WINJ 0 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: N/A 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl 1097 ¡ 1050 900 Casin Pressure Tubin Pressure 2134 2261 Daily Report of Well Operations _X Contact Printed Name Signature WDSPLO Title Production Engineering Technician Phone 659-7535 Date "5 B ð' o RIG I N A L RBDMS 8ft JUN 112M) :S~bm.~%k Form 10-404 Revised 04/2004 . . 3G-20 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/01/071 Commenced WAG EOR Injection service ( .0' ! RECE\VED 06/13/06 Scblumbepger (2; /\?J D\() "- <yt/ \J dUN :I. 4 2006 NO. 3850 ,'\Iæka Œt & (13S Cons, Commission Anchorage Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ";. 1,., ~ ,.J Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 '·~·'C·~ ~ ....~~U:;;U '~ ,__.,<~~_",~''''F \,.,' ,4 ¡;... Field: Kuparuk Well Job# Log Description Color CD Date BL 3J-16 11249908 INJECTION PROFILE 06/03/06 1 1 R-08 11249909 INJECTION PROFILE 06/04/06 1 3H-11 . 11213760 PRODUCTION PROFILE W/DEFT 05/31/06 1 1R-07 11249912 PRODUCTION PROFILE 06/07/06 1 1 F-12 11320981 PRODUCTION PROFILE WIDEFT 06/06/06 1 3G-20 11249911 INJECTION PROFILE 06/06/06 1 2A-16 11213754 PRODUCTION PROFILE W/DEFT OS/25/06 1 2A-22 11213756 LDL OS/27/06 1 1Y-04 11320980 LDL 06/03/06 1 2Z-02lREDrn 11235362 INJECTION PROFILE OS/28/06 1 1H-19 (REDO) 11320975 INJECTION PROFILE OS/29/06 1 2A-13 (REDO) 11320976 LDL 05/30106 1 3J-09 11320977 INJECTION PROFILE 05/31/06 1 1 F-17 11249913 PRODUCTION PROFILE W/DEFT 06/08/06 1 1J-170 11320983 USIT 06/11/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. r / .l),~/,,-_.. ~) / I Lf (()6 e e MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: JpiffiI SRegg. --;)K' êë.7t(i tJ <;'(Olp .. upervlsor " DATE: Wednesday, May 24, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G-20 KUPARUKRIV UNIT 3G-20 Src: Inspector ~ J\'>r ,C\O Reviewed By: P.I. SuprvJ~ Comm FROM: Chuck Scheve Petroleum Inspector NON~CONFIDENTIAL Well Name: KUPARUK RIV UNIT 30-20 API Well Number 50-103-20141-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060515060406 Permit Number: 190-123-0 Inspection Date: 5/14/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I IType Inj. i W i TVD I I ----~--~. ! ! I 3G-20 5796 IA i 800 2020 2010 2010 I , i -- P.T. I 1901230 !TypeTest I SPT ! Test psi I 1500 V! OA I 420 I 560 I 560 560 , i 4YRTST Tubing I 2300 i 2300 I 2300 2300 I Interval P/F P I -~--- Notes Pretest pressures were observed and found stable, Well demonstrated good mechanical integrity, ~Ç/\NNEC JUN ., ¿) 20D6 Wednesday, May 24,2006 Page 1 of 1 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 2000 P C:LO~LM.DOC E E L E W A T E R IA L UNDER TH IS M ARK ER STATE OF AI.ASKA OIL AND GAS ~RVATION CCMM~ REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate Plugging Perforate Repair well Other ;~ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development Exploratory Stratigraphic Service 2538' FNL, 170' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1551' FSL, 1778' FWL, Sec. 26, T12N, R8E, UM At effective depth 1310' FSL, 1686' FWL, Sec. 26, T12N, R8E, UM At total depth 1224' FSL~ 1653' FWL~ Sec. 26~ T12N~ R8E~ UM 12. Present well condition summary Total Depth: measured 1 01 0 0' feet true vertical 6075' feet Plugs (measured) 6. Datum elevation (DF or KB) % I 9O' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3G-20 9. Permit number/approval number 90-123/91-222 10. APl number 5o-103-20141 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 1 001 6' feet true vertical 5985' feet Junk (measured) Casing Length Size Structural Conductor 11 5' 1 6" Surface 46 76' 9 5/8" Cemented 216 Sx AS I 1050 Sx AS III & Measured depth 115' 4676' True vertical depth 115' 3220' Intermediate Production Liner Perforation depth: 10100' 7" measured 9686'-9700', true vertical 5855'-5862', Tubing (size, grade, and measured depth) 610 Sx Class G 610 Sx Class G & 347 Sx PRMC 9720'-9760', 9780'-9820' 5873'-5894', 5.905'-5926' 3 1/2" 9.3#, EUE, ABMOD, IPC, w/tail @ 9602' Packers and SSSV (type and measured depth) SSSV: Otis FMX Series 10 @ 1804'~ Packer: Camco HRP-1-SP @ 9575' 13. Stimulation or cement squeeze summary Converted from Producing Well to Water Injection Well on q [4-/~1, Intervals treated (measured) 10100' 6075' Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. 14. Prior to well operation Subsequent to operation Reoresentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Mcr WateroBbl Casing Pressure 1631 1731 1 0 - - 0 - - 0 - 6166 900 Tubing Pressure 158 2600 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as:. Water Injector _X Oil _ Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C-~J. ~ Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE Well Name Log Type Run I)alc Kuparuk iiiver {init iFTiA ~'-3 ~ Kuparuk Kuparuk Kuparuk Kupamk Kuparuk Kuparuk Kupamk Kupamk g, uparuk K. uparuk Kuparuk Kupmuk Kuparuk .Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk River Unit 11.-..10 River Unit 11..-14 River Unit 1I..-..17 River Unit IR 04 River Unit 1Y.-10 iiiver l~nii iV-ii rib-er Unit River Unit 2B.-08 River Unit 2C..-02 Rive, Unit 2C-04 River Unit ~" os River Unit 2C-O6 i6ver tinit 2V-i0 River Unit 2V-- River Unit 3G-12 River Unit 31t-.-02 t~iver Unit 3G--20 Water How f.og (' i'i Yl'.. P) Injection Profile Injection Profile Injection Prohle Injection Profile Injection P~'ofile Injection Profile Injection Profile lnjtx:tion Profile Injection Profile fnjection Profile Injection Profile Injection Profile Injection Profile Survey Injection Profile Survey Injection Profile Production l.og Production l_.og Injection Profile Injection Profile Survey Injc'ction Profile 07.IA N 1991 10--1..91 03 NOVEMBI?;R1991 4 NOVI:'.;MI3EIt 1991 4 NOVEMBER 1991 11.O6~- 1991 6/30/91 12-13..--1991 ii .-19.-9I 11..17.-1991 12.2-91 12..27...1991 26 DEC 1991 10--27-1991 11/25/91 11.-16-1991 8...IIJNI;7-1991 31 -.J U'Ii~ ¥. 1991 11 N()V 1991 10/1 t9/91 11..-29-1991 Iteceived by: ~__ ~~--~-'~ Dated: Copy' sentto ;;ender: Yea ~ No ~ RECEIVED MAR 2 (5 1992 Alask~ 011 & Gas Cons. Commission Anchorage 1. Operation Performed: Operation Shutdown ~ Pull tubing Alter casing STATE OF ALASKA REPORT OF SUNDRY WELL OPERATIONS Stimulate __ Repair well 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development _ Exploratory _ Stratigraphic Service X 2538' FNL, 170' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1551' FSL, 1778' FWL, Sec. 26, T12N, R8E, UM At effective depth 1310' FSL, 1686' FWL, Sec. 26, T12N, R8E, UM At total depth 1224' FSL~ 1653' FWL~ Sec. 26~ T12N~ R8E~ UM 12. Present well condition summary Total Depth: measured 1 01 0 0' feet true vertical 6075' feet Plugging Perforate _ Other X 6. Datum elevation (DF or KB) 90' RKB feet 7, Unit or Property name Kuparuk River Unit 8. Well number 3G-20 9, Permit number/approval number 90-1 23/91-222 10. APl number 5o-103-20141 11, Field/Pool Kuparuk River Oil Pool Plugs (measured) Effective depth: measured 1 001 6' feet true vertical 5985' feet Junk (measured) Casing Length Size Structural Conductor 1 1 5' 1 6" Surface 4 6 76' 9 5/8" Intermediate Production 1 01 0 0' 7" Liner Perforation depth: measured 9686'-9700', true vertical 5855'-5862', Tubing (size, grade, and measured depth) Cemented Measured depth True vertical depth 216 Sx AS I 1 15' I 15' 1050 Sx AS III & 4676' 3220' 610 Sx Class G 610 Sx Class G & 10100' 6075' 347 Sx PRMC 9720'-9760', 9780'-9820' 5873';5894', 5905'-5926. RECEIVED 3 1/2" 9.3#, EUE, ABMOD, IPC, w/tail @ 9602' OCT 2 Packers and SSSV (type and measured depth) SSSV: Otis FMX Series 10 ~ 1804', Packer: Camco HRP-1-SP @ 9575' Alaska 0Jj & (~as C0~s. C0mmis~ 13. Stimulation or cement squeeze summary Anch0ra~9 Converted from Producing Well to Water Injection Well. Intervals treated (measured) Treatment description including volumes used and final pressure Re~3resentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing 14. Pressure Prior to well operation 1631 1731 1 - 0 - 158 Subsequent to operation - 0 - 0 - 61 6 6 9 0 0 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys runm Water Injector X.. Daily Report of Well Operations X Oil_ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 0 ~ 2600 Service Date Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Sul~Idlary of Atlantic Richfield Company WELL iTRACTOR Oh'~ - ~'7',~ REMARKS · PBDT I OOlC,, FIELD- DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT IDAYS I DATE q · I~* DV ~/I~K I~Y'ch - ~~ ~'~ q~'~' c~c~ - k~,,4 damn · 7 ~ "h'/.~¢.r - CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots ARCO Alaska, Inc,'~% Su~s~cliary of Atlantic Ricl~fleld Company WELL SERVICE REPORT WELL NTRACTOR REMARKS PBDT , I(~01~ !FIELD- DISTRICT. STATE OPERATION AT REPORT TIME ,DAYS DATE ~,--~ ....... ,-~, 0ii ,~ _. .__ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor ' Visibility Wind Vel. Report °F °F miles knots Alaska, Subslchary of Atlantic Ric~fieiO ComDany .LL ~ iPBDT 3(., - ~ CONTRACTOR C~h's AARKS WELL SERVICE REPORT I FtELD- DISTRICT-STATE DAYS I DATE , ~ , ~l~,l~/ . IOPERATION AT REPORT TIME ! RECE!VED CHECK THIS BLOCK iF SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor Visibility Wind Vel. Report °F °F miles .-~l"il~/ /,~Ii~K(~, Inc. V SuD$icllary of Atlantic Richffelcl ComD~--'~, ,'BDT CONTRACTOR ,EMARKS '"'~ FIELD- DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPOR' AF~ '~q~/901 E:~'. co~t ' ti 700 ['-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK W"ther1 T'mP'Report 'F Chill Fact°r t Vl'lbllltY'F mile. IWInd v'l' ' STATE OF ALASKA , · ALASKA OIL AND GAS CONSERVATION COMMIS~ 0 ~ I REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown Stimulate __ Plugging Perforate ~ Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 2538' FNL, 170' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1551' FSL, 1778' FWL, Sec. 26, T12N, R8E, UM At effective depth 1310' FSL, 1686' FWL, Sec. 26, T12N, R8E, UM At total depth 1224' FSL~ 1653' FWL~ Sec. 26r T12N~ R8E~ UM 12. Present well condition summary Total Depth: measured 1 0100' feet true vertical 6075' feet 6. Datum elevation (DF or KB) 90' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-20 9. Permit number/approval number 9o-123/N^ 10. APl number so-lo3-20141 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) Effective depth: measured 1 0 01 6' feet : true vertical 5985' feet Casing Length Structural Conductor 1 1 5' Surface 4 6 7 6' Intermediate Production Liner Perforation depth' 10100' 7" measured 9686'-9700', true vertical 5855'-5862', Tubing (size, grade, and measured depth) Junk (measured) Size Cemented Measured depth 1 6" 216 Sx AS I 1 1 5' 9 5/8" 1050 Sx AS III & 4676' 610 Sx Class G 610 Sx Class G & 1 01 0 0' 347 Sx PRMC 9720'-9760', 9780'-9820' 5873'-5894', 5905'-5926' True vertical depth 115' 3220' 6075' P[CE VED \, 3 1/2" 9.3#, EUE, ABMOD, IPC, w/tail @ 9602' and SSSV (type and measured depth) SSSV: Otis FMX Series 10 ~ 1804', Packer: Camco HRP-1-SP ~ 9575' 13. Stimulation or cement squeeze summary Perforated upper intervals of Kuparuk Formation. Intervals treated (measured) 9686'-9700' & 9720'-9760' Treatment description including volumes used and final pressure Perforated intervals using strip guns with a density of 8 SPF phased at 90°. Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Pressure Tubing Prior to well operation 1620 1695 1 -0- 158 Subsec 1 6 5 9 2 9 8 5 1 1ts Copies of Logs and Surveys run__ Water Injector __ Daily Report of Well Operations X Oil ~ Gas [I ~s true and correct to ned Title -O- as: Suspended Service ge. 158 Date Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company ~H '~- CELL PBDT ~ REMARKS WELL SERVICE REPORT 'DATE ././~0 0 _'-~_ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. i Chill Factor i Visibility Wind Vel. ;Signed Repod OF °F miles; knots i AROO Alaska, Inc. Subsidiary of Atlantic Richfield Company JELL PBDT C ~CTOR REMARKS WELL SERVICE REPORT DAYS I DATE j / 7/5' /9 v'c, L_J CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Report Temp. ! Chill Factor . Visibility l Wind Vel. °F ' °Fi miles i knots WELL ARCO Alaska, Inc, Subsidiary of Atlantic Richfield Company /-, a-5 ~ /A,,.~ IPBDT REMARKS OPERATION AT REPORT TIME , WELL SERVICE REPORT IDAYS/ DATE /~o~ · /y/~- ~--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Visibility miles Iwind Vel. knots Isigned Weather ]Temp. Chill Factor Report I °F °F STATE OF ALASKA ALAoKA OIL AND GAS ~SERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_ Suspend _ Operation Shutdown Re-enter suspended well Alter casing _ Repair well _ Plugging _ Change approved program _ Pull tubing _ 2. Name of Operator 5. Type of Well: IARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface Development Exploratory Stratigraphic Service 2538' FNL, 170' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1551' FSL, 1778' FWL, Sec. 26, T12N, R8E, UM At effective depth 1310' FSL, 1686' FWL, Sec.26, T12N, R8E, UM At total depth 1224' FSL~ 1653' FWL~ Sec. 26~ T12N~ 12. Present well condition summary Total Depth: Effective depth: measured true vertical measured true vertical Length 115' 4676' 1010O' R8E~ UM 10100' feet 6075' feet 10016' feet 5 9 8 5' feet Size I 6" 9 5/8" # Plugs (measured) Junk (measured) Cemented 216 Sx AS I 1050 Sx AS III & 610 Sx Class G 347 Sx PRMC measured 9780'-9820' true vertical 5905'-5926' Time extension _ Stimulate _ Variance _ Perforate_ Other X 6. Datum elevation (DF or KB) RKB 9O 7. Unit or Property name Kuparuk River Unit 8. Well number 9. Permit number 90-123 Detailed operation program Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: feet 10. APl number r~-103-2o141 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool . Tubing (size, grade, and measured depth) 3-1/2" J-55 , 9.3#, AB Mod., IPC, w/Tail @ 9602' Packers and SSSV (type and measured depth) Camco HRP-I-SP Pkr. @ 9575'~ Otis FMX Series 10 SSSV ~ 1804' 13. Attachments Description summary of proposal_ Convert well from oil producer to wate.r injector. , 14~. Estimated date for commencing operation 15. AUGUST 1991 16. If proposal was verbally approved Measured depth True vertical depth 115' 115' 4676' 3220' 10100' 6075' · BOP sketch Status of well classification as: Oil X Gas __ Service Name of approver Date approved 17. I herel~y~certify~thj~ the foregoin~i is true and correct to the be.,I of my knowledge. S,(::jned"~Jx'~ J/ 'V~ r¢/~.~,~.~), ~ Title FOR COMMISSION U~E ONLY Conditions of approval: Notify Oommission so representative may witness Plug integrity ~ BOP Test m Location clearance Mechanical Integrity Test ,~ Subsequent form r-'~quire 10-¥07 Suspended _ ~./t¢_..~ Date 7- Z Z - BI fj IAppro~al No~ ..~ ~--, Approved by order of the Commission Commissioner Form 10-403 Rev 09/12/90 SUBMIT IN TRIPLICATE Water Injection Conversion Procedure Well 3G-20 Procedure· I · SI well to perform surface equipment modifications. Install catalytic heater, rotate check valve and choke, install 1.5" meter runs, and calibrate instrumentation. 2. MIRU slick line unit. RIH and tag fill. 3. Conduct MIT. Note: The state should be notified a few days prior to performing the MIT so they can witness the test. After well has been shut in for at least 72 hours, contact Operations Engineering (x7525) to record wellhead pressure and shoot tubing fluid level. This information will be used for waterflood surveillance. . Begin injection, eventually working up to a flow rate of approximately 2500 BWPD. STATE OF ALASKA i~',i~ ~'~ I {~ IN ~ ALASKA OIL AND GAS CONSERVATION COM~v,ISSION · ~-~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Clessificalion of Service Well OIL ~ GAS r""] SUSPENDED r~ ABANDONED r~ SERVICE r~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-123 3'Address 8 APl Numbe~ RE£EIVe- ) 50-103-20141 P.O. Box 100360, Anchora§e, AK 4 Location ofwell at surface ~ ~: ~ :'..-ii' .... -- - : . .~ ~. LOCATIOI'~ 9 Unit or Lease Name 2538' FNL, 170' FEL, SEC 23, T12N, ROE, uM///55'~,/.~ ;i' tl V,,~ER"I~i;) KUPARUK RIVER [v~;..~,~ ~ ~ ~ 10 WellNumber At Top Producing lnterval = ~/..~r/~ ,~ ~'~ ~ () 1551' FSL, 1778' FWL, SEC 26, T12N, R8E,~M/~o~,~.,d~ $~ 3G-20 AtTotal Depth ~ ......... ~ ;;::~."~,~., 0il & GaS C0i~[$'. 11 Fietdana Pool 1224' FSL, 1653' FWL, SEC 26, T12N, RSE, UM ,~gC~0~0 KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 90'I ADL 25548 ALK 2662 12 Date SpuddedD/02/90. 13 Date T.D. ReachedD/12/90. 14 Date Comp. , Susp. or Aband.1/03/91. I15 Water DOpth' if OffshOreNA foot MSL 118 No' Of cOmpletiOnsl 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 DireclJonal Survey 20 Depth where SSSV set 21 Thickness of permafrost MD, 6075' TVD 10016' MD, 5985'TVD YES ['~ NO [--'[ 1804' feet MD 1600' APPROX 101O0' 22' Typ~ Electric or Other Logs Run EWR/CN/SFD/DGR/CET/CBL/GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FroM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H~40 SURF 115' 24" 216 SX AS I 9-5/8" 36# J-55 SURF 4676' 12-1/4" 1050 SX AS II1~ 610 SX CLASS G 7" 26# J-55 SURF 10100' 8-1/2' 347 SX PRMC 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) - SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9602' 9575' 9780'-9820' W/4-1/2" CSG GUN @ 4SPF MD 5905'-5926' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ,,~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE =~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ,, Form 10-407 Submit in duplicate Rev. 7-1-80 C(~TINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 9686' 58,55' NA KUPARUK C Bo'n'OM 9700' 5862' KUPARUK A TOP 9701' 5863' KUPARUK A BO'I-rOM 9916' 5977' · · ,~ . .... 31. LIST OF ATTACHMENTS GYRO 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pedinent 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. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Rel~ort" on the first Wednesday after a well is spudded or workover operations are started. Daily wort( prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field KUPARUK RIVER UNIT c ....y, pari~g%LOPE Lease°rU~DL 2554 2662 : 8 ALK: Title COMPLETION IState AK Well no, 3G-20 Auth. or W,~l~t~.164 Operator ARCO Spudded o~'~r.]~begu n Date and depth as of 8:00 a.m, 01/02/91 (13) TD: 0 PB: 0 SUPV:DB/SK 01/03/91 (14) TD: 0 PB:10016 SUPV:DB r3ate 09/02/90 {Hour Complete rec~:~)~'~ ~_ay reported 11:00 ARCO W I. 55.252072 Pr or status if a w.o. RIH TO PERF 7"@10100' MW:10.5 NaC1/Br MOVE F/3G-18 TO 3G-20, NU BOPE & TEST, RU HLS, RIH TO PERF. DAILY:S23,055 CUM:$1,151,234 ETD:S1,151,234 EFC:$1,729,400 TEST 7" CSG & PKR 7"@10100' MW:10.5 NaC1/Br RIH & PERF F/9780'-9820' W/4.5" CSG GUNS @ 4SPF 180 DEG PHASE IN 2 GUN RUNS, ORIENTED & REF TO EWR LOG OF 9/12/90 & PET LOG OF 9/22/90, RD HLS, RU & RUN 3-1/2" COMP ASSY, TESTED SSCL WHEN HA. DE TO SSSV & TBG HANGER, DROPPER BALL BEFORE HANGER MADE UP, LAND HANGER, RILDS, RU CIRC LINES, PRES TBG TO 2500 PSI SET PKR, HOLD 10 MIN, HOLD TBG & PRESS ANN TO 1000 PSI, HOLD 10 MIN, BLEED ANN, HOLD TBG @ 1200 PSI BOLDS, PU & SHEAR PBR @ 92K, BLEED TBG RELAND HANGER RILDS, TEST SSSV-OK, LDLJ, SET BPV, ND BOP STACK, NU 3-1/8" WKM GEN IV 5KSI TREE, TEST TREE & PO TO 5000 PSI, TEST SSSV LINE TO 5000 PSI, OPEN SSSV, PULL TP, RU CIRC LINES, PRESS ANN TO 2500 PSI DAILY:S206,032 CUM:$1,357,266 ETD:S1,357,226 EFC:$1,729,440 RECEIVED The above is correct Signat]~'~ I [ For fo~m p~:~ret~/~n and distribution see Proce(~es Mah~ual, Section 1~.~ Drilling, Page'%'.,E;a..e~d 87. IDate, . I Title AR3B--459-1-D Number all daily well history forms consecutively as they are prepared for each well. ARCO O,, ,,,nd Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also whe. operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO ALASKA INC. Field KUPARUK RIVER UNIT !County or Parish NORTH SLOPE Lease or Unit ADL:25548 ALK:2662 Title COMPLETION IAccounting cost center code State AK Well no. G-20 Auth. or W.O. no. -AK5164 Operator ARCO Spudded or W.O. begun SPUD Date and depth Complete record for each day reported as of 8:00 a.m. NORDIC 1 '1/04/91 (15) DAILY: $7,397 TD: 0 PB:10016 SUPV:DB A.R.Co. W.I. Date 09/02/90 Iotal number of wells (active or inactive) on this ost center prior to plugging and ~ bandonment of this well 5. our Prior status if a W.O. 11:00 RIG RELEASE 7"@10100' MW:10.5 Diesel TEST ANN & TBG TO 2500 PSI F/15 MIN-OK, PRESS TBG & SHEAR SOS @ 3800 PSI, REV CIRC 12 BBL DIESEL CAP INTO ANN, INJECT 4 BBL DIESEL CAP DOWN TBG, SIT?=250PSI AND FALLING, SICP=0PSI, 7X9 SIAP=550 PSI, RELEASE RIG 1/3/91 07:00 CUM:$1,364,663 ETD:S1,364,663 EFC:$1,729,400 252072 OIdTO JNew TD JP8 Depth Rel drig .... JDate IKind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective corrected __ The above is correct Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well, age Dlvlilon el AtlarlticRichfJel~Coml3any GREAT LAND Client .... : Field ..... : Well ...... : Section at: Surveyor..: ORIGINAL DIRECTIONAL DRILLING, ARCO ALASKA, INC. Kuparuk River Unit KRU 3G-20 (23-12-8) S,27.18,W MIKE NAIRN INC. 10/12/90 Computation...: RADIUS OF CURVATURE survey Date...: 09/22/90 RKB Elevation.: 90.00 ft Job Number .... : AK0990G243 API Number .... : 50-103-20141 MEAS INCLN DEPTH ANGLE 100 0.29 200 0.43 300 1.07 400 4.88 500 11.34 VERTICAL-DEPTHS BKB SUB-SEA SECTION DIRECTION DISTNCE BEARING RELATIVE-COORDINATES FROM-WELL-HEAD CLOSURE DL DISTNCE BEARING /100 100.0 10.0 0.0 S 30.08 W 0.0 N 0.2 W 0.2 N 74.96 W 0.29 200.0 110.0 0.6 S 1.81 E 0.6 S 0.3 W 0.6 S 30.97 W 0.14 300.0 210.0 1.9 S 11.21 W 1.9 S 0.4 W 1.9 S 13.31 W 0.64 399.8 309.8 7.0 S 40.68 W 6.5 S 2.7 W 7.0 S 22.53 W 3.82 498.8 408.8 20.5 S 45.22 W 16.8 S 12.3 W 20.8 S 36.21 W 6.46 600 13.91 596.4 506.4 41.2 S 47.11 W 31.9 S 28.1 W 42.5 S 41.31 W 2.57 700 17.80 692.5 602.5 67.1 S 44.73 W 50.9 S 47.7 W 69.8 S 43.11 W 3.90 800 19.27 787.3 697.3 97.5 S 43.08 W 73.8 S 69.7 W 101.5 S 43.36 W 1.48 900 23.03 880.6 790.6 133.0 S 31.80 W 102.4 S 91.6 W 137.4 S 41.81 W 4.14 1000 27.68 970.9 880.9 175.7 S 26.31 W 139.8 S 112.4 W 179.4 S 38.79 W 4.80 7 1100 32.15 1057.6 967.6 225.'6 S 27.28 W 184.3 S 134.9 W 228.4 S 36.19 W 4.48 7 1200 33.96 1141.4 1051.4 280.1 S 27.74 W 232.7 S 160.1 W 282.4 S 34.52 W 1.82 7 1300 35.75 1223.5 1133.5 337.3 S 26.78 W 283.5 S 186.2 W 339.2 S 33.30 W 1.82 7 1400 38.17 1303.4 1213.4 397.4 S 25.30 W 337.5 S 212.6 W 398.9 S 32.21 W 2.49 7 1500 40.06 1380.9 1290.9 460.4 S 26.02 W 394.4 S 239.9 W 461.6 S 31.32 W 1.91 7 1600 43.52 1455.5 1365.5 527.1 S 25.85 W 454.3 S 269.1. W 528.0 S 30.64 W 3.46 7 1700 46.80 1526.0 1436.0 597.9 S 26.25 W 518.0 S 300.2 W 598.7 S 30.10 W 3.29 7 1800 47.62 1593.9 1503.9 671.3 S 28.58 W 583.1 S 334.0 W 672.0 S 29.80 W 1.51 7 1900 47.48 1661.4 1571.4 745.1 S 29.01 W 647.8 S 369.6 W 745.8 S 29.70 W 0.27 7 2000 48.58 1728.3 1638.3 819.4 S 28.86 W 712.9 S 405.5 W 820.1 S 29.63 W 1.10 7 2100 51.92 1792.2 1702.2 896.2 S 29.79 W 779.9 S 443.2 W 897.0 S 29.61 W 3.39 'Survey Codes: 7/GYRO (KRU3G20G) KRU 3G-20 (23-12-8) S MEAS INCLN C DEPTH ANGLE 7 2200 54.13 7 2300 54.54 7 2400 57.84 7 2500 59.45 7 2600 60.07 7 2700 59.26 7 2800 59.14 7 2900 59.39 7 3000 57.53 7 3100 55.72 7 3200 56.41 7 3300 56.76 7 3400 56.59 7 3500 56.85 7 3600 57.45 7 3700 57.98 7 3800 58.55 7 3900 56.55 7 4000 54.02 7 4100 54.02 7 4200 53.87 7 4300 53.91 7 4400 53.83 7 4500 53.70 7 4600 53.30 7 4700 52.23 VERTICAL-DEPTHS BKB SUB-SEA 1852.4 1762.4 1910.7 1820.7 1966.3 1876.3 2018.3 1928.3 2068.7 1978.7 2119.2 2029.2 2170.4 2080.4 2221.5 2131.5 2273.8 2183.8 2328.8 2238.8 2384.7 2294.7 2439.7 2349.7 2494.7 2404.7 2549.5 2459.5 2603.8 2513.8 2657.2 2567.2 2709.8 2619.8 2763.5 2673.5 2820.4 2730.4 2879.1 2789.1 2938.0 2848.0 2996.9 2906.9 3055.9 2965.9 3115.0 3025.0 3174.5 3084.5 3235.0 3145.0 RECORD OF SURVEY SECTION DIRECTION RELATIVE-COORDINATES DISTNCE BEARING FROM-WELL-HEAD 976.0 S 29.84 W 849.2 S 482.9 W 1057.1 S 31.45 W 919.1 S 524.3 W 1140.0 S 29.87 W 990.6 S 566.7 W 1225.3 S 29.67 W 1064.7 S 609.1 W 1311.6 S 31.46 W 1139.1 S 653.0 W 1397.7 S 30.29 W 1213.1 S 697.3 W 1483.5 S 27.50 W 1288.3 S 738.8 W 1569.5 S 27.35 W 1364.6 S 778.4 W 1654.7 S 28.31 W 1440.0 S 818.2 W 1738.2 S 28.38 W 1513.5 S 857.8 W 1821.2 S 28.40 W 1586.5 S 897.3 W 1904.6 S 27.59 W 1660.2 S 936.4 W 1988.2 S 28.60 W 1733.9 S 975.8 W 2071.7 S 28.40 W 1807.4 S 1015.7 W 2155.7 S 29.00 W 1881.1 S 1056.0 W 2240.2 S 29.97 W 1954.6 S 1097.6 W 2325.1 S 30.05 W 2028.3 S 1140.2 W 2409.4 S 29.54 W 2101.5 S 1182.1 W 2491.6 S 28.01 W 2173.6 S 1221.7 W 2572.5 S 28.17 W 2244.9 S 1259.8 W 2653.3 S 28.94 W 2316.0 S 1298.4 W 2734.1 S 29.58 W 2386.4 S 1337.9 W 2814.7 S 30.26 W 2456.4 S 1378.2 W 2895.3 S 30.27 W 2526.1 S 1418.8 W 2975.5 S 31.57 W 2595.1 S 1460.1 W 3054.9 S 31.15 W 2663.1 S 1501.6 W Page 2 10/12/90 CLOSURE DL DISTNCE BEARING /100 976.9 S 29.62 W 2.21 1058.1 S 29.70 W 1.14 1141.2 S 29.77 W 3.49 1226.6 S 29.77 W 1.62 1313.0 S 29.82 W 1.48 1399.3 S 29.89 W 1.18 1485.1 S 29.83 W 2.06 1571.0 S 29.70 W 0.27 1656.2 S 29.60 W 1.98 1739.7 S 29.54 W 1.81 1822.6 S 29.49 W 0.69 1906.1 S 29.43 W 0.67 1989.6 S 29.37 W 0.72 2073.2 S 29.33 W 0.30 2157.2 S 29.31 W 0.74 2241.7 S 29.32 W 0.88 2326.8 S 29.34 W 0.57 2411.2 S 29.36 W 2.03 2493.4 S 29.34 W 2.72 2574.3 S 29.30 W 0.10 2655.1 S 29.28 W 0.52 2735.9 S 29.28 W 0.42 2816.6 S 29.29 W 0.45 2897.3 S 29.32 W 0.13 2977.6 S 29.36 W 0.93 3057.2 S 29.42 W 1.10 ~Survey Codes: 7/GYRO KRU 3G-20 (23-12-8) S MEAS INCLN C DEPTH ANGLE 7 4800 52.49 7 4900 52.51 7 5000 52.51 7 5100 53.83 7 5200 54.23 7 5300 54.28 7 5400 55.86 7 5500 56.28 7 5600 56.56 7 5700 59.39 7 5800 59.91 7 5900 59.92 7 6000 59.86 7 6100 60.07 7 6200 60.17 7 6300 60.12 7 6400 60.32 7 6500 60.84 7 6600 60.27 7 6700 60.19 7 6800 60.31 7 6900 60.58 7 7000 60.62 7 7100 60.56 7 7200 59.71 7 7300 59.88 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 3296.1 3206.1 3133.9 3356.9 3266.9 3213.1 3417.8 3327.8 3292.2 3477.7 3387.7 3372.1 3536.5 3446.5 3452.8 3594.9 3504.9 3533.8 3652.2 3562.2 3615.5 3708.0 3618.0 3698.2 3763.3 3673.3 3781.2 3816.3 3726.3 3865.8 RECORD OF SURVEY DIRECTION BEARING S 30.96 W S 30.85 W S 30.84 W S 31.50 W S 31.05 W S 31.00 W S 31.99 W S 32.16 W S 31.68 W S 31.51 W 3866.8 3776.8 3951.8 S 31.17 W 3917.0 3827.0 4038.2 S 30.58 W 3967.1 3877.1 4124.5 S 30.98 W 4017.2 3927.2 4210.9 S 30.85 W 4067.0 3977.0 4297.4 S 30.70 W 4116.8 4026.8 4384.0 4166.5 4076.5 4470.7 4215.6 4125.6 4557.7 4264.7 4174.7 4644.'7 4314.4 4224.4 4731.5 4364.0 4274.0 4818.3 4413.3 4323.3 4905.3 4462.4 4372.4 4992.4 4511.5 4421.5 5079.5 4561.3 4471.3 5166.1 4611.6 4521.6 5252.2 RELATIVE-COORDINATES FROM-WELL-HEAD Page 3 CLOSURE DISTNCE BEARING 2730.9 S 1542.4 W 3136.4 S 29.46 W 2799.0 S 1583.2 W 3215.7 S 29.49 W 2867.1 S 1623.8 W 3295.0 S 29.53 W 2935.6 S 1665.3 W 3375.0 S 29.57 W 3004.7 S 1707.3 W 3455.9 S 29.61 W 3074.3 S 1749.1 W 3144.2 S 1792.0 W 3214.5 S 1836.0 W 3285.2 S 1880.1 W 3357.4 S 1924.5 W 3431.1 S 1969.4 W 3505.4 S 2013.8 W 3579.7 S 2058.0 W 3654.0 S 2102.5 W 3728.5 S 2146.9 W S 30.14 W 3803.3 S 2190.8 W S 30.10 W 3878.3 S 2234.3 W S 29.60 W 3953.9 S 2277.7 W S 29.68 W 4029.6 S 2320.8 W S 26.71 W 4106.1 S 2361.8 W S 26.10 W 4183.8 S 2400.4 W S 25.86 W 4262.0 S 2438.5 W S 25.81 W 4340.5 S 2476.4 W S 25.56 W 4419.0 S 2514.2 W S 22.84 W 4498.0 S 2549.8 W 10/12/90 3537.0 S 29.64 W 3619.0 S 29.68 W 3701.9 S 29.73 W 3785.1 S 29.78 W 3869.9 S 29.82 W DL /lOO 0.29 0.07 0.01 1.39 0.50 0.06 1.72 0.44 0.44 2.83 3956.1 S 29.85 W 0.58 4042.7 S 29.88 W 0.44 4129.1 S 29.90 W 0.31 4215.7 S 29.92 W 0.23 4302.4 S 29.93 W 0.15 4389.1 S 29.94 W 0.42 4475.9 S 29.95 W 0.20 4563.0 S 29.94 W 0.64 4650.1 S 29.94 W 0.57 4736.9 S 29.91 W 2.24 4823.5 S 29.84 W 4910.3 S 29.78 W 4997.2 S 29.71 W 5084.1 S 29.64 W 5170.5 S 29.55 W S 22.62 W 4577.8 S 2583.1 W 5256.3 S 29.44 W 0.48 0.33 0.06 O.2O 2.20 0.24 ~Survey Codes: 7/GYR0 ~RU 3G-20 (23-12-8) S MEAS INCLN C DEPTH ANGLE 7 7400 59.76 7 7500 59.94 7 7600 60.27 7 7700 60.63 7 7800 60.55 VERTICAL-DEPTHS BKB SUB-SEA RECORD OF SURVEY SECTION DISTNCE DIRECTION BEARING 4661.9 4571.9 5338.4 S 22..27 W 4712.1 4622.1 5424.5 S 21.94 W 4762.0 4672.0 5510.8 S 21.38 W 4811.3 4721.3 5597.3 S 21.47 W 4860.4 4770.4 5684.0 S 21.04 W 7 7900 60.46 4909.6 4819.6 7 8000 60.61 4958.8 4868.8 7 8100 58.82 5009.2 4919.2 7 8200 58.70 5061.1 4971.1 7 8300 58.76 5113.0 5023.0 7 8400 57.95 5165.5 5075.5 7 8500 57.70 5218.7 5128.7 7 8600 57.83 5272.1 5182.1 7 8700 57.37 5325.7 5235.7 7 8800 57.41 5379.5 5289.5 7 8900 57.11 5433.6 5343.6 7 9000 57.14 5487.9 5397.9 7 9100 57.41 5542.0 5452.0 7 9200 57.62 5595.7 5505.7 7 9300 57.55 5649.3 5559.3 RELATIVE-COORDINATES FROM-WELL-HEAD · Page 4 CLOSURE DISTNCE BEARING 4657.7 S 2616.1 W 5342.1 S 29.32 W 4737.8 S 2648.7 W 5427.9 S 29.21 W 4818.3 S 2680.7 W 5513.8 S 29.09 W 4899.3 S 2712.5 W 5600.1 S 28.97 W 4980.5 S 2744.0 W 5686.4 S 28.85 W 7 9400 57.88 5702.7 5612.7 X 10100 57.88 6074.9 5984.9 5770.5 S 21.04 W 5061.7 S 2775.3 W 5772.7 S 28.74 W 5857.1 S 20.74 W 5143.1 S 2806.3 W 5858.9 S 28.62 W 5942.9 S 21.55 W 5223.6 S 2837.5 W 5944.5 S 28.51 W 6028.0 S 20.93 W 5303.3 S 2868.5 W 6029.4 S 28.41 W 6112.9 S 20.57 W 5383.2 S 2898.7 W 6114.1 S 28.30 W S 22.20 W 5462.5 S 2929.8 W S 21.71 W 5541.0 S 2961.4 W S 21.04 W 5619.8 S 2992.3 W S 22.77 W 5698.1 S 3023.8 W S 23.53 W 5775.6 S 3056.9 W 10/12/90 6197.6 6281.9 6366.1 6450.1 6534.1 6618.1 6701.8 6785.6 6869.5 6953.4 S 23.04 W S 22.36 W S 21.50 W S 21.28 W S 21.04 W 7037.5 7626.8 DL /lOO 0.29 0.31 0.54 0.37 0.34 0.09 0.27 1.89 0.47 0.27 6198.6 S 28.21 W 1.42 6282.7 S 28.12 W 0.43 6366.8 S 28.03 W 0.50 6450.7 S 27.95 W 1.31 6534.7 S 27.89 W 0.54 5852.8 S 3090.1 W 6618.5 S 27.83 W 5930.3 S 3122.5 W 6702.2 S 27.77 W 6008.4 S 3154.0 W 6785.8 S 27.70 W 6086.9 S 3184.7 W 6869.7 S 27.62 W 6165.6 S 3215.2 W 6953.6 S 27.54 W 0.46 0.48 0.67 0.26 0.18 S 20.90 W 6244.6 $ 3245.4 W S 20.90 W 6798.4 S 3456.9 W 7037.6 S 27.46 W 0.34 7626.8 S 26.95 W 0.00 'Survey Codes: 7/GYRO X/EXTRAPOLATED (RU 3G-20 (23-12-8) Page 5 10/12/90 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL gUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 0 90 0.26 100 190 0.42 200 290 1.01 300 390 4.50 400 491 10.76 90 190 290 390 490 0 0 S 30.08 W 0.04 N 0.15 W 0 0 S 1.38 W 0.48 S 0.33 W 0 0 S 9.91 W 1.68 S 0.41 W 0 0 S 37.77 W 5.81 S 2.24 W 1 1 S 44.81 W 15.56 S 11.09 W 500 593 13.74 600 697 17.70 700 803 19.38 800 910 23.51 900 1022 28.65 590 690 79O 890 990 3 2 S 46.99 W 30.86 S 26.91 W 7 4 S 44.79 W 50.35 S 47.10 W 13 5 S 42.76 W 74.51 S 70.35 W 20 7 S 31.24 W 105.87 S 93.73 W 32 11 S 26.52 W 148.97 S 116.94 W 1000 1138 32.85 1090 1100 1259 35.02 1190 1200 1383 37.76 1290 1300 1512 40.47 1390 1400 1648 45.10 1490 48 17 S 27.46 W 202.67 S 144.36 W 69 21 S 27.17 W 262.34 S 175.46 W 93 24 S 25.55 W 328.12 S 208.15 W 122 29 S 26.00 W 401.29 S 243.31 W 158 36 S 26.04 W 484.61 S 283.83 W 1500 1794 47.57 1590 1600 1942 47.95 1690 1700 2096 51.80 '1790 1800 2264 54.39 1890 1900 2445 58.56 1990 204 46 S 28.44 W 579.37 S 331.96 W 252 48 S 28.95 W 675.30 S 384.78 W 306 54 S 29.76 W 777.44 S 441.77 W 374 68 S 30.88 W 894.33 S 509.32 W 455 81 S 29.78 W 1023.72 S 585.67 W 2000 2642 59.73 2090 2100 2838 59.24 2190 2200 3030 56.99 2290 2300 3210 56.44 2390 2400 3392 56.60 2490 552 98 S 30.96 W 1170.49 S 672.03 W 648 96 S 27.44 W 1317.48 S 753.94 W 740 92 S 28.33 W 1462.15 S 830.09 W 820 80 S 28.32 W 1593.56 S 901.08 W 902 82 S 28.51 W 1727.68 S 972.40 W .. 2500 3574 57.30 2590 984 83 S 28.85 W 1862.21 S 1045.60 W KRU 3G-20 (23-12-8) Page 6 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 10/12/90 SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 2600 3762 58.33 2690 1072 88 S 30.02 W 2000.38 S 2700 3947 55.35 2790 1157 85 S 28.81 W 2135.82 S 2800 4118 53.99 2890 1228 71 S 28.31 W 2258.11 S 2900 4288 53.91 2990 1298 70 S 29.50 W 2378.16 S 3000 4458 53.75 3090 1368 70 S 30.27 W 2496.68 S 3100 4626 53.02 3190 1436 68 S 31.46 W 2612.72 S 3200 4790 52.46 3290 1500 64 S 30.98 W 2724.12 S 3300 4954 52.51 3390 1564 64 S 30.84 W 2835.96 S 3400 5121 53.91 3490 1631 66 S 31.41 W 2949.89 S 3500 5292 54.28 3590 1702 71 S 31.00 W 3068.45 S 3600 5468 56.14 3690 1778 76 8 32.11 W 3191.75 3700 5649 57.96 3790 1859 82 S 31.60 W 3320.59 3800 5846 59.91 3890 1956 97 S 30.90 W 3465.38 3900 6046 59.96 3990 2056 99 S 30.92 W 3613.56 4000 6246 60.15 4090 2156 101 S 30.44 W 3763.00 4100 6448 60.57 4190 2258 102 S 29.86 W 3914.32 4200 6651 60.23 4290 2361 103 S 28.17 W 4068.28 4300 6853 60.45 4390 2463 102 S 25.97 W 4224.93 4400 7056 60.59 4490 2566 104 S 25.67 W 4384.55 4500 7257 59.81 4590 2667 101 S 22.71 W 4543.40 4600 7456 59.86 4690 2766 99 S 22.09 W 4702.38 S 4700 7657 60.47 4790 2867 101 S 21.43 W 4864.23 S 4800 7860 60.50 4890 2970 103 S 21.04 W 5029.40 S 4900 8062 59.49 4990 3072 102 S 21.25 W 5193.62 S 5000 8256 58.73 5090 3166 93 S 20.73 W 5347.76 S 1124.03 W 1201.25 W 1266.83 W 1333.20 W 1401.66 W 1470.96 W 1538.35 W 1605.26 W 1674.03 W 1745.61 W 1821.72 W 1901.85 W 1989.97 W 2078.32 W 2167.26 W 2255.09 W 2342.14 W 2420.45 W 2497.71 W 2568.80 W 2634.38 W 2698.67 W 2762.85 W 2825.73 W 2885.37 W 5100 8446 57.83 5190 3256 90 S 21.97 W 5498.72 S 2944.48 W ~RU 3G-20 (23-12-8) Page 7 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL lO/12/9o SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 5200 8634 57.68 5290 3344 87 S 21.62 W 5646.26 5300 8819 57.35 5390 3429 86 S 23.43 W 5790.55 5400 9004 57.15 5490 3514 84 S 22.33 W 5933.31 5500 9189 57.60 5590 3599 86 S 21.30 W 6078.56 5600 9376 57,80 5690 3686 87 S 20.93 W 6225.70 5700 9564 57.88 5790 3774 88 S 20.90 W 6374.48 5800 9752 57.88 5890 3862 88 S 20.90 W 6523.29 5900 9940 57.88 5990 3950 88 S 20.90 W 6672.10 3002.60 W 3063.38 W 3123.76 W 3181.47 W 3238.24 W 3295.06 W 3351.88 W 3408.71 W KRU 3G-20 (23-12-8) Page 8 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 10/12/90 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING 100 1000 27.68 971 881 176 S 26.31 W 140 2000 48.58 1728 1638 819 S 28.86 W 713 3000 57.53 2274 2184 1655 S 28.31W 1440 4000 54.02 2820 2730 2492 S 28.01W 2174 5000 52.51 3418 3328 3292 8 30.84 W 2867 6000 59.86 3967 387~ 4125 S 30.98 W 3580 7000 60.62 4462 4372 4992 S 25.81 W 4340 8000 60.61 4959 4869 5857 S 20.74 W 5143 9000 57.14 5488 5398 6702 S 22.36 W 5930 10000 57.88 6022 5932 7543 S 20.90 W 6719 112 W 179 S 38.79 W 4.8 406 W 820 S 29.63 W 1.1 818 W 1656 S 29.60 W 2.0 1222 W 2493 S 29.34 W 2.7 1624 W 3295 S 29.53 W 0.0 2058 W 4129 S 29.90 W 0.3 2476 W 4997 S 29.71 W 0.1 2806 W 5859 S 28.62 W 0.3 3123 W 6702 S 27.77 W 0.5 3427 W 7543 S 27.02 W 0.0 by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. 10/12/90 Client .... : ARCO ALASKA, INC. Field ..... : Kuparuk River Unit Well ...... : KRU 3G-20 (23-12-8) Section at: S,27.18,W Surveyor..: MIKE NAIRN Computation...: RADIUS OF CURVATURE Survey Date...' 09/22/90 Pd<B Elevation.' 90.00 ft Job Number · AK0990G243 API Number .... : 50-103-20141 · INTERPOLATED MARKERS REPORT Surface Location' 2538 SNL 170 WEL S23 T12N R8E MARKER IDENTIFICATION KB 9-5/8" CASING. TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A 7" CASING/TD MEAS INCLN VERT-DEPTHS SECT DEPTH ANGLE BKB SUB-S DIST 0 0.00 0 -90 4675 52.50 3220 3130 9686 57.88 5855 5765 9700 57.88 5862 5772 9701 57.88 5863 5773 9916 57.88 5977 5887 10100 57.88 6075 5985 BEARING DIRECTION REL-COORDINATES FROM-WELLHEAD 0 N 0.00E ON OE 3035 S 31.26 W 2646 S 1491 W 7278 S 20.90 W 6471 S 3332 W 7290 S 20.90 W 6482 S 3336 W 7291 S 20.90 W 6483 S 3336 W 7472 S 20.90 W 7627 S 20.90 W 6653 S 3401 W 6798 S 3457 W Spear Land Directional Drilling. Inc. <KB>O 700 t400 2t00 2800 3500 4200 4900 5800 6300 7000 7700 8400 glO0 9800 700 VERTICAL SECTION VIEW ARCO ALASKA, INC. KRU3G-20 (23-t2-8) Section at: S 27.t8 W I TVD Scale.' t inch = t400 feet Dep Scale.' 1 inch = t400 feet Drawn · t0/12/90 Marker Identification MD TVD SECTN I A) KB 0 0 0 A 8} TD 10100 6075 7627 5 _ '-,., ,, INCLN 0.00 57.88 0 700 i400 2:1.00 2800 3500 4200 4900 5600 6300 7000 Section Departure Harker Identification MD N/S Al KB 0 0 N 0 B} TO iOiO0 6798 S 3457 PLAN VIEW ARCO ALASKA. INC. KRU 36-20 (23-i2-8} CLOSURE ..... : 7627 ft S 26.95 W DECLINATION.: 0.00 E SCALE .......: i inch = ilO0 feet DRAWN .......: 10/12/90 55o 0 55o itO0 i650 3300 3850 4400 495O 5500 6O5O 6600 7i50 6050 5500 4950 4400 3850 3300 2750 2200 i650 t 100 55O 0 55O <- NEST · EAST -> GEOLOGICAL MATERIALS ......... ~w~ fi~'~' LiST A eco cnec~ on or list aata as it is received.~list received date tot 40?. il not required list as NR '"407' i'*..9,/~. ?/?/ j drilling_ ,i~t.,.-. ,I ~-'I ~u..~vl., . ./, .! '-~. ~t~,, !~/~! core descriptio ,r~. cored intervals core analysis L~/~ dry ditch intervals ,, digital data ............ y~ ~< ~ ~ ,, ARCO Alaska, Inc. Date' December 7, 1990 Transmittal #: 7949 RETURN TO: ARCO Alaska, Inc. ATTN: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3G-20 Pulse Echo Cement Evaluation(PET) 9-22-90 6900-9899 3G-5 Pulse Echo Cement Evaluation(PET) 9-20-90 5000-8074 3 G- 20 Acoustic Cement Bond Log 9 - 21 - 9 0 6 9 0 0 - 9 8 9 6 Receipt Acknowledged: Date: DISTRIBUTION: Drilling NSK State of Alaska(+Sepia) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend Alter casing _ Change approved program _ 2. Name of Operator ARCO Ale, aka. lng, 3. Address P. O. Box 100360, Anchorage, AK 99510 Repair well _ Plugging _ Pull tubing _ 5. Type of Well: Development X_ Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2538' FNL, 170' FEL,SEC 23,T12N,R8E,UM At top of productive interval 1551 Fsi, 1178' FWL, Sec. 14, T12N, RSE, UM At effective depth NA At total depth 1224"FSL, 1653' FWL, Sec. 26, T12N, R8E, UM 12. Present well condition summary Total Depth: measured 10100' feet (approx) true vertical 6076' feet Effective depth: measured NA feet (approx) true vertical NA feet Operation Shutdown :X Re-enter suspended well _ Time extension Stimulate Variance Perforate Other 6. Datum elevation (DF or KB) Plugs (measured) Junk (measured) RKB 90' 7. Unit or Property name Kuparuk River Unit feet 8. Well Number 3G-20 9. Permit number · 90-123 10. APl number 50-103-20141 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Size Structural Conductor 8 0' 1 6" Surface 4641' 9 5/8" Intermediate Production 1 0065' 7" Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Cemented Measured depth True vertical depth 216 SX AS I 1 15' 115'. 1050Sx AS III& 4675' 3220' 610Sx Class G 347Sx PRMC 10100" 6075' RECEIVED DEC - 4 Alaska 0il & Gas Cons. comm~ssi0t~ ;Anchorage 13. Attachments Description summary of proposal_ Detailed operation program BOP sketch 14. Estimated date for commencing operation January, 1 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as:, Oil ~( Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~.~ ~/~~,~j~ Title Area Drilling Engineer ,,- / v - FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test m Location clearance m Mechanical Integrity Test_ Subsequent form require IApproval No. Approved by the order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 Approved Copy ORIGINAL SIGNED BY LONNIE C. SMITH SUBMIT IN TF~IPLI~ATE ARC~ dil a.d Gas Company Well History - Initial Report - Daily Inllmctionl; Prepare and submit the:,'~ I~/ll~' on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to al~~...d:.be ~ummarlzed on the form giving inclusive dates only. District ;:.; I County. parish or borough ARCO ALASKA INC. ~?~- I NORTH SLOPE Field I/ease or Unit KUPARUK RIVER UNIT I ADL 25548 ALK 2662 I Auth. or W.O. no. ITM AK5164 I DRILLING State AK Well no. 3(~--20 Operator ARCO W.I. ARCO 55.2500 Spudded or W.O. begun pate IHour IPr or status if a W.O. SPUD I 09/02/90 I 11:00 I Date and depth as of 8:00 a.m. 09/03/90 (1) TD: 3070'(3070) SUPV:JMM 09/04/90 (2) TD: 4698'(1628) SUPV:JMM 09/05/90 (3) TD: 4698'( 0) SUPV:JMM 09/06/90 (4) TD: 4698'( 0) SUPV:KSP 09/07/90 ( TD= 7500'(2802) SUPV:KSP Complete record for each day re~ed DOYON 14 NAVIDRLG, 12.25" HOLE t,;IW: 9.2 VIS: 55 N/U SURFACE HYDRIL AND DIVERTER, P/U BHA AND TAG CMT AT 60', DRLG CMT TO 115'. SPUD TO 3070", KOP AT 300'. DAILY:S84,373 CUM:$84,373 ETD:S84,373 EFC:$1,729,400 RUNNING 9-5/8" CASING MW: 9.6 VIS: 47 DRILL FROM 3070' TO 4698'. CIRC, MAKE WIPER TRIP, DROP SS SURVEY, POOH TO RUN 9-5/8" CASING. RUN 120 JTS OF 9-5/8" J-55 BTC CASING. DAILY:S54,066 CUM:$138,439 ETD:S138,439 EFC:$1,729,400 CIRC AND COND HOLE 9-5/8"@ 4675' MW: 9.5 VIS: 44 RUN 9-5/8" CSG, HIT TIGHT SPOT AT 1950'. WORK AND WASH CSG, UNABLE TO PASS. POOH L/D 5 JTS CSG. CIRC AND PUMP SLUG, POOH LAYING DN CSG. PU AND RIH WITH HOLE OPENER. HIT TIGHT SPOT AT 1700'. WASH AND REAM TO 2412', RIH, CIRC AND CONDITION HOLE. DAILY:S53,608 CUM:$192,047 ETD:S192,047 EFC:$1,729,400 DRLG PLUG AND CMT 9-5/8"@ 4675' MW: 9.5 VIS: 37 CIR AND PUMP HI VIS SWEEP, POOH, LD BHA. RU AND RUN 120 JTS I 9,W , CSG. OMT CSG, OST .IT. 70 oF DISPLAC. NT !~~ 2500 PSI BEFORE: DRLG SHOE. i~~239,777 CUM:$431,824 ETD:S431,824 EFC:$1,729,400 5) : 7500' 9-5/8"@ 4675' MW: 9.5 VIS: 43 TEST 9-5/8# SHOE TO 2500 PSI, DRLG CEMENT AND 10' OF NEW HOLE, DISPLACE MUD WITH 9.5 PPG MUD. RUN LEAKOFF TEST TO EMW 12.1 PPG, NO LEAK OFF. MWD FAILURE, TRIP TO CHG OUT MIND, DRLG 4708' TO-7500'. DAILY=S61,510 CUM:$493,334 ETD:S493,334 EFC:$1,729,400 09/08/90 (6) TD: 9550'(2050) SUPV:KSP 09/09/90 (7) TD: 9619'( 69) SUPV:KSP DRLG AT 9550' 9-5/8"@ 4675' MW:10.6 VIS: 40 DRLG FROM 7500' TO 9200', CBU WITH 10.6 PPG MUD. POOH TO 9-5/8" SHOE, RUN LEAK OFF TEST TO 11.1 PPG EM~, HELD OK. TRIP IN HOLE, CONTINUE DRILLING FROM 9200' TO 9550'. DAILY:S62,800 CUM:$556,134 ETD:S556,134 EFC:$1,729,400 STUCK PIPE 9-5/8"~ 4675' MW:10.6 VIS: 40 DRLG 9550' TO 9619'. DROP SS SURVEY, POOH FOR BIT. TIH, STUCK PIPE AT 9229'. JAR AND WORK STUCK PIPE, MIX 60 BBLS OF BLACK MAGIC, SPOT 35 BBL OUTSIDE BHA. PUMP 25 BBL AT 5 BBL/HR. LET BLACK MAGIC SOAK. DAILY:S68,342 CUM:$624,476 ETD:S624,476 EFC:$1,729,400 .. Proc.dures s.ct,o. ,0. Drilling, Pages 86 and 87. AR3B-459-1-D INumber all dally well history forms consecutively as they are prepared for each well. jPage no. · ARCO ~., at,,, Gas Company Daily Well History--Interim Instructions: This form is used during drilling or wOrkover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ]County or Parish IStare ARCO ALASKA INC. I NORTH SLOPE AK I Lease or Unit I ADL 25548 complete record for each day while drilling or workover in progress DOYON 14 Field KUPARUK RIVER UNIT ALK 2662 Date and depth as of 8:00 a.m. 09/10/90 (8) TD: 9619'( 0] SUPV:KSP 09/11/90 (9) TD: 9619'( SUPV:KSP 09/12/90 (10) TD:10004' ( 385 SUPV:KSP 09/13/90 (11) TD:10100' ( 96 SUPV:KSP POOH 9-5/8"@ 4675' MW:10.5 VIS: 40 JAR ON PIPE FOR 12 HOURS. RU AND RUN FREE POINT. STUCK AT BAFFLE PLATE. BACK OFF AT 8993' (BOTTOM OF 5TH STEEL DC) ON THE SECOND TRY. POOH W/ WL AND RD. POOH W/ PIPE. DAILY:S52,943 CUM:$677,419 ETD:S677,419 EFC:$1,729,400 REAM AND WASH TO BTM 9-5/8"@ 4675' MW:10.6 VIS: 55 FINISH POOH WITH BACK OFF. RU AND RIH W/ FISHING TOOL AND JARS. SCREW INTO FISH AND JAR LOOSE. POOH W/ FISH. LD FISH, TOOLS AND CHG BHA. TIH TO 9100'. CIRC HOLE, WASH AND REAM 9100' TO 9410'. HAVING TROUBLE REAMING TO BTM, PACKING OFF AND TRQ. DAILY: $94,020 CUM: $771,439 ETD: $771,439 EFC: $1,729,400 DRLG AT 10004' 9-5/8"@ 4675' MW:10.7 VIS: 42 WASH AND REAM TO 9619'. POOH, MU BHA WITH RLL TOOL. TIH, CUT DRLG LINE, REAM FROM 9569' TO 9619' DRILL FROM 9619' TO 10004'. DAILY:S63,341 CUM:$834,780 ETD:S834,780 EFC:$1,729,400 RUNNING 7" CASING 7"@10100' MW:10.7 VIS: 44 DRILL FROM 1004' TO 10100' TD. CIRC BU, SHORT WIPER TRIP TO 9100', CBU. POOH LDDP, REMOVE RLL SOURCE. RUN 7" CASING (205 JTS RUN BY 0600 HRS). DAILY:S53,736 CUM:$888,516 ETD:S888,516 EFC:$1,729,400 I Well no. 3~-20 The above is correct S i g n at u~,.-~t~,~.~ ~ For for~preparatioj;~a~d distribution ~ see Procedures Ma~u~ Section 10, Drilling, Pages 86 al'rd 87 RECE IVED Title AR3B-459-2-B OEO - 4 1990 Oil & Gas Cons. CommiSsion Anchorage Number ail daily well history forms consecutively as they are prepared for each well, IPage no AR(., ~,.and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Filtal Rel3ort" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted alee whet~ operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. t Accounting cost center code District County or Parish State ARCO ALASKA INC. ] NORTH SLOPE AK /wen no. Field ILease or Unit KUPARUK RIVER UNIT ITitle ADL 25548 ALK 2662 ~G-20 Auth. or W.O. no. I AK5164 I DRILLING Operator AR.Co. W.I. ARCO 55,2521 Spudded or .W,O. begun Date SPUD 09/02/90 Date and depth as of 8:00 a.m. 09/14/90 (12) TD:10100' ( SUPV:KSP Complete record for each day reposed DOYON 14 I otal number of wells (active or inactive) on this cst center prior to plugging and bandonment of this well our ] Prior status if a W.O. I 11:00 RIG RELEASED 7"@10100' MW:10.5 VIS: 0 FINISH RUNNING 7" CASING, TOTAL OF 233 JTS 26#, 7", J-55, AB MOD TO 10100'. CIRC CASING VOLUME, CEMENT WITH HALLIBURTON: 10 BBL PRE-FLUSH, 40 BBL 11 PPG SPACER, 347 SX CLASS G CEMENT (71 BBLS) 15.8 PPG WITH 3% KCL, .5% H-344, .2% CFR-3, .11% LWL. DISPLACE WITH 383 BBLS OF 10.5 PPG BRINE. BUMPED PLUG TO 2500 PSI, HELD OK. PUMP 50 BBL MUD DOWN ANNULUS, ND AND INSTALL TBG HEAD. RELEASE RIG AT 14:00 HRS 9/13/90. CUM:$1,128,179 ETD:S1,128,179 EFC:$1,729,400 REC EIVED DEC - 4 '~99g ^[asks .0il & Gas Cons. C0mmiss[0[I Anchorage MOVE TO 3G-18. DAILY: $239,663 Old TD Released rig Classifications (oil, gas, etc.) Producing method Potential test data INew TD Date PB O~pth K nd of rig Type completion (single, dual, etc.) IOff cial reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P, C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct see Procedu er s Mand-al, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. Page no. DIvlMon of AtlantlcRIchfleldCompsny ARCO Alaska, Inc. Date' September 28, 1990 Transmittal #: 7904 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 3G-17 3G-20 3G-18 LIS Tape and Listing LIS Tape and Listing LIS Tape and Listing Please acknowledge receipt and return 9- -90 500-785 0. 9-18-90 4550 101 9-24-90 6550-9700 ~:> ~'~7 Receipt Acknowledged: Date' "RECEIVED- DISTRIBUTION: Lynn Goettinger OCT o ~ 1990 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: September 28, 1990 Transmi~,'~7~l:~ ED RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 OCT 0 i 990 011 & Gas Cons. Commission Anchorage Transmitted herewith are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 3 G- 17 Dual Gamma Ray Compensated 8 - 31 - 90 3533 - 7795 Neutron Porosity Simultaneous Formation Density 3G-17 Dual Gamma Ray Electrmagnetic . 8- 31 - 90 3533-7795 Wave Resisti~vity Formation Exposure Time 3 G- 20 Dual Gamma Ray Compensated 9 - 1 2 - 90 4640 - 10100 Neutron Porosity Simultaneous Formation Density 3 G- 20 Dual Gamma Ray Electrmagnetic 9 - 1 2 - 90 4640 - 10100 Wave Resistivity Formation Exposure Time Dual Gamma Ray Compensated Neutron Porosity Simultaneous Formation Density Dual Gamma Ray Eiectrmagnetic Wave Resistivity 3G-18 9-20-90 4566-9650 3G-18 9-20-90 4566-9650 Receipt Acknowledged' ~~J~----~ .... Date: DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK __,¥~tate of ~}~s~a(+Sepia) , Telecopy No. (907) 276-7542 August 30, 1990 A W McBride Area Drilling Engineer ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3G-20 ARCO Alaska inc Permit # 90-123 Surf Loc 2538'FNL, 170'FEL, Sec 23, T12N, RSE, UM Btmhole Loc 1297'FSL, 3623'FEL, Sec 26, T12N, RSE, Dear Mr McBride: Enclosed is the approved application for permit to drill the above referenced well. The pe~it to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Cou~nission will advise you of those BOPE tests that it wishes to witness. Sincerely, Commissioner BY O~ER OF THE CO~4ISSION jo enet Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALA,~r,,A OIL AND GAS CONSERVATION COMMI,5oiON PERMIT TO DRILL 20 AAC 25.005 I la. Type of Work Drill X Redrill m I lb. Type of Well Exploratory__ Stratigraphic Test _ Development Oil Re-Entry _ Deepen --I Service _ Development Gas __ Single Zone ~ Multiple Zone _ ?-. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 90', Pad 53' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25548 ALK 2662 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2538' FNL, 170' FEL, Sec. 23, T12N, R8E, UM Kuparuk River Unit At top of productive interval (TARGET) 8. Well number Number 1585' FSL, 3475' FEL, Sec. 26, T12N, R8E, UM 3G-20 #U630610 At total depth ~. Approximate spud date Amount 1297' FSL, 3623' FEL, Sec 26, T12N, RSE, UM 04-SEP-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ~property line 3G-19 10064' MD 1657' @ TD feet 25' at surface feet 2560 6035 TVD feet 16. To be completed for deviated wells 17. Anticipaled pressure (see 20 AAC 25.035(e)(2)) kickoff depth 300' feet Maximum hole angle 58° Maximum,u,ace 1900 psig At total depth(TVD) 3100 p.si~l @ 5835' 18. casing program setting Depth size Specification Top Boltom Quantity of cement Hole Casing Weight Grade Coupling Length IvD TVD IVD TVD (include stage data/ 24 16" 62.5# H-40 Weld 80' 35' 35, 115' 115' _+200 Cu. Ft. 12.25 9.625 36.0# J-55 BTC 4663' 35' 35' 4698 3215' 2100 Cu. Ft. AS III & HF'-E'~ V' /~ 7:'.~,'1/',~'~/~,.F//',¢~.' ~-,~. 700 Cu. Ft. Class G 8.5 7" 26.0# J-55 AB-MOE 4777' 35' 35' 4812' 3275' 200Cu. Ft. ClassG $.5 7" 26.0# J-55 BTC 5252' 4812' 3275' 10064' 6035' Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true verticaltrue vertical feet Casing Length Size Cemented Measured depth True Vedical depth Structural Conductor Cu. Ft. RECEIVED Surlace Cu. Ft. Intermediate Production AUG 2 81990 Liner Perforation depth: measured Alas~a Oil & Gas Cons. mm..issJ true vertical Anch0raff~ 20. Attachments Filin9 fee ~ Property plat ~ BOP Sketch ~ Diverter Sketch X Drilling program Drilling fluid program ~ Time vs depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby certily that t'he foregoing is true and correct to the best of my knowledge Signed ~~I~~ Title Area Drillin~ Engineer Date--/~:~/2~/~;~") Commission Use Only Permit Number I APl number I Approva~)(~ 0/9 0 ,~ See cover letter for ~,:,~<::~--.//.~.~,~ 50~ /03"" 2_O/'~/ other rec~uirements Conditions of approval Samples required __Y e s :~' N o Mud Icg required m Ye s N o Hydrogen sulfide measures__ Yes '~ N o Directional survey required ,,~Yes m N o RequiredworkingpressureforB~,~__2M; .~I]; __5M' __10M' __ 15M Other: Appr. oved by[ t Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate DRILLING FLUID PROGRAM (3G-20) Spud to 9-5/8" Drill out to ,surface casing weight uo Density 8.6-10.0 8.6-9.3 PV 15-35 5-15 YP 15-35 5-8 Viscosity 50-100' 30-40 Initial Gel 5-15 2-4 10 Minute Gel 15-40 4-8 APl Filtrate 10-1 2 8-1 0 pH 9- 1 0 8.5-9 % Solids 10 +/- 4-7 Weight up to TD 10.5 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 10-12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1900 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3G-20 will be 3G-19. As designed, the minimum distance between the two wells would be 25' at surface. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3G PAD , , , . . . , . , 10. 11. 12, 13. 14. 15. 16. 17. 18. 19. 20. 21. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. Reperforate and add additional perfs. ARCO ALASKA. ]ne. Pad 3G. Well No, 20 Propoeed Kuperuk Field. North Slope. Aleeka m m 0 _ RKB ELEVAT!ON, 90' 1 000 _ 2000 _ 3000 _ 4000 _ 5000 _ 6000 _ 7000 KOP TVD=300 TMD=300 DEP=O 3 9 ~339,,~ B/ PERMAFROST TVD=1605 TMB=1737 DEP=515 '~,~OC iP=906 = = ~SAK SNDS TVD 2515 TMI3=3366 DE~1861 . ~ B/ 14 SAK SNDS TVD 3015 TMD 4317 DEP 2671 ~9 5/8" CSG PT = = ~TVD-3215. TMD 4698 DEP 2995 K-5 TVD'4315 TMD=6791 DEP'4775 AUG 2 8 1990 "-,~!aska Oil & Gas Cons. Ancho~ag~a AVERAGE ANGLE 58 DEO 18T A~IO:T- T/ ZONE C/A T VD: 5835 T MD:9683 DEP.723~ B/ KUP SNDS TVD 5930 TMD 9864 TMD 7390 '-- ~'- TD / LOG PT TVD=6035 TMD=lO064 DEP=7560 I I I I I I I 1000 2000 3000 4000 5000 6000 7000 VERTICAL SECTION I 8000 100 5O 5O 100 150 200 , . 200 150 100 I, l, I, 200 1 50 1 O0 / / / / / 7'1100 5O m ' 2oo / / / / ! 900 / / ??oo leoo 1100 5O 5O lO0 I 1 500 150 I '~ 2,500 ll~oo · SO0 '~' 500 500 ,==== O0 ~> c> . ..,,. 700 I ~700 [ I 900 900 200 1 _1 i 100 150 I 200 100 5O 5O _ 100 _ 150 _ 200 HORIZONTAL PROJECTION SCALE 1 IN. = 1000 FEET z I 1000 ! 000 _ 2000 _ 3000 _ 4000 . 5000 _ 6000 _ ?000 _ ARCO ALASKA, ,.,, .o, Kup.ruk Field, North Slope' Alaska 4000 3000 I WEST-EAST 2000 1000 I I SURFACE LOCATIO#, 2538' FNL. I?0' FEL SEC. 23. TI2N. RSE S 27 DEO 11 MI N W 7236' (TO TAROET) TAROET TVD=$835 THD-9683 DEP-?236 SOUTH 6437 WEST 3305 TARGET LOCATION~ 1585' FSL. 34T$' FEL SEC. 26. TI2N, R8E TD LOCATION, 1297' FSL. 3623' FEL SEC. 26, TI2#. RSE SURFACE 1000 I JPARUK RIVER UNI', 20" DIVERTER SCHEMATIC 5 6 ,., 1 HCR / 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16"CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20"- 2000 PSI ANNULAR PREVENTER SRE ~6~0 7 , 6 5 4 13 5/8" 5000 F,..,t BOP STACK .ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'FI'OM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 L B~$15 OF IO~ATION ANO ~'/.b'VAT/ON /$ 0,$o // s, ;aa, ~0. 49 4 90, 4 NO, ~ x eo ~,9o0, ~oo.o~ 490, e/ ~,9OO~ ~oo.o~ 490~ /0~. ee ,goe, oo. o 4OD,/ 9. VIC/NITY I"~ ~ MI. /o FW,~.. 0.8. PAD R45' ,~$.1' ~4.0 eeO' ~0.4 195' 4O.R ~4.0 /~0' 4?.8 140' 4?.P IPO' 4~.~ ~8' 46.9 5' 47.3 F. ~, L.0.~, ~ 0 PO' 4?.g 53, I 45' 4Y, I 70' dS.~ 53. I 98~ 45.0 89.0 I RO' d6,8 5R.9 14 ~' 4~.8 53.0 / r O ' 48.4 198' ~$.3 55.0 SUAV£)'OR'$ CMPPffl NEOtSTKRffO AND LIOPNS~D ~ NRACTIC~ ~NO SU~V~YIN8 IN rH~ STATff OF ALASKA MADE ~ Mff ~ UN~R M~ OlR~r ~ T~T ALL OI~N~I~$ AND ~TAILS ANff ~N~T AS OF ~PRIL N$DK, $$00. C£A, 05 ;X. $$0?08 DOlL L $I rg 3, $ AS Bull r LOCATION M. Sht i ~ t NO..'NSK 8.30?d8 CEECK LIST FOR NEW VELL PE~TS IT_~M APPROVE ~ (I) ~e,e. ~ 1. (3) Admire ~ 9. 10. (10 amd i3) 12.' 13. (14 :hr~ 22) (23 :hr; 28) permit fee at:ached .......................................... Is the 2. Is well to' be located ima defimed pool ..2 .......................... 3. Is well located proper distance from prope~:y line .................. 4. Is we!! located proper distance from other wells ........ ~ ........... 5. is sufficient undedica:ed acreage available in this pool ............ 6. Is we!! :o be deviated and is wellbore plat included ................ 7. Is onerator the only affected par=v ......... ~' ....................... 8. Can permit be approved before fifteen-day wait ...................... 14. 15. 16. 17. 18. !9. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. is a conservation order needed ...................................... Is adm~astrarive approval needed ................................... Is :he lease number appropriate ..................................... Does :he well have a unique marne and n~mber ......................... IS a6nductor string provided ........................................ WiLl surface casimg pro~ect all zones reasonably exTecned :o serve as am umderground source of drinking water ..................... is enough cemen: used :o circuiaue on conductor and surface ......... Will cement tie in surface and intermediate or produc:ion strings .. Will camera: cover ~ known productive horizons ..................... Will al! casing give adequate safety in collapse, :ca,sion and burs=. Is :his well :o be kicked off from am e.~stimg we!!bore ............. Is old wei!bore abandommen: procedure included on 10-403 ............ Is adequate we!lbore separa:ion proposed ..................... ' ...... Is a diver:er system required ....................................... Is :he drilling fluid program schematic and lis: of equipment adequate ~ Are necessary diagr~ and descriptions of diveruer and BOPE attached. ~ Does BOPE have sufficient pressure rating - Test :o .~ 0~ psig ...~f~f Does :he choke ~=~ifoid comply w/AMI RP-53 (May 84) .................. Is the presence of HZS gas probable ............................. ~... .,, (]6) O~ "(29 thru 31) rev: 01/30/89 6.011. ~or 29. 30. 31. 32. exploratory amd Suratigraphic wells: Are da:a presented on po~em:ial overpressure zones? ................. Are seismic analysis dana presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented ----- , Addi:ional reouirements ............................................. /~ Additional R-~rks: ' 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. (NOTE: ** REEL HEADER ** **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/09/18 ORIGIN OF DATA: FEWD REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: FEWD DATE: 90/09/18 ORIGIN OF DATA: 3G20 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** RECEIVED OCT 0 1 1990 ~l~ka 011 & 0~ ~ms. ~mmission Anchor~e NFO NFl NN0 NN1 EWR ROP GRC FXE RHOB CAL NPSC MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD CTS CTS CTS CTS OHMM FT/H API HOUR G/C3 INCH P.U. 68 68 68 68 68 68 68 68 68 68 68 ** DATA VERIFICATION (every 100 FT) ** DEPT NF0 NFl NN0 NN1 GRC FXE RHOB CAL NPSC EWR ROP 4550.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4600.000 420.000 469.000 2600.000 2520.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4700.000 511.000 567.000 2424.000 2440.000 86.644 4.733 2.204 8.640 42.109 6.298 165.314 4800.000 559.000 559.000 2536.000 2504.000 95.595 .391 2.379 8.540 39.977 5.012 348.526 4900.000 541.029 516.912 2543.882 2499.824 94.548 .449 2.420 8.610 40.725 4.105 304.688 5000.000 535.000 527.000 2600.000 2536.000 86.015 .572 2.722 8.750 39.147 3.998 429.102 5100.000 519.000 497.000 2520.000 2488.000 88.744 .499 2.306 8.530 42.676 3.767 190.777 5200.000 569.162 550.352 2723.676 2643.676 86.723 .539 2.343 8.500 37.063 3.899 281.250 5300.000 104.520 559.000 599.000 2728.000 2568.000 .722 2.675 8.400 37.502 3.855 287.738 5400.000 83.548 532.634 497.875 2570.024 .495 2.412 8.500 2583.098 40.871 3.898 160.114 5500.000 105.875 529.209 575.275 2616.549 .487 2.454 8.590 2547.033 38.752 3.307 365.801 5600.000 121.830 639.000 567.000 2616.000 .581 2.839 8.590 2760.000 35.332 3.591 430.469 5700.000 79.488 591.000 599.000 2840.000 .736 2.610 8.400 2808.000 33.595 4.119 170.431 5800.000 94.842 631.000 607.000 2872.000 .679 2.248 8.530 2728.000 32.760 3.525 239.180 5900.000 96.479 575.000 591.000 2712.000 .609 2.361 8.450 2792.000 34.996 3.176 127.835 6000.000 105.777 551.000 567.000 2520.000 .484 2.594 8.690 2664.000 37.895 3.193 248.789 6100.000 103.937 639.000 647.000 2776.000 .574 2.565 8.520 2952.000 31.155 3.989 356.401 6200.000 86.429 591.000 647.000 2920.000 .430 2.566 8.950 2776.000 29.655 3.467 260.156 6300.000 102.634 607.000 591.000 2936.000 .510 2.371 8.510 2824.000 32.048 3.975 210.060 6400.000 109.017 599.000 583.117 2626.029 2622.204 .550 2.612 8.650 36.360 3.384 155.985 6500. 149. 6600. 108. 6700. 107. 6800. 111. 6900. 129. 7000. 159. 7100. 119. 7200. 146. 7300. 135. 7400. 116. 7500. 128. 7600. 119. 7700. 113. 7800. 118. 7900. 106. 8000. 101. 8100. 105. 8200. 97. 8300. 99. 8400. 96. 8500. 109. 8600. 92. 8700. 107. 000 089 000 859 000 610 000 408 000 119 000 921 000 763 0O0 961 000 405 000 417 000 432 0OO 461 000 893 00O 021 000 628 00O 196 000 188 000 789 000 186 000 315 000 869 000 806 000 648 567. · 566 · · 599. · 599. · 591. · 623. · 591 · · 607. · 551. · 575. · 591. · 599. 1. 639. · 575. · 655. · 636. 1. 577. · 599. · 631. · 639. · 583. · 599. · 623. · 000 697 948 811 000 636 0O0 555 0O0 598 000 849 O00 940 000 571 0O0 481 00O 389 834 756 000 422 000 640 000 513 000 633 685 097 490 976 000 673 000 751 000 556 000 601 000 847 00O 898 647.000 2.835 558.948 2.671 575.000 2.601 567.000 2.699 527.000 2.690 607.000 2.396 615.000 2.590 615.000 2.639 591.000 2.681 543.000 2.672 560.668 2.628 615.000 2.768 591.000 2.549 607.000 2.451 599.000 2.609 580.685 2.169 545.312 2.458 599.000 2.531 599.000 2.231 607.000 2.548 615.000 2.545 615.000 2.783 631.000 2.628 2648.000 8.660 2613.625 8.740 2600.000 8.400 2616.000 8.400 2536.000 8.490 2440.000 8.400 2680.000 8.400 2648.000 8.800 2648.000 8.730 2568.000 8.400 2561.328 8.520 2584.000 8.410 2648.000 8.870 2632.000 8.980 2728.000 8.490 2625.055 8.670 2649.955 8.810 2744.000 8.620 2760.000 8.580 2680.000 8.660 2648.000 8.480 2840.000 8.890 2728.000 8.780 2616.000 36.036 2703.020 36.619 2616.000 37.979 2584.000 38.676 2520.000 40.895 2440.000 41.348 2584.000 36.869 2504.000 36.294 2552.000 37.773 2456.000 41.245 2516.664 39.483 2568.000 37.878 2520.000 35.329 2680.000 33.967 2664.000 34.375 2678.638 34.957 2640.978 36. 091 2696.000 34.397 2728.000 33.513 2920.000 31.760 2680.000 35.968 2872.000 30.124 2600.000 33.364 4.009 2.687 2.634 2.691 3.298 2.748 4.541 4.550 4.246 5.092 5.035 4.390 3.545 3.331 3.783 4.075 4.168 4.074 3.990 4.584 6.566 4.710 5.336 281.656 186.504 150.293 238.862 196.782 313.916 115.280 258.009 276.923 445.313 386.543 302.054 268.066 179.121 202.930 173.772 46. 148 238.359 214.453 259.652 202.344 188.634 130.078 8800. 000 663. 000 583. 000 135.601 ' ·833 2.627 8900.000 631.000 583.000 107.731 .807 2.574 9000.000 127.056 2600 8 2728 10 628.689 609.276 2593 1.046 2.550 8 9100.000 616.002 647.000 2632 144.127 .697 2.572 8 9200.000 785.038 752.987 2624 278.227 6.119 2.452 8 9300.000 614.468 581.466 2505 129.483 .788 2.483 8 9400.000 504.308 514.939 2375 106.800 .903 2.420 8 9500.000 550.002 492.742 2419 97.474 1.064 2.584 8 9600.000 466.979 467.309 2180 104.716 87.657 2.351 9 9700.000 563.876 563.876 2619 100.280 1.010 2.535 8 9800.000 617.225 637.084 2920 80.213 .850 2.422 8 9900.000 637.559 600.838 2819 77.618 1.160 2.372 8 10000.000 573.513 538.276 2572 103.483 1.399 2.481 8 10100.000 -999.250 -999.250 -999 -999.250 -999.250 .500 -999 ** 534 DATA RECORDS ** 1024 ** FILE TRAILER** FILE NAME: 3G20.MWD SERVICE NAME: FEWD VERSION #: V2.4 DATE: 90/09/18 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: .000 .780 .000 .660 .103 .930 .00O .590 .050 .750 .534 · 680 .892 .490 .976 .850 .291 .010 .503 .990 · 618 .500 .037 .590 .282 · 670 .250 .250 FROM 2648.000 34.762 2664.000 21.981 2533.654 35.348 2531.334 36.605 2601.987 32.336 2444.316 39.899 2391.892 46.107 2323.976 45.101 2213.277 52.545 2698.841 34.897 2863.391 31.241 2807.850 32.427 2589.068 38.551 -999.250 -869.348 4550.00 TO 3.421 5.113 4.813 4.524 3.636 5.526 2.824 3.309 3.001 3.232 11.374 9.956 3.783 -999.250 10150.00 FT 202.734 199.023 155.757 213.212 85.212 143.059 180.134 132.552 83.475 31.227 74.402 66.787 47.505 -999.250 ********** END OF FILE (EOF # 2) ********** TAPE TRAILER** SERVICE NAME: FEWD DATE: 90/09/18 ORIGIN OF DATA: 3G20 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 90/09/18 ORIGIN OF DATA: FEWD REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT