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187-099
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3H-17 KUPARUK RIV UNIT 3H-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 3H-17 50-103-20081-00-00 187-099-0 W SPT 5927 1870990 1500 2810 2810 2810 2810 730 840 840 840 4YRTST P Austin McLeod 6/1/2025 MITIA. 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 3H-17 Inspection Date: Tubing OA Packer Depth 910 2030 2000 2000IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250602191650 BBL Pumped:1.9 BBL Returned:1.5 Thursday, July 24, 2025 Page 1 of 1 elevated OA pressure -- jbr MEMORANDUM TO: Jim Regg I/ P.I. Supervisor i eje)— FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Cas Conservation Commission DATE: Tuesday, June 8, 2021 SUBJECT: Mechanical Integrity Tests CowcoPbillips Alaska, Inc. 3H-17 KUPARUK RN UNIT 3H-17 Src: Inspector Reviewed By: P.I. Supry ..J,.-3-1— Comm Well Name KUPARUK RIV UNIT 3H-17 API Well Number 50-103-20081-00-00 Inspector Name: Brian Bixby Permit Number: 187-099-0 Inspection Date: 6/1/2021 ' Insp Num: milBDB210602040946 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 311-17 'Type Inj w TVD 1 5927 Tubing 1 2796 j 2796 - 2794 2795 - PTD 1870990 • Type Test SPT Test psi 1500 - IA 210 1815- 1790 - 1785 " BBL Pumped: 1.5 "BBL Returned: 3 OA 525 690 ' 680 - 680 Interval 4YRTST Notes: Tuesday, June 8, 2021 Page I of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 15,2017 TO: Jim Regg P.I.Supervisor 74( 61 z-0/t 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-17 FROM: Chuck Scheve KUPARUK RIV UNIT 3H-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3H-17API Well Number 50-103-20081-00-00 Inspector Name: Chuck Scheve Permit Number: 187-099-0 Inspection Date: 6/4/2017 Insp Num: mitCS170605171138 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well j 3H-17 - Type Inj W TVD 5927 - Tubing 2906 2905 - ( 2905 - 2905 - PTD 1870990 Type Test SPT Test psi 1500 IA 990 2000 - 1970_ 1970 - BBL Pumped: 1.2 BBL Returned: 1.2 - OA 250 370 370 - 370 - Interval 4YRTST P/F P ✓ Notes: scANNED AUG 3 0 2017. Thursday,June 15,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,June 12,2013 ( -� </6/ZI/ > P.1.Supervisor ( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-17 FROM: John Crisp KUPARUK RIV UNIT 3H-17 Petroleum Inspector Src: Inspector Reviewed By: P.1.Suprv....1i=- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3H-17 API Well Number 50-103-20081-00-00 Inspector Name: John Crisp Permit Number: 187-099-0 Inspection Date: 6/9/2013 Insp Num: mitJCr130610084825 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Type Well yP J TVD 5927 IA 900 2220 2200 2195 3H-17 W PTD 1870990 Type Test SPT,Test psi 1500 OA 460 600 595 595 Interval 4YRTST P/F P Tubing 2898 2898 2898 2898 Notes: 1.4 bbl pumped for test. SCANNED FEB 2 0 2014 Wednesday,June 12,2013 Page 1 of 1 • • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 May 15, 2012 %AOC At1C7 2: LIB L Commissioner Dan Seamount 68 0 qg Alaska Oil & Gas Commission 1 7 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU), and the Kuparuk field (KRU). Each of these wells was 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 spreadsheets 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 spring of 2012. The corrosion inhibitor /sealant was pumped in the months of April and May 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. Sincerely, Martin Walters 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 5/15/2012 1C,1D,1E,2L,3H 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 qal - 1C-133 50029230130000 2010770 16" 3.9 12" 5/8/2012 6.8 5/14/2012 1D-116 50029229150000 1981720 10" 1.2 10" 5/8/2012 4.3 5/15/2012 i 1E-123 50029232080000 2040740 5" n/a 18" n/a 5.1 4/9/2012 2L -304 50103206130000 2100110 31" 0.30 20" 3/30/2012 4.3 5/14/2012 2L -306 50103206300000 2101820 8" n/a 8" n/a 3.4 5/14/2012 2L -310 50103206160000 2100280 25" 0.25 12" 3/30/2012 2.6 5/14/2012 2L -312 50103206260000 2101640 13" n/a 13" n/a 2.5 5/14/2012 2L -319 50103205520000 2071120 112" 1.00 20" 3/30/2012 6 5/14/2012 2L -320 50103206270000 2101660 36' 1.00 50" 3/30/2012 3.4 5/14/2012 3H -17 50103200810000 1870990 19" n/a 19" n/a 3.4 4/9/2012 I • III vr"*" ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 *4iiReaViihEtAii Ali % O' Zt) I March 9, 2012 Commissioner Dan Seamount A.inoL.i ri.:1i 2: SI) 0.- COraiLdliii Alaska Oil & Gas Commission Ailtorngs 333 West 7 Avenue, Suite 100 . -...---.. • ..-----,--- -.-...--.-.....-..--- Anchorage, AK 99501 ( 6 a r l - 0 qg Commissioner Dan Seamount: 31-1-17 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. Sincel, J MJ eland Z ConocoPhillips Well Integrity Projects Supervisor . 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 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 31" NA 13" NA 5.95 2/14/2012 3G-20 50103201410000 1901230 SF NA 24" NA 3.83 2/14/2012 31-17 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 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 3H-17 Run Date: 12/15/2009 December 21, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3H-17 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20081-00 ~~~~'~ F~t~ ~ ZO~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto ei ~allibui-toncom Date: U~-~ d~S~ -D~~ l~a~r r~ ~; 1~ /~ Signed: jt ~`~~ ~ MEMORANDUM 'ro: Jim Regg ~ ~?~~ ~(~(~ ~1 P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 1Q 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-17 KUPARiIK RN UNIT 3H-17 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv tJ ~~ Comm Well Name: KUPARUK RN LTNIT 3H-17 API Well Number: 50-103-20081-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS090608151358 Permit Number: 187-099-0 ~ Inspection Date: 6/7/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wel1T 3x-1~ Type Inj. ~' ~ TVD 592~ IA~ 660 2200 2iso ( ziso ~ ~ P.T.D 1870990 ---- TypeTest - SPT Test psi I - I500 ~ QA 200 - 400 400 400 - Interval ar~TST p~ r ~ Tubing z~oo 2~00 2~0o z~oo Notes: Pretest pressures observed and found stable. . ,~t~ .~. ~ sE '~~~it;i ~ .'~':~F° tivrac~:s~ +" l) (.i _ i ' . Wednesday, June 10, 2009 Page 1 of 1 MEMORANDUM ) ) State of Alaska Alaska Oil and Gas Conservation Commission TO: r R ./7 ' 1m egg , V "'~"', ä 7c (iA.,e P.I. Supervisor ,,,\t:: 11 ' I." DATE: Wednesday, June 14,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS A.LASKA INC 3H-17 KUPARUK RIV UNIT 3H-17 Src: Inspector \C&1;OQQ FROM: John Crisp Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. SuprvJj<%- Comm Well Name: KUPARUK RIV UNIT 3H-17 Insp Num: mitJCr060613125005 Rei Insp Num API Well Number 50-103-20081-00-00 Permit Number: 187-099-0 Inspector Name: John Crisp Inspection Date: 6/10/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -Well ~-17-'lTypeI-~jl-w ! TVD .. I 5927 i-- IA --1'850 fD4Ö'-,' 1730'- -.1725---¡-------, - --.- P.!. -] 187Ó9901TYP;Test ¡ SPT~ PS¡j - 150~ OA I 28~r 390 -1- 390 -t--~ L~I~--=-~ Intery-ª.L.4YRTST___XŒ__u~______,_______ Tu~~~___ 2740. _L.2740 __..1_=~4~_ J 2740 ,_.___.L___________ Notes 1.1 bbl's pumped for test. SCANNED ~JUN 2 7 2006 Wednesday, June 14,2006 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor Chair THRU: Tom Maunder P.I. Supervisor FROM: John H. Spaulding Petroleum Inspector DATE: June 27, 2002 SUBJECT: Mechanical Integrity Tests PAl 3H multiple KRU Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. , 'Welll 3H-15 I Type inj. I G i T'.V.D. 1"5832 ! Tubing'l' 3700 I "370(~ I '3700 I' 3700 l lntervall 4 P.T.D.I 1871030 Ty'petestI 'P ITeStps. il 1~458 I Casingl' ~'2,7,5 1'2875 1,285o,,1' 2050 I' 'PIE I P Notes: We,,I 3,-17 I Type,nj.I G I T.V.D. 15927 I Tubingl 1'450'1 1'~0I'I~ I'nte~va'l 4' P.T.D.I 18709,,90 ITypetes,tlp ,, JTestpsiI 1482 J CasingI 200 1"2280 I 2270 I 2260 I 'Pi'F I P Notes: "'w~,I 3.-~8 , 'P,T.D.[ 1880090 Notes: , Well] 3H-22 P.T.D.J 1880110 Notes: 'Weil'I 3"-24 ,P.T.D.I 196015O Notes: Type lnj'l' S IT'v'D' I~'1 Tubin'gl 14°0 I~''°° I~43° I1425 I'nterVa'l 4 Type testl, P I Testpsil 1458 I Ca,,sin~ I' '~875 I 23201 2320 I~ 2320 I p/F I P Type lnj.I S I T.v'.DiI 5951"l'Tubir~gi 1600 I 1490 I149° I' ¥46O I~ntervall 4 ','rypetestI P IT~stpgil 1'488 I Casi,n.g.I ~00.1,'2~80 I ~50 I' 21:4° I PiE .I P Type Inj.! S I I I I I' I' I"~o I,'nterVa, I' 4 Type testi 'P , IT.e,s,t psi! 1485 '! CaSing I 1400 I 2275 I 2260' I, 2250 '1 ' PIE I P Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Page 2 of 3 Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: _5 Attachments: none Number of Failures: .0.0 Total Time during tests: 3 hrs. cc: none MIT report form 5/12/00 L.G. mit(2) kru 3h 6-27-02js.xls 7/16/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1082' FNL, 282' FWL, Sec. 12, T12N, RSE, UM At top of productive interval 3890' FNL, 1191' FVVL, Sec. 1, T12N, RSE, UM At effective depth At total depth 1124' FNL, 1164' FVVL, Sec. 1, T12N, RSE, UM 5. Type of Well: Development __ Exploratory__ Stratigraphic_ Service__X (asp's 498654, 6000579) (asp's 499562, 6005546) (asp's 499533, 6005812) 6. Datum elevation (DF or KB feet) RKB 76 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3H- 17i 9. Permit number / approval number 187-099 10. APl number 50-103-20081 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing CONDUCTOR SURF CASING Length 115' 3614' 8525' PROD CASING 8614 feet Plugs (measured) 6341 feet 8323 feet Junk (measured) 6128 feet Size Cemented 16" 210 SxAS I 9-5/8" 1450 Sx AS III & 400 Sx Class G 7" 300 Sx G & 175 Sx CS I Milled Cement & Sand (9/9/00) to 8323' MD. Measured Depth True vertical Depth 115' 115' 3690' 3017' 8601' 6332' RECEIVED Perforation depth: measured 8275 - 8285'; 8299 - 8311'; 8340 - 8360' true vertical 6093 - 6100'; 6110 - 6119'; 6140 - 6155' MAR 2 ? ; 001 Alaska Oil & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55, Tubing @ 34' MD; 2-7/8", 6.5#, J-55, Tubing @ 8123' MD. Packers & SSSV (type & measured depth) Camco 'HRP-I-SP' Packer @ 8049' MD. Camco 'TRDP-1A-SSA' @ 1827' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl - Representative Daily Average Production or Injection Data Gas-Mci Water-Bbl - 500 - 500 Casing Pressure Tubing Pressure 2900 29OO 15. Attachments Copies of Logs and Surveys run m Daily Report of Well Operations __X 16. Status of well classification as: Oil __ Gas __ Suspended Service __.(Water Inj)~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 · Date '-"-"~..,~ ~,~__O~' ~ ' Prepared by Jot'in Peir~e 265-6471 SUBMIT IN DUPLICATE 3H-17i DESCRIPTION OF WORK COMPLETED CEMENT SQUEEEZE & PERF BREAKDOWN TREATMENT 6/5/00: RIH & tagged fill at 8341' MD. 8/23/00: Pumped gelled sand slurry containing 2250 lbs of sand, to spot an isolation sand plug across the lower open 'A' Sand perforation intervals located at: 8275- 8285' MD 8299-8311' MD 8340- 8360' MD 8125100: RIH&dumped 2 gallons of Latex-SandCap on top of sand plug to 8264'MD. 8/26/00: Performed a Cement Squeeze for 'C' Sand Shutoff as follows: MIRU CTU & PT equipment. RIH w/CT & reciprocated a Diesel/Xylene wash across the open 'C' sand perforation interval located above the sand plug at: 8219 - 8229' MD Pumped total of 40 bbls of Diesel/Xylene, and displaced the fluids into the formation pumping Seawater. POOH w/CT. SI well to perform an injection step rate test, then RIH w/CT & pumped 27 bbls of Latex Acid Resistive Cement to squeeze the perforation interval (above). Placed a total of 22 bbls of cement behind pipe, but never got more than a 350 whp bump. Contaminated cement w/biozan & jetted contaminated cement from wellbore to 8267' MD. POOH w/CT. RD. 8/27/00 - 8/28/00: Performed a Cement Resqueeze for 'C' Sand Shutoff as follows: RU CTU & PT equipment. RIH w/CT & resqueezed the 'C' sand perforation interval (listed above). Pumped 7 bbls of Neat LARC, followed by 24 bbls of LARC w/aggregate, and placed an additional 1 bbl of cement behind pipe. Held 2700 psi squeeze pressure for I hour, then contaminated cement w/biozan and jetted contaminated cement from wellbore to 8257' MD. POOH w/CT. RIH w/2.22" milling BHA and milled 5' of cement to 8262' MD, but could not make progress deeper than 8262' MD. POOH w/BHA. RD. 9/1/00 - 9/9/00: RIH & tagged cement at 8258' MD, then made multiple runs w/underreamers & milling BHA's to mill out cement & sand plug down to 8300' MD. Established good communication with the 'A' sand perforation intervals (listed above). RD. 1/20/01- Ran an Injection Profile log indicating all the injection was going into the 'A' sand perforation intervals. 2/9/01' RU hardline to wellhead & PT equipment. Pumped 280 bbls of Slick Diesel fullbore @ 2 bpm w/4000 whp for Breakdown of the open 'A' sand perforation intervals (above). Did not see breakdown response. RD. Returned the well to water injection & obtained a valid injection test. MICROFILMED 9/28/O0 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well OIL C~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Oper'ator 7. Permit Number ARCO Alaska, Inc. 87-99 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20081 4. Location of well at surface 9. Unit or Lease Name 1082' FNL, 282' FWL, Sec.12, T12N, R8E, UN Kuparuk River Unit ._ At Top Producing Interval .. 10. Well Number 3890' FNL, 1191' FWL, Sec. 1~ T12N, R8E, UM 3H-17 At Total Depth i 1. Field and Pool 1124' FNL, 1164' FWL, Sec.1, T12N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 76' RKBI ADL 25531 ALK 2657 ,, 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. J15. Water Depth, ifoffshore ]16. No. of Completions 10/03/87 10/09/87 06/27/88*I IN/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 8614'MD/6341 'TVD 8514'MD/6268'TVD YES'~ NO [] 1827 feet MD 1600' (aDprox) 22. Type Electric or Other Logs Run D IL/SFL/SP/Cal/GR~ FDC/CNL~ CBT, (]CT "]23. CASING, LINER AND CEMENTING RECORD .... SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 2b," ?IR _~× AR I 9-5/8" 36.0# J-55 Surf 3691 ' 12-1/4" 1450 ~.~x AS I II &-/~Orl .~x £1a~_~ , 7" 26.0# J-55 Surf 8601' 8'1/2" .. _~lgt~ .~x £1a$$ C. & 175 s;~ CS . , 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) 2-7/8" 81 ?~ ' 8049 Perforated w/4 spf, 90° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 8341 '-8361 'MD/6141 '-6156'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS~MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED '' 01L-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~l~ 28. CORE DATA "'Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ,.. ir, I~L ~ None [~.~G '~ t 1 * NOTE: Drilled RR 10/11/87. Perforated well and tubing run 5/23/88., Fractured well 6/27/88. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE WC5/029 GEO~_OGIC MARKERS ' ~' FORMATION TESTS · , , . '.. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. "1 Top Kuparuk C 8220' 6052' N/A Base Kuparuk C -. ,8226' 6057' Top Kuparuk A 8261' 6082' Base Kuparuk A 8389' 6176' 31. LIST OF ATTACHMENTS Addendum (dated 7/7/88) , ., 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed__ //~) ~ ~)-/,)~' Title Associate. . Engineer` Date ... ~'~-~-~~~-~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 2i: 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 ADDENDUM WELL' 3H-17 6/12/88 RU Hot Oil. Pmp 20 bbls diesel + 5% Musol. Displ d]esel/Musol thru "A" sand perfs w/54 bbls diesel @ 1.5 BPM, 3000 psi. Secure well. 6/27/88 ~ ~'rac Kuparuk "A" sand perfs 8340'-8360' in seven Stages per procedure dated 6/20/88 as follows' Stage 1: 20 bbls 145° diesel @ 2 BPM, 3100 - 2970 psi Stage 2: 150 bbls gelled diesel @ 22 BPM, 6900 - 5600 psi Stage 3: 900 bbls gelled diesel @ 22 BPM, 6400 - 5070 psi Stage 4: 38 bbls gelled diesel w/ i ppg 16/20 Carb @ 22 BPM, 5070 - 5100 psi Stage 5: 92 bbls gelled diesel w/2 ppg 16/20 Carb @ 5100 - 5390 psi Stage 6: 85 bbls gelled diesel w/4 ppg 16/20 Carb @ 5390 - 5800 psi Stage 7' 31 bbls gelled diesel w/6 ppg 16/2'0 Carb @ 5800 - 8000 psi Screened out at 8000 psi. 7/3/88 Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 1316 bbls diesel 20,000# 16/20 Carbolite 9600~ 5500 ps i RIH w/coiled tbg & pumped 1-1.5 BPM G/D. Received sand @ _+4000'. Well started flowing @ 7850'. Tagged fill @ 8490' & washed to 8502'. Displace well w/75 bbl diesel. Clean out plugged lines. RIH w/coiled tbg. Tagged SSSV @ 1821'. Pressured up & opened SSSV. RIH washing w/G/D. Tagged sand @ 2540'. Washed to 10113'MD and tagged bottom. Washed up to 9880'. Started sticking @ 10061'MD. Displacing w/diesel @ 9880'._,,, ~~c'e3~ed ~go ~0~b'l. d~S~lr~cmDa~e~rr~~ AL,. . ,A OIL AND GAS CONSERVATION COMMIb,.~ION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate __ Plugging Alter casing Repair well Pull tubing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X WI 4. Location of well at surface 1082' FNL, 282' FWL, Sec. 12, T12N, At top of productive interval 3890' FNL, 1191' FWL, Sec. At effective depth 1259' FNL, 1178' FWL, Sec. At total depth 1124' FNL, 1164' FWL, Sec. 1, T12N, 1, T12N, 1, T12N, R8E, UM R8E, UM R8E, UM R8E, UM 12. Present well condition summary Total Depth: measured 8 true vertical 6 614' feet Plugs (measured) 3 41 ' feet None Effective depth: measured true vertical 851 4' feet Junk (measured) 6 2 6 8' feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 84' 1 6" 210 Sx AS I 3660' 9 5/8" 1450 Sx AS III & 400 Sx Class G 8 5 7 0' 7" 300 Sx Class G 175 Sx CS I measured 8300'-8312', 8276'-8286', 8220'-8230' @ Perforate __Pull tubing Other X Convert well to WI. 6. Datum elevation (DF or KB) RKB 7. Unit or Property name Kuparuk River Unit 76 ,feet 8. Well number 3H-17 9. Permit number 88-814 10. APl number so-103-20081 11. Field/Pool Kuparuk River Field Kul3aruk River Oil Pool Measured depth ' True~.l~epth 115' 115' 3691' 3017' 8601 ' 6331 ' 12 SPF, 8340'-8360' @ 4 SPF true vertical 6111'-6120', 6093'-6101', 6052'-6060' @ Tubing (size, grade, and measured depth 2 7/8" J-55 set at 8123' Packers and SSSV (type and measured depth) Camco HRP1-SP @ 8049', Camco TRDP-1A-SSA @ 1827" 12 SPF, 6140'-6155' @ 4 SPF 13. Stimulation or cement squeeze summary Well was converted from oil producer to water injector. Procedure and MIT record are attached. Intervals treated (measured) Treatment description includin~l volumes used and final pressure 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 320 330 0 1000 psi 190 psi 0 0 -1350 700 psi 1950 psi 16. Status of well classification as: Oil ~ Gas Suspended Service Water Injector 17. I hereby certify that the foregoing is true and correct to the .best of my knowledge. Si~ned ("~ "V"'% Title ~ Z ~ Form -10-404 ~v 06/15/88 Date SUBMIT IN DUPLI/CATE .... WELL SERVICE REPOF Subsidiary of Atlantic Richfield Corn WELL i PBDT CONTRACTOR /?C - REMARKS FIELD - DISTRICT. STATE OPERATION AT REPORT TIME IDAYS i DATE / //-/~'- CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Temp. Weather Report OF I Wind Vel. Chill Factor I Visibility °FI , ,. miles[ knots Signed REMARKS CONTINUED: DESCRIPTION CAMCO OTIS SCHLUMBERGER DRESSER. ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision Pre-Job Safety Meeting TOTAL FIELD ESTIMATE DAILY ACCUM. TOTAL il Signed~, ~' , /~o¢_E -. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG , , 1. Status of Well Revised to reflect added perforations Classification of Service Well OIL ~. GAS ~ SUSPENDED ~ ABANDONED ~ SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 87-99 3. Address .- 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 . 50- . 103-20081 r' . 4. Location of well at surface 9. Unit or Lease Name 1082' FNL, 282' FWL, Sec.12, T12N, R8E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 3890' FNL, 1191' FWL, Sec. 1, T12N, R8E, UH 3H-17 At Total Depth 11. Field and Pool 1124' FNL, 1164' FWL, Sec.l, T12N, R8E, UH Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet 0i l Pool 76' RKBI ADL 25531 ALK 2657 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. or Aband. I 15. Water Depth, if offshore ]16. No. of Completions 1 0/03/87 1 0/09/87 06/27/88*I N/A feet MSLI 1 17. TotalDepth(MD+TVD) ,8.PlugBackDepth(MD+TVD) 19. Directional Survey [ 20. Depth where SSSV set I 21. Thickness o' Permaf'rost 8614'MD/6341 'TVD 8514'MD/6268'TVD YES [] NO [] 1827 feet MD 1600' (approx) _ 22. Type Electric or Other Logs Run DIL/SFL/SP/Cal/GR, FDC/CNL, CBT, GCT .... 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1R" 67_r~# H-b,~3 _~,_,rf 115' 24" 210 sx AS I q-c~/R' ~,~ {3E _l-C,& R,,r~ '~,~-,ql ' 19-1/h" lhC,~ 7" 26.0# J-55 Surf 860!' 8-!/2" 300 sx C~._~ss G & !75 , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/12 spf, 60° phasing 2-7/8" 8123' 8049' 8220 ' -8230 ' MD/6053 ' -6060 'TVD ~6. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 8276 ' -8286 ' MD/6093 ' -6101 'TVD ~--~ ~.. , EPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL usED " phasi ~;ee attached Addendum, dated 10/26/88, for Fracture data ag 8341 '-8361 'MD/6141 '-6156'TVD JAN ~ . r~ ,PRODUCTION TEST Date First Production Method of upera~,on ~r"~owing, gas litt, etc.~ N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GA~-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED=1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None * NOTE: Drilled RR 10/11/87. Perforated we]] and tubing run 5/23/88. Fractured we]] 6/27/88. Added perforations 9/22/88. Form 10~,O7 WCS/OZ9 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH 8220' 8226' 8261' 8389' TRUE VERT. DEPTH 6052' 6057' 6082' 6176' 30. FORMATION TESTS Include interval te~ted, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Addendum (dated 10/26/88) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Area Dri 11 ing EngineerDate 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 inositu combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- 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 ADDENDUM WELL: 6/12/88 6/27/88 7/3/88 3H-17 RU Hot Oil. Pmp 20 bbls diesel + 5% Musol. Displ diesel/Musol thru "A" sand perfs w/54 bbls diesel @ 1.5 BPM, 3000 psi. Secure well. Attempt to frac Kuparuk "A" sand perfs 8340'-8360' in seven stages per procedure dated 6/20/88 as follows: Stage 1: 20 bbls 145° diesel @ 2 BPM, 3100 - 2970 psi Stage 2: 150 bbls gelled diesel @ 22 BPM, 6900 - 5600 psi Stage 3: 900 bbls gelled diesel @ 22 BPM, 6400 - 5070 psi Stage 4: 38 bbls gelled diesel w/ 1 ppg 16/20 Carb @ 22 BPM, 5070 - 5100 psi Stage 5: 92 bbls gelled diesel w/2 ppg 16/20 Carb @ 5100 - 5390 psi Stage 6: 85 bbls gelled diesel w/4 ppg 16/20 Carb @ 5390 - 5800 psi Stage 7: 31 bbls gelled diesel w/6 ppg 16/20 Carb @ 5800 - 8000 psi Screened out at 8000 psi. Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 1316 bbls diesel 20,000# 16/20 Carbolite 9600# 5500 psi RIH w/coiled tbg & pumped 1-1.5 BPM G/D. Received sand @ ±4000'. Well started flowing @ 7850'. Tagged fill @ 8490' & washed to 8502'. Displace well w/75 bbl diesel. Clean out plugged lines. RIH w/coiled tbg. Tagged SSSV @ 1821'. Pressured up & opened SSSV. RIH washing w/G/D. Tagged sand @ 2540'. Washed to 10113'MD and tagged bottom. Washed up to 9880'. Started sticking @ 10061'MD. Displacing w/diesel @ 9880'. Displace coiled tbg w/74 bbl diesel. Diesel F/9880'-3100'. G/D F/3100'. RD Fracmaster. ADDENDUM WELL: 8/12/88 9/22/88 3H-17 RU CTU; tst Ins; OK. Cln out well. Displ well to cln diesel. Secure. RU Schl. Perf well f/8276'-8286', 8220'-8230', 8276'-8286', 8220'-8230', 8300'-831~' & 8300'-8312' MD @ 6 SPF, 30° phasing. Turn well over to Production. · Dat~a .... /d:;,,,.g ..... 2 =- 6 ............. 6 -" a,;- e? ~ ~ o Crc c__ SUB-SURFACE DIRECTIONAL SURVEY [~]UIDANCE [~]ONTINUOUS r-flooL RECEIVED JUN 1 0 ]988 Alaska Oil & Gas Cons. Commission Anchorage Company ARCO ALASKA, INC. Well Name 3H-17 (1082' FNL, 282' FWL, SEC 12, T12N, RSE, UM) i i i ! ! Field/Location_KUPARUK, NORTH. SLOPE ., .,ALASKA Job Reference No. 72610 Lm3~3ed By: SARBER [3ate 20-FEB-88 Computed By: KOHRING ',- e GCT OIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKa, INC. KUPARUK NORTH SLOPE,ALASKA SURVEY DATE: 20-FEB-88 ENGINEER: SARBER METHODS OF COMPUTATION TOOL LOCtTION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH g DEG 6 MIN EAST ARCO ALASKA, INC. 3H-17 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: O2-MAR-S8 PAGE DATE OF SURVEY: 20-FEB-88 KELLY BUSHING ELEVATION:' 76.00- FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SU3-SE~ COURSE MEASURED VERTICAL VERTIC.~L DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0,00 0,00 -76,00 0 0 N O_ 0 E 100,00 100.00 24,00 0 11 S 42 57 E 200.00 200.00 124.00 0 16 S 77 9 E 300.00 300.00 224.00 0 22 N 77 6 E 400.00 399.99 323.99 0 23 N 68 31 E 500.00 499.99 423.99 0 21 N 84 8 E 600.00 599.99 523.99 0 20 N 81 `9 E 700.00 699.99 623.99 0 58 N 53 21 E 800 O0 799 83 723 83 5 4 N 27 35 : 900.00 899.03 823.03 9 29 N 28 2 c 1000.00 997.10 921.10 12 59 1100.00 1093.48 1017.,48 17 45 1200.00 1187.79 1111.79 21 6 1300.00 1280.01 1204.01 23 56 1400.00 1370.45 1294.45 26 32 1500.00 1458.B0 1382.80 29 34 1600.00 1543.68 1467.69 33 59 1700.00 1625.11 1549.11 37 2 1800.00 1703.1.5 1627.15 39 51 1900.00 1780.11 1704.'11 39 14 VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH E~ST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 2000.00 1858.09 1782.08 38 16 2100.00 1937.03 1861.03 37 44 2200,00 2016.00 1940.00 37 34 2300.00 Z094.96 2018.96 38 51 2400.00 21'71.89 2095.88 40 20 2500.00 2246.89 2170.89 42 20 2600,00 2320,87 2!44,97 41 50 2700.00 2394.63 2318.63 43 48 2800.00 2464.55 2388.55 47 26 2900,00 2530,05 2454.05 50 6 0.00 0.00 0.00 N 0.00 E -0.17 0.05 0.20 S 0.13 E -0.30 0.09 0.39 S 0.54 E -0.20 0.15 0.38 S 1.0~ E 0.11 0.00 0.16 S 1.71 E 0.40 0.13 0.03 N 2-33 E 0.58 0.18 0.12 N 2.92 E 1.00 2.46 0.42 N 3.6`9 E 5.71 3.40 4.76 N 6.41 E 17.46 4.54 15.74 N 12.13 E N 27 41 E 35.88 4.37 N 24 50 E 61.22 4.15 N 24 15 E 93.32 4.08 N 24 ! E 130.60 1.96 N 21 26 E 172.05 2.70 N ZO 34 E 217.93 4.58 N 17 44 E 269.85 3.59 N 14 6 E 327.42 4.16 N 13 4~ E 389.75 2.11 N 15 40 E 453.28 1.23 3000.00 2593.98 2517.98 50 24 3100.00 2657.40 2581.40 50 57 3200.00 2719.96 2643.96 51 36 3300.00 2781.64 2705.54 52 14 3400.00 2842.49 2766.48 52 44 3500,00 2902,74 2826.74 53 ~ 3600.00 2962.55 2885.5~ 53 2~ 3700.00 3022.0~ 2946,04 53 21 3500.00 3081.56 3005.56 53 29 3900.00 3140.90 3064.90 53 49 N 17 5 E 515.39 N 18 56 E 1576.01 N 19 43 E 636.39 N 19 33 E 696.65 N 19 1~ E 759.55 N 19 8 E 824.73 N 17 43 E ~91.20 N 15 50 E 958.10 N 13 43 E 1029.21 N 13 3 E 1104.56 N 13 24 E 1181.25 N 13 33 E 1258.35 N 13 47 E 1336.11 N 14 1 E 1414.55 N 14 13 E 1493.60 N 14 45 E 1573.04 N 15 1 5 1652.77 N 15 ~ E 1732.71 N 14 51 E 1912,64 N 14 43 E 1892,74 0.00 N 0 0 E 0.24 S 34 22 E 0.67 S 54 16 E 1.14 S 70 46 E 1.72 S 84 34 E 2.33 N 89 18 E 2,92 N 87 41 E "~ 3,70 N 83 28 E 7.9~ N 53 26 E 19.87 N 37 38 E 32,92 N 21,34 E 39,23 N 32 57 E 56,71 N '33,02 E 65,62 N 30 12 E ~7.05 N 46.55 E 98.71 N 28 8 E 122.25 N 52.52 5 137.31 N 27 5 E 161,60 N 78,95 E 179,86 N 26 2 E 205,26 N 95,79 E 226,52 N 25 1 E 255.18 fl 113.08 E 279.11 N 23 53 E 310.90 N 129.17 E 336.67 N 22 33 E 371.71 N 143.68 E 398.51 N 21 8 E 433.42 N 160.07 E 462.03 N 20 16 E 1.70 0.81 1.69 3.08 I .37 0.99 I .51 3.95 3.79 0.48 493.49 N 177.69 E 524.51 N 19 48 E 551.84 N 196.72 E 585.86 N 19 37 E 609.75 N 216.93 E 647.19 N 19 35 E 667.43 N 237.86 E 708.55 N 19 36 E 727.75 N 259.01 E 772.45 N 19 35 E 790.36 N 280.27 E 838.58 N 19 31 E 854.33 N 301.06 E 905.83 N 1'~ 24 E 918.97 N 320.55 E 973.27 N 19 13 998.07 N 338.78 E 1044.53 N 13 55 E 1061.60 N 356.11 E 1119.74 N 18 32 E 0.42 0.65 0.60 0.61 0.40 0.61 0.34 0.96 0.45 0.47 1136.46 N 373.67 E 1196.31 N IS 12 E 1211.64 N 391.74 E 1273.39 N 17 54 E 12.97,44 N 410,15 E 1351.20 N 17 40 E 1363.85 N 429.07 E 1429.75 N 17 27 E 1440.80 N 448.47 E 1508.98 N 17 17 E 1518.06 N 468.48 E 15~8.70 N 17 9 E 1595.50 N 489.12 E 1668.79 N 17 2 E 1673.09 N 510.13 E 1749.13 N 16 57 E 1750.71 N 530.91 E 1~29.44 N 16 52 E 1828.54 N 551.42 E 1909.8~ N 16 46 E COMPUTATION DATE: O2-MAR-88 ARCO ALASKA, INC. 3H-17 KUPARUK NORTH SLOPE,ALASKa DaTE KELLY BUSHING 3F SURVEY: ELEVATION: ENGINEER: INTERPOLA'TEO VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH COURSE VERTICAL DEVIATION AZIMUTH SECTION DEG MIN DEG M[N FEET PAGE Z 20-FEB-88 75.00-~T SARBER 4000.00 3199.67 3123.67 4100.00 3257.88 3181.88 4200.00 3316.85 3240.86 4300.00 3380.60 3304.60 4400.00 3444.74 3368.74 4500.00 3508.72 3432.72 4600.00 3573.07 3497.07 4700.00 3638.92 3562.92 4800.00 3705.08 3629.08 4900.00 3771.30 3695.30 54 9 N 14 38 E 1973.26 54 3'7 N 14 35 E 2054.19 51 58 N 14 47 E 2134.57 49 57 N !6 34 E 2211.07 50 13 N 16 34 E 2287.13 50 12 N 16 29 E 2363.35 49 16 N 15 29 E 2439.29 48 39 N 14 17 E 2514.20 48 35 N 14 Z E 2588.89 48 24 N 13 59 E 2663.54 0.90 1906.81 N 571.95 E 1990.74 N 16 41 E 0.43 1985.48 N 592.44 E 2071.99 N 16 36 E 6.78 2063.64 N 612.70 E 2152.68 N 16 32 E 0.18 2137.72 N 633.87 E 2229.72 N 16 30 E 0.11 2211.25 N 655.78 E 2306.44 N 16 31 E 0.24 2284.93 N 677.64 E 2383.30 N 16 31 E 3.41 2358.41 N 699.08 E 2459.83 N 15 30 E 0.21 2431.23 N 718.05 E 2535.05 N 16 27 E 0.16 2503.94 N 736.41 E 2609.98 N 16 23 E 0.37 2576.63 N 754.55 E 2684.84 N 16 19 E 5000.00 3837.98 3761.98 5100.00 3906.0t 3330.01 5200.00 3974.45 3898.45 5300.00 4042.74 3966.74 5400.00 4111.14 4035.14 5500.00 4179.33 4103.33 5600.00 4247.80 4171.80 5700.00 4316.28 4240.28 5800.00 4384.21 4308.21 5900.00 4451.75 4375.75 47 4.3 N 12 57 E 2737.82 46 52 N 10 4'7 E 2811.05 46 46 N 10 46 E 2883.92 46 55 N 10.27 E 2956.95 46 57 N 9 51 E 3029.89 46 57 N 9 24 E 3103.03 46 45 N 9 10 E 3175.91 47 0 N 8 50 E 3248.T8 47 27 N 8 2~ E 3322.17 47 36 N 6 54 = 3395.90 3.59 2649.02 N 772.27 E 2759.29 N 16 15 E 0.19 2720.86 N 786.76 E 2832.32 N 16 7 E 0.62 2792.48 N 800.41 E 2904.92 N 15 59 E 0.56 2864.27 N 813.92 E 2977.67 N 15 51 E 0.73 2936.08 N 826.79 E 3050.27 N 15 43 E 0.72 3008.19 N 839.00 E 3123.00 N 15 35 E 1.34 3080.12 N 850.76 E 3195.45 N 15 26 f 0.25 3152.10 N 862.14 E 3267.88 N 15 17 E 0.21 3224.65 N 873.20 E 3340.79 N 15 9 E 0.99 3297.70 N 883.31 E 3413.95 N 14 59 E 6000.00 4519.23 4443.23 6100.00 4586.43 4510.48 6200.00 4653.35 4577.35 6300.00 4720.05 4644.05 6400.00 4786.44 4710.44 6500.00 4852.53 4776.~3 6600.00 4918.42 4842.42 6700.00 49~4.26 4908.26 6800.00 5050.13 4974.13 6900.00 5116.65 5040.65 47 36 N 6 2~ E 3469.63 47 56 N 5 53 E 3543.54 48 lO N 5 14 E 3517.75 48 11 N 4 26 E 3692.05 48 41 N 4 7 E 3766.56 48 40 N t 3! E 3841.29 48 57 N 2 58 E 3916.13 48 50 N 2 16 E 3990.90 48 42 N ! 41 E 4065.57 47 28 N 1 40 E 4139.59 0.61 3371.00 N 891.84 E 3486.98 N 14 49 E 0.64 3444.58 N 899.81 E 3560.17 N 14 38 E 0.35 3518.59 N 907.02 E 3633.61 N lW 27 E 0.53 3592.82 N 913.30 E 3707.09 N 14 15 E 0.78 3667.40 N 918.83 E 37~0.75 N 1~ 3 E 0.41 3742.28 N 923.83 E 3854.62 N 13 52 E 0.91 3817.38 N 928.13 E 3928.59 N 13 39 E 0.56 3892.56 N 931.56 E 4002.48 N 13 27 E 0.58 3967.76 N 934.19 E 4076.25 N 13 14 E 2.18 4042.39 N 936.24 E 4149.40 N 13 2 E 7000.00 5185.01 5109.01 7100.00 5254.21 5178.21 7200.00 5323.47 5!47.47 7300.00 5393.06 5317.06 7400.00 5463.09 5387.09 7500.00 5533.55 5457.55 7600.00 5604.69 552 ~. 69 7700.00 5676.04 5600.04 7800.00 5747.61 5671.61 7900.00 5819.41 5743.41 46 25 N 1 49 E 4212.01 46 10 N I 17 E 4283.57 46 9 N 0 4'9 E 4355.00 45 37 N 0 2 W 4425.98 45 30 N 0 39 W 4496.39 44 47 N I 18 W 4565.27 44 34 N 2 ? W 4635.29 44 22 N 2 3~ W 4703.96 44 17 N 3 21 W 4772.24 43 57 N 3 52 W 4840.13 0.97 4115.34 N 938.75 E 4221.05 N 1Z 50 E 0.40 4187.50 N 940.67 E 4291.86 N 1Z 39 E 0.51 4259.62 N 942.05 E 4362.55 N 12 28 E 0.74 4331.43 N 942.51 E 4432.79 N 12 16 E 0.52 4402.81 N 942.08 E 4502.47 N 12 4 E 0.91 4473.77 N 940.92 E 4571.64 N 11 52 E 0.50 4544.01 N 938.77 E 4639.97 N 11 40 E 0.44 4614.02 N 935.86 E 4707.97 N 11 27 E 0.33 4683.76 N 932.19 E 4775.62 N 11 15 E 0.49 4753.22 N 927.78 E 4842.92 N 11 2 E DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 9EG/IO0 FEET FEET FEET DEG MIN ARCO ALASKA, INC. 3H-17 KUPARUK NORTH SLOPEsAL~SKA C~]MPUTATION DATE: O2-MAR-S8 PAGE DATE OF SURVEY: ?.O-FEE,-88 KELLY BUSHING ELEVATION: 76.00- FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH ~EPTH DEPTH OEPTH DEG MIN 8000.00 5891.67 5815.67 43 27 8100.00 5964.4S 5888..45 43 12 8200.00 6037.57 5961.57 42 50 8300.00 6110.88 6034.38 42 52 8400.00 6184.22 610~.22 42 43 8500.00 6257.57 6181.57 42 47 8600.00 6330.95 6254.95 42 47 8614.00 6341.23 62_65.23 42 47 DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HGRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH E&ST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 4 40 W 4907.38 N 5 8 W 4973.~9 N fi 20 W 5039.99 N 5 31 W 5105.84 N 5 51 W 5171.57 N 5 55 W 5!37.22 N 5 55 W 5302.83 N 5 55 W 5312.01 0. 611 0.43 0.5Z 0.47 0.40 0.00 0.00 0.00 4822.15 N 922.63 E 4909.62 N 10 49 E 4890.47 N 916.67 E 4975.64 N 10 36 E 4958.41 N 910.44 E 5041.30 N 10 24 E 5026.11 N 904.04 E 5106.77 N lO 11 E 5093.76 N 897.32 E 5172.19 N 9 5'9 E 5161.37 N 890.31 E 5237.59 N 9 47 f 5228.94 N 883.29 E 5303.02 N 9 35 E ~ 5238.40 N 882.31 E .5312.18 N 9 33 E ) ARCO ALASKA~ INC. 3H-17 KUPARUK NORTH SLOPE~ALASKA COMPUTATION D~TE: 02-MAR-88 PAGE z, DATE OF SURVEY: ZO-FEB-88 KELLY ~USHING ELEVATION: 76.00- FT ENGINEER: SARBER INTERPOLATEO VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOU'TH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DES MIN 0.00 0.00 -76.00 0 0 1000.00 997.10 921.10 12 59 2000.00 1858.08 1782.08 38 16 3000.00 2593.98 2517.98 50 24 4000.00 3199.67 3123.67 54 9 5000.00 3837.98 3761.98 47 43 6000.00 4519.23 4443.23 47 36 7000.00 5135.01 5109.01 46 25 8000.00 5891.67 5815.67 43 27 8614.00 6341.23 6265.23 42 47 N 0 O E 0.00 N 27 41 E 35.88 N 17 5 = 515.39 N 13 24 ~ 1181.25 N 14 38 E 1973.26 N 1Z 57 E 2737.82 N 6 28 E 3469.63 N 1 49 E 4212.01 N 4 40 W 4907.38 N 5 55 W 5312.01 0.00 4.37 1.70 0.42 0.90 3.59 0.61 0.97 0.61 0.00 0.00 N 0.00 E 0.00 N 0 0 E 32.92 N 21.34 E 39.23 N 32 57 E 493.49 N 177.69 E 524.51 N 19 48 E 1136.46 N 373.67 E 1196.31 N 1~ 12 E 1906.81 N 571.95 E 1990.74 N 16 41 E 2649.02 N 772.27 E 2759.29 N 16 15 E 3371.00 N 891.84 E 3486.93 N 14 49 F '~ ~115.3~+ N 938.75 E 4221.05 N 12 50 l 4822.15 N 922.63 E 4909.62 N IO 49 E 5238.40 N 882.31 E 5312.18 N 9 33 E ARCO ALASKA, INC. 3H-17 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 02-MAR-B8 PAGE 5 DATE OF SURVEY: 20-FEB'-88 KELLY BUSHING ELEVATION: 75.00' FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH gEPTH DEG MIN DEG MIN 0.00 0.00 -76.00 0 0 N 0 0 E 76.00 76.00 O.O0 0 12 S 33 6 E 176.00 176.00 100.00 0 17 S 73 12 E 276.00 276.00 200.00 0 19 N 82 16 5 376.00 376.00 300.00 0 23 N 69 6 E 476.01 476.00 400.00 0 22 N 77 29 E 576.01 576.00 500.00 0 19 N 78 55 E 676.01 676.00 600.00 0 34 N 65 53 E '776.10 776.00 700.00 4 9 N 29 9 E 876.68 876.00 800.00 8 20 N 27 36 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY N~RTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 978.38 976.00 900.00 12 10 1081.68 1076.00 1000.00 16 56 1187.37 1176.00 1100.00 ZO 1295.62 1276.00 1ZOO.O0 23 51 1406.20 1376.00 1300.00 26 41 1519.86 1476.00 1400.00 30 30 1639.25 1575.00 1500.00 35 8 1764.79 1676.00 1600.00 39 14 1894.69 1776.00 1700.00 39 17 2022.79 1876.00 1800.00 38 0 O.O0 0.00 0.00 N 0.00 E -0.12 0.09 0.13 S 0.0.8 E -0.29 0.00 0.36 S 0.43 E -0.25 0.21 0.40 S 0.94 E 0.03 0.00 0.22 S 1.56 E 0.35 0.23 0.00 N 2.18 E 0.53 0.00 0.09 ~ 2.78 E 0.79 1.19 0.26 N 3.41 E 3.~38 4.2'7 3.05 N 5.50 E 14.03 5.33 12,54 N 10.45 E 2149.36 1976.00 1900.00 37 57 2275.77 2076.00 2000.00 38 9 2405,41 Z1T6.00 2100.00 40 25 2539.45 2276.09 2200.00 42 2674.38 23T6.00 2300.00 42 55 2816.98 2476.00 2400.00 48 4 2971.80 2576.00 2500.00 50 19 3129.60 2676.00 2600. O0 51 8 3290.80 2776.00 2700.00 .52 11 3455.49 2876.00 2800.00 52 59 N 28 5 E 31.43 N 25 23 E 55.97 N 24 I E 88.95 N 24 4 E 12~.90 N 21 21 E I74.74 N ZO 6 E 227.57 N 16 38 E 291.90 N 13 11 E 367.40 N 15 36 E 449.94 N 17 31 E 529.32 3622.59 2976.00 2900.00 53 30 3790.65 3076.00 3000.00 53 31 3959.64 31'76.00 3100.00 54 3 4131.27 3276.00 3200.00 54 31 4292.85 3376.00 3300.00 49 57 4448.85 3476.00 3400.00 50 13 4604.51 3576.00 3500.00 49 10 4756.07 3676.00 3600.00 48 32 4907.07 3776.00 3700.00 48 22 5056.05 3876.00 3800.00 46 59 N 19 9 E 605.84 N 19 53 E 681.83 N 19 15 E 763.00 N 18 Z E ~51.02 N 16 1~ 6 940.64 N 1~ 2~ ~ 1041.71 N 13 17 E 1159.59 N 13 35 E 1281.30 N 13 5q F 1407.30 N 14 31 E 1537.63 N 15 4 E 1670.82 N 14 53 E 1805.16 N 14 42 E 1940.72 N 14 31 E 2079.56 N 16 33 E 2205.64 N 16 30 E 2324.36 N 15 21 E 2442.69 N 14 8 E 2556.08 N 13 59 E 2668.80 N 10 58 E 2778.96 0.00 N 0 0 E 0.15 S 32 13 E 0.56 S 49 58 E 1,02 S 66 43 E 1.57 S 81 56 E 2.18 N 89 54 E 2,78 N 88 2 F ~ 3.42 N 85 42 t - / 6.2'9 N 60 58 E 16.32 N 39 47 E 3.28 5.04 3.50 1.94 2.80 5.24 3.44 2,62 1.21 1.83 28.76 N 19.14 E 34.55 N 33 38 E 51.76 N 30.70 E ,50.19 N 30 40 E 82.93 N 44.69 E 94.20 N 23 19 E 120.64 N 61.80 E 135.55 N 27 7 E 164.16 N 79.96 E 182.60 N 25 58 E 214.58 N 99.25 E 236.42 N 24 49 E 276.45 N I19.67 E 301.24 N 23 24 E 349.90 N 138,47 E 376.30 N 21 35 E 430.18 N 159.17 E 458.68 N 20 18 E 506.93 N 181.88 E 538.57 N 19 44 E 0.72 2.95 1.52 0.41 3.44 4.40 0.53 0.62 0.64 0.69 580.47 N 206.63 E 616.15 N 19 35 E 653.24 N 232.77 E 693.47 N 1? 36 E 731,06 N 260.17 E 775.97 N 19 35 E 815.65 N 288.53 E 865.13 N 1-~ 28 E 902.07 N 315.68 E 955.71 N 19 17 E 1000.25 N 341.74 E 1057.02 N 18 51 E 1115.32 N 368.66 E 1174.67 N 13 17 E 1234.02 N 397.14 E 1296.35 N 17 50 E } 1356.80 N 427.31 E 1422.49 N 17 28 E 1483.64 N 459.49 E 1553.16 N 17 12 E 0.55 0.43 0.63 0.99 0.23 0,29 3.56 0.27 0.38 1.24 1613.02 N 493.84 E 1686.92 N 17 1 E 1743.45 N 528.98 E 1821.93 N 16 52 E 1875.18 N 563.67 E 1958.06 N 15 43 E 2010.15 N 598.85 E 2097.45 N 16 35 E 2132.48 N 632.31 E 3224.25 N 16 30 E 2247.24 N 666.47 E 2343.98 N 16 31 E 2361.70 N 700.01 E 2463.26 N 16 30 E 2472.00 N 728.38 E 2577.03 N 15 25 E 2581.76 N 755.82 E 2690.12 N 16 19 E 2689.33 N 780.72 E 2800.36 N 16 11 E ARCO ALASKA 3H-17 KUPARUK NORTH ,5LOPE,ALASK& COMPUTATION D4TE: 02-MAR-88 PAGE DATE OF SURVEY: 20-FEE-8B KELLY BUSHING ELEVATION: 75.00- F.T ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FE~T DF SUB-SEA DEPTH TRUE SUE-SE4 CDURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG M[N DEG 5202.26 3976.00 3900.00 46 4'7 5348.63 4076.00 4000.00 46 47 5495.12 4176.00 4109.00 46 57 5641.11 4276.00 4200.00 46 41 5787.86 4376°00 4300.00 47 26 5935.98 4476.00 4400.00 47 34 6084.36 4576.00 4500.00 47 50 6233.96 4676.00 4600.00 48 8 6384.21 4776.00 4700.00 48 34 6535.58 4876.00 4800.00 48 47 6687,45 4976,00 4900,00 48 48 6839,19 5076,00 5000,00 48 35 6986,91 5176,00 5100,00 46 31 7131,48 5276,00 5200,00 46 11 7275,57 5376,00 5300,00 45 46 7418,42 5476,00 5400,00 45 30 7559,70 5576,00 5500,00 44 37 7699,95 5676,00 5600,00 44 22 7839,.61 5776,00 5700, O0 44 7 7978,39 5876,00 5800,00 43 32 8115.83 5976.00 5909.00 43 9 8252.44 6076.00 6000.00 42 51 8388,81 6176,00 5100,30 42 44 8614,00 6341,23 6265,23 42 47 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET ~EET FEET DEG MIN N 10 46 E 2685,57 N 10 10 E 2992,42 N 9 25 E 3099.46 N 8 58 E 3205.q2 N 8 3t E 3313,23 N 6 39 E 3422,45 N 5 57 E 3531,95 N 4 55 E 3543.00 N 4 8 E 3754.76 N 3 21 E 3867.91 N 2 20 E 3981.53 N 1 34 E 4094.75 N I 56 E 4202.59 N 1 I1 E 4306.08 N 0 6 E 4408,72 N 0 44 W 4509.34 N 1 50 W 4607,52 N 2 38 W 470~,92 N 3 35 W 4799.19 N 4 30 W 4892,93 N 5 lO W 4984,40 N 5 21 W 5074,53 N 5 47 W 5164,23 N 5 55 W 5312,01 0,66 0,64 0,69 0,54 0,36 0,55 0.72 0,77 1,09 0,67 0.72 1,33 0,94 0.07 0,81 0,55 0,60 0,44 0,35 0.,86 0.92 0.46 0.42 0.00 2794.09 N 800.72 E 2906.56 N 15 59 E 2899.18 N 820.27 E 3012.98 N 15 47 E 3004.67 N 838.42 E 3119,46 N 15 35 E 3109,66 N 855,47 E 3225.18 N 1S 22 3215.81 N 871.87 E 3331.91 N 15 10 E 3324.09 N 8~6.44 E 3440.25 N 14 55 E 3433,03 N 898.62 E 3548,69 N 14 40 F 3543,79 N 909,27 E 3658,58 N 14 23 L 3655,58 N 917,98 E 3769,08 N 14 5 E 3768,98 N 925,45 E 3830,94 N 13 47 E 3883,12 N 931,18 E 3993,21 N 13 29 E 3997,18 N 935,02 E 4105,09 N 13 9 E 4105,85 N 938,43 E 4211,73 N 12 52 E 4210.22 N 941,17 E 4314,13 N 1Z 36 E 4313,95 N 942,50 E 4415,71 N 12 19 E 4415,95 N 941,92 E 4515,25 N 1Z 2 E 4515,72 N 939,75 E 4612,47 N 11 45 E 4613.98 N 935.86 E 4707.93 N 11 27 E 4711.32 N 9.30.51 E 4802.34 N 11 10 E 4807.32 N 923.82 E 4895.28 N 10 52 E 4901,26 N 915,70 E 4986,07 N 10 34 E 4993,92 N 907.11 E 5075,63 N 10 17 E 5086,20 N 898,09 E 5164,88 N 10 0 E 5238,40 N 882,31 E 5312,18 N 9 33 E ARCO ALASKA, INC. 3H-17 KUPARUK NORTH SLOPE,ALASKA HARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD COMPUTATION DATE: 02-MAR-88 PA,SE ~ L OATE OF SURVEY: ZO-FEB-88 KELLY BUSHING ELEVATION: 75.O0-FT. ENGINEER: SARBER ' INTERPOLATEg VALUES FOR CHOSEN HORIZONS MEASUREO DEPTH BELOW KB FROM KB SURFACE LOCATION AT ORIGIN: 1082 FNL, 282 FWL, SEC 12, T12N, RSE, UM 'TVD RECTANGULAR COORDIN~T ES SUB-SEA NORTH/SOUTM EAST/WEST ~220.00 8226.00 ~261o00 8389.00 8514.00 8614.00 6052.23 5976.23 4971.95 N 909.17 E 6056.62 5980.62 4976.01 N 908.'79 E 6082.28 6006.2~ 4999.71 N 906.56 E 6176.14 6100.14 5086.33 N 898.08 E 6267.84 6191.84 5170.83 N 889.33 E 6341.23 6265.23 5238.40 N 882.31 E ARCO ALASKA~ INC,, 3H-17 KUPARUK NORTH SLOPE~ALASKA COMPUTATI3N O~TE: OZ-MAR-88 KELLY DATE 3F SURVEY: BUSHING ELEVATION: ENGINEER: PAGE 20-FEB-88 76.00,F~ SARBER MARKER TOP BASE TOP B~,SE PBTD TD KUPARUK C KUPARUK C KUPARUK A KUPARUK A FINAL WELL LOCATION AT TO: ORIGIN= 1082 MEASURED DEPTH TVO BELOW KB FROM KB SUB-SFA 8220.00 6052.23 5976.2'3 8226.00 6056.62 5980.6Z 8261.00 6082.28 6006.28 8389.00 6176.14 6100.14 8514.00 6267.B4 6191.84 8614.00 6341.23 6255.23 TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN FNL~ 282 SURFA FWL~ SE RECTANGU NORTH/S 4971.9 4976.0 4999.7 5085.3 5170.5 5238.4 CE LOCATION C 1Z, TI2N, RBE, LAR COORDINATES OUTH EAST/WEST 5 N 909.17 E 1 N 908.79 E 1 N 906. S6 E 3 N ~198.08 E 3 N 889.33 E 0 N 882.31 E UM 6341.23 6265.23 5312.18 N 9 33 E SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA, INC. WELL 3H- 17 FIELD KUPARUK COUNTRY U.S.A. RUN ONE DATE LOOOED 20 - FEB - 88 REFERENCE 72'6 ! 0 WELL' (1082' 3H-17 VERTICAL PROJECTION FNL, 282' FWL, SEC 12, T12N, R8E, UM) 189. -1000 0 0 1000 2000 9000 4000 SO00 SO00 -'4"'?'"?'"~.'''' ---r'"t'" .4""'.: ...... 't'"-', '"':""t"" '""??'"?'-4. ...... .;""F'4.-"? ....... ~..4...4....4. ...... 4......r ..t' ..4. ....... 3-3"'3'";. ...... 3,.4...4,.. ~ ..... i"4."';--3 ...... ;:.....4:..4.-4..,4....4:....;,....;..4....~..4,. 3 -3-.-3 ...... 3 .-'3.' '-i-'4.-"! .%;--.-F.4..-4. ....... 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T"'~'"T'"T ...... ~'~"'~-T"' "'~?"T"I ...... -'~'T'?'~''',..4..+.+.~ .... ~.++4 ....... 74..+~ ..... ~..+.4-~ ..... ~-.~+~ ..... ~,.4..+.4-~-+.++-~ ..... ~-.?~-.~--~-.?~.?.-~-?~---~ ...... ~.-f.-~.-~ ....... ~--~-~--~.---??--~...?..~-~-~-.,-??.?~..- · ?- ,..-~'.4 ~ .... ;-.m4..4-.;..4...;..~-.~ ....... ;...;.4-.: ....... ;...;-4....~...~-.~-~...~..~ ...... ;..4-~-~-~-+ ........ "f ff: : t "~ ~ ':"': ...... t"t"t"'~ ...... :"T"T'T'""'T'T"T"T"T TT'-F 'T'T'T'"~ ' ~ . ~ - 3000 -2000 - 1000 0 1000 2000 3000 4000 EAST ARCO Alaska, Inc. Date: December 15, 1988 Transmittal #: 7375 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~ 3 H- 14 Kuparuk Fluid Level Report ' 1 2- 1 0 - 88 ~ 3 H- 15 Kuparuk Fluid Level Report 1 2- 09 - 88 · 3 H- 17 Kuparuk Fluid Level Report I 2- 09 - 88 · 3 M - 19 Kuparuk Fluid Level Report I 2- 09 - 88 "3 H- 06 Kuparuk Fluid Level Report 1 2- 08 - 88 · 3 H- 09 Kuparuk Fluid Level Report I 2- 1 3 - 88 · 3 H- 21 Kuparuk Fluid Level Report I 2- 1 3- 88 · 3 K- 06 Kupaurk Fluid Level Report 1 2 - 1 2 - 88 · 3 H- 21 Kuparuk Fluid Level Report 1 2- 1 2 - 88 · 1 Y- 06 Kuparuk Fluid Level Report I 2- 1 2 - 88 ~ 30-07 BHP Report I 1 -27-88 Casing Tubing Casing Casing Tubing Casing Casing Casing Casing Casing Receipt Acknowledged: Alaska 0il & O.~c Cs~,:. Ccrnmi,~sior~ Date: ............ DISTRIBUTION: State of Alaska D&M Unocal SAPC Chevron Mobil Ab J~ OILAND GAS CONSERVATION COMMI. ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well_ Stimulate Convert to _ Plugging _ Time extension _ _ Pull tubing _ Variance _ Perforate _ Other ~ WI 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 6. Datum elevation (DF or KB) 4. Location of well at surface 1082' FNL, 282' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 3890' FNL, 1191' FWL, Sec. 1, T12N, R8E, UM At effective depth 1259' FNL, 1178' FWL, Sec. 1, T12N, R8E, UM At total depth 1124' FNL~ 1164' FWL~ Sec. 1~ T12N~ R8E~ UM 12. Present well condition summary Total Depth: measured 8 61 4' true vertical 6 3 4 1 ' RKB 76' 7. Unit or Property name Kuparuk River Unit feet 8. Well number ;~H-17 9. Permit number 87-cj~) 10. APl number 50-1 03-20081 11. Field/Pool Kuparuk River Field . Kuparuk River Oil Pool feet Plugs (measured) feet None Effective depth: measured 851 4' feet Junk (measured) true vertical 6 2 6 8' feet None Casing Length Size Cemented Measured depth True ve~t!i'c~d-e'pth Structural Conductor 8 4' 1 6" 210 Sx AS I 1 1 5' 1 1 5' Surface 3 6 6 0' 9 5/8" 1450 Sx AS III & 3 6 91 ' 3 01 7' Intermediate 400 Sx Class G Production 8 5 7 0' 7" 300 Sx Class G & 8 6 01 ' 6 3 31 ' Liner 175 Sx CS I Perforation depth: measured 8300'-8312', 8276'-8286', 8220'-8230' @ 12 SPF, 8340'-8360' @ 4 SPF true vertical ¸13. Convert oil producer to water injector. !14. Estimated date for commencing operation November, 1988 16. If proposal was verbally approved 6111'-6120', 6093-6101', 6052'-6060' @ 12 SPF, 6140'-6155' @ 4 SPF Tubing (size, grade, and measured depth 2 7/8" J-55 set at 8123' Packers and SSSV (type and measured depth) Camco HRP1-SP @ 8049', Camco TRDP-1A-SSA @ 1827' Attachments Description summary of proposal X.~ Detailed operation program _ BOP sketch _ Name of approver Date approved 15. Status of well classification as: Oil __ Gas m Suspended Service W~ter In!ector 17. I hereby certify that the foregoing is true and correct to the,~est of my knowledge. Signed ~¢,~ /,,/ ~ ~.,~~ Title"/,~. ~~ j...c.-¢'-I-~ / FOR ~MMISSION~SE ONLY Date Conditions of approval: Plug integrity _ BOP Test Mechanical Integrity Test ~ ORIGINAL SIGNED BY Approved by the order of tl~t~;l~l~ir~ss~,~TH Form 10-403 Rev 06/15/88 Notify Commission so representative may witness Location clearance Subsequent form require .~pp~c, ved Copy Returned IIAppr°val N°'s "" ~'~/"~--/' Commissioner Date SUBMIT IN TRIPLICATE Well 3H-17 Conversion to Water Injection 1. The proposed procedure is attached. 2. No BOPE is necessary to convert the well to water injection service. 3. The static bottomhole pressure will be acquired by taking a wellhead pressure and fluid level (using an echometer) prior to the well's conversion. The reservoir pressure is estimated to be 2800 psi based on the producing GOR. 4. No workover fluid will be used. 3H WATERFLOOD CONVERSIONS GENERAL PROCEDURE I , , . . Obtain final 12 hour well test. SI well to perform surface equipment modifications. Install catalytic heater, rotate check valve and choke, install 2" meter runs, and calibrate instrumentation. Notify the State of the upcoming Mechanical Integrity Test. After 72 hour shut in, contact Engineering (ext. 7525) to record wellhead pressure and shoot tubing fluid level. Conduct MIT. Packer depths and required 7" annular pressures are shown in the table below. Bleed the annulus to 500 psi after completing the test. Send a copy of the WSR and the State's MIT form to S. Twiggs at ATO 1130. WELL 3H-6 3H-15 3H-1 7 DEPTH (TVD) OF PACKER 5 79 5' 5 83 2' 592 7' REQUIRED CSG PRESSURE FOR MIT (PSI) 2086 2100 2134 . The targeted injection rates and estimated set pressures are summarized below. After the initial trial, modify the injection set pressure to more closely match the desired rates (+/- 500 BPD is fine). WELL 3H-6 3H-15 3H-1 7 DESIRED INITIAL INJECTION RATE (BWPD) ESTIMATED SET PRESSURE (PSI) 5000 6500 30OO 2500 2100 25O0 ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6001-A ARCO Alaska, Inc. Date: October 14, 1988 Transmittal ~. 7316 RETURN TO: - -,' ARCO Alaska. Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 3H-12 3H-12 3H-17 3H-22 2C-11 3H-14 3F-13 3C-16 3K-06 Sub-Surface Pressure Survey Sub-Surface Pressure Survey Sub-Surface Pressure Survey Bottom-Hole Pressure Survey Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Please acknowledge receipt and return 9 - 2 2 - 8 8 PBU 9 - 2 2 - 8 8 PBU 9 - 2 2 - 8 8 PBU 8 - 0 7 - 8 8 PBU 1 0 - 0 6 - 8 8 Casing I 0 - 0 7 - 8 8 Tubing 1 0 - 0 7 - 8 8 Casing 1 0 - 0 7 - 8 8 Casing 1 0 - 1 I - 8 8 Casing Receipt Acknowledged: DISTRIBUTION' D&M -~.!State of Alaska Chevron Unocal Mobil. SAPC STATE OF ALASKA ALASK.. OIL AND GAS CONSERVATION COMIV,._,51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdoWn ~ Stimulate [] Plugging [] Perforate E~ Pull tubing Alter Casing [] Other EX COMPLETE 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1082' FNL, 282' FWL, $ec.12, T12N, R8E, UM At top of productive interval 3890' FNL, 1191' FWL, Sec. 1, T12N, R8E, UM At effective depth 1191' FNL, 1171' FWL, Sec. 1, T12N, R8E, UM At total depth 1124' FNL, 1164' FWL, Sec. 1, T12N, R8E, UM 5. Datum elevation (DF or KB) RKB 76 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 3H-17 8. Approval number 7-838 9. APl number 50-- 103-20081 10. Pool Kuparuk River Oil Pool Feet 11. Present well condition summary Total depth: measured true vertical 8614'MD 6341 ' TVD feet feet Plugs (measured) None Effective depth: ~ measured 8514'MD true vertical 6268'TVD feet feet Junk(measured) None Casing Length Size Conductor 80 ' 16" Surface 3656' 9-5/8" Cemented Measured depth True Vertical depth 210 sx AS I 115'MD 115'TVD 1450 sx AS III & 3691 'MD 3017'TVD 400 sx Class G Production 8566' 7" 300 sx Class G & 175 sx CSI 8601'MD 6332'TVD Perforation depth: measured 8341 '-8361 'MD true vertical 6141 '-6156'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail 8 8123' Packers and SSSV (type and measured depth) HRP1-SP pkr (~ 8049'~ & TRDP-1A-SSA SSSV ~ 1827' JUN 1 0 19BB Alaska Oil & Gas Cons. Commission /~chorage 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13.N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments _ (Completi,~n Well History) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~_~ ()~[?~,'L~' ~--~';[J._L [~_.~ Title Form 10-404 Rev. 12-1-85 Associate Engineer Date (Dani) SW03/92 Submit in Duplicate ARCO ~... and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or worl(over operations ere started. Daily work prior to spudding should be summarized on the form giving inclusive dates only, District ARCO Alaska, Inc. KUPARUK RIVER FIELD ICounty, parish or borough NORTH S 1'.O? F.. Lease or Unit AD~.: 25531 Title COMPLET ION IWell no. Field 3H-17 Auth. or W,O. no. AK2602 API: 50-103-20081 Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 05/23/88 ( 10 TD: PB: 8513 SUPV:SC IDate 05/22/88 IHOur Complete record for each day reported NORDIC 1 1645 HRS JARCO W I 56.0000 Prior status if a W,O DROP BALL MW:10.0 NACL/NABR MOVED ONTO 3H-17. ND MASTER VALVE. NU BOPE AND TESTED. RU SOS. PERFORATED F/8341'-8361' W/4 SPF, 90 DEGREE PHASE. RAN 2-7/8" COMPLETION ASSY. LANDED TUBING. SSSV @ 1827', PKR @ 8049', TAIL @ 8123'. DROPPED BALL. DAILY:S135,418 CUM:$135,418 ETD:S135,418 EFC:$1,406,000 RECEIVED JUN 1 0 1988 Alaska Oil & Gas Cons. Commission Anchorage The above is correct For form preparaflorv/~nd distribution, see Procedures Mar/u~ll, Section 10, Drilling, Pages 86 ah4 87. IDate Title ASSOCIATE ENGINEER AR3B-459-1-D laNUmberall daily well history forms consecutively no. s they are prepared for each well. '1Page I ARC(, ~,il and Gas Company Daily Well History-Final Report Instructions: Prepare end submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged~ Abandoned, or Sold. "Fioal Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting coat center code District I State ARCO Alaska, Inc. ~ AK KUPARUK RIVER FIELD Auth. or W.O. no. AK2602 Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. County or Parish NORTt{ SLOPE JLease or Unit ADL: 25531 ITit[e COMPLETION 3H-17 IWeU no. 05/24/88 ( 1 TD: PB: 8514 SUPV:SC API: 50-103-20081 AR.Co. W.I ITotal number of wells (active or inactive) on this cost center prior to plugging and 56. 0000 taband°nment of this well Date Hour IPrior status if a W.O, I 05/22/88 1645 HRS Complete record for each day reported NORDIC 1 RIG RELEASED MW: DIESEL WAIT ON BALL. PRESS TBG TO 2500 PSI. PACKER SET AT 1250 PSI. TEST TBG TO 2500 PSI. OK. SHEAR PBR. TEST ANN TO 2500 PSI. OK. TEST SSSV TO 1000 PSI. SET BPV. ND STACK. NU AND TEST TREE. DISP WELL TO DIESEL. SET PBV. RIG RELEASED AT 1330 HRS 5/23/88. DAILY:S9,275 CUM:$144,693 ETD:S144,693 EFC:$1,406,000 JtIN l 0 1988 Alaska 0il & Gas ConS. Commission Anchorage Old TD J New TD PB Depth I Released rig IDate Kind ol rig I Classifications (oil, gas, etc.) I Type complet,on (single, dual, etc.) I Producing method IOlticial reservoir name(s) I Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P, C.P. Water % GOR Gravity Allowable Efiective date corrected The above is correct Signature // IDate l'Tjtle U,, ~/~ ~/m ,, ~_ 7_~,.~c3 ASSOCIATE ENGINEER For form preparation~d distribution, see Procedures Man~a.l, Section 10, Drilling, Pages 86 an'~'87. AR3B-459-3-C Number all daily well history forma consecutively es they are prepared for each well. iPage no. Olvldon of AtlantlcRIchfleldCompany WEST SAK ENGINEERING TRANSMITTAL ].181 TO: DATE: John Wills STATE March 1, 1988 FROM: H. D. White/P. S. Baxter WELL NAME: 3H-17 TRANSMITTED HEREWITH ARE THE FOLLOWING: One copy of a blueline and sepia for each: ~-- 2" Temperature Log 5" Temperature Log 02/19/87 run 1 02/19/87 run t RECEIPT ACKNOWLEDGED: DATE PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN: P. Susanne Baxter, AT0-1269 P. O. Box 100360 Anchorage, Alaska 99510 Date: ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 9951(3-0360 Telephone 907 276 1215 February 29, 1988 Transmittal #: 7107 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~3H-11 Cement Evaluation Log 2-15-88 5000-7534 ~3H-12 Cement Evaluation Log 2-15-88 4300-7108 ~3H-13 Cement Evaluation Log 2-15-88 4400-7228 ~--3M-17 Cement Bond Log 2-19-88 6300-8470 -'3H-14 Cement Bond Log 2-17-88 3150-8102 -~ 3H-15 Cement Evaluation Log 2-17-88 5250-8330 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Date: State of Alaska(+sepia) .~,A~iA STATE OF ALASKA "-'-' AL OIL AND GAS CONSERVATION COk .... :SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown~ Re-enter suspended well [] Alter casing ~ Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order C Perforate ~ Other 2. Name of Operator ARCO Alaska~ Inc 3. Address P. 0o Box 100360 Anchorage, AK 9951 0-0360 4. Location of well at surface 1082' FNL, 282' FWL, 5ec.12, T12N, R8E, UN At top of productive interval 1405' FNL, 1076' FWL, Sec. 1, T12N, R8E, UN At effective depth 1166' FNL, 1069' FWL, Sec. 1, At total depth 1098' FNL, 1078' FWL, Sec. 1 , 11. Present well condition summary Total depth: measured true vertical T12N, R8E, UM T12N~ R8E~ UM 861 4 ' MD feet 6337 ' TVD feet (approx) (approx) (approx) Plugs(measured) 5. Datum elevation(DF orKB) RKB 76~ 6. UnitorPropertyname Kuparuk River Unit 7. Well number 3H-17 8. Permit number 87 -99 9. APl number 50-- ln~-~nn~l 10. Pool Kuparuk River Oil Pool None feet Effective depth: measured 8514 ' M D true vertical 6263 ' TVD Casing Length Size Conductor 80 ' 1 6" Surface 3656 ' 9-5/8" P roducti on 8566 ' 7" feet Junk (measured) None feet Cemented Measured depth 210 sx AS I 1450 sx AS II I 400 sx Class G 300 sx Class G True Vertical depth 115 ,IVlD 115~TVD 3691 'MD 3016'TVD 8601 'MD 6327'TVD Perforation depth: measured None true vertical None ~bing(size, grade and measured depth) None Packers and SSSV(type and measured depth) None 12.Attachments WELL HISTORY Description summary of proposal [] Detailed operations program V~ BOP sketch 13. Estimated date for commencing operation FebrUary, 1988 14. If proposal was verbally approved Name of approver Form No· ~Datecl'~t'~F-~ Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Engineer' Commission UseOnly (Dani) SA2/125 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved by Date Commissioner Form 10-403 Rev 12-1-85 by order of the commission Date //-') '~.~ . Submit in triplicatc~/~ ARCO Oil and Gas Company Well History - Initial Report - Daily Inllructlons: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District I County~ parish or b .... gh I State Alaska I North Slope Borough Field JLease or Unit JWell no. Kuparuk River ADL 25531 3H-17 Auth. or W.O. no, |Title AFE AK2505 I Drilling Alaska Doyon 14 API 50-103-20081 Operator ~ ARCO W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun JDate I.our IPrior status if a W.O. Spudded 10/03/87 2245 hrs. Date and depth as of 8:00 a.m. 10/04/87 thru 10/05/87 10/06/87 10/07/87 10/08/87 Complete record for each day reported 16" @ 115' 2532', (2417'), Drlg Wt. 9.2, PV 15, YP 19, PH 8.5, WL 12.4, Sol 6 Accept rig @ 1200 hrs, 10/03/87. NU diverter sys. Spud well @ 2245 hfs, 10/03/87. Drl to 2532'. 455', .5°, N31.3E, 454.99 TVD, 1.84 VS, 1.70N, 1.03E 1196', 21.0°, N24.4E, 1184.06 TVD, 93.76 VS, 87.18N, 48.64E 2111', 37.9°, N16.68E, 1947.04 TVD, 583.55.VS, 559.74N, 195.11E 16" @ 115' 3706', (1174'), C&C Wt. 9.3, PV 28, YP 22, PH 8.5, WL 8.8, Sol 6 Drl to 3706', short trip, C&C, POOH. RU & rn 93 its, 9-5/8", 36#, J-55 BTC csg. 2332', 39.7°, N18.0E, 2119.26 TVD, 720.61VS, 691.94N, 236.29E 2712', 44.3°, N13.dE, 2400.02 TVD, 974.49 VS, 937.61N, 307.79E 3633', 53.8°, N13.8E, 2982.10 TVD, 1685.39 VS, 1632.13N, 466.62E 9-5/8" @ 3691' 4165', (459'), Drlg Wt. 8.5, PV 4, YP 1, PH 9.0, WL --, Sol 1 Cmt 9-5/8" w/1450 sx AS III & 400 sx C1 "G". ND diverter. NU & tst BOPE. RIH, tst csg to 2000 psi; OK. DO FC, cmt, FS & 10' new hole. Perform formation tst to 11.2 ppg EMW. Drl to 4165'. 4014', 54.4°, N12.4E, 3205.51TVD, 1993.26 VS, 1932.72N, 536.57E 9-5/8" @ 3691' 5974', (1809'), Drlg Wt. 9.2, PV 7, YP 3, PH 9.0, WL 12.4, Sol 6 Drl 8½" hole to 5974'. 4395', 50.1°, N14.5E, 3439 TVD, 2294 VS, 2226, 607E 5682', 46.8°, N 8.2E, 4301TVD, 3247 VS, 3162, 789E The above is correct Signature /3_ · or o m preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or welt is Plugged, Abandoned, or Sold, "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code State Alaska District iCounty or Parish Alaska I North Slope Borough Field |Lease or Unit Kuparuk River I ADL 25531 Auth, or W.O. no. ITitle AFE AK2602 I Drill Doyon 14 API 50-103-20081 Operator ~ A.R.Co, W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun J Date Spuuded j 10/03/87 Date and depth as of 8:00 a.m. 10/09/87 10/10/87 thru 10/12/87 Complete record for each day reported Iotal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well 1 our ~Prlor status if a W,O. 2245 hrs. 9-5/8" @ 3691' 8600', (2626'), Drlg Wt. 9.9+, PV 14, YP 7, PH 9.0, WL 4.8, Sol 11 Drl 8½" hole to 8600'. 6141', 48.0°, N3.3E, 4612 TVD, 3585 VS, 3499N, 823E 7217', 46.0°, N1.6W, 5333 TVD, 4374 VS, 4297N, 827E 8296', 43.0°, N6.6W, 6104 TVD, 5107 VS, 5049N, 767E 7" @ 8601' 8614', (14'), RR 10.0 ppg Brine Drl to 8614', short trip, CBU, POOH. RU Schl, log DIL/SP/SFL/CAL/GR & FDC/CNL, RD Schl. Make cond'g rn f/csg. RU & rn 207 jts, 7", 26#, J-55 BTC csg w/FC @ 8514', FS @ 8601'. Cmt w/lO0 sx 50/50 Pozz w/4% D-20, .2% D-46 & .5% D-65 & 200 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ w/10.0 ppg brine & bump plug. ND BOPE, NU & tst tbg head to 3000 psi. RR @ 0730 hrs, 10/11/87. 8527', 42.9°, N8.7W, 6273 TVD, 5257 VS, 5205N, 746E Old TD New TD PB Depth Released rig Date Kind of rig 0730 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data 10/11/87 Type completion (single, dual, etc.) Single . Official reservoir name(s) Kuparuk Sands Rotary Well no. Date Reservoir Producing interval Oil or gas Test time Production Oi'i 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 For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ITitle Drilling Superintendent ARCO Alaska, Inc.~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: October 20, 1987 Transmittal #6086 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3H-7 OH Lis Tape 10-1-87 3H-17 OH Lis Tape 10-9-87 Receipt Acknowledged: DISTRIBUTION: ~nchorag-~ M. Stanford ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany ARCO Alaska, Inc~-'~' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: October 20, 1987 Transmittal # 6089 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~'3H-17 2" Dual Induction · 10-9-87 3690-8562 '~-~3H-17 Cyberlook ..... ~ 10-9-87 3690-8562 "--3H-17 2" and 5" Raw Data FDC~ 10-9-87 3690-8562 "'-3H-17 5" Dual Induction ~ 10-9-87 3690-8562 -" 3H-17 2" and 5" Poroaity FDC:' 10-9-87 3690-8562 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Franzen D & M State of Alaska(+sepia) L. Johnston(vendor package) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Vault(film) September 25, 1987 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 3H- 17 ARCO Alaska, Inc. Permit No. 87-99 Sur. Loc. 108Z'FNL, 282'FWL, Sec. 12, T12N, R8E, UM. Btmhole Loc. 1088'F~, 1127'F~..~, Sec. 1, T12N, R8E, U~. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The pe~it to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ver~ truly yours, Lonnie C. Smith Co~issioner of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COMMISSION dlf Enclosure CC: Depar~nent of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKa. OIL AND GAS CONSERVATION ,,- .~MMISSION . PERMIT TO DRILL 20 AAC 25.005 ....... la. Type of work Drill L~ Redrill FqI lb. Type of well. Exploratory [] Stratigraphic Test [-~ Development Oil Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone ~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, inc RKB 76' PAD 39' feet Kuparuk River Field · ~ Kuparuk River 0il Poo 3. Address 6. Property Designation P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25531 ALK 2657 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.0251 1082'FNL, 282'FWL, Sec.12, T12N, R8E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well nu ,mber Number 1405'FNL, 1076'FWL, Sec. 1, T12N, R8E, UN 3H-17 #8088-26-27 At total depth 9. Approximate spud date Amount 1088'FNL, 1127'FWL, Sec. 1, T12N, R8E, UN 09/30/87 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD property line 3H-7 8583 ' MD feet feet 1088,~ TB feet ~,1c,' ~ $,,rfan¢ ~n (6778.'TVO) 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 700 feet . Maximum hole angle 490 Maximum surface 1 7~ psig At total depth (TVD) ~07~ psig 18. Casing program Setting Depth size Specifications Top Bottom Ouantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 cf 12-1/4 ' 9-5/8" 36.0# J-55 BTC 3611 ' :35' :35' ~646' 3010' 1200 sx AS II I & HF-E[W 400 sx Class G blend 8-1/2" 7" 26.0# J-55 BTC 8549' 34' 34' 858~' 6278' 200 sx Class G(minimun HF-E~W T0C 500' above top of 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 vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor j~I~"CEI rED~ Surface Intermediate ~k';~'? ~,~ :~, Production ~J~aSA'~ Liner ~as.. Corl$. Coi.iilTi[$$~.cj Perforation depth: measured Chorage true vertical 20. Attachments Filing fee ,~, Property plat [] BOP Sketch ~;~ Diverter Sketch,,~,_ Drilling program ~ Drilling fluid program,l~ Time vs depth plot [] Refraction analysis [] Seabed report Lq 20 AAC 25.050 requirements 21. I hereby ~/hat the f/~n~e and c, orrect to the best of my knowledge // S i~ned/~ / ,/,./~,,~I~,,.~Y,JJ//'' '/%")-'.V~~.Cvc-~&,...~['¢' .¢ __, -,/Title Regi on al Dri 1 1 i ng Engi neer Dat m~ r//"' (./c/,/ Y-"'" - CommissionUseOnly (JLQ) PD2/47 Permit N · u ~_J~r ' I APl number I Approval date See cover letter I I 09/25/87for other requirements Conditions of approval Samples required [] Yes Ec~'-No Mud Icg required L-] Yes [~No Hydrogen sulfide measures [] Yes Ei~'No Directior''~'~ survey required [~h'Yes [] No Required working pressure_~for BOPE []2M; ~ 3M; ,, 5M; [] 10M; [] 15M Other: r-7~~ ~/?~'¢;)-. by order of Approved by Commissioner the commission Date ?-5%,¢' Form 10-401 Rev. 12-1-~ Submit in triplicate ARCO ALASKA, l PAD 3H. WELL NO' 17 Propoaed Kuparuk Field, North Slope, Aleeka 0 ~ SURFACE 1 000. 2000 _ 3000_ 4000_ 5000 _ 6000 _ 7'000 _ KOP TVD=?O0 TMD=700 DEP=O 3 9 BUILD 3 DEG PER 1 O0 FT 21 27 B/ PERHAFROST TVD=1591 THD=1627 DEP=221 ,.33 45 T/ UGNU SNDS TVD=2011 THD=2145 DEP=521 EOC TVD=2132 THD=2318 DEP=646 T/ W SAK SNDS TVD=2596 THD=3020 DEP=1172 K-12 TVD=2810 TI"ID=3343 DEP=1414 9 5/8" CSG PT TVD=3010 Tt'ID=3645 DEP=1640 COLVILLE TVD=3060 THD=3721 DEP=1697 AVERAGE ANGLE 48 DEG 33 MI N T/ ZONE D TVD=5981 TMD=8134 DEP=5004 T/ ZONE C TVD=5995 TMD=8155 DEP=5020 T/ ZONE A TVD=6038 THD=8220 DEP=5069 TARGET CNTR TVD=6071 TMD=8270 DEP=5106 B/ KUP SNDS TVD=6146 THD=8383 DEP=5191 TD (LOG PT) TVD=62?8 THD=8583 DEP=5341 K-5 TVD=4456 TMD=5830 DEP=3278 " Anchorage ,~ I I I I 1000 2000 3000 4000 VERTICAL SECTION I I 5000 60O0 H 0 ~ZO N T AL SCALE' 1 IN. PROJECTION = 1000 FEET 6000 , 5000 _ TARGET LOCATION' 1320' FNL. 1090' FWL SEC. 1. T12N. RSE 4000 _ 3000 2000 1 000 _ O a SURFACE LOCATION~ 1082' FNL. 282' FWL SEC. 12. T12N. R8E 1000 _ ARCO ALASKA. INC- PAD 3H. WELL NO, 17 Proposed Kuparuk Field. North Slope. Alaska WEST-EAST 2000 1000 0 I I 1000 I 2000 I TARGET CENTER TVD=60?I THD=82?O DEP=$108 NORTH 5042 EAST 808 TD LOCATION, 1088' FNL. 1127' FWL SEC. I. T12N. RSE SURFACE RE£EIVED Sr:r:' 2 ~ Alaska 0il & Gas Cons. Commissiot'~ Anchorage N 9 DEG 6 MI N E 51 06' (TO TARGET) KUPARUK RI VER UNIT 20' DIVERTER SCHEMATIC L DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH T~O 2-1 / 16" 2000 PSI BALL VALVES 4. 20' 2000 PSI DRILLING SPOOL W/1 O' OUTLETS S. 10' HCR BALL VALVES W/lO' DIVERTER LINES, A SINGLE VALVE OPENS AUTOIdATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., REOLIESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION 2 i -'--'i · . . 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. DO NOT SHUT IN WELL U,NDE~R ANY CIRCUMSTANCE~; RECEIVED JG I L-~-8.6 Alaska Oil & Gas Cons. uomm~ss~c-r~ Anchorage I' I 7 DIAGRAM #1 13-5/8' 5000 PSI RSRRA BOP STAC~ I. 16' - 2.0(X) P~I TAI~CO STARTING FF_AD 2. II · - ~ I:~! CA~IN~ ~ 3. I1' - 3000 PSI X 1.3--5/8' - ~ PSI SPACER ~ 4. 13-5/8' - 5000 PSI PIPE, RN~ 5. I,.,~5/8" - 5000 PSI 5RILLING SP(XI. w/a-IO(E AN:) KILL LIKES 6. 1~-5/8' - 5000 PSI ~ RAM W/PIPE RAM6 ON Tel:', 7. i~-5/8' - 5000 PSI ~ A~TOR CAPACITY TEST I. (]-ECK ~ Fill LEVEl. WITH ~IC FLUID. AS~IJRE THaT ~T~ 3. ~ TI~, ~~ ~ ~ SIXThlY 4. ~ ~~~, ~ A~~ L~ L~T IS 45 ~~ ~I~ T~ ~ I~ ~I ~I~ 5 4 13-5/~" B(;:p STA,Q( TEST i. FILL BCP STACK ~ C:HI:;KE I, aN~F~LD WITH N:~CTIC 2. Q-ECK THAT ALL LOCI( ~ SCRE:N8 ZN I~_/HF. AD ARE FULLY RETRACTED. SEAT TEST PLUG :IN WITH ~IN~ JT ~ RUN IN L~ SCREY~. LIllE VALVES ADJACENT TO B(~ STAO(. ALL 011-ER 4. ~ UP TO 250 PSI ~ HCLD FCR I0 MZN. IN- CREASE ~ TO 3(X30 PSI ~ HClLD FOR I0 MIN. BLEED PRESSURE TO 0 PSI. LIKE: VALVES. CL__C~_ TOP PIPE ~ ~ HCR VALVES ON KILL ~ ~ LIKES. 6.TEST TO 250 PSI AN3 3000 PSI AS IN STEP 4. ?. CC:NTINLE TESTING ALL VALVES, LIKES, N~ ~ WITH A 2.50 PSI LC~ ~ 3(:X:X} PSI HIGH. TEST AS IN STEP 4. nO N~T i=~=.~q~a~ TEST ANY CHeK~ THAT NOT A FULL CLOSING P(~TTIVE SEN_ ~. CI~LY ~ICN TEST ~~ THAT DO ~ FULLY CLOSE. 8. C:PEN TOP PIPE I:~ ~ CLOSE BOTTCM PIPE RAMS. TEST BOTTC:IVIPIPE RAMS TQ 250 PSI ~ 301:30 PSI. 9. (:::PENBOTTCI~4 PIPE RANIS, BACK OUT RUN, lING JT 10. CL__Ct~_ BLII~) RAMS AN3 TEST TO 250 PSI AN3 PSI. MANIFOLD ~ LIKES ARE FULL CF NON-FI:~EE::ZlNG FLUID. SET ALL VALVES IN DRILLING POSlTICN. 12. TEST STA/~[::PIPE VALVES, KELLY, KELLY O:X:XS, DRILL PIPE SAFETY VALVE, ~ INSIEE BCl= TO 250 PSI AN3 3OOO PSI. 13. RECCRD TEST II~FCRIK~T]:CN ON BLCIM::Lff ~ TEST FCRM, SION, ~ SE:AD TO DRILLING StJ::~:A~ISCR. 14. PERFCRVl C:CIVPLETE BOPE TEST AFTER NIPPLING UP WEEKLY Thr~ FUNCTI~LY C]PERATE ~ DALLY. 510084001 REV. 2. MAY 15,1985 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. In~tall Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill.8½" hole to logging point according to directional plan. 8. Run open hole'logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. I0. Run and cement 7" casing. Pressure test to 3500 psig. 11. Dovnsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. Ii. Run cased hoh logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. SHALE SHAKER,{' , , [ .up .... EANER STIR ,~..~ STIR _~ STIR TYPICAL MUD SYSTEM SCHEMATIC LWK4 / ih Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & 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 (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, 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 shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. LWK5 / ih 'reserve Pit wing valve flm,~ IIn~ swab valve master valve pad center [Plan'~ViewI actuator valve g. I. valve Kuparuk Well-head Orientation ARCO ALASKA, INC. line wing valve---~. actuator valve VR plug-.. psi gauge w. I. adaptor --J ~ swab valve flow'cross master valve well line View from Pad Center valve ,/ , ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 5, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ,":lES E N,. i_~_].~ 'SR ENG. .~ SR ENG '-7'"-.~- SRGE0 SUBJECT: Conductor As-Built Location Plat - 3H Pad (Wells 1-22) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/pk GRU1/31 RECEIVED Enclosure Alaska 0il & Gas Cons. Commission Anchorage AI3t"t3 Al~(:b:a Inr, i~ a R~lhRidi,trv of AtlanticRichfieldCompnny II I,z I \ ¥1ClNITY MAP S~.ALE I" · 2 MILES ALL WELLS LOCATED IN SEC. 12, T. 12 N.,R.8 E., UMIAT MERIDIAN. ASPs 'X' 6,000,110.75 6,000,135.51 6,000,160.57 6,000, 185.28 6,000,g85.82 6,000,310.30 6,000, 335.43 6,000,42 5.37 6, O0 0,450 51 6,000,475.46 6,000, 500.41 6,000, 525.44 6,000,550.46 6,000,575.45 6,000,600.44 6,000,650.45 6,000,675.40 6,000,700A2 498,655.44 498,655.43 498,65559 498,655.43 498,655.47 498,655,40 498,655.4 I 498,655.44 498,655.45 498,655.44 498,655.44 498,655.38 498,655.42 498,655.45 498,655.41 498,655.47 498,655. 55 498,655.59 498,655.49 498,655.65 49 8,655.73 LATITUDE TO° 24 '41.531" 70°24'41. 775" 700 24'42.022'_'' 7cF' 24_: 42 70° :)4 42: .514' 7o° 74:42. 1'0° 24 45,003 0 " 3# 7'0 24 43.25. 70° 24' 43.494, 70oz4'43.741' ?0o Z4'44.GZ6' TO° 24' 44.873" 70o24'45.119" 70°24 45.610 T0O24'45.856" ?0°24'46.102" TCP24' 46348" ?0o24'46.84o" 70°24'47.085' 7002:4'47. $$1" LONGITUDE l 1500 00' 39.416"I 150°00' 39.417~, 150° 00'39.418' ~o° oo', 150° O0 39.416' O0 39.4~ 150e 00' 39.417" 150° 00'. 39.4~7" 150° O0 39.417" 15OEO0' 39.418" 150e 00'39.421~ 150° 00'39.419" 150e 00'39.41El 150e 00' 39.419 150000' 39.417 1 50e00' 39,415" 150e00'38.4~' 150o00'39.418'' 15 0°00' 39.413" 150o00'39.410" I HEREBY CERTIFY THAT REGISTERED AND LICENCED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION,AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 6/9/87. I AM PROPERLY NOTES I. ALL COORDINATES ARE A.S.P., ZONE 4. 2. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE B.P.M.S.L. 4. REFER. FIELD BOOK L-17-1~,35-44 ~ L-~?-II, E. 0.6. ELEVATIONS FROM CED-RlXX- 6. HORIZONTAL POSITION ,ASEDON 3H CONTROL MONUMEI~EI~I~ L~rL~IUR*' ABsoc. [~st F N,,.L, i ~laska 0ii 15:~2', 149i: 147 1422' 1397' 1371' 347' 1322' 1232' 1207' 1182' I107' 1057' 1007' 98Z' 957' Pod Elev._ 38.8' 38.8' 38.7~ 38.7 38.8' 38.8', 38.9 281' 281', 28 I' 281' 281' 281', 281 281' 282' 282' 282' 282' 282' 33.6~ 33.6, 33.6 33.7' 33.8' 33.8' 33.8', 33.8 33.8' 33.8' 33.8* 33.9' 33.9' 33.9' 38.7', 38.6, 38.6 38.?' 38.8' 38.8' 38.7~ 38.7 38.7* 38.8' 38.9' $8.7' 38.6' 3 8.6' ARCO Alosko Inc. __ KOII~RUK PROdECT D.S. 3 H - WELL CONDUCTOR AS-BUILT PI~EPARED BY LOUNSBURY & Associoles ANCHORAGE ALASKA OW~ev: Pdw ! CaK8Y: JWT ~ FeZ ~ 1 Is the p~t fee au-~_had ~ -- (1) ........................................... (2) (2 cam~ 8) (8) i3) '(lO '~ -C~==u 28) (6) OI~ ..~.~...~..~-:,. ;~,;~,r~o~ (29 ~ 31) 2. Is ~ to be located in a ~d pool ............................. ~ ~. Is well located proper H~ mrmz~ce ~ prooe_--dy lina .................. ~ ~. Is ~ locauad p .~ dLsr.,~c~ ~ o -~ .., ................. .~_ 5. Is sufficient undadicated a~~ ~le im this pool .......... d~ 6. Is ~ r~ be dev'ia~ecl and .is w~ll]oore plat included ........... ].. ]. m3 7 Is operator dna only affected parry ~_ ,i 8. Can l~v~i: be approved before ~eem-day wai: ~ 9. Does operator have a bond im force .................................. 10 Is a conserva~ ordar needad '~" 1! ~ a~~~ ~~-n~d ' z~ ~ ~ ~ ~ ...... . ~ ~ ~~~. ~ ~d~ ~ .................... . . . . . . ~ ,, ., ~8. ~ c~ ~ ~ ~ ~~~ ~~ ~ ........ 20. ~ ~ ~ ~ be ~d o~ ~ ~. ~ old ~~e ~~~ ~ce~e ~~d ~ 10-403 ............ /~/~ ~. ~ a~:a ~~o~ s~a~ ~sed ............................ ~ , 24. ~ ~ ~ ~d p~~ schema 26. ~ ~ ~ ~~= p~: 27. ~ ~ ~ ~ ~old ~ly w/~I ~-53 ~ 84) .................. F~ ~l~~ ~ S:~~ ~: 29. ~ ~ ~~tad ~ ~t~~ ~~~ z~? ................. 30. ~ s~c ~m]~ ~ ~~d 31. ~ ~ o~ ~c., ~ ~ ~~ of s~ed ~~ ~~ . rum~: 01/28/87 6.011 FH -/7 u 7 ,, J 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. CATE SIZE CODE 000 OOO 017 065 OuO o00 005 065 o00 000 007 065 Ot)O 000 002 065 (') 0 0 0 0 ~) 0 0 i~ 0 6 5 00 o 000 002 0 b 5 oo0 OOO 011 065 CATE SIZE CODE 000 000 OOl Ob5 I $C0,.,SI T¥ = 9,()25' ¢3690'(LO(;(;FR) ' BiT SlZg = 8,5' TO 8610'(LOGGER) = i0,o [~}?./(; Ra = 5 08 (a fi6 DF i,~,,,g = 3 ~0 (4 62 DF = 4,4 C3 ~::?~ AT BBT = 2 456 [a 144 DF ........ ~o'1 i.i~ElfJC~]~,,iT b!.JT ;)~(]Ob i:3Ai,,i~E;D OP, TNf..EE HIGH 6PEED 4411' TO 3690' PAGE CODE (OCTAL) 68 O0000OO0000000 68 O0000OO0000000 b8 00000000000000 68 00000000000000 68 0o000000000000 68 OOO00000000000 68 00000000000000 68 00000000000000 ~8 00000000000000 68 00000000000000 68 0o000000000000 68 O00000000OO000 68 O0000OO0000000 68 00000000000000 68 OOO0000OO00000 b8 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 O0000OO0000000 69 OuO00000000000 68 00000000000000 ~* bA:'rA ** 3.5702 l[,~ 4172.000(2) GR 1i.6951 CALl 3.0037 RCFT P~o9.6519 .T~NS 3.4478 9~ 5000 B:6719 7~7,1987 4172,0000 106 * 5625 3.I731 652.3195 -999. 2500 3. 9405 0:0{. 9.. 3,,i51. g 6!4. 306b -999,2500 1.3.6719 7e.125o 0 . {..' (; 78 2.8234 9.~ 5 . ~:~"1 -999,2~' 2,0227 4. b 825 0. I}098 3 . 4:53 9.76 93 9,2500 'HO~ 2 4492 ;R -999,2500 2,1263 ! 09,9375 9, t) 229 5 21, '/783 -999. 2500 $ F L, t.,~ G CFTC 125. '25 o C' 3.71.38 486.9404 -999.2500 3.8889 3 . 67 [:5 C! 0.0078 3.491(.'; 0t:~.3793 -999.2500 b.9243 -999,2500 -999. 250~) i b i) C ::~ T C I b D t.') P k~ I C:~i'C I bO C :.! 'i'C lbo l"g,,"6 OPnJ. C :: '[ C 6392.©000 GR 12.~;502 CALl 3,61.22 RCFT 3,5978 IbP: 6080,0000 GR I1.9318 CALl 2099. 176~ .1. 2,8 P 21 1 ih,, 20.0994 CALl 2,9753 RCFT 2571,6343 TENB 2,141i 6100.0000 GA 19.981I Chbl. 3.9655 RCFT l'790,9695 TE~$ 2.1676 5928,0000 GR 12.1686 CAhl 3.6849 RCFT 1854,4~29 TENS 2,6222 ILM 5928.0(7}00 GR 18.5o06 CALl 4.055~ RCFT 1756.2964 TENS 3.3054 I1,:~ 5800.0000 GR 1.4,6544 CALl 3,~304 RCFI' 2057.1162 TENS 4.1~6 5884.0000 -g99.25(>0 -999.2500 ~CFT -999.2503 TEmS 3,2121 10615625 579,1.564 6392,0000 3.7438 100 0625 8 9453 583 5431 6080 0000 ½,4303 ,1250 8,8359 869,7625 6052,0000 2 1857 124 5625 9 0156 462 6262 6100 0000 2,2413 109,9375 9,1328 452.9219 5928,0000 2,7348 125,2500 9,4766 440,7514 5928,0000 3.4626 183,8750 9,3750 521,8545 5800.0000 ~. 445e -.999,2500 999,2500 '999,2500 -999.2500 -45 .3 ! 25 GR 999 2500 -999 2500 -999~2500 TEaS 70 ~} ti. t> t} 9 V S F L ~, -75.b~25 GR -999,2 bO 0 4 4a89 93"3125 ,.. , 250() ,,999,2500 - 99 ~, 25 :s 0 4 5404 -e99 2500 - 999 2500 -999'250o ~ · -999' 2500 - 999,2 50 0 -999,2!50o -999,250{i) .-999,250{) 3.7895 103.375 f; -999. 250(5 -999.2500 -999 o 2500 -999,2500 4.31.59 103.1~75 -q99 250() -a99: -999,250 - 999,2500 t L 0 D P H t DPMt C ?,; I b t> [,:Ph i ~ :. C ~'<; T C i b D Tg!~ S C~'.~ TC DFh I 3.8090 100,~250 -999. 2500 -999,256ti -999. 2500 5,2377 58.~A37 -q99. 2500 i. bi) TEi'~ $ f)PhI i bO 4.0382 5724,0000 GR -999,2500 CALl -999.2500 ~CKT 3.9451 1b~ 5704'0000 GR -999.2500 CAbI -999,2500 RCFT -999.2500 TENS 3,3920 IL~i 5592.0000 GR '999,2500 CALl -999.2500 RCFT -999.2500 'tENS 3.0559 ILM 5604'0000 GR -999,2500 CAbI -999,2500 RCFT -999,2500 TENS 4.3755 l[.,~ 5628,0000 GR '999. 2500 CALl 'g99,2500 RCFT - 999.25 0 0 T E t~i $ ~.4085 5792,0000 GR -999.2500 CALl -999.2500 ~CFT -999.2500 TENS 3,87~I iLM 5368.0000 GR -909.2500 CALl -999.2b00 RCFT -999.2500 TMh$ 3.7:39'7 5iaS.0OOt, GR -909,2bb0 CkbI { 2431 -999 2500 -999 2500 -999 2500 -999 2500 4 583 -999 500 .-99~ 2500 -999 2500 -999 2500 3 3060 -999 2500 -999 2500 -999 2500 -999 2500 3,1270 -999.2500 -999.2500 -999,2500 -999.2500 4 2162 -999 2500 -999 2500 -999 2500 -999 2500 4,523! -999,2500 -999 ;2500 -999,2500 -999,2500 ;94I~2 2~9 2500 999.2500 -999,2500 '999,2500 4,0135 -999 2500 -999:2500 :.EPT ,p :Ci;T ;R :'EFT :PSI :.Ca:3:' ;P ;R - 999 . 2500 T E i:~ ,5 -56,5625 .... ~.,~ ~. ? ~,,, '999,2500 CFTC - 999,2500 ~ g i',~ 6 6400, t~Oo,j -14,203i -999.2560 -999.2500 CF'lC '-999,250 -<~99 25O 4,1!54 9b, 125O -999. 2500 ...q49 ¢} 9 9 ' " -.... ,2500 -99:9,2500 .- ~.~ 99 2500 -9~9 2500 -999 2500 -999 25O0 4.2058 I. 06,0000 -~99,2500 -qO'e 2S{,} -999,2500 3.5366 90.7500 99,250 u -999.2bOu -.999.25u0 4.6654 3.937 b -999.2b('O -c)99' 25C. 0 -999,2500 :I bD C::~TC ib P h I C ~.i T C L~ P H I Tk; F-~ 5 D ? H iL C~l'C i !, i) -999,2500 RCFT -999,2500 :rgN$ · 4,0988 IbM 5152.00(>0 GR '999,2500 CALl "999,2500. e RCFT. .. ~999 ' 2500 TE~S 4,I414 II.,a 5220,0000 GR -999,2500 CALX 2999, 500 RCFT 999.2500 TEk8 3.7534 4968,0000 GR -999,2500 CAbI -999.2500 RCFT -999,2500 ~rg~s 4,1290 4905,0000 GR -999.2500 CALl -999.2500 RCFT -999,250o TgNS 4,0472 IbM 4868,0000 GR '999,2500 CALl -999,2500 RCFT -999.2500 TEN5 3,7121 iL"} ,i748,0000 GR '999.25~0 CAhl -999.2500 RCFT -~99,2500 TENS 4.3g97 4620.0 O (.~ 0 d R -999,2500 CALl -999,2500 RCFT -999.2500 T~JN8 -999,2500 -999,2500 4 2364 -999 2500 -999 2500 -999 2500 -999 2500 4 1846 -999 2500 -999 2500 -999 2500 -999 2500 ~,7319 -999,2500 '999,2500 -999,2500 -999,2500 4,.1747 -999,2500 -999,2500 -999,2500 -999,2500 4 1020 -999 500 -999 2500 -999 2500 -999 2500 J,763~ -999,2500 -999,2500 -999,2500 -999,2500 4,6802 '999,2500 -999,2500 '999,2500 '999,2500 -999 25{;0 -999 25o0 CFTC -999,2500 I 03 7500 -<)99 2500 -999 250(} -999 2500 -999,25()0 .3 352 i~: t <, t: . .... 7500 -999 ' 250O -999,2500 -999 , 2500 -999 ' 2500 3. 486'1 i 1 l O250 -999 25O0 -999 25§0 -999 2500 -999. 2500 1!6.3i25 -999 ' 2500 -999. 2500 -999 250{~ ' 99 ~ * ' ' ,, 2500 2.24o2 12].500u 2500 2 5 O 25 (:,: 0 -99q.25CCi 3,7607 140, -999. 250(; -999.25t) 0 -999. 2500 -999,2590 2,9012 !. 8? . 250(2 -999.2500 -99 .~. 2500 -999,250{> -999,250i.~ Ci:: :r C I bD 1 b D C ::': T C C :;;: T C I F.; a S C ;: T C I LU D P n 1 4568.0000 g t,{ -999. 2500 CALI -999. 2500 RCFT -999,2500 TEN8 $.5059 Ib~ 4428,0000 GR I999.2500 C A b i -999,2500 RCFT -999. 2500 4428,0000 GR -999,2500 CAbI '999,2500 RCFT '999,2500 TENS 1,961t. 4288,0000 dR -999.2500 CaUl -999.2500 RCFT -999,2500 TENS 2.2976 4224.0000 '999,2500 CALl -999,2500 RCFT '999.2500 TE~8 3.6163 lb~ 4148.0000 GR -999.2500 CALl '999,2500 RCP'T -999,2500 TENS 3,~309 4208.0000 GR -999,2500 CALl: -999,2500 RCFT '999.2500 tENS 2.857a 4(;si.riO0() GR '999.2500 CALl '999.2500 RCFT '999.2500 FENS '999,2500 -999.2500 -999,~500 -999, 500 t .5,! so -999 2500 -999 ZSO0 -999 2500 -999 2500 3,5393 -999 ;2500 '999,2500 '999,2500 '999'2500 I 9670 -999 2500 -999 2500 -999 2500 -999 2500 2 3135 -999 2500 -999 2500 -999 2500 -999 2500 3,6107 '999,2500 -999,2500 '999,2500 '999,2500 3 8417 -999 2500 -999 2500 -999 2500 -999 2500 2.7334 -999 2500 -999 2500 -999 2500 -999 2500 :, T I i',~ ~:.g P A G E 9 3 5324 77 0000 -999 2500 -999 2500 -999 2500 2.8354 113.6875 -999 25 '999' 250a: . -999,2500 -999,2500 99.'U525 -999.2500 -999.2500 -999.2500 -999,2500 2.8850 10~.~125 -999.2500 -999,2500 -999,250C~ -999.25H1) 3.5557 -999.250~) -999.25(>u -999.2500 4.6535 -999.25u0 - ~ 99.250 C, i bD DPt~I 0 P H 1'. I L D D P H I C :i TC I' b D DP~I DPM I 3,4439 l:bPi 39'74,0000 GR -999,2500 CAb:[ -999,2 50 (> R - ~ -999,2500 Tgi'~S 2,0983 iL~ 4000,0000 -999,2500 CAbl -999.2500 RC['T -999,250{~ 3.7686 iLt~ 850,0000 GR '999 2500 CALI - 99 ~. 2500 T E N $ :2,9639 IbM ~740,0000 GR 999,2500 CALl -999,2500 RCf'T '999,2500 TENS 2,891.9 3804,0000 GR -999.2500 CA&i -999,2500 RCF~~ -999,2500 TENS 3.2~40 3540.0UU0 GR -999,2500 CALl -999.2b00 RCFT -999,2500 TE~S 4 t, Sz7 l[.,a 3520.000u GR -999,25b0 CALl, -999,2500 RCFT -999.2500 TENS 4.1601 IbM 3824.0000 (;R -99g.2500 CALX -999.25()0 RCFT 3 4855 .999 2500 "999 2500 '999 2500 '999 2500 2,6427 "999,1500 '999, 500 '999,2500 '999,2500 3 6799 -999 2500 -999 2500 "999 2500 -999 2500 2 9386 -999 2500 -999 2500 -999 2500 -999 2500 U343 .999,2500 .999~2500 999,2500 3 1581 -999 2500 -999 2500 -999 2500 -999 2500 3,9969 :999,2500 999,2500 -999,2500 '999,2500 4,0799 '999,2500 '999,2500 '999,2500 t P Ct~T R 4 -999 -999 -999 :EPT iP !P H I ,~EPT :p ;R ) E P T ,:PHI ,, 4000, Ut)O(; SPbu 2.21 ~ 'd t) t: F, L; 1664. 2002 CF'?C -999.25(:) t~ TEt,,~S 3p .2 ,2 ,2 .2 .6 ,0 .2 .2 .2 ,2 .0 3 97 0 3. ,466. -999, O. 3. 5 ! 0, -999, 3 10 0 -99~ 2 i10 o 3 -999 3 9b 50 o 9 ~ 3 500 500 500 837 625 500 500 500 44t. 375 376 055 06 S .500 '733 5 ~ 6 ~69 50 <) 4!9 i25 190 305 837 500 2044 bOuO () 493 ,9538 '1 ~()7 ,250o ,5093 ,031 ii .b354 , b 02 .2500 C '~, T C C ':! I' C i i3 t) T E :',.~,.s C a r C t LD C;xTC 1 i., D T E/.~ g 0 P :4 I C ;! I7 C I h 0 0 P H i C :': T C i.> P ~ I R l' f,~ R I) PH i, ¢:: ,i i7 C 3460.000!) GR -999'2b00 CAbl -999.2500 MCFT -999,2500 TENS 4.2091 3564.0000 Ga -999.2500 CAhI 999,2500 C -99 9,2500 00 o 0 G R 2570 C A L, I 0278 :,.,C~ :i;' J. 736,4187 TENS 3.9471, 3100.0000 29.6B75 CAbI ~,22.45 RC~'. 1.7i8.099I TENS 5.0659 I:LN 3000.000() GR 35,2b09 CA~i 4.1132 RCFT 1792.1030 TENS 4.104a 2784.0o00 GR 27.4384 CaLl 4.0392 ~CFT 1'741.9492 TENS 3.2220 I L t~; 2694.0000 GR 26.2547 CALl 4.3333 RCFT 1700.2b~,1 'I'ENS 3.9905 Ih5~ 2680. 0000 GR PAGE I0 '999,2500 . 4.5!92 .999~2500 .999 ~ 2500 .999; 2500 999'~ 2500 4 0257 -999 2500 '999 2500 '999 2500 -999 2500 4 0799 100 4375 ~ 8281 410 9661 3404 0000 3 7057 97 0000 9 17i9 420 5298 3100 0000 4,7449 92 3125 7 3438 488 2780 3000 0000 3 5996 lOO 5000 7 7734 39~ 9622 278~ 0000 2,9889 110,6250 8,3438 397.8428 2694.0000 3 7438 95:6250 .p PHI 'EPT C t'~ T p H ! C~'~T 2 . 205 I 47.5227 -999,2509 0 443 -999 2 91 3 89 2740 0536 2500 ,7705 .1875 ' 7907 .08 t{ 9 .2500 794,4. 1875 0O59 5802 0000 -999,2500 '95) 9' 2500 -999. 2500 ;? :Phi ~C~T 'gPT ;P ,PBI ' g'~ 9.25n" - q 99,250 (ii -9'.~9. 2500 -999.2500 2490,0000 -999.2500 -999.250 G -999. 250(; -999.2500 -999°2500 2464. OOoO 9c~9.2bt)(? 999. 2500 -999. 250U -grig. 2500 43 0.00 L, O ) i!Z P T ~p :. Ci'~ ~: I b D C ~;; T C 1' LaD 0 p .d J. C '~ T C t b. D D P }'{ 1 C ~,: T C. 0 P H I C i',:! 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