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5HJJ-DPHV% 2*& )URP %URRNV3KRHEH/ 2*& 6HQW 7XHVGD\-XQH $0 7R 5HJJ-DPHV% 2*& 6XEMHFW ): >(;7(51$/@5( .58(3DGQRQZLWQHVVHG0,7,$V WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůLJƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗tĞůů/ŶƚĞŐƌŝƚLJ^ƉĞĐŝĂůŝƐƚW&ϭΘW&ϯфŶϭϲϭϳΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ĞŶƚ͗dƵĞƐĚĂLJ͕:ƵŶĞϭϰ͕ϮϬϮϮϭϬ͗ϮϭD dŽ͗ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗Z ͗ yd ZE>Z ͗<Zhϭ ͲWĂĚŶŽŶǁŝƚŶĞƐƐĞĚD/d/Ɛ WŚŽĞďĞ͕ zĞƐƚŚĞĐŽƌƌĞĐƚĚĂƚĞŝƐϲͬϭͬϮϮ͘/ĐŽƌƌĞĐƚĞĚŽƵƌĐŽƉLJ͘dŚĂŶŬƐĨŽƌĐĂƚĐŚŝŶŐƚŚĂƚ͊ ZĞŐĂƌĚƐ͕ -DQ%\UQH :HOO,QWHJULW\6SHFLDOLVW &RQRFR3KLOOLSV$ODVND,QF 2IILFHSKRQH &HOOSKRQH &ƌŽŵ͗ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗DŽŶĚĂLJ͕:ƵŶĞϭϯ͕ϮϬϮϮϭϭ͗ϭϭD dŽ͗tĞůů/ŶƚĞŐƌŝƚLJ^ƉĞĐŝĂůŝƐƚW&ϭΘW&ϯфŶϭϲϭϳΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ƵďũĞĐƚ͗ yd ZE>Z ͗<Zhϭ ͲWĂĚŶŽŶǁŝƚŶĞƐƐĞĚD/d/Ɛ CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. .58( 37' ĐŽƌƌĞĐƚĚĂƚĞŝƐϲͬϭͬϮϮ͘ :ĂŶ͕ tŝůůLJŽƵǀĞƌŝĨLJƚŚĞĚĂƚĞŽĨƚĞƐƚŝŶŐ͍dŚĞĨŝůĞŶĂŵŝŶŐĐŽŶǀĞŶƚŝŽŶŝŶĐůƵĚĞĚϲͬϭͬϮϮ͕ďƵƚƚŚĞƌĞƉŽƌƚĚĂƚĞŝŶĐůƵĚĞĚϲͬϮͬϮϮ;/͛ŵ ĂƐƐƵŵŝŶŐŝƚƐŚŽƵůĚďĞϲͬϭͿ͍ dŚĂŶŬLJŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůLJƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗tĞůů/ŶƚĞŐƌŝƚLJ^ƉĞĐŝĂůŝƐƚW&ϭΘW&ϯфŶϭϲϭϳΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵх ^ĞŶƚ͗dŚƵƌƐĚĂLJ͕:ƵŶĞϮ͕ϮϬϮϮϭ͗ϮϴWD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖tĂůůĂĐĞ͕ŚƌŝƐ;K'ͿфĐŚƌŝƐ͘ǁĂůůĂĐĞΛĂůĂƐŬĂ͘ŐŽǀх͖ƌŽŽŬƐ͕WŚŽĞďĞ> ;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂLJфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂLJΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗<Zhϭ ͲWĂĚŶŽŶǁŝƚŶĞƐƐĞĚD/d/Ɛ ůů͕ ZĞĐĞŶƚŶŽŶǁŝƚŶĞƐƐĞĚD/d/ƐŽŶϭ ͲWĂĚ͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨLJŽƵŚĂǀĞĂŶLJƋƵĞƐƚŝŽŶƐ͘ ZĞŐĂƌĚƐ͕ -DQ%\UQH :HOO,QWHJULW\6SHFLDOLVW &RQRFR3KLOOLSV$ODVND,QF 2IILFHSKRQH &HOOSKRQH &$87,21 7KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH Submit to: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1800390 Type Inj N Tubing 450 525 525 525 Type Test P Packer TVD 5941 BBL Pump 3.3 IA 290 3180 3050 3030 Interval V Test psi 3000 BBL Return 3.3 OA 105 300 245 215 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1820780 Type Inj N Tubing 1050 1150 1150 1150 Type Test P Packer TVD 6090 BBL Pump 1.5 IA 484 2000 1900 1885 Interval 4 Test psi 1523 BBL Return 1.4 OA 180 300 300 300 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1821100 Type Inj N Tubing 1550 1650 1650 1650 Type Test P Packer TVD 6019 BBL Pump 1.3 IA 860 2500 2450 2440 Interval 4 Test psi 1505 BBL Return 1.3 OA 200 320 320 320 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1830170 Type Inj N Tubing 950 950 950 950 Type Test P Packer TVD 5970 BBL Pump 1.1 IA 500 1800 1750 1730 Interval 4 Test psi 1500 BBL Return 1.2 OA 320 410 420 420 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1821700 Type Inj N Tubing 1500 1500 1500 1500 Type Test P Packer TVD 5940 BBL Pump 1.7 IA 560 2400 2290 2275 Interval 4 Test psi 1500 BBL Return 1.7 OA 40 40 40 40 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2042310 Type Inj N Tubing 50 50 50 50 Type Test P Packer TVD 3655 BBL Pump 1.2 IA 247 1800 1740 1730 Interval 4 Test psi 1500 BBL Return 1.2 OA 158 160 160 160 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2050060 Type Inj N Tubing 300 350 350 350 Type Test P Packer TVD 3512 BBL Pump 3.1 IA 234 1800 1750 1750 Interval 4 Test psi 1500 BBL Return 2.3 OA 138 140 138 138 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2040310 Type Inj N Tubing 275 425 425 425 Type Test P Packer TVD 3024 BBL Pump 0.6 IA 245 1800 1710 1700 Interval 4 Test psi 1500 BBL Return 0.5 OA 145 190 152 146 Result P TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting 1E-105 1E-119 Notes: 1E-19 1E-25 1E-102 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec hanicall Integrityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: 1E-16 Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 1E Pad N/A Arend / Richwine 06/02/22 Notes:MITIA to MAIP per AIO 2C.076 Notes: Notes: Notes: 1E-01 1E-13 Form 10-426 (Revised 01/2017)2022-0601_MIT_KRU_1E-pad_8wells 9 9 9 9 9 - 5HJJ 91E-13 • MEMORANDUM To: Jim Regg ~~ 7~Z?~l /o P.I. Supervisor ~~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 30, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 E-13 KUPARUK RIV UNIT 1E-13 Src: Inspector NnN-CnNFiDENTIAL Reviewed Bye P.I. Suprv Comm Well Name: KUPARUK RIV UNIT 1E-13 API Well Number: 50-029-20750-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100627133625 Permit Number: 182-078-0 Inspection Date: 6/24/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1E-13 ' Z' pe nj. N TVD 6090~~ IA~ 300 1810 1770 1760 P.T.D 1szo7so TypeTest _ ~_- SPT Test psi 1810 QA 0 0 0 0 i IriterVal 4YRTST p~ P "~ Tubing 2425 2425 2425 2425 Notes: Mi In. ~ ~ GQ (5 Z,Z~~ ;, .... Wednesday, June 30, 2010 Page 1 of 1 • ConacoPhillips a~ska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16~', 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: ~~~~~~~ ~~~ (~ $~ ~~ ~llf`~. CQ(ItIr1iSS10ti Anc~r~ra~e ga-o7g I E, - j3 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRil). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped November 25~` 2007 & March 21 2009, the corrosion inhibitor/sealant was pumped July 6~', 7th, 8~' 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klem ConocoPhillips Well Integrity Projects Supervisor ~ i ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7116110 1A.1 C.1 E PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-11 50029206850000 1811730 10" n/a 10" Na 3.4 7/8/2010 1A-12 50029206880000 1811780 2" n/a 2" n/a 1.7 7/8!2010 1A-13 50029207000000 1811950 11" n/a 11" n/a 3.4 7/8/2010 1A-14 50029207060000 1820100 4" n/a 4" n/a 2.1 7/8/2010 1G01 50029205260000 1801280 SF n/a 24" n/a 4.3 7/6/2010 1 C-02 50029205320000 1801350 24" n/a 24" n/a 8.5 7/6/2010 1 G03A 50029205350100 2070630 SF Na 16" Na 7.7 7/6/2010 1C-04 50029205470000 1801550 SF n/a 5" n/a 2.6 7/6/2010 1C-06 50029205640000 1810250 76 17.70 32" 3/21/2009 9.4 7/6/2010 1 C-09 50029208590000 1821850 38' 8.00 6" 11/25/2007 6.8 7/6/2010 1C-10 50029208650000 1821930. 37'6" 8.00 8" 11/25/2007 6.8 7/6/2010 1E-02 50029204720000 1800500 21" Na 21" n/a 1.7 7/7/2010 1E-03 50029204770000 1800560 4" n/a 4" n/a 2.4 7/7/2010 1E-06 50029204930000 1800780 12" Na 12" n/a 13.6 7/7/2010 1 E-07 50029204950000 1800800 5" n/a 5" n/a 2.6 7/7!2010 1E-08 50029204960000 1800810 5" Na 5" n/a 2.6 7/7/2010 1 E-10 50029207250000 1820360 2" n/a 2" n/a 1.7 7/7/2010 -13 50029207500000 1820780 5" Na 5" Na 2.6 717!2010 1E-19 50029209050000 1830170 1" Na 1" n/a 1.7 7/7/2010 1E-21 50029208920000 1830020 3" Na 3" n/a 2.6 7/7/2010 1 E-24A 50029208570100 1971870 2" n/a 2" n/a 1.7 7/7/2010 1 E-25 50029208440000 1821700 3" Na 3" Na 1.7 7/7/2010 1E-28 50029208320000 1821580 4" n/a 4" n/a 2.5 7/8/2010 1E-29 50029208280000 1821540 7" n/a 7" Na 2.5 7/8/2010 r MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~ I ~'etci f)11{)~ OA TE: Wednesday, June 07, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lE-13 KUPARUK RIV UNIT IE-13 Src: Inspector ~\)\<t \~ FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RIV UNIT IE-13 API Well Number 50-029-20750-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS06060509575 I Permit Number: 182-078-0 Inspection Date: 6/4/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -- Well IE-13 IType Inj. iN: TVD 6102 IA 0 2260 2240 I 2240 , I I I . ,i , 1820780 iTypeTest ¡ SPT ¡ Test psi ¡ I ! : P.T. 1525.5 OA 0 0 0 0 ¡ 850 i- ¡- Interval 4YRTST PIF P Tubing 850 850 850 Notes Well temporarily shut in for common line repair. NON-CONFIDENTIAL Reviewed By: P.I. Suprv::j3í2- Comm 'c;,;,p ~.~;,'k~~~) ·~w!i~4'''~',.., , ....~.. " I:" _::.'J Wednesday, June 07, 2006 Page I of I MEMORANDUM TO: Camille O. Taylor Chair State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 11, 2002 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder Phillips Alaska P.I. Supervisor ~ f_...O"'~ 1E Pad 1E-11,1E-13,1E-15,1E-27 FROM: John Crisp Kuparuk River Field Petroleum Inspector Kuparuk River Unit NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. "Wall[ 1E-11 I Typelnj. I S I T.V.D. I 6020 I Tubingl 2400 [ 2400 I 2400 I 2340 Ilntervall 4 .. P.T.D.I 1820510 ITypetestl P ITestpsil 1505 I Casingl 2175 ] 2850.I 2820 I 2800 I P/F I P Notes: 1 bbl. pumped for test pressure. - We, I 1E-13 I Type Inj. I N I T.V.D. I 0090 I Tubing I 1225 ! 1225 } 1225 J 1225 J lnterval} '4 P.T.D.I 1820780 ITypetestl P ITestpsil 1'523 I CasingI 0 I.-~'830I 1775 I 17'60I p/Fl?_ Notes: 5 bbls. pumped for test pressure. "We,,I 1E-15 I Typelnj.I N I T.V.D. 10066 I Tub,ngl 1350 I 1350 11050 1 350 I lntervall 4 P.T.D.I 1821020 ITypetestl P ITestpsil 1517 I CasingI 1450 I 2000' I 1970 I' 1'96~) I P/F I P Notes: 5 bbls. for test pumped pressure. .... WellI 1E-27 I Typelnj. I N I T.V.D. 15888 I Tubing ]2700 12700 12700 12700 I,nterva,! 4 P.T.D.I 1821100 ITypetestl P ITestpsil 1500 I Casingl 1300I 22S0I 2260I 2260I P/F I P Notes: 1/2 bbl. pumped for test pressure. J Type. In]. JType test Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING 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 4:MIT's perfOrmed, no failures witnessed. 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: 4_ Attachments: Number of Failures: 0 Total Time during tests: 4 hrs. c.c: MIT report form 5/12/00 L.G. MIT PAl 1Eb 07-11-02jc.xls 7/24/2002 REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown m Stimulate __ Plugging Perforate X Pull tubing Alter casing Repair well Pull tubing Other 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 4. Location of well at sudace 683' FSL, 813' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 2604' FSL, 1992' FWL, Sec. 16, T11N, R10E, UM At effective depth 2376' FNL, 1732' FWL, Sec. 16, T11N, R10E, UM At total depth 2376' FNL, 1732' FWL, Sec. 16, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 7 7 5 0 feet Plugs (measured) 6695 feet 6. Datum elevation (DF or KB) 106' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1E-1:~ /,~"3 ~- r °/r- 9. Permit number/approval number 82-78 / 8-508 10. APl number 50-029-2O750 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 7 6 4 5 feet Junk (measured) true vertical 6612 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 7 8' 1 6" 296 Sx AS II 7 8' 7 8' Surface 2678' 10 3/4" 1100 Sx AS III & 2678' 2484' Intermediate 250 SX AS I Production 7732' 7" 1234 Sx Class "G"& 7732' 6681' Liner 250 Sx AS III Perforation depth: measured 7110'-7192', 7345'-7358', 7374'-7398', true vertical 6194'-6257', 6376'-6386', 6398'-6417', Tubing (size, grade, and measured depth) 3 1/2" 9.3 Ib/ft, J-55, 7055' MD RKB 7402'-7416' MD 6420'-6431' TVD Packers and SSSV (type and measured depth) ~ ~.i~'~. Camco TRDP-1 SSSV @ 1909'; Otis Packer @ 6976' .~ ;,~,;,,m,'ts~,~[~ '. .... ~. ~.;~ ~,~.~ ~.~-~, 13. Stimulation or cement squeeze summary Well 1E-13 was perforated ~n the C,~~f~'"~ .~.~_ 7110'-7192' MD on 6-19-88 (se~'~{iachee~?~ Intervals treated (measured) Treatment description including volumes used and final pressure 14. Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 800 1 200 2450 Subsequent to operation (WI) 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations i 0 0 2100 1200 2250 16. Status of well classification as: Oil __ Gas Suspended Service .water.. in j.. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. // SUBMITIN DUPLICATE - ~ &RCO Alas,,.k..a,: Inc~ , Subsidiary of Atlantic R c Compa~ WELL IPBDT , I FIELD- DISTRICT- STATE / 6 -- ! "~ I iOPERATiON AThEPOR.j. TiME C, ONT~CTO~,.~ .&MARKS WELL SERVICE REPOR~ IDAYS /73'~ V CHECK THIS BLOCK IF SUMMARY C~6TT66E~60I~ACK '' ' Weather ITemp. Chill Fact°r.F I Visibility iwind vel' Sign" ~~ZJ~ ,,, DESCRIPTION DALLY AccuMi .,, TOTAL :OTIS ' ' - "' SCH LUM BERGER ...... ' · iDRESSER-ATLAS '~":DOWELL 'HALLIBURTON , ARCTIC COIL TUBING , FRACMASTER B. J. HUGHES Roustabouts .... .... Diesel ,, Methanol ..... Supervision ................ Pre-Job Safety Meeting ............ AFE ,,-- ,, ....... TOTAL FIELD ESTIMATE ALA OIL AND GAS CONSERVATION COM APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . ' Operation Shutdown , ] Re-enter suspended well -- Alter casing ?. T,me extension Change approved program Plugging '~ Stimulate .? Pull tubing Amend order .r Perforate ,_~ Other 2 ~ ~f~OD~.rator a§Ra, Inc. 3 Address PO Box 100360, Anchorage, Al( 99510 4. Location of well at surface 683' FSL, 813' FEL, Sec.16, T11N, R10E, UN At top of productive interval 2604' FSL, 1992' FNL, Sec.16, T11N, R10E, UM ~§~fec~¥~l_d, ep!t~32' FWL, Sec.16, T11N, R10E, UM At total depth 2376' FNL, 1732' FWL, Sec.16, T11N, RiOE, UM R~B Df~rr2 ~elevation (DF or KB) 6. Unit or Property name Kuparuk River Unit 7. Well number 1E-13 9. APl number 50- 029-20750 10. Pool Kuparuk River Oil Pool feet 11. Present well condition summary Total depth: measured 7750' MD feet true vertical6695' TVD feet Plugs (measured) None Effective depth: measured 7645' MD feet true vertical6612, TVD feet Junk (measured) None Casing Length Size xxx~y~gxxxx Conductor 78' 16" Surface 2678' 10-3/4" X X X,~(,t~F,r~ ~ t e Production 7732 ' 7" XXX~A~XXX X Perforation depth: measured Cemented Measured depth 296 SX ASII 78' 1100 SX ASIII & 2678' 250 SX ASII 1234 SX Class G 7732' & 250 sx ASII 7345'-7358' 7374'-7398' 7402'-7416' MD true vertical6376'-6386' 6398'-6417' 6420'-6431' TVD Tubing (size, grade and measured depth) 3½" J-55 @ 7055' MD Packers and SSSV (type and measured depth) Camco TRDP-1 SSSV @ 1909' MD, Otis Packer @ 6976' MD, 12.Attachments Description summary of proposal 5~ Perforate C Sands: 7110'-7192' MD-RKB. True Vertical depth 78' 2484' 6681' RECEIVED Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation 6-17-88 14. If proposal was verbally approved Name of approver ~ ~/I,//~/~, 17°tm N°' --Date(:]'-"/'-"~/'Vate o approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,/'~O~ ~.~.,/~/'"~~Ti~ Title Sr. Operations Engineer Commission Use Only Conditions of approval Notify commission so representative may witness i Approval No. ~ Plug integrity ~ BOP Test .1~ Locat[on_clearancel Approve~ (Jopy Returned ORIGINAL SIGNED BY LONNIE C. SMITH Approved by Date Commissioner by order of the commission Date ~'.-3~ ~ Form 10-403 Rev 12-1-85 Submit in triplicate WELL 1 E-13 PERFORATING PROCEDURE 1) MIRU Wireline for gauge ring run. PT lubricator to 3000 psi. 2) RIH. Tag fill (last tag at 7500'MD-RKB on 3/7/83?). 3) POOH. RDMO Wireline unit. 4) MIRU E-line perforating unit. PT lubricator to 3000 psi. 5) With well shut-in, RIH with CCL/perf guns/magnetic decentralizer. 6) Tie in depth using Schlumberger CBL dated 7/1/82 (short joints at +_ 7400-7450' MD-RKB) 7) Perforate the following interval: Depth (MD-RKB) ]=C~ Shot Density Phasing 71 1 0'-7192' CBL 7/1/82 4 SPF 0° or DIL 6/28/82 8) After last gun run, POOH, RDMO E-line unit. 9) Return well to injection. RECEIVED JUN Oil & Gas Con3. Co~[ss[orl ~ Anch0i's;e 1. 5000 PSI ?" WELLH[.AD OONNECTOR FLANGE 2. 5000 PS1 WIRE:LINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ,H, ] REL ],NE BOP Eo,U ! PHEN? · V.' Ch~'~'ertOn Mr. ~, 1986 May Page 2 · ATTACHMENT ~ ~, ~.v ~ r !e~,6 ~" KUPARUK RIVER UNIT INJECTIOh LOGS . INITIAL INJECTION PROFILES Well Number Date of Initial Injection Date of Injection Profile 1A-7 3/21/83 3/25/83 1A-9 3/1/83 3/22/83 1A-11 3/7/83 3/21/83 1A-12 3/1/83 3/6/83 lA- 13 2/4/83 10/17/83 1A-14 2/22/83 '. 4/11/83 1A-15 3/1/83 3/18/83 1A-16 3/1/83 3/24/83 Well Number Date of Initial Injection Date of Injection Profile 1E-lA 1E-4 -- 1E-9 1E-16 1E-19 1E-21 1E-23 1E-27 1E-30 5/8/83 5/17/83 4/17/83 5/19/83 2/16/83 10/4/83 2/8/83 3/7/83 2/10/83 8/2/83 2/11/83 3/15/83 4/29/83 5/11/83 5/2/83 10/4/83 5/3/83 4/5/84 2/11/83 10/7/83 2/14/83 10/7/83 Well Number Date of Initial Injection Date of Injection Profile 1F-10 8/13/84 10/30/84 1F-11 8/12/84 9/24/84 1F- 13 8/16/84 9/25/84 1F-15 8/16/84 9/26/84 · Well Number Date of Initial Injection Date of Injec.tion Profile '- 1G-3 1G-6 1G-9 IG-i4 1G-16 10/25/85 12/20/85 7/28/84 9/23/84 9/15/84 9/23/84 8/24/84 9/22/84 8/24/84 9/22/84 STATE OF ALASKA O~~' ALASKA ,L AND GAS CONSERVATION C v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' TllN, R10E. 683' FSL, 813' FEL, SEC. 16, BOTTOM HOLE LOCATION' SEC. 16, T11N, R10E. 5. Elevation in feet (indicate KB, DF, etc.) _ 105 (KB) 12. 2376' I~L, 1732' F~L, 7. Permit No. 82-78 8. APl Number 50-029-2072'0-00 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-13 11. Field and Pool KUPARUK RIVER FIELD 6. Lease Designation and Serial No. KUPARUK R I VER O I L ADL 25651 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation .J~] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all Pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On October 27, 1982 a step rate injectivity test was performed River Unit Well 1E-13. Following is a log of the times, surface pressures. on Kuparuk rates, and Time Surface Pressure Injection Rate 1305 1850 psig 384 BWPD 1335 2100 204 1405 2300 447 1410 2500 1368 Following the test the tubing was displaced with diesel and the well was left SI. RECEIVED MAY 0 6 1983 Alaska 0il & Gas Cons, Commission Anchorage 14. I hereby certify, that the_ foregoing is true and correct to the best of my knowledge. Signed Title OPERAIIONS The space below for Commission use COORDINATOR Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK ENGINEERING TRANSMITTAL TO: William Van Allen FROM: D.W. Bose/Shelby J. Matthews WELL NAME: Transmitted herewith are the following' PLEASE NOTE': BL - BLUELINE, S - SEPIA, F - FILM, T - TAP PY RECEIPT ACKNOWLEDGED' PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN: SHELBY J. MATTHEWS - AFA/311 P.O. BOX 360 ANCHORAGE, AK. 99510 C~' 'any ARCO Exploration · Exploration O .,tions - Alaska Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 SAMPLE TRANSMITTAL SHIPPED TO:-STATE OF ALASKA Alaska 0il & Gas Conservation Comm. 3001 Porcupine Dr. Anch.,AK. 99501 }lAND CARRIED by R.Pittman DATE: Feb. 3,1983 OPERATOR: ARCO SAMPLE TY~E: 'SAMPLES SENT: ~uparuk 1E-30 ~750- 70'84 · Kuparuk 1H-6 6364 - 6421 6424 - 6539 6630 - 6689 Kuparuk 1G-4 6444 - 6467 6469 - 6503 6520 -'6616· 6624 - 6637 6761 - 6885 COre chips NAME:Kuparuk 1E-30,1H-6,1G-4, 1E-12,1E-13,and 1E-14. NUMBE]i~ ..~F BO~]~: 64 _ALL SAMPLES ARE AT ONE FOOT INTERVALS. Kuparuk 1E- 12 7016 - 7018 7026 - 7038 7040 - 7097 7238 - 7266 7270-- 7310 Kuparuk 1E-13 7086 - 7173 7176 - 7228 7294 - 7322 7324 - 7352 7354 - 7439 Box Count Kup. 1E-30 = 13 Kup. 1H-6 = 9 Kup. 1G-4 = 10 'Kup. 1E-12 = 6 Kup. 1E-13 = 12 ~up. 1E-14 = 14 Total boxes =64 Kuparuk 1E-14 6603 - 6628 6635 - 6645 6649 - 6766 6769 - .6934 "NT BY: Paleo Lab Tech. · RECE T OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED .COPY OF THIS FORM TO: RECEIVED BY: ARCO EXPLORATION CO. P. O. BOX 360 ANCHORAGE, AK. 99510 ATTN: R. L. BROOKS DATE: ARCO Alaska, Inc. ~ Post Office Bo 60 Anchorage, Alaska 99510 Telephone 907 277 5637 Landon B. Kelly Kuparuk Operations Manager October 21, 1982 Chat Chatterton State of Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 Commission Dear Chat: Attached is a notice of ARCO injectivity tests/un-propped wells 1E-10, 1E-9, and 1E-13. Alaska, Inc.'s intent to run fracture treatments on Kuparuk These wells are low rate producers that will be converted to water injection for the Increment I Waterflood late~ this year. We feel that these wells need to be stimulated to ensure sufficient injection rates to prevent freezing problems. Based on our previous experience, we anticipate that creating short, unpropped fractures by injecting water at pressures above the formation parting pressure will result in improved injectivity at pressures below the fracture pressure. Notice of our intent to clean out well 1A-11 is also attached. Please call me at 263-4528 if you have any questions. L. St ramp Kuparuk Operations Coordinator RLS/b Attachments xc: L. K. Blacker - AFA 330 L. M. Sellers - ANO 332 E. A. Simonsen - AFA 331 H. C. Vickers- AFA 326 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ( OI STATE OF ALASKA O(v ALASKA LAND GAS CONSERVATION C .MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, :INC. 82-78 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 5o-029-20720-00 4. Location of Well SURFACE LOCATION' 683' FSL, 813' FEL, SEC. 9. Unit or Lease Name 16, KUPARUK RIVER UNIT T11N, R10E. 10. Well Number 1E-13 BOTTOM HOLE LOCATION' 2376' FSL, 1732' FEL, SEC. 16, T11N, R10E. KU 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. _ 105 (KB) ADL 25651 11. Field and Pool PARUK RIVER FIELD KUPARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate ~] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perform a combination step rate/unpropped fracture treatment on Kuparuk well 1E-13 to gain further reservoir data and to improve the injectivity of the well. The test will consist of injecting heated water from our water source well testing program into the well for approximately thirty minutes at each of the following surface injection pressures: 1800 psig, 2100 psig, 2400 psig, 2500 psi. g, 2600 psig, and 2700 psig. The anticipated fracture pressure at the surface is 2437 psig. After the test, the well will either be produced to tanks, produced to the CPF, or shut-in, depending on the results. Expected start date' 10/28/82 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ¢-~.,~ L, ~"~ .~~ ; ho ~ ~ ~j; % s?j~jjro vC~ ,~ T~ sj¢: n use Title KUPARUK OPERATIONS COORD!,NATOR Date ~,pproved Copy Rev. 7-1-80 COMMISSIONER Returned By Order of the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE: F - F/IM, T - TAPE, PC - PHOTOCOPY AsIPT A~~: E ~ R~CEIPT TO: ~.. .REC,EIV.,EO~ ~ ~a_~. SE'- 2~~9~2 ARCO ALASKA, INC. Alaska 0ii & Gas Cons. Commissiorl ATIN: LORIE L. JOHNSON - AFA/311 Anchorage P. O. BOX 360 · ANCHORAGE, AK. 99.510 TO: KUPARUK ENGINEERING TRANSMITTAL # /~ /~1~ FROM: D.W. Bose/Lorie L. Johnson Transmitted herewith are the following: .. PLEASE NOTE: F - FILM, T'- TAPE R~EIPT ACKNOWLEDGED: ~LEASE RETURN 'RECEIPT TO: ARCO ALASKA, INC. ' AI~ska Oil & ATTN: LORIE L, JOHNSON - aF~~e P. O. BOX 360 ANCHORAGE, AK 99510 TO: KUPARUK ENGINEERING TRANSMITTAL Transmitted herewith are the following: NOTE: ~-BLuELIN~~E ~ F- FILM, T~- TAPE PLEASE ARCO ALAS~, INC. " ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX B60 ANCHO~GE, ~ ~ 99510 ARCO Alaska, Inc. ~, Post Office BoX 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 28, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1E-13 Well Completion Report Dear Mr. Chatterton' Enclosed are the well completion report and gyroscopic survey for Kuparuk Well 1E-13. If you have any questions, please call JoAnn Gruber at 263-4944. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JG:llm Enclosures GRU1/L52 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany A.( STATE OF ALASKA ALASK ._ AND GAS CONSERVATION C'~[._ .VIlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL7[~xx GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-78 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20750 4. Location of well at surface 9. Unit or Lease Name , 683' FSL, 813' FEL, Sec. 16, TllN, RIOE, UM LOCATIOI~ Kuparuk River Unit At Top Producing Interval VERIFIED i' 10. Well Number ~ ~_ ' 1E-13 2604' FSL, 1992' FWL, Sec. 16, TllN, R10E, UM l~$urf___ _ At Total Depth B.H.~ 11. Field and Pool 2376' FNL, 1732' FWL, Sec. 16, TllN, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.)16.Lease Designation and Serial No. Kuparuk River Oi 1 Pool 105.7' RKBI ADL 25651 ALK 469 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 06/14/82 06/28/82 07/02/82 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7750'MD,6695'TVD 7645'MD, 6612'TVD YES J)(-I NO [] 1909' feet MDI , o0, (approx) 22. Type Electric or Other Logs Run D IL/SP/GR/SFL/FDC/CNL/Cal, RFT, Gyro/ccL, CBL 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# ~-40 Surf 78' 24" 296sx AS I I 10-3/4" 45.5# (-55 Surf 2678' 13-1/2" ll00sx AS Ill & 250 sx AS II 7" 26.0# .-80/ Surf 7732' 8-3/4" 1234sx Class G & 250 sx A:~ II (-55 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) 7402 ' -7416 ' ') 3-1/2" 7054 ' 6976' 7345' -7358' 7374'-7398' 4spf, 90° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS~OILRATIO TEST PERIOD ~ Flow Tubing Casing PresSure CALCULATED .k, 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. See attached sheet AUG- I982 /~lasI<a 0il & ~;as COns. C0~'~rnissi0n ~,nch0rage .,, Form 10-407 Submit in duplicate Rev. 711-80 CONTINUED ON REVERSE SIDE GRU1/WC13 NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7111' 6195' N/A Base Upper Sand 7190' 6256' Top Lower Sand 7331' 6365' Base Lower Sand 7496' 6494' · 31. LIST OF ATTACHMENTS Drilling Histor¥'~ Core Description, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge / / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements giVen in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 Show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data 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 KUPARUK 1E-13 Core No. 1 2 '3 4 5 6 7 8 9 10 Depth 7086-7114 7114-7134 7134-7176 7176-7205 7205-7234 7294-7324 7324-7354 7354-7384 7384-7411 7411-7441 Cut/Recovery/% 28'/28'/100% 20'/20'/100% 42'/40'/95% 29'/29.5'/102% 29'/24'/83% 30'/29'/97% 30'/29'/97% 30'/27.5'/92% 27'/29.8'/110% 30'/29'/97% Lithology Shaly Mudstone Shal y Mudstone/Sandstone Sandstone Sand s tone/S i 1 t stone/Mud s tone Si 1 tstone/Mudstone Si 1 tstone/Mudstone Sandstone/Si 1 tstone/Mudstone Sandstone/Si 1 tstone Sandstone/Si 1 tstone Sandstone/Si 1 tstone/Mudstone AUG- i 82 /~nchoracje 1E-13 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 0600 hrs, 06/14/82. Drld 13-1/2" hole to 2693'. Ran 162 jts 10-3/4", 45.5#/ft, K-55, BTC, SMLS, csg w/shoe @ 2678'. Cmtd 10-3/4" csg w/1100 sx AS III cmt & 250 AS II cmt. ND diverter. Set 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' of new form. Chg over to polymer mud. Tstd form. to. 12.5 ppg EMW - ok. Drld 8-3/4" hole to 7086'. Cut core #1 f/7086'-7114' & core jammed. Recovered 28' of shale. Cut core #2 f/7114'-7134' (recovered 19') (sh, Kuparuk Sand). Cut core #3 f/7134'-7176' (recovered 40') (Kuparuk Sand). Cut core #4 f/7176'-7205' (recovered 29') (sand. sh). Cut core #5 f/7205'-7234' (recovered 29') (interbedded siltstone & sh). Ream 7086'-7234',. Drld 8-3/4" hole to 7294'. Cut core #6 f/7294'-7324' (recovered 29') (interbedded siltstone & sh). Cut core #7 f/7324'-7354' (recovered 29') (interbedded siltstone & mudstone, i nterbedded sandstone). Cut core #8 f/7354'-7384' (recovered 27') (sandstone, siltstone, mudstone). Cut core #9 f/7384'-7411' (recovered 27'). Cut core #10 f/7411'-7441' (recovered 29') (interbedded sandstone, siltstone, mudstene.) Reamed f/7294'-7441'. Drld to 7750' TD (06/28/82). Ran DIL/SP/GR/SFL/FDC/CNL/Cal f/7731'-2671'. Sample fluids @ 7389' &,7128'. Ran RFTs. Ran 128 its 7", 26#/ft, K-55 & 42 jts 26#/ft, L-80, BTC csg w/shoe @ 7732'. Cmtd 7" c~ w/1234 sx Class G cmt. Instld 7" packoff & tstd to 3000 psi - ok. Drld cmt to 7645' PBTD. Ran gyro/CCL f/7550' - surf. Ran CBL f/7554' -' surf. Perf'd 7402'-7416' & 7345'-7358' w/4 spf & 90° phasing. Perf'd 7374'-7398' w/4 spf & 90© phasing. Arctic packed 7" x 10-3/4" ann w/300 bbl H20, 250 sx AS II & 97 bbls Arctic pack. Ran 3-1/2" peri: completion assy w/tail @ 7054' & pkr @ 6976'. Tstd tbg hanger & packofi: to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp brine w/diesel. Dropped ball & set pkr. Tstd tbg to 3500 psi - ok. Tstd ann {3-1/2" x 7") to 200 psi - ok. Press ann to 2000 psi & tstd - ok. Pressured tbg to shear out @ 4100 psi. Cl-osed SSSV @ 1909'. Instld tree cap & tstd to 3000 psi - ok. Secured well & released rig @ 2200 hrs, 07/02/82. JG:llm 07/07/82 GRU1/DH24 CAMEF;.,A NO.t 1629 GYRO NO~' 63? 5--.90 .T.).r:!iG, A/..I NOt .1.248 F:' .r.) R E c:-._., .T. lq... 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Z F;,' E C T .T. 0 N F E F.i: T D H t] M F' E E T F E E "f' F' E F.i: T F' E E T F' E E T F E E: T D H S ~-' T' ,E~, E. RI ZIG,/100F' Snr',a,.~ 33 15 N 54 0 W :1.00, 2753,~F-'- 896,5'-' o/,zt8·,08 507,94 N 738,-.'4 W o,-,z 52 N %5 ")'-' ,.,7~.,, ~:.7 W 0,60 .,·........, .... , ,.,. ..K.. ., 3100, ,Z,.";~Cs N 52 0 W 100, ,~o~-:, ="-, 951 11.-."~'"'z 1.., o'-~'-'~:: 540,83 N 782,38 bl o~-:;,..,1 , 11 N =' ~:' .......... ...'.. · .:'z, ,? r~ ~'~, ..... -~ ~z ..... 0' 'N-5~ .0---q, ~ ........ .'[-0.. 0 ,,...,,...,. ~, . ...,* ...~ .., · ...-., ~:5;nO., "z3 50 N .s.'z, 0 W 100, xnO'q OF;: lr, A,:],''''~ '",po9 7~0 606,98 N 869,38 13 1060 7~n N.,.,='= 5 W 0,50 .-f, 40n, '~S 30 i',/ 5.'_f 0 I,,I 100, X0F-,'8,41 tlIF; 4° ":,oo9 -"1 640,on N 913.~46 W 1115 54 ... ., ........................... 0 W 100, 3171.,68 1!70.:74 3065,98 673,52 N 957,69 W 1170,8I N 54 53 W 0~25 0 W 100, 3254.,94 1226~07 ~149.~24 706,85 N 1001,9I W 1226~16 N 54 48 W 0~25 n., H.. 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O0~ A97~+36 lo-c;, oo .a16-~ z.z, 1085 ~6 N 151J,,02 W I860,74I x; 5.4 lC' W 0,00 100, 4360, xg,. lOa°, o7 ......, ..... 4°54, ~©.,`. ,, !ti=;, ..... ,48 N 154c', 83, ~) 1909,='),<. N 54 15 k) I.,0o~ 5000, 29 0 N 52 0 5100, 28 45 N 51 0 .... 5200;- ...'3.,0 0 N -51 '0 5300. 32 15 N 52 0 5400, 34 ~0 N 5.1. 0 W 100, 4447,85 1957~46 4342,15 1145,35 N 1588,03 W t957~96 N 54 12 W 0~00 I/.t 100,,a .~'~':;,_ ....., 42 2005,6-z,-, 4aoo., ~= . ~ '~o, ,... 1175,39 N lZO=;,,,,. ~ · ,.,c:°~. W 2006 ~ °0... , ......... N 5;4 ,.c:', W 0,54 -- I,O. ......... .t.-00-;----q -8~72-;-5-.~-~? 05=4 -;' 5-.--f ...... .4'5.1:-8-,.:8 6 .......... .I:-'20 6-;'?5--N----I~>?,-v? 4 .... W---'2 0555- I'8 ....... N '-' 54 ........ '4'-W .............. tw'"?5- .... W 100, 4708,I6 2106 09 4602~46 1238,,43 N 1704,39 W 2:i06~81 i"4 5.4 0 W 2~31 '"':'" W '-' 32 to. 100, 4791,66 216o,9/,_ .. .a,.6RS~96, ..... I''~:-'o~., ,=, AY_ N 1747,44 W 5500. ...'3.,6 .1. 5 N 5.1. 0 W .I. O0, ,5600, J~E,,' 45 N ----5-700'; ..... .78"--'~ 0 -N 5800, 37 45 N 5900. -z-~ n N · ...., ~ ..~. . 4 F' ~ DtE ,-, W E.:. 1... 1... i,,! _O; :1. ,-_z, h:CI. JF'AF:!..tK FT~!...D ~ NOF.,TH F:' A G E N .r.)., :5 i',! E A'S LI tq!'E .T.r ..T.~'R'T-F T ........... .T.~ R T F D E F:' T F! A i',.! G 1... E f.) I R E r.:: T F' E [..-'. 'f' D H D 6000~ :35 .I. 5 N 50 6100~ 7.4.4 30 N 50 ' 6200'.~ .... ._"5.30-N' 50 6S00~ ,"~,q?0 N 49 -'.40,", '~,.1."zO N 49 T F.: U E: T ..... COURSE-'U EF.!'TTC AI2'- V E R T.T C'?~ L ...... S UBE;'EA ........... R -'E--C-T-;~--]W-~- -Z?].:7--Pi-Ft ................. C- 1L"--0-'S- Lr-'F:-'E !ON L. ENGTH DEF:'TH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI7 H F' E E T F' E E T F' E E T F:' E E T F E E T F E E T D H D G / I 00 F n,,W .1nO,, .=;o6o~. ~ ~A n='~J.,56.,: .... ~Io,:,,c.,_:,'" ¢,z i507~-79 N ,...0,=,~, ,'~ '~" .aO W '~5o'~z ............ ,-~ N 5~r 18 W n t,,J 10n ~ F;~F;.1. , An ~=--,.,o, 4R ,::.;".',.a oO ................ ,, ....... 5., 154.4,55 N 2067,"":'0 W .?=;8,"',.,,50 N 53 14 W 0,75 0 ' [91 ..... ]' "0 f~';- ....... .=;(Zt-z-Zt'-,' "7-~ ........ '? ~--z '"z' ;-'7 o ....... .=~] -t'? O-7--h-':.n._ ........... T~:;'~O'E-")-?.,-----i~j---"rl],'¥~.~, :~,---!,3 ....... n ~.-u:;--o, .'9- .......~:].-,i=N'z' ....... 1"l')'--1';1 ................ 1-7'~'r't] ...... O.. L,J 10o.,_. ,. 5;5.1. o,(.':,8. , ..... .,.,_,9,'..o, 7 ., '-'1,= 5413.,:'38 1615,15 N ,..7150,6---),... W 2689 ,.. ~°... , N 5''z., /,_ W 1,'~4., 0 W .1.00, ,SAn4.: 1! ,.-.., ,., .,'":'"::'.~c'/~0 ~4c.'aS.,.a'~ 164o..., 67 N 7190,3"':" W "':'":'4'-',,.0° .'5 ,..: FI 7, 1 W 0.,50 ..... . .... _, ~ ~.,i ...b ,'" _, ';00., ...'3.,0 ...'3.0 N 48 0 bi '~.,. Of).,.F;A89.,, 83 o79 z. .... , 6 W 1,1? 6700 i .-:, r," ' .a ~ 'N 4P, o W .1 O0 :, ~'.¢. ?, -o-? .. .... ;. ~ ........... .. -.... · ...... , ~..., ~. , ,. a.. l",,.c..~. (:'0 ,, ............... .'~."q ...... 4.% N. Z~F:, P,.:1,4 1.00.,, ,.,= O.a -/ ., 40, . . , ,=."-, o z,. n, , .<. ,, 84 Fl.c".'4 '~ -:.':'c;-,. ., ,' 1-Jo:' '':..' :.,,., .:. 5'a, N .~°343,,01. W .,:.'=' 9 .4 6 ., .,~'"'. , .,.:. N 5'"".,,. ,..~,,r',.., H. 3, hr',,, ,, A c'Or', ~. .... XA ....... ...... r,.., N 45 n,.. W In,", ~.,..., Ao'~o, ,.:. , ~ .~:~">,.... ,.,.')°q;'c/, . , , ._.,"Zl .~92~ ~ 82,. 1°'-':5 , Rc;', N. .~.738.a. , 48 l,,J ,.,"zP,,.. 0 ,..,-z -, ,.::'~"., N 5 .,,:--, ._,-"r,.,'z I.,.). 2,83: 7r.,r~r~ ..]~8 45 N 474 0 H .1.00+ ........ £1O,o,,o,q ............ ~f-)~8.7~ AOc',.'~.'::'P, 1RAO.,"';.~ N .°.a.n.z.A.a [,~ ~OAT. 3.0 N ='"" °3 I/J 3 01 7.1.00 74.0 4.=; N ,~X o l.,~ 100~i.::::~i6186..,42 ..... ,...::~, N 5'..' 1'-' W .1. oo -"~00 ............... .-49 r', N 41 0 W .1.00:::~::;::i:-i:6340,60 324~.~;lg~¢/62~4., 9o. ~0.t0~0~ - W ,..,"'z "'" '::i.,:. ..., 1 18 x.~ 5; 1 -48 .[,.,~ 0 98 7~00. _ , ,.'37.. 45;. N 41 n,.. bi. .1.00., 6497.,,5.7, SS6-4 ,, 45 7550,, 37 45 N .aO 0 I,.t 50 6.~7q7 06 3.L394,n'::-' A.43.1.,,ZA '-'1?-:, ,37, N .nA?]A,25 (,l 3403 11 N .':']1 19 L<) 1,'')'::' F'F.:O._.~E:CTEtE~ 1'0 7640 'THE FOLI_.OWING SI'ATIONS ARE: F'ROJE.r..':TE:D FOR INTERPOLATION VAI..UES~ '.7645 MD- F'BTI) ';'64,'.5,, 37 45 N 40 0 W 5, ¢..,61'~.,. , 18 3a.~0,06. , .... 65o6,48 ~:'-'~ 71,89.,. N 269S · 6..'3 W ,.,~460 · ].6 N 5;]. ~., .[,I 0 ,00 -~ 7 50 --'M D'-'---TI) .................................................. 7750, 37. 45 N 40 0 W ].0::;,_. /,A9~: 20 ...... ,_,'z5~ ,...: Ol.. 6589 , ..=;n.. ,. . ., . ~ ..9 '-- > ';' ]. , 1~,_, N 2734,9.'=;_ W 359~,.. · ~...'"6 N 50 55. W 0~00' F']:NA[.. CL.O.C:;IlRE: ....... --- DIRE:CTION~ N 50 DE:GS =.%,.,,. MI NS ................................................... ~.. · . -+ ................ r~- ~. "Z - "~')"f. ....... ~S~ ~-'" DI .: r ANCE., =4...: ......... : .....E. ET R ~ECo W ._IO~ NO~ A0781.)G0447 OA1'E RUN~ 01~,.~1UL-8'2 CAMERA NO~' 16:).9 GYRO NO: 6'32 ~;--90 OEG.~ A/U NO.', 1,':..).48 F'OREiSIGFII'~' N 00 E PAD E,,WEL. I... NOt .1...'5 Gl'IS lOB NO~ An-.-'~r~n447 TIME DATE K I...1F' A R I...I K F I Eli...T.~ .,' "N 0 R T H S EO F'E, A [.i A S K A "m'z~?"'~.':~'?'-~.~,' ........ ?x"::-~q~ a.....' .1 .,....... I, .~ -.. ~......i .......... ~... ~._~ ...... : ................. MARKER ............. TRUE SUBSE.:A ..... :-:=:' :: =~ :;= =- -C '0 T.i E--::::::::::-:.: :.: :::=: --t"t E '~-BL.11q. IET. F-V ERTI C "~i' [it--Pi .T,F=T~TT.i-'~:~EF,t T .T.'C:'A"[~'-' R"- E--C--T --A~N-~C~--I.~?~]--A--'R .............. C-I/Z--O--B--ZT-R-'E ................. b~ERTITt_. '~'[.. ............. NAME.'. .............. DEPTH DEF'TH DIFF' ]:IEF'TH C 0 0 R !g I N A T E S DISTANCE DIRECTION THICK:NESS FEET FEET FEET FEET FEET FEET .0 M 'TOP OF' UF'F:'ER ...q. AN!) BASF...'. OF: UPPER SAND "T 0 F" 'OF '-'L'O WE R "- SAND BA._qE OF L. OWER SAND F'BI'T.~ 7111+00 6194~88 916~1 6089~18 1921,01 N 2474,54 W S152~67 N 52 11 W 7190~00 6:~lF,~...~._,~,.z,'~ oz4,_ ~4 6149~97.... 1958~2~ N. 2508~67 W ~182~48_ N 52 I W 7496,00 6494,S8 10n1,z.~ ~., 6S88,,~F~ ...... -,].0~. ~...,20. N 2634+7=;. ~ W S370,6~.~, N 51 ~ W 7645,00 6612,18 ].0S2,8 6506,48 2171,89 N 269S,6S W S460~16 N ~JI 7 W A ?~'TROLAN£ C©~4PANY ! Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. · Operator. ~ W~l 1 Name ahd Number Reports and Materials to be received by: ~-- 0 · - Date Required Date Received Remarks Completion Report Yes ff --~ 3- ~ l,.,d.,/'d~, _ Well History Yes _s~l~s "~d --.P I J f" , · , Mud Lo:j ~ . ...... , pi ,Core ~scription ~ 3 . ~--~ ~-~ l :d ~!*. ,,. Registered ~ey Plat ~ ~ ~ ~, , Inclination S~ey. ~~ Drill Stm Test Returns ~d ~'~ ~ , KUPARUK ENGINEERING TO: ~~ Y~4~~FROM: D.W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM,~ RECEIVED ~ ,~ ~ J U L 2 9 ]t§82 Anchorage PLEASE RETURN RECEIPT TO: . . ARCO ALASKA, INC. ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK 99510 ARCO Alaska, Inc. t Post office Bo[ 0 Anchorage, Alaska 99510 Telephone 907 277 5637 July 12, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear_ Mr. Chatterton' Enclosed are monthly reports for June on these drill sites- 2-24 14-22 2-25 15-6 6-17 18-1 13-22 18-2 13-25 ~~~ 13-26 1H-8 14-15 Also enclosed is a well completion report for Kuparuk 1E-12, and subsequent sundry reports for' 3-14 14,-6 4-9 15-3 4-15 Eileen No. 1 11-4 NGI-7 (Since the information on the Eileen well is of a confidential nature, we would appreciate it if you could store it in a secure area. ) Surveys for 2-22 and 13-21 are being reran; completion reports for these wells will be submitted when approved surveys are received. Sincerely, P. A. VanDusen Regional Drilling Engineer PAV/JG:llm Enclosures JUL 1 2 1 82 Oil & Gas Cons. Comrnis$ioa GRU1/L48 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldComp'any .~: , STATE OF ALASKA ALASKA ~'. AND GAS CONSERVATION CO(~''' dlSSlOU MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well Xl~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-78 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20750 9. Unit or Lease Name FSL, Sec. 16, T11N, R10E, UN Kuparuk River Unit 4. Location of Well 813' FEL, 683' at surface 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 105.7' RKBI ADL 25651 ALI( 469 10. Well No. 1E-13 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of June ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0600 hfs, 06/14/82. Drld 13-1/2" hole to 2693'; ran, csg, Drld 8-3/4" hole to 7086', Cut cores. Drld to 7294', Cut cores. Ran logs & RFTs, Ran 7" csg. Cementing 7" csg as of 06/30/82, SEE DRILLING HISTORY cmtd & tstd 10-3/4 Drld to 7750', 13. Casing or liner run and quantities of cement, results of pressur9 tests 16", 62.5#/ft, H-40, conductor set ~ 78'. Cmtd w/296 sx AS II. 10-3/4",45.5#/ft,K-55, BTC csg w/shoe (~ 2678'. Cmtd w/1100 sx AS III & 250 sx AS 7", 26#, L-80/K-55, BTC csg w/shoe ~ 7732'. SEE DRILLING HISTORY II. 14. Coringresumeand briefdescription Core #1 7086'-7114' (recovered 28' - shale) Core #2 7114'-7134' (recovered 19' - shale, Kuparuk Sand) Core #3 7134'-7176' (recovered 40' - Kuparuk Sand) Core #4 7176'-7205' (recovered 29' - sand, shale) Core #5 7205'-7234' (recovered 29' - siltstone, shale) Core #6 7294'-7324' (recovered 29' - silts~one: shale) 15. Logs run and depth where run DIL/SP/GR/SFL/FDC/CNL/CAL f/7731'-2671' RFTs, Core #7 7324'-7354' (recovered 29' - siltstone, mudstone, sandstone) Core #8 7354'-7384' (recovered 27' - sandstone, siltstone, mudstone) Core #9 7384'-7411' (recovered 27') Core #10 7~11'-7~1' (r~ov~r~d ?Q' - sandstone,siltstone, mudstone) 16. DST data, perforating data, shows of H2S, miscellaneous data N/A RECEIVED J U L 1 2 1982 Alaska Oil & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. //~.~./,./~. Sr. Drilling Engineer SIGNED ~. ...... TITLE DATE NOTE--R is f is required for each calendar month, regardless of the status of operations, and must be Oil and G~ Conservation Commission by the 15th of the succeed ng month, unless otherw se directed. Form 10-404 Rev. 7-1-80 GRU1/MR1 8 f//t' Ieo in oup icate with the Alaska Submit in duplicate 1E-13 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 0600 hrs, 06/14/82. Drld 13-1/2" hole to 2693'. Ran 162 jts 10-3/4", 45.5#/ft, K-55, BTC, SMLS, csg w/shoe @ 2678'. Cmtd 10-3/4" csg w/1100 sx AS III cmt & 250 AS II cmt. ND diverter. Set 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' of new form. Chg over to polymer mud. Tstd form. to 12.5 ppg EMW - ok. Drld 8-3/4" hole to 7086'. Cut core #1 f/7086'-7114' & core jammed. Recovered 28' of shale. Cut core #2 f/7114'-7134' (recovered 19') (sh, Kuparuk Sand). Cut core #3 f/7134'-7176' (recovered 40') (Kuparuk Sand). Cut core #4 f/7176'-7205' (recovered 29') (sand. sh). Cut core #5 f/7205'-7234' (recovered 29') (interbedded siltstone & sh). Ream 7086'-7234'. Drld 8-3/4" hole to 7294'. Cut core #6 f/7294'-7324' (recovered 29') (interbedded siltstone & sh). Cut core #7 f/7324'.-7354' (recovered 29') (interbedded siltstone & mudstone, interbedded sandstone). Cut core #8 f/7354'-7384' (recovered 27') (sandstone, siltstone, mudstone). Cut core #9 f/7384'-7411' (recovered 27'). Cut core #10 f/7411'-7441' (recovered 29') (interbedded sandstone, siltstone, mudstone.) Reamed f/7294'-7441'. Drld to 7750' TD (06/28/82). Ran DIL/SP/GR/SFL/FDC/CNL/Cal f/7731'-2671'. Sample fluids @ 7389' & 7128'. Ran RFTs. Ran 128 jts 7", 26#/ft, K-55 & 42 jts 26#/ft, L-80, BTC csg w/shoe @ 7732'. Cmtg 7" csg as of 06/30/82. JG:llm 07/07/82 GRU1/DH24 RECEIVED JUL 1 2 ]982 Alaska 0il & Gas Cons. Commissjo,~ Anchorage MEMOR , IDUM sta\e of 'Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO~ C. ~. ~tg~rton D^TE: June 22, 1982 , FILE NO: 108/P Thru: Lonnie C. Smith , % Commissioner ~ TELEPHONE NO: FROM: Ben LeNo~an SUBJECT: Witness BO~E ~est on Petroleum Inspector ARCO's Kuparuk 1E-13 Sec. 16, TllN, R10E, UM Kuparuk River Field Undefined Wednesday, June... 16, 1982 - I departed my home at 12:45 p.m. 'f~'"a 1:15 p.m. showuP and 2:15 p.m. departure via Alaska Airlines flight #57 for Deadhorse arriving' at 3:55 p.m. Weather: +29"F, light wind, light snow. BOPE tests on Kuparuk 1E-13 began at 10:00 p.m... Thursday, June 17, 1982- . . and were completed at 12:30 p"m. BOPE ins~cti°n ~eport i; attached. BOPE tests on ARCO'S DS 13-25 were, completed, the subject of a separate report. Friday ,... June !8,_ 1982 - Standing by on ARCO's DS 6-17. June 19 1982 - BOPE tests on ARCO's DS 6-17 were corn ct of a separate report.. I departed Deadhorse via Wien flight #10 at 3:30 p.m. arriving in Anchorage via Fairbanks at 6:00 p.m. and at my home at 6:30 p.m. In summary, I witnessed successful BOPE test on ARCO's Kuparuk 1E-I 3. O~G #4 4/8]. ' ~ ,, · ' ( TATE OF ALASKA ALASKA OIL & GAS O0NSERVATION C(/z~LqSION B .O. P .E. Inspection Report _Inspector Operator /~ ~>_ w, Representative: ~~';~. //9~-~"C~,'~ Location: Sec /~,. TT/~/R/~6M ~ /6;~%sing Set @, ~~ ft. Prillinq Contractor ~9z~/A~ Rig ~-~Representative ~)~_ ~.~F ~;1<~-;~ Location, Genera] Wel 1 Sign Ceneral Housekeeping Peserve pit Test Pressure BOPE Stack Annular Preventer Pipe ~ ACCUMUIATOR SYSTEM Full Charge Pressure ~.~S-o psig Pressure After Closure /~~ psig Pump incr. clos. pres. 200 psig. Full Charge Pressure'Attained: N2 .~1oo. --~.0~..~.~1~./~J-~ psiq / 1. / - _ Controls: ~ster _ Remoke Z~/(~ Blinds switch cover~--~ Kelly and Floor Safety Valves - Upper Kelly Test Pressure Lo~er Kelly Test Pressure ~_~ · Ball Type__~D~f~ .Test Pressure Ins ide BOP~est Pres sure Choke Manifold Test Pressure Blind Rams Choke Line Valves.__ H.C.R. Valve-- Kill Line Valves Check Valve Test Results: Failures, v ves.__ .... NO. flanges___ ~Z%) A~j ustab le Chokes ~ Hydrauically operated '~e Test Ti~' ~ ~ '~. Repair or Replacement of failed equipment to be made within days and Inspector/Ccmmission office notified. min q sec. min ~sec. Distribution orig. - AO&OCC /9 ~ cc - Operator ~/~__~ cc - Supervisor Inspector~--~-u ~~ 1982 ar. Mark A. Major Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 9'9510 Petrol t 1~o. 82-?8 Bur. Loc. 813*FEL, 683'F~, Sec 16, Tli~, RXOE, Bt~ole Loc. 3~41'~SL, J694*FSL, See 16, TII~, R10S, Enclosed is the approved application for permit to drill the above referenced wel 1. Well samples and'a mud log are not required. A continuous directional survey is required as per 20 AAC 25.{)59(b)($). If available, a tape containing the digitized lo[~ information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. ~n~ rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadrornous fish. Operations in these areas are subject to AS 16.9§.870 and the resulations prmnul~ted thereunder (Title 5, Alaska Administrative Code). Prior to cmncing operations you may be contacted by the Habitat Coordinator*s Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations prmuulgated thereunder (Title 18, Alaska Administrative Code, Chapter TO) and by the ~edmral Water Pollution Control Act, as amended. Prior to cemmencin$ operations you may be contacted t~ a representative of.the Departumnt of Environmental Conservation. To aid us in schedultnt~ field work, we would appreciate your notifying this office within 48 hours after the well is spt. tdded. ~ ~uld also like to be notified so that a representative of the ~isston ~y be present to witness P~r. Uark A. rdaJor Prudhoe Bay Unit DS 1E-I~ -2- ~y 26, 1982 testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yourS, C. V. Chatterton Chairman of ~Y ORDER OF THE COn, MiSSION Alaska Oil and (las Conservation Commission line 1 o sure Department of Fish & Game, l~abitat Section w/o enel. Department of Environmental Conservation w/o enel. CVC~be ARCO Alaska, Inc. { Post Office B~, 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Hay 11, 1982 Hr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001Rorcupine Drive Anchorage, AK 99501 SUBOECT: Kuparuk 1E-13. Dear Hr. Chatterton: Enclosed are: · An application for Permit to Drill Kuparuk 1E-13, along with a $100 application fee. · A diagram showing the p'roposed horizontal and vertical projection of the wellbore. · An as-built drawing of "E" pad indicating the proposed surface location. · A proximity map indicating the relative location of Kuparuk wells 1E-5, 1E-6, and 1E-12. · A determination of the maximum pressure to which BOR equipment could be subjected. · A diagram and description of the surface hole diverter system. · A diagram and description of the BOR equipment. If you have any questions, please call me at 26~-4970. Sincerely, 3BK:30/hrl Attachments ' ON I1/A~O ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany Oil & ~a.~ Cons ,, Anchorag'~ ~°mmiSSion O(iL STATE OF ALASKA . fi' ALASKA AND GAS CONSERVATION COI~,MISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [~K MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, AK 4. Location of well at surface 813'FEL, 683' FSL, Sec, 16, T11N, At top of proposed producing interval 3474'FEL, 2510'FSL, Sec. 16, T11N, At total depth 3741'FEL, 2694'FSL, Sec. 16, T11N, F ECE!VED R10E, UH MAY1 9 1982 R10~as~10il & Gas Cons. Commission R10E, UM Anch0rag~ 5. Elevation in feet (indi_cate KB, DF etc.) I 6. Lease designation and serial no. 66.7' GL, 71.7'Pad, 105'7/RKBIADL 25651, ALK 469 12. Bond information (see 20 AAC 25.025) Federal insurance Co. Type St atewide surety and/or number #8088-26-27 9. Unit or lease name Kuparuk Rlver Field 10. Well number 1E-13 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW Deadhorse miles At surface, 683' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7716' MD, 6624' TVD fe~t 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICKOFF POINT 1000 feet. MAXIMUM HOLEANGLE36° °l(see2OAAC25.035' (c) (2) 21 Proposed Casing, Liner and Cementing Program 15. Distance to nearest drilling or completed 1E12Well At surface 120' feet 18. Approximate spud date 06/24/82 2782 3165 psig@80~ F Surface ...psig@~l~ ft. TD(TVD) SIZE Hole Casing Weight 24" k. 16" 65# 13-1/2[ 10-3/4. 45.5# 8-3/z~ 7" 26# 7" 26'11: 22. Describe proposed program: :ASING AND LINER Grade Coupling Length H-40 I Welded · 80' K-55 [BTC 2629' L-80 /BTC 3859' K-55 /BTC 3826' SETTING DEPTH MD TOP TVD 3Z;. 7' 134.7' 32 9' 132.9' ' I I 31 0" I . ,31.0' 3890' 13500' i MD BOTTOM TVD 115' 115' 2662' Il 2500' ;3890' I 3500' 7716' 6624' QUANTITY OF CEMENT (include stage data) 150 cf 1100sx AS III plus 250sx AS II l125sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field, Kuparuk River 0il Pool develop- ment weii to approximateiy 7716' MD, 6624' TVD. Seiected intervais wiii be iogged. A 20'~ 2000 psi annuiar diverter wiii be instaIied on the 16" conductor whiIe driiiing the surface hoie. A 13-5/8" RSRRA BOPE stack wiii be instailed on the 10-3/4" surface pipe. It wiii be tested upon instaiiation and weekiy thereafter. Test pressure wiii be 3000 psig (1800 psi for annuiar). Expected maximum surface pressure wiii be 2782 psig based on cooiing of a gas bubbie rising at constant voiume. The weii wiii be compieted with 3-1/2", 9.2# 3-55 buttress tubing. Non-freezing fiuids wiIi be ieft 'in uncemented annuii through the perma- frost intervai. Seiected intervais wiii be perforated within the Kuparuk formation and reported on subsequent reports. A downhoie safety vaive wiii be instaiied and tested upon conciusion of the job. · 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space bey~or~r~mis~n use'- - DATE CONDITIONS OF APPROVAL Directional Survey required APl number ,I~Y E S []NO 50- t~ ~Z-, ~ '- Z SEE COVER LETTER FOR OTHER REQUIREMENTS Samples required Mud Icg required I--lYES [~10 []YES {~f-N 0 Permit number Approval date ,COMMISSIONER DATE by order of the Commission May 26, 1982 Form 10-401 GRU6/A8 Rev. 7-1-80 Submit in triplicate ~EEEiVED MAY 1 9 1982 Oil & Gas Cons. Commission /~nchore. go i 8o,i~ > .' · ~31' r WE E"/~t,~~,- . "~.' " E 'WE ~ ~. . · ... ..: .. 'r- ..,_ " '. 'i glq'" :' · WE , . L " '" · ,isi,=.. ~6~.~...---. m . .. " .-- ~ ,,g F-. >' ~ E4.~. . . .EZ4~ WI · .' ~s,,,,-=~ .... .-- ';" ' '" :':--' > WI :.: i~''I,.,:!=:.: ., ~.- '. :...= ~- :..~.: -' . .. . . ', ..- :C7] ....... ~ ..'~,.:.-... . ~. . · .: ... -~ .~'. ' . ~ ... _ 'i ".,. _..'i7 ' .-- y/.. . .. ;':'~:' ".'- - ". A ';' ..ii · . '' ~';' 2 ' :...:':'~ 7" i:.~?!!.':'~I~ ':.'.~^L~-'r= 2a~' . 16 15 ... '' . ,/ :- . , ~.... ..,~ ......... {-r~,~io~,u.~4.)?.l 2?. EBY 'CERTIFY THAT i AM ~'.i:-,::'....:-: :,.?: .4; ' .¢ .:'Z'.:..J' ." ' ' . '"- ' ,..-.-?.j... -'~..;.!.:. _: .. .- .. _ . . . · · . ., i I WELL //8 Y 5,960,60Oo2~O i' X = -. 549,889.825 ~ 1~ 80~ ,.-----.._ LAT .-- 70°18~11o283'' ~ I - I LONG = 149°35~45 185" _ ' ' I> ., ' WELL #7' Y = 5,960,480.368 ~ ~, ,~,,O =. ,8'10 , , X = 549,889.1~86 il--~=~7 '~4~? ~,Ze' < ~ tAT= 70918' 10.104I'' · s:t~ ' LONG = 149°35~45.219'' .. "~ ,*",,L'1~''' · ~1' r WELL #6 Y 5,~60~360-~,207'. ~~ ~./ · '-~ I-- --- X = - ~49 889.2'55' ~ . . .. - LAT = .70 18~08.923'' - . LONG = 149o35745°249''' · ~." .. ~'~ 'WELL //5 Y = 5,960,240.4i0 '~'~'i':- x ii-..' ~. :.~. · ... · .---:. ~ ~=. -.: >~- .. "X =' - 545'..,889°039 ~ "'__... ,~ ,.i--~'.' .. "=- LAT 70°~8'V07o.74/4'' ... ' r- -.,- ~SS' --! LONG = 149°35~45°278'' !' .., i · '.' - " i . *'. - .... · " - '" 'd, ELY" =' · -_ WELL /i4 Y = .5,~60.,~20.o~55 '~i'-:~.'~:' *o. .."..',' ,, .. .. ' ...... -- X6T~ .... u~ .- .i b~q, , X 549, .,~ .. 889o818 I~ , ~ . x ,~ K' > LAT ' 70°18!06.561'' ,..::~i' ~ ...... ~ · ?' ~...".".'x'~L:"".'-"..' "' I E4~. LON~ = 149°35nq5°279': i. ~ ..:. ," " ~' . ,,.. . ~, . ,8/.~,..i~. . < ..__. . ....... "" "' I ' ~,'"e"-"~ - = ~,~' _-- WELL #3 · Y = 5~960'000o596' x ii -"K E '~J.~. ~ X = 549,889.506 · i LAT =.. 70o18.'05.386'' .= ~....,q. !: - ' , >~'1/.~ : ..i_ .' --~ LONG = .149o35"45.31~" [=..~,,L~ EZ~ : : WELL #2 X: 5,95911,880.504 · ~ i '"'/- ~t' ~ 817'"_ <=~ .Y =. '549., 889.996 ~ . .- ~s ,,i_.~ .~ _ LAT 70°18~04o204'' .. ~., ,, ~ ~ ,'_ 65'1' = - . ~ .,,,, . · EI.L- ~ LONG = 149,35'45o320"' ';;..--;..'.".~ -"..'. l¥" ' ,": '~ ; ·" --~ . .' ...... '"; '~'~"'~" .... :"" "' ' > ' WELL #1 · X = "5'959..,760.244 ...: :.......-.... ~'/... ;. i~ ... .. ., i=: -' /-=:- .: ~.:..;.:: · '.:'.'.C'. '~:..:-'.".:,i:i-~; ..'~.~, ..:/;.'=:'i.: ~.'.. "' 'Y = .... 549",889.514 -' "' ".='.:.' ~,'=;:"'.·."!'.' ~ -'~' ~'""~- "::' ' ...'-' . LAT =. 70°1'8"O3.O22'' "./.~" ;'.. -.~i"- ~ -...' )" '. "i~.'?' I :':L~ ....?i~''-' ' ,'. "i ^ · , ' ' LONG'= 149°35's45°358'' ' · . ..... '.'-- Y: ';T. l = · ; · - . - -" ' '.~.". .'~. ~ "'.'- i'':=' ".=' .' '. · ' ' . ' · ' . : , i ..':' ' · ' ' ' ' ' ':" " '. · - # ~,.'~1 ' .-,'.' .:.q~ ..-.'-~j :...-.-.,......,....~..~. ~... .. __ .-.'='.=,.-."':" .'...- =.... '.~.... ....... {'ri[ N,l~lOl~u.~.)21 ?.?. · ' ~.-~.~,~ OFA/.. ~t:~,~. -" '" ':'~..;':=. '.?:~-!'.HE~EBY 'CERTIFY THAT ~ AM ,' .?_'~..- ....... .~?~'i ':' '~'~.'.'-."i'?'i'p~OPE~L~. ~EG ~STERED'AND L~CENSEb. '~.'.. ~ .~'/'-~-". "'--'" "-''TO ~^CT~CE L^NO.SU~V~'~N~ ~ "~[~iV~:n ~,_%".,~.',?;:j;":':- .':~:~:. · ?-' :' 'THE' STATE OF ALASKA AND THAT ' · - :~.~...;.-'.-.~;u, ..... ~---m .... "-'='~'""' THAT ALL DIMENSIONS AND OTHE~D?ka0ii o"~,-~,- -[' '?~ :~ '- "' ;'."- '~%'~:? ~"-'~.~ ~'~ - · . ,, et ~ao UOflS {,; .... · . - ~ . _..., ..: :.....- ....-. /:- -. . ... . ."',~",~,~..~,..~-,.<~'>-. ..- I I I I II I I I I I I I . . ? , ~ L.5 J.- LQGATIoI...I~.....,. ' I J II I I , 'AllanlicRichtieldCompany 4~ DATE' DRAWlN~ ALASKA DISTRICT ' - KUPARUK I I i Iii I I I I III I I ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3165 psig from RFT and pressure build-up data. This pressure ~ 6060' SS = 6166' TVD will be balanced by 9.87 ppg mud weight. Normal drilling practice calls for 10.4 ppg weight prior to penetration and during drilling of the Uppe£ Kuparuk and remaining intervals. This will result in a 170 psi overbalance. It is anticipated the surface BOPE equipment could be subjec[ed to a maximum of 2?82 psi during drilling opera[ions. Derivation assumes a gas kick at reser- voir temperature and pressure (154°F, 3165 psi), gas migration to the surface without expansion, and cooling to 80°F cellar temperature. This is well below the 5000 psig BOPE working pressure and less than the 3000 psi weekly test pressure. . = pressure initial (reservoir) Pz · = temperature initial (reservoir) Tz V, = volume initial (reservoir) 1 Pf = pressure final (surface) Tf = temperature final (surface) Vf = volume final (surface) PiVi = PfVf Ti Tf Since Vi = Vf, i.e., no expansion. Pi = Pf PiTf ~i -~f Then Pf _ Ti _ (3180 psia)(8OOF + 460) (154UF + 460) Pf = 2797 psia = 2782 psig 30:hrl 05/11/82 ONT1/B2 Surface Dive~ ,- System 1. 16" Bradenhead. 2. 16" x '20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/10" side outlets. 4. 10" ball valves, hyraulically actuated,~ lines to reserve pit. Valves to open~{omati- cally upon closure of annular preve~t~..~ 5. 20" 2000 psi annular preventer. ~ ....... Maintenance & Operation ~ 1. Upon initial installation close annular '! preventer and verify that ball valves ~1 have opened properly. ~ .I 2.~ Close annular preventer and blow air ~ , through diverter lines every 12 hours.. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not shut in well under anS circumstances. 16" Conductor 6. ~20" bell 2ipple. RNNULRR PREVENTOR ..o 13-5/8" 5000 PSI RSRRA BOP STACK · 2. 3. 4. Be ® 16" Bradenhead 16" 2000 PSI x 10" 3000 PSI casing head 10" 3000 PSI tubing head 10" 3000 PSI x 13-5/8" 5000 PSI adapter spool 13-5/8'i 5000 PSI pipe rams 13-5/8" 5000 PSI drilling spool w/choke and kil 1. 1 ines 13-5/8" 5000 PSI pipe rams 13-5/8" 5000 PSI blind rams 13-5/8" 5000 PSI annular . BLIND RRHS 8 " ACCI~,IULAI'OR CAPACITY TEST -" .o PIPE RRHS 7 ILLING SPOOL PIPE RRHS 5 -_ 1. - CHECK M;D FILL ACC~1ULATOR RESERVOIR TO PROIPER LEVEL WIT~ HYDRAULIC FLIJI1). 2. ASSURE THAT-ACCtT-IULATOR PRESSURE IS 3000 PSI WITH 1500 PSI D(7~LSTREAI~ QF THE REGULATOR. 3. OBSERVE TIME THEN CLOSE ~ UNITS SIMULT~qE- OUSL¥ M;D RECORD THE TII~tE AND PRESSURE RB4~[X- ING AFTER ALL U!IITS ARE CLOSED WITI4 CHARGtN6 Pt~4P OFF. 4. RECORD ON IADC REPORT. 1TIE ACCEPTABLE LCt&ER LIMIT IS 45 SECO:(DS CLOSII~G TIME ~(D 1200 PSI REMAINING PRESSURE. . 13-5/8' BOP STACK TEST 1. FILL BOP STACK A~(D MANIFOLD WtTlt ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCl~EWS ARE FULLY TRACTED. PREDETERMINE DEI~ll-I THAT TEST PLU~ WILL SEAT AND SEAT IN WELI.~. RIJN IN LOCK DOWN SCREWS IN HEAD. $. CLOSE ANNULAR PREVEtCFER AIiD CHOKES Arid BYPASS VALVES ON MANIFOLD. TEST ALL CO~4PONF,'(TS TO 250 PSI AND HOLD FOP` . l0 MINUTES. INCREASE PRESSURE TO 1800 PSI AND HOLD FO~ l0 MINUTES. BLEED TO ZE~O PSI. 6. OPEN ANbtULAR PRE1/ENTER AIilD~CLOSE TOP SET OF 7. INCREASE PRESSURE TOy2t)O(0I AND limo FOR MINUTES. ~ /'. ' 8. CLOSE VALVES. DIP~CTLI~UPST~/V'I OF C~OKES. BLEED DO'~NSTREA,'~ PRESSURE TO ZERO PSI TO. TEST VALVES. TEST R~IAINING L~ESTED I4ANIFOLD VALVES, IF ANY, WITH 3O00 PSI UPSTP, E~4 OF VALVE AND ZERO PSI DO'&)ISTI~,EAM. BLEED SYSTB~ TO ZERO PSI. - 9. OPEN TOP SET OF PIPE RAILS AND CLOSE SET OF PIPE RAHS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOP, 10 MINUTES. BLEED TO ZERO PSI. l l. OPEN BOTTOH SET OF PIPE R&MS. BACK OFF RUN- NING JOINT AND PULL OUT OF HOLE. CLOSE BL.I~D RA/,IS /~ND TEST TO 3000 PSi FOR lO I-IINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAHS AND RECOI~ TEST PLUG. MAKE SURE HA~tlFOLD AIJD LILIES ~qJ~E FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN i)RILLI~;G POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCICS Arid II(SIDE BOP TO 3000 PSt WITH KO~EY PUNP. 15. RECORD TEST INFO,~4ATI,ON ~ BLOWOUT PI~EVEiITE1R TEST F'OP~! SIGN AND SEIID TO DRILLI~4G SUPE~- VISOR. 16. PERFORI-! CCIIPLETE BOPE TEST ONCE A WEEK AJIB FUNCTIO(IALLY OPERATE BOPE DAILY. CHECK LIST FOR NEW WELL PERMITS ITeM APPROVE DATE / (2) Loc ~ ,~-Z~ ~' (2 thru 8) (3) Admin thru 11) (4) Casg ~~ ~--~'g~" 1 ~1~2 thru 20) (5) BOPE thru 24) Comp any /&C~,O Lease & Well No. (6) Add: ~ ~ .,J~'.,~2,-' 3. 4. 5. 6. 7. 8. ® · 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. YES NO Is the permit fee attached ....................................... Is well to be located in a defined pool ............................ Is well located proper distance from property line .............. ,... Is well located proper distance from other wells .................. Is sufficient undedicated acreage available in this pool .......... Is well to be deviated and is well bore plat included .............. ~[ Is operator the only affected party .., ........................... ...~__ Can permit be approved before ten-day wait .......................... ~ Does' operator have a bond in force .................................. (~ . .. Is a conservation order needed ........................... , .......... ~-,~ ~ IsIs conductor administrative string approval provided, needed, i.iiiiiiii.iiiiiiiiiii.iil.i.ii..~. ~~_~ Is enough cement used to circui~g o ; ~ i ii Will cement tie in surface and intermediate or production strings, ~.~ Will cement cover ~all known prodUctive horizons ..~.~..~.~~~ ........ Will surface casing Protect fresh water zones ........ Will. all casing give adequate safety in collapse, tension and burst. Is this well to be kicked off from an existing wellbore ............. ~~. Is old wellbore abandonment procedure included on 10-403 .' ........... ~. Is adequate well bore separation proposed ......................... ~ .... REMARKS Is a diverter system required ............ Are necessary diagrams of diverter Does BOPE have sufficient pressure rating -Test to ~<~O ps,ig [~ . Does the choke manifold comply w/API RP-53 (Feb.78) .................. 25 Additional requirements Additional Remarks: Geology: Engi~: HWK K LCS ~fBEW JKT ~'RAD ~,.~": !/0 rev 1/13/82 ........ INITIAL 'GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process . but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. JUL 2 9 i~82 Alaska Oil & Gas Cons. Commtssioo -- .:~ Anchorage ::: ii' :. ::. ,~ - ':!. ; -:: : ': ** REEL HEADER ~* SERVICE ~AME :SE~VIC DAT£ :821071 7 ORI¢IN : REEL NAME :REEL ID CONTINUATION # :01 PREVIOUS REEL : COMMENTS :REEL COMMENTS ** TAPE HEADER SERVICE NAME :$ERVIC DATE :82/07/ 7 ORIGIN :i070 TAPE NAME :65262 CONTINUATION # :01 PREVIOUS TAPE COMMENTS :TAPE COMMENTS FILE NAME :$ERVIC,O01 SERVICE NAME : VERSION ~ : DATE : MAXIMUM LENGTH : 102~ FILE TYPE : PREVIOUS FILE INFORMATION RECORDS MNEM CONTENTS CN : AT6ANTIC RICHFIELD COMPANY WN : KUPARUK E-13 FN : KUPARUK RANG: TOWN: llN SECT: 16 COUN: NORTH SLOPE STAT: ALASKA CTRY: MNEM CONTENTS ~ RECORD TYPE 047 '~ ~ ~.~-~ ~ .:_~_ ~ .:~ .' 'c~:-'.~ : ~:x: /' ' ' ' ~ ~L~SKA CO~PUTIN'G CENTER "~-' ' COMPANY ATLANTIC RICHFIELD WELL FIELD COUNTY STATE JOB NUMBER AT ACC RUN ~1, DATE LOGG BOTTOM DEPTH TOP DEPTH CASING BIT SIZE TYPE FLUID DENSITY VISCOSITY KUPARUK E-13 KUPARU~ ~ BOROUGH~ < >~ '~-~'<- < .:_ NORTH SLOPE ALASKA ==================================== ~'~. '~i:~]~ ~i~:::;:~ ::,__ : 10707,65262 ED: 28 JUN 82 = 7731 FT. -- 267 ~ FT = ~0 3/4 ~N. = 8.75X IN. = X'C POLY a 10.4 LB/G = 46.0 S PH FLUID LOSS R~ RMF RM AT BHT 10.0 4,6 C] 2.080 ~ 66.0 DF 1,710 ~ 66.0 DF 1.950 ~ 66.0 DF 0,998 ~ 145, DF ** DATA FORMAT RECORD ENTRY BLOCKS TYPE 4 9 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API IO DMPT SFLU ILM DIb lbo DIb SP DID GR NPHI FDN RHOB FDN GR FDN CALI FDN DRHO FDN NRAT FDN NCNL FDN ~CNL FDN ~PI ORDER OHMS 7 0 0 0 OH~ MV 7 GAPI 7 PU 42 G/C3 42 ~API 4~ IN 42 G/C3 42 42 ** DATA ** DEPT 7743.0000 SFLU NCNL SP GR NCNL -50.2187 GR 78.0000 CALI 1360.0000 FCN5 7700.0000 SFLU -53.9375 GR 78,0000 CALl 1360.0000 FCNL DEPT 7600,0000 SFLU SP 56,5000 GR GR ~00.1875 CALI NCNL 2029,0000 FCNL DEPT SP NCNL DEPT SP GR NCNL OEPT SP NCNL DEPT SP GR NCNb DEPT SP GR gCNL DEPT SP NCNL DEPT SP GR NCNL DEPT $P NCNL 7500 0000 SFLU -47:2500 GR 108,0625 CAhI 17tl.0000 FCNL 7400.0000 SFL[} -62 0000 dR 9§~3125 CALl 2302.0000 FCNL 7.]600 0000 SFLU 2:7500 GR 93,1875 CALI 2118,0000 ~CNL 7200.0000 SFLU -58.5000 GR 84,7500 CALl 2290,0000 FCNL 7100 0000 SFbU -57:9687 GR 120,0]125 CALl 1686. 000 FCNL 7000,0000 SFLU '59,6875 GR 129.5000 CALI 1651,0000 FCNL 6900,0000 SFLU '59.7188 GR 155,0000 CALl '999.2500 FCNL 6800.0000 SFLU '55,1875 OR 209,2500 CALI '999,2500 FCNL .0000 ~PHi ~1,,992:2. ,RHOB, -, 2.0.95:7 429.500:0 ~. ? .;;;-,; '; "' :.. ; ,--<" ~. 2. 4~8'1562~2 D'RH~ ~:, :_O.2832'..,NRAT::.~: 9~ ~687 -D~:6 ~:~-'' -~62~'7~]:: ":C~AT'~- 634,0000 ~: :. : ~,:'.;,, : 0~o' 2715 . ~h~ _., . -__ ..-: ~ .2 ,:3.0.08-: I .062~ ~ ~P~I : - ":-~4~26S-8::'2` R"i~0~'~ 48]'75008 D~HO .- 3,5430- .7500 :~- :'~- ' ' ' ' : - 9 o :oooo' - .~06 DAN~ ~ · "-O2:0:~1::8~'''' 'NRAT":- - · ' 2;728:5:'- - ' 869,0000 4. . ooo - 129: 5000, !4'~?"~ ~H~ '~ -:::'~"~¥0~7~":-:-NRAT''' : ..... :"3;:9902' ': ' 4]8,5000 ,99 15 ~, ~ 60- ~'~'~ ' ' '~--g :~'500""" :::'R~OB?'- :' '999':?250'0.:. : - ~ . ~ ~ ~ ~ . , 12, 209. 11 · ::::::::::::::::::::::::::::::::::::::::::::: NCNb DEPT GR NCNb DEPT 5P GR NCNb DEPT NCNb DEPT NCNb DEPT NCNb DEPT SP GR NCNb DEPT NCNb DE~T SP GR NCNL DEPT SP NCNb DEPT GR NCNb 7oo. ooo '63. 375 u.. 131,7500 CALI '999,2500 FCNL 6600.0000 SFLU -58,9375 GR 120.3750 CALl -999,2500 FCNL 6500,0000 SFbU -57i4375 GR 170.6250 CAb! -999.2500 FCNL 6400.0000 8FLU ~57,7500 GR 27.4375 CALX -999,2500 FCNL 6.350.~000 SFbU 2. 00O GR 159,3750 CAI~I -999,2500 FCNL 6200.0000 SFLU -58,656] GR 192.2500 CALl -999,2500 FCNb 6100 ~000 SFbU -60:188 GR 155,0000 CAb! -999,2500 FCNL 6000.0000 8FLU 171. 50 CALX -999,2500 FCN!J 900,0Q00 SFLU -70,2500 GR 20~,7500 CALl 99 .2500 FCNb 5800.0000 SFLU -70 75 GR -999,2500 FCNb 5Z006,0000 SFbU 6 , 0000 GR 152 3750 CALI -999".2500 FCNL 131. 12,31'25 DRHO, . 13'. 10~ 999,2500 ~:.: : -: ~ : .:>..'.::' ~¥- ~:./::..: :::: <~-:: ':: >' . : .. :, : : - . . : .. . 4551 170. 1 t 00'78 -999:2500 ~? .... -:' ---~ ': :' ': "- .... " ..... :~::' ' :: 127,4375.:' -999,2500 14. i 95 3 '999. 2500 2,1543 .Ib~ 10-, 3281 -999; 2500 173'1,8750' i t; l -999,2500 ,SD NCNb DEPT NCNL DEPT NCNb D~PT GR NCNL DEPT NCHL SP GR NCNb DEPT SP NCNb 5600.0000 SFLU =67.5000 GR 96.0000 CALI -99g.2500 FCNb 5500.0000 SFLU ~68.5000 GR 15.5000 CALl -999.2500 FCNL 5400.0000 SFLU -7~ 0000 GR ~0 ~4375 CALl -999.2500 FCN5 5~00.0000 SFLO 72.0000 GR 106.~000 CALl -999. 500 FCNL 5200.0000 SFLU · 75O CAL! -999.2500 FCNb 5100.0000 SFLU -75.7500 GR 100.8750 CALl -999.2500 FCNL 5000.0000 SFLU 10 . 06 CAbI -999.2500 FCNL DEPT 4900.0000 SFLU 5P -83.2500 GR GR 103.3750 CALl NCNL -999.2500 FCNL DEPT GR NCNb DEPT SP GR NCNL DEPT SP oo.oooo ~0 0625 CALl -999.2500 FCNL 8 , 7500 GR 115,6875 CALl 999.2500 FCNL 4600.0000 SFLU -88 0000 OR 11]:6875 CALl -999.2500 . ~ii :::~ :.~.:~..i.:il: ~,.:: .~ :~: :: . .4512 -999 . 2500 ~00.-4375 ~ 1 i ,~6 -99g,2500 ~06 .9~.3203-=. .2500 94. -999,2500 : 0352 I00. 5000 DRH:O RAT:: 108. 0625 ~:P.~I ~:999-,:.250.0~...~-HOB::~ ~.~2<i, ~: '999,2500 103; '999,2500 : :: ' - ';~:'":':-- ~:::-:"<: ::::: ~ ..... ': ...... -999:2500 13 i 078 t DRHO :' ': :'~:~' ~ 999'2500~: :'N"::RA T -:~'vv, z sv u NCNL DEPT SP NCNb DZPT SP NCNb DEP? SP NCNb DEPT SP NCNb DEPT SP GR NCNb DEPT SP GR NCNb DEPT SP NCNL DEPT SP ~R NCNb GR NCNL DEPT SP GR NCNb -99 440 -9 10 -99 9.2500 FCNb 0.0000 SFLU 9.6875 GR 6 9375 CALI 9:2500 FCNL 0.0000 SFLU 0 7500 GR 3:5625 C~[.I 9.2500 FCNL 4300.0000 $FbU -93.2500 GR 69 2500 CAbI 2168~0000 FCNL 4200. -94. 86. 1853. 4100. -96. 80. 2028' 4000. '102, 68, 2050. ~900, 114. 88 1795: 3800, -127, 2268. 3700, -112. 82. 2015, 00. 22. 46. 2302, 0000 SFLU 0000 GR 2500 CALI 0000 FCNL 0000 SFbU 0000 GR 6875 CALI 0000 FCNL 0000 SFLU 0000 GR 0000 CALI 0000 FCNL 0000 $FLU 7500 GR 5625 CALl 0000 FCN5 0000 SFLU 8125 GR 0000 CALI 0000 FCNb 0000 SFLU 8125 GE ]125 CALl 0000 FCNE 0000 SFLU 5625 GR 2500 CALI 0000 FCNb DEPT ~500 0000 SFLU Sp 122:0625 GR -999,2500 ), 8418. 13 1719: ~" . 000'6 -999.2500 12.5469 . 1084,0000 86 2500 489 7 5 0 0 ~, 160:2 8 ; ~ 5 .oooo 5 i 573. O0 O0 9 ~ 2969:- _.__ _ _5,7.0o0o o 0.00 0- 6 58.500 O, I 016 82, 15.3125 ':D.RHG 605. 5000 710,500 17,4375 51; ~8 '~'~HI GR 51.3438 CALl NCNb 2196.0000 FCNL DEPT 3400.0000 SFLU SP -119,5000 GR GR 49.8125 CALI NCNb 1952,0000 FCNL DEPT ~300.0000 SFLU SP 112.4375 GR R 50,~437 CALI ~CNL 1267. 000 FCNL DEPT 3200.0000 SFLU Sp -108.0000 GR GR 84.~875 CALI NCNb 1605, 000 FCNL DEPT 3100.0000 SFLU SP -108 7500 GR GR 92i3750 CAb! NCNb 1633 0000 FCNL DEPT 3000,0000 SFLU SP -1~1.7500 GR R ,7158 CALI GNCNL 2186,0000 FCNh DEPT .29000,0000 SFLU SP 12 ,6875 GR GR 45,5313 CALl NCNb 2008.0000 FCNL DEPT 2800,0000 SFLU SP -108 9375 GR GR 73:0000 CALI NCNb 1635,0000 FCNL DEPT 27070,0000 SFLU SP -11 ,0000 GR GR 64.0625 ~cAL~ NONL 2:148.0000 NL DEPT 2652.5000 SFLU i~ -115,1500 GR 37 · 688 CALI NCNb 1262.0000 FCNL ** FILE TRAILER FILE NAME :SERVIC.00i SERVICE NAME VERSION # ~ DATE : 553.5000:- - - _: : ,: - . - .. :: . : 7500" 84, 465.0000 9 . 41~'898'4~ DRHO- : 0:,.O3.8~?' ,N:RA:T~: -'. -- :~:4-.:2~:4:8'::: 614,5000 ~ 2,75.~8 I~'- ,'~ .1':1~,35i&:.: t~:D:.::::-.:...',- ~-: 1:2, :::. 655;5000: -' MAXIMUM LENGTH : t024 FILE TYPE ,' _. ~:."i ~ ~>:'" > ~'~ ' ' NEXT FILE NAME : ** TAPE TRAILER SERVICE NAME :SERVIC DATE :$2107/ 7 ORIGIN :1070 TAPE NAME :65262 CONTINUATION # :01 NEXT TAPE NAME COMMENTS :TAPE ** REEL TRAILER SERVICE NAME :SERVIC DATE :82/07/ 7 ORIGIN : REEL NAME :REEL ID CONTINUATION # NEXT B~EL NA~E COMMENTS :REEL COMME~T$
