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187-103
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-15 KUPARUK RIV UNIT 3H-15 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 3H-15 50-103-20082-00-00 187-103-0 W SPT 5832 1871030 1500 2791 2793 2792 2792 750 925 925 925 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-15 Inspection Date: Tubing OA Packer Depth 180 2015 1960 1950IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250602191433 BBL Pumped:2 BBL Returned:1.9 Thursday, July 24, 2025 Page 1 of 1 187-103 T38921 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.13 08:21:08 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor '\�f11C2DLt FROM: Brian Bixby Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 8, 2021 SUBJECT: Mechanical Integrity Tests Cono xoPhillips Alaska, Inc. 311-15 KUPARUK RIV UNIT 311-15 See: Inspector Reviewed By: P.L Supm TJW- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 311-15 API Well Number 50-103-20082-00-00 Inspector Name: Brian Bixby Permit Number: 187-103-0 Inspection Date: 6/12021 Insp Num: mi[BDB210602040724 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 311-15 Type Inj I w' TVD 5832 Tubing 2758 2759 2758 2758 ' PTD 1 1871030 "Type Test SPT' Test psi 1500 - IA Sas 1820 - 1780 - 1780 - BBL Pumped: 1 BBL Returned: 1 OA szs 625 625 625 Interval 7 avRTST p/p P Notes: Tuesday, June 8, 2021 Page 1 of I Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Friday, October 30, 2020 7:04 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: KRU 31-1-15 (PTD 187-103) Update: Report of OA Pressure Increase Attachments: KRU 31-1-15 Diagnostic MITIA MITOA 8-31-20 10-426.xlsx; 3H-15.pdf; 31-1-15 90 Day TIO Trend 10-30-20.pdf Chris, KRU injector 3H-15 (PTD 187-103) is at the end of its 60 day monitor (30 days original monitor+ 30 days extension) for an unexplained OA pressure increase. Since the diagnostics done on 8/31/20, the OA and IA pressure changes have all appeared to be thermally induced. ConocoPhillips intends to return the well to normal operations. Please let me know if you have any questions or disagree with the plan. Attached are the schematic, 90 day TIO trend, and 10-426 for the diagnostic MITIA and MITOA performed 8/31/20 at the start of the monitor. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Wednesday, September 30, 2020 12:44 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: CPF3 Prod Engrs <n1223@conocophillips.com>; CPA Wells Supt <n1030@conocophillips.com> Subject: KRU 31-1-15 (PTD 187-103) Update: Report of OA Pressure Increase Chris, KRU injector 31-1-15 (PTD 187-103) is coming to the end of its 30 day monitor for the unexplained OA pressure increase. Passing diagnostic tests including an MIT -IA, MIT -OA and inner casing pack off test which were achieved at the beginning the monitor period. Currently the OA pressure is elevated above the IA pressure & the IA pressure is slowly trending up, but the OA pressure appears to have stabilized. CPAI intends to conduct an additional 30 day monitor as well as additional pressure manipulations to determine the cause of the increase. Depending on the results of the diagnostics and monitor, the proper paperwork for continued injection or repair will be submitted. Attached is a the 90 day TIO plot. Please let me know if you have any questions or disagree with the plan. Regards, Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Wednesday, September 30, 2020 12:44 PM To: Wallace, Chris D (CED) Cc: CPF3 Prod Engrs; CPA Wells Supt Subject: KRU 31-1-15 (PTD 187-103) Update: Report of OA Pressure Increase Attachments: 3H-15 90 day TIO plot 9-30-20.pdf Chris, KRU injector 3H-15 (PTD 187-103) is coming to the end of its 30 day monitor for the unexplained OA pressure increase. Passing diagnostic tests including an MIT -IA, MIT -OA and inner casing pack off test which were achieved at the beginning the monitor period. Currently the OA pressure is elevated above the IA pressure & the IA pressure is slowly trending up, but the OA pressure appears to have stabilized. CPAI intends to conduct an additional 30 day monitor as well as additional pressure manipulations to determine the cause of the increase. Depending on the results of the diagnostics and monitor, the proper paperwork for continued injection or repair will be submitted. Attached is a the 90 day TIO plot. Please let me know if you have any questions or disagree with the plan. Regards, Matt Miller Filling in for Stephanie Pilch/Sara Carlisle Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 354-5520 WELLS TEAM G -o Nips Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Sunday, August 30, 2020 1:53 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 31-1-15 (PTD 187-103) Report of OA Pressure Increase Attachments: 31-1-15.pdf, 3H-15 90 Day TIO Plot 8-30-20.pdf, MIT KRU 3H PAD 06-4-17.xlsx Chris, KRU injector 3H-15 (PTD 187-103) is exhibiting an unexplained OA pressure increase. CPAI intends to perform diagnostics to determine the cause of the increase. (The most recent MITIA was the four year AOGCC-witnessed MITIA on 6/4/17.) Following diagnostics, the well will be placed on a 30 day monitor period. Depending on the results of the diagnostics and monitor, the proper paperwork for continued injection or repair will be submitted. Attached are the schematic, 90 day TIO plot, and 10-426 from the most recent MITIA. Please let me know if you have any questions or disagree with the plan. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 Annular Communication Surveillance Well Name: 3H-15 Start Date: 1 -Aug -2020 Days: 90 End Date: 30 -Oct -2020 PTD (77/o3o 7000 3000 Injection Rate Summary Pressure Summary 6000 O 150 140 2500 LL V � $DDD 130 O a 4000 2000 m 120 m ii 3000 v 110 v z v 1500 0 100 2000 v M a c 90 n 1000 1000 w 0 80 Soo 0 0 0 70 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N N N N N N N N N 60 N N N N N N N N N N 0 N N N N N N N N N 00 OU J J 00 J 00 J 00 04 J 00 J 00 00 tl0 e0 6 Q Q Q Q Q 6 6 Q Q j'iii V V 50 t) t 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o O O o 0 'I 4 1-� O N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N 3>>> M 3>>>>> ti N N N N v v a v v a v v a v u u. —DGI is it ti Y, ti a a a a a a a a a a a K, Up IQ �� �T T�� o 0 0 0 0 0 0 0 0 0 0 0 "I V r O M l0 Ol N IA W 'i M l0 O1 N Ill CO 'i O h O M l0 OI N L!1 M ei 4 I� O rl H H N N N N M •'I ♦i ti N N N M rl ei e4 N N N M —WHP —IAP —OAP —WHT 7000 Injection Rate Summary 6000 O LL V � $DDD O a 4000 m 3000 z 0 2000 v c 1000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N 00 OU J J 00 J 00 J 00 04 J 00 J 00 00 tl0 e0 6 Q Q Q Q Q 6 6 Q Q j'iii V V V t) t U U ¢ ¢ ¢ ¢ ¢ ¢ ¢ J ¢ J ¢ J ¢ J W W UI W y y y d UI ¢ vI M M v+ In H H H In N In O O 0000000 'I 4 1-� O M 6 01 N N M ei A l0 O1 N t!1 N 'i V N O A 6 O1 N N W N Q I� rl e'I ei M N N N M "'I e'I e'1 N N N M N ti N N N N —DGI MGI —PWI —SWI —BLPD Annular Communication Surveillance 3H-15 90 -Day Bleed History WE I ID 31-1-15 31-1-15 31-1-15 31-1-15 31-1-15 31-1-15 31-1-15 9/9/20 9/9/20 8/31/20 8/31/20 8/16/20 8/16/20 8/9/20 300 375 837 719 750 200 950 200 500 360 500 200 500 400 e. 100 -125 477_ 219 550 -300 550 CASING INNER OUTER INNER OUTER OUTER OUTER OUTER SERVICE PWI PWI PWI PWI PWI PWI PWI • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 15,2017 TO: Jim Regg J� I 7 P.I.Supervisor ' \et� ` / SUBJECT: Mechanical Integrity Tests 1 CONOCOPHILLIPS ALASKA INC 3H-15 FROM: Chuck Scheve KUPARUK RIV UNIT 3H-15 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry I NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3H-15API Well Number 50-103-20082-00-00 Inspector Name: Chuck Scheve Permit Number: 187-103-0 Inspection Date: 6/4/2017 Insp Num: mitCS170605170939 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3H-15 - Type Inj W /TVD 5832 • Tubing 2410 2412 - 2412 e 2412 PTD I 1871030 Type TestLsPT Test psi 1500 IA 740 1800 - 1750 - 1750 BBL Pumped: ] I.I , BBL Returned: I - OA 550 650 • 650 - 650 -J Interval 4YRTST P/F P Notes: SCANNED AUG 3 0201-7, Thursday,June 15,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 17,2013 TO: Jim Regg P.I.Supervisor � -I zr(I 3 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-15 FROM: John Crisp KUPARUK RIV UNIT 3H-15 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv;f2'— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3H-15 API Well Number 50-103-20082-00-00 Inspector Name: John Crisp Permit Number: 187-103-0 Inspection Date: 6/9/2013 Insp Num: mitJCr130610084505 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 3H-I5 Type Inj G jTVD 5832 - IA 1380 2220 - 2200 , 2180 . i 2180 PTD; 1871030 Type Test'SPT Test psi 1500 - OA 400 1- 500 • 500 500 500 Interval - P/F P 1 Tubing 2969 2971 2976 2977 2974 4YRTST � 1- Notes: I bbl pumped for test. SCANNED FEB 2 0 2014 Monday,June 17,2013 Page 1 of 1 . ~ COI'10 ~~~ coPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 ~ ~n. n ~ ~p~ ~,~ - ~, ~ _ ! : ~.. . `: ~.~ . _ u ~~ Mr. Tom Maunder ~ ~ 3 Alaska Oil & Gas Commission ~ ~ " 333 West 7~' Avenue, Suite 100 ~ Anchorage, AK 99501 ~ ~ _- ~ ~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRi~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treahnents took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30~' 2009 and the corrosion inhibitor/sealant was pumped August 8~', 9th and 10~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~~~~ MJ Lov land ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Da~ 08/11/09 ~r± ou ov o~n o.,,~ ell IVame PI # TD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date ~~ Corrosion inhibitor ~ Corrosion inhibitor/ sealant date bbls al 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" Na 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" n/a 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'5" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 50103200790000 1870790 17" n/a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" n/a 17" n/a 5.52 8/8/2009 3H-106 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" - Na 3.4 8/9l2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9/2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30/2009 2.25 8/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 21" 7/30/2009 8.5 8/9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF n/a 9" n/a 2.12 8/9/2009 3H-28A 50103202360100 1960370 SF n/a 18" n/a 5.1 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" n/a 1.27 8/9/2009 3K-102 50029233786000 2071650 n/a n/a 5" n/a 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30/2009 4.25 8/8/2009 3Q-02 50029216880000 1870040 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.50 16" 7/30/2009 4.25 8/8/2009 3Q-07 50029216820000 1861940 6" n/a 6" n/a 1.7 8/9/2009 3Q-12 50029216770000 1861890 7" n/a 7" n/a 2.97 8/8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30/2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'5" 4.50 20" 7/30/2009 9.35 8/8l2009 3Q-16 50029216670000 1861790 46' S.25 30" 7/30/2009 8.5 8/8J2009 ~ LJ MEMORANDUM To: Jim Regg ~' y' 7(2210 ( P.I. Supervisor ~ FROM: Chuck Scheve Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-15 KUPARLTK RIV LTNIT 3H-15 Srr. Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: KUPARUK RIV iJNIT 3H-15 API Well Number: 50-103-20082-00-00 Inspector Name: Chuck Scheve Insp Num: mitCSO9o6o8150927 Permit Number: 187-103-0 ~ Inspection Date: 6/7/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ I 3H-15 Type Inj. W TVD 5832 ' jL~ 540 2120 2060 2060 - P.T.D ls~~o3o ITypeTest sPT, Test psi ~soo _ -----~ -~ -- pA o - 0 0 - -- o - Interval a~TST ~ p~ r ,,, Tubing >>so liso iiso iiso NOtes: Pretest pressures observed and found stable. ~- ~; ~~,7ZS~s~"'~~ ~'~, 'u~~ J~;~~l,~~ Wednesday, June 10, 2009 Page 1 of 1 N0.4947 ~~t Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # P,<,r>>. C °f~ " r ~ 431'._ t~'~ ` ~ ~L~tt l~ y ~..,ssi ~'~ 6;.~i~:y.71 '~' Log Description U~'~' Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnkein 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/29/08 3S-OSC 12066554 MEM PRODUCTION PROFILE - '~' 10/14/08 1 1 1C-26 11978487 SBHP SURVEY t -b r 10/15/08 1 1 1C-119 11978488 INJECTION PROFILE ~ 10!16/08 1 1 3H-15 iC-121 12080445 11978490 INJECTION PROFILE - '3 C./ INJECTION PROFILE 10/16/08 10/17/08 1 1 1 1 3H-18 12080446 iNJECTION PROFILE ~ - p 10/17/08 1 1 iJ-159 12097431 PRODUCTION PROFILE ~ y" 10/13/08 1 1 1 F-10 12080453 INJECTION PROFILE 10/27/08 1 1 1C-121 11978490 INJECTION PROFILE 10/17/pg 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. C MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~¡. / I /. """'A (. 'r, i (//.'1.; ~':;:';" tr.,:..lcV , Ptt DATE: Wednesday, June 14,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-15 KUPARUK RIV UNIT m-15 Src: Inspector , \ Q.:~" ,<tÎ FROM: John Crisp Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~TI3 P- Comm Well Name: KUPARUK RIV UNIT 3H-15 Insp Num: mitJCr060613124158 Rei Insp Num API Well Number 50-103-20082-00-00 Permit Number: 187-103-0 Inspector Name: John Crisp Inspection Date: 6/10/2006 Packer Depth Pretest Initial Well i 3H-15 Type Inj. i G I TVD --r 5832 -rIXT'--15õQ'r-2ï6ö-'- p.i.1l871030 --TypeTest-¡ SPT I-Test p~i I 1500 I OA i-~-I 650 ____1..__ .. .---...--- I -4--.----¡.------... ..l!!.t~!val__ 4YRTS2-_ p~_ .._~___ TubingJ_~~_~_..~_?030 Notes 2 bb1's pumped for test. 15 Min. 30 Min. 45 Min. 60 Min. ..-í..·------..---r-------..-¡-----··..--- 2130 2120' ! --- i ---------1-- 650 : 650 I ---\-------------..-.:--------.- 3030 ¡ 3030 I ¡ ____....-L-____--L ...._....._ .. 5CANNEtJ: JUN 2 Ðì1 lGUt) Wednesday, June 14,2006 Page 1 of 1 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 We'llI 3H-15 P.T.D.I 1871030 Notes: ,, We"I 3H-17! P.T.D.I 1870990 Notes: ,' We,I 3H-18 ! ,, P.T.D:I 1880090 Notes: ' We, i 3H-22i P.T.D.I 1880110 Notes: '.vve'J 3H-24 J P.T.D.I 1960150 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. J Type,nj.J G'I T.V.D. J 5832 J fubing'j 3700J 370d J '37d0 J 3700 J lntervalJ 4 Typetestj _P .jT. eSt'psij 1458 J Casingj "2275I 28751,285oI :;8501 P/F I'P_ Typelnj. J" G J T.V.D.J 5927 JTubingJ 1450 J :1440'J 1465 J '1465 Jln'tervalJ 4 ' Type testJ P , J~'estpsiJ 1,482 JCa~ingJ 200 ,J 2280 "J 2270J 2260 J. pIF I P Type~nj.J S J'T.V.D. J 5831 JTubingJ 1400 J 1400'j 1430 J 1425 J~nter~a~J 4 TypetestJ. P . 'JTest psi J '1458 '1, glcasin1875 J2320 '1,,, 123202320 J PIFI_P Typelnj. J S J'T.v.D. I '1TubingJ 1500'J 1490 J 1490 J' 1460 J,nte~alJ 4 :rypetestJ P J.T. estpsiJ 1488 JCasingJ' 1100.J '2180..I.'.".21501 21~0J PIF I P Type lnj. J sJ T.V.D. III S0"! j,nterva, J TypetestJ 'P JTestpsiJ 14B5 j CasingJ 1,100 'J 22'75 j 2260J 2250J P/F I P-- Type INJ. Fluid Codes F = FRESH WATER INJ. (3 = GAS INJ. S = SALT WATER IN J, 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 dudng Workover O= Other (describe in notes) M.I.T.'s performed: _5 Attachments: none Number of Failures: 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 WI to WAG Injection 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1129' FNL, 4997' FEL, Sec. 12, T12N, R8E, UM 5. Type of Well: Development __ Exploratory _ Stratig raph ic __ Service__X (asp's 498655, 6000526) 6. Datum elevation (DF or KB feet) RKB 76 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3H-15 At top of productive interval 1246' FSL, 1331' FWL, Sec. 12, T12N, R8E, UM At effectiVe depth At total depth 3969' FNL, 4198' FEL, Sec. 2, T12N, R8E, UM (asp's 494174, 6002967) 9. Permit number / approval number 187-103 / 10. APl number 50-103-20082 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 115' SUR. CASING 3543' PROD. CASING 8366' 8460 feet 6223 feet Plugs (measured) feet Junk (measured) feet Size Cemented 16" 220 sx AS I 9-5/8" 1340 sxAS III & 325 sx Class G w 7" 300 sx Class G & 175 sxAS I Measured Depth 115' 3619' 8442' True vertical Depth 115' 2960' 6210' Perforation depth: measured 8072-8110; 8116-8148; 8164-8174; 8174-8184; 8184-8204 true vertical 5935-5963; 5967-5990; 6002-6010; 6010-6017; 6017-6032 Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tbg @ 8002' MD. Packers & SSSV (type & measured depth) BAKER 'FHL' @ 7930' MD. CAMCO 'TRDP-1A-SSA' @ 1782' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Avera.qe Production or Injection Data Gas-Mcf Water-Bbl 2659 9923 Casing Pressure 660 Tubing Pressure 2352 660 2934 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service _X WAG Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed' JeffA. St~encer'~~ ~-~' (~~'~J~'~'~r'¢~'~ ~ TItle Pr°ductl°n Engineering Supervis°r' ' ' Questions? Call Jeff Spencer 659-7226 Date Prepared by Robert Christensen 659- 7535 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 3H-15 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary ::::: ::.~.:i~,ii19i25/01 I:c~m~enced:EOR!njectiOn:~: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown_ Stimulate_ Plugging _ Perforate X Pull tubing _ Alter casing _ Repair well_ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development ~ 76' RKB 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service X. Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1132' FNL, 281' FWL, Sec 12, T12N, R8E, UM 3H-15 At top of productive interval: 9. Permit number/ap rl~_9_val number;_ 1246' FSL, 1331' FWL, Sec 2, T12N, R8E, UM ~ ~:)'-7-"" ~/~'~ At effective depth: 10. APl number: ...... 1291' FSL, 1148' FWL, Sec 2, T12N, R8E, UM 50-103-20082-00 At total depth: 11. Field/Pool: 1308' FSL, 1079' FWL, Sec 2, T12N, R8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 8460 feet Plugs (measured) None true vertical 6223 feet Effective Deptl measured 8353 feet Junk(measured) None true vertical 6143 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 220 Sx AS I 115' 115' Surface 3584' 9-5/8" 1340 Sx AS III & 3619' 2970' 325 Sx Class G w/top job of AS I to 80' Production 8407' 7" 300 Sx Class G & 8442 6214' 175 Sx AS I Liner Perforation Depth measured 8072'-8110'; 8116'-8148'; 8164'-8174', 8174'-8184', 8184'-8204' true vertical 5935'-5963'; 5967'-5991'; 6002'-6010'; 6010'-6017'; 6017'-6032' O~IGINAL Tubing (size, grade, ond meosured depth) 3.5", 9.3 Ib/ft, J-55 @ 8002' Packers and SSSV (type and measured depth)P,E£EtVED Packer: Baker FHL @ 7930'; SSSV: Camco TRDP-1A-SSA @ 1782' OCT 13. Stimulation or cement squeeze summary Perforate "A" sand on 11/15/98. AJaska 0ii & Gas Cons. Commission Intervals treated (measured) Anchorage 8164'-8184' Treatment description including volumes used and final pressure Perforated using 2-1/2" HC guns w/DP charges @ 4spt, fp was 1900 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 7136 520 2700 Subsequent to operation 7318 590 2703 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~X Oil Gas Suspended _ Service _j~_ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~15/;~~ Title'. Production Engineering Supervisor Date Form 10-404 Re~ ,8 SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT ~ ,YELL SERVICE REPORT · · K1(3H-15(W4-6)) WELL JOB'SCOPE JOB NUMBER 3H-15 PERFORATE, PERF SUPPORT 1111980853.4 DATE DAILY WORK UNIT NUMBER 11/15/98 PERFORATE A SAND 2158 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSO'N SUPERVISOR 1 (~. Yes O NoI (~ Yes (~ No ROJAS LIGENZA ESTI MATE KAWWRK 230DS36HL $7,871 $9,405 Initial Tbg Press2100 PSI Final Tbg Press1 Ann 0 ,na, ,..e. ^.n a0 DAILY SUMMARY PERFORATE A SANDS FROM 8164' TO 8184' W 20' X 2-1/2' HC, DP, 4 SPF 180 DEG +/- 90 DEG PHASE. [Perf] TIME 02:30 04:00 05:30 05:45 06:45 07:20 07:30 08:30 LOG ENTRY MIRU SWS. TGSM. LATE START. DON'T GET IN A HURRY. PT LUBE / BOPS. RAM HEAD SEAL LEAKED. DRAIN LUBRICATOR, INSPECT O RINGS, REPAIR THREADS ON RAM HEAD. PT LUBE / BOPS TO 3,000 PSI. RIH W 20' X 2-1/2' HC, DP, 4 SPF 180 DEG +/- 90 DEG PHASE. 7' 11" FROM TOP SHOT TO CCL. TIE IN TO SWS CET DATED 2/17/88. LOCATE AT 8156' W / CCL 8' ABOVE TOP, SHOT. INDICATION ALL SHOTS FIRED. LOG OFF POH ALL SHOT FIRED.-RDMO SWS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $42.00 , APO $0.00 $600.00 HALLIBURTON $0.00 $892.00 SCHLUMBERGER $7,871.25 $7,871.25 3::OTAL FIELD ESTIMATE $7,871.25 $9,~'5.:~5 1. Type of Request: 2. Name of Operator STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown w Stimulate Plugging Pull tubing Alter casing Repair well 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X W l ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 2, T12N, R8E, UM 2, T12N, R8E, UM 2, T12N, R8E, UM 4. Location of well at surface 1132' FSL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1246' FSL, 1331' FWL, Sec. At effective depth 1291' FSL, 1148' FWL, Sec. At total depth 1308' FSL, 1079' FWL, Sec. Present well condition summary Total Depth: measured 8 4 6 0' feet true vertical 6223' feet Effective depth: measured 8353' feet true vertical 6143' feet Casing Length Size Structural Conductor 80' 16" Surface 3584' 9 5/8" Intermediate Production 8 4 0 7' Liner Perforation depth: true vertical 12. Perforate Convert well to Pull tubing WI Other X Plugs (measured) Junk (measured) Cemented 210 Sx AS I 1340 Sx AS III & 6. Datum elevation (DF or KB) RKB 7. Unit or Property name Kuparuk River Unit 70 feet 8. Well number 3H-15 9.. Permit number/approval number I 8-813 I lo.~PI number I 5o-103-20082 Ill. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth ,, 115' 115' 3619' 2960' 325 Sx Class G Top job w/AS 1 to 80' (approx) 300 Sx Class "G" 8 4 4 2' 6 21 0' measured 8116'-8148', 8072'-8110' @ 12 SPF, 8174'-8204' @ 4 SPF 5966'-5990', 5934'-5962' @ 12 SPF, 6009'-6031' @ 4 SPF Tubing (size, grade, and measured depth) 3 1/2", J-55, tbg w/tail @ 8002' Packers and SSSV (type and measured depth) FHL pkr @ 7930' & TRDP-1A-SSA SSSV @ 1782' 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 including volumes used and final pressure 14. Prior to well operation Subsequent to operation 15. Attachments Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl 3900 ' 5000 0 0 0 -8200 Copies of Logs and Surveys run 16. Status of well classification as: Casing Pressure 1000 psi 520 psi Tubing Pressure 200 psi 1900 psi Daily Report of Well Operations X Oil Gas Suspended Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Re~ 06/15/88 SUBMIT IN DUPLICATE Alaska, In~ {) S._,bsidiary of Atlantic Richfield Comp, WELL SERVICE REPOR WELL CONTRACTOR ~?C - REMARKS iPBDT /.x~ IFIELD - DISTRICT. STATE OPERATION AT REPORT TIME JDAYS/ [DATE ~-~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. ' TOTAL CAMCO ,,,?2O OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision Pre-Job Safety Meeting TOTAL FIELD ESTIMATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOCI 1. Status of Well Classification of Service Well OIL~ GAS ~ SUSPENDED ~ ABANDONED ~ SERVICE [] Name of Operator Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1132' FNL, 281' FWL, Sec.12 T12N, R8E, UM At Top Producing Interval 1246' FSL, 1331' FWL, Sec.2, T12N, RSE, UM At Total Depth 1308' FSL, 1079' FWL, Sec.2, T12N, RSE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 76 ' 7. Permit Number 87-1,~9 8. APl Number 5O- 1 03-20082 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3H-15 11. Fieldand Pool Kuparuk River Field 12. Date Spudded 10/11~8~ ~ ~ "':17. Total Depth (MD+TVD) 8460 'MD/6223 'TVD 6. Lease Designation and Serial No. Kuparuk River Oil Pool ADL 25531 ALK 2657 13. DateT.D. Reached I 14. Date Comp., Susp. orAband. 115. Water Depth, ifoffshore I16. No. of Completions I N/A feet MSL [ 1 10/17/87 [ 07/16/88w I Depth where SSSV set i 21. Thickness of Permafrost 18.Plug Back Depth (MD+TVD)I 19. Directional Survey 20. 8353'MD/G143'TV[~ YES [Ix NO [] 1782' feet MD I 1600' (approx.) 22. Type Electric or Other Logs Run D I L/GR/SP/SFL, FDC/CNL,CAL~GR ~CET ~GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM 16" G2.5# H-40 g,,r'f !!5' 9-5/8" ~G _0~ J-q5 Surf 36! 9 ' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 80727-8110~MD/59357-59627TVD w/2 spf~ 60° phasing 81167-81487MD/59677-5990~TVD w/12 spf~.60° phasing 8174~-8204~MD/60097-6031~TVD w/4 spf, 135° phasing 27. N/A HOLESIZE CEMENTING RECORD AMOUNT PULLED !2-!/4" 8-!/~'t 2!0 sx AS ! !340 sx AS III & 325 Top job :.:/AS I to 80 300 sx Class G & !75 sx Class G sx AS ! 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 8002 ' 7930 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) [ AMOUNT 8l KIND OF MATERIAL USED I jAN h'0DUCTION TEST Date First Production Date of Test Hours Tested Flow Tubing Casing Pressure Press. 28. I PR O DUCT I~ ~='[~'6'¢~YB B L GAS-MCF ICALCULATED ~IO,L-BBL GAS-MCF 124-HOUR RATE "~ / CORE DATA WATER-BBL WATE R-B B L CHOKE SIZE IGAS'OILRATIO OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None * NOTE: Drilled RR 10/18/87. Perforated well and ran tubing 5/18/88. Fractured well 7/16/88. Added perforations 9/23/88. Form 10-407 Rev. 7-1-80 WC5/066 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS NAME MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Top Kup~ruk C Base Kuparuk C Top Kuparuk A Base Kuparuk A 8072' 8130' 8130' 8226' 5934' 5977' 5977' 6048' 31. LIST OF ATTACHMENTS Addendum (dated 10/26/88), Stimulation Summary (dated 7/16/88) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 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 ADDENDUM WELL: 6/12/88 9/23/88 10/25/88 3H-15 RU Hot Oil. Pmp 20 bbls diesel + 5% Musol. Displ diesel/Musol thru "A" sands perfs w/75 bbls diesel @ 1.5 BPM, 2100 psi. Secure well. RU SOS. Perf well f/8116'-8148' @ 6 SPF. Flow well. SI. RIH, perf 8116'-8148' @ 6 SPF. Flow well. SI. RIH, perf well f/8072'-8110' @ 6 spf. Flow well. SI. RIH, perf well f/8072'-8110' @ 6 spf. Flow well. SI. Turn well over to Production. Arctic Pak well w/175 sx AS I. A]as~ Oil .& Gas tons. t3ommissi~:~ ? Drilling Supervis6r Date KUPARUK STIMULATION SUMMARY U/ELL: TUB 4) PERFS: MD 4) PERFS: HOLE ANGLE 4).PERFS: DATE: CONTRACTOR: ARCO REP: SAND PERF INTERVAL DENSITV PHASING ACTUAL VOLUME RATE PRESSURE . /._.__. ! / / , EFF. PnD: ~ EFF. SLURRY: ~"/~ DESIGN ¢~,i& PROP. PROP. ANN. VOLUME M~SH ~ ~ PR[SS. STG/£UM , i , EFF. PROP: //700 WHTPR: ~t0 / ~J A FRIIC ORRO: 0.-~.~/ ISIP: 22~ / ~/~ TBS.FRIC: ~(~o P~I PERF FRIC: 5o0 / LOG INTERUilL: FLUID TEMP: FLU I O U I SC: 5,~ · ~,.-., - s ,.,,,..-, LEAK OFF~ 5 MIN..~{~0 I0 MIN. 2c'/2-0 15 MIN. (~ I;bs ,JoB /oo % SUB-SURFACE DIRECTIONAL SURVEY ~'~UIDANCE ~ONTINUOUS n~OOL Company ARCO ALASKA~ INC. , .... Well Name ,3, H-15 I1!32' FNL, 281' FWL, SEC 12, ,,,, T12N, R8E, UM} , Field/Location KUPARU,K,,, NORTH SLOPE , ,, ALASKA, Job Reference No. Date 72609 21-FEB-88 ~ Computed By; SARBER KOHRING ~ SCHLUMBERGER * GCT DIRECTIONAL SURVEY CUSTOMER CISTING FOR ARCO ALASKA, INC. 3H-15 KUPARUK NORTH SLOPE,ALASKA SURVEY DATE: 20-FE.5-88 ENGINEER: SARBER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 59 OEG 5~ MIN WEST 02-MAR-88 COMPUTATION DAT== ARCO ALASKA, INC. 3H-15 KUPARUK NORTH SLOPE,ALASKA [NTERPDLATED VALUES FOR EVEN 100 FEET TRUE SUB-SEa MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH COURSE VERTICAL DOG DEVIATION AZIMUTH SECTION SEV DEG MIN DOG M'IN FEET 9EG 0.00 0.00 -76.00 100.00 100.00 24.00 200.00 200.00 124.00 300.00 300.00 224.00 400.00 400.00 324.00 500.00 499.99 423.99 600.00 599.99 523.99 700.00 699.99 623.99 800.00 799.99 723.99 900.00 899.99 ~23.99 0 0 N 0 0 E O.DO 0 8 S 7 36 E -0.12 0 8 S 64 59 E -0.31 0 12 N 71 39 E -0.56 0 22 N 49 9 E -0.79 0 19 N 44 56 E -0.97 0 15 N 66 2 E -1.15 0 15 N 58 33 E -1.45 0 16 N 68 2 E -1.76 0 15 N 64 43 E -2.06 1000.00 999.99 923.99 1100.00 1099.92 1023.92 1300.00 1199.2,6 1123.26 1300.00 1297.48 1221.48 1400.00 1394.11 1318.11 1500.00 1498.42 1412.42 1600.00 1579.79 1503.79 1700.00 1667.60 1591.60 1800.00 1751.61 3675.61 1900.00 1831.82 1755.82 0 26 N 6 21 W -2.04 4 7 N 47 54 W 0.99 8 37 N 52 7 W 12.06 12 45 N 43 29 W 30.22 16 59 N 42 6 W 54.66 21 44 N 41 27 W 86.15 26 10 N 37 55 W 124.23 30 51 N 37 48 W 168.37 34 45 N 40 57 W 218.97 38 19 N 46 22 W 276.21 2000.00 1908.52 1832.52 2100.00 1980.62 1904.62 2200.00 2048.68 1972.68 2300.00 2116.67 2040.57 2400.00 2183.18 2107.18 2500.00 2248.25 2172.25 2600.00 2313.78 2237.78 2700.00 2379.44 2303.~4 2800.00 2444.53 2368.53 2900.00 2508.73 2432.73 41 48 N 50 13 W 339.11 45 59 N 49 20 W 407.25 47 25 N 50 36 W 479.43 47 13 N 54 13 W 552.09 49 20 N 57 59 W 626.54 49 9 N 50 10 W 702.47 48 59 N 59 30 W 778.01 49 1 N 58 59 W 853.42 49 47 N 58 4~ W 929.33 50 12 N 58 33 W 1005.97 3000.00 2572.69 2496.69 50 21 3100.00 2636.17 2560.17 50 53 3200.00 2698.85 2622.85 51 27 3300 O0 >2760.B8 2584.88 51 50 3400.' O0 ~' 2822.50 2746.50 51 49 3500.00~ 2885.23 2809.23 50 54 700 00:30~0 2934.30 51 44 3 2 2996.37 51 56 900 C~ 3 3 3057.42 52 19 N 58 22 W 1082.82 N 58 18 W 1160.05 N 58 14 W 1237.94 N 58 2 W 1316.33 N 57 56 W 1395.04 N 57 40 W 1472.87 N 57 43 W 1550.64 N 58 4 W 1628.82 N 58 22 W 1707.42 N 58 25 W 1786.36 KELL't DATE BUSHING OF SURVEY: ELEVATION: ENGINEER: OF MEASURED DEPTH L 5G R EC'TANGUL ~R ERITY NORTH/SOUTH /100 FEET 0.00 0.00 N 0.00 0.29 S 0.00 0.47 S 0.25 0.49 S 0.00 0.18 S 0.24 0.28 N 0.00 0.56 N 0.00 0.74 N 0.00 0.92 N 0.00 1.10 N 1.13 1.51 N 5.60 4.00 N 4.77 10.84 N 4.27 23.58 fl 4.42 42.47 N 4.59 67.14 N 4.99 98.31 N 4.60 136.19 N 5.20 178.32 N 4~62 221.48 N P~GE 1 ZO-F: =8-8.8 76.00 FT SARBER COORDINATES HORIZ. DEPARTURE EAST/WEST DIST. AZIMUTH FEET FEET 9EG MIN 0.00 E 0.00 N 0 0 E 0.03 W 0.29 S 6 3 W 0.08 E 0.47 S 10 6 E 0.36 E 0.61 S 36 6 E 0.81 E 0.83 S 77 9 E 1.29 E 1.32 N 77 44 E 1.69 E 1.78 N ?1 38 E 2.11 E 2.24 N 70 34 E 2.56 E 2.72 N 70 15 E 3.01 E 3.21 N 69 53 E 4.27 263.78 N 4.59 308.55 N 1.00 355.52 N 2.20 400.37 N 4.07 442.29 N 0.74 480.79 )4 0.49 518.78 N 0.56 557.35 N 0.72 596.63 N 0.21 636.52 N 0.49 676.73 N 0.47 717-30 N 0.26 758.26 N 0.21 799.65 N 1.61 841.39 N 0.45 882.88 N 0.63 924.51 N 0.68 966.05 N 0.34 I007.45 N 0.27 1048.86 N 3.23 E 3.57 N 64 57 E 1.1T E 4.17 N 16 14 E 7.66 W 13.28 N 35 14 W 21.28 W 31.76 N 42 3 W 38.58 W 57.38 N 42 15 W 60.70 W 90.51 N 42 6 W 86.66 W 131.05 N 41 23 W 115.74 W 178.73 N 40 Z1 W 149.84 W 232.92 N 40 Z W 191.01 W 292.47 N 40 46 W 239.21 W 356.09 N 4Z 12 W 292.04 W 424.84 N 4.3 25 W 348.26 W 497.68 N 44 24 W 406.26 W 570.39 N 45 25 W 458.03 W 643.95 N 46 37 W 533.46 W 718.15 N 47 58 W 598.75 W 792.24 N 49 5 W 663.57 W 866.58 N 49 58 W 728.54 W 941.67 N 50 41 W 794.01 W 1017.65 N 51 16 W 859.53 W 1093.95 N 51 47 W 925.28 W 1170.76 N 52 12 W 991.57 W 1248.26 N 5Z 35 W 1058.19 W 1326.36 N 52 55 W 1124.98 W 1404.82 N 53 12 W 1190.89 W 1482.46 N 53 26 W 1256.66 W i560.10 N 53 39 W 1322.94 W 1638.12 N 53 51 W 1389.80 W 1716.54 N 54 3 W 1457.04 W 1795.29 N 54 15 W .> COMPUTATION DATE: 02-MAR-B8 PAGE 2 ARCO ALASKA, INC. 3H-15 KUPARUK NORTH SLOPE,~LASK,~ DATE OF SURVEY: 20-FEB-88 KELLY 6USHING ELEVATION: 76.00 FT ENGINEER: SARBER INTERPOLATEO VALUES FOR EVEN 100 FEET OF MEASURED OEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 31'94.60 3118.60 52 13 4100.00 3255.91 3179.91 51 49 4200.00 3319.11 3243.11 49 28 4300.00 3384.29 3308.29 49 20 4400.00 3449.28 3373.28 49 33 4500.00 3514.09 3438.09 49 39 4600.00 3578.78 3502.78 49 43 4700.00 3643.40 3567..40 49 44 4800.00 3707.99 3631.99 49 46 4900.00 3772.63 3696.63 49 42 N 58 25 W 1865.44 N 58 56 W 1944.41 N 59 13 W 2021.89 N 59 7 W 2097.72 N 59 B W 2173.72 N 59 6 W 2249.97 N 59 10 W 2326.I2 N 59 25 W 2402.43 N 59 37 W 2478.77 N 59 34 W 2555.06 0.29 1.67 1.56 0.32 0.16 0.13 0.17 0.21 0.34 0.19 1090.22 N 1524.48 W 1874.20 N 54 25 W 1131.39 N 15'91.90 W 1952.99 N 54 35 W 1170.99 N 1658.49 ~ 2030.22 N 54 46 W 1209.94 N 1723.57 W 2105.86 N 54 55 W 1248.91 N 1788.82 W 2181.66 N 55 4 W 1288.00 N 1854.19 '~ 2257.64 N 55 12 W 1327.11 N 1919.64 W 2333.7Z N 55 ~0 W N 1985.26 W 2409.86 N 55 28 V '} 1366.05 1404.79 N Z051.06 W 2486.02 N 55 35 W - 1443.40 N Zl16.87 W 256Z.14 N 55 42 W 5000.00 3837.42 3761.42 49 31 5100.00 3902.49 3H26.49 49 15 5200.00 3967.71 3891.71 49 15 5300.00 4033.02 3957.02 49 7 5400.00 4098.60 402~.60 49 5 5500.00 4163.84 4087.84 49 24 5600.00 4229.69 4'153.69 48 4 5700.00 4296.56 4.220.56 48 3 5800.00 4363.3'9 4287.39 47 58 5900.00 4430.36 4354.36 48 1 N 59 37 W 2631.23 N 59 33 W 2707.17 N 59 25 W 2782.97 N 59.17 W 2858.69 N 59 48 W 2934.18 N 60 45 W 3009.97 N 62 28 W 3085.19 N 62 38 W 3159.47 N 62 32 W 3233.78 N 52 38 W 3307.96 0.12 0.45 0.3.3 0.54 0.81 0.93 1.12 0.44 0.51 0.96 1481.93 N 2182.58 W 2638.13 N 55 49 W 1520.35 N 2248.08 W 2713.91 N 55 55 W 1558.83 N 2313.39 W 2789.57 N 56 1 W 1597.43 N 2378.53 W 2865.17 N 56 6 W 1635.77 N 2443.57 W 2940.54 N 56 12 W 1673.3! N 2509.41 W 3016.14 N 55 18 W 1709.19 N 2575.55 W 3091.08 N 56 25 W 1743.37 N 2641.59 W 3165.02 N 5,5 34 W 1777.62. N 2707.62 W 3239.01 N 56 42 W 1811.83 N 2773.53 W 3312.88 N 56 50 W 6000.00 4497.22 4421.22 47 59 6100.00 4553.94 4487.94 48 6200.00 4630.37 4554.37 48 14 6300.00 4696.79 4620.79 48 30 6400.00 4763.26 4687.26 48 10 6500.00 4830.18 4754.18 47 50 6600.00 4897.47 4821.47 47 44 6700.00 4965.14 4889.14 47 12 6800.00 5033.48 4957.48 46 29 6900.00 5102.63 502-6.63 46 10 N 62 55 W 3382.24 N 53 12 W 3456.61 N 63 35 W 3531.24 N 64 3 W 3605.82 N 64 57 W 3680.29 N 65 43 W 3754.28 N 66 16 W 3827.82 N 66 58 W 3900.95 N 68 3 W 3973.32 N 68 35 W 4044.79 0.34 0.61 0.66 0.80 0.62 I .20 1.12 0.49 0.99 0.60 1845.88 N 2839.65 W 3386.86 N 56 58 W 1879.61 N 2906,05 W 3460.93 N 57 6 W 1913.14 N 2972.86 W 3535.26 N 5'7 14 W 1946.11 N 3039.95 W 3609.52 N 5'7 22 W 1978.26 N 3107.39 W 3683.6,6 N 57 31 W 2009.26 N 3174.93 W 3757.30 N 57 40 W 2.039.27 N 3242.53 W 3830.49 N 57 50 W Z068.48 N 3310.11 W 3903.26 N 57 59 W 2096.40 N 3377.57 W 3975.28 N 53 10 2123.05 N 3444.72 W 4046.40 N 58 21 W 7000.00 5172.02 5096.02 45 46 7100.00 5242.04 5166.04 45 30 7200.00 5312.2~ 5236.26 45 28 7300.00 5382.39 5306.39 45 15 7400.00 5453.06 5377.06 44 49 7500.00 5524.13 5448.13 44 41 7600.00 5595.41 5519.41 44 26 7700.00 5666.88 5590.38 44 23 7800.00 5738.43 5662.48 44 12 7900.00 5810.17 5734.17 44 ~ N 69 33 W 4115.89 N 70 17 W 4186.21 N 70 37 W 4256.21 N 71 5 W 4326.22 N 71 45 W 4395.56 N 72 16 W 4464.36 N 72 51 W 4532.80 N 73 17 W 4600.92 N 73 32 W 4668.82 N 73 53 W 4736.54 I .06 0.19 0.30 0.74 0.59 0.27 0.50 0.28 0.47 0.42 2148.83 N 3511.94 W 4117.18 N 58 32 W 2173.23 N 3579.04 W 4187.18 N 58 44 W 2197.02 N 3646.14 W 4256.91 N 53 55 W 2220.46 N 3713.46 W 4326.69 N 59 7 W 2243.00 N 3780.53 W 4395.85 N 59 19 W 2264.69 N 3847.45 W 4464.50 N 59 31 W 2285.70 N 3914.37 W 4532.85 N 59 43 W 2306.05 N 3981.28 W 46{)0.92 N 59 55 W 2325.99 N 4048.18 W 4668.83 N 60 7 W 23~5.53 N 4115.11 W 4736.63 N 60 19 W ARCO ALASKA, 'INC. 3H-15 KUPARUK NORTH SLOPE,~LASK~ CgMPUTATI~N DATE: O2-MAR-88 PAGE 3 DATE OF SURVEY: 20-FEB-88 KELLY BUSHING ELEVATION: 76.00 FT ENGINEER: SARBER INTERPBLATEO VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR C30RDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN BO00.O0 5882.17 5906.17 43 40 8100.00 5954.69 5878.69 43 17 8ZO0.O0 6028.17 5952.17 42 2 8300.00 6102.85 6026.85 41 32 8400.00 6177.67 6101.57 41 33 8460.00 5222.56 6146.56 41 33 DEG MIN FEET OEG/IO0 FEET FEET FEET DE,',; MIN N 74 30 W 4803.83 N 75 12 W 4970.39 N 76 11 W 4935.66 N 76 15 W 4999.49 N 76 14 W 5063.18 N 76 14 W 5101.39 0.96 1 1.19 8.31 0.00 0.00 2'364.52 N 4181.86 W 4804.05 N 60 30 W 2382.57 N 42~8.30 W 4870.80 N 60 42 W 2399.27 N 4314.04 ~ 4936.33 N 60 55 W 2415.02 N 4378.66 W 5000.50 N 61 7 W 2430.80 N 4443.10 W 5064.58 N 61 19 W 2440.26 N 4451.77 W 5103.05 N 61 25 W ARCO ALASKA, lNG. 3H-15 KUPARUK NORTH SLOPE,ALASK~ COMPUTATION DATE: 02-MAR-88 DATE OF SURVEY: 20-FEB-88 KELLY BUSHING ELEVATION: 76.00 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SE~ COURSE MEASURED VERTICAL VER'TICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -76.00 0 0 1000.00 999.99 923.99 0 26 2000.00 1908.52 1832.52 41 48 3000.00 2572.69 2496.69 50 21 4000.00 3194.60 3118.60 52 13 5000.00 3837.42 3761.42 49 31 6000.00 4497.22 4421.Z2 47 59 7000.00 5172.0Z 5096.02 45 46 8000.00 5882.17 5806.17 43 40 8460.00 6222.56 6146.56 41 33 VERTICAL DOGLEG RECTANGUL&R COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 0 E 0.00 N 6 21 W -2.04 N 50 13 W 33'9.11 N 58 22 W 1082.82 N 58 26 W 1865.44 N 59 37 W 2631.23 N 62 55 W 3382.24 N 69 33 W 4115.89 N 74 30 W 4803.33 N 76 14 W 5101.39 0.00 1.13 4.27 0.49 0.29 0.12 0.34 I .06 0.96 0.00 0.00 N 0.00 E 0.00 N 0 0 E 1.51 N 3.23 E 3.57 N 64 57 E 253.79 N 239.Z1 W 356.09 N 42 12 W 676.7,3 N 859.53 W 1093.96 N 51 47 W 1090.22 N 1524.48 W 1874.20 N 54 25 14,~1.93 N 2182.58 W 2638.1.3 N 55 49 W 11845.88 N 2839.65 W 3386.86 N 55 58 W 2148.$3 N 3511.94 W 41117.18 N 58 32 2364.52 N 41,'31.86 W 4804.05 N 60 30 W 2440.26 N 4481.]'7 ,~ 5103.05 N 61 25 W ARCO ALASKA, INC. 3H-15 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 02-MAR-88 DATE OF SURVEY: 20-FEB-88 KELLY BUSHING ELEV;~TION: 76.00 FT ENGINEER: SARBER INTERPOLATEO VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASUREO VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -76.00 0 0 N 0 0 E 76.00 '?6.00 0.00 0 10 S 3 23 W 176.00 176.00 100.00 0 7 S 50 24 F 276.00 276.00 200.00 0 10 N B5 Z E 376.00 376.00 300.00 0 21 N 51 24 E 476.00 476.00 400.00 0 23 N 43 59 E 576.01 5'76.00 500.00 0 15 N 63 27 E 676.01 676.00 600.00 0 15 N 67 36 E 776.01 776.00 700.00 0 17 N 68 51 E 876.01 876.00 800.00 0 16 N 67 12 E 976.01 976.00 900.00 0 18 1076.04 1076.00 1000.00 2 50 1176.50 1176.00 1100.00 7 31 1278.00 1276.00 1200.00 11 50 1381.07 1376.00 1300.00 16 9 1486.63 1476.00 1400.00 21 7 1595.78 1576.00 1500.00 25 58 1/09.76 1676.00 1600.00 31 18 1829.92 1776.00 1700.00 35 57 1956.99 1876.00 1800.00 40 4 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 2093.41 1976.00 1900.00 45 41 2240.27 2076.00 2000.00 47 7 2389.03 2176.00 2tO0.O0 49 10 2542.37 2276.00 2200.00 49 3 2694.74 2376.00 2300.00 49 0 2848.91 2476.00 2400.00 50 5 3005.19 2576.00 2500.00 50 22 3163.39 2676.00 2600.00 51 17 3324.49 2776.00 2'700.00 51 54 3485.38 2876.00 2800.00 50 50 0.00 0.00 0.00 N 0.00 E -0.08 0.22 0.22 S 0.03 W -0.25 0.00 0.44 S 0.04 E -0.50 0.13 0.51 S 0.28 E -0.74 0.06 0.23 S 0.69 E -0.94 0.13 0.17 N 1.18 E -1.12 0.05 0.51 N 1.59 E -1.39 0.00 0.70 N 2.01 E -1.69 0.00 0.88 N 2.4,5 E -1.99 0.00 1o06 N 2.91 E 3644.84 2976.00 2900.00 51 25 3806.38 3076.00 3000.00 51 58 3969.63 3176.00 3100.00 52 14 4132.33 3276.00 3200.00 51 18 4287.27 3376.00 3300.00 49 lB 4441.21 3476.00 3400.00 49 36 4595.71 3576.00 3500.00 49 43 4750.45 3676.00 3600.00 49 46 4905.21 3776.00 3700.00 49 42 5059.35 3876.00 3800.00 49 23 N 9 6 E -2.12 0.3'7 N 43 9 W -0.44 5.32 N 53 13 W 8.79 4.56 N 44 32 W 25.65 4.36 N 42 8 W 49.43 4.47 N 41 40 W 81.47 4.69 N 38 4 W 122.51 4.93 N 37 55 W 172.98 4.56 N 42 31 W 235.42 4.92 N 49 14 W 311.40 4.49 N 49 19 W 402.63 N 51 44 W 508.67 N 57 27 W 618.25 N 59 50 W 734.49 N 59 0 W 849.45 N 58 38 W 965.75 N 58 21 W 1086.81 N 58 17 W 1209.35 N 58 1 W 1335.59 N 57 41 W 1461.53 N 57 55 W 1585.64 N 58 22 W 1712.44 N 58 28 W 1841.44 N 59 17 W 1969.74 N 59 6 W 2088.07 N 59 7 W 2205.08 N 59 10 W 2322.84 N 59 32 W 2440.93 N 59 34 W 2559.03 N 59 36 W 2676.34 0.00 N 0 0 E 0.22 S 8 39 W 0.44 S ~ 40 E 0.58 S 28 49 E 0.74 S 67 33 E 1.19 N 81 46 E 1.67 N 72 3 F 2.13 N 70 43 2.61 N 70 21 E 3.10 N 70 2 E 1.36 N 3.2~ E 3.51 N 67 13 E 2.98 N 2.23 E 3.72 N 3,5 51 E 8.85 N 5.04 W 10.18 N 29 40 W 20.14 N 17.99 W 27.00 N 4.1 45 W 38.39 N 34.90 W 51.88 N 42 16 W 63.44 N 57.43 W 85.58 N 42 9 W 96.85 N 35.52 W 129.20 N 41 26 W 140.13 N 118.80 i 183.71 N 40 17 W 191.23 N 161.38 W 250.23 N 40 9 W 245.60 N 217.72 i 328.21 N 41 33 W 4.64 3.43 4.33 0.65 0.46 0.48 0.53 0.76 0.38 0.42 305.49 N 288.48 W 420.17 N 43 21 W 374.06 N 371.31 W 527.06 N 44 47 W 437.83 N 461.03 W 635.80 N 46 28 W 496.80 N 561.20 W 749.50 N 43 28 W 555.30 N 660.16 W 862.66 N 49 55 W 616.07 N 760.52 W 978.75 N 50 59 W 678.82 N 862.93 W 1097.93 N 51 48 W 743.21 N 967.24 W 1219.81 N 52 27 809.85 N 1074.54 W 1345.55 N 52 59 876.81 N 1181.30 W 1471.14 N 53 24 W 0.24 0.37 0.48 2.03 0.26 0.04 0.15 0.36 0.16 0.29 943.16 N 1286.30 W 1595.03 N 53 44 W 1010.09 N 1394.08 W t721.55 N 54 4 W 1077.67 N 1504.02 W 1850.25 N 54 22 W 1144.39 N 1613.63 W 1978.24 N 54 39 W 1204.98 N 1715.28 W 2096.23 N 54 54 W 1265.01 N 1815.75 W 2212.96 N 55 8 W 1325.43 N 1916.83 W 2330.46 N 55 20 W 1385.63 N 2018.43 W 2448.27 N 55 31 W 1445.41 N 2120.29 W 2566.10 N 55 43 W 1504.74 N 2221.50 W 2683.15 N 55 53 W ARCO ALASKA, INC. 3H-15 KUPARUK NORTH SLOPE~ALASKA C3MPUTATIDN DATE: O2-MAR-B8 PAGE 6 DATE OF SURVEY: 20-FEB-88 KELLY BUSHING' ELEVATION: 75.00 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRU? SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR CgORDIN&TES H3RIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH D='PTH DEPTH DEG MIN 5212.70 3976.00 3900.00 49 12 5365.52 4076.00 4000.00 48 59 5518.67 4176.00 4100.00 49 20 5669.25 4276.00 4200.00 48 581B.84 4376.00 4300.00 47 55 5968.29 4476.00 4¢00°00 48 0 6118.14 4576.00 4500.00 48 23 6268.63 6676.00 4600.00 48 26 6419.08 4776.00 4700.00 48 6 6568.08 6876.00 4BO0.O0 47 42 6715.96 49'76. O0 4900. O0 47 8 6861.56 5076.00 5000.00 46 9 7005.70 5176.00 5100.00 45 44 7168.38 5276.00 5200.00 45 19 7290.91 5376.00 5300.00 45 19 7632.31 5476.00 5400.00 44 42 7572.~1 5576.00 5500.00 44 7712.75 5676.00 5600.00 64 21 7852.34 5776.00 5700.00 44 13 7991.47 5876.00 5800.00 43 43 8129.21 5976.00 5900.00 43 0 8264.17 6076.00 6000.00 41 38 8460.00 6222.56 6146.56 41 33 DEG MIN FEET OEG/IO0 FEET FEET FEET DEG MIN N 59 2~, W 2792.60 N 59 31 W 2908.15 N 60 57 W 3024.13 N 62 40 W 3136.63 N 62 32 W 3247.76 N 62 4~ W 3358.70 N 63 15 W 3470.14 N 63 53 W 3582.39 N 65 7 'W 3694.44 N 66 10 W 3804.34 N 67 7 W 3912.56 N 68 26 W 4017.38 N 69 38 W 4119.92 N 70 29 W 4220.08 N 71 1 W 4319.87 N 71 5B W 4417.~2 N 72 43 W 451.4.23 N 73 19 W 4609.59 N 73 44 W 4704.27 N 74 25 W 4798.13 N 75 33 W 4~389.65 N 76 19 W 4976.71 N 76 14- W 5101.39 0.01 0.59 ! .39 0.43 0.82 0.58 0.60 0.38 0.96 0.69 0.85 0.62 1.05 1.01 0.87 0.64 0.40 0.29 0.63 1,03 1.35 0.10 0.00 1563.73 N 2321.67 W 2799.18 N 56 2 W 1622.6'3 N 2421.10 W 2914.56 N 55 10 W 1680.21 N 2521.78 W 3030.26 N 56 19 W 1732.87 N 2621.28 W 3142.28 N 56 31 W 1784.07 N 2720.04 W 3252.93 N 56 44 W 1835.13 N 2818.68 W 3363.43 N 56 56 W 1885.72 N 2918.14 W 3474.41 N 57 7 W ~, 1935.81 N 3018.85 W 3586.19 N 57 19 t,. 1984.25 N 3120.27 W 3697.75 N 57 32 W 2029.74 N 3220.92 W 3807.12 N 57 46 W 2073.03 N 3320.89 W 3914.81 N 58 1 W 2112.89 N 3418.92 W 4019.12 N 58 17 W 2150.25 N 3515.76 W 4121.18 N 58 32 W 2184.79 N 3611.49 W 4220.92 N 58 49 W 2218.36 N 3707.35 W 4320.37 N 59 6 W 2250.08 N 3802.15 W 44.18.06 N 59 22 W 2280.06 N 3896.18 W 4514.30 N 59 39 W 2308.61 N 3989.82 W 4609.59 N 53 56 W 2336.26 N 4083.20 W 4704.32 N 60 13 W 2362.95 N 4176.18 W ~,798.33 N 60 29 W 2387.61 N 4267.64 W 4890.13 N 60 46 W 2409.40 N 4355.60 W 4977.59 N 61 2 W 2440.26 N 4481.77 W 5103.05 N 61 25 W COMPUTATION DATE: 02-MAR-88 PAGE 7 ARCO ALASKA, [NC;. 3H-15 KUPARUK NORTH SLOPE~ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARU~ ~ PBTO TO DATE 9F SURVEY: 20-FEB-88 KELLY BUSHING ELEVATION: 76.00 FT ENGINEER: SARBER INTERPOLATE~ VALUES FOR CHOSEN HORIZONS MEASURED OEPTH BELOW KB FROM KB SURFACE LOCATION AT ORIGIN: 1132 FNL, 281 FWL, SEC 12, T12N, RSE, UM TVD R~CTANGULAR C00RDIN,&TES SUB-SEA NORTH/SOUTH EAST/WEST 8072.00 8130.00 B130.00 8226.00 8353.00 8460.00 5934.34 5976.58 5976.58 6047.52 6142.50 6222.56 5858.34 2377.61 'N 4229.72 W 5900..~,B 2387.74 N 4268.15 W 5900.58 2387.74 N 4268.15 W 5971.52 2.403.40 N 4330.92 W 6066.50 2423.38 N 4412.82 W 6146.56 2440.26 N 448I.?T W ARCO ALASKA~ INC. 3H-15 KUPARUK NORTH SLOPE~ALASKA C'.,IMPU TAT 19N DATE: 02-MAR-88 KELLY MARKER TOP KUPARUK C BASE XUPARUK C TOP KUPARUK A BASE KUPARUK & PBTD TD FINAL WELL LOCATION AT TO: ORIGIN: 11 32 MEASURED DEmTH TVD BELOW KB FROM KB SUB-SEA 8072°00 5934.34 5858.34 8130.00 5976.58 5900.58 '~130.00 5976.58 5900.5 8 8226.00 6047.52 5971.52 8353.00 6142.50 6066.50 8460.00 62.22.56 6146.56 TRUE SUB-SEA MEASURED V.ERTIC,~L VERTICAL DEPTH D.=_PTH DEPTH HORIZONTAL D~PARTURE DISTANCE AZIMUTH FEET DEG MIN FNL~ DATE BUSHING gF SURVEY: ELEVATION: ENGINEER: SURFACE LOCATION AT 281 :WL, SEC 12, T12N, RECTANGULAR COORDIN NORTH/SOUTH EAST/' 2377.61 N 4229. 2387.74 N 4268. 2387.74 N ~268. 2~03.40 N 4330. 2423.38 N 4412. 2440.26 N 4481. PAGE 20-FEB-88 75. O0 FT SARBER RSE, &TES WEST 72 W 15 W 15 W g2 W ~2 W 77 W UM 8460.00 6222.56 5146.56 5103.05 N 61 25 W SCHLUMBERGER O I RECT ! ONAL SURVEY COMPANY ARCO ALASKA, INC. WELL 3H- 1S FIELD KUPARUK COUNTRY U..S .A. RUN ONE DATE LOOOED 20 - FEB - 88 REFERENCE ?2809 WELL' (11.32' 3H-15 .~. ENL, 281' FWL, S ~'12, T12N, R8E, UM) HORIZONTAL PROJECTION N0flTH ,~000 4000 ~000 1000 - ! 000 -20OO SOUTH -3000 WEST REF ?2609 SCALE = 1/10[~] IN/FT ~ ! :' ~ .: ~ ~ , 7 %'7"?"~"7"':~T'T''--:''',?':'''%'' "7-~ 7 T 7 , % %"'t"~'T'~'7'"' "%"7"~"~" "~"7"?"'T''~ "T"?"?"'~"' ....... "T'?T"l-'-~"i-f'i'-'i"i"!"i-ri"!-fi'-"!"i--h'?~"'fi'-i-t--i-i"i-i- ~"i-'hi-i ....... f'i"i-"~ .....l f"i"'fi ....... h'f"f-~ ...... hi'i-'+ ...... ~"+-'~'-~ ....... ~-~.-.~'"~,.. '+"~'~"~-' ~'~"~-~ ...... 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L.i.~..~ ....... ~...!...4..4 ....... 4..4-4..4 ...... 4...4...4.--4 ....... 4..4-.{.-.4 ...... ~..-+.-.{-~ .... · .+-+~..:.-+.~-~.~ ..... ~"~-T"T-~'"~-~"~-'~"T'~' 'T"~I ~ T~ ~ ~ ~. ~..i ....... ~...~-.i..~ ....... i...i...~...~...:...~..4-.~..~ ...... ~...:...~..-~ ....... 4..4-+.4 ...... +-~--+.+... ~-~.~--~q: ~- -+.~-~-++~-~---r.+-~-~-~?~-~? "~-T"T-r'""~'~'T'T" 'T"T"'I"~ ..... ~"'?"T ~ ~ ~ ~ ~ i: ~ ~ ~ { = ..}-4...~ ...... ~, 4.4 .... ) t : , j · : : ~ : : : : I : , : : · '~.. I...4...4...4 .... ' : ~ i : ~ ~ : ! : : : : ~ : : : ..... ...... 7OO0 300. PROJECTION ON VERTICAL PLANE 300. - 120. $CAt.£O IN VERIlCAL OEPIH~ HORIZ SCALE = l/1000 IN/FT 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- 1 4 Kuparuk Fluid Level Report 1 2 - 1 0 - 8 8 Casing · , 3 H- 1 5 Kuparuk Fluid Level Report I 2 - 0 9 - 8 8 Tubing · 3 H- 1 7 Kuparuk Fluid Level Report I 2 - 0 9 - 8 8 Casing e 3 M - 1 9 Kuparuk Fluid Level Report I 2 - 0 9 - 8 8 Casing · 3 H- 0 6 Kuparuk Fluid Level Report I 2 - 0 8 - 8 8 Tubing · 3 H- 0 9 Kuparuk Fluid Level Report I 2 - 1 3 - 8 8 Casing ~ 3 H- 21 Kuparuk Fluid Level Report 1 2 - 1 3 - 8 8 Casing · 3 K- 0 6 Kupaurk Fluid Level Report 1 2 - 1 2 - 8 8 Casing ~' 3 H- 21 Kuparuk Fluid Level Report 1 2 - 1 2 - 8 8 Casing · 1 Y- 0 6 Kuparuk Fluid Level Report 1 2 - 1 2 - 8 8 Casing · 30-07 BHP Report 1 1-27-88 Receipt Acknowledged: Alaska Oil & ~s Cc~.;. Cc, rnmissio~ ........................... Date: ............ DISTRIBUTION: State of Alaska D&M Unocal SAPC Chevron Mobil AL~,_,~, OIL AND 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_ _ Plugging _ Time extension _ Stimulate _ Convert to Pull tubing _ Variance _ Perforate _ Other ~ WI 2. Name of Operator ARCO Alaska, lnG, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1132' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1246' FSL, 1331' FWL, Sec. 2, T12N, R8E, UM At effective depth 1291' FSL, 1148' FWL, Sec. 2, T12N, R8E, UM At total depth 1308' FSL~ 1079' FWL~ Sec. 2~ T12N~ R8E~ UM 12. Present well condition summary Total Depth: measured 8 4 6 0' true vertical 6 2 2 3' 6. Datum elevation (DF or KB) RKB 76' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3H-15 9. Permit number 87-103 10. APl number 50-1 03-20082 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool feet Plugs (measured) feet None Effective depth: measured true vertical 8353' feet Junk (measured) 61 4 3' feet None Casing Structural Conductor Surface Intermediate Production Perforation depth: Length Size Cemented 80' 3584' Measured depth True vertical depth 8 4 0 7' 7" 300 Sx Class G 8 4 4 2' measured 8116'-8148', 8072'-8110' @ 12 SPF, 8174'-8204' @ 4 SPF true vertical 5966'-5990', 5934'-5962' @ 12 SPF, 6009'-6031' @ 4 SPF 1 6" 210 Sx AS I 1 15' 1 1 5' 9 5/8" 1340 Sx AS III & 361 9' 2960' 325 Sx Class G Top job w/AS 1 to 80' (approx) 6210' Tubing (size, grade, and measured depth 3 1/2", J-55, tbg w/tail @ 8002' Packers and SSSV (type and measured depth) FHL pkr @ 7930' & TRDP-1A-SSA SSSV @ 1782' 13. Attachments Description summary of proposal Convert oil producer to water injection. Detailed operation program BOP sketch 14. Estimated date for commencing operation November, 1988 16. If proposal was verbally approved Name of approver Date approved 15, Status of well classification as: Oil Gas Suspended Service Water In!eGtor 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance Mechanical Integrity Test,~ Subsequent ORIGINAL SIGNED BY Returned // .,~~ '! C SMITH Approved by the order of th[,0~lmFrn,~s,on ..... "J"-~'~"----"~----'- Commissioner IApproval~o. I Date J~)~¢:~~)" ~¢ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Well 3H-15 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 2600 psi based on the producing GOR. 4. No workover fluid will be used. 3H WATERFLOOD ~VERSIONS GENERAL PROCEDURE . . . . 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 7 9 5' 5 8 3 2' 5 92 7' REQUIRED C.,SG 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 3000 25O0 2100 25OO ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6001-A ARCO Alaska, Inc. Date: October 21, 1988 Transmittal #: 7330 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. 3H-14 Sub-Surface Pressure Survey 9- 14-88 #AKU3H14 3H-15 Sub-Surface Pressure Survey 9-17-88 #01KU3H15 3H-16 Sub-Surface Pressure Survey 9-21-88 #01KU3H16 3H-18 Sub-Surface Pressure Survey 9-27-88 #01KU3H18 3 N - 1 7 Kuparuk Fluid Level Report 1 0-1 3 - 8 8 Casing Receipt Acknowledged: DISTRIBUTION; D&M State of Alaska Unocal Mobil SAPC Chevron STATE OF ALASKA ALASK~tblL AND GAS CONSERVATION COMM,~ ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other IX[ COMPLETE 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 76' 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 7. Well number 3H-15 4. Location of well at surface 1132' FNL, 281' FWL, 5ec.12, T12N, RSE, UH At top of productive interval 1246' FSL, 1331' FWL, Sec. 2, T12N, R8E, UN At effective depth 1291' FSL, 1148' FWL, Sec. 2, T12N, R8E, UM At total depth 1308' FSL, 1079' FWL, Sec. 2, T12N, R8E, UM 8. Approval number 7-868 9. APl number 50-- 103-20082 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8460'MD 6223'TVD 8353'MD 6143'TVD Casing Length Size Conductor 80 ' 16" Surface 3584 ' 9-5/8" Production 8407' 7" feet feet feet feet Plugs (measured) None None Junk (measured) Cemented Measured depth 210 sx AS I 115'MD 1340 sx AS I11 & 3619'MD 325 sx Class G Top job w/AS I to 80' (approx) 300 sx Class G 8442'MD Rue Vertical depth 115'TVD 2960'TVD 6210 ' TVD Perforation depth: measured 8174'-8204 'MD 12. true vertical 6009'-6031'TVD Tubing (size, grade and measured depth) 3½", J-55, tbg w/tail (~ 8002' Packers and SSSV (type and measured depth) FHL pkr @ 7930'& TRDP-1A-SSA SSSV ~ 1782' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED 1 0 1 88 & uas Cons. Cor~lll$$fot Anchorage 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 (Completion Wel 1 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 Form 10-404 Rev. 12-1-85 Title Associate Engineer (Dani) SW03/90 Feet Date ~-¢~ Submit in Duplicate ARCO Oil 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 workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. ARCO Alaska, Inc. ICounty, parish or borough NORTH SLOPE - KUPARUK Lease or Unit ADL: 25531 Title COMPLETION/PERFORATION IStatL District Field KUPARUK RIVER FIELD 3H-15 ]Well no, Auth. or W.O. no. AK2581 ARCO API: 50-103-20082 ARCO W I 0.0000 Prior slalus i! a w.o, Operator Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 05/18/88 ( TD: ?B: 8335 SUPV:DL The above is correct J Date 05/17/88 Hour 1815 HRS Complete record for each day reported NORDIC 1 RIH WITH COMPL. EQUIP. MW:10.0 NACL/NABR MOVED RIG FROM 3H-14 TO 3H-15. ACCEPTED RIG @ 1815 HRS, 5/17/88. ND TREE. NU BOPE AND TESTED TO 3000 PSI. PERFORATED 'A' SAND WITH 4 SPF FROM 8174'- 8204'. NU FLOW NIPPLE AND FLOW LINE. RIH WITH 3-1/2" COMPLETION ASSEMBLY. DAILY:S46,150 CUM:$46,150 ETD:S767,872 EFC:$-,721,722 RECEIVED JUN 1 0 1988 Alaska Oil & Gas Cons. CommissJort Anchorage For form prepara~n and distribution, see Procedures ~411nual, Section 10, Drilling, Pages Eib/and 87. Date I Title ~'- 7- ~5 ASSOCIATE ENGINEER AR3B-459-1-D Number ell dally well history forms consecutively iPage no, as they are prepared for each well. ARCO ~,,I and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well ia 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. I Accountlng cost center code District County or Parish State ARCO Alaska, Inc. J AK KU?ARUK RIVER FIELD NORTH SLOPE - KUPARUK Lease or Unit ADL: 25531 ITitle COMPLETION/PERFORATION 3H-15 IWell no. Auth. or W.O. no. AK2581 Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 05/19/88 ( TD: PB:8335' SUPV:SC A?I: 50-103-20082 I A.R.Co. W.I. fTotal number of wells (active or inactive) on thisj cost center prior to plugging and abandonment of this well I Date Hour ~ Prior status if aW,O. I 05/17/88 1815 HRS Complete record for each day reported NORDIC 1 RELEASED RIG MW: DIESEL RAN 3-1/2" COMPLETION ASSY WITH TAIL @ 8002', 'FHL' PKR @ 7930', SSSV @ 1782'. LANDED TUBING. DROPPED BALL. SET PACKER. TESTED TUBING. SHEARED ?BR. TEST ANNULUS TO 2500 PSI. TESTED SSSV. SET BPV. ND BOPE. NU TREE AND TESTED. DISPLACED WELL WITH 280 BBLS DIESEL DOWN THE ANNULUS. TESTED CV. SET BPV. SECURED WELL AND RELEASED RIG @ 1630 HRS, 5/18/88. DAILY:S112,154 CUM:$158,304 ETD:S112,154 EFC:$46,150 Old TD /NewTD I PB Deplh Released rig J Date IKind of rig Classifications (oil, gas, etc.) I Type complelien (single, dual, etc.) I Producing method ! Official reservoir nama(s) I Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Produclion .,_ Oil on teal Gas per day Pbmp size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected _.., The above is correct For form prepara~n-and distribution, ASSOQIATE ENGINEER AR3B-459-3-C Number all daily wall history forms Page no. las they are prepared f ..... h wel. C ...... tlvely I I Dlvl~on of AllantlcRIchfleldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 Date: February 29, 1988 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #: 7107 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 ~3H-17 Cement Bond Log 2-19-88 6300-8470 ~3H-I4 Cement Bond Log 2-17-88 3150-8102 "~ ~.~, Cement Evaluation Log 2-17-88 5250-8330 Receipt Acknowledged: DISTRIBUTION: NSK Drilling · '--"- Oil & ~3~. C'.:,,~s. Comrni%i?~ .t ,;...,~[',.O. .... ~ ,,., Date: State of Alaska(+sepia) ARCO Alaska. Inc. is a Sul3s~diary of AtlanticRichfieldCcr'nf3any ARCO Alaska, Irt/-`` Post Otfic ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: October 28, 1987 Transmittal ~ 6095 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorages AK 99510-0360 Transmitted herewith are the following items. and return one signed copy of this transmittal' OH Lis Tape 3H-15 10-16-87 Please acknowledge receipt #72468 Alaska 0il & Ga.~s Corm. Commission Receipt Acknowledged: DISTRIBUTION: M. Stanford Date; ____ State of Alaska ARCO Alaska, Inc. is a SubSidiary ot AttanticRichfieldc°mpany STATE Of ALASKA AL~-'~r~A Oil' AND GAS CONSERVATION CE 'IlSSION 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 ,- Perforate- Other 2. Name of Operator ARCO AlaskaI inc 3. Address P. 0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1132' FNL, 281' FWL, $ec.12, T12N, R8E, UM 5. Datum elevation(DF orKB) RKB 76' 6. UnitorPropertyname Kuparuk River Unit 7. Wellnumber 3H-15 feet At top of productive interval 1297' FSL, 1360' FWL, Sec. At effective depth 1332' FSL, 1162' FWL, Sec. At total depth 1351 ' FSL, 1093' FWL, Sec. 11. Present well condition summary Total depth: meaSured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 3584' Production 8407' Perforation depth: measured None 2, T12N, R8E, UM (approx) 2, T12N, R8E, UM (approx) 2, T12N¢ RSEI UM, (approx) 8. Permit number 87-10~ 9. APl number 50-- 103-2oo82 10. Pool Kuparuk River 0il Pool 8460 ' MD feet Plugs (measured) 6227 'TVD feet None 8353 'MD feet feet 6148 'TVD Size 1 6" 9-5/8" 7" Junk (measured) None Cemented 210 sx AS I 1340 sx AS I II 325 sx Class G Top job w/AS I 300 sx Class G Measured depth Rue Verticaldepth llS'MD 115'TVD I 3619'MD 2970'TVD I to 80' (approx) 8442'MD 621 4 ' TVD true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments WELL HISTORY Description summary of proposal - Detailed operations program -_-_; BOP sketch 13. Estimated date for commencing operation February, 1988 14. If proposal was verbally approved Name of approver Subsequent Work Reported on vo, Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed L/~/~?J~J .~-4~_, Title Ass o cia t e E n~ in e er ~/ Commission Use Only (D a n i ) SA3/5 Date Conditions of approval Approved by Notify commission so representative may witness ~ Plug integrity 'Z BOP Test - Location clearance 7 /~fl-~L~O ~ ~ Commissioner Approval No. ~ <~¢;~'¢~ by order of the commission Date //'- Submit in tripl(ca;.:- Form 10-403 Rev 12-1-85 or wort(ov~r ol~rettone em dlt~. only. ~ ~ NotCh Slope Borough [st.t. r unit ADL 25531. Alaska Title Drillin$ .,~I 50-103-20082 10/14/'87 - - ~' (1783') POH f/cas ' 91'z, Pv 10, Pa 8.5, 10.2, Sol 6 Otl& surv to 3637', CBU, POH. 487' 3° N63.0E, 487 TVD, -.69 VS, , · 9 1105', 4.6°, N50.9~, 1105 TVD, 1.41VS, .58N, 1.14g 10.02N, 4.17E 1485', 20.9°, N42.4W, 1474 TVD, 82.32 VS, 70.76N, 54.18W 2277', 46.7°, N54.4~, 2104 TVD, 537.27 VS, 389.85N, 395.22~ 3526' 51.0° N60 7~ 2912 TVD, 1488.42 VS 885 65N, 1207.24W 9-5/8" @ 3619' 3637' (0'), RIH w/drlg assy · Wt. 8.3 POH, LD BHA. RU & rn 91 jts, 9-5/8", 36#, J-55 BTC csg w/FS @ 3619'. Cmt w/1340 sx AS III & 325 sx Cl "G". Displ w/wtr, bump plug. ND diverter. Perform top job to 80' W/ASI cmt. NU &tst BOPE. RIH w/drlg assy. 10/15/87 9-5/8" @ 3619' 6439', (2802'), Drlg Wt. 9.3, PV 4, YP 2, PH 9.0, WL 8.6, Sol 7 DO FS + 10' new formation. Chg over to Polymer. Conduct LOT to 12.5 ppg EMW. Drl to 6439'. 3980', 52.2°, N58.6W, 3194.48 TVD, !844.21VS, 1065.43N, 1514.28W 4867', 49.8°, N58.6W, 3761.62 TVD, 2526.04 VS, 1417.17N, 2098.51W 5753', 48.1°, N61.4W, 4341.39 TVD, 3195.82 VS, 1762.76N, 2672.37W The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARC° Oil and Gas C¢ ZPany Daily History-Final Report Inatmotione: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well iS Plugged, Abandoned, or Sold. "Filial RelN~rt" 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 reDresentative test data in blocks provided1 The "Final Report" form may be used for reporting the entire oDeration if space is available. :Accounting cost center code District 1County or Parish Alaska Field [Lease or Unit Kuparuk River Auth. or W.O. no. ~Title AFE AK2581 Doyon 14 A.R.Co. W,I. Operator ARCO Alaska, Inc. North Slope Borough ADL 25531 Drill AP1 50-103-20082 56.24% Spudded or W.O, begun Date Spudded 10/11/87 Date and depth Complete record for each day reported as of 8:00 a.m. State Alaska Well no. 3H-15 lO/16/87 10/17/87 thru 10/18/87 I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our [Prior etatue if a W.O, 1630 hrs. 9-5/8" @ 3619' 8437', (1998'), CBU Wt. 9.9, PV 9, YP 6, PH 9.0, WL 4.8, Sol 10 Drl to 8437', short trip to shoe, CBU. 6196', 48.5°, N62.SW, 4636.09 TVD, 3526.35 VS, 1917.53N, 2964.69W 6641', 47.7°, N65.9W, 4933.28 TVD, 3856.60 VS, 2060.91N, 3263.27W 7179', 45.5°, N69.1W, 5302.93 TVD, 4244.13 VS, 2210.50N, 3624'.41W 7717', 44.4°, N72.0W, 5683.69 TVD, 4617.76 VS, 2337.06N, 3982.81W 7" @ 8442' 8460' TD, 8353 PBTD, (23'), RR 10.0 ppg Brine Spot diesel pill, POOH. RU Schl, log DIL/GR/SP/SFL f/8438'-3619', FDC/CNL f/8438'-7700', 7400'-7200', 6800'-6600', 6300'-6100', 4700'-4600', 4000-3800' & CAL f/8438'-3619'. Drl to 8460' TD, CBU, spot pill, POOH, LD DP. RU & rn 195 jts, 7", 26#, J-55 BTC csg w/FC @ 8353', FS @ 8442'. Cmt w/lO0 sx 50/50 Pozz w/4% D-20, .2% D-46, .5% D-65 & tail w/200 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Dispi w/lO.O ppg brine, bump plug. ND BOPE. Instl packoffs & tst to 3000 psi. RR @ 0300 hrs, 10/18/87. 8309', 42°, N74W, 6115.26 TVD, 50]2.58 VS, 2455.54N, 4370.35W *8437', 42°, N74W, 6210.36 TVD, 5095.67 VS, 2479.15N, 4452.68W *Projected Old TD [ Ne,~ -~ t 8460' TD i 8353 PBTD Released rig Date 0300 hrs. ]0/18/87 j Rotary Classifications (oil, gas, etc.) Oil j Single Producing method I Kuparuk Sands Potential test data Production Well no. Date Reservoir [ Pump size, SPM X length Choke size The above is correct C~i on :est Gas per day Allowable FIfocuve date For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inr,~-.. Posl Offic ~x 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 Date: October 28, 1987 Transmittal #: 6097 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-15 5" Dual Induction 10-16-87 3617-8430 '-3H-15 2" Dual Induction 10-16-87 3617-8430 "-3H-15 2" Porosity FDC 10-16-87 3800-8405 ~-3H-15 Cyberlook 10-16-87 7700-8405 ~"3H-15 5" Porosity FDC 10-16-87 3800-8405 -~'3H-15 5" Raw and Hi-Res Pass FDC 10-16-87 3800-8405 --~ 3H-15 2" Raw FDC 10-16-87 3800-8405 Receipt Acknowledged: DISTRIBUTION: Date: NSK Drilling Franzen D & M L. Johnston(vendor package) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Vault(film) October 7, 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 t~it 3H-15 ARCO Alaska, Inc. Permit No. 87-103 Sur. Loc. !132'F~fL, 281'FILL, Sec. 12, T12N, RSE, UM. Btmhole Loc. 1420'FSL, l147'FWL, Sec. 2, T12N, R8E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit 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 y~s, Commissioner of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~-~IISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enc!. Mr. Doug L. Lowery ALAS~.~"~ ,-'~'-, STATE OF ALASKA '-~" .... ' .. O, AND GAS CONSERVATIOL ";ON,. ~ISSION PERMIT TO DRILL 20 AAC 25.005 t la. Type of work Drill J~ Redrill IZ]I lb. Type of well. Exploratory [] Stratigraphic Test [-~ Development Oil F~ Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone ~ Multiple Zone F~J 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 3. Address 6. Property DesignatiOn Kuparuk River Oil Pool 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 25.025) 1132'FNL, 281'FWL, Sec.12, T12N, R8E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well nu .tuber Number 1297'FSL, 1360'FWL, Sec. 2, T12N, R8E, UM 3H-15 #8088-26-27 At total depth 9. Approximate spud date Amount 1420'FSL, 1147'FWL, Sec. 2, T12N, R8E, UN 10/09/87 $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-17 8423 'ND 11b, 7,f~ TD feet ~n, ~ g..r-~:~,-,,, feet ?5~n. (RI~Z,,Tvn) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 1000 feet Maximum hole angle 50 0 Maximum surface 1776 psig At total depth (TVD) ~0(;}0 psig 18, Casing program Setting Depth size Specifications Top Bottom Quantity 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 3469' 35' 35' 3504 3000' 1100 sx AS III & HF-EFW 400 sx Class G blend 8-1/2" 7" 26.0# J-55 BTC 8389' 34' 34' 8423 6154' 200 sx Class G(minimum HF-EFW TOC 00' abo/e 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 Surface RECEIVED Intermediate Production 00[ 0 ~ i~J~j7 Liner Perforation depth: measured Alaska 0ii & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee ~ Property plat [] BOP Sketch [] Diverter Sketch J~ Drilling program~ Drilling fluid pro, g, ra'l}n ~. Time vs depth plot E~ Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements ~ 21.1hereby,~ifThatthe~oystrueandcorrecttothebestofmyknowledge''~ Si-ned // ' -'//f// /'/' '"/ Title Regional Drilling Engineer (/' // ' Commission Use Only (JLQ) PD2/49 ' 'erm, I I Approv,,,I oover,etter (!~ "7 '-/¢~ Z l, --_:',2; - ;-' ::~-:" c:, ~ *:h I 10 / 0 7 / 8 7 I for other requirements Conditions of approval Samples required [] Yes [~No Mud Icg required ~ Yes ~ 'No Hydrogen sulfide measures [] Yes ~-~N© Directional survey required ~"Yes [] No Required working pressure for BOPE E32M; ~ ~3M; [] 5M; [] 10M; [] 15M Other: //"~'"'"'"'~( ~~~ by order of Approved by Commissioner the commission Date ["O.- ') ~) ,, Form 10-401 Rev. 12-1-85 Submit in triplicate ARCO ALASKA. INO. Pad 3H, Nel I No' 15 Proposed · Kupar'uk F'leld, Nor'l:h Slope, Alaska O ~ 1000_ 2000 _ 3000_ 4000_ 5000 6000 _ 7000 SURFACE KOP TVD=IO00 TMD=IO00 DEP=O 3 BUILD 3 DEO 9 PER 100 FT IS B/ PERHAFROST TVD=1591 THD=1601 DEP'94 21 2Z T/ UGNU SNDS TVD=1846 THD=1876 DEP=198 33 39 4S EOC TVD=2465 THD=2670 DEP'685 T/ W SAK SNDS TVD=2571THD'2835 DEP'811 K-12 TVD=2800 T~D=3192 DEP=1085 9 5/8' CSG PT TVD=3000 T~D'3504 DEP'1325 COLVILLE TVD=3050 T~D=3582 DEP"1385 AVERAGE ANGLE 50 DEG 7 HIN K-5 TVD=4376 THD=5650 DEP=2971 T/ ZONE D TVD=5941 THD=8090 DEP=4844 T/ ZONE C TVD=5948 THD=8101 DEP=4852 T/ ZONE A TVD=5960 THD=8120 DEP=4867 TARGET CNTR TVD=5987 T~D=8162 DEP=4899 B/ KUP SNDS TVD=6026 T~D=8223 DEP=4945 TD (LOG PT) TVD=6154 THD=8423 DEP=5099 I 1000 I I I I ooo ooo REC I VEI) sooo VERTICAL SECTION OCT 0 5 ..~'1 Alaska 0il & Gas Cons. Commission Anchorage 1 6000 SCALE 1 IN. = 1000 FEET ARCO ALASKA. INC. Pa¢l 3H. Well No, 15 P,"opoaed Kupar'uk FI eld. Nor'th SI ope. Alaeka 4000 3000 _ =, 2000 _ I · -r 1 000 _ O 1000 _ WEST-EAST 5000 4000 3000 2000 I I I TD LOCAT [ ON, 14.20' F~[.. 1147' FWL SEC. 2. TI2}1. RSE TARGET CENTER TVDm$987 TIII)-8162 DEP-489,~ NORTH 2452' WEST 4241 TARGET LOCATION~ 1320' FSL, 1320' FWL SEC, 2. T12N. R8E 1000 I 1000 I SURFACE LOCAT l ON ' 1132' FNL. 281' FWL SEC. !2. T!2N. R8E 300 ; : 200' 1,00 1~00 2;00 : 4OO I I - I _ I I - I 400 · , 300 ~°'-2200 c~ 'c,..) oc' 300 200 I lO0 I "1,.600 I ~' 1600 300 000 '~,OOooo 200 1 000 ~oo,o , i00 0 100 I I lO0 200 I I 200 300 I 4OO I .500 I 300 I 400 I 500 KUPARUK RIVER UNIT 20' DIVERTL: R SCHEHATIC II I DESCRIPTION 1. 16" CONOUCT0g 2. FMC SLIP-ON WELD STARTING HEAD 5. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16' 2000 PSI BALL VALVES 4, 20" 2000 PSI DRILLING SPOOl. W/10" OUTLETS 5. 10" HCR BALL VALVES W/10' DIVERTER LINES, A SlNOLE VALVE 0I~ENS AUTOIqATICALLY UPON CLOSURE OF ANNULAI~ PI~EVENTER. VALVES CAN BE REMOTELY CONTROl. LED TO ACHIEVE DOWNWINO DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., REQUESTS APPI::IOVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION i 2 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2, CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWlq~IND DIVERSION. OmmO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES JG 11-3-86 ii 7 , 6 5 4 2 > > BOP STA~O( ACCt. M.I_ATGR C~ACZTY TEST !~r-5/8' B(]= STAC~ TEST I. FILL I~P 8'rN:x N~) Q. EKE ~ WTrH AqcTIC DIESEL. ~Y ~~. ~T ~ ~ ~ LI~ V~ ~TO~~ ~~ 4. ~~TO~I~~F~ I0~ I~ ~~TO~~I ~~F~ I0~ ~ ~ TO 0~I, LZ~ V~. ~ T~ PI~ ~ ~~ V~ ~ ~ ~ ~ LI~. 7. ~I~ ~TI~ ~ V~, LI~, ~ WI~ A ~I L~~~~I HI~ ~ ~ 8. ~ TOP PIPE ~ AN~ CLOSE BOl'rC~ PIP~ RAMS. TEST BOTTC~ PIPE RAM5 TO 250 PSI AN~ 3000 PSI. 9. ~ BOTTCM Pll:~ ;~.~o BA(]( CUI' RLI~IIN~ JT ~ I0. Cl.C~E BLII~) ~ AN) TEST TO ~ PSI AN~ ~ PSI. II. ~ BLII~ RN~IB AJ~ I~TRIEVI[ TE.b"T F~.UG. N~ ~ MANIFCt..D N~ LII~.S ARE I=IJ.L OF ~ING FLUID. SET ALL VALVES IN ORILLING PO6ITI~N. 12. TEST STRIPE VN.VESo I~JLY, ~ Iy ~o DRILL PIPE SAFE'~ VALVE,, AJ~D INSISE BCP TO 250 PSI A~ 3000 PSI. ~3. RECCI~ TEST I~I:'CIRI~TION ON BI..CeM3JT ~ I'EST FOlio SIGN, ~ ~ TO C~ILLINO ~ISCR. 14. PI~F~ ~ ~ TEST ~ NIF~LING UP AJ~ WEEKLY ~ ~IONAU.Y ~l'[ ~ DAILY REV. GENERAL DRILLING PROCEDURE KUPAItUK RIVER FIELD DEVELOPHENT WELLS I. Hove in tis. 2, In~tall Tankco divercer system. Drill 12~!' hole co 9-5/8" surface casin$ point accordin$ co direc~ional Run and ce~enc 9-5/8" 5. Install and t~sC blow ouc preventer. Test casin~ co 2000 psis. 6. Drill out c~nt and 10~ ney hole. Pe~om 7. Drill 8¥~ hol~ Co ~o~in~ point accordin~ co dir~cCio~l plan. 8. Inn open hole loss. 9. Continue drilli~ 8~** hole co p~ov~de 100' baleen PlUS back cecil depth end boCC~ of Kupe~k 10. ~u ~d c~n~ 7" ceoins. Pressure eeoc co 3500 psiS. Il. D~queeze ~c~ic Pack and ceMn~ ~n 7" x 13. Secure wll a~ release tiS. ~ ~oed hole loss. 15. ~e ~ ~r~er Fir. Nipple up bl~ ~c pr~eu~er. 16. Pick up 7' casins scraper ~d c~~, ~rip ~ ~le co plus back ~o~al depth. Circ~ce hole ~ch cle~ brine ~d ~ip c~~ ba~. 17. Perforate nd ~n c~leci~ asee~12, oe~ ~d eeoc pacbr. 18. Nipple d~ bl~ ouc p~eveu~er and ~scall ~ ~ree, 19. ~se over ~o diesel. 20. FI~ ~11 ~o ca~s. Shu~ in. 21. Secure well and release ris. 22. Fracture DE~R HUD CLEANER SHALE STIR :~TIR STIR SHAKERS HUD CENTRIFUOE CLEANER TYPICAL HUD SYSTEH SCHEHATIC LWI~4 / ih , Alaska Oil & p_a_s._C~ns' Commissi,:., 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 AP1 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drillin~ Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit'Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Alaska Oil & Gas Cons. Commissiort Anchorago 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 line wing valve swab valve master valve pad center lplan-vieW] actuator valve I line g. I. valve psi gauge I. adaptor swab valve wing valve~ flow'cross actuator valve Kuparuk Well-head Orientation ARCO ALASKA, INC. VR plug-. master valve well line , L valve View from Pad Center 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 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 ARCO Alaska. Inc. is a Subsidiary of AllanticRichfieldCompany 1t · III ALL WELLS LOCATED IN SEC. 12, T. 12 N., R.8 E., UMIAT MERIDIAN. ASPs 'X' 6,000,110.73 6,000,135.51 6,000,160.57 6,000, 185.28 $,000,210.66 6,000,235. 50 6,000,260.34 6,000,Z85.B2 6,000,310.30 6,000, 3 35.43 6,000,42 5.37 6, 000,450.51 6,000,475.46 6,000, 500.41 6,000, 525.44 6,000, 550.46 6,000,575.45 498,655.44 498,655 A3 498,655.39 498,655.43 498,655.47 498,655.40 498,655.4 I 498,655.44 498,655.45 498,655.44 4 98,655.44 498,655.38 498,655.42 4 98,655.43 498,655.41 498,655.47 498,655. 55 498,655.59 6,000,650.45 6,0 00,675.40 6,000,700A2 498,655.49 498,655.63 49 8,655.73 LATITUDE 70° 24 '41.531" 70° 24'41. 775" 7 0° 24'42.022" 70~ 24' 42 ~6¢,: 70° 24' 4;) .514 70 24'45.003 70 24' 43.494, 70o24'43.741' 70°24'44.626' T0O24'44.875'' 70o24' 45.119" 70 24' 45.610 70024'45.856" ?0024'46.102'' 70024'46348' 70o24'46.840" 70°24'47.085" 70024'47. 331 '° LONGITUDE J 150° 00' 39.4~6"1 150000' 39.417~ 150° 00' 39.418' 150° 00' 39.417" ~5oo oo', 150° O0 39.418 150° 00' 39.417" 150° 00~ 39.41Y' 150° O0 39.417" 150° O0' ~9.418" 150o 00'39.42d' 150° 00'39.419" 150° 00'39.419 150° 00' 39.419 150°00' 39.417' 1 50000'39.415" 150000'~9.4~' 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 NY SUPER¥1SlON,AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 6/9/87. I AM PROPERLY W ; ·.: 497---H VICINITY MAP S~..ALE I", 2MILES NOTES I. ALL COORDINATES ARE AS.P., ZONE 4. 2. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE B.P.M.S.L. 4. REFER. FIELD BOOK L-67-19,35-44 ~ L-~7-11, 5. 0.43. ELEVATIONS FROM CED-RIXX- 3471,t~ 6. HORIZONTAL POSITION 6ASEDON 3H CONTROL MONUMEI~fI~ L~U~GURY' [~st £N.L. ~la~ka Oil 522', 49 7, 472, 446 422', 397' 371' 347' 322' IZ32' 1207' 1182' II07' 1082' 1057' 1007' 982' 957' D ,t r'w:L:! O.G. Elev. G~C'o,s. Co,miSfit'. ^m~draoe / 34.o' 2B,:" / 33.9: gel, I 33.8, 281 / 337 281' ' 33,7; 28~' 33.6 ~81' 33.6: 281', 33.6, 281 33.6 28 I' 281' 281' 20~', 281' 262' 262' 282' 282' 282' 33.7' 33.8' 33.8' 33.8', 33.8 33.8' 33.8' 33.8' 33.9' $3.9' 33.9' ARCO Alaska Inc. KUII~RU K P~OJ'ECT Pod Elev._ 38.8' 38.8' 38.7~ 38.7 36.6' 3e.e'. 38.9 38.6, 38.6 38.7' 36.6' 38.8' 38.71 38.7 38.7' 38.8' 38.~' $8.7' $8.6' 58.6' D.S. 3 H - WELL CONDUCTOR AS-BUILT PREPARED BY LOUNSBURY I& Associates ANCHORAGE ALASKA_ DWN BY: PJW J CHK BY: JWT __ (8) (3) A~d.n ~./~),~ (9 r. Lnzu (4) (14 rlnr~ 22) 2. Is ~ rD be locaued in a ~da~.ued pool ............................. ~ ~. Is well locauad proper d~uance ~m properuy line .................. ~ ~ 4. Is well locaued p .~ d~uance ~=-cm ouhar w~]-~ .., ................. (~, , 5. Is sufficienu umdeiicaued a~eage av~]~hle in rlzis pool ............ ' .... ~ , , 6. Is well to be deviated and .is w~3lbore plau ina!~d ................ ~' 7. Is operator the only affected part7 ................................. 8. Can tm~: be anoroved before fi~~-~ wai: ...................... 9 Does .operator hav~ a bond in force 10. ~ a c~~~ o~ ~~d ...................................... 1! ~ a~~~ ~~-~e~d 16. ~ ~~ c~~ ~e~ ~ ~~~a 19. ~ ~ ~~ ~ a~~ s~e~ 20. ~ ~s~ ~ be~d o~ ~ ~. ~ old ~ore ~~u ~ce~e ~~d ~ 10-403 ............ " (29 rfnru 31) 24. Is the d~J~ling fluid progrsm s~~uic and lisu of equ~. u admquaUe ~ . 25. Are necessary d~ and das~--ipuions of diverzar and BOPE arza~d. ~ .... 26. Does BCZE have inefficient: pressur~ rat/nE - Test: 1:o 3 ooo psig .. ,w~ 27. Does fha choke manifold comply wtAPI RP-53 Gwmy 84) .................. ' ' 28. Is the presence of ~S gas probable ................................. _ . For ex~lorauo=y and S~-auigrzphic w~lls: 29. Ar~ data presenrad om pot:m'~.tial overpr~sur~ zones? ................. /i/ 30. Are seismic ~lysis dar. a presenr~d on sb~ll~ gas zones .... .. ....... _~ ' ' 31. If an offshore loc., are ~ resulrm of smmbed cundi~:ions prasenra~w7- (6) Add: - , rev: 0112B/87 6.011 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 impmve 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. ~ A"F F' :~'111C, t19 ~RI(;!~ :724:6 ~RFVIObS TAPE : ~9~':,;,457T~ :gPI'l' blS,ARCO UNiT TX'PS CATE SIZE CODE ARCO ALASKA, ti';C. 000 000 017 065 3H-15 000 000 005 065 K~JP&R K 000 (')00 008 065 ~E; 00o 000 002 065 12t~ 000 000 003 065 12 000 000 002 065 t'.~ {} R T ~,; S L 0 P F, 000 000 011 065 ,A,[,AS~A 000 000 006 055 t,!~IT TYPE CATE SIZE CODE YPE ?t,;.i'I?, .1'; $(:05,1. 1, Y 'bi. III) I'~")$ $ 9o62b" ~i~ 3t'19' - Bi:l: SIZE = ~.b" TO 8437" 39 $ R?F = 4.61 fa 71 DF 9,5 R~:'~C = 3,95 (0 71 DF <~.~! C3 ~;~a'~ AT BHi' = 2.539 ~ 142 DF Ti;.'~r.':i.iCT!(:)t,:, F!")R~:ATIt:ir~ ~.,,t.,r; 1: ¥ COI~iPENSATED~ RAY TP. RU CASI::'~JG DATA b'A!:I?L~gD F~ ,,5' 8405' '.!'[~7692' 741.0' TI) '1i94' 6810~ '~['0 6594' 6310' TO 6095' 40!.t)' TO ~AT[!~'~ SPECIF'ICATI(3r,i ~L(,,!Cg$ !NB;~i SB;PVICE; SF. RV!CE iJ{~:lT AP.[ APl [Pi at'.'t FICHE SI]Z~; 5P!.., RE;PR PROCESS CODE (OCTAL) 68 00o00000000000 1 68 00000000000000 i 68 000000o0000000 ! 6B 00000000000000 I 68 o0000000000000 1 68 0o000000000000 ! 68 00o00000000000 I 68 00000000000000 i 68 000000o0000000 1 ~8 00000000000000 I 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 88 000000o0000000 I 68 00o000000o0000 1 68 00000000000000 ! 68 00000000000000 a P FmC EPT ~FDC 'EPT ~ALI 'FDC 'EPT IALI '~FDC ~EPT ;P 7ALI ~TMR ~P :AL I :'FDC 845b,bOOf -34.46~b 951. 5000 3,5867 1907. q.424 400,00 'O 0 -35.9362 B,7031 3. 2687 851,3062 ~ 100 0 -63 7813 8 9453 674 OOO0 3 5385 2286 !,382 SFLb RCFT a ,4 lli b DP¢I ¢ C F T 5PLU S F L, U D P t{ I 5 F L U D P H i a C F T SFLU 3 i9 5 ! 7 !. 5 5 0 ! ,9 3 2 !7 543 3 91 2 13 692 4920 .5380 3359 .0422 ,6764 00 (? 0 {~ 011 3750 3594 ~62i9 t:l~ 25 ~'~ 00 0 6898 ' ~ . · 4277 ,4793 , (~16 , 0 0 2 18 486 0, 2it ! 47 2 21 4880' I 1!7 2 2i. 4 o9 4592 7376 5625 3477 332O t523 000 t) 7363 0938 2988 291 f) 5083 000 0 390g 0 o 0 o 2988 291{~ 669~ O~.iO0 I bP T E ~i $ 1 LO T E N S r4phI 1 LO TF,~Xl S I L D T E ~ S P R H 0 N P H I I L D TEf~S aC.t~ T 0 4 0 4 0 4 0 4 0 4 3,~053 1550, O00O 0, I 826 40,9154 it{al.5266 -999.2500 2.941a 0.i074 35,9953 !796.9233 '999,2500 3,6694 4920.000 o -0.007~ 32,412t ~65.2217 7.4493 48 6 O, 0000 0 0063 33,6755 2156.5713 '999,2500 147.5861 34,6~I9 2284.905B -999.2500 !,6370 4592.0000 0 0039 49 ' ,8075 i667.2554 -999,2500 l 68 1 6a 1 68 1 68 1 68 GR i4FDC CFTC TENS CFTC GR ~iFDC TNRA CFTC TENS IbM SFDC CFTC GR CFTC TENS O0000OO0000000 OUO00000000000 00000000000000 00000000000000 00000000000000 O000000000000O 00000000000000 3,6608 9B,0629 864.0000 3 31b0 585:9301 -999.2500 2 9844 103 3750 748 0000 3 1225 600 8047 -999 2500 3 7727 91 0625 548 0000 2 9290 790 1936 -999 2500 7 4158 82 5625 6i0 5000 3 0049 761 6377 -999 2500 96 6219 47 0938 633 0000 3 0676 763 8788 -999 2500 I 6954 117 0000 627 5000 3 8866 453 0930 -999 2500 ~ E P '.1.' 76 O o, 000 ~) S K I.~ (J ; P - 4, 4,2500 (; R :A[,I -999,2500 R?!OB 'FDC -999,2500 DF~I ]NTC -999'2500 TE6.:5 I 5 4624 5 128 2 !4 535 4660 3 199 2 17 <i, 21 ,t. 432 3 -g99 -999 -9:)9 -999 -999 -999 - 999 -999 4 9 '? !,2 632 42?0 5 97 2 t7 567 4!28 2 i45 1.3 549 4 2 28 .9375 .398 4 2547 ;5423 . (i 00 (. .1727 (.) 0 r: i6629 032 ,:.' 009 3750 3613 5035 4525 ,0000 5000 25 ()0 2500 250(:.' 250 {? 2440 ,5000 2500 :2500 ,2500 .250(> ,3~7] I875 4140 9276 0 '00 () 750 o 3594. 6219 0000 7777 1250 0059 7520 0000 G~ I L [., :ILO ~ P H i I LD T E a S t; P H I RC ~.~ T R C i'~ T I L D D R H 1 L I) I LO :':,:! P i-i I {,; a 0,03 52 1.755.9451 -999. 250o 3.3952 4660,0000 0.0190 40,3070 !724.1265 -999.2500 z ,4 '11 ~432,0 (.~ 00 0.0142 47,2706 lb49.444tt '999.2509 3,8!394 4424,0000 '999,2500 '999,2500 -999,2500 -999,2500 4,3q70 4344,0000 '999,2500 -999,2500 '999,2500 -999.2500 4.2775 4220,0000 0.0264 33.6676 2107,0425 -999.2500 5,7237 8,0000 4120.02'I 0 35.3136 2039,8267 -999.2500 2,7728 4228.0000 .0099 !982,921i. 999,2500 G i G R hFDC TNRA CFTC Ib~ GR L~Fi2C CFTC TENS GR i~FDC CMTC TE~S ~FDC T ~ R A CFTC CFTC I CF:tC TENS Ih~i ~FDC CFTC TENS 105 9375 b30.5000 3.8230 479.9702 -999,2500 3 5619 128 5000 603 0000 3 3664 55~ 7981 -999 2500 2 4806 199:3750 617,0000 ~,7539 488,0135 -999,2500 3,8919 -999,2500 -999,2500 '999,2500 '999,2500 '999.2500 I 3978 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 4 4088 97 1875 597 0000 3 0709 70~ 5096 -999 2500 5,5500 97,7500 628,5000 3,0963 668,3519 '999,2500 2 8843 145 1250 611 5000 3 4485 597 6484 -999 2500 68 (,i 0. O 0 u 0 8 F b -75 1250 GR 8 ~ .6328 R ~.t [3 a 3: 27'44 RCFT 2058,93i2 T~:NS ! 11. 250e -999 ' 2500 -999 2%qn 'gq9' ....... -999 ° 250,3 .2509 3.7013 I 12,4 375 -999. 2500 -9~9~ 250(, -999.2500 5,0971 gl , 8750 2,37 ~,,~ q !6.6383 628,~41~ 381 4, 000 4,2501 9 U. 75 0 0 2,3809 ~6 3199 558 96611 379.0 0000 4 O72t lO1 9375 2 3633 !7 385t 554 6569 37S0 0000 4 5789 9q 4375 -999 25OO -999 2500 -999 2500 - 9':i) 9 2500 :',Phi I LO [) P H [} P C r~ T I TE¢~S '4 ? H i I bO TENS D R H O N P H I GR 1 LD RC~,~ T GR ! LD i h D "i; g N $ RCNT {q P H. i 4! 44.0000 -999. 2500 ~'~F'DC - 9 q 9.25 O 0 I' !~! a A -999. 2500 CF'IC -999.2500 3 . 8075 4050.0009 GR -999.25U0 -999.2500 T~.iR h -9o~.2500 CVTC -g99,2500 TENS 3,9580 i bt"! 4064. O00C GR -g99,2500 :'!FUC -999. 2500 T!:,iRA -g99.2500 CFTC -999.2500 TENS 3.8322 I i,.,~'~ 38 l 4,0000 GR 0.0156 N~DC 36.6645 2088. 2754 CFTC -999.2500 TENS 4.0315 3780.0000 0.0!22 NFDC 36,0185 T~RA 1975,5498 CFTC -999.2500 TENS 3.9542 ibh 3760.0000 GR 0.0596 i"SFDC 39.7946 'r~RA 1,984'0!07 CFTC -999.2500 TENS 3.9~53 I.b~i 3784'0000 (iR -999.2500 NFDC -999,2500 TNRA -999,2500 CFTC -999.2500 TENS 3.9425 -999 2500 -99912506 -999,2500 -999,2500 -999.2500 3 8962 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 3.9975 -999.2500 i9992500 999:2500 999.2500 999,2500 ~ 1735 91 8750 611 0000 3 1538 676 8033 -g99'2500 4 0773 98 7500 ~05 5000 3 1941 627 0924 -999 2500 4 0852 101 9375 680 5000 3 3847 624 4642 -999 2500 4,1442 -,999~250o -999~2500 -999;2500 -999,2500 -999,2500 3,9602 -999'2500 -999,2500 -999,2500 > E P T 5 ~;,} 00 00 {) 0 $ F 1,, :,; ;P "' '~3' . -., ,8437 {;R :AL1 -999 2500 RaC. 8 ~FDC -999 25u0 DP'HI ~TF~R -999 2500 RCFT :NTC -999 2500 TENS 3.6244 ILl; 14, 0711 3.8627 112 0625 -9q9 2500 -999 2500 -999 2500 -999 2500 3 87'79 122 i250 -9!:)9 25O0 -999 25OO -9!.)9 2500 -999 2 9358 114 0000 -99'9 25()0 -999 250O -999 7500 -999 25O0 3.20O2 i 38 -999 2500 -999 2500 -999 2500 -999 25O0 4. !, 782 i, 34,5 (.)0 I !., i) P R. H 0 F:C~'gT I D R H {3 RC?~T i l[,! D GR i L D I b 0 -999. 2500 CFTC - 9 q 9,250 () T E i',.~ $ 3.92S5 0.1123 37. 2961 'I r~R ~ 1895,8748 CFTC -9q9.2500 TENS 3.~271 iL~i 3~}24.0000 GR 0.0142 NFDC 36.1525 T~;R A i965.2!83 CFTC '999,2500 TENS 3,922! IL~ 3430. 0000 GR 0.0552 aFDC 2023.2 37 ij CFTC -999,2500 4.1595 3470.0 )(,.. 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