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Home My WebLink About182-211MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 24, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1F-02 KUPARUK RIV UNIT 1F-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2024 1F-02 50-029-20881-00-00 182-211-0 W SPT 5791 1822110 1800 2400 2400 2400 2400 460 2010 1965 1950 REQVAR P Kam StJohn 6/12/2024 MITOA to 1800 psi Per AIO 2C.059 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 1F-02 Inspection Date: Tubing OA Packer Depth 773 863 855 863IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240614072846 BBL Pumped:1 BBL Returned:0.8 Wednesday, July 24, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9MITOA AIO 2C.059 James B. Regg Digitally signed by James B. Regg Date: 2024.07.24 14:13:58 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 24, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1F-02 KUPARUK RIV UNIT 1F-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2024 1F-02 50-029-20881-00-00 182-211-0 W SPT 5791 1822110 3000 2400 2400 2400 2400 484 658 674 681 REQVAR P Kam StJohn 6/12/2024 MITIA to Maximum Anticipated injection pressure Per AIO 2C.059 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 1F-02 Inspection Date: Tubing OA Packer Depth 770 3310 3220 3220IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240614072540 BBL Pumped:2 BBL Returned:2 Wednesday, July 24, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 99 9 9 99 9 9 9MITIA AIO 2C.059 James B. Regg Digitally signed by James B. Regg Date: 2024.07.24 14:11:58 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1F-02 KUPARUK RIV UNIT 1F-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 1F-02 50-029-20881-00-00 182-211-0 W SPT 5791 1822110 1800 2625 2625 2625 2600 630 2000 1950 1930 REQVAR P Austin McLeod 6/6/2022 Two year OA to 1800. AIO 2C.059. 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 1F-02 Inspection Date: Tubing OA Packer Depth 850 920 920 920IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220606191730 BBL Pumped:1 BBL Returned:1 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 OA to 1800. James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 15:57:12 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1F-02 KUPARUK RIV UNIT 1F-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 1F-02 50-029-20881-00-00 182-211-0 W SPT 5791 1822110 3000 2625 2600 2625 2600 660 820 840 840 REQVAR P Austin McLeod 6/6/2022 Two year to MAIP. AIO 2C.059. 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 1F-02 Inspection Date: Tubing OA Packer Depth 830 3300 3210 3195IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220606191327 BBL Pumped:2.1 BBL Returned:2.1 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 9 9 99 9 9 AIO 2C.059. James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 15:55:14 -08'00' MEMORANDUM TO: Jim Reggo . / P.I. Supervisor ` FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 8, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhdlips Alaska, Inc. 1F-02 KUPARUK RIV UNrf 1F-02 See: Inspector Reviewed By: P.I.n Supry ��!— Comm Well Name KUPARUK RN UNIT IF -02 API Well Number 50-029-20881-00-00 Inspector Name: Austin McLeod Permit Number: 182-211-0 Inspection Date: 6/7/2020 Llsp Num: mitSAM200607202256 Rel Insp Num: Packer Depth Pretest Initial IS Min 30 Min 45 Min 60 Min Well IF -02 - Type Inj I w • TVD 5791 - Tubing 1900 1900 • 1900 - 1900 PTD 1822110 Type Test SPT Test psi 3000 - IA ago 3300 - 3280• 3280 BBL Pumped: 2.7 BBL Returned: 2.7 - OA 110. 220 220 - 220 - Interval RaQVAR P/F P Notes: 2 year MIT -IA to MAIP as per Alf) 2C.059. Monday, June 8, 2020 Page I of 1 MEMORANDUM State of Alaska Insp Num: mitSAM200607202513 Alaska Oil and Gas Conservation Commission To: Jim Regg P.I.Supervisor 1 \ � I I �w DATE: Monday, June 8, 2020 SUBJECT: Mechanical Integrity Tests ConomPhillips Alaska, Ie. Packer 1F-02 FROM: Austin McLeod KUPARUK RiV UNIT 1F-02 Petroleum Inspector Type Inj W - Sra Inspector 5791 Reviewed B�, P.I. Sopry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IF -02 API Well Number 50-029-20881-00-00 Inspector Name: Austin McLeod Permit Number: 182-211-0 Inspection Date: 6/7/2020 Insp Num: mitSAM200607202513 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1F-02 Type Inj W - TVD 5791 Tubing 1900 - 1900 - la90 - 1890 - PTD 1822110 • Type Test I SPT Test psi 1800 IA 509 612 618 623 BBL Pumped: 1.7 BBL Returned: 1.4 OA 110 2010 1930 1910 Interval REQVAR P/F P . — Notes: 2 year MIT -OA as per AIO 20.059. w' Monday, June 8, 2020 Page I of I • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Wednesday, February 21, 2018 6:56 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 1F-02 (PTD 182-211) Report of suspect annular communication Attachments: 1F-02.pdf; 1F-02 90 day TIO trend 2-21-18.JPG Chris, KRU WAG injector 1F-02 (PTD 182-211)was reported today by Operations after bleeding the OA when it neared DNE. Upon further review of the TIO trends there appears to be a very slow OA pressure build up. DHD will perform standard initial diagnostics after which the well be placed on an extended 60 day monitor due to the slow nature of the OA pressure build up. The proper paperwork for continued injection or corrective action will be submitted upon the completion of the monitor period. A 90 day TIO and wellbore schematic are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 WELLS TEAM Gongxamps , 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,August 08,2016 TO: Jim Regg e C I0t1 SUBJECT: Mechanical Integrity Tests P.I.Supervisor ( i g y CONOCOPHILLIPS ALASKA INC 1F-02 FROM: Bob Noble KUPARUK RIV UNIT 1F-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 2-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1F-02 API Well Number 50-029-20881-00-00 Inspector Name: Bob Noble Permit Number: 182-211-0 Inspection Date: 8/1/2016 Insp Num: mitRCN160801171211 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 1F-02 w 5791 185 1850 1850 • 1850 - Well - Type Inj TVD Tubing� PTD 1822110 Type Test SPT Test psi 1500 - IA 842 2620 - 2540 1 2530- 1 Interval 4YRTST PAF P OA 570 600 -I 600 600 - 1 Notes: SCANNED MAY I 0 2017 Monday,August 08,2016 Page 1 of 1 s MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg j DATE: Friday,June 17,2016 P.I.Supervisor h l �1 ! /° SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IF-02 FROM: Matt Herrera KUPARUK RIV UNIT IF-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1F-02 API Well Number 50-029-20881-00-00 Inspector Name: Matt Herrera Permit Number: 182-211-0 Inspection Date: 6/15/2016 Insp Num: mitMFH160616143546 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1F-02 - Type Inj N` TVD 5791 - Tubing 2220 - 2220 ' 2220 - 2220 PTD 1822110 " Type Test!SPT Test psi 1500 IA 400 1730 - I 1680 - 1670 .- I Interval 4YRTST P/F P ✓ OA 300. 300 300 300 - i______ Notes: SCANNED DEC 2 9 2016 Friday,June 17,2016 Page 1 of 1 • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Thursday, October 01, 2015 2:07 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report of unexplained IA pressure rise 1F-02 (PTD 182-211) 10-1-15 Attachments: 1F-02 schematic.pdf Chris, Kuparuk WAG injector 1F-02 (PTD 182-211) is experiencing an unexplained rise in IA pressure. The well has been on gas injection since 9-11-15. Yesterday a bleed of the IA was performed when the pressure neared the DNE of 2400psi. There has been a fluctuation in injection rates in the last week and the pressure rise may only be a delayed response to that increase in heat throughput. Therefore to minimize any further disruption in the wellbore thermal regime, initially there will only be additional bleeding of the IA as necessary and packoff testing performed. The well will be monitored for 30 days on gas injection. If the well continues to exhibit signs of communication, an MITIA will be performed and the well will be WAG'ed to water injection for 30 days to ensure communication is only present when on gas injection, in anticipation of an AA submittal. A follow-up email will be provided at the conclusion of the diagnostic monitor period. Please let us know if you disagree with the plan. Attached are the 90 day TIO plot and schematic. SCANNED AUG 0 4 2016 Well Name 1F-02 Notes: Start Date 71312015 Days 90 End Date 10/112015 4S0C - — 15 WHP Annular Communication Surveillance "CC - 13 12 3000 — 11 2E00 — 10 2CH 12-1E0C — 80 1000 — 70 E00 = 60 0 EO Jun-1E Jul-15 Jul-15 Jul-15 Aug-15 Aug-15 Aug-15 Sep-15 Sep-15 Sep-1E Oct-1E Oct-15 F - Jun-1E Jul-1E Jul-1E Jul-15 Aug-15 Lug-15 Aug-15 Sep-1E Sep-15 Sep-15 Oct-15 Oct-15 Date Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager(907) 659-7000 pgr 909 2 • • • ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, AUISKA 99510-0360 March 18, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: 4 ~~ -~~_ ~~~ ~~~ ~S ~pP~ p eeOF$pfv~3~a~idlE i~a-air ~~ - ~ ~-. Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped February 13~', 2009. The corrosion inhibitor/sealant was pumped March 4~', 11 ~' & 16~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Pen, ~~~.,~~~ ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/16/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1F-01A 205-029 7" N/A 7" N/A 1.7 3/16/2009 1 F-02 182-211 SF N/A SF N/A 2.90 3/4/2009 1 F-03A 196-096 SF N/A SF N/A 2.20 3/4/2009 1 F-04 182-172 20" N/A 20" N/A 5.20 3/4/2009 1F-05 182-132 SF N/A SF N/A 1.60 3/4/2009 1F-06 182-145 SF N/A SF N/A 2.10 3/4/2009 1 F-07 182-156 SF N/A SF N/A 2.40 3/4/2009 1 F-08 182-162 SF N/A SF N/A 2.20 3/4/2009 1 F-10 183-105 20" NA 20" NA 1.70 3/11!2009 1F-12 183-136 54' 7.50 5'6" 2/13/2009 18.70 3/11/2009 1F-13 183-144 SF NA 6" NA 1.30 3/11/2009 1F-16A 201-209 SF NA 22" NA 1.70 3/11/2009 f Ci I ~ ~C~11~~1'~' N0.5105 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description a 1, b , ;~ 02/23/09 ;1-=• u ~ .=a ~ ~. Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2B-06 AYS4-00031 INJECTION PROFILE ~ - ( (p l 02/02/09 1 2A-26 B04C-000011 SFRT O ~ 02/14/09 1 3F-07 AZED-00009 INJECTION PROFILE ~ 12/26/08 1 1 F-02 B04C-00010 INJECTION PROFILE-: 02/13/09 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~J ,, ,.-- Toy Jim Regg i' P.I. Supervisor ~~~~~ ~(~lU''~' FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 11, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IF-02 KUPARUK RIV UNIT 1F-02 Src: Inspector NON-CONFIDENTIAL Reviewed By: ~ 2 P.I. Suprv ~j. Comm Well Name• KUPARUK RIV UNIT 1F-02 API Well Number 50-029-20881-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ080610115308 Permit Number: I8z-2t t-o i Inspection Date: 6ili2oo8 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ' IF-oz Type Inj. ~' ~ TVD r sas I I Iso I 3000 ~ ~ z96o ~ z9so p: ~ I s22 t to Iso TypeTest SPT I Test ps' ~ I soo A ~, Iso t so Iso I t 4YRTST P % Tubin ~ 2400 I 2400 ~ Interval P/F ~__-- g ' ._ I I 2400 2400 ! ~ i ~ Notes' I.6 BBLS diesel pumped; no exceptions noted. ___ _ _ __ !t}t~ ', ~GCC CalLc~~i%~,I~s ~~es,1'Ce~ T4'~ _ ~71~1 `~ t rp-C;~-t ~~S ~/ c>~ ~,'RC:Ir<~ ~ G~ ~~ C 1 ,~ t~ Sv~~~ M 1 ~, ' r ' ,{ /~~ ~,.~ ~UL ~. ~ 2Q~U Wednesday, June I I, 2008 Page I of I MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg ~q 7('?>t 107 P.I. Supervisor ( t DATE: Friday, July 20, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1F-02 KUPARUK RIV UNIT IF-02 Src: Inspector .;~\ \ \Cö?f FROM: Bob Noble Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv,.Jl~J!-- Comm Well Name: KUPARUK RIV UNIT IF-02 API Well Number: 50-029-20881-00-00 Inspector Name: Bob Noble Insp Num: mitRCN070719102817 Permit Number: 182-211-0 Inspection Date: 7/15/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. i IF-02lType Inj. i /1 I --------¡ - -,------ Well I G TVD 5783 IA I 1200 I 1980 1980 I 1980 I 1/ I I -- P.T.DI 1822110 ITypeTest I SPT Test psi 1980 '10A 240 I 250 250 I 250 I I I - ; I I Tubing I 1 2860 2860 2860 1 2860 , Interval 4YRTST -rr'" P ,/- I 1"1 I - I Notes: ¡Ù~ PetC /4:;- ÒeptÍì l n/~) 6ÙÚL!iLfeS uJe Ll C{'wI(Jl¿h~~... ~~'-<+- (lvlJ- ~ fC>Ch-t~~ . I . ~ ..J-e+ prtC;5b~"e- b ~ '?r1ù ì (,?:\v, S"iNVê¿' J SCANNED AUG 0 6 2007 Friday, July 20, 2007 Page I of I Schlurnberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well Job# ¡<¡1..¡//1F-02 195 ""011- 2T-23 :;- 2W-12 I~'f ¿z.l(- 2Z-19 / f8 -/?;o 1 C-111 )f;¡--12.. <i 1 C-117 )...e{- 1'2.. { 3F-14 I 8'5- :2.72 2K-07 <:iJ 2Z-12A I 0 f.., 07 ( { 15-/rf% 10922513 10952507 10942806 10922502 10922504 10922505 10922499 10922503 10922501 Log Description Date 12/23/04 NO. 3292 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk -' BL Color CD INJECTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE LEAK DETECTION LOG INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE LEAK DETECTION LOG 12/14/04 12/08/04 12/15/04 12/04/04 12106/04 12106/04 12/03/04 12/05/04 12104/04 1 1 1 1 1 1 1 1 1 --- S'GNd ~ t};[~ SCANNEr þ,PP. 1 5 l005 DATE: f3f; Please sign and return on(opy of this transm iltal to Beth at the above address or fax to (907) 561-8317. Thank you. Mike Mooney Wells Group Team Leader Drilling & Wells ConocJP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 January 26, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1 F-02 (APD # 182-211) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 1 F-02. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, )A,M~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVE:[1 FEB 0 3 2004 Alaska Oi\ & Gas Cons. Comïni::',sqon Anchorage 1~)CÂfNj~EIJ FEE 1 8 200~~ OQIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED FEB 0 3 2004 Abandon D Suspend D Alter Casing D Repair Well 0 Change Approved Program D Pull Tubing 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 115' REPORT OF SUNDRY WELL OPERATIO~~ I n' ~ r"' ~^ ," r"~"I~i~~¡nn Perforate D M!a;)I\i."V~~ia~qßu"'hl~ ÅnnUlarDisp. D Ant ge Stimulate D Time Extension Other D Re-enter Suspended Well D 5. Permit to Drill Number: 182-211 1303-169 6. API Number: 50-029-20881-00 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Status: Development D Stratigraphic D Exploratory D Service 0 1. Operations Performed: 8. Property Designation: ADL 25652, ALK 2578 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURF CASING PROD CASING Perforation depth: measured 8085' feet true vertical 6291' feet measured 7795' feet true vertical 6126' feet Length Size MD 80' 16" 80' 2214' 10-3/4" 2329' 7948' 7" 8063' 9. Well Name and Number: 1 F-02 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Burst Collapse 80' 2224' 6279' Measured depth: 7481'-7539',7696'-7772',7842'-7856' Intervals treated (measured) true vertical depth: 5944'-5978',6069'-6112',6152'-6160' N/A Oil-Bbl Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations _X - Aras Worthington @ 265-6802 ZJMO~~ Form 1 0-404 Revised 2/2003 . Tubing (size, grade, and measured depth) 3-1/2" , J-55 1 L-80, 7659' MD. Packers & SSSV (type & measured depth) pkr= Baker FHL Retr., OTIS 'RH' RETR.; OTIS 'WD' PERM W/MILLOUT EX. set @ 7215', 7325'; 7627' SSSV= Cameo 'OS" NIP set @ 528' 12. Stimulation or cement squeeze summary: 13. Treatment descriptions including volumes used and final pressure: Casina Pressure Tubina Pressure Representative Daily Average Production or Injection Data Gas-Met Water-Bbl - 1700 - 2200 15. Well Class after proposed work: Exploratory D Development' D Service 0 16. Well Status after proposed work: OilD GasD WAGD GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Printed Name Signature - - - WDSPLD Title Phone Wells Group Team Leader. , I Date // Z /0 ~/ PreDared bv Sharon AllsuD-Drake 263-4612 nD1 ~'J\,' .^\' -- BFl ÆB 0 .:~ 200~ SUBMIT IN DUPLICATE ConocoPhillips Alaska Page 1 of 2 Operations Summary Report Legal Well Name: 1 F-02 Common Well Name: 1 F-02 Spud Date: 12/28/1982 Event Name: WORKOVER/RECOMP Start: 11/21/2003 End: Contractor Name: Nabors38CompanyM @conoco Rig Release: 11/25/2003 Group: Rig Name: Nabors 38 Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 11/21/2003 16:00 - 21 :00 5.00 MOVE MOVE MOVE Rig Released from 1 D-12 @ 1600 hrs. Rig down, scope down, and lay down derrick. Prep for rig move. Move pipe shed and pits away from rig carrier. Move rig carrier off well. Remove old FMC tree, BOPs, Herculite, and mats. 21 :00 - 23:30 2.50 MOVE MOVE MOVE Move rig and camp/office from 1 D to 1 F-02. (6.2 miles.) 23:30 - 00:00 0.50 MOVE MOVE MOVE Set office/camp. Set mats. Prepare to spot carrier. 11/22/2003 00:00 - 06:00 6.00 MOVE MOVE MOVE Set camp/office. Set mats. Move 400 bbl tank. Lay down Herculite. Move carrier over well & level same. Move pipe shed and pits into place. 06:00 - 16:00 10.00 WELLSR NUND RIGUP Prep rig for well. Pre-spud meet. Pull BPV. Pull Tree. Begin assym. of BOP's. Prep for Bop test. Load pits. 16:00 - 16:15 0.25 WELLSF SFTY RIGUP Pre BOP test meet. 16:15 - 23:00 6.75 WELCTl BOPE DECOMP Bop test. State waived. Mr. Chuck Scheve. 23:00 - 00:00 1.00 CMPL TN RURD DECOMP Prep to install landing joint for tubing extraction. 11/23/2003 00:00 - 01 :00 1.00 WELLSF RURD WRKOVR Blow down lines. Pull blanking plug. LD test joint. Pull BPV. 01 :00 - 03:00 2.00 WELLSF RURD DECOMP MU landing joint with TIW valve and circulating hose. 03:00 - 04:30 1.50 WELLSF OTHR DECOMP BOLDS. PU on hanger and pull up to maximum pull of 122K#, no go pulling SBR barrel free. Work pipe up & down. Hold maximum pull at 122K# for 40 minutes. Work pipe, all no go to pull SBR free. 04:30 - 07:30 3.00 LOG RURD WRKOVR LD 31' landing joint. MU 22' landing joint, Baker Lok 3 pups to allow RU for chemical cut close to rig floor. MU full opening TIW valve. PJSM. RU SWS. MU pump in sub and packoff. Hang sheaves. (Check OA = 150 psi). 07:30 - 11 :30 4.00 LOG ELOG WRKOVR MU & RIH with 12' string shot. Fire string shot across area to be cut, middle of joint between SBR and GLM. POOH. 11 :30 - 12:30 1.00 LOG RURD WRKOVR LD sheave on rig floor. PU on string to 122K#, no go. Work pipe, no go. PU and hold 15K# overpull on slips for chemical cut. 12:30 - 17:30 5.00 LOG ELOG WRKOVR PU sheave in blocks. PJSM on chemical cutter. MU 2-5/8" Chemical cutter & RIH. Cut tubing at 7264', in middle of joint between SBR & GLM, approx. 15' top stub. Good indication in E-line unit and on rig floor of cut. POOH, recovered all cutter tools. 17:30 - 18:00 0.50 LOG RURD WRKOVR LD cutter tools. LD sheave on rig floor. 18:00 - 19:00 1.00 LOG RURD WRKOVR Pull tubing hanger to rig floor. Got clean cut, no overpull. 63K# PU weight of string. LDLJ. LD tubing hanger. MU TIW valve and circulating line on tubing. RD SWS. 19:00 - 21 :00 2.00 WELCTl CIRC DECOMP Circulate on hole volume and balance brine weights. 21 :00 - 00:00 3.00 CMPL TN PULD DECOMP Begin pulling pipe. up wt = 63,000#. Hole condition is static. Begin spooling up control line. Set down 1 st joint with space out pup in pipe shed. Space out joint is cross over. 11/24/2003 00:00 - 04:00 4.00 CMPL TN PULD DECOMP Continue pulling pipe to surface. Strap and rabbit with 2.867" drift. Top setion unable to drift with 2.91" drift due to small amount of scale in pipe. DISPLACEMENT = 3 BBLS every 10 stands. Currently at stand #70. Released Haliburton Completion services after removing SSSV. 04:00 - 05:00 1.00 CMPL TN PULD DECOMP Called KCS for confirmation on supplies. Currently at stand 90. 05:00 - 06:00 1.00 CMPL TN PULD DECOMP Continue to pooh with current completion. starting to see signs of corrosion. Discuss procedures if pipe becomes to bad to set in slips. 06:00 - 09:00 3.00 CMPL TN PULD DECOMP OOH. Inspect chemical cut and mic. Pipe currently 3.6" O.D. Found one hole aprox 1/2" O.D. in jt# 225. 09:00 - 12:00 3.00 CMPL TN PULD DECOMP Begin RIH. Inspect 35 stands of tubing. 12:00 - 14:30 2.50 CMPL TN PULD DECOMP Lay down 70 JTS. of bad tubing. (35 stands). Send pictures to town. 14:30 - 17:00 2.50 CMPL TN PULD DECOMP Clear pipe shed / Begin loading with L80 & J55. Stap tubing and drift. Prep for new pipe tally. 17:00 - 18:00 1.00 CMPL TN TRIP DECOMP Begin to rih with PBO, Camco 2.812", w/ RHC Plug in place, Nipple, Printed: 1/20/2004 11 :34:58 AM ConocoPhillips Alaska Page 2 of 2 Operations Summary Report Legal Well Name: 1 F-02 Common Well Name: 1 F-02 Spud Date: 12/28/1982 Event Name: WORKOVER/RECOMP Start: 11/21/2003 End: Contractor Name: Nabors3SCompanyM @conoco Rig Release: 11/25/2003 Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 11/24/2003 17:00 - 18:00 1.00 CMPL TN TRIP DECOMP and Baker PBR with PKR. Final completion string. 18:00 - 00:00 6.00 CMPL TN TRIP DECOMP Continue to run completion. Will slow down when we reach 6,200' due to possible scale issues. 11/25/2003 00:00 - 02:00 2.00 CMPL TN TRIP CMPL TN Continue ot RIH with new completion. monitoring liquid level, along with O.A. press. Current O.A. pressure = 145#. 02:00 - 02:45 0.75 CMPL TN TRIP CMPL TN PUH for weight check prior to sting over. up wt = 62,000#. Dwn wt = 48,000#. prep to sting over pumping at 2.5 BPM. 02:45 - 03:00 0.25 CMPL TN PCKR CMPL TN Prep to launch ball and rod. Drop and weight 10 ten min. for ball and rod to hit. Set PKR with 2100#. Pressure test tubing to 2,500# for 15 "charted Min". 03:00 - 08:00 5.00 CMPL TN SOHO CMPL TN Pump 20 BBLS inhibited brine for PKR isolation. Begin space out for landing hanger. Measurements = 26.1' Drop joint #79. Set space out pups below joint #78. Space out, drain stack. MU hanger & landing jt. Land completion string - RILDS. 08:00 - 10:00 2.00 CMPL TN DEOT CMPL TN Move kill ine to IA. RU to test tbg & IA. Test tgb to 2500 psi F/15 min. Test annulas T/21 00 psi F/15 min. Bleed tbg press to 0 psi. to shear RP valve. Hook up reverse line to verify RP open. 10:00 - 11 :00 1.00 CMPL TN SOHO CMPL TN Blow down kill line. LD landing jt. & set BPV. 11 :00 - 12:30 1.50 CMPL TN NUND CMPL TN PJSM. Put tree in cellar. ND BOPE & place on cradle. 12:30 - 15:30 3.00 CMPL TN SEOT CMPL TN NU tree. Test adapter flange to 5000 psi. Pull BPV. install tree test plug, test tree to 5000 psi. Tighten leaking flange at bottom of master valve. Re-test tree to 5000 psi. Pull test plug. 15:30 - 20:00 4.50 CMPL TN FRZP CMPL TN Rig up to displace and freeze protect. PJSM. Displace well with seawater. RU Little Red pump and pumped 75 bbls diesel for freeze protect. 20:00 - 22:00 2.00 CMPL TN FRZP CMPL TN Put tubing and annulus into communication with hose. Well still has 25 psi 22:00 - 00:00 2.00 CMPL TN OTHR CMPL TN Rig up lubricator and set BPV. NU flange on wing valve. Clean around tree and cellar. Released rig at 2400 hrs 11/25/03. Printed: 1/20/2004 11 :34:58 AM ConocoPhillips Alaska, Inc. 1 F-02 7483 8085 KRU 1 F-02 500292088100 NIPPLE INJ 1/11/1983 11/30/2003 Size To Bottom TVD Wt Grade Thread 7.000 0 8063 6279 26.00 K-55 10.750 0 2329 2224 45.50 K-55 16.000 0 80 80 65.00 H-40 Bottom TVD Wt Grade Thread 2492 2360 9.20 J-55/L-80 ABM-EUE 7135 5745 9.20 J-55 ISTC MOD 7281 5828 9.20 L-80 ABM-EUE 7659 6047 9.20 J-55 IBTC Zone Status Ft SPF Date 2 4 1/9/1983 C-4,UNIT B 58 20 8/2/1984 UNITB 2 4 8/2/1984 APERF A-5 2 4 11/13/1993 RPERF A-5 A-4 74 12 11/13/1993 RPERF PATCH A-3 14 8 1/9/1983 IPERF 319-7335, e Comment Blast Jt 476-7544, Perf 398-7772) ~~:r .~" ~.: I , ~':~;~I . 'j~ . Ii! !~ I., ' If~t: .. ,1"I__J.11 .' .. : ~~~i, V Mfr V Type V OD Latch Port TRO Date Run 0 10/7/1988 0 107/1988 0 2,10/2000 Vlv Cmnt BK 0.000 BK 0.000 BEK 0.000 ID 2.875 2.990 2.970 2.812 3.750 Otis PERMANENT PATCH SET 1/29/2000 W/AVA NIPPLE AVA NIPPLE Otis 'RH' RETR. AVA ni Ie set 2/28/2000 AVA CII Sleeve set 2/28/2000 - CLOSED Min. ID 1.875" ID 2.813 2.375 2.750 2.970 2.313 2.310 2.992 4.000 2.250 Otis 'WD' PERM w/MILLOUT EXTENSION Otis 'XN' NO GO. Set Nipple Reducer in XN nipple 1/27/2000. Reducer has 2.25" CAMCO D Profile Otis 7659 6047 7660 6048 Generål.Notes Date Note 11/25/200 TREE: FMC ADATPER, NEW 2KM 3-1/8", 5 Ksi TREE INSTALLED TREE CAP CONNECTION: 3" OTIS UNION 1/5/2004 TOP OF PERMANENT PATCH SET IN OTIS SLICK STICK. OD OF PATCH IS LESS THAN 10 OF SLICK STICK- RESULTING IN NO SEAL. ALSO, DIFFICULT TO ENTER. .. ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission \ . J./ ~ 1D 01 TO: JimRegg I(tdt] \ \ DATE: January 19, 2004 P.I. Supervisor { SUBJECT: Mechanical Integrity Test Conoco/Phillips Kuparuk River Unit 1 F-02 FROM: John Crisp Petroleum Inspector NON- CONFIDENTIAL I P P Type Test Interval M= Annulus Monitoring 1= Initial Test P= Standard Pressure Test 4= Four Year Cycle R= Internal Radioactive Tracer Survey V= Required by Variance A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details Water in wellhouse floor appeared to be coming from conductor. 1 discused the water w/WIE for Kuparuk. 1 requested possible water sample test to verify the water was thaw from hot injection well & not injection fluid. Well house needed clean up, Hyd fluid in secondary containment under Hyd SVS panel. see C{~( {\.ee1 ,:Jßf?- 'fu J04 M.I.T.ls performed: ! Number of Failures: .Q Total Time during tests: 2 hours Attachments: cc: ~(;t~NNE[¡) JAN ~~~ ~ 2004, MIT report form 5/12/00 L.G. MIT KRU 1F-02 01-19-04 JC.xls 1/20/2004 RE: MIT IA IF-02, -i. , Subject:RE: MIT IA IF-02, . Frôm:NSK Problem Well Supv<n1617@conocophillips..com> Date: Sat, 24 J an 2004 18:28:06-0900 . . . . . To: J ~1J1~s Regg <j im ~regg@admip.~st~t~:~ak. US~ ". "]' 91I1Maundet;:.A9GÇÇ::,'.:: .'. Jim, Here is a copy of the Lab report from the standing water in the v/ 1F-02 well cellar. The water is mostly fresh, however there are some salts in it from the gravel in well cellar area. I had the gravel removed from around the starting head and followed up with a wellhead inspection by A DHD tech. DHD notes are below. Monitored cellar for fluids (appears to be ground water). T/1/O = 1850/1350/180. Well does not have an open conductor, it has an outer casing hanger. Fluids in cellar appear to be clean water v/ with no visible trace of hydrocarbons which should be present from FP fluids if it was a casing communication problem. I agree with the DHD tech's assessment that the water is coming v'" from the thaw bulb. Which is very reasonable since this well was just brought back on line post rig workover after being S1 for a couple years. . The Hydraulic fluid in the containment was less than a teaspoon in volume and cleaned up before the M1T was completed. Let me know if you require any more information. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: J ame s Regg [~_~..~.l ~S?..:_j--~_~~9.9..@adE1J:n . s_~-~~~ . a~_~§.] Sent: Tuesday, January 20, 2004 1:58 PM To: NSK Problem Well Supv Subject: Re: M1T 1A 1F-02, CMIT 3A-06 Attached is inspection report from John Crisp for KRU 1F-02. He requested a water sample of the water found in the wellhouse¡ he also noted hydraulic fluid in secondary containment under the SVS panel. 1 of2 1/26/2004 8:33 Aìv RE: Mlr IA IF-02, ..:.. t Please provide the results of efforts to address these 2 issues. Jim Regg AOGCC NSK Problem Well Supv wrote: Bob, Attached is the MIT IA data for 1F-02 and the CMIT data for 3A-06 Call if you have any questions. Marie McConnell ConocoPhillips Problem Well Supervisor 659-7224 «MIT KRU 1F-02 01-19-04.xls» «MIT KRU 3A-06 01-19-04.xls» > . . . 1 f-02 glacial ice Content-Description. 012204.xls ,If-02 glacial ice O12204.xls C t t T I' t' nJ d 1 on en - ype: app lca 10 vn .ms-exce Content-Encoding: base64 2 of 2 1/26/2004 8:33 AM ... ¡. .. Kuparuk lab Analvtical Report Sample 1 F-02 Glacial ice melt Analyst Marlon Ash Date 23-Jan-04 Sp Grav Cond Chloride mg/l 0.24 0.17 Sulfate mg/l 8.21 0.35 Aluminum mg/l Boron mg/l 0.01 0.03 Barium mg/l Calcium mg/l 14.33 2.69 Chromium mg/l Iron mgll Potassium mg/l 395 0.82 0.11 Lithium mg/l 0.43 Magnesium mgll 1240 0.03 0.01 Manganese mg/l <0.003 Sodium mg/I 10800 0.15 0.13 Phosphorous mg/l <1 Silicon mg/l <1 0.06 Strontium mg/l 7.2 1.79 0.99 Zinc mg/l Notes Original chloride value reported for first sample was incorrect, Corrected value in yellow Composition of CPF1 PW Tank should be pretty similar to. injected water Values in green are from 2/8/02 BVL analysis Except for the reported chloirde error the two 1 F-02 samples are fairly similar in composition. There are too many salts present to say for sure which of posssible water sources is forming this ice. ConocOPhillips Aras Worthington Wells Group Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6802 June 17, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Operations for 1F-02 and 2N-348 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Operations for the Kuparuk well 1F-02 and the Tarn well 2N-348. The sundry for 1F-02 is to repair an apparent packer leak. We are planning to pull the tubing and stack a packer on top of the existing one and re-run the tubing. The sundry for 2N-348 is to pull the 3.5" tubing and run a 4.5" tubing to increase injection rate. If you have any questions regarding this matter, please contact me at 265-6802. Sincerely, ~.,¢"'~./ ^. Worthington Wells Group Engineer CPAI Drilling and Wells AW/skad RECEIVED JUN ] 9 2003 Alaska 0il Anchorage SCANNED JUL 2, :3 20t)3 ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Annul O~th~e~r./~ 1. Type of Request: Abandon Alter casing Change approved program Suspend FI Operation Shutdown ~] Pedorate Repair well [-~ Plug Perforations [--'] Stimulate Pull Tubing [-~ Perforate New Pool r-'-] [~ Variance C~ r-'l Time Extension ['--] Re-enter Suspended Well [~ 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 4. Current Well Class: Development [] Exploratory [~ Stratigraphic [~ Service [-~ 5. Permit to Drill Number: 182-211 '~ 6. APl Number: :50-029-20881-00 7. KB Elevation (ft): RKB 115' 8. Property Designation: ADL 25652, ALK 2578 9. Well Name and Number: 1 F-02 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): 8085' Total Depth TVD (ft): 6291' Casing Length CONDUCTOR 80' SURF CASING 2214' PROD CASING 7948' Perforation Depth MD (ft): 7481'-7539', 7696'-7772', 7842'-7856' Packers and SSSV Type: pkr= OTIS 'RH' RETR. · OTIS 'WD' PERM. SSSV= Camco TRDP Effective Depth MD (ft): 7780' Effective Depth TVD (ft): 6117' Plugs (measured): ,Junk (measured): Size MD TVD Burst 16" 80' 80' 10-3/4" 2329' 2224' ,1 Perforation Depth TVD (ft): 5944'-5978',6069'-6112',6152'-6160' 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program ~ BOP Sketch 8063' July 15, 2003 14. Estimated Date for Commencing Operations: 6279' 16. Verbal Approval: Date: Packers and SSSV MD (ft) pkr= 7318'; 7618' SSSV= 1807' Tubing Size: 3-1/2" 13. Well Class after proposed work: Exploratory [~ Development [--1 Collapse Tubing Grade: J-55 15. Well Status after proposed work: oil FI Gas I--I WAG [] GINJ Tubing MD (ft): 7652' Service r'~ Plugged [~ Abandoned W NJ [] WDSP, I--I 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Aras Worthington. Signature ~:~ ~ ~" Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Contact: Aras Worthington @ 265-6802 Title: Wells Group Engineer Phone ,,~.~.¢'. ¢~'~2,.~. Date Plug Integrity Other: Subsequent Form Required: Approved by: Form 10-403 Revised 2/2003 · Location Clearance ~ RECE - VED JUN ] 9 2003 BYORDEROF ~ ~/. THE COMMISSION Date:/~¢/~ SUBMIT IN DUPLICATE 1F-02 Proposed Workover Current Completion Proposed Completion 2.875" Camco DS Nipple 6 GLMS Original 3 %" Tbg Stacked Packer 2.812" Camco D-nipple Original 2.75" Camco D-nipple Original Packer PHILLIPS Alaska, Inc. KRU ~1F-02 A Subsidiary ol= PHILLIPS PETROLEUM COMPANY TUBING 1F-02 (C)-765Z APl: 500292088100 Well Type: INJ Angle @ TS: 55 deg @ 7483 0D:3,500, ~ SSSV Type: TRDP Orig 1/11/1983 Angle @ TD: 55 deg @ 8085 ID:2,992) L Completion: Annular Fluid: Last W/O: 10/7/1988 Rev Reason: Format changes b! ImO Reference Log: Ref Log Date: Last Update: 411012002 Last Ta~l: 7780 TD: 8085 ftKB ] .... gl Last Ta~] Date: 10/16/1995String - Max Hole An~le: 55 de, (~ 7200 Casing ALL STRINGS ! Description Size Top Bottom TVD Wt Grade Thread PROD CASING 7.000 0 8063 6279 26.00 K-55 SBR -_ SURF CASING 10.750 0 2329 2224 45.50 K-55 (7290.7291, CONDUCTOR 16,000 0 80 80 65.00 H-40 OD:3.500) Tubing String - TUBING Size I Top Bottom I TVD I Wt I GradeI Thread 3.500 0 7652 6043 9.20 J-55 BTC ABM Perforations Summary Interval TVD Zone Status Ft SPF Date Type Comment 7406 - 7408 5901 - 5902 2 4 1/9/1983 APERF Sqz perf; SOS 4" Squeeze perle 7481 - 7539 5944- 5978 C-4.UNIT 58 20 8/2/1984 RPERF 120 deg. Ph; 5.5" csg PATCH ; B 7610 - 7612 6019 - 6020 UNIT B 2 4 8/2/1984 APERF Sqz parr; SOS 4" Squeeze (7311-7333, OD:3.500) I t perfs t 7696-7698 6069-6070 A-5 2 4 11/13/1993 RPERF 180deg. Ph; 2.5" Titan 7698-7772 6070-6112 A-5,A-4 74 12 11/13/1993.RPERF 180deg. Ph; 2.5" Titan 7842-7856 6152-6160 A-3 14 8 ~ 1'9'1983 IPERF SOS 4" H';'por?t stimulations &;Treatments Interval I Date TypeI Comment 7406- 7408 1/9/1983 Cement 7610 -7612 8/2/1984 Cement Gas iLift MandrelSNalves:: : stI MD J TVD ManIMfr TypeMan J 'V'Mfr JVType J voD Latch Port TRO'j'j Date J VlVRun Cmnt ] ~I i'i~I 1 1. 7252Extended5812pk,q. Merla TPDX DMY 1.5 RM 0.000 0 J3/18/1999 (1) Injection Mandrels!Valves: : :;:. : : =~[~- :-=~ St MD TVD Man Man V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Type Run Cmnt : :::! 2 7357 5872 Otis Oval-'D' DMY 1.0 BK 0.000 0 10/7/1988 Close( 3 7425 5912 Otis Oval-'D' DMY 1.0 BK 0.000 0 10/7/1988 Close( ]Fi?':, 4 7582 6003 Otis Oval-'D' CV 1.0 BEK 0,000 0 2/10/2000 Open i: ,:::JEWEER¥ ....... ~ Depth TVD Type Description ID ................... 1807 1770 SSSV Camco TRDP 2.813 ................ 7290 5834 SBR Otis 2.813 7311 5846 PATCH Set 3.5" permanent patch 0.000 7318 5850 PKR Otis'RH' RETR. 2.970 !!~,i.,. ..~.., 7323 5853 NIP ,AVA nipple set 2/28/2000 2.313 ii J'~;J[~ 7323 5853 SLEEVE-C 'AVA Cll Sleeve set 2/28/2000- CLOSED 2.310 .~j~ 7618 6024 PKR Otis'WD' PERM. 4.000 I.,IL: - - jj. 7641 6037 NIP Otis'XN' ,O GO.Reducer has 2.25"Se' 2,21"X Nipple Reducer in XN nippleCAMCO D Profile 1,27,2000. 2.750 L/ :::: 7652 6043 SOS Otis 2.992 7653 6044 TTL 2.992 , 1F-02 Workover Procedure Pre-riq Work Note: Leaking pkr & AVA sleeve. Patch unsuccessful. Tbg X IA Comm. Patch across upper packer failed; attempted twice to patch across the top of it unsuccessfully. 1. Run XX plug in top of SBR. (done) 2. MITIA to 2500 psi (done, failed); MITT (done, pass). 3. Pull XX plug/holefinder. (done) 4. Obtain SBHPS (Done 3/30/03; 2606 psi @ 7324' MD) 5. Pump sand plug fullbore to sand back A-sand or run TTP. 6. Tag TOS. 7. Pull DGLV @ 7252'. 8. Circulate Well to sea-water & diesel. ~). Set BPV. ]. 0.Prepare location for Workover Rig. Ri_q Work KWF w/100 psi over = 8.9 PPG 1. 9. Swallow SBR slick stick, drop B&R, set packer. hanger. RILDS. 10. PT tbg & inner annulus to 2500 psi. 11. Run BPV. NDBOPS. NU Tree. Pull BPV. 12. Run Test plug, PT tree to 5000 psi. Pull test plug. 13. Circulate well to seawater & diesel. M IRU Workover Rig. 2. Pull BPV. 3. Circulate well to 8.9 ppg mud. 4. Verify that well is dead. Run BPV. ND Tree, NU BOPE. Function test BOPE. Pull BPV. Install test plug. 5. Test the BOPE rams to 4000 psi, annular preventer to 2500 psi. 6. Pull Test plug. 7. Pull tbg hanger & tbg from SBR. 8. MU & run new 3 ½" completion with SBR overshot, landing nipple w/ RHC in place & new packer. Shear PBR pins, space-out & land tbg 14. Run BPV. 15. RDMO Workover Rig. PIPE RAMS BLINDS ~3 5/g" 5000// wp HYDRIL, TYPE "GK" STUDDED ANNULAR BOP ~3-5/g" 5000// STUDDED HYDRIL DOUBLE GATE PREVENTOR 15-5/8" 5000// APl STUDDED MUD CROSS HABORS ALASKA RIG 3S BOP STACK CONFIGURATION I~!11 ~ ~ 2525 C S~'e$! .~. 200 ~ ~BORS ~ RIG 3S ~ CONOCO P~LUPS 2~3 RIG ~RKO~R SCHE~ II aop STACK ~ ~T~I ~HE~ ~ - Re: Sundry Information for 1F-02 & 2N-348 Subject: Re: Sundry Information for 1F-02 & 2N-348 Date: Wed, 16 Jul 2003 09:31:20 -0800 From: "Aras Worthington" <Aras.J .Worthington@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> Tom, Thanks for asking & checking; you are correct on 1 F-02 (2606 psi @ - 5850' TVD). On 2N-348 I somehow got the wrong pressure information in what I sent you; many apologies for the confusion. The pressure is assumed to be - 2040 psi @ 4819' TVD, for an equivalent weight of 8.1 ppg (we will need an updated static befor the workover). I edited the procedure for 2N-348 and sent it with this correction. It is attached below. Please replace the procedure I sent you yesterday with this one. Thanks, Aras (See attached file: 2N-348 Workover Procedure.doc) Tom Maunder <tom_maunder@admin.state.ak.us> 07/16/2003 08:59 AM To: Aras Worthington/PPCO@Phillips cc: Subject: Re: Sundry Information for 1F-02 & 2N-348 Aras, Thanks for the information. Just a couple of questions. On 1 F-02, in step 4 of pre-rig a BHP is given with a MD. What is the TVD?? Backing in from BHP + 100 = 8.9*.052*TVD, I get 5847' TVD. Is that correct?? On 2N-348, I calculate the BHP to be 3040 psi. Is that correct?? Thanks. Tom Aras Worthington wrote: > Tom, > Sorry for the delay in getting you this information. > > Attached are abbreviated procedures for these two wells and a schematic of > the BOP stack. 1 of 2 7/16/2003 1:25 PM Re: Sundry Information for 1F-02 & 2N-348 Please note that we will run the below represented 13 5/8" stack for 2N-348, but for 1F-02 we will run a 7 1/~ 6" 5M stack of the same configuration. Let me know if you need additional information. Thanks, Aras > (See attached file: 1F-02 Workover Procedure.doc)(See attached file: 2N-348 > Workover Procedure. doc) (See attached file: BOP Stack.pdf) > Name: 1F-02 Workover Procedure. doc > 1F-02 Workover Procedure. doc Type: WINWORD File (application/msword) > Encoding: base64 > > Name: 2N-348 Workover Procedure. doc > 2N-348 Workover Procedure. doc Type: WINWORD File (application/msword) > Encoding: base64 > > Name: BOP Stack. pdf > BOP Stack. pdf Type: Acrobat (application/pall) > Encoding: base64 (See attached file: tom_maunder.vcf) D2N-348 Workover Procedure.doc: Name: 2N-348 Workover Procedure.doc Type: WINWORD File (application/msword) Encoding' base64 Tom Maunder <tom maunderC, admin state ak us> sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 7/16/2003 1:25 PM Subject: 2N-348 & 1F-02 Date: Thu, 26 Jun 2003 09:48:37 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Aras Worthington <ajworth@conocophillips.com> CC: Winton G Aubert <winton_aubert@admin.state.ak.us> Aras, Just wanted to send you a note with regard to these two sundry applications. As discussed, the applications are a little bare. Please refer to 20 AAC 25.280 (b) (1) through (5) for the items needed. I will be out of the office starting tomorrow thru July 9. If the items are submitted today, I hopefully will get the sundries forwarded for signature. If l have already left, I will have given the information to Winton to finalize. Tom Maunder Tom Maunder <tom maunderC, admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 6/26/2003 9:48 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_ RKB 115 feet 3. Address Explorato~___ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Kuparuk Unit 4. Location of well at surface 8. Well number 1279' FNL, 368' FEL, Sec. 19, T11N, R10E, UM (asp's 539611, 5958248) 1F-02i At top of productive interval 9. Permit number / approval number 1121' FSL, 3518' FEL, Sec. 18, T11 N, R10E, UM (asp's 536440, 5960633) 182-211 At effective depth 10. APl number 50-029-20881 At total depth 11. Field / Pool 1499' FSL, 3897' FEL, Sec. 18, T11 N, R10E, UM (asp's 536058, 5961009) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8085 feet Plugs (measured) true vertical 6291 feet Effective depth: measured 7940 feet Junk (measured) - true vertical 8946 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 80' 16" 200 Sx AS II 80' 80' SURF CASING 2214' 10-3/4" 1000 Sx Fondu, & 250 2329' 2224' Sx PFC PROD CASING 7948' 7" 935 Sx G & 250 PFC 8063' 6279' Perforation depth: measured 7481 - 7539'; 7696 - 7772'; 7842 - 7856' true vertical 5944-5978'; 6069-6112'; 6152- 6160' RECEIVED Tubing (size, grade, and measured depth) 3-1/2", 9.2#, J-55 Tubing @ 7652'MD.FEB :l 6 2001 Packers & SSSV (type & measured depth) Otis 'WD' Perm Packer @ 7618' MD; Otis 'RH' Retr. @ 7318' MD. Alaska 0il & Gas Cons. Commission Camco TRDP @ 1807' MD. Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mci Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - - - Subsequent to operation - 2100 - 2200 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service __.(WAG),__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by John Peirce 265-6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 1 F-02i DESCRIPTION OF WORK COMPLETED TUBING PATCH INSTALLATION ACROSS TUBING LEAK 5/28/99: Pumped down IA & took returns up tubing. Found a small leak at about 7320' MD in tubing. 1/27/00: RIH & set a 2.81" x 2.25" Nipple Reducer at 7641' MD. 1/29/00: RIH & set a Tubing Patch at 7313 - 7334.5' MD across tubing leak. 2/28/00: RIH & set an AVA Sleeve in Tubing Patch at 7323' MD. Returned the well to water injection & obtained a valid injection rate. RECEIVED FEB 1 6 2001 Alaska Oil & Gas Cons. Commission Anchorage Re: NofificalJon - Kuparuk Well 1F-02-PTD 1~'~'"~ 1 ~ Subject: Re: Notification - Kuparuk Well 1F-02--PTD 182-211 Date: Mon, 13 Mar 2000 12:40:58 -0900 - From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Ferguson&O'Dell <N1032@mail.aai.arco.com> CC: Blair Wondzell <blair_wondzell@admin.state.ak. us> Brian, In checking my email, I could not tell if I had sent a reply back to you. Your plan to investigate other repair options for 1F-02 sounds good. Too bad the patch didn't work. Keep us informed as to your future plans. Tom Maunder AOGCC Ferguson&O'Dell wrote: > Tom: > Kuparuk Well 1F-02 was previously identified to have a tubing x IA communication > problem, suspected at the time to be a leak in the circulating mandrel. The > original notification was made on or around 3/20/99 by Eric Zuspan. At that > time, we proposed to perform further diagnostics to identify the leak and > develop a repair plan. Testing of the tubing hanger confirmed integrity of the > wellhead. Wireline operations were performed, a small leak was found at the > packer, and a procedure was developed to isolate the leak with a tubing patch. > The patch was run on 1/29/00. Followup wireline work was completed on 2/28/00. > On 3/1, a small volume (.-5 bbls) was bled off of the IA in an atterrpt to verify > integrity of the patch. On 3/6, the IA ws bled again to see if the leak had > been repaired. The IA pressure built back up to pre-bleed pressure of 2700 psi. > At that time it was apparent that the communication problem had not been > successfully repaired, so the well was shut-in. > I am sending you this notification in Eric Zuspan's absence. We plan to leave > the well shut-in while we develop and pursue a plan to identify the current leak > and repair it. > Follow-up notification will be made when the leak has been identified and > repaired. Please let me know if you require additional information at this > time. Brian O'Dell Wells Specialist Tom Maunder <tom maunder~,admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission ~ -~ ~ 3/13/00 12:41 PM ARCO Alaska, Inc. Post Office Box 'i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 5, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form I0-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ~"~:.-- :~'~ j 1B-12 Other (SSSV) -!~1B-12 Perforate ~'~ B-12 Stimulate ~>-.:~ 1F-02 Stimulate ~¢.~,~, 1 L-24 Perforate q'~--7~ 1Y-23 Stimulate ~'~-~/i 1Y.,34 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS;~,,.)N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface At top of productive interval 1121' FSL, 1762' FWL, Sec. 18, T11N, R10E, UM At effective depth 1413' FSL, 1465' FWL, Sec. 18, T11N, R10E, UM At total depth 1499' FSL, 1383' FWL, Sec. 18, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 115 7. Unit or Property name Kuparuk River Unit 8. Well number 1 F-Q2 9. Permit number/approval number 82-211 10. APl number 50-029-20881 11. Field/Pool Kuparuk River Oil Field/Pool feet 8085 feet Plugs (measured) None 6 2 9 0 feet Effective depth: measured 7940 true vertical 6 2 0 7 feet Junk (measured) None feet Casing Length Size Structural Conductor 8 0' 1 6" Surface 2296' 10 3/4" Intermediate Production 8 031 ' 7" Liner Perforation depth: measured 7481 '-7539', true vertical 5943'-5977', Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 7634' Packers and SSSV (type and measured depth) Cemented Measured depth 200 Sx AS II 1 1 0' 1010 Sx Fondu & 2330' 250 Sx PFC 935 Sx Class G & 8 0 6 3' 250 Sx PFC 7698'-7772', 7842'-7856' 6069'-6112', 6152'-6160' True vertical depth 110' 2224' 6277' RECEIVED JAN -'$ i994 ~,iaska 0ii & Gas Cons. C0mmissior~ Anchorage PKR's: Otis 'RH' @ 7633' & Otis 'WD'@ 7611'; SSSV: Camco 'TRDP' @ 1807' 13. Stimulation or cement squeeze summary Fracture stimulated "A" Sands on 12/10/93. Intervals treated (measured) 7698'-7772', 7842'-7856' Treatment description including volumes used and final pressure Pumped 80 Mlbs of 16/20 & 12/28 ceramic proppant into formation, fp was 6300 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 1644 1350 2249 Subsequent to operation 0 0 2638 1500 2283 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service H20 Injector 17. I hereb~ certify that the foregoing is true and correct to the best of my knowledge. Sic, lned '~t~~,/I ~j~ Title Senior Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT WELL iF-o~ DATE TIME DESCRIPTION OF WORK CONTRACTOR/KEY PERSON OPERATION ~AT REPORT TIME DAY 0750 o91o Ioo6 icj7 Io~. 103~ lz~,7 I~OO [~/COMPLETE LOG ENTRY [] INCOMPLETE FIELD EST: $ ti Y./o,~" AFClee'-' ACCUMULATED COST $ PAGE 1 OF ! i'(UPAi:~UK Pi: I HL)LEUM ENGINEERING JAN -,5 i994 A!asl~ 0il & flas ~ons. Commission Anchorage [-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemp. ! Chili Factor I Visibi'ity Report °F °F miles AR3B-7031 Wind Vel. I Signed knots I ..~,--~ ~--ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 17, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION 1F-02 Perforate 1L~01 Perforate 2X-13 Perforate 2X-15 Perforate //3A-03 Stimulate "-.3A-03 Perforate 3A-10 Perforate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECEIVED DEC 2 1 199~ Oil & Gas Cons. Commission Anchorage ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany ' ' STATE OF ALASKA ~ OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown M Pull tubing Alter casing Stimulate __ Plugging Repair well ... Perforate X Other 2. Name of Operator ARCO Alaska, In¢, 3. Address P. O. Box 100360, Anchorage, AK 9951O 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1276' FNL, 368' FEL, Sec 19, T11N, R10E, UM At top of productive interval 1121' FSL, 3518' FEL, Sec 18, T11N, R10E, UM At effective depth 1413' FSL, 3815' FEL, Sec 18, T11N, R10E, UM At total depth 1499' FSL, 3897' FEL, Sec 18, T11N~ R10E, UM 12. Present well condition summary Total Depth: measured 8 0 8 5 feet true vertical 6 2 9 0 feet 6. Datum elevation (DF or KB) RKB 115 7, Unit or Property name Kuparuk River Unit 8. Well number 1 F-02 9. Permit number/approval number ~12-211/8-690 10. APl number so-029-20881 11. Field/Pool Kuparuk River Oil Field/Pool feet Plugs (measured) None Effective depth: measured 7 9 4 0 feet true vertical 6 2 0 7 feet Junk (measured) None Casing Length Structural Conductor 1 1 0' Surface 2296' Intermediate Production 8 0 3 1' Liner Perforation depth: measured 7481 '-7511 ', 7511'-7521 ', true vertical 5943'-5961', 5961'-5967', Size Cemented 1 6" 2O0 SX AS Ii I 0-3/4" 1000 SX Fondu & 250 SX PFC 7" 935 SX Class G & 250 SX PFC Measured depth True vertical depth 7521'-7531', 5967'-5972', 110' 110' 2330' 2224' 8063' 6277' 7531'-7539', 7481'-7539', 7698'-7772', 7842'-7856' 5972'-5977', 5943'-5977', 6069'-6091', 6152'-6160' Tubing (size, grade, and measured depth) 3.5", 9.2#, L-55 @ 7634' Packers and SSSV (type and measured depth) PKR: Otis RH ~ 7316' & Otis WD @ 7620'; SSSV: Camco TRDP @ 1807' ..... 13. Stimulation or cement squeeze summary K~L~iV~D Reperforated "A" Sand on 11/13/93. Intervals treated (measured) 7698'-7772' DEC 2 1 1993 Treatment description including volumes used and final pressure N/A Alask~ 0il & Gas Cons. Commission 14. Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2 0 0 0 1850 23OO Subse( 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 0 - - 0 - 2100 1400 2280 16. Status of well classification as: Oil _ Gas Suspended , Service H20 Injector 17. I hereby_certify that the foregoing is true and correct to the best of my knowledge. ned '~~~· ~ Tit,e Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE WELL SERVICE REPORT WELL ARCOAlaska, Inc. - Subs~.~y of A'tlanllc Richfield Company ° "NTRACTOR~c~/j/,//14.~'~'~ ~ ° FIELD-DISTRICT-STATE JDAYS [DATE /e~ I 1//595 REMARKS OPERATION AT REPORT TIME 09.;0 1155' RzH ff ~'/z" wra/J pmeF ~u/J · 4.5PF, 180~ dp, At~~rtNc,°8~6 ~o~*6~"z~=F aa~a'mAruw, " Poi.l, ~I.L. SI. tOT'S E. XCEFT ~ BPI F~REb. RECFIVFn D~C 2 Alask~ Oil & Ai,uhorage I-"1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots j Signed WELL ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company PBDT .~F-02~ WELL SERVICE REPORT REMARKS . P~o~,~"rF_... A4 &' A 5 - - OPERATION AT REPORT TIME dO13 e,o~PI.~'T'6 095o il$ff B~H ff Z Vz" r/rAN PERF Ou~l ' 4 5PF., 180' d~, AI. TE~NItTUVC.'81~ #OI,.~'"~'~ PE'~E'TRAr/N~ " ,~/.toT~ o,q AdPD O~r ro ~r~o~q 8H ,suon I~0' ccW VSIo8 $~). 8uoor ~,/775Z'- 777Z' RECEIVED DEC 2 1' 1B~6 Alaska 0~1 & Gas Cons. Commission Ahuhorage [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots Signed ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510=0360 Telephone 907 276 1215 May 2, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Subject: Kuparuk River Field Water Injection Surveys In compliance with Rule 4 of Conservation Order No. 198, Kuparuk River Field Waterflood Rules, we are forwarding the blue line and sepia copies of the spinner logs referenced in our previous submittal of April 30. If you have any questions concerning the information reported, please contact me at 263-4978. Sincerely, S. E. Schmidt Operations Engineer SES:DLG Enclosure · , l) ARCO Alaska, Inc. is a Subsidi ry of AtlanticRichfieldCompany q .. AR3B-6003-C STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMI'SSION -~.,.~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG .... 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE~ Water Injector 2. Name of Operator 7. Permit Number ARCO A1 aska, I nc. 82-211 3. Address 8. APl Number P, 0, Box 100360, Anchorage, AK 99510 50- 029-20881 4. Location of well at surface 9. Unit or Lease Name 1279' FNL, 368' FEL, Sec.19, T11N, R10E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1121' FSL, 3518' FEL, Sec. 18, TllN, R10E, UM 1F-2 At Total Depth 1i. Field and Pool 1499' FSL~ 3897' FEL, Sec.18, T11N, R10E, UM Kuparuk River Field 5~ Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool 115' RKB[ ADL 25652 ALK 2578 12. Date Spudded 13. Date T.D. Reached 14. Date comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 12/28/82 01/04/833 01/11/83*J N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19.,~:)irectional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8085'MD/6290'TVD 7940'MD/6207'TVD YES~ NO [] 1807' feet MD 1450' (approx) 22. Type Electric or Other Logs Run DIL/SFL/FDC/CNL/GR/SP/Cal, Gyro/CCL, CBL/VDL/GR/CCL, CBL , 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 80' 24" 200 sx AS Il 10-33/4" 45.5# K-55 Surf 233330' 133-1/2" 1000 sx Fondu & 250 Sx PFC 7" 26.0# K-55 Surf 80633' 8-1/2" 9335 sx Cl.ass G & 250 ix PFC 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 76334' 73308' & 7611' . 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. . Perforated w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7481 '-7539'MD/59#3'-5977'TVD 7406' - 7408' 200 sx Class G Perforated w/8 spf 7610' - 7612' 150 sx Class G 7698 ' -7772 'HD/6069 ' -611 2 'TVD See Sundr~ dated ~)/18/84 for' 7842 ' -7~=;~ ,Mn/C;1 ~;~, -6160'TVD for fracture datal 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc,) N/A I "Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATEDa~'=l~i OIL-BBL GAS-McF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. . . CORE DATA . Brief d, escription of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. I\ ~ ~'~ ~Ui V None DEC - ? 1~q-83 ,~,~;~,:.~ 0il & u~S Con,:-. COI11~iSS'~,?, * NOTE: Dri77ed, perforated and ran tubing 1/11/833. Workover, squeeze and reperf performed 8/9/84, Fractured we]] 8/2.3/8/+° Converted to Water Injector 10/9/85, Workover performed 10/7/88, Form 10-407 WCS/0~ Submit in duplicate 29. 30. ' GEOLOGIC MARKERS FORMATION TESTS " NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7430' 5914' N/A Base Upper Sand 7539' 5977' Top Lower Sand 7678' 6057' Base Lower Sand 7848' 6155' 31,,I~IST OF ATTACHMENTS i~lOFi 6; 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~ ~'~U~J· TitleArea Drill ing Engineer Date / ~ J~-J~ 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- lng 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 /~' STATE OF ALASKA ALt . OIL AND GAS CONSERVATION COM MIS. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pedorate __ ~ Pull tubing __ Alter casing Repair well __ Pull tubing % Other WORKOVER 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1279' FNL, 368' FEL, Sec.19, TllN, RIOE, UM At top of productive interval 1121' FSL, 3518' FEL, Sec. 18, TllN, RIOE, UM At effective depth 1413' FSL, 3815' FEL, Sec.18, TllN, RIOE, UM At total depth 1499' FSL, 3897' FEL, Sec.18, TllN, RIOE, UM 5. Type of Well: Development Exploratory Stratigraphic~ Service ~___ 6. Datum elevation (DF or KB) RKB 115' 7. Unit or Property name Kuparuk River Unit 8. Well number 1F-2 9. Permit number/approval number 82-211/8-690 10. APl number 50-629-20881 11. Field/Pool Kuparuk River Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 8085 ' MD feet Plugs (measured) 6290 ' TVD feet Effective depth: measured 7940 'MD feet Junk (measured) true vertical 6207 ' TVD feet Casing Length Size Cemented Structural Conductor 80' 16" 200 sx AS I I Surface 2296' 10-3/4" 1000 sx Fondu & Intermediate 250 sx PFC Production 8031' 7" 935 sx Class G & Liner 250 sx PFC Perforation depth: measured 7481 '-7539' 7698',7772', 7842'-7856' true vertical 5943 ' -5977 ', 6069 ' -6112 ' , 6152 ' -6160 ' None None Measured depth True vertical depth 1lO'MD llO'TVD 2330 'MD 2224 ' TVD 8063'MD 6277'TVD Tubing (size, grade, and measured depth) 3-1/2", J-55, .tbg w/t.ail @ 7634' Packers and SSSV (type and measured depth) OTIS 'WD' pkr @ 7611' & OTIS 'RH' pkr ~ 7308', Camco 'TRDP' SSSV ~ 1807' 13. Stimulation or cement squeeze summary /A I~e/rvals treated (measured) Treatment description including volumes used and final pressure · , ..... :,,~ ~;~ & 6:..~ Cons. C0mraiss[o~ '.Anchorage 14. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run,,__ Daily Report of Well Operations _N.. 16. Status of well classification as: Oil __ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of mY knowledge. Service Water Infector Signed ~ Form 10-404 Rev 06/15/88 ~.~ Title Area Drillin~ Engineer (Dani) SW03/050 *NOTE: Workover Well History Date/¢/~///~',~ SUBMIT IN DUPLICATE ARCO Oil and Gas Company ~,~ Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Repori" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field KUPARUK RIVER UNIT ICounty. parish or borough NORTH SLOPE Lease or Unil ADL: 25652 Title WORKOVER StateAK 1F-02 Iweu no. Auth. or W.O. no. AK3552 Operator API: 50-029-20881 IARCO W.I. 56.0000 Prior status if a W.O. ARCO Spudded or W.O. begun ACCEPT I Date 10/04/88 ]Hour 1700 }{RS Date and depth as of 8:00 a.m. 10/05/88 ( TD: 8085 PB: 7940 SUPV:JH/ZR 10/06/88 ( TD: 8085 PB: 7940 SUPV:MD/GG 10/07/88 ( TD: 8085 PB: 7940 SUPV:MD/GG Complete record for each day reported NORDIC i SPEAR TBG BELOW HGR MW:12.0 NACL/NABR MIRU. ACCEPT RIG @ 1700 HRS, 10/4/88 PULL BPV, DISPLACED WELL WITH 260 BBL OF 12 PPG NACL/NABR BRINE, ND TREE, NU BOPE, PULLED BPV, SET TEST PLUG, TEST BOPE DAILY:S155,436 CUM=$155,436 ETD=S155,436 EFC=$190,000 POH W/TBG CO COUPLINGS MW:12.0 NACL/NABR SPEAR TUBING, PO AND LD TUBING HANGER, CO TUBING HEAD TO 5000 PSt EQUIPMENT, NU BOPE, TEST BOPE, POH W/ TUBING, CO COUPLINGS TO AB MOD DAILY=S27,600 CUM=$183,036 ETD=S183,036 EFC:$190,000 DISPLACE WELL W/DIESEL MW=12.0 NACL/NARR CONTINUE POH CHANGING OUT COUPLINGS, MU AND RIH WITH 3-1/2" COMPLETION ASSEMBLY, TEST TUBING TO 2500 PSI, TEST ANNULUS TO 2500 PSI, TEST SSSV, ND BOPE, NU TREE, TEST THEE TO 5000 PSI, DISPLACE WELL WITH DIESEL. (NOTE= CAMCO 'TRDP' SSSV 1807', OTIS 'WD' PKR @ 7611', & TT @ 7634'.~ DAILY=S45,163 CUM:$228,199 ETD:$228,199 EFC:$190,000 - (L iVED The above is correct For form preparation and distribution, see Procedures Manual. Section 10, ...... Date ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District ARCO Alaska, Inc. Field KUPARUK RIVER UNIT Auth. or W.O. no. AK3552 County or Parish NORTH SLOPE State Lease or Unit ADL: 25652 1F-02 Title WORKOVER no. Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 10/08/88 ( TD: 8085 PB: 7940 SUPV:MD/GG API: 50-029-20881 IA.R.Co. W.i. Fotal number of wells (active or inactive) on this] ~ost center prior to plugging and 56,0000 ~bandonment of this well lO/04/88 [ 1700 HRs' Complete record for each day reposed NORDIC 1 RIG RELEASED MW:12.0 NACL/NABR FINISH DISPLACING WELL W/ DIESEL, PRESS TST TBG, SET BPV, RIG Old TD I New TD Released rig I Dale RELEASED AT 0745 HRS, 10/7/88 DAILY:SS,216 CUM:$231,415 Classifications (oil, gas, etc.) ETD:S231,415 EFC:$190,000 IPB Depth I T ype completion (single, dual, etc.) Official reservoir name(s) Producing method Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test lime Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate Tltle///~ ~ I . ARCO Alaska, Inc. Date: October 7, 1988 Transmittal #: 7314 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. 3Q-02 Kuparuk Fluid Level Report(4:20) I 0-02-88 Casing $Q-02 Kuparuk Fluid Level Report(3:10) 10-02-88 Casing' 2 D - 01 Kuparuk Fluid Level Report I 0 - 0 2 - 88 Casing I Y- 1 6 Kuparuk Fluid Level Report I 0 - 0 2 - 88 Casing $A-01 Kuparuk Fluid Level Report(3:55) I 0-02-88 Casing 3A-01 Kuparuk Fluid Level Report(4:45) I 0-02-88 Casing 1 F- 05 Kuparuk Fluid Level Report I 0- 0 4 - 88 Tubing 1 F- 0 8 Kuparuk Fluid Level Report 1 0- 0 4 - 8 8 Tubing 1 F- 02 Kuparuk Well Pressure Report 9-30-88 Amerada / ' - u(.;l ! o ~Alaska 0ii & Gas Cons. C0mmissior~ Anchorage Receipt Acknowledged' ........................... Date: DISTRIBUTION: D&M State of Alaska Chevron Unocal Mobil SAPC " ~ STATE OF ALASK,Zk AL~,_ .A OIL AND GAS CONSERVATION COMMIb,.- JN APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ 2. Name of Operator ARCO Alaska~ Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 8. Operation shutdown __ Re-enter suspended well __ Plugg_~ __ Time extension ~ Stimulate ~ ~' Pull tubing Variance __ Perforate __ Other v' 5. Type of Well: Development Exploratory Stratigraphic 9 9 51 0 ' 0 3 6 0 Service 6. Datum elevation (DF or KB) RKB 115' 7. Uniter Property name Kuparuk River Unit Well number 1279' FNL, 368' FEL, Sec.19, T11N, RIOE, UM At top of productive interval 1121' FSL, 3518' FEL, Sec.18, TllN, RIOE, UM At effective depth 1413' FSL, 3815' FEL, Sec.18, TllN, RIOE, UM At total depth 1499' FSL, 3897' FEL, Sec.18, TllN, RIOE, UM 1F-2 10. Permit number 82-211 APl number 50-- 029-20881 11. Field/Pool Kuparuk River Field feet 12. Present well condition summary Total depth: measured true vertical 8085 ' M D feet Plugs (measured) N o n e 6290 ' TVD feet Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length 80' 2296 ' 8031 ' measured true vertical Tubing (size, grade, and measured depth) 7940 ' MD feet Junk(measured) 6207 'TVD feet None Size Cemented Measured depth True vertical depth 16" 200 sx AS II 1lO'MD 110'TVD 10-3/4" 1000 sx Fondu 2330'MD 2224'TVD & 250 sx Permafrost C 7" 935 sx Class G & 8063'MD 6277'TVD 250 sx Permafrost C 5943'-5977', 6069'-6112', 61 52'-6160' u 7, 1988 3-1/2" 9 2# J-55 tubing w/tail (~ 7652' Alaska OJi & Gas Cons. Commission '-. ~' ~nchorage Packers and SSSV (type and measured depth) Otis FMX-TRSV SSSV ~ 1958'; Otis EH pkr @ 7318'; Otis WD pkr @ 7620' 13. Attachments Description summary of proposal .__~ Detailed operations program __ BOP sketch 14. E_stimated date for commencing oPeration ! 15. Status of well classification as: October 1, 1988 . I 16. '?. ~.,,:_i,.../D~Oc/_~,,~:~i o/~//.~r Oil~ Gas_ Suspended~ If proposal was verbally ap'proved ' '~ , / Name of approver Date approved I Service W a t e r I n j e c t o r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~0~.,~,./M'JL~ Title Associate En§ineer Date FOR COMMISSION USE ONLY Conditions approval: Notify Commission so representative may witness Plug integrity ~ BqP,/Test ~ Location clearance __ 4~[~,~ Mechanical Integrity Test~ Subsequent form req~i(~it0v~.m,~,~v Returr~ed - ..% ORIGINAL SIGNED BY Approved by order of the Commissioner LONNIE C. SMITH Commissioner ' JApprova, No. Date Form !0-403 Rev O6/15/88 SUBMITIN TRIPLICATE ~ KRU 1 F-02 General Workover Procedure Change.ut of Wellhead and Couplings Pre-Rig O.oerations 2. Set plug in D-Nipple to isolate A-Sand. 3. Obtain C-Sand BHP after seven days. Close C Sand. . Rio Ooerations 1. MIRU Nordic #1. NU BOPE. Displace well with completion brine. ,, ND tree. Pull tubing hanger to floor, pickup storm Packer and set below hanger 1'. Change.ut the tubing hanger to 5000~ equipment. Pull storm packer. POOH with tubinf.....j, changing couplings to AB Modified. 4. Rerun completion assembly. 5. Release rig. Completion Fluid = NaCI/NaBr Expected BHP = 3Joo Psi Anticipated Start Date = (/o'/o/ /~'~r.) RECEIVED AnChorage ,7- 1 / 16" 5000 PSI BOP STACK ANNULAR PREVENTER 6 PIPE RAMS 4 BLIND RAMS 5 TUBIN6 HEAD 2 1. 16" CONDUCTOR SWAGED TO 10-3/4" 2. 11"-:3000 PSI STARTING HEAD 3. 11 "-3000 PSI X 7-1 / 16"-5000 PSI TUBING HEAD 4. 7-1/16" - $000 PSI PIPE RAMS 5. 7-1/16" - 5000 PSI BLIND RAMS 6. 7-1/16" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS :3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. :3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCPEWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSi AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH :3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING dOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISQR_ 14. PERFORM COMPLETE BOPE ~[~ ~.~ IiA!~I~ND FUNCTIONALLY OPERATE BOPE DAILY. ~.iask~ Oil & Gas Cons. Cornmissio,q Anchorage JG ,JULY 28, 1986 ('NORDIC RIG 10-3/4") ATTACttHENT 1 PAGE I KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE h - INJECTIVITY PROFILES FIRST QUARTER 1987 SUBHITTAL WELL APl DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION TAKING 50-029 INJECTION SURVEY SURVEY ~URVEY WATER INJECTION BWPD "~ClA-13 20700 02/04/83 03/26/87 SPINNER FOLLOWUP A&C SS A&C /'~1A-15 20711 03/01/83 03/25/87 SPINNER FOLLOWUP A&C SS A&C i"-'~--~1F-02 20881 10/15/85 01/13/87 SPINNER FOLLOWUP A&C SS A&C 1F-05 20807 10/28/85 03/08/87 SPINNER FOLLOWUP A&C SS A&C .~Z'IF-IO 20984 08/13/8h 01/27/87 SPINNER FOLLONUP A&CSS A&C '"~1F-11 20993 08/12/84 03/09/87 SPINNER FOLLOWUP A&C SS A&C "J'~1F-13 21020 08/16/8h 03/19/87 SPINNER FOLLOWUP A&C SS A&C ~%~'D1G-09 21001 09/15/8h 02/23/87 SPINNER FOLLOWUP A&C SS A&C ~. 1G-lb 21017 08/24/84 02/2h/87 SURVEY FOLLONUP A&C SS C 9100 ~X~1R-15 21387 11/10/86 02/25/87 SPINNER INITIAL A&C SS A&C .,.-~ ska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 30, 1987 Mr. C. V. Chatterton Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Subject- Kuparuk River Field Water Injection Surveys In compliance with Rule 4 Conservation Order Number 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk water injection wells for the first quarter of 1987. The data is provided in the form of spinner logs or separate zone surveys as listed in Attachment I. The spinner logs will be sent' separately. Injection rates determined by separate zone surveys are also listed in Attachment Io If you have an~ questions concerning the information reported, please contact me at (907) 263-4262. Sincerely, Operations Engineer BBB/SPT: pg' 0069 Attachments Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfielclCompany Attachment ! I Page Z Drill Site 1H Wel 1 No. ~'1H-3 ~1H-4 '~1H-6 11t-7 ~lH-8 Log Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Drill Site Well No. Log Date 1E 1E-lA Ne/19/81 1E-2 '~8/17/81"--7 ~ '"'1/17/84/ 1E-3 "iO/18/81~, ~ '~11/7/81J 1E~.4~X,t,pI '-,8/4/80-\_?, -,,[,I,, 1[-5 ',,10/27/81,, 1[-6 --10/21/81 '-.~ ? -,.11/~2/82 / ~ '""1[-7 ".'.8/28/81x,, ~ "~11/1/8 1[-12 '"11/28/84 1[-15 "~/26/82 1[-16 ~'8/29/82 1[-17 ~9/1/82 1[-20 "~5/7/83 .1[-24 "~2/17/83 1[-25 '"'1/17/83 1[-26 x-1/13/83 1[-27 ~',q'lO/31/82 ~6/13/83 1[-30 ~0/16/82 I~'~ ~/~/~ 3 Drill Site 1G Well Ho. "~IG-1 %g-~ "~1G-3 '~1G-4 '~ 1G-8 Log Date 9/7/82 9/28/82/ 12/8/84./ 10/12/82 11/12/82 3/12/83 1/22/83 Dri 11 Si te Wel 1 No. Log Date 1F ,~IF-1 2/19/83 1F-2 2/3/83 '~IF-3 1/31/83 ~ ~ "1F-4 5/29/83 %1F-5 . 10/25/82 '~1F-6 10/28/82' '~ 1F-7 11/19/82~ ~- ~ 5/7/83~ RECEiV FEB 2 1 1986 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 15, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Attached in duplicate are subsequent notices following wells at the Kuparuk River Field. Well Action Date Performed on the 1F-2 Convert to Water 10/9/85 1G-2 Convert to Water 10/11/85 1L-16 Convert to Water 9/15/85 1Q-1 Convert to Water 9/14/85 1R-8 Convert to Water 8/29/85 1Y-1 Convert to Water 10/8/85 If you have any questions, please T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) call me at 263-4212. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COiv~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION: 1279' FNL, 368' FEL, SEC. 19, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 1 1 5 ' (RKB) 12. 7. Permit No. 82-211 8. APl Number 50- 029-20881 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1F-2 I 6. Lease Designation and Serial No. ADL 25652, ALK 2578 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' 11. Field and Pool KUPARUK RIVER F! ELD KUPARUK RIVER O I L POOL (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On October 9, 1985 Kuparuk well 1F-2 was converted from a producer to a water iniector well as part of the full field waterflood conversion effort. Water is being injected into both the "A" and "C" sands. RECEIVED oct 7 1985; Alaska 0il & Gas Cons. Commission Anch,srag6 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Title KUPARUK Date1 0 / 1 5 / 8 5 OPERATIONS COORDi NAIU~t,/~. ? .._./'~-__,~,'S-~-~' Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA' _ AND GAS CONSERVATION L~ MISSION . SUNDRY NOTICES AND REPORTa, ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ 2. Name of Operator - 7. Permit No. ARCO Alaska, :['nc, see attached 3. Address' _ 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 so- see attached 4. Location of Well OTHER [] ~N/A . 5. Elevation in feet (indicate KB, DF, etc.) N/A 12. I 6 . Lease Designation and Serial No, ' see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 11. Field and Pool Kuparuk River Fi eld - Kuparuk River 0il P0ol Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Will [] Change Plans ~ Repairs Made [] Other [] Pull Tubing [] Other X~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). - Pursuant to form 10-403, it is proposed that the attached list of/^producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion: to a nine-spot pattern will occur approximatel~v 10/15/85. The second conversion to a line drive pattern will occur approximatel~v 12/:]5/85. Injection will be into the A and C sands. SEP 2 0 19 5 Anchorage -14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .:::~, /~fi~'~ ~.~.~t~.~'~',~ Title Kuparuk Operations Coordinator Date The space below for Commission use 9/18/85 Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 ^pproved Copy J~.IiUrr~ ! By Order of COMMISSIONER the Commission Date__ Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 1E- 6 -26 - 5 - 8 1G- 2 -- 3 - - 4 · -- 5 1L- 1 - 3 - 5 - 7 -16 IQ- 1 - 2 "' 7 - 8 -11 -12 -13 -14 IR- 3 - 8 -10 -13 1Y- 1 - 7 -10 -13 2B- 5 - 6 - 7 - 8 -- -9 -10 -11 -12 2C' 1 - 2 - 3 - 4 - 5 MARK:0091 permit 80- 78 82-166 81-211- 172 132 162 149 161 83- 20 84-173 158 123 145 181 84-231 232 .. 218 209 199 193 85- 44 45 85-177 73 96 150 83- 50 68 51 15 84- 4 22 24 28 27 29 35 38 83- 83 93 89 94 99 API ~ 029-20493 029-20840 029-20881 20846 20807 20836 029-20813 20824 20835 20908 029-21196 21182 21155 21171 21202 029-21247 21248 21234 21225 21216 21210 21306 21307 029-21406 21333 21351 21385 029-20933 20950 2093.4 20903 029-21067 21078 21080 21079 21082 21084 21089 21092 029-20962 20972 20968 20973', 20978 Lease & Serial # Convert Date 25651 469 10/15/85 " " 10/15/85 25652 2578 10/15/85 " " 10/15/85 " " 10/15/85 " " ' 10/15/85 25640' 2571 10/15/85 " " 10/15/85 " " 10/15/85 " " 10/15/85 25659 2585 12/15/85 " " 10/15/85 " " 1.0/15/85 " " 12/15/85 " " 10/15 / 85 25634 2567 10/15/85 " " 12/15/85 " " 12/15/85 " " 10/15/85 " " 12/15/85 " " 10/15/85 " " 12/15/85 " " i0/i5/85 25635 2568 10/15/85 " "' i0/i5/85 " " i0/i5/85 " " i0/i5/85 25641 2572 12/15/85 25646 2577 12/15/85 " " 12/15/85 25548 2662 12/15/85 25656 2582 12/15/85 " " 10/15/85 " " 12/15/85 " " 10/!5/85 25655 2581 12/15/85 " " 12/15/85 " " 10/15185 " " 10/15/85 25654 2580 12/15/85 " " 10/15/85 " " 12/15/85 " " 10/15/85 ,, ,, S 2 0 AI~,sk~, ('lii& Gas [:.rms. C.qmmissiop ARCO Alaska, inc Posl Ollice Box 100360 Anchorage. Alaska 99516-0360 Telephone 907 216 1215 DATE: 8/30/85 TIiANSHITTAL NO: 5234A TO: A~{CL) ALAUK~, INC. KUPARUK t3PE kATIt~NS RECORDS CLERK ATO- ! 115U P.o. BoX 100360 i~i,'GINLKi<I NG T IiAN SI-! I TTLD RECEIPT AND 5EwUENCE OF UVEN'I'S 1G-4 PRESSURE DATA 1F-2 PRESSURE DATA 1~'-4 PIiUSSURE DATA 1F-8 PRESSURE DATA !F-7 PRESSURH DATA iF-5 PRLSSUt4U DATA iF-7 PSESSUI{r DATA ii"- 3 P~ESSU~E DATA iC-11 PREbSURU DATA ;0-6 PI{CSSURE DATA _U-11 PHEbSUi~ DATA _U-5 PRESSURE DATA tIEREWITn ~ttE 'flJU FOLLOWING ITI-:MS. PLEASE ACKNOWLEDG~J RUTUI{/~ ONE $IGNLD COPY OF TI/IS TRANSMITTAL. - A bAND - £.'ALLOFF C b~-.I,4D - A SAND PDU - PBU CO£,iCINIJD 4/27/85 3/ 8/85 1/22/85 1/22/85 1/21/85 4/21/85 4/21/85 4/21/85 3/ 8/s5 5/ 7/85 4/27/85 31 185 i/30/~5 ~ZEIPT ACKNUWLEDGLD: .: PlY I.)R I L L ! N G L. JOIlNSTUhl l-lO S I L" NaN rdL i '. I<K ~,'. PAbIIER LXXON PiiiLLIPS OIL ~ J. kATtI[dULL/. STATE OF ALASKA.< SOHIO ' UNION ~ K. TULIN/V AU L'-," ARCO Alaska, Inc. Post Office/--'"' 100360 AnChorage, ,-.,aska 99510-0360 Telephone 907 276 1215 DA'FE' APRIL m'~ io85 TRANSMITTAL NO' ,5i48 REI'URN TO' ARC[) ALASI<A, INC. ATTN: RECORDS'- CLERI<' ATO-i i i 5B F:' ri T.',.Nv i0r.-;~6C. · ... a ...... .-'~. ..' ANE.'.F!ORAC,-E, -Al< F'9~I 'f'RAH,'?MITTED HEREW.T. TH 'ARt:; THE F'O!...t:.Ot,J];.UG I'f'EHS, PI_EA.S'E ACI<NOWL_ED(;E RECE!F'T AND RETUF..'.N ONE SIGNED COi::-'Y OF TI-IlS 'TRANSMITTAL, ,'7., DE / I N ]'IS RM I TTENT LIFT SOE/F'ROD 1..O(.; ,.".-,. 'A' SAND F'BLI · '~ I'"/t, I ,.'., 0,:'~, F B U ( I T l A L ,'[ .,. PRES,S'URE ) SOE/F'BU £OE/F'BU ~O.E/F'F.:U · ~q~"-/' C' $~-~ND F'BU SOE/SBi-.IF' - 'A' & STATIC BHF' DATA STATIC BHF' DATA STATIC BI"IP DATA 2. TATIC BHF' DATA ~TATIC BI"IF'~.~.AT~^ STATIC ['-,'HF' DATA ~TATIC BHP DATA ~TATIC BHF' DATA . STATIC BHP DATA STATIC BHF' DATA ,_,T~--~T]:C;:.,I'IF DATA STATIC BHF' DATA ,."?TATIC F;HF' DATA ST''.'r Ru':' I-'i~ .'[I'~ i'~ ~TAT]P. ~"'"" ~ATA ,."- _ ~:: 1"1 I" ... ~TA'i-Zr- ~,u.!:, DATA ~...- .-.,i l, . . STAT.~C BHP DATA STATIC BHP DATA STATIC BHP DATA STATIC -r-;HPDATA '~-rA-r'rC BI'IP P-'ATA ~.~ i "- .,~. STATIC BHF' DATA 'C' SANDS F'R~' ~'' ~''~'';' SURVEY ¢',5 ,~ U Fk 12.. DISTRIBUTION: DRILLING W. F'A£HER .... O,--,r~, _F, EXXON MOBIL F'HILLIF'S OIL NSK CI._ERK J, RATHMELL ARCO Alaska, Inc. is a Subsidiary of AtlanticRIchfieldCompany 416-7185 ~/i t/85 ,, ~I:~6185 ¥/2/85 S/~/85 -- ~f4/85 ~/t 8i85 i/24,/8~ i/24/8~, 3/~/85 312/85 ~/2/85 S/2/85 3/t9/85 I/2'! S/2~/85 S/24/85 S/26/85 ~ /'26/85 t125/85 i/5'/85 i/24-/85 -- t/24/8~ . i RECE VED APR 2 5 1985 AlSska Oil & Gas Cons. D A T E: Anchora~ ~ DF AL.A,.?K¢ UNZON K. TWL ! N,/~ '~ ' ' ~, ~,.~ T ARCO Alaska, ir~x'~, Post Office. ~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 T f~ · ...- :.-,.: .... ,.!:...:'" .,,,,.,.-. ~ K."' '[ '~ E'----"i %' --- .1 !! '[ r-i ... ii--I .... ¥ ~ i i-, .. "i '~ '- , :.: .:.. '::';"'"' i-I ~... ~.. ?f':. i ':j.: ~' ....... .,...... · ':, ¥~ ,'", .-.% ..: "t'-..~ · '.,'! !)-- i i .--- :.-.-.~ ....... i ?T. ~ · '~ '...i. - ,:" ~ :',L: ..... ~ 0 .:-:. ,.: i'!' !J 1. i i '~ 21..,J ..... i i ; ,-: {.:.: -. · ::; ~, ..Z '~ ~..~ ! ! · .,..-, ~' ::.:.~Y-.' '"-i :? !4 .... i "':' / ..... ~-. ;?.H '" i :5 -~' :.- ,.. -..- _.. ..... ¢ ! .~.., ............. '"" '"":: '"' "'"" -':?- .... -'"::;'::: - C';- ~':~ ,i-:.' !_.. '[ F:' '~" ,':::." U F;-: V [;: "r" ,-"-, .% -.. ;-.-., ,.~ :,::-.:...,::; ,.., I .-,, . ..... -. - :. -.; ....... :.. "?" "?: '-" "-'" '::': "-:'::-' ':": I::' :(!-: t..-" 0 :T;- '-':.'-) "2--- · ' "."" -.'".. 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(i:'"'"' "''':" ' ,r.: [ i I :I; ','" 'i: 'F.', -,.,- "" C:'..:' ....... ; ... '::: ~-":', i"i C'. O C.."f' ]: C; 'T' :[ ,!-;-' () 'T']: :!-::' C: ;:: i"'! !::; Ci (3 T :i: ,-!:7 !..j I .!. ,:: ;:, : I..1~ I!~. I II;!:,%' · ' I' ~'f' .~. ,.? "'; '"-:r. '.-'- i _l .; ... I' £.-'i FII-i~ ..~ ,..., C: ,":':'i :""; ""' q [ I '..- -.1. I'": ..... ,.. ~':'-~ J"i i": f'i I"; '~' T '-? ....' i .:. f)f"i!.~r"~ ~ ...... - '.-'.: i::. i... i... [:.., f"~ I,.I ~:" I ~ ...- .. (:} '!-:l: :ii.' '~:; . I u! Ii..:.: ~. .... i I ..... .[~ ..J I'l U !']- !--l!Z,~-;-' O 'f' :l: C: ~'::', i'i {.: O C ,'-':; H C O "' '"" :l: '" !..~ I 1.;. ¢" "F' r --"~ ,... I ~ .L I"i "F T :." .... i. ~.~ {3 f' :I: 57 O ']" :1: ,!i-' [:) T .,r. ,..'.? {:;I i' ]: ,!7 ARCO Ataska, Inc. Pc.' Of;~c¢ E,~,---~.[~ ~'; ~-':o:ag-~ .... 9S510 ; e:ephone 907 277 5637 Date: 1~ Transmi~al No: 4740 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed popy of this transmittal. S CHLL,~,:,.~ERGER FINALS/PRODUCTION ..~q, 2G-7 CBL "Variable Density" "GCT/4" HJ" 7/13/84 Run 5 6000- 6459 2G-7 Completion Record "CBL/VDL/GCT" 7/14/84 " 6000 - 6423 2B-9 CCL & Perf. Record 7/18/84 Run 1 2B-8 CCL & Perf. Record 7/13/84 " .2B-7 . CCL & Perf. Record 7/10/84 " 2A-5 Completion Record "PPS/JB" 6/26/84 " 8.600 - 8920 1F-2 Completion Record "Sq. 4" Retain" 8/02/84 " 7400 - 7750 1F-2 .Completion Record "Set Plug & Retain 8/03/84 Run 2 7450 - 7690 1F-2 CCL'& Perf. "Perf & Packer Set" 8/06/84 " "CBL/Plug ~ Retain/JB" lF-2 CBL -"var iable Density" 8/05/84 " "Packer Retain/Perf/JB" 6950 - 7935 -lG-4 CBL "Variable D~nsity" 1G-4 Depth Determination Log "CBL" 1G-13 EPL "Tracer" Receipt Acknowledged: 8/ll/84 8/11/84 7/03/84 Run 3 5964 - 6903 Run 1 5934 - 6548 " 7400 - 7941 /cat Date: DISTRIBUTION B. Adams D & M W.V. Pasher C.R. Smith F.¢vgB~ke~r ¢/~" / ¢/(7 ,'- ~illing G. Phillips ~' State of Alaska P. B~ter .... / < ¢¢,-..._ g~&¢v ~', p Phillips Oil Sohio ~,.:~ ~, .~ -~-,.~ ~_ J.J. ~t~ell Union BP'~~' .~ ~ ~ .... Mobil~ ..... u';;:~'~.o ...... :s~o~ R & D Well ~iles ChevrOn KSK Operations .. · " . ~~-~'/~ / - ~. ~ ~-:. ~f - ~../{ ~Y ,- ARCO AlasKa, inc. Pos! Office-'~x 360 Anchorag ~aska 99510 Telephone ~07 277 5637 Date: 1/07/85 Transmittal No: 4955 RE Tb~d~ ' TO: ARCO AI3~, INC. ATTN: Records Cler~ ATO-1115B P.J~.~ Box 100360 , //~chorage, AK 9951~ ~ ~ransmitted are the following items. Please acknowledge receipt here%-ith and return one signed copy of this transmittal. OTIS. P~U ~UfiVZ~S " . . 1F-14 12/05/84 .- _ 2~-4 - 12/06/84 2B-5 .'"' 12/04/84 !Y-13-" !2/07/84 . - 2C-7 "- 12/12/84 /cat Receipt Acknowledged: B. Currier BP~ Chevron D&M Drilling Geology' Mobil NSK Ops. D I S TRIBUTI ON Alaska Oii& fas 6otis. r. . Anchorage ~'omm~ssion W. Pasher State of AK G. Phillips Sohio Phillips Oil Union J. Rathmell Well Files Inc. i~ a subsidiary o! Ali~r.l,¢Richl~elc:C:o."n.o~,nv ARCO Alaska, Inc. ~:'c. ' Off=cc ~E~-'~35[~ '~ e:+p,~,or, e 907 277 5637 Date: 10/05/84 Transmittal No: 4739 Return To: ARCO ~ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 tted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PBU Surveys/Pressure Analysis ._ lB-2 :'~ 9/08/84 1F- ' 9/15/84 2V-6i~ 8/17/84 2V-7 8/17/84 2V-3 8/17/84 2C-6 8/18/84 a SEQUENCE OF EVENTS C~mco 9 / 08 / 84 S BI-IP Otis 9 / 15 / 84 /PBU Torque Turn 8/17/_84 < ........... _. " " 8/17/84 SET " " 8/17/84 <FBU "A" SA~.~-'~" " " 8/18/84 i PBU /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron D&M DISTRIBUTION Dzilling G. Phillips State of Alaska Geology Phillips Oil Sohio Mobil J.J. Rathmell Union NSK Operations R & D Well Files ARCO Alaska, h Post Office ,.,ox ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 1, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1F-2 Dear Mr. Chatterton' Enclosed is the Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU1/L69 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ' ~--'--'~- STATE OF ALASKA --~" ~ ~ ~ -' ALASK, _ AND GAS CONSERVATION (. ...MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-211 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20881 4. Location of well at surface 9. Unit or Lease Name 1279' FNL, 368' FEL, Sec.19, TllN, R10E, UM Kuparuk River Unit . . At Top Producing Interval 10. Well Number 1121' FSL, 3518' FEL, Sec.18, TllN, R10E, UM 1F-2 At Total Depth 11. Field and Pool 1499' FSL, 3897' FEL, Sec.18, TllN, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 115' RKBJ ADL 25652, ALK 2578 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 1 2/28/82 01/04/83 01/11/83I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I'VD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8085'MD,6290'TVD 7940'MD,6207'TVD YES [] NO [] 1958 feet MDI 1450' (approx) 22. Type Electric or Other Logs Run DIL/SFL/FDC/CNL/GR/SP/Cal, Gyro/CCL, CBL/VDL/GR/CCL, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 80' 24" 200 sx AS II 10-3/4" 45.5# K-55 Surf 2330' 13-1/2" 1000 sx Fondu & 250 sx Permafrost C 7" 26.0# K-55 Surf 8063' 8-1/2" 935 sx Class G & 250 s: Permafrost C 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 7652' 7318' & 7620, 7698' - 7772' w/8 spf 78427 - 7856' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 74817 - 75397 w/12 spf, 120° phasing 7406' - 74087 200 sx Class G 7610' - 76127 150 sx Class G 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE J~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED oC, o 1994 Alaska 0il & Gas Cons, Commission Form 10-407 GRU1/WC10 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. .: - GEoLoGic'MARi~-ERs .:_- ., ~ . -.- '.' F-0RM/~TiON.Ti~.Si_~;. ~ , . · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7430' 5914' Base Upper Sand 7539' 5977' Top Lower Sand 7678' 6057' t N/A Base Lower Sand 7848' 6155' I I · 31. LIST OF ATTACHMENTS Workover We]] Hi story 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Area Dri ] l i ng Engr. Date D 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- lng 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". Fnrm 1 n-an7 Well Hi.tory - Initill Report - Dilly ~ ~ ..I s,I.NI tt~ "1~1.1 ~ on 11~ )I~1~..' ~ ~ I ~1 le ~dd~t or wom~r ol~r~tone sm star, sd. DMiy ~ ~ t~ .lgaMtng ~ould be ~.~ tt~ form gtvmg Inolasive dates only. Olatdot Alaska Fleld Kuparuk River Auth. or W.O. no. AFE 103861 - 204528 North Slope Borough Leto or Unit ~., ADL t/25652 Recompletion IState WWS #1 Operator ARCO Alaska, Spudded or W.O. begun Workover Date IHour 7/30/84 1600 Hrs. Date and dep~ as of 8:00 a.m. 7/30/84 thru 7/31/84 8/01/84 8/02/84 8/03/84 Complete reCOrd for elch d~y ml)ort~ The above 18 correct Alaska ell ~, 1F-2 W/O 7" @ 8063' 7940' PBTD, C&C br 8.6 NaC1/NaBr Accept rig @ 1600 hfs, 7/30/84. Cuc brine wt to 8.6 f/kill. Tst lub to 2500 psi. RIH w/vlv pulling tl, pull vlv @ 7301'. Bullhead kill well w/20 bbl brine, followed by 25 bbls calcium carbonate 9.4 ppg pill. Pmp 30 bbls brine to put pill to perfs. C&C brine to reduce gas cut. 7" @ 8063' 7940' PBTD, Circ 8.6 NaCl/NaBr C&C brine to 8.6, observe well, no press. Set BPV. ND tree, NU & tst BOPE to 250/3000 psi. Pull hgr to flr, rev CBU, no loss to formation. POH, std back tbg in drk. RIH w/223 jts, 3½" DP, pull pkr free, circ out bas bubble f/below pkr. 7" @ 8063' 7940' PBTD, Prep to perf 8.6 NaC1/NaBr Fin rev cite, POOH, LD pkr & tailpipe assy. RIH to PBTD w/6-1/8" bit/7" csg scrprs, circ, POOH. RIH w/R-3 pkr, set @ 7391' DPM, ts~ csg to 2500 psi; OK. POOH to 7580' DPM, set pkr, pmp 30 bbls @ 2750 psi, 6 BPM. POOH, LD pkr. RU Schl to perf. 7" @ 8063' 7940' PBTD, POOH w/bit 8.7 NaCl/NaBr RIH w/sqz gun, perf 7610'-7612' @ 4 SPF/120° phasing. RIH, set Bkr Model "K" cmt retmr @ 7555' WLM. RU BJ Hughes, sting in, est IR @ .5 BPM, 1400 psi; note ann rets of 1BPM. Unsting f/retnr, rev circ, POOH. RIH w/6-1/8" bit & tandem boot bskts, tag retnr @ 7557' DPM, drl on retnr. RIH to PBTD @ 7942' DPM, C&C, POOH. -_ 8/30/84 I RECEIVED f'-~F'-'T' A~fmka nil ~, ~ Cons. Commission Anchora~c Drilling Superintendent ARCO W.,. 56.24% Prior status If a W,O. ARCO 011 and Gas Company Daily Well History--Interim Inaln~-t~nl: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Flnll' form. 1) Submit "lrltlrh~" sheets when filled out but not leu frequently than every 30 day~, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workover~ and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. r county or Parish Alaska North Slope Borough I Lease or Unit Kuparuk River ADL 25652 Complete record for each day while drilling or workover in progress 8/04/84 thru 8/06/84 8/07/84 8/08/84 8/09/84 IS/ate Alaska IWell no. iF-2 w/0 7" @ 8063' 7940' PBTD, Perf'g 8.7 NaC1/NaBr POOH w/bit & JB. TIH w/bit & 7" csg scrprs, tag PBTD @ 7942'' DPM, rev circ & balance well, POOH. RU Schl, RIH w/EZSV BP, set @ 7680' WLM. RIH w/EZSV CR on WL, set @ 7550' WLM. RIH, sting into CR, hesitate sqz w/final rate of 1/4 BPM, 2700 psi. POOH w/stinger. CIP @ 0330 hrs, 8/4/84. RIH w/Economill & 5" DD to 7450' DPM, WOC. Mill soft cmt f/7540' DPM to top of CR @ 7550' DPM. Mill CR, hard cmt f/7552'-7680' DPM, mill BP & jnk @ 7680', CPU, POOH w/mill. RIH to 7940' DPM, rev circ DP until cln. RU SOS, tst lub to 1000 psi. Rn CBL f/7935'-6950' WLM; good bond bet sqz perfs. RIH w/perf gun, perf 7521'-7539' @ 12 SPF/120° phasing. RIH f/perf rn #2. 7" @ 8063' 7940' PBTD, Space out tbg 8.7 NaC1/NaBr Perf 7501'-7521' WLM & 7481'-7501' WLM @ 12 SPF/120° phasing. (Accum fluid loss = 209 bbls). Rn 6.125" gage ring & JB to 7700' WLM. RIH w/pkr & tailpipe assy on WL, set WD pkr @ 7620' WLM. RIH w/3½", 9.2#, J-55 BTC IPC tbg & space out. 7" @ 8063' 7940' PBTD, PU stinger & 2' XO seal assy 8.7 NaC1/NaBr Att to space ou~ tbg, string moved up 7'. Press tbg to ck seals, rec'd ang ret's. Wrk string; tbg still 3' high. POOH w/3½" CA & std back. Redress SBR w/retrv'g tl. RIH, tag fsh @ 7320' RKB, POOH w/fsh; btm rubber seal of RH pkr gouged & damage to seal assy. PU sting & 2' XO seal assy. 7" @ 8063' 7940' PBTD, PU tbg hgr 8.6 NaC1/NaBr TIH, tag pkr @ 7605' DPM, rev circ w/no fluid loss. Press tst seals; OK, TOH. TIH w/3½", 9.2#, J-55, BTC compl string, PU tbg hgr, space out. ~ The above is correct Signature For form preparation and distl~bulion see Procedures Manual Sectidh 10, Drilling, Pegee 86 and 87 IDate ITille 8/30/84 Drillin~ Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code State North Slope Borough Alaska Well no. DS 1F-2 W/O District ]County or Parish I Alaska Field Lease or Unit Kuparuk River ADL 25652 Auth. or W.O. no. I Title AFE 103861/204528 ] Drill & Complete WWS #1 A.R.Co. W.I. Operator ARCO Alaska, Inc. Spudded or W.O. begun W/O Date 7/30/84 I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well I 56.24% our I Prior status if a W.O. I 1600 hrs Date and depth as of 8:00 a.m. 8/10/84 thru 8/13/84 Complete record for each day reported 7" @ 8063' 7940' PBTD, RR Kuparuk crude Stab into lower pkr, tst hgr; OK. Drop ball, set pkr. Set BPV, ND BOPE, NU & tst tree to 250/3000 psi. Displ well w/30 bbls diesel, followed by crude. Set BP-V. RR @ 2130 hrs, 8/9/84. SSSV @ 1958' - SBR @ 7292' - Pkrs @ 7318' & 7620' - Tbg Tail @ 7652' Old TD New TD 8085' Released rig 2130 hrs Date 8/09/84 PS Depth 8063 ' I Knd of rg Rotary Classifications (oil, gas, etc.) 0il Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test'time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR correctedGravity Allowable , Eff~'dJivJF"dla~'~ [~ ..fl ~ k ~ ~ii ~ The above is correct Signature I Date ITitle /JA,~ ~. 8130/84 For ,or~--preparation and disl~ibution, see Procedures Manual, Section 10, ED :uasXa 0il & Gas Cons. Commission Drilling Superintendent A;ici~u~!~e ARCO Alaska, Inc~ ;- -" Off.'c,- u-c:x 36[} Aac.ho:age. Alaska 99510 ~e!e~hone 907 277 5637 Date: 9/04/84 Transmittal No: 4712 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 ~ransmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PRESSURE ANALYSIS/PBU SURVEYS & SEQUENCE OF EVENTS 1E-12~ PBu "BOOm!" 1E-15 ' ' ' .......... ~' STATIC BHP 1F-2~ SIBHP 1F-4 / SIBHP 1F-6- SIBHP iF-? J SIBHP 1F-7-'- SIBHP 1F-7- SIBHP 8/17/84 8/05/84 6/04/84 4/30/84 6/04/84 5/08/84 6/05/84 12/19/83 6~05~84 4/30/84 1F-9'j GAS LIFT. SURVEY 4/29/84 1F-9~"-~PB~/bRAWDOWN 8A~ 12/26/83 1F-10-~O/DRAWD0~iN~ 12/20/83 1F-i0~ DRAWDOWN 12/21/83 1F-11~- ~0~> 12/23/83 1F-11-~P~~WDOWN-A?-3/15/84 1F-11~- ~'~U/DRAWDOWN-~' 12/24/83 1F-12 .~- ~BU/DRAWDOWN3A 3/09/84 1F-12-'~ ~BU-"A" SAND/) 7/03/84 1F-12-~ PBU/PDD 3/10/84 1F-12 / PBU/PDD "A" 3/09/84 1F-13~('~BU "A" S.~, 5/03/84 1F-13~/ SIBHP-NEW~"C" 1/26/84 1F_16~ ?p~U-;,-~,,'-SANTD~.~.~> 5/04/84 Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE D&M 1F-16~/ LOGS & PBU_"A" SAND~/04/84 /cat Date: .... ' : DISTRIBUTION W.V. Pasher C.R. Smith Drilling Geology Mobil G. Phillips State of Alaska Phillips Oil Sohio J.J. Rat}~ell Union Chevron NSK Operations R & D Well Files ARCO Alaska, I' Post Offic= Box ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 17, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SuBjECT: 1F-2 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU1/L40 Enclosure If RECEJV£D SEP 2 Ataska 0il & Gas Cons. Commission Anchorage ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany '~" ~'-'" STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION ~,OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 82-211 3. Address 8. APl Number P. O. BOX :360, ANCHORAGE, ALASKA 99510 50- 029-20881 4. Location of Well SURFACE LOCATION: 1279' T11N, R10E, UM FNL, 368' FEL, SEC. 19, 5. Elevation in feet (indicate KB, DF, etc.) 115 ' (RKB) 12. I 6 . Lease Designation and Serial No. ADL 25652, ALK 2578 9. Unit or Lease Name KUPARUK RIVER UN IT 10. Well Number 1F-2 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOl Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation I~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On August 23, 1984 the "A" sands of Kuparuk well 1F-2 were hydraulically fractured and propped to improve production. The treatment consisted of 226 BBLS of gelled water as pad and carrying fluid and 15,456 LBS of 12/20 sand as proppant. Prior to pumping, equipment and sand was tagged with R.A. tracer performance. lines were tested to 5800 psi. The to aid determination of job 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title OPERATIONS COORDI NATOR The space below for Commission use 9118184 Date Conditions of Approval, if any' By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, l' Post Office 8ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 21, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Attached in duplicate are subsequent notices on the following wells at the Kuparuk River Field- Well Action Date Performed 1 F-2 Fracture 8 / 23 / 84 1 F-1 0 Convers i on 8 / 13 / 84 1 F-11 Conver s i on 8 / 12 / 84 1F-13 Conversion 8/16/84 1F-15 Conversion 8/16/84 1G-3 Fracture 8/10/84 1G-4 Fracture 8/30/84 1G-5 Fracture 8/10/84 1G-6 Fracture 8/12/84 1G-6 Conversion 8/28/84 1G-9 Conversion 8/24/84 1G-14 Conversion 8/24/84 1G-16 Conversion 8/24/84 2C-7 Fracture 8/14/84 If you have any questions, please call me at 263-4253. Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~r~Cflorage Corrllrli88}l~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION tJOMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 1279' FNL, 368' FEL, Sec.19, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 115' 12. 6. Lease Designation and Serial No. ADL 2F, F~52 Al K ?~78 7. Permit No. 82-211 8. APl Number 50-- 029-20881 9. Unit or Lease Name K,,p~r,,l~ R~v~r IIq~t 10. Well Number 1F-? 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other ~ [] Pull Tubing [] Other [] Pulling Tubing ?[] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig @ 1600 hfs, 07/30/84. Pulled BPV. Bullhead kill well.w/20 bbls brine followed by 35 bbl Calcium carbonate 9.4 ppg pill. Observed well. Set BPV. ND tree. NU BOPE & tstd to 3000 psi - ok. Pulled hgr & tubing. Pulled pkr. Circ. out gas bubble. POH w/pkr & tailpipe assy. Tagged fill ~ 7910'DPM. Rev. circ. Washed to 7938'DPM. RIH & set R-3 pkr ~ 7391'DPM. Tstd csg to 2500 psi - ok. Unset pkr. RIH to 7934' & set pkr. Tstd DP & pkr to 2500 psi - ok. Unset pkr. POH to 7580'DPM & .set pkr. Est i~j rate on DP into "A" sand of 600 psi ~ 1BPM. No communication - no ann flow. POH & LD R-3 pkr. Tstd lubricator ~ 250 psi & 2000 psi - ok. RIH & Perf'd 7610' - 7612' w/4 spf, 120° phasing. Set EZSV (made up as retainer) @ 7550'WLM. Pumped and squeezed 150 sx Class G cmt. PU hgr and land. Tstd packoff to 3000 psi - ok. Drld soft cmt and milled Pkr. Milled hard cmt, bridge Plug & junk ~ 7680'. CBU. Dropped ball & sheared out drain sub. Tstd lubricator to 1000 psi - ok. Ran CBL f/7935' - 6950'WLM. Perf'd the following intervals w/12 spf, 120° phasing: ~' RECEIVED 7521' - 7539' 7501' - 7521' SEP2 4 ,984 7481' - 7501' ..... Atas~a 0i~ & ~as Cons. Commission RIH w/gauge ring/JS to 7700'. RIH & set WD W/L pkr & tailpipe assy @ 7620'WLM. Ran 3-1/~C~eetion assy. Attempted to PU to space out. POH w/3-1/2" completion assy. RIH & tagged fish ~ 7320'. Jarred and POH w/fish. Reran 3-1/2" completion assy w/tail ~ 7652', RH pkr ~ 7318' & SSSV ~ 1958'. Tstd hanger - ok. Dropped ball & set pkr. Set BPV. ND BOPE. NU tree and tstd to 3000 psi - ok. Pulled BPV. Disp well w/diesel & crude oil. Opened SSSV. Set BPV. Secured well and released rig ~ 2130 hfs, 08/09/84. 14. I hereby ce, r, tlT~ that the foregoing is true and correct to the best of my knowledge. ?/ Signed ..... ' Title Area Drilling Engineer The space ~'~r ~ission se Conditions of Apprq~l, if any: Approved by Form 10403 By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Rev. 7-1430 GRU1/SN40 and "Subsequent Reports" in Duplicate ARCO Alaska, I Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 8, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton. Attached are notices of intention to fracture the following Kuparuk Field wells. 1F-2, 1F-4, 1F-6, 1F-7 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED AUG 0 9 Alaska Oil & Gas Cons, Comml~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ ~-- STATE OF ALASKA --. .... ALASt,. ~C__AND GAS CONSERVATION 3. .~IlSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 82-211 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50- 029-20881 4. Location of Well SURFACE LOCAT I ON- 1 279 ' T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 11 5' (RKB) 12. FNL, 368-' FEL, SEC. 19, t 6 . Lease DesignatiOn and Serial No. ADL 25652, ALK 2578 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1F-2 11. Field and Pool KUPARUK RIVER F! ELD KUPARUK RIVER OIL POOl Check- Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe PropOsed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" sand in Kuparuk well 1F-2 be hydraulically fractured and propped to improve production. The treatment uses gelled water as the pad and carrying fluid and 12/20 sand as the proppant. Lines and equipment will be pressure tested to 5000 psi prior to starting job. Radioactive tagging of the proppant and pre-post frac logs are included in the treatment program. Fluid- Gel led water 238 BBLS Proppant- 12/20 sand 16,500 LBS AUG 0 9 August 17, 198q Subsequent Work Beport~-~. '~' c/1./- AtaS~a 0il & ABohorageGaS Cons. on Form No./~-~! Dated ANTI C I PATED START DATE: 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title OPERATIONS COORDI NATOR The space below for Commission use Date 8/8/84 Conditions of APproval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1430 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In Post Office ~ox ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Hay 23, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' 1F-2 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to convert 1F-2 to a single selective completion. Since we expect to start this work on June 2, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, A~e~Engi neer JBK/JG'tw GRU7/L60 Enclosures RECEIVED MAY 2 Alaska Oil & Gas Cons, Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~. STATE OF ALASKA ALASK _ AND GAS CONSERVATION .MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL E~X OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P, 0, Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 1279' FNL, 368' FEL, Sec,19, T11N, R10E, UN TD: 1499' FSL, 3897' FEL, Sec. 18, T11N, R10E, UN 5. Elevationinfeet(indicate KB, DF, etc.) RKB 115' I 6. Lease Designation and Serial No. ADL 25652 ALK 2578 7. Permit No. 82-211 8. APl Number 50-- 029-20881 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1F-2 11. Field and Pool Kuparuk River Fi eld Kuparuk River Oil Pool 12. Perforate Stimulate Repair Well Pull Tubing- ~ Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a sub ted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) [] Alter Casing [] Perforations [] Altering Casing [] Abandon [] Stimulation [] Abandonment [] Change Plans [] Repairs Made [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1F-2 to a single selective completion. The procedure will be as fol 1 ows: 1. The well will be killed with brine. Weight to be determined after running pressure bomb. 2. The current completion assembly will be pulled. 3. A retrievable packer will be run to verify zone isolation between A and C sand. 4. The well will then be completed as a single selective. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator,will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: June 2, 1984 RECEIVED Wo ,, MAY on Fora No. ~ Dated ~/~d~ ataska Oil a Gas Cons. Commission Anchorage 14. I hereby/"7 ~certify that the foregoing is true and correct to the best of my knowledge. Signed . The space~o-v~o~/C~/ission use Conditions of Appr~(~l, if any: Date Approved by Form 10403 COMMISSIONER Approved Copy l-- By the Commission Date ___ __ Submit "Intentions" in Triplicate Rev. 7-1q]0 GRU7/SN26 and "Subsequent Reports" in Duplicate KUP~ EF~I NEERiI~ D. W. Bose/Shelby J. Matthews'' · . Transmitted herewith are the fol lowing: PLEASE NOTE- BL - BLUELINE, S - SEPIA, F - F I LM, T - TAPE, _ I LIPT ~:]<K~¥LED:3ED: - PLEASE RETUPJq RECEIPT TO: ~ ALASKA, IND. ATTN: SHELBY J. /V~TTHEV,?5 - ATO! 1115-B: P. O. BOX 100360 ~E, Alt. 9951O Transmitted herewith are the follC~ing: PT.WASE' AK/I~: BL - ~.rNE, S - SEPIA, F - FTIM, T - TAPE, PC - PHOICCOPY [0_-5 /:-¼ _ · TO: William VanAlen FRCM: Transmitted herewith are the following: p~ NOT~.- ~- F- FT~I, T- ~APE~ PC -PHOTOOOPY ARCO AIASKA, INC. ATTN: ~-- ',. --~-2-2--~C-~%~ - AFA/311 ~. o. ~ox_ 3so ~/. ~~ ANCHORAGE, AK. 99510- .- DATE: Alaska Oi! & Gas'Cons, Commissior~ Anchorage TO: William VanAlen FROM: , TO: William VanAlen FREM: Transmitted herewith are the following: PLEASE NOTE: BL- BU3ELINE, S - SEPIA, F- F~I~ PC - PH.U/ocopY RECEIPT ACK~.~: ARCO ALASKA, INC. AT1N: ~v=_ v..~£.2271~.? - AFA/311 P. O. BOX 360 AI~ORAGE, AK. 99510 ~Post Office B~,,,360 Anchorage,~ ia 99510 Telephone 9~, 277 5637 February 10, 1983 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton- Enclosed are monthly reports for January on these drill 1-24 1E-20 7-18 1E-21 '7-19 1E-22 7-20 1F-1 12-17 1G-6 12-18 1G-7 13-9 1Y-13 13-98 WSW-IO .WSW-11 Tract Well 24-11-14 CIRI Wolf Lake Well #1 Ravik State #1 sites' Also enclosed are well completion reports for 2-11 1E-23 7-17 1F-2 12-19 1F-3' 13-11 1G-8 13-21 WSW-8 13-24 WSW-9 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Re~c~.r~~_l~2qA, 2-11, 13-21 (3 reports), and 13-24. · Alaska Oi~ ~& Gas Coqs~ O'ommissior~ Anchorage ARCO Alaska. Inc. is a subsidiary of AllanticRichlieldCompany ~-~: STATE OF ALASKA .-- ' ALASK. L AND GAS CONSERVATION ,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-211 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20881 9. Unit or Lease Name 4. Location of well at surface '¥E~JFIED 1279' FNL, 368' FEL, Sec. 19, TllN, R10E, UM I Kuparuk River Unit At Top Producing Interval Surf.~.___ 10. Well Number 1121' FSL, 3518' FEL, Sec. 18, TllN, R10E, UM iB.H. ~ 1F-2 At Total Depth 11. Field and Pool 1499' FSL, 3897' FEL, Sec. 18, T11N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 115' RKBI ADL 25652, ALK 2578 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 12/28/82 01/04/83 01/11/83I N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 8085'MD,6290'TVD 7940'MD,6207'TVD YES [] NO [] 1973 feet MD 1450' (approx) 22. Type Electric or Other Logs Run D IL/SFL/FDC/CNL/GR/SP/Cal, Gyro/CCL, CBL/VDL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 80' 24" 200 sx AS II 10-3/4" 45.5# K-55 Surf 2330' 13-1/2" 1000 sx Fondu & 250 sx P.,~rmafrost C 7" 26.0# K-55 Surf 8063' 8-1/2" 935 sx Class G & 250 sx~Permafrost C 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7481 ' -7539' 3-1/2" 7392 ' 7361 ' 7698'-7772' w/8 spf 7842' -7856' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. : DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7406'-7408' 200 Sx 01ass G I 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing; gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO I TEST PERIOD I~ - Flow Tubing Casing Pressure CALCULATED OIL~BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. COP E DATA . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 101407 Submit in duplicate Rev. 7-1-80 GRU1/WC22 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7430' 5914' N/A Base Upper Sand 7539' 5977' Top Lower Sand 7678' 6057' Base Lower Sand 7848' 6155' B1. L~ST OF ATTACHMENTS Drill'in§ History, Gyroscopic Survey (2 copies) 32. I hereby certify that the fore§oin§ is true and correct to the best of my knowled§e 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". 1F-2 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 2230 hrs, 12/28/82. Drld 13-1/2" hole to 2350'. Ran 55 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2330'. Cmtd 10-3/4" csg w/lO00 sx Fondu & 250 sx Permafrost C. ND 20" Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld cmt, FS, & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 7960'. Ran DIL/SFL/FDC/CNL/GR/SP/Cal. Cont drlg 8-1/2" hole to 8085' TD (01/04/83). Ran 200 jts 7", 26.0 #/ft, K-55, BTC csg w/shoe @ 8063'. Cmtd 7" csg w/530 sx Class G & 405 sx Class G extended. Instld 7" packoff & tstd to 3000 psi - ok. Ran Gyro/CCL f/7978'-surf. Ran CBL/VDL/GR/CCL f/7978'-7000' (twice). Perf'd 7406'-7408' w/4 spf. Set EZ drill @ 7300'. Pumped 200 sx Class G cmt - squeezed. Drld EZ drill & cmt to 7480'. Tstd perf's (7406'-7408') to 1500 psi - ok. Drld remaining EZ drill @ 7940' PBTD. Perf'd the following intervals: 7481'-7539' 7698'-7772' 7842'-7856' w/8 spf Ran 3-1/2" completion assy w/tail @ 7392', pkr @ 7361' & SSSV @ 1973'. Tstd tbg hanger to 3500 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Dropped ball & set pkr. Closed SSSV. Set BPV. Secured well & released rig @ 0630 hrs, 01/11/83. JG/GRU1/DH21:1 lm 01/21/83 <'.9 COMPUTATION DATE JANUARY 7. 19:E:3 ]'RUE SUB-'3.~A COLIRSE COURSE MEASURED VERT I CAL VERT I C:AL I NC:L I NAT I ON D I RECT I ON DEPTH DEPTH DEF'TH DEG ~IN ' REES 200 199.97 84.97 1 19 N 15. 0 W 300 299.95 184.95 I 10 N 1. ,{,'P W ' 400 :~99.93 , 2a4.9::: ' ..]~L..:.,......~ ...... ~-~.- ,.-~ ...... ~ --~-., ~ ............ ...~ .., .~.. ,~. t.-', . :~ .-~ ........... ,--., WJ .%~,~,,~ 800 799.87 684.87 0 45 N O, E:'~ W ~00 899.86 784.86 0 22 N 17~,1'~ E 1 o00 99,~. a4 884 84 . : . . .:,, . :::: :: ·: :. ,: :..4.: ~:i:::~ . DOG-LEG SEVERITY 0.29 O. 7:2 0.17 0.42 1150 1200 1250 11.99.10 1084.10 8 0 N 79,, 1.'-) W 3.74 1248.44 113:3.44 10 26 N 75,,8} W ~,~'.00 1 ~'-a3 ....................... BOSS GYROSC:OPIC SURVEY JOB NLIMBER AK-BO-30002 :I~G.:ELEM-.-.~---.1 !5. (:)Cl. F:r. .............. TOTAL RECTANGULAR COORD I NATES; VERTIC:AL Q ..~Z ......... 2.96 N 0.55 W 2.:26 5.11 N 0.87 W :3.84 ~ .:.:. :.: .~ ~: <: ..',: ::. :.6.26 .: :::: ::..':!:'~ ~?: I.:..::::::::: ::: .::::::: .:7, 1:3.7:3 N 1..52 W 9.69 14.71 N 1.43 W 10.23 ~ ......... ~ ...... 11...,~ ........... .. . . . 19.46 N 17.81 W 26.03 21.23 N 25.62 W 3:3.26 130c) 1297.46 11 :--:2.46 12 _!_5_, N 76. :~':> ~ ............ ._~.~._, ...........~..:,? b'.~_.bJ_. _.~.5, 17_id .......... .4'.2, '""" "w ........... '"~ .............. "~ .... 'w' ........... :' ................................................ ~ ............ .-- -.~--~ -,.~-:.--~- .. :...., . ., - ~ .... ,g~.~ .......... 1350 1346. !8 1231,18 1:3 .:40: Iq':' ' '-' "" '"' '"' '~ ' '-" N.::: .:::::: ~..~,' ~ ~'" .. :7:5, ;~ W . .::.:: ~, ~6: :: .... ..:.:: ~, a!~ , (J-.' W <.,.~. 46 1400 1:~,'' =- : :,~.-.~.: ::' e,':':a :' .:~:.::::: $' .',~:.-. ": ~ N.71 ,-~- w ~, .~<,: · . 9.,_~N '::::::~,~,0:~ U 64. il : ,. ~)4. ,.,7 1279'57 15 ' . ........ 1450 1442.55 1327.55 ........ i7 :: !~:: &.._.'"~..._::')~___J4: :'::::::'::' ' ::3"' ":::':~' ',...:,.. .:' :..~4 ;" , ~':..='~ · ~ ':: ::: 71 · ;30--t{.- ............ ZZ,..~2 ...... 1500 1490.08 1:375.08 18 56 N 67.10 W :3.67 40.40 'N 85.6A W 9'-.'.'.:31 155:) 1537 1 o 1422.10 20 4z-. N 66. '-"-'~ - . - _ o:. W as.b6 47.04 N 101.7:2 W 108.71 ¢')¢-) .~,- .- r-..-,=- -, ~_- .-,.-, .- ~ ~ - - .-, ~ ~. 16_ . 1._d.:: ...... , 14A:-,..,., --' -.'- .':., N 6., .'=,:) N .-,. 76 ....... .~L4. -..-.~_..hl .......... 11 ~ .22_.J~ ..................... ! ;2:/~, ,..~,.Q ........... ................................. ~ ............................ "~-~, . ~,'~, ,~- ,. ........................... 165A 1629.47 1514.47 24 1 tq 63. 0 W 3.49 .6.3,!! N 136.03 W 145.92 !700 1674.81 1559.8i ! 75:~ ............. ; Z.! '..-?, ~.? ......... 1.~04 ,.5_? ........ 1800 176:3.96 1648.96 1900 1,:,'-'~'-'~, ~. 19 1737.19. 2000 19:3'F~. :34 18:24.84 .................................................................... 2100 2026.78 1911.78 ~.-., 46 N 60: 60. W "'-" · " ' 4.0~ . 73' 06 N !54,57 W 166.64 · ~- ,. ,'~, . :: ::7 % : - 27 ~ N 6o.5o.w .:: ..~.:....::::~..~l._~ ' . ~.~._u .......... l~;~.~ ...... 27 48 N 61.:30 W 1.60 95.21 N 194.08 W 211.:39 2:3 21 N 61 60 W 0 ='-' ' '?':'~ 43 W . ._,,:, 117.71 N 257.79 · -~ ~' ~ = .... 29 10 N 61.39 W 0.:92 140.67 N 277.Z2 ~ .....................:;,,.J:.~ ~ ......... W .:,~,.:, 99 0 0 0 1F ~2 <:SEC 1.c/ Tl lN R10E) COMPUTATION DATE BOSS GYROSCOPIC SURVEY I<UF'ARLIK JANUARY 7, 1983 ...lOB NUHBER AI<-BO-:Ea)C)02 A.L.~s!F:A KELLY . = . ............................................................................................................................. B Jc, H I NG ELEV 11.., ~' 00 FT.~ VERTICAL SECTION CALCULATED, ALONO.CLOS TRUE .. UB ,..EA COURSE COURSE DOG-LEO TOTAL MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATER DEPTH DEPTH DEPTH DEG MIN DEGREES DEO/100 NORTH/SOUTH EAST/WEST .. :':':::v:.': . '::: ..".: .~ '.".:;'"';, "'.. "'. '.','::'.'.:' .;xf;:'.:x::..v.:'..'.'. .... T.~'...:.;.; ......'.......'. ::.:. ~:".' .". :: '' . ' "'..:' ':.'. '. '' ... ' . :....:,:...:.. .:. ":.' ... ?: .. i ,, i.,: :u ,-,.-, - '.") ,,,, .~ '. ." ...' ' ~.' ',: ' ::.':'.~"':'":: :' :'. .: ! : .'.. ' "" ::: F 2500 2366.05 · .' 4,._,., 2406 41 2168.56 33 I N 58.30 W 2251.05 35 48 N 57.69 W ~1.41 36 31 N 57.8~ W 2900 2672 63 '~-~ . . l .... ,~.63 43 47 N 54 60 W :3000 2743.~4 '~ '-":' ~6~ .... 94 45 13 N 53.69 W 3100 2813.35 2698.35 46 51 N 52.69 W VERT I CAL SECT I ON 403, s, 7, :;': ,~ ', 454.88 ~':, ' 1.90 243.24 N 454.55 W 507.61 : 2.81 273.20 N 502.47 W 563.79 1.46 288.92 N 527.44 W 593.14 ~:?~/',~;:~i~;ii',~,?,~:: ::~!~!ii~?.~O~?i:O~ "iN:::~ ~:.':':~:. 552~:.9i w ::: i:i :!' ~'§ :''''~''~ ..... ]" ......... .. " : ?.::: :~: /: .. .?: . .: . :": ?::.:: .~:.~:~: '~ :" ', '". :::. .... z ,:,~. C,~ 2.07 4~4.91 N 716.04 ~ 8~9.26 1.56 455.96 N 772. :35 W 88'P. 2'P 1.79 499.08 N 830.48 W 961.25 3300 34O0 3500 3600 3700 ......................... }~8'00 : 3900 4000 4100 4200 4300 ~.e~ !, ,~ :~ ::,: ~7~6 ? e,~.? .:'.?: :.~:,~'~:: ,::~?,~:.~:~'::~:::?:::,,:~,~::N':i:~:~:,:~::~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~ :,~ ~:: ~ ! ~:, ~ :~ N:::: ?::::.":::':.~:~':,~, 0 - ~.. ::.:':: :~..~,-,,- ~" '.-'.:::;:: :':~:::+.~::~': : ::.~:.~ ~ "'?"':~:~::~'.~::~::~:/: ~:.~::~ ~:".h:~;~'/' ~:~?.~'~?~::~::'~;~ ..... :~:::"'. '. .... :'.~':: ~:~.~: ::~:.::.~ ~ ::.:,'.:.:~: :: - ~9,. ~ . ...... ,,.,..~ . ......... :::~ { , ....................... , ~ , )&, . 3089.31 2974.31 45 38 N 51.80 W O. 63 676.30 N 1059.46 W 1250.79 3159.42 304~.42 45 1~ N 52.10 W 0.39 720.24 N 1115.61 W 1322.09 3229.92 3114.92 45 1 N 51.&0 W 0.46 7~4.05 N 1171.38 W 1393.01 ~300, ' ' '~'~ ' -'~ ~" : ' ':'~' '~ "::~::'':' :'~:"~ "??'~:~' ~ :":" c~:?~??7%~:: .... '"':"~:'.?.:'. :"?: ::~:: ~,. ~..' .~, : ~7. 1~.,7 :~:::~0~..~,~ ~ ~226.6.4 N 146:3 38 ~' .~, -:.~ ' . '. ~. ,' ~'?::: '~':f: :.. ":'":> '"::"'.:~?:.~ '~.: ::'7' :.:??.~':2~: L~:.:::h~:~'~',i ........ ;~::: :~::..~::;~.:.:);:?;;~'. ..... ~ ::,~:::,: ~:~ ~'":::' : "' ': ........... ' ~;372.7~. :'~.: :~7.74 · ....::: ~ ,:~::::: ~..~::.~:.>:: ..:: N.:. ~!~:.,'~:~Q..~ , .&,=; :.N I28 t ~,._ o c) 1 !~...::::::.: ~o0, ~ .. :~,,~...~:~.,:?~o ....~:::~.....:.N.::~.:~.~O...::?:8~:~. 4~ N 1335.50 w 1602.00 3517.98 3402.98 43 4 N 51.&9 w 0.35 935.99 N 1389.19 W 1&70.50 3591.28 347&.28 42 38 N 51.&9 W 0.44 978.14 N 1442.57 ~ 1738.52 3&65.07 3550.07 42 15 N 51.80 W 0.39 1019.93 N 1495.58 W 1806.02 4700 '~'- = ...... '-"-' . ~:~6._,. 13 :=::~5c~ 13 40 17 N 52 10 W 0 72 11o.=,.44 N 170:3 45 4800 4041.70 :3926.70 39 45 N 52.19 W 0.53 1222.90 N 1754.2:3 4900 4119.06 4004.06 :38 5:3 N 52.30 W 0.87 1261.70 N 1E:0~. .............. ~ ...................................................~ ..... ~ .......... ~ · ......... ~'~~-. c-..-.....-.- :..': . . . 5(]00 4197.48 4082' 48 :37 872.99 9:39 ~ 46 ~0 .)..,. 37 W 2(:)7(:). 49 W 2134. :3('-) ..H ................ ~ !.'.:::!~_: ,..!'?_ ............. W 2260.2 ~ 1F (~2 (SEC: 1.9 ]'llN RIOE) COMPUTATION DATE BOS:=; GYROSCOPIC SURVEY KUPARUK dANUARY 7, 1.983 dOB NUMBER AK-BO-30002 TRUE SUB-SEA CCmURSE COURSE DOG-LEG TOTAL MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEF'TH DEPTH DEG MIN I "' ~ ........... . .... ¢ ..... ' IiEoREE~, DEO/lOO Nm'RT /suur E ---,- :-, ,E~ ~m S200 42:56.9,5 4241.95 :36 40 5300 4436.32 42:21.32 38 13 s400 4si4_~8 4399.38 39 8 ,:~:,~7oo':;:?,'~::~:??,~7~a::;;:~:~:/.:::?/:i~ [~ ~: :~;8~::~::~:,~:, ~: ?~ ~ ~ ~::~'~ 5800 4818,25 4703.25 41 5.900 4892.66 4777.66 41 50 N 52.69 W 0.24 1373.23 N 1949.10 W 2380.90 N 52.10 W 1.59 1410.33 N 1997.28 W 2441.71 : ~ r~ 9 ' - .-, ~_'r, ~- · .-, ' ~.-~ .-, =' - .-, , N ,-!.8. W ., ~,~,,,.,,~, -,.,,,7 ..... -,,. ...... : ........... ~'~ :: ~:~ ':'~U~:]~:' ::' :~:~ ":, N 51.8.9 W 0.34 160.9.71 N 2250.79 W 2764.23 N 51.6~ W 0.20 1651.02 N 2303.29 W 2831.03 6000 4966..93 4851 93 42 14 N 50 89 w 0 67 1699-8c-'~ N 2':,55 55 w ..;,,:,,:~7 ,:~,:~ ·, .. ::::.:; :... . . :,: .;: . ~ , :1:::~ :,,,;;:.:::.x::., ,.: ~ ~..: ,.;,.:,,:,,..::,.,.,.,,:::::,... ..... ,.;,.,.: ::::~,: ,.: ::,:,::::,:: ::::,:,.,...,:.:x:.,,.,.,..:',:::.::...v.:,, ,.:::::..',.,: ?,:::::::::::::,::x:x:::;::x,,..'::n::,;.,::,x-':;,x]::::xxxx. x>?-.: ,xq.v<:x:: ,x ~, :,,~:'x,xxx :, .,,,,. , , ,. - _ -~ _ ": .: . ,~ - (]::: .. ' :"' '.:::T' ............. ~::.::::::l.:/'.//~:.:~:'' "..:..:/:"':.Y:~.::::C?':.:.::;:':/'.:.: ::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::: :/:'~' ~;~:::'::.'::::~,~: ;~.'~ ': :' j: ~ .- .: .: ..... 6~o 51~.:;,.~7. ~ ~07~,.~%~?~.:: ::::::..~17:~.~::~ :: ~Si:~U W 6400 5262.58 5147.58 43 11 N 50. 0 W 1.24 1864.31 N 256:3.40 W :3167.34 6500 53S4.46 521.9.46 44 52 N 49.50 W 1.71 1909.22 N 2616.44 W 3236.80 ~ ~~8~. 5289~ 45 38 N 4.9~19 W 0,80 .1~5.48 N 2~,.~R __.~::3~2,7~ .... 7000 5664.76 5549.76 53 7 N 47.10 W 1.46 2158.07 N 2896. :39 W :3610.69 7100 5723.77 5608.77 54 32 N 46.6.9 W 1.46 2213.22 N 2955.2:2 W 3691.12 7200 ~ ~ 2~{ ] 5~6~.~ 5~ !E_ N 4~, ~0 W 0, 72 ~69, 4:3 ~ .... =_ 3O.l.~_Z~...~ ......... 87'Z2..~ .......... ~ 73o0 ~a, ~c?:::~.',.~ ~72~, ~0 ~: :.:] :':: :' ~4~:'~: ~ :: ~: ~:.::.~ :~::::<~?~.::::::~:~::~:.~::~']~ ~9 ~N ':'. ':?o74 ~ ~ W ~4, ~4 7~°O ' 5.9~4,4~:::; :::::: ~839.4~ ':::::::'~: ~4 ::::::::~:~'?~8_~~.~..--:.__~1~.2~ _ 7600 6012.38 5897. :38 54 34 N 45.80 W .0.41 24.95.55 N :=4250.25 W 4097.49 7700 6070.15 5.955.15 54 51 N 45.3~ W O. 42 2552.66 N 3308.57 W 4178.64 7750 6098..91 5,~:=:~ 9 5 ~= -9 ' = .-.=,~ .=.- .~.~c, , ........... . : . ~ : ,;:~x... : , · : .: ;::: ::.:,.:~: x: ::: ,: ..... ~ .: :.: .. .~" 7. ...... ~ . '5 ~ ' ~ ' '~ ,:.:., · . : ~ ,x:.,:,: ,, . ..; ..... .:,::,, ,.;, ~ . :::" :' ::.. ~w, ~ - ~ 7800 ~' ! 27. ~ :.' 6~ !~, ~ : ': :~ · ::~:..1 ===================================================== ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~. ::::::::::::::::::::::::::::::::::::::::: ~.~::~.! .: ~ :::::::::::::::::::: :::: ::::::7 . U~ ~ ..:.. ~260.0~ :' :;. ,0 0 0 1F I~2 (SEC 19 I'llN RIOE) CONPUT~TZON D~TE BOSS GYROSCOPIC SURVEY kUP~RLt,. ,J~NU~RY 7, ~983 JOB NUMBER ~K-BO-:30002 AL. ASK~ ~ELLY BUSHING ELE~_~ llD~J!(!.,F~.~ TRUE SUB-SE~ COURSE COURSE DOG-LEG TOTAL MEASURED VERT [ C:~L VERT Z C~L ] NCL Z N~T [ ON D Z RECT Z ON SEVER Z Ty RECTaNGULaR COORD Z N~TES VERT I C~L - '' '-'~ I ' DEPTH DEF'TH DEPTH DEG ~[N DEGREES DEG/IO0 NURI H/=.LL ] H E~ST/~E.,T SECTION ~,,.,ooc'""-': 6290.41 6175.41 55 7 N 43.60 W O, O0 2778.48 N ~._,~'":'-"-;~. 24 W 4491.71 HORIZONTAL DISPLACEi~ENI' = 4491.71 FEET AT NORTH 51 DEG 47 MIN. WEST AT MD = '"'"'= . i.:, ¢3 i'-, 1F #2 (SEC 1:-~ Tl lN R1OE) COMPUTATION DATE I I<UF'ARUK JANUARY 7, 1Sz83 dOB NUMBER AK-BO-30002 I ]'RUE SUB-SEA TOTAL ? ~ MEASURED VERT I CAL VERT I CAL RECTANGULAR COORD I NATES MD-TVD VERT I CAL : ,,, ...... ....... . ] . 1000 ~'P~. 84 884.84 15.58 N 2.57 W O. 16 O. 16 2000 1 ~3Sx. 84 1824.84 140.67 N 277.72 W 60.16 60. O0 ~ 3000 2743. ~74 2628. ~4 455. '~6 N 772.85 W 256.06 1~5. ~0 7000 5664.76 554'P. 76 2158.07 N 28'P6.3~ W 1335.24 302.17 8000 6241 . 81 6126.81 2727. '~7 N 3481 . 15 W 1758. lt~ 422. 'P5 ~ ~.~ ~i ~i ~liZ5~.4! ........... ~.~....~ ............. ~?~.~..~.~....~ ........................... ~.~.74.~..~? ....' ~ , ./ : . . . :'~.. ~.~ :~: ~ ~ ~i~::!.,~.~..:. .~ .:. ............................... .,~ , 0 IF #2 (SEC: l'.:~'TllN RIOE) COMPUTATION DATE I<UF'ARUK JANUARY 7~, 1983 ALASKA .......... :-"~ ' ............................. :"--'.'. ........... "I'RLIE '-'1 ' '" .=, _IB-.=,E~ TOTAL ::!:::::i:::::::::::::::'::::::'.:S ::: :.i:::i::::: :'::':::.:::::,, ' '.:::: ::::::::::::::::::::: :,:':::::: ::.':?:.i::::: ::' ::::::::'::: .:,: :' :,, :::::, : .' : ' ,...lOB NUMBER AK-BO-30002 MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL ';:i':"'"ibEPTH' ...... ;"" ........ ,DEP'¥Ff-" .......... ': ....... ::'7: .:,::~.~,:,:. :. ,,,~ 215 215. O0 100. O0 3.30 N I I 0. ~'S~ W 0. 03 0. 02 315 315.00 200'00 5.42 N 0.88 W 0.06 0.02 715 715.00 600.00 12.50 N 1.48 W 0.12 0.02 815 815.00 700.00 13. S~3 N 1.52 W 0.13 0.01 '~15 '~15.00 800.00 14.81 N 1.40 W 0.14 0.00 1:::17 1315.00 1200.00 24.4:--: N 38.87 W '2.95 1421 1415.00 1 :_--:00.00 31.65 N 63.45 W 6.20 15'26 1515. O0 1400.00' 4:::. 80 N '~3.71 W 11.40 174.4 1715 O0 1600. O0 '"'" '-'~ .... =,z, ,=,~, N t 71. :~0 , :::: :2~. 8~ :: ': · ' ......................... : :::.-:_7 .......... ~ 8.~:~ 0¢ ............... ; 700, (p ....................... !r;~,=:::.~:...~ .............. ~ ;Z;..78 E_. ~::....: :...:' :.,~2':"7~ · 1.8? :,]. 5~2! 7 ....:'77 1F ~2 (SEC: 19 TllN RIOE) I<UF'ARUI<: ALASKA '~ ........ ~-" .................................................................... ~ ................................................... ~ ...... 7--. .... ..... .. COMF'LITATION DATE JANLIARY 7, 1983 ._lOB NLIMBER AI<-BO-30002 LE~.: = 1.=;.r'"~ ]"RIJE :E;UB-SEA TOTAL MEASLIRED VERT I CAL VERT I CAL RECTANGIJLAR COORD I NATES MD-TVD VERT I CAL ......... 7-'"."';'"'~ ........................................ i .... ' ................................... ':':: ......... ~ .................... : ....... ":"' ;' ~ -?''' ',:4':'~ .......... . '"'-'~-:'.~'; '"'~';;7 "'""" ~i~¢-:''7~'':'' i'!"-~,'--:;:' :'~:':-' ~ :?~:..;i~::~:>.,' · '---4:'-' ' :,""~-~'~. ? ' ,, ~:: :' .:: ::: i: .. ' : ~ :. ::: i:: pEF 'I H. : . I]EFTH DEPTH :. Jq~-*R! H/:,0I-!TH.:: ~ ~:!~.E.'.~..L.].Ti:~:~?:i!:::::?:i:!:::i!:::~::: .:. : :'":' ':' ",--_,~' o ~ "' ,'."" "~ ;--~ .... :::i:::r=::~: _. ':.i:' ?:.'.i' ~::~:..?::~.~ ::%: :' ??!:..:::!:.?:.:.:''.:~: .' .;::~: ::i~: :::.:" !:~i!.!i'.:::.~>:.'::::. : .~:::~?:::~: : . ' ' 1~71 1.1<.,.~0. !o~'~.~'~ ' 1",4,0;..'~ N' '"~".,"d"'~ ..... _, :~'::' ............ ': ..... :'"; '~ ....... ................ -- ..................... :..:.. -_ , .....". , _.- ~. ~,=5.~ W .... .:.~_~, ~,. ....... . ...... ... :.: .... I,...~..::..:. ;.. . . 2086 2015.00 1900.00 161.25 N 2202 2115.00 200A. 00 190.13 N 2318 2215.00 21 O0. O0 220.63 t',l '-" '~' -'54. . : ...... .-. ....... : ' 2~,88 ': :. 2~15.1]0 ' "24r~0 00:' 335 ;82 N _--~ ........... ; ........... ~ ........................... z ......... ~ .................... ~_ .~:. · ' :':' 2821 · 2615.00 2500.00 384.01 N 2958 2715. O0 2600.00 438.71 N · :o 1 ,.. O0 W 71 ":'9 I . 1.1 , 365 89 W 6.:7 '-': · · , .,S.--~ 417.56 W 10:--:. 87 14.84 15.86 16.62 ::i77 ::':: :' ':: "' ':~ ~' ....... --~-':--'~--'-~::' .......................... ' .............. 671.86 W 206.07 3'2.7'.-? 74~.. 36 W 243. 'P2 37..:.,.'-'5 3678 3215.00 3100.00 754.77 N 1159.68 W 463.89 3819 3315.00 3200.00 816.10 N 1237.46 W 504./_-,5 3'F~58 3415.00 3300.00 875.6? N 1313.20 W 543.52 ........................ ;'~ ~ ..... : ..... ;~;~-'~'" -~,.-:c, "' ~ .... '= ..... . 'i~ 1.6~ N 14 .... 71: W .... 617.':Z~:'. ". 4~.: ~ o61 ~,. ~, I .-,~,~ ~ ~. 0< ~ c~ u ' -, 5':~ . :..... ____4367 .......... 42.14 4<'1~. 76 3:s:. 88 ._lOB NUMBER AK-BO-30002 L1..~.. ...... ~..T. , TRUE SUB-SEA TOTAL MEASURED VERT I CAL VERT I CAL RECTANGULAR COORD I NATES MD-TVD VERT I CAL ::: ::? ::'.?: ....... ~ ,. ":. ::::h:~. ~i:,~, ~. ~::' 4'.. .:.-;. ' -' '::: - ' "': ':::::~'?': :'"':":.::.' u:::::::;u:!uu!i~ :f:?.?.""'"~:~!! i;,~;'i~: i "~ ! ?: :?..: !:: ~: i~::': :":.:"': :~ ' ?::':'.~. :::::::':~:'.: .~.~. :. 4,.:.,0 :il,: .w,', :~;,~ ! ~,,,'00 '~..::70o'.,:o0.::~ .,:,, i :'.': :~'.',::?:.,,:'~?~ ~:a)l.r~, O5 :~:W.,:::~:~::~r~;m:~:',x???::.~,~'!6~ 4"::,.:?.. ...... ::~ 46~4 :39:15. O0 3800. O0 1157.14 N 166~. 75 W 719.12 :32.8:3 4765 4015.00 3900.00 :1.202.29 N 1736.68 ~ 750.27 :31.14 4894 4 ! 15.00 4000. O0 125~. 70 N 1801 . 7'5 W 779. 7'."".,' 2'F.,'. 52 5400 4515.00 4400.00 1449.12 N · _ ._,o,., 461._, =. 00 4?]AA._.. 00 1499.78 N 5661 4715. O0 4600.00 .._~.~'-' 48 N ................ : ...... ~:" ~'~= ..... ~]z~ '-'-~' "7~' = .................. :: .......... c:'- ..... . C~ ' . .: ,.,7Y.~ 4,:,1 ~,. Oo .~: 47o0. OO 1.607. ~ O .:.. : .': ~ ~,~ : ::>. :: ,'. ~" L' ::.'~:.: ,.:,.' . .:::.:~::.<. :'::~::f. ':~'~::.?::..:~,:"~.:~:: :':~: ~2~: ...... ..~215, o0 ::.: 4~,o0,o0 .....: ::: '": ":':::':' =' ~ ' ~'' '" ' :":::'"~:~: :?:':" .... : .:~ ~,064 ~,01o. O0 ' 4~00. O0 · :'..:::~ 17~ 62(30 5115.00 5000.00 1778.31 N · -~ .-m ~ ~ ~ -- . 6oo.. 5215.00 5100 00 1835.92 N 6472 5315.00 5200.00 18'Fy6.63 N 6614 5415. O0 6'~ 18 5615.00 .............................................................. 2046.93 W 885.80 27.94 2111.54 W915.18 2'~.39 2178.31 W946.47 31.29 ' :~' :,..:::::::::': :":':, :,~"' ~::: :!i:::::~ :::i?:!:': '3 1,6 '::': '::?::::: : ?.:~:¥'.':?~ :..:: ,::::.:::.:::.:: ,.-,,,~:::':~,6::.:::, : :.:::. :..: ..,..: ,::: x:::,:,..}~,. ,w,:..,.:r.. ;:... : :7 ' . .. '.' ::: :::: ':: :3~r,:.98: :.:' ' 2459.82 W 1085.23 7:5.28 2529.46 W 1120.02 34.7':? 2601.71 W 1157.53 37.51 5::-:00. C30 1962., ~6 N :: .... ~,7~. 1:'7 W:. :::' .:.'.: 1'' 41.97 5400 00 203~, ~'~ ' :: : : : :: ::::: ::: : :: ::::: :: .... ~':: ~ ~ ~ ....... " o~. N ~z~.,~, ~.:~: :::::::::::::::::::::: .4~,~.~,~=,' ~'-' . ......... 5:.C.: ............ .... ~ r ' .... ._,._, jo. 0<~ .......... ~ 113.9~ N : ::.. 2848.. 6~:'::::W'::::" ' :.:1:';::03,: ! 4 :::::::::::::::::::::: ..,,,T. ~.... © 0 0 ,xx:,.~':x'.:~; :x:,., , ,~ ~,... ,~, .,, ,~'~ ,.xx:, .~ x;,.,, ~' ~,~:. ,',;:xx;:',:x:;xx,.::,.x:;;;;,.:x,,,,;,x::,,;m::;x;xx ,.: : x:: x~;xx:~x:~x::~:' , ~::'':;,',x:~ ,.::x:': , ,: ,::~: · 1F ~2 (SEC: 1~ T11N RIOE) C:OMPUTAT!ON DATE I<UF'ARUK JANUARY 7, 1'~83 dOB NLIHBER AK-BO-:30002 i. ALAS:[::'~ ~ ... , ..... = .... I'RLIE SUB-SEA TOTAL MEASURED VERTICAL V, E~T_I_ C:A_L _RECTANGU_LAR COORDINATES MD-TVD VI~F~T I~AL ......................... -"1 ~ ~ 7~3~ ~'~ ~ ~ O0 ~'-" '. '~' ' ' ~ . .' : ~ ......... ..: .... '..x........ x...:.x: x.....;.:xx::x'..'~x...x,'x..:;..xx.,.~. ~:. '..'. x :: ~ ~ · x , ,' . ~ ...... ...' ........ x..'.' ........ :~..........,..... '...... ~:~..'...:...>:x.x.'..:.>.:,:....::.A.::>:.:.::.',.....,:..~,~.~ .... , xx:....: ,..~.;:~.~:~x..~:~x'~:~;~:~x:::;::~:~:x.~::x .~:...'.; .~, x.... '...: .xx:. ~ .::: ' . :~. : . . ~ ~ x .~........x: :: .... i~ :. m.... ~'.x :.,~, x.x:. ~ 'xxx:xx~...;".:........x .'~x ~ xx'.'~.x > x :x: ...x ~' . . .~...~. ,.::.?~...>'.:x:x~...~...xxxx:..x::mT...,.;.....:,.:.,........... ]'HE C:ALCULATICIN PROCEDURES USE A LINEAR INTERPOLATION BETWEEN 1F #2 (SEC 19 Tl lN RIOE) I<UPARUK ALASKA ]'RUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES " ' ~ .... >l', "x?.="~i-:'. ;i~7:~:~:i ", ';~'.;;:: :i :;?,!;~x;:;;i: ;? ~;: ?,: ~'"'' !m! ;" ii!!!Yi!i!ii!~'~i!~'?~ ' ' i~'?'?'!~"'i~' i"!;lii ?i:',iiiiiii!i!iiil;!' ,~ '~;~, ,,?.~' ,'.~!, ,!!iii!!!!! ?i i~ii!',~ '" ". '~'. ' ~' ' "/,?, i'! ~i ~i ;!! ,,~! ii! :i?! i;~i !;:i:~';: 7~------~;.~.~77';'0~ .......... 58~2'~'~3~ '24~.0',"~75'" q 3214.56 W BASE OF UPPER SAND 7678 6057.48 5'~42.48 2540.03 N 32~5.76 W TOP OF LOWER SAND 7848 6154. 'B 1 603;~. ~ 1 2637.70 N 33~7/5.11 W BASE OF LOWER SAND 0 0 0 STRAT I GRAPH I C oUMMARY DERIVED USING DIL DEPTHS AND SPERRY ~UN oURVEY DATA TOF' OF UPPER SAND SURVEY DEPTH F'BTD TOTAL DEF'TH nRILLER ~'A'-'~' 7430 5913.84 5798.84 7.900 6104.64 6069.64 7?,40 6 o7.5o 6om . 62.90.41 6175.41 SEC 19 T1 IN RIOE 23'P9.51N :3150.4:3W 2668.56N :3424.57W 2692.32N :3447.20W 2778.48N :3529.24W : . ,,, 1 ) FR JM LINEAR. EXTRAPOLA~!UN:. BE:LUW '..[.'~EEP~T:::'::' i: .':'.: '.:: ) COMPUTER PROGRAM :~ SPERRy sUN: THR_EE:'!::.DiaE~SI'Oa~:E.'::'i~RAD'I:!~iS:!IIOF . .:'::; .' :.. :. DATA CALCULATION AND INTERPOLATION BY RADILIS OF CURVATURE COHPUTA. TION DATE": ':'.: :!i::::':' '1 ' "" """ ' '" ' '-* ;'::'::'~':' '''-~ .... i JANUARY 7, 1 .983. . .: ::~.:.~ JOB NLHBER AI<--BO=~VO!;Iz ::.. KELLY BUSHING ELEV. = 11.5.00 FT. 8Q85 ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No, AK-BO-30002 Well: 1F ~2 (SEC19. TllN R10E) Kuparuk Field North Slope, Alaska Survey Date: January 6, 1983 Operator: Tom McGuire Scale: 1" = 500' TRUE NORTH -2500. O0 00 500. O0 000. O0 O0 --4oho. oo -~5bo. oo -~obo. oo -~sbo. oo -~obo. oo -, sloo. oo -,oho. oo -sob. oo HORIZONTF~L PROJECT I ON Surface Location (1279FNL 368~ED l_500.00 0.00 1000. O0 ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-BO-30002 Well: iF ~2 (SECl9 TllN R10E) Kuparuk Field North Slope, Alaska Survey Date: January 6, 1983 Operator: Tom McGuire Scale: 1" = 1000' 2000.00 3000.00 4000. O0 5000. O0 6000.00 4491.71' @ N51° 47'W 7000.00 I t O00. O0 2000.00 3000.00 4000.00 5000. O0 VERT I CfiL PROJECT I ON Suggested .form to be inserted in each "Active" well folder to d~eck for timely compliance with our regulations. ' Oper. at'or,-/W-e,~ 1--~ame ahd Number Reports and Materials to be received by: Date Required. Date Received Remarks ! , Ccarrp le~.on Report Yes Wel 1 History. . .. .,, Yes .-, . Mud Log . _ . ...... ~/~, ..... /gt .... d K ' · .,, . Core l~scription , . Registered '~ey Plat Dire~iOnal ~ey Drill St~ Test Re~s ... . . -. ARCO Alaska, Inc. J'~ ~ Post Office [5 .,60 Anchorage, Alaska 99510 Telephone 907 277 5637 January 13, 1983 Mr. C. V. Chatterton Commi ssi oner State of.Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage,: AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are monthly reports for December on these drill sites' 1-24 13-14 1G-7 2:11 13-98 1G-8 7-16 1E-22 WSW-8 7-17 1E-23 WSW-9 7-18 1E-24 WSW-IO 12-18 1F-2 Tract Well 24-11-14 12-19 1F-3 CIRI Wolf Lake Well #1 13-11 1F-4 Also enclosed are well completion reports for' 1-22 13-13 1-23 14-6 6-24 1C'1 7-15 1C-IOGI 12-20 1E-25 13-6 The survey for 2-22 needs to be reran; a completion report for this-well will be submitted when an approved survey is received. We also are including Subsequent Sundry Reports for 7-17, 13-6, 14-6 and 1C-1. Since the information on the Wolf Lake and Tract wells is of a confidential nature, we would appreciate it if you could store in a secure area. Sincerely-, P. A. VanDusen District Drilling Engineer PAV/JGL28'llm Attachments. JAN ! 4 ^nch0rage ARCO Alaska. Inc. is a subsidiary of AllanticRichlieldCompany ~-- STATE OF ALASKA J-- ALASKA~ .AND GAS CONSERVATION CC AISSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-211 3. Address 8. APl Number P. 0o Box 2,60, Anchorage, AK 99510 50- 029-20881 9. Unit or Lease Name 367' FEL, Sec. 19, T11N, RIOE, UM Kuparuk River Unit 4. Location of Well 1279' FNL, at surface 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 115' RKB ADL 25652 ALK 2578 10. Well No. 1F-2 11. Field and Pool Kuparuk River Fi eld Kuparuk River Oil Pool December 82 For the Month of. , 19__ 12. Depth at end of month, footage drilled, fishing jobs, directiOnal drilling problems, spud date, remarks Spudded well ~ 222,0 hfs, 12/28/82. Drld 13-1/2" hole to 2350'; ran, cmtd & tstd 10-3/4" csg. Drld cmt, FS, & 10' new form. Tstd form. to 12.5 ppg EMW as of 12/31/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 10-2,/4",45.5#/ft,K-55,BTC csg w/shoe @ 2330'. Cmtd w/lO00 sx Fondu & 250 sx Permafrost C. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run None I 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. AJaska Oil & Gas Cons. Commiss[or~ SIGNED ~ /.,,,,~'./,'/N-,J__/'. /' ~ ./ /I/LI:: DATE e/ /'~ - ,,....- ................ NOTE--R t on thiv .orm is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Ga~s Conservation Commission by the 16th of the succeeding month', unless otherwise directed. Form 10-404 GRU 1/MR22 Submit in duplicate 1F-2 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 2230 hrs, 12/28/82. Drld 13-1/2" hole to 2350'. Ran 55 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2330'. Cmtd 10-3/4" csg w/lO00 sx Fondu & 250 sx Permafrost C. ND 20" Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld cmt, FS, & 10' new form. Tstd form to 12.5 ppg EMW as of 12/31/82. JG/GRU1/DH21' 1 lm 01/11/83 MEMORA IDUM TO: THRU ' FROM' Lo nDie C. Smith Commi s si oner Ed~ar ~. Sipple, J Petroleu~ Inspector State of Alaska C. ~.~tt.erton DATE: January 6, 1983 Cha~k~ .~ FILE NO: 108A/E TELEPHONE NO: SUBJECT: Witness BOPE,; Test on ARCO' s Kuparuk 1F-2 Sec. 19, TllN, R10E, Permit ~o. 82-211 Doyon Rig 9 ~huroday. Decgmber 30. 1982 - I traveled this date from Ro~n 34 (subject of another report) to ARCO's KuF~ruk 1F-2 Doyon Drilling rig. The drilling rig was in the process of nipp lin9 up. The BOPF.--- test comn~nced~at 10:00 p.m. and was concluded at 12:20 a.m- Friday December 31, 1982. There v~s one failure, the upper ~kelly valve .failed. The upper kelly valve was %~orked and circulated through, it ~s retested to 3000 psi satisfactorily. I fille~ out the A.O.G.C.C. BOPE .test report which is attached. In summary_., I witnessed the EOPE test on ARCO's Kuparuk V ~ Doyon Ri~ No. 91. 02-001 A(Rev.10/79) ~ TAI E ~'~ A£A(JKA ALASKA OIL '?AS EDt!S[.;RVAT [~ 'i~ ._.f~y,[SSIO~ B,O, ~-.E. Ins[~ection l-tcbxDrb Location, -Genera]__ Well Sign Cenera 1 Housekeeping .!~c~or WelI .i-¢. ~tion: Sec ;~ T;INRI~F H ~ ]D~ Casing Set ~ ~~9 ft. ~11 O~ar~e ~es~rc ~950 Reserve Pit Rig, BOPE Stack · : Annu3~r Preventer - OKi- ' P, ipe~ ~ams : ~ ~ke ~e Valves ..... ~,c:N.'-~ .. ' '~ ' -~::~ ~ ~~ Val~ Test Pressure psig psig O _rrfi_n ~scc. Pressure After Closure Pu~,i) incr. clos. pres. 200 psig Full Chazx3e Pressure Attained: _ ~ rain 07sec. ~.~ ~ .,~,~ ~'~ psig Controls: MaSter C ~.~. ~/-/~-~$ Remote O .~.__ B1 i nds. swi td.. L..qov__c.r. Kelly and Floor Safety Valves · Upper Kelly r~&~. Test. Pressure -'~ Lo,ur Kelly. ~-~ ~est Pressure Ball Type .... ¢.~Test l~-essure Ins ide SDP___~eSt Pressure Choke b~nifold ~./% Test Pressure 3~00 , = _ Repair or Replacement of failed equipment to be made within ~' !,~"t~f~s ~ · Inspectoq/Cc~mi~Sion office notified. "' ':"' q'~¢' ~ '-'3 oo o P~ ; ) ~.-~ / ,~._,¢ /.~ ~ R~,¢-o,-,, ~r~ tl ,~,~ ¢, ~* g~. ,~" I 0 : o o ,~ ,,~ Distribution orig. - BO&CCC . CC - Ope. ra tot cc - Supervisor December 10, 1982 Mr. Jeffrey B. Kewin Senior Drilling Engineer ARCO Alaska, inc. P. O. Box 360 Anchorage, Alaska 99510 Re: ~.uparu~'~ River Unit iF-2 ~ Alaska, ~n¢. Pe~it' No. 82-211 Sur. Loc. 1279'~L, 367'FEL, Sec. 19, Tllit, - R10E ~ole Loc. !489'FSL, lO08'~L, Sec. 18, TIllS, , · Enclosed is the approv~ application for hermit to drill the above referen¢od well. · ~ -' 'w~' i'm conducted, a one cubic inch chi~ fron~ each-foot; of reCoverc~d core is ~, '~ . r=qu~red Samples of well cuttings and a xo~ are not required. A continuous directional survey is ,' ' 20 AAC 25.~-~ requmre~ as per ~O(b)(5). If available, a tape. containing the digitize~ lo~ information shall be subnitted on all logs for copying except experi~ntal log~, velocity surveys a~ di~me ter surveys !~any rivers in Alaska amd their drainage systems have been classified as important for the spawning or migration of ana~r~ous ~is~- ©peration~ in these areas are subject to ~%S 16 n~ 870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you ~ay be contacted by the Habitat Coordinator's Office, Depart~.~ent of Fish and Ga~e. 'Pollution of any waters of the State is. prohibited by AS 46, ~hapter g, ~r~_.cl~ 7 amd the regulations prom~_lgated thereunder (Title lg~ Alaoka-Administrative Code, Chapter 70) and by the recera!-~'~ter Pollution Control Act, a~ amended. Prior ~o ~g operations you ~ m~y be contacted by a representative of the Department of g~vironP~mtal Conservation. To aid us in sche~duling rield 'wot<, please notify ~" office 24 hours prior to c~mencing inmtallation of the blowo~=~t Mr. Jeffrey B. Kewin Kuparuk River Unit 1F'2 -2- December 10, 1982 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. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation $o that the Commission may witness testing before drilling below the shoe of the conductor pipe, In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a · ~ritness present. Ve~y_ truly yours, Chairman of ~¥ ,~ ........ ~.~o~ Alas~ Oil and Gas ConservatiOn Commission Enclosure cc~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. CVC:be ARCO Alaska, Inc. Post Office B~. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 8, 1982 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1F-2 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 1F-2, along with a $100 application fee. A diagram showing the proposed horizontal and vertical projections of the wellbore. A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. Since we expect to spud this well on December 21, 1982, your earliest approval would be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Sr. Drilling Engineer JBK/JG:llm Attachments JG1/L1 Oil & Gas Cons. commission A~ct~o~a~ ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA "'"', ALASKA (J,L AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL JO[ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPH lC SINGLE ZONE ~( MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. 3. Address 360, Anchorage, Alaska 99510 RECEIVED P. O. Box 4. Location of well at surface 1279' FNL, 367' FEL, Sec. 19, TllN, R10E, UM At top of proposed producing interval 1320' FSL, 1225' FWL, Sec. 18, T11N, R10E, UM At total depth 1489' FSL, 1008' FWL, Sec. 18, TllN, R10E, UM DEC 0 9 I982 Alaska Oil & Gas Cons. Commissi Anchorage 9. Unit or lease name Kuparuk River Unit 10. Well number o.n.1 F-2 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5, Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. PAD 79.4', RKB 115' ADL 25652 ALK 2578 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 1008' FWL ~ TD feet F-3 well 120' + @ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 8048' MD, 6240' TVD feet 2480 12/21/82 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2464 ._ psig@ 80°F Surface KICK OFF POINT 1000 feet. MAXIMUM HOLE ANGLE45,5 oI (see 20 AAC 25.035 (c) (2) 2762 psig@ 5840 ft. TD (TVD) !21 Proposed Casing, Liner and Cementing Program SIZE J Hole 24" 73-1/2" Casing 16" 10-3/4" Weight 65# 45.5# 8-1/2" 7" 26# 22. Describe proposed program: CASING AND LINER Grade Coupling Welded H-40 BTC K-55 K-55 BTC Length SETTING DEPTH MD TOP TVD 80' 36' I 36' 2263' 35' I 35' I I 33' I 33' 8015 ' M D BOTTOM TV D 116'11 116' 2298' 12200' I 8048' 16240' I I QUANTITY OF CEMENT (include stage data) 300 c.f. 1100 sx ext. Perm 250 sx Perm C 200 sx Class "G" ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 8048' MD, (6240' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Tesb pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure will be 2464 psig. Pressure calculations are based on current reservoir pressure. Surface ipressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be lleft in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the iKuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested iupon completion of the job. 1F-2 will be 120' from 1F-3 at surface. Their courses are divergent from there. · 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED //~~~,~.~ TlTLESerlior Drilling EngiQeer The space b~ f~l~C~oTiss~rl/use CONDITIONS OF APPROVAL DATE Samples required Mud log required Directional Survey required APl number ~]YES ~-NO []YES ,~NO J~YES [[]NO 50-- O'~ -7.,~ ~'~ Permit number SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY DATE ]}P_£grlrlhP_T 1 f)~ 1 9R2 .! Approval date ~'~~,COMMISSl ON ER // Form 10~401 Submit in triplicate ! ~ : i : ! : :.' : ! ~ '. ! i, ::iii: I :' : : I : ~' ~ ~ : i : ~i _L~_~__L_._:__ :_~ : i ::~: I-'~ ~-:1-: ....... !~:'---~-P"--~ :?:~' --'~ :-:-~-: ~-~-:-7~-:-:--' ~--~:T~ ~7 '1 } ' ' ' ; ' ' !il ~1~ : : ' i : : : ~ ' ' ' : ) ' :~ ~ : " .............. ~,,~'i""" '~S ............ ; ; l~ i , , ' ~ ' ' ; : I : , ' ' , " NDS; :; f~6iO0; Ti~DiZS,' .... ~ .... , · : : ; : ~ : . . . · : s , : : , _ ...... ~ .............. + . . . . ~ ~ . . , . ~ . . , . ~ , i ~uuu~ ,~UUU -uuu~ ~ ~ uuu ~ ~ ,.~ ~ Ii iii ! I ~ iii ! I ~ I I [ ! I ! I ¢-~-~44 : ~ I ' : ~ ~ ~ I [ · , ~ · ' I , , ' ~ ~ ~ · ' - ' ' . . I ~ I , : : , , i ' i ' ' ~ ~ : , ; I ~ ~ I ~ ~ ~ i . , . ~ : ~ , , . , ; , . ............... ~ i · i , . . , . , , , . . . . . : , ,. ~~~ ~ . . ~ ~~~ ~~ ~ . . _.~ ; ~ -~ : , . : · : : : · ·, : . ~~~~ , , , ~~~~ ....... ~, ~ - , : . : · ~ ' · ' - ~~- , , · ' ~ , ~ · ~ I ~ , ; I ! i : ~ ' ' ' ' ' ' ' : ' i ' - ~ , - : . · , , ~ .... , . . ~ - ' ~ ~ , ~ : , · : . , ! ; . - : : : : ~~~ , ~ ~ . : , Surface Dive, .r System -®. O. . Maintenance & Operation Upon initial installation close annular preventer and verify that ball valves have opened properly. Close annular preventer and blow air through diverter lines every 12 hours~ 1. 16" Bradenhead. 2. 16" x'20" 2000 psi double studded adapter. 3. 20" 2000 psi dri.lling spool w/lO" side outlets. 4. lO" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automatic cally upon closure of annular preventer-. 5. 20" 2000 psi annular preventer. 6. -20" bell ,nipple. 16" Conductor · RECEIVED DEC 0 9 i,982 Alaska Oil & Gas Cons. Commission Anchorage. . 3~ Close annular preventer in the event that gas or fluid flow to surface is · detected. If necessary, manually over~ ride and close ball valve to upwind diverter line. Do not. shut in well under any circum~-~ances. --' 5000 PS1 ,~SRRA BOP STP~CK 2. 3, 4, 5~ : _ _t_.t BLIND _1...-1 o PIPE RRNS . )'7'(.--' C ). '.. ' > ..- ... . · . CSG J..---" -D C0-9. 982- ,. 3. 5. 6. 8. - . 16" Bradenhead 15" 2000 PSI x lO" $-~S3 FSI czsing head 10" 3000 PSI tubing he:_d lO" 3000 PSI x 13-5/8= 5000 PSI .. adapter spool 13-5/8" 5000 PSI pipe ra:s 13-5/8" 5000 PSI drilling s-pool w/choke and kill lines -_- .13-5/8" 5000 PSI pipe ra~s- '-.... 13-5/8" 5000 PSI_bli,~d ra~s -- 13-5/8" 5000 PSI anr~lar --. '- -_ . · _ _. _ .. - 10. 11. _. C -1 ~ -Alaska Oii & Gas-Cons. Commissi~lr~' _ -' Anchorage 14. '-" ';'----- .... : -. T ' . - ' -'- --' - ..i. -. . . . . . -: . . _.~.:.~'~ . ·.. . :- ~ --_-- ..-- _~ . ACCh:IULATOR C2,P~ITI' TEST - . /~ ~._ ...'- . . _. C'-~C~-A~','O FILL ACCL~%q_R%OR -~..~..SE~'~I~- ~ p,ci~DPL-~ ' : '--'- Lc~'E[ WIT4 HYDRAULIC FI. OID; _. A~SL~ THAT A£O~-~.~._A¥O~ PP~..E I~ ~ PSI -- Will.[ 1500 PSI DO'.,~'i'R~I O~ 0~$ERYE TIME Th=.N CLOSE ~ L~ITS ~..,.~LI' A,qO RECORD THE T]~ ~ PR-"~-qz_~ .~..qIl~- ' PU:--~ OFF.. . _ ~.~,AIIIII,'G PRESSURE. - 13-5/$' EOP, STA;.T.': TEST FILL BOP STACK A~ M~Nzr-OLD l~l~l( ~?J:3'IC DI-CSEL. C~EC3: THJ~T ALL HOLD ~ 'SC2~)~ A~_ FULLY TRAC'TZD. PREDETE~-'.IIiE DEPT--' T?,AT ~ k'ILL SEAT N-a3 SEAT I,~ W~I.t----___~. Zl~ I~ LOC~ DOJN SCR~S IN HF.~. CLOSE A~L'{ULA~ PR~cNTER AND C~.:LKES ~ YALYES 0:( ~bLqIFOLDo TEST ALL CC~4POF~'ITS TO Z50 .mSI A~'~ )=~3LD FC~R lO MlhqJTES. It~--REASE PRESSUP~ TO 1800 PSI A~;D FJ~..O FO?. l0 XIhq~FES. BLEED TO ~0 OP:J{ .At~,"dLAR PP~T~,---TF'6~, A~(O O.~E ~ SET OE PIPE I);C~EASE PREssbT. E TO 3C00 PSI' ~J{D h'C~_O FOR l0 CLOSE VALVES DIRECTI.¥ U~I~..A'( OF C~o ' BLEED DG'.~t(STRF.~{ PP. ESSb~ TC ZE.RO PSi TO TSST YALYES. TEST P~L!Ii!)G UNI~'-'~_ ,e.~ ,TI FOLD VA. LYES, IF ~(Y, RI'TH 3,203 PSi UPST'~r¢4 C= ¥;±¥E A~(D ZE:u3 PSI Dc~,:(~. S~ TO ZERO PSI. 0~1 TOP SET OF PIPE P,A-~ A.~.D ~_-~'= SET OF, PIPE I I;CP, EASE PRESSUP£ TO 300~ ~ ~ID ~OI_D ~ 10 lt!I~J'[=~o BI_~ED TO Z~ PSI. OP~I BOTTOR SET OF PIPE R~'~. .SA~-"'( ~"'l~ ~ IiI:~ JOI,'fT A~ID PULI. ~T OF i~;~-Eo CLOSE BLIND I~.'-IS .~ TEST TO ~000 PSI F~ lO BLEED TO ZERO PSI. DIESEL A~;D ALL YALY'-r.5 AP'~ S~ 'III POSITIO~I. - TEST STA~tDPIPE YAI.¥ES TO ~0-~ ,~I. ' TEST ~I. LY CO0(S A~"O I,'~II~~ ~ TO 30DO PSI RECORO TEST [~IFO.~ATIO~ O~ ,.~.~",~JT TEST FO~-! SIG;t A:ID SFS,,.~ TO ~U.I~ ¥ISOR. - - P~.FOP:-t CC~IPLETE BOPE TE~ ~..~_ A ~ .._. · . 2-*-_-. o. . -rPoE 4 · *8 · I Z.I ! 2,. Y: ~o~2.47. 2. -4-. "¢: 5'9 ~,o~o.'=J"/' Y= 5'0~8,4-=~2.4o' ARCO Alaska, Inc. Kuparuk Project North Slope Drilling Jscale, i"--'~°°~ dwg. no. ~k~l~'~.! 06.6 ,~'~ CHECK LIST FOR NEW WELL pERMITS Lease & Well No. /(.. 7'1,, t~ /1~'%..' Company ITEM APPROVE DATE (1) Fee (2) Loc 1. Is the permit fee attached ......................................... 2. Is well to'be located in a defined pool ............................ 3. Is well located proper distance from property line ................ 4. Is well located proper distance from other wells .................. 5. Is sufficient undedicated acreage 'available in this pool ............ 6. Is well to be deviated and is well bore plat included ............... 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... thru 11) 10. 11. (4) Casg ~/~ (12 thru 20) 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO REMARKS ( 5 ) B 0 PE ////~.__ /o1 -_____}~ (21 thru 24) (6) Add: ~f/-/ Does operator have a bond in force ~ -- I®elleeeeeeeeeeeeeeeeeeeeeeeeetlee ~-- Is a conservation order needed ...................................... / ~ Is administrative approval needed ~ ' ' Is conductor string provided .......... Is enough cement used to circulate Will cement tie in surface and £ntermediate or production string's. Will cement cover all known productive horizons ................. .'' Will surface casing protect fresh water zones ....... , ............. Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ........... Is old wellbore abandonment procedure included on 10-403 .......... Is adequate well bore separation proposed ......................... Is a diverter system required ....................................... ~/~ Are necessary diagrams of diverter and BOP equipment attached ....... ~/~ Does BOPE have sufficient pressure rating -Test to ~Z~ psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. l~oT ..<0£)~ / 7T'~'O Additional requirements ............................................. Additional Remarks: Geology: Engineering HWK J~_ LC$ ~- BEW WVA~ JKT rev: 08/19/82 ' INITIAL "GEd. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,-, Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~/P OIO.HO1 VEalF,iCATION blSTING PAGE I NTIN[ Al, ION .EVIOUS REEL 3MME.NTS ~LIBRARY TAPE TAPE HEADER ~,;RV I C~; NAbi~ ~TE :8~/01/18 RIGIN ~66~5 ]NTINOATION ~ :01 REVIOUS TAPE 3~ENT8 :LIBRARY TAPE IbE NAME JSERVIC,001 ERVICE NAME : ~TE : ~XiMUM LENGTH J 1024 ILE TYPE J REVIOU$ FILE : * INFORMATION RECORDS CONTENTS TYPE CATE SiZE CODE N : 1F-2 000 000 004 0~5 N I KUPARUK 000 000 00~ ANG: 105 000 000 004 065 ow~: 11~ ooo ooo 004 gCT~ 19 000 000 002 OUN: NO~TH MLOP~ 000 000 012 065 TAT: ALASKA 000 000 00~ 065 T~r: U.S.A. 000 000 006 0~5 * COMMENTS ** . ''' ...... '~h PAGE 2 IP 0~.0 HO1 VERIFICA~I, ON LIS.II G ~ ~u~i~. AT ACC, ~~ JN # DATE LOGGED: 1 AN"'83 NG = ,1:0 3/4" FLUID : POLYMER SIZE I TY bUID LOSS : 5,6 SURFACE, ~:0 232(~ : 3,380 (a 66,0 DF RMC : 990 ~ ' DF RM AT BNa> = 477 0 1 ,0 D~' ATRI× SANDS]f[ NE, rp OIO,HOI VERIFICATION I.,ISTING ..PAGE 3 * ~CHbUhB~:R:G~R LOGS: INCbUDED WITH ]:HIS MAGN~:TIC T.APE: * DUAb INDUCIION 8:PHERICA:Lb~ ~(JCU8~, bOG * FORmATiON DENoITY COMP~:NSAIED hOG (FDC) * ~ b(JG (CNL) DATA P~ORMAT R~CO.RD *:~ ! b5 , lin API API FIbE SIZE PROCESS SAMPb~i REPR hEYEb CODE 0 0 31 6B 44 35 34 bOG TY:PE CbA$ MOD N , '0 0 0 0 0 4 0 0 0 0 4 0 1 0 0 0 4 0 1 46 0 0 4 O ~ 08 0 0 0 ~ 0 1 68 32 0 0 4 0 1 68 2 0 0 4 0 1 68 0 0 0 4 0 1 68 I 0 0 4 0 I 68 92 0 0 4 0 I IP (,)10 HOI VERIFiCA~ILN LISTING ',,PAGE 4 FDN FDN FDN F DN FDN IN GAPI] ~2 31 32:0 0 4 ~j 42 42 '-1 0 0 4 42 0 0 0 0 4 0 DATA ? P R R ~P'I' P BDT HOB EPT EPT 79,.80. OOOO ~FLU 3,0898 IbM 2,8965 2:.:1,76:5:& : G'R':': :'I 93:75:: NPHI 50' DRHU 1'7012 NCNB 1890 0000 FCNh 508 2500CAbi 111 9 ...... ' ' ' , $15 : NRA~ : 3,4785 ~NR:A : 7900,0000 '28.0625 2,~1~'0 NCN:~ 99. 7500 NRA]; . . ,0000 SFLU ~.3691 NCNB 78.8'1~0 NR*AT 7700,0000 6iFbU '46,7813 GR 2,318~ NCNB 60,I87 NRAT {)000 SFLU 7600'50~0 GR '45, 2,3926 NCNb 75.3125 NRAT _ 7500 0000 SFLu -45i5313 GR 2 6543 NCNb 57,B125 NRAI 7~00,0000 ~FLU 35.2813 GR 2 3281 NCNb 114:2500 NRAT 7~00,0000 SFbO 44.5938 OR 2.3662 NCNb 123.9~75 NRAI .... oooo 1:9~75 GR 2.~145 NCNB 155.5000 NRAT 4~,.9609 IhD] '8477 DRHO 52~',500:0 CAb! .5078 4,5508 IbM 5.2109 C Ab I '16, 6O 2637RNRA 5 75 2134 3 3,429'1 94, 57, 2400, 2, 196:9 lb . 15,0625 I8'75 NPHI 31.8359 ooook ,o, : ooo 8828RNR ' 0391 , 114, 1834, 01~59 IbM 5,2813 l, bD 31 5 N'PHI "4,1309 ORHO 0000 FCNL b 9.5000 CAb~ 0898 RNRA 3.5000 2 123: 1887, 3, 6875 lbN 5'1, 8750 lbo 8125 NPHI 32'3730 DRHO 0000 fCNh 786,0000 CAbI 9785 RNRA 3.0527 155, 2068, 3, 7734 IBM 1,9131 ILD 2500 NPHI 45,3613 DRHO 0000 FCNb 447,2500 CAbI 7168 RNRA 4,0977 ' 2'I34 IbM 2 4492 IbD 9375 NPHI 45:8984 DRHO 0000 FCNb 512.0000 CAbI 7520 RNRA 3.6855 3633 IbM 4,3164 5000 NPHI 49,6582 0000 FCNL 436.7500 CAbI 9531 RNRA 4,7344 68 68 2,7988 ~,0630 .5000 04'20 9.062:5 5,1758 0,0459 11,4375 I~,4766 '.0029 ~,7344 5,2461 9, 43 52,3750 -O 0078 9:4844 1.8945 0.0420 9.8672 2,4785 0.0103 9,9609 4,2969 0.0308 ~.8359 ~P 010,H01 VERIFICATI[]N I, Io~[ING PAGE 5 gPT 7100g,OOOO ~RL '~ U 0000 i~PT 7 00,0000 8~hL 2695 NCNL 40~ 2.7 ' ~ 190, 500 NRAT ~PT 6900,0000 8FL~ 3125 GR -5~, 25~0 NCNL ~[)B -99 11 ,8125 P -57, .~125 HOB -999,2500 NC. NL R 105,6MTb NRAT ~PT 6700. 0000 8FLU P - 59,65~3 HOB -999,2~00 NC R 108,8750 ~:PT 6600 0000 SVLU P -44:9062 G~ HOB -999,2500 N R 96,b875 EPT 6500,0000 P -63,5625 GR HOB -999,~b00 R 127. 500 NRAT EPT 6400,0000 MFLU P -71,3125 GR HOB -999,250() NCNI~ ' ~ T HOB - 9,2500 NCNb R 162,3750 NRAT EPT 6200,0000 8FLU P -50,2b00 GR HOB -999,2500 NCNL R 131,b2bO EPT 6100,0000 P '55.b000 G~ HOB -999 2500 NCNh R 138~7b0 NRAT 1,~254 IL 309,0000 NPH1 .0000: FCNb 200~ .4727 RNRA 4.9062 IbM 190,75(10 NPHI 2022,0000 FCNL 3,9277 RNRA I ,628 IbM ,8125 NPHI -999,2500 FCNh -999,2500 RNRA 4,2305 IbM .105,~875 NPHI .999,2500 FCNL 999,250:0 R~RA 10:,8:789 lha ,8750 NPHI -999,2500 PC b '.999,2500 RNRA 2,7813 IL, S 96:,6875 NPHI -999,~500 FCNL '999'2500 RNRA 12'!,7500 NPHI '999,2500 FCNL '999,2500 RNRA 3.1074 ILM 122,4375 NPHI '999,2500 FCNb -999.2500 RI'IRA 3 5430 162,3750 NPHI -999,2500 FCNb -999,2500 RNRA 1.5410 IbM 13I,b250 NPHI -999,2500 FCNL -999,2500 RNRA 2.0254 Ih~ 138,8750 NPHI '999 2500 P'CNb '999:2500 RNRA 1:,7041 41'0645 57~,,5:~00 ,4805 4,0039 48,6816 459,7500 4,3945 3,3750 '999,2500 '9'99,2500 '999,2500 3.6914 ":999i:~500 '999 '~500 '999'2500 .99~3223 :2500 "99~'250 '99 :'~' 0 2500 . 2,~813 999, 500 -999, 500 '999.2500 4,0898 -999,2500 -999,~500 -999, 500 3,0586 '999,2500 -999,2500 -999,2500 2,2813 -999,2500 '999,2500 -999,2500 1.5537 -999.2500 -999,2500 -999,2500 1.b523 -999,25OO -999,2500 -999,2500 DRHO CALl DRHO CAbI DRHO C A b I DRHO CAI.,I DRHO C.ALI ILD D R H (3 (;AL1 I LD I)RHO CA lb I IbD DRHU CALI IL, I) DRHO CAbI IbD DRHO CAb I DRHU CALl 1,6924 0,0034 9,8281 3,802'7 '0,007~ 1.0,1797 3,3.28 -999,2500 9,476o 3.7285 ~,084~ -999,250. 10,2500 '999, 0 9,5313 3,9531 -999,2500 9,1953 3.0000 -999,2500 ~1.5938 2,2148 '999,2500 10,2891 1,3848 '999,2500 10,0156 1,5176 '999,2500 9,9375 rp OIO.HOI VERIFICATI'~ON LISTING PAGE 6000.0000 -58,5313 -999,2500 128.7500 5900 '999, 97, !JPT :~0~ SPT EPT P MOB EPT P MOB 8F[,IJ 2, GR 1:28, NCNb '999, NR~I 999' 0 $~'bU ~00 2B13 GR 25'0 NCNb 9375 NRA:[ 4023 ILM 2500 FCNL 2500 RNRA 999, 89,6~75 NRA~ 5700 -61, -999, 111. 5600,0000 MF'LU -999.2500 NCNL 88.0625 NRAT oooo '999,2500 NCN~ 88,7500 o0,oooo 62,0000 GR 999,2500 NCNL 87.8750 NRAT ~0~,0000 SFbU ~ .7500 GR 999,2500 NCN{~ 79,187b NRAT 5200 0000 SFbU '63,9687 GR '999,2500 67,7500 5100 0000 SFLU -68:~250 GR -999.2500 NCNb 91.0625 NRAT 5000.0000 70.00()0 -;99,2500 ~CNL ,':999 ,:~5'00 F:CNL -999. 250(,) RNRA 88,0625' NPRI -999. 2500 F~NP -999,2500 RNRA 2,533:2 IbM 88,7500 NPHI -999,25 0 FCNL -999,2500 RNRA 2.5156 l:LM 87,8750 NPHI -999,~500 FCNL '999,2500 RNRA 2,2383 79.1875 '999,2500 FCNL -999,2500 RNRA 2 4316 ILN 67:7500 NPHI -999,2500 FC.NL -99g,2500 RNRA 2 7012 91:0625 NPHi -999,2500 FCNL '999.2500 RNRA 3 0156 94i5625 NPHI -99g 2500 FCNL . 2.5898 .999,'~500 DRHO 2500 CALI 2999' 999,2500 2 8867 '999' ,2500 DRHO '999,2500 CAbI °999,2500 3.3320 · '9:99,:.2500 ~R:HO '999; ~500 CALl: -999:' 2500 999,2500 DRHO :999'2500 CAl~l 999"2500 2,6582 -999,2500 DRHO -999,2500 CALl -99D.2500 2 5957 ILD =999:2500 DRHO :~5oo 999 :999 500 2,5332 ILD -999.~00 O~HO -999, . O0 CALI -999,2500 2,4746 -999,2500 DRMO -999,2500 CALl: -999,2500 2,5762 ILL -999.2500 DNHO -999,2500 CALl '999,2500 3 0098 ILO -999:2500 ORHO :999,2500 CABI 999.2500 2,7852 '999,2500 ORHO '999,2500 'CALI 2,5586 -~9~,2500 I ,6172 2,8574 '999.2500 10,0938' 3,2187 -999,2500 10,0000 2,9980 '999.2500 10,3359 2.6191 -999,2500 9.9375 2,5508 -999.2500 9,9687 2,5117 '999,2500 10.0156 2,4902 -999,2500 9,7969 2,6445 -999,2500 10.2109 3,0430 -999,2500 10,2187 2,8262 '999,2500 10,4141 ~P OIO.HOI VERIFICA'rlOI. L, 1SI~ING PaGE 7 P HOB EPT HOB R HOB R EPT R EPT P 4800 -68 -999 76 -999,2500 MNRA B 125 NPHI '999,2500 FCN~L -999' 2500 RNR 0000 SFLU 2 0625 GR 76~ 2500 NCNL. '999, 0625 NRA~ 999, ,25 O0 GR 83.5625 NRA, ..999. 4bO0 0000 SFbU 3, -78 3125 -999 2500 NCNb 999, 126 0625 'NRA]~ -9.:99, 4500,()000 74.8750 N'RAq~ 4400 0000 SFLU -80,8125GR 2.2871 NCNb 96.b875 NRAT 4~00,0000 82.5000 GR 2,3027 NCNb 94.0000 4200 0000 SFLU -8311125 GR 2 2598 NCNb 79 2500 4100,0000 SFLU -86,0000 GR 2,23W~ NCN~ 72,4375 NRA · 4000,0000 "8~.3125 GR 2.2266 NCNb 71.B125 NRAT 3~00 OUO0 8FLU 85:8750 GR 5'142 062'5 : 2500 ~'cNi., .25oo ~6:37 IbM 5625 NPH! 2500 FCNb 2500 RNRA 17.9.7 ILt~ 0625: ~PH]', 2500 ~CNL 2500 RNRA 7:~1,3750 IbM .8750 NPHI 2002,0000 FCNL 3,4102 RNRA 2 96 200~ 9492 68'15 NPHI 0000 FCNL 5918 RNRA 2,8145 IbM 94,0000 ~PH.I 2148,0.000 CNh 3.5723 RNRA 2.3203 IbM 79,2500 NPHI ~957.0000 FCNb 3,9590 RNRA 3,0234 IbM 72,4375 NPHI 2246 0000 FCNL 3:7676 ~NRA 4.9805 IbM 71,8125 NPHi 2074,0000 FCNL 3.6.855 RNRA 5,1875 ILM 71,1875 NPHI -999,2500 I h t) ORHO CA h £ 3.3867 i[,D 2 -99 ,2500 ~RHO "99~, 500 CRbI -999,2500. . 3,~20 IbD 999. 00 DRHO '999,2500 CAbI "999,2500 3 ~949 IhD :soo a.o 999,2500 CALI' -999,2500 3~,3945 lbD ,1836 DRHO 591,5000 CAb! 3,3828 3.'134B 41,2109, 519,0000 CALl 3,8535 3,1895 lbo 40,9668 DRHO 563,5000 CALl 3.8105 2,6973 47,9004 DRHO 458,0000 CAbI 4,2695 ' 3.7109 43,9941 DRHO 554.0000 CALl 4,0508 4,4102 IbD 43,2129 DRHO 530.5000 CALI 3,9082 6 0156 IhD 39:6973 DRHO ,4961 -99 ,2500 10,13'28 3.4590 -999,2500 10.3672 ,2500 10,3672 ,3691 -99 .2:500 11.6094 3,~2,34 O, 215 11.6016 3.2090 0,0161 12,1641 O, 83 11,9687 2,8086 V,Ol12 11.9297 3,9258 0.0181 12.882~ 4.7773 0,0249 11,4766 0,5742 0,0000 [P OIO,HO1 VERIFICATION LISTING PAGE 8 2 71. CPT 3800, ~ "'93, ~.OS 2. ~ 66' .3700, 100, ~600 3500 '107 .DB 7:~: gPT 3400, P '11~. R 61~ EPT 3300. ~ '105, HOB R 67. H OB 2. R EPT 3100. P '~07. HOB 2, R 57, EPT 3000 P '129. H OB 2 EPT 2900, P HOB 2, R EPT 2~00, 1816:NCN~ 1875 NRA 0000 SFLU 25 0 21~t NCNL 6875 NRAT.: 208~,0000 ' 'FCNb .5020 RNRA 4 0117 : : 3 5:645 RNRA 0000 ~ bU ....5,5547 ILN 25~0 GR 8l. 4375 NPH! 3223 ':NCN~: 2::l~:~',OOgO :FCNL ~375 NRAf 3,4922 RNRA OOOO SFDU ~000 G~ 2891 NCNb · ,, ,~ , , 6815 :NRA~ go00 8FLUi 8,5078: I:LA 8't50 GR 9 '! 7 ,0625NPHI 062~3:0~NRAT 3.5801 ~CNrhRNRA 0000 5FLU 7b O: G~: 38.3 NCNL 1250 NRAT 13,3~59 .6iI,1250NPH] 2118'0000 FCNL 3,~24.2 : ~NRA 0000 SFbU 5625 NPHI 3750 G~ I 6 ,7813, XLM 3105 NCN~ 205~,0000 FCNL 5625 NRAT .6055 RNRA 0000 SFLU 12,6484 ILM 3125 GR 49,1875 NP~I 1621 NCN5 2172,0000 FCNL 1875 N~AT 3,5000 RNRA 0000 SFLD 7,2773 Ib~ 0625 GR 57,4688 NPHI 1992 NCNL 2007,0000 FCNL 468~ NEAT 3'822] RNRA · 0000 SFLU 16 1250 Ib~ ~750 GR 43:9687 NPHI 0859 NCNb 2174,0000 FCNL 96~"7 NRAT 3,7930 RNRA 57~,5000 CALl 11.9531 .6172 4.9727 ILD 5,4570 ,5000 CALI. ,0015 3.8809 5313 : IbD b,99&:l: "7578 ' ::40:7715: DRHO 0,0225 545,5000 CALI 1~,8672 3.855:5 .8203 ORHO 46 5.39,$000 CALX lZ. 5625 3 · 8 ! 64 14 35 610 3 1875 IbD 1b,1953 8:398 DRHO 0,0103 5000 CALI 13,2891 4~88 10 4O 519 3 ,0150 ILL 10,5391 .4785 DR.O 0.03 .9609 9 40 632 3 .8594 IbD 9.6875 ,7715 DRHO 0 0034 .0000 CALl 10:3438 .4355 8 46 5O6 3 .1094 lbo 8.3672 .5332 DRHO =0.0073 ,7500 CALI 10,3750 .9590 18 45 533 4 ,1250 ILL 1~,5781 ,2637 ORHO -0.00~8 .5000 CALI 11.23~4 ,0742 0000 SFLU 13,2109 IbM 15,3438 lbo lb. O000 5000 GR 45.3438 NPHI 46,1426 ORHO 0.0015 0604 NCNb 1948.0000 FCNL 442,7500 CALl 11,5313 3438 NRAT 3.8496 RNRA 4,3984 " 0000 SFL. U 8,9609 IbM 9.6563 ILL 10.2500 IP 010,HO1 VERIPICA.~I.]N blSr PAGE 9 !OB CPT CPT .2305 NCN5 1901,0000 FCN 71.5000 NRAT : :3:,558:6: RNR:A ..... ' ..... B437 NPHI 42, 1500 GR , .... ) . .~'l NRAT .'000(9023 :':~C:NLRNRA 0000 SFLU 18 3594 ILM 2~39 . 0:0 24.00 SPT 2300 P -84 ~{OB R EPT 2,249 P -88 HOB I 150 NRA1 : :: : 3 4453 ,0000 S~:LL .7500 GR ' 5~,2500 NPHI 0000 5FLU .5000 G ,9238 NC .~250 NRA 14,4375 IL~ i .39.~1i25 N:PHI 2190'0000 FCNL ::3.8~203 :RNR:A ,.00:00: :FCNL : I451 5 ,1445 RNRA ,5000 5FLU 2,0801 .000:0 GR 3:2,'8457 NPHi ,9248 NCNL 1413,0000 FCNL ,~437 NRAT 4.3359 RNRA * FILE TRAILER ** ILE NAME :SERVIC,O01 ERVICE Nh. ME : ER$ION # : ATE : AXIMUM LENGTH : 1024 ihg TYPE : EXT FILE NAME : EOF 40,]320 ORHO 480, 500 CALI 3.95:70 DR}~O 9,6094 ILD 8'8672 ORHO 609*O000CALI :3:.:b211 4~, 2~6270 DRHO ,440,50:00 ALI 3'8633 14,0938 ,IbD :44,2383DR:HO 510'0000 CALI 4,2930 DRHO CALl 2000.0000 ILD 56.1035 L)RHO 340'7500 CALI 4,i445 "' 1 .757 !~'47~6 ,0068 12,1641 19,9844 ~0,0176 1,5000 15,0313 0,0073 14,4844 30,4:21] -0,450 10,2.266 4b,7188 -0,5806 10,I562 · TAPE TRAILER ERVICE NAME :8ERVIC ATE :83/01/18 RIGIN 16625 APE NAME ONTINOATION # EXT TAPE NAME ~P 010,HOI VERIF'ICATION LI,BIING PAGE 10 JMMENTS :LIBRARY TAPK kTE :83t01/18 ~IGI, N : CEL NA, Mg ~ 11 ~)NTiNUATION ~ ~0i' ~XT REEL' NAME : ", ~M,MENTS :LIBRARY ~APE