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186-164
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3K-11 KUPARUK RIV UNIT 3K-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 3K-11 50-029-21654-00-00 186-164-0 W SPT 6580 1861640 1800 2925 2925 2925 2925 970 2000 1900 1880 REQVAR P Josh Hunt 5/9/2025 Required 2-year MIT-OA per AIO 2B.061 OA to be tested to a minimum of 1800 psi. 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 3K-11 Inspection Date: Tubing OA Packer Depth 720 760 760 760IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250510091705 BBL Pumped:0.8 BBL Returned:0.7 Friday, July 18, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 99 9 9 9 MIT-OA per AIO 2B.061 James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 13:53:29 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3K-11 KUPARUK RIV UNIT 3K-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 3K-11 50-029-21654-00-00 186-164-0 W SPT 6580 1861640 3000 2925 2925 2925 2900 975 1200 1200 1200 REQVAR P Josh Hunt 5/9/2025 Required 2-year MIT-IA per AIO 2B.061 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 3K-11 Inspection Date: Tubing OA Packer Depth 730 3520 3440 3410IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250510090952 BBL Pumped:2.7 BBL Returned:2.6 Friday, July 18, 2025 Page 1 of 1 9 9 9 99 9 9 99 999 99 9 9 9 AIO 2B.061IT-IA James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 13:51:18 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3K-11 KUPARUK RIV UNIT 3K-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/01/2023 3K-11 50-029-21654-00-00 186-164-0 W SPT 6580 1861640 1800 2930 2930 2930 2930 1150 1990 1910 1910 REQVAR P Austin McLeod 5/7/2023 Two year MITOA to 1800psi. AIO 2B.061. 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 3K-11 Inspection Date: Tubing OA Packer Depth 640 680 670 670IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230507190842 BBL Pumped:0.3 BBL Returned:0.3 Thursday, June 1, 2023 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 9 9Two year MITOA AIO 2B.061. James B. Regg Digitally signed by James B. Regg Date: 2023.06.02 11:20:49 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3K-11 KUPARUK RIV UNIT 3K-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/01/2023 3K-11 50-029-21654-00-00 186-164-0 W SPT 6580 1861640 3000 2930 2930 2930 2930 1170 1480 1500 1500 REQVAR P Austin McLeod 5/7/2023 Two year MITIA to MAIP. AIO 2B.061. 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 3K-11 Inspection Date: Tubing OA Packer Depth 650 3500 3390 3365IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230507190643 BBL Pumped:3 BBL Returned:2.5 Thursday, June 1, 2023 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 9 9 Two year MITIA AIO 2B.061. James B. Regg Digitally signed by James B. Regg Date: 2023.06.02 11:18:09 -08'00' MEMORANDUM TO: Jim Regg 7 m5 P.1. Supervi1 sor I i / `•[ FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, May 13, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3K -II KUPARUK RIV UNIT 3K-1 I Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K -I I API Well Number 50-029-21654-00-00 Inspector Name: Lou Laubenstein Permit Number: 186-164-0 Inspection Date: 5/4/2021 ' IDSA Num: mi[LOL210505081207 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - Well 3K -n PTD 861640 T— - _Type Inj w TVD T - esso -�- Tubing x900 x900 J -- 2900 • -- 2900 — BBLPumped: -- Type Test) SPT-ITest psi 3z BBL Returned: j 3000 -� 32 - IA OA 75 ---� 3450 1000 3330 1001 3310 - 000- Interval ---� REQvAR P/F- RE r --- Notes: MIT -IA to the maximum anticipated injection pressure per AIO 2B.061 ✓ Thursday, May 13, 2021 Page I of I MEMORANDUM TO: Jim Regg P.1. Supervisor FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 11, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhilOps Alaska, Inc. 3K -1I KUPARUK RIV UNIT 3K -I l Src: Inspector Reviewed By: P.I. Sup" ITIt-- Comm Well Name KUPARUK RIV UNIT 3K -I I API Well Number 50-029-21654-00-00 Inspector Name: Lou Laubenstein Permit Number: 186-164-0 Inspection Date: 5/4/2021 ' Insp Num: mitl•ol,zlasososlasa Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-11 TypeInj w. r VD 1 6580 - Tubing 2900 - z9oo _ z900 - 1900 PTD 1961640 Type Test sPT Nest psi 1800 IA 300 - 325 - 325 ' 325 BBL Pumped: os BBL Returned: os . OA 1040 1950 - 1850 1840 Interval F REQVAR P/F P Notes: MIT -OA to 1900 psi per AIO 26.06 t ✓ Tuesday, May 11, 2021 Page I of 1 MEMORANDUM State of Alaska Depth Alaska Oil and Gas Conservation Commission TO: Jim ReggDATE: P.I. Supervisor �4+ 5/31117 � Thursday, May 30, 2019 SUBJECT: Mechanical Integrity Tests 3K-11 CONOCOPHILLIPS ALASKA, INC. Type Inj w 'TVD 3K-11 FROM: Bob Noble KUPARUK RIV UNIT 3K-11 Petroleum Inspector PTD Src: Inspector ',Type Reviewed By: 3000 IA P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K -1I Insp Num: mitRCN190528143046 Rel Insp Num: API Well Number 50-029-21654-00-00 Inspector Name: Bob Noble Permit Number: 186-164-0 Inspection Date: 5/28/2019 - Thursday, May 30, 2019 Page I of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-11 Type Inj w 'TVD 6580 Tubing! 2900 2900 2900. j 2900' PTD 1861640 ',Type Test SPT Test psi 3000 IA 900 3500 - 3430 3410 - BBL Pumped: zs - IBBL Returned: zs - OA 69 s - Interval REQVAR P/F P Notes: MIT -]A every 2 years to max anticipated injection pressure per AIO 26.061 Thursday, May 30, 2019 Page I of 1 n • N ) uJ _ L V° H > O �- X ro a cc OI"W - > in 0 0 0 a) Qo o 3 r O-wti4 ' co T co h _ Jra mY 0 75 a) H Y O E r rt) Y 0 a) �O IIII ❑� = V a a C C C — T 0 ro ✓ co t._ Y co O a Q 0 L U N 7 lit ow r r r r r r r r N N N `'� N E o 6 m N L (1 U 0 J J 6) 6 Co 0) O) O) O) E 4-' L -C O ✓, J Q Q Q Q Q Q Q d N d N s_ ✓ (p c w fn to co to C co u L N G 1- MU) U) 4 N N N N CCO 4' I` C U 0 +' v a > E a) ii =+' u (70 O c v N u 00000000000 c E 2,w p J J J J J J J J J J J C O CI' W W W W W W W W W W W vi a 'C U 0 4- I- LL LL LL LL LL LL LL LL LL LL LL ✓ a) Q) (I) 75 0 3 Q J J J J J J J J J J J a L > C a) C0 F Q Q Q Q Q Q Q Q Q Q Q a) '^ C ,F `✓ OG cf, -. 0 Z Z Z Z Z Z Z Z Z Z Z u L a) O O LL LL LL LL LL LL LL LL LL LL LL CC L t > to to N +u-4 > 4-, a) E Y v ro CO L EL 0 z E Q _ u > fro. 0 C co +) 0 or U O 1.- v Y u L c 4. > u a) ✓ Z. O U d-2 ~ C co a o O ceI = u rn Q v a n c a N. C o a a n Cr) a -� O �= a �' • s OQrn U 2C mm CO- 000 -.I a. \ cv c0 rl. > a W 8o ° > 0 \ 00 W f0 m Cry c AS 11 v a 0 , z _ I 1 d .X roYyy .� w O V t. >, 2 A q a J O J J J J J J _J J >J -J 1 on 0 iii)li,,,C1---4100 d a R CGCCCLCLCLCeCtW W W W E W W W W W W WW W W W 7 LU > > > > > > > > > > > L zin Y Y Y Y Y Y Y Y Y Y Y O > > > > > > > > > > > C1 W d' X Q' LL' LL' LL' R' Q' Q' 0' '� W Q Q Q Q Q Q Q Q Q Q Q CI ,� a a a a a a a a a a a c > > > > > > > > > > > Co OU W Y Y Y Y Y Y Y Y Y Y Y �_ c. U X �, O 0., C) N O O O M 7 In c0 c0 Co �' v c 7 0 0 •,- 0 0 0 0 0 0 0 0 ani f� 0 O = 0 o o 0 0 0 22888 LU O u, N � ^ MMM � � � � � C 0 �r �o0Exxx vnv5 ( Fv> (0 wtit g X ❑ 0 0 0 0 0 0 0 0 0 0 m N CE 0 O O O co O O O O O O ko < O O O O O O O co O co C O c to Q 0 0 c0 O 4 O In IA h E M t0 N In CO r c0 CO r0 In 0 M N M N CO c0 O V N CO c0 u Nx C) M N N M 0 0 N r. N N N N N N N N N N N ar _J O) 0) O 0) 0 O) O 0 0, 0) 0) C) in R N N N N N N N N N N N � O) 00000000 0 0 0 7 0 0 0 0 0 0 0 0 0 O 0 i' 0 a) L 00 In In In In In Ln In In In In In a 0 ✓ / C _cia C C. z Q) EC C CC CI L _ . r/ Y p Iw �� f- O Q w N 2 0 N Q Nar) c0 a) 7 2 y Z ODM Z O 7 O — N N O ,— O O C N >_ tl C Cl.erQ co,_vl N W r ,_ M C) C) ,— C) = m m E co H ro Y ._ '-I '' r• x ` c co tr, a) ro 0 CO2 a 1 c a _ H a` a Q • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,May 16,2017 TO: Jim Re P.I.SupervisorC (1Ct(i 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-11 FROM: Chuck Scheve KUPARUK RIV UNIT 3K-11 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-11 API Well Number 50-029-21654-00-00 Inspector Name: Chuck Scheve Permit Number: 186-164-0 Inspection Date: 5/9/2017 Insp Num: mitCS170511115845 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-11 Type Inj W TVD 6580 • Tubing 2810 2810 r 2810 - 2810- PTD 1861640 'Type Test, SPT Test psi i 3000 = IA 660 3510 - 3420 3410 , BBL Pumped: 2.9 " BBL Returned: 2.8- 1 OA 1250 1560 ' 1560 1560 , Interval REQVAR P/F P ✓ Notes: MIT-IA per AIO 2B.061 - SCROD UIL. .l 1n17 Tuesday,May 16,2017 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,May 16,2017 TO: Jim Regg `' P.I.Supervisor �7 i S I l el((7 SUBJECT: Mechanical Integrity Tests tt CONOCOPHILLIPS ALASKA INC 3K-11 FROM: Chuck Scheve KUPARUK RIV UNIT 3K-11 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry - NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-I1 API Well Number 50-029-21654-00-00 Inspector Name: Chuck Scheve Permit Number: 186-164-0 Inspection Date: 5/9/2017 Insp Num: mitCS170511120258 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-11 - Type Inj W -1TVD 6580 • Tubing F-281 2810 slo 2810 • 2810 . PTD 1861640 Type Test SPT Test psi 1800 - IA 720 j 760 . 770 , 770 , BBL Pumped: 0.4 - IBBL Returned: 0.3 - OA 1240 1980 , 1880 1870 , Interval REQVAR P/F ! P .✓ Notes: MIT-OA Per A1O 2B.061 scale U 1 1 `01? Tuesday,May 16,2017 Page 1 of 1 0 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 04,2016 TO: Jim Regg qtr ,j Ii 3/1L P.I.Supervisor ( t SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-11 FROM: Chuck Scheve KUPARUK RIV UNIT 3K-11 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-11 API Well Number 50-029-21654-00-00 Inspector Name: Chuck Scheve Permit Number: 186-164-0 Inspection Date: 4/30/2016 Insp Num: mitCS160502075623 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-11 •iType Inj W- TVD 6680 Tubing 2790 - 2790 - 2790 - 2790 '._ PTD 1861640 ''Type Test SPT Test psi 3600 - IA 560 3840 3720 3700 Interval REQVAR PAF P ✓ OA 920 - 1220 .. 1181 1160 - I I Notes: MITIA Per AIO2B.061 v SCANNED SEP 2 7 2010 Wednesday,May 04,2016 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 04,2016 TO: Jim Regg ke�c 5 I 174 I(a P.I.Supervisor `/ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-I1 FROM: Chuck Scheve KUPARUK RIV UNIT 3K-11 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-11 API Well Number 50-029-21654-00-00 Inspector Name: Chuck Scheve Permit Number: 186-164-0 Inspection Date: 4/30/2016 Insp Num: mitCS160502080328 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K 1 1TYP a In' wTVD Esso Tubing 2790 2790 . 2790 . 2790- J PTD 186164° - IType Test SPT Test psi 1800 - I IA 450 510 • 520 520 • Interval REQVAR P/F P ✓ OA 820 1 1990 - 1910- 1900 , Notes: MITOA Per AIO 2B.061 SCANNED SEP 2 7 2016 Wednesday,May 04,2016 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg DATE: Friday,June 14,2013 P.1.Supervisor f l 61Z 1/i SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-1I FROM: Lou Grimaldi KUPARUK RIV UNIT 3K-11 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry _er-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-11 API Well Number 50-029-21654-00-00 Inspector Name: Lou Grimaldi Permit Number: 186-164-0 Inspection Date: 6/1/2013 Insp Num: mitLGl30601112452 Rel lnsp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-11 Type Inj W iTVD 6580 IA 989 3850 - 3759 . 3739 - -- — - T Test -- _ __- --- ---_ -- - PTD 1861640 YPe es 'SPT Test psi 3480 OA 928 1017 - 1015 1012 • Interval REQVAR TP/F P Tubing 2875 2890 -, 2890 2890 Notes: MIT IA for compliance with AIO 2B.061.Crew well prepared for test.2.9 bbl's diesel pumped,2.9 bbl's returned.Gas still present in OA. See subsequent record for MIT OA. SCANNED FEB 2 2014 Friday,June 14,2013 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg �� DATE: Friday,June 14,2013 P.I.Supervisor Ic-1tI (�71 1(I' SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-11 FROM: Lou Grimaldi KUPARUK RIV UNIT 3K-11 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry j , NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-11 API Well Number 50-029-21654-00-00 Inspector Name: Lou Grimaldi Permit Number: 186-164-0 Inspection Date: 5/28/2013 Insp Num: mitLG130528135635 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-11 Type Inj W 'TVD ' 6580 1 IA 1042 3400 - 3317 - 3301 - , PTD' 1861640 'Type Test SPT Test psi 2890 OA 1072 1092 1094 1095 Interval 'REQVAR PP/F ' F Tubing 2880 2880 2880 2880 MIT lA for compliance with AIO 2--- test. p l' -.1 -.,- --- Notes: P B.061'Crew well prepared for test.2.0 bbl's diesel pumped,2.4 bbl's returned,IA mistakenly bled 110 psi below`pretest pressure.See subsequent record for MIT OA. SCANNED FEB 2 0 2014 Friday,June 14,2013 Page 1 of 1 4111 tie-iit Regg, James B (DOA) 1 1 €04 - o From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Friday, February 24, 2012 2:56 AM -7 , To: Regg, James B (DOA) �e 4z- -4 Cc: NSK Problem Well Supv Subject: RE: Monthly Failed MIT report for January 2012 Jim, Below in the body of your email are my answers to each question. If there are any other concerns, please call. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 From: Regg, James B (DOA) [mailto:jim.regg(aalaska.gov] Sent: Monday, February 13, 2012 4:51 PM To: NSK Problem Well Supv Subject: [EXTERNAL]RE: Monthly Failed MIT report for January 2012 What are the short pressure spikes in IA of well 1F -16A (PTD 2012090)? This well used to have a wireless pressure transmitter attached to the IA, but it was disconnected several months ago in preparation for an upgrade to a hardwire system. The SCADA system is still set up to read these pressures (which is now essentially reading atmospheric pressure). Unfortunately, the daily well walk pressures are often times not input correctly into the system to allow an overwrite of the erroneous wireless transmitter pressure readings. The issue has been brought to the attention of operations and more diligence will be forthcoming. Any diagnostics done on 1Y -08 (PTD 1830620) to evaluate sudden pressure build in IA (100 to 900psi on 1/28/11)? Operations intentionally pressured the IA in order to establish a better dP between the IA and OA. We will be pursuing diagnostics in the next couple of days to investigate further. ion csg). (PTD 1840220) indicates IA pressures have stabilized at 3100 psi (62% of MIYP rating for g) KRU 2B -06 ( ) p p ( g production Why allow 3100psi to remain on IA? The IA was bled several times in January without success. Based on initial diagnostics where the MITIA passed yet failed an IA drawdown test, a packer leak or other one way leak (from formation into the IA) is suspected. On February 1, the IA finally was able to be bled off to - 1750psi and is currently maintaining pressure below 2000 psi. Slickline /E -line work is now under way to secure the well with a downhole plug which will enable us to pursue further diagnostics. What is reason for unusual OA pressure spikes on KRU 3K -11 (PTD 1861640) 1/23 and 1/26? This well has wireless pressure transmitters. Reported daily readings are averaged from the entire day's recordings. Occasionally, the transmitters malfunction temporarily, recording very high pressures (several orders of magnitude above actual pressures). These malfunctions usually only last minutes or seconds; but these erroneously high pressures get calculated into the average, causing the reported daily numbers to show up as spikes. ✓ Jim Regg AOGCC 1 • 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: NSK Problem Well Supv [ mailto :n1617Caconocophillips.com] Sent: Tuesday, February 07, 2012 8 :46 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: Monthly Failed MIT report for January 2012 Jim, Guy, Attached is the monthly failed MIT report for January 2012. 2B -06 and CD2 -22 were added due to suspect TxIA communication. Thanks Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 2 . . Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, February 13, 2012 4:51 PM � 2`c 3 , z-- To: 'NSK Problem Well Supv' Subject: RE: Monthly Failed MIT report for January 2012 What are the short pressure spikes in IA of well 1F -16A (PTD 2012090)? Any diagnostics done on 1Y -08 (PTD 1830620) to evaluate sudden pressure build in IA (100 to 900psi on 1/28/11)? KRU 2B -06 (PTD 1840220) indicates IA pressures have stabilized at 3100 psi (62% of MIYP rating for production csg). Why allow 3100psi to remain on IA? /What is reason for unusual OA pressure spikes on KRU 3K -11 (PTD 1861640) 1/23 and 1/26? Jim Regg AOGCC L D F E B 1 `t USkL 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 -793 -1236 From: NSK Problem Well Supv [ mailto :n1617ftconocophillips.com] Sent: Tuesday, February 07, 2012 8:46 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: Monthly Failed MIT report for January 2012 Jim, Guy, Attached is the monthly failed MIT report for January 2012. 2B -06 and CD2 -22 were added due to suspect TxIA communication. Thanks Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, September 07, 2011 TO: Jim Regg SUBJECT: Mechanical Integrity Tests P.I. Supervisor � � 111/11 CONOCOPHILLIPS ALASKA INC 3K -11 FROM: Bob Noble KUPARUK RIV UNIT 3K -11 Petroleum Inspector Src: Inspector NON - CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3K -11 API Well Number: 50- 029 - 21654 -00 -00 Inspector Name: Bob Noble Insp Num: mitRCN1 1 0802 1 7 1 005 Permit Number: 186 -164 -0 Inspection Date: 7/29/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K -11 'Type Inj. j W TVD 6580 • IA 1300 2345 - 2300 - 2290 - P.T.D 1861640 TypeTest SPT I Test psi 1645 OA 950 955 960 960 Interval Initial Test ' , P/F Pass ' Tubing 2980 2980 2980 2980 Notes: Initial MIT, post conversion to injector SEA' ZU'� Wednesday, September 07, 2011 Page 1 off • • 1111 FE LiAsl! SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL AIO 2B.061 Ms. Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 -"' ` (� f RE: KRU 3K -11 (PTD 1861640) Request for Administrative Approval Dear Ms. Lyons: In accordance with Rule 9 of AIO 2B.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby GRANTS ConocoPhillips Alaska Inc. (CPAI)'s request for administrative approval to continue water injection in the subject well. Kuparuk River Unit (KRU) 3K -11 exhibits pressure communication between the production and surface casings (outer annulus or OA). The Commission was notified of the communication on June 18, 2011. Individual positive pressure tests have been successfully performed on the well's inner annulus (IA) and OA. Since the IA and OA pressures tend to equalize over time, the leak is apparently small. CPAI reports that while operating as a development well, it was necessary to employ sealants on a routine basis to energize the wellhead packoff that isolates the IA and OA. The Commission finds that CPAI does not intend to perform repairs at this time, however if fluids other than water are considered for injection CPAI will perform the work necessary to eliminate the pressure communication. Reported results of CPAI' s diagnostic procedures and wellhead pressure trend plots indicate that KRU 3K -11 exhibits at least two competent barriers to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection only in KRU 3K -11 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; AIO 2B.061 • • ' August 31, 2011 Page 2 of 2 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall perform an MIT -IA every 2 years to 1.2 times the maximum anticipated injection pressure; 4. CPAI shall perform an MIT -OA every 2 years to 1800 psi; 5. CPAI shall limit IA pressure to 2000 psi and OA pressure to 1400 psi; 1 6. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 7. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection, and o%% S 8. The MIT anniversary date is July 29, 2011. y3� 1 AI DONE at Anchorage, Alaska and dated August 31, 2011. % V 1 AkV \. '''' -\,-, QikrERVATiON G -0/400"...-- / r 4 e'' L i il ' Iil IP _Ail Daniel T. eamount, Jr. Cathy ' . Fo - rster ' 'l orm. Chair, Commissioner Com issioner Co is • . loner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 August 19, 2011 fk l e se° 1 \1 0\ 67) Commissioner Dan Seamount wG $ Alaska Oil & Gas Conservation Commission to 333 West 7 Avenue, Suite 100 &�e� . Anchorage, AK 99501 1690 NR�'r Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. presents the attached proposal per AIO 02B, Rule 9, to apply for Administrative Approval allowing well 3K -11 (PTD 186 -164) to be online in water only injection service with IAxOA communication. ConocoPhillips intends to pursue repairs should MI injection be desired in the future. If a successful repair is achieved we will request the well be returned to normal status and resume ability to inject MI. If you need additional information, please contact myself or Brent Rogers at 659 -7224, or MJ Loveland / Martin Walters at 659 -7043. Sincerely, Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska Inc. Cc: Working Well File, Legal Well File • • ConocoPhillips Alaska, Inc. Colville River Unit 3K -11 (PTD# 186 -164) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue injection with known annular communication for Kuparuk injection well 3K -11. Well History and Status Kuparuk River Unit well 3K -11 (PTD 186 -164) was drilled and completed in 1986 as a producer and was converted to a service well on June 12, 2011. 3K -11 was reported to the Commission on June 18, 2011 as showing signs of IAxOA communication based upon the need for frequent outer annulus bleeds. Before being converted to injection, 3K -11 displayed similar IAxOA communication when operated as a producer and had to have its IC packoffs re- energized with sealant on a regular basis. The following recent pertinent operations have been completed to date: Date Operation Result Comment 7/29/11 MITOA/MITIA Passed State Witnessed MITIA by Bob Noble 6/20/11 IC -POT and Passed IC -PPPOT 6/18/11 MITOA/MITIA Passed 7/13/10 IC -PPPOT Passed Re- Energize 7" IC packoffs with sealant 9/10/09 IC -PPPOT Passed Re- Energize 7" IC packoffs with sealant 3/15/09 IC -PPPOT Passed Re- Energize 7" IC packoffs with sealant ConocoPhillips requests Administrative Approval which will allow the OA to equalize with the IA in water only injection service at a pressure not to exceed 1400 psi. Barrier and Hazard Evaluation Tubing: The 2.875 ", 6.5 #, J -55 tubing has integrity to the packer @ 7452' MD, based on the passing MITIAs. Production casing: The production casing has integrity down to the packer based on the passing MITIAs. Integrity is demonstrated by a passing MITIA with a known minor leak presumed to be through the packoff assembly. Based on the passing IC POTs, the leak rate is insignificant except over extended periods of time. The 7 ", 26 #, J -55 production casing has an internal yield pressure rating of 4980 psi. NSK Problem Well Supervisor 8/19/2011 • • Surface casing: The surface casing and cement shoe have integrity based on passing MITOAs at 1800 psi. The 9 -5/8 ", 36 #, J -55 surface casing has an internal yield pressure rating of 3520 psi. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the production tubing and packer. Second barrier: The secondary barrier to prevent a release from the well and provide zonal isolation is the production casing. The packoff assembly leak is insignificant except over time. Tertiary barrier: The tertiary barrier to prevent a release from the well and provide zonal isolation is the surface casing. A 1400 psi OA pressure is allowed to eliminate frequent annular bleeds. Monitoring Each well is monitored daily for wellhead pressure changes. Should leaks develop in the tubing or surface casing above the conductor shoe, it will be noted during the daily monitoring process. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including a shut -in of the well. T /I /O plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. Proposed Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed). 2. Perform a passing MITIA every two years as per AOGCC criteria (0.25 x tvd @ packer, 1500 psi minimum). 3. Perform a passing MITOA to 1800 psi every two years. 4. IA pressure not to exceed 2000 psi & OA pressure not to exceed 1400 psi. 5. Submit monthly reports of daily tubing & IA pressures and injection volumes. 6. Shut -in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. NSK Problem Well Supervisor 8/19/2011 2 Well Name I 3K -11 Notes: Administrative Approval Application Start Date 5,21.2011 Days 90 End Date 8,1912011 Annular Communication Surveillance 3500 — __ �._.._ — . _ __.. _ - 90 IAP OAP - 80 • 3000 WHT - 70 2500 - 60 2000 r ► - 50u, 0- s .../ / , \ i r--- j , \ 1500 - 40 - -30 1000 , _ .^.. -I\ ../ '' e r\---- - 20 • 500 - 10 0 0 May -11 Aug -11 DGI s PWI MGI s 2 S1N1 _ 141 0° 2 ---BLPD z 1000 500 0 May -11 Jun -11 Jul -11 Aug -11 Ti) • KUP • 3K -11 CO�'IOCUP�'11ll1 • ° ' Well Attributes Max Angle & MD TO Alaska. Wellbore APIIUWI Field Name Well Status Ina CI � MD (M8) Act Btm (MO) 500292165400 KUPARUK RIVER UNIT INJ 40.47 5,800.00 7,854.0 Comment H2S (ppm) Date Annotation End Dab KB-Ord (R) Rig Release Date "` Well Conl9 - 3K - 11, 61162011 655:45 AM SSSV: TRDP 150 12/22/2010 Last WO: 39.01 11/5/1986 Schematic - Actual 1 Eniclu9tIal2te 010 • 6/201 1 HANGER, 35 , ' F Casing Strings CONDUCTOR ' String 1. 1 110.0 110.0 , 1 1 WELDED IL Getting Description String 0... String 10 ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.921 1 3,895.0 3,807.2 11 J BTC II Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 35.0 7,837.8 6,884.2 26.00 J-55 BTC CONDUCTOR, Tubing Strings 361t0� Tubing OncriptIon String 0... String ID ... Top (ftKB) Set Depth (/.. Set Depth (TVD) ... String Wt... String ... String Top Thrd III TUBING 2 7/8 2.441 1 7,478.0 6,600.8 6.50 • a SAFETY VLV, o Details 1,805 1 Top Depth GAS LIFT, i ii. 2,560 . 1 35.0 0.19 HANGER CIW TUBING HANGER 2.875 1,805.2 1,805.2 1 • TRDP-1A-SSA SAFETY VALVE 2.312 7,434.0 • :1 • HRP-1-SP PACKER 2.347 SURFACE. A • • NIPPLE NO GO 2.250 363095 GAS LIFT, 6611 1 • • OUT SUB 2.441 4,412 Perforations & Slots GAS LIFT, Shot 5,664 Top (ftKB) Btm (f1KB) MB/ IfIKB) Zone Date (. Type Comment GAS LIFT, , 1 7,566 7,567 6,669.9 1 GAS L : 6.1 GAS L, 7 7,598 7,614 6,695.1 deg. phase; 2 1/8" EnerJet SBR.7,434 7,606 7,607 6,701.2 6,702.0 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 2 1/8" EnerJet PACKER, 7.452 7,610 7,611 6,704.4 6,705.2 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 21/8" EnerJet I 7,612 7,613 6,706.0 6,706.7 A -2, 3K -11 7,619 7,620 6,711.5 6,712.3 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 21/8" EnerJet 1/13/1987 1.0 IPERF 0 deg. phase; 21/8" EnerJet NIPPLE, 7467 ,•j 7,621 7,622 6,713.1 6,713.9 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 21/8" EnerJet . 7,625 7,626 ' 6,716.2 6,717.0 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 21/8" EnerJet sos. 7.477 7,631 7,632 6,721.0 6,721.7 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 2 1/8" EnerJet 7,637 7,642 6,725.7 6,729.6 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 21/8" EnerJet RPERF. Notes: General & Safety 7544 -7568 End Date Annotation IPERF, 1/25/1989 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 7557 - 7,558 7/27/2010 NOTE: View Schematic wl Alaska Schematic9.0 IPERF, 7,560.7,561 IPERF, 7,566 -7567 i I IPERF, 75877588 RPERF, 7,582 -7,598 IPERF, 7594 -7.595 MERE, ' '' 75997600 =c meits RPERF, 7,5967,614 IPERF -. 7,606-7607 IPERF 7.610.7,611 IPERF, 7612 -7613 PERF, 7,6,9 -7.620 = = Mandrel Details Top Depth Top Port .= . (TVD) Incl OD Valve Latch Sloe TRO Run 7,621-76 IPERF MB) (RKB) (1 Make Model (in) sect, Type Type (in) (psi) Run Date Com... 22 Stn To P( ' 1 2,559.8' 2,559.5 3.18 MERLA TMPD 1 GAS LIFT DMY BK -2 0.000 0.0 5/21/2011 IPERF, 2 4,412.4 4,218.8 37.34 MERLA TMPD 1 GAS LIFT DMY BK -2 0.000 0.0 5/21/2011 7,6267,626 3 5,684.3 5,214.6 39.67 MERLA TMPD 1 GAS LIFT DMY BK -2 0.000 0.0 5/21/2011 IPERF 4 6,233.8 5,636.4 39.20 MERLA TMPD 1 GAS LIFT DMY BK -2 0.000 0.0 12/4/1986 7631 - 7632 ' 5 6,627.5 5,940.1 39.76 MERLA TMPD 1 GAS LIFT DMY BK -2 0.000 0.0 5/21/2011 7,637 -7.61 IPERF , III 6 6,991.3 6,220.2 38.97 MERLA TMPD 1 GAS LIFT DMY BK -2 0.000 0.0 12/4/1986 7 7,387.8 6,530.0 38.31 MERLA TGPD 1 1/2 GAS LIFT DMY 'RK 0.000 0.0 5/22/2011 • PRODUCTION, 35- 7,1338N 46 TD, 7,854 ■ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaq(8 alaska.gov; doa.aoacc.prudhoe.bav(8 alaska.gov; phoebe.brooks(a)alaska.aovi tom.maunderc8 alaska.aov OPERATOR: Conoco Phillips Alaska Inc. FIELD / UNIT / PAD: Kuparuk / KRU / 3K DATE: 07/29/11 OPERATOR REP: Phillips / Arend AOGCC REP: Bob Noble Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K -11 Type Inj. W TVD 6,580' Tubing 2,980 2,980 2,980 2,980 Interval P.T.D. 1861640 Type Test P Test psi 1 800 Casing 1,300 2,345 2,300 2,290 P/F P Notes: Initial state witness post conversion to injector OA 950 955 960 960 MITIA Well Type Inj. TVD ,Tubing Interval • P.T.D. Type test Test psi Casing P/F OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10-426 (Revised 06/2010) MIT KRU 3K - 11 07 - 29 - 11 Witnessed.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reooftalaska.00v; doa .aoacc.prudhoe.bavealaska.aov; phoebe.brooks(alaska.00v; tom.maunder @alaska.crov OPERATOR: Conoco Phillips Alaska Inc. FIELD 1 UNIT 1 PAD: Kuparuk / KRU / 3K DATE: 07/29/11 OPERATOR REP: Phillips / Arend AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K -11 Type Inj. W TVD 6,580' Tubing 2,980 2,980 2,980 P.T.D. 1861640 Type Test P Test psi_ 1800 Casing 1,325 1,350 1,350 F Notes: OA 960 1800 1550 MITOA Well 3K -11 Type Inj. W TVD 6,580' Tubing 2,980 2,980 2,980 2,980 P.T.D. 1861640 Type Test P Test psi 1800 Casing 1,350 1,350 1,350 1,350 P OA 1550 1825 1775 1765_ MITOA retest Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 - 426 (Revised 06/2010) MIT KRU 3K -11 07 -29 -11 Waived.xls Page 1 of 2 • Maunder, Thomas E (DOA) From: Brooks, Phoebe L (DOA) Sent: Thursday, August 11, 2011 3:22 PM ( 1 To: NSK Problem Well Supv (— ` o Cc: Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: RE: MITs for KRU 3K -11, 3A -11, and 3A -14 7/29/11 Attachments: MIT KRU 3K -11 07 -29 -11 Waived.xls; MIT KRU 3K -11 07 -29 -11 Witnessed.xls; MIT KRU 3A- 11 & 3A -14 07 -29 -11 Revised.xls Kelly, Attached are revised MIT reports as follows: • MIT KRU 3K-11 07-29-11 was separated into two reports (waived and witnessed) • MIT KRU 3A -11 & 3A -14 07 -29 -11 now reflects a test psi of 2900. Please let me know if you disagree. Thank you, Phoebe Phoebe Brooks AUG 20 . Statistical Technician II Alaska Oil and Gas Conservation Commission x .:. t ' TAG V 1f Phone: 907 - 793 -1242 Fax: 907- 276 -7542 From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Thursday, August 11, 2011 3:28 AM To: Brooks, Phoebe L (DOA) Subject: RE: MITs for KRU 3K -11, 3A -11, and 3A -14 7/29/11 Hi Phoebe, I'm not sure if they did go out -we had a fill -in while Brent's been on vacation. I don't believe there were any other witnessed tests while I was off. As usual, let me know if I get anything wrong in the forms. Thanks Kelly Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks @alaska.gov] 8/30/2011 Page 2 of 2 • Sent: Wednesday, August 10, 2011 1:56 PM To: NSK Problem Well Supv Subject: MITs for KRU 3K -11, 3A -11, and 3A -14 7/29/11 Brent /Kelly, I'm reviewing the July MIT reports and 1 don't seem to have the corresponding operator reports for these MITs dated 7/29/11...were they sent? I'm working on July imports now so if you could please send them (and any other reports that occurred after the 7/27/11 email) as soon as possible I would appreciate it. Thank you, Phoebe Phoebe Brooks Statistical Technician it Alaska Oil and Gas Conservation Commission Phone: 907 - 793 -1242 Fax: 907 - 276 -7542 I II 8/30/2011 . • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaa(8alaska.gov doa .aoacc.prudhoe.bay laska.aor, phoebe.brooksetialaska.uov; tom.maunderetalaska.gov OPERATOR: Conoco Phillips Alaska Inc. FIELD / UNIT / PAD: Kuparuk / KRU / 3K DATE: 07/29/11 OPERATOR REP: Phillips / Arend • AOGCC REP: Bob Noble Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K -11 Type Inj. W TVD 6,580' Tubing 2,980 2,980 2,980 2,980 Interval P.T.D. 1861640 Type Test P Test psi 1800 Casing 1,300 2,345 2,300 2,290 P/F P Notes: Initial state witness post conversion to injector OA 950 955 960 960_ MITIA Wet Type try. TVD Tubing Interval P.T.D. Type test _ Test psi Casing P/F OA Well Type lnj. TVD Tubing Interval P.T.O. _ _ Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differentia( Temperature Test 0 = Other (describe in notes) Form 10-426 (Revised 06/2010) MIT KRU 3K - 11 07 - 29 - 11 Witnessed.xls • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(8alaska.uov; doa .aogcc.pnudh0e.baVaIalaska.gov; phoebe.brooks(dalaska.gov; tom.maunder(dalaska.0ov OPERATOR: Conoco Phillips Alaska Inc. FIELD / UNIT / PAD: Kuparuk / KRU / 3K DATE: 07/29/11 OPERATOR REP: Phillips / Arend AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K -11 Type Inj. W TVD 6,580' Tubing 2,980 2,980 2,980 P.T.D. 1861640 Type Test P Test psi 1800 Casing 1,325 1,350 1,350 F Notes: OA 960 1800 1550 MITOA Well 3K -11 Type In . W WO 6,580' Tubing 2,980 2,980 2,980 2,980 P.T.D. 1861640 TA. - Test P Test 1800 Casi . 1,350 1,350 1,350 1,350 P OA 1550_ 1825_ 1775_ 1765 MITOA retest Well Type Inj. TVD Tubing Interval P.T.D. Type test _ Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Dittetentiat Temper-440e Test 0 = Other (describe in notes) I Form 10 (Revised 06/2010) MIT KRU 3K-11 07 -29-11 Waived.xls Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Monday, July 25, 2011 9:07 AM To: Maunder, Thomas E (DOA); NSK Problem Well Supv Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Subject: RE: June 2011 monthly failed MIT report 07 -24 -11 Tom, We have added 2L -305, 3F -04, and 3K -11. 3H -09 was removed because it was getting a RWO. I will be sending in a cancellation notice for 3H -09 in the coming days. rP Thanks IS b k Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, July 25, 2011 8:46 AM To: NSK Problem Well Supv Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Subject: RE: June 2011 monthly failed MIT report 07 -24 -11 Hi Kelly, I am just starting to review the document. Can you provide a list of any wells added or removed? That helps focusing my review. Thanks, Tom Maunder, PE AOGCC From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Sunday, July 24, 2011 8:33 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Subject: June 2011 monthly failed MIT report 07 -24 -11 All, Attached is the monthly failed MIT report for the month of June 2011. Please call if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 7/26/2011 • • ConocoPhillips Well 3K -11 Injection Data • Water Injection ® Gas Injection I 4000 3500 3000 P) 2500 a i • AA a 2000 A_ 1500 . A • 1 000 500 0 0 500 1000 1500 2000 2500 3000 3500 Injection Rate, bwpd or mscfpd I Water Tubing Date of Gas Injected IA Pressure OA Pressure Injection Injected Pressure (mscfpd) (psi) (psi) (bwpd) (psi) 30- Jun -11 2841 0 2436 1200 900 29- Jun -11 2924 0 2426 1200 980 28- Jun -11 2958 0 2427 1200 831 27- Jun -11 3031 0 2388 1200 950 26- Jun -11 2967 0 2299 1200 950 25- Jun -11 3008 0 2243 1200 950 24- Jun -11 3133 0 2212 1150 847 23- Jun -11 3075 0 2197 1150 950 22- Jun -11 2790 0 2103 1050 625 21- Jun -11 2719 0 2005 1025 625 20- Jun -11 1683 0 1345 950 870 i 19- Jun -11 2695 0 1952 100 765 18- Jun -11 2783 0 1889 1050 800 17- Jun -11 2793 0 1749 875 650 16- Jun -11 2747 0 1623 1000 950 15- Jun -11 2843 0 1499 1391 900 14- Jun -11 2909 0 1349 950 882 13- Jun -11 1971 0 1199 1000 846 12- Jun -11 2 0 2176 950 950 11- Jun -11 0 0 2894 1391 932 10- Jun -11 0 0 2899 950 929 950 929 950 930 950 929 1390 929 1000 900 1000 900 • • ConocoPhillips Well 3K -11 Injection Data • Tbg Psi • IA Psi • OA Psi 4000 - 3500 - 3000 - , , .N 2500 - , • • • • • a 2000 • • • • • 1500 - • • ■ • MM MMMM •• 1000 - ■ • ■ :: • ! : : : : • • • • • • • • 500 - 0 06/11 07/11 Date J PTD# 186 -164 IAxOA communication 6/18/11 - MITIA,MITOA passed 6/20/11 - ICPOT, ICPPPOT passed • • From: NSK Problem Well Supv [ mai lto:n1617 @conocophillips.com] Sent: Friday, June 17, 2011 6:18 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: 3K-11 SW Injector (PTD 186 -164) Suspect IA X OA Tom, Jim, Guy Kuparuk SW injector 3K -11 (PTD 186 -164) was reported to have suspect IAxOA communication on SW injection post conversion based on IA and OA equalized and operations report of being unable to bleed OA to attain differential. Diagnostics will be performed tomorrow. I will update you with results. The well passed an MIT -IA to 2500 psi 05/23/2011 and was BOI on 06/12/2011. Based on results of diagnostics the well may be added to the Monthly Failed MIT report. Attached is a 90 day TIO plot and schematic. Please let me know if you have any questions. Ian Ives Problem Wells Supervisor DHD Lead Technician AES Central Shops Phone: (907) 659 -7224 Pager: 909 TRN_ANNL ANNULUS PRESSURE TRENDS 500. 3000. s`" WELL NAME WLKRU3K -11 3000 200. 3000. F\ I 3000. 2700 3000. 3000. 2400 3000. 2100 1800 .__ __ ____ - 1500 1200 1 . 1 A 1(1,1111 ��iia - _ J . - . . _ `�' - - - . , _ - _ - _ 900 0. 0. 600 1 1 0. 0. 300 0. 0. 0 0. 0. PLOT START TIME MINOR TIME PLOT DURATION PLOT END TIME 19- MAR -11 09:22 MAJOR TIME WEEK 02160:00:0( HRS 7- .IUN -11 09 :22 PICK TIME: 7D ®n OW ® 6M miim® RT SC TAG NAME DESCRIPTION P -VALUE LATEST III WL3K -11 -CHOKE FLOW TUBING CHOKE 7777777 II[PREV WELL DRILLSITE WELL III SCRATCH 31 FLOW TUBING PRESSURE 7727777 3K 11 MI SCRATCH_31 FLOW TUBING TEMP 7777777 • NEXT WELL ® ? ? ? ? ? ?? ® 7777777 ENTRY TYPE OPERATOR POr 7777777 - OPERATOR VERIFIED Pr SCRATCH_31 INNER ANNULUS PRES ? ? ? ? ? ?? MI SYSTEM AUTO ENTRY P' SCRATCH_31 OUTER ANNULUS PRES ? ? ? ? ? ?? BOTH 1 11WELL PROD SUM WELL EVENTS SUM IAN UL BLEED SUM "[PRESSURE DIFF RECORDING SUMMARY pi WELL GUIDELINES I IFWELL INJECT SUM I W.E. ANALYSIS I CREATE ANUL EVNT III 500 PSI DIFF III RECORDING TREND III MONTHLY SUMMARY • • Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK -69 PO Box 196105 ConocoPhiflips Anr, 9951 -6105 Phone (907)659 ageAK -7535 Fax: 659 -7314 May 16, 2011 Dan Seamount RE EIVED AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission ?UN 22, 2O1 33 W. 7` Ave. Ste. 100 Anchorage, AK 99501 iktalla & Cow. Commission Dear Mr. Seamount, Enclosed you will find 10 -404 report of Sundry Well Operations recording the conversion of Kuparuk Well 3K -11 (PTD 186 -164), to water injection service. If you have any questions regarding this matter, please contact myself or Robert D. Christensen at 907 - 659 -7535. Sincerely, D ll R. Humphrey JV Darrell Attachments Sundry Notice Well Schematic STATE OF ALASKA ` ALASK/IIIL AND GAS CONSERVATION COMMIS IL REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Fbrforations r Stimulate r Other r PROD to WINJ Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory r - 186 -164 3. Address: 6. API Number: Stratigraphic r Service r P. 0. Box 100360, Anchorage, Alaska 99510 — 50-029-21654-00 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25629 / ALK 2562 " 3K -11 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7853 feet Plugs (measured) None true vertical 6896 feet Junk (measured) None Effective Depth measured 7753 feet Packer (measured) 7434, 7452, 7467, 7477 true vertical 6809 feet (true vertucal) 6566, 6580, 6592, 6600 Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 110 110 0 0 SURFACE 3860 12 3895 3807 0 0 PRODUCTION 7803 7 7838 6884 0 0 0 0 0 0 0 0 0 0 0 I Perforation depth: Measured depth: 7544 - 7568, 7582 - 7598, 7582 - 7598, 7598 - 7614, 7619 - 7622,7625- 7626,7631- 7632,7637 -7642 True Vertical Depth: 6652 - 6671, 6682 - 6695, 6695 - 6707, 6711- 6714,6716- 6717,6721- 6722,6726 -6730 RECEIVED Tubing (size, grade, MD, and TVD) 2.875, J -55, 7477 MD, 6600 TVD t_ii\' ';1, 901: Packers & SSSV (type, MD, and TVD) SBR - CAMCO OEJ SBR @ 7434 MD and • D PACKER - CAMCO HRP -1 -SP PACKER (1-nd 6580 TVD�;a8 o � C i8 CON. Commission NIPPLE - CAMCO D NIPPLE NO GO @ 7467 • and 6592 TVD SOS - CAMCO SHEAR OUT SUB @ 7477 MD and 6600 TVD A n ne rap SAFETY VLV - CAMCO TRDP -1A -SSA SAFETY VALVE @ 1805 MD and 1805 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 113 340 17 948 339 Subsequent to operation 0 0 2747 925 1623 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service ( Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations _ X GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 16. 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: 311 -025 Contact Darrell Humphrey /Bob Christensen Printed Name Darrell R. Humphrey Title Production Engineering Specialist Signature ` Phone: 659 -7535 Date ( ( ---t , t \ Form 10 -404 Revised 10/2010 \ RBDMS JUI� 1 1 zon -'`21 1Z Submit Original Only /"" /( • • 3K -11 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/12/111WeII brought on seawater injection 1 • KUP ill 3K -11 CQ(yQcQPhjjjjp5 e ll Attributes Max Angle & MD TD A;3Y Wel!bore API /UWI Field Name Well Status Inc(( ") MD (tt813 ct ) A Btm (ftKB) ;;c„a ety 500292165400 KUPARUK RIVER UNIT INJ 40.47 5,800.00 7,854.0 Comment H2S (ppm) Date Annotation End Dale KB.Grd (R) Rig Release Data "' SSSV: TRDP 150 12/22/2010 Last WO: 39.01 11/5/1986 Well Con69. - 3K -11 6/162011 8.55.45 AM - Schematic- Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: RKB 7,629.0 11/9/2010 Rev Reason: GLV C/O ninam 6/16/2011 ammouillosiL Cas Strings HANGER 35 Casing Description String 0... String ID ... Top (ft8B) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 36.0 110.0 110.0 62.50 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 35.0 3,895.0 3,807.2 36.00 J - 55 BTC Casing Description String 0... String ID ... Top MKS) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd PRODUCTION 7 6.276 35.0 7,837.8 6,884.2 26.00 J -55 BTC CONDUCTOR,___ Tubing Strings 36'110 Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 2 7/8 2.441 35.0 7,478.0 6,600.8 6.50 J -55 EUE8rdABMOD SAFETY VLV, Completion Details 1,805 Top Depth (TVD) Top Inc! Komi... GAS LIFT, Top (ftKB) tKB) (RKB) 1') Item Description Comment ID (In) 2,560 35.0 35.0 0.19 HANGER CIW TUBING HANGER 2.875 1,805.2 1,805.2 1.02 SAFETY VLV CAMCO TRDP -1A -SSA SAFETY VALVE 2.312 7,434.0 6,566.3 38.35 SBR CAMCO OEJ SBR 2.312 7,451.6 6,580.1 38.33 PACKER CAMCO HRP -1 -SP PACKER 2.347 SU353,5RFACE, 7,467.4 6,592.5 38.32 NIPPLE CAMCO D NIPPLE NO GO 2.250 95 GAS LIFT, 1 7,477.3 6,600.3 38.30 SOS CAMCO SHEAR OUT SUB 2.441 4,412 I Perforations & Slots GAS LIFT, Shot 5,584 Top (TVD) Btm (TVD) Dens Top (RKB) Ben (RKB) IRKS) (RKB) Zone Date ( °h... Type Comment GAS LIFT, 7,544 7,568 6,652.7 6,671.5 A - 3, 3K - 11 8/26/1988 8.0 RPERF 60 deg phase; 2 1/8 " EnerJet 6,234 1111 7,557 7,558 6,662.9 6,663.6 A -3, 3K -11 1/13/1987 1.0 IPERF Zero deg. phasing; 21/8" EnerJet GAS LiFT, 7,560 7,561 6,665.2 ' 6,666.0 A -3, 3K -11 1/13/1987 1.0 IPERF Zero deg. phasing; 2 1/8" EnerJet 6,628 MI 7,566 7,567 6,669.9 6,670.7 A -3, 3K -11 1/13/1987 1.0 IPERF Zero deg. phasing; 2 1/8" EnerJet GAS LIFT, 7,582 7,598 6,682.5 6,695.1 A -2, 3K -11 8/26/1988 8.0 RPERF 60 deg phase; 21/8" EnerJet 5,931 - 7,587 7,588 6,686.4 6,687.2 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 21/8" EnerJet GAS LIFT, i - 7,594 7,595 6,691.9 6,692.7 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 21/8" EnerJet 7,386 III 7,598 7,614 6,695.1 6,707.5 A-2, 3K -11 8/12/1988 4.0 RPERF 90 deg ph; Tornado Link Jet In 7,599 7,600 6,695.9 6,696.6 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 2 1/8" EnerJet 566, 7,434 •= 7,606 7,607 6,701.2 6,702.0 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 21/8" EnerJet PACKER. 7,452 III 7,610 7,611 6,704.4 6,705.2 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 21/8" EnerJet 7,612 7,613 6,706.0 6,706.7 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 2118" EnerJet 7,619 7,620 6,711.5 6,712.3 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 21/8" EnerJet NIPPLE, 7,467 $ U/ 7,621 7,622 6,713.1 6,713.9 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 21/8" EnerJet El 7,625 7,626 6,716.2 6,717.0 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 21/8" EnerJet SOS, 7,477 t. - 7,631 7,632 6,721.0 6,721.7 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 2 1/8" EnerJet 7,637 7,642 6,725.7 6,729.6 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 2 1/8" EnerJet RPERF, Notes: General & Safety • 7 5447 566 End Date Annotation IPERF, 1/25/1989 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 7557 - 7558 a I 7/27/2010 NOTE: View Schematic w/ Alaska Schematic9.0 IPERF, 7,560 -7 561 IPERF. 7,566 -7,567 IPERF, 75877588 RPERF, 7,562-7595 IPERF. 7,594 -7,595 IPERF, seem :we 7,599- 7,600 RPERF, - 7,598 - 7,614 = IPERF, 7,506 -7,507 same IPERF, 7,610.7,611 IPERF, ac 7,612 -7613 IPERF, 7,619.7,620 - Mandrel Details Top Depth Top Port • (TVD) Inc! OD Valve Latch Size TRO Run 7,621 - IP7,822 Top _ Stn To ftKB (RKB) (1 Make Model (!n) Sery Type Type (in) (psi) Run Date Corn... 1 2,559.8 2,559.5 3.18 MERLA TMPD 1 GAS LIFT DMY BK -2 0.000 0.0 5/21/2011 IPERF, - 2 4,412.4 4,218.8 37.34 MERLA TMPD 1 GAS LIFT DMY BK -2 0.000 0.0 5/21/2011 7825 - 7,526 3 5,684.3 5,214.6 39.67 MERLA TMPD 1 GAS LIFT DMY BK -2 0.000 0.0 5/21/2011 IPERF, 4 6,233.8 5,636.4 39.20 MERLA TMPD 1 GAS LIFT DMY BK -2 0.000 0.0 12/4/1986 7,631 - 7,832 - i 5 6,627.5 5,940.1 39.76 MERLA TMPD 1 GAS LIFT DMY BK -2 0.000 0.0 5/21/2011 IPERF, al ■ 6 6,991.3 6,220.2 38.97 MERLA TMPD 1 GAS LIFT DMY BK -2 '0.000 0.0 12/4/1986 7,637 - 7,642 7 7,387.8 6,530.0 38.31 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/22/2011 PRODUCTION, 35 -7 834 35 7,854 ■ • • STIAlfE LYLASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Darrell R. Humphrey f Production Engineering Specialist (Q ConocoPhillips Alaska, Inc. P.O. Box 100360 \ C66- Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3K -11 Sundry Number: 311 -025 Dear Mr. Humphrey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. SPZ- Chair DATED this / day of March, 2011. Encl. • • Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK -69 PO Box 196105 ConocoPhillips Anchorage, AK 99519 -6105 Phone: (907) 659 -7535 Fax: 659 -7314 January 28, 2011 Dan Seamount AOGCC Commissioner FEE , tl State of Alaska, Oil & Gas Conservation Commission 33 W. 7 Ave. Ste. 100 ^.x'! tl 7 GA': COOS. C. ;Sion Anchorage, AK 99501 Dear Mr. Seamount, ConocoPhillips Alaska Inc. requests approval to convert KRU Well 3K -11 from Oil Production service to Water Injection service. Well 3K -11 will be used for reservoir . pressure support for 3K -10 CTD planned for 2011 Enclosed you will find 10 -403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. for 3K -11 (PTD 186 -164). If you have any questions regarding this matter, please contact myself or Robert D. Christensen at 659 -7535. Sincerely, Darrell R. Humphrey ump ey Attachments Sundry application Well schematic r Con Wr u/t,I( {oaf Arver 6e44 q frr6,7 t'' ' /L ,eflc � < 100 154 Gee 4 ,'j GrM't� took f 4 /f/°,v'�'',ie ict' M/' � Wa w e� 1`e• - TO l� r or pFff rn� , CO V " R, (04 vor! • ^ roe 4/l ( ro 44 rip 140,41 (e/ (e$" b" # I' "mod /cawiy 44694 7f f PIE7 'o, of r4r M/. ,• G4%s:do ; s 44)ei1 n Ce d/. - ro c.. ou t Ci 3dd ` iso ,3kes. /bc cKpedea A w dov Co IL ue es oz. , 2 Z Z- ll STATE OF ALASKA AO /\\ ALASKOIL AND GAS CONSERVATION COMMISSION 3i(' ( I ‘‘, APPLICATION FOR SUNDRY APPROVALS V 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell r Change Approved A r Suspend r Rug Perforations r Perforate r Pill Tubing r Tine Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other: PROD to WINJ [7 • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development J Exploratory r 186 -164 • 3. Address: Stratigraphic r Service 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50 -029- 21654 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number where ownership or landownership changes: Spacing Exception Required? Yes r No I✓J • 3K -11 • 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25629 / ALK 2562 Kuparuk River Field / Kuparuk River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7853 • 6896 • 7753' 6809' Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 110' 110' SURFACE 3860 12 3895' 3807' PRODUCTION 7803 7 7838' 6884' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 582- 7598,7598- 7614,7619- 7622,7625 - 76.6652- 6671,6682- 6695,6695 - 6707,6711- 6714,E 2.875 J -55 7477 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) SBR - CAMCO OEJ SBR MD= 7434 TVD= 6566 PACKER - CAMCO HRP -1 -SP PACKER MD= 7452 TVD= 6580 NIPPLE - CAMCO D NIPPLE NO GO MD= 7467 TVD= 6592 SOS - CAMCO SHEAR OUT SUB MD= 7477 TVD= 6600 SAFETY VLV - CAMCO TRDP -1A -SSA SAFETY VALVE MD= 1805 TVD= 1805 12. Attachments: Description Summary of Proposal F7 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r • 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: Febuary 20, 2011 011 r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r • GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Darrell Humphrey /Bob Christesen Printed Name Darrell R. Humphrey Title: Production Engineering Specialist Signature Phone: 659 -7535 Date / -2S • 1 Commission Use Only 0496 Sundry Numbers I I • Conditions of approval: Notify Commission so that a representative may witness fiq R Plug Integrity r BOP Test r Mechanical Integrity Test r/Location Clearance r er: .j- irn D j, 'to. ! at 4Gt0 r4P 4 . A 2 i '' 0 1 irc .41 1,11-z t:, Form Required: t, , co R, U - Cons. C .. 3SIon APPROVED BY f Approved by: / r COMMISSIONER THE COMMISSION Date: CA MAR 02 101 1 R 1 G 1 N A L (' Form 10 -403 Rev Su frmjp D u li �e / • 3K -11 DESCRIPTION SUMMARY OF PROPOSAL Conoco Phillips Alaska Inc. requests approval to convert KRU Well 3K -11 from Oil Production service to Water Phill p s q PP _Injection service. Well 3K -1 will be used for reservoir pressure support for 3K -10 CTD planned for 2011. . The 16" Conductor was cemented with 1540# Poleset (110' and / 110' tvd). The 9 -5/8" Surface casing (3895' and / 3807' tvd) was cemented with 970sx AS IV and 320sx Class G. The 7" Production casing (7838' and / 6884' tvd) was cemented with 300sx Class G and 175sx AS I. The top of the Kuparuk C was found at 7338' and / 6491' tvd. The top of the Kuparuk C1 was found at 7386' and / 6529' tvd. The top of the Kuparuk B was found at 7396' and / 6536' tvd. The top of the Kuparuk A was found at 7524' and / 6637' tvd. The injection tubing /casing annulus is isolated via Camco 5.937" OD x 2.347" ID located @ 7451 and / 6580' tvd. An MIT -IA was last performed on 9/28/10; WC) TIFL- passed; MITOA- passed; Initial T /I /0= 140/970/980; OA FL @ 67ft. Pressured up OA to 1800psi. with 2.75bbls. of diesel T /I /0= 140/970/1800; 15min. reading T /I /0= 140/970/1771; 30min. reading T /I /0= 140/970/1767; Bled OA. 'T/I/0= 140/970/990; Shot IA FL @ 6991ft. #6 DMY. Shut in WH and stacked out T with liftgas. T /I /0= 775/790/990; Bled IA. T /I /0= 775/275/920; Shot IA FL © same location. Final T /I /0= 775/275/920 c ra - e 3 "`° e 5 1.-410 7ed 2-Zo -1l • KUP 3K -11 - ConocoPhillips ell Attributes Max Angle & MD TD 1, 7 t i , I Wellbore APIIUWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (RKB) l „ Ihp 500292165400 KUPARUK RIVER UNIT PROD 40.47 5,800.00 7,854.0 Comment 425 (ppm) Data Annotation End Date KB-63rd (R) Rig Release Dab "- - SSSV: TRDP 90 11/29/2009 Last WO: 39.01 11/5/1986 Well Config: - 3K -11, 11272010 7:43:33 PM - Schemata -Actual Annotation Depth (RKB) End Date Annotation Last Mod.., End Date Last Tag: RKB 7,629.0 11/9/2010 Rev Reason: DRIFT & TAG Imosbor 11/27/2010 Casing Strings AN HGER, 35 1 r• Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd - CONDUCTOR 16 15.062 36.0 110.0 110.0 62.50 H WELDED II Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 35.0 3,895.0 3,807.2 36.00 J BTC , 11111 Casing Description String 0... String ID ... Top (fti(8) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 35.0 7,837.8 6,884.2 26.00 J -55 BTC CONDUCTOR,_ Tubing Strings 38 „0 Tubing Description String O.. String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING I 27/8 2.441 I 35.0 I 7,478.0 I 6,600.8 I 6.50 I J -55 EUE8rdABMOD SAFETY VI-v, j __. Completion Details 1,1x/5 l_ ° 1 Top Depth (TVD) Top Inc! Noml... GAS UFT . E Top (RKB) (RKB) (1 Item Description Comment ID (In) z 1 35.0 35.0 0.19 HANGER CIW TUBING HANGER 2.875 1,805.2 1,805.2 1.02 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.312 7,434.0 6,566.3 38.35 SBR CAMCO OEJ SBR 2.312 7,451.6 6,580.1 38.33 PACKER CAMCO HRP -1 -SP PACKER 2.347 SURFACE, ,J ■ 7,467.4 6, 592.5 38.32 NIPPLE CAMCO D NIPPLE NO GO 2.250 35 - 3,895 OAS LIFT, 7,477.3 6,600.3 38.30 SOS CAMCO SHEAR OUT SUB 2.441 4,012 [ Perforations & Slots GAS LIFT, Shot 5,684 - Top (TVD) Btm (TVD) Dens Top (8168) Btm (RKB) (R148) (RKB) Zone Date (.h••• Type Comment GAS LIFT, ( 7,544.0 7,568.0 6,652.7 6,671.5 A -3, 3K -11 8/26/1988 8.0 RPERF 60 deg phase; 2 1/8" EnerJet 6'234 7,557.0 7,558.0 6,662.9 6,663.6 A-3, 3K -11 1/13/1987 1.0 IPERF Zero deg. phasing; 2 1/8" EnerJet GAB LIFT, - 7,560.0 7,561.0 6,665.2 6666.0 A-3, 3K -11 1/13/1987 1.0 IPERF Zero deg. phasing; 21/8" EnerJet 6,626 7,566.0 7,567.0 6,669.9 6,670.7 A-3, 3K -11 1/13/1987 1.0 - IPERF Zero deg. phasing; 2 1/8" EnerJet GAS LIFT, 1 7,582.0 7,598.0 6,682.5 6,695.1 A -2, 3K -11 8/26/1988 8.0 RPERF 60 deg phase; 2 1/8" EnerJet 1 Li 7,587.0 7,588.0 6,686.4 6,687.2 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 2 1/8" EnerJet GAS LIFT, 7,594.0 7,595.0 6,691.9 6,692.7 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 2 1/8" EnerJet 7,388 H 7,598.0 7,614.0 6,695.1 6,707.5 A -2, 3K -11 8/12/1988 4.0 RPERF 90 deg ph; Tornado Link Jet 7,599.0 7,600.0 6,695.9 6,696.6 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 2 1/8" EnerJet 66 } ( 6, 7,434 l l 7,606.0 7,607.0 6,701.2 6,702.0 A-2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 2 1/8" EnerJet PACKER, 7,452 tN� ' 7,610.0 7,611.0 6,704.4 6,705.2 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 2 1/8" EnerJet 7,612.0 7,613.0 6,706.0 6,706.7 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 21/8" EnerJet 7,619.0 7,620.0 6,711.5 6,712.3 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 2 1/8" EnerJet NIPPLE, 7,467 7,621.0 7,622.0 6,713.1 6,713.9 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 2 1/8" EnerJet 7,625.0 7,626.0 6,716.2 6,717.0 A -2, 3K -11 1/13/1987 ' 1.0 IPERF 0 deg. phase; 2 1/8" EnerJet SOS, 7,477 f ' 7,631.0 7,632.0 6,721.0 6,721.7 A -2, 3K -11 1/13/1987 1.0 IPERF 0 deg. phase; 2 1/8" EnerJet 7,637.0 7,642.0 6,725.7 6,729.6 A -2, 3K -11 1/13/1987 1.0 IPERF ' 0 deg. phase; 2 1/8" EnerJet RPERF, Notes: General & Safety 75447588 End Date Annotation IPERF, 1/25/1989 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 7,557 - 7.558 7/27/2010 NOTE: View Schematic w/ Alaska Schernatic9.0 IPERF, 7,5607,567 IPERF, 7,568 -7,587 IPERF, 7,587 -7,588 RPERF, 7582 -7,598 IPERF, 7,594 -7,595 IPERF, 7,599 - 7,800 RPERF, 7,5987,514 - IPERF, °- 7,6087,507 eves. am.. IPERF, _ 7,8767,877 PERF, 7,612 -7,673 e = 7,e,si�o - - Mandrel Details Top Depth Top Port (TVD) Ind OD Valve Latch 510. TRO Run IPERF, = _ 7,821-7,622 - Stn To MRS/ 1 ") Make Model (In) Sery Type Type (In) (Pei) Run Date Com... PI 1MKB ) 1 2,559.8 2,559.5 3.18 MERLA TMPD 1 GAS LIFT GLV BK -2 0.188 1,410.0 6/14/1992 IPERF, 2 4,412.4 4,218.8 37.34 MERLA TMPD 1 GAS LIFT GLV BK -2 0.188 1,365.0'6/14/1992 7,625 - 7,620 - -3 5,684.3 5,214.6 39.67 MERLA TMPD 1 GAS LIFT GLV BK -2 0.188 1,335.0 6/14/1992 IPERF, 4 6,233.8 5,636.4 39.20 MERLA TMPD 1 GAS LIFT DMY BK -2 0.000 0.0 12/4/1986 7,631.7,532 5 6,627.5 5,940.1 39.76 MERLA TMPD 1 GAS LIFT GLV BK -2 0.188 1,305.0 6/14/1992 IPERF, 6 6,991.3 6,220.2 38.97 MERLA TMPD 1 GAS LIFT DMY BK -2 0.000 0.0 12/4/1986 7,637 - 7512 7 7,387.8 6,530.0 38.31 MERLA TGPD 1 1/2 GAS LIFT GLV RK 0.188 1,030.0 6/14/1992 PRODUCTION, 357,838 .-- TD, 7,851 ■ A c r Distances from 3K -11 to offset wells Conoc . ,... Phillips Alaska NoR,� SLOPE OPERATIONS _No oEME oPMEN, 1J 1 (76 - g Y - • • 3K- 1o3P62` 1 ; (CTD): � , ;3K - 103P61 From 3K -11 to: 3K -12L1 CTD : 975' rd'--.-- 3K -10 , 3K- 12L1 -01 (CTD): 975' _ -, 3K -09 -"A 3K -12 (parent): 1565' r\-___ 3K-01 -- 3K -10 planned CTD: 1400' • 3K -10 parent: 2690' r14 z- 3?,�._ 3K- 13:2635 -� 3K-15: 300 5 3K -17: 3550' 3K -35: 3705' -SV/ ,<,, y/ 3K -16: 3845' 3K. 3411 � 2635° ' 1 1 156 - 3K-12 3K- 09BL2 -01 (CTD): 2505' ( Note: measurements are to /from A Sand perfs rounded to nearest 5'; • � 4) )0 \5..., distances o L. i u slueuacKs are to /from closest point along lateral 3K-17 3K -I6 3K -35 3K -15 • . . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission crMIr.\'I\1c·U:;-O Au G 0 1 20tH 333 West ih Avenue, Suite 100 t;i}W1"U,I'U- Anchorage, AK 99501 \e-b- ¡It,1f Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, 1 -='-'.- ~-:. \- Perry KI . ConocoPhillips Well Integrity Supervisor / fILii/of- . . jUL 3 1 2007 & ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/28/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft na Qal 3K-1 186-101 19' 2.6 19" 7/7/2007 7 7/27/2007 3K-2 186-102 53' 7.2 9" 7/7/2007 3.7 7/22/2007 3K-3 186-103 43' 5.8 11" 7/7/2007 4.2 7/27/2007 3K-5 186-123 66' 9.0 26" 7/7/2007 9.6 7/22/2007 3K-6 186.;124 58' 7.9 13" 7/10/2007 4.8 7/22/2007 3K-7 186-125 70' 10.5 35" 7/7/2007 13.2 7/22/2007 3K-8 186-126 54' 4.0 9" 7/10/2007 3.6 7/22/2007 3K-9 186-174 26' 9.0 16" 7/10/2007 6 7/22/2007 3K-11 186-164 43'- 6.5 .. 21" . 7/10/2007 ..- 7.8 - 7/16/2007 3K-13 186-136 8" none 8" 7/10/2007 3.1 7/16/2007 .. 3K-14 186-137 8" none 8" 7/10/2007 3.1 7/16/2007 3K-15 186-138 50' 6.0 22" 7/10/2007 8.4 7/22/2007 3K-16 186-139 46' 7.0 27" 7/10/2007 9.6 7/22/2007 3K-17 186-152 56' 8.0 30" 7/10/2007 10.7 7/22/2007 3K-18 186-151 38' 5.5 23" 7/10/2007 8.4 7/22/2007 . MEMORANDUM. TO: THRU' State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, Commissioner Tom Maunder, P. i. Supervisor ~'/;~%"O\ FROM: jOhn Crisp, SUBJECT: Petroleum Inspector DATE: May 18, 2001 Safety Valve Tests Kuparuk River Unit 3K Pad May 18., 2001: I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, SSV on 3K-27 would not pass the DP test. The valve was serviced & passed the re-test The AOGCC test report is attached for reference. I inspected 14 well houses on 1Q Pad w/no problems witnessed. 'SUMMARY: I witnessed SVS testing in Kuparuk River Field. 14 wells, 28 components tested' 1 failure witnessed. 3.57% failure rate. 14 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc cc; NON-C.0NF. IDE. NTIAL SVS KRU 3K 5-18-0 ljc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Operator Rep: Ernie Barndt AOGCC Rep: John Crisp Submitted By: .. Date: Field/Unit/Pad: Kuparuk River Unit 3K Pad Separator psi: LPS 65 HPS 5/18/01 Well Permit Separ Set L/P Test Test Test Date o~l, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GASorCYCL~ 3K-01 1861010 65~ 70 50 P P OIL 5K-03 1861030 65' 70 55 P P ...... OIL .5K-06 1861240 65 70 50 P P " OIL 3K-09A 1861740 65 60~ 54 p P oIL , 3K-10 1861630 65 70: 52 P P OIL ~ 1861640 65 70,, 50 P ,. 'P , OIL 3K-14 1861370 65 60 58 P P OIL 3K-16' 1861390! 65 70 70 P'" P "oiL 3K'i7 1861520 65 60 35 P P ...... OIL 3K-23 1970970 65 70 58 P P OIL 3K-24 'i982490 65 70 50 "'P P oiL 3K-27 1970460 6~ 70 '521 P 4 OIL 3K-32 1970760 65 70 55 P P OIL 3K-35 1971090 65 70~ 50 P P OIL ,,, Wells: 14 Components: 28 Failures: 1 Failure Rate: 3.57% r--I O0 Day Remarks: RJF 1 / 16/01 Page 1 of 1 SVS KRU 3K 5-18-01jc MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ..... Ab~ OIL AND GAS C(~SERVATI~ COMIV,,...,ION ~ REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Pull tubing ,,, 2. Name of Operator Operation Shutdown Stimulate X ARCO Alaska, Inc, 3. Address P. O. Box 100360, Anchorage, AK Alter casing Repair well 5. Type ~f Well: Development X Exploratory .- Stratigraphic --. 99510 Service _ 4. Location of well at surface 1135' FSL, 316' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1173' FNL, 1177' FEL, Sec. 2, T12N, R9E, UM At effective depth 1414' FNL, 1312' FEL, Sec. 2, T12N, R9E, UM At total depth 1475' FNL, 1278' FEL, Sec. 2~ T12N~ R9E~ UM 12. Present well condition summary Total Depth: Plugging Perforate _ Other 6. Datum elevation (DF or KB) 69° RKB 7. Unit or Property name measured 7 8 5 3' fe et true vertical 6896' feet feet Kuparuk River Unit 8. Well number ,3K-11 9. Permit number/approval number , 86-164 10. APl number 5o-029-21654 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) Effective depth: measured 7753' feet true vertical 6809' feet Junk (measured) Casing Length Size Structural 1 1 0' 1 6" Conductor 389 5' 9 5/8" Surface Intermediate ' Production 783 8' 7" Liner Perforation depth: measured 7544'-7568', 7637'-7642' true vertical 6652'-6671 ', 6725'-6729' Cemented 1540# Poleset 970 Sx AS IV & 320 Sx Class G 300 Sx Class G & 175 S x AS I 7582'-7598', 6682'-6695', 7598'-7614', Measured depth 110' 3895' 7838' True vertical depth 110' 3807' 6884' 7619',7621', 7625', 7631' 6695'-6707', 6710', 6712', Tubing (size, grade, and measured depth) 2 7/8" 6.5#, J-55, ABMOD, 7478' ~ackers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA~ 1805'~ Packer: Camco HRP-1-SP, 7452' 13. Stimulation or cement squeeze summary A-Sand Water Gel Refracture Treatment Intervals treated (measured) 7544'-7568', 7582'-7598', 7598'-7614', 7619',7621', 7625', 7631', Treatment description including volumes used and final pressure Pumped 91.5MIbs in perfs-16/20 Carbolite followed by 12/18' Carbolite (see Well Service Report) 14. Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 6715', 6720' RECEIVED S E P 2 1992 Alaska 0il & Bas Cons. (;0remiss Anchorage 7637'-7642' Prior to well operation I 75 70 - 0 - I 1 00 1 05 Subsequent to operation ,4 0 0 5 0 0 - 0 - 1 1,0 0 15. AttaChments 16. Status of well classification as: Copies of Logs and Surveys run__ Water Injector __ Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Service 11o Form 10-404 Rev 09/12/90 Title Kuparuk Petroleum Engineer SUBMIT IN DUPLICATE WELl. ARCO Alaska, In,.. Sul:~ldil~y of Atllntlc Richfield C.K)ml~lny CONTRACTOR REMARKS tPBDT 77s'a WELL SERVICE REPOR FIELD - DISTRICT- STATE OPERATION AT REPORT TIME F'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weath~ ! Temo. t Chill Factor f VlMbillty l Wlnd VM. ARCO Alaska, Inc. Date' July 22, 1988 Transmittal #: 7232 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 K- 1 1 Kuparuk Well Pressure Report 5 - 1 6 - 8 8 PBU 3 K - 1 6 Bottom-Hole Pressure Survey 8 - 2 7 - 8 7 PBU Receipt Acknowledged' DISTRIBUTION: D&M ,, State of Alaska Chevron Mobil SAPC Unocal ' .... ' STATE OF ALASKA .... ~ ALASKA OIL AND GAS CONSERVATION C~MMISSION ,~ .: WELL COMPLETION OR RECOMPLETiON REPORT AND LOG 1. Status of Well Classification of Service Well / OIL [~, GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .......... 2. Name' of Operator :~. Permit Number ' ARCO Alaska, Inc. 86-164 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21654 , 4. Location of well at surface 9. Unit or Lease Name 1135' FSL, 316' FWL, Sec.35, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10'. Well Number 1173' FNL, 1177' FEL, Sec. 2, T12N, R9E, UM 3K-11 At Total Depth 11. Field and Pool 1475' FNL, 1278' FEL, Sec. 2, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc,) 6. Lease Designation and Serial No, Kuparuk River 0i 1 Pool RKB 69' ADL 25629, ALK 2562 1'2. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 10/30/86 11/05/86 01/1 8/87* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Bac~ DePth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness "of Permafrost 7853'MD 6896'TVD 7753'MD 6817'TVD YES~] NO []I 1805 feetMD 1700' (Approx) . . 22. Type Electric or Other Logs Run D IL/SP/SFL/Cal, FDC/CNL, GR, CBL/GR/CCL, Gyro 2'3. 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 "110' ''24" 1540# Poleset ,,. ...9-5/8" 36.0# J-55 Surf 3895' 1'2-1/4" 970 sx AS IV & 320 sx C ass G 7" 26.0# J-55 Surf 7838' 8-1/2" 300 .SX Class G & 175 sx AS I , , , 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) 7557 'MD 6662'TVD 7610'MD 6703'TVD 2-7/8" 7478' 7452' 7560'MD 6664'TVD 7612'MD 6705'TVD Perforated w/1 s~2rE,' ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7566'MD 6669'TVD 7619'MD 6710'TVD 0° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7587'MD 6685'TVD 7621 'MD 6712'TVD 7594'MD 6690'TVD 7625'MD 6715'TVD See attached AddenJum, dated 02/17/87. 7599'MD 6694'TVD 7631 'MD 6720,TVD for Fracture dat~. .. 7606 'MD 6700'TVD 7637'-7642'MD 6725'-6729'TVD 27. N//~ ' PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 1 "bate of Test Hours Tested PRODUCTION FOR OIL-BBL' GAs-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I ,,, , .... ~low Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-FLOUR RATE 28. · CdR E DATA Brief description of lithol°gy, porosity, fractures, apparent dips and presence of oil gas or water. Submit core chips. r~one ' *Note: Drilled RR 11/05/86. Tubing run 12/04/86. ~-:;5 [;ii ~'~ ri...:; ~;,.~i:.~;. WC2: 039: DAN I , , , Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' 30. . . GEOLOGIC MARKERS * . .. . 'FORMAl'ION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C ,..7.338' 6490' N/A . . Base Kuparuk C 7382' G525' Top Kuparuk A ., 7524' 6636, . . · Base Kuparuk A 7688' 6765' · . . . , . 31. LIST OF ATTACHMENTS . Addendums: (dated 12/13/86 & 02/17/87). 32. I hereby certify that the foreg'oing is true and correct to the best of my knowledge :. , Title neer Date ---/ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and.. Iogon all types of lands and leases in Alaska. Item 1' Classification o'f Service Wells: Gas injection, water injection, steam injection, ~air injection, .salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the prodUcing intervalS'for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. . Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement. ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 11/21/86 3K-11 Arctic Pak w/29 bbls AS I & 54 bbls Arctic Pak; tst OK. Drilling Supervisor ~ Dat*e ADDENDUM WELL: 11/17/86 1/18/87 3K-11 Rn CBL/GR/CCL f/7730'-5547'. Rn gyro f/surf to 7700'. Rn gyro f/surf to 7700'. Make GR/JB rn to 7735' WLM. Frac Kuparuk "A" sand perfs 7552' 7557' 7560' 7566' 7587' 7594' 7599' 7606' 7610' 7612' 7619' 7621' 7624' 7625' 7631' & 7637'-7642' per procedure dated 12/16/86 as follows: Stage 1: 40 bbls 145° diesel w/10% Musol @ 4.5 BPM, 4620 - 4380 psi Stage 2: 160 bbls gelled diesel @ 10.5 - 20 BPM, 7400 - 6800 psi Stage 3: 24 bbls gelled diesel @ 19 BPM, 6820 psi Stage 4: 45 bbls gelled diesel w/l# 100 mesh @ 19 BPM, 6820 - 6440 psi Stage 5: 360 bbls gelled diesel @ 19 - 20.5 BPM, 6440 - 5720 psi Stage 6: 30 bbls gelled diesel w/2# 20/40 sand @ 20.5 BPM, 5720 - 5660 psi Stage 7: 26 bbls gelled diesel w/3# 20/40 sand @ 20.5 BPM, 5660 - 5520 psi Stage 8: 30 bbls gelled diesel w/4# 20/40 carbolite @ 20.5 BPM, 5520 - 5910 psi Stage 9: 30 bbls gelled diesel w/5# 20/40 Carbolite @ 20 BPM, 5910 - 5960 psi Stage 10:31 bbls gelled diesel w/6# 20/40 carbolite @ 20 BPM, 5960 - 6020 psi Stage 11:15 bbls gelled diesel w/7# 20/40 carbolite @ 20 - 19 BPM, 6020 - 5900 psi Stage 12:23 bbls gelled diesel w/8# 20/40 carbolite @ 19 - 18 BPM, 5900 - 5650 psi Stage 13:43 bbls gelled diesel flush @ 18 BPM, 5650 - 6010 psi Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 857 bbls 1900# 100 mesh, 6300# 20/40 sand & 29,700# carbolite 806# 20/40 carbolite 5900 psi ' Drilling Supervisor ' Dat~ December 5, 1986 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-60089 Well: 3K-11 Field: Kuparuk North Slope, Alaska Survey Date: November 17, 1986 Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures NL Sperry. Sun/NL Industries, Inc. RO. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 VERTI (.'.:AL.. SEC'I"I ON CAL..CI...IL'i~'~'~'~i""'~'L. ONG CI_O ..":i;URE ...................................................................... ~ ......... ,...~.,,~..., ~ wa, k,- ~,. ~.:~:.~:....~. _ . _ _ TRLIE ;!i[~,.,~i?!i~:E~ COURSE I-:O! IR.C;E .... '-'~ -' -' F' ~., MEA._-, JRED VERT ]'...:.A.L ......... VERTIt]AL _~._N_L-.:.L_:_[ ~.~]~._I. @ ~ ....... DIRE_.TION [)E F"I'H I:IE F'T H I]EPTH I:l[_:. C~ I'-t I N SF:'EF~:F~:Y-'-SUtq WELl... SLIRVEYING C:OMF:'ANY A N iF.:: H 0 R A Ei E A l_ A S I.:.'.' A DATE OF' F;URVEY NOVEMBF.::F:~: ].'7, COMPUTATION ELATE BOSS IqYROSCOPIC SURVEY NOVEMBER I'P~ 1~86 dOB NUMBER AK-BO-6008'.:;' ........... KEI....I...Y BL.I'.3H i NG IEI...EV. =" 6'i:?. 0 F' El R A "1" 0 R- M C G t...I I R ......................... i .,.'. t i DOG'LEO ;,EVER I TY I]EG / 100 TOTAL. REU TANI3ULAlx COI]IRD I NATES () 1 O0 :20C.) 300 500 6C)() 700 1 C) 00 11 ()0 1:2 C) 0 1:300 1400 1£._o,O 1 ./:, 0 c~ 1700 (") ,, ()() -.6'?. (~iO 0 0 I',1 C.). () E C). OC) C). 0C) 1. oo. oo .... ~ 1 :"'66 ............................ 6 ........... -J:'~: ............. i:i""':,_::i'~."fif'~ ...................... 62:::~i .............................. '6'F~!-"i~i ................ 2c)(') O0 1:31 O0 0 16 "" :::0 0 W 0 1'-' .:::, (') '-', - c' .... ,, . . ._-, . .~. ~:tJ' ._, :"::OC.). ()0 2.'.:.: 1. O0 0 16 N :35.50 W O. 29 0. 14 S 3 ?,.:.?, ,:..?,.:.? .............. ::i'3i)-:"::-;;~ ................... 6 ...... !:i':F ........... ~i'"--::ii:i:';:::6'"ij ............... 6-:?? ............................. B::6-"'::i ............ I',1 2'?. :..3'i:~ W O, 1() 1.46 Iq I',1 1,'.':,.67 W 0.20 2.45 N N ?.'.::9 W 0.2:'? 3. 14 N 0 10 N 2. c.(.)'" E 0 lC) i:: ,:.:-'r, N 0 18 N :3. 0 W 0.12 3..95 N :1:3 Iq :32. 3(-) W O. 15 4. ::.4:F: hi :.-7: N 74.6,0 14 (). 16 4.58 N '7 :::; .1. '7. :30 W 0. 1 '.:/ 4.50 N '.-? L:; 44.17 E 0,15 4.2'F/ N 12 I',1 :.E:::.:,. :7::'.:.) E 0. 16 4.20 N 1.~ N 74 6? E O.P'-' ...... ,o 4.26 N 15 iq '78. :3'F,' E 0.0:3 4. :37 N 27 :::; 5'.:;'../:,0 E:: 0 · :31 4.21 Iq 1800 17':?'.-:.:'. '.:,',' 7 17:30. '.:.;' '7 1 · F' C) 50 2200 :2.--: :':': 00 · -: .J .-, 0 240 C) '.25C)C) 2600 270 0 0 :_::8 (') ~":' ~ %.. o~m C) 44 0 '-'¢~ 'c. 40.60 E 0'. 26 :3.5'.::::' N · o0 E 0.56 2 '-": · -, . ._, ~ N S 6.19 W 0.1."2 0.?.7 N · _,'=' 4 .10 E O. 31 0 · 38, N 0 1 ':? '::' 0 27 N 1 :31 N 234'.-?. 90 2280 · '.:'/C) 1 .~'--'._ ~ 2 :':: 9 9 8 6, 2.':: :':: (') ,_ 6 2 ........ :.24'.-? 9 76 -:, a .:,(-), -- · ~ ...... 76 .,,:: 45 2' F; 99., 4,1 :2--': 5 :.7: 0.6, :i. :]-: 28 N 26 '.:.?'.:.;'. 4 J 26:3 ('-) ,, 41 :3 4 5 Iq 44.3':? E 0.9I C).02 S ":":'. 10 E 0.61 O. 12 N 15. i0 E l. Ci'? :[.74 N N 12. lC) E 0.74 N 6. 19 E 1.20 N "~ ':'F, E .... ?~::::":!'!~':~ ~' 3.18 N 5.04 N 0. :.-:;,0 W 0.74 .1. 5.00 N O./.:,0 W O, .'.-]:7 '21. :':-::("~ I'q t. .. (). O. O. OC, ('). 16 W (-) ~'= (.'). c.,.-., W :[ "::'"", :1 ':'":" 2, ::.:.'::2 W 2.4.'::;' W - .']., I:." ."', '-.' F';:':: W .,:. ~ ..... .2'. '~::' C:,.._, ::2' ':::"::' .'i!:. O:]i: ?7 W /:,'? N .-:,c, F", ,:: .... N :?() I..d :2: .1. W .,~._, W ::!:7 W O. 11:':,!j ..... (..~ .... :' .," I- " ,2," ', ' ! i. 1. 1 7 t:i:. 1,4&, .1.. :3.1. [:il I.. 9 .l. i - J. :!:::,':, · i' ARC:O AL.A._-,I..,A.., I NC, 3K-. 1 1 ( '?' ...... "~"' ".: .. E ) · ::,EL..:,._, "r 13N R()'~" · "1 I-'"" ' I" I':, _ F ~RI.. I':.. :i::;f:'ERf:;:Y-S-.;I...IN NEI...L SI_IFi'VEY I NG L.L MF ('II',ICHORA C'iE'-. ALASI<A COMPLITATION [)ATE NOVEMBER 1S/, 1 '~'' ..-]:~6 DATE OF SURVEY NOVEMBER !.:.. YRO.=,UL F I C .=, .. RVE. BOSS ] "~' ...... ;" ,'"-il "' "" B U -- (:, (.) (),::, :: ,.lOB NUMBER A L. A :F; K A KEL..I....¥' BL.ISFIING E:I...EV,. : .... 0 P E R A T 0 R- I'1C G I...t I F;,' E DOG-I_EC'i ]"C~TAI_ SEVER I TY RECTANGLIL. AR COORD I NATES VE F:;,"!' V E R '1' I C A I .... MEASI...IRED DEF'T'H :!'.'; F.'i: C 'T I I:) I':1 C A L... E: I...I I... A'T E D "'A [._ 0 N G C I_ 0 :F_'; I...i R E ~UB-.~EA L. LILIF~.:.~ E COLIRSE T'RII-'_E ~:" ........ "-' VERT I C:AL VERT I CAL I NCI_ I NAT I ON D I RECT I ON DE'F:'T'H D E P 1" FI Ii Ii.:. G M I hi 0 E (:ii R [.-.'-. E' S [:1 E: (3 / ]. () C) N iD R T H / .S I..-.I I...I T H [i:' A '.S "I"/W [!i: :i.-'.; T' :2:047.8(:3 :3 Ci'P 6, &'P :3 :[ 4. 5. :1. '7 :3 C3'76..1. '7 .1. 5 () :31 'F' :3.2 4 :312,-!.. 2 4 16 '.5:2: :3 '24 (). 81 :}.': 171 . 81 1,_,':' ""-_,.. '=, :3 2 8 7.9 6 :3:218. 'i.:~ 6 :;;it 0 0 :_3:3:3 4 8 4 :':: 2.:: /-, 5 c, :'t. 2(:3 4 ] ':!:: :3 C.: l, 4 ::ii: :'3:3 :[ 2, 4. :3 2 l- 5'2 3 .':t. ::.i: '7. , ,'"-, .......... ::::: :'::: :2: % :::: ,,/-_, ,_':", .,.-.."':' .,:..":' 4 ::3 :34 '7 :.3. :39' :2:404. ::ii:'ii;' 24 5 '7 :::.'=; 18 4:2: ':: 44 ':/ 4:3 26 ...:, c, ..... ii ',, ,- I . ,g,. :3562, 78 :':: 49:3, 78 :28 :'30 · "'._-, ,.:, ' c). 6 .28 ..:'"' .... .=, '-'.:, 7 ,28 3 () . .:,'-' z.'-' :364 :.:::. '::~.......':: .... ..:,"=._, 7 ?' 9. ~_9 ::3-/3 J. ~ :}:: ? :36,'_'- 2. :'3'P :.7-.: 7'71,4:1 ::,:.: 702.41 2'73C).' 1 1 .1. 9 N :3:3. () W 2. :31 2.5.4'? hi :2 ::: :'-: () . :~!~- .................... 4 ........... ¢, ....... ,s ~;'i ~' SO w ;~":':~.i'i~i ............................ ::.~:':-'j:"~"-'"~ ................ 'F":.)".:":'/ ~4 ':' 4'F~ S 4° 69 W 4 '73 16:34 N 2978,8C3 .1. (:3 52 '.S 42. (:3 W 4.14 10.C)6 hi S :21. :5<:) W 4..% 1 :iii:. 0'7 4 ,, 4. 2 :2C). 05 4.1" ..::._:,. 7'7 5. 19 49.09 1. 'P 1 65.58 4. O'P :32.6, :3 :3. 18 .1. C)(). () ] 4. :3'7 :11:3. :3:::: 3.21 138. 14 :'S 4.44 159.46 S 4.11 1 :"-' c; ~z., 42 ._ ":'":' 2:3 b; :Z:2 1 (') W ::: 87 '2(')/-, 6'P .::,'-' · .., .4. · . · . - -- · :_36 27 .... '.'.-'.'; 22, ::-::'.4~ W 4 . C)'P 2":'""._, c,. '-:>0. :::; . :.3 7 1:3 ':' ':: 9 W 1 /_-,:.3 '--"':'/- ~/- :.'-.-; ._! -... i .1... i..l _, · ...._l ..... :28 () 2'.:.)00 :300C) .3C~5() ::ii: 2 () 0 :}::25C) 3:30C) :3:35C) 34()() :3450 :3 500 :355C) 3600 :}::650 :3700 :3800 3850 :?00 4000 3889.85 410 C) 396'P. (:34 4 ~00 4. 04:-h: 66 4 :_300 4128.5 ::-.': 4400 42C)8.5'? 46(.'30 4367.71 4700 4447.23 4 '.::)00 S,- ..- .'-"-' F:_ c). W 1 .46 314 .77 '-' '":'"':' 0 W 0 lC'./ 371 77 ~* *'4:.,. . · · S '21.69 W 0.77 428.44 21, 0 W (':3.4:3 484.8(:3 . 2: 0, 6'F/ W ('-) 48 541. (:32: 1 ?. 6(:3 W 0.67 5'? 7. :2:0 .... 2C). 69 W O, 83 65:::, 'F~7 20.6(:3 W 0 · 08 71 (:3.8::-: ; ......... :..-i~ L:::~ .;; ': 20.5(:) W ::::::::::::::::::::: 767.62 - 2 C)./.,_ 9. W (')_. 48 8:24 . ._, ='.._, ~'- ............. .1. 8.80 W I · :37 8 Fi: :1.. 5 ? .............. A ~: l-: l-i 1 - A 'L Al'..~i i:i' ~i-~ ]' Nl-}. :3 K- i i ( '-' ~- c'-':: = · =,c_ .... : ._, 1' 1:3N RO?E > I<LIF'ARLIK .............................................. Al._ AS1.::;A :i.:.';I.:'IEF;,'F;;Y- :::;L.IN WE.:I....L. :-:;I...IF;,'VEY I NG COMPANY A hi C 1-417.1R A f.? E{ A L. A L:; K A COMPUTATION DATE; NOVEMBER 19, !'-'-' DATE OF .:,LRVEY NOVEMBER 17, BOSS GYROSCOPIC SURVEY dOB NUMBER. F~.K-'BO-6Q.Q8'!i~ KELL. Y BUSHII',IG EL.EV, :,:," ,S 9 ,, ,./, ,'/, ¢:"I :. OF'ERATI3R-MCGLI I RE; VEF?'TICAI .... :!.:.:EF';'T'ION CAI....CUi._ATED ALONG E:I...O'.-7;LIF::E ... ,~ .... . . .~: .... ::~.. IR _IE SUB~:~EA F-:I'3LIRSF: C:OLIRSE flOR-LEG TOTAL MEAg;I IRED VERTICAL. VERTICAL I NC[_ I NA'T I ON DIRE... TION u, EVER I TY RECTANGULAR COORD ! NATE;Ej DEPTFI DE:PTFI DEF'TH I) E(3 M I N [)Et'.~F,'EiES DEG/100 IqORTH / SOUTFI E'.A'.E;T / WE]:3 T 5 () 0 C) 51 C)0 5:20C~ 5:3C)0 '::" 4. 0 0 5700 58C) C) <':,OC.)C) 61 C)O 620 .. /_-, 400 6500 6 `5, () 0 6, 7 c)() 68c)0 '=/'-'-' '- ' 7.'s:4 78 W 5 /. -.':: -':,o ,-. ~ S 747.87 1,4 · _ 70 ..... 1._,"'- F,/-,9/-, .... . 1 ._."-'i ...,,_, F,(') .......:, 21. :':-:(") W 0 .38 17._ 6 .79 %'"' '-' .i:"'i- '-" "4 '= ..... · _ 77.z .... 4 4 () /:,, 24 .50 o ::'_: 9 ..... :,4 ..'. 34 :3 , . W .,=., _. 1815 , .:.": 1 ._, 7 ? :..:' ,/-._ 1 W ............................................................... 1:2' ,"'. · · ..... ll · .~l · ..... /18:32 5849 82 4(:) 7 S 7-::3 :::(") !.4 C) 4._ 1874 10 :-3 75:'8 'i:.,'7 W ':::: ") ':"'-- 41 59?/-. 4.1 ':."T., 5:.'-.': ...... :..:.:.'?4 5 '1. t,.J ., .-:-. ................... ~---; :,;5::3. 0 W O, 56 19:::":-:. 11 :.-5-_; . ............................... /-,._ C) 72 . (') 4 /-, ...... A c)::: .04 4 (3. .._,":' ._.':' 22 · `5, 9 W C) · 24 1 '-"','.. ,--/...,_'s.' · 32 S 849. .4- ,:!:,t,..I.. .... 70(:)0 6226, 53 7100 6304.29 '7:300 6,46,(_'). ,5.,8 740(_-) 65:39. 11 /-,079_. . ,.98 39 21 S ~°1,60 W 0,99.. 2051·47 S 87:]-:.F~4... W 6157 53 38 5 · O. :::':;'/-, `5,8 W ~6 S 21.3~ W 43 2110 21 '"' / .-,---,~ ...... , -) .~,.~ ..... '-",-'-:,._. '/Y 38 5.9 .'-: .,:.(. W 2168 ' = · ,:, FY 0 · 6,3 . P.-, .S '"':; 1 '--; 11 W ....... 6,:'::1:'::...:,.-- :3:.--_:..-... :.:.'; 19 :=:9 W (') ,5,5 2227 66 '.E; 'P,'-TC) ;;.-:.'.!5 W ................................... ........ 6,:2:':.) 1.6,:_--: :3::: 2:_:: S 19. :::.9 W O. C).3 2;.--.-::--:6,. (:)7 S 5:',:':, .I. ::7i:0 (..~ ......................... .... _ ._ 7 2:3 4 4 5,'!, ,/_-,47('). I 1 :3:-_:: 18 :-5-_; 19. 0 W 0..=i- . 76,0(.') 6696.15 7700 /_-,774.9:3 *'-:, ,-', .LZ.'~ --', .-' ,' ', ,', '"" /.~ / '~'-....Z) (7' .'7. 5"-..! ~ '_, .. 6548 60 38 17 :E; 18.8.9 W 0 06 '-"-',':0':' c- · . ,,:. .....18 lO02 · .-, 1,0 /./-,..>7 1.5 '-"~' 1 C) S 17.89 W i'FJ'.l~l 6:3 ..--46 1 '-";' oo '":'- - ,:,.~S 1(')'2'2 1 :;2 b.i ...1~ .,&...#,~ ........ · . . . · . ' % ¢,'"' ':' 7 .=, ''" '-' %'-' C). ............ ,"_-,'7:.-.:.:4, :36 :_::'7 52 S 1:3. 1'..7; W C). C)C) '257F.:, 75'; :E; 1 {'J)d:, (;;}] ................... ........ ,, ....... ...I a::. . .. · ........ · ..... ~ . · ........... SF:'EF:~F:~Y-SL.IN WEI....I._ SURVEYINL'.~ COMF'ANY (:;~ I',1 C: F-.I 0 R (:.~ GEi: A L. ('~ S I-::: ,% i-o. ? 31-:::- :1. 1 ( .:,E .... :,.::, T 1 3N ROgE ) COMF'UT~T Z ON DCFf'E '"11-' ' " I- ' 19 ~ .... F ¢tRLII.:.. N dVEHBER , ! ............................................................... .-.., .. ............................... DATE OF SURVI.EY NOVEMBER JOB NUMBER AI.:::--BO-./-.,OC~t3'!.;/ i.:.'.'EI....L.Y BUSH I NC:i EI.._E:',/'. 0 I=' E R (::~ T 0 R -'-.' PI C: G I...I ]] I:;,' IRLE H [.=. ~'*":i :i.:.';'l_! R lei; Kf V [.;: R'T']: E: ~:.'~ L_ I] Ei; F::' T' H D IF:: F:' 'T' H SUB-SEA TOTAL V E R 'f' Z C: A I._ R I.=: C: "1' ~'~ N G l.J I.... [:;.'J R i_-.: t:"~ 0 R D I N ~::.~ T E S Pi D- "f V D V .F.!: IR 'T' :[ C: ~ I .... [)EF'TH Nt':fR'I'H / S.:Cd...ITH E:~:~S;T / WE'.F;-F Ii I FF'ERENC:E". CORF;,'E C:T I ON 0 C). O0 100C) 999.98 2(30 0 1999.9 5 :2:0 0 0 :2 9'P 8.5 4 4. 0 0 0 "::::::::::', 9 '""':= · . ....... ,. ,:::, ....s 5000 4 ./.':, :35.8 <.":, 6000 5455.6,4 700(") ~ '-"-' '=;':' .. -,, x..d.~, ,, ._ ._~ 7:35:3 68':':~5.69 :: ::'?':':.'::?:' ARCO AI_ASKA, INC. *-$ ..' ,"'. .... ..-i I~." .-~ ..:, I':.. - 11 ( .:, E- L.._-,..., T J ..:, N R 0'~ E ) A L. A Si; K A SF:'EF?I::(Y--.SLIN NEI_I... SIJRVEYING COMF'ANY A 1_}12::: H I LF.~A ~__::~ E_.:_.. [7~i...__(.y_'_4 I<. A_. D~TE OF .:,LRUEY NOVEHBER COMPL.ITATION D~TE q "-' _'F/, 986 : ,...lOB N!.JMBER A1<-80'6C)C)::::'?~ NL VEMBER 1 1 ......... I-::.'E:.' L L. Y B L.IS I-..I I N G EL. E V ,, :-:: 0 F' [.:.: R A "r cJ R - M C l'.'ii I...I ]: R ~.ED VAI...LE.:, FUR E_VE, N i(.)U FE-E1 UF .:,LIB-.:,EA DEFTH j.:. ::,.i!ii.i:~: ..... TOTAL NORTH / SC)L.I'T'H L:': A ..:.'; ]' / NE S T r) :1' FF'£R£NCE CORRF..~C'r' I ON .... TRUE M F: A ti_:; I...i R I~'-.': ][:l L/E::. I..t I 1 I:.'.: A I .... I)E F' T H I'.::~E I::' ]" H SUB=SEA VERT l CAt.._ DE:'F' TH 0. C)0 /_'-, ?. 00 I. 6'!?. 00 2 ,S'.:.:'. ()':.:) :i:', 6'!? ,, ()0 4 ,::,":.: ,, ()() 56'?. 00 66'.-7~. C)C) '76'? ,, 0 C) ;~:~,i,':::' ,, 'i;,' (!:,'.::;'. 00 .1. 06'.:.;'. 00 1169/. 00 J '.:-'6'.~. 00 :1 :B6':7~. 0C) J 5 (':,'!?. 00 1.66'.->. 0 () 0. ()C) 0.05 S 0. C)6 W 0.0C) (). C)0 100.C) 0 C).26 S 0.41 W 0.00 0.00 2()C). 0() O. 25 '.:i; (). 8:B W 0. ()0 (),, ()C, 30,.'") ~")(") ,.'") 2:::if N t 1. '::"' W ;'~ 0C) C) (')(") 4.0C:. C)0 :1.. 14 N :l.. ,:..~,'F~ W (), ()1 0 ,, 01 5 C) 0.00 :2. 16 N 2 ,, :2::ii: W 0.02 0. C) 1 /-,0(") ()0 2 c)':~ N '-:' 4- 7 W 0.02 0 (") -- .- .. ,~ i= · ,- .~... .. . n .... '7 (-)0 o o 3 43 N ':-' =''-' W C) · () 2 0.0 () .. _ . . . ,. .0,..._1 ..', ................................. 8 ()(). OC) 3. '7::: N 2.52 W (). ()2 (). ()0 'i;'oo (")<") 4 27 N '":' '='"> . _ ................ , :: W ("). (')2 C). C, 0 (')00. ,:'_')C) 4.56 N 2.8C) W (). C)2 (). (..~0 iC)0.0C, ........ 4'"57 N ........... :~'"'0'i"~ ........................ ~'('~;~ .................................... (]" Oo ' . . . 2(')C). 00 4 '"/ .:, :, N 3. ')'-' . . . - . ~o W (').02 0 (')0 :B00.00 4.20 N 2.8C) W 0.02 0. C) 0 40o. N ................................... ('3':"5Y5 ................... 5()0.00 4.:B4 N i.';~8 W 0.0:B ().C)0 ..... ,SC)C). 0() 4.33 N J. 51 W 0.03 (),, ()() 0 ':'"' W O. 03 (') 0(') 0(') 17(')0.00 ':' '-' = - . ._,. ,:,._1 N 1 '7 :, 1 ';):i:i:,',!:,. 3K- 1 1 (SEC:E:5 T 13N RC)gE) KLIPARUK '.3F'Ef:;tRY-.-.SL.IN WEL..L. Sl_IRVEV I NC.:i C.:OMPF,1NV A N C H O R A (3 El A t.. h :.'.5; K A COMPLITATION DATE NOVEMBER 1 'P, 1""-' ~Yo6 DATE OF SURVEY NOVEHBER 1 7, :t. 9::_:it,':.::, dOB NUMBER AI':..-BU-60¢o.:, i-:.'.'EI...LY BI...IE:~H I NG EI....EilV, :=. (59 .. ,'?r":, !:: i., O F'E R A. T O R-' M C: G I..I I F:: E M E" A '.:~: !..I R E D I]EF'TH "I'RI_IE ' '"l "-' :=, UB-~:,EA TOTAL I]E F:'-I"H I]EF'T'H I',IORT'H / E;CH_IT'H EAST / WE:.ST' I] I FFERENCE C:OF;tREC'F I ON 1 :s:/:, 9 18 t'..,9.0 0 19 6 9 1 9 6 9. ()0 :2 0 6'? 2 0 6 9.0 0 :216. 9 :2 J. ,"-, 9. c)O 2:2: 6'il;' 2 2 4:.'P. () () 2:3 6'P '2:3 ,:':. 5;'. ()0 ::.-it 4 6 9 2 4 6 9.0 0 :2' 5 6 '.:..~ 2 5 6 9.0 0 :2 6 6 9 :2.: 6, 6 9.0 0 2 7,./:, 9 :2:7 6'P. 0 C, :2 8 6 'i;;' :2 8 6 9. () C) :'2:9 7 () ':ii:'.:.z 6, 9. ()0 :L:; 0 '71 :3 0 6 9. ()0 ':' 17 4 :31 A 9 0 0 · ..! .... :3 2 '7'? 3 2 6 '.:.'~. () 0 :'::: :':: F.':/4 :2::'3 6 '.::? · (.~ 0 :34'i:,' 5 :3 4-6'ii>, 0 () - - .", 3 7 2:2: ::-: 6 6'F,. ;.} :3 K - 11 ( S E C :35 T 1 :':: N R C)':.? E ) KLIF'ARLIK A L. A S K A SF'ERRY..-:E;LIN WIF.]....L ,'"'1 I""' '","', .:, _. r~ v r... ~ I I',li".~ C 0 M P A N Y F:" F. i'i, i'. A N (": H 0 R A G E A L. A :::; K A ~. ! -.. . .... DATE OF o. LIRVEY NOVE-'MBER ].7., M E A '.E; Li F: E D I]E F:"I"H C. uMFLITAT I ON DATE NOVEMBER 1 · JOB NUMBER AK--BO-6008'{~ KEL. LY BI...I°..:.';H I NO EI...EV ,, :::" /",':? ,, ,".)':..~ F:.' i' i") F' E R a T 0 R - M C L'ii I_11 Fi/liii; I NTE~R~i~::~ED VAI._UIF'S FOR EVEN 100 FEET OF SUB-SEA DEPTH ]"RLIE ~1 ~B-'~E A TOTAL V E'I::;,' T I CA.I .... VERT I C:AI .... F:,'EC T'ANOIJI...AR [.-.:00RD I N A'I"I.-.-.'.'..:.} MD-"]'VD VER'I" I CAI... Df<I::)TH [)E P T H N 0 R'I'H / S L-.H_I T' H E (.i '..:.; 'T' / WEE'.-];]- I:.~ IF ....... F EREN, ~-".E.' C: 0 I'~ R Ei' r':'l'. ...... I AI',I :3:300, 0 C) :356 66 S I 7... 92 W 104:54 2/-,. :::i A 2, ...... ? C)(]. 0 C.) 428 .41 S 204 . '74 W 1 :'::(') '-.~J.. ''='., '.'.'/-, 4'1 ----'--.~- ~::t ::,. '~ . .' ~ 4C)C)() ~")(") 4'~".~ 2'2 :.:i; .,;:..:,,::.'"."'"" :32 W 1=''' :54 ':"F.'; '::',-, ,~ '-... . ~ .. I~, n ., . .... , .... ~, . I ':· 4:1. C.)0. ()C) · :,,':,'", ? ~!' 258 8:3 W .1. :31 .=i :'.:: . ':' .... 7 .-,.., S ....... 24 'i.:;',!3 42 C) O, ()() 640. 1:3 S 284 ,, 4 :.?: W 2()6. '72 :;;it!!il ,, 2 () .................................................. 4.:30(') ('~C) '711 '75 S :311 42 W '-"-"-' /- ":' '-' '= :::9 ' · " # - "" '"" J:~ n -',.~ d::...~' ~ - . 4 4 c). A.. 0 0 -/8:3 . i 1 S :3.'3:3 ,, 1 ..~-; W ...'-' ._, = ,:,'-', ..:,'-' 4 .,..'.--' ._'=~. 7 :Z-.': 4 ?,(')C)C)0 ,'-,= =- o, ,:,._,..,. 1 S :'~ A ?, ! 7 N '~'"-'-" /,:,4. t' .................. ,1 ',T:'6.1 A i. ,..t~'" 'i? :;::' /-, 24 S :3'.-.?0 45 I,$ :'::Ag, :::() "",= .... :,,:; --'-" · - ......... ~::. %.1 ~ ~;..... 4'70() ,, 0() '?'78, 45 '.!.::; 420.4./::, H :.:.::36, 76 ::!'~, ?,..!:, ZJ.~:O("} (-)(') ]('i'7:'-': '::).~- ,::' z:l.~;~ .::,cz I,I .':,/.z. ','--]c "::":) ;?,.7:, .. n . . ·., ,.' -. ~, . -. --,' i-../ ~ ..i . t,~ -. 'L."'_"~ ,~ , ............................................................................................ ' ........ ' ...... ::t. t7 ..................... "~'. ;: * 4.'~?¢)0. C.)O 115C). 42 S 4:--:8. 1 '.';' W :3'i~6.91 :30. :3:':: 50C)0.00 1226.78 S 57.-!('.). '..~'(') W 426.75 2'.-.?. :34 ... .. '-' ................. ,-','? ..... . . _. _ ............................ =... ...... 5!_~')~'J~ 0(:) . 1 .~.!~...~,. 44 '.E;'~: ..... :,~..(-'_'.Z..W ............... _47_'A_._4_C) ...... '2'-.?. 64 · 52C~0, 00 :1. :}.'::.:.i:C~. :32 S.i; 5:32.5:3 W 4::-:/:.,. 52 :3C). 12 -~ :'::,' (') (") (")(') 14 Fi'7 1 F.] S /-, 19 1 '::) W ?, 1 "z c,-:, :31 ,, 3 I ....... ,~ .... ... u ..... u .. ... · ~ ~...~ ...~ 6017 5469. () C) 540 ('). C) C) 1 :~:.'_::3 41 S /_- 54. '?'=' W =' "":'" · . - ,~ ..... ,4,:,, :'_::'.~ :30.56 1(:,0':/ 15 '-' =-..o - ' ........... .... :, 687. :31 W c, 7,;,. 25 :29. :36 AR_&J ALASKA · .:, {':.. "- 1 1 ( ._-. E L...:, ..., KUPARUK AL..fq.:,I.,.H I NC. 'T13N ROgE) L:i:F'[<IRI:;.IY---L:i;I_.IIq WE:.L.L. SURVEYING COMPANY ANCHORAGE AI._ASKA DATE] OF SURVEY NOVE]MBEF:,' COMPUTAT I ON DATE NOVEMBER 19, 1986 ,..lOB NUMBER AK-BO-6008':7.' K El... L Y BUSI-.i I N G E l_ E V. = 0 F:' Er R A T 0 R - M C: (3 L.I I Fi' I:..-..i I NTERROLA:TED VAL. L E.:, F'OR EVEN 100 FEE]' OF ._-,I..IB-,.EA DEFTH I ,:1! S.UB-:,EA ""F _E '"' '~ MEA'.BI...IF:;tI!ii;FI VEI..-;,"I' I CAI ....VERT I CAI .... D E F:' ]" Fi I] F.'i' F::' 'l" H I. E F 7 H TOTAl_ REC"FAIqt3LII.....AI::;t CCfOI:?I[] I NA'I'ES MD--T'VD VEF:;,"I" I .:.:Al .... NORTH / :.:.'; FII..I-I" HI!.:.':A Ei;]" / WE:ST' II I F:FE'ERE]VCE E:OI:~IR E'(:':T I I_') I\l 627 6 566'.-), 0 64. 04. 576'.:.;', O0 65:34 ='"" "" ..... :, 6 ::~. (-) 0 /.:, 665 5 ':.'.;' 6 '.:.:'. C.) 0 (': 7'i),"..:, 6069.0 () /-, 9.';:' f::; ,._/-, ]. / ':) () 0 ........ ,_., .. ~, .. . 7() 54 6269.00 '7.1. 82 /_..,:_::/z,'F~. C)0 7:2: .l 0 646'?. 00 6400.0 C) 74 :."-.'::'_-::/::,5/:,':".;'. 00 ' '65()Ci: ()0 ' I::." · 7..., (:: ...... 6, ,'.':, 69 ,, () 0 6600, 00 '76'.:.)2 6'76'F.>. 0C) /::,7C)0, 7:_:: 19 ./.-., 8/:,'F~. 00 ..... 6 ,:,':~" =0 C) ...... 00 '784 0 /- '-' '-":";. . :,,:,o._ 4:2: 6816 42: 0 :!-'.': 61 9.1. 77: 4 ,:!:, .- . 17.1 (~, 71 :3 '.-7; /:.1 47 ('::5', 70 :39 THE ('.:AI....CLII._A-I"I(]N F:'F:¢OCE. TDLIRE'.i'_:; I...I:~'.-;E A LINEAR I N'I'I.'.-'.':RF'OLATION BETWEEN THE: NEARE.':_:;-r 20 F:OOT MD (FROM RADIUS OF CURVATURE) F:'OINTS ] '7, .1. '.-::-':? &, ARCO ALA:F]KA, INC. 3K- 1 1 ( '-'~'F'''''~ ._-, = _..:,._, T 1:3 N R 0 ? E ) KLIPARUK AI._A:!:.;KA M E A S IJ R E D Et E F' 1" FI SF'E]:~RY-SLIN WEI...L SLIRVI:':'YING COMF'ANY DATE OF' SLIRVEY NOVEMBEF;: ~MFUTA]ION DATE NOVEMBER 19, 1986 17 :, i 'i ) F.:: ,:':, VALLIE..-., FUR oFEL. IAL .... URVEY FU]:NT._-, TRLIE SUB'~$EA .................. .T.C! T.~.L. ............................................................................................................................. ~,, ~:--. ~:~,..i..,.:.,., .,T ....... CAI... VERT I I.]: A i... F,' E C'I"A N G !..11.. A R F: Fu]IR I'i I NATES 'i ..,-g" - - - ]] E I:::' I" H EEF i H NL-.ll:;.']"H/'.::;f'il ITH E':A'.:3]"/WF.'].'.-".;T MARKER ........................... 7:382 7/:, :,:.i: 8 '7'70C~ -7 '7 ':] '-" ; . o......'.~ 6 4'!9 0 ,, 4 '7 /:,._, ~:- 4. ':.:' 9 66 :::.-: 6.4:3 4:, ''-' ' =' / (:,....~, Z[ ...., ,:?, 774. '? :3 ,:":,8:1. z-':,. 76 68':.'? 5.6 ... : 7,.-., 8:3 W BASE KLIF'ARLIK C 6 4.5 5. '-? 9 2:3 3 4.0 2 S ':,' '-'. . ,/.., .~'i /-, '7 . 4 :3 241 '7. "" "= ..... :,., S .1.(')(.')7, 40 W TOP I<I_IPARiJI-::: A ' ,::,/.:, ....... ::, ,~::,' ,,' 2'~'-;-1..:: ..................... ::!;'~'--:F"'-:~;.,: ..... 1 ..... ............ 4_g ..... ;!:' .....:1 ............... ("" :'-:J ":; '" '~:;(':) ............................... W BA...,E:':--"7:'":--F":Fi~:7:-""::i~ .... I AR _i't-..::' ...... ,--,;°' ............. 6705,, '?3 2520,46 S 1..04:1. ,20 W SLIRVE.:Y DEI::'Tt.i 6'747, 7/.-., 255.i.. :3:3 S 105:i.. :..:.:7 W F:'[.IJf.~BACK TD ................................................ 6826,6'.9 ............ 2607.71 S 1070.54 1,4 I'OTAI_ DEPTH DRII_I...ER 3K-1 I ( '-"-"-"-~:' ":' ' '~ · .-.,,==,. ....... , T 1 .:,N RO ~E ) :3TRAT I GRAPH I C oLIMMARY I]E~IVEn LJSING [}IL DEPTHS ~ND ..FER~¥ ._-,1_t~ c,_IRVEY DATA T 01'-" K UI:' ARUI< C '" BAL:.:E I-::]I. Ji;;>AF-';fI...II-::J C.': T()F-' I.::]1...11::'~;.'.',1::;:1..11-;;] A F'I... I..I G D A f_] K "!" El TO T Al... I) E F"T H DR I L.. I._ E R 1) FROM L. INEAR EXI'RAPCd_..AT];ON BELC'W r'~EEPE.S]' F;I"AI-IC. dq. 2') .... iE!O'I;IF"i-i'TE~ F'ROc~:AM -2--i~:i~:i~i~:~'~-'-'.---~lji,~i- THREE'. D ! MENS [,_-,NAL RAD l LiS OF CURVATURE. DATA F:ALr-:LIL. AT1'0N AND INTERF'OLAT!FeN BY RAD!US OF CURVATURE F:CiMF'I.JTATIC, N DATE NOVEMBER 19, 1986 DATE OF :..:;LIRVEY NOVE;MBE.'F~ ,_lOB NLIPIBER AK-BO-60089 KELLY BUSHING ELEV. 17: l'P:3d, 69. O0 FT. ? i 'I I / '785~ -... ~7853 i ARCO Alaska, Inc. Post Office Bo,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 22, 1987 Transmittal # 5893 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Finals: (1 blueline unless otherwise specified) 3K-12 2" & 5" FDC Raw 11-11-86 7100-7741 2" & 5" FDC Porosity 11-11-86 7100-7741 2" & 5" DIL 11-11-86 3980-7767 Cyberlook 11-11-86 7150-7720 2" & 5" FDC Porosity 11-4-86 7000-7782 3K-11 2" & 5" FDC Raw 11-4-86 7000-7782 2" & 5" DIL 11-4-86 1000-7808 Cyberlook 11-4-86 7000-7750 · 3Q-16 2" & 5" FDC Raw 11-18-86 5900-Y226 2" & 5" FDC Porosity 11-18-86 5900-7226 2" & 5" DIL 11-18-86 3931-7252 Cyberlook 11-18-86 6030-7100 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Date: Rathmell D & M ~ L. Johnston (vendor Pkg). vault (~f i lin) ARCO Alaska, Inc. is a Subsidiary of AtlantlcRichfieldCornpan¥ ARCO Alaska, Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE January 2, 1987 TRANSMITTAL # 5869 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ..,. 3K-11 3K-8 3K-10 CBL 11-16-86 5547-7730 CBL 11-17-86 5115-7674 Pulse Echo Log 11-16-86 7002-8381 CBL 11-16-86 5502-7173 Receipt Acknowledged: DISTRIBUTION: Chevron (+ sap) Vault (film) NSK Drilling State of AtaSka (+ sep) BPAE Mobil (+ sep) SAPC (+ sep) Unocal (+ sep) L. Johnston ARCO Alaska. Inc. ia, a Subs;diary of AtlanticRichfieldCom~any --~ -~~-- STATE Of ALASKA ~ ALASKA . AND GAS CONSERVATION COMMIt )N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging Alter Casing [] Other [~ CClViPLETE Perforate Z Pull tubing 2. Name of Operator ARCO Alaska. Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510 4. Location of well at surface 1135' FSL, 316' FWL, Sec.35, T13N, RgE, UM At top of productive interval 1173' FNL, 1177' FEL, Sec. 2, T12N, R9E, LH At effective depth 1416' FNL, 1258' FEL, Sec. 2, T12N, R9E, UM At total depth 1475' FNL, 1278' FEL, Sec. 2, T12N, R9E, LH 5. Datum elevation (DF or KB) RKB 69' 6. Unit or Property name Kuparuk River Unit Feet 7. Well number 3K-Il 8. Approval number 9. APl number 50-- 029-21§54 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: 7853 'i VD 6896'TVD measured 7753'1vD true vertical 6817'TVD feet feet feet feet Plugs (measured) None Junk (measured) None Casing Length Size Conductor 80' 16" Surface 3860' 9-5/8" Production 7803' 7" Cemented Measured depth 1540# Poleset 1lO'MD 970 sx AS IV & 3895 '~ 320 sx Class G 300 sx Class G & 7838'~ 175 sx AS I True Vertical depth 110'TVD 3807 'TVD 6884'1VD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 7478' Packers and SSSV (type and measured depth) HRP pkr @ 7452' & TRDP-1A-SSA SSSV @ 1805' 12. Stimulation or cement squeeze summary I nterN~/~s treated (measured) Treatment description including volumes used and final pressbre 13. 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 14. Attachments (Ccmpletion Well History w/Addendum, dated 11/19/86) Daily Report of Well Operations _~ Copies of Logs and Surveys Run X Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~/o~ O-~'~'-"OO,,~' Signed &~Q"~/)~ ~~ Title Agc, f.lri,3t, p Frlg'ip¢~:~' Date /~-/'7-~ Form 10-404 Rev. 12-1-85 ~/ (D~) Sk0/139 Submit in Duplicate ARCO Oil and Gas Company Daily Well .istory-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 p~ovided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code State Alaska Well no. 3K-11 District County or Parish Alaska Lease North Slope Borough Field or Unit Kuparuk River ADL 25629 Auth. or W.O. no. T t e AFE AK1436 Completion Nordic 1 AP1 50-029-21654 Operator I A.R.Co. W.I. ARCO Alaska, Inc. J 56.24% Spudded or W.O. begun J Date Complete J 12/3/86 Date and depth as of 8:00 a.m. Complete record for each day reported I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our IPrior status if a W.O, 2245 hrs. 12/04/86 12/05/86 7" @ 7838' 7753' PBTD, Rn'g 2-7/8" CA 10.2 ppg NaC1/NaBr Accept rig @ 2245 hfs, 12/3/86. begin rn'g 2-7/8" CA. 1615 hrs. ND tree, NU & tst BOPE. RU & 7" @ 7838' 7753' PBTD, RR 6.8 ppg Diesel Rn 226 jts, 2-7/8", 6.5# J-55 EUE 8RD AB-Mod tbg w/SSSV @ 1805', HRP Pkr @ 7452', TT @ 7478'. Tst pkr & ann to 2500 psi; OK. Tst SSSV; OK. ND BOPE, NU & tst tree. Displ well w/diesel. RR @ 1615 hfs, 12/4/86. Old TD New TD PB Depth 7753' PBTD Released rig Date Kind of rig 12/4/86 Rotary Classifications (oil, gas, etc.) Oil Flowing Producing method Potential test data Type completion (single, dual, etc.) Single JOfficial reservoir name(s) J Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity MIowable Effective date corrected The above is correct Signature,""), J,/"'~ J Date I ITM .... Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ADDENDUM WELL: 3K-11 Rn CBL/GR/CCL f/7730'-5547'. Rn gyro f/surf to 7700'. Rn gyro f/surf to 7700'. Make GR/JB rn to 7735' WLM. Drilling supervisor DAte .... ~' STATE OF ALASKA ALASK,..~IL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown .~ Re-enter suspended well ~ Alter casing ~ Time extension ~ Change approved program ~ Plugging ~ Stimulate ~ Pull tubing .._ Amend order- Perforate-' Other 2. Name of Operator ARCO Alaska, Inc. 3. Address p, o, BoM 100360 An~-hnrage.. AK 99c, 1cJ-riRc. n 4. Location of well at surface 1135' FSL, 316' FWL, Sec. 35, T13N, R9E, UM 5. Datum elevation (DF or KB) 69 ' RKB 6. Unit or Property name I(~n~r~,[~ River IIn'J'k 7. Well number 3K-11 feet At top of productive interval 1133' FNL, 1236' FEL, Sec. At effective depth 1414' FNL, 1312' FEL, Sec. At total depth 1472' FNL, 809' FEL, Sec. 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 2, T12N, R9E, UM(Approx) 2, T12N, R9E, UM(Approx) 2, T12N, R9E, UM(Approx) 8. Permit number 86-164 9. APl number 50-- 029-21654 10. Pool Kuparuk River 0il Pool 7853 'MD feet 6887 ' TVD feet 7753 'MD feet 6809 ' TVD feet . . Plugs (measured) None Junk (measured) None Casing Length Size Conductor 80 ' 16" Surface 3860 ' 9-5/8" Producti on 7803 ' 7" Cemented 1540# Poleset 970 sx AS IV & 320 sx Class G 300 sx C1 ass G Measured depth 110'MD 3895'MD 7838'MD ~ue Vertical depth 110'TVD 3808'TVD 6876'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None RECEIVED ii! -8 1986 Alaska Oil & Gas Cons. Commission Anchorage 12.Attachments Well Hi story Description summary of proposal Detailed operations program BOP sketch 13. Estimated date for commencing operation November ~ 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed & ~,),~ ~~l,f./L,, Title Associate Engineer Date (DAM) SA/160 Commission Use Only Conditions of approval Notify commission so representative may witness ~ Plug integrity ~ BOP Test ~ Location clearance Commissioner IApproval No. A~/~---- by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O, no. AFE AK1436 ICounty, parish or borough North Slope Borough Lease or Unit ADL 25629 Title Drill lState Alaska IWell no, 3K-11 Doyon 9 AP1 50-029-21654 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date 10/30/86 IHOur Date and- depth' as of 8:00 a.m. 10/31/86. 11/01/86 thru 11/03/86 Complete record for each day reported IARCO W.I. Prior status if a W.O. 1700 hrs. 16" @ 110' 2204', (2089'), Drlg Wt. 9.0, PV 13, YP 17, PH 9.0, Wig 14, Sol 6 Accept rig @ 1430 hfs, 10/30/86. NU diverter sys. 1700 hfs, 10/30/86. Drl 12¼" hole to 2204'. Spud well @ 9-5/8" @ 3895' 5824', (1909'), Drlg Wt. 8.9, PV 4, YP 2, PH 9.0, WL 11.6, Sol 4 Drl & surv 12¼" hole to 3915', short trip, TOH. RU & rn 92 jts, 9-5/8", 36#, J-55 BTC csg w/FS @ 3895', FC @ 3810'. Cmt w/970 sx AS IV & 320 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmp, bump plug. ND diverter. NU & tst BOPE. TlR, tst csg to 2000 psi. DO cmt & flt equip + 10' new hole. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 56.24% 11/04/86 5824'. 1492', 0.4°, Nll.7E, 1491.97 TVD, - 3.79 VS, 6.51N, 5.22W 2490', 2.6°, N15.SW, 2489.70 TVD, + 0.07 VS, 8.97N, 20.06W 2898', 4.0°, S51.4W, 2896.91TVD, - 11.39 VS, 26.20N, 30.36W 3270', 19.4°, S24.8W, 3259.62 TVD, 64.11VS, 35.98S, 76.16W 3860', 37.4°, S22.4W, 3780.30 TVD, 335.42 VS, 284.17S, 185.75W 4180', 37.3°, S20.6W, 4034.68 TVD, 529.32 VS, 464.79S, 256.90W 4777', 37.8°, S21.3W, 4508.28 TVD, 892.26 VS, 803.67S, 388.33W 5559', 39.6°, S21.4W, 5113.29 TVD, 1387.44 VS, 1259.70S, 581.62W 9-5/8" @ 3895' 7813' TD, (1989'), Short trip 11/05/86 Wt. 10.0, PV 15, YP 4, PH 9.0, WL 4.2, Sol 10 Drl & surv to 7813', 24 std short trip, POH f/logs. 5845', 40.6°, S25.3W, 5332.06 TVD, 1571.60 VS, 1428.80S,. 654.62W 6222', 39.3°, S22.2W, 5621.06 TVD, 1813.63 VS, 1650.35S, 752.10W 6727', 40.0°, S23.7W, 6009.89 TVD, 2135.78 VS, 1947.08S, 877.75W 7290', 38.5°, S20.1W, 6445.87 TVD, 2491.67 VS, 2277.60S, 1010.62W 9-5/8" @ 3895' 7853', (40'), POOH, LD DP Wt. 10.1, PV 18, YP 8, PH 9.5, WL 4.4, Sol 11 Short trip, circ hole cln, TOH, LD DP. RU Schl, rn DIL/SP/SFL/CAL f/7816'-3804', FDC/CNL f/7816'-7000' & GR f/7818'-1000', RD Schl. TIH, drl f/7813'-7853', circ, POOH, LD DP. 7813', 38.1°, SlS.1W, 6856.31TVD, 2814.49 VS, 2583.90S, 1116.67 RECEIVED The ~e ia correct For form preparatjefJ~d distribution . dlst_rtbuti_on see Procedures Nr~iual, Section 10, Date ] Title I Drilling, Pages 86 and 87. Aiaok: Oil & Gas Cons. Commission Drilling Supervia~h0ra0e 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 ere 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 "Finsl Report" form may be used for reporting the entire operation if space is available. ICounty or Parish Lease or Unit Title District Alaska Field Kuparuk River Auth, or W.O. no. AFE AK1436 Doyon 9 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 11/06/86 North Slope Borough IA.R,Co. Date Complete record for each day reported Accounting cost center code State Alaska ADL 25629 Drill IWell no. 3K-11 AP1 50-029-21654 W.I. rTotal number of wells (active or inactive) on this i Icost center prior to plugging and I 56.24% labandonment of this well i ]Hour J Prlor status if a W,O, 10/30/86 ! 1700 hrs. I 7" @ 7838' 7853' TD, 7753' PBTD, RR 10.2 ppg NaC1 POH, LD DP. RU & rn 187 its, 7", 26#, J-55 BTC csg w/FC @ 7752', FS @ 7838'. Cmt w/100 sx 50/50 Pozz w/4% D-20, 5% D-65, 2% D-46 & 200 sx C1 "G" w/.9% D-127, 3% D-13, 3% KC1 & .2% D-46.ND BOPE, NU & tst tree to 3000 psi. RR @ 2230 hfs, 11/5/86. , . r · RrucEIVr:b ,Alaska Oil & (}as Cons, Comrflission Anchorage PB Depth Kind of rig 11/5/86 Rotary Flowing Old TD New TD 7853' TD 7753' PBTD Released rig Date 2230 hrs. Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Oil I Single I Official reservoir name(s) I Kuparuk Sands Producing method Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected Th,~ve is correct see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Alaska, Inc Post Office 3ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 17, 1986 Transmittal #5830 RETURN TO' ARCO ALASKA, INC. ATTN' Kuparuk Records Clerk AT0-1119 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. 3K-11 OH LIS Tape & Listing 11-4-86 #72038 Receipt Acknowledged' Date' Distribution' State of Alaska D. Wetherell ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany September 24, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy.- (907) 276-7542 Re: Kuparuk River Unit 3K-11 ARCO Alaska, Inc. Permit No. 86-164 Sur. Loc. l135'FSL, 316'FWL, Sec. 35, T13N, R9E, UM. Btmhole Loc. 1484'FNL, 1394'FEL, Sec. 2, T12N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site.. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. tru. l~y~ypD~r~, C. V. Chatterton . Chairman of Alaska Oil and Gas Conservation Commission BY O~ER OF ~E COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA _,IL AND GAS CONSERVATION CUMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill '~ Redrill ~1 ~b. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone ,l~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ~,RCO Alaska, Inc. RKB 69' , PAD 35' feet <uparuk River Field 3. Address 6. Property Designation 4uparuk River Oi 1 Pool =.0. Box 100360 Anchorage, AK 99510 ADL 25629 ALK 2562 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 135'FSL, 316'FWL, 5ec.35, T13N, R~E, UN Kuparuk River Unit ~tatewide At top of productive interval 8. Well nu .tuber Number I133'FNL, 1236'FEL, Sec.2, T12N, R~E, UM 3K-11 ¢8088-26-27 At total depth 9. Approximate spud date Amount 484'FNL, 1394'FF'~L, Sec.2, T12N, R9E, UPI 10/10/86 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 7845 'MD 1135' @ surface feet 3K-10 25'~ surfacefeet 2560 (6852'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth2750 feet Maximum hole angle40 0 Maximum surface 2265 psig At total depth (TVD) 3420 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 1R" R?.~# H-4(1 W~_IH ROI' ~r~, '~c,, 11r-,, 11c,, ~+200 cf 12-1/4"~-5/8" 36.0# J-55 BTC 3856' 35' :~5' ~891 ' ~1~24' 1075 HF-ERW 320 sx C]a~ G blanC 8-1/2" ?" 26.0# J-55 BTC 7811' 34' 34' 7845' 6852' 200 sx Class G (minimu~ HF-ERW TOC 500' above Top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface I'~ ~ C i~':~ ~ '~' ~ ~ Intermediate Production ~i;.i~P 7' ;[986 Liner Perforation depth: measured .... ¢.~.,.~.o,,, 0ii & Gas Cons. "'-,"," .... - '¢ true vertical ~,,v,, 20. Attachments Fili.ng fee ~ Property plat [] BOP Sketch ~ Diverter Sketch [~ Drilling program ,~ L/ Drilling fluid program ~ Timevs depth plot [] Refraction analysis [] Seabed report [] 20AAC25.050 requirements certif at the foregoi is .true and correct to the best of my knowledge 21. I hereby ~~ r .e~,l .~ ..¢_,,,O0~¢,,.,~,./' ~ ' Regional Dril ling Engineer Signed t Title Dat ./'- ~" 6,' // Commission Use Only ( LWK ) PD/005 Permit Nurrf6ero.~, ~-,/~¢c? 50--~t.~ ~ Z.i ~, .5-~' 09/24/86 for other requirements Conditions of approval Samples required [] Yes ~LNo Mud Icg required [] Yes ¢-No Hydrogen sulfide measures [] Yes [] No Directional survey required .I~ Yes [] No Required working j;xr, c, tS~ure ~ B¢,PE~ ~~]i¢ 3M; [] 5M; [] 10M; [] 15M Other: (~~~/(~~, -~ ~--'"~/ by order of Approved by Commissioner the commission Dat Form 10-401 Rev. 12-1-85 Suit triplicate / ARCO ~ALASKA~ .... !NC. ................. PAD;;~K.--WELL NO, 1 1 PROPOSED K_UPA_RUK_' F I ELD_,._ NORTH_ SLOPE.. ALASKA EASTMAN WHIPSTOCK!. INC. ..... 0 .................. SURF~U:~ · 1. 000_ BASE PERMAFROS.r 'rVD=l 721 .200O_ rn ;30.00.._ ~ .4000... 5000 _ 6000 _ 7000 _ TOP UGNU~ SNDS' TVD=2694 KOP TVD=2?50 THO=2?50 DEP=O BUILD_ .3~_.I).EG.. P.E,R.~. H:~ FT,.. 9- ! TOP W SAK SNDS TVD=3324, TMD=3333 DEP=88 2Z K-12 TVD=3624- THD=3658 OEP-212 33 9 5/8-' CSG PT TVD=3824 THO=3891 OEP=331 3g- EOC .. TVD=398Z, ];1~1D~4089 DEE=4.511 AVERAGE ANGLE 40 DEC 10 MI N K-5 TVD=5709 TMD=6349 DEP=I 908 I I 1 000 2000 VERTICAL SEC.rI ON T/ ZONE D TVD=6309 THD=?134 DEP-2415 T/ ZONE C TVD=6396 TMD=7248 DEP-2488 T/ ZONE A TVD=6578 TMD-7486 DEP-2642 TARGET CNTR TVD-66~9 THD=7566 OEP=2693 B/ KUP SNDS TVD=6699 THD-7645 DEP=2744 TD (LOG PT) .rVD=6852 T~D=?845 OEP=28?3 I 3000 . / ~ H:OR.'~ ONTAL__ PR0 JECti O N' ~t;ALE 1' IN'. = 1000 FEET ARCO-ALASKA-, INC. PAD' 3K. WELL NO, 11 PROPOSED KUPARUK FIELD. NORTH SLOPE. ALASKA _ EASTMAN WHIPSTOCK. INC. 10.OO g 100O _ 2000 _ 3000 _ 4000 _ TARGET LOCATION, 1320' FNL. 1320' FEL SEC. 2. T I2N. R9E WEST-EAST 3000 2000 1 000 0 I I I TAROT CENTER TMD=TS~6 DEP=26~' SOUTH. 24,55. WEST I I0~ TD LOCATION' 14~4' FNL. 1394' FEL SEC. 2. TI2N. RgE 1 000 S 24 DEG 17 MI N W 2693' (TO TARGET) :'-'~:-:' 7198~ Oil & Gas Cons. 1605 t 571 3952 ' .... l O.OOL gO.O: _ 800 _ 700 O- t 00- 200 300 400 500 600 KuPARUK R I VER UN I T 20" D I VERTER SCHEMAT I C DESC R I PT I ON 1. 1G" CONDUCTOR. 2. TANKO STARTER HEAD. 3, TANKO SAVER SUB. 4. TANKO LONER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. G. 20" 2000 PSI DRILLING SPOOL H/JO" OUTLETS. 7. 10" HCR BALL VALVES DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DONNNIND DIVERSION. 8, 20" 2000 PSI ANNULAR PREVENTER. 7 8 7 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC25.035 (b) MAINTENANCE & OPERAT ION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLON AIR THROUGH DIVERTER LINES EVERY !2 HOURS. 3, CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF NELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DONNN I ND D I VERS I ON. DO NOT SHUT IN NELL UNDER MNY C ! RCUMSTANCES. 0084002 R 1 ( 6 DIAGRAM #1 13-5/8" 5000 pSI RSRRA BOP STACK,// I. 16" - 2000 PSI TAb'CO STARTING HEAD 2. I1" - 5000 PSI CASING HEAD 3. II" - 5000 PSI X 13'-5/8" - 5000 PSI SPACER SPOOL 4. 15-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRILLING SPOOL W/CHOKE AhD KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/PIPE RAMS ON TOP, BLIAD RAMS ON BOTTOM. 7. 13-5/8" - 5000 PSI ~ ACCL.MJLATOR CAPACITY TEST 1. CHECI( AI~ FILL ACCL~TOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUVE~LATDR PRESSI~ IS 3000 PSI WITH 1500 PSI D(~TRF_~ CF THE REGULATOR. 3. OBSERVE TINE, THEN CLOSE ALL UNITS SIMULTAhEOUSLY AI~ RECORD THE TINE AbE) PRES,SI~ REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUV~ OFF. 4. RECCRD ON NADC REPORT, THE ACCEPTABLE LCI~ LIMIT IS 45 SE(X)NDS CLOSING TINE AbE) 1200 PSI RE]VlAINING PRESSURE. 5 L 13-5/8" BOP STACK TEST FILL BOP STACK At~) Q-K~KE MANIFOLD WITH ARCTIC DIESEL. CHEC~ THAT ALL LOCK D(~ SCRENS IN WELLt~ ARE 3 2 FULLY RETRACTED. SEAT TEST PLUG IN WELLFF_AD WITH RULING JT AhD RUN IN LO(~ SCREWS. 3. CLOSE A~ PREVEI~ER AhD MAI~JAL KILL AhD CHOKE LINE VALVES ADJACE~ TO BOP STAC~ ALL OTHER VALVES AND CHOKES SHOULD BE OPEN. 4. PRESSURE UP TO 250 PSI AhD HOLD FOR 10 MIN. IN- CREASE PRE~ TO 3000 PSI ~ HOLD FOR I0 MIN. BLEED PRESSURE TO 0 PSI. 5. OPEN A~AR PREVENTER AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AhD HCR VALVES ON KILL AhD CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. ?. CONTINUE TESTING ALL VALVES, LINES, AhD CHOKES WITH A 250 PSI LOW ~ 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRF~SSURE TEST ANY CHQKE THAT IS NOT A FU~L CLOSING POSITIVE SEAL CHOKE. ON_Y FUNCTION TEST CHOKES THAT DO NOT FULLY CLOSE. 8. OPEN TOP PIPE RAMS AhD CLOSE BOTTOM PIPE RAMS. TEST BOTTOM PIPE RAMS TO 250 PSI AhD 3000 PSI. OPEN BOTTOM PIPE RAMS, BACK OUT RUhI~ING JT AbE) PULL OUT OF HOLE. CLOSE BLIND RAMS AhD TEST TO 250 PSI AhD 3000 PSI. ' OPEN BLINO RAMS ANO RETRIEVE TEST_ PL_U_G.____.M~._E SURE MANIFOLD AND LINES ARE FULL OF NCN-FREEZiNC'~ FLUID. SET ALL VALVES IN DRILLING POSITION. TEST STANOPIPE VALVES, KELLY, KELLY COCKS, DRILL PIPE SAFETY VALVE, AhD INSIDE BOP TO 250 PSI FORM, SIGN, AND S~ TO DRILLING · ;~!5~,?i~ERFORM CCt,~LETE BOPE TEST AFTER NIPPLING WEEKLY THEREAFTER FUNCTIONALLY OPERATE BOPE DAILY. 510084001 REV. 2 MAY 15.. 1985 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. --~ DE~3R$SERt SHALE CLEANER .~-STIR SHRKERS . STIR _.~. STIR CLI~AU~iER t I CENTRIFUGE ! TYPICAL HUD SYSTEH SCHEHATIC LWK4 / ih DRILLING FLUID PROGRAM Spud to 9-5/8" Surface Casing Density 9.6-9.8 PV 15-30 , YP 20-40 Viscosity 50-100 Initial Gel 5-15 10 Minute Gel 15-30 Filtrate API 20 pH 9-10 % Solids 10± Drill out to Weight Up 8.7-9.2 5-15 8-12 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. 7 1986 Gas Cons. ARCO Alaska, inc. Post Office BOx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 7, 1986 Mr. C. V. Chatterton Commissioner State of Alaska ' Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat - 3K Pad {Wells 1 - 18) Dear I.Ir. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU1/12 Enclosure If ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany LO~AT~D IN PROTRACTED LO~AT~D IN PROTRaCTeD X - 6~,~.%9 L~G. t49046'~.932~ X - 5Z9,~5.73 L~. ~49045'~.9774* 8 - Y ' 6,~,253.70 ~T. 70'26'01.0~' 17 - Y - 6,007,978.8] ~T. 7~25'~.3551' X - 5~.~S.92 L~G. ~4904S'~.~, X - 5~.~5.73 L~G. ~49045'~,9977' I. ALL COORDINATES ARE A.S.~ZONE4. ~A~L DISTANCES SHOWN ARE TRUE. " 5. HORIZONTAL POSITIONS BASED ON ~K CONTRO~ MONUMENTS PER ~HD 4. VERTICAL POSITIONS B~SED ON ~K TBM No. 4 ~ TBM No. 5 PER LHD ~ ~SS~. 5.0. G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED-RIXX-~070 rev.~ REGISTERED ~ND LICENSED ~ PRACTICE [ .... ~ ~ THIS P~T REPRESENTS ~ ~OC~TION SURVEY ~.-% THAT ALL DIMENSIONS AND OTHER DETAIL~ ARE CO~E~. AS OF ~ MAY 1986. SURVEYED FOR: ~ AR Alaska, Inc. ~.~w.~ DRILL SITE 5K CONDUCTOR " '" .... iii i i ii i i i i iii i i i i i i '(_8) / ~ (3) Admin (~thru 13~;t )' *b 9. 10. (10 ~d 13) ;' 12. 13. (4) Casg (14 thru 22) (5) BOPE (23 thru 28) (6) OTI-~ A/A (29 thru 31') · LCS BE'W ' - JAIL, /7~,t.__. · ' rev: 07/18/86 6.011 /~-~g- L.4 Lease & Well No. ,~,'~./t O'l YES NO t- 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 w~lls .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~7 Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement 'tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ...................... 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 wellbore separation, proposed ............................ 23. 24. 25. 26. 27. 28. For 29. 30. 31. Is a diverter system required ..................................... .. Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~o~ psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable .... ............................ exploratory and Stratigraphic, wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are .survey results of seabed conditions presented 32. Additional requirenmnts ............................................. POOL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE Additional Remarks: '"31<-!! ,, m~,7, ' b~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. L ' S T ~ P ~ FiLE SERVICE NA ~,! E : VERSION ~ : O~iE : H~XiHUN LEN~T~ : ;iL TYPE : ,.PAEV~OiJS~ FILE .' !'1 N E ~,1 C '3 N T E N T S U N I T T Y P ' C -~'~ T ::': S l Z E C 3 D [ :3U Jrj-3 :, UN _ ,....~ Ntu~SE~ AT .&CC: 72,933 T H:ILSTEAC SAS ViS P~, FLU >,t~ T ? ,q .3 :_ .,: L U Z 3 S Z TY CSSZTY LOSS S .& N '.-'),, S T C N ~ .,. ;:' N T R Y 2. L O C K S DATUM S~ECiFIC~Ti3N MN=M SE,~ViC: £ERViC: DEFT SFLO ILO D IL ILM DIL SP OiL GR ~: L 30 S: Z E VtD oi0 '~iD2 V-'.:~iFIC",TiC;,~ LCE:~T':'i',~" :'A:L;' 4 OEPT 7400.0000 SFLU SP -52.2500 GR ~H05 2.49,~I NPMi 29.4~34 GR -9'99.2500 7300.0000 SPLU - 53.7 -500 G 2. ~ 527 S R :H ~ 5. '.:. '? 5 '0 n n771 I!.5855 107.5000 i3.S34~ '24. 1312 5 '7.750 0.01 90 i~ 7.4.3.8i '75.62 '50 O. 0,327 i 1. 9406 7. :45 73.!375 0.0317 9.4551 '= I030 iOA.7;On .; L :3 k .~ A T ~,~ CNL !LO N C N L ,~. 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