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193-179
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 26, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2E-05 KUPARUK RIV UNIT 2E-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/26/2024 2E-05 50-029-22423-00-00 193-179-0 W SPT 5921 1931790 1500 2730 2730 2737 2737 38 69 74 75 4YRTST P Adam Earl 7/1/2024 MIT IA 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 2E-05 Inspection Date: Tubing OA Packer Depth 470 2100 2050 2030IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240703133643 BBL Pumped:2.4 BBL Returned:2.3 Friday, July 26, 2024 Page 1 of 1 MEMORANDUM TO: Jim Regg Q/ P.I. Supervisor % Zl �✓3(�CTA FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 8, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2E-05 KUPARUK RIV UNIT 2E-05 Ste: Inspector Reviewed By: ,,p P.I. Supry Comm F-- Comm Well Name KUPARUK RIV UNIT 2E-05 API Well Number 50-029-22423-00-00 Inspector Name: Adam Earl Permit Number: 193-179-0 Inspection Date: 7/4/2020 ✓ Insp Num: mitAGE200705092518 Rel Insp Num: Packer - Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 05 'Type Inj W'TVD 5921 - 'Tubing 2650 2650 - 2650 2790 F Type Test SPT Test psi 1500 - IA 405 2000 1940 1930: 23 BBL Returned: 2.3 ' OA 50 s0 80 so 4rRTST _ P/F _ P Notes: MIT IA Wednesday, July 8, 2020 Page I of I O X O 00`�z v "0 0 r 3 4-,7 O Cw a f0 `- -0 tO OQ 1-- Y O NYO N U N " > u a` CU C �-.. 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Q G J N N M N N H z N Q O ia• ' ^ W crts C (5 • E E 0 Q t— a a 1°- 12 • I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,July 22,2016 TO: Jim Regg 7�?/Gf/(o P.I.Supervisor —(q SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2E-05 FROM: Lou Grimaldi KUPARUK RIV UNIT 2E-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2E-05 API Well Number 50-029-22423-00-00 Inspector Name: Lou Grimaldi Permit Number: 193-179-0 Inspection Date: 7/21/2016 Insp Num: mitLG160721150747 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2E-05 Type Inj W"TVD 5921 - Tubing 2650 2650 - 2650 - 2650 PTD 1931790 - Type Test SPT Test psi 1500 - IA 230 2000 - 1970 - 1965 - Interval 4YRTST P/F P ,r OA 25 40 - 40 - 40 - Notes: 1.9 Gallons Diesel pumped 2.1 returned(OK).Good solid test.All pertinent paperwork supplied prior to test. M4 &hal : CO Civ F- est Pkv SINED MAY 1 9 2017 Friday,July 22,2016 Page 1 of 1 • • d'mai/smog 0 oo t) N r" r V) I I, i .I . lI d .it-Ir Ii . , i,--d-1--I. i .E r 4I-4--+1--F . T.-. . • I . Z • , —7 • 0 . • C.C. Y r— 1 . . N . . O . • N :• r a) C .. . cp I"" . . . . N • to . rM as .a..._ . . : Co . • • • •' • C1 LL . : . : CoCh • I Y ' I If I' I' I 1 i` 1 1 9 I' i 'I S ]I` rj_: II-i' I;I- 4 I - <0 In 0 0 oN 0 o `O d N N T T- 1 1 H ISd • • i--'1 KUP INJ 2E-05 s ConoclPhilli p i Well Attributes Ma AiiOn 1W MD ID r:r1:-.,,s,swum Taldtanr 1 A14,0a0,010. lYellboiestattis „1,'I IND 0099 Ad Baa ,,„,..,,,,,,4„,,,,,,,,, 500262242300 KUPMtM RIVER UNIT NJ I 86.711 4,67684 6-0 ••• -..-. Comment 11264Pa8 iLdo-. Ann:'attcn.—. End Dale K8-0.41 n 10 !MOWN=3 2645,5/401391104016a0 58s17:18PA1-E ,_ Last NC)- 414/2009 12/7!1883 : _...._-...-- Aletiblloa Meth 411/0t. Edd AZ Anmast lun Ural Mod By end 0.1.7 Lao lag'SLK 12,057-9 4127/2016 Rev Reason.TAG,CLOSED CMU [Ural 111111111111 5/6/2016 Casing Strings Gas , c bn 09-110- not N. Top. -__ 011(3 _-361 Depth 0192) See Depth OV60...Mon 01.:Grale TopVuo,d CONDUCTOR 16 16.260 39 T 79 76.9 6750 ii as WELDED 11ANGER,Z7.0 . ,i11 C.-irg Ducripton un Ml 108/7 1e)Op15130c„j-11.1;an 11910) 8e1 p.14n OM..1k9L1a lam...Geo.. ie)Thread �t..4, I SURFACE 9996 C6; 1 8.621 41.2 6,137.7 7.488.7 3Hit: Castng Orsedplion &lfl/r TlY lm; 'rop 04191 '$N Berta pd(9) 6e1 06p111 MM..VYdI.en Q..,Or1•b lop Thlo d PRODUCTION 7 6059 349 12,196.5,_ 6,371.3 ' L1: n:, BTC-Mad _...:. Tubing Strings ...,_. TOhlne Desd0p1100 7t M,.. .n c.ni Tor 1!015) red Depth 91.Bet Nate Iraq I..WI Mee G..d. TOSS'a n.aia.. TUBING 3 117---. 2.992 77 01 11,783.0 8,074.4 9 30 T40 CAE Completion Details l ID Ton PIM TOP 11‘00 Rets Top16c1 PI Bela Des Cmn {,w0 Nam. 27.0 27.0 14T W.I47,I-9 Cameron Gen 4 Tubing flamers/36'Pup 15,006 4190 5189 629 2.5PPIE Gamed 3.5'x2875"AS'Nipple lEUE 3rd) 2875 k474L39T:71 - 11,8804 :.5050 4716 SESL Baker Mop Seal May wlLocator b6'pup Space out 21 2560 NlPPtgME ,.e 11,6582 5.9105 4717 0119 BakerPBR . 4A00 11,571.5 6,920.7 4729 FPAC/.EF Ea9Ar 7'280 FR43B2 Pecker ..:....... ...... 2.990 11.705,6 8.0188 4564 SLEEVE-0 CMUBrding SYeave u/2.80.DS Prolfie(Cl08ED 2.812 q 4127/2016) !1761.8 8,961 6. 41:96 SEAL Baker 6040§salAssembryw/ talar pup(apace 3.000 0711; 11,760.1 6,067.9 44.00 PACKER Baker r28d Pe/maneat"F 1'Packerwl SBE 4.000 —11:7111 6.071.3 44.01 NIPPLE Cando 3.6.s 2 76''O'Neal° 2.750 3a311r✓,rF 4+7411 aT 7,------e a _--11,787.1 - 6,073.7 44.02 8LEO Bakar Solid Ball Shear Out Sub w/MUG 8411001 3000 (KNOCKED OFF SHEAR GUT WB)) Perrorailone&Slots ,..--' 911M I hois le)live) et.RVL9 1,/271,8 905(9108 01.1a311 01-591 Zone ash. 11 1P, Com GASt IFi,11$001 I 111701.11 11.7094 8,015.3 8.048.6 CA,2E415 PLR,978/2006 50 LR, 4.5'NSD OMEGA b PJ4605,72 deg phase 11,8850 11,11x6.0 6119.0 8.133.fA42E-05-640.51W 50 PERI 3318"14S0PJ3406,80 IIdeg phase _ MAilrke11inserts 6E3411./741,4 et .... all maim 689,I1,61e2 Imo on rr4'DI alba Loran Pad slew Ten Ran alarN le Top(tKie)SI In6B4 halo Dodd vD le:, ealy TYI.4 ii,. ilni DTI_ Rua Data Core PAC1cER,11,5715 ( 11,506.65 0726 Cam° KBMG 1 GASI7FT OW OS 0005 00 4.1707009 — 2 11,619.11 ?"L..nII tot 'KBMG 1 do sph1Y Olt.5 0-000 00 41412079 __..."_ . Notes;General&Safety I End Data M71Mdion 474720910 NOTE:WELL CONVERTED FROM PRODUCTION TO INJECTION 167cT101(119/e.1 $ 4/1712005 NOTE VIEW SCHEMATIC MAIasRe fiche II4/17/2806 ND)E:Need 1125 reading ppsl conversion to hinter s.revr.oI:ro. 1. "ERF;11.7010.11.T340-----... BEAL•11,7858 PACKER;11,7401- —... JR.. ,s NIPPLE.11.7786- 1"/ , WLEO.11.7821 3'0RI'.11345 0-11.366 a— T 750090700, aa9-u,1965 l � I • • eijr - .... 0 Q Xtan L, cu ° �Q 0 r 0 � Z 4-', ' 0 :Cil O rcs Q m O ` O) O F.�ay • a; E • 0 III..:.. Q 1 U d v w �+ Q C 0 '5 0 co -, ca >.• Q Q 0 LW.7 N O O O LID CO CD cD O r}'a O y m Q o ,� c • c 0 c 0 0 CU 0 "' ,� � -0 a CU 2 44 F.W., co T 4' co r- co O) N N 7 c -O > Q N (NI C m CD Q v 0 E o >- K ~ N > c- 0 I-iii s_ . - 0 0 0 0 0 0 0 0 0 ra QJ V 0 I." J J J J J J J J J r w w w w w w www c ra 0 o F- LL LL LL LL LL LL LL LL LL cn c E -c Q Q J J J J J J J J J v 0 C N G? 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' � C VI of a � aO a0 > a tv u m o J a m a o a p \ v '� ,�, • LL CD U L) U ix U CDm U i 13 Lii > ►meq 6 a CI W ' O W U > 0 m 0 pL • W i (i Z v a J J J J O J J J J 11Z 2 VI o Ce W W W CC W W W W own W w > > > w > > > > v 4 _0 cc z Y Y Y Y Y Y Y E w d' Q Q Q C4 Q Q Q Q uN ,7_ Q a d d Q d LL LL 0. a = _ = LL = _ _ = 0 0 CI = Y Y Y = Y Y Y Y >.Y Y c IX CC 0) X v 0 wQra O CO _ N- y O •n U) O CD •V O Q r •V U) O O p OOOOOOOO O O O O O O O O O - ra Tana L.? 0 0 0 0 c0 0 0 0 O E yij Ql0 5; U U O U N �U U� O9 CO C) t) J 0 W -- O O D O D 0 0 0 0 lcN 0 X m pp 0 lDm O O O O O O O V 0 0 0 0 0 0 0 0 0 Vf Or N N c0 tt (O 6 O N M C (D M CO M O7 V N E CI'' r N N CO CO On N N N O M O O N N N 0 N N N N N N N N N N v n O (4) O M T M O) O) O) 0 4 O o 0 0 a- 0 0 0 0 a y 6 0 0 0 0 0 0 0 0 .,- v) u) in Un in in u) in in a G=.7 1= Lij c a CV o C L Z v m U Q Y CO W +' Q `-' '" cc i '. �= ^ Q O O O N m QJ 3 2 PP v Z N O M O O a+ E +' In M !_ H 19 _� C Q N m N N V N N E z d Y CO3 a a a Q · XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs-of vadous kinds . [] Other COMMENTS: Scanned by: iann~Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 2E-OS Run Date: 8/17/2010 August 27, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2E-OS Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-22423-00 Injection Profile Log 1 Color Log 50-029-22423-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.w . ~~3, r~ ~~ Date: ,,~~~ ~ •;~ r,;J~ Signed: MEMORANDUM To: Jim Regg ~~~~ ~} ~~-~ ~(v P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 26, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2E-05 KUPARUK RIV UNIT 2E-OS Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~' <- Comm Well Name: KUPARUK RIV UNIT 2E-OS API Well Number: 50-029-22423-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ100721183525 Permit Number: 193-179-0 Inspection Date: 7/5/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2E-OS ~ Type Inj w ~ T`/D 5921 ~ IA 940 3000 2950 2940 ~ P.T.D 1931790 TypeTest SPT Test psi 1500 r QA 420 680 680 680 IntervalINITAL p/p' P Tubing z17s zzoo 2zoo 2200 NOtes: 2.8 BBLS diesel pumped. 1 well inspected; 2 exceptions noted: the swab and wing valves were both leaking at the valve stem packings. These items were repaired aft^ e_ r the test. I also noted that wells 2E-08, 2E-10 & 2E-15 exhibit significant external corrosion on the well heads, fasteners & flow line S-risers & we112E-I S has (6) substandard bolt/nut engagements: 2E pad operator will initiate repairs ,..~ ~ 7 ~.lGC, r~(~~,: Monday, July 26, 2010 Page I of 1 ' Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, August 27, 2010 9:44 AM To: 'NSK Problem Well Supv' Cc: DOA AOGCC Prudhoe Bay Subject: RE: KRU 2F and KRU 2E Exceptions wait until complete; thank you! Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 ~~2,~`~ ~~ i From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, August 27, 2010 9:04 AM To: Regg, James B (DOA) Subject: RE: KRU 2F and KRU 2E Exceptions Jim, Following up on 2F and 2E exception reports. We have repair plans in place, however they have not been executed yet. Do you want an interim report of the plans or would you prefer we wait until they are completed? Please advise. MJ From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, August 26, 2010 3:31 PM To: NSK Problem Well Supv Subject: KRU 2F and KRU 2E Exceptions MJ - This new encryption program the State IT people have implemented is making it a bit difficult to follow-up on messages; please refer to my message July 27, 2010 Thank you for the update of KRU 1 D; please also update KRU 2E (external corrosion; substandard bolt/nut engagements; notes in Remarks of 2E-05 MIT) and KRU 2F (substandard bolt/nut engagements) Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 Page 1 of 1 8/27/2010 Regg, James B (DOA) • From: Regg, James B (DOA) ~ iJ Sent: Tuesday, July 27, 2010 12:25 PM ` `~~ 7I~?I ~ To: 'NSK Well Integrity Proj'; 'NSK Problem Well Supv' Cc: DOA AOGCC Prudhoe Bay Subject: KRU 2E-05 MIT Exceptions Attachments: MIT KRU 2E-05 7-5-10.pdf Inspector's report attached for witnessed MIT 7-5-10. Please provide status of response to noted exceptions on wells 2E-08, 2E-10, and 2E-15 Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 Page 1 of 1 7/27/201 ~ . . Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, June 12, 2009 9:57 AM To: 'Long, Jill W' Subject: RE; 2E-05 (193-179) Jill, Thanks much. No need to send a new summary. Tom Maunder, PE AOGCC From: Long, Jill W [mailto:JiII.W.Long@conocophillips.com] Sent: Thursday, June 11, 2009 4:17 PM To: Maunder, Thomas E (DOA) Subject: RE: 2E-05 (193-179) Tom- Here are my answers to your questions. 1. When the BOP was initially tested, it is not indicated what Inspector waived or witnessed the BOP test. This information should be included whenever a BOP is tested. Our records show that 24 hour notice was given to the AOGCC on 3/2912009 at 15:00 hrs. The AOGCC was then updated of the upcoming BOP test again on 3/30/09 at 14:45. Witnessing of the BOP test was waived by AOGCC Rep Chuck Scheve on 3/30/09 at 15:15. Attached are the first pages of the 2 morning reports in our WeIlView system that document the communication. Because the Rig Supervisors entered the comments in the "General Remarks" section of WeIlView rather than the "Last 24hr Summary" or "Operations" section, the documentation did not appear in the reports you received with the 404. I have added the comments in the other sections of WeIlView so they will now be captured correctly. 2. The BOP was initially tested to 3500 psi, the test pressure listed on the 403. When the break was tested after changing the packoff seals it was only tested to 3000 psi. Please comment on the discrepancy. This is a data entry error in WeIlView. The void between the packoffs was tested to 3000 psi but then the BOP break was tested to 3500 psi (not 3000 psi as noted in the report). Attached you will find a copy of the pressure test chart documenting the test to 3500 psi. I have also made the change in WeIlView to reflect the correct test pressure. 3. On 4/2/09, the annular and choke were tested to 3500 psi using the test plug after circulating a kick. Were any of the breaks subjected to this higher pressure? After circulating out the kick, the entire system was pressure tested to 3500 psi. So yes, the breaks were tested to the pressure of 3500 psi. Give me a call if you have further questions.. Would you like a new copy of the Operations Summary that contains the changes I've noted above? If so, just let me know. 6/12/2009 . Page 2 of 2 Thanks, Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907-240-6574 Fax: 918-662-6330 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, June 11, 2009 1:20 PM To: Long, Jill W Subject: 2E-05 (193-179) Jill, I am belatedly reviewing the 404 recently submitted for the workover on this well and have some questions. 1. When the BOP was initially tested, it is not indicated what Inspector waived or witnessed the BOP test. This information should be included whenever a BOP is tested. 2. The BOP was initially tested to 3500 psi, the test pressure listed on the 403. When the break was tested after changing the packoff seals it was only tested to 3000 psi. Please comment on the discrepancy. 3. On 4/2/09, the annular and choke were tested to 3500 psi using the test plug after circulating a kick. Were any of the breaks subjected to this higher pressure? Call or message with any questions. Tom Maunder, PE AOGCC 6/ 12/2009 • • O r r ra i ~ u.l i/l(ei l V I' P.Il~ R P ~ ~-I-S T~~ cu~-m ~~i ~ ~ ~~~~~ ~~ ©~ ~.~~ ~~(~~C Securi Level: Development ( Daily Drilling Repo`=rtl 2E-05 Report Number: 1 ... Rlg: Report Date: 3/29/2009 AFE Type NelworWlD # Total AFE+Sup 10243475 977,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftK8 ) Depth End (ftK8) 2E-05 KUPARUK RIVER UNIT 5602.00 1.0 0.0 0.0 Daily Mud Cost Cumulative Mud Cost Dally Cost Total Cumulative Gost 101,344.32 101,344.32 Aetual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration {days) Job Days Ahead (days) Projected Job End Date 3/29/2009 11/27/1993 3.00 3.00 0.00 4/1/2009 last Casing String Next Casing OD (in) Naxt Casing Set Depth (ftK8) PRODUCTION, 12,186.2ftK6 Ops and Depth @ Morning Report 24hr Forecast Rig on standby with crews at 2B Pad Rig on standby at 2B Pad uniii CPF 2 resovies plant issues, cunt rig move to 2E Pad. Last 24hr Summary Moved rig from 2T Pad to 28 Pad, stopped rig move for CPF 2 plant issues, to keep road open. mar Weather Head Gount 24 hr notice given to AOGCC for up-coming BOP test on 3/29/2009 at 15:00 hrs. -201, Clear 31.0 Tills Nezaticky, Peter -CPAI, Wells Supervisor WO Wells Supervisor WO Pederson, Rance -CPAI, Wells Supervisor WO Wells Supervisor WO Time Lo Start Time End Time Dur {hrs) Phase Op Code Activity Code Time P-T-X TdH Code Trbl Class. Depth Start tRK6) Depth End tRKB) Opaa6on 13:00 16:00 3.00 MIRU MOVE MOB P Move rig from 2T-220 to 2E-05. 16:00 00:00 8.00 MIRU MOVE MOB T Waiting Wait on CPF2 having plant operations problems, Other requested Nordic 3 Rig standby on 2B to keep road acess to the pads open. Stand by with crews at 26 Pad. Welibores Wellbore Name Wellbore APINWI 2E-05 500292242300 Sectlon Size (in) Aa Top (ftK8) Aa Btm (ftK8) SteR Date End Date CONDUCTOR 18 0.0 62.0 12/1/1993 SURFACE 11 5/$ 82.0 6,165.0 12/2/1993 PRODUCTION 9 6,925.0 12,210.0 12/3/1993 Surve Data MD (ItKB) Ind (°) Azm (°) TVD (ftK8) VS (ft) NS {R) EW {R) DLS (°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Latest BOP Test Data Date Cornment Page 1/1 Report printed: 6/11/2009 • C Security Level: Development Daily Drilling Report 2E-05 Report Number: 2 Rig: NORDIC 3 Report Date: 3/30/2009 AFE Type NeMrorkllD # Total AFE+Sup 10243475 977,000.00 Wellbore Weil Type Field Name DFS (days) DOL Depth Progress (fi) Depth Start (fiK8 ) Depth End (fiK8) 2E-05 KUPARUK RIVER UNIT 5603.00 2.0 0.0 0.0 Daily Mud Cost Cumulative Mud Cost Dally Cost Total Cumulative Cost 2,071.05 2,071.05 59,480.05 160,824.37 Actual Start Data Original Spud Date AFE DurTotal (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 3/29/2009 11!27/1993 3.00 3.00 0.00 411!2009 lest Casing String Next Casing OD (in) Next Casing Set Depth (fiK6) PRODUCTION, 12,188.2ftKB Ops and Depth ~ Morning Report 24hr Forecast PU RIH with milling BHA on 31/2" DP Tesi hardline at 250/3,500 psi, rack and tally 2,500' 3 112" DP, install wear ring, PU and MU milling BHA, PU and single in hole to 2,500', circ out diesel tzp with 9.$ ppg brine, MU 7" storm packer and RIH 100', set and test same, LD running tool, ND BOP Last 24hr Summary Rig on standby at 2B Pad until CPF 2 resovles plant issues, cont rig move to 2E Pad, spotted and leveled rig, accepted rig ai 12:30 hrs, bermed up cellar, RU hardline, pulled BPV, installed HP-BPV, ND tree, NU 13 5/8" BOP, RU and tested BOPE at 250/3,500 psi. General Remarks Weather Head Count Ac t Nordic Ri 3 on - 3-2IL-2nns (~ +~•~n nm -19?, Clear 33.0 Up-dated' AOGCC of up-corning BOP test on 3!30/09 at 14:45 hrs. Witness of BOP tesYwas waived b AOGCC Rep Chuck Scheve on 3/30/09 at 15:15 hrs. arv(sor Tdle Nazaticky, Peter -CPAI, Wells Supervisor WO Wells Supervisor WO Pederson, Rance -CPAI, Wells Supervisor WO Wells Supervisor WO Time Lo Start Time End Time Dur (hrs) Phase Op Code Actlvity Cade Time P-T•X Trbl Code Trbl Class. DePih Stan (itKe) DepM End (flK8) Opatadon 00:00 07:00 7.00 MIRU MOVE MOB T Waiting Wait on CPF2 having plant operations problems, Ocher requested Nordic 3 Rig standby on 2B to keep road aces to the pads open. Stand by with crews at 2B Pad. 07:00 12:00 5.00 MIRU MOVE MOB P Move rig from 2B Pad to 2E-05. 12:00 12:30 0.50 MIRU MOVE PSIT P Spot and level rig over 2E-05 Accept Nordic Rig 3 on 2E-05 on 3-20-2009 @ 12:30 pm. 12:30 14:00 1.50 COMPZN RPCOMP RURD P Berm up around the well. Pull BPV and set HP-BPV. 14:00 15:30 1.50 COMPZN RPCOMP NUND P ND tree. Install plug off tool. 15:30 19:00 3.50 GOMPZN RPCOMP NUND P NU 13518" BOPE. 19:00 00:00 5.00 GOMPZN WELCTL BOPE P RU and test all BOPE at 250!3,500 psi, good tests. Welibores Wellbore Name Wellbore API/UWI 2E-05 500292242300 Sedlon Size (in) Act Top (fFK6) Ad Btm (flK8) Start Date End Dete CONDUCTOR 18 0.0 $2.0 12/1/1993 SURFACE 11 518 82.0 6,165.0 12/2/1993 PRODUCTION 9 8,925.0 12,210.0 12/3/1993 Surve Data MD (f0(e) Ind (°) Azm (°) TVD {flKa) VS (fl) NS (fl) EW (fl) DL.S (°l100ft) o.oo o.oo o.oo o.oo o.oo o.oo o.oo o.oo Latest BOP Test Data Date Comment 3/30/2009 Initial BOP Test Page 111 Report Printed: 6/11/2009 • • ~~ / f~ '~~.. s 1t. r' F it ~ . ~ i /~ '~ '~ r(~ ~r rl ~~ ~~ .. , r ~` . ~' i f 1 ; ~ F I` ~~ ~ dt r w.~ jf +~ ,"" ~ ; I~ 1 ~ i ~ i ~ fir. 1 ~ ~~~ ' ~ i ' ~ ~~i_~ -` ~ t . --~... ~ ~_ ~ II r ~~ ~ ~~ ~! ~ ~,! " ~ I~ li , y ', '. 11 I i i 1' ~ t l 1 ~ 1 ~- ~ ' ~ ~ ~ I~ j li ~ i ~t ~~ ~ 4 ~~ it ~ ~ .. _1---L~-- 1 ~. ~-~ i~~,,y-'~ r 1 ^~ ,S ~~ "s., ,\ it ~~~- ~ ~_ ~-_ ' __ - -'_---. - ~ ~`--.,~ ~`~-` `..~ .'~ -~. '°t'i . ~~ ~ ! ~ ~-' - ~ --~ ~-- _ _ %t - --;.. '_`' -'-.; ~ Vii`~~`~ O~ :~ ~^~ rte' f _ .,_~ ~~.. y„- ~~~ \ ~~ .~ ~ ~- ' ~~ -~~ ' ~ _ ~ __ _ `~. l'am` ~ \' __ ~11--- `~ \ `\ Kam- ~,~oa°~y~ ~j ti~ __ ---J ___ _;"-~~-- _~ ;~ \~~\-~ .~. Xr / .~ _ fl _ _ __ ~ "n `. \ ` , ~'~ \ ~1, ! t' t fly. , 1. DV / ! • ~~ kt ~/' _'~. ___ ~~ ~'`, .l "`ti ` ?~ `,~~•+' ~ ~j ~ X55 l ~~ ~~ ' r _ ~ __ ~_. .. ~ - •~ ~ ;`,;',\~ ~\ UT ''~. \S C~~ 121~ ~ _~Y' ~~. / ~~ / C1 ~` ^ ~ _ _ -- - -' - ~':~ ~j~ .~, `, ~ `rte- ',s r' ,~ t' 11 '']lam !' f`~ ` ., w'r ~` j. %~ ~i ~ 5t w ` ~,-.-`- ~ "`--~~_`-t--~}~._ F ~ / ~ . ~~ ~ '~ ~ ~ -^'~ ~~. \ 1 ~ 1 ~ 1 it { ~. ~ , I . I ''` ~~hg~ Nom. .Y~`.~~` .~ ~,~ ~~~~,~~_~ ~ iy~ I I 11't tii .1 5~..--{ ''~~ ~:,~~ v \ ~ r [.. r . ~ n t`- ~ J 1~.~ l i li~~~..~~~h '1 i 1 ~ ( 1 i. I 1 5 ,~ ~~ ~ -r ~ r: ~i~~y;~ _ J"')~ .~_•}~~ rf % \,`.. ~f ~~ i. 1 Jar ~~~w~i 1 ~ `~ /K On _ / ' ~t"~ ~ / J / . ~ f ~ fT ~'~.. i f' ~~ r'1' j x0 i 7 .7 '\~ ,'~ --` -~,~ ~-- ~ _ t __ _ -S' ~ i' \ ro ~ if , ,/' ~ ~ /~j f ~ I ../~ ~ ~._ . ~ -~--- ~•~~,, ~,..~.~ ~~` qtr I - -t' j._ - _ ~.1- ` •. ~ ,~' . ow ~~' OZ ~ ~~ r ~% r J~ ,; f; ~,~, ~~ F ;~; ~ f , .! ./ i~ l !~'~ ~~ ~4 D STATE OF ALASKA • r~ w ' ~' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERAT s1 &'~~~ ~"~~''' ~ ;~rnissian /1 n nta...= n z~ t, 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q convert to inj Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConoCOPhilljps Alaska, InC. Development ^ Exploratory ^ 193-179 / ' 3. Address: Stratigraphic ^ Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22423-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 147' 2E-05 8. Property Designation: 10. Field/Pool(s): . ADL 25664 - Kuparuk River Field /Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 12210' - feet true vertical 6381' . feet Plugs (measured) Effective Depth measured 12100' feet Junk (measured) true vertical 6303' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURFACE 6097" 9-5/8" 6138' 3489' PRODUCTION 12147" 7" 12188' 6366' Perforation depth: Measured depth: 11701'-11736', 11845'-11 865' true vertical depth: 6015'-6041', 6119'-6134' / `~~~ ' Tubing (size, grade, and measured depth) 3.5", L-80, 11783' MD Packers & SSSV (type & measured depth) Baker FHL pkr, Baker perm. F-1 pkr @ 11572', 11760' Camco nipple @ 519.55' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative._Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation na SI -- Subsequent to operation na SI -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~ ` Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG^ GINJ^ WINJ ^~ ~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Nr,4 if C.O. Exempt: 309-031 Contact Jill Long @ 263-4093 Printed Name Ji Long ~ Si t ~ Title Phone: 263-4093 Wells Engineer Date Q~/~~ `~~ ~ gna ure ~ / 6 Pre ared b Sharon All u Drake 263-4612 Form 10-404 Revised 04/2006 .~ S ~ JUN ~ 11DOq s~~ ~~ Submit Original my ~ ``~ KUP .` ~QCtOCQ~11~~I~JS Well_Attributes ],I._yrt4 I1M1 ~ Wellbore APVUWI .Field Naml r 500292242300 KUPARUI Com ent m WeILCOMIg 2EA5,4q 7x2005126:4 ti------_-"- SSSV'. NIPPLE ._ Stllemati. AMUaI A notation (Depth (ftK6) NIPPLE. 520 SURFACE. _ 41-6,138 GAS LIFT. ___ 11,507 SEAL, 11.550 PBR, 11,556 PACKER. __. 11,572 INJECTION. _ 11,619 SLEEVE, 11,706 IPERF, 11,70111,736 SEAL. '. 1.]52 PACKER, 11.]60 NIPPLE, 11,779 WLEG. 11.782 2E-05 iWell Status "Prod/lnj Type Intl (°) MD (ftK6) '(Act Bim (HKB) RIVER UNIT JNJECTING 168.71 4,576.84 12,210.0 'H25 (ppm) (Date Annotation End Date KBGrd (h) Rig Release Date 0 4/17/2009 Last W0- _I 4/42009 12/7/1993 ~Entl Date (Annotation Entl Date LaSi Tag: ( KEV KeaSOn_WVKKV VtK I.ODVCR YfOOUCer IO Ir11P,CIOr I 4/i/~GUUy 'Casing Strin s (Casing Description String 0... String ID ... Tap (ftK6) Sat Depth (f... Set Depih (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.250 0.0 79.5 79.5 62.50 H-00 Casing Description String 0... String ID ... Top (HKB) Set Depth (f... Set Depth (ND) ..- String Wt... String ... String Top Thrd SURFACE 9 5/8 8.921 41.3 6,137.7 3 488.6 36.00 J-55 BTC Casing Description String 0... ,String ID .. . Top (HKB) Set Depih (t... Set Depth (ND) ... String WI... String ... String Top Thrd PRODUCTION 7 ~ 6.059 30.6 12,188.2 6,3654 29.00 L-80 BTC-Mod Tubing Strings 'Tubing Des iption Set Depih((... Sat Depth(ND).. (String W[... Str ng ... (String Top Thld Top (ftK6) String O._String lD ... ~ TUBING ' 31/2 2.992 ( ( 27.0 11,783.0 6,0744 9.30 L-80 EUE Com letion De tails Top Depth (ND) Top (ftK6)' (ftK6) Top Intl', (°) (tam Description 1 Commen[ _ _ _ _ _ _ ID (in) ~' 27.01 27.0 HANGER 4.30 Cameron Gen 4 Tubing Hanger w/ i5" Pup 3.0001 519.5 518.9 6.28 NIPPLE Camco 3.5" x 2.875"'DS' Nipple (EUE 8rd) 2.875 11,550.4 5.904.9 41.92 SEAL Baker 80-00 Seal Assy wl Locator & 6' pup (space out 2') - 2.960 11,558.21 5,910.7 42.06 PBR ( Baker PBR 4.000 11,571.5 5,920.6 42.29 PACKER Baker 7" 26# FHL 4762 Packer 2.930 11,705.9 6,018.8 43.64I SLEEVE CMU Sliding Sleeve w/ 2.813" DS Profile (closetl) 2.812 11,751.8 6,051 91 44.00 SEAL Baker 80-00 Seal Assembly w/ Locator & 6' pup (space out 2') 3.0001 _--_ 11,760.1 6,057.9- 43.95 PACKER ~ Baker 7"26# Permanem'F-1"Packer w/SBE __ - 4.000' 11,778.6' 6,071.3 44.00 NIPPLE Camco 3.5" x 2.75"'D' Nipple 2.750 11,782 1 6,073.7 44.01 WLEG Baker Solid Ball Shear Out Sub w/ WLEG Bottom 3.000 IPERF, 11,865-11,Bfi5 PRODUCTK)N. _ 3111.188 TD. 12.218 • Conoc©Phillips Time Log & Summary iNeJJview SNeb Re~orttng Report Well Name: 2E-05 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 3/30/2009 12:30:00 PM Rig Release: 4/4/2009 10:00:00 PM _ _ _ - __ Time Loys Da e _ From To _ Dur _ S C_epth E._Depth Phase Code_ Subcode T Comment ___ __ 3/29/2009 24 hr Summary Moved rig from 2T Pad to 2B Pad, stopped rig move for CPF 2 plant issues, to keep road open. 13:00 16:00 3.00 MIRU MOVE MOB P Move rig from 2T-220 to 2E-05. 16:00 00:00 8.00 MIRU MOVE MOB T CPF2 having plant operations problems, requested Nordic 3 Rig standby on 26 to keep road acess to the pads open. Stand b with crews at 26 Pad. 3/30/2009 Rig on standby at 26 Pad until CPF 2 resovles plant issues, cont rig move to 2E Pad, spotted and leveled rig, accepted rig at 12:30 hrs, bermed up cellar, RU hardline, pulled BPV, installed HP-BPV, ND tree, NU 13 5/8" BOP, RU and tested BOPE at 250/3,500 si. 00:00 07:00 7.00 MIRU MOVE MOB T CPF2 having plant operations problems, requested Nordic 3 Rig standby on 26 to keep road acess to the pads open. Stand b with crews at 26 Pad. 07:00 12:00 5.00 MIRU MOVE MOB P Move rig from 26 Pad to 2E-05. 12:00 12:30 0.50 MIRU MOVE PSIT P Spot and level rig over 2E-05 Acce t Nordic Ri 3 on 2E-05 on 3-20-2009 12:30 m. 12:30 14:00 1.50 COMPZ RPCOM RURD P Berm up around the well. Pull BPV and set HP-BPV. 14:00 15:30 1.50 COMPZ RPCOM NUND P ND tree. Install plug off tool. 15:30 19:00 3.50 COMPZ RPCOM NUND P NU 13 5/8" BOPE. 19:00 00:00 5.00 COMPZ WELCTL BOPE P RU and test all BOPE at 250/3,500 si, ood tests. 3/31 /2009 Test hardline at 250/3,500 psi, rack and tally 2,500' 3 1/2" DP, install wear ring, PU and MU milling BHA, PU and single in hole to 2,500', circ out diesel cap with 9.8 ppg brine, MU 7" storm packer and RIH 100', set and test same, LD running tool, ND BOP, ND tbg head, CO pack-offs, NU tbg head and test, NU BOP, tested BOP breaks, LD storm acker, cont PU sin le in hole to 11,115'. 00:00 01:00 1.00 0 0 COMPZ WELCTL BOPE P RD test equipment, RU and test hardline to kill tank at 250/3,500 psi., ood test. 01:00 02:00 1.00 0 0 COMPZ RPCOM PULL P Pull plug off tool and HP-BPV, PU landing jnt, BOLD's, pull and LD han er with u . 02:00 03:00 1.00 0 0 COMPZ RPCOM OTHR P Set wear ring, load Baker milling tools, 4 3/4" DC's and storm packer on ri . _ ~~ ~e ~.. ~ ._ ~.~_, f~~~e 1 ~ f n Time Logs Date From To Dur S. De th E De th Phase Code Subcode T Comment 03:00 08:30 5.50 0 2,561 COMPZ RPCOM PULD P PU and MU milling BHA, 9 jnts 4 3/4" DC's, PU and single in hole with 70 jnts 3 1/2" DP taking diesel returns to kill tank, to 2,561'. 08:30 09:00 0.50 2,561 2,561 COMPZ RPCOM CIRC P Circ out diesel cap taking returns to kill tank. 09:00 10:00 1.00 2,561 2,561 COMPZ RPCOM PACK P MU storm acker, RIH -100' and set same, test storm packer, POOH LD settin tool 10:00 15:00 5.00 2,561 2,561 COMPZ RPCOM SEOP P Remove rise nipple and ND BOP stack. Change out seals on primary and secondary packoff. Test to 3000 psi. for 30 min. OK. NU BOP stack, replace riser. Body test flange on BOP break to 3000 si, retest kill line. 15:00 15:30 0.50 2,561 2,561 COMPZ RPCOM PACK P PU RIH w/ retrievin tool. Re e storm acker POOH and LD. 15:30 00:00 8.50 2,561 11,115 COMPZ RPCOM PULD P Continue to PU 3 1/2"drill pipe and RIH w/BHA (bit, boot baskets, bumper jar, oil jars, 9 drill collars), from 2,561' to 11,115', up weight 157K, down wei ht 75K. 4/01 /2009 PU single in hole to 11,599', weight up surface volume to 10.2+, displace well to 10.2+. mill out CIBP at 11,607', circ out gas bubble, chase to bottom and tagged at 12,068'_, CBU, cut and slip drill line, POOH LD 3 1/2" DP and millin BHA. 00:00 01:00 1.00 11,115 11,599 COMPZ RPCOM PULD P Cont PU and single in hole with milling assembly on 3 1/2" DP from 11,115' to 11,599', up weight 165K, down wei ht 80K. 01:00 03:30 2.50 11,599 11,599 COMPZ RPCOM CIRC P Blend surface volume to bring up to weic ht and displace hole to 10.3 ppq brine at 5 b m - 1,340 si. 03:30 05:30 2.00 11,607 11,629 COMPZ RPCOM MILL P Ease down and to ed to of CIBP at 11,607', start milling on bridge plug, 80 rpm's, off btm torque = 4,800 fUlbs, on btm torque = 5,500 ft/Ibs, pumping 5 bpm - 1,300 psi, weight on bit 2-10K. Milled thru CIBP and pushed down free to 11, 629'. 05:30 06:00 0.50 11,629 11,629 COMPZ WELCTL CIRC P Pumped 35 bbl sweep, flow rate increased. Shut well in. SIDP - 70 psi. Notified AOGCC, Chuck Sheve 0630 hrs. Will retest Annular & Choke when out of hole with drill i e. 06:00 08:00 2.00 11,629 11,629 COMPZ WELCTL CIRC P Circulate out gas bubble 4 BPM w/980 psi slowed down to 3 BPM w/600 psi. Circulate sweep back. SD monitor well, static. 08:00 09:00 1.00 11,629 12,037 COMPZ RPCOM MILL P RIH f/11,629' rotating w/80 RPM and tagged up @ 12,068' ORKB. Up wt. 155K Dwn wt 90K. Pulled 1 jt to 12,037 09:00 10:00 1.00 12,037 12,037 COMPZ RPCOM CIRC P CBU, 5 BPM w/ 1440 psi. Shut down um ,monitor well, static. ~ s~ f ~~~~~~~ l Time Logs __ Date From To Dur S De th E. De th Phase Code Subcode T Comment _ ___ _- 10:00 11:00 1.00 12,037 11,509 COMPZ RPCOM PULD P Blow down TD. POOH w/first 15 jts 3 1/2"drill pipe laying down. Hole fill accurate. SD. 11:00 12:00 1.00 11,509 11,509 COMPZ RIGMNT SLPC P Slip and cut drill line. 12:00 00:00 12.00 11,509 0 COMPZ RPCOM PULD P Continue to,POOH laying down 3 1!2"drill i e 4 3/4" DC's and milling assembl . 4/02/2009 Off loaded Baker milling tools, pulled wear ring, installed test plug and tested annular and choke valves at 250/3,500 psi, RU SWS, RIH with 7" 26# permanent "F-1"packer with SBE but could not get past 11,550' after numerous attempts, POOH LD packer assembly, R!H w/gauge ring and junk basket to 11,900' no problem, POOH LD gauge ring, RIH with packer assembly on a-line but could not get past 11,200', POOH RD SWS, MU acker assembl and started PU sin le in hole on 3 1/2" tb to 841'. 00:00 00:30 0.50 0 0 COMPZ RPCOM OTHR P Clean boot baskets, off load Baker milling tools, clean rig floor, unload i eshed. 00:30 02:00 1.50 0 0 COMPZ WELCTt BOPE P Pull wear ring, install test plug, RU test annular and choke valves at 250/3,500 si, good tests, pull test lu . 02:00 03:00 1.00 0 0 COMPZ RPCOM CIRC P RU and flush BOP stack, RD wash tool and blow down to drive. 03:00 07:30 4.50 0 11,589 COMPZ RPCOM PACK P PJSM with crew and SWS, spot and RU a-line unit, load tools, MU "F-1" packer assembly and adaptor kit, RIH with packer assembly, stacked out at 11239' (end of tools). Worked up and down attempting to get to set depth of 11,760'. Straight pick up except twice, little sticky, pulled 2K over and let go. Worked down to_ 11, 589'. 07:30 10:00 2.50 11,589 0 COMPZ RPCOM PACK P POOH and examine packer, no visible dame e. ND and stand back. 10:00 13:00 3.00 0 0 COMPZ RPCOM ELNE P MU 6.05" guage ring and junk basket and RIH on E-line. Ran dow_ n tQ,_ 11,900' with no obstructions. POOH, LD au a rin funk basket em 13:00 14:00 1.00 0 0 COMPZ RPCOM OTHR P Took out 10' pup jt on packer assembly and replaced w/2' pup jt to shorten u BHA. MU 'F-1' packer assembl and ada for kit. 14:00 21:30 7.50 0 0 COMPZ RPCOM PACK T RIH w/packer assembly on E-line to 11,200' and packer assembl will not slide down hole, made numerous attempts at different running speeds, but could not get below 11,200', POOH with packer assembl on e-line as er Well Engineer to run acker on 3 1/2" tb . RD SWS. 21:30 00:00 2.50 0 841 COMPZ RPCOM PULD T Install wear ring, MU adaptor kit and "J" hydraulic tool, PU and single in .. hole with "F-1" acker assembl on 3 1/2" tubin to 841'. ~_ .~. _ __ ~~g~ 3 of 5 • Time Logs _ _ Dat~___ From _ To Dur S Depth E. Depth Phase Code _ Subcode T Camment___ __ _____ 4/03/2009 2a hr summary Cont PU and single in hole with "F-1" packer assembly to 11,760', RU RIH and correlate depth with SWS, POOH RD SWS, set "F-1"permanent packer at 11,760', POOH stand back 3 1/2" tbg, MU FHL packer and seal assembf ,RIH with 3 1/2" com letion and 'ewel to 3,647'. 00:00 10:00 10.00 841 11,850 COMPZ RPCOM PULD T Cont PU and single in hole with "F-1" packer assembly on 3 1/2" tubing from 841' to 11 850'. 10:00 12:30 2.50 11,850 11,850 COMPZ RPCOM PACK P RU SWS E-line. RIH w/ GR/CCL. Correlated de the w/ erforation to and USIT cement log. POOH w/Eline. Dropped ball for setting F-1 acker. RD E-line unit. 12:30 14:00 1.50 11,850 11,760 COMPZ RPCOM PACK P Pulled and LD 3 jts of 3 1/2" tubing spotting packer @ 11,760' as pe correlation. Up wt 95K swm wt 65K. RU head pin, circulated 68 bbls before ball on seat. Pressure up to 2500 si and held for 5 min. to set packer. Pulled up and sheared setting tool w/10K over wt. This opened by pass and pressure dropped off releasing from packer. ND head in. 14:00 20:30 6.50 11,760 0 COMPZ RPCOM TRIP P POOH standin back 3 1/2" tubing in _ derrick, LD last 6 joints and Baker settin tool. 20:30 21:00 0.50 0 0 COMPZ RPCOM OTHR P Pull wear ring. 21:00 00:00 3.00 0 3,647 COMPZ RPCOM RCST P PJSM, MU FHL packer and seal assembly, RIH on 3 1/2" EUE tubin from derrick to 3,647', up weight 53K, down wei ht 50K. 4/04/2009 Cont RIH with 3 1/2" completion, from 3,647' to 11,760', locate SBE in F-1 packer, pull out and spot inhibited seawater between packers, sting in and press test tbg to 500 psi, set FHL packer, shear out of PBR, space out and MU hanger, pump corrosion inhibited seawater, landed hanger, RILD's, tested tbg and 7" csg, sheared SOV, set 2 way check, ND BOP, NU tree and tested same, pulled 2 way check, freeze protected well, set BPV, pulled rig off well, cleaned cellar and well site. Released Nordic Ri 3 at 22:00 hrs, on 4/4/2009 00:00 05:30 5.50 3,647 11,745 COMPZ RPCOM RCST P Cont RIH with 3 1/2" completion from 3,647' to 11,745', up weight 97K, down wei ht 65K. 05:30 06:00 0.50 11,745 11,756 COMPZ RPCOM HOSO P MU jnt # 368, MU head pin and circ hose, ease inhole and locate SBE, no-go'd 21' in on ~nt #368 at 11 7 6' confirmed with um , PU 10'. 06:00 06:30 0.50 11,756 11,756 COMPZ RPCOM CRIH P Lined up, pumped and spotted 5 bbl corrosion inhibited seawater between packers at 4 bpm - 600 psi. total 1990 strokes. 06:30 07:00 0.50 11,756 11 COMPZ RPCOM PACK P Lowered back into seals, put 500 psi to confirm seals engauged. PU to neutral wt. PU 2' off locator. Pressured up to 2500 psi to set'FH~ acker. Wait 5 min. Bled press. down to 1500 psi. PU and sheared PBR w/20K over wt. PU out of seals. ~..__-_..._.. ~"~€}~ ~ of 5 ~~ Time Logs Date From To Dur S. De th E. De t_h Phase Code Subcode T Comment 07:00 08:30 1.50 COMPZ RPCOM CRIH P Pumped 280 bbls corrosion inhibited SW chased w/102 bbls SW , 5 BPM w/690 si. 08:30 10:00 1.50 COMPZ RPCOM HOSO P Space out w/ 2-6' pup jts approximately 2' off bottom and MU 1 full jt. of tulbing immediately below the tubing hanger. Drain stack. Land tubing hanger, up weight 97K, down wei ht 65K, RILDS 10:00 11:30 1.50 COMPZ RPCOM DHEQ P RU test lines & chart recorder. Pressure u on tubin to 2500 si and held for 15 min. Bled tubin own to 2000 si. Pressure u on IA to 3000 si. held for 30 min. Bled pressure off IA, bled pressure off tubing. Pressure back up on IA and sheared SOV in GLM @ 11,506' @ 1400 si. Bled ressure to 0. 11:30 15:00 3.50 COMPZ RPCOM NUND P Set HP-BPV. ND BOPE. NU and alighn wellhead. Test tree & packoffs to 250/5,000 si. Pull HP-BPV. 15:00 21:00 6.00 COMPZ RPCOM FRZP P RU LRS, Pum ed 130 bbls die el down tubing for freeze protect X3700' MD). RU hose and let U-tube. ND hoses. Set H-BPV. RDMO. SITP = 0 si, IA = 0 si, OA = 0 si. 21:00 22:00 1.00 COMPZ MOVE RURD P Contacted DSO, backed rig off well, cleaned cellar box and well site. released Nordic Ri 3 on 4/4/2009 at 22:00 hrs. ~_®®m ~ .~. #~~~ 5 of 5 2E-05 Well Work Summary DATE SUMMARY 2/22/09 PRE-RWO, MIT CASING -PASS , T & IC POT INCONCLUSIVE DUE TO WEATHER, FUNCTION TESTED LDS'S 3/29/09 (PRE RWO) IC POT -INCONCLUSIVE. IC PPPOT -PASSED. 4/1/09 ATTEMPTED TO SET BAKER PACKER AT 11760' USING ELINE. COULD NOT PASS 11500' ON FIRST ATTEMPT IN HOLE. RAN IN HOLE WITH JUNK BASKET AND 6.05" GAUGE RING TO 11900' NO ISSUES. RAN BACK IN HOLE WITH BAKER PACKER WITH MODIFIED CONFIGURATION AND HUNG UP AT 5860'. UPON RETURNING TO SURFACE FOUND A SET SCREW BACKED OUT OF PACKER. RAN BACK IN HOLE AND COULD NOT PASS 11200' PACKER RAN IN HOLE ON TUBING AND ELINE USED TO CORRELATE. TOP OF SHORT JOINT IS 90.22' FROM MIDELEMENT. SHORT JOINT FOUND AT 11765', TO SET PACKER AT 11760' SHORT JOINT NEEDS TO BEAT 11669.8'. TUBING NEEDS TO BE PULLED UP 95.3' 4/20/09 REPLACE SOV W/ DV @ 11506' RKB. MITIA TO 3000 PSI, PASS. PRESSURED UP TBG TO SHEAR SHEAR OUT SUB IN TTL. UNABLE TO BLOW OFF WITH PRESSURE ALONE. TAP DOWN & KNOCKED OFF SOS @ 11782' RKB. TAGGED @ 12060' SLM, NO SAMPLE OBTAINED. PUMPED 30 BBLS DIESEL DOWN TBG @ 1.2 BPM @ 2100 PSI, JOB COMPLETE. • • a ~ a ~ a SARAH PALIN, GOVERNOR ALA58iA OIL A1~TD GA5 333 W. 7th AVENUE, SUITE 100 COliT5ERQATIOPIT COI~IDIISSIOPIT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jill Long Wells EngYneer ConocoPhillips Alaska Inc. PO Box 100360 (~ Anchorage AK 99510 r r~ ~' `~ `~ _ I f~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 2E-05 Sundry Number: 309-031 Dear Ms. Long: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount, Jr. Chair DATED this 3 day of February, 2009 Encl. • .~ Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 27, 2009 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7`h Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: U ~~~~ ~ ~~~ #~a~~ ## ~ ~a~ ~n~, ~,arnm~ss~~i A~~tr~r~p ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2E-05 (PTD# 193-179). Well 2E-05 was originally drilled and cased in 1993 but never completed due to concerns about poor reservoir/rock quality. The well was however perforated in both the A and C sands in 2006 and infectivity tests were performed. Examination of the surrounding pattern indicates that the producers are lacking injection support. Completing this well as a water injector will increase areal sweep efficiency and supply additional pressure support. The workover plan is to mill out the cast iron bridge plug currently in the hole and run a single selective completion. The necessary facility tie-ins will then be made post-rig workover. Attached you will find a proposed schematic and proposed procedure. If you have any questions or require any further information, please contact meat 263-4093. Sincerely, Jill ong Wells Engineer CPAI Drilling and Wells ~A '~~ ~~~~ ~~'# 4 20 AAC 25.280 anP~ 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ run completion ~~v~ ~~ Chan e a roved ro ram g pp p g ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well Q _ ~~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 193-179 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22423-00 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 Requires? Y2S ^ NO ^~ 2E-05 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): Q~~S- ADL 25664 RKB 14T ~ Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12210' . 6381' - CIBP @ 11614' Casing Length Size MD TVD Burst Collapse Conductor g0' 16" 121' 121' Intermediate 6097' 9-5/8" 6138' 3489' Production 12147' 7" 12188' 6366' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11701'-11736', 11845'-11865' 6015'-6041', 6119'-6134' none Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat February 6, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^~ - WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Long @ 263-4093 Printed Name ,fill Long Title: Weils Engineer Signature Phone 263-4093 Date Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ - ~ 3 Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: ~QQ PS ~ ~c`c3,+*1 ~ Wit- r~ ~~ pS l Mi +~~ ~`-L~ v"L O.t~~\S `G~ ~ST Subsequent Form Required: j~ ~ v - ` ~ t ~ _. APPROVED BY ~ ~ ~ I I Approved by: COMMISSIONER T E COMMISSION Date: `~~~~ • ,~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION `~ ~~~ ~~~ .~~~; 2 ~ 2009 APPLICATION FOR SUNDRY APPROVA,~~ ,~ ~~~ La>~~o ~~~rnissi~,:x M 1 Form 10-403 Revised 08006 4 } l ~ ~-. ~ ~!`~ ~ ~ Submit in Duplicate Well: 2E-05 API: 50-029-22423 'tt~}Ct?~'1j~~I~]S Field: Kuparuk PTD: 93-179 DRAFT 2009 RWO PROPOSED COMPLETION WELLHEAD Lift threads: 3'/" 8rd EUE BPV: Model: WKM Gen 4A CONDUCTOR 16", 62.5 ppf, H-40, welded SURFACE CASING 95/", 47 ppf, L-80, BTC 95/", 36 ppf, J-55, BTC PRODUCTION CASING 7", 26 ppf, L-80, BTC-MOD NEW COMPLETION A: Nipple: 2.875" DS B: Gas Lift Mandrel C: Seal Assembly D: Premier packer with SBE TUBING 3'/", 9.3 ppf, L-80, EUE 8rd PERFS C: 11,701'-11,736'MD A: 11,845-11,865' MD Last Tag: 08/06/06 Tag Depth: 12,063' SLM Fill: tag was prior to perfs TD: 12,188' RKB E: Gas Lift Mandrel F: Sliding sleeve with 2.813" profile G. Premier packer H: 2.75"D Nipple w/ RHC plug installed I. Wireline Entry Guide Last Updated: 27-Jan-09 Updated by: JWL I ,. .. Kuparuk 2E-05 Injector Workover Pre-Riq Work 1. Apply for Sundry approval 2. Pressure test casing against cast iron bridge plug to 2,500 psi. 3. Function tubing and IA packoffs and lockdown screws 4. Prepare wellsite for rig arrival. General Workover Procedure 1. Verify Sundry approval has been acquired 2. MIRU Nordic 3. Pull BPV. Ensure well is dead. Set HP-BPV. MU and run plug off tool. 3. NU and pressure test BOPE to 250/3,500 psi (The well currently has a cast iron bridge plug set at 11,614', isolating both the C and A sands. It is loaded with 9.8 ppg brine. The last SBHP measurement was 3,097 psi on 8/9/06 at 11,720' MD, mid-pert. The estimated kill weight needed would be 9.9 ppg. The calculated maximum possible surface pressure assuming a gradient of 0.1 psi/ft from mid C pert is 2,500 psi.) 4. Pull plug off tool/BPV. 5. Unland tubing hanger and remove. 6. RIH with mill BHA for milling out the cast iron bridge plug and chase into rat hole. Circulate and condition brine to 10 ppg. POOH. 7. RIH with 3-1/2" selective packers on drillpipe. 8. Drop ball and rod and set packers. Pickup out of SBE and circulate in corrosion. inhibitor. 9. POOH with drillpipe and RIH with new 3-1/2" tubing. 10. Space out and land tubing hanger. 11. Pressure test the tubing and inner annulus to 3,000 psi. 12. Set TWC and ND BOPE. 13. NU tree and test tree 14. Remove TWC, freeze protect, and set BPV 15. RDMO Nordic 3 Post-Riq Work 1. Pull BPV and SOV. Install dummy valve. 2. Pressure test tubing to 3,000 psi. 3. Pull ball and rod and RHC plug body. 4. Turn over to production engineer. '~ Guy Schwartz Wells Group Engineer Drilling & Wells ConocriP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6958 October 23, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED OCT 24&_ Alaska Oil & Gas CGns. Cûmmission Ancnttmgß Subject: Report of Sundry Well Operations for 2E-05 ~ C\"b-,\19 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent well work on the Kuparuk well 2E-05. .' Operations performed on the well inçluded perforating the Kuparuk A and C sands followed by injection testing into the individual zones. A CIBP was then set above the perforations at 11614' md. in the 7" casing. CTU then laid in 9.8 ppg brine to 2500' md and freeze protected with diesel to surface. Future plans for the well are to move in a workover rig and run a selective completion sometime next year (2007) and utilize the well as a Kuparuk injector. ý' If you have any questions regarding this matter, please contact me at 265-6958. Sq~~ ~è'~ " G. Sch~aftz Wells Group Engineer CPAI Drilling and Wells .~If"AMMC:['~) NO\5 ^ ~-:: 20n0 ;~~fiatH~~~ . _. l U ð ;... lJo GS/skad ~ ..._""......., v r::u OCT 2 4 2006 Alaska Oil & Gas Cons Cn.mm' .' . . VIS I ISSfon REPORT OF SUNDRY WELL OPERATIONS Anchorage - STATE OF ALASKA '~ ALASKA OIL AND GAS CONSERVATION COMMISSION Repair Well 0 Pull Tubing 0 Operat. ShutdownD 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB147' 8. Property Designation: ADL 25664,· ALK 473 11. Present Well Condition Summary: Total Depth measured 12210' . 6381' . true vertical Effective Depth measured true vertical Casing Structural Conductor Intermediate Production Length Size 16" 9-518" 80' 6097' 12147' 7" Perforation depth: Measured depth: 11701'-11736', 11845'-11865' true vertical depth: 6015'-6041',6119'-6134' Tubing (size, grade, and measured depth) none" MD. Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Stimulate 0 Waiver 0 o o o Other Time Extension Re-enter Suspended Well Exploratory Service o o 5. Permit to Drill Number: 193-179/306-171 6. API Number: 50-029-22423-00 9. Well Name and Number: 2E-05 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool feet feet Plugs (measured) Junk (measured) feet feet MD TVD Burst Collapse 121' 6138' 12188' 121' 3489' 6366' Packers & SSSV (type & measured depth) set CIBP @ 11614' MD to temporary suspend well until rig runs completion ./ no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) temporary injection test performed on 'A' and 'C' sand zones ,/' Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl CasinQ Pressure Tubinq Pressure Prior to well operation SI Subsequent to operation SI 14. Attachments 15. Well Class after proposed work: NONE. Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: NONE, OilO GasD WAG 0 GINJD WINJ 0 WDSPLO 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Printed Name Signature Guy Schwartz @ 265-6958 Guy Sch~aW: 67;.. ~J~ Form 10-404 Revised 04/200n R I ~ f l\1111 Title Phone Wells Group Engineer Date IO-'A3-ðÍ;; Preoared bv Sharon AI/suo-Drake 263-4612 RBDMS BFL DCl 3 1 2006 ~ö j~ '-- A /[)'77"VIp Subr:!::J» Original Only -- 2E-05 Well Events Summary .--- DATE Summa~ July 11, 2006 MITOA PASSED (INTERGRITY CHECK PRE-PERF) ./ July 13, 2006 CMIT T X IA PASSED (PRE-PERF INTEGRITY CHECK) July 16,2006 ATTEMPT TO TAG AND FIND TT TAGGED HYDRATES @ 48' SLM. UNABLE TO LOCATE TT APPEARS TO BE EITHER BELOW HYDRATE PLUG OR POSS NONE (ONLY ABLE TO LOCATE TBG. HANGER W/ TOOLS). July 24, 2006 TAG & REMOVE ICE PLUG FROM 58' CTMD TO 120' CTMD WITH HOT DIESEL.DRIFT CASING TO 4000' CTMD WHILE PUMPING DIESEL.LAY IN DIESEL FROM 4000' TO SURFACE LEFT WELL SHUT IN AND NOTIFL Y DSO OF STATUS. July 29,2006 STATE WITNESSED CMIT T&I- PASSED August 1, 2006 REMOVE ICPO INTERNAL CHECK, POT IC - PASSED, PPPOT IC - PASSED August 2,2006 ATTEMPTED TO LOCATE POSSIBLE TUBING JOINT, NONE FOUND. TAGGED BOTTOM @ 12,061' SLM. RDMO, JOB COMPLETE August 6,2006 TREE SWAP-OUT PULLED TREE AT 7-1/16" FLANGE- REMOVING CAMERON TUBING HANGER SPOOL, TUBING ADAPTER BONNET (NO TUBING HANGER IN TREE), TWO 3-1/8" TREE VAVLES. ALL DROPPED OFF AT VALVE SHOP FOR REBUILD/SERVICE REPLACED TREE WITH TWO 6-1/8" FULL OPEN VALVES WITH 7" OTIS TREE CAP. August 6,2006 DRIFT CSG W/5.96" GAUGE RING TO 12063' SLM. TEST TREE TO 2000 PSI, GOOD. BLEED BACK WELL TO 0 PSI. August 7,2006 PERFORATE INTERVAL 11721' - 11736' > GUN DATA: 4.5" OMEGA HSD PJ4505 5 SPF 72 PHASING, API ENT - 0.43", API PEN - 59.2" August 8,2006 PERFORATE INTERVAL 11701-11721' > GUN DATA: 4.5" HSD OMEGA PJ4505 5 SPF, 72 PHASING, API PEN: 59,2", API ENT: 0.43" > FLUID LEVEL AT 75' > SBHP: 11830' 2868 PSI, 156 DEGF /11670': 2810 PSI, 155 DEGF > DID NOT TAG. August 9, 2006 INJECTION TEST: PUMP SW DOWN CASING, SLOWLY INCREASE RATE AND PRESSURE TO 2500 PSI- RATE STABLES OUT AT 0.5 BPM./ SLOWLY STEP PUMP UP TO 3000 PSI- AT 1.6 BPM- PRESSURE SLOWLY DROPPING- BUMPING UP RATE 3000 PSI- RATE UP TO 2.63 BPM IN 20 MIN./ PUMP 2.63 BPM FOR 90 MINUTES WITH A 50 PSI DROP TO 2950 PSI - 350 BBLS AWAY - PRESS UP & DROP RATE TO 2.2 BPM AT 3000 PSI./ BRING PRESSURE TO 2600 PSIAND RATE STEADY AT 0.88 PSI FOR 90 MIN,/ FREEZE PROTECT TUBING WITH 95 BBLS DIESEL TO"" 2100' tvd. September 6,2006 STATIC BOTTOM HOLE PRESSURE SURVEY & A-SAND PERFORATIONS. SBHP: C SAND PRESS: 11720 FT = 3097.3 PS1I151.2 DEGF. 11625 FT = 3054.9 PSII151,5 DEGF. PERFS: (3 3/8" HSD PJ3406, 6 SPF, 60 DEG PH) 20 FT A SAND ZONE SHOT FROM 11845 -11865 FT. WELL LEFT SHUT IN. September 7, 2006 AN INJECTION PROFILE WAS PERFORMED ON 2E-05. LITTLE RED WAS USED TO INJECT FLUID. THREE RATES WERE TRIED (.4 BPM @2600 PSI, .9BPM @ 2800PSI, 1.1 BPM@ 2900 PSI). ALL RATES RESULTED IN SAME 100% C SAND SPLITS. CHECKED FOR CROSSFLOW AFTER PUMPING WAS COMPLETED, NO CROSSFLOW OBSERVED, WELL LEFT SHUT IN AND Fpt=¡::7J= PROTECTED WITH 100 BBLS DIESEL. Æg~\,;)l~_\ _ \ September 8, 2006 A BAKER 5.97" RBP WAS RUN IN HOLE TO A DEPTH OF øObl, , TOOL TAGGED UP @ 2061' MULTIPLE TIMES. PULLED TOOLS OUT OF HOLE, SLlCKLlNE TO DRIFT HOLE September 9,2006 DRIFTED CSG.. W/5.975 GAUGE RING DOWN TO 12051' SLM. TOOLS FELL SLOW BUT STEADY FROM 2100' SLM TO 3000' SLM, DRIFTED AREA AGAIN WITH SAME RESUL TS. '---- 2E-05 Well Events Summary ~' September 23, 2006 BAKER BRIDGE PLUG RAN TO 2810 FT THEN HELD UP. TOOLS STICKING AFTER BEING HELD UP. HAD TO PULL MAX (1200 LBS) TO COME OFF. TOOLS SITTING DOWN AT COLLARS. JOB POSTPONED. September 27,2006 ATTEMPT TO SET 5.97" 00 BAKER RETRIEVEABLE BRIDGE PLUG. COULD NOT GET PAST 3098' CTMD.i-COIL CCL CORRECTED DEPTH SHOW THAT TAG DEPTH COUL BE TAGGING ON COLLAR. MADE SEVERAL ATTEMPTS AT DIFFERENT SPEEDS AND DIFFERENT CASING PRESSURES. September 28,2006 SUSPEND OPERATIONS UNTIL MORE EQUIPMENT CAN BE RIG UP,GOING TO INSTALL A SET OF 7 1/16" BOP'S BEFORE TRYING TO MAKE DRIFT RUN SO LONGER TOOL STRING CAN BE RUN, September 30, 2006 DRIFTED TO 11,885' CTMD WITH 6" 00 SWAGE. WHILE RUNNING IN HOLE WITH PLUG SAT DOWN @ 3212' CTMD AND SET PLUG, PLUG LENGTH = 4.63' WITH A 5.97" 00. FISHING NECK = 2.61" 00. RETURN IN AM TO RETRIEVE PLUG, IN PROGRESS. October 1,2006 RAN IN HOLE AND LATCHED UP TO PLUG @ 3211' CTMD. HIT 4 JAR LICKS AND CAME FREE. PULLED OFF THE 2.54" 00 CATCH NUT. ABANDON JOB AND TURN OVER TO SLlCKLlNE TO RETRIEVE CATCH SLEEVE AND OVERSHOT 2.12" 00 MANDREL. **NOTE: PLUG IS NOT EQUALIZED, MAY HAVE 700# BELOW PLUG. October 2,2006 PULLED RBP (BRIDGE PLUG) @ 3204' SLM (NOTE: PIECE OF WHAT APPEARS TO BE FLIPPER DOG FELL OFF OF BRIDGE PLUG ). October 19, 2006 USED i-COIL CCL TO CORRELATE AND SET A BAKER K1-3bb CIB PLUG IN 7" ,/ CASING @ 11614' CORRECTED DEPTH.TESTED PLUG FOR 5 MINS @ 2500 PSI.LAY IN 9.8 BRINE FROM TOP OF PLUG TO 2500 FEET. LEFT WELL SHUT IN AND FREEZE PROTECTED WITH SLICK DIESEL FROM 2500' TO SURFACE. Re: 2E-05 injection test . . Thanks Guy. Persistence pays off. Good news that the project is moving forward to tie in the wells. Tom Maunder, PE AOGCC Schwartz, Guy L wrote, On 10/23/2006 3 :02 PM: Tom, We finally got a packer set to isolate the perfs on 2E-05. We gave up on running a RBP and set a CIBP. We left KWF on top of the CIBP and plan to come back sometime next year with a rig to run the selective completion. There are some surface piping issues that also have to be worked out concurrently to get this well kicked off as a KRU injector. Should see the 10-404 on your desk shortly. See you later...... Guy Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 QUy.l. schwartz@conocophiHips.com ;)tMNEtd! ¡; ,. ~, ~] 1 of 1 10/24/20067:54 AM Re: 2E-05 injection test . . Guy, I do not believe that another 403 will be necessary. Your shooting and testing the injectivity ofthe A sands is similar to what was done with the C sands and the volume pumped will be small. Please be sure that the 407 information covers the results of both intervals. Call or message with any questions. Tom Maunder, PE AOGCC Schwartz, Guy L wrote, On 8/1412006 3:46 PM: Tom, Another update for you and question..... Asset has decided it is a go for completing the well but want some more diagnostics done. They also want to perforate the A sand and see if it wiB also take injection. Will help determine if we want a selective completion or not. Do I need to submit another 403 for this work??? Work scope is as follows: 1. RU SL - get a static pressure survey of C sand. 2. RU Eline- Perf A5 sand interval (20' zone) 3. Perform another injection test (similar to last one--- 500 bbls or so) with Eline in wellbore to do an Injection profile while pumping into the A and C zones. 4. Secure well with downhole packer... .. Thanks, Guy Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 QUY .I.schwartz@conocophillips.com -----Original Message----- From: Schwartz, Guy L Sent: Friday, August 11, 2006 12:27 PM To: 'tom maunder@admin.state.ak.us' Subject: 2E-OS injection test Tom, Just wanted to update you on the injection test on this well. We pumped about 500 bbls of lof2 10/24/20067:55 AM Re: 2E-05 injection test . seawater into the well successfully.(injected about .9 bpm at 2600 psi whp) The asset is evaluating the results to decide if we can go ahead a complete as an injector. We have not done anything else.... Will set a plug/packer in the next couple of days. I'll keep you posted and let you know what options are being considered before we do anything to make sure we get the right paperwork done. . Thanks, Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 ÇJUY .1.schwartz(â2conocophillips. com 20f2 10/24/20067:55 AM 09/15/06 Schlumbergep RECEIVEr::; NO. 3959 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth SEP 1 5 2006 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ Cll & Gas Coos. Q:;íJ1fi'J~S'¡(¡j ~ " (\ 'ìi\\\t l03 - l~ SCf\NNE-tJ. ~)Er ). JFi:;; Kuparuk Uy¿ Well Job # Log Description Date BL Color CD 2A-18 11213804 LDL 09/09/06 1 1A-20 11213802 PROD PROFILE W/DEFT 09/07/06 1 3A-17 11213803 PROD PROFILE W/DEFT 09/08/06 1 1 J-156 11415621 PRODUCTION PROFILE 09/06/06 1 2A-13 11415619 PRODUCTION PROFILE 09/04/06 1 1 L-28 11213805 PROD PROFILE W/DEFT 09/10/06 1 1 L-1 0 1142164 INJECTION PROFILE 09/09/06 1 1J-102 11421625 US IT 09/11/06 1 2E-05 N/A INJECTION PROFILE 09/07/06 1 2E-05 11216326 SBHP 09/06/06 1 2U-03 11213007 INJECTION PROFILE 09/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . 08/22/06 Scblumbepgep RECE\VED NO. 3936 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 AIJG 2 3 2006 commission ~SŒ Oil & Gas Cons. . Anc1'1orage U.:I-C-,\C1·~ -11L1 Field: Kuparuk Well Color CD Job# Log Description Date BL 2E-05 11249943 SBHP SURVEY 08/08/06 1 1J-109 11235392 CBUUSIT 08/07/06 1 30-11 11213793 LDL 08/14/06 1 2T-28 11235394 INJECTION PROFILE 08/16/06 1 1 H-17 11213794 PROD PROFILE WIDEFT 08/15/06 1 1 L-22 11235395 INJECTION PROFILE 08/17/06 1 1J-166 40013010 MD VISION RESISTIVITY 01/19/06 1 1 1 J-166 40013010 TVD VISION RESISTIVITY 01/19/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~ q./-:Jc(ç ¡'--Ørq I 1 DATE: Monday, July 31,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2E-05 KUPARUK RIV UNIT 2E-05 \'\3/\1~ FROM: John Crisp Petroleum Inspector 8rc: Inspector Reviewed By: P.I. Suprv 19.~.- Comm NON-CONFIDENTIAL Permit Number: 193-179-0 Inspector Name: John Crisp Inspection Date: 7/2912006 Well Name: KUPARUK RIV UNIT 2E-05 Insp N um: mitJCr06073 II 027 II Rei Insp N um API Well Number 50-029-22423-00-00 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2E-05 IType Inj. I N I TVD 0 lA, 2300 3020 2990 2980 P.T. 1931790 iTypeTest I SPT I Test psi 3000 I OA.1 70 ISO ISO ISO Interval OTHER P/F P j Tubing I i I Notes .5 bbl pumped for PI. This is suspended weIl2E-05. 7" casing test performed to PBTD 12147 MD. 6366 TVD. I discussed the PT with Torn Maunder, data given is for 3 rd. pressure test. OA had previously beed PT & passed C/P test. (" '." t'!'.Ì ' Monday, July 31, 2006 Page I of I 2E State witnessed CMIT e e \~~-\~~ Gentlemen, Enclosed is the CMIT test results for 2E-05. This work was completed in compliance with sundry # 306-171 pre casing perforation and injection test. Let me know if you have any questions or comments. Thanks Perry Klein il Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 «MIT KRU 2E-05 7-28-06.xls» KRU 2E-05 Content-Description: MIT KRU 2E-05 7-28-06.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 1 of 1 7/31/20068:24 AM e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. West Sak I KRU 12E-05 07/28/06 Greenwood lives John Crisp Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. We1l12E-05 I Type Inj. I N TVD I Tubing 0 3090 3020 2980 2920 Interval 0 PTD.11931790 I Type test I P Test psil 3000 Casing 0 3020 2990 2980 2920 P/F F Notes: State witnessed CMIT required before perfing OA 0 150 200 200 200 Casing for injection test Weill I Type Inj. I I TVD I Tubing 2920 3050 3030 3010 Interval 0 PTD.I . I Type test I Test psil Casing 2920 3050 3030 3010 P/FI F Notes: OA 200 200 200 200 Weill I Type Inj.1 I TVD I Tubing 2300 3020 2990 2980 Interval 0 PTD.I I Type testl I Test psi I Casing 2300 3020 2990 2980 P/F P Notes: OA 70 150 150 150 Weill I Type Inj.1 TVD I Tubing Interval PTD.I I Type testl Test psil Casing P/F Notes: OA Weill I Type Inj. I TVD I Tubing Interval P.T.D.I I Type test I Test psil Casing P/F Notes: OA Weill I Type Inj.1 TVD I Tubing Interval P.T.D.I I Type testl Test psi I Casing P/F Notes: OA Weill I Type Inj.1 TVD I Tubing Interval P.T.D.I I Type testl Test psi I Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= other (describe in notes) MIT KRU 2E-05 7-28-06-2.xls lìrb LTU U l6 rñì rp ,^,î ¡'~ q H ! Þ J.iJ \... ' , ~1¡ïU! ¡i in' \~ W U U L:::3 ~7 ill I:.'. LAJ". ¡ , \ .. u FRANK H. MURKOWSKI, GOVERNOR AI.ASIiA OIL AlÐ) GAS CONSERVATION COMMISSION 333 W. "fT" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Guy Schwartz Well Engineer ConocoPhillips Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 '!J /\ 1 q \q Re: Kuparuk River Field, Kuparuk Oil Pool, 2E-05 Sundry Number: 306-171 .. A 21'\f!"" .1 (;,,~ ~u ~:,fJ Dear Mr. Schwartz: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, , ~ DATED thisli. day of May, 2006 Encl. Guy Schwartz Wells Group Engineer Drilling & Wells Conoc6Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6958 May 10, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for 2E-05 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the upcoming well work on the Kuparuk well 2E-05. If you have any questions regarding this matter, please contact me at 265-6958. zel~ G. âwartz Wells Group Engineer CPAI Drilling and Wells GS/skad Cff S ..£~,(/I" L STATE OF ALASKA (/5(,..,.... ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25 280 Y. ,...n.'.;',!,·) 1. Type of Request: Abandon D Suspend D Operational Shutdown D Perforate 0 Waiver D Other D Alter casing D Repair well D Plug Perforations D Stimulate D Time Extension D Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 193-179 . 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22423-00 " 7. KB Elevation (ft): 9. Well Name and Number: . RKB 147', Pad 106' GL 2E-05 r 8. Property Designation: 10. Field/Pool(s): ADL 25664, ALK 473 Kuparuk River Field 1 Kuparuk 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): 1221 0' 6381' Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 121' 121' Intermediate 6097' 9-5/8" 6138' 3489' Production 12147' 7" 12188' 6366' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development 0 . Service D 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 15, 2006 Oil 0 , Gas D Plugged D Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Guy Schwartz @ 265-6958 Printed Name GUY Schwartz Title: Well Engineer Signature Gk4.. C-/ Phone 265-6958 Date / ....-J Commission Use Onlv RBOMS 8Ft MAY 1 8 2006 Sundry Number: 1'1 \ Conditions of approval: Notify Commission so that a representative may witness (!J) La - Plug Integrity ci BOP Test D Mechanical Integrity Test ~ Location Clearance D Other: ~"~'--\-~\t)~~\--~ '"-~~cts,> Cctà~~~~\,)~ -\e<s:.+- I \' .. . J LÇ' ?r! of 1Ð ~ 1\\I.....tt ~ -j, I 'j <0 10M, r,.... ~ Subsequent Form Required: I' ~ c.o..f.'ð "¥')() 25. #2-. $--/t ,of:, _, / ~ ~~ COMMISSIONER APPROVED BY Approved by: THE COMMISSION Date: 01 ~crG\NM. ~ ç;. /Z·c>(,. Form 10-403 Revised 7/2005 Sub it in Duplicate ;;3--,/¡~ 1C6 2E-05 Injection Test 7 -May-2006 Background: 2E-05 is a suspended producer after C sand quality was found to be poor during 2nd phase drilling on the pad in 1994. A ten well program was shut down after 5 wells due to finding low quality oil (tar) in the Kuparuk C sand interval. 7" production casing was set and cemented. A cement bond log was logged over the 7" casing and shows good cement bond in the area of the intended perforations and as well as above the Kuparuk interval. The well has been dormant since. There is a wellhead only at surface and no riser/GL line has ever been connected. The proposed injection test on the C sand is being done to determine if the sand is floodable and would be economic to complete as an injector to help support offset Kuparuk C sand producers to the north.. AOGCC was notified of our intent to perforate and perform a temporary injection test on ./ the well without tubing in the well (fullbore through the 7" casing). A 10-403 will need to be generated before working commences. Job Objective: Perforate and perform injection test on the C sand zone. ' Well Status: · Well is currently shut-in · 7" casing in well.... No production tubing. · Will need to swap out top valve (3 1/8"?) on wellhead to a full opening valve. · Wellhead only... no tree or well house. · Wellbore has KW brine with 70 bbl diesel cap. · Max deviation is 66 deg. · WKM wellhead is rated to 5000 psi. Outline of procedure: 1) Verify drift and tag. 2) Pressure test casing to 3000 psi. ~c.c~\o...<- ~ 1:,",,:>~~,-~ç-~,,\~~ 3) Perforate C sand from 11701'- 11736' md. r:a 4) Perform injection test with Seawater. ~?tYlÇ¡I~_ 5) Set Packer or cement retainer to re-suspend well. Equipment: -Eline unit - Little Red Pumping Services (2) -SW transports (4 X 290 bbls) -KW brine (350 bbls - weight TBD) -Diesel (100 bbls) Procedure: 1. Change out top valve to full open ID valve (well is not perforated). 2. .Rig up SL and drift with 6" OD swage and tag TD. RD SL. 3. PT casing to 3000 psi for 30 min. (chart results) ---""<:)\\~'i "S:.~V~~~,~"~";¡,,, 4. RU E-line. RIH with 4.5" HSD guns with DP charges at 6spf. Perforate the df1:;r interval 11701-11736' (35' total). RBIH with pressure-temp gauge and obtain r,::> SBHP. RD E-line. 5. RU Little Red pump trucks (2 in tandem) and perform injection test (chart pressure and rate). Inject SW and slowly increase pressure to identify matrix injection rate. Inject approx. 100 bbls at matrix rate. If injection is not possible go to step 10. 6. Continue to increase pressure/rate to maximum rate obtainable and pump away remaining SW. (Limit surface injection pressure to 2500 psi. Have 4 transports available for a total of approximately 1000 bbls of fluid to pump away. ) ~ 7. Switch to KW brine (with 5% inhibitor) and pump 350 bbls away. Follow with 95 bbls diesel. Secure Wellhead and RD pump trucks and hardline. .\-0\~\ o,l ~ \~\.\S\\\ / If injection test is successful: 8. RU Eline. RIH with Junk basket /5.95" gage-ring to TD. PU 7" X 3 %" FB-1 packer with 6' tubing tail pups, 2.75" D nipple and 10' seal bore (preset a CA plug in 0 nipple to provide a barrier).. Set at 11620' md. RD Eline. 9. Pressure test plug/packer to 2500 psi. Notify AOGCC of well status and intent to re-suspend the well. (submit new 10-407???) '( '¡O~I'I ~~_ ~~ rv ( ;;I\~ If injection test is not successful: 10. If Injection test does not justify completing the well then RU CTU unit. Lay in cement plug across perforations and continue to 11600'md with cement. Swap to biozan and jet out cement to 11650' md. RD CTU. 11. Wait 24 hrs. RU SL and tag top of plug. RD SL. 12. Pressure test cement plug to 3000 psi.( Notify AOGCC of pressure test) . Submit new 10-407 outlining well status and CPAI intentions. 'V-- RE: 2E-05 Injection test What time is good for you this morning? I can come over anytime but need to scoot out by a. bout ~ 11:15am. f' \ \. _ ~\ cta "T'"-" ~~'t ~\-"'-r ~1'-.Jc \c~ O~ ~\:ICè..' +- ~ ~c...~\t Guy 4-\.....~\-- .-\-"-.(¿: \s.c~~t--... ~~> ó.~c::....~~\Q: ~ ~,~\\., ~~\;\t--.~5!. 0. ~O-C..-~~\-C)..~ ~~~'\: rl '- \ '-- '- --- .",.~ ~e.,-~~ ,~'\L ~ ~,"'"'-'\~~......-\.C)<'-.... (~. \ (~l~. \M;'j S~ \. \.. ~\ ~ ~\...e: 'a~ ~Ö,""~<ê:. , . ? \G."~~ II> T4 Q'1-~~'\'> C9.-~ (L¥--(t o..\- \t...\<... \J sc-\-4s-~ '\ ~ f'C~~~~" Wo..--.\-es---__ r ~c.D~~~ÆCJL ?~~~\, -----Origina I Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] ~ Sent: Thursday, October 27,20054:19 PM 5:fl";)-..-o~ To: Schwartz, Guy L Subject: Re: 2E-05 Injection test Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy.l.schwartz@conocophillips.com great, look forward to seeing you. Schwartz, Guy L wrote, On 10/2712005 4: 10 PM: I can bring the bond logs over tomorrow.... I'll check on the raduis by then too. Guy Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 ç uy.l.schwartz(ã2conocophillips .com -----Original Message----- From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] Sent: Thursday, October 27, 2005 3:49 PM To: Schwartz, Guy L Subject: Re: 2E-05 Injection test Guy, Can you send me a copy or bring it over. We don't have anything in the file. Having that log or the relevant portion helps support what you desire. One other question, how does the 1/4 mile radius circle look around the wellbore at the zone of interest?? Ion 5/12/20063:00 PM RE: 2E-05 Injection test 20f3 Tom Maunder, PE AOGCC Schwartz, Guy L wrote, On lO/27/2005 3:38 PM: Tom, I pulled the USIT and CST log. They show excellent cement in the area we want to perforate... 11700-11736'. There is at least 60' of excellent cement above the zone also from 11640-11700' so don't see much risk of fluid going uphole out of zone. Again, think we are looking at 1000-2000 bbls of fluid for injection for our test. Guy Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 ÇJUY .1.schwartz(ã2conocophillips. com -----Original Message----- From: Thomas Maunder rmaiito:tom maunder@admin.state.ak.us] Sent: Wednesday, October 26, 2005 2:33 PM To: Schwartz, Guy L Subject: Re: 2E-05 Injection test Hi Guy, I just did some review of the well file. It appears that "breathing" was experienced while drilling the production hole section and while casing and cementing. The file indicates they lost about 300 bbls while circulating and cementing and then gain 180 bbls after stopping pumping. It is also indicated they did not bump the plug. In one of your earlier messages you mentioned about a "cement log". Do you mean a bond log? One of those would be nice. Look forward to your reply. Tom Maunder, PE AOGCC Schwartz, Guy L wrote, On 10/26/2005 2:02 PM: Tom, Have you had time to think more about the injection test into 2E-05 down the 7" casing?? Guy Schwartz Drilling and Wells Engineer 5/12/20063:00 PM RE: 2£-05 Injection test office: 907-265-6958 Cell: 240-5696 ATO-1512 ç¡uy. . schwartz@2conocophì!!ips.com 300 5/12/20063:00 PM THE MÄ_ _TElU£ HIS COVER HAS BEpN - - 1 ll(Rl ILMED - -~- - - ~ ~ IN O"F BEFORE J ~NU \RY 03 2001 PERMIT ~ DATA ..... AOGCC Individual Well ~eological Materials Inventory T DATA_PLUS Page' I Date' 10/13/95 RUN DATE_RECVD 9'.,-179 ~D!RECT!ONAL 93-i 79 '~S~T 93-179 ~/~DN- LWD/DC -e~ ~ ~- ~., '/_- ~ ~R-LWD/DC 93-'~ 79 ~R-VER/LWD/DC ~ ,C&'~ 3-179 S!~T ( ~) 6138--12210, OH-CDR/CDN ? L 10700-12021 6000-12200 L 6000-12200 L 11300-12200 L 10700-12050 CMPS 03/14/94 01/31/94 1 01/11/94 CMPS 03/14/94 CMPS 03/14/94 CMPS 03/14/94 1 0t/11/94 Are dry ditch samples required? Was the wez= cored? yes ~%nalysis a descri~--received? yes ~nd received? ~ yes no Are well tests required? yes ~__~~ceived~ yes ~ Well is in compliance ~ initial COMMENT S ARCO Alaska, Inc. Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 March 31, 1995 Mr. David W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Johnston, Re: Suspended Well Update ARCO Alaska Inc. ("ARCO") has compiled data pertaining to the 25 suspended wells described in your August 19, 1994, letter. Any additional suspended wells which were discovered during our research are also included in this update. I have attached an update on each well and grouped the wells by geographic area. If you have any questions, please call the ARCO Contact indicated for each geographical area or me at 265-6914. Sincerely, /- ~ , ,.?'Senior Land~/en' · / // JRW:hb / finclosures · CC: M. L. Bill L. D. Brown H. R. Engel R. M. Lance T. W. McKay G. K. Phillips M. J. Reisterer ATO 1528 LAC 466 ATO 1918 ATO 1420 ATO 1202 ATO 496 ATO 1439 RECEIVED APR 1 4 1995 Alaska 0il & Gas Cons. Commission Anchora - ARCO Alaska, Inc. Is a Subsidiary of Aflanllc Richfield Company Kuparuk River Unit Page 2 RECEIVED APR 1 4 1995 ~i~ska 0il & 6as Cons, Commission ~ ,n This well does have future potential as either a producer or water iJ~j~'tr~r. Again, emerging completion technologies may provide stronger economic justification for completion in the future. Additionally, Well 1L-26 is strategically located regarding future development of the southern KRU area. Well 1L-26 is in a secure condition with 7" casing to TD which is cemented to above the top of the Kuparuk. The 7" X 9-5/8" annulus is cemented with 200 sacks of Permafrost 'C' cement with a 70 bbl Arctic Pack cap. The 7" casing is filled with kill weight brine and, as mentioned above, is not perforated. KRU Well 2E-05, APl # 50-029-22423-00, Permit # 93-0179-0 While open hole LWD logs for Well 2E-05 indicate that there is 9' of net pay in the C Sand and 6' in the A Sand, there is concern about the quality of fluid contained within that pay. Cores taken from the C Sand in Well 2E-17, 0.9 mile to the west, and from the C Sand in Well 2E-08, 1.2 miles to the northwest, contained a highly asphaltenic, non- flowable hydrocarbon. There is a large degree of uncertainty as to the flowability of hydrocarbons contained in either the A or C Sand in 2E-05. If only the A Sand contains flowable hydrocarbons, the reserves associated with that pay is limited. At this time, development of the A and C Sand reserves in Well 2E-05 have poor economics due to the fluid quality uncertainty and oil price. Nevertheless, the well does have future potential as either a producer or water injector. Completion and production of nearby wells may increase confidence as to the flowability of hydrocarbons in Well 2E-05. Geochemical studies of the fluid from the 2E-17 and 2E-08 cores may increase understanding of why and where non-flowable hydrocarbons occur within the southern Kuparuk River Unit. Advances in coiled tubing completion technology and a more favorable oil price may enable economic development of limited reserves. Well 2E-05 is in a secure condition with the 7" casing run to TD and cemented to above the top of the Kuparuk. The 7" x 9-5/8" annulus is cemented with 650 sx of ASI with a 59 bbl Arctic Pack fluid cap. The 7" casing is filled with kill weight brine and has not been perforated. KRU Well 2E-06 While open hole LWD logs for Well 2E-06 indicate that there is 19' of net pay in the C Sand and 6' in the A Sand, there is concern about the quality of fluid contained within that pay. Cores taken from the C Sand in Well 2E-17, 0.6 mile to the northeast, and from the C Sand in Well 2E-08, 1.4 miles to the north, contained a highly asphaltenic, non-flowable hydrocarbon. There is a large degree of uncertainty as to the flowability of hydrocarbons contained in either the A or C Sand in 2E-06. If only the A Sand contains flowable hydrocarbons, the reserves associated with that pay is limited. At this time, development of the A and C Sand reserves in Well 2E-06 have poor economics due to the fluid quality uncertainty and oil price. Nevertheless, the well does have future potential as either a producer or water injector. Completion and production of nearby wells may increase confidence as to the flowability of hydrocarbons in Well 2E-06. Geochemical studies of the fluid from the 2E-17 and 2E-08 cores may increase ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 August 19, 1994 David Sutter, Land Manager ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Suspended Wells Compliance with regulations Dear Mr. Sutter: ARCO Alaska Inc.- has 25 suspended wells as shown on the attached lists: ARCO SUSPENDED WELLS PRIOR TO 1980 and ARCO SUSPENDED WELL SINCE 1980. The applicable regulation is as follows: 20 AAC 25.110 SUSPENDED WELLS (a) Upon application by the operator under 20 AAC 25.105(e), the commission will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have future value as a service well. For each well on the attached lists of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above or advise as to your plans to abandon the well. Wells that meet the criteria of (a) above that you wish to maintain as suspended, as required by 20 AAC 25.110(e), must have well site inspections this year prior to snow covering the locations. · Chairman encls c: Blair Wondzell bew/llarsusp PERMIT 00-0242-0 68-0095-0 69-0036-0 73-0027-0 74-0056-0 74-0057-0 76-0013-0 76-0017-0 76-0034-0 78-0017-0 API NUMBER 029-2182~-00 029-20004-00 029-20017-00 179-20004-00 029-20150-00 029-20151-00 029-20195-00 029-20199-00 029-20208-00 029-20278-00 ARCO SUSPENDED WELLS PRIOR TO 1980 AS OF AUGUST 1994 WELL WELL WELL NAME CLASS STATUS PRUDHOE BAY UNIT OWiDW-C SER SUSP DELTA ST i EXP SUSP PUT RIV ST 1 EXP SUSP KAVIK UNIT 3 DEV SUSP DELTA ST 2 EXP SUSP GULL IS ST I EXP SUSP GULL IS ST 2 EXP SUSP HIGHLAND ST i DEV SUSP W BEACH ST 3 EXP SUSP W MIKKELSEN ST 1 EXP SUSP STATUS DATE 6/23/73 2/27/69 7/01/69 5/02/74 5/17/75 4/01/76 4/22/77 4/12/76 7/26/76 11/11/78 SECT 11 10 O7 08 35 28 28 24 25 32 TWP 10N 10N 10N 03N 11N 12N 12N llN 12N 10N R.NG 014E 016E 014E 023E 016E 015E 015E 011E 014E 019E MER U U U U U U U U U U ARCO SUSPENDED WELLS SINCE 1980 AS OF AUGUST 1994 PERMIT 60-0041-0 82-0038-0 82-0218-0 83-0181-0 84-0156-0 84-0205-0 86-0056-0 89-0013-0 89-0041-0 90-0036-0 91-0069-0 92-0065-0 93-0174-0 93-0179-0 94-0043-0 API NUMBER 133-10142-00 029-20727-00 029-20888-00 029-21056-00 029-21181-00 029-21221-00 029-20138-01 029-21912-00 029-21937-00 029-22027-00 029-22173-00 029-22261-01 029-22419-00 029-22423-00 029-20614-01 WELL WELL WELL NAME CLASS STATUS SWANSON RIV UNIT 34-15 DEV SUSP KUPARUK RIV UI~IT 1H-05 DEV SUSP I~AVIK ST I EXP SUSP HEMI SPRINGS ST 1 EXP SUSP PRUDHOE BAY UNIT DS18-11 DEV SUSP PRUDHOE BAY UNIT D811-15 DEV SUSP W BEAC~ ST 1-A SER SUSP PT MCINTYRE P1-03 EXP SUSP PT MCINTYRE P3-01 DEV SUSP KUPAEUK RIV UNIT 1L-20 DEV SUSP KUPARUK RIV UNIT 1L-26 DEV SUSP PT MCINTYRE P2-50A DEV SUSP KUPARUK RIV I/NIT 2E-17 DEV SUSP KTJPARUK RIV U~IT 2E-05 DEV SUSP PRUDHOE BaY U~IT DS12-13A DEV SUSP STATUS DATE 8/21/91 5/18/82 4/03/83 4/03/84 9/17/84 2/14/91 5/06/86 4/26/89 7/03/89 3/31/91 6/09/91 8/30/92 4/25/94 4/25/94 4/03/94 SECT 15 33 32 12 19 33 25 16 22 29 32 14 36 36 18 TWP 08N 121~ 091~ 10I~ 11N llN 12N 12N 12N 11N llN 12N llN 11N 10N 009W 010E 009E 011E 01SE 015E 014E 014E 014E 010E 010E 014E 009E 009E 015E S U U U U U U U U U U U U U U STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [] GAS I--I SUSPENDED I'~ ABANDONED [] SERVICE 2 Name of Operator 7 Permit Number 3 AdAdrResCs© Alaska, Inc 0 R I G I ~ A L 8 API9N3~IJ9erPermitj94-098 SA P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22423 4 Location of well at surface ~ ...... ~, 9 Unit or Lease Name 605' FSL, 160' FWL, SEC 36, T 11N, R 9E, UM ~ ~,~<.~, - ' KUPARUK RIVER 1488' FSI.., 2117' FEI_, SEG 6, '!' 10N, R 10E, UM~ ~,~ 2E.05 At Total Depth ~,~,~,..,o~ 11 Field and Pool 1293' FSL, 1824' FEL, SEC 6, T 10N, R 10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. RKB 147', PAD 106' GLI ADL 25664 ALK 473 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Depth, if offshore 116 No. of Completions 27-Nov-93 05-Dec-93 04/25/94(SUSP)I NA feet MSLI NA 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directionalr~Survey 20 Depth where SSSV set 21 Thickness of permafrost 12210' MD, 6381' TVD 12100' MD, 6303' MD YES ~ NO E~ NA feet MD 1600' APPROX 22 Type Electric or Other Logs Run CDR, CDN, CBT, USIT, GCT 23 CASING, LINER AND CEMENTING RECORD SE'FI'lNG DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16. 62.5# H-40 SURF 121' 24" 200 SX CMT 9.625 47#/36# J-55/L-80 SURF 6138' 12.25" 930 SX ASIII, 810 SX G 7. 26# L-80 SURF 12188' 8.5" 275 SX CLASS G CMT 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) NA NA 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24~HOUR RATE I~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NA RECEIVED MAY 1 2 1994 ~t~sl(a U~l & Oa~ C0n~. C0rnrni.,.~ion Form 10-407 "~r~0rl0ra~mit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 2§. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUEVERT. DEPTH GOR, and time of each phase. TOP OF KUPARUK C 11 704' 6017' BASE OF KUPARUK C 11704' 6017' TOP OF KUPARUK A 11 820' 61 01' BASE OF KUPARUK A 11 959' 6201' 31. LIST OF A-I-FACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEY 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed ~_/~/~~/'~k,. Title ~"~ ~)/"~ (~'¢'~, DATE INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 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 ARCO ALASKA INC. DAILY OPERATION PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 2E-05 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25664 ALK 473 50-029-22423 93-179 ACCEPT: 11/27/93 09:30 SPUD: 11/27/93 01:00 RELEASE: 12/06/93 06:00 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: 11/28/93 ( 1) PARKER 245 TD: 4121' (4121) 11/29/93 (2) PARKER 245 TD: 6165' (2044) 11/30/93 ( 3) PARKER 245 TD: 6165'( o) 12/01/93 ( 4) PARKER 245 TD: 6165'( o) DRILLING 12.25" HOLE 16"@ 121' MW:10.5 VIS: 64 <~OVE TO 2E-05. ACCEPT RIG @ 0930 HRS 11/27/93. FUNCTION TEST BAG & DIVERTER VALVES. FILL HOLE W/MUD & CHECK F/LEAKS. PU & ORIENT BHA. SPUD 12.25" HOLE @ 1300 HRS 11/27/93. DRILL TO 4121' COND MUD & HOLE 16"@ 121' MW:10.5 ViS: 44 DRILL F/4121'-4470' COND MUD & HOLE. SHORT TRIP. SERVICE TOP DRIVE. TIH. WASH F/4380'-4470' HOLE TIGHT. DRILL F/4470'-6165'_ CIRC & COND MUD & HOLE. SHORT TRIP. SWAB SLIGHTLY F/1944'-1660' CIRC & COND MUD. PREP TO WELD BELL NIPPLE 9-5/8"@ 6137' MW:10.5 VIS: 40 TOH-LD 12.25" BHA. RU TO RUN 9-5/8" CSG. HOLD SAFETY MEETING. RIH W/9-5/8" 36# J-55 CSG. 9-5/8" ELEVATOR FAILURE-CHANGE OUT. RIH W/9-5/8" 36# J-55 CSG. CIRC @ 3000' RIH W/9-5/8" 36# J-55 & 47# L-80 TO TD @ 6154'. MU CMT HD. CIRC & COND HOLE. FLUSH DS CMT LINE W/15 BBLS FW-PT TO 3500#-DROP BTM PLUG & PM]? 100 BBL FW PREFLUSH @ 6 BPM @ 600 # FOLLOWED BY 321 BBLS(930 SX) LEAD CMT FOLLOWED BY 166 BBLS TAIL CMT WHILE RECIP PIPE. DROP TOP PLUG FOLLOWED BY 20 BBLS FW. START DISPLACEMENT W/RIG PMPS. DISPLACE CMT W/445 BBLS. 30 BBLS CMT RETURN @ 11.2 PPG. BMP PLUG 2000# F/10 MIN. CIP @ 0030 HRS. UNABLE TO LD HGR WHILE RECIP. 9-5/8" SET 16' HIGH-SHOE SET @ 6138' ND 20" ANN & PRE-FLUSH ANN & DIVERTER VALVES-RD CMT HD. SET SLIPS W/100K PIPE WT. PREP TO WELD BELL NIPPLE. MU BHA #2 9-5/8"@ 6137' MW: 8.4 VIS: 28 MAKE FINAL CUT, INSTALL SLIP-ON WELD X 11-3/4 BTC NIPPLE. PRE-HEAD W/HOT HEAD, WELD NIPPLE, POST HEAT & LET COOL DOWN. TEST TO 2000 PSI FOR 20 MIN-OK. CUT DRILL LINE & CHANGE OUT SWIVEL PACKING WHILE WAITING ON COOL DOWN. MU SPEED HEAD & TORQUE TO 24,000 FT/LBS. NU 13-5/8" BOPE. SET TEST PLUG & TEST BOPE TO 300/3000 PSI. UPPER IBOP FAILED @ 300 PSI. JERRY HERRING W/AOGCC WAIVED WITNESSING TEST. PULL TEST PLUG, SET WEAR RING. RD TEST JT & BLOW DOWN LINES. CHANGE OUT UPPER IBOP VALVE. RETEST TO 300/3000 PSI. MU BHA #2. MAY '12 1994 Alaska Oil & Gas Corm. Cornmissior, Ancflora~e WELL: 2E-05 API: 50-029-22423 PERMIT: 93-179 PAGE: 2 12/02/93 (5) PARKER 245 TD:10415' (4250) 12/03/93 (6) PARKER 245 TD:11638' (1223) 12/04/93 ( 7) PARKER 245 TD:11638' ( o) 12/05/93 ( 8) PARKER 245 TD:12080' ( 442) 12/06/93 ( 9) PARKER 245 TD:12210' ( 130) DRILLING 9-5/8"@ 6137' MW: 9.0 VIS: 34 FIN MU BIT, TURBINE, MWD. OREINT & TEST. TIH TO FC. TEST CSG TO 2000 PSI FOR 30 MIN-OK. DRILL PLUGS, FC, CMT, FS, & 10' NEW FORMATION TO 6175'. CBU. RUN LOT W/8.5 PPG MUD. DID NOT BREAK DOWN FORMATION W/725 PSI. EMW=12.5 PPG. DRILL 8.5" HOLE F/6175'-10415' TIH 9-5/8"@ 6137' MW: 9.9 VIS: 40 DRILL F/10415'-11638' FIN CIRC 10.1 PPG MUD AROUND. <~TARTED LOSING RETURNS, CUT MUD WT TO 9.8 PPG & CIRC 16 PPB LCM. LOST A TOTAL OF 125 BBLS-SHUT DOWN PUMPS & MONITOR WELL-FLOWED BACK 85 BBLS. POOH. DOWN LOAD SOURCE & LD BHA & TURBINE. MU ROTARY ASSY. INSTALL RADIOACTIVE SOURCE & RIH SLOW. FILL PIPE EVERY 3000' TIH 9-5/8"@ 6137' MW: 9.9 VIS: 43 ATTEMPT TO CIRC-LOST 134 BBLS W/NO RETURNS. POOH. TIGHT @ 11210', & 10850' ATTEMPT TO CIRC @ 10000', 9000', 7500', & @ THE SHOE. NO RETURNS. FIN POOH F/SHOE. REMOVE SOURCE & LD STAB. HOLE DID NOT TAKE ANY FLUID UNTIL 100 STDS HAD BEEN PULLED. CLEAN OFF STAB. PROGRAM FRT & INSTALL SOURCE. TIH. CBU. FULL RETURNS W/NO LOSSES. SLIP & CUT DRILL LINE. TIH. CBU. NO LOSSES @ 6 BPM @ 800 PSI. DRILLING 9-5/8"@ 6137' MW:10.0 VIS: 44 FIN TIH. BROKE CIRC @ 10800' CIRC & COND MUD. TIGHT & PACKING OFF F/11410'-11637'. WORK PIPE FREE. 20' FILL ON BTM. SHORT TRIP-30 STDS. TIGHT F/11475'-10800' SERV RIG & TOP DRIVE. TIH SLOW. LOST A TOTAL OF 12 BBLS. CIRC & COND MUD. LOST 70 BBLS WHILE CIRC, THEN HOLE STAB. DRILL 8.5" HOLE F/11638'-11715'. CBU TO CATCH MUD SAMPLES AT TOP C SAND. DRILL 8.5" HOLE F/11715'-12080' NO LOSSES WHILE DRILLING. RUNNING 7" CSG 7"@12188' MW:10.0 VIS: 42 DRILL 8.5" HOLE F/12080'-12210' POOH 17 STDS-NO TIGHT SPOTS. TIH. CIRC & COND MUD TO RUN CSG. POOH. RETRIEVE SURVEY, REMOVE SOURCE, & LD BHA. PULL WEAR RING. RU CSG TOOLS & HOLD SAFETY MEETING. RUN 7" CSG. RECEIVED MAY ] 2 1994 ~taska Oil & ~as Cons. Commission Anchorage WELL: 2E-05 API: 50-029-22423 PERMIT: 93-179 PAGE: 3 12/07/93 (10) PARKER 245 TD:12210' ( o) FINAL REPORT 7"@12188' MW:10.0 VIS: 0 FIN RUNNING 7" CSG BROKE CIRC @ 7536', 9031', 10523'. LOST 100 BBL$ WHIL~ CIRC. WORK THROUGH BRIDGE @ 10582' CIRC & COND MUD. PACKED OFF. WORKED PIPE & REGAINED CIRC W/PARTIAL RETURNS. RU DOWELL, FLUSH LINES W/WATER & TEST TO 4000 PSI. PMP 20 BBLS PREFLUSH. CMT W/275 SX CLASS G CMT. FLUSH LINES & DISPLACE W/459 BBLS BRINE. DID NOT BMP PLUG. FLOATS HELD. CIP @ 16:40 HRS 12/06/93. LOST + 300 BBLS TOTAL WHILE CIRC & CEMENTING. MONITOR WELL UNTIL STAB-FLOWED BACK +180 BBLS. PU STACK & SET SLIPS W/290, ~-900#. MAKE ROUGH CUT. LD LANDING JT, & SET BOPE BACK. MAKE FINAL CUT. INSTALL PACKOFF & LOWER TREE ASSY. TEST TO 3000 PSI FOR 15 MIN-OK. FREEZE PROTECT 2E-05 W/200 BBLS WATER & 70 BBLS DIESEL. FINAL PRESS=900 PSI @ 4 BPM. LD DP & CLEAN MUD PITS. 12/19/93 (11) DOWELL TD-12210 DO ARCTIC PACK JOB. 7"@12188' SIGNATURE: DATE: RECEIVED MAY 1 2 1994 u~ & Gas Cons. Commission Ancimrage SUB-SURFACE DIRECTIONAL F'~UiDANCE [~]ONTINUOUS SURVEY RECEIVED ~JooL MAY 12 1994 A~aska Oil & Gas Cons. Commission Anchorage Company ARCO ALASKA, INC. Well Name 2E-05 (605'FSL,160'FWL,SEC.36, T11N, R9E,UM) F]oldlLocatlorl KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 94003 Lo{3oed FORMICA Date · 19-DEC- 1993 Computed B~ SINES SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 2E-05 KUPARUK NORTH SLOPE, ALASKA SURVEY DATE: 19-DEC-1993 ENGINEER: FORMICA METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 60 DEG 16 MIN EAST COMPUTATION DATE' 17-JAN-94 PAGE I ARCO ALASKA, INC. 2E-05 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY- 19-DEC-1993 KELLY BUSHING ELEVATION' 147.00 FT ENGINEER' FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 -147 O0 99 98 -47 199 98 52 299 97 152 399 83 252 499 42 352 598 67 451 697 23 550 795 01 648 891.72 744 0 0 N 0 0 E 02 0 12 S 71 42 E 98 0 24 N 77 48 E 97 1 31 S 82 50 E 83 4 8 S 71 34 E 42 5 58 S 58 22 E 67 8 32 S 53 35 E 23 10 57 S 52 17 E 01 13 23 S 50 15 E 72 16 32 S 53 22 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 -0.05 0.38 1.46 6 34 15 28 37 41 44 12 64 76 89 85 0 O0 0 03 0 O0 0 0'1 0 o3 0 O2 0 02 0 O3 0 O2 0 O3 0 oo N 0 05 N 0 12 N 0 14 N 0 91S 4 94 S 11 83 S 22 O1S 35 14 S 51 04 S 0.00 E 0.03 W 0 0.51E 0 1.76 E 1 6.78 E 6 14.78 E 15 24.80 E 27 38.24 E 44 54.51E 64 74.32 E 90 0 oo N 0 0 E 05 N 29 25 W 52 N 76 16 E 77 n 85 33 E 84 S 82 24 E 58 S 71 30 E 48 S 64 30 E 12 S 60 4 E 86 S 57 12 E 16 S 55 31E 1000 GO 1100 1200 1300 1400 1500 1600 1700 1800 1900 O0 1078 O0 1167 O0 1253 O0 1337 O0 1419 O0 1501 OO 1580 O0 1655 O0 1724 23 931 67 1020 82 1106 49 1190 79 1272 12 1354 29 1433 13 1508 32 1577 986 26 839 26 21 24 23 24 19 67 28 28 82 32 3 49 34 3 79 35 3 12 36 30 29 39 30 13 44 11 32 48 16 S 58 45 E S 57 52 E S 56 39 E S 57 25 E S 56 51E S 56 41E S 56 28 E S 56 55 E S 57 47 E S 58 I E 122 25 161 46 206 06 256 72 311 41 368 10 426 17 487 ll 553 29 625 41 0 O5 0 04 0 04 0 04 0 O2 0 01 0 O1 0 03 0 04 0 O5 68 97 S 101 40 E 122 63 S 55 47 E 89 113 141 170 202 234 267 303 341 46 S 134 84 S 172 40 S 214 98 S 260 20 S 3O8 20 S 357 83 S 407 68 S 463 89 S 524 84 E 161 29 E 206 89 E 257 97 E 311 42 E 368 02 E 426 99 E 488 73 E 554 96 E 626 82 S 56 26 E 5O S 56 33 E 23 S 56 39 E 99 S 56 46 E 79 S 56 45 E 98 S 56 44 E 05 S 56 43 E 32 S 56 47 E 48 S 56 55 E 2000.00 1788 71 1641 71 51 35 2100.00 1849 '2200.00 1905 2300.00 1957 2400.00 2004 2500.00 2048 2600.00 2090 2700.00 2129 04 1702 29 1758 12 1810 90 1857 30 1901 42 1943 29 1982 04 53 57 29 57 18 12 59 59 90 62 43 30 64 53 42 66 2 29 67 31 2800.00 2167.34 2020.34 67 45 2900.00 2204.91 2057.91 68 6 S 57 55 E S 57 36 E 781 S 58 6 E 864 S 59 45 E 949 S 60 43 E 1037 S 60 44 E 1127 S 60 44 E 1218 S 61 14 E 1310 S 61 3 E 1402 S 60 53 E 1495 701 83 49 07 56 39 47 16 28 75 42 0 04 0 o3 0 o3 0 o3 0 O3 0 O3 0 O2 0 O0 0 O0 0 O0 382 38 S 589.84 E 702 94 S 57 3 E 424 469 513 556 600 645 689 734 98 S 657.25 E 782 03 S 727.19 E 865 09 S 800.47 E 950 53 S 876.81 E 1038 54 S 955.41 E 1128 10 S 1034.40 E 1219 58 S 1115.08 E 1311 25 S 1196.06 E 1403 779.20 S 1277.10 E 1496 68 S 57 7 E 33 S 57 11E 80 S 57 20 E 52 S 57 36 E 48 S 57 51E 07 S 58 3 E 08 S 58 16 E 45 S 58 27 E 04 S 58 37 E 3000 O0 2242 02 2095.02 68 15 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 2279 O0 2317 O0 2357 O0 2397 O0 2438 O0 2480 O0 2521 O0 2563 oo 2605 27 2132.27 68 5 21 2170.21 66 52 11 2210.11 66 16 70 2250.70 65 51 71 2291.71 65 42 06 2333.06 65 28 72 2374.72 65 19 70 2416.70 65 6 79 2458.79 65 11 S 60 42 E 1588 27 S 60 31E 1681 S 61 26 E 1773 S 61 45 E 1865 S 61 27 E 1956 S 61 29 E 2O47 S 61 6 E 2138 S 60 49 E 2229 S 60 44 E 2320 S 61 0 E 2411 O7 59 25 62 8O 84 74 5O 21 0 O0 0 O0 0 O1 00l 00l 0 O1 0 O0 o oo o oo o oo 824.53 S 1358 15 E 1588 84 S 58 44 E 870 08 S 1439 915 958 1002 1045 1089 1133 1178 1222 28 S 1519 69 S 1600 20 S 1680 77 S 1760 53 S 1840 73 S 1920 05 S 1999 29 S 2078 O0 E 1681 59 S 58 50 E 73 E 1774 07 S 58 56 E 50 E 1865 66 S 59 5 E 86 E 1956 97 S 59 12 E 98 E 2048 10 S 59 18 E 83 E 2139.10 S 59 23 E 27 E 2229.98 S 59 27 E 48 E 2320.71 S 59 30 E 67 E 2411.40 S 59 33 E ARCO ALASKA, INC. 2E-05 KUPARUK NORTH SLOPE, ALASKA COMPUTATION DATE: 17-JAN-94 PAGE 2 DATE OF SURVEY: 19-DEC-1993 KFILY BUSHING ELEVATION: 147.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG HIM DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 2646 93 2499 93 66 4 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 2687 83 2540 O0 2729 43 2582 O0 2771 65 2624 O0 2812 39 2665 O0 2852 48 2705 O0 2889 74 2742 O0 2926.24 2779 O0 2963.60 2816 83 65 35 43 65 13 65 65 1 39 66 22 48 66 56 74 68 41 24 68 22 60 67 49 O0 3001.58 2854.58 67 37 S 61 55 E 2502 33 S 61 57 E 2593 S 61 57 E 2684 S 61 23 E 2775 S 60 19 E 2866 S 60 38 E 2957 S 61 24 E 3050 S 61 32 E 3143 S 61 41E 3236 S 61 42 E 3329 54 44 06 37 99 77 85 58 06 0 O1 0 O1 0 O1 0 O1 0 O1 0 O0 0 O1 0 O1 0 O1 0 O0 1265 84 S 2158 73 E 2502 49 S 59 37 E 1308 1351 1394 1439 1484 1529 1573 1617 1661 68 S 2239 31E 2593 48 S 2319 54 E 2684 35 S 2399 41E 2775 07 S 2479 03 E 2866 36 S 2558 66 E 2958 14 S 2639 94 E 3050 61S 2721.72 E 3143 68 S 2803.35 E 3236 58 S 2884.78 E 3329 67 S 59 42 E 54 S 59 46 E 14 S 59 50 E 45 S 59 52 E 05 S 59 53 E 82 S 59 55 E 89 S 59 58 E 61 S 60 1E 08 S 60 4 E 5000 O0 3039 65 2892 65 67 31 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 3078 O0 3117 O0 3156 O0 3196 O0 3236 O0 3275 O0 3315 O0 3354 O0 3394 12 2931 12 67 14 O1 2970 O1 66 54 54 3009 54 66 35 60 3049 60 66 8 53 3089 53 66 55 80 3128.80 66 49 10 3168.10 66 58 26 3207.26 66 43 04 3247.04 66 33 S 61 38 E 3421 50 S 61 46 E 3513 S 62 8 E 3605 S 62 19 E 3697 S 62 3O E 3789 S 63 9 E 3880 S 63 26 E 3972 S 63 27 E 4064 S 63 29 E 4156 S 63 2 E 4247 78 87 67 23 82 66 47 35 95 0 O0 0 O0 0 O0 0 O0 0 O0 0 01 o 01 0 O0 0 O0 0 O0 1705.52 S 2966 14 E 3421 52 S 60 6 E 1749.29 S 3047 1792.68 S 3128 1835.46 S 3209 1877 91S 3291 1919 83 S 3372 1961 15 S 3454 2002 27 S 3537 2043 43 S 3619 2084 46 S 3701 40 E 3513 67 E 3605 96 E 3697 15 E 3789 70 E 3880 85 E 3972 10 E 4064 40 E 4156 46 E 4248 79 S 60 9 E 87 S 60 11E 67 S 60 14 E 23 S 6O 17 E 83 S 6O 21E 67 S 60 25 E 50 S 60 29 E 40 S 60 33 E 03 S 60 37 E 6000 O0 3433.75 3286 75 66 39 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 3473.51 3326 O0 3513 99 3366 O0 3554 32 3407 O0 3594 27 3447 O0 3634 12 3487 O0 3673 82 3526 O0 3713 34 3566 O0 3752 44 3605 O0 3791 41 3644 51 66 34 99 66 7 32 66 19 27 66 30 12 66 35 82 66 37 34 66 53 44 67 3 41 67 5 S 61 47 E 4339 69 S 62 17 E 4431 S 62 39 E 4522 S 62 32 E 4614 S 62 28 E 4705 S 62 28 E 4797 S 62 50 E 4889 S 63 0 E 4980 S 62 57 E 5072 S 62 48 E 5164 40 77 2O 81 46 16 92 86 86 0 O1 0 01 0 O0 o oo 0 O0 0 oo 0 O0 0 oo o oo 0 O0 2127 54 S 3782 49 E 4339 78 S 60 39 E 2170 2212 2254 2297 2339 2381 2423 2465 2507 54 S 3863 77 S 3944 90 S 4025 27 S 4107 70 S 4188 96 S 4269 74 S 4351 58 S 4433 55 E 4431 65 E 4522 88 E 4614 18 E 4705 49 E 4797 96 E 4889 77 E 4981 75 E 5073 60 S 4515.70 E 5165 51 S 6O 4O E 9O S 6O 43 E 36 S 60 45 E 99 S 60 47 E 67 S 6O 49 E 41 S 60 51E 21 S 60 53 E 19 S 6O 55 E 23 S 60 57 E 7000.00 3830 87 3683.87 66 32 7100.00 3870 7200.00 3911 7300.00 3952 7400.00 3994 7500.00 4036 7600.00 4078 7700.00 4120 7800.00 4162 7900.00 4204 84 3723 84 66 12 57 3764 77 3805 24 3847 53 3889 78 3931 87 3973 68 4015 44 4057 57 65 50 77 65 33 24 65 20 53 64 54 78 65 4 87 65 11 68 65 22 44 65 10 S 62 47 E 5256 66 S 63 10 E 5348 22 S 63 38 E 5439 41 S 63 54 E 5530 36 S 64 15 E 5621 16 S 64 38 E 5711 53 S 64 43 E 5801.90 S 64 49 E 5892.33 S 64 56 E 5982.88 S 65 6 E 6073.44 O. O0 0.01 0.01 0. O0 O. O0 O. O0 0 O0 0 O0 0 O0 0 O0 2549 71S 4597.37 E 5257 07 S 60 59 E 2591 2632 2672 2712 2751 2790 2828 2867 2905 41 S 4679 O0 E 5348 20 S 4760 52 S 4842 26 S 4924 32 S 5006 12 S 5087 81 S 5170 38 S 5252 83 S 5334 71E 5439 42 E 5530 28 E 5621 05 E 5712 96 E 5802 O1E 5893 26 E 5983 58 E 6074 68 S 61 1E 93 S 61 4 E 95 S 61 6 E 82 S 61 9 E 29 S 61 12 E 77 S 61 16 E 31 S 61 19 E 98 S 61 22 E 67 S 61 25 E COMPUTATION DATE' 17-JAN-94 PAGE 3 ARCO ALASKA, INC. 2E-05 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY' 19-DEC-1993 KELLY BUSHING ELEVATION' 147.00 FT ENGINEER' FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000 O0 4246 52 4099.52 65 7 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 4287 O0 4328 O0 4369 O0 4409 O0 4449 O0 4490 O0 4530 O0 4570 O0 4610 82 4140.82 65 57 53 4181.53 66 1 11 4222.11 66 6 57 4262.57 66 12 87 4302.87 66 18 05 4343.05 66'20 12 4383.12 66 24 10 4423.10 66 26 11 4463.11 66 25 S 65 0 E 6163 82 S 63 34 E 6254 S 63 43 E 6345 S 63 46 E 6437 S 63 50 E 6528 S 63 55 E 6619 S 64 6 E 6711 S 64 15 E 6802 S 64 26 E 6893 S 64 33 E 6985 69 88 10 38 72 10 51 94 34 0 O0 00l 00l 0 O1 0 O0 0 O0 0 O0 0 oo 0 O0 0 O0 2943 95 S 5416 89 E 6165.19 S 61 29 E 2983 3024 3064 3105 3145 3185 3225 3265 3304 77 S 5498 33 S 5580 78 S 5662 17 S 5744 49 S 5826 68 S 5909 60 S 5991 30 S 6074 78 S 6156 80 E 6256.17 S 61 31E 64 E 6347.45 S 61 33 E 59 E 6438 77 S 61 35 E 64 E 6530 16 S 61 36 E 80 E 6621 61 S 61 38 E 08 E 6713 11 S 61 40 E 55 E 6804 64 S 61 42 E 17 E 6896 21 S 61 44 E 88 E 6987 75 S 61 46 E 9000 O0 4650 42 4503.42 65 54 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 4691 O0 4731 O0 4772 O0 4813 O0 4854 O0 4895 O0 4936 O0 4976 O0 5017 16 4544 16 66 1 84 4584 63 4625 48 4666 38 4707 23 4748 O0 4789 84 4829 82 4870 84 65 57 63 65 56 48 65 51 38 65 53 23 65 55 O0 65 55 84 65 52 82 65 42 S 63 3 E 7076 65 S 62 .56 E 7167 S 63 4 E 7259 S 63 12 E 7350 S 63 26 E 7441 S 63 32 E 7532 S 63 34 E 7623 S 63 39 E 7714 S 63 47 E 7805 S 63 53 E 7897 88 13 32 47 58 71 86 98 03 0 O0 0 O1 0 O1 0 O0 0 O0 0 O0 0 O0 o O0 0 O0 0 O0 3344 82 S 6239 16 E 7079 19 S 61 48 E 3386 3427 3469 3510 355O 3591 3632 3672 3712 39 S 6320 87 S 6401 15 S 6483 15 S 6564 91S 6646 59 S 6728 18 S 6810 63 S 6891 92 S 6973 47 E 7170 86 E 7261 30 E 7353 85 E 7444 50 E 7535 21E 7626 O0 E 7718 83 E 7809 67 E 7900 50 S 61 49 E 83 S 61 50 E 11 S 61 51E 36 S 61 52 E 58 S 61 53 E 82 S 61 54 E 09 S 61 56 E 32 S 61 57 E 50 S 61 58 E 10000 O0 5058 98 4911.98 65 39 10100 10200 10300 10400 10500 10600 10700 10800 10900 O0 5100 O0 5141 O0 5183 O0 5225 O0 5269 O0 5316 O0 5366 O0 5419 O0 5476 30 4953.30 65 31 72 4994.72 65 36 12 5036.12 65 34 07 5078 07 64 55 06 5122 06 63 17 08 5169 08 61 9 09 5219 09 59 0 70 5272 70 '56 35 14 5329 14 54 58 S 64 1E 7987 97 S 64 5 E 8078 S 64 14 E 8169 S 64 24 E 8260 S 63 40 E 8351 S 64 7 E 8440 S 63 44 E 8528 S 63 0 E 8615 S 62 23 E 8699 S 61 47 E 8782 84 65 45 O2 65 73 2O 55 O6 0 O0 0 oo 0 O0 0 oo 0 oo 0 O1 0 02 0 02 0 02 0 02 3752 91 S 7055 56 E 7991 58 S 61 59 E 3792 3832 3871 3911 3951 3990 4029 4068 4107 77 S 7137 45 S 7219 91S 7301 66 S 7382 18 S 7463 13 S 7542 17 S 7620 22 S 7694 19 S 7767 44 E 8082 36 E 8173 39 E 8264 99 E 8355 63 E 8444 81E 8533 10 E 8619 93 E 8704 70 E 8786 58 S 62 1 E 54 S 62 2 E 50 S 62 4 E 21 S 62 5 E 97 S 62 6 E 18 S 62 7 E 76 S 62 8 E 16 S 62 8 E 7O S 62 8 E 11000 O0 5534 75 5387 75 53 16 11100 O0 5595 11200 O0 5659 11300 O0 5725 11400 O0 5795 11500 O0 5867 11600 O0 5941 11700.00 6014 11800.00 6086 11900.00 6158 79 5448 39 5512 72 5578 07 5648 67 5720 64 5794 56 5867 63 5939 71 6011 79 51 26 39 49 23 72 47 15 07 44 32 67 42 17 64 42 47 56 43 36 63 44 3 71 43 44 S 61 32 E 8863.06 S 60 27 E 8942.25 S 60 2 E 9019.42 S 60 40 E 9094 24 S 60 23 E 9166 27 S 60 31E 9235 02 S 60 37 E 9302 31 S 59 22 E 9370 75 S 58 37 E 9440 05 S 57 50 E 9509.32 O. 02 O. 02 O. 02 0 02 0 02 0 03 0 O1 0 O1 0 O1 0 O1 4145 60 S 7839.03 E 8867 72 S 62 8 E 4184 4222 69 S 7975 4259 92 S 8039 4295 09 S 8102 4329 11S 8162 4362.24 S 8221 4395.89 S 8280 4431.74 S 8340 4468.29 S 8398 18 S 7908 20 E 8946 07 E 9024 97 E 9098 84 E 9170 58 E 9239 15 E 9306 74 E 9375 07 E 9444 90 S 62 7 E 02 S 62 6 E 80 S 62 5 E 81 S 62 4 E 53 S 62 4 E 80 S 62 3 E 21 S 62 2 E 43 S 62 I E 97 E 9513.59 S 61 59 E COMPUTATZON DATE: 17-JAN-94 PAGE 4 ARCO ALASKA, INC. 2E-05 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 19-DEC-1993 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 12000.00 6231.06 6084.06 43 54 S 56 6 E 9578.25 12100.00 6302.55 6155.55 44 32 S 54 0 E 9647.81 12200.00 6373.83 6226.83 44 32 S 54 0 E 9717.52 12210.00 6380.96 6233.96 44 32 S 54 0 E 9724.49 0.01 4505.72 S 8456.97 E 9582.37 S 61 57 E 0.00 4546.32 S 8513.90 e 9651.71 S 61 54 E 0.00 4587.55 S 8570.63 E 9721.18 S 61 50 E 0.00 4591.68 S 8576.30 E 9728.13 S 61 50 E COMPUTATION DATE: 17-JAN-94 PAGE 5 ARCO ALASKA, INC. 2E-05 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 19-DEC-1993 KELLY BUSHING ELEVATION: 147.00 FT INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 0 26 839.26 21 24 71 1641.71 51 35 02 2095.02 68 15 93 2499.93 66 4 65 2892.65 67 31 75 3286.75 66 39 87 3683.87 66 32 52 4099.52 65 7 42 4503.42 65 54 ENGINEER: FORMICA VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 -147.00 O0 986 O0 1788 O0 2242 O0 2646 O0 3039 O0 3433 oo 3830 O0 4246 OO 4650 0 O0 25 83 27 33 50 69 66 82 65 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 90O0 N 0 0 E S 58 45 E 122 S 57 55 E 701 S 60 42 E 1588 S 61 55 E 2502 S 61 38 E 3421 S 61 47 E 4339 S 62 47 E 5256 S 65 0 E 6163 S 63 3 E 7076 10000.00 5058.98 4911.98 65 39 11000.00 5534.75 5387.75 53 16 12000.00 6231.06 6084.06 43 54 12210.00 6380.96 6233.96 44 32 S 64 1E 7987.97 S 61 32 E 8863.06 S 56 6 E 9578.25 S 54 0 E 9724.49 0 O0 0 O5 0 O4 0 O0 0 01 0 O0 0 01 0 O0 0 O0 0 O0 0 O0 N 68 382 824 1265 1705 2127 2549 2943 3344 97 S 101 38 S 589 53 S 1358 84 S 2158 52 S 2966 54 S 3782 71S 4597 95 S 5416 82 S 6239 40 E 122 84 E 702 15 E 1588 73 E 2502 14 E 3421 49 E 4339 37 E 5257 89 E 6165 16 E 7079 0 O0 E 0 O0 N 0 0 E 63 S 55 47 E 94 S 57 3 E 84 S 58 44 E 49 S 59 37 E 52 S 60 6 E 78 S 60 39 E 07 S 60 59 E 19 S 61 29 E 19 S 61 48 E O. O0 O. 02 0.01 O. O0 3752.91S 7055.56 E 7991.58 S 61 59 E 4145.60 S 7839.03 E 8867.72 S 62 8 E 4505.72 S 8456.97 E 9582.37 S 61 57 E 4591.68 S 8576.30 E 9728.13 S 61 50 E COMPUTATION DATE' 17-dAN-94 PAGE 6 ARCO ALASKA, INC. 2E-05 KUPArUK NORTH SLOPE, ALASKA DATE OF SURVEY' 19-DEC-1993 KELLY BUSHING ELEVATION' 147.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 0 N 0 0 E O0 0 19 N 79 55 E O0 0 38 N 87 34 E O0 2 57 S 80 53 E O0 5 8 S 63 19 E O0 6 46 S 55 43 E O0 9 38 S 52 57 E O0 11 57 S 51 6 E O0 14 40 S 50 57 E O0 19 25 S 57 3 E 0 O0 -147 O0 147 O0 0 247 O0 100 347 O0 200 447 O0 300 547 O0 400 647 O0 500 747 O0 600 847 O0 700 947 O0 800 ENGINEER' FORMICA 0 O0 147 02 247 02 347 07 447 33 547 87 648 95 750 78 853 58 958 10 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.13 0.69 3.20 10 17 20 55 35 09 $4 o8 77 52 107 63 O. O0 0 O2 0 O0 0 O2 0 O3 0 O2 0 03 0 O1 0 O2 0 04 0 O0 N 0 05 N 0 18 N 0 14 S 2 43 S 7 82 S 16 48 S 28 25 S 43 39 S 61 23 S 0 O0 E 0 18 E 0 90 E 3 61 E 10 32 E 19 19 E 31 O0 E 46 14 E 64 50 E 88 0 O0 N 0 0 E 0 0 3 lO 20 35 54 77 98 E 108 19 N 73 57 E 92 N 78 44 E 61 S 87 44 E 6O S 76 44 E 73 S 67 49 E 11 S 62 0 E 10 S 58 31E 73 S 56 4 E 01 S 55 28 E 1065 83 1047 O0 , 900 O0 23 39 1176 1291 1411 1533 1657 1788 1934 2096 2279 60 1147 95 1247 50 1347 28 1447 38 1547 75 1647 31 1747 53 1847 90 1947 O0 1000 O0 1100 O0 1200 O0 1300 O0 1400 O0 1500 O0 1600 O0 1700 O0 1800 O0 27 36 O0 31 47 O0 34 19 O0 35 16 O0 37 44 O0 43 28 O0 49 4 O0 53 54 O0 59 34 S 58 31E S 56 36 E S 57 27 E S 56 45 E S 56 47 E S 56 34 E S 57 37 E S 58 6 E S 57 35 E S 59 30 E 147 60 195 11 252 46 317 86 387 23 460 55 545 53 651 13 778 68 932 19 0 05 0 04 0 04 0 O2 0 O1 0 O2 0 O4 0 O4 0 O3 0 O3 82 15 S 123 06 E 147.96 S 56 16 E 107 139 174 212 253 299 355 423 504 80 S 163 10 S 211 52 S 266 72 S 324 22 S 385 53 S 457 51S 546 47 S 654 31S 785 12 E 195.52 S 56 32 E 29 E 252.97 S 56 39 E 37 E 318.45 S 56 46 E 44 E 387.96 S 56 45 E 75 E 461.44 S 56 43 E 17 E 546.55 S 56 46 E 80 E 652.21 S 56 58 E 88 E 779.87 S 57 7 E 49 E 933.44 S 57 18 E 2496.95 2047 O0 1900.00 64 54 2746.42 2147 '3013.45 2247 3274 85 2347 352O 10 2447 3760 33 2547 4000 16 2647 4241 81 2747 4486 08 2847 O0 2000.00 67 38 O0 2100.00 68 13 O0 2200.00 66 22 O0 2300.00 65 38 O0 2400.00 65 7 O0 2500.00 66 4 O0 2600.00 65 2 O0 2700.00 66 33 4755.82 2947.00 2800.00 68 I S 60 44 E 1124 70 S 61 7 E 1353 S 60 42 E 1600 S 61 51E 1842 S 61 25 E 2066 S 60 46 E 2284 S 61 55 E 2502 S 61 54 E 2722 S 60 27 E 2945 S 61 41E 3195 19 76 23 11 52 48 37 19 65 0 O3 0 O0 0 O0 0 O1 0 01 0 O0 0 O1 0 01 0 O0 0 O1 599 19 S 953 O0 E 1125.71 S 57 50 E 710 28 S 1152 67 E 1353.94 S 58 22 E 830 64 S 1369 04 E 1601.32 S 58 45 E 947 79 S 1580 20 E 1842.65 S 59 3 E 1054 54 S 1777 07 E 2066.40 S 59 19 E 1160 47 S 1968 08 E 2284.74 S 59 28 E 1265 91 S 2158 87 E 2502.64 S 59 37 E 1369.34 S 2353.02 E 2722.46 S 59 48 E 1478.08 S 2547.52 E 2945.26 S 59 53 E 1598.26 S 2767.31 E 3195.69 S 59 59 E 5019.21 3047.00 2900.00 67 29 5275 96 3147 O0 3000.00 66 39 5526 5781 6033 6281 6532 6786 7040 7286 72 3247 57 3347 37 3447 80 3547 42 3647 06 3747 51 3847 03 3947 O0 3100.00 66 56 O0 3200.00 66 49 O0 3300.00 66 34 O0 3400.00 66 16 O0 3500.00 66 37 O0 3600.00 67 1 O0 3700.00 66 32 O0 3800.00 65 35 S 61 39 E 3439.25 S 62 17 E 3675.61 S 63 14 E 3905.37 S 63 26 E 4139.43 S 61 59 E 4370 30 S 62 33 E 4597 55 S 62 30 E 4827 19 S 62 58 E 5060 04 S 62 53 E 5293 79 S 63 50 E 5517 67 0 O0 0 O0 0 O1 0 O0 o O1 0 oo 000 o O0 0 O0 o Ol 1713.95 S 2981 76 E 3439.26 S 60 7 E 1825.20 S 3190 1930.92 S 3394 2035 85 S 3604 2141 97 S 3809 2247 22 S 4011 2353 45 S 4214 2459 74 S 4422 2566 68 S 4630 2666 91S 4831 42 E 3675.61 S 60 14 E 63 E 3905.38 S 60 22 E 25 E 4139.48 S 60 32 E 50 E 4370.40 S 60 39 E 10 E 4597.71 S 60 44 E 87 E 4827.41 S 60 49 E 32 E 5060.36 S 60 55 E 43 E 5294.22 S 61 0 E O1 E 5518.25 S 61 6 E COMPUTATION DATE: 17-JAN-94 PAGE 7 ARCO ALASKA, INC. 2E-05 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 19-DEC-1993 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG BIN 7524 71 4047.00 3900 O0 64 58 7762 8001 8245 8492 8742 8991 9237 9481 9726 41 4147.00 4000 13 4247.00 4100 47 4347.00 4200 87 4447,00 4300 22 4547.00 4400 60 4647.00 4500 18 4747.00 4600 95 4847.00 4700 95 4947.00 4800 O0 65 19 O0 65 7 O0 66 3 O0 66 17 O0 66 27 O0 65 56 O0 65 55 O0 65 52 O0 65 54 S 64 38 E 5733 85 S 64 54 E 5948 S 64 59 E 6164 S 63 45 E 6387 S 63 54 E 6613 S 64 19 E 6841 S 63 16 E 7058 S 63 7 E 7293 S 63 30 E 7516 S 63 41E 7739 83 85 35 20 11 99 03 13 42 0 O0 0 O0 0 oo 0 O1 0 O0 0 O0 0 O0 0 O1 0 O0 0 O0 2760 92 S 5026.27 E 5734 64 S 61 13 E 2852 2944 3042 3142 3242 3341 3443 3543 3643 89 S 5221.32 E 5949 39 S 5417.82 E 6166 72 S 5617.89 E 6388 62 S 5820.93 E 6615 39 S 6026.41E 6843 38 S 6232.30 E 7071 24 S 6432.13 E 7295 56 S 6631.75 E 7519 10 S 6832.05 E 7742 89 S 61 21 22 S 61 29 97 S 61 34 08 S 61 38 30 S 61 43 52 S 61 48 77 S 61 50 10 S 61 53 68 S 61 56 9970 92 5047 O0 4900 O0 65 42 10212 10450 10662 10848 11020 11180 11331 11471 11607 78 5147 58 5247 49 5347 75 5447 41 5547 93 5647 16 5747 92 5847 32 5947 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 OO 5700 O0 5800 O0 65 37 O0 63 46 O0 59 46 O0 55 37 O0 52 32 O0 50 3 O0 46 35 O0 42 52 O0 42 52 S 64 1E 7961.53 S 64 15 E 8181.26 S 63 54 E 8396.51 S 63 0 E 8582 95 S 61 43 E 8739 92 S 60 55 E 8879 38 S 60 8 E 9004 92 S 60 53 E 9117 O0 S 60 25 E 9216 02 S 60 45 E 9307 30 0 . O0 0.00 0.01 0.02 0 02 0 O2 0 O2 0 O2 0 O3 0 01 3741 30 S 7031 74 E 7965.09 S 61 59 E 3837 3931 4014 4087 4153 4215 4271 4319 4364 51S 7229 80 S 7423 51S 7591 23 S 7730 42 S 7853 45 S 7962 04 S 8059 74 S 8146 67 S 8225 84 E 8185.17 S 62 2 E 87 E 8400.77 S 62 6 E 34 E 8587.47 S 62 8 E 57 E 8744 55 S 62 8 E 36 E 8884 04 S 62 8 E 51 E 9009 53 S 62 6 E 83 E 9121 55 S 62 5 E 05 E 9220 54 S 62 4 E 51 E 9311 78 S 62 3 E 11744.92 6047.00 5900.00 43 55 11883.80 6147.00 6000.00 43 45 12022.17 6247.00 6100.00 44 12 12162.36 6347.00 6200.00 44 32 12210.00 6380.96 6233.96 44 32 S 58 50 E 9401.81 S 57 54 E 9498.13 S 55 10 E 9593.60 S 54 0 E 9691.28 S 54 0 E 9724.49 0.01 0.01 0.02 0.00 0.00 4411.87 S 8307.38 E 9406.23 S 62 2 E 4462.33 S 8389.49 E 9502.42 S 62 0 E 4514.41 S 8469.70 E 9597.69 S 61 57 E 4572.04 S 8549.27 E 9695.03 S 61 52 E 4591.68 S 8576.30 E 9728.13 S 61 50 E COMPUTATION DATE: 17-JAN-94 PAGE 8 ARCO ALASKA, INC. 2E-05 KUPARUK NORTH SLOPE, ALASKA MARKER g 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A GCT LAST READING PBTD 7" CASING DATE OF SURVEY: 19-DEC-1993 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 605' FSL & 160' FWL, SEC36 TllN R9E MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 6138 O0 11704 O0 11704 O0 11820 O0 11959 O0 12050 O0 12100 O0 12188 O0 12210 O0 3488 79 6017 45 6017 45 6101 O0 6201 44 6266 89 6302 55 6365 28 6380 96 3341 79 5870 45 5870 45 5954 O0 6054 44 6119 89 6155 55 6218 28 6233 96 2186 69 S 4397 31S 4397 31S 4438 99 S 4490 12 S 4525 70 S 4546 32 S 4582 61S 4591 68 S 3894 37 E 8283 11E 8283 11E 8351 94 E 8433 30 E 8485 54 E 8513 90 E 8563 82 E 8576 3O E COMPUTATION DATE: 17-JAN-94 PAGE 9 ARCO ALASKA, INC. 2E-05 KUPARUK NORTH SLOPE, ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a BASE KUPARUK a PBTD DATE OF SURVEY: 19-DEC-1993 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: FORMICA ************ STRATIGRAPHIC SUMMARY ************ SURFACE LOCATION = 605' FSL · 160' FWL, SEC36 TllN R9E MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 11704.00 6017.45 11704.00 6017.45 11820.00 6101.00 11959.00 6201.44 12100.00 6302.55 12210.00 6380.96 587O 45 5870 45 5954 O0 6054 44 6155 55 6233 96 4397 31S 4397 31S 4438 99 S 4490 12 S 4546 32 S 4591 68 S 8283 11E 8283 11E 8351 94 E 8433 3O E 8513 90 E 8576 3O E FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 12210.00 6380.96 6233.96 9728.13 S 61 50 E COMPANY ARCO ALASKA, INC. FIELD 2E-05 WELL KUPARUK COUNTRY USA RUN I DATE LOGGED 19-DEC-1993 REFERENCE 94OO3 All nterpretations are opinions based on nferences from e ecffical or other measureme ~I~ and we cannot, and do not guarai~tee 1he accuracy or correctness of anyinterpretat OhS, and we sha not, except in the case o[ gross or wilfull negligence o~ our part be liable or responsible for any loss, costs, damages or expenses incurred or sustained by anyone resulting from any interpretation made by any of otr officers, agenfs or employees. These interpretations are also subject to our General Terms and Conditions as set out in our current price Schedu e. WELL'. 2E-05 ( 6g 5' FSL, 160' FWL, SE C. 36, T 11N, R'?~'JM ) 'HORIZONTAL PROJECTION NORTH 6000 4000 2OO0 -2000 -400O -6000 -8000 SOUTH - 10000 REF 94003 SCALE: 1 / 2000 IN/FT ;i~:. ~i..~..i .... j.~i..L.~ ...... ~..~..~..~ .... ~..~..~ ..... ~.~.~. :...;;..;..~;. .L;i..: .:.;;;. ,.; ..... ~..~i..i.;: ..... ~; :; . :.. ~. . :,.. :]'. ii.] .......... 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' :... ~ , I_- - -~_.L.~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~&~ ~ ~ ; ; ~ ~ ; ~ ~ ~ ~ : : ~_.~ ~ , ~ : ~ ~ : ~ ~ : - · .} . . .:: :...: ~:~.:..::::-:::: ~:~: :.:: : · . : . :.:: ~:~:-~::~ ::.. .. . . ...... ::~ ~ ~- ~-~ .... ~--~-~-'~ :~-:~-~-~}~:; ;':~ ':-: ~:;~ ~1:~'~:-' :}:: '~:' : . ::.: ...... :.: .... : ............ :.: ..... :;.~ 1.~ 1~.: ! . :;..~ ~ .~ : :~:::: :::: .::. : i: -:. :. :. .; .... . :~;:'~ "~'~i'"~' ~'"~-'~?' ~'~'~';"~'~ ;~ :;;~ i~:; i'~>;'; '::~ ~:~ ~:; : ''~ ;-~,:~ .... , ,-~.-~.-,....,.<-,-.-~.-~--,..,~-.,..**..~- -,..,.**. ~ ...... ,. ~ ..... .i.:.~.-,-: ... z~;%:~ ~ ~ ~--'~ -~'"~ .... ;..~---~---~.-~m ~;.oo..~-.~. ~-. ~---;'--.~.~ %~:-:: ;.-~ ::%; :~.~ ~..;..; ~..; :, :' :..<~.'::. _~. , 12000 120,0 PROJECTION ON VERTICAL PLANE 300.0 - 120.0 SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1 / 2000 IN/FT ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 14, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 oil & Gas Cons. Cammission Anchorage Dear Mr. Johnston' Attached in triplicate are multiple-Applications for Sundry Approval on the following Kuparuk wells. Well Action 2E-05 ~i3--f'?. ~'Suspend 2E-06 ,~'~t/o? Suspend 2E-17 '$~'-¢~¢ Suspend 3M-20 Change Program (Cony to WI) AR3B-6003-93 if you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments File: FTR041495 ALA,_. ,A OIL AND GAS CONSERVATION COMMIS~_ ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend ~ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well Plugging _ Time extension Stimulate _ -- -- Change approved program_ Pull tubing _ Variance _ Perforate _ Other___ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 605' FSL, 160' FWL, SEC. 36, T11N, R9E, UM 6. Datum elevation (DF or KB) RKB 147', PAD 106' GL 7. Unit or Property name KUPARUK RIVER 8. Well number 2E-05 feet At top of productive interval At effective depth 1339' FSL, 1887' FEL, SEC. 6, T10N, R1 At total depth 1293' FSL, 1824' FEL, SEC. 6, T10N, R1 0E, UM OF, UM 9. Permit number 93-179 10. APl number 50-029-22423 11. Field/Pool KUPARUK RIVER 12. Present well condition summary Total Depth: measured 1 true vertical 6 2210' feet Plugs (measured) 381 ' feet Effective depth: measured true vertical 121 00' feet Junk (measured) 6 3 0 3' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 6097' 12147' ,- measured None Size Cemented Measured depth True vertical depth 24" 200Sx Cmt 121' 121' 9-5/8" 930 SxAS III & 6138" 3489' 810 Sx Class G 7" 275 Sx Class G 1 21 8 8' 6 3 6 6' RECEIVED true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None /:,PR 9 1994 Ai~st4a u~l & Gas Cons. Commissior: Anchorage 13. Attachments Description summary of proposal X Detailed operation program_ BOP sketch -- 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas _ -- Suspended X Service 17. I hereb~certif~ tt-~¢ the foregoing is true and correct to the best of my knowledge. Si~nod ~r ~ ,1)¢ Title FOR COMMISSION USE ~LY Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance__ Mechanical Integrity Test _ Subsequent form require 10-qo7 IApproval ~,,~1o. Approved by the order of the Commission Form 10-403 Rev 06/15/88 jriginai Signed Commissioner Date '/7"7..-,~//~- 6( Approved Copy Returned SUBMIT IN TRIP'LICATE Attachment I - ~' Request for Suspension KRU Well 2E-05 ARCO Alaska Inc. requests approval to place KRU Well 2E-05 on suspended status pursuant to AOGCC 25.105 (e). Additionally, a waiver to AOGCC 25.110 (c) is requested for the surface Plug requirement. While open hole LWD logs for Well 2E-05 indicate that there is 9' of net pay in the C Sand and 6' in the A Sand, there is concern about the quality of fluid contained within that pay. Cores taken from the C Sand in Well 2E-17, 0.9 mile to the west, and from the C Sand in Well 2E-08, 1.2 miles to the northwest, contained a highly asphaltenic, non-flowable hydrocarbon. There is a large degree of uncertainty as to the flowability of hydrocarbons contained in either the A or C Sand in 2E-05. If only the A Sand contains flowable hydrocarbons, the reserves associated with that pay is limited. At this time, development of the A and C Sand reserves in Well 2E-05 have poor economics due to the fluid quality uncertainty and oil price. Nevertheless, the well does have future potential as either a producer or water injector. Completion and production of nearby wells may increase confidence as to the flowability of hydrocarbons in Well 2E-05. Geochemical studies of the fluid from the 2E-17 and 2E-08 cores may increase understanding of why and where non-flowable hydrocarbons occur within the southern Kuparuk River Unit. Advances in coiled tubing completion technology and a more favorable oil price may enable economic development of limited reserves. Well 2E-05 is in a secure condition with the 7" casing run to TD and cemented to above the top of the Kuparuk. The 7" x 9-5/8" annulus is cemented with 650 sx of ASI with a 59 bbl Arctic Pack fluid cap. The 7" casing' is filled with kill weight brine and has not been perforated. 2E-05 is in a safe and accessible location on a producing drillsite that is monitored daily. RECEIVED I~,PR 'I 9 1994 .~.~,-~ Oil & Oas 6ons. 6orrlrnissio~: t, t ,.../.~ I% ¢-' - - Anchorage ARCO Alaska, Inc. Date: March 11, 1994 Transmittal #: 9027 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATC)-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. and return one signed copy of this transmittal. 2E-17-~~, LIS Tape and Listing: 02-21-94 '~ o~ v' HNGS/APS/LDS/CNTG and GR/AIT ~. \ 2E-06~ (~o5o LIS Tape and Listing: 02-23-94 ,-,-, // o~--CDR/CDN-2Bit Runs with QRO Processing -.E-,7 ~c~ LIS Tape and Listing: 02-09,94 o~-CDR/CDN-2Bit Runs with QRO Processing 2E-07 ~:~?... LIS Tape and' Listing: 02-14-94 o~-CDR/CDN-1Bit Run with QRO Processing 2E-05 (ocrs~ LIS Tape and Listing: 02-04-94 o~ -CDR/CDN-2Bit Runs with QRO Processing 3M-25A c~Sq LIS Tape and Listing: 02-15-94 oR-~3DR/CDN-2Bit~Runs with QRO P. rocessing Bob Ocanas DISTRIBUTION: Please acknowledge receipt 94034 93545 R.,-, ~¢',~'~. 93457 93521 93549 ¢,- c.,~,?~. (v~ '5~--tz~ 0 94015 Date: I ECEIVED MAR 1 4 199~ ~nchorage ARCO Alaska, Inc. Date: March 11, 1994 Transmittal #: 9028 RETURN TO: ARCO Alaska, inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following ~3pen h~items. receipt and return one signed copy of this transmittal. /2E-05 ~%"' I "+°~}2E-05 12E-05 Please acknowledge CDR ~,,~.r~ \~,c~ 11-30-93 to 12-5-93 cm. 6000-12200 CDN ~-w~[~c. 11-30-93 to 12-5-93 c"w'~- 6000-12200 CDR Very Enhanced 11-30-93 to 12-5-93~r~s. 11300-12200 Resisitivity I L-W~ "CDR Very-Enhanced Resistivity/ "¥1':6-8-93 ~ 9000-10300 CDN 1~'~ l'~c.~ 11-6-8-93 ~ 4750-9100 CDR/L.v,r~ IBc- 11-6-8-93 I 4750-10300 -~'~ CDRJ,..w'~,c- 11-21-25-93'~"4400-9150 ~.~------~ CDN/~4~1 ~c. 11-21-25-93 ~ 8640-9150 ADN/LW~i~s - ~.~,r~5. ---11-23-25-93 ~-8640-9100 ~.~ --CDR Very-Enhance Resistivityl~-.11-21-25-93 t 4400-9150 CDR/L_~ I=c. 1-6-9-94 t CDN/u-~c .~-6-9-94 ~ CDR Very-Enhanced Resistirityl~-6-9-94 ~ 5200-8900 ,z.~ [ 5140-8900 ,,,t~ 8000-8900 $ '2E-06 CDR 2E-06 CDN t.~.,~ ~... 2E-06 CDR.Very-Enhanced Resistivity Acknowledged: _/~,,,~,,~._, · DISTRIBUTION: D&M Drilling 11-13-17-93 4750-10650 11-13-17-93 ¢,?.-10100-10650 11-13-17-93p, 9800-10670 5 Date:_ ~.0i1~ ,~_ '~ Cathorino Wodoy(Goolo~y) ARCO Alaska, Inc. Date: January 28, 1994 Transmittal #: 8992 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~¥-' ~--2E-05 ?~-~q ---2E-06 q %-~5-2E-07 q¥~\~-2E-08 ~-Directional Survey '- Directional Survey -- Directional Survey ~-Directional Survey Receipt Acknowledged: 12-19-93 12-20-93 12-21-93 12-21-93 DISTRIBUTION: Date: D&M State of Alaska (2 copies) 94003 94004 94007 ARCO Alaska, Inc. Date: January 7, 1994 Transmittal #: 8972 'RETURN TO: ARCO Alaska, Inc. ATTN: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the .following Cased Hole items. receipt and return one signed copy of this transmittal. Receipt Acknowledge: -dJItrasonic (~Cement & - Ultrasonic CCement & -- Ultrasonic (Cement & -'Ultrasonic Imager-USIT Corrosion) Imager-USIT Corrosion) Imager-USiT Corrosion') imager-USlT f, Cement& Corrosion') ~-Cement Bond Log (CBT) .-Cement Bond Log (CBT) ,-Cement Bond Log (CBT) · -'Cement Bond Log (CBT) .-Cement Bond Log (CBT) 12-20-93 ~ 12-19-93 1 12-20-93 I 12-20-93 12-19-93 12-20-93 12-20-93 12-20-93 12-20-93 Date' Drilling State of Alaska(+sepia) NSK Please acknowledge 8900-10548 10700-120~'1~ 6400-7645 ~' 7400-9088 10700-120~ 8900-10520 8400-10206 6400-7616 7400-9059 ALASKA OIL AND GAS CONSERVATION COMMISSION _WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 January 10, 1994 Phyllis Billingsley ARCO Alaska lnc P O Box 100360 Anchorage, AK 99510-0360 Dear Ms Billingsley: The Commission is compiling statewide drilling statistics for 1993. Attached is a list of outstanding Permits to Drill issued to your engineering group (permits for which no form 10-407 has been received by this office). Please review this list to determine if any of the wells were ddlled in 1993. If so, please note the well name, total measured depth, and class (development, service or exploratory). If any wells were drilling as of 12/31/93, estimate the depth at 12:00 midnight. We would appreciate your reply by the end of January if possible. Thank you for your cooperation with this project. If i may be of any assistance, please call me at 279-1433. Yours very truly, Robert P Crandall Sr Petr Geologist encl jo/A:RPC:~rlstats .1/04/94 OPERATOR ARCO ALASKA ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA ARCO ALASKA INS ARCO ALASKA INC ARCO ALASKA ARCO ALASKA ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA ARCO ALASKA ARCO ALASKA ARCO ALASKA ARCO ALASKA ARCO ALASKA INC ALASKA WELLS BY ARCO PEB~4IT 93-0166-0 93-0152-0 93-0151-0 93-01~3-0 93-0144-0 93-0188'0 93-0179-0 93-0169-0 93-0104-0 93-0189-0 93-0174-0 93-0175-0 93-0187'0 93-0195-0 93-0196-0 93-0193-0 92-0040-0 WELL NAME KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV %INIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV LTNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV LTNIT KUPARUK RIV UI~IT KUPARUK RIV ~TNIT KUPARUK RIV UNIT KUPARUK RIV LTNIT KUPARUK RIV UNIT KUPARUK RIV UIqIT 2A-18 2A-19 2A-20 2A-22 2A-24 2E- 04 2E-05 2E-06 2E- 07 2E-08 2E-17 2E-18 3M-23 3M-24 31~1- 2 6 3R-16 PAGE ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 November 18, 1993 A W McBride, Area Drlg Engr ARCO Alaska lnc P O Box 100360 Anchorage, AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 2E-05 ARCO Alaska Inc 93-179 605'FSL, 160'FWL, Sec 36, T11N, R 9E, UM 1066'FSL, 1716'FEL, Sec 6, T10N, R10E, UM Dear Mr McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the Nodh Slope pager at 659-3607. airman BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Drill X Redrill r~ lb Type of Well Exploratory D Stratigraphic [] Development Oil X Test Re-Entry E] Deepen [] Service ~ Development Gas E] single Zone X Multiple Zone r'-] 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 147', Pad 106' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25664, ALK 473 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 605' FSL, 160' FWL, SEC. 36, T11N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1200' FSL, 1950' FEL, Sec. 6, T10N, R10E, UM 2E-05 #U-630610 At total depth 9. Approximate spud date Amount 1066' FSL, 1716' FEL, Sec. 6, T10N, R10E, UM /til/1 8/93 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TV•) property line 2E-06 12174' MD 3564' @ TD feet 24.6' @ 325' MD feet 2560 6338' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300 feet Maximum hole angle 66.31 o Maximum sudace 2064 psig At total depth ('I-VD) 3020 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Couplingl Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" 47.0# L-80 BTC 2469' 41' 41' 2510' 2049' 600 Sx Arcticset III & HF-ERW 810 Sx Class G 12.25" 9.625" 36.0# J-55 BTC 4040' 2510' 2049' 6089' 3487' HF-ERW 8.5" 7" 26.0# Lo80 BTCMOE 12133 41' 41' 12174' 6338' 170 SxClass G HF-ERW Top 500' above 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 cSt°rnudCJclr°arl R E C E IV E D Surface Intermediate Production ['iOW '~ Liner Perforation depth' measured ;,.!~.:_;l(a 0il & Gas Cons. Commission true vertical Anch0ra,~e 20. Attachments Filing fee X Property plat [] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot D Refraction analysis r'~ Seabed report [] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Area Drilling Engineer Date Commission Use Only Number I APl number i ^..,ov~, ..,~ ~ ._ ¢...% I See cove..etter for Permit, ,,.? '/79 50- o ~__ ~ - ~_. ~.. ~---z/,~ ~ i/,/-- / ~ other requirements ~onditions of ~pproval Samples required [] Yes [] No Mud Icg required ~ Yes [~ No Hydrogen sulfide ~ Yes [] No Directional survey required ~] Yes E] No measures Required working pressure for BOPE ~ 2M ~:~ 3M E] 5M [] 10M D 15M Other: OnCnai Signet] ~y David W. Johnston byorder of Approved by Commissioner the commission Date .~ Form 10-401 Rev. 7-24-89 triplicate I , , , 10 11 12 13 14 15 16 17 18 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2E-05 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (6089')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (12174') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve & NU tree assembly. Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED NOV I 7 }9--03 Aiaska 0il & Gas Cons. Commission Anchorage iCreated by ' jones For: W McBRIDE Date plotted : 12-Nov-93 iPIot Reference is 5 Version #2. Coordinates are in feet reference slot #5. i True Vertical Depths are reference wellhead. Baker Hughes INTEQ --- ARCO ALASKA, Ixac. 3000_ _ 3500_ _ 4000_ _ 4500 _ _ Structure : Pad 2E Well : 5 Field : Kuparuk River Unit Location : North Slope, Alaska : 0.00 E a S f -- -- > 500 0 500 lO00 1500 2000 2500 3XXDO350~ 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 I I I t t I J I I J f I I I I I I J I I I I I I I I I I I I I I I I I I I I 500 SURFACE LOCATION: I 605' FSL, 160' FWL S 60,27 DEC E SEC. 36, TllN, RgE ° / I SEC. ~. TION, RIOE I [ KOP WD=300 TMD:300 DEP=O T~GET "~ ~D=6017 ~ ~0 6.00 TMD=11755 m - ~ 12.00 DEP=9447 ~ ~_ [ ' ~T 8203 TD LOCATION: ~ 24.00 30.00 1066' FSL, 1716' FEL 3~ O0 ~' ~2 O0 B/ PERM~ROST ~D=1502 mD=lCOO DEP=¢26 SEC. 6, TION, RIOE ~ ~s.oo ~ 54.00 -- ~~e°~oo [ac WD=2049 TgD=2510 DEP=1142 T/ UGNU SNDS ~D=2t32 TMD=2717 DEP=1332 T/ W $~< SNDS ~=2692 IMD=41 ~ 1 DEP:2608 ~ B~ W SAK SNDS m0=3287 *MD=5591 DEP=3964 5/8" CSG PT ~D=3487 1MD=6089 DEP=4420 ~ K-lO ~D:3827 %1D=6935 DEP=5194 MA~MUM ANGLE 66.31 DEG K-5 ~D=5157 D~D=10245 OEP=8225 ~ - ~Eo..J ~,~b[ ORO~ ~:S2~S mD= ~04~ ~CP:S40;"-- ~~~¢¢~0~00° s~_ ~ 54.00 DROP 2 DEC / ~00' 50.00 46.00 ~_ T~GET -T/ ZONE C (EOD) ~'D=6017 TMD=II755 D~P=9447 ~42.00 TARGET ANGLE r/ zo~[ A ~D=6092 T~D=~853 DEP=95~O - 40 DEC ~/KuP SNDS ~D=6185 TMD=11974 DEP=9588 65~_ TD/7" CSG PT ~=6338 TMD=12174 DEP=9716 i i i i i i i i i i i i i ~ i ~ i i i i ~ i ~ i i ~ I I i { i I i i ~ i i i i ~ i i 5~ 0 5~ 1~0 15~ 20~ 2~o 3~ ~ 4~D 45~ 50C~ 5500 6~ 6~ 70~ 7500 80~ 8500 Scale1 ' 250.00 Vo~icolSection on ~ 19.73 ozimuth wilhreference 0.00 N, 0.00 E from sloi ~5 - I ._4000 4500 RECEIVED h, iaska 0il & Gas Cons. Commission Anchorage Scale 1 : 50.00 1 O0 50 East 0 50 1 O0 1100 )9oo 1100 9OO 300 ~ r~ 1700 1500 1300 150 200 250 300 ,350 ARCO ALASKA, Inc. Structure : Pad 2E Well : 5 Field : Kuparuk River Unit Location : North Slope, Alaska 1500 1700 1900 100 .....t,, 50" i o - c) 0 - I _ 150 [ ) _ V _ 200 _ 250 _ 300 DRILLING FLUID PROGRAM Well 2E-05 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.5 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-t5 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.1 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and 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 and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2064 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2E-05 is 2E-06. As designed, the minimum distance between the two wells would be 24.6' @ 325' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. RECEIVED NOV 1 7 19~f (JiI & 6as Cons. Commission Anchorage Casing Design / Cement Calculations 15-Nov-93 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 2E - 05 6,089 ft 3,487 ft 12,174 ft 6,338 ft 4,111 ft 11,755 ft 6,017 ft 3000 psi ** See Page 4 For Casing Choices 3,500 psi Maximum anticipated surface pressure Estimated BH pressure at top of target zone TVD surface shoe {(13.5*0.052)-0.11}*TVDshoe Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =[ 3,487 ft 2,064 psiI 3,OOO.O ppg 6,017 ft 150 psi 10.1 ppgJ Surface lead: Surface tail: Top West Sak, TM D = 4,111 ft Design lead bottom 500 ft above the Top of West Sak = 3,611 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 1,131 cf Excess factor = 15% Cement volume required = 1,301 cf Yield for Permafrost Cmt = 2.17 Cement volume required =1 600 sxJ TMD shoe = 6,089 ft (surface TD - 500' above West Sak) * (Annulus area) = 776 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4110 cf/If Cmt required in casing = 33 cf Total cmt = 809 cf Excess factor = 15% Cement volume required = 930 cf Yield for Class G cmt = 1.15 Cement volume required =1 810 sxJ RECEIVED 1 ? ,~!~.~a. 0il & {3as Cons. Commission Anchorage Casing Design / Cement Calculations 15-Nov-93 Production tail. TMD = 12,174 ft Top of Target, TM D = 11,755 ft Want TOC 500' above top of target = 11,255 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 160 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 178 cf Excess factor = 15% Cement volume required = 204 cf Yield for Class G cmt = 1.23 Cement volume required =1 170 sxJ TENSION - Minimum Design Factors are: T(pb)=l.5 and Tfjs)=l.8 Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =b Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WlYft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy - Tension (Pipe Body) = Design Factor =[ Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud RECEIVEI Casing Rated For: Length = Casing Wt (Ib/ft) - Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 1086000 lb 6,089 ft 47.OO Ib/ft 286183.0 lb 43218.3 lb 242964.7 lb 4.5] 1161000 lb 6,O89 ft 47.O0 Ib/ft 286183.0 lb 43218.3 lb 242964.7 lb 604000 lb 12,174 ft 26.O0 Ib/ft 316524.0 lb 48061.3 lb 268462.7 lb 667O00 lb 12,174 ft 26.OO Ib/ft 316524.0 lb 48061.3 lb 268462.7 lb :2.5] Casing Design / Cement Calculations BURST - Minimum Design Factor = 1=.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =1 Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =1 COLLAPSE - Minimum Desiqn Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom- Design Factor =l Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom: Design Factor =[ 15-Nov-93 6870 psi 2064.3 psi 3.3J 7240 psi 6818 psi 2933 psi 3885 psi 1.9J 4750 psi 0.524 Ib/ft 890 psi 5.3J 5410 psi 0.524 Ib/ft 3318 psi 1.61 RECEIVED i, OV ] 7 '199 a,;.~,M 0il & Gas Cons. Commission Anchorage Casing Design / Cement Calculations 15-Nov-93 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb 2090 psi Burst 6870 psi 5750 psi 3520 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb Collapse 5410 psi 4320 psi Burst 7240 psi 4980 psi RECEIVED Oil & 6as Cons. Commissk)n Anchorage kJPARUK RIVER UNI'i 20" DIVERTER SCHEMATIC I 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 6. 20" - 2000 PSI ANNULAR PREVENTER 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20"-2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION RECEIVED l,iOV 1 7 ~90~ t,.!~,,.s[a fJil & Gas Cons. Commission Anchorage EDF 3/10/92 7 , 6 5 4 13 5/8" 5000BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3.CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOq-FOM PIPE RAMS. TEST BOTFOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16"-2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11"-3000 PSI X 13-5/8"-5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8"- 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR RECEIVED fqOV 1 7 I9.,9f ?'-,is. sk~ Oil & I~as Cons. Commission Anchorage ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE, // /72 [2 thru 8] ['9 t]~ru ][3]" ' El0 & 13] ¢4]) Casg [14 thru 22] (5) BOPE j~~ ! f/~ T,/~ S [23 thru 28] . 10. 11. 12. 13. 14. 15. YES 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undndicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. ~_.. 8. Can permit be approved before 15-day wait ............................ ~,, 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company./vr.c~ Lease & Well ~.,,q'~/_. ~s'"'~'~''' ./-/~ /~'"'~.~. ~..~'"'""0_..~ NO ~EMARKS Does operator have a bond in force ................................... Is a conservation order needed ....................................... I s admi n i st rat i ve approval needed .................................... Is lease ncrnber appropriate .......................................... Does well have a unique name & ncmber ................................ ~_ Is conductor st r i ng provided ......................................... ~ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~©c~Opsig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... (6) Other ~_~ [29 thru 31]' (]7]) Cont. act//~"". . [32] (8) Addl ~_~ 29. 30. 31. 32. 33. geo 1 ogy: eng i nee r i ng: 'DW~J~L~ ~J~_ RAD ~\ - ~ rev 6/93 jo/6.011 FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ncmber of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' UM MERIDIAN' SM WELL TYPE' E x p.,~...~, Redri 11 ,, In j, Rev C~ 0 .---I "T'Z ~0 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 simp!ify finding information, informati;3n 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. oV RECEIVED ~A.R ! 4 1994 Alaska 01I & Gas Cons, CommissiOn Ancl~orage P A C,., [: · ':':, I. 15 fi. r'.. ?{:9.7k)~. 1. n {:, :}. 0 0 n -99c' . 2. 7.C'2S 0. r: 2 7 R LiP. x P P A ¢; E: -999.250 -999.250 ~4.37E 3.H33 42.539 3.345 2.615 295.0~9 0.327 2.838 3.391 353.367 0.41,9 1.9.565 -999.250 -999.250 -999.250 -999.250 -909.250 -999.250 -999.250 , # -999.250 -999,250 9~9.250 -999,250 0,(}10 2. 858 91. 359 0. h?2 0.025 3.221 85,409 0.!69 -0,369 -999.250 -999.250 ¢' 250 "~99,250 -999.250 -999,250 ~'~J,t' 'r'un i?'~ Se!)avate fJ~ie$. PACE: 1. 0 4 ,
