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TTT RR AA NN SS MM II TT TT AA LL FROM:: Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Shark Tooth 1 DATE: 04/02/2024 Transmitted: North Slope, Kuparuk River Unit Via SFTP data drop ___ Shark Tooth 1 Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: Shark Tooth 1- e-transmittal well folder Receipt: Date: Alaska/IT-GGRE/ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 211-165 T21327 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.03 12:58:20 -08'00' TT RR AA NN SS MM II TT TT AA LL FROM:: Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Exploration - Image logs Backlog DATE: 03/02/2024 Transmitted: North Slope, Exploration – Shark Tooth 1 Via hard drive data drop 1 of 1 Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 211-165 T38548 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 08:15:30 -09'00' FROM: Sandra D. Lemke, ATO -704 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Core Photo well list DATE: 11/15/2019 North Slope, Alaska RECEIVEL,2-11-1b5 � NOV 15 2019 Z414`� Con oc©Phi(tips TRANSMITTAL AOGCC TO: Meredith Guhl AOGCC 222 W. Th Ave., Suite 100 Anchorage, Alaska 99501 Transmitted: Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Leml(e@conocoghillig5.com CCC Receipt: V (V Date: I I I g I Alaska/IT-GGRE I C ocoPhil s Alaska I Office: 907.265.6947, Mobile 907.440.4512 tla „E O 2P-417 Core photos 31445 10- 3S-16 Core Photos 31444, IOAtlas 1 Core photos 31443 pt CD2-24 Core Photos 31442 0t J_q Cirque3Corephotos-Tw*A`- !0 Meltwater North 1 UV_WLphotos—TZ5(0(10 11'SharkTooth1 Corephotos,q9� 1004025935_Meltwater-N-l,pdf- J-2.6 ?) � 1004279632_3S-16.pdf 31444 DD -0 1&D4282603 Rendemous-A.pdf 3 1 4 4 6 Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Leml(e@conocoghillig5.com CCC Receipt: V (V Date: I I I g I Alaska/IT-GGRE I C ocoPhil s Alaska I Office: 907.265.6947, Mobile 907.440.4512 em i am ' lo ~ L. 9 ■ 0 V 9 aa)) aa)) as aa)i n .. w . 0 \ 3 7 3 (I)i r a) 'C O z C fn co co to • • O) O) 0. a) o a) a) N ,.._ 15 : Ecii 6:o m a) a� a) m ❑• j ❑• > c'• • x 0 > ❑ ❑ > > >' ❑ ❑ ❑ ❑ ❑ 2 F 2 H a3) N w 2 f- 2 2 H F- F- ci a� >� Z Z > L L L L .L., L L L E r r L L L L L L b 'co I «� O O O Oo o o o w o o o o o o • To Cl) H H H H O O O H H H H H H a CO •L •� s_ ,_ -6 T ` -6 -t Y Y Y Y Y E `O N L/ LU) co L co L7 Cl) co L L L O L co L L L L L L L CO U) (0 V) 0 Co aCO (0 f0 CO CO CO I— d Q O c 4 N 4) aaaaN 0aN N N aN a) aa '� Z f ,',,it w it ii,� i it it it it it it it it it it it it it ).L co a s p a v v v v v v v E 'c •c 'c c 'c •c •c •c 'c -c "c 'c 'c 'c •c 'c 'c •c N O' O N O N O C O co o o o o o o o o o o o o o o Cl) — U 0 Q 0 Q CD Q a0)Q a0i CD a0i 0) 0 aU) 00)) 0 aU) 0 4)) av) 0 aa)) a) EE wz wz wz w w w w w w w w w w w w w w w O tiSt c av v v v v v v v v c v v v v v v v va 0 x > o 0 0 E. o o o o o o o o o o o o o o .p- N N N N N N N N N N N N N N N N N N W S V OO O o o O o O O O O o O o O o o o Et (1a co m'r r O W'v v v v v v v v v v v v Zr- v v v v v V W ZOS S V < O t) 0 Z a Qa � 0 .2 ate0 co 8co v. o }I E t • N y (0 co E m O � ii E .s. .-- „........C) U 1 E c.. w Tr Nc 1.--1o J1 0O' a � Z a H 0.,ii N a) O I— r Q Z J =' o w r N ❑ CO • 0.1 CD To W O N LU J (/) p i I- a) Z Y c° ❑ U_ Q co c• > 0 r W co a▪) y Q Z E• }I w O 0) Ct O J C a) O Z j a) a) (0 a) a) a) CO CO CO CO a) CO CO CO a) CO a) a) O a) f0a) a) a) a) a) a) a) a) a) a) a) a) a) a) a) a) CO CO E E ❑ 0 0 0 ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ 0 Z 0 a) a) a) a) m CO CO CO () CO a) CO CO CO CO CO CO y O) O) O) O) O) O) _O) _5) _) O) O) _) O) ) _) O O) W o 0 Z O w ❑ ❑ ❑ 0 ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ in > O J ., atm n n n N- N- N- N- n n N- N- n n n n N- N- n Q H ++ u) ja N N N N N N N N N N N N N N N N N N Q z L C E co M M _M C) M c) M M M M M M M M M M Co N 2 0 O p w O z N N N N N N N N N N N N N N N N N N 0 Q IPp RI Z 2 v • 0 • D O c � mD UO co CtLL d Z w c 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 E 5 Q a J 0 a`) o f' a m 6):° a'❑ 0 0 0 ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ a I O F 3 JcF w w w LU w w w w w w w w w w w w w w o • o C • .. 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W z V 0 0 0 Z o 8 Q1- co d a w O co O. etcG Co N m a • N E r VM U o vi c Q a I-- N 5 O G T N CO • N_ W 00 N V/ W co 0 Q Q = O r H i Q o a z E p E U co z o 3 co o co co o to > m v 3 NN re 77. 0 CO y l v D.L. Nojski Conocurhillips Alaska Inc 700 G Street ATO 3-382 Anchorage,AK 9950 Phone: 907.263.485ConocoPhillips Dan.L.Przywojski@C. mac: Date: May 9, 2014 ConocoPhillips Alaska Inc. RECEIVED 700 G St. V ATO3-382 MAY 0 9 2014 Anch., AK. 99501 Attn: D.L.Przywojski AOGCC To: State of Alaska Alaska Oil &Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 '' .- •. Date: May 9, 2014 Well Name: SHARK TOOTH#1 SCANNED AUG 1 1 2014 Sample Type: Dry Cuttings Depth Range. Surface to T.D. (200'-6688') Please sign and return a copy of this transmittal to: ConocoPhillips Alaska Inc. 700 G St. ATO3-382 Anch., AK. 99501 Attn: D.L.Przywojski Dan.L.Przywojski@ConocoPhillips.com SIGNED: << _' • • MAY 0 9 2014 : OGCC Conoco Phillips Alaska, Inc. Sharktooth #1 Dry Samples Box Samples 1 200' - 2500' 2 2500' - 5000' 3 5000' - 6310' 4 6310' - 6688' Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Tuesday, April 15, 2014 3:07 PM To: 'Lemke, Sandra D'; Bender, Makana K(DOA) Cc: Allsup-Drake, Sharon K; Bottrell, Phil M; Elgarico, Richard E; Davies, Stephen F (DOA) Subject: RE: Shark Tooth 1 reporting compliance-final deliverables Attachments: CPAI_Transmittal.pdf Sandra, Thank you. Four of those reports were not in our records. I just reviewed all data and files submitted one last time. At this time the only outstanding item required to complete compliance are the ditch samples,when they are found. '""'~'•"�•�... Meredith SCANNED AUG 1 1 2014 Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907)793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.nuhl@alaska.gov. From: Lemke, Sandra D [mailto:Sandra.D.Lemke@conocophillips.com] Sent: Monday, April 14, 2014 6:13 PM To: Guhl, Meredith D (DOA); Bender, Makana K (DOA) Cc: Allsup-Drake, Sharon K; Bottrell, Phil M; Elgarico, Richard E Subject: FW: Shark Tooth 1 reporting compliance - final deliverables Meredith and Makana, Here are the 5 outstanding reports that I don't have record of sending you. I think the core analysis may be duplicate of that delivered 24SEPT12 but since I truncated the name on the transmittal I can't be sure—so I'm resending it. The transmittal for this data is also included as an attachment here. Please sign,scan and return at your earliest convenience. I will include the 4 signed transmittals for data already sent over to AOGCC on Shark Tooth 1 to you in the next e-mail. I don't want to get transmittals and new data delivery mixed up. Please review the signed transmittals along with the new 5 files I'm sending to day and get back with me if you feel there is still missing data. I will be on vacation April 18- 27. Sandra D. Lemke Alaska IT Staff Associate-Data ConocoPhillips Alaska 700 G Street,AT01412 1 Release of Confidential Data Coversheet Well Name: N,1,ps;,V -cocrc' 1 PTD: \C E-Set: 2A3 2 7 l 2 u V Physical data labeled with PTD, E-Set# Conf. entry: f— f– ✓ Import CD data to RBDMS via GeoLogs tab V Confidential (incomplete)entry in Well Data List notes Import to DigLogs via E-Set tab Scan labeled data Fully logged: 14/ Z / 144 4- Apply OCR text recognition Save to Well Log Header Scans New"complete" entry in Well Data List notes Logged by: Guhl, Meredith D (DOA) 1 (-4, 5 From: Lemke, Sandra D [Sandra.D.Lemke@conocophillips.com] Sent: Tuesday, April 01, 2014 4:50 PM To: Guhl, Meredith D (DOA) Cc: Allsup-Drake, Sharon K; Bottrell, Phil M Subject: Shark Tooth 1 COP transmittal -directional survey delivery Attachments: Shark Tooth 1_AOGCC_logs_10APR12.pdf Please call if you still can't locate the digital files for the directional survey on Shark Tooth 1. I will resend. Sandra t Lemke L/// /l Alaska IT Staff Associate-Data � o� ltd / ConocoPhillips Alaska 0 cam/ R f✓ 700 G Street,AT01412 Anchorage,AK 99501 (907)265-6947 phone, (907)440-4512(cell) Sandra.D.Lemke@COP.com SCANNED AUG 1 .1 2014 Guhl, Meredith D (DOA) From: Decker, Paul L(DNR) Sent: Thursday, March 13, 2014 1:48 PM To: Guhl, Meredith D (DOA) Cc: Davies, Stephen F (DOA) Subject: RE: Extended Confidentiality Applications Hi Meredith,The answer is no,we have not received applications for extended confidentiality on either well. Shark Tooth 1 is inside the Kuparuk Unit on state land, no case to be made about impacting unleased acreage, etc, and would have no chance of being granted extended confidentiality. However, as Shadura 1 is on CIRI fee subsurface, I have a call in to NordAq to check that neither they nor CIRI are planning a last-minute attempt to keep it from being released. -Paul From: Guhl, Meredith D (DOA) Sent: Wednesday, March 12, 2014 4:12 PM To: Decker, Paul L (DNR) Cc: Davies, Stephen F (DOA) Subject: Extended Confidentiality Applications Hi Paul, There are two wells approaching release date. 1. Shark Tooth 1, ConocoPhillips, PTD 211-165,API 50-103-20647-00-00, completed February 22, 2012, releasing March 22, 2014. 2. Shadura 1, Nordaq Energy, PTD 211-014, API 50-133-20593-00-00, completed February 26,2012, releasing March 26, 2014. Please advise if either operator has applied for extended confidentiality. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907)793-1235 1 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Thursday, March 13, 2014 8:58 AM To: 'david.j.reimer@conocophillips.com' Cc: Davies, Stephen F(DOA) Subject: Reporting Compliance Shark Tooth#1 Dear Mr. Reimer: I am completing the final compliance check for Shark Tooth#1, PTD 211-165,API 50-103-20647-00-00, completed on 2/22/2012 and due for release to the public on 3/22/2014. As required by Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.050 (d)the operator shall file with the Commission (d)... a complete digital copy of each inclination and directional survey... must be filed with the commission in a format acceptable to the commission. An ASCII or Excel version of the final definitive survey is required for Shark Tooth#1. Please also submit a PDF version of the final definitive survey. • Also, as submitted,the form 10-407 "Well Completion Report" is incomplete because it does not include a list of all formations and geologic markers encountered in Box 29.The purpose of form 10-407 is to provide a concise,two-page summary for AOGCC's well records.As required by Regulation 20 AAC 25.071(b)(5)the operator shall file with the Commission (5)a list of the geologic markers encountered and the measured and true vertical depths of each marker. In addition, as required by Statute AS 31.05.030(d)(2)(B)and Regulation 20 AAC 25.071(b)(3)and also noted in box 28 on form 10-407,the operator is required to "list formations and intervals cored (MD+TVD of top and bottom of each) and summarize lithology and presence of oil,gas and water".TO BE SENT WHEN AVAILABLE,as noted on the current form 10-407,defeats the purpose of the form by not listing the intervals and formations cored and is not acceptable. Please update the form with a list of the intervals and formations cored, both sidewall and conventional, and summarize the lithology and presence of oil,gas or water. Finally, no dry ditch samples have been received for this well.As required by Statute AS 31.05.030(d)(2)(B)and Regulation 20 AAC 25.071 (b)(2), and noted in the approved PTD letter dated January 5, 2012,the operator is required to submit a complete set of washed and dried, legibly identified samples of all drill cuttings, in no greater than 30' sample intervals from the point where sampling begins and 10'sample intervals through target zones. Please submit the cuttings as required. Please provide the requested definitive survey files, an updated form 10-407 addressing both formations/geologic markers and formations/intervals cored, and dry ditch samples by April 13, 2014. If you have any questions, please contact me. Sincerely, Meredith Guhl Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907) 793-1235 1 + onhlllii::. TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT00340 TO: Howard Okland ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501-3539 RE: Shark Tooth 1 Permit: 211-165-0 DATE: 09/25/2012 Transmitted: North Slope, Alaska Shark Tooth 1 (501032064700) CD 1/digital data 1-1 P&P Analysis (1 .xls file) Geochem ( 5 folders, 3 .xls files) Mudgas Isotope data (2 .xls files) Shark Tooth 1 was drilled as an exploration well-All data is confidential until State of Alaska(AOGCC)designated release date Transmittal instructions: please promptly sign, scan, and return to e-mail address below CC: Shark T o 1 -e-transmittal well folder Receipt: v Date: A c crt- ZJQ , 2- 1735-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 Sandra,D.Lemke0Conocophillips.corn - - ":;42'1'rCir'01 7:17 I* Shark Tooth main_digLadcl ik Shark Tooth AOGCC Organize IF Include in library v Share with v Burn New folder Name Date modified Type Size Favorites Desktop L August 19 delivered 924120121103 AM File folder Downloads Shark Tooth No.1_ARO.GCMS 9;242012 3:04 PM File folder Recent Places 4, Shark Tooth Noi._Extrad GC_CS2 Extracti... 9.'24/2012 3.04 PM File folder I, Shark Tooth No.I._Extract GC Soxhlet Extr... 9;24:2012 2:04 PM File folder Libraries Shark Tooth No.1._GCMSNIS 9/242O122:04 PM File folder L1 Documents Shark Tooth No.l_SAT.GCNIS 9,724)2017 2:04 PM File folder ,f.112012-03-22_HolbaMudGas_SlAIC_select..xls 61141:2012 1117 PM Microsoft Excel 97... 79 KB IL Computer J Conoco Phillips Shark Tooth No.1 HH-55.., 8;29/2012 8:04 AM Microsoft Excel,97... 383 KB OSDisk(Ci) J Isatopes_Shark Tooth No.xls 8.14./201212:13 PM Microsoft Excel 97... 74 KB sl'emkeS("\\anna05) [j MPLC_Shark Tooth No.xls 8 14.201212:13 PM Microsoft Excel 97... 103 KB AK_shared 0.1+,,conoc j Shark_Tooth_1_Pull_8-14-12.xls 8/1.4::2011 11:15 AM Microsoft Excel 97... 1010 KB SOXHLET_Shark Tooth No.xls 814:2012 1113 PM Microsoft Excel 97... 79 KB Network 11: 12 items 111111111,11, ?Tl: 211 - 165 ConocoPhilll s TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke,AT00340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave. Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501-3590 RE: Shark Tooth 1 Permit:211-165-0 DATE: 08/17/2012 Transmitted: North Slope, Alaska Shark Tooth 1 (501032064700) CD/digital data Laser grain size analysis and graphs;Weatherford; Job HH-55704; 6326.05-6363' and(zip file) LPSA-Laser grain size conventional core raw data;Weatherford; Job HH55704; 6326-6363(.xls) Core Photos_Weatherford labs;Job HH-55704; stitched TIFF files(folder) _Thin Section photo micrographs(.ppt)-core 6324-6362 including detailed descriptions and formation/facies(.xls) folder 3 files-Sidewall grain size and point count+converted to load format file(.xls) 2 files Conventional Core grain size and point count data(.xls) Total Gamma RCA Profiles,2-16-12;Weatherford Job HH-55704(.xls) , FIT Test 2/9/2012(.xls) GT3 scan 2-11-12(.xls) Load on tool 12/30/11 (.xls) Shark Tooth 1 was drilled as an exploration well-All data is confidential until State of Alaska(AOGCC)designated release date Transmittal instructions: please promptly sign, scan, and return to e-mail address below CC: Shark Tooth 1 -e-transmittal well folder Receipt: UK/`^ Date: , C 11111•11111111111111111L ITSS-Technical Data Management I ConocoPhillips Anchorage, Alaska I Ph: 907.265.6947 Sandra.D.LemkeDConoc phi/lips com r :i c �, .� ConocoPhillips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke,AT00340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave. Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501-3590 RE: Shark Tooth 1 Permit: 211-165-0 DATE: 08/17/2012 Transmitted: North Slope, Alaska Shark Tooth 1 (501032064700) CD/digital data 21 .7 Laser grain size analysis and graphs;Weatherford;Job HH-55704; 6326.05-6363' and(zip file) LPSA-Laser grain size conventional core raw data;Weatherford; Job HH55704; 6326-6363(.xls) Core Photos_Weatherford labs; Job HH-55704; stitched TIFF files(folder) -"Thin Section photo micrographs(.ppt)-core 6324-6362 including detailed descriptions and formation/facies(.xls) folder 3 files-Sidewall grain size and point count+converted to load format file(.xls) 2 files Conventional Core grain size and point count data(.xls) Total Gamma RCA Profiles, 2-16-12;Weatherford Job HH-55704(.xls) FIT Test 2/9/2012(.xls) 7 GT3 scan 2-11-12(.xls) / Load on tool 12/30/11 (.xls) Shark Tooth 1 was drilled as an exploration well-All data is confidential until State of Alaska(AOGCC)designated release date Transmittal instructions: please promptly sign, scan, and return to e-mail address below CC: Shark Tooth 1 -e-transmittal well folder Receipt: Ll -- Date: (-4 ` i '� ITSS-Technical Data Management I ConocoPhillips I Anchorage, Alaska i Ph: 907.265.6947 Sandra.D,Lemke0Conocophillips.com ConocoPhillips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke,AT00340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave. Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501-3590 RE: Shark Tooth 1 Permit: 211-165-0 DATE: 04/27/2012 T an mitt- .: North Slope, Alaska Shark Tooth 1 (501032064700) CD/digital log data & hardcopy report CANR/G Final Well Report-Mudlogging data-Shark Tooth#1, compiled 2/16/2012; equipment and crew,well data,geologic data, pressure/formation strength,drilling data,show reports,daily reports,formations logs` Color logs of Formation(MD),gas ratio(MD);LWD Combo(MD)'drilling dynamics(MD),cd co gins dailty reports, DML data,final well report, LAS f les, Log PDF files, remarks files,and TIFF files *Shark Tooth 1 was dill/ed as an exploration well-All data is confidential until State of Alaska(AOGCC)designated release date Transmittal instructions: please promptly sign, scan, and return to e-mail address below CC: Shark Tooth 1 -e-transmittal well folder Receipt: � �". vl Date: 2 7 Kilo /T:55-Technical Data Management i ConocoPhillips i Anchorage, Alaska I Ph: 907265:6947 Sandra.D.Lemke0Conocovhillips com ConocoPhilli s TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke,AT00340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave. Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501-3590 RE: Shark Tooth 1 Permit: 211-165-0 DATE: 04/10/2012 /Transmitted: North Slope, Alaska Shark Tooth 1 (501032064700) -T' 3 � i-, ( ts, CD/digital log data C -1-Al 3 Ag KC-4;01;v"1),4 �°';,��``" Hal/ibu WD final processed data 2/13/2012 logging date; digital data; digital graphic logs vZ t S , servoir Description tool; Extended Range Micro Imager;Wavesonic; runs 2/3/2012, 2/13/2012, 2/14/2012 LAS/DLIS data, digital logs, Interpretation report _Halliburton Definitive directional survey; .txt and .pdf report file C1cc4) e 1 J Log prints-1 each L' -4/CTN/ALD/ADR; 1:600&1:240 MD /EWR-4/CTN/ALD/ADR; 1:600/1:240 TVD 1_" XRMI-Detail nalysis 1:20 XRMI-extended range fracture frequency 1:240; XRMI extended range Borehole breakout 1 ; XRMI extended range-detailed analysis plot; 1: 02 ;Wavesonic Semp anc� a processed;Wavesonic Anistrophy; V I field prints;Wavesonic; Wavesonic 2/3/2012; extended range micro imager 2/14/2012; reservoir description tool RDT-A 2/13/2012 Hardcopy reports RECEIVED X�R I Image Log processing report 2/24/2012 `-RDT Pressure Transient Analysis 2/13/2012 APR 1 0 2012 AOGCC *Shark Tooth 1 was drilled as an exploration well-All data is confidential until State of Alaska(AOGCC)designated release date Transmittal instructions: please promptly sign, scan, and return to e-mail address below CC: Shark Tooth 1 -e-transmittal well folder Receipt: a Date: (0 G L ITSS-Technical Data Management j ConocoPhillips J Anchorage,Alaska I Ph:907.265.6947 Sandra.D.L emkeCa7Conocophillips.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil El Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory Cl GINJ Cl WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: February 22,2012- 211-165/312-059 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 January 18,2012- 50-103-20647-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1793'FNL, 1023'FEL,Sec.20,T1ON, RO8E, UM February 12,2012 , Shark Tooth#1 Top of Productive Horizon: 8.KB(ft above MSL): - 149'RKB 15.Field/Pool(s): 1797'FNL, 1022'FEL,Sec.20,T1ON,RO8E, UM GL(ft above MSL): 121'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 1791'FNL, 1019'FEL,Sec.20,T1ON, RO8E,UM surface Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-481546 y- 5925974 Zone-4 6688'MD/6688'TVD ADL 25603 TPI: x-481550 y- 5925970 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-481553 y- 5925976 Zone-4 none 2677 18.Directional Survey: Yes ❑✓ No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1391'MD/1391'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res/Sonic/Neutron/Density not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.58# B surface 82' surface 82' 30" 91 sxAS 1,181 sxAS 1 10.75" 45.5# L-80 28' 2590' 28' 2590' 13.5" 1108 sx Arctic LiteCRETE,234 sx DeepCRETE 7.625" 29.7# L-80 26' 6244' 26' 6244' 9.875" 489 sx Class G w �Z y�' Z.Z. VY' ( 2'-I'-f ' CSL SS ' C. 7C- e.)M -fz 7-1, --/- 3-s'-12 24.Open to production or injection? Yes ❑ No ❑✓ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) none none none RECEIVED26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. .,ir r j t#Iv,: , ® DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1 p ' MAR 0 7 2012 surface to 1500' 362 sx ASI surface to 300' 77 sx AS 1 ' 6144'-6688' 165 sx Class G 7 Ste" i Alaska Oil&Gas Cons. Commission 5700'-6135' 89 sx Class G d(f p/ 27. Anchorage PRODUCTION TEST Date First Production ing,gas lift,etc.) not applicable plugged Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑✓ No ❑ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. TO BE SENT WHEN AVAILABLE RaDMS le.,,,R IA 2012 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only _J. •. - Y-iz Aieb 28. GEOLOGIC MARKERS(List all formations and mi encountered): 29. FORMATION TESTS NAME MD TVD Well tested? [j Yes ❑✓ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1391' 1391' needed,and submit detailed test information per 20 AAC 25.071. Top Kuparuk 6316' 6316' Base Kuparuk 6435' 6435' N/A • Formation at total depth: Miluveach 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey,4 photos,as-built 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: DAR Reimer @ 263-4347 Printed Name Alvord Title: Drilling Manager Signature Phone 265-6120 Date 3 4;12.011- INSTRUCTIONS b/2.01LINSTRUCTIONS 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 - 1 (05 Guhl, Guhl, Meredith D (DOA) 2L-11H9 From: Lemke, Sandra D [Sandra.D.Lemke@conocophillips.com] Sent: Monday, April14, 2014 6:13 PM To: Guhl, Meredith D (DOA); Bender, Makana K(DOA) Cc: Allsup-Drake, Sharon K; Bottrell, Phil M; Elgarico, Richard E Subject: FW: Shark Tooth 1 reporting compliance-final deliverables Attachments: Conoco Phillips Shark Tooth No.1 HH-55704 Core Data 8-27-2012(1).xls; Copy of Conoco Phillips Shark Tooth No.1 HH-55704 Submerged Cleaning Study Data 10-4-2013.xlsx; Geochem RSWC Chip descriptions.doc; Rotary sidewall core 5feb2012.xls; SharkToothl corel_chip_descriptions_12Feb2012 (2).xls; Shark_Tooth_1_AOGCC_finaldata_trans_ 14APR14 .doc Meredith and Makana, Here are the 5 outstanding reports that I don't have record of sending you. I think the core analysis may be duplicate of that delivered 24SEPT12 but since I truncated the name on the transmittal I can't be sure—so I'm resending it. The transmittal for this data is also included as an attachment here. Please sign, scan and return at your earliest convenience. I will include the 4 signed transmittals for data already sent over to AOGCC on Shark Tooth 1 to you in the next e-mail. I don't want to get transmittals and new data delivery mixed up. Please review the signed transmittals along with the new 5 files I'm sending to day and get back with me if you feel there is still missing data. I will be on vacation April 18- 27. Sandra D. Lemke Alaska IT Staff Associate-Data ConocoPhillips Alaska 700 G Street,AT01412 Anchorage,AK 99501 (907)265-6947 phone, (907)440-4512(cell) Sandra.D.Lemke@COP.com SCANNED AUG 1 2 2014 From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Monday, April 14, 2014 9:37 AM To: Bottrell, Phil M; Allsup-Drake, Sharon K Cc: Davies, Stephen F (DOA) Subject: [EXTERNAL]RE: Shark Tooth 1 reporting compliance deliverables estimate? Hello Sharon and Phil, I did locate the 10-407, it had delivered to the statistical technician. Were there any laboratory analyses completed on the cores? Porosity, permeability, etc? Or any photographs taken? If so, those results need to be submitted. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission /- 1 11H ( 5 Z Ll ( LE°I meredith.guhl@alaska.gov Direct: (907) 793-1235 From: Guhl, Meredith D (DOA) Sent: Monday, April 14, 2014 9:08 AM To: Bottrell, Phil M Cc: Davies, Stephen F (DOA) Subject: Shark Tooth 1 reporting compliance deliverables estimate? Hello Phil, Can you please provide a date estimate for when I can expect the deliverables for reporting compliance? I received your message about the missing samples but there are other outstanding items in addition to samples. At this time I have only received the survey data.See the attached email for the other required items. Thank you for your assistance. Sincerely, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907)793-1235 2 ZII - 1 (o5 Iv" I Li COnOCOPhillipS TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke,ATO-03-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501 RE: Shark Tooth 1 Permit: 211-165-0 DATE: 04/14/2014 Transmitted: North Slope, Alaska Shark Tooth 1 (501032064700) RECEIVED Exploration Tax Credit data submittal AP 1 5 20111, Transferred via e-mail AOGCC ✓Shark Tooth 1 -Submerged Cleaning Study data, 10-4-2013 (.xlsx) ✓ Shark Tooth 1 HH-55704 Core analysis data 9-27-2012 (.xls) (pk6 r n 2/8 s3) ✓Shark Tooth 1 Geochem rotary Sidewall core description (.doc) ✓ Shark Tooth 1 Core 1_chip description 12_Feb 2012(.xls) hark tooth 1 Rotary Sidewall core description 5FEB2012 (Bannan and Goyette) (.xls) Transmittal instructions: please promptly sign, scan, and return to e-mail address below CC: Shark Tooth 1 -e-transmittal well folder i�� / OP `/�l�� Recei t: ✓► Date: echnical Data Management I ConocoPhillips I Anchorage,Alaska I Ph:907.265,6947 Sandra.D.LemkecConocophillips.com 2A c`-f9 02//-165 Guhl, Meredith D (DOA) From: Lemke, Sandra D [Sandra.D.Lemke@conocophillips.com] Sent: Monday, April 14, 2014 6:16 PM To: Guhl, Meredith D (DOA); Bender, Makana K(DOA) Cc: Allsup-Drake, Sharon K; Bottrell, Phil M Subject: signed transmittals from AOGCC for Shark Tooth 1 Attachments: Shark Tooth 1_AOGCC 23AUGI2.pdf; Shark Tooth 1_AOGCC_logs_10APR12.pdf; Shark Tooth 1_AOGCC_ML_27APR12.pdf;_ Shark Tooth 1_AOGCC_pnp_MGI_geochem_ 24Sept12.pdf Data previouslysent and signed for at AOGCC on Shark Tooth 1. g Sandra D. Lemke Alaska IT Staff Associate-Data ConocoPhillips Alaska 700 G Street,AT01412 Anchorage,AK 99501 (907)265-6947 phone, (907)440-4512(cell) Sandra.D.Lemke@COP.com ;28 ,21yc>72-- I 7-(r)l7cr a� 55� ConocoPhullu S p RECEIVED TRANSMITTAL APR 142012 , CONFIDENTIAL DATA AOGCC FROM: Sandra D. Lemke,AT00340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC 2 13 2- P.O. Box 100360 333 W. 7th Ave.Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501-3590 2) 2 13 RE: Shark Tooth 1 Permit:211-165-0 DATE:04/10/2012 - I 1I•I • North Slope, Alaska Shark Tooth 1 (501032064700) CD/digital log data H'all/burton WD final processed data 2/13/2012 logging date;digital data;digital graphic logs - 21 3 2� //Reservoir Description tool; Extended Range Micro Imager;Wavesonic; runs 2/3/2012,2/13/2012,2/14/2012 -21 3Z8 LAS/DLIS data,digital logs, Interpretation report Halliburton Definitive directional survey; .txt and .pdf report file0/(et, 4-4214.;/) 2I 32:3- Log 2 1Log prints- 1 each `/ROP/SGR/EWR-4/CTN/ALD/ADR; 1:600&1:240 MD - -2-1?)2T DGR/EWR-4/CTN/ALD/ADR; 1:600/1:240 TVD - 2' 3 27- KXRMI-Detailed analysis 1:20;XRMI-extended range fracture frequency 1:240;XRMI extended range Borehole breakout 1:240;XRMI extended range-detailed analysis plot; 1:20;Wavesonic Semplance processed;Wavesonic 113243 Anistrophy; Vfield prints;Wavesonic;2/14/2012;Wavesonic 2/3/2012; extended range micro imager 2/14/2012; reservoir 2_ 3 28 description tool RDT-A 2/13/2012 0000V Hardcopy reports Z102 a I ?ld'd >/ RMI Image Log processing report 2/24/2012 it 3 2$ V RDT Pressure Transient Analysis 2/13/2012 it 32. a3A13331:I *Shark Tooth 1 was drilled as an exploration well-All data is confidential until State of Alaska(AOGCC)designated release date Transmittal instructions: please promptly sign,scan, and return to e-mail address below CC: Shark Tooth 1 -e-transmittal well folder t 3 27- / 2 ,2136 Receipt: / Date: /U 6 1 �--- XIS-Technical Data Management:I-ConocoPh/ll os.!Anchorage,Alaska I Ph:907265 6947 Sandra.D.Lemke aConocophillips cam INV ConocoPPhilll s P TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke,AT00340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7"'Ave.Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501-3590 RE: Shark Tooth 1 Permit 211-165-0 DATE: 04/27/2012 North Slope,Alaska Shark Tooth 1 (501032064700) CD/digital log data & hardcopy report a 1 Z CANR/G Final Well Report-Mudlogging data-Shark Tooth#1,compiled 2/16/2012; equipment and crew,well data,geologic data, pressure/formation strength,--drilling data,show reports,daily reports,formations logs; Color logs of Formation(MD),—gas ratio(MD);LWD Combo(MD)'drilling dynamics(MD);cd contains dailty reports, DML data,final well report, LAS files, Log PDF files, remarks files and TIFF files' *Shark Tooth 1 was drilled as an exploration well-All data is confidential until State of Alaska(AOGCC)designated release date Transmittal instructions: please promptly sign,scan,and return to e-mail address below CC: Shark Tooth 1 -e-transmittal well folder Receipt: Ltk/7� Date: ,2 7 ear2.e1 i IT. S-Technical Data Management 1 ConocoPhi//ips I Anchorage, Alaska Ph: 907.265.6947 Sandra.D.LemketaConomphi/lips com (2114(02- ConocoPhillips f� TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke,AT00340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W.7th Ave. Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501-3590 RE: Shark Tooth 1 Permit: 211-165-0 DATE: 08/17/2012 Transmitted: 1 •(o 3 North Slope, Alaska Shark Tooth 1 (501032064700) CD/digital data Laser grain size analysis and graphs;Weatherford;Job HH-55704; 6326.05-6363' and(zip file) LPSA-Laser grain size conventional core raw data;Weatherford;Job HH55704;6326-6363(.xls) Core Photos_Weatherford labs;Job HH-55704; stitched TIFF files(folder) Thin Section photo micrographs(.ppt)-core 6324-6362 including detailed descriptions and formation/facies(.xls) folder 3 files-Sidewall grain size and point count+converted to load format file(.xls) 2 files Conventional Core grain size and point count data(.xls) Total Gamma RCA Profiles,2-16-12;Weatherford Job HH-55704(.xls) , FIT Test 2/9/2012(.xls) ( GT3 scan 2-11-12(.xls) Load on tool 12/30/11 (.xls) Shark Tooth 1 was drilled as an exploration well-All data is confidential until State of Alaska(AOGCC)designated release date Transmittal instructions:please promptly sign, scan,and return to e-mail address below CC: Shark Tooth 1 -e-transmittal well folder Receipt: - � `" Date: k ul ( , t ► L ITSS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph:907.165.6947 Sandra.D.Lemke0Conocovhillips.com ConocoPhillips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke,AT00340 TO: Howard Okiand ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave, Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501-3539 RE: Shark Tooth 1 Permit: 211-165-0 DATE: 09/25/2012 Transmitted: a t '55 North Slope, Alaska Shark Tooth 1 (501032064700) CD 1/digital.data —P&P Analysis (1 .xls file) Geochem (5 folders, 3 .xls files) Z [Uo S -j _Mudgas Isotope data (2.xls files) Shark Tooth 1 was drilled as an exploration well-All data is confidential until State of Alaska(AOGCC)designated release date Transmittal instructions: please promptly sign, scan, and return to e-mail address below CC: Shark Tooth 1 -e-transmittal well folder 42Receipt: Date: ? " a 1T55-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph:907.265.6947 Sandra.D.LemkeaConocophillips com J t19 3 4 s ''r, �P ,SIS kT�¢th m .,e d, r Tootham ► 1 organize T .Ipdude in library Skk,rswith Burn l�tn+fp�dfit q -- Name Date modified Type Size Fayonts�. IN Desktop Lb August 19 delivered 9/24/201211;03 AM File folder Downloads IN Shark ToothNo1_ARO.GCMS 9/24/20122:04 PM File folder '9 Recent Places Shark Tooth No.1_Extract GC_CS2 Extracti... 9/24/20122;04 PM File folder Lti Shark Tooth Not Extract GC_Soxhlet Extr.,, 9/24/2012 2:04 PM File folder cl Libraries j4 Shark Tooth No,1 GCMSMS 9/24/2012204 PM File folder 12 Documents Shark Tooth NotSAT.GCMS 9/24/2012 204 PM File folder 2012-03-22_HolbaMudGas_SWC selectxis 6/14/201212;17 PM Microsoft Excel 97... 79 KB $S Computer eiConoco Phillips Shark Tooth No.1 HH-55.., 8/29/2012&04 AM Microsoft Excel 97.,, 383 KB ito OSDisk(G) 61 Isotopes Shark Tooth No.xls 8/14/2012 12:13 PM Microsoft Excel 97... 74 KB slemke$(\\anna05) L.'al MPLC Shark Tooth Noxls 8/14/201212;13 PM Microsoft Excel 97— 103 KB AK shared(1lconoc Shark Tooth_1._Pull 8-14-12.xls 8/14/201211;15 AM Microsoft Excel 97.,, 1,010 KB SOXHLET Shark Tooth Noxls 8/14/2012 12:13 PM Microsoft Excel 97... 79 KB Network 12 items a G.L.Alvord Alaska Drilling Manager Drilling&Wells P.0.Box 100360 INV Anchorage,AK 99510-0360 conocol'Iiilhips Phone: 907-265-6120 April 8, 2014 AOGCC Y r w Commissioner 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Subject: Revised Completion Report for Shark Tooth #1 Dear Commissioner: Attached for your review is the revised completion report for Shark Tooth #1. Corrections to the original completion report include additional data in box 28 and box 29. Attached to the revised AOGCC form 10-407, are the core descriptions for both cores. This package should be added to the data we already sent with the original completion report which includes the final directional survey, daily operations summary and a schematic. We are still waiting for the sample cuttings from the vendor and we will send this to you as soon as we receive it. If you have any questions, please feel free to call me at anytime. Sincerely, 4L0& G. L. Alvord Alaska Drilling Manager CPAI Drilling GLA/BN/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION �,��.,, WELL COMPLETION OR RECOMPLETION REPORT AND LO ' -" la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory 0 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: February 22,2012 211-165/312-059 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 January 16,2012 50-103-20647-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1793'FNL, 1023'FEL,Sec.20,T1ON, R8E, UM February 12,2012 Shark Tooth#1 Top of Productive Horizon: 8.KB(ft above MSL): 149'RKB 15.Field/Pool(s): 1797'FNL, 1022'FEL,Sec.20,T1ON, R8E,UM GL(ft above MSL): 121'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 1791'FNL, 1019'FEL,Sec.20,T1ON,R8E, UM surface Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-481546 y- 5925974 Zone-4 6688'MD/6688'TVD ADL 25603 TPI: x-481550 y- 5925970 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-481553 y- 5925976 Zone-4 none 2677 18.Directional Survey: Yes Q No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1391'MD/1391'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res/Sonic/Neutron/Density not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.58# B surface 82' surface 82' 30" 91 sx AS 1,181 sx AS 1 10.75" 45.5# L-80 28' 2590' 28' 2590' 13.5" 1108 sx Arctic LiteCRETE,234 sx DeepCRETE 7.625" 29.7# L-80 28' 6244' 28' 6244' 9.875" 489 sx Class G 24.Open to production or injection? Yes ❑ No ❑✓ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) none none NONE 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No Q DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED surface to 1500' 362 sx AS I surface to 300' 77 sx AS I 6144'-6688' 165 sx Class G 5700'-6135' 89 sx Class G 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) not applicable plugged Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes �❑✓ No ❑ Sidewall Cores Acquired? Yes ❑ No ❑ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. Conventional Core-Formations cored:Kuparuk C and A sands Depths cored-Core#1:6323'MD-6373'MD(recovered 44') Summary of Lithology-see attached core chip descriptions Sidewall Core-Formations cored:Brookian Tarn/Bermuda Depths cored-4932'MD-5700'MD (15 cores) Summary of Lithology-see attached core chip descriptions Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑✓ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1391' 1391' needed,and submit detailed test information per 20 AAC 25.071. C-90 2642' 2642' C-85 2660' 2660' C-80 2910' 2910' C-50 4297' 4297' C-40 4582' 4582' C-37 4775' 4775' C-35 5734" 5743' C-31 5753' 5753' C-30 5891' 5891' C-20 6086' 6086' Kalbk 6130' 6130 K-1 6224' 6224' N/A Kuparuk 6316' 6316' Kuparuk C-4 6316' 6316' Kuparuk A-5 6328' 6328' Kuparuk A-4 6343' 6343' Kuparuk A-3 6418' 6419' Miluveach 6435' 6435' Formation at total depth: Miluveach 31. LIST OF ATTACHMENTS Description of Rotary Sidewall Core,Sidewall Core description 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brian Noel @ 265-6979 •a Email: Brian.Noel Cacop.com Printed Name /� ,G.L.Alvord Title: Alaska Drilling Manager Signature /�J�_Q./� Phone 265-6120 Date 4/I3120 q— _ 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20.Provide MD and ND for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Exported Table Data Common Well Name * Name Depth (feet) Depth [TVD] SHARK TOOTH 1 PFROST 1391 1391 SHARK TOOTH 1 C-90 2642 2642 SHARK TOOTH 1 C-85 2660 2660 SHARK TOOTH 1 C-80 2910 2910 SHARK TOOTH 1 C-50 4297 4297 SHARK TOOTH 1 C-40 4582 4582 SHARK TOOTH 1 C-37 4775 4775 SHARK TOOTH 1 C-35 5734 5734 SHARK TOOTH 1 C-31 5753 5753 , SHARK TOOTH 1 C-30 5891 5891 SHARK TOOTH 1 C-20 6086 6086 SHARK TOOTH 1 KALBK 6130 6130 SHARK TOOTH 1 K-1 6224 6224 SHARK TOOTH 1 KUP 6316 6316 SHARK TOOTH 1 KUP C4 6316 6316 SHARK TOOTH 1 KUP_A5 6328 6328 SHARK TOOTH 1 KUP_A4 6343 6343 SHARK TOOTH 1 KUP A3 6418 6417 SHARK TOOTH 1 MILV 6435 6435 .291 Shark Tooth #1 Rotary Sidewall Description Dave Bannan and Jennifer Goyette 5-Feb-12 DEPTH(md) Description odor/stain vis fluor cut Fluor visible cut ring light brown ss, lower very fine,salt and pepper,quartz and lith fragments,white tuffaceous matrix,sub ang-sub rnd, 5700 moderate sorted, poor porosity. none none none none none light brown ss, lower very fine, salt and pepper,quartz and lith fragments,white tuffaceous matrix,sub ang-sub rnd, very faint 5680 moderate sorted, poor porosity none none dull yellow none none light brown ss, lower to upper very fine,salt and pepper,quartz, lithic, and brown mica grains,sub ang-sub rounded, poor to 5646 moderate porosity none none none none none light brown ss, lower to upper very fine,salt and pepper,quartz, lithic, and brown mica grains,dull white tuffeceos matrix, sub ang to sub rnd, moderate sorted,calcite 5630 cemented none none none none none light brown ss, lower to upper very fine,salt and pepper,quartz, lithic,dull white tuffeceous matrix reduced from sample below(5630'), sub ang to sub rnd, light petroleum moderate sorted(slightly better sorted than odor; no visible even bright fast milky bright yellow 5590 samples below, but not well sorted) staining yellow cut none ring light brown ss, lower to upper very fine, salt and pepper,quartz, lithic,fewer dark even bright lithics,dull white tuffeceous matrix still yellow with reduced similar to sample @ 5590', sub faint petroleum scattered fast milky bright yellow 5587 ang to sub rnd, moderate sorted odor gold cut faint light b ring light brown ss, lower to upper very fine,salt and pepper,quartz, lithic,some light green grains,fewer dark lithics,dull white tuffeceous matrix still reduced similar to sample @ 5590', sub ang to sub rnd, light petroleum even bright slow milky faint yellow 5586 moderate sorted odor yellow cut none ring 5559 mudcake 5364 dark gray mudstone with poorly developed t none none none none none light brown ss,quartz, lithics with not as many dark, upper very fine,clayey matrix, sub ang to sub rnd, moderate sorted, light petroleum slightly more friable than samples below in odor/even light even gold to fast milky light bright yellow 4987 bermuda brown stain bright yellow cut brown ring • slightly less light brown ss,quartz, brown mica and intense lithics with not as many dark, upper very strong yellow ring fine,clayey matrix,sub ang to sub rnd, petroleum even gold very faint than sample moderate sorted,slightly more friable than odor/even light with some fast milky light below 4976 samples below in bermuda brown stain bright yellow cut brown (4987') even gold to slightly yellow ring light brown ss,quartz, lithics with not as yellow; slower similar in many dark, upper very fine,clayey matrix, strong slightly less milky cut intensity as sub ang to sub rnd, moderate sorted, petroleum intense than than sample slightly more friable than samples below in odor/even light below sample below @ 4948 bermuda brown stain sample below none 4976' light brown ss, salt and pepper,quartz, milky cut lithics, upper very fine,slightly clayey strong similar to matrix,sub ang to sub rnd, moderate petroleum even gold previous sorted,slightly more friable than samples odor/none to with some sample @ light yellow 4947 below in bermuda slight staining bright yellow 4948 none ring light brown ss,salt and pepper,quartz, lithics, upper very fine, clayey matrix,sub ang to sub rnd, moderate sorted, slightly more friable than samples below in light petroleum even very slow milky faint yellow 4934 bermuda odor/none faint gold cut none ring 4932 slightly silty brown mudstone none/none none none none none �44/ii 9 2 a) o E E 22f E p » » £ » ® £ £ :£ m o ƒ c .0 % _a Ti) - \ %f _a \ c.i CD LL kO \ \@ . � w § =. o : o » c _a q k _a @ -- a) G O m / 2 ) » / ± o c E �a E ° E o ƒ c t E f t t E • = E / 2 m w \ c / _c LI@ c % C » E - » q % ° f » 9 m >,2 a co t c ° o > 2 $ k $ \ %\ .0 \2 q % 2as to 2 ° k 2 8 2 a £ E = -00E 2 ? 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N X (9 I d Co O Y O Cl) Co Q I1 t N 0) N 7 O I- CO• O Cr) N- O 1 OU /) _ e L = d O O Z• LL D N >, O 0 a i co O J CL CO O C U r co N O 00 (0 (n N N N O lueoJed 'glee o!uos- sod A1!saod Ce0 a CI o Z o Q H J CO a 2 co U ce O (Q w . . . • O -a a • — E • ..:-t- 0 >, La Co O E Oa U - co C - O (0 N Y II Cl, (l ,- >+ Q O Iwcc az O it ¢ O H j O O OC mt 1E o U Y as O U Y sA3Jep!II!W `glee o!uos-sod J!y o;A�!I!geaLuJad Weatherford I.ABORATORIES PERMEABILITY VERSUS POROSITY Convection Dried at 200°F ConocoPhillips Alaska, Inc. 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North Slope Borough, Alaska Shark Tooth No. 1 Well File: HH-55704 Kuparuk Field Date: 8-27-12 Permeability, Sample at 2000 psi NCS, Porosity, Grain Core Sample Depth, Plug millidarcys percent Density, Number Number feet Orientation to Air I Klinkenberg at 2000 psi gm/cc 1 1-2 6324.05 Horizontal 0.305 0.207 14.3 3.02 1 1-2V 6324.20 Vertical 0.025 0.011 15.4 3.17 1 1-3 6325.10 Horizontal 0.118 0.070 17.8 2.91 1 1-3V 6325.20 Vertical 0.067 0.037 16.9 3.00 1 1-4 6326.05 Horizontal 8.43 6.78 22.0 2.94 1 1-4V 6326.20 Vertical 0.0074 0.0024 12.8 3.08 1 1-5 6327.00 Horizontal 0.042 0.021 14.5 3.13 1 1-5V 6327.20 Vertical 0.025 0.011 17.1 3.14 1 1-6 6328.00 Horizontal 0.062 0.033 12.2 2.74 1 1-6V 6328.20 Vertical 0.022 0.0094 14.8 2.74 1 1-7 6329.00 Horizontal 2.03 1.57 16.6 2.65 1 1-7V 6329.20 Vertical 1.39 1.03 16.4 2.65 1 1-8 6330.00 Horizontal 0.148 0.091 15.8 2.63 1 1-8V 6330.20 Vertical 0.044 0.022 15.6 2.64 1 1-10 6332.00 Horizontal 0.051 0.027 12.8 2.65 1 1-10V 6332.20 Vertical 0.0052 0.0015 10.7 2.63 1 1-11 (pf) 6333.00 Horizontal 0.061 0.033 13.9 2.64 1 1-11V 6333.20 Vertical 0.040 0.020 14.3 2.65 1 1-12 6334.00 Horizontal 0.039 0.019 10.5 2.64 1 1-12V 6334.20 Vertical 0.0019 0.0004 10.8 2.64 1 1-13 6335.00 Horizontal 0.012 0.0043 10.7 2.64 1 1-13V 6335.20 Vertical 0.0050 0.0015 11.0 2.65 1 1-14 6336.00 Horizontal 0.028 0.012 13.1 2.66 1 1-14V 6336.20 Vertical 0.0095 0.0033 12.3 2.66 1 1-16 6338.00 Horizontal 0.020 0.0087 11.8 2.66 1 1-16V 6338.20 Vertical 0.016 0.0066 12.8 2.64 1 1-17 6339.00 Horizontal 0.014 0.0056 11.6 2.68 1 1-17V 6339.20 Vertical 0.023 0.0099 9.5 2.64 1 1-18 6340.00 Horizontal 0.0059 0.0018 10.9 2.66 1 1-18V 6340.20 Vertical 0.0014 0.0003 9.9 2.65 1 1-20(f) 6342.00 Horizontal 0.404 0.283 9.2 2.65 1 1-20V 6342.20 Vertical 0.0006 0.0001 9.9 2.68 1 1-21 (f) 6343.00 Horizontal 0.418 0.294 9.0 2.68 1 1-21V 6343.20 Vertical 0.0044 0.0012 11.3 2.67 1 1-28 6350.00 Horizontal 0.040 0.019 11.2 2.66 1 1-28V 6350.20 Vertical 0.012 0.0043 13.2 2.66 1 1-30 6352.00 Horizontal + 2.66 1 1-30V 6352.20 Vertical 0.0062 0.0019 11.5 2.65 1 1-31 6353.00 Horizontal 0.022 0.0095 11.2 2.65 1 1-31V 6353.20 Vertical 0.0024 0.0006 8.3 2.63 1 1-33 6355.00 Horizontal 0.044 0.022 15.3 2.92 W Weatherford LABORATORIES SUMMARY OF HORIZONTAL VERSUS VERTICAL CORE ANALYSES RESULTS ConocoPhillips Alaska, Inc. North Slope Borough, Alaska Shark Tooth No. 1 Well File: HH-55704 Kuparuk Field Date: 8-27-12 Permeability, Sample at 2000 psi NCS, Porosity, Grain Core Sample Depth, Plug millidarcys percent Density, Number Number feet Orientation to Air I Klinkenberg at 2000 psi gm/cc 1 1-33V 6355.20 Vertical 0.235 0.154 18.3 2.65 1 1-34 6356.00 Horizontal 53.1 46.0 22.0 2.64 1 1-34V 6356.20 Vertical 28.4 23.9 22.3 2.63 1 1-35 6357.30 Horizontal 26.8 22.4 21.5 2.63 1 1-35V 6357.20 Vertical 43.5 37.4 21.6 2.64 1 1-36 6358.60 Horizontal 0.019 0.0077 16.3 2.91 1 1-36V 6358.20 Vertical 0.051 0.026 16.3 2.66 1 1-37 6359.30 Horizontal 7.14 5.60 20.8 2.63 1 1-37V 6359.20 Vertical 1.39 1.09 21.0 2.63 1 1-38 6360.00 Horizontal 39.2 33.4 22.1 2.66 1 1-38V 6360.20 Vertical 1.28 1.01 21.9 2.65 1 1-39 6361.25 Horizontal + 2.64 1 1-39V 6361.20 Vertical 49.8 42.9 22.2 2.65 1 1-40 6362.05 Horizontal 0.183 0.116 12.6 2.66 1 1-40V 6362.20 Vertical 0.0052 0.0015 13.8 2.65 1 1-41 6363.00 Horizontal 0.191 0.122 14.0 2.66 1 1-41V 6363.20 Vertical 0.027 0.012 16.5 2.66 1 1-42 6364.00 Horizontal 0.262 0.174 14.2 2.64 1 1-42V 6364.20 Vertical 0.018 0.0074 14.0 2.63 1 1-43 6365.00 Horizontal 0.022 0.0097 15.2 2.65 1 1-43V 6365.20 Vertical 0.0050 0.0015 12.1 2.67 1 1-44 6366.00 Horizontal 0.125 0.075 14.4 2.65 1 1-44V 6366.20 Vertical 0.0039 0.0011 11.6 2.67 U, N aB _,C - u) • • coQ _cO o) N 7 0 O m Ol,1 • •• a)a a)an O O , N a) 7 2 co 2 a) U o °) it Z Z it O —6 H >, CO • • _ - CL u • • • • o a a o __ O N 1 M • N a) a� ce W o • • Z 4) O F— U o co co N < aoeds aiod waalad `suoi}eanTes pine Cen H -o • 7 Cl) 2Ln N O N . 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Cement Pumped i r / i %5 5 i s j Cement Retainer Set @ 300'MD 16" 65# H-40 @ 4 I y 82'MD/TVD i % % i f10-%' x 7-5/8"Annular Cement Plug / / / / i i i Volume:65.7 BBL 15.8 Arctic Set 1 0 i Cement Pumped At Surface 0 f 0 5 0: : ) l0 Surface Casing y y i � l 10-3/4"45.5#L-80 BTC i (2590'MD/TVD) 3' 0 f 0 i I Cement Plug Tagged @ 5903'MD/TVD Intermediate Casing Volume:56.9 BBL 15.8 Arctic Set 1 7-5/8"29.7#L-80 BTCM Cement Pumped (6244'MD/TVD) Pressure Test:1600 psi 6-3/4"Open Hole TD:6688'MD/TVD ion JPE 02/28/12 ARNOW REV DATE BY CIC APP DESCRIPTION REV DATE BY APP DESCRIPTION NOTES IR 16 PS71. GRID AND GEODETIC COORDINATES ARE ALASKA STATE PLANE, --- - .2A 11 aEsrU �`14 4 2I ZONE 4, NAD 83. 20 22 07 • ,p ' 20 , mi 2. HORIZONTAL COORDINATES WERE DERIVED HOLDING THE OPUS _ .. ........................_:...._._./ R .`i^ 4 PF-2- SOLUTION FOR RP1, POST PROCESSING RP2 AND DS2_K-NOR TH. Zn ^,6 �,1.-_-rte_' ,, 3. ELEVATIONS ARE B.P,M.S.L. D 2M' i " 4. ELEVATIONS WERE DERIVED HOLDING DS2K-NORTH MONUMENT & s2 -1-'-----m-34� '--l5 ,._ r I--- .... _ -)S-2H DS-2F POST PROCESSING IT WITH RP1. ,2 „ 5. SCALE FACTOR IS 0.999900200, DERIVED BY TAKING THE AVG. T11N IDS-2Q SCALE FACTOR FROM OPUS SOLUTIONS FOR RP1 AND _pow 1 1 ' DS2K-NORTH. ' ' ! 2 ' I m'' 5 " 6. WELL IS LOCATED WITHIN PROTRACTED SECTION 20, T1ON, R8E, ! S-2K UMIAT MERIDIAN. a __,_..,.,..,__..,., : a9 7. DATE OF SURVEY: 01/10/12, FIELD BOOK L12-03 pp37. THIS , PROJEC! 11 :E 15 14 13 IP ,2 16 V\ i 17 16 (._..__...._..._._...._._.. _._ __._._....._._. 6 ARKT°9711 z, ! 1Q m , 21 N 20 21 VICINITY MAP (Not To Sege) Section Corner I T1ON., R8E. I SCALE: '.®®®'y�� -,50 ®.�� OF .... 44, ® 4.4V-...C • •,S4-®11 LOy � 49th 1 i 7,p� 0 0 i 0 c� ` `•LAN 1 ROOKUS s ao/ 41 it I- A� 111 s• LS-eons ,•,. Jr SHARK TOOTH SURVEYOR'S CERTIFICATE EXPLORATORY ICE PAD I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT LEGEND SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF AS-BUILT CONDUCTOR LOCATION JANUARY 10, 2012. CONDUCTOR IS LOCATED IN PROTRACTED SECTION 20, T. 10 N., R. 8 E. ASP COORDINATES GEODETIC SECTION OFFSET ELEVATIONS WELL ID y 'X' LATITUDE LONGITUDE F.N.L. F.E.L. 0.0. ICE PAD SHARK 5,925,724.20 1,621,582.20 70' 12' 30.993" 150' 09' 06.728" 1793' 1023' 117.9 121.4 TOOTH OALOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS vb AREA: MODULE: XXXX UNIT: ConocoPhillips SHARK TOOTH EXPLORATORY WELL CONDUCTOR Alaska, Inc. AS BUILT LOCATION CADD FILE NO, DRAWING NO. I PART: REV: LK6O1D779 01/10/12 I CEA—M1XX-601D779 1 OF 1 I 0 ConocoPhillips Time Log & Summary Wellvlew Web Reporting Report Well Name: SHARK TOOTH 1 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 1/17/2012 12:01:00 AM Rig Release: 2/18/2012 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 31/14/2012 24 hr Summary Rig release from 3N-11 Noon.Wait on weather to moderate. Prepare rig for move. 12:00 17:30 5.50 0 0 MIRU MOVE MOB P Wait on weather to moderate before rig move to Shark Tooth#1. PJSM. Change out handling tools from 4"to 5". Mud bucket, slips,tongs dog collar, iron roughneck dies, SIMOPS: take steam heater down to repair core,welding heater bracket in pipe shed, suck out vac-unit with super sucker, off load all fluids from the pits, rock washer. suck out cellar box. 17:30 00:00 6.50 0 0 MIRU MOVE MOB P Install new screens on shakers. Clean mud cleaner, clean up cellar. Pick up lift subs, clear rig floor of all tools not needed. Pick up 5" elevators, rig down geronimo line, blow down water lines and disconnect inner connects, disconnect glycol waste heat lines, rebuild test pump seals,freeze protect washing machine, cellar pump, and test pump. Disconnect flow line, mud lines, charge pump lines, pop off lines, Rig down mud pumps. Inspect swabs,valves, seats.Tighten drag chain, L/D saver sub. Pull inner rotary bushings and install plumb bob. Pull skate rail to floor. Lifted mud elevator, rig down handy berm around rock washer. Pick up all duck ponds. Clean suction manifold on#2 MP. SIMOPS: Roustabout crew laying down herculite on Sharks Tooth ice pad and mats for rig camp. Rig up hydril on new location. 31/15/2012 Prepare rig for move. Begin moving camp @ 0900 HRS. Camp on location 16:00 HRS.4 loads. 2 camp sections, sewer plant,welding shop. The Peak trucks went back to 3N for the first four rig modules. Page 1 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Continue to winterize the rig in preparation for rig move from 3N to Shark Tooth#1. Prepare camp for move. Blow down all water lines in camp. Begin move with four loads,2 camp modules, Sewer Plant module, Welding shop. Blow down steam in rockwasher and disconnect. freeze protect wash down pump. Did a 500 hour service on#2 Generator. Reassembled mud pumps. checked oil on all cold start generators. Start cold start gens. Change out leaky steam valve in rockwasher. 12:00 00:00 12.00 0 0 MIRU MOVE MOB P Continue to prepare the rig modules for move. SIMOPS on Shark Tooth. Set camp and sewer plant. Hook up lines. Bring camp on line for service. Sows returned to 3N to bring the rig modules.4 loads, 2 pipe shed mods, rock washer,sub base. Move rock washer, load on trailer. Separate boiler complex, motors, pump room, pits. Position mods to end of pad. Hook up to pipe sheds. Move to entrance with pipe sheds, rock washer. Move sub off of 3N-11 @ 23:00 hrs. SIMOPS: Nipple up diverter line to Hydril on Shark Tooth. 31/16/2012 Moved Doyon 141 from 3N-11 to exploration ice pad. Shark Tooth#1.25 miles one way.Three trips with 4 Peak Sows. Move in and rig up on well. 00:00 12:00 12.00 0 0 MIRU MOVE MOB P PJSM. Pull rig off 3N-11 well. Mobilize rig, pipeshed 1 &2, rockwasher, pipeshed heater to Shark Tooth#1. Spot rig on Shark Tooth#1. 25 mile travel distance. 5 hour travel time. Spot pipesheds, lay mats for rig.Trucks leave to go back to 3N Pad. Continue installation of diverter system.Winterize/Seal up cellar area. Rig up Tioga heaters into cellar. 12:00 15:30 3.50 0 0 MIRU MOVE MOB P Fuel camp. Continue to rig up diverter line. Diverter is 87'from closest ignition source. Fuel rig and pipeshed cold start generators with 500 gallon portable fuel tank. Continue to seal up and winterize cellar area, bring in 3rd Tioga heater. Page 2 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 00:00 8.50 0 0 MIRU MOVE MOB P Spot pits, pumps motors, boiler room modules. Shim up and level all rig components. Begin to hook up inner connects between modules,water, steam, air, glycol, mud line, flowline, pop off lines, suction lines,fuel lines. Plugged into Cat power, cycle off cold start generators. Begin to bring steam on as heat builds. Prepare rig for Rig Acceptance. Lowered all stairs and landings, bermed up pipeshed Tioga heater&rockwasher. Lifted skate rail,function test skate, load BHA into pipeshed, fueled rig up, and topped off Tioga heater. Fired up pipeshed heater. Bring on water. Nipple up Hydril. D1/17/2012 Rig accepted 00:01. Kuparuk River Bridge access road closed to heavy traffic due to drifting snow. Load pipeshed with BHA components, 180 joints of 5"DP, 14 joints 5"HWDP,jars.Verify all plugs are closed in the pits, check all valves, bring spud mud on board. Continue to winterize, and warm up all equipment after rig move. Pick up and rack back 60 stands of 5"DP, 5 stands HWDP, one stand of monels. 00:00 09:30 9.50 0 0 MIRU DRILL RURD P Rig accepted 00:01 hrs. PJSM. Hammer up diverter, Install riser, Install 4"ball valves on conductor, Pick up mouse hole, Load BHA#1 into pipe shed, 90 joints 5"DP into pipe shed. Strap all tools and drill pipe.Take on spud mud into pits. Double check all inner connects. Perform derrick inspection. 09:30 12:00 2.50 0 0 MIRU DRILL PULD P PJSM. Pick up singles of 5"DP out of the pipe shed and stand back. 12:00 13:45 1.75 0 0 MIRU DRILL PULD P PJSM. Continue to pick up and stand back 5"DP. 13:45 15:15 1.50 0 0 MIRU DRILL RURD P Load pipe shed with 90 joints of 5" DP.Thaw out and strap. Clean rig floor. 15:15 16:00 0.75 0 0 MIRU DRILL PULD P Continue to pick up DP from the pipe shed and stand back. 16:00 16:30 0.50 0 0 MIRU DRILL RURD P Calibrate top drive height indicator and depth wheel with Sperry.Test Crown-0-Matic 16:30 21:15 4.75 0 0 MIRU DRILL PULD P Continue to pick up 5"DP from the pipe shed and rack back in derrick. 21:15 00:00 2.75 0 0 MIRU DRILL PULD P Pick up and stand back 14 joints of 5"HWDP, set of jars, one stand of 8"NM Flex collars. 01/18/2012 Conduct Diverter test with AOGCC Rep John Crisp.Wait on weather and roads to be opened. Drill from 82' MD to 225' MD. Stop.Wait on weather. ( Rig crews cleaned and serviced the rig) Begin drilling again at midnight. Page 3 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 0 0 MIRU WHDBO BOPE P PJSM test diverter, Hi/Lo flow, pit gain/loss, and gas alarms w/state J` rep John Crisp.Accumulator test, system PSI=2900 PSI, PSI after closure=1900 PSI, 200 PSI precharge time 44 secs,full charge time= 182 sec, 5 bottle avg=1925 PSI. 02:00 09:30 7.50 0 0 SURFA( DRILL OTHR T Wait on weather:simops, scrub boiler room, oil room, cent.room, pump room, mud pits, cellar, rig floor,doghouse, clean up motor room. R/U heater to Canrig shack. 09:30 10:30 1.00 0 0 SURFA( DRILL PULD P PJSM M/U BHA#1 as per Halliburton rep. 10:30 12:00 1.50 0 75 SURFA( DRILL PULD P PJSM P/U 1 std. HWDP tag up 75' MD, flood lines w/spud mud 12:00 12:15 0.25 75 75 SURFA( DRILL PRTS P Pressure test T/3500 PSI (good) 12:15 14:15 2.00 75 225 SURFA( DRILL DRLG P Set drilling parameters-Pump 450 GPM=500 PSI, 30 RPM, Flow 53%, RIH tag up @ 75", MD drill f/75'MD t/111'MD out of pit 5 V drill out_ conductor cement.Swapped over to spud mud @ 111'MD and increased pump rate f/450 GPM t/550 GPM=800 PSI, Cont.t/drill f/111' MD V 225'MD. Total Jar hrs=50.89, Bit hrs=1.89, P/U wt=42K, S/O wt=41 K, Rot wt=40K, On=600 ft/lbs, Off=O, Flow out 53% 14:15 15:30 1.25 225 0 SURFA( DRILL TRIP T POOH f/225'MD L/D BHA/Stop drilling due to weather, inability to have access to 1R/G&I. WOW 15:30 16:15 0.75 0 0 SURFA( DRILL OTHR T Clean and clear rig floor 16:15 17:15 1.00 0 0 SURFA( DRILL SVRG T Service top drive and blocks 17:15 19:15 2.00 0 0 SURFA( DRILL RURD T Strap and rabbit casing in pipeshed. Clean rig, good house keeping. 19:15 21:15 2.00 0 0 SURFA( DRILL PULD P The Roads and Pads Group informed Doyon 141 that the path was clear to 1R Pad, and on into Deadhorse to the G&I Plant. Prepare to Drill. PJSM: Pick up Sperry BHA. Bit/ Motor/MWD. Orient. 21:15 22:15 1.00 0 0 SURFA( DRILL PULD P UpLoad MWD system. SIMOPS: Prepare the Super Suckers,water trucks, dirty fluid trucks for commencement of drilling. 22:15 00:00 1.75 0 0 SURFA( DRILL PULD P Pick up stand of monel collars, HWDP&jars.Wash down from 213' to 225'. No Fill. Survey.Trouble shoot stroke counter. 01/19/2012 Drilled from 225'MD to 1753'in 17.32 HRS, Rop=88'/hr. Good hole conditions. Max gas units=270.Average back ground units 45. Back ream each stand. Runnin. 40 BBLs/hr water. Mud temp 65°. Page 4 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 225 643 SURFA( DRILL DRLG P Drill F/225'T/643', 643 TVD, ART=4.61,AST=O,ADT=4.61,Total Jar hrs=55.51, Bit hrs=6.51, P/U wt=69K, S/O wt=74K, ROT wt=74K. TQ On=2K,TQ Off=1 Flow out 60%, GPM 550, RPM 90,Wt on Bit=10-12K 06:00 12:00 6.00 643 1,040 SURFA( DRILL DRLG P Drill F/643'T/1040'MD, 1040'TVD, ART=4.37,AST=0,ADT=4.37,Total Jar hrs=59.88, Bit hrs=10.88, P/U wt=73K, S/O wt=76K, ROT=76K.TQ On=1.5K,TQ Off=0, Flow out 57%, GPM 550, RPM 90,Wt. on Bit=10-15K 12:00 18:00 6.00 1,040 1,417 SURFA( DRILL DRLG P Drill F/1040'T/1417'MD 1417'TVD, ART=3.68,AST=.77,ADT=4.54. Total Jar hrs=64.33, Bit hrs=15.33, P/U wt=84K, S/O wt=86K, ROT= 87K,TQ On=2K,TQ Off=1K. Flow out=54%, GPM 550, RPM 80,Wt on Bit=10-15K 18:00 00:00 6.00 1,417 1,573 SURFA( DRILL DRLG P Drill F/1417'T/1573' MD 1571'TVD, ART=4.66,AST=.00,ADT=4.66. Total Jar hrs=68.22, Bit hrs=19.22, P/U wt=90K, S/O wt=91K, ROT= 92K,TQ On=2K,TQ Off=1K. Flow out=54%, GPM 650, RPM 100,Wt on Bit=10-15K D1/20/2012 Drilled from 1753' MD to 2603' in 11.72 HRS, Rop=73'/hr.Good hole conditions. Max gas units=329.Average back ground units 45. Back ream each stand. Running 40 BBLs/hr water. Mud temp 65°. Reach Total Depth @ 2603'MD. CBU 2x's. Short trip on elevators to top of HWDP. No over pull seen.TIH. Circulate and condition in preparation for cement job. 00:00 06:00 6.00 1,753 2,106 SURFA(IDRILL DRLG P Drill F/1753'MDT/2106'MD, 2106' TVD.ART=5.2,AST=.32,ADT=5.52. Total Jars hrs=74.51, Bit hrs=25.51, P/U wt.=95K, S/0 wt.=95K, ROT=96K,TQ On=2K,TQ Off=1K. Flow out 64%, Bit wt.=9-12K, RPM=100, GPM=650, Pump PSI=2000 06:00 12:00 6.00 2,106 2,412 SURFA( DRILL DRLG P Drill F/2106'MD T/2412'MD, 2412' TVD.ART=3.80 SLT=0,ADT=3.80. Total Jar hrs=78.31, Bit hrs=29.31, P/U wt.=100K, S/O wt.=101 K, ROT=103K,TQ On=2K,TQ Off=1K, Flow out 64%, Bit wt.=15-20K, RPM=100, GPM=650, Pump PSI=2025 12:00 15:30 3.50 2,412 2,603 SURFA( DRILL DRLG P Drill F/2412'MD T/2603' MD,2603' TVD.ART=2.72 SLT=0,ADT=2.72. Total Jar hrs=81.03, Bit hrs=32.03, P/U wt.=105K, S/O wt.=106K, ROT=106K,TQ On=2K,TQ Off=1K, Flow out 64%, Bit wt.=12-17K, RPM=100, GPM=660, Pump PSI=2150 Page 5of31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 17:00 1.50 2,603 2,603 SURFA( DRILL CIRC P Circulate 9000 strokes. 2 x's gauge hole BU. Pump weighted sweep surface to surface. 17:00 17:15 0.25 2,603 2,603 SURFA( DRILL OWFF P Observe well for flow. Static 17:15 19:30 2.25 2,603 2,603 SURFA( DRILL TRIP P Trip out of the hole on elevators. No over pulls seen.Trip to top of HWDP. Calc. Disp=15.0 BBLs.Actual Disp.=20.75 BBLs. 19:30 22:15 2.75 2,603 2,603 SURFA( DRILL TRIP P Trip back to bottom. No tight spots. No fill. Calc. Disp=15 BBLs.Actual Disp.=14 BBLs. 22:15 23:45 1.50 2,603 2,603 SURFA( DRILL CIRC P Circulate on bottom.660 GPM, 80 RPM. Slowly reciprocate. Pump a citric acid pill to calculate hole volume. Hole volume=15.0"hole size. Pump 8900 strokes. Shakers cleaned up. 23:45 00:00 0.25 2,603 2,603 SURFA( DRILL OWFF P Observe well for flow. Static. Prepare to POOH to run casing. Bring cement head to rig floor. Bring centralzers(18 of them), 3 stop rings to rig floor. J1/21/2012 POOH on elevators to surface. L/D BHA#2. R/U and run 10%" L-80 45.5#BTC surface casing. C&C wellbore. Cement. 00:00 00:15 0.25 2,603 2,603 SURFA( DRILL OWFF P Monitor Well , Static 00:15 02:30 2.25 2,603 181 SURFA( DRILL TRIP P POOH on elevators t/181' MD 02:30 03:30 1.00 181 0 SURFA( DRILL PULD P L/D BHA#2 03:30 04:00 0.50 0 0 SURFA( DRILL PULD P Download MWD 04:00 05:45 1.75 0 0 SURFA( DRILL PULD P Cont.t/L/D BHA#2 05:45 06:45 1.00 0 0 SURFA( DRILL RURD P Clean and clear rig floor 06:45 08:00 1.25 0 0 SURFA( CASING RURD P Hold PJSM and R/U t/run 10 3/4 surface casing tools 08:00 09:30 1.50 0 0 SURFA( CASING OTHR P Make dummy run w/landing joint, had to clean out debris around ;landing ring. 09:30 10:15 0.75 0 0 SURFA( CASING RURD P Cont to R/U 10 3/4"casing tools 10:15 12:00 1.75 0 124 SURFA( CASING RNCS P PJSM-Run 10 3/4"casing t/124'_ MD 12:00 19:30 7.50 124 1,748 SURFA( CASING RNCS P PJSM. Run 10%"casing. Run casing, Baker-Loc shoe track and the pin end of joint#4 going in the hole. Run centrailizers on the first 3 joints, and then every 4th joint for a total of 17. Break circulation on joint #20.(940' MD)Pump pipe volume. 900 strokes©4 BPM=250 PSI (No losses,good circulation). Break circulation on joint#40(1748' MD)@ 3 BPM=200 PSI,stage up to 5 BPM =300 PSI ( No losses,good circulation). P/U Wt=95k, S/O Wt=96k. Page 6 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 21:00 1.50 1,748 2,591 SURFA( CASING RURD P Land hanger @ 2590.55' MD. L/D Frank's Tool. Blow down Top Drive, R/U cement head, CBU with spud mud. 3 BPM=250 PSI,stage pumps up to 7 BPM. 500 PSI. P/U Wt=123k, S/O Wt=115k. 21:00 22:15 1.25 2,591 2,591 SURFA( CASING CIRC P Swap over to treated mud out of pit #6. Circulate until hole has seen treated mud @ 7 BPM. 22:15 22:45 0.50 2,591 2,591 SURFA( CEMEN-SFTY P Prejob safety meeting. Cement job with Schlumberger.All truck drivers and rig hands attended. Discuss high pressure. 22:45 00:00 1.25 SURFA( CEMEN-CMNT P Shut rig pumps down, line up to cement van. Pump 5 BBLS of CW-100 @ 5 BPM. Pressure test lines to 3,000 PSI. Good. Pump 45 BBLS CW-100. Pump 50 BBLS 10.5 PPG Mud Push with red dye marker. Shut down SLB pump. Drop bottom plug. Crew change during cement job. 31/22/2012 Complete surface cement job. Bumped the plug.The floats held. 90 barrels of cement returns. N/D diverter. N/U well head. C/O seals on starting head after failed test.Test metal to metal seals to 1000 PSI 10 mins. Good. N/U BOPE.Test BOPE with AOGCC Rep. John Crisp. 00:00 01:15 1.25 SURFA( CEMEN-CMNT P Cont t/Pump cement as per plan. Pumped 375 bbls of 11.1 ppq Arctic . 3 LiteCRETE lead cement and 68 bbls `t of 12.0 ppg DeepCRETE tail cement. Shut down, Drop bottom plug. Pumped 10 bbls of water behind 01:15 02:00 0.75 SURFA( CEMEN-CMNT P Displace cement with rig pumps @ 7 BPM, 600 PSI. Staged pumps down t/5 BPM at 1900 stks, Staged pumps down t/3 BPM at 2200 stks, Staged pumps down U 2 BPM at 2250 stks. Bumped the plug @ 2275 stks with 600 PSI, pressured up t/ 1100 PSI. Cement in place @ 02:00. Full circulation was observed the entire job. 90 bbls of cement was returned to surface, 02:00 02:15 0.25 SURFA( CEMEN-CMNT P Bleed pressure off cement head and check floats(holding) 02:15 03:15 1.00 SURFA( CEMEN-RURD P Hold PJSM, R/D casing equipment and L/D landing joint. 03:15 04:45 1.50 SURFA( CEMEN-RURD P Hold PJSM, Flush riser. L/D casing equipment and bails. Blow down lines. 04:45 08:30 3.75 SURFA( CEMEN-NUND P Hold PJSM, N/D Diverter line and surface equipment. 08:30 10:30 2.00 SURFA( CEMEN-NUND P N/U FMC wellhead.Test metal on metal seals, Could not get a test. 10:30 12:00 1.50 SURFA( CEMEN-NUND P N/D FMC wellhead and CIO rubber seal on starting head. - �__ Page 7 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:45 0.75 SURFA( CEMEN-NUND P Cont V C/O seals on FMC starting head. N/U starting head and test metal on metal seals V 1000 PSI for 10 minutes. (Good Test) 12:45 16:45 4.00 SURFA( CEMEN"NUND P Cont V N/U BOP stack, SIMOPS R/U to test BOP's 16:45 19:30 2.75 SURFA( CEMEN NUND P Install BOP yoke(Lifting device for BOP's) 19:30 00:00 4.50 SURFA( CEMEN"BOPE P PJSM.Testing BOPE. Begin test. AOGCC Inspector John Crisp on location as witness for test. Test all components 250 PSI low& ,pI 3500 PSI high for 5 mins. Charted. (An Test#1:Top variable pipe rams(3'/2' x 6),Valve 1,12,13,14,and manual kill. Test#2: Upper IBOP HCR kill, Choke valves 9& 11. Test#3: Lower IBOP,Valves 5,8,10. Test#4: Dart valve,valves 4,6,7. Test#5: Floor valve&valve#2. Crew change,test still ongoing. 01/23/2012 Continued testing BOPE with AOGCC rep. John Crisp. Began to M/U BHA when cold weather shut down came into effect. L/D BHA and P/U a mule shoe. RIH w/mule shoe V 2409'. Circulate well @ 5 BPM 00:00 02:00 2.00 0 0 SURFA(WHDBO BOPE P Cont. testing BOPE. AOGCC Inspector John Crisp on location as witness for test. Test#6: HCR Choke,4"Kill line Demco valve Test# 7: Manuel choke valve, HCR kill Test#8:Annular(2500 PSI) Test#9:Lower pipe rams,5"test joint Test #10: blind rams,valve#3 Accumulator Test:System pressure=3000 PSI, after closed=1900 PSI,200 PSI attained after 38 sec, full pressure after 172 sec. Nitrogen bottle(avg)5 btls @ 1950 PSI. 02:00 03:00 1.00 0 0 SURFA(WHDBO RURD P R/D all test equipment. Set wear ring, blow down choke and kill lines. Install double valve on IA. 03:00 04:00 1.00 0 0 SURFA( DRILL RURD P Set mouse hole, install short bails and elevators. P/U BHA tools via the beaver slide 04:00 04:45 0.75 0 0 SURFA( DRILL PULD P C/O Jars, rack back in derrick 04:45 06:15 1.50 0 73 SURFA( DRILL PULD P Hold PJSM-M/U BHA#3 t/73' 06:15 06:45 0.50 73 0 SURFA( DRILL PULD T L/D BHA-Due to cold weather. Weather=-55 F with wind chill of-88 F 06:45 08:00 1.25 0 2,409 SURFA( DRILL TRIP T Hold PJSM-P/U Mule shoe and RIH t/2409'MD P/U wt.=80K S/O wt.=85K Page 8 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 12:00 4.00 2,409 2,409 SURFA( DRILL CIRC T R/U circulating equipment. Circulate well©5 BPM, 180 PSI.Work on MP 2's. 12:00 00:00 12.00 2,409 2,409 SURFA( DRILL CIRC T Cont.to cirulate well©5 BPM, 150 PSI .Work on MP 2's. Scrub rig floor, pits, charge pump room, cellar and pump room. Change oil in Iron Roughneck spinners, install pins in new yoke for BOP stack, install Johnny Jump up on rig floor, repaired leak on hydraulic unit for elevator. (-51° F reading at midnight.) 31/24/2012 Cold weather shut down still in effect. Cont. circ.well @ 5 BPM w/mule shoe at 2409 MD. Performing routine rig maintenance. 00:00 12:00 12.00 2,409 2,409 SURFA( DRILL CIRC T Cold weather shut down still in effect. Cont. circ.well @ 5 BPM w/mule shoe at 2409' MD. Performing routine rig maintenance. Clean drip pan,thaw out centrifuge, repair iron roughneck retaining ram thread. 12:00 00:00 12.00 2,409 2,409 SURFA( DRILL CIRC T Cont. circ.well©5 BPM w/mule shoe at 2409'MD. Performing routine rig maintenance. Perform housecleaning in cellar, organize tools and equipment,work on centrifuge 0&M procedures. 31/25/2012 Cold weather shut down still in effect. Cont. circ.well @ 5 BPM w/mule shoe at 2409 MD. Performing routine rig maintenance. Review Situational Awareness Power Point with rig crews. 00:00 12:00 12.00 2,409 2,409 SURFA( DRILL CIRC T Cold weather shut down still in effect. Cont. circ.well @ 5 BPM w/mule shoe at 2400' MD. Performing routine rig maintenance. Clean Mezzaine in cellar, invetory parts cabnet on rig floor, clean and inspect floor handling tools. Inventory Rockwasher parts, service#1 air filter on air compressor. Replace 2nd sump line in centrifuge room. 12:00 00:00 12.00 2,409 2,409 SURFA( DRILL CIRC T Cont. circ.well©5 BPM w/mule shoe at 2400' MD. Performing routine rig maintenance. Scrubbed top drive, painted handles yellow on iron roughneck and elevators. Did work order on drawwroks. Reviewed dropped object matrix. Cleaned dog house. 31/26/2012 Cold weather shut down still in effect. Cont. circ.well @ 5 BPM w/mule shoe at 2409'MD. Performing routine rig maintenance. Review Situational Awareness Power Point with rig daylight crew. Page 9 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 2,409 2,409 SURFAC DRILL CIRC T Cont. circ @ 2409'MD w/150 PSI due to extreme cold tempeture. Install stripping rubber catcher,service and inspect pipe skate.Tighten bolts on cold start generators in pipe shed, scrub in pits. Scrub, service and paint air slips. Clean mezzanine and weld drain under pipe skate in mezzanine. Service centrifuge in mud pits. 12:00 00:00 12.00 2,409 2,409 SURFA( DRILL CIRC T Cont. circ©2409'MD. Clean and perform routine maintenance,watch a Situational Awareness video,fixed hydraulic jack for#3 shaker, scrubbed rock washer and painted agitators and guard for conveyor. Cleaned roof walkway,worked on employee evaluations,cleaned up SAA/RAA station. 31/27/2012 Cont. circ.well @ 5 BPM w/mule shoe at 2409' MD while W.O.W. Performing routine rig maintenance. Temp.warmed quickly to-33. Prep to POH and test BOPE. 00:00 12:00 12.00 2,409 2,409 SURFAC DRILL CIRC T Cont. circ @ 2409'MD w/150 PSI, Cont with cleaning in mezzanine, pits, rockwasher.Tighten glycol bolts on cat radiator lines. Grease choke manifold, choke and kill valves, remove low torque valves off#1 and #2 mud pump for inspection/certification. 12:00 00:00 12.00 2,409 2,409 SURFA( DRILL CIRC T Cont. circ @ 2409' MD w/150 PSI. Prep to POOH with drilipipe. )1/28/2012 Test BOPE. MU BHA#3 and RIH to 2472' MD. Test casing to 3000 PSI for 30 min. Drill out floats,shoe track and 20'of new hole. Swap to 9.6 PPG LSND mud. Perform FIT to 16 PPG EMW. Drill from 2623'to 2808' MD. 00.00 01:00 1.00 2,409 0 SURFA( DRILL TRIP T Hold PJSM-POOH and L/D mule shoe 01:00 01:30 0.50 0 0 SURFA(WHDBO BOPE P Pull wear bushing and set test plug 01:30 02:15 0.75 0 0 SURFA(WHDBO BOPE P R/U BOPE test equipment. 02:15 07:30 5.25 0 0 SURFA(WHDBO BOPE P Hold PJSM-Test BOPE,test all Rams and Choke valves U 250 PSI LO, 3500 PSI HI.Test Annular t/ 2500 PSI.Accumulator test: system pressure=3000 PSI, pressure after closed=1800 PSI, 200 PSI attained after 40 seconds, Full pressure attained after 3 minutes 6 seconds,5 bottle nitrogen average=1925 PSI. AOGCC Rep Matt Herrera waved witness of e BOPE test @ 22:00 hrs 07:30 08:15 0.75 ,0 0 SURFA(WHDBO PULD P R/D Test equipment, blow down choke and kill lines. Set wear bushing. — — — – ---- -----– – --- –--— Page 10 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 10:00 1.75 0 126 SURFA( DRILL PULD P Hold PJSM-M/U BHA#3, orient Mud Motor t/MWD and cont.to M/U BHA t/126' MD 10:00 11:30 1.50 126 126 SURFA( DRILL PULD P Upload MWD 11:30 12:00 0.50 126 126 SURFA( DRILL DHEQ P Shallow hole test MWD @ 126' MD w/550 GPM, 1200 PSI 12:00 12:15 0.25 126 126 SURFA( DRILL DHEQ P Cont.t/shallow test MWD @ 126'w/ 560 GPM, 1450 PSI 12:15 12:30 0.25 126 126 SURFA( DRILL PULD P Blow down topdrive, L/D 10'pup. P/U Non-Mag drill collar,torque lift sub and P/U t/nuclear source point 12:30 12:45 0.25 126 126 SURFA( DRILL SFTY P Hold PJSM w/crew/MWD on loading nuclear sources 12:45 13:15 0.50 126 126 SURFA( DRILL PULD P Load nuclear sources 13:15 14:00 0.75 126 126 SURFA( DRILL PULD P Cont t/M/U BHA#3 14:00 15:00 1.00 126 2,437 SURFA( DRILL TRIP P RIH w/drilling assembly t/2437' MD, P/U wt. 95K S/O wt. 97K 15:00 15:15 0.25 2,437 2,502 SURFA( DRILL TRIP P M/U t/stand#20,fill pipe and wash down @ 200 GPM, 500 PSI.Tag TOC @2502'MD 15:15 15:45 0.50 2,502 2,502 SURFA( DRILL CIRC P Circulate 1 1/2 bottoms up @ 525 GPM, 1700 PSI while rot&recip 15:45 16:30 0.75 2,502 2,502 SURFA( DRILL DHEQ P L/D single,fill string and rig up casing test equipment. Flood cement and kill line. 16:30 17:00 0.50 2,502 2,502 SURFA( DRILL DHEQ P Test casing Ca?2472'MD t/3000 PSI f/30 min and record on chart 17:00 17:30 0.50 2,603 2,623 SURFA( DRILL DRLG P Bleed off pressure. R/D test equipment, blow down cement and kill line. PU single and wash down to top of plug @ 2503'. Drill out floats, shoe track, and 20'of new hole to 2623'. 17:30 20:00 2.50 2,623 2,623 SURFA( DRILL CIRC P Displace well to 9.6 ppg LSND mud @ 12 BPM and 1100 PSI. Noted 10 PPG ECD 20:00 22:00 2.00 2,623 2,623 SURFA( DRILL LOT P Perform FIT to 16 ppg EMW(860 _ PSI with 9.6 ppg mud). Plotted leak-off for 10 minutes on chart, dropped to 625 PSI. Bleed off, R/D and blow down lines. Prep to drill ahead. 22:00 00:00 2.00 2,623 2,808 INTRM1 DRILL DRLG P DRLG From 2623' MD to 2808' MD. (2808 TVD),W/500 GPM, 80 RPM, 7K WOB,ART=1.85,AST=0, ADT=1.85,Total Jar HRS=1.85, Bit HRS=1.85 P/U WT=102K, S/O WT=106K, ROT WT=105K.TO ON- 2K,TQ OFF= 1K, ECD=10.2 PPG, Got SPR's 01/29/2012 Drill from 2808' MD to 4198' MD. Short trip to shoe. Hole in good shape. RIH and resume drilling to 4475'. �_ _ Page 11 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 2,808 3,214 INTRM1 DRILL DRLG P Continue DrIg From 2808' MD to 3214'MD. (3214 TVD),W/610 GPM @ 1650 PSI, 100 RPM, 5- 10K WOB,ART=3.70,AST=0,ADT= 3.70,Total Jar HRS=31.55, Bit HRS = 1.85 P/U WT=112K, S/O WT=116K, ROT WT=117K.TQ ON - 2K,TQ OFF= 1K, ECD=10.16 PPG, Got SPR's @ 2808'MD Max Gas= 167 Units. 06:00 12:00 6.00 3,214 3,734 INTRM1 DRILL DRLG P Continue DrIg From 3214'MD to 3734'MD. (3734 TVD),W/610 GPM © 1650 PSI, 100 RPM, 5-10K WOB,ART=3.63,AST= .08,ADT= 3.71,Total Jar HRS=35.26, Bit HRS =35.26 P/U WT=122K, S/O WT=126K, ROT WT=125K.TQ ON- 2K,TQ OFF= 1K, ECD=10.18 PPG, Got SPR's @ 3271' MD Max Gas= 64 Units. 12:00 16:30 4.50 3,734 4,197 INTRM1 DRILL DRLG P Continue Drlg From 3734'MD to 4197' MD. (4197 TVD),W/650 GPM @ 2100 PSI,90 RPM, 5-7K WOB, ART=3.31,AST=.09,ADT=3.40, Total Jar HRS=38.68, Bit HRS= 38.68 P/U WT=130K, S/O WT=132K, ROT WT=135K.TQ ON- 3K,TQ OFF= 1K, ECD=10.24 PPG, Got SPR's @ 4197' MD Max Gas= 72 Units. 16:30 17:15 0.75 4,197 4,197 INTRM1 DRILL CIRC P Pump 30 Bbl hi vis sweep and circ hole clean. Had 20%increase in cuttings. 17:15 20:00 2.75 4,197 2,530 INTRM1 DRILL WPRT P Begin wiper trip on elevators from 4197' MD to 3086'MD. Hole not taking correct fill. Pump out @ 2.5 BPM at 200 PSI from 3086'to 2530' MD. 20:00 21:00 1.00 2,530 4,197 INTRM1 DRILL WPRT P RIH from 2530' MD to 4177'MD. Wash to bottom at 4197' MD. 21:00 00:00 3.00 4,197 4,475 INTRM1 DRILL DRLG P Continue DrIg From 4197'MD to 4475' MD. (4475 TVD),W/650 GPM @ 2150 PSI, 100 RPM, 8K WOB, ART= 1.91,AST=0,ADT= 1.91, Total Jar HRS=40.57, Bit HRS= 40.57 P/U WT=135K, S/O WT=137K, ROT WT=141 K.TQ ON- 2.5K,TQ OFF= 1K, ECD=10.23 PPG, Got SPR's @ 4475' MD Max Gas=83 Units. 31/30/2012 Drill from 4475'MD to 5829' MD. Hole in good shape. Stop drilling due to extremely cold weather. Circulated 2 BU and begin to POOH, racking back 1 stand per hour. Circulating 360 gpm and low rpm. `� _ _ Page 12 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 4,475 5,031 INTRM1 DRILL DRLG P Continue Drlg From 4475'MD to 5031' MD. (5031'TVD),W/650 GPM ©2150 PSI, 100 RPM, 5-10 K WOB,ART=3.82,AST=.34,ADT= 4.16,Total Jar HRS=44.73, P/U WT=145K, S/O WT=147K, ROT WT=150K.TQ ON-2.5K,TQ OFF= 1K, MW raised from 9.6 to 9.85 ppg, ECD=10.26 PPG, Got SPR's @ 4475' MD Max Gas= 1330 Units. 06:00 12:00 6.00 5,031 5,480 INTRM1 DRILL DRLG P Continue Drlg From 5031'MD to 5480'MD. (5480'TVD),W/650 GPM @ 2500 PSI, 100 RPM, 5-8 K WOB, ART=3.60,AST=.23,ADT=3.83, Total Jar HRS=48.56, Bit HRS= 22.56, P/U WT=151 K, S/O WT=154K, ROT WT=155K.TQ ON- 3K,TQ OFF= 1K, MW raised from 9.85 to 10.1 ppg, ECD=10.77 PPG, Got SPR's @ 4475'MD Max Gas= 550 Units. 12:00 18:00 6.00 5,480 5,772 INTRM1 DRILL DRLG P Continue Drlg From 5480' MD to 5772' MD. (5772'TVD),W/650 GPM @ 2450 PSI, 100 RPM, 3-7 K WOB, ART=5.27,AST=0,ADT=5.27, Total Jar HRS=53.83, Bit HRS= 27.28, P/U WT=157K, S/O WT=160K, ROT WT=162K.TQ ON- 2K,TQ OFF= 1K, MW= 10. ppg, ECD=10.53 PPG, Got SPR's @ 5772' MD Max Gas=297 Units. 18:00 19:15 1.25 5,772 5,829 INTRM1 DRILL DRLG P Continue DrIg From 5772'MD to 5829' MD. (5829'TVD),W/650 GPM @ 2450 PSI, 100 RPM, 5K WOB, ART= 1.03,AST=0,ADT= 1.03, Total Jar HRS=54.86, Bit HRS 28.86, P/U WT=157K,S/0 WT=160K, ROT WT=162K.TQ ON = 2K, TQ OFF= 1K, MW 10.1 ppg, ECD=10.53 PPG, Max Gas=295 Units. 19:15 20:45 1.50 5,829 5,829 INTRM1 DRILL CIRC T Weather SD. Temp dropped to-40 deg. Circ 2 X BU @ in prep to trip to casing shoe. 20:45 00:00 3.25 5,829 5,370 INTRM1 DRILL TRIP T Begin to POH pumping at 300 GPM and 50 RPM. Pulling 1 stand/hour to prevent freeze up and maintain hole integrety. 31/31/2012 Cont. POOH, racking back 1 stand per hour. Circulating 270 gpm and low rpm. 00:00 12:00 12.00 5,370 4,231 INTRM1 DRILL TRIP T Cont. pumping at 270GPM and 10 RPM. Pulling 1 stand/hour to prevent freeze up and maintain hole integrety. 12:00 00:00 12.00 4,231 3,133 INTRM1 DRILL TRIP T Cont. pumping at 270GPM and 2 RPM. Pulling 1 stand/hour to prevent freeze up and maintain hole integrety. Page 13 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 32/01/2012 24hrSummary Cont. POH to 2903' CBU X 2 and hole unloaded cuttings. Pull into shoe and slip/cut drill line. Stand-by in shoe WOW. 00:00 02:00 2.00 3,133 2,903 INTRM1 DRILL TRIP T Cont. pumpping out of hole from 3133'-2903'MD. Pumping at 275 GPM and rotate at 10 RPM. Noted slight shale returns over shaker. 02:00 02:30 0.50 2,903 2,903 INTRM1 DRILL CIRC T Circ.X 2 BU from 2903,working pipe up 60'. Kept top of BHA 30' below the shoe. Shale/clay returns started out sparse then increased to a heavy load of hard,dehydrated clay pieces that had been stuck to the inside of the surface pipe. Cleaned up after 1-1/2 BU. 02:30 03:00 0.50 2,903 2,533 INTRM1 DRILL TRIP T Pump OOH from 2903' to 2533'MD. BHA inside surface casing. 03:00 03:30 0.50 2,533 2,533 INTRM1 DRILL CIRC T CBU X 2 inside surface casing at 600 GPM while recip. pipe with no rotation. Recovered more dehydrated clay,then cleaned up after 1 BU. 03:30 06:00 2.50 2,533 2,533 INTRM1 DRILL SLPC P Slip and cut drilling line. 06:00 00:00 18.00 2,533 2,533 INTRM1 DRILL CIRC T Monitor well via trip tank circulating across top. Break circulation down drill pipe periodically to condition mud. 32/02/2012 W.O.W. until weather hold lifted. RIH and drilled to TD @ 6254' MD. Circ BU,short trip to 5802' MD, RIH to TD and circ BU. POH for BOP test. 00:00 04:00 4.00 2,533 2,533 INTRM1 DRILL CIRC T Circulating over the trip tank inside surface casing while waiting on weather 04:00 04:30 0.50 2,533 2,533 INTRM1 DRILL CIRC T CBU @ 320 GPM,600 PSI, ROT 2 RPM 04:30 07:30 3.00 2,533 5,829 INTRM1 DRILL TRIP P BD Top Drive, RIH from 2533'MD to 5775'MD,wash and ream from 5775' MD to 5829' MD @ 600 GPM,2100 PSI, ROT 50 RPM, no fill 07:30 12:00 4.50 5,829 6,050 INTRM1 DRILL DRLG P Drlg ahead from 5829'MD to 5865' MD @ 60 ft/hr, continue DrIg from 5865'MD to 6050' MD @ 100 ft/hr W/650 GPM @ 2600 PSI, 100 RPM, 6-9K WOB,ART=2.37,AST= 0,ADT=2.37,Total Jar HRS=57.23, Bit HRS=31.23, P/U WT=164K, S/O WT=166K, ROT WT=168K.TQ ON=3K,TQ OFF= 1.5K, MW 10.1 ppg, ECD=10.61 PPG, Max Gas= 435 Units. -- --— —_ — — -- Page 14 of 31 • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 12:00 14:45 2.75 6,050 6,253 INTRM1 DRILL DRLG P DrIg ahead from 6050'MD to 6253' MD @ 100 ft/hr,W/650 GPM @ 2600 PSI, 100 RPM, 7K WOB, ART=2.77,AST=0,ADT=2.77, Total Jar HRS=60.0, Bit HRS= 34.0, P/U WT=167K, S/0 WT=170K, ROT WT=172K.TQ ON =3K,TQ OFF= 1.5K, MW 10.2 ppg, ECD=10.61 PPG, Max Gas=400 Units. 14:45 16:30 1.75 6,254 6,081 INTRM1 DRILL CIRC P Circulate BU @ 700 GPM,2750 PSI, ROT 100 RPM while reciprocating string, obtain SPR's, rack back stand, M/U to stump and circulate high vis sweep @ 700 GPM, 2750 PSI, ROT 100 RPM while reciprocating string, rack back 2nd stand 16:30 17:00 0.50 6,081 6,174 INTRM1 DRILL WPRT P Short trip from 6081'MD to 5803' MD, RIH to 6174' MD 17:00 19:30 2.50 6,174 6,254 INTRM1 DRILL CIRC P M/U last stand to TD&fill pipe,wash to bottom and drill 1'to 6254'MD, WT up mud to 10.4 PPG, obtain SPR's. Monitor well for 15 minutes, well static. 19:30 00:00 4.50 6,254 681 INTRM1 DRILL TRIP P POOH on elevators from 6254'MD to 681'MD, monitor well(static) 02/03/2012 LD BHA,test BOPE, RU and run open hole logs, LD logging BHA, begin MU side wall core tool on E-line 00:00 04:45 4.75 681 0 INTRM1 DRILL TRIP P LD BHA, download MWD data, clear _and clean rig floor, pull WB. 04:45 06:45 2.00 0 0 INTRM1 WHDBO RURD P Flush stack @ 650 GPM, 100 PSI. Set test plug, R/U test equipment, _flood choke manifold and kill line 06:45 10:30 3.75 0 0 INTRM1 WHDBO BOPE P Test BOPE, test all choke valves 1-14, uper 3.5"X 6"VBR, lower 5" rams, upper and lower IBOP,flor valve and dart valve to 250 PSI low, 3500 PSI high,test annular to 250PS1 low, 2500 PSI high for 5 minutes each. Accumulator test, Pressure=3000 PSI, Pressure after closed=1900 PSI,200 PSI attained @ 45 sec, full pressure attained @ 171 sec, 5 bottle nitrogen ave=2000 PSI 10:30 13:30 3.00 0 0 INTRM1 WHDBO RURD P R/D test equipment, pull test plug, install WB and blow down choke, kill, and TD, line back up. Clear and clean rig floor. SIMOPS spot HES ,unit 13:30 15:30 2.00 0 0 INTRM1 EVALFN RURD P PJSM, R/U HES equipment 15:30 16:30 1.00 0 0 INTRM1 EVALFN ELOG P RIH w/HES wave sonic tool @ 200 FPM in casing and 150 FPM in open hole to TD @ 6220' E-line MD Page 15 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 20:30 4.00 0 0 INTRM1 EVALFN ELOG P Log OOH @ 30 FPM, make 30' repeat pass and continue POOH w/ wave sonic tool 20:30 21:00 0.50 0 0 INTRM1 EVALFN RURD P LD wave sonic BHA 21:00 00:00 3.00 0 0 INTRM1 EVALFN RURD P MU side wall core tool on E-line 32/04/2012 RU and run E-line,drill side wall cores, RIH for cleanout trip. Lost circulation after pumping Hi-Vis sweep while on bottom. Pulled up above HRZ, circulating and monitoring flow. Total loss of 280 bbls, still losing fluid when circulating, no losses when static. Experiencing minor breathing with pumps off. 00:00 00:15 0.25 0 0 INTRM1 EVALFNSFTY P PJSM for HES wireline. Halliburton Sidewall Core tool. 00:15 03:00 2.75 0 0 INTRM1 EVALFN DHEQ P Testing/troubleshoting-Halliburton Sidewall Core tool. Tested ok 03:00 12:00 9.00 0 0 INTRM1 EVALFN ELOG P RIH with Halliburton Sidewall Core tool and drill side wall cores. 12:00 12:30 0.50 0 0 INTRM1 EVALFN ELOG P POOH w/E-line 12:30 13:30 1.00 0 0 INTRM1 EVALFN RURD P LD sidewall core assembly BHA, move HES unit 13:30 15:00 1.50 0 506 INTRM1 DRILL PULD P PJSM, MU BHA#4 for clean out run 15:00 18:30 3.50 506 6,156 INTRM1 DRILL TRIP P RIH from 506'to 6156'. W/P/U WT=150K, S/O WT=147K 18:30 19:30 1.00 6,156 6,254 INTRM1 DRILL TRIP P MU last stand to TD&wash down to bottom @ 300 GPM,600 PSI, ROT 10 RPM. Tag up w/21'of fill,wash down stand @ 600 GPM, 1800 PSI, MU single,wash down to TD @ 6254'. Stage up pumps to 700 GPM, 2050 PSI, and pump 30 bbl Hi Vis sweep. 19:30 21:30 2.00 6,254 6,254 INTRM1 DRILL CIRC T W/sweep approximately 400'up annulus(near 9.75"stabilizer), lost circulation, slowed pumps from 300 GPM to 85 GPM while rotating and reciprocating, 50 RPM, loss rate slowed from 100 BPH to 50 BPH, shut down pump, keep string moving. Monitor well, observed slight loss, continue to circulate @ 1 BPM on up stroke,shut pump off, 2 BPM on up stroke,shut pump off, stage pump up to 3 BPM w/minimal returns. 21:30 23:15 1.75 6,254 5,540 INTRM1 DRILL TRIP T Pump OOH @ 2.5 BPM, 100 GPM, 200 PSI,40 RPM from 6254'to 5540',torqued up and packed off several times through HRZ from 6130' to 6000'. Slowed rate and worked string through tight spots. 23:15 00:00 0.75 5,540 5,540 INTRM1 DRILL CIRC T Circulate @ 3 BPM,250 PSI, 23% return flow,25 RPM, reciprocate string, loss rate 20 BPH. Total loss for past 12 hours 280 bbls. 02/05/2012 Pump OOH while monitoring returns. Layed down severely clay packed stabilizer, cleaned clay from bit flow courses,and RIH to clean out. Successfully cleaned out hole to TD. Spottd wellbore strengthen pill. Lost a total of 108 BBL in last 24 hours. Page 16 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:15 1.25 5,540 5,448 INTRMI DRILL CIRC T PJSM and monitor well,slight flow. Circulate @ 1 BPM, 80 PSI, 30 RPM. Shut down and monitor well through trip tank,2 BBL gain. 01:15 05:30 4.25 5,448 2,577 INTRM1 DRILL TRIP T POOH from 5448'to 2577'@ 1 BPM, 80 PSI, 30 RPM, PU WT= 150K, SO WT= 145K 05:30 05:45 0.25 2,577 2,577 INTRM1 DRILL OWFF T Monitor well, slight flow 05:45 07:30 1.75 2,577 2,577 INTRM1 DRILL CIRC T Circulate and work pipe,start off w/2 BPM, 115 PSI, 9%return flow, 100 RPM. Stage pumps up to 4.5 BPM, 200 PSI, 44% return flow, 160 RPM 07:30 08:30 1.00 2,577 2,577 INTRM1 DRILL OWFF T Monitor well,slight flow. 12.7 BBL gain 08:30 08:45 0.25 2,577 2,577 INTRMI DRILL OWFF T PU 30'w/no pumps, observe slight flow. Slack off 30', observe fluid drop. PU=90 K, SO=90 K 08:45 10:30 1.75 2,577 1,550 INTRM1 DRILL TRIP T Continue to POOH from 2577'to 1550', pumping©2 BPM, 115 PSI, staging pump rate to 3.5 BPM, 165 PSI,42%return flow. Calculated fill =31.2 BBLS, actual fill=58.6 BBLS 10:30 11:15 0.75 1,550 1,550 INTRM1 DRILL CIRC T Pump bit balling pill @ 1550',4 BPM,200 PSI,40%return flow, no increase in cuttings 11:15 12:00 0.75 1,550 1,550 INTRM1 DRILL OWFF T Monitor well, slight flow. Total loss for last 12 hours=72.3 BBLS 12:00 13:00 1.00 1,550 630 INTRM1 DRILL TRIP T Pump OOH @ 2.5 BPM, 100 PSI, 35 FPM from 1550'to 630'. 13:00 14:30 1.50 630 630 INTRM1 DRILL OWFF T Monitor well until static 14:30 15:30 1.00 630 170 INTRM1 DRILL TRIP T Well still swabbing, pump OOH from 630'to 170'@ 2.5 BPM, 100 PSI, 35 FPM 15:30 16:15 0.75 170 0 INTRM1 DRILL PULD T PU and pull 9.75"stabilizer to floor (flow courses completely packed off with clay), LD stabilizer, PU and clean off bit(packed off with clay), clean up and monitor well, static 16:15 20:00 3.75 0 4,697 INTRM1 DRILL TRIP T RIH w/clean out assembly(same as last,without stabilizer),fill every 20 stands to 4697'. Displacement from trip actual=45.4 BBL, calculated= 49.7 BBL 20:00 21:30 1.50 4,697 4,787 INTRM1 DRILL CIRC T Fill pipe, stage pumps up to 300 GPM, 500 PSI,40%return flow, 50 RPM, reciprocate @ 20 FPM. Circulate BU,work string from 4700' to 4790'. Stage pumps up to 400 GPM, 600 PSI,44%return flow. Hole taking approximately 20 BBL to obtain returns,giving 20 BBL gain with pumps off. 21:30 22:00 0.50 4,787 5,809 INTRM1 DRILL TRIP T Continue RIH from 4787'to 5809'. Total displacement from trip=47 BBL, calculated=53.9 BBL Page 17 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 5,809 5,902 INTRM1 DRILL CIRC T Circulate BU, stage pumps up to 400 GPM, 725 PSI, reciprocate string from 5809'to 5902', 50 RPM,20 FPM,44%return flow. PU= 150 K, SO= 152 K, 1 K torque. Total loss for last 12 hours=36 BBL 32/06/2012 RIH and spotted wellbore strengthening pill from TD to—5400'. POOH and LD BHA, RU and begin to run 7 5/8"casing. 00:00 00:30 0.50 5,902 6,254 INTRM1 DRILL TRIP T PJSM,wash and ream from 5902'to 6254'©400 GPM, 725 PSI,45% return flow,20 RPM. PU= 152 K, SO= 158 K,TQ=0 00:30 02:15 1.75 6,254 6,254 INTRM1 DRILL CIRC T Circulate and condition hole©400 GPM, 725 PSI,45%return flow,20 RPM 02:15 02:45 0.50 6,254 6,254 INTRM1 DRILL OWFF T Monitor well, slight flow 02:45 03:30 0.75 6,254 6,254 INTRM1 DRILL CIRC T Spot 80 BBL wellbore strengthening pill to bit, starting© 1 BPM and staging up to 3 BPM, 175 PSI, 125 GPM, 38%return flow 03:30 05:15 1.75 6,254 5,448 INTRM1 DRILL CIRC T Spot pill from 6254'to 5448'@ 1 BPM, 100 PSI, 50 GPM, 5%return flow 05:15 05:45 0.50 5,448 5,448 INTRM1 DRILL OWFF T Blow down TD, monitor well, slight flow 05:45 08:45 3.00 5,448 3,500 INTRM1 DRILL TRIP P Pump OOH from 5448'to 3500'@ 2 BPM, 125 PSI, 16%return flow 08:45 10:00 1.25 3,500 2,390 INTRM1 DRILL TRIP P Blow down TD. Line up to trip tank, pull from 3500'to 2390',good fill 10:00 10:15 0.25 2,390 2,390 INTRM1 DRILL OWFF P Monitor well inside casing shoe, static 10:15 11:15 1.00 2,390 502 INTRM1 DRILL TRIP P Continue POOH on elevators from 2390'to 502', actual fill from trip=51 BBL, calculated=50 BBL 11:15 11:30 0.25 502 502 INTRM1 DRILL OWFF P Monitor well, static 11:30 12:30 1.00 502 0 INTRM1 DRILL PULD P Rack back BHA 12:30 13:00 0.50 0 0 INTRM1 DRILL PULD P Clear and clean rig floor, LD subs, monitor well, static. Bit was balled up again. 13:00 13:30 0.50 0 0 INTRM1 WHDBO RURD P Drain stack, pull wear bushing 13:30 15:30 2.00 0 0 INTRM1 WHDBO RURD P PJSM,close blind ram sandchange out upper 3 1/2"X 5"VBR to 7 5/8" rams SIMOPS change out bails, MU Franks tool 15:30 17:30 2.00 0 0 INTRM1 WHDBO DHEQ P MU test plug to 7 5/8"test joint and RIH, RU test equipment,test upper 7 5/8"rams to 250/3500 PSI&annular to 250/2500 PSI for 5 minutes each. RD test equipment. 17:30 18:00 0.50 0 0 INTRM1 DRILL PULD P PU landing joint and hanger, make dummy run, change out pup for space out to RKB, mark and LD landing joint. Page 18 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 19:00 1.00 0 0 INTRM1 CASING RURD P RU casing equipment and PJSM for casing run 19:00 00:00 5.00 0 2,560 INTRM1 CASING RNCS P RIH w/75/8',_29.7#L-80 BTC_. casing @ 20 FPM to 2560'and circulate, staging pumps in 1/4 BBL increments. PU=95 K, SO=97 K. Actual displacement=3.49 BBL, calculated=27.6 BBL 02/07/2012 RIH with 7 5/8"casing to 6244' MD. Make up landing joint&hanger. Land casing @ 6244'MD. Install cement head.C&C wellbore. Pump 101 barrels 15.8 PPG cement. L/D landing joint.Set pack off.test 7 5/8"X 10%"to 5000 PSI. 10 Mins. Perform injectivity test. Bull head 180 barrels seawater for flush. Freeze protect with Little Red. 120 barrels diesel. L/D 5"DP. 00:00 00:45 0.75 2,560 2,560 INTRM1 CASING CIRC P Circulate and condition©2560'MD. Stage pumps up to 6 BPM, 325 PSI, 249 GPM, 38%flow, P/U Wt=93k, S/O Wt=100k. 00:45 02:45 2.00 2,560 3,956 INTRM1 CASING RNCS P RIH with 7 5/8"casing from 2560 PSI to 3956' MD. 02:45 03:30 0.75 3,956 3,956 INTRM1 CASING CIRC P Circulate and condition @ 3956' MD. 4 BPM,275 PSI, 172 GPM,40% flow. 03:30 05:30 2.00 3,956 5,400 INTRM1 CASING RNCS P RIH.with 7 5/8"casing from 3956'MD to 5400'MD. 05:30 06:30 1.00 5,400 5,400 INTRM1 CASING CIRC P Circulate and condition @ 5400'MD. Stage pump up to 4 BPM. 300 PSI, 170 GPM, 39%flow. 06:30 07:45 1.25 5,400 6,244 INTRM1 CASING RNCS P RIH with 7 5/8"casing from 5400' MD to 6244' MD.Actual displacement= 51.75 BBLS. Calculated displacement=67.25 BBLS. 07:45 08:00 0.25 6,244 6,244 INTRM1 CASING RURD P Break Franks fill up tool off, blow down top drive, make up landing hanger. 08:00 08:30 0.50 6,244 6,244 INTRM1 CEMEN-RURD P Land out @ 6244'MD. Install cement head. 08:30 10:45 2.25 6,244 6,244 INTRM1 CEMEN"CIRC P Break circulation @ 2 BPM, 200 PSI, 90 GPM, 20%flow. Stage pump up to 5 BPM, 380 PSI,40% flow. P/U Wt=181k, S/O Wt=182k. 10:45 11:00 0.25 6,244 6,244 INTRM1 CEMEN-SFTY P Prejob safety meeting. Cement job with SLB. 11:00 12:00 1.00 6,244 6,244 INTRM1 CEMEN"CIRC P Reciproacte casing while pumping 21/2 BPM, 230 PSI, 20%flow. SIMOPS: Cementers preparing to pump cement. (Total barrels of mud loss for tour=101 barrels) Page 19 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:00 2.00 6,244 6,244 INTRM1 CEMEN-CMNT P Pump cement job per detail. Line up to Dowell/Schlumberger. Pump 5 BBLS of CW100 to flood surface (.6) lines. Shut in and test to 3500 PSI. Good. Line up cement head to I 'S casing. Pump 35 BBLS CW100,40 BBLS 11.5 PPG mud push, drop bottom plug, pump101 BBLS 15.8 ppg cement.drop top plug, pump 10 BBLS water,displace with rig @ 7 BPM. 300 PSI. Slow down to 4 BPM, 1000 PSI FCP, 5 BBLS from bumping. Bump on schedule. Pressure up to 1500 PSI. Bleed off and check floats. Good. 14:00 16:30 2.50 6,244 6,244 INTRM1 CEMEN-RURD P PJSM. Blow down surface lines and rig down casing equipment. 16:30 18:30 2.00 6,244 6,244 INTRM1 CEMEN-PRTS P L/D landing joint,flush out flutes on hanger,set pack off, run in lock down screws.Test 7 5/8"x 10'A" pack off to 5000 PSI,for 10 mins.As per FMC rep. and CoMan. 18:30 19:30 1.00 6,244 6,244 INTRM1 CEMEN-RURD P Rig up to lay down 5"DP using the mouse hole. SIMOPS: Rig up to flush OA with seawater, and freeze protect. 19:30 21:30 2.00 6,244 6,244 INTRM1 CEMEN-FRZP P PJSM. Flush 7 5/8"x 10.75"annulus__ (OA)with 180 barrels of sea water. Start @ 1 BPM for injectivity test. Broke over @ 205 PSI, 1.4 BBLS away. Stage pump up to 2.5 BBLS, 500 PSI for flush. Monitor pressure for 10 mins. ISIP=495 PSI, FSIP= 460 PSI. 21:30 23:00 1.50 6,244 6,244 INTRM1 CEMEN-FRZP P PJSM. Diesel freeze protect with Little Red. Pump 120 barrels of diesel. ICP @ 1.5 BPM=550 PSI. FCP @ 2 BPM=725 PSI. Simops: Lay down 5"DP. 23:00 00:00 1.00 6,244 0 INTRM1 DRILL PULD P Lay down 5"DP out of the mouse hole, into the pipe shed. 32/08/2012 L/D 5"DP from derrick. Slip and cut drilling line. Change out both pipe rams. Place 3.5"X 6"on top, 2 7/8"X 5"on bottom.Test with 4"test joint. 250 PSI/3500 PSI.Test annular preventer, 250/2500.Test 4"floor valves. P/U BHA#600, single in the hole.Test casing to 3000 PSI for 30 mins. 00:00 02:30 2.50 0 0 INTRM1 DRILL PULD P PJSM. Lay down 5" DP from derrick. 02:30 02:45 0.25 0 0 INTRM1 DRILL RURD P Clear and clean rig floor. 02:45 04:00 1.25 0 0 INTRM1 DRILL SLPC P PJSM. Slip and cut drilling line. SIMOPS: clean pits, rockwasher, unload DP from pipe shed. 04:00 04:30 0.50 0 0 INTRM1 RIGMNT SVRG P Service top drive. 04:30 05:30 1.00 0 0 INTRM1 WHDBO RURD P Install test plug, mobilize 4"XT 39 floor valves and handling tools to rig floor. — --- — — — — Page 20 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 08:15 2.75 0 0 INTRM1 WHDBO RURD P PJSM. change out top rams to 3.5" X 6",bottom rams to 2 7/8"X 5". SIMOPS: Change out saver sub, bell guide and dies. 08:15 08:45 0.50 0 0 INTRM1 DRILL PULD P Clear all 5"handling tools off rig floor. 08:45 11:15 2.50 0 0 INTRM1 WHDBO BOPE P Rig up and test Annular preventer to 250/2500 for 5mins.Top rams to 250/3500 for 5 mins. Bottom rams to 250/3500 for 5 mins.Test Dart valve, and TIW both to 250/3500 for 5 mins. 11:15 12:00 0.75 0 0 INTRM1 WHDBO RURD P Rig down test equipment. Blow down lines. Change out mud bucket rubbers to 4". 12:00 12:45 0.75 0 0 INTRM1 DRILL PULD P PJSM.Set wear bushing, clear and clean rig floor, rig up 4"handling equipment, lift subs, elevators,dog collars for BHA. Bring all tools for BHA to rig floor. 12:45 13:15 0.50 0 0 INTRM1 RIGMNT SVRG P Service iron roughneck,top drive. Inspect BHA handling equipment. 13:15 15:00 1.75 0 0 INTRM1 DRILL PULD P PJSM. Pick up and stand back 8 stands of 4" DP. 15:00 18:15 3.25 0 395 INTRM1 DRILL PULD P PJSM. Make up BHA#600 per Sperry DD and MWD hands. Shallow hole pulse test. Good. 275 GPM, 1250 PSI. Blow down TD. Pick up HWDP. 18:15 23:15 5.00 395 6,085 INTRM1 DRILL TRIP P Trip in the hole with singles. Coming out of the pipeshed. Fill every 20 stands.Took weight @ 6085' MD. 3k WOB. Cement stringer.Actual displacement=37.53 BBLS. Calculated displacement=37.45 BBLS. 23:15 00:00 0.75 6,085 6,130 INTRM1 DRILL TRIP P Pick up and make up to top drive. P/U Wt=116k, S/O Wt=117k, Rot Wt=120k, Breal circ. @ 280 GPM, 2000 PSI. 50 RPM wash and ream to 6130. J2/09/2012 C&C mud system above float collar. Perform Casing test to 3000 PSI for 30 mins. Drill out shoetrack and clean out rathole to original depth.6254'MD. C/O mud systems. Drill fr 6254'to 6274'MD. Perform LOT to 14.6 PPG. Drill fr 6274'to 6323'MD. Core point. CBU.Weight up fr 10.5 PPG to 10.8 PPG due to connection gas. CBU. Monitor well. POOH 00:00 01:15 1.25 6,130 6,130 INTRM1 DRILL CIRC P Circulate and condition mud system above the float collar for the casing pressure test. Balance mud weight out to 10.5 PPG as per well plan. 01:15 01:30 0.25 6,130 6,130 INTRM1 DRILL RURD P Blow down top drive. Rig up to 9_ pressure test. 01:30 02:15 0.75 6,130 6,130 INTRM1 DRILL PRTS P Zest casing to 3000 PSI for 30 mins 02:15 02:30 0.25 6,130 6,130 INTRM1 DRILL RURD P Rig down test equipment. blow down lines. 02:30 04:45 2.25 6,254 6,254 INTRM1 DRILL DRLG P Drill out shoe track and clean out rat hole to 6254'MD. ©6.5 BPM. 1850 PSI, 100 RPM, 1k TQ,36%flow. Page 21 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:45 05:45 1.00 6,254 6,254 INTRM1 DRILL CIRC P PJSM. Displace well from 10.5 PPG LSND to 11.0 PPG Core fluid @ 6.5 BPM, 1850 PSI, 100 RPM, 1k TQ, 36%flow. 05:45 06:15 0.50 6,254 6,254 INTRM1 DRILL RURD P Clean shakers and possum belly trough. 06:15 08:45 2.50 6,254 6,274 INTRM1 DRILL DRLG P Drill from 6254'to 6274' MD. 7 BPM, 2800 PSI,45%flow, 150 RPM, TQ=1 k 08:45 09:30 0.75 6,274 6,274 INTRM1 DRILL CIRC P CBU @ 7 BPM.2800 PSI. 09:30 09:45 0.25 6,274 6,274 INTRM1 DRILL RURD P Blow down top drive, rig up to perform LOT. 09:45 10:15 0.50 6,274 6,274 INTRM1 DRILL LOT P Perform LOT to 14.6 PPG EMW. 10:15 10:30 0.25 6,274 6,274 PROD1 DRILL RURD P Rig down test equipment, blow down lines. 10:30 12:00 1.50 6,274 6,284 PROD1 DRILL DRLG P Drill from 6274'to 6284'MD. 7 BPM, 2800 PSI,45%flow, 150 RPM, TQ=1 k.ADT=2.88 Hrs.Jar Hrs=2.88. Bit Hrs=2.88. 12:00 15:00 3.00 6,284 6,323 PROD1 DRILL DRLG P Drill from 6284'MD.to 6323'MD. Geologist picked core point. ADT=2.27 Hrs.Total Jar Hrs=5.15. Total bit Hrs=5.15. P/U Wt=119k. S/O Wt= 117k. Rot Wt=119k, TQ=1.5k off/on. 300 GPM.2650 PSI. 15k WOB. 150 RPM. SPR's:#1-20 SPM=410 PSI. 30 SPM=610 PSI. #2. 20 SPM=390 PSI. 30 SPM=640 PSI. 15:00 16:00 1.00 6,323 6,323 PROD1 DRILL CIRC P CBU @ 300 GPM. 50 RPM. Rotate and reciprocate. Confirm core point with cuttings samples. Circulate potassium iodide tracer in mud system.(175 lbs.)Rack back one stand. C&C. 16:00 18:30 2.50 6,323 6,323 PROD1 DRILL CIRC P Due to 3200 units of connection gas decision was nade to weight up to 10.8 PPG. Circulate and condition while reciprocating and rotating. 18:30 19:00 0.50 6,323 6,323 PROD1 DRILL OWFF P Observe well for flow. Static. 19:00 19:30 0.50 6,323 6,223 PROD1 DRILL CIRC P CBU. 1300 Unit spike. Rack back one stand to place bit inside casing. 19:30 20:00 0.50 6,223 6,223 PROD1 DRILL OWFF P Observe well for flow. Static. 20:00 23:30 3.50 6,223 395 PROD1 DRILL TRIP P Trip out of the hole from 6223'MD to 395'. Pull 15 stands.Taking good hole fill. Pump 20 barrel dry job, down down top drive. POOH to 395' top of HWDP. Hole fill=38.16 BBLS. Calculated 32.06 BBLS. Loss due to pulling wet. 23:30 00:00 0.50 395 395 PROD1 DRILL OWFF P Observe well for flow at top of HWDP. Static. 02/10/2012 POOH w/BHA#600. L/D tools.Test BOPE.Weekly test.Witness waived by AOGCC John Crisp. P/U Core barrel assembly#700.TIH and begin coring @ 6323'MD to 6347'MD. Page 22 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 395 85 PROD1 DRILL TRIP P PJSM. Rack back HWDP/Flex collars. 00:30 01:00 0.50 85 0 PROD1 DRILL PULD P Lay down MWD tools, break off and grade bit. 01:00 01:30 0.50 0 0 PROD1 DRILL PULD P Clean and clear rig floor. 01:30 02:45 1.25 0 0 PROD1 WHDBO RURD P Pull wear ring, set test plug. Rig up to test BOPE. 02:45 06:45 4.00 0 0 PROD1 WHDBO BOPE P Test BOPE,test all choke valves 1-14, upper 3.5"X 6"VBR, lower 2 7/8 X 5"rams, upper and lower IBOP,floor valve and dart valve to 250 PSI low, 3500 PSI high, test annular to 250PSI low, 2500 PSI high -' for 5 minutes each. (All charted). t Accumulator test, Pressure=2900 PSI, Pressure after closed=1900 PSI, 200 PSI attained @ 46 sec,full pressure attained @ 182 sec, 5 bottle nitrogen ave=2000 PSI.Test all gas alarms.Witness of test waived by AOGCC Rep.John Crisp. 06:45 07:45 1.00 0 0 PROD1 WHDBO RURD P Rig down BOPE test equipment. blow down top drive, kill line, choke line, choke manifold. Install wear bushing. 07:45 08:15 0.50 0 0 PROD1 DRILL SVRG P Service top drive and draw works. 08:15 10:00 1.75 0 434 PROD1 CORING PULD P Pick up Core Assembly Run#700. Core run#1 10:00 12:00 2.00 434 2,316 PROD1 CORING TRIP P Rip in the hole with Core Assembly. to 2316'MD. Fill every 20 stands. Actual displacement=15.25 BBLS, Calculated displacement=16.13 BBLS. 12:00 15:30 3.50 2,316 6,323 PROD1 CORING TRIP P Trip in the hole from 2316'MD to 6082' MD.Wash down to bottom @ 6323' MD. Pump 150 GPM, 750 PSI. CBU, 2900 units of gas. Rack back one stand, pick up one single from pipe shed. 31.23'Add to string. P/U Wt=114k, S/O Wt=115k. 15:30 15:45 0.25 6,323 6,323 PROD1 CORING CIRC P Pick up stand#63. Circ steel ball down to core barrel. Pressure increase from 750 PSI to 1050 PSI after seated. 15:45 00:00 8.25 6,323 6,347 PROD1 CORING CORE P Start coring @ 6323'MD. Pump 150 GPM, 1225 PSI, 70 RPM, 10 to 12 kWOB, 1k TQ, Slowly increase mud weight from 10.8 PPG to 11.00 PPG, and then from 11.0 PPG to 11.2 PPG. Core to 6347'MD. 32/11/2012 Core from 6347'to 6373'MD. POOH. Process core for shipment. Pick up Sperry BHA. Gamma/Resistivity/ Neutron/Density/PWD. Page 23 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 07:30 7.50 6,347 6,373 PROD1 CORING CORE P PJSM. Coring from 6347'to 6373' MD. 150 GPM, 1165 PSI,42% Flow, 70 RPM,TQ=2k,ADT=7.5 Hrs.Jar hours total=20.9 Hrs. Bit Hrs=15.75. P/U WT=115k, S/O Wt=116k, Rot Wt=110k. Stopped coring. No ROP. Prepare to POOH. 07:30 08:30 1.00 6,373 5,888 PROD1 CORING TRIP P POOH 5 stands. From 6373'to 5888' MD. ( L/D one single). 08:30 09:00 0.50 5,888 5,888 PROD1 CORING OWFF P Observe well for flow. Blow down top drive. Static. 09:00 12:00 3.00 5,888 3,631 PROD1 CORING TRIP P POOH on elevators. 3.5 mins per stand. From 5888'to 3631' MD.Fill=18.8 BBLS. Calculated fill=15.66 BBLS. 12:00 15:45 3.75 3,631 434 PROD1 CORING TRIP P Continue to POOH with core barrel assembly.Tripping speeds were 4 mins per stand to 1900'.Then 6 mins per stand to BHA. 15:45 16:30 0.75 434 434 PROD1 CORING TRIP P Rack back HWDP and flex collars. 16:30 16:45 0.25 434 434 PROD1 CORING SFTY P PJSM on laying down the core barrels. 16:45 20:00 3.25 434 0 PROD1 CORING RECR P Pull up to inspect the bit. Pulled a core fragment out of the bit throat. Remove core from bit area. Ran back to top of barrels. Set slips. Lay down barrels as per Baker Core Hands. Cored 50'recovered 42'. 84% recovery. 20:00 20:30 0.50 0 0 PROD1 CORING PULD P Clear and clean rig floor, pick up tools from slide. SIMOPS: Begin core processing in the pipeshed. Finish core processing @ midnight. 20:30 21:45 1.25 0 0 PROD1 DRILL SFTY P Prejob safety meeting. P/U BHA to top of MWD tools. Gamma/Resistivity/Neutron/Density/ PWD. 21:45 22:45 1.00 0 0 PROD1 DRILL PULD P Plug in and up load MWD system. 22:45 23:00 0.25 0 0 PROD1 DRILL SFTY P PJSM. Nuclear sources.Time Distance Shielding. 23:00 23:30 0.50 0 180 PROD1 DRILL CIRC P Shallow hole pulse check MWD tools. No pulses. 23:30 00:00 0.50 180 0 PROD1 DRILL PULD T Pulser would not begin pulsing. Crew change. Prepare to change out Telemetry module. 02/12/2012 TIH w/Sperry BHA#800. CBU @ shoe. Mad Pass to TD. Drill to 6688'MD. CBU 2x's. POOH. 00:00 02:15 2.25 0 - 100 PROD1 DRILL PULD T Blow down Top drive. Rack back HWDP. L/D flex collars. PJSM. Remove sources.Trouble shoot MWD tools. Change out Telemetry Module. Up Load MWD. 02:15 02:30 0.25 100 100 PROD1 DRILL PULD T Pulse test MWD. Good. Off trouble time. 02:30 02:45 0.25 130 130 PROD1 DRILL PULD P Blow down top drive. Pick up 1 joint flex collar, clean source ports. Page 24 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:45 03:00 0.25 130 130 PROD1 DRILL SFTY P PJSM. Load sources as per Sperry. 03:00 03:30 0.50 130 448 PROD1 DRILL PULD P Pick up 2 flex collars, 3 stands of HWDP. 03:30 06:30 3.00 448 6,244 PROD1 DRILL TRIP P Trip in the hole with 4"XT39 DP. Fill pipe every 20 stands.Trip from 448' to 6180'MD.Actual displacement=35.7 BBLS, Calculated=38.47 06:30 07:30 1.00 6,244 6,244 PROD1 DRILL CIRC P Circulate bottoms up at the shoe @ 6244' MD. 07:30 11:30 4.00 6,244 6,244 PROD1 DRILL RGRP T Trouble shoot PVT. (Totco system). 11:30 12:00 0.50 6,244 6,244 PROD1 DRILL RURD P Calibrate block height measuring system on totco. Set depth with Sperry. Prepare to conduct Mad Pass 12:00 14:30 2.50 6,244 6,373 PROD1 DRILL REAM P Mad Pass with MWD tools. Ream to bottom.took weight from 6350'to 6373' MD. Some torquing and slight pressure spikes. 14:30 23:30 9.00 6,373 6,688 PROD1 DRILL DRLG P Control Drilling from 6373'to 6688' • MD @ 50'/hr.TVD=6688'.ART=6.69 Hrs. Total Jar Hrs.=27.59, P/U Wt= 125k, 5/0 Wt= 123k, ROT Wt= 126k,TQ on bottom=2k,TQ off bottom= 1.5k, ECD=12.38 PPG, WOB=8k to 10k. RPM=110, GPM=300, PP=2900 PSI. 23:30 00:00 0.50 6,688 6,688 PROD1 DRILL CIRC P TD©6688' MD. Begin circulating bottoms up. 02/13/2012 POOH to BHA#800. Lay down Sperry tools. Clear and clean rig floor. rig up to run Halliburton RDT on DP. Stop.Wrong side door entry sub OD. Rig up to run Halliburton RDT on E-Line. Conduct E-Line operations. 00:00 00:15 0.25 6,688 6,688 PROD1 DRILL CIRC P CBU ©300 GPM, 2950 PSI,45% flow, 110 RPM, TQ=1k 00:15 00:30 0.25 6,688 6,688 PROD1 DRILL OWFF P Observe well for flow. Static. 00:30 01:00 0.50 6,688 6,688 PROD1 DRILL CIRC P CBU.Total of 5800 strokes.Two full surface to surface strokes. 01:00 01:30 0.50 6,688 6,688 PROD1 DRILL OWFF P Observe well for flow. Static. 01:30 02:45 1.25 6,688 6,170 PROD1 DRILL CIRC P Obtain SPR's. Pump out of the hole into the casing. 6688' MD to 6170' MD. 2 BPM, 580 PSI, 22%flow, P/U Wt=120k, S/O Wt=122k. 02:45 03:15 0.50 6,170 6,170 PROD1 DRILL CIRC P CBU @ shoe. 300 GPM, 2925 PSI, 45%flow, 50 RPM. 03:15 03:30 0.25 6,170 6,170 PROD1 DRILL OWFF P Observe well for flow. Static. 03:30 04:45 1.25 6,170 5,243 PROD1 DRILL CIRC P Attempt to pull on elevators. Swabbing. Pump out of the hole 10 stands. 6170' MD to 5243'MD. 150 GPM. 925 PSI. 33%flow. 04:45 05:00 0.25 5,243 5,243 PROD1 DRILL OWFF P Blow down top drive. Observe well for flow. Static.Attempt to pull on elevators. NoGo.Hole not taking proper hole fill. 05:00 06:00 1.00 5,243 4,772 PROD1 DRILL CIRC P Pump out 5 stands. 150 GPM, 925 PSI, 33%flow. 5243'to 4772'MD. Page 25 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 06:30 0.50 4,772 4,582 PROD1 DRILL TRIP P Line up on trip tank. Pull 2 stands. Good hole fill. Blow down top drive. 06:30 08:45 2.25 4,582 488 PROD1 DRILL TRIP P Trip out of the hole on elevators. From 4582'MD to 488'MD.Top of HWDP. 08:45 09:00 0.25 488 488 PROD1 DRILL OWFF P Observe well for flow. Static. 09:00 09:30 0.50 488 100 PROD1 DRILL TRIP P Rack back HWDP and Jars. 09:30 09:45 0.25 100 100 PROD1 DRILL SFTY P PJSM. Retrieve sources from MWD tool.Actual fill=45.90 BBLS, Calculated fill=41.76 BBLS. 09:45 10:15 0.50 100 100 PROD1 DRILL PULD P Down load MWD. 10:15 11:15 1.00 100 100 PROD1 DRILL PULD P Lay down BHA as per Sperry DD/MWD hands. 11:15 12:00 0.75 0 0 PROD1 DRILL PULD P Clean and clear rig floor of all drilling tools. Prepare for wireline operations. 12:00 13:45 1.75 0 0 PROD1 EVALFN PULD P Pick up tools from beaver slide to rig floor. 13:45 14:45 1.00 0 0 PROD1 EVALFN PULD P PJSM. Pick up Halliburton RDT tools for drill pipe convey data acquisition. 14:45 15:15 0.50 0 0 PROD1 EVALFN RURD P Spot wireline unit, line up to beaver slide. Pick up eline and X/O's to test tools. 15:15 17:30 2.25 0 0 PROD1 EVALFN PULD T Discover the side door entry sub OD was 7'/4'. Unable to run DP conveyed system. Decide to run tools on electric line. 17:30 18:00 0.50 0 0 PROD1 EVALFN PULD P Pick up electric line, conduct test on RDT(pressure testing tools), calibrate tools. 18:00 20:30 2.50 0 0 PROD1 EVALFN ELOG P Run in hole with electric line RDT run #1. Locate targe sands around 6373' MD. 20:30 00:00 3.50 0 0 PROD1 EVALFN ELOG P Conduct 8 pressure stations with Halliburton RDT tools from 6373 to 6353' MD. 92/14/2012 RIH w/E-Line RDT tools. Clear and clean rig floor. RIH w/Drill pipe and mule shoe t/6205'MD. Performed LOT= 13.5 ppg EMW. POOH on elevators, clear and clean floor. R/U E-Line and run WaveSonic tool. 00:00 06:30 6.50 0 0 PROD1 EVALFN FLOG P Hold PJSM. E-Line w/RDT as per Halliburton 06:30 09:00 2.50 0 0 PROD1 EVALFN ELOG P Hold PJSM. R/D E-Line RDT tools as per Halliburton 09:00 09:30 0.50 0 0 PROD1 DRILL PULD P Clean and clear rig floor. P/U Mule shoe 09:30 12:00 2.50 0 5,176 PROD1 DRILL TRIP P Hold PJSM. RIH w/XT-39 Drill pipe and mule shoe f/5'V 5176' 12:00 12:15 0.25 5,176 6,205 PROD1 DRILL TRIP P Cont RIH w/XT-39 Drill pipe f/5176 V 6205'. Calc displacement=35.6, Actual=37.06. P/U wt.=108K 5/0 wt.=106K 12:15 12:30 0.25 6,205 6,205 PROD1 DRILL LOT P Rig up for LOT 12:30 14:45 2.25 6,205 6,205 PROD1 DRILL CIRC P CBU @ 250 GPM=1150 PSI. Cont. conditioning mud for LOT, observed 3500 units of gad at bottoms up. Page 26 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 15:00 0.25 6,205 6,205 PROD1 DRILL LOT P Performed LOT w/11.3 ppg mud, pumped 8 strokes=730 PSI. 13.5 ppg EMW Leak-off. bleed off back to the trip tank=.7 bbl 15:00 15:45 0.75 6,205 6,205 PROD1 DRILL LOT P R/D cement line and kill line, check flow 15:45 19:15 3.50 6,205 0 PROD1 DRILL TRIP P POOH on elevators f/6205'. Calc displacement=35.64 bbls,Actual displacement=37.74 bbls 19:15 19:45 0.50 0 0 PROD1 DRILL OTHR P Clean and clear rig floor 19:45 20:00 0.25 0 0 PROD1 EVALFN SFTY P Hold PJSM, R/U E-Line 20:00 21:00 1.00 0 0 PROD1 EVALFN ELOG P M/U E-Line WaveSonic tool f/shed 21:00 00:00 3.00 0 0 PROD1 EVALFN ELOG P RIH with wave sonic logging tools on Halliburton electric Line. Log from 6680' MD to 4900' MD. J2/15/2012 Trip in the hole with 33 joints PH6. RIH from derrick to 6589'MD.Wash down to bottom. CBU. Pump balanced cement plug. 34 barrels 15.8 PPG slurry. POOH to 5733.WOC.while circulating. 00:00 00:15 0.25 0 0 PROD1 EVALFN ELOG P POOH w/WaveSonic E-Line Logging tool 00:15 01:15 1.00 0 0 PROD1 EVALFN PULD P PJSM L/D WaveSonic E-Line tools as per Halliburton Rep. 01:15 01:30 0.25 0 0 PROD1 EVALFN RURD P R/D E-Line and clear tools off rig floor. 01:30 02:00 0.50 0 0 PROD1 DRILL SVRG P Service top drive. 02:00 03:00 1.00 0 0 PROD1 PLUG RURD P Mobilize casing tools t/rig floor. Clean threads on 3.5"PH-6 tubing and R/U casing tongs. 03:00 04:30 1.50 0 1,032 PROD1 PLUG PULD P PJSM P/U 33 joints of 3.5"PH-6 tubing f/pipe shed 04:30 04:45 0.25 1,032 1,032 PROD1 PLUG RURD P R/D casing tongs and change elevators 04:45 06:45 2.00 1,032 6,589 PROD1 PLUG TRIP P RIH f/derrick w/4"XT-39 pipe f/ 1032' MD t/6589'MD. Actual displacement=38.44,Calc displacement=37.41 06:45 09:00 2.25 6,589 6,683 PROD1 PLUG WASH P M/U Top drive and wash down t/ 6683'MD @ 300 GPM, 71 SPM, 1480 PSI,45% Flow, 50 RPM. Tq=1K, P/U wt.=115K, S/O wt.=115K 09:00 09:15 0.25 6,683 6,683 PROD1 PLUG SFTY P PSJM on cement job 09:15 10:00 0.75 6,683 6,683 PROD1 PLUG RURD P Blow down top drive and R/U to cement 10:00 10:15 0.25 6,683 6,683 PROD1 PLUG PRTS P Pressure test cement lines t/ 700/2500 PSI (good) 10:15 11:00 0.75 6,683 6,683 PROD1 PLUG CMNT P Pump 6.23 bbls of 12.5 ppg MudPush II, Shut down and batch up. Pumped 34 bbls of 15.8 ppq_.__ Class G blend slurry @ 5 BPM, pump 3.77 bbls of 12.5 ppg MudPush II @ 5 BPM. Shut down and flushed lines w/5 bbl of water. Rig pumped 50 barrels of mud to spot cement. . _ _ __ _ __ _ Page 27 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 6,683 5,733 PROD1 PLUG TRIP P POOH on elevators from 6683' MD to 5733'MD. 12:00 13:15 1.25 5,733 5,733 PROD1 PLUG CIRC P Rig up to circulate. Drop foam ball. Circulate 300 GPM. 3 full bottoms up. 5700 strokes. 13:15 14:15 1.00 5,733 5,733 PROD1 PLUG CIRC T Work on top drive stand, repair bracket for compensator system- broken bolt. SIMOPS: Rig up on 10 3/4"X 7 5/8"annulus for injectivity test with Schlumberger. 14:15 14:30 0.25 5,733 5,733 PROD1 PLUG SFTY P PJSM on injectivity test.W/SLB. 14:30 16:45 2.25 5,733 5,733 PROD1 PLUG CMNT P Opened annulus valve showed 200 PSI. Start pumping 100 barrels water flush @ 1 BPM. Pressure increase to 934 PSI. Broke over to 680 PSI. Increase pump rate to 1.5 BPM. Pressure drop to 525 PSI. Complete flush. Line up to pump with cementers. Pump 11.3 BBLS 12.5 PPG mud push 60 BBLS 15.8 PPG cem.gnt. 16:45 00:00 7.25 5,733 5,733 PROD1 PLUG WOC P WOC. Rig up cement line to circulate @ 1.5 BPM.200 PSI.Work on MP2's. House keeping. 32/16/2012 Wash down to top of 1st plug. Tag w/12k @ 6107' MD CBU. R/U and test plug. Unable to establish baseline @ 1600 PSI.Attempt to retest. NoGo. Complete 30 min.test. 1650 PSI ISIP, 960 PSI FSIP. Order 40 more BBLS of 15.8 G. Retag top of plug @ 6135'.CBU. R/U and pump 2nd plug. 18.4 BBL plug. Perform hesitation squeeze to 1600PSI. Charted for 30 mins. Good. SIMOPS: Pump cement down OA. 00:00 01:00 1.00 5,733 6,107 PROD1 PLUG CIRC P PJSM.Wash down @ 1.5 BPM. 300 PSI. 11%flow, from 5733'to 6107' MD. Set down 12k.Witnessed by AOGCC Lou Grimaldi. 01:00 01:30 0.50 6,107 6,107 PROD1 PLUG CIRC P CBU @ 300 GPM.7 BPM. 1420 PSI.44%flow. FCP=1295 PSI. 01:30 01:45 0.25 6,107 6,107 PROD1 PLUG RURD P Rack back 1 stand. Blow down top drive. Rig up to test casing. 01:45 03:45 2.00 6,107 6,107 PROD1 PLUG PRTS P Pressure test casing to 1600 PSI. _ Record pressure every 2 strokes up to 1600 PSI. Shut in. Bleed off from 1650 PSI to 960 PSI in 30 mins. Rerig surface equipment. Change sensors. Isolate the downhole pressure.Attempt 3 times. Unable to hold a baseline.All surface equipment tested good. R/D test equipment. 03:45 04:00 0.25 6,107 6,107 PROD1 PLUG CIRC P Line up to trip tank. Bleed off casing pressure.We had Pressured up with 2 BBLS. Bleed back volume=.67 BBLS. 04:00 04:15 0.25 6,107 6,107 PROD1 PLUG RURD P Rig down cement lines, blow down all surface equipment. `_ _� Page 28 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 06:00 1.75 6,107 6,135 PROD1 PLUG CIRC P Pick up one stand. Pump 1.5 BPM. 220 PSI, 11%flow.Tag up on rubble 10 feet high.Wash down to original tag depth @ 6107'MD. Drop through. Continue to wash down to 6135'MD. Tag hard cement.Set 12,000 lbs down multiple times.Verify hard cement. 06:00 11:00 5.00 6,135 6,135 PROD1 PLUG CIRC P CBU @ 7 BPM. 1300 PSI.43%flow, 50 RPM.After BU and shakers clean up,slow down to 2 BPM. Begin WOC. 11:00 12:00 1.00 6,135 6,135 PROD1 PLUG RURD P Rack back one stand. Blow down top drive. Pick up single from pipe shed. Rig up to perform 2nd bottom abandonment plug. 12:00 12:15 0.25 6,135 6,135 PROD1 PLUG RURD P Rig up cement line. 12:15 13:15 1.00 6,135 6,135 PROD1 PLUG CMNT P PJSM. Pump cement. Pump 11.5 BBLS mud push. 12.5 PPG.Chased with 18.4 BBLS 15.8 ppg G cement. followed with 2.5 BBLS mud push. Chase with 49 BBLS from rig , 11.2+ mud,@ 3.5 BPM, 150 PSI.Stop. Rig down cement line. 13:15 13:45 0.50 6,135 5,565 PROD1 PLUG TRIP P Trip out 6 stands. R/U cement line on rig floor.CBU @ 300 GPM. 1450 PSI. 13:45 16:45 3.00 5,565 5,565 PROD1 PLUG SQEZ P Shut top pipe rams.Squeeze cement. Performed hesitation squeeze as follows: 1.Pressure up t/1600 PSI,20 stks, bled t/1200 PSI in 10 min 2. Pressure up t/1600 PSI,4 stks, bled t/1200 PSI in 11 min 3. Pressure up t/1600 PSI, 3 stks, bled U 1200 PSI in 15 min 4.Pressure up t/1600 PSI,3 stks, bled t/1200 PSI in 20 min 5. Pressure up t/1600 PSI, 3 stks, bled t/1300 PSI in 10 min 6. Pressure up t/1600 PSI, 3 stks,bled t/1300 PSI in 20 min 7. Pressure up t/1600 PSI,2 stks, bled t/1400 PSI in 10 min 8. Pressure up t/ 1600 PSI,2 stks, bled t/1400 PSI in 10 min 9. Pressure up t/1600 PSI, 2 stks, bled t/1425 PSI in 10 min 10. Pressure up t/1600 PSI, 1 stks, bled t/1480 PSI in 10 min 11. Pressure up t/1600 PSI, 1 stks, bled t/1550 PSI in 6 min. 12 Pressure up t/1600 PSI, 1 stks, held at 1600 for 10 min. Squeezed 4.5 bbls of cement in the formation. 16:45 17:30 0.75 5,565 5,565 PROD1 PLUG PRTS P Pressure test cement plug t/1600 PSI on chart for 30 min(good test) Page 29 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 18:00 0.50 5,565 5,565 PROD1 PLUG RURD P R/D cement line, L/D single in shed, R/U cement line and Circ @ 2 BPM=230 PSI, SIMOPS, rig up on annulus to pump cement 18:00 18:15 0.25 5,565 5,565 PROD1 PLUG SFTY P PJSM on pumping cement down annulus. 18:15 19:30 1.25 5,565 5,565 PROD1 PLUG CMNT P Pressure test lines t/250 PSI, low 1000 PSI high.(good)pump 12.7 bbls of 15.7 ppg AS1 cement down L, annulus, pressured up t/900 PSI, shut in at wellhead. Bled off pressure and washed up lines into cellar. 19:30 00:00 4.50 5,565 PROD1 PLUG WOC P Cont to Circ @ 2 BPM while WOC. Crews conducting MP2's. 32/17/2012 Cont t/WOC. RIH pumping 1.5 BPM and tag cement @ 5903'MD. CBU and POOH. L/D PH-6 pipe. P/U cement retainer and RIH t/300'. Set retainer and pump 12.8 bbls of AS1 on top of retainer. POOH. M/U casing cutter and cut casing @ 30.5". L/D cutter and M/U spear. Pull casing hanger and packoff to floor. N/D BOPE and Wellhead. RIH w/1"pipe and tag cement @ 40'. Pump top job,14 bbls of AS1.Cement to surface. Clean out cellar and L/D 4"drill pipe. 00:00 02:00 2.00 5,546 5,546 PROD1 PLUG WOC P PJSM, Circ @ 2 BPM,230 PSI WOC 02:00 03:00 1.00 5,546 5,903 PROD1 PLUG TRIP P RIH pumping @ 1.5 BPM f/5546' MD,Tag cement @ 5903' MD set down 15K three times 03:00 03:30 0.50 5,903 5,546 PROD1 PLUG TRIP P POOH f/5903'MD t/5546'MD 03:30 04:00 0.50 5,546 5,546 PROD1 PLUG CIRC P CBU @ 7 BPM, 300 GPM, 1275 PSI,42%Flow 04:00 04:15 0.25 5,546 5,546 PROD1 PLUG OWFF P Blow down, Monitor well(Static) 04:15 05:45 1.50 5,546 1,032 PROD1 PLUG TRIP P POOH f.5546'MD t/1032'MD 05:45 06:00 0.25 1,032 1,032 PROD1 PLUG PULD P R/U t/L/D 3.5" PH-6 pipe(33 joints) 06:00 07:00 1.00 1,032 0 PROD1 PLUG PULD P L/D 3.5"PH-6 pipe f/1032' MD t/ surface 07:00 07:30 0.50 0 0 PROD1 PLUG OTHR P Clean and clear rig floor 07:30 08:45 1.25 0 300 PROD1 PLUG PULD P P/U pups f/slide. M/U cement _ retainer and setat?300'MD.Test retainer t/500 PSI(good) 08:45 09:15 0.50 300 300 PROD1 PLUG CIRC P R/U cement line and Circ @ 2 BPM 09:15 09:45 0.50 300 300 PROD1 PLUG RURD P R/U Cementers 09:45 10:00 0.25 300 300 PROD1 PLUG SFTY P PJSM on cement job 10:00 10:45 0.75 300 300 PROD1 PLUG CMNT P Batch up cement and pump 12.8 , bbls of 15.7,ppg.AS1 cement on to of. retainer.Shut down and clean up 10:45 11:15 0.50 300 0 PROD1 PLUG TRIP P POOH f/300' MD. Rack back in derrick and L/D running tool 11:15 12:00 0.75 0 0 PROD1 PLUG PULD P Pull wear ring and L/D running tool 12:00 12:45 0.75 0 31 PROD1 PLUG PULD P PJSM, M/U Mulit-String cutter as per Baker Rep Payk 30 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 13:45 1.00 31 0 PROD1 PLUG RTWH P Rl[w/utter t/30.5"MD Start pumps @ 1 BPM=60 PSI,60 RPM, TQ=600 Ft/lbs. Stage pump up t/5 BPM=775 PSI, pump f/5 min. Shut down pump and rotary. Pick up 6"on string, pump©4 BPM=750 PSI, slack off 6"into cut, saw pressure drop f/positive indication cut was made. POOH L/D cutter. 13:45 14:00 0.25 0 0 PROD1 PLUG SFTY P PJSM M/U Spear 14:00 14:45 0.75 26 0 PROD1 PLUG FISH P M/U Spear. RIH w/spear and spear into hanger @ 26'MD. Back out lock downs, pull hanger and packoff to rig floor(10K overpull) 14:45 15:15 0.50 0 0 PROD1 PLUG PULD P L/D Spear 15:15 16:00 0.75 0 0 PROD1 PLUG OTHR P R/U stack washer and flush stack, B/D all lines 16:00 16:15 0.25 0 0 PROD1 WHDBO SFTY P PJSM on N/D BOPE 16:15 17:00 0.75 0 0 PROD1 WHDBO NUND P N/D BOPE and rack back 17:00 19:00 2.00 0 0 PROD1 WHDBO NUND P N/D casing spool and tubing spool 19:00 20:00 1.00 0 0 PROD1 PLUG PULD P Load pipe shed w/1"pipe f/top job, P/U 1"pipe and RIH. Taged cement inside the 7 5/8 casing @ 40'. POOH and L/D 1 joint of 1"pipe. 20:00 21:15 1.25 0 0 PROD1 PLUG RURD P PJSM, R/U cementers and load biozan pill on vac truck 21:15 22:00 0.75 0 0 PROD1 PLUG CMNT P Pressure test lines to 250 PSI. Pump 14 BBLS 15.8 AS1 cement for top job down 7 5/8"casing. Using 1" Hydril tubing and mule shoe. Fill to surface. 22:00 23:15 1.25 0 PROD1 PLUG RURD P Clean up and rig down cement lines. Secure cellar. 23:15 00:00 0.75 PROD1 MOVE DMOB P PJSM. Set mouse hole, Rig up to lay down 4"DP. 32/18/2012 Lay down all drill pipe and clean pits. 00:00 06:00 6.00 0 0 PROD1 MOVE DMOB P Lay down all drill pipe.Clean pits. Prepare for rig move. Release rig @ 0600 HRS. Page 31 of 31 Sharks Tooth P&A Summary Feb. 19, 2012: Set welding hooch over well casings and place heater trunks in cellar to melt ice around cellar box. Feb. 20, 2012: Continue heating cellar box. Contact AOGCC for upcoming P&A operations. Note to self 8 to 12 hours of heat would have been long enough. Feb. 21, 2012: Obtain hot work and confined space permits. Cut off 16" landing ring and 10 3/4" hanger, return to KCS materials. Cut cellar box around conductor and remove same. Return cellar to KCS materials. Feb. 22, 2012: Dig out casing strings. Obtain hot work permit. Cut off conductor, 16" conductor, 10 3/4" and 7 5/8" casings 3 feet below tundra. Weld on Abandonment Marker Plate. Job witnessed and approved by AOGCC inspector Chuck Sheve. Robert L. Morrison Jr. 02/22/2012 ConocoPhillips(Alaska) Inc. Western North Slope WNS Non-pad Shark Tooth #1 501032064700 iI 1111 ' il Sperry Lirillinci Definitive Survey Report ort 28 February, 2012 UI , , i r il i, p,;, HALLIBURTON Sperry OrtIling ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well Shark Tooth#1 Project: Western North Slope TVD Reference: Sharktooth#1 @ 148.73ft(D141 (27.33+121.4)) Site: WNS Non-pad MD Reference: Sharktooth#1 @ 148.73ft(D141 (27.33+121.4)) Well: Shark Tooth#1 North Reference: True Wellbore: Shark Tooth#1 Survey Calculation Method: Minimum Curvature Design: Shark Tooth#1 Database: CPAI EDM Production Project Western North Slope Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Shark Tooth#1 Well Position +N/-S 0.00 ft Northing: 5,925,974.69 ft Latitude: 70°12'32.115 NI +EI-W 0.00 ft Easting: 481,548.83 ft Longitude: 150°8'55.586 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 121.40ft Wellbore Shark Tooth#1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 1/15/2012 20.52 80.80 57,614 Design Shark Tooth#1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.33 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (ft) (ft) (ft) (°) 27.33 0.00 0.00 250.06 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 170.72 2,539.21 Sharktooth#1 MWD R200(Shark Tooth MWD MWD-Standard 1/18/2012 12:C 2,635.37 6,157.63 Sharktooth#1 MWD R300(Shark Tooth MWD MWD-Standard 1/28/2012 12:C 6,297.04 6,297.04 Sharktooth#1 MWD R600(Shark Tooth MWD MWD-Standard 2/12/2012 12:C 6,357.47 6,678.10 Sharktooth#1 MWD R900(Shark Tooth MWD MWD-Standard 2/12/2012 12:C Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°l100') (ft) Survey Tool Name 27.33 0.00 0.00 27.33 -121.40 0.00 0.00 5,925,974.69 481,548.83 0.00 0.00 UNDEFINED 170.72 0.14 255.79 170.72 21.99 -0.04 -0.17 5,925,974.65 481,548.66 0.10 0.17 MWD(1) 227.65 0.14 267.97 227.65 78.92 -0.06 -0.31 5,925,974.63 481,548.52 0.05 0.31 MWD(1) 321.88 0.19 244.22 321.88 173.15 -0.13 -0.56 5,925,974.56 481,548.27 0.09 0.57 MWD(1) 412.61 0.40 252.79 412.61 263.88 -0.29 -1.00 5,925,974.40 481,547.83 0.24 1.04 MWD(1) 502.44 0.25 231.02 502.44 353.71 -0.51 -1.45 5,925,974.19 481,547.38 0.21 1.54 MWD(1) 594.55 0.17 254.42 594.55 445.82 -0.67 -1.74 5,925,974.02 481,547.09 0.13 1.87 MWD(1) 689.25 0.25 261.18 689.25 540.52 -0.74 -2.08 5,925,973.96 481,546.75 0.09 2.21 MWD(1) 782.08 0.35 239.73 782.07 633.34 -0.92 -2.52 5,925,973.78 481,546.30 0.16 2.69 MWD(1) 871.55 0.31 233.16 871.54 722.81 -1.20 -2.95 5,925,973.50 481,545.87 0.06 3.19 MWD(1) 965.48 0.28 229.02 965.47 816.74 -1.50 -3.33 5,925,973.20 481,545.50 0.04 3.64 MWD(1) 2/28/2012 11:56:01AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well Shark Tooth#1 Project: Western North Slope TVD Reference: Sharktooth#1 @ 148.73ft(D141 (27.33+121.4)) Site: WNS Non-pad MD Reference: Sharktooth#1 @ 148.73ft(D141 (27.33+121.4)) Well: Shark Tooth#1 North Reference: True Wellbore: Shark Tooth#1 Survey Calculation Method: Minimum Curvature Design: Shark Tooth#1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,055.35 0.38 219.53 1,055.34 906.61 -1.88 -3.69 5,925,972.83 481,545.14 0.13 4.11 MWD(1) 1,149.41 0.62 236.32 1,149.40 1,000.67 -2.40 -4.31 5,925,972.30 481,544.52 0.30 4.87 MWD(1) 1,241.88 0.31 205.58 1,241.86 1,093.13 -2.90 -4.83 5,925,971.80 481,543.99 0.42 5.53 MWD(1) 1,335.56 0.25 207.44 1,335.54 1,186.81 -3.31 -5.04 5,925,971.39 481,543.79 0.06 5.86 MWD(1) 1,428.99 1.11 62.58 1,428.97 1,280.24 -3.08 -4.33 5,925,971.63 481,544.50 1.42 5.12 MWD(1) 1,520.85 1.37 57.69 1,520.81 1,372.08 -2.08 -2.61 5,925,972.62 481,546.22 0.31 3.16 MWD(1) 1,615.86 1.25 57.24 1,615.79 1,467.06 -0.91 -0.78 5,925,973.78 481,548.05 0.13 1.04 MWD(1) 1,707.43 1.38 58.44 1,707.34 1,558.61 0.21 1.00 5,925,974.90 481,549.83 0.15 -1.01 MWD(1) 1,799.84 1.30 61.15 1,799.72 1,650.99 1.29 2.87 5,925,975.98 481,551.70 0.11 -3.14 MWD(1) 1,891.52 0.09 139.83 1,891.39 1,742.66 1.74 3.83 5,925,976.42 481,552.66 1.40 -4.19 MWD(1) 1,982.24 0.14 150.99 1,982.11 1,833.38 1.59 3.93 5,925,976.27 481,552.76 0.06 -4.23 MWD(1) 2,074.01 0.33 137.83 2,073.88 1,925.15 1.30 4.16 5,925,975.98 481,552.99 0.21 -4.35 MWD(1) 2,168.92 0.43 128.10 2,168.79 2,020.06 0.87 4.62 5,925,975.55 481,553.45 0.13 -4.64 MWD(1) 2,261.24 0.44 166.18 2,261.11 2,112.38 0.32 4.98 5,925,975.00 481,553.81 0.31 -4.79 MWD(1) 2,353.83 0.41 171.20 2,353.70 2,204.97 -0.36 5.11 5,925,974.32 481,553.94 0.05 -4.69 MWD(1) 2,446.80 0.25 164.19 2,446.66 2,297.93 -0.88 5.22 5,925,973.80 481,554.05 0.18 -4.61 MWD(1) 2,539.21 0.33 184.63 2,539.07 2,390.34 -1.34 5.25 5,925,973.34 481,554.08 0.14 -4.48 MWD(1) 2,635.37 0.33 178.87 2,635.23 2,486.50 -1.89 5.24 5,925,972.79 481,554.06 0.03 -4.28 MWD(2) 2,727.64 0.25 168.31 2,727.50 2,578.77 -2.36 5.28 5,925,972.32 481,554.11 0.10 -4.16 MWD(2) 2,818.25 0.36 153.19 2,818.11 2,669.38 -2.80 5.45 5,925,971.88 481,554.27 0.15 -4.17 MWD(2) 2,910.37 0.45 163.52 2,910.23 2,761.50 -3.41 5.68 5,925,971.27 481,554.51 0.13 -4.18 MWD(2) 3,005.24 0.40 164.32 3,005.09 2,856.36 -4.08 5.88 5,925,970.59 481,554.70 0.05 -4.13 MWD(2) 3,099.74 0.36 153.10 3,099.59 2,950.86 -4.67 6.10 5,925,970.01 481,554.92 0.09 -4.14 MWD(2) 3,190.89 0.31 153.28 3,190.74 3,042.01 -5.14 6.34 5,925,969.53 481,555.16 0.05 -4.21 MWD(2) 3,280.53 0.17 170.04 3,280.38 3,131.65 -5.49 6.48 5,925,969.19 481,555.29 0.17 -4.21 MWD(2) 3,377.56 0.62 344.28 3,377.41 3,228.68 -5.13 6.36 5,925,969.55 481,555.18 0.81 -4.23 MWD(2) 3,467.67 1.20 349.92 3,467.51 3,318.78 -3.73 6.06 5,925,970.95 481,554.88 0.65 -4.43 MWD(2) 3,563.31 1.05 341.10 3,563.13 3,414.40 -1.91 5.60 5,925,972.77 481,554.43 0.24 -4.61 MWD(2) 3,654.81 1.06 337.12 3,654.61 3,505.88 -0.34 5.00 5,925,974.34 481,553.83 0.08 -4.58 MWD(2) 3,747.60 1.15 338.63 3,747.38 3,598.65 1.32 4.33 5,925,976.00 481,553.16 0.10 -4.52 MWD(2) 3,840.74 0.57 319.38 3,840.51 3,691.78 2.54 3.69 5,925,977.22 481,552.52 0.69 -4.33 MWD(2) 3,934.26 0.57 292.60 3,934.03 3,785.30 3.07 2.95 5,925,977.76 481,551.79 0.28 -3.82 MWD(2) 4,026.95 0.62 289.77 4,026.71 3,877.98 3.42 2.06 5,925,978.11 481,550.89 0.06 -3.10 MWD(2) 4,119.45 0.62 299.25 4,119.21 3,970.48 3.83 1.15 5,925,978.52 481,549.99 0.11 -2.39 MWD(2) 4,211.33 0.56 290.97 4,211.08 4,062.35 4.24 0.30 5,925,978.93 481,549.14 0.11 -1.72 MWD(2) 4,302.97 0.53 297.63 4,302.72 4,153.99 4.59 -0.50 5,925,979.29 481,548.34 0.08 -1.10 MWD(2) 4,397.50 0.48 293.24 4,397.25 4,248.52 4.95 -1.25 5,925,979.65 481,547.59 0.07 -0.51 MWD(2) 4,485.84 0.31 291.35 4,485.58 4,336.85 5.18 -1.81 5,925,979.88 481,547.03 0.19 -0.06 MWD(2) 4,581.57 0.74 200.51 4,581.31 4,432.58 4.70 -2.27 5,925,979.40 481,546.57 0.84 0.53 MWD(2) 4,671.16 1.37 186.90 4,670.89 4,522.16 3.09 -2.60 5,925,977.79 481,546.24 0.75 1.39 MWD(2) 2/28/2012 11:56:01AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well Shark Tooth#1 Project: Western North Slope ND Reference: Sharktooth#1 @ 148.73ft(D141 (27.33+121.4)) Site: WNS Non-pad MD Reference: Sharktooth#1 @ 148.73ft(0141 (27.33+121.4)) Well: Shark Tooth#1 North Reference: True Wellbore: Shark Tooth#1 Survey Calculation Method: Minimum Curvature Design: Shark Tooth#1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,765.76 1.43 189.58 4,765.46 4,616.73 0.81 -2.93 5,925,975.51 481,545.90 0.09 2.48 MWD(2) 4,859.98 1.42 162.54 4,859.65 4,710.92 -1.46 -2.78 5,925,973.23 481,546.05 0.71 3.11 MWD(2) 4,951.05 1.54 147.68 4,950.69 4,801.96 -3.58 -1.79 5,925,971.12 481,547.04 0.44 2.90 MWD(2) 5,038.56 0.52 154.41 5,038.18 4,889.45 -4.93 -0.99 5,925,969.77 481,547.83 1.17 2.61 MWD(2) 5,136.65 0.20 129.07 5,136.27 4,987.54 -5.44 -0.66 5,925,969.26 481,548.16 0.36 2.48 MWD(2) 5,321.24 0.14 139.72 5,320.86 5,172.13 -5.81 -0.27 5,925,968.88 481,548.55 0.04 2.23 MWD(2) 5,415.29 0.12 125.67 5,414.91 5,266.18 -5.96 -0.11 5,925,968.74 481,548.71 0.04 2.14 MWD(2) 5,508.79 0.20 121.60 5,508.41 5,359.68 -6.10 0.11 5,925,968.59 481,548.92 0.09 1.98 MWD(2) 5,601.23 0.22 110.40 5,600.85 5,452.12 -6.25 0.41 5,925,968.45 481,549.23 0.05 1.74 MWD(2) 5,692.99 0.31 119.81 5,692.61 5,543.88 -6.43 0.79 5,925,968.26 481,549.61 0.11 1.45 MWD(2) 5,783.06 0.20 138.09 5,782.68 5,633.95 -6.67 1.11 5,925,968.02 481,549.92 0.15 1.23 MWD(2) 5,874.46 0.06 143.11 5,874.08 5,725.35 -6.83 1.24 5,925,967.86 481,550.06 0.15 1.16 MWD(2) 5,971.40 0.00 43.11 5,971.02 5,822.29 -6.87 1.27 5,925,967.82 481,550.09 0.06 1.14 MWD(2) 6,065.33 0.09 141.83 6,064.95 5,916.22 -6.92 1.32 5,925,967.77 481,550.13 0.10 1.12 MWD(2) 6,157.63 0.09 174.14 6,157.25 6,008.52 -7.05 1.37 5,925,967.64 481,550.19 0.05 1.12 MWD(2) 6,297.04 1.11 0.01 6,296.65 6,147.92 -5.81 1.38 5,925,968.88 481,550.20 0.86 0.68 MWD(3) 6,357.47 1.52 19.36 6,357.06 6,208.33 -4.47 1.65 5,925,970.22 481,550.47 0.99 -0.03 MWD(4) 6,451.56 1.44 25.76 6,451.12 6,302.39 -2.23 2.58 5,925,972.46 481,551.40 0.20 -1.66 MWD(4) 6,544.41 0.74 11.45 6,543.96 6,395.23 -0.59 3.20 5,925,974.09 481,552.03 0.80 -2.81 MWD(4) 6,639.31 1.19 30.02 6,638.84 6,490.11 0.86 3.82 5,925,975.55 481,552.65 0.57 -3.88 MWD(4) 6,678.10 0.99 11.59 6,677.62 6,528.89 1.54 4.09 5,925,976.22 481,552.92 1.03 -4.37 MWD(4) 2/28/2012 11:56:01 AM Page 4 COMPASS 2003.16 Build 69 C M , U to C 4) • 4 ... pi gl• 00 0 te 0 •=. 0, ' r ^1,0,4:' < ...E ti t 6, 1E C w• .03 .10 0 c DO C .N 40 O N — fct c Z1 00 31 CL ..N to co o cy. ., ' tit , . .it,c11 'k''' mu uo L '-- • o as c la. 44 N 0 .... ... , .,.. ..*4• - t i CL. 0 0 0 ,e e O• eC eie ..t C °L 0° ;5 • O 00 a C LVE co 0 ''- ' CZI ••••' u LI f*'t * . , ,,- , * \ ) ,4 •• ' I : ' •4•,• ' li.#42 , .400.- ,:,1. * , 0 ,.„ , .. . .‘ . • .., t •4, . _ v I . •• ,_=, •. 1 1 •, , ? , ? ri7 i',1 •••.-,......„ - I i 1 t ; • i '.1 l ICI 17 r .1 ) i II ' . • U rw: t0 d Y L . pp - u ttr 1.2 3 m t: 0i C .d C d L R.7 £� x 09,74 v C� a m A D } M uO C pq 4 a ' 0 L C Y1 0 a u „ fzn4 r x Cq • U C a y 61 d m 1C 4 a. pp d d pq u W a tr► ^ sem', G o 0.7 d m .t C C - * �. . g V v `n ` ' � CC T E 4i � - <.. 3 • O O C a 11 I H u 41* 4 ' e . . .._ t . , , 4 ,,„, ,. . „,„>-:,, 4 Ni t s 0.1 tt1 U c m = c o R Se a oo m t v d 0 0 °u .c a o ea o'at c o c v - U ✓" ,F m 0_.o Y c V °�` el ,Crl to O a.13000w ., o ` t � w, u o c p� —� "` a p L C M .. r, f fia„ 3 0 ` k , :.07 Ftp q al '---„,1 C N ti c-N1 C) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, -471(1-1,,- DATE: February 22 2012 P. I. Supervisor ( FROM: Chuck Scheve, SUBJECT: Surface Abandonment Petroleum Inspector Shark Tooth #1 PTD# 2111650 Wednesday, February 22, 2012: I traveled to the Conoco Phillips Shark Tooth #1 exploration location to inspect the casing cut off and abandonment of this well. All casing strings were cut off at approximately 4' below original ground level. Cement was found at surface in all casing stings. A 1/2" thick cap was welded to the outer most casing string with the required information bead welded to it. SUMMARY: I inspected the casing cut off depth, and the P&A marker plate on the Shark Tooth #1 well and found all to be in order. Attachments: Shark Tooth #1 cut off.JPG Shark Tooth #1 marker plate.JPG r I ♦F Surface Abandonment - Shark Tooth #1 (PTD 2111650) Photos by AOGCC Inspector C. Scheve 2/22/2012 ( A1441., , . ,.. . . .. \,4 ilw. 4 � Y w / t ._ s 02/211201; < Ail i 0 ti fix . F 410 V i 0 l � �� LrEIA SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Chip Alvord Drilling Manager N\ ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Exploratory Pool, Shark Tooth #1 Sundry Number: 312-059 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, — Daniel T. Seamount, Jr. Chair jya- DATED this?L day of February, 2012. Encl. DECEIVED Niee FEB 157012 COncillips Alaska Gil&Gas Cons. Commission Anohorago Post Office Box 100360 Anchorage,Alaska 99510-0360 February 14, 2012 Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry approval to P&A: Shark Tooth#1 Dear Commissioners: ConocoPhillips Alaska, Inc hereby applies for a Sundry to permanently plug and abandon the Shark Tooth#1 wellbore. Doyon rig 141 spud this well on January 18, 2012 and reach TD for the well on February 12, 2012. Please find attached for review the Sundry form 10-403 and the information that describes the P&A procedure for the exisiting wellbore. If you have any questions or require further information, please contact Dave Reimer at(907) 263-4347. Sincerely, C ip Alvord Drilling Manager '%1 • STATE OF ALASKA ‘2/ RECEIVED ALASKA OIL AND GAS CONSERVATION COMMIS ION APPLICATION FOR SUNDRY APPR VAL FEB 1 5 2012 20 AAC 25.280 1.Type of Request: Abandon Q Suspend ❑ Operational shutdown wgivgr ❑ ❑ Perforate ,,,iosk< u Gas Co .Commis l Alter casing ❑ Repair well E Plug Perforations ❑ Stimulate t--I Time Eit\ii14319r ide Change approved program ❑ Pull Tubingp ❑ Perforate New Pool ❑ Re-enter -Sus ended Well U 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑., 211165 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20647-0000 7.KB Elevation(ft): 9.Well Name and Number: 148.73'AMSL ' Shark Tooth#1. 8.Property Designation: 10. Field/Pools(s): ADL 25603/ALK 2677 Kuparuk River Field 11. PRESENT WELL CONDITION SUMMARY I Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured) Junk(measured): 6688' 6688' 6688' 6688' Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 16" 82' 82' Surface 2590' 10.75" 2590' 2590' 5210 2470 Intermediate 6244' 7.625" 6244' 6244' 6890 4790 Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft): N/A N/A 12.Attachments:Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑., BOP Sketch ❑ Exploratory .❑ Development ❑ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/15/2012 Oil ❑ Gas ❑ Plugged L Abandoned ❑., 16.Verbal Approval: Date:2/14 WAG ❑ GINJ❑ WINJ ❑ WDSPL ❑ Commission Representative: Guy Schwartz V- 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dave Reimer a 263-4347 Printed Name Chip Alvord Title Drilling Manager Signature %._Otl� Phone 265-6120 Date 2((4.(2_,( COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �) ( Z oc- Plug Integrity a. BOP Test ❑ Mechanical Integrity Test❑ Location Clearance dsu an....a` — A)01-i fi Vftsp t....144,- a_s i pa;c.r...4_,,r, z-ot Z----- Other: /1 P ido ca.si`,4 c...�e�i( t w�a, Q r Subsequent Form Required: / ..... (67 ®® V� G V APPROVED BY Approved by: / / COMMISSIONER THE COMMISSION Date:z/2'4 f Z RBD �P( ,v FEBFEB2220 �''? 7-- - i . #4rzi�,� ti ,Ak' ConochiIIips an.S IS ...err Plug & Abandon Program 13.1. Plug&Abandon Procedure 13.1.1. Notify AOGCC 48 Hours in advance of all well P&A operations.Hold pre job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 13.1.2. Mobilize and rig up SLB/Dowell for well abandonment operations.RIH with 1000'/33 joints of 3-1/2"PH6 tubing to cement through. 13.1.3. Set a 15.8 ppg balanced cement plug from TD(6,688' MD/TVD)to 6,144' MD/TVD(100' ' above 7-5/8"casing shoe). Total plug length approximately 544'. Pick up one stand and circulate out after setting plug. Cement volume calculation: 6688' —6244' =444' x.0443 bbl/ft in 6-3/4"hole x 1.5 washout=29.5 bbls 6244' —6144' = 100' x .045 bbl/ft in 7-5/8"29.7#csg=4.5 bbls Total cement=29.5 +4.5 =34 bbls 13.1.4. WOC to achieve compressive strength, approximately 10 hours. 13.1.5. While waiting on cement,RU to pump down the 10-3/4"x 7-5/8"annulus. Downsqueeze—60 bbl 15.8 ppg cement to fill 1500' of the annulus. No hydrocarbon zone is present from 10-3/4"casing shoe at 2591' MD/TVD to TOC for 7-5/8"casing at—4600' MD/TVD. Annulus cement volume calculation: Surface to 1500' = 1500' x 0.0397 bbl/ft(7-5/8"x 10-3/4"45.5#)=59.5 bbls 13.1.6. RD equipment required to pump down 10-3/4"x 7-5/8"annulus. 13.1.7. Tag,record location and pressure test plug to 1600 psi for 30 minutes. 13.1.8. POOH, PU mechanical barrier and set at 300' MD. Pressure test barrier. 13.1.9. Un-sting and spot a 300' plug (-13.8 bbl) of 15.8 ppg cement on top of barrier to surface in the 7-5/8"29.7# casing. Cement volume calculation: 300' x .0459 bbl/ft in 7-5/8"29.7 csg= 13.77= 13.8 bbls 13.1.10. POOH and lay down 4"drill pipe.N/D stack. 13.1.11. RIH as needed to top off 7-5/8"casing with cement. 13.1.12. RD and move out rig. 13.1.13. Cut off wellhead and all casing strings at 3 feet below ground level. Verify cement is at surface in all strings. Send casing head with stub to Materials for repair/redressing. Shark Tooth#1—Appraisal Well Page 1 of 2 Drilling Program v1.1 (11/20/2011) 111.101.•4101•MI.114011••- --r ConochiIIips 13.1.14. Weld 1/4"thick cover plate (at least 18" in diameter) over all casing strings with the following 'ormation bea. we .-• '• • the top. Drill 1/8"weep hole in cover plate. • ConocoPhillips Alaska, Inc. L-3. Ai 01--; '- • Shark Tooth#1 / • PTD# 211165 -6 6-)'11`e SS • API# 50-103-20647-0000 Remove cellar. Back fill cellar with gravel as needed. Clear ice pad location and demob all materials/equipment. Call agencies for final inspection. Shark Tooth#1—Appraisal Well Page 2 of 2 Drilling Program v1.1 (11/20/2011) Shark Tooth #1 Proposed P&A Schematic 2-14-2012 Depths are 13.8 BBL OH cement plug- based on est i i i 15.8 ppg Arctic Set 1 cement rig RKB i i i ^i (From 300'MD to Surface) Mechanical Barrier Set @ 300'MD 82'MD/TVD i i % i i f 0 0 $ i i i 1500'-6OBBL of i f ; 15.8 ppg Arctic Set 1 i i 0' i cement in 10' annulus to 0 surface 40 0 i % / i i % % 4 i i i i y i 0 i 0. iSurface Casing 1 $ i10-3/4"45.5#L-80 BTC (2590'MD/TVD) 4 i r r i i i i i i Intermediate Casingii 7-5/8"29.7#L-80 BTCM (6244'MD/TVD) 6144'-6688'MD/TVD -36 BBL of 15.8 ppg Arctic Set 1 6-%"Open Hole cement plug TD:6688'MD/TVD JPE 02/14/12 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, February 14, 2012 3:45 PM To: 'Reimer, David J' Cc: Engel, Joseph (Swift Technical Services LLC); Allsup-Drake, Sharon K Subject: RE: Shark Tooth P&A(PTD 211-165) Dave, You have verbal approval to P &A Sharktooth #1 as outlined in your procedure below. Notify inspectors as indicated to witness the tag, pressure test and surface cutoff. A copy of this email should be forwarded to the rig until the approved sundry hardcopy is available. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Reimer, David J [mailto:David.J.Reimer@conocophillips.com] Sent: Tuesday, February 14, 2012 2:42 PM To: Schwartz, Guy L (DOA) Cc: Engel, Joseph (Swift Technical Services LLC); Allsup-Drake, Sharon K Subject: Shark Tooth P&A Guy: Attached are the P&A procedures and 403 form the Shark Tooth#1 well. In the procedure it states that a mechanical barrier will be set at 300'. We are waiting to discuss this with the rig as to whether a CIBP or retainer will be used. If the attached documents meet with your satisfaction, please indicate your verbal approval for us to proceed with P&A operations. Hardcopies to follow. Thanks Dave 2/21/2012 Shark Tooth#1 Well Status as of Feb 20, 2012 Permit Number:211165 Current Operations: Well P&A'd. Rig released at 06:00 on February 18 Weekly Summary: Feb 13: POOH to BHA#800. Lay down Sperry tools. Clear and clean rig floor. rig up to run Halliburton RDT on DP. Stop. Wrong side door entry sub OD. Rig up to run Halliburton RDT on E- Line. Conduct E-Line operations. Feb 14: RIH w/E-Line RDT tools. Clear and clean rig floor. RIH w/ Drill pipe and mule shoe t/ 6205' MD. Performed LOT= 13.5 ppg EMW. POOH on elevators, clear and clean floor. R/U E- Line and run WaveSonic tool. Feb 15: Trip in the hole with 33 joints PH6. RIH from derrick to 6589' MD. Wash down to bottom. CBU. Pump balanced cement plug. 34 barrels 15.8 PPG slurry. POOH to 5733. WOC. while circulating. Feb 16: Wash down to top of 1st plug. Tag w/ 12k @ 6107' MD. CBU. R/U and test plug. Unable to establish baseline @ 1600 PSI. Attempt to retest. NoGo. Complete 30 min.test. 1650 PSI ISIP, 960 PSI FSIP. Order 40 more BBLS of 15.8 G. Retag top of plug @ 6135'. CBU. R/U and pump 2nd plug. 18.4 BBL plug. Perform hesitation squeeze to 1600PSI. Charted for 30 mins. Good. SIMOPS: Pump cement down OA. Feb 17: Cont t/WOC. RIH pumping 1.5 BPM and tag cement @ 5903' MD. CBU and POOH. L/D PH-6 pipe. P/U cement retainer and RIH t/300'. Set retainer and pump 12.8 bbls of AS1 on top of retainer. POOH. M/U casing cutter and cut casing @ 30.5". L/D cutter and M/U spear. Pull casing hanger and packoff to floor. N/D BOPE and Wellhead. RIH w/ 1" pipe and tag cement @0. ti O cf.., Pump top job,14 bbls of AS1.Cement to surface. Clean out cellar and L/D 4"drill pipe. Feb 18: Lay down all drill pipe and clean pits. Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, February 16, 2012 5:09 PM To: DOA AOGCC Prudhoe Bay Cc: Regg, James B (DOA); 'Reimer, David J' Subject: Sharktooth Lou/chuck, We will waive the second tag of the bottom cement plug for Sharktooth.... They sqz'd 8 more barrels and it is holding now. I asked them to chart test and retag the cement plug. Next step is setting a retainer at 300' and bringing cement to surface . Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 2/17/2012 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, February 14, 2012 3:45 PM To: 'Reimer, David J' Cc: Engel, Joseph (Swift Technical Services LLC); Allsup-Drake, Sharon K Subject: RE: Shark Tooth P&A(PTD 211-165) Dave, You have verbal approval to P &A Sharktooth#1 as outlined in your procedure below. Notify inspectors as indicated to witness the tag, pressure test and surface cutoff. A copy of this email should be forwarded to the rig until the approved sundry hardcopy is available. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Reimer, David 3 [mailto:David.].Reimer@conocophillips.com] Sent:Tuesday, February 14, 2012 2:42 PM To: Schwartz, Guy L (DOA) Cc: Engel, Joseph (Swift Technical Services LLC); Allsup-Drake, Sharon K Subject: Shark Tooth P&A Guy: Attached are the P&A procedures and 403 form the Shark Tooth#1 well. In the procedure it states that a mechanical barrier will be set at 300'. We are waiting to discuss this with the rig as to whether a CIBP or retainer will be used. If the attached documents meet with your satisfaction, please indicate your verbal approval for us to proceed with P&A operations. Hardcopies to follow. Thanks Dave 2/14/2012 Shark Tooth#1 Well Status as of Jan 30, 2012 Permit Number: 211165 Current Operations: Drilling ahead @ 5125' MD/TVD Weekly Summary: Jan 23: Continued testing BOPE with AOGCC rep. John Crisp. Began to M/U BHA when cold weather shut down came into effect. L/D BHA and P/U a mule shoe. RIH w/mule shoe t/2409'. Circulate well @ 5 BPM Jan 24: Cold weather shut down still in effect. Cont. circ. well @ 5 BPM w/mule shoe at 2409 MD. Performing routine rig maintenance. Jan 25: Cold weather shut down still in effect. Cont. circ. well @ 5 BPM w/mule shoe at 2409 MD. Performing routine rig maintenance. Review Situational Awareness Power Point with rig crews. Jan 26: Cold weather shut down still in effect. Cont. circ. well @ 5 BPM w/mule shoe at 2409' MD. Performing routine rig maintenance. Review Situational Awareness Power Point with rig daylight crew. Jan 27: Cont. circ. well @ 5 BPM w/mule shoe at 2409' MD while W.O.W. Performing routine rig maintenance. Temp.warmed quickly to-33. Prep to POH and test BOPE. Jan 28: Test BOPE. MU BHA#3 and RIH to 2472' MD. Test casing to 3000 PSI for 30 min. Drill out floats, shoe track and 20'of new hole. Swap to 9.6 PPG LSND mud. Perform FIT to 16 PPG EMW. Drill from 2623'to 2808' MD. Jan 29: Drill from 2808' MD to 4198' MD. Short trip to shoe. Hole in good shape. RIH and resume drilling to 4475'. Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, January 11, 2012 2:14 PM To: 'Reimer, David J'; Davies, Stephen F(DOA) Subject: RE: Shark Tooth#1(PTD 211-165) Dave, This email notice is sufficient for the mud program change. Also, please do send in a weekly update. A short summary is fine. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Reimer, David J [mailto:David.J.Reimer@conocophillips.com] Sent: Wednesday,January 11, 2012 2:09 PM To: Schwartz, Guy L(DOA); Davies, Stephen F(DOA) Subject: Shark Tooth #1 Guy/Steve: When we submitted the PTD for Shark Tooth, the supporting documents stated that we were planning to use a DRILPLEX AR type mud system in the surface hole. After reviewing this further with MI, we decide to use a conventional spud mud system. Do you need any notice from me about this change or will this note suffice? Also, in the past when we drilled NPRA wells, we provided a weekly update to the AOGCC. Even though Shark Tooth in not in the NPRA, do you still want me to submit a weekly update on the wells progress? Thanks Dave ca�tttl 71,0+-t, Regg, James B (DOA) PT--° -z(1/6s0 From: Crisp, John H (DOA) Sent: Tuesday, January 24, 2012 8:56 AM S i 2' (1 Z To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Subject: C/P Shark Tooth Exploration Well WSL Guy Whitlock called @ 0850 & notified Inspectors Crisp & Herrera that they were having well control drill on Exploration well Shark Tooth#1 located approximately 4 miles off KRU 2K Pad. Thanks for the call. 1 Shark Tooth#1 Well Status as of Jan 23,2012 Permit Number: 211165 Current Operations: Waiting on weather—temperature-56°F Weekly Summary: Jan 16: Moved Doyon 141 from 3N-11 to exploration ice pad. Shark Tooth#1. 25 miles one way. Three trips with 4 Peak Sows. Move in and rig up on well. Jan 17: Rig accepted 00:01. Kuparuk River Bridge access road closed to heavy traffic due to drifting snow. Load pipeshed with BHA components, 180 joints of 5" DP, 14 joints 5" HWDP,jars. Verify all plugs are closed in the pits, check all valves, bring spud mud on board. Continue to winterize, and warm up all equipment after rig move. Pick up and rack back 60 stands of 5" DP, 5 stands HWDP, one stand of monels. Jan 18: Conduct Diverter test with AOGCC Rep John Crisp. Wait on weather and roads to be opened. Drill from 82' MD to 225' MD. Stop. Wait on weather. ( Rig crews cleaned and serviced the rig) Begin drilling again at midnight. Jan 19: Drilled from 225' MD to 1753' in 17.32 HRS, Rop=88'/hr. Good hole conditions. Max gas units=270. Average back ground units 45. Back ream each stand. Running 40 BBLs/hr water. Mud temp 65°. Jan 20: Drilled from 1753' MD to 2603' in 11.72 HRS, Rop=73'/hr. Good hole conditions. Max gas units=329. Average back ground units 45. Back ream each stand. Running 40 BBLs/hr water. Mud temp 65°. Reach Total Depth @ 2603' MD. CBU 2x's. Short trip on elevators to top of HWDP. No over pull seen. TIH. Circulate and condition in preparation for cement job. Jan 21: POOH on elevators to surface. L/D BHA#2. R/U and run 103/4" L-80 45.5#BTC surface casing. C&C wellbore. Cement. Jan 22: Complete surface cement job. Bumped the plug. The floats held. 90 barrels of cement returns. N/D diverter. N/U well head. C/O seals on starting head after failed test. Test metal to metal seals to 1000 PSI 10 mins. Good. N/U BOPE. Test BOPE with AOGCC Rep. John Crisp. Lir-Air 5 r, /A\ SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 G. L. Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, Shark Tooth #1 ConocoPhillips Alaska, Inc. Permit No: 211-165 Surface Location: 1792' FNL, 1025' FEL, SEC. 20, T1ON, R8E, UM Bottomhole Location: 1792' FNL, 1025' FEL, SEC. 20, T1ON, R8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced exploration well. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Mud log required from base of conductor to total depth of the well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 41 Daniel T. Seamount, Jr. f✓� Chair DATED this f day of January, 2012. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVETY STATE OF ALASKA OEC 1 0 201 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Mesita Oil&Gas Cons.Commission 20 AAC 25.005 �610E±Oreig0 la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service-Winj ❑ Single Zone 2• lc.Specify if well is proposed for: Drill 0 ` Re-drill❑ Stratigraphic Test❑ Development-Gas❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑J • Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: 0 Blanket ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 • Shark Tooth#1 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD:6686' • TVD: 6686' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1792'FNL, 1025'FEL,Sec.20,T1ON,R8E, UM • ADL 25603 Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1792'FNL,1025'FEL,Sec.20,T1ON, R8E, UM 2677 1/15/2012 Total Depth: 9.Acres in Property: 14.Distance to 1792'FNL,1025'FEL,Sec.20,T1ON,R8E,UM 2560 Nearest Property: 1025 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 147.9 feel 15.Distance to Nearest Well Open Surface:x- 481546 ' y- 5925974• Zone- 4 GL Elevation above MSL: 117.9 feet to Same Pool: 2K-19AL1 11098 ft, 16.Deviated wells: Kickoff depth: 0 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) 2S 08 to.sz Maximum Hole Angle: 0° deg. Downhole:3500 psig Surface j3A7sig /t•ZS• 18.Casing Pro.ram: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24' 16" 62.5# H-40 Welded 80 Surf Surf 80' 80' Pre-installed 13.5" 10.75" 45.5# L-80 BTC 2688' Surf Surf 2688' ' 2688' 1030 sks Arctic LIteCRETE,220 sksDeepCRETE 9.875" 7.625" 29.7# L-80 BTCM 6243 Surf Surf 6243' ' 6243' 480 sks Class G 6.7C" -- --• -- - 02--13 , GGYG' OH sc..-i-i a,. 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: Property Plat EA BOP Sketch ❑ Drilling Program❑ Time v.Depth Plot❑ Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report❑ Drilling Fluid Program❑ 20 MC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: '"pz. 22. I hereby certify that the foregoing is true and correct. Contact Dave Reimer @ 263-4347 Printed Name G L Alvord Title Drilling Manager / Signature A '0 � Phone:265-6120 Date 'a( /�N G• Commission Use Only 1 Permit to DrillAPI Number: Permit A royal See cover letter Number: 2/ ( 1(--, 50-/V`�-G-�•-'�i��-ei-te Date: I (4)12, Ifor other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or prodcoalbed methane,gas hydrates,or gas contained in sha : Er 3500 f,,,c: /30t° /c 5 F Samples req'd: Yes U ❑ Mud log req'd: Yes [ No 0 Other:_- ,Q_ n G [>H2S measures: Yes Noo 0 Directional svy req'd: Yes [V7 No 0 Wroet Ss rep:PAC • 4.11;re SAPPROVED BY THE COMMISSION `4 DATE: > i, i (E ,COMMISSIONER ) orm • Ar', 'evise• ."f� y •-,-1 ,- -. i:i o'•' •rmt'- .a - • approva r •V• .r r g 'u mit in Duplicate ir1. f-3-/Z. ( t/,, I11Z, RECEIVED ocoPhif i DEC 1 6 Post Office Box 100360 Anchorage,Alaska 99510-0360 Alma Oil&Gas Cons. Commission Anctaorage December 15, 2011 Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill: Shark Tooth#1 Dear Commissioners: ConocoPhillips Alaska, Inc hereby applies for a Permit to Drill for the onshore exploratory well Shark Tooth#1. This vertical delineation well will be drilled off an ice road/pad originating from 2K Pad using Doyon Rig 141. The objective of this well is to confirm the presence of the Kuparuk A sand, penetrate it, and then conduct an evaluation program. A Geopressure and Shallow Hazards analysis was undertaken in preparation for drilling this well. As indicate in the attachments, the drilling program calls for drilling 13-1/2"surface hole to approx. 2688' MD/TVD, followed by an 9-7/8" intermediate hole section to approx. 6243' MD/ TVD and finally a 6-3/4" production hole section through the zone of interest, Kuparuk A-sand, to a well TD of approx 6686' MD/TVD. The evaluation program in production hole section of Shark Tooth#1will consist of cutting a 120' core of the Kuparuk A-sand, obtaining an RDT fluid sample, followed by a wireline logging program. The well will then be P&A'd. No testing will be performed. The planned spud date for Shark Tooth#1 is January 15, 2012. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information, please contact Dave Reimer at(907) 263-4347. Sincerely, A(- Chip Alvord Drilling Manager Shark Tooth #1 Schematic ConocoPhillips 24"x 16"62.5#H-40 @80' MD/TVD 10-3/4"45.5#L-80 BTC @ 2688' MD/TVD TOC ©4600' MD/TVD L 7-5/8"29.7#L-80 BTCM @ 6243' MD/TVD 6-3/4" Hole to well TD Depths based on rig RKB A 6686' MD/TVD Schematic not to scale Att_06 Shark Tooth#1 Well Schematic ORIGINAL prepred by: Dave Reimer 12/5/2011 Page 1 of 1 Schwartz, Guy L (DOA) From: Reimer, David J [David.J.Reimer@conocophillips.com] Sent: Thursday, December 29, 2011 1:03 PM To: Schwartz, Guy L (DOA) Cc: Davies, Stephen F (DOA); Engel, Joseph (Swift Technical Services LLC) Subject: RE: Sharktooth#1 (PTD 211-165) Attachments: Shark Tooth#1 PERMIT IT rev1.DOC; BOPE System.pdf Guy: Attached please find a revised Permit to Drill Document that addresses the issues you noted below Revisions were made to the following sections: Section 4: MPSP calculation Section 13: steps 6, 8, 11, 12, 13 & 16 (note bolded text) Also attached is a the initial BOP configuration Let me know if there is anything else you need Thanks Dave From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, December 23, 2011 2:13 PM To: Reimer, David J Cc: Davies, Stephen F (DOA) Subject: [EXTERNAL]Sharktooth #1 (PTD 211-165) Dave, Please get with Randy Kanady and make sure detail is consistent on CPAI PTDs. We had a long discussion about more detail in lieu of getting the whole and complete drilling package. Your steps are pretty detailed but the PTD application does not include minimum acceptable LOT or FIT values or include any mention of casing Ram testing or ram change out. I realize you are planning on doing those steps but I need them spelled out in the application. Could you also send me your initial BOP configuration ( Ram size and type)for the first pressure test in step 6. The MPSP value seems to be off... I get 2808 psi vs 3477 psi as shown. Even though this is close to the producing field it will be on a 7 day BOP test cycle. Also a separate sundry will need to be submitted to P &A the well at the end of the logging and coring operations. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 1/3/2012 Applicati Permit to Drill,Well Shark Too I r Sav= gagEW Permit It— Shark Tooth #1 66 Application for Permit to Drill Document (,<,t91"- j frd-cJ .Fr4. doh. i'o MaxVVell a x � m l z w 1Me11 Vplu � Table of Contents 1. Well Name 5 Requirements of 20 AAC 25.005(/) 5 2. Location Summary 5 Requirements of 20 AAC 25.005(c)(2) 5 Requirements of 20 AAC 25.050(b) 7 3. Blowout Prevention Equipment Information 8 Requirements of 20 AAC 25.005(c)(3) 8 4. Drilling Hazards Information 9 Requirements of 20 AAC 25.005(c)(4) 9 5. Procedure for Conducting Formation Integrity Tests 11 Requirements of 20 AAC 25.005(c)(5) 11 6. Casing and Cementing Program 12 Requirements of 20 AAC 25.005(c)(6) 12 7. Diverter System Information 13 Requirements of 20 AAC 25.005(c)(7) 13 8. Drilling Fluid Program 14 Requirements of 20 AAC 25.005(c)(8) 14 9. Abnormally Pressured Formation Information 16 Requirements of 20 AAC 25.005(c)(9) 16 10. Seismic Analysis 16 Requirements of 20 AAC 25.005(c)(10) 16 11. Seabed Condition Analysis 17 Requirements of 20 AAC 25.005(c)(11) 17 12. Evidence of Bonding 18 Requirements of 20 AAC 25.005(c)(12) 18 13. Proposed Drilling Program 18 Requirements of 20 AAC 25.005(c)(13) 18 Shark Tooth#1 APD Prepared by:Dave Reimer Page 1 of 7 Printed:3-Jan-12 Applicati - Permit to Drill,Well Shark Tooth#1 Saved:3-Jan-12 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 23 Requirements of 20 AAC 25.005 (c)(14) 23 15. Attachments 7 Attachment 1: Location Maps....................................... 7 Attachment 2: Directional Plan. .7 Attachment 3:Drilling Hazards Summary..............................................................................................7 Attachment 4: Cement Summary...........................................................................................................7 Attachment 5:Shallow Hazards and Pore Pressure Conclusions. 7 Attachment5:Seismic Analysis7 Attachment6: Well Schematic7 1. Well Name Requirements of 20 AAC 25.005 0 Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b).For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as Shark Tooth#1. This will be an exploratory delineation well 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth:and(D)other information required by 20 AAC 25.050(b); Location at Surface 1,792' FNL, 1,026' FEL, Sec 20-T1ON-R08E NAD 1927 RKB Elevation 147.9' AMSL Northings: 5,925,974 Eastings: 481,546 Pad Elevation 117.9' AMSL Location at Top of Productive Interval 1,792' FNL, 1,026' FEL, Sec 20-TION-R08E NAD 1927 Measured Depth, RKB: 6,278' Northings: 5,925,974 Eastings: 481,546 Total Vertical Depth, RKB: 6,278' Total Vertical Depth, SS: 6,130' Location at Total Depth 1,792' FNL, 1,026' FEL, Sec 20-TION-R08E NAD 1927 Measured Depth, RKB: 6,686' Northings: 5,925,974 Eastings: 481,546 Total Vertical Depth, RKB: 6,686' Total Vertical Depth, SS: 6,538' Plats showing the Ice Pad Configuration and Proposed Ice Pad and Ice Road Route are included. NOTE: Location coordinates on maps are in NAD 83. Please refer to Attachment 1: Ice Pad Configuration& Proposed Ice Pad and Ice Road route Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Shark Tooth#1 APD Prepared by:Dave Reimer Page 2 of 7 Printed:3-Jan-12 Applicat Permit to Drill,Well Shark Tooth#1 Saved:3-Jan-12 Application is for vertical Exploratory(delineation)well. There are no wells within 200 feet of the proposed wellbore. Please refer to Attachment 2: Directional Plan. and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. N/A—Application is for a vertical Exploratory(delineation)well. There are no wells within 200 feet of the proposed wellbore 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPS)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 141. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; Expect normal with possible light overpressure(3100—3500 psi)at top of Kup A sand at 6,278'TVD. Offset well 2K-19a data shows the maximum BHP of 3,500 psi at 6294' TVD. Equivalent Mud Weight @ TD=3,500 psi/(6,294'*.052)= 10.69 ppg The maximum potential surface pressure(MPSP)while drilling Shark Tooth#1 is calculated using the predicted 3,500 psi reservoir pressure,a 0.11 psi/ft gas gradient and A4 sand top TVD of 6,278 ft. MPSP =FPP—(0.11 x TVD) MPSP = 3500—(0.11 x 6278) =2,809 psi 0K— (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; A Shallow Hazard and Pore Pressure Study was conducted for well. Mudlogging service will be utilized on this well. Please refer to Attachment 3: Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(/); Drill out surface casing shoe and perform LOT test or FIT in accordance with the Kuparuk LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. Shark Tooth#1 APD Prepared by:Dave Reimer Page 3 of 7 Printed:3-Jan-12 Applicat •Permit to Drill,Well Shark Tooth#1 Saved:3-Jan-12 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed; Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program Pre-installed 16 24 62.5 H-40 Welded 80' Surf 80'/80' Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 BTC 2,688' Surf 2,688'/2,688' 1030 sks Arctic LiteCRETE Lead 10.85 ppg, 220 sks Tail Slurry DeepCRETE 12.0 ppg Cement Top planned @ 4,600'MD/4,600' 7-5/8 9-7/8 29.7 L-80 BTCM 6,243' Surf 6,243'/6,243' ND. Cemented w/ 480 sks Class"G"15.8 ppg Please refer to Attachment 4: Cement Summary • 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 141. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already onf le with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Drilling will be done using water based mud systems having the following properties: Surface 80'—2,688' Mud Type Drilplex AR Density(ppg) 8.6—9.4 Funnel Viscosity(seconds) 60-120 sec. Yield Point(cP) 40-80 API Fluid Loss(ml/30min) NC—< 10 Chlorides(mg/I) <1000 pH 10.8 Intermediate 2,688'—6,243' Mud Type LSND Density(ppg) 9.6— 10.5 Low Shear Rate Yield Point(LSYP) 5- 10 (lb/100 ft^2) API Fluid Loss(ml.30min) <6 pH 9.5— 10.0 Drill Solids(% V/V) <7 Shark Tooth#1 APD Prepared by:Dave Reimer Page 4 of 7 Printed:3-Jan-12 C Applicat •Permit to Drill,Well Shark Tooth#1 Saved:3-Jan-12 Production 6,243'—6,686' Mud Type LSND/Core Fluid Density(ppg) 10.5— 11.0 Low Shear Rate Yield Point 5-6 (LSYP) (lb/100ft"2) API Fluid Loss(mL/30min) <6 pH 7.5—8.5 Drill Solids(% V/V) <6 Diagram of Doyon 141 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.0330; A Shallow Hazard and Pore Pressure Study was conducted for well. Mudlogging service will be utilized on this well. Please refer to Attachment 5: Shallow Hazards and Pore Pressure Conclusions 10. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); A Shallow Hazard and Pore Pressure Study was conducted for well. Mudlogging service will be utilized on this well. Please refer to Attachment 5: Shallow Hazards and Pore Pressure Conclusions 11. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom founded structure,jack-up rig,or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC 25.061(b); N/A-Application is not for an offshore well. 12.Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding)have been met; Evidence of bonding for ConocoPhillips Alaska,Inc.is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program for Shark Tooth#1 is listed below. 1. MIRU Doyon 141 on Shark Tooth#1 conductor. + Lµr 2. NU and function test diverter system and prepare spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. Shark Tooth#1 APD Prepared by:Dave Reimer Page 5 of 7 Printed:3-Jan-12 Applicai -Permit to Drill,Well Shark Tooth#1 Saved:3-Jan-12 4. Spud and drill vertical 13-1/2"hole to the 10-3/4"surface casing point(2,688' MD/2,688' TVD)according to the directional plan. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 5. Run and cement 10-3/4"45.5#L-80 BTC casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Perform top job if required to bring cement to surface. � !Vol;5 sin 6. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE,install 3-1f2"x 6"VBR's, (y 6J44. test to 250/3500 psi. 7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results. 8. Drill out cement and 20'minimum to 50' maximum of new hole. Perform FIT up to 16.0 ppg EMW FIT (minimum acceptable 13.5 ppg EMW) 9. Drill vertical 9-7/8"hole to 6,243' MD/6,243' TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 10. POOH with DP and stand back. R/U and run wireline logs. 11. POOH and R/D wireline. Close blind RAMS,change 3-1/2"x 6"VBR's to 7-5/8"RAMS,test to 250/3500 psi. RU and run 7-5/8"29.7#L-80 BTCM casing to 6,243' MD/6,243' TVD and cement. 12. Change upper pipe RAMS f/7-5/8"to 3-1/2"x 6"VBR's,freeze protect well. 13. P/U BOP test equipment. Test BOPE to 3,500psi.Record the results.Test 3-1/2"x 6"VBR's to 250/3500 psi. 14. LD 5"DP and PU 4"DP with 6-3/4"hole BHA. 15. Shut in BOP's and pressure test casing to 3,000 psi per AOGCC regulations. Record results. 16. Drill out cement and 20'minimum to 50' maximum of new hole. Perform LOT up to 16.0 ppg EMW. If unable to obtain 16.0 ppg notify Drilling Engineer 17. Drill vertical 6-3/4"hole to core point at a projected depth of 6,278' MD/6,278' TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 18. POOH with DP and stand back. L/D drilling BHA and P/U 5-1/2"core barrel and core 120' in 2 runs. 19. POOH with DP and L/D core barrel. P/U drilling BHA,MAD pass cored interval and drill vertical 6-3/4"hole to TD of 6,686' MD/6,686'TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 20. POOH with DP and stand back. L/D drilling BHA. P/U RDT tool on DP,RIH and proceed with sampling program. 21. POOH with DP and stand back. L/D RDT tool and P/U drilling BHA,RIH and conduct open hole LOT. 22. POOH with DP and stand back. L/D drilling BHA. R/U and run wireline logs 23. POOH and R/D wireline. RIH with DP and conduct P&A operations 24. POOH,L/D DP and associated equipment. FE A 25. N/D BOP and rig down and move out rig. S Gt U D11-1 Please refer to Attachment 6: Well Schematic. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Shark Tooth#1 APD Prepared by:Dave Reimer Page 6 of 7 Printed:3-Jan-12 Applicati Permit to Drill,Well Shark Tooth#1 Saved:3-Jan-12 Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class Il disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. A cuttings pit will be constructed on location as a secondary plan for cuttings disposal in the event that Phase 2 or 3 weather conditions prevents the hauling of fluids off location to disposal facilities. This well will not be tested and no completion will be run. ConocoPhillips Alaska intention is to plug and abandon this well. 15.Attachments Attachment 1:Location Maps Attachment 2:Directional Plan Attachment 3:Drilling Hazards Summary Attachment 4:Cement Summary Attachment 5:Shallow Hazard and Pore Pressure Conclusions Attachment 5:Seismic Analysis Attachment 6: Well Schematic Shark Tooth#1 APD Prepared by. Dave Reimer Page 7 of 7 Printed:3-Jan-12 BOP Equipment • 1 ea. -Hydril annular BOP, model MSP,21 1/4"x 2000 psi , flanged,NACE trim • 1 ea. -Hydril annular BOP, model GK, 13 5/8"x 5000 psi, flanged,NACE trim • 2 ea. -Hydril single gate,model MPL, 13 5/8"x 5000 psi, flange x flange,NACE trim with ten inch operators • 1 ea. -Hydril single gate,model MPL, 13 5/8"x 5000 psi, flange x flange,NACE trim with fourteen inch operators Stack is moved by 2 ea., 20 ton hydraulic BOP cranes controlled by a remote console • Rams are handled with a hydraulic winch in the cellar BOP Closing Unit 1 ea.—Hydril, 8 station, 3000 psi, 165 gallon accumulator unit Primary closing hydraulic power is provided by an electrically driven triplex pump with adequate high pressure hydraulic bottle storage. Secondary system back-up is a 30:1 air pump,and emergency tertiary back-up closing pressure is provided by a four-bottle,high pressure nitrogen rack. The PLC controlled remote closing BOP operator panels are located in the doghouse,accumulator unit and the utilities module. BOP Test Pump 1 ea.—5000 psi ,variable triplex pump with dedicated test fluid tank and two pin chart recorder Spools and Valves • 1 ea. -20 1/4"x 20 1/4"x 2000 psi, flanged diverter spool with one ea. - 10" x 300 psi flange for an hydraulically activated diverter system knife gate valve. • 1 ea. -20 1/4" x 16"x 2000 psi adapter spool • 1 ea. - 13 5/8" x 13 5/8"x 5000 psi flanged mud cross with two ea.-3 1/8" x 5000 psi outlets, NACE trim • 1 ea. - 13 5/8"x 11"x 5000 psi flanged adapter spool,NACE trim • 1 ea. - 3 1/8"x 5000 psi , hydraulically operated gate valve(kill HCR),NACE trim • 1 ea.-3 1/8" x 5000 psi ,manual gate valve ,NACE trim • 1 ea. - 3 1/8" x 5000 psi , hydraulically operated gate valve(choke HCR),NACE trim • 1 ea. -3 1/8"x 5000 psi , hydraulically operated gate valve ,NACE trim Choke Manifold d • 2 ea. - 2 1/16" x 5000 psi,manual gate valves • 13 ea. - 3 1/8" x 5000 psi,manual gate valves • 1 ea. -3 1/8" x 5000 psi,manual adjust choke • 1 ea. -3 1/16"x 10,000 psi,remote operated hydraulic choke All valves have NACE trim and color coded handles for sequencing the remote choke control panel is located on the drill floor Drillstring Valves • 2 ea. - 15,000 psi, 3"ID x 6 5/8"upper and lower IBOP valves, air actuated ( in top drive mode ) • 1 ea. -Hydril , 10,000 psi ,upper kelly cock • 2 ea. -Hydril , 10,000 psi , lower kelly cocks • 2 ea. -Hydril , 5,000 psi , 4 1/2"IF, IBOP safety valve • 1 ea. -dart valve, 10,000 psi , 3 1/2 IF • 1 ea. -dart valve , 10,000 psi ,4 1/2 IF The FMC 13-5/8"Blow out Preventer System is rated to 5,000 psi and consists of the following(Top to Bottom as per previous figure): • 13-5/8", 5000 psi Hydril Annular BOP, studded top/flanged bottom. Attachment 02 BOPE System • Single 13-5/8", 5000 psi, 10"MPL Operators, Hydril Pipe Ram. Flange bottom/ studded top BX 160 • Single 13-5/8", 5000 psi, 14"MPL Operators,Blind Shear Ram. Studded bottom/Flanged top BX 160 • 3-1/8" 5000 psi HCR Valve. • 2"Kill Line/3" Choke Line • 3-1/8" 5000 psi gate Valve. • Single 13-5/8", 5000 psi, 10" MPL Operators, Hydril Pipe Ram. Flange bottom/Flange top BX 160 • 13-5/8"x 11", 5000 psi,riser spool. Flange bottom/Flange top BX160 `_x 1 - II 13 5/8" 5000 PSI HYDRIL ANNULAR BOP t j STUDDED TOP/FLANGED BOTTOM 4 6' � I i / FANGED TOP/STJDDED BOTIOV Hz 160 ■ 13 5/8", 5000 PSI, 10" MPI OPERATORS - HYDRIL PIPE RAM c P _ M I ( ■ 13 5/8", 5000 PSI, '.�' MPL OPERATORS HYDRIC BLIND/SHEAR RAM ✓ STUDDED TO?/FLENGEC BOTTOM BX 160 3/8'�- - - - - --- - - 3 1/8" 5000 PS- HCR VALVE ' 10 1/8" 3" CHOKE LINE ';>- > 2" KILL LINE �— — — — _-- i- "`) 3 1/8" 5000 PS! GATE VALVE 3/a 3 1/8" 5000 PSI HCR VALVE1 L I 1-— FLANCE/FANGS BX 160 3 1/8" 5000 PSI GATE VALVE I a SINGLE 13 5/5- 5000 PSI 10" MPL OPERATORS HYDRIL PIPE RAM '- —�— — ----- — -----------I' STUDDED TOP/FLANGED BOTTOM BX 160 BOP STACK , ADAPTER SPOOL HUB x ;INCE WELLHEAD r--- —� FIANCE/FLANGE Attachment 02 BOPE System Applicatic Permit to Drill,Well Shark Tooth#1 Saved: 15-Dec-11 Permit It— Shark Tooth #1 ss Application for Permit to Drill Document MaxWell maximize well volae Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(f) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 2 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005(c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 3 Requirements of 20 AAC 25.005(c)(5) 3 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 8. Drilling Fluid Program 4 Requirements of 20 AAC 25.005(c)(8) (eV 4 9. Abnormally Pressured Formation Information 1'�, 5 Requirements of 20 AAC 25.005 (c)(9) 471P 5 10. Seismic Analysis 5 Requirements of 20 AAC 25.005(c)(10) 5 11. Seabed Condition Analysis 5 Requirements of 20 AAC 25.005(c)(11) 5 12. Evidence of Bonding 5 Requirements of 20 AAC 25.005(c)(12) 5 13. Proposed Drilling Program 5 Requirements of 20 AAC 25.005(c)(13) 5 Shark Tooth#1 APD Prepared by:Dave Reimer Page 1 of 7 ORIGINAL Printed: 15-Dec-11 Applicatic permit to Drill,Well Shark Tooth#1 Saved: 15-Dec-11 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 6 Requirements of 20 AAC 25.005(c)(14) 6 15. Attachments 7 Attachment 1: Location Maps. 7 Attachment 2: Directional Plan7 Attachment 3:Drilling Hazards Summary7 Attachment 4: Cement Summary. 7 Attachment 5:Shallow Hazards and Pore Pressure Conclusions. 7 Attachment 5:Seismic Analysis7 Attachment 6: Well Schematic......................................................................................................... 7 1. Well Name Requirements of 20 AAC 25.005(fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b).For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as Shark Tooth#1. This will be an exploratory delineation well 2. Location Summary 1"`' Requirements of 20 AAC 25.005(c)(2) ��`3. ! An application for a Permit to Drill must be accompanied by each of the following items,exceptf i a ady on file with, mmission and identified in the application: (2)a plat identing the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation, total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plaoordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth:and(D)other information required by 20 AAC 25.050(6); Location at Surface 1,792' FNL, 1,026' FEL, Sec 20-T1ON-R08E NAD 1927 RKB Elevation 147.9'AMSL - Northings: 5,925,974 Eastings: 481,546 Pad Elevation 117.9'AMSL Location at Top of Productive Interval 1,792' FNL, 1,026' FEL, Sec 20-T1ON-R08E NAD 1927 Measured Depth, RKB: 6,278' Northings: 5,925,974 Eastings: 481,546 Total Vertical Depth, RKB: 6,278' Total Vertical Depth, SS: 6,130' Location at Total Depth 1,792' FNL, 1,026' FEL, Sec 20-T1ON-R08E NAD 1927 Measured Depth, RKB: 6,686' Northings: 5,925,974 Eastings: 481,546 Total Vertical Depth, RKB: 6,686' Total Vertical Depth, SS: 6,538' Plats showing the Ice Pad Configuration and Proposed Ice Pad and Ice Road Route are included. NOTE: Location coordinates on maps are in NAD 83. Please refer to Attachment 1: Ice Pad Configuration&Proposed Ice Pad and Ice Road route Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Shark Tooth#1 APD Prepared by:Dave Reimer Page 2 of 7 ORIGIN A L Printed: 15-Dec-11 Applicatic 'ermit to Drill,Well Shark Tooth#1 Saved: 14-Dec-11 Application is for vertical Exploratory(delineation)well. There are no wells within 200 feet of the proposed wellbore. Please refer to Attachment 2: Directional Plan. and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. N/A—Application is for a vertical Exploratory(delineation)well. There are no wells within 200 feet of the proposed wellbore 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: { (3)a diagram and description of the blowout prevention equipment(BOPS)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037, as applicable: Please reference BOP schematics on file for Doyon 141. 4. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application Jur a Permit to Drill thus!be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; Expect normal with possible light overpressure(3100—3500 psi)at top of Kup A sandha;t 6278''TVD. Offset well 2K-19a data shows the maximum BHP of 3,500 psi at 6294' TVD. Equivalent Mud Weight @ TD=3,500 psi/(6,294 .052) 10.69 ppg The maximum potential surface pressure(MPSP)while drilling Shark Tooth#1 is calculated using the predicted 3,500 psi reservoir pressure,a 0.11 psi/ft gas gradient and A4 sand top TVD of 6,278 ft. MPSP =(6,27 )*(0.69-0.11 psi/ft) ,477 psi Z 8oO r 5c 35�� psi — ( (( x (oZ9cD) (B)data on potential gas:ones; , /L,23./t The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; A Shallow Hazard and Pore Pressure Study was conducted for well. Mudlogging service will be utilized on this well. Please refer to Attachment 3: Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.0300; Drill out surface casing shoe and perform LOT test or FIT in accordance with the Kuparuk LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. Shark Tooth#1 APD Prepared by:Dave Reimer ORIGIN L Page 3 of 7 Printed: 14-Dec-11 Applicatic 'ermit to Drill,Well Shark Tooth#1 Saved: 14-Dec-11 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed Casingand Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program Pre-installed 16 24 62.5 H-40 Welded 80' Surf 80'/80' Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 BTC 2,688' Surf 2,688'/2,688' 1030 sks Arctic LiteCRETE Lead 10.85 ppg, ✓ 220 sks Tail Slurry DeepCRETE 12.0 ppg Cement Top planned @ 4,600'MD/4,600' 7-5/8 9-7/8 29.7 L-80 BTCM 6,243' Surf 6,243'/6,243' TVD. Cemented w/ 480 sks Class"G"15.8 ppg Please refer to Attachment 4:Cement Summary 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under 20 AAC 25.0350)(2); Please reference diverter schematic on file for Doyon 141. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Drilling will be done using water based mud systems having the following properties: Surface 80'-2,688' p „ 18, Mud Type Drilplex AR Density(ppg) 8.6-9.4 Funnel Viscosity(seconds) 6.0-12.0 sec. Yield Point(cP) 40-80 � " API Fluid Loss(ml/30min) NC-< 10 -'' Chlorides(mg/l) <1000 pH 10.8 Intermediate 2,688'-6,243' Mud Type LSND Density(ppg) 9.6-10.5 Low Shear Rate Yield Point(LSYP) 5 - 10 (lb/100 ft^2) API Fluid Loss(ml.30min) <6 pH 9.5-10.0 Drill Solids(% V/V) <7 Shark Tooth#1 APD Prepared by:Dave Reimer ORIGIN, t Pagee of- 7 Printed: age 4 -11 Applicatio, 'ermit to Drill,Well Shark Tooth#1 Saved: 14-Dec-11 Production 6,243'—6,686' Mud Type LSND/Core Fluid Density(ppg) 10.5— 11.0 Low Shear Rate Yield Point 5 -6 (LSYP) (lb/100ft^2) API Fluid Loss(mL/30min) <6 pH 7.5—8.5 Drill Solids(% V/V) <6 Diagram of Doyon 141 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); A Shallow Hazard and Pore Pressure Study was conducted for well. Mudlogging service will be utilized on this well. Please refer to Attachment 5: Shallow Hazards and Pore Pressure Conclusions 10. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) in application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a): A Shallow Hazard and Pore Pressure Study was conducted for well. Mudlogging service will be utilized on this well. Please refer to Attachment 5: Shallow Hazards and Pore Pressure Conclusions 11. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom founded structure,jack-up rig,or floating drilling vessel,an analysis of seabed conditions as'required hi20;1A( 25.061(6): N/A-Application is not for an offshore well. 12. Evidence of Bonding 4)r Requirements of 20 AAC 25.005(c)(12) r' An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file.witethe commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025(Bonding)have been met; Evidence of bonding for ConocoPhillips Alaska,Inc.is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program for Shark Tooth#1 is listed below. DoT t `1 r,3ec�fcr �V hes Pry°r 1. MIRU Doyon 141 on Shark Tooth#1 conductor. 2. NU and function test diverter system and prepare spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. Shark Tooth#1 APD Prepared by:Dave Reimer Page ORIGINAL Printed: 14-Dec-11 Applicatio. 'ermit to Drill,Well Shark Tooth#1 Saved: 14-Dec-11 4. Spud and drill vertical 13-1/2"hole to the 10-3/4" surface casing point(2,688' MD/2,688' TVD)according to the directional plan. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 5. Run and cement 10-3/4"45.5#L-80 BTC casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Perform top job if required to bring cement to surface. _--? M71-47130 13 p 1° 6. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE and test to 3,500 psi. Re ord Con A results. 7 7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results. 8. Drill out cement and 20'minimum to 50'maximum of new hole. Perform LOT. M t N 4° . 9. Drill vertical 9-7/8"hole to 6,243' MD/6,243' TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 10. POOH with DP and stand back. R/U and run wireline logs. S/ " 1 AM L �. � P. 11. POOH and R/D wireline. Run 7-5/8"29.7#L-80 BTCMeCasing to 6,243' MD/6,243' TVD and cement. 12. LD 5"DP and PU 4"DP with 6-3/4"hole BHA. `� . ,m 13. Test BOPE to 3,SOOpsi.Record the results. Nal 14. Shut in BOP's and pressure test casing to 3,000 psi per AOGCC regulations. Record results.) 15. Drill out cement and 20'minimum to 50'maximum of new hole.Perform LOT. NtV4 16. Drill vertical 6-3/4"hole to core point at a projected depth of 6,278' MD/6,278' TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 17. POOH with DP and stand back. L/D drilling BHA and P/U 5-1/2"core barrel and core 120' in 2 runs. 18. POOH with DP and L/D core barrel. P/U drilling BHA,MAD pass cored interval and drill vertical 6-3/4"hole to TD of 6,686' MD/6,686'TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 19. POOH with DP and stand back. L/D drilling BHA. P/U RDT tool on DP,RIH and proceed with sampling program. 20. POOH with DP and stand back. L/D RDT tool and P/U drilling BHA, R1H and conduct open hole LOT. 21. POOH with DP and stand back. L/D drilling BHA. R/U and run wireline logs 22. POOH and R/D wireline. RIH with DP and conduct P&A operations 23. POOH,L/D DP and associated equipment. £ (c)-(10 24. N/D BOP and rig down and move out rig. n Please refer to Attachment 6: Well Schematic. w"Y e- Ju'r` rj o 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorisation under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Shark Tooth#1 APD Prepared by:Dave Reimer Page JRIGINAL Printed: 14-: 14-Dec-11e -11 Applicatio 'ermit to Drill,Well Shark Tooth#1 Saved: 14-Dec-11 A cuttings pit will be constructed on location as a secondary plan for cuttings disposal in the event that Phase 2 or 3 weather conditions prevents the hauling of fluids off location to disposal facilities. This well will not be tested and no completion will be run. ConocoPhillips Alaska intention is to plug and abandon this well. 15. Attachments Attachment 1:Location Maps Attachment 2:Directional Plan Attachment 3:Drilling Hazards Summary Attachment 4: Cement Summary Attachment 5:Shallow Hazard and Pore Pressure Conclusions Attachment 5:Seismic Analysis Attachment 6: Well Schematic Shark Tooth#1 APD Prepared by:Dave Reimer Page 7 of 7 ORIGINAL Printed: 14-Dec-11 - _ h �� ..,_\' C _ 4 4) 6 R ''f :-A x 8 ooh .. x ii i 'I (2 Csi \ t .J\ 111116 +'ill plunk .. 2 �S eop )- 3 0 i 0 ��" Z N R zylIllkIIIIIIIILltkPb Rv 14 Jr �• LI+7 Z \Y✓ R{ J-. �. 9 R `� (J ]�j(�=f.�YW �C Z < pgFp < N p 3 OZZ ^ Y < p p p 0,-<ZI 2 i Q t,^ 0 S a 2p Op''''' >O i aa a aiz o� gQ LI O Qo L3- CC R Z �-;_§ dJ� K 1 ® ooW � �ZUgZO�V=Q 7 - �p VgQWONH Y u pN3< o. Oom2z 8p \ O Q a U K N w O pZZ�4 O� � .*. arO.i�wo as r rN ���U 6 J S \ IS 0...,,....- z...,.-.. '2 1�VI w W Y- 'pp t7i • 1� 2 N M :N 2 as aoW.p- 70 = i $0 If ��p w �1e` N�"- t 3 ct 0 I I ttr, \ r (3 ; rT 5gg4 (Cl'i.% S os \ ‘,),, FA .-§x \ �!� -- \ U d, o 100dipk. Ok x rN Ifc 4 0 id - `Sd 111iii f'010 f J ..\ O a Ir � ,-t-_ . 'fir \ � \ X ui ^SQ Ute- \ 8 \ 0 O or n } o N rn al Ea Y S p $ -, if 0 -o 3 E m I▪ 6 @ �N $ o N O� a • W 7 0 op ° w O 0 �o -J a a tDI ( 1MA I REV DATE BY CK APP DESCRIPTION REV DATE BY APP DESCRIPTION 1 11/10/11 AJR Moved BOP to 2K Access Rood N WEST SAX 20 ' 22 23 Is l■ 20 „`= CPF2`.; ---ir-. ii. i Irfr DS-2B% �� -1b -4111 29 0 SCALE 28 26 25 30 . 1" 1 Mile fD: .t-' •• �S_2H PT�,- 32 /O 3. C6,34 3i ri.2 ..... 4 ,' ,a T11NR8E T11 -9E 1' . • DS-2G • • T1ONR8E T1ONR• C. .; 110 Si -: , , :"▪• 3 l'It\:—) 5 i 1S-2K • CP' '• qs„, .L.c., + ; ��t 8 ! �•`� 9 5,': 10 1. 11 � 1 )1787/ �.. t _ ,,, N 14 13 r . I AV.• _ 1 vv i. i , 1. ��a v: a r ' t.: • >..,_' I . IS PROJECT ° y. , ,.., .1_\ , , 22 :.i!^+ 23 24 19 •, ..0,-- SHA'KTOOTH ,,1;) ' .N4 I U 29 .' 2t" 27 30 41 �� IO 25 Q O THIS PROJECT IS LOCATED 4 Q ° IN HARRISON BAY A-1 o ° QUADRANGLE 0 0 32 1 3 0 34 35 0 36 LOUNSBURY ' 0do ASSOCIATES, INC. SU ORS ENGINEERS PLANNERS T1 ONR8E lb INV AREA: MODULE: UNIT: ConocoPhil lips SHARKTOOTH APPRAISAL WELL PROPOSED ICE PAD & ICE ROAD ROUTE Alaska, Inc. PERMIT EXHIBIT CADD FILE NO. I DRAWING NO: PART: REV: LK601D763 9/05/11 . NSK 6.01 —d763 1 of 2 I 1 REV DATE BY CK APP DESCRIPTION REV DATE eY APP DESCRIPTION 1 11/10/11 AR Moved BOP to 2K Access Rood ,.., • 6:30:-...„,--- , • --\ ....-N* ye.....13 r./...; " ,:,r . a) -0" - ‘- \ ----' . ,1 :---1r: r0 V:- 4'.. I / \ 2 - I .. .:'7'.0 --- • • •:;;; -••-e. :.-r \ .... .----s.7-tA .,,,,,4Jea''''''.*43?'..."<=;:.„ \ ....-7.;•'' ' -I C%1 • \ Cr''..r.•'.e e.....r'''' Z '• 04' < \ • • 0. .-- (...).-- _s ... .,. \ • 0 .. •1••''..t''• ul II DS-2K • 1\, . 0 • '1„,".t•'.. f., . :.•••• •-•70. •-•.••.,• V.."e,.• e'..,. k--. ea .^.. • 1,:::•;' It f;;, - • \ PROPOSED 35' WID ,.. \\ 4.4 MILE LONG ICE ROAD v.-, 4 '*,• • too i-.-"!.. ..„.2 A,..• llirb.i.' I .r ,_z.. - 1 .,..6.. ... ....a 1•••; ‘ # A : •-• ' •. ..'1 ,.. . • ‘ \ +7f...7:'•11% 0• \ , 1'il \ .ti: I •C.; ,..e S. -..1c. 9 ..j.. Ik, \ ''''.6.5.r: -fr ,,„,„, lap,..„ --N,.,.; .. \ z ei• , Ae" • . • • 0' s'•".. - :"' .. 7-,41.?!- "-•• 64:•t' \ ., . e rt:•-:*•.7-..4..- .. 21e‘.e,•-.*•.i-r_,‘i . .. _ _ , lI .-,"-- . %. • • ; -'1, ( POJECT CENTROID: r- 0 • 0 • Y 5,931,830.1 k.------,,,, ...*•,, -..1. ,....- -^----'-' 0 0)p % X 1 630 139.1,...' •.,..-.....tj, .....?. 1 :. .. Si - -. % 0 ........ ..- " 7.k...4..) 4%).. % LAT. 7013'31.2a :,11%....-.1.•••% . \'' ....... ) % LONG. 150'04'58.6" !.... ...,....', %,.....-..-,:„.r r.....- 1%. 1 . '‘.. 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(..•••••..i. .%..,..-, i ..-.•••••• ../. I 7..‘„.. r.; ""•;:: 6%'-i , r-i , %.-- - -..,.0:.r.k'-•• S.,. ,-r...:•,.. V / .t..••_•:::4 .. -„, ••• - - -.! •••:" 1/4.-XI il \ i!.' & --.. !7'..,S;9.....N.• lik •-i02.-t T., !V;;...'.1,S • ‘ -I " s.• ,r.:.„,,•,... .0 ,1 4,..,,.., ibrj .../ ,. .. ,-0. r •:::...........-.*:...t... S. ..„..., .... •-•... "...%i 1,, •!1 ‘ /...-.. - ... " "..tfi ...5,. zont -....-...V.'. \ ,I...! • i% C.,; (• t'''..• '`. .; it...--". ...!. . - !.i-' 41-... 7. _ 44,.. ...,....: I 4A .. .., si.D ,oe';' .1) 1 ,Lt' • r--.7,,.. .....e.r. ‘50CX5001 .,, -.------ -..-- -----• is. _ .... ....4 ‘ tf r- SHARKTOOTH WELL: -'6"--- \ICE PAD NOTES: - C.;',":.rs:_gY 5,925,724.0 1. COORDINATES ARE ASP, ZONE 4, NAD83. X 1,621.579.4 v° 2. GEODETIC COORDINATES ARE NAD8.3LAT. 7012'31.0 P' ----- LONG. 15009'06.8" SURVEYORSLIMNERS 7 LOUNS ENGINEERSBURPY ASSOCIATES, INC. ( IIIIPV AREA: MODULE: UNIT: ConocoPhillips SHARKTOOTH APPRAISAL WELL PROPOSED ICE PAD & ICE ROAD ROUTE Alaska, Inc. PERMIT EXHIBIT CADD FILE NO. DRAWING NO: PART: I REV: LK601D 763 9/05/11 NSK 6.01—d763 2 OF 2 I 1 0 ri i GIL ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Non-Pad Plan: Shark Tooth #1 Shark Tooth #1 Plan: Shark Tooth #1 (wp03) Standard Proposal Report 02 December, 2011 mommi HALLIBURTON Sperry Drilling Services ) n ! N ! • HALLIBURTON Project: Kuparuk River Unit Site: Non-Pad WELL DETAILS Plan Shark Tooth 111 Ground Level: 119.9 Well: Plan: Shark Tooth #1 +N/-S +E/-W Northing Easting Latittude Longitude Slot Sperry Drilling Wellbore: Shark Tooth #1 0.0 0.0 1806164.29 494258.3869°58'56.119 N 141°1'35.898 W Plan: Shark Tooth#1 (wpO3) REFERENCE INFORMATION -1000 Co-ordinate(N/E)Reference:Well Plan Shark Tooth#1,True North I..1_ -_ Vertical(TVD)Reference:Sharktooth Staked 6 147.98(0141(28+119.9)) - Measured Depth Reference:Sharktooth Staked($147.98(0141(28+119.9)) -1_�,---- Calculation Method:Minimum Curvature -500 �� � 1 1 I' i . CASING DETAILS Art MD TVD TVDSS Name Size Hole Size 0 SHL ENL,1026'FEL-Sec20-TION-11•04E 2687.9 2687.9 2540.0 10 3/4" 10.750 13.500 - 6242.9 6242.9 6095.0 7 5/8" 7.625 9.875 - -- 6685.9 6685.9 6538.0 6 3/4" 6.750 6.750 500 - — DDI = 0.000 -- 1000— - 1000 I P•nna(rvcr- 1 1500 2000--- - -- 1 2000 1 '' t0 3/4" 2500--- - Il C 3000 ---t-„m/,,,„n,h;rod_ 8 r _ C3500 -- Ca - To _ U_ - 1- - 4000—r i1- --- 2 It r -I E / I I ✓ z_c-rrr- 77 4500 -- 400 --- -- 300 5000 5000 - --- -- ---------� - -- SHL 1793'FNL,1026'FEL-Sec20-TION-R08E 200 1 1,41411 ThIh I 14 5500_ I -, --IIDD Ibh .or ri w Top Bermuda - —1 C-35-... _ p 100 --- - -+_-+ - r --._ .N. Shark T,.t #`(wp03) r I s ,HItZ(K-2 M1larhrr/- ----- - _ : - 6000 I I I I 7 5/8' 6000 + rr - Upper Kalabik_ -_-s _ t 0 10 3/4” ' Lou erKalubi/r -`4 Ic--'.Sl L Tooth,I AA j 7 5/8'' —. - „Top Kupanr 7 - - - - 7 lir �. _ C,-, 5/8'..3/4” I -- 6500-1-BaseKupanik �%100 ! I 6 3/4" .$ - -- ‘4111ii/ ''116686 O -200 = M Acimu hs to True Korth - - 7000 — --- - _ /� Magnetic North:2).89" Shark Tooth#1(wp03) - Magnetic Field I --- - _ -300 SVayth:67604.66AT - - Dip Angle'83.77" I 7500 i Date: 5/16/2011 _ - Model.BGGM2010 -400 i I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 r t t t 1 r 1 1 1111 I III -400 -300 -200 -100 0 100 200 300 400 8000 - West(-)/East(+)(250 ft/in) 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1111 11111 . . 1 1 -1500 -1000 -500 0 500 1000 1500 2000 Vertical Section at 0.00°(1000 ft/in) ConocoPhillips Alaska ORIGINAL Halliburton -Sperry I-IALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:Shark Tooth#1 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Sharktooth Staked @ 147.9ft(D141(28+119.9)) , Project: Kuparuk River Unit MD Reference: Sharktooth Staked @ 147.9ft(D141(28+119.9)) Site: Non-Pad North Reference: True Well: Plan:Shark Tooth#1 Survey Calculation Method: Minimum Curvature Wellbore: Shark Tooth#1 Design: Shark Tooth#1(wp03) Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Non-Pad Site Position: Northing: 1,811,859.81 m Latitude: 70°0'13.393 N From: Map Easting: 515,598.17 m Longitude: 140°27'9.678 W Position Uncertainty: 0.0 ft Slot Radius: 0.000 in Grid Convergence: 8.89 ° Well Plan:Shark Tooth#1 Well Position +NI-S 0.0 ft Northing: 1,806,164.29 m Latitude: 69°58'56.119 N +E/-W 0.0 ft Easting: 494,258.38 m Longitude: 141°1'35.898 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: - 119.9ft Wellbore Shark Tooth#1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 5/16/2011 20.89 80.77 57,605 Design Shark Tooth#1(wp03) Audit Notes: Version: Phase: PLAN Tie On Depth: 28.0 Vertical Section: Depth From(TVD) +NI-S +E/-W Direction (ft) (ft) (ft) (°) 28.0 0.0 0.0 0.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 28.0 0.00 0.00 28.0 -119.9 0.0 0.0 0.00 0.00 0.00 0.00 2,028.0 0.00 0.00 2,028.0 1,880.1 0.0 0.0 0.00 0.00 0.00 0.00 4,998.0 0.00 0.00 4,998.0 4,850.1 0.0 0.0 0.00 0.00 0.00 0.00 6,277.9 0.00 0.00 6,277.9 6,130.0 0.0 0.0 0.00 0.00 0.00 0.00 6,388.0 0.00 0.00 6,388.0 6,240.1 0.0 0.0 0.00 0.00 0.00 0.00 6,685.9 0.00 0.00 6,685.9 6,538.0 0.0 0.0 0.00 0.00 0.00 0.00 1 12/2/2011 10:08:41AM Page 2 COMPASS 2003.16Build 69 ,.," r), , el ,' • IJ, , ,„,,, 1,, t1L Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:Shark Tooth#1 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Sharktooth Staked @ 147.9ft(D141(28+119.9)) Project: Kuparuk River Unit MD Reference: Sharktooth Staked @ 147.9ft(D141(28+119.9)) Site: Non-Pad North Reference: True Well: Plan:Shark Tooth#1 Survey Calculation Method: Minimum Curvature Wellbore: Shark Tooth#1 Design: Shark Tooth#1(wp03) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-5 +EI-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (m) (m) -119.90 28.0 0.00 0.00 28.0 -119.9 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 SHL 1793'FNL,1026'FEL-Sec20-T10N-R08E 100.0 0.00 0.00 100.0 -47.9 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 200.0 0.00 0.00 200.0 52.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 300.0 0.00 0.00 300.0 152.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 400.0 0.00 0.00 400.0 252.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 500.0 0.00 0.00 500.0 352.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 600.0 0.00 0.00 600.0 452.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 700.0 0.00 0.00 700.0 552.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 800.0 0.00 0.00 800.0 652.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 900.0 0.00 0.00 900.0 752.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 1,000.0 0.00 0.00 1,000.0 852.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 1,100.0 0.00 0.00 1,100.0 952.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 1,200.0 0.00 0.00 1,200.0 1,052.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 1,275.9 0.00 0.00 1,275.9 1,128.0 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 Permafrost 1,300.0 0.00 0.00 1,300.0 1,152.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 1,400.0 0.00 0.00 1,400.0 1,252.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 1,500.0 0.00 0.00 1,500.0 1,352.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 1,600.0 0.00 0.00 1,600.0 1,452.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 1,700.0 0.00 0.00 1,700.0 1,552.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 1,800.0 0.00 0.00 1,800.0 1,652.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 1,900.0 0.00 0.00 1,900.0 1,752.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 2,000.0 0.00 0.00 2,000.0 1,852.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 2,028.0 0.00 0.00 2,028.0 1,880.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 2,100.0 0.00 0.00 2,100.0 1,952.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 2,200.0 0.00 0.00 2,200.0 2,052.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 2,300.0 0.00 0.00 2,300.0 2,152.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 2,400.0 0.00 0.00 2,400.0 2,252.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 2,500.0 0.00 0.00 2,500.0 2,352.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 2,600.0 0.00 0.00 2,600.0 2,452.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 2,687.9 0.00 0.00 2,687.9 2,540.0 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 10 314" 2,700.0 0.00 0.00 2,700.0 2,552.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 2,800.0 0.00 0.00 2,800.0 2,652.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 2,900.0 0.00 0.00 2,900.0 2,752.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 2,912.9 0.00 0.00 2,912.9 2,765.0 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 C80 2,977.9 0.00 0.00 2,977.9 2,830.0 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 Campanian Sand 3,000.0 0.00 0.00 3,000.0 2,852.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 3,100.0 0.00 0.00 3,100.0 2,952.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 3,200.0 0.00 0.00 3,200.0 3,052.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 3,300.0 0.00 0.00 3,300.0 3,152.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 3,400.0 0.00 0.00 3,400.0 3,252.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 12/2/2011 10:08:41 AM Page 3 COMPASS 2003.16 Build 69 ORIGINAL I Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:Shark Tooth#1 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Sharktooth Staked @ 147.9ft(D141(28+119.9)) Project: Kuparuk River Unit MD Reference: Sharktooth Staked @ 147.9ft(D141(28+119.9)) Site: Non-Pad North Reference: True Well: Plan:Shark Tooth#1 Survey Calculation Method: Minimum Curvature Wellbore: Shark Tooth#1 Design: Shark Tooth#1(wp03) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (m) (m) 3,352.10 3,500.0 0.00 0.00 3,500.0 3,352.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 3,600.0 0.00 0.00 3,600.0 3,452.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 3,700.0 0.00 0.00 3,700.0 3,552.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 3,800.0 0.00 0.00 3,800.0 3,652.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 3,900.0 0.00 0.00 3,900.0 3,752.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 4,000.0 0.00 0.00 4,000.0 3,852.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 4,022.9 0.00 0.00 4,022.9 3,875.0 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 C50 4,100.0 0.00 0.00 4,100.0 3,952.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 4,200.0 0.00 0.00 4,200.0 4,052.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 4,300.0 0.00 0.00 4,300.0 4,152.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 4,400.0 0.00 0.00 4,400.0 4,252.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 4,422.9 0.00 0.00 4,422.9 4,275.0 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 C40 4,500.0 0.00 0.00 4,500.0 4,352.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 4,600.0 0.00 0.00 4,600.0 4,452.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 4,622.9 0.00 0.00 4,622.9 4,475.0 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 C37 4,700.0 0.00 0.00 4,700.0 4,552.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 4,800.0 0.00 0.00 4,800.0 4,652.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 4,900.0 0.00 0.00 4,900.0 4,752.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 4,998.0 0.00 0.00 4,998.0 4,850.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 5,000.0 0.00 0.00 5,000.0 4,852.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 5,100.0 0.00 0.00 5,100.0 4,952.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 5,200.0 0.00 0.00 5,200.0 5,052.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 5,300.0 0.00 0.00 5,300.0 5,152.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 5,400.0 0.00 0.00 5,400.0 5,252.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 5,500.0 0.00 0.00 5,500.0 5,352.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 5,557.9 0.00 0.00 5,557.9 5,410.0 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 Top Bermuda 5,600.0 0.00 0.00 5,600.0 5,452.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 5,697.9 0.00 0.00 5,697.9 5,550.0 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 C-35 5,700.0 0.00 0.00 5,700.0 5,552.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 5,800.0 0.00 0.00 5,800.0 5,652.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 5,874.9 0.00 0.00 5,874.9 5,727.0 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 HRZ(K-2 Marker) 5,900.0 0.00 0.00 5,900.0 5,752.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 6,000.0 0.00 0.00 6,000.0 5,852.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 6,100.0 0.00 0.00 6,100.0 5,952.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 6,111.9 0.00 0.00 6,111.9 5,964.0 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 Upper Kalubik 6,200.0 0.00 0.00 6,200.0 6,052.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 6,201.9 0.00 0.00 6,201.9 6,054.0 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 Lower Kalubik 12/2/2011 10:06:41 AM Page 4 COMPASS 2003.16 Build 69 ORIGINAL • Halliburton -Sperry H A L L I B U R TO N Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:Shark Tooth#1 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Sharktooth Staked @ 147.9ft(D141(28+119.9)) Project: Kuparuk River Unit MD Reference: Sharktooth Staked @ 147.9ft(D141(28+119.9)) Site: Non-Pad North Reference: True Well: Plan:Shark Tooth#1 Survey Calculation Method: Minimum Curvature Wellbore: Shark Tooth#1 Design: Shark Tooth#1(wp03) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) C) (ft) ft (ft) (ft) (m) (m) 6,095.01 6,242.9 0.00 0.00 6,242.9 6,095.0 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 7 5/8" 6,277.9 0.00 0.00 6,277.9 6,130.0 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 Top Kuparuk-Shark Tooth#1 A4 6,300.0 0.00 0.00 6,300.0 6,152.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 6,388.0 0.00 0.00 6,388.0 6,240.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 6,400.0 0.00 0.00 6,400.0 6,252.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 6,435.9 0.00 0.00 6,435.9 6,288.0 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 Base Kuparuk 6,500.0 0.00 0.00 6,500.0 6,352.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 6,600.0 0.00 0.00 6,600.0 6,452.1 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 6,685.9 0.00 0.00 6,685.9 6,538.0 0.0 0.0 1,806,164.29 494,258.38 0.00 0.00 6 3/4" Targets Target Name -hIt/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (") (') (ft) (ft) (ft) (m) (m) Shark Tooth#1 A4 0.00 6,277.9 0.1 -0.4 1,806,164.29 494,258.27 -plan hits target center -Circle(radius 150.0) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 2,687.9 2,687.9 10 3/4" 10.750 13.500 6,242.9 6,242.9 7 5/8" 7.625 9.875 6,685.9 6,685.9 6 3/4" 6.750 6.750 12/2/2011 10:08:41AM Page 5 COMPASS 2003.16 Build 69 0 II RI GIN -,L • Halliburton -Sperry I-IALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:Shark Tooth#1 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Sharktooth Staked @ 147.9ft(D141(28+119.9)) Project: Kuparuk River Unit MD Reference: Sharktooth Staked @ 147.9ft(D141(28+119.9)) Site: Non-Pad North Reference: True Well: Plan:Shark Tooth#1 Survey Calculation Method: Minimum Curvature Wellbore: Shark Tooth#1 Design: Shark Tooth#1(wp03) Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Llthology (1 n 6,435.9 6,435.9 Base Kuparuk 0.00 4,022.9 4,022.9 C50 0.00 5,557.9 5,557.9 Top Bermuda 0.00 5,697.9 5,697.9 C-35 0.00 6,111.9 6,111.9 Upper Kalubik 0.00 4,422.9 4,422.9 C40 0.00 2,977.9 2,977.9 Campanian Sand 0.00 2,912.9 2,912.9 C80 0.00 4,622.9 4,622.9 C37 0.00 1,275.9 1,275.9 Permafrost 0.00 6,277.9 6,277.9 Top Kuparuk 0.00 6,201.9 6,201.9 Lower Kalubik 0.00 5,874.9 5,874.9 HRZ(K-2 Marker) 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 28.0 28.0 0.0 0.0 SHL 1793'FNL,1026'FEL-Sec20-T10N-R08E 12/2/2011 10:08:41AM Page 6 COMPASS 2003.16 Build 69 ORIGINAL Page 1 of 2 Reimer, David J From: Taylor, Cary L(Halliburton) Sent: Thursday, December 08,2011 2:46 PM To: Reimer, David J; Engel,Joseph (Swift Technical Services LLC) Subject: AC Scan for Shark Tooth#1 Dave/Joe, I applied a global scan against all the wells in the Definitive Database as shown by the attached screen capture. No wells fell within the scan radius so I am unable to generate the normal Anti-Collision Summary report for this well. 4 a�f at E 3ii e . '` L. 12/8/2011 Page 2 of 2 Offset Design Selection _1DI si -Offset Designs - OK IFiltering r Kuparuk 2W Pad Cancel i Kuparuk 2X Pad $ r k Kuparuk 2Z Pad i Include all sites within 15,0 mi Help rk Kuparuk 3A Pad ii r Sites with the same project name r" ` Kuparuk 3B Pad ❑+.r k Kuparuk 3C Pad r Include prototype designs ❑+ r k Kuparuk 3F Pad Wo Includelanned p (principal)designs ❑ ('-'�' Kuparuk 3G Pad ❑+ Kuparuk 31-I Pad f Include designs with no program Save r �{ p1� selection to $ r k Kuparuk 3I Pad database $ r k Kuparuk 33 Pad r k Kuparuk 3K Pad $ r Kuparuk 3M Pad $ r Kuparuk 3N Pad rFilter by Type r- Kuparuk 30 Pad Definitive Plan r k Kuparuk 30 Pad Definitive Survey Graft profile ❑+ r 1 Kuparuk 3R Pad Horizontal Dep r Kuparuk 3S Pad $ r k Kuparuk 3W Pad G Filter by Range ❑+ r k Kuparuk Oliktok Range: I 200.00 ft r Kuparuk River Unit Non Pad $ r f Kuparuk Tarn +XJ1000; ! 100.000 r k Kuparuk UGNU Filter All I I ❑+ r 1 Kuparuk W.Sak i-r k NEWS ICEPAD p r Non-Pad G{`.51 CPF-1A b.f.'i E KUPARUK 1 3.fA KALUBIK CREEK 1 C•.o'c 7l Eilte ;Arr'(]ED.i p+ {" KRU 21-10-8 $.r- KRU STATE 1 111- t KRU STATE 2 - ❑+-{ KUP UNIT 1 O{" KUP UNIT 1A 1±1-.1 Plan:Shark Tooth#1 — Select All I Selected p Shark Tooth#1 't Shark Tooth#1(wp03) J -Additional Surveys --- Name Tod From Toj Lock Cary Taylor Technical Professional- Well Design, Sr. Halliburton Energy Services 700 G. Street—ATO 1529C Anchorage, AK 99501 PH:907-265-6024 Cell:907-748-3920 Fax:918-662-6095 ORIGINAL 12/8/2011 Shark Tooth #1 Drilling Hazards Summary 13-1/2" Hole/ 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Shallow Gas Pressure Anomalies High f' Shallow hazard study has identified possible shallow gas V anomalies at 715', 1404'TVDSS&2394' TVDSS. ✓ Control drill,increase mud weight as needed. Mudloggers will be logging interval. ✓ Gravel/Sand Sloughing/Clay Moderate Increase mud weight/viscosity,High viscosity sweeps. Sections Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill(use of Trips trip sheets),Pumping out of hole as needed. Washouts/Hole Sloughing Low Cool mud temperatures,minimize circulating times when possible Lost Circulation Low Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology,use LCM 9-7/8" Hole/7-5/8" Casing Interval Event Risk Level Mitigation Strategy Shale stability Moderate Control with higher MW and proper drilling practices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling to casing point. Pump and rotate out on trips as a last resort. Lost Circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates,Mud rheology,LCM. Use GKA LC decision tree. Hole cleaning Low Use PWD and TAD to monitor hole cleaning.Control the ROP and use the best hole cleaning practice. 6-3/4" Hole Event Risk Level Mitigation Strategy High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Pressure Kuparuk C Moderate Setting 7-5/8"casing above zone. Follow mud weight sand schedule and do not fall behind. Stripping Drills, Shut-in Drills,PWD Tools,Increase mud weight as needed. ✓ Ensure adequate kick tolerance prior to drilling pay interval. Abnormal pressure in zone of Low Use PWD to monitor hole. Follow mud weight schedule interest as needed. Per shallow hazard study and offset well data, anticipate normal pressure Differential sticking with core Low Follow mud weight schedule. Keep drill string moving barrel Lost Circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates,Mud rheology,LCM. Use GKA LC decision tree. Att03 Shark Tooth#1 Hazards.doc k� Prepared by Dave Reimer $ t Page 1 of 1 Shark Tooth #1 Schlumberger CemCADE Preliminary Job Design 10-3/4" Surface Casin• (V3) Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Doyon 141 Volume Calculations and Cement Systems Location: Exploration Volumes are based on 225% excess in the permafrost and 50% excess below the Client: CPAI Revision Date: 12/01/2011 permafrost. The top of the tail slurry is designed to be at 2140' MD. Prepared by: Mike Martin Location:Anchorage,AK Lead Slurry Minimum pump time: -235 min. (pump time plus 120 min.) Phone: (907)263-4207 Arctic LiteCRETE @ 10.85 ppg-1.97 ft3/sk, 6.61 gal/sk water Mobile: (907)748-6900 email:martin13©slb.com 0.6381 ft3/ft x (80')x 1.00 (no excess) = 51 ft3 0.3638 ft3/ft x(1400'-80')x 3.25(225% excess)= 1561 ft3 < TOC at Surface 0.3638 ft3/ft x(2140'-1400)x 1.50 (50% excess)= 404 ft3 51 ft3+ 1561 ft3+404 ft3= 2016 ft3 2016 ft3/1.97 3 = ✓ 1024 sks Round up t(1030 skk Have ASI on location for Top Out stage,if necessary. Previous Csg. Tail Slurry Minimum pump time: -175 min. (pump time plus120 min.) < 16",62.6#casing 12.0 ppg DeepCRETE +additives- 1.62 ft3/sk, 5.4 gal/sk water at 80'MD 0.3637 ft3/ft x(2688'-2140')x 1.50 (50% excess) = 298 ft3 0.53997 ft3/ft x 80' (Shoe Joint) = 43 ft3 298 ft3+43 ft3= 341 ft3 341 n 1 211 sks Round upp to16-`2 O s_sks BHST= 75°F, Estimated BHCT =65 °F. < Base of Permafrost at (BHST calculated using a gradient of 2.1°F/100 ft below permafrost) 1,400 MD(1,400'TVD) PUMP SCHEDULE Stage Cumulative Stage Pump Rate Volume Stage Time Time (bpm) (bbl) (min) (min) CW100 5.0 50.0 10.0 10.0 MUDPUSH II 5.0 50.0 10.0 20.0 < Top of Tail at Drop bottom plug 0.0 0.0 5.0 25.0 2,140'MD Arctic LiteCRETE 6.0 358.9 59.8 84.8 DeepCRETE 5.0 60.9 12.2 97.0 Drop top plug 0.0 0.0 5.0 102.0 Water 5.0 10.0 2.0 104.0 Switch to rig 0.0 0.0 3.0 107.0 Mud 8.0 234.8 29.4 136.4 Slow&bump plug 3.0 6.0 2.0 138.4 < 10-3/4",45.5#casing in 13-1/2"OH MUD REMOVAL Expected Mud Properties:9.6 ppg, Pv<25, Ty< 35 TD at 2,688'MD (2,688'TVD) Spacer Properties: 10.5 ppg MudPUSH* II, Pv 20-25, Ty 30-35 Centralizers: As per CPAi program. •Mark of Schlumberger ORIGINAL ___ Shark Tooth #1 Schlumberger CemCADE Preliminary Job Design 7-5/8" Intermediate V3 Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Doyon 141 Location: Exploration Client: CPAI Revision Date: 12/01/2011 Volume Calculations and Cement Systems Prepared by: Mike Martin Volumes are based on 50% excess. The topof the tail slurryis designed to be Location:Anchorage,AK g Phone: (907)263-4207 -4,600' MD. Mobile: (907)748-6900 email: martin13@slb.com Tail Slurry Minimum pump time: -185 min. (pump time plus 120 min.) 15.8 ppg Class G +0.2%D46+0.3%D65+ 0.4%D167+ D177 as needed- 1.16 ft3/sk, 5.09 gal/sk water 0.2148 ft3/ft x(6,243'-4,600')x 1.50 (50%excess) = 530 ft3 0.2578 ft3/ft x 80' (Shoe Joint)= 21ft3 530ft3+ 21 ft3= 551 ft3 Previous Csg. 551 ft3/1.16 ft3/sk= '- 475 sks < 10-3/4",45.5.#casing Round up to 480 at 2,688'MD BHST = 150 °F, Estimated BHCT = 116 °F. (BHST calculated using a gradient of-2.1 °F/100 ft. below the permafrost) PUMP SCHEDULE Stage Cumulative Stage Pump Rate Volume Stage Time Time (bpm) (bbl) (min) (min) CW100 5.0 40.0 8.0 8.0 Drop bottom plug 0.0 0.0 5.0 13.0 MUDPUSH II 5.0 40.0 8.0 21.0 Tail Slurry 6.0 97.9 16.3 37.3 V Drop top plug 0.0 0.0 5.0 42.3 Water 5.0 10.0 2.0 44.3 Switch to rig pumps 0.0 0.0 3.0 47.3 < Top of Cement at Mud 8.0 267.0 33.4 80.7 4,600'MD / Slow&bump plug 3.0 6.0 2.0 82.7 MUD REMOVAL < 7-5/8",29.7#casing Expected Mud Properties ppg, Pv< 25, TY< 15. in 9-7/8"OH 1./Spacer Properties: 11.5 ppg MudPUSH* II, Pv=20-25, Ty= 35-40 TD at 6,243'MD Centralizers: As per COP program (6,243 TVD) 4 Mark of Schlumberger ORIGINAL Well : Shark Tooth#1 Schlumberger Field : Exploration CemCAD E plug cementing recommendation for P&A Operator : ConocoPhillips Alaska,Inc. Prepared for : Dave Reimer Prepared by : Mike Martin Date Prepared : December 01,2011 Phone : 907-748-6900 E-Mail : martin13©slb.com Plug Configuration Target K.O.P.: 6055.0 ft ft SPACER MUDPUSH II - Density: 11.50 lb/gal • Volume: 16.9 bbl Length(without Drill Pipe): 176.2 ft u-, • Length(with Drill pipe): 182.5 ft • • - • SLURRY Plug Slurry - • Density: 15.80 lb/gal ti • Volume: 42.0 bbl Length(without Drill Pipe): 631.0 ft 10, Length(with Drill pipe): 641.4 ft Wet Phase Content a Fresh water Base Fluid 5.091 gal/sk �n cy `n - Dry Phase Content Blend: G Yield: 1.16 ft3/sk 0 _ cn- Fluid Sequence Load -210 sacks Class G +0.35% D167o+0.3% 0.2%D65 + D153 + 0.01 gps D177 + 0.2/o D46 Fluids Placement Name Volume(bbl) Rate(bbl/min) Working Time: -3:30 hh:mm MUDPUSH II 15.0 5.0 Plug Slurry 42.0 5.0 MUDPUSH II 1.9 5.0 Mud 57.6 5.0 Mud 4.0 2.0 Drill Pipe MD OD Weight (ft) (in) (Ib/ft) 5966.0 4 14.0 6686.0 31/2 9.3 Other Total pumping time: 00:25 hr:mn Displacement volume: 61.6 bbl Mark of Schlumberger ORIGINAL Shark Tooth #1 Shallow Hazard and Pore Pressure Conclusions November 23, 2011 Executive Summary ConocoPhillips Alaska Inc. (COP) intends to drill stratigraphic well Shark Tooth #1 in January 2012. As part of the well planning process, COP contracted with Fusion Petroleum Technologies Inc. (Fusion) of Houston, Texas to perform geopressure prediction on 21.5 mit of 3D seismic data from the Tarn/Meltwater 3D seismic survey and evaluate the down-hole pore pressure regime at the Shark Tooth location (Figure 1). The pressure interpretation was based on local well control and seismic interval velocities. The results of the shallow hazards and pore pressure analysis indicated that the proposed well location contains no significant hazards that would require any change in the proposed location. Further, the project helped to identify three zones along the well path which should be monitored during the drilling process for increased pressure or gas influx into the wellbore. 150°15'W 150°W ii I a 4. • • • • •• • • •• • •. • Alaska • • • • • • • • • • • • • • • • • • 2008 Tarn-Meltwater 311 t;u . v •-- • • • • 2L-03s • • • < • • ••KRU 21-10-8 N TARN 2 Shark Tooth#1 z N G e t` O ti TARNr- 1 •Bermuda 1 WSAK 13 r nA • Area of Interest for Hazard Survey 1:100,000 (21.5sgmi) N S Miles I 150°15'W 150°W Figure 1: Location map of Shark Tooth area and area of interest for hazard study Project Description Fusion utilized REVELTM, a proprietary software product, for residual velocity analysis to refine the input gathers and velocity field, provided by ConocoPhillips, for pressure prediction. Continuous velocity dal:a Att05_Shark Tooth#1 Shallow Hazard doc ORIGINALPrepared by"Kent Smith&Dave Re mer at every CDP location were generated, and used to calibrate for pressure using the control well locations. Pressures were then predicted in 3D across the prospective area using the GEOPRESSTM tool, another Fusion proprietary software product. Attributes were generated for pore pressure (PP), pore pressure gradient (PPG), overburden pressure (OB), overburden gradient (OBG), fracture pressure (FP), fracture pressure gradient (FPG) and effective stress (ES) along the wellbore. Shallow hazards interpretation was also performed around the proposed well location in the seismic volume, and detailed hazard maps for a series of shallow features were generated. Control wells for this project included 2L-03, Tarn-2, Bermuda-1, and KRU 21-10-8. Figure 2 shows the area of interest with the wells and lines of section for seismic panels in this report. 800 1600800 165800 161 800 1615816208008 1625800 A 2702 , N 2720 5500- 2L-03 C 5935t00 J 2022 0500_ 5930,00 KRU 21-10-8 A' I L 2502 Sharktoo P. 5400_ - - __ _ __ �I:: 5 00 m2 0500- 5920.00 2400 , -_. _ - __ .. __.... 2402 rmuda 5500 591E 0) 2±,20 }—. 2:3)2 000_ - y _- i _- 5910 0) 1E9E800 8600800 1615800 161(1100 151583 1620800= 1625800 Figure 2: Area of interest for hazard study showing wells used for calibration and 21.5 mit seismic volume. Red lines are lines of section for figures 4 and 5. Note the arbitrary line A-A' is not used in this report. Conclusions The fluid and fracture pressure models derived from the control wells were applied to the interval velocity volume and used to generate fluid and fracture pressure models for the Shark Tooth proposed location'. 3-D data volumes of fluid pressure, effective stress, fracture pressure, overburden and their gradients were prepared. Figure 3 presents the predicted down-hole pressures in the Shark Tooth well. Att05Shark Tooth#1 Shallow Hazard doc Prepared by"Kent Smith&Dave Reimer Pressure Gradient Data(ppg) 8.00 10.00 12.00 14.00 16.00 18.00 20.00 0 IT , , , , „ „ , , . . . . . . 2000 • ✓ ■ • ., ` \ ■ .c 4000 a ■ aJ � ■ ■ ■ ■ • • 6000 I ��'l r`�' • \\\1 i 8000 Figure 3: Final well plan for the Shark Tooth location for the Kuparuk target interval. The curves include the predicted pore pressure (blue), proposed mud weight(green)for drilling, and error bars (red and blue dashed curves). The red lines are the suggested casing runs and the black lines show the suggested casing points with error margin for leak off tests. Pressure is in pounds per gallon. Shallow hazards analysis of the study area revealed 12 zones of interest for possible pressure anomalies; however, upon detailed analysis, the risk for shallow gas influx was confined to 3 specific zones at the proposed location. The final well prognosis for the Shark tooth is shown on the ThinMAN r"" pseudo-impedance sections for in-line 2502 (Figure 4) and cross line 6092 (Figure 5). Both displays have the depths to each of the three zones noted with depths relative to sea level as determined from the REVELTM time-depth conversion. Inspection of these two displays shows that Zone 1 gas anoma y will be encountered just below the base of permafrost at 715 feet below sea level. Zone 5 gas anomaly will be encountered at 1404 feet below sea level, and Zone 10 gas anomaly will be encountered at 2394 feet below sea level. ORIGIN Al- Att05_Shark Tooth#1 Shallow Hazard doc Prepared by"Kent Smith&Dave Re mer r SnNmMiPDL r __-- G4,"c' lj • 1- -i Irb�e 25020 2W20 2W20 2W20 25020 :`0:0 :'sA0 ns6e 59600 59500 60000 f0500 6'NO 61500 f:0 f WI �JJJJJ9fb, _ lir* i r q `...yam` r OW ` r �.4 • ,.> 7,A *t I.4���♦.1 a ', t t, . s11jt�,1 ��. ,fl ♦• Jti• eA a.V��yts i�1 ,' .;' ib i 'y'-';tt. 1, 'e. ,..1 ' SS Nitz. ,I:o--gich 4i,*1 �"".' 4 '� ,psi.•;....... f�!i!t/1r�!!� ~, • _ �:!,< ,. -��� `_�-...�`�rw� •r �� ���a' .li " ����isomer- ,*. -4 >„ x'14' c N'A ♦, • 715- It(MSL) 43 900 11.44 "II'i� _,47,14,'-'-'11M11,111 ..4.1.414-774/14.•• . ..<,a =may +, r 144 . I 7, - vii 1,- • ----1;------ � a, 1 Ste! f ` l 3L..11 I 41 T�a'`�, 1� �-'�� 7y 'c c if �,;,*, a. K - / r lair x 11� ut°04tt ,-r,...--,1� '��,r -,���r. ' Fu \!' !_" ; ����.,�<dTI� �yyy I j�y 308000 4"� 1. '.\ 7 -a. /-,M� 'STV+ ^'ft� • ii^'1.. ...lir; t 33)000 ii Ial; 4. �Z ....../.14C11111 -4,1111"...-. '114."1 d.`. J, .1ti 1� i i14Ar,r a ... 1� :t ccc a S} r • .+< >to,Oakt '+` 0 kr-, e 'c`3�� 'Cay ..`�1 ` ;�- �'I ,a y .-4,0,A,., > !R �'- KA'a rf3 * •r*W4i4 .54 0�� �� .�1 -r♦,+ca::y its..,..+114I1. asi `^`' '-1:17.447:14 ,151 14.1 f`?`4 ,1 14114,1 �' t1�` .,s10' "+ ,. 1 rlr -. '�, .. mss ' 4 '1 lP�„ ,� ��..L �� ,T� )+� :irv...../ar'3�1 7TH -... �� j�J-- ' z , - ---4..7. ,,,. �' ,f'.."4140; ,1� �,, ♦ '. ~a'�� �lJ�40" •o I ��� �� - 2394 ft(MSL) i' -i i ( l irOnfillaf \ ii 3 . 1 r1t=il1J�}:hNrq•,.r;a4;At tm�7 t %-�1.e0.p.,... w lf,zr,,,zsexr.,i.._%„vq r s_� iiii, Figure 4: ThinMANT"' impedance section for in-line 2502 through the Shark Tooth #1 well showing the 3 important horizons mapped in the hazards analysis with depth (MSL)to the horizon shown in feet. a ^...- ‘;' c.' • is =1 It a5-0 :L00 25500 26030 26500 E+fi:0 GP_0 6[920 W920 60920 1�„ I , e ,q:. Apr♦ �R [t11 1 ' x(11 f r',';i- .1<0 CO. M<� ter. `� 1'C�y fj�r�I '4� r (s t :f: i t'',4-Q. );•+ 1�� ,P S ii 14k•' 369 COO s } - '�" l ay 1....:1 c, J.'�. §-. �`i 1�`r`'• 3155E00 "i4 Gam „ ,.e..,, F a`. .a1 ', '.`� 1`9 I , ts<�2ioa 1. ft`.v..n� T t a. A 260 otc '.�1'. 44' g�.�a`4,f314 . 1 ..+y�i �. 4°�Z�`".,,,• /' ' -'mac ;:�. -1lsf zM:.oc0 „� . rd�Y'�: 4.411;4111-111‘11.4.414!'m 'K<z - �a--t.< -..144044.4.040 153 toe 99 on - • 1(, 9/0,1}"1-'f�o 715 fttfJl - - • / ivwc � - -� -� - ,;� • --_ _.'1G tom, .....47.•2�.a• 7•,.` ,ane 72 DOC ta No 63 000 i'llle4i4t -,of 90 00o 000 --7.7.--- eP, W Li �,r+ .. 1tii 1;1o*AI '° � 1�.� „r ..‘4 4144.4;iCi'tet . « .199 OW ♦L _ �t' . 21�� `l'IN ''`....:Ay-14.-,0!'Al)) ! i, 'ti °- N :tib �r . 1F7iy .252 NO ttt :G� cti . 2i * � i coonit .a. ,� 1¢1_ „ _ .-*�p'iv 000 ,.,........4,‘„,„„...,..... I , .„ -4 ' ,-,--• , , ___ ,e.:%N','-'"ott7s.....)„,.. . .__..go— _ � '' t ''''''K''', '""-"------. ''t"--7-7—=----k=- \ ..- FA '� +/6^a 1 s *_ ic-,✓ -mss`!. ' ` -r II; a� +t '' ---44/1 zr, -1-4, r '\4.::=�� '19+.4 N• it.,,,,,-----,----- , -1''" -� 1� '11Ats,y1' 1 11 *i�� ;1 e 7t1t * ?'): S l �1 t1l ��t4�� .61 il4III' [14 { �.• '--- 0417-*c. ,'464: r q. -��?? .�f3�*z;� �,, ,.,� �� 0J2,.t ...,►3. 0 d0?1. 1, * . 1 fI Yl .rrl .�_� -- L4 ..� I Figure 5: ThinMANTM impedance section for IL 2502 through the well showing the 3 horizons of interest mapped in the hazards analysis with depth (MSL)to the horizon shown in feet. R ' ,vrrue anarK r oorn et r anauow nazared �J Prepared by"Kent Smith&Dave Reimer In summary, Fusion has identified several key zones in the Shark Tooth #1 well which should be carefully monitored for gas influx while drilling. These three zones are at 715-feet, 1404-feet and 2394- feet. Fusion has also made suggested picks for casing points and mud weights to yield a safe drilling program. ConocoPhillips will take these observations and recommendations into account when planning its final casing and mud programs for the Shark Tooth #1 well. "' Att05 Shark Tooth#1 Shallow Hazard.doc ° t Prepared by"Kent Smith&Dave Reimer Davies, Stephen F (DOA) From: Reimer, David J [David.J.Reimer@conocophillips.com] Sent: Wednesday, December 21, 2011 11:25 AM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: Sharktooth 1: Request for Offset Well Mudlog Attachments: 2011 Mudlogging Procedures Shark Tooth#1.doc; Shark Tooth Data; Shark Tooth#1 Logging program.ppt Steve: Attached is the mud logging procedure for Shark Tooth. I do not have a "formal"well logging procedure document, however I have attached an email that outlines the well logging program and a schematic that outlines well logging by hole size. Let me know if this will suffice. thanks Dave From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, December 21, 2011 10:41 AM To: Reimer, David J Cc: Schwartz, Guy L(DOA) Subject: [EXTERNAL]FW: Sharktooth 1: Request for Offset Well Mudlog Dave, Unless I've overlooked it, I also didn't see a well logging and mud logging program among the supporting documentation for the Sharktooth No. 1 Permit to Drill Application. Could you please provide this? Thanks, Steve Davies AOGCC From: Davies, Stephen F (DOA) Sent: Wednesday, December 21, 2011 10:31 AM To: 'Reimer, David J' Cc: Schwartz, Guy L(DOA) Subject: Sharktooth 1: Request for Offset Well Mudlog Dave, I'm one of the AOGCC senior staff charged with reviewing ConocoPhillip's Permit to Drill Application for the Sharktooth No. 1 exploratory well. As part of my review, I always examine records from offset wells. The nearset well to Sharktooth No. 1 is ARCO's KRU 21-10-8 exploratory well,which is located about one mile to the east. The AOGCC does not have a copy of the mud log from KRU 21-10-8. Attached is a 1990 letter sent from AOGCC to ARCO requesting that ARCO submit printed and reproducible copies of the mud log to the AOGCC along with a set of cuttings samples from the well . Our well records contain no evidence that a this request was ever fulfilled. The attached copy of the Permit to Drill for KRU 21-10-8 clearly requires both samples and a mud log as conditions of approval for the Permit(see the lowest portion of the form). 1 Could you please check on this for me? I would appreciate receiving a copy of the mud log so that I can complete my review of Sharktooth No. 1. Thanks for your help, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 Steve's phone: 907-793-1224 AOGCC's receptionist: 907-793-1223 AOGCC's fax: 907-276-7542 AOGCC's website: http://doa.alaska.gov/ogc 2 Q% N Q o m _o 0 s 0 E '5" f- \' p C w O (i) O O U N cO O+ t ( NN U0 co O C U > O ca La) c Cl) . O O \ U • O I— CD U O(Ni co CO O 0) L O Ca 2 CO 1 r = It 0 O 0) Z Z_ 0 ,.0 U N - C U O 'E cm O • o 0 0 0° a)Et a) a) _ oQ i 0 � 0f �a� .2 0CA .� 0XrY CU � ' � 0 50 - s J J > CO ` ' _ L -- - 1 N N C a O i N • ' N CU 1 CD ° c?E 1 Q M -/ 2 ) Q _ i COJ 0 O '� Shark Tooth Mudlogging Procedures (2011) The information detailed below should be adhered to unless otherwise stated by the operations or well site geologist. The roles and responsibilities of the mudlogging crew are not limited to the procedures and instructions listed below. PRE-SPUD MEETINGS Prior to drilling, ConocoPhillips Geology will arrange a meeting with a mudlogging representative, at the Anchorage Office, to discuss geological aspects of the well and to go through procedures and requirements. The Pre-Spud Drilling Meeting held at ConocoPhillips in Anchorage should be attended by the Senior Mudlogger and/or the Operations Manager. It is the responsibility of the Senior Mudlogger to set up a meeting at the wellsite to discuss procedural reporting requirements with the Drilling Supervisor and Tool Pusher. WELL SITE General Information: Y/ The Mudlogging Service will be in operation from base of the conductor to TD. A phone is requested in the mudlogging unit. Personnel and Equipment: Epoch must furnish all equipment and personnel necessary to provide a full mudlogging service including but not limited to: 1. High quality microscope and made for purpose microscope light and backup equipment for both. 2. Sample examination tools and references, including several grainsize charts to allow logger to discriminate between lower and upper fine and very fine grained sands. 3. Sample bags and boxes for all wet and dry samples. 4. Equipment and chemicals in working order necessary to examine cuttings for shows. 5. Computers,writable CDs, diskettes and printers 6. All other equipment associated with a mudlogging unit, including gas detection. CUTTINGS SAMPLING PROGRAM: Potential reservoir sandstones are expected to be very fine- to fine-grained. Please ensure that Sample Catchers/Mudloggers work with the Mud Engineer and Wellsite Geologist to ensure the appropriate shaker screens and sample cleaning sieves/meshes are employed for both sample collection and operational considerations. See Appendix 1 for sampling guidelines. All samples(except unwashed samples)will be sent to the ConocoPhillips Bayview warehouse for distribution. 1 Unwashed Samples—1 Set: To be collected in plastic Whirlpak' bags. 50 ft intervals from base of permafrost to Reservoir Zone 10 ft intervals throughout the Reservoir Zone In the shallow hole, make the best efforts to collect 50'samples, if that is not possible go to 100'sample intervals due to fast penetration rate and place empty sample bags for any intervals missed in the box. Unwashed samples should be shipped to: Halliburton Energy Services 6900 Arctic Boulevard Anchorage,AK 99518 Attn: Robert Haverfield Washed and Dried Samples—3 Sets: To be collected in paper envelopes. 50 ft intervals from base of permafrost to Reservoir Zone 10 ft intervals throughout Reservoir Zone Two sets for ConocoPhillips One set for the State In the shallow hole, make the best efforts to collect 50'samples, if that is not possible go to 100'sample intervals due to fast penetration rate and place empty sample bags for any intervals missed in the box. Onsite Samples—1 Set: One set washed immediately for wellsite analysis. These wet samples should be retained in `samplex'trays for onsite review and must be saved for the well site geologist. Samples while Conventional Coring: The Shark Tooth well will take 2 sixty-foot conventional cores with a tracer in the mud system. Mud samples will need to be collected for this procedure. Also see the coring procedures. From the suction pit—collect 2 samples(-250 ml)at the beginning and end of coring From the return line(before the shakers)—collect 1 250 ml sample at the beginning of coring and then a sample after every 15 feet of core. GAS SAMPLING PROGRAM: Background Gas Samples—1 Set: Background gas sampling is to be collected in Isotubes. Alternatively, `Calibond' gas bag with valve may be used for gackground gas sampling. 500 ft intervals from Base Permafrost to 100 ft above Top Reservoir, and/or at every significant gas peak containing C2 or heavier alkanes>5 to 10 times greater gas concentrations than background. 2 Reservoir Zone IsoTube Gas Samples—1 Set: To be collected in IsoTube aluminium vessels with valve Beginning 100 ft above expected Top Reservoir zone and continuing throughout the reservoir section as directed by wellsite geologist or operations in Anchorage: 30 ft intervals and/or at every significant gas peak C2 or heavier containing>5 to 10 times greater gas concentrations than background. The gas bag and isotube samples will be sent direct to: Isotech Laboratories, Inc. CPAI samples, contact: Albert Holba 1308 Parkland Court Champaign, IL 61821 Special provision has to be made for shipping the gas bags as they are classified as hazardous materials(see Appendix 1). Daily Reporting: Mudlogs: A standard Formation Log should be placed in the designated\S: drive folder every morning by 6 AM. The mud log format should include ROP,WOB, depth, cuttings percentage,total gas, chromatography, and lithology description. These should be 2"/100' measured depth logs of the previous 24 hour period+ 200',to facilitate splicing. Daily Report: A Daily Mudlogging Report should be placed in the designated \S: drive folder by 06:00 each morning. This report should contain at least the following information: 1) Depth at 06:00 2) 24 hr progress 3) One line operational summary 4) Brief listing of lithologies encountered 5) Background gas 6) List of gas peaks with depth and their chromatographic breakdown 7) List all connection gases and other gas events(eg trip gas, swab gas etc)and their chromatographic breakdown 8) List of gas peaks sampled with gas bags with their chromatographic breakdown Through any zones of interest, there may be need for 5":100' logs more than once per day, at these times the CPAI Geologist will communicate these special needs. END OF WELL REPORT Final reports will be sent using Greatr Kuparuk distribution procedure as soon as possible after completion of the well. A brief, but not comprehensive, outline of the end of well report format follows: 3 Mudlogging Contractor Details: Equipment Summary, Crew Details Geologic data: important aspects of the drilling history, lithology summary, gas data, show reporting, and sample collection. Also paper copies of the Formation and Drilling dynamics logs at a 2":100' scale. Final reports: Report requirement are as follows: 3 hardcopy of the final report. 5 copies of a CD ROM with the following information: a. Digital copy of the final report b. PDF file of the Gas Ratio Formation Log c. Digital versions of all the morning reports d. LAS files of all numeric data—format as specified by C.Worley 12/20/2000., Appendix 1: Sampling Guidelines CUTTINGS SAMPLING Mud logging should commence at first returns. Unless otherwise instructed, all sample sets should be collected from first returns at a sample interval specified in the individual well plan. The samples must be collected in such a way that they are representative of all the sampling interval specified in the prognosis. The cuttings catching board or bucket should be cleaned off after each sample has been caught. If a sample is missed due to high ROP's etc the empty bags should be put in the sample boxes to indicate a missed sample. A full range of sieve sizes must be supplied by the mudlogging contractor for use at the wellsite. Mud loggers are responsible for collecting, labelling and dispatching all cuttings samples. A record of all sample shipments from the rig must be kept in the mudlogging unit. The CPAI Geologist may alter sample intervals or distribution instructions if necessary. CUTTINGS SAMPLES COLLECTION& PREPARATION The Mudloggers are responsible for collecting, labelling and dispatching all cuttings samples. UNWASHED SAMPLES: Water Based Mud: When using water based mud Unwashed Samples should be collected in plastic 'Whirlpack' bags. Each bag should contain approximately 500 grams of sample, or as much as possible when sample return is poor. The sample bag must be annotated as follows using a permanent marker pen resistant to water, oil and physical abrasion. Each sample bag must be clearly marked with: 4 (I) ConocoPhillips Alaska Inc(or abbreviated to CPAI) (ii) Well number (iii) Sample Depth (iv) Set Owner Gas Bag and Isotube Samples Background Gas Bag and Gas Isotube samples are to be collected at the specified intervals. Each sample must be clearly marked with: (I) ConocoPhillips Alaska Inc(or abbreviated to CPAI) (ii) Well number (iii) Sample Depth (iv) Set Owner Sample Distribution All Cuttings samples, with the exception of gas samples and unwashed cuttings samples, must be sent to the ConocoPhillips Bayview warehouse who will then distribute the samples. The sample boxes containing the gas samples should be labeled and shipped directly to the laboratory performing the analysis.This information will be provided in the specific sample and data requirements. The boxes containing the gas samples must be labeled as`HAZARDOUS MATERIAL—GAS SAMPLES' and as such are subject to specific regulations, one of which is that they can not travel on passenger planes. Two days before end of well the Mudlogging crew chief should notify the Kuparuk Shipping Agent of their estimated time of arrival to allow them time to open up heated space to handle the samples and to arrange that is to arrange that they are picked up in a heated vehicle. 5 TRANSMITTAL LETTER CHECKLIST WELL NAMECA_b-" L4C)(:)-(k PTD# �( ! Cr S Development Service Exploratory Strati ra hic Test Non-Conventional Well FIELD: eU.i?V L l!l / /0-e 'POOL: / � j - l\�C �l (--(--)z I Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. • - -4 7 L_ Ctscic Rev: 9/09/2011 i V //(z(i —4 4:Se- (-77-C c --/ci / vq. rf -16Q_ tz 21- i/ C Y i N O` c0 to w O) a c Q t� c N N o a) Y -o y 0 cd c iii a) o E c c a _ ? EO o N N o • C 4- U o co N Q • O m COL L'O m-0 co O. 9.O N a c c Q a) O O O) O CO w E C a) O -0a ci 0 o L -o o O Z c O' m aEi 3 E 3 E to m 2 = a o n � m g y m 0_• (/) 3 n w 0N c`O E IL 0 o 9-') O 2 '— °ts in m=t o = n o i0 cn p 0 3O E O c i Y o CO`� am . 2 Cl) _ co ELH p U L C C C 0 a L w, w i 2 as to o N C CL v 3 0 0, m c '3 c, .N n m w _ 6. _ U L o o c n CO (D C -o N -o C '- 7 O Z N N L C N a) = a) C 0 a)'O-p Mo op` .N co co m co 3 a) -> •c 'v` af)) w 3 w o O C C C C a) L U O O ° f0CO O 0 d C 9 cp 0 L� U U 3 c N C co N as O c -p 'O U = 77-1 "O a) Z 0 m ° p a CO E = CO N m m 3 N a cx a) m Q Z a a) m > �� c a) V) o c) 0 U L n •.N `" a s N N E C O N N n CO. 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W >- a 0 0 E NCL = X a N — w Y -o.- O Q Cl) aa') a`)) Cl) Cl) a) a aa)) aa)) Cl) s`n) Cl) s`n) Q Q Q a Q a) O o a`n) a`n) Q a) Cl) Cl) a-') Cl)a)) aa)) ai a) Q o a Cl) Q aa)) a z >- >- >- >- >- >- >- >- >- >- >- >- >- Z Z Z >- z >- Z Z >- >- Z >- >- >- >- >- >- >- >- Z Z >- >- Z T ` v ca _m U N o I To o a) = E 3 — E a) O 0 I5 Cl) N N o Oo _ \j O 3 V) T a ` o n > c 0) C Y o v # p c Tlrf J a)° E 3 0 -23 co V) U i U C 2 0 a N w E a) _O V) O• Q as a) U V (°n) ° a) E °- NI CC N "O To O. N. U _ n (6. OU LOL N x ` Q J C O C �, °- O C 7 .0+ CL O T C 3 01 N co O' "O V) V) a3 Z Q a a p a 2 o O) cc) m m a) �0 0 Y c ° flI1 ° m N 3 0 o 06 E ate) m a c•) O ° `) ` E o o = .c rn � Z N cu 3 3 A. to c rn L c (n 3 Q — u? c Q w a a a) CD Z _ -o o C -O o a) 'C a as a) p. 0 C a) CO 0 0 0) a) a L C C N C p 0 co E E _ c c •E CO o C 0 w ' H L o c- us a) tY C a) t a) o- N 0 a 0)C Yco Q o o `o o o m c o o m U •a 0 a a) o 0 •- a o z '3 0 > V) N T d Q o 0 °O a) a) C C >, O 7 7 a CO Y �. � O o O a) (6 � Q f6 0 N O O) p N C .N 0 J E n U U a) r _o o o a) c — n o E 0 3 o a) L Ti) 3 a) E Y Q' E. m c o w w ii n n a) L L, �, m 'o m N i c o a M m .N r r o a o n 3 0 .c o T 3 c o O tnj o a) ti u, as 3 3 a) o .. .5 ._ 3 m O n a) a n _ m o 3 a) r a) o w U o a' C O c C -0 •"0 > p N .o. "O 'O p c0' '� o .>p N. O O c Q `O N p N N n o. O) c "O. a V) 7 a) CL _ip 'O ca N as d U p a) a) U ,c O O E a) E L o m cn C J ° a) a a) -p `m m o ° c a 5 v a ° °: °> — -° a) 2 E °) o r. CO 0 05-p 2 cn 0 m 2 m o o g m@ a .� us m L .- c T:7) n = aT@ N co ° 2° '- o S a 3 N �o a' v, _ o c L • CL • CL rn CO ° CO c n n E Co >, 0 •a) a) a) 3 E -p c c) Q o• `a) c c m — a C@ o c 0 a) ›. o a) i.l O - N L — -O 0 70 U V) 9 L 1) -O L m Cl) a) a) > m -E• a) o- N _ U o U c E U m a) E a) a) m m w - 0 co c c " a) '3 c m m m v YO = 3 _ p v) c o a Cl) c aci c O > 3 is m m w Cl) Cl) o U = co ._ a) co = c v co Cl) oU c Z c " C o U U U 0 co o o 0 a) U n o o a) 0 O co -`o m r m vi n E 3 a E 0 t 0 a v 0 p N 3 O O O U .> c0 co n a) a 7 o > > > C 3 N O O ST 5 C w w N a) n ' 0 as N U 0 • m a) a) 3 -0 Cl) n a) a) m a) 3 E o c 2 2 2 m a m -0 -a = 0 0 o °- aa)) a`) co o Cl)) o 0 z a J n 5 to 0 0 a a U Q a O to O O O O Q '=- Q ± 0` m m O w g a 0 (n to O W CO ...W n r _ O — N Co V CC) U7 CO O) CC N M A CL) CO N- CO O) O c,-:)' M V LC) O r CO O) ar+ EO N Co V IO CO r CO CA N N N N N N N N N N Co Co Co Co M M Co Co M `Y 0 0 N N CD C a) N .o. O o N c O C c0 _ . N . _ U o c C O N m O M D N O�y , N C ,- N ° E ..�,{.. N • N a) a o opi0 c Q 0 O C). J O d 0 U • aa W 1 c� 0 to Well History File P ENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history the. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 1 CONFIDENTIAL 1 HALLIBURTDN -A* [tKum;._ -- 1 r I . 4 4/4 1 XRMI Image Log I 1 PROCESSING REPORT ConocoPhillips Alaska, Inc. °t I Kuparuk River Unit Field Shark Tooth #1 North Slope, Alaska Sec. 20 T10N R8E 1 I 1/ 1 Date: 2-24-2012 ! Prepared by: Jessica Mitchell f Jessica.Mitchell@Halliburton.com 1 Location: Denver Formation and Reservoir �/ Solutions `/ 1 Telephone: 303-899-4735 f I 4 • 1 le I ) ii - I (, 1 132,5 t ' HALLIBURTON Denver Formation and Reservoir Solutions ' 1125 17th Street#1900, Denver, CO 80202 Confidential Page 1 2/24/2012 Table of Contents Table of Contents 1 Log Environment 2 Motivation 4 Executive Summary 5 Dip Classification Scheme 7 Processing 8 Fracture Definitions 9 Borehole Stress and Condition 11 Continuous Image and Dip Azimuth Plots 15 Fracture Typing, Frequency and Orientation 19 Formation Statistics 25 Disclaimer 28 Core Boxes 29 1 1 HALLIBURTON Denver Formation and Reservoir Solutions 1125 17th Street#1900, Denver, CO 80202 Confidential Page 2 2/24/2012 Log Environment • Imaged Interval: 6,283 - 6,675 feet • Bit size: 6.750 inches Max Deviation: 1.5 degrees 84.0 Top Depth6207.08 F 75.6 Bottom Depth6683.53 F 672 - Depth Range476.691 F 58.8 Data Points: 1905 50.4 Number Absent: 30 t _ 42.0 33.6 Mean Value: 1.04882 Standard Deviation:0.379101 252 Median Value: 1.06271 16.8 I Mimimum Value0.0967079 8.4 At Depth6207.08 F 0.^ 0.10 0 24 0.38 0.53 0.67 0.81 0.96 1.10 1.25 1.39 1.53 Maximum Value: 1.53315 I - DEVIL At Depth6394.07 F • Magnetic Declination: 20.824 degrees Max Temperature: 160 degF (wireline) ' Mud Sample: MWD Run 900 • Rm 0.160 ohmm © 67 degF @ max tool temp Rm 0.0815 @ 138 degF • Rmf 0.140 ohmm @ 67 degF ' • Rmc 0.170 ohmm @ 67 degF • Mud Type: LSND • Density 11.2 ppg e • Viscosity 85.00 s/qt • 8.2 pH • Fluid Loss 8.6 cptm ' - Services: XRMI, RDT, WAVE SONIC t 1 I I HALLIBURTON Denver Formation and Reservoir Solutions I 1125 17th Street#1900, Denver, CO 80202 Confidential Page 3 2/24/2012 Raw XRMI Data QC IThe cross-plots of the X- and Y-axes of the accelerometer and magnetometer sensors were well centered indicating that the magnetometer readings were correct and required I little post-processing corrections. Accelerometer Magnetometer I 0.050 high side 30000.000 north I • I --- i -- -•-- 0.050 RB- - - 30000.001 .I -0.050 -30000.000 Correction=-0.0007 Y Correction=-0.0035 X Correction=-300.0000 V Correction=-600.0000 XIY Ratio=1.0000 Z Correction=0.0000 XIV Ratio=1.0000 Z Correction=0.0000 IThe AZI1 and RB are tracking each other parallel also indicating that the tool's orientation unit is functioning properly for the main run. I I I 1 I I I I ' HALLIBURTON Denver Formation and Reservoir Solutions 1125 17th Street#1900, Denver, CO 80202 Confidential Page 4 2/24/2012 Motivation At the request of ConocoPhillips Alaska, Inc., the XRMI data recorded by Halliburton Energy Services in the well Shark Tooth #1, API 50-103-20647-0000 Kuparuk River Unit Field, North Slope, Alaska were interpreted for the interval 6,283' - 6,675'. In addition to the standard image and dipmeter processing, manual dip picking was performed interactively on the XRMI image. General stratigraphic, sedimentologic, and ' structural interpretations were carried out over the reservoir section. The main objectives of this work were: a) Distinguish between stratigraphic and structural dips in the logged formations b) Accurately interpret structural dip azimuths and magnitudes in the logged formations c) Interpret fracture types, orientations, abundance, frequency within logged interval ' d) Identify present day stress field orientations where sufficient induced fracture and borehole breakout information is present Image logprocessingand analysis consisted of: 9 Y • speed correction • depth shift to primary log (triple combo) • navigation reconstruction • center re-projection ' • static and dynamic equalization • image enhancement • borehole geometry/breakout analysis ' •• automatic dip picking and dip trend analysis manual dip picking and analysis • manual fracture picking and analysis I HALLIBURTON Denver Formation and Reservoir Solutions 1125 17th Street#1900, Denver, CO 80202 Confidential Page 5 2/24/2012 Executive Summary Data Quality ' Striping was common in higher conductive sediments throughout the imaged interval related to the low mud resistivity (Rm 0.0815 @ 138 degF), the image was corrected with pad equalization however, the correction distorted the high resistive formation so ' much that interpretation was impossible within these zones. Thus, the interpretation was done using both images together to provide the best possible interpretation with the given data set. The final data in the plots and ReadyView are a combination of ' corrected and not corrected data that were zoned to provide the best outputs possible. Borehole Stress Borehole breakout was seen with an E - W strike orientation in several small areas of the well (all below 6322.5'). Induced fractures (all above 6322.5') in a SSE — NNW strike orientation. The relationship between the two is expected to be orthogonal. A suitable explanation for the non orthogonal relationship is the unconformity LCU @ 6322.5' acts as a boundary between two different stress fields. Below the LCU borehole breakout ' suggests Sh minimum E —W orientation with an inferred SH maximum N — S orientation. Above the LCU induced fractures suggest a SH maximum SSE - NNW orientation (rotation counter clockwise 20-30 degrees) and an inferred Sh minimum orientation of ENE—WSW. Natural Fractures ' Natural fractures were rare and occurred as both mineralized and open in the interpreted interval. Termination on bedding was common. The natural fractures were commonly found in small cluster of similar strike orientation and dip magnitudes; however the fracture summary data shows multiple strike orientations and a wide range of dip magnitudes. ' Faulting I One microfault was observed in the interpreted interval with very little displacement N - S striking E dipping. The displacement appears to be normal or extensional. Bedding Gentlydipping beds were common in the logged interval, averaging 1 degree to the N. pp 9 999 9 9 ' The imaged interval demonstrates a gradual sanding/cleaning upward sequence through 6322.5'. Bedding was parallel to sub parallel at the base of section that gradually transitions into to bedding that was sub parallel and wavy up section with a few high energy sedimentary deposits. The high energy deposit above 6322.5' has hummocky cross bedding (NE and SW dip azimuth) suggesting wave action. Unique Features HALLIBURTON Denver Formation and Reservoir Solutions ' 1125 17th Street#1900, Denver, CO 80202 Confidential Page 6 2/24/2012 ' Conductive nodules (pyrite) were common in the logged interval and observed as both disseminated and bedded. Some of the bedded conductive nodules showed a resistive halo which may be an indication of fossil replacement. I 1 e I I I I I I t I I HALLIBURTON Denver Formation and Reservoir Solutions I 1125 17th Street#1900, Denver, CO 80202 Confidential Page 7 2/24/2012 Dip Classification Scheme IThe tadpole and fracpole (strike and dip) color and symbol scheme used throughout this report, as well as on the attached log plots, is as follows: Bedding tadpoles: I11 Blue Tadpoles = Sedimentary Dip lJ Red Tadpoles = Compaction Bedding '.`) Green Tadpoles = Bed Boundary (Structural/Regional Dip) V Magenta Tadpoles = Soft Sediment Deformation I ' Black Tadpoles = Stylolite US Orange Tadpoles = Erosional Surface Fracture symbols: I / Blue Fracpoles = Open Fracture (conductive) IY Red Fracpoles = Mineralized Fracture (resistive) V Green Fracpoles = Fault IY. Magenta Fracpoles = Borehole Breakout (not picked in this interval) Black Fracpoles = Induced Fracture IY Orange Fracpoles = Microfault I The quality of the pick has either been assigned manually by the interpreter or assessed computationally by the programs Shiva and AutodipTM. In either case, the quality can be identified by the fill inside the head of the tadpole of the base of the fracpole. Five quality levels are presented below: Highest quality W i(v 0 Lowest quality I Highest quality yx- y.Lowest quality 1 I I I I HALLIBURTON Denver Formation and Reservoir Solutions 1125 17th Street#1900, Denver, CO 80202 Confidential Page 8 2/24/2012 I. Processing I Handpicked Dip Principle I Unlike dip meter processing, which uses only one resistivity curve per pad, manual dip picking form the XRMI/OMRI image can provide good quality dips even when the formation resistivity contrast is poor or when the image quality is degraded. This noticeable improvement, both in I dip density and dip quality, is mainly due to the fact that manual picking takes full advantage of both the borehole coverage of the six image tracks and the accuracy of the human eye. Interactive dip picking is preformed with a sliding sine wave of which both the amplitude and azimuth can be manually fitted to a planar feature on the XRMI/ORMI image. When the I interpreter estimates that the fit between the sine wave and the feature is satisfactory, then the true dip is computed. The dips interactively picked on the XRMI/OMRI are then classified into dip sets according to their interpreter. IStrike and Dip Orientation Convention The orientations in the rest of this report is presented as follows 5° / 300° (where the first I number represents the dip magnitude, and the second represents dip azimuth with respect to true north— corrected for magnetic declination). For strike orientations, the following is used: 090°/270° (which would be striking EMI). All measurements have been corrected for borehole deviation. The statistical analysis use vector addition to calculate average strike values. e I I I I I I I I I I I HALLIBURTON Denver Formation and Reservoir Solutions I 1125 17th Street#1900, Denver, CO 80202 Confidential Page 9 2/24/2012 Fracture Definitions I Fractures picked from the image may include the following types of fractures: natural open fractures, natural closed/mineralized fractures, faults/microfaults, and drilling induced fractures. The fractures picked on the images are coded according to the colors shown in the I "Dip Classification Scheme" section. Fractures were typed with the following criteria. I Natural open fractures are conductive as they are usually filled with �� ;v. ,.. drilling mud and appear as traces that are darker than the surrounding I i - formation rock. Natural fractures are generally symmetrical allowing a sine wave to be fit to them. Natural fractures often terminate in a single � ' lithology, whereas induced fractures often continue through several I _ 1-.4. ti_ lithologies. If the orientation is the same as an induced fracture, then it may not be possible to differentiate between the two types. The examples to the left show some natural open fractures. I I ' -s 111 y b.'s s 7 rk• ' . :-- , P, i 1 t Natural closed/mineralized fractures are those that have been filled I - - by secondary mineralization making them more resistive than open fractures which are usually filled with drilling mud. Closed fractures generally appear as traces that are brighter than the surrounding rock and sometimes demonstrate a "halo" appearance due to the resistivity I i of the secondary mineralization. Natural closed fractures are generally A symmetrical and a sine wave can be fit to them. The example to the left shows a mineralized fracture. __. Induced fractures are generated during different stages of the drilling I '•!• �; process. Induced fractures are open fractures, thus will be conductive _ . and show a dark fracture trace. There are different types of induced >} fractures. Petal and centerline fractures form ahead of the bit while < < '' - drilling and are caused by the weight of the bit and/or mud pressure. �` '' • Tensile fractures can form from hydraulic fracturing with mud behind I "0 ^ "' the bit. Since tensile fractures develop after the wellbore was cut they i - ..ic -' r,' la develop in isolation and will be asymmetrical. The example to the left i ''� `. shows a drilling induced tensile centerline fracture. Induced fractures I , - 1 `` typically do not terminate in a single lithology. I I I I I HALLIBURTON Denver Formation and Reservoir Solutions 1125 17th Street#1900, Denver, CO 80202 Confidential Page 10 2/24/2012 Faults occur when there is displacement along a fracture plane. On I - ,,,, ++ image logs, faults can be distinguished where bedding planes are PPterminated - by the fault plane. Often a change in dip azimuth occurs , - -, above a fault zone. Microfault° are faults display minor displacement I _ in bedding along the fracture plane. These micro faults can occur above and below a fault zone. The examples to the left show faults. — _ I I 1 _- Slumps are mass movement processes of slope failure, where the rock I or unconsolidated material drops along a concave slip surface. Slumps usually move down slope as an intact unit without internal deformation. 1 I I ' 1 1 I I I I 1 1 HALLIBURTON Denver Formation and Reservoir Solutions 1125 17th Street#1900, Denver, CO 80202 Confidential Page 11 2/24/2012 i i 1 1 Borehole Stress and Condition ' 1 1 i 1 1 i 1 1 I HALLIBURTON Denver Formation and Reservoir Solutions I 1125 17th Street#1900, Denver, CO 80202 Confidential Page 12 2/24/2012 FRACTURE/STRESS REVIEW IMIN horizontal stress cm n Sh I I breakout IMAX horizontal stress MAX horizontal stress induced induced 4... Iri? fracture fracture SH II breakout I 1 MIN horizontal stress .Jh I EXAMPLE: Rose(Strike)Plot )h North n I Breakout direction/ellipticity ','e��Ir�1�' ♦11f► long axis will be orthogonal to X111► drilling induced fracture strike if 4A, ����1IIft1►����1 I S1 = overburden. -��t111* %��rri���������;,i fSH west ••�■``P *, 11 ast I More info about Natural $H P ••,����i� ll►�����*�11 Fractures at: ` 1140w Viii*a4- ... www.naturalfractures.com , �.►�11����' • Induced '°" aau, t'° 1 Fractures sh 1 I HALLIBURTON Denver Formation and Reservoir Solutions I 1125 17th Street /1900, Denver, CO 80202 Confidential Page 13 2/24/2012 BOREHOLE STRESS CONDITIONS I 14 Dr 4 4 en_ee 19 :VB B orehola Ellipticity Oh PmIa otw lib 2 19 4 4 14 I �— loatu nab Nara.x own Ban Hole Deviation BR EY Breakout Diwtlon 14 14 Met 10 'q a . ,..., QeQ,eK a.Br•e, .o�••• %Washout' washout 1 1 Gamma API Max-Min M.*Min Borehole Break out Vector MD STATIC IMAGE I Ir ._ I °__L" t:24U —EB004--- Poim atlon formation " 111111 a1+ ResLction RezL ktlon N E B w N IL83110 MUM SOIA , - - rt . _ L , ��,I — — T. _ _E— -- I► _r- __ I t— —_(-7 11 Rose(s ' e)Plot Norh l �`HoY „� , ,e :e 11 The orientation of the present day in situ state of stress can be 9�p5� .t��► determined from the orientations of borehole breakout and :A��� ♦ 114:40 R�♦ ♦'�?Sh? drilling induced fractures if the data is reliable and consistent N ��04, , $ �� �j ' ��% ��♦1► � throughout the wellbore. It is important to note that in deviated I � lair, boreholes the relationship between the drilling induced fractures Wen Illi r. - .■cilli and the borehole breakout orientation may not be directly 7:0:011 ...m.24-A .;: mIF;llf,,L„,,8East rr�. pp,����1�� g correlative to the maximum and minimum horizontal stresses. � 4��j�rau ik 44 lop The Borehole Breakout Plot example above shows an area I ?Sh'� �♦' ainfi.14 where no amount of borehole breakout or elongation recorded ���►. with the calipers.. 40,90 leo+TO • I South H The Rose Plot diagram to the left shows the overall strike INDUCED FRACTURES orientation of the induced fractures that were (n=6) 0.02 FRACS/FT observed/interpreted in the logged interval above 6322.5'. The Average strike: 156°/336° induced fractures provide evidence to estimate the orientation of I E Mean SH orientation7.___________sithe maximum horizontal stress direction, or SH. The red arrow ���` represents the inferred minimum horizontal stress, or ._= \\\\ The cross section diagram to the left show the average strike / \\ orientation for the borehole breakout observed below 6322.5. \ The borehole breakout provides evidence to estimate the 11 1 orientation of the minimum horizontal stress, or Anisotropy • t below 6322.5 albeit rare when seen showed a N — S orientation l1 providing evidence for maximum horizontal stress direction, or I \� / SH below 6322.5. ---------__12,---- Depth=6374.419 BOREHOLE BREAKOUT I Average strike:080°/100° E Mean Sh orientation I I HALLIBURTON Denver Formation and Reservoir Solutions I 1125 17th Street 1/1900, Denver, CO 80202 Confidential Page 14 2/24/2012 BOREHOLE STRESS CONDITIONS [hi . . \ Zi•11';. 17 ffl R] 637 t = rr r Qr. . • . u y; I 637 E ,,,,. 637 ... 1 �• .M . ,..,. . IP gw! f-p; ®O'. . . I'+ . - !! heo I A 63 4 •1' � .� c e all dig [t Cross-Section . (::::::----_ --- .... -i I 637• I Jej 1I ..a+u 0 t...roc A.• ,r a \'amu/ VDL -ACX VDL 11YY VDL L,XY VDL QST VDL :I AN'SO ISO ISOT. F - _ice _� �� AD DM w 340 om 40 DMw..o and 'o+a MAD ISO o •uuv >w I �,240 DIC w 340 OTC w>b DTCors a..O DTC .B 40 MAMA.+.O 260 SAS BO O.O 01 VOL w+4044,40 IN OBO IST BOO 460 100 �w0w�w OTC 0 o IN 'i 111117 i 1.1 r .1 r I, 1 . . . . I , _ . I 1 1 1 ) � �p r r a i 1 lit �! iU i i A small amount of borehole breakout is seen between 6,372' — 6,373' and 6,374' — 6,375' in I the dynamic image. Borehole breakout is seen as parallel dark bands that occur 180 degrees apart and provide good evidence for the minimum horizontal stress SIT A small amount of anisotropy occurs near 6570' with a N — S orientation (far right track I labeled AMAP) providing evidence for the maximum horizontal stress direction, or SH 1 HALLIBURTON Denver Formation and Reservoir Solutions 1 1125 17th Street#1900, Denver, CO 80202 Confidential Page 15 2/24/2012 1 1 1 1 1 I 1 Continuous Image and Dip Azimuth Plots1 1 1 i i 1 i 1 1 I 1 HALLIBURTON Denver Formation and Reservoir Solutions 1 1125 17th Street#1900, Denver, CO 80202 Confidential Page 16 2/24/2012 CONTINUOUS IMAGE AND CULMUATIVE DIP PLOT I __rgin. o 1 CUMULATIVE DIP PLOT AT 't�"f 6300 f C 2�, lative Dip Plot � 0. Quadrants 80 -/ , A- 354 •180 to 270 ■27▪ 0tto1360 D 0 P AT i a F1 404 �7� ,,\j m Ij P I s V450 -640' 7 \fs1z -645' \(i623 1 - _ I ' Cumulative Dip Iiijii6501 1 0x6550 1 ' -6600 -6 0 1 True Di `[dL�j w P — Continuous image and cumulative dip plot showing all manually picked beds and fractures within the 1 logged interval of the SHARK TOOTH #1 well (6,283'-6,675'). The continuous plot is a small scale view of the logged interval and provides a way to view the occurrence and distribution of the different types of bedding and fractures that were interpreted. The cumulative dip plot method provides a way to analyze dip angle as a function of depth and is used for determining/detecting faults and unconformable surfaces I by deflection points in the bedding dip data. Please see the more detailed summary bedding and fracture data and formation statistics on the following pages. I I II 1 HALLIBURTON Denver Formation and Reservoir Solutions 1125 17th Street#1900, Denver, CO 80202 I Confidential Page 17 2/24/2012 STRUCTURAL DIP _ 1•i4:k1 0 Cilative Dip Plot Dip Magnitude 6300 '�\ :u0adrrantts s20 qse 90 to 180 c180 to 270 354 270 to 360 416 \ R 4 Q .. 3 'T404 v,p y11 (x60 El N 6458 ,20e \ 6 6� ` 104 - X5,2 4 52 0 I / 23 0 22 45 Degrees `/ s� Cumulative Dip •of tllps 1181 /'` Mean Dip Beds-0.827 deg 348.323 deg azimuth Dip-Azimuth Plot �� Rose(Dip)Plot North / t. SOY�.O r° 4 _To I ' _ west *•�gi!4,' ktdc,'.nr8E8" / 7 / South �4/6 t of dips 1181 1 Mean Dip Betls-0.821 deg Q 348.323 deg azimuth J Current Range-6283-6675 0 Depth Range.6283-6675 /7 yy�//f���j/ Field:KUPARUK RIVER UNIT /// 'e Well:COP_SHARK1_RUN2 �G!44:1/ 1rue 0 pp Company CONOCOPHILLIPS ALASKA,INC. II Dip azimuth plot showing structural dip azimuths that were interpreted in the logged interval (n = 1,181, green tadpole symbols from the image log). A rose diagram shows the overall direction of structural bedding dip azimuths. Structural dip: 0.8°/348° I (dip magnitude /dip direction) I I I I I HALLIBURTON Denver Formation and Reservoir Solutions I 1125 17th Street#1900, Denver, CO 80202 Confidential Page 18 2/24/2012 SEDIMENTARY DIPS ®_UN ei Clative Dip Plot Dip Magnitude 6300 Quadrants 20 ■ 0to90 90 to 180 le ` - ,`R354 •100 to 270 x270 to 360 16 r • i/. ` a FIs - 0 E 12 m $1\ • P `.\ N 10 e s C .. s \58 66�t2 y e 4 2 - 623 00 2® /S Itt -645$ Cumulative Dip ♦of tlips 102 Mean Dlp Betls•2.213 deg 139.797 deg azimuth `/ 1 Dip-Azimuth Plot pp.{{��.. Rose(Dip)Plot North i.I_, o,350 0 ro J Ps.� .o4. I ./, •650 ~ •�Cfl�•�S~ 1•��'t+ West4 err=. n,_1 it i 8 East � 0 � •6550 . 14W t`f g � M� ,. '..mil, �� 600 °Jeb.11/11111111111 rqo tee 170 0O �/ South •of tllps 102 1�� Mean Dip Betls=2.213 deg�139.797 deg azimuth 1 J 1' Current Range 6263-6675 / '6 0 Depth Range.6283-6675 Field:KUPARUK RIVER UNIT �/ Well:COP SHARKIRUN2 /i:t.�gy 1 .True Dip] Company CONOCOPHILLIPS ALASKA,INC. IDip azimuth plot showing high energy sedimentary bedding dip azimuths that were interpreted in the logged interval (n = 102, blue tadpole symbols from the image log). The rose diagram shows the distribution of the sedimentary dip. I I I I I I I HALLIBURTON Denver Formation and Reservoir Solutions U 1125 17th Street#1900, Denver, CO 80202 Confidential Page 19 2/24/2012 I I I I I I II Fracture Typing , oFrequencyand Orientation I I I I I I I I I HALLIBURTON Denver Formation and Reservoir Solutions I 1125 17th Street#1900, Denver, CO 80202 Confidential Page 20 2/24/2012 ALL FRACTURES: 6,283' - 6,675' 1 6300 41. — Rose(Strike)Plot North 1_- MG_ O yp 350 0 to ,p ,., n o 30 - fit:IT: V- i ,I °°*\ .e �r�AuM1 1l‘ , /4•♦.�$ :::1064 $ iri fr itwo• oots , West ii`ait 'rI 113silli s.8, V ast 1 Eas, ■ h ''O7, 'r__ ILos I 11 °40 Sao tao„o`pO ' _� South -640 NATURAL OPEN FRACTURES (n= 10) 0.03 FRACS/FT Rose(Strike)Plot Ne„ 4 -645 4.4‘ �o %�ra iRi� n ♦ / , WesterR'i 1fal1tr���►=�:It�rfll t East t�rg ��hD\rr#l '8 •I / 650 1 %., $144•44/4 BittV440° ill -b,,A1Mit'S „0--° I South I MINERALIZED FRACTURES J (n=6) 0.02 FRACS/FT Rose(Strike)Plot Norm /i / -6550 °,° :o0.,° 441k-1625F41" A .. vti . s1 �ffr•ir�� , r.ratt I / west *f...ii� a...ES} I^t gEast 6600 1� IMIV inn` :�a'1141'8 /// s rm"O..vii i` ��j� - / f� lea00 fy°. . BOO r10 1ir0„0% -6' 0 5°°a INDUCED FRACTURES J� (n=6)0.02 FRACS/FT �[33F1 True Di ***Average Strike= 156°/336° Continuous image showing the orientations and distributions of the natural open and I the mineralized closed and the drilling induced fractures that were observed in the logged interval of the SHARK TOOTH #1 well. Rose plots to the right show the overall orientation of all fractures types with frequency of fractures/foot within this interval. I ***Average strike calculation for the induced fractures used simple addition. I I I HALLIBURTON Denver Formation and Reservoir Solutions I 1125 17th Street#1900, Denver, CO 80202 Confidential Page 21 2/24/2012 NATURAL OPEN (CONDUCTIVE) FRACTURES: 6,283' - 6,675' Polar(Strike)Plot NOAh 1 + x o ssu o *o '' Y� c •�*Vili+♦�'�o X00 I -4. % 040 • i WestArr/iait ► -dime East -411101, 4,' South r� -6401 NATURAL OPEN FRACTURES (n= 10) 0.03 FRACS/FT I � Dip Azimuth 10 6 a -6451 F R E6 6 I. �E 5I ' / � 3 lt I 4 1 Q' 2 fej1 t IIII I I I I 0 e 60 �i Degrees I HISTOGRAM OF DIP AZIMUTHS J� � // -6550 Dip Magnitude I r %/ a 6 /-9 6600 N S / 'ti v , 2 I 1 ,i , Zo 1 3 �//I 11111 1 I 1 -6 r 0 °o as sa �� neee� /Gatti, / Illgt4.PiHISTOGRAM OF DIP MAGNITUDES Continuous image showing the orientations and distribution of the natural open (conductive) I fractures that were observed in the logged interval of the SHARK TOOTH #1 well. Rose plot to the upper right shows the overall orientation of natural open (conductive) fractures with frequency of fractures/foot within the logged interval. Histograms to the right show the I frequencies of dip azimuths and dip magnitudes. I I HALLIBURTON Denver Formation and Reservoir Solutions I 1125 17th Street#1900, Denver, CO 80202 Confidential Page 22 2/24/2012 NATURAL MINERALIZED (RESISTIVE) FRACTURES: 6,283' - 6,675' 6283 c Polar(Strike)Plot hush 'Q�� a o 0 5.0 I \--- 444%Awry At Robi z' west int \���sns�>it i-imiumiEast II 1 ►t i pj iu '.�41i -IP isowei4 41*Wry? y meq. LL o?�'-1!0,-�O� South -6401 MINERALIZED FRACTURES (n=6) 0.02 FRACS/FT F' • Dip Azimuth 10 y 9 4... -6451 8 R6 R 6 5 JI} C 4 I3 -650 leiI ° i I II 0 180 36° Degrees 2HISTOGRAM OF DIP AZIMUTHS li -6550 Dip Magnitude 41/1 I -6600 R R E fi D / N 5 N i I I' 4 C 0 3 I • Z -6 0 ' � 0 0 _ I - - 0 45 °° �km True DI HISTOGRAM OF DIP MAGNITUDES IContinuous image showing the orientations and distributions of the mineralized fractures that were observed in the logged interval of the SHARK TOOTH #1 well. Rose plot to the upper right shows the overall orientation of the mineralized fractures with frequency of fractures/foot I within the logged intervals. Histograms to the right show the frequencies of dip azimuths and dip magnitude. I I I I HALLIBURTON Denver Formation and Reservoir Solutions P1125 17th Street#1900, Denver, CO 80202 Confidential Page 23 2/24/2012 INDUCED FRACTURES: 6,283' - 6,675' _ o Polar(Strike)Plot North 1 art 6300 °'e4`l■gr�:° �, e Ik_ Ak ,f,,,,,„*.ist• i rtgAttit West���%a#tjr `�it� ���t���ate East I .S.-: : ' -• ,• 0 �i0oa °0,a, teoey � J.{i. ..I aiev_ .. SOuth 76401INDUCED FRACTURES (n=6)0.02 FRACS/FT "'Average Strike= 156°/336° , p: : 111Dip Azimuth to -6450 I e J F 7 R 7 I GI 6 • 1 (' 5 N C I id, -650 3 I/ 2 S(1 111 ll I II °0 150 360 De.rees // -6550 HISTOGRAM OF DIP AZIMUTHS JDip Magnitude / m i "A/ . 6600 } E e / S6 i j', Vs N C 4 V 3 I I 1a iI!Itb1 True Di 0 45 eo 5494444 IHISTOGRAM OF DIP MAGNITUDES Continuous image showing the orientations and distribution of the induced fractures that were observed in the logged interval of the SHARK TOOTH #1 well. Rose plot to the upper right I shows the overall orientation of drilling induced fractures with frequency of fractures/foot within the logged interval. Histograms to the right show the frequencies of dip azimuths and dip magnitudes. ***Average strike calculation for the induced fractures used simple addition. I I I HALLIBURTON Denver Formation and Reservoir Solutions I 1125 17th Street#1900, Denver, CO 80202 Confidential Page 24 2/24/2012 ALL FAULTS: 6,283' - 6,675' _ Polar(Strike)Plot Nmn �ltl (MO 4. rr 414 e West ,....w.--ye�;aaaia,isvEest • brp, W SOVN FAULTS (n=0) Polar(Strike)Plot Noun m„°550 a r°t° SSOS •=rr=� 6 -640 $ jam..it IA $g -- k ♦i�. •nu o••A s 1■ri@p t %Grrass 1111111.0P-iii0441114ei ♦ p•Inv#44,4411. .. -6451 4111.1t1}4414e: i I ::,...1 Dip Azimuth ,,t'-- io L. -650 ' a q., Es 0 1 CO VZ 6550 . 1 o oeor180 9. HISTOGRAM OF DIP AZIMUTHS—ALL FAULTS Dip Magnitude t m / e ( 6600 EJJg J/ff` S / 2 -,117 r a n, HISTOGRAM OF DIP MAGNITUDES—ALL FAULTS [I}bi Tru�Dip Continuous image showing the depths and orientations of the faults and the I microfaults that were observed in the logged interval of the SHARK TOOTH #1 well. Polar plots to the right show the strike orientations of the structures. U Depth Dip Magnitude Dip Azimuth Dip Direction Strike Azimuth 6329' 38.4 98.7 W 009/189 I I HALLIBURTON Denver Formation and Reservoir Solutions 1 1125 17th Street#1900, Denver, CO 80202 Confidential Page 25 2/24/2012 1 1 1 1 1 1 1 Formation Statistics 1 1 1 1 1 1 1 1 1 I I HALLIBURTON Denver Formation and Reservoir Solutions I 112517th Street#1900, Denver, CO 80202 Confidential Page 26 2/24/2012 Around the Upper Sand: 6,314' — 6,328.5' (14.5') S 6314 N 63M 'w!LhA! A WW �NJ N E S AA Dip-Azimuth Plot ! " 6315 \ _ 63 • v ="..r _ Jl/'/� 63 7 �J _II y'y _.- 8 om:632a �� 63 8 !/ DIP AZIMUTH PLOT I ' t 69 9 rt- . •� -� a ao.e!°gl Plot Role(DglPq. 1;63 0 i•1iit• rost. X d; p -I - – _ ,..3' fNi - ii1.P� ..i / . 63 1 %`,dfr "'!ad4t,*.„".7:1411:`�iLD��ss to pi, 63 2 M-;`-+ In 1`;'_'` STRUCTURAL DIP(n=25) I / 2.3°/024°(magnitude/direction) Me- ••e' .1 SEDIMENTARY DIP(n=23) ! 63.3 1 + "-- _i 2.0°1065°(magnitude/direction) I _ ~ - _ _ Polar(Strike)Plot , TMM 634 _. i l :, __ .. _ " ;Alrrrrfts►'. 41.1W 4.111111.... 410re P 44 '' - 4' 't 1 ` ux -n.. — wa:i 11111.10;',";%4,4-444404; $pu r S� risif east i ‘�♦ 1 . J3 .04 nu` �1 1�: $ ffrrrrt► r U J /jAr0/iii � °- '-- i fir.� � �\ E x "fi` e soum •� ., _� �= OPEN FRACTURES(n=2) I . �7 63 I :�- E.....„narcernIc XE Ir. 6 Average 0 14 fractures/foot = sf oot 6°/246° I 'Static RMI :True DIFI Dip interpretation display showing frequency and distribution of Polar(Stnke)Plot .p,. all beds and fractures that were observed within the Upper ,>A°''° � 1 Sand. The dip azimuth plot shows the direction change in the �'°•' r1.'i!�pi1'4. dip directions color coded to dip type. Rose plots show : 44#.• 1rffrS•olk R.4.-04 irib bedding dip direction trends and summarize the fracture strike a.,:Jt" !,ea.I : direction by type. Gamma Ray is plotted over the static .1 ;.y�%��18 image 0— 150 api. **"Average strike calculation for the s 11r.**all 'i# Le induced fractures used simple addition. �114,001:t' �_!, rb!a°1� 1 INDUCED FRACTURES(n=6) ***Average Strike= 156°/336° 0.41 fractures/foot 1 1 I I I HALLIBURTON Denver Formation and Reservoir Solutions I 1125 17th Street#1900, Denver, CO 80202 Confidential Page 27 2/24/2012 Lower Sand: 6,349.5' — 6,364' (14.5') I ...)7ii 6 i.;, ❑a r 1 1Pic:tm n L/ IL Dip-Azimuth Plot e-em.���p amri I 3 mom 8353 6 52 ti ‘\''.: I 6;53 \\Cyr/y Top \6349 f e.....„.,..�,,., 352 <54 - 1 DIP AZIMUTH PLOT 6 55 t= i rametna e„ Rae(01p)Aa ill B aet�w i ,;;”; ""max.66 .el (p •ya .- 1'tI ':r Et tti .�� r 1 iii tt STRUCTURAL DIP(n=40) I 6 58 0.3°/229°(magnitude/direction) SEDIMENTARY DIP(n 77) .� Pik' '� 2.5°/153°(magnitude/direction) c 6'59 ' � t _rola'gem ,--....-v i 1 -411 Polar(Strike)Plot I i O aa�•e ( NanI+ .�..." .. *it., 44.0 oktero '4* 4111 UM I IV • 4/ 4.01 0.•4 1. I 63.1 ! ........ s ..._: we,1fr7.nrS-.*_G.NSJIIII E.n "SU*11V40 'r II►`�"41.q e / 6 62 .:. 3 .88=11�0•��4p 6 63 p seam l� I + Wag%ike•154456.33•.•58 degrees Hmeg.3453 • / ' ,.•jam 1[I SO Dynamic XRMI MINERALIZED FRACTURES(n=4) I 1i8b7!� I6ta XRMI.,...aa-. ITrueDIPI ` Enhanced(Emao55ed) 0.28 fractures/foot Dip interpretation display showing frequency and distribution of all beds and fractures that were observed within the Lower Sand. Rose plots show bedding dip direction trends and summarize Ithe fracture strike direction by type. Gamma Ray is plotted over the static image 0— 150 api. I I I f HALLIBURTON Denver Formation and Reservoir Solutions 1125 17th Street#1900, Denver, CO 80202 Confidential Page 28 2/24/2012 Disclaimer 1 1 1 1 1 1 1 1 1 1 1 DISCLAIMER Halliburton does not guarantee the accuracy of any interpretation of the log data, 1 conversion of log data to physical rock properties or recommendations which may be given by Halliburton personnel or which appear on the log or in any other form. Any user of such data, interpretations, conversions, or recommendations agrees that 1 Halliburton is not responsible except where due to gross negligence or willful misconduct, for any loss, damages, or expenses resulting from the use thereof. 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Well: SHARK TOOTH #1 I Field: KUPARUK RIVER Rig: DOYON 141 I r Country: USA I � Logged: 02/13/12 * Engineer: BILLY WYRICKI I ROHIN NAVEENA-CHANDRAN Analyst: 11 ROHIN NAVEENA-CHANDRAN I i - Date: 02/15/12 , I HALLIBURTON I I I Table of Contents Table of Contents 2 I Overview 3 Log Header 4 Tool String Diagram 5 ITest Summary 6 Plots 9 ITest No. 1.1; MD:6317.10 ft;ND: 6317.10 ft 9 Test No.2.1; MD:6318.05 ft;ND:6318.05 ft 10 ITest No.3.1; MD:6322.08 ft;ND:6322.08 ft 11 Test No.4.1; MD:6327.07 ft;ND:6327.07 ft 12 I Test No.5.1; MD:6328.10 ft;ND:6328.10 ft 13 Test No.6.1; MD:6350.99 ft;ND:6350.99 ft 14 I Test No.7.1; MD:6356.51 ft;ND:6356.51 ft 15 Test No.7.1; MD:6356.51 ft;ND:6356.51 ft Bubble Point 16 ITest No.8.1; MD:6361.09 ft;ND:6361.09 ft 17 Test No.9.1; MD:6365.05 ft;ND: 6365.05 ft 18 ITest No. 10.1;MD:6364.53 ft;ND:6364.53 ft 19 Test No. 11.1; MD:6370.00 ft;ND:6370.00 ft 20 I Test No. 12.1; MD:6376.06 ft;ND:6376.06 ft 21 Test No.13.1; MD:6356.58 ft;ND:6356.58 ft 22 I Test No. 13.1; MD:6356.58 ft;ND:6356.58 ft Bubble Point 23 Test No.13.1; MD:6356.58 ft;ND:6356.58 ft Contamination Analysis 24 I Test No. 14.1; MD:6318.07 ft;ND:6318.07 ft 25 Test No. 15.1;MD:6317.04 ft;ND:6317.04 ft 26 Test No. 16.1; MD:6326.98 ft;ND:6326.98 ft 27 IDisclaimer 28 I I I Page 2 of 28 I I Overview I At the request of CONOCOPHILLIPS ALASKA, INC., the RDT DPS tool was run in the SHARK TOOTH#1 well, KUPARUK RIVER UNIT field, USA in a$BitSize hole for formation pressures and establishes gradients in various formations. I I I I I I I I I I I I I I IPage 3 of 28 I I 1 Log Header `i $ 3 S If 6 R 3, . A R lo_ 1 a lis I P g Q E 4 COMPANY CONOCOPHILLIPS ALASKA,NC. $o` 3g Lq "44320 ". 2 6 as � n ? ,4 IgA I a s g + p / a 3 ie ail -c `s Q 44 ill WELL SHARK TOOTH+t1 s ;so � °� x = siii a y s + c 1 « u HELD KUPARUK RIVER UNI '+ . a a COLNTY NORTH SLOPE a : 5 I IIIIIIIIlIIIi ' ;ATE ALASKA W 3 (7 ?1�' V 0 m XI Z 7C (A l7 I = U C Z 0 = 2 N r 08 � � � 0 A. m -I to d a m m I � _ � s- � _ x m i !i• D O . O 0 p w p • 010 Z r m �... r,' $ $ I T • T 71003w Service Tidxt No.: 9216420 API Serial No: 50-103-20647-0000 PGM Version: WL NSITE R3.4.4(Bu8d 2) DRECTIONAL INFORMATION IMaiinum Deviation 000 deg 0 0.00 t I KOP ! 000 ft Remade: DEPTH CORRELATED TO HAL LIBUFtTON 1260 TRIPLE COMBO LOG ACQUIRED BETWEEN JANJARY 17 201210 FEBRUARY 122012 DPS 86 CONFIGURED WITH DUAL PROBES FOR PRESSURE TESTS:DPS 87 COFFIGU9ED WITH SUM OVAL PAD FOR SAMPLING I FPS 86 AND FPS 100 CONFIGURED WITH 8K PLRAP FLUID ID PERFORMED WITH DUAL FLIDTOOLS:ALL SAMPLES TRANSFERRED AND DELIVERED TO PVT LAB FOR ANALYSIS MCS 19 PLACED N BETWEEN BOTH FPS'TO ACT AS A HYDROSTATIC ISLET IN BETWEEN PUMPS:CONFIGURED WITH 1 INET FILTER AND 2 WATER F FOR CLEANING MCS 95 CONFIGURED WITH 1 INET FILTER AND 2 NITROGEN BACK CHAMBERS;MCS 115,MCS 122 EACH CONFIGURED WITH 3 NITROGEN CHAMBERS I TEST AT 6328 FT(FLE 2-11)ENDED SHORT DUE TO LOSS OF TELEMETRY BUBBLE POINT PERFORMED AT 6356 FT(FLE 2-14)TO SHOW PRELIMINARY RUD ID WITHOUT PUMPING AT CUSTOMER REQUEST RIG:DOYON 141 THANK'YOU FOR CHOOSING NIL LB LRTON ENERGY SE RACES I PALLEU2TON ODES NOT GUARANTEE THE ACCURACY OF ANY S ERPIETAIION OF TIE LOG OAT&CO WE RS ON OF LOG MTA TO PHYSICAL ROOC PARAMETERS OR R'COAMIRICATONS WHICH MAY R GIVENBY HILLISUARON PERSONNEL OR WINCH APPEAR ON TIE LOG OR IN ANY OTHER FORM.INS USER OF SUGH OVA.I141ERPIETA1101i,CONVERSIONS,OR R'ODISEIDATIONS AGII@S THAT MWMAIrON IS NOT RESPONSES!EXCEPT WHERE OLE 10 GROSS NEGLIGENCE OR WLLfll MSIOOIOUCT,RSR ANY LOSS.DAMAGES,OREXPEN0E!ROUSTING FROMTFE USE TIEIEOF. IIMLLSURTON I IPage 4 of 28 I I ITool String Diagram R...1711.1.41...M[ONT i [ [ ..... •.. I 1 .... ..., I .-- 1 - •••• MT .....- ... . -,...-....... I M.. ..-. . . .....- ... , „... . VIZ ....-. .... i 2= ....-. I [ , ..: ...... i ••• Izr. ......—. — ---— . I . :7. i . / •••• . . . I Itrz • i .....— , I — , ..., s.-. ... I I — r.o. ..— . I en . t r.:. ... I f - I i - -1 I rAt. ... ... I 7TH'iF :7: :=.-ir-=-7— . _. ..-. . = .. ..— I ........ 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Ea E 12 H o 01 > 5:: > c E a O L M (31 ttoo to CA to CA to AI lto O.`- 'o d •'T' O d ,O ° >,a_T+ 'O 0J O .•-1 .-1 N N m m E o a N a ° E a o Y - y LL Z N O N N N N N N N N N 0 m E 0J •°1-' a g)'' 0.2 N ' E .2 c ff0 O. LA H . `l O O OJ a O c 'O £ 1 E U > > ri MI C M M M M M M O) 1- a m a �E E c O N 0 0 0 0 7 d H E .--1 .--1 c-1 .-I r-1 ."1 MON N Cl. a) O (1) O Na a.Z a 11 r• In � F- amF- UDa .> 22Ow • I I IPlots ITest No. 1.1; MD: 6317.10 ft; TVD: 6317.10 ft RDT Test File#2-7.1 Date:13-Feb-12 20:57:54 _ PRESSURE/TIME 4500 9Q F. .T-- 4. ---1 1 . 1 so0ao' , _ __ a 0 100 200 300 400 500 800 100 EXACT PRESSURE TIME I 4500 0 _0.30 4000 00• _.__-.- ._.....-_.__ ... ... .................t......."'._.......-- - 0.27 Lopencl 3500 0o- y 0.24 smnwy Clow_ -� =021 -Mea PTR* 3000 0o-------- - PnNuq D* -Exec.Cum . 0.18 O'H7Aoete4c/ • m 2500 0o- __. _-.--- _. - __...... .. 'Ele11 00 OEnd DD 2au 0.15 2swp 2000 oo- --..._._ I 012 i <R7Aro92009 2 I. .—.-__.-. .I 0.09 1000 001 II 0.08 500.00 0.03 0.00 ( ` r 0 0.00 0 100 200 300 400 500 800 700 I .- - ETIM(sec) - - _ EXACT PRESSURE/ TIME PLOT SUMMARY MD(ft) TVD(ft) Pedd(psia) Pstop(psia) Pexact(psia) Mexact(md/cp) I 6317.10 6317.10 2955.19 3384.69 3432.35 0.037 CONSTANTS-SPHERICAL FLOW Volume(cc) Rate(cc/sec). Rsnorkel(in) Porosity Ct(1/psia) Flow-line Storage I (fraction) (cc) 0.72 0.18 0.66 0.25 4.28e 006 180.00 TEST CONDITIONS&STATUS +/-stdev Stability Stability Exposure Time Pump Status Tool Face(deg). (psia) (psi/min). (deg/min). (hr). 29.01 144.05 0.00 REMARKS Tight Test I I I I I Page 9 of 28 I I 1 Test No. 2.1; MD: 6318.05 ft; TVD: 6318.05 ft RDT Test File#2-8.1 Date:13-Feb-12 21:11:06 I PRESSURE/TIME m 4800.00 _ 1000 a 0 200 400 600 800 1000 1200 1400 1600 I4500.007 EXACT PRESSURE/TIME 1.50 I 4100.00.._-_.__-_..__._- _-_-_._--_-_.__I __.-__._._._ -.. ...-_ .____- 1.35 1 legend ' 37000 . ell r. __. --'�.-___-_...__._-...- 1.20 -Stability Curve _Mea.PT Rete 3300.00• _........ .................... 1.05 -Pressure Data -Exact Curve 2900.OP __....._.- _ ........................................................................................_._-_.-_......._.._......._..... -.__- __....._..- 0.90 P Hydrostatic 1 °Stam DD I I I [ eEnd DD S.2500.00 1 0.75 a V.! m •54p m e /1 I m 42Hydroatatk 2 I;210000-....._..__..-- It _---.--.- 1 - �'�j ---- 0.60 a II I 1700.00-'-_............_ _-_........_._........_.._� -___ .___.-_._ 0.45 I1300.00.................. -.-_ 030 900.00-_. ..__.. ... _.... 0.15 iit 500.00 - "'"'''l// ' - - 1 0.00 0 200 400 600 800 1000 ,200 1000 1600 I ETM(sec) EXACT PRESSURE/ TIME PLOT SUMMARY I MD(ft) TVD(ft) Pedd(psia) - Pstop(psia) Pexact(psia) _ Mexact(md/cp) 6318.05 6318.05 1044.12 3767.12 3767.14 0.041 CONSTANTS-SPHERICAL FLOW Volume(cc) Rate(cc/sec). Rsnorkel(in) Porosity Ct(1/psia) Flow-line Storage I (fraction) (cc) 3.53 0.83 • 0.66 • 0.25 • 4.22e-006 180.00 TEST CONDITIONS&STATUS I +/-stdev Stability Stability Exposure Time (psia) (psi/min). (deg/min). Pump Status (hr) Tool Face(deg). 32.80 40.01 0.00 REMARKS 111 Tight Test I I I I I 1 Page 10 of 28 I ITest No. 3.1; MD: 6322.08 ft; TVD: 6322.08 ft RDT Test File#2-9.1 Date:13-Feb-12 21:37:04 I F.,45130 00________... 4. .. . 8. --r-t=tittt'.------- = .... .-.._: --. ,__ .-- PRESSURE/TIME 2.-- 1500 0 • - - I • ' i • L 0 100 200. 300 400 700 800 900 1000 I 4500 00 EXACT PRESSURE I TIME f . 1.00 4200.00. 0.90 I 3900 00: 3600 0: f f• -4 1-----.3 Legend 0-90 -Stability Curve 0.70 -Mess PT Rate -Pressure Data -Exact Curve 330000 - --- -. 0 00 Hydrostatic 1 1 I l'a' V Start DO .-------j 0.50 ri: a End OD I . P 3000.011.- ---------r-7--------• F6' g- 4---- 0.40 0 "'Stop M H drostatic 2 2700.0CPY O.- • 240000----------- 0.30 I2100.00 Ai1U20 1 85:0 001dY{- 40141004. 1011018-. T , f f f , -,:: s. 1 00 0.10 0. I 0 100 200 300 400 500 ETIM(sec) 800 700 800 900704 EXACT PRESSURE/ TIME PLOT SUMMARY I MD(ft) 6322.08 TVD(ft) 6322.08 Pedd(psia) 2984.25 Pstop(psia) 3297.20 I Pexact(psia) 3349.18 Mexact(md/cp) 0.021 ., CONSTANTS-SPHERICAL FLOW I Volume(cc) Rate(cc/sec). 0.62 Rsnorkel(in) Porosity(fraction) 0.25 Ct(1/psia) Flow-line Storage 1.09 0.66 3.58e-006 180.00 TEST CONDITIONS&STATUS I +/-stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). • Tool Face(deg). 45.18 215.51 0.00 REMARKS Tight Test I I I I I IPage 11 of 28 I I 1 Test No. 4.1; MD: 6327.07 ft; TVD: 6327.07 ft RDT Test File#2-10.1 Date:13-Feb-12 21:55:33 I PRESSURE/TIME - m 510000 8 _. _ -- - �- _ -.. ._ - - _ /500.0 - ti LL 0 100 200 300 � � - 400 500 600 I5000.00 EXACT PRESSURE/TIME -1.00 4!00.00 -_ -.___._-.___. ___ ..._.................._...... t -0.90 Legend ' 4200.00 0.80 -Starkly Curve - ss PT Rale 7500 0.70 - ePressure Data -Exact 3100,00..... .__.__.._._ ._. .._....-.. �..._-_ .................._..- ._ ......_........ ..... .._....... ......._.`a._.._..._ 0.00 a 0H�oste 1 Curve k 13000 � S V S DD r IEM DD 3000.00-- -. ---- --- 0.50 a =Stop i 2500.00.___....._-_----- - --- -----..---�-. 0.40 1 41Hydoele0c 2 a 2200.00_..________-__ -- -- T.......___.___ i -_ 0.30 I 1900.00^__......_...._.- - ILJ - --_._ 011_------------ .- 0.20 1400.00__. ---_- ._._.._-. n ..._.. ..._.._. .. .. .'- -1 0.10 7'1 1000.00 II i 0 100 200 300 400 500 900 0 .00 ETIM(sec) _ EXACT PRESSURE/ TIME PLOT SUMMARY I MD(ft) TVD(ft) Pedd(psia) Pstop(psia) Pexact(psia) Mexact(md/cp) 6327.07 6327.67 3105.80 3762.75 3762.80 0.156 CONSTANTS-SPHERICAL FLOW I Volume(cc) Rate(cc/sec). Rsnorkel(in) Porosity Ct(1/psia) Flow-line Storage (fraction) (cc) 0.39 0.52 0.66 0.25 2.23e 006 180.00 TEST CONDITIONS&STATUS I +1-stdev Stability Stability Exposure Time (psia) (psi/min). (deg/min). Pump Status (hr). Tool Face(deg). 18.54 42.18 0.00 REMARKS I Valid Test I I I I I IPage 12 of 28 I ITest No. 5.1; MD: 6328.10 ft; TVD: 6328.10 ft RDT Test File#2-11.1 Date:13-Feb-12 22:08:09 I PRESSURE MIME _ __ _ _ 4500 _ _. -_ . ...... _- _-�L _.. ... '�f. - f "0 50 100 150 200 250 300 350 400 I a700.00 EXACT PRESSURE I TIME -2.50 4400.00. ......._.......... ... - ._.-..-... - - - - 2.25 Legene I ._-....__-..____.-.-_ 2.00 -Stability Curve Mees PT Rafe 380000' fs h 1.75 Pressure Dace a1 -Exact Curve 1.50 . 0Hyd osc I alk 7.;3500.00-_._-.-...... -__._...........-__.._-_.-.,.. _._-.....- 1.25 a V Sart DD i ,.- SEM DD m3200.00.._. 1 m 11115100tb 2 $ O 1.00 a` 2900.00'....__........._......_--- 0.75 ' 260000---.-....._.- -- 0.50 2300.00- .' .._.-_ -+ -I.. - - -I 1 - -,-.2 t_ ... .__-.._�1 0.25 zona„ . 11J it ill aL lUlL d illli 1.1,�.,-.1/1111,4lex IA L,A.,rtl181/1I....tu W i -o 000 I 0 60 100 150 200 250 300 350 400 TIM(sec( EXACT PRESSURE/ TIME PLOT SUMMARY I MD(ft) TVD(ft) Pedd(psia) Pstop(psia) I Pexact(psia) Mexact(md/cp) 6328.10 6328.10 3270.52 3756.38 3757.53 0.703 CONSTANTS-SPHERICAL FLOW I (cc) Rate(cc/sec). Rsnorkel(in) Porosity Ct(1/psia) - Flow-line Storage (fraction) (cc) 1.66 1.66 0.66 0.25 7.90e 006 180.00 TEST CONDITIONS&STATUS I +/-stdev Stability Stability Exposure Time (psia) (psi/min). (deg/min). Pump Status (hr). Tool Face(deg). 11.04 78.06 0.00 _ REMARKS ' Valid Test I I I I OPage 13 of 28 k I ITest No. 6.1; MD: 6350.99 ft; TVD: 6350.99 ft RDT Test File#2-13.1 Date:13-Feb-12 22:38:49 U PRESSURE/TIME ^4800 ._ .._ _.... .- 1000. 0 100 200 300 000 500 000 700 800 900 1000 I 4800.00 EXACT PRESSURE I TIME -1.50 4200.00 __ 1.35 Legeed I 3800.0 t. ... ....... 120 Stab,My Curve Mees PT Rate 340000 -- Ir 1.05 -Pressure Data -Exact Curve 0.90 >Hydrostatic 1 I i.,3000.00. .. `. I . AStan DD a oEnd DD 9 0.75 e 2600.Otr 0.60 aHydraatatic 2 ..._.____. a 2200 0o- 0.45 1800 00. .... I 030 t // -�1 0.15 1000.00 II/�'vmigimpt,tsw_ . IS 100 200 300 400 500 000 700 800 900 1000-o W ETNA(4419) EXACT PRESSURE/ TIME PLOT SUMMARY I MD(ft) TVD(ft) Pedd(psia) Pstop(psia) Pexact(psia) 3773.48 Mexact(md/cp) 6350.99 6350.99 2768.16 3773.46 0.218 CONSTANTS-SPHERICAL FLOW Porosity Volume(cc) Rate(cc/sec). Rsnorkel(in) Ct(1/psia) Flow line Storage (fraction) (cc) 0.84 0.37 0.33 0.25 3.59e-006 180.00 TEST CONDITIONS&STATUS I +1-stdev (psia) Stability (psi/min). Stability (deg/min). Exposure Time (hr). Pump Status Tool Face(deg). 17.64 7.07 0.00 REMARKS IValid Test I I I I I IPage 14 of 28 I ITest No. 7.1; MD: 6356.51 ft; TVD: 6356.51 ft RDT Test File#2-14.1 Date:13-Feb-12 22:57:21 I i 5500 ' PRESSUR E/TIME 1 I :-. 4 10001200' • • • • • . 1400 1600 0 800 1 EXACT PRESSURE/TIME 5500 00 -2000 5000 00. 4 t 18 00 1 L egend 16 00 -Stabraly Curve 4500 00, • 1 I --,-- -Maas PT Rate I 40000w__ 14 00 -Pressure Data '.--1 JP k-41 -E x act Curve 12 00 . "Ydr°'tak 1 I ! V Stan OD i 35000S. I 10 00 ,- a End OD I 3000 00- ----------. 800 1 4Hydrostatic 2 ,1 I 2500 00- '11 -,-- 1 600 I 2000 00• I- i 400 i50000' ,i 1 2 00 -1,1 ' 11^1 I 1 000 0 200 400 800 800 ETIM Recl 1000 1200 1400 100. 0 00 EXACT PRESSURE/ TIME PLOT SUMMARY I MD(ft) i 6356.51 1 TVD(ft) 6356.51 Pedd(psia) 2075.24 Pstop(psia) 3784.08 Pexact(psia) 3784.08 Mexact(md/cp) - 3.08 I CONSTANTS-SPHERICAL FLOW I Volume(cc) Rate(cc/sec). Rsnorkel(in) Porosity (fraction) Ct(1/psia) 1.20e-005 Flow-line Storage 28.73 2.87 0.66 0.25 (cc) 180.00 TEST CONDITIONS&STATUS I +1-stdev (psia) Stability (psi/min). Stability (deg/min). Pump Status Exposure Time (hr). Tool Face(deg). 1.86 0.55 0.00 REMARKS IValid Test I I I I I IPage 15 of 28 I I I Test No. 7.1; MD: 6356.51 ft; TVD: 6356.51 ft Bubble Point RDT Test File#2-14.1 Date: 13-Feb-12 22:57:21 PRESSURE/TIME I — e two.. —-- —- — 0 — 9. 200 400 000 800 1000 1200 1400 1800 BUBBLE POINT II• 0-IS 0.09 ------------------------ --- 008 —1- i I 007 , 8 0 06 i t 0 05 I § Nu I . t— : \0 0 03 .-- \ •... 1 ' 0 02 I000 ''' .. .1............. ...... ".'"..**"'""-....-.--‘.."."4"w""`"ItA0--- ,------,----i-- - i • - 1500 1900 2300 2700 3100 3500 3900 4300 4700 5100 Pressure(Bubble Plot 0,a, IBUBBLE POINT SUMMARY MD (ft) TVD (ft) Pressure Bubble Point(psia) Compressibility(1/psia) I6356.51 6356.51 2282.03 7.99e-006 I I I I i I I I IPage 16 of 28 I r . . I t . ITest No. 8.1; MD: 6361.09 ft; TVD: 6361.09 ft RDT Test File#2-15.1 Date:13-Feb-12 23:23:07 I 4700 PRESSURE/TIME ....._..... a _.________________ ____ __.....• .20003 • - - ,T, 0 100 200 • . 300 400 500 800 . . . . 700 800 900 I4700 00 ! ! EXACT PRESSURE/TIME • 1 I .000 i . 1 i . 4400 00. . - I4 I ! • . 1 500 Legend I 4100 00. 3800 oct — . .._ - - —Stability Curve —Meas PT Rate —Pressure Data i•3500 00. 1F-- ___- 4- 4.00 —Exact Curve 3 ou , re Hydrostatic 1 . cl :Start DD .. End DD 0 I,S lop I ,S 3200 00. i • - . 4Hydrostalic 2 294000 2.00 I 260400: . ,.. t - _1 00 2300.00.4—..„, _./ 2000 00-.-- '5b0 I 0 1 , 200 300 400 ETIM 114.) 800 700 800 900 EXACT PRESSURE/ TIME PLOT SUMMARY I MD(ft) 6361.09 TVD(ft) 6361.09 Pedd(psia) 2493.16 Pstop(psia) 3785.90 Pexact(psia) 3785.90 — Mexact(md/cp) 2.92 CONSTANTS-SPHERICAL FLOW Porosity I Volume(cc) Rate(cc/sec). Rsnorkel(in) (fraction) 0.25 Ct(1/psia) Flow-line Storage 29.23 0.98 0.33 1.02e-005 " (a) 180.00 TEST CONDITIONS&STATUS I +1-stdev (psia) Stability (psi/min) . Pump Status • Stability (deg/min). Exposure Time (hr). • Tool Face(deg). 3.42 0.67 0.00 REMARKS IValid Test I I I I I IPage 17 of 28 I I Test No. 9.1; MD: 6365.05 ft; TVD: 6365.05 ft RDT Test File#2-16.1 Date: 13-Feb-12 23:39:07 P PRE85URE I TIME 5000.0 ._. ...... _ _ .. _.._ ‘___ _. �. .. r _.._.. 2900. . - - - --- =, a 0 100 200 300 400 500 600 700 800 900 1000 I 4895.89 t EXACT PRESSURE/TIME -20 00 4395.8' - 18 00 lidLegerU 18.00 -51abiMy Curve 1 40958/ -�- _ ` �.1 -. Meas re Rata 3795.8•- 14.00 -Pressure Date r�r -E�aclCurve 12.00 OSostDelk 1 v i m 3495.8. _.______ -.__ ._ I■,I " i� .__.__ .__._-_ n _Ex4 D a 10.00 a EM DD t 31958• ' aR"Stop a Hydrostatic 2 a I 8.00 2895.8. __ _.......-._..... 8.00 1 25958. ._ -....._-" ""...�....__._.. I 4.00 2295.8. ...... _. ._.. ..__......PI .. _.. _.._._..__.. i 200 J . ' /el I I. ,al 111111. i . �i 1421, /se 1995 89 IT 100 200 300 400 500 800 700 800 900 1000 ETIM 188) EXACT PRESSURE/ TIME PLOT SUMMARY I MD(ft) TVD(ft) Pedd(psia) Pstop(psia) Pexact(psia) 3787.80 Mexact(md/cp) 6365.05 6365.05 2982.21 3787.80 1.43 CONSTANTS-SPHERICAL FLOW p Porosity Volume(cc) Rate(cc/sec). Rsnorkel(in) Ct(1/psia) Flow-line Storage (fraction) (cc) 1.66 0.74 0.33 0.25 6.97e-006 180.00 TEST CONDITIONS&STATUS I +/-stdev Stability (psi/min). Stability (deg/min). Exposure Time (hr). Pump Status Tool Face(deg). (psia) 3.66 0.80 0.00 REMARKS I Valid Test I I I I I IPage 18 of 28 I I Test No. 10.1; MD: 6364.53 ft; TVD: 6364.53 ft RDT Test File#2-17.1 Date:13-Feb-12 23:59:33 _ F PRESSURE/TIME — — 4700.00-_ . .. -f _.. .. ... .— - - - - - - . 0 100 200 300 400 500 500 700 ' 4700... EXACT PRESSURE/TIME 2.50 4400... _.- .._._.._._ -. ......_—__ I __.__._..._.I__— -2.25 II, Legend 4100 n I ._. .._..._._ _ y 2.00 -Stability Curve -Mees PT Rate 3800 — .____. 1.75 -Prouuro Dela -Exact Curve I --_ `1.50 �H7Mostelk 1 3500... .._....-..._......_..__........_....i........ _—__ -- S DD I _..__._...._ I 1.25 iSM DD a Yd top X3200... 1111..-. I._r ......... __...- I f dH rotetk2 00 2800... ...__.......... 0.75 I 2600.0. —}— _.._...__.__.._.. __-._..._._. 1 0.55 2300.0. ........_..... / .... _.. 1 I __. 111 1 __.._I __...._____ 1 0.25 2000 0. Al �1�111' ii..6,A1/I/+..ii—Ill)/ .JIIk,.IJ�I„�a.�.ul1(11'/„4111 ' I 0 100 200 300 400 Soo 600 700 ETIM(sec) EXACT PRESSURE/ TIME PLOT SUMMARY I - MD(ft) _ TVD(ft) Pedd(psia) Pstop(psia) Pexact(psia) Mexact(md/cp) 6364.53 6364.53 2035.14 3785.96 3785.96 1.08 CONSTANTS-SPHERICAL FLOW _ _ I Porosity Volume(cc) Rate(cc/sec). Rsnorkel(in) Ct(1/psia) Flow line Storage (fraction) (cc) 29.74 0.98 0.66 0.25 1.09e-005 180.00 TEST CONDITIONS&STATUS I +1-stdev Stability Stability Exposure Time (psia) (psi/min). (deg/min). Pump Status (hr). Tool Face(deg). 7.90 1.17 0.00 REMARKS IValid Test I I I I I IPage 19 of 28 I I Test No. 11.1; MD: 6370.00 ft; TVD: 6370.00 ft RDT Test File#2-18.1 Date: 14-Feb-12 00:12:47 I PRESSURE r TIME ^45000r _. 22500.rr ei ga 0 50 100 150 200 250 300 350 400 450 500 i EXACT PRESSURE/TIME 4500.r, -2.50 4300.r, 'El legend legend I 4100.Or I. III gall 2.00 -$IaSiliry Curve-Maas PT Rale 3900.Or 1.75 -Preaaure Data �� Mill 3700.,r -Exact Curve 1.50 P Hydrostatic 1 - taDD 1.25 I aIli DESd4"1:: n DD 3300.0, 111111111M21111 3100... I IIII�II� 1.90 i •5p dHydroslatk2 a 3100...-_ ' .I■ 0.75 I 2900.,, 0.50 2700.,,IBEI i II ....._._ ......_.��_ ..._. .._.....Llol 1 0.25 ,, ArIlli iri,Iili�1:1�1i11► �,li , la„r miuiWitrl9W Ail I Illi t iil L' 5000-0.00 I 0 50 100 150 200 250 300 350 400 450 500 ETIM(sec) EXACT PRESSURE/ TIME PLOT SUMMARY I MD(ft) TVD(ft) I Pedd(psia) Pstop(psia) Pexact(psia) Mexact(md/cp) 6370.00 6370.00 2981.56 320:;.92 3212.09 0.713 CONSTANTS-SPHERICAL FLOW I Porosity Volume(cc) Rate(cc/sec). Rsnor.66 (in) Ct(1/psia) - Flow-line Storage (fraction) (cc) 3.86 1.55 0.66 0.25 8.06e 006 180.00 TEST CONDITIONS&STATUS I +/-stdev Stability Stability Exposure Time (psia) (psi/min). (deg/min). Pump Status (hr). Tool Face(deg). 8.53 13.82 0.00 REMARKS ITight Test I I I I I IPage 20 of 28 I I Test No. 12.1; MD: 6376.06 ft; TVD: 6376.06 ft RDT Test File#2-19.1 Date: 14-Feb-12 00:23:36 I PRESSURE/TIME -- - .. . ... -r a 0 50 100 1150 200 250 300 350 400 I 5200.0. NE EXACT PRESSURE I TIME -6.00 4900.01 -__.__._ ___-__-_.+I ............._........— 111 Mil ewd 5.00 l �Dune4800 01 —._.1 ` -S -Maes PT RW -Pronto*Deo 430001 .. d.00 -ExaG Curve V Ratic 1 01.113 I 64000... _ --- _ OEnd DD =11111111111111111111111111111111M 3006-. � nA DD •Stop 3700... ■■ • 3 dRyMoalatb2 li :::: �� 200 I 11, 1.00 2800 O. mm I 1 lhll,l1/1111 Tr," 2500 0.0 11,...0.11011111:11E? 11� Ilil�, limiiiii 1..1.1.,1,Aii1 i,a, I 0 50 100 150 200 250 300 350 � 0.00 ETV sec; EXACT PRESSURE/ TIME PLOT SUMMARY I MD(ft) TVD(ft) Pedd(psia) Pstop(psia) Pexact(psia) 3039.30 Mexact(md/cp) 6376.06 6376.06 2942.31 3037.63 2.11 CONSTANTS-SPHERICAL FLOW Porosity Flow-line Storage I Volume(cc) Rate(cc/sec). Rsnorkel(in) (fraction) Ct(1/psia) (cc) 1.50 0.50 0.33 0.25 2.21e-006 180.00 TEST CONDITIONS&STATUS I +1-stdev Stability Stability Exposure Time (psia) (psi/min). (deg/min). Pump Status (hr). Tool Face(deg). 3.52 13.96 0.00 REMARKS ITight Test I I I I I IPage 21 of 28 I Test No. 13.1; MD: 6356.58 ft; TVD: 6356.58 ft RDT Test File#2-20.1 Date:14-Feb-12 00:35:31 I PRESSURE/TIME ^8000. g. l 10- _._ _. _.. u 0 2000 4000 6000 8000 10000 12000 14000 16000 I EXACT PRESSURE/TIME 6000.0. 1 -6 00 5800.x. __- � ..._—..._—._._ ....._._ _.f .- e0ene 5200...II— __.. _.._ -500 -Meas PT Rate rossuro Data -Esad Curve 48000. —_....._._..... _._ .............. - DHydrostatic 1 -4 V Start DO 4400 0. _—.__...___.._...._-__.-..__..__......__...._� -P -._................_.._ ._. ..._.__..._ .00 MSto DD ^. A •Stop ' 4000.�. --- ..___.............._ ..___ -3.00 a Y4 k 2 dHostet Hydrostatic e IIP m 0800... a I -'---- =2.00 2600 2400..111 i W ..'-- . .._...... .__ -,. I 2000. 0.00 0 2000 4000 6000 8000 10000 12000 14000 , ETIU(sec) _ EXACT PRESSURE/ TIME PLOT SUMMARY I — MD(ft) TVD(ft) _ Pedd(psia) Pstop(psis) 3746.16 I Pexact(psia) Mexact(md/cp) 6356.58 6356.58 2751.20 3746.16 2.38 CONSTANTS-SPHERICAL FLOW I I Volume(cc) Rate(cc/sec). Porosity Flow-line Storage Rsnorkel(in) Ct(1/psia) (fraction) (cc) 29.10 3.76 1.51 0.15 4.87e-005 180.00 TEST CONDITIONS&STATUS I +/-stdev Stability Stability Exposure Time (psia) (psi/min). (deg/min). Pump Status (hr). Tool Face(deg). 4.97 1.61 0.00 REMARKS IValid Test I I I I I IPage 22 of 28 I I ITest No. 13.1; MD: 6356.58 ft; TVD: 6356.58 ft Bubble Point RDT Test File#2-20.1 Date: 14-Feb-12 00:35:31 PRESSURE I TIME / 8. .___._._.—._._.__ m -- • 200011 F _ O: 0 . 2000. 4000 6000 8000 17000 12000 14000 18000 I/ 0.10 _ _ —�—BUBBLE POINT 0.09 —._. -.. ._—_............._.__�_._—_ w..__. _'__._—__— ( 0.08 I 007 s0.06 f_..-....._........_........_.. __...._....._.._— ._..____....._._.._.._.._-._..._-._.__.�_. __._—_. I::I j __ irt, . .. . u003 •-_-- _._.0.02 -- .._. I 0.01 i _. ... _...--"--_--- 0 0 . ,... 2000 2400 2800 3200 3600 4000 4400 4800 5200 5800 IPressure(Bubble Plot psia) BUBBLE POINT SUMMARY MD (ft) TVD (ft) Pressure Bubble Point(psia) Compressibility(1/psia) I6356.58 6356.58 2807.70 1.13e-005 I I I I I I I I IPage 23 of 28 I I ITest No. 13.1; MD: 6356.58 ft; TVD: 6356.58 ft Contamination Analysis RDT Test File#2-20.1 Date:14-Feb-12 00:35:31 1 Contamination Results Depth Calculated Filtrate Value Calculated Clean Fluid Value I I6356.58 ft 1.000 gm/cc 0.895 gm.+cc Calculated Contamination Using Trendline error Using Raw Data Volume based 2.1 % s-,,i 2.000 % -6.8 % Weight based 2.4 % To reach 5.0 %contamination: I You need to pump -Int min Or -21.46 It NALLIBURTON IModeled Data 1.4 T I , f i I 1 , I U 1.2- L..................................... ..............,„,„,,, t X0.8 5 10 15 20 25 30 35 40 45 50 I100 , , , , , 90 I 80- 70- 0 60- I I m 50- 1 j 0 40 1 I 30- fi 20- \C 10 , iltra1�rtt rr1Y1 ,.j.''•v+i;-',4:0 . u4 1,, x it ! l:.' 00 5 10 15 20 25 30 35 40 45 50 Accumulated Volume(It) I I I I Page 24 of 28 I I ITest No. 14.1; MD: 6318.07 ft; TVD: 6318.07 ft RDT Test File#2-21.1 Date:14-Feb-12 04:15:38 PRESSURE/TIME 8. 0 20 40 80 80 100 120 140 160 180 200 EXACT PRESSURE I TIME I 3785 o, u o0 3780.••ill IIIIIMIIMI 00 Lagar 3755... 6 MN III ! --Meas PasPT RRatabe I 3750.•• Ell '111111111111_ -Pressure Data 4.00 -Exact Cum VH 4t0 1 37a5.. Hydrostatic t V Start DD I'M' 3740 aa���d_�1��-1-�� wt,... A End DD i .3735... ��."—■'■_ 3.00 7[SreP C Hldraata0c 2 a. 11. Mil 3730... M 2.00 N NM Ma I/ 3725... 111111=111111_ _ ,-�1 ►'I I 1.00 37211.i.P_________________ ID�� �1Mlirdaltral= - 3715...0 0-0.00 20 s0 80 a0 100 120 140 180 180 200 IE70A(sae) EXACT PRESSURE/ TIME PLOT SUMMARY MD(ft) TVD(ft) Pedd(psia) Pstop(psia) Pexact(psia) Mexact(md/cp) I 6318.07 6318.07 3742.16 3742.52 3742.52 >1530 CONSTANTS-SPHERICAL FLOW Volume(cc) Rate(cc/sec). Rsnorkel(in) Porosity Ct(1/psia) Flow-line Storage I (fraction) (cc) 14.06 • 4.02 1.51 0.15 2.08e-002 180.00 TEST CONDITIONS&STATUS +/-stdev Stability Stability Exposure Time Pump Status Tool Face(deg). (psia) (psi/min). (deg/min). (hr). 0.10 0.95 0.00 REMARKS ILost Seal I I I I I IPage 25 of 28 r I 1 Test No. 15.1; MD: 6317.04 ft; TVD: 6317.04 ft RDT Test File#2-22.1 Date:14-Feb-12 04:19:48 i PRESSURE/TIME 17,-3747 00.. .. ii .00 20 40 00 60 100 1211 140 160 160 200 I3765 01 EXACT PRESSURE!TIME _ 8.00 3765.01Emilie% _-_ -5.00 Legend3760.01 �.-II - - Stability Curve i -Meesnd Ra19 3755.01 _Pren DO DB to _�11119111111111111111111111111.111_ .��__ 4.00 Hydrostatic Cery 3750.11 �Hydrosletk 1 :Stan DD I _ S3.EM DD �3745.11 3.00 13740.11 111111.1111111611:4" II ___ 9H7d OD 2 3735.11II611 -IN 2.00 I 3730.01 It 'uI ,,nnrr r' 7.00 3725.1 ■'11MI ENIV'-� I 3720.1 i 0 0.00 0 20 40 60 BO 100 720 140 760 160 200 E100(MC) EXACT PRESSURE/ TIME PLOT SUMMARY I MD(ft) TVD(ft) Pedd(psia) - Pstop(psia) _ Pexact(psia) Mexact(md/cp) 6317.04 6317.04 3744.90 3745.27 3745.27 >2260 CONSTANTS-SPHERICAL FLOW I Porosity Volume(cc) Rate(cc/sec). Rsnorkel(in) Ct(1/psia) Flow line Storage (fraction) (cc) 13.72 4.23 1.51 0.15 2.17e-002 180.00 TEST CONDITIONS&STATUS I +/-stdev Stability Stability Exposure Time (psia) (psi/min). (deg/min). Pump Status (hr). Tool Face(deg). 0.09 0.95 0.00 REMARKS I Lost Seal I I I 1 I IPage 26 of 28 I II Test No. 16.1; MD: 6326.98 ft; TVD: 6326.98 ft RDT Test File#2-23.1 Date:14-Feb-12 04:30:34 I PRESSURE/TIME ' 4700 0 p2000.,, ___-_� LL 0 200 400 600 800 1000 1200 1400 1600 I 470000 EXACT PRESSURE I TIME I i -4.50 4400.06 ._._._.___.___.__._._.._ _.__.___._ 405 Legend - 3.60 -Stability Curve a100.00:, _........._ ._.._ -Meas PT Rate 3800. / .. 3.15 -Pressure Data -Exact Curve 2.70 "Hydrostatic 1 R 350000--_______..__. ._-._ 9 'Start DD i 'a "End DD 2.25 a Sop y�3200.06 -_ •-- dNyMostatk 2 to 18 8 • 1.80 a 290000 - 1.35 2600.00-._ -- 0.90 2300.00---.-.--- -_ x I I ■ 045 2000,, . .i A ,. i A ,l) I Li ,_. �.t,u�_... .,II -- 0.00 I 0 200 400 900 800 1000 1200 1400 no% ETIM(sac) EXACT PRESSURE/ TIME PLOT SUMMARY I - MD(ft) TVD(ft) Pedd(psia) Pstop(psia) "exact(psia) 3761.36 Mexact(md/cp) 6326.98 6326.98 3083.54 3761.360.745 CONSTANTS-SPHERICAL FLOWI Porosity Volume(cc) Rate(cc/sec). Rsnorkel(in) Ct(1/psia) Flow line Storage (fraction) (cc) 2.36 1.35 1.51 0.15 9.91e-006 180.00 TEST CONDITIONS&STATUS I +1-stdev Stability Stability Exposure Time (psia) (psi/min). (deg/min). Pump Status (hr) Tool Face(deg). 4.49 1.15 0.00 REMARKS IValid Test I I U I I IPage 27 of 28 I 1 Disclaimer DATA, RECOMMENDATIONS, INTERPRETATIONS LIMITATIONS Because of the uncertainty of variable well conditions the necessity of relying on facts and supporting services furnished by others, Halliburton IS UNABLE TO GUARANTEE THE EFFECTIVENESS OF THE PRODUCTS, SUPPLIES OR MATERIALS, NOR THE RESULTS OF ANY TREATMENT OR SERVICE, ' NOR THE ACCURACY OF ANY CHART INTERPRETATION, RESEARCH ANALYSIS,JOB RECOMMENDATION OR OTHER DATA FURNISHED BY Halliburton. Halliburton personnel will use their best efforts in gathering such information and their best judgment in interpreting it, but Customer agrees ' that Halliburton shall not be liable for and Customer SHALL RELEASE, DEFEND AND INDEMNIFY Halliburton against any damages or liability arising from the use of such information even if such damages are contributed to or caused by the negligence,fault or strict liability of Halliburton. 1 1 1 1 1 1 1 1 1 1 1 1 Page 28 of 28 ConocoPhil li s Alaska, Inc. FINAL WELL REPORT MUDLOGGING DATA SHARK TOOTH #1 �x z ' I . • { CANRIG DRILLING TECHNOLOGY LTD. Approved by: David Bannan Compiled by: James Foradas Joshua Dubowski Contributions by: Douglas Waters David Bannan Barry Wright Distribution: April 17, 2012 Date: February 16, 2012 i - t toy 2t�{�2 ConocoPhillips Alaska.Inc. Shark Tooth#1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT& CREW 3 1.1 Equipment Summary 3 1.2 Crew 3 2 WELL DATA 4 2.1 Well Summary 4 2.2 Hole Data 4 2.3 Well Synopsis 5 3 GEOLOGICAL DATA 6 3.1 Formation Tops. 6 3.2 Lithologic Descriptions/Stratigraphy 7 3.3 Sidewall Core Sample Descriptions 13 3.4 Conventional Core Descriptions 14 3.5 Connection Gas Summary. 15 3.6 Trip/Wiper Gas Summary 16 3.7 Sampling Program/Sample Dispatch 19 3.8 Iso-Tube Samples 20 4 PRESSURE/FORMATION STRENGTH DATA 21 4.1 Pore Pressure Gradient Evaluation 21 4.2 Quantitative Methods 22 5 DRILLING DATA 23 5.1 Daily Activity 23 5.2 Survey Data 26 5.3 Bit Record 28 5.4 Mud Record: 29 5.4.1 Mud Record for 13%" Hole 29 5.4.2 Mud Record for 9%" hole 30 5.4.3 Mud Record for Coring to TD, 6'/" hole 31 6 SHOW REPORTS 32 7 DAILY REPORTS 41 Enclosures: 2"/100' Formation Log (MD and TVD) 2"/100' LWD Combo Log (MD and TVD) 2"/100' Drilling Dynamics Log (MD and TVD) 2"/100' Gas Ratio Log (MD and TVD) Final Well Data on CD ROM 2 CANRIG ConocoPhillips Alaska.Inc. Shark Tooth#1 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type/Position Total Comments Downtime Chromatograph malfunction; QGM QGM agitator and gas trap occasionally plugging Ditch gas Flame ionization total gas 24.2 hr in clay zones; QGM and chromatography. replacement; maintenance on generator and Totco. Hook Load, Weight on bit TOTCO WITS Feed* 9 hr Derived from Pump Stroke Mud Flow In 9 hr Rates*and Pump Output Mud Flow Out TOTCO WITS Feed* 9 hr Mudlogging Unit computer HP Compaq Pentium 4 9 hr systems (x2: DML& RigWatch) Mudlogging Unit Acromag In-unit data 9 hr box collection/distribution center Pit Volumes, Pit Gain/Loss TOTCO WITS Feed* 9 hr Pump Pressure TOTCO WITS Feed* 9 hr Pump Strokes TOTCO WITS Feed* 9 hr TOTCO Well Monitoring TOTCO computer networked g hr Components in mud logging unit* Derived from TOTCO depth Rate of Penetration tracking components(block 9 hr height*) RPM TOTCO WITS Feed* 9 hr Torque TOTCO WITS Feed* 9 hr *Drilling data intermittently unavailable due to sporadic interruption of data transmission from rig. 1.2 Crew Unit Number: ML056 Unit Type: Custom/Arctic/Steel Days at Days at Days at Logging Geologist Years of Shark Sample Catchers Years of Shark Technician Shark Experience Tooth Experience Tooth Tooth #1 #1 #1 Joshua Dubowski 4 29 Justin Ashar 1 26 Howard Lamp 1 James Foradas 5 29 Steve Franzen 4 26 3 CANING Conoco✓Phillips Alaska.Inc. Shark Tooth#1 2 WELL DATA 2.1 Well Summary Well: SHARK TOOTH#1 API Index#: 50-103-20647-00-00 Field: Kuparuk River Unit Surface Co-Ordinates: 5925724.2E 1621582.2E Borough: North Slope Primary Targets: Kuparuk sands State: Alaska Primary Target Depth: 6279'MD/-6130'SSTVD Rig Name/Type: Doyon 141/Arctic Triple Primary Actual Depth 6323'MD/-6174'SSTVD Spud Date: January 18, 2012 TD Depth: 6688'MD/-6539'SSTVD TD Date: February 12, 2012 Ground Elevation: 121.4' Days Drilling: 25 KB Elevation: 148.73' Completion Status: Plug and Abandon TD Formation: Miluveach Classification: Exploration Well Days Evaluating: 2 2.2 Hole Data Maximum Depth Mud Shoe Depth Hole MD SSTVD TD Weight Dev. Casing/ MD SSTVD LOT Section (ft) (ft) Formation (ppg) ( inc) Liner (ft) (ft) (ppg) 13W 2603' -2454' Surface 9.5 0.33 6.276" 2597' -2448' 16 _ Casing Point 9'/8" 6254' -6105' Intermediate 10.4 1.11 5.5" 6244' -6095' 16 Casing Point 6%" 6688' -6539' Miluveach 11.2 0.99 3.5" NA* NA* 16 *Well was plugged and abandoned. 4 CANRIG ConocoPhillips Alaska.Inc. Shark Tooth#1 2.3 Well Synopsis Shark Tooth #1 is an exploration well drilled to 6688' MD / -6539' SSTVD targeting the Upper and Lower Kuparuk sands. The well will serve to assess the reservoir potential for both the Upper and Lower Kuparuk as well as overlying deposits in this part of the KRU. The well was spudded in on January 18th, 2012; a directional bit was used to drill Shark Tooth#1 vertically from the conductor to the Surface Casing Point of 2603' MD/-2454' SSTVD. After cementing 10%"casing in place,directional drilling commenced to an intermediate casing point of 6254' MD/-6105' SSTVD. At this point evaluation of the existing borehole commenced with electronic logging. Based on the results of the electronic logging, the wellsite geologists made a decision to obtain up to 32 sidewall cores from selected zones in the Iceberg,Cairn and Bermuda sections. Wellsite geologists,assisted by Canrig logging geologists, conducted preliminary analyses of small chips from selected sidewall core samples on site. The field analysis methods consisted of macroscopic techniques typically used in cuttings analysis(see Sidewall Cores,Section 3.3,below;and Appendix:Show Reports for some examples of results). The core samples were subsequently shipped to ConocoPhillips for further analysis,and intermediate casing was run to 6244' MD/-6095' SSTVD, cemented in place, and tested in preparation for coring. After drilling out of casing, controlled drilling with a 6%"bit proceeded. Drill rates were guided by the wellsite geologist to assure sample quality, and identified a core point TD at 6323' MD/-6174'SSTVD. At this depth wet sample collection ceased. After pulling out of the hole to rig up for coring and a trip in with two core barrels on a coring BHA,coring commenced from 6323'to 6373'MD/-6174'to-6274'SSTVD. During coring, the mudlogging team sampled cuttings and gas chromatography at maximum 15-foot intervals, and also collected Isotubes®at intervals of 30 feet as well as at shows of interest. Coring ceased at 6373' MD after only 50 feet of core(of 120 feet planned). It was decided to pull out of the hole and examine the core,cuttings and other data. Chips were obtained from portions of the conventional core and analyzed using the same field techniques as the sidewall cores in the intermediate section (above). Five Show Reports appended to this report illustrate the field results within the core interval. Based on these analyses the Wellsite Geologist team decided not to obtain a second core, but to drill to TD instead at 6688' MD/-6539' SSTVD. Cuttings samples obtained between 6370'and 6380'MD/-6271'and-6281'SSTVD indicated a high amount of pyrite in shale and possibly pyrite veins present. These may account for problems the coring bit had drilling below this depth. Standard wellsite procedures during this segment of the drilling including cuttings analysis, gas chromatography,and MWD data analysis(gamma ray)indicated that the lower A-sands are poorly developed in this well. This was confirmed by subsequent electronic logging consisting of an RDT log and a wavesonic log. No further coring was recommended at the conclusion of the electronic logging. The well was plugged and abandoned on February 15th, 2012, and the mudlogging unit rigged down on the following day. 5 Cl !NRG ConocoPhillips Alaska.Inc. Shark Tooth#1 3 GEOLOGICAL DATA 3.1 Formation Tops: Prognosed Depth (ft) Actual Depth (ft) Zone or Horizon MD TVD SSTVD MD TVD SSTVD 131/2" Surface Borehole: 10%' Casing Shoe 2,688 2,688 -2,539 2,591 2,591 -2,442 9'/8" Intermediate Borehole: C80 (K10) 2,914 2,914 -2,765 2,910 2,910 -2,761 Camp. Sand (Top) 2,979 2,979 -2,830 2,965 2,965 -2,816 C50 4,024 4,024 -3,875 4,297 4,297 -4,148 C40 4,424 4,424 -4,275 4,659 4,659 -4,510 C37 4,624 4,624 -4,475 4,873 4,873 -4,724 S8 -Top Resevoir 5,559 5,559 -5,410 5,540 5,540 -5,391 C-35 5,699 5,699 -5,550 5,735 5,735 -5,586 HRZ (K-2 marker) 5,876 5,876 -5,727 6,002 6,002 -5,853 Upper Kalubik 6,113 6,113 -5,964 6,130 6,130 -5,981 Lower Kalubik 6,203 6,203 -6,054 6,224 6,224 -6,084 7%" Casing Shoe 6,244 6,244 -6,095 6,254 6,254 -6,105 63/4" Coring Borehole: Top Kuparuk 6,278 6,278 -6,130 6316 6,316 -6,167 Base Kuparuk 6,436 6,436 -6,288 6,435 6,435 -6,286 TD 6,686 6,686 -6,538 6,688 6,687.5 -6,539 Note: Horizons, Zones, and Depths provided by the Wellsite Geologist. 6 CANRIG . . . . Conoco Phillips Alaska,Inc. Shark Tooth#1 3.2 Lithologic Descriptions/Stratigraphv GROUND SURFACE TO SURFACE CASING SHOE: (0' MD/-149'TVDSS to 2604' MD/-2455'TVDSS) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 496 5.4 89.6 315 0.8 0.8 Gas Peaks Depth(MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 2490 315 45379 Gas is generally low in the surface hole. For the purposes of this report the formations in the surface hole are described as a whole. The rocks in this interval are composed of claystone, sands, sandstone and conglomeratic sands. Claystones in this section generally appear below the permafrost, at approximately 1400' MD. A representative claystone sampled between 2300 and 2450' MD was medium gray to dark gray with lighter hues as it dried. The sample was cohesive; very plastic, hydrophilic and somewhat adhesive; clumpy to pasty in consistency; exhibited pulverulent tenacity, especially after drying; had irregular fracture; and massive cuttings habit. Luster was generally dull, becoming microsparkling at higher magnifications. Smooth to gritty textures and massive structure were typical; and cuttings were often impregnated with upper fine to medium sand. The sands were composed of translucent quartz, dark lithics, trace glauconite and other lighter color minerals. A spot sample was collected at 2014'associated with a gas peak. The sample was more arenaceous than was typical in this interval which is increasingly arenaceous with depth. The increased sand may represent a seismic amplitude event predicted in models and possibly associated with a thin sand bed. Rocks in this interval were also non calcareous and interbedded with thin stringers of sands and increasingly sandstone. Sands in this section are common, and generally appear as thin stringers in other rocks or mixed with conglomerates. A sand sampled at 1380— 1470' MD in the transition zone near the base of permafrost was medium gray to dark medium gray with occasional blackish hues. The sand was upper medium to lower coarse grained with lower medium and upper coarse grains common. Grains exhibited moderate to good sphericity; ranged from sub angular to sub rounded to occasionally rounded; and were well to very well sorted. The sands were unconsolidated and overall the sample consisted mainly of clear to translucent to milky white quartz and dark gray to black lithics, giving the sample a salt and pepper appearance. Trace amounts of pyrite and glauconite were present throughout, and clay increased from minor amounts at the top of the interval to substantially higher amounts near the bottom. Impact abrasions, grinding and polishing are common surface features in this sand and there were no hydrocarbon indicators. Sandstone cuttings appear rarely in this section, and only toward the bottom. A sandstone at approximately 2450 to 2500' MD was dark gray with medium and light gray hues as it dried. The framework is predominantly quartz; it is lower medium to lower coarse grained and fair to well sorted. Clasts are angular to rounded with subrounded angularity dominant and exhibit very low to moderate sphericity. Some impact and abrasion features were observed, and polish is common. Rocks are unconsolidated to friable; and grain supported in weak silica cement. Hydrocarbon indicators include no odor, but pale yellow brown fluorescence in some cuttings; and instantaneous pale milky pinkish white cut in some specimens. The sandstones are interbedded with claystones as described above appear to occur as stringers and thin sand beds. 7 CANRIG ConocoPPhillips Alaska.Inc. Shark Tooth#1 Conglomeratic sands are found higher in this section. They generally appear light to medium gray with greenish hues;predominantly upper medium to lower coarse grained with coarser grains very common along with very fine gravels and occasional coarser gravels. The framework is predominantly quartz with common dark lithics giving a salt with pepper appearance to the sands. They are poor to fair sorted with angular to subrounded angularity common and some rounded fragments. Sphericity is low to very low with some clasts having flat oval or elongated forms with rounded ends. Common impact and abrasion surface features are present. The entire sample is unconsolidated. Sands are dominated by white and clear translucent quartz, with yellow quartz and glauconite common,and traces of dark carbonaceous matter. Coarse materials include common fine grained igneous rocks (e.g. quartzite) traces of chert and coarser clasts of the fines. No hydrocarbon indicators are present. SURFACE CASING SHOE TO TOP OF C80(K10): (2604'MD/-2455 TVDSS to 2914'MD/-2765'TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 260 25 161 183 5 50.6 Gas Peaks Depth(MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 2768' 167 34922.180 94.657 Gas is low to moderate in this formation section with one notable peak. This interval consists of claystone. The Claystone is generally medium gray to light medium gray to occasionally dark medium gray. Mushy to pasty with poor to no induration. Pulverulent with earthy fracture and no discernable cuttings habit. Dull to earthy luster, clayey to slightly silty texture and poor to moderate adhesion with good to moderate cohesion. Commonly displays moderate to low hydrophillia, trace amount of unconsolidated sand and a black carbonaceous material. No hydrocarbon indicators. TOP OF C80(K10)TO TOP OF CAMP SAND: (2914' MD/-2765'TVDSS'TO 2979' MD/-2830'TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 214 20 63 47 8 25 Total gas was generally low in this section with no notable gas peaks. No gas peak table provided. This interval generally consists of claystone The claystone is generally medium gray to light medium gray. Commonly displays a clumpy to mushy consistency with poor to no induration. Is typically pulverulent,earthy fracture and a dull to earthy luster. Has a clayey to silty texture with good to moderate cohesion and moderate to good adhesion. Overall it is slightly hydrophillic and expansive with trace amounts of unconsolidated sand and a black carbonaceous material. No hydrocarbon indicators. 8 CANRIG ConocoPhillips Alaska.Inc. Shark Tooth#1 TOP OF CAMPANIAN SAND TO TOP OF C50: (2979'MD/-2830'TVDSS'TO 4024'MD/-3875'TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 248 32 146 70 4 32 Total gas was generally low in this section of the formation with no notable gas peaks. No gas peak table provided. This interval generally consists of primarily unconsolidated sandstone logged as sand. The claystone is commonly dark to medium gray with brownish and lighter gray hues lightening as it dries. Overall it is slightly adhesive and somewhat plastic with a clumpy to curdy consistency. Crumbly to pulverulent tenacity with thin blocky fracture being common throughout the interval. Coarse to medium tabular cuttings habit though amorphous cuttings are still very common. Overall the samples had a dull earthy to microsparkling luster. Sample texture is mostly silty but gritty textures are also common. A well developed thin structure is occasionally observed though uncommon. Occasionally lntergrades with siltstone and trace to common amounts of sand appear to represent thin stringers or locally arenaceous zones. Rare yellow fluorescence is observed on a few of the samples. TOP OF C50 TO TOP OF C40: (4024 MD/-3875'TVDSS TO 4424' MD/-4275'TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 277 39 166 73 5 39 Total gas was generally low in this section of the formation with no notable peaks. No gas peak table provided. This interval is comprised of claystone and siltstone with trace amounts of sand. No hydrocarbon indicators where observed. The claystone is commonly medium gray to light medium gray with slight black and olive hues. It displays a mushy to pasty consistency with poor to no induration. The Samples are predominantly pulverulent with an earthy fracture and an amorphous cuttings habit. Overall the samples have a dull to earthy luster with a clayey to slightly silty texture. Poor to moderate adhesion, good to moderate cohesion and moderate to low hydrophillia; The siltstone displays poor to moderate induration with planar to blocky fracture. It is commonly brittle to crumbly to occasionally tough with platy to tabular cuttings habit and a dull to earthy luster. TOP OF C40 TO TOP OF C37: (4424' MD/-4275'TVDSS TO 4624' MD/-4475'TVDSS) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 223 24 166 157 13 57 Total gas was generally low in this section of the formation with no notable gas peaks. This interval is comprised of claystone, siltstone and trace amounts of sand. 9 CANRIG ConocoPPhillips Alaska.Inc. Shark Tooth#1 The claystone is commonly medium gray to dark medium gray with olive and black hues. The sample displays pasty to mushy to clumpy consistency with poor to no induration and amorphous cuttings habit. It has a dull to earthy luster, irregular to earthy fracture and occasionally blocky. Overall the sample has a silty to clayey to slightly gritty texture with good cohesion, moderate to good adhesion and moderate hydrophillia. The siltstone has moderate induration and planar to blocky fracture. Overall the sample displays crumbly to brittle tenacity and platy to tabular cuttings habit. TOP OF C37 TO TOP OF S8 (TOP OF RESERVOIR): (4624' MD/-4475' TVDSS TO 5559' MD/-5410' TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 231 13 130 1302 4 105 Gas Peaks Depth(MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 4625 161 30296.2 738.7 102.6 4927 1302 218352 12165.8 3646.5 284.2 553.9 73.5 90.5 5381 551 90183.8 6809.8 2568.7 256.5 599.8 62.1 87.3 Total gas was generally moderate to low with a few notable gas peaks. This interval consists of claystone and sand with minor to trace amounts of siltstone and shale. The claystone in this interval is commonly medium gray to light medium gray with occasional olive hues. It typically has poor to no induration, amorphous cuttings habit and a mushy to pasty to clumpy consistency. Overall it displays earthy to blocky to irregular fracture, dull to earthy luster, silty to clayey to slightly gritty texture with good to moderate cohesion and moderate to poor adhesion. The sand in this section is typically light medium gray and unconsolidated. Lower medium to upper fine grained, good to moderate sphericity and sub angular to sub rounded. Well to moderate sorting and dominated by translucent to smokey gray to clear quartz. Fluorescence is uncommon and on individual grains covering about 10%of the samples observed. No other hydrocarbon indicators observed. TOP OF S8 TO TOP OF C-35: (5559' MD/-5410' TVDSS -5699'MD/-5550'TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 89 30 48 250 27 81 Gas Peaks Depth(MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 5559 250 29583.3 2349.7 833.8 57.1 167.5 11.4 18.4 Total gas was generally low in this section with one notable gas peak. This interval consists primarily of sandstone with minor shale. The sandstone in this interval was light gray to medium gray with brownish and black hues; in a 10 CANRIG ConocoPhillips Alaska.Inc. Shark Tooth#1 predominantly quartz, with igneous and other dark lithic framework; lower very fine to upper fine with some coarser grained. Sandstones grains were poor to fair sorted; with subangular to subrounded angularity; and moderate to high sphericity. Surface features included common polish, impact and grinding features. Sandstones were unconsolidated to easily friable forming tabular to nodular cuttings with floating fabric; and a grain supported in silty clay matrix. Occasional zones of yellow fluorescence were observed in most samples but for the most part only a few better indurated cuttings exhibit bright yellow fluorescence and instantaneous pale milky white to bright yellow streaming cut. The sandstones were Interbedded with minor shale as described above. Traces of pyrite, and glauconite were also present in samples. TOP OF C-35 TO TOP OF UPPER KALUBIK: (5699' MD/-5550'TVDSS-6113'MD/-5964'TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 117 22 77 529 4 139 Gas Peaks Depth(MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 5873 162 32388.2 1687.0 605.6 13.5 100.3 5924 184 36693.7 2003.0 764.8 16.5 129.3 5960 420 83341.8 4737.0 1815.3 44.5 340.1 6028 529 100715.3 5865.0 2260.0 63.5 474.2 Total gas was generally moderate to low in this section with a few notable gas peaks. This section is composed mainly of sandstone, siltstone, claystone and shale. The sandstone in this section is light medium gray to medium gray with brown and black hues. It's commonly friable to firmly friable with lower fine to upper very fine to occasionally upper fine grained. Subangular to subrounded to occasionally angular, grain supported in a silty clay matrix and occasionally calcareous. Overall the samples are predominantly made up of clear to translucent to smokey gray quartz with some dark lithics. The Siltstones have moderate induration. The tenacity of the samples vary from dense and firmly friable to moderatley hard to rarely easily friable to brittle. Blocky to planar fracture with tabular to platy to somewhat elongated. Commonly displays Earthy to resinous luster with a silty to gritty texture. The claystones are commonly dark gray to gray black with brownish hues. Samples are typically pasty and very adhesive with a lumpy to clumpy consistency. They're commonly malleable to pulverulent with massive to tabular cuttings habit. Overall they have a dull,earthy luster and become microsparkly with increased light and magnification. Silty texture, increasing silt with depth and are interbedded with dark gray shale and sandstone. The shales in this section are commonly dark gray to very dark gray to black. Overall it has a stiff consistency and a dense to brittle tenacity. Sample displays planar to splintery fracture with platy to flaky cuttings habit and a thin laminar structure. Partially carbonaceous and displays a bright yellow fluorescence. 11 CANRIG Conoc Phillips Alaska,Inc. Shark Tooth#1 TOP OF UPPER KALUBIK TO TOP OF LOWER KALUBIK: (6113'MD/-5964'TVDSS-6203'MD/-6054' TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 108 29 85 411 122 193 Gas Peaks Depth(MD) TG Cl C2 C3 _ iC4 nC4 iC5 nC5 6123 411 79390.503 4816.555 2073.284 81.775 313.645 151.019 153.208 6144 257 49654.847 3083.725 1374.059 40.239 262.245 52.382 53.142 Total gas was generally low to moderate in this section with no notable gas peaks. This section was composed mainly of shale and a minor amount of siltstone. The shale in this interval is commonly dark gray to very dark gray with black and gray hues. They display a stiff to slimy consistency with a dense to crumbly tenacity. The samples typically have blocky to splintery fracture with fine platy to flaky and coarse tabular cuttings habit. They show a dull to resinous luster, smooth to silty texture and have a fine laminar structure. Also are carbonaceous in part and have no hydrocarbon indicators. TOP OF LOWER KALUBIK TO TOP OF KUPARUK: (6203'MD/-6054'TVDSS-6279'MD/-6130'TVDSS) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 100 3 54.9 181 32 89 Total gas was generally low in this section with no notable gas peaks. No gas peak table provided. This section was composed mainly of shale with occasional stingers of siltstone. The shale in this section is commonly dark gray with brownish hues and has a crunchy tenacity. The cuttings habit is mainly planar to splintery to tabular with a dull to sparkling luster and a silty to gritty texture. Overall the sample has a thin structure with siltstone and stringers of siderite and tuff cemented sandstone of quartz and dark lithics. Samples fluoresces yellow in places;oil sheen in 6291'to 6320'samples with trace pyrite and chert. TOP OF KUPARUK TO BASE OF KUPARUK: (6279' MD/-6130'TVDSS -6437'MD/-6288' TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 87 1 28 2255 14 190 Gas Peaks Depth(MD) TG _ Cl C2 C3 iC4 nC4 iC5 nC5 6301 2255 6324 916 6369 550 72958.2 10789.6 4299.3 388.3 768.2 159.2 48.7 12 �+��� \.JOU RIG ConocoPPhillips Alaska,Inc. Shark Tooth#1 Total gas was generally moderate in this section with some noticeable gas peaks. Gas chromatograph malfunctioned so Iso-tubes were taken in place of chromatograph readings. Coring samples done by CPAI and BP geologists BASE OF KUPARUK TO TD: (6437' MD/ -6288' TVDSS—6688' MD/-6539'TVDSS) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 63 19 47 197 41 69 Total gas was very low in this section with no notable gas peaks. No gas peak table provided. This section was composed predominantly by shale and siltstone with minor amounts of sand. The shale in this section is commonly dark medium gray to medium gray with blackish hues with moderate induration and is dense to slightly tough. Commonly platy to tabular to massive cuttings habit with planar to blocky fracture and a dull to sparkly at higher magnifications. The sand in the sample is dominantly clear to translucent quartz with lower to upper fine to commonly upper very fine with some coarser grains and is moderate to well sorted. Commonly subrounded to subangular, moderate to good sphericity and commonly unconsolidated with occasional easily friable to friable sandstone clasts. Overall weak to moderate sample fluorescence decreasing through the interval with no fluorescence seen at the end of the interval. Very faint to no odor on the samples; fluorescence was typically yellow gold being brighter higher up in the interval. Commonly immediate milky cut with a pale yellow residual cut. 3.3 Sidewall Core Sample Descriptions CPAI Shark Tooth#1 Rotary Sidewall Core(Geochem) Chip Descriptions by Doug Waters and Jim Foradas 4 February 2012 4936' MD: Light gray to light brownish gray quartzose sandstone, in part feldspathic with a salt & pepper appearance,darker grains represented by plagioclase,chert and possible hornblende,very fine to upper fine grained, moderate-well sorted,sub angular-subround, moderate spherecity, hard-friable, siliceous cement, moderate intergranular porosity, petroliferous odor, moderate-minor oil staining,abundant bright yellow-gold sample fluorescence(over 80%of sample), instantaneous milky-white to pale blue cut fluorescence, strong residual ring cut fluorescence, no visible cut in plain light. 5390'MD: Light gray to light brownish gray quartzose sandstone, in part feldspathic,possibly tuffaceous,with a salt&pepper appearance, darker grains represented by plagioclase, chert and possible hornblende, very fine to lower fine grained (predominantly very fine grained), moderate -well sorted, subangular-subround, moderate spherecity, hard, siliceous and calcareous cement, moderate-poor intergranular porosity, petroliferous odor,moderate-minor oil staining,abundant bright yellow-gold sample fluorescence(over 80%of sample), immediate milky-white to pale blue cut fluorescence,strong residual ring cut fluorescence, no visible cut in plain light. 5543'MD: Light gray to light brownish gray quartzose sandstone, in part feldspathic,possibly tuffaceous,with a salt&pepper appearance, darker grains represented by plagioclase, chert and possible hornblende, very 13 CANRIG ConocoPhillips Alaska.Inc. Shark Tooth#1 fine to lower fine grained (predominantly very fine grained), moderate -well sorted, subangular-subround, moderate spherecity, hard,siliceous and clay cement,moderate-poor intergranular porosity,faint petroliferous odor, moderate-minor oil staining, abundant bright yellow-gold sample fluorescence (60-70% of sample), immediate milky-white to pale blue cut fluorescence, strong residual ring cut fluorescence, no visible cut in plain light. 5563'MD: Light gray to light brownish gray quartzose sandstone, in part feldspathic,possibly tuffaceous,with a salt&pepper appearance, darker grains represented by plagioclase, chert and possible hornblende, very fine to lower fine grained(predominantly very fine grained),well—moderately sorted, subangular-subround, moderate spherecity, hard,calcareous and clay cement,moderate-poor intergranular porosity(predominantly poor), no petroliferous odor,minor oil staining,dull yellow-gold sample fluorescence with a trace bright spotty yellow-gold sample fluorescence (20-30% of sample), gradual faint pale white-blue cut fluorescence, no residual ring cut fluorescence, no visible cut in plain light. 5664'MD: Light gray to light brownish gray quartzose sandstone, in part feldspathic,possibly tuffaceous,with a salt&pepper appearance, darker grains represented by plagioclase, chert and possible hornblende, very fine to lower fine grained(predominantly very fine grained),well—moderately sorted, subangular-subround, moderate spherecity, hard,siliceous and clay cement, poor porosity, no petroliferous odor, no oil staining, no sample fluorescence, no cut fluorescence, no residual ring cut fluorescence, no visible cut in plain light. 3.4 Conventional Core Descriptions Conventional core descriptions were primarily conducted off site by the Wellsite Geologists and are not included in this report with the exception of show reports appended to this report(see below). 14 CANRIG Conocoi hiiiips Alaska.Inc Shark Tooth#1 3.5 Connection Gas Summary: 1 Unit=200 ppm=0.05% Methane Equivalent Depth (ft) Units Depth (ft) Units Above Above MD/TVD Background MD/TVD Background 1752' 36 6235 43 1938' 11 6270 2921 2216' 44 6373 247 2401' 31 6460 110 2587' 148 6554 436 2715' 13 6646 270 2808' 18 2900 31 2992 20 3178 7 3271 6 3454 37 3549 1 3642 4 3734 4 3827 3 3920 27 4012 4 4104 35 4197 25 4380 35 4472 5 4751 26 4843 19 5032 12 5125 14 5310 37 5402 16 5495 14 5587 151 5679 26 5772 37 5859 6 5958 264 6050 65 6144 165 15 CANRIG ConocoPhillips Alaska.Inc. Shark Tooth#1 3.6 Trip/Wiper Gas Summary 1 Unit=200 ppm=0.05% Methane Equivalent Depth (ft) Trip to (ft) Max. Gas MD/TVD MD/TVD (Units) Comments Drilling of 13W Surface Hole Section 2089' 2089'/2089' 21 Survey gas 2258' 2258'/2258' 2 Survey gas 2401' 2401'/2401' 38 Survey gas 2457' 2457'/2457' 48 Swab 1 stand 2493' 2493'/2493' 253 Swab 1 stand 2586' 2586'/2586' 45 Swab 1 stand After TD of the Surface Hole Section 2604' 1st BU 230 9.45 ppg MW 2604' 2nd BU 190 9.45 ppg MW 2604' 640'/640' 21 TOOH on elevators with drilling BHA. 640' 2600'/2600' 38 TIH on Cleanout Run 2600' 3rd BU 81 9.45 ppg MW 2600' SURFACE 23 POOH on elevators with drilling BHA. SURFACE 2591'/2591' 45 Run 10.75" Casing 2591' BU 53 BU after landing surface casing. 9.45 ppg MW Drilling of 9%" intermediate section before POOH SURFACE 2428'/2428' 7 WOW Circulation Breaks inside casing. 9.25 ppg MW 2428' SURFACE 0 POOH on WOW SURFACE 2600' 2 TIH to tag cement and drill out on Run 300 2623' 2623' 45 CBU after drilling 20' of new hole section 4197' 4197'/4197' 11 CBU before planned short trip 4197' 2560'/2560' 2 R/B 16 stands on Planned short trip 2560' 4197'/4197' 5 RIH after planned short trip 5827' 5827'/5827' 23 CBU at 5827'while pausing to assess weather conditions 5827' 5400'/5400' 19 BROOH 5 stands after drilling to 5827'and pausing to assess weather conditions 5400' 2422'/2422' 16 BROOH one stand per hour and Wait on Weather(WOW); MW 9.25. 2422' 2422'/2422' 7 WOW Circulation Breaks inside casing. 9.25 ppg MW. 2422' 5827'/5827' 2 RIH after release from WOW. 2422' 5827'/5827' 300 At commencement of drilling after RIH after WOW; 10.1 ppg MW. 6253' 6253'/6253' 70 CBU at TD 6253'; MW 10.2. BROOH 5 stands on pumps on wiper trip 6253' 6080'/6080' 68 after drilling to initial Intermediate TD at 6253'; Pump Sweep and weigh up MW from 10.2 to 10.4. 6080' 6253'/6253' 0 RIH 5 stands to initial Intermediate TD at 6253'to drill additional foot; MW 10.4. 16 CANRIG ConocoPhillips Alaska.Inc. Shark Tooth#1 Depth (ft) Trip to(ft) Max. Gas MD/TVD MD/TVD (Units) Comments 6254' 6240/6240 55 CBU Prior to POOH after drilling additional foot to 6254'; MW 10.4. 6240' SURFACE 4 POOH on elevators with drilling BHA. SURFACE SURFACE 0 E-Logging SURFACE SURFACE 0 Sidewall Coring Wiper Trips prior to Running 7%" Casing SURFACE 6254' 2 Clean out string 1st run; RIH 6254' 6254' 182 Clean out string 1st run; CBU; MW 10.5bbl 6254' 4720'/4720' 669 Clean out string 1st run; Maximum wiper gas 4720' SURFACE 170 Clean out string 1st run; pump out of hole 3760' 3760' 27 Clean out string 2nd run; Break circulation 3760' 4720' 0 Clean out string 2nd run; TIH pumps off 4720' 4800' 275 Clean out string 2nd run; CBU 10.4 MW 4800' 6250' 174 Clean out string 2nd run; RIH pumps on 6250' 6250' 134 Clean out string 2nd run; Wiping hole 6250' 3520' 90 Clean out string 2nd run; pump out of hole_ 3520' SURFACE 0 Clean out string 2nd run; POOH on elevators Running 7%" Casing SURFACE 4040' 24 Running casing 4040' 4040' 80 CBU; MW in/out 10.35/10.4bbl 4040' 5410' 36 Running casing 5410' 5410' 102 CBU; MW in/out 10.4/10.35bbl 5410' 6244' 59 Running casing 6244' 6244' 231 CBU at end of casing run; MW in/out 10.35/10.4bbl 6244' 6244' 63 Max gas during cementing 6%" Bottom Hole Section including coring SURFACE 6161' 0 RIH to tag cement 6161' 6254' 20 Drill out shoe track 6274' 6274' 827 BU after FIT 6215' 6262' 3300 CBU; oil in possum belly; MW 10.5 6262' 6291' 294 TIH Prior to coring 6295' 2394 BU Prior to coring; MW 11.0 6373' 6373' 558 CBU after coring; MW 11.2 6373' SURFACE 0 TOOH after coring 6133' 6133' 584 TIH to drill through Coring interval to TD 6133' 6133' 1293 CBU prior to drill through Coring interval; MW 11.2 6273' 6273' 3971 CBU prior to drill through Coring interval; MW 11.2 6273' 6273' 3997 CBU prior to drill through Coring interval; MW 11.2 6273' 6244' Trip to Shoe to wait for Totco repairs 6244' 6323' TIH to Core Point 6323 • 17 CANRIG ConocoPhillips Alaska.Inc. Shark Tooth#1 Depth (ft) Trip to(ft) Max.Gas MD/TVD MD/TVD (Units) Comments 6323' 6373' 510 Drill through Coring interval with new BHA; MW 11.2 6680' 6680' 137 CBU at TD; MW 11.25 6480' 6480' 231 CBU after TD; MW 11.25 6480' 5960' 403 BROOH after TD; MW 11.25 5960' SURFACE 39 POOH; MW 11.25 SURFACE SURFACE 0 E-Logging (RDT) SURFACE 6205' 0 TIH for FIT CBU prior to FIT(monitored on THA—wits 6205' 6205' 3250 down) Gas Cut mud at MW 9.35/11.3 pressurized 6205' 6205' 34 FIT; MW 11.3 6205' SURFACE 0 POOH to R/U for Sonic Logging SURFACE SURFACE 0 E-Logging (Wavesonic) SURFACE 6685' 0 TIH with DP and liner 6685' 6685' 2865 CBU on bottom; MW 11.3 6671' 6671' 76 Cementing 6671' 5728' 42 R/B 10 stands 5728' 5728' 117 CBU after R/B 10 stands; MW 11.3 6012' 6012' 53 CBU after cement cure 18 CANRIG ConocoPPhillips Alaska,Inc. Shark Tooth#1 3.7 Sampling Program/Sample Dispatch Set Type/Purpose Frequency Interval Dispatched To 50 ft 0'to 6000' MD Halliburton Energy Services Washed, screened and dried 6900 Arctic Boulevard (A) for geologic analysis. 10 ft 6373'to 6688' MD Anchorage,AK 99518 Attn: Robert Haverfield 50 ft 0'to 6000' MD Halliburton Energy Services (B), Washed, screened and dried 10 ft 6373'to 6688' MD 6900 Arctic Boulevard for geologic analysis. Anchorage,AK 99518 Attn: Robert Haverfield 50 ft 0'to 6000' MD Halliburton Energy Services (C), Washed, screened and dried 10 ft 6373'to 6688' MD 6900 Arctic Boulevard for geologic analysis. Anchorage,AK 99518 Attn: Robert Haverfield 50 ft 0'to 6000' MD Halliburton Energy Services (D)2 Wet, unwashed bagged for 10 ft 6000'to 6250' MD 6900 Arctic Boulevard geologic analysis. Anchorage,AK 99518 Attn: Robert Haverfield Isotech Laboratories, Inc. 0'to 6000' MD CPAI samples, contact: 500 ft (E)3 Isotubes 30 ft 6373'to 6688' MD Albert Holba 1308 Parkland Court Champaign, IL 61821 (F)4 Core Fluid 15 ft 6323'to 6373' MD Wellsite Geologists and at TD (6688' MD) 1. Sets A-C are composed of four blue plastic 50-sample vial storage boxes each. All were shipped in the same box. 2. Set D is composed of individually labeled Whir/pak®bags shipped in four separate boxes marked with depth ranges 0-1900, 1900-4200, 4200-5550, and 5550-6250, respectively. 3. Set E is composed of individually labeled Isotubes in two approved containers for air transport of UN2037 materials. 4. Samples collected by Canrig and the Mud Engineer as directed by the Wellsite Geologist. These samples were hand delivered to the Wellsite Geologists for analysis off site by Schlumberger. 19 CANRIG ConocoPhillips Alaska.Inc Shark Tooth#1 3.8 Iso-Tube Samples No. D(MD) TG Cl C2 C3 iC4 nC4 IC5 nC5 1 500 1 2 1549 31 4873 _ 3 1745 250 28854 4 2000 62 10280 5 2500 164 24072 6 3000 41 7505 7 3500 29 5157.657 8 4002 31 5739.112 9 4924 1300 328805.1 18330.12 5509.17 433.47 844.83 112.77 138.09 10 5000 65 10837.89 723.9712 246.45 10.63 53.27 0 11 5379 534 12 5480 46 6274.433 576.6464 219.85 9.79 74.51 0 13 5510 35 4621.802 429.4449 178.90 14.92 35.32 0 14 5525 246 15 5536 209 32683.87 2460.281 949.13 99.60 226.11 14.45 16 5569 144 17 5580 245 34275.51 3746.046 1430.12 142.33 373.79 51.90 18 5600 75 10243.08 1062.209 522.55 60.08 85.14 0 19 5630 78 10153.77 952.78 510.815 63.52 179.41 12.92 20 5660 40 21 5972 245 22 6019 514 97843.21 5928.9 0 0 490.23 23 6249 104 24 6271 37 25 6274 765 26 6291 1055 27 6294 371 28 6304 422 29 6315 1746 -- 30 6315 3000 31 6317 334 32 6322 2256 34 6335 40 35 6347 70 36 6350 24 37 6353 78 10902.31 1210.006 490.0 0 80.3 0 38 6357 501 64168.69 10012.5 4047.3 374.7 734.6 145.5 39 6365 362 48652.84 6440.141 2483.1 212.9 428.9 99.1 40 6372 46 5994.494 686.3549 391.1 54.9 115.4 16.0 41 6373 3997 493465.3 162802.3 57989.1 4847.8 9760.8 1811.4 42 6380 145 43 6410 147 44 6440 87 45 6470 60 46 6500 80 47 6553 503 48 6687 134 20 CANRIG ± N .2 E 0 0 0 0 0 0 0 0 0 0 \ / A A ƒ A A A ƒ ƒ ƒ 2 c 0 0 (9 0 0 0 0 0 0 0 \ _ _ _ m m I m CO CO CO R = w § \ LU LU > LU LU 0 w / / (-) �� I- w w L LU w w 2 Ui UJw k § C. $ @ ƒ + + % f r § . 0) ® = o \ 2 0 ' a) o Tr r k 0. 2 a \ \ co co / \ / \ 2 \ ® ® k 00 0 a e a w w b b a b o a) ƒ 1- > ^ = CO ¥ w w m CD CD CO / e ■ ¥ = co N Cr \ m = 0 = ca) CO 9 9 @ 7 7 9 9 9 9 \ 7 F » =\@ _ " t o> # E \ c �� \ J % ^ -a) % % % $ $ ® k \ \ f / 0} o > \ = o Tr co m = '— N m c O J �. (f) � e � N N Tr # t m r Q CD CO ^�} § k 8\ = ^ $ N N N d 0 ® Co ¢ CV 0) 9 ' co $ CD G N N 2 0 ff � 4 � / / _ c0 _e ■ o + / oo + o + + / oS / o + o / o / , , ca « = o _ _o o_ No Nonoo 0 no0N0N0 0 � 2o = I kk � 0 0 u) cn co0cI0 = U) IeC) 0U) OU) I / \ � \ F- c ■ � n m \ n \ m \ = m = \ = n \ m \ q \ m 0 = 00 0 o ® m m m m n m m m = 01- W k Cu g N_ \ \ / / \ o o o 0 0 Z c § o@ R i- e e e ' _ — n co = m m 0 0 I I 0 4 -I 0 0 0 0 0 ® ® & 0 >, o U. E Cu CO w k ¥ 4 c c C) Ce 02 cn $ -o La La To To $ to 2k cm w k ..o Lo 2 ? r-- co q E $ / \ ± 2 Ce o £ S k 0 0 0 J k 2 2 . II 41) / C2 L O C o ¥ 11Oil 4 4 a0 ƒ E § ConocoPhillips Alaska.Inc. Shark Tooth#1 4.2 Quantitative Methods The primary indicators used for PPG evaluation were gas trends relative to mud weight(MVV)and effective circulating density(ECD), including increases in background gas(BG),appearance and trends of connection gas (CG), and magnitudes of trip gas(TG)and wiper gas (WG). Regional pore pressure trends from sonic data, provided by ConocoPhillips, and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Canrig Drilling Technology LTD,and then modified using the indicators described above, DXC and resistivity(RES)data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD—(0.6-((.001*TLGSU) + (0.05*DX))) The formula has certain limitations,such that it does not allow for a PPG more than 1 ppg less than the ECD, and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However,the formula proved useful in helping formulate a PPG range,when estimating trends, as with DXC data, with data points in shale intervals. 22 CANRIG ConocoPhillips Alaska,Inc. Shark Tooth#1 5 DRILLING DATA 5.1 Daily Activity January 18,2012 Wait on weather, drilled out conductor and 5 new feet. Displaced to spud mud. Drill to 225' and POOH for drilling BHA. P/U BHA and resume spud. January 19, 2012 Drilled from 271' MD to 1752' MD. January 20,2012 Drilled from 1752' MD to TD at 2603' MD. CBU, POOH on elevators. RIH to bottom. Circulating and conditioning mud. January 21, 2012 POOH, UD BHA and rig up to run casing. Run to bottom with casing and prep to pump cement. January 22,2012 Finish pumping cement. N/D Diverter and N/U BOP stack. Testing BOP's. January 23, 2012 Finish testing BOP's and rig down test equipment. Begin making up BHA, UD BHA due to cold weather. M/U mule shoe and RIH to 2409'and circulate till weather clears. January 24,2012 Continued circulating while waiting on weather. January 25, 2012 Continued circulating while waiting on weather. January 26, 2012 Continued circulating while waiting on weather. January 27, 2012 Continued circulating while waiting on weather. January 28, 2012 POOH with mule shoe. LID BHA and R/U BOP testing equipment and test BOP's. M/U new BHA and run in hole to 2472'and test casing to 3000 PSI for 30 minutes. Drill out float,cement and 20'of new hole. Perform FIT to 16 ppg. Drill ahead from 2823'. January 29, 2012 Drilled from 2808 to 4197'. Short trip to 2530'. RIH and continued drilling to 4516' January 30, 2012 Drilled from 4516 to 5827'. Stop drilling due to weather. Rack back one stand per hour at 360 GPM,50 RPM and reciprocate from 5827'to 5370'. 23 CANRIG ConocoPPhillips Alaska,Inc. Shark Tooth#1 January 31, 2012 Circulating while back reaming out of hole at 1 stand per hour and waiting on weather.- February 1, 2012 BROOH to 2903'. CBU 2X. Pump out of hole to 2533 and CBU 2X. Slip and cut drill line while monitoring the hole on the trip tank and waiting on weather. February 2, 2012 Continue Waiting on weather. RIH and Resume drilling from 5827'to 6254'. CBU and weigh up mud to 10.4 ppg. POOH on elevators and L/D BHA. February 3,2012 Continue L/D BHA,Test BOP. R/D test equipment. M/U wave sonic BHA. RIH with wave sonic tool and log out of hole at 30 fpm. L/D wave sonic BHA. M/U side core tool on e-line and test. February 4, 2012 M/U side core logging tools on e-line. RIH with e-line to perform side wall coring. POOH w/e-line and L/D BHA. M/U clean out assembly and RIH. Pump hi-vis sweep. With sweep approximately 400'up annulus, lost circulation. Slowed pumps to mitigate losses from 300 GPM to 85 GPM while rotating and reciprocating. Loss rate slowed from 100 BPH to 50 BPH. Shut down pump, keep string moving and monitor well. Observed slight loss, continued to circulate at 1 BPM on up stroke, S/O pump off, 2 BPM on up stroke, S/O pump off, stage pump up with minimal returns. Pump out of hole,torqued up and packed off several times through HRZ from 6130' to 6000'. Slowed rate and worked string through tight spots. Circulate and reciprocate string, obtain loss rate at 20 BPH. February 5, 2012 Monitor well(slight flow). POOH from 5448'to 2577'. Monitor(slight flow). P/U 30'with no pumps, observe slight flow. Slack off 30' observe fluid drop. Continue POOH from 2577' to 1550'. Pump bit balling pill (no increase in cuttings). Monitor (slight flow). Pump out of hole to 630'. Monitor well intill static. Well still swabbing, pump out of hole . poull last stand on elevators. P/U and pull stabilizer to floor(packed off) L/D same, P/U and clean off bit(packed off). Monitor well(static)RIH w/o stabilizer to 4697'filling every 20 stands. Fill pipe and CBU,work string from 4700'to 4790'. Hole taken approx 20 bbl to obtain returns and giving 20 bbl. Gain with pumps off. Continue RIH from 4787'to 5809' and CBU. February 6,2012 Wash and ream from 5902' to 6254'. Circulate and condition hole. POOH to 2390' and monitor (static). Continue to POOH on elevators to 502'. Monitor well(static). Rack back BHA and drain stack. Close blind rams. M/U test plug and test upper rams. R/D test equipment and R/U casing equipment. RIH to 2560'with 7 5/8" casing. February 7, 2012 Stage in hole with 7 5/8"casing to 6244'. Pump cement and rig down casing equipment. L/D landing joint, flush out flutes on hanger, set packoff, run in LDS and test 7 5/8"X10'/"packoff to 5000 PSI for 10 minutes. R/U to L/D 5"drill pipe. Laying down 5"drill pipe. February 8,2012 Continue L/D 5"drill pipe. Slip and cut drill line. Change out rams and test. R/D test equipment. M/U BHA and single in to hold with 4"drill pipe to 6085'filling every 20 stands Conditioning mud.. February 9,2012 Circulate and condition mud from 10.3 to 10.5 ppg. R/U to test casing. Test to 3000 PSI for 30 minutes. R/D test equipment. Drill out shoe track and CBU. Displace to coring fluid and drill 20' of new hole. CBU and perform FIT. Drill from 6254'to 6323'and CBU. Weigh up mud to 10.8 due to connection gas. Monitor hole (static). CBU and rack back stand. Monitor well (static). POOH 24 CANRIG ConocoPPhillips Alaska.Inc. Shark Tooth#1 February 10,2012 L/D BHA, R/U to test BOP and test BOP. R/D test equipment. P/U core equipment and RIH filling every 20 stands. Begin coring February 11, 2012 Cored to 6373' and pulled out due to no penetration. POOH to 5888' and monitor(static). POOH on elevators to 3631'pulling stands at control rate as per well plan. L/D core barrels, inspected bit and discovered a piece of core sticking out of bit. Removed core from bit and L/D core barrels. 42' of 50' cored recovered. P/U BHA.. February 12,2012 Continue P/U BHA and RIH. RIH to 6180 and CBU getting back 3991 units of gas. Mad pass from 6255' to 6372'. Tight spot from 6350'to 6372'. Drill ahead to TD at 6688'. Circulating. February 13, 2012 CBU two times and monitor hole(static). Pump out to shoe and CBU. Continue pumping out to 4772 due to thick mud and swabbing. POOH on elevators with proper hole fill. R/U E-line and begin RDT logging.. February 14, 2012 L/D wire line and P/U mule shoe. TIH to 6205 and CBU. Continue to circulate to get gas out. . Performed FIT to 13.5 ppg. POOH to run wavesonic logs February 15,2012 RIH with cement string. CBU and pumped cement. WOC and circulating. February 16, 2012 WOC and circulating. DML Unit released at 0630 hours. 25 CANRIG ConocoPhiOips Alaska.Inc. Shark Tooth#1 5.2 Survey Data Measured True Vertical Latitude Departure Dogleg Depth Inclination Azimuth Vertical Section N(+)/S(-) E(+)/W(-) Rate (feet) (degrees) (degrees) Depth (feet) (feet) (feet) (°/100ft) (feet) 26.48 0 0 26.48 0 0.00N 0.00E TIE-IN 170.72 0.14 255.79 170.72 -0.04 0.04S 0.17W 0.1 _227.65 0.14 267.97 227.65 -0.06 0.06S 0.30W 0.05 321.88 0.19 244.22 321.88 -0.13 0.13S 0.55W 0.09 412.61_ 0.4 252.79 412.6 -0.29 0.29S 0.99W 0.24 2.4 4 0 0.25 231.02 502.44 -0.51 0.51S 1.44W 0.21 594.55_ 0.17 254.42 594.55 -0.67 0.67S 1.73W 0.13 689.25 0.25 261.18 689.25 -0.74 0.74S 2.07W 0.08 782.08 0.35 239.73 782.07 -0.92 0.92S 2.52W 0.16 871.55 0.31 233.16 871.55 -1.2 1.20S 2.95W 0.06 965.48 0.28 229.02 965.47 -1.5 1.50S 3.32W 0.04 1055.35 0.38 219.53 1055.34 -1.87 1.87S 3.67W 0.13 1149.41 0.62 236.32 1149.39 -2.39 2.39S 4.29W 0.3 1241.88 0.31 205.58 1241.87 -2.89 2.89S 4.82W 0.42 1335.56 0.25 207.44 1335.54 -3.3 3.30S 5.02W 0.06 1428.99 1.11 62.58 1428.97 -3.07 3.07S 4.31W 1.42 1520.85 1.37 57.69 1520.81 -2.07 2.07S 2.59W 0.3 1615.86 1.25 57.24 1615.79 -0.91 0.91S 0.76W 0.12 1707.43_ 1.38 58.44 1707.33 0.21 0.21N 1.02E 0.15 1799.84 1.3 61.15 1799.73 1.3 1.30N 2.88E 0.11 1891.52 0.09 139.83 1891.39 1.75 1.75N 3.84E 1.4 1982.24 0.14 150.99 1982.12 1.6 1.60N 3.93E 0.06 2074.01 0.33 137.83 2073.88 1.3 1.30N 4.17E 0.22 _2168.92 0.43 128.1 2168.79 0.88 0.88N 4.63E 0.12 2261.24 0.44 166.18 2261.11 0.32 0.32N 4.99E 0.31 _2. 353.83 0.41 171.2 2353.7 -0.35 0.35S 5.13E 0.05 2446.8 0.25 164.19 2446.66 -0.88 0.88S 5.23E 0.18 2539.21 0.33 184.63 2539.07 -1.35 1.35S 5.27E 0.14 _ 2635.37 0.33 178.87 2635.24 -1.9 1.90S 5.25E 0.03 _2727.64 0.25 168.31 2727.5 -2.37 2.37S 5.30E 0.1 2818.25 0.36 153.19 2818.11 -2.82 2.82S 5.47E 0.15 2910.37 0.45 163.52 2910.22 -3.42 3.42S 5.70E 0.12 3005.24 0.4 164.32 3005.09 -4.09 4.09S 5.89E 0.05 3099.74 0.36 153.1 3099.59 -4.67 4.67S 6.11E 0.09 3190.89 0.31 153.28 3190.74 -5.15 5.15S 6.36E 0.05 3280.53 0.17 170.04 3280.38 -5.5 5.50S 6.49E 0.17 3377.56 0.62 344.28 3377.41 -5.15 5.15S 6.37E 0.82 3467.67 1.2 349.92 3467.51 -3.75 3.75S 6.08E 0.65 ___3563.31 1.05 341.1 3563.13 -1.94 1.94S 5.62E 0.24 3654.81 1.06 337.12 3654.61 -0.36 0.36S 5.02E 0.08 3747.6 1.15 338.63 3747.39 1.3 1.30N 4.34E 0.1 3840.74 0.57 319.38 3840.51 2.52 2.52N 3.70E 0.69 26 CANRIG Conoco`Phillips Alaska,Inc. Shark Tooth#1 Measured True Vertical Latitude Departure Dogleg Depth Inclination Azimuth Vertical Section N(+)/S(-) E(+)/W(-) Rate (feet) (degrees)) (degrees) Depth (feet) (feet) (feet) (°/100ft) (feet) 3934.26 0.57 292.6 3934.03 3.05 3.05N 2.97E 0.28 4026.95 0.62 289.77 4026.71 3.39 3.39N 2.08E 0.06 4119.45 0.62 299.25 4119.21 3.81 3.81N 1.17E 0.11 4211.33 0.56 290.97 4211.09 4.21 4.21N 0.32E 0.11 4302.97 0.53 297.63 4302.72 4.56 4.56N 0.47W 0.07 4397.5 0.48 293.24 4397.24 4.92 4.92N 1.22W 0.07 4485.84 0.31 291.35 4485.58 5.16 5.16N 1.79W 0.19 4581.57 0.74 200.51 4581.31 4.67 4.67N 2.25W 0.85 4671.16 1.37 186.9 4670.88 3.06 3.06N 2.58W 0.75 4765.76 1.43 189.58 4765.45 0.78 0.78N 2.92W 0.09 4765.76 1.43 189.58 4765.45 0.78 0.78N 2.92W 0.09 4859.98 1.42 162.54 4859.65 -1.5 1.50S 2.76W 0.71 4951.05 1.54 147.68 4950.69 -3.61 3.61S 1.77W 0.44 5038.56 0.52 154.41 5038.19 -4.97 4.97S 0.96W 1.17 5136.65 0.2 129.07 5136.28 -5.48 5.48S 0.64W 0.36 5321.24 0.14 139.72 5320.86 -5.85 5.85S 0.25W 0.04 5415.29 0.12 125.67 5414.91 -5.99 5.99S 0.10W 0.04 5508.79 0.2 121.6 5508.41 -6.14 6.14S 0.12E 0.08 5601.23 0.22 110.4 5600.85 -6.28 6.28S 0.42E 0.05 5692.99 0.31 119.81 5692.61 -6.47 6.47S 0.80E 0.1 5783.06 0.2 138.09 5782.68 -6.7 6.70S 1.12E 0.15 5874.46 0.06 143.11 5874.08 -6.86 6.86S 1.25E 0.15 5971.4 0 43.11 5971.02 -6.9 6.90S 1.28E 0.06 6065.33 0.09 141.83 6064.95 -6.95 6.95S 1.33E 0.09 6157.63 0.09 174.14 6157.25 -7.08 7.08S 1.38E 0.05 6297.04 1.11 0.01 6296.65 -5.83 5.83S 1.39E 0.86 6357.47 1.52 19.36 6357.06 -4.49 4.49S 1.65E 0.99 6451.56 1.44 25.76 6451.12 -2.25 2.25S 2.58E 0.19 6544.41 0.74 11.45 6543.96 -0.61 0.61S 3.21E 0.8 6639.31 1.19 30.02 6638.84 0.85 0.85N 3.82E 0.57 6678.1 0.99 11.59 6677.62 1.52 1.52N 4.09E 1.03 6688.0 0.99 11.59 6687.52 1.69 1.69N 4.12E 0.02 27 CANT IG . . . . . . . . . . co 2 � < \ O \ � 22 \ f \ f , / I 2 = _ E _ < � CD- o z0 , x _CI / �12 �12 \ / \ 2 / - p \ f / w \ k kk / � » \ \ = ._ 2 E < < / Lo co k & # / Z Z ® / ® la $ .- co co c) c) $ o c .— CV n 7 _ Vm n I' # # n Cr) = C CV \ CO CO / / / co 0 « # r n °c / \ co / \ CO / / q 6.2 o c �a xcoNQIN- ¥ N- + C) 4 \ mak = z $ Nl- Q ® N- G ¥ < < � G < m ao a " / wax ¥ kN 22A � z X 0} ` k n � - o - ted = 0 0 0 ^�{ § k 0 2 > 8, __. .1 r) 0) a) r-% « < N ® - 0 J § q q b 2 2 2 \ \ m • Z Q G 0 E / \ = _ . o_ 2 o .cNc 1— z — x x 7% \ 22 0_ =± 215 _ k © t ,- it , to = > c 2 41 4 � � GCL � � = � 17EEo m c k 2 1>,>< col- w ic8 k s = t , 0 k k \ ¢ ¢ \ \ in ._ -0 ° -0a) 22E = sa Erc o qo no 0077 27 / C)5 inc § c ko # o # 0 oo 2 '- 2 (N 2n # La2 = 2 ¥ 2 = o � b 2277 mz = z = 2 2z = 2 = 2 = 2 &'b = z ill ■ re _ _ CCD _ _ _ _ _ _ _ _ = omu) 2 iii . 2r ccct 2t: ccEtzw zcc 2cc \ 2 0c000 2I & r 0 m q U) a) (N • 0 N o o o o o o N N � ✓• £ r- co ..a- V' r- r- ui c a) a 0 E - 0 0 0 0 0 0 0 0 0 0 o N (3 84' 28228888 C � 1— E .„3 . 0 7O 2 75 5: O J X LI) In I"- O CO CO O CA V 1- O. 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Shark Tooth#1 CANRIG Core #1 Hydrocarbon Show Report # 1 Operator: ConocoPhillips/BP Exploration(Alaska) Well: SHARK TOOTH#1 API Number:50-103-20647-00:00 Field: KUPARUK Date: 10-Feb-12 Rig: DOYON 141 Time: 17:31 County: NORTH SLOPE BORROUGH Depth Start �� _ End State: ALASKA 6323 MD 6327 MD _ Country: USA 6323 TVD 6327 TVo Averages Before During After Maximum Pixley Plot ROP(fph) 6.00 10.85 17.55 18.00 10000 WOB 9.50 6.20 7.50 10.00 RPM_ 59.00 68.00 68.00 68.00 , - Mud Weight 11.00 10.90 11.00 11.00 • DRY GAS: Chloride 32,000.00 32,000.00 32,000.00 32,000.00 •'GAS Total Gas 113.83— 111.03 105.67 174.64 C1 (ppm) 18,688.75 17,818.48 16,569.55 29,316.740 _. ••' C2(ppm) 1,586.78 1,622.48 1,615.46 2,316.78 ' NON PRODUCTIVE C3(PPM) 843.82 886.75 904.66_ 1,194.34 1 —- ---- - C4(ppm) 336.92 358.70 370.04 469.58 c c2 °..a -as '.. C5(ppm) 97.28 126.51 150.51 99.49 Lithology Fine to medium,occasional coarse sandstone,mostly siderite cemented zones and loose grains. Quartz some glauconite,and some dark lithics. Sub ang to sub rnd.moderately sorted. Patchy blobs of black viscous oil 20-30%. Splinters of black Kalubik shale. Debris of bag fragments and metal shavings in sample. Cuttings Analysis Odor I Faint Fluorescence Cut FluorescenceR esidual Cut Typeammedi Stain Amount 50% ate Amount Bright Amount NA Distribution!Even Intensity Bright Color;Yellow/White Color NA Intensity Color Milky Residual Fluorescence Cut Color Yellow/gold Intesity Color M/dk Brown Color Show Rating Good Free Oil in Mud 20-30% Comments Lithology described by J.Goyette,D. Bannan, R.Bailey.and N.Landi. Gas Chromatography and Drilling Dynamics data provided by Canrig. Report by: J. Foradas 33 LAIVKILi Conoco Phillips Alaska.Inc. Shark Tooth#1 CANRIG Core #1 Hydrocarbon Show Report # 2 Operator: ConocoPhillips/BP Exploration(Alaska) Well: SHARK TOOTH#1 API Number:50-103-20647-00-00 Field: KUPARUK Date: 10-Feb-12 Rig: DOYON 141 Time: 19:17 County: NORTH SLOPE BORROUGH Depth Start End State: ALASKA 6327 MD 6335 MD Country: USA 6327 TVD 6335 TVD Averages Before During After Maximum Pixier Plot ROP(fph) _ 10.85 2.69 2.47 17.55 moo WOB 6.20 _ 8.10 9.10 8.6 • RPM 68.00 68.00 68.00 68.00 moo , Mud Weight 11.00 10.90 11.10 11.00 DRY GAS Chloride 32,000.00 32,000.00 32,000.00 32,000.00 *+in, s I TE i Total Gas 111.03 44.35 40.158 105.67 , Cl (ppm) 17,818.48 2,471.87 2,301.95 16,569.55 10. I�..- .- . C2(ppm) _1,622.48 328.07 281.97 1,615.46_ .. NON PRODUCTIVE , _ C3(ppm) 886.75 206.66 180.40 904.66 C4(ppm) 358.70 84.41 70.06 370.04 C u I CC3 C,u c,Gf C5(ppm) 126.51 51.58 42.82 150.51 Lithology fine to very fine sandstone,quartz, some chert and some lithics trace glauconite. Mostly loose grains. Sub angular to sub rnd,moderate sorted, evenly dispersed black viscous oil 30-40%. Kalubik shale fragments. Debris of bag fragments and metal shavings in sample. Cuttings Analysis Odor !Faint Fluorescence Cut Fluorescence Residual Cut Stain Amount.50% Type Immediate Amount Bright Amount None Distribution Intensity.Bright Color Yellow/White Color NA IntensityColor Milky Residual Fluorescence Cut Color Yellow/gold-LL Intesity Color1M/dk Brown Color Show Rating Strong Free Oil in Mud 30-40% Comments Lithology described by J. Goyette, D. Bannan, R. Bailey,and N. Landi. Gas Chromatography and Drilling Dynamics data provided by Canrig. Report by: J. Foradas ConocoPhillips Alaska,Inc. Shark Tooth #1 CANRIG Core #1 Hydrocarbon Show Report # 3 Operator: ConocoPhillips/BP Exploration (Alaska) Well: SHARK TOOTH#1 API Number:50-103-20647-00-00 Field: KUPARUK Date: 11-Feb-12 Rig: DOYON 141 Time: 3:11 County: NORTH SLOPE BORROUGH Depth Start End State: ALASKA 6335 MD i 6350 MD Country: USA 6335 TVD 6350 TVD Averages Before During After Maximum Pixley Plot ROP(fph) 10.85 2.69 2.47 2.57 10000 , WOB 6.20 8.10 9.10 11.4 1 RPM 68.00 68.00 68.00 68.00 r I Mud Weight 11.00 11.10 11.20 11.20 DRY GAS Chloride 32,000.00 32.000.00 i 32.000.00 32,000.00SA.•--GAS R �1 , -. '••CON NTE • ^* Total Gas 44.35 23.747 28.648 40.16 r Cl (ppm) 2,471.87 3,049.77 3,600.92 2,301.95 '4,41 C2(ppm) 328.07 _ 209.25 286.17 281.97 I NON PRODUCTIVE C3(ppm) 206.66 129.54 162.16_, 180.40 ' --- C4(Ppm) 84.41 1.3.45 i 21.63 70.06 C,C2 ,,2,c, +u C5(ppm) 51.58 1.88 3.03 42.82 Lithology Fine to very fine sand, dominantly quartz. sub rnd. loose grains, sloughing of both C-sand and Kalubik shale(with abundant pyrite also long fragments). Much less of the black viscous oil 15-25%. Cuttings Analysis Odor None/Faint Fluorescence Cut Fluorescence Residual Cut Stain Amount Type Fast Amount Bright Amount None Distribution Spotty Intensity Bright Color Yellow Color NA Intensity _ Color Milky Residual Fluorescence Cut _ Color Pale Yellow Intesity Color Med. Brown Color! Show Rating Good Free Oil in Mud 15-25% Comments Lithology described by J. Goyette. D. Bannan. R. Bailey, and N. Landi. Gas Chromatography and Drilling Dynamics data provided by Canrig. Report by: J. Foradas ConocoPhillips Alaska,Inc. Shark Tooth#1 CANRIG Core #1 Hydrocarbon Show Report # 4 Operator: ConocoPhillips/BP Exploration(Alaska) Well: SHARK TOOTH#1 API Number:50-103-20647-00-00 Field: KUPARUK Date: 11-Feb-12 Rig: DOYON 141 Time: 6:10 County: NORTH SLOPE BORROUGH Depth Start_ _ End State: ALASKA 6350 MD 6365M -_.-. Country: USA 6350 TVD j 6365 TVD Averages Before During After Maximum Pixier Plot ROP(fph) 10.85 2.69 2.47 21.17 10000 WOB 6.20 8.10 9.10 11.4 RPM 68.00 68.00 68.00 68.00 tow Mud Weight 11.20 11.20 11.20 11.20bRY GAS ' Chloride 32,000.00 32,000.00 32,000.00 32,000.00 � -- Total Gas 23.747 388.852 354.096 550.19 C1 (ppm) 3,049.77 52,948.48 48,652.84 72,958.20 10 .OIL --... C2(ppm) 209.25 7,142.09 6,440.14 10,789.60 NON PRODUCTIVE C3(ppm) 129.54 2,770.11 2,483.15 4,299.33 C4(ppm) 13.45 719.70 641.90 1,156.55 a c c3 .. .. C5(ppm) 1.88 187.68 , 179.65 207.96 Lithology Fine to very fine sandstone, mostly quartz some lithics, sub ang to sub rnd,mod sorted,consolidated zones of grains that are dark almost black oil staining,also light brown stained aggregates. Very little of the viscous oil. Occasional small flat pieces of shale. Cuttings Analysis Odor ,None/Faint Fluorescence Cut Fluorescence Residual Cut Stain Amount Type Fast Amount Bright Amount Strong Distribution Intensity,Bright Color Yellow Color Black/Brown Intensity Color Milky Residual Fluorescence Cut Color Pale Yellow Intesity ColoriMed. Brown Color Show Rating Free Oil in Mud Little Comments Lithology described by J. Goyette, D. Bannan, R. Bailey, and N. Landi. Gas Chromatography and Drilling Dynamics data provided by Canrig. Report by: J. Foradas ConocoPhillips Shark Tooth Tooth #1 CANRIG Core #1 Hydrocarbon Show Report # 5 Operator: ConocoPhillips/BP Exploration (Alaska) Well: SHARK TOOTH#1 API Number:50-103-20647-00-00 Field: KUPARUK Date: 11-Feb-12 Rig: DOYON 141 Time: 6:41 County: NORTH SLOPE BORROUGH Depth 'Start lEnd State: ALASKA 6365 mo 6371 MD Country: USA 6365 TVD 6371 TVD Averages Before During After Maximum Pixler Plot ROP(fph) 2.69 7.30 1.52 21.24 ow WOB 8.10 12.00 12.20 11.7 RPM 68.00- 68.00 , 68.00 68.00 'No , Mud Weight 11.20 11.20 11.20 11.20 - P.o .-0".RY GAS - Chloride 32,000 32,000 32,000 j 32.000 , .-• GAS .- - 100' .••.• ---'4-7" Total Gas 23.75F 208.001 86.001 388.85 Cl (ppm) 3049.77 28307.90 5994.50, 52948.48 lo• .------•- --- * --' C2(ppm) 209.25' 3693.20 686.40 7142.09 -- NON PRODUCTIVE C3(ppm) 129.54 1516.301 391.20 2770.11 , C4(ppm) 13.45 440.40 170.40 719.70 . .5 C5(ppm) 1.88. 105.20 25.80! 187.68 Lithology Fine to very fine sandstone with some coarser grains, dominatley quartz with some lithics. Subangular to subrounded and moderatly sorted. Some consolidated zones of grains that aredark almost blackoil staining. incrasing amounts of light brown stained aggregates. Black viscous oil blobs, minor small flat, grey, shale pieces. Cuttings Anal isis Odor faint Fluorescence Cut Fluorescence Residual Cut Stain Amount Type'fast-instanl Amount Amount 70% Distribution even Intensity mod-brigh; Coloribright yel gold Color black brown Intensity mod-bright Color opaque Residual Fluorescence Cut Color yellow gold Intesity Color med brown Color Show Rating Show Free Oil in Mud yes Comments Lithology described by J. Goyette, D. Bannan. R. Bailey, and N. Landi. Gas Chromatography and Drilling Dynamics data provided by Canrig. Report by: J. Dubowski ConocoPhillips A?1,-;',;1 -.1-- Shark Tooth .1--DhorhTomth #1 CANIN��N��N���N�~� Sidewall Core #1 Hydrocarbon Show Report # 1 operator: ConocoPhillips/BP Exploration (Alaska) Well: SHARK TOOTH API Number: Field: KUPARUK Date: 30'jan'12 Rig: _ DOYON 141 — Time:_ 4:50 County: NORTH SLOPE BORROUGH Depth Start End ,State: ALASKA «Su6mo 4936 MD _ Country: USA I 493�rvu 4y3e-rvn--- Averages Before During After Maximum Pixler Plot ROP(fph) 14520 | l . |V }B 2.90 ! /RPM ! 8-i3V =°� .- ---- -- ' '^|Mud Weight 9.80 ' ^ - DM'GAS '' Chloride 400 — u '� '...' �xs Total Gas I 250.181 ___ Cl (ppm) 6282848 � � °^~-_.__��''__._''' �n 3572.29 ''' | / NON -- - PRODUCTIVE ] C3(ppm) ' ' _- . , " " C4(ppm) 256.30' "" ~ ~° C5(ppm) l 42.93 Lithology Light gray to light brownish gray quartzose sandstone, in pail feldspathic with a salt& pepper appearance.darker grains represented by plagioclase.chert and possible hornblende.very fine to upper fine grained, moderate well sorted, nvhangv|a,yvb'oond, mode,atoophe,enity. hard-friable. siliceous cement, moderate intergranular porosity, petroliferous odor. moderate-minor oil staining, abundant bright yellow-gold sample fluorescence (over 8Ov6o/uamp|o}. instantaneous milky-white to pale blue cut fluorescence. strong residual ring cut fluorescence, no visible Cut in plain light. Cuttings Analysis Odor mod-faint Fluorescence Cut Fluorescence Residual Cut _ Stain Amount "80m Type Amount Amount mod-minor Distribution'even Intensity pale Color gold Color _ Intensity bright _. Color blue Residual Fluorescence Cut Color Intesity Color mlkywhpale blue Color Show Rating Free Oil in Mud Comments Lithology described by D. Waters. Gas Chromatography and Drilling Dynamics data provided by Canrig. Report by: J. Dubowski ConocoPhillips Alaska.Inc. Shark Tooth #1 CANRIG Sidewall Core #1 Hydrocarbon Show Report # 2 Operator: ConocoPhillips/BP Exploration (Alaska) Well: SHARK TOOTH#1 API Number:50-103-20647-00.00 Field: KUPARUK Date: 30-Jan-12 Rig: DOYON 141 Time: 10:31 County: NORTH SLOPE BORROUGH Depth Start 'End State: ALASKA5390 MD _ 5390 MD Country: USA 5390 TVD 5390 TVD Averages Before During After Maximum Pixler Plot ROP(fph) 197.46 ' I I WOB 6.70 RPM 101.00 1 Mud Weight 10.10 Div GASChloride 45.0 ""' DENSATE Total Gas 186.66 Cl (ppm) 23724.38 _ .. •--- -- C2(ppm) 1606.59 NON PRODUCTIVE C3(ppm) 523.07 C4(ppm) 168.46 , 2 3 4 c�O cIA:3 c'.c. CMS C5(ppm) 18.93 _ Lithology Light gray to light brownish gray quartzose sandstone. in part feldspathic. possibly tuffaceous.with a salt &pepper appearance. darker grains represented by plagioclase,chert and possible hornblende, very fine to lower fine grained (predominantly very fine grained), moderate -well sorted, subangular-subround, moderate spherecity, hard, siliceous and calcareous cement, moderate-poor intergranular porosity, petroliferous odor, moderate-minor oil staining. abundant bright yellow-gold sample fluorescence(over 80%of sample), immediate milky-white to pale blue cut fluorescence, strong residual ring cut fluorescence. no visible Cut in plain light. Cuttings Analysis Odor ;mod-faint Fluorescence Cut Fluorescence Residual Cut Stain Amount >80% Type immediate Amount strong Amount mod-minor Distribution even Intensity pale Color gold _ Color Intensity bright Coloriblue Residual Fluorescence Cut Color yellow-gold Intesity Color mlkywht- pale blue Color Show Rating Free Oil in Mud Comments Lithology described by D. Waters. Gas Chromatography and Drilling Dynamics data provided by Canrig. Report by: J. Dubowski ConocoPhillips Alaska,Inc. Shark Tooth #1 BRIG Sidewall Core #1 Hydrocarbon Show Report # 3 Operator: ConocoPhillips/BP Exploration (Alaska) Well: SHARK TOOTH#1 API Number:50-103-20647-00-00 Field: KUPARUK Date: 30-Jan-12 Rig: DOYON 141 Time: 13:07 County: NORTH SLOPE BORROUGH Depth Start End State: ALASKA 5543 MD 5543 MD Country: USA 5543 TVD 5543 Tvc Averages Before During After Maximum Pixley Plot ROP(fph) 46.03 ,moo r _ WOB 5.30 RPM 103.00 _ woo Mud Weight 10 10 _ • Chloride 450 ORY GAS ••'AS - - € 1" I NSATE Total Gas 152.361 Cl (ppm) 23943.44 ••---• 1 C2(ppm) — 1757.66 _ i NON PRODUCTIVE I C3(ppm) 646.47 a C4(ppm) 209.91' C,C2 ,,,, «• C1,5 C5(ppm) 14.54 Lithology Light gray to light brownish gray quartzose sandstone. in part feldspathic. possibly tuffaceous. with a salt &pepper appearance. darker grains represented by plagioclase, chert and possible hornblende. very fine to lower fine grained (predominantly very fine grained), moderate -well sorted, subangular-subround, moderate spherecity, hard. siliceous and clay cement. moderate-poor intergranular porosity. faint petroliferous odor. moderate-minor oil staining. abundant bright yellow-gold sample fluorescence(60- 70%of sample). immediate milky-white to pale blue cut fluorescence. strong residual ring cut fluorescence. no visible cut in plain light. Cuttings Analysis Odor faint Fluorescence Cut Fluorescence Residual Cut Stain Amount 60-70% Type immediate Amount strong Amount mod-minor Distribution even _ Intensity pale Color gold Color Intensity bright Color blue Residual Fluorescence Cut Color yellow-gold lntesity Color mlkywht- pale blue Color Show Rating Free Oil in Mud Comments Lithology described by D. Waters. Gas Chromatography and Drilling Dynamics data provided by Canrig. Report by: J. Dubowski ConocoPhillips Alaska.Inc. Shark Tooth#1 7 DAILY REPORTS 41 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: Guy Whitlock Robert Wall Date: 1/18/2012 Time: 00:01 Current Depth (MD): 271' Current Current Depth271' Operations: Drilling (TVD): 24 hr Footage (MD): 196' Drilling Parameters ROP: Current: 86 Max: 212 Torque: Current: 1081 Max: 1650 WOB: Current 5.5 Max: 11 RPM: Current: 55 Max: 55 PP: Current: 1140 Max: 1169 Lag: Strokes: 333 Time: 2.6 Surf-Surf: Strokes: 358 Time: 2.8 ECD: Current: Max: Mud Properties @ 21:30 MW: 8.9 FV: 423 PV: 27 YP: 84 FL: Nc Gels: 37/414/49 Sol: 2 pH: 9.5 Cr 600 Ca++: 160 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 1 Max: 2 Depth (MD/TVD): Avg BG : 1 Gas Events Depth (MD/TVD) Cl C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG Cl C2 C3 C41 C4N C51 C5N 1 500/500 1 Lithologies: Current: Conglomeritic sand 70%sand 20%clay 10% Last 24 hrs: Conglomeritic sand 70%sand 20%clay 10% Operational Summary: Wait on weather, drilled out conductor and 5 new feet. Displaced to spud mud. Drill to 225' and POOH for drilling BHA. P/U BHA and resume spud. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $5,485.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: Guy Whitlock Robert Wall Date: 1/19/2012 Time: 00:01 Current Depth (MD): 1752' Current Current Depth1746" Operations: Drilling (TVD): 24 hr Footage (MD): 1481' Drilling Parameters ROP: Current: 91 Max: 161 Torque: Current: 1386 Max: 3292 WOB: Current 4.4 Max: 28 RPM: Current: 103 Max: 103 PP: Current: 1904 Max: 1972 Lag: Strokes: 2573 Time: 16.7 Surf-Surf: Strokes: 2725 Time: 17.7 ECD: Current: Max: Mud Properties @ 21:00 MW: 9.3 FV: 260 PV: 42 YP: 48 FL: 6 Gels: 22/38/44 Sol: 8 pH: 9.5 Cr 450 Ca++: 32 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 121 Max: 267 Depth (MD/TVD): 1745'/1741' Avg BG : 45 Gas Events Depth (MD/TVD) Cl C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG Cl C2 C3 C41 C4N C51 C5N 2 1549/1545 31 4873 3 1745/1739 250 28854 Lithologies: Current: Claystone 70%, sand 30% Last 24 hrs: Conglomeritic sand 40%sand 30%clay 30% Operational Summary: Drilled from 271' MD to 1752' MD Calibrations: None. Failures: Integrator malfunctioning Daily Cost: $3,235.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: Guy Whitlock Robert Wall Date: 1/20/2012 Time: 00:01 Current Depth (MD): 2603' Current Circulate and Current Depth 2603' Operations: conditioning (TVD): 24 hr Footage (MD): 851' Drilling Parameters ROP: Current: 0 Max: 163 Torque: Current: 0 Max: 2798 WOB: Current 0 Max: 27 RPM: Current: 0 Max: 113 PP: Current: 0 Max: 2273 Lag: Strokes: 3862 Time: 25 Surf-Surf: Strokes: 4088 Time: 26.5 ECD: Current: Max: Mud Properties @ 21:00 MW: 9.5 FV: 250 PV: 48 YP: 59 FL: 5.8 Gels: 25/33/42 Sol: 8.2 pH: 8.7 CI 550 Ca++: 40 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 329 Depth (MD/TVD): 2493/2493 Avg BG : 45 Gas Events Depth (MD/TVD) Cl C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG Cl C2 C3 C41 C4N C51 C5N 4 2000/2000 62 10280 5 2500/2500 164 24072 Lithologies: Current: none Last 24 hrs: Claystone 80%sand 20% Operational Summary: Drilled from 1752' MD to TD at 2603' MD. CBU, POOH on elevators. RIH to bottom. Circulating and conditioning mud. Calibrations: Chromatograph. Failures: None Daily Cost: $3,235.00 Total Cost: $11,955.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: Guy Whitlock Robert Wall Date: 1/21/2012 Time: 00:01 Current Depth (MD): 2603' Current Current Depth2603' Operations: Pumping Cement (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 23:30 Pit 6 MW: 9.3 FV: 58 PV: 26 YP: 13 FL: 8.4 Gels: 3/5/8 Sol: 8 pH: 7.9 Cr 500 Ca++: 40 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 20 Gas Events Depth (MD/TVD) Mud Weight (ppg) Gas (units) Trip Gas 2603 9.5+ 57 Connection Gases Gas Samples No. Depth (MD/TVD) TG Cl C2 C3 C41 C4N C51 C5N Lithologies: Current: none Last 24 hrs: none Operational Summary: POOH, UD BHA and rig up to run casing. Run to bottom with casing and prep to pump cement. Calibrations: Chromatograph. Failures: None Daily Cost:$3,235.00 Total Cost: $15,190.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: Guy Whitlock Robert Wall Date: 1/22/2012 Time: 00:01 Current Depth (MD): 2603' Current Current Depth2603' Operations: Testing BOP's (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 20:00 Pit 6 MW: 9.6 FV: 51 PV: 10 YP: 15 FL: 6.6 Gels: 7/8/11 Sol: 8 pH: 9.6 Cr 200 Ca++: 40 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) Mud Weight(ppg) Gas (units) Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG Cl C2 C3 C41 C4N C51 C5N Lithologies: Current: none Last 24 hrs: none Operational Summary: Finish pumping cement. N/D Diverter and N/U BOP stack. Testing BOP's Calibrations: None Failures: None Daily Cost: $3,235.00 Total Cost: $18,425.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: Guy Whitlock Robert Wall Date: 1/23/2012 Time: 00:01 Current Depth (MD): 2603' Current Current Depth2603' Operations: Waiting on weather (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: , Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 20:00 Pit 6 MW: 9.6 FV: 53 PV: 8 YP: 24 FL: 6.4 Gels: 11/12/13 Sol: 8 pH: 9.6 Cr 200 Ca" 40 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) Mud Weight (ppg) Gas (units) Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG Cl C2 C3 C41 C4N C51 C5N Lithologies: Current: none Last 24 hrs: none Finish testing BOP's and rig down test equipment. Begin making up BHA, L/D Operational Summary: BHA due to cold weather. M/U mule shoe and RIH to 2409' and circulate till weather clears. Calibrations: None Failures: None Daily Cost: $3,235.00 Total Cost: $21,660.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: G. Whitlock P. Archey Date: 1/24/2012 Time: 00:01 Current Depth (MD): 2603' Current Current Depth2603' Operations: Waiting on weather (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 21:00 Pit 5 MW: 9.2 FV: 44 PV: 26 YP: 13 FL: 8.4 Gels: 3/5/8 Sol: 7.2 pH: 7.9 CI' 500 Ca++: 40 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) Mud Weight(ppg) Gas (units) Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG Cl C2 C3 C41 C4N C51 C5N Lithologies: Current: none Last 24 hrs: none Operational Summary: Continued circulating while waiting on weather Calibrations: None Failures: None Daily Cost:$3,235.00 Total Cost: $24,895.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: G. Whitlock P. Archey Date: 1/25/2012 Time: 00:01 Current Depth (MD): 2603' Current Current Depth2603' Operations: Waiting on weather (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 21:00 Pit 5 MW: 9.2 FV: 42 PV: _26 YP: 13 FL: 8.4 Gels: 3/5/8 Sol: 7.2 pH: 7.9 Cr 500 Ca++: 40 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) Mud Weight (ppg) Gas (units) Trip Gas • Connection Gases Gas Samples No. Depth (MD/TVD) TG Cl C2 C3 C41 C4N C51 C5N Lithologies: Current: none Last 24 hrs: none Operational Summary: Continued circulating while waiting on weather Calibrations: None Failures: None Daily Cost: $3,235.00 Total Cost: $28,130.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: G. Whitlock P. Archey Date: 1/26/2012 Time: 00:01 Current Depth (MD): 2603' Current Current Depth2603' Operations: Waiting on weather (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 21:00 Pit 5 MW: 9.1 FV: 42 PV: 13 YP: 2 FL: 10.2 Gels: 1/2/2 Sol: 5.7 pH: 8.4 Cr 500 Ca++: 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) Mud Weight (ppg) Gas (units) Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG Cl C2 C3 C41 C4N C51 C5N Lithologies: Current: none Last 24 hrs: none Operational Summary: Continued circulating while waiting on weather Calibrations: None Failures: None Daily Cost: $3,235.00 Total Cost: $31,365.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: G. Whitlock P. Archey Date: 1/27/2012 Time: 00:01 Current Depth (MD): 2603' Current Current Depth2603' Operations: Waiting on weather (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 21:00 Pit 5 MW: 9.1 FV: 41 PV: 13 YP: 2 FL: 10.2 Gels: 1/2/2 Sol: 5.7 pH: 8.4 Cr 500 Ca++: 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) Mud Weight (ppg) Gas (units) Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG Cl C2 C3 C41 C4N C51 C5N Lithologies: Current: none Last 24 hrs: none Operational Summary: Continued circulating while waiting on weather Calibrations: None Failures: None Daily Cost:$3,235.00 Total Cost: $34,600.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: G. Whitlock P. Archey Date: 1/28/2012 Time: 00:01 Current Depth (MD): 2808' Current Current Depth2808' Operations: Drilling (TVD): 24 hr Footage (MD): 205 Drilling Parameters ROP: Current: 70 Max: 235 Torque: Current: 1871 Max: 3548 WOB: Current 4.5 Max: 8 RPM: Current: 93 Max: 98 PP: Current: 1221 Max: 2126 Lag: Strokes: 2366 Time: 16.5 Surf-Surf: Strokes: 2604 Time: 18 ECD: Current: Max: Mud Properties @ 21:00 Pit 5 MW: 9.6 FV: 56 PV: 7 YP: 26 FL: 6.5 Gels: 8/8/9 Sol: 5 pH: 9.8 Cl- 300 Ca++: 40 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 47 Max: 183 Depth (MD/TVD): 2712'/2712' Avg BG : 50 Gas Events Depth (MD/TVD) Mud Weight (ppg) Gas (units) Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG Cl C2 C3 C4I C4N C5l C5N Lithologies: Current: 90% Claystone, 10%sand Last 24 hrs: 90% Claystone, 10%sand POOH with mule shoe. L/D BHA and R/U BOP testing equipment and test BOP's. Operational Summary: M/U new BHA and run in hole to 2472' and test casing to 3000 PSI for 30 minutes. Drill out float, cement and 20' of new hole. Perform FIT to 16 ppg. Drill ahead from 2823'. Calibrations: Chromatograph Failures: Replaced QGM in possum belly. Daily Cost:$3,235.00 Total Cost: $37,835.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: G. Whitlock P. Archey Date: 1/29/2012 Time: 00:01 Current Depth (MD): 4516' Current Current Depth4516' Operations: Drilling (TVD): 24 hr Footage (MD): 1708' Drilling Parameters ROP: Current: 148 Max: 277 Torque: Current: 2189 Max: 4087 WOB: Current 5.2 Max: 25 RPM: Current: 100 Max: 106 PP: Current: 1872 Max: 2237 Lag: Strokes: 3557 Time: 23.2 Surf-Surf: Strokes: 3943 Time: 25.8 ECD: Current: Max: Mud Properties @ 21:00 MW: 9.6 FV: 49 PV: 11 YP: 21 FL: 5.6 Gels: 8/10/11 Sol: 8 pH: 9.6 Cr 400 Ca++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 35 Max: 84 Depth (MD/TVD): 2825 Avg BG : 45 Gas Events Depth (MD/TVD) Mud Weight (ppg) Gas (units) Trip Gas 4197' 9.6 83 2900 9.6 31 2992 9.6 20 3454 9.6 37 Connection Gases 3920 9.6 27 4104 9.6 35 4197 9.6 25 4380 9.6 35 Gas Samples No. Depth (MD/TVD) TG Cl C2 C3 C41 C4N C51 C5N 6 3000 41 7505 7 3500 29 5157.657 8 4002 31 5739.112 Lithologies: Current: 60% Claystone, 30%siltstone, 10% sand Last 24 hrs: 70% Claystone, 20%siltstone, 10% sand Operational Summary: Drilled from 2808 to 4197'. Short trip to 2530'. RIH and continued drilling to 4516' Calibrations: None Failures: None Daily Cost:$3,235.00 Total Cost: $41,070.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: G. Whitlock P. Archey Date: 1/30/2012 Time: 00:01 Current Depth (MD): 5827' Current Circulating, waiting on Current Depth 5827' Operations: weather (TVD): 24 hr Footage (MD): 1311' Drilling Parameters ROP: Current: 0 Max: 227 Torque: Current: 1237 Max: 4992 WOB: _Current 0 Max: 11 RPM: Current: 8 Max: 108 PP: Current: 632 Max: 2655 Lag: Strokes: 4466 Time: 29.2 Surf-Surf: Strokes: 4965 Time: 32.5 ECD: Current: Max: Mud Properties @ 21:00 MW: 10.1 FV: 42 PV: 10 YP: 25 FL: 4 Gels: 6/9/10 Sol: 9.5 pH: 9.6 CI' 400 Ca`+: 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data FDitch Gas: Current: 9 Max: 1325 Depth (MD/TVD): 4927' Avg BG : 94 Gas Events Gas above Depth (MD/TVD) Mud Weight (ppg) background _ (units) Trip Gas 4751 9.6 26 4843 9.6 19 Connection Gases 5310 9.6 37 5587 9.6 151 5679 9.6 26 5772 9.6 37 Gas Samples No. Depth TG Cl C2 C3 C41 C4N C51 C5N (MD/TVD) 9 4924 1300 328805.1 18330.12 5509.17 433.4724 844.8302 112.7799 138.0996 10 5000 65 10837.89 723.9712 246.4503 10.6315 53.2712 0 11 5379 534 12 5480 46 6274.433 576.6464 219.8583 9.791 74.5105 0 13 5510 35 4621.802 429.4449 178.9007 14.9291 35.324 0 14 5525 246 15 5536 209 32683.87 2460.281 949.1339 99.6082 226.1153 14.4588 16 5569 144 17 5580 245 34275.51 3746.046 1430.112 142.3333 373.797 51.9089 18 5600 75 10243.08 1062.209 522.5554 60.0803 85.1475 0 19 5630 78 10153.77 952.7891 510.815 63.5288 179.4198 12.9226 20 5660 40 CANRIG 21 5690 39 4992.47 339.2763 225.0357 37.0152 114.613 15.9148 Lithologies: Current: 30% Claystone, 20%siltstone, 40% sand, 10% shale Last 24 hrs: 50% Claystone, 30%siltstone, 20% sand Operational Summary: Drilled from 4516 to 5827'. Stop drilling due to weather. Rack back one stand per hour at 360 GPM, 50 RPM and reciprocate from 5827' to 5370'. Calibrations: None Failures: None Daily Cost:$3,235.00 Total Cost: $44,305.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: G. Whitlock P. Archey Date: 1/31/2012 Time: 00:01 Current Depth (MD): 5827' Current Current Depth5827' Operations: Waiting on weather (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: 4466 Time: 29.2 Surf-Surf: Strokes: 4965 Time: 32.5 ECD: Current: Max: Mud Properties @ 21:00 MW: 10.1 FV: 47 PV: 10 YP: 22 FL: 4 Gels: 5/5/5 Sol: 10 pH: 9.3 CI 450 Ca" 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: 17 Depth (MD/TVD): Avg BG : 9 Gas Events Gas above Depth (MD/TVD) Mud Weight (ppg) background (units) Trip Gas Connection Gases Gas Samples No. Depth TG Cl C2 C3 C41 C4N C51 C5N (MD/TVD) • • Lithologies: Current: Last 24 hrs: Operational Summary: Circulating while back reaming out of hole at 1 stand per hour and waiting on weather.- Calibrations: None Failures: None Daily Cost: $3,235.00 Total Cost: $47,540.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: L. Hill P. Archey Date: 2/1/2012 Time: 00:01 Current Depth (MD): 5827' Current Current Depth5827' Operations: Waiting on weather (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: _ Lag: Strokes: 4466 Time: 29.2 _Surf Surf: Strokes: 4965 Time: 32.5 ECD: Current: Max: Mud Properties @ 21:00 MW: 10.1 FV: 46 PV: 12 YP: 28 FL: 4 Gels: 9/15/18 Sol: 10 pH: 9.6 CI' 400 Ca" 40 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Gas above Depth (MD/TVD) Mud Weight (ppg) background (units) Trip Gas Connection Gases Gas Samples No. Depth TG Cl C2 C3 C4l C4N C51 C5N (MD/TVD) Lithologies: Current: Last 24 hrs: Operational Summary: BROOH to 2903'. CBU 2X. Pump out of hole to 2533 and CBU 2X. Slip and cut drill line while monitoring the hole on the trip tank and waiting on weather. Calibrations: None Failures: None Daily Cost:$3,235.00 Total Cost: $50,775.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: L. Hill P. Archey Date: 2/2/2012 Time: 00:01 Current Depth (MD): 6254' Current Current Depth6254' Operations: L/D BHA (TVD): 24 hr Footage (MD): 427' Drilling Parameters ROP: Current: 0 Max: 117 Torque: Current: 0 Max: 4142 WOB: Current 0 Max: 12 RPM: Current: 0 Max: 105 PP: Current: 0 Max: 2644 Lag: Strokes: 4763 Time: 31.1 Surf-Surf: Strokes: 5300 Time: 34.6 ECD: Current: Max: Mud Properties @ 21:00 MW: 10.4 FV: 49 PV: 13 YP: 23 FL: 4.6 Gels: 9/13/17 Sol: 12 pH: 9.2 Cr 400 Ca++: 40 MW Change: Depth: 6253 10.1 To: 10.4 Reason: Gas Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 529 Depth (MD/TVD): 5828 Avg BG : 174 Gas Events Gas above Depth (MD/TVD) Mud Weight (ppg) background (units) 5859 T 10.1 6 5958 10.1 264 Connection Gases 6050 10.1 65 6144 10.1 165 6235 10.1 43 Gas Samples No. Depth TG Cl C2 C3 C41 C4N C51 C5N (MD/TVD) 21 5972 245 22 6019 514 97843.21 5928.993 0 0 490.2332 23 6249 104 Lithologies: Current: None Last 24 hrs: 50% Shale, 30% Carbonaceous Shale, 10% Siltstone, 10% Claystone Operational Summary: Continue Waiting on weather. RIH and Resume drilling from 5827'to 6254'. CBU and weigh up mud to 10.4 ppg. POOH on elevators and UD BHA. Calibrations: None Failures: None Daily Cost: $3,235.00 Total Cost: $54,010.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: L. Hill P. Archey Date: 2/3/2012 Time: 00:01 Current Depth (MD): 6254' Current Current Depth6254' Operations: E-Line (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 21:00 MW: 10.4 FV: 49 PV: 13 YP: 24 FL: 4.3 Gels: 9/13/17 Sol: 12 pH: 9.2 CI' 400 Ca++: 40 MW Change: Depth: 10.1 To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 529 Depth (MD/TVD): 5828 Avg BG : 174 Gas Events Gas above Depth (MD/TVD) Mud Weight(ppg) background (units) Connection Gases Gas Samples No. Depth TG Cl C2 C3 C41 C4N C51 C5N (MD/TVD) Lithologies: Current: Last 24 hrs: Continue L/D BHA, Test BOP. R/D test equipment. M/U wave sonic BHA. RIH Operational Summary: with wave sonic tool and log out of hole at 30 fpm. L/D wave sonic BHA. M/U side core tool on e-line and test. Calibrations: None Failures: None Daily Cost:$3,235.00 Total Cost: $57,245.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: L. Hill P. Archey Date: 2/4/2012 Time: 00:01 Current Depth (MD): 6254' Current Current Depth6254' Operations: POOH with losses (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 21:00 MW: 10.4 FV: 54 PV: 12 YP: 24 FL: 3.9 Gels: 8/11/14 Sol: 12 pH: 9.0 CI- 400 Ca' 40 MW Change: Depth: 10.1 To: Reason: Mud Loss event: Depth: 6254 Volume: 280 Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Gas above Depth (MD/TVD) Mud Weight (ppg) background (units) Trip Gas 6254 10.4 668 Gas Samples No. Depth TG Cl C2 C3 C41 C4N C51 C5N (MD/TVD) Lithologies: Current: Last 24 hrs: M/U side core logging tools on e-line. RIH with e-line to perform side wall coring. POOH w/e-line and L/D BHA. M/U clean out assembly and RIH. Pump hi-vis sweep. With sweep approximately 400' up annulus, lost circulation. Slowed pumps to mitigate losses from 300 GPM to 85 GPM while rotating and Operational Summary: reciprocating. Loss rate slowed from 100 BPH to 50 BPH. Shut down pump, keep string moving and monitor well. Observed slight loss, continued to circulate at 1 BPM on up stroke, S/O pump off, 2 BPM on up stroke, S/0 pump off, stage pump up with minimal returns. Pump out of hole, torqued up and packed off several times through HRZ from 6130'to 6000'. Slowed rate and worked string through tight spots. Circulate and reciprocate string, obtain loss rate at 20 BPH. Calibrations: None Failures: None Daily Cost:$3,235.00 Total Cost: $60,480.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: L. Hill P. Archey Date: 2/5/2012 Time: 00:01 Current Depth (MD): 6254' Current Current Depth6254' Operations: Circulating bottoms up (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: ___Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties Unavailable MW: FV: PV: YP: FL: Gels: Sol: pH: Cf Ca++: MW Change: Depth: 10.1 To: Reason: Mud Loss event: Depth: varies Volume: 108 Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 49 Gas Events _ Gas above Depth (MD/TVD) Mud Weight (ppg) background (units) Trip Gas 4700 10.4 275 6254 10.4 167 Gas Samples No. Depth TG Cl C2 C3 C41 C4N C51 C5N (MD/TVD) Lithologies: Current: Last 24 hrs: Monitor well (slight flow). POOH from 5448'to 2577'. Monitor(slight flow). P/U 30'with no pumps, observe slight flow. Slack off 30' observe fluid drop. Continue POOH from 2577'to 1550'. Pump bit balling pill (no increase in cuttings). Monitor (slight flow). Pump out of hole to 630'. Monitor well intill static. Well still swabbing, Operational Summary: pump out of hole . poull last stand on elevators. P/U and pull stabilizer to floor (packed off) UD same, P/U and clean off bit (packed off). Monitor well (static)RIH w/o stabilizer to 4697' filling every 20 stands. Fill pipe and CBU, work string from 4700'to 4790'. Hole taken approx 20 bbl to obtain returns and giving 20 bbl. Gain with pumps off. Continue RIH from 4787'to 5809' and CBU Calibrations: None Failures: None Daily Cost: $3,235.00 Total Cost: $63,715.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: L. Hill P. Archey Date: 2/6/2012 Time: 00:01 Current Depth (MD): 6254' Current Current Depth6254' Operations: RIH with 7 5/8"Casing (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 21:00 MW: 10.4 FV: 54 PV: 13 YP: 24 FL: 4.1 Gels: 8/10/15 Sol: 12 pH: 9.7 Cr: 400 Ca": 40 MW Change: Depth: 10.1 To: Reason: Mud Loss event: Depth: varies Volume: 24.5 Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 25 Gas Events Gas above Depth (MD/TVD) Mud Weight(ppg) background (units) Trip Gas Gas Samples No. Depth TG Cl C2 C3 C41 C4N C51 C5N (MD/TVD) Lithologies: Current: Last 24 hrs: Wash and ream from 5902'to 6254'. Circulate and condition hole. POOH to 2390' and monitor (static). Continue to POOH on elevators to 502'. Monitor well (static). Operational Summary: Rack back BHA and drain stack. Close blind rams. M/U test plug and test upper rams. R/D test equipment and R/U casing equipment. RIH to 2560' with 7 5/8" casing. Calibrations: None Failures: None Daily Cost:$3,235.00 Total Cost: $66,950.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: L. Hill P. Archey Date: 2/7/2012 Time: 00:01 Current Depth (MD): 6254' Current Current Depth6254' Operations: L/D Drill Pipe (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 21:00 MW: 10.4 FV: 54 PV: 13 YP: 24 FL: 4.1 Gels: 8/10/15 Sol: 12 pH: 9.7 Cr 400 Ca++: 40 MW Change: Depth: 10.1 To: Reason: Mud Loss event: Depth: varies Volume: 101 Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 0 Gas Events Gas above Depth (MD/TVD) Mud Weight(ppg) background (units) Trip Gas Gas Samples No. Depth TG Cl C2 C3 C41 C4N C51 C5N (MD/TVD) Lithologies: Current: Last 24 hrs: Stage in hole with 7 5/8"casing to 6244'. Pump cement and rig down casing Operational Summary: equipment. L/D landing joint, flush out flutes on hanger, set packoff, run in LDS and test 7 5/8"X10 /a packoff to 5000 PSI for 10 minutes. R/U to L/D 5"drill pipe. Laying down 5"drill pipe. Calibrations: None Failures: None Daily Cost: $3,235.00 Total Cost: $70,185.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: L. Hill R.Wall Date: 2/8/2012 Time: 00:01 Current Depth (MD): 6254' Current Current Depth6254' Operations: Conditioning mud (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: _ Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 21:00 MW: 10.4 FV: 40 PV: 12 YP: 23 FL: 4.8 Gels: 8/10/15 Sol: 12 pH: 8.7 Cr 400 Ca' 40 MW Change: Depth: 10.1 To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 0 Gas Events Gas above Depth (MD/TVD) Mud Weight (ppg) background (units) Trip Gas Gas Samples No. Depth TG Cl C2 C3 C41 C4N C51 C5N (MD/TVD) Lithologies: Current: Last 24 hrs: Continue L/D 5"drill pipe. Slip and cut drill line. Change out rams and test. R/D Operational Summary: test equipment. M/U BHA and single in to hold with 4"drill pipe to 6085'filling every 20 stands Conditioning mud.. Calibrations: Chromatograph Failures: None Daily Cost: $3,235.00 Total Cost: $73,420.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: L. Hill R.Wall Date: 2/9/2012 Time: 00:01 Current Depth (MD): 6323' Current Current Depth6323' Operations: POOH (TVD): 24 hr Footage (MD): 68 Drilling Parameters ROP: Current: Max: 28 Torque: Current: Max: 1870 WOB: Current Max: 21 RPM: Current: Max: 153 PP: Current: Max: 2942 Lag: Strokes: 2581 Time: 36.3 Surf-Surf: Strokes: 2958 Time: 41.8 ECD: Current: Max: Mud Properties @ 21:00 MW: 10.8 FV: 88 PV: 28 YP: 28 FL: 3.8 Gels: 4/14/23 Sol: 17 pH: 8.4 Cr 33500 Ca++: 80 MW Change: Depth: 6274' From: 10.4 To: 10.8 Reason: Connection Gas Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: _ Max: 2255 Depth (MD/TVD): 6292 Avg BG : 242 Gas Events Mud Weight Gas above Depth (MD/TVD) (ppg) background (units) 6274 790 Connection/downtime 6315 3003 Gas 6323 1311 6323 987 Trip Gas Gas Samples No. Depth TG Cl C2 C3 C41 C4N C51 C5N (MD/TVD) 24 6271 37 25 6274 765 26 6291 1055 27 6294 371 28 6304 422 29 6315 1746 30 6315 3000 31 6317 334 32 6322 2256 Lithologies: Current: 80%shale 10%siltstone 10%sandstone Last 24 hrs: 80%shale 10%siltstone 10%sandstone CANRIG Circulate and condition mud from 10.3 to 10.5 ppg. R/U to test casing. Test to 3000 PSI for 30 minutes. R/D test equipment. Drill out shoe track and CBU. Operational Summary: Displace to coring fluid and drill 20' of new hole. CBU and perform FIT. Drill from 6254'to 6323' and CBU. Weigh up mud to 10.8 due to connection gas. Monitor hole (static). CBU and rack back stand. Monitor well (static). POOH. Calibrations: Failures: Chromatograph will not stay lit. having a new one shipped in. Daily Cost: $3,235.00 Total Cost: $73,420.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: L. Hill R.Wall Date: 2/10/2012 Time: 00:01 Current Depth (MD): 6348' Current Current Depth6348' Operations: Coring (TVD): 24 hr Footage (MD): 25 Drilling Parameters ROP: Current: 1.4 Max: 18.3 Torque: Current: 1373 Max: 2530 WOB: Current 8.5 Max: 11 RPM: Current: 68 Max: 68 PP: Current: 1152 Max: 1295 Lag: Strokes: 2592 Time: 74 Surf-Surf: Strokes: 2982 Time: 85.2 ECD: Current: Max: Mud Properties @ 21:00 MW: 11.0 FV: 98 PV: 32 YP: 31 FL: 3.8 Gels: 6/14/25 Sol: 17 pH: 8.2 CI 32000 Cal 80 MW Change: Depth: 6340 From: 10.8 To: 11.0 Reason: Gas Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 20 Max: 174 Depth (MD/TVD): 6325' Avg BG : 62 Gas Events Mud Weight Gas above Depth (MD/TVD) (pp background (units) Trip Gas 6323 2939 Gas Samples No. Depth TG Cl C2 C3 C41 C4N C51 C5N (MD/TVD) 33 6335 40 3379.7 484.3 303.0 23.8 103.3 50.5 24.4 34 6347 70 Lithologies: Current: 40%shale 40%sand 20%clay Last 24 hrs: 40%shale 40%sand 20%clay Operational Summary: LID BHA, R/U to test BOP and test BOP. R/D test equipment. P/U core equipment and RIH filling every 20 stands. Begin coring. Calibrations: Chromatograph Failures: Daily Cost: $3,235.00 Total Cost: $79,890.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: L. Hill R. Wall Date: 2/11/2012 Time: 00:01 Current Depth (MD): 6373' Current Current Depth6373' Operations: P/U BHA (TVD): 24 hr Footage (MD): 25 Drilling Parameters ROP: Current: Max: 21.2 Torque: Current: Max: 3096 WOB: Current Max: 12 RPM: Current: Max: 68 PP: Current: Max: 1166 Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 21:00 - MW: 11.2 FV: 80 PV: 28 YP: 26 FL: 4 Gels: 5/12/23 Sol: 17 pH: 8.0 Cf' 34000 Ca++: 80 MW Change: Depth: 6345 From: 11.0 To: 11.2 Reason: Gas Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: 550 Depth (MD/TVD): 6360' Avg BG : 215 Gas Events Mud Weight Gas above Depth (MD/TVD) (ppg) background (units) Gas Samples No. Depth TG Cl C2 C3 C41 C4N C51 C5N (MD/TVD) 35 6350 24 36 6353 78 10902.3 1210.0 490.0 0 80.3 37 6357 501 64168.6 10012.5 4047.3 374.7 734.6 145.5 10.8 38 6365 362 48652.8 6440.1 2483.1 212.9 428.9 99.1 80.4 39 6372 46 5994.4 686.3 391.1 54.9 115.4 16.0 9.6 Lithologies: Current: 50%sand 30%sandstone 20% shale Last 24 hrs: 50%sand 30%sandstone 20% shale Cored to 6373' and pulled out due to no penetration. POOH to 5888' and monitor (static). POOH on elevators to 3631'pulling stands at control rate as per well plan. Operational Summary: L/D core barrels, inspected bit and discovered a piece of core sticking out of bit. Removed core from bit and L/D core barrels. 42'of 50'cored recovered. P/U BHA.. Calibrations: Failures: Daily Cost: $3,235.00 Total Cost: $83,125.00 CANRIG llnii,u ,'I r.inu.,r Lri. ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: L. Hill R.Wall Date: 2/12/2012 Time: 00:01 Current Depth (MD): 6688' Current Current Depth6688' Operations: Circulating (TVD): 24 hr Footage (MD): 315 Drilling Parameters ROP: Current: _ Max: 87 Torque: Current: Max: 3385 WOB: Current Max: 12 RPM: Current: Max: 114 PP: Current: Max: 3065 Lag: Strokes: 1991 Time: 30 Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 21:00 MW: 11.2 FV: 85 PV: 32 YP: 29 FL: 3.8 Gels: 6/25/32 Sol: 17 pH: 8.6 CI 34000 Ca": 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 65 Max: 197 Depth (MD/TVD): 6553 Avg BG : 45 Gas Events Mud Weight Gas above Depth (MD/TVD) (ppg) background Comments (units) 6373 11.2 247 Connection/downtime 6460 11.2 110 Gas 6554 11.2 436 6646 11.2 270 6688 11.2 205 Pumps off 10 min Trip Gas 6180 11.2 3990 Trip in after core 6200 11..2 3086 Gas Samples No. Depth TG Cl C2 C3 C41 C4N C51 C5N (MDlTVD) 40 6373 3997 493465.3 162802.3 57989.1 4847.8 9760.8 1811.4 41 6380 145 22615.4 1586.0 487.9 60.9 146.3 15.2 52.4 42 6410 147 43 6440 87 11632.6 829.2 261.6 14.9 66.6 12.7 2.6 44 6470 60 45 6500 80 10847.6 955.0 329.1 26.6 73.5 19.2 14.2 46 6553 503 47 6687 134 Lithologies: Current: 60%shale; 30%siltstone, 10%sand Last 24 hrs: 40%sand, 30%shale, 20% siltstone, 10%sandstone CANRIG Continue P/U BHA and RIH. RIH to 6180 and CBU getting back 3991 units of gas. Operational Summary: Mad pass from 6255' to 6372'. Tight spot from 6350'to 6372'. Drill ahead to TD at 6688'. Circulating. Calibrations: Failures: Daily Cost: $3,235.00 Total Cost: $86,360.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: L. Hill R. Wall Date: 2/13/2012 Time: 00:01 Current Depth (MD): 6688' Current Current Depth6688' Operations: E-Line (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: _ Max: PP: Current: Max: Lag: _ Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Pro erties @ 19:00 MW: 11.3 FV: 88 PV: 32 YP: _ 29 FL: 3.8 Gels: 6/25/32 Sol: 17 pH: 8.2 Cr 34000 Ca++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Mud Weight Gas above Depth (MD/TVD) (ppg) background Comments (units) Connection/downtime Gas Gas Samples No. Depth TG Cl C2 C3 C41 C4N C51 C5N (MD/TVD) _ Lithologies: Current: Last 24 hrs: CBU two times and monitor hole (static). Pump out to shoe and CBU. Continue Operational Summary: pumping out to 4772 due to thick mud and swabbing. POOH on elevators with proper hole fill. R/U E-line and begin RDT logging.. Calibrations: Failures: Daily Cost:$3,235.00 Total Cost: $89,595.00 CANlIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: G. Whitlock R.Wall Date: 2/14/2012 Time: 00:01 Current Depth (MD): 6688' Current Current Depth6688' Operations: Logging w/wavesonic (TVD): 24 hr Footage (MD): Drilling Parameters ROP: _ Current: _ Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 19:00 MW: 11.3 FV: 88 PV: 30 YP: 30 FL: 3.8 Gels: 6/25/30 Sol: 17 pH: 8.2 Cr 34000 Ca': 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Mud Weight Gas above Depth (MD/TVD) (ppg) background Comments (units) Trip Gas 6205' 11.3 3251 Wiper trip Gas Samples No. Depth TG Cl C2 C3 C41 C4N C51 C5N (MD/TVD) Lithologies: Current: Last 24 hrs: Operational Summary: UD wire line and P/U mule shoe. TIH to 6205 and CBU. Continue to circulate to get gas out. . Performed FIT to 13.5 ppg. POOH to run wavesonic logs Calibrations: Failures: Daily Cost: $2,625.00 Total Cost: $92,220.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: G. Whitlock R. Wall Date: 2/15/2012 Time: 00:01 Current Depth (MD): 6688' Current Current Depth6688' Operations: WOC and circulating (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ 19:00 MW: 11.3 FV: 65 PV: 29 YP: 28 FL: 3.8 Gels: 6/22/29 Sol: 17 pH: 8.8 Cl- 34000 Ca++: 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Mud Weight Gas above Depth (MD/TVD) (PPM (units) Comments (units) Trip Gas 6205' 11.3 2865 Wiper trip Gas Samples No. Depth TG Cl C2 C3 C41 C4N C51 C5N (MD/TVD) Lithologies: Current: Last 24 hrs: Operational Summary: RIH with cement string. CBU and pumped cement. WOO and circulating Calibrations: Failures: Daily Cost:$2,625.00 Total Cost: $94,845.00 CANRIG ConocoPhillips Alaska Inc. SHARK TOOTH #1 Daily Report Report for: G. Whitlock R.Wall Date: 2/16/2012 Time: 06:30 Current Depth (MD): 6688' Current Current Depth6688' Operations: DML Unit Rigdown (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: _ PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: _ Time: ECD: Current: Max: Mud Properties @ 19:00 MW: 11.3 FV: 65 PV: 29 YP: 28 FL: 3.8 Gels: 6/22/29 Sol: 17 pH: 8.8 CI-' 34000 Ca++: 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: _ Current: Max: Depth (MD/TVD): Avg BG : Gas Events Mud Weight Gas above Depth (MD/TVD) (PPg) background Comments (units) Trip Gas 6130' 11.25 29 CBU while WOC Gas Samples No. Depth TG Cl C2 C3 C41 C4N C51 C5N (MD/TVD) Lithologies: Current: Last 24 hrs: Operational Summary: WOC and circulating. DML Unit released at 0630 hours. Calibrations: Failures: Daily Cost: $5,435.00 Total Cost: $100,280.00 CANRIG OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format.
